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182-203
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 01-25 JBR 10/10/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Good test Test Results TEST DATA Rig Rep:Blake / PotthoffOperator:Hilcorp North Slope, LLC Operator Rep:Kavanagh / Williams Rig Owner/Rig No.:Nabors CDR3AC PTD#:1822030 DATE:8/26/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopAGE250827155735 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 2396 Sundry No: 325-322 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2 3/8"P Annular Preventer 1 7 1/16"P #1 Rams 1 Blind/Shear P #2 Rams 1 2 3/8"PS P #3 Rams 1 3"PS P #4 Rams 1 2 3/8"PS P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 2 2 1/16"P Kill Line Valves 1 2 1/16"P Check Valve 0 NA BOP Misc 2 2"P System Pressure P3050 Pressure After Closure P2125 200 PSI Attained P18 Full Pressure Attained P52 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 1900 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer P13 #1 Rams P9 #2 Rams P3 #3 Rams P3 #4 Rams P3 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 7240 / 7740 / 8430 5410 / 6280 / 7500 9700, 9850 & 11000 By Grace Christianson at 8:09 am, May 23, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.05.22 15:04:36 - 08'00' Sean McLaughlin (4311) 325-322 DSR-6/3/25A.Dewhurst 10JUN25JJL 6/2/25 *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 JLC 6/11/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.06.11 10:50:33 -08'00' 06/11/25 RBDMS JSB 061225 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: May 22, 2025 Re:01-25 Sundry Request Sundry approval is requested to set a whipstock in the 01-25 wellbore as part of the drilling and completion of the proposed 01-25A CTD lateral. Proposed plan: See 01-25 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock. Coil will place cement between the 4-1/2"x7" annulus for the dual string sidetrack. E-line will set a 4-1/2" whipstock. If unable to set the whipstock pre -rig, 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 pre-rig, the rig will set the 4-1/2" whipstock and mill a dual (4-1/2"x7") string 3.80" window + 10' of formation. The well will kick off drilling in the Shublik and land in Ivishak Zone 2. The lateral will continue in Zone 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. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. 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 June 20th, 2025) 1. Coil : Perforate the 4-1/2" tubing at ~9699 - 9694 and ~9605 - 9600'. Set cement retainer at ~9689'. Place ~1.7 bbls of cement between the 4-1/2"x7" casing strings. 2. Slickline : Dummy WS drift 3. E-Line : Set 4-1/2" Whipstock at 9670’ MD at 0 degrees ROHS 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in August 2025) x Reference 01-25A Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2396 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window. 3. Drill build section: 4.25" OH, ~590' (24 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~1828' (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: 35 bbls, 15.3 ppg Class G, 1.24 (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. * Alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig RPM and perforate (~30’) 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"or 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 01-25 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 182-203 50-029-20874-00-00 10330 Surface Production Scab Liner Liner Liner 9282 2591 9579 6011 1006 928 9700 13-3/8" 9-5/8" 7" 7" 7" x 4-1/2" 8694 33 - 2624 31 - 9610 2984 - 8995 9317 - 10323 9219 - 10147 33 - 2624 31 - 8613 2981 - 8096 8364 - 9275 8282 - 9108 unknown, 10325 2670 4760 7020 7500 9700 5380 6870 8160 8340 9612 - 10104 4-1/2" 12.6# , 5-1/2 17# L-80 27 - 8960 , 9030 - 9184 8615 - 9067 Conductor 81 20" 34 - 115 34 - 115 1490 470 4-1/2 BKR S-3 , 8835 , 7964 No SSSV 8835 , 9064 7964 , 8153 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028329 27 - 8067 , 8125 - 358 447 10164 13177 1929 1985 0 0 290 1286 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" BKR SB-3A, 9064 , 8153 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 3:10 pm, Sep 05, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.09.05 13:39:22 - 08'00' Bo York (1248) DSR-9/11/24WCB 10-3-2024 RBDMS JSB 091124 ACTIVITYDATE SUMMARY 7/11/2024 ***WELL S/I ON ARRIVAL*** RAN 3' x 1.875" STEM, AND 3.78" GAUGE RING TO 8981' SLM (UNABLE TO FLIP INTO TBG STUB). DRIFTED CLEANLY W/ 22' x 2 7/8" DUMMY GUNS (3.16" RINGS), 3.0" CENT, AND BULLNOSE TO TAG @ 9794' SLM. ***WELL S/I ON DEPARTURE*** 7/13/2024 *** WELL S/I ON ARRIVAL*** OBJECTIVE: PERFORATE INTERVAL W/2 7/8" GEO RAZOR GUN 6 spf 60 DEG PHASE MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH RUN#1 W/CH/1.69'' WB/ 2.75'' GR-CCL/BAKER#10 SETTING TOOL/3.50'' CIBP PLUG TOOL TAGGED AT 9070' MD, AFTER TWO ATTEMPS TO PASS TRUGH, TOWN DECIDE TO PULL OUT AND RIG DOWN, EVERY TIME THE TOOL TAG WE HAVE TO OVER PULL TENSION TO GET THE TOOL FREE ONSURFACE INSPECT THE PLUG IT WAS FOUND FULL PARAFFIN ON BOTTOM OF THE PLUG JOB NOT COMMPLETE WELL READY FOR S/L ***WELL S/I ON DEPARTURE*** 7/20/2024 ***WELL S/I ON ARRIVAL*** RUN 4-1/2" BLB, 3.50" G-RING SD AT 8816'SLM (pkr area) RAN 3.30" CENT, 2' X 1-3/4" STEM, 3.50" CENT DRIFT DOWN TO 9832'SLM RAN 20' X 2-7/8" DUMMY GUNS, 3.50" CENT, 2' X 1-3/4" STEM, 3.70" CENT DOWN TO 9800'SLM ***WELL S/I ON DEPARTURE*** 7/20/2024 T/I/O=2450/0/0 TFS Unit 1 Assist SL (Brush and Flush) Pumped 160 BBLS Crude to Load TBG to 9850ft for Slickline. Slickline in control of well upon departure FWHP=150/0/0 Daily Report of Well Operations PBU 01-25 Daily Report of Well Operations PBU 01-25 7/22/2024 *** WELL S/I ON ARRIVAL*** OBJECTIVE: SET PLUG AND PERFORATE INTERVAL W/2 7/8" GEO RAZOR GUN 6 spf 60 DEG PHASE MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH RUN#1 W/CH/ 2.75'' GR-CCL/BAKER#10 SETTING TOOL/3.50'' CIBP PLUG, TOOL TAGGED AT 9066.4' MD, AFTER ATTEMP TO PASS MULTIPLE TIMES WHILE PUMP ~2 BPM, UNABLE TO GET PAST 9066.4' MD , POOH TO INSPECT THE PLUG. AND RECONFIGURE THE TOOL STRINGS RUN#2 W/CH/ 2.75'' GR-CCL/2.75'' CENTRALIZER/BAKER#10 SETTING TOOL/3.50'' CIBP/MODIFIED BOWSPRING CENT ON THE BOTTOM OF CIBP UNABLE TO GET PAST THE 5.5'' PKR AND TOP OF THE CROSS OVER AT 9066.4' MD, ATTEMP TO PASS WITH MULTIPLE SPEED AND TOOL TAG AT 9066.4' MD, TOOL HANG UP AND OVER PULL TENSION EVERY TIME MOVE THE TOOL UP RUN#3 W/CH/1.69'' WB/1.69'' GAMMA RAY CCL TO TAG DEPTH 9818' MD JOB INCOMPLETE ***WELL S/I ON DEPARTURE*** 7/22/2024 T/I/O=65/0/0 LRS 72 Asist E-Line load and test CIBP (PERFORATING) Pump 10 bbls crude to assist E-Line downhole FWHPs=20/0/0 7/23/2024 T/I/O= 112/0/0 Asist slickline brush & flush (PERFORATING). Pumped 165 bbls of 180* diesel into TBG. FWHP= 603/1061/4 7/23/2024 ***WELL S/I ON ARRIVAL*** (Perforating) BRUSH & FLUSH w/ 4 1/2" BLB & 3.50" GAUGE RING TO TD @ 9,792' SLM DRIFT w/ 10'x2 7/8" DUMMY GUNS,3.5" CENT,3.5" CENT,BOWSPRING CENT TO 9,750' SLM DRIFT w/ 10'x2 7/8" DUMMY GUNS,3.70" WRP DRIFT ***CONTINUED ON 7/24/24 WSR*** 7/24/2024 ***CONTINUED FROM 7/23/24 WSR*** (Perforating) SET 4.5" BIG BOY CIBP @ 9,703' SLM DRIFTED WITH 24' x 2-7/8" DUMMY GUNS TO 9,703' SLM ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 7/25/2024 *** WELL S/I ON ARRIVAL*** (ADPERF) MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH, FUNCTION TEST WLVS PERFORATE 9612'-9636' WITH 2 7/8'' GEO RAZOR GUN 6 spf 60 DEG PHASE CCL TO TOP SHOT 12.9' CCL STOP DEPTH 9599.1' INITIAL TBG PRESSURE=1450 psi FINAL TBG PRESSURE= 225 psi GR-CCL CORRELATE TO SLB IPPROF DATED 9-JAN-2012 RDMO YELLOW JACKET E-LINE ***WELL S/I ON DEPARTURE*** JOB COMPLETE 7/26/2024 Hot Oil Treatment on FL (HOT OIL WASH) Suspected hydrate in FL. Pumped 10 bbls 50/50 meth and 235 bbls 190* crude down FL, Pressured FL to 1500 psi. DSO notified of well status per LRS departure. SV,WV,SSV=SI MV=O IA,OA=OTG CIBP and adperfs are correctly shown on the WBS, below. -WCB PERFORATE 9612'-9636' SET 4.5" BIG BOY CIBP @ 9,703' SLM Daily Report of Well Operations PBU 01-25 7/28/2024 T/I/O=2500/0/0 HOT TBG ( Ops Call ) Pump 0.5 bbls 50/50 down tbg. Tbg locked up. Pump 3 bbls 50/50 & 150 bbls 190* crude down flowline for hot FP. Pressure up on Tbg w/ .1 bbls. Tbg still froze. DSO notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 8/1/2024 T/I/O= 2045/0/4 (HOT OIL TBG WASH) Pumped 2 bbls of 50/50 and 118 bbls of 190* Crude down TBG. DSO notified of well status upon departure. Valve Positions - SV/WV/SSV = Closed, MV = Open, IA/OA = OTG FWHPs= 526/871/6 **Standby for fluid for 4.75 hours** 8/4/2024 T/I/O = 1963/31/0 Hot Oil Treatment (HOT OIL TBG WASH) Pumped 2 bbls of 50/50 & 118 bbls of 190*F crude down TBG. Pumped 73 bbls of 190*F crude down FL. DSO notified upon departure. FWHP = 685/684/3 8/6/2024 LRS 76 (HOT OIL TBG WASH) ***Job Cancelled by DSO on arrival*** 8/7/2024 T/I/O= 2304/0/2. LRS 72 Hot Oil Treatment (HOT OIL TBG WASH). Pumped 118 bbls of 190*F crude into the TBG. Pumped 140 bbls of 190*F crude into the F/L. Final T/I/O= 518/0/2 2 hour wait for fluids. 8/9/2024 T/I/O= 2106/0/0. LRS 72 Hot Oil Treatment (HOT OIL TBG WASH). Pumped 2 bbls of 60/40 MeOH and 118 bbls of 190*F crude into the TBG. Pumped 140 bbls of 190*F crude into the F/L. Final T/I/O= 675/0/2. 8/10/2024 ***WELL S/I ON ARRIVAL*** (Hot oil tbg wash) RAN 4-1/2" BRUSH & 3" SAMPLE BAILER TO HYDRATES AT 1591' SLM ***CONTINUE ON 8/11/24 WSR*** 8/10/2024 T/I/O = x/vac/0, LRS 46, Assist Slickline w/ B&F (HOT OIL TBG WASH) ***Called off for priority job*** 8/11/2024 T/I/O = 689/vac/2 LRS 46 - Assist Slickline (HOT OIL TBG WASH) Pumped 160 bbls 180* Diesel into TBG for B&F. SL in control of well and DSO notified upon LRS departure. 8/11/2024 ***CONTINUE FROM 8/10/24 WSR*** (hot oil tbg wash) RAN 3-1/2" BRUSH & 2.50" G. RING TO CIBP AT 9,700' MD RAN 4-1/2" BRUSH & 3.60" G. RING TO CIBP AT 9,700' MD (LRS pumped 160 bbls hot diesel) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS**** 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 01-25 Convert Inj to Prod Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 182-203 50-029-20874-00-00 10330 Surface Production Scab Liner Liner Liner 9282 2591 9579 6011 1006 928 9850 13-3/8" 9-5/8" 7" 7" 7" x 4-1/2" 8827 33 - 2624 31 - 9610 2984 - 8995 9317 - 10323 9219 - 10147 33 - 2624 31 - 8613 2981 - 8096 8364 - 9275 8282 - 9108 unknown, 10325 2670 4760 7020 7500 none 5380 6870 8160 8340 9610 - 10104 4-1/2" 12.6# , 5-1/2 17# L-80 27 - 8960 , 9030 - 9184 8613 - 9067 Conductor 81 20" 34 - 115 34 - 115 1490 470 4-1/2 BKR S-3 , 8835 , 7964 No SSSV 8835 , 9064 7964 , 8153 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028329 27 - 8067 , 8125 - 0 358 0 10164 0 1929 0 0 0 290 323-098 13b. Pools active after work:PRUDHOE OIL 5-1/2" BKR SB-3A, 9064 , 8153 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 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.09.05 12:23:49 -08'00' By Grace Christianson at 3:17 pm, Sep 05, 2023 RBDMS JSB 090823 DSR-9/12/23WCB 4-9-2024 ACTIVITYDATE SUMMARY 5/28/2023 T/I/O = 1222/-4/-8. Temp - SI. Conduct MIT-IA. Pumped 4.4 bbls 50* DSL into IA to reach max applied pressure of 2743 psi. 1st 15 min, IA lost 105 psi. 2nd 15 min, IA lost 34 psi. Bled back 4.4 bbls. Tag hung. Pad operator notified upon departure. FWHP's = 1222/0/-8 7/19/2023 2023 Shut down-Installed divert valves and drain valves for conversion tie in. 7/23/2023 Well start up check list complete. Copy filed at drill site in well folder and copy given to DSL. Well should be good to BOL. 8/4/2023 Hot Oil Treatment (HOT OIL TBG WASH) Pumped 3 bbls 60/40 meth and 7.75 bbls 190* Crude before TBG locked up at 2750 psi. SV/WV/SSV = C, MV = O, IA/OA = OTG. DSO notified upon LRS departure. 8/6/2023 T/I/O= 897/0/3 LRS Unit 72 Hot Oil Treatment. (HOT TBG WASH) Pumped .13 bbls 60/40 meth down the TBG, Well locked up at 2500 PSI. (WELL FROZEN) Bled TBG pressure to 1500 psi. FWHP's 1500/0/3 DSO notified of well status per LRS departure. 8/14/2023 LRS #2 2" Coil Tubing - Job Scope = Hydrate plug removal. MIRU. MU 2.25" DJN. Swap coil to 60/40 methanol. RIH and tag ice 1,079' ctmd. Begin jetting ice at 1 bbl/m down to 1,282', had a spike in pressure. Closed the choke and bull head fluid. Good communication to the formation. Continued in hole for a drift. Tag at 9813' CTM. POH. FP well with 38 bbl (5 bbl 60/40 + 33 bbl diesel). RDMO. Fullbore to FP outlet well 01-26 flowline. ***Job Complete*** Daily Report of Well Operations PBU 01-25 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: 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 What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 01-25 Convert Inj to Prod Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 182-203 50-029-20874-00-00 ADL 0028329 10330 Surface Production Scab Liner Liner Liner 9282 2591 9579 6011 1006 928 9850 13-3/8" 9-5/8" 7" 7" 7" x 4-1/2" 8827 33 - 2624 31 - 9610 2984 - 8995 9317 - 10323 9219 - 10147 33 - 2624 31 - 8613 2981 - 8096 8364 - 9275 8282 - 9108 unknown, 10325 2670 4760 7020 7500 none 5380 6870 8160 8340 9610 - 10104 4-1/2" 12.6# , 5-1/2 17# L-80 27 - 8960 , 9030 - 91848613 - 9067 Conductor 81 20" 34 - 115 34 - 115 1490 470 4-1/2 BKR S-3 , 5-1/2" BKR SB-3A No SSSV Installed 8835 , 9064 7964 , 8153 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3-15-23 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 8:30 am, Feb 16, 2023 323-098 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.15 15:15:23 -09'00' X DSR-2/22/23 DLB 02/23/2023 10-404 MGR16FEB23GCW 02/24/23 JLC 2/24/2023 2/24/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.24 12:48:39 -09'00' RBDMS JSB 022823 From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 01-25 (PTD #1822030) Lapse on 4 year AOGCC MIT-IA Date:Tuesday, October 5, 2021 3:23:55 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 5, 2021 1:21 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector 01-25 (PTD #1822030) Lapse on 4 year AOGCC MIT-IA Mr. Wallace, Injector 01-25 (PTD #1822030) will not be on injection this month for required 4 year AOGCC MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 8:41 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 01-25 (PTD #1822030) Lapse on 4 year AOGCC MIT-IA From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 5, 2021 1:21 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector 01‐25 (PTD #1822030) Lapse on 4 year AOGCC MIT‐IA Mr. Wallace, Injector 01‐25 (PTD #1822030) will not be on injection this month for required 4 year AOGCC MIT‐IA. The well is now classified as NOT OPERABLE and will remain shut in. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggro DATE: Tuesday,October 17,2017 l P.I.Supervisor '!1(/7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 01-25 FROM: Bob Noble PRUDHOE BAY UNIT 01-25 Petroleum Inspector Src: Inspector Reviewed Bye� P.1.Supry X) ---- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 01-25 API Well Number 50-029-20874-00-00 Inspector Name: Bob Noble Permit Number: 182-203-0 Inspection Date: 10/13/2017 Insp Num: mitRCN171013171015 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ] 01-25 `Type Inj W "TVD 7964 - Tubing 702 - 702 • 703 705 - I PTD , 1822030 [Type Test SPT i Test psi 1991 - IA ' 16 2500 ' 2399 2371 BBL Pumped: 1 3.4 •'BBL Returned: 2.9 OA 1 - 1 1 - ! I - P • Interval 4YRTST P/F P Notes: SCANNED I , 1 Tuesday,October 17,2017 Page 1 of 1 • 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 May 11, 2012 <'L F AU G 1 lZ Mr. Jim Regg oZ� Alaska Oil and Gas Conservation Commission ( 333 West 7 Avenue ` Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -01 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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) DS-01 01/20/12 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft NA qal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover _ NA NA NA NA NA 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -17B 2040120 50029202890200 Sealed conductor NA _ NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -19B 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 01 -225 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 ...---, 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA _ 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA ' %2 -20 31- JAN2O12 -2 Schhnderger 5885 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -24A BINC -00093 INJECTION PROFILE 15-Jan-12 1 1 01 -25 BBSK -00105 INJECTION PROFILE 9-Jan-12 1 1 14-44A BUTT -00054 MEMORY LEAK DETECT LOG 28- Dec -11 1 1 01 -02 BVYC -00024 CROSSFLOW CHECK 30- Dec -11 1 1 V -212 BAUJ -00106 MEMORY INJECTION PROFILE 26- Dec -11 1 1 S -110 BX69 -00018 USIT 7-Jan-12 1 1 01 -02 BYS4 -00015 CROSSFLOW CHECK 4-Jan-12 1 1 R -16 BG4H -00106 SBHPS 23- Dec -11 1 1 01 -30 BD88 -00189 MEMORY INJECTION PROFILE 19- Dec -11 1 1 15-47 BG4H -00105 CEMENT BOND LOG SCMT 20- Dec -11 1 1 13 -12A BVYC -00018 ISOLATION SCANNER 30- Nov -11 1 1 MPI -18 BG4H -00107 ISOLATION SCANNER 25- Dec -11 1 1 NGI -10 BBSK -00102 USIT 16- Dec -11 1 1 Z -116 BBSK -00104 ISOLATION SCANNER 22- Dec -11 1 1 V -222 BUTT -00051 MEMORY INJECTION PROFILE 26- Dec -11 1 1 V -106A BCRJ -00108 FSI 15- Aug -11 1 1 • - I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 I 1 12/30/10 rger NO. 5672 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambe9 Street, Suite 400 Alaska Oil B Gas Cons Comm Anchorage, AK 99503 - 28381 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 / i- ° Anchorage, AK 99501 Y Job # Log Description Date BL Color CD E -05= BL65 -00011 MEM DDL 12/18/10 1 1 AY1M -00056 -'•. -•• • � a.. —/ _. 11/27/10 1 � •.0 1 • ' AY1M -00058 IJa•].99a• i #» ,M.l_ ♦ li �0 1 —_ • B5JN -00077 �jf1rME lIlnZT3EMO E.III—_ IMIMMEMIIII BC22.00030 IEMIIIIM/dgire •1=1110 - SZ INIM■111111111■11 lN.tMV• ' r e YjO11111■1111111■ ELlatliivai liralL'!!'11111EIMMOBLT.LY_#111•=111111111111111■111111 - .. 2- 28 _� • 8/0 -19 BCRJ -00055 PROD PROFILE T , , , „, SCMT — k • — � �. - ®O�iT+E�iT� -- :: , , , SCMT • aes"i - r'1' • ®' (i • .5:' t�B , ,,,,. SCMT /n — ' A 1• 00 -- ' - SCMT ( j - , : r P2-16 B5JN-00077 USIT ( ,10 e • ♦ • T b �0 � i 16-06B BBSK-00037 MCNL r — , • , -- RST O ii • 7 09/20/10 (G7 ' � -- D88-00 , , MCNL — 09/28/10 -- W-219 BGZ7-00012 CH EDIT PDC -GR USIT ,�• ' y r P! • 11 1111111ME-- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Ben50n Blvd. Anchorage, AK 99503 -2838 4s 4; ` - m 1 4 2.01 • n U MEMORANDUM To: Jim Regg ~C~c~ /(~3a~C~ P.I. Supervisor l FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 02, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 01-25 PRUDHOE BAY UNIT OI-25 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT 01-25 Insp Num: mitCS09 103 0 1 5 1 543 Rel Insp Num: API Well Number: 50-029-20874-00-00 Inspector Name: Chuck Scheve Permit Number: 182-203-0 - Inspection Date: 10/29/2009 Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. - -- ---- ~ ~ Well 01-25 ~1T e In ~ W .~~ - --- - 7964 ~IA -T -- 2400 ~ 2370 ~ 2360 T yP - P.T.D 1822030 ~' eTest SPT~est SI p _ --- ---~--1 - ~ T~ 1991 ~ QA -- -~- T bi l -- --- -~ ~ 0 ' 0 i 0 __ ____ ~--- --- - lsso lsso ~ lsso vR P Interval ~O P/F u n g ~ Notes• Second pressure test. ~•la-~ ~ 2 YW AVY~ Yiy Y~ai~~ ~~~~4 V C:. {` V 1 tv Monday, November 02, 2009 Page 1 of 1 I"-1 U MEMORANDUM To: Jim Regg I~c~ ~ ]t~3z5~p~i P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 02, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 01-25 PRUDHOE BAY UNIT 01-25 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: PRUDHOE BAY UNIT 01-25 API Well Number: 50-029-20874-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS091030150940 Permit Number: 182-203-0 Inspection Date: 10/29/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1-25 i ' ! Well I- ~TYPe InL~~' a TVD I 7964 ~ IA_-_ 0 ~ - 7-- _--- 2400 .~ -- 0 -~ 2230 2000 22 7 ~ -- --- - - -i --- ---- I - 1822030 SPT ~~TYpeTest i ~ Test psi P.T.D. 1 --- 1991 ~ ~ OA ~ ~ ~ ~ ~ 0 0 I - --- ------ ~ - ~ / _ - --- -~ -_ F - WRKOVR P~F, InterVal g --- -- TUbin ~ I550 --- 1.550 ~ _-~- r - 1550 i I550 ~ 1550 I - JJJ~~~-~ _ _ Notes• ~ appeazed to have steady pressure leak on this test. Repressured and test passed. ~ ~~~~ ~~~ J~« Monday, November 02, 2009 Page 1 of 1 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM~ION REPORT OF SUNDRY WELL OPERATIONS `,°~' ~ ° fi~ ~ ~~~ ~ ~.~~~ ,=~~,3 z~; ~ 4 2Q0~ , .,.a. h~,~,. ~~~.r~~~~sr~~ , r , : ,e~m 1. Operations Performed: ' ~ ^ Abandon ~ Repair Weli ^ Piug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ~Other ^ Change Approved Program ^ Operation Shutdown ^ PerForate ^ Time Extension ~-o~~ ~~^ ~-~r 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 182-203 3. Address: ~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20874-00-00 7. KB Elevation (ft): 74, 9. Well Name and Number: PBU 01-25 8. Property Designation: 10. Field / Pool(s): ADL 028329 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 10330' feet true vertical 9282' feet Plugs (measured) 9850' Effective depth: measured 9850' feet Junk (measured) true vertical 8827' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2624' 13-3/8" 2624' 2624' 4930 2670 Intermediate 9610' 9-5/8" 9610' 8613' 6870 4760 Production Liner 1011' 7" 9317' - 10328' 8364' - 9280' 8160 7020 Liner 928' 4-1/2" 9219' - 10147' 8282' - 9108' 8430 7500 Scab Liner 6058' 7" 2984' - 9042' 2981' - 8135' 7240 5410 Perforation Depth MD (ft): 9610' - 9850' PerForation Depth TVD (ft): 8813' - 8827' °N°~• ~ ~~g~ '' } `.' ~ ' '~~,~,~~~ 4-1/2", 12.6# L-80 8960' Tubing Size (size, grade, and measured depth): 5-1/2", ~ 7# x 4-1/2", 12.6# 9030' - 9185' Packers and SSSV (type and measured depth): ~~~ x 4-1/2" BKR S-3 packer ~~ ~,,~~gs~ -~ 8835'; 9-5/8" x 5-1/2" Baker'SB-3A' packer; ~9yN 9064' 12. Stimulation or cement squeeze summary: r `L1 ~- °Q~- /'~+-~ ~~~~ ~ l Intervals treated (measured): ~ 3 - Treatment description including volumes used and final pressure: Cut and pull tubing from 9030'. Run 7(26#, L-80, BTC-M) scab liner. Cement w/183 bbls Class 'G° (1027 cu ft/ 888 sx). Cut and pull 9-5/8" casing from 1960'. Run 9-5/8" (47#, L-80, BTC-M) tieback to surface. Cement w/ 137.1 bbls Class 'G' w/ Gas-Blok (770 cu ft/ 664 sx). Clean out and run new tubing. 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ~ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ~ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: Contact Hank Baca, 564-5444 309-094 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: ~ Si nature Phone 564-5743 Date ~~ ' ondra Stewman 564-4750 ~G~~ Form 10-404 Revised 04/2006 Submit Original Only ,~ : ~~ ~ _ A ~~., AEJG ~ €3 ~OQ9 ~I ~Q l`~~'` ~- TREE = CNV VEiELLHEAD FMC ACTUATOR = BAKER C KB. E1EV = 74' BF. ELEV = KOP = 300d' Max Angie = 35° @ 6300' Datum MD = 9900' Datum ND = 8800' SS 9-5/8", 47#, L-80 HYD 523 XO TO L-80 BTC 9-5(8" BOWEN CSG PATCH, 47#, L-80 BTC, ID = 8.681" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ O~ ~~ ~ ALL~jOTES: *""PWI ONLY/NO MI INJECTION ,.~« 1893' ~ 1916~ 9-5/8" HES ES CEMENTER 1919~ 4-1l2" HES X NIP, ID = 3.813" 1938~ 9-5/8" ECP, ID = 8.760" 1963' I 2624' I Minimum ID = 3.725" @ 9173' 4-1/2 OTIS XN NIPPLE 4-1/2" TBG, 12.6#, L-80 TCII, -j $960~ 0152 bpf, ID = 3.958" 7" SCAB LNR, 26#, L-80 BTGM, ID = 6.276" -1 2984' - 8995~ 5-1/2" TBG STUB (06/25/09) 9030~ 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 9084' TOP OF 4-1/2" TBG-~ 9084' 4-1/2" TBG-PC, 12.6#, L-80, 9184~ .0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR 9219~ PERFORATION SUMMARY REF LOG: BHCS ON 02/21/83 A NGLE AT TOP PERF: 23° @ 9835' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERF BREAFmOW N TOP OF 7" ~NR I~ 9317~ 9-5/8" CSG, 47#, L-80, ID = 8.681 " ~-{ 9610~ I4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-1 10147, 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10323~ TD 10330' 2984~ -~ 9-5/8" X 7" BKR ZXP LTP, ID = 6.159" ~ 3003~ 9-5/8" X 7" BKR FLIX LOCK HGR, ID = 6.159" 8804~ 4-1/2" HES X NIP, ID = 3.813" 8835~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.813" $$68~ 4-1/2" HES X NIP, ID = 3.813" 8960~ 4-1l2" MULESHOE, ID = 3.95~ 8995~ 7" X 5-1/2" PORTED XO, ID = 4.892" 9042~ 5-1/2" UNIQUEOVERSHOT~ 9064~ 9-518" X 5-1/2" BKR SB-3A PKR, ID = 4.875" 9084~ XO MILLOUT IXT X 4-1l2", ID = 6.625" 9173~ 4-1/2" OTIS XN NIP, ID = 3.725" 9184' 4-1/2" X 7" XO, ID = 3.90" 9185~ 7" MULESHOE JOINT, ID = 6.276" 9207' 9-5/8" X 7" BROWN HY FLO II LNR/HGR, ID = 6.184" 9212~ 7" X 9-5/8" BROWN TYPE H LNR TOP PKR, ID = 6.196" 9218~ ' 7„ X 4-1/2" XO, ID = 3.958„ 9850~ --I TOPOFCEMENT(12/21/05) ~ 9986~ 7" X 4-1/2" BKR ECL ISOLATION PKR, ID = 3.958" 10000' CTM TAG TD PRE CMT (12/21/05) 10325~ 1/8" X 1" X 6" PIECE OF CENTRALIZER SPRING (LEFT 06/10/94) DATE REV BY COMMENTS DATE REV BY COMMENTS 03l24l83 ORIGINAL COMPLETION 03/03/90 LAST WORKOV FR 07/07/09 D16 RWO 07/28/09 HB/JMD DRLG DRAFT CORRECTIONS PRUDHOE 8AY UNIT W ELL: 01-25 PERMIT No: r1822030 API No: 50-029-20874-00 SEC 7, T10N, R15E, 872' FNL & 594' FWL BP 6cploration (Alaska} ~ 01-25 ~ PERFORATION SUMMARY REF LOG: BHCS ON 02/21/83 ANGLEATTOP PERF: 23° @ 9835' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 3-3/8" 9610 - 9612 0~ 03/04/83 3-3/8" 9778 - 9796 ~ ~I 09/15/89 3-3/8" 4 9806 - 9812 Q~ 12/03/96 3-3/8" 9822 - 9824 ~~ 03/04/83 2-1/2" 6 9835 - 9850 ~ 02J16/06 3-3/8" 9861 - 9863 S 03/04/83 3-3/8" 9890 - 9900 S 07l03/93 9908 - 9914 S 07/03/93 9920 - 9924 S 07/03/93 2-1 /2" 6 9928 - 9940 S 02/19/97 9940 - 9944 S 12/03/96 2-1/2" 4 9954 - 9974 S 12/92/96 9984 - 9990 S 07/03/93 9990 - 10010 L 12/03/96 10010 - 10073 S 06/03/91 10102 - 10104 S 03/04/83 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/24/83 ORIGINAL COMPLETION 03/03/90 LAST WORKOV ER 07/07/09 D16 RWO 07/28/09 HB/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: 01-25 PERMff No: ~1822030 API No: 50-029-20874-00 SEC 7, T10N, R15E, 872' FNL & 594' FWL BP E~cploration (Alaska) ~ ~ 01-25 Well History Date Summary LJ 03/27/09 RIG UP BRAIDED LINE ON SWCP 4515, DHD SHOT TBG FLUID LEVELS --T @ 7164' / IA @ SURFACE 03/28/09 T/I/0=2200/0/200 Assist Slickline with load and kill. Pumped 5 bbls neat, 270 bbls of 140" 1% KCL capped w/ 10 bbls neat and 50 bbls 100* diesel down tbg. 03/28/09 DRIFT W/ 4.5" GAUGE RING TO TOP OF PATCH C~3 8059' BLM (no restrictions). PULLED UPPER ECLIPSE PATCH FROM 8059' BLM (element intact) 03/29/09 PULLED 5-1/2" ECLIPSE LOWER ANCHOR FROM 8096' BLM (one slip & back up for element missing). DRIFT W/ DOUBLE KJ 5-1/2" BL- BRUSH 2.75" MAGNET TO 4-1/2" XO @ 9084' MD. DRIFT W/ 4.25" CENT, S. BAILER TO XO C«~ 9080' BLM, (no restrictions / no sample). DRIFT W/ 3.70" CENT, S. BAILER TO 9840' SLM (no sample). RAN 3.625" CENT 3.50" SUPER MAGNET TO RESTRICTION C~ 9500' BLM (no recovery) 04/24/09 T/I/O=SSV/70/200, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (0+ psi). Functioned LDS (standard), all moved freely (1 "). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (50 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (.75"). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 06/13/09 yFT 5-1/9~~ WHII~I~QN C:-SI1R CaZ 9076~ sLM. PULLED STA# 9 CHEM INJ VLV Q 8958' SLM/ 8955' MD. PUMPED -5 BBLS DIESEL THROUGH CHEM INJ LINE TO FLUSH OUT. PULLED EMPTY C-SUB Q 9(l76' SI M*`~TA# Pn ,KFT I FT ~P N"' 06/14/09 INITIAL T/IA/OA: 150/50/200. RIG UP E-LINE. RIH WITH 4-1/2" FASDRIL PLUG TO 9200'. 06/15/09 SET 4-1/2" 2 FASDRIL PLUGS AT 9162' AND 9142' (TOP OF PLUG). TIED INTO TUBING TALLY DATED 3/30/90. VERIFIED PLUG AND PACKER INTEGRITY BY LOGGING LEAK DETECTION LOG FROM PLUG SET DEPTH TO SURFACE. NOTICED TEMP KICK AT APPROX 5700', BUT NO OTHER ANOMALIES. CUT 5.5" TUBING AT 9036' IN THE MIDDLE OF THE FIRST FULL JT ABOVE THE PACKER. DSO NOTIFIED OF VALVE POSITIONS ON DEPARTURE. FINAL T/IA/OA: 350/ 06/15/09 T/I/0=390/140/165 Temp=Sl Assist E-line, LDL (RWO Prep) Pumped a total of 42 bbls of diesel down IA to establish a LLR of 0.9 bpm @ 1020 psi and a LLR of 0.25 bpm @ 520 psi. Riqqed up to Tbq to attempt LLR. Leak too small for LRS pump_ Pumped a total of 9 bbis down Tbg to hold pressure between 2100 psi and 1900 psi on Tbg to allow E-line to run LDL. E-line on well upon departure. FWHP's=440/200/250. 06/18/09 T/I/0=600/60/400 Temp=Sl Circ Out, MIT OA PASSED to 2000 psi (RWO Prep)_ Pumped down Tbg through Jet Cut at 9036' up IA and to the treecap of 01-26 with 3 bbls meth & 260 bbls 9.8 brine. At 260 bbls away down Tbg, slowly shut IA to qauqe LLR on PC Leak. ,Pumped 20 bbls at 1.7 bpm Q 2000 psi to establish LLR. Once LLR established Increase rate to 4.5 bpm for a total of 730 bbls of 9.8 brine followed by 3 bbls diesel to freeze protect tree. Freeze protected Hardline jumper with 3 bbls diesel. Pressured up OA to 2000 psi with 2 bbls crude for MIT OA, OA lost 60 psi in the 1 st 15 mins and 30 psi in the 2nd 15 mins for a total pressure loss of 90 psi in 30 min test. Verify annulus casing valves open & tagged. Swab-shut, Wing-shut, SSV-shut, Master-open, Hardline shut from 01-25 to 01-26 and Shut 01- 26 Swab valve. Final WHP's= 0/0/0. 06/20/09 Set 5 1/8 FMC ISA #538 thru tree pre rig for poyon 16. 1-2' ext used tagged Q 92". No problems Page 1 of 2 ~ ~ ' BP' EXP Operations ~ Legal Well Name: 01-25 Common Well Name: 01-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 _ I_ _; I.. I_ . I_ , I 6/22/2009 17;00 - 00:00 7.00 MOB P 6/23/2009 I 00:00 - 03:00 I 3.00 I MOB I P 03:00 - 14:00 I 11.001 MOB I P 14:00 - 15:00 1.00 MOB P 15:00 - 16:30 1.50 MOB P 16:30 - 17:30 I 1.00 I MOB I P 17:30 - 19:00 1.50 MOB P 19:00 - 21:00 2.00 MOB P 21:00 - 22:30 1.50 MOB P 22:30 - 23:00 0.50 MOB P 23:00 - 00:00 1.00 MOB P 6/24/2009 J 00:00 - 01:00 ~ 1.00 I WHSUR I P 01:00 - 02:30 I 1.50I WHSUR ~ P Spud Date: 2/9/1983 Start: 6/17/2009 End: 7/6/2009 Rig Release: 7/6/2009 Rig Number: Phase Descriptian of Operatit~ns PRE Lower derrick. Move rig off of L3-31 and spot in middle of L3. Remove BOP stack from cellar. Install rear boosters. Move rig off of L3 pad down the access road and onto East Dock road. PRE Move rig down East Dock road, turn left toward the East Side Guard shack, right onto DS 1 access road. PRE Replace inner ODS rear tire that went flat (due to broken bead) on the DS-1 access road. PRE Remove Booster Wheels from front of rig. PRE Move rig around South end of DS1 on rig mats without incident. Set up to R/U the Cellar which had been stripped to replace one of the tires. PRE P/U BOP stack and set on pedestal in cellar. Hold PJSM to R/U Cellar. PRE Spread herculite, lay rig mats, position rig to in order to pull onto the well. PRE Move rig over the well, but could not spot due to valve position on the tree. Call DSM to remove and cap the valve. PRE Raise the derrick and rig up the rig floor. PRE S ot ri over Well 1-25. PRE Rig up circulating manifold in the cellar, bridle down, and spot the slop tank. WHDTRE Continue to rig up circulating lines and annulus valves. Spot the generator and pump modules. WHDTRE Begin to take on 9.8-ppg brine. Rig up DSM and pressure test the lubricator to 500-psi for 5 minutes. Pull the BPV and riq . 02:30 - 05:00 I 2.501 WHSUR I P 05:00 - 06:00 I 1.001 WHSUR I P 06:00 - 08:00 I 2.001 WHSUR I P 08:00 - 11:00 I 3.001 BOPSUa P 11:00 - 12:00 1.00 BOPSUF~P 12:00 - 16:00 4.00 BOPSUF~ P WHDTRE Pressure test circulating lines to 3500-psi. Good Test. Reverse circulate in 40-bbls at 450-psi until returns were seen at surface, continue to pump an additional 23-bbls to clear diesel out of the tubing, Swap over the lines and begin to pump the long way with a 25-bbl Hi-vis sweep followed by 630-bbis of 9.8-ppg brine at 500-psi. Clean returns of 9.8-ppg brine were seen after a full surface to surface circulation at 610-bbls pumped. Shut down the pumps and monitor the well for 30 minutes. Static. WHDTRE Set the BPV and perform rollin4 test at 1-BPM to 1000-psi frorr WHDTRE ~ N/D Tree and adaptor flange. Called AOGCC at 0610-hours to give 2-3-hour callout for initial BOP Test. Jeff Jones, AOGCC Inspector, returned call at 0615-hours and waived State's right to witness Doyon 16's initial BOP test on DS1-25. P/U and M/U XO to LH Acme threads 9-1/2-turns. Install blanking plug with 10 RH turns. WHDTRE PJSM. N/U BOP stack nd adaptodspacer spool. Remove 2-7/8" x 5" VBRs and replace with 3-1/2" x 6" VBRs. WHDTRE R/U to test BOPE. WHDTRE Perform initial BOPE test: 250-psi low and 4,000-psi high using 4" and 5-1/2" test joints for the VBRs and holding the max pressure on the Annular Preventer to 3,500-psi. Record all tests for 5-minutes on chart recorder. Koomey test: system pressure 3000-psi; pressure after close 1950-psi; 200-psi increase after 17-secs; full pressure after 67-secs; 5-bottles N2 ~ 2120-psi. Printed: 7/29/2009 3:03:12 PM ~ ~ _ __ __ BP EXPLQR,4TI~N Page 2 of 15 Operations Summary Report Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Qate From - Tv Hours Task ~ Code NPT 6/24/2009 16:00 - 16:30 0.50 BOPSU P 16:30 - 17:30 I 1.00 I BOPSUp P 17:30 - 18:00 0.50 BOPSUF~ P 18:00 - 18:30 0.50 WHSUR I P 18:30 - 19:00 ~ 0.50 ~ PULL ~ P 19:00 - 20:00 I 1.00 I PULL I P 20:00 - 20:30 0.50 PULL P 20:30 - 00:00 3.50 PULL P 6/25/2009 00:00 - 01:30 1.50 PULL P 01:30 - 02:30 1.00 PULL P 02:30 - 10:00 I 7.501 PULL I P 10:00 - 11:00 I 1.001 PULL I P 11:00 - 12:30 I 1.501 CLEAN I P ~ ruu.,~v ~,'~.. .. .. ._.~i~~..sic.~,,i t. ..p.:...~....~..~,~,., WHDTRE R/D BOPE test equipment. M/U landing joint to blanking plug running XO, RIH, M/U to blanking plug, and FMC pull the blanking plug. WHDTRE P/U Dutch Riser and install in BOP stack; RIH locking pins. P/U DSM lubricator install on Dutch Riser and PT to 500- si. Bleed off control lines and bleed the chemical injection line to the cuttings tank. Hook up IA to cement line and fill with 5.1-Bbls or F/L at -117' after being S/I for 5-hours. M/U BPV pulling tool to extensions, RIH and engage into BPV. Release, BPV and get a puff of air that immediately bleeds off. POH and break off BPV. dismantle extensions, and UD lubricator. WHDTRE R/D Dutch Riser, POH and UD same. DECOMP Drain the stack and make up the landing joint to the hanger with 9 turns. Screw into the landing joint with the top drive and back out the lock-down screws. DECOMP Pull the hanger free at 195k (20k overpull) and pull the tubing ree at 2 overpull . Pull the hanger above the rotary table with a string weight of 175k. Terminate the control lines and chemical injection line at the rig floor. DECOMP Circulate a bottoms up (396-bbis) at 10-bpm with 400-psi. Rig up Schlumberger control line spooler and the power tongs. Monitor the well, static. DECOMP Break out and lay down the hanger and landing joint. DECOMP Start laying down the 17# 5.5" L-80 completion from 9036' to 6847', terminate the control lines at the SSSV. Continue to pull the 5.5" tubing from 6847' to 6536'. Recovered 5 Stainless Steel bands to the SSSV and 59 clamps. All joints breaking out smoothly. DECOMP Continue laying down 5.5" tubing from 6536' to 4956'. DECOMP Well began flowing over the stub, shut down hole fill. Still showing flow, so stabbed the floor valve and began to monitor the annulus. No Flow. Circulate surface to surface (347-bbls) at 10-bpm with 1020-psi. Monitor the well. Static. Pump a 15-bbl dry job. DECOMP Continue laying down 5.5" tubing from 4956' to 3523'. Joints breaking out smoothly. Recovered a total of 1 SSSV, 2 GLM's, 5 stainless steel bands and 146 clamps. Fluid loss to well .3-bbls per joint during initial POH. Fluid loss as of 0700-hours usin constant hole fill was limited to re lacement of tubin displacement. Joint #187 UD at 0715-hrs. The chem-injection line clamps now require use of the air chisel to cut the closure pins. Floorhands wearing goggles and face shields while performing this operation. Recover 1-SSSV, 8-ea GLMs, 1-Chemical Injection Mandrel, 223 full joints of 5-1/2" tubing, a 20.74' cut-off joint, 236 Clamps, and 7 SS bands. The cut off was 6-1/2" by 5-1/2" ovoid and had been attached to the stub with a 1-1/2" tag. DECOMP PJSM to remove spooler from rig. Remove Schlumberger Camco spooler. R/D power tongs and move out of rig. Clear and clean Rig Floor. DECOMP P/U and install 8-3/4" Wear Ring. P/U 5-1/2" Dress-off BHA and bring to Rig Floor. Load and strap 6-1/4" DCs in Pipe Shed. Printed: 7/29/2009 3:03:12 PM • ~ BP EXPLORATION : Page 3 of 15 ' Qperations Summary Repart Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Date Fr€~m - To HQUrs Task Code NPT Phase Description of Operations 6/25/2009 12:30 - 14:00 1.50 CLEAN P DECOMP P/U and M/U dress-off BHA: 8-1/2" x 5-1/2" Dress-off Shoe, 10' of washpipe extension, 6" Triple Connection with inner Dress-off Mill, 9-5/8" Scraper, Bumper Sub, Pump-out sub, 6-ea 6-1/4" DCs, and XO to DP. 14:00 - 21:00 7.00 CLEAN P DECOMP RIH Dress-off BHA on DP from Pi e Shed. DP joint #45 RIH at 1515-hours. #75 RIH C~ 1550-hrs. #106 RIH C~ 1645-hrs. Not experiencing an fluid loss or gain to or from formation as of 1645-hrs. #150 RIH at 1750-hrs. #195 RIH at 1900-hrs. #225 RIH at 1945-hrs. #255 RIH at 2035-hrs. #280 RIH at 2100-hrs. 21:00 - 22:00 I 1.001 CLEAN I P 22:00 - 23:00 I 1.00 I CLEAN I P DECOMP Make up to the topdrive and establish parameters of P/U Wt. 175k, S/O Wt. 150k with 40-RPMs with a torque of 4k. Begin pumping at 6-bpm with 650-psi. Slow down the pumps to 2-bpm and continue to run in hole and tag the stub at 9029'. Pick up and begin rotating and start polishing the stub. Continue polishing while slacking off to 9042', where the inner polish mill tagged the stub. Milling with 4k to 7k torque and WOB of 5k. Mill off 1' of the stub leaving it at 9030', Quit rotating and pick up off of the stub and slide over the stub 2 times with no issues, begin rotating and slide over the stub 2 times. DECOMP Pump a 20-bbl hi-vis sweep, followed by a surface to surface circulation (661-bbls) at 12-bpm with 2500-psi. Saw returns of a small amount of what looked to be paraffin. Worked the scraper from 9029' to 8930' while circulating. Have not 23:00 - 23:30 0.50 CLEAN P DECOMP Monitor the well. Static. Pump a dry job and blow down the top drive. 23:30 - 00:00 0.50 CLEAN P DECOMP Begin pulling out of the hole from 9012' to 8663'. 6/26/2009 00:00 - 02:00 2.00 CLEAN P DECOMP Continue to pull out of the hole from 8663' to 226' racking back the drillpipe. 02:00 - 03:00 1.00 CLEAN P DECOMP Stand back the drill collars and break out and laydown the dress off assembly. Recovered 1/2-gal of inetal shavings and 1 stainless steel band in the boot basket. 03:00 - 03:30 0.50 CLEAN P DECOMP Clear and clean the rig floor and prepare to pick up the 9-5/8" RTTS. 03:30 - 08:30 5.00 EVAL P TIE61 Pick up 9-5/8" RTTS and run in the hole on 4" drillpipe. 08:30 - 10:30 2.00 EVAL P TIEB1 Set RTTS at 8983'-COE and PT from below to 4000-psi for Call Sr RWO engineer and agree to POH one stand to retest. Re-set RlTS at 8887'-COE. See the same leak-off. Break off circulating line, unseat RTTS and prepare to POH. 10:30 - 13:00 2.50 EVAL P TIEB1 POH to re-set RTTS at 3990'. 13:00 - 16:30 3.50 EVAL P TIEB1 Set RTTS and test the IA. Test leaks off 300- si ' - in t. Pressure up again to 4100-psi and leaks off to 3600-psi in 20-minutes. Trv aqain and find leakina Casina Head LDSs. Call FMC to service LDSs. Service all LDSs and resume testinq. See same leak-off results. Call RWO Engineer and discuss the option of connecting a pressure gage to the 9-5/8" lower Packoff void and also arranging for another RTTS. Connect Printed: 7/29/2009 3:03:12 PM ~ ~ BP EXPLQRATION Page 4 of 15 Qperations Summary R~port Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Date Fram - To Hou~~ Task Code NPT Phase Description of t~perations 6/26/2009 13:00 - 16:30 3.50 EVAL P TIEB1 gage and start pressurinq up on IA and pape sees ~ressure, immediately with a max of 2000-psi when IA reaches 3500-asi. Stop testing, call RWO engineer and decide to POH, S/B DP in Derrick, L/D RTTS, then continue with RWO program to RIH 7" Scab Liner. 16:30 - 19:00 2.50 EVAL P TIEB1 Unseat RTTS and POH from 3990' and laydown the RTTS. 19:00 - 19:30 0.50 CASE P TIEB1 Pick up 3 drill collars to be used on the next run and rack them back. 19:30 - 20:30 1.00 CASE P TIEB1 Finish strapping and tallying the 7" jewelry and remaining jts. 20:30 - 21:00 0.50 CASE P TIEB1 PJSM and rig up to run the 7" scab liner. 21:00 - 00:00 3.00 CASE P TIE61 Pick up the overshot and Bakerlok all connections up to the landing collar. Fill the casing and pick up 50' to check the floats. (Floats Held) Run in the hole with 7" 26# L-80 BTC-M to 577'. Average make-up torque of 8k-ft/Ibs.on 7" casing. 6/27/2009 00:00 - 02:30 2.50 CASE P TIEB1 Continue in the hole with 7" 26# L-80 BTC-M casing from 577' to 2715.10' (Jt. 62). 02:30 - 03:00 0.50 CASE P TIE61 Shut down to fix a hydraulic cylinder on the pipe handler. 03:00 - 09:30 6.50 CASE P TIEB1 Continue running in the hole with 7" 26# L-80 BTC-M casing from 2715.10'. #62 at 0320-hrs, #87 at 0420-hrs, #104 at 0520-hrs, #120 at 0640-hrs, Liner Hanger and Liner 7op Packer assembly at 0815-hrs. M/U XO on top of hanger running tool DP pup joint to 6-1/4" DCs and RIH with 3-stands of 6-1/4" DCs. 09:30 - 10:30 1.00 CASE P TIEB1 Circulate a liner volume, 230-Bbls, to ensure liner is clean; 5-1/2-BPM at 340-psi. Returning fluid is 65-F. Increase steam heating to Pits. 10:30 - 12:00 1.50 CASE P TIEB1 Continue RIH with 7" Scab Liner on DP from Derrick. 12:00 - 12:30 0.50 CASE P TIEB1 Get Parameters: 235K-Ibs up weight and 205K-Ibs down weight. P/U stand #29 and RIH to taa and see stub at 9030'. See first set of pins shear with 10K-Ibs 4' in from dress-off de th of to of stub then second set shears with 10K-Ibs weight at 12.7' in and see No-Go at 15' in• for a total of 36' in on stand #29. POH and S/B stand #29 and P/U 5' DP pup joint and a single joint of DP. RIH and park DP 4-5' above Rig Floor to P/U and M/U the Baker Cementing Head assembly. 12:30 - 13:30 1.00 CASE P TIE61 PJSM with crew, Baker Completions tech, Schlumberger crew leader, MI Engineer, Toolpusher and WSL to P/U and M/U the Baker Cementing Head assembly. P/U and M/U Baker Cementing Head assembly to DP, H/U to TopDrive and circulate heated 9.8-ppg Brine to clean out Scab Liner and 9-5/8" x 7" annulus. Pump rate 6-BPM at 650-psi, returning fluid temperature 60F. 13:30 - 14:00 0.50 CEMT P TIE61 PJSM to pump cement with 6 Schlumberger personnel, 4 Vac truck drivers, Baker Completions Tech, MI Engineer, Doyon 16 Rig crew, Toolpusher, and WSL. WSL requested all personnel to contribute their Safety concerns at the very beginning of the meeting. The Schlumberger crew leader said later that Doyon 16 conducts the best PJSMs for cementing that he attends on the Slope. 14:00 - 17:30 3.50 CEMT P TIEB1 Make final Schlumberger hookup and test lines to 5000-psi. Pop-off for Schlumberger pump truck set at 5000-psi. Start Schlumberger pumping at 1420-hours. Pump 5-Bbls of water to PT lines to 5000-psi and check for stalls. Pumping 15.8-ppg Printed: 7/29/2009 3:03:12 PM ~ ~ BP EXPLQRl~TION Page 5 ofi 15 Qperatio:ns Summary R~port Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Date From - T~ Hours Task Code NPT Phase ' Description caf Operati~ns 6/27/2009 14:00 - 17:30 3.50 CEMT P TIE61 Class G cement (1.16 cu fUsk yield) downhole at 1420-hrs at 5-BPM with 730-psi. At 50-Bbls away, pumping at 5-BPM with 720-psi. At 100-Bbls away, pumping at 5-BPM and 700-psi. At 150-Bbis away pumping 5 BPM at 728-psi, 183-Bbis away (full 'ob . Sto um in and dro dart; chase with 5-Bbis freshwater from Schlumberger; see the flag drop on the flag sub. Bring rig pump on at 7-BPM at 327-psi and catch plug with 97-Bbls displacement pumped. Slow pumps to 5-BPM at 560-psi, then to 4-BPM at 2300-psi, then worked up to 2650-psi and slowed to 3-BPM at 2200-psi, then to 2-BPM at 2440-psi. Bump plug at 2452-strokes with 3200-psi. Slack off to 75k-Ibs on wt indicator, bled off pressure to 0-psi, swap pumps to get to the higher discharge pressure pump. Pressure uo to 4500-psi and obseroed the Liner Han er set at 4200- si. Then bled off to check the float and no flow. CIP at 1615-hrs. lined up to pump through the Top Drive, right hand rotation to release the running tool. Pressured up to 700-psi, P/U and saw pressure bleed off and started pumping 11-BPM, 1200-psi to circulate cement out of wellbore. Recovered 16-Bbls of cement in cuttin s tank. 17:30 - 18:30 1.00 CEMT P TIEB1 Stand back a 1 stand of drillpipe, break down cement and blow down the top drive. 18:30 - 19:30 1.00 CEMT P TIEB1 Pull out of the hole from 2800' to surface. Service break and lay down the running tool. 19:30 - 20:00 0.50 CEMT P TIEB1 Flush the stack with a 20-bbl citric acid pill. 20:00 - 20:30 0.50 CEMT P TIE61 Clean the rig floor and break down the crossover on the 10' pup joint. 20:30 - 22:30 2.00 EVAL N DECOMP Wait on Schlumberqer to run USIT Log on the 9-5/8" to find the to of cement. 22:30 - 00:00 1.50 EVAL P DECOMP Rig up Schlumberger E-line and begin to run the USIT log. 6/28/2009 00:00 - 03:30 3.50 EVAL P DECOMP Continue logging from 2800' to surface. Top of cement located at 2020'. Rig down E-line tools, then clear and clean the rig floor. 03:30 - 06:30 3.00 PULL P DECOMP Make up 9-5/8" RBP, run in the hole and set at 2060'. 100' below planned cut depth. 05:30 - 06:30 1.00 DHB DECOMP RBP won't set at 2060' ; try again 6-times and won't set; move down to attempt to set and doesn't appear to have set. P/U and lose 15K-Ibs on string. Suspect that strinq has backed off durin last attem t to set RBP. Slowly lower, stack out right away; P/U to slowly rotate into string and M/U to DP. P/U and gain back the 15K-Ibs. Decide to POH and re-torque all ' I connections. 06:30 - 08:00 1.50 PULL P DECOMP POH, re-torque all connections and S/B DP in Derrick. Find that stand #13 had backed out. Continue POH and re-torque all connections and S/B DP in Derrick. Inspect RBP and find no reason to lav it down. Stand #13 was being RIH when the Driller handed over control to the Motorman in order to eat breakfast. 08:00 - 10:00 2.00 PULL P DECOMP RIH with RBP to set at 2090'. 10:00 - 12:30 2.50 DHB P DECOMP Set RBP at 2090' overpulled 40,000-Ibs. Release fr.om-R~P, POH 1-stand and test to 1000-psi for 10-minutes, recorded, for 'u -ti ht test. Install Sand Ho er on to of DP and dum 42-sacks~,2100-Ibs) of 20-40 river sand on top of RBP, Elapsed Printed: 7/29/2009 3:03:12 PM • ~ uh+~~ ua~va ~ Legal Well Name: 01-25 Common Well Name: 01-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 ~ ~ R ~ ~ 6/28/2009 I 10:00 - 12:30 I 2.50I DHB I P 12:30 - 14:30 2.00 PULL P 14:30 - 15:30 1.00 PULL P 15:30 - 16:30 1.00 FISH P 16:30 - 19:00 I 2.50I FISH I P 19:00 - 21:00 I 2.001 FISH I P 21:00 - 00:00 I 3.001 FISH I P 6/29/2009 I 00:00 - 01:30 I 1.501 FISH I P 01:30 - 03:00 1.50 FISH P 03:00 - 03:30 0.50 FISH P 03:30 - 10:00 6.50 WHSUR P 10:00 - 10:30 I 0.50I PULL I P LORATION Page G of 15 ummary Report Spud Date: 2/9/1983 Start: 6/17/2009 End: 7/6/2009 Rig Release: 7/6/2009 Rig Number: Phase De$eription of fjperations DECOMP time to dump 42-sacks was 15-minutes using the recently modified sand hopper. 1100-hours, M/U DP to Top Drive and circulate sand out of DP, 1-BPM 110-psi. RIH to tag sand, and sand is still in solution in the IA. POH 1-stand and wait for sand to settle. See note in Remarks section. DECOMP Pump dry job, but sand had gone around the end of DP when circulated out the DP. Dry job didn't stop flow. Wait until sand settles out. Check DP several times. DECOMP POH using rig tongs to break out DP connections while repairs being performed on Iron Roughneck. DECOMP PJSM to M/U Baker Multi-string Cutter to RIH and cut 9-5/8" Casing. M/U Multi-string Cutter BHA: 8-1/4" Mulii-string cutter and 8-1 2" ta ilizer. DECOMP RIH Baker Multi-string Cutter on DP from Derrick. One stand from est. cut depth obtain the parameters of Up wt. 66k, Down wt. 70k, Rot. Wt. C~3 40-rpm with 1.5k free torque. Engage the pumps at 3-bpm with 150-psi to locate the collar. Coliar located at 1949'. Run in the hole 10' to 1959' and beqin cuttinq the casin at 7-b m with 800-psi. Torque while cutting at 3-6k. Casing cut at 1959'. Circulate out to the flow back tank with the bag closed. Took 450-psi to break circulation between the 13-3/8" and 9 5/8" casin . DECOMP Rig up and pressure test LRS to 3500-psi. Shut the OA and pump 20-bbls of diesel at 1-bpm with 50-psi down the drill pipe while taking 20-bbls of 9.8-ppg brine returns back to the pits. Shut the annulus and pump an additional 30-bbls of diesel at 1.6-bpm with 820-psi followed by 20-bbls of hot brine (100-deg) at 2-bpm with 600-psi. Shut in the well and allow the diesel to soak for 1 hour. DECOMP Displace diesel at 2-bpm with 440-psi until the diesel is seen at the rental tank then increase the pump rate to 8-bpm with 3000-psi. Pump a 40-bbls Safe-Surf-O pill and chase out of the hole at 8-bpm with 2940-psi. Displace the IA C~3 8-bpm with 1170-psi. Pumped a total of 370-bbls of brine. Received 25-bbl of OBM from the 13-3/8" x 9-5/8" to surface. DECOMP Finish displacing the IA until we had 8.45-ppg in and 8.45-ppg out. Monitor the well for 10 minutes. Static. Broke off connection and still running over drill pipe. Circulate 1 drill pipe volume (23-bbis) at 7-bpm with 850-psi. Pump dry job and monitor well for 10 minutes, Static. DECOMP Pull out of the hole with the 9-5/8" casinq cutter BHA racking back the drill pipe. DECOMP Clear and clean the rig floor. Flush and drain the BOP stack. DECOMP Chan e out the VBRs from 3-1/2" x 6" to 2-7/8" x 5". Nipple down the Tubing Spool to Casing Spool flanges below the BOP stack and remove the packoff. Upper packoff sticking on top of casing; lower BOP stack and RILDS; P/U on stack and pull packoff free. lower packoff is determined by FMC to be too large to pull through the BOP stack. Use jacking plate to pull top ring and the packoff came. This Casing Spool also has Emergency Slips in the bottom of the Bowl. DECOMP RIH with Baker 9-5/8" s ear with bullnose and ackoff and enqaqe in 9-5/8" Casing. Pull to 115K-Ibs and Casing pulls free Printed: 7/29/2009 3:03:12 PM • • Qperati Legal Well Name: 01-25 Common Well Name: 01-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 ~, 6/29/2009 10:00 - 10:30 0.50 PULL P 10:30 - 13:00 2.50 WHSUR P 13:00 - 17:30 4.50 PULL P 17:30 - 19:30 2.00 BOPSU P 19:30 - 00:00 ~ 4.50 ~ CLEAN ~ P 6/30/2009 00:00 - 01:00 1.00 CLEAN P 01:00 - 03:30 2.50 CLEAN P 03:30 - 09:00 I 5.501 CASE I P 09:00 - 09:45 ~ 0.75 ~ CASE ~ P 09:45 - 13:00 I 3.251 CASE I P 13:00 - 14:00 ~ 1.00 ~ CASE ~ P 14:00 - 14:30 I 0.501 CASE I P aaaTioN ~mmary Report Spud Date: 2/9/1983 Start: 6/17/2009 End: 7/6/2009 Rig Release: 7/6/2009 Rig Number: Phase : ' Deseription caf Operations DECOMP from spool; continue POH with 123K-Ibs until 9-5/8" Collar moves Emergency Slips out of spool. FMC release and remove Emergency Slips. DECOMP Set BOP and Tubin Spool down on Casinq Spoo! and N/U with new studs. Install BOP stack turnbuckles, inflate airboots. DECOMP POH and UD 9-5/8" Casin . Joint #10 POH at 1430-hours. Average breakout torque -35K-Ib-ft. Joint #20 UD at 1510-hrs. Joint #40 POH UD at 1630-hours. L/D 10.64' cut-off at 1700-hours. The cut-off had a 10" diameter flare. DECOMP Test the 2-7/8" x 5" VBRs, the break on the wellhead, and the ram door sea s to 2 0-psi ow an 4000-psi high. All tests were charted for 5 minutes and were good tests. Lay down testing equipment and install the wear ring. Clear and clean the rig floor and prepare to run in the hole with the dress off assembly. DECOMP RIH with 9-5/8" dress-off BHA: 12-1/8" x 9-5/8" Shoe, 11-3/4" Washpipe extension, 9-5/8" Inner Dress-off Mill, 11-3/4" Washover Boot Basket, 13-3/8" Scraper, Float Sub, 6-1/4" Bumper Sub, Pump-out sub, and 9-ea 6-1/4" DCs. Establish parameters of Up wt. 85k, Down wt. 87k, Rot wt. 85k at 40-rpm with 2k torque, pumping at 6-bpm with 90-psi. Tag stub at 1959' and mill at 60-rpms with torque of 4-5k. Pick up off of the stub and rotate on and off of the stub 3 times. Then stop rotation and slide over the stub 2 times. Left stub at 1960'. DECOMP Pump a 40-bbl Safe-Surf-O pill followed by a 20-bbl Hi-vis sweep. Didn't see much of a difference in the returns. DECOMP Pull out of the hole racking back the drill pipe and drill collars. Lay down the milling/scraper BHA. Boot basket had 1/2-gal. of cuttings in it. TIEB2 Clean the rig and prepare to run the 9-5/8" casing. Bring 13-3/8" hydraulic tongs to Rig Floor. Set up Doyon Casing Torque Turn equipment. TIEB2 PJSM with Baker Completions and Fishing techs, Halliburton techs, Doyon Casing techs, Rig Crew, Toolpusher, and WSL to IH with 9- /8" Tieback Liner. Major Safety concerns: congested rig floor, installing lifting nubbins on Hydril 523 casing, looking up to watch lifting nubbin while in elevators to ensure it is not backing out while during joint make-up, controlling hydraulic tongs, and staying clear of backup tong snub line. TIE62 P/U the Baker Casin Patch and ECP assembl and RIH. P/U Halliburton ES-Cementer assembly and Bakerlok it to the Casing Patch assembly and M/U to 10,020-Ib-ft. P/U joint #1 of 9-5/8" 47# L-80 H dril 523 casin and M/U to ES-Cementer assembly with 19,000-Ib-ft torque. Continue M/U Hydril 523 casing with 19,000-Ib-ft optimum torque using Jet Lube Seal Guard pipe dope on all connections. Joint #12 RIH at 1100-hours. Joint #30 RIH at 1230-hrs. Joint #37 RIH at 1300-hrs. TIE62 Toolpusher and WSL welcome and escort visitors from BP and Halliburton for a tour of the rig while casing running operations were temporarily ceased. TIEB2 Find small drip leak on BOP stack that is coming from 2 LDS Printed: 7/29/2009 3:03:12 PM • ~ BP EXPL~RAT[~N Page 8~f 15! Operations Summary Report '~ Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Ta$k Code NPT Phase ' D~scription of Operations 6/30/2009 14:00 - 14:30 0.50 CASE P TIEB2 on the Dutch Riser. Drain the stack, remove and replace Dutch Riser LDS O-rings. 14:30 - 16:30 2.00 CASE P TIEB2 Resume RIH with 9-5/8", 47#, L-80, Hydril 523 Casing. Joint #40 RIH at 1500-hours. 1540-hours P/U and M/U 5.11' Hyd 563 pup joint. 1545-hrs P/U and M/U full joint of Hyd 563. P/U wt 125K-Ibs, S/O wt 125K-Ibs. 1600-hrs P/U M/U XO pup: 9-5/8", 47#, BTC box x Hydril 563 pin. lowl lower over stub and lose wei ht. P/U and rotate, 2-3-RPM while slowly RIH and see casing patch go over stub, stop rotating and see slips and seals slip over stub. Set down 55K-Ibs then pull to 250K-Ibs and relax to 100K-Ibs over strino wei ht or 225K-Ibs and set sli s. 16:30 - 17:00 0.50 CASE P TIEB2 PJSM. R/U Halliburton Cementing Head at 5' above rig floor. 17:00 - 17:45 0.75 CASE P TIEB2 PJSM. PT 9-5/8" casinq to 1000-psi and record for 10-minutes; 'u ti ht. Increase ressure to 1400- si and let stabilize, then to 1600-psi and the ECP inflation valve opens. Continue to 2000-psi to close the valve and to test the casinq to 2000-psi for'u ti ht test. Bleed off ressure to 0- si, then increase to 3000- si at 2-BP and ES-Cementer shears o en at 3280- si. Called AOGCC with a weekly BOP test update for 2200-2400-hours tonight. Lou Grimaldi, NS AOGCC inspector returned the call immediately and waived State's right to witness the BOP test. 17:45 - 18:30 0.75 CASE P TIE62 Circulate hot seawater to warm up wellbore. 105F degrees from Pits. -Conduct Cementing PJSM With Schlumberger Cement Crew, CH2MHill Truck Divers, Doyon Rig Crew and BP WSL -Final return Seawater temp before cementing 81 F degrees 18:30 - 20:00 1.50 CEMT P TIEB2 Pump Primary cement job for 9 5/8" casing patch -Schlumberger Cementing pumped 5-Bbls of freshwater before pressure testing lines. -Pressure Test lines to 4,500-psi. Good Test -Pum 137-Bbls of 15.8- Class G cement with GasBlok. -Drop ES-Cementer closing plug. -Chase plug out with 5-Bbls. Positive indication plug left cement head. -Switch over to Rig Pump. -Displace with 140-Bbls of seawater (1600 strokes) with rig pumps at 5 BPM -Reduced rate to 2-BPM when within 15-Bbls of landing -Bumq pluq and pressure uq to close the ES Cementer, -CIP ~ 20:00 hrs 6/30/2009. -Pressure Up to 1700-psi on Closing plug and Hold for 15-mins. Good Test. -Bleed off. No flow up the 9-5/8" casing. -20 Barrels of cement back to surface. 20:00 - 20:30 0.50 CEMT P TIEB2 Flush Surface equipment and rig down casing and cementing equipment 20:30 - 21:30 1.00 BOPSU P TIEB2 Nipple Down Stack and raise to install emergency slips -Install Slips without issues Printed: 7/29/2009 3:03:12 PM ~ ~ E Operat. Legal Well Name: 01-25 Common Well Name: 01-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 i , i i ~ t Start: 6/17/2009 Rig Release: 7/6/2009 Rig Number: ' 6/30/2009 20:30 - 21:30 1.00 BOPSU P TIEB2 21:30 - 23:00 1.50 WHSUR P TIE62 23:00 - 00:00 1.00 WHSUR P TIE62 7/1/2009 00:00 - 00:30 0.50 WHSUR P TIEB1 00:30 - 02:30 2.00 BOPSU P TIEB1 02:30 - 04:00 1.50 BOPSU P TIEB1 04:00 - 11:00 7.00 BOPSU P TIEB1 11:00 - 16:00 ~ 5.00~ BOPSUF~N ~DPRB ~TIEB1 16:00 - 17:30 I 1.501 BOPSUFIP I ITIEBI 17:30 - 18:00 0.50 WHSUR P TIEB1 18:00 - 18:30 0.50 CLEAN P CLEAN 18:30 - 19:30 1.00 CLEAN P CLEAN 19:30 - 21:00 1.50 CLEAN P CLEAN 21:00 - 21:30 0.50 CLEAN P CLEAN 21:30 - 22:30 1.00 CLEAN P CLEAN 22:30 - 23:00 0.50 CLEAN P CLEAN Spud Date: 2/9/1983 End: 7/6/2009 uescription or ~peranons -Landed Casing with 100,000 Lbs Set up Wach's casing cutter and cut 9 5/8" casing -Laid Down cut joint, length= 25.23' Make up Pack-Off running tool and Run 9 5/8" Pack-off , -Run in lock down screws and torque to 450 Wlbs , Install new 9 5/8 Pack-Off -Pressure Test Pack Off to 3800-psi for 30-mins, Good Test. Nipple BOP's -install Turnbuckles and Risers Flush BOP Stack -PJSM on testing BOP's Test BOPE. -Test to 250-psi low and 4000-psi high (3500 psi on annular) for 5 minutes. -Chart Record Test -Test VBRs with 4 1/2" and 2-7/8" test jts. Test annular using 2-7/8" test joint. -AOGCC rep Lou Grimaldi waived witness of BOP test at 1800 hrs on 6/30/2009. -Test witnessed by BP WSLs (Dave Newlon & Mike Rooney) and Doyon Tool/Tourpushers (Glenn Hermann & David Evans). The Hvdril baq will have to be replaced. PJSM to remove and replace Hydril bag, which entails removing the Drilling Riser, breaking out the Hydril cap and removing it with the Potato Masher to get at the Hydril element. The element showed no wear on the inside, but the sealing area on the back side was significantly worn with chunks of rubber torn out of it. Insert new Hydril element, reassemble Hydril cap to body using the Potato Masher. N/U drilling riser and inflate airboots. Resume BOP Testing. P/U 2-7/8" test joint and RIH to test bag to 250-psi low and 3500-psi high. Good Test -Perform Accumulator test -Rig Down Test equipment and Clear Floor Make up running tool and set 8 1/2" Wear Bushing Make up 9 5/8" Cleanout assemblv , -8 1/2" used bit 2 x Boot Baskets, Bit Sub, Bumper Sub, Circ. Sub,XO, 9 x SDC's, XO RIH to 1909' Break circulation and establish parameters -PUW 85k / SOW 80k / RtWt 80k -80 rpm / 2k ft-Ibs of torque off / 5k ft-Ibs of torque on -6-BPM / 220 psi -Taq Cement ~ 1916' and cleanout to 1919' md -Drilled cement, plug and cementer out with 5-10k WOB -Wash and Ream to 2039', Tag top, of sand -Dry Drill on top of sand to 2040' Pump High Vis Sweep -Sand and some rubber returned with sweep Monitor well, static 8.4 ppg seawater In / Out POH Lay Down Bit and Cleanout Boot Baskets Printed: 7/29/2009 3:03:12 PM ~ • BP EXPLQRaTION Page 1 Q of 15 : Qperations Summary Report Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Date From - TQ Hours Task Code NPT Phase Description of Operations 7/1/2009 22:30 - 23:00 0.50 CLEAN P CLEAN -Apx. 5 Ibs of rubber , aluminum debris 23:00 - 23:30 0.50 CLEAN P CLEAN Make up RCJB and Boot Baskets 23:30 - 00:00 0.50 CLEAN P CLEAN RIH 7/2/2009 00:00 - 00:30 0.50 CLEAN P CLEAN RIH to 2026 ' md 00:30 - 01:30 1.00 CLEAN P CLEAN Service Rig -Slip and Cut drilling line -Service Top Drive, Draw Works and Crown 01:30 - 02:30 1.00 CLEAN P CLEAN Break Circulation and Wash Down to Top of Sand -Take SPR's -PUW 87k / SOW 85k / RtWt 87k -40 rpm / 2k ft-Ibs of torque -6-BPM / 470 psi Wash from 2026 to 2037', tag top of sand -Drop ball and cleanout from 2037 - 2041' md -10-BPM / 1200 psi 40 rpm / 5-8k ft-Ibs of torque -5-10k WOB 02:30 - 03:00 0.50 CLEAN P CLEAN Circ at 10-BPM / 1200 psi -Sand and some small pieces of rubber on bottoms up Monitor Well, static 8.4 ppg seawater In / Out 03:00 - 04:00 1.00 CLEAN P CLEAN POH to surface, setting back DC's 04:00 - 05:00 1.00 CLEAN P CLEAN Cleanout RCJB and make back up -Cleanout 1 gal of Metal Shaving, 6- 2-3" Aluminum chunks and 10" rubber piece 05:00 - 05:30 0.50 CLEAN P CLEAN RIH to 2026' 05:30 - 06:30 1.00 CLEAN P CLEAN Break Circulation and Wash Down to To of Sand Wash from 2026' - 2041', tag top of sand Cleanout from 2041' to 2057' -10-BPM / 1200 psi 40 rpm / 5-8k ft-Ibs of torque -5-10k WOB 06:30 - 07:00 0.50 CLEAN P CLEAN Circulate HiVis sweep, 10-BPM at 1380-psi. 07:00 - 08:30 1.50 CLEAN P CLEAN POH and S/B DP and DCs in Derrick. Empty RCJB and get one small piece of aluminum. Decide to make another RCJB run. 08:30 - 09:00 0.50 CLEAN P CLEAN Close Blinds and PT 9-5/8" casing down to the RBP at 2090' for 10-minutes recorded for jug tight test. Will test entire casing down to 7" Shoe Tract after POH with the RBP, 09:00 - 10:30 1.50 CLEAN P CLEAN Discover drip leak coming out of Blinds Door. Re-torque bolts on door. Also find Koomey pump continuing to run. Troubleshoot the Kill HCR valve, but find 4-way valve on Koomey had not fully actuated to the open position. 10:30 - 11:00 0.50 CLEAN P CLEAN RIH with RCJB to 2022', obtain parameters: P/U wt 87K-Ibs, S/O uvt 89K-Ibs, Rot wt 89K-Ibs, 6-BPM at 490-psi. Stop rotating, RIH and tag sand at 2062'. Start pumps and washr down to 2080' with 10-BPM at 1420-psi. 11:00 - 12:00 1.00 CLEAN P CLEAN Circulate Bottoms Up, 10-BPM at 1420-psi. Make crew change. 12:00 - 13:30 1.50 CLEAN P CLEAN POH and S/B DP and UD DCs. Empty RCJB and it is "empty"...nothing inside 13:30 - 14:00 0.50 CLEAN P CLEAN Clear and clean Rig Floor. 14:00 - 16:00 2.00 ZONISO P CLEAN RIH to unseat and POH with RBP. While slowly RIH above top of 9-5/8" stub, tag something at 1940' and tag stub at 1960'. P/U and rotate and tool slides through. Perform same operation Printed: 7/29/2009 3:03:12 PM • • BP EXPLORATION; Pag~ 11 ~f ~5: Operations Sumrnary R~por~ Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: ' Date From - To Ht~urs Task Code NPT Phase Description caf t'~peratic~ns 7/2/2009 14:00 - 16:00 2.00 ZONISO P CLEAN twice more to verify and see same obstruction. Decide to 16:00 - 17:30 1.50 ZONISO P 17:30 - 19:00 1.50 ZONISO P 19:00 - 19:30 0.50 CLEAN P 19:30 - 20:30 1.00 CLEAN P 20:30 - 23:00 2.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P 7/3/2009 100:00 - 03:00 I 3.001 CLEAN I P 03:00 - 03:30 0.50 CLEAN P 03:30 - 05:00 1.50 CLEAN P 05:00 - 08:30 ~ 3.50 ~ CLEAN ~ P 08:30 - 09:30 1.00 CLEAN P 09:30 - 11:00 1.50 CLEAN P continue to -2080' and Hoover off the top of the RBP then latch into it and unseat it. Latch on and attempt to unseat, but it won't. Set back down to 30K-Ibs and P/U; repeat twice and won't unseat P/U and suddenlv moves about 3'.,Halliburton tech calls office to qet permission to go to 35K-Ibs down. Set down 35K-Ibs then P/U and RBP comes free. CLEAN POH with RBP, S/B DP in Derrick. There were no signs of any damage to the RBP. Break-off and UD RBP and running tool. CLEAN Close Blind Rams and Test Casin to 4000 s+ for 30 minutes -Tested 9 5/8" casing and 7" scab liner to LC and plug at 8875' md -Tested Chart recorded -Good Test, drop 35 psi first 15 minutes and 10 psi the second minutes CLEAN Clear and clean Rig Floor. CLEAN Make U 7" Clean out BHA -6 1/8" Bit, &" Csg. Scraper, 2 x Boot baskets, Bit Sub, Bumper Sub, Circ. sub, XO, 9 x SDC's CLEAN RIH from 303' to 8836' md CLEAN Break Circulation and establish parameters -PUW 180k / SOW 142k / RtWt 162k -60 rpms / 5k ft-Ibs of torque -8-BPM / 1450 psi Wash down to 8886' md and tag cement stringers, Drill out Cement to Wioer Pluq at 8911' md Drilll on plug with 80 rpm / 8k ft-Ibs of torque and 10-15k WOB CLEAN Drilll on plug Landing Collar, Cement and Float Collar 8911 - 8935' md -80 rpm / 8k ft-Ibs of torque and -10-15k WOB -8-BPM / 1570 psi -PUW 180k / SOW 142k / RtWt 162k Once we drilled throuqh landinq collar we reamed out several CLEAN ~ Pump High Vis sweep -9.6-BPM / 2700 psi CLEAN Drill firm cement 8935 - 8997' (tag depth for 7" x 5-1/2" ported ~b crossoverl -80 rpm / 8k ft-Ibs of torque and -10-15k WOB -8-BPM / 1570 psi -PUW 180k / SOW 142k / RtWt 162k CLEAN Pump High Vis sweep at 9.6-BPM / 2700 psi. Call RWO engineer to discuss plan forward and decide to swap out to clean seawater in order to get sufficient rate while the 6-1/8" bit is still in the hole, hovering above the 7" x 5-1/2" crossover at 8997'. Call for 3-loads of seawater and a dirty vac to perform the operation. CLEAN Take on seawater to Pits and transfer old seawater to cuttings tank. CLEAN PJSM. Displace wellbore to clean seawater, 10-BPM, 2675-psi. Printed: 7/29/2009 3:03:12 PM i • BP EXPLQRATEON Page 12 c~f ~5 Qperations Summary Report Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Date From - To Haurs Task Code NPT Phase Description of Operations 7/3/2009 09:30 - 11:00 1.50 CLEAN P CLEAN 11:00 - 15:00 4.00 CLEAN P CLEAN POH and S/B DP in Derrick. Work scraper from 8990' to 8895' 3-times. Continue POH. Break out and UD 7" Drill-out BHA. 15:00 - 15:30 0.50 CLEAN P CLEAN Clear and clean Rig Floor. 15:30 - 17:00 1.50 CLEAN P CLEAN P/U 2-7/8" handlin e ui ment and et read to M/U FasDril Plu MIII-out BHA. 17:00 - 20:00 3.00 CLEAN P CLEAN Make Up FasDril BHA -3.625" Convex Mill,Bit Sub, 6 x 3 1/8" DC's, 23 x 2 7/8" DP, XO, 4 3/4" Bumper Sub, 4 3/4" Oil Jar, Circ. Sub, XO, 9 x 4 3/4" DC's Break Circulation at 3 bpm to verify BHA is Clear -3 bpm = 880 psi 20:00 - 22:30 2.50 CLEAN P CLEAN RIH to 8960' md 22:30 - 00:00 1.50 CLEAN P CLEAN Break Circulation and Establish Prameters -4 BPM / 1700 psi -50 rpm / 6k ft-Ibs of torque -PUW = 187k / SOW= 140k / RtWt= 182k Take SPR's 7/4/2009 00:00 - 01:30 1.50 CLEAN P CLEAN Clean out to FasDrill Plugs -RIH wash down to 7" x 5 1/2" XO and tagged up firm with 5k without washing off, ream through crossover and then continue to ream down to 6 feet past 5 1/2" stub to 9036'. Still unable RIH without rotating and taking 5k WOB. Reamed down to top FasDril plug at 9137' md. ' -4 BPM =1530 psi i~ I -60 rpm / 6k ft-Ibs of torque Backream each stand, no issues RIH. 01:30 - 02:30 1.00 CLEAN P CLEAN Mill out Top FasDril Plug at 9137' md, 15 minutes to mill up. -4.2 BPM = 1550 psi -60 RPM / 6k ft-Ibs of torque Mill Bottom Fasdril plug at 8157' md, with same parameters, 15 mi nutes to mill up. No issues after drilling through plug. The well took 2 bbl loss then stabilized at 12 b h. Monitored well with a sli ht loss. 02:30 - 03:15 0.75 CLEAN P CLEAN Run in hole washing and reaming to 9685' md. -4.2 bpm / 1900 psi ', -60 rpm / 6k ft-Ibs of torque Gas entrained returns on bottoms up from drilling bottom I FasDril plug. 03:15 - 03:45 0.50 CLEAN P CLEAN Circulate out gas entrained seawater while monitoring hole -After finishing getting bottoms up the gas ceased. -Monitor well, slight losses 12 bph 03:45 - 04:30 0.75 CLEAN P CLEAN Run in hole washing and reaming to 9855' md. Tapqed sand at 9848'. -4.2 bpm / 1900 psi -60 rpm / 6k ft-Ibs of torque 04:30 - 06:00 1.50 CLEAN P CLEAN Circulate Bottoms Up -5 BPM / 2700 psi. DVnamic loss -9-BPH, Static loss 4-BPH. 06:00 - 15:30 9.50 CLEAN P CLEAN POH and UD DP through Pipe Shed. UD DP joint #50 at 0730-hours. #150 at 0945-hrs. #165 at 1015-hrs. #180 at Printed: 7/29/2009 3:03:12 PM • • _ ----- - - _ BP~~~~~~~ EXPLORi4TI~N ~' Paz~e 13 of 15 ~- Operations Summary Report Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: ' Date Fr4m - To Hours Task Gode NPT Phase ' Description of Operations 7/4/2009 06:00 - 15:30 9.50 CLEAN P CLEAN 1030-hrs. 1230-hrs P/U 4-stands and RIH to POH and continue to UD drill-out string through Pipe Shed. 1330-hours, UD 6-ea 4-3/4" DCs. 1400-hrs, UD Jars and Bumper Sub. 1430-hours, UD 23-jts 2-7/8" PAC DP, 9-jts 3-1/8" PAC DCs. Total Loss = 14 bbls 15:30 - 16:30 1.00 BOPSU P CLEAN Pull Wear Bushing -Clear floor of third parry equipment -PJSM with Rig Crew and Casing Crew on rigging up completion runnning equipment. 16:30 - 18:00 1.50 RUNCO P RUNCMP R/U 4-1/2" Handling Equipment: Single Joint Elevators, Slips, Torque Turn, and Stabbing Guide. -PJSM with Rig Crew, Casing Crew, Baker Production Tech, DDI Toolpusher and BP WSL on running completion 18:00 - 00:00 6.00 RUNCO RUNCMP Make up and Run 4 1/2" L-80 TCII Completion , -Ran completion per Drillers Running Tally -BakerLok connections below packer: -M/U Torque 4-1/2": Optimum = 3,850-Ib-ft; maximum = 4,200-Ib-ft; -Use Jet Lube Seal Guard Pipe Dope 7/5/2009 00:00 - 05:00 5.00 RUNCO P RUNCMP Make up and Run 4 1/2" L-80 TCII Completion -Ran completion per Drillers Running Tally -M/U Torque 4-1/2": Optimum = 3,850-Ib-ft; maximum = 4,200-Ib-ft; -Use Jet Lube Seal Guard Pipe Dope -PUW 145k / SOW 123k with block wt of 37k 05:00 - 08:30 3.50 RUNCO P RUNCMP Taq Crossover 11.5' in on ioint #216 -Laydown Joints # 216,215, & 214 Call ADW engineer and lead RWO engineer and leave messages. Talk to WL and Completions Supervisor and Wells Support Supervisor and agree that the muleshoe should be parked as high as possible above the 7" x 5-1/2" ported XO. Discuss with RWO Superintendent the possibility of making a Slickline Dummy run to verify ability to get wireline tools through the gap between the muleshoe and 7" x 5-1/2" XO. ADW Lead RWO engineer, ADW WL and Completions Supervisor, and the ADW W ireline Coordinator all agree this is a good option. 08:30 - 10:00 1.50 RUNCO RUNCMP Re-calculate spaceout: P/U 2-ea 10' pups and 1 x 8' pup and RIH under full joint #213. P/U and M/U hanger and landing joint. RIH and RILDSs. Install Dutch Riser. 10:00 - 11:00 1.00 RUNCO P RUNCMP Wait on Slickline unit to make slickline tools dummy run. 11:00 - 13:30 2.50 BOPSU P RUNCMP Bring Schlumberger equipment to rig floor. Hold PJSM with Schlumberger crew, rig crew and WSL. Learn that one of the Schlumberger hands had not R/U their equipment on a drilling rig. R/U Schlumberger pressure control equipment and sheaves. M/U lubricator to BOPs and PT lubricator to 650-psi. 13:30 - 14:45 1.25 RUNCO RUNCMP _RIH with slickline to pull RHC-M plug. Latch into RHC-M plug 14:45 - 16:00 125 RUNCO RUNCMP POH with RHC-M plug. Can't get plug past 3300'. Work slickline and finally pull ree. ontinue , rea o u ricator and let tool out bottom and find a chunk of solid aluminum wedged in one of the do s of the GS ulling tool. The only source for this chunk of aluminum would be the wiper plug or Printed: 7/29/2009 3:03:12 PM • ~ BP EXPLORATf~N Page 14 af 15 Qperations ~ummary Report Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Date' From - To Hc~urs Task Code NPT Phase ff Description of Operations 7/5/2009 14:45 - 16:00 1.25 RUNCO P RUNCMP cementer that would have been run with either one of the cemented strings. Likely had been circulated uphole or fell out of a junk basket and landed on a ledge in the BOP stack. 16:00 - 16:30 0.50 RUNCO P RUNCMP RIH with 1-7/8" tool strin OAL 20' with 3-5/8" centralizer and 3.50" LIB on bottom as a gage ring. Did not see the 4-1/2" Muleshoe end either exiting or re-entering the muleshoe which was qarked at -8959'. Saw a slight bobble when the LIB and_ centralizer entered the 7" x 5-1/2"ported crossover but did not see an bobble on thewa out. Saw the 5-1/2" cutoff at 9030', but did not go past that point since there was an LIB that we'll want to check when iYs out of the hole. 16:30 - 17:30 1.00 RUNCO P RUNCMP POH with tool string, break off lubricator and find a small mark on the face of the LIB, but no major or definitive impression. 17:30 - 20:00 2.50 RUNCO RUNCMP M/U re-dressed RHC-M olua and RIH to set in the bottom I 20:00 - 21:30 1.50 21:30 - 22:30 1.00 22:30 - 00:00 1.50 7/6/2009 00:00 - 01:30 1.50 01:30-03:15 1.75 03:15 - 04:00 0.75 04:00 - 06:30 2.50 06:30 - 07:30 07:30 - 10:00 10:00 - 13:00 1.00 WHSUR P 2.50 BOPSU P 3.00 WHSUR P -Set at 8878' slickline measurement -Rig Down Slickline Equipment -Rig Lubricator and Dutch System Riser -Release Slickline Unit RUNCMP Rig Down Slickline Equipment -Rig Lubricator and Dutch System Riser -Release Slickline Unit RUNCMP Rig Up to pump Corrision Inhibited Seawater -PJSM with CH2MHill truck Drivers and DDI Rig crews -Pressure Test Surface Lines to 4000 psi RUNCMP Reverse Circulate -140 barrels of 120 degree seawater -Start pumping 120 degree Corrision Inhibited seawater -3 bpm / 140 psi -Inhibited Seawater with EC1124-A RUNCMP Finishing Pumping Corrosion Inhibited seawater -3 bpm / 140 psi -Inhibited Seawater with EC1124-A PJSM with LRS on pumping Diesel Freeze Protect. RUNCMP Pump 140 barrels of 100 degree Diesel -ICP = 200 psi C~3 1.8 BPM / FCP = 200 psi C~3 1.8 BPM RUNCMP U-Tube Diesel -Drop 1 7/8" Ball and Rod -PJSM on testing tubing and IA RUNCMP Set Packer and Test Tubing and IA -Pressure tested to 4000 psi for 30 minutes -Chart Record Test -Bob Noble waived witness of test ~ 14:30 hrs on 7-3-2009 -Tubing Test lost 60 psi the first 15 minutes and 30 psi the second 15 minutes for a total of 90 psi (2.3%) -Bleed Down tubing to 1500 psi and Pressure up the fA to 4000 psi -IA Test lost 125 psi the first 15 minutes and 75 psi the second minutes for a total loss of 200 si 5% WHDTRE P/U TWC on dry rod and have FMC tech install in hanger. Test from above to -psi. WHDTRE N/D BOP stack and lines. Set BOP on transfer stump in cellar. WHDTRE N/U adaptor flange and test void to 5000-psi, recorded for Printed: 7/29/2009 3:03:12 PM . • ~ BP EXPLQRATiON Page 15 ofi 15 ' Operations Summary R~eport Legal Well Name: 01-25 Common Well Name: 01-25 Spud Date: 2/9/1983 Event Name: WORKOVER Start: 6/17/2009 End: 7/6/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 7/6/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Gode NPT Phase ' aeseription of Qperations 7/6/2009 10:00 - 13:00 3.00 WHSUR P WHDTRE 30-minutes. N/U Tree. 13:00 - 14:00 i.00 WHSUR P WHDTRE Secure Well and Release from DS 01-25 Printed: 7/29/2009 3:03:12 PM 07/14/09 ~chtu~~er~e~ ~llaska ~ata & Consulting Services 2525 Gambell Street, Suite 400 l~nchorage, AK 99503-2838 ~4TTiV: Beih M/ell Job # m.y .,vc~,~~~#~~ ~ ~ ~ ` ; ~~1:`~~ ` ~, .~~w' ~~ ~ • Log Description Date N0. 5310 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnkian 333 West 7th Ave, Suite~ 100 Anchorage, AK 99501 BL Color CD Z-20 AP3~-00043 SBHP SURVEY - O6/17/09 1 1 P2-31 AZCM-00029 LDL L~ ~ 06/17/09 1 1 12-03 AY1M-00022 SBHP SURVEY 06/15/09 1 1 ~-148 AYQQ-00036 TEMP SURVEY & BHP - 06/23/09 1 1 RI-96 AP3Q-00042 SBHP SURVEY ` ~ O6/16/09 1 1 V-QS..,. 11999053 USIT •- 10/12/08 1 1 N-11C , AP3Q-00042 SBHP SURVEY 06/16/09 1 1 "' `Y3=1? AY3J-00030 LDL ._ 06/12/09 1 1 ~1-30 AVYS-00049 PRODUCTION PROFILE -~j b~ pg/2ypg 1 1 17-078 AYQQ-00031 SBHPSURVEY "3 / '~~ 06/11/09 1 1 05-256 AP3Q-00040 SBHP SURVEY - 06l11/09 1 1 B-27A AXBD-00028 MEM INJ PROFILE 06/12/09 1 1 11-36 614B-00066 CROSSFLOW & IBP ~- O6/23/09 1 1 ~-21~4 B14B-00065 SBHP SURVEY ' 06/21/09 1 1 X-17 AYTU-00043 PROD PROFILE -/ 06/08/09 1 1 Z-25 AW18-00018 LDL v~~ ~'~5- 05/28/09 1 1 02-338 AYTU-00033 USIT ` f 05/19/09 1 1 P2-07 AVY5-00051 PRODUCTION PROFILE ~~ s O6/25/09 1 1 13-03 AWL8-00020 LDL 06/01/09 1 1 3-17F/F(-30 B2NJ-00008 MEM INJ PROFIIE ~J 06/15/09 1 1 MPS-08 AYS4-00080 LDL O6/15/09 1 1 13-92 AViH-00019 LDL ( 07/05/09 1 1 01-25 AYTU-00046 USIT -~ ~~ 06/28/09 1 1 lM-39Ba AWL8-00023 STATIC TEMP SURVEY ~ ~ 06/26/09 1 1 ~-35 AYTO-00022 SBHP SURVEY ~ ~ 06/29/09 1 1 Z-96 AV1H-00017 SBHPSURVEY ~ ()~j 06/29/09 1 1 18-20 B581-00004 LDl ~ ,_ ~ 06/27/09 1 1 Z-29 AVY5-00053 SBHP SURVEY ~~~j -~ p~~f ~a3 ~°f`~~ 07/03l09 1 1 L5-09 AYQQ-00032 RST ~ ~ ~- ~ 06/13/09 1 1 07-10A 61JJ-00022 MCNL -- b1 ~ 05/26/09 1 = d~-~r.-.+~.,,.~eo~ .a4..~..~~~~ o~ JIVry11YV NIYN IICI VIIIVIIVIi VIVC IiVF'T CHGI~ ~v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. Alaska Data & Consuiting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ~~ '1 ~ ~,1 a ~chf~ml~er~~r Alaska Daea & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 l~TTN: Beth Mlell Job # . i~ ~tA "~ ~~ " ~~U~ ~ 4~ ~~~~~ ~i } Log Description N0. 5297 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnk~en 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD o~rosios Z-06 AYTO-00035 GLS/PRODUCTION PROFILE ~- OS/12/09 1 1 07-338 B4C4-00003 SCMT -- 05/30/09 1 1 17-14 AVY5-00049 PRODUC ION PRO ILE L/- 05/31/09 1 1 12-01 AYTU-00039 PRODUCTION PROFILE _ OW01/09 1 1 04-43 AXWS-00011 IBP/CROSS FLOW CHECK - ~- O6/02/09 1 1 D-13A B04C-00059 USIT - O6/03/09 1 1 Z-i12 B2WY-00011 MEM PROD PROFILE "'~ - 06/03/09 1 1 06-OS B04C-00061 USIT 06/04/09 1 1 12-18 AV1H-00014 PRODUCTION PROFILE 06/04/09 1 1 A-35 AY3J-00026 USIT a(p ~ 06/0M09 1 1 ~2-aa AXWS-00013 PROD PROF/GlS O6/OS/09 1 1 12-16A AXWS-00014 PRODUCTION PROFILE -~ 06/05/09 1 1 18-298 B04C-00062 PSP XY-CALIPER LOG 06/06/09 1 1 C-12A AXWS-00015 SCMT ,- / 06/06/09 1 1 B-27A AXBD-Q0028 MEM PROD PROFILE 06/11/09 1 1 L2-13A AWJI-00036 MEM CNL & INJ PROFILE ~ 06/17/09 1 1 L2-13A AWJI-00036 MEM PROD PROFILE f 06/17/09 1 1 07-21 6148-00064 LDL 06/20/09 1 1 17-01A AYQQ-00030 SBHP SURVEY 06/11/09 1 1 01-25 AP3Q-00041 LDL O6/15/09 1 1 L-202 B2WY-00010 MEM PROD PROFILE ~- C,/ 06/02/09 1 1 IL-103 AXBD-00027 MEM INJ PROFILE O6/04/09 1 1 GNI-03 AWJI-00034 MEM PRESS & TEMP SURVEY ~'~-.- 06/15/09 1 1 G-31B AWJI-00027 MCNL _03 04/30/09 1 1 15-29BP81 09AKA0143 OH MWD/LWD EDIT _ ~ ~~ 05/11/09 2 1 rLCfiJC N1.1~1VVtlYLCUUC 11C1iC11'I 6T ,IUIVtIVU AIVU Fitl UF(IVIIVIa VIVt l:UY7 tAl:Fl 1 V: BP Expioration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. ` i ~ '~ ~ ~, ~~.. ~_ _ - - - Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2638 01-25 (309-094) ~ Maunder, Thoma~ E (~QA) From: Maunder, Thomas E (DOA) Sent: Thursd~zy, Jt~ne 18, 20€)910:32 AM To: '$aea, Hank' Subject: RE: 0't-25 (182-Z03} - (309-094) ~ ~ . ; ~ ~ ,;r- ~ , . ~a~- ;... , _~ Page 1 of ~~ ~~t~ki '~h~t~~ ~~r yaur "~r~ugl~t" ~~ ~~i/~ i~n~~l~, t~i~~ ~~ k~t~v-% w~ ~r~ ~n ~~ ~~~~ ~~~~. ! l~~~i~t~ ~ ~e~li~ put ~ ~~a~ ~t~~ ~a~, 1 g~~~ ~ . . . ~ ~ ~~ar~ ~~ ~ ~~ai~~ ~~`w~~ ~ti~~ad ~ ~ ~, ~# i~ ~ > ~ ~5~"~ ~~ ~~~ ~~ ~ ~i~ ~~ `~a# ~~ j~~ ~~ ia~~ ~ ~t ~~ ~l~ ~~ ~~a ~~r ~ ~~~~~~ ~-~~~ ~~i~~.. ~~ ~'/~~ x~" ~~n~r~~fy k~t~" mts~t ~itu~tion~, ~~ct~~t wh~r~ it do~~r~'t. T~~t From: Baea, Hank [maittca:ktank.tjacaC~bp,eom} Sent; Thursday, 7une 1$, 2009 10;23 AM To: Maunder, Thomas E (DOA) Suaject: RE: ~1~25 (182-~03) - (3Q9-094) Tl~~ni€~ "~~rr~, w~ h~v~ t~ ~~II ~ 5.~" ~rrrp0~t~~~, ~ut tti~~r~ i~ w~11~~~d w~rk ~~r ~s~t ~v~"!1 r~~~d ~~ tdC~ ~r~d ~ ~fit~r ~~y~va~. ~~ ~h~~~ ~i r~~~c i~»~t~ y~u'~~ ~t°~f~rt~~l~ ~~1(i~~ ~ ~i~~~ ~~~' ~~~m~ i~r~g t~ r~~ t~, ~~t~~ ~~l~i~z~ ~~a~in ` 9Q~7=~~4-~444 ~i~~ 9~7~~4~-{~~~7 ~il FrQm: Maurzder, Thomas E (DQA) [ma~Ito;tom.maunderCa~ataska.gov] Sent: Thursday, )une 18, 2009 10:13 AM To: Bsca, Hank subject: RE: ~1-25 (18z-2U~} - (3o9-t}94) li~r~k, ~~~I~~ x 5" V~~t~ I~lcc~l~ wi~l ccsv~f ~11 t~~ drilf~i~~ ~~d t~bir~~ y~u wilf ~~ runt~i~~. ~~t ~ ~a ~ ~~1~ ~ ~~ ~ . "~'~a ~~i~~~~r, f~~ ~~~~~ ~rom; Baca, Mank [maftto:hank.bacaC~bp.com] Sent: Thursday, June i6, 2t109 1Q;05 AM To; Maunder, Th~mas E (D~A) sua~ect. ~~: Qi-25 (182-2Q3} - (3(?9-Q94) v~6 kriF~ ~~~~ (IF 4/!!~ ~E~6~ 4J~ ~~~6 1GiI~1~ VII ~ftl~ •Y~~1~~~Q~. YY~j'~ ~'611! LII ~9tGF~~~!!~ ~67At1 ~i.l~: Ia~l~'!~C ~~~~~~ ~~~~~~ 9~7~~-~444 e~~fi~ r~"~~ ~ ~ca ~i~ oi~aog O1-25 (309-094) ~~~-~~ Y ~~ _ ~ L~ ~ Page 2 of ~ ~ From; Maunder, Thomas E (DOA) [mailto;tom,maunderQalaska.gov] Sent; Thursday, lune 18, ~~(39 9;39 AM To: Baca, Hank 5ubj~ct: RE: 01-25 (182-203j - (3Q9-094) ~~ ~s ~e~~~ ~C~~ ~~ ~ip~ ~t~~~~~n~ . ~~~ r~~t t~a~ ~ ~' ~11 ~p+~ t ~~~. ~~ ~r~~s ~a# :~-~'~~ ~ ~~ ~p~~~ ~~ "~r~~~ ~r ~ ~~. Tom tVi~und~r, P`~ A~C~~ From; Baea, Ha~k [rrtaitto:hank.kaacaC~bp.cam] Sent: Thursday, June i8, 2009 9:31 AM To: Maunder, Thomas E (DOA) Subject: RE; Q1-25 (182-2Q3) - (3f19-Q94} '~~~, f~~p~~c~fly t~-~ I~~t ~u~~ti~t~ ~n fhi~ w~ll: W~ r~~~d ti~ pi~k u~ ~bdut ~00' ~s~ ~~~`l~ driil ~i~~ ~ d~ill up a~u~ ~ ~~sm~~~i~ b~i~g~ pfu~~ ~nd ~h~~~ ~h~rr~ ~ ~~`~C~. IS~s w~ ~~~d t~ ~~~ ~~d ~f~~r~~~ ~~ ~a~~f~b~~ ~ip~ r~tt~~, ~r ~~~r ~ ~~a ~ , ~ t~a~ ~ ~~~ ~"~a~~a~; H~-~!~ ~~c~ C~~illing ~r~~i~~~r ~~ . ~ ~~-~~~~~~ ~~ : Maunder, Thomas E (f?OA) ~mailto:torr~.maunder@ala~ka.g~av] Sent; edneRsda~, June 10, 2QU9 ].:54 PM 7o.6aca, t~k Subject: RE: - 5 (182-203) - (309-094) r~~, ;i~~~ ~a~~ ~~~~~~a~ ~~ ~ r ~~~ `° ~ ~ ~+~~ ~ ~ ~ ~~~ `~~~ h~~ plug ha~ n~t r~m~ir~~d ~-~p~t~n . ~t~d {tt~l~ ~trith ~h~ ~v~rk. '~'~~ ~~~~a~~r, ~~ ~ ~~ From: Baca, Mank [mailto:hank.baca@bp.c~m] Sernt. PRIQnday, June (~8, 2Qt?9 9:26 AM To: Maunder, Thomas E (faQA} / Subject: RE: 01-25 (182-203) - (3p9-094j ~` , j~~t ~ ~ ~~~ r~'~ ~ara t~sP~a `i~ `. ~~ p~~~ ~t~ Har~k E~~~~ C~r~lli~g ~~~'tt- ~~ ~a ~~~ ~~"~ ~i , ~r~ y~~ ~1~ v~ t~~ ~~~a ~~~ ~ ~~ ~ ~~ 1~~ ~ ~ 8/10/20Q~ 01-25 (309-094) Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, June 10, 2009 1:54 PM To: 'Baca, Hank' Subject: RE: 01-25 (182-203) - (309-094) Page 1 of 2 Hank, After our conversation, it does appear appropriate to set 2 Fasdrils. There have been occasions where only 1 plug has not remained competent. Good luck with the work. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Monday, June 08, 2009 9:26 AM To: Maunder, Thomas E (DOA) Subject: RE: 01-25 (182-203) - (309-094) Tom, just to make sure we're on the same page, are you OK with this plan and would you like a second composite bridge plug set? Thanks, Hank Baca Drilling Engineer <». , ~ ~ ~~= .- ~~ 907-564-5444 office '" 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, June 08, 2009 8:02 AM To: Baca, Hank Subject: RE: 01-25 (182-203) - (309-094) Thanks Hank, you have answered my question. Tom From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Monday, June 08, 2009 7:22 AM To: Maunder, Thomas E (DOA) Subject: RE: 01-25 (182-203) - (309-094) Tom, I'm not sure which pipe you're referring to. The composite bridge plug/production packer will be tested (with a packer) prior to running the 7" liner from just above them since there is a leak in the 9.625" casing. We'd like to run the 7" liner with this tested barrier to the reservoir and no casing rams, but you've asked that a second composite plug be set in the past. Hope that answers your question. Thanks, Hank Baca Drilling Engineer 907-564-5444 office 6/10/2009 01-25 (309-094) U 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, June 05, 2009 2:06 PM To: Baca, Hank Subject: RE: 01-25 (182-203) - (309-094) Page 2 of 2 Hank, Sorry I did not get back to you sooner. Having multiple barriers is preferable. Will a pressure test be accomplished on the pipe prior to running the casing? Also note, the permit to drill number should be included in the subject line. Thanks for listing the sundry, that helps too. I look forward to you reply. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Friday, June 05, 2009 10:56 AM To: Maunder, Thomas E (DOA) Subject: 01-25 (309-094) Hi Tom, I'd like to change the plan slightly on DS 01-25 (sundry 309-094, PTD 1822030). We were planning to NU a 3 ram stack so we could run 7" pipe rams with the scab liner. This is what we did on 01-29 several months ago since you weren't comfortable with a composite bridge plug as our barrier to the reservoir. Unfortunately the wellhead is too tall for this to work on 01-25. In the past, I believe you've allowed us to set 2 composite bridge plugs as our double barrier to the reservoir and not run 7" casing rams. Is that acceptable in this case? If so please reply, and we will proceed that way. Thanks, Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell 6/10/2009 • • ~~~ ~~.~ ~ SARAH PALIN, GOVERNOR ..._ ~5~ OIL ~ ~ 333 W. 7th AVENUE, SUITE 100 C01~5ERQA7`IOIQ CO1rII-'IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ,.. ,~~ ~~ ~ ~ r. '%U `' ~ ~,"~ ~~ Anchorage AK 99519-6612 '~~~'~~"~" ~ ~ ~ ~,'' ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU O 1-25 Sundry Number: 309-094 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Conunission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days alter written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~/~ .. Daniel T. Sea; nount, Jr. Chair DATED this j ~ day of March, 2009 Encl. STATE OF ALASKA ~;~~~~ f~'` ALA OIL AND GAS CONSERVATION COMII~ION \1A~ ~` 'b APPLICATION FOR SUNDRY APPROVA(t.~ MAR ~ ~ ?U09 20 AAC 25.280 . _ ,. , _ ~:.~,n rnmmission 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ xtensio~ft~hQl.g~s ' ®Alter Casing ~ ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program - ®Pull Tubing ^ Perforate New Pool ^ Waiver Other ~.~~~ ~O StRI 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number '3(x`1 BP Exploration (Alaska) Inc. development ^ Exploratory 182-203 3. Address: - ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 i(.~ 50-029-20874-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 01-25 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028329 - 74' ' Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10330' - 9282' • 9850' 8827' 9850' Below Cmt Plug C in Len th ize M TVD Bur C II s tr ural r 7' 2 7' 7' 14 47 S rfa 2624' 13-3/ " 2 24' 2624' 4 2670 In erm i e 9610' 9-5/8" 9610' 8 13' 6870 47 0 Pr i n Liner 1011' 7" 17' - 10328' 4' - 280' 8160 702 Liner 28' 4-1/2" 1 ' - 10147' 282' - 91 843 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9835' - 9850' 8813' - 8827' 5-1/2", 17# x 4-1/2", 12.6# L-80 9185' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SB-3A' packer; Packers and SSSV MD (ft): 9064'; 9-5/8" x 7" Brown Hy Flo II 9207' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 1, 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Nam avid Reem Title Engineering Team Leader Prepared ey NameMumber. Signature Phone 564-5743 Date 3_/~_2~0 Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: _ Conditions of approval: Notify Commission so that a representative may witness ``S~ ors( ~~ k ^ Plug Integrity BOP Test Mechanical Integrity Test ^ Location Clearance W ' ] i ~ ~ r'1;~~-' i~ Other: '~~~ ~ S t rri"~~~ w.vw~ t~"C3.~ S~ ~ a ~~ PS ~ Mti~ ni ~.V ~.q,r~~ Subsequent Form Required: W. ~ c~- /~~ ~ APPROVED BY ~ I e A roved B COMMISSIONER THE COMMISSION Dat Form 10-403 R,e~sed 06/2006 W ~ ~ ~ Submit In Duplicate • • by cr,~,~ 01-25 Rig Workover (Repair IA x OA communication and PC leak) Scope of Work: Pull 5.5" L-80 completion. Run & cement 7" 26# L-80 scab liner from 9000-3000'. Run USIT log to find TOC, cut and pull 9.625" casing as deep as possible. Tie back 9.625" casing, and cement to surface. Replace 9.625" packoff and hanger. Run 4.5" L-80 completion. Engineer: Hank Baca MASP: 2370 psi Well Type: Injector Estimated Start Date: May 1st, 2009 S 1 Recover 44' Eclipse tubing patch (bottom ~ 8110' ELMD). Drift tubing to 9050' for 4.5" Fasdril & 'et cutter. E 2 Set 4.5" Fasdril C~ 9152'. Reference tubin tall dated 2/3/90 F 3 CMIT-TxIA, test will fail due to Cret leak and tbg holes behind patch. Obtain LLR ~ 500 psi and 1000 si to u date 2005 data MIT-0A to 2000 si S 4 Run memory LDL w/ cold fluid down tubing to verify fasdril & upper packer are holding and leak is u hole E 5 Jet cut tubing at 9036'. Reference tubing tally dated 3/3/90, cut desired to be'/z way down first full 'oint above acker F 6 Circulate well with 9.8 brine, diesel FP ca as needed. Bleed WHPs to 0 si. W 7 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 8 Set a BPV in the tubin han er. O 9 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 4000 psi high. Circulate out freeze protection and circulate 9.8 ppg brine. 2. Pull and LD tubing string to the cut. 3. Dress 5.5" tubing stub 4. PU 9.625" RTTS &RIH to 3500'. Test above RTTS to 4000 psi for 30 minutes to determine top of leak and scab liner top. Continue to RIH w/ RTTS to 9000' and test Fasdril plug/packer to 4000 psi for 10 minutes to verify they're holding 5. Run 7", 26#, L-80 scab from 9000' - 3000'. 5.5" overshot on 5.5" tubing XO'd to 7". 6. Cement 7" liner, set liner hanger and packer 7. Drill out 7" float equipment. 8. Test 7" scab liner to 4000 psi for 30 charted minutes. 9. RU wireline and run USIT from cut to surface. 10. Run 9-5/8" RBP and set 100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump ~50 ft of sand on RBP. 11. Mechanically cut 9-5/$" casing in 1~ full joint above top of cement. Pull casing thru stack. Dress-off 9- 5/a" stub in preparation of casing overshot. Note: VBR's will not be changed to 9 5/e" pipe rams as the well has~'iested barriers (RBP & packerffasdril) to the reservoir. C~ • 12. Run back in with condition B 9-5/8", 47#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9-5/8" pack-off to 3500 psi. Cement new 9-5/$" casing to surface 13. Drill out 9.625" 14. Cleanout above 9-5/8" RBP. PT 9.625" tieback to 4000 psi. Pull 9-5/a" RBP. 15. Drill up 4.5" fasdril ~ 9152' 16. Run 4-1h" L-80 TC-II stacked packer completion 17. Displace the IA to packer fluid and set the packer. 18. Test tubing and IA to 4000 psi. Freeze protect to 2,200' MD. 19. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE = FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = KOP = 3000' Max Angle = 35 Q 6300' Datum MD= 9900' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" H 262 Minimum ID = 2.970" @ 8080' 5-1 /2" WF ECLIPSE PATCH 15-1 /2" TBG-fC, 17#, L-so, .0232 bpf, ID = 4.892" H 9084' TOP OF 41 /7' TBG-PC 9084' 4-1 /2" TBG-FC, 12.6#, L-80, .0152 bpf, ID= 3.958" 9184' TOPOF4-1/2" LNR 9219' PB2FORATION SUMMARY REF LOG: BHCS ON 02/21/83 ANGLEATTOP PERF: 31 @ 9610' Note: Refer to Ftoduction DB for historical perf data SQE SPF INTERVAL OpnlSgz DOTE SEEPAGE2 FOR PERF BREA KOOWN 7" LNR H 9317' 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9610' 01 -~~ I ALLOWB)"'~' H*~IONLY/NOMIINJECTION 2129' 13-3/8" X 9-5/8" BOT IXTERNAL CSG Pi(R 2176' 5-1/1"CANICOBAL-OSSSVNIP,ID=4.56" GAS LIFT MANDRH-S MD ND DEV TYPE VLV LATCH PORT D~ 1 2918 2916 8 MMG RK 2 5022 4768 33 MMG RK 3 6547 6030 34 MMG RK 4 7471 6798 34 MMG RK *5 8098 7340 33 MMG RK 6 8204 7432 33 MMG RK 7 8741 7887 29 MMIG RK 8 8847 7974 29 MMG RKP 8080'$124' ~ 5-1/2" WF ECLIPSE P14TCH (02/17/05), ID= 2.970" 8110' ELMD BTMOFS-1/7' ECLIPSE PATCH (LOGGED 11I22lOS) 9064' 9.5/8" X 5-1 /2" BKR SB-3A PKR ID = 4.875" 9084' XO MLLOUT EXT X 4-1/2", ID = 6.625" 9173' 4-1/2" OTiS XN NIP, ID= 3.725" 9184' 41/2" X 7" XO, ID = 3.90" 9185' 7" MULESHOE JOINT, ID = 6.276" 9207' 9-5/8" X 7" BROWN HY FLO II LNR/HGR, ID = 6.184" 9212' 7"X 9-5/8" BROWNTYPEH LNRTOP PKR, D = 6.196" 9218' 7" X 41 /7' XO, ID = 3.958" 9850' HTOP OF CEMENT (12/21/05) LNR 12.6#, L-80, .0152 bpf, ID= 3.958" ~ 10147' T' LNR, 29#, L-80, .0371 bpf, ID=6.184" 10323' 99$6' H 7" X 41/1" BKR ECL ISOLATION PKR ID = 3.958" 10000' CTM TAG TD PRECMT (12/21/05) 10325' 1/8" X 1" X6" PIECE OF CENTRALeER SPPoNG (LEFT 06/10/94) DATE REV BY COMMENTS DOTE RB/ BY COMMENTS 03/24/83 ORIgNAL COMPLETION 07/01/06 RDW/PA REVISEDWANER SFTY NOTE 03/03/90 LAST WORKOVER 06/01N7 RDW/PA WANERSFTY NOTE DELETED 11/19/05 MORIPJC PULL IBP@ 9150' 11/02/05 KSBIPJC BTM TBG PATCH LOGGED 12/30/05 KEY/TLH CMTPLUG (12/21/05). 03/25/06 DFRIPJC ADPERFS (02/16/06) PRUDHDEBAY UNIT WELL: 01-25 PERMIT No: 1822030 API No: 50-029-2087400 SEC 7, T10N, R15E, 2563.05' FEL & 2863.9' FNL BP Exploration (Alaska) TREE= FMC WELLHFAD= FMC ACTUATOR= AXELSON KB. ELEV = 74' BF. ELEV = KOP= 3000' Msx Angle = 35 @6300' Datum MD = 9900' Datum TVD = 8800' SS PERFORATION SUMMARY REF LOG BHCS ON 02/21 /83 ANGLEATTOP FERF: 31 @9610' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 9610 - 9612 S 03/04/83 3-3/8" 9778 - 9796 S 09/15/89 3-3/8" 4 9806 - 9812 S 12/03/96 3-3/8" 9822 - 9824 S 03/04/83 2-102" 6 9835 - 9850 O 02/16/06 3-3/8" 9861 - 9863 S 03/04/83 3-3/8" 9890 - 9900 S 07/03/93 9908 - 9914 S 07/03/93 9920 - 9924 S 07/03/93 2-1/2" 6 9928 - 9940 S 02/19/97 9940 - 9944 S 12/03/96 2-102" 4 9954 - 9974 S 12/12/96 9984 - 9990 S 07/03/93 9990 - 10010 L 12/03/96 10010 - 10073 S 06/03/91 10102 - 10104 S 03/04/83 DOTE REV BY COMMENTS DATE REV BY COMMENTS 0324/83 ORIGINAL COMPLETION 07/01/06 RDV1/PA REVISEDWANERSFlY NOTE 03A3/90 LAST WORKOVER 06/01/07 RDV~dPA WANERSFTY NOTE DELETED 11/19/05 MOR/PJC PULL IBP @ 9150' 11/02/05 KSB/PJC BTMTBGPATCHLOGGED 12/30/05 KEYORH CMT PLUG (12/21/05) 03025/06 DFR/PJC ADPERFS (02/16/06) FRUDHOE BAY UNff WELL: 01-25 PERMIT No: ~ 822030 A PI No: 50-029-20874-00 SEC 7, T10N, R15 ~ 2563.05' FEL & 2863.9' FNL BP Exploration (Alaska) 01-25 TREE = FMC WELLHEAD = FMC ACTUATOR = AXEt_SON K$. ELEV = 74' BF. ELEV = KOP = 3000' Max Angle = 35 @ 6300' Datum MD = 9900' Datum TV D = L-80 from old TOC to s 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2624' 7" 26# L-80 scab liner cmt'd -3000`-9000' 5.5" x 7" ported 10` XO/pup 5.5" overshot 5-1/2" TBG•PC, 17#, L-80, .0232 bpf, ID = 4.892" 9084' TOP OF 4-1/2" TBG-PC 9084' 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9184' TOP OF 4-1 /2" LNR 9219' PERFORATION SUMMARY REF LOG: BRCS ON 02/21/83 A NGLE AT TOP PERF: 31 @ 9610' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERF BREAKDOWN ~ TOP OF 7" LNR ~ = 8.681 " LNK, 1Z.(iiF, L-SU, .U152 bpt, M7= 3.958" H 7U'14T 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184- 10323' ~TD~ 10330' I TOP OF CEMENT (12/21 /OS) I 7" X 4-1/2" BKR ECL ISOLATION PKR, ID = 3.958" TAG TD PRE CMT (12/21 /05) I/8" X 1' X 6" PIECE OF CENTRALQER sPRrvG (L~ r os/1o/sa) DATE REV BY COMMENTS DATE REV BY COMMENTS 03/24!83 ORIGINAL COMPLETION 07/01/06 ROWlPA REV IS®WANB2SFTY NOTE 03/03/90 LAST WORKOVER 06/01!07 RDW/PA WANER SFTY NOTE DELETED 11/19/05 MOR/PJC PULL ~P@ 9150' 11/02!05 KSB/PJC BTM TBG PATCH LOGGED 12/30!05 KEY/TLH CMT RUG (12/21105) 03/25106 DFR/PJC ADPERFS (02/16!06) PRUDHOE BAY UNfT WELL: 01-25 PERMfr No: 1822030 API No: 50-029-20874-00 SEC 7, T10N, R15E, 2563.05' F~ ~ 2863.9' FNL BP Exploration (Alaska) 2000' 4-1/2" HES X NIP, ID = 3.813" 2129' 13-3/8" X 9-5/8" BOT EXTERNAL CSG PKR 7" x 4.5" Baker S-3 packer @ -8370` 4-1/2" 12.6#/ft, L-80 TC2 tbg 9064' H 9-5/8" X 5-1 /2" BKR SB-3A PKR ID = 4.875" 9084' H XO MILLOUT EXT X 4-1/2", ID = 6.625" 9173' H4-1/2" OTIS XN N~, ID = 3.725" I 9184' 4-1/2" X 7" XO, ID = 3.90" 9185' 7" MULESHOE JOINT, ID = 6.276" 9207' 9-5/8" X 7" BROWN HY FLO II LNR/HGR, ID = 6.184" 9212' 7" X 9-5/8" BROWN TYPE H LNR TOP PKR, ID = 6.196" 9218' 7" X 4-1/2" XO, ~ = 3.958" From: Dean, James A [James.Dean@bp.com] Sent: Tuesday, March 17, 2009 4:07 PM To: Maunder, Thomas E (DOA) Cc: Baca, Hank; Seltenright, Ana Maria Subject: RE: DS 01-25 (182-203) Tom, r ~ ~~~-~~'~~~ ~ ~ ~~~ ~~~~; n.': , r ; This note documents our earlier conversation. The 01-25 well will be converted to water-only injection service this year. The downhole conversion (plugging zone 2 perforations and perforating zone 4) has already been completed. The planned workover will restore the production casing integrity and return the well to an "operable" status. Over the summer months, construction crews will tie the 01-25 into the existing water injection system at DS 1. We will not produce this well after the workover and expect to commence water injection in 3Q 2009. --James From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 17, 2009 2:10 PM To: Dean, James A Cc: Baca, Hank Subject: FW: DS 01-25 (182-203) James, Sorry I forgot to add you to the list. Tom Frb~ • aunder, Thomas E (DOA) Sent: Tue March 17, 2009 2:03 PM To: 'Baca, Hank' Subject: RE: DS 01-25 ( 3 Hank and James, I have reviewed the well file for DS 01-25 and foun t a sundry (305-21 as approved 8/11/05 to convert this well from producer to injector. Administrative Approval A 08 w ~ sued 12/13/05 allowing water injection only with known IA to formation communication. On 5/31/07 the tegrity Engineer issued a message stating the well was not operable due to the production casing lea d the AA ncelled 7/20/07. I just spoke with James and he confirmed that the original conversion was never complete o injection has taken place into this well. He also confirmed that the well wil be produced after the workover an ~ await connection to the WI header. Based on the information from th nversations, I will add "convert to service" to Block 1. It appears that the' necessary assessments re mg integrity were performed in July - August 2005. The planned work should restore integrity to the uction casing string. The pressure tests planned during the work should confirm the repairs. Call or ssage with any questions. T aunder, PE OGCC 3/17/2009 DS 01-25 (182-203) • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 17, 2009 2:03 PM To: 'Baca, Hank' ;", ~~~,:~ ~~~~ ~ r ~~~ Subject: RE: DS 01-25 (182-203) Hank and James, I have reviewed the well file for DS 01-25 and found that a sundry (305-216) was approved 8/11/05 to convert this well from producer to injector. Administrative Approval A104C.008 was issued 12/13/05 allowing water injection only with known IA to formation communication. On 5/31/07 the Well Integrity Engineer issued a message stating the well was not operable due to the production casing leak and the AA was cancelled 7/20/07. I just spoke with James and he confirmed that the original conversion work was never completed and no injection has taken place into this well. He also confirmed that the well will not be produced after the workover and will await connection to the WI header. Based on the information from the conversations, I will add "convert to service" to Block 1. It appears that the necessary assessments regarding integrity were performed in July -August 2005. The planned work should restore integrity to the production casing string. The pressure tests planned during the work should confirm the repairs. Call or message with any questions. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Tuesday, March 17, 2009 11:24 AM To: Maunder, Thomas E (DOA) Subject: FW: DS 01-25 (182-203) Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell From: Dean, James A Sent: Tuesday, March 17, 2009 11:21 AM To: Baca, Hank Subject: RE: DS 01-25 (182-203) Hank, This well is still technically a producer, but we have a project underway to convert it to injection. It will be switched to water-only injection service around 3Q 2009 after the surface facility work is completed. --James From: Baca, Hank Sent: Tuesday, March 17, 2009 10:43 AM To: Seltenright, Ana Maria Subject: FW: DS 01-25 (182-203) 3/17/2009 DS 01-25 (182-203) • • Page 2 of 3 Hi, looks like the AOGCC is still showing this well as a producer. I'm not sure if something needs to be done form a permitting standpoint? Thanks, Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Tuesday, March 17, 2009 10:41 AM To: Maunder, Thomas E (DOA) Subject: RE: DS 01-25 (182-203) Tom, its going to be a water injector. I'll pass on to the pad engineer that its still showing up as a producer in your records. It shows as converted to injection in mine. I'll also confirm they're planning to inject immediately after the workover. I'm not worried about debris on top of a plug that will be drilled out, we'll just be chasing it out the tubing tail at 9184' Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 17, 2009 9:36 AM To: Baca, Hank Cc: Reem, David C Subject: RE: DS 01-25 (182-203) Hank, Thanks for the replies. To continue ... 1. Is it desired that this well be a water injector or WAG? Is it intended for the well to go on injection "soon" after the workover? 2. Sorry about the IBP reference. Debris from cleaning out the 7" float equipment could still be possible on top of the Fasdril. 3. Regarding the small cleanout string, how far do you intend to chase the remains of the Fasdril? PBTD is -700' deeper than the intended Fasdril setting depth. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Tuesday, March 17, 2009 9:20 AM To: Maunder, Thomas E (DOA) Subject: DS 01-25 (182-203) Dave, Please forward to Hank. They changed out our computers over here and some on the address lists didn't make the move. 3/17/2009 DS 01-25 (182-203) ~ ~ Page 3 of 3 Your name however came through just fine! I am reviewing the 403 for this well and had some questions. 1. According to our records, this well is "development, 1-oil". Is it desired to convert the well to "service, 1-winj"? 2. Is any sand or "sluggits" planned on top of IBP? Cleaning out 7" float equipment could result in debris falling downhole. 3. Step 16 says to run a stacked packer completion, however I believe the stub will have already been engaged when you run the 7" liner. 4. Will the BOP rams be capable of covering the 2-7/8" DP needed to drillout and push the Fasdril downhole? Thanks in advance. Tom Maunder, PE AOGCC 1) yes 2) not sure what this is a reference to, no IBP planned. There will be a 4.5" composite bridge plug that will be drilled up and a 9.625" retrievable by that we'll dump sand on. 3) correct regarding tubing stub. stacked as in the packer at 9064 will not be milled up 4) my hope was the -150' of 2-7/8" required would be considered a BHA and the annular preventor would be adequate. Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell 3/17/2009 • LJ SAR.4W PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 275-7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 4C.008 ~~~J~~ JAS ~ 20~ Ms. Anna Dube, Well Integrity Coodinator BP Exploration (Alaska) Inc. P.O. Box 19661 Z ~ ~~ Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO O~C.008 (Well PBU OI-2~) Dear Ms. Dube: Pursuant to a BP Exploration (Alaska), Inc. ("BPXA") request dated June 10, 2007 Alaska Oil and Gas Conservation Commission (-`AOGCC") hereby cancels Administrative Approval AIO O~C.008, which allowed continued water injection. This well exhibited inner annulus by outer annulus pressure communication, and a production casing leak, and BPXA did not at the time propose repairing the well to eliminate the problems. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has shut in the well pending a rig workover to restore the well's mechanical integrity. Consequently, Administrative Approval AIO 04G008 no longer applies to operation of this well. Instead; injection in well PBU Ol-2~ will be governed by provisions of the underlying AIO ivTo. 4E which supersedes and replaces AIO 4C. DONE at Anchorage, Alaska and dated July 20, 2007. The Alaska Oil and Gas Conservation Commission --.- -;= _~~ - ~: ~~ ,,: Y\,_. Danie! T. Seamount, 3r Commissioner Cathy P ~oerster Commi sinner ...% it - R ~ i# '[. S ~ l~~~ t.j~; h ~.'. '- i' • _ _ _ . -~ - - J -; - '~ - _ _ - FRANK H. MURKOWSKI, GOVERNOR ~T~+ ~7~L1 ~®+ iJ~/ ~~+ 1~~1-7~ 333 W. 7`" AVENUE, SUITE 100 ~I]ls-7~~~~~®~ C®P~IIrII~SI®1~ ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 4C.008 ~1r. Steve Rossberg, Wells :Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 :=~nchoraae, AK 99~ 19-6612 RE: PBli 01-2~ (PTD 182-203) Request for Administrative Approval Dear VIr. Rossberg: Per Rule 9 of Area Injection Order 004C.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA"}'s November 2, 200a request for administrative approval to inject water in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBli 01-2~. The Commission further finds that, based upon reported results of BPXA's diag- nostic procedures, PBU 01-2~ exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to inject water in PBU 01-25 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates: 3. BPXA shall perform an annual VIIT - OA to 1.2 times the maximum anticipated well pressure; 4. BPXa shall perform an annual ~1IT - T to 1.2 times the maximum anticipated well pressure; ~. BPXA shall limit the well`s OA pressure to 1000 ps.i and Limit the well's IA pres- sure to 500 psi; !vlr. Steve Rossberg December 13, 2005 Page Z of 2 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. after well shut in due to a change in the well`s mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Alaska and dated December 13, 200. Chairman $ CJ `,v,; • ~'; ~ i , '~ .rte ~ i%. ~ r ~ ~ :ate ~ N ~~;~ 1 *~ t V 7 ~ !! 3 1 .:_~~~ ~~ =~ ~, °<a ~ _ - 'r'id ~ '~ •, n ''*f 1 ~~ :`~ . aniel T. Seamount, Jr. Cathy . Foerster, Commissioner Commissioner 01-25 (PTD #1822030) Internal Waiver Cancellation All, An internal waiver was issued for a PC Leak and IAxOA communication on well 01-25 (PTD #1822030) on 01/29/06. The well does not pass an MITIA and is not considered operable. Paperwork will also be sent to the AOGCC canceling the corresponding Administrative Approval. Plans are to restore this well with a rig workover. The well is reclassified as Not Operable. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you - )lnna (])u6e œ/E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 <,",,,,,,,...,"'1:;0 JUN 0 J 2007 ~~'P""" 1 of 1 6/1/2007 9:21 AM . !tc.. 9/:z..çk;: RECEIVED STATE OF ALASKA. ' . ALASKA Oil AND GAS CONSERVATION COMMISSION SEP 2 2 2006 REPORT OF SUNDRY WELL OPERA TIÐNSil & Gas Cons. Commission . 1. Operations Performed: Repair Well 0 Pluç¡ Perforations 0 Stimulate 0 Other!&] MIT-T Abandon 0 Alter CasingD Pull TubingD Perforate New PaolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD 182-2030 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20874-00-00 7. KB Elevation (ft): 9. Well Name and Number: 74.00 01-25 8. Property Designation: 10. Field/Pool(s): ADL-028329 Prudhoe Bay Field I Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10330 feet true vertical 9282.0 feet Plugs (measured) None Effective Depth measured 9850 feet Junk (measured) None true vertical 8827.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 20" 91.5# H-40 34 - 115 34.0 - 115.0 1490 470 SURFACE 2591 13-318" 72# L-80 33 - 2624 33.0 - 2624.0 4930 2670 PRODUCTION 9579 9-518" 47# L-80 31 - 9610 31.0 - 8613.0 6870 4760 LINER 1006 7" 29# L-80 9317 - 10323 8364.0 - 9275.0 8160 7020 SCAB LINER 33 7" 29# L-80 9185 - 9218 8254.0 - 8281.0 8160 7020 SCAB LINER 929 4-112" 12.6# L-80 9218 - 10147 8281.0 - 9108.0 8430 7500 Perforation depth: 8CANNEJ) <¡ED 2 ? 2DCF . "<'- U ~ .;;;' ' . v . ,- Measured depth: 9835-9850 True vertical depth: 8813-8827 Tubing ( size, grade, and measured depth): 5-112" 17# L-80 @ 27 - 9084 4-1/2" 12.6# L-80 @ 9084 - 9184 7" 26# L-80 @ 9184 - 9185 5-1/2" 17# L·80 @ 8080 - 8124 Tubing Patch Packers & SSSV (type & measured depth): 13-318" BOT External CSG PKR @ 2129 5-112" Eclipse Patch PKR @ 8080 5-112" Eclipse Patch PKR @ 8118 5-112" Baker SB-3 Packer @ 9064 9-518" Brown Type H LNR Top PKR @ 9212 7" BKR ECL Isolation PKR @ 9986 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft SEP 2 {} 2006 Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation: SI 0 0 --- --- Subsequent to operation: SI 0 0 - --- 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilOO GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr NIA Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature A '>1.... .~ JJ...Y J Phone 564-5174 Date 9120/06 v '- -, .. Form 10-404 Revised 412004 U K \ b \ 1'J A L . . 01-25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07106/2006 (pull ibp) PULLED 2.5" IBP @ 9078' SLM, RECOVERED ALL ELEMENTS "''''* LEFT WELL SHUT IN *** 07105/2006 *** WELL SHUT IN ON ARRIVAL *** (pull ibp) RIG UP SLlCKLlNE RIH WI 2.70" CENT, 2.50" Ea. BELL GUIDE, 2" RS 07104/2006 T/I/O= 800/40/180 MIT-T to 3000 psi. Passed on second attempt Pumped 52 bbls 60/40 meoh to reach test pressure tbg lost 100 psi in first 15 min and 20 psi in second 15 min bleed off pressure FWHP=800/40/450 07103/2006 WELL SHUT-IN TIIIO 950/0/200. SET BAKER 2.5" RETREIVABLE IBP BRIDGE PLUG IN 4-1/2" TAILPIPE AT 9110 FT. DEPTHS TIED TO TUBING SUMMARY DATED 3-MAR- 1990 Baker IBP SERIAL # 10110807 07102/2006 WELL SHUT-IN TIIIO 950/0/200. RIH TO SET IBP IN 4-1/2" LINER BELOW PACKER. 07102/2006 T/I/O = 780/100/160. Temp = SI. WHPs, Tubing FL (Pre-IBP). Tubing FL @ 2510' (above 06/12/2006 T/I/O = 560/90/160. Temp = SI. T FL (WC). Tubing FL @ 1740' (above the SSSV). 06/0712006 TIIIO=500/40/100 MIT OA to 3300 psi. PASS (MIT Campaign) Pumped 3.8 bbls crude to pressure up to 3300 psi. OA passed on 1 st try. Bled OAP. Final WHP's=500/40/150 06/05/2006 T/I/O= 45010/100. Temp= SI. OA FL (MITOA Campaign). OA FL near surface. No integral flanges on annuli. FLUIDS PUMPED BBLS 2 Diesel --- PT Surface Equipment 3.8 Crude 52 60/40 Methanol Water 57.8 TOTAL Page 1 TREE = FIIt1C SA OTES: -PC LEAK & IAxOA COM M. WELLHEAD - FIIt1C 01-25 OPERATING LIMITS: MAX lAP = 500 PSI, MAX OAP = ACTUATOR = AXELSON 1000 PSI (01/29/06 WAIVER) . NOTE: PWI ONLY/NO M I KB. ELEV = 74' INJECTION ALLOWS)- BF. ELEV = KOP= 3000' >< ~ I 2129' H 13-318" X 9-5/8" BOT EXTERNA L CSG A<R I Max Angle = 35 @ 6300' 2176' H 5-1/2" CAIIt1CO BAL-O SSSV NIP, 10 = 4.56" I Datum MD = 9900' . DatumTVD= 8800' SS GAS LIFT MANDRELS S1 MD TVD DEV TYPE VLV LATCH PORT DATE 1 2918 2916 8 MMG RK ~ 2 5022 4768 33 MMG RK 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2624' ~ 3 6547 6030 34 MMG RK - 4 7471 6798 34 MMG RK *5 8098 7340 33 MMG RK Minimum ID = 2.970" @ 8080' 6 8204 7432 33 MMIG RK 7 8741 7887 29 MMIG RK 5-1/2" WF ECLIPSE PATCH 8 8847 7974 29 MMIG RKP CHEMICAL MANDRELS C LJ IST MD I TVDI DEV TYPE VLV LATCH PORT DATE I 9 8955180631 29 MMG-L TS-R I RK I ~ 80S0'.8124' 1-15-1/2" WF ECLIPSE PATCH (02/17/05),10 = 2.970" I 18110' ELMD BTM OF 5-1/2" ECLIPSE PA TCH ~ ~ (LOGGED 11122/05) ~ 9064' H 9-5/8" X 5-112" BKR SB-3A PKR, 10 - 4.875" I 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892"' 9084' I - --r HXOMILLOUTEXTX4-1/2", 10=6.625" I TOP OF 4-1/2" TBG-PC , r-- ~ 9084' 9084' . It- 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID= 3.958" I 9184' I --r 9173' 1-14-1/2" OTIS XN NIP, 10 = 3.725" I TOP OF 4-1/2" LNR , 9219' r-. ~ r--.I 9184' H4-1/2" X 7" XO, 10 = 3.90" I IJ r---r 9185' H 7" MULES HOE JOINT, 10 = 6.276" I PERFORA TION SUMMARY 8 ~ r---r 9207' 9-5/8" x 7" BROWN HY FLO II REF LOG: BHCS ON 02/21/83 LNR/HGR, 10 = 6.184" ANGLEATTOPPERF: 31 @9610' . 9212' 7" X 9-5/8" BROWN TYÆ H LNR TOP Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE " PKR, 10 = 6.196" SEE PAGE 2 ~ 9218' H 7" X 4-1/2" xo, 10 - 3.958" I FOR PERF BREAKDOWN I 1 TOP OF 7" LNR I 9317' I . . I 9-5/8" CSG, 47#, L-80, 10 = 8.681" I 9610' ~ ~ Il-J 9850' H TOP OF CEMENT (12/21/05) I ~ 9986' 1-/7" X 4-1/2" BKR ECL ISOLATION PKR, 10 - 3.958" I 14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 'D'4T ~I'DOOO'CTMHTAGTDmECMT(12121105) I 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 10323' I I 10325' 1/8" X 1" X 6" PIECE OF CENTRALIZER I QÐ 10330' I SPRING (LEFT 06/10/94) DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNfT 03/24/83 ORIGINAL COM PLETION 12/30/05 KEY ITLH GMT PLUG (12/21/05) WELL: 01-25 03/03/90 LAST WORKOVER 03/16/06 RPH/TLH REVISEDWM/ERSFfY NOTE PERMfT No: '1822030 01/02/05 RA ClTLP MIN 10, REMOVE IBP, PATCH 03/25/06 DFRlPJC ADPERFS (02/16/06) API No: 50-029-20874-00 04/22/05 LDKlTLH SEr ECLIPSE PA TCH (2/17/05) 07/01/06 RDW/PA( REVISED WANER SFfY NOTE SEC 7, T10N, R15E, 2563.05' FEL & 2863.9' FNL 11/19/05 MQR/PJC PULL IBP@ 9150' 11/02/05 KSB/PJC BTM TBG PATCH LOGGED BP Exploration (Alaska) . TREE = FMC . WELLHEAD = FMC ACTUA TOR - AXELSON KB. ELEV - 74' BF. ELEV - KOP= 3000' Max Angle = 35 @ 6300' Datum MD = 9900' Datum TVD = 8800' SS ÆRFORA TION SUMMARY REF LOG: BHCSON02/21/83 ANGLE AT TOP ÆRF: 31 @ 9610' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 9610 - 9612 S 03/04/83 3-3/8" 9778 - 9796 S 09/15/89 3-3/8" 4 9806 - 9812 S 12/03/96 3-3/8" 9822 - 9824 S 03/04/83 2-1/2" 6 9835 - 9850 0 02/16/06 3-3/8" 9861 - 9863 S 03/04/83 3-3/8" 9890 - 9900 S 07/03/93 9908 - 9914 S 07/03/93 9920 - 9924 S 07/03/93 2-1/2" 6 9928 - 9940 S 02/19/97 9940 - 9944 S 12/03/96 2-1/2" 4 9954 - 9974 S 12/12/96 9984 - 9990 S 07/03/93 9990 - 10010 L 12/03/96 10010 - 10073 S 06/03/91 10102 - 10104 S 03/04/83 01-25 PERFS . DATE REV BY COMMENTS DATE REV BY COMMENTS 03124183 ORIGINAL COM PLETION 12/30/05 KEY /TLH CMT PLUG (12/21/05) 03/03/90 LAST WORKOVER 03/16/06 RPHITLH REVISED WAIVER SFTY NOTE 01/02/05 RAC/TLP MIN 10, REMOVE IBP, PATCH 03/25/06 DFRlPJC AOÆRFS (02/16/06) 04122/05 LDKlTLH SET ECliPSE PA TCH (2117/05) 07/01/06 RDW/PA( REVISED WAIVER SFTY NOTE 11/19/05 MORlPJC PULL IBP@ 9150' 11/02/05 KSB/PJC BTM TBG PA TCH LOGGED . PRUDHOE BA Y UNIT WELL: 01-25 ÆRMIT No: '1822030 API No: 50-029-20874-00 SEC 7, T10N, R15E, 2563.05' FEL & 2863.9' FNL BP Exploration (Alaska) ,. . STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ,:.0'_ 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time ExtensionD Change Approved Program 0 Operat. Shutdown 0 Perforate [] Re-enter Suspended Well [] 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development M Exploratory 182-2030 . 3. Address: P.O. Box 196612 Stratigraphic D Service 6. API Number: Anchorage, AK 99519-6612 50-029-20874-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 74 KB 01-25 8. Property Designation: 10. Field/Pool(s): ADL-028329 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 10330 feet Plugs (measured) None true vertical 9282.02 . feet Junk (measured) 10325 Effective Depth measured 10290 feet true vertical 9243.98 feet Casing Length Size MD TVD Burst Collapse Conductor 81 20" 91.5# H-40 34 - 115 34 - 115 1490 470 Surface 2591 13-3/8" 72# L-80 33 - 2624 33 - 2623.99 4930 2670 Production 9579 9-5/8" 47# L-80 31 - 9610 31 - 8613.1 6870 4760 Liner 1006 7" 29# L-80 9317 - 10323 8364.15 - 9275.37 8160 7020 Liner 33 7" 29# L-80 9185 - 9218 8253.62 - 8281.2 8160 7020 Liner 929 4-1/2" 12.6# L-80 9218 - 10147 8281.2 - 9107.98 8430 7500 Perforation depth: Measured depth: 9835 - 9850 9725 - 9805 ';'·C·f:¡X -:\~"~~f IT >.,", >itì 'iI'1JJ\:"', ";" ;;.. <oJ' True Vertical depth: 8813.46 - 8827.32 8713.58 - 8785.88 Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 8080 - 8124 4-1/2" 12.6# L-80 9084 - 9184 5-1/2" 17# L-80 27 - 9084 7"26# L-80 9184 - 9185 Packers and SSSV (type and measured depth) 9-5/8" BOT External CSG PKR 2129 5-1/2" Eclipse Patch Packer 8080 5-1/2" Eclipse Patch Packer 8118 5-1/2" Baker SB-3 Packer 9064 12. Stimulation or cement squeeze summary: Intervals treated (measured): -..- RBDMS 8Ft MAY 2 6 2006 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: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development M' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil M Gas D WAG D GINJ D WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Title Data Mgmt Engr Signatur~~~~ ~ Phone 564-4424 Date 5/23/2006 Form 10-404 Revised 04/2004 ih/f\IJ\1 sUb':Ploriginal,OnlY /~. $·4,c· ~ e e 01-25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 2/15/2006 PERFORATED FROM 9835' - 9850' WITH 2.5" HSD 2506 PJ HMX GUNS. TD TAGGED AT 9850'. GUNS BECAME STUCK AFTER FIRING. POSITIVE INDICATION OF SHOT SEEN AT SURFACE, BUT UNABLE TO CONFIRM AFTER POOH. GUNS LEFT IN HOLE. ***CONTINUED ON NEXT DA Y*** 2/16/2006 ***CONTINUED FROM PREVIOUS DA Y*** PERFORATED FROM 9835' - 9850' WITH 2.5" HSD 2506 PJ HMX GUNS. TD TAGGED AT 9850'. GUNS BECAME STUCK AFTER FIRING. POSITIVE INDICATION OF SHOT SEEN AT SURFACE, BUT UNABLE TO CONFIRM AFTER POOH. GUNS LEFT IN HOLE. 2/17/2006 ***WELL WAS SHUT-IN ON ARRIVAL*** (Fish E-Line Toolstring) RAN 2.875 SWEDGE WILL NOT PASS LOWER PORTION OF THE TBG PATCH, 2.75" SWEDGE WILL PASS RAN WIRE FINDER AND SCRATCHER AND BALLED UP WIRE @9,290' SLM. ****JOB STILL IN PROGRESS, WSR CONTINUED ON 2-18-2006**** 2/18/2006 Fished 600' of cable with fired 20' HSD gun (15' loaded) on the end. 2/18/2006 ***WSR CONTINUED FROM 2-17-2006**** (Fish E-Line Toolstring) FISHED 1/4" E-LlNE TO SURFACE, LEFT APROXX. 25' TAIL FOR E-LlNE TO RE-HEAD WITH, PAD OP NOTIFIED OF WELL STATUS, SSV BLOCKED IN AS PER E-LlNE OP. *** ASSIST E-LlNE RIGGING UP *** 2/26/2006 ***WELL S/I UPON ARRIVAL*** RAN 2.5" DMY GUN & SB, TAG TD @ 9857' SLM WELL LEFT S/I 3/25/2006 PERFORATE FROM 9725' - 9805' IN 3 RUNS USING 2.5" HSD LOADED WITH POWERJET 2506 HMX. **CONTINUED ON 26-MAR-2006** 3/26/2006 **CONTINUED FROM 25-MAR-2006** PERFORATE FROM 9725' - 9805' IN 3 RUNS USING 2.5" HSD LOADED WITH POWERJET 2506 HMX. RU N 1 : PERFORATE FROM 9805' - 9775' (30') CCL STOP DEPTH = 9770.7' CCL TO TOP SHOT = 4.3' GUN STUCK AFTER SHOOTING. UNABLE TO MOVE UP OR DOWN HOLE. PULLED FREE AFTER PUMPING. KINKED LINE STOPPED AT FLOWTUBES AT 575'. **CONTINUED ON 27-MAR-2006** FLUIDS PUMPED BBLS 58 Diesel 275 Crude 290 KCL 12 Meth 635 TOTAL Schlumberger NO. 3748 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII J b# L D Of D BL CI CD IE}.. p ;'ðJ e 0 oa escrrptlon ate o or 06-02 10715379 MEMORY PRODUCTION PROFILE 01/26/04 1 04-06 10672293 INJECTION PROFILE 08/07/03 1 03-31 9153242 PRODUCTION PROFILE 02/05/03 1 03-29 10866560 PRODUCTION PROFILE 07/30/04 1 02-29A 10563072 LDL 06/22/03 1 01-34 10563167 SBHP SURVEY 06/05/03 1 01-25 10889226 LDL 04/07/05 1 01-24A 10772257 SCMT 05/11/04 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth :¡;;ri~NN~F'~j\, [')D ''1f' ?r¡n~ ~~~";;'~~¡;'~~G~~ ~'H j\ .1. '.0 ·>"..vuU 03/27/06 e e Ht;:L;t.:IVEt') DEC 2 2 2005 _ STATE OF ALASKA _ ALA" Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Con Stimulate 0 Other 0 AnchorQge WaiverO Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 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: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 8. Property Designation: 74 KB ADL-028329 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Production Liner Liner Liner Perforation depth: measured 10330 true vertical 9282.02 measured 10290 true vertical 9243.98 Length 81 2591 9579 1006 33 929 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 7" 29# L-80 4-1/2" 12.6# L-80 Measured depth: 9928 - 9940 True Vertical depth: 8900.09 - 8911.38 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Class: Development (;'¡ Stratigraphic L feet feet feet feet MD 34 - 115 33 - 2624 31 - 9610 9317 - 10323 9185 - 9218 9218 - 10147 9954 - 9974 8924.58 - 8943.5 3-1/2" 9.3# 4-1/2" 12.6# 5-1/2" 17# 7" 26# rn~ss Exploratory Service 182-2030 L: 6. API Number: 50-029-20874-00-00 9. Well Name and Number: 01-25 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) None 10325 ~{;!\NNE:t. .' TVD 34 - 115 33 - 2623.99 31 - 8613.1 8364.15 - 9275.37 8253.62 - 8281.2 8281.2 - 9107.98 Open Open Burst 1490 4930 6870 8160 8160 8430 Collapse 470 2670 4760 7020 7020 7500 L-80 L-80 L-80 L-80 8080 - 8124 9084 - 9184 27 - 9084 9184 - 9185 9-5/8" BOT External CSG PKR 5-1/2" Eclipse Patch Packer 5-1/2" Eclipse Patch Packer 5-1/2" Baker SB-3 Packer 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl o o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development R1 16. Well Status after proposed work: Oil (;' Gas 0 WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatu~ Form 10-404 Revised 04/2004 ~ 2129 8080 8118 9064 RBDMS 8Ft DEC 2 .2 2005 Tubing pressure o o Service WDSPl Title Data Mgmt Engr Date 12/16/2005 Phone 564-4424 Submit Original Only .. e e 01-25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY DATE SUMMARY 11/19/2005 ***WELL SHUT IN PRIOR TO ARRIVAL*** FISH IBP FROM 9,080' SLMD ***CONT ON 11-20-05 WSR*** 11/21/2005 ***CONT FROM 11-20-05 WSR**** PULLED IBP - MISSING ONE 6" ELEMENT RIG DOWN AND MOVE TO 13-31 FOR HOT JOB. ***TURNED WELL OVER TO DSO - LEFT WELL SHUT IN*** 11/22/2005 ***WELL SHUT IN PRIOR TO ARRIVAL*** RAN 2.25" THREE PRONG WIRE GRAB AND 4.5" BRUSH AND RECOVERED ONE ELEMENT FROM IBP PULLED ON 11-20-05 AND RECOVERED ONE ELEMENT FROM IBP PULLED ON 10/24/04. DRIFT W/ 2.5" CENT & SB TO TD @ 9988'SLM (HARD BTM - NO SAMPLE - ABOUT 25' OF RAT HOLE, OPEN BTM PERF @ 9974'MD). RAN PDS DEPTH LOG AS PER PDS PROGRAM. ***TURN WELL OVER TO DSO, \JIJELL LEFT SII*** FLUIDS PUMPED BBLS 2 I ::::L 2 ) fQJ 'T7~.', !;ì,~ ~ ftC, ":11', \:.~\ ¡ ¡ ,/ iJ~\ ¡ II il r riY~ il /.1 \\\ U.: [¡il.... _'} w" . , l~ :l. 'I ni /;i:~~~ ,r;::;"\, ill ~7" /j\\' II ¡'II~ \ ! ¡ i, ð' '~, II n...J ¡ I~', ! li~ \. I :¡\.\, 1 I' i I I \\ ! ,I :\ ,'~ ': ! U ~ ;11 i '/1\ 'II ," \. ¡ I' 1':\ \\ : I : \ ¡ i' / ,r.J-Jj \ .,'~ j ï \ / u \\ IJlJ Ilbil..ll \ ® U'Ui ¡ q FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alex Yancey Petroleum Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 \9S~y dÞ3 Re: PBU 01-25 305-216 Dear Mr. Yancey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd da following the date of this letter, or the next working day if the 23rd day falls on a ld y or weekend. A person may not appeal a Commission decision to Superior 'urt less rehearing has been requested. DATED this /1 day of August, 2005 Encl. .~CANNEù, }qU'~ 'f 1 Îl~lriç- ~, - .J.. ... U,J 1. Type of Request: C¡J¡ 13 -11--{)~ ~GA- ð'1 It I zooç ) STATEOFALASK~ff I "'rlls ALASKA Oil AND GAS CONSERVATION COMMISSION CJ:C' EIVED APPLICATION FOR SUNDRY APPROVA'f:- 20 AAC 25.280 AUG 1 0 2005 Abandon D D D Suspend D Repair Well D Pull Tubing D Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: Alter Casing Change Approved Program 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 7. KB Elevation (ft): P.O. Box 196612 Anchorage, Ak 99519-6612 8. Property Designation: ADL-028329 11. Present Total Depth MD (ft): 10330 Casing CONDUCTOR SURFACE PRODUCTION LINER SCAB LINER SCAB LINER Perforation Depth MD (ft): 9928 .. 9940 9954 .. 9974 Stratigraphic 0 Service 0 9. Well Name and Number: 01-25 ,/ 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10290 9170.0 S~ MD ~D top 34 33 31 9317 9185 9218 74.00 KB Total Depth TVD (ft): 9282.0 Length 81 2591 9579 1006 33 929 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 7" 29# L-80 4-1/2# 12.6# L-80 Perforation Depth TVD (ft): 8900.. 8911.0 8925.. 8944.0 Packers and SSSV Type: 9-5/8" BOT External CSG Packer 5-1/2" Baker SB-3 Packer 7" Brown HY FLO II LNR/HGR 7" Brown TY PE H LNR Top Packer 4-1/2" Baker ECL Isolation Packer 5-112" Eclipse Patch Packer 5-1/2" Eclipse Patch Packer 12. Description Summary of Proposal ŒJ Detailed Operations Proç:¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: August 23, 2005 Development ŒJ perforateDA\aska Oil &~8€£~s. Comm~~~p[!] StimulateD Time Ext~[!peCONVERT TO INJ Re-enter Suspended Well D 5. Permit to Drill Number: 182-2030 ~ / Exploratory 0 6. API Number /' 50-029-20874-00-00 Plugs (md): Junk (md): 9150 (6/25/05) 10013 (10/24/04) Burst Collapse bottom top bottom 115 34.0 115.0 1490 470 2624 33.0 2624.0 4930 2670 9610 31.0 8613.1 6870 4760 10323 8364.0 9275.4 8160 7020 9218 8253.6 8281.2 8160 7020 10147 8281.2 9108.0 8430 7500 Tubing Size: Tubing Grade: Tubing MD (ft): 5-1/2 " 17# L-80 27 9084 4-112 " 12.6 # L-80 9084 9184 7 " 26 # L-80 9184 9185 Patch 3-1/2" 9.3 # L-80 8080 8124 Packers and SSSV MD (ft): 2129 9064 9207 9212 9986 8080 8118 13. Well Class after proposed work: Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD ~ Service 00 Abandoned D 16. Verbal Approval: Date: WAG D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ø;;"1:( /' ¿ /.. / Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Printed Name Signature GINJD WINJŒ] WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Contact Alex Yancey Title Phone Petroleum Engineer 564-5092 8/9/05 Mechanciallntegrity Test ~ Location Clearance D Sundry Number:-?_ J [ ~5-2¿-ì z..IC: ~~ RBDMS BFL AUG 15 2005 BY ORDER OF THE COMMISSION Date: ¢//or SUBMIT IN DUPLICATE ,1 ") ) /L August 1, 2005 RECEIVED AUG 0 3 2005 Alaska 0;1 & Gas Cons. Commission Anchorage Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RE: Sundry Notice for 01-25 --- Conversion from Production to Injection BP Exploration Alaska, Inc. proposes to convert well 01-25 to a Sea Water injection / well. Step Type Procedure o LNFT-IA 2 S Pull Tubing Tail Plug 3 0 Conductor Top Job (cement conductor) Well 01-25 is currently having its surface facilities converted to water and injection service. The objective of the conversion is to provide pressure support to current producers, improve volumetric sweep efficiency, and to mobilize and capture remaining oil saturation above the GOC (Updip Zone 4 injection). This program is consistent with a larger regional strategy to manage and develop the GDWFI area in a manner that considers the maturity of the waterflood areas, the maturing of the GD process and the possible impact of gas sales on overall recovery. Included is the Cement Bond Log from well 01-25 (03-14-1983). The top of the cement is above the 9-5/8 production string shoe, and the top of Zone 4 is at 9724. The nearest offset / wells are 01-15A, 01-13, and 01-10 and their bottom hole locations are beyond 1320 ft from well 01-25. 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ELEV ==.tI BF:-ELEV == KOP= Max Angle = Datum MD = Datum TVD = FMC FMC AXELSON 74' 3000' 35 @ 6300' 9900' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 Minimum ID = 2.977" @ 80941 51/2" AVA DWP 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 I TOP OF 4-1/2" TBG-PC 1-1 '4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 I TOP OF 4-1/2" LNR 1--1 DATE 03124/83 03/03/90 05/08/01 05/31/02 06/04/03 07/13/03 PERFORA TlON SUMMARY REF LOG: BHCS ON 02/21/83 ANGlEATTOPÆRF: 31 @ 9610' Note: Refer to Production DB for historical perf data SIZE SPF INTERV Al Opn/Sqz DA TE SEEPAGE2 FOR PERF BREAKDOWN I TOP OF 7" LNR 1-1 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 7" LNR, 29#, l-80, .0371 bpf, ID = 6.184" 1-1 ~-I REv BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RNlKAK CORRECTIONS KAK PERF CORRECTIONS KRBfTLP ÆRF CORRECTIONS TGlKAK SET BKR IBP "') 2624' ~ 9084' 9084' 9184' 9219' 01-25 g g &, ;g - L c L R g ~ ~ ST MD TVD 1 2918 2916 .~ 2 5022 4768 ' 3 6547 6030 4 7471 6798 *5 8098 7340 6 8204 7432 7 8741 7887 8 8847 7974 STI MD TVD 9 8955 8063 2129' 2176' '\ ) SAFETY NOTES: 8 I " ., ,/- 1-113-3/8" X 9-5/8" BOT EXTERNAL CSG PKR 1 1-15-1/2" CAMeO BAL-O SSSV NIP, ID = 4.56" 1 GAS LIFT MANDRB.S DEV TYPE VlV lATCH PORT DATE 8 ""MMG RK 33 MMG RK 34 MMG RK 34 MMG RK 33 MMG RK 33 MMIG RK 29 MMIG RK 29 MMIG RKP 'CHEMICAL MANDR8.S DEV TY PE VL V LATCH PORT DA TE 29 MMG-l TS-R RK *8094' 1- 5-1/2" A V A DWP RETRIEVABLE PATCH (SET 5-23-95) GUM5, ID = 2.977" 9064' 9084' 9100' 9173' 9184' 9185' l-i 9-5/8" X 5-1/2" BKR SB-3A PKR, ID = 4.875" 1 1-1 XO MILLOUT 8<T X 4-1/2", ID = 6.625" I 1-1 BKR IBP SET 11/04/04 1 1-1 4-1/2" OTIS XN NIP, ID = 3.72" I 1-1 4-1/2" X 7" XO, ID = 3.90" 1 I--L 7" MULESHOE JOINT, ID = 6.276" ~ 9207' 1- 9-5/8" X 7" BROWN HY FLO II LNR/HGR, ID = 6.184" 9212' 1- 7" X 9-5/8" BROWN TYPE H LNR TOP PKR, ID = 6.196" 9218' 1-1 7" X 4-1/2" XO, ID = 3.958" I 9317' J I~ 9610' a 10323' ~8 ~ 1~/1 ~ I 9986' I.., 7" X 4-1/2" BKR EeL ISOLATION PKR, ID = 3.958" 1 10147' 1-14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 10325' 1- 1/8" X 1" X 6" PIECE OF CENTRALIZER SPRING (LEFT 06/10/94) DA TE REV BY COMMENTS 09/25/04 CAOrrLH IBP DEPTH CORRECTION 11/04/04 MDCIll..P SET 2-1/2" BAKER IBP PRUDHOE BAY UNIT WB.L: 01-25 PERMIT No: 1822030 API No: 50-029-20874-00 SEC7, T10N, R15E, 2563.05' Fa & 2863.9' FNL BP Exploration (A,laska) ) ) MECHANICAL INTEGRITY REPORT' '.. :. .I G R E ~ E J._ S .:: : 21~llqis -. ~!24-llqfŠ OPER Ex FIELD -B ¡ì '", P g Vl 5?UD DA:Z: 'k"ELL NUMB ER () I - 2 S 7~~LL DATA rn: lo3"?o Jill.. Qlf2, TVD; :?BTD: 102.QO HD q /70 TVD Casi~g: ~ 5/ 1/ qfo t (:) ~lo I "? 1 ~ f' Shoe: HD TVD i DV: MD ·Tvu .:...:":1e::-: 7 ,.. Shoe: 10 'S z. ~ MD 9 t 7 )'. TVD ; :OF: 9?/7 HD f~fo4 ;:"'['"0 4 '( II qq .¡ ¿, 10147 :-.Joi:;g: ~ t P 2.cke.r MD T"fD i Set ê.t ::ole. S :'z e It ~ II t II f- 'I L .) c¡q 2 f ~q74 ana Perfs to :-SCP"þ24IC;..L INTEGRITY - PlŒ.T ¡ 1 Annulus Press Test: ~p 15 m~n 30 min Comaents: M IT I-<D M N'd ~ :-Œ:CH.tÜqICAL INTEGRITY - PART ¡ 2 [.... Cement: Volumes:' þ...mt_ Liner ~ 00 S/¿ ; Csg ;)00 SJL, j DV C¡:¡¡t 701 to cove:!:' per::s Ilf ,c.~IL +'~OO'@ so7, øf-c..ç.ç::. Theoret:ical TOC ¡Z2e¡ I Cement Bond Log (Yes or No) 1.1 ; In AOGCC File' v CBL =:valuation, ::one 2.DOVe perfs 4c{¿('"( G-01..7r- b t/L-\ J.; IV:', It'"\. I l Þ ~! fi/~ C ,,~,..·t.c¿ i-O 0\ / {) 'v' (J C[ - ç / f ') ç. ¿~.e ' Prociu~tion Log: Type ¡Evaluation , - . ! ! CONC;LUSIONS: ? art: n: AliI T 1--<'1 IA/¡' ¡..'"'" J ? ar:: : z: ~ t- 1/ rtJ /. ) () e,W\. t 1 ¿'-".J I,.>" ¡I ,j¡ c<,c-! -t }1-( -t! Lw./r" It)\ i.,.<^" ;.:..; 4r / w tied f/Jl/wo'5, i/ NO vJpll~ "v'J-J.t.J r- /\-0 ~ I' \¡JG~' , . ... - ~ -- ) ) Ir2-203 FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL A1Q) GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alex Yancey Petroleum Engineer BP Exploration (Alaska) Inc. 900 E. Benson Blvd. P.O. Box 196612 Anchorage, AK 99519 Re: Your request to convert PBU Well 01-25 to injection service. Sundry Number: 304-472 Dear Mr. Yancey: AOGCC hereby denies your application to convert PBU Well 01-25 to injection service. This denial is without prejudice. If you wish to resubmit this application, please include with your submittal the following information in support thereof: (1) a copy of the subject well's cement quality log(s), and (2) a list of all well penetrations within a one quarter-mile radius (the Area of Review) of the subject well's proposed injection zone. AOGCC appreciates your attention to this matter. ~in~ ~~I T. Seamount, Jr. Commission DATED this~day of December, 2004 Enc!. SCANNED DEC 1 3 2004 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: 2004 Suspend D Repair Well D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: ;,¡ '. . PerforateD waiverG:r:'~';Ânlì~ìår DisJb~áiI:r¡ StimulateD Time ExtensionD '.. OtherŒl Re-enter Suspended Well 0 Convert to Inj 5. Permit to Drill ~umber: 182-2030 / BP Exploration (Alas' ka), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-661 7. KB Elevation (ft): 74.00 KB 8. Property Designation: ADL-0028329 Development Œ] Stratigraphic D 9. Well Name and Number: 01-25 /' 10. Field/Pool(s): Prudhoe Bay Field / Pru PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Dept 10290 11. Total Depth MD (ft): 10330 Casing Total Depth TVD (ft): 9282.0 Size Length MD top bottom p 34 11 34.0 9185 18 8253.6 9218 0147 8281.2 9918 9971 8890.7 31 9610 31.0 33 2624 8890.7 Tubing Size: 4 " 9.5 # 4.5 " 12.6 # 5.5" 17# 7 " 26 # bottom 115.0 8281.2 9108.0 8940.7 8613.1 8940.7 Tubing Grade: L-80 L-80 L-80 L-80 Conductor 81 20" 91.5# H-40 Liner 33 7" 29# L-80 Liner 929 4-1/2" 12.6# L-80 Liner 53 3-1/2" 9.3# N-8f Production 9579 9-5/8" 47# L-8C Surface 2591 13-3/8" 72#'L-30 i Perforation Depth MD (ft): Perforation Depth TVD ',i~ 9928 - 9931 8900.09 - j 8902.9 9931 - 9936 8902.91 8907.6 9936 - 9939 8907.62 t- 89~0.4 9939 - 9940 8910.44 8911 9954 - 9974 8924.58 89 .5 Packers and SSSV Type: r . / ~ 3-1/2" Baker F-1 B Prod Packer {\ / ~ 4-1/2" Baker ECL Isolation packer. . /.' 5-1/2" AVA-DWP Patch Packer. I \ ~ 5-1/2" AVA-DWP Patch Packer ~.. ;/ I\..J' 5-1/2" Baker 8B-3 Packer '. / " 7" Baker H Packer / 12. Attachments: Description Summary 0 r~sal D Detailed Operations Program D 14. Estimated Date for Commencing Operation: Packers and SSSV MD (ft): 13. Well Class after proposed work: ExploratoryD DevelopmentD 15. Well Status after proposed work: Oil D GasD WAG D GINJD PluggedD AbandonedD WINJŒ] WDSPLD Prepared by Garry Catron 564-4657. Alex Yancey 16. Verbal Approval: Commission Representa 17. I hereby certify th th ore ing is true and correct to the best of my knowledge. Contact 1 ~n#fLU-1 Title Phone Petroleum Engineer 564-5092 Commission Use Only Notify Commission so that a representative may witness Plug Integrity D BOP TestD Mechanciallntegrity Test D Location Clearance D RBDMS BFL DEC 0 6 2004 Other: Subsequent Form Required: 6. API Number / 50-029-20874-00-00 Plugs (md): Junk (md): None 10013 Burst Collapse 1490 8160 8430 10160 6870 4930 Tubing MD (ft): 8094 9084 27 9184 470 7020 7500 10530 4760 2670 8124 9184 9084 9205 9918 9986 8094 8118 9064 9212 Service Œ] 11/11/04 Sundry NumhM' 3oLj-lfp.. . - - ( Approved by: Form 10-403 Revised 06/2004 ORIGINAL BY ORDER OF THE COMMISSION Date: SUBMIT IN DUPLICATE TREÊ = . WEl.LHEAO'= ACTUA TOR = KB. ELEV = .r, BF:-ELEV = KOP= Max Angle = Datum MD = Datum TVD = FMC FMC AXELSON 74' ) 3000' 35 @ 6300' 9900' 8800' SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1--1 2624' Minimum ID = 2.977" @ 8094' 51/2" AVA DWP 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" 1--1 I TOP OF 4-1/2" TBG- PC 1--1 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1--1 I TOP OF 4-1/2" LNR 1--1 DATE 03/24/83 03/03/90 05/08/01 05/31/02 06/04/03 07/13/03 9084' 1 9084' 9184' 9219' ÆRFORA TION SUMMARY REF LOG: BHCS ON 02/21/83 ANGLEATTOPÆRF: 31 @ 9610' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE SEE PAGE 2 FOR PERF BREAKDOWN I TOP OF 7" LNR 1--1 9317' 1 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9610' 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1-1 10323' OÐ-t 10330' 01-25 g 8> ~ L ~ 2129' 2176' C L 5<- & ~ ST MO TVO 1 2918 2916 ~ 2 5022 4768 3 6547 6030 4 7471 6798 *5 8098 7340 6 8204 7432 7 8741 7887 8 8847 7974 ST MO TVO 9 8955 8063 ) SAFETY NOTES: & & :8: ~ ~ I . " / . 1--113-3/8" X 9-5/8" BOT EXTERNAL CSG PKR 1 1--15-1/2" CAMCO BAL-O SSSV NIP, 10 = 4.56" 1 GAS LIFT MANDRELS OEV TYÆ VLV LATCH PORT DATE 8 MMG RK 33 MMG RK 34 MMG RK 34 MMG RK 33 MMG RK 33 MMIG RK 29 MMIG RK 29 MMIG RKP CHEMICAL MANDRELS OEV TYÆ VLV LATCH PORT DATE 29 MMG-L TS-R RK 1 *8094' 1- 5-1/2" A V A OWP RETRIEV ABLE PA TCH (SET 5-23-95) GU,¡1#5 , 10 = 2.977" 9064' l-f 9-5/8" X 5-1/2" BKR SB-3A PKR, 10 = 4.875" 1 9084' 9100' 9173' 9184' 9185' 1--1 XO MILLOUT EXT X 4-1/2", 10 = 6.625" 1 1--1 BKR IBP SET 11/04/04 1 1--1 4-1/2" OTIS XN NIP, 10 = 3.72" 1 1--1 4-1/2" X 7" XO, 10 = 3.90" 1 1--1 7" MULESHOE JOINT, 10 = 6.276" 1 9207' 1- 9-5/8" X 7" BROWN HY FLO II LNR/HGR, 10 = 6.184" 9212' 1- 7" X 9-5/8" BROWN TYÆ H LNR TOP PKR, 10 = 6.196" 9218' 1--1 7" X 4-1/2" XO, 10 = 3.958" 1 I ~:8: ~ 9986' ~ ~ 10147' I ~ I 10325' REV BY OA TE REV BY COMMENTS 09/25/04 CAOITLH IBP DEPTH CORRECTION 11/04/04 MDClTLP SET 2-1/2" BAKER IBP COMMENTS ORIGINAL COM PLETION LAST WORKOVER RN/KAK CORRECTIONS KAK ÆRF CORRECTIONS KRBITLP ÆRF CORRECTIONS TG/KAK SET BKR IBP 1--17" X 4-1/2" BKR ECL ISOLATION PKR, 10 = 3.958" 1 1--14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1 1- 1/8" X 1" X 6" PIECE OF CENTRALIZER SPRING (LEFT 06/10/94) PRUDHOE SAY UNIT WELL: 01-25 ÆRMIT No: 1822030 API No: 50-029-20874-00 SEC 7, T10N, R15E, 2563.05' FEL & 2863.9' FNL BP Exploration (Alaska) TREE = FMC ) 01-25 WELLHEAD = FMC ACTUA TOR = AXELSON KB. ELEV = 74' PERFS " BF. ELEV = ,",' KOP= 3000' g g Max Angle = 35 @ 6300' Datum MD = 9900' fa DatumTVD = 8800' SS .4 l ~ L g g Z C K & Z ÆRFORA TION SUMMARY REF LOG: BHCS ON 02/21/83 ANGLE AT TOP PERF: 31 @ 9610' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 9610 - 9612 S 03/04/83 3-3/8" 9778 - 9796 S 09/15/89 3-3/8" 4 9806 - 9812 S 12/03/96 3-3/8" 9822 - 9824 S 03/04/83 3-3/8" 9861 - 9863 S 03/04/83 3-3/8" 9890 - 9900 S 07/03/93 9908 - 9914 S 07/03/93 9920 - 9924 S 07/03/93 9928 -9940 0 02/19/97 9940 - 9944 S 12/03/96 9954 - 9974 0 12/12/96 9984 - 9990 S 07/03/93 9990 - 10010 L 12/03/96 10010 - 10073 S 06/03/91 10102 - 10104 S 03/04/83 ~ ~ . / I " 2-1/2" 6 2-1/2" 4 I I .4 ~ ~Z \ ~ DA TE REV BY COMMENTS 09/25/04 CAOfTLH IBP DEPTH CORRECTION 11/04/04 MDCITlP SET 2-1/2" BAKERIBP PRUDHOE BAY UNIT WELL: 01-25 ÆRMIT No: 1822030 API No: 50-029-20874-00 SEe 7, T10N, R15E, 2563.05' FEL & 2863.9' FNL COMMENTS ORIGINAL COMPLETION LAST WORKOVER RNIKAK CORRECTIONS KAK ÆRF CORRECTIONS KRBfTLP PERF CORRECTIONS TG/KAK SET BKR IBP REV BY DATE 03/24/83 03/03/90 05/08/01 05/31/02 06/04/03 07/13/03 BP Exploration (Alaska) . . STATE OF ALASKA ALASKA ,_.-AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown Stimulate Plugging Perforate X _ Pull tubing ~ Alter casing ~ Repair well~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec 8, T10N, R15E, UM. At top of productive interval 1020' SNL, 2376' EWL, Sec 18, T10N, R15E, UM. At effective depth At total depth 1112' SNL, 2556' EWL, Sec 18, T10N, R15E, UM. 5. Type of Well Development X Exploratory Stratigraphic Service ORIGINAL 6. Datum of elevation(DF or KB) 74' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10330 feet 9282 feet Plugs(measured) PBTD @ 10054' MD (12/3/96). Effective depth: measured 10054 feet true vertical 9019 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1895# Poleset 79' 79' Surface 2591' 13-3/8" 3000 Sx CS III & 400 Sx CS I 2624' 2624' Production 9579' 9-5/8" 500 Sx Class G & 49 Bbls CS I 9610' 8613' Liner 1011' 7" 300 Sx Class G 9317 - 10328' 8363 - 9280' Scab Liner 928' 4-1/2" 85 Sx ARC (Class G) 9219 - 10147' 8282 - 9107' Perforation depth: measured 9928 - 9940'; 9954 - 9974' true vertical 8899 - 8911'; 8924 - 8943' Tubing (size, grade, and measured depth) 451/2", 17#, L-80, PCT @ 9084' MD; 4-1/2", 12.6#, L-80, PCT @ 9184' MD. Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2176' MD; Baker SB-3A Pkr @ 90,64' MD; BOTH Pkr @ 9207' MD; Baker ECL Isolation Pkn@ ~986 MDt 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure Oil ~;, Gas Cons. Con-~rnission ,I..~LI I ~1 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production orlnjection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 32 397 1558 -- 154 i643 3268 -- 16. Status of well classification as: Oil X Gas Suspended Service Tubing Pressure 235 26O 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Engineering Supervisor Date -~ -.2..7 - ? 7 SUBMIT IN DUPLICATE 1 -25 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/1 9/9 7" MIRU & PT equipment. Added Perforations: Reperforated: RIH w/perforating gun & shot 12' of perforations as follows: 9928 - 9931' MD (Z4) Ref. Log: BHCS 2/21/83. 9931 - 9940' MD (Z4) Ref. Log: BHCS 2/21/83. Used a 2-1/2" carrier & shot the perfs at 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. "-" STATE OF ALASKA ALASKA ,.,,L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. Operation shutdown Stimulate Plugging Perforate X Pulltubing ~ Alter casing ~ Repair well Other X 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec 8, T10N, R15E, UM. At top of productive interval 1020' SNL, 2376' EWL, Sec 18, T10N, R15E, UM. At effective depth At total depth 1112' SNL, 2556' EWL, Sec 18, T10N, R15E, UM. 5. Type of Well Development X~ Exploratory Stratigraphic Service ~ 6. Datum of elevation(DF or KB) 74' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10330 feet 9282 feet Plugs(measured) PBTD @ 10054' MD (12/3/96). Effective depth: measured true vertical 10054 feet 9019 feet Junk(measured) Casing Length Conductor 79' Surface 2591' Production 9579' Liner 1011' Scab Liner 928' Perforation depth: Size Cemented Measured depth True vertical depth 20" 1895# Poleset 79' 79' 13-3/8" 3000 Sx CS III & 400 Sx CS I 2624' 2624' 9-5/8" 500 Sx Class G & 49 Bbls CS I 9610' 8613' 7" 300 Sx Class G 9317 - 10328' 8363 - 9280' 4-1/2" 85 Sx ARC (Class G) 9219 - 10147' 8282 - 9107' measured 9954 - 9974' true vertical 8924 - 8943' RECEIVED FEB 24 1997 ,,~,~.a,,O iJ ~.C~a~_6o rts..Commission1 Tubing (size, grade, and measured depth) 451/2", 17#, L-80, PCT @ 90 ..... u; ~-,/,-A~o~L-80, PCT @ 9184' MD. Packers and SSSV (type and measured depth) Camco BaJ-O SSSV @ 2176' MD; Baker SB-3A Pkr @ 9064' MD; BOTH Pkr @ 9207' MD; Baker ECL Isolation Pkr @ 9986' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1825 31601 98 Tubing Pressure 1613 Subsequent to operation 54 551 1798 221 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: OilX___ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ '734. ~ Title Form 10-404 Rev 06/15/88 Engineering Supervisor Date 2-'/3- 77 SUBMIT IN DUPLICATE~ I -25 CEMENT SQUEEZE FOR GAS SHUTOFF DESCRIPTION OF WORK COMPLETED 9/1/96: RIH & tagged PBTD at 10027' MD. 1 2/3/9 6: A CTU Cement Squeeze for Gas Shutoff was performed as follows: MIRU CTU & PT equipment. Loaded the wellbore w/1% KCI Water & RIH w/CT to bottom, then PU & pumped cement to squeeze the open perforation intervals located at: 9806 - 9812' MD (Z4) 9936 - 9944' MD (Z4) 9990 - 10010' MD (Z3) Ref. Log: BHCS 2/21/83. Pumped 40 bbls of Latex Acid Resistive Cement & placed 5 bbls of cement behind pipe at 3500 psi max squeeze pressure held for 1 hour. Contaminated cement w/biozan & jetted contaminated cement & fill from wellbore to 10054' MD. POOH w/CT. Rigged down. I 2/1 2/96: Added Perforations: 9954 - 9974' MD (Z3) Ref. Log: BHCS 2/21/83. Used a 2-1/2" carrier & shot the perforations at 4 spf at 180 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/lift gas & obtained a valid welltest. are being evaluated Future wellwork options GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I-I'N: Sherrie NO. 9778 Company: 10/5/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-16 '"'7' ~- ~ ~ ~' .PRODUCTION PROFILE 950922 I 1 D.S. 1-25 ~' ~ '7.--O~ PRODUCTION PROFILE 950924 I 1 D.S. 4-8 "~_~ ~ t (3 PERFO~NG RECORD 95 0 92 2 I 1 D.S. 4-37~ ~ (~ ~ PRODUC~ONPROFILE 950924 I 1 D.S. 7-2 ~ ~ ~ r ~ LEAK DETECTION LOG 950926 I I . D.S. 7-33 ~ ~ ~ EST 950922 I 1 D.S. 7-34 ~~ ~~RST 950923 I 1 ~ ,,, SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKA r"'"'-"-AND GAS CONSERVATION CC'-'-~ISSION REPORT SUNDRY WELL OPE,,ATIONS ,, 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1020' SNL, 2376' EWL, Sec. 18, T10N, R15E, UM At effective depth At total depth 1112' SNL, 2556' EWL, Sec. 18, T10N, R15E, UM 5. Type of Well Development Exploratory StratJgraphic Service 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10330 feet Plugs(measured) 9282 feet Effective depth' measured 10040 feet true vertical 9006 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1895# Poleset 79' 79' Sudace 2591' 13-5/8" 3000 sx CS III & 400 sx CS II 2624' 2624' Production 9579' 9-5/8" 500 sx Class G & 49 bbls CS I 9610' 8613' Liner 1011' 7" 300 sx Class G 9317-10328' 8363-9280' Scab Liner 928' 4-1/2" 85 sx ARC (Class G) 9219-10147' 8282-9107' Perforation depth: measured 9806-9812'; 9936-9944'; 9990-10010' true vertical 8786-8792'; 8907-8914'; 8959-8978' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9084' MD; 4-1/2", 12.6#, L-80, PCT tail @ 9184' MD Packers and SSSV (type and measured depth) Camco Bal-O SSSV @ 2176'; Baker SB-3A pkr @ 9064' MD; BOTH Packer @ 9207' MD; Baker ECL Isolation Packer @ 9986' MD 13. Stimulation or cement squeeze summary 14. RECEIVED Intervals treated(measured) see Attached Treatment description including volumes used and final pressure d U N 2 0 1995 Representative Daily Average Production or Iniectio'~iiJ~a~"" '~ ua, uu,~. 6ummissi0n OiI-Bbl Gas-Md Water-Bbl Casing PresAs~eh0r~' -;:* Tubing Pressure Prior to well operation 1404 23273 1224 1401 Subsequent to operation 1881 23019 222 1288 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~;'ogr nj~0-404'Rev 06,15,88 Title Engineering Supervisor ¢.¢.. K7 .IWP Date SUBMIT IN DUPLICATE~ 1-25 tt4sTALLATtOt~ -r~BtNG pAT-CH..,,-,o~ coMPLETED o~s'c'R~P~o" o~ ,,,~-- ~rom 8094' to 8115' MD (seal to seal}, across down. 5/2.3195' Rill & set a 2.977" iD AVA DWP 'i'ubing patch Rigged leaking GLM #5, in the 5-1/2" tubing at 8098' MD. pOOH. Returned the weft to production & obtained a va%id welttest- RECEIVED ,IUN 20 ]995 Alaska Oil & Gas Cons. Commission Anchor~: ,, GeoQuest 500 w. Intornational Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9507 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 6/6/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BI_ RF Sepia DIR MWD Disk D.S. 11-29i ~""-,,~ 951 92 DUAL BURST TDT-P 051 59 S 1 D,S. 2-19 "'"J 95193 DUAL BURST TDT-P 051695 1 D.S. 1-25 AVA PATCH SETTING RECORD 052395 I 1 D.S. 4-16 RSTB 052295 1 1 D.S. 5-26 PROD PROFILE 052295 I 1 D.S. 6-8 PROD PROFILE 051 895 I 1 D.S. 9-38 DUAL BURST TDT-P 052095 I 1 D.S. 9-,~. ~ TEMP SURVEY 052096 1 1 D.S. 11-35 RSTB 0521 95 I I Please sign and return one copy of this transmittal to Sherrie at tho above address. Thank you. Alaska Oil & Gas Co~ls. commission Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I-I'N: Sherrie NO.9296 Company' 3/2/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field' Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Mylar Disk D.S. 1-2~."~ LEAK DETECTION 021995 I 1 D.S. 4-1'~ TUBG PUNCHER REcoRD 021 895 I 1 , D.S. ~,~6~., . RESERVOIR SATURATION 0221 9.5 1 1 DiS..4~?.~6~ CNT-G 0221 95 I 1 D.S. 4-19'"o PERF RECORD 021795 I 1 D'i'S. 4-~3'~---] ' PERF RECORD 021 995 1 1 D.S. 4-4~''''''D I~ERF RECORD 021 395 1 1 D.S. 6-3,,,'Q.j)' PRODUCTION LOG 0221 95 1 1 D.S. 7-4A"',..~ PERF RECORD 021 595 1 1 D.S. 9-2,,,"'-.., f INFLATABLE .BRIDGE PLUG 021 795 I 1 D.S. 9-11 "'-,~ PERF RECORD 0218951 1 1 D.S. 9-45 '"'-.2- PERFRECORD 0220951 1 1 ..... D.S. 13-20~ INFLATABLE BRIDGE PLUG 021 795 1 1 D.S. 11-4 A"-.-..~ PROD PROF1LE ... 022095 I 1 D,S. 15-11-~. '~ PROD PROFILE 022095 1 1 ........... D,S. 18-1-.1,..., ~- DUAL BURST TDT-P 021895 I 1 g.,s.. ! 1-0.t4~.-' 95058 DUAL BURST TDT-P 021195 .... 1 D.~S. ~~'- q5 95057 DUAL BURST TDT-P 020595 .,1. ..... ,,, ,,, , , s's-$/'"/ 9~-/o7 g 1-13.2 SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. RECEIVED ~/~E: 3 1995 Alaska 011 & Gas Cons. Commission Thank you. Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1117.?F ~,.. E IV ATTN: Sherrie .... NO. 9264 Company: 2/22/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Anch0rag. e Field: Well Job # Log Description Date BL Prudhoe Bay Floppy RF Sepia Mylar Disk "D.S, 1-25 PATCH SETTING RECORD 020495 I 1 D.S. 1-22A DUAL BURSTTDT-P 020395 I 1 D.S. 11-11 PERF RECORD 020395 1 1 D.S. 9-38 INJEC PROFILE 020495 I 1 D.S. 9-45 DUAL BURSTTDT-P 020595 I 1 D.S, 9-45 RST 020495 I 1 D,S. 9-51 PROD PROFILE 020595 I 1 D,S, 16-4A RST 020295 1 1 D.S, 18-14 TUBING CUTTER RECORD 020595 I 1 D,S, 5-26 PROD PROFILE 020695 I 1 D.S. 5-28 PROD PROFILE 020695 1 1 D,S. 6-10 DUAL BURSTTDT-P 020795 I 1 D.S. 9-8 PERF RECORD 020695 1 1 D.S. 11-1"6 PERF RECORD 020395 1 1 D.S. 14-34 PERF RECORD 020795 I 1 ,,, SIGNED' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Schlumberqer GeoQuest , ;". 500 W. International Airport Road ~... Anchorage, AK 99518-1199 A'I-I'N: Sherrie RECEIVED kl~sk¢ 0il & Gss 00ns. Commission NO. 9211 Company: 1/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description BL RRSepia RFSepia Mylar D.S. 1-3 POGLM SE'I-I'ING RECORD (12-23-94) /1 -~1 D.S. 1-3 POGLM RECORD (1-3-95) v-1 vl D.S. 1-25 LEAK DETECTION .(1-3-95) v,-1 ~" 1 D.S. 3-27 BAKER IBP RECORD (12-31-94) ~'1 ,'"1 D.S. 4-7 ST I pERF RECORD (.12-3..0-94) . ,"1 ,'1 D.S. 4-22A. .... PROD PROFILE (12-26-94) ~'1 ~/1 .D.S..6-.4 PERF RECORD (12-25-94) ...... ..'1.. -'1 .D.S...6-14A ..... PERF RECORD (12-26-94) ,,,1 ,-'1 D.S. 9-4A ..... PERF RECORD (12.23-94) D.S, 9-30 ST ..... PERF RECORD (1-2-95) ¢1 . .. ~1' D.S. 9-32 PERF RECORD (12-25-94) ,/1 ,/1 D.S. 11-16""'S~'1 LEAK DETECTION (12-31-94) ,-"1 ~'1 .D..S...1.1-23A PERF RECORD (12-21-94) D..S. 13-15 ......... SBHPS & INJEC PROFILE (12-29-94) cT D.S. 13-33 LEAK DETECTION (12-30-94) I 1 D.S....1.3-33 .... BAKER INFLAT BRIDGE PLUG RECORD (1-3-95) "'1 /11 .... .DrS. 14-21 . . SBHPS & INJEC PROFILE (12-2.3~94) .... .-1 "'1 D.S. 15-7A DUAL BuRsT TDT-P (12-27-94) ,,Dr,,Sr,. 1..5-30 LEAK DETECTION (12-27-94) ¢1 ,-"1 D.S. 15-30 ... DUAL BURST TDT-P (CT/E-LINE) (12-30-94) /1 /1 D.S. 18-9A DUAL BURST TDT-P (12-22-9~) .... ,/1 D.S. 18-27 DUAL BURST TDT-P (CT/E-LINE) (12-29-94) . .. SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASK.C'-'",IL AND GAS CONSERVATION C~-'"IMISSION REPOR1 OF SUNDRY WELL OF=RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1020' SNL, 2376' EWL, Sec. 18, T10N, R15E, UM At effective depth At total depth 1112' SNL, 2556' EWL, Sec. 18, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service ORIGINAL 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10330' feet 9282' feet Plugs(measured) Fill @ 10040' MD (6/8/94) Effective depth: measured 10040' feet true vertical 9006' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1895# Poleset 79' 79' Sudace 2591' 13-3/8" 3000 s× CS III & 400 sx CS II 2624' 2624' Production 9579' 9-5/8" 500 sx Class G & 49 bbls CS I 9610' 8613' Liner 1011' 7" 300 sx Class G 9317-10328' 8363-9280' Scab Liner 928' 4-1/2" 85 sx ARC (Class G) 9219-10147' 8282-9107' Perforation depth: measured 9806-9812; 9936-9944'; 9990-10010' true vertical 8786-8792'; 8907-8914'; 8959-8978' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9084' MD; 4-1/2", 12.6~, L-80, PCT tail @ 9184' MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2176'; Baker SB-3A pkr @ 9064' MD; BOTH Packer @ 9207' MD; Baker ECL Isolation Packer @ 9986' MD 13. Stimulation or cement squeeze summary R E C E iV E D 14. Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Representative Daily Average Production or Injectiorl Data AUG 1 2 1994 Alaska 0ii & Gas Cons. C0mmiss Anchora,.j:~ Prior to well operation OiI-Bbl Gas-Md Water-Bbl 853 8651 869 1666 20190 624 Casing Pressure -- Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢ ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Tubing Pressure 923 986 16. Status of well classification as: Oil x Gas Suspended Service SUBMIT IN/DUPLICATE 11l:;~/11 r,r.' .l~:n .IWP I -25 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 6/8/94: RIH & tagged bottom fill at 10040' MD. 6/10/94: MIRU & PT equipment. RIH w/perforating gun & shot 6' of perforations as follows: Reperforated: 9806 - 9811' MD (Z4) Ref. Log: BHCS 2/23/81. Added Perforations: 9811 9812' MD (Z4) Ref. Log: BHCS 2/23/81. Used 3-3/8" carrier, shot 4 spf, at 180 degree phasing. Shot at balanced pressure. POOH w/perfgun. Rigged down. Returned the well to production & obtained a valid welltest. RECEIVED AUG 1 2 1994 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: June 21, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well i Log Date i Tool Type Number! (M-D-Y)~. 1-05ST i 6-13-94 -/ Dual Burst 1-06 i 6-13-94 !./ Dual Burst '5'q- ! 1-11 i 6-14-94 ]-' Perf Record 1-25 i 6-10-94 i/ PerfRecord 1-29 i 6-14-94 i~ Dual Burst ,: 1-30 ! 6-08-94 !.- CNL 3-02 I 6-07-94 ix Tubincj Cutter 3-19 i 6-05-94 i-/' Perf Record 4-36 i 6-11-94 i"' Per[ Record '~© i 5-11 i 6-11-94 i / Dual Burst '-;%~ i 9-15 ! 6-13-94 t ' IniPmf Scale 1 4-41 ! 6-12-94 i '-/Cutter Record 1 et' 15" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" I 5" 15" 9-18 i, 6-14-94 i / Ini Prof 1, 5" 9-25 i 6-i4-94 i / injProf i 5" -35 i 6-11-94 !/ Per[ Record ~o i 11-36 ! 6-07-94 !./ Per[ Record (-('.O ! 13-31 ! 6-09-94 i /'' Per[ Record !ql ! 13-35 i 6-09-94 i / Perf Record !r-:,_Z. /'! 14-03 i 6-15-94 I ~ Prod Log "~ 14-03 i 6-15-94 I ,- Dual Burst I eI' 1 5" I 5" I 5" 1 5" 1 5" 1, 5" 1,5" 7-02 i 6-6-94 i~ ProdProf I 1,1"&5" 18-02 i 6-12-94 ]/' Per[ Record ! 1, 5" 18-04 ! 6-12-94 i~- Duai Burst i 1,5" 8-19 ~ 6-10-94 j.-'l_eak Detection ~ 1, 1" & 5" 16-23 !. 6-13-94 i/Leak Detection 6-23 ! 6-10-94 i ~' Alpha Tubing Sch Sch Sch, Sch Sch Sch Sch Sch Sch Sch Sch Sch i Sch i Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch * The correct APl # for 1-05ST is 50-029-20076-00 Number of Records: E. DeGrey Distribution: Central Files ANO-8 Geology Exxon Mobil Phillips BPX State of Alaska ARCO Alasim, Inc. Is a Subsidiary of AtlanlJcRIchfleldCompany ARCO Alaska, Inc. Date' Subject- From/Location- Telephone' To/Location' P.O. Box 100360, , .norage, AK May 24, 1994 Transmittal #: ARCO cased hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94042 99510,~ ~, Well Number 1-25 6-15 Log Date (M-D-Y) O3-O6-94 ~ 02-22-94 Tape Type CNT-D CNT-D R un, t Contractor Footage 1,960010030- I Sch 1, 9311- 8801 Sch ~ Number of Records: 2 Distribution: Central Files Phillips BPX Exxon State of Alaska Please acknqwledge re, c; eipt by signing and returning a copy of transmittal. By: .J _ .. :.-'.. Date: -. ARCO Alaska, Inc, is a Sub$1dla~'y of AtiantlcRIchfletdCompany ARCO Alaska, Inc. Date- Subject: From/Location: Telephone: To/Location: P.O. Box 100360, A~--~orage, AK Mar 15,' 1994 Transmittal #: 94029 John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510.~ ~ l Well iLog Date1 Tool Type I Run, Contractor~ Number (M-D-Y) Scale root_ ~c~ ! 01-02 I 2-26-94 j Prod/Spin/TempI~,.~ 1, 5" Schlumber "~o--[[o ! 01-03 2-19-94 1 Prod~BS/Temp~'~e~'~ 1,5" Schlumber '~c~-i~ { 01-09 3-01-94 Tubin!t Cutter ~ 1, 5" Schlumber Or"+--i~';- ~ 01-11 2-27-94 Prod Prof/Spin~ 1, 5" Schlumber · ~riT.-c~ I 01-18! 2-23-94 Leak Detection ! 1, 1"&5" Schlumber ~7..-i?.b~ ! 01-25 ~ 3-06-94 CNL ! 1, 5" Schlumber ~--!L~r .~3-20A ~ 2-17-94 Perf ! 1, 5" Schlumber ;~03-20A f 3-03-94 Dual Burst '~¢'-~' 1, 5" Schlumber 03-32 f 2-26-94 Leak/Press/Tempi 1,2" Schlumber!Sc~-ql. oo ~- !O~ I 03-34A i 2-24-94 Pmd/Press/Temp 1 2"&5" c~2"' L°~ f , Schlumber H?" I 04-01 ~ 2-19-94 Prod ! 1, 5" Schlumber ~:~* ~ 04-24 ! 2-22-94 Prod i 1,5" Schlumberl [l, bbO'"tVL~'U~ ct\_ [~t{ i 04-40 ! 2-22-94 Perf ! 1,5" Schlumber orb- ~_~'-4- i 04-46 . 2-16-94 Rope Perf ~ 1, 5" Schlumber ol~[- ~ i/04-47 ~ 2-18-94 v Perf ~ 1,5" Schlumber ~ 04-47 i '2-15-94 '/CBT-GR ! 1, 5" Schlumber 1~,04-47 i 2-15-94 vCET-GR 1, 5" Schlumber ;P~-~0 i 05-06 ~ 2-11-94 Perf 1, 5" Schlumber ct ~2-- i 05-14A I 7-11-93 USIT/Cem&Corr (.F.~'~I, 5" Schlumber c~! ~. I 05'15A t 05-15A ~G. ND/GR-L-~ 1, 5" Schlumber ~t;~- lt'~ l 05-26 3-02-94 Dual Burst 'l'cr~' 1, 5" Schlumber ~- ~,"z. F06-15 2-21-94 Prod 1, 5" Schlumber IX0066.~125A 2-22-94 Comp Neutron 1, 5" Schlumber 5~- 3-01-94 Perf 1, 5" Schlumber ~1o 07-08 3-02-94 Prod~~.~ 1, 5" Schlumber 07-23 3-07-94 Leak/Spin/Temp//j~ 1, 5" Schlumber ~- ' 09-34 2-21-94 Tubin!] Cutter ~ 1, 5" Schlumber ~t- FL~ 11-02 2-10-94 Inj Pmf/_~~f~, 5" Schlumber '~0-~O /11-04 2-20-94 Tubing Cutter ~..-- ,5" Schlumber i~,~11-04 2-17-94 Tubing {)V,~ [~ l~4.1, 5" Schlumber 15 ~- t-'Jr~ 11-7ST i 3-06-94 Inj Pmf/Spin ~ '('~ 1, 5" Schlumber / 11- I 2-25-94 Leak/Press/Temp 1, 1"&5" Schlumber ~- ~, 16ST /Spin//~C.~b~ ~-t~ IX~111'6ST !3.08.94 Comp/l~l~table IZoCo---17.\~,01'5" Schlumber ~(o-- ~ [/¢11-17 ~ .2-20-94 Leak 1, 5" Schlumber P...11-17 f 3-08-94 Prod 1, 5" Schlumber ~(~- ~[% 11-23 I 8-09-91 TMD 1, 5" Halliburton et%-- 2Duc /11-24A ! 3-05-94 Perf/GR/CCL 1, 5" Schlumber ' ~.!1-24A [ 2-22-94 Comp/Perf [ 1, 5" Schlumber ARCO Alaska, Irt¢. Is · 14-2B 14-2B 12-01 3-06-94 ! Prod i 1, 1"&5" 13-10 2-24-94 i Perf i 1, 5" , 1-16-94 i CNL/GR i. 1, 2"&5" 14.-2B 14-2B 14-2B 1-16-94 ! Sub-Sea i 1, 1"&2" 1 - 16-94 1-16-94 1-19-94 1-23-94 i BH~ Acoustilo9/4¢-. 1, 2"&5" ! DualLaterloCGR/? 1, 5" j Secj Bond/GRfc%.. 1, 5" i PFC/GR/CCL i 1, 5" Schlumber Schlumber Schlumber Schlumber Schlumber 14-2B .14-2B 1-23-94 i PFC/Collar i 1, 5" Schlumber 14-24 2-19-94 Schlumber i 14-34 Lea~ i 1, 5" Leak i 1 1"&5" Prod/Press/Tempi 1, 2"&5" 14-28 3-05-94 2-15-94 3-07-94 i Prod Prof/Spin ! 1, 2"&5" 2-24-94 i Perf i 1, 2"&5" i Water , I nj/FBS/Templ¢'¢¢{ 2-09-94 1, 5" 16-08 i 17-21 6~ i PWDW ~ ! 02-01 Well 4-24 the correct APl # is 50-029-21508-00 Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Z. Number of Records: eGrey - Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon 'State"of Alaska Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: . /~"~0/~ /,~--~ ~?~ Date: RECEIVED ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: ~2~ 3-q 1-18 ~7____%Za ~_1-25 ~--/~_U 2-22 ~ 3-4 ¢O--'qT.. 4-1 -*'-e~ 58 4-1lA ~!l~i!O _5-28 '9S'- ~0 /'9-1 '~9-29 ~-36A ~-36A ~l-13A 4-1 5-9A ~6-17 ~6-23 ~~ ~6-~9a 1-3-94 ARCO CASED HOLE FINALS 12-18-93 12-12-93 12-03-93 12-17-93 12-05-93 10-22-93 12-20-93 12-11-93 12-06-93 12-13-93 12-14-93 12-11-93 12-14-93 12-10-93 12-20-93 12-15-93 12-5-93 12-9-93 12-19-93 12-13-93 12-17-93 12-17-93 12-07-93 12-06-93 12-14-93 12-5-93 12-9-93 12-4-93 12-10-93 12-18-93 CNL (Cfi) l~'2,.?..o~to~O Run Leak Detect J~(~ r(.o.p] fr¢5~/~ Run Perf Record ~'~(~0 --105oo Run Prod Profile I ~0(0 ~a'clo }/~J>}6 ra~Run Perf Record ~O\~ia~ -[Iqllb ' Run TDTP (depth corrected) Run ~nj Profne I¢~,~ )'[~¢lPceS~ ~n Perf Record 12.oqo---/7.Zq 0 Run Perf Record ~la%0 -~j$c~O Run Perf Record ~ oo o 0 -- I 1.¼00 Run Dual Burst TDT-P (ih') . Run Prod Proflle~f,a ~¢],~¢%)?.ce} Run 1, 5" Sch 1, 5" ~?oa - q2~9c Sch 1, 5" Sch 1, 5" ctc.~0o ~{e0zO Sch 1, 5" $ch 1, 5" ~'C0o -- ~55a Sch I, 5" I t00o --t'L-bqo Sch 1, 5" $ch 1, 5" $ch 1, 5" Sch 1, 5" q"~O -R~-2-% Sch 1.5"q%a~fi/a Sch Perf Record ~%08--~%'00 Run 1, 5" Sch Dual Burst TD~Y-P 1[5 [. Rrm 1 5" ~0U?O .-i0~q t Sch ~/, ~. ,-~ ~, ~ ..... I,.,' ' "~'- '~ ~t ~' '2,~ Producaonl~i~¢ ~ .~o,~: :,~,,~c~i~ 1, 5 -, ~ t u . ,~ c.... ~. Sch Prod Profll~ ,~i,a } ~)~t~o~ 1, 5" ~7 ~C'~'i c C Sch M~ Detect/:?res ;~(5 ~ ~(~ ~ ?~t~ 1, l"&5' ~c o - t~Sah tc ~'~o MI In ~oflle 5¢,Qf~'¢Jvc¢~l~ ~1 5"qt~C ~q'-' ~ ~ Sch CNL } C~T~ ~a30 ~qq$ ~ 1, 5" Sch Dui Brat ~T-P/GR ,. _ ~ 1, S' q050-~iq q~ Sch ~G CuEer fl~0 ~~ ~ 1, 5" Sch ~ Detecaon I~fe5~ ~fl 6~a ~ 1.~&5"~--It~.o Sch · Peff Reeo~ llgo0-iZlt~ ~1,5' Sch 10-19-93 TDTP (depth corrected) Run 1, 5" Please sign and return t~e attached cgpy ~ ~ceipt of dam. RECEIVED ' .BY__.~4~~.~'~¢_._~ : John E. DeGrey ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA APPROVED Trans# 94002 The correct well name is 4-1lA and the corrected API# is 50-029-20286-01 The correct well name is 4-31 and the corrected API# is 50-029-21334-00 - The correct well name is 18-29A ~_nd the corrected APl# is 50-029-22316-01 STATE OF ALASKA ALASKA ' AND GAS CONSERVATION C("-"-~IISSION REPORT UF SUNDRY WELL OPP. RATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing AItercasing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 10330' feet true vertical 9282' feet Effective depth: measured 10045' feet true vertical 9011' feet Casing Length Size Conductor 80' 20" Surface 2591' 13-3/8" Production 9579' 9-5/8" Liner 1011' 7" Scab Liner 948' 4-1/2" Plugs(measured) Fill @ 10045' MD (8/8/93) Junk(measured) Cemented 1895 # Poleset 3000 sx CS III & 400 sx CS II 500 sx Class G & 49 bbls CS I 300 sx Class G 85 sc ARC (Class G) Measured depth True vedicaldepth 79' 79' 2624' 2624' 9610' 8613' 9317-10328' 8363-9280' 9199-10147' 8265-9107' Perforation depth: measured 9936-9944'; 9990-10010' true vertical 8907-8914'; 8959-8978' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9084' MD; 4-1/2", 12.6#, L-80, PCT tail @ 9184' MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2176'; Baker SB-3A pkr @ 9064' MD; BOT "H" Packer @ 9207' MD; Baker ECL Isolation Packer @ 9986' MD E 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Representative Daily Averaqe Production or Injection Data 0il & Gas Cons. Co[.nmission Anchorage Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations OiI-Bbl Gas-Md Water-Bbl 770 ~ ' 11096 762 1770 ./'/' 3717 326 Casing Pressure -- Tubing Pressure 2026 237 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~.~L ~ Title Engineering Supervisor Form 10-404"Rev 06/15/88 tt't~q/~ r~rcrcl~ttl_l~ r-,-,- .qW .IWP SUBMIT IN DUPLICATE I -25 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF & FOAMED ACID STIMULATION 7/11/93- RIH & tagged bottom at 9784' MD. 7/13/93: An Acid Wash & CTU Cement Squeeze for Gas Shutoff, were performed as follows: MIRU & PT equipment to 4000 psi. RIH w/CT & loaded wellbore w/1% KCl Water & Crude, then reciprocated an acid wash across the perforation intervals at: 9807 - 9811' MD (Z4) 9908 - 9915' MD (Z4) 9920 - 9924' MD (Z4) 9931 - 9939' MD (Z4) 9940 - 9944' MD (Z4) 9984 - 10010' MD (Z3) Ref. Log: BHCS 2/21/83. Jetted 75 bbls 1% NH4CI Water, followed by 50 bbls 15% HCI w/10% Xylene @ 2.3 bpm, followed by 50 bbls 15% HCl w/20% Xylene @ 2.3 bpm, followed by 53 bbls 9% HCl - 1% HF, followed by 225 bbls 1% NH4Cl Water displacement, then switched to cement to squeeze the perforations above. Pumped 28 bbls Latex Acid Resistive Cement & placed 5 bbls of cement behind pipe at 3200 psi max squeeze pressure, held for 1 hour. Contaminated cement w/biozan & jetted contaminated cement from the wellbore down to 10027' MD. POOH w/CT. Rigged down. 7/15/93 & 7/22/93' RIH w/CT & jetted through cement bridges encountered in the tubing between 8181' to 9998' MD. 7/27~93 - 8/2~93- Made several runs w/CT mounted milling assembly & milled cement from 9918' to 10048' MD, while circulating cuttings from the wellbore w/biozan gel. 8/8/93 · Reperforated: 9936 - 9944' MD (Z4) 9990 - 10010' MD (Z3) Ref. Log: BHCS 2/21/83. 10/3/93: MIRU & PT equipment to 4500 psi. Loaded wellbore w/224 bbls 1% KCI Water w/friction reducer, then pumped a Fullbore Foamed Acid Stimulation Treatment through the perforations (listed above). Pumped: a) 30 bbls 9% HCi w/10% Xylene & w/N2 injected @ 500 scf/stb, followed by b) 30 bbls 1% KCI Water @ 0.5 bpm w/N2 injected @ 1000 - 3500 scf/stb, followed by c) 7 bbls 9% HCI w/10% Xylene & w/N2 injected @ 500 scf/stb, followed by d) 24 bbls 9% HCl w/10% Xylene (without N2) @ 0.3 - 1.0 bpm, followed by e) 200 bbls 1% KCI Water @ 1.5 bpm, followed by f) 214 bbls Crude @ 1.5 bpm, followed by g) 10 bbls Diesel Flush, followed by h) Shutdown. Rigged down. RECEIVED 10/8/93: Pumped ESL Scale Inhibition Treatment. Returned the well to production & obtained a valid production test. ......... ,, ~ O.~s Cons. Commission Anchorage L' ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-9-93 REFERENCE: ARCO ~ HO~FINALS 1-5ST 8-14-93 1-24A 8-6-93 ~o51-25 8-8-93 ~5-~t</2-10 8-13-93 ~2-10 8-13-93 2-13 8-14-93 2-21 8-9-93 3-18A 8-9-93 4-4 8-6-93 4 -9 8-8-93 -9 8-11-93 4-38 8-16-93 R~9-29 8-14-93 11-9 8-5-93 11-22 8-15-93 12-28 8-7-93 12-30 8-11-93 13-12 8-11-93 14-13 8-15-93 /16-29A 8-7-93 /16-29A 8-8-93 qg-~ (~ t~ ~x 16-29A 8-9-93 "q6-29A 8-10-93 17-16 8-12-93 17-21 8-16-93 Production ~o%~ Perf Record i ~Tao~ Perf Record q0~0~ CNL ~oo-qoo I Prod ProfileeTUo Prod Profile ~,~0o-q$ Perf Record Perf Record ~75o~ Perf Record Inj Profile ~v-~ Production ~0 - Baker IBP ~%o- TBG Patch Set Record Leak Detect ~ - Perf Record~lz~ Run Run alln alln Rlln R1 ~n Rll'n R~_~n Rl11,1 R~n Run R~n Perf Record ~1070~ I lqeO Rl~n TBG Patch ~Y~u .--~,~o Rnn Inj Profile/S~-~e- Perf Record 1~Tvo- Microsetsmtc Survey Run I. nj Profile/%?t ~--ferrt'z'~9-ff>Rnn Microseismtc Survey Run Perf Record %~c~Tz~ Run Completionq%~o~Sao Run 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 2"&5" Sch 1, 5" q~- 1, 5" Sch 1, 5" Sch 1, 5" Sch 2, 5" ~qso- t~ 1, 5" o~h 1, 5" ~m0-lz~ h 1, 5" tm~>-- Schr~0 2, 5" ~-~so- Sch 1, 5" Sch 1, 5" Sch Please sign and return 9e attached copy/as re~t of data. RECEIVED BY~~ Have A Nice Dayl Sonya Wnllnce ATO-1529 APPROVED_ __ Trans~ 93100 # ~A~ OF ~ ~~? * The correct APl# for 1-5ST is 50-029-20076-00. ARCO ~l~qkn; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS ~~-~ ~ 2-21-93 Prod Profile Run 1, 5" 1-24-93 Alpha Patch CCI. Run 1, ~' 2-21-93 GR/Collar Run 1, ~' 221-93 InJ Profile ' l~_m 1, ~' 1-25-93 Static Temp Run 1, ~' 2.20-93 GR/Collar Run 1, ~' 2.20-93 Prod Profile Run 1, ~' 4ST 2-11-93 Prod Profile Run 1, ~' Please sign and return the attached copy as receipt of data. RECEIVED BY_~_~~ Have A Nice Day! Sonya Wallace APPROVED~'_~~./ ATO-1529 Trans# 9304~ --- Ca/nco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL ~ # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PI4~.rPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO The correct well name for this log is I-lB. RECEIVED MAR 2 6 ~993 Alaska 011 & Gas Cons, Commission Anchorage ARCO Alaska, Inc. P.O~Box 100360 Anchorage, ~l~slr~ 99510 DATE: 10-2-92 REFERENCE: ARCO CASED HOr.~ FINALS Per/ Run L 5" HLS Per/ l~m 1, 5" HLS Per/ Run 1, 5" HLS Per/ Run 1, 5" HLS Collar l~m 1, 5" HLS Per/ Run 1, 5" Per/ Run L 5" Per/ l~m 1, 5" Per/ Run L 5" HLS Per/ Run L 5" HLS Per/ l~m 1, 5" HLS Per/ Run L 5" HLS Per/ Run L 5" HLS Colla~ l~m L Per/ Run 1, Collar Run 1, 5" Per/ Run 1, 5" HIS Per/ Run 1, 5" ~rLs Per/ l~m 1, 5" HLS Per/ R,m 1, 5" HLS APPROVEDff~__ Trans# 9221~~'~--~ Please sign and return_~t~~ copy u receipt of dat~ RECEIVED~ Sonya Wallace OCT 0 5 1992 ATO-1529 AJaska 0il & Gas Cons. Commi~j.oj] # CENTRAL ~ora~ # CHEVRON # EXTENSION EXPLORATION # EXXON # MOBIL # PB WELL ~ # BPX # STATE OF ALASKA The ~ AP1 # fro' 1. Operations performed: .-.. STATE OF ALASKA ALASKA- '.AND GAS CONSERVATION RI=PORT SUNDRY WELL OPI=rlATIONS Stimulate Operation shutdown Pull tubing Alter casing Plugging Repair well Perforate :X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 80' Conductor 2591' Sudace 9579' Production 1011' Liner 948' 10330' MD feet 9282' TVD feet Plugs(measured) 10072' MD feet 9037' TVD feet Size 20" 13-3/8" 9-5/8" 7" 4-1/2" Junk(measured) Cemented 1895 #Poleset 3000 sx CS III & 400 sx CS II 500 sx Class G & 49 bbls CS I 300 sx Class G Scab Inr 85 sx ARC (Class G) RECEIVED S E P 1 0 1992 Alaska 0il & Gas Cons. Oornmissio~ Measure~a~rue vertical depth 79' M D 79' TVD 2624' MD 2624' TVD 9610' MD 8613' TVD 9317-10328' MD 8363-9280' TVD 9199-10147' MD 8265-9107'TVD Perforation depth: measured 9807-9811'; 9908-9915'; 9920-9924'; 9931-9939'; 9940-9944'; 9984-9990'; 9990-10010' MD true vertical 8788-8791 '; 8883-8886'; 8892-8896'; 8903-8910'; 8911-8914'; 8953-8959'; 8959'-8978' TVD Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9084' MD; 4-1/2", 12.6~ L-80, PCT tail @ 9184' MD Packers and SSSV (type and measured depth) CAMCO 'BaI-O' SSSV @ 2176', Baker 'SB-3A' pkr @ 9064' 13. Stimulation or cement squeeze summary Intervals treated(measured) Well was pedorated Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1018 8962 3 .. 1401-~( 11506 1079' I 16. Status of well classification as: Oil x Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~' ~ Title Senior Engineer Form 10-404 Rev 06/15/88 Service Tubing Pressure 1958 1739 Date ~//~Z.--. SUBMIT IN DUPLICATE REPORT OF WELL OPERATIONS DS 1-25 AP1 # 50-029-20874 PERMIT 82-203 ARCO Alaska, Inc. perforated the subject well within the Sadlerochit interval as follows' INTERVAL TVD. ZONE COMMENTS DATE 9990-10010 8959-8978 3 ADPERF 4-10-92 RECEIVED S E P 1 0 1392 Alaska Oil & Gas Cons. Cornmissior~ Anchorage STATE OF ALASKA ALASKA (;'-'"AND GAS CONSERVATION REPORT Or: SUNDRY WELL OP£ ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 10330' MD feet 9282' TVD feet 5. Type of Well Development Exploratory Stradgraphic Plugs(measured) 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 10072' MD feet true vertical 9037' TVD feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 80'._ 20" 1895 #Poleset 79' MD 79' TV D Conductor 2591' 13-3/8" 3000 sx CS III & 400 sx CS II 2624' MD 2624' TVD Surface 9579' 9-5/8" 500 sx Class G & 49 bbls CS I 9610' MD 8613' TVD Production 1011' 7" 300 sx Class G 9317-10328' MD 8363-9280' TVD Liner 948' 4-1/2" Scab Inr85 sx ARC (Class G) 9199-10147' MD 8265-9107'TVD Perforation depth: measured 9807-9811;9892-9896; 9910-9914; 9920-9924; 9940-9944; 9984-9990; 9998-10013; 10013-10073' MD true vertical 8788-8791; 8865-8869; 8883-8886; 8892-8896; 8911-8914; 8953-8959; 8966-8981; 8981-9038' TVD Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80 tbg w/tail @ 9192' Packers and SSSV (type and measured depth) CAMCO 'BaI-O' SSSV @ 2176', Baker 'SB-3A' pkr @ 9064' 13. Stimulation or cement squeeze summary Intervals treated(measured) Well was perforated Treatment description including volumes used and final pressure I ELE!V EL/ DEC - 9 1991 ~[~ ~0iJ .& L~as ~;0ns. L;0mm[ssi0n 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data ..... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1359 13230 16 -- 1521 15711 17 Tubing Pressure 2062 2018 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . .X. 16. Status of well classification as: Oil X_~_ Gas__ Suspended._. Service g is true and correct to 17. I hereby certify that the fore~l~ the best of my knowledge. Signed/")' ~~ ~/8-'5/8~~ Title Senior Engineer Form 10-404 Rev 06/1 REPORT OF WELL OPERATIONS DS 1-25 AP1 # 50-029-20874 PERMIT 382-203 ARCO Alaska, Inc. perforated the subject well within the sadlerochit interval as follows: INTERVAL [MD) TVD ZONE COMMENTS DATE 9807-9811' 8788-8791 4 REPERF 11-15-91 RECEIVED DEO- 9 1991 Alasl~ Oil & Gas Cons. ¢ommiss~Ot~ Anchorage 5 4 2 CO~LE'I) TU~I,N~ tRaIT 8C~ EOUIPHEN'i' 1. SO00 PSi 7" W[LL~ COM~CTOR IrLAhG[,. 2.~lO00 PSI 4 1/16" PIPE RAIDS " SO00 PSi 4 1/S" HYDRAULIC SLIPS 4.SO00 PSi 4 1/6" Slit. AR ~ 5.SO00 PSi 4 1/6" BLIND RAMS 6.SO00 PSi 4 1/16" sTurrm BOX 2 1. 5C)00 PSI ?" WCLLH~ CC)NN[C~OR rL~G[ 2. SO00 PSI WlR[LIN£ RAJAS (¥~RLA~BL[ SIZC) 3. SO00 PSI 4 1/6" LUI3RICA~C)R 4. SO00 PSI 4 1/6" fLOW TUBE: P,¢K-c)rr AF"co ALASKA, INC~ P~O~ ~OX ~~ - ANCHORAGE, ALASKA 995~ ('} DATE: · t t -.22-9 REFERENCE. ARCO CASED HOLE FINALS i i i 5-9i ~2 .'-'S t i t 7.-.~i ~t~? 4-3 ti-i f~ 6-9 i i---4-ei 9-S i i-9-.9i ~f 9--28 ~ i i-5-..~i .~ i 2-4-A~. i i-"i 4-'9i ~i S-98 ~ i~>-24-9i F'ERF RECORD CBT ( COLOR ) ULTRASONIC IMAGER-USIT (COL. OR) PFC CNi._-GR/[~CI_ CNi_-GR CC)LL. AR-F'ERF COLLAR-PERF C[)LL..AR-F'EF~F COLLAR-F'ERF F:'ERF RECORD DIT-E CNL. - EF'ITHERMAL. CNL. - THERH~I_ RECEIVED NOV 2 b 1991 Alaska 0il & Gas Cons. Commission Anchorage RUN i, RUN i, RUN t , RUN i , RUN i , RUN t, RUN i, RUN t , RUN t , RUN i, RUN i, RUN :37, RUN S7, RUN 37, SE;FI $ C H SCH ATLAS ATLAS S C H ATLAS ATLAS Al'LAS A'i-I_(~S SCH S C H SCFi $CH F'I...EASE SIGN AND F;:Ei'URN i"HE ATi"ACHED COPY AS RECEIPT OF DATA. RECEIVED BY __ ~ ~_~~.Z_ HAVE A NICF DAY! SONYA WAI_L. ACE ATO- i 529 AF'PROVIED~ '¥RANS:~ 9 RECEIVED D I 2 T R I B U "1" I 0 N :~ _ CEN'FF;..'AL F'iLEE$ ~: C H [:_' V R 0 N D &iq · ,-'"' E X TEN q' I 0 N,., E: X P L. 0 F.: A T I ri N.. , · ~EXXON i'.tARA TI-~ON · .-'"' fi 0 B I !.. :~ F' Fi I L I... :1: F:' ,.S' PB WEI...L. F:'IL.E:'.,.? I':,' & D :.": ~ ,':gTA'rE OF AI..ASKA i"EXACO Ti-II:' CORRECT AF']:f~ FOR i'2--4A I,S' 'S-O-029-20g84-,'-"J,i ~ NOV 2 b 1991 Alaska 0il & Gas Cons. Commission Anchorage ~. STATE OF ALASKA _~_ -. ALASKA t _ AND GAS CONSERVATION CO fISSION REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, T10N, R15E, UM Plugging Perforate X Repair well Other X 5. Type of Well Development Exploratory Straligraphic 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudho_e B~y,.,OjJ. P, oplm r- ~ ~ feet 12. Present well condition summary Total depth: measured true vertical 10330 feet 9282 feet Plugs(measured) Effective depth: measured 10072 feet true vertical 9037 feet Junk(measured) ~.UG 1 2 1991 AJas~ ~Ojl & Sas Cons. C0m~'tss'~e~ Casing Length Size Cemented Measured depth True vertical depth Structural 80' 20" 189,5ff Poleset 79' 79' Conductor 2591' 13-3/8" 3000 sx CS III & 400 sx CS II 2624' 2624' Sudace 9579' 9-5/8" 500 sx Cl G & 49 bbls CS I 9610' 8613' Production 1006' 7" 300 sx Cl G 9317-10323' 8363-9275' Liner 948' 4-1/2" Scab Inr85 sx ARC (CI G) 9199-10147' 8265-9107' Perforation depth: measured 9908-9910'; 9910-9915'; 9920-9924'; 9931-9939'; 9940-9944' true vertical 8881-8883'; 8883-8887'; 8892-8896'; 8903-8910'; 8911-8914' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9084' MD; 4-1/2", 12.64t, PCT tail @ 9184' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2176' MD; Baker SB-3A packer @ 9064' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 430 -" 3394 3108 -- Subsequent to operation 1391 -" 10409 0 -- Tubing Pressure 1280 1557 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X, Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE~~ DS 1-25 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT-OFF 5/22/91: Added Perforations: 9807 - 9811' MD Ref. Log: BHCS 2/21/83. 5/31/91: MIRU CTU & Stimulation Equipment. PT equipment to 4000 psi. Loaded wellbore w/Seawater. RIH w/CT & washed perforations at: 9807- 9811' MD (Z4) 9892 - 9896' MD (Z4) 9910 - 9914' MD (Z4) 9920 - 9924' MD (Z4) 9940 - 9944' MD (Z4) 9984 - 9990' MD (Z3) 9998 - 10013' MD (Z3) 10013 - 10040' MD (Z2) 10040 - 10073' MD (Z2) Ref. Log: BHCS 2/21/83. Pumped: a) 48 bbls 15% HCI w/10% Xylene, followed by, b) 48 bbls 12-3% HCI-HF, followed by c) 48 bbls 3% NH4Cl Water. Displaced CT w/Seawater. POOH. Rigged down. 6/3/91: A CTU Squeeze for Water Shutoff was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/Seawater & Meth~Water. Pumped 5 bbls of Neat Acid Resistive cement, followed by 35 bbls of cement w/Aggregate, squeezing the open perforations. (perf intervals listed above). Placed 15 bbls of cement behind pipe, squeezing at 3500 psi for one hour. Contaminated cement & cleaned out contaminated cement from wellbore. POOH. RD. 6/1 2/91: Reperforated: 9910 - 9914' MD (Z4) 9920 - 9924' MD (Z4) 9940 - 9944' MD (Z4) Ref. Log: BHCS 2/21/83. Added perforations: 9908- 9910' MD (Z4) 9914 - 9915' MD (Z4) 9931 - 9939' MD (Z4) Ref. Log: BHCS 2/21/83. Returned well to production and obtained a valid production test. RE"""'EL Alaska 0ii a Sas Cons. 'Anc mge ARCO ALASKA, INC' F'.O. BOX lO0360 "~-"'~ ANCHORAGE, ALASKA 99. · DATE' 7-3~ -gJ REFERENCE' ARCO CA..?ED HOLE FINALS ~J~i-iB 6-26-9i PROD PROFILE r'~"~ RUN i, ,-22 7-3-9, PROD PROFILE E~C~/~ ~-24 6-27-9~ PROD PROFILE RUN ~-25 7-4-9~ PROD PROFILE 2-9 6-29-9t PROO PROFILE ~ RUN 5-3 6-23-9~ LEAK DETECT 9-2 7-8-9i LEAK DETECT ~s~ Oil ~ ~s Go~s. 9-35 7-8-9i LEAK DETECT Aocb~s~e RuNRUN ti', i3-i0 7-6-9i LEAK DETECT RUN' i, i4-i4 7-5-9i LEAK DETECT RUN t, * iT-ii 6-2~-9i CA~ING IN~'PECTION CALIPER RUN i, iT-ii 6-2~-9i LEAK DETECT RUN t, i8-7 7-5-9i PROD F'ROFILE RUN i, i8-i7 7-5-9t PROD PROFILE RUN i RECEIVED BY ___ HAVE A NICE DAY! $ONYA WALLACE ATO-t 529 TRAN$~ 9 5' 5' 5' 5' 5'&lO' 5' 5' 5' 5' t'&5' 5' 5' 5' CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON PB WELL FILES D & M R & D EXTENSION EXPLORATION ' T BPX EXXON ~ STATE OF ALASKA MARATHON TEXACO MOBIL * THE CORRECTED BOTTOM LOG INTERVAL IS 4,9~ FEET RITFEI:;..'I.:ZNC:15' ARC(] CA.S'ED HOI_E FINALS' i :-9 6-'-i 2-"9i F'ERF--COI...LAR RUN t , i -25 6'"' i 2'"'9 i F'Ii--RF---'COI..LAI"< '~ RUN t , 5 I B'-7 6-it-9t I::'FC-'CfR (F:'ACKE:R SEI'I'INC;) ' RUN t, S-i '7 6"'~ 0"-9~ F'IERF--COLI._AR RUN ~ , 5" S'-'~ 7 6 .... i 8-9t AC::Blll.-VDI...""C;R RUN t , 4-9 ~-'9""~i SPINNISR (W:['FH 'FEMF') RUN ~, 'P'"'~ 8 6 .... ~ 4-'9~ PERF-"C:OI...I...AR RUN ~ , ~ i"'~ 3 ~-'5""9~ F'DK-~ ~/CCL_--(;R RUN t , 5 ~S""98 6'"'2'-9~ CNL. - E:PZi'I'~ERNAL. RUN 36, ~ 3-98 5"-2-9~ CNI... "- THERMAl.. RUN ~, '3" ~ :3"-98 6-"~ B'"91 D ]:T-E: RUN 3~ ~4'-~0 ~'-'7'"9~ F':[TS RUN ~, 5" F'I..E"'ASE ,S;I(':;N ANI) RETURN I'HE AI'I'ACHED C[)PY AS RECE:'IF'I' OF DATA, [.lAVE: A NICE DAY! $C)NYA WA[.I..ACE APPROVED ATO'-t529 TRANS:~ 9~2D2 / A'I'LA,S' AI'I..A,? AfL. AS A'i"LAS A'I'L. AS1 HRS ATL. A,? A 'i" I.. A Z ,S'CH ,S'CH ,~ ...H HRS DI£TRIBUTION .,-"~ CENTRAL_ FILES ~' CHEVRON D & M ~' EXTENSION EXPLORATION · ' EXXON NARAI'HON ~ MOBIL PHILLIPS F'B WELL FILES R & D .BPX STATE OF ALASKA TEXACO * I'FIE CCIRRE:CI'ED AF'I~ FOR 9-i8 IS '%eke Oil ~ C~as Cons. ALASKA_, BOX i ANCHORA6E, ALASKA 99'Si DATE · 6-27-9i REFERENCE: ARCO CASED HOLE FINALS t-'2.5 5'-3i "9i L. EAK DETEC. I'ION 2.-3 5-3t-9i I"-'R 0 D F'ROF" I LE 3-i $ S'"L~i -"9i INJ PROFIL. E 4-'iS 5-29-9t INJ F:'ROFIL. E :~-"33 6-8-9i CBT -33 6-8-9i BET 6-' i 6-.5-9i F'FC 9-8 '5-Si -9i PERF BREAKDOWN 9--2S 6--i -9i F'ROD PROFIL. E i i-S 5-2:5-9i POST BREAKDOWN i 6-9A S-29-.9i GR-CCL RLJN i , 5" RUN t , "5" RUN t , 5" RUN t, '5' RUN t, 5" RUN t, 5' RUN i , 5:" RUN t , .5" RUN t , 5" RUN i , 5" RUN t , 5" PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. RECEIVE:D BY ..................................... HAVE A NICE DAY! SONYA WALLACE ATO-i~29 APF'ROVED 'i'RANS~ 9t~ei CAMCO CAMCO CAMCO CAMCO ,S' C FI SCH A 1' L.. A ,S' CAMCO CAMCO CAHCO CAMCO DISTRIBUTION CENTRAl_ FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARAI'HON MOBIL PHILLIPS F'B WEI_L FILES R & D '"' BF:'X ...'"' STATE OF ALASKA I"EXACO * 'THE: CORRECTED AF'I~: FOR 2-3 IS 50-029-:20077 ** THE CORRECTED WELL NUMBER FOR THIS LOG IS t6-9A RECEIVED JUL 11991 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA~ -INC,,4:-...~ ; - . ~ F'.O. BOX tee~6e :_-J_:._ _ ~ ~. ' ANCHORAGE, ALASKA 995~8 REFERENCE' ARCO'CASED HOLE FINAl. 5' _~. __3-7.' .... 5_~SS~_i_.~..Z.;.~TLIBING CUTTER_: .... ~.~.~~ ...... RUN t., .5_~ . A;fLA~ ~l;~ ~--~" ~'~_2~-~t-~L--/Tc~-i- ~- ' '_-' ~ ~/~,_ ' ~UN ~, ~"' ~CH . ~_~ .... ~S4,.~.!./.-_--C~T . .... ~ ,_. .~ . ~. V~ ~u~ t, ~' ~CH. ~-t ' --"~-24'9~.~_ . . PFC (RETAINER)'., '~.,~,, Z ,~ . ~ RUN . _. ~_~ · ,. ~ ' 9-te '5'2eZgi COLLAR/PERF ~ RUN t, 5' ~i'LA~ ... 9-t~ .... 5-_-25~_t_.. COLLAR (RETAINER) ............ RUN t, 5"__. .ATLAS ' ~ '~" t' ' -' - : , ATLAS f~-ti . :~3-:~ :~.-. .FFC . . RUN I 5" ".--_ - -- ':~- - / '-.>-": '2 . ' ....... _ . ~ .-~. _ ..... ~.....~. .... ~ ....... . -. ..... . ....... ..... ~., .......... ...... .......... . .......... I-LE.~,~E ~]~N ~ND RETURN THE ATTACHED COPY ~ RECEIPT OF DATR~ UCEZV "'-~Y:.; .... ' ~y~':'~'~h-,~ ' ~-"' ' ' ';'-'?:'~"::" '" "' ' -z.- -- - _.H~VE ~ N~CE.:~AY~ .... /::-.'_ ........................... ~'...': ........................... - . -_- .. ,S'ONYA ~LLACE ~PF'ROVED ~T0-'i529 TR~NE'~ 9t 79 ....................................................' ..- .. ~_ '..:,:- .-_ ~-: _.----. __ ... . -_ -_ .-~.:.____~._ _~...~ ~ty_'._?-._-:D~ST~UTION. , .... . ...... ~ CENTRAL F~LES ~ PH~LL~F'S ~ _CHEVRON ..... PB ~ELL F'~LES ~ ........................... D & M R & D .... ~.~ EXIEN~ION EXF'LORAIION · ~ BP~X~ ~ · ~- ~- EXXON ~- STATE OF ALASKA ..... ~AR/AIHO.N __.'!.'E.X~. CO ....... . ...... · ,.'"' ~OBIL ~ ~: 1..: ........ . ~,.' F:'~ 0 ~ {?, 0 ;-'< i 9 (') 3,5 (? :'::',. N C H 0 F;.'. A G IF.:, F', L. A ;:.; K A R E F: E F;.' [..- N C Iii: · A F;.'. C !_".- C A S E." D H (.3 L. I!:.' F." I N A L.. S C: 0 L.. L. A F;,' / I::' E R F F' F.'. 0 D l.j C'¥ ii: 0 N F' R 0 F I I_ E P F;: 0 D U C i" ]: 0 N F:' F;.: Ct F" I L E C 0 i... L. A R / F:' Iii: R t:' I N J- f:' F;.'. 0 F:' 3: L.. E C 0 I... L. A I:;: / F:' Iii R F" F' I:;.: 0 D U C l' :1:0 N F:' R 0 F:' I I... E: '1" ii.": H F' Ii"' F;: A 'F U R Ii'" L Ii'.: A I< i) E T E C 'l' I 0 N I N..J i::'R 0 F"' :1: L. FZ F' R 0 D IJ C"[' ]: 0 N P R 0 F:' ]: L E :i_' N .! F'F;.'.O F' i L E I... r.i: A i< i> E T [..: C l' l' 0 N C 0 L L A I-';.: ,."' P [." F,' F:' F'F;,'13DUCT I ON PI:;:OF I LIE · j F_.: W Ii:: L I;.'. Y F:' F;.'. 0 D U C T I 0 N P R 0 F' I L [..': F"I~ODUCTION PROF'IL.E I::'R I SH ANALYSIS I_FAK DE'i'F,.CT I ON L. EAI< DETECI'ION PRODUCTION I:' I:,:CI F I I..1:.' F;: LJ i'.! F;: LJ N F;: U H. F;: U N R U N F;.'. [.J R U N I:;,'l..J N R U N I:i,'L) N I:;: U N R U N I:;: L.I N I:~'. U i",! R U N R U N F;: I.J N RUN RUN F;,' U N R U N F'I_EASE SIGN ANI) F;.'.Ei'LIRN THE ATI'ACHED COF'Y AS R li"'C Ii:: I V E D B Y .../~~~~ ....... HAVE: A NICF DAY! Si.iAF;~ON WIL. SOi',I A 'i" 0 '-' i 5 2 9 f;.'. E C E I F:' T 0 I::' I) A "F A APF'ROVEI) ........... 'I"I:;:AN;S'~- 91 (')82 .... DISTRIBUTION --. .,-'"- ENTRAI_ FILES- .,,-'''' CHEVRON g & M -,-'"'E X'I' [:'i',l."~' I 0 N . EXPLORATION · "' E X X 0 N MARATHON :[ itOBJ:L :~ T I..I E C 0 F< F;,' E C'T' · .',~:..'~. 'T' I..! E C 0 F: I-;: !!i: C ~ F' I"11 L. L. :[ F:' $ F:'B WELL. F']:I_E.,~' R & D -..'"'BF:'X $'i'A'I'E OF" ALASKA - 'I"E:'XACO ED AF'I-$ F'OF,' i3'-5 IS :~'.,0-'" "~..-.9-n':.0626, "FE:D AF'I-$ FOF,: i'1--2S IS 5(-)-929-.2e. 7'.!~7, STATE OF ALASKA ----~. tO .~ ~ ~' '~ -, ALASKA "'--'"' AND GAS CONSERVATION CC IlSSIO'N REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 80' Conductor 2591' Surface 9579' Production 1011' 10330' MD feet 9282' TVD feet Plugs(measured) Liner Perforation depth: 10072' MD feet 9037' TVD feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 1895 # Poleset 79' MD 79' TVD 13-3/8" 3000 sx CS III & 400 sx CS II 2624' MD 2624' TVD 9-5/8" 500 sx Class G & 49 bbls CS I 9610' MD 8613' TVD 7" 300 sx Class G 9317-10328' MD 8363-9280' TVD 948' 4-1/2" Scab Inr 85 sx ARC (Class G) 9199-10147' MD 8265-9107' TVD measured 9892-9896'; 9910-9914'; 9920-9924'; 9940-9944'; 9984-9990'; 9998-10013'; 10013-10073' MD true vertical 8865-8869'; 8883-8886'; 8892-8896' 8911-8914'; 8953-8959'; 8966-8981 '; 8981-9038' TVD Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80 tbg w/tail @ 9192' Packers and SSSV (type and measured depth) CAMCO 'BaI-O' SSSV @ 2176', Baker 'SB-3A' pkr @ 9064' 13. Stimulation or cement squeeze summary Intervals treated(measured) Well was perforated Treatment description including volumes used and final pressure L. I' I V DEC 181.990 Representative Daily Average Production or Iniection Data ' -~,., ~10~0~!~. · "' "' Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 318 2313 3982 ..... 233 510 2387 5481 ..... 211 14. 16. Status of well classification as: Oil x Gas Suspended Service 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Date SUBMIT IN DUPLICATE 17. I hereby cedi~ha,~e foregoing is true and correct to the best of my knowledge. Signed ~ C/{jt/[ ~~:~:~ Title Senior Area Engineer Form 10-404 Rev 06/15/88 WHS/SunVII feet DESCRIPTION SUMMARY PRUDHOE BAY UNIT DS1-25 WELL APl # 50-029-20874 Permit # 82-203/9-568 ARCO Alaska, Inc. perforated the subject well within the Sadlerochit interval as follows' Interve_l MD TVD ZOne Comments Date 9892-9896 4' 8865-8869 4 Reperf 1 1/07/90 991 0-991 4 4' 8883-8886 4 Adperf 1 1/07/90 9920-9924 4' 8892-8896 4 Adperf 1 1/07/90 9940-9944 4' 8911-8914 3 Adperf 1 1/07/90 9984-9990 6' 8953-8959 3 Adperf 1 1/07/90 All depths per BHCS log dated 2/21/83. ARCO ALASKA, INC~ F'~ O, BOX i ANCHOF;,'A[.~E, ALASKA 995', ,, DATEr.' t t--'2i -90 R Iii:t:: E R E N C E. ' A R C 0 C A.S' E D H 0 I.. E F I N A I... S "":2.~ i i-7-90 COL. L. AR/!::'ERF:' RUN i , 2-'i 9 ~ i--i 4-90 COLl..AR RIJN ~ .. 9-3 i 'J '-i 5:-'9(') 'i"B~ CLJ'i"TE:R RUN i , 9'-'44 i ~ .... 6-9;3 CCL/F:'E:F~:.F RUN i , ~" 4 ~-~' i i ,::.'... o r:, C ~:'". 'i" F< U N"'~ ,,.' . .,Z ~" :,-' .... · 9-a5 i i ~- ~'' '~, , -_:.--.?g CE'T RUN t , 3;-98 i i-i -90 DIL. RUN 34, 3..-98 i t-i--90 CNL. -.- THI.ZRH~L RUN 2;4, .... -'' [HERH~.~L RUN 34, i~ 98 ii i---"-;-~(-) CNL. - EPI ...... ''~' iS-i6 ii-9-.9,2, H.-..C'HANNEL VERTII._O(; (COMI::'Ui"ED) RUN i, i"~'.--i,g ~i- c;' - .- ': :.~ ;."', M-CHANNEL VERTII...OG fB'.AW I)A'f'A; RUN i, 5-i 6 i i-9-9,:) M-F'INGEIr<ED VEF,'TILOG ('72 ARM) RUN i , F:'l...tiftASr< S"IC-N ANi) RETURFi THE ATTACHED COPY AS Riii]CEtF:"i' OF DATA,. RECEIVED BY _.~~.A~ ....... ~ HAVE] A NICE DAY! S A l... t... Y H 0 F:' F:' E C: K E R : 1::' :') C~ A T 0 - '~ _.: ,:.., D i] S 'T' R i B L1 'T' ]i 0 N :[: C E:'. N T F.:..' A i... F: ;J: l... E: $ '11' -.'1 I~ · ,."'"- E. XTEIN;.?iON E':'4PI. ..... FiF;..'AT1;ON ~ EXXON H A R A '1" H 0 N :~: H 0 B I i._ :[~ F:' J"l :[ L_ L. :[ J::' S F"B W E i...i... F:']: I... iii. R & D ~: BPX Si"AI"E Oi':' ,::'~I..A;~?I<A i" E X A C RECEIVED ~OV 2 ~ Oil & (~ Oons. OomrriJssJon Anch. or~ge · ¥' ;.....; ~ .- ! .~... i::' }:;-: () :0 {.J C T ]; (] N i::' l:;..' ()¢::' ]; !... iii: (; F,' ;!':..' {.J i:~ V iii;'..," F:'.:;.: () ",}. JC T T (')N F:' Fi.: (')F' ;[ i... Fi' i::' i!i; i:;.: F' i:;..' E C 0 {:;.: :0 F:' ,:..' O ~'...;:, {.J C 'i" ;[ O .-:'ii !::' F.." C;: F:' ;ii L. iii; ;::' iii; J:;.: i::' Fi.: iii; (3 (;)J:;-: 'i" iii; f'i F:' :.!i: U i:,: V ii{; '," "i' iii; ¢'"i i::' ,!':/U Fi.: "'-./iii; Y E;, i-".' r"i r': i i -"- } .... ¢"i i...i ii.', !:, i-'~ i7' -i' i ;-- '*f' '£'.: i''l i%: i ,;'*. i"' ~ i [ · ': r: Z' -:"' '-"] E': [ l:..: :..Y -'...: :- %" :.*** I ! :,.. l i.. ~ % :.,l :..: .'.l.. ~ ,**.: J::' i!il i:;.: F:' F~: ii:. E: O i:;..' iii:, RECEIVED OCT 1 9 1990 Alaska Oil & Des Cons. Commission Anchorage ARCO ALASKA: INC;.~ p ,~ F'~ ~ B 0 X i (:,',,.'ii)'5 6,:':) ANCHORAGE: ALA,?KA 9 9 ~"-;- i (-) A R C 0 M A E,. N E-f' .1; C T A P E. ( :? ) W i "i".H i... ]: ,% 'i" ]. N C- ( ,~'.:.' ) F.:.:'E:CE]: YED BY ................................................................................. !'iAVE A iq]iCE DAY! ,?Ai...L.Y HOF:'F:'ECK ii!:l:;..' A'TO .... i 5:29 ')-J:;.: A N ;=':: :;1: 9 ,:})/"..-.: 9 i) 'J: :ti: l' F;.: ]Z B U T .i: 0 N RECEIVED OCT 9 1990 Alaska Oil & Oas Cons. Commission Anchorage STATE OF ALASKA ~- "~ ALASK~'"'~",L AND GAS CONSERVATION C~ ,MISSION REPORT oF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number/approval number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 10330' MD feet Plugs(measured) true vertical 9282' TVD feet Effective depth: measured 10072' MD feet true vertical 9037' TVD feet Junk(measured) Casing Length Size Cemented Measured depth Structural 80' 20" 1895 # Poleset 79' M D Conductor 2591' 13-3/8" 3000 sx CS III & 400 sx CS II 2624' MD Sudace 9579' 9-5/8" 500 sx Class G & 49 bbls CS I 9610' MD Production 1011' 7" 300 sx Class G 9317-10328' MD True vertical depth 79' TVD 2624' TVD 8613' TVD 8363-9280' TVD Liner 948' 4-1/2" Scab Inr85 sx ARC (Class G) 9199-10147' MD Perforation depth: measured 9998-10013'; 10013-10073' MD true vertical 8966-8981 '; 8981-9038' TVD Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80 tbg w/tail @ 9192' Packers and SSSV (type and measured depth) CAMCO 'BaI-O' SSSV @ 2176', Baker 'SB-3A° pkr @ 9064' 13. Stimulation or cement squeeze summary 8265-9107' TVD Intervals treated(measured) Well was perforated Treatment description including volumes used and final pressure S E P - 6 1990 Alaska 0il & Gas Cons. uommission 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 318 2313 3982 206 2371 4560 Anchorage. Tubing Pressure 233 237 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas__ Suspended Service 17. I hereby certify tha, Hhe foregoing is true and correct to the best of my knowledge. Signed ~~ ~~/~/~~ Title Senior Area Engineer Form 10-~04 Rev 06/15/88' ' t WHS/SunVII SUBMIT IN DUPLICATE DESCRIPTION SUMMARY PRUDHOE BAY UNIT DSl-25 WELL APl # 50-029-20874 Permit # 82-203/9-568 ARCO Alaska, Inc. perforated the subject well within the Sadlerochit interval as follows: Interval MD TVD Zone Comments Date 9998-10013' 15' 8966-8981' 3 Aperfs 7/5/90 Proposed plug back procedure was not performed. All depths per BHCS log dated 2/21/83. RECEIVED S F P - 6 1990 ~J~isJ~ Oil & Gas f3ons. ARCO ALA~-TKA, iNC. P,O. BOX ANCHORAGE, ALASKA 995. t REFEREi:!CE' ARF-:O CA,S'ED-HOLE FINALE: ~, --i -,,, -~ ,,__, =.-_ o r:~ ., ~... COLLAR/F'ERF i -25 7-5-9'3, C. OLLAR/F'ERF i-36 6-ii-9"'3 PERF RECORD 4-,-' '" '7 , - '~ _, - ':'-: . ":; ... C . 0 I.. L A F.: / P E F'.'. F 7 '- i '2 7 - 4 - 9 ,::_:, T E N P 7--27 6-2':'}-9¢ PERF RECORD i 2-i 5 6-i 3-9¢ TEHP i S-2A '7-i -9-'?;, TEMP YUF:VEY i S'-i,;. '~ 6,i c.,_o. ¢, , ,. F:'ERF i S-i 2 6-.3¢.;)-9¢5 TEMP i.,a-'--:6.~. A-6--q',':;_ , .., DA'f'A FRAC i"EMF' RUN i, RUN i: RUN R U N i RUN t , .5" RUN i: 5 RUN i, 5" RUN i , RUN i, '.:5:" RUN i , ~' :,q'UN i , F'LEAYE :'7. IGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA~ HAVE A NICE DAY! z~ALLY HOFFECKEF.: AT(]-- i ~---')9 JULl lB90 __ . ,/ 'Ancb~ge TRANS'~ 9¢27'7 A f'i..AZ A -!"L A ;!'~ HL_:? A FI._A;S' H R t",' H L ,':'-: FILS' !.-I R Z HLZ DISTRIBUTION CENTRAL FILES CHEVRON EXTENZION EXF'LORAT ION EXXON MARATHON MOBIL ~ F'H ILL I F',S' F'B WELL F']:LE. 5' R & D -,-'"'BF'X '"' STATE OF AL. AZI<A TEXACO 1. -Type ef Request: STATE OF ALASKA ALASKA LAND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator ARCO Alaska, Inc. Abandon Suspend Operation shutdown Alter casing Repair well Plugging )~ Change approved program Pull tubing 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Re-enter suspended well Time extension Stimulate Vadance Perforate X Other X 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number 82-203/9-568 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, T10N, R15E, UM 10330' MD feet 9282' TVD feet Plugs(measured) None 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 10290' MD feet true vertical 9244' TVD feet Junk(measured) None Length Size Cemented 80' 20" 1895 # Poleset 2591' 13-3/8" 3000 sx CS III & 400 sx CS II 9579' 9-5/8" 500 sx Class G & 49 bbls CS I 1011' 7" 300 sx Class G 948' 4-1/2" Scab Inr 85 sx ARC (Class G) measured 10013'-10073' MD Measured depth True vertical depth 79' M D 79' TVD 2624' MD 2624' TVD 9610' MD 8613' TVD 9317' - 10328' MD 8363' - 9280' TVD 91.99' - 10.t47' MD 8265' - 9107' TVD ECEIVE Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: true vertical 8974'-9038' TVD .~j ~j ~h,j 2 6 Tubing (size, grade, and measured depth) 5-112"14-112", L-80 tbg w/tail ~ 9'19~' .;;l'~s~.Ojj.& ~aS ~O~S. Packers and SSSV (type and measured depth) CAMCO 'Bal-O' SSSV ~ 2176', Baker 'SB-3A' pkr ~ 9064 13. Attachments Description summary of proposal x Detailed operations program BOP sketch X' 15. Status of well classification as: Suspended Date Approval No~:::::~O _,~ ~ 14. Estimated date for commencing operation June - July, 1990 16. If proposal was verbally approved Oil x Gas Name of approver Date approved Service 17. I hereby ce~ tha/t~e foregoing is true and correct to the best of my knowledge. Signed ~--~/~ ~/~ Title Sr. Aroa Engineer / ~ FOR COMMI.~SlON USI= ONLY Conditions (of approval: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test Location clearance Subsequent form required 10- _..~A-~ ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved by order of the Commissioner Form 10-403 Rev 06/15/88 WHS/SUNVII Approved Copy SUBMIT IN TRIPLICATE Returned DESCRIPTION SUMMARY PRUDHOE BAY UNIT DS1-25 WELL APl # 50-029-20874 PERMIT # 82-203/9-568 ARCO Alaska, Inc. proposes to plug back to a total depth of 10036' MD by dumping a sand/cement plug and/or setting a cast iron bridge plug in the 4-1/2' scab liner. The new plug will isolate water production from 37 ft of the Zone 2 perforations, 10036 - 10073' MD. After raising the PBTD, we propose to perforate within the Sadlerochit interval as follows: Interval MD Zone Comments 9998-10013 I 5 3 Aperfs All measurements per BHCS log dated 2/21/83. 6 5 4 2 COILED TUB!NI~ UNIT BOP EOU ! PP. ENT 1. ~ PSi ?" W[LLH~ CONN£CI'OR FLANGE 2. ~)00 PSI4 1/16" PIPE ~S 3. ~ PSI4 1/6" ~WLC ~IPS 4. ~ PSI4 1/6" ~~ ~S S. ~ PSI4 1/6" BLIND ~S 6. ~ PSI4 1/16" STUrrlK BOx Anchorag~ ,,1 I" I I NIRELINE BOP EOUIPHENT 1. 5000 PSI 7" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WlRELIN[ RAIaS (VARLABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-orr ARCO AL. A3'KA, INC., P,.O,. BOX ~00360 ANCHORAGIZ, AI_.A~'KA 99.5~ 0 DATF. · 6/20/90 F;:. iii: F:' E R E iq C: E ' A R C 0 P !:;.". O f;', LJ C T ]: O N P R O F' I L. E ,? t.J I:;..' %; E.:. YR t.J N i: 5" '¥ E H P iii: R A T U R E t_. 0 {; R I I N i ':"" T Ii"' i'"'i i::',r.'.:, i:;.'. A "i" U F;.'. E I... O (.;- I:;.: t.J i'.! i , '.fi:" 'f' Ii:.:' M P '" '" '" ... E. RHT::.JRE ;"'.?UI'?.VL::.Y RLIN i , ':'~," 'i" E i'-i P E R A 'T' U !:;.: r..[ ,;.~'i .... i~:;.,, .... v r.:' y R t.J Ni , ..:.'::" 'f' E H F:' E R A T U R E L C)(;. R U f'.J. t , ::.:;:" T F f-iP I:;; F;.: A T U R E I... O C.;. R t..I N i , ..;.'::" TEHPEt:;,'ATUF;.:E ,'~UI-:.'VEY F;;UN i, '5" "1" E N !::' Ii..': I:;.: A ".i" U R Iii: L.. 0 [.'-;- F;.'. t.J i".! i , ...,':;" 'f'EHPE:'RA"f'tJI:;.'.i::' 3' IF;.:VEY RUN i., ::~;" 'f' [:.: i'i P E F;.'. A 'f' t.J I:;.: E L.. 0 C-;. R L.I i"'.J, i , '::'..,." L E A K D E "F, ,l:' ...... C: T :[ O N I;.: U i'.i i , ':":," TE:NP/2'P]:NNER G/[.. ,'.?IJRVlii:Y F;..'t..li'-J i '::"" · ! ../ C ,'q M C: O C: ~'::'~ ,"'i C 0 i:: A H C O ¢:; A ri C 0 "' A fi C'.' O ": ¢:', ri C 0 C ¢::~ f'i C 0 C f::'l I"'i C O C r::~ ii C O C :::~ ri C O C ¢."~ M C O C R H C 0 I":.'L. EA,?F ';:2).'(;N AND RETURN "FHIE A'f'TACHiED COPY A,~-:: "'"'r .... ~ · . I',..1:: ... I:- l' F' f' O I::' D A 'f' A ~vE~ k, :e ,::: L~: ~::,;:'~,Y ~ JUN ~ 2 '~990 :~: A i... L.. Y H O F F E C l< E F,: Alas~ 0il & Gas Cons. A'r O .... i ,.~..:..:,o,,., /~nchorage D 15,! 'i" R I B U i' ]: 0 N · ,r''I, CENTRAl_ FILES -,,- C i..i E V R O N D & H · - '- ,' .... i "'- -' '1 # '1 -i" E~,IEN$ION E,~FL, LIRAIION 'Il' · ~'"- EXXON HARAI'HON · ~,'~' HOBIL F' t"1 :[ I.. I._ I F' i::'B W E L.. L_ F: I L.. E: $ R & D · ~ BPX · .-'"' ,S'i"A'i"E OF:. AL.A;!,;'K A i' ii: X A C: O ARCO ALA,?!<A: ]~NC~ F',O,. BOX t(D(DS6C) ANCHORAGE: AI_AI~KA 995i(-) RECEIVED DA TE' 5- MAY REFERENCE' ARCO CASED HOLE FINAl_5: ~O~ge ~i~ion :; -t ,':', '::.--7-o;:~ cRI.LAR R.I.IN t :-" ~ ..'-, c.- :--..-: ,.* .......... ,... · --,:. _., 4 -. '-':"~ -- ':;' ¢,I:' ir I-;' r: ~, r.: C 0 I;.'. D I;.: I.J N t ....... ,..:. i ~: 4-?7-o;:..' TR(.;. r:l ITTF'I:;' F;.'E]F'Or.;.'T.', I:;.:1 Ii'../ i , "~'" - --. : ~.- , ............. ; -. . .=..- .............. .. ":' .i 5 "'/4--~/e,'-", F':CL I:.;:l...li",.~ -* ~ . ...:' ,.. ..¢ .- .- --- ~_ . . "'" "':'C'A 4--"':',.':.-q',c'-, PEF;.:F RE'F'.'FiK"f':, RI IN i , "~'" .....~ ~ ...._ ¢ ¢.:'. ~ . ;: .................... : ..... · .:-A ,.'5. o¢; F"F"~ R.JN i , ~'" .. ~ .. ~ ..- ._. ~.: ~- 1~ . ...' · -~- 4 .'3 4-.':~,q-c';--' F'FI': RI IN t , ";'" ...... : .... ........ ~.-..t 4--'~4-e,':, KIX~LEY R!~TTF]N 3."Tt; RE'CORD R _: : ..- :_ : ._. , : ...... .. _ · ., .,, · ~-4 4-._.. ;-.~'" 9,:%._ PERr: K'EF.'F~Rf'~ RI.IN t , ~"... :_, ........... 6-9 4.-5,:~-- 96 F'ERF .!;.' I~ C 0 R .I.-.~ RUN i t -2° ~' 4-~:; ~:E.GMENTE!) P,F~Nr~/GR/F:¢:I R IN .% _..'- ~ : .... . ........ .. ,, .............. ..' i 4-t 7 5-i -9:) VERTiLOG RUN t 5:-i ? 4-29-9(D CI_')LLAR/PERF RUN WGI-6 5-'7-9,:~ CCL F;.'UN t, 5' · 1 ~ ~-i · .. F.t..E~,.,E SIGN AND RETUf;:N THE ATTACHED CrlF'Y AS RECEIPT OF DATA RECEIVED BY ___j~-C-C'z,'~ _ HAVE A NICE DAY! ,~A[..I_Y HOFFECK ER ATO-t .529 TRANS.S DISTRIBUTION ft.._.ENTR.~I'" FILEZ CHEVRON D & M EXTENSION EXF'LOR. AT ION EXXON MARAI'HON MOBIL F'FIILLIF'S F:B WELL FILE~ R & D BPX ~TATE OF ALASKA TEXACO AR(.'.[) ~' -" ~L..A~KA F'~O. BOX t ANCHORAGE, DATE · R.EF'E'RENp- ......... E' ARCO CASE]) HOLE FINAL,S' ~ '-2."~; J.~-" ~ 8-.. 9c=~ F F _. 4 '-'S t ~-8.- ~ .~ 'TEHP '7--2~ ~-"~ 4-9~ F'EE'F' RECORD 7':.-2;~ 3-t 4-..~ F'ERF RECORD ,' .... ,..7 ~-'.t 8~.~ COMPLETION RECOR'D ~-.'24 ~i~.- 7.-~,3 PRODUCTION PROFILE 2-t 8 3- i 7-...,"~ F'ERF 2-27 ~-t ';~.-~ PERK RECORD t4-t8 S-.'i 8-9~ FERF RECORD ~6-4 ~-2~ -9~ COLLAR 6-~ 7-8--9~ L. EAK DETECTION t..EA;.~E SIGN AND RETURN THE ATTACHED HAVE A NICE APR ' !990 ,S'AL L.. Y' HOFFECKER ATO-i RUN RUN RUN kUN RUN RUN RUN RUN RUNS F,'UN RUN COPY A,S' R ..... ECEIP'F OF /)ATA, A TI...AS CAMCO ..?CH S C !-I SCH CAMCO SCH ,.~'CH 5'CH AT[..A~' CAMCO DISTRIBUTION CENTRAL FILES CHEVRON E'XTEN~ION EXPLORATION EXXON HARATHON MOBIL · ~' HILLIPS' F'B WELL F'IL.E~' R & I) ',' BF'X '.- ~TATE OF ALA~'KA ~ TEXACO STATE OF ALASKA AL~KA OIL AND GAS CONSERVATION COMMISSION REPORT OF-SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown m Stimulate m Plugging Pull tubing ~ Alter casing ~ Repair well __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development~_._ Exploratory __ Stratigraphic __ Service __ 4. Location of well at sudace 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, TiON, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, TiON, R15E, UM 12. Present well condition sUmmary Total depth: measured true vertical Effec!ive depth: measured true vertical 10330 ' MD feet feet 9282'TVD 10290 ' MD feet 9244 ' TVD feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 2591' Perforate __ Other"%.__ 9579' 1011' 7" 948' 4-1/2" measured None open to production 6. Datum elevation (DF or KB) RKB 74' /, Workover 't~ 7. Unit or Property name Prudhoe Bay Unit 1-25 9. Permlt number/~pproval ~u.,~er 82-203/9-568 10. APl number 50-- 029-20874 11. Field/Pool Prudhoe Bay Oil Pool Plugs (measured) None Junk (measured) None Size Cemented Measured depth 20" 1895 # Poleset 79'MD 13-3/8" 3000 sx CS III & 2624'MD 400 sx CS II 9-5/8" 500 sx Class G & 9610'MD 49 bbls CS I 300 sx Class G 9317'-10328'MD Scab lnr 85 sx ARC (Class G) 9199'-10147'MD None open to production true vertical Tubing (size, grade, and measured depth) 5-1-/2"/4-1/2", L-80 tbg w/tail @ 9205' Packers and SSSV (type and measured depth) CAMCO 'Bal-O' SSSV @ 2176', Baker 'SB-3A' pkr @ 9064' 13. Stimulation or cement squeeze summary I nt~rvaJs t r.¢ ~t~d_.{~ e~a~s..u_r e~ ~1) ~er~s ~'/~llJ5 -.LUUI5 Treatment description including volumes used and final pressure 75 bbls Class G & 50 bbls ARC (Class G) N/A 14. Prior to well operation Subsequent to operation feet 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations %_._ RepreSentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 16. Status of well classification as: Oil ~ Gas __ Suspended __ ~ueverticaldepth 79'TVD 2624'TVD 8613'TVD 8363'-9280'TVD 8265'-9107'TVD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Drilling Analyst Signed &Q/]Q/K ,//~ Form 10-40~/JRev 06/15/88 * Workover Well Histories (DAM) SWO4/048 ~AA,-.,-,A,,.m [A~;,-~A Q /1 ~ I0~ Tubing Pressure Service Date SUBMIT IN DUPLICATE ARCO O,, and Gas Company Well History - Initial Report - Daily Insb'uctimla: Prepare and submit the "lalfllt RIImrr' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to epuddil~g should be summarized on the form giving inclusive dates only. Distdct A~CO A~T.~I~ INC, Field PRUDHOE BAY rCounty. Lease or Uii~)T.'. 28329 Title WORKOVER Auth· or W.O. nJ)~S3480 IState ~ DS 1-25 JWe,, no. API: 50-029-20874 Operator ~.CO Spudded °r W.C~Ck~T ]Date 02/21/90 IH°ur 2000 HRS Date and depth as of 8:00 a.m. 02/22/90 ( TD: 0 PB:10144 SUPV:GTG Complete record f~l~[~o~ d~Yl~l~roo4ted I^RCO ~":[. 0000 Prior status il a W.O. CIRCULATE TO KILL WELL iF, q: 8.5 seawater MIRU AODI RIG 4. ACCEPTED RIG @ 2000 HRS, 02/21/90. PULL BPV. SITP - 450 PSI, SICP - 1000 PSI. BLEED TUBING AND ANNULUS TO 0 PSI. ¢IRC SEAWATER DOWN TUBING, TAKING RETURNS OUT ANNULUS. DAILY:S77,997 CUM:$77,997 ETD:S77,997 EFC:$570,000 The above is correct For ,om% p~eparatiohdV'~dl~st~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling AR3B-459-1-D INumber all dally well history forms consecutively as they are prepared for each well. iPage no. ARCO Oh ..nd Gas Company Daily Well History--Interim Instructions: This form is Used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until linal completion. Report official or representative test on "Final" form. 1) Submit "interim" sheets when filled out but not less frequently than eve[y 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District . ARCO ALASKA INC. County or Par~)RTH SLOPE Field PRUDHOE BAY ILease or unitDs 1-25 I Date and depth Complete record for ,%~b~ayR,~e (~jilling or workover in progress as of 8:00 a.m. 2) Slate AK IWell no. 02/23/90 ( TD: 0 PB:10144 SUPV:GTG 02/24/90 ( TD: 0 PB:10144 SUPV:GTG 02/25/90 ( TD: 0 PB:10144 SUPV:GTG 02/26/90 ( TD: 0 PB:10144 SUPV:GTG 02/27/90 ( TD: 0 PB:10144 SUPV:GTG 3) The above is correct ~ Signatd~ '~ ~ ~ .~. ~_ For form pro~aration and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 RIH W/PKR MILL MW: 8.5 seawater CIRC AND MONITOR WELL. WELL STABLE. SET BPV, ND TREE. NU BOPS. ATTEMPT TO PULL BPV. BPV STUCK. MU LANDING JOINT. TEST BOPS TO 5000 PSI. BOLDS. PULL TBG HNGR TO FLOOR. LD HNGR. PULL AND LD 5-1/2" TUBING AND COMPLETION EQUIP. CHANGE RAMS TO 3-1/2" AND TEST. MU 8-1/2" PKR MILL AND RIH. DAILY:S27,450 CUM:$105,447 ETD:S105,447 EFC:$570,000 CIRC BOTTOMS UP MW: 8.5 seawater SERVICE RIG. CONT. TO M/U FTA 91 & RIH TO 9229'. SHEAR OUT OTIS "FC" PLUG W/ 2050 PSI. MONITOR FOR FLUID LOSS, 17 BBLS IN 30 MIN. TAG BAKER SB-3A PKR @ 9260' MILL PKR FREE. CIRC BOTTOMS UP. DAILY:S29,075 CUM:$134,522 ETD:S134,522 EFC:$570,000 CIRC @ PBTD MW: 8.5 seawater CIRC GAS OUT FROM UNDER PKR. MONITOR WELL, LOST 22 BBL IN 10 MIN. MIX & PUMP 100 BBL HEC PILL. SQUEEZE HEC INTO PERFS, FLUID LOSS 2 BBLS IN 15 MIN. PUMP DRY JOB & POOH. L/D PKR ASEMBLY, FULL RECOVERY. L/D 6" DRILL COLLARS. M/U BHA #2 & RIH. TAG FILL @ 10128'. CLEAN OUT TO PBTD @ 10144'. PUMP 50 BBL HEC SWEEP AROUND, FLUID LOSS RATE 18 BBLS/HR. DAILY:S29,248 CUM:$163,770 ETD:S163,770 EFC:$570,000 RIH W/ 4-1/2" LINER MW: 8.5 seawater FIN CIRC HEC SWEEP AROUND. POOH. SLIP & CUT DRILL LINE. FIN POOH. PU HOWCO 9-5/8" RTTS & RIH TO 9245'. SET RTTS & TEST ABOVE TO 3000 PSI. EST INJ RATE BELOW W/ 475 PSI @ 1 BPM. RELEASE RTTS & POOH. RU CSG TOOLS & RUN 4-1/2" SCAB LINER W/ BAKER ECL, HYFLO II HANGER & TYPE "H" LINER TOP PKR. RAN 29 JT 4-1/2", 12.69, L-80, BTC, CLASS B CSG. DAILY:S54,257 CUM:$218,027 ETD:S218,027 EFC:$570,000 POOH W/ 6" BIT MW: 8.5 seawater FIN RIH W/ 4-1/2" LINER F/ 9199'-10147'. TAG BOTTOM @ 10149'. CIRC WHILE BATCH MIXING 25 BBL(85 SX) BJ TITAN "ARC" CMT @ 15.7 PPG. PUMP 10 BBLS FRESH WATER, 25 BBLS CMT & 5 BBLS WATER. DISPLACE W/ FSW. BUMPED PLUG, PRESURE UP TO 2900 PSI & SET HANGER, ECL & LINER TOP PKR. RELEASE F/ HGR & PU 7'. REVERSE OUT, RECOVERED 1/4 TO 1/2 BBL CMT. POOH & LD RNG TOOL. PU 6" BIT AND BHA ~3. RIH. TAG @ 9191'. WASH & REAM TO 9209'. REVERSE OUT. CLOSE RAMS & PRESSURE TEST AR3B-459-2-B JNumber all daily well hislory forms consecutively as they are prepared lot each well, IPage no. ARCO O.. ,,nd Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until linal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when tilled out but not less Irecluently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following selting o! oil string uniil completion. District .]~D, CO ALASKA INC. I,County or Par[~IORTH SLOPE Is!a!eAK I Field PRUDHOE BAY Lease or Unit DS 1-25 Complete record for ~l)d~y ~/3(~ cEjlling or workover in progress Date and depth as of 8:00 a.m. 02/28/90 ( TD: 0 PB:10144 SUPV:GTG 03/01/90 ( TD: 0 PB:10144 SUPV:ZR 03/02/90 ( TD: 0 PB:10144 SUPV:ZR 03/03/90 ( TD: 0 PB:10130 SUPV:ZR to) The above is correct ~, For form prepa}'ation and distribution CSG TO 3000 PSI FOR 30 MIN. RELEASE PRESSURE & POOH. DAILY:S95,509 CUM:$313,536 ETD:S313,536 EFC:$570,000 RIH TO CLEAN OUT 4-1/2" LINER MW: 8.5 seawater HEL H2S DRILL. FIN POOH W/ 6" BIT. RIH W/ POLISH MILL & POLISH TIE BACH RECEPTACLE. REVERSE OUT. POOH (2) STDS & MU RTTS & STORM VALVE. SET RTTS @ 28'. ND BOPS,TUBINGHEAD & 9-5/8" PACKOFF, INSTALL NEW 4-PORT TUBINGHEAD, 9-5/8" PACKOFF. NU & TEST BOPS. HELD H2S & SAFETY MTG. RELEASE RTTS & L/D RTTS & STORM VALVE. FIN POOH W/ POLISH MILL. PU 20 JTS 2-7/8" DP & (12) 3-1/8" COLLARS. RIH W/ 3-3/4" MILL TO CLEAN OUT 4-1/2" LINER. DAILY:S32,790 CUM:$346,326 ETD:S346,326 EFC:$570,000 POOH W/ BHA 95 MW: 8.5 seawater SERVICED RIG. FIN RIH W/ 3-3/4" MILL & BHA 95. TAG FIRM CMT @ 9938'. CLEAN OUT 4-1/2" LINER TO 10,130' (10' ABOVE FLOAT SHOE). CIRC 75 SWEEP AROUND. POOH 12 STDS TO TOL. PRESSURE TEST CSG & LINER TO 3000 PSI FOR 30 MIN, OK. RIH, TAG 9' OF FILL. POOH W/ BHA 95. DAILY:S90,447 CUM:$436,773 ETD:S436,773 EFC:$570,000 TSTG 5-1/2" RAMS MW: 8.5 seawater FIN POOH W/ BHA 95. LD MILL & 3-1/8" COLL~S. RIH W/ 3-1/2" X 2-7/8" DP W/ MULE SHOE. WASH F/ 10100'-10130', REVERSE CIRC 50 BBL HEC SWEEP AROUND. REVERSE AROUND CLEAN SEAWATER TREATED W/ C-193 INHIBITOR. POOH LAYING DOWN DRILL PIPE. SLIP & CUT DRILL LINE. FIN LAYING DOWN DRILL PIPE. RU TO RUN COMPLETION, LOAD PIPE SHED, INSTALL 5-1/2" RAMS. TSTG 5-1/2" RAMS. DAILY:S26,'455 CUM:$463,228 ETD:S463,228 EFC:$570,000 LANDING TBG STRING MW: 8.5 seawater PU BAKER SB-3A PKR & TAIL ASSEMBLY. RIH W/ 5-1/2", 17#, L-80, BTC MOD, IPC TBG W/ GLMS, SSSV & TREATER STRING, & 2 JTS 4-1/2", L-80 TBG. STING INTO TIE-BACK RECEPTACLE & SPACE OUT. MU FMC GEN III TBG HGR & CONNECT CHEM INJ LINE & SSSV LINES, TEST ALL LINE TO 5000 PSI. LANDING TBG STRING. (RAN 222 JTS OF 5-1/2" TBG, CAMCO 'BAL-O' SSSV @ 2176',BAKER 'SB-3A' PKR @ 9064' & TT @ 9205'.) DAILY:S26,957 CUM:$490,185 ETD:S490,185 EFC:$570,000 IWell no. see Procedures Manual Section 10. Drilling, Pages 86 and 87 AR3B-459-2-B JNumber all daily well hislory forms consecutively IPage no. as they are prepared for each well. ARCO .,il and Gas Company Daily Well History-Final Report Instructions: Prepare and su~t'he ,,Final I~' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final R~l~rt" should be submll~ at~ ..~:operatlons are suspended for an indefinite or appreciable length of time. On workovers when an official lest is not required upon comptetiml, rel~rt"¢olltl~l~ ~ I~presentefive lesf data in blocks provided. The "Final Reporl" form may be used for reporting the entire operation if space is aveilable. ~..?' ~ *'. _ I Accounting cost center code District County or Parish State ARCO AL~ INC. NORTH SLOPE AK Field ILease or Unit [Well no. PRUDHOE BAY ~Title ADL:28329 DS 1-25 I Auth. or W.O. no. AS 3480 [ WORKOVER Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 03/04/90 ( 1 TD: 0 PB:10130 SUPV:ZR A.R.Co. W.I. 21.0000 Date 02/21/90 Complete record for each day reposed AUDI RIG 4 50-029-20874 Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our ]Prior slafus If a W.O. I 2000 HRS RIG RELEASED @ 1800 HRS 3/3/90 MW: 8.5 seawater RILDS. FREEZE PROTECT W/ 163 BBLS DIESEL TREATED W/ C-190. DROP 2-7/8" BALL W/ STEEL ROD. PRESSURE DN TBG TO 3000 PSI & SET PKR. BOLDS. SHEAR SEALS FREE. RELAND TBG & RILDS. TEST TBG TO 3000 PSI FOR 30 MIN, TEST ANNULUS TO 3000 PSI FOR 30 MIN. ATTEMPT TO SHE.aR "RHC" PLUG, PRESSURED TO 4200 PSI, PLUG DID NOT SHEAR. BACK OUT LDG JT. SET BPV. CH~GE RAMS TO 2-7/8", ND BOP. NU 5-1/2" FMC TREE. PULL BPVo SECURE WELL. RELEASE RIG @ 1800 HRS 3/3/90. DAILY:$74,$29 CUM:$564,714 ETD:S564,714 EFC:$$70,000 OIdTD I New TD IPB Depth Rel drig .... IDate IKind of r~g Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Producing method I Official reservoir name(s) I Potential test data Well no. Dale Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. ! Water % GOR Gravify Allowable Effective date corrected sigThe above iai% ....... ~.~"~~t ~. ~~{~te Title For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. OlvlNon of AtlafltlcRIchfteldCompa~Y ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "lnl~kl Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District J County. parish or borough ARCO ALASKA INC~. I NORTH SLOPE Field JLease or Unit PBU I ADL: 28329 Auth, or W.O. no. ~Title AS 3129 I WORKOVE R JStat~K DS 1-25 IWell no. API: 50-029-20874 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 07/16/89 ( TD=10330 PB:10156 I ARCO W.I. IDate 07/15/89 IH°ur 1800 121'0000 JPrlor status if a W.O. tComplet d f h day reported ...... ..... AUDI 4 ) KILL WELL. MW= 8.5 sw MIRU AUDI 4 AT 1800 HRS ON 7-15-89, RU HARDLINES, KILL WELL, SET BPV, ND TREE, NU BOPE AND NEW CHOKE LINES. DAILY:S159,100 CUM:$159,100 ETD:S159,100 EFC:$1,500,000 SUPV:ZR.BS 07/17/89 ( TD=10330 PB:10156 SUPV:ZR.BS 07/18/89 ( TD:10330 PB:10156 SUPV:ZR.BS 07/19/89 ( TD:10330 PB=10156 SUPV:ZR.BS 07/20/89 ( TD:10330 PB:10156 SUPV:BS.RB 07/21/89 ( TD:10330 PB:10156 SUPV:BS.RB 07/22/89 ( TD:10330 PB:10156 SUPV:BS.RB The above is correct For form preparation and distribution, see Procedures Manual, Section 10, DHIling, Pa~es 86 and 87. RUN PRT ON 3.5" DP. MW: 8.5 sw NU BOPE W/ VBR'S, TEST BOPE, BOLDS, PULL HGR PUW-235k, CBU AND PUMP DRY JOB, POH W 5.5" TBG AND SPOOL PARTED CNTL LINE, RU TO RETRIEVE PKR. DAILY:S256,889 CUM:$415,989 ETD:S415,989 EFC;$1,500,000 MU FTA ~2. MW: 8.5 sw INSTALL AND TEST VER'S, RIH ON 3.5" DP W/ PRT, LATCH PBR ROT POOH W/ PBR AND PKR, 100% RECOVERY, MU FTA ~2 TO RETRIEVE LOWER PKR AND RIH. DAILY:S24,200 CUM:$440,189 ETD:S440,189 EFC:$1,500,000 CO FILL IN 7" LINER MW: 8.5 sw SERVICE RIG, TIH W/FTA92. TAGGED 7" PACKER AT 9930', MILLED PACKER FREE. CBU , TOH, RECOVER PKR AND TAILPIPE. TIH W/6" BIT AND 9-5/8" SCRAPER. TAG FILL AT 10066'. WASH OUT FILL. DAILY:S38,414 CUM:$478,603 ETD:$478,603 EFC:$1,500,000 · TIH FOR SQUEEZE. MW: 8.5 sw CO LINER TO 10146' CBU, CLOSE BAG INJECT 1BPM ~ 500 PSI, POOH, RIH W/ 9 5/8" RTTS, TEST CSG AT 3100' AND AT 9276', OK TO 1500 PSI, POOH, RIH W/ 2 7/8" TAIL ON 3.5" DP FOR SQUEEZE. DAILY:S29,315 CUM:$507,918 ETD:S507,918 EFC:$1,500,000 DISP W/DIESEL-2206' MW: 8.4 DIESEL TIH W/2-7/8",SET TT @ 10136. CIRC WELL. MIX 75 BBL CLASS G W/ LATEX CEMENT. SPOT CEMENT W/10 BBLS FW, 75 BBL CEM., 5 BBLS FW & 57 BBL FSW. TOH 18 STDS. B-H SQZ 8 BBL, PRESS TO 1500, HOLD I HOUR. GOT BACK 5.75 BBL. REV OUT DP. TOH. RAN CBL, TOC @ 2370'. RAN 8.5" OD GR/JB, TAG AT 8750'. SET 9-5/8" BR PLUG AT 8747'. PRESSURE TEST 9-5/8" CAS. TO 2000 PSI FOR 30 MIN, NO LEAKOFF. PU TSA FTA #3 & TIH TO 2206'. DISP TOP FO HOLE TO DIESEL. PU WT. 50K. DAILY:S79,517 CUM:$587,435 ETD:S587,435 EFC:$1,500,000 LAYING DOWN 9-5/8 MW: 8.4 DIESEL SET 9-5/8" CSG CUTTER @ 2136', WOULD NOT ENGAGE CSG. TOH AND LD CUTTER. TIH W/ NEW CUTTER. CUT 9-5/8" AT 2136/'. TOH. PULL 9-5/8" MANDREL HGR PACKOFF. ATT. TO ENGAGE 9-3/4" LH ACME RUNNING TOOL, COULD NOT. PU TSA 9-5/8 CASING SPEAR. PULL Dfllling 8u.~ AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formalion name in describing work perlormed. Number all drill stem tests sequentially. Attach description of ell cores. Work performed by Producing Section will be reported on 'lnlarlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil slring is set. Submit weekly for. workovers and following setting of oil string unlil completion. District ARCO ALASKA INC. Field PBU Date and depth as of 8:00 a.m. 07/23/89 TD:10330 PB:10156 SUPV:BS.R! 07/24/89 TD:10330 PB:10156 SUPV:BS.R] 07/25/89 TD:10330 PB:10156 SUPV:BS.R~ 07/26/89 TD:10330 PB:10156 SUPV:BS.R The above is correct County or Parish JState NORTH SLOPE ILease or Unit DS 1-25 Complete record for each day while drilling or workover in progress AUDI 4 9-5/S" C'Si"-,~ ~,~. ~U 125,C05; OFF ~CTTC;-;. t[A;-~ 41 JCi~;T$ LAYED DOWN. DAILY: $26,565 CUM: $614,000 ETD:S614,000 EFC:$1,500,000 10) JWell no. WELDING BRADENHEAD MW: 8.4 FSW FIN POOH LD 9-5/8" CSG. TIH W/6-6" DC, 9-4" DC, XO TO RTTS & STORM VALVE SET 10 BELOW STARTER HD. N/D BOP, TBG SPL & BRADEN HD. CUT LONG RING, ATT TO BACKOUT 13-3/8" BTC PIN X PIN SUB. COULD NOT. CUT OFF SAME AND FLUTED MANDREL. WELDED ON 13-3/8" COLLAR W/4' OF 13-3/8" CSG TO FLUTED MANDREL. BACKED OUT FLUTED MANDREL +3' PUP JT BELOW. L/D. M/U JT OF 13-3/8" 68# KSS BTC MOD. RU. TEST CONN TO 1000 PSI. PULL 50M ON 13-3/8" CSG. SET 13-3/8" CSG SLIPS. CUT OFF 13-3/8". C WELD ON FMC GEN IV 13-5/8"SMX13-3/8"M 50W BRADEN HEAD. DAILY:S24,200 CUM:$638,200 ETD:S638,200 EFC:$1,500,000 BACK OUT 9-5/8 CONN MW: 8.4 FSW TEST BRADEN ~D TO 1000 PSI. NU TBG SPL & BOPS C/O RAMS F/9-5/8" TO 3-1/2"X6" VARIABLE. TEST RAMS TO 5000PSI. RETR RTTS STORM PKR, L/D. PU 8-1/2" BIT W/CSG SCRPR RUN ON 3-1/2" DP TO 2330. CIRC & C/O W/DIESEL. REV OUT TO BALANCE. TOH L/D CSG SCRPR PU FTA#2 BACKOFF TOOL ASSY. TIH ON 3-1/2" TO 2366'. SET BTM ANCHOR W/1200PSI SET 12M ON. SET TOP ANCHOR W/1800 PSI, SET ADDITIONAL SM DOM. PU-S/O 61M BACKING OUT 9-5/8 CONNECTION @2157'. NOTE BACKOUT i TURN @ SURF @ 0600. DAILY:S38,200 CUM:$676,400 ETD:S676,400 EFC:$1,500,000 11) SETTING CSG SLIPS MW: 8.0 OBM BRK 9-5/8" CONN @ 2157' W/7 L TURNS W/TRISTATE TOOL. TOH, LD TOOL. PU SPEAR, TIH ENGAGE FISH, ROT 6 LH TURNS. TOH LD FISH W/COLLAR DOWN. FISH 23.5'LONG. TEST 13-3/8"X9-5/8" TO 2000. PU TRISTATE TRIPLE CONN. SUB W/ 9-5/8"BTC BOX W/CUT LIP GUIDE & 9-5/8" 10' PUP, BAKER LOCK TO BDT EXT CSG RKR & BKR LCK TO 9-5/8" 10' PUP JT MOD. TIH RAN 48 JTS 9-5/8 479 L-80 BTC MOD & 25' 9-5/8" PUP TO LAND @2153. CIRC DIESEL, THEN DISP W/8.0 PPG OIL BASE MUD. TAG &SCREW INTO 9-5/8" BTC PIN LOOKIN UP AT 2157' W/13 RH TURNS. 11000FT9 TORQUE. TEST 9-5/8"X13-3/8" ANNULUS TO 2000 FOR 15 MIN. ND BOP,TBG SPL. SET EMERG CSG SLIPS. DAILY:S103,700 CUM:$780,100 ETD:S780,100 EFC:$1,500,000 Signature~ ~%~ For form pre~3aration and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 DRLG ON EZSV@8759 MW: 8.4 FSW CUT 9-5/8" CSG ABOVE SPOOL. INSTALL UPPER & LOWER 9-5/8" CSG PKOFFS. NU TBG HD & BOPS. TEST PKOFFS TO 3500. PRESS 9-5/8" TO 2500 TO SET BROWN EXT. CSG PIN @2300PSI TEST 9-5/8" FOR 30 MIN ~ 3000. BROKE OUT TIW-XO & CUT JT F/25' LANDG JT. LD. C/O 9-5/8" RAMS TO 3-1/2-6"VBR. TEST. MU BHA-TIH W/ 3-1/2" DP TO 2205. DISP OIL MUD W/ 20 BBL DIESEL SPACER & 8.4 PPG FSW. CONT TIH TAG @ 8715. DRLD CMT STRINGERS FROM 8715-8758', I o~%~. ITM Drilling Supt. ' AR3B-459-2-B INumber all daily well history forms conseculively JPage no as they are prepared for each well. I ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lllterlm" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil string until completion. District Field I County or Parish IStale ARCO ALASKA INC. J NORTH SLOPE J AK I Lease or Unit PBU J DS 1-25 JWell no. Date and depth as of 8:00 a.m. 07/27/89 ( TD:10330 pB:10156 SUPV:BS.RB 07/28/89 ( TD:10330 PB:10156 SUPV:RJB 07/29/89 ( TD:10330 PB:10156 SUPV:RJB 07/30/89 ( TD:10330 PB:10156 SUPV:RJB 07/31/89 ( TD:10330 PB:10156 SUPV:RJB Complete record for each day while drilling or workover in progress AUDI 4 DRLG ON EZSV DAILY:S45,100 CUM:$825,200 ETD:SO EFC:$2,325,200 12) DRLG CMT MW: 8.4 FSW DRLD EZSV F/ 8759 - 8760'. TIH F/ 8760 - 8770'. DRLD STRINGERS F/ 8770 - 8808'. DRLD JUNK AND HARD CMT F/ 8808 - 8849'. TOH W/ 8-1/2" CO BIT. CHNG BHA (PU 2 BOOT BASKETS) AND RIH TO 8847'. DRLD CMT F/ 8849' TO 9104'. DAILY:S33,300 CUM:$858,500 ETD:S858,500 EFC:$1,500,000 13) DRLG CMT AT 9695'. MW: 8.4 FSW DRLG CMT IN 9 5/8" CSG FROM 9104 TO 9312, CIRC HI VIS PILL, POOH, LD BHA,PU 6" BIT, TIH DRLG CMT IN 7" LINER FROM 9312' TO 9695'. DAILY:S30,942 CUM:$889,442 ETD:S889,442 EFC:$1,500,000 14) TIH SCRAPING 9-5/8" MW: 8.4 FSW DRLD CMT F/9695'-10144 PBTD. PUMP 50 BBL HEC SWEEP @ 9821' WHILE DRLG. PUMP 100BBL HEC SWEEP AROUND @ 10144'. TEST 9-5/8" & 7" CSG TO 1500 PSI FOR 30 MIN REV CIRC. DISP. HOLE W/CLEAN 8.4 PPG FSW @ 5 BPM 1250 PSI. POH. LD 2 JTS 3-1/2" DP. BOOT BSKTS WERE EMPTY. TIH W/ BHA. SPACED OUT 9-5/8" CSG SCRAPER IN 3-1/2" DP. DAILY:S27,607 CUM:$917,049 ETD:S917,049 EFC:$1,500,000 15) RUNNING 5-1/2" COMP MW: 8.5 FSW SERV. RIG. FIN TIH W/ 6"BIT & 9-5/8" SCRPR ON 3-1/2. CIRC WELL CLEAN @ 10144. PUMP 50 BBL HEC SWEEP FOLLOWED BY INHIBITED FSW @ 5 BPM 1200 PSI. TOH, LDDP. SLIP & CUT LINE. FIN LOADING PIPE SHED. STRAP SAME. PULL WEAR BUSHING. RU FLOOR TO RUN 5-1/2" 179 L-80,BTC MOD IPC. MU 4-1/2" TAIL PIPE ASSY & BAKER SB-3A PKR ASSY. TIH ON 5-1/2" TBG. DAILY:S24,743 CUM:$941,792 ETD:S941,792 EFC:$1,500,000 16) ND BOP MW: 8.5 FSW CONT. TIH W/ 5-1/2" 179 L-80 BTC MOD IPC TBG. PU CAMCO SSSV, ATTCH & TST 1/4" CONTROL LINES @ 5000 PSI, TIH PU FMC GEN III TBG HGR, MU & TST. LAND STRG PU WT 156M. S/G WT 123M. RILDS. PUMP 139 BBLS DIESL W/C-120 CI DN TBG @ 3 BPM W/350-800PSI, U-TUBE W/600-0 PSI. DROP 2" BALL. PRESS UP ON TBG W/ 3000 PSI HOLD 10 MIN. BOLDS. PU 5-1/2" TBG STG WHILE HOLDING 3000 PSI ON TBG. SEAL ASSY SHEARED W/ 40009 OVER STRING WT. LAND 5-1/2" TBG, RILDS. PU WT 150 M, S/O WT 118M. TST TBG @ 3000 PSI FOR 30 MIN & ANNULUS FOR 30 MIN. LD LANDING JT. SET BPV. ND BOP. (CAMCO 'BAL-O' SSSV @ 2173', BAKER 'SB-3A' PKR @ 9274, & TT @ 9405'.) DAILY:S279,200 CUM:$1,220,992 ETD:S1,220,992 EFC:$1,500,000 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IT,t,e ~, ~,,,ng Supt. AR3B-459-2-B Number all daily well history forms conseculively las hey are prepared for each well, Page no. ARCO Oil and Gas Company Daily Well History-Final Report . Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official lest is not required upon completion, repo~1 completion and representative test data in blocks provided. The "Filial Repo~l" form may be used for reporting the entire operation if space is available. I Accouniing cost center code Dislrict I SIaI~i.K ARCO ALASKA INC. PBU ICounty or Parish NORTH SLOPE Lease or Unit ADZ,: 28329 Title WORKOVER DS 1-25 I Well no. Auth. or W.O. no. AS3129 API: 50-029-20874 Operator ,^.ri. Co. W.,. rrota, number of wells (active or inactive)on this, I ' Icost center prior to plugging and I ARCO 21,0000 labandonment of this well Spudded or W.O.sPUDbegun IDate 07/15/89 ./IH0ur 1800 IPrlor status if a W.O. Date and depth Complete record for each day reported as of 8:00 a.m. AUDI 4 08/01/89 ( 1 TD:10330 PB:10156 SUPV:RJB RELEASED 1200 7/31 MW: 8.5 FSW ND BOPS, NO TREE, 1/4" CONTROL LINES TO 5000PSI. PULL TEST PLUG. SHEAR OUT BALL CATCHER SUB W/3400PSI DN TBG. W/1000 PSI ON ANNULUS BLEED OFF TaG & ANNULUS PRESS. SET BPV, RELEASE RIG & SECURE WELL @ 1200 NRS 7/31/89. DAILY:S37,050 CUM:$1,258,042 ETD:$1,258,042 EFC:$1,500,000 Old TD New TD PB Depth Released rig Date K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. : Date Reservoir Producing Interval Oil or gasTest time Production 011 on test ~Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Theabove, t ........ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C iNumber all dally well history forms consecutively as they are prepared tor each well, jPage no. Dlvl,do~t of Atl~flcRichfieldCompany ADDENDUM WELL WORK LOG SUMMARY Well # 1-25 Date: 9/15/89 Work performed: CTU SQUEEZE Cost: $65.769.8~; AFE: KS0684 50 bbl of Halliburton's acid resistive cement (ARC) were pumped during the 1-25 squeeze to repair leaking squeeze perfs. Well 1-25 had been squeezed during the rig workover, but salt from the kill pills appeared to have blocked the perfs, resulting in a poor squeeze. This CTU squeeze was Halliburton's first job pumping their ARC blend. The job had been delayed due to problems obtaining a cement that met the desired specifications. Squeeze pressure was brought up to 1500 psi with 5 bbl behind pipe, and then increased to 2300 psi. WHP broke back twice while walking on up to 2300 psi, resulting in 5 additional bbl placed behind pipe, for a total of 10 bbl cement behind pipe. The well was cleaned out with the combination ball nozzle, pumping 2# biozan. Bbl for bbl returns were noted. One bbl was pumped maintaining 1000 psi WHP overnight. SIGNATURE DATE TITLE ARCO ALA3-"KA: iNC, ~:' F1 B I.J.~ '~ ~"'~ ~"; 5 A ,'4 ANCHORAGE, ALASi<A 995' i "':..:' ..... DA!~· ~ , R,"r'E ,ENCE ARCO PRE¢$URE DATA i-t9 i-25 2-25 i i :J-"2 i t S-6 i i 5-6 ._"5,-8 3-2¢ v-'~i i i S-:.~ >5 i i S--~,S, i i 7-5.3 i 7-54 i 9-9 i 9-24 i 9-:34 i i6-9 i i6-t8 i iT-iS i - i ".,-"'-89 '-- 8 ~:-~C:' 0... -8-8o,. -t i .... 89 -- i 7;-89 - i 6-89 - i 2-89 ! :..' · - i 6,-89 -9-89' - i 6,-89 t -5-89 ! -i 5-89 t-t6-89 !-i6-89 i - i t -q'-' i-t9-89 i -9-89 BHF'--$TATIE: GRADIENT BHP--S'TATIC GRADIENT BHF ....FLOWING GRADIENT BHF ..... FLOWING GRADIENT BHF ....I::LOW :!: NG GRAD I EMi" BHF: ..... £'TATiC, ,-.-~,.~.oI;"'""~'" ENT BHF ....Fl..OWiNG G i:;.: A T:, l E:N-.',' BHF ....FLOWING GRADIENT !.:~HP--F LOW I i'"~G GRADIENT P.~4{:'-- VT;:'F T C GRADIENT · ..~ ,. ~ ~.- , i~ ~ .~. , BHP--$TATI~ CRA~IFNT BHP--PRESSURE FALL-OFF BHF .... STATIC GRADIENT BHP--$T~TIC GRADIENT SHF ....STATIC GRADIENT ~HP--$TATIC CR'.A~ I EN'~ ',_~HF ~, A~ I ~RADILNT CAMCO CAMCO CAMCO CAMCO CAMCO F:AMCO CAMCO CAMCO CAMCO CAMCO CAMCO CA~CO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PI_EASE SIGN AND RETURN THE ATTACHED RECEIVED BY HAVE A NICE DAY!. SALLY HOFFECK EF..' ATO-i.,.-,~'~° FEB 1 5 !9¢ . Oil & Gas Cons. Com Anchomgei COPY AS RECEiPF OF DATA, APPROVED ~__ 'FRANS.S 9¢,6~2 DISTRIBUTION CENTRAL FiLE,S -.-'"' CHEVRON D & M ~ '"' EXTENSION EXPLORATION ~ EXXON ~ ~ MARATHON ~ ~ MOBIL ~ F'HILLIF'$ F'B WELL FILES R & D BPX STATE OF ALASKA TEXACO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA[[S 1. Type of Request: Abandon __ Suspend __ Alter Casing ~ Repair well Change approved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100;560 Anchorage, AK 99510-0;560 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, TION, R15E, UM At top of productive interval 2764' FNL, 2;576' FEL, Sec. 7, TION, R15E, UM At effective depth 2421' FSL, 2545'FEL, Sec. 7, TION, R'I5E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, TION, R15E, UM Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate __ Pull tubing ~ Variance __ Perforate __ Other 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED 'FEB 12. Present well condition summary Total depth: mea§ured 10;530'ND feet true vertical 9282'TVD feet 10290 'MD Effective depth: measured 9244 'TVD feet true vertical feet Casing Length Size Structural 80 ' 2 0" Conductor 2591 ' 1 ;5-;5/8" Surface Intermediate 9579' 9-5/8" Production Liner Perforation depth: IGIN A % 6. Datum elevation (DF or KB) RKB 74 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number -25 9. Permit number 82-20;5 ~0. APl number 50-- 029-20874 Plugs (measured) Junk(measured) None None 11. Field/Pool Prudhoe Bay Oil Pool Cemented Measured depth True vertical depth 1895 # Poleset 79'MD 79'TVD ;5000 sx CS Ill & 2624'MD 2624'TVD 400 sx CS II 500 sx Class G & 96'lO'MD 86'I;5'TVD 49 bbls CS I 1011' 7" ;500 sx Class G 9;517'-10;528'MD measured 9610 ' -961 2 ' MD, 9778 ' -9796 ' MD, 9806 ' -9811 'MD, 9890 ' -9900 'MD, 100't ;5 ' -10073 'MD true vertical 86'1;5'-8615'MD, 8761-8777'TVD, 8787'-8791'TVD, 8864'-887;5'TVD, 8980 '-90;57 'TVD Tubing (size. grade, and measured depth) 5-1/2", L-80, tbg w/tail (~ 9405' Packers and SSSV (type and measured dc~h6~ WRDP 555V e 2172', Baker SB-;SA pkr e 9274' feet Description summary of proposal ,,, Detailed operations program 13. A~achments 15. Status of well classification as: 14. Estimated date for commencing operation Start Date: February '15, 1990 Date approved Oil ~ Gas__ Service 16. If proposal was verbally approved Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~/ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ~,poroved Copy · 'Returned, 0~iG!~AL SIGNED BY Approved by order orCe Commission 8;56;5 ' -9280 'TVD BOP sketch Suspended~ Date IApproval No]c,¢ -¢ 7 Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 1 - 25 WORKOVER PREUMINARY PROCEDURE · Pull the 5-1/2" completion. - · Mill and Retrieve the 9-5/8" Baker'SB-3A' permanent packer. · Clean outto PBTD. · Run a 4-1/2" scab linerto coverthe existing 7" iner. · Run a new 9-5/8" permanent packer and re-run the 5-1/2" completion. Coordinate with the wireline group and perform the following slickline work: · Puli the Camco SSSV at 2172'. · Set a 4-1/2" Otis 'IUD' pump out plug (shear value = 2050 psi) in the XN nipple at 9317'. · Pull the RKED from the bottom GLM at :!:9172' MD. 1. 'MIRU AUDI Rig 4. Kill and displace the well with 8.5 ppg seawater. 2, ND Tree. NU and test BOPE. 3. Pull and LD the 5-1/2" completion. and plan to re-run in this well. 4. Mill and retrieve the Baker 'SB-3A' permanent packer at 9274' MD. 5. RIH w/ 6" mill and dean out to PBTD at 10156'MD. POH. 6. Run and cement a 4-1/2" scab linerto cover the existing 7" liner. · . Have all the tubing and completion accessories inspected RECE'IVEO 7. Drill/dean out the 9-5/8" casing to the TOL Pressure test the 9-5/8' casing and liner lap. 8. Drill/dean out the 4-1/2" liner. Pressure test the 4-1/2" liner. 9. Dross the linertie-back sleeve. 10. Run a 9-5/8" permanent packer and re-run the 5-1/2" completion string with a CIM and GLM's. 11. Freeze protect the permafrost interval with inhibited diesel. Set the packer and pressure test the tubing and annulus. 12. ND BOPE. NU and test the Tree. BI-E' = 356O psi at ~0o' TVO (8.o ppg equ~veJent) Bruce Smith 1-11-90 13-5/8" 5000 PSI BOP STACK ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 TUBING HEAD 3 1.13~3/8" CASING HEAD 2.9-5/8" CASING HEAD 3.5000 PSI TUBING HEAD 4.13-5/8" - 5000 PSI BLIND RAMS 5.13-5/8" - 5000 PSI PIPE RAMS 6.13-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEl 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5, INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI, 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES, 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM, BLEED SYSTEM TO ZERO PSI, 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI, 10, OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP, 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. R CE!V[ DAM 8/4/89 REVISION OF11/21/S6 BOP SCH (FOR:AUDI 4,NORDIC 1, ~ ARCO AL.A;~t,'.'.'A: iNC., F' !3 ~ F:;-'v i (~,;:',¢;At~, ANCHORAGE, ALA3'KA 995:i '-:.'!:, REF'ERENCE' ARCO CA;~ED H, OLE F'Ii'~AL~: .-o~' i F:;-':'~'--'-°"-;' 'FHD Ri I~-,J i , ~-:" ~ _,... :: ~ ..._,, i...t : . ..~,, .. _.- 'm ' -""', .- '::'- R IJ i",! ':~'" -,=~ i i _oc:, ..... ...... ; I I'~ lJ' i ; 4-i 6 i ;3'-26-89 C. AHMA D;~'N RUN i; .5:" 4-24 i0-26-89 ';]ANNA DSN RUN i; ~:' =;'-i--,-'"' i '3'-28-'89. GAMMA i);:-?N f;.fl, ji".~, i , ..:-~':'" ........Pi F:A?F- 3'i(:.N AND RE'i-URN 'FItF Al-T;;;.''~'''i:'''''-~U,~.L; COF'Y fi;~' RECEIF'T OF: DA'FA, liA;,/E A NiCE DAY" JAN 1, 0 lg O E.:ALLY HOFFECKER-' A T O- i S',.~':? Ala$1~ 0il ~ ~ ~m~, ~.l~lll~l(~ Anchorage APPROVIED .~__ 'i'RAN;~.'.'~- 900'0 i LJ '::' , ~ I._ ,.~ J-il_;-'..:' !~! !... ;~..' H i_ ;~." F! ..'-L. ;~.' D I S." T R I BUT i ON · ,,-'"' CENTRAL F-ILE3' .,,-'"' CHEVRON D & M '~' FXTENSTON E':~F:'I_OF:A T i F,'N ~ EXXON MARATHON · " HF~BII_ · .-'"' F' I-I I i,... ,_i I F' ,~' F'B WFL. L FILE. S-' R & D ~ BPX = ~TAi"E 01' ALA~$'I<A ~'~. TFXACO ARCO ALA~"KA: ii'.!C~ P,. O, BOX ~ ,::':, (') S 6 ,:_:) ANCHORAGE, ALA,'~'KA 99~i ,."_:.~ F;:.EF:EF;..'ENCE:' ARCO HA£-~NE:TtC TAPE(S) WiTH L..I2TIN('~.(/.'i:) 'i - 2 ~5 'i (9 '"' 22 '-' 89 ","' M D 'i .... 26 '~ (!:'-2i .... 89 "!"MD 'i 4-'i 6 'i G'-26""89 GAMMA DS-'N 'i 4-'2-'"'.I. 'i;. ';'}- :.'2 6"' :3 9 C;-AMMA ~ 15 .... 'i 4 'i ,3,-28-89 GAMMA DSN · J 0 B-',~ 'i JOB:if' '1 56S9X · ..! 0 B :~ :56 '7279 ,.J 0 B ~: S 6 '728 X · ..J 0 "-'~1_-_. '"... .5" 6," ":',... ':'):- r'-.:,, F:'i.. E A $ F.!: ,? I ('.;- N A N 1) F;..' E't" U t:;,' N T kt E: A T T A C I-.1E D C 0 P Y A i.' R E C E.:. I P T 0 I::' D A T A., !;..' ii-" C I:T. :1: V E D B Y H;AYE: A NICE ,:::,A:,", RECEIVED ::?AL. LY I"iOF:'FEC':KER JAN 0 ATO- i ~29 Alaska Oil 'Gas Cons. Anchorage D I :~:TR I BUT I ON '"'.,-CENTRAL i::I:L.E:~' r, Cl'-l) C H E V R 0 N D & M TAMMA~-: BROWN ([)Fl) · " ~: "--' X fi N MARATHON HOB I L AF:'F'RO Vl~i:l) .... [i~.. .... F.,r:~..~ ~ 9 (.~,3,;Y2 ~ F'H I L.L I F',S' PB I,,Ji~::l...i.. F:'IL.E.,.:. R & D -.-~'- B . F:' X · .-'"' ;~.'I"ATF: 01:: ALA;~,'KA i"EXACO ARCO ALASKA, INC. ANCHORAGE, ALASKA DATE - -8-89 REFERENCE. ARCO CASED HOLE FINAL~ i-3 8-~3-89 PERF RECORD i-3 8-~6-89 F'ERF RECORD ~-25 1~-22-89 t-25 t¢-oo o' DSN (2 i-26 t¢-2t-89 DSN (3 3-27 8-t2-89 F'ERF RECORD ~-'~7 8-t4-89 F'ERF RECORD 9-16 9-4-89 PERF R¢¢ .... ~6-24 8-7-89 PERF RECORD RUN t RUN ~, PLEASE ;~'IGN AND RETURN THE ATTACHED COPy A~' RECEIPT OF DATA, RECEIVED BY' HAVE A NICE DAY~ ' V ~ALL Y HOF'FECKER. ATO-i 5:29 ~ ~08IL DISTRIBUTION CENTRAL FILE,2 CHEVRO~¢.- ~ PHILLIPS' D & Pi PB WELL F'I:LEs, EXTEN£ION EX'PLOR'A'FION R' & D EXXON ~- BPX HARA1H · ' ' ON ~ STATE OF ALASKA TEXACo RUN RUN RUN RUN RUN RUNS RUN ARCO Ai. ASKA, INC'~ P.. 0 ~ BOX i ANCHORAGE: ALA,S'KA 995 DATE' t t-8-89 REF'EF:ENCE' ARCO MAGNETIC TAF'EL(.S') WIi"H I...i.'_'?l'IN[.~,::.:'9) -'2 ':~.., -26 ¥-28 ,;. Pl..lEASE SiGN R Iii: C E I ¥ E D B Y i ,.")....22-89 DSN (2 i/8" & S S/8" ) JOB.St S64(.},:'.} i(.)-.2i .... 89 DSN (S ~/8") ,.JOB~tS6~i~9X i':'] .... tS-89 F'DK-tOG (.3 F'AS,S") i0-tS-89 F'DK-'iO':') (S PAS£,') ,JOB.~:L~4(')S HAVE A NICE DAY! SALLY HOFF'ECKER AT0.-t529 RECEIVED APF'ROVEi) .~._ CEN'FRAL FILES (CH) CHEVRON D&M TAMMAS BROWN (OH) EXXON MARATHON MOBIL -,- F'I"I I L.L I F',S' PB WELL. FILES R & D "~ BPX $'F~TE OF ALASKA TEXACO H L. ,";,' HI...;S' A fLA.'_:.;,' A"I"I..A S ARCO ALASKA, INC. F'.O. BOX i0056~ ANCHORAGE, ALASKA DATE' REFERENCE' PLEASE £IGN RECEIVED BY HAVE A NICE SALLY HOFFE AT0-t529 ARCO CASED HOLE FINALS 8-i3-89 PRODUCTION PROFILE RUN i, 5' CAMCO ~-'22-89 CNL-GR RUN t, 5' ATLAS ~-°i~ -89 F'DK-iOG/GR/CCL RLJN. i, 5" ATL. A,S' G-i6-89 PRODUCTION PROFILE RUN t, 5' CAMCO 0-i9-89 F'ERF RECORD RUN i, 5" SCH G-20-89 CNL-GR RUN t, 5' Al'LAS ~" CAMCO 0-i5-89 PRODUCTION PROFILE RLJN t, ~ 0-t 5-89 PRODUCTION PROFILE RUN 1, 5 · CAMCO 0-i4-89.. PRODUCTION F'ROFILE RUN t, j:' C~tq.,O 0-i8-89 CNL RIJN 2, 5' SCH ~-i6-89 TEMF' SURVEY RUN i, 5' CAMCO 0-25-89 CNL-GR RUN ~, 5' AI'I_AS 0-25-89 CNL.-GW RUN 1, 5' Al'LAS ~-25-89 PDK-iS~/GR/CCL RUN t, 5' Al'LAS ~-t6-89 F'RODUCTION PROFILE RUN i, 5' CAMCO 0-ii-89 F'RODUCTION PROFILE RUN t, 5" CAMCO 0-ii-89 INJECTION PROFILE RUN i, 5' CAMCO 0-'7-89 F'RODUCI'ION PROFILE RUN t, 5' CAMCO 0-i5-89 TEMP RUN i, ~'>'&5' CAMCR_ 0-i4-89 COMPLETION RECORD RUN 1, 5' SCH · 0-t5-89 LEAK DETECTION RUN i, 2' CAMCO 0-4-89 TEMP RUN i, 5' CAM(](] 0-i4-89 PRODUCTION PROFILE RUN t, 5' CAMCO -i8-89 PITS RUN t, 5' CAMCO _ AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. DAY! CKER DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXF'LORATION EXXON MARATHON MOBIL . THE UORRE~.I'' '"r:'ED AP-It- FOR ** -THE CORRECTED-AF'I~ FOR *** THE CORRECTED AF'I~$ FOR ~. PHILLIPS F'B WELL FILES R & D ~ BPX -,,-"" STATE OF ALASKA ~t . . - 2 ~ z s ~ o- o 2 ~- 2 0 7 6 6, L ~ A~ Oil aa ~ . ~ Con~. ~mml~iO~ 4-25 IS 50-029-26757 ARCO ALA~KA, INC~ P~O~ BOX i0(')S6'3 ANCHOR. AGE, ALASKA 99.5~0 D A "1" E ' 7 - 2 6 - 8 9 F,:EFFF,:ENCE' ARCO CASED HOLE FINALS 'i "' 2.5: '?-- 2(~:'- 89 ACBt../VDL'-GAMMA S-29 '?-'i S""89 (;R 5,'f"EC, TOOL _. :) (:.~ ..... ) . ~-.,., ; .... ,.i -89 r:OL. LAR/F'ERF: 4.-.22 7-2 'i -89 C Ot_L. AR./f"ERF 9.-4 7-19-89 COLLAR/PEF;.:F ii :.'.4 ..... ' "" C'. - ;-,~,~.-89 Oi..LAR/PERF 'i 6-4 7-22-89 COLLAR/PERF:' i 8-24 7-20-89 CBT i 8--24 7-20-89 CET I:(UN i , 5" RUI~ 2, 5" F?. U N i , 5" RUN i, .5" R.U N t, 5:" i';;UN'i, 5" RLJN i, 5" RtJ N i, :S" I:~'.UN i , 5" F'i_EAZ~E ,'~:[GN AND RETURN THE AT'¥ACHED COPY A;~ RECEIF'T OF DATA. A T I... A,].:; ;:?CH A f L.A;j( A i I..AZ A 'f'i_..A~? A'f' i_ A ;:,;' A'i'I...AZ ;:,;' C i.-I 5'CH REC'.E:IVE:D BY ............... FiAVE A NICE [)AY!. i~~~~ ;~,' At...L Y HOF:FECKER ATO--i 5... . . DISTRIBUTION -.-'"' CENTRAL FILES ~,.~"CHEVRON D & M ~ EXTENSION E. XPLORATION ~ EXXON ........ MARATHON :~ MOBIL_ ~-'"' F'HILL !F',S' PB WELl_ F']:LES,' '"' BF:'X 3'i'A'i'E OF; F~LAS'KA -"- "I"EXAUO THE CORRECTE~::!~F.::i:~; :FOR :}4-20 ZS' 5e-,a29--209¢6, .-, ARCO Alaska, Inc. Prudhoe Bay _ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 21, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-25 Permit No. 82-203 Dear Mr. Chatterton: Attached, in triplicate, is the Application for Sundry Approvals to be performed on the above-referenced well. detailing work Very truly yours, D. F. Scheve DFS/WHS/ljm Attachment cc: T.B. Gray, BP Exploration J. Gruber- ATO 1478 Pl(DS1-25)W1-3 RECEIVED Alaska Oil & Gas Cons. C0mrnJss/0n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/ iLAND GAS CONSERVATION C( MISSION APPLICATION FOR SUNDRY APr ROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM At effective depth 2421' FSL, 2545' FEL, Sec. 7, T10N, R15E, UM At total depth 2414' FSL, 2556' FEL, Sec. 7, T10N, R15E, UM Operation shutdown Plugging Pull tubing Vadance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-25 9. Permit number 82-203 10. APl number 50 - 029-20874 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10330' MD feet 9282' TVD feet Plugs(measured) Effective depth: measured 10290'MD feet true vertical 9244'TVD feet Casing Length Size Structural 80' 20" Conductor 2591' 13-3/8" Intermediate 9579' 9-5/8" Liner 1011' 7" Junk(measured) Cemented Measured depth True vertical depth 1895 # Poleset 79' 79' 3000 sx CS III & 400 sx CS II 2624' 2624' 500 sx Class G & 49 bbls CS I 9610' 8613' 300 sx Class G 9317-10328' 8363-9280' Perforation depth: measured 9778-9796', 9806-9811', 9890-9900', 10013-10073' true vertical 8761-877'7', 8787-8791', 8864-8873', 8980-9037' Tubing (size, grade, and measured depth) 5-1/2"/3-1/2", L-80/N-80, tbg w/tail @ 9945' Alaska Oil & Gas Cons. '' A~c,borage Packers and SSSV (type and measured depth) Otis RQM SSV @ 2199', Baker FHL pkr @ 9288' & F-1B pkr @ 9918' (WLM) 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation 15. Status of well classification as: July 31, 1989 16. If proposal was verbally approved Oil x Gas Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '-~L)~c~"~------~/ ~;~']~)I==.~¢/~E-O~--- Title Operations Engineering Manager Date ~ ~ FOR COMMI.~ION U~l= ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. I Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH /~ Lf ~xpproved CoPY Return.ed ,~ Commissioner Date SUBMIT IN TRIPLICATE DS1-25 PROPOSAL SUMMARY ARCO Alaska, Inc. proposes to perforate DS1-25 following a rig workover and cement squeeze of the well. Upon perforating, the well will be flowed for cleanup. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested at 1.2 times the maximum expected surface pressure. The SSV will be installed at the conclusion of the perforating and cleanup operations. Perforations Type S PF Zone 10040-10073' MD Reperfs 4 2C 10078-10085' MD Contingent Adperfs 4 2B Note: All depths referenced to the Schlumberger BHCS dated 2/21/83. oil & Gas Eons, Commfssb.~, Ar~chorarle ARCO Alaska lac. is a subsidiary of Aflanlic Richfield Company H 1 REL I NE 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE). 3. 5000 PSI 4, 1/$" LUBRICATOR 4. 5000 Peal4, 1/6" FLOW TUBE PACK-OFF BOP EGU IPHENT Oil & Gas Cons. .Anchorage ANCHORAC-E, AL. ASKA 995i(3, DATE~ · 7-. i (3-89 REF'Ei:~:ENCE- ARCO CASED HOt. E FiNAL,S' i -.25< S-.-i 6-i 4-89 .'q--'~) A 6---'~ i --8° · ,,. ~. .... ~ ., : S--S4 6-i S..-87 ¥--S4 6-i 9....89 4-i 9 6.-i '.~-..-89 4-Si A-i 4-89 9-i6 6-i 8-89 i i .-i 6-i 6-89 i i-24 6-i 7-89 i :%-6 6--2S-89 i 4-2'7 6-2S-89 i 4-.S7 6-26-89 i 4-S8 6-2S-89 i 6-9 6-22-89 A/2.X-"~4/89,.:-. L. EAK DETECTION F'RODUC'F T_ ON F'ROF:' I i..E F'F;:.OI)UCT i ON PROF' I LE F't:;~ODUCT I ON F:'ROF.[ i..EE F' t T,S' I N J E C 't" I 0 N F:' R 0 F ! I._ E INJECTION PROFILiE PRODUC'FION PROFti_E PRODUCTION PROFILE INJECTION RROFIL. E PRODUCTION F'ROFIt_E PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PR. OF I LE F;.'. i...~ f-.~ i , ,..."~" c~....>'" I";.:I. JN i, ':~" RUN t , .5" R~J['4. i, 5" RUN t , .5" I:;,:UN i , .5" RUN i, .,-':~'" RUiH i , .5" F;:UN t , 5" RUN t, 5" R~JN t, 5" RUN i; ~' RUN t , 5" RUN I, 5" RUN i , 5" F'LEASE SIGN AND INEFUI<N THE ATTACHED t....~i-f AS RECEIPi" OF DATA C A Fi L; 0 C A i'l C O C A i',i C C) C A H C[] C A ~"~ C: 0 C A M C O C A H C O C A i'"i C 0 C A t,i C 0 t.;AMCO CAHCO C A M C 0 C A M C 0 CAMCO CAHCO RECEIVED BY HAVE A NICE DAY! SALLY I-iC)I::F'ECK ER A'FO t AF'PROVED ~_._ I'RANS~ 89~.86 CENTRAL FILES CHEVRON EXT. EN£IO~EXF, LORATiON EXXON-: .... MARATHON~. · MOBIL ~- I::'H II_L. I PS PB WELL F'ILES R & D ii: BF'X -.. Si'ATE OF' AI, A.S'KA -.--"' i"EX~CO AF;.".CO AI...A.?KA, INC. F:'.,C, BOX ~0(')'560 ANCHORA[:.E, AL. ASK 995 i ,.") DATE:' 7-i 0-89 t;..'EF'EFtE:NCE' ARCO CAS;ED HOLE FINAl_:? --.., / ,.-.. o ,=..I. / d, L. E: A K T' l 0 R t.; N i :3 -' 'i 6 '- 'i 4 - F~ 9 i::' !;..' 0 D U C "!" '_[ 0 N F' i:,' 0 i::' I i.. E I:;..' U N 'i 5-' 26 6 -'2 ~ '" 89 P i:~'. 0 I) U C T ]: 0 N P R 0 F:' ]: L.. E R U N 'i 3-:34 6-i 3-89 F'F,.:ODUC'I'ION F:'i.;,'OF.[LE RUN · .'3--34 6--i 9-...89 F']:"I"5' RUN i 4-t 9 6-i :5-..-89 :[NJEC'f'ION F'ROF:[t_E RUN i 4-5i 6-i 4-89 -I"[:-MP I:;:t..IN i 9-i ,5 6--t 8.-89 INJEC'f']:ON PROFILE RUN it--i 6-i 6-89 F'i:;tODUCT]:ON PROFII_E RLIN i i i -24 6"-i 7'-89 F'F;.:ODUCTION F:'I:;:OFII_E RUN i3 6 ' ":': R':;' ....... ..,N · - 6-,. .... -'.,, INJEC"f'If'iN F'ROFI~ E RI' f 4'-2'7 6-25-89 PI;,'ODUC]T:[ON F:'ROFILE F;.:UN t 4-'37 6-26-89 PRODUC'I-ION F:'ROFILE: F;,'UN t t 4-'.58 6-2;5'-89 F'RODUC'rION PROFILE RUN i6-9 6-2'2-89 PRODUC:TION F'ROFILE RUN i F'LEA&'E 5,~I6N AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA C A i".i L; 0 C ~ ~"1C L) C (:~ i:'i C 0 C r:~ M C 0 C r:~ ~'1C' 0 C ¢~ M C 0 C r::'~ id C 0 C A t'i C 0 C A i'i C 0 £;AMCO C (4 M C 0 C A i'4 C 0 C A H C 0 CAHCO DIZTRIBU'¥ION CENTn'AL,, FILES CHFVRON D &'~M ,- EXTENSION, EXF'LORATION EXXON MARATHON MOBIL : ~. F'H I t_L I F'.";,' F'B WELl_ FILE,",' R & D ii: B I::'X -,- :~ i'ATE OF' r::~t_AS'KA · "' 'i"EXRCO "'--" STATE OF ALASKA .... "'i; AL, ...,KA OIL AND GAS CONSERVATION COM M ON O J~'G '% APPLICATION FOR SUNDRY APPROVALS 1. Type Request: Abandon ,,. Suspend Operation shutdown __ Re-enter suspended well __ Alter casin~--V'" Repair ~ ~ Plugging __ Time extension __ Stimulate___ Change approved program __ Pulltubing.__~ Variance__ Perforate__ Other ~ ~e?-,;" ~.11~,~ J 2. Name~Oper~or ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 872' FNL, 594' FWL, sec. 8, TION, R15E, UM At top of productive interval 2764' FNL, 2376' FEL, Sec. 7, TION, R15E, UM At effective depth 2421' FSL, 2545'FEL, Sec. 7, TION, R15E, UM At total dep. th 2414' FSL, 2556' FEL, Sec. 7, TION, ELSE, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 74 ' Unit or Property name Prudhoe Bay Unit 8. Well number 1-25 9. Permit number 82-203 10. APl number 50-- 029-20874 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10330'MD 9282'TVD 10290'MD 9244'TVD feet Plugs (measured) feet feet Junk (measured) feet None None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 80' 2591' 9579' 1011' 20" 1895 # Poleset 79'MD 13-3/8" 3000 sx CS III & 2624'MD 400 sx CS II 9-5/8" 500 sx Class G & 9610'MD 49 bbl s CS I 7" 300 sx Class G 9317'-10328'MD measured true vertical 9778'-9796'MD, 9806'-9811'MD, 9890'-9900'MD, 10013'-10073'MD 8761-8777'TVD, 8787'-8791'TVD, 8864'-8873'TVD, 8980'-9037'TVD True vertical depth 79'TVD 2624 ' TVD 861 3 'TVD 8363 ' -9280 'TVD RECEIVED ;JUN Tubing (size. grade, and measured depth) 5-1/2"/3-1/2", L-80/N-80, tbg w/tail (~ 9945' Alaska 0il & Gas Cons. C0mm Anchorage Packers and SSSV (type and measured d0ep~hs) 'ROH' 5S$V @ 2199', Baker 'FHL' pkr @ 9288' & 'F-lB' pkr (~ 9918' (WLM) 13. A~achments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation Start Date: July 4, 1989 16. If proposal was verbally approved Mi ke Mi nder/AOGCC Name of approver 6/29/89 Date approved 15. Status of well classification as: Oil./~_. Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and. correct t9 the best of my knowledge. Signed ¢)''~ ~ ~/' J',~.~~-.~Title Regional Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical lntegrity Test __ Subsequent form required 10- ~ ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE sslon PBU DS 1-25 WORKOVER PRELIMINARY PROCEDURE OBJECTIVE: Pull the 5-1/2" completion, 9-5/8" FHL retrievable packer and straddle assembly. Mill and recover the 7" FB-1 permanent packer. Replace the 13- 3/8" Braden Head. Test the 9-5/8" casing. Cut, Pull and Repair the 9-5/8" casing as required. Squeeze the entire perforated interval. Run a 5-1/2" completion with GLM's. PROCEDURE: 1. MIRU AUDI Rig #4. Stabilize the wellhead to the rig substructure with chains, boomers and turnbuckles as required. 2. Kill and displace the well with 8.5 ppg seawater. Pump HEC pills if required to control the fluid loss. 3. ND tree, NU and test BOPE. 4. Pull and LD the 5-1/2" tubing and seal assembly. 5. PU 3-1/2" DP and retrieve the 9-5/8" FHL packer and straddle assembly. 6. Mill and retrieve the 7" FB-1 packer. . RU E-line. Set a 7" ClBP inside the liner above the perfs. Pressure test the 7" liner, lap and 9-5/8" casing to 1500 psi. If a leak is observed, MU a 9-5/8" RTTS and isolate the leak. 8. Set a 9-5/8" RTTS and Storm Valve at +_200'. Pressure test the RTTS and Storm Valve to 1500 psi. 9. ND BOP's and Tubing Spool. 10. MU 9-5/8" mandrel hanger landing tool and latch the mandrel hanger. Lift the 9-5/8" casing and set 9-5/8" emergency slips. Remove the mandrel hanger. Spear the 9-5/8" casing, lift and remove the emergency slips, slack-off the casing and release the spear. 1 1. Remove and replace the Braden Head. 12. Spear the 9-5/8" casing and land the casing in the Braden Head.with emergency slips. Install pack-offs and pressure test. 1 3. NU BOP's. 14. Retrieve the 9-5/8" RTTS and Storm Valve. 15. Pressure test the 9-5/8" casing and 7" liner lap to 2500 psi. If a leak is observed: 16. MU a 9-5/8" RTTS and isolate the leak. Cut, Pull and Repair the 9-5/8" casing as required. Mill up the 7" ClBP and clean out the liner to PBTD. RECEIVED 'JUN 3 ,'a 198.9 Alaska 0ii & Gas Cons. Commission 17. 18. 19. 20. Braden head squeeze the perforated interval. Drill out the cement, pressure test the squeeze and m-squeeze if required. POOH and LDDP. Run a 5-1/2" completion with GLM's. Displace the well with inhibited seawater and freeze protect the permafrost interval. Land the tubing and pressure test. ND BOPE, NU and test the tree. Shear the shear-out sub. Release the Rig. Turn the well over to Production to perforate. ANNULAR PREVENTER 6 PIPE RAHS 5 BLIND RAHS 4 TUBIN6 HEAD 1. 13-3/8" CASING HEAD 2. 9-5/8" CASING HEAD 3. 5000 PSI TUBING HEAD 4. 1;3-5/8" - 5000 PSI BLIND RAMS 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 1;3-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS ;3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ;3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. §. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI, 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11, TEST STANDPIPE VALVES TO 5000 PSI, 12, TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 21, 1986 ARCO ALASKA, :[NC,. F:" ,. C)~. B 0 X i (.) (.).."36 (-) ANCHORAGF-':, AI...AZK A R E F:' E F;.: E N C. E ' i -' 2 '"5 2 .... i i :') _.."") .~- -.~ ~...~ · z_.,i ,,:-, ::3 .... i ''~ · -4' "" ':~': ~.. 4-'/ 4 .... t.,- ~' 4 .... 26 "~' '-' ~ -7 '?-"S(~ 9"-28 t 8- i d ..- ,:. PLEASE ZIG ARCO CASED t-tOI..E F:.r. NAi...,5; 5-..-A-89 F'Rf']D F'F;:CiF ]:L..tE/L_E. AK L',E'f'E.C'I 1ON RUN i ':'" ....... .,. .. · ~ ...:' 5-~.4-89 -f'EEHF'/I""'I..U ! D DENZITY I-,' U N ..............::i: -.- 2 ,::~ - 89 C Fi L. t.. A R / I::' E R F R LJ N i , '"~' ", ~.:-... .o_ 9 ..~ i,_, 8 CNL.-GAMMA RUN ..,, .... i 8- 89 D ]: F' F' T Ii:: M P I:;: U N 5 - .3 '-" 89 I N J E C T i 0 N I::' I:;..' U F' I I.. E R U N !5".-:5-89 INJECTION I::'ROF' i i_..E/TiLMP RUN '5 -- 2 ¢. -- 8 9 CNI..-GAMi"~A !:;tUN 'i ~ .... t 9...'89 CNi...-..GAMMA RUN t ,...,'::'" :5--i 9-.-'.,:39 CNL..-L~AMMA RIJN 'i .. .5 --.E.~ ...- 8 9 ! N J E C Ir' I 0 N F:' R 0 F' I L. E:' R U N i , .~" 4--f-89 COLI_AR/t::'iERF RUN f , '5" ':~'--.~ c~--.°9 C:NL-GAMNA RUN i '3" ....' S--"~' '~"-:3~;',~, , C 01_ L A R / P El;..'!"-" RLIN · ]~-'29'"'89 COI..LAR/P[:'RF I:;..'U N 5-"~7"-89 DUAL BURST TD'r-F' RUN ~., :5" ~:;- .- .-i ...' ..,,-I ;-89 C:NL RUN t , ~"," :5-'-3~3-89 COLI_AR TO :':,'E'i' I:'~TCH RUN 1, .,-1.:'-'.. :8? LEAK DE"f'EC'I"ION RUN i, 2" 5--5-89 INJECT:ION PROFTLE/TENF' F;,'UN i, ~" 5;-8-89 FI..UID DENS]:TY/'f'Ei'~F' F;.'.UNt, ':~' ..,'"':.--8"-89 F't_UTD.,. DENS f'f'Y/"rEMP. RUN i , _,."~'" ":-' ;~ ' ""*- .~. .A, ". .-' '~ " . '" ,::,-,:'.6-'-R9.. L..L~L.L~aF',; F F.".RF RLIN 'i , ..:.=" N AND RETURN THE ATTACHED COF'Y AS RECEIF:'"f' OF:' DATA AT [..A U (~ ['1 L.' U C A ~'i C 0 A f'I..AS ~'::'~ '1" I... A A"I' i... A HI..,'~ A '['L A 5' t..I I..."-;' 5' CH ,:...,H HL£' C A t'i C r-~ C A i'~ C t .'..! C R M C f') C': A hi C 0 H I... 3' RECE]:VED BY iqAVE A NICE DAY! ,~;;A L i... Y HOFFECKER ATO-' t f5'29 Anchorage DISTRIBUTION ~-~' CENTRAL FILES ~-'"' PHILL-[F'$ ~ Ct-IEVRON PB WEI..L F']:L.E. 5' D & M 1;: & D ~,- EXT["'NS' I ON EXPLrjF,'A]" I ON .,. BPX -,-'"'EXXON. .,-'"'Z'f'ATE OF' ALA$1(A MARATHON -,-'"'1' [i:XP, CO ~' MOBIl.. ARCO Alaska. Inc. Post Office Box 100360 , Anchorage. Alaska 99510 '- Telel~hone 907 276 1215 Date' June 18, 1985 REference· ARCO CH Finals ~1-25 Spinner 6-7-85 Run 2 5" Camco /14-35 Spinner 5-30/31-85 i 5" Camco /15-17 CCL/Spinner 6-6/7-85 i 5" Camco ~ 18-3 Static Temp. 6-5-85 I 5" Camco l~- 18-3 Dynamic Temp. 6- 3-85 i 5" Camco Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 166 Chevron Expl. Services · Ext. Exploration Exxon Marathon Mobil Phit.iips PB Well Files R & .D SOhio State of Alaska Texaco ARCO Alaska, Ira. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Pressure Data D.S. 1-4 ~ 3-15-84 PBU/CDBR D.S. 1-25/-" 5-25-84 PBU/CDBR D.S. 1-26_f- 5-30-84 PBU/CDBR D.S. 3-19 ~-- 5-25-84 PBU/CDBR D.S. 3-22f' 6-29-84 PBU D.S. 3-23~- 5-24/25-84 CDBR D.S. 6-17~---- 6-16-84 Static Survey D.S. 7-7A: ...... 6-15-84 Static Survey D.S. 7-13'-~ 6-14-84 Static Survey D.S. 7-14,/ 6-14-84 Static Survey D.S. 7-16'-~' 6-30-84 PBU D.S. 7-16~-~ 7-2-84 PBU/CDBR D.S. 9-8~ 6-20-84 Static Survey D.S. 9-18/ 6-20-84 Static Survey .l ~ 6-21-84 Static. Survey D.S. 12-16~ 5-19-84 CDBR D.S. 12-17f 5-20-84 CDBR D.S. 13-33~ 6-22-84 PBU/CDBR D.S. 14-8~- 6-28-84 Static Survey D.S. 14-23 ~--5-16-84 CDBR D.S. 14-24~ 5-17-84 CDBR D.S. 14-25 5-18-84 CDBR D.S. 14-32~ 5-20-84 CDBR D.S. 14-33~ 4-29/30-84 CDBR D.S. 14-34 ~ 5-19-84 CDBR Otis Camco GO Camco Camco GO GO GO GO GO GO GO Camco Camco Camco Camco Camco /'/Please sign and ~ data. return the attached copy as receipt of Kelly McFarland ATO-1429F Trans. ~290 DISTRIBUTION ~hevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil ~ ~s ~ ~.,.~, .~. Ann~"'-'~s. Cot~/l~iss/o~ Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 14, 1984 Reference: ARCO Cased Hole Finals ~,- D.S. 1-21 5-4-84 ,-D.S. 1-25 5-26-84 ~D.S. 2-17 3-28-84 ~D.s. 3-13 5-21-84 ,~D.S. 3-27 5-18-84 ,,,D.So 4-1 5-6-84 ~.D.S. 4-4 5-14-84 ~D.S. 5-8 ~-5-84 ~D.S. 6-4 5-30-84 ~DcS. 7-20 4-18-84 ~D.S. 12-16 5-20-84 ~'D.S. 9-4 5-7-84 jD.S. 7-25 4-22-84 ~D.S. 7-22 4-20-84 ~D.S. 12-18 6-1-84 ,~D.S. 12-23 5-19-84 ,-~D.S. 14-2 5-3-84 ~-D.S. 14-25 5-18-84 /D.S. 14-32 5-20-84 /D.S. 14-34 6-5-84 ~,D.S. 17-1 5-24-84 Epilog Spinner Log Spinner Log/Basket Flowmeter CFS / Sp inner ACBL/VDL/S igna ture /GR Epilog CH CNL Epilog CP1/TDT-M w/listing Spinner PLS Epilog Spinner Sp inner CPL/TDTTM w/1 is ting ACBL/VDL/S ignatur e / GR Epilog CFS/Spinner CFS/Spinner CPL/TDT-M w/listing Collar/Perf Log ' P~leasl sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Run 2 5" DA Run ! 5" Camco Run 2 5" Camco Run ! 5" GO Run ! 5" DA Run 2 5" DA Run 1 5" GO Run 1 5" DA 5" Sch Run 1 5" Camco Run 1 5" DA Run 1 5" DA Run 1 5" Camco Run 1 5" Camco 5" Sch Run 1 5" DA Run 3 5" DA Run 1 5" GO Run 1 5" GO 5" Sch Run 1 5" GO Kelly McFar land ATO-1429F Trans. # 242 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Bo~ 360 Anchorage, A, a 99510 Telephone 907 277 5637 April 26, 1984 Reference' ARCO Cased Hole Finals D'S. 1-25J 3-18-84 / PFC/GR D.S. 3-19~'- 4-7h84 /' Collar/Perf . D.S. 3-22J 4-7-84 ~' Collar/Perf Log D.So 3-23~-~-4-7-84/~ Collar/Perf Log D S 5-9~--- 4-8-84-''''~ CFS/Temp Survey D S 7-16 / 3-10-84-' EPL D S 9-14f 4-6-84 ~-" Collar/Perf Log D S 9-17/ 4-6-84/ Collar/Perf Log D S 9-20 ~ 4-6-84//_ Collar/Perf Log D S 9-21 ~'~ 1-11-84- ACBL/VDL/Signature/GR D S 9-23~ 3-8-84/' ACBL/VDL/Signature/GR D S 9-25~' 4-2-84/ ~Epilog/Sandstone Analysis D S 12-26~'~.~2-19-84~ ACBL/VDL/Signature/GR D S 12-27/i~-6-84 / ACBL/VDL/S ignature/GR D S 12-28/ 3-28-84~- ACBL/VDL/Signature/GR D S 12-28.~ 3-30-84 ~D S 13-11 ~ S 13-11 ~S 1.3-98 D S 13-98 D S 13-98 D S 13-98 D S 13-98 D S 13-98 D S 13-98 ~ D S 13-98 'D S 13-98 ~D S 13-98 .~ 13-98 4-4-84 4-4-84 5-8-83 / 3-16-84. no date' 11-12-83 no date 2-13-84 2-19-84 2-18-84 3-30-84 2-14-84 2-16-84 Collar Log (used to cut tubing) Collar/Perf Log Diff Temp ~D S. 14-32~ 4-1-84/' Collar/Perf Log Run 1 U.S. 16 5-- 3-10-84//'. Completion Record Run 2 ~/./Please sign and return the attached copy as receipt of data. Have a Nice Day! DISTRIBUTION Kelly McFarland ATO-1429F Chevron D & M Dallas Drilling Ext. Exploration Exxon Getty Marathon Trans. ~171 5" DA Run ALL 5" GO Run 1 5" GO Run ALL 5" GO Run 3 5" GO Run 1 5 Sch Run 1 5 GO Run 1 5 GO Run 1 5 GO Run 1 5 DA Run 1 5 DA 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" GO Run 1 5" GO Run 1 5" GO Epilog/Carbon-Oxygen 5-pass overlay5" DA CPL/GST/DIL (3 runs) w/listing 5" Sch Epilog/overlay avg. CO, SI/CA, SW 5" DA Epilog/Carbon-Oxygen 6-pass overlay5" DA Epilog/Compare Induction Curves 5" DA Epilog/Carbon-Oxygen 5-pass overlay5" DA GST Inelastic & Stations Run 3 5" Sch GST Capture & Activiation Run 3 5" Sch CH DIL Run 11 5" Sch CH CNL Run 4 5" Shc CH DIL Run 10 5" Sch 5" GO 5" Sch Mobil Mobil E & P ." ~- ~- (.. ~ " Phillips ,.' Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc, Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 18, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 1-24 Permit No. 82-127 DS 1-25 Permit No. 82-203 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 1-24,25)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ,-~'--' STATE OF ALASKA -J- ALASKa, .)IL AND GAS CONSERVATION C ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 COMPLETED WELL OTHER [] 4. Location of Well 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM 2764' FNL, 2376' FEL,Sec. 7 T10N, R15E, UM 2866' FNL, 2556' FEL, Sec. 7, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 74' RKB I ADL 28329 7. Permit No. 82-203 8. APl Number 50- 029-20874 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 1-25 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all 'pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operations 3/18/84. RU perf unit, pressure tested equipment. RIH with gun #1, flow well, shot 10053-10073' MD, 4 spf (20' Ref: BHCS 2/21/83), flow well to clean up, shut in well, POOH, all shots fired. RD, secure well. Resume wireline operations 3/21/84. RU perf unit, pressure tested equipment. RIH with gun #2, flow well, shot 10033-10053' MD, 4 spf (20' Ref: BHCS 2/21/84), flow well to clean up, shut in well, POOH, all shots fired. RIH with gun #3, flow well, shot 10013-10033' MD, 4 spf (20' Ref: BHCS 2/21/83), flow well to clean up, shut in well. RD, secure well. RECEIVED . 14. I hereby c..ertify that the foregoing is true and correct to the best of my knowledge. Ti,, The space below for Commission use Conditions of APproval, if any: By Order of Approved by_ COMMISSIONER the Commission Date ..... .I Form 10-403 Rev. 7-1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,,--'- STATE OF ALASKA .-'~' ALASK. 31L AND GAS CONSERVATION MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED []- ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-203 3. Address 8. APl Number /-~ P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20874 / 4. Location of well at surface 9. Unit or Lease Name 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2764' FNL, 2376' FEL, Sec. 77 TiON, R15E~ UM DS 1-25 At Total Depth 1 1. Field and Pool 2866' FNL, 2556' FEL~ Sec. 7~ T10N~ R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 74' RKBI ADL 28329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 2/9/83 2/21/83 3/28/83I N/A feet MSL 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10330'MD~ 9282'TVD 10290'MD~ 9244'TVD YES ~ NO [] 2185' feet MDI 1900' Approx, 22. Type Electric or Other Logs Run CBL, DIL/SP/BHCS/GR: FDC/CNL/GR/Cal, CET: CBL; CBL/CCL/GR. Gau~e Rin~/JB. CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20~ ~A.b~ ~-~O Sur~. 79' 30" Installed w/1895# Poleset 13-3/8" 72.0# L-80 Surf. 2624' 17½" Cmtd w/3000 sx CS III ~ 400 sx CS II 9-5/8" 47.0# L-80 Surf. 9610' 12¼" Cmtd w/500 sx Class G ~ 49 bbls CS I for AP job 7" 29.0~A L-80 9317' 10328' 8~" Cmtd w/300 sx Class G :mt. 2~,. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9890-9900' MD (10') 4 spf Ref: BHCS 2/21/83 3½" 9945' 9918' 9806-9811' MD ( 5') 5½" -- 9288' 9778-9796' MD (18') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10013-10073' ~ (60') DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8688-8964' TVD . . 27. PRODUCTION TEST Date First Production '- : - I Method of Operation (Flowing, gaslift, etc.) 10/13/83I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/9/84 4.1 TESTPERiOD I~ · 768~ 2063 0 38 3239 Flow Tubing Casing Pressure CALCULATED . _~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 2010 N/A ' 24-HOUR RATEI~ 3931 -12733 0 33.5 2[~. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit rere ps None. ' ' Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit G/O Contact GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered ar]ri gravity, GOR, and time of each phase. G/O Contact O/W Contact 31. LIST OF ATTACHMENTS 9722' 9828' 9851' 10143' 8711' 8807' 8828' 9104' N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed-,,'4~ ~~,t~~'~-'~~v Title Regional_ En ~ neerv Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Pnrm 1N_A~7 ARCO Alaska, Inc. Prudhoe Bay i--'ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 6, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 1-24 DS 1-25 Permit No. 82-187 Permit No. 82-203 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfieldCompany STATE OF ALASKA .-- ALASKa. oIL AND GAS CONSERVATION C .vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-203 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20874 4. Location of Well 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM 2866' FNL, 2556, FEL, Sec. 7, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 74' RKB I ADL 28329 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number DS 1-25 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in T~iplicate) (Submit in Duplicate) Perforate E~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) OTHER [],~ / 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 1-25 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will.be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10013-1007-~3' MD (60') Ref: BHCS 2/21/83 Subsequemt Work Beported Date / / ' 14. hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~f/~~~~ Title Regional Engineer The space below for Commission use Conditions of APproval, if any: Approved Copy Returned By Order of the Commission Date t}~1 ~ ;9^L SI~,""""t., Approved by BI L09~lE I~. S~IITIt COMMISSIONER Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplidate and "Subsequent Reports" in Duplicate -NOvember 30; 1983 .- ~ere~ce: A~co ~essu~e Data . -. .'.. ~:'- ~,~ 'i:, ~ '-~'D~:S;-~ 1-25 '10-12-83 - .. D.;$. 3-11 ~/ 11-2-83 - . D.S ~-15 0-19-83 10-19-83 -. D.:S-, 9-6 ''ff~' 10-13.--83 D.'S. 16-11y 1'1-1-83 Static Survey :Static Survey Pressure Build-up Pressure Build-up Data Sheet Pressure Build-up Static'Survey Camco Camco Camco Camco Camco e Sign and return the attached copy as receipt of data. Kelly McFarland ATO-i429F Trans, # 617 Chevron Dallas Drilling t ~xxon {'Getty Marathon _DI STP~IBUTION · ;f } / - £ · ~hi'llips' ~~~ ' .... '" f& ~,' '~' Caroline Stol tin Sohio ~-~Stat~--6f-Alas~a . ARCO ,,~laska. Inc .... Po:;t ~, ,:Cl~C,: ;- ::c. Tole?hone c,'j7 275 1215 August 11, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Report of Drilling & Workover Operations Dear Mr. Chatterton- Enclosed are Monthly Reports of Drilling and Workover Operations for the following' DS 14-25 DS 14-31 DS 3-19 DS 3-20 DD 3-21 Pingut State #1 South Point State #1 Also enclosed is a revised Well Completion or Recompletion Report and Log fon~'DS 1-25.':~ The report previously submitted inadvertentl~y included perforations which had been squeezed under Item //24. Sincerely, M. A. Major Area Drilling Engineer MAM/C SM41 · tw Enclosures ARCO Alaska, Inc. Prudhoe Bay ,_,~gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 8, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 1-25 Permit No. 82-803 Enclosed is the Completion Report for work done on the above-mentioned well. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lmi Enclosures cc: J. C. Dethlefs R. Iden K. McFarland - File 100.0 J. R. Schuyler D. S. Smiley SOHIO Petroleum ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompany STATE OF ALASKA ALASK, .)ILAND GAS CONSERVATION ( flMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OI LX~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7, Permit Number ARCO Alaska, Inc. 82-203 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20874 4. Location of well at surface 9. Unit or Lease Name 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM DS 1-25 At Total Depth 11. Field and Pool 2866' FNL, 2556' FEL, Sec. 7, T10N, R15E, UM Prudhoe Bay Field , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 74' RKBIADL 28329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 1 15. Water Depth, if offshore 16. No. of Completions 02/09/83 02/21/83 03/28/83I N/A feet MS L 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost 10330'MD,9282'TVD 10290'I~,9244'TVD YES'Il NO [] 2185 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run CBL, D IL/SP/BHCS/GR, FDC/CNL/GR/Cal, CET, CBL, CBL/CCL/GR, Gauge Ri ng/JB, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" Instld w/1895# Poleset 13-3/8" 72.0# L-80 Surf 2624' 17-1/2" Cmtd w/3000 sx CS III & 4(~0 sx CS II 9-5/8" 47.0# L-80 Surf 9610' 12-1/4" Ontd w/SOO sx Class G & 4c. bbls CS I for AP job 7" 29.0~ L-80 9317' 10328' 8-1/2" Cmtd w/300 sx Class G cmt. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9945' 9918' 9890-9900' MD 8791-8800' TVD 5-1/2" --- 9288' 9806-9811' MD 8712-8717' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9778-9796 ' M.D 8687-8703 ' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A Ref BHCS: 2-21-83 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 10/13/83 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 10/15/83 12.0 TEST PERIOD I~ 2662 4912 0 67I 1845 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 852 N/A 24-HOUR RATE I~ 5324 9823 . 0 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9722' 8711' N/A GOC 9828' 8807 ' GOC 9851 ' 8828' OWC 10143 ' 9104 ' 31. LIST OF ATTACHMENTS 32. I ~erel~y cer~if'y that the f~)regoing is true and correct to the best of my knowledge Signed ~. ~;~~~ ~_~-/:---- ~'~/~z..,,~, Title Regional Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (mul[iple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reI~orted in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Wa[er In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". STATE OF ALASKA f- ALASK,..~IL AND GAS CONSERVATION L :"AMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well - REVISED - OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-202; 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20874 4. Location of well at surface 9. Unit or Lease Name 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM DS 1-25 At Total Depth 11. Field and Pool 2866' FNL, 2556' FEL, Sec. 7, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 74' RKB ADL 28329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/09/83 02/21/83 03/28/83 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 10330'MD,9282'TVD 10290'HD,9244'TVD YES I~ NO [] 2185 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run CBL, DIL/SP/BHCS/GR, FDC/CNL/CR/Cal, CET, CBL, CBL/CCL/GR, Gauge Ring/JB, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" Instld w/1895# Poleset 13-3/8" 72.0# L-80 Surf 2624' 17-1/2" Cmtd w/~000 sx CS III & z.00 sx CS II 9-5/8" 47.0¢ L-80 Surf 9610' 12-1/4" Cmtd w/500 sx Class G & z.9 bbls CS I for AP job 7" 29.0¢ L-80 9317' 10328' 8-1/2" Cmtd w/~00 sx Class G cml. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9890 ' -9900 ' 3-1/2" 9945 ' 991 8 ' 9806 ' -9811 ' 5-1/2" --- 9288 ' 9778 ~-9796' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT& KINDOF MATERIAL USED Block 26 (continued) 10102'-10104' 150 sx Class G 9610'-9612' 150 sx Class G 9942'-9944' 150 sx Class G 9610'-9612' 300 sx Class G blend 9861'-986~' 100 sx Class G 9610'-9612' 300 sx Class G 9822'-9824' 100 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of'Operation (Flowing, gas lift, etc.} Date of Test Hours Tested PRODUCTION FOR .OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing PresSure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ : 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .~ · ~ r.,~ ;,~ None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Sadl erochit GOC OWC GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 8711' 8807' 9104' FORMATION TESTS 9722' 9828' -10143' Include interval tested, pressure data, all fluids ~t,cove, e(t and gravity. GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ Title Area Dri 1 ] i nD Engr. Dale INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" 1-25 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1145'hrs, 02/'09/83. Drld 17-1/2" hole to 2640'. Ran 65 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2624'. Cmtd 13-3/8" csg w/3000 sx Cold Set III & 400 sx Cold Set II. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1000 psi - ok. Drld FS. Ran CBL f/2620'-surface. Tstd form - would not hold 10.0 ppg EMW. Pumped & squeezed 45 bbls of LCM. Retested form- held 11.8 PPG EMW. Drld 12-1/4" hole to 9625'. Ran 232 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 9610'. Cmtd 9-5/8" csg w/500 sx Class G. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW -ok. Drld 8-1/2" hole to 10330' TD (02/21/83). Ran DIL/SP/BHCS/GR f/TD - 9-5/8" shoe & FDC/CNL/GR/Cal f/TD - 9-5/8" shoe continued w/CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/49 bbls CS I & 131 bbls AP. Ran 25 jts 7" 29#/ft, L-80, BTC csg f/9317'-10328'. Cmtd 7" lnr w/300 sx Class G. Drld cmt to 10290' PBTD. Tstd lnr lap to 3000 psi - ok. Ran CET f/10290'-10000'; tool failed. Ran CBL f/10290'-9317'. RIH & set EZ drill retainer @ 10150'. Stung into EZ drill & pumped 200 sx Class G cmt; squeezed. Set 9-5/8" EZ Drill @ 92.~7'; sting into retainer & pumped 50 sx Class G. Drld on retainer & pushed to 10123'. Drld cmt to 10159'; tstd csg to 3000 psi. Ran CBL f/9200'-10150'. Ran CET f/9200'-10150'. RIH w/gauge ring/JB; stuck tool @ 9450' WLM. Worked tool - pulled out of rope socket; left CCL/JB/gauge ring in hole; top of fish @ 9402'. Fishing. Push fish to btm. Left JB/GR @ btm, recovered cable head/CCL/wt, bars. Perf 10102-10104. Set EZSV. RIH w/3-1/2" DP & stab in tool. Sqz 150 sx "G" cmt. Perf 9942-9944'. Set ret @ 9976'. Sting into ret. Sqz 150 sx Class "G". Perf 9861-9863, set EZSV @ 9834' Sqz w/lO0 sx Class "G". Perf 9822-9824', 9610-9612'. Ran GR/JB, CCL to 9826'. Set EZ drl cmt ret 9795'. Sting into ret, attempt to circ fr/lower perfs to upper perfs. Press up on upper perfs, form broke dwn. Sqz lower perfs w/lO0 sx Classy] "G". Set EZSV @ 9583' Sting into ret Sqz 100 sx Class "G" followed by 50 sx tail slurry of Class "GII. Drl E-Z drl ret. Drl cmt to 9621, wash dwn to 9644 Tst csg to 2000 psi Bled to 1000 psi Drl cmt stringers & was~i:,i-~ dwn to 9750' POOH Set EZSV ~ 9583' Sqz perfs w/200 sx Class "G" blend~=! followed by tail slurry of 100 sx Class G blend. Tag cmt $ 9144, LD joints DP. Drl cmt & EZSV to 9640'· Tst csg w/2000 psi, perfs took fluid.. DS 1-25 DRILLING HISTORY (Cont'd) TIH, rotate thru 7" lnr. Set EZSV @ 9555'. Sting into cmt ret. Sqz perf w/300 sx Class "G". Unsting. Drld E-Z drl ret & cmt. Drld cmt to 9625, wash 9625-9640. Tst csg, no leak at perfs. Drl cmt stringers & lower part of ret, CO to 9797. Tst csg, no leakoff. Drl EZSV & cmt to 9846'. POOH. Left I cone in hole. Mill @ 9846. Drld ret & hard cmt. CO. Drl cmt to 9985. Wash. Drld ret & cmt 10082-10120, wash to 10157. Wash & ream 9317-10156'. Ran CBL/CCL/GR fr/10108-9200'. Ran GR/JB to 9286. Displ hole to 9.8 ppg NaC1. POOH. RIH w/RTTS. Found leak @ 9942'. Set EZSV @ 9915'. Sqz 50 sx Class "G" followed by 50 sx Class "G" (old perfs 9942-9944'). Drill cmt rtr & CO to 10,156'. Tst lnr several times, lost pressure. Bradenhead squeeze 50 sx Class "G". Pull 6 stds DP, pump NaC1 thru DP, pull 10 more stds. Hold 2000 psi on squeeze for 5 hours. Wash 9916-10096'. Drl cmt to 10156. Bradenhead squeeze 100 sx Class "G". LD 12 jts DP. Hold 2000 psi for 5 hours. Drl cmt to 10156'. Test csg to 2000 psi. LD DP. Perf 9890-9900, 9806-9811, 9778-9796'. Ran GR/JB to 9960'. Ran tailpipe assembly. Pkr set @ 9918. Ran 3-1/2" tbg & 5-1/2" stradlepack compl assy. Attempt to land tbg twice w/o success. LD tbg hngr & tbg string. Set RTTS w/SSCV. ND BOPE, replace tbg spool. NU BOPE. Ran 5-1/2" tbg & 3-1/2" tbg w/ pkr @ 9288. Displace tbg w/diesel. Drop ball & set pkr. Set BPV. ND BOPs, NU tree & tst to 5000#. RR @ 1400 hrs 03/24/83. Gyroscopic survey run on 03/28/83. CSM/DH7' 1 lm 06/09/83 ~.-: (.J~ .~.- ~., :ARCO Alaska, : i:~i?'i ~: :: i.. :'_' pOst :offic'e :B0~36b: ': :::::::; ~ :' :: :.- Anchorage: Ai~ska 9951 "- ' Telephone907 July 13, 1983 Mr.. C. V. Chatterton Commi s s i oner State· of AlaSka Alaska-Oil'& Gas Conservation commission -. 3001 'Porcupine Drive Anchorage, AK 99501 SUBJECT- Monthly 'Report of Drilling & Workover'Operations Dear Mr.-Chatterton' Enclosed are Monthly RePorts of Drilling and Workover Operations fOr the following: DS 14-23 Pingut~ State #1 DS 14-24 South Point State #1 DS 13-27 DS 3-19 and Well Completion on Recompletion Reports and Logs for: DS 7-24 DS 13-28 Also enclosed are revised Well Completion or Re¢ompletion Reports and Logs for- DS 13-29 DS 7-25 Sincerely, M. A. Major Area Drilling' Engineer MAM/CSM34-sm Enclosures j ,.- · . . ARCO Alask'a. Inc. is a Subsidiary of AtlanlicRichfieldCompany - '"-" STATE OF ALASKA "'-"' Revised ALASKA..,;L AND GAS CONSERVATION C;,. ~MISSION WELL COMPLETION oR RECOMPLETION REPORT AND 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-203 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20874 4. Location of well at surface 9. Unit or Lease Name 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2764' FNL, 2376' FEL, Sec. 7, T10N, R15E, UM DS 1-25 At Total Depth 11. Field and Pool 2866' FNL, 2556' FEL, Sec. 7, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 74' RKBI ADL 28329 12. Date Spudded . 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore i16'N°'ofC°mpIeti°ns 02/09/83 02/21/83 03/28/83 N/A feet MS LI 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 10330'MD,9282'TVD 10290'ND,92#4'TVD YES [] NO [] 2185 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run CBL, DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CET, CBL, CBL/CCL/GR, Gauge Ri ng/JB, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" Instld w/1895# Poleset 13-3/8" 72.0# L-80 Surf 2624' 17-1/2" Cmtd w/3000 sx CS Ill & 4(10 sx CS II 9-5/8" 47.0# L-80 Surf 9610' 12-1/4" Cm~;d w/500 sx Class G & 4~. bbls CS I for AP job 7" 29.0# L-80 9317' 10328' 8-1/2" Cmtd w/300 sx Class G cmt, 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10102 ' -10104' 9890' -9900 ' 3-1/2" 9945' 9918 ' 9942 ' -9944 ' 9806 ' -9811 ' 5-1/2" --- 9288 9861 '-9863' 9778'-9796' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9822'-9824' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9610' -9612' N/A 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~'~' ~' :- ~"' ': t: ,~ ''~' ,' ',, None ,. ;., ! ~ !;: ~,~i~;":' Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadleroch~t GOC GOC O~C GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 8711' 8807' 8828' 9104' 30. FORMATION TESTS 9722' 9828' 9851' 10143' Include interval tested, pressure data, all ~l,Jids ~ecr,vered and qravity, GOR,and time of each phase. N/A 31. LIST OF ATTACHMENTS Dri]]ing Hist~or_y, Gyroscopic Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signedj~~~~ Title INSTRUCTIONS General' This form is designed for submitting a complete and correct well complet on report and og on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 :-ARCO Alaska,i-nc, ' , . Post_OffiCe Box 360 AnchOrage. Ala~99510 -. TelephOne'907 ~'? 563'7 June 23, 1983 Reference: Arco Cased Hole· Finals D. $.' 1-25 ~ 3-14-83 'D. S. 2-19 ~' 3-26-83 D.$. 2-21-~ 3-27-83 D.S. 2-23~ 3-25-83 D.S. 2-24~/ 3-23-83 D.S. 2-25w 3-23-83 D.S. 2-26~- 3-24-83 D.S. 6-9'- 3-3-83 D.S. 6-22~- 4-29-83 ' D.S. 13-'2A--'~-1-83 D.$. 13-12~ 3-31-83 D.S. 13-22/ 3-20-83 D.S. 13-98/ 3-17-83 D.S. 14-26 / 2-27-83 ACBL/VDL/GR/$ignature PLS/Sp£nner PLS/PBU-$pinner PLS/PBU-Spinner 'PLS/Spinner PLS/Flowmeter PLS/PBU-Spinner D~TNLL/GR - - . CCL & Perf Record ACBL/VDL/GR/Signature PLS/Spinner PLS/Temp/Spinner/Flowmet~r/HP/GR GR DDTNLL/GR Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA · Run 1 5" DA Run 1 5" DA Run 2 5" DA Run 1-3 5" GO Run 1 5" DA Run 1 5" DA- Run 1 5" DA Run 1 5" DA Run 1 5" DA e sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 385 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOB I L GETTY D&M STATE OF ALASKA DALLAS CAROL-/NE SMITH -~'r .... r ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 13, 1983 Mr. C. V. chatterton Commissioner State of Alaska Alaska Oil'& Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Report of Drilling & Workover Operations Dear Mr. Chatterton' Enclosed are Monthly Reports of Drilling and Workover Operations for the following- DS 7-24 DS 14-23 DS 13-28 DS 13-29 DS 13-27 South Point State #1 Pingut State #1 Sincerely, M. A. Major Area Drilling Engineer MAM/CSM' tw CSM/31 Enclosures P.S. Also enclosed are Well Completion or Recompletion Report and Log for the following wells' DS 1-25, DS 13-29, and DS 7-25. RECEIVED ,J"t.' i '" Absk~ 011 & Gas ARCO Alaska. Ir~c ~s e -C-~b~irH3rv' of AHantieRichfieldC..-:,mpmny 1. Status of Well Classification of Service Well oILX~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-203 3. Address 8. APl Number ./~,~, P. 0. BOx 360, Anchorage, AK 99510 50- 029-20874 4. Location of well at surface 9. Unit or Lease Name / 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UN LOCATIONS Prudhoe Bay Unit ~J~L At Top Producing Interval r~ i VERIFIED 10. Well Number ~ 5NL, 2376' ~J~L, Sec. J-8, T10N, R15E, UN !Sud. F~i DS 1-25 At Total Depth (~p~ t_ ~ B.H. -- 11. Field and Pool _1Jt2~ $1~L-, 2556' ~/flZ, Sec. ~1~~, T10N, R15E, UN ' Prudhoe Bay Field ' 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 74' RKBIADL 28329 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' No. of Completions 02/09/83 02/21/83 03/28/83I N/A feet MSLI 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10330'HD,9282'TVD 10290'HD,9244'TVD YES;~ NO []I 2185 feetMD 1900' (Approx) 22. Type Electric or Other Logs Run CBL, DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CET, CBL, CBL/CCL/GR, Gauge Ring/JR, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# U-40 Surf 79' 30" Instld w/1895# Poleset 13-3/8" 72.0# L-80 Surf 2624' 17-1/2" Cmtd w/3000 sx CS Ill & 4tl0 sx CS II 9-5/8" 47.0# L-80 Surf 9610' 12-1/4" Cmtd w/500 sx Class G & 4! bbls CS I for AP job 7" 29.0# L-80 9317' 10328' 8-1/2" Cmtd w/300 sx Class G cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10102 ' - 10104 ' 9890 ' -9900 ' 3-1/2" 9945 ' 9918 ' 9942 ' -9944 ' 9806' -9811 ' 5-1/2" --- 9288 ' 9861 '-9863' 9778'-9796' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 9822'-9824' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9610' -961 2' N/A '1 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD e Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED · '-'~ STATE OF ALASKA ~. 0 R 16 i ~.J~_ [ ALASK~-~ ~,,L AND GAS CONSERVATION ~- 'MISSION WELL COMPLETION OR RECOMPLETION'REPORT AND LOG L~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29_ NAME Top Sadlerochit G0C GOC OWC GEOLOGIC MARKERS MEAS. DEPTH 9722' 9828' 9851' 10143' TRUE VERT. DEPTH 8711' 8807' 8828' 9104' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and Hravlly, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History~ Gyroscopic Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . Title Area Dri 11 lng Engr, Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and :24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". 1-25 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1145 hrs, 02/09/83. Drld 17-1/2" hole to 2640'. Ran 65 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2624'. Cmtd 13-3/8" csg w/3000 sx Cold Set III & 400 sx Cold Set II. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1000 psi - ok. Drld FS. Ran CBL f/2620'-surface. Tstd form - would not hold 10.~0_ ppg EMW. Pumped & squeezed 45 bbls of LCM. Retested form- held 11.8 PPG EMW. Drld 12-1/4" hole to 9625'. Ran 232 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 9610'. Cmtd 9-5/8" csg w/500 sx Class G. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10330' TD (02/21/83). Ran DIL/SP/BHCS/GR f/TD - 9-5/8" shoe & FDC/CNL/GR/Cal f/TD - 9-5/8" shoe continued w/CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/49 bbls CS I & 131 bbls AP. Ran 25 jts 7" 29#/ft, L-80, BTC csg f/9317'-10328'. Cmtd 7" lnr w/300 sx Class G. Drld cmt to 10290' PBTD. Tstd lnr lap to 3000 psi - ok. Ran CET f/10290'-10000'; tool failed. Ran CBL f/10290'-9317'. RIH & set EZ drill retainer @ 10150'. Stung into EZ drill & pumped 200 sx Class G cmt; squeezed. Set 9-5/8" EZ Drill @ 9287I; sting into retainer & ?~u~~sx~ Class G. Drld on retainer & pushed to 10123'. Drld cmt to 10159'; tstd csg to 3000 psi. Ran CBL f/9200'-10150'. Ran CET f/9200'-10150'. RIH w/gauge ring/JB; stuck tool @ 9450' WLM. Worked tool - pulled out of rope socket; left CCL/JB/gauge ring in hole; top of fish @ 9402'. Fishing. Push fish to btm. Left JB/GR @ btm, recovered cable head/CCL/wt, bars. Perf 10102-10104. Set EZSV. RIH w/3-1/2" DP & stab in tool. Sqz 150 sx "G" cmt. Perf 9942-9944'. Set ret @ 9976'. Sting into ret. Sqz 150 sx Class "G". Perf 9861-9863, set EZSV @ 9834' Sqz w/lO0 sx Class "G". Perf 9822-9824', 9610-9612'. Ran GR/JB, CCL to 9826'. Set EZ drl cmt ret @ 9795'. Sting into ret, attempt to circ fr/lower perfs to upper perfs. Press up on upper perfs, form broke dwn. Sqz lower perfs w/lO0 sx Class "G". Set EZSV @ 9583'. Sting into ret. Sqz 100 sx Class "G" followed by 50 sx tail slurry of Class "G". Drl E-Z drl ret. Drl cmt to 9621, wash dwn to 9644. Tst csg to 2000 psi. Bled to 1000 psi. Drl cmt stringers & wash dwn to 9750'. POOH. Set EZSV @ 9583' Sqz perfs w/200 sx Class "G" blend, followed by tail slurry of 100 sx Class G blend. ~Ecmt~V~,~)~@ 9144, LD 6 joints DP. Drl cmt & EZSV to 9640'. Tst csg w/2000 p_._p~,~ ~u~,luid. Alaska Oil /~ Gas DS 1-25 DRILLING HISTORY (Cont'd) TIH, rotate thru 7" lnr. Set EZSV @ 9555'. Sting into cmt ret. Sqz perf w/300 sx Class "G". Unsting. Drld E-Z drl ret & cmt. Drld cmt to 9625, wash 9625-9640. Tst csg, no leak at perfs. Drl cmt stringers & lower part of ret, CO to 9797. Tst csg, no l eakoff. Drl EZSV & cmt to 9846'. POOH. Left 1 cone in hole. Mill @ 9846. Drld ret & hard cmt. CO. Drl cmt to 9985. Wash. Drld ret & cmt 10082-10120, wash to 10157. Wash & ream 9317-10156'. Ran CBL/CCL/GR fr/10108-9200'. Ran GR/JB to 9286. Displ hole to 9.8 ppg NaC1. POOH. RIH w/RTTS. Found leak @ 9942'. Set EZSV @ 9915'. Sqz 50 sx Class "G" followed by 50 sx Class "G" (old perfs 9942-9944'). Drill cmt rtr & CO to 10,156'. Tst lnr several times, los~t ~pressure. Bradenhead squeeze 50 sx Class "G". Pull 6 stds DP, pump NaC1 thru DP, pull 10 more stds. Hold 2000 psi on squeeze for 5 hours. Wash 9916-10096'. Drl cmt to 10156. Bradenhead squeeze 100 sx Class "G". LD 12 jts DP. Hold 2000 psi for 5 hours. Drl cmt to 10156'. Test csg to 2000 psi. LD DP. Perf 9890-9900, 9806-9811, 9778-9796'. Ran GR/JB to 9960'. Ran tailpipe assembly. Pk~r set__@___~8. Ran 3-1/2" tbg & 5-1/2" stradlepack compl assy. Attempt to land tbg twice w/o success. LD tbg hngr & tbg string. Set RTTS w/SSCV. ND BOPE, replace tbg spool. NU BOPE. Ran 5-1/2" tbg & 3-1/2" tbg w/ pk__~_ @~_9288. Displace tbg w/diesel. Drop ball & set pkr. Set BPV. ND BOPs, NU tree & tst to 5000#. RR @ 1400 hrs 03/24/83. Gyroscopic survey run on 03/28/83. CSM/DH7' 1 l m 06/09/83 RECEIVED ARCO ALASKA INC. ~"- [ .:. 1 W E L L hi 0: "~' .~ S I G M A G M S / G M'S ,_10 B N 0: A'"'- .... ' ", ~ , · , .~ ..... A.._', o.-, R ().:, 4._,- T F I::'RUDHOE BAY~ NORTH SLOPE~ ALASI<A '.'...-]IGMA GMS, 0-~/200 MD GMS, ~.~:::00-10157 MD '.:;I_IRVEYOR: ,_IAHN/MILLER/PEFFERKORN DATE RUN: 28-MAR-8:3 '.iii;IGMA 300 NO: 76'.'-? ~/0 DEG A/U NO: 1248 FORESIGI.4T: N 5 55 W VERTICAL ::;ECTION CALCULATED IN F'LANE OF PROPOSAL DIRECTION: :3 ='"' ")5 · _,;~ DEG. .-. MIN. W RECORD OF SURVEY RADIUS OF CURVATURE METHOD ARCO AL. ASKA INC. , ~-5 S DS 1 WELL NO: o' IGMA OMS/P '-' F::'RI,JDI-~r:~E BAY NORTN .:,LCFE~ ALASKA dOB NO: A0383RO345-TP C:OMF'UTAT I ON T I ME DATE 10: 57: 09 24-MAY-8:3 PAGE NO. I TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA ' R E C T A N G U L A R C: L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100F]" 0~ 100. 200. 300. 400. }500. 600. 700. :::00. 900. 0 0 0 0 0. O. 00 O. O0 -74.00 O. 00 0.00 O. 00 0 0 0.00 0 1 S 76 56 W 100. 100.00 0.03 26.00 0.01 S 0.03 W 0.0:3 S 76 56 W 0.02 0 5 '.S 51 :3 W 100. 200.00 0.12 126.00 0.06 S 0.10 W 0.12 S 57 16 W 0.07 0 5 N 88 34 E 100. 300.00 0.14, 226.00 0.18 S 0.06 W 0.18 S 18 15 W 0.17 0 11 N 26 56 W 100. 400.00 -0.05 326.00 0.01 N 0.05 E 0.05 N 81 44 E 0.25 0 8 N 73 4 W 0 7 N 42 21 E 0 16 N 17 14 E 0 11N 6 35 E 0 13: N 37 ..58 E 100. 500.00 0.05 426.00 0.20 N 0.18 W 0.27 N 41 47 W 0.14 100. 600.00 0.01 526.00 0.37 N 0.23 W 0.44 N :31 17 W 0.23 100. 700.00 -0.27 626.00 0.67 N 0.06 W 0.67 N 4 57 W 0.17 100. 800.00 -0.57 726.00 1.07 N 0.03 E 1.07 N I 24 E 0.09 100. 900.00 -0.85 826.00 1.40 N 0.16 E 1.41 N 6 37 E 0.12 1000. 1100. 1 '..=: ()0. 1300. 1400. 0:3:3 N 22:34 E 0 16 N 40 27 E 0 16 N :38:33 E 0 13 S 47 4. E 0 19 S 58 11 E 100. 999.99 100. 1099.99 100. 1199.99 100. 1299.99 100. 1399.99 -1.45 925.99 -2.09 1025.99 -2.56 1125.99 -2 92 1 .... = 99 -3.09 1325.99 1.99 N 0.51 E 2.06 N 14 17 E 0.34 2.61 N 0.89 E 2.76 N 18 45 E 0.30 2.99 N 1.20 E :3.22 N 21 52 E 0.01 3.02 N 1.60 E 3.42 N 27 56 E 0.37 2,73 N 1.98 E 3.37 N 35 54 E 0.11 15 () A 160, 0 1700,. 1 :=: 00 ' .~00. :2000 2100 ::2200 2:3C~0 240o ~':'-':' '.=; ':'._. 10' W 3:3 S 14 '57 E 21 S 3 10, E 28 S :'::3 1 E 25 .c_; 13 33 E 0:34 S 21 4 E 0 19 S 3:5 9 E 0 12 N 16 21 E 0 12 N 52 7 E 0 16 S 59 25 E 100. 1499.99 100. 1599.98 100. 1699.98 100. 1779.98 100. 1899.97 100. 1999.97 100. 2099.97 100. 2199.97 100. 2299.96 100. 2399. '76 -3.06, 1425.99 -'2.72 1525.98 -2.42 1625.98 --2.27 1725.98 -2.17 1825.97 -1.97 1925.97 -1.94 2025.97 · -2.29 2125.97 -2.61 2225.96 -2.96 2325.96 2.22 N '.:' 24 E 3 16 N 45 17 E 0 .,..., m - . .~,..m _m . '- _ " 58 E 24 1 41 N :z.:3R E ;..'.72 N 49 0. 0.61 N 2.46 E 2.53 N 7/-'. 4 E 0.22 0.08 S '2.68 E '."-'.68 :_:; 88 23 E 0.24 0.80 .q 2.99 E 3.09 8 75 6 E 0.16 1.63 S 3.25 E 3.6:3 S 63 24 E 0. 16 2.32 S 3.62 E 4.29 S 57 23 E 0.27 2.25 S 3.?'?¢ E 4.58 S 60 31 E 0.48 1.c/Z-..._ S 4.1c~.. E 4.62 ¢'._, 64 57 E 0.1:3 1.'F.-'3 S 4.58 E 4.97 S 67 7 E 0.27 .,..._m(.)(_) · 2/:.00. :27 0 0. 2800. 290 ('). 0 35 S 57 10 E 0 48 S 24 8 E 4. :B:3 S 37 32 W 6 25 S 44 38 W 7 47 S 4? 28: W 100. 2499.96 100. 2599.95 lA(') 2A99.o':' . . . --.. i_1.~ 100. 27?9.36 100. 2898.59 -3.31 2425.96 -3.51 2525.95 -0.82 2625.83 :B.25 2725.:36 20.34 2824.59 2.32 ¢;.._ 5 .21 E.=,_. 71 ._¢; 65 59 E 0 . ...':".-".,- 3.23 S 5.99 E 6.81 S 61 40 E 0.45 7·65 S 5.47 E 9.40 S 35 3,(::. E 4.23 14.85 S 0.81 W 14.87 S 3 7 W 1.'2'.=-' 23.28 S 9.87 W 25.28 S 22 58 W 1.50 ARCO AI...A"SKA IblC:. DS 1, WELL NO: 25 ".::;IGMA GMS/GMS PRUDI.40E [-{AY, NORTH SLOPE, ALASKA ,_lOB NO: AO383RO345-TF' COMPUTAT I ON T I ME DATE 10: 57: 09 24-MAY-83 PAGE NO. 2 TRUE MEASURED, DRIFT DRIFT COLIRSE VERTIE:At_ VERTICAL SLIBSEA R E C: T A N O U L A R C L 0 S LI R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD CCI 0 R D ,I N A T E :3 DISTANCE DIRECTION SEVERIT'~' F'EFT D b'l II M F'EEiT FEET FEET FEET FEET FEET D M DG/100F'I :30 OA_. 11 ._4 ..., 4:3 4'7 W ::.:.:100 1:3._s'---',.., 'S 45 '='".' W :L::200. 19 15 S 4. 9 2 W :3:300. ;'::.'<") 45 S 49 4.0 W 3400. 21 29 S 50 19 W ).:Pi(')C) '-"-" ~i , .~z. 2:_: S ._1 l'-Z W :3600. 27 21 S !51 16 W :})700. 29 30 S 51 54 W :3800. :7::0 4.4 S 52 18 W :':: ';¢ (') o . .qo_ .. 56 c.._, F;'2 4-4 W 10(). 2997. 10 100. 3094.55 100. 3190.34 100. :'=::284. :3 (") 100. 3377.58 100. :347 C). :31 100,, 3560.97 100. :3648.91 1 <.])0. 3735.40 100. 3821.26 37.02 2'..~2:3. 10 58.68 :3020.55 86.62 3116. :_=:4 1 '-'(' '=' ..' .)· ._, 1:3210 ,2:. O. 155.86 3:303.58 192 87 '"""~ .31 . .-', --', .'.~ 6 2:34.56 :'-:4:36.97 · .',,:, 1,72: 3574.91 :.=:31.50 3661.40 382.4¢) :3747, 2/-', 35.03 S 22.30 W 41.52 S 32 29 W 4.23 50.96 S 38.05 W 63.59 S 36 45 W 2.10 70.34 S 59.05 W 91.84 S'40 I W 5.38 92.62 S 85.01 W 125.72 S 42 33 W 1.51 115.79 S 112.61 W 161.52 S 44 12 W 0.78 13~.~.47 S 141.61 W 198.76 E; 45 26 W 1.03 /~ ':"-' S '-' (' S 27 1=..'. 174 46 W z4.) 70 46 W 4 1'-?.~. _. 40 '..=; 211 .77 W .."""-'~',:,,=,, 14 c,~' 47 18 W 2 .16 226.21 S 251.37 W 3:38.17 S 48 1 W 1.26 257.40 S 292.06 W 389.31 S 48 37 W 0.30 40¢)0. 31 24 S 52 42 W 4100. :31 28 S 52:37 W 4200, :31 56._, '=' ._,'=.:..'":' :34 W 4:300. :32 8 S 5:3 27 W 44()0. :32 22 S 53 41 W 100. 3906.82 100. 3992. 14 100. 4077.21 100. 4161.9::: 100. 4246.54 433.79 3832.82 485.59 3918.14 537.78 4003.21 590.51 4087.~8 643.60 4172.54 288.75 S 333.24 W 440.94 S 49 5 W 0.45 320.37 S 374.72 W 493.00 E; 49 28 W 0.08 352.28 S 416.48 W 545.49 S 49 46 W 0.45 384.20 S 458.86 W 598.47 S 50 4 W 0.51 415.~0 S 501.80 W 651.75 S 50 21W 0.26 4.5()o. :3 2 44 S 5:3 27 W 4. A00. :'::3 0 S 5:..-..: '2 W 4. 7 (3 ¢) '-' '=' 52 .... : .... 18 '.:; 49 W 4:=:00. :3:3 2(:) '.3 52 44 W ")900. 3:3:36 :_:; 5:7 57 W 5000. :32 55 S 52 56 W 5100. :3 .'5:25 S 53 9 W 5200.. 3:::_ 41 '.~_ ._._,'-]':' 6 W 5300. :3:3 4:,2 '.=; 52 54. W 5400. :34 0 'S 53 6 W 100. 433:0. :_--:3 100. 4414.81 100. 4498.52 100. 4582.08 100. 4665.50 697.14 4256.83 751.11 4340.81 805.46 4424.52 860.03 45<)8.08 914.,82 4591.50 100. 4749. 11 969.30 4675. 11 100. 48:32.81 1023.68 4758.81 100. 4916. 15 1<1)78.62 4:::42.15 100. 49'F.¢9. :.=:4 I 133.76 4.925.34 100. 50:92.39 1189.12 500:--:. 39 447.85 S 545.11 W 705.49 S 50 36 W 0.39 480.33 S 588.60 W 759.72 S 50 47 W 0.36 513.30 S 632.25 W 814.38 S 50 56 W 0.3:2 546.53 S 676.00 W 869.29 S 51 3 W 0.06 579.84 S 719.96 W 924.42 S 51 9 W 0.29 612.89 S 763.71W 979.23 S 51 15 W 0.68 645.78 S 807.44 W 1033.92 S 51 21W 0.51 678.94 S 851.65 W 1089.16 S 51 26 W <).27 712 c:? c- ~,~= ¢- ....~. o;._,.97 W 1144.63 ~, ~1_ 31W 0.11 745.84 S 940.47 W 1200.32 S 51 35 W 0.32 5Y;00. :=:4- 2Pi c:. p;3:51 W 5600. 34 26 S 5:3 52 W 5700. :3:3 42 S 54 15 W 5800. :3:3 44 S !54 2:=: W 5900. 3:..]: 55 '.E; 54 44 W 100. 518.5.08 1245.05 5091.08 100. 5247· 55 1301.35 517:3.55 100. 53:30. :_=:8 1357.13 5256. :38 100. 5413.56 1412.44 5339.56 100. 5496.63 1467. ? 1 5422.63 · . i '-I -~l 779:30 E; ¢/85 66 W 1..'._6.52 S 51 40 W 812.66 S 1031.:35 W 1313.05 S 51 46 W 845.53 S 1076.72 W 1369.03 S 51 51 W 877.91 'S 11'21.8:3 W 1424.51 S 51 57 W 910.18 S 1167.19 W 1480.12 S 52 3 W 0.59 O. 02 0.77 O. 09 0.26 ARCCi ALASKA INC. DS.'; 1, WELL NO: '.:25 'SIGMA CM..,/GM!3~ '-' PRUDHOIE BAY, NC~RTH SI_C~F'E, ALASKA COMF'UTAT I ON T I HE DA~E : .~ : .. 4-MAY-,:,._- 10 ._ 7 C)'P '-' '-"-' PAGE NO. :3 TRUE MEASI_IRED DR IF:T DR IF'F F':nIIRF:E .... VERTICAL VERTICAL SUB.SEA R E F:_ T A N G U L A R C L 0 .., ¢' I_1 R E DOGLEG 'l '" '" _ - - ._-,EVER I TY [.E. FFH ANGLE DIRECTII]N I..ENOTH DEPTH SEF:TION TV[I FI n 0 R D I N A T E :3 DISTANCE DIRECTION '-' ' FEE'F D M I') M FEET FEET FEET FEET FEET FEET D M DO/1 6C)00. :33 54 8 54 47 W /.,100 ":"=' .'==i/-, c. ................. 4 W 6200. :34:34 S 55 50 W ./:,:300. :'-':4 5'F.~ S 56 6 W 6400. 34 51 S 56 26 W _).5('>¢~. :34 46, S 5/:, :_::2 W lOC). 5579.6:3 1523.50 5505.63 'P42.37 S '1212.74 W 15:35.:34 S 52 9 W 100. 56/.,2.61 157.9.1:3 55,.c.:8.61 .974.4::: .c_; 1258.41 W 15.91.58 S 52 15 W 100. 5745.26 1635.29 5671.26 1006.35:3 1304.'7'7 W 1647.78 S .=.;2 2! W 100. 5:327.40 16.92.22 5753.40 10:38.27 S 1352.04 W 1704.70 S 52 27.~ W 100. 5'.:.)0.9.40 174.9.38 5835.40 1070.05 S 13.97.65 W 1761.82 S 52 36 W 0.0:3 0.1/-, 0.76 0.4.5 0.23 :E; T A T I ON A T 660 c).. M Ii - M I .:,.:,EK'-'" ..... I 6,700. 34 51 S 56 39 W 6:300. :34 .9 S 56 4.7 W /.,,9<] c~ . :34. :=: ~, ¢' F_ ~... :37 W 7000. 33 4:3 8 56 17 W 200. 6155.70 1920.48 6081.70 11/-,4.44 S 1542.62 W 1932.77 S 52 57 W 100. 6238.11 1777.07 6164.11 1195.52 S 1589.98 W 1989.30 S 53 4 W 100. 6320.87 2033.13 6246.87 1226.33 S 1636.89 W 2045.31 S 53 10 W 100. 640:3.84 2088.87 6329.84 1257.18 8 1683.41W 2101.04 S 53 15 W O. 05 0.71 0.10 O. 46 100. 6486.76 2144.38 6,412.96 1288.13 $ 1729.59 W 2156.56 S 53 19 W 100. 6570.08 2199.85 6496.08 1319.29 $ 1775.62 W 2212.09 $ 53 23 W 1()0. 6653.54 2254.84 /.,579.54 1350.25 S 1821.19 W 2267.14 $ 53 27 W 100. 6737.42 2309.17 6663.42 1380.80 S 1866.24 W 2321.52 S 53 30 W 100. ~,821.79 2362.75 6747.79 1410.89 $ 1910.70 W 2375.16 S 53 33 W 0.17 0.21 0.56 0.35 0.67 '7600. :31 1:3:3 56 :=:7 W '~00. :3(')_ 41 ¢'._, 57 :3 W , ~'-.',_,.(') c). 29. :37 ._, © ?,_ :~. 8 W '7900. 28 3'2 S 59 1 W 800C). 2:3 ,12 S 6. 0 '2 W 100. 6906.85 2415.26 6832.85 1440.06 :_--; 1954.45 W 2427.68 S 53 37 W 100. 6992.56 2466.71 6t-'718.56 14/-,8.23 S 1.9.97.57 W 247.9.11 S 53 41 W 100. 707.9.03 2516. '.~2 7005.03 1475.14 S 203.9.9.9 W 252.9.23 S 5:3 46 W 100. 7166.4,2 2.=-;/.,5.52 708.~2.42 1520.48 S 2081.47 W 2577./:,6 S 5:3 51 W 100. 7254.20 2613.4.'3 7180.20 1544.77 S 2122.76 W 2625.35 S 53 57 W O. 8'F~ O. 66 1.21 1.15 O. 52 8100. 29 37 S; 60 -'.58 W :_::200. :--:0 18:3 62 28 W :!=:300. 31 11 '.=; 63 '? W C-:400. 31 42 S 65 12 W 8500. :::2 20 S 66 25 W 100. 7:2:41.52 2662..15 7267.52 1568.76 S 2165.18 W 2673.77 $ 54 5 W 100. 7428.15 2712.05 7354.15 1592.42 S 2209.16 W 2723.27 S 54 13 W 100. 7514.10 27/:,3.0.9 7440.10 1615.77 S 2254.64 W 2773.6:3 $ 54 22 W 100. 75.9'.-?. 40 2815.0.9 7525.40 1638.50 S 2301.61 W 2825.26 .S; 54 33 W 100. 7684.18 2867.7.9 7610.18 1660.22 S 234.9..9.9 W 2877.2.9 S 54 46 W 1.0i 1.02 0.95 1.1'.:~ 0.8.9 8600. 32 50 .'_=; 67 28 W 8700. :3:3 30 :E; 68 27 W :=::=:0 0. 2:4 1 '.-.-' '.E; /=.'.=.? :3:=: W 100 776:3 44 2921 18 7A94 44 16,'-]:1 31 '.3 23.99 :~ . _. ......... --,._, W 292.9 .96 'S 54 .~'.~ W 0.76 1 (')(') .... 7,:,._ z. 14 2'.-='75 2.9 7778. 14 1701 . 84 ,..c' 2450.27 W ..--, c, ,-, ,:,, ,= .... 30 ,..¢' .:i, :',. ,., 13 W 0.8/., 100. 79 ....... :'~.=,. 12 :3 c)::: ('). ._'~ 1 7,=,'-' 61 . 12 1721 . 7.9 '.3 2502 . :38 W :30:37 . ._.=, I S ._._,~ =' 28 W 1.05 AR r: (] A L A::;I< A I NC. [ .:-., 1 Wile L.L hlr]: '-, ~ , .. ~._, '.L:; I GMA _,M,:./GM Fs F:'RUDHOF BAY, NOR'¥H ¢;LOF'E-, ALASKA JOB NO: AO383RO345-TF' C:OMPUTAT I ON PAGE NO. 4 T I ME DATE , 10: 57: 09 24-MAY-83 TRUE MEA'.31JRED DRIFT DRIFT COURSE VERTICAL VERTICAL C-;UB'SEA R E C T A N G U L A R C L 0 S U R E DOGLEG I)EPTH ANGI_E DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY F:EE"r l.] M D M FEET FEET FEET FEET FEET FEET D M I]G/100F'F 8'P00. :34 36 S 70 41 W 9cJcJ('i , 5:4 ._,..":"-] S 71 28 W '--.'.. 100. :34 2 S 71 ,.'"-,::'- W 'P200. 33 17 S 71 9 W 9:300. :3:3 0 S 70 0 W ) 40o '-'"" 0 S 7A 0 W 'P500. :31 45 S 70 0 W 9/_',()0. 5:1 0 S 68 0 W 97('~0. 28 15 S /.:,5 0 W 9800. :23 45 S 65 0 W 0 c) 8017. = / 'q(')'-' = 'T~ 1 7943. !56 1740 99 :~ '-' ='.=,, =' _,'-, "' o" ".,,~, ,:. ....· ,:, .-. ,:,.-,. . . . .-' ....... ,./:..'- W .::0.. ~. ~... ._, 55 44 W 00. c,¢,c,~ ,:,¢., ~] ~, .-,~ ",~o 2609 .... ' ' ~' = ..... .- .-.. ,_,. 3141. ._ 1 o 0 ~._, ,89. 1 /.., .-.. 40 S . . ,:,.:, W .5:147 .08 z, ,.,/:, 1 W 00. 8182.49 3196./:,4 8108.49 1777.31 S 2662,78 W :5:201.44 S 5/:, 17 W 00. :.:.:2/:.5,71 :5:250.88 815.~ 1,71 175/5.06 S 2715.2'F.~ W .5:255.01 S 56 .5:2 W 00. 8:'::49.4.4 3:304.5:-: 8275.44 181:3.24 S 27/o6.86 W :3308.08 S 56 46 W 0.66 0.45 0.55 0.76 0.70 100. 84:33.78 .5:357.2:4 :]:359.78 1831.62 S 2817.35 W 3360.40 S 56 58 W 100. :3518.70 :3409.25 844.4.70 1849.68 S 2866.97 W 3411.87 S 57 10 W 100 8604 07 5:4/: (') .~q '-'='"' '::4~ 2 ...... ~ ,:,._,.:,0 07 1868, 34 o 2915 ='-' ~, ._,,:, W 84 ~ 57 21 W i ~ ~ i . ~ .. .m ~ ~ 100. 8690.99 :3509.63 8616.9~ 1888.04 S 2960.90 W :3511.64 S 57 29 W 100. 8780.85 3553.2.5 8706, 85 1906.57 S 3000.62 W 3555.10 S 57 34 W 1.00 O. 25 1.28 3.12 4.50 'P'700. 20 45 ::; 64 A W 1000(). 18 0 :i; 59 0 W 1~"~100. I:F: 0 S 57 0 W 100. 8873.39 :3590.96 8799.39 1922.86 S 3034.79 W 3592.68 S 57 38 W 100. 8967.72 3624.10 8893.72 1938.69 S 3063.94 W 3625.7% S 57 41W 100. ?062.83 3654.99 8988.83 1955.06 S 3090.14 W 3656.67 S 57 41W 3.02 3.21 O. 62 F'RCIdEC'FED 1():L57. 18 0 S 57 0 W 57. 9117.04 3672.59 . 9043.04 1964.66 S 3104.91 W 3674.28 S 57 41 W 0.00 PRO,.JECTED TO F'BTD "i290. 18 (:) S 57 0 W F'ROJECTED TO TD 133. 9243.53 3713.65 9169.53 1987.04 S 3139.38 W 3715.38 S 57 40 W 0.00 10:3:30. 18 0 S 57 0 W 40. 9281.57 3726.00 9207.57 1993.77 S 3149.75 W 3727.74 S 57 40 W 0.00 FlhlAL CLOSURE - DIRECTII-IN: D I STANCE: S 57 DEGS 40 MINS W :3727.74 FEET ARCO ALASKA INC. DS 1, WELL NO: 25 SIGMA GMS/GMS ._lOB NO: A0383R0345-TF' PRUDHOE BAY, NORTH SLOF'E, ALASKA '.B I OMA GM'.=_;, 0-'.-'.~200 MD GMS, ?~300-10157 MD '..--:URVEYOR: dAHN/MILLER/PEFFERKORN DATE RUN: 28-MAR-83 '.!F.:IGMA 300 NO: 7/_'.'.-} '.--/¢'~ DEG A/I_I NO: 1248 FORE:=;IGHT: N 5 !55 W REC:ORD OF INTERPOLATED SURVEY ARC:O ALASKA INC:. DS 1, WELL NO: 25 SIGMA GMS/GM:=; PRUDHOE BAY, NORTH '.':;LOPE, ALASKA dOB NO: AO383RO345-TP COMF'UTAT ION T I ME DA'rE 10: 59: 44 24-MAY-83 PAGE NO. ' 1 MARKER C 0 D E NAME TRUE SUBSEA MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R C L 0 S U R E VERTICAL DEPTH DEPTH DIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M TOP SAG F:IVER TOP SI...IIJBLIK A TOF' SHIJBLII< B "['("lF' '.:j:;I.-II..,IBL.. I K C TOP SADLERt]CH!T 0 C:ON'I"AC]' G / 0 C 0 N T A C T TOF' Z CfN El :-_-: TGI=' ZONE 2 HOT 9606.00 8609.29 9'~6.7 8535.29 1869.54 S 2918.38 W 'F~63:=:. 00 8637.10 1000. '.-.-~ 8563.10 1875.85 :E; 2'.'-~32.88 W 9661.00 8657.10 1003.9 858:3.10 188(:).38 S 2943.30 W '.-}681.00 8674.4:.: 1006, 5 8600.48 1:-:84.32 '.:.: 2'T. z52.37 W 9722.00 8710.76 1011.2 8636.76 18'.'}2.14 ."} 276'B. 72 W '~82E:.()0 8806.76 1021.2 8732.76 1911.15 E; 3(}10.27 W '.-}851.00 :.::--:28.05 10:23.0 8754.05 1 '~ 14.90 S 3018.13 W 9':'.,'2::: C)0 ~.,,-,o,:, E: ~,c,.:,?l , ",') '-, ........ :,,=, :.- .~-. I 1 (')28.2 ,:, ~, ,,... ._ . :.:: 1 1 ~"27 .:".'::' ~: ..:,(. 4.:, C) 3 W 1001:3.00 8980.08 1032,9 8906.08 1940.:34 S 3067.42 W 10075.00 S~03'."]. 05 1035. 'F~ 8'.-}65.05 1S/50. '.--7S~ :,; 3083.67 W 3465.85 S 57 21W 3481.47 S 57 24 W c'~' S · ~--...~.6~ 57 26 W 3502.45 S 57 27 W 352~1.28 $ 57 30 W 3565.70 S 57 35 W 3574.35 S 57 36 W 3602.03 S 57 39 W 3629.87 S 57 41W 364~.03 S 57 41W O/W CONTACT 'l"OF' ZONE 1. B 10143.00 ~103.72 103'~.3 ~027.72 1'~62.32 S 3101.36 W "-'/. '-' ""'" :.-q:,. 76 W ]. (.),.' :,,:, (") C) '=-' ':'~'':' '-~ ,, .-.-~=~. ~-. 6,0 1045.4 S/148. ~,C) 19,:,c,. 5.~ E; 31 ~ '-' 3670.04 S 57 41W 3708.66 S 57 40 W Eastman/ Whipstock A PET'ROLANE ~PANY REPORT of SUB-SURFACE D IREC TI ONA L SURVEY ARCO ALASKA r INC. COMPANY DS ir Well Number: 25 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATI ON JOB NUMBER TYPE OF SURVEY Teleco DATE Alaska Oil & Gas Cun,~.. CummlSxior, Anchol-ag~ SURVEY BY Controlled Drilling Consultants OFFICE ARCO ALASKA~ INC:. ]]iS: I ~ WELl_ NO: 25 TELECO PRUDHOE BAY, NORTH SLOPE, ALASKA TELECO. 0-S/625 MD~ DRILLER: CHAF'MAN ( C D C: ) SLIRVEY F'RnVII]ED BY CONTROLLED [IRI LLING CON':_;ULTANTS. ~' r' CALCULATED IN PLANE OF PROPOSAL VERT I CAL .:,E_.T I ON DIR.ECTION: S .59 DEL]. 25 MIN. W RECORD OF SURVEY RADIU.'_--: OF CURVATURE METHOD ARCO ALASKA, INC. DS 1, WELL. NO:..-.._,'-'=' TELEE:O ( E:DC ) PRUDHOE BAY, NORTH SI._OF'E, ALASKA .,~ COMPUTATION TIME DATE 09:01:23 24-FEB-83 . PAGE NO. 1 ~ TRUE MEASURED 'DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C' O' O"'R"'D'I"'N A T E S DISTANCE' DIRECTION SEVERITY FEET B M D M FEET FEET FEET FEET FEET FEET D M DG/100F~ O. . 0 0 0 0 O. 2623. 0 0 0 0 2623. 2623.00 O. 00 254.9.00 2779. 6 54 S 36 0 W 156. 2778.62 8.61 2704.62 2935. 9 12 S 52 0 W 156. 2~33,08 27~,60 2857~,08 : 144 18 1 ~ ~' 48 0 W 2~]9. '~ 1 "'= 87 7~. = ~ · :..... ~ ._,4 3061 ,~ 7 32Sz9. 21 30 S 49 0 W 155, 3281.60 I30.34 '3207.60 345:3. 22 12 S 50 0 W 154. 3424.53 186.80 3350.53 3579. 28 0 S 51 0 W 126. 3538.5.9 23~7.58 3464.59 3671. 30 6 S 51 0 W 92. 361~'01 283.77 3545.01 3767 ~' 52 '~:32 . .:.1 0 S 0 W 96.: .3701.68 10 3627 68 , ,:,:, :~,~, 42.92.._~'::'" 18 S ~._~ ~' 0 W 4851. 33 48 S 53 0 W 5316. 34 12 S 52 0 W t~A'~'~. :}4 1°,.., 'S 54 0 W 618.9. 35 12 S 56 0 W 0.00 0,00 -74, 00 0'~00 0.00 0,00 0 0 O. 00 0.00 O. O0 0 0 7.5.9 S 5.51 W .9.38 S :36 0 W 2:5;25 .S 20.64 W 31.0?~ S 41 36 W 55.14 S 58.65 W 80.50 S 46 46 W :~0;I0 S .98.15 W 127.32 S 141.74 W 161 3A ¢' 1~'~' .. ,.. ,:,~.,96 W 189:,'42 S 217.68 W 21.9.7.9 S 255.86 W 5'-'= ' 4148 5~ . . ',:.:: 4:2 w 133.24 S 47 27 W 1.90.53 $ 48 4 W 243.91 S 48 36 W 288.55 S 48 58 W 337.31 S 49 20 W 612.62 S 50 32 W · _.5.~:? 4617. 13 S.~07 ~... 90 4543.1 .:~: 574 . .97 c;.. .:714. SA. W :-] 17 .35 S 51 11 W :..5002,~6~ 1166,:03,'. ... :~4928.68 :~2· 1.0.9 W 1177.32 S 51 2.9 W 374, : ~311..77'.: 1375,:17 528?.77 . 85.g..~ E; :108.9.17 W 1387.71 S 51 42 W 49.9. 5721.77 1658.74 5647.. 77 1023..'0.5 S 1322.14 W 1671.73 S 52 16 W O. O0 0.00 4.42 2.04 4.38 2.08 0.51 4.62 2.28 1.08 O. 25 0.28~ 0.15 0.30 O. 2~ 6718 :_--:4 42 c. ..... ~.. 0 W 7:_::33. 33 0 ?-; 56 0 W 78:'::2. 29 2 '1. ._.':' 58 0 W ' '--:':~::: ~- 1 48 c. 63 A W . : '~ 34..':-:/-, '.:_: ~'-,*n W 529. 6155.36 1961.47 6081.36 1188,09 S 1576.28 W 1~73.88 S 53 0 W 615. 6666.10 2303.73 65.92.10 1374.65 S 1863.56 W 2315.71 S 53 35 W 49.9. 7092.86 2561.94 7018.86 1515.41 $ 2080.30 W 2573.74 S 53 56 W 561. 7575.70 2847.35 7501.70 1655.98 S 2328.76 W 2857.51 $ 54 35 W 496. 79.90.6.9 3117.00 7916.69 1766.38 S 2576.73 W 3124.04 S 55 34 W O. 24 O. 33 0.75 O. 62 0.87 9625. 31 0 S 72 0 W 736. 860?. 25 3508.15 8535.25 187.9.43 S 2952.45 W 3510.67 S 57 15 W 0.54 FINAL CLOSURE - DIRECTION: D I STANCE: S 57 BEGS 14 MINS 43 SECS W 3510.67 FEET DRIFT CHART'S RELATED DATA FIEE ARCO ALASKA, INC. D.C_; 1~ WELL NO: 25 TELEC:O PRI.JDHOE BAY~ NORTH SLOPE, ALASKA CDC ) · SURVEY FILE NUMBER 1051 BOTTOM HOLE ASSEMBLY, VALUES USED FOR DEPTH ARE MD DEPTH 110.00 2640. O0 3770.00 7958. O0 9625.00 DESCR iPi' ION DAY DRILLING DAYS VALUES USED FOR DEPTH ARE MD DEPTH 1 2 3 4 5 6 7 8 10 11 12 13 1805. O0 2640. O0 2640.00 2640.00 3430. O0 5400.00 6670.00 7870.00 ,:, 4,:, ~. 00 '?::-~40. O0 ~625. O0 9825.00 0 3 :E:~'~. 0 0 DEPTH WEIGHT ON BIT ...... WEIGHT IS GIVEN PER 1000 F_ILIND.:, VAL.IEo USED FOR DEPTH ARE MD WEIGHT 70.00 65.00 65.00 65.00 40"00 DEPTH 110.0C) 2640. O0 3770.0 C) 7'.;~58. O0 '.;~325.00 REVOLUTIONS PER MINUTE VALUES USED FOR DEPTH ARE MD R.P.M. 150.00 50.00 110.00 110.00 75.00. = . 8000 _ t i Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · Operator,' Well Name and Number Reports and Materials to be received by: ~.~. Date Required Date Received Remarks C°mP letion Report Yes - .,.. _Samples /~,~ -- Mud Log .~ ,. ,/~- ~ ~' ~::L Core ~scrip~on Inclination S~ey ~ .... ~ ...... /. ~. ~,.~ Drill St~ Test Re~s , .c~~, L~ ? ~' ~S R~. Yes . Digitiz~ ~ta ~C ~ <~.~' ~ .... ~.:..~ .. '-""-' STATE OF ALASKA ~ ALASKA ',~,L AND GAS CONSERVATION C~JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL7~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-203 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20874 4. Location of Well Surface: 872' FNL, 594' FWL, Sec. 8, TION, R15E, UN 5. Elevationinfeet(indicate KB, DF, etc.) 74' RKB 6. Lease Designation and Serial No. ADL 28329 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 1-25 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) XIX] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Spudded well ~ 1145 hrs, 02/09/83. Drld 17-1/2" hole to 2640'; ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 9625'; ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 10330' TD; ran logs; ran, cmtd, & tstd 7" csg. RIH w/CCL & perf'd 9890'-9900' & 9806'-9811'. Tie-in w/BHCS log. Perf'd 9778'-9796'. Ran 3-1/2"/5-1/2" completion assembly. ND BOPE. NU tree & tested to 5000 psi - ok. Secured well & released rig ~ 1400 hrs, 03/24/83. Alaska Oi! & Gas Cons. Cumrnis$iop Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~/~ Title Area Drilling Engineer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 GRU3/SN17 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office E' 360 Anchorage, A~aska 99510 Telephone 907 277 5637 April 18, 1983 Reference: Arco Cased Hole Finals D.S. 1-25~/ 3-2-83 ~ CCL for Squeeze Gun & Retainer 2-24-83/ CCL & Perf Record 2-24-83.~-- CBL/VD 2-27-83/ CBL/VD 2-27-83~/ CET D.S. 7-21 ~5~-5-83 CBL/VD 3-1-83 PAL D.S. 12-15~'~3-13-83 CBL/VD D S 13-2A/3-6-83 ~ EPLJ 2_-26-83 2-25-83~ CET D.S. 13-23A~3-11-83 EPL D.S. 14-26~4/83 Spinner Log DoS. 14 30~4-1-83 Spinner Log D.S. 15 3~2-i2-83~ CET 3-3-83~CBL/VD 3-3-83 CCL & Perf Record 2-28-83/ Squeeze Gun (4" Carrier, 4 shots per/ft.) 5" Sch D.S. 15-4 /4-4-83 Spinner Log 5" Camco Run 2 5" Scl Run 1 5" Sc Run 1 5" Sc Run 2 5" Sc. Run 1 5" Sc Run 1 5" Sc Run 1 5" Sc Run 2 5" Sc · -Run 2 2" Sc. ~Run 1 2" & 5 Run 1 5" Sc Run 1 5" Sc 5" Camco 5" Camco Run 2 5" Sc Run 1 5" Sc Run 1 5" Sc ~sign and return the attached copy as receipt of data. Kelly McFarland DISTRIBUTION AFA-403 NORTH GEOLOGY ~z:an-s. ~f 286R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS CAROLINE '- ' STATE OF ALASKA ~ ' ALASKA/-': AND GAS CONSERVATION C£ MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION 4. Location of Well atsurface 872' FNL, 594' FWL, Sec. 8, T10N, R15E, UM · Drilling well [~]X Workover operation [~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-203 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20874 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 1 -25 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 74' RKB ADL 28329 For the Month of. March ,19 83 ran, cmtd & tstd 13-3/8" Drld 12-1/4" hole to 9625'; ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" TD; ran logs. Ran, cmtd & tstd 7" csg. Ran CET & CBL. Squeezed cmt. Stuck CCL/JB/gauge ring in hole. Fishing. Push fish to btm. Perf, cmt again. Ran logs. Broke dwn formation. Sqz cmt. Drld cmt to 9621 and STORY (See Over) 2.Depthatend~fm~nth~f~~tagedri~~ed~fishingj~bs~directi~na~dri~lingpr~b~ems~spuddate~remarks Spudded well ~ 1145 hfs, 02/09/83. Drld 17-1/2" hole to 2640'; csg. Ran CBL. hole to 10330' Ran CET & CBL. sqz. Perf, sqz SEE DRILLING H! III & 400 sx 3. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 79'. Instld w/1895# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe ~ 2624'. Cmtd w/3000 sx Cold Set Cold Set Il. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe @ 9610'. Cmtd w/500 sx Class G. 7", 29.0#/ft, L-80, BTC csg f/9317'-10328'. Cmtd w/300 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None Gauge Ri ng/JB, CCL to 9286' BHCS/GR f/10330' - 9-5/8" shoe /GR/Cal f/10330' - 9-5/8" shoe continued w/CNL/GR to 13-3/8" shoe 0290'-10000' & 9200'-10150' 0290'-9317' & 9200'-10150' /GR f/10108'-9200' 15. Logs run and depth where run CBL f/2620' - surface DIL/SP/ FDC/CNL CET f/1 CBL f/1 CBL/CCL /'i: .... ~ ~ ,~3~ slurry of Class "G" slurry of "Class G" (over) 6. DST data, perforating data, shows of H2S, miscellaneous data 10102-10104' sqz W/150 SX Class "G" 9942-9944' sqz w/150 sx Class "G" 9861-9863' sqz w/100 sx Class "G" 9822-9824' sqz w/lO0 sx Class "G" & 50 sx tail 9610-9612' sqz w/200 sx Class "G" & 100 sx tail DATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~'~~ TITLE Area Dr,.' ~. I i n~ Eng~. nee.- NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 CSM/MR7 Submit in duplicate CONTINUATION OF MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS (DS 1-25) 12. (Cont'd ) wash. Tst csg. Sqz perfs. Drld cmt to 9640' Tst csg, perfs took fluid. Sqz perfs. Drld EZ-drl ret & cmt, wash. Tst csg, no leak. Mill ~ 9846'. Drt ret & cmt. CO. Drl cmt. Wash & ream to 10156' Ran logs. Disp hole w/NaC1 water. Sqz cmt. Tst lnr, no cn in hole to 9965. Sqz cmt. Drl cmt, LD DP. Perf. Ran logs. Set pkr ~ 9918' Ran 3-1/2" & 5-1/2" tbg. Replace tbg spool & land tbg. RR ~ 1400 03/24/83. 16. (Cont'd) Perf 9890-9900 9806-9811 9778-9796 CSM/MR7A:llm 04/15/83 1-25 Drilling Hi story NU 20" Hydril & diverter. Spudded well @ 1145 hrs, 02/09/83. Drld 17-1/2" hole to 2640'. Ran 65 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2624'. Cmtd 13-3/8" csg w/3000 sx Cold Set III & 400 sx Cold Set II. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1000 psi - ok. Drld FS. Ran CBL f/2620'-surface. Tstd form - would not hold 10.0 ppg EMW. Pumped & squeezed 45 bbls of LCM. Drld 12-1/4" hole to 9625'. Ran 232 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 9610'. Cmtd 9-5/8" csg w/500 sx Class G. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10330' TD (02/21/83). Ran DIL/SP/BHCS/GR f/TD - 9-5/8" shoe & FDC/CNL/GR/Cal f/TD - 9-5/8" shoe continued w/CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus. Ran 25 jts 7" 29#/ft, L-80, BTC csg f/9317'-10328'. Cmtd 7" lnr w/300 sx Class G. Drld cmt to 10290' PBTD. Tstd lnr lap to 3000 psi - ok. Ran CET f/10290'-10000'; tool failed. Ran CBL f/10290'-9317'. RIH & set EZ drill retainer @ 10150'. Stung into EZ drill & pumped 200 sx Class G cmt; squeezed. Set 9-5/8" EZ Drill @ 9287'; sting into retainer & pumped 50 sx Class G. Drld on retainer & pushed to 10123'. Drld cmt to 10159'; tstd csg to 3000 psi. Ran CBL f/9200'-10150'. Ran CET f/9200'-10150'. RIH w/gauge ring/JB; stuck tool @ 9450' WLM. Worked tool - pulled out of rope socket; left CCL/JB/gauge ring in hole; top of fish @ 9402'. Fishing. Push fish to btm. Left JB/GR @ btm, recovered cable head/CCL/wt, bars. Perf 10102-10104. Set EZSV. RIH w/3-1/2" DP & stab in tool. Sqz 150 sx "G" cmt. Perf 9942-9944'. Set ret @ 9976'. Sting into ret. Sqz 150 sx Class "G". Perf 9861-9863, set EZSV @ 9834', Sqz w/lO0 sx Class "G". Perf 9822-9824', 9610-9612'. Ran GR/JB, CCL to 9826'. Set EZ drl cmt ret @ 9795'. Sting into ret, attempt to circ fr/lower perfs to upper perfs. Press up on upper perfs, form broke dwn. Sqz lower perfs w/lO0 sx Class "G". Set EZSV @ 9583'. Sting into ret. Sqz 100 sx Class "G" followed by 50 sx tail slurry of Class "G". Drl E-Z drl ret. Drl cmt to 9621, wash dwn to 9644. Tst csg to 2000 psi. Bled to 1000 psi. Drl cmt stringers & wash dwn to 9750'. POOH. Set EZSV @ 9583' Sqz perfs w/200 sx Class "G" blend, followed by tail slurry of 100 sx Class G blend. Tag cmt @ 9144, LD 6 joints DP. Drl cmt & EZSV to 9640'. Tst csg w/2000 psi, perfs · ~, i~ ~ :~- , .,.~.~ ~ ,i~i took fluid, i~ ~i '~. ~ ~ '~, ?~. ~.~? DS 1-25 DRILLING HISTORY (Cont'd) TIH, rotate thru 7" lnr. Set EZSV @ 9555'. Sting into cmt ret. Sqz perf w/300 sx Class "G". Unsting. Drld E-Z drl ret & cmt. Drld cmt to 9625, wash 9625-9640. Tst csg, no leak at perfs. Drl cmt stringers & lower part of ret, CO to 9797. Tst csg, no l eakoff. Drl EZSV & cmt to 9846'. POOH. Left 1 cone in hole. Mill @ 9846. Drld ret & hard cmt. CO. Drl cmt to 9985. Wash. Drld ret & cmt 10082-10120, wash to 10157. Wash & ream 9317-10156'. Ran CBL/CCL/GR fr/10108-9200'. Ran GR/JB to 9286. Displ hole to 9.8 ppg NaC1. POOH. RIH w/RTTS. Found leak @ 9942'. Set EZSV @ 9915'. Sqz 50 sx Class "G" followed by 50 sx Class "G" (old perfs 9942-9944'). Drill cmt rtr & CO to 10,156'. Tst lnr several times, lost pressure. Bradenhead squeeze 50 sx Class "G". Pull 6 stds DP, pump NaC1 thru DP, pull 10 more stds. Hold 2000 psi on squeeze for 5 hours. Wash 9916-10096'. Drl cmt to 10156. B~radenhead squeeze 100 sx Class "G". LD 12 jts DP. Hold 2000 psi for 5 hours. Drl cmt to 10156'. Test csg to 2000 psi. LD DP. Perf 9890-9900, 9806-9811, 9778-9796'. Ran GR/JB to 9960'. Ran tailpipe assembly. Pkr set @ 9918. Ran 3-1/2" tbg & 5-1/2" s~trad~l~Pack compl assy. Attempt to land tbg twice w/o success. LD tbg hngr & tbg string. Set RTTS w/SSCV. ND BOPE, replace tbg spool. NU BOPE. Ran 5-1/2" tbg & 3-1/2" tbg w/ pkr @ 9288. Displace tbg w/diesel. Drop ball & set pkr. Set BPV. ND BOPs, NU tree & tst to 5000#. RR @ 1400 hrs 03/24/83. CSM/DH7' 1 lm 04/14/83 ARCO Alaska, Inc. Post Office B,. 360 Anchorage. Alaska 99510 Telephone 907 277 5637 April 14, 1983 Reference: Arco Open Hole Finals D.So 1-25 2 - 21- 83 CP L/Cyber look 2-21-83 B~CS 2-21-83 DIL/SFL 2-21-83 LDT/CNL/GR Run 1 5" Sch Run 1 2" & 5" Run 1 2" & 5" Run 1 5" '/Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-4 03 Transo 9 269 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY PHILLIPS SOHIO MARATHON CHEVRON D&M CAROLINE ~mT~ ~, ,~' ' ' ~'~ ~-~ ~"~' ~.~__ ARCO Alaska, Inc. Post Office S' ;60 Anchorage, Al~ks 99510 Telephone 907 277 5637 March 24, 1983 Reference: _,Arco Directional Data D.S. 1-25 ~'~ 2-10-83 D.S. 7-17~/' 12-7-82 D.S. 7-18 ~' 12-29-82 D.S. 7-22'- 3-7-83 'D.S. 12-i~ 2-23-83 Magnetic Survey Magnetic. Survey Magnetic Survey Magnetic Survey Teleco/Single Shot Teleco Teleco Teleco Teleco EW sign and return the attached copy as receipt of data. Kelly McFarland AFA-4 03 Trans. 230 R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION GETTY D&M Alaska Oil & Gas Cons. c;ummissiori Anohorage ~¥ATE ' OF 'ALASKA DALLAS CAROL!NE SMITH ARCO Alaska, Inc. ~' Post Office Anchorage, AlasKa 99510 Telephone 907 277 5637 March 15, 1983 Mr. C. V. Chatterton Commissioner State of A16ska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for February on these drill sites' 1-25 1E-18 7-20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1Y-13 13-2A 1Y-14 15-3 1Y-15 CIRI Wolf Lake Well #1 Ravik State #1 Also enclosed are well completion reports for: 1-24 1E-21 2-8. 1E-22 7-18 1F-1 7-19 1G-7 12-18 WSW-iO 13-9 WSW-11 1E-20 Tract Well 24-11-14 We also are including subsequent Sundry Reports for 2-8, 7-18, 12-18, and 13-9. ARCO Alaska, Inc. Is a subsidiary of AllanticRichfieldCompany , .,~-. STATE OF ALASKA ALASKAC ANDGAS CONSERVATION COt 'ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well Workover operation [] 2. Name of operator ARCO A]aska, lnc. 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of Well 872' FNL, 59/+' FWL, Sec. 8, T10N, R15E, UM at surface 5. Elevation in feet (indicate KB, DF, etc.) 74' RKB 6. Lease Designation and Serial No. ADL 28329 7. Permit No. 82-203 8. APl Number 029-20874 50-- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 1 -25 11. Field and Pool Prudhoe Bay Fie]d Prudhoe Bay 0i] Poo] For the Month of. February ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1145 hfs, 02/09/83. Dr]d 17-1/2" hole to 2640'; ran, cmtd & tstd 13-3/8" csg. Ran CBL. Drld 12-1/4" hole to 9625'; ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 10330' TD; ran logs. Ran, cmtd & tstd 7" csg. Ran CET & CBL. Squeezed cmt. Ran CET & CBL. Stuck CCL/JB/gauge ring in hole. Fishing as of 02/28/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 79'. Instld w/1895# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe ~ 2624'. Cmtd w/3000 sx Cold Cold Set Ii. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe ~ 9610'. Cmtd w/500 sx Class G. 7", 29.0#/ft, L-80, BTC csg f/9317'-10328'. Cmtd w/300 sx Class G. SEE DRILLING HISTORY Set III & 400 sx 14. CoringreSumeandbriefdescription None 15. Logs run and depth where run CBL f/2620' - surface DIL/SP/BHCS/GR f/10330' - 9-5/8" sho'e FDC/CNL/GR/Ca] f/10330' - 9-5/8" shoe continued w/CNL/GR to 13-3/8" CET f/10290'-10000' & 9200'-10150' CBL f/10290'-9317' & 9200'-10150' shoe DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED_~'~~~ TITLE Area Dri 1 I ing Engi neet NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU2/NR1 4 Submit in duplicate 1-25 Drilling History NU 20" Hydril & diverter. Spudded well @ 1145 hrs, 02/09/83. Drld 17-1/2" hole to 2640'. Ran 65 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2624'. _ Cmtd 13-3/8" csg w/3000 sx Cold Set III & 400 sx Cold Set II. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1000 psi - ok. Drld FS. Ran CBL f/2620'-surface. Tstd form - would.______..gnot_ ~ FMW. Pumped & squeezed ~ bbls of LC~._~M. Drld 12-1/4" hole to 9625'. Ran 232 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 9610'. Cmtd 9-5/8" csg w/500 sx Class G. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10330' TD (02/21/83). Ran DIL/SP/BHCS/GR f/TD - 9-5/8" shoe & FDC/CNL/GR/Cal f/TD - 9-5/8" shoe continued w/CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus. Ran 25 jts 7" 29#/ft, L-80, BTC csg f/9317'-10328'. Cmtd 7" lnr w/300 sx Class G. Drld cmt to 10290' PBTD. Tstd lnr lap to 3000 psi - ok. Ran CET f/10290'-10000'; tool failed. Ran CBL f/10290'-9317'. RIH & set EZ drill retainer @ 10150'. Stung into EZ drill & pumped 200 sx Class G cmt; squeezed. Set 9-5/8" EZ Drill @ 9287'; sting into retainer & pumped 50 sx Class G. Drld on retainer & pushed to 10123'. Drld cmt to 10159'; tstd csg to 3000 psi. Ran CBL f/9200'-10150'. Ran CET f/9200'-10150'. RIH w/gauge ring/JB; stuck tool @ 9450' WLM. Worked tool - pulled out of rope socket; left CCL/JB/gauge ring in hole; top of fish @ 9402'. Fishing as of 02/28/83. JG2DH12'llm 03/08/83 ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 11, 1983 Reference: Arco Cased Hole Finals D.S. 1-.24 ~1-19-83 EPL 1-18-83 CBL/VD D.S. 1-25j 2-13-83 CBL/VD D.S. 2-17~ 11-27-82 CNL/GR/MSN %/~I~/D S. 2-20' 1-27-83 Perforating Record D.S. 3-15~ 12-9-82 CNL/GR/MSN --~-D.S. 6-11 11-29-82 CNL/GR/MSN D.S. 12-12' 2223-83 D.S. 12-17~'1-28-83 · 'D.S. 13-2A/2-7-83 1-29-83 D.S. 13-9J 1-24-83 1-27-83 1-30-83 1-?-83 2-3-83 1-28-83 1-28-83 Temperature Survey Temperature Log CBL/VD ~Tubing Puncher Record ~CEL CET CBL/VDL & Waveforms Temperature Log EPL~ CCL & Perf Record CET D.S. 14-15/ 12-15-82 CNL/GR/MSN D.S. 16-13~/12-10/11-82 CNL/GR/MSN Run 1 2" & 5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" DA Run 1 5" Sch Run 2 5" DA Run 2 5" DA Run 1 5" Camco Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch Run 3 5" Sch Run 2 5" DA Run 2 5" DA ' P~~lease sign and return the attached copy as receipt of data. -Kelly McFarland AFA-403 Trans. # 207- NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EXXON MOB I L GETTY .~ D&M 'g~, -~.. A . "~. STATE ALAS DALLAS CAROLINE SMITH ARCO Alaska, Inc. Post Office B?-~-,360 Anchorage, /~. ,.<a 99510 Telephone 907 277 5637 March 1, 1983 Reference: Arco Directional Data D.S-. 1-25 2-11-83 Teleco EW sign and return the .attached copy as receipt of data. Kelly McFarland ' AFA-403 Trans. # 175 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Al,.ska. inc_ [o a ~,uDs,dia~v of AHanticRicn,,e!cC: :~"~ :'- EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS CAROLINE SMITH Alaska Oil & Gas Cons. Oommissior, ARCO Alaska, Inc. Post Office Box/~-~O Anchorage. Ala 99510 Telephone 907 277 5637 March 1, 1983 Reference: Arco Magnetic Tapes * D.S. 12-16 2-16-83 * D.S. 1-25 2-21-83 .tape K/Listing # 68021 Run 1 Sch OH ta2e w/Listings # 68024 ch * Exxon & Sohio - 1 copy already sent by Schlumberger. ase sign and return the-attached copy as receipt of data. · ~ ~ · ~- .. -. -.~ Kelly McFarland AFA-403 Trans. 9 177 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON GETTY D&M STATE OF ALASKA DALLAS CAROLINE SMITH ARCO A~aska. ,r'c. ~.~ a SuO$,'!ia~¥ Of Allan[icr~iC,~'elnCC','' :" MEMOR^ IDUM Sta e of Alaska ALASKA OIL A~D -GAS CONSERVATION COMMISSION TO:c.' V. Chatterton - DATE:February 16, 1983 Chairman F~,E NO.' 10 ~/G Lonnie C, Smit~~ Comm~ssione r Thru: FROM: Doug Amos ~ Petroleum_. Inspector TELEPHONE NO: SUBJECT: Witness the BOPE Test on ARCO's DS 1-25 Well Sec. 8, T10N, ~.15~;, U~,4 Permit No. ~2-203, on Rowan Rig No. 35 Saturday February 12, 198-3 - The BOPE test commenced, at 5:00 a.m. and w~s concluded at 10:00 a.m. I filled out an ~.O.G.C.C. BOPE test report which is attached. There were no failures during this test. The longer than average test time was because of an unorganized crew. In summary, I witnessed the successful BOPE test on ARCO's DS 1-25 Well. 0&G #4 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date. lC'/ Inspector D0~7 ~/'~q ~;3 Well ~,~, I-Z~ Operator A~d Representative ,,~' ~ / ,~/~ ~ ?;~..~_~ Well ~,,~, /'~ Permit Location: Sec ~ T ]~ R ~ ~.t .~/ /5 ~/~ 'f ,-Casing Set ~ 2~. ~ ft. Drilling Contractor ~]~~ Rig ~ ~ Representativ~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer. Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure ps ig psig 200 psig Above Precharge Attained: Full charge Pressure Attained: Controls: Master Remote min ~ sec min /~ sec Blinds switch cover Kelly and Floor Safe Upper Kelly I ~Test ty Valves Pressure Pipe Rams ~ vz~- ~ Blind Rams' \_~ Choke Line Valve~~ H.C.R. Valve ~f Kilt Line Valves Check Valve ~/ Test Results: Failures I! /! Lower Kelly ~ ~Test Pressure Ball Type. ~ ~/Test Pressure Inside BOP / ~Tes. t Pressure Choke Manifold. ~ .~/Test Pressure No. Valves ' /~ NO. flanges _~ Adjustable Chokes / Hydrauically operated choke. . / Test Time. ,~ hrs. ~z3~ days and Repair or Replacement of failed equipment .to be made within. . Inspector/Commission office notified. Remarks: Distribution orig.'- AO&GCC cc - Operator cc - Supervisor Inspector.. ,.~0~ ~. December ~ 1982 Mr. Mmrk A. Major Ar~a Drill~n~ ~ gn~ineer~ ARCO 'Alaska· Inc. o. Box 360 Anchorage, Alas~-m 99510 Re: Prudhoe Bay Unit DS 1-25 ARCO Alaska, Inc. Pe~it No. 82-203 . . . U?~ Sur Loc 872'FNL, 594'F~, Sec 8, TION, R15E, . T10N R15E UH B~ole Loc. 2715,~L, 2524'FEL, .~ec. 7, , , . Dear }~. Major, Enclosed is the approved application for permit to drill the above' referenced well. If corin~ i~ conducted, a one cubic inch chip fron each foot of recovered core is required. Sa~ples of well cuttings and a mud log are not required. A continuous directional survey re~umred as per ~0 A C ~5 . ~ ' .~ ~A . .050(b)(5) if available, a tape containing the digitized log information shall be subnitted on all lo~.~s for .~ ~ ~ except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and t~-~- ~=~z drainage systems have been class.f~ed as important for the spawnzng or migration of anadr~ous fish. Operations in these areas are subject to AS 16.05.870 and the regulations proraulgated thereunder (Title 5, Alaska Administrative Code). Prior te co~mencinK operations you may be contacted by the Habitat Coordinator's u~z~e, Department of Fish an~ Game. Pollution of any waters of the State is prohibited by AS 46, C~ - -~ ,,., 'I ~ hapter 3, Art~e 7 ano the re~ulation, s pro~utgated thereunder ~ ~ ~ Chapter 70) an0 by the (Title 18, g~aska Administrative ~.o~e, ., _ Federal %~ter Pollution Control Act, . as a~ended Prior to c~encin~ operations you ~av~-~ ~ be contacted by a representative of the n = ~ ~ o~ ~ ' ~ep~r_~nt ~ ~ nnvlrop~ental Conservation. To aid us in scheduling field work· please notify this office 2&. hours prior to co~encin~ ~-~si~ ta!~_ation of ~.e~: blowout Mark A. Major Prudhoe Bay Unit DS 1-25 -2- December 8, 1982 prevention equipment so that a representative of the Commission may be present to witness .testing of the equipment before the surface casing shoe is drilled. Where a dtverter system is required, please also notify this office 24 hours prior to co~amenctng equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chair_man of MY 'Alaska Oil and Gas Conservation Commission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC: be ARCO Alaska, Inc. ~ Post Office B~_ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 18, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 1-25, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 1-25 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Sincerely, M. A. Major Area Drilling Engineer MAM/JG: sm Encl osures GRU2/L42 RECEIVED DEC 0 2 i982 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... -~ ALASKA (J,~ AND GAS CONSERVATION CO~v, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~]( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L_~ SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address RECEIVED P. O. Box :360, Anchorage, Alaska 99510 4. Location of well at surface 872' FNL & 594' FWL of Sec. 8, T10., R15E, UH DECO 2 : 982 At top of proposed producing interval 2561' FNL & 2263' FEL of Sec. 7, T10N, ELSE, UM Alaska0il & Gas Cons. Commiss, At total depth Anchorage 2715' FNL & 2524' FEL of Sec. 7, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 74' PAD 40' ADL 28:329 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Prudhoe Bay Unit 10. Well number o~)DS 1-25 11. Field and pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line NW of Deadhorse 2 miles 2525 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10233'MD, 9242' TVD feet 2501 I 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT2700 feet. MAXIMUM HOLE ANGLE 31.57' (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed well DS 1-24, 120 feet 18. Approximate spud date 12/15/82 3700 psig@__ Surface 4093 psig@ 9242 ft. TD (TVD) SIZE :50~, ¢7-1/2" Casing ZO" 13-3/8" Weight 91.5# 72# 2-1/4" 9-5/8" 47# I 8-1/Z" 7" 29# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling! H-40 Welded L-80 BTC L-80 BTC L-80 BTC Length SETTING DEPTH MD TOP TVD 76' 34' I 34' 2566' 34' I 34' 9493' I I 32' 32' I 9225' 18383' 1008' MD BOTTOM TVD 110' 1110' 2600' Ii 2600~ 9525' 18639' 102:33' 19242' QUANTITY OF CEMENT (include stage data) 2200 lbs. Poleset 2300sx Cold Set II1+ 400 sx Cold Set II /800sx Class "G" Cmt ¢~.~. 350sx Class "G" Cmt ARCO Alaska, Inc., proposes to directionally drill this well to 10233' MD (9242' TVD) to produce the Sad]erochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. The well will be completed with 5-1/2", 17#, L-80 plastic-coated tubing with provisions for a subsurface safety valve. A nonfreezing fluid will be left in all uncemented annuli within the permafrost zone. The packer will be set above the Sadlerochit and Sag River formations. A separate Sundry Notice will be submitted before the well is perforated. A surface diverter will be used on this well. - DS 1-24 will be 120' away at the surface. No other close crossings will be encountered anywhere downhole. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ' SIGNED,~~~/~ TITLE Area Drilling Engineer The space below for Commission use DATE CONDITIONS OF APPROVAL Samples required Mud Icg required FqYES ~NO [~]YES J~;~kl O Permit number Approval date ¢.,, ~--~2/08/82~ Form 10~401 GRU2/PD26 Directional Survey required APl number J~YES [~]NO 50- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE I'~¢¢:~n~¢-r' R 1 OR9 by order of the Commission Submit in triplicate I Ii' i i :~. .J'~ :~.j ~'!' '~'I.~ r~'l.~l'~ j 1 j j i i , j I I i ! i ~uuI I ! ~ i !~A~liri~N ~ ~ ~iil iii! iiii iii iii ~iii i , !'ii Jli ' ~ ; ! I i ] I I I I !i i I I I ,,i! ~ i ~UUi ! I i I i i i i ; I i ! I :i~ iill lil! iJli iiii ii.il iii, !iii Iii i , ,1i ! Ii ii!l-:~.'~-L ~ I ii' !!ii Ii ! i ~UUl ) i i i i I I J ! i I ! ~' i [i i I i ''' i,, i i , i ,, ~ i i i' i l~m-~ I I i ! I I I i I ' J~i ' ~ , ~ ~Til~ i1~ ~' Ii Jl~ II i ,i]1 ~ ~ Ii I1 i r I i u''' 'JJ '"' i'" [ ~ ~ I i ~ ~ i i i ~ i J ~ I '! I i i i I i ! I I I , ~ I I I I J' ,. iiii i11i !ili !iil ~ I ! i.~i ! ! I i I i I i I i i ' I I ! i I ~ ~ i , i I i I i '~ I i 1 I i '~ i i i IIMMI i i i I ! I i ! i I I i I ! ,,ii ,,,,,, { i 1i Ill I 'i lilt I I ~ I , ~ ! ! I. ! J.-~-[.t~ ! ' r i ~ ~ ~ i I ~ I I I i ' I I i ~' ~"-~ l.;m'' ~ ~ ~ ! I i i i ! i I I ~"' I . Y ~17~ ~ I ' ! i [ i i i I ~'~.i ~ I : ~ ~. r - i ~ il A I -~ I I ~iI U il ~ ~-~ ! i I :il! ii i I I ~ i i :i~.~ ~ ii,, ~ i i I~1 i I iI1~ili iil i i i/ i i ~ l~il~UUll_ Iiii i ~i i!1i i li~J~i Iii ~ I ~,i i ii il ~ i ~ ~ i i i ~ i i i i i i I i i i ~ I ~ I ~i i i ' ~ i J ! ~ ~ i i i i i ~ ~ i i! ii1~ i!i ! ill! !1i ~~ii ~i!i i1~ i111 ~1 i ~iiI iili i'II ~ ~, iiil ii i i!!i u~ii_ ili! ~I~ !ili il i. ilii '*:i* i' IX~ ~iii ii'i ~*I~ ii, · ' i ~ ' i i ~i! a i~ i I i11! !ili ~Ii , - ' , , '' ',, ~ jill ,iii ~I' i iJJ [~1! i jj~l Jill till Jl i J ! i ~, ~ I i I ! i i I j i i ] ~ ~--~ I J I i I j I i J I I I i I I I 1 ~t ~.]~ J J J J J ' j i ~ ~ J J J j J I l ' ~ ..... , ; ' ~UUI~-- ijJJ {ill jill iji~ l; ijji j))l il i Jill Jill I ~ il . j lJ li~ i il ill il j ii ii~1 ~iii !1 l .... ~''' 'l~ij' '~i!iil~ ~:'J i~'~ iiJl i~t~ ili ANNULAR PREVENTER BLIND RAMS PIPE RAMS SPOOL PIPE RAMS 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and -fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. / Observe time, then close all units simultane- ously and record the time and pressure remaining ~/ after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. . . 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a. 250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to ze~o. Open bottom set of pipe rams o 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezingdrilling position, liquid and all valves are set in 13. Test standpipe valves to 5000 psi. 14 Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. AI2$k~ 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. SURFACE IO" HYD. (]PR. BALL VALVE WE,L,L BORE ISEE DETAIL) IO HYD. OPR. BALL VALVE ALL go° TURNS ARE "TEE CUSHION ~LL HOLE DiVERTER SYSTEM ARC(:: ALASK¢, INC'o FLO~L INE RESERVE PIT AREA NOTE' SCHEMATZC I· DR ILL ING RISER F 20" 2000 PS[ WP ANNULAR PREVENTOR OPERATED BALL VALVES 'Valves on diverter lines open automati- cally when the annular oreventer is closed. 20" CONDUCTOR PIPE "DETAIL" 2026010202 5 8 19 21' PA D~'-z 6, czl~: I'-- 4--00' '~,~C 8,, diON, F-,~bF, LIM. I HEREBY CERTIFY THAT I ~,M PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT. ALL DIMENSIONS AND OTHE'R DETAILS 1/23 LAT = 70°14'27.348'' LONG = 148° 24'06.631" y = 5,940,265.01 X = 697,879.04 NW CORNER CELLAR BOX ELEV = 40.01 1/24 LAT = 70°14'26.187'' LONG = 148024'05.982 y = 5,940,147.66 X = 697,904.48 NW CORNER CELLAR BOX ELEV = 40.11 ARE CORRECT, AS OF: k:D/7/~¢' ~ 1/25 LAT = 70°14' 25. 029'' / LONG = 148o24'05.333'' ....~~F .~'"~, ' Y= ~, 940,030.52 ~.~W.. A '%.~ I1 X = 697,929.87 ~ ~.¢'" ~':¢~ .~ ~ ' ' NW CORNER CEL~R BOX ELEV = 39.98 ~'~*~'"~% ~; .... .'"[/' ','~ 1/26 LAT = 70°14'23.S69' R E 6 E I V E ~ L 0 N O = I 48° 24' 04.590" ~;,~,..v ~..,zn-~ "'~ .......... ' ~ - ~97 955 09 ~'7~ '~. .."-~ NW CORNER CELLAR ~X ELEV - 39 95 ~ ~;~"~S~Ox~ ~ ~,,.o~ Oil & Gas cons. uommlsmon CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (2 thru 8) 3. 4. 5. 6. 7. 8® (3) Admin (9' thru 11) 1 10. 11. (4) Casg ~. ~, ,,~,,~ ?~-~o ?fi__. 12. (12 thru 20) 13. 14. 15. 16. 17. 18. 19. 20. (5) BOPE ~,/z~',~/,,~.~.~ .... (21 thru 24) 21. 22. 23. 24. 25. YE S NO the permit fee attached ~~' Is Illllllllllllllllllll~llllllelllllllllele .. Is well to be located in a defined pool ............................ Is well located proper distance from property line ................ di Is well located proper stance from other wells ................... Is sufficient undedicated acreage'available in this pool ............ Is well to be deviated and is well bore plat included .............. Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Is conductor string provided ...................................... Is enough cement used t° circulate on conductor' and surface ... Will cement tie in surface and intermediate or production strings .~. Will cement cover all known productive horizons .................. ..'.. Will surface casing protect fresh water zones ....... , ............. '.. Will all casing give adequate safety in collapse, tension and burst;". Is this well to be kicked off from an existing wellbore .......... Is old wellbore abandonment procedure included on 10-403 ......... ~.. Is adequat well bore separation proposed e tllltelllelllllllllllllltll Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating - Test to ~--OOO Does the choke manifold comply w/API RP-53 (Feb.78) ................ Additional requirements ............................................. REMARKS Additional Remarks: Geology: Engineering: HWK ~ LC S BEW WVA~~.~, RAD ,~ JAL HJH rev: 08/19/82 INIT IAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo_ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-ol' this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. DIRECT DIGITAL LOGGING COMPUTER Company ARCO ALASKA INC, Wel 1 DS 1 o - .... -~3 F'ield PRUDHOE BAY DATE OF JOB: 10-..,-L3-,~::, County NORTH SLOPE State AL.A'~'._-, K"R Country, USA CLIENT FORMAT DATA TAPE LOG I I'..I F ORMA T I ON STANDARD FORMAT ( L, I, S, ) [:,epth_=:: 1 0599 00 t.o i 'I.,. ;- r, 00 Name: DS ~i-,::""-',z, C:H/'CNE: Field: PRUDHOE BAY DaTE OF ,.;OB: 1 0--2:3.-85 ' NUV,~. lq,- , T:i. ma: 4:46 PM b. IED. Pag,:-z: 1 .... L II I S TAPE RECORD~ Sel,,,,,,.icm name: :~G5F Oi 'HEADER RECORDS Date: 85/I1/06 Or'.igin: Reel .name Comments P a g e 2: Cont. ir',uation .~: Oi c, ervice name: ,~.bSFOi Pr-evious tape Date: 85/iI/06 Comment_~: Origin: T~p=- ~. name: ~-~oc~a~., Continuation EOF File nmm~::,:,.~'GSFOi , OOi HEADER RECORD"~ [)ate: File tppe: LO P ..--:~ g e H i',1E H C N i.,.I f',l FN C 0 LI i'..i S TA "F C T R Y S E C T T 0 i,j N R A H G EKB E DF E G L ~ D L HF D H F F..t. N L. CC S 0 N i._ ~J N FL L. UL E I',i ~ i kl I T i',l D D DL TL ~[ BI.i · TCS TLAB BHT i"i R T H T !IS S H V I S Ri:i RHF bi F S T HFSS R 1i C MCST bi C S S I NFORHR T I ON RECORDS CON T ' "'q Et~l ... UNIT TYPE C~TG ': " o I ZE L.O[:,E A R C: C) f"~ L t::~ S K A I N C:, DS i .... 2:~ CH,/CNS P F.: LID FI 0 E B A Y hlORThi ,.-., ,- r-,-- . oL. dc' t: LIS A 0 '8 I ON ............. i 5E ? 4,000 ..... 7S. 000 ...... 0,000 ...... HS' ......... i< B .......... I<B ......... SO ......... ill Ill ilItll i i'll iiiii111111111111111111111111 IIi IIi i II ii 37~99::~4 .......................... , .... 5066,."'7208 i~ .... ' ..... '.E OF tx. uN IH ;L. ' ..................................... NO F.'T H SLOPE .................................... HUPP .................................... SENNETT .................................... i i :$78,000 ............................................... i i359,000 ............................................... i 0600, 000 .............................................. 11358. 000 .............................................. O.OOO .................................................. O, 000 .................................................. O, 000 .................................................. O, 000 ...... CRUOE , , , 0 0 40 6='-._, 0 0 40 65 0 0 ,40 65 0 0 20 65 0 0 20 65 ~0 65 0 0 :2 65 0 0 :~ 65 0 0 ?; 65 F T 0 3] 4 68 FT 0 3 4 68 F' T 0 3 4 6 8 O :7; 2 65 0 3 ':' "~ 0 3 2 65 O O '-' - ' .... ,... ,~ 0 0 2 79 0 0 iO 0 Ct i 0 65 0 0 20 ' 65 0 O 20 65 0 0 20 ~._ 0 0 20 65 F T 0 .S 4. 6 :'.._:', F T 0 .S 4 6 :.3 F T 0 3 4. 6 8 F T 0 3 .4 6 :.'-: t.-I R 0 2 'i. 68 H R 0 4 4 6 8 DEGF 0 i 4 L,: ,_,o D E (l F' 0 i 4 6 0 2 20 65 0 2 20 65 0 2 4 6 8 0 2 4, ,S ::: 0 ':.' 4 6 ',~', 0 ';' '! 2 ,S 5 0 '2 4 E, :_--: 0 2 .'i- 6 :l: 0 '2 i 2 :::, 5 o ,'.-, ................................................... c:P 0, 00 O ................................................... iD H H Fi 0, 000 ................................................... 0 H Ii 0. 000 ................................................... DEGF 0, 000 ................................................... D E 6 F P.ag e C O M M E N T R E C O R D "~ :.~:~. ]"hi?.-~ LIS t..~p~ ~,~.~s wr.i~.t, mn [",,,~.~ Gm,~rhar. t Indu~t. rim~ tJir.~lin,z S~zrvic:ms:, :~:~ All cur. v~ mhd t. ool mn~a~onics used are thos~ which ~ost clos~lp ~atch ~EARHART TO S C:HLUMB EF~C~E~R MI',IEH SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT GR MERGE GAPt GR MERGE GAPI CCI. MERGE MV CCL MERGE MV FCNL MER~]E CPS FCI.,IL MERGE CPS NCNL MERGE CPS NCNL MERGE CPS; NPHS COMPUTED SSPU NPHi COMF'UT PU RAT C OI'IPU I'ED RAI' COMPUT AVG COMPUTED AVG COMPUT DATA ENTRY BLOCKS ENTRY OlIIlllllllllllltllllll,IIlIiIIIIi ,*** ENTRY BLOCK LEGEND :4.: * ~, :+: :~. '~, ~. :~. :'1': :~ ~: :~. :~': * :4': ~: :.~. :4.,' :~: :{,: W. :4.: :~: TYPE DESCRIPTION 0 Terminator ( no mor. e entities ) FORMA TYPE T SPEC I F I CA TI ON'$ SIZE cu[ E 0 1 6 6 DATA FORM"T -,,t SERVICE SERVICE APi MNEM Zt) ORDER ~ VI,liT LOG AP I AP I AP .'¢. F I LE TYPE CL. AS'~ c, M 0 D DEPT 3,399.3,~$ FT 0 GR MERGE :339934 .GAP I 0 CC:L MERGE 3139934. HV 0 "'~q 9 F C N L M E R G E ...,, .~, ... .'~. .C P S 0 NCNI_ MERGE .... ~':~ .. ,~ ,,; 9 ~ 4. .C P S 0 NPHI COMPUT 7.:~ .... s4 PU .0 R~T t.. OI'IF U ~ AVG COMPUT ~.~ .-, .. ,'~"+ ........ 0 0 0 0 0 54 i 0 0 i 50 i 0 0 78 3i 0 0 78 ~0 0 0 i22 2 0 0 0 0 0 0 0 0 0 0 P RC ~:.iZE LVL SMPL 4 0 1 68 4 0 1 68 ,~ 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 I 68 4- 0 1 68 P~<v L.E :.-,.. It,ID ICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT DA T A R E C 0 R D S GR ~CCL FCNL NCNL NPHi RAT AV~ P~g~ '1 i :340,000 0,000 O, ~27.5'00 J52,~00 24 840 .--999.250 20 292 27,900 ,230 353,800 24 030 1 , 09I 24 362 '1i140.OOO 35, 000 5,2:00 500 550,200 22 690 061 22 702 I 1 04 O, 0 O0 ~5.800 ,440 838.400 771.800 15 456 ,942 15 339 '10940. 000 44,100 9.30 567,200 590. 700 21 660 · 90:0 21 590 1 0840. O00 ~7.900 ,640 704,700 679.800 16 1.75 067 i 7 098 10740,,000 4,0,2.00 .410 727,, 1.00 716,600 17 181 ,991 17 541 10640, 000 76,5 O0 ,590 833,200 796,900 15 467 1 .136 Film r',m~e: ,.:,~oFOi ,OOi Maximur~, tmngth: 1024 TRAILER RECORDS File tgpe: LO Next Version f'ilm: Date: Page RECORDS Mmximum length: 1'024 File t.gpm: LO Version Prmviou$ ?ilm: Date Page 10 H H E M CN WN FN COUi',i STAT CTRY SECT TOWN RANG El<8 EDF EGL. PD LMF RUN LCC SON L U N 'FL LUL ENGi WITN DD DL TLI BL.I TCS TLAB 8HT MRT MT MSS MVIS RM RMF MFST MFSS RHC MCST MCSS 1 NFORMAT 1 [lin RECORDo COHTENTS UNIT TYPE CATG ARCO ALASKA INC. DS i --2:3 C:H.,' CNS PRUDHOE BAY i,IORTH SLOPE ALASKA LISA i ON .... i5E,.. 74,0.0.0 73, O00 O, 000 KS,,. K8,,, 30.., 6066/7208 NORTH SLOPE NORTH SLOPE HUPP SENNE'"T ~ i 359 000 ~ 0600 00:0 i i S58 000 0. O00 . , , 0,000 ,,, O. 000 , , , 0.000 ,,, CRUDE u 0 0 0 u 0 DATE OF JO8: i 0-2~-85 ,, ir · i SIZE '000 ............... 0 H bi M 000 ................................................... OHMM 000 ................................................... pbGF 6 6 ....... : ............ : ......................... : .... 000 ................................................... DEGF I I i I I i I i i I I I I I I i i i I i I I I I I i I I I I i i I I i i I I I I I I i I i I I I I I I I I I CODE 0 0 40 .65 0 0 40 6.., ~' 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 ';' "~ ,_ t~.F.~ 0 0 ;~ 65 0 0 3 65 FT 0 3 4 ,68 FT 0 3 4 68 FT 0 3 4 68 0 3 ':' ' ~ 0 3 ~'-" 65 0 3 2 65 0 0 2 79 0 0 2. 79 0 0 i 0 65 0 0 i 0 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 :DO '=' ,. C",.D FT 0 3 4 68 FT 0 3 4 68 FT 0 ~ 4 68 FT 0 :~ 4. 68 HR 0 '-",~. 4 G 8 HR 0 4 4 68 DEGF 0 I 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 0 2 4 68 0 '2 ,4 68 0 2 4. 68 0 '2 4 68 0 2 1 '-2 65 0 2 4 68 0 2 4 68 0 '2 12 65 P.ag e ii :COMMENT RECORDS Thi=~. [.IS t.~pm ,,.,as wri'%.%mn bp Gmar. hmrt Inclust~,ie~_-. Wir.~linm Ail curvm and tool mnmmonics usmd are thos~m ~,~hich most ciose, lp Gear-I-,aft. cu;.-ve and %ool mnemonics. GE:AP, HART TO SCHLUMBERGER MH Et'I SERV I CE UN I T MNEM ,.~c.o,~ .., ~,-,., I CE UN I T DEPTH FEET DEPT FT GR i MERGE GAPI GR MERGE GAPI C ~.L I MERGE MV C:CL MERGE MY FCNL 1 MERGE E.P~ FCNL MERGE CPS NCNL 1 MERGE CPS NCNL NERGE CPS NPHS 1 COMPUTED SSPU NPHI COMPUT PU RAT ~ COMPUTED RAT C:OMPUT Page: i2 ~AT A :~** ENTRY BLOCKS ENTRY *:~:~: ENTRY 8LOCK LEGEND TYPE DESCRIPTION 0 Te.]~minator < no more entries ) F 0 R M A T SPECIFICA TYPE m' olZE CODE TiON~=~ DATA FORMAT SERVICE SERVICE MNEM ID ORDER ~l: AP1 AP1 AP1 AP! FILE UNIT LOG TYPE vL~ blOD DEPT 339934 GR MERGE 339934 CCL MERGE 3J9934 .FCNL MERGE 339934 NCNL MERGE NPHI COMPUT RAT COMPUT FT 0 0 0 0 0 GAPI 0 54 1 0 i NV 0 i 50 i 0 i CPS .0 .78 ~ i 0 i C P S 0 78 30 0 i ~PU "0 i ;:.2 2 0 i ..... 0 0 0 0 i oPECIFICA, TIONS PRC ~ SITE LVI_ SMPL Rb 4 0 i 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 i 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 P .-.ag m DEPT DATA RECORDS GR .CCL FCNL NCNL NPHI RAT Page i5 11342,500 0. O0 0 O. 000 0 000 0,000 26,470 -999 250 1 i 242,5 80 29,800 ,380 294 000 ~46.000 26.04 0 I '!,72 '1i142,500 41.908 ,250 575 000 609, I O0 21 .620 053 I 1 042,500 B4,70O 680 839 400 785,400 15.456 987 10942,500' 34,800 ,670 821 2:00 753,300 17.990 921 1,0842,500 38,200 ,620 625 SOO 65~ ~00 21 ,160 1 053 i0742,500 39.7.00 · . 480 625 200 677,400 21.480 i 089 1 0642,5 00 62. 000 ,.67.0 1 047 700 856,300 8.589 861 *** FILE TRAILER .m** Fiie n~me: ~,GSF01 . 0'02 Maximum length: TRA Z LER RECORD"~o Film 'type: LO N ~ x t f'i Date: P ag e 'I G File.. nmmm: ~,~oF01,0.03 Maximum le. ngth: 1024 HE ADER REC:ORD'~o File :type: LO Previous ¢ilm: F' age i 7' MNEM CN WN FN COUN STAT CTRY SECT TOWN RANG EI<B EDF EGL PD l. H F DNF R U LCC SON LUN FL LUL E I',t G I W I TN DD DL TLI 8LI ]'CS TLA8 BHT MRT MT MSS MViS RH RHF MFST MFSS RHC MCST HCSS INFORMATION RECORDS CONTENTS ARCO ALH..I~.H iNC [)S i-23 C H.." C:NS PRUDHOE BAY I,,tO RTH SL, OPE ALASKA USA i ON,,, iSE,,, 7,4, 00:0 73, 0 O0 O, '000 MS, , . t< 8 , , i<8, , , 6066/7~ 08 NORTH SLOPE NORTH SLOPE HUPP SENNETT i i ~78 O00 ,~59 "OOO i 0600 'OOO 'l i~58 O0 O,OOO O, O00 ,,, 0. 000 , , , O.OOO ,, , CRUDE 6 666 ............... 0 DATE OF JO8 i0-23-85 UNIT TYPE C'ATG o IZE CODE 0 0 4 0 65 0 0 4 0 6 0 0 4 0 65 0 0 20 65 O O 2,0 65 0 0 20 65 0 0 '2 65 0 0 3 65 O 0 FT 0 7.4 ,4 GE: FT O 3 4 68 FT O 3 4. 68 0 0 3 2 65 0 3 2 ":' 0 0 '":' -9 0 0 ,:.° 7g. 0 0 1 0 65 0 0 1 0 65 0 0 -.-'":' fi 6 =',_, 0 0 2 0 6 5 0 0 20 65 0 0 20 65 FT 0 .S 4 68 FT 0 ..'3 4 68 FT 0 3 4 68 FT 0 3 4 68 I-IR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 1 4 .68 0 2 20 6,5 0 2 21:1 65 CF' 0 2 4 OHHM 0 2 4. 68 OHHH O 2 4 6'" DEGF 0 2 4 68 O 2 i 2 65 0 H bi bi 0 2 4- E, 8 [)EOF 0 2 4 6,8 O 2 i 2 ,S 5 P a g 6: '! 8 COMMENT RECORD :.i.~. Thi~-. LIS tmpm ~,.,a-~ writ. t~n by Gmarhart In,.-.lu~tri~ Wir~lin~ S~rvic~:, $. All curvm and tool mnemonics usmd arm tho~m which most clo~ml,p match ** Gmat-hart c~ul,'.vm ar',d tool mnmmonics. GEARHART TO SCNLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEF'TH FEET DEPT FT GR;2 MERGE GAPI GR MERGE GAPI CCL2 MERGE MV CCL MERGE NV FCNL2 MERGE CPS FCNL MERGE CPS NCNL. 2 MERGE CPS NCNL MERGE CPS NPHS2 COMPUTED "" .... r p · .=oPU NPHI uJM UT PU RAT2 COMPUTEr.) RAT COMPUT ~DATA .~.** ENTRY 8LOCK,S ENTRY FORMA TYPE T I!~ oPEC 1 F 1 CAT I ON'~ SIZE CODE 0 1 66 '-20 :+:** ENTRY BLOCK LEGEND :~ :+: :~.., * :+: :~ :.lc. * :+.' :+:. :'k * :'I': :,lc. :'k. :'k * * W. :~ :~ TYPE DESCRIPTION O Tmrminator ( no more entrims ) ~ATR F 0 R M A T ~..~:,;~ DATUM SPECIFICATION BLOCKS SERVICE SERVICE AP1 APl AP1 APl FILE M N E M I D Fi R D E "~ ...... ., · R .~ UNIT LOG TYPE L:~_H::~ MOD DEPT 3 ..",.: 9 '.~ 3 4 FT o o o o o GR MERGE .-,l..~,,:, 9~4 GAP I 0 54. 1 0 2 CCL MERGE .;..t:~'99 ~4M',/ 0 i 50 i 0 2 FCNL MERGE '" ""- ':" ' NCNL MERGE $ ."~] 99 ~44. CPS 0 78 ~ 0 0 2 H I-'" H IC 0 M P U T ,.= ..., 9 ,...4 ._ 4. P U O 1 '"" '"' ~ 2 0 2 R A T C O' bi P U 'f ....* oPEL,,, I F I CA T IoNS P RC: ~. SIZE LVL SMPL RC 4 0 I 68 4 O 1 68 4 0 1 68 4 0 i 68 4 0 I 68 4 O I 68 4 0 i 68 PROC:ESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 00000:0 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Page 2i DEPT DATA RECORDS GR CCL FCNL NCNL NPHi RAT 22 11377,000 0,000 0,000 0.000 0.000 -3,643 .-999 250 i1277.000 54,000 · 5.00 ,308,600 309. 500 21 800 [ ..,;, 7 '1i177o:000 61,900 .440 484.100 531 ,300 22 450 1 i 'I 7 ii077,000 29,600 ,.330 550,600 60i ,100 22 780 I 130 10977,000 S8, 000 270 1069. 400 906.,300 10 2i4 885 i0877,.000 :~9. 000 ,350 653,,900 641.700 19 660 972 10777,000 35,600 ,320 553,500 588,900 22 760 10677.000 149,50.0 ,400 796,000 733.400 i4 229 ,968 Fiim naa, m: ~GSFOi , l"la ::.'. i m u n', 1 m n g t. h: 1 0 2 4 TRAILER RE:~:.ORDo Film type: LO Nmxt. Vet-sion ~.: DIRECT DIGITAL LOGGING COMPUTER RECEIVED OCT 1 9 1990 Alaska 0il & Gas Cons. Commission Anchorage PROCESSED AN~,LYSIS I I I I I I I I I I $$S$SSSS II I I I I I I I I SSSSSSSSSS ' II SS SS II SS II SS II 8SSSSSSSS II' SSSSSSSSS II SS II SS II ' 8~ S~ LLLLLLLLL I I I I I I I i I I SSSSSSSSSS LLLLLLLLL I I I I I I I I I I SSSSSSSS , DDDDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU DD DD IJU UU Db DD IJU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DDDDDDDDDD UUUUUUi.!iJUUUU DDD'DDDDDD UUUUUI. IIJUUU NM MN PPPPPPPPPPF MNM NHH PPPPPPPPPPF HMHM MHHH PP F MN MM MM MM PP F MM NH NH PPPPPPPPPP~ MN NN PPPPPPPPPP~ MM NM PP NM NM PP NM NH PP NH NH PP NH NM PP 22222222 222222222 22 22 22 22 22 22 22 222222222 222222222 777777777777 77777777777 77 77 77 77 77 77 77 77 77 77 77 777777777777 77777777777 77 77 77 77 77 77 77 77 77 77 77 SSSSSSSS SSSSSSSSSS SS SS SS SSSSSSSS~ SSSSSSSSS SS SS SSSSSSSSSS SSSSSSS$ '00000000 8888888888 O0000000OO 888888888888 O0 O0 88 88 O0 O0 88 88 OO oo ee 88 O0 O0 88888888 O0 O0 '88888888 O0 O0 88 88 O0 O0 88 88 O0 O0 88 88 00.00000000 888888888888 00000000 8888888888 EEEEEEEEEEEE PPPPPPPPPPP £EE£EEEEEEEE PPPPPPPPPPPP EE PP PP EE PP PP EE PP PP EE£EEEEE PPPPPPPPPPPP EEEEEEEE PPPPPPPPPPPP EE PP EE PP EE PP EEEEEEEEEEEE PP EEEEEEEEEEEE PP TTTTTTTTTTTT TTTTTT'FTTTTT TT T'F TT T'F TT TT TT T'F T'F TT AA NM AAAA HHH Mi' AA AA HHHN I'iHl AA AA MM NH NH I AA AA MM MHHH 1' AA AA MM NM I' AAAAAAAAAAAA NH AARAAAAAAAAA MN AA AA NH I A.A. AA NM I' AA AA NM t' AA AA NH 9999999999 OOOO00OO 999999999999 000000000 99 99 O0 99 99 O0 99 99 O0 999999999999 O0 999999999999 O0 99 O0 99 O0 99 99 O0 999999999999 000000000 9999999999 00000000 :~.~ REEL HEADER Service name: &G5F01 Previous reel: Date: 90/09?27 Comments: 'HEADER Origin: RECORDS Reel name: Page 1 Continuation ~: O1 TAPE HEADER Service name: &GSF01 Previous .tape: Date: 90/.09/27 Comments: Origin: Tape name: 5 ~ 2 2 7 '9 Continuation ~: Ol FILE. HEADER File name: .0.0! Service name: Version Date: Haximum length: 1'024 File type: LO Previous ¢ile: TION RECORDS Page MNEM COHTENTS UNIT T"/PE CATG SIZE CODE ERROR CH WN FN, COUN STAT CTRY APIN LATI LOHG SECT TOWH RANG EK8 EDF EGL PD LHF DMF' RUN TIME DATE LCC SON LUN FL LUL ENGI WITN DD DL CBDI CBL1 TLI 8LI TCS TLA8 8HT NRT MT DFD MVIS DFPH DFL RH RMF HFST HFSS RMC ARCO ALASKA INC. DS i-2S PRUDHOE BAY NORTH SLOPE ALASKA USA 2'.0874, '0 0 0 ..... 0 Deg. 0 Min O, Deg, 0 Mtn '1 ON .... 15E .... ?4.0.00. 7:3., 0 O0 . ,1.0. 000. MS ..... KB ..... KB ..... 11.00. 000 8/ 9/90. 30 ...... 532279 51:301 HORTH SLOPE NORTH SLOPE FIHSTERWALD DETHLEFS/SMALSTI 10130.000 , . I0071 .000 , , 0.000 ...... 0,0'00 ...... 9700.000, , , 10064.000 , . O,OOO ...... il00.000, , , 0,000 ...... 0.000 ...... PRODUCED 6'666'. 0 000, 0 000. 0 000, 0 O00. 0 000. 0 000. AP1NUM: 50-029-20874 [)ATE LOGGED: 08-,08-90 [iwmiiiiii iIilimiiili iIiiiiIiiii |lllIii iiliiii iliiili 0 Sec 0 Sec IIIlIIIIIIIdIII IIIIlilIIIIII · IIlIIWlIIIII I I , -. . 0 0 40 65 0 0 40 0 0 40 0 0 20 0 0 20 65 0 0 20 0 0 4 G8 0 0 34 65 0 0 34 65 'o 0 2 65 0 0 3 G5 0 0 3 65 FT 0 3 4 68 FT .0 :3 4 G8 Fl' 0 3 4 G8 0 3 2 6,5 0 :3 2 65 0 3 2 65 0 0 2 79 0 0 4 68 0 0 8 6,5 Ct O 2 79 0 0 10 65 0 0 10 G5 0 0 20 65 0 0 20 6,5 0 0 20 65 0 0 20 65 F'r o :3 4 68 F'T O 3 4 68 FT O ;3 4 68 FT 0 3 4 68 FT 0 :3 4 68 FT 0 3 4 6,8 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF O 1 4 68 0 2 20 65 0 2 20 65 LB/C, 0 2 4 68 CP O 2 4 68 0 2 4 68 0 2 4 68 OHHM 0 2 "4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHMH 0 2 4 68 MNEM BS I NFORMAT I ON RECORDS CONTENTS D.E GF TYPE SIZE 4 12 4 4 CODE 65 Page ERROR COMMENT RECORDS Well Location Comment ~: Well Location Comment 2: Well LoCation Comment 3: Well Location Comment 4: Well File Comment 1: TIED SURFACE: 872' FNL & 594' FWL INTO WESTERH ATLAS PFC LOG DATED 03-1 e,-90. ~ell File Comment 2: ~ell Fil~ Comment 3: ~ell File Comment 4: LIS tape written by: ANCHORAGE COHPUTING CENTER All curve and tool mnemonics used are those which mozt closely, match Halliburton curve and tool mnemonics. HALLIBURTON TO SCNLUHBERGER TOP 80TTOH MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 9690.08 10075.00 SGFN THD CU SGFN TMD CU 9696.00 10067.80 SGFF THD CU SGFF THD CU 9696.88 SGBH THD CU SGBH THD CU 9696.08 1006'/.00 NSBF TMD CNTS NSBF THD CNTS 9696.00 FSBF THD CHTS FSBF TMD CNT$ 9696,00 NTHD TND HTMD THD 9696.8~ 10067.80 FTMD THD FTHD THD 9696.00 10067.80 RTMD THD RTHD THD 9696.00 1~067.00 CRNF TMD CRNF THD 9696.00 10067.00 Pag~ PHIT S~FH ~4ER RSBF ABTN S~IN SI~C ~R ~LU SDD$ SDDP TMO TMD TMO TMD T~D TMD TND TMD TND THO TMD CONPUT CONPUT CONPUT CONPUT CU CU ~API CU PHIT SGFM G4ER RSBF ABTN SC, IN $iGC CCL SODS SDDP THD THD TMD THD TMD TMD THD THD THD TMD TMD COMPUT COMPUT ~OHPUT COHPUT CU CU ~flPI 9696 9696 9696 9696 9696 9696 9696 9696 9696 9696 9696 9696 9696 9696 9696 .00 ,0.'0 ,00 . .00 . ,00 ,00 .00 O0 · 0 0.0 O0 00 O0 O0 O0 '006?, 00 .0:061=' , 0 0 0067, O0 :0061', O0 0:067. O0 0.06 ?, 00 0.06? . 0 0 0067, O0 006 ?', 00 0'067,0 0 '0,06?, 00 006~''~, O0 0 '06 ? . 00 006? , 00 0067. O0 DATA ENTRY BLOCKS ENTRY FORMAT SPECIFICA TypiE SIZE CODE T IONS Page ENTRY BLOCK LEGEND TYPE DESCRIPTION 16 Datum spec 0 Terminator i,?ication block sub-type ( no more entries ) D A T A 0 R M A T DATUM SPECIFICATION BLOCKS **** SPECIFICA TION Page HNEH SERVICE SERVICE AP1 APl APl API FILE ID ORDER # .UNIT LOG TYPE CLASS HOD ~ PRC SIZE LVL SHPL RC PROCES9 INDICATORS DEPT SGFN THD SGFF THO SGBH THO NSBF TMD FSBF TND NTHD TND FTHD TND RTHD THD CRNF THD PHIT THD SGFM THD SIGQ TMD G4ER TMD RSBF THD ~BTN TND S~IH THD ~IGC THO GR THD CCL TND CCLU THD 532279 FT 0 0 0 0 1 532,279 CU 94 0 0 i 0 532279 CU 94 0 0 ! 0 532279 CU 94 0 0 1 0 532279 CNTS 94 0 0 1 0 532279 CNTS 94 O 0 i 0 532279 94 :0 0 1 0 532279 94 O 0 '1 O 532279 94 0 0 '1 0 532279 94 0 0 1 0 532279 94 0 0 1 O 532279 CU 94 0 0 1 0 532279 94 O 0 ! 0 532279 94 0 0 i 0 532279 94 0 0 I 0 532279 94 O 0 1 0 532279 CU 94 0 0 1 0 '532279 94 O 0 1 O' 532279 .GAPI 94 '0 0 1 0 532279 94 :O 0 1 0 532279 94 ,0 0 1 0 CU 94 0 0 1 0 CU 94 O 0 1 0 94 0 0 i 0 94 0 0 1 0 ~VGS COMPUT 532279 SDDS COMPUT 532279 AVGP COMPUT 532279 SDDP COHPUT 532279 4 0 1 68 4 0 1 68 4 0 I 4 0 1 68 4 0 1 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 4 0 i 68 ,4 0 1 68 4 0 ~ 68 4 0 1 68 4 0 ! 68 4 0 I 6e 4 0 1 68 4 0 '1 68 4 0 1 4 0 i 4 0 i 68 4 0 1 68 4 0 1 68 000000 000000 000000 000000 O0000O 000000 000000 O00000 000000 OOOO00 OOOOOO 000000 000000 000000 000000 000000 000'000 000000 ,000000 000000 000000 000000 000000 000000 · 000000 000000 000000 O00OO0 80O,OOO 000000 000000 O0000O 000000 000000 OOOOOO O00OO0 000000 OOOO00 000000 000000 OOO0,OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 0'00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT RTMD S~IN SDDP SGFN ~RNF S~FF Pi-liT ~R DA S~FM CCL TA RECORDS NSBF $I~Q CCLU FSBF ~4ER NTHD R~F FTHD ~BTN ~VCP Pag~ 10067. O. 15. 10000, 5. 14. 9900, 5. 13, . 9800. 15· . 9700, 5, 18. . 000 000 O2;=' 392 O00 594 258 0 O7' 000 548 O84 000 049 555 029 000 708 481 019 21 ,807 O, 000 1 , 095 19. 141 5,594 I , 1'01 18,231 5.548 1.127 20,213 6. 049 1. O82 22.63.3 5,708 1, 049 22. 089 1,039 -1 .000 14,772 ,244 23.530 13,459 ,238 18,715 ·309 19, O56 19.884 ,260 35,491 8'0. 656 16,455 -1 , 000 84.'128 7:04 362 82.547 14,752 ,494 83,365 16.832 48.016 77. 753 19,389 64.41 2 64.541 ,959 22,728 70,953 .989 4.877 76,238 ,987 13,725 78,093 ,982 20,600 82.811 .989 (,6. 696 5. 076 ,018 14,025 6.936 .018 14. 1.4.4 6,421 · 02 0 12.977 6,459 ,007 15,101 6,493 -. 03i 19,310 0,000 3,653 ,375 9182,352 1 ,388 .379 1 0184,496 1 ,3i3 ,500 7'923,957 1,353 ,312 6618,906 2.339 .7i9 0,000 30040.137 ,413 : 1641,490 27259,660 ,235 1835.677 25609.957 ,235 1309,918 25387,699 ,268 1159,682 .249 ** FILE TRAILER File name; &GSFOJ.001 Service name: TRAILER RECORDS Maximum length: 1024 File t,ype: LO Version #: Next f'ile: P ag e File namm: .002 Service name: Version #: Date: Maximum length: '1'024 File type: LO Previous ~ile: I N FORMAT I ON RECORDS Page MNEM CN WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKD EDF EGL PD LMF DMF RUN TIME DATE LOC SON LUN FL LUL ENGI WITN DD DL C8D1 CBLI TLI BLI TCS TLA8 BHT NRT MT MSS DFD MVIS' DFPH DFL RM RMF MFST MFSS RMC CONTENTS ARCO ALASKA INC, DS 1-25 PRUDHOE BAY NORTH SLOPE ALASKA USA 2'0874,.000 .......... .O.Dmg, 0 Min. O '0 Deg. 0 Hin, 0 10N .... 15E .... 74,000 . 73.00'0 . 40.000 , 1100,000 , e? 9?90. , 532279 , 51301 , NORTH SLOPE NORTH SLOPE FINSTEEWALD DETHLEFS/SMALSTIG 10130.'000 .... 10071,000 .... O,O00 ........ O.O00 ........ 9700,000 ..... 100'64.000 .... 0.000 ........ 1100.000 ...... 0..000 ........ 0.000 ........ PRODUCED b'666' '. .... O,.O00 ...... O. '000 ...... 0.000 ...... 0,000 ...... O.O00 ...... O.-O00 ...... i e . ! i m API t4UM: 50-029-20874 DATE LOGGED: 08- 08-90 i i / i i 41 i 0 0 $,.'c . 'IAI i i · ! i i i i illili . UN I T F 'r FT FT FT FT FT FT FT FT HR HR DEGF DEGF LB/G CP OHMM OHMM DEGF OHMM TYPE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CATG 0 O O 0 0 0 0 0 0 0 0 0 3 3 3 3 3 3 0 0 0 0 '0 0 0 0 0 0 3 3 3 3 3 3 2 4 1 i 2 2 2 2 2 2 2 2 2 2 SIZE 40 40 40 20 2.0 20 4 34 34 3 3 4 4 4 2 4 2 10 10 20 2O 20 2O 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 65 65 65 65 65 65 68 65 65 65 65 65 79 68 65 79 65 65 65 65 68 68 68 68 68 68 65 68 68 68 68 65 ERROR INFORMAT I ON RECORDS Page i0 BS CONTENTS 0 0 0 0 ~'~: ................................................... I IIIllIIllllIIIIIIllIIlIIllIIIItIIIlIIlIlIIlllIIllll 0 000 · , IllllJllJmmmllmmllellllllJlflJllall&llllamllmlllmdl UN IT DEGF TYPE 0 0 0 0 CRTG SIZE 4 12 4 4 CODE 65 68 68 ERROR COMMENT RECORDS Well Location Comment 1: SURFACE: 8,?2' FNL & 594' FWL Well Location Comment 2: Well Location Comment 3: Well Location Comment 4: Well File Comment 1: TIED INTO' WESTERN ATLAS PFC LOG DATED 03-18-90, Well File Comment 2: WelI Fil.e Comment 3: Well File Comment 4: · ~ LIS tape written by: ANCHORAGE COMPUTING CENTER · :~ All curve and tool mnemonics used are those which most closely match · ~ Halliburton curve and ,tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE DEPTH DEPTH UNIT DEPTH FT DEPT FT SGFN1 TMD CU SGFN TMD CU SGFF1 TMD CU SGFF TMD CU SGBH1 TND CU SGBH THD CU NSBF! TND CNTS NSBF TMD CNTS FSBFI TMD CNTS FSBF TND CNTS HTNDI TMD NTMD TMD FTMDI TND FTMD TMD RTMDI TMD RTMD TMD CRNFI TMD CRNF TMD 9690 00 9696 75 9696 75 9696 75 9696 75 9696 75 9696 75 9696 75 9696 75 9696 ?5 Page 1¸1 PHI T1 SIGQ! G4ER ! R~BF~ ABTHI S G I N i $IGC1 (;RI CCL! CCLU1 TMD THD TMD TMD TMD TMD THD THD TMD THD TMD CU CU GAPI PHIT SGFH SIGQ G4ER RSBF ABTN SGIN SlGC GR CCL CCLU THO 'THO TMD TMD THD THD TMD TMD TMD THD THO CU CU GAPI 9696 9696 9696 9696 9696 9696 9696 9696 9696 9696 9696 .75 ,75 .75 75 75 75 75 75 75 75 75 O06L~, 00 006::~, 00 O06:i.i:, 00 ..0060, O 0 IO06G:,O0 O'06E~, 0 0 006 :ii:, 00 006:3, O0 006 ::3.00 006:i~., O0 . 00~:3.00 D A T ~ F 0 R M A T · ~ EHTRY BLOCKS ENTRY TYPE 16 0 · ~ ENTRY BLOCK LEGEND, TYPE DESCRIPTIOH 16 Datum speci¢ication block zub-t,ype 0 Terminator ( no more entriez ) SIZE SPECIFICA CODE T I OHS Page 12 DATA FORMAT SPECIFICA ,T I ,Oi4S Pag~ 1S HNEH SERVICE SERVICE API API API API FILE ID ORDER # UNIT LOG TYPE CLASS MOD # lmII III II~! PRO # SIZE LVL SMPL RC PROCESS INDICATORS DEPT SGFN THD SGFF TMD S~BH TMD NSBF T~D FSBF TMD NTHD THD FTHD THD RT~D' TMD CRNF TMD PHIT TND SGF~ TND SIG~ T~D G~ER TND RSBF T~D' ~BTN T~D SGI~ TND $IGC THD GR THD CCL TMD CCLU THD 532279 FT 0 0 0 .0 2 532279 CU 94 '0 0 3 1 532279 CU 94 0 0 3 532279 CU 94 0 0 3 532279 CNTS 94 0 0 3 1 532279 CNT8 94 0 0 3 i 532279 94 0 0 3 1 532279 94 0 0 3 1 532279 94 0 0 3 i 532279 94 0 0 3 532279 94 ,,0 0 3 1 532279 CU 94 0 0 3 i 532279 94 O 0 3 i 532279 94 O O 3 1 532279 94 O 0 3 i 532279 94 0 0 ~ 1 532279 CU 94 0 0 3 1 532279 94 O 0 3 1 532279 GAPI 94 O O 3 i 532279 94 0 0 3 532279 94 0 0 3 i 000000 000000 000000 000000 OOO000 000000 000000 OOOO0'O 000000 000000 000000 000000 000000 OO0000 000000 O0000O 80O0OO 000000 000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT RTHD ,SG i N SGFN CRt. IF 8IGC. SGFF PHIT GR DATA SGBH SGFM CCL RECORDS NSBF SlGQ CCLU FSBF G4ER NTHD RSBF FTHD ABTN Page 14 i 0068, 000 O, 000 i4,794 iO000.O00 5.529 14,477 9900,000 5,572 13.564 9800,:000 5.752 14,948 9?O0,000 5. 699 20,015 20. 042 0.000 1, 100 19,349 5.529 1,100 18,574 5,572 1',114 19.787 5,752 1,096 23.822 5.699 1.032 16.414 ,i55 - 1,000 15.i61 ,235 23.071 14.483 ,241 24,398 'l 7,634 ,266 23,607 20,525 .259 42.002 75.5i5 i6,276 -1.,OOO 83,036 15.922 26,100 84,139 iS.ii,O 7.428 80,817 16,384 17,615 82,233 20.651 32,451 89.931 ,983 i.215 89,907 ,991 1,783 93.269 .990 55,254 94,566 ,990 45.247 96,251 ,986 27,478 6.9i9 · Oi 3 8.969 , .0i 7 7,803 . .006 7,58! .01 3 8, .005 '0..O00 i .869 9152,547 1 ,364 1 0345,477 i ,289 8011 , 434 1 ,415 6655. 363 2.155 0.000 29242. i 02 1655,494 26954,562 1856,768 26367,008 139::' ,871 26028,711 I167,758 27567,629 ** FILE TRAILER File name= &GSF.O1,002 Maximum length: 1024 TR'AILER R'ECORDS 'Service name: Film type: LO Version ,#: Next ~ i 1 m: Date: Pag~ 15 ** FILE:HEADER **** File name: ,'003 SePvice name: Version #: Date: Maximum length: 1024 . File type: LO Previous ?ile: MNEM FN COUN STAT CTRY APIN LATI LONG ,SECT TOWN RANG EKB EDF EGL PD LMF DMF RUN TIME DATE SON LUN FL LUL ENGI ~ITN DD DL CBDI CBL1 TLI BLI TCS TLAB BHT HRT MT MSS DFD MVIS DFPH DFL RH RMF HFST MFSS RMC I N'FOR'MAT I ON CONTENTS ARCO ALASKA DS 1-25 PRUDHOE BAY NORTH SLOPE ALASKA USA 20874. OOO .......... O,Dcg. 0 Min. O Deg., O Min. 1 ON ...... tSE ...... 74,00,0. , . 73,0,0:O.,. 40,000... I'1S KB ....... 1 I,:00. O00. 8/ 9/90, , 532279 51301 NORTH SLOPE 'NORTH SLOPE FINSTERWALD DETHLEF$?SHALST 101'30. 000 ..... 1 0071 , 000 ..... O, '000 ......... O, '0.00 ......... 9700,000 ...... 1 0064. O 00 ..... 0,000 ......... 1100,000 ...... 0,000 ......... 0,000 ......... PRODUCED INC. APl NUM: 50-029-20874 ~D: 08-08-90 Iiii DATE LOQG IIIIIII 0 Sec I w · · "666" 0,000., 0,000, , 0.000, , O.OOO, , 0,000.. 0.000. , 6'666" Il ! i i i II ii w i , · ,i · ,i i i i m I i i RECORDS UHIT · i i T '~" PE CATG 0 0 0 ,0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 3 FT ' 0 FT 0 0 3 O 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT. 0 3 FT 0 3 FT 0 3 FT 0 3 FT .0 3 FT .0 3 HR 0 2 HR 0 4 DEGF 0 'I DEGF 0 1 0 2 0 LB,:G 0 2 CP 0 2 0 2 0 2 0 Ft H H 0 2 OHHH 0 DEGF 0 2 0 2 0 Iq hi M 0 2 SIZE 40 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 2 4 2 10 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 65 65 G5 G5 65 65 G8 G5 65 65 65 G8 68 G8 G5 79 68 G5 79 G5 G5 G5 G5 G5 65 68 68 G8 G8 68 G8 G8 G8 68 68 G5 G5 68 68 68 68 68 68 68 65 68 ERROR 16 I NFORMAT I ON RECORDS Page 17 MNEM CS BS CONTEHTS 0 ,000 ~,~ ................................................... I IIIIlIIllIIIlIlIIlIIIIlltlllIlIIlIll IIlII 0 ,000 , I IIIlIIIllIIOIIlIllltIllllIIeIlIIIIIllIlIIlIIiIIliIi UNIT DEGF TYPE CATG SIZE , i2 4 4 CODE ERROR COMMENT .RECORDS Well Location Comment l: Well Location Comment '2: Well Location Comment 3: Well Location Comment 4: Well File Comment i: TIED Well File Comment 2: Well File Comment 3: SURFACE: 8?2' FNL ~ 594' FWL IHTO WESTERH ATLAS PFC LO~ DATED 03-18-90. Well File Comment 4: · =~ LIS tape wpitten b~: AHCHORAGE COMPUTING CEHTER ~ · ~ All cupve and tool mnemonics used ape those ~hich most closely match ~ · ~ Hallibupton cur. ye and tool mnemonics. ~ HALLIBURTON TO SCHLUHBERGER TOP BO'I"TOH .MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 9690.00 10075.00 SGFN2 TMD CU SGFN TMD CU 9696,50 10069.00 SGFF2 TMD CU SGFF TMD CU 9696,50 1.0069.00 8GBH2 THD CU SGBH TMD CU 9696.50 10069.00 NSBF2 THD CNTS NSBF TMD CHTS 9696,50 10~69,00 FSBF2 THD CNTS FSBF TMD CNTS 9696,50 10~69.00 NTMD2 TMD HTMD THO 9696.50 10069..00 FTMD2 TND FTMD TMD 9696,50 10069,00 RTHD2 TMD RTHD TMD 9696.50 10.069,00 CRNF2 TMD CRHF TMD 9696,50 10069,00 Page 18 PHIT2 SGFN2 G4ER2 R~BF2 'ABTN2 SGIN2 SIGC2 GE2 CCL2 CCLU2 TND TND TND TND TND TND TND TND TND TI'ID TND CU CU GAPI PHIT SGFH ~IGQ G4ER RSBF ABTN SGIN SIGC GR CCL CCLU TMD .THD THD THD THD TMD THD THD TMD CU CU GAPI 9696,50 9696,50 9696,50 969~,50 9~96,50 9696,50 9696.5:0 9696,50 9696.50 9696,~5,0 9~96,5~ 10069 O0 I 0:069 O0 100d, 9 O0 i 0069 O0 t .0:069 00 'l ,0069 00 1 006 ':~ 00 100~9 O0 ! 0.069.00 10069, O0 10069. O0 DATA FORMAT ENTRY BLOCKS ENTRY TYPE 16 0 ENTRY'BLOCK LEGEND TYPE DESCRIPTION 16 Datum specification block sub-t~pe 0 Terminator :( no more ~ntpies ) SIZE SPEC I F I CA CODE TIOHS Pag~ 19 DATA F'ORFIAT SPEC I F I CAT I ObIS DATUM 8PEO~FIOATION BLOOKS ~ERVICE SERVI~E APl APl API APl FILE ID ORDER # UNIT LO~ TYPE CLASS MOD # PRC # SIZE LYL SHPL RC II PROCESS INDICATORS Pag~ 2O DEPT 532279 FT '0 0 0 0 3 SGFN THD 532279 CU 94 0 0 4 2 SGFF THD 532279 CU 94 ~0 0 4 2 SGBH TND 532279 CU 94 0 0 4 2 NSBF THD 532279 CNTS 94 0 0 4 2 FSBF THD 532279 CNTS 94 0 0 4 2 NTND THO 532279 94 0 0 4 2 FTHD TND 532279 94 0 0 4 2 RTMD THD 532279 94 0 0 4 2 CRNF TND' 532279 94 0 0 4 2 PHIT TMD 532279 94 '0 0 4 2 SGFH THD 532279 CU 94 0 0 4 2 SIGQ THD 532279 94 '0 0 4 2 G4ER TMD 532279 94 0 0 4 2 RSBF TND 532279 94 '0 0 4 2 ABTN TMD 532279 94 O 0 4 2 SG'IN THD 532279 CU 94 '0 0 4 2 SIGC THD 532279 94 0 O 4 2 GE TND 532279 GAPI 94 :0 0 4 2 CCL THD 532279 94 0 0 4 2 CCLU THD 532279 94 '0 0 4 2 000000 000000 000000 000000 00000.0 000000 000000 000000 000000 O000OO 000000 000000 000000 000'000 000000 000000 O00000 000000 000000 0OO00O 000000 ,000000 OOO'OOO 000000 000000 OOO000 000000 000000 000000 000000 00000'0 000000 000000 000000 OOOOOO O000OO 00000.0 000000 000000 000000 O00000 000000 00O000 000000 000000 0000~00 000000 000000 000000 O0000O 000000 .00000'0 000000 000000 00000~0 O0.O000 000000 000000 O00000 000000 000000 O0000O 000000 DATA RECORDS DEPT 8~FH ~FF ~BH NSBF RTMD ~RHF PHIT ~FH SI~Q 0 14 10000 5 13 9900 S 12 9800 5 14 ,0:0 0 .0,0 0 ,318 19, '000 468 581 5, 1. O0 0 440 174 17, 5, 000 5.05 951 19. 5. 1. .00 0 405 371 23, 5. 1. 9700 5 19 201 17,408 74,'137 00'0 ,197 15,874 I 09 -1 , 0 O0 - 1 , .O.O'O 98.434 .986 ,536 645 15.432 82,230 468 .227 15,184 118 1416.179 71.608 99.416 ,993 191,096 566 14,364 60.236 440 ,223 14.955 155 253,966 1,437 1'03,487 .980 4,0.296 811 16,752 79. 798 5 r 05 ' 232 16,4:08 .097 3.0,138 1 .725 1 01 . 65 0 ,994 19,736 341 21 , 288 77.9'19 405 .218 20. 140 040 41 ,997 5,181 1 03,690 ,984 3.677 FSBF G4ER NTMD RSBF FTMD ~BTN 9.259 .0,02 0. 000 2. 077 0,000 30261 ,992 8.217 .015 8898.109 1.437 1627,219 26781,793 9.73 0 ,:018 9861 . 762 I .290 1812.981 25177.676 7.811 ,009 7237.875 1.448 1314,765 25782.121 9.815 -.016 6561,262 2,354 1213.966 28433,195 Page 21 FILE ,TRAILER File name: &GSF01.~OO3 Naximum length: 1'024 REEL TRAILER ************************ Service name: &GSFO'I Next reel: TRAILER RECORDS Service name: Version #: File type: LO Next File: Date: 90/09/2? Origin Comments: Reel name: Date: 532279 Page Continuation #: 01 22 ~** TAPE TRAILER e**e Service name: &GSF01 Next tape: Oate: 90/09/22 ,Origin Comments: Tape name: 532279 Continuation #: 01 LIS TAPE VERIFICATION LISTING ~P 010,,~O2 YERIFICATIL~N L~ST,ING ~G~) 1 ATE .'I~3/02/24 APE K~ A N~E O~TINI) AT.'ION ~ :01 REVIOUS TAPE [71~EN~'S :LI, SRARY TAPk * FILE HE;ADEt,i: ERVICE NAME g R S I 0 N ~ ATE : IbE TYPE REVlf)U5 FILE * INI~'C!P,',,ATIOIi RECORDS ;~1 : A T i, A N T 'I C R I C !t F' 'l. g' b [) C, 0 M ["" A f~ Y t~ : ~! E I,,, [,, N ; PRUDHOE, B.~Y ANG: OWN: 1 ON ECT: OUN: NO~TH Sk, i~Pg TAT: ALASKA * COMMENTS 000 000 026 065 000 000 004 065 O00 000 012 065 000 000 003 065 000 000 003 065 OOt) OOO 001 Ob5 000 000 012 065 000 000 006 065 000 000 006 005 "P Ol(.).HO2 ~/'ERI',F.[CATIO~,t L,~o.ING ~ ¢' ® ..... PAGE 2 SCNLU~iDERGER ALASKA CO~!PI,iTING CENTER }~4PANY : ATLAf',~TIC RICi~FIEbD COb,~PANY ;LL : 1) 5, 1-25 ::EL, D = P~.UDH{3~. BAY )UNTY = {'~ORT~ SbOPE BOROUGH 7ATE = ALASKA ~E~ oE~VICF SERVICE ;' b U D i L ~ M D ] b ';) D I L BHC ~ H [) L D T "J 0 B L D T ~ [ DT .,Nb LD~ ~j F L D T ~I,,I LDT ~{AT bDT ~RA LOT ? H I C ~,~ L RAT C N L ~! R A C N L g N L C J~ b R CNL BL, OCKS UNIT AP1 APl'. F',[~ 0 0 ~V 7 GAPI 7 USIF 6o 52 GAPI 60 31 PLt O G / C 3 0 44 G/C3 0 3b 0 0 0 G~PI 0 0 0 Pti 42 42 42 42 0 42 34 42 34 G~PI 42 31 AP1 CLASS 0 0 0 0 32 32 32 2 0 1 92 ~3 0 3 32 1 (') 2 ! 0 92 93 32 API o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 7 3 65 b O FILE NO . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 $ I 60 .1IN o ZE PROCESS bgYEb 4 0 4 0 4 0 4 0 4 0 4: 0 4 0 4, 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 4 0 4 0 4 0 4 0 4 0 8A~Pbg 1 1 1 1 1 1 1 1 1 1 1 1 1, 1 1 1 1 REPR CODE 68 68 68 68 68 68 68 68 ~8 68 * [) A T A P PHI R AT E: P 'I' P PHI CNL RAT EPT P PHI Cr,i I, RAT t,,! RA 10330,5000 -53.3125 -999,2500 -999.2500 -999.2500 -999.2500 10300.0000 -6~,5000 24,9023 -112~8,0000 2.3965 -099.2500 10~00 65:1250 26,36'12 1449.0000 2.b000 -999.2500 SFLU C; ~. D R H 0 RNEA N C tx, L. S.FLU GR D R H 0 PEF RNRA SFI,U ORHO PEF RNRA o -201. -999, -999. 99, -116, O. 2. 2, '999. , 1, 2. -999. 1836 5000 2500 250O 2500 2500 621 [ 1875 0107 7988 5742 250O 0u59 2187 0034 5'781 6035 2500 lbo DT RHOB CALl NPHI FCNL I [, D DT RHO~ C~[,I t,, P H I ILD DT ChLI NPH1 FCN[, 4,0586 IbM 80,0000 GR -999,2500 NCNb -999,2500 GR -999,2500 NRAT -999.2500 GR 3,5859 80.0000 GR 2,3672 NCNb 8,4297 GR -999,2500 -999,2500 GR 3,2168 IbM ~8,7500 GR 2.2344 NCNb 8.5313 GR -999,2500 NRAT '999,2500 GR 3,8066 -201.5000 i999,2500 999,250() 999,2500 -999,2500 3,5586 '110,1875 '29056,0000 '43q 7500 '999~2500 '999,2500 3,0~79 33.2187 3774,0000 30,8906 '999,2500 -999.2500 VP 010,HO2 VEPIFICATIO~ LISTING PAGE 4 EPT 10100 000() P .,46.4375 GR PHI 22,55166 CNL i, 657. 0900 PEF RAT 2,2734 NRA -999,250() EPT I 0000 P ~NI,, 2020 R A T 1 NRA -999 EPT 9 900 P ,,,61 PHI 26 CNL 1 374 RAT 2 t~RA -999 EPT 9800 P -56 P H I 21 UNb 1 568 RAT 2 NRA -999 EPT 9700 P -19 PHI 17 CNL 2292 ~AT 1 NRA -999 EPT 9600 p 7 PHI 51 CNb 359 RAT 4 NRA 4 EPT ~500 P 999~ PHI -999. CNI.., -999, RAT =999, NRA 4, EPT 9400, P -999 PHI -999: C~L -999, O00(~ SF[,U 1250 GR 6035 [)RMO OO()0 PEF 9~24 RNRa 2500 NCN6 0000 SF'LU ~262 0000 PEF 2031 RNRA 2500 NCNb ,0000 S F L U ' , 1250 GR ,1387 0 k H 0 ,0000 P E F 9424 RNRA :2500 NCN!., 0000 SFLU 7617 GR 1719 DaHO 7500 PEF 2031 RNRA 3633 NCN[, 0000 SFLU 2500 GR 2500 2500 2500 RNRA 3320 NCNL 0000 SFI',iJ 25O0 Ga 2500 FJRHD 2500 PEF :t2,71,88 30.5 (') 00 '9,, 0244 ~: 095'1 4980 - 999 ~ 2500 40 5000 2~ 0~25 0210 2 2012 2 1~16 -999 2500 ]5 4375 49 0938 0 0176 1 9844 2 4570 -999 2500 38.9062 39 7500 -~ 0259 5000 2 216~ -999 2500 I b D D T RHOB CAI, I NPH 1 FCN I.., II_,D DT RHOM CAbI NPH1 FCNL I LD D ¢ A L I NPItI F'CNL I I5 D DT RHOB CAbI F'CNb 69,8750 1~0,B125 DT 0,0093 RHOB 4,4648 CALl 2,1133 NPHI -999.2500 FCNL 4,4414 IbD 99 6875 PT 0!1.196 RHOP 2 7578 CALl 4,5625 NPHI 1669.0000 VCNL -999;2500 -999,2500 bT -999,2500 -999,2500 CAbI -999.2500 NPHI 1582.0000 VCNL -999,2500 iUD -999,2500 OT -999,2500 RHOE -999,2500 CALl I~,~685 ibm , 750 GR , 2539 NCNb ,fl828 GR 2500 ~RAT -999,,,, ( '999,250) 51.4063 3359 8i 3.750 5313 -999 2500 -999 2:500 G:R N C il L 'GR NRAT GR 37,7813 88,3750 GR 2 3398 NCNb 8:6250 "999,2500 NRAT -999,2500 GR 43.5313 II, M 84,0000 GR 2,4()82 NCNI .... 8 ~250 GR 999~ 500 RA.~ -999.2500 GR 61,1562 I[.M 69,3750 GR 2,6211 NCNb 9,2109 GR -999,2500 NRAT -999.2500 GR 1.7334 IbM 104,5625 GR 2.3672 NCNb 14,3750 GR 46.3379 NRAT 382.5000 G~ '999,2500 IIJ~ '999,2500 GR -999,2500 NCNL -999,2500 GR 48,5840 NRAT 365,0000 GR -999.2500 Ib~ -999,250o GR -999,2500 [';CNL '999,2509 GR 15,525 30,50 (.) ~ 41~,0000 · ,8125 -999 ~500 999~ - 500 4'1, l'$~2 2 , 0625 44.08,0000 22,6563 -999,2500 "999. 2500 't, 0000 9.o93a 39, 75 999,2500 -999,2500 39,656.3 39.7500 3~78.0000 32,4063 ~999,2500 999,2500 67,7500 100,8125 4844'0000 90,7500 -999,2500 -999,~500 1,8936 99,6875 1642,0000 103,5000 3,9453 101.0000 -999,2500 -999,2500 -999.2500 -999,2500 4.0664 77,6875 999,2500 ~999,2500 -999.2500 '999,2500 CP OlO,H02 VE]RI',F1CATION bISTING PAGE 2500 8320 - g 9 g, 2500 16O 3. 0000 !'..P T 9300 :~ -999 PHI -999 ['] N L, -999 ~AT -99~ -999,2500 -909,2500 -999 2500 -999 2500 -999 2500 1769 0000 ~;P~I" 9200, !)uO0 SFI..li -999,250o - 99,2500 GR -999,~500 p 9~' ~Hi -999,2500 ['} RH ~ -999, 500 ,TNb -999,~500 PEF -999,2500 RAT -999 ~500 RNRA -999. 250() aRA 3:012 NCNb !934.0000 EPT 9100 P -999 PHI -999 ~." hl 1.~ - 999 RAT -999 N.R a 4 0000 SFLU 2500 GR 2500 D R H 0 2500 PEF' 2500 RNRA .2~.52 NCnb, -999 -999 -999 -999 -999 1625 N P H I F C N b EPT 9000 P -999 PM1 -999 CNL -999 RAT -999 NRA 3 · 00 U 0 5 F b U 25O0 GR 2500 DRHu 2500 PEF 2500 RNRA 5488 NCNb IlbD CfiLI F C a ,b EPT 8900,0000 SFLU P '999,2500 GR PHI '~',999' 2500 DRHO CNb . 99,2500 PEF' RAT -999.2500 RNRA NR~ 4, ~.)~9~ NCNb I b D DT CALl FCNb · 00 00 S F L U EPT ~ 800, . , P -999.2500 GR PHI -999,2500 DRH0 CNL, -999 2500 PEF RAT -999'2500 RhRA , NRA 4,9453 NCNb 2500 lb[) 250 o D T 2500 2500 NPHI 0000 FCNh EPT B700,0000 SFI..U P -999,2500 GR PHI -999.2500 Dt~HO CNL -999,2500 PF;F RAT -999.2500 RNRA NRA 4,1367 NCNL -999,2500 I L -999,2500 DT -999,2500 RHOb -999,2500 CA I.,I -999,2500 NP'HI 1986.0000 FCNL E PT P 8600. 0000 SFLU -999,2500 G~ 999 2500 IlL, I) :999 ' '.[" ,25 00 [.) -999,2500 -999,2500 CAb1 -999,250() NPHI 1498,000C) FCN '999,2500 ILO .'999,2500 PT 999,2500 RHOb -999.2500 CAbI -999.2500 NPHI 1697,0000 FCNb -999.25(,)0 IbD -999. 2500 DT -999,2500 RHO~ -999. 2500 CaLl -999,~500 NPHI 1647.0()00 FCNL -999. 2500 IL, l) -999,2500 DT 44.,2871 NRAT 418.2500 GR '999,250 ) II',.~N -999,2500 GR "999,2500 .. CNb -999,2500 GR 43,0175 NRAT 4.1,5.2500 GR '999 2500 IL~i -999 2500 GR '999 2500 NCNL -999 2500 GR 34 1309 NRAT 52'2,500() GR '999,2500 '999,2500 GR '999. 2500 NCNP -999. 250(i) GR 48,7305 NRAT 379,0000 ('; R -999,2500 -999.2500 GR -999. 2500 NCNb -999,2500 GR 37.4512 NRAT 559.5u00 GR -999,2500 99,2500 47,0703 NRAT 366,0000 -999,2500 IbM '999.2500 GR -999.2500 NCNb -999 2500 GR 49:5605 NRAT 343,0000 GR -999,2500 IbM -999,2500 GR -999,2500 NCNb '999,2500 GR 44.1895 NR~T 398,0000 GR '999,2500 IbM '999,2500 GR 3,8340 73,6250 -999,2500 -999,2500 -999,2500 2500 -999, , O0 -999 2500 -999 2500 -999 2500 -999 2500 3 2754 54 6250 -999,2500 -999,2500 -999,2500 -999,2500 4, 742 120'~1.25 -99~ 2500 -99 ~500 -999 500 -999 2500 3 4570 54,1875 -999,2500 -999,2500 -999,2500 -999.2500 3,9844 99,0625 -999 2500 -999 2500 -999 2500 -999 2500 4 1211 95,~750 -999,2500 -999,2500 -999,2500 '999,2500 3,8281 65,0~25 -999.2500 -999.2500 IP 010.b02 VERIFICATION I. iISTING PAGF. 6 ::.~ H I - q 99, '2500 D R H t'i..~ - 999 .,~iL -999. 500 EF -99 : ~AT -999~ 500 R.N~A -99 ~Rl~ 3.4629 NCNL 1817 2 ,500 .2500 2500 0000 ~500,0000 SFLU .,999 999.2500 (;R -999 -999,2509 D.RF~O -999 -999,2500 PE;F -999 -999,2500 RNRA -999 3,6055 ~CNL, 2500 250{3 2500 2500 2500 0000 ~.; P T 8400, () 000 S F L U - 999,2500 ~ -999,2500 GR -999,2500 :~HI -999,2500 DRH{] -999,2500 "I~L -999, 2500 PEF '999,2500 ~AT -999,2500 RNRA -999,2500 ~IRA 4.1328 NCNL 1708.0000 EPT 8 3OO ? -999 ?MI -999 =N 1.., -999 RAT -999 0000 S F L O 999 2500 GR -"999 2500 DRHO -999 2500 P Fi F.'"' -9g9 2500 RNRA -999 433~ NCNL 1731 25OO 2500 25O0 2500 2500 0 () 00 ~: P T ~ 200 ? -999 PHI -999 = N L - 999 RAT -999 ~RA 4 o 000 $ F.[, u - 999 2500 GR -999 2500 [)~ He.) -999 2500 PEF -999 2500 RN~A -999 0000 NCNL I ~ 12 25O0 .2500 .2500 .2500 .2500 .0000 ~PT 8100,0000 SFL, U -999 P -999,2500 GR -999 PHI -999.2500 DRHD -999 =NL -999.~500 PEF '999 RAT -999 2500 RNRA -999 ;~R.A 315996 N'C~]_, 1628 .2500 .2500 ,2500 ,2500 ,2500 ,0000 EPT ~000 P -999 PHI -999 C~L -999 RAT -999 NRA 3 .00("0 8FL, U -999 ,2500 G~ '9 99 ,2500 DRHO -999 ,2500 Pf~ -999 ,2500 R~A -999 .3105 NCNL 1673 ,2500 ,2500 .2500 ,2500 .2500 ,0000 EPT 7900, ~Q99, §99, CNL 999, RAT -999, NRA 4. 0000 S F I-, U 2500 GR 2500 D 1~ H 0 25(')0 PEF 2500 RNRA 2070 ~ C r,: b -999,2500 -999,2500 :999.2500 999,2500 -999.2500 1764,0000 HOB CA5 I NPHI FCNL I L D D T RHOB CALl NPHI FCNL .1 L D D T CALl NPHI F C N L I b D D T C A L I NPMI FCNL I b D DT CALI F C N L I LD DT C~a.L I F C {~ L I L L) DT RHOB CAI.,].. ~, P H I FCNL ILO DT CALl NPMI FCNL -999 2500 NCNb -999 25~0 GR 37 69..3 NRAT 524 5000 GR "i999,25~0 ILM -999,25~'0 GR, -999.~500 NCNL -999.2500 GR 3'6 425~ NRAT 505:5000 GR -999,2500 ILM '999,2500 OR -999,2500 NCNb -9]~ 2500 GR ~6484 NRAT 413.0000 GR -999 2500 -999 2500 -999 2500 -999 250O 38 8184 5O4 0000 GR N :C :N b GR NRAT -999,2500 -999,2500 GR -999 2500 -999,2500 GR 39.~602 NRAT 453,0000 GR '999.2500 ILM -999,2500 GR -999.2500 NCNL -999,2500 GR 43,45;0 NRAT 452.25 0 GR -999,2500 Iii.,a -999,2500 GR -999,2500 NC~L -999.2500 GR 34.2285 NR~T 505.2500 GR -999,2500 IL,~ -999,2500 GR -999,2500 NCNb -999.2500 GR 44.8242 NRAT 419,0000 GR -999.2500 -99~,2500 '",4707 59,6563 '999 250 -999 2500 999 250¢ -999 2500 3 4004 49 3438 '999,2500 '999,2500 '999,2500 '9'99,2500 3'5781. 63'1562 -999 250O -999 25OO -999 2500 -999 2500 3 5332 59 1,250 i999'i~00 999, O0 999. 00 -999,2500 3,5527 59,8125 999,2500 :999.2500 '999.2500 '999,2500 3,787~ 52.96~7 -999.2500 -999 2500 -999:2500 -999.2500 3.2793 63,6250 '999,2500 '999.2500 :999,2500 999,2500 3.8613 47.9375 !; P T 7800 ~ -999 :~HI -999 -999 00 o u ,.% F l., ~t - 999 2500 GR -999 2500 0 R F~ [1 - 999 2500 PEF 999 2500 ~NRA ~999 6934 MCN 1., 1. 538 5 PT 7 1 t 0,0000 S F I:,, 0 - 999 :~ - q 99 ~ 2 S 00 G :~ - 999 :~ H I -999,2500 [) ~ H 0 - 999.. []NI: .... -999,2500 PEF -999 RAT -999,2500 aNaA -999 x~aA 4~()~9~ NCN~, 1572 2500 I b D 2500 2500 2500 CaLl 2500 NPhI 0000 FCNI., Fl P T 7 ~ 00 P -999 ~'HI: -999 CN I.., -999 RAT -999 N R A 4 ,0000 SFI.,U 2500 GR 2500 DRH~'} 25O0 PEF 2]4.4 NCNL -999,~500 -999, 500 DT ' 9 q 9 , 2 tS 00 R t"t 0 B '999,2500 CAbI '" 999,250 (') N P H I 1554,0000 F'CNb -uq9 2500 ILD 999,2500 R H O ~:~ . '990.,2500 CAbI 999,2500 NPHI . 1537,0000 F'C N I., P 999,5 (r) 0 GR Pt!I -999,2bO0 DRHO CNL -999,2500 PEF RAT -999.2500 RNRA NRA 4,2~5'2 NCNb - 999,250 C) I -999,2500 DT -999,2500 999,2,500 C~[,I :999,2500 [)PHI 1572,0000 EPT 7300,0000 SFI..Ij P -999,2500 GR PHI -999,2500 ORhO CN[, -999.2500 PEF RAT -999.2500 RNRA N R A 4,093 8 a C N 1'.; -999,2500 .IDD -999,2500 DT -999,2500 ~,HOB -999,2500 CALl 999. 250() NPHI 502,0000 FCNL EPT 7200,0000 P 999 2500 GR PHI -'999:2500 DRH[, CNL 999,2500 P ~,':F RAT ~999.2500 NRA 3,2891. NCNI., -999,2500 Il.,{) -999,2500 DT -999.2500 RHUB -999,2500 -99g,2500 NPHI 1429.0000 FCN[, EPI 7100 P -999 PHI -999 C~I., -999 RAT -999 ,00 00 S F L U · 25OO Gk ,2500 O R H Ii ,2500 PEP' ,2500 RNRA -q99,2500 IDD -999,2500 D'F -999,2500 RHOB -999,2500 CALl -999,2500 ~PMI -999,2500 '999,2500 -999,2500 NCNb '999,2500 GR 36.8164 NRAT 416.2500 '999 2500 li~ -999:2500 GR -999,2500 NCNL -999,250() GR 43.7988 NRAT 384,2500 GR -999,250() :tL~t '999.2500 GR -9q9,2500 NCN[, -999,2500 GR 47.9004 NRAT 366.7500 GR '999,2500 lhM '999,2500 GR -999,2500 NCNL, -%;99. 2500 GR 45,1172 ~RA,I~ 384.2500 GR -999,2500 IbM -999,2500 (iR -999,2500 NCNb -999,2500 GR 45.0684 NRAT 366.7500 GR -999,2500 IbM -999,2500 GR -999,2500 NCNb -999.2500 GR 37.4023 NRAT 366.7500 GR -999,2500 IL~ -999.2500 GR -999'2500 NCNb -999,2500 GR 28,2227 NRAT 434.2500 GA -999,2500 -999,2500 GR -999,2500 NCNb -999,2500 GR 50.5371 NRAT -999,2500 -999,~500 -999~2500 -999,2500 3,4219 45.1250 -999,2500 -999,25OO -999,2500 -999,2500 3,8047 87.5625 -999.2500 -999,2500 -999,2500 -999.2500 4,0313 ob.8125 -999.2500 -999 2500 -999 2500 -999 25O0 3 8770 56 0625 -999 2500 -999 2500 -999 2500 -999 2500 3 8770 55.6563 '999,2500 -999,2500 99.2500 3.4551 4~,0938 -999,2500 '999,2500 -999,2500 -q99,2500 2,9531 4~.8750 -999.2500 -999,2500 -999.2500 -999,2500 4.1719 ~P 010~H02 YERIFriC~T%[~~ LISTING P~gE B ~{~ R A 4 , 62 B 9 N C N L !t) U999 999 2NB -'999 RAT -999 ~RA 4 EPT 6900 p -999 PHI -999 CNL, -999 RAT -c)99 NRA 4, 0000 SIFI,,O 250O (IR 2500 P E: F 25O0 R ~'~ I~ A 0391 NCN[., 0000 $ F L U 2500 G R 2500 2500 PkF 2500 RNRA 4~1~ E; P T 6 I~ 0 0,0 () 0 0 S ~' [, lj P '999,2500 GR PHI '999.2500 DRB(.t CN[~ '"999,2500 PEF R h T - 999,2500 R ~ R A NRA 4,3008 NCNL E P T 6 '700 P -999 PHI -999 C., L 999 RAT -999 NRA 4 EPT 6600 P -999 PHi -999 CNL -999 F~AT -999 NRA 5 EPT 6500 P -999 PHI -999 Chi., -999 RAT -999 NRA 3 EPT' 6400 P =999 PHI -999 CNL -999 RAT -999 NRA 4 ,0000 SFLU ,2500 2500 D R ~{ ti 250O PE~' 2500 RNRA 53 ,1 3 N C', [',i 0000 S FI. 2500 2500 2500 2500 ~ N R A 132B NCNb 0000 SF'l,;tl .2500 GR .2500 DRMO 2500 PEF 2500 RNRA 42 19 NCNJ] ,0000 SFI..U .2500 GR .2500 .2500 ,3 '1 B 9 N C N h EPT 6300,0000 SFLU P -999.2500 G~ PHI -999,2500 DRbt~ 1592,0000 FCNL -999,2500 II.,D -999,2~500 DT -999,..500 -999 2500 CALl '999:2500 NPH1 162 ). 000() FCNL -999,250{. ILO -999,2500 DT -999,2500 NPH:I 1447,0000 F CN 99~.2500 ILl) -99 ,2500 DT -999. 2500 RHDB -999, ~50(} CA, LI -99~.25oo NPH] 1556.0000 FCNL -999.2500 ILD -999.250u DT -999,2500 RHOB -999,25{)0 CA[,I '999,.2~00 NPHI 1233,0000 FCNI, '999.2500 ILD :~99,2500 DT 99,2500 RHOB -999,2500 CALl -999,2500 NPHI. 1393,0000 FCNI., -999.2500 IhD -999.2500 DT -999 2500 RHOB -999:2500 CAI..,I -999,2500 15S4,0000 -999,2500 ILD -999,2500 DT -999.2500 R}lOb -999.2500 CALl -999.2500 NPHI 16~1,0000 FCNI~ -999,2500 ILD -999.2500 [;'iF -999,2500 ~MO}J. 343,7500 (;R -999,2500 ILW~ "999,2500 GR '999,2500 NCNL -999,2500 GR 38,671 Y NRAT 4 o 0,75 O0 G R -999,2500 IbM '999,2500 GR -999;2500 NC'hi,,,, '999.2500 GR 47,4609 NRAT 325.7500 GR :999,2500 IbM 999,2500 GR -999,2500 NCNL '999,25{0 GR 43.5547 N'RAT 361.7500 GR 2 '999, 500 -999'2500 GR -999,2500 NCNb -999.2500 GR 44,6289 N~AT 272.0000 GR -999.2500 ILS -999,2500 GR -999,2500 NCNL -999.2500 GR 52,636'7 N~AT 271,2500 GR :999,2500 ibm 999.250O GR -999,2500 NCNL -999,2500 GR 33,2520 NRAT 454,0000 GR -999,2500 II.,M -999,2500 GR -999,2500 NCNL '999,2500 GR 39.257~ NRAT 379.0000 GR -999 2500 iLM -999:2500 GR -999.2500 NCNb 42,1,562' -999 2500 -999 2500 -999 250.0 -999 2500 3 5234 45 9062 '999.2500 '999'2500 -999,2500 -999,2500 62,468~ '999,2500 '~ 2500 -999,2500 3,7930 43,6~75 -999,2500 -999.2500 : 9 . soo 999,2500 3,B51~ 46.2813 -999.2500 -999 2500 -999 2500 -999 250O ~'1 9375 '999,2500 -999.250O -999,2500 -999,2500 3.2266 42.6875 -999,2500 -999 2500 -999:250o -999,2500 3.5586 38.1250 -999,2500 -999,2500 -999,2500 IP 010,)402 VERIFI(?ATI('.iiN LISTII~G PAGE 9 2NL -999,2500 PEF .~AT -999,2500 ~{NRA gPT 0200,0000 SFI, U ~ -'999 2500 GR >~41 -999,2500 DRH 7NI,, -999,2500 ~t I -999,2500 RNR~ ~RA zi,0820 NC'NL ~.iPT 6100 P -999 Pal -999 CNL -999 RAT -999 ,,~RA 5 0000 SFLU 2500 G R 2500 DRIdU 2500 PEF 2500 RNRA 71 O 9 N C N i, EPT P~t I RAT NRA 6000,0000 S!fLU '999,2500 GR -999,2500 [) R tiF~ 99,2500 PEIv -.. 99,2500 RN~'~ g, I I 33 N CN b EPT P RAT NRA 9000(300 SFL, U ! 999,2500 (;14 -999,2500 I.)R I40 -9949, 2500 RNR ,1400 EPT P CNL R A T NRA 5gO0,O000 SFI, u -999,2500 (iii -999,2500 -999,2500 PEP -999,2500 R N F,,'. A 4,1016 E PT P PHI CNL RAT NRA 5700,0 U O 0 $ ? I.. 0 -999,2500 Ga -999,25o0 DRH[i -999,2500 PF.F -999,2500 RNRA 4.6445 !qC ~! J, EPT P PHI CNI., RAT NRA 5600, o000 SFI.:U -999,2500 GR -999,2500 [)RHIl~ -999.2500 PEF -999,2500 P. NRA 4.2617 NCNL El PT 5500,0000 SFLU -999,2500 -999,2bO0 1620. 0000 -999,2300 "9~9 2500 -9 9 25o,) -99.9° 2500 - 99 2500 1773 0000 C .a L I NPH I FCNI,~ I 'h D DT R }4 L) k~, CAthI -999,2500 ILD -999,2500 DT '99~,2500 -99 .2500 C~bl -999,2500 .NPHI 1.397,000(~ -999,2500 ILD -999,2500 -999.2500 RHI3B -999,2500 CALI - 999.2,. 500 t~, ti) )'~ I, 1266,0000 FCnL -999 2500 I' I., D , -999,2500 DT 99,2500 !',"Pa I 1411, ()000 FCNb -999,2500 IbD -999,2500 DT -999,2500 RH(J~ -999,2500 C~LI -999,2500 NP~4I 14.29,000C) FCNL -999,2500 ILl;) -999,2500 DT -999,2500 RHOB -999,2500 CaLl -9~9,2500 I~PNI 1521.0000 ~'CNI, -999,2500 ILl) -999,2500 GR 3~,8672 418,2500 GR -999,2500 Il, bi '999,2500 GR -999' 500 NCNL -999,250~ 43 701 ' , N R A 1 434,2500 GR -999,2500 IbM -999.2500 GR -999,2500 NCNb 'q99.2500 G~ 50,4395 NRAT 244,5000 GR -999,2500 Ib~ '999,2500 (JR, -999,2500 NCNb '999,2500 GR 53.0273 NRAT 307,5000 GR '999,2500 Ii,.,~ -999,2500 GR -999,2500 NCNL '999,2500 GR 43,6523 NRA. T 380,0000 GR -999.2500 -999,2500 GR -999, ~500 .4CNL -999,2500 GR 46,1914 NR. AT 343,7500 -999,2500 I!,,~ -999,2500 Ga '999,2500 NCNb '999,2500 {;R 50,0488 NRAT 307,5000 Ga -999.2500 Ik,~ -999,2500 GR '999,2500 NCNb '999,2500 GR ' 49,9512 NRAT 356,7500 GR -999.2500 Ibm -999,2500 ~,5352 2'3,5156 2999,2500 999,250O -999 25(10 -999 2500 3 8008 20 21~7 -999,2500 -999.2500 -999,2500 -999,2500 4,1680 50,6250 -999,2500 -999,2500 -999,250O -999,2500 4,3125 49,1250 -999,~500 -999, 500 Z999,~5oo 999.2500 3,7969 44,8125 '999,2500 '999,2500 '999,2500 '999,2500 3,9375 34,4063 '999,2500 '999,2500 '999,2500 '999.2500 4,1484 39,2813 -999,2500 :999 2500 999:2500 '999,2500 4,~445 43,7188 '999,2500 ~'P OIO.H02 VER1F'IC'ATICN LISTING PAGE 10 :' -999.2500 GR DHI -999,2500 DRH!.] ,.". N L -999,2500 PEF RAT -999.2500 P, NRA VR~ 4.0000 NC~[. 5400 -999 -999 -999 -999 5 0000 S F b U 2500 GR 2500 D R ii [t 2500 PEF 2500 RNRA 3555 NCNI., ~:PT 530O ~ -999 ?HI: -999 :~L -999 RAT -~99 ~RA 4 PHI. RAT NRA 5200 0000 -999:2500 GR - 999,250 -999. 2500 P~F -999,2500 RNI{A 4.'7~95 NCNL E P 'ID P PHI CNI., RAT NRA 5100 -999 -999 -999 -999 4 0000 SFbU 2500 GR 2500 DR}!O 2500 PEI,' 2500 PNRA 5313 NCNI, P PHI CNL RAT EPT P PHI C N 1, RAT 4900 . 0000 -999 2500 -999:2500 ORb('] -999.2500 PEF -999,2500 RNRA 4.0000 EPT P P}i I CNL RAT 4800,0000 SFLU -999,2500 GR -999,25()0 I)RSU -999,2500 PEF -999.2500 RNRA 5,1B75 NCN I., -999,2500 - 9 99,, ,2500 '999. 2500 '999,2500 1, 447. 0000 -999, ~500 -999,2500 -999. 2500 -999,2500 -9q9,2500 1.408, ()000 -999,250(O) -999,250 -~99,2500 -999 . 2500 -999,2500 1342,000() -999,2500 -999,2500 '999. 2500 '999,2500 -999.2500 1262,0000 -999,250o '999,2500 -999,25(. 0 -999,2500 -999,2500 1.216.00()0 -999,250(]) 999,2500 '-999,2500 -999,2500 -999,2500 1 39 2,0 0 0 0 -999,2500 -999,2500 -9q9,2500 -999,2500 -999,2500 1280,0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1502,000U DT RHO8 CALl NPH1 FCNL I L D DT R H O B CALI FC N I,., I L D D T RHOB (TALl N P H I FCNL ILD DT RHOH CAGI SPHI FCNb I LD DT £lbI NPHI FCNI,, ILD DT CALl: N P H I FCNI., I LD D T RHOB CALl: NPH I VCNL I I.,D R H 0 B CaLl i~,; P H I FCNL -999 2500 '999 2500 -999 2500 41 5039 361 7500 -999 2500 -999 2500 -999 2500 -999 2500 50 0000 262 7500 GR NCN5 GR NRAT GR I [.,, M GR NCNb GR NRAT GR '999,2500 '999,2500 GR -999 2500 -999.2500 GR 42,1875 NRAT 308.2500 -999.2500 I[.,~ -999,2500 GR -999.2500 NCNL -999.2500 GR 5~,398,4 NEAT 264,5000 GR '999,2500 IbM '999,2500 GR "999,2500 NCNL '999.2500 GR. 47,656.3 NRAT 2~1.5000 GR -999,2500 I[,~ -999,2500 GR -999.2500 NCNL -999.2500 GR 55.0293 NRAT 301.0000 GR -999,2500 -999,2500 GR -999,2500 NCNL -999,2500 GR 44,6777 NRAT 320.0000 GR -999.2500 ILN :999 2500 GR 999:2500 I~CNL -999.2500 GR 60.0098 NRA'[ 289,5()00 GR '999,2500 '999,~500 '999, 500 3~,6797 ,0313 -999 2500 -999 2500 -999 ~500 4 445 39,5625 -999,2500 -999,2500 :999,25(0 999.2500 3,7188 34,4375 -999 2500 -999 2500 -999 2500 -999 2500 4 b055 51 4688 -999,2500 -999,2500 -999 2500 -999,2500 4,0156 37,1875 -999 2500 -999i2500 -999 2500 -999,2500 4.4219 24,1875 i999,2500 999,2500 999,2500 999.2500 3,8555 27,8905 -999,2500 -999,2500 -999,2500 '999,2500 4.6953 43.3750 IP OlO,H02 VERIFIC~TIO~ L.ISTiN(; PAGE. ,".'PT 4.700 ~' -999 ? H I - q 99 ]NL -999 {AT -999 '~[{ A 4 {': P T 4 60 () ~ -999 ~MI, -999 ZNL -999 tAT -999 ~RA 4 LPT 4500 · ~ -999 ~HI -999 ]NL -999 ~AT -999 ~RA 4 4400 -999 -999 -999 -999 ,0000 SFI,li -999,25o0 ,25(]10 GR -999,2500 , ~5()0 DRH[] -999. 2500 .2500 PF, F -999. ~500 ,2500 RN~4 -999,2500 .g297 NCNL I ~92,00()0 ,00()() SFI.t; -999 ,250(} GR -999 · 2500 PE':F -999 ,25 o 0 R ~ R A - 999 ,2930 NCNL I 3~1, 0000 SFL[J -999 2500 C; ~ - 999 2500 DRBf] -999 2500 PF]F -999 2500 RNR~ -999 3125 ~'~ C ~ I,., 15 ¢3 · 0000 S F l.., U -999 .2500 (IR -999 ,25()0 ORHO -999 ,25()0 PEF -999 ,2500 RNRA -999 , ~750 NCNL 1468 {PT ~300,0000 SFLU -999 ~ '999,2500 GR -999 ?HI -999,2500 DRHO -999 .~NL -999,2500 P.t{;F -999 RAT -999 2500 RNRA -999 ~RA 412617 NC]r,~ i., 1521 ~: P T 4200.0000 S F I., U - 999 ~ -999 2500 GR -999 PHI -999:2500 DRHO -999 =NL -999,2500 PEF -999 ~AT '999.2500 RP~RA -999 qRA 4,21()9 NCNb 1451 ~PT 4100,0000 SF[..U -999 ~ '999.2500 GR -999 ~HI -999,~500 DRHO -999 :~b -999.2500 PLF -999 RAT -999,2500 ~NRA -999 NRA 4,~500 NC~.} b 1600 EPT 4000. 0000 SF'I, U -999 P -999.2500 Ga -999 PHI -999. 2500 DH~O '999 :NI., -q99. 2500 PE:F -999 2500 250o 2500 2500 0000 00"~ O0 2500 2500 ,2500 0000 250u 25 o 0 25O 0 2.500 2500 0000 ,2500 , 2500 ,2500 ,2500 2500 ' 0000 ,2500 ,2500 .250O ,2500 , 2500 ,0000 ,2500 ,250 U .2500 .2500 ,2500 · 0000 · 2500 2500 :2500 .250O I L D DT CALl NPH I FC !'~ L I LD D T C A L I F C N L I L D D T RHOB CALl NPHI F C N L I LD DT CALl F C N L I BD D,i. 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I LP D T RHOH Cab] -999. 2500 '999.2500 GR -999,2500 NCNL, -999' 2500 GR 43 '15 N.R A T 4B,, 5 2R2 , 2.00 GR -999.2500 IbM -999,2500 GR '999 , 2500 '999,2500 G.R 46.8 750 ~RAT 307,5000 GR -999 2500 IbM '999' ,2500 GR -9{)9 · 2500 NCNL -~99.2500 GR 43.1641 NRAT 35'7. 5000 GR -999 · 2500 II.,g -999,2509 G~ -999,2500 N NL -999,2500 GR 52. 1973 NRAT 301 , 0000 GR -999,2500 Ib~ -999,2500 GR -999,2500 NCNB -999,2500 GR 4~ 6055 .NRAT 35 : 7500 GR -999,2500 -999.2500 -999,2500 NCN[~ -999,2500 GR 52.0020 NRAT 344,5000 GR -999,2500 lbs -999.2500 GR -999.2500 NCNb -999.2500 GR 46,9235 NRAT 376,2500 GR -999,2500 -999,2~00 GR -999.2500 -999,2500 GR '999,~500 '999. 500 2 '999, 500 '999,2500 4,058~ 45..4375 -9 g, 5oo -999i2500 '999,2500 -999.2500 3,9746 40.50OO -999,2500 -999.2500 -999.2500 '999,2500 3,77~5 32.90 2 -999 250o '2 -999, 500 -999,2500 -999.2500 4.2656 49.6875 -999,2500 -999.2500 -999,2500 -999,2500 3.9043 29,1719 -999.2500 -999 2500 -999:2500 -999.2500 4.2539 59,0938 '999,2500 '999,2500 '999.2500 '999.2500 3.9785 51,7813 -999.2500 -999,2500 -999,2500 -999,2500 ~P 010.H02 VERI'F.[CATiO~,,] !.,,1,,~T[NG PAG~j 12 ~AT -999,2500 RNRA -999 ~iRA q. 05()%~ NCNL I ,2500 .0000 gPT 3900 0000 S F [. 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ANCI] ALASKA INC.,PPUDHOE BIY,DS 01'25,500292087400 1bT $"l, R I'iG DS 01'25 50029208740() ~ R C O A, l.,, A S C,~ N [., l.l b'! g E R (; E }~ 1. 2-APB-94, g4097 ~, REE~ ~72 74.0e 73.0r~ ~., 4 () . v 0 PAGE: IS Tare Vet c h 1 t.~ tab e r 9e r ifJcat!on Lis't J., ng A],,as~:a Comp~,~tt, n~ Center 10007, 1 O006. 99~6, 9'~43, 9942 o 994 ~, 9921, 9926. 98~6, 9~61,0 9~24,0 9814.,5 9~U3,0 9776,0 9775,~ 974:~. 5 97 39,5 972fl,5 9710,5 9713,5 9695,5 9676,0 9645.0 9630.0 9603,0 10 n , 0 0 0 0 5 0 5 5 0 .... -.-..-~,~,!I ]',',VjtLEIv, T I~r',~S'b~JjFTF. I,:~ D'EPTi4 .... 6,5 10004,5 9945,0 9942,5 9.040,0 9025,0 9917,5 9~90,5 9~8.4.5 9~2~,0 9~02.0 979 ~., 0 9775,0 9738 9727 9716 969~ 9.&87 9.~74 9646 .5 ,0 '100 U 5,0 904n . 0 9925.0 .O .0 .0 9~37,5 960~.0 9601,0 98 O?. 0 9 775. r) 9741.n 972! ,o 9716,0 9710,5 9692, O 965g,0 964. 2.0 97.0 .'Ii'ti[-.'.. DEPTH CORPtECTI()f'~S (.;PC.'-~ Tf.j ('!PF.;f',~ HOLF; (.;P GP. AIL ~"~'l'itEk CfIRVES; $ S ,5i,4D c'ASED HOI,E {,;Pi4I TO OPEN HOLE b~EPt CARrieD ~,~'.!U Wt.tF NPHI SqlFTS, P A G E: verification :hlurab. erqer Alaska ComputlnO Center 18,-APR-1.994 t. 8:J4 PAGE~ SFRVICE : FL!C ~IX REC SIZE i !024 LAST shifted and clipped curves :for each Pass i~ separate files, E.R: 1 R F ~ E'N T: 0,5000 rot)l.., CODE aTla~ DLP ~ STOP DEPTH 1 ,0 96 i 0030.0 9600.0 DgP 1.' 4 ) NE CI~RVE FOt~.: SHIFTS ~i~i~i ..... ' '~ " PASEI',INE DEPTH ~ii~l~ii~Ii~I '!'9 ~.SS SHIFTS ~;PFi APPLIEI.,~ TO THIS S ** nA?A ~'r3R."A~ SF'ECIFICATTO,N Rk;CC"~D ** IS Ta~e Verificat,!o:~ Listinq chlu!~berger AlasKa ('i',o~lputinc~ Ceqter 1 a-APR-.19q4 18:J, 4 PAGE: -;------;; c E,. V T C E OAD~P # 480363 a. 8o363 O0 ,~,803~3 00 480363 O0 ~80363 o0 480363 00 4~0363 00 ,t. 80363 O0 a80363 O0 4:80363 ~0 0 6~ 0 G TYPE ChASS MOD NO,lB $,AI',~P EhEM CODE (HEX) 000 O0 0 1 1, 1 4 68 0000000000 000 b,O 0 1 1. 1 4 68 O000oO0000 000 00 0 1 1 1 4 68 0000000000 000 0 ~ (~ 1 .1, 1 4 68 0000000000 000 00 0 1 J,. 1 4 68 0000000000 (:'00 O0 0 1 l 1 4 68 O0O0000000 00o O0 0 1 1, 1 4 68 000000o000 000 O0 0 1 1. ,t 4 68 0000000000 00o O0 o 1 1 1 4 68 0000000000 00 (,', O0 u 1 1 I ~ 68 0000000000 D~p'r. 10(.; t ,',). u NC~'~'r, C~,i vii 2341.7 (;~ Cfi'. C;.;'v,' qou 2 DFP'V. 1 O00 f). 0 Nr,~: 'r. C:,; 'ri_: 3152,2 (;~ C ;"!, C',.~'~ ~ .! 6.7 D E P'". 9900. O h{ C:~ v. C~,: 7't.~ 3532. ~ .9,9 FC ~ u T ~ nC, 39 0 o 25 91 IJ P T L: ~C 40.054. ¢'R/~ "i'. CI~ TD 6.1.99 NRAT.Ci'OTD 394.99~ Ct~q'C. C~TD 2192.330 CFTC.CNTO 1470.000 H I . C~! T,'" 27.031 CF ,a.'r . C.~!'rD 4.677 NRAT.CN?f) ~ 'l' C r,! '" ~ .... ', ti,. ~gq R33 C ~,, TC. Ch~T .D. 2940.620 CwTC.CNTD [:8. C,'q'['P, 1475. 000 ~'1. C ~'~ .q.'r, 25,5+.:, 3 CFAT.CNTD 4.490 NR.AT.CNTD 1': '1:. C "~ '.l" 9 810.O00 CNTC.CNTD 3284.375 CFTC.CNTL) US. Ct',; T D !47! .92~ ~I. Ct~?;D 27 .qg~ C[:aT.CNTD 4.79~ NRAT.CNTI) '<"r. Ct,' T D 690.016 Cr,~:!'C. C~TP 2956.500 CFTC. C',~TO NS. CN TP. 1457.750 6.027 359.428 4.5n4 632.01,0 4.357 737.688 4.464 607.188 [$ Ta~e '~'eri.~(cat,!on Listir~q ~hlt]mherc;er ~i.!aska Comp~]t,!nq Center 18-/~PP-1994 ::[~11,4. NCh(~'rr:,~'r['~ 18B'2 353 FCWT ["~'J?D 236 980 (,f,~'r CNTD . 7~.,, 37,650 ~ff:NS, Ct'?TP' 1, ~90. ()00 4 600 NR/~T.CNTD 32641875 CFTC.CN~D 6 7 0 N P A T. C i(~ T D PAGE: 4.362 724.344 8 000 De~th shifted and cllpr)ed curves for each pass in se~,arate f~les. DEPT ~.i .I ~' C~ E~,~ E]f' T: 0.5 O 00 FTL~ CNW{) ~ 0~30,0 9600,0 Cf{F~VE ~:IF'].' l)~,'],~ - PASS T~ P!~S~(~'.~EASi.iPF_.D DEPTH) .......... Ft)IIIVAI,EN'I ;_lf,lSHIFT'E[) {.,~:PTH .......... IS q'ape Verification Listfnq =hlU~berc~er AlasKa Comp,.lt..in~ Center 0029,1') 1 . 9, , 0017,0 ~O0!6,S 0016,0 10016,0 000:7,0 10007,0 997 3,5 9973,5 9947.0 9046.5 0 9936 5 q 037,., , , 9901,0 9900.5 9~65,0 986A. 5 9961 ,5 9~61 .0 98~.4,0 9~24,0 9Blg,P 981~.5 9~OQ. 5 9809. (') 980~. O 980~, ~ 9760.0 9759,5 9746.0 9745,5 972~.0 972~.0 9718.5 9718.~ 9704.0 9704,0 9697.5 9697.0 969~, 0 969~. ~ 9676.5 9678.0 9675,~ 9675,0 9645, 9645,0 9611,5 961!.0 960~,5 9&O~, 5 1.00,0 10{~'. 0 I 0.. o. 0 'i~.I$ F][i~',E CO~g~,'A!~,~$ ~'}!w SECO~.ID OF' THREE PASSES OF THE C~.!TB. THE OMP'?g CORPECTIOb;S SHOB~N .AB[IrE ~MFbECT PASS Gr~C~ wi] PASS 1 C~.(?}.i A~D PASB 2 t,,~pHI TO P~S8 I NP}.{I, (}m~,~F[,: C~3TD CUPVES i~FRF CA[~RIED WITH T~E NPl{I SHIFTS. ALL PAGE: ** DATA ** S!'2T mY~i - t, 4EB ** ! 66 0 2 6~ e 3 73 40 4 6 6 i[8 Ta~e V.~z'l~.!cation l.:.istlno :hlumberqer... .. AlasKa ~omput.ino. . C. enter., PAGE: fi 73 7 65 9 65 1,2 68 la 65 15 66 1,6 66 0 66 O, 5 F T P! I?ILE U~XB NUN~B [)D ~%!' [J ~ B SANP ELE~ CODE (HEX) ~ 1 I 4 6~ O000000000 2 1 1 4 68 0000000000 2 1 1 4 62 0000000000 2 i 1 4 68 0000000000 2 1 1 4 68 0000000000 2 1 1 4 68 O00OO00000 2 1 1 4 68 0000000000 2 1 1, 4 6~ 0000000000 2 DFFT. 1000(;, 0fi0 NCr'!~'. . C'!,.,T[, 9897,566. GPC".. C r,.~m9 ~9. 397 DWPT, Ogou, NCN'r. CNTO 3375. 250 G~CW.CN~'[.~ ~o, 359 N C ~,"~, C {'~'.r D 29 35,500 GPCP · C},~mi) 1 5.4~0 r.,l p 14. I. CNI'D 'tENS. l'ipH I · ? C ~': T. C"!T TEN,S,. ~',! P F' !. C N T P FC~,'T. CNTD mE'~!S. CN ID N P [41. C '~! T r~ TENS. CNTD 29.758 CRAT,CNTD 5.015 NRA'r,CNTO 643,267 C[,3TC. CNTD 2671.710 CF]/C.CNTD 1560,000 26. 355 CRn:r. C.UTD 4.592 NRAT.CNTD 792,1b~, Ct,.~ 1'C, C ~TD 31bl.250 CFTC,CNTD 1514.219 29.297 CRA'I~.C~TD 4,958 NRAT.CmTD 65~.8~Q ChTG,C!fT9 2~04.313 CFTC,CbmL) 1492.750 5,7n3 362,o52 4,423 539.648 4.326 696,969 4,660 560.313 IS Tape ver.~..fJ..cation ListIn. cl cblu{tlberge'r Alaska Computln~ Cer~ter l~-APP-!994 lB:J4 9700 000 NPHI ,~, .... c'~,'r r) 24.19 l, eR. AT. CNTD 3237 1,~5 ?'CN r, C~TD 809,500 ,. r '~ C~,~'rn 1~82 375 ' . , ,.. ' ' ...... '',.' r , ':~T" CNTD NCN~,C~',:,~i) 17~9.2~9 ~CNT-CN' ~ 222 ~22 C~ C. G~C~I ,CN?D ..... 41 .094, T E M 5 ' ~; k~ "1-D, ..,,. ,,,. 1440 .000 4 ,313 N R A T . C f'~T l) 3006: 000 C F T C , C bi ? 7,732 NRAToCNTD 168~,355 CFTC,CNTD PAGE: 4,047 709,734 8.000 210,402 **** F'!'LF ~"R,~, i LER **** FTLF NA~4E : EDIT .002 SERVICE : FLTC VFRSIOf : O0~.COl DAT~ : 04t04/~,8 LAST' F I !,,,E : S~RVIC~; : FLIC I') ~ T F r,~X ~,~'~C SIZE : !074 FILF TYPE L,~ST FILE De~th 5hl. fte~] arid clJ. pped curves for each pass in separate fi:Les. t [,k'G TOO[, Ct;P[': START gkj~kN S!.OP [)FPTH p,_[~ . ,,. 960 CNTD 10r)3O. 0 9600, ~ C~RVE SWIFT [~A'f~ - PaSS Tn PASS(?~:ASUPE,P D~:OT~) ~.ASET..L~,~K ('ITk~,~' FCR ~ ,. ~ - bn~.~,~ CLJPVF: C(:iD~]: P~SS ~.~tJv t~Fk: t .......... F~)T.~IVAT,f'.N~' I..~;5~IFTF[.~ DEPTH .......... IS Tame 'VeriflcstIon l,isti, nq .-blumberoer A].aska Comp,it.lng Center lg-A.P~-I. 994 lg:l ,4. PAGE: 0030.0 0017,~ 0016.0 t 0016.o 9~72.5 9947.0 9946.5 9037,0 90t0.0 991P.5 9897.0 '9~65.0 9~24.0 9~2,4.0 9~1,~,5 9'~10,0 9 ~ 03 ' 9791..0 9775.5 9761'5 9760.5 9760.5 971~,~ 971~,0 97 03, 9704. O 96..°..7.0 9695,5 9695.5 9680,0 9660.5 967~. 0 9676.0 9670,5 9~67.5 9667.5 9659,0 9644.5 96'30.~ 9&3~.~ 960q. ~ 96(')~. 5 960~. 0 1 O0,0 ~ 00.5 PEMARK~; ~. 0032,0 ! 0016,5 ! 0007,0 10O00.5 9972,0 9936,5 9~96.5 9864,5 g f? 0 o 0 '176,0 9697,0 967~.,0 96~9,0 9645,0 960~. 5 100,5 C'.'T~. I'~tE BE:PTa Cr~kpH',CTIUr,~$ 5MUWN ABOVE REFLECT P~S8 GPCn TU P~8S ~ ORCi-i Af',iL) P~SS ~ NP~I ~"0 PASS 1 NPMI'. U'P~WR CHTD CL]P'VF'S V,'E~{~ CAPi(IE:D WI~H TH[,i ~',PHT SHIFTS. 3 ALL iS Tare 'qer.i~i, catio~ [.,istln~ =hlumber~er ~l. as~a Comput:.~nq Center NPHI C~',',i"'O PU-S 48o363 NRA'~ CN~t) 480363 NCN~ C~4'rD CPS 480363 FCNT CNTD CPS ,!b0363 C ~ 1"C Ci~ ¢1.3 CPS ash363 CFTC C,~ ~ [') CD6 ~8o363 G~Cu C~"rD G.~F/ ~0363 TFbS C:,:TD LF, 480363 . APl' AP PILE N' NUKB 8 B: REP}{ pROCESS E C}'...,A~$ ~,C;D NUMB Sg.FP EbElq C[]DE (HEX) ................ . .................. ...... .... O0 0 3 1 1, 4 ~ 0 0 00000c, 0 (,) 000 00 0 3 1 1 4 68 0 O 0000000 e O0 000 00 0 3 1 1 4 6~ 0000000000 r) () 0 0 9 0 0 0 3 1 1 4 6 8 0 0 0 0 0 0 0 0 0 0 O0 000 OO 0 3 1 1 4 6~ OOOO000000 O0 000 cO 0 ! I 1 4 68 0000000000 O0 OOO O0 o ~ 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 6~ 0000000000 nO ()00 O0 0 3 1 1 4 6~ 0000000000 OO OOC O0 0 3 I 1 4 68 OOt~O000000 b ~' P T. 10 (30 £.':. U r) () t,JCNT. C,~q'f') 77 ~ %. 43[; GPC~, C!,;Tt.) 94.60 l FC"'T C~7.'D 580 ~7~ CI','TC C~IT T ~',~.~ ~. C~' 'I'D 1523. R 52 }4 P A T. C,~,, TD CFTC.CN?O N ,D A"P. C N T [? CVTC.CNTD 5.660 352.009 4.985 527.605 1 g-,APR-1994 1.8:],4 25. 677 CRAT, CNTD 4,505 794.375 C ~...~ T(.'] , C t! T D 31ql.500 I496,563 29.~11 Ct? ~T, Cf,~TD 4,960 4 i':~ 7. 703 25.569 I. C~!:TD 4 49 , ~ To' CNT 775,500 C,~ ..... , D 3050~500 1470,781 50.~,58 CRhT.C~TD 7.342 ~3.~,58 C~,~?C , CU'I'D 1699.320 475 . 000 PAGE: 11 ,l'l R A T. C N T D 4.223 C~'TC.C!qTD 701.469 k;iP AT. Ct~'q!D 4: o 709 CFTC. Ci~TD 567. 969 NR,AT.CN'TD 4. 321 CFTC, CNT[) 696. 063 NRAT.CNTD 6,733 c~*mr' C~'D 222.153 * * * * F t L, E "r R ~, i[ !, E t:,', , * SE~.v ICE : ~L'!C V ~R, 810l',,,~ : D a'l:'~ : 94104/t M~X RFC 81ZE ~ 1024 FIL~ TtPE : L9 8 F ~ tt I C, t:;.i : F 1,..~ T C V!+.'RSiOi'.~ : O0:ICO1 ~4~X ~'~ ~C sI'gr~ ". ! O2,rt I., t~ 8 T F'I !,hi AY E P a C,,t... D CUP V F,5 ¢owp~nsate~ ."':eu tro n: Pulsed Of edited static pasgEs T;',IC!,,~DF~i,> lin ¢}~? ._ Arithmetic average of edited ~asses for all. curves. Pass 1 gamma Ray and backround counts; ior all Other cnrves. f)naveraqed edited baseline passes O, !, ?, 3, ari, thmetic average iS ? ~ ~ ,,:. er c on 0 ;h.lU.mherger ,a]asks Co~putJ..ns. Center !9- &P]:~- 199,4 ,1.,8:],4 PA~E: PE~,'~ARi<$: T}~i~. t:i.[.,f;i; COi',,i~.~Ib. tS THE ~RTI'H~,~ETIC A. VE~AGE OF THREE C~;'!'P PASSES, AbL DEPT~ C[!P~','~CTiDNS WERE; APPt.,I~D BEFORE ** 8E:T T'YP~'] - CUAN ** DFpq' ?w 480363 O0 000 O0 n 4 1 1 4 68 N~HT Cr;?,,V PI~-$ ,~.~n363 00 000 O0 e 4. 1, I 4 68 CP.~T C i',~ .~, V ~80363 O0 OOO O0 O 4 I ,1 4 69 N ~ A ~ C ~T,i ~ v ~ ~ 0 3 6 3 o ~} t.; 0 {.~ 0 0 O 4 ! 1 4 6 8 NCN ~ C~fiV C~8 41s0363 O0 000 O0 r~ .~ 1 I 4 6~ FC[,;~ C?,:g V CPS ~,80363 O0 OOO CC, (~ 4 I I 4 ~8 CNTC Ci,~ a V CPS ~8{7363 O0 000 O0 e 4 I I 4 6~ CFTc. C~. A'V C~S ~8o363 nO ()0o 90 0 4 1 1 4 68 G~C~ C!,~,~,V G~P! 480363 r')O ()O[, O0 o 4 1 1 4 68 T F N ,~ C ,i ~ ~ 6 ~'~ a. F: n 363 00 u 00 0 t, 0 4, 1 1 4 o ~ 0000000000 O0000000OO O000OO0000 OOOO000000 OOOOOOOOOO O0~O00000O 0000000000 00000o0000 0000000000 ,IS ~'ane V~tif~.cat.!.on bistinn ;chlumherc, er Alaska Cor, outin~ Center 18-hFP-! 994 18114 GPC,q . ('!~,~ ~V .35 7. NC?4m . ('[,; A~/ 79~ 4.7 F, 7 FCMT. CNAv GPCt~. C~ ~ V ? 3. b 38 YEr,'S. C~;AV DFPT. 99(~{; . 000 t.~PPl. C".!AV ~ C i'~ q_'. C;., ?x V 34, ? O. 1 ~ ~-~ ~CI',7 T. Ct',, AV G~Ct'~ . C[,. h'V ?C. 0?4 T E.~' ~. C'.~ AV D~:PT. t~8 n 0. t, C., ~.~ ~,l p I41. C ~q AV 337..~.5~B FC~'.IT. C~, AY .867 ** g!q!.) OF .hATh,, 30.32P CRhT 400.676 Ci, iTC:C~'AV 29.01n 6~.1 .?59 CkTC. C~,~A¥ 6.11.9 218R.061 4.~2~ 274~.~35 25.~bl CF{ ~. T. C~,~AV A.528 799.774 CNTC.CNAV 31.95.389 149~.0~5 2R.mb6 CRAT.C~4AV 4.905 653.5~ Cb~,TC.C~,AV 2873.~75 1479.953 25.391 CRAT. C~,!Aw 4.468 790.020 CNTC.C:~AV 31.06.814 14b,:~. 78 !. 5~,24P CEAT.C~AV 7.581 740.7~3 CNTC.C~AV 1718.97~ 1434,.856 CFTC i~RAT. Ci'4AV C~'TC. C,; z~ ¥ {'~ R A T. CNAV CFTC. C N ~ V CFTC.CNA'~ i~ R A T. C ~ A 'v CFTC.CNAV 5.823 357,794 4.637 566,395 4.302 711.970 4.611 578.4~2 4.243 709.976 7.577 219.799 **** F~iLM TRA I..I,ER **** FT[,E ~,!A,~E .,' EDI'.[: .004 VFRSION : CO1CO1 ~,X aEC SIZE : 1024 L~S~ W,I !,,E **** FILE ~,~EAOEa **** F,,TL~' NA~;?.'g : E[>.TT ,005 6ERViCE ; DAT? : 0.410,41!8 LAST FiLE : IS Tape Yeriffcat, io~ l,ist~n~ Chlum%erqor Al. asKs ComPtlt!.t~ Center PAGE: 14 Curves and loc,' neaO,,er data fnr each pass i,n separate DATE ~.! ~E '2 DP !LL~R · [: LnGGEP nEPT~ TOt]f, STPlNG (~:np TO LOGGERS C'..nSING DE'PTt. I (FT): FLOID SURFACE TE~,~PERATURE (DEGF]: ~.{%F]TTO~ HOI...E TEMPERATURE (DEGF): FLUID 8AbTN.'fTY (PP?4): FLUID LEVE~. (FT): FI,[.JID RATF ~,T U~ELI,.,HEhD t,iA';['ER CUTS CPCT): GAS![)IL RaT]:O: flies; raw bacKnrounO pass in last fi 38.2 16~6 :10032. o 1003~ .0 9~00.0 ~0030.0 12oO.u SEAW~.TER T }'.I E R t~, A L PATE NOR~'~A.,!,IgATION IN OIL gONE ZING W!?,iP[']',w (F~): IS 'ra~e Verlticatien l, istino chlumberqer A~aSKa COmPuti~& CenEer 12-APR-1994 18:14 ~.:~LI, SiI!!T 1.~ n.~l) FblJSHED WITH 2~7 R~I,~S O[;' S~AWATE~ (60 BIlL :,'.[::.!'HA~.',OL) C~F ()N l'[,.lp aF SEAWATkR. THREE PISSES LOGGED AT 90() F"!~/~tk i)VEP ~;'~'I. OE I~']'~kVAL (960~-10030') ONE OF THE PASSES LO(;GEb ar, Fr,~ FLUID P[.l~PED INTO TH~ WELL. WELb i~'AS AFTER ALL FT_,li~O LIS FflRYAT PAGE: 15 . . .... lC., 1: ~'P] AP.I ~P~ ri! E N[~NB ~U~BSIZEREPR~P~DCE:S ID ORDER ~ bOG 'r~p~ C[,~SS NOD N!,I~tB SA~P EI,~M CODE (HEX) ';"' ........ 'FT"""';'"'" ......... '"'"'"'"""""' .... "'"";'"' ........ [; .... "'"' ~cp'r 4~0 63 no 000 O0 0 5 1. 1 68 00000000 NPHT PS) PI) 480363 O0 O00 O0 0 5 1 2[ 4 68 000O000000 RT ~ PS[Ii a80363 O0 000 00 0 5 1 1 4 68 0000000000 T~R~ PS! 480363 O0 000 O0 0 $ i i 4 68 00C, O0OOe00 IS Tame Ver. if~cat.lc:n ch],.umberq~r AlasKa Comp~!t.~[to center 1 ~--~P~.-! 994 18:1.4 PAGE;: 16 KCNT P51 CPS 48n363 ..R CFT ¢51 CPS 4d0.363 00 CNTC ~5~ C'~S ~80363 CFTC PS1 CPS ~80363 G~ mS1 GAF! ~363 C~L PS! V n8~363 O0 mmmmmmmmmmm~mmm~mmmmmmmmmmmmmm m mmm~mmMmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmmmmmmm ~m~m ~ DEPT. 1 D, 0,~2.50i, MPN I. PS RCr.'T. PS1 P277 .L;Ol r~CFT. PS G~. P,S .~ 19.1n9 TE?.~,5. PS P $1 RCFT.PS1 PS1 .... 1. 34.644 RT'}.~k. PA1 5.333 I 426.938 Cr,,7'C. P,q. 1 2134.298 CFT.'C. PS! i 1.045. OC'O CCL.PSI 0.000 1 24.70!, RT~IR.PS1 3.959 Tr,~RA.FS1 ! 795.432 ChTC.PSI 3150.833 CFTC.PS! 1. 1.455.000 COL.PSI 0.000 25.631 RTNR.PS1 4.174 TNRA.P$~ ~40.1,~] CNTC.P$1 3381.634 C~TC.PS1 i,i05.000 CCh. PSI 0.000 25.735 PTNR.PSI 4,.350 TNAA.PSI 772.9~3 CbTC.P$1 31,14.878 CFTC.PS1 1440.000 CCh. PSI 0.000 l~.B60 ~TNR.PSI 3.,4,44 TN~A.PS1. 1. 1,54.32~.. C,NTC.P~I 3651.288 CFTC.P81, 1425.000 CCL,PSI 0,000 51,417 RTNR.PSI 6,94.1 1.'NR ~. PS ~.. 2 , 14 NTC, b9 o C PSI 171 , 04 C,t.C.PS~ . "c PS1 0 1375 OUO ( ........ L. .00n 5 593 381:588 4.379 688.846 4.499 738.242 4.513 684.391 3.599 997,562 7 487 225:309 chlumberqer AlaSP~a Co~"p~:~t,!ne Center PAGE~ ~7 F"TLr' NU~;'BER t5 R~w C~NVE$ Curves and loo header data ~or each ~ass in separate P ~ S ~ N IJ u ~ E R: 2 D F' Pq" H. I ~IC ~ EM lgl'~ '.[': 0,5000 FILl;' V'I~,]I~,I[',FtR ".["rli.')l, C[3F)I:'] STAR'!'~ LnG H~,AD~;R DATA PATE LOGGED: · L) [:,RII'.,L.W. tR (FT'): TI) t,,OGC, E]~ (FT): POTTOi,~, LOG I. NTv'RVAL (FT): L(.)G(:iING SPEED fi,'Ptria): S'iOP DEPTH TO[IT STRIE:~G C?OP TO (; R (,]D[;*N FI[)I,,~ kTT ~'' DRI.bLEPS ChSI.~.~g DEPTH LOGGERS C&SING D~:Pmf~ E; ~ 0 5 E C O ~4 D I m .[ 0 i:':~ S FI,Lt.ID TYP~: FLUID DFt",iSiTY (LB/G): SURFACE TE:F~P[,,';~ATU~E (DE:gF) FbLIIP l,E:i;~;l~ fFT); files; raw baek~rnund pass in last 06-~AR-94 1616 10034.0 96O0°O 10030.0 1200,0 NO 06-~AR-94 T O O L N 1,! N B E IR 9610.0 .:I$ Tane ¥.¢rif~cattot~ .~,istinq i~-AY~-.1994 18:14 ',', .~ 'T r~ i X: S A r,I D S 'i' ~ r., E 2.65 t-< ~.. Ii. E SCALES uATE L~,,' SCALE (CPS): 0 PATE; HIGN .~CA~:F (CPS}: 2250 RATE RI. CH 5CA[.,E (CPS): ]10O0 # T!E;-I,t:: 81;,,!5 BHC 2/21183 W~7[,,,f, Sd(!T I~:~ n,'~'D FLUSHED wITf~ 287 BPLS OF SEAWATER (60 F~ETFA~(~f.,) C.ap ON TOP OF 8FAWATEP, THREE PASSES [,(")GGED AT 900 FT/NR (.JVE:P B~HTiRE; If,~'I'ER~AL (9600-10030,) ONE OF THE E I,,, L W E L b W AFTPR AL.L E:'LUZD PII!¢;DED INTO THE WELL. LiS FOR~AT DATA PAGE: 1¸8 ** C>ATA FOR~4AT SPECIFICATfOt',I REC,~.~PD ** 2 66 0 3 73 44 4 66 1, 5 66 6 73 7 65 8 6B 0,5 9 ~5 PT !1 66 23 I2 68 1.3 66 n ,IS ~'aoe verif,,icati, on t:istina i.a-Ai'~-!gq4 l,a:14 P~GE: 1.9 mmmmmemmmmmmmmmmmemmmmme e 14 65 NPltT PS2 PU ~8~363 RTk!P P52 480363 ACNT DS2 CPS 48n3&3 I,(CF~ PS2 C~S 48n363 CWTC PS2 CPS ~80363 O0 c~'rc ~$~ c~5 ~a9363 00 G~ °52 G.~PI 489363 OO T~r,~ S PS2 LR a~0363 nO mmmmmmm.mmmmmmmmme~mmmemm! , 00 L, 00 COO O0 0 0{"O Oo n 00 0 00 0 () .n 9 00 0 00 (; 00 0 000 O0 0 009 00 00 0 00 0 6 1 ! 4 6g OOCO000000 6 1 I 4 6a O0000nO000 6 1 ! 4 6g 0000000000 6 1 1 4 68 OOOOOOO000 6 1 I 4 6~ 0000000000 ~ 1 I 4 68 0000000000 6 I 1 4 6~ O00OO00000 6 1 1 4 68 0000000000 6 I I 4 69 00()0000000 6 ! 1 4 6~ 0000000000 1 1 8 o 0 0000 DEPT, P$2 10038. 009 RCN~. 7347.9~9 G~.DS2 ~1 ·766> DKpm. RCMT.PS2 3458.970 G~.052 16.609 MPHi. PS2 37,4.4 ~C, PS2 41~ 56 'T'EN$.ps~ 1790 O0 4 RTTR.PS2 5 636 T~3RA. PS2 ~ CN C.,P$2 2200:78!, CWTC.PS? 0 C C !:,, P S 2 0.000 ~'PHI PS2 26·654 .~ur~..P$2 714,367 TE~S,P$2 1,54,0.000 ~,:pHI.PS2 26 456 RCFT. PS2 788: 796 TENS, PS2 1510' OOO NPH I, P$2 26,523 RCFT. PS2 696. 050 TE .~ $. P $ 2 1470.00 0 '~' ' q'l(:0 0o0 I. [~94 . . P~:.., 2 19, . RCN? PS2 ~66fi 667 RCF'I? PS2 104:6 296 GP. ~S~ 32. 938 TEN~:;. PS2 1490. 000 5(>0 IcPHI,~82 4,8 8t~6 330 R, CF~r. $2 259 I 0g 5q4 'rE~,,:',' 'PS2 1365 OOn ~TN,R.P$2 4 051 CNTC.PS2 2896:520 CCh,PS2 0.000 RTNR.PS2 4, 500 TNAA.P52 CNTC.PS2 3231'501 CFTC P82 COb,PS2 0.000 RTNR.PS2 CNTC.PS2 298 . (.)g C C L,, P S 2 0.000 P1*"N,:'R" . P$2 3.504 CI, iTC. PS2 34;52. 402 C C !.,. P $ 2 0.0 0 (} RTNR.PS2 6 786 CNTC,PS7 1707: 384 CCL, ,PS2 0, CFTC.PS2 TNRA.P$2 CFTC.PS2 5.]11 372. 20 4.630 596,591 4,605 707.104 4.~13 635,224 3. 39 920. 834 7 ,'i87 233.499 Tame g~,ri, l.tcatJon LiSt. ir~O .chlum.h. erqer Al. asks Com,p,.~Li. no Centel 1 g-l%P~-I 9Q4 PAGE: 20 **** F J'LFt FILF i~tA~,.,~E' : ~"OIT ,007 SFRV !C~.: : FI.., I C VFRSIC~".~ : aO~COl L.AST VILE FILF RA.~ CURVES Curves and lo0' header data i~l" each pass in separate PAS,~ NUMBER: 3 D F P T H l ~ C R E h~ g ~'~ T: 0.5 0 0 0 F'IL~ VE~.~D['~R T[.)Of, Cl.;DE STAR.~ DEPTH STOP CNTb ~, 0 ~97,0 LOG HEADER DATA hATE LOG~E:D: SOFTWARE VFRSi~h: TD DRILLER (FT); · L) bOGGER (FT): TOP LOG INTEPVAL (FT): POTTOt¥~ LOG INT[;:RVAL (F'P): TOOL STRING (TOP TO V~iNI')OR TOOb Ctf~DE TOUL ~YPE, files; raw backorouod pass in last fi 06- i.') A'R-94 38,2 ~1. 6 ~. 6 10032 ! 0 03 9600.~ ], 200 06-MA.P.-94 TOOL ,I$ Ta~e \~erif. tcation Listi. nq ;ChlUmberq.~r ,~,lask'a PomL~utino Cer. ter PAGE: 21 961~,.0 .TH E R]P,' A b 2.65 !~t.,tlE;f,I~,!E Cf')LJt,.'T .R/!.,!fE SCALES, 8ET BY F'IEbD F'tt',:GI~.IEER FAR Ct'}U~.:T t~ATE l,C~,~ 5.C.A!.E (CPS): (,;, F.AP Ct3~.l~.",;~ RATE HIGH SCALE (CPS): 225C NEAR CmUNT R~TE ~'~I(:i:t S. CALE (CPS): ilO00 TT[E-I~,I: .S~,t$ BI,.!'C 212.1t83 ~t:':LI, SHUT I~' I~!.;D FLUSHED 'WIT}~ 287 BBLS ~,~IFi'i'HJ~,~OL) CAP (}N Trip OF SEAWATER. T~IREE P~SSES LOGGED fiT 900 FT/NR OVEP ENTIPE INT~;RVAL (9600-10030') ONE OF THE . , ......... T ' P~SSES [('idGE[) B~F'C)RE FLUID PI.!'~P~I").1~!~0 ,.HE.. WELL. WE!,.,L WAS AF'.f'~?R .AI, L FI...t. ITO 'P[)'~,~PED INTD THE: WELL. IS Va~e Verification ~,istinq chlu,~erc~r A!asKm CompLltln~' Ce~teI' PA~E: ** nAq'A FOR~-~AT SPF'CTFTCA'~TC,Ih: P,bjCOPD ** $ ~ R v · o ~ P .... T 4.8036 NPHT PS3 pit ~B0363 .00 900 O0 0 7 I 1 4 68 RTNP PS3 ~80363 00 UO0 00 0 7 t 1 4 6B ,r ~ R ~ ~, 5 3 ~, 8 0 3 6 3 0 0 0 0 o 0 o 0 7 1 1 4 6 8 k c N ,' ~ s 3 c p a ,4 6 ~ 3 6 3 0 0 0 0 (,) 0 0 0 7 1 1 4 6 ~ [,~CFT PS3 CP~ A80363 0(,) 0 () (3' 00 0 7 1, I 4 68 C',~ T C Pa3 CPS 480J63 O0 O()O O0 0 7 1 ! 4 68 CW~',c PS3 CPS ,48o363 O0 O00 00 0 7 1, I 4 68 G~ PS3 G~PT 480363 00 00(,) 0O 0 7 1 1, 4 6R TKNS DS3 bB ,..t, 8 n 363 O0 000 O0 0 7 1 1 4 68 CCL PS ~ V a80363 oO [)00 O0 0 7 !, I I ~a 0000000000 0000000000 OOOOOO0O00 0000000000 0000000000 0000000000 O00nO00000 O000OO0000 0000000000 22 6a2.54~ CNTC.PS3 15~0.000 CCh.ps3 5.238 TNR&.P63 2093.526 CFI .... 0.000 4.753 TNRA.PS3 2974 74~ C~'!'C.P53 0:000 5.493 381.104 4.788 61,0,038 ~chlumheroer ~.].ask. a Comp~tinq Cen%er RCN'r. DS 3 34.~ 1. 275 PCW?'. F$3 RC~W. PS 3 '~ 1 ~2.9()b PCW?. D~--'PT. Q7OO.Ot~O ~!PHI.PS3 G~. P53 36. ~ 1 3 W[~a. PS3 DwPT. 9-5 .o6. SO() 5~P~i.PS3 RCNT.PS3 ~ ~e6.077 ~C, FT. P$3 GD.DS~ ~9.,.l:Ob 'P.,'ZN 8. PS 3 1 R-APR-.1994 25.535 .~T~.,R. PS3 4.000 abg.35S ChTC.P$3 3272.690 520. O()n, CCh. P,%3 O.OOC. 26.~5@ RTI,.,~R. PS3 4.525 70c).1il CbmC.PS3 2q91..733 .~ 490.o0r) CCL.PS3 0.O00 20, .~. '1 ~.. RTP, R.P$3 3.752 99! .228 CN'PC. PS3 3480.777 1470.000 CCh.oS3 0.000 55.340 9TNR.PS3 7.071. 245.61.4 C['.iTC. PS 3 1654.934 1460.000 CCL.PS3 0.000 TNRA.PS3 CFTC.PS3 C~TC. ~;S3 TNk[.P53 CFTC.PS3 CFTC.PS3 PAGE: 23 4.4~7 723.826 4.655 644.396 3.776 906,211 7.93b 206.434 **** FiL~ FILF,, ~JA~,'~E : FDIT S~RVICE : FI. lC VERglOi,,, : 001 CO!, D~TE : MIX R~C SlZ~ : 1,0~4 FTb~ T~PE bASra FILE **** T ~ P F..,. TRAILER **** SFRVICE NAFiE ! EDIT TAPE NA~,~E : 94097 pREVlOOS ~ a ~ t:~:', **** R, FE!., TRAILgP **** DATF : 94104/ OPlGIN : F'LIC CONTINUATION :~ : P~EV"t ~US PEEl., : COMfiEST ~ ARCO A[,,ASKA Ii'.iC.,PPUDf'!nE; k!,,A~',DS 01-25 , 500292087400 I~C.,PR[tDHOE BAY,DS 01-25,500292087400
