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183-063
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 07-24 JBR 08/04/2025 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:1 2 3/8" and 3" combo test joint was used for testing. The lower 2 3/8" pipe rams failed the initial low. Functioned the rams and retested for a pass. 8 precharge bottles with an average of 975 psi. Test Results TEST DATA Rig Rep:K. McGrath/N. BlakeOperator:Hilcorp North Slope, LLC Operator Rep:M. Iglanloc/W. Williams Rig Owner/Rig No.:Nabors CDR3AC PTD#:1830630 DATE:7/1/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopGDC250630183318 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 2387 Sundry No: 325-264 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" 5000 P #1 Rams 1 Blind/Shear P #2 Rams 1 2 3/8" Solid P #3 Rams 1 3" Solid P #4 Rams 1 2 3/8" Solid FP #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 2 2 1/16" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA BOP Misc 2 2" Piper P System Pressure P3000 Pressure After Closure P2225 200 PSI Attained P20 Full Pressure Attained P52 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@1850 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer P15 #1 Rams P11 #2 Rams P3 #3 Rams P2 #4 Rams P1 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 10910, 10941 & 11155 11085, 11155 & Unknown (x2) By Grace Christianson at 2:01 pm, Apr 28, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.04.28 11:58:58 - 08'00' Sean McLaughlin (4311) 325-264 A.Dewhurst 13MAY25 10-407 JJL 5/7/25 *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. DSR-4/29/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.15 09:37:27 -08'00'05/15/25 RBDMS JSB 051625 To:Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: April 24, 2025 Re: 07-24 Sundry Request Sundry approval is requested to set a whipstock in the 07-24 wellbore as part of the drilling and completion of the proposed 07-24A CTD lateral. Proposed plan: See 07-24 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock, caliper and MIT. E-line will set a 4-1/2"x7" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window, 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"x7" whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 4 and lands in Zone 2. The lateral will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, 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 May 2025) 1. Slickline : DGLVs, MITs, WS drift, and caliper 7" 2. E-Line : Set 4-1/2" x 7" whipstock @ 10,883' MD (0 deg ROHS) 3. Fullbore : MIT-IA to 2,500 psi 4. Coil : Mill Window (if window not possible, mill with rig) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: x Reference 07-24A Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~457' (14 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~1967' (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: 45.8 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) pyppg(p will completely isolate and abandon the parent Prudhoe Pool perfs Existing open perforations (10,635-10,660' MD and 10,760-10,791' MD) will be incorporated into the redrill wellbore as shown on proposed schematic. -A.Dewhurst 13MAY25 Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : LGLVs, contingent LTP* 3. Service Coil : Post rig RPM and perforate (~30’) Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 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 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:183-063 6.50-029-20945-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11377 10914 8798 10112 , 10271 10914 8142 , 8272 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31 - 110 31 - 110 1490 470 Surface 2499 13-3/8" 30 - 2529 30 - 2502 5380 2670 Intermediate 10559 9-5/8" 27 - 10586 27 - 8523 6870 4760 Production Perforation Depth: Measured depth: 10635 - 11160 feet True vertical depth:8564 - 9006 feet Tubing (size, grade, measured and true vertical depth)25 - 10354 25 - 8340 10112 , 10271 8142 , 8272Packers and SSSV (type, measured and true vertical depth) Baker S-3 Perm , 4-1/2"Baker FHL Liner 1091 7" 10286 - 11377 8275 - 9191 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2890553720 158197 0 4219 940 1033 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4535 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9191 Sundry Number or N/A if C.O. Exempt: n/a No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028309 , 028312 PBU 07-24 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 11085 , 11155 , unknown 5-1/2" 17# x 4-1/2" 12.6#, 13Cr80 / L-80 By Samantha Carlisle at 3:15 pm, May 26, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.26 14:25:22 -08'00' Bo York MGR30JUL2021 RBDMS HEW 6/9/2021 DSR-5/26/21 SFD 6/16/2021 ACTIVITYDATE SUMMARY 4/29/2021 ***WELL SI ON ARRIVAL*** PULLED 3.81" XX PLUG @ 10137' MD DRIFT TBG w/ 33' x 3.66" DMY GUNS TO 11040' SLM (no issues) ***JOB COMPLETE, WELL LEFT SI, DSO NOTIFIED OF STATUS*** 4/30/2021 LRS unit 72 Assist E-Line (PERFORATING). Job cancelled 5/1/2021 ***Well Shut in on Arrival*** Job Scope: Set Plug / Dump Bail Cement RIG UP ALASKA WIRELINE UNIT. SET NEO THRU TBG BASKET PLUG AT 10941'. OAL= 4'. SLACK OFF ~ 150# INDICATING GOOD SET. POOH. DUMP BAIL 5 GALLONS OF BRIDING BEADS ON TOP OF BASKET PLUG. LAY DOWN FOR THE NIGHT. ***JOB IN PROGRESS*** 5/2/2021 ***Job Continued from 5/1/21 WSR*** DUMP BAIL 5 GALLONS OF NEO CASING CLEANER FOR BETTER CEMENT SHEAR BOND. DUMP RUN #1 OF 9.3 GALLONS OF NEO SUPER SLURRY 17ppg CEMENT ON TOP OF BRIDGING BEADS. ESTIMATE TOC SO FAR AT ~ 10932'. ALLOW CEMENT TO BUILD COMPRESSIVE STRENGTH OVERNIGHT BEFORE DUMPING REMAINING CEMENT. ***JOB IN PROGRESS*** 5/3/2021 ***Job Continued from 5/2/21 WSR*** DUMP BAIL RUN #2 OF 9.3 GALLONS OF NEO SUPER SLURRY 17PPG CEMENT. DUMP BAIL RUN #3 OF 9.3 GALLONS OF NEO SUPER SLURRY 17PPG CEMENT. DUMP BAIL RUN #4 OF 9.3 GALLONS OF NEO SUPER SLURRY 17PPG CEMENT. ***TOTAL OF 5 GALLONS OF BEADS & 37.2 GALLONS OF 17 PPG ACCELERATED NEO SUPER SLURRY CEMENT DUMPED ON NEO BASKET PLUG. ESTIMATED TOC ~ 10914'*** ***JOB COMPLETE FOR NOW / WILL RETURN IN ~ 3 DAYS TO PERF*** 5/7/2021 RIH w/ 3-3/8" x 31' OF GEO CONNEX PERF GUNS TAGGED TOP OF CEMENT AT 10910' ELMD PERFORATE INTERVAL 10760' - 10791', CCL TO TOP SHOT = 9.6', CCL STOP DEPTH = 10750.4' Daily Report of Well Operations PBU 07-24 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:183-063 6.50-029-20945-00-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11377 11155 9002 10112, 10271 11085, 11155, UnkQRZQ 11155 8142, 8272 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31 - 110 31 - 110 1490 470 Surface 2499 13-3/8" 30 - 2529 30 - 2503 5380 2670 Intermediate 10559 9-5/8" 27 - 10587 27 - 8523 6870 4760 Production Perforation Depth: Measured depth: 10635 - 11142 feet True vertical depth:8573 - 9016 feet Tubing (size, grade, measured and true vertical depth)25 - 10354 25 - 8340 Packers and SSSV (type, measured and true vertical depth) Liner 1091 7" 29# L-80 10286 - 11377 8275 - 9191 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 23200116 1460 4686 Shut-In 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Thompson, Ryan RYAN.THOMPSON@bp.com Authorized Name:Thompson, Ryan Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4535 Treatment descriptions including volumes used and final pressure: 13. Petroleum Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9191 Sundry Number or N/A if C.O. Exempt: N/A 10271 8272 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Pull Hex Plug Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028309 & 028312 PBU 07-24 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 5-1/2" 17# x 4-1/2" 12.6#, 13C/ 10112 81421/2" Baker S-3 Perm Packer 1/2" Baker FHL Packer 1R6669,QVWDOOHG Ryan Thompson Digitally signed by Ryan Thompson Date: 2020.05.11 14:48:22 -08'00' By Samantha Carlisle at 4:39 pm, May 11, 2020 DSR-5/11/2020 SFD 5/13/2020RBDMS HEW 5/12/2020 MGR18MAY20 ACTIVITYDATE SUMMARY 4/15/2020 ***WELL S/I ON ARRIVAL*** (profile mod) RAN 3.50" LIB TO HEX PLUG AT 10,775' MD (impression of fishing neck) PULLED HEX PLUG FROM 10,775' MD (missing element) RAN 4-1/2" BRUSH & 3.40" WIRE GRAB TO 10,850' SLM (no recovery) ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU 07-24 183063 by Date: 1/20/2020 2 1 1 3 Transmittal Number: 93734 BPXA WELL DATA TRANSMITTAL Enclosed is one disc containing the information listed below. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendallkby.com. Please Sign and Email a copy of this transmittal to. GANCPDC@bp365.onmicrosoft.com Thank you, .T4er Xendaff Subsurface Information Management AOGCC ConocoPhillips Alaska, Inc. ExxonMobil, Alaska JV-2019-USONSHOR-291 RECEIVE® MAR 3 2020 AOGCC 1 Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Disk SW Name API Run Date Company Description Number GYROSCOPIC SURVEY DATA AND GyroData / FINAL COMPOSITED GYROSURVEY 07-24 500292094500 1/22/2020 Baker Hughes REPORT 1 Please Sign and Email a copy of this transmittal to. GANCPDC@bp365.onmicrosoft.com Thank you, .T4er Xendaff Subsurface Information Management AOGCC ConocoPhillips Alaska, Inc. ExxonMobil, Alaska JV-2019-USONSHOR-291 RECEIVE® MAR 3 2020 AOGCC 1 Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set Hex Plug 0 2. Operator Name: SP Exploration (Alaska), Inc 4. Well Class Before Work Development D Exploratory ❑ 5. Permit to Drill Number: 183-063 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20945-00-00 7 Property Designation (Lease Number): ADL 028309 & 028312 8. Well Name and Number: PBU 07-24 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHDE BAY, PRUDHOE OIL �� 11. Present Well Condition Summary: 9 measured 10775 feet OCTTotal Depth: measured 11377 feet Plus C 2 8 201 true vertical 9200 feel Junk measured 11065, 11155, Unknown feet Effective Depth: measured 10775 feet Packer measured 10112, 10271 feet ^ ��� A true vertical 8691 feet Packer true vertical 8142, 8272 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 31-110 31-110 1490 470 Surface 2499 13-3/6" 30-2529 30-2503 5380 2670 Intermediate 10560 9-5/8" 27-10587 27-8533 6870 4760 Production Liner 1091 7" 10286 - 11377 8284-9200 8160 7020 Perforation Depth: Measured depth: 10635 - 11142 feet True vertical depth: 8573-9016 feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2" 12.6#, 13C 25-10354 25-8340 4-1/2" Baker S-3 Penn Packer 10112 8142 Packers and SSSV (type, measured and 4-1/2" Baker FHL Packer 10271 8272 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 71 14397 4908 0 311 Subsequent to operation: 100 9084 1 0 213 14. Attachments: (required per2o nnc 25.070.25.071, a 25.205) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Thompson, Ryan Contact Name: Thompson, Ryan Authorized Title: Petroleum Engineer Contact Email: RYAN.THOMPSON@bp.com Authorized Signature: ��— Date: f�� Z" f Contact Phone: +1 907 564 4535 Form 10-404 Revised 0412017G+riJ r�//� T 1BDMS_L16J0CT292019 Submit Original Only Daily Report of Well Operations PBU 07-24 ACTIVITVnATF 10/3/2019 —WELL SHUT IN ON ARRIVAL*** RIG UP ELINE & LRS. LRS BEGIN L&K OF TBG. ***JOB CONTINUED ON 4 -OCT -19*** ***JOB CONTINUED FROM 03 -OCT -2019*** RE -PERFORATE 10637'-10662' (REFERENCE DEPTHS: 10635'-10660') W/ 2-7/8" MAXFORCE, 6 SPF, 60 DEG PHASE, CCL TO TOP SHOT 15'. CCL STOP DEPTH 10622'. SET INTERWELL 363-700 HEX PLUG AT 10775' MID-ELEMEN, CCL TO MID ELEMENT = 14.9', -IT- CCL STOP AT 10760.1' (top of Flu 10770' md) LOGS CORRELATED TO BAKER RPM DATED 18 -OCT -14 10/4/2019 ***JOB COMPLETE ON 04 -OCT -2019*** TRff= 5"X7"LFNC120 AELFEAD= GRAY GEN3 A&IJKTOR= BAKER OKB. E_EV = 57.00' BF. B -EV = 28.89' KOP= 2000' N§rz Angle = 46'a 8900' Datum ND= 10973 Datum TVD= 8800'SS 20' COND, 91.5#, H-00, D =19.124' J -3/B- [SG, 72#, L -B0 BUTT, D = 12.347 - Minimum ID = 3.813" @ 2125' 4-1/2" HES X NIPPLE 1-1/2" TBG, 12.6#, 13CR-BO VAM TOP, .0152 bpf, D = 3.958' 110220- ELM I 5-1/2' TBG -PC, 17#, 12' TBG -PC, 12.69, L-80,.0152 bpf, D = 3.958' 1036 L&HYDHGR,D=? SAFETYNOTEs- "-4-la 4-12' CAMCO DB -6 LANDING N! 10353' 4-12'BKR BREAKOUT SUB,D= 9-5/8' CSG, 47#, L-80 BTC, D = 8.681' 10581 10340' ELMD TT LOGG® 04/06!87 10775' 363-7001NTERWELL HEX PLUG 0725/16 GJB/JMD GLV C/O (0724/1fi) _ 2126' PERFORATION SUMMARY REF LOG: BHCS ON 05/14/83 ANGLE AT TOP PERF: 33' @ 10635' Note: RetertO Pmduction DB Tor Hstodcal perfdato SIZE SPF INTERVAL OpNSgz I SHOT SQ7 2-7/8' 6 10635 -10660 O 10/04/19 4 2-12' 6 10635 -10660 O 10/11/18 1228/15 33/8' 6 10998-11013 C 07/07/17 44 NMG DONE RK 33/8' 6 10998-1'1013 C 02/07/17 8862 1-11/16' 4 11088-11118 S 11/18/83 06/12/88 3 3/8' 2 11096-11116 C 09/06/96 0 3 318' 4 11105-11113 S 0326/95 06/15/96 1-11/16" 6 11122-11160 S 11/18/83 06112/88 3-3/8' 4 11128-11142 C 0627/96 33/8' 6 11130-11140 S 07106/88 06/15/96 3-3/8' 6 11140-11160 S 07/04/88 06/15/96 LUM 7-2 w `f •� 07-24 L&HYDHGR,D=? SAFETYNOTEs- "-4-la 4-12' CAMCO DB -6 LANDING N! 10353' 4-12'BKR BREAKOUT SUB,D= 10354' 4-12'WLEG,D=3.958' 10340' ELMD TT LOGG® 04/06!87 10775' 363-7001NTERWELL HEX PLUG 0725/16 GJB/JMD GLV C/O (0724/1fi) _ 2126' 4-1/2'HESX NP,D=3.613' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORI �47E 4 3441 3257 44 MMG DONE RK 16 1228/15 3 6611 5593 44 NMG DONE RK 16 1228115 2 8862 7204 45 NMG SO RK 28 0724/16 1 10021 8069 37 MN1G OMY RK 0 0724/16 rvvv 10066' ESTTOC(1022/151 Ht ANP, D=3.813' X 4-12' BKR S-3 PKK, D = HESX NP,D=3.813' HFS XHFS X N UKR PBR ASSY, D = X 5-12' BKR SAB PKR D = 101 286' 1-19-5/8'X7-BROWNTEBKSLV 363-7001NTERWELL 11166' -1 L&HYDHGR,D=? 10341' 4-12' CAMCO DB -6 LANDING N! 10353' 4-12'BKR BREAKOUT SUB,D= 10354' 4-12'WLEG,D=3.958' 10340' ELMD TT LOGG® 04/06!87 10775' 363-7001NTERWELL HEX PLUG 363-7001NTERWELL 11166' -1 TOP OF 20/40 CARBOLfTE (01/1fi/1 11155' 02106/17 GJWJMD REMVD OUTDATED CARBOLITE NOTI FISH: 4-12 BKR CBP HALED & PUSHED TO BTM 1020/15 0210&17 BTWJMD ADPERFS (02/07/17) 02/12/16 TTRUMD MILLED CMT&CARBOLfrE 01/16/16 ??? F6H: RETANER PN (07/08/14) DATE REV BY COMMENTS DATE REV BY COMMENTS 05!18/83 ORIGINAL COMPLETION 02106/17 GJWJMD REMVD OUTDATED CARBOLITE NOTI 05106105 JDMITLH RWO 0210&17 BTWJMD ADPERFS (02/07/17) 02/12/16 TTRUMD MILLED CMT&CARBOLfrE 01/16/16 10/15/18 MS/JMD ADPERFS&SETHEX PLUG 10/11/18 02/16/16 RB/JMD TREE C/O 02101/16) 1029118 DD/JMD ADDED OKB, BF & COND INFO 0224/16 DU/JMD TREE C/O 02/01/16 0521/19 NXW/JM HEX UH 05111119 0725/16 GJB/JMD GLV C/O (0724/1fi) _ 10107/19 W/JM SET HEX PLUG & REPERF (10104/19) PRUDHOE BAY UNIT WELL: 07-24 PERMIT No: 91830630 API No: 50-029-20945-00 SEC 33, T11 N, R14E, 1869' FNL & 244 BP Exploration (Alaska) WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. May 21, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 07-24 Run Date: 5/10/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 07-24 Digital Data (LAS), Digital Log file 50-029-20945-00 RECEIVE p JUN 0 3 2019 AOGCC I CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: FRS—A] Date: 18 30 53 STATE OF ALASKA 0LASKA OIL AND GAS CONSERVATION COMMI1 REPORT OF SUNDRY WELL OPERATIONS • 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate EZ1 Other Stimulate ❑ Alter Casing El Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 183-063 3. Address: P.O.Box 196612 Anchorage, Development a Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20945-00-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PRUDHOE BAY UNIT 07-24 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: ti ECEIVED Total Depth: measured 11377 feet Plugs measured feet true vertical 9200 feet Junk measured 11155/11333/1133 feet MAR 0 2 2017 Effective Depth: measured 11155 feet Packer measured See Attachment feet U true vertical 9012 feet Packer true vertical See Attachment feet , s Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 31 -110 31-110 1490 470 Surface 2501 13-3/8"72#L-80 30-2531 30-2505 4930 2670 Intermediate 10559 9-5/8"47#L-80 29-10588 29-8534 6870 4760 Production Liner 1091 7"29#L-80 10288-11379 8286-9201 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: WED APR 1 3 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 115 / 0 2982 1800 236 Subsequent to operation: Shut-In 300 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development Ell Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I3 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 3/2/17 Form 10-404 Revised 5/2015 VTI- 3/al/ ,*t07�� ^ ' y '" Submit Original Only i • Packers and SSV's Attachment PRUDHOE BAY UNIT 07-24 SW Name Type MD TVD Depscription 07-24 TBG PACKER 10117.58 8146.47 4-1/2" Baker S-3 Perm Packer 07-24 TBG PACKER 10272.48 8272.85 4-1/2" Baker FHL Packer , • • 0 Cl) m m d- N Ln V m m CO CD V V L M Ln = 0) = CO M QO Ln M a ,- O) Ln a0 O 0o O a0 0 In m 6) c cc N- N- 00 aO 0) 0) o c- p co O) 6) 6) O) O) 6) 0) 6) O O 0 cc 00 ca 0o 00 00 cc 00 cc C) 0) > I- 0 H N N Ln co N- cc CO V t . N- Ln CD Nt L() CO CO CO Ln a cc d' .- CA Ln CO ch 00 O a0 O 0 a) Ln co co N- N- CO 0o C) C) CD W OMMMMMMMMMMCD > 0 CO CO CO CO CO 00 00 CO CO CO CA 0 > 2 I- w cr o 0 o WZ W w 0 W 0 d g ICI J 0 W to Y 0 O CO 00 w Y Y H 2 M co Ln c) CO 00 0O o o N o J U U W a W 4_, N - a) o = = N C) V co J J J d d U7 Z O O r r 0 0 0 J W W O J O N. 222000 -10 -1 J J J o J O NX 0 0 2 Q Q Q = � � aIi22. a" • I-- 0 0 0 W Z O Z W W W a H H < J < C.) Z 2 22 O cn cn cn cn cn CO M 4-0 < >- Q 0 < H w co co co in co c0 N 0o O O N a) 00 o) O = = N N Cr) d' c p_Q O 0 0 •47, W L O N tt• 0_ 2 2 2 O cn cn cn u) cn ct) m 0_ 18 0 C ▪ LL N LL LL LL N N LL LL LL N m - OUQ- 0.. 00000O 0. 0 t m a m H D o N- cococomm � mcoc cc a 0 F, <a) a) 0) C) CA C) C) 01 a Z a Q W _ N ,- r r r .- - r r r . ,..‘ f: W N W 6 -a 6 6 • f� C_O C\o N (\o N o a 0 0 O W fY ON C CO C) C) C CO m 0 _i H J J J D G a Q Q a cn L. LL u. �O a CC a) E m Z v v v v Nrv 5 N N N N N N N N N N N a a 0 W N a LL NN- NNNNNIr- c"- NN m as a0J00w Cl 0 0 0 0 0 0 0 0 0 0 0 < < m m u u cn cn a s • • • C, o• 0 0 0 0 0 0 0 co N- (0 N CO O CO O CO I" O N LO N LC) O N ti U 7) o 0 0 0 0 0 0 0 i O) co I- (0 co V co • V 0) co N- ct m r- (0 CO 1` CO t` 00 Ln V O co O d7 Nr 00 Ln Ln N N N N CO N CO O) 00 CO CO CI 1 1 1 I I 1 1 1 I— (0 d' O O O) co t` O co co co CO N N N N N N CO CO CO 00 0) Ln N N o 00M CO LO r-• Loco Lo EM N N N CO c N O O O O mC 4-1 ICC M co In ✓ 0 0) O) N CO • } co co N O N N O • W O 00 0 O 02 oaow0VUo0oao i CD C L!) N. N. 4# M c cv CI' a7 ;oeoN - OM CV (V N N co i L() 4 O) 00 LC) O co r � N O �O O M NO Ln ti _ N W 0 O• W U puf:tZZZZ Z W W m m m m ODHZDDDD U (n Z J F- F- I- I- • 0 LL J 0 -J_ CO LL LL O 0 � _ coX -J I w H W o -) O o 0 0_ Orn rn 2 < Cl) MO U Z • II o EC_ Cl, � � 0 11 N- = N F L, C °ow Q w xd 3 0 co N � o f CC 0- EoW0 Z E Ili Q = m 0 Qcr) p ' aE a) 0 O © % Cl.c� a ' D CL W � Op aH �Qo �� -OZ � .� HO .= c[ w toJQ _ L _X L O m /, p CC W LT �' LL J O 0 Ur Q a) in J w0 S O m d J W w Z o OJ E t W 00 H * LHL * p n d < • O J Z * J IL w w 0 QU) p * � f5 < c - 0 p Q2 > - O p > �n v) 0 re m > N- W o - o J H _ 0 A Ce < N 0 . H z < ,r > 0 0 ,r Z cC Q' Z ~ � oQI- Z � uU1N- * Q UN N 00 D O 0 Z Et oN H 2 , o O N- 2 MND V (/) — � — ZY '1- JU) p X o 0� U H j II 0 () Q II , LL H to ZL_ 0 Q m u) „ JCn - Q = O � OJ J H H U) J J H L' d H E 0 J J ZZ JJJO O Z H CO -1 W � � 0 0 0 W W Q LL W — J W I ppQO1 Cl)l * - - * * — * * wow - * * a) * a0 * CC * * Zo_ (0E- U * p Lu H 0 r I- >- 0 0 0 w H N N N _ •<-- 5 m � N � F N N (N 0 Q S FREE= 5"X 7"L FMC 120 • _� NOTES: ***4-1/2"CHROME TBG*** WELLHEAD= GRAY GEN 307 ACTUATOR= BAKER C OKB.ELEV= 58.0' I 1--ILI 1 1 E BF. E/= ? / � 22' H5-1/2"X 4-112"XO,D=3.958" KOP= 2000' Max Angle= 46°@ 890(Y "GOND A , , ' 2125' H4-1/2"HES X NP,D=3.813" Datum MD= 10973' — Datum ND= 8800'SS #'— D= " GAS LFT MANDRELS 13-318"CSG,72#,L-80 BUTT,ID=12.347" — 2529' ST NU ND DEV TYPE V LV LATCH PORT DATE4 3441 3257 44 MNG DONE RK 16 12/28/15 III 3 6611 5593 44 AiNG DOME RK 16 12/28/15 2 8862 7204 45 MUG SO RK 28 07/24/16 1 10021 8069 37 P 1G DMY RK 0 07/24/16 Minimum ID = 3,813" a{,_') 2126' 4-1/2" HES X NIPPLE 1���11 ►��t�� 10065' —{EST TOC(10/22115) '4'4' 1•4* 10092' H4-1/2"HES X NP,D=3.813" OA .11 A . 1A A A 10112' H9-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" ,v1v1v1 ►40• FOY ' y.��• 10137' —14-1/2"I IGS X NP,D=3.813" 441 I.. .1. 11 ►11 4.1 114488. 10200' —14-112"HES X NP,D=3.813" 4.1 10216'-10217'HTBG FUNCH(10/13/15)1 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, H 10221' 14.1....) i�1�1 .0152 bpf,D=3.958" ►�4 .►..1 10221' --14-1/2"X 5-1/2"XO,D=3.958" 10223' H5-112"UNIQUE OVERSHOT 5-1/2"TBG STUB(04/17/05) —{10220' ELM 10252' —I5-1/2"BKR PBR ASSY,D= " 10271' —19-5/8"X 5-1/2"BKR SAB PKR,0= " 5-1/2"TBG-PC,17#,L-80,.0232 bpf,ID=4.892" --I 10280' J 10280' —15-1/2"X 4-1/2"XO,D=3.958' TOP OF 7"LNR H 10286' -- 10286' —9-5/8"X 7"BROWN TISK SLV &HYDHGR 13=? JiI 10341' H4-1/2"CA MCO -6 LANDING NP,0=3.813" 10353' H4-1/2"BKR SI-EAROUT SUB,0=4.125" 4-1/2'TBG PC,12.6#,L-80,.0152 bpf,0=3.958" 10354' • 10354' —4-1/2"WLEG,D=3.958" 10340' —J ELME)TT LOGGED 04/06/87 9-5/8"CSG,47#,L-80 BTC,D=8.681' -H 10587' JJ ' PERFORATION SUMMARY . I AMSUMMARY REF LOG:BHCS ON 05/14/83 ANGLE AT TOP PERF:33°@ 10998' Note:Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 10998-11013 0 02/07/17 1-11!16" 4 11088- 11118 S 11!18/83 06/12/88 11156' ,—{TOP OF 20/40 CARBOLRE(01/16/16) I 3 3!8" 2 11096- 11116 0 09/06/96 I -- 3 318" 4 11105- 11113 S 03/26/95 06/15/96 11155' —FISH:4-1/2 BKR CBP MILLED& 1-11!16" 6 11122-11160 S 11/18/83 06/12/88. PUSHED TO BTM 10(20!15 3-318" 4 11128- 11142 0 06/27/96 3-3/8" 6 11130-11140 S 07/06/88 06/15/96 ??? —FISH:RETAINER PN(07/08/14) 3-318" 6 11140-11160 S 07/04/88 06/15/96 ??? —I FASDRLL PLUG MLLED 05/06/05 PBTD —I 11335' /•//1/// 7"LNR 29#,L-80 8T&C,.0371 bpf,D=6.184" —J 11377' ,1;1;1;1;1;1;1;1 DATE REV BY COMMENTS DATE REV BY COMVBITS J PRlJDF1OE BAY MT 05118/83 ORIGINAL COMPLETION 02/06/17 CJN/JMJ REM'/D OUTDA I ED CARBOLITE NOTE WELL: 07-24 05/06/05 JDM/TLH RWO 02/08/17 BTN/JM)ADPERFS(02/07/17) PERM-No:'1830630 02/12/16 IIROAD MLLED CMT&CARBOLITE(01/16/16) API No: 50-029-20945-00 02/16/16 RB/JM3 TREE C/O(02/01/16) SEC 33,T11 N,R14E 1869'Fa.&244'FEL 02/24/16 DU/JM? TREE C/O(02/01/16) 07/25/16 GJB/JMD GLV C/O(07/24/16) BP Exploration(Alaska) STATE OF ALASKA •1LASKA OIL AND GAS CONSERVATION COMMI IIIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well El Re-enter Susp Well 0 Other:Alt Mech Comp-Pkr Sqz El 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 183-063 3. Address: P.O.Box 196612 Anchorage, Development 8 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20945-00-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-24 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11377 feet Plugs measured feet true vertical 9200 feet Junk measured See Attachment feet FEB 16 2016 Effective Depth: measured 10250 feet Packer measured See Attachment feet true vertical 8254 feet Packer true vertical See Attachment feet (,G{>C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 32-111 32-111 1490 470 Surface 2501 13-3/8"72#L-80 32-2533 32-2507 4930 2670 Intermediate 10559 9-5/8"47#L-80 29-10588 29-8534 6870 4760 Production Liner 1091 7"29#L-80 10288-11379 8286-9202 8160 7020 Perforation Depth: Measured depth: 11088-11096 feet 11088-1 1096 feet 11096-11105 feet 11105-11113 feet 11113-11116 feet 11122-11128 11116-11118 feet 11122-11128 feet 11128-11130 feet 11130-11140 feet True vertical depth: 8955-8962 feet 8955-8962 feet 8962-8969 feet 8969-8976 feet 8976-8979 feet 8984-8989 8979-8980 feet 8984-8989 feet 8989-8990 feet 8990-8999 feet ... Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Alteration of Mechanical Completion-IA Packer Squeeze SC-10065'-10221'. N ��� t 1', Treatment descriptions including volumes used and final pressure: 10/22/15:110 Bbls 60/40 Methanol/Water,272 Bbls Slick 1%KCL w/SafeLube,38 Bbls Sand Slurry,10 Bbls Clean Gel,16 Bbls Fresh Water,11 Bbls 16 ppg Class G Cement,21 Bbls 3 ppb PowerVis,179 psi. 11/6/15:141 60/40 Methanol/Water,285 Slick 1%KCL w/SafeLube,16 Bbls Fresh Water,6 Bbls 15.8 ppg Class G Cement,44 Bbls PowerVis,2428 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1443 4752 2577 1300 275 Subsequent to operation: 75 0 3533 1840 284 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development M Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil f3 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name nW�JCatron,Garry R(Wipro) Title PDC Principal Engineer Signature i 1 A Phone +1 907 564 4424 Date 2/12/16 Form 10-404 Revised 5/2015 V11- 311/ RBDMS LL FEB 1 6 2016 Submit Original Only • • Junk Attachment PBU 07-24 SW Name MD Date Comments 07-24 11155 10/20/2015 Milled CBP 07-24 11333 07/08/2014 Retainer Pin 07-24 11335 05/06/2005 Fasdrill Plug Milled • • Packers and SSV's Attachment PBU 07-24 SW Name _ Type MD TVD Depscription 07-24 TBG PACKER 10117.81 8146.72 4-1/2" Baker S-3 Perm Packer 07-24 TBG PACKER 10272.71 8273.11 4-1/2" Baker FHL Packer ! • O• 0 0 0 0 0 0 0 mN- O N CO O CO Co CO I� O N LO N LP) O N I` (O N- O N- U N 0 0 0 0 0 0 0 0 i 0) CO N- CO cr Cr) CO • d- 0) CO r N- m r O CO N- CO N- CO N- N •cr O r O CO O 6) CO Ln L() N N N N CO r N CO 07 CO CO CO • l i i i l i H (0 O N N O) CO N- O) Cr) CO M M N N (V N N N CO CO CO CO O N LO r ✓ M CO N- CO CO L() r M Lf) (M O N N ✓ N O r N 0 0 0 U p COllllll CO LO N O N r O N N Cr) M M N O N N O O Cc r r r • MM a O OO O O O O O p0 � °° 0UUco = J CO (+) r J d 4 N /# C(OO NLn *k * O • r a• ) N - O oo 0D N r - • N = CV U oN M C 7 r in I Ln 't O co LL) O O O a7 O C N- Ln LI) O N U) J N O r O W U W W 0• pu � � ZZZZ Z EtW W m m m E O D L- Z » » UU) Z � HHHH • • 6 0) o 2 o o \ f 0 ° : 0 2° CO - _0 011 >< 7 � 2 = / f Of % 3 m R� § 2 12 W 7 $ b / c § a \ m — o E E 7 \ 0 / ■ \ / ƒ % C ° < N C $ _ as W \ ) / / m <co 16. / \ a� CO 0 $ H % © �r6 EF O N w 2 - = y eq ¥ 7 g / 7 Ov. $ @ e 2 ._ E y 2 _ _ I . / / 2 / J ° E / > N ± o NO o E 5 � ° E cn $ § � E � ® o 9O / 7 0 0 CO \ N D D 6 6 c O 2 O Z » / / *R : R 6 t O E E / / ® � 2 t E & 7 O 7 § i 2 z _ - O 0 : w ± ± ; O o c\i0 www - - o - I t � I W 2 O. �o R R o 2 � � � w w t ± 2 o O � : ± - Cl) � * m rx @ - .- Z z o co e 7 % % O 3 M < W ct 0 \ w / iy ± f O O = c m e a) Li ƒ / \ O r m r a L m 2 / / � ©00 © © Z / � 2 $ rw 5 ,_ wl $ ii H- co / / 0 ��pppppp> / \ � / LIJ, � / / / y / / / / f / \ ƒ 0 w U E E O -I -I -I O o G I a o I ~ a U l Zr) 6 L < R W ± O / / / o o O HI 6 < z - 7 = ƒ 2 / = ƒ $ 7 + O gy0Or ctet222 \ '- O > >< fi / '- R \ 0 = � 00 / k ± ± 2 � � 2WW � Z ± \ I2Et = m22I22 ¥ icC (N - � & ZZ H-CL / in / .- d / / eE / R9 < H HLU \ - 2aJa \ / / \ RRR Z Z Y4gZZ 'TIZZ70Z / Z - 2 4 E E m m m I o o I 0 0 4@ 0 0 4 # O 11 r 0 & ± R % \ _1 _i _i _IRRR � U UGH _1 _iOOZ < OOZZU / � UU � i $ : : / a. a_ a. ƒ $ $ \ i : \ $ a. i : : J 5 : : J J : / / i \ : L < LU m r LID r r r \ \ \ CD \ d d R �; _, a a - & \ o r. r / \ .-- \ U < • °' w H cu 70 +n WZW W U° �n ° O Q W O v Q ct H N N N L LL o c _ O 0 - 0 D m U Q l CCw a -t,' cn2C- w N J _0 9_7—P, -(1 _ O . u) J � .0 - c0 a) E � L0 Owa < N -...1w W JO c\ "- f (n IZ -C c 00- 0m� H wat0 C� L E c O Q 0) Z U J c — U 0.- 5 D H J O pip Q a (� N p Q H m N Q ° m J , Z ill o 0 O u_ 0)w ' OUr ) • dO 1- z t L Z D W (N ti = a ° Q o O O > o m o C 0 ° � C7 � MD m _ NwOQf- pa • Z 0 N m 0 NN W N w O > d r IP Em 0 m .cr L- mQ Lo © — (n (nom wQH 0 _ m G) 0 0LoJ NN X -ON = ° H NW O L � 2Zm � Q. 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J * H 0_ co 3 2 'o J * J * J * J * J * J (0 CO O CO (0 (0 O (0 (0 C,-- O `- = O O Or O CD O CD CD O O N N N N N N N N 01 OO ,- N M V 10 10 (O N- 0 • 7 o 7 k q0 qi D @ D E c /2 s / - I— o - 00 z- — / ( 0 70 E o ± ots- / ® / 0 k / k cu H _ G S 0 I o @ a a • R / _8 ¢ o � 2 IP < ± < ca E coal % co £ / >' Oa ,zi / / / 0 fR - - � r / \ / o � c $ ) oast = * O G O to p ri \ / ; / 6 Ct. & -.. @ o - - o cL % ƒ \ % % ° « ¢ ¢ 2 $ o co $ E 2 $ E - • / E E \ p m E g ! oi o 0 ® 2 ® / / m 0 0 / 0 ° \ 0 \ e k O .° co C � I > a 5 / C / / _ U - C \ -4. k n \ \ R / / c 2• * / / ¢ a_ E 5 / ® o .g ® o a \ f ƒ ? = U t k o_c % 3 0 2 3 0 E Et ; O ct o 9 2 6 2 § R ,- e a 0 1-0 & - 0 _1 t 0 5 U 2 e m $ # ± - n - E Z e (0 N- / ° w n o (D N.- CO o CV N- o / % d / 2 2CO A CO e / -a- .1- TFEEE= GRAY GEN 3 !WELLHEAD LI-EAD= GRAY IIII 7 S TY NOTES: "'*4-112"CHROME TBG*** ACTUATOR= AXELSON OKB.ELEV= 58.0' I l J BF.ELEV= ? 22' 5-1/2"X 4-1/2"XO,D=3.958" KOP= 2000' Max Angle= 46`@ 8900' "ooNDuCTOR ..._.__j , I 2125' —14-1/2 FES X NP D=3.813"J Datum MD= 10973' — DatumTVD= 8800'SS — 0= " GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH PORT DATE 13-3/8'CSG,72#,L-80 BUTT,D=12.347" 1— 2529' 4 3441 3257 44 MMG DOW RK 16 12/28/15 J 3 6611 5593 44 MMG DOME RK 16 12/28/15 2 8862 7204 45 MAG DOME RK 16 12/28/15 __ 1 10021 8069 37 MMG SO RK 28 12/28/15 Minimum ID = 3.813" @ 2125' 4412" HES X NIPPLE IP1 rrt 10065' HEST TOC(10/22/15) 11111' �1�Q1 10092' —44-1/2"FES X tom,D=3.813" 11 ►.• �1�1�. 1_111j 10112' H9-518"X 4-1/2"BKR S-3 PIR,D=3.875" .1.1.; ei.A. 1111, ',vvv1 10137' H4-1/2"FSSXNP,D=3.813" 1111.1 1�1. 11111 14 6,11. 10200' --I4-1/2"HES X NP,D=3.813' 111 111 I1,11, A.41 10216'-10217' —TBG PUNCH(10/13I15> 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, —{ 10221' :1,14•4, 10 10221' H4_1/2'X 5-1/2'XO,D=3.958" .0152 bpf,D=3.958" '.x.0.4 !.-.•. — 1. 10223' H5-1/2"UPNQ4 OVERSHOT 5-1/2"TBG STUB(04/17/05) H 10220' ELM J 10252' H5-1/2"BKR FSR ASSY,D= " 20/40 CARBOLJTE(10/22/15) --110260'CTM �� 10271' —{9-5/8"X 5-1/2"BKR SAB PKR,D= " 5-1/2"TBG-PC, 17#,L-80,.0232 bpf,D=4.892" — 10280' , - j 10280' H5-1/2"X 4-1/2"XO,D=3.958" TOP OF 7"LNR 10286' v, r 10286" --9-5/8"X 7"BROWN TE3K SLV &HY D HGR,ID=? il I 10341' H4-1/2"CA MCO DB-6 LANDING NNP,D=3.813" 10353' —{4-1/2"BKR SH-EAROUr SINS,D=4.125" 4-1/2"TBG-FSC, 12.6#,L-80,.0152 bpf,D=3,958' --L` 10354' 1--- \ 10354' —j4-112'WLEG,D=3.958" 10340' --I ELMD TT LOGGED 04/06/87 9-5/8"CSG,47#,L-80 BTC,D=8.681" —1 10587'A-4 PERFORATION SUMMARY REF LOG:BHCS ON 05/14/83 ANGLE AT TOP PERF:32 @ 11088' Note:Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 1-11/16" 4 11088-11118 S 11/18/83 06/12/88 3 3/8" 2 11096-11116 0 09/06/96 3 318" 4 11105-11113 S 03/26/95 06/15/96 11155' --ITOPOF 20/40 CARBOUTE(01/16116) 1-11/16" 6 11122-11160 S 11/18/83 06/12/88 I _ 11155' —FISH:4-1/2 BKR CBP MNLLED& 3-3/8" 4 11128-11142 0 06/27/96PUSHED TO BTM 10/20/15 3-3/8" 6 11130-11140 S 07/06/88 06/15/96 3-3/8" 6 11140-11160 S 07/04/88 06/15196 .......... - ??? --I RSH:RETAIM R PN(07/08/14) ??? H FASORLL PLUG P,&LED 05/06/05 PBTD H 11335' 11111111 111/11/11/11111 7"LIQ 29#,L-80 BT&C,.0371 bpf,D=6.184" --F 11377' ��AA.A.A, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/18/83 ORIGINAL COMPLETION 01/01/16 JPKRLH GLV C/O(12/28/15) WELL: 07-24 05/06/05JDM/TLJIRWO 02/12/16 TTR/JMD MLLEDCMT&CARBOLTTE(01/16/16) PERMTT No:'1830630 07/15/15 TR/PJC CSG/LM TBG/PERF UPDA 1 hS API No: 50-029-20945-00 10/21/15 CJNYTLH GLV CJO&PULL BP(10/9/15) SEC 33,T11R R14E,1869'Ft&&244'FEL 10/21/15 CLW/TLH SET COMPOSITE PLUG(10/13/15) 1 01/01/16 TTWTLH PLUG MLUSANDfCMT SQZ(10/22/15) 8P Exploration(Alaska) et' In • 0 a) u J Xu cu L) Q t o a Y (1 CC a) v O wAw Oz , C E hoz O 0: o ~ co rillaw v a Y a� o w QTY O_ N f 0 .O F-. 7i Q� ❑ (13 to > 0_ Q H O U a) a) a) Y N U O ''a _ 2 -I O Z p ❑ ❑ ❑ EYra az Li., in o � -o 0 a) eel N - C > in >.. a z 0 Q Q o YH u •-•di E _> _c -2 --,-, Y W J J J J J J (1:3C a u T, w w w w w w ta0 C rt3 O O F- LL LL LL LL LL LL 'N a) E in r� O f" Q Q Q Q Q Q O_ O co v Q Z Z Z Z Z Z a) V U Q p N Y � LL LL LL I.L. 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Q tiL Q Q Q N M .. a 7 d T z M O O N N r N al F- W O.a N N w-i X U' ,- O J E Z a) ro _ v eA LDo CU c0 a Q F- (V) G— J J Cr N O Dau 0 3 o aJ0.0 U cJ U0, 3 o Qas N O !� O cc N N p (1 N ® N H , t L c ` 1 ® J Z to 4-' I— > Q E ul 4� J a u v O w E— ;4 a N _. p •Q m �- ( ) (o , ra >- a Q st c O J P 7 in in in M (9 O73 co Q r r .c u a-, J O. a ' 4. 'i"' aJ Q y F 0 Crv y y y s c c a w p O N w CD Z (VI Q7�nZ Q N N CO v Q - ..w 0 • fO a CI iii P". fQ A Y al ff co a, a Ors 0 0 0 Si 0 a s CD u W W J W W W C } W W W W W pp r9 \ p F LL LL LL LL LL •vi a� E 'Q 0 a J J J J J N Q c v co 1— aaaaa an y c �O M Z Z Z Z Z • -Q `n , Y > Y0 4 aJ a1 Q O O 1 M Z ,� a (1) .,--' -Q r.r V pray 0 • O a1 r-r 00 F- CV QJ a-� w 0 a G itc r c Z CV 2 < a) .c L) > 1.4 W J O y J a' 0q p m Q O. Oi r.-4 'C cyQ mvaUJU ....%1 c , cz M al 00 tJ: > v PI V c0 yfm ge V, 0 II] e b co 2 o k _. 0 ... C C4 0h CO -� C) Z V Pi N. LL' O , L iw o 0 o, a p � d � ��za 11 w 0 ,4".-i-p01112.....,r, P N >, ›, ›. >, >>, 11.0 CO m m CO m I z O O O O O O L L L _c .c J L w_ O 7 7 7 7 7 7 4 N waa` a` a` a` '5 �1N 0 Y ccc >. o. _ X N o UJ N O O O 0 a C O O CC 0 O O O CLI O O O O O O O _ O 0 0 0 0 - 2i0c7 co > co x m vcv IX w 0 0 0 0 0 C ns vi x c 0 o N 0 O u lD o• 0 o O o u+ NM o v d) so C N P1u) 1` Cr f") x r u) . E N O N , al M O N p, (Ni N NN N L U 1:: Q Q) O O T 6O fl N N N i N p N N 1N Q1 O O o 0 o aJ o O O O O N N N O I() 7 ti 0 v ggix y} .a �+ " Q K c .z Y n 9. Q O CO N M ct co N E d �Op M z N M N N N !_' t0 .- f- E Q f� N J U X >- O O E z QJ N v W M r t I� c c t�0 10 C., '4 Q471 ea _ QJ c0 O y F — a < • 40 -2-NO-\OO3 063 25 614( 25613 WELL LOG DATA LOGGED 5/1/2015 � TRANSMITTAL C M.K.BENDER RECEIV PROACTIVE DIACINOSTIC SERVICES, INC. APR 0 9 2015 AOGCC To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage,Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage,AK 99508 SCANNED Mi- 0 7 2015 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1] LeakPointTM Survey 09-Mar-15 C-37B BL/ CD 50-029-22360-02 2) LeakPointTM Survey OB-Mar-15 07-24 Bt/ CD 50-029-20945435) Signed : fl94a42OJ ) 6.,,,,G Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archt,es\MasterTemplateFtles\Templates\Dtstnbutton\TransmittaISheets\BP_Transmit docx SEAN PARNELL, GOVERNOR �b T ' ALA KA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Brad Gathman Well Engineer BP Exploration (Alaska), Inc. �'�j P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-24 Sundry Number: 309-421 Dear Mr. Gatham: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 n . . . kr=man, Commissioner DATED this /9 day of December, 2009 Encl. STATE OF ALASKA ALASIAIL AND GAS CONSERVATION COMMISSIW 4 9 C GE APPLICATION FOR SUNDRY APPROVALS 14 . 20 AAC 25.280 2009 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ -enter y a ed Well Alter casing El Repair well ❑ Plug Perforations El Stimulate ❑ $ C !0 Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ _ Exploratory ❑ 183-0630- 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20945- 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: Spacing Exception Required? Yes ❑ No ❑ PBU 07 -24 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028309. PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11377 9200.23 - 11172 9026 NONE YES, UNKNOWN Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" SURFACE 79 SURFACE 79 1490 470 Surface 2529 13 -3/8" 72# L -80 SURFACE 2529 SURFACE 2503 4930 2670 Intermediate 10587 9 -5/8" 47# L -80 SURFACE 10587 SURFACE 8533 6870 4760 Production Liner 1091 7" 29# L -80 10286 11377 8284 9200 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED 4 -1/2" 12.6# 13CR80 SURFACE -10221 5 -1/2" 17# L -80 10220 -10280 4 -1/2" 12.6# L -80 10280 - 10354 Packers and SSSV T VDe: 9- 5/8'x4 -1/2" bkr s -3 okr Packers and SSSV MD and TVD (ft): 10112 8142 9- 5/8'x5 -1/2" baker sab Dkr 10271 8272 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Q - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/21/2009 Oil Q' Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: W ►NJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brad Gathman Printed Name Brad Gathman Title Well Engineer Signature Phone Date 564 -5778 12/15/2009 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: pp Y p Y rY 4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ I Other: Subsequent Form Required: �© • �� Y APPROVED BY D /1 Approved by: COMMISSIONER THE COMMISSION Date: !Z !! 7 4000! i Form 10-403 Revised 0712009 Su u lic to 07 -24 183 -063 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 07 -24 11/18/83 PER 11,088. 11,118. 8,954.81 8,980.26 07 -24 11/18/83 PER 11,122. 11,160. 8,983.65 9,015.89 07 -24 6/12/88 SQZ 11,088. 11,320. 8,954.81 9,151.78 07 -24 7/4/88 RPF 11,140. 11,160. 8,998.92 9,015.89 07 -24 7/6/88 RPF 11,130. 11,140. 8,990.44 8,998.92 07 -24 3/26/95 RPF 11,105. 11,113. 8,969.23 8,976.02 07 -24 6/15/96 SQZ 10,531. 11,160. 8,486.58 9,015.89 07 -24 6/27/96 RPF 11,128. 11,142. 8,988.74 9,000.62 • 07 -24 9/6/96 RPF 11,096. 11,116. 8,961.6 8,978.56 07 -24 9/6/96 RPF 11,128. 11,142. 8,988.74 9,000.62 07 -24 11/10/04 BPS 10,308. 11,160. 8,302.17 9,015.89 07 -24 3/30/05 BPP 10,308. 11,160. 8,302.17 9,015.89 07 -24 4/16/05 BPS 10,315. 11,160. 8,307.94 9,015.89 07 -24 5/4/05 BPP 10,315. 11,160. 8,307.94 9,015.89 07 -24 10/18/08 BPS 10,080. 11,160. 8,116.25 9,015.89 07 -24 10/29/08 BPP 10,080. 11,160. 8,116.25 9,015.89 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE by • • MW -41W %lor To: Jerry Bixby /Clark Olsen Date: December 14, 2009 NSU, ADW Well Operations Supervisor From: Tiffany Quy, WIE Office: 907 - 659 -5525, Cell: 253 - 576 -6153 Subject: 07 -24 Load OA with Gelled Brine Est. Cost: $20M AFE: PBD07WL24 IOR: (Reg Compl) Please add the following steps to the WBL: Step Type Procedure 1 F Pump 30 bbl gelled 9.8 ppg brine w/ corrosion inhibitor in OA. Fill OA to surface w/ crude Current Status: On line PAL Last Well Test: 535 bopd, 2423 bwpd, 86% WC, 533 IOR Latest 1-12S value: 22 ppm 06/02/09 Purpose The purpose of this procedure is to load the OA with gel diesel to mitigate a falling OA FL. Current practice is to load any OA FL below 500' up to -300' with crude. A deep OA fluid level represents a hazard in the event of a surface casing failure, potentially resulting in the release of a large gas volume. A gelled mixture is used for wells which require multiple OA loads to prevent the slow loss of fluid from an OA with a slowly dropping fluid level. A non- freezing mixture of gel is used that will form a filter cake and seal off small leaks around the SC shoe. The placement of the gel is done by filling the OA void volume and allowing it to migrate down to plug the leak over time. 07 -24 has an OA FL @ 1380'. It has been loaded repeatedly over the last 6 -years and continues to fall out 1000' every year. OA FL History: • 12/24/03: MITOA Passed to 3000 psi • 06/23/04: MITOA to 3000 psi Failed LLR @ 2.5 BPM @ 850 psi • 03/05/05: OA FL found at 1644'(96 bbl) • 03/26/05: FB loaded OA with crude • 05/05/05: RWO complete, tubing replaced • 01/03/06: OA FL @ 1464' • 01/04/06: Loaded OA with 80 bbls crude • 11/24/06: OA FL @ 1610' • 11/30/06: OA load w/ 93 bbls crude • 12/01/06: OA FL @ 450' • 01/07/08: OA FL @ 1080' • 01 /17/08: Load OA w/ 52 bbls crude • 10/20/08: OA FL @ 1200' • 10/30/08: Load OA w/ 67 bbls crude • • • 12/29/08: OA FL @ 740' • 01/02/09: Load OA w/ 30 bbis crude • 11/29/09: OA FL @ 1362' cc: w /a: Well File NSU, ADW Well Integrity Engineer JOB PLANNING DETAILS: Gelled Recipe The treatment consists of four stages. The brine used will be gelled 9.8 ppg brine w/ corrosion inhibitor (30 bbis gel brine total). The corrosion inhibitor, EC1124A, requires -25 gal EC1124A/100 bbl brine. The gel will be a 40 HEC from 12gal/1000 gal Liquid HEC (J512, 40% Solid HEC (J164) by weight). For 30 bbis gel brine, 7.5 gal EC1124A & -15 Ibs J512 are required. Stage 1 will require 2500 # 100 mesh sand. Stage 2 will require 850# bentonite & 5 Ibs cello - flake. Stage 3 is clean gel, and stage 4 is straight crude (see pump schedule for details). Pressure and pump rate considerations: The OA is effectively a tank being filled. The initial pumping should kill any residual OA pressure and make it possible to pump into the OA at max rate. Watch for any OA pressure rise as the total volume pumped approaches the OA fill -up volume. Be prepared to slow the pump if a rapid pressure increase is observed. Well has an open shoe (MITOA to 3000 psi Failed w/ LLR of 2.5 BPM @ 850 psi 06/23/04) so this is not expected. Safety Consideration This procedure results in the OA being liquid packed. It is preferable to do this procedure on a warm well with warm fluid to prevent the possibility of a large annular fluid expansion. If the procedure is done on a cold well it must be clearly communicated to Operations that the OA is fluid packed and will require close monitoring as the well is put on production. The IA pressure should also be monitored for rising pressure as the warm fluid is pumped into the OA. The solids can cause problems monitoring the OA pressure. These solids can plug surface pressure gauge orifices resulting in erroneous readings. The final stage of straight crude helps to flush any solids away from the surface jewelry. Recommended Equipment 1. Double valve connection to OA, terminating in a 2" 1502 connection. 2. FB Pump truck. 3. Tank for pump truck to wash up into. 4. Tanker of hot brine for mixing gel. 5. Batch mixer for gel stages Job Preparation: 1. D: Confirm OA pressure and FL. (12/12/09 OA FL @ 1380'(81 bbls) - 13 -3/8" x 9 -5/8" = 0.0581 bpf) DA Vol. = l y(- 6,61 - 2. F: Ensure pump truck and gel ingredients are available 3. D: Bleed the OAP to < 200 psi (just prior to FB w/ gel) 4. F /SLB: Prior to the job, have required (30 bbl) brine loaded into a transport and heated by LRS. Add the gelling agents using a batch mixer and allow mixing. Procedure: 1. Lay hardline from the pump truck to the OA valve. 2. Take OA pressure reading. 3. Pressure test hardline and double valves to 3000 psi. 4. Make sure the piping is empty of water (less than 10 gallons) before adding the brine to the batch mixer. Impurities may have a detrimental effect on the gel. 5. Spear into the OA with 5 bbis McOH. 6. Pump Treatment down OA @ -3 -4 bpm if pressure allows. This is a four stage treatment as described below. Maximum treating pressure is 2000 psi. Plan to batch mix and pump in stages as follows: a. 10 bbis gelled 9.8 ppg brine w/ 2.5 gal EC1124A corrosion inhibitor & 6 a of 1 mesh sand. This results in 2 pp 00 s 500 Ibs of 100 mesh sand and a 12.7 bbis slurry volume. The fine mesh sand helps fill any cracks in the formation and i gives the bentonite a better surface to form a filter cake against. b. 10 bbis of ppg elled 9.8 brine w/ 2.5 gal EC1124A corrosion inhibitor & 9 2000 ppt of bentonite and 1 /z lb/bbl of cello -flake additives. This requires 850 Ibs of bentonite and 5 Ibs of celloflake. These additives will form a filter cake over the leak and prevent further fluid loss. c. 10 bbls clean 9.8 ppg gelled brine displacement fluid w/ 2.5 gal EC1124A corrosion inhibitor. This sweeps any remaining solids from the mixing tub and lines and displaces into the well. d. - 44 bbls straight diesel /crude to fill up the annulus and displace the gel to the bottom of the void. 7. Notify Operations of well condition (note that the OA is now fluid packed). A yellow caution tag should be hung on the OA valve handle, clearly stating fluids pumped and date. Post Treatment Gel will take time to settle though existing OA fluid and seal off leak. Monitor the OA pressure and fluid level. A second treatment or OA load with crude or diesel is not uncommon. The OA fluid level may drop as the gel migrates downhole. TREE= GRAY GEN 3 WELLHEAD = GRAY O -� SAFETY NOTES: * ** 4 -1/2" CHROME TBG * ** ACTUATOR= AXELSON KB. ELEV = 58.0' BF.REV= KOP = 2000' 22' 5-1/2" X 4-1/2" XO UNDER TREE HGR Max Angle = 46 @ 8900' Datum MO = 10973' Datum TV D = 8800' SS 2125 4 -112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS 13 -318" CSG, 72 #, L -80, ID = 12.347" 2529' ST MD TVD DEV TYPE VLV LATCH PORT1 DATE 4 3441 3257 44 MMG DOME RK 16 09/03/09 3 6611 5593 44 MMG DOME RK 16 09/03/09 Minimum ID = 3.813" @ 2125' 2 8862 7204 45 MMG DOME RK 16 09/03109 1 10021 8069 37 MMG SO RK 28 09103/09 4 HES K NIPPLE 10092' 4 -112" I-ES X NIP, D = 3.813" 10112' 9 -5/8" X 4 -112" BKR S -3 PKR, ID = 3.875" 10137 4 -112" HES X NP, ID = 3.813" 10200' 4 -112" HES X NP, ID = 3.813" 4 -1/2" TBG, 12.6 #, 13CR80..0152 bpf, ID = 3.958" 10221 10221 4-1/2"X 5 -1/2" XO TO OVERSHOT, ID = XXXX TOP OF5 -1/2 ' (04/17105) 10220 10223 5- 1 /2 " UNIQUE OVERSHOT 10252' 4T11Z BAKER PBRASSY 10271 9 -5/8" X 5 -112" BAKER SAB PKR 5-1/2' TBG -PC, 17 #, L-800232 bpi, ID = 4.892" 10280' 10280' 5 112" X 4 -112" XO TOP OF 7" LNR 10286' 10341 4 -112" CAMCO DB -6 LANDING NIP, ID = 3.812" 10353' 4 -112" BAKER SHEAROUT SUB 4 -1/2" TBG -PC, 12.6 #, L- 80..0152 bpf, ID = 3.958" 10354 10354 4 -112" TUBING TAIL 4 MLOGGED /06/87 9-5/8" CSG, 47 #, L -80, ID = 8.681" 10587' PERFORATION SUMMARY REF LOG: BHCS ON 05/14/83 ANGLE AT TOP PERF: 32 @ 11088' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 1- 11/16" 4 11088 - 11118 S 11/18/83 3 318" 2 11096 -11116 O 09/06196 3 318" 4 11105 -11113 S 03/26/95 1- 11/16" 6 11122 - 11160 S 11/18/83 3 -3/8" 4 11128 -11142 O 09/06/96 3 -318" 6 11130 - 11140 S 07/06/88 3 -318" 4 11130 - 11142 O 06/27/96 3 -318" 6 11140 - 11160 S 07104188 ? ?? FASDRILL PLUG MILLED 05,�06l05 PBTD 11335' 7" LNR, 29 #, L-80 bpf, ID = 6.184" 1137T DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05118/83 ORIGINAL COMPLETION 10101 /09 CJNISV GLV GO (09103109) WELL: 07 -24 05106/05 JDM/TLH RINO PERMIT No: F 1830630 09/17/04 GJB/TLP GLV C/O API No: 50 -029- 20945 -00 12/15/04 RDJ /PAG WAIVER SAFETY NOTE SEC 33, T11N, R1 4E, 5099.58' FEL & 4.09' FNL 05/14105 KDCIPJC GLV C/O 07/31/05 1 TWCITLH I TBG DESCRErK)N ADDED BP Exploration (Alaska) STATE OF ALASKA) . !~":~. ......... .... .~. ALASKA J_ AND GAS CONSERVATION CO....q ISSION REt,EIVf::D REPORT OF SUNDRY WELL OPERATIONSJUN 062005 1. Operations Performed: o Aba ndon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028312 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 99519-6612 A'~sk~ Œ~ & :5ít¡3J o Other Imr.h@mge o Re-Enter Suspended Well ",,-ot¡;J o Time Extension ,\ ~ 5. Permit To Drill llber: 063 6. API Number: 50-029-20945-00-00 Cummí3~ìon o Suspend 0 Operation Shutdown 0 Perforate 1m Repair Well 0 Plug Perforations 0 Stimulate o Pull Tubing 0 Perforate New Pool 0 Waiver 58' 11377 9200 11172 9026 79' 2529' 10587' 1091' 4. Current Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 9. Well Name and Number: DS 07-24 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) Yes, Unknown feet Size MD TVD Burst 20" 79' 79' 1490 13-3/8" 2529' 2503' 4930 9-5/8" 10587' 8533' 6870 7" 10286' - 11377' 8284' - 9200' 8160 SCANNEC JUN 1 4 2005 Collapse 470 2670 4760 7020 11096' - 11142' 8962' - 9001' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", 12.6# x 5-1/2", 13Cr80 x L-80 17# x 4-1/2", 12.6# 9-5/8" x 5-1/2" Baker 'SAB' packer; 9-5/8" x 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'X' Nipple 10354' 10271'; 10112'; 2125' Treatment description including volumes used and final pressure: RBDMS 8Ft ,¡UN 072005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure 11,094 2,426 4,413 1,970 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 N/A Oil-Bbl Prior to well operation: 545 Subsequent to operation: 821 14. Attachments: 0 Copies of Logs and Surveys run 1m Daily Report of Well Operations 181 Well Schematic Diagram 13. Printed Name Terrie Hubble Signature~.ANJ¡~ ~ Form 10-404 Revised 04/2004 TubinQ Pressure 1,700 250 Title Technical Assistant o RIG I N jl!28 Date cµ/tf3/D5 Prepared By Name/Number: Terrie Hubble. 564-4628 Submit Original Only Well: Field: API: Permit: ') ) 04/29/05 N/A 05/05/05 Doyon 16 03/30/05 DRIFT W/4.5" CENT. TO 10,237' SLM. PULL PRONG FROM PLUG BODY AT 10,305' SLM. PULL PLUG BODY FROM 10,308' SLM. 07-24 Rig Workover Prudhoe Bay Unit 50-029-20945-00-00 183-063 Accept: Spud: Release: Rig: 04/16/05 SET 4.5" HES FASDRILL PLUG AT 10315' ELM. SHOT TUBING PUNCH FROM 10217' - 10219', JOB COMPLETE. PRE-RIG WORK 04/17/05 CHEMICALLY CUT 5.5" TUBING AT 10220' ELM USING 4-3/16" CHC. GOOD INDICATIONS OF CUT. JOB COMPLETE. ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -24 07 -24 WORKOVER DOYON DOYON 16 Hours Task Code NPT Phase 4/29/2005 00:00 - 01 :00 1.00 MOB P 01 :00 - 02:00 1.00 MOB P 02:00 - 04:30 2.50 MOB P Start: 4/29/2005 Rig Release: 5/5/2005 Rig Number: Spud Date: 4/30/1983 End: 5/5/2005 Description of Oþeratioms PRE R / D Floor, Cleared Pad Around Rig f/ Move. PRE Moved Rig Off of 14 - 15, Pulled to Center of Pad. PRE 04:30 - 07:00 2.50 MOB P 07:00 - 07:30 0.50 MOB P 07:30 - 10:30 3.00 MOB P 10:30 - 11 :30 1.00 MOB P 11 :30 - 12:30 1.00 MOB P 12:30 - 13:30 1.00 MOB P 13:30 - 14:00 0.50 MOB P 14:00 - 15:00 1.00 MOB P 15:00 - 18:30 3.50 WHSUR P 18:30 - 19:30 1.00 WHSUR P 19:30 - 20:00 0.50 KILL P 20:00 - 23:30 3.50 KILL P PRE PRE PRE PRE PRE PRE PRE PRE DECOMP DECaMP DECOMP DECOMP 23:30 - 00:00 0.50 WHSUR P DECOMP 4/30/2005 00:00 - 00:30 0.50 WHSUR P DECOMP 00:30 - 02:30 2.00 WHSUR P DECaMP 02:30 - 06:00 3.50 BOPSUP P DECOMP 06:00 - 06:30 0.50 BOPSUI P 1.50 BOPSUR N SFAL DECOMP DECOMP 06:30 - 08:00 P / U Stack, Hydril Rep Performed Annual Inspection of Lower Rams. N / D Annular Preventer and Lowered Same to Rig Mat. Secured Stack. PJSM. R / U Derrick Bridle Lines, Lowered Derrick. Held PJSM w/ Rig Crew and Security on Rig Move. Moved Rig from DS 14 to DS 7. Held PJSM. Raised and Pinned Derrick. Performed Full Derrick Inspection. R / D Bridle Lines, R / U and P 1 U Top Drive. R / U Drill Floor and Cattle Chute. N / U Hydril Annular Preventer. Spotted and Shimmed Rig Over 7 - 24. R / U Lines to 9-5/8" x 5-1/2" Annulus, R / U Circulating Manifold. Took On Seawater. Mixed Vis'd Detergent Sweeps. Held PJSM. R / U DSM Lubricator, Latched and Pulled BPV, R / D DSM Lubricator. Tubing Pressure 0 psi / Annulus Pressure o psi. Held PJSM w/ Rig Crew - Truck Drivers - Drilling Supervisor. R / U Trucks to Pits. Circulated Through Lines, Pressure Tested Lines to 2,000 psi, OK. Bled Down Pressure, Lined Up to Pump Down 9-5/8" x 5-1/2" Annulus and Take Returns Off of Tubing. Engaged Pump, Took 50 bbls to Establish Returns. Pumped 100 bbls of 140 deg Seawater Down Annulus to Displace Diesel from Tubing. Pump Rate 5 bpm, 1,800 psi, Took Returns to Slop Tank. Shut Down Pump and Lined Up to Pump Down Tubing and Take Returns off of 9-5/8" x 5-1/2" Annulus. Pumped 40 bbl Vis'd Detergent Sweep, Followed by 800 bbls 140 deg Seawater, Initial Circulation Rate 10 bpm, 1,530 psi. After Pumping 250 bbls, Slowed Pump Rate to 6 bpm, 400 psi to Maintain Safe Fluid Level in Slop Tank. Shut Down Pump, Monitored Well, Fluid Dropping in Well bore. Blew Down and Rigged Down Lines. R / U DSM Lubricator. Set BPV, R / D DSM. Attempted to Test BPV from Below to 1,000 psi, Well Taking Fluid. Held PJSM. N / D Tree and Adapter Flange. Worked on Adapter Flange Studs. Bled Down and Terminated Control Lines. Installed Blanking Plug in BPV. N / U BOPE: 13-5/8" 5M GK Annular Preventer, 13-5/8" 5M Blind Shear Rams, Mud Cross w/ Kill and Choke Lines, 13-5/8" Lower Pipe Rams w/ 3-1/2" x 6" Variable Rams. N / U Riser and Installed Flow Line. Held PJSM. R / U BOPE Test Equipment, M / U Test Joint w/ XO. RIH and M / U to Tubing Hanger. Filled BOP Stack, Closed Annular and Attempted to Perform Body Test on BOP Stack without Success. Pulled Test Joint and Inspected Threads and XO. Reran Test Joint and M / U to Tubing Hanger. Attempted to Perform Body Test on BOP Stack Printed: 5/9/2005 11 :29:49 AM ') ) BPEXPL..OffiAIIØN Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -24 07 -24 WORKOVER DOYON DOYON 16 Start: 4/29/2005 Rig Release: 5/5/2005 Rig Number: CödeNPT Phasë Spud Date: 4/30/1983 End: 5/5/2005 4/30/2005 06:30 - 08:00 1.50 BOPSURN SFAL DECOMP without Success. Tubing Hanger and / or BPV w/ Blanking Plug Leaking. 08:00 - 09:00 1.00 BOPSUP N SFAL DECOMP R / D BOP Test Equipment, Pulled and L / D Test Joint. Discussed Situation with AOGCC Rep Chuck Scheve and Drilling Superintendent Steve Rossberg. Decision Made to Pull Tubing Hanger plus 3 Joints of Tubing, Run and Set RTTS w/ Storm Valve and Utilize Test Plug to Test BOPE. 09:00 - 10:00 1.00 WHSUR N SFAL DECOMP R / U T-Bar, Latched and Pulled Blanking Plug. R / U DSM Lubricator, Latched and Pulled BPV, R / D DSM Lubricator. Well bore on Strong Vacuum. Pumped 150 bbls in Attempt to Fill Hole, Unsuccessful. 10:00 - 10:30 0.50 PULL N SFAL DECOMP Held PJSM. M / U Baker Spear w/ Double 4.805" Grapples and Packoff. M / U Spear Assy to 4" DP. RIH and Speared Tubing. P / U w/ 10,000# Overpull to Ensure Grapples Fully Engaged. BOLDS. Applied Steam to Wellhead. 10:30 - 12:30 2.00 PULL N SFAL DECOMP Picked Up on Spear to 200,000#, No Movement. Worked Spear Assy from 100,000# to 200,000# x 4, No Movement. Picked Up on Spear to 250,000#, No Movement. Worked Spear Assy from 50,000# to 250,000# x 5, No Movement. Picked Up on Spear to 300,000#, No Movement. Worked Spear Assy from 50,000# to 300,000# x 10, No Movement. Picked Up on Spear to 325,000#, No Movement. Worked Spear Assy from 50,000# to 325,000# , No Movement. Continued to Work Spear from 50,000# to 325,000# with No Success. 12:30 - 16:30 4.00 PULL N SFAL DECOMP Released Spear and POOH. M / U Fishing Jars Between Spear Assy and 4" DP. RIH Engaged Grapples. Jarred on Tubing Hanger w/ 175,000# - 200,000#. Jarred Averaged of 20 / Hour, No Success. Drained Stack, Poured 10 gallons of Oil and 10 gallons of Diesel on Top of Hanger. Allowed to Soak. Resumed Jarring w/ 175,000# - 200,000#, No Success. 16:30 - 18:30 2.00 PULL N SFAL DECOMP Drained Stack, Cameron Pulled LDS 1 x 1 to Ensure All Lock Downs were Backed Out. 18:30 - 20:00 1.50 PULL N SFAL DECOMP RIH Engaged Grapples. Jarred on Tubing Hanger wI 175,000# - 200,000#. Jarred Averaged of 20 / Hour, No Movement. 20:00 - 22:00 2.00 PULL N SFAL DECOMP Released Spear, B / 0 and L / D Jars. Repaired Top Drive Pipe Handler Guide Bearings. Inspected Derrick and Top Drive. 22:00 - 00:00 2.00 PULL N SFAL DECOMP RIH and ReEngaged Grapples. Poured 10 gallons of Oil and 10 gallons of Diesel on Top of Hanger. Allowed to Soak. Worked Spear Assy from 50,000# to 325,000# , No Movement. Continued to Work Spear from 50,000# to 325,000# with No Success. 5/1/2005 00:00 - 05:30 5.50 PULL N SFAL DECOMP Worked Spear Assy from 50,000# to 325,000# , No Movement. Continued to Work Spear from 50,000# to 325,000# with No Success. Continued to Apply Steam to Wellhead. 05:30 - 09:00 3.50 PULL N SFAL DECOMP Released and POOH w/ Spear. Lowered Steam Hose Downhole to Top of Tubing Hanger. Applied Steam Directly to Tubing Hanger. 09:00 - 09:30 0.50 PULL N SFAL DECOMP M / U Spear Assy: Spear w/ Double 4.805" Grapples - Fishing Jars - Accelerator Jars - XO - TIW Valve - 1 Jt 4" DP. 09:30 - 10:00 0.50 PULL N SFAL DECOMP RIH w/ Spear and Engaged Tubing. Jarred Up w/ 150,000#, Pulled to 300,000#, No Movement. Reset Jars, Jarred Up w/ 175,000#, Pulled Up to 225,000#, Tubing Hanger Came Off Printed: 5/9/2005 11 :29:49 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -24 07 -24 WORKOVER DOYON DOYON 16 Start: 4/29/2005 Rig Release: 5/5/2005 Rig Number: Spud Date: 4/30/1983 End: 5/5/2005 Code·· NPT 5/1/2005 09:30 - 10:00 0.50 PULL N SFAL DECOMP Seat. Pulled Tubing Hanger to Rig Floor wi 215,000# Up Weight. 10:00 - 11 :00 1.00 PULL P DECaMP Held PJSM. B I 0 Spear from Tubing Hanger. B I 0 and LID Spear, Jars, Accelerator Jars, XO, TIW Valve and 4" DP. Terminated Control Lines at Tubing Hanger. B I 0 and LID Tubing Hanger. 11 :00 - 12:00 1.00 PULL P DECOMP Held PJSM. R I U 5-1/2" Tubing Handling Equipment. 12:00 - 13:00 1.00 PULL P DECOMP POOH, LID 3 Jts 5-1/2" Tubing. Spooled Up Control Line. Terminated Control Line at Jt #4 and Banded Control Line to Same. 13:00 - 13:30 0.50 PULL P DECaMP Held PJSM. M I U 9-5/8" RTTS Packer wi Storm Valve, XO. RIH wi RTTS to 80'. String Weight Up 200,000#, String Weight Down 155,000#. Set RTTS and Released from Same. Filled the Hole, Closed Annular and Tested RTTS from Above to 1,500 psi, OK. Bled Down Pressure. POOH, B I 0 Running Tool from DP Racked DP in Derrick. 13:30 - 14:30 1.00 BOPSUPP DECOMP Held PJSM. R I U BOPE Test Equipment. M I U Test Plug and Joint, RIH and Set. 14:30 - 17:30 3.00, BOPSUR P DECOMP Tested BOPE. Tested Annular Preventèr, Lbwer Rams,Blind Rams, Choke Manifold and Valves, HCR's, Kill Line, Choke Line, Floor Valves and IBOPs to 3,500 psi High I 250 psi Low. All Tests Held fl 5 Min. All Pressure Tests Held wi No Leaks or Pressure Loss. All Tests Witnessed by AOGCC Rep. Chuck Scheve and BP Drilling Supervisor. 17:30 - 18:00 0.50 BOPSURP DECOMP Retrieved Test Plug. RID BOPE Test Equipment. Blew Down All Lines. 18:00 - 18:30 0.50 DHB P DECOMP M I U RTTS Retrieving Tool to 4" DP. RIH, Latched and Released RTTS. Monitored Well, POOH, B I 0 and LID RTTS and Storm Valve. 18:30 - 20:30 2.00 PULL P DECaMP M I U Circulating Head and Lines. Pumped and Circulated Around 40 bbl Hi-Vis Detergent Sweep. Pump Rate 10 bpm, 970 psi. Pumped 100 bbls to Gain Circulation. No Gas to Surface on Bottoms Up. R I U Camco Control Line Spooling Equipment While Circulating. 20:30 - 00:00 3.50 PULL P DECOMP POOH, B I 0 and LID 5-1/2" 17# L-80 8rd Tubing. Spooled Up Dual Encapsulated Control Line. 5/2/2005 00:00 - 00:30 0.50 PULL P DECOMP POOH, B I 0 and LID a Total of 52 Joints of 5-1/2" 17# L-80 8rd Tubing. Spooled Up Dual Encapsulated Control Line. 00:30 - 01 :00 0.50 PULL P DECaMP RID Camco Spooling Equipment, B I 0 and LID SSSV Assy. 01 :00 - 10:00 9.00 PULL P DECaMP POOH, B I 0 and LID 5-1/2" 17# L-80 8rd Tubing. Total Recovery: 241 Jts 5-1/2" 17# L-80 8rd Tubing, 1 - Cut Joint = 20.18',10 - GLM Assys, 1 - SSSV Assy, 2,151' Dual Encapsulated Control Line, 27 of 27 Control Line Clamps and 2 of 4 SS Bands. 10:00 - 10:30 0.50 PULL P DECOMP RID Tubing Handling Equipment, Cleared and Cleaned Rig Floor. 10:30 - 11 :00 0.50 PULL P DECOMP Held PJSM. Brought BHA Components to Rig Floor. 11 :00 - 13:30 2.50 CLEAN P DECOMP M I U DressOff Mill BHA. 8-1/2" x 5-1/2" Shoe - 2 x Wash Pipe Ext - Triple Connection Bushing wi Dressoff Mill - Double Pin XO - 2 x Junk Baskets - 9-5/8" Csg Scraper - Bit Sub - Bumper Jars - Oil Jars - XO - 12 x 4-3/4" DC - 21 Jts 4" HWDP. Total BHA Length 1,070.62' Printed: 5/9/2005 11 :29:49 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -24 07-24 WORKOVER DOYON DOYON 16 Start: 4/29/2005 Rig Release: 5/5/2005 Rig Number: Spud Date: 4/30/1983 End: 5/5/2005 Frönt"To Hours Task Cöde NPT Phase 5/2/2005 13:30 - 21 :00 7.50 CLEAN P DECOMP RIH wi DressOff BHA on 4" DP, PI U Drill Pipe 1 x 1 From Pipe Shed, Rabitted All Pipe. RIH to 10,150'. 21 :00 - 22:30 1 .50 CLEAN N RREP DECOMP Work On Top Drive, Install New Air Lines for IBOP 22:30 - 23:30 1.00 CLEAN P DECOMP M/U Top Drive and Establish Parameters, Break Circulation at 50 spm 1650 psi. String Weight Up 215,000#, String Weight Down 142,000#, Rotatry String Weight 172,000#. Wash Down fl 10,150' and Tag Tbg. Stub at 10,220'. P/U 10' and Rotate Down with 100 rpm and 12,000 ft/lbs Torque. Rotate and Washover Stub to 10,231' (11' swallow). Observe 75 psi. Pressure Increase When Overshot Extension Bottomed out @ 10,231'. Dress Stub with 100 rpm and 14,500 ft/lbs Torque. P/U t/ 10,210' and SIO WIO Rotating or Pumping t/ 10,231' wlo Any Problems 23:30 - 00:00 0.50 CLEAN P DECOMP Establish Reverse Circulation at 6 bpm. Fluid Loss of 2 bpm. Unable to Sustain Pump Rate Because of Fluid Losses. Pumped 40 bbl Hi-Vis Detergent Sweep Long Way. 5/3/2005 00:00 - 01 :30 1.50 CLEAN P DECOMP Circulate Hi-Vis Detergent Sweep Around at 10 bpm 12,500 psi. 01 :30- 06:00 4.50 CLEAN P DECOMP POH wi 5-1/2" Dress Off BHA 06:00 - 07:30 1.50 CLEAN P DECOMP Break out & LID BHA #1. Clear & clean rig floor. Empty Junk Baskets. No Recovery. 07:30 - 08:00 0.50 CLEAN P DECOMP Hold PJSM. P/U & strap 9 5/8" RTTS wi circulating sub & M/U on DCs. 08:00 - 12:30 4.50 CLEAN P DECOMP RIH wi DCs, HWDP & 4" DP to 10161' 12:30 - 14:00 1.50 CLEAN P DECOMP Space out & set RTTS wi 20K down weight @ 10155'. Fill 9 5/8" x 31/2" DP annulus. Close annular & Pressure test 9 5/8" casing to 3500 psi. for 30 min. Charted test. Test good. P/U, Unset & equalize RTTS. 14:00 - 17:30 3.50 CLEAN P DECOMP POOH wi RTTS & stand back DP & HWT 17:30 - 18:30 1.00 CLEAN P DECOMP POH Laying Down DC's and RTTS 18:30 - 19:00 0.50 CLEAN P DECOMP Clear and Clean Floor 19:00 - 21 :00 2.00 CLEAN P DECOMP P/U & M/U Mill Assy., 3-5/8" Junk Mill, Shear Thru Guide, 6 x 2-7/8" PAC DP., XO Sub, XO Sub, Bumper Sub, Oil Jars, XO Sub, 21 x 4" HWT DP. Total Length = 864.59' 21 :00 - 22:00 1.00 CLEAN P DECOMP PJSM-Slip and Cut Drlg. Line 22:00 - 00:00 2.00 CLEAN P DECOMP RIH wi 3-5/8" Junk Mill Assy. on 4" DP 5/4/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP RIH wi 3-5/8" Junk Mill BHA on 4" DP t/ 10,210' 01 :00 - 03:00 2.00 CLEAN P DECOMP Establish Milling Parameters. Circulating rate 6.5 bpml 2250 psi., String Weight up 198,000#, String Weight Down 142,000#, Rotating String Weight 165,000#, Rotary 60 rpm @ 7,000 ft/lbs Torque. Wash Down fl 10,210' and Tag 5-1/2" Tbg Stub at 10,220' wi 8-1/8" Shoe Extension. Wash Over Same. Rotate Mill Down and into Stub and Tag Fasdrill @ 10,311'. Mill Fasdrill wi 45 rpml 10,000 ft/lbs Torque, 3-5 K Weight on Mill. Push Fasdrill Out 4-1/2" Tgb Tail. Lost Total Circulation. 03:00 - 13:00 10.00 CLEAN P DECOMP POH wI 3-5/8" Junk Mill BHA, LID DP, Using Double Displacement on Dp for Hole Filling 13:00 - 13:30 0.50 CLEAN P DECOMP Clear & clean rig floor. 13:30 - 14:30 1.00 RUNCOtvP RUNCMP Pull Wear bushing. RID DP tools. R/U 4 1/2" tubing tools & torque turn equipment. 14:30 - 15:00 0.50 RUNCOtvP RUNCMP Hold PJSM wi all hands. Review completion running procedure. 115:00 ~ 00:00 9.00 RUNCOí RUNCMP P/U and RIH wi Unique Machine Overshot Assy., 4 x "x" Nipple Printed: 5/9/2005 11 :29:49 AM ') ') Start: 4/29/2005 Rig Release: 5/5/2005 Rig Number: Phase RUNCMP Assy's. Baker S-3 Permanent Packer, 4 x 4-1/2" GLM Assy's. 165 jts. 4-1/2" 12.6# 13Cr80 Vam Top Tbg. RUNCMP RIH wi 4-1/2" 12.6# 13Cr80 Vam Top Tbg. 237 jts. total. M/U Torque 4440 ft/lbs RUNCMP String Weight Up 160,000#, String Weight Down 115,000#, P/U jts. 238 & 239 for Space Out Measurements.. Btm'd Out 26' in on jt. # 239. Obsereved Overshot Shear pins shear at 21' in on jt.# 239. LID Jts. 239, 238 and 237. P/U 8.08',10.17', 19.19' 12.6# 13Cr80 Vam Top pup jts. Change Out Elevators and P/U Hgr., Ldg. Jt. and M/U same. RIH and Land Tbg Hgr. RILDS. Tbg. Hgr. Thread 5-7/8" RH ACME. BPV Profile-Vetco Gray "K" Type. R/U Circulating Lines to IA and Tbg. Test lines to 3500 psi, OK. Reverse circulate 550 Bbls of 120 degree inhibited seawater. Pump @ 3 BPM, 950 psi. RID head pin. Drop Ball/Rod. Allow to fall. R/U head pin. Hold PJSM. Pressured up to test packer & pump pop off sheared @ 3200 psi. apparently pin had waekened. Changed out pop off. Pressure up on tubing. Set packer & test tubing to 3500 psi for 30 min. Bled off tubing pressure to 1500 psi. & SI. Fill annulus wi 30 Bbls. Pressure up on 9 5/8" x 4 1/2" annulus to 3500 psi & hold for 30 min. Rapidly bled off tubing pressure & DCR-SV sheared. Tubing & annlus bled off to 0 psi. Pump down tubing and annuluus to insure of good clean shear. 3 BPM @ 180 psi. Charted entire test. Blow down lines. RID lines & test equip. LID landing jt. Drain BOP stack. Set & test TWC. Test to 1000 psi, Ok. N/D BOPE. N/U adpter flange & X-mas tree. Test tree & adapter to 5000 psi, OK. R/U DSM Lubricator and Pull TWC. RID Lubricator R/U Circulating Lines to Reverse Circulate Freeze Protection Down IA. Test Lines t/ 2,500 psi. Pump 140 bbls Diesel Down IA taking returns to slop tank. Pump rate 2 bpm with 400 psi final circulating pressure. U-Tube Freese Protection from IA to Tbg. RID Circulating Lines Install BPV and Test from Below t/ 1,000 psi. Remove Secondary Annulas Valve and Secure Tree. Released Rig at 2400 hrs. 5/5/05 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -24 07 -24 WORKOVER DOYON DOYON 16 Date From-To Ho lJ rs Task Code NPT 5/4/2005 15:00 - 00:00 9.00 RUNCOrvP 5/5/2005 00:00 - 03:30 3.50 RUNCOMP 03:30 - 05:00 1.50 RUNCOrvP 05:00 - 06:00 1.00 RUNCOMP RUNCMP 06:00 - 10:00 4.00 RUNCOrvP RUNCMP 10:00 - 10:30 0.50 RUNCOrvP RUNCMP 10:30 - 13:30 3.00 RUNCOMP RUNCMP 13:30 - 14:00 0.50 WHSUR P RUNCMP 14:00 - 14:30 0.50 WHSUR P RUNCMP 14:30 - 15:30 1.00 BOPSUR P RUNCMP 15:30 - 19:30 4.00 WHSUR P OTHCMP 19:30 - 20:00 0.50 WHSUR P OTHCMP 20:00 - 21 :00 1.00 WHSUR P OTHCMP 21 :00 - 22:30 1.50 WHSUR P OTHCMP 22:30 - 23:30 1.00 WHSUR P OTHCMP 23:30 - 00:00 0.50 WHSUR P OTHCMP Spud Date: 4/30/1983 End: 5/5/2005 Printed: 5/9/2005 11 :29:49 AM TREE = GRA Y GEN 3 wELLHEÀD'; GRA Y "ÃCYùATOR = AXELSÖÑ ·ï<S:äE\i; . . . sä.·öï BF. ELEV = ? KOP = 2000' .."""..."""..."........"...".".." '" rv1~~.t\n~I:= . 46 @ 8900' Datum MD =16973' .....".". "".."..." "".."".."..". "". Datum 1VD = 8800' SS ) 07 -24 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2529' ~~ Minimum ID = 3.813" @ 2125' 4-1/2" HES X NIPPLE . :8: TOPOF 5-1/2" (04/17/05) I.., 10220' I I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I.., 10280' TOP OF 4-1/2" TBG-PC 1-1 10280' 1 TOP OF 7" LNR 1-1 10286' z ~ ST MD 1VD 4 3441 3257 3 6611 5593 2 8862 7204 1 10021 8069 l.. .J . . L I I \j . Z & \ / . . . . 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 10354' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10587' ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 05/14/83 A NGLE AT TOP ÆRF: 32 @ 11088' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 4 11088 - 11118 S 11/18/83 33/8" 2 11096 - 11116 0 09/06/96 3 318" 4 11105 - 11113 S 03/26/95 1-11116" 6 11122 - 11160 S 11/18/83 3-3/8" 4 11128 - 11142 0 09/06/96 3-3/8" 6 11130-11140 S 07/06/88 3-3/8" 4 11130-11142 0 06/27/96 3-3/8" 6 11140 - 11160 S 07/04/88 I \ I PBTD I'" 11335' 17" lNR, 29#, L-80, .0371 bpf, ID = 6.184" l-f 11377' ., ~ DA TE REV BY COMMENTS DA TE REV BY 05/18/83 ORIGINAL COM PLETION 05/06/05 J DM/TLt- RWO 09/17/04 GJB/TLP GLV C/O 12/15/04 RDJ/PAG WAIVER SAFETY NOTE 05/13/05 ATO/PJC 97WAIVERSF1Y NOTE REMOVED 05/14/05 KOC/PJC GL V C/O I COMMENTS .. ) SAr-I:: TV NOTES: -122'1"'5-1/2" X 4-1/2" XO UNDER TREE HGR, ID = 3.958" 1 2125' 1"'4-1/2" HES X NIP, ID = 3.813" I GA S LIFT MA NDRELS DEV ìYÆ VLV LATCH 44 MMG DOME RK 44 MMG OR RK 45 MMG DMY RK 37 MMG DMY RK DATE 05/14/05 05/14/05 05/04/05 05/04/05 PORT 16 o o o 10092' 1"'4-1/2" HES X NIP, ID = 3.813" I 10112' 1"'9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10137' 1-f4-1/2" HES X NIP, ID = 3.813" 1 10200' 1"'4-1/2" HES X NIP, ID = 3.813" 1 10221' 1"'4-1/2"X5-1/2"XOTOOVERSHOT,ID=XXXX 1 10223' 1"'5-1/2" UNIQUE OVERSHOT 1 10252' 1"'5-1/2" BAKER PBRASSY 1 10271' 1"'9-5/8" X 5-1/2" BA KER SA B PKR 1 10280' 1-15-1/2" X 4-1/2" XO 1 I I 10341' 1-14~1/2" GAMCODB-6 LANDING NIP, ID = 3.812" 1 10353' 1"'4-1/2" BAKER SHEA ROUT SUB I 10354' 1"'4-1/2" TUBING TAIL 1 1 10340' I.., ELMD TT LOGGED 04/06/87 ??? I.., FASDRILL PLUG MILLED 05/06/05 1 PRUDHOE BAY UNrr WELL: 07-24 ÆRMrr No: "1830630 API No: 50-029-20945-00 SEC 33, T11 N, R14E, 5099.58' FEL & 4.09' FNL BP Exploration (Alas k a) .---... STATE OF ALASKA .--- ALASKA-£ . AND GAS CONSERVATION COM..JSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing ~ Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1869' FNL, 244' FEL, Sec 33, T11 N, R14E, UM. At top of productive interval 5119' FNL, 4802' FEL, Sec 33, T11N, R14E, UM. At effective depth At total depth 5' FNL, 5092' FEL, Sec 4, T10N, R14E, UM. 5. Type of Well Development Exploratory Stratigraphic Other 6. Datum of elevation(DF or KB) 58 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-24 9. Permit number/approval number 83-63 10. APl number 50 - 029-20945 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11377 feet 9200 feet Plugs(measured) PBTD @ 11222' MD (10/23/96) Effective depth: measured 11222 feet true vertical 9069 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 79' 20" 1900# Poleset 79' Sudace 2471' 13-3/8" 2050 Sx Fondu & 400 Sx PFC 2529' Production 10529' 9-5/8" 500 Sx CI C & 300 Sx PFC 10587' Liner 1091' 7" 350 Sx CIG 11377' True ve~icaldepth 79' 2503' 8533' 9200' RECEIVED Perforation depth: measured 11096- 11116'; 11128 - 11142' 1,~0~..l 0 - - true vertical 8961 8978'; 8989 9001' Alaska 0il & C-~s Corm. 6,,.nm, ..... o[~ Tubing (size, grade, and measured depth) 5-1/2", 17#, IPC, L-80, PCT @ 10280' MD; 4-1/2", 12.6~,"~?Sb~'Tbg @ 10354' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 10271' MD; Camco Bal-O SSSV @ 2151' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 172 1154 318 796 4610 2226 Tubing Pressure 223 277 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. Form 10-404 Rev 06/15/88 Title Engineering Supervisor Date //?-/---~--~, SUBMIT IN DUPLICAT~ 7-24 DESCRIPTION OF WORK COMPLETED FULLBORE ACID STIMULATION TREATMENT I 0/23/96: RIH & tagged PBTD at 11222' MD. I 0/27/96: A Fullbore Acid Stimulation Treatment was performed as follows: MIRU & PT equipment. Pumped stimulation fluids through the perforation intervals located at: 11096 - 11116' MD (Z2) Ref. Log: BHCS 5/14/83. 11128 - 11142' MD (Z2) Pumped: a) 100 bbls 2% KCI Water @ 5 bpm, followed by b) 40 bbls 50% Diesel/50% Xylene w/5% Musol @ 2 bpm, followed by c) 40 bbls 12% HCI w/10% Xylene @ 3 bpm, followed by d) 20 bbls 9% HCI - 1% HF @ 3 bpm, followed by e) 20 bbls 12% HCI w/10% Xylene @ 3 bpm, followed by f) 10 bbls 3% NH4CI Water w/10 ppb Benzoic Acid Flake diverter @ 3 bpm, followed by g) 40 bbls 12% HCI w/10% Xylene @ 3 bpm, followed by h) 20 bbls 9% HCl - 1% HF @ 3 bpm, followed by i) 20 bbls 12% HCl w/10% Xylene @ 3 bpm, followed by j) 120 bbls 2% NH4CI Water Overflush w/5% Musol @ 3 bpm, followed by k) 270 bbls Crude displacement @ 3 bpm, followed by I) 6 bbls Diesel, followed by m) Shutdown. Rigged down. 1 0/3 1/96: Pumped a scale inhibition treatment. Returned the well to production w/lift gas & obtained a valid welltest. STATE OF ALASKA ALASKA C""-"'AND GAS CONSERVATION CON ,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X~ Pull tubing Alter casing Repair well Olher 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1869' FNL, 244' FEL, Sec 33, T11N, R14E, UM. At top of productive interval 5119' FNL, 4802' FEL, Sec 33, T11N, R14E, UM. At effective depth At total depth 5' FNL, 5092' FEL, Sec 4, T10N, R14E, UM. 5. Type of Well Development Exploratory Strafigraphic 6. Datum of elevation(DF or KB) 58 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-24 9. Permit number/approval number 83-63 10. APl number 50 - 029-20945 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11377 feet 9200 feet Plugs(measured) PBTD @ 11233' MD (6/27/96) Effective depth: measured 11233 feet true vertical 9078 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1900# Poleset 79' 79' Sudace 2471' 13-3/8" 2050 Sx Fondu & 400 Sx PFC 2529' 2503' Production 10529' 9-5/8" 500 Sx Cl C & 300 Sx PFC 10587' 8533' Liner 1091' 7" 350 Sx Cl G 11377' 9200' Perforation depth: measured 11096 - 11116'; 11128 - 11142' true vertical 8961 - 8978'; 8989 - 9001' Tubing (size, grade, and measured depth) 5-1/2", 17#, IPC, L-80, PCT @ 10280' MD; 4-1/2", 12.64t, L-80, Tbg @ 10354' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 10271' MD; Camco Bal-~[~ ~~{~ ~I.~'!~D. 13. Stimulation or cement squeeze summary Intervals treated(measured)see Attached a resRs ! ! N b' Treatment description including volumes used and fin u e 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 Tubing Pressure - Subsequent to operation 275 1970 961 232 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 '~,~4..~ ~,'[~ . (~F,--~ Title Engineering Supervisor :orm 10404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 7-24 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/6/96: MIRU & PT equipment. Reperforated: 11096 o 11116' MD (Z2) 11128 - 11142' MD (Z2) RIH w/perforating guns & shot 34' of reperforations as follows: Ref. Log: BHCS 5/14/83. Used 3-8/8" carriers & shot upper interval at 2 spf at 180 degree phasing at underbalanced pressure. Shot lower interval at 4 spf at 60/120 degree phasing at underbalanced pressure. POOH w/perf guns. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. ,'--'-' STATE OF ALASKA ~--' ALASKA O,- AND GAS CONSERVATION COMIvlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing ~ Alter ~tsing 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 1869' FNL, 244' FEL, Sec 33, T11 N, R14E, UM. At top of productive interval 5119' FNL, 4802' FEL, Sec 33, T11 N, R14E, UM. At effective depth At total depth 5' FNL, 5092' FEL, Sec 4, T10N, R14E, UM. 5. Type of Well Development X~ Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 58 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-24 9. Permit number/approval number 83-63 10. APl number 50 - 029-20945 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11377 feet Plugs(measured)PBTD @ 11233' M.,.~D (6,~/27,/96,.), . . __ __ true vertical 9200 feet UR/GINAL Effective depth: measured 11233 feet true vertical 9078 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1900# Poleset 79' 79' Surface 2471' 13-3/8" 2050 Sx Fondu & 400 Sx PFC 2529' 2503' Production 10529' 9-5/8" 500 Sx CI C & 300 Sx PFC 10587' 8533' Liner 1091' 7" 350 Sx CIG 11377' 9200' Perforation depth: measured 11130 - 11142' true vertical 8990 - 9000' Tubing (size, grade, and measured depth) 5-1/2", 17#, IPC, L-80, PCT @ 10280' MD; 4-1/2", 12.6#, L-80, Tbg @ 10354' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 10271' MD; Camco BaI-O S~'(i~l~,.r~ 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure JUL I 2 1996 Alaska 0il & ~3as Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 822 14972 1786 558 3729 0 Tubing Pressure 897 295 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 ~.~. ~'~"x,~..,J..._ L~. ZS--.///4. O/0~ Title Engineering Supervisor Form 10-z~04 Rev'06/1~,~88 Date ~h/~~ SUBMIT tN DUPLICATE 7-24 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER & GAS SHUTOFF 5/22/96: RIH & tagged PBTD at 11232' MD. 6/14/96: A Pre Squeeze Acid Wash was performed as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/CT nozzle & loaded the wellbore w/1% KCI Water. Reciprocated wash fluids across the open perforation located at: 11105 - 11113' MD (Z2) 11130 - 11160' MD (Z2) Ref. Log: BHCS 5/14/83. Pumped: a) 10 bbls Xylene, followed by b) 25 bbls 12% HCI w/10% Xylene & 3% Acetic Acid @ 2.3 bpm, followed by c) 1% KCI Water Flush, followed by d) Shutdown. POOH w/CT. Rigged down. 6/15/96: A CTU Cement Squeeze for Water & Gas Shutoff was performed as follows: MIRU & PT equipment. RIH w/CT loading the well w/1% KCL Water. Acid Resistive cement to squeeze the open perforations (listed above). Switched to pumping Latex Pumped 38 bbls of cement & placed an estimated total of 21 bbls behind pipe at 3000 psi maximum squeeze pressure. Took several pressure breaks, then held a 2350 psi final squeeze pressure for 90 minutes. Contaminated cement w/biozan & jetted contaminated cement from well to 11250' MD. POOH w/CT. Rigged down. 6/27/96: RIH w/perforation gun to tag PBTD at 11233' MD, then PU & reperforated the well at: 11130 - 11142' MD (Z2) Ref. Log: BHCS 5/14/83. Used a 3-3/8" carrier & shot the perfs at 4 spf at 90 degree phasing with the well underbalanced. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid production welltest. Note: Oil rate decreased by 264 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 750 BOPD, resulting in a net oil benefit of 486 BOPD. RECEIVED JUL 1 2 1996 Alaska Oil & Gas Con~. Cornrni~sio~ Anchorage ~--. STATE OF ALASKA .~. ALASK OILAND GAS CONSERVATION t. MMISSlON 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 1869' FNL, 244' FEL, Sec. 33, T11N, R14E, UM At top of productive interval 5119' FNL, 4802' FEL, Sec. 33, T11N, R14E, UM At effective depth At total depth 5' FNL, 5092' FEL, Sec. 4, T11N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 11377 feet 9200 feet 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 58' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-24 9. Permit number/approval number 83-63 10. APl number 50 - 029-20945 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 11234 feet true vertical 9079 feet Plugs(measured) PBTD Tag @ 11234' M D (3/26/95) dunk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1900 # Poleset 79' 79' Surface 2471' 13-3/8" 2050 sx Fondu & 400 sx PFC 2529' 2503' Production 10529' 9-5/8" 500 sx Class C & 300 sx PFC 10587' 8533' Liner 1091' 7" 350 sx Class G 11377' 9200' Perforation depth: measured 11105-11113'; 11130-11160' true vertical 8969-8976'; 8990-9016' Tubing (size, grade, and measured depth) 5-1/2", 17#, IPC, L-80, PCT @ 10280' MD; 4-1/2", L-80, 12.6::4¢, tubing tail @ 10354' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 10271' MD; Camco BaI-O SSSV @ 2151' 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 Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 884 10756 1661 891 10205 1596 Tubing Pressure 377 377 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil~ Gas __ Suspended __ Service 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 ,-,,,- · IX'7 I~AID SUBMIT~N t~UPLICATE O~ 7-24 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/26/95 - MIRU & PT equipment. RIH w/perforating gun & tagged PBTD at 11234' MD, then PU & shot 8' of reperforations as follows: Reperforated: 11105 - 11113' MD (Z2) Ref. Log: BHCS 5/14/83. Used a 3-8/8" carrier & shot 4 spf at 90 degree phasing at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RE¢£1VED APR 1 2. 1995 Naska Oil & Gas Cons. Commission GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie RECEIVED APR 1 2 1995 Alaska Oil & Gas Cons. Commission Anchorage NO. 9391 Company: 4/11/95 Alaska Oil & Gas Cons Corem 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. 6-9 ~ 95055 ICNTD 01 2395 1 D.S. 4-35 ~ 95085 DUAL BURST-TDT-P 022895 1 D.S. 14-3 '"'J 94187 REDO CNTD 032894 1 D.S. 2-16ATM 95147 REDO MWDGR 102394 1 . , D.S. 1-06 "'J 94399 REDO DUAL BURST TDT-P 061394 1 D,S, 4-19 '"J 95106 DUAL BURST TDT-P 031795 1 ., , D.S. 9-36 BL'''''J 95025 MWDGR 101294 1 D.S. 1-06A"---J CBT 032495 I 1 D.S. 1-06A"'-J CNTG 032495 I 1 D.S. 1-22A ~--J PERF RECORD 033095 I 1 D.S. 4-12''''''-~ CBT '032695 1 1 D.S. 4-12 ~ TUBGPUNCHER RECORD 032395 I 1 D.S. 6-8 ~ PERF RECORD 032595! I 1 D.S. 7-24 "--J PERF RECORD 032695 I 1 D.S. 11-27 ",-4 BASE LINE SURVEY 032395 I I , , D.S. 9-36 BL''-d MWD GR (MD) 1 021 94 I 1 D~S. 9-36 BL "'J MWD GR (TVD) 102194 I 1 DrS. 9-36 EL ~ MWDGTF(MD) 102194 1 1 · PLEASE NOTE: D.S. 14-3 REDO - ORIGINAL WAS MISSING FILE #4 D;S. 2-16A REDO - MERGED TWO PREVIOUS RUNS TOGETHER (JOB # 93560 & 93561) .... Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: No. 9190 SCHLUMBERGER GEOQUEST INTERPRETATION AND COMPUTING SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY · LOCATION · ATTENTION · WELL NAME · SERVICES · AK OIL & GAS CONS COMM 3001 PORCUPINE DRIVE LARRY GRANT D.S. 7-24 (REDO) I TDTP FLOPPY DISK DATE · 1-17-95 WELL NAME · SERVICES · NO. OF BOXES: JOB NO. : ADD'L TAPES : PLEASE NOTE: WELL NAME : SERVICES : ONE ENVELOPE NO. OF BOXES: 94240 JOB NO. ' -- ADD'L TAPES · THIS FLOPPY REPLACES THE ONE SENT 12/21/94. IT WAS DEPTH SHIFTED TO THE DT CURVE INSTEAD OF THE OH GR CURVE. THIS PROBLEM WAS CORRECTED. WELL NAME · SERVICES · NO. OF BOXES: ADD L TAPES -: WELL NAME SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES: JOB NO. ADD'L TAPES · NO. OF BOXES: JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: RECEIVED BY: 12/21/94 NO. 9161 GeoQuest 500 W. International Airport Road CompanY: Alaska Oil & Gas Cons Corem Anchorage, AK 99518-1199 Attn'. Larry Grant ATTN: Sherrie 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well BL RR Sepia RF Sepia Mylar Disk [." c~. 15-39 _~.~---//~'- PDC (11-9-94) (,,L~"-- / 1 ,J. 15-07A~ ~.--O II DUAL BURST TDT-P (4-11-94) ~(7_¢~ 1 D.S. 14-19 ST ~./-- ~/-/~,~ DUAL BURST TDT-P (10-7-94) /~ ~=,'~ ~"-'~--- 1 D.S. 14-01A ~~/ ~ ~ DUAL BURST TDT-P (10-3-94) ~. ~ ~~ 1 ~ - ~'~~ nllAI RHR~T T~~- ~ 1 D.S. 4-23A ~ ~ --! ~ ~ DUAL BURST TDT-P (12-4-93) ~ ~ ~ 1 D.S. 4-32 ~ ~~~ CNTG (10-24-94) ~~~ ' D.S. 1-14 ~ ~ ~ ~/ DUAL BURST TDT-P (10-2-94) . 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest iS(X] W. International Aiq:~ort Road Anchorage, AK 99518-1199 ATTN: Sherfle NO. 8975 Company: Alaeka Oil &. Gae Cone Comm , Attn: Lam/Grant I 3001 Porcupine Drive Anchorage, AK 99501 10/7194 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 1-6 [-[ ~'"--- t '/-~ PERF REOORD (~9-20-94~] 1 1 D.S. 2-lA ~ C>-- J'~ ~ STATIO PRESSURE SURVEY (9-19-945 1 1 D.S. 3-31 ~ ~( --- ~"L_ BRIDGE PLUG RECORD (~9-13-94~) 1 1 D.S; 3-36 '~ ~ -- I q PERF REOORD (~9-14-94) 1 1 D.S. 4-2 "~(~. - /o._~ TUBG CUTTER REOORD (19-13-94) 1 1 D.S. 5'4-)~'~C~-~ ~ STATIO PRESSURE SURVEY (19" 19'94) 1 , D.$. 5-19 STATIO PRESSURE SURVEY (9-20-94) 1 1 D.S. 7-24 ~ ~ ~ (.~ ~ STATIO BHP SURVEY (~9-19-94) 1 1 D.S. 9-26 -~ [,jr _. 3'7 POGLM SETTING REOORD (9-11-94) 1 1 D.S. 13-13 ~ '~- ""1 '7 ~'~ LEAK DETEOTION [19-20-94) 1 1 D.S. 15-37 c~ ~ .--/~ STATIO BHP SURVEY/PERF RECORD (~9-15-945 1 1 D.S. 16-5 ~ I"'-~. ~ STATIO BHP SURVEY/INJEO PROFILE (~9-16-94) 1 1 D.S. 16-14 ~ | -- ~ 'z_..- PROD PROFILE (~9-8-94) 1 1 D.$. 16-22 ~'~-'- ~'"1 PERF REOORD (9-11-94) 1 1 Pleas6sign and return one copy of this transmittal to Sherrle at the above address. Thank you.' STATE OF ALASKA ALAS IL AND GAS CONSERVATION C"--~'~IMISSION REPORI' OF SUNDRY WELL OP,-RATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging Perforate 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 1869' FNL, 244' FEL, Sec. 33, T11N, R14E, UM At top of productive interval 5119' FNL, 4802' FEL, Sec. 33, T11N, R14E, UM At effective depth At total depth 5' FNL, 5092' FEL, Sec. 4, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 58' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-24 9. Permit number/approval number 83-63 10. APl number 50 - 029-20945 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11377 feet 9200 feet Plugs(measured) PBTD Tag @ 11235' MD (7/5/94) Effective depth: measured 11235 feet true vertical 9079 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1900 # Poleset 79' 79' Sudace 2471' 13-3/8" 2050 sx Fondu & 400 sx PFC 2529' 2503' Production 10529' 9-5/8" 500 sx Class C & 300 sx PFC 10587' 8533' Liner 1091' 7" 350 sx Class G 11377' 9200' RECEIVED Perforation depth: measured 11130-11160' AUG 1 2 1994 true vertical 8990-9016' Ataska 0il & Gas Cons. C0mmissi0 Anch0ra~e Tubing (size, grade, and measured depth) 5-1/2", 17#, IPC, L-80, PCT @ 10280' MD; 4-1/2", L-80, 12.6~, tubing tail @ 10354' M D Packers and SSSV (type and measured depth) Baker SAB packer @ 10271' MD; Camco BaI-O SSSV @ 2151' 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 Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 301 - 2928 717 1012 ,~ 3373 1464 Tubing Pressure 218 246 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 foreg?.j.ing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 11Rl/ID nn- 14'7 .IWP Date SUBMIT IN DUPLICATE.,~, 7-24 DESCRIPTION OF WORK COMPLETED SELECTIVE ACID STIMULATION TREATMENT 7~5/94 · RIH & tagged PBTD at 11235' MD. 7/15/94: A Selective Acid Stimulation for CaCO3 Scale removal was performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded the wellbore w/1% KCL Water, then RIH w/CT mounted inflatable packer. Inflated & set packer at 11135' MD to protect squeezed perforation intervals located between 11088' & 11130' MD. Pumped the stimulation fluids to treat the open perforation intervals located below the packer at: 11130 - 11160' MD (Z2) Ref. Log: BHCS 5/14/83. Pumped: a) 80 bbls 50% Diesel / 50% Xylene @ 1.8 bpm, followed by b) 90 bbls 12% HCI w/5% Xylene @ 1.8 bpm, followed by c) 160 bbls 1% KCl Water @ 1.9 bpm, followed by d) Shutdown. Deflated & POOH w/packer. Rigged down. 7/24/94 · Pumped ESL Scale Inhibition Treatment. Returned well to production & obtained a valid production welltest. R£C I'V£g / UG 2 1994 Gas Cons. Commission Anchorage ARCO Alaska, inc. Date- Subject' From/Location: Telephone: To/Location- May 10, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 P.O. Box 100360, ~nchorage, AK Transmittal #: 94037 99510~ ~, Gas Cons. O0~ission Anchor.ge Distribution Well i Log Date i Tool Type Number ! (,,-D-Y) OWDW-Nw i! 04-30-94~1 fPump'in Temp OWDW-f 04-30-94 ! Pump-in Temp SE 1-2 1-4 1-17 1-24A 2-18 2-34 2-35 3-17 3-17 3-21 3-29 4-29 4-33 f 5-15A. i 5-15A 5-35 6-6 4-44 4-44 4-45 4-45 4-46 5-10 04-19-94 ! 04-20-94 Run, Scale 1,5" 1,5" CNL ! 1, 5" TDT-P i 1, 5" ; 04-07-94 { ~ TDT-P i 0'4-08-94 ! ~ Perf Record I 04-16-94 { ~' Perf Record i 04-17-94 {/ Prod Profile [ 1, 5" 04-18-94 !.-- Bridge Plucj 04-19-94 i~' Prod Log 04-12-94 ~' Prod Profile 04-27-94 !/Injection Profile 04-19-94 !.- Perf Record 04-20-94 j ~' Perf Record .04-14-94 1 ~ Leak Detect 04-29-94 i.~niection Profile 04-12-94 {/' USlT 04-14-94 { ~- TDT-P 04-14-94 { /" CNTG 04-24-94 i ~- CNTG 04-24-94 { ~ TDT-P 04-22-94 { ~ Perf Record 04-13-94 t~ Leak Detect 04-25-94 ! / CTU Prod Log 04-26-94] / TDT-P 04-16-94 { -'- Leak Detect 04-17-94 !,-" Completion 04-08-94 ~ ~ TDT-P 04-19-94 i,--- Completion 04-13-94 i --~Patch Record · " 1,5" } 1"&2"&5" 1 5" 1 5" 1 5" I 5" 1 5" 1, 2"&5" Contractor 5" 5" 5" 5" 5" 5" 5" Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 'Sch Sch Sch Sch Sch Sch Sch Sch 04-27-94 { /Peri Record Sch Sch 04-16-94 i ~'Leak Detect [ 1, 2"&5" 12-09-93 { ~- TDT-P i 1, 5" 1,5" 04-18-94 { ----' Inj Profile 04-12-94 {~" Patch 04-23-94 i ,--'Patch Record 04-20-94 ~ -'-Inject Profile Sch Sch Sch Sch Sch Sch ARCO AlaSka, Inc. I$ a SubsiJary o! AtlantlcRlchtleldCompany ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 16, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 7-24 Approval No. 8-317 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DMF/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 7-24)W1-3 WELLS3/56 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ,~--- STATE OF ALASKA AL, A OIL AND GAS CONSERVATION COMM, ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown w Stimulate __ Plugging B Perforate __ Pull tubing _.... Alter casing ~ Repair well ~ Pull tubing ~ Other 2. Name of Operator ARCO A'laska, Tnc. 3. Address P. O. :Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1869' FNL, 244' FEL, Sec. 33, At top of productive interval 5119' FNL, 4802' FEL, Sec. 33, At effective depth TllN, R14E, UM TllN, R14E, UM At total depth 5' FNL, 5092' FEL~ Sec. 4~ TllN~ R14E, UM 12. Present well condition summary Total depth: measured 11377 feet true vertical 9200 feet 6. Datum elevation (DF or KB) 58' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number 7-24 9. Permit number/approval number 8-317 10, APl number 50-- 029-20945 11, Field/Pool feet Prudhoe Bay Oil Pool Plugs(measured) Effective depth: measured 11335 feet true vertical feet 9164 Casing ~ngth Size Surface 79' 20" Intermediate 2471' 13-3/8" Production 10529' 9-5/8" Liner 1091' 7" Pedor~ionde~h: measumd Junk (measured) Cemen~d Measureddepth 1900# Poleset 79' 2050 sx Fondu & 2529' 400 sx PFC 500 sx Class G & 10587' 300 sx PFC 350 sx Class G 11377' .~uevedicaldepth 79' 2503' 8533' 9200' 11130-11140'; 11140-11160' truevertical 8990-8999'; 8999-9016' ~bing(size, grade, andmeasu~ddepth) 5½", 17#, IPC, L-80, PCT @ 10280' MD; 4½", L-80, PackersandSSSV~ypeandmeasureddepth) Baker SAB packer @ 10271--M~; Camco Bal-0 SSSV @ 13. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 12.6#, tubing tail @ 10354' MD 2151' MD t-ti~.,~;~ ~i <_~ - , , ~.. ..... -:c... Tubing Pressure -- 1798 Representative DaJly Average Production or Injection Data ;';;-, .'i ....... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2993 14377 0 2104 2721 0 956 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _~_ 16. Status of well Classification as: Oil V/ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~/~ T'~le Operations Form 10-404 Rev 06/15/88 WELLS3/56 D. M. Fife, 263-4278 Engineering Manager Date SUBMIT IN DUPLICATE 6~8/88 6/1 2/88 6/13/88 7/4/88 7/6/88 7/12/88 DS 7-24 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF Performed mud acid stimulation as follows: MIRU CT. Pressure tested equipment to 4000 psi. RIH and washed perforations from: 11088-11160' MD Ref. Log: BHCS5/14/83 Pumped the following treatment: 1. 200 bbls crude 2. 33 bbls 12% HCI/xylene 3. 77 bbls 12-3% HCI-HF 4. 35 bbls 12% HCI 5. 25 bbls diesel flush Flushed well, POH, rigged down. The CTU squeeze was performed as follows: MIRU CTU. Pressure tested equipment to 4000 psi. RIH w/CT and packed wellbore w/seawater. Pumped 15 bbls FW, then 31 bbls cement, squeezing perforations: 11088-11118' MD Ref. Log: BHCS 5/14/83 11122-11160' MD Attained squeeze pressure of 1500 psi. Contaminated cement w/95 bbls contaminant. OOH. WOC. Cleaned out contaminated cement. Reperforated: 11140-11160' MD Ref. Log: Reperforated: 11130-11140' MD Ref. Log: N2 lifted well to flow after perforating. BHCS 5/14/83 BHCS 5/14/83 Flowed well to attain new capacity. DMF/0048 DATF' 7-R-RR F~' r..- F FT. r.:: r...- h~ r.'. F- - ARCO .4--Z''~ ~-?R--RR F-rp 1' I i"1 ~, 7-?4 7-A--RR C. Fll I. AF,',/F'FF~-'F- F1F,'~'I"'I'NNI 9-:?A '-; -- :-':' F) - R,q Fl:' 1:1 fiF. 9-?7 ?-A-RR CNI I A,q'/PF~'FflR'~'¥TflM '.-? - '.':) 9 =f- :.:"7- :q,q FI::' 1' I f'l f'.; i ~ - % ':~',-.."~ ,'7, -- :q ,-,"" F: I:' T I FI 13 ! i -t ...-5. ~.:--?A-FI,q F'F'I'I FIK F'I._F.A.',..':F .%TI-,F.~ AND. ,LTE'TIIR'N TI41-- A'TTACHFD CFIF'Y RIECETVFD RY I--IA~JI: A NI'I-:F DAY ~ F' 1:-'. G [, Y 'I-',,F N N F T T ATFI-i T F-,: A N 5..'¢ ~,q R 4 ~ ='-:. A F' F:' 17' F1 ",/F 1") f') T :":..' 'T ,~: '[ R i I'T T [1 N RF-..c,r--Ti:'T I'IF DATA. JUL ,o ~~ 0'~ 8, Gas 6ons. Oommission , Ar~chorage F.' F'F~ T F: A I F: !' I...F ?, F': 1--t F ",/F;' FI ig · F"% T F- KJ :,Z T FI N FYF:'I F W ',% F',' N MAF:ATNFIN -"' MF,'R T 1 -~1, . . :~ F'N'I'I I TF'X' F' R W F I I. F: 1' I. F:' .q' R' ° :.":. ?. A F' ~ ?,TATF' FiF' Al AS:KA ~ 'T F Y, A F'.[] AI:;:.CO AI...A,.?KA ... ]'Nf: .. F', O., RFI'.( i Ai'J!7;HOF,'AI].F.], AI..AS,'K.A c79':.;~ (.) .D ~ T .F.. - 7-7-~8 F,'FFERF.:ii',,~CE· ARCO C.A~'ED H,"'i F:' 7-i '') 7-4-.00 -.-.4 7-4-88 c.r.}l ! AF,'/PF.F~'Fr]RATIf]N C 01..I.. A R.,"F:'E RI--0 R A T 7[ [_'IN F'I_I{A,':,'E' ,?I[~N AN[) RIE'I'IJF:i,.~ ThlF7 AT-f'AC!--IF.D Cf]F'Y A.'7 PI:[CETI::'T OF' PATA.. R !::: C IT ! 'v' F' O B Y. ............................................. HAVE A N]]C'E DAY' P F'!:, i.~ Y RFNNETT ..... ;- :,.'. 3. T !;,' A N :~; ~:8 8 4'5'"', A F' .c. !7 f:_l b' E )":, _ _ O 'r 2'r R ]' t?: ! IT l' FI i'-J ~7,$:,,~ ~"J" ARCO Alaska, Inc. - Prudhoe Bay L,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 25, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 7-24 Permit No. 83-63 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DMF/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 PI(DS 7-24)W1-3 to be RECEIVED Alaska Oil & r-Sas Cons. Commission Anchorage WELLS2/126 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCornpany AR3B--6132-C '--'- STATE OF ALASKA --' ALASK. ')IL AND GAS CONSERVATION COMb,. ,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon © Suspend ~, Operation Shutdown ~ Re-enter suspended well -' Alter casing - Time extension ..'-q Change approved program ~ Plugging [] Stimulate [] Pull tubing © Amend order [] Perforate ~; Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1869' FNL, 244' FEL, Sec. 33, TllN, R14E, UM At top of productive interval 5119' FNL, 4802' FEL, Sec. 33, TllN, R14E, UM At effective depth At total depth 5' FNL, 5092' FEL, Sec. 4, T10N, R14E, UM 5. Datum elevation (DF or KB) 58' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 7-24 8. Permit number 83-63 9. APl number 50-- 029-20945 10. Pool feet Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11377 feet Plugs (measured) 9200 feet Effective depth: measured 11335 feet Junk (measured) true vertical 9164 feet Casing Length Size Cemented Conductor 79' 20" 1900# Poleset Surface 2529' 13-3/8" 2050 sx Fondu & 400 sx PFC Production 10587' 9-5/8" 500 sx Class G & 300 sx PFC Liner 1091' 7" 350 sx Class G Measured depth 79' 2529' 10587' 10286-11377' ~ue Verticaldepth 79' 2529' 8533' 8283-9189' Perforation depth: measured 11088-11118', 11122-11160' true vertical Su{usequ~t YFor]~ Repo~e~ o~ 8898-8923', 8927-8959' Form No. /~ ' /''/0 /''[ Dated/~-~//~__~~ Tubing (size, grade and measured depth) 5!~'', IPC, L-80 tubing w/4!~'' L-80 tubing tail to 10354' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 10271' MD; Camco Bal-0 SSSV @ 2151' RECEIVED &laska 0il & Gas Cons, Commis 12.Attachments Description summary of proposal ~ Detailed operations program © BOP sketch 13. Estimated date for commencing operation 5/15/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~ertify that the,foregoing is true and correct to the best of my knowledge Signed ~/,¢~'dfz~~/~.~' Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test ~ Location clearanceI Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned,, L;ommissioner by order of the commission Date Submit in triplicate Form 10-403 Rev 12-1-85 WELLS2/126 D. M. Fife, ATO-1510 ~ ._ ARCO ALaska, :Inc. Anchorage, ALaska DATE: Apri [L 2~, .t 987 REFERENCE: ARCO Cased HoLe Final 4-t5 4-t -87 7-24 4-6-87 9-3 4-3-87 t 4-34 4-5-87 Inj. F'rofi Le Survey Run Leal,, De~ec'~ion Log Run t, 2" F[Lowme+.er/Temp. ~urvey Run t, 2' F~owmet'er/F~u~d Densi~y/'Femp Run & 5' &5' C a m c o Camco Camco F'[Lease sign and R'eceived By HAYE A NICE DAY! Rosanne Peek ATO- t 529 reCur'n the a¢¢a_ci~ea9 cop~?~ as re?'~p~ 'f'RAN$ ~87229 ..~ Approved D I,~TR I BUT I ON of data, ~ Cen+ra[ Fi Les .,. · ~ . F'hi I_Lips ~ Chevron F'B WeLL F'i I. es D & M !;.'. & I) · ~."" Extension Exp[ora'f Jc:,f~ .,,- ~'oh Jo ~.,,.Exxon ¢: .-.~'tate of'ALaska Mara'fhon $~- Texaco '"' Hob i l - " DS 7-24 CTU Cement Squeeze AFE# 797961 Preliminary Procedure 1. Make a slickline tag run to verify the PBTD. Perform a fill cleanout. 2. RIH with CT. Wash the perforations with full strength mud acid. Flow well to produce out all the acid. 3. RIH with coiled tubing and fluid pack the wellbore with filtered seawater. 4. Pump 45 bbls of cement followed by 2 bbls of water and 100 bbls of contaminant. Hold 1500 psi surface squeeze pressure for 60 minutes. Squeeze off the following perforations: Zone Perforations SPF (Ref.: BHCS 5-14-83) 2 11088-11118 4 2 11122-11160 4 5. Jet or reverse out the contaminated cement. 6. Perforate as follows: Zone 2 7. Test the well. Perforotigns SPF 11122-11160 FSD (Ref.: BHCS 5-14-83) Other Well Information: Current status: On production. Expected static bottomhole pressure: 3670 psi. @ 8800' SS Expected fluid in wellbore at reperfomtion: seawater. 3 J 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) .~. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H ! REL ! NE BOP EOU l PMENT 6 5 4 3 2 ii ii 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANO£ 2. 5000 PSI 4 1/16" PIPE RAMS :3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX CO I LED TUB 1 NO UN l T BOP EOU l PHENT i i ARCO Alaska, ,' Post Off ~3ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 25, 1984 Mr. Harold Hedlund State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 7-24 Completion Report Dear Harold, The Well Completion Report, dated July 15, 1983, incorrectly lists the ADL number as 28310. The correct lease designation is ADL 28309. Enclosed is a sundry noting this change. Please update your records/files. If you have any questions, please call. Sincerely, d. Gruber Associate Engineer JG/tw GRU2/L40 Enclosure xc: Well File K. McFarland, ATO 1429 P. Willman, ATO 1069 ?ECEIVED Gas Cons. Cornrnisslort Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompeny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION t~(~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLx~ 2. Name of Operator 7. Permit No. ARCO A]aska, Inc. 83-63 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20945 OTHER [] 4. Location of Well Surface: 1869' FNL, 244' FEL, Sec.33, TllN, R14E, UM 5. Elevationinfeet(indicate KB, DF, etc.) RKB 58' 12. I 6. Lease Designation and Serial No. ADL 28309 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 7-24 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 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 Pull Tubing [] Other ~ Pulling 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). The Well Completion Report, dated 07/15/83, incorrectly lists the ADL number as 28310. The correct lease designation is ADL 28309. Please make this change to your records and files. RECEIVED ocT llleska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Associate Engineer The space belo~//for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Form 10-403 GRU2/SN23 Rev. 7-1-80 Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, h. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, 1984 Reference: ARCO Cased Hole Finals D.S. 3-6~ 6-10-84 Diff Temp D.S. 3-19-~ 5-25/26-84 Spinner Survey D.S. 3-22~ 6-29-84 D.S. 6-10f 7-4-84 D.S. 7-3~- 7-6-84 D.S. 7-18~ 7-4/5-84 D.S. 7-24' 4-19-84 D.S. 9-18--- 6-21-84 D.S. 12-15'-~- 4-13-84 Spinner Survey Temp Log Temp Survey Spinner Spinner Diff Temp Spinner D.S. 12-18' 4-14/16-84 Spinner D.S. 13-1 / 6-17-84 D.S. 13-10f' 6-22-84 D.S. 13-12-~ 6-18-84 D.S. 13-13 ~'- 5-31-84 D.S. 13-16J 4-12-84 ~ , ~__ ~.S. 13-27"~ 6-2-84 D.S. 13-28'- 6-3-84 D.S. 13-28-~-~ 6-3-84 D.S. 13-28~ 7-8-84 D.S. 13-33~ 6-22-84 D.S. 13-33/ 6-23-84 D.S. 14-3~ 6-30-84 D.S. 14-21- 7-7-84 D.S. 14-24/ 3-25-84 D.S. 14-34~ 5-19-84 Diff Temp Temp Log Diff Temp CFS/Spinner Diff Temp CFS/Spinner CFS/Spinner Temp Survey Temp Log Diff Temp Spinner Log Diff Temp Caliper Log Caliper Log Spinner Log Run 1 5" Otis Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" GO Run 1 5" Camco Run 1 5" GO Run 1 5" Go Run 1 5" Camco Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 4 5" Camco Run 1 5" Camco . 17-10/ 6-17-84 Diff Temp Run 1 5" Camco se sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F DISTRIBUTION · Trans. #301 Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Ge tty Marathon Mob i 1 Mobil E & P A!aska Oil & ~-;as Cot~s. Commissior~ ,A~chomqe Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, l,~c: ...... Post Of~z' 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Pressure Data D.S. 3-19f D.S. 3-22¢ D.S. 3-23 D.S. 4-1/ D.S. 6-4f D.S. 6-7f D.S. 6-18 D.S. 6-23 D.S. 7-20 D.S. 7-21 D.S. 7-22 D. S. 7-24 D.S. 7-25/ D.S. 7-26' D.S. 12-7A/ -D.S. 12-15f D.S. 12-18 D.S. 13-13 D.S. 13- 15 D.S. 13-16~ D.S. 13 33 D.S. 18-7 / ease sign 4-9-84 Static Camco 4-9-84 Static Camco 4-9-84 Static Camco 3-17-84 Static Camco 1- 25- 84 PBU GO 1-25-84 Common Data Base Report 1-15- 84 PBU GO 1-15-84 Common Data Base Report 12-27-83 Horner Plots w/listing Sch 8-11-83 Horner Plots w/listing Sch 4-18-84 PBU Camco 4 - 29- 84 PBU DA 4-20-84 PBU Camco 4-20-84 Common Data Base Report 4-20-84 PBU " Camco 4-21-84 Common Data Base Report 4-22-84 PBU Camco 4 - 2 8- 84 PBU DA 4-14-84 PBU Otis 4-14-84 Common Data Base Report 4 - 13- 84 ~BU Camco 4-13- 84 Common Data Base Report 4-15-84 PBU Camco 4-16-84 Common Data Base Report 4-12-84 Static DA 4-13-84 PBU DA 4-12-84 Pressure Draw-Down Camco 41-5-84' Static DA 3-14-84 PBU DA 3-14-84 Common Data Base Report and return the attached copy as receipt of data. Kelly McFar land · ATO- 14 29F Chevron D &M Trans. ~ 187 Have A Nice Day: '".._'.:!).. '.. >',,i · Mob i 1 PIODi/ r., ~ 1" i'i~,.,~ ...... ~,~, Drilling Phillips '" .... · ' ' ' "'~t'- ' ' "'~'rb ' Exp. Services Prudhoe Bay Well Fzies Ext. Exploration R & D Exxon Carolyn Smith Getty Sohio Marathon State of Alaska ARCO Alaska, In/.; Prudhoe BaT~ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 8, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 7-15 Permit No. 82-173 DS 7-16 Permit No. 82-182 DS 7-17 Permit No. 82-200 DS 7-18 Permit No. 82-209 DS 7-19 Permit No. 82-217 DS 7-20 'Permit No. 83-14 DS 7-21 Permit No..83-19 DS 7-22 Permit No. 83-39 DS 7-24 Permit No. 83-63 DS 7-25 Permit No. 83-56 DS 7-26 Permit No. 83-48 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. S cheve Regional Engineer DFS/JCD/lmi Enclosures cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlanticRIchfleldCompany ¢--' STATE OF ALASKA ALA{ i,i~i~AN D GAS CO N SERVATIOI, ,,MISSION ELL COMPLET OR RECOMPLETIO I REPORT AND LOG · 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Alaska, Inc. 83-63 ARCO 3. Address 8. APl Number P.O. Box 100360, Anchorage~ Alaska 99510 50- 029-20945 4. Location of well at surface 9. Unit or Lease Name 1869'FNL, 244'FEL, Sec. 33, TllN, R1/+E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 5119'FNL, 4802'FEL, Sec. 33, TllN, R1/+E, UM DS 7-24 . .. At Total Depth 11. Field and Pool 5'FNL, 5092'FEL, Sec. 4, TiON~ R14.E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.)~ Lease Desiqrtation and Sezial No. 58' RKB ADL~_~~ ~ Prudhoe Bay Oil Pool 12. DateSpudded0/+/30/83 13. DateT.D. Reached05/14/83 14'DateC°mp"Susp'°rAband' 115'WaterDeplh'if°ffsh°re 116'N°'°fC°mpleti°ns05/23/83 N/A feet,MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ f-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11377 'MD,9200'TVD l1335'MD,9164'TVD YES [] X NO [] 2151 feet MDI 1900' (Approx) 22. Type Electric or Other Logs Run DIT,/S?/BHCS/6R~ ~q)C/CN[~/O~/Cal~ ~ CBL 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/1900# Poleset 13-3/8" 72.05A L-80 Surf. 2529' 17½" Cmtd w/2050 sx Fondu & 400 sx PFC cmt. 9-5/8" 47.0# L-80 Surf. 10587' 12¼" Cmtd w/500 sx Class G cmt & 300 sx PFC Cmt for AP job. 7" 29.0~A L-80 10286' 11377' 8½" Cmtd w/350 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) 11088-11118'MD 8898-8923' ss 4 spf 5~" 10354' 10271' 11122-11160'MD 8927-8959' ss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETc. - : DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Ref: BHCS 5-14-83 N/A · 27. PRODUCTION TEST Date First Production : I Method of Operation (Flowing, gas lift, etc,) 12/2/+/83I Flo~±ng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO 12/29/8~ 12.8 ' TEST PERIOD J~- 2120 1067 0 41 635 Flow Tubing Casing pressure CALCULATED..~ OIL-BBL : ' GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 889 NA 24-HOUR RATE I~ 3580 2273 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 · , , ~.' '~ - '..' i,- , Form 10-407 Rev. 7-1-80 ,: CONTINUED ON REVERSE SIDE Submit in duplicate 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 10750' 8669' N/A O/W Contact 10790' 8703' Base Sadlerochit 11228' 9073 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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". ARCO Alaska, Inc._ Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 15, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 7-18 DS 7-19 DS 7-20 DS 7-21 DS 7-22 DS 7-24 DS 7-25 DS 7-26 Permit No. 82-209 Permit No. 82-217 Permit No. 83-14 Permit No. 83-19 Permit No. 83-39 Permit No. 83-63 Permit No. 83-56 Permit No. 83-48 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmi Attachments cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc. Im a Subsidiary of AtlantlcRIchlleldCompany STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION C~.,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL IX] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 1869' FNL, 244' FEL, Sec. 33, TllN, R14E, UM (Surface) 5119' FNL, 4802' FEL, Sec. 33, TllN, R14E, UM (Top Prod) 5' FNL, 5092' FEL, Sec. 4, T10N, R14E, UM (Total Depth) 5. Elevation in feet (indicate KB, DF, etc.) 58' RKB 6. Lease Designation and Serial No. AZ)L 28310 7. Permit No. 83-63 8. APl Number 50- 029-20945 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS ?-24 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 [] Pull Tubing [] Other [] Pulling 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 operation 11/18/83. RU perforating unit, pressure tested surface equipment. RIH with gun ~1, shot 11134-11158' MD, 4 spf. POH - no shots fired. RIH with gun #lA, shot 11134-11158' MD, 4 spf (16' ref: CBL 5/17/83), flow well to tank for cleanup, monitored rate and took shakeouts. POH - all shots fired. RIH with gun 92, shot 11110-11116' MD and 11120-11134' MD, 4 spf (20' ref: CBL 5/17/83) flow well to tank. POH - all shots fired. RIH with gun 93, shot 11086-11110' MD, 4 spf (24' ref: CBL 5/17/83), flow well to tank. POH - all shots fired. RD. Secured well 11/18/83. 14. I hereby,c, ertify that the foregoin~g is true and correct to the best of my knowledge. ~.~F~ ~ ~~ Regional Engineer Signed ..... Title The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" in Duplicate --~ STATE OF ALASKA ALASKA ._ .~ AND GAS CONSERVATION C~ 'vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-63 3. Address 8. APl Number P.O. BOX 100360, Anchorage, Alaska 99510, 50- 029-20945 4. Location of Well 1869' FNL, 244' FEL, Sec. 33, TllN, R14E, gM (Surface) 5119' FNL, 4802' FEL, Sec. 33, TllN, R14E, UM (Top Prod) 5' FNL, 5092' FEL, Sec. 4, T10N, R14E, UM (Total Depth) 5. Elevation in feet (indicate KB, DF, etc.) 58' RKB 6. Lease Designation and Serial No. ADL 28310 9. Unit or Lease Name Prudhoe Bay Unit 10. WellNumber DS 7-24 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 E~ 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.) 13. Describe Proposed or Completed OperatiQns (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 operation 11/18/83. RD perforating unit, pressure tested surface equipment. RIH with gun #1, shot 11134-11158' MD, 4 spf. POH - no shots fired. RIH with gun #lA, shot 11134-11158' MD, 4 spf (16' ref: CBL 5/17/83), flow well to tank for cleanup, monitored rate and took shakeouts. POH - all shots fired. RIH with gun ~2, shot 11110-11116' MD and 11120-11134' MD, 4 spf (20' ref: CBL 5/17/83) flow well to tank. POH - all shots fired. RIH with gun #3, shot 11086-11110' MD, 4 spf (24' ref: CBL 5/17/83), flow well to tank. POH - all shots fired. RD. Secured well 11/18/83. 14. I hereby, c,ertify that the foregoing is true and correct to the best of my knowledge. . _~_~ ~ ~~ Regional Engineer Signed Title 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. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office' "~ 360 Anchorage ...... ska 99510 Teiephone 907 277 5637 December 27, 1983 Reference: ARCO Pressure Data . 6-17 12-9-83 )/~. S. 7-16 12-4-83 ~S. 7-17 12-5-83 ~1~. S. 7-19 12-9-83 ~.S. 7-22 12-5-83 ~D~. 7-24 11-19-83 ~/~. S. 7-25 11-21-83 ,./~. S. 7-26 11-21-83 ~/D. S. 13-14 12-7-83 Static Statzc Statzc Static Static Statzc Statzc Static Static Camco Camco Camco GO Camco DA DA DA DA Pleasesign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 702 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay R & D Caroline 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 October 31, 1983 Mr. C. V. "Chat'' Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive ADchorage, AK 99501 Re: DS 7-18 DS 7-19 DS 7-20 DS 7-21 DS 7-22 DS 7-24 DS 7-25 DS 7-26 Permit No. 82-209 Permit No. 82-217 Permit No. 83-14 Permit No. 83-19 Permit No. 83-39 Permit No. 83-63 Permit No. 83-56 Permit No. 83-48 Dear Mr. Chatterton: Attached are "Intention" Sundry Notices detailing work proposed on Drill Sites 7-18, 7-19, 7-20, 7-21, 7-22, 7-24, 7-25, and 7-26. Si-ncerely, D. F. Scheve Regional Engineer DFS:la cc: Sohio Petroleum Co. ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompany STATE Of ALASKA ~- ALASKA -,L AND GAS CONSERVATION C, ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLX:X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well 1869' FNL, 244' FEL, Sec. 33, TllN, R14E, UM (Surface) 5119' FNL, 4802' FEL, Sec. 33, TllN, R14E, UM (Top Prod) 5' FNL, 5092' FEL, Sec. 4, T10N, R14E, UM (Total Depth) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 58' RKB I ADL 28310 7. Permit No. 83-63 12. 8. APl Number 50- 029-20945 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 7-24 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 Triplicate) (Submit in Duplicate) Perforate ~[~ 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.) 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 perforate selected intervals within the Sadlerochit sand from the Prudhoe Bay unit. Upon perforating, the well will be flowed to a tank for cleanup. The perforated intervals will be given in the subsequent report. 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 cleanup operation. Proposed perforated intervals: 11088-11118' MD (30') 11122-11160' MD (38') RECEIVED NOV g83 Ref. BHCS 5-14-83 · aska Oil & Gas Cons. ~0mmissi0~ 14. i hereby certify that the foregoing is true and correct to the best ~i~'ha]~c/~N~J~. Signed ._~69~. ~ _~~--~,,'l~.,- Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: SIGNED Approved by COMMISSIONER Approve.'..! Returned By Order of the Commission Date - i Form 10-403 Rev. 7-1-80 Submit "Intentions" m Triplicate and "Subsequent Reports" ,n Duplicate Aiaska, inc. Pos! O!fic~.--~-~.x 360 ,. Ar, chorac ska 99510 - Telephone 907 277 5637 September 9, 1983 Reference' Arco Cased Hole Finals D.S. 1-26 ~-~ 4-11-83 D.S. 7-24_ 5-17-83 D.S. 7-25 / 4-28-83 D.S. 7-26 ~ 4-11-83 D.S. 13-28~ 5-25-83 D.S. 13-29 5-6-83 ACBL/VDL/Sig/GR/N ACBL/VDL/Sig/GR/N ACBL/VDL/Sig/GR/N ACBL/VDL/Sig/GR/N ACBL/VDL/Sig/GR/N ACEL/VDL Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA ~~PleaSe sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 515 Ch~vro~ DaM Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe ;B_ay- C~U ~ ' c~ ' Sohic ! , State of Alaska ARCO Alasl~a, Inc~'"'~ '""~"~<'"' -~ ~-:. ; . t ": pOst O ffice',';~':'~.j360 '"-~-'"" .... ' Anchorage. Alaska 99510 July 14, 1983 Reference: Arco Open Hole Finals D.S'. 7-24 D.S. 13-28 sign 5-14-83 5-14-83 5-14-83 5-14-83 5-14-83 5-14-83 5-22-83 5-22-83 5-22-83 5-22-83 5-22-83 5-22-83 5-22-83 CPL/Cyberlook BHCS DIL/SFL LDT/CNL/GR (Poro) LDT/CNL/GR (Raw) GR through 9-5/8" casing CPL/Cyberlook BHCS 'DIL/SFL LDT/CNL/GR (Raw) LDT/CNL/GR (Poro) GR (3600 ft/hr) GR (8000 ft/hr) Run 1 5" Sch Run 1 2" & .5" Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 -2" & 5'" Run 1 '5" Sch Run 1 2" & 5" Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 2" & 5" Run 1 2" & 5" and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 420 chevron D &M Dallas Drilling Exxon Marathon Mobil DISTRIBUTION R & D Caroling Smith Alaska Oil & Gas Cons. Commis~;ior¢ Anchorage Sohio :?S~a.te- of. Alaska ARcO~AlaSka; Inc. ~}.. - Post Office B~',J0360 Anchorage, Alaska 99510 Teleplion6 907 276 1215 July 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 Dri ling & Workover Operations Dear Mr.-Chatterton' Enclosed are Monthly RepOrts of Drilling and Workover Operations for the following- DS 14-23 DS 14-24 DS 13-27 DS 3-19 Pingut State #1 South Point State #1 and Wel 1 DS 13-28 Completion or Recompletion Reports and Logs for' Also enclosed are revised Well COmpletion or Recompletion Reports and Logs for' DS 1-25 DS 13-29 DS 7-25 Sincerely, M. Ao Major Area Drilling Engineer MAM/CSM34-sm Encl.osures ARCO Alaska. Inc. is a Subsidiary of AllanlicRichfieldCompany WELL COMPLETION OR RECOMPLETIOI I I. EPORT 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. 83-63 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20945 4. Location of well at surface : - LoCATioNS 9. Unit or Lease Name 1869' FNL, 244' FEL, Sec. 33, TllN, R14E, UN VEP, iFiED Prudhoe Bay Unit At Top Producing Interval - Surf. ~ I 10. Well Number 5119' FNL, 4802' FEL, Sec. 33, TllN,' R14E, UM DS 7-24 - - . 11. Field and Pool At Total Depth 5' FNL, 5092' FEL, Sec. 4, T10N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i ] Pool 58' RKBI ADL 28310 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 04/30/83 05/14/83 05/23/83I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey_ I 20. Depth where SSSV set 21. Thickness of Permafrost 11377'MD,9200'TVD 11335'MD,9164'TVD YES K~ NO []I 2151 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR; FDC/CNL/GR/Cal; GR; CBL 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/1900# Poleset 13-3/8" 72.0# L-80 Surf 2529' 17-1/2" Cmtd w/2050 sx Fondu & 40 sx PFC cmt. 9-5/8" 47.0# L-80 Surf 10587' 12-1/4" Cmtd w/500 sx Class G cmt:& 300 sx PFC cmt for AP job. 7" 29.0# L-80 10286' 11377' 8-1/2" Cmtd w/350 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) N/A 5-1/2" 10354' 10271 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27.N/A PRODUCTION TEST 1 Date First Production I Method of Operation (FloWing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OI L RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None A' ",~'"" OiJ (;. Gas {P:.,nt;. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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 Sad] erochi t 10750' 8669' N/A 60C 10790' 8703' 0WC 11228' 9073' 31. LIST OF ATTACHMENTS Dri 1 ling Hi story, Gyroscopic Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ Title^rea Dr''l''ng Engr' Date 7/'S/~? 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". 7-24 DRILLING HISTORY NU 20" diverter and lines. Spudded well @ 0230 hrs, 04/30/83. Drld 17-1/2" hole to 2540'. Ran 63 jts 13-3/8", 72.0#/ft, L-80, BTC, csg w/FS @ 2529'. Cmtd 13-3/8" csg w/2050 sx Fondu and 400 sx PFC. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 10.8 ppg EMW - ok. Drld 12-1/4" hole to 3425'. Tight hole fr/3425'-3042'. Wash & ream 3303' -3364', 3304' -3425'. Drl to 5144'. Work stuck pipe. Spot 80 bbls SFT oil pill, pulled pipe free. Drld to 5558'. Ream 5448' -5558'. Drld to 8958'. Wash & ream tight hole 8644'-8958'. Con't drlg 12-1/4" hole to 10,610' (05-11-83). Ran 265 jts 9-5/8", 47#/ft, L-80, BTC csg w/FS @ 10587'. Cmtd 9-5/8" csg w/500 sx Class G. Tstd csg to 3000 psi - ok. 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 10738', lost all returns. Hole taking fluid. Spot LCM pill. POOH w/5 stds. Ream to btm. Con't drlg 8-1/2" hole to 11,377' (05-14-83). Ran DIL/SP/BHCS/GR fr/11377'-10587', FDC/CNL/GR/CAL fr/11377'-10587', GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 sx PFC cmt & 127 bbls AP. Ran 28 jts 7", 29#/ft, L-80 BTC csg fr/10,286-11,377'. Cmtd 7" lnr w/350 sx Class "G" cmt. Wash 9732'-9930'. Drld firm cmt f/10,000'-10,288'. TOH. Change BHA. Drld cmt f/11,150'- 11,355' PBTD. Tstd l nr lap to 3000 psi - ok. Displaced well to 9.7 ppg NaC1. Ran CBL fr/11355'-10550'. Ran 5-1/2" completion assy w/tail @ 10354' & pkr @ 10271'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Remove BPV. Secured well & released rig @ 1800 hrs, 05/18/83. Gyroscopic survey run on 05/23/83. CSM/DH15 07/08/83 ARC:O ALASKA, INC:. DS 7, WELL NO: 24 SIGMA-GYRO JOB NO: A0583RO~::47PZ F'~:UDHOE BAY., NORTH '.=;LOPE, AI._A'.=;KA ~=;IGMA-GYRO-, 0-1!300 MD-, SURVEYOR: PEFFERI<ORN/MILLER., DATE RUN:23-MAY-:E:3 '.E;IGMA/GYRO NO: 271, PROBE NO: 067 FORE"..=.;IGHT: N 7 15 W '._=;URVEY TAKEN FROM WELLHEAD VERI'ICAL SECTION CALCULATED IN F'LANE OF F'ROPOSAL DIRECTION: S 57 BEG. 27 MIN. W RECORD OF SURVEY RADII...IS OF CURVATURE METHI:ID ARC:O ALASKA, INC. COMPUTATION F'AGE NO. 1 DS 7, WELl._ NO: 24 SIGMA-GYRO ,_lOB NO: A0583RO347F'Z TIME DAI'E F"'RI_IDHC~E BAY-, NORTH SI_OPE, ALASKA 12: 0/",: 28 14-,_II_IN-:E::F: TRUE MEASURED DRIFT [,RIFT COURSE VERTICAL VERTICAL °._::LIBSEA R E C T A N G U L A R C: .L 0 S U R E DOGLFG DEPTH ANGLE D'IRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A ]' E S DISTANCE DIREF:TION SEVER I 'T","' FEET D M D M FEET FEET FEET FEET FEET FEET D I'1 DG/1AOF] 0. 100. 200. :300. 400. JO0. 600. 700. :.':: 00. '.;'00. 1000. 1 100. 1200. 1. 300. 1400. o 0 0 0. O. 00 0.00 -57.00 O. 00 0. O0 0.00 0 0 0.00 .30 N 71 0 W 100. 100.00 0.27 4:3.00 0.14 N 0.41 W 0.4.4 N 71 0 W C~.50 2.5 S 72 0 W 100. 200.00 0.'.-.?:3 14:3. C)0 0. 15 N 1.20 W 1.21 N 82 56 W 0. :30 40 N F::3 42 W 100. 2'F.~'F.¢.'.:.¢S.~ 1.77 242.99 0.05 hi 2.14 W 2. 14. hi 88:2:4, W 0.:-:::3 . .58 ':342.'.;,9 0.21 N 3.20 W .:,.21 N 8/". 11 W 0. 1.1. 3:4 N 7'.-.? 1 I W 100 3'Fr?.':.?9 2. '-' 0:2:4 S 80 2/", W 0 4:3 S 84 15 W 0 17 N /",7 51 W 0 '.-.-' N 50:36 E 0 23 N 75 16 E 0 19 N 57 4.2 E A 2'.'-7 N /",0 2 E 0 2? S 66:3:3 E 0 2A S 5 14 W t 53S71 7 W 1. 00. 4'.-.-*':}. 98 :-::. 40 442.98 0.22 N 4. 18 W 4. 19 N 8/", 5/", W 0.20 ..... .=, '-' 97 .A7 .2'P = 29 . . 1A0. ~99 '.-}7 4 42 ._4.... 0 N 5 W .J. . N :::9 11 W (').16 100. /",".-)'F.~.'.--.~7 5.08 /",42.'.--.~7 0.20 N 6. 15 W 6. 15 N 88 9 W 0.48 100. 7'P'?. '? 7 4. '-Y ~._, 742 .... '.;,7 0 51 N 6.20 W /-, .."-'~'-' N 85 1. 9 W 0. :2:8 100. ::.:9'.-7. 97 4.. 49 842.97 0.72 N 5.78 W 5.8:3 N 8:2 55 W O. '-.'25 100. '9'Fr.-.-,. '77 1 O0. 109'F.~. 96 100. 11 '.-.?".-7,. 96 1 O0. 12',-}'.T¢. '96 100. 13'F/~. ~.~4 :3. ::-.:8 942. 'F.~7 3.18 1042.~6 2.48 1142.96 2.50 1242.96 4.2:2 1342.94 0.96 N 5.22 W 1.32 N 4.62 W 1.37 N :3.81 W 0.80 N 3.47 W' 0.64 S 4.60 W 0.1 :-:: 0.17 0.4:3 0.4',-? 1.77 1500. 1600. 1700. 1800. ( "'00. 4. :'::6 S /-F,_,... 11 W 4 40 S 57 2 W 5 12 S 62 4.5 W ':-- ~ /-,'7 5 · .., ... 1 :3 W 7 27 S 67 5 W :2000. 9 21:3 5'7 56 W 2100. 12 33 S 49 51 W 2:200. 14 54 S 48:31 W .?:'::(')(). 16 4:':: ':'._. 48 ._r'-]'..'~.. W 240C). 1'~) 50 S 46 22 W 100. 1499.77 100. 15'.-]9.44 100. 1/-,99.07 100. 1798.60 100. 1 :E:97. ?3 100. 1996.85 100. 2095.02 100. 21'P2. 16 100. 2288.37 100. 238:3. :31 S).78 1442.77 17.83 1542.44 26.42 1642.07 35.96 1741.60 47.~,.-, ~, o.:. 1,:,4L.~:3 61. '~2 193'.-}. 85 80. c, ~'/:, 2038 .02 104.33 21:35. 16 131 2/.:, ¢"-"-'1:37 . .~..,,: .-, 16:2. 16 232/",. 31 c, 74. S 9 ':'.=, W · '.. m . ~_m ,_ 6./",4 S 16. ':.'-,1 W 10 9/-. c. 24. c,.=, W . . -- .... . ..m ._ 1.~ (:)4 S :33 07 gl .., ..., S: 43.7 ::: gl ';:'6.2:3 '.3 56.6:3 W 37.4.7 S 7:2.01 W 52.97 S :39.96 W 70. '.=73 S 110.4.5 W '92.()4 S 13:3.62 W 10. ?.:.'2 '.E; 74. 25 W 18. 17 '.3 /.'>8 33 W 26.70 S 65 46 W 36. :33 '.::; 65:33 W 62.4:3 S 65 '7 W 81.1'7 S /",2:31 W 104.40 S 5'F' :3i W 1:":1.26 '._=; 57 17 W 16:2,:26 S 55 26 W .,:. 7:3 0.4:.6, C) 7° 0. '77 I. 60 ':;i:50(). 22 27 S 43 1:3 W 26 00. 2'7 (') o'" 4:2 4':).. W 2700. 29 20 S 44 2..:5 W 2::::00. 2'P :3:3 '.3 4/.:, 4.6 W 2'.:.)00. :31 1 '.:; 5C) 4 W 100. 2476.56 100. 2567.36 :L 00 '-'/:':' :5 . z. '",.",._,. 1 100. 2742.56, 1. 00. ~,=, ... o'-' '-' '-' ¢' . 88 197. :2:7 2419.56 237.90 :2510.3/", 2:'-::3.73 257~8.51 331.8'.-.-¢ 2685.5/-, 381.75 2771. :E:8 11'7,.64 :_=; 157.07 W 148,,21 :E; 187.6:3 W 1 :"]:2. :::8 S 220,, 1 'F7 W · . '-'~'= :3 :216:31 S z ........ W 250. :32 S 293,, 11 W 19 7.84. S 5;:]:.: '-' .:,1 W 2:-::'.;' 11 :i.:; W . .51 42 · -..":"-] 9,1 '.B .=;(') ".' 3:34. '? 8 S 4'.:.) 40 W :385.45 :-_'; 49:30 W 2.87 4.. 52 :2.45 1. 1 '~.) 2.17 ARCF~ ALASKA, ZNC. COidF:'L.ITAI'ZFIN F'AGI.E IHO. :,:: lis 7, WELL NO: 24 '.SIGMA-GYRO ._lOB NO: A¢)5::::3RO:347PZ TIME [:lATE PRIJDHOE BAY, NORTH :..:.:LOPE, ALA:=;KA 12: 06:28 14-,_11JN-8:3 TRUE MEA'.E;I_IRED DRIFT DRIFT COURSE VERTICAL VERTICAL '.:;UBSEA R E C: T A N G I_1 L A R C L 0 S U R E DOGLEF4 DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C iD 0 R D I N A T E S DI:.2;TANCE DIRECTION :--;EVER I 'T";' FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100F'! :301')0· :2:2 4.5 S 5:3 11 W :.':':100. 35 7 '.:; 49 2'4, W :3200. :~::: 6 S 54 24 W :B:.300. 4.1 :34 S 55 7 W :34c) 0. 4:3 50 S 55 2'P W ~ .,0o. 44 44. :E; 55 :"-:8 W _ . . - .5 6 56 5'2 :--: 6 C)0 4- :_-: '.--; W :B70C). 4.3 :::/.:, ::; .i:_;78 W :_-..:F-:00. 4. :3 38 S 57 14 W :::.::900. 43:3:7 S 57 43: W 100. 2913.79 1 (])0. 2.996.. 75 100. 3077.01 100. :':: 153.7S,' 100. :3227.28 4:2:4 2g '-"-'~'" · . ..,:,._,,:-,. 7:0 489.78 '2939.75 549. 1. 1 :3020. o 1 61:3.08 :3096.7'.-} 680.84 :3170.2:3 100. 32'.-'.,'8.87 750.63 3241.87 100. 3370.40 820. 4'.-.-.' 3313.40 100. 2:44.2,61 ::::::':.~_ _. ,/_-,6 ._,.':,.':,o~._,,_,._. 61 100. :3515.01 95:3./_-.4 3458.01 100. :-_-:587.40 1027.62 3530.4~"~ 2:.2::3, 10 S :35:4.51 W 43:E:, 2:3 . S 4.'? 45 W 2. :3'.'-..' :317,'.".~'.:,' :E; .378.07 W 4S.~4.02 '.:; 4'P 56 W 3.16 :2:54.76 ::; 424. 'P'P W !55:3.6 C) '.3 .5 C) 9 W 4.2 (]). '3':} l. 77'- ':".: ......... 477 :::0 W 617 4/- '.:; 5(] :37 W :':: · F:;O 4:30. :.32 S .~::::"4.05 W /_-,85.07 S 51 5 W 2.28 4.69.81 S 590.63 W 754.69 S 51 ::-:0 W 0.'?1- 508.63 S 648.7:.3 W :::24.35 'S 51 54 W 1. 18 546,3:0 ._,c- 706 .75 W ,c:_ 9. '::._. 27'.:; ~_ 2_ 1 :.2: W o.. :38 583.69 S 764.71 W 962.02 S 52:3'? W 0.c) 620.78 S 822.87 W 1030, 77 S 52 58 W 0. :3:3 4 c) c)o . 42 4.4 ,.s; ._,_,.'9':' 44 W 4.1 i'~. ("~_. 4. 2: ~_ 1 c.._, F:;_ F.: 2.0 W 4, 2()0. 42 22 S 5:.2: 2 W 4.:'=:00. 4-2 56 :E; 57 3::: W 4400. 42 10 8 5:_.: 48 W 100. :3660.33 10'B6.04 3603.3:3 100. :_.:733.71 1163..'2.6 3676.7 _1. 100. 3807. :31 1231.66 3750.31 100. 3880.86 12.99.41 3823.86 100. 3954.53 1:367.02 3897. 6 .... ~.,. :31 :S ::'P, 1. ¢)4 W 10'..-7:3 '~)'."'S ~9:':: .1. ::: W 692.27 $ 938.99 W 11./:,6./_-.0 '.:: 5:':: :::6 W 727. '?"6 S 9¥76, 52 W 1234. O'F~ .'S 5:3 51 W 764.0.'3, S 1053.87 W 1301./_-.9 S 54 4 W 7'.~TM. 65:3 I 111.35 W 136'.-.-,'. 14 'S 54 16 W 1. 12 - 0 ,, :2:0 0 · 52 0 ,, 6:3 1..1. () Zl. 500. 42 1 S 58 59 W 4600. 4:2 13 :iS 58 5:3 W Zl, 7('x). 4.2 1:2 '.E; 5:3 56, W 4.:BOC~. 42 13 S 5:3 48 W ( "00. 4-:2 5 'S 59 12 W .~: ..... (') o 0 . 4- 2 6 ._,':' 5_ ':}. 1:2 bi '9 ! ('~o. 41 F: '.--.; 5'::' 4 ! W 52o0. 4t 11 S 5:.2:29 bi 5 300. 4, .1.1:2 S 58 !2 bi .'94, 0(") 41 o S ........ ._7:2:7 N 100,~ 4028.74 1434.04 :3'271.74 :__.:34.29 S 1168.75 W 14:_.:5, 97 :E; 54. 2'F." W 100. 4102.92 1. 501.0'P 4045.'P2 868.90 S 1226.:20 ,W 1502.8!5 S 54 41 W 100. 4.177.00 1568.24 4, i20.00 S"03.59 S 12:_.:3.72 W 156'.'-,'. :::4 'S 54 52 W ..... 1 :,.:,...,, 42 41 ..... . .... 100. 4";'.~ 1 06 /' '-' = 94 06 '~) :::::: '-": 4 S 1341 24 W 16:36 8:::: '.S.., '='''-:, 1 W 100. 4325.20 170:2.51 4268.20 972.90 S 1:37v8,, 77 W 1703, 85 '.:; 55 1 1 W 100. 4:399.40 1'769.52 4342.40 1007· :23 S 1456.36 W 1'770.7::3 S 55 20 W 100. 4474.16 18:35. S.,' 1 4417.16 1041.50 S 151 :'_-:. 25 W 1837.02 S 55 '.'..?. f-i: W 100. 454'P. 44 1901.71 4492.44 10'75. rE:O '.:: 156'P. 4. :2 W 1 S.,'0:2.74. S 55:34 W 100. 4624.. 68 1 S.,' 67.57 4(567.6 :'-: 1110. :':: 7 '..2; 1/_-. 25,48 W 1 '.-:' 68,. 5 :'_:: S 55 4. () W 100. 4700. (:)3 203:3. :31 4/_-.43.0:':: 1145. :30 S 1681. 17 W 2(:):34.. 22 S 55 4,4 W 0. 1 '? O. :,_.-..: :1. o. 0,4 (). 0.30 0.02 1.0:3 0. 14. 0. 1 ? 0.4:3 5500. 4.() 59 S 52 5 W 5600. 41 !57 S 48 50 W ._. 7 (]0 4.1 · ,,.' '.-'; 4::-.":: 21 W 58(')0. 41 35 '.S 4:B 14 W 5S'00. 41 50 S 47 4.1 W 1¢)0. 4.775 . ='?.-.'._ .,_ 2 0'--¢ ,'.:::. .. .. . :::0 4718 . .=;2.. . 11c"':',_,..,., . 04, ...,c:. 1734.78 W 209'P. 77 ':'._, '=='._.,._, 4:2 W 100. 485O. 44 2164.54 4793.44 1225.20 S t785.85 W 21./,:,5.7:3 S 55 3:3 W 1 ,:,.: ..... W 07 c- 5:9 ...... lO0. 4924 :.2::3 2230 55 4:367 o.-., '-'*'~ 9,/:, '-"-' .... ..... ,_ ..... 1:7' 6 9.4 0 :--'; ..- z.o...' .... ".:' ¢"~ W 100. 4'F)99.47 22'.-.-~6.2/_-, 4'.-}42. 4'7 1:313../:,7 S 1885.65 W 229:3..1. 4 S 55 :.2: W 100. 5074.12 23./:,1.:E:'~.:' 5017.12 ' 1358.23 S 193:3.06 W 2364..16 S 54 56 W 3.6:3 2.3'7 0 ,, :34 0. 0.44 R C 0 Al._ A S K A, I N C .. ~:=: 7, WELL_ NO: 24 SIGMA-GYRO 'RUDHC~E BAY, NORTH '.E:LC~PE, ALASKA ,JOB NO: AO58:3RO:B47F'Z C 0 M P U T A T I (] N T I ME DATE 12: 06: 28 14-,_1UN-8:3 P A GF I',lr3. TRUE tEASURED DRIFT DRIFT COUR::;E VERTICAL VERTICAL sI_iB'.E:EA R E C: T A N G U L A R C L 0 '.=; U R E DOGLEG DEPTH ANGLE DIRECTION LENC..i'¥H DEPTH '.::ECTION TVD C 0 0 R D I N A T E .'_=; DISTANCE DIRECTION :SEVERITY FEET D M D M F'FET FEE]' FEET FEE']' FEET FEET D M EIG/1 ,:"~,~")F-[' 60~")0,. 42 21-~ S 47 26 W 6100. - 42: 54. S 50 30 W 6200. 43 12 '.S 50:36 W /=,:300. 4.2 42 S 50 54 W 6400. 4:3 30 '.=~ 51 18 W ~! ,~('~ 44 12 ,.E; Sl 48 W 660(]). 44 18 S 52 0 W /.':,700. 44 12 S 52 18 W A80F~ 44 /: :=; ._~ 48 W /=.'FLOC). 4.4 18 S 52 54 W ..... ' .......... 54 44 W 1 ¢~(]) 514:-_-:. :::4 2427 91 F,¢)91:34 14(:):7.-: 4A S 19:94 52 W 24:::¢~. 64 S 100. 5221. 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'.E; 52 6 W 780(]). 4:3 54 S 52 12 W )0. 43:32 'S 52. 12 W 8 c")c.'.)0. 4. :'-2 '-3 52 · _4 ~:; 6 W 1C)O F,'-' F,~ % . W 31 '-:'(') 12 'S 5/I· . ._, :,,' ....... 1 W 100. 5942.67 3184.61 5885,67 1875.88 S 2580.68 W 31'.~0.4:=: S 5:--: .5'.T~ W 100. 601:3.39 3255.02 5956.39 1919. 17 S 2636.59 W 3261.11 S 53 57 W 100. 6084.16 3325.33 6027.16 1"B62.76 S 26~2.18 W 3331.71 '.=.; 5:3 54 W 100. 6154.75 :3:3.95.82 6097.75 2006.56 S 2747.8!5 W 3402.4'?~ S' 5:;.]: 52 W 6.,::.,.:.._ 21 :::466 45 61 / '" ':.:' :=: C) :=: W :347:3 41 % .'=1:3 4'.=..' W 10(]) .... .=, . =,,=, 21 2¢)F, 0, ":-'=~ '=' 68 10(]). /=,2'.T,'5. ':l:'2 :=:5:36.8:3 6:.~:38. '.T,,2 209:::. ?8 S 28!:'~'.:::'. :3:=: W :::544.08 S 5:3 4.7 W 10(). 6:2:67.0¢).. :3/=.06. '='~._.._ 6:310.00 21:=:7.28 t=.; 2'::,' 14.,. .76 W ._'=:/-. 1,~T_ . ._'=:'=.'.. S ~3_ 45 W 10¢). 643:=:. 6:3 :~676.3:3 6:381.6:3 21:=:0. t 0 S 2'~/=.'i;'. 86 W :=:684.14 S 5:3 4.3 W 100. 6510. '~;~ 1 3745.15 645:3.9' 1 22'22.45 S 3024.47 W 375:3,22 S 53 41 W 1(")('). 658:3.78 :3:-:1:3. f:::=: 6526.78 22/.:,4.47 S :3078.54 W :=:F::21.68 :--; 5:3 40 W :i!i:l(')C) 42 18 S .'"',"." (:) W 100 /-./-..'=F7 :=:? .'=: F: :=: ¢) 72 6600 :'=:9 '-,'='c~/- lC) '=' .... =' "'"'-"-"- .... '=F" -' ...... ............ · , .............. :, 1 1 91 W -,,-,,-,-/ :]-;:4'.: .... :, ::::.':: W 8:2 (])0. 42 54 S 52 6 W 1 (])0. 6'7:31.0 (]) :3'? 48. 11 6674. C) C) 7_' 347.7:3 '.E; 31 :B 5.28 W :395'7.0 (]) S 5:3:36 W 8300. 43 18 S 52 '..'.:4 W 100. 6F.:04.02 4016.15 /=,747.02 238'P.5./::, S 323'?. :31 W 4¢..)2.'.5. :31 S 5:'-: :3.':"~ W :_=,'4(.')(:). 44 0 S 5:2 4:2 W 100. 6876.38 4084.'?2 681'P. :38 24:31..'.53 'S 3294.1(:) W 40'74,.3:2 S 5:3:34 W 0.2:iii: 0 ,, 8() 0. ]i!:'!~) . (]). :2:(]) 0. ('.). 00 0.4(") ("). i.'..:4 ('). 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F.:.:$7 W 4447.29 S FJ;:E: 34 W 0 ,, 4'? 0.4.2:' 0.4. :2 0.4. 1 £). 44 LASI<A, INli:· WELL NFl." 24 ::;II31'lA-13¥RCl PRLIDHOE BAY, NORTH SI_riPE, ALA:E;KA ,_lOB NO: AO58:3RO:347PZ I]: I]1M P I_1T A 'T I 0 N T I ME DATE 12: 06: 28 14 -,J U N- :=: :2: F:'A G IE hlr.'.l. 'Zl. TRUE MEASURED DRIFT DRIFT COUR:=;E VERTICAL VERTIC:AL '.=:UBSEA R E C: T A N G U L A R C L 0 ".=; U R E [~CIGI_EG DEPTH ANGLE BIREF:TION LENGTH DEF'TH F;ECTION TVD C 0 0 R D I N A T E S DISTANC:E DIRECTION :s;EVERIT',' FEET D M D M FEET FEET FEET FEET FEET FEET D I,1 DG/10(-)F-I ':700A. 45 12 S 54 42 W 'P100. 44 18 S 55 0 W 'P:20~'). 4:2: /.. '.:; 55 () W '?:2:00. 41 54 S 55 18 W ?400. 42 0 S 55 4:3 W · 5(-~0. 41 24 S 56 0 W ...... .56 9/-,~'~ A 4 (] 54 '.=; 24 W '.:.) 7 (')0,4.0 (] S S 6 54. W '?:=-:00. :.3'?:3:0 S 57 54 W 9900, :38 24 S 58 42 W 100. 7300.75 4508. 12 724:3.75 2682.5:9 S 3/.,35.'P2 W 4.518.42 S 53 35 W 100. 7371.77 4.578.45 7314.77 272:}. I i :E; 3693. 4:=-: W 458:-=:. 8£) S 5:3:36 W 100. 7444· 06 4647.47 7:387.06 2762.74 '.=; 3750.07 W 4657.87 S 5:3:37 W 100. 7517.79 4714. ?7 7460.79 2801. :34 S :3805.51 W 472._='. 40 'F; 5:3:39 W 100. 7592.16 4781.78 7535. 16 2839. 15 S 3860.6:3 W 4772.21 S 5:3 40 W 100. 766/',. 82 4846:. 27 7609.6:2 287/',. 45 S 3'?15.72 W 4.858./.,:=: S 53 42 W 100. 7742.12 4914.06 7685. 12 2913.05 '.3 :3'~70.40 W 4924.42 S 5:3 44 W 100. 7818.22 4978.S.~3 7761.22 2948.72 S 4024.59 W 4'.=.'87~.22 Si; 5:3 46 W 100. 78'P5.10 5042.8:3 7838.10 2'.-.-¢8:3.17 S 4078.46 W 5053.03 S 5:3 49 W 100. 7972.87 5105.73 7S/15.87 :3016.20 S 4131.94 W 5115.71 S 53 52 W ~]~. :31 0. 'P2 . 1.2o I .22 0. :35 0./=. 1 (-). r..-.--., _ .D / 0. '.:;' 6 1.21 10000. :3 '7 6 S 57 18 W 10100. :'36 18 S 60 0 W 10200. :35 12 S 60 12 W :!.0:300, :34 .'_-:(:~ '..=.; /.,1 6 W 10400. :34 18 S 61:30 W 1050('). :34 0 S 6:2 0 W 10/=,00, :3:3 18 S 6:3 :_::(') W 10700. :=::3 12 S 6,4 0 W 10:=:00. 3':.=' :=:0 S 6:'=: .48 W ' 9(')(') '-"-' ':' 62 1 P, W ..... =,z. 24 ._, ... 110()0. 3:2 :=:6 S 60 42 W 1. 1; ()(').. ....°'='.... 0 ._,c. Pi'Fy_ 18 W t1:.20¢). :=:1 54 S 58 24 W 1 1:=x')0... :'::1 48 c.._. F'i-/_1°,_, W 100,, 8460.61 Rzt.=,z~._ ~._ -, 41 840:3.61 31°'=',_,,., , 7/., F; 44.=,._ ,4.5 W 5462 .7o S rq4_ 17 W ,:,,_, 4.:, '-'"- ~ ~'' "' '] '"~'-' "4 P; 5 '=; .... ' 1(')('). '-"= '-' .S,.=i(')'T,~ ,=,4,:. 6 '""'= 0 h"~ . mm i~ ......... ,= ...... ..-14 I S 4484 71 W 1'7,,54 54 .-".,' W ,-, .~. - .- .. ¢. :;--,.-, :::,.-y .~,% 100 8627 4° 55/.4 08 ,:,.., 70.48 :32.'38..::::: ._, 4 .... :,.:,. W ._ ,_ / 1 /-,.~ S 54 ""-' .~. (:, W 4 ._, ,=, i · 6 A W %' '?: ~ ,_-, 0._ '~ - - 1 (:)(:) L=.: 711.4. 9 .... 617, 98 "-" ='" 49 3'.::' 62 '='.-"5, S ='-' '-' ....... · _ o,:.._,, 1/-,".E; 54 :.'4:':: 14 1. :35 0.90 1.].1 C). :'.:]:7 0. :3C) ('.). 4.1 I. 0.29 (). 71 0. :E:8 (). '.:.)6 C). 4.'? 0.59 F'I?O,_IEECTED TF_I 11 :=::'::'? PR 0 J mE C"I' E D 'r f"l P B T D - I 1 .:,.:,._ I'1D ., 1:L:377. :31 48 S 57 18 W ... .._ ;.-.4 /-0 9142 '.:../7 3416 29 '._=: ¢)3 W ~ '-} .'=: O . F: ¢) ._, P;4 :Z;C) W 4. 2. 9199 ,? 7 =; ¢/'-' . ...... 4848 ......... o _ C). F: I NAI_ CL. Zr.31_IRE - D I REC'T I L')N: D I '.=: T ~ N C [:" ~ · :,E _..:, W :--; 54- DEG:E; 4'P M I N.S 4:2: '-' I-"-' J' · J- ,-i ' ._, ?..:, (..). :=: C) F E E T ARCO AI._ASKA, INC. [~:.-} 7.~ WELL NO: 24 SIGMA-GYRO .JOB NO: AO583RO347F'Z PRUDHOE BAY, NORTH SLOPE, ALASKA SIGMA-GYRO, 0-11:}00 MD, .SURVEYOR: PEFFERKORN/MILLER, 1lATE RUN:23-MAY-83 '.--;IGMA/GYRO NE): 271, PROBE NO: 0~:.'? FORESIGHT: N 7 15 W SURVEY TAKEN FROM WELLHEAD RECORD OF INTERPOLATED SURVEY ARCO AI....A::;KA,, I NC. CONF'LITAT ]'ON DS 7, WELL NO: 24. '.:;IGMA-GYRO ,_lOB NO: AODS:_:.:RO:::4-ZPZ 'FINE DATE PRI._IDHOE BAY, NORTH SLOPE, ALASKA 12: 08:47 14-,JI.,IN--8::.::: MARKER ........ TRUE SLIBSEA C:O[IE MEA:-];LIRED VERTICAL MD-TVD VERTIE:AL R E C: T A N G I_1 L A R C L 0 F; U R E NAME F'AGE biO. DI--PTI4 DEPTH D IFF DEPTH FEET FEET FEET FEET VERTI CAL C 0 0 R O I N A T E S DISTANCE DIRECTIOI,,I TH]'CKNE:_=..;:!:; FEET FEET D M .JB TOP '.:_:;AG R I VER TOP SHIJBLIK A T OF' '.E;FIU BL I K B TOP '._:;HLIBL I K C ( -' '.::ADLE:ROCH I T G/O CONTACT 'f' OP Z ON E :2: TOP ZONE 2 HOT 10407.00 8383.64 202:3.4 :s:326.64 :_:: 164.05 '.3 4:::87.46 W 10627.00 :E:566. 4-3 2060. 6 850'.'--~. 4:--': 3220. /-',8 '.:_'; 44'S~7. 9'.:.~ W 1066:_::. 00 857~6.53 2066.5 85:.:,'?. 53 322'.'}. 4-1 .,E; 4515. /-','.'-.~ W 10/-','.:.~7.00 8624.97 2072.0 :E:567. 97 3237. 66 ,.E; 4532. 41 W 10711.0¢~ 8636.72 2074.3 857'.~. 7? 3241 · 01 ,.E; 4537. 25 W 10750.00 :::66'.':*. 48 2080.5 :::612.48 :-::250.31 S 4.558.24 W 10790.00 8703.08 2086.'.-) 8646.08 3259.86 S 457'7.73 W 11001.00 ,'_::8:::1.06 2119.9 8824.06 3312.47 S 4678.11 W 1108L:,'. 00 8954.59 213:2:. 4 8897.59 33:_:,'5.71 '.S 4.718.37 W I i 163.00 9018. 19 2144.8 8961. 1 ~ :2:356.16 ,.'E; 47.=_;2. 45 W 5410. '.:) 7 :S ~ · _4 1:3: W 55:2:2. 15 '.:; 54 24 W 5551 /-,'q S 26 W · - .- .-=,4 5570.02 S 54 2:E: W 5577.5:} S 54 28 W 55'?,'8.4.0 S 54 31 W 561'.~'.81 S 54 :~:~ W ._, 7.:. ,.. 12 '.::; 54. 4'.-..! W 577:::.40 S 54 4-4 W 581:::.05 ."=_.; 54 46 W O/W CONTACT 11228.00 9073.:37 2154.6 9016.:37 :3:374.15 :_:; 4.781.72 W 5 8 5'.':_). :'-':3 S 54. 4. 8 W TELEEO TELECO OILFIELD SERVICES INC. 6116 NIELSON WAY. ANCHORAGE. ALAS'KA 99502 TEL. (907) 562-2646 ARCO ALASKA PRUDHOE BAY WELL PAD DS-7, NO. 24 PARKER 176 JOB NO. 268 AK Attached please find a copy of the computer calculated survey for the above mentioned well. On behalf of Teleco, I would like to thank.you for the opportunity to serve Arc6% We at Teleco understand the importance of good service and are always striving to supply only the highest quality service to Arco. Please feel free to contact me if you have any questions. Sincerely, Steve Billeaud Field Service Supervisor SB/km Enclosures Alaska Oil & Gas Con,~. Oummissjor~ Anchora§e SURVEY REPORT pRGE CUSTOMER : ARCO '. LOCATION : PRUDHOE BAY, ALASKA WELL PAD : DS-7 WELL NO. : DRILLINO CO. : PARKER CUSTOMER JOB NO. : TELECO JOB NO. : 268-AK MAGNETIC DECLINATION : 30.30 E PLANE OF PROPOSED DIRECTION IS m 24 RIG NO. 176 S 57.27 W TELECO OILFIELD SERVICES OF ALASKA, INC. 6116 NIELSON WY., ANCHORAGE, ALASKA, 99502 TEL : (907) 562-2646 DATA REDUCED BY RADIUS OF CURVATURE METHOD TYPE OF SURVEY m MAGNETIC START DATE m 04/30/83 FINISH DATE m 05/12/83 REPORT PREPARED BY m DAVE REIMER MEASURED DRIFT TRUE VERTICAL DRIFT TOTAL COORDINATES C L O S U R E S D~8 _ LES DEPTH ANGLE VERTICAL SECTION DIRECTION DISTANCE ANGLE SEVERITY DEC MIN DEPTH DE8 MIN DD MM SS DEB/lO0 FT. 1392 0.00 1392.00 0.00 S 57.00 ~ 0.00 S 0.00 W 0.00 1440 4.12 1439.97 1.74 S 72.00 W 0.76 S 1.59 W 1.76 S 64 30 00 W 1534 4.42 1533.68 8.97 S 58.18 W 3.82 8 8.21 W 9.05 8 65 01 25 W 1.~46 1625 4.24 1624.40 16.19 S 53.24 W 7.87 S 14.18 W 16.22 8 60 57 17 W 8,939 1717 5.00 1716.09 23.72 S 62.30 W 11.87 S 20.57 W 23.75 S 60 00 05 W i,838 1811 6.18 1809.63 32.90 S 67.24 W 15.79 S 28.95 W 32.98 S 61 23 18 W i.474 1902 7.24 1899.98 43.57 S 67.48 W 19.93 8 38.99 W 43.79 S 62 55 31 W I.~10 1994 8.54 1991.05 56.55 S 57.54 W 25.88 S 50.~9 W 56.83 S 62 54 28 W ~.~27 2086 12.06 2081.51 73.30 S 50.54 W 35.64 S 64.23 W 73.45 S 60 58 22 W 3.738 2178 14.42 2171.01 94.41 S 47.24 W 49.59 S 80.35 W 94.42 S 58 19 15 W ~.959 2302 16.54 2290.32 127.75 S 49.06 W 72.07 S 105.54 W 127.80 S 55 40 23 W 1.B13 2458 21.30 2437.65 178.18 S 44.12 W 107.29 S 142.85 W 178.65 S 53 05 30 W 3.122 2591 26.30 2559.15 230.79 S 43.30 W 146.30 S 180.32 W 232.21 S 50 56 51 W 3.765 2684 29.24 2641.30 273.25 S 44.54 W 177.55 S 210.71 W 275.54 S 49 52 57 W 3.197 2776 28.54 2721.65 317.20 S 47.00 W 208.70 S 242.92 W 320.26 S 49 19 57 W I.~37 2867 30.12 2800.81 361.48 S 48.48 W 238.79 S 276.22 W 365.13 S 49 09 23 W 1.730 2960 32.00 2880.44 409.27 S 54.06 W 268.73 S 313.79 W 413.13 S 49 25 23 W 3.~21 3052 34.06 2957.56 459.18 S 48.48 W 300.00 S 353.03 W 463.28 S 49 38 33 W 3.882 3144 36.54 3032.46 512.28 S 53.00 W 333.69 S 394.49 W 516.69 S 49 46 21 W ~.~35 3~36 39.06 3104.95 568.80 S 54.06 W 367.34 S 440.05 W 573.22 S 50 08 44 W ~.~02 3329 42.18 3175.46 629.34 S 53.42 W 403.08 S 489.05 W 633.75 S 50 30 16 W 3.452 3849 43.36 3556.07 983.39 S 56.30 W 605.79 S 779.64 W 987.33 S 52 09 07 W 0.444 4346 42.54 3918.07 1323.93 S 57.54 W 790.26 S 1065.88 W 1326.88 S 53 26 46 W 0.~9 4839 42.06 4281.55 1656.87 S 59.42 W 962.80 S 1350.77 W 1658.78 S 54 31 10 W 0.295 5300 41.06 4626.29 1962.38 S 61.48 W 1112.35 S 1617.82 W 1963.33 S 55 29 20 W 0.~72 DIRECTIONAL DRILLING SURVEY REPORT PAGE 2 JOB NUMBER : 268-AK CUSTOMER : ARCO PAD m DS-7 WELL NO. : 24 MEASURED DRIFT TRUE VERTICAL DRIFT TOTAL COORDINATES C L 0 S U R E S DO8 - LEG DEPTH ANGLE VERTICAL SECTION DIRECTION DISTANCE ANGLE SEVERITY DEG MIN DEPTH DEG MIN DD MM SS DE8/t80 FT. 5550 41.54 4813.52 2128.03 S 53.42 W 1200.75 S 1757.92 W 2128.86 S 6009 42.24 5153.82 2435.40 S 53.24 W 1383.75 S 2005.68 W 2436.70 S 55 23 51 W 0.1t? 6379 43.18 5425.08 2686.46 S 53.24 W 1533.78 8 2207.70 W 2688.20 S 55 12 38 W 0,~3 6876 44.12 5784.10 3029.66 S 55.06 W 1734.57 8 2486.62 W 3031.83 6969 44.30 5850.60 3094.62 S 54.48 W 1771.91 S 2539.84 W 3096.84 S 7436 45.18 6181.40 3423.81 S 53.42 W 1964.50 S 2807.37 W 3426.45 7930 43.30 6534.35 3768.63 S 53.00 W 2170.82 8 3084.67 W 3771.95 8430 44.06 6895.23 4113.65 S 52.36 W 2380.05 S 3360..33 W 4117.82 ~ 54 41 26 W 0.~3~ 8884 45.42 7216.81 4433.42 S 54.24 N 2570.67 S 3617.93 W 4438.22 S 54 36 17 W 9080 44.42 7354.92 4572.26 S 53.30 ~ 2652.52 S 3730.38 W 4577.29 S 54 35 05 W 0.68~ 9174 43.42 7422.31 4637.66 S 53.42 W 2691.41 S 3783.13 W 4642.81 S 54 34 15 W 1.074 9680 40.24 7798.05 4976.24 S 55.48 W 2887.01 S 4059.89 W 4981.72 S 54 34 59 W ~.709 10175 35.36 8188.11 5280.96 S 60.24 W 3048.05 S 4318.62 W 5285.93 S 54 47 08 W 10425 34.18 8393.02 5423.77 S 62.48 W 3116.17 S 4444.60 W 5428.16 S 54 57 54 W 0.?~? 10519 33.48 8470.91 5476.11 S 63.54 W 3139.77 S 4491.64 W 5480.24 S 55 02 43 W 0.844 BOTTOM HOLE CLOSURE: 5480.23 PRINTED m 26 MAY, 1983 2:10:10 PM FEET AT S 55 2 43 W COPYRIGHT (C) 1983 ABACUS COMPUTER SERVICE 820 W. 71st AVENUE ANCHORAGE, AK. 99502 ( 907 ~ 344-0761 Eastman/ Whipstock A FETROLANE C, OM~ REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY D. S. 7, Well Number: 24 WELL NAME Prudhoe Bay, North Slope, Alaska JOB NUMBER CDC A-0483-028 LOCATI ON RECEIVED TYPE OF SURVEY TELECO AI~ gl! ~ Gas fJons. 't.u,,,mssion DATE 17-MAY-83 SURVEY BY A CHAPMAN OFFICE Anchorage, Alaska ............. A RC:O ~..~ ALA SKA.--I NG,~ ' DE; 7' WELL NO: 24 TELECO (CDC:) PR'UDHOE BAY, ' NORTH SLOPE, ALASKA ......... TELEGO-, .... O,,-,IO~I.,,9---MD,--DRI ~LER.: .... A,-C4HAPMAN ~ SURVE,¥-pRov I DED-B¥-E:DG RIG: F'ARKER 176 CDC JOB NO: A-0483-028 ,4 f:'FT:R(..)LANE COIVIF~INY RECORD.--OF-.$URVEY ................. t ................ RADIUS OF CURVATURE METHOD ~RCO ALASKA, ][NC, COMPUTATION ' PAOE NO. 1 · .::, 7, WELL NO: 24 ....... TELiECO ........... (CD~'} ........... T'IME .................. DATE- :'RUDHOE BAY, NORTH SLOPE, AUASKA 11: 4(:.: 30 17-MAY-83 · ..... TRUE ................. : ....... ,,, IEASURED DRIFT DRIFT COURSE VERTICAL' VERTICAL SUB,SEA R E C: T A N G U L A R,. C.. L O S U R E DOGLEG DEPTH ANGLE DIRECTION ~ENGTH DEPTH ,SECTION TVD C O O R D I N A T E S DI'STANCE DIRECTION ,SEVERI FEET .............. D H ................ D'.-'-M ......... ~' FEE'T ................. FEET ....... 'FEET ................ : ........... FEET FEET FEET ................. : D .... I'1 .......... DP-,/-tOOFT O. 0 0 0 0 O, 0,00 , 0,00 -57.00 0,00 0,00' 0,00 0 0 0,00 1392, .......... 0 ...... 0 .............. 0 ........ 0-- ....... 1..3e-2 ~- ....... t.-3 .g2.~.-00 ..... 0'~" O0 ........... 1-335 ~ O0 .............. 0 ~' 00 ............................... O, 00 ......................... 0 ,-00 0 0 ................... 0 ~ 00 ...... 1440. 4 12 S 72 0 W 48. 1439,9& 1,70 1382,96 0,54 S. 1,67 14 1,7/_-. S 72 0 W 8,75 1534, 4 42 $ 58 0 W 94, 1533,&7 8,91 1476,67 3.62 S 8,27 W 9,02 S 66 22 W 1.27 ' 1625. ' 4 24 'S '5:3 ........ O"'W ............... e t"~ ................. t 624'~"39 ...... 16~"1'~ ........... 1567'~'89 .......... -7','7't--'S ..... 14'~'"~ t--"W ........ t'6'~'t7 ....... S ' 61 ' 32 W ......... O~ 55 ..... 1717 5 0 S 62 0 W 92, 171(>,08 23,6(> 1659,08 11.75 $ 20,56 W .... 1811~ ................ 6.,'t8.',,S ' 67 ......... 0"- W-.~-,94..~- ............ '1809-~-62~: .... 92~,.84 ........... 1752.~,6~ ........ 1.5 ~...73-..,9 .......... ~8~.~t-W ..... 1902. 7 24 S 68 0 W ~1, 1899, 97 43, 52 1842,97 19,89 S' 38, 1~4. 8 54 S 58 0 W ~2. 1~1.04 56,~ 1~34.04 25,80' ........ 2086.' ......... 12 ......... 6"'$' '51' ...... O--W ........ e2'~---2081';'48'~7C~."~2 ....... ~024'~'"48 .......35.'53"-S ........... 64.-te--W , 2178. 14 42 S 47 0 W -,~-- ~ -~J~2170'~~'~'~";~:~'1"~'~"~'~ 49.51 8 80.27 W ~4.31 2302. ..... 16 54-'S'4¢ ........ 0 W 1~~22~0.~~~/~~j~8~, ~t~~~;,(~.36 W 127.,67 .... 2458 21 30 S 44 0 W 1~'~'. 12437. ~ --l~Tj~e~:;~ -2~80'. 56 _ 107.4q,,~ s ~$?~. . 2~{:~~.~[~2~~,l,.~[~3¢~?~i'~. 12 W 232 05 c; 50 55 W 3.76 ., 2~84. .....2~..24 8 .45 ....... 0 W ~~~ 2~~ ~~i~.[~l~~.~; A [:~ 'rROLANE' CC~MF:4NY 2776, 28 54 S 47 0 W ~2. 2721,52 31~.?E 2~64,52 208,51 S 242,~0 W 320.12 S 47 21 W 1,17 2867. .....80 12. S ... 4~ ........ 0--W ........... ~ 1.~ ........ 2800.. &8 .... 8& 1., 21 ..... 2743,-&8 .... 238, 54-.S ....... 27&,-25-W ..... 3&~...e9 8 49 .-.11- W ........... t.,77 2?~60 32 0 `S 54 0 W 93 2880 31 408 ~8 2823 31 268 .43 S 313.83 W 412 ~7 c; 49 27 W 3 ~"' 3052, 34 0 S 49 0 W 92, 2957,46 458,80 2900,46 299,61 S 353,03 W 463,03 S 49 41 W 3.67 ....... ~144, ...... C~&--S4--..S--~3.~(~.--W ....... ~2, S03~-4~~1-1--,-80 · .... 2~7~.,-40 3~3,-18-8. ' '.. C~94,4~W ~l.&.,-~& .... S.-49--.-49.-W-~,.04.~ 3236. 39 6 S 54 0 W 92, 3104.89 568,31 3047.89 3bb.87 S 440,01 W 572.89 S ._OM 11 W 2 48. ..... 3329. - 42 18.--8-...~4 ..... O...-W ..... 93,-.~31-75,39 ..... ~28,84 ..... 3118,.39.~---402.51.-S ......... 48~,07--W -~33,41 ..... `S 50-.33 W ........ 3,44 3849. 43 3& S 56 0 W 520, 3555,99 982,80 3498.99 ~05.72 S 779.28 W 987.00 S 52 9 W 0.36 4346 42 54 S 58 0 W 4~7, 3917 99 1323 31 38~0 99 791 18 S 1064 --. 4838, - .... 42 .... & - S.--&O .... 0-..W.~492.- .... 428~.73.~1~55~55 .... 4223,73 ... ~b2-,3~S---1349.-.7&~.W~-1&57-.71.--S. 54-.31-.W ..... 0,32 ...... . 5300. 41 ~ S ~2 0 W 4(>2, 462b,21 19~1,~7 4569.21 1111,06 S 1~18,01 W 19~.2.76 S 55 31 W 0.36 ~.5550,.~..41-54 -S-~4~O-..W 250,. ..... 4813.-45 .... ~12%,. 18 475&...45 ~- 1-1-~8.-]7 , M~ , ~ , Mr, oz_ . S 55 6009 42 24 S ~;~ 0 W 459 515~,75 2434 47 ..... 75 1381,~9 S 2005,98 W 2435 ?x5 26 W 0.18 ~379. 43 18 S 53 0 W 370, 5425.01 2~85.35 53~8.01 1533,42 S ~'3 . , ~(~.94 W 2~87 37 S 55 12 W 0.24 ARCO ALASKA, ~NC.~ COMPUTATION · PAGE NO. 2 DS, 7~ WELb-NO: ....... 24.:--~ELECO~ ~.~DC,) ' ~-t,M~-- .DAT~ ........................ PRUDHOE BAY, NORTH SLOPE, ALASKA 11: 46:30 17-MAY-83 · MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C L O S LI R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C O O R D I N A T E S DISTANCE DIRECTION SEVERITYf, ........ FEET D ....... M ................. D ..... M ........ FEET ....... FEE% ........... FEET ...................... FEE% .FEE,T, EEE~ ....................... D ..... M ......DGZ,1,DOETi o 6969. 44 30 S 55 0 W 93. 5850.52" 3093,34 5793.52 1772.71S 2538.22 W ' 3095.9,5 S 55 4 W 0.32 ' ......... 74~6 ......... 45.,lo.,~s-,,~4---~-w~' = ' .... ~,4.~ ~i~1.,..~1.-_~422.,55 ........ ~12~.,.3! ...... 1264 14..s ....... 2806.,,58-.W,--3425...60 ..... s.55 ....... l~.~.w ............. 0.2~ 7930. 43 30 S 53 0 W 494. 6534.25. 3767.35 6477.25 2169.72 S 30~4.41~ W 3771.11 $ 54 53 W 0.39 8430. 44 6 S 53 0 W 500. 6895.12 4112.39 ,6838.12 2377.9~ S 3360.80 W 4117.01 S 54 43 W .0.12 .... 8884- ......... 45.42...$....54 .......... O.-..W ........... 454 .............. 721.~.,.~0.-=-4432,D8 ........... ~15~,.~.0---2568,..~0.-S ..... 3~18,3~..W--4437.,.3~ .... 8.5~.38. W ....... 0,3~ .... 9080, 44 42 S 54 0 N !96, 7354,80 4570,91 7297,80 2650,34 S 3730,90 N 4576,46 S 54 37 N 0,~ ) .... ~680,..-.-.40,24.9....5~ .......... O-..N ........ 600,. ........ 177~b.,..7.t'-~4~76,~.16 ............. 7739.,.7! .... 2883,00-...$ 406:3,.l.7-N~.4W82,07 ........ $54.3W.N 0,75 10175, 35 36 S hO 0 N 495, 818~,66 5280,75 8129,66 3044,41S 4321,48 N 5286,18 S 54 50 N 10425. 34 18 S 63 0 W 250. 8391.57 5423.58 8334.57 3112.74 S 4447.33 W 5428.43 $ 55 '1W 0.86- .... 10519, ..... 83--48-$-.~4 .... O-W ...... ~4.,---~-.84~-,-4~ .... 54.75,-~2 ........ 8412.,-46..--~1~,.23...$ ..... 44~4,43-W--.~4~0,4.~ ........ ~,..55 ...... 6...W ........ 0,80 .... . , DRIFT CHART'S RELATED DATA FILE ~RE:O ALASKA, INC. iS 7, WELL"NO. ~4 TELECO (ODC) >RLIDHOE BAY, NORTH SLOPE, ALASKA E:LIRVEY FILE NUMBER 1714 BOTTOM HOLE ASSEMBLY VALUES USED FOR DEPTH ARE'MD ...................... ~...~ .......................................... j ................................................................ DEPTH DESCRIPTION ., . 1392. O0.......................... dETTING ASSEM~ ' 254(:}. O0 ,..IETT I NG ASSEM~ ' .' . . .~,. W pstoclr 3425. (30 LOCKED ASSEMB , 5448. O0 ...................... DYNADR ! LL' 555.9. O0 LOCKED ASSEMBLY A F'~TROLANE COMPANY ~.46.1. O0 LOCKED ASSEMBLY .. 8125. O0 LOCKED..,-ASSEMBLY 8~58. O0 LOCKED ASSEMBLY · ~270.00 LOCKED ASSEMBLY W/ROLLER REAMER --10610, O0 -- LOCKED-ASSEMBLY .W/ROEL~R.~EAMER ,) DRILLING DAYS ~"~_. ~1~. .................................................................. IJALI_IE,o-U.:.E D- F'OR-DEP-TH- ARE- MD DAY ............................... DEDTH ............................ 515..00 2085.00 2540.00 3425.,00 5 5000.00 6 5558.00 ................ 7 ................. , .............. 6461-.00 8 7471.00 9 8220.00 .................... 10 ...................... 8958r00 11 9270.00 12 10349.00 ................. 13 ..................... 10610.00. i 14 10620.00 15 11360.O0 ............. 16 11377.00 A FE!I'ROLANE COMPANY ...................................... WEtGHT-ON.--.BIT ................................................................................................................... . WEIGHT ZS GIVEN PER 1OOO POUNDS VALUES USED FOR DEPTH ARE ND DEPTH WEIGHT 1392. O0 ' 65. O0 2540. O0 ................. 6~5. O0 ....................... 3425.00 65.00 5448. O0 15.00 .... 5558. O0 60. O0 ................ 6461. O0 60. O0 7050.00 55. O0 ..... 8125. O0 ........................ 55.-00 .......................... 8958. O0 65. O0 9270. OO 65. O0 . :,: 034'P. 00 .................... 6~ ~-0(,;-.-: ....................... I0610. O0 40.00 REVOLUTIONS PER MINUTE --VALUE$-USED-FOR-DEPTH-~ARE--MD DEPTH ........ 106.00 .......................... -150-~--OE} -- 515. O0 ' 170. O0 1392. O0 85. O0 2540. O0 65~' O0 3425, O0 140, O0 5448, O0 O. O0 .... 5558. O0 ......... :--: ................... t'30-,~00 6461. O0 130. O0 7050.00 130. O0 .... 8125 ~ O0 ................. t-1-0'~-00 o.,......,~,. O0 1 O0.00 9270 · O0 100.00 10610.00 110.00 , Wt ipstock A F'/:? TROLANE COMPANY Suggested form to be inserted in each "Active" well 'folder to check for timely con~liance with our' rc<julatiork.q. Operator, Well Name and Number Reports and Materials to be received by: Date Required Date Received Remarks .. Completion Report Yes. .___ ..... ' . . ', _Samples : . :./,~-P!. .,. .Core Chips J'"> -~x/~-~- Core Description //p~/~._...¢o.._.. Registered Survey Plat :~ /~//'- · Inclination Survey ./~ '~ - .~ xc.;~.~-~! ~ ~- 7:- ...... , . . Drill Stem Test Reports /~ ?" ~ "~ , Production Test Reports ~,~_...~ . / ~ _:--_~,.. i +~. Digitized Data ~._/_...~¢ ~,: , , ,, . . ,,. .: ARCO AlaSka, Inc. Post Office B,¥r'?':'~0 Anchorage. Ai%~ 99510 Telephone 907 277 5637 June 20'~ 1983 Reference: A~'co Directional Data D.S. 7-24 4-30-83 D.So 14-23 6-13-83 Magnetic Survey Directional Single Shot Teleco EW ~ P/~~ease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. ~ 369 NORTH GEOLOGY : ..... '" EX~ka Oil & Gas Cons. Cuu~u~i~sion R & D HOB IL Anchorage DRILLING GETTY PHILLIPS D & M SOH I 0 ~.,S.TA-TE OF ALASKA MARATHON DALLAS CHEVRON CAROLINE SMITH · ARCO Alaska, Inc. Post Office Box J Anchorage, Alaska 99510 .TelephOne 907 277 5637 June 20, 1983 Reference: Arco Magnetic Tapes w/Listings --- ---- ~D. S. 13-29 5-2-83 --- ~D.$. 1-10 ' 5-12-83 -¢WD. S. 13-28/~--'* 5-22-83 -d~D. S.. 5~16 ~ 5-12-83 ~X D. $.. 7-24 ~' 5'14-83 -~D'. S. 15-11/ 5-6-83 -'lJ-. $. 1-17 '~' 5-13-83 /D.$. 11-2-'~ 5-7-83 . ____ ~ D.S. 5-12 5-12-83 ___ % D.S. 2-12 5-11-83 -~D.S. 13-98~-~ 5-29-83 · .,-U.S. 3-12~--' 5-8-83 OH tape w/Listing #68235 CH CNLw/Listing #68330 OH tape w/Listing #68314 CH CNL w/Listing #68331 OH tape w/Listing #68275' CN/MSN w/Listing. #1711 CN/MSN w/Listing #1715 CN/MSN w/Listing #1709 CH CNL w/Listing #68274 CH CNL w/Listing #68263 CH w/Listing CN/MSN W/Listing Run 1 Sch Run 2 Sch Run 1 Sch Run 3 Sch Run 1 Sch DA DA DA Run 9 Sch Run 2 Sch Run 4 Sch DA ~/Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 365 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON GETTY 'STATE OF DALLAS CAROLINE SMITH 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 Alaska Oil & 8as C. ons, f.;omm!ssion ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany A~l~[~lll[~ " , ,---. STATE OF ALASKA ~ ALASK/~ _AND GAS CONSERVATION C' .MISSION t~ MONTHLY REPORT OF DRILLING AND WOI KOVER OPERATIONS, ' · Drilling well [] Workover operation [] XX 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-63 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20945 4. Location of Well atsurface 1869' SNL & 244' FEL, Sec.- 33, T11N, R14E, UM 9. Unit or Lease Name Prudhoe Bay Unit 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. 58' ~KB~ 28' GL 10. Well No. DS 7- 24 11. FieldandPool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of May , 19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks : S~pudded ~ 0230 hfs, 04/30/83. Drld 17-1/2" hole to 2540', Run, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 10610'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 11377'. Ran logs. Ran, cmtd & tstd 7" lnr. Ran 5-1/2" completion assy. Secured well & released rig ~ 1800 hfs 05/18/83. 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/1900# Poleset. 13-3/8", 72#/ft, L-80 BTC csg w/FS ~ 2529'. Cmtd w/2050 sx Fondu & 400 sx PFC cmt. 9-5/8", 47.0#/ft, L-80 BTC csg w/FS ~ 10587'. Cmtd w/500 sx Class G cmt. 7", 29.0#/ft, L-80 BTC csg fr/10286'-11377'. Cmtd w/350 sx Class G cmt. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/BHCS/GR fr/11377'-10587' FDC/CNL/GR/Cal fr/11377'-10587' GR to 13-3/8" shoe CBL fr/11355'-10550' 16. 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 ,y TITLE DATE 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 CSM/MR1 4 Submit in duplicate 7-24 DRILLING HISTORY NU 20" diverter and lines. Spudded well @ 0230 hrs, 04/30/83. Drld 17-1/2" hole to 2540'. Ran 63 jts 13-3/8", 72.0#/ft, L-80, BTC, csg w/FS @ 2529'. Cmtd 13-3/8" csg w/2050 sx Fondu and 400 sx PFC. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 10.8 ppg EMW - ok. Drld 12-1/4" hole · to 3425'. Tight hole fr/3425'-3042'. Wash & ream 3303' -3364', 3304' -3425'. Drl to 5144'. Work stuck pipe. Spot 80 bbls SFT oil pill, pulled pipe free. Drld to 5558'. Ream 5448' -5558'. Drld to 8958'. Wash & ream tight hole 8644'-8958'. Con't drlg 12-1/4" hole to 10,610' (05-11-83). Ran 265 jts 9-5/8", 47#/ft, L-80, BTC csg w/FS @ 10587'. Cmtd 9-5/8" csg w/500 sx Class G. Tstd csg to 3000 psi - ok. 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 10738', lost all returns. Hole taking fluid. Spot LCM pill. POOH w/5 stds. Ream to btm. Con't drlg 8-1/2" hole to 11,377' (05-14-83). Ran DIL/SP/BHCS/GR fr/11377'-10587', FDC/CNL/GR/CAL fr/11377'-10587', GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 sx PFC cmt & 127 bbls AP. Ran 28 jts 7", 29#/ft, L-80 BTC csg fr/10,286-11,377'. Cmtd 7" lnr w/350 sx Class "G" cmt. Wash 9732'-9930'. Drld firm cmt f/10,000'-10,288'. TOH. Change BHA. Drld cmt f/11,150'- 11,355' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.7 ppg NaC1. Ran CBL fr/11355'-10550'. Ran 5-1/2" completion assy w/tail @ 10354' & pkr @ 10271'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Remove BPV. Secured well & released rig @ 1800 hrs, 05/18/83. CSM/DH15 06/07/83 RECEIVED ARCO Alaska, Inc, ' ,- Post Office . ,, 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 26, 1983 Reference: Arco Directional Data D.S. 7-24 5-17-83 Teleco EW D.S. 13-29 5-5-83 Teleco EW D.S. 1-26 3-27-83 Magnetic Survey Teleco D.S. 7-26 3-29-83 Magnetic Survey Teleco D.S. 13-29 4-20-83 Magnetic Survey Teleco P~~lease~sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 356 NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M i~:.S.TATEi OF ALASKA DALLAS CAROLINE SMITH ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 11, 1983 Mr. C. V. Chatterton Commissioner State Of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive -Anchorage, Alaska 99501 Subject' Monthly Report of Drilling & Workover Operations Dear Sir: Enclosed find Monthly Reports of Drilling and Workover Operations for the .following' · 7-26 DS 7-25 ~ DS 7-24 DS 1-26 DS 13-29 DS 5-11 NGI #7 S Point State #1 Sincerely, M. A. Major Area Drilling Engineer MAM/CSM'tw Attachments ARCO Alaska. lnc is a suhsidir~r¥ of Atlanl, :R,chfieldCompany STATE OF ALASKA .',. ALASK'~ ~ILAND GAS CONSERVATION C AMISSION MONTHLY REI ORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-63 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50_029-20945 4. Location of Well at surface 1869'SNL & 244'FEL, Sec. 33, T11N, R14E UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Desiqnation and Serial No. 58' RKB, 28' GL I ADL 28310 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 7-24 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of Ap ril ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded (~ 0230 hfs, 04/30/83. Drld 17-1/2" hole to 1392' as of 04/30/83. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40 weld conductor 14. Coring resume and brief description None 15. Logs run and depth where run None 6. 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 Drilling Engineer DATE 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 10404 Submit in duplicate DS 7-24 DRILLING HISTORY NU 20" diverter & lines. Spudded well Ia 0230 hrs, 04/30/83. Drld 17-1/2" hole to 1392' as of 04/30/83. CSM/ltc MO6 April 1 ~ 1983 Mr. ~ark A. Major Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Prudhoe Bay Unit DS 7-24 ARCO Alaska, Inc. Permit No. 83-63 Sur. Loc. 1869'SiqL, 244'~, Sec. 33, T1]N, P. 14E, Btmhole Loc 167'~R' 46'WEL Sec 32 Wlli'] Pl4E UM Dear ~r. '~ ~-~j 0%7: mnclo~ed is the approvsd application for Der~it to drill the above referenced well. I~ coring is conducted, a one cubic inch chip from each ~,:oo_ of recovered core is r~uired ~ples of well cuttings and a mud log are not required. A .continuous directional survey is required as p~r 20 AAC 25 n=n . .~,(b)(5). If available, a tape containing the digitized log information shall be submitted on all ~ o =~ · ogs ~o~. copying except experi~ntal logs, velocity surveys a~! dipmeter surveys Many rivers in Alaska a m their drainage sy~tens have been classified ag impOrtant for the spa~ing or migration of anadromous fish. Operations in thes~ areas are subject to AS 16.05.870 ~nd the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencin~: operations you may be contacted by the ?fabitat Coordinator~'s O~~, Depar~ent of ~_sh and Ga~e. Pollution of any waters of the State is prohibited by Ag 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as smended. Prior to commencing ..operation~ you may be contacted by a representative of ~ . ~m ' of ~e De~ar,~=ent Enviro-~ental Conservation. To aid us in s..nedulin~ field wor~, please notify nh~s office 24 hours prior to ...... ~ g com,~e~,~zn~.~ installation of the blowout Mr. Mmrk A. Major Prudhoe Bay Unit DS 7-24 -2- April 12, 1983 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 diverter system is. required, please also notify this office 24 hours prior to commencing 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. Ver~ t~uly yours, C. V. Chatterton ~Y OR'D~ OF THE COI~,/iIVIIS$ION Chairman o f Alaska Oil and Gas Conservation Commission Eric 1 o sure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. "~'"- Post Office B,._~. ,~$0 Anchorage, Alaska 99510 Telephone 907 277 5637 Harch 30, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 7-24, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 7-24 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 posi- tion 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 Dril ling Engineer MAM/jG2L42:sm Enclosures RECEIVED- APR 0 8 IBB3 Alaska Oil & Gas Oons. Oommissior~ Anchorage ARCO Alaska, Inc. is a subsidiary o! AtlanticRichfieldCompany · "-" STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION CO~,,MlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc· 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surfaceb~E& 1869' SNL & 244' ~Wt_, Sec. 33, T11N, R14E, UM At top of proposed producing interval #10' NSL & 335' EWL, Sec. 33, T11N, R14E, UN At total depth 167' NSL & 46' WEL, Sec 32, T11N, R14E, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 58' RKB 28' GL I ADL 28310 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line 5 mi. NW of Deadhorse miles I 46' ~ TD fr/ADL 28309 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 11368' MD, 9185' TVD feet 2491 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1400 feet. MAXIMUM HOLE ANGLE 41 oI (see 20 AAC 25.035 (c) (2) SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~X MULTIPLE ZONE [] 9. Unit or lease name Prudhoe Bay Unit 10. Well number /7 7-24 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool Amount $500,000 I15. Distance to nearest drilling or completed 7-25 well 121 ' (~ surface feet 18. Approximate spud date 04/28/83 3382 . psig@__~ Surface 41;~4 _psig@ 91R~ _ft. TD (TVD) SIZE ~ Hole ;,30- 7-1/2" ~ 2-1/4" Casing 20" 13-3/8" 9-5/8" Weight 91.5# 72# 47# 8-1/2" 7" 29# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling H-40 Welded L-80 BUTT L-80 BUTT L-80 BUTT Length 80' 2752' 0495' 1144' SETTING DEPTH MD TOP TVD 30' I 30' 30' I 30' 29' ~ 29' I 10224' 18323' I MD BOTTOM TVD 110' 110' 2782' 12700' 10524' 18549' I 11368' II 9185' QUANTITY OF CEMENT (include stage data) 1900 # Poleset (to surf) 2300 sx Fondu + 400 sx PF 500 sx G 1st stage & 300 sx PF 1, 2nd stage 400 sx Class G cement ARCO Alaska, Inc., proposes to directionally drill this well to 11368' MD (9185' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will 5e set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well. DS 7-25 will be 121' away from DS 7-24 at the surface. There are no closer wellbores anywhere down hole. 23. I hereby certify that the foreg~Pg is true and correct to the best of my knowledge The space below for Commission use CONDITIONS OF APPROVAL DATE Samples required f--lYES ~NO Permit number APPROVED BY Form 10-401 '-~I~U2/PD15 Mud log required I Directional Survey required APl number []YES ~]~O J ~._ES []NO 50-- 0 'i~ - Approval date I SEE COVER LETTER FOR OTHER REQUIREMENTS / //,~~~~.COMMISSl ON ER DATE ~_.._~'~'~/~ by order of the Commission // Submit in triplicate 13-5/8" BOP STACK DIAGRAM / ,, ANNULAR PREVENTER --J=-- BL IND RAMS PIPE RAMS PIPE R~S 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 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 30~,p~)psi and hold for a minimum of 3 minutes.'---Bleed pressure to zero. 6. Open annular preventer and close top~ of pipe rams. Increase pressure t~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 zero. Open bottom set of pipe rams. 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-freezing liquid and all valves are set in drilling position. 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. 16. Record test information on Ulowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev, 5/13/81 SURFACE HOLE D IVERTER SYSTEM ARCO ALASKA INC', SCHEMATZC 8 /" //'"' I ALL 90" TURNS ARE "TEE" ~ I CUSHION I ,. , .. ~ELL QBORE - I RESERVE PIT AREA NOTE' FLOV~ INE DR ILL RISER 20" 2000 PSI WP ANNULAR PREVENTOR '"I0" DIVERTER LINE 'Valves on diverter ~'-' lines open automati- cally when the annular oreventer is closed. DR ILL ING SPOOL 20" CONDUCTOR PIPE I O" HYDRAULIC OPERATED BALL "DETAIL" VALVES 2026010 CHK. DATE 5o~ T ILL-], ~ )4-P_.) U .h,1. I HEREBY CERTIFY THAT I AM 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 OTHER DETAILS ARE CORRECT, AS OF: --% OF ~'~... --".:...q~' l~ E1/z,, o s. h,,, (_.. 7/23 LAT - 7o°15'57.930', LONC - 145°34'36.537'' y = 5,~kg,534.44 X - 676,002.66 NV COR~ER CELLAR BOX EL£V = 26.82 7/15 LAT = 70°16'07-52N~' LONG = 148°34'15,431'' y = 5,9~9,926.66 X I 676,705.72 N~ CORNER CELLAR BOX ELEV = 27.29 7/16 LAT - 70°16'06.733'' LONG = 48°34'14.6~N'' Y = 5,949,810.19 X = 676,733.0~ N~/ COR~ER CELLAR ~0× ELEV = 27.44 7/17 L_AT = 70°16'05.225'' LONG = 48°34II3.954'' y - 5,9~9,654.09 x = 676,760.90 ~w CORNER CELLAR BOX ELEV = 27.31 7/I8 LAT LONG Y CORNER 7/19 LAT LONG Y NW CORNER 7/24 LAT = 70°15'59.079'' 7/20 t_AT LONG = 148°34,37 272" LONG Y = 5,949,050.67 y X = 675,574.69 x NW CORNER CELLAR BOX ELEV = 26.42 N~/ CORNER 7/25 LAT LONG Y X NW CORNER = 70°16'00.236'' 7/21 LAT = 148°34'38.005'' LONG : -5,949,q~7.66 Y = 675,946.76 X CELLAR BOX ELEV = 26.44 MW CORNER = 70°16'01.393'' 7/22 LAT = 146°34'38.712'' L3NS = 5,949,2.84.67 Y = 675,~)9.74 x CELLAR BOX ELEV = 26.69 M~,' CO~NER = 70°16,04.710'' = 45°34'13.225'' - 5,9k9,577.45 = 676,78~.69 CELLAR BOX ELEV = 27.29 I 70016,02.915'' = ~6034'12.505'' 5,9~9,4G0.46 = 676,816.)9 CELLkR BOX ELEV = 27.35 7/26 LAT LONG Y X NW CORNER . 70°16'Oi.763'' . ~$°34,11.775" - 5,9~9,344.o4 - 676,843.S9 CELLAR 50x ELEV o 27.30 . 70°16,00.609'' , 46°34,11.047I' - 5,9L9,227.26 i 676,~71.77 CELLAR EOX ELEV = 27.37 = 70°1~'59.45i'' = 45°3 '10 322" = 5,9~9,110.18 - 676,899.43 CELLAR B~ ELEV = 27.59 ARCO Alaska, [nc. Subsid;ory of Atlontic Richfield Compony NORTH SLOPE DRILLING-PRUDHOE BAY mi . I ~ SHEET O~ .. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee ~:17~;';"~-~ ~"~'- ~'"~' thru 8) ~(~ thru 1.1) (4) Casg ~. ~~, (/-F-~ (12 thru 20) (21 thru 24) ® YES NO Is the permit fee ttached a ®eeeeeeeeee®eeeeeeeleeleleleee®eleeteee le 2. Is well to be located in a defined pool 3. Is well located proper distance from property line ................ 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten'day wait'. ......................... ® 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Does operator have a bond in force .................................. Is Conservation ord needed · a 'er ...................................... administrative approval needed Is eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Is conductor string provided ........................................ Is enough cement used to 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 adequate well bore separation proposed .............. , ............ Is a diverter system required ....................................... ~z Are necessary diagrams of diverter and BOP equipment attached ....... ~ Do~s BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. REMARKS (6) Add: .~~,~/ ~-~-~' 25. Additional requirements ............................................. Additional Remarks: 0 ~-~ ~Z ~0 Ge o 1 ogy: En gig~i~g: LCS Z/ f EW WV~..:::~/ JKT -- HJH- / rev: 12/06/82' INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi ,. No special'effort has been made to chronologically organize this category of information, .o * ALASKA COMPUTING CENTER * * * ****************************** ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NA~E : D.S. 7-24 FIELD NAFIE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292094500 REFERENCE NO : 98024 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: **** REEL HEADER **** SERVICE NAFIE : EDIT DATE : 98/01/22 ORIGIN : FLIC RRRL NAME : 98024 CONTINUATION # : PREVIOUS REEL : CO~IENT : ARCO ALASKA INC, D.S. 7-24, PRUDHOE BAY, 50-029-20945-00 **** TAPE HEADER **** SERVICE NAFIE : EDIT DATE : 98/01/22 ORIGIN : FLIC TAPE NAME : 98024 CONTINUATION # : 1 PREVIOUS TAPE : COf~rf : ARCO ALASKA INC, D.S. 7-24, PRUDHOE BAY, 50-029-20945-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 7-24 API NUFiBER: 500292094500 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 22-JAN-98 JOB NUFIBER: 98024 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: K. NEUPERT SURFACE LOCATION SECTION: 33 TOWNSHIP: 11 N RANGE: 14E FNL: 1869 FSL : FEL: 244 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 57. O0 DERRICK FLOOR: 56. O0 GROUND LEVEL: 27. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.675 10587.0 47.00 7.000 11377.0 29.00 5.500 10280.0 17.00 4.500 10354.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(BIEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 14-MAY-97 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRC~ TDTP 88888.0 88885.0 88886.5 11171.5 11170.0 11168.0 11167.0 11166.5 11165.0 11164.5 11162.5 11160.5 11159.0 11152.5 11150.0 11143.5 11140.5 11140.5 11133.0 11130.5 11130.5 11128.0 11124.5 11124.5 11121.0 11119.0 11119.0 11113.0 11112.5 11112.5 11109.5 11108.0 11108.0 11105.5 11104.5 11104.5 11097.0 11098.5 11098.5 11093.5 11095.0 11095.0 11090.0 11092.5 11092.5 11087.0 11089.5 11089.5 11083.5 11088.0 11088.0 11077.0 11080.0 11080.0 11071.5 11074.5 11071.0 11074.5 11067.0 11069.0 11069.0 11065.0 11066.0 11066.0 11063.0 11064.5 11064.5 11059.0 11057.5 11057.5 11057.0 11054.0 11056.0 11054.0 11048.5 11049.0 11048.0 11049.5 11045.0 11045.0 11045.0 11038.5 11040.0 11040.0 11036.5 11037.0 11037.0 11030.0 11029.0 11029.0 11027.5 11025.0 11025.0 11017.5 11017.0 1~017.0 11011.5 11011.5 11011.0 11011.5 11006.0 11006.5 11006.5 11002.0 11000.0 10999.5 10998.5 10997.0 10998.0 10997.5 10993.5 10992.5 10992.0 10992.5 10989.5 10989.5 10989.5 PA GE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 10986.5 10986.5 10986.0 10982.0 10981.5 10981.5 10981.5 10976.5 10976.5 10972.5 10971.0 10971.0 10970.5 10969.5 10969.5 10967.0 10966.5 10966.5 10962.5 10962.5 10961.5 10962.5 10956.5 10956.5 10956.5 10953.0 10953.5 10953.5 10950.5 10950.0 10950.0 10950.0 10945.0 10944.5 10944.5 10940.0 10940.0 10930.5 10930.0 10930.0 10930.0 10925.5 10924.5 10925.0 10924.5 10921.0 10921.0 10921.0 10919.5 10919.5 10919.0 10919.5 10916.0 10916.0 10910.5 10909.5 10909.5 10908.0 10906.0 10906.0 10904.5 10903.5 10903.5 10900.5 10899.0 10899.0 10899.0 10898.0 10898.0 10890.5 10890.5 10890.5 10886.0 10887.5 10887.5 10884.0 10884.5 10884.5 10882.0 10883.5 10881.5 10883.0 10879.0 10878.5 10878.5 10878.5 10876.0 10876.5 10875.5 10876.5 10874.0 10874.0 10873.5 10874.0 10870.0 10870.0 10870.0 10868.5 10868.5 10868.5 10867.5 10866.0 10866.0 10863.0 10864.5 10862.5 10864.5 10858.0 10859.5 10859.5 10855.5 10855.5 10855.5 10853.5 10854.0 10854~0 100.0 100.5 100.5 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO ALASKA'S DS 7-24 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAFiF~A RAY, ALSO SIGMA BASE PASS #1 AND THE BCS GAMMA RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center $ $ 22-JAN-1998 16:35 PAGE: **** FILE HEADER **** FILE NA~IE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER : 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER : 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11148.0 10850 . 5 TDTP 11174.5 10850.5 $ CURVE SHIFT DATA - PASS TO PASS (~EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUF1BER : BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 1i 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 SBHFTDTP CU 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 1065835 O0 000 O0 0 1 1 I 4 68 0000000000 SIGC TDTP CU 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 TRATTDTP 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 LCO1 TDTP 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 TCANTDTP CPS 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 TCAFTDTP CPS 1065835 O0 000 O0 0 1 1 I 4 68 0000000000 TCND TDTP CPS 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 TSCNTDTP CPS 1065835 O0 000 O0 O. 1 1 1 4 68 0000000000 TSCFTDTP CPS 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 Ilq~D TDTP CPS 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1065835 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: ** DATA ** DEPT. 11185.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD.TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD.TDTP GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL.TDTP -999.250 GR.BCS DEPT. 10840.000 SIG~.TDTP -999.250 TPHI. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL.TDTP -999.250 SBHF. TDTP -999.250 TRAT. TDTP -999.250 FBAC. TDTP -999.250 TCFD.TDTP -999.250 INFD.TDTP -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 34.281 -999.250 -999.250 -999.250 -999.250 -999.250 23.031 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~iE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUBiBER : 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INC~: 0. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 11148.5 TDTP 11173.5 STOP DEm 10850.0 10850.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11173.5 11168.5 11165.0 11160.5 11151 0 11147 5 11143 5 11137 0 11135 5 11133 5 11131.5 11130.5 11128.5 11124.0 11123.5 11121.5 11120.0 11114.5 11113.0 11112.0 11111.0 11097.0 11094.0 11091.5 11089.5 11086.5 11084.5 11081.5 11076.5 11070.5 11068.0 11067.5 11064.5 11062.0 11060.0 11059.0 11057.0 11056.5 11054.5 11049.0 11045.5 11040.5 11039.5 11034.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH 88885.5 11145.0 11140.5 11136.0 11133.5 11130.5 11127.0 11124.5 11122.0 11119.0 11113.5 11112.0 11110.0 11098.5 11095.0 11092.0 11087.5 11077.5 11069.0 11066.0 11060.5 11054.0 11049.0 11037.0 TDTP 88885.5 11171.0 11167.0 11162.5 11159.0 11150.0 11144.5 11128.5 11124.5 11121.0 11118.5 11110.0 11093.5 11088.5 11083.0 11074.0 11066.0 11061.0 11057.5 11054.0 11053.0 11045.0 11041.5 11034.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 11031.0 11029.5 11028.5 11029.0 11021.5 11023.0 11017.0 11016.0 11013.5 11014.5 11012.5 11011.5 11006.0 11006.5 10998.5 10997.0 10998.0 10997.0 10994.5 10994.5 10994.0 10992.5 10992.0 10992.5 10987.0 10986.5 10986.5 10986.0 10983.0 10981.5 10977.0 10976.5 10976.5 10976.5 10973.5 10971.0 10972.5 10970.5 10967.5 10966.5 10966.5 10966.0 10962.5 10962.5 10960.0 10961.5 10959.0 10958.0 10957.0 10956.5 10956.0 10956.0 10953.5 10953.0 10950.5 10950.0 10948.0 10947.5 10948.0 10946.0 10944.5 10945.5 10944.5 10941.0 10940.5 10940.0 10940.0 10936.0 10935.5 10935.5 10934.0 10933.0 10926.0 10925.0 10923.0 10924.5 10919.5 10919.5 10919.0 10919.5 10916.0 10916.0 10916.0 10911.0 10909.5 10908.0 10906.0 10905.5 10905.0 10903.0 10900.0 10899.0 10899.0 10899.0 10894.0 10893.0 10890.5 10890.5 10890.5 10888.0 10888.5 10881.5 10883.0 10881.0 10883.5 10879.0 10878.5 10878.0 10878.5 10875.5 10876.5 10874.0 10874.5 10872.5 10873.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 10871.5 10871.0 10870.5 10870.0 10869.0 10868.5 10868.0 10868.5 10866.5 10866.0 10863.5 10864.5 10864.0 10860.0 10859.5 10857.0 10856.5 10854.0 10854.0 10853.5 10854.0 100.0 100.0 100.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 10 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) DEPT FT 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 SBHFTDTP CU 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1065835 O0 000 O0 0 2 i 1 4 68 0000000000 TRAT TDTP 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 LCO1 TDTP 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 TCIlD TDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 T$CNTDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 TSCFTDTP CPS 1065835 O0 000 O0 0 2 1 I 4 68 0000000000 INND TDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1065835 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11173.500 SIGT4. TDTP 13.748 TPHI.TDTP 23.544 SBHF. TDTP 42.023 SBI41V. TDTP 47.957 SIGC. TDTP 0.897 SIBH. TDTP 53.513 TRAT. TDTP 1.693 LCO1.TDTP 2.209 SDSI. TDTP 0.287 BACK. TDTP 115.378 FBAC. TDTP 27.679 TCAN. TDTP 38559.625 TCAF. TDTP 17456.090 TCND. TDTP 26102.520 TCFD. TDTP 9077.975 TSCN. TDTP 7779.304 TSCF. TDTP 3521.721 INND. TDTP 1957.141 INFD. TDTP 419.339 GRCH. TDTP -999.250 TENS. TDTP 1560.000 CCL. TDTP 0.000 DEPT. 10850.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 LCO1.TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 33.813 TENS. TDTP -999.250 CCL. TDTP -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 11 **** FILE TRAILER **** FILE NAFIE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER : 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11151 . 5 10849.5 TDTP 11174 . 0 10850 . 5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFI~ER : 1 BASELINE DEPTH 88888.0 51169.0 11164.5 11162.0 11157.5 11148.0 11144.5 11143.0 11141.0 11138.5 11136.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.5 88886.0 11145.0 11142.5 11140.5 11136.5 11134.5 11167.0 11162.5 11159.0 11154.0 11150.0 11145.0 11141.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 12 11135.0 11134.0 11133.0 11130.5 11131.5 11128.5 11130.5 11127.0 11129.5 11125.0 11128.5 11125.0 11124.5 11122.0 11124.0 11121.0 11121.0 11119.0 11120.5 11118.5 11117.0 11115.0 11114.5 11113.5 11113.0 11112.0 11111.5 11109.5 11110.0 11109.0 11106.5 11105.0 11104.5 11102.5 11103.0 11097.5 11098.5 11093.5 11095.0 11093.0 11095.0 11091.5 11092.5 11090.5 11093.5 11087.5 11087.5 11086.0 11088.0 11082.0 11080.5 11079.0 11076.0 11082.5 11075.5 11074.5 11072.0 11071.5 11071.5 11074.0 11066.5 11066.0 11064.0 11066.5 11061.0 11061.0 11059.5 11057.5 11057.5 11057.5 11056.5 11054.0 11055.0 11054.0 11051.0 11049.5 11049.0 11049.0 11045.5 11045.0 11041.0 11041.0 11040.5 11041.5 11039.0 11040.0 11038.0 11040.0 11034.0 11034.0 11032.5 11032.5 11031.0 11029.5 11021.0 11019.5 11019.5 11018.5 11016.5 11016.0 11015.5 11015.0 11012.0 11011.5 11011.5 11007.5 11006.5 11003.0 11003.0 11000.5 11000.0 10998.5 10997.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 13 10998.0 10997.0 10994.5 10992.5 10987.0 10986.5 10986.5 10985.5 10984.5 10983.0 10982.0 10981.5 10980.5 10981.5 10977.0 10976.5 10976.5 10976.5 10972.0 10970.0 10967.5 10966.5 10966.0 10965.5 10965.0 10965.0 10961.0 10962.5 10960.5 10962.5 10956.5 10956.5 10956.0 10956.0 10950.5 10950.0 10949.0 10949.0 10948.0 10947.5 10948.0 10945.5 10944.5 10945.0 10944.0 10941.0 10940.5 10940.0 10940.0 10936.0 10935.5 10931.0 10930.0 10930.5 10930.0 10928.0 10927.5 10926.0 10925.0 10924.5 10924.5 10921.0 10921.0 10919.5 10919.5 10918.5 10919.5 10916.0 10916.0 10915.0 10916.0 10912.0 10914.0 10908.0 10906.0 10905.5 10906.0 10903.5 10903.0 10900.0 10899.0 10899.0 10890.5 10890.5 10888.0 10887.5 10888.5 10884.5 10883.5 10881.5 10883.0 10878.5 10878.5 10878.5 10876.0. 10876.5 10875.5 10876.5 10869.0 10868.5 10868.5 10864.5 10864.5 10864.0 10864.0 10860.0 10861.0 10857.5 10856.0 10857.0 10857.0 10854.0 10854.0 10853.5 10854.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 14 10852.0 10851.5 100.0 99.5 $ 100.5 RE~a~RKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT- 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1065835 00 000 O0 0 3 1 1 4 68 0000000000 SBHFTDTP CU 1065835 00 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 1065835 00 000 O0 0 3 1 1 4 68 0000000000 SIGCTDTP CU 1065835 00 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TRATTDTP 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 LCO1 TDTP 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB BI]M~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1065835 FBAC TDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TCANTDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1065835 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11174.000 SIGM. TDTP 13.884 TPHI. TDTP 26.326 SBHF. TDTP 41.214 SBHN. TDTP 53.175 SIGC. TDTP 0.889 SIBH. TDTP 64.466 TRAT. TDTP 1.733 LCO1.TDTP 2.292 SDSI. TDTP 0.350 BACK. TDTP 141.933 FBAC. TDTP 35.504 TCAN. TDTP 38438.625 TCAF. TDTP 16767.598 TCND. TDTP 26072.551 TCFD. TDTP 8824.957 TSCN. TDTP 7632.500 TSCF. TDTP 3329.429 INND. TDTP 2080.562 INFD. TDTP 402.826 GRCH. TDTP -999.250 TENS. TDTP 1535.000 CCL. TDTP 0.000 DEPT. 10849.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP GRCH. TDTP 39.656 TENS. TDTP -999.250 CCL. TDTP -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 16 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11147.5 10850.0 TDTP 11174.0 10850.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUf4~ER : 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88884.5 88886.0 11167.0 11165.0 11165.0 11162.5 11162.0 11159.0 11158.5 11154.5 11153.0 11147.5 11149.0 11145.0 11146.0 11142.5 11142.5 11139.0 11136.0 11136.0 11136.0 11130.5 11130.5 11131.5 11127.0 11127.0 11125.0 ~1122.0 11122.0 11121.0 11119.0 11119.0 11116.5 11115.0 11115.0 11113.5 11112.5 11112.5 11111.5 11110.0 11110.0 11106.0 11104.5 11104.5 11099.0 11098.5 11098.5 11095.0 11092.5 11092.5 11088.5 11087.5 11086.5 11089.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PA GE: 17 11079.0 11077.5 11070.5 11069.5 11073.5 11068.5 11066.0 11062.5 11060.0 11062.0 11061.0 11059.5 11057.5 11057.5 11055.5 11053.0 11049.0 11049.5 11047.5 11049.0 11041.0 11041.5 11038.5 11039.5 11034.0 11034.0 11026.5 11029.0 11021.5 11023.0 11016.5 11016.0 11012.5 11011.5 11011.0 11011.5 11010.5 11010.0 11005.0 11006.5 11004.5 11003.5 11003.5 11003.0 11001.5 11000.0 10998.0 10997.0 10997.5 10994.5 10992.5 10992.0 10992.5 10987.5 10986.5 10986.5 10986.0 10983.0 10981.5 10981.5 10981.5 10977.5 10976.5 10977.0 10976.5 10972.0 10971.0 10971.5 10970.5 10967.5 10966.5 10966.0 10965.5 10964.5 10964.5 10961.5 10962.5 10959.0 10957.5 10956.5 10956.5 10956.0 10956.0 10953.0 10953.5 10949.5 10949.0 10948.0 10947.0 10948.0 10944.5 10944.5 10944.0 10941.0 10940.5 10940.0 10940.0 10938.0 10936.5 10932.5 10930.0 10931.0 10930.0 10926.0 10924.5 10925.0 10924.5 10922.5 10922.5 10919.5 10919.5 10918.5 10919.0 10915.5 10916.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 18 10915.0 10916.0 10912.0 10909.5 10908.0 10906.0 10904.0 10903.0 10900.0 10899.0 10898.0 10897.5 10890.5 10890.5 10890.5 10887.0 10888.0 10885.0 10886.0 10882.0 10883.0 10878.5 10878.5 10878.0 10878.5 10876.0 10876.5 10875.5 10876.5 10874.0 10874.5 10872.0 10871.5 10868.5 10868.5 10868.5 10867.5 10866.0 10864.5 10864.5 10863.5 10864.5 10857.5 10855.5 10856.5 10857.0 10854.0 10854.0 10853.5 10854.0 100.0 100.0 100.5 $ ~S: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 19 TYPE REPR CODE VALUE .............................. 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP EL~ CODE (HEX) DEPT FT 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 SIGMTDTP CU 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1065835 O0 000 O0 0 4 i 1 4 68 0000000000 SBHNTDTP CU 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 SIBHTDTP CU 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 TRATTDTP 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 LCO1 TDTP 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 TCANTDTP CPS 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 1065835 00 000 00 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1065835 00 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1065835 00 000 O0 0 4 1 1 4 68 0000000000 TSCNTDTP CPS 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 TSCFTDTP CPS 1065835 00 000 00 0 4 1 1 4 68 0000000000 INND TDTP CPS 1065835 00 000 00 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1065835 00 000 00 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1065835 00 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1065835 00 000 00 0 4 1 1 4 68 0000000000 CCL TDTP V 1065835 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11174.000 SIGM. TDTP 13.613 TPHI. TDTP 24.407 SBHF. TDTP SBHN. TDTP 49.578 SIGC. TDFP 0.949 SIBH. TDTP 56.712 TRAT. TDTP LCO1.TDTP 2.249 SDSI. TDTP 0.269 BACK. TDTP 63.036 FBAC. TDTP TCAN. TDTP 39461.742 TCAF. TDTP 17544.668 TCND. TDTP 26314.035 TCFD. TDTP TSCN. TDTP 7818.082 TSCF. TDTP 3475.915 INND. TDTP 1880.543 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP 1655.000 CCL. TDTP 0.000 42.450 1.710 . 21.180 9005.211 437.665 DEPT. 10850.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 2O TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 36.188 TENS. TDTP -999 . 250 CCL. TDTP -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER: 5 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11149.0 10850.5 TDTP 11175.0 10851.0 $ CURVE SHIFT DATA - PASS TO PASS (f4EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFI~ER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88886.0 88887.0 11166.5 11165.5 11164 . 5 11162 . 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 21 11159.5 11156.5 11152.0 11147.5 11149.0 11145.0 11143.0 11141.0 11141.0 11139.0 11137.0 11137.0 11134.0 11130.0 11130.0 11130.0 11126.0 11126.0 11124.0 11121.5 11121.5 11118.0 11117.0 11117.0 11114.5 11113.5 11113.5 11111.5 11110.5 11110.5 11109.0 11108.0 11105.0 11104.5 11105.0 ii101.0 11101.0 11101.0 11093.5 11092.5 11093.0 11092.0 11085.0 11087.5 11084.5 11088.5 11075.5 11077.5 11070.5 11073.5 11070.0 11069.5 11061.0 11060.5 11059.5 11057.5 11058.5 11057.5 11057.0 11055.0 11056.5 11054.0 11051.5 11049.0 11049.0 11049.0 11040.5 11041.0 11040.0 11041.0 11037.5 11040.0 11036.5 11037.0 11035.5 11036.0 11033.5 11033.5 11031.5 11032.5 11028.5 11029.0 11020.5 11023.0 11019.0 11017.0 11016.5 11016.5 11013.5 11011.5 11006.0 11006.5 11004.0 11003.5 10998.0 10997.0 10997.5 10997.0 10994.5 10993.0 10994.0 10992.5 10987.0 10986.5 10986.5 10986.0 10980.5 10981.0 10977.0 10976.5 10973.0 10971.0 10971.5 10970.5 10967.0 10966.5 10966.0 10965.5 10962.5 10962.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 22 10960.5 10962.5 10956.0 10956.5 10955.5 10956.0 10954.0 10953.5 10953.5 10954.0 10947.5 10947.5 10944.5 10944.5 10944.5 10940.5 10940.5 10940.0 10940.0 10937.5 10935.5 10936.5 10936.5 10932.5 10930.0 10930.5 10930.0 10928.0 10926.5 10927.0 10926.5 10924.5 10925.5 10925.0 10919.0 10919.5 10918.5 10919.5 10917.0 10916.0 10916.0 10917.0 10907.0 10906.0 10903.5 10904.0 10901.5 10899.5 10899.5 10899.5 10896.5 10896.0 10894.5 10895.0 10890.0 10890.5 10890.5 10886.5 10887.5 10885.0 10886.0 10883.0 10883.5 10882.0 10883.5 10878.0 10878.5 10876.0 10876.5 10875.0 10876.5 10873.5 10874.0 10873.5 10870.0 10870.0 10868.5 10868.5 10865.5 10864.0 10863.0 10864.5 10861.0 10861.5 10857.0 10856.0 10856.5 10857.5 10853.5 10854.0 10853.0 10854.0 100.0 100.5 101.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCHBORAXPASS #2 AND GRCHBASE PASS #1, ALSO SIGMA BORAX PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~IB SAMP ELE~ CODE (HEX) DEPT FT 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 SIGMTDTP CU 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 SBHFTDTP CU 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNTDTP CU 1065835 O0 000 O0 0 5 1 i 4 68 0000000000 SIGCTDTP CU 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 SIBHTDTP CU 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 TRATTDTP 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 LCO1 TDTP 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 TCANTDTP CPS 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 1065835 00 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 1065835 O0 000 O0 0 5 i 1 4 68 0000000000 TSCNTDTP CPS 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 TSCFTDTP CPS 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 1065835 00 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 1065835 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 24 ** DATA ** DEPT. 11175.000 SIGM. TDTP 13.802 TPHI. TDTP 24.853 SBHF. TDTP SBHN. TDTP 51.658 SIGC. TDTP 0.840 SIBH. TDTP 61.108 TRAT. TDTP LCO1.TDTP 2.232 SDSI. TDTP 0.302 BACK. TDTP 123.339 FBAC. TDTP TCAN. TDTP 36430.656 TCAF. TDTP 16320.771 TCND. TDTP 24288.688 TCFD. TDTP TSCN. TDTP 7251.023 TSCF. TDTP 3248.426 INND. TDTP 1917.468 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP 1655.000 CCL. TDTP 0.000 DEPT. 10850.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP GRCH. TDTP 45.875 TENS. TDTP -999.250 CCL. TDTP -999.250 39.530 1.702 29.704 8377.453 412.723 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 6 DEPTH INCRE~iENT: 0.5000 FILE SUMM3~Y LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 25 GRCH 11148.5 10850.5 TDTP 11174.0 10850 . 5 $ CURVE SHIFT DATA - PASS TO PASS (f4EAS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NI]bI~ER : 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP ............................ 88888.0 88885.5 88886.0 11174.0 11172.0 11167.0 11165.0 11164.5 11162.0 11158.0 11154.5 11152.0 11148.0 11149.5 11145.5 11145.0 11142.5 11140.0 11137.0 11135.5 11130.0 11132.5 11131.0 11130.5 11126.5 11124.5 11121.5 11121.0 11119.0 11118.5 11117.0 11114.5 11113.5 11114.0 11112.5 11112.0 11110.5 11108.0 11108.0 11105.5 11105.0 11104.0 11104.5 11102.0 11101.0 11094.5 11092.5 11094.0 11092.5 11086.0 11089.0 11075.5 11074.5 11070.0 11069.5 11061.0 11061.0 11059.0 11057.5 11051.0 11054.0 11047.5 11048.5 11044.0 11045.0 11034.0 11033.5 11032.5 11037.0 11027.5 11029.0 11027.0 11024.5 11022.5 11023.0 11021.0 11019.5 11017.0 11016.5 11016.0 11015.0 11013.0 11012.0 11011.5 11011.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 26 11006.5 11006.5 11005.0 11003.5 11000.5 11000.0 10998.5 10997.0 10997.5 10997.5 10994.5 10992.5 10992.5 10987.0 10986.5 10986.0 10986.0 10981.5 10981.0 10977.0 10976.5 10975.5 10976.5 10973.0 10971.0 10970.5 10970.0 10967.0 10966.5 10966.0 10966.0 10961.5 10962.5 10960.0 10962.5 10958.5 10958.0 10956.5 10956.5 10956.0 10956.0 10953.5 10953.0 10953.0 10953.0 10948.5 10948.0 10944.5 10944.5 10944.0 10944.5 10940.5 10940.5 10940.0 10940.0 10936.0 10935.0 10935.5 10935.5 10932.5 10933.0 10931.5 10930.0 10929.5 10930.0 10926.5 10924.5 10926.0 10925.0 10923.0 10922.5 10919.5 10919.5 10919.0 10919.5 10916.0 10916.0 10915.0 10914.0 10910.0 10908.0 10907.5 10905.5 10906.0 10906.0 10901.0 10899.5 10896.0 10896.5 10890.5 10890.5 10890.5 10883.5 10883.5 10882.0 10883.0 10880.5 10879.0 10878.0 10878.5 10876.5 10876.5 10875.5 10876.5 10873.5 10874.0 10869.0 10868.5 10868.5 10868.5 10867.5 10866.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 27 10864.0 10864.5 10863.0 10864.0 10862.5 10862.0 10859.0 10859.5 10858.5 10860.0 10856.0 10857.0 10854.0 10854.5 10853.5 10854.0 100.0 100.5 100.5 $ ~S: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP EL~ CODE (HEX) DEPT FT 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 28 NA~E SERV UNIT SERVICE API API API API FILE NUF~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELM CODE (HEX) SBHFTDTP CU 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNTDTP CU 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 SIBHTDTP CU 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TRATTDTP 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 LCO1 TDTP 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TCANTDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TCAFTDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TSCNTDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TSCFTDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 1065835 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 1065835 O0 000 00 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11174.000 SIGM. TDTP 13.115 TPHI.TDTP 25.872 SBHF. TDTP SBHN. TDTP 58.166 SIGC. TDTP 0.859 SIBH. TDTP 74.542 TRAT. TDTP LCO1.TDTP 2.225 SDSI. TDTP 0.364 BACK. TDTP 144.892 FBAC. TDTP TCAN. TDTP 35475.766 TCAF. TDTP 15941.131 TCND. TDTP 22595.840 TCFD. TDTP TSCN. TDTP 7029.390 TSCF. TDTP 3158.675 INND. TDTP 1910.302 INFD.TDTP GRCH. TDTP -999.250 TENS. TDTP 1675.000 CCL. TDTP 0.000 45.423 1.722 38.842 7898.562 431.832 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX RBC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PA GE: 29 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCRE~IENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUPI~ERS .......................... I, 2, 3, TDTP THIS FILE CONTAINS THE ARITHFIETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATIONRECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 30 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAF~ SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) DEPT PT 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 SIGMPNAV CU 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 SBHFPNAV CU 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPNAV CU 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PNAV CU 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PNAV CU 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PNAV CU 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 FBACTDTP CPS 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPNAV CPS 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPNAV CPS 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPNAV CPS 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 TCFDPNAV CPS 1065835 O0 000 O0 0 7 1 i 4 68 0000000000 TSCNPNAV CPS 1065835 O0 000 O0 0 7 1 i 4 68 0000000000 TSCF PNAV CPS 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPNAV CPS 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 INFDPNAV CPS 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 LCO1 PNAV 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 1065835 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11174.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC.PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 62.367 FBAC. TDTP 20.639 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 LCO1.PNAV -999.250 GRCH. TDTP -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 31 **** FILE TRAILER **** FILE ~ : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFI~ER : 1 DEPTH INC~: 0.5000 FILE SUF~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 11198.0 10837.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~IE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ BORE}tOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12-0CT-97 CP 44.2 1451 12-0CT-97 11181.0 11184.0 10850.0 11178.0 1800.0 TOOL NUMBER CGRS-A- 862 TDT SET 21 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 32 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BORE~OLE COI~DITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~4PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 11377.0 DEAD CRUDE 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STAHDOFF (IN): REMARKS: TIED INTO BHCS DATED 5/14/83 · .. PUMPED 330 BBLS DEAD CRUDE INTO TUBING PRIOR TO LOGGING MADE 3 BASE PASSES WHILE PUMPING AT 0.5 BPM MADE BORAX PASSES WITH35,68AND 83 BBLS BORAX AWAY GOC AT 11090' SQUEEZE PERFS AT 11088-11096, 11116-11118 AND 11142-11160 ARE LEAKING. NO DOWN CHANNEL THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 33 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELD CODE (HEX) DEPT FT 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 SIGMPS1 CU 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS1 PU 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS1 CU 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 SB~NPS1 CU 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS1 CU 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS1 CU 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS1 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 LCO1 PS1 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS1 CU 1065835 O0 000 O0 0 8 1 I 4 68 0000000000 BACK PS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 TCAFPS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 TCNDPS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 TCFDPS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 TSCNPS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 INNDPS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 INFDPS1 CPS 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 T~NS PS1 LB 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS1 GAPI 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS1 V 1065835 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 34 ** DATA ** DEPT. 11185.000 SIGM. PS1 SBHN. PS1 50.888 SIGC. PS1 LCO1.PS1 2.193 SDSI.PS1 TCAN. PS1 40248.844 TCAF. PS1 TSCN. PS1 7641.160 TSCF. PS1 TENS.PSi 1605.000 GR.PS1 DEPT. 10840.000 SIGM. PS1 SBHN. PS1 42.917 SIGC. PS1 LCO1.PS1 1.861 SDSI.PS1 TCAN. PS1 56365.570 TCAF. PS1 TSCN. PS1 11350.795 TSCF. PSI TENS.PSI 1540.000 GR.PS1 13.431 TPHI.PS1 0.809 SIBH. PS1 0.307 BACK. PSi 18357.301 TCND.PS1 3485.096 INND.PS1 26.922 CCL.PS1 11.281 TPHI.PS1 1.292 SIBH. PS1 0.213 BACK. PSi 30283.547 TCND.PS1 6098.445 IA~D.PS1 17.359 CCL.PS1 23.247 59.095 92.552 25923.379 1995.893 0.000 14.049 43.282 96.274 32237.332 2008.038 0.000 SBHF. PS1 TRAT.PS1 FBAC. PS1 TCFD.PS1 INFD.PS1 SBHF. PS1 TRAT. PS1 FBAC. PS1 TCFD.PS1 INFD.PS1 44. 068 1. 671 26.296 8991. 721 423. 762 30.307 1.474 19.274 13519.914 507.309 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFI~ER: 2 DEPTH INCREmENT: 0.5000 FILE SUF~fARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11204.0 10841.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 35 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPE~D (FP~R) : DEPTH CONTROL USED (YES/NO): 12-0CT-97 CP 44.2 1451 12-0CT-97 11181.0 11184.0 10850.0 11178.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~A RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS-A-862 TDT SET 21 BORE~OLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 11377.0 BORI~HOLE CONDITIONS FLUID TYPE: FLUID D~NSITY (LB/G): SURFACE Tb~4PERATURE (DEGF) : BOTTOM HOLE T~MPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : DEAD CRUDE 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO BHCS DATED 5/14/83 ... LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 36 PUMPED 330 BBLS DEAD CRUDE INTO TUBING PRIOR TO LOGGING MADE 3 BASE PASSES WHILE PUMPING AT 0.5 BPM MADE BORAX PASSES WITH 35,68 AND 83 BBLS BORAX AWAY GOC AT 11090' SQUEEZE PERFS AT 11088-11096, 11116-11118 AND 11142-11160 ARE LEAKING. NO DOWN CHANNEL THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 SIGMPS2 CU 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS2 CU 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 SBHNPS2 CU 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS2 CU 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS2 CU 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 LCO1 PS2 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS2 CU 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 37 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TCANPS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 TCAFPS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 TCNDPS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 TCFDPS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 TSCNPS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 INNDPS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 INFDPS2 CPS 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS2 LB 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 1065835 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11185.000 SIGM. PS2 13.687 TPHI.PS2 23.445 SBHF. PS2 SBHN. PS2 48.286 SIGC. PS2 0.854 SIBH. PS2 54.072 TRAT. PS2 LCO1.PS2 2.211 SDSI.PS2 0.301 BACK. PS2 144.917 FBAC. PS2 TCAN. PS2 38511.508 TCAF. PS2 17421.434 TCND.PS2 26181.168 TCFD.PS2 TSCN. PS2 7730.852 TSCF. PS2 3497.202 INND. PS2 2024.984 INFD.PS2 TENS.PS2 1570.000 GR.PS2 32.531 CCL.PS2 0.000 DEPT. 10841.000 SIGM. PS2 SBHN. PS2 41.407 SIGC.PS2 LCO1.PS2 1.853 SDSI.PS2 TCAN. PS2 58636.617 TCAF. PS2 TSCN. PS2 11859.658 TSCF. PS2 TENS.PS2 1515.000 GR.PS2 10 853 1 578 0 239 31637 699 6398 941 32 500 TPHI.PS2 13.452 SBHF. PS2 SIBH. PS2 41.407 TRAT. PS2 BACK. PS2 136.711 FBAC.PS2 TCND. PS2 32975.445 TCFD.PS2 INND. PS2 2179.781 INFD.PS2 CCL.PS2 0.000 40.394 1.689 34.408 9017.375 437.085 33.233 1.470 30.096 13960.895 507.958 ** END OF DATA ** **** FILE TRAILER **** FILE NAF1E : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 38 **** FILE HEADER **** FILE NAME : ~DIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER : 3 DEPTH INCREF1ENT: 0.5000 FILE VENDOR TOOL CODE START DEPTH TDTP 11204.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BORE~OLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~4PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : STOP DEPTH .......... 10840.5 12-0CT-97 CP 44.2 1451 12-0CT-97 11181.0 11184.0 10850.0 11178.0 1800.0 TOOL NUFIBER ........... CGRS-A-862 TDT SET 21 11377.0 DEAD CRUDE 15.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 39 FLUID RATE AT W~.rJLMEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): R3E~ARKS: TIED INTO BHCS DATED 5/14/83 ... PUMPED 330 BBLS DEAD CRUDE INTO TUBING PRIOR TO LOGGING MADE 3 BASE PASSES WHILE PUMPING AT 0.5 BPM MADE BORAX PASSES WITH 35, 68 AND 83 BBLS BORAX AWAY GOC AT 11090' SQUEEZE PERFS AT 11088-11096, 11116-11118 AND 11142-11160 ARE LEAKING. NO DOWN CHANNEL THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 40 TYPE REPR CODE VALUE 13 66 0 14 65 PT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 SIGMPS3 CU 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 SBHFPS3 CU 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS3 CU 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS3 CU 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS3 CU 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 LCO1 PS3 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS3 CU 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS3 CPS 1065835 00 000 00 0 10 1 1 4 68 0000000000 FBAC PS3 CPS 1065835 00 000 00 0 10 1 1 4 68 0000000000 TCANPS3 CPS 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 TCAFPS3 CPS 1065835 O0 000 00 0 10 1 1 4 68 0000000000 TCl~DPS3 CPS 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 TCFDPS3 CPS 1065835 00 000 00 0 10 1 1 4 68 0000000000 TSCNPS3 CPS 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS3 CPS 1065835 O0 000 00 0 10 1 1 4 68 0000000000 INNDPS3 CPS 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 INFDPS3 CPS 1065835 O0 000 00 0 10 1 1 4 68 0000000000 TENS PS3 LB 1065835 00 000 00 0 10 1 1 4 68 0000000000 GR PS3 GAPI 1065835 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS3 V 1065835 O0 000 00 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 11185.000 SIGM. PS3 13.789 TPHI.PS3 25.531 SBHF. PS3 41.642 SBHN. PS3 50.150 SIGC. PS3 0.859 SIBH. PS3 58.148 TRAT. PS3 1.734 LCO1.PS3 2.271 SDSI.PS3 0.333. BACK. PS3 183.965 FBAC. PS3 47.317 TCAN. PS3 39108.984 TCAF. PS3 17218.988 TCND.PS3 25831.055 TCFD.PS3 8783.873 TSCN. PS3 7724.236 TSCF. PS3 3400.844 INND. PS3 2023.246 INFD.PS3 428.173 TENS.PS3 1585.000 GR.PS3 43.625 CCL.PS3 0.000 DEPT. 10840.500 SIGM. PS3 11.315 TPHI.PS3 13.161 SBHF. PS3 32.825 SBHN. PS3 41.015 SIGC.PS3 1.371 SIBH. PS3 41.015 TRAT. PS3 1.450 LCO1.PS3 1.823 SDSI.PS3 0.237 BACK. PS3 161.712 FBAC. PS3 32.673 TCAN. PS3 56560.406 TCAF. PS3 31022.809 TCND.PS3 31949.871 TCFD.PS3 13550.980 TSCN. PS3 11222.082 TSCF. PS3 6155.198 INND.PS3 2098.513 INFD.PS3 512.596 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 41 TENS.PS3 1490.000 GR.PS3 38.156 CCL.PS3 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~ER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 4 DEPTH INCREmENT: 0.5000 FILE SUMFAa~Y VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 11206.0 10837.5 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 12-0CT-97 CP 44.2 1451 12-0CT-97 11181.0 11184.0 10850.0 11178.0 1800.O TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 42 GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS-A- 862 TDT SET 21 11377.0 DEAD CRUDE 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (PT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): RE~ARKS: TIED INTO BHCS DATED 5/14/83 ·.. PUMPED 330 BBLS DEAD CRUDE INTO TUBING PRIOR TO LOGGING MADE 3 BASE PASSES WHILE PUMPING AT 0.5 BPM MADE BORAX PASSES WITH 35, 68 AND 83 BBLS BORAX AWAY GOC AT 11090' SQUEEZE PERFS AT 11088-11096, 11116-11158 AND 11142-11160 ARE LEAKING. NO DOWN CHANNEL THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 43 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1' 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP EL~4 CODE (HEX) DEPT FT 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 SIGMBX1 CU 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX1 PU 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF BX1 CU 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 SB~NBX1 CU 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC BX1 CU 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 SIBHBX1 CU 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BXl 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 LCO1 BX1 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI BX1 CU 1065835 00 000 O0 0 11 1 1 4 68 0000000000 BACK BXl CPS 1065835 00 000 00 0 11 1 1 4 68 0000000000 FBAC BX1 CPS 1065835 O0 000 00 0 11 1 1 4 68 0000000000 TCANBXl CPS 1065835 O0 000 00 0 11 1 1 4 68 0000000000 TCAFBX1 CPS 1065835 00 000 00 0 11 1 1 4 68 0000000000 TCl~BX1 CPS 1065835 O0 000 00 0 11 1 1 4 68 0000000000 TCFDBX1 CPS 1065835 00 000 00 0 11 1 1 4 68 0000000000 TSCNBXi CPS 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF BXl CPS 1065835 O0 000 00 0 11 1 1 4 68 0000000000 INNDBX1 CPS 1065835 O0 000 00 0 11 I 1 4 68 0000000000 INFDBXl CPS 1065835 O0 000 00 0 11 1 1 4 68 0000000000 TENS BX1 LB 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 GR BX1 GAPI 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 CCL BX1 V 1065835 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 44 ** DATA ** DEPT. 11185. 000 SIGM. BXl SBHN. BX1 48. 474 SIGC. BXl LCO1.BX1 2.320 SDSI.BXl TCAN. BX1 40454. 953 TCAF. BXl TSCN. BX1 7916. 003 TSCF.BXl TENS. BX1 1685. 000 GR. BXl DEPT. 10840. 000 SIGM. BX1 SBHN. BX1 90.208 SIGC. BXl LCO1.BX1 1.551 SDSI.BX1 TCAN. BX1 35713.039 TCAF. BXl TSCN. BX1 7101. 697 TSCF.BXl TENS. BX1 1615. 000 GR . BX1 13. 487 TPHI.BX1 O. 738 SIBH. BX1 0.271 BACK. BX1 17437. 754 TCND.BX1 3412.124 INND.BX1 31. 656 CCL.BX1 11.083 TPHI.BX1 0.036 SIBH. BX1 0.194 BACK. BX1 23024.750 TCND.BX1 4578.575 INND.BX1 36.750 CCL.BX1 26.108 SBHF. BX1 54.766 TRAT. BXl 98.339 FBAC. BX1 26204.594 TCFD. BX1 1867.235 INFD.BX1 0.000 12.396 SBHF. BX1 124.379 TRAT. BX1 100.797 FBAC. BXl 17030.652 TCFD.BX1 2004.048 INFD.BXl -0.657 37.696 1.775 28.486 8847.092 424.868 73.268 1.282 22.147 8818.904 460.976 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01COi DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : ~DIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 5 DEPTH INCREFiENT: 0.5000 FILE SUMM3~Y VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11203.5 10838.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 45 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~IE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 12-0CT-97 CP 44.2 1451 12-0CT-97 11181.0 11184.0 1O85O. 0 11178.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A-862 TDT SET 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11377.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : DEAD CRUDE 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO BHCS DATED 5/14/83 ... LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 46 PUMPED 330 BBLS DEAD CRUDE INTO TUBING PRIOR TO LOGGING MADE 3 BASE PASSES WHILE PUMPING AT 0.5 BPM MADE BORAX PASSES WITH 35,68 AND 83 BBLS BORAX AWAY GOC AT 11090' SQUEEZE PERFS AT 11088-11096, 11116-11118 AND 11142-11160 ARE LEAKING. NO DOWN CHANNEL THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) DEPT FT 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 SIGMBX2 CU 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX2 PU 1065835 O0 000 O0 0 12 1 1 4 .68 0000000000 SBHFBX2 CU 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 SBHNBX2 CU 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC BX2 CU 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 SIBHBX2 CU 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 TRATBX2 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 LCO1 BX2 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI BX2 CU 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 BACK BX2 CPS 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 FBACBX2 CPS 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 47 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) TCANBX2 CPS 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 TCAFBX2 CPS 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 TCNDBX2 CPS 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 TCFDBX2 CPS 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 TSCNBX2 CPS 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF BX2 CPS 1065835 00 000 00 0 12 1 1 4 68 0000000000 INNDBX2 CPS 1065835 00 000 00 0 12 1 1 4 68 0000000000 INFDBX2 CPS 1065835 00 000 00 0 12 1 1 4 68 0000000000 TENS BX2 LB 1065835 00 000 O0 0 12 1 1 4 68 0000000000 GR BX2 GAPI 1065835 00 000 00 0 12 1 1 4 68 0000000000 CCL BX2 V 1065835 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 11185.000 SIGM. BX2 13.678 TPHI.BX2 27.267 SBHF. BX2 40.330 SB~ZN. BX2 52.654 SIGC. BX2 0.763 SIBH. BX2 63.739 TRAT. BX2 1.771 LCO1.BX2 2.312 SDSI.BX2 0.289 BACK. BX2 150.572 FBAC.BX2 39.217 TCAN. BX2 39000.391 TCAF. BX2 16868.781 TCND.BX2 25104.039 TCFD.BX2 8440.941 TSCN. BX2 7580.365 TSCF. BX2 3278.725 INND.BX2 1839.812 INFD.BX2 421.256 TENS.BX2 1660.000 GR.BX2 50.656 CCL.BX2 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDiT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~IE : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 48 FILE NUFIBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREFIENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11202.5 10840.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE Tb~4PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 12-0CT-97 CP 44.2 1451 12-0CT-97 11181.0 11184.0 10850.0 11178.0 1800.0 TOOL NUMBER ........... CGRS-A- 862 TDT SET 21 11377.0 DEAD CRUDE 15.0 THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 49 BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): RE~2L~fS: TIED INTO BHCS DATED 5/14/83 ... PUMPED 330 BBLS DEAD CRUDE INTO TUBING PRIOR TO LOGGING MADE 3 BASE PASSES WHILE PUMPING AT 0.5 BPM MADE BORAX PASSES WITH 35, 68 AND 83 BBLS BORAX AWAY GOC AT 11090' SQUEEZE PERFS AT 11088-11096, 11116-11118 AND 11142-11160 ARE LEAKING. NO DOWN CHANNEL THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 · 6 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1998 16:35 PAGE: 50 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP ELEM CODE (HEX) DEPT FT 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 SIGMBX3 CU 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX3 PU 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF BX3 CU 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 SBHNBX3 CU 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC BX3 CU 1065835 O0 000 O0 0 13 1 i 4 68 0000000000 SIBH BX3 CU 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT BX3 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 LCO1 BX3 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI BX3 CU 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 BACK BX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC BX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TCANBX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TCAFBX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TCNDBX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TCFDBX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TSCNBX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TSCFBX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 INNDBX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 INFD BX3 CPS 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX3 LB 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX3 GAPI 1065835 O0 000 O0 0 13 1 I 4 68 0000000000 CCL BX3 V 1065835 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 11185.000 SIGM. BX3 13.063 TPHI.BX3 25.831 SBHF. BX3 46.396 SBHN. BX3 54.191 SIGC. BX3 0.839 SIBH. BX3 66.561 TRAT. BX3 1.741 LCO1.BX3 2.245 SDSI.BX3 0.291 BACK. BX3 183.506 FBAC.BX3 44.109 TCAN. BX3 37875.133 TCAF. BX3 16870.730 TCND. BX3 24064.000 TCFD.BX3 8204.252 TSCN. BX3 7375.146 TSCF. BX3 3285.114 INND. BX3 1914.056 INFD.BX3 427.335 TENS.BX3 1645.000 GR.BX3 52.813 CCL.BX3 0.000 ** END OF DATA ** **** FILE TRAILER- **** FILE NA~E : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22~JAN-1998 16:35 PAGE: 51 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/22 ORIGIN : FLIC TAPE NA~IE : 98024 CONTINUATION # : 1 PREVIOUS TAPE : COF~4ENT : ARCO ALASKA INC, D.S. 7-24, PRUDHOE BAY, 50-029-20945-00 **** REEL TRAILER **** SERVICE NAFIE : EDIT DATE : 98/01/22 ORIGIN : FLIC REEL NAME : 98024 CONTINUATION # : PREVIOUS REEL : COF~4ENT : ARCO ALASKA INC, D.S. 7-24, PRUDHOE BAY, 50-029-20945-00 *********************** 000 000 00¢) 000 00 o 0 O0 (10t.) 000 o 00 C n, T E 00o 000 nO0 000 O0 0 000 000 000 o16 004 012 004 004 002 OOB 006 004 C 0 D E 065 065 065 065 065 065 065 065 065 '0 ?' : 1,570 ia 60,0 : 2, 050 ¢ 60 0 DF 4 ~, P~ P U c t C 3 C P S CPS ('.; a H T 7 3 C 0 D E 68 68 68 68 68 68 68 68 68 68 t p t-.-1, I 4 2 , 0 6 25 [:' 'F 9.()117 2.9766 C,~ L, J' 2,7930 1 4,5(:25 t T, .9o9.2500 -999,2500 8.5000 GR -99q, 250~'~ 5. 378.° 79.56?5 2,41 $0 8.7500 CF -q99.25fln 1 5 6,t'~q4 3' -999.2500 -999.2500 3658.0000 45,1075 5.7305 42,0625 3428.0000 42.4375 9,0703 19,9219 2906.0000 23.5938 12.2500 137 . iPH l' tP~T I P H 1 iRAT "C % L !t) ti T ,'C!,,! i, ,'C;: I: 10800 0000 727 [2949 I?[!7 afi(~r: 2. T) f~ t4 2. 291 r'? l[l. D ;,' "iF, 4 375 !.') T .:~, 4 FI 0 5 (:" a l,, 4:, 12~q -999.25(::(~ I f. L) 2 . 2207 NCNb -999. 2500 ..... ] 75 00 ~ ra 0 ,") 0 ft -999,2500 74.9375 .Il, q O 1. F! 7 5 (.:, ': 2 2305 t~?: C I~ L * 67 q 7 ('; t~ '999. 2500 7.6953 I51~ 99. 5625 GR 2.7637 ~': C N L 9.5f:~59 GR 52. 875o -999.2500 -999,2500 -999,, 2500 r,;CND -999,2500 65.1 -999.2500 Il'iH -9'99. 2500 -999,250c~ -999 . 25(?,0 59,031 3 -999. 2500 21.8750 3394.0000 26.2187 4~ 8437 2 484,4 3666 0000 24 00()0 41, ,9 ~, 7:5 18,82B1 293~.0000 2 , 0781 I4,7S91 67,7500 3082.0000 75.3750 7.2266 489,2500 2140,.0000 149,3750 1, 926R 87,4375 ~636,0000 85.4375 -999.2500 -999.2500 999.2500 2999.2500 -.999 2500 999~2500 q99.2500 -'699.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 ~ Pf,.! Y -009 ' 2500 'C~f, -999. 2509 Ipaq' -999.25C0 )FP'r 9400. O00t,', !RAT -q(~Q,25OO -9q9,2500 II..r~ -999,250(? UT 2500 ~T-It)[~ -999,,, ,.. ,-~ ,.~ 2500 ~ l,, I ,2500 o; p -.999,2500 q q q 25 00 [: T -9q9.2500 . g .c~ 9.254 (') n f'"~ I. -9~o , 2500 -qq9.2500 ILO -qgq, ?500 f~'l' 0~.750C, Cat.,] -999. 2500 2500 I T,f'.' -999, 2500 -q, g9 ,2500 - 999 ,2500 -999 25('.'o 63 7BJ. ] :I, 1.., U! t',J C N b G R -999,250'0 I.I,M ,,, o q 9,2 S 00 G R -999,2500 GR 63,7189 -g99.2500 lI~a -999,250!1) GP -999,2500 NCNI., -999,25(!0 -999,7500 ILN -qg9,2500 (;P -999.2500 NCNL -999,2500 GP 109,6250 - 999.250 0 I l, ~,I 25OO -999,, .999,25C0 -999 2500 -999,~500 -999. 500 -999,2500 -999,2500 -999,2500 -999,,2,500 -999,2500 -999,2500 -999 25O0 ,2500 09,25(.)0 -999,2500 -999,2500 -999,2500 -909.2500 -999 2500 -g99i2500 -999 2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999 2500 -999i2500 -999 2500 -999,2500 -999 2500 -999:2500 -999.2500 -g99,2500 250o [. !" ? f-i o 0 C ~ L T ,250 O: : :I ,250(') ,250 ri C ~-~ L T ,2500 f:, R K P T 9100,00 L, t S )r I., tJ 1:: - q q <:) 2 51) 0 G P H T -99 9 . 2 500 [!) :~ H 0 -99q, 2500 99 9,2 5 0 o 999 ~ 2500 -99a, 250(') -99° , 2500 -999,2500 - q q ~, 250 r'; C -999 , 2500 -9~9 , 2500 Ir, r, -999,25o0 c~ -999,2500 f~CNL -999 2500 f;t7 74,: i0625 2 ,.:, 00 -099, -999) 75()0 69;8750 -9~g, 2o0,) - 999,2500 -999,2500 -999. 2500 101 ,1250 9 .~ .. 2 % 00 [ I., b~ - 999.25 o {') G R 132 ,2500 -999,2500 II.,M -ga9.25(,)0 -999,2500 -999,25C0 4.~,71.89 -999,2500 -999 . 2500 -999 . 2500 -~gg. 250,') GR 55.8437 -999,2500 -999.2500 -999,2500 NCNt., -999.2500 GP 58,0625 -999,2500 -99q.2500 -999,2560 NCNL -~99,25C0 GP 57.156~ 2500 '' " l ,250(. 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