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Home My WebLink About192-1291. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Abandoned 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10300'2322 None Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-545-1144 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Brian Glasheen brian.glasheen@conocophillips.com RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 7" Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 10280' Burst 3932' AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 9497'MD/6489'TVD 9527' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025636 192-129 P.O. Box 100360, Anchorage, AK 99510 50-029-22313-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? 121'121' 3974' 7068/ 16" 9.625" 79' 3048' 2/1/2026 3-1/2" BAKER HB Retrievable SSSV: None Perforation Depth MD (ft): 7083'None6683'9761' KRU 1H-20 9618-9640' 9691-9701' 9726-9760' 10238' 6578-6594' 6632-6640' 6658-6683' m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 326-039 By Grace Christianson at 11:23 am, Jan 20, 2026 10-407 X AOGCC witnessed BOP and annular test to 2500 psi. AOGCC witness tag TOC and MIT. AOGCC witness casing cuts before any top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut. XX of both West Sak and Schrader plugs. X J.Lau 1/26/26 A.Dewhurst 26JAN26 DSR-1/27/26JLC 1/27/2026 01/27/26 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 31, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. submits this application for sundry approval to Plug and Abandon (P&A) KRU 1H-20 (PTD 192-129). 1H-20 is a Long Term Shut In (LTSI) well that has been selected for slot recovery for upcoming 1H-North new drills that are currently scheduled for late Q2 of 2026 and needs to be P&A. The P&A will be performed in multiple phases. Sundry 325-715 has been submitted and approved to P&A the reservoir. After a traditional Kuparuk P&A (Sundry 325-715), the tubing will be cut above tubing cement retainer/top of cement. Then a rig will come and pull the 3.5" tubing and stack two 7-1/16" valves on the wellhead. This will give eline and coiled tubing access to the 7" casing. The Production casing and OA cement and final P&A details of the well will be completed non rig. If you have any questions or require any further information, please contact me at 907-545-1144. Brian Glasheen Rig Workover Engineer CPAI Drilling and Wells 1H-20 RWO and Plug and Abandon Procedure Kuparuk Injector PTD # 192-129 Page 1 of 3 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Punch and Cut the tubing above tagged top of cement. 3. Prepare well for rig 48-72 hours before rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1H-20. (No BPV will be install pre-rig due to internal risk assessment for N7ES for MIRU/RDMO without a BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2 tubing down to pre-rig cut. a. On POOH with tubing, circulate well over to diesel freeze protect as necessary. 6. Perform 30 minute NFT. ND BOP, NU Tree 7. ND BOPE. NU two 7-1/16 tree valves and any adapter spool. 8. RDMO. Post-Rig Work P&A Eline 1. MIRU. 2. RIH with IBC/DSLT and log 7 casing to confirm TOC of original cement job. POOH If TOC is BELOW Top of Schrader, then do additional production casing x open hole, slot or perf, wash then cement 50 into Schrader and 100 into confining zone above it to isolate for a total of ~150 cement plug. 3. RIH and set 7 CIBP at base of perforation zone, approximately 4,928 MD. POOH. Coil 4. RIH with Gator slot tool or perf guns and perforate 7.0 casing as required to get exposure to top ~50 of West Sak Pay sands and ~100 into the confining zone above it. (Note CIBP set depth and slot/perf intervals may be adjusted, based on log response and/or well conditions encountered) POOH. 5. RIH with wash tool. Gently tag the CIBP. 6. PU and wash slots/perfs. 7. RIH with cement retainer and set at 4758 MD. 8. Pump ~35 bbls of cement through cement retainer. 9. POOH Slickline 10. Notify the AOGCC Inspector of timing for TOC tag and pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 11. SL: RIH and tag top of cement (witnessed) 12. SL: Perform MIT on production casing (witnessed) to 1500 psi 13. RDMO. <100' aboveTOC shall be atleast 100' above top of West Sak and Schrader - J.Lau 1H-20 RWO and Plug and Abandon Procedure Kuparuk Injector PTD # 192-129 Page 2 of 3 Coil 14. RIH with Gator slot tool or perf guns and perforate 7.0 casing as required to get exposure to top ~50 of Schrader formation and ~100 into the confining zone above it. (Note CIBP set depth and slot/perf intervals may be adjusted, based on log response and/or well conditions encountered) POOH. 15. RIH with wash tool. Gently tag the Cement/ Cement Retainer. 16. PU and wash slots/perfs. 17. After wash procedure is completed, cement through slots/perforations with ~35bbls cement, including excess. 18. Leave Top of Cement in production casing ~150ft above top perforation at ~4,252 MD (Note, TOC depth may be adjusted, based on log response and/or well conditions encountered). Circ out excess. 19. RDMO. Wait on cement. Slickline 20. Notify the AOGCC Inspector of timing for TOC tag and pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 21. SL: RIH and tag top of cement (witnessed) 22. SL: Perform MIT on production casing (witnessed) to 1500 psi 23. RDMO. Eline 24. MIRU. 25. RIH and set 7 CIBP at the top of cement logged in the OA. 26. Punch hole in the 7 casing just above CIBP and establish circulation from IA to OA. Pumping 27. MIRU. 28. Pump ~175 bbls cement down the 7 casing taking return up the OA until good cement is seen at surface. 29. RDMO Wellhead Excavation / Final P&A: 30. Confirm production casing and production casing x surface casing annulus pressures are at 0psi. 31. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 32. Remove the tree, in preparation for the excavation and casing cut. 33. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 34. Verify that cement is at surface in all strings. Perform cement top off job(s) if required. AOGCC witness and photo document required. 35. Send the casing head w/ stub to materials shop. Photo document. 36. Weld ¼ thick cover plate (16 O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 1H-20 PTD #: 192-129 API #: 50-029-223-1300 37. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 31. Obtain site clearance approval from AOGCC. RDMO. 1H-20 RWO and Plug and Abandon Procedure Kuparuk Injector PTD # 192-129 Page 3 of 3 General Well info: Wellhead type/pressure rating: FMC Gen 4 Production Engineer: Marina Krysinski Estimated Start Date: 02/01/2026 Workover Engineer: Brian Glasheen (907-545-1144/ brian.glasheen@conocophillips.com) Current Operations: This well is currently shut in the lower Kuparuk is being P&Ad. Well Type: Injector Scope of Work: Pull the existing 3-1/2 completion down to pre-rig cut. Stack two 7-1/16 valves for Eline and coil unit cement operations post-rig. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-IA Passed to 3000 psig on 12-8-2025. MIT-OA Passed to 1800 psig on 12-8-2025. IC POT & PPPOT N/A, to be tested in pre-rig. TBG POT & PPPOT N/A, to be tested in pre-rig. MPSP: 2,322 psi using 0.1 psi/ft gradient Static BHP: 2942 psi / 6200 TVD 1/12/2026. Rig work should be done over P&Ad well and not exposed to formation pressure during Rig portion of work. 1H-03 & 1H-20 Overburden AnalysisWest Sak and Ugnu Sands are hydrocarbon-bearing pay in both wellsNo other hydrocarbon zones in either wellBoth intervals are located between surface casing and production casing Remedial cement jobs performed in both wells and partially cover Ugnu and West Sak Need to investigate quality of remedial cementUgnupay sandsSurface casingWest Sak pay sandsKuparuk reservoirTop PC cementP.C. Cement1H-031H-20Top: 3,746 MD (3,413 SSTVD)Base: 4,336 MD (3,882 SSTVD)Kuparuk reservoirTop PC cementTop PC remedial cementTop: 3,249 MD (2,978 SSTVD)Base: 3,477 MD (3,182 SSTVD)Ugnupay sandsWest Sak pay sandsTop: 4,868 MD (3,521 SSTVD)Base: 5,526 MD (3,927 SSTVD)Top: 4,126 MD (3,048 SSTVD)Base: 4,202 MD (3,098 SSTVD)Top PC remedial cement Detail: Ugnu and Schrader Bluff1H-031H-20Top of Ugnu pay zone 4,080 MD (3,018 SSTVD)Base of Ugnu pay zone 4,199 MD (3,096 SSTVD)Top N Sands4,352 MD (3,196 SSTVD)Base N Sands4,647 MD (3,385 SSTVD)Top West Sak sands4,756 MD (3,453 SSTVD) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,761.0 1H-20 SCOLEM Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Plug 1H-20 SCOLEM Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 9/27/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.53 41.6 3,973.8 3,047.8 40.00 L-80 BTC PRODUCTION 7 6.28 41.6 10,280.0 7,068.0 26.00 J-55 AB-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.6 Set Depth 9,526.5 String Max No 3 1/2 Set Depth 6,510.4 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.6 37.6 0.10 HANGER 8.000 FMC GEN IV HANGER 3.500 1,786.0 1,669.4 36.44 NIPPLE 3.750 OTIS SELECTIVE LANDNG NIPPLE - PULLED MCX INJECTION VALVE 4/25/01 2.813 9,436.1 6,443.5 42.57 GAS LIFT 5.968 CAMCO MMG 2.920 9,483.8 6,478.7 42.21 PBR 5.125 BAKER SHEARED PBR 3.000 9,497.4 6,488.8 42.14 PACKER 6.063 BAKER HB RETRIEVABLE PACKER 2.890 9,514.0 6,501.1 42.13 NIPPLE 4.540 CAMCO D NIPPLE NO GO----- Set Camco CA-2 Plug 3/24/2018 2.750 9,525.6 6,509.7 42.13 SOS 4.570 BAKER SHEAR OUT SUB 3.015 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 9,436.1 6,443.5 42.57 1 GAS LIFT DV RK 1 1/2 7/2/2018 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,618.0 9,640.0 6,578.3 6,594.6 UNIT D, C-4, 1H -20 4/29/2007 6.0 RPERF 2" HSD W/Omega PJ 9,619.0 9,621.0 6,579.0 6,580.5 UNIT D, C-4, 1H -20 3/29/1994 6.0 APERF 2 1/8" Enerjet; 90 deg. 'V' Ph 9,621.0 9,638.0 6,580.5 6,593.1 C-4, 1H-20 4/9/1994 6.0 RPERF 2 1/8" Enerjet; 90 deg. 'V' Ph 9,691.0 9,701.0 6,632.2 6,639.5 C-3, 1H-20 3/29/1994 6.0 APERF 2 1/8" Enerjet; 90 deg. 'V' Ph 9,726.0 9,760.0 6,657.8 6,682.7 C-1, UNIT B, 1H- 20 1/8/1993 12.0 IPERF 60 deg Phasing Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 670.0 3,974.0 667.4 3,047.9 Primary Full Bore Lead 300 bbl 12 ppg Permafrost E + Tail 71 bbl 15.8 ppg Class G... Circulated 10 ppg mud @ 7 bpm with good returns prior to cmt job. Pumped 50 bbl FW spacer, 300 bbl lead cement, and 71 bbl tail cement. Displaced with 20 bb FW. Swwitch to rigpump. Cont. displace w/ 277.2 bbl ppg mud. Lost returns w/ 232.2 bbls displ pumped. Landed csg- after bcome sticky- after 120 bbl displ. Bump plug 2000 psi. Floats held. Fluid level standing at surface. CIP at 1130 hs, 12/21/1992. Performed top job. Ran 1" lines to 80' inside annulus. Flushed with 19 bbl water and pumped 17bbl 15.5 ppg Permafrost C slurry @ 2.5 bpm. Clean cement returns to surface. ^^Csg OD=9.625 0.0 128.0 0.0 128.0 Grouting / Top -Up Top Job 17 bbl 15.6 ppg Permafrost C ... Ran 1" lines to 80' inside annulus. Flushed with 19 bbl water and pumped 17 bbl 15.5 ppg Permafrost C slurry @ 2.5 bpm. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 9,050.0 10,280.0 6,170.6 7,068.0 Primary Full Bore Lead 320 sx 12.5 ppg Class G + Tail 272 sx 15.6 ppg Class G... Batch mix 58.7 bbls, 15.6 ppg cement slurry. Test cement line to 4500 ps. Pump 50 bbls preflush, drop bottom plug. Pump 20 bbls spacer, Pump 130 bbls, 12.5 ppg lead cmt slurry, released middle plug. Pumped 59 bbls 15.6 ppg tail slurry. Dropped top plug. Displace with 384 bbls brine 10.5 ppg. Unable to reciprocate after dropping btm plug andloading top plug. Csg stuck. Bump plug with 3500 psi. Held 3500 psi for 30 minutes. Held. Check floats, holding CIP at 2019 hrs, 12/28/1992. Fullreturns throughout job. Shut hydril and pumped 125 bbls 10.5 ppg mud down 9 5/8" x 7" annulus at 3 bpm- 700 psi. ^^Csg OD=7 2,020.0 3,320.0 1,846.7 2,647.4 Squeeze Behind Casing Squeeze Top Job 38 bbl 15.6 ppg Permafrost C + Tail 60 bbl Arctic Pack **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 1H-20, 1/16/2026 10:32:58 AM Vertical schematic (actual) PRODUCTION; 41.6-10,280.0 IPERF; 9,726.0-9,760.0 APERF; 9,691.0-9,701.0 Primary Full Bore; 9,050.0 ftKB RPERF; 9,621.0-9,638.0 RPERF; 9,618.0-9,640.0 APERF; 9,619.0-9,621.0 PACKER; 9,497.4 GAS LIFT; 9,436.1 SURFACE; 41.6-3,973.8 Squeeze Behind Casing Squeeze; 2,020.0 ftKB Primary Full Bore; 670.0 ftKB NIPPLE; 1,786.0 CONDUCTOR; 42.0-121.0 Grouting / Top-Up; 0.0 ftKB KUP INJ KB-Grd (ft) RR Date 12/26/199 2 Other Elev 1H-20 ... TD Act Btm (ftKB) 10,300.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292231300 Wellbore Status INJ Max Angle & MD Incl (°) 54.70 MD (ftKB) 2,673.49 WELLNAME WELLBORE1H-20 Annotation Last WO: End Date 6/9/1993 H2S (ppm) DateComment SSSV: NIPPLE 1H-20 Proposed Completion Post RWO COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15 62.5 H-40 Surface 3973 3047 9-5/8'' 8.53 40 L-80 Production/ Intermediate 10280 7068 7 6.2 26 J-55 Liner Tubing 9526 6510 3.5 2.9 9.3 J-55 Proposed completion 3.5'' Completion removed Install two 7-1/16" gate valves freeze protect when pulling out of hole COMPLETION Left in hole GLM @ 9436' Packer @ 9497 Cement retainer @~9509' Surface Casing Production Casing Conductor perfs ~PC TOC 9050 CBT ~TBG TOC 9395' via Coil Tubing Schrader sands Top: 4,352 3MD Base: 5521' MD ~Tubing cut 9000' ~PC TOC top job 2020' 1H-20 Proposed Completion P&A COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15 62.5 H-40 Surface 3973 3047 9-5/8'' 8.53 40 L-80 Production/ Intermediate 10280 7068 7 6.2 26 J-55 Liner Tubing 9526 6510 3.5 2.9 9.3 J-55 COMPLETION Left in hole GLM @ 9436' Packer @ 9497 Cement retainer @~9509' Nipple @ 9514 Surface Casing Production Casing Conductor perfs ~PC TOC 9050 CBT ~TBG TOC 9395' via Coil Tubing Schrader sands Top: 4,352 MD Base: 5521' MD ~Tubing cut 9000' ~PC TOC top job 2020' Cement Retainer ~4758' MD Perf/Slots from 4252-4402 West Sak Pay sands Top: 4868 'MD Base: 5521' MD Perf/Slots from 4768-4918' MD CIBP~4928 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A KRU 1H-20 Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk River Field Kuparuk Oil Pool Kuparuk Oil Pool - Abandon 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10300' N/A 9747' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Brown HB Retrievable packer Packers and SSSV MD (ft) and TVD (ft): SSSV: None 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7083' 9747' 6673' N/A jan.byrne@conocophillips.com 808-345-6886 Jan Byrne 12/25/2025 Length Size Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 9497' MD and 6489' TVD N/A Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025636 192-129 P.O. Box 1000360, Anchorage, Alaska 99510 50-029-22313-00-00 ConocoPhillips Alaska, Inc Proposed Pools: J-55 TVD Burst 9526' MD 3932' 121' 3048' 121' 3974' 3.5" 7068'7" 16" 9.625" 79' Staff Intervention Engineer 10280' Perforation Depth MD (ft): 9618-9640', 9691-9701', 9726- 9760' 10238' 6578-6594', 6632-6640', 6658- 6683' m n P 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.11.20 13:00:22-09'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne 325-715 By Grace Christianson at 2:17 pm, Nov 20, 2025 J.Lau 12/18/25 10-407 TS 12/15/25 AOGCC witnessed tag and PT of Kuparuk abandonment plug. DSR-11/21/25 X 12/22/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 20, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, ConocoPhillips Alaska, Inc. submits this application for sundry approval to Plug and Abandon (P&A) KRU 1H-20 (PTD 192-129) of the Kuparuk reservoir. 1H-20 is a Long Term Shut In (LTSI) well that has been selected for slot recovery for upcoming 1H-North new drills that are currently scheduled for late Q2 of 2026 and needs to be P&A. The P&A will be performed in multiple phases. This sundry is specifically for the P&A of the Kuparuk reservoir with non-rig intervention equipment. Per this procedure P&A well operations will be performed to isolate the C-sand perforations by pumping 20 bbls of 15.8 ppg class G cement through a cement retainer at ~9509. Additional sundries will be submitted for the remainder of the P&A which will be performed with a combination of rig and non-rig intervention equipment. As such CPAI requests variance to allow the 10-407 be submitted post the subsequent sundries and completion of the full P&A to surface. Please contact Jan Byrne at 265-6471 if you have any questions. Sincerely, Jan Byrne Wells Engineer ConocoPhillips Alaska, Inc. 1 1H-20 P&A of Kuparuk reservoir Date: 11/18/2025 Network Number: 50075898 Prepared by: Jan Byrne (808-345-6886) Objective 1H-20 has been selected as a slot recovery location for the upcoming 1H-North wells slated to be drilled in late Q2 of 2026. As such the well needs to be P&Ad. This procedure is to isolate the Kuparuk reservoir with cement. A RWO rig will follow in late Q1 of 2026 to complete the Plug and Abandonment. Current Well Status LTSI well, shut in since November 2013 No known anncomm issues. Passed an MITIA to 1820 psi on 8/23/25 Last tag at 9747 on 3/24/2018 Last SBHP: 2,488 psi at 6,535' TVD on 03/24/18 Reservoir temperature: ~160°F Tubing: 3.5", 9.3 lb/ft, J-55 Production Casing: 7", 26 lb/ft, J-55 Volume calculations: o Cement retainer, C-sand Retainer set at ~9509 in 3.5 Cals from 7 casing from packer at 9497 to 9747 (last tag) = 250. 250 x 0.03826 = 9.6 bbls. Procedure Slickline/LRS 1. Brush and flush tubing (plan to set cement retainer at ~9509). 2. Drift tubing for cement retainer (2.75 OD x 84 OAL) down to D nipple at 9514. 3. Drift and tag as deep as possible for fill depth. 4. RIH with dual spartek gauges to acquire SBHP. o 10 min lubricator stop o 30 min stop at 9691 or just above fill depth o 15 min stop at 9486 or 100 TVD above previous stop 5. Perform step rate test pumping down tubing to formation with 60 bbls seawater in 20 bbl increments at 1 bpm, 1.5 bpm & 2 bpm. 1500 psi max pressure. 6. Freeze protect tubing with 18 bbls diesel. Coil 7. RIH with Quadco 2.750 FH cement retainer to set at ~9509 middle of 10.3 pup joint (tag 2.75 D nipple at 9514 for correlation). Pull test < 1000 lbs to verify good set. Perform PT between coil x tubing annulus to verify retainer integrity. 8. Pump down coil through the retainer, performing an injectivity test to verify injectivity for cementing. 9. Pumping down coil to formation, pump the following schedule through the retainer. With one barrel of cement remaining in coil, un-sting from the retainer and lay the last barrel on the retainer. o 5 bbls freshwater spacer o 20 bbls 15.8 ppg class G cement (2x volume) o 5 bbls freshwater spacer o Coil displacement to surface o Freeze protect tubing with 18 bbls diesel from 2000 TVD to surface Slickline/LRS 10. WOC a minimum of 48 hours before proceeding to the AOGCC witnessed Tag and MITT. 11. Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 12. RIH for AOGCC witnessed TOC tag (estimate 9395 MD / 6413 TVD) and perform MITT to 1603 psi (TOC TVD x .25 or 1500 psi, whichever is higher). Record results in WSR. 13. With passing TOC tag and MITT, bleed pressures back to starting and RDMO, leave well as is. Ready for pre-Rig well work. Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 121.0 Set Depth (TVD) 121.0 Wt/Len (l 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.53 Top (ftKB) 41.6 Set Depth (ftKB) 3,973.8 Set Depth (TVD) 3,047.8 Wt/Len (l 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 41.6 Set Depth (ftKB) 10,280.0 Set Depth (TVD) 7,068.0 Wt/Len (l 26.00 Grade J-55 Top Thread AB-MOD Tubing Strings Tubing Description TUBING String Ma 3 1/2 ID (in) 2.99 Top (ftKB) 37.6 Set Depth (ft 9,526.5 Set Depth (TVD) ( 6,510.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.6 37.6 0.10 HANGER FMC GEN IV HANGER 3.500 1,786.0 1,669.4 36.44 NIPPLE OTIS SELECTIVE LANDNG NIPPLE - PULLED MCX INJECTION VALVE 4/25/01 2.813 9,483.8 6,478.7 42.21 PBR BAKER SHEARED PBR 3.000 9,497.4 6,488.8 42.14 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,514.0 6,501.1 42.13 NIPPLE CAMCO D NIPPLE NO GO----- Set Camco CA-2 Plug 3/24/2018 2.750 9,525.6 6,509.7 42.13 SOS BAKER SHEAR OUT SUB 3.015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,618.0 9,640.0 6,578.3 6,594.6 UNIT D, C-4, 1H -20 4/29/2007 6.0 RPERF 2" HSD W/Omega PJ 9,619.0 9,621.0 6,579.0 6,580.5 UNIT D, C-4, 1H -20 3/29/1994 6.0 APERF 2 1/8" Enerjet; 90 deg. 'V' Ph 9,621.0 9,638.0 6,580.5 6,593.1 C-4, 1H-20 4/9/1994 6.0 RPERF 2 1/8" Enerjet; 90 deg. 'V' Ph 9,691.0 9,701.0 6,632.2 6,639.5 C-3, 1H-20 3/29/1994 6.0 APERF 2 1/8" Enerjet; 90 deg. 'V' Ph 9,726.0 9,760.0 6,657.8 6,682.7 C-1, UNIT B, 1H -20 1/8/1993 12.0 IPERF 60 deg Phasing Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 9,436.1 6,443.5 CAMCO MMG 1 1/2 GAS LIFT Open RK 7/2/2018 Notes: General & Safety End Date Annotation 9/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE 1H-20, 7/3/2018 5:18:01 AM Vertical schematic (actual) PRODUCTION; 41.6-10,280.0 IPERF; 9,726.0-9,760.0 APERF; 9,691.0-9,701.0 RPERF; 9,621.0-9,638.0 RPERF; 9,618.0-9,640.0 APERF; 9,619.0-9,621.0 SOS; 9,525.6 NIPPLE; 9,514.0 PACKER; 9,497.4 PBR; 9,483.8 GAS LIFT; 9,436.1 SURFACE; 41.6-3,973.8 NIPPLE; 1,786.0 CONDUCTOR; 42.0-121.0 HANGER; 37.6 Last Tag Annotation Last Tag: RKB End Date 3/24/2018 Depth (ftKB) 9,747.0 Last Mod By jhansen8 Last Rev Reason Annotation Rev Reason: Pull 1.5" Dummy Vlv End Date 7/2/2018 Last Mod By Jhansen8 KUP INJ KB-Grd (ft) Rig Release Date 12/26/1992 Annotation Last WO: End Date 6/9/1993 1H-20 H2S (ppm) Date... TD Act Btm (ftKB) 10,300.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292231300 Wellbore Status INJ Max Angle & MD Incl (°) 54.70 MD (ftKB) 2,673.49 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 121.0 Set Depth (TVD) 121.0 Wt/Len (l 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.53 Top (ftKB) 41.6 Set Depth (ftKB) 3,973.8 Set Depth (TVD) 3,047.8 Wt/Len (l 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 41.6 Set Depth (ftKB) 10,280.0 Set Depth (TVD) 7,068.0 Wt/Len (l 26.00 Grade J-55 Top Thread AB-MOD Tubing Strings Tubing Description TUBING String Ma 3 1/2 ID (in) 2.99 Top (ftKB) 37.6 Set Depth (ft 9,526.5 Set Depth (TVD) ( 6,510.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl ComItem Des(°) Nominal ID (in) 3.500FMC GEN IV HANGERHANGER0.1037.637.6 OTIS SELECTIVE LANDNG NIPPLE - PULLED MCX INJECTIONNIPPLE36.441,669.41,786.0 VALVE 4/25/01 2.813 3.000BAKER SHEARED PBRPBR42.216,478.79,483.8 2.890BAKER HB RETRIEVABLE PACKERPACKER42.146,488.89,497.4 2.750CAMCO D NIPPLE NO GO----- Set Camco CA-2 Plug 3/24/2018NIPPLE42.136,501.19,514.0 3.015BAKER SHEAR OUT SUBSOS42.136,509.79,525.6 Perforations & Slots Btm (ftKB)Top (ftKB) Top (TVD) (ftKB) Btm (TVD) DateLinked Zone(ftKB) Shot Dens (shots/ft )ComType UNIT D, C-4, 1H6,594.66,578.39,640.09,618.0 -20 2" HSD W/Omega PJRPERF6.04/29/2007 UNIT D, C-4, 1H6,580.56,579.09,621.09,619.0 -20 2 1/8" Enerjet; 90 deg. 'V' PhAPERF6.03/29/1994 2 1/8" Enerjet; 90 deg. 'V' PhRPERF6.04/9/1994C-4, 1H-206,593.16,580.59,638.09,621.0 2 1/8" Enerjet; 90 deg. 'V' PhAPERF6.03/29/1994C-3, 1H-206,639.56,632.29,701.09,691.0 C-1, UNIT B, 1H6,682.76,657.89,760.09,726.0 -20 60 deg PhasingIPERF12.01/8/1993 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) ServOD (in)ModelMake(ftKB) Valve Type Latch Type Port Size (in) TRO Run ComRun Date(psi) 1 7/2/2018RKOpenGAS LIFT1 1/2MMG6,443.5 CAMCO9,436.1 Notes: General & Safety AnnotationEnd Date NOTE: View Schematic w/ Alaska Schematic9.09/27/2010 Comment SSSV: NIPPLE 1H-20, 7/3/2018 5:18:01 AM Vertical schematic (actual) PRODUCTION; 41.6-10,280.0 IPERF; 9,726.0-9,760.0 APERF; 9,691.0-9,701.0 RPERF; 9,621.0-9,638.0 RPERF; 9,618.0-9,640.0 APERF; 9,619.0-9,621.0 SOS; 9,525.6 NIPPLE; 9,514.0 PACKER; 9,497.4 PBR; 9,483.8 GAS LIFT; 9,436.1 SURFACE; 41.6-3,973.8 NIPPLE; 1,786.0 CONDUCTOR; 42.0-121.0 HANGER; 37.6 Last Tag Annotation Last Tag: RKB End Date 3/24/2018 Depth (ftKB) 9,747.0 Last Mod By jhansen8 Last Rev Reason Annotation Rev Reason: Pull 1.5" Dummy Vlv End Date 7/2/2018 Last Mod By Jhansen8 KUP INJ Rig Release DateKB-Grd (ft) 12/26/1992 Annotation Last WO: End Date 6/9/1993 1H-20 DateH2S (ppm)... TD Act Btm (ftKB) 10,300.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292231300 Wellbore Status INJ Max Angle & MD Incl (°) 54.70 MD (ftKB) 2,673.49 Cement retainer at ~9509' Calculated TOC at ~9395' Post cementing reservoir CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:10-426 form from 1H PAD on 8-23-25 Date:Sunday, August 24, 2025 8:41:47 AM Attachments:image001.png MIT KRU 1H PAD SI TESTS 08-23-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s that were conducted on 8-23-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58+ 37' non witnessed shut in MITIA’s OPERATOR:FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1930200 Type Inj N Tubing 2300 2300 2300 2300 Type T 6334 BBL Pump 1.1 IA 460 1760 1730 1725 Interv 1584 BBL Return 1.0 OA 10 10 10 10 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1921290 Type Inj N Tubing 200 220 220 220 Type T 6489 BBL Pump 1.7 IA 170 1820 1780 1775 Interv 1622 BBL Return 1.6 OA 130 320 320 320 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2180310 Type Inj N Tubing 0 0 0 0 Type T 3737 BBL Pump 1.4 IA 250 1810 1770 1760 Interv 1500 BBL Return 1.4 OA 20 30 30 30 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu TYPE TEST Codes INTERVAL Codes Result Codes 1H-18 1H-20 1H-110 p, Kuparuk / KRU / 1H Pad Arend 08/23/25 9 9 9 9 999 99 9 9 -5HJJ 1H-20 K2� t 4-7,0 Regg, James B (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> �j Sent: Thursday, August 12, 2021 8:39 AM Cl To: Regg, James B (CED); Wallace, Chris D (CED); Brooks, Phoebe L (CED); DOA AOGCC Prudhoe Bay Subject: Recent KRU SI MITIAs Attachments: MIT KRU 2C-03 SI TEST 08-10-21.xlsx; MIT KRU 1H PAD SI TESTS 08-09-21.xlsx; MIT KRU 2D PAD SI TESTS 08-09-21.xlsx; MIT KRU 1 H PAD SI TESTS 08-08-21.xlsx W Recent non -witnessed SI MITIAs performed in Kuparuk. Please let me know if you have any questions. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to:jim.regg(a)alaska.gov: AOGCC.Inspectors(a)alaska.gov; phoebe.brookst?a alaska.gov chris.wallaceaalaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD /UNIT /PAD: Kuparuk /KRU / 1 H Pad DATE: 08/09/21 1l\ tJ OPERATOR REP: Hills / Green AOGCC REP: Well 1H-12 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I = Initial Test P = Pass PTD 1930440 Type Inj N Tubing 530 2010 1975 1965 I = Industrial Wastewater Type Test P Packer TVD 6085 BBI -Pump 1.3 IA 530 2010 1980 1970 Interval 4 Test psi 1521 BBL Return 1.3 OA 0 0 0 0 Result P Notes: CMIT due to dummy valve removed from station # 1 Well 1H -19A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2130020 Type Inj N Tubing 275 275 275 275 Type Test P Packer TVD 6369 BBI -Pump 1.4 IA 50 1900 1870 1860 Interval 4 Test psi 1592 BBL Return 1.2 OA 330 350 350 350 Result P Notes: Well 1H-20 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1921290 Type Inj N Tubing 60 100 100 - 100 - Type Test P Packer TVD 6489 BBL Pump 1.6 IA 170 1900 - 1865 1855 Interval 4 Test psi 1622 BBL Return 1.8 OA 85 310 310 310 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Form 10-426 (Revised 01/2017) MIT KRU 1H PAD SI TESTS 08-09-21 INTERVAL Codes Result Codes TYPE INJ Codes TYPE TEST Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance 1 = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 1H PAD SI TESTS 08-09-21 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,August 27,2013 TO: Jim Regg Pi) TNe,,,, 61(70( P.I.Supervisor 1.3 SUBJECT: Mechanical Integrity Tests (/ CONOCOPHILLIPS ALASKA INC 1H-20 FROM: Jeff Jones KUPAR1JK RIV UNIT 1H-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv.jeC-- NON-CONFIDENTIAL Comm Well Name KUPARUK R1V UNIT 1H-20 API Well Number 50-029-22313-00-00 Inspector Name: Jeff Jones Permit Number: 192-129-0 Inspection Date: 8/11/2013 Insp Num: mitJJ130822144926 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 111-20 -- Type Inj I, w-TVD 6489 " 1 IA 1 720 1 2800 , 2700 .1 2670 - 1 1 1 I PTD1 1921290 - Type Test SPT Test psi, 1622 -T OA--1 I 120 1 340 , 1 340 1 340 , 4- Interval 4YRTST IP/F I P - Tubingl 2125 . _1 2100 .1 2150 , 2150 1 Notes: 2.9 BBLS diesel pumped. I well house inspected,no exceptions noted. - SCht4t45) - - Tuesday,August 27,2013 Page 1 of 1 • ConocoPhillips a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 12, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: C~ ~E~E~~~° gEg 1 g 2010 COmi't11SS10n ~-laske Oil & A~ er~ge' ~~~~ 4~~ 11 .. ~,,~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the. annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped February 9~' &l0a`, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ Loveland 1~~= ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date D...1 A U A I O A A C ell Name PI # TD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date 1 PV 111 IV V Corrosion inhibitor [ 11\ Corrosion inhibitor/ sealant date ff bbls ft al 1 H-15 50029223280000 1930030 23" n/a 23" n/a 4.2 2/9/2010 1 H-16 50029223150000 1921310 25" n/a 25" n/a 4.8 2/9/2010 1 H-19 50029223120000 1921280 22" n/a 22" n/a 4 2/10/2010 1 H-20 50029223130000 1921290 25" n/a 25" n/a 4.6 2/10/2010 1 H-22 50029223640000 1930600 22" n/a 22" n/a 4.2 2/9/2010 1H-105 50029207270100 2042280 3" n/a 3" n/a 3.4 2/9/2010 1J-180 50029233290000 2061500 18" n/a 18" n/a 3.8 2/9/2010 1J-182 50029233210000 2061320 17.5" n/a 17.5" n/a 3.6 2/9/2010 1 R-21 50029222110000 1911130 24" n/a 24" n/a 4.6 2/9/2010 • ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, August 17, 2009 Jim Regg P.I. Supervisor ~ Z,C(a / aCi SUBJECT: Mechanical Integrity Tests ~ b CONOCOPHILLIPS ALASKA INC l I H-20 FROM: Bob Noble KUPARUK RN UNIT 1H-20 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By:T P.I. Suprv J~~' Comm Well Name: KUPARUK RIV iJNIT 1H-20 API Well Number: 50-029-22313-00-00 Insp Num: mitRCN090815085110 Permit Number: 192-129-0 / Rel Insp Num: Inspector Name: Bob Nobie Inspection Date: 8~14/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 1H-20 TYPe Inj. ~/ 'j'~ 6489 ~ jA 170 2350 i 2280 2270 i P.T.D 1921290 TypeTest SPT Test psi 2350 / ~A 0 200 190 190 Interval 4YRTST P~ r Tubing 1650 1650 1650 1650 Notes: ~~l ~ ~„ ' , ~~ `~ P"~~~e r6 z z..~; ~``~~~',~~~ t.._. ., . ~1~~~~ Monday, August 17, 2009 Page I of 1 ons. f'IUM, 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other l'1"cnf!!)ge 'V'VIi Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 0 / 0 Change Approved Program Operat. ShutdownD Perforate 0 Re-enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 192-1291 r 3. Address: Stratigraphic 0 Service 0 , 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22313-00 r 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 1 H-20 . 8. Property Designation: 10. Field/Pool(s): ./ Kuparuk River Field 1 Kuparuk Oil Pool " ADL 25636, ALK 2569 11. Present Well Condition Summary: Total Depth measured 1 0300' / feet true vertical 7083' . feet Plugs (measured) Effective Depth measured 9767' feet Junk (measured) true vertical 6688' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 39'31' 9-5/8" 3974' 3048' PROD. CASING 10239' 7" 10280' 7068' Perforation depth: Measured depth: 9618'-9640',9691'-9701',9726'-9760' true vertical depth: 6578'-6595',6632'-6640',6658'-6683' öCANNEDJUN 14 2007 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 9527' MD. Packers & SSSV (type & measured depth) pkr- BAKER 'HB' RETR @ 9497' Nipple @' 1786' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinn Pressure Tubina Pressure Prior to well operation na na SI -- Subsequent to operation na na 3545 ./ -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after work: OiID GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Guy Schwartz @ 265-6958 Printed Name ..-,Guy SC~/ () _ Title Wells Group Engineer Signature Cì~ ¿./ ~ Phone Date S" -I ~-Or p~nared b" Sharon AI/suo-Drake 263-4612 Form 10-404 ~eLed 04/2006 ....,."..~ RBDMS 8Ft JUN "I :I. Z007 .AJ> >. z> -ò7 Submi ri i a Onl . R~8~D STATE OF ALASKA . MAY 1 6 ALASKA OIL AND GAS CONSERVATION COMMISSION A/ask' 2007 REPORT OF SUNDRY WELL OPERATIONS a 0" & Gas C DLJPt fCl~;TF ~fY ~}~~ . 1 H-20 Well Events Summary . DATE Summary 4/29/07 PERFORATED: 9618' - 9640' ,6 SPF, USING 2" HSD GUNS WITH OMEGA POWERJET CHARGES. EH= 0,22", PENT= 21.8" . . ConocoPhillips Alaska, Inc. KRU 1 H -20 1 H-20 API: 500292231300 Well Type: INJ Angle @ TS: 42 dea (á) 9620 ~ SSSV Type: NIPPLE Orig 12/26/1992 Angle @ TD: 41 deg @ 10300 Completion: Annular Fluid: Last w/o: 6/9/1993 Rev Reason: TAG NIPPLE Reference Loa: Ref Log Date: Last Update: 8/29/2006 (1786-1787, 00:3.500) Last Taa: 9767 RKB TD: 10300 ftKB TUBING Last Taa Date: 8/27/2006 Max Hole Angle: 55 deg @ 2674 (0-9527, Casino Strino - ALL STRINGS 00:3.500, 10:2.992) Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 SUR. CASING 9.625 0 3974 3048 40.00 L-80 W PROD. CASING 7.000 0 10280 7068 26.00 J-55 Gas Lift Tubino Strlno - tUBING I ndrellOummy Size I Top 1 Bottom I TVD I Wt I Grade I Thread Val",,1 3.500 I 0 I 9527 I 6511 I 9.30 I J-55 I ABM-EUE (9436-9437. Perforations Summarv 00:5.968) Interval TVD Zone Status Ft SPF Date Type Comment 9619- 9621 6579 - 6580 UNIT 2 6 3/29/1994 APERF 2 1/8" Enerjet; 90 deg. 'V' ... D,C-4 Ph PBR 9621 - 9638 6580 - 6593 C-4 17 6 4/9/1994 RPERF 2 1/8" Enerjet; 90 deg. 'V' (9484-9485, -- Ph 00:3.500) 9691 - 9701 6632 - 6640 C-3 10 6 3/29/1994 APERF 2 1/8" Enerjet; 90 deg. 'V Ph 9726 - 9760 6658 - 6683 C-1,UNrT 34 12 1/8/1993 IPERF 60 OOg Phasing B Gas Lift MandrelsNalves St I MD I TVD I Man Man Type I V Mfr I V Type I V OD I Latch I Port I TRO I Date I VIv PKR Mfr Run Cmnt (9497-9498, 1 1 94361 64431 Camco I MMG I I DMY I 1.5 I RK I 0.000 I 0 I 7/4/1993 I 00:6.156) Other (I luos e[]uip. etc.) - JEWELRY Depth TVD Tvpe Description ID 1786 1669 NIPPLE Otis Selective Landing - Pulled MCX Injection Valve 4/25'01 2.813 9484 6479 PBR Baker sheared 3.000 9497 6488 PKR Baker 'HB' Retr 2.891 NIP I..J 9514 6501 NIP Camco 'D' Nipple NO GO 2.750 (9514-9515, 9526 6510 SOS Baker 2.992 003.500) 9527 6511 TTL 2.992 SOS (9526-9527, 00:3.500) TTL (9527-9528, 00:3.500) Perf - - (9619-9621) - - PROO. .m._ CASING -...... - (0-10280, ........-. -- OOTOoo, Wt:26.OO) - --.-... Perf =--- = (9621-9638) --- - _. ..n...... - - - ..... .. ----..- - - - - - - - - Perf - - (9691-9701) ..- .--- -."--- .. - ........... - - - - m....._ --.---- -- Perf - - (9726-9760) - - - - - - _.~ -. .n ....__. - - .."-- ........... ......--- --. - I------ ..---- e ConocóP'hillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 March 16, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 i.'j; Subject: Report of Sundry Well Operations for 1 H-20 (APD # 192-129) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 H-20. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Il4~~j M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad Kt:.L,t:1 V ~u e e MAR 2 8 ZO()6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas CO!'l$. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. , Development 0 Exploratory 0 192-129/' 3. Address: Stratigraphic 0 Service 0 6. API Number: ,,- P. O. Box 100360, Anchorage, Alaska 99510 50-029-22313-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 1 H-20 , 8. Property Designation: 10. Field/Pool(s): ADL 25636,'ALK 2569 Kuparuk River Field 1 Kuparuk Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 1 0300' . feet true vertical 7083' / feet Plugs (measured) Effective Depth measured 9759' feet Junk (measured) true vertical 6682' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 3878' 9-5/8" 3974' 3048' PROD. CASING 10184' 7" 1 0280' 7068' Perforation depth: Measured depth: 9619'-9638',9691'-9701',9726'-9760' true vertical depth: 6579'-6593',6632'-6640',6658'-6683' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 9527' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' RETR @ 9497' Otis nipple @ 1786' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9619'-9638', 9710'-9750' Treatment descriptions including volumes used and final pressure: see summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure TubinQ Pressure Prior to well operation -- -- 2700 -- Subsequent to operation -- -- 2700 -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Lead Signature d~ J4,~ Phone Date ",--1: cÝô6 p~nared b haron AlIsun-DrakR 263-4612 { j ~ Form 10-404 Revised 04/2004 JPLICATE k"$.; , A7á~ Sub~ Original Only 4D $.,(.óC. NIPPLE (1786-1787, 00:3.500) TUBING (0-9527, 00:3.500, 10:2.992) Gas lift ,ndrellOummy Valve 1 (9436-9437, 00:5.968) PBR (9484-9485, 00:3.500) PKR (9497-9498, 00:6.156) NIP (9514-9515, 00:3.500) SOS (9526-9527, 00:3.500) TTl- (9527-9528, 00:3.500) Perf (9619-9621) PROD. CASING (0-10280, 00:7.000, Wt:26.00) Perf (9621-9638) Perf (9691-9701 ) Perf (9726-9760) ConocoPhilUps Alala, Inc. 1 H-20 o - e KRU - - - -., "1=i=20 9621 - 9638 9691 - 9701 9726 - 9760 6580 - 6593 6632 - 6640 6658 - 6683 Zone UNIT D,C-4 C-4 C-1,UNIT B C-3 Bottom 121 3974 10280 6 6 12 ~Qgle @ IS: .42 deQ @ 9_~20 ___ Angie @ TD: 141 deg @ 10300 Rev Reason: TAG FILL Last U date: 1/2/2006 TVD 121 3048 7068 Description Otis Selective Landin - Pulled MCX In'eetion Valve 4/25/01 Baker sheared Baker 'HB' Retr Cameo 'D' Ni Ie NO GO Baker Well Type:_'INJ,__ Orig 12/26/1992 Com letion: Last W/O: 6/9/1993 Ref L Date: TD: 10300 ftKB _J_astTa Date: 12/30/2005 ____.' Max Hole An Ie: 55d~@_?674 C_~_~!~g_§Jring - ALL STRING?___ Descri tion ' Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Tubin Strin - TUBING __,_____;~O~ T~ '=j ___,B~~~7m H~---+~~~~-' Perforations SU!1'!1'ary Interval TVD 9619 - 9621 6579: 6580-- Date -TJY¡:J~__' comrñ-én(~ 3/29/1994, APERF 21/8" Enerjet; 90 deg. V' Ph 4/9/1994 RPERF 21/8" Enerjet; 90 deg. V' Ph 3/29/1994 APERF 21/8" Enerjet; 90 deg. V' Ph 1/811993 IPERF 60 deg Phasing Stãius_LJt I SPF . '2 6 17 10 34 Wt 62.50 40.00 26.00 Thread Thread ABM-EUE Vlv Cmnt ID 2.813 3.000 2.891 2.750 2.992 2.992 DATE 02/20/2006 e e 1 H-20 Well Events Summary Summary PIEZO SONA TOOL - STIMULATE PERFORATION INTERVALS 9619'-9638',9710'-9750' INJECTING 2700BWPD AT 1925 PSI AT STARTOF JOB, INJECTING 2700 BWPD AT1909 PSI AT FINISH e e MECHANICAL INTEGRITY PART II REPOTR ' Calculation Sheet For No Fluid Movement Behind Pipe " T 2,.- 2. iii,,:!;;.::",!::..;!i:!:::::i;:¡;;:¡:.,i;;):::]!:;::ii¡;j¡ii:i!i¡!::j::i;:.i)i¡d;i!::¡¡);;¡!¡)i¡;ji:i:¡¡'!i;¡j¡¡;¡.i!j;j::¡:ij¡i:;WEULÐA1TA:¡¡.i,;i:;i;::!!,i,;¡;.:;;¡!,¡¡;¡,:;;"ji;.i",¡,:;;i.:¡:;;'¡::.".:;:,,'i;'¡¡¡!'¡¡¡i;i";;:':;;:;;;':;']':';.'::';:¡:::"!'¡:;';;'::i::":.:;,;,;.:!¡:., SPUD DATE: 12.{ ( 9 {9? WELL NAME & NUMBER: ~ R U ( H - 2. 0 RIG RELEASE: (2../~&/9 ê OPERATOR I FIELD I POOL: Arco 6 íco f93 TD: Shoe: Shoe: Set@: And PBTD: DV: Top: Packer: Perforations: 972. , MD: TVD: MD: Open Hole: Casing: -¡ 2 b.J ('" e Y"t.... liner: Tubing: '37-'2.. 4.3 --1 Hole Size: 97~ 0 :.;::¡¡¡:;:ii¡;¡;;n:Hii¡;¡¡¡:¡H¡;:::¡:¡¡¡¡¡:::ni¡¡;¡::i¡¡:¡¡¡¡::¡::¡¡H¡H¡i:¡¡i;:!¡;¡:i¡j;;MEÇf:i~IGAL.lNIT1Ëßar;f¡;'(iH;p-"Frt;Jjji;:¡;¡¡¡:;::¡¡;¡::;¡¡;¡:;;ji¡:i;j;;¡¡¡i¡:¡¡¡:j:i¡¡:¡¡;:¡¡:¡j¡;:j¡:¡¡¡¡¡¡j¡¡¡¡:¡¡¡¡¡¡¡¡¡¡ii¡:¡¡:¡:¡¡¡¡j:¡¡:;jj!¡¡H¡;¡ Annulus Pressure Test. Initial Press: 15 Min.: 30 Min.: Comments: I _ ",,::;.:;:.!:,;;,!:,::::;;:::,,:::;'.:.;;:;:;:;i!:¡;..i,;¡:¡:::·i¡::¡:,i;;;;.,,;,;:¡:..MECHANICAu}iNTEßBr:D'nH,:eART:IJ,:;¡:¡¡:.:'¡';,:'j,;;¡¡".:;;;¡j,j;;:i;:.!:!",,:i::,¡!i;;¡;;::::¡;;·j.::.¡;;¡..:;i:;!;¡:;;i:;,:.;:;;:¡::::;:;.;::::.;::!I :.. ,f Volumes: Amount Liner: Casing: 592. s.¡;.. DV: 7" Z S¡t ~V2 ('1. 'é3V~ Theoretical TOG: 97'2.~ 'roduction Log; Type: CC3r Cement Bond Log (Yes or No) ;SL Evaluation. Zone Above Perfs: Evualation: , ,,' ,.':, ,:,,',',"'" ·.;¡i:;. ¡':i'.,:(UU:,,::.:,',;i:.!,:,:'./;:';:i..j¡;::;:.:':¡;::¡.U:¡,¢PNSlUSIpNS2H::::::':;'.¡¡:¡¡:;:;::::'::U:i:H:/:::,:,:::i¡·:.":¡:!'¡'H;:·'·¡:¡¡¡u:;n}iU;i;·.Hj¡¡j:¡iii¡::;H:;,::;;:¡:;U¡:" 'ART III 'ART 1111 1'1 t::B~..A 9 /¡5"/~ l:o, ~ATURE: DATE: sfribution: g - Well File ,EPA n_a-....___ MEMORANDUM TO: Julie Heusser ~ Commissioner/~\q,; ' State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 6, 2001 FROM: Jeff Jones Petroleum Inspector SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~r"'~.,~O~ Phillips Alaska Inc. P.I. Supervisor/~]~ "~'"- ' 1H Pad 1H-12,1H-18, 1H-19, 1H-20, 1H-22 KRU Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. · w,,,I ~.-~= I T~,nJ.I s i.~.v.o. I ~ I Tu~,n~ l. 2~ I =~ I =~ I. ==' I.'nt~'a'l 4 P.T.D.I 1 ,93(M40 ITypetesti P ITest~l, 1524, I Cas~ngI 475 I 49501 4925 .I 4900. i P/F I P Notes: Monitored casing pressure additional 15 min. & pressure stabilized at 1900 psi , , w=~l ~8 ,ITy.~,,..J.I. s I T-Y-O-I 6333 ITuangi 2O6O1 20~0 i. 2o~o. I 2~,l~nt~,~l4i P.T.D.I 1930200 ITypetestI P i~.= ,~i ~583"1 caan~! Soo ! 2;~s0 I 244o I 244o I P/F I P Notes: "w,~,l ~.-~9 I'+~nj.I's I T.v.b. i 63~ I Tubing'! 25~,0I 2~0 I 250O I 25r,0 I~.t,.~l 4 P.T.D.I 1921280 ITy~t~l' PIT~I ~= Ic,~,..i ~o'1'~='I,.~, I~o. I P~FIP Nol~s: wa~l 4H-2O I T~e~.J.isIT.v-D- ! ~ ITua~l' 27251'2725 I 2725 I' 2725' I~nterva~l 4 PiT. D.! 1921290IT~,~e"I p"'lTeStpsi'l 4622 IcaangI 750 1'.,4790 I' 47~ .I 47.50 I P/FIE #OIDeS: i. wa~! 4H-22 I Type~nJ.I, S iT-v'D- I'.5332 ITu~"~.! 22.50 I =~ol =~o'1'=~o I'.~a'l ~' P.T.D.I 4930a)0 ITypetest.!' P, ITest~I 4583. I CasingI 92O l.,4750 I 1730 I 1740 I P/F I.P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Friday~ J.uly 6, ..2001: I traveled to Phillips Alaska Inc.'s 1H Pad and witnessed the 4-year MIT's on wells 1H-12, 1H-18, 1H-19, 1I-I20 and 1H-22. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all five wells passing the MIT's. Summary,: I witnessed successful 4-year MIT's on PAl's wells 1H-12, 1H-18, 1H-19, 1H-20, and 1H-22 in. the Kuparuk River Field / KRU. M.I.T.'s performed: Attachments: Number of Failures: _.0 Total Time during tests: 3 jhm. CC: MIT report form 5/t2/00 L.G. MIT 1H Pad KRU 7-6-01 JJ.xls 7/16/01 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE DECEMBER 01 2000 M E P L W E IA L U N D ER A T TH IS M ARK ER C:LO~.DOC PERMIT 92-129 92-129 92-129 92-129 92-129 92-129 92-129 92-129 92-129 92-129 AOGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS -- 5572 ~-T~'0H CDR/CDN 407 .?~R COMP DATE'06-10-93 DAILY WELL OP. ~'~DRILLING HISTORY SURVEY ~R~- SUB-SURFACE DIRECT. SURVEY {~R SS DIRECTIONAL CBT ~I~ CH CDN-DC /~ 3973-10300 CDR ENHANCEMENT~'-' 9568-9802 CDR-DC -'~ 3973-10300 CET /.2~" CH Are dry ditch samples required? yes._~nd received? Was the well cored? yes ~t~/Analysis & description rec d? Are well tests required?I/yes g__~Received?~ ~ no Well is in compliance Initial COPIMENTS Page' Date: 04/11/95 RUN DATE_RECVD 04/02/1993 07/14/1993 07/14/1993 03/09/1993 07/14/1993 01/19/1993 05/03/1993 08/30/1993 05/03/1993 01/19/1993 y~~o yes no ARCO Alaska, Inc. Post Office Box i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 6, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices, in the Kuparuk field. The wells are listed below. WELL ACTION '~'i ~; ~ ~,c 1 H- 10 Stimulate ~5-5~- 1H-14 Perforate ~!; - tz¢~ 1H-20 Perforate ~q- !'~ 1Q-04 Stimulate ~_-~z. 1Y-24 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR050696 (w/o atch) RECEIVED MAY ]1 1994 0ii & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing ~ Alter casing Stimulate Plugging Repair well Perforate X Other 2. Name of Operator ARCO Alaska, In.c. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 582' FNL, 1160' FEL, Sec 33, T12N, R10E, UM .. At top of productive interval 1508' FNL, 1751' FWL, Sec 28, T12N, R10E, UM At effective depth 1189' FNL, 1576' FWL, Sec 28, T12N, R10E, UM At total depth 1131' FNL, 1545' FWL, Sec 28, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-20 9. Permit number/approval number 92-129 10. APl number 5O-029-22313 11. Field/Pool Kuparuk River Field/Oil Pool 8990 feet 6928 feet Plugs (measured) None feet Effective depth: measured 8 8 8 7 feet true vertical 6849 feet Junk (measured) None Casing Length Size Structural Conductor I 21 ' 1 6" Surface 530 3' 9.625" Intermediate Production 8 9 3 5' 7" Liner Perforation depth: measured 9619'-9638' true vertical 6579'-6593' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 99527' Packers and SSSV (type and measured depth) PKR: Cemented 225 Sx PF 'C' 1390 Sx PF 'E'& 500 Sx Class (3 270 Sx Class (3 Measureddepth 121' 5345' 8970' , 9691'-9701', 9726'-9760' , 6632'-6639', 6658'-6683' Baker FHL @ 8566 & Baker FB-1 @ 9013; SSSV: Baker FVL @ 1815' True vertical depth 121' 4270' 6913' 13. Stimulation or cement squeeze summary Perforated 'C34' sands on 3/29/94 and 4/09/94. Intervals treated (measured) 9619'-9638', 9691'-9701' Treatment description including volumes used and final pressure N/A. 14. Representative Daily Average Production or Injection Data RECEIVED MAY l l 1994 Alaska (Jii & Gas Cons. C0mmi; Ancr~orage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 3517 440 2296 Subsequent to operation 0 0 3604 300 2288 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Water Injector 17. I hereby/~rtify that the foregoing is true and correct to the best of my knowledge. Signed ~/~~" ~~'~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMITIN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT REMARKS IPBDT t OPERATION AT REPORT TIME 0 /ooo !!:o /./~5 1210 - r -- · - - ~ w' . - = . '-- = ¢~&~ SeT ~IpT~, Fizz l~z~zt P~?/- ¢7oi ~D ' ' - /~ ' / ~ e i r J/ ' ' CYoT 6(~.~ ~ P I p[/F lyPEAYAL ¢6/9 ~ POP' ~D-.RKO. PoH. O~ :~FAc~ , o~r Top .~E~AtH/~6 JHoTS drILL ON JT~IB + HoT FI~zO. gl~p /v~ /eAo~ o~ 7~-ZFI RECEIVED ~,~^v 1 '~ IOQA Alaska U~i & Gas Cons. Commissior, [-'-i CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor I Visibility Report ]~ oF OF I Wind Vel. Signed Anchorade ARCO Alaska, Inc. ~}, Subsidiary of Atlantic Richfield Company WELL 1H-20 DATE 4/9/94 DAY 2 TIME 0945 1140 DESCRIFrION OF WORK PERFORATE C 34 CONTRACTOR / KEY PERSON SCHLUMBERGER/JACK RATHERT PBTD (RKB) ILAST TAG (RKB) . DATE 10190 ] 10037 - 3/26/94 LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# - SCA# ] 997617 - 11223 In~LI> cost~sr. {ACCUMULATED COST { *9,800 I *17,619 [SSSV TYPE / STATUS IOT[S SLN W/OTIS MCX INJ VALVE MIRU SCHLUMBERGER, SAFETY MEETING, PSI TEST TO 3500 7" PSI AT 250, 9 5/8" PSI AT 420 DISPLACE W/15 BBLS DIESEL RIH W/1 11/16" TS, HEAD, 6'WT BAR, CCL, MPD, 18.5' 2 1/8" ENERJET W/6 SPF, 90 DEGREE PHASING, DP, 5' FROM CCL TO TOP SHOT 1300 TIE IN TO CET DATED 1/8/93 AND TUBING TAIL, PULL UP TO 9615.5' W/CCL, SHOOT 9620.5' TO 9639'. POOH 1415 CCH. BOTTOM5 SHOTS DID NOT FIRE. PERFED FROM 9620.5' TO 9638' 1500 RDMO. 7" PSI AT 0, 9 5/8" PSI AT 0 SUMMARY: PERFED FROM 9620.5' TO 9638'. BOTTOM 5 SHOTS DID NOT FIRE RECEIVED mAY 1 1 1994 hias~ Oil & Gas Cans .¢,nrnrn~, ,-. ,,v, I'.~l r.j ;.:j i; I I CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK We~th~" T~mP' ~Chi"r~ct°~' Iv~i~'i~ity IW~"a Wi' ISi~n~a~n, ort miles mph COMPLETE INCOMPLETE rtlo~cie ~to llingsmorth ARCO Alaska, Inc. Date: August 27, 1993 Transmittal #: 8845 RETURN TO: ARCO Alaska, inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following o~pen~ items. receipt and return one signed copy of this transmittal. Please acknowledge 1H-15 -,'CDR Enhancement 2-27-93 LWD/Depth Corrected 1H-17 -"'CDR Very Enhanced 2-26-93 LWD/Depth Corrected "CDR Very Enhanced LWD/Depth Corrected -- CDR Enhancement LWD/Depth Corrected --- CDR Enhancement LWD/Depth Corrected -- CDR Enhancement LWD/Depth Corrected ---CDR Enhancement LWD/Depth Corrected .,-. CDR Enhancement LWD/Depth Corrected --' CDR Enhancement LWD/Depth Corrected 5-02-93 1-21-93 1-12-93 9678-10337 7848-8422 3-26-93 7052-7320 4-05-93 9568-9802 4-12-93 8398-8993 4-14-93 7988-8632 Acknowledged' . 4392-7512 DISTRIBUTION: 5960-9772 D&M Drilling Date' 5296-10002 Catherine Worley(Geology) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 status of well O~L I--~ GAS I----I SUSPENDED r-1 ABANDONED I-q SERWCE Classification of Service Well x, 7 Permit Number ~,~ V 92-129 8 APl Number 50-029-2231 9 Unit or Lease Name KUPARUK RIVER 10 Well Number 1 H-20 11 Field and Pool KUPARUK RIVER 2 Name of Operator ARCO Alaska, Inc 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 552' FNL, 1164 FEL, SEC 33, T 12N, R 10E, UM At Top Producing interval 747' FSL, 998' FEL, SEC 21, T 12N, R 10E, UM At Total Depth 1211' FSL, 955' FEL, SEC 21, T 12N, R 10E, UM 5 Elevation in feet (indicate KB, DF, etc.) RKB 96', PAD 54' 6 Lease Designation and Serial No. ADL 25636 ALK 2569 12 Date Spudded 19-Dec-92 17 Total Depth (MD+TVD) 10300' MD, 7083' TVD 13 Date T.D. Reached 26-Dec-92 18 Plug Back Depth (MD+TVD) 10190' MD, 7000' TVD J14 Date Comp., Susp. or Aband. 6/10/93. (Comp) 19 Directional Survey 15 Water Depth, if offshore 116 No. of Completions NA feet MSLI 1 20 Depth where SSSV set 1786' LNDG NPL FT MD 21 Thickness of permafrost 1800' APPROX 22 Type Electric or Other Logs Run CDR, CDN, USIT, CBT, CET, GCT 23 CASING, LINER AND CEMENTING RECORD CASING SIZE WT 16" 62.5# 9.625 40#/36# HOLE SIZE CEMENT RECORD 24" 200 SX PFC CMT 12.25" 778 SX PF E CMT, 350 SX CLASS G CMT GRADE H-40 L-80/J-55 J-55 SE'I-I'ING DEPTH MD TOP BTM SURF 121' SURF 3974' SURF 10280' 7" 26# 8.5" 592 CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 9726'-9760' @ 12 SPF W/4.5" CSG GUN MD 6658'-6682' TVD 25 TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9.3# J-55 9527' 9497' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested WATER-BBL Flow Tubing Casing Pressure WATER-BBL Press. 28 CORE DATA I PRODUCTION FOR IOIL-BBL GAS-MCF I TEST PERIOD ¢: CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE I~ CHOKE SIZE I GAS-OIL RATIO O L GRAV TY-AP (corr) Brief description of iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RE EEIVED d U L 1 4 199,~ Alaska Oil & Gas Cons. Cornrnissio~ Anchorage 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 OF KU PARUK C 9608' 6571' . BASEOF KUPARUKO, 9745' 6672' TOP OF KUPARL¢--K'& }i 9955' 6825' BASE OF KUPA~0K A "" 10107' 6938' ¥ : 31. LIST OF A-I-FACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY -- 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed Title DATE / INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1H-20 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-22313 92-129 ACCEPT: 12/18/92 10:30 SPUD: 12/19/92 03:30 RELEASE: 06/10/93 08:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 12/19/92 ( 1) PARKER 245 TD: 380' ( 380) 12/20/92 (2) PARKER 245 TD: 3999' (3619) 12/21/92 ( 3) PARKER 245 TD: 3999'( o) DRILL 12-1/4" HOLE 9-5/8"@ 3973' MW: 9.7 VIS:102 MVW RIG F/1H-19 TO 1H-20. RIG ACCEPTED @ 22:30 HRS 12/18/92. RU. NU DIVERTER SYSTEM. FUNCTION TEST SAME. FILL MUD RISER. CHECK FOR LEAKS ON DIVERTER VALVES-NO LEAK. PU 12.25" TC-11H BIT. MU BHA. CLEAN OUT CONDUCTOR TO 121' DRILL 12.25" HOLE F/121'-380'. CIRC TO COND HOLE 9-5/8"@ 3973' MW: 9.8 VIS: 62 DRILL/SURVEY 12.25" HOLE F/380'-2409' GAS CUT MUD WT F/9.6 PPG TO 9.3 PPG. CBU. FOUND LIGNITE IN SHAKERS. DRILL/SURVEY 12.25" HOLE F/2409'-2593'. MONITOR WELL. STILL HAVE LIGNITE IN CUTTINGS. CBU. DRILL/SURVEY 12.25" HOLE F/2593'-2873'. MONITOR WELL. CBU. DRILL/SURVEY 12.25" HOLE F/2873'-3999' CIRC TO COND HOLE. RUN 9-5/8" CSG 9-5/8"@ 3973' MW: 9.9 VIS: 58 FIN CIRC TO COND HOLE. MAKE SHORT TRIP. POH TO 2870' TIGHT HOLE F/3100'-2870' RIH BACK TO 3999'. CBU. CHECK FOR GAS- NO SIGN AMT. POH TO 2537' TIGHT HOLE F/2870'-2537'_ HOLE SWABBING. RIH TO BTM. CIRC TO ,CONDITION MUD/HOLE. POH. HOLE SWAB F/2631'-1660' HOLE TIGHT F/2010'-1660' WORK PIPE THRU TIGHT SPOTS, BACK REAMS AS NECESSARY. LD MWD, NAVIDRILL & BIT. PU BULNOSE & 12-1/4" HOLE OPENER. MU BHA. RIH. BRIDGE OFF @ 1901' WASH F/1900'-2600'. REAM THRU BRIDGES @ 1901', 2026', 2089' 2215' 2431', 2537' CIRC TO COND HOLE. DROP ' [ ' SURVEY. POOH LD BHA. RU 9-5/8" CSG EQUIP. HOLD PREJOB SAFETY MEETING. RUN 9-5/8" CSG. %.. Alaska Oil & Gas Cons. Commission .Anchorage WELL: 1H-20 API: 50-029-22313 PERMIT: 92-129 PAGE: 2 12/22/92 (4) PARKER 245 TD: 3999' ( 0) 12/23/92 ( 5) PARKER 245 TD: 7035' (3036) 12/24/92 ( 6) PARKER 245 TD: 9087' (2052) 12/25/92 (7) PARKER 245 TD: 9500' ( 413) DRILLING FLOAT SHOE 9-5/8"@ 3973' MW:10.5 VIS: 45 12/26/92 ( 8) PARKER 245 TD: 9920' ( 420) CIRC & COND MUD FOR CMT. PMP 5 BBLS WATER, TEST LINES TO 3000 PSI, DROP #1 PLUG, PMP 45 BBLS WATER, DROP #2 PLUG, MIX & PMP 300.7 BBL LEAD CMT, 12.0 PPG, FOLLOWED BY 71.7 BBLS TAIL CMT @ 15.8 PPG. DROP TOP PLUG, DISPLACE WITH 20 BBL WATER & 273 BBL MUD, BUMPED PLUG W/2000 PSI & HELD 1/2 HRS. CIP @ 11:30 HRS. FLOATS HELD. TRACE OF CMT TO SURF. RIG DOWN CMT HEAD, LAY DN LANDING JT, RD CSG EQUIP. ND DIVERTER. RUN 1" TBG TO 80' IN 9-5/8" X 16" ANN, FLUSH ANN W/19 BBLS WATER & CMT W/17 BBLS 15.6 PPG CMT. INSTALL PACKOFF & 11-3/4" X 11" 3M SPEED HEAD & TORQUE TO 37,500 FT/1BS. NU BOPE. TEST ALL TO 3000 PSI-GOOD. RUN WEAR BUSHING, BLOW DOWN ALL LINES. PU BHA, ORIENT MWD, LOAD SOURCE IN LWD TOOLS. TEST MWD @ 1200'. RIH TO 3400' CUT DRILLING LINE 116' CONT TO RIH TO 3889', FILL PIPE & TEST CSG TO 2000 PSI-OK. DRILL CMT F/3889'-3895', DRILL PLUGS & FC, DRILL CMT, DRILLING FS @ 0600 HRS. DRILLING 9-5/8"@ 3973' MW:10.5 VIS: 46 CIRC & COND MUD @ 3,999', 10.5 PPG, 40 VIS. DRILL 10' NEWHOLE F/3999-4009, RAN EMW TEST @ 4009'/3068' TVD W/10.5 PPG MUD. PRESS ON CSG TO 320 PSI, HELD EMW 12.5 PPG, DRLG F/4009'-4550', ADT 2 HRS, MONITOR GAS, SERVICE TOP DRIVE, DRLG F/4550'-7035', MONITOR GAS, ADT 11.75 HRS TRIP F/MWD 9-5/8"@ 3973' MW:10.5 VIS: 47 DRILL 8.5" DIRECTIONAL HOLE F/7035'-9087', MWD NOT WORKING-BAD SURVEYS. REPAIR UPPER IBOP ON TOP DRIVE. CBU-45 UNIT BG GAS. DROP SURVEY, SLUG. POOH. CHANGING BHA 9-5/8"@ 3973' MW:10.5 VIS: 44 FIN POOH. HOLE TIGHT & SWABBING F/4900'-4520'. DOWN LOAD LWD TOOLS. CHANGE OUT MWD-ORIENT. REPROGRAM LWD TOOLS. , , , RIH. TEST TOOLS @ 1200 MWD SURVEYS @ 4231 , 6658 , 7312', 8333', & 9084'. HOLE IN GOOD SHAPE-NO FILL. DRLG 8.5" DIRECTIONAL HOLE F/9087'-9500' DROP SURVEY-PMP SLUG. POH W/BIT #3RR FOR BHA CHANGE. REMOVE SOURCE-LD MWD-DOWN LOAD LWD TOOLS. DRILLING 9-5/8"@ 3973' MW:10.5 VIS: 42 FIN LD MWD & TURBINE. PU NEW BHA. PROGRAM LWD TOOLS. TIH TO 9-5/8" SHOE. CUT DRLG LINE. SET CROWN-0-MATIC. TIH. BREAK CIRC @ 3910', 6300', 6800', & 9390' HOLE IN GOOD SHAPE. RELOG W/ANADRILL F/9390'-9500' NO FILL. ROTARY DRLG 8.5" HOLE F/9500'-9920'. J Iii I 4 ,'~laska 0il & Gas Cons. Cornmissim~' ;Anchorag WELL: 1H-20 API: 50-029-22313 PERMIT: 92-129 PAGE: 3 12/27/92 ( 9) PARKER 245 .TD:10300' ( 380) 12/28/92 (10) PARKER 245 TD:10300' ( o) 12/29/92 (11) PARKER 245 TD:10300' ( o) 06/09/93 (13) TD:10300 PB:10190 RUNNING CSG INSPECTION 9-5/8"@ 3973' MW:10.5 VIS: 42 ROTARY DRLG 8.5" HOLE F/9920'-10300' CBU @ 10300'. MADE 10 STD SHORT TRIP TO 9546'. CBU & COND MUD @ 10300' DROP SURV & PMP SLUG. POH FOR CSG INSPECTION LOG-SLM-NO CORRECTION. HOLE IN GOOD SHAPE. DOWN LOAD & LD LWD TOOLS. RU SWL. RUN USTI CSG INSPECTION LOG. RUNNING 7" CSG 7"@10280' MW:10.5 VIS: 41 FIN RUNNING CSG INSPECTION F/3928'-200'. MAX METAL LOSS F/600'-280'. FROM 340'-300' HAVE ABOUT 30% LOSS. SERV RIG & TOP DRIVE. PU BHA. TIH. BREAK CIRC @ 7500' & 9500' REAM F/10277'-10300' CIRC & COND FOR 7" CSG. SLUG DP. POH. LD 71 JTS DP & BHA. PULLED WEAR BUSHING. RU CASERS. HOLD SAFETY MEETING. RUN 7" CSG -140 JTS IN HOLE-NO MUD LOSS. RIG RELEASED 7"@10280' MW:10.5 VIS: 0 FIN RUNNING 7" CSG. RU HOWCO CMT HEAD. CIRC & COND HOLE FOR CMT JOB. RECIPROCATE CSG-UP 360,000, DN 150,000. TEST LINES TO 4500 PSI. HOWCO CMT 7" CSG. UNABLE TO RECIPROCATE-CSG STUCK WHILE DROPPING BMT PLUG & LOADING TOP PLUG. DISPLACED W/384 BBLS 10.5 BRINE. FULL RETURNS THROUGHOUT JOB. BMP PLUG W/3500 PSI. HELD 30 MIN-OK. FLOATS HELD. SHUT HYDRIL. PMP 125 BBLS 10.5 PPG MUD DOWN 9-5/8" X 7" ANN. MONITOR ANN. HAD 17 BBL/HR FLOW-DECREASED TO 5 BBL/HR. ND & PU BOP. SET 175,000 ON 7" SLIPS. CUT OFF 7" LD LANDING JT. SET STACK BACK. MADE FINAL CUT. BLEW BRINE OUT OF 7" TO 40' NU TREE. TEST TBG HEAD TO 3000 PSI-OK. FREEZE PROTECT 9-5/8" X 7" ANN W/100 BBLS WATER & 70 BBLS DIESEL-2.5/3 BPM @ 900-1200 PSI. RELEASED RIG F/1H-20 @ 06:00 12/29/92. MOVING TO 1H-17. PERF W/RUN #1 7"@10280' MW:10.5 NaC1/Br MOVE RIG F/1H-02 TO 1H-20. ACCEPT RIG @ 0230 HRS, 06/09/93. ND TREE, SET TEST PLUG. NU BOP. TEST BLIND RAMS & FLANGES TO 250 & 3000 PSI. BEGIN LOADING, STRAPPING & DRIFTING TBG. RU SWS, TEST LUB TO 1000 PSI. PU PERF GUNS & RIH. Oil & Gas Cons, Commission'" Rnchora~qe WELL: 1H-20 API: 50-029-22313 PERMIT: 92-129 PAGE: 4 06/10/93 (14) TD:10300 PB:10190 06/11/93 (15) TD:10300 PB:10190 ND BOP 7"@10280' MW:10.5 NaCl/Br PERF F/9740'-9760' W/4-1/2" CSG GUNS @ 12 SPF, 34B DP, 60 DEG PHASING. POH. PU GUN #2 & RIH. PERF F/9736'-9740' & 9726'-9736' W/4-1/2" CSG GUNS @ 12 SPF, 34B DP, 60 DEG PHASING. POH. RD SWS. CORRELATE TO CET LOG DATED 01/08/93. RU FLOW RISER. RU TO RUN 3-1/2 TBG. MU BAKER HB PKR & TAILPIPE ASSY. RIH ON 3-1/2", 9.3#, J-55, ABM-EUE, IPC TBG. MU FMC HGR & LAND TBG. RILDS. PRESS TBG TO 2500 PSI, PRESS ANN TO 1000 PSI TO BE SURE PKR IS ENERGIZED. BRING PRESS UP TO 2500 PSI. SHEAR OUT SHEARED EARLY (2400 PSI)-DID NOT GET A GOOD TEST. CALL FOR OTIS SLICKLINE UNIT & WAIT ON SAME. RU OTIS UNIT. RIH & SET STANDING VALVE IN CAMCO D NIPPLE @ 9482'. POH. PRESS TBG TO 3000 PSI & ANN TO 2500 PSI. TBG HGR UNSET. BLED OFF PRESS. PULL HGR TO FLOOR. PACKING RUBBER GONE & METAL PACKING BLOWN. LD HGR & REDRESS. PULL ONE STAND OF TBG TO CHECK UP & DOWN WEIGHTS. RERUN REDRESSED HGR & LAND TBG. RILDS. TEST TBG TO 3000 PSI & AN TO 2500 PSI, OK. RIH W/SLICKLINE & PULL STANDING VALVE. RD OTIS UNIT. SET BPV. ND BOP. ND BOP 7"@10280' MW:10.5 NaC1/Br NU LOWER & UPPER X-MAS TREE, TESTED PACKOFF TO 5000 PSI, TESTED TREE TO 250 PSI & 5000 PSI, PULLED TEST PLUG. RU PUMP LINES, PUMPED 12 BBLS DIESEL DOWN ANN & 4 BBLS OF DIESEL DOWN TBG @ 1 BPM @ 1500 PSI. SECURED WELL, NO BPV SET. PREPARING TO MOVE TO 1H-22. SIGNRTURE: : (~ s'uperint~dent ) DATE: 'U 1 4 !9 3 ~,1 ~ . , Oil & Gas Cons. I;;ornmissioi' Anchorage SUB- SURFACE DIRECTIONAL SURVEY UIDANCE ONTINUOUS J-~ OOL Company Well Name Field/Location ARCO ALASKA, INC. 1H-20 1582' FNL, 1164' FEL, SEC 33, T12N, RIOE, UN! KUPARUK) NORTH SLOPE~ ALASKA Job Reference No. 93012 Loclcjed BV: NARNER Date 8-dAN-g3 SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. IH - 20 KUPARUK RIVF__~ NORTH SLOPE, ALASKA sUrVEY DATE: 08-JAN-1993 ENGINEER: D. WARNER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 3 DEG I4 MZN EAST COMPUTATION DATE' 30-JAN-g3 PAGE I ARCO ALASKA, INC. 1H - 20 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 08-JAN-1993 KELLY BUSHZNG ELEVATION' 96.00 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 200 3O0 400 500 600 700 800.00 794 900.00 890 0 O0 -96.00 0 0 N 0 0 E O0 100 O0 200 O0 300 O0 399 O0 499 O0 598 O0 696 O0 4.00 0 20 S 42 11 W O0 104.00 0 5 S 12 8 W O0 204.00 0 31 N 5 15 E 90 303:90 3 52 N 13 32 E 50 403.50 6 15 N 15 36 E 57 502.57 9 27 N 12 48 E 79 600.79 12 4 N 10 59 E 11 698.11 14 37 N 11 26 E 19 794.19 17 52 N 7 43 E 0 O0 -0 08 -0 35 -0 36 3 74 12 34 25 59 44 12 66 86 94 36 0 O0 0 O0 0 37 2 35 3 23 2 36 2 92 2 39 2 65 4 O5 0.00 N 0 07 S 0 33 S 0 33 S 3 73 N 12 21 N 25 28 N 43 64 N 66 93 0 O0 E 0 0 0 0 2 6 9 16 N 14 43 N 19 0.00 N 0 0 E 07 W 0.10 S 44 10 W 41 W 0.53 S 51 47 W 48 W 0.58 S 55 21 W 33 E 3.74 N 5 2 E 59 E 12.49 N 11 59 E 06 E 26.00 N 13 28 E 78 E 44.72 N 12 38 E 28 E 67.68 N 12 11 E 06 E 95.35 N 11 32 E 1000 O0 984 22 888 22 21 28 N 3 44 E 128 29 1100 1200 1300 1400 1500 1600 1700 1800 1900 O0 1076 O0 1167 O0 1257 O0 1345 O0 1431 O0 1515 O0 1599 O0 1680 O0 1758 49 980 61 1071 30 1161 36 1249 60 1335 83 1419 10 1503 57 1584 32 1662 49 23 35 N 3 47 E 166 61 25 10 N 4 53 E 208 30 27 21 N 5 31 E 252 36 29 16 N 6 7 E 299 60 31 37 N 6 16 E 350 83 33 14 N 6 6 E 403 10 34 19 N 5 48 E 459 57 36 58 N 5 8 E 517 32 40 49 N 4 48 E 579 82 O1 19 52 05 88 19 12 95 2 49 1 71 2 25 2 72 2 58 2 77 0 6O 2 12 4 35 2 79 127 24 N 22.18 E 129 16 N 9 53 E 165 206 250 297 348 401 456 514 577 70 N 24..56 E 167 78 N 27.72 E 208 80 N 31 73 E 252 93 N 36 49 E 300 24 N 41 96 E 35O 82 N 47 74 E 404 89 N 53 60 E 460 6O N 59 11E 517 23 N 64 43 E 580 51 N 8 26 E 62 N 7 38 E 80 N 7 13 E 16 N 6 59 E 76 N 6 52 E 65 N 6 47 E 03 N '6 41E 98 N 6 33 E 81 N 6 22 E 2000.00 1832.34 1736 34 43 50 N 5 4 E 647 13 2100.00 1902 34 1806 2200'.00 1967 2300 O0 2031 2400 O0 2095 2500 O0 2156 2600 O0 2215 2700 O0 2273 2800 O0 2332 2900 O0 2390 71 1871 13 1935 11 1999 51 2060 85 2119 88 2177 18 2236 62 2294 34 47 33 N 4 58 E 718 71 50 26 N 4 29 E 794 13 50 30 N 3 46 E 871 11 50 25 N 4 20 E 948 51 53 21 N 5 8 E 1027 85 54 6 N 4 54 E 1107 88 54 32 N 4 3 E 1189 18 54 15 N 4 18 E 1270 62 54 4 N 3 24 E 1351 48 11 42 27 15 59 O1 25 39 2 60 3 48 715 1 49 790 1 16 867 2 34 944 0.47 1023 2.05 1103 0.91 1184 0.26 1265 1.90 1346 644 19 N 70 30 E 648 O1 N 6 14 E 30 N 76 69 N 82 82 N 88 49 N 93 12 N 100 28 N 107 48 N 113 52 N 119 45 N 125 50 E 719 81E 795 23 E 872 62 E 949 21E 1028 45 E 1108 62 E 1189 49 E 1271 32 E 1352 38 N 6 6 E O1 N 5 59 E 29 N 5 48 E 12 N 5 40 E 02 N 5 36 E 50 N 5 34 E 92 N 5 29 E 15 N 5 24 E 27 N 5 19 E 3000 O0 2449 62 2353 62 53 38 N 2 41 E 1432 12 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2509 O0 2572 O0 2634 O0 2697 O0 2759 O0 2821 O0 2882 O0 2942 O0 3002 99 2413 26 2476 86 2538 40 2601 25 2663 26 2725 99 2786 95 2846 96 2906 99 51 45 N 2 24 E 1511 26 51 20 N 2 30 E 1590 86 51 12 N 2 50 E 1668 40 51 30 N 2 51 E 1746 25 51 51 N 2 33 E 1824 26 51 32 N 2 26 E 1903 99 52 34 N 2 42 E 1981 95 53 23 N 3 12 E 2061 96 52 47 N 3 3 E 2141 83 07 04 08 65 O9 76 79 78 0 58 1427 09 N 129 43 E 1432 95 N 5 11 E 55 1506 38 1584 47 1662 84 1740 45 1819 16 1897 30 1976 34 2056 66 2135 72 N 132 90 N 136 80 N 139 74 N 143 23 N 147 60 N 150 20 N 154 11N 158 99 N 162 93 E 1512 23 E 1590 82 E 1668 78 E 1746 50 E 1825 85 E 1903 33 E 1982 59 E 2062 91 E 2142 58 N 5 3 E 75 N 4 55 E 67 N 4 48 E 66 N 4 43 E 20 N 4 38 E 59 N 4 33 E 22 N 4 28 E 22 N 4 25 E 19 N 4 22 E COMPUTATION DATE- 30-JAN-93 PAGE 2 ARCO ALASKA, INC. iH - 20 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 08-JAN-lg93 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3063 92 '2967.92 51 52 N 2 55 E 2221 05 4100 4200 4300 ' 4400 4500 4600 4700 4800 4900 O0 3127 O0 3192 O0 3258 O0 3323 O0 3388 O0 3451 O0 3514 O0 3576 O0 3639 O0 3031.00 49 35 N 2 15 E 2298 87 3096.87 48 29 N 2 31E 2373 56 3162.56 49 28 N 3 25 E 2449 08 3227..08 49 47 N 3 45 E 2525 08 3292.08 49 29 N 3 20 E 2601 46 3355.46 51 22 N 3 50 E 2678 24 3418.24 51 6 N 2 57 E 2756 60 3480.60 51 29 N 3 9 E 2834 33 3543.33 51 0 N 2 19 E 2912 1 63 2215 14 N 167 09 E 2221 44 N 4 19 E 63 2 86 0 25 65 64 98 1 82 0 99 1 86 35 2292 43 2367 04 2443 18 2519 34 2595 12 2672 38 2750 58 2828 24 2905 64 N 170 82 N 173 12 N 177 35 N 182 21N 187 39 N 192 10 N 196 16 N 200 94 N 204 75 E 2298 86 E 2374 68 E 2449 62 E 2525 27 E 2601 23 E 2679 70 E 2757 89 E 2835 62 E 2913 99 N 4 16 E 19 N 4 12 E 57 N 4 10 E 96 N 4 9 E 96 N 4 8 E 29 N 4 7 E 12 N 4 5 E 28 N 4 4 E 14 N 4 2 E 5000 O0 3701 54 3605.54 52 6 N 2 5 E 2991 15 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3763 O0 3825 O0 3886 O0 3947 O0 4007 O0 4068 O0 4129 O0 4190 O0 4251 36 3667.36 51 33 N I 29 E 3069 20 3729.20 51 54 N 1 48 E 3148 95 3790.95 52 4 N 1 47 E 3226 55 3851.55 53 1 N 2 22 E 3306 93 3911.93 52 45 N 1 40 E 3386 62 3972.62 52 38 N 1 4 E 3465 48 4033.48 52 26 N 0 32 E 3544 51 4094.51 52 25 N 0 7 E 3623 30 4155.30 52 51 N 1 3 E 3703 71 28 9O 43 13 56 84 95 25 0 98 2984 18 N 207 70 E 2991 40 N 3 59 E 12 3062 41 3141 69 3219 67 3299 81 3379 62 3458 41 3537 21 3617 62 3696 74 N 209 29 N 212 92 N 214 40 N 217 06 N 220 51N 222 85 N 223 07, N 224 46 N 224 96 E 3069 37 E 3148 63 E 3227 77 E 3306 56 E 3386 49 E 3465 60 E 3544 OI E 3624 59 E 3703 93 N 3 55 E 46 N 3 52 E 06 N 3 49 E 58 N 3 47 E 26 N 3 44 E 66 N 3 41 E 91 N '3 37 E O0 N 3 33 E 28 N 3 29 E 6000 O0 4311 60 4215 60 52 53 N 0 52 E 3782 97 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4371 O0 4432 O0 4493 O0 4553 O0 4612 O0 4671 O0 4729 O0 4790 O0 4850 87 4275 51 4336 26 4397 55 4457 57 4516 02 4575 78 4633 33 4694 73 4754 87 52 57 N 0 44 E 3862 51 52 29 N 3 8 E 3942 26 52 42 N 3 3 E 4021 55 53 20 N 1 49 E 4101 57 54 7 N 0 27 W 4181 02 54 23 N 0 58 W 4262 78 53 2 N 0 50 W 4343 33 52 47 N 0 51W 4423 73 52 52 N 1 22 W 4502 69 17 60 38 99 94 63 03 49 0 60 3776 23 N 226 03 E 3782 99 N 3 26 E 38 3856 52 3935 33 4014 35 4094 49 4175 53 4256 44 4337 52 4416 33 4496 O1N 227 49 N 229 80 N 233 49 N 237 20 N 238 34 N 237 23 N 235 82 N 234 50 N 233 11E 3862 63 E 3942 97 E 4021 72 E 4101 24 E 4181 24 E 4262 74 E 4343 77 E 4423 22 E 4502 7O N 3 22 E 18 N 3 20 E 61 N 3 20 E 39 N 3 19 E 99 N 3 16 E 95 N 3 11 E 64 N 3 7 E 05 N 3 3 e 54 N 2 58 E 7000 O0 4911 28 4815 28 52 35 N 0 27 W 4581 85 7100 O0 4971 7200 O0 5032 7300 O0 5092 74OO O0 5152 7500 O0 5212 76OO O0 5271 7700.00 5332 7800.00 5392 7900.00 5453 97 4875 53 4936 77 4996 78 5056 40 5116 71 5175 04 5236 76 5296 39 5357 97 52 42 N 0 40 W 4661 53 52 50 N 1 6 W 4740 77 53 1 N 1 25 W 4820 78 53 6 N 1 39 W 4899 40 53 39 N 1 55 W 4979 71 53 31 N 2 32 W 5059 04 52 29 N 2 21 W 5139 76 52 39 N 2 43 W 5218 39 52 42 N 2 34 W 5297 15 52 10 82 79 93 29 35 43 0 45 4576 07 N 231 71 E 4581 93 N 2 54 E 34 4655 33 4735 30 4814 31 4894 56 4975 12 5055 35 5135 37 5214 42 5294 54 N 231 11N 229 91N 228 87 N 225 12 N 223 57 N 22O 24 N 216 63 N 213 O5 N 2O9 O0 E 4661 76 E 474O O2 E 482O 91 E 4900 41E 4980 23 E 5060 88 E 5139 40 E 5218 54 E 5298 27 N 2 50 E 68 N 2 47 E 30 N 2 43 E 08 N 2 39 E 13 N 2 34 E 36 N 2 30 E 82 N 2 25 E 99 N 2 21 E 20 N 2 16 E COMPL/TATION DATE: 30-JAN-93 PAGE 3 ARCO ALASKA, INC. 1H - 20 KUPARUK RIVEE NORTH SLOPE, ALASKA DATE OF SURVEY: 08-JAN-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: D. WARNER IN]-ERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 5514 30 '5418.30 52 20 N 2 28 W 5376 37 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 5575 O0 5636 O0 5698 O0 5759 O0 5821 O0 5883 O0 5946 O0 6009 O0 6072 51 5479.51 52 17 N 3 3 W 5455 73 5540.73 52 7 N 1 27 W 5533 18 5602 18 52 3 N 0 44 W 5612 80 5663 80 51 57 N 0 58 W 5690 40 5725 40 51 52 N 1 15 W 5769 63 5787 63 51 21 N 3 2 W 5847 12 5850 12 51 14 N 3 33 W 5924 17 5913 17 50 28 N 4 4 W 6002 98 5976 98 50 13 N 4 23 W 6078 O1 66 37 91 48 40 96 O0 35 0 48 5373 30 N 206 35 E 5377 26 N 2 12 E 0 49 5452 3 52 5531 0 54 5610 0 56 5688 0 64 5767 0.45 5845 0.36 5923 0.55 6001 1.19 6078 28 N 202 27 N 198 15 N 197 90 N 196 66 N 195 88 N 192 82 N 187 27 N 182 06 N 177 51E 5456 86 E 5534 86 E 5613 59 E 5692 23 E 5770 28 E 5849 82 E 5926 70 E 6004 09 E 6080 04 N 2 8 E 84 N 2 4 E 64 N 2 1E 29 N 1 59 E 96 N 1 56 E 04 N 1 53 E 79 N 1 49 E 05 N I 45 E 64 N I 40 E 9000 O0 6137 68 6041.68 49 15 N 4 25 W 6153 91 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 6203 O0 6273 O0 6344 O0 6416 O0 6490 O0 6564 O0 6638 O0 6711 O0 6784 90 6107.90 47 46 N 5 11W 6228 18 6177.18 44 45 N 2 5 W 6299 49 6248.49 44 19 N 0 58 W 6369 91 6320.91 42 56 N 2 14 E 6438 65 6394.65 42 8 N 2 27 E 6505 86 6468.86 42 3 N 3 57 E 6572 73 6542.73 42 51 N 4 11 E 6640 82 6615.82 43 5 N 4 10 E 6708 93 6688.93 42 55 N 4 12 E 6776 10 58 44 33 87 90 28 52 74 0 76 6154 08 N 171 18 E 6156 46 N 1 36 E 33 6228 66 6300 14 6370 22 6439 27 6507 31 6574 O1 6641 11 6709 28 6777 74 N 164 63 N 159 71N 157 64 N 158 13 N 161 07 N 165 28 N 170 35 N 175 39 N 180 86 E 6230 69 E 6302 79 E 6372 97 E 6441 70 E 6509 23 E 6576 20 E 6643 17 E 6711 17 E 6779 92 N 1 31 E 65 N 1 27 E 66 N 1 25 E 61 N 1 25 E 14 N 1 25 E 14 N 1 26 E 46 N '1 28 E 63 N 1 30 E 78 N 1 31 E 10000.00 6858.53 6762.53 42 13 N 5 20 E 6844.41 10100.00 6933.02 6837.02 41 29 N 6 28 E 6911.06 10200.00 7007.94 6911.94 41 27 N 7 3 E 6977.15 10300.00 7082.86 6986.86 41 27 N 7 3 E 7043.24 1.22 6844.86 N 185.72 E 6847.38 N 1 33 E 2.41 6911.23 N 192.51 E 6913.91 N 1 36 E 0.00 6976.97 N 200.48 E 6979.85 N 1 39 E 0.00 7042.70 N 208.61 E 7045.79 N 1 42 E ARCO ALASKA, INC. IH - 20 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 30-JAN-g3 PAGE 4 DATE OF SURVEY: 08-JAN-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1000, FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DE~/IATION AZIMUTH SECTION SEVERII'Y NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEP'rH DEPTH DEPTH DEG ~IN DEG ~IN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 O. O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 O0 984.22 888.22 '21 28 N 3 44 E 128 O0 1832.34 1736.34 43 50 N 5 4 E 647 O0 2449.62 2353.62 53 38 N 2 41 E 1432 O0 3063 92 2967~92 51 52 N 2 55 E 2221 O0 3701 54 3605.54 52 6 N 2 5 E 2991 O0 4311 60 4215.60 52 53 N 0 52 E 3782 O0 4911 28 4815.28 52 35 N 0 27 W 4581 O0 5514 30 5418.30 52 20 N 2 28 W 5376 O0 6137 68 6041.68 49 15 N 4 25 W 6153 0.00 -96,00 0 0 N 0 0 E 0 O0 29 13 12 O5 15 97 85 37 91 2.49 127 2.60 644 O.58 1427 1.63 2215 0.98 2984 0.60 3776 0.45 4576 0.48 5373 0.76 6154 24 N 22.18 E 129 19 N 70.30 E 648 09 N 129.43 E 1432 14 N 167 09 E 2221 18 N 207 70 E 2991 23 N 226 03 E 3782 07 N 231 71 E 4581 30 N 206 35 E 5377 08 N 171 18 E 6156 0 O0 N 0.00 E 0 O0 N 0 0 E 16 N 9 53 E O1 N 6 14 E 95 N 5 11E 44 N 4 19 E 40 N 3 59 E 99 N 3 26 E 93 N 2 54 E 26 N 2 12 E 46 N 1 36 E 10000.00 6858.53 6762.53 42 13 N 5 20 E 6844.41 10300.00 7082.86 6986.86 41 27 N 7 3 E 7043.24 1.22 6844.86 N 185.72 E 6847.38 N 1 33 E 0.00 7042.70 N 208.61 E 7045.79 N 1 42 E COMPUTATION DATE' 30-JAN-g3' PAGE ARCO ALASKA, INC. 1H - 20 KUPARUK RIVB NORTH SLOPE, ALASKA DATE OF SURVEY' 08-JAN-1993 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' D. WARNER INTF_I:~POLATF_.D VALU~ FOR EVEN 100 FEET OF SUB-SF_A. DEPTH 3'RUE SUB.SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 96 196 296 396 496 597 699 801 906 O0 96 O0 196 O0 296 09 396 47 496 39 596 19 696 95 796 12 896 0 O0 -96.00 0 0 N 0 0 E O0 0.00 0 17 S 37 38 W O0 100.00 0 5 S 24 49 W O0 200.00 0 26 N 3 7 E O0 300;00 3 45 N 13 31 E O0 400.00 6 10 N 15 32 E O0 500.00 9 22 N 12 56 E O0 600.00 12 3 N 10 58 E O0 700.00 14 40 N 1i'25 E O0 800.00 18 7 N 7 23 E 0 O0 -0 06 -0 34 -0 39 3 49 11 97 25 17 43 96 67 35 96 25 0 . O0 I 82 0 42 i 95 3 26 2 71 3 03 2 32 2 43 4 50 0 O0 N 0 06 S 0 32 S 0 37 S 3 48 N 11 85 N 24 87 N 43.48 N 66.64 N 14 95.32 N 19 0 O0 E 0 O6 W 0 0 41W 0 0 48 W 0 0 27 E 3 2 49 E 12 5 96 E 25 9 75 E 44 38 E 68 30 E 97 0 O0 N 0 0 E 08 S 45 23 W 52 S 52 6 W 61 S 52 50 W 49 N 4 24 E 10 N 11 52 E 57 N 13 29 E 56 N 12 38 E 18 N 12 10 E 25 N 11 27 E .1012.67 996 O0 900.00 21 49 N 3 37 E''~,, 132 97 1121 31 1096 1231 1343 1458 1576 1696 1819 1950 2090 46 1196 74 1296 44 1396 32 1496 25 1596 43 1696 30 1796 59 1896 O0 1000.00 23 54 N 4 5 E 175 O0 1100.00 25 52 N 5 4 E 221 O0 1200.00 28 8 N 5 41 E 272 O0 1300 O0 30 36 N 6 12 E 328 O0 1400 O0 33 3 N 6 6 E 390 O0 1500 O0 34 15 N 5 51E 457 O0 1600 O0 37 43 N 4 57 E 528 O0 1700 O0 42 11 N 5 4 E 613 O0 1800 O0 47 13 N 4 58 E 711 40 55 57 65 95 09 91 24 53 3 04 1 43 2 18 1 43 2 12 0 89 2 16 3 61 3 42 3 65 131 91N 22 48 E 133 81 N 9 40 E 174 220 271 326 388 454 526 610 7O8 25 N 25 27 N 28 09 N 33 93 N 39 95 N 46 80 N 53 36 N 60 42 N 67 38 N 75 15 E 176 89 E 222 72 E 273 63 E 329 37 E 391 38 E 457 14 E 529 29 E 614 9O E 712 06 N 8 13 E 16 N 7 28 E 18 N 7 5 E 32 N 6 55 E 71 N 6 48 E 92 N 6 42 E 78 N '6 31 E 11 N 6 17 E 43 N 6 7 E 2244 57 1996 O0 1900 O0 50 45 N 4 0 E 828 54 2401 2566 2738 2909 3077 3237 3397 3559 3721 40 2096 34 2196 02 2296 16 2396 30 2496 95 2596 75 2696 35 2796 51 2896 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 50 27 N 4 21E 949 O0 53 38 N 5 12 E 1080 O0 54 21 N 4 5 E 1219 O0 54 1 N 3 13 E 1358 O0 52 13 N 2 25 E 1493 O0 51 15 N 2 36 E 1619 O0 51 29 N 2 52 E 1744 O0 51 37 N 2 24 E 1871 O0 52 58 N 2 52 E 1998 35 42 93 81 95 68 32 25 88 0.87 2.47 945.56 N 93 1.01 1076.20 N 105 0.11 1215.33 N 115 I 67 1353.86 N 125 2 99 1488.86 N 132 0 24 1614.49 N 137 0 84 1738.98 N 143 0 56 1865.79 N 149 I 89 1993.30 N 155 825.04 N 85 36 E 829 44 N 5 54 E 71E 950 05 E 1081 82 E 1220 76 E 1359 18 E 1494 54 E 1620 69 E 1744 50 E 1871 17 E 1999 20 N 5 40 E 32 N 5 35 E 84 N 5 27 E 69 N 5 18 E 72 N 5 4 E 34 N 4 52 E 90 N 4 43 E 77 N 4 35 E 33 N 4 27 E 3888.48 2996.00 2900 O0 52 52 N 3 4 E 2132 60 4051.52 3096.00 3000 4204.73 3196.00 3100 4357.95 3296.00 3200 4512.27 3396.00 3300 4670.98 3496.00 3400 4831.05 3596.00 3500 4991.01 3696.00 3600 5152.69 3796.00 3700 5314.78 3896.00 3800 O0 51 I N 2 49 E 2261 O0 48 30 N 2 32 E 2377 O0 50 0 N 3 51E 2493 O0 49 46 N 3 24 E 2611 O0 51 0 N 3 3 E 2734 O0 51.10 N 2 54 E 2859 O0 52 2 N 2 10 E 2984 O0 51 52 N 1 52 E 3111 O0 52 17 N 1 58 E 3238 37 40 48 O2 25 23 O6 06 59 0 81 2126 82 N 162 42 E 213~3 O1 N 4 22 E 54 2255 55 2371 51 2487 19 2604 57 2727 88 2852 14 2977 61 3104 97 3231 41N 169 36 N 174 26 N 180 57 N 187 56 N 195 36 N 202 10 N 207 08 N 211 60 N 215 13 E 2261 02 E 2377 49 E 2493 83 E 2611 52 E 2734 17 E 2859 43 E 2984 17 E 3111 03 E 3238 74 N 4 17 E 74 N 4 12 E 80 N 4 9 E 33 N 4 7 E 56 N 4 6 E 52 N 4 3 E 31 N 3 59 E 26 N 3 54 E 74 N 3 48 E COMPUTATION DATE: 30-JAN-93 PAGE 6 ARCO A~SKA, INC. iH - 20 KUPARUK RIVER NORTH SLOPE, A~SKA DATE OF SURVEY: 08-JAN-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1OO FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 5480 29 3996 O0 3900,00 52 47 N I 48 E 3370 44 5645 5809 5974 6139 6304 6471 6642 6809 6974 05 4096 O0 4196 14 4296 95 4396 51 4496 75 4596 89 4696 38 4796 83 4896 O0 4000.00 '52 31 N 0 50 E 3501 O0 4100.00 52 25 N 0 6 E 3631 O0 4200.00 52 54 N 0 58 E 3762 O0 4300:00 52 43 N I 26 E 3894 O0 4400.00 52 43 N 3 3 E 4025 O0 4500.00 54 2 N 0 14 W 4159 O0 4600.00 54 19 N I 10 W 4297 O0 4700.00 52 48 N 0 54 W 4430 O0 4800.00 52 40 N 0 49 W 4561 0 60 3363 38 N 220 08 E 3370.57 N 3 45 E 31 0 O8 0 36 0 51 2 19 0 16 1 71 1 48 0 90 1 51 3494 20 3624 58 3755 80 3887 35 4018 O1 4152 06 4291 55 4424 97 4556 29 n 223 21N 224 61N 225 86 N 227 38 N 234 33 N 238 20 N 236 29 N 234 07 N 231 08 E 3501.40 N 3 39 E 02 E 3631.12 N 3 32 E 69 E 3762.39 N 3 26 E 68 E 3894.52 N 3 21 E 17 E 4025.20 N 3 20 E 37 E 4159.16 N 3 17 E 60 E 4297.72 N 3 9 E 66 E 4430.50 N 3 2 E 92 E 4561.97 N 2 55 E 7139 65 4996 O0 4900 O0 52 42 N 0 52 W 4692 61 7305 7472 7640 7805 7970 8133 8296 8458 8619 37 5096 37 5196 62 5296 34 5396 03 5496 50 5596 46 5696 80 5796 81 5896 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 53 1 N 1 26 W 4824 O0 53 34 N 1 50 W 4957 O0 52 56 N 2 25 W 5092 O0 52 39 N 2 44 W 5222 O0 52 24 N 2 17 W 5352 O0 52 19 N 3 5 W 5481 O0 52 4 N 0 43 W 5609 O0 52 0 N 0 59 W 5737 O0 51 21 N 3 8 W 5862 37 64 32 58 74 36 58 13 78 0 48 4687 07 N 230 59 E 4692 74 N 2 49 E 32 4819 45 4952 59 5088 35 5218 53 5349 62 5478 54 5607 51 5735 23 5861 19 N 227 89 N 224 09 N 218 87 N 213 58 N 207 75 N 201 36 N 197 23 N 195 33 N 191 91E 4824 13 E 4957 81E 5092 20 E 5223 33 E 5353 09 E 5482 89 E 5610 84 E 5738 46 E 5864 58 N 2 42 E 96 N 2 35 E 79 N 2 28 E 22 N 2 2O E 59 N 2 13 E 44 N 2 6 E 85 N '2 1E 57 N I 57 E 45 N I 52 E 8779.29 5996 O0 5900.00 50 35 N 3 55 W 5986 15 8935.81 6096 9088'.22 6196 9232.06 6296 9371 36 6396 9507 21 6496 9642 O0 6596 9778 33 6696 9915 10 6796 lO050 45 6896 O0 6000.00 49 47 N 4 32 W 6105 O0 6100.00 48 1 N 5 7 W 6219 O0 6200 O0 44 33 N 1 35 W 6322 O0 6300 O0 43 17 N 1 55 E 6418 O0 6400 O0 42 8 N 2 27 E 6510 O0 6500 O0 42 15 N 4 19 E 6601 O0 6600 O0 43 6 N 4 11 E 6693 O0 6700 O0 42 51 N 4 18 E 6787 O0 6800 O0 41 50 N 5 52 e 6878 53 46 02 77 71 07 72 O1 16 1 21 5985 33 N 183 82 E 5988.15 N 1 46 E 38 6105 57 6220 76 6323 22 6420 24 6511 89 6602 11 6694 73 6787 14 6878 40 N 174 04 N 165 15 N 158 08 N 158 97 N 161 17 N 167 58 N 174 63 N 180 47 N 189 96 E 6107.91 N 1 38 E 64 E 6222.24 N 1 32 E 99 E 6325.14 N 1 26 E 26 E 6422.03 N 1 25 E 91 E 6513.98 N 1 25 E 28 E 6604.29 N 1 27 E 09 E 6696.85 N 1 29 E 94 E 6790.04 N 1 32 E 03 E 6881.07 N 1 34 E 10184.07 6996.00 6900.00 41 27 N 7 3 E 6966.62 10300.00 7082.86 6986.86 41 27 N 7 3 E 7043.24 0.00 6966.50 N 199.19 E 6969.35 N 1 38 E 0.00 7042.70 N 208.61 E 7045.79 N 1 42 E COMPUTATION DATE: 30-JAN-g3 PAGE 7 ARCO ALASKA, INC. 1H - 20 KUPARUK RIVE~ NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a GCT LAST READING PBTD DATE OF SURVEY: 08-JAN-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 552' FNL & 1164' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 96O8 O0 9745 O0 9955 O0 10107 O0 10119 60 10190 O0 10300 O0 6570.80 6671.66 6825.30 6938.26 6947.70 7000.44 7082.86 6474 80 6575 66 6729 30 6842 26 6851 70 6904 44 6986 86 6579 42 N 6671 87 N 6814 63 N 6915 84 N 6924 12 N 6970 40 N 7042 70 N 165.60 E 172 43 E 183 O5 E 193 03 E 193 95 E 199 67 E 2O8 61E COMPUTATION DATE: 30-JAN-g3 PagE 8 arco ALASKA, INC. iH - 20 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KuPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a PBTD DATE OF SURVEY: 08-JAN-1993 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: D. WARNER · ~~~ STRATIGRAPHIC SLJIVIMARY ~~~ SURFACE LOCATION = 552' FNL ~ 1164' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW Kb "FVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9608 O0 9745 O0 9955 O0 10107 O0 10190 O0 10300 O0 6570.80 6671.66 6825.30 6938.26 7000.44 7082.86 6474 80 6575 66 6729 30 6842 26 6904 44 6986 86 6579 42 N 6671 87 N 6814 63 N 6915 84 N 6970 40 N 7042 70 N 165.60 E 172.43 e 183.05 E 193.03 E 199.67 E 208.61E FINAL WELL LOCATION ATTO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10300.00 7082.86 6986.86 7045.79 N I 42 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WELL 1H - 20 COUNTRY USA RUN I DATE LOGGED 08 - JAN - 93 DEPTH UNIT FEET REFERENCE 93012 All Interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and we shall not, except In the case of gross or wltfull negligence on our par'[, be liable or responsible for any loss. costs, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These inter33retatlons are also subject to our General Terms and Conditions as set out in our current price Schedule. HELL: 1H-20 (582' FNL, 1164' FEL, SEC T12N, RIOE, UI~) HORIZONTAL PROJECTION NORTH 12000 REF 93012 10( 8000 6OO0 4OOO 2OOO -2000 SOUTH -4000 -8000 SCALE - I / 2000 IN/FT ......................... ................................................................... ..................... ! ......... !, ...... ................. i:.. ....... .... :::: :::: .::: ::.: :::: .::: :::. ::: .::.,: : ! i i i ~ ! ! ; i i i i i.-~ ! ~ .; i ! i : ! ! i i ! ! i i ! ! ! . ; ; ! ! ~ i i ; i ~ i .i ; ! i , :.! . ; : ; · : : . - ~ .... i ; i i .i i i i i*..i..i...i i i i.i ~ i.i i i i..i i i* .i i i i...i i i..J i.i i i i i i i i.i i...i., i..;.i i i.i i i ; i i : : , ; : . . .................................... i i..i.; .i.i..i i .... i.i i i...;.i.i ~ i ...i.i.!.! i i i.i.., i i.i.!..i..i i-.i...i.-.i...i.i..i..!..;.!..i.l.i.i i.i.i...i :,!..!..i..!.. i !.~ .... I .... ~ . ~ : ~ ;~-~...}.~-¢---} ..... i!---i---}..~-;.-;-.i..i. -:.il}-!-.~i}-;.~-;i---;-;-.ii ,t-i-8oco-..i---i-..} ..i.-!..}..i .... }-i.}.~ ~.-;--}--~-. ~;;; :~. ; : : ~ ..~.;.: ~ ~*: ~*i ~ :.:-: I.i ; i : ; : ;..~-' :-: : i i i i i ' i i i- ~ ; !.i. i-i :.i...; i-!-: .i ! ; i ; : : : ' ' ' .... i:::'i~ .... :~-':-'~ .... .'~' ~' ii ............. ~" :: i ...... ~ ~ :~'~c~ '~ ':':'~'"~:"i:i': i: ": ........ :' 'i ........ ........... : ! ; ~ ~ .i-!-i-! ..... i.i--!--; -i-i-i-i--.i-i!--! .... i i. i- -.i !-i ;---~ i i i ,-~ ~ ! !-; i i-~-;-; :. -.i.i ~.~ ~ , ~ .... . ............................................... . .i. ::. ....... :; ,:. .: .::: . ............... ~!...!..!.!!.!...! ...... !..!_!..~ ...... ~..?.~.~.?.!.~ ~..~.~. ~..~..~..~..~ ~, .~...~.~,~.!..: .... :..;.il.}.~.~,, : . . -6000 -4000 -2000 0 2000 4000 6000 8000 Wr::~3T EAST NELL' 1H-20 (582' FN[, 1164' FEL, SEC 33, T12N, RIOE, UR) VERTICAL PROJECTION 183.00 -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 . . . . . : : .............. ::,- ::-: :::: ::::1:-:: :::: .:: :::: .. : :.. ,:~:! ~-:: : ...... ~ '*~'~ :: ........... x ~ ' : ' .... ' : ~ / . I ' I : : ~ : . I : . 1--? ' : t : : : : : : : i ' 0 PROJECTION ON VERTICAL PLANE t83.00 3.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = I 2000 IN/FT STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Alter casing m Repair well Change approved program ~ Operation Shutdown ~ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate__ Pull tubing __ Variance m Perforate __ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~_. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 582' FNL, 1160' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1508' FNL, 1751' FWL, Sec. 28, T12N, R10E, UM At effective depth 1189' FNL, 1576' FWL, Sec. 28, T12N, R10E, UM At total depth 1131' FNL, 1545' FWL, Sec. 28, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8 9 9 0 feet 6 9 2 8 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1H-20 9. Permit number 92-129 10. APl number 5o-029-2231 3 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth' measured 8 8 8 7 true vertical 6 8 4 9 feet feet Junk (measured) None Casing Length Size Structural Conductor 1 2 1 ' 1 6" Surface 5 3 0 3' 9 - 5 / 8" Intermediate Production 8935' 7" Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented 225 Sx PF 'C' 1390 Sx PF 'E'& 500 Sx Class G 270 Sx Class G Measured depth True vertical depth 121' 121' 5345' 4270' 8970' MAY 2 0 1995 Alaska 0il & Gas Cons, 6omrnissior' Anchorage 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch Change classification of well from oil producer to water injector prior to initial completion. 14. Estimated date for commencing operation I 15. Status of well classification as: June 1993 I Oil ~ Gas Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,~lned C-~I~. ~ Title FOR COMMISSION USE ONLY Water Injector Conditions of approval: Notify Commission so representative may witness Plug integrity BOP/'Test m Location clearance Mechanical Integrity Test _Y' Subsequent form require 10- Origin~'~ ~"-.-~ned By David W. Johnston Approved by order of the Commission Form 10-403 Rev 06/15/88 Commissioner Approvsd C;op, Re'-~u?ned IApprovaLNo..,.., I ?'..¢ · ~..~ r~_.17 Date SUBMIT IN TRIPLICATE Attachment 1 Change of Well Classification Kuparuk Well 1H-20 ARCO Alaska requests approval to change the classification of Well 1H-20 from an oil producer to a water injector prior to its initial completion. This well will be operated as a Class II UIC well in compli'ance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval, correlating with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. Aiaska Oil & Gas Cons. Corilrnission Anchorage 1. Type of Request: Abandon __ STATE OF ALASKA ALASrtA OIL AND GAS CONSERVATION COMMIS,..,,.)N APPLICATION FOR SUNDRY APPROVALS Suspend__ Operation Shutdown __ Re-enter suspended well __ //"V~,'~ 1"- ' Repair well _ Plugging_ Time extension _ Stimulate__ Pull tubing __ Variance ~ Perforate __ Other __ Alter casing __ Change approved program __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 582' FNL, 1160' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1508' FNL, 1751' FWL, Sec. 28, T12N, R10E, UM At effective depth 1189' FNL, 1576' FWL, Sec. 28, T12N, R10E, UM At total depth 1131' FNL, 1545' FWL, Sec. 28, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8 9 9 0 feet 6 9 2 8 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1H-20 9. Permit number 92-129 10. APl number 50-029-2231 3 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8887 true vertical 6849 feet feet Junk (measured) None Casing Length Size Structural Conductor 121 ' 1 6" Surface 5303' 9 - 5 / 8" Intermediate Production 8935' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 225Sx PF'C' 121' 121' 1390 Sx PF'E'& 5345' 4270' 500 Sx Class G 270 Sx Class G 8970' 691 3' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Aiaska Oil & Gas Cons. 'Anchorage 13. Attachments Description summary of proposal ~ Detailed operation program _ nstall sub-surface, spring controlled safety valve in 'water injection well. 14. Estimated date for commencing operation 15. Status of well classification as: June 1993 oil Gas 16. If proposal was verbally approved 17. BOP sketch I __ Suspended Name of approver Date approved Service Water Injector I hereby certify that the foregoing is true and correct to the best of my knowledge. Title ~"/~ ~, FOR COMMI&ION USE ONLY Conditions of approval: Plug integrity BOP Test Mechanical Integrity Test_ Origins! ~':--:_-3ned i~y David W. Johnston Approved by order of the Commission Notify Commission so representative may witness Location clearance Subsequent form require 10- Commissioner Form 10-403 Rev 06/15/88 Copy IApprova_l No..,. SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 1H-20 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to install a downhole, spring-controlled, injection valve in Injection Well 1H-20. This injection valve will act as a one-way check valve allowing downward injection of water while preventing upward flow of the injected fluid. The injection valve is capable of preventing uncontrolled upward flow by automatically closing if such an event should occur. This well's completion design, scheduled to be installed in June, will not include a hydraulic control line from the surface to the subsurface valve, however a landing nipple will be installed at approximately 1800' to accept the spring-controlled injection valve. Installation of the valve would b(~ performed following the original completion and prior to initial water injection. Attached is a schematic of the proposed injection valve. Alaska Oil & Gas Cons. Cornr~'tiss~on Anchorage TOP SUB ORIFICE SPRING GUIDE -'-"- SEAT INSERT FLAPPER VALVE AND SPRING ASSEMBLY Otis MC Injection Valve Alaska Oil & Gas Cons. Cornrrdssio~ Anchorage ARCO Alaska, Inc. Date: Apdi 30, 1992 Transmittal #: 8725 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the foilowin~_~pen items. acknowledge receipt and return one signed copy et tl3is transmittal. CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected 1/15-21/93 1/15-21/93 2/2-5/93 2/2-5/93 1/26-29/93 1/26-29/93 12/21-27/92 12/21-27/92 Please 5945-10332 5945-10332 4458-8090 4458-8090 4838-7880 4838-7880 3973-10300 3973-10300 Receipt Acknowledged: Date: DISTRIBUTION: D&M Drilling VendorPackage( Johnston) NSK State of Alaska(+Sepia) ARCO Alaska, inc. Date: April 2, 1993 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 8701 Transmitted here with are the following items. one signe.~?py of this transmittal. -.-1 H- 1 6 ~-~l~ LIS Tape and Listing -1H-17~ --.1 H-20 ~%"77.. -1 H-01 Please acknowledge receipt and return 01-10-93 CDR/CDN & Enhanced Resolution CDR LIS Tape and Listing 01 - 1 5 - 9 3 CDR/CDN In 2 Bit Run LIS Tape and Listing 0 2 - 2 0 - 9 3 CDR/CDN in 2 Bit Runs. 1 Mad Pass & Resistivity LIS Tape and Listing 1 2 - 2 7,- 9 2 CDR/CDN In 3 Bit Runs. Phasor Enhanced ~%'TI~LIS Tape and Listing 01 - 2 9 - 9 3 tCDR/CDN In 2 Bit Runs/Enhanced Resistivity c~...0~------1 H- 02'~%Lob LIS Tape and Listing 0 2 - 0 5 - 9 3 CDR/CDN & QRO Enhanced Resistivty LIS Tape and Listing 0 9 - 2 6 - 9 2 CDR Data from Bit Runs 1 & 2/HLDT/LDWG Format LIS Tape and Listing 0 8 - 1 8 - 9 2 CDR/CDN 1 Bit Run in LDWG Format & HLDT Data LIS Tape and Listing 1 0 - 2 9 - 9 2 CDR Bit Runs 1 & 2/Hi Resolution CDR Processed HLDT-& 3 Passes CNTG cl'z.-c~':5 --2M-04 ~-~S"/[ q2.-'7~ -- 2M-09 ~ o17..,.-105 --2M-01 93013 93007 93038 92735 93045 93056 92586 92511 92640 ReCeipt Acknowledged' - ............................ Date: .......... DISTRIBUTION: Bob Ocanas State of Alaska 'RECEIVED APR 0 2. 199,~ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Dale: February 5, 1993 Transmittal #: 8658 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Sub-Surface Directional 0 1 - 0 8- 9 3 93 01 2 Survey Sub-Surface Directional 0 1 - 0 7- 93 93009 Survey Receipt Acknowledged: .......................... DISTRIBUTION: D&M State of Alaska (2 copies) Date: .............. RECEIVED Al~s~k.a. Oil t~ Ga8 Cons. Commission Anchorage ARCO Alaska, Inc. Date: January 15, 1993 Transmittal #: 8644 RETURN TO: ARCO Alaska, Inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. H-20 2M 077 2M 29 Cement Bond Log Cement Evaluation Log Cement Evaluation Log Cement Bond Log Cement Bond Log Cement BOnd Log Cement Evaluation Log Cement Evaluation Log 01 -08-93 01 -08-93 01 -07-93 01 -07-93 01 -09-93 01 -08-93 01 -09-93 01 -08-93 Receipt Drilling Acknowledge: State of Alaska(+sepia) Date: 3950-10145 3950-10164 6950-8882 6950-8863 7000-9308 9900-11979 7O00-935O 9900-12027 RECEIVED NSK JAN 19 1995 Alaska 0il & Gas Cons. Commission Anchorage WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION December 18, 1992 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14.33 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1H-20 ARCO Alaska, Inc. Permit No: 92-129 Sur. Loc. 552' FNL, l164'FEL, Sec. 33, T12N, R10E, UM Btmhole Loc. 1229'FSL, 764'FEL, Sec. 21, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 5'TATE OF ALA~:;KA ALASKA OIL AND GAS CONS~VA~ COMMISSION PERMIT TO DRILL 20 AAC 25.005 Type of Work Drill X Redrill r~ lb Type of Well Exploratory n Stratigraphlc Test I--I Development Oil X Re-Entry n Deel3en n Service n DeveloDmentGas n Slngle Zone ~-~ MultlpleZone X "2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 96'r Pad 54' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25636, ALK 2569 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 552' FNL, 1164' FEL, SEC. 33, T12N, R10E Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 763' FSL, 790' FEL, SEC. 21, T12N, R10E 1H-20 #UI!tt630610 At total depth 9. Approximate spud date Amount 1229' FSL, 764' FEL, SEC. 21, T12N, R10E 12/18/1992 $200,000 ,, 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 H- 19 10298' MD 1229' @ TD feet 30' ~ 100' MD 2560 7082' TVD feet 16. To be completed for deviated wells 17. AnlJcipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 51.8° Maxirr~rnsurface 1,818 ~,~ At totaJ deoth CTVDi 3,226 ,*lo 18. Casing program Setting Depth size Specifications Top Bottom Quantlt~ of cement Hole Casing Weight Grade Coupling Length IVI3 'I'VD I~D TVD (Include stage datnI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 12.25" 9.625" 40.0# L-80 BTC 2,959' 41' 41' 3,000' 2,402' 510 Sx Permafrost E 12.25" 9.625" 36# J-55 HF-ERW 1,081' 3,000' 2,402' 4,081 3,071' 350SxClassG 8.5" 7" 26.0# J-55 BTClVlOC 4370' 41' 41' 4411' 3275' 320SxClassG HF-ERW To BTM of Surface Casing 8.5" 7" 26.0# J-55 BTC 5887' 4411' 3275' 10298' 7082' 220Sx ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Opera,ohs. Present well condition summary ~ TotaJ depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True VerflcaJ depth Structural E C F IV E D Intermediate Produc~on ,99~ LinerDEC 141 Perforation depth: measured Alaska 0il & Gas Cons. Corn~ss~O~ true verticalAnchorage 20. Attachments Filing fee,~. Property plat ~--I BOP Sketch X Dlverter Sketch X Drilling program X Drilling fluid program~ /~,/~x./~(x/imevsdepthp,o, 0 Refrac~on analysis 0 Seabed repert r~ 20 AAC 25.050 requirements X Signed i/'~/x' ~/'/ ~ ~"~"' ~./'~. /'~ ~'4~f~;~/' Title Area Drilling Engineer Date ~/~,~.~/'/x ,~ f~ Commission Use Onh/ Conditions of al313r~val Samples recluired r~ Yes ~ No Mud lol3recluired D Yes ~ No Hvdroi:len sulflde measures r~ Yes x~ No Directional survey reauired ~ Yes n No Required working pressure forBOPE [~] 2M [~ 3M ~--~ 5M r~ 10M r~ 15M Other: $~gned by order of ./,.~ ~ _~.~ Approved by ~ ~;'[~ V~/. dOhrh~oi3 Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit In triplicate I . , . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 1H-20 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,081')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (10,298') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED DEC 1 4 1992 Alaska Oil & Gas Cons. L;unlrnissior' Anchorage DRILLING FLUID PROGRAM Well 1H-20 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-9.6 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Weight up to TD See Well Plan 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,500 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1H-20 is 1H-19. As designed, the minimum distance between the two wells would be 30' @ 100' MD. The wells would diverge from that point. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well ddlled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. RECEIVED DEC t 4 1992 Alaska Oil & Gas Cons. Cornmissior, Anchorage Casing Design / Cement Calculations 14-Dec-92 Well Number: Surface Csg MD: Surface Csg 'rVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Well TD, TVD: Well TD, TVD: Estimated Mud Weight: Surface Casing Choice: i Production Csg A Choice · Production Csg B Choice: Production Casing Frac. Pressure 1 H-20 4,081 ft Note: Wells withTD less 3,071 ft than 11,000' TMD recommend 4,411 ft using all J-55 7" casing. Wells 3,275 ft with TD greater than ll,000'TMD 1 0,298 ft recommend crossing over to L-80 7,082 ft 7" casing at 5800' TMD from 4,841 ft surface. 9,572 ft 6,526 ft 10,298 ft 7,082 ft 9.8 ppg 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,071 ft {(13.5*0.052)-0.11}*TVDshoe =1 Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =1 1,818 psiJ 9.8 ppg 6,526 ft 3,326 psi 3226 psi] Surface lead: Surface Casing, TMD = 4,081 ft Design lead bottom 1000 ft above the Bottom of Casing Shoe = 3,081 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 965 cf Excess factor = 15% Cement volume required = 1,110 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 510 sxI Surface tail: TMD shoe = 4,081 ft (surface TD - 1000' above BTM of Surface Casing ) * (Annulus area) = 313 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 347 cf Excess factor = 15% Cement volume required = 399 cf Yield for Class G cmt = 1.1 5 Cement volume required =[ 350 sxI EE EIVED DEC 1 4 !99 . Alaska Oil & Gas Cons. Anchorage Casing Design / Cement Calculations 14-Dec-92 Production lead: ~ Surface Casing,TMD Design lead from 500' above Target to bottom of Surface Casing Annular area Lead length * Annulus area Excess factor Cement volume required Yield for Permafrost Cmt Cement volume required 4,081 ft 4,991 fi 0.1268 cf/If 633 cf 15% 728 cf 2.28 320 sxJ Production tail' Aiask~ Oil & Gas Cons. Comm'~ss'~o~' Anchorage TMD = 10,298 ft Top of Target, TMD = 9,572 fi Want TOC 500' above top of target = 9,072 fi Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 214 cf Length of cmt wanted in csg = 80 fi Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 231 cf Excess factor = 15% Cement volume required = 266 cf Yield for Class G cmt = 1.23 Cement volume required =1 220 sxJ Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud TEN,~ION - Minimljm Desiqn Fectors are: T¢_DbI=1.5 and T(isI=1.8 Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 916000 lb 4,081 fi 40.00 lb/fi 163240.0 lb 23794.7 lb 139445.3 lb 6.61 Surface (Joint Strength): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = Dead Wt in Air = Length * (Wt/ft) Casing Wt (lb/fi) = Buoyancy = Weight of displaced mud Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 979000 lb 4,081 fi 40.00 lb/fi 163240.0 lb 23794.7 lb 139445.3 lb 7.0J Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WtYft) Buoyancy -- Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 415OOO lb 10,298 ft 26.0O lb/fi 267748.0 lb 39574.3 lb 228173.7 lb Production A (Joint Strength): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = Dead Wt in Air = Length * (Wt/ft) Casing Wt (lb/fi) = Buoyancy = Weight of displaced mud Dead Wt in Air = Buoyancy = Tension (Joint Strength) = 2 Design Factor =1 490000 lb 10,298 ft 26.00 Ib/ft 267748.0 lb 39574.3 lb 228173.7 lb 2.11 Casing Design / Cement Calculations 14-Dec-92 Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Production Csg A: 1. Design Case- Tubing leak while well is SI inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Production Csg B: 1. Design Case- Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure COLLAPSE - Minimum Desi.qn Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2. External pressure =Mud Wt * 0.052 * TVD Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Casing Rated For: Max Shut-in Pres = Design Factor =1 Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 415000 lb 5,887 ft 26.00 Ib/ft 153062.0 lb 22623.2 lb 130438.8 lb 3.2] 490000 lb 5,887 ft 26.00 lb/fi 153062.0 lb 22623.2 lb 130438.8 lb 5750 psi 1818.0 psi 3.2j 4980 psi 5169 psi 1516 psi 3653 psi 1.41 4980 psi 7109 psi 3278 psi 3831 psi 1.3'I 3090 psi 0.510 lb/fi 1565 psi 2.0J 4320 psi 0.510 Ib/ft 1669 psi 2.6J 4320 psi 0.510 Ib/ft 3609 psi 1.2J D E 0 1 4 !99'Z Alaska Oil & Gas Oons, Anchorage Casing Design / Cement Calculations 14-Dec-92 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section I 9.625 8.681 47 L-80 13.5724 sq. in. 2 9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength Body Strength Collapse Burst 1161000 lb 1086000 lb 4750 psi 6870 psi 979000 lb 916000 lb 3090 psi 5750 psi 639000 lb 564000 lb 2020 psi 3520 psi 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section I 7.000 6.276 26 L-80 7.5491 sq. in. 2 7.000 6.276 26 J-55 7.5491 sq. in. Jt Strength 667000 lb 490000 lb Body Strength Collapse Burst 604000 lb 5410 psi 7240 psi 415000 lb 4320 psi 4980 psi RECEIVED D E 0 I 4 !99,2 Alaska 0il & Gas 6ons. Anchorage KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC t 5 4 3 DO NOT SHUT IN DIVERTER AND VALVES .AT SAME TIME' UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT 'THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ~ ARCO ALASKA, INC,, REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16' CONDUCTOR 2. SLIP~:)N WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16-- 2000 PSI BALL VALVE 4. 20' - 2000 PSI DRILLING SPOOL WITH TWO 10- OUTLETS. 5. ,.r) FL O ~l -~i !992 ^Iaska Oil & Gas Cons. Anchorage o 10' HCR BALL VALVES WITH 10- DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. vALVEs CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20' - 2(XX) PSi ANNULAR PREVENTER EDF 3,'10,92 I I 13 5/8" 5000 BOP STACK 7 i I AQQUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATEFL ?_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCRE'WS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(XX) PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSi. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE lINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KJLLAND CHOKE UNES. 7, TEST TO 250 PSI AND 3(XX) PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, MNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSi HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAl. CHOKE. OPEN TOP PIPE RAMS AND CLOSE Bo3'rOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMSAND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSi. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3(X30 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2000 PSI STARTING HEAD 11' - 3000 PSI CASING HEAD 11' - 3(X30 PSI X 13-6/8' - ~ PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 13-5/8'-5(XX3 PSI DRLG SPCX:)LW/ CHOKE AND KiLL UNES ~ 13-5/8' - 50(X) PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-5/8' - 5(:XX) PSi ANNULAR OEO I 4 1992 Oil & Gas Cons. Commission Anchorage ,_ Created by : jones For: D STOLTZ Date plotted ' 12-Dec-92 Plot Reference is 20 Version tt7. Coordinates are in feet reference slot #20. True Vertical Depths are reference wellhead.! N 3.24 DEG E 6606' (TO TARGET) I I V ARC0 ALASKA, Structure : Pod 1H Well : 20 Field : Kuporuk River Unit Location : Nodh Slope, Alaska 1200 - 1600_ _ 2000_ _ 2400_ _ 2800_ _ 5200_ _ 3600_ _ 4800_ _ 5200_ _ 5600_ _ 6000_ _ 6400_ _ 6800_ 7200_ .... East --> RKB ELEVATION: 96' KOP TVD=300 TMD=500 DEP=O 3.00 TD LOCATION: 1229' FSL, 764' FEL SEC. 21, T12N, RIOE TARGET LOCATION: 765' FSL, 790' FEL SEC. 21, T12N, R10E TARGET TVD=6526 TMD=9573 DEP=6606 NORTH 6595 EAST 374 400 0 40O 800 1200 I I I I I I I I I I 7600 - _7200 - _5600 - _5200 - _ _4400 ~ 9.00 k 21.00 BUILD 3 DE(; / 100' 3600 'X,, 33.00 5200 0 x. 39.00 %%45.00 B/ PERMAFROST 1VD=1634 TMD=1777 DEP=545 - EOC TVD=1801 TMD=2027 DEP:729 _28oo _2400 _2000 ~'x~ 9 5/,5" CSG PT I'VD=3071 TMD=4081 DEP=2344 _1600 ~'~ T/ UGNU SNDS TVD=3121 TMD=4162 DEP=2407 ~ A/B MODIFIED CSG TVD=3275 1MD=4411 DEP=2605 - ~, ' 1 T/ W SAK SNDS TVD=3541 TMD=4841 DEP=2941~ I "°c^*'°": I I I sEc. - MAXIMUM ANGLE ~ .,00 o 51.81 DEG o,os ,.~Ec / ,oo, x. ;:3.so jr) F P 1 4 !qq9 TARGET ANGII~' TARGET - T/ KTJP SNDS (EOB) TVD---6526 TMD=9573 DEP=6606 N----NN---~4N,0'50 ..... w ,. , ,O',.,,~ .c-- ~.J 4o DEG v~~..~ B/ KUP SNDS 7VD=6929 TMD=10099 DEP=694~~--~ T~r"--'~r~ r"c'c~--~'~4- x \ ~ / ,.o~ .~- ~=?o.~ ~'~.=,o~, m.=~o~ '"~ Anchorage 0 400 800 1200 16<]0 2000 24.00 28 3200 ,56 40 4400 4800 Scale 1 : 200.00 Vertical Section on 3,24 azimuth with reference 0.00 N, 0,00 E from slot #20 52 56 O 6000 6400 6800 72 West Scale 1 ' 50.00 200 150 100 50 0 50 100 150 ! I I '" ~~ ~o °° o 1100~ 170O 700 3900 900% 1500 7( 500 550( 5700 1300 1100 t900 ~o140 I I I I RECEIVED Alaska 0il & Gas Cons, CornrnissioO Anchorage ARCO ALASKA, Inc. Structure : Pad 1H Fleld: Kuparuk River Unit Well: 20 Location : North Slope, Alaska Plot includes Proposed 16 & 17 200 _ 150 _ lO0 _ 5O _ 0 _ 50 _ 100 _ 150 _ 200 A I I Z I I V State: Alaska Borough: Well: 1H-20 Field: Kuparuk River St, Perm ~ 92-1~ Date , ~16/'92 Engr: M. Minder 1H 28.XLS Interval Intervai Size Bottom Top Length !A 16 121 41 80 2A 9.625 2402 4.1 2959 SA 9.625 307I 2402 1081 4A '7 - `7082 4I 10298 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 SA 0 0 0 0 9A 0 0 0 0 IOA 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 62.5 40 36 26 0 0 0 0 0 0 H-40 WELD 0 L-80 BTC $8961 J-55 BTC 0 J-55 GTC t,~0P 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 4B 5B 6B 7B 819 9B 10B Mud Hydraulic Wieght Gradient ppg psi/fi 9.6 0.499 9.6 0.499 9.6 0.499 9.8 0.510 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 Maximum Minimum Pressure Yield psi psi BDF N/A 1640 ####### 2542 5`750 2.3 2542 3520 1.4 2542 4980 2.0 0 0 #DIV/0! 0 0 #DIVIO~ 0 0 #DIV/OI. 0 0 #DIV/O! 0 0 #DIV/OI. 0 0 # DIV/0.1 Tension Strength K/Lbs 1C 5 2C 157.321 3C 38.916 4C 26,7,748 5C 0 GC 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 736 147.2'0 916 ,5.82 564 14.49 4.15 1.55 0 #DIV/O! o #DIV/0! o #DF,,//O! 0 # DlVl0'.- 0 #DP¢I0! 0 #DIV,10! Collapse Collapse Pr-Bot-Psi Resist. CDF 60 670 11.092 1280 :2090 2.413: 1533 2020 1.318 3515 4320 1.229 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DlVlOl. 0 0 #DIVIO! 0 0 #DlVlO! 0 0 #DIVI0! Pa~ 1 iN-2OCM¥.X"L§ SI:ate: Field: State Permit lH-20 Kupacu/; Fiive¢ Engineer:. Work Sheet: Date: Iv/Idinder 12/1£/92 Casing Type Casing Size -Inches Casir,:j Length - Feet Hole Diarr~er-I~hes Cernent - Sacks _~1 Cemer¢. - Yield Cement.-Cubic ft Cement-Cubic It Cement-Sacks Cement- Yield ~.2 Cement- Cubic It1:I2 Cement-Cubic It 1:I2 Cerr~nt- Sacks Cement-Yield ~3 Cement-Cubic ft ~3 Cement- Cubic tt~3 Cernent - Cubic It / Vol Cement- Fill Factor Casing Type Casing Size -Inches Casing Depth- Feet Hole Diamete~ -Inches Cement- Sacks Cement- Yield Cement- Cubic It Cement- Cubic tt Cement-Sacks ~2 Cement- Yield ~12 Cement- Cubic ft Cement- Cubic tt ~2 Cement-Sacks ~3 Cement-Yield Cement- Cubic It Cement- Cubic It ~3 Cement- Cubic It / Vol Cement-Interval tt Top of Cement- Feet Conducto~ 16.000 80.000 24.000 0.000 0.000 0.000 200.000 0.000 0.000 0.000 O. O00 200.000 1.432 Intermediate ~1 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~DIV/O! ~DIV/O! Surface 9.625 4,040.000 12.250 510.000 2.170 1,106.700 t,106.700 350.000 1.150 402.500 402.500 0.000 O. OOO 0.000 0.000 1,509.200 1.193 inte~mediete 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~IDIV/O! ~DIV/O! Line~ 0.000 0.000 O. O00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ttDIV/O! Production 7.000 10,298.000 8.500 320.00 2.28 729. G0 729.60 220.00 1.23 270.60 270.60 0.00 0.00 0.00 0.00 1,000.20 7,887.60 2,410.4 Measured E)epl-h ** CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc [2'thru 8] (3) Admin [8~-- *~')~ou~'~ [9 thru 13] /~ [10 S 13] h.~ [14 thru 22] [23 thru 28] (5) BOPE · 10. 11. 12. 13 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 1. Is permit fee attached ............................................... 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 & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ j~. Does operator have a bond in force ................................... )0/4 Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ntrnber appropriate .......................................... Does well have a unique name & number ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Lease & Well ~ YES NO Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~C~2 psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other '~- ),~/~ 'IX [29 thru 31] (7) Contact /~//~ (8) Addl )~.-~'- ¢'Z..,- geology' engineering' DWJ_~ MTM/'~' P-,AD ~__~'~[ RPC ~ BEW JD~___Z~~ LAG rev 08/18/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntrnber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CEMTE~ * , , ******************************** *-----=- $CHLU~:~BE~R~ ----~--* ****************************** COMPANY NAMF. : ARCO AL/%$KA, INC. WELb NAME : 1, H - ~0 FIELD NA~E : K, UPA. RUK RIVER BO~OUG~ : NORTH ST.,OPE ST~T~ : ALASKA API ~.~IUV~BER ~ 50-029-223~3-00 P~;FERENCM NO : 92735 RECEIVED APR OZ 19~ ~ask'a Oil & (;as Cons. Commission Anchorage Tame Veri, flcation Listing ~chlumberqer AlasKa Comput!nQ Center 22-jAM-1993 05::]8 **** REEL HEADER **** SERVICE NA~M : EDIT DATE : 93/01/22 OPIGIN : FLIC REEL WAME : 92735 C~NTINUA~:ION' ~ : PREVIOUS' CO, NENT : ARCO ALASKA INC ,KUPARUK ~IVE~ UNIT,lH-20,50-029-223~B 00 **** TAPE HEADER **** SERVICE NAN~ ~ EDIT DAT~ : 93/01122 OPI~I~ : FLIC T~,PE N'A~E : 92735 CONTINUATION # pREvIOUS TAPE CO~ENT : ARCO ALASKA, INC.,KUPARUK RIVER UNIT,1H-20,50-029-.22313-O0 WELL NA~E: ADi NUMBER: OPERATOR:., LOGCING COMPANY.: TaP~ CREATION DATE: jO~ DATA JOB NUMBER: OPERATOR WIT~!ES$: SURFACE LOCATIOn3 SECTIf]N: FbEVATION(FT FRO~ ESL O) K~LLY BUSHI~3G: DERRICK FI,OOR: GROUND LEVEL: w~LI, CASIgG RECORD 8IT RUN 92735 ST. WHITELY !ST STRING I H-20 . 22-jAN-9] BIT RUM 2 Q2735 S T A M 0 I] R w H ~ T E I,, Y 33 2r~ JOE 552 1164 9~735 ST, AMOUR WHITELY 96.00 96.n0 54. () 0 OPEN HOLE CASIhG ORILLER$ FilT SIZE (IN) SIZE (iD.:) DEPTH (ET) 8.~00 3_., . Schlumberqer aska Comp~time Cemter 22-JAN- .l. 993 08:38 P~ODUCTION STRING REMARKS: FI:ELD ENGINEER'S REMARKS: ********** RUN 3,, ********** BIT TO RB:S 65.86' BIT TO (";R 7~.28', BIT TO DEN 132 89 BIT TO N~:UT 139.1{:,~. D~ILLED I::TERVAL ~973' TO 9087; BIT T'O PES 65 86' BIT TO GR 76.2a', BIT TO DEN 133 77; BIT TO ,KUT 1~0.0:~'. DRILLED IN'T~RVA[, 9087, TO 9500~ BIT TO RES 15 53' BIT TO GR 25.95~ BIT TO ['~:)~ 42 ~}2 BIT TO ~EUT ,4~ 30$~ ~ASHDO~N I~'TE~VAL 9408~ T'O 950~ DRIL, LED INTERg~[, ~00' TO 10300'. , ,,.I ~ 1 0E ~4AT~iX DENSITY ~ 65 (G~/~C:). FLUID DE~S ~ (G~/CC) ROT,~T~O~,~AL BULK ~ENSITY PROCESSING USED .1,. . AR ,iT A DD~:D TO ~{JD SYSTOle. DATA. FRO~ D(]WNHOLE ~,~OPY. DOWN,tOLE SOFTW.ARE vE~SI(:)~ V4.0C. $ PAGE: **** FILE HEADER FIL~ NAME : EDIT .001 SERVICE ~ FbIC V~R~ION : O01A07 D~TE : 93/01./22 ~AX R~C SIZ~ : 1024 FILE TYPE : LO LaST FILE : FILF HEADER FII, F NUMBER: ~ De~tb shifted and c!~P~ed curves~ all blt runs DEPTH INCRE~ENT 0.5000 # PILF SUMMARY gR[! TOOL COOK START DEPTH CON 3973.0 CDR 3073.0 $ BASELIN~ CURVE FOR SN~FTS: GR CURVE SHIFT D~TA (~FASURED DEPTH) BASELINE DEPT[; 1002~.5 ~.0013.0 9990.5 qgT~.5 STOP DEPTH 10256,0 102~2.5 --- ....... FOUIVALE:NT UNSHIFTED DEPTH .... - ..... 10044,5 !00~,0 10oo0.5 9988.0 ;chlumberger Alaska Computing Center 9065.5 90~0.o0 9939,0 9953.0 9877 O 9~92.0 0,27.5 9761.~ 9776.0 9715o 9729.0 9683.5 9697,5 60~.5 ~55 .0 9565.0 9534.~ 9547.5 951).0 463.~ 9477.5 ~37 g. 9391.. 0 q344.5 9358. 9337,5 9324. 9230 ~ 9243.5 84 0 9096,5 ~ 0o0 9002.5 _970.5 8982.0 8935.0 894,3.0 8866.0 9977.5 879n 5 88~ 5 78 10 87 86~7,5 8639.0 8a64.0 8174.0 ~455.0 ~64.0 8425.0 8435.0 8392.0 8402.0 83~9,0 8400.0 8376.0 8386.0 8344.5 8354.5 8312 O 8320,5 8283:0 8293.0 8273.0 ~283.0 8222,5 8231.0 820Bo0 8216,0 8~1a,5 8125.0 eO14.0 ~022.5 8004.0 80~3.0 7~39.0 7947.0 7887,5 7896.5 7875,5 79B3.5 7837.5 7845.5 7795,0 7803.0 7644.5 7652,0 22-JAN-1993 08:38 PAGE: Alaska Computlnq Center ~-JAN-1993 08:38 PAGE: 754.2.0 7548.0 89.0 7495.5 ~6~.5 7,74.5 727,.0 7979'5 7189 5 7194,0 6974~5 6979.0 6905.5 668~.0 6685.0 o40:5 6os .o 5942.5 5943.5 5906.5 :5869,5 5~70.0 5666.0 56~3.0 5623 550~.0 5492 0 5491.,0 547]:0 5406.0 5406.0 5~60.0 5~69.'5 5~1~'0 5217,5 100.0 99,5 $ ~ERGED QATA SOURCE ~'RU TOOL CODE BIT RUN NO. ~ERGE TOP ~WD I 3973,0 ~W[) 2 9087.0 ~WD 3 9500,0 REMARKS: mERGE BASE 9087.0 9500.0 10309.0 THE DEPTH ~DJUSTt~ENT$ SHOWN AB..VE REFLECT I~Wt) GR TO ~IRELI~;F GR OF 08-JA~-93. ALL OTHER CURVES WERE CARRIED WITH T~E GP SHIFT. THF SAMPLI~3G TICKS CONTAINED IN THIS EDITED FII:E ARE AT .5 SAMPLIP~G RATE. TEE SAMPLING TICKS IN FILE ~ WILL BF CLOSER TO ACTUAL AC(~UIMITI~N RATE. LTS FORe, AT DATA 22-JAN-lg93 08:38 ** DATA. FO~MAT~ ,..P~i, CIF'ICATIONS ~ ~ECORD" ** ** SET TYPE - 64L8.** ?YPE ~P~ CODF, V A I..,ll E 1 66 0 2 66 0 3 73 90 4 66 5 66 6 73 7 65 a 68 0 5 9 6S !.1 66 12 13 66 0 14 65 FT 15 66 68 16 66 0 66 .ORDER ~ LOG TYPE CLASS ~OD NUMB SIMP EbEM CODE [%iiEX) -,,,,------------------,------.--,,---,-------------------------,-----,,----,,,,------- FT 61898 O0 0 0 0 1 1, I. 000000 ~()~ MWD G/C3 618983 00 00O 00 9 I 1 1 4 6~ 0000000000 Dm~;Q ~WD G/C3 6180~3 00 000 00 0 1 1 ! 4 68 00OO000000 PKF ~WD BN/E 618983 00 000 00 0 1 ~. I 4 68 000OO00000 Cab~ MwD IN 618983 00 O00 00 0 I 1 1 4 68 0000000000 NPHT MwD PU-$ 6189~3 O0 OOO O0 0 1 ! 1 4 6~ 0000000000 a~ ~) OHM~ 61~9~3 00 000 O0 0 I 1 ! 4 68 000O000000 RP ~WD OH~ 6189~3 00 000 00 0 I 1 1 4 68 0000000000 ROP MwD F/~R 618983 00 000 00 0 ! 1 1 4 68 00fi0000000 G~ ~wD GAPI' 618983 o0 000 00 0 1 I 1 4 68 O00000000o NMI ~WD 61~983 OO OD0 00 0 1 ! 1 4 68 0000000000 R$I MWD 618983 OO O00 0O 0 1 i I 4 68 0000o0oo00 M~NA ~W9 CP$ 618983 00 000 O0 0 1 1 1 4 68 000000000O ~F~ ~W~ CPS 618983 00 000 O0 0 1 ! 1 4 68 0000000000 T~ MWD 61~9~3 00 000 O0 0 ! ! 1. 4 68 000000000O T~B~ ~wo 618983 o0 000 O0 0 1 ! ~ 4 68 00n0000000 GTCW ~WD S 61~983 00 000 00 0 1 1 I 4 68 0000000000 NTC~ ~w9 S 61~983 00 000 CO O 1 1 1 4 68 0000000000 DTC~ MWD S 618993 O0 000 00 0 1 ! 1 4 68 0000000000 RTCK aWO S 6199~3 00 000 0O 0 1 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ;chlumberoer .AlasKa Computing Cet~t. er D~PT. 10313,000 C~LN.MWD -999,250 ~(?)P, MWD 30,717 HEN,a.MWD ~ 000 HEFA,~WD GTCK. ~WD -'99.. :~50 MTCK o~pw i o 3oo. ooo C&LN ~MWD -999.250 ~0~ ~W~ ~5;070 GTCK:MWD -999,250 NTCK~MW6 DEPT. 10~00.000 RHOB.,~wO ~OP.MWD 27,:777 G~,MWD P ~ N ~, ~ W O 267 ,, 500 H g F A., ~ W D GTCK,:~WD 1,900 NTCK,~WD D E p ·. 10100.000 R H 0 B. ~ W .O ALM,MWD 8.,~34 NPHI.,MWD C~Op,MWO 31,41 ~. GR', MWD H~N.~ ~Wn 280 750 ~EFA,NWD . ~wo I: 000 NTCK..MwD RO~. MWD 06,775 GR. MWD ~EN~,~WD 302,430 MEFA,MWO GTCK,MWD -999,~50 NTCK,MWD BEPT, 9900,000 RHOB,MWD CaLN,MWD 8,706 POP. B~WD 34,440 GR, }.,{EN~. ~ WO 206,144 GTCE, ~WD 1,000 NTCK. MWD D~PT ~800,00Q RHOB.MWD C.~LN:MWD 9.7a2 NPNI.MWD ROD. ~WO 46,320 GR. H~N~ ~WO 2B8 906 HEFA,MWD GTCK~MWD -909:250 h'TCK.~WD DEPT, q700.000 RHOR. MWO CALN.MWD 8,776 NP~I.~WD ~mNA.~WD 299,750 GTCO. ~{WD 1,00o NTCK.~aWD D~PT, 9609,0Q0 RHOB.MWD C5LN.MWD 8.9~7 HWN~.~WD 278,6~9 HEFA.MWD GTCK .~WD -990,250 MTCK. ~W!') '999 250 DpNO,MWD -g99~250 ~A,MWD -999,250 NSI,~WD 0 000 TAB.~WD '999~250 DTCK,MWD -999,250 DRHO:,MWD -999,250 -999,250 N$I,~WD 0 ~0C TAB,MWD -099: 50 DTCM 495 DR~O,.MWD ~ :Boo ~.~.~wo 93,785 NSI,MWD 5,846 TAB,MWD ],OOO DTC~,MWD ~ ~1 DRHO..~WD 3 ~ 0 RA,.MWD 6.542 TAB,MhD 1,000 DTCK,MWD 2,~03 28.500 46.844 NSI,MWD 8,050 TAB,MWD 1,000 DTCK,~WD ~ 419 30~64~ RA,:MWD 72.52~ N$I,MWD 7,6~! TAB.MWD -999,~ 0 DTCK,~WD 2o417 31,133 P.~,~WD 74.789 N$I,MWD 7,5~5 TAB,~W~ 2,49~ DPHO,MWD ~,~00 ~,~WD 86,884, ~SI,MWD 8.608 TAB.MWO -~99.~50 DTCK,MWD 9,554 3~,72~ 9&,~WD 109.750 NSI,~WD 6.777 TAB,MWD 1.0C0 DTCK,MWD -999,~50 999.250 -999,250 -999,~50 -999,.250 -999,250 .-999'950 -999~50 0.:022 1.719 0,009 0594 :ooo 0,013 2.480 0:.000 . 999 250 0.009 1.96~ 0.000 , 0 235 -9992250 0 013 0,000 0,360 -999.250 0.014 3.411. 0,000 0.310 1.000 0.022 2.760 0.000 0.68? -999.250 0.022 ~.412 0.000 0.76! -999o~50 RP.,MWD RSI,MWD ThBD.,~MWD RTCK.~WD PEF,~WD RP:,~WD R$i,MWD TABD,~WD RTCK,~WD PE~,~WD RP.MWD RTCK.~WD P~F,MWD RP,~WD TABD.~WD RTCK.PWD PEF.MWD RP.MWD R$!,~WD TABD.~WD RTCK.MWD P~F.MWD R$I,NWD TABD,~WD RTC~,MWD PEF,MWD RP,~WD RSI,~WD T&BD.~WD ~TCK.MWD PEF,MWD RSI,uwD TABD,~WD RTCK.NWD DRF.MWD RP.uwD TABD.~WB RTCK.~WD PAGE: -999:250 -999.,~50 -999,]50 -999,~50 :999J, 250 999,250 '999.250 -999,~50 '-999.250 3,670 1 7~5 0:000 1.619 -999,250 3,47~. 2.44 0,000 1.496 1,000 35 0.000 0,897 1.000 3,205 3,734 0,000 1.225 -999,250 3,~92 3,344 0.000 0.974 -999.~50 3.1~9 2.601 0,000 1.568 1,000 3,855 2,165 0.000 1,~99 -999,250 ~chlumberqer Alaska ComDut~i~q Center DEPT. 9500,000 RHOB MWD C,!~ LN MWD 9,5~7 ~.!PHI." MWD ROP~ ~4:WD 168,0~9 ~R,~'WD H~N~,~WD 240,636 HEFA,MWD ~TC~, ~WD -999, ~50 ~'~TCK, MWD D~PT 9400,000 ~OP, ~W~D ~25 563 GR,MWD }.{~N.~ MWD 2~8 500 GTCO' ~WD -999 ~50 CaSN, ~WD ~,678 ROP, MWD 1.68 ,~23 GR, MWD }4~N~ ,:MWD 263,000 HEFA,~WD GTCK.MWD -ggg,2KO NTCK.~WD DEPT, 9200,000 C.~LN, ~WD 8,500 NPHI,MWD ROP, MWD 193,24~ GR.~WD H ~,i N ~, ~ W D 264 ,, 250 H E F A. ~ W D GTCK. M~D -999,~50 NTCK,MWD [)EDT. 9100,000 C~[.~ MWD 8., :77~ NPHI ~OP, MWD 241,517 GR,~4WD HEN~.MWD 265,000 ~EFA.MWD GTCK,~WD -909,~50 ~TCK,MWD DE, PT, 9000,000 RUOB,MW'D CaLN,~WD 8,500 NPMI.MWD POP,MWD 165,143 HYha,~WD 256,000 GTCK,~WD -999,250 NTCK,~,wD D,~PT,. ~900,000 RHDB,~WD CaLN,MWD 8,500 NPHI,~WD ROP, ~WD 246,408 GR. ~WD HFN~.~wD 258,750 HEFA,MWD GTCK,~WD -99~,250 NTCK.~WD DFPT. 8800,000 RHOB,HWD C &I...D~. MWD 8,5~ NPHI,MWD RO~, MWD 105.8~5 GR, H~K}a.~WD 280,750 HEFA,MWD GTCK.~WD 1,000 NTCK. MWD OFDT. R700.000 GTCK,MWD -999,~50 NTCK.~.tWD 22'dAN-1993 08:38 , 38 ~:,'~WD 105 ~69 4,~69 -099'~50 106,9' 83 N$I,MWD -9991. 0 2 ~57 41. 300 ~A*MWD 130 143 NSI,~WD 5,563 TAB:,~WD -999'250 DTCK,~WD 3:9oo 2~2,954 NSI.~WO -999:250 DTCR,MWD 2,279 DRHO.,MWD 50,002 172,242 4,773 TAB,~WD 1,000 DTCK,~WD 2,788 D~HO,~WD 37.460 RA,~WD 122.803 N$!.~WD 5.802 TAB.~WO -999.~50 DTCK.~WD ¢.288 DRHO,MWD 3~,897 ~A,MWD ~07,008 NSI,~wD 6,738 TAB,~WD -999,250 DTCK.~WD 2,497 DRHO,,WD 33,650 RA.~WD 95.7~5 NSI.~WD 6.855 TAB,~WD ~.000 DTCK,~wD 0.043 .:804 .000 0,396 I. 000 0,039 1.363 .9992577 ~50 -0,.007 1,799 0.000 0 744 1:.000 -0.021 2,567 1,000 0.494 1.000 -0.009 1.987 0.000 0.88~ -999,~50 0.04! 3,072 ~ .000 0.619 -999.250 0.060 2.890 1.000 1.906 -999.~50 0.030 1.000 0,621 -999.250 -0.022 3.~53 0,000 ~,49~ -~99,~50 PEF,~WD RP,MWD RSI,MWD TABD,MWD RTCK,MWD PEF.MWD RP,~WD RSI.~WD ABD PEF.MWD RP,MWD R$I,~WD TABD,MWD RTCK,MWD PEF.~WD RP,MWD ~SI,MWD TABD.~W:D RTCK.MWD P~F,~W'D ~SI.~WD T~BD,~WD ~TCK.~WD PEF,~WD RP,~WD RSI,MWD TABD,M'WD RTCK,MWD PEF,MWD RP,~WD R$I,MWD TABD,~WD RTCK,~wD PEF,MWD RP.MWD RSI.MWD T~BD,~WD RTC~.MWD PEF.~WD RP.MWD RSI.MWD TABD.~WD RTCK,~WD PAGE: 6 138 1:924 0,000 1.785 1.000 3'680 000 '99~,250 -999,250 ,862 6.000 2 '999: 50 3.32 2.73 0,000 1,438 '-999,250 3,408 2,356 1,000 1.442 1.000 4,524 3,387 0,000 -999,250 -999,250 4,9~7 3,260 1.000 2.853 1.000 3,495 2.516 0.000 2,056 -999,250 3,588 3.979 0,000 2.0gl -999.250 .,IS Ta~e Verification Listing ~chlUmberger Alaska Computinq Center DEDT. 8600.000 Rt]D.~WD 142.856 GR.MWD HEN.~.~WD 291:.~50 GTCK.~WD ~'000 ~TCK.MWD D~PT. 8500.000 CALN.~WD 8.675 NPHI.~WD ~OP. ~WD 168.446. GR,NWD GTCK.~Wn -99 . 50 I.)E~DT. 8400.000 RitOB.MWD C.~LN.MWB 8.5~2 NPHI.~WD ROD.~WD 37.888 HENA.MWD ~54.667 HE~A..~WD GTC~.~WD ' 99.250 NTc~.MWD DEPT. ~300.000 RH~B.~WD CALN.~WD 8.618 ~HI.MWD HEN~.~WD 2 .336 HEFA.~·W9 GTCE.~iWD -9 .250 NTCK..~WO D~P~. 8200.000 RHOS,MWD CAL~t.~WD ~.571 NPHI.MWD ROD.~WO 236,959 G'R,MWD ~ENA,,W~ 266.766 GTCN,~WD -999,250 DEPT. ~100.000 ~HOB,MWD CALN.~WD 8.850 ~OP.~WD 171.4~1 GR.~WD HFNa.~WD 272.250 ~EF~.MWD GTCK.~WD -999.250 NTCK.~WD DEPT. 8000.000 CALN.NWD 8.694 NPHI.MWD ~OP.~WD ~78.23B GR.~WD HE~a.~WD 277.552 HEF~.~WD GTCK.MWD -999.~50 NTCK.~WD DFDT. 790~.000 Ca[.N.UWD 8.811 NPHI.MWD POP.HWD 88.867 GR.~WD ~!a.~WD 259.891 GTC~.~WD -999.250 NTCK.~WD DFP~, 7800.000 CALN.~WD 8.690 NP~I.~WD ROD.~WD 2~6.53~ H~!~.~WD 274.854 NEF~.MWD GTC~.WWD -999.250 NTCK.~WD 22-JAN-1993 08:3~ 32i503 DRHO.~WD I 400 87 ~.]1 NSt.~wD 7,3 0 TAB'MWD -999.250 DTCK.~WD 99,496 6.652 TAB.:NWD -999.250 DTC~.~wD ~,276 DRH~.~WD 39.200. !09.719 N$I.~'WD 5.447 TAB.~WD ~.000 DTC~.MWD 3 .071 R.A.~WD 101.3~6 6.880 TAB.MWD -999.250 DTCK.MWD 3~,363 DRBO.~WD 111.873 N$I.~WD 5.938 TAB.~WD -999.~50 DTCK.~wD 2 DPH0 MWD 37:~7 8 RA.~WD 109.963 NSI.MWD 6 ~23 TAB.MWD -999:50 DTCK.gWD 2.401 DRHO.~WD 36.~00 126.166 NSI.~WD 6.340 TAB.~WD -999.~50 DTCK.UWD 41,741 PI.~WD 124.029 NSI.~WD 5.520 -g99.~50 DTCK.UWD ~.395 DPHU.~WD 36.604 RA.~WD 103.045 6.170 -999.250 DTCE.iqwD 0.007 000 0.722 -999.250 ' o' i..183 1.000 0,042 0 951 0000 0 686 -999 250 . 0.665 -999.~50 0.018 2.448 0.000 0.370 -999.250 0.005 3.135 0.:000 0.717 -99g.~50 -0.019 2.331 0.000 0.480 -999.250 0.002 1.905 o.000 0.740 -g99.250 -0.005 ~.786 O.OOO 0.403 -999.250 PEF.MWD RS TABD.MWD RTCK.~WD RP.~WD RSI.~WD T.a. BD.MWD RTCK.MWD '' ~WD RP.~:WD ~SI..~WD TABD.~WD RTCK.~WD PEF.MWD RP.~WD T~BD.~WD RTCK.MWD PEF.~WD RP.~WD R~I.MWD TABD.~WD RTCK.~WD PEF MWD RP:~WD RSI.MWD RTC~.~WD PEF.~WD RP.~WD R$I.~WD TABD.~WD RTCK.~WQ RSI.MWD TABD.~WD RTCK.MWD P~F.gWD RP.~WD RSI.~WD TABD.MWD RTCK.MWD PAGE: 3,343 ,3,145 0.000 1.661 -999.:250 3.536 2.877 0.000 1.906 -999.250 ~,577 0.720 ~ 8 '999.250 3.233 .400 .000 1.506 1.000 3,458 2,299 0.000 0.761 1.000 1.000 1,278 -999.~50 3.569 2,952 0,000 0.888 -999.250 3.536 2.220 0.000 1,335 -999.250 3.342 2,15~ 0.000 1.474 1.000 ,chlUmbe'roer laska ComPut nC/ center. [)EPT,~ 7700,000 RHOB,MWD CALN,MWD 8,682 NPHI,MWD ROP:.~WD 178,I72 .GR:~.~WD HENa,~WD 291,000 HEFA,MWD GTCK,MWD -999,250 NTCK.~qWD DEPT,. 7600,000 ~MOB':MWD C.~LW.MWD 8,586 NPHI,MWD ~OD,~WD 97,B91 HMN~ MWD 2~8 250 HEF~,MW'D GTCW:MWD '999~250 NTCK'MWD D~ 7500.ooo ALN'~WD 8,500 NP~I,~fWD Cp'OD:MWD 50.107 HENs.~WD 291,,500 gEFA.~WD GTCK.~WD .1.000 NTCK,MWD DEPT 7400.000 RHOB.MWD C,ILN;~WD 8.707 ROP.~WO 247,61~ GR:~WD HEN~,~WD 280.750 HEFA,~WD GTC~.MWD -999.250 NTC~,MWD DMP?. 73O0,000 C.~LM MWD 8.,635 NPMI.M. WD ROP:NWD 3O0.203 H'EN,~.~,WD ..280,906 HEF.A,~WD GTCK,MWD -999,250 MTCK,~WD DEPT. 7200,000 RHOB,MWD C.~LN,~WD 8,639 UPHI,MWD ~OP,~WD 151.820 ,GR,MWD HFMA.MWD 279 949 HF.F~,~WD GTCK,.MW9 1:000 NTCK,MWD DEPT. 7100,000 ~HOB'~WD CALN.MwD 8,606 wPHI,~WD ~OP.MWD 260.4~8 GR.~WD HFN.~.~WD 290,~50 HEFA.MWD GTCK.~WD 1,000 NTCK,~WD DEPT. 7000,000 CaL~Y.MWD 8'511 NPHI.WWD ~OP.MWQ 307,761 gR.MWD HPN~.~wD 28~,500 HEFa,MWD GTC~,~wD -999.250 NTCK.WWD DFPT. 6900,000 RHOB.~WD C~LN.~wD 9,559 MPMI.~WD ~OP.~W~ 336,89~ G~.MWD HE~a.~WD 286.250 HEF~.~WD GTCK.~WD -999,250 NTCK.MWD 22-JAN'1993 08:38 97,467 NSI 6,890 T~B, qW'D '-999,250 DTCK:,'MWD 3~ ~49 8 ~ 535 6,6~5 TAIl. ~WD -999,250 DTCK. 35.48 3 6'498 TAB, ~WD -999,250 DTCK WD 2,394 DRHO',~W'D 34,363 RA'~WD 100.382 NSI.,~WD 6.598 -999.250 DTCK'~WD 2. ,410 D R ~{ 0. ~ w D 83 5 N 6. 0 TAB, ~a~WD 89. 20 6.240 TAB,MWD -999.250 DTCK.~WD 2 392 D~HO.MWD 32:300 ' R~,MWD 87.349 NSI,~WD 7,~30 TAB.MWD -999.250 DTCK,~WD 2,332 DRHO,aWD 29.600 RA.MWD ~5.510 NSI, ~.~WD 7,490 T~B.MWD -999.~50 2 311 34:27~ 60,275 6.742 TAB.~WD -999,250 DTCK.~WD 0.000 3,440 0.000 :0.283 -999.:,2:50 0 O09 2 685 O 000 0.033 2.487 1, 000 -990,250 -0 008 3 039 0 000 0 441 -999 250 0 002 2 585 0 000 0 5~ - ::oos 695 0.o00 0.417 -999,~50 0.000 2.890 0.000 0.328 -999.~50 -0,014 3,394 0.000 0.358 -999,250 'O,OOB ~,991 0.000 0.715 -999,250 PEF,MWD RP.~WD R$I,MWD TABD,~WD PEF,MWD RP*MWD TABD,VWD RTCK.NWD PEF MWD RP:MWD R$I.~WD TABD.~WD RTCK.MWD PEF R$I.~WD TABD.~HD RTCK.~WD PEF.~WD RP:.~WD RSI,MWD TABD.~WD RTCK.MWD PEF,g'WD RP.~WD RSI.~WD TABD,MWD ~TC~.~WD PEF.MWD RP.MWD R$I.~WD TABD.~WD RTCK.~WD PEF.MWD RSI,~WD TABD.MWO RTCK.~WD PEF.~WD RP.~WD R$!,~WD TABD.MWD RTCK.~WD 3 312 3 530 0 000 0 736 -999 250 3,252 2,624 0.000 1,150 -999,250 2,504 0.00o 1,743 ~999,250 076 0.000 1.410 -999,250 ~:602 0,000 1,056 -999,250 3,204 2,723 0.000 0972 -999:250 3,180 2.665 0.000 0,748 -999,250 2.892 3.46! 0,000 0,570 -999.250 2,943 2.8~2 1,000 0,956 -999.~50 lChlu~berger 1~)<~ Comt~>,]t .in... n r DEPT, 6800,00!) ROP, ~'WO 406,578 HFM,5, ~WD 2~6.,67,~ HEFA,MWD GTCK,MWD -999,250 MTCK,~WD DEPT, 6700,000 RHOB')~WD C A L~.~ ~WD 9,5'70 MWD ROP'~WD 371,695 . ,:M WD ~N~,~WO 287,000 HEFA,MWD GTCO, ~'~4D -999,250 NTCK'MWO DB:PT' 6600.000 ~LN'.M~D e,6~5 C~op,~.~wD 181,8e5 GR,~WD HF~,t,~ ,, ~WD 285,750 GTCY,~WD 1,000 NTCK,MWD D~DT, 6500,000 CAbN ~WP 8,~1 NP,I.MWD RC);~:M'WD 31 1.~,1 GR. GTCK.MWO ' g9] SO 5~TCK,MWD CAIS~. MMD 8., 500 NPMI, MWD ~OP. ~WD 87,062 GR',~WD HEN.~. )"WD 285,702 GTCK,MWD -999,~50 NTCK,MWD DEPT, 6300,000 C~LN,MWO 8,562 MPMI,NWD ~0~. MWD 416.953 GR.~WD HFNA ~WD 276,000 HEFA. MWD GTCK:~WD -999,~50 ~'TCK,MWD DEPT, 6~00,000 C~LN, ~WO 8.500 ROm, MWD 415,357 GR, GTC~, B~WD { ,000 ~TCK, MWD DFPT. 6{00,000 RHOB,~WD C~[,M.MWD 8,647 HPHI,~'WD POp. cwo 463,555 GR, HPNa.?~WT) 268,5~4 H~F~.~WD GTCK, MWD -999,250 ~'TCK. DEPT. 6000,000 RHOB.MWD C~LM ~WD ~,5OO NPHI,MWD ~O~'Mwo 202 258 tt~.qwO 275,375 HEF'A.~WD GTCK,~wD -999,250 NTCK.~WD 22-JAM-1993 08: 38 6,942 TAB,iMWD -999,~50 DTCK,MWQ ~.3-94.7 MSI,~WD. . 7,038 TAB,.~WD 999,250 DTCK"MWD 2.301 34,122 88,072 NSI.MWD 6,641. TAB,~WD -999,250 DTCK,~WD . R A, ~qWD 87,546 6 ~03 TAB,MWD -999:~50 DTCK,MWD 2,~99 37,~00 RA,gWD 89, 31 NSI,~WD 6 205 TAB,~WD -999:250 DTCK,MWQ 2,300 DRHO.~WO 37.~00 RA,qWD 9a,397 NSI,MWO ~,070 TAB,MWO -999,250 DTC~,MWD 2,336 37,800 RA,~WD 82,7~7 N$I,MWD 5,973 TA~,MWD -999,250 DTCK,~WD 2.270 37.313 81,695 NSI,~WD 6,205 T~B.MWD -999,950 DTCK,~WD -o.oOl 3,718 0,000 0,444 '999,~50 0.003 3.093 0.000 0.311 -999..250 ' >.o0e 3,1.57 0.0'00 0.517 '999'250 -0,007 3 341 0 000 0 ~67 -999 .50 4, 05' 0.000 0 370 -999:2S0 -0.014 2.873 0,000 0.~6! -999.250 -0.013 2.911 0. 000 0.165 -q99.~50 0.006 2.185 0.000 0,~21. 1.000 -0.004 2,643 0,000 0,322 1.000 PEF,MWD RP,M:WD RSI,MWD TABD,~WO RTCK:,~WD PEF,MWD RP,MW:D RST,MWD T.ABD,MW~ RTCK,~WD PEF';~WD RP:MW'D RSI,MWD TAMD,~WD RTC:K,~WD PEF.~WD RSI,~WD TABD.,~wD RTCK,MWD P'EF,MWD RP.MWD RGI,MWD TABD,~WD RTCK,~WD PEF,~WD RP,~WD R$I,MWD T.~BD MWD ~TCK]~WD RP,MW9 RSI.~WD TABD,~WD RTCK.~ PEF,MWD RP,~WD RSI.~WD T~Q.~WD RTCK,MW9 PEF,WWD RP,MWD R$!.YWO T~BD.~WD RTCK.~wD PAGE: 10 3.155 000 0,7:00 -999,250 3,165 2,992 0,000 0,497 -999,~50 3.123 3.1~0 0,000 0,947 -999,250 3.030 3,231 0,000 0,713 '999,250 3,330 4,763 0,000 0,698 .-999,250 3,079 3.128 0.000 0.794 -999.250 3,039 2.700 0.000 0.429 -999.250 3.205 2,405 0,000 1.071 -999.250 3.147 2,660 0.000 0.811 -999,250 cblumber~erAalasK ComputlnO Center D K P T. 5900" 000 R g 0 B, M w D ~Om~ ~WD ~53:,056 GR, ~.WD M ~i N .~. ~ W ~ 274,68 g GTC' M. ~qWD -999'.~50 NTCK, DFPT. 5~00.000 RHOB.MWD C~bN..~WD 8 .~5 wPHI.MWD ROP MWD 3~09 GR,MWD G CK ~wD 1 (}00 NTCK.~WD t~pT. 570o.ooo C~N MWD 8'507 NP~I'~WD H:~N ~ .MWD 268,500 HEF~.MWD GTCK.~WD -999,950 NTCK,~WD DEPT. 5600.000 CA L~' MWD ~.. 500 NP~I. ~WD ~Om[~WD 104.653 GR.~WD HEN~a.MWD 264.000 GTCK.~WD -999.~50 NTCK.5~WD DFPT 5500.000 POP.~WD 25~.5{ 7 GR.MWD H~'Na ~WD 279,~25 HEFA.MWD G. CK MWD -999.~50 NTCK MWD DEPT. 5400.000 CaLN.MWD 8.688 NP~I.~WD ROP. ~WD 95.20] GR.~W~ HE%I.~ , ~W'D 262,750 HEF~,NWD GTCK.MWD -999,250 NTCK,~WD DFPT, 5300,000 HFNa .~WD 279.500 HEF~.,WD GTCO. ~WD -9~9. 250 NTCK. DEPT. 5200.000 C~I.~'. ~WO 8.500 ~PHI. ~WD ~OP. N~WD ~38. 440 GR. HFNa.NWD 266.500 HEFA. ~WD GTCK.~WD -999.250 NTCK.MWD DEPT. 510n.OOO RHOB.UWD C~LN.~wD 8.695 POP,,WO 291,6~0 GR. GTCK .~WD -999,250 NTCK, ~{wD 22-JAN-~993 08:38 5.747 T~B.~WD -999.~50 DTC~ .MWD 2.~51 DRMQ.~WD 4: ~. 900 85.811 NSI.:~WD 5 ~7 ~, 259 D R 'H 0. ~ W D 36.4:72 73.987 NSI. 6.155 TAB ~WD -999.250 DTCK:~WD 2.239 DRHO..MWD 40.,900 ~A.,~WD 77.731 NSI.,MWD 5.596 TAB.~WD ~.000 DTCK.~WD 8 1 6 95 TA, B.~WO 90.109 5.673 -999,~50 DTCK. ~WD ~ 200 D~HO. 35~789 ~. MWD 571096 NSI. MWD 6 463 -999:250 DTCK.~WD 2.~72 DRHO. ~Wg 64.8~9 NSI.'~WD 6.162 ~ .000 DTCK.UWD 2 B24 36:400 RA.MwD 6~.417 6.138 T~B.~WD -999.~50 DTCK.~WD -0.002 3,802 0.,000 0 ~ -9992 50 -0 016 ] 745 0 00~0 0 580 -999 250 , -0,006 000 0.483 -999.~50 -0 ~16 3.! 36 0 000 0 2 0.000 0.456 1.000 0.006 3 198 0~000 0.636 -0.016 5.009 0.000 0.697 -999.250 -0.009 4.468 1.000 0.397 1.000 -0.004 5.012 0.000 0.423 -999.250 PEF.MND RP.MWD RSI.MWD TABD.MWD RTCK.~WD RP.~'WD RSI.~WD TABD.~WD RTCK.~WD PEF.~WD RP.MWD RSI.~WD TABD.MWD RTCK.MWD PEF ~WD R$I.MWD TABD.MWD RTC~.~WD PEF.MWD RP.~WD RSI.~WD TABD.MWD RTCK.~w9 P~F.~WD RP.~WD RST.M'WD TABD.MWD RTCK.~WD PEF.M~D RP.MWD R$I.~WD TABD.MWD RTCK.MWD PF~FoUWD RP.~WD RST.PWD T~BD.MWD RTCK.~WD PEF.~WD RSI.MWD TABD.~WD RTCK.MWD PAGE: 11 ~.310 .887 0.000 0.744 -999.250 3,168 3.626 t.000 1,008 -999.250 3.217 3 625 0:000 0896 -999~250 2.856 2'953 0,000 1.122 -999.250 757 0,000 .99~ '006 ,:250 3.5~9 3.379 0.000 0.908 -999.250 3.008 5.416 0.000 1,264 -999.250 3.017 3.878 0.000 0.999 -999.250 3.326 4.828 0.000 0.687 -999.250 IS Tape yeri. flcatlon Listlno ichlumberoer A!asK ComDutlnC Center sooo.ooo RHOB. ND 5oo HENA,NWD 265,157 HEFA.~WD 1.ooo zc . wn DEPT. 4900,000 ~HOB,.MWD H~N,~,~WD 265,750 GTC~,MWD 1,000 NTCK,MWD D..,,PT 4800 000 RNOB' ~ W D C~LN,~WD 8,500 NPHI,~WD ~OD.,MWD 445,749 GR.,M'WD H~a,~WD 265,500 HEFA,~WD GTCK MWD -999,250 4rCK,MWD D~PT, 4700,000 ~'HOB,MWD ~D 8.91.0 C~['"N'~WDROP, 221..915 GR.. WD HEN~a,MWD 265,75(3 HEFA, ~WD GTC~.MWD -999,250 NTCK:~WD DEPT, 4600,000 C~bN. MND 8. 867 NPHI, ~WD ROP, ~WD 458,179 GRo MWD H~N'~.~WD 249.500 HEF,~,NWD GTCK,,WD -999,250 NTCK,~W9 DEPT, 4500.000 C~LN,.MWD ~.995 NPNI,~WD DOD.M'WD 116 ~30 GR.,~WD HENA,~WD 268~u37 HEFA.MWD GTC~,MwD -999,250 NTCK,MWD DFPT, 4400,000 RHOB.MWQ CaLN,MWD 8,5~6 NPHI,~WD ROD,~WD 381,162 GR.NWD M~Na..~WD 271,333 GTCK,MWD 1,000 NTCK.~.WD DE~T, 4300,000 CaLN.. , ~wD 8. 640 NDHI,~WD.. ROD,~.~WD 273,826 GR,~WD HENS,~W~ 270,246 MEFA,MWD GTCF.~WU -999,P50 NTCK,MWD DEPT. 4200,0~0 C.SLN.M%~D 8,570 NPNI,~WD ROD.~WD 55,3.737 GR.~W~ H~NA.~WD 257,750 HEFA..¥WD CTCK.~W~ l,O00 NTCK.MWD 22'JAN-J993 05:38 5~,325 N~I,.MWD 5 763 TAB,~WD -999~250 DTCY,MWD 2,2~9 DRHO,~wD 36.300 53,575 N$I.:,~WD 6,045 TAB,MW~ -999,~50 DTCK,MWO :5~, 8 NSI,MWD 6 0~3 TAB.,~WD 1:0 0 DTCK,~WD 2,4.31 DRHE1,MWD 364.~00 RA,MWD 5,8~0 NS~.'~WD: 6,~.49 TAB ~,000 DTCK:MWD 2.268 DRHO,:MWD 39 R MWO NSI.~WD 5,455 TAB,~WD '999,250 DTCK,~WD ~.254 37:92 NSI,MWD 6 ~.30 TAB,MWD -999~250 DTCK,MWD ?,029 DRHO.MWD 3~,200 34,912 NSI,~WD 5.0.30 TAB,MWO -999.~50 DTC~,MW9 38,800 RA,~WD 5~.47~ N$I.~WO 5,8~7 TAB,MWD -999.250 DTCK,~WD 2,319 40.200 54.496 NSI,~4WD 5,438 TAB,qWD -999,250 DTCK,HWD 0,0~4 7,1. 4 ~,.000 0,247 'g99,~50 0 ~08 0,000 °so 0.,000 8,069 1,000 0,278 -999,250 0'040 8,069 0,000 . 0,769 999'250 0.018 6.71 0.000 0,758 1.:000 0.001 12.457 0 O00 0:847 -999.~50 -0026 8:452 1.000 0.,469 -999.~50 0.004 ~0,907 0.000 0.536 -999.250 -0.008 2~.756 ~.000 0,924 -999,250 PEF,MWD RP,MWD RSI,MWD T~BD,~WD RTCK,MWD PEF.~WD RP,~WD RSI,~WD TABD,~WD RTCR,~WD R$I,MWD T~BD,MWD RTCR,MwD PEF,MWD RP.~wD R$I.MWD TABD.~WD RTCK,~WD PEF, WD RP,~ND RSI,MW'D TABD.WWD RTCK,MWD PEF,MWD RP.~WD TABD.~WD RTCK.UWD PEF,MWD RP.NWD RSI'.~WD T~BD,~WD RTCK.~WD PEF.MWD RP.MWD ~$I,MWD TABD,~WD RTC~.~WD PEF,~WD RP.~WD RSI,~WD TABD,MWD RTCK,~WD PAGE: 12 3,047 6,562 0,000 0 753 3,053 1.2.554 I ,O00 -999, 0 3,051 7,.482 0,.000 0,985 1,000 I:ooo . o4: 250 3,801 6.326 0,000 1.381 1.000 4.513 1.3,499 1.000 1,816 1,000 2,675 B,465 O.O00 1.052 -999,250 3,623 10,296 1,000 1.056 -999,250 3.380 16,734 1,000 1,471 -999.250 ~chlumberqer i !aska Comput nq Center 22-JA'N-1993 08:38 PAGE: DEPT. 4100,000 RHOB.MWD WD CALN'.MWD 9,136 POP,~WB 603.950 HFNA.~WD 227,750 GTC~'.~WD 999,2'50 NTCK,MWD CaL~,MWD 9:,5~2 NPHI,~WO Pi3~,~WD 546,,305 GR;,NWD ~EN~.~W:~ 249.000 HE,&. . GTCK'.MWD -g99.250 DE.PT, 3973,000 RHOB.~WD C~LN. MWD ~. 741 !qPNI. MWD ROP. ~'WD -999, ~50 H~N~ ,:~WD 232.750 GTCO. ~wD 1,000 N'TCK. MWD END (}F DATA .251 4 .900 32.648 4,740 1,000 37 43 0 45 ~45 5 0.45 -999 250 0 3 .5 6 '999, 0 DRHO,MWD NSI:,~WO TAB,:MWD DTCK,~WD DRHO,MWD R.A,~WD T.AB,MWD DTCM,~WD DRH0.~WD RA,~WD NSI,~WD TAB,MWD DTCK.~WD -0,005 PEF,~WD 12.565 RP,MWD 0.:000 RSI,~WD ,1,690 TABD.~WD -999.250 RTCK.~WD 4 035 13 620 0 000 0 442 -999 250 6,104 11'505 0,000 I .,809 -99g.250 '999.250 '999,250 0.000 2,355 -999.2,50 **** FILE TRAILER FIL~ NA~E : EDIT ,OOf SERVICE : FbIC V~RSI. ON : 001.~07 D,~T~ t 93101122 ~aX REC SIZE : I0~4 FILE TYPE : LO LAST FILE **** FILE HEADER FIL~ NAME : EDIT ,002 SERVICE : FLIC V~R$IO~ : 00IA07 DATE ~ 93/01/22 ~AX REC SIZE : ~024 FTL~ TYPE : LO L~ST FILE FILF ~EADER E~ITED ~ERGED Peuth shifted and CllDDed curves; ail bit runs merged. DFPTN INCRFMENT 0.~000 FILE SI.I~ARY ~Rll TOOT.~ CC)DE START DEPTH STOP D~PTH Tape VerlficatioD .bi. stinq) .{chlumherc~er Alaska Computing Cente'r 22.-aAN-~99,3 0~:38 ! 03OO. 0 10300,0 C D t~t 3973,0 CDR 3973.0 $ H~,SE,~I~': CURVE Fo~, SHIFTS: ~AsEbI'NE DEPTH M~R~ED DATA SOURCE KRU TOOL COD~ BIT RUN NO, MER. G~ TOP .......-..... ................. .......... ~WD ~. 3~7~,~ ~0 '0. 87 ~WD 2 9087,0 9500,0 ~WD 3 9500,0 1,0300.0 REMARKS: THIS FILE CONTAINS THE .~ERGED SAHPLING TICKS, # bis FORMAT DATA UNSHI.FTED'~ ''~ DEPTH---'------ PAGE: ** DATA FORMAT SPEC!FICATI~N RECORD ** ** SET TYPE -64EB ** TYPE EPR CODE VALUE i 66 0 2 66 0 3 73 4 66 5 66 6 73 1 65 8 69 9 65 11 66 13 66 ~¢ 65 15 66 !.~ 66 20 2.55 0 1 0 FT 68 o 66 emmmmmmmmmmmmmmmmmmmmmmmmmmmmm Tape Verification [.,istin~ ,cblumbercTer laska Compute. nO Center 993 0.8: 38 PAGE ** MET TYPE - (:HAM ** N~E SERV UNIT SERViC~ API AP~ API~ A~! FIDE NU~g Nl.i~ SIZE REPR PROCESS ID ORDER ~ hOG TYPE CI..,~S$ ~OP N~:I~M $~NP Eii, E~ CODE; (HEX) DEPT FT 618983 O0 000 O0 0 2 ~ 1 4 68 0000000000 GTC~ 005 $ 618983 O0 000 O0 0 2 I 1 4 68 0000000000 NTC~ 005 $ 618983 O0 000 O0 0 ~ 1 1 4 68 0000000000 DTC~ 005 S 618983 O0 000 O0 0 ~ I I 4 68 0000000000 , ** DATA DEPT, 3835 100 GTCK,O05 -999,:250 MTCK,O05 !,000 D.~C. ,005 RTCK,O05 -999,~50 DEPT' 3B99,900 GTCK'O05 -999,250 N'TCK,O05 -999,~50 DTCK],O05 RTC~,005 -999,250 DEiPT, 3900,100 GTCK,005 '999,250 NTCK,005 ~999o250 DTCK,005 RTCK.O05 -999,250 DMPT, 3999,900 GTCK'005 '999,250 NTCK,005 -999'250 DTCK.O05 ~TCK,~O05 -999,250 ., DEDT, 4000,100 GTCK.O05 '999,250 NTCK,O05 -999,250 DTCK,005 RTC~,005 '999,250 4099,900 GTCK.005 '999,250 NTCK,O05 ~,000 DTCK,005 DFPT, RTC~,O05 -999,250 ~ 4~oo.~o~ ~c~.oos -~gg.~so ~wc~.oos ~.ooo ~TC~.OoS RTCK:O05 -9~9.250 PT 41~9,900 GTCK.005 -999,~S0 NTC~,005 -9~9.2§0 DTCK,00S vc~:oos DEPT, 4200.~01 GTCK.005 -999,250 NTCK.O05 -~99,250 DTCK,005 ~,c~.oo~ 1.ooo O~P'. 42~9,900 GTCK.O05 -999,~50 NTCK,005 -999.250 DTCK,005 ~p,. ~30o.~.ot ~Tc~.00~ -999.2~0 ~TC~.00S ~.000 OTC~.00S RTCK.005 -9Q9.250 DE~T. 4399,900 GTCK,005 -q99.250 ~{TCK,005 ~.000 DTC~.005 ~TC~.005 -9o9,250 D~PT. 4400,10). GTCK,O05 -999,250 ~TC~,005 -99~.250 DTC~,005 ~TC~.005 -999,250 -999,250 -999,250 -999,250 '999,250 -999,250 -999,250 -~99,~50 -999,250 -999,250 -999,250 -999,250 -999,250 ?aVe Veri.flcatlon ;chlumberger A!as~a Computino.. Center D~'PT 4,499.900 CTC~.OOS DEPT, 4,500,101. GTCK.O05 ~wC~'.o05 1,.000 D~PT, 4599,900 GTCK,O05 RTcK'O05 DFPT 4600,~01 GTCK 005 DEPT,: 4609,900 GTCK,OO5 RTCW,O05 -999,250 DEPT 4700,101 GTCK,O05 R,c~l°os -9~9.250 D~PT, 4709,900 GTCK,O05 RTC~,O05 -999,250 DEPT, ~00,1.01 GTCKo005 R*CK,O05 -999,250 DEPT. 4~09,90() GTCK,O05 RTC~.O05 -999,250 O~PT :900.~01 GTCK,O05 RTcKiO05 909, 50 D~PT, 4999.900 GTCK.O05 RTC~,005 -999,~50 t,)~, sooo lol a,cK.oos RTC~:O05 '999:250 D~P*. 5099.900 GTCK,005 R'C~.OOS r)~T. Sloo.~o~ ~C~.0os DEPT, 5199.900 GTCK,005 RTC~.O05 -999.250 ~:p,. s~oo.~ol ~TC~.Oos ~rC~.OOS -999.~So DEPT, 5299.900 GTCK.O05 22-JAN-lg93 08:38 -099,250 t{TCK,O05 '999,250 NICK,005 '999,~'50 NTCK,O05 -999,250 NTCK,O05 -~.~o ~?c,~'oos -~99'~o ~c~.oos -999,250 NTCK,OO5 -999.250 NTCK,005. 1.000 ~TCK,O05 ~,000 NTCK,O05 -999'250 NTCK,O05 -999,250 NTCK'O05 -999,750 ~TCK,O05 -999,250 NTCK,O05 -999,250 NTCK,O05 -999,250 NTCK,O05 -999.~50 NTCK,005 '999,,~50 ~...000 ~999',~50 .. -999,~50 -999,~50 ~999.250 -o~.~so -99~.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 DTCK,005 DTCK.O05 DTCK.O05 DTCK,O05 DTCKoO05 DTCK,O05 DTCK,O05 DTCK,005 DTCK,O05 DTC~,O05 DTCg.O05 DTC~.O05 DTCK,O05 DTCK,O05 DTCK.O05 DTCK.005 DTCK.O05 PAGE: 16 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 1,000 1,000 -999.250 TaPe Ver'i~Icat,ion biStrina ~chl..,,~mber,~er Alaska ComPutin~ Center OEPT ~c~2ooS D~PT. RTC~.005 ~TC~'O05 DE~T.' ~¢~.oos R~C~.O05 ~c~2Oos DEPT. RTCK,005 DEPT ~TC~]005 DEPT. Rq"C~. 005 ~EPT DEPT. RTCK.005 D~PT DEpT RTCK:005 DEPT, RT¢~.O05 , RTCK.O05 DEPT. ~CK.O05 . ~T¢~.005 -999,250 ~400,101 GTCK.O05 999,250 5499,900 GTCK,005 -999.250 5500.10~ GTCK.005 -999.250 5599,900 GTCi.005 -999.250 56OO -999,250 5699,900 GTCK,005 -999,25{) 5700 101 GTCK,005 -999225{) 5799,900 GTCK.005 1.000 5800.~01 GTCO.005 -999,250 58.99 gOO ~.,,]~CK 005 1,000 900 101 GTCK 005 ~9~.~:~5o ' 5999.900 GTCK.O05 -999.250 6000.1Ol GTCK,O05 -999,250 6090,900 GTCK.O05 -990.250 6100,101 GTCK.O05 -99q.250 6199.90o GTCK.O05 -999.250 22-JAN-1993 08:3~ ,~. o o o ~ m c,~. o o s -999,250 NTcK.005 -999.2,50 NTCK,O05 -999.250 NTCK.O05 -999.25o -999,250 NTCK.:005 -~. ~$o ~TC~<:.Oo5 -999.250 NTCK,O05 -999.250 ~TCK.O05 '999,250 NTCK.O05 -999,250 NTCK.O05 -999o250 NTCK.O05 -999.250 NTCK.O05 -999.250 NTCK.O05 -999.,250 ~TCK,O05 -990.250 NTCK.O05 -999.250 STCK.O05 1.000 NTCK,O05 -999. 250 -999.250 -999,250 -999 .:250 -999.~50 '~,~so -999.250 1,000 1.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DTC'K.O05 DTCK.O05 DTCK.O05 D..CK OO5 DTCK, 005 DTCK, 00,5 DTCK. 005 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK,O05 PAGE: I7 -999.250 -999.250 -999,250 '-999.250 - 999.250 -999,.250 -999",250 -999,250 -999.250 -g99.250 -g99.250 -g99.250 -999.250 1,000 1,000 -999.250 -999.250 -999.250 ,,lis Ta.~e Ver.f. fication !.,istf.~n~ ;chlumberger: ~lasKa Computin~ Center DEPT. 6200.10! GTCK.005 RTCW.00B -999.250 PEET. 6299 ~no ~?cK.,~O~ ~TCK.005 oep?, 63oo,iol ¢TC~,O05 RTCK.O05 -999,250 9MP:T, 6399,900 GTCK.O05 ' M 005 999,250 ~tC., OF.!~T 6400,~01 GTCK,O05 RTL ~005 -99:9 250 DEPT. 6499,900 GTCK'O05 RTCW,O05 -999,250 DE:PT . 6500,I0~ GTCK.O05 ~TC~:: 005 -999. 250 DEPT, 6599,9~0 GTCK,O05 RTc~.O05 -999.250 DEPT, 6600,101 GTCK'O05 RTCK,O05 -999,250 DEPT, 6699'900 GTCK,005 RTCK,005 DEPT 6700,I01 GTCK,005 RTC~i:005 -999,250 DFP?. 6799,900 GTCK,005 RTCK,005 DMPT, 6~00,~01 GTCK,O05 R~CK,005 -999,250 ~EPT', 6~99,900 GTCK,005 RTCK,005 DEPT., 6900,~01 GTCK.005 RTCW,005 -999,250 DFPT, 6999,g00 GTCK,OO5 RTCW,0G5 -99g,250 DPPT, 7000,~01 GTCK,005 RTCM,005 -999,250 22 JAN-1993 08:38 1.OOO NTC~.O05 -999.~50 NTCK.O05 -999,250 NTCK.O05 -999.250 MTCK.O05 ~.000 NTCK.O05 -'999.~50 NTCK.O05 1.000 NTCK.O05 l.ooo ~TC~:.OO5 '999.~50 ~TCK.O05 '999.250 NTCK.O05 -999.250 NTCK.O05 -999.~50 NTCK.O05 -999.250 NTCK.005 -999.250 NTCK,005 -999,250 NTCK,005 -999,250 NTCK,005 -999.250 -999.950 -999o250 '999.~50 '999.~50 -999.~50 -999.250 -999'.~50 -999.~50 '999.~50 -999'250 -999.~50 -999.250 1.ooo -999.250 -999.~50 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 D C .OO5 DTCK,OO5 DTCK.OO5 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~0 -999.250 ~999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~I5 ~aPe Verl~!¢atlon Lis~imo 5chl, umberger AlasKa Computlm6 Cent. er DEPT, RTC~. 005 D~PT RT~:OO5 I)~PT ~c~Oos DEPT, ~TC~.oO5 DMPT ~TC~:OOS D~PT. R~C~.005 DEPT, RTC~.O05 RmCK.O05 DVPT. RTC~.O05 D~PT RTCW.O05 DE~V. ~TCK,OO5 RTCY.O05 DFPT. RTCK.005 DFPT. RTC~.O05 ... R?~,O05 7099.900 GTCK.O05 -999.250 7100.101 GTCK.O05 -999.250 7~99.900 GTCK.O05 -999.250 Z200,101 GTCK.O05 999.250 7~99.900 GT.,~K.O05' C 7300,101 GTCK.O05 -999.~50 7399.900 GTCK.O05 -999.250 1400.101 GTCK.O05 999. 50 7499.900 GTCK.O05 -999.250 7500.10! GTCK.O05 -999.250 7599.900 GTCK.O05 -999.250 7600.Inl GTCK.O05 -999.250 7699.900 GTCK.005 -999.250 7700,101 GTCK,O05 -999,250 7799,900 GTCK,O05 -999.25{) 78A0.101 GTCK.O05 -999.250 78q9.900 GTCK.O05 1,009 7900.101 GTCK.O05 -999.250 22 - d A N-,~, 99,3 08: 3 B -999.250 NTCM,O05 -999.~50 NTCK.O05 '999,~50 NTCK,O05 -999,~50 NTCK,O05 - 99 O. 250 N T C K. ,005 c ,oos -999,250 NTCK,,O05 -999.250 NTCK.O05 '999.250 NTCK.005 -~99.2so ~TC~.OOS -999'~$o ~TC.~.OOS -999.250 ~TCK,O05 "999,250 NTCK,O05 -999.250 NTCK,O05 -999.250 NTCK.O05 -999.250 NTCK.O05 1,000 NTCK,O05 -999.250 NTC~.O05 -999.~50 '9~9,~So -999 1.000 1. Ooo '999.~250 -g99.250 - 999.250 -999 .'250 -999.250 i999.:250 -999.~50 -999.250 -999.~50 -999.250 -999.250 -999.25o DTCK, 005 r c <'ooS D T C K. 005 DTCK .005 DTCK.O05 DTCK.O05 DTCK.O05 DTC~.005 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.005 DTCK. O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 PAGE: 19 -999.250 -999.250 -999.250 -999,250 '999,250 -999.250 -999,250 :-999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1.000 -999.250 bls TaPe Verif~,,cat~,on Llst.i.O ~chlUmberger AlasKa ¢omp~ltino Center !J~ T. 7999 900 6TCK 005 ~TCg.O05 -999'250, DEPT. 8000,10~. GTCK,O05 RTCK. 005 I , 000 DKPT. 8099,900 GTCK.O05 RTCK..O05 -999,250 DEPT. 81.00,101 GTCK.O05 ~TCK.O05 -999,250 DK:PT, 8199,900 GTCK,O05 RrcK.O05 -999,~:50 8200,100 GTCK,O05 DEPT, RTCK'.005 -999.250 D~PT 8299.900 GTCK,005 RTC~O05 -999,250 D~PT. ~300 ~0:0 GTCK, 005 RTCW.O05 999: 5() DKPT, 8309.900 GTCK,O05 RTC~',O05 -999,~50 DKDT' 8400,1.00 GTCK.O05 RTC~.O05 -999,250 D~PT" ~499,990 GTCK,O05 ~TCF,O05 -999.~50 OEPT. 8500.1~0 GTCK.O05 RTCK,O05 -999.250 DFPT. 8599,900 GTCK.O05 RTCW.O05 -999,259 DWDT. R6OO.JO0 GTCK.O05 ~'rC~.OO5 !.000 DKPT, 8699.900 GTCK.O05 RTCK,OO5 DEPT. 8700,100 GTCK.O05 PTCK.O05 -999,250 DEPT. 8709.900 GTCK.O05 RTC~.O05 -999.250 22-jAN'1993 08:3,~ '999,250 ~TCK,O05 -999.250 NTCK,O05 1.000 ~TCK'O05 1,000 NTCK,O05 ~,000 NTCK,O05 -999,250 ~!TCK,O05 l,O00 NTCK,005 '999'~50 NTCK,005 '999,~50 NTCK,O05 '999,~50 NTCK,005 -999,~50 NTCK,O05 '999.~50 NTCK.O05 '999,~50 NTCK,O05 -999.250 NTCK,O05 -~99.250 NTC~,O05 -999,250 ~TCK,O05 -999.~50 NTCK,O05 -999.250 '999,~50 -999,.~50 . -999.250 -999.250 '999',~50 -999.:250 '999,:~50 -999,250 -999.~50 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 DTCK. 005 DTCM.O05 DTCK,O05 DTCK.O05 DTCK.O05 DTC~.O05 DTCK.005 DTCK,O05 DTCK.O05 DTCK,O05 DTC~.O05 DTCK.O05 DTCK.O05 DTCK.005 DTC~.O05 DTCK.O05 DTCK.O05 PAGE: :20 -999.250 -999,250 -999,250 -999,250 -999'250 -999.250 -999o~50 1,000 1.0oo -999,250 1,000 -999,250 -999.250 -999.250 -999.~50 -999,250 Tame Verlficatiom I, istinO ,~cblumberqer AlasKa Computi~o center 8800.1.00 GTCK.005 D:EPT RTCW:005 -999.250 DEPT' 880~,900 GTCO,005 RTCK.005 -999.250 RTCK~005 999. 50 ooo. oo G CK.OOS RTC~:005 999.250 DEPT. ~099.900 GTC~.O05 RTCg.005 -999,250 ~EPT ~,00.:100 GTCK,005 ~TC~::005 999.250 , , DE~T. 91~9,9:00 GTCK.O05 DEPT 9200,100 GTCK.005 RTC~]005 -999,~50 DEPT, 9299,900 GTCK'005 ~TCK,005 DEPT, g300,1()0 GTCK,00§ RTCK,005 -999,250 DEPT.. 9399.900 GZCK.005 RTCK,0O5 -999,250 D~PT 9~00 100 GTCK,00§ RTCW]O05 DE~T. 9499.900 GTCK.005 DE~T 9500.100 GTCK.005 RTCW:0O5 -999.250 D~PT. 9599.900 GTCO.005 ~TC~.005 -999.250 DF~T. 96©0.{.00 GTCK.O05 ~TC~.O05 1.000 D~T. 9699.900 GTCK.005 RTCK.005 -999.250 22..JAN-1993 08:38 =999'250 NTCK,005 -999,~50 NTCK,005 -999,250 NTCK,005 -999.250 NTCK,005 -999.~50 NTCK,005 -999.~50 NTCK,005 -999,250 NTCK,005 1.000 NTCK,O05 1.000 NTCK'005 '999'250 NTCK,005 '999,250 NTCK.005 -999.250 NTCK.005 '99g.~50 NTCK.005 '999.250 NTCK.005 1.000 NTCK.005 '999,~50 NTCK.005 '999.~50 NTCK.005 '999.250 NTCK,005 -999.250 -999'250 -999.250 -999'~50 -999"~50 -999"250 -999:'250 -999.~50 -999.250 -999.250 ~999.~50 1.000 1.000 -999.~50 -999.250 -999.250 DTCK,005 DTCK,O05 DTCK.005 DTCK,005 DTCK.005 · DTCK.005 DTCK,005 DTCK.O05 DTCK.O05 DTCK.O05 DTCK,O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 DTCK.O05 PAGE: -999.250 -999.250 -999.250 -999,250 '999'250 .sgs. So '999,250 -999,250 -999.250 1.000 -999.250 -999.250 '999.250 1.000 1,.000 1.000 -999.250 1.000 bis Tan, e ~ert~ication ~,istinq ~chl. umber~er Alaska comput.~.n0 Center DEPT 9700.t00 GTCK.005 RTCK:005 1.000 , ~ 9799 90o ~CK.OOS RTCK:005 -999:250 D~DT, 9800,100 GTCKo005 RTC~.00s DFPT. 9899,900 GTCK.005 RTCK.005 -999,250 DEPT. 9900.1.00 GTCK.005 RTCK,005 -999,250 DEPT. 9999,~:900 GTCK.005 RTCK.005 -999,250 DEP?. 10000.100 GTCK.005 RTCK.005 t,000 DEPTo~ 10()99 900 GTCK.005 RTCR,O05 -999~25Q O~eT.~ ~0100.100 G~CK.005 RTCK.005 -999,250 OFPT. 10199,900 GTCK.O05 ~?¢~.005 1.000 DRPT. 10200,~00 GTCK.005 RTCK.O05 -999.250 ~TC~.005 1.OO0 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FL!C VERSION : 001~07 F!t,~ TYPE ~ LO LaST FILE ~ 22-dAN-1993 08:38 1..000 NTCK,:005 -999,250 NTCK,005 1,000 NTCK.O05 1,000 MTCK'005 ~'000 NTCK"O05 -999,250 NTCKoO05 -999'250 NTCK,O05 !.000 MTCK,O05 -999.~50 NTCK.005 1,000 NTCK'O05 1.,000 NTCK,O05 -999,250 NTCK.005 -999.250 1. 000 1-000 -999.250 1,. 00 O' '999" :250 -999.250 -999.250 1,000 -999.250 1.000 -999.250 DTCK.005 DTCK, 005 DTCK, 005 DTCK.005 DTCK,005 DTCK.005 DTCK,005 DTCK.005 DTCK.005 DTCK. 005 DTCK. 005 DTCK.005 1,000 -999,250 -999,250 1,000 1.000 1.000 '999.250 '999,250 -099,250 1.000 -999,250 -,IS Tame ver{,flcatlon biSt]~q ~Chlumberqer ,A3. asKa Comp!,~tl~O Center 22'JAN-1993 08:38 PAGE: 23 **** FILE HEADER **** FIL~i NA~E : EDIT SERVICE : Fb!'C VE~!$IOM : 001A07 DAT~7 : FILE TYPE ~ LO b,~ST FILE RAW: NWD , Curves and log header data for each bit run In separate fil, es. BIT RU~; NUMBER: ~ DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH 973 LOG f"{EADER DATA ~ATE bOGGED: SOFTWARE~ SURF,ACE SOFTWARE VERSION': DOWNHObE SOFT~ARE VERSION: DATA TYPE (MEMORY OR RE~L-TIME): TD DRILLER TOp LOG INTE~VA[~ mOTTO~ LOG INTERVAL (FT): ~IT ROTATIMG SPEED ~{OLE INCLINATION (PEG) ~IN!~!J~{ ANGLE: MAXI~!.,~~ ANGLE: TOO[, STRING. (TOP TO BOTTON) VENDOR TOOB CODE TOOL.TYPE CDR ~ESISTIVITY $ BO~EHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): [)RIbbERS CASING DEPTH (FT): ~OREMOLE CO~DITIONS ~UD TYPE: ~UD DEMS!TY (LB/G): ~UD VISCOSITY STOP EP:rH 9087.0 9087,0 PT-DEC-9~ FAST2,] ~E~ORY 9087,0 ~973,O ~087.0 ~GSo58 8 49o ~chl. umber~er A.I~sKo Comput. ln.~ Cente.r 22-dAMmlg~3 08:38' ~uD PH: ~I.iD ¢~LORIDE$ (PPM) FSIJID bOSS (C3 R~SISTIVITY' (OH~ AT TE~PE~T'[3RE DEGF) MUD AT ~EAS..]~ED T._,~PE,RATU.~E, (,.T), ~UD AT g~X CI~CUL.~T'ING ~4UD FILTRATE AT ~T~ gUD CAKE AT ~EUT~ON TODL MATRIX: MATRIX DENSITY: HOL~ CORRECTION (IM): TOoL STANDOFF (IN EW[~ FREOUEMCY (MM) 2,020 1.7 3 o 65.0 SANDSTONE: 2.65 8, .500 ********** ********** ~[T TO [t~UT 139 4'.,:.DRILLED :IN:{~V[b ~97~' TO 9087 : TO MUD SYSTEM. D.~TA FRO~ DOWNHOL~: MEMORY, DOW SOFTWARE VERSION V4,0C, LIS FORe, AT DATA PAGE: 24¸ ** DATA FOR~tAT SPECIFICATION REC{3RD ** SET TYPE - 64ES ** TYPE ~EP~ CODE VALUE 66 66 ~ ~6 5 66 ? 65 8 68 ~ 65 11 66 1~ 68 13 66 ~4 65 1.5 66 16 66 6 0 6 i tm m mm ~im m m m tm mm mm mmm I im 0 0 68 0.5 15 0 FT ! 215 'Tape Verification Listing ~chlumberaer, las~a Computind Cente~ 22-JAN-I. 993 0~:,38 PAGE: ** SET T N'AM~ SERV UNIT' S ID O Y DEPT FT 61~9~ 00 000 O0 ~.MOB LW1 G!C:3 618983 00 O00 00 D~RO LW1 G/C] 6189831 00 000 00 PEF bW1 618993 00 000 00 DCAL LW~ IN 61~9~3 00 000 00 DPN! LW~ PU 6189~ 00 OO0 00 TNPH LW1 PU 618983 O0 000 O0 ATR LW1 ONM~ 61~9~3 O0 000 O0 PSR LW! O~M~ 618983 00 000 00 ~OPE LW1 F/H~ 618983 00 000 00 NE~A LW! CPS 618983 00 000 00 ~FA bW~ CPS 618983 00 000 00 T~B LW'I 6189S3 00 000 O0 TABD LW! 618983 00 000 00 NS! LWl 61~9~3 00 000 00 ~SI LW1 6189~3 O0 000 00 PC - CHAN ** ~VICE API API API ,APl F DER # LOG TY'P~ CLASS MOD N NUMB NUmB SIZE REPR P~OCESS SA~P EbE}~ CODE (HEX) 0 ] 1 1 4 68 O00OO00000 0 3 1 I 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 ! 1 4 68 0000000000 0 3 I 1 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 ~. 1 4 68 0000000000 0 3 1 1 4 6~ 0000000000 0 3 1 1 4 6~ 0000000000 0 3' 1 1 4 68 0000000000 0 3 ! I 4 6~ 0000000000 0 3 1 1 4 6~ 0000000000 O, 3 1 I 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 . 3 1 1 4 68 0000000000 25 DEPT. 9000.000 RHOB.LW1 DCAY,,.LWl -990.250 OPHI,.bW1 PS~.LW1 3,086 ROPE,LW1 HFF'~.LW1 0.OO0 TAB.LW! ~SI.[,~ 0.000 DFPT. 8900.000 RHOB.LWl DCAL.LWI 0.404, DP{!I.LW1 PSR.LW1 3,612 ROPE.LW! H~F~.LW1 4.863 TAB.LW1 ~ST.LWl 0.000 DEPT. RSO0.O00 RHOB.LW1 DCI{.,.LW1 0.329 DPHI.LWl PS~.Lw!. 2,032 ROPE.LW1 HEF~.LWI 5.798 T~B.LW1 RST.LW! O,OO0 DEPT. 8700.000 RHOB.LWt DCAI,.LWl 0.278 DPHI.LW! PS~.LWI 3,O76 ROPE,I.,w1 ~FF.~.LWI 6.649 TAB.LW! · ,999,'250 DRH0' [.~Wl -999. 250 -v9 ..25o wl -gv 250 76.231 GR:'LWt -9992250 -999.250 TABD.LWl -999.250 NSI:.t,,'~I -999.250 DRMO.LW1 '999.250 PEF.LWl "999,250 TNPH,LW1 -999.250 ATR.I.,W! 2 07.963 GR.LW1 191.069 HENA..LW1 0.653 TABD.LWl -999.250 NSI.LW1 2.406 DRHO.LWl 0.01! PEF.LW1 o.148 TNPH.L, Wl 48.500 AT,.Lw! 174.836 GR.LW1 ,15~.263 HENA.LWl 1.156 TAED.Lw1 9.030 NSI.LWl 2.4.21 DRHO.I,W! 0.002 PEF.LW1 0.139 TNPH.LW1 3~.000 ATR.LW1 74.999 GR.LWl 148.194 HENA.LW1 0.424 TA~D.LWl 1.97~ N$I.LW! 2.495 DRHO.LW1 0.004 PEF.LWl 0.094 TNPM.LWl 33.900 ATR.LW1 !47.545 G~.LW1 99.321 HEN~.[,Wl 1.457 TA~D.LWl 2.085 NST.LW! -999.250 -999,250 0.000 1.000 .250 0 000 1.000 3.966 2.821 256.750 0.000 3.147 1.859 262.500 0.000 3,711 2.928 2~3.000 0.000 ~chl, Umber.a, er Alaska Co,Put r~ Center DEPT PSR bW 1., ~, $.,T.. DFPT. DCAL', L~ 1. r~ST. LWl DEPT PSP. LW! HFFA.BW1 DEPT, DCAL.LW1 HFF~,LW1 ~SI.!.,Wl DCA. L.LW! HEF~,bWl DEp'r. HEleg~. hwl ~SI. !.,W 1 o'0oo 8600.00~ RHOB,,LWI ' 0,24.9 DP~I,LW1 3,~16 ROPEIr~Wt, 7.5o~ 0.000 8500.000 0,181 DPHI.LW! ],339 ROPE.LW~ 0'000 8400 000 0~000 DP~I!LWl 1.998 ROPE 0.000 8300.000 RHOB,LWl, '0,234 DPHI.LW! 0,fl39 ~OPE.LW~ 5,563 TAB.bW1 0.000 8100,000 RHOB,LWl 0.292 DPHi. LW1 3.263 ROPE.LWl 5.880 TAB.LW1 ~.000 8000. 790 780 000 RHOB.LWl 0.261 DPHI.bW! 2.561 POPE.LW1 5.733 TAB.LW1 0.000 0.o00 RHOB.LW1 0,200 DPHI.LW1 2,756 ~OPE.LW! 5.823 T~B.LW~ O.OOn 0.OO0 0..161 DPHI.LW1 1.774 ~OPE.LWl 5.873 T~.LW! 0.000 22-JAN-1993 08:38 2 ...460 D R H O, 'b :~ i 0.115 T N P H'. b W 1 159,2~I GR,LW1 0.7 2 TABD.:DWI 6 ?NPH. LW 1 1.61.3~0 GR.LWI 2.~B6 DRNO.Lwl 0. 60 TNPH.bW1 251,542 GR.LWl 0,389 TABD,LWl 2,494 DRMO.LWl 0 095 TNP~J.LW1 1.85~573 Gn.bWl 0.819 TABD.LWl 2,357 DRHO.LW1 0,178 T~PH,LW1 191.501 GR.LWl 0.536 TABD.LW:I 2.297 DRHO,LW! 0.214 T~P~.Lw1 18!.820 GR.Lwl 0.850 TA~D.I, wl 2.386 DREO.LWl 0.160 TNPH.LWl 173.201 GR.LWl 0,414 TABD.LWl 0.004 30,600 8 3,75 ! 1. 661 -0,00~ 32., 600 95,083 I.,910 0 . 009 36.900 1.03 428 0,0 40.6 0 99.093 1.612 37. O0 0 011 39:500 1.13.692 1.260 -0.030 37.600 139.328 0.886 -0.014 39.100 9~.085 !.294 -0.002 37.100 93.757 1.503 PEF,LM1 ATR,LWl HENA,LWl NSI,I.,W1 PEF LW 1 A T ~: L W 1 HEN A. L W ~l NSI.LW~, p, AT~,LWl H E N ~, . [, W 1 NSI ,LWl PEF,LWl ATR;.I,,W1 HENA.bW1 NSI.:Lw! PEF.LW1 ATR.LW1 HEMa.LW1 N$I.LWl PEF.I,wl ATR.LW! BENA.[,Wl N$I.bWl PEF,LW! ATR,LWl WEN~,LV;1 qSI,LWl PEF.LWl ATR.I,Wl HENA.LW! NSI.LWl PAGE: 26 O98 293.000 o.o0o 3,271 2,556 284,08 3 0,000 2. 6 266. 500 1,000 .3,076 '~ 250 2s :o 0.000 3.634, 2.738 270.750 0.000 3 789 3!348 274 250 0.000 3.241 2.455 269.500 0.000 3.482 2.095 280,500 0.000 3,499 1.879 273.000 0,000 5iS Tare Veriflcati"°n°mputi. ngC 5chlumheroer AlasKa Center D~PT. 7700.000 D ¢ a I,., ,. [, W'I 0 216 pSU,.LWi 3~568 ~SI~ W~. 0,.000 DEPT, 7600, OOO DC~.L. LWl O. 260 PSR,LWl 2.989 H~F~ [,W~ 6.'762 DEPT. 7500,000 DC.~L,LWl O, 168 PSR.LW~ 2,6~9 ~ S I. L W 1 0 ~ D~P~. 7400 PS~. LWl 2' 977 N~F~.LW1 6,630 7300 · ooo nwl 2: HEFa.LWl 6.609 ~SI.LW~ 0.000 DEPT. 7200.000 D C ~ l.,. b ~ 1 0. :121 HEFA.LWl 6.269 ~Sr.LWl 0,000 DEPT. 7100. 000 DC~.L.LWl 0.212 PS~.Lwl 2. 875 HFF~. LWI 6. 755 ~SI .LW1 0.000 DWp?. 7000.000 GCAL. I, Wl 0. 025 PS~.LWl 2.975 HEFB ,LWl 6,99~ RSI,LW1 0,000 DEPT, 6900,000 DCA f.., LWl. 0,046 ~SR,L~I 2,665 HF~ .LW1 6,961 ~SI. LW 1 0. ROPE.LW1 RHOB,LWl DPHI.LW1 ROPE'L~I TAB.LW1 RHOB,LW1 DPH'I..LW1 ROPE,LWl RHOB.:L,~' 1 D P H I, :b W 1 ROPE.LWl RHOB,LWl DPNI.LW! ~OPg,hWt T~B,LW1 ~HOB.LWl DPHI,LWi ROPE,LWl T~B.LW! DPHI.LW1 T~B.LWl RHOB,LWl DPMI.LW! ~OPE.LW~ RHOB.LWl DPMI.LW1 mOPE.LW1 T~B.LWl 22-JAN-1993 0.8:38 2,438 DRHO.,h~I 0,129 TNPN'LW'I 1.69,821 GR,b~l 0,280 TABD,LW1 2.367 DRHO,[~Wl 0.171 T~PN.LWI 142.856 GR.LWl 1.012 TABD,LW1 2.3~8 DRHO.Lw1 O.l. 1 TNPH.bW1 274.310 ' GR..L, Wl 0,545' TABD,LW1 2,391 DFHO.bWl O' 157 T~{PM. LW 1 221. 188 GR.LWl O. 413 TABD. bWl 2,374 DRHO.LWl 0,167 TMPH.LW1 274,017 0.331 TA~D,LW1 2.325 DRHS,Lwl 0,197 TNPH.LWl 320,564 GR.LWI 0,357 TABD.LW1 2.314 DRHO.LW1 0.204 TNPH.LWl 367.066 GR.LWl 0,733 TAB~.LW1 o,Ooo .625 0.733 0 007 34~900 84.336 1.13t 0 0 O9 92 089 1.784. ]0.003 5.700 1.00.725 1..420 o: o7 ~3 O0 91.440 1,066 -0 001 37!400 90 704 0.969 -0,006 34.700 86.406 0.755 -0.011 33.000 86.353 0.664 0.004 33.000 78.042 0.958 ATR:.bWl HENI.LWl ~$l.LWl PEF,LW1 ATR.LWl MENA.LW1 PEF.LWl HENA.LW1 NSI.LWl PEF'LWl ATR.LWl HENA.LW1 PEF.LN1 ATR,LW! HENA,LW1 NSI.LW1 PEF.LWl ATR.LW1 HENA.LWl NSI.bWl PEF.BW1 ATR.LWl HENA.L~I NSI,LW! PEF.LW1 ATR.LWl HENA.bWl ~$I.LW1 FEF.LW! HENA.LW1 NSI.LW1 PAGE: 27 3,461 3.512 287,000 0,000 3,51.4 896 0,000 3,072 2,748 277.500 0,000 i!409 980 27 1750 0.000 3 254 2~ 480 277,. 500 0,000 3.226 8:250 0.o00 3.1.93 2 978 28R:000 0.000 2.973 3.130 290,131 0.000 3,144 2.821 286,750 0,000 ~c~lU~beraer ~laska ¢omoutln~ Center D~PT. 6800.000 RHOB,bW:! DC,~L, [.,W I 0,000 PS~,LWI 3.599 ROPE:,LW 1. H~F~.LWl 7.0~ 5 TAB.LW ~S~.LW~ 0,000 D~PT. 6700,000 RHOB'.LN~ DCAL.LWI 0~06~ MF'F~., LW1 6' 770 sz.nw o.ooo 600' ooo PS~,LW1 30~3 ROPE,L~I ['i EF ~{. LW 1 6.7 ~ 0 T.~B. bW ~SI:. bWl 1.000 , D~PT 6500,000 ..SW~LW1 3.I~1 ROPE.LWl },t:EF ~ LW1 6,865 T~B,LW1 ~SI,LWI O.OOO D~P~'., 6400,000 RH~B,LWl DCAL.LW1 0.000 DP I.LWl ~S~.LWl 3,750 ~FF.~.LW1 7.~63 T~ RSI.LW1 0.000 DEPT, 6300,000 RHOB,bWl DCAL.LWI 0.048 DPHI..LW1 PS~.LWl ~ 952 ~OPE 5Wl H~.FI r~W'l ~965 TAB,LW1 RSI. LWI 0,000 DFPT. 6200,000 RHOB.LWl DCIL.!.,W1 0,000 PS~.I,Wl 3,122 ~OPE,LW~ HEFI.[.W1 6.473 T~B.LW1 ~S~.LW1 0.000 DEPT. 6100.000 RHOB.LWI DCAL.LW1 0.000 DPMI.LW1 ~S~.LW1 2.244 ROPE.LW1 HFFA. LW1 5.973 PS!. LW 1 o. D~PT. 6000,000 DCAL. LW 1 O. 000 DP~I. LW 1 ~S~.LW1 ~.759 ROP~.LW3 HmFa. Lw1 5. 995 TAB.LW1 RS!. [,W ! O. 000 22'JAN-1993 08:3~ ~.30! D~MD.LWl 0.211 TNPH,,:LW1 412,464 0,444 TA. BD,LW! O, 97 TNPH.LW1 374.,379 GR.LW! 0.31I TABD.LW! ~.:328 DRHO,L:Wl ,195 TNPH,LWl 192,955 GR-LW1 0,565 TABD,LW! 2,288 D~HO,LW1 0,220 TNPH,LWl 316,518 0,~69 TABD,LW1 2.~91 D..HD,LW1 !!2:18 TNPH..LWl 1t i 318 GR,~W1 35? TABD.LW1 2.315 DRHO,Lw1 0,~03 TNPH,L'Wl 397,367 GR,LWi 2.294 DRHD.LWI O.P16 T~PM.LWl 410.435 G~.LWl 0.165 TABD.SWl ~.~75 DR~O.LW1 0.38! TABD.LWl ~.~67 DRHO.Swl 0.232 T~P~.Lwl 197.406 G~,LWi 0.001 32. 500 93.24~7 0.703 0.001 34.000 90.997 0,520 '0.011 33,400 81.~91 .47~6 0.724 0.009 ! .100 87 .::852 0.688 -0.004 9000 4:060 0.795 -0.010 34.600 92.721 0.429 -0.013 37.900 84.922 0.732 -0.005 38.400 81.424 0.806 PEF,LW1 ATR.LWl HENa.LW! NSI.LWl PEF.LW! ATR,L'Wl H~NI,LWI NSI,LW! PEF.'L'Wi ATR,LWl HENA.LWl NSI.LWl P E F. L w 1 ATR NSI. LW 1 PEF .L W 1 NSI.LWl PEF.LWl AT~.LWl HENA.Lwl NST.LW1 PEF.LW~ ATR.LWl HENA.LWl NSI.LWl. PEF.LWl nTR.LW1 HENA.Lwl NSI .LW! PEF.LW1 ATR.LW1 HENA.LW1 NSI.LWl G e:: 2 e 3,214 '3,718 286,500 0.000 3,1.65 3,146 287,000 0,000 3,059 3.125 283,.750 0,000 3. i 04 3 348 2832ooo 0.000 2.. 947 4 077 0.000 3.1.74 2.9~5 275,399 0.000 3.109 3.157 276,500 0.000 3.043 1.967 268,250 0,000 3.085 2.721 271.500 1.000 LIS Ta~e Verifi..cation Listin~ Ce ~er ~c~l, Um, erqer A!a$~a Computin n DEPT. :5900.000 RHOB.LWl PS~.Lwl ~. ~t 9 ROPE.hW H~F,I LW1 5.747 T,AB ..~ ~ 0,000 [)~P~, 5B00,000 RiiOB,, LW i DCAL, Lffl 0,069 DPH1,L~ ~F~,, LTl 5.763 TAB.LW ~SI,LW1 ! .OOO D~PT 5700,000 D C,~ L' [, W 1 0 · 014 D P ~ I, L P $ R: b W t 3,600 .~ O P ~:. b HFF~,.I, W1 5. 748 T~,5. LW ',I.LWi 0,000 D~P' ~ 5600,000 RHOB.,LWi D AI~ LWi 0,000 DPNI.SWl PS~ LW1 2 953 R[P~2,LWl F{ ~ LW1 5 596 TAB ~s~ '1 [,w t o. 0o0 . 9 C A L. ~ W 1 0. ~ 82 D P H I · ~ W 1 PS~.LWl 7'681 ROPE:,Lw ~. H~FA.. LW 1 6,995 T.nB, LW1 ~$l. 5Wl O.O00 DEPT, 5400,000 RHOB.'LWl DCAL, [.WI O, 188 DPHI ~S~.LW1 3.379 ROPE:I.,Wi ~FFA LW1 5,673 TAB,LWI ~SI :LWl 0,000 DEPT. 5300.000 RHOB,LWI DC.AL.LW1 0.000 9PHI.LWl PS~. I...Wl 5,17~ ROPE.LTl HFF.~.. Lk' 1 6,255 T4B. LW ~SI.LWl 0,000 DEPT. 5200.000 RHOB,LWl PS~,LWl 3.795 ~OPE.LWl H~FI. Lw 1 5. 973 TAB. LW ~SI.LWl O,O00 DEPT. 5100.000 ~HOH.LW! DCAL.I:Wl 0,208 DPHI.bWl PS~.LW1 4.763 HEFt. LW1 6,1 ~8 TiB,LWt ~SI.LW1 0,000 2~-JAN-lgg3 08:38 2,319 DRHO,LW1 0,201. ~50,010 GB,LW! 0.331 TABD,LWl 2.270 DRHO,LW1 0.230 TNP}.i. LWl 318'659 GR..LWl 0.581, T.ABD.,LWl 2,~60 DRNO,LN1 0,4S3 TABD,:LW1 0,~9 TNPH,SWl 104, ] 257:0 9' TNPH,[~W1 354 0'453 TABO,~Wi ii'333 D'HO,LWI ~92 9 931 GR,SW! 0.636 TAB9,LW1 2.197 DRHO,LWl 0.275 TNPH.LW1 79.294 GR.LWl 0.699 TABD.LW! 2,278 DRHO.LWi 0.225 TNPH,LW1 233.760 GR.SW1 0.397 2,337 ~RHO,Lwl 0,~90 292.504 GR.L~I 0,339 TABg,LWt 0,011 41.500 !3.290 0,741 ~0 01.6 0:500 85.375 1.008 -0..,007 0 300 0,894 -0,016 40,900 77.~731 300 1. 0,.006 39400 901110 0.908 -0,021 36,100 58.279 1,264 -0.006 36.700 6~.788 0.996 0.Ool 36.300 67.091 0.688 PEF LTl ATR, [,W 1 HENA,LWl PEF.LWl ATR,LWl HENA,LWI NSI,5Wl PEF'LW1 ATR,LWl NSI.LW1 PEF,LWl ATR.LW! NSI.LWl PEF.LWl HENA,LW1 NSI,LWl PEF.LWI HENA.L~I NSI.LW1 PEF.LW1 ATR.LW1 NSI.LW1 PEF.LWl HENA.LW1 N$I.LW1 ITR,LW1 HENA.LW! NSI.LWl PAGE: 29 3.467 3 45 0,000 3,:166 3,691 266.750 0.000 26~,,500 0o000 2,886 3.036 264,000 0,000 3.:623 7,964 293,250 0,000 3.591 3.196 262.750 0,000 2,976 4,837 279,500 0,000 3.047 4,345 266.500 1.000 3,370 4.996 271.000 0.o00 $chl. UmberCler Alaska Computing Center V~,:pT 5000,O00 VC,~ lLWl 0. ooo ~S'I.LW'I 0,000 DEPT 4900. 000 DC~L~ LWl O, 24:2 ~'s~: t,w 1' eoo [)~PT, 4800,000 DCAL.LW1. O, 000 PSR, LW1 7,496 ~SI.LWl 0.000 D~PT, 4700, DCAL, LW ~ 0,430 ~SR l,,Wl 7.403 ~EFI ~LW1 6. 348 RSI*I,W'l l. 000 DEP~. 4600. D C A l.,, I, W 1 0.380 PSR.LWl 6.297 HFF.a .LW1 5.20~ ~S!.LWl O,OOO D~PT. 4500.000 DCAL. LW1 0.526 PS~. LWl ~..4,1o2 H~F~,Lwl 6, ~95 DEPT. 4400. 000 DCAL. LW 1 0.0 49 ~S~. LWl 8, H~FI, LW1 6.102 RST.LW1 0.000 DmPT. 4300.000 DCAL.LW! 0.190 P$~.LW1 10.196 HPP~.LWl 5.8q4 DEPT. 4200.000 9CAI,.I.,wl 0.028 PS~.LW1 17.245 H~Pn.SWl 5.43B ~ST.LWi 1.000 TAB.,LWl RHOB~.LW1 DPH ~, LW ! R 0 P E, L W ~ TA, B.LWl 22-JAN-I993 08:38 02'.198 ORHO.[.~~ , Wl 6 O. GR. LW ~ o, 2 5 o T ~ e. D, t, w ~ 2.~.18 DFHO-Lwl 0.~2 TNP,,LWl. 439, 3: GR.,LWl · 1o091 TABD'LWl. '0.002 38.900 55.576 0.755 0.00! ,'496 1.4.11 RHOB.LW! OPHI.LWi TAB.LW1 RHOB.LW1 OPHT.bWl ROPE,.LWl TAB.LW1 RHOB.LWl D~HI.I,,,w1 ROPE.LWl T~B.LWt RHOB.LWl DPHI.LW1 R'3PE.LW1 TI3.I,,Wl 2.464 DRHO.LWl O.1, A3 T~!PH.L, W1 211,7 3: ~R.:LWI 0.769 TABD.LWl 2.297 oRHO.5w:I 0.21,4 TNPH,.LW! 471..414 GR.LWl 0.758 TABD.LWl 2.259 DRHO.LWl 0.237 TNPH.:LWl 200.632 OR.LWl 0.84~ TABO.LW! 2.052 DRHO.LWl 0.363 TNPH.LW1 380.468 GR.LWl O.a6B TABD.LWl 2.324 DRHO.DW1 0.198 TNFH.bWl 273.826 GR.L, Wl 0.536 TA~D,LWl 2.211, OPHO.L, W1 0.266 T~]PH.LW! 549.363 G~.LWl 0.920 TABI).D~I R~OB.LWl DPHI.LW1 ROPE.LW1 TaB.LW1 RHOB.LWI DPHI.LWl ROPE.LWl 0'051 34.200 64.361 ~.357 0.029 40:600 532215 1.381 0.004 35 600 33~401 1.015 -0.020 37.300 35.046 1.050 O.OOl 38..400 54.135 1.057 -0.041 40.~00 52.985 1.466 ATR.LW1 NSI.LW! ATR-Lw1 HENA.LW1 NSI.LWl NSI.LW1 PEF,LWl HEN'A.LW! NSi.LW! PEF.LW1 ATR.LW! HEN~..LW1 NSI.LW! PEF.I, Wl ATR.LWl HEN5.LWl NSI.[,Wl PEP.bW1 ATR.L, Wl HENa.LWl NSI.LWl PEF.LWl ATR.LW1 HENA.Lhl NSI.LW! PEF.I.,~I HENA.LW! NSI.LWl PAGE: 30 2.972 7.293 266.181 .1.:000 995 875 0,000 3,. 15,5 ~ 069 2:65~500 1.0oo 4.~34 8. 69 265.750 0.000 4.01,6 6.644 24g.500 0.000 !676 1 338 27 250 0.000 2.709 8.402 271.750 1.000 3.614 10.762 268.750 0.000 3.271 26.078 257.750 1.000 ~chlumherqer Alaska ComPutf, n~ center DE'PT 4100.'000 RHOB. I,,Wl ~ S ~ · I,,, W 1 15.168 e J ~ E ,. b W HFF'!, LWI 4,740 TAB. DEPT, 4000,.000 RHOB,LWl DCAL,LW1 1,035 DPHI, L PS~.LW1 10,I07 R0~E,LW~. HFFA. LW! 5,0:45 TAB.LW ~SI. LWl 0.O00 ,, , DEP~ 3900.000 RHOB.LWI D C ~ L: I, W 1 2.06 ~ D p ~ I. PS~.LW1 -999.250 ROPE.LW'I , ** EMD OF DATA **** FIL,w, TR~II,,~I~ **** FIL~, MAb~E : EDIT ,003. V~RStOM : 001107 D~T~ : 93/0~/22 ~laX R~C SIZE : FIhE TYPE : LO I.,l $~ FILE **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : wLiC VERSIeN : 00~07 DAT~ : 93/01/22 ~IX REC SIZE : 1024 FIL~ TYPE ! LO L~ST FILE : FILE NUMBER 22-JAN-1993 0813~ 2.27! DR~O.bW! 0.230 TNPH,bW'I 623.956 ' G~,bW1 0,329 T~.~D,SWl 33 DR, HO.bWl s4:646 ~,690 TAB9oLW1 ~,4.16 DRHO.,LWi 24 TNPH.SWI -99,'150 GR'LW1. '99~,250 -999,250 -999.25'0 TNPH.LWl -999.250 GR.LWi '999.250 T~BD,LW~ 0.055 42 200 32 444: 0 442 ,'0.011 · 8 10 -0.644 43 500 211540 '999,9~50 -999.~50 -999.250 -999.250 -999.000 PEF.L, W1 ATR.bWl HKNA.LW! NSI.LWl ATR,LWI NSI,LW1 PEF.LWI ATR.LW1 HMNA.LWI PEF.LwI ATR.LW1 NSI.LWl PAGE: 31 3,757 14,936 230.282 1,000 5 91,7 12 107 249 000 0 000 8. 186 -99g,250 23 4 .. 000 0.000 -999 ~50 -999:: 50 0.000 1.000 bis Tape Vert, fi, cation L~sti g Schlumberger AlasKa ComPuttnn~ Center 22-JAN-1993 08138 PAGE: ¸32 Curves and SIT P,.UN DKPTH INCRE~ENT: LOG HEADER DATA DATE LOGGED: log header data'for 0,5000 START DEPT~ 9087,0 SUP, FACE SOFTWARE IERSION: DOWNHO. LE SOFTWARE VERSION DATA TYPF, (MEMORY' OR ~EAL-TIME): TD DRILLER (MT): TOP LOG I~'TEPVAL (FT]' ... ~0TT0~ bOG iWTERVAL RI'T ROTATING SPEED HOLE I'NCL!Ma. TION (DEG) TOO V C C $ OPEN NO[, DRILLERS ,'~UO TYPE ~XI~!,'~ ANGLE: [, STRING (TOp TO .BOTTOm) KMDOR TOOL CODE TOOL.:.TYPE DN NEUTRON/POROSITY DR RESISTIVITY Y~UD DENS MUD VISC NUD PH: MUD CHLO FLUID 40 "UD A ~UD F ~UD C D CASING DATA E R. IT SIZE: (IN),' C.ASI~'G DEPTH (FT): NDITIONB ITY (I:.,B/~): OSITY (S).,' RIDES ss ITY (OH~ AT TEMPERATURE DEGF) T MEASURED TEMP~RATURF (~T): T ~X CIRCUb.ATI~G TEmPERaTURE: ILTRATE AT ~T: AKE AT ~,~EUTRON ~IATRI YATRI HOLE TOOL X: X DENSITY: CORRECTIng' TOOL STANDOFF each bit run in separate files. STOP DEPTH 9500.0 9500,0 27-DEC-92 MEI~ORy 9500,0 9087,0 9500,0 TOOL NUMBER NDS0~5~ RCS 0 8 8,500 3973,0 10,50 2,020 1,730 75.0 65.0 SANDSTONE 2,65 ~,500 TaPe uerl, f.lcation bist, inq 5chlumberoer Alaska computing Center 22"JAN-1993 08:38 ',.BIT TO GR 7~.28', BIT . BIT TO MEUT 140 02 ", DR.I (GM/CC) R ~?g ADDED TD MUD 8YSTEt~.. DATA. FROM DOWNHObE MEMORY O~'~HOI, E' SOFTWARE VERSION V4,0C',: ¸33 ** DATA FORMAT spECIFICATION RECORD ** **' SET TYPE .. 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 4 6,6 5 66 6 7 65 8 68 0 5 9 65 F~5 11 66 13 66 0 14 65 ~T 15 66 68 16 66 1 0 .66 1 ** SET TYPE - CHAN ** N~ME ~RV IINIT SERVICE API AP1 APl API FILE NUMB NUMB SIZE REPR PROCESS ID ~RDER # I,OG TYPE CLASS MOD NUMB $~MP EbE~ CODE (HEX) P FT 6189~3 00 000 O0 0 4 1 I 4 68 0n00000000 RHO~ I, W2 G/C3 6189~3 O0 090 00 0 4 1 1 4 68 DRHO LW2 G/C3 61~9~3 00 000 00 0 4 1 1 4 68 PMF bW2 61~983 O0 OOO O0 0 4 ! 1 4 6~ DCAL I,,w~ IN 618983 00 000 O0 0 ~ 1 1 4 68 D~HT LW2 PU 61~983 O0 000 00 0 a 1 1 4 6~ TNPH LW~ PU 6!~983 00 000 00 0 4 1 I 4 68 ~TD LW2 O~M 618983 nO 000 0C o 4 1 1 4 69 PSR LW~ Q~M~ 61~983 00 000 00 0 4 ~ ! 4 68 RODE Lw2 FIHP 618983 00 000 on 0 4 1 I 4 68 0000000000 O000000000 oo00000o00 0o00000000 0000000000 0000000000 0000000000 o00000o000 000o000000 :,.I$ ?~e ver!ftcetton t,!st, tng ~chlumber~er Alaska ¢omputina Center 22-JAN-1993 08:38 PAGE: NAME SE~V UNIT SERVICE API AP ID ORDER # LOG TYP G~ LWi2 GA~I 618983 00 HFNA LW~ CPS 61~983 O0 000 NEFA LW~ CPS 61~983 O0 000 TAB [,W~ 618gB3 O0 000 TABD LW~ 61~983 O0 000 NSI LW? 6~99~3 O0 000 RS'! LW2 61~983 O0 000 E CLASS MOD 9UMB SAMP ELE~I CODE (HEX) O0 0 4 i 1 4 68 0000000000 O0 0 4 ! 1 4: 68 0000000000 O0 0 4 i ~:, 4 68 0000000000 O0 0 4 1 i, 4 68 0000000000 O0 0 4 ! 1 4 68 0000000000 O0 0 .4 1 1 4 68 0000000000 O0 0 4 1 1 4 6~ 0000000000 34 ** DATA DEPT, PS~.LW2 H~F~.LW2 RSI.I.,W2 D~P~. DCAI,,,.LW2 ~SI.LW2 DEPT DCi~L[LW2 PS~.LW2 HFF.~,LW~ ~ST.LW2 DEPT. DCAL.LW2 PS~,L~2 BFFm.LW2 ~Si.LW2 DEPT. ~EF~.bw2 D~PT. DCAI..I.,W~ PSg.LW~ [t~F~,LW2 ~SI.LW~ 9500,000 ~HOB,.LW2 -999,250 D[~NO'LW'2 =999.250 PEF.L~2 -,'999, :250 DP~l, L, W2 -99q,~50 T~PF{, 1[.,~2 -099,250 ATR,LW2 -999,~50 R:OPE.LW2 120, 95 . GR,L'W2 -~9,250 HENA.LW2 0,000 TAB,LW2 -999,~50 T~BD,L~2 -9~9,000 NSI.LW~ 1.000 9300.00a ~HOB bW2 2.297 o.o3~ ~P~'{~:Lw2 o.2i4 1.,7~7 ROPE.B~2 1.7.4.7 2 5.350 T~S.I,,W2 0.9.2 0,000 9200.000 RHOB.LW2 2.:381 0.031 DPHI.I.,,W2 0.163 2.1.05 ROPE.LW2 22~,223 5,775 TAB,LW2 0,825 0.000 9100.000 CHOB,LW2 2~466 O.OgO DPHI.LW2 0.11.¢ 1.972 ~OPE.LW2 122.414 5,813 T~B.LW~ 0~938 0.000 9000,000 RHOB.LW2 2,926 0,000 DPHX.LW2 0,257 -999,250 ROPE,LW2 -999,250 5,000 T.~B.LW2 '999.250 0,000 D~HO.L'~2 0.022 TNPH,L!.42 41.600 ATR.LW2 GR.,LW2 100,025 HE~)'A.L~2 TABD,LW2 2.432 NSI.LW~ DRHO.:LW~ -0.005 PEF.LW2 T~PH,Lw2 39,800 ATR.LW2 GR,LW2 112.804 HEN~.LW2 TABD:,LW~ 1,747 NSI.LW2 DRHO,Lw2 -0.013 PEF.I, W2 T~iPH.I, W2 38.000 aTR.LW2 GR.GW2 177.812 HENA.Lw2 TABD.LN2 1.540 NST.LW2 DRHO.LW2 0.022 PEF.LW~ TNPH.Lw2 44.300 ATR,LW2 G~.LW~ -999.250 HE~t.~..LW2 TABD.LW2 -999.~50 NSI.LW~ :.999 250 999'.25o 0 00o 1:000 -999 250 0,000 1.000 14,: 405 668 254~750 1.000 3,277 2.102 262,000 1.000 4.542 1.820 266,500 0.000 4.388 -999,250 0.000 1,000 tis Ta~e Yerlftcatlon bisti, DO ;c~lumberger AlasKa Co~Dutlng Center ,, 22-dAM-1993 08:38 DEPT.. 8900,:000 DHOB.LW2 -999,250 DRHO.Lw2 DCAI,,'.LW2 -999.250 DPHI.LW:2 -999.250 TNPH.!.,W2 PS~.:LW~ -999.250 RF)PE,.LW~ -~99:,~50 .GR.LW~ HF'F,~.LW2 0.000 ~AB.bW2 -999.~50 TABD.bW2 ~S!.LW~ t.O00 I)~PT. ~66,000 RHOB.LW2 -99~ ~50 DRHO.LW2 DCAL.[,t~2 -999.250 DPHI.LW2 -99~ .50 TNPH.LW2 PSR.LW2 -999'~50 ROPE:,LW2 -999 250 GR.LW2 H~FS.LW~ 0.000 T~B.LW2 -999.~50 PSI.LW2 ** F~ND OF DATA ** -999.250 PEF.L~2 -999.250 ATR.bW~ -999.0~0 i,,,EN~ LW2 -999. 0 NSI: Y,:,:W~ 999:.250 HEN'A,LW2 -999. 000 NSI,LW2 PAGE: 35 ' 999 ' 250 -999.250 0.000 1. 000 '999,~50 '999.250 0,000 1.000 **** FILE TRAILER **** FIt, E MA~E : EDIT .004 SERVICE : FLIC VERSlO~ : 00lA07 DAT~ ~a× REC SI'ZE : ~024 FILE TYPE : L~ST FILE **** FILE. HEADER, **** FILM NAME : EDIT ,005 SERVICE ; FLIC VERSION : O01.a07 DATE : 93/01/22 ~AX REC SIZE : ~024 FILE TYPE : LO LAST FiLE FILE N!IMBER 5 Curves and log header data for each bit run in seoarate ~tles. VEMDOR TOOL CODE START DEPTW STOP DEPTM '" .... '"" .... ?DD ~0 . CDN 9500.0 10300,0 LOG HEADER DATA DATE L~GGED: 27'DEC'92 3IS Tape.refill. cation blstt, n.q ~chlumberqer hlas~.a ComPuttnq Center 22-JA~i:-1993 08:38 PAGE: 36 SOFT ARE,. SURFACE SOFT,fARE VERSION~ DOWNHOLE SOFTWARE VERSION: TD DRILLKR (FT): ~OP LOG INTE~V.~,b (ET): BOTTOM LOG I'MTERV'AL ~IT ROTATING 8PES:D ~O!.,E INCI,!~ATIOM (DEG) MINIMUM ANGLE~ MAXIMUM ANGLE: TOOL' ST~ING (TOP TO BOTTOm) VENDO~ TOOL CODE TOOL.TYPE CON N~UTRON/PORDSITY CDR RESISTIVITY $ BOREHOLE AND CASING DATA OPEN HOLE SIT SIZE fiN):'. DRILLERS CASING DEPTH (ET): BOREHOLE CONDITIONS MUD TYPE': DENSITY CL~/G): VISCOSITY CS): ~UD C~hORIDES (PP~): FLUID LOSS RESISTIVITY (OHM~ AT TE~PERATURE DEGF) MUD AT MEASURED TEMPERATURE MUD aT MAX CIRCULATING TENPER&TURE: MUD FILTRATE AT ~T: ~!:;D CAKE AT NEHTRON TOOL MATRIX: ~ATRIX DENSITY: HOI, E CORRECTION (IN): TOOL STANDOFF (IN): rWR FREQUENCY (HZ): FA. ST 10300,0 9500.0 ~0300.0 RGS058 8:,500 3973~0 10,50 2,020 1,730 75.0 65.0 SANDSTONE 2.65 8,500 .. ~IT TO RES 1~A53' BlT TO. GR ~5.95', BIT TO DEN 4:.32; BI! TO NEUT9~-~0s WAS"DOWN INTERVAl., ~408' TO 9500' DPlLLED INTERVAL 9500' TO 10300' ~.~TRIX DENSITY ~.65 (G~/¢C). FLU{D DENSITY ! 0 (GP/CC) ROTaTIONAl,., BULK DENSITY PRO~ESSING USED. BARITE ADDED TO MUD SYSTE~ DATA F~OM DOWN,OnE ,E~ORY. DOWNHOLE SOFTWARE VERSION ¥4.0C. $ [,IS FORMAT DATA Schlumberc)er .!aska Comput pg CeDter 22-JAN-.1. 993 O8:38 37 ** ,r)-ATa. FORMAT SPECIFI;CATION I~ECORD ** SET TYPE . TYPE i 66 2 66 0 5 66 7 65 ~ 68 0,5 11 66 15 I~ 68 t3 66 0 14, 65. Fl' 15 6'6 68 1.6 66 1 0 66 ! DEPT FT D~ ~:.~0 LW3 G/CB DP}ti LW3 PU TNP~ LW3 PU AT~ LW3 0~ G~ LW3 GAPI H~N~ LW3 CPS HFFA Lw3 CPS Th~ 5W3 TABU LW3 ~'~$I Lw3 PS!'. LW3 TYP 6~m9 6189 6189 6189 6189 61R9 6~89 6199 6189 6189 6189 6189 ~lR9 6189 61~9 E - CHAN ** ER # LOG TYPE CLASS NOD ~U~B SA~P El, EM CODE (HEX) ~3 O0 000 O0 0 5 1 1 4 68 0000000O00 83 00 000 O0 O 5 1 1 ~ 68 0000000000 8) O0 000 O0 0 5 1 I 4 68 0000000000 83 O0 000 O0 0 5 1 1 4 68 0000000000 83 O0 000 O0 0 5 1 1 4 68 0000000000 ~3 O0 000 O0 0 5 ! 1 4 6~ 0000000000 83 O0 000 O0 0 5 1 i 4 68 0000000000 83 O0 go0 O0 0 5 1 1 4 68 0000000000 83 O0 000 O0 0 5 ~ ! 4 68 0000000000 93 O0 000 O0 0 5 1 1 4 68 0000000000 93 O0 000 O0 0 5 1 1 4 68 0000000000 83 O0 000 O0 0 5 1 1 4 6~ 0000000000 83 OO 000 O0 0 5 1 1 4 68 0000000000 83 O0 000 O0 0 5 ! I 4 68 0000000000 B3 O0 000 O0 0 5 1 1 4 68 0000000000 ~3 00 000 O0 0 5 1 1 4 68 00000OO000 83 O0 000 O0 0 5 ! 1 4 68 OOO0000000 mmmmmmmmmmmmmmmmm~mmmmmmemmmmmmmmmmmmmmmmmmmemmmmmmmmmmmmmmmmmmm ** DATA ** his Ta°e Verification t,!st, tnq '~chlumber.~er Alaska Computinq Center DFPT. 10299.5{)0 DC.~],LW3 -999,250 HEF",. LW3 0,00O ~ST .LW~ 1 D~PT 10200,000 PS~.LW3 1,583 gFFA,LW3 6,631 RS!.LW3 0.000 D C A l,, :. L W 3 , t: ~ 0 P S ~, L W 3 ,973 HMFi~. LW3 . ~Sl, LW3 0,OOO D~:PT. 10000. 000 D C ,~ L, L W 3 0,109 PS~.LW3 2,~66 H~FA. LW3 8.921 RSI ,LW3 0,000 DEPT.. 9900.000 DCAL. LW3 0,254 PS~. LW3 3, ~IFFA,LW3 8.650 ~S!,LW3 0.000 DEPT. 9800,000 DCAL. LW3 0,244 PSP,LW3 3,718 HWFa.LW3 7,913 ~SI.LW3 0,000 DFPT, 9700,000 DCAI,, LW3 O, 297 PS~, LW~ 2.442 HEF~,LW3 7,638 ~ST. LW3 O, 000 DE~T. 9~00.000 9C~L. LW3 0.512 PS~,LW3 2.154 ~FA. LW3 7,07 1 ~SI,LW~ 0,000 DFPT. nC~L.t,W~ 1.205 PS~.LW~ 2.277 HFFa. LW3 5,631 ~SI.LW3 0,000 R a 0 B. L W 3 · [)PHI. LW3 R O P E. L W 3 TA P,. LW3 R H 0 ~' L w 3 DPHI.LW3 R H 0 B · I, W 3 D~gI · LW 3 ~ OP ~2, L DPHI, LW.3 ROPE ,LW 3 TAB. LW 3 r H O B. b W 3 DPHI.LW3 POPE.I,,W3 TAB.L, W3 RMOa,LW3 OPHI,LW3 ~OPE,LW3 TAB,LW3 RHOB,LW3 DPHI,LW3 ~OPELW3 TiB:LW3 RHOB.LW3 OPMI,bW3 ROPE,LW3 T~8.LW3 22-jA~-1.993 08:38 0,088 TNPi'I:,LW3 29.998 GR.LW3 0 750 ~:A..D. . ' B LW 3 2 458 DRHO,LW3 0'. 1 ! 7 TNP}.{. LW3 29' 140 6; "a, b w 3 0,635 TABD, [,~3 2.320 DR.O.LW3 0.200 TNPH'~LW3 87 . 803 G~ , bVt 3: 0.514 T.A~BD.bt~3 2,488 ~HO.L, W3 0.098 T ~,~ P H. [.., {~ 3. 51.]~0 ~R.LW3 0.1 TABD.LW3 2.393 DRHO,LW3 0.1.56 TNPH,hW3 53,097 CR,LW3 0,~92 TABt),LW3 ~:483 DRHO,.bW3 101 TNPH.LW3 23.003 GR,LW3 0.636 TA~D,LW3 ~,561 DRHO,LW3 0.054 TNP?i,LW3 2{.201 ~R,LW3 0.613 TABO,LW3 2.442 DRNO,LW3 0,J26 TNPH,bW3 179,994 GR,LW3 1,0~9 TABD,LW3 99 250 : 5o 999; O0 94 8 rio o 9ols 271 oo 73 616 0 013 53. ~852 0,986 0.017 27.000 63.267 1.267 0.014 28.:800 71,871. 1,018 21 O0 91.452 326 0.024 31.400 i06.725 1.349 0,031 99,956 2.350 P "~ L W 3 ATt. b W3 ~: ' LW 3 H: .~N A,, N$I.LW3 PF.F. L W 3 ATB ,LW3 H E N A. L w: 3 NS.I.LW3 PEF.LW3 ATR, L'W3 HENI .LW3 HS!, LW3 PEF,LW3 ATR.LW3 HENA,LW3 NSI,I.,W3 P E F. L W 3 ATR,LW3 HENA bW3 PEF,LW3 A. TR,LW3 HENA,LW3 NSI,LW3 PEF.LW3 ATR.LW3 HENA.La3 NSI.LW3 PEF,LW3 ATR.LW3 HKN~.LW3 NST.L~3 PAGE:. 38 -999,250 -999.250 0.000: 1,000 28 ~, 143 .000 :050 000 2.769 2.9t9 319.438 0.000 3.360 3.857 307,500 0.000 3.087 3,915 292,750 0,000 3.251 2.715 284.875 0.000 3.770 2.208 281.9~7 0.000 5.390 2.245 249,188 0.000 ;chlumberqerAlasKa ComPutir,~ Center 22-JAN-1993 08:]8 PAGE: 39 DEPT., 9400,000 RHOB*LW3 2,349 DPH(],I.~W3 P S ~:. [, W 3 1.55 ~ R 0 P ~;. b W 3 131.~ 87 G ~. 5 ~ 3 RSI :LW3 :500030 T:~.LW3 -99~.~50 TABD.bW3 DEPT. 9327.500 DCAL.LW~ -999 ~50 PSR.LW3 -999'250. HEFA LW3 0,000 RST:LW3 1.000 ROPE bw3 TAB LW3 50i800 ~T~:,LW3, A 90:256 H~N ~W3 -999.~50 NSI:LW3 6,073 1,.403 243.000 0.000 -999.250 -999.250 0.000 1.000 ** END OF DATA ** **** FIbE TRAILER **** FII,F U~ME : EDIT .005 SERVICE : FL!C VERSION : 00~07 ~AX REC SIZE : ~0~4 FTT,F TYPE : LO LAST FILE : **** FILE PEADER **** FILE N~ME : EDIT .006 SM~VlCE : FLIC VERSION : 00~07 D~T~ ~ 93/01/22 ~X REC SIZE : 1024 FILF TYPE : hO LAST FILE : FIL~ FIL~ NUMBMR: 6 EDITED ~ERGED ~WD depth shifted and cltDPed curves; all bit rums merged.-.' DEPTH INCREMENT 0.5000 FILE SUMMARY KR[,! TOOL CODE START DEPTH STOP DEPTH 977, BASELINE CURVE FOP SHIFTS: CURVE SW'I~T DATA (~EAS[.I~ED DEPTH) .......... EQUIVAbF~IT U~$NIFTEb DEPTH ',,,IS ,.o~e Verl. f.f~cation List:~nq 5chlumberqer Alaska Co~vut.l. nq Center ~2'.JAN-lgg3 08:38 ~PU TOOL CODE RE~ARKS: THIS FI'bE CONTAINS RESISTIVTY DATA. LIS FORMAT DATA i!3IT RI]N ~f). MERGE TOP H'i~t~ ~ESOLUTION ORO PRoCEssED PAGE: 4,0 FORMAT SPECIF'~CATION RECORD ** ** SET TYPE -64~B.** ..... TYPE ~P~ CODE VALUE 1 66 0 2 66 0 3 73 ~'8 4 66 5 66 6 73 7 65 98 ~ PT 0.5 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 ~ 0 66 1 ** SET ~E SERV U DEDT FT ~TP~ OO1 ATE~ 001 PSEP 00l ATVq O01 PSVP 001. TYPE: - CHA ORDER # 618983 O0 6189~3 O0 61~q~3 6~83 O0 61~983 00 61m9~3 oo I API API API FILE NUU~BSIZEED~MB N ~ PROCESS G T¥'PE CLASS ~OO NUMB SAMP EI, E~ COOK (HEX) ooo oo o oooooooooo 000 O0 O 6 1 1 4 68 0000000000. 000 O0 0 6 1 1 4 6g O0000OO000 000 O0 0 6 ! 1 4 6~ 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 ! 1 4 6~ 0000000000 ,IS Tame Verification bistino ;chlumber~er Alaska Computin0 Center 22'JAN-1993 08:38 ii ** DATA ** PSE~.OOt 4:37 ATV~.OOI 4.. 6 PSV~.O01 9700.000 AT~..OO1 ~.787 PSP~.O0~ DEPT. 9600,500 ATP~,O0I. ~,321. PS[~H,O01 2,:193 ATER,OOi PSE 001 2 196 ATVR OOi 2 329 PSVR 001 2.197 ** EN'D OF DATA ** 4.77.,1, 2'324 **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FblC VERSION : O01A07 DATE : 93/01/22, MAX REC SIZE : FILM TYPE : LO bAST FILE : **** TAPE TRAILER **** SERVICE NAME = EDIT DATE = 93101/22 OPICI'N' : ?bI~ TAPE wA~E : 927 5 CONTINUATION # : ~ PREVIOUS TAPE : COu~ENT ~ ARCO ALASKA, **** REEL TRAILER **** SERVICE MA~E : EDIT DaTF : g]/01/22 OP!~IN : FLIC REEL NA~E : 92~35 C~NTINUATION # : PREV!CUS ~EEL : COq"ENT ~ ARCO ALASKA, RIVER UNIT,IH-20,50-029-22313-00 IMC.,KUPARUK RIVER UNIT,IH-20,50-o2g-22313-00