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HomeMy WebLinkAbout192-1301. 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-17 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): 8455' N/A N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packer: Baker FB-1 permanent packer Packers and SSSV MD (ft) and TVD (ft): SSSV: Camco TRDP-4A safety valve 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 Staff Intervention Engineer 8437' Perforation Depth MD (ft): 7797-7847', 7800-7860', 7854- 7864', 7899-7919', 7899-929', 7919- 7929 8118-8143' 8399' 6495-6544', 6497-6545', 6540- 6548', 6576-6592', 6576-6600', 6592-6600'6752-6773' 3.5" 7010'7" 16" 9.625" 78' 4941' 121' 4283' 121' 4983' J-55 TVD Burst 7735' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025639 192-130 P.O. Box 1000360, Anchorage, Alaska 99510 50-029-22314-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7699' MD / 6416' TVD 1825' MD / 1775' TVD Perforation Depth TVD (ft): 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 7025' 7717' 6431' 7717' jan.byrne@conocophillips.com 808-345-6886 Jan Byrne 12/25/2025 Length Size m n P s 66 t 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 325-764 By Grace Christianson at 3:54 pm, Dec 16, 2025 X 10-407 DSR-12/19/25 AOGCC witnessed tag and PT of abandonment plugs 1, 2, and 3. AOGCC witness casing cuts before any top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut J.Lau 12.22.25 A.Dewhurst 16DEC25JLC 12/22/2025 12/22/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 16, 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 fully Plug and Abandon (P&A) KRU 1H-17 (PTD 192-130). The well 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’d. 1H-17 is a Long Term Shut In (LTSI) well completed with 3.5” tubing, 7” and 9.625” casing strings. The well has been secured with a RBP at 7717’ since 10/25/2019 when a tubing leak at 6680’ was identified. A passing CMIT TxIA and MITOA both performed 12/1/25 demonstrate that the production casing and surface casing both maintain integrity. Per this procedure a full P&A will be performed, the first step is for Coil to set a cement retainer at ~7717’ and pumping plug #1, 30 bbls of cement to isolate the Kuparuk reservoir. Eline will punch holes in tubing just above plug #1 TOC. Then Coil will set a retainer at ~6728’ and pump plug #2, 34.2 bbls of cement to bring plug #2 TOC to ~6613’ in the tubing and IA. Eline will punch holes in the tubing just above plug #2 TOC. Plug #3, 154.9 bbls cement will be full bore pumped to place a balanced plug from ~2200’ to ~6613’. Then Eline will shoot holes through the 3.5” tubing and 7” casing at ~2070’. Plug #4, 174.3 bbls cement surface plug will be pumped full bore down the tubing taking returns off the IA and OA leaving cement from surface to ~2200’ in the tubing, IA, and OA. The well will then be excavated ~6 feet below original ground level, wellhead and cellar will be removed, and the site backfilled with gravel to ground level. Please contact Jan Byrne at 265-6471 if you have any questions. Sincerely, Jan Byrne Wells Engineer ConocoPhillips Alaska, Inc. 1 1H-17 Full P&A Date: 12/16/2025 Network Number: 50075788 Prepared by: Jan Byrne (808-345-6886) Objective 1H-17 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&A’d. This procedure is to perform a full P&A from the Kuparuk reservoir to surface. Current Well Status LTSI well, shut in since November 2018 Secured with 2.725” RBP at 7717’ 10.25.19 Tubing leak identified at 6680’ 10.24.19 TxIA 1 BPM LLR at 1500 psi TxIA circ’d out with CI SW and DSL 10.24.19 Passed CMIT TxIA to 2500 psi 12.1.25 Passed MITOA to 1800 psi 12.1.25 Last tag at 8131’ on 8.10.19 Tubing: 3.5", 9.3 lb/ft, J-55, IPC tubing Production casing: 7", 26 lb/ft, J-55 Surface casing: 9-5/8”, 36 lb/ft, J-55 OA cement from 2188’ – 3669’ Freshwater zones: None Hydrocarbon bearing zones: Kuparuk 7798’ – 8204’ Last SBHP: 2,812 psi at 6,667' TVD on 8.9.19 o = 8.1 ppg Reservoir temperature: ~160°F Volume calculations: o 1st cement plug, Kuparuk reservoir A & C-sand: Retainer set at 7717’ in 3.5” tubing 3.5” tbg from 7717’ to 7735’= 18’. 18’ x 0.0087= 0.2 bbls. 7” casing from 7735 to 8234’ (100’ below lowest perf)= 499’. 499’ x .0383= 19.1 bbls Excess 50%. 1 bbl on top of the retainer Total volume: 0.2 + 19.1 + 50%= 29 + 1= 30.0 bbls o 2nd cement plug from ~6728’ to 7602’ in tubing and IA. Retainer, set at 6728’ in 3.5” tubing: 3.5” tbg from 6728’ to 7602’ = 874’. 874’ x 0.0087= 7.6 bbls 3.5” x 7” from 6728’ to 7699’ = 971. 971’ x 0.0264= 25.6 bbls. 1 bbl on top of the retainer Total volume: 7.6 + 25.6 + 1 = 34.2 bbls o 3rd cement plug from ~2200’ to ~6613’ in tubing and IA retainer, set at 2200’ in 3.5” tubing: 3.5” tubing from 2200’ to 6613’ (estimated TOC) = 4413’. 4413’ x 0.0087 = 38.4 bbls. 3.5” x 7” from 2200 to 6613’ (estimated TOC) = 4413’. 4413’ x 0.0264 = 116.5 bbls Total volume: 38.4 + 116.5 = 154.9 bbls o 4th cement plug from surface to ~2200’ in tubing, IA & OA 3.5” tubing. 2200’ x 0.0087 = 19.1 bbls 3.5” x 7” annulus. 2200’ x 0.0264 = 58.8 bbls. 7” x 9.625” annulus. 2070’ x 0.0297 = 61.5 bbls. Excess 25% Total volume: 19.1 + 58.8 + 61.5 = 139.4 bbls + 25% = 174.3 bbls Procedure Slickline - prep 1. Set catcher. 2. Pull GL valves at 2739’, 4522’ & 5252’. 3. Install dummy valves at 2739’, 4522’, 5252’ & 7648’. 4. Run HF to just above tubing leak at 6680’ and PT tubing to verify integrity. If PT does not pass investigate with HF. 5. Pull catcher. 6. Pull RBP at 7717’. 7. Brush and flush tubing string. 8. Drift tubing for cement retainer (2.75” OD x 84” OAL) down to D nipple at 7722’. 9. Drift and tag as deep as possible for fill depth. 10. RIH with dual spartek gauges to acquire SBHP. a. 10 min lubricator stop b. 30 min stop at 7914’ or just above fill depth c. 15 min stop at 7788’ or 100’ TVD above previous stop 11. 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. 2000 psi max pressure. 12. Freeze protect tubing with 18 bbls diesel. Coil & Cement Unit – plug 1. Cement retainer reservoir plug 13. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Stephen Lauper 907-952-0445). Plug 1 is designed for 30.0 bbls of 15.8 class G cement to isolate the reservoir. 14. RIH with Quadco 2.750” FH cement retainer to set at ~7717’ middle of 10.2’ pup joint (tag 2.75” D nipple at 7722’ for correlation). Pull test < 1000 lbs to verify good set. Perform PT between coil x tubing annulus to verify retainer integrity (this will be a combo coil x tubing x IA due to the tubing leak. 15. Pump down coil through the retainer, performing an injectivity test to verify injectivity for cementing. 16. 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. a. 5 bbls freshwater spacer b. 30.0 bbls 15.8 ppg class G cement c. 5 bbls freshwater spacer d. Coil displacement to surface e. Freeze protect tubing with 18 bbls diesel from 2000’ TVD to surface Slickline – plug 1 test, prep plug 2 17. WOC for 48 hours or until field blend UCA chart shows cement developed 1500 psi compressive strength before proceeding to the AOGCC witnessed Tag and CMIT TxIA. 18. 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). 19. RIH for AOGCC witnessed TOC tag (estimate 7602’ MD / 6339’ TVD) and perform CMIT TxIA (due to tubing leak at 6680’) to 1585 psi (TOC TVD x .25 or 1500 psi, whichever is higher). Record results in WSR. 20. With passing TOC tag and MITT, move forward with subsequent steps. 21. Drift tubing for tubing punches (2” x 5’) down to 7602’ or TOC. 22. RIH to set catcher, pull dummy at 2739’, pull catcher. Eline – prep plug 2 23. RIH with CCL & tubing punches (2” x 5’) to punch tubing at 7595’ or middle of full joint above TOC (estimated 7602’). Correlate to tubing tally/Well View schematic. Use CCL to correlate TOC exact depth so that Coil can use it to tag off. 24. Verify sufficient injectivity by pumping 20 bbls diesel down tubing taking returns of IA to tanks. Target 2BPM at < 1500 psi. Coil & Cement Unit – plug 2. Cement retainer TxIA cement plug from ~6613’ to ~7602’ 25. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Stephen Lauper 907-952-0445). Plug 2 is designed for 34.2 bbls of 15.8 class G cement from 6613’ to 7602’. 26. RIH with Quadco 2.750” FH cement retainer to set at ~6728’ (middle of full joint below tubing leak at 6680’) (tag off TOC depth correlated by Eline CCL). Pull test < 1000 lbs to verify good set. Unable to PT between coil x tubing annulus due to tubing leaks. 27. Pump down coil through the retainer taking returns off the IA to tanks performing an injectivity test to verify injectivity/circulation for cementing. 28. Pumping down coil taking returns off IA to tanks, 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. a. 5 bbls freshwater spacer b. 50 bbls surfactant wash c. 160 bbls freshwater d. 55 bbls diesel (freeze protect for IA) e. 119.3 bbls freshwater f. 34.2 bbls 15.8 ppg class G cement g. 5 bbls freshwater spacer h. Coil displacement to surface i. Freeze protect tubing with 18 bbls diesel. Slickline – plug 2 test, prep plug 3 29. WOC for 24 hours or until field blend UCA chart shows cement developed 1500 psi compressive strength before proceeding. 30. RIH to tag TOC (estimate 6613’ MD). 31. Perform CMIT TxIA to 1500 psi. 32. Drift tubing for tubing punches (2” x 5’) down to 6613’ or TOC. Eline – prep plug 3 33. RIH with tubing punch (2” x 5’) to punch tubing at 6586’ middle of the full joint above the TOC (estimated 6613’). 34. Verify sufficient injectivity by pumping 20 bbls diesel down tubing taking returns of IA to tanks. Target 2BPM at < 1500 psi. Cementing Unit – plug 3. TxIA balanced cement plug from ~2200 to ~6613’. 35. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Stephen Lauper 907-952-0445). Plug 3 is designed for 154.7 bbls of 15.8 ppg class G cement full bore pumped to place a balanced cement plug from ~2200’ to ~6613’. 36. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 37. RU SLB Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the IA (3.5” x 7”). Also ensure that there is a way to pump down the IA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 38. Verify sufficient circulation exists pumping down tubing taking returns off IA to tanks then pump the following schedule: a. 5 bbls freshwater spacer b. 50 bbls surfactant wash c. 160 bbls freshwater d. 31.6 bbls diesel e. 26.4 bbls 9.8 ppg NaCl f. 154.7 bbls 15.8 ppg class G cement g. 8.7 bbls 9.8 ppg NaCl h. 10.4 bbls diesel 39. Clean surface equipment as needed, RDMO. Slickline – plug 3 test, prep plug 4 40. WOC for 24 hours or until field blend UCA chart shows cement developed 1500 psi compressive strength before proceeding. 41. RIH to tag TOC (estimate 2200’ MD). 42. Perform MITT to 1500 psi. If communication to IA the perform CMIT TxIA to 1500 psi. 43. Drift tubing for perf guns (2” x 5’) down to 2100’ or TOC. Eline – prep plug 4 44. RIH with perf guns to perf holes in 3.5” tubing and 7” casing (do not shoot through 9.625” casing) at ~2070’ or middle of full joint (estimated OA cement TOC at 2188’ so targeting ~100’ above OA TOC). 45. Verify sufficient circulation by pumping 20 bbls diesel down tubing taking returns off IA to tanks. Target 2BPM at < 1500 psi. 46. Verify sufficient circulation by pumping 20 bbls diesel down tubing taking returns off OA to tanks. Target 2 BPM at < 1500 psi. o Note any losses from 1:1 returns while performing circulation tests. 47. If insufficient injectivity/circulation is achieved, then re-perf ~ 100’ shallower and reattempt injectivity tests. Cementing Unit – plug 4. Surface plug. 48. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Stephen Lauper 907-952-0445). Plug 4 is designed for 174.3 bbls of 15.7 ppg ArcticSet 1 (AS1) cement with appropriate expansion enhancement additives and gas blocking additives to be full bore pumped to place cement from surface to ~2200 in the tubing, IA, and OA. 49. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 50. RU SLB Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the IA (3.5” x 7”) and OA (7” x 9.625”). Also ensure that there is a way to pump down the IA and OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 51. Verify sufficient circulation and perform a hydrocarbon flush by pumping down the tubing taking returns off the OA: a. 50 bbls of hot diesel (target 100°-140° F for hot fluids) b. 15 bbls hot fresh water c. 50 bbls surfactant wash d. 70 bbls hot fresh water e. Observe water returns, inspect for clean returns. 52. Once clean returns from OA flush is complete, shut in OA. Pump down tubing taking returns off IA. a. 15 bbls hot fresh water b. 50 bbls surfactant wash c. 70 bbls hot fresh water 53. After circulation and flush to IA and OA is complete batch up 174.3 bbls of 15.7 ppg AS1 cement (25% excess). 54. Line up to pump AS1 cement down the tubing, taking returns from the OA 1st then the IA 2nd. 55. Follow Pump Schedule below: 56. After approximately 80.6 bbls of cement is pumped away, expect to see OA cement returns. Pump minimum additional 8 bbls (~10%) and utilize mud density scale to confirm proper weight Permafrost Cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 57. With good OA cement to surface, open the IA, close the OA and line up to take IA returns to tanks. This step must be performed on the fly and efficiently as Permafrost Cement is thixotropic and will develop gel strength quickly when static. 58. After approximately 58.8 bbls of cement is pumped away, expect to see IA cement returns. Pump minimum additional 6 bbls (~10%) then utilize mud density scale to confirm proper weight Permafrost Cement to surface coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 59. After good IA cement is seen at surface, shut down pumps and close in the IA valve. 60. Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 61. RDMO WI / DHD – Final surface work 62. MIRU required equipment. 63. DHD to perform drawdown test on tubing and IA. 64. Remove well house. 65. Bleed off T/I/0 to ensure all pressure is bled off the system. 66. Remove production tree in preparation for excavation and casing cut. 67. Excavate to ~6’ below grade. Install shoring box as needed. 68. Cut off wellhead and all casing strings 4 feet below original ground level. 69. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 70. Send the casing head with stub to materials shop. Photo document. 71. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. ConocoPhillips 1H-17 PTD #: 192-130 API #: 50-029-22314-00-00 72. Remove cellar. Back fill cellar as needed. Back fill remaining hole to ground level. 73. Obtain site clearance approval from AOGCC. RDMO. 74. Provide photos and final site clearance to Engineer for preparation of the 10-407. Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag: DSL MD 8,131.0 8/10/2019 bworthi 1H-17 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Pull DV, Pull CAT-SV, Set RBP, Tubing Leak 10/25/2019 famaj 1H-17 Notes: General & Safety End Date 9/27/2010 Annotation NOTE: View Schematic w/ Alaska Schematic9.0 Wellbore 1H-17 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 43.0 121.0 121.0 62.50 H-40 WELDED 1H-17 SURFACE 9 5/8 8.92 42.3 4,983.1 4,283.0 36.00 J-55 BTC 1H-17 PRODUCTION 7 6.28 38.5 8,437.2 7,010.8 26.00 J-55 BTC 1H-17 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 3 1/2 2.99 38.4 7,734.7 6,444.9 9.30 J-55 ABM-EUE 1H-17 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 38.4 38.4 0.09 HANGER FMC GEN IV HANGER 3.500 1H-17 1,825.1 1,775.0 30.97 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 1H-17 7,695.9 6,413.9 37.19 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 1H-17 7,698.9 6,416.3 37.17 PACKER BAKER FB-1 PERMANENT PACKER (2.5' SPACE OUT ABOVE PKR) 3.000 1H-17 7,722.2 6,434.9 37.09 NIPPLE OTIS XN NIPPLE NO GO 2.750 1H-17 7,733.8 6,444.2 37.05 SOS BAKER SHEAR OUT SUB, ELMD TTL@ 7720' ON SWS DEPTH DETERMINATION 11/2/02 3.015 1H-17 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 6,680.0 5,612.4 37.42 Tubing Leak Tubing Leak at 6680' 10/24/2019 2.992 1H-17 7,717.0 6,430.8 37.10 Bridge Plug 3 1/2" P2P RBP (CPP35037) w/ Equalizing Valve (CPEQ35027) OAL 8.5' Max OD 2.725" 10/25/2019 0.000 1H-17 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 42.3 42.3 0.10 HANGER 8.921 1H-17 43.0 43.0 0.10 CONDUCTOR 15.062 1H-17 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 7,797.0 7,847.0 6,494.7 6,534.7 UNIT D, C-4, 1H- 17 10/9/1993 6.0 APERF Enerjet III; 0 deg Ph 1H-17 7,800.0 7,860.0 6,497.1 6,545.1 C-4, 1H-17 1/9/1994 4.0 RPERF Titan Guns- BH/DP; 180 deg Ph; 1 deg f/ High side 1H-17 7,854.0 7,864.0 6,540.3 6,548.3 C-3, 1H-17 10/8/1993 6.0 APERF Titan Guns- BH/DP; 180 deg Ph; 1 deg f/ High side 1H-17 7,899.0 7,919.0 6,576.3 6,592.4 C-1, 1H-17 1/9/1994 4.0 RPERF Titan Guns- BH/DP; 180 deg PH; 1 deg f/ High side 1H-17 7,899.0 7,929.0 6,576.3 6,600.4 C-1, 1H-17 10/8/1993 6.0 APERF Titan Guns- BH/DP; 180 deg PH; 1 deg f/ High side 1H-17 7,919.0 7,929.0 6,592.4 6,600.4 C-1, UNIT B, 1H- 17 10/8/1993 6.0 APERF SWS 4.5"; 180 deg PH 1H-17 8,118.0 8,143.0 6,752.4 6,772.6 A-4, 1H-17 6/13/1993 4.0 IPERF Enerjet III; 0 deg Ph 1H-17 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in)TRO Run (psi) Run Date Com Wellbore 1 2,739.4 2,503.5 CAMCO KBUG 1 GAS LIFT GLV BK5 0.156 1,335.0 8/6/2007 1H-17 2 4,522.2 3,918.0 CAMCO KBUG 1 GAS LIFT GLV BK5 0.156 1,329.0 8/7/2007 1H-17 3 5,251.9 4,494.0 CAMCO KBUG 1 GAS LIFT OV BK5 0.250 0.0 9/19/2019 1H-17 4 6,043.6 5,109.8 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 8/7/2007 1H-17 5 6,807.4 5,713.6 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 8/7/2007 1H-17 6 7,224.2 6,043.8 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 6/13/1993 1H-17 7 7,648.0 6,375.9 CAMCO MMG-2 1 1/2 GAS LIFT OPEN RK 0.0 10/24/2019 1H-17 Comment 1H-17, 10/26/2019 10:47:12 AM Vertical schematic (actual) PRODUCTION; 38.5- 8,437.2 IPERF; 8,118.0-8,143.0 APERF; 7,919.0-7,929.0 APERF; 7,899.0-7,929.0 RPERF; 7,899.0-7,919.0 APERF; 7,854.0-7,864.0 RPERF; 7,800.0-7,860.0 APERF; 7,797.0-7,847.0 SOS; 7,733.8 NIPPLE; 7,722.2 Bridge Plug; 7,717.0 PACKER; 7,698.9 SEAL ASSY; 7,695.9 GAS LIFT; 7,648.0 GAS LIFT; 7,224.2 GAS LIFT; 6,807.4 Tubing Leak; 6,680.0 GAS LIFT; 6,043.6 GAS LIFT; 5,251.9 SURFACE; 42.3-4,983.1 GAS LIFT; 4,522.2 GAS LIFT; 2,739.4 SAFETY VLV; 1,825.1 CONDUCTOR; 43.0- 121.0 HANGER; 38.4 KUP PROD KB-Grd (ft) Rig Release Date 1/6/1993 Annotation End DateH2S (ppm) 100 Date 11/5/2014... TD Act Btm (ftKB) Well Attributes Field Name Wellbore API/UWI Wellbore Status Max Angle & MD Incl (°) MD (ftKB) Legal Wellname 1H-17 Common Wellname1H-17 AK All Wellbores Schem 1H-17 (PTD 192-130) Proposed P&A schematic 16” 62.5# H-40 Conductor @ 121' KB 9 5/8" 36# J-55 Surface Casing @ 4,983' KB 7" 26# J-55 Production casing @ 8437' KB 9-5/8" surface casing primary cement job: cement to surface 7" production casing primary cement job: Sonic CBT log TOC 7120' 7" x 9-5/8" OA shoe cement job: Calculated TOC 2188'. Cement from 2188'-3669'. Uppermost Kuparuk C-4 perfs at 7797' Tubing leak at 6680' Plug 1 reservoir 30.0 bbls 15.8 PPG class G cement from ~7602' to 8143' Plug 2 Intermediate 34.2 bbls 15.8 class G cement TxIA from ~6613' to 7698' Plug 3 Intermediate 154.7 bbls 15.8 class G cement TxIA from ~2200 to 6613' Plug 4 surface 174.3 bbls 15.7 ppg ArcticSet 1 TxIAxOA from surface to ~2200' Kuparuk formation from 7798' to 8204'. Baker FB-1 Packer at 7698' Tubing tail at 7734' Page 1/5 1H-17 Report Printed: 12/10/2025 Directional Survey API / UWI 5002922314 Legal WellName 1H-17 Field Name KUPARUK RIVER UNIT Well Type Development Original KB/RT Elevation (ft) 96.00 Well Status PROD Wellbore Name 1H-17 Parent Wellbore 1H-17 Vertical Section Direction (°) Date 1/31/1993 As Ran Yes Description Survey #1 Proposed? No MD Tie In (ftKB) TVDTie In (ftKB) Inclination Tie In (°) Azimuth Tie In (°) NSTie In (ft) EWTie In (ft) Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°/100ft) Method Survey Company 1/31/1993 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 G SCHLUMBERG… 1/31/1993 100.13 0.23 196.49 100.13 -0.19 -0.19 -0.06 0.23 G SCHLUMBERG… 1/31/1993 102.40 0.26 194.08 102.39 -0.20 -0.20 -0.06 1.40 G SCHLUMBERG… 1/31/1993 123.52 0.29 191.20 123.52 -0.30 -0.30 -0.08 0.16 G SCHLUMBERG… 1/31/1993 141.67 0.33 186.79 141.67 -0.39 -0.40 -0.10 0.26 G SCHLUMBERG… 1/31/1993 158.86 0.36 180.14 158.86 -0.50 -0.50 -0.10 0.29 G SCHLUMBERG… 1/31/1993 175.56 0.35 173.55 175.56 -0.60 -0.60 -0.10 0.25 G SCHLUMBERG… 1/31/1993 192.62 0.35 171.05 192.62 -0.70 -0.71 -0.08 0.09 G SCHLUMBERG… 1/31/1993 209.61 0.33 165.03 209.61 -0.80 -0.81 -0.06 0.24 G SCHLUMBERG… 1/31/1993 226.84 0.28 162.85 226.83 -0.89 -0.89 -0.04 0.30 G SCHLUMBERG… 1/31/1993 244.32 0.26 165.08 244.32 -0.97 -0.97 -0.01 0.13 G SCHLUMBERG… 1/31/1993 261.68 0.22 169.72 261.68 -1.04 -1.04 0.00 0.26 G SCHLUMBERG… 1/31/1993 279.33 0.22 178.93 279.33 -1.11 -1.11 0.01 0.20 G SCHLUMBERG… 1/31/1993 297.34 0.20 192.70 297.34 -1.18 -1.18 0.00 0.30 G SCHLUMBERG… 1/31/1993 315.45 0.22 199.70 315.45 -1.24 -1.24 -0.02 0.18 G SCHLUMBERG… 1/31/1993 333.92 0.24 203.92 333.92 -1.31 -1.31 -0.04 0.14 G SCHLUMBERG… 1/31/1993 352.66 0.29 200.68 352.65 -1.39 -1.39 -0.08 0.28 G SCHLUMBERG… 1/31/1993 371.39 0.31 198.55 371.39 -1.48 -1.48 -0.11 0.12 G SCHLUMBERG… 1/31/1993 390.32 0.35 195.60 390.32 -1.58 -1.59 -0.14 0.23 G SCHLUMBERG… 1/31/1993 409.28 0.37 191.46 409.28 -1.70 -1.70 -0.17 0.17 G SCHLUMBERG… 1/31/1993 428.51 0.38 185.85 428.51 -1.82 -1.83 -0.19 0.20 G SCHLUMBERG… 1/31/1993 447.67 0.41 179.77 447.67 -1.95 -1.96 -0.19 0.27 G SCHLUMBERG… 1/31/1993 467.06 0.39 171.66 467.05 -2.09 -2.09 -0.18 0.31 G SCHLUMBERG… 1/31/1993 486.42 0.36 171.28 486.41 -2.21 -2.22 -0.17 0.16 G SCHLUMBERG… 1/31/1993 505.81 0.35 171.17 505.80 -2.33 -2.34 -0.15 0.05 G SCHLUMBERG… 1/31/1993 525.33 0.36 166.14 525.32 -2.45 -2.45 -0.12 0.17 G SCHLUMBERG… 1/31/1993 544.78 0.36 164.69 544.78 -2.57 -2.57 -0.09 0.05 G SCHLUMBERG… 1/31/1993 564.27 0.33 162.39 564.26 -2.68 -2.69 -0.06 0.17 G SCHLUMBERG… 1/31/1993 583.89 0.27 164.00 583.88 -2.78 -2.78 -0.03 0.31 G SCHLUMBERG… 1/31/1993 603.44 0.25 167.73 603.44 -2.87 -2.87 -0.01 0.13 G SCHLUMBERG… 1/31/1993 622.60 0.22 168.89 622.60 -2.95 -2.95 0.01 0.16 G SCHLUMBERG… 1/31/1993 641.90 0.14 175.31 641.89 -3.01 -3.01 0.02 0.43 G SCHLUMBERG… 1/31/1993 661.35 0.03 205.91 661.34 -3.03 -3.03 0.02 0.59 G SCHLUMBERG… 1/31/1993 680.54 0.07 327.62 680.54 -3.03 -3.03 0.01 0.47 G SCHLUMBERG… 1/31/1993 699.70 0.12 334.29 699.70 -3.00 -3.00 -0.01 0.27 G SCHLUMBERG… 1/31/1993 718.90 0.16 320.85 718.89 -2.96 -2.96 -0.03 0.27 G SCHLUMBERG… 1/31/1993 738.16 0.11 295.47 738.15 -2.93 -2.93 -0.07 0.40 G SCHLUMBERG… 1/31/1993 757.58 0.28 339.24 757.57 -2.88 -2.88 -0.10 1.10 G SCHLUMBERG… 1/31/1993 776.94 0.74 348.37 776.93 -2.71 -2.71 -0.14 2.41 G SCHLUMBERG… 1/31/1993 796.39 1.26 349.27 796.38 -2.37 -2.38 -0.21 2.67 G SCHLUMBERG… 1/31/1993 815.75 1.72 352.64 815.73 -1.87 -1.88 -0.28 2.42 G SCHLUMBERG… 1/31/1993 835.10 2.33 352.83 835.07 -1.19 -1.21 -0.37 3.15 G SCHLUMBERG… 1/31/1993 854.53 3.09 354.18 854.47 -0.28 -0.29 -0.47 3.93 G SCHLUMBERG… 1/31/1993 874.02 3.83 355.68 873.93 0.90 0.88 -0.57 3.83 G SCHLUMBERG… 1/31/1993 893.47 4.41 355.60 893.33 2.29 2.27 -0.68 2.98 G SCHLUMBERG… 1/31/1993 912.93 5.12 356.21 912.72 3.91 3.88 -0.80 3.66 G SCHLUMBERG… Page 2/5 1H-17 Report Printed: 12/10/2025 Directional Survey Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°/100ft) Method Survey Company 1/31/1993 933.33 6.18 356.28 933.03 5.91 5.89 -0.93 5.19 G SCHLUMBERG… 1/31/1993 952.76 7.12 355.91 952.32 8.16 8.13 -1.08 4.84 G SCHLUMBERG… 1/31/1993 972.34 8.32 356.21 971.73 10.79 10.76 -1.26 6.13 G SCHLUMBERG… 1/31/1993 991.83 9.13 356.31 990.99 13.75 13.71 -1.45 4.16 G SCHLUMBERG… 1/31/1993 1,011.32 10.03 356.19 1,010.21 16.99 16.94 -1.67 4.62 G SCHLUMBERG… 1/31/1993 1,030.87 10.71 356.00 1,029.44 20.50 20.46 -1.91 3.48 G SCHLUMBERG… 1/31/1993 1,050.46 11.32 355.93 1,048.67 24.24 24.19 -2.17 3.12 G SCHLUMBERG… 1/31/1993 1,070.05 11.53 355.93 1,067.87 28.12 28.06 -2.44 1.07 G SCHLUMBERG… 1/31/1993 1,096.39 12.19 356.22 1,093.65 33.53 33.46 -2.82 2.52 G SCHLUMBERG… 1/31/1993 1,135.33 13.08 356.05 1,131.65 42.04 41.96 -3.39 2.29 G SCHLUMBERG… 1/31/1993 1,175.49 14.00 355.54 1,170.69 51.44 51.34 -4.08 2.31 G SCHLUMBERG… 1/31/1993 1,215.68 15.05 355.16 1,209.59 61.50 61.38 -4.90 2.62 G SCHLUMBERG… 1/31/1993 1,256.23 15.68 355.28 1,248.70 72.23 72.09 -5.79 1.56 G SCHLUMBERG… 1/31/1993 1,296.88 16.63 355.45 1,287.74 83.53 83.36 -6.71 2.34 G SCHLUMBERG… 1/31/1993 1,337.53 17.35 355.61 1,326.61 95.39 95.20 -7.63 1.77 G SCHLUMBERG… 1/31/1993 1,378.38 18.46 355.92 1,365.48 107.94 107.73 -8.56 2.73 G SCHLUMBERG… 1/31/1993 1,419.00 19.61 356.28 1,403.88 121.18 120.94 -9.46 2.85 G SCHLUMBERG… 1/31/1993 1,459.02 20.50 356.98 1,441.48 134.90 134.65 -10.26 2.30 G SCHLUMBERG… 1/31/1993 1,499.21 21.15 357.40 1,479.04 149.18 148.92 -10.96 1.66 G SCHLUMBERG… 1/31/1993 1,540.03 21.38 357.86 1,517.08 163.98 163.71 -11.58 0.70 G SCHLUMBERG… 1/31/1993 1,580.77 21.67 358.04 1,554.98 178.93 178.65 -12.11 0.73 G SCHLUMBERG… 1/31/1993 1,621.62 22.29 358.61 1,592.86 194.22 193.93 -12.56 1.61 G SCHLUMBERG… 1/31/1993 1,662.57 23.35 359.15 1,630.60 210.10 209.80 -12.86 2.64 G SCHLUMBERG… 1/31/1993 1,703.77 25.37 359.78 1,668.14 227.09 226.80 -13.02 4.94 G SCHLUMBERG… 1/31/1993 1,744.55 27.09 0.39 1,704.72 245.11 244.82 -12.99 4.27 G SCHLUMBERG… 1/31/1993 1,785.66 29.45 2.16 1,740.92 264.55 264.28 -12.55 6.09 G SCHLUMBERG… 1/31/1993 1,826.61 31.03 3.74 1,776.29 285.09 284.88 -11.48 4.32 G SCHLUMBERG… 1/31/1993 1,867.59 31.29 3.94 1,811.36 306.20 306.03 -10.06 0.68 G SCHLUMBERG… 1/31/1993 1,908.43 31.58 3.81 1,846.21 327.40 327.29 -8.62 0.73 G SCHLUMBERG… 1/31/1993 1,949.51 33.20 2.63 1,880.89 349.31 349.25 -7.39 4.23 G SCHLUMBERG… 1/31/1993 1,990.65 34.82 1.90 1,915.00 372.27 372.25 -6.48 4.06 G SCHLUMBERG… 1/31/1993 2,031.82 36.20 2.20 1,948.51 396.13 396.15 -5.62 3.38 G SCHLUMBERG… 1/31/1993 2,072.74 37.91 2.80 1,981.16 420.71 420.77 -4.55 4.27 G SCHLUMBERG… 1/31/1993 2,113.68 38.11 2.96 2,013.42 445.85 445.96 -3.28 0.54 G SCHLUMBERG… 1/31/1993 2,154.89 38.06 3.15 2,045.86 471.17 471.34 -1.93 0.31 G SCHLUMBERG… 1/31/1993 2,195.34 38.06 3.41 2,077.71 496.02 496.24 -0.50 0.40 G SCHLUMBERG… 1/31/1993 2,235.37 38.06 3.54 2,109.22 520.59 520.87 1.00 0.20 G SCHLUMBERG… 1/31/1993 2,275.23 38.13 3.63 2,140.59 545.08 545.41 2.54 0.22 G SCHLUMBERG… 1/31/1993 2,315.68 38.11 3.74 2,172.42 569.93 570.33 4.14 0.17 G SCHLUMBERG… 1/31/1993 2,356.27 38.25 3.75 2,204.32 594.91 595.36 5.78 0.35 G SCHLUMBERG… 1/31/1993 2,396.72 38.45 2.57 2,236.05 619.91 620.42 7.16 1.88 G SCHLUMBERG… 1/31/1993 2,437.27 38.70 0.68 2,267.75 645.15 645.70 7.88 2.97 G SCHLUMBERG… 1/31/1993 2,477.95 38.73 0.40 2,299.49 670.57 671.14 8.12 0.44 G SCHLUMBERG… 1/31/1993 2,518.44 38.75 0.40 2,331.07 695.89 696.48 8.29 0.05 G SCHLUMBERG… 1/31/1993 2,559.19 38.74 0.37 2,362.85 721.38 721.98 8.47 0.05 G SCHLUMBERG… 1/31/1993 2,599.70 38.67 0.39 2,394.47 746.69 747.31 8.63 0.18 G SCHLUMBERG… 1/31/1993 2,640.45 38.70 0.41 2,426.28 772.15 772.78 8.81 0.08 G SCHLUMBERG… 1/31/1993 2,681.10 38.66 0.44 2,458.01 797.53 798.19 9.00 0.11 G SCHLUMBERG… 1/31/1993 2,721.36 38.69 0.43 2,489.44 822.67 823.34 9.19 0.08 G SCHLUMBERG… 1/31/1993 2,761.81 38.67 359.87 2,521.02 847.94 848.62 9.26 0.87 G SCHLUMBERG… 1/31/1993 2,802.33 38.61 358.23 2,552.67 873.23 873.92 8.84 2.53 G SCHLUMBERG… 1/31/1993 2,842.62 38.63 357.89 2,584.15 898.38 899.05 7.99 0.53 G SCHLUMBERG… 1/31/1993 2,882.68 38.56 357.90 2,615.46 923.37 924.02 7.07 0.18 G SCHLUMBERG… 1/31/1993 2,922.93 38.44 357.85 2,646.96 948.43 949.06 6.14 0.31 G SCHLUMBERG… Page 3/5 1H-17 Report Printed: 12/10/2025 Directional Survey Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°/100ft) Method Survey Company 1/31/1993 2,962.43 38.23 357.71 2,677.95 972.93 973.55 5.19 0.58 G SCHLUMBERG… 1/31/1993 3,001.97 38.04 357.62 2,709.04 997.34 997.94 4.20 0.50 G SCHLUMBERG… 1/31/1993 3,041.37 37.97 357.54 2,740.09 1,021.60 1,022.18 3.17 0.22 G SCHLUMBERG… 1/31/1993 3,080.91 37.80 357.63 2,771.29 1,045.87 1,046.44 2.15 0.45 G SCHLUMBERG… 1/31/1993 3,120.51 37.65 357.63 2,802.61 1,070.10 1,070.64 1.15 0.38 G SCHLUMBERG… 1/31/1993 3,160.70 37.57 357.71 2,834.45 1,094.63 1,095.15 0.15 0.23 G SCHLUMBERG… 1/31/1993 3,200.16 37.51 357.66 2,865.75 1,118.68 1,119.18 -0.82 0.17 G SCHLUMBERG… 1/31/1993 3,239.60 37.43 357.70 2,897.05 1,142.67 1,143.15 -1.79 0.21 G SCHLUMBERG… 1/31/1993 3,279.27 37.42 357.75 2,928.55 1,166.77 1,167.24 -2.75 0.08 G SCHLUMBERG… 1/31/1993 3,318.77 37.42 357.86 2,959.92 1,190.77 1,191.22 -3.67 0.17 G SCHLUMBERG… 1/31/1993 3,358.23 37.26 357.98 2,991.30 1,214.71 1,215.15 -4.54 0.45 G SCHLUMBERG… 1/31/1993 3,397.74 37.37 358.08 3,022.71 1,238.66 1,239.08 -5.36 0.32 G SCHLUMBERG… 1/31/1993 3,437.34 37.70 358.22 3,054.12 1,262.78 1,263.19 -6.14 0.86 G SCHLUMBERG… 1/31/1993 3,476.71 37.81 358.31 3,085.24 1,286.89 1,287.29 -6.87 0.31 G SCHLUMBERG… 1/31/1993 3,515.85 37.37 358.42 3,116.26 1,310.77 1,311.15 -7.55 1.14 G SCHLUMBERG… 1/31/1993 3,555.09 36.49 358.46 3,147.62 1,334.34 1,334.72 -8.19 2.24 G SCHLUMBERG… 1/31/1993 3,594.39 35.84 358.80 3,179.35 1,357.53 1,357.91 -8.75 1.73 G SCHLUMBERG… 1/31/1993 3,633.76 35.56 359.03 3,211.33 1,380.51 1,380.88 -9.18 0.79 G SCHLUMBERG… 1/31/1993 3,672.74 35.51 359.19 3,243.04 1,403.16 1,403.53 -9.54 0.27 G SCHLUMBERG… 1/31/1993 3,711.32 35.51 359.20 3,274.45 1,425.57 1,425.94 -9.85 0.02 G SCHLUMBERG… 1/31/1993 3,749.97 36.17 359.42 3,305.78 1,448.19 1,448.56 -10.12 1.74 G SCHLUMBERG… 1/31/1993 3,788.48 37.69 359.95 3,336.57 1,471.32 1,471.70 -10.25 4.03 G SCHLUMBERG… 1/31/1993 3,827.10 38.30 0.23 3,367.00 1,495.08 1,495.48 -10.21 1.64 G SCHLUMBERG… 1/31/1993 3,865.62 38.29 0.17 3,397.23 1,518.94 1,519.35 -10.13 0.10 G SCHLUMBERG… 1/31/1993 3,904.13 38.07 0.10 3,427.51 1,542.73 1,543.15 -10.07 0.58 G SCHLUMBERG… 1/31/1993 3,942.78 38.06 0.09 3,457.94 1,566.55 1,566.98 -10.03 0.03 G SCHLUMBERG… 1/31/1993 3,981.43 38.03 0.06 3,488.37 1,590.36 1,590.80 -10.00 0.09 G SCHLUMBERG… 1/31/1993 4,020.14 37.94 0.02 3,518.89 1,614.17 1,614.63 -9.98 0.24 G SCHLUMBERG… 1/31/1993 4,059.25 37.84 359.85 3,549.75 1,638.18 1,638.65 -10.01 0.37 G SCHLUMBERG… 1/31/1993 4,098.62 37.79 359.97 3,580.85 1,662.31 1,662.78 -10.05 0.23 G SCHLUMBERG… 1/31/1993 4,137.60 37.60 359.95 3,611.69 1,686.13 1,686.62 -10.07 0.49 G SCHLUMBERG… 1/31/1993 4,177.20 37.58 359.84 3,643.07 1,710.27 1,710.77 -10.11 0.18 G SCHLUMBERG… 1/31/1993 4,217.52 37.47 359.85 3,675.05 1,734.83 1,735.33 -10.18 0.27 G SCHLUMBERG… 1/31/1993 4,258.07 37.41 359.92 3,707.25 1,759.47 1,759.98 -10.23 0.18 G SCHLUMBERG… 1/31/1993 4,299.02 37.33 0.03 3,739.79 1,784.31 1,784.84 -10.24 0.25 G SCHLUMBERG… 1/31/1993 4,339.73 37.25 360.00 3,772.18 1,808.96 1,809.50 -10.23 0.20 G SCHLUMBERG… 1/31/1993 4,380.68 37.13 359.88 3,804.80 1,833.70 1,834.25 -10.26 0.34 G SCHLUMBERG… 1/31/1993 4,421.29 36.98 359.74 3,837.21 1,858.17 1,858.73 -10.34 0.42 G SCHLUMBERG… 1/31/1993 4,461.58 36.81 359.48 3,869.43 1,882.35 1,882.91 -10.50 0.57 G SCHLUMBERG… 1/31/1993 4,501.71 36.73 359.33 3,901.57 1,906.36 1,906.93 -10.75 0.30 G SCHLUMBERG… 1/31/1993 4,542.16 37.01 359.25 3,933.94 1,930.63 1,931.20 -11.05 0.70 G SCHLUMBERG… 1/31/1993 4,582.38 37.58 359.18 3,965.93 1,955.00 1,955.57 -11.39 1.42 G SCHLUMBERG… 1/31/1993 4,622.51 37.81 359.10 3,997.68 1,979.53 1,980.10 -11.76 0.59 G SCHLUMBERG… 1/31/1993 4,663.09 37.61 359.01 4,029.79 2,004.35 2,004.92 -12.16 0.51 G SCHLUMBERG… 1/31/1993 4,703.41 37.34 358.98 4,061.79 2,028.88 2,029.45 -12.59 0.67 G SCHLUMBERG… 1/31/1993 4,743.77 37.17 358.89 4,093.91 2,053.31 2,053.88 -13.05 0.44 G SCHLUMBERG… 1/31/1993 4,784.06 37.01 358.83 4,126.05 2,077.60 2,078.17 -13.53 0.41 G SCHLUMBERG… 1/31/1993 4,824.25 37.41 358.78 4,158.06 2,101.91 2,102.47 -14.04 1.00 G SCHLUMBERG… 1/31/1993 4,864.76 38.10 358.77 4,190.09 2,126.71 2,127.27 -14.57 1.70 G SCHLUMBERG… 1/31/1993 4,905.09 38.43 358.72 4,221.75 2,151.68 2,152.24 -15.12 0.82 G SCHLUMBERG… 1/31/1993 4,945.60 38.41 358.67 4,253.50 2,176.86 2,177.41 -15.69 0.09 G SCHLUMBERG… 1/31/1993 4,985.99 37.98 358.28 4,285.24 2,201.84 2,202.37 -16.35 1.22 G SCHLUMBERG… 1/31/1993 5,026.51 38.08 358.05 4,317.15 2,226.80 2,227.32 -17.15 0.43 G SCHLUMBERG… 1/31/1993 5,066.80 38.20 358.01 4,348.84 2,251.68 2,252.19 -18.01 0.30 G SCHLUMBERG… Page 4/5 1H-17 Report Printed: 12/10/2025 Directional Survey Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°/100ft) Method Survey Company 1/31/1993 5,107.41 38.29 357.93 4,380.74 2,276.82 2,277.32 -18.90 0.25 G SCHLUMBERG… 1/31/1993 5,147.47 38.34 357.94 4,412.17 2,301.66 2,302.14 -19.80 0.13 G SCHLUMBERG… 1/31/1993 5,187.27 38.40 357.88 4,443.37 2,326.36 2,326.82 -20.70 0.18 G SCHLUMBERG… 1/31/1993 5,227.07 38.43 357.75 4,474.55 2,351.09 2,351.53 -21.64 0.22 G SCHLUMBERG… 1/31/1993 5,266.93 38.37 357.56 4,505.79 2,375.85 2,376.27 -22.65 0.33 G SCHLUMBERG… 1/31/1993 5,306.73 38.44 357.53 4,536.98 2,400.57 2,400.97 -23.71 0.18 G SCHLUMBERG… 1/31/1993 5,346.49 38.48 357.40 4,568.12 2,425.30 2,425.68 -24.81 0.23 G SCHLUMBERG… 1/31/1993 5,386.29 38.54 357.40 4,599.26 2,450.07 2,450.43 -25.93 0.15 G SCHLUMBERG… 1/31/1993 5,426.08 38.54 357.38 4,630.38 2,474.87 2,475.20 -27.06 0.03 G SCHLUMBERG… 1/31/1993 5,465.98 38.51 357.17 4,661.60 2,499.71 2,500.02 -28.24 0.34 G SCHLUMBERG… 1/31/1993 5,505.12 38.54 357.08 4,692.22 2,524.09 2,524.37 -29.46 0.16 G SCHLUMBERG… 1/31/1993 5,545.14 38.59 357.09 4,723.51 2,549.03 2,549.29 -30.73 0.13 G SCHLUMBERG… 1/31/1993 5,584.84 38.58 356.86 4,754.54 2,573.79 2,574.02 -32.04 0.36 G SCHLUMBERG… 1/31/1993 5,624.57 38.68 356.72 4,785.58 2,598.58 2,598.78 -33.43 0.33 G SCHLUMBERG… 1/31/1993 5,664.37 38.84 356.54 4,816.61 2,623.49 2,623.65 -34.89 0.49 G SCHLUMBERG… 1/31/1993 5,704.40 39.04 356.52 4,847.75 2,648.63 2,648.76 -36.41 0.50 G SCHLUMBERG… 1/31/1993 5,744.19 39.21 356.45 4,878.62 2,673.73 2,673.83 -37.95 0.44 G SCHLUMBERG… 1/31/1993 5,784.06 39.29 356.35 4,909.49 2,698.94 2,699.00 -39.54 0.26 G SCHLUMBERG… 1/31/1993 5,823.79 39.41 356.29 4,940.21 2,724.12 2,724.14 -41.15 0.32 G SCHLUMBERG… 1/31/1993 5,863.48 39.49 356.26 4,970.87 2,749.33 2,749.31 -42.79 0.21 G SCHLUMBERG… 1/31/1993 5,902.72 39.50 356.25 5,001.15 2,774.27 2,774.21 -44.42 0.03 G SCHLUMBERG… 1/31/1993 5,941.83 39.56 356.18 5,031.31 2,799.14 2,799.05 -46.07 0.19 G SCHLUMBERG… 1/31/1993 5,980.97 39.53 356.10 5,061.49 2,824.05 2,823.91 -47.74 0.15 G SCHLUMBERG… 1/31/1993 6,020.18 39.60 356.03 5,091.72 2,849.00 2,848.83 -49.46 0.21 G SCHLUMBERG… 1/31/1993 6,057.61 39.69 356.03 5,120.54 2,872.87 2,872.65 -51.11 0.24 G SCHLUMBERG… 1/31/1993 6,094.23 39.57 356.02 5,148.74 2,896.20 2,895.95 -52.73 0.33 G SCHLUMBERG… 1/31/1993 6,130.45 38.79 356.60 5,176.82 2,919.07 2,918.79 -54.20 2.38 G SCHLUMBERG… 1/31/1993 6,167.32 38.09 357.48 5,205.70 2,941.99 2,941.68 -55.39 2.41 G SCHLUMBERG… 1/31/1993 6,204.23 38.05 357.44 5,234.76 2,964.75 2,964.42 -56.40 0.13 G SCHLUMBERG… 1/31/1993 6,241.37 38.01 357.32 5,264.01 2,987.63 2,987.27 -57.44 0.23 G SCHLUMBERG… 1/31/1993 6,278.31 37.93 357.23 5,293.14 3,010.35 3,009.98 -58.53 0.26 G SCHLUMBERG… 1/31/1993 6,315.26 37.83 357.09 5,322.29 3,033.03 3,032.63 -59.65 0.36 G SCHLUMBERG… 1/31/1993 6,352.03 37.66 357.00 5,351.38 3,055.54 3,055.12 -60.81 0.49 G SCHLUMBERG… 1/31/1993 6,389.14 37.41 356.78 5,380.80 3,078.14 3,077.69 -62.04 0.76 G SCHLUMBERG… 1/31/1993 6,426.21 37.29 356.63 5,410.27 3,100.63 3,100.14 -63.33 0.41 G SCHLUMBERG… 1/31/1993 6,463.19 37.08 356.43 5,439.73 3,122.96 3,122.45 -64.68 0.66 G SCHLUMBERG… 1/31/1993 6,500.13 36.99 356.24 5,469.22 3,145.20 3,144.66 -66.10 0.39 G SCHLUMBERG… 1/31/1993 6,537.24 37.15 356.14 5,498.83 3,167.56 3,166.97 -67.59 0.46 G SCHLUMBERG… 1/31/1993 6,573.39 37.14 355.99 5,527.65 3,189.37 3,188.75 -69.09 0.25 G SCHLUMBERG… 1/31/1993 6,609.81 37.27 355.92 5,556.65 3,211.37 3,210.72 -70.64 0.38 G SCHLUMBERG… 1/31/1993 6,646.06 37.39 355.85 5,585.48 3,233.34 3,232.65 -72.22 0.35 G SCHLUMBERG… 1/31/1993 6,682.15 37.42 355.79 5,614.15 3,255.24 3,254.51 -73.82 0.13 G SCHLUMBERG… 1/31/1993 6,716.99 37.42 355.76 5,641.82 3,276.39 3,275.63 -75.38 0.05 G SCHLUMBERG… 1/31/1993 6,753.18 37.43 355.74 5,670.56 3,298.37 3,297.56 -77.01 0.04 G SCHLUMBERG… 1/31/1993 6,789.27 37.34 355.66 5,699.23 3,320.26 3,319.41 -78.65 0.28 G SCHLUMBERG… 1/31/1993 6,825.62 37.35 355.50 5,728.13 3,342.28 3,341.39 -80.35 0.27 G SCHLUMBERG… 1/31/1993 6,861.94 37.33 355.44 5,757.01 3,364.29 3,363.35 -82.09 0.11 G SCHLUMBERG… 1/31/1993 6,898.06 37.24 355.42 5,785.75 3,386.14 3,385.17 -83.83 0.25 G SCHLUMBERG… 1/31/1993 6,934.42 37.32 355.35 5,814.67 3,408.13 3,407.11 -85.60 0.25 G SCHLUMBERG… 1/31/1993 6,970.60 37.42 355.30 5,843.43 3,430.07 3,429.00 -87.39 0.29 G SCHLUMBERG… 1/31/1993 7,006.86 37.45 355.29 5,872.22 3,452.08 3,450.97 -89.20 0.08 G SCHLUMBERG… 1/31/1993 7,043.14 37.36 355.17 5,901.04 3,474.09 3,472.93 -91.04 0.32 G SCHLUMBERG… 1/31/1993 7,080.58 37.32 355.15 5,930.80 3,496.76 3,495.56 -92.95 0.11 G SCHLUMBERG… 1/31/1993 7,119.55 37.51 355.40 5,961.76 3,520.41 3,519.16 -94.90 0.62 G SCHLUMBERG… Page 5/5 1H-17 Report Printed: 12/10/2025 Directional Survey Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°/100ft) Method Survey Company 1/31/1993 7,159.28 38.31 356.20 5,993.11 3,544.80 3,543.50 -96.69 2.36 G SCHLUMBERG… 1/31/1993 7,198.98 38.72 356.77 6,024.17 3,569.51 3,568.18 -98.20 1.37 G SCHLUMBERG… 1/31/1993 7,238.48 38.80 356.84 6,054.97 3,594.23 3,592.87 -99.58 0.23 G SCHLUMBERG… 1/31/1993 7,277.33 38.89 356.67 6,085.23 3,618.59 3,617.19 -100.96 0.36 G SCHLUMBERG… 1/31/1993 7,316.14 38.84 356.76 6,115.45 3,642.93 3,641.51 -102.36 0.19 G SCHLUMBERG… 1/31/1993 7,354.43 38.68 356.64 6,145.30 3,666.90 3,665.44 -103.74 0.46 G SCHLUMBERG… 1/31/1993 7,393.93 38.73 356.55 6,176.13 3,691.59 3,690.10 -105.20 0.19 G SCHLUMBERG… 1/31/1993 7,433.89 38.61 356.64 6,207.33 3,716.54 3,715.02 -106.69 0.33 G SCHLUMBERG… 1/31/1993 7,474.31 38.42 356.68 6,238.95 3,741.71 3,740.15 -108.15 0.47 G SCHLUMBERG… 1/31/1993 7,514.63 38.17 356.76 6,270.60 3,766.68 3,765.10 -109.58 0.63 G SCHLUMBERG… 1/31/1993 7,554.86 38.12 356.99 6,302.23 3,791.52 3,789.90 -110.94 0.37 G SCHLUMBERG… 1/31/1993 7,594.98 37.78 357.11 6,333.87 3,816.19 3,814.55 -112.21 0.87 G SCHLUMBERG… 1/31/1993 7,633.73 37.61 357.50 6,364.53 3,839.88 3,838.21 -113.32 0.76 G SCHLUMBERG… 1/31/1993 7,672.64 37.29 357.86 6,395.42 3,863.54 3,861.85 -114.28 1.00 G SCHLUMBERG… 1/31/1993 7,711.35 37.12 357.85 6,426.26 3,886.95 3,885.24 -115.16 0.44 G SCHLUMBERG… 1/31/1993 7,750.00 37.00 357.86 6,457.10 3,910.24 3,908.52 -116.03 0.31 G SCHLUMBERG… 1/31/1993 7,788.58 36.84 358.01 6,487.95 3,933.42 3,931.68 -116.86 0.48 G SCHLUMBERG… 1/31/1993 7,827.33 36.74 357.96 6,518.97 3,956.62 3,954.87 -117.68 0.27 G SCHLUMBERG… 1/31/1993 7,866.17 36.86 357.95 6,550.08 3,979.89 3,978.13 -118.51 0.31 G SCHLUMBERG… 1/31/1993 7,904.76 36.85 357.90 6,580.95 4,003.03 4,001.25 -119.35 0.08 G SCHLUMBERG… 1/31/1993 7,942.81 36.79 357.82 6,611.42 4,025.84 4,024.04 -120.20 0.20 G SCHLUMBERG… 1/31/1993 7,968.31 36.63 357.75 6,631.85 4,041.08 4,039.27 -120.79 0.65 G SCHLUMBERG… 1/31/1993 7,984.22 36.56 357.76 6,644.63 4,050.56 4,048.75 -121.16 0.44 G SCHLUMBERG… 1/31/1993 7,999.48 36.51 357.77 6,656.89 4,059.64 4,057.83 -121.51 0.33 G SCHLUMBERG… 1/31/1993 8,014.67 36.46 357.74 6,669.10 4,068.67 4,066.85 -121.87 0.35 G SCHLUMBERG… 1/31/1993 8,030.31 36.43 357.71 6,681.69 4,077.97 4,076.14 -122.24 0.22 G SCHLUMBERG… 1/31/1993 8,046.16 36.36 357.71 6,694.44 4,087.37 4,085.53 -122.61 0.44 G SCHLUMBERG… 1/31/1993 8,062.01 36.31 357.72 6,707.21 4,096.76 4,094.92 -122.99 0.32 G SCHLUMBERG… 1/31/1993 8,077.82 36.26 357.68 6,719.96 4,106.12 4,104.27 -123.36 0.35 G SCHLUMBERG… 1/31/1993 8,093.64 36.22 357.58 6,732.71 4,115.47 4,113.61 -123.75 0.45 G SCHLUMBERG… 1/31/1993 8,118.47 36.14 357.53 6,752.76 4,130.13 4,128.26 -124.37 0.34 G SCHLUMBERG… 1/31/1993 8,143.64 36.00 357.50 6,773.10 4,144.94 4,143.06 -125.02 0.56 G SCHLUMBERG… 1/31/1993 8,168.93 36.05 357.57 6,793.56 4,159.82 4,157.92 -125.66 0.26 G SCHLUMBERG… 1/31/1993 8,194.13 36.04 357.50 6,813.93 4,174.64 4,172.73 -126.29 0.17 G SCHLUMBERG… 1/31/1993 8,217.72 35.97 357.45 6,833.01 4,188.51 4,186.59 -126.90 0.32 G SCHLUMBERG… 1/31/1993 8,240.42 36.00 357.44 6,851.38 4,201.85 4,199.91 -127.50 0.13 G SCHLUMBERG… 1/31/1993 8,263.75 35.90 357.43 6,870.27 4,215.54 4,213.60 -128.11 0.43 G SCHLUMBERG… 1/31/1993 8,285.43 35.88 357.51 6,887.84 4,228.25 4,226.30 -128.67 0.23 G SCHLUMBERG… 1/31/1993 8,300.33 35.91 357.50 6,899.90 4,236.99 4,235.02 -129.05 0.21 G SCHLUMBERG… 1/31/1993 8,300.43 35.90 357.51 6,899.98 4,237.04 4,235.08 -129.06 11.72 G SCHLUMBERG… 1/31/1993 8,454.99 35.90 357.51 7,025.18 4,327.67 4,325.62 -132.99 0.00 G SCHLUMBERG… WELL LOG TRANSMITTAL #906036485 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Plug Setting Record: 1H-17 Run Date: 10/24/2019 and 10/25/2019 192130 3160 1 November 21, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com IH -17 DECEIVED Digital Data in LAS format, Digital Log file DEC 0 9 2019 1 CD Rom 50-029-22314-00 AQ G C C PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: op Signed: WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Static Bottom Hole Pressure Record: 1H-17 Run Date: 8/9/2019 192130 3 135 6 October 16, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1H-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22314-00 RECEIVED OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton. com Date: /0�j2v/ Signed; • ConocoPhillips s p Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 SCANNED SEP 2 0 2016 December 19,2015 Commissioner Cathy Foerster i• CI — 3 Alaska Oil & Gas Commission 1 k, ( 7 333 West 7th Avenue, Suite 100 [1 Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Roger Winter at 907-659-7043 or 943-1055, if you have any questions. Sincere , / Roger Winter ConocoPhillips Well Integrity Field Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 12/19/2015 1H-17,2F-17&2L-311 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1H-17 50029223140000 1921300 8" N/A 8" N/A 5.8 12/6/2015 2F-17 50029227310000 1962040 9" NA 9" NA 5.5 12/6/2015 2L-311 50103204690000 2031550 10" NA 10" NA 3.4 12/6/2015 STATE OF ALASKA AL OIL AND GAS CONSERVATION COM ION REPT OF SUNDRY WELL OPERA IONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r- Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Conductor Ext p- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ' Exploratory r 192-130 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service I! 50-029-22314-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025639 • KRU 1H-17 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 8455 • feet Plugs(measured) None true vertical 7025 • feet Junk(measured) None Effective Depth measured 8346 feet Packer(measured) 7699 true vertical 6937 feet (true vertical) 6416 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 0 0 SURFACE 4941 12 4983 4281 0 0 PRODUCTION 8399 7 8437 7010 0 0 ''i .l Perforation depth: Measured depth: 7797-8143 >iN�� ' " a. r True Vertical Depth: 6495-6773 . NO v I . Tubing(size,grade,MD,and TVD) 3.5,J-55,7734 MD, 6444 TVD / (4 Packers&SSSV(type,MD,and TVD) PACKER-BAKER FB-1 PERMANENT PACKER @ 7699 MD and 6416 TVD SSSV-CAMCO TRDP-4A SAFTY VALVE @ MD= 1825 TVD= 1775 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: • Daily Report of Well Operations F, Exploratory r Development F, Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F, Gas r VVDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WWJ r WAG r GINJ r • SUSP r SPLUG r 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: 315-658 Contact MJ Loveland Email n1878nconocophillips.com Printed Name MJ Loveland Title WI Project Supervisor Signature P 159-7043 Date 11/11/2015 V'77.— Form 10-404 Revised 5/2015 6 <<G RBDMS4,NOV 16 2015 Submit Original Only //,3--%6 • ConocoPhillips Alaska e # P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 11, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1H-17, PTD 192-130, Sundry 315-658, conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, /77/ e MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 1H-17 • DESCRIPTION OF WORK COMPLETED SUMMARY Date 11/11/1;Event Summary 11/09/15 Welded a 8"conductor extension onto existing conductor due to rising wellhead. OF T�j,, Alaska Oil and Gas �w • \� �� sA THE STATE ofAConservation Commission LAsKA c ; 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALASI1e' Fax: 907.276.7542 www.aogcc.alaska.gov SCONG MJ Loveland WI Project Supervisor c� ' Q ConocoPhillips Alaska, Inc. t �+ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-17 Sundry Number: 315-658 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this day of October, 2015 Encl. RBDMST 2 6 2015 STATE OF ALASKA • •KA OIL AND GAS CONSERVATION COMMON • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing E Operations shutdown 1— Suspend Suspend r Perforate r Other Stimulate E Alter Casing r Change Approved E Plug for Redrill r Perforate New Pool E Repair Well r Re-enter Susp Well Other:Conductor Ext 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development F' 192-130 • 3.Address: 6.API Number: Stratigraphic r Service I— P.O. Box 100360,Anchorage,Alaska 99510 50-029-22314-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F KRU 1H-17 • 9.Property Designation(Lease Number): 10.Field/Pool(s): I)CT 2 1 ,y L �� ADL0025639 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY 0 d S lcaiL /5 Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measurecO GCC 8455 . 7025 , 8346' . 6937' • None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 121' 121' 0 0 SURFACE 4941 12 4983' 4281' 0 0 PRODUCTION 8399 7 8437' 7010' 0 0 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7797-8143 N 6495-6773 3.5 J-55 7734 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FB-1 PERMANENT PACKER(2.5'SPACE OUT A MD=7699 TVD=6416 e SSSV-CAMCO TRDP-4A SAFTY VALVE MD=1825 TVD=1775 - 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch r Exploratory r Stratigraphic E Development Service r 14.Estimated Date for Commencing Operation 11/2/2015 15. Well Status after proposed work: WINJ r WDSPL E Suspended E OIL F' 16.Verbal Approval: Date: GAS E WAG r GSTOR r SPLUG 1— Commission Commission Representative: GINJ r Op Shutdown E Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland Email: n1878conocophillips.com Printed Name MJ Lovela d i Title: WI Project Supervisor Signature A/4// 7(71 Phone:659-7043 Date 10/19/15 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3/5' 51? Plug Integrity E BOP Test r Mechanical Integrity Test r Location Clearance E Other: Spacing Exception Required? Yes 0 No I/ Subsequent Form Required: f® 4 C� e-}- i ii , APPROVED BY Approved by: y_.., �pp MIS TONER THE COMMISSION Date: (' -73--(S ..roved a plication is valid for 12 month fro the Edatc o approval. / Submit Form and Form 10-403 Revise.5/2015 I• R I I N A L i'��Z 'S Attachments in Duplicate VTC �/z3/t (��� RBDMS1`' k 2 6 2015 • • • RECEIVED ConocoPhillips OCT 21 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 19, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1H-17, PTD 192-130 conductor extension. Please contact MJ Loveland at 659-7043 if you have any questions. Sincerely, 0 MJ Love and ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 111-17 (PTD 192-130) SUNDRY NOTICE 10-403 APPROVAL REQUEST October 19, 2015 This application for Sundry approval for Kuparuk well 1H-17 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 8". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP PROD • 1H-17 t ConocoPhillips e, Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cnnnrnldltipa 500292231400 KUPARUK RIVER UNIT PROD 39.69 6,057.61 8,455.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-17.4/22/20152:0758 PM SSSV:TRDP 100 11/5/2014 Last WO: 1/6/1993 Vertical schematic(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,097.0 4/20/2015 Rev Reason:TAG !shall( 4/22/2015 HANGER'38.4 Casing Strings -r--- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED 11- ir Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread SURFACE 9 5/8 8.921 42.3 4,983.1 4,283.0 36.00 J-55 BTC f Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR;43.0-121.0 PRODUCTION 7 6.276 38.5 8,437.2 7,010.8 26.00 J-55 BTC Tubing Strings :. Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 38.4 7,734.7 6444.9 9.30 J-55 ABM-EUE SAFETY VLV;1.825.1 11 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 38.4 38.4 0.09 HANGER FMC GEN IV HANGER 3.500 1,825.1 1,775.0 30.97 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 GAS LIFT;2,739.4 i. 7,695.9 6,413.9 37.19 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 7,698.9 6,416.3 37.17 PACKER BAKER FB-1 PERMANENT PACKER(2.5 SPACE OUT 3.000 ABOVE PKR) 7,722.2 6,434.9 37.09 NIPPLE OTIS XN NIPPLE NO GO 2.750 GAS LIFT;4.522.2 7,733.8 6,444.2 37.05 SOS BAKER SHEAR OUT SUB,ELMD TTL@ 7720'ON SWS 3.015 DEPTH DETERMINATION 11/2/02 Perforations&Slots Shot Den Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) 6,494.7 (ftKB) Zone Date t) Type Com 7,797.0 7,847.0 6,534.7 UNIT D,C-4, 10/9/1993 6.0 APERF Enerjet III;0 deg Ph SURFACE;42.34,983.1-• I, 1H-17 7,800.0 7,860.0 6,497.1 6,545.1 C-4,1H-17 1/9/1994 4.0 RPERF Titan Guns-BH/DP;180 deg Ph;1 deg f/High GAS LIFT;5,251.9 i z- side I 7,854.0 7,864.0 6,540.3 6,548.3 C-3,1H-17 10/8/1993 6.0 APERF Titan Guns-BH/DP;180 deg Ph;1 deg f/High GAS LIFT,6,043.6 side 7,899.0 7,929.0 6,576.3 6,600.4'C-1,1H-17 10/8/1993 6.0 APERF Titan Guns-BH/DP;180 II deg PH;1 deg f/High GAS LIFT;6,807.4 Side 7,899.0 7,919.0 6,576.3 6,592.4 C-1,1H-17 1/9/1994 4.0 RPERF Titan Guns-BH/DP;180 deg PH;1 deg f/High side GAS LIFT;7,224.2 7,919.0 7,929.0 6,592.4 6,600.4 C-1,UNIT B, 10/8/1993 6.0 APERF SWS 4.5";180 deg PH I 1H-17 8,118.0 8,143.0 6,752.4 6,772.6 A-4,1H-17 6/13/1993 4.0 IPERF Enerjet III;0 deg Ph Mandrel Inserts GAS LIFT;7,648.0 St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Madel OD(in) Sery Type Type (in) (psi) Run Date Com 2,739.4 2,503.5 CAMCO KBUG 1 GAS LIFT GLV BK5 0.156 1,335.0 8/6/2007 2 4,522.2 3,918.0 CAMCO KBUG 1 GAS LIFT GLV BK5 0.156 1,329.0 8/7/2007 3 5,251.9 4,494.0 CAMCO KBUG 1 GAS LIFT OV BK5 0.250 0.0 8/7/2007 SEAL ASSY;7,695.9 ? 4 6,043.6 5,109.8 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 8/7/2007 5 6,807.4' 5,713.6 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 8/7/2007 6 7,224.2 6,043.8 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 6/13/1993 PACKER;7,698.9 °'ti7 7,648.0 6.375.9 CAMCO MMG-2 11/2 GAS LIFT DMY RK 0.000 0.0 8/6/2007 Notes:General&Safety End Date Annotation NIPPLE;7.7222 9/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 SOS;7,733.8 k APERF;7,797.0-7,847.01 RPERF;7,800.0.7,860.0-� APERF;7,854.0-7.864 0-.--4 RPERF;7,899.0-7,919.0L_ APERF;7,899.D-7.829.DAPERF;7,919.0-7,929.D-" 1- IPERF;8.118.0-8,143.D PRODUCTION;38.5-8,437.2 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 18, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 g i3iz°� �,.K.BENDER Anchorage, Alaska 99501 EP 01. ZJtJ RE: Production Profile: 1H-17 = Run Date: 7/16/2015 ' C:44: Run The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1H-17 Digital Data in LAS format,Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22314-00 Production Profile Log 1 Color Log 50-029-22314-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. SC11NE ' Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6-e4tizat • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 11, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 7 k ~t ~,,}~1; RE: Production Profile:lH-17 ~°"~-' ~~~ ''~ ~::~ ~...:a ~% . Run Date: 7/9/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 lII-17 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22314-00 Production Profile Log 1 Color Log 50-029-22314-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood Date: ~U G y ~ ,~ 010 O~ mss. i&siors e q ~.- T3v ~~ Signed: . . ConocóPhillips Alaska RECEIVED APR 1 8 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 16, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SGf.WAIED APR 1 8 20D7 \ q ~ \30 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~ ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field ADril16,2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft aal 1 C-25 119-031 9'4" 0.8 14" 4/14/2007 3.8 4/15/2007 1 C-119 201-139 25'6" 4.8 16" 4/14/2007 5.4 4/15/2007 1C-121 201-080 11' 2.0 18" 4/8/2007 8.6 4/15/2007 1C-131 201-185 12' 1" 1.8 16" 4/8/2007 6.8 4/15/2007 1C-135 201-220 11' 1.3 10" 4/8/2007 2.4 4/15/2007 1 C-172 203-095 10' 8" 1.5 18" 4/14/2007 6.6 4/15/2007 1 H-02 193-008 14' 6" 2.0 4/5/2007 3.3 4/15/2007 1 H-09 193-029 11" n/a 11" n/a 4.9 4/15/2007 1 H-17 192-130 20" n/a 20" n/a 7.5 4/15/2007 . . Conoc;';hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 .:'J~ ""C,·"'> March 4, 2007 A!ì!chQ~3ge Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notice's for Co chilli s Alaska Inc. We1l1H-09 (PTD# 193-029, 10-403# 307-029) & welllH-l TD# 192-130, 10-403# 307-030). The Sundry Notices regards extension of conductor. There was no amage associateWlth the repairs, so no photos are submitted. Please call MJ Loveland or myself at 907-659-7043 if you havè"ãñÿ qùëstlòñs:- ,.' -..' ~ c D~ S!~NEP MAR 2 0 2007 Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor . . RECEIVED MAR 0 7 2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~.~. na 2. r.~C! rnn!t Commission 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 ........nw -::;".: ~ Other Ancho ge Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. 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 0 192-130/ .- 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22314-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' - 1 H-17 , 8. Property Designation: 10. Field/Pool(s): ADL 25639'P.LK 646 Kuparuk River Field / Kuparuk Oil Pool / 11. Present Well Condition Summary: Total Depth measured 8455' - feet true vertical 7025' .- feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 4885' 9-5/8" 4981' 4281' PROD. CASING 8340' 7" 8436' 7010' Perforation depth: Measured depth: intervals frm 7800-7864, 7899-7929, 8118-8143' true vertical depth: intervals frm 6497-6548', 6576-6600', 6752-6773 Tubing (size, grade, and measured depth)' 3-1/2" , J-55, 7735' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FB-1' PERM (2.5' SPACE OUT ABOVE PKR) pkr= 7699' SSSV=SSSV SSSV=1825' 12. Stimulation or cement squeeze summary: Intervals treated (measured) RBDMS 8Ft MAR 1 9 2U07 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CaSing Pressure Tubina Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 0 .- 0 Development Service Daily Report of Well Operations_X 16. Well Status after proposed work: oil0 GasD WAG 0 GlNJD WINJD WDSPLD 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: 307-030 Contact MJ Loveland! Jerry Dethlefs F Printed Name è LovelandlJr~rb Title Well Integrity Proj Supervisor ... Signature Phone 659-7043 Date 3/4/07 ~C'_--/I / _L<'.. -0 Form 10-404 Revised 04/2004 OR\G\NAL #-;( f\ .AS.Þ 34 '7 4' ø~ Submit Original Only . . . 1H-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/24/2006 Conductor has subsided 2' down below top of flutes. T/I/O=SII1100/400. Conductor has subsided 2' below top of flutes. Appears that conductor TOC @ SF of subsided conductor. Will need to remove cellar gravel to expose all of the conductor top to weld on extension for adding sealant. 1/19/2007 Submitted request 10-403 Sundry Approval to extend the conductor 1/26/2007 AOGCC approved 10-403 # 307-030 for surface casing extension. Notify Inspector to witness work and submit photos with 10-404. 3/3/2007 Notify state (Chuck) inspector (did not wish to witness), extend conductor 20" f/sealant project. . . SARAH PALIN, GOVERNOR AI~SKA OIL AlO) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Well Integrity Proj Supervisors ConocoPhillips Alaska, Inc. PO Box 100360 SCANNED JAN 2 5 l007 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1H-17 Sundry Number: 307-030 '0.'Y 0° Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, J Chai DATED this tf, day of January, 2007 Enc!. . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED JAN 2 3 2007 Alaska Oil & Gas Cons. Commission Anchorage January 19,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. wells IH-09 (193-029) and IH-17 (192-130). The request is for approval to extend the conductors that have subsided back to original height. Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. SU;;/iL M~d Problem Well Supervisor Attachments tP?S //':< ~~ . . RECEIVED 1" Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver D Other D Alter casing 0 Repair well D Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 192-130 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22314-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes D No 0 1 H-17 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25639 ALK 646 RKB 96' Kuparuk River Field I Kuparuk Oil Pool ~ 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8455' 7025' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 4885' 9-5/8" 4981' 4281 . PROD. CASING 8340' 7" 8436' 7010 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): intervals frm 7800-7864, 7899-7929,8118-8143' intervals frm 6497-6548', 6576-6600', 6752-6773 3-1/2" J-55 7735' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'FB-1' PERM (2.5' SPACE OUT ABOVE PKR) pkr= 7699' SSSV= SSSV SSSV= 1825' 13. Attachments: . Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 2/10/07 Oil 0 Gas D Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: /' 18. I "''''by oortify thm th, fo""o'o, I, In" 00' OO''''~'''''. Contact: MJ Lovelandl Jerry Dethlefs Printed Name MJ Loveland/ Jerrv Dethlefs Title: Well Integrity Proj Supervisors Signature .d7J/ £,r L:> ./ Phone 7043 Date /'1 Y CU'II r\:J :)" / / Commission Use Only \ , Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .:807,..O~ Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other:~\o Q~~~ ~c;t~ \\-~~J..~_b~~ ~~~ " Subsequent Form Required: l-\\) L\ ûÞ) RBDMS 8Ft JA.N 2 9 2D07 APPROVED BY Date: 1--3' ,.0 r Approved by: () rrí1< [u( tI THE COMMISSION Form 10-403 Revised 06/2006 V I \ì \...; ~ in - . Submit in t STATE OF ALASKA \ 3 2 7 ALASKA OIL AND GAS CONSERVATION COMMISSION (-;}'? JAN 2 00 APPLICATION FOR SUNDRY APPROV AWaska Oil & Gas Cons. Cnmmission 20 MC 25.280 Anchorage .Ab I ~J.~ ~~.I.ø? . . ConocoPhilIips Alaska, Inc. Kuparuk Well1H-17 (PTD 192-130) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 19, 2007 This application for Sundry approval for Kuparuk welllH-17 is to extend the conductor to original height so as to prevent any further corrosion to SC. This well is a single casing producer. It was completed in January 1993 and is currently on line. At some point during normal operations the conductor subsided about 2 feet. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor. 2. Examine SC below where landing ring was for any corrosion damage. 3. Install anti-corrosion coating onSC as specified by CPAI Corrosion Engineer. 4. Extend the conductor to braiden head and fill the void with cement and top off with sealant. 5. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor . 05/07 /05 ~.J :(ß t~~ ',~t 11/28/06 ScblumbBPgep NO. 4054 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NO\{ ~~, ~) 'lmln Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ..' '" W;'1,;ç.:~) /'\:.~ '~r""""'P' 1 ~ d - 13u:;;)~' ",.. Field: Kuparuk Well Job# Log Description Date BL Color CD 3B-13 11415652 PROD PROFILE W/DEFT 11/16/06 1 3&-07 11502019 SBHP SURVEY 11/19/06 1 3S~1 0 11502020 SBHP SURVEY 11/19/06 1 1 E-24A 11502021 SBHP SURVEY 11/20/06 1 1Y ·23 11502022 PROD PROFILE WIDEFT 11/23/06 1 1H·17 11502023 SBHP SURVEY 11/24/06 1 1A-17 11502024 SBHP SURVEY 11/24/06 1 3G-09 11486082 SBHP SURVEY 11/25/06 1 3B-08 11486081 SBHP SURVEY 11/25/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ê -11- ~ . . 08/22/06 Scblumbel'gel' RECE\VEqCAN)~J:n f.\\JG 2: ~j AüG 2 3 Z006 NO. 3936 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 commission ..ja..<1Œ Oil & ~~~:~ t t:) 9 -l3Ò Field: Kuparuk Well Job# Color CD Log Description Date BL 2E-05 11249943 SBHP SURVEY 08/08/06 1 1 J-1 09 11235392 CBUUSIT 08/07/06 1 3Q-11 11213793 LDL 08/14/06 1 2T -28 11235394 INJECTION PROFILE 08/16/06 1 1H-17 11213794 PROD PROFILE W/DEFT 08/15/06 1 1 L-22 11235395 INJECTION PROFILE 08/17/06 1 1 J-166 40013010 MD VISION RESISTIVITY 01/19/06 1 1 1J-166 40013010 TVD VISION RESISTIVITY 01/19/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2879 Company' Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 06~24~O3 Field: Kuparuk Well Job # Log Description Date BL Color CD 3S-17A .'~O~ -(~'J~ .~t SBHP SURVEY 05/07/03 3S-06 '~C"~L'~ "~"~ ~1 PERF RECORD W/SBHP & JEWELRY LOG 05/25/03 3S-08B ~-~L~ PROD PROFILE W/TEMP SURVEY 05/24/03 1 3S-23 ~ '~ ~' PRODUCTION PROFILE 05/~ O/O3 1 1H-17~ ' ~ PRODUCTION PROFILE 051~4/03 1 2U-08 '~-~ ~ SBHP SURVEY 05/09/03 1 1R-14 t~l'-l.~ ~ ~ LDL 05/08/03 3F-01 j~5-~,~.~ PRODUCTION PROFILE 05/19/03 19-103 ~-~ MEM PSP INJECTION PROFILE 04/04/03 3S-17A~0.~ ~ 23361 SCMT 05107/03 36-06 :.~~ , 23353 SCMT 05123/03 SIGNED: ~"~. ,,r,~. ~. ~~/',N,,/-~. DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. F' E R H I T D ,& T A T D A "f A._P !_ U S 92 I:0 4.07 "~ COHF' DA'f 'E:06--. 14 ..... 93 ., 9 ~ ..... i30 [2'AiLY \',! ~ .-... . c. LL OP, :~r'4 DRILLINq I"-IiSTORY SUB ....... S!.IRFACE DIRE,CT~ 0 7/'J 5// 'i 9 9 3 r) 3 / 'l !:::;,; 1 fi (l:~ ' ' ffNHANCE ._ 8z[8 ..... ~4.22 , f) 8/3 (i,l 1 g 9 3 .-,_~... ' r.,H: 4 9 8 i c. ~. -l-- (j 1 8 0 '3/' 1/: / 'J !::t 93 9 2" i ?,~ 0 C [~ m b LI (,2 t-,I ('J 3 Il 'J t:-'. / 'j ,(.) 9 ,~')~ ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 4, 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 82--" LccO 1H-06 Stimulate ~7-.--t -~:)1 H-1 7- Stimulate ~q-~::/(¢ 2X-1 5 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) FTR030496 (w/o atch) RECEIVED Aissk~ 0;,', &- Gas Cons. C3mmissio¢. 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 X Plugging __ Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 12. 5. Type of Well: .Development X Exploratory _ Stratigraphic _ Service Location of well at surface EO.)~{~ tG 642' FNL, 1156' FEL, Sec 33, T12N, RIO At top of productive interval 1987' FNL, 1273' FEL, Sec 28, T12N, RIOE, UM At effective depth 1660' FNL, 1286' FEL, Sec 28, T12N, RIOE, UM At total depth 1596' FNL, 1289' FEL, Sec 28, T12N, RIOE, UM Present well condition summary Total Depth: measured true vertical 8455 feet 7025 feet tNAL 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-17 9. Permit number/approval number 92-130 10. APl number 5o-029-22314 feet 11. Field/Pool Kuparuk River Field/ Oil Pool Plugs (measured) None Effective depth: measured 8 3 4 6 true vertical 6937 feet feet Junk (measured) None Casing Length Structural Conductor 1 2 1 ' Surface 4939' Intermediate Production 8 3 9 8' Liner Perforation depth: measured 7797'-7847', true vertical 6495'-6535', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7735' Packers and SSSV (type and measured depth) PKR: Size Cemented Measured depth True vertical depth I 6" 200 SX PFC 121' 121 ' 9.625" 950 SX PF E & 4981' 4281' 480 SX Class G 7" 270 SX Class G 8 4 3 6' 7 01 O' 7854'-7864', 7899'-7929', 8118'-8143' 6540'-6548', 6576'-6600', 6752'-6772' Baker 'FB-I' Perm @ 7699'; SSSV: Camco TRDP-4A @ 1825' 13. Stimulation or cement squeeze summary 14. Refractured "C" Sands on 1/22/94. . _.' ,:::' !_,':'_:;; ..... ~",.,r,--'-='~. Intervals treated (measured) ,.5~ii~;:~3r~,~~ 7797'-7929' Treatment description including volumes used and final pressure Pumped 25.6 Mlbs of 16/20 & 12/18 ceramic proppant into form., fp was 5630 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 279 40 0 550 345 Subsequent to operation 349 89 0 1450 355 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service hereby ertify that the foregoing is true and correct to the best of my knowledge. Si~ned " Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE FRAO 1 .S~lM_U LATION W~LL NO: t H -~ ] . AFC: ~ c~-1 b~5 . DA~: fl -. 2. P_--c~ ~ PROCEDURE DA'I~: i-" ~O,'- ~ H BEGIN FRAC: oc~?_,_~. .... SERVICE CO: '~::::k~t::,] ZONE: ~ ., ANNULUS PRESS: ~ ~ PSI TEST UNES TO:__~?/'I~ · .. P~FS: 77q~ - ~.9 gq_ i S~AGE VO.L J ,~ F'LUID I.P~'oP CONC. PROP SIZE RATE/BP.M) pRESSURE , i . ~ 57.5 " ".., ~ ~g/tg " ~_~ i L Il II · ~_ , · i . Il I I I , ISIP: FLUID TO R'ECOV~R:'- - .~.7/~ SAND tN ZONE: .,_ e,~5'~ ~ ITI~MIZED COST: i:RAC: PSi AVG. PRESS: -- JOB COMPLE"I'~', / tD~(o H.,~. _ SAND IN CASING: _.1~: , HOT OIL SERVICE: ,,~: 9 _ TRUCKING: /; SUPERVISION: P5 File SUPERVISOF~ $ JO,3. IO'd ~00'ON 17S'Z ~6,£E N~JE ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 14, 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 ~;'~ -It~¢1 1F-15 Perforate ¢i~-Ii~e 1 H-1 7 Perforate ~k-~q¥ 1Q-12 Stimulate c/.:5_ ucj 1Y~17 Stimulate 9~q 1Y-28 Stimulate ¢/o., 13,~ 3G-04 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED FEB 1 6 1994 A~as~ Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,SiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate ~ Plugging ___ Perforate X_ Pull tubing . Alter casing Repair well Other _ -' 5. Type of Well: 6. Datum elevation (DF or KB) 2. Name of Operator Development X ARCO Alaska. In(;. Exploratory RKB 96 feet 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic _ Service 4. Location of well at surface 642' FNL, 1156' FEL, Sec 33, T12N, R10E, UM At top of productive interval 1987' FNL, 1273' FEL, Sec 28, T12N, R10E, UM At effective depth 1660' FNL, 1286' FEL, Sec 28, T12N, R10E, UM At total depth 1596' FNL, 1289' FEL, Sec 28, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8455 feet 7 0 2 5 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-17 9. Permit number/approval number 92-130 10. APl number 50-029-22314 11. Field/Pool Kuparuk River Field/ Oil Pool Plugs (measured) None Effective depth: measured 8 3 4 6 true vertical 6937 feet feet Junk (measured) None Casing Length Structural Conductor 1 21 ' Surface 4 9 3 9' Intermediate Production 8 3 9 8' Liner Perforation depth: measured 7797'-7847', true vertical 6495'-6535', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7735' Packers and SSSV (type and measured depth) PKR: Size 16" 9.625" 7" Cemented 200 SX PFC 950 SX PF E & 480 SX Class G 270 SX Class G Measured depth 121' 4981 ' 8436' True vertical depth 121' 4281 ' 7010' 7854'-7864', 6540'-6548', 7899'-7929' 6576'-6600' 8118'-8143' 6752'-6772' Baker 'FB-I' Perm @ 7699'; SSSV: Camco TRDP-4A @ 1825' RECEIVED 13. Stimulation or cement squeeze summary Reperforated "C134" Sands on 1/9/94 @ 4spf, 180° phasing. Intervals treated (measured) 7800'-7860', 7899'-7919' Treatment description including volumes used and final pressure N/A Ai~.ska Oil & Gas Cons. C0mmissi0P, Anchorage., 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 279 40 0 550 345 349 ''/''' 89 0 1450 355 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~ ~,, //V~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date 2-/q-~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL 114-1'1 DATE DAY TIME D~DO trio- !~46 . DESCRIPTION OF WORK CONTRACTOR/KEY PERSON .~chl. / /_,. OPERATION AT REPORT TIME I~ COMPLETE [-] INCOMPLETE LOGENTRY SI'~P - ~\00 ?~ [ FIELD EST: $ ~ ~.,~,q AFC/CC ACCUMULATED COST $ ~[u, - ~o~t , ?[~ t.o~i~ Ha, CP- "(_~'" pS'~ PAGE1OF J PI~ ,'RIN to glO0' ELM . 'Ro, N 5-{-r~,> Lo~ ~cl.~lOO-"lOP, o'., ~e-i~ ',.Correld~ LID Gu.~ , OJ{ 5ko'l'~ -Fired. · · · ~e.P~r~c. 'C' 5'~ ¢f ~fo' o~ 'f,'f'~ &.u4; , 4sPF, · 7qlq - 7Bqq ~--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK R~ort °~ °F milos AFI~B-70gl IR Lb v Wind Vel. knots ~,,!asku Oil & Ga~ Cu.u. Cum,.ission Anchorage I Signed~ ~' ~~4~ ~'0~ 298-~6 ARCO Alaska, Inc. Post Office Bo. .)360 Anchorage, Alaska 99510-0360 Telephone 907 276 !215 November 9, 1993 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 ?._- '5 ,,,, ~ Perforate '1E-10 Stimulate fl :~-c~ 1H-01 Stimulate flS-:z~ 1H-09 Perforate c~.- ~o 1H-10 Stimulate ,~_5~, 1 H-11 Stimulate a z-~i¥o 1 H- 1 7Stimulate 8~- z~rl Q-04 Stimulate Q-04 Perforate ~55-b~ 1Y-03 Other (conversion) ~5-~t~1Y-04 Other (conversion) If you have any questions, please call me at 263-4241. · ,. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED NOV 12 1993 Alaska Oil & Gas Cons. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,51ON /'~_ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other ~. Name of Operator 5. Type of Well:ExploratoryDeVelopment X ! 6. Datum elevation (DF o~"~B)RKB ~)6 feet~;;~"{ ARCO Alaska. Iris, 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic Service _ 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-17 9. Permit number/approval number 92-130 10. APl number 50-029-22314 11. Field/Pool Kuparuk River Oil Field/Pool 4. Location of well at surface 642' FNL, 1156' FEL, Sec 33, T12N, R10E, UM At top of productive interval 1987' FNL, 1273' FEL, Sec 28, T12N, R10E, UM At effective depth 1660' FNL, 1286' FEL, Sec 28, T12N, R10E, UM At total depth 1596' FNL, 1289' FEL, Sec 28, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 8 4 5 5 feet true vertical 7 0 2 5 feet Plugs (measured) None Effective depth: measured 8 3 4 6 feet true vertical 6937 feet Junk (measured) None Casing Length Size Structural Conductor 1 21 ' 1 6" Surface 4939' 9.625" Intermediate Production 8398' 7" Liner Perforation depth: measured 7797'-7847', true vertical 6495'-6535', Cemented 2OO SX PFC 950 SX PF E & 480 SX Class G 270 SX Class G Measured depth True vertical depth 121' 121' 4981 ' 4281 ' 8436' 7010' 7854'-7864', 7899'-7929', 8118'-8143' 6540'-6548', 6576'-6600', 6752'-6772' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7735' Packers and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 7699'; SSSV: Camco TRDP-4A @ 1825' 13. Stimulation or cement squeeze summary 14. RECEIVED I~LI ¥ I (_ IJJtl Acidized "C134" Sands on 10/24/93. At~ska 0~1 & Gas Cons. Commissior Intervals treated (measured) 7797'-7847', 7854'-7864', 7899'-7929' Anchorage Treatment description including volumes used and final pressure Pumped 25 bbl diesel/N2, 3000 scf N2, & 21.2 bbl nitrified acid, 12% HCI and 500 scf/bbl N2. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 392 13 8 65O 276 Subsequent to operation 380 315 3 525 287 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '"~~~,, ~--~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. 0 Subsidiary of Atlantic Richfield Company WELL DESCRIPTION OF WORK 1 H- 17 Matrix Acid Stimulation DATE CONTRACTOR / KEY PERSON 10/24/93 Dowell / Yoakum DAY 1 PBTD (RKB) 8346' LAST TAG (RKB) - DATE 8244' - 9/13/93 KUPARUK RIVER UNIT WELL SERVICE REPORT IAgC/C¢# - SCA# I 997625 - 80528 IFIELD COST F_.ST. [ACCUMIJLATED COST I$8,099 ! $8,099 ISSSV TYPE / STATUS [Camco TRDP-4A / In service TIME LOG ENTRY 1115 MIRU from 1H-11. Hold safety meeting. PT lines to 4000g. SI well 1145 1153 1255 1204 Cut rate to 1 bpm at 500 scfm. 1208 21.2 bbls acid pumped with 500 scf/bbl N2. SD N2 and acid. Final pressure 1845#. 1235 1240 WHP 481#. Start 25 bbl diesel preflush. Final pressure 1250g SD diesel pump and switch to straight N2 at 2000 scfm. Pump 3000 scf. 3000 scf pumped. Cut N2 rate to 1000 scfm and start acid pump at 2 bpm. Final pressure1687#. Start pumping 69.5 bbl. diesel displacement. Displacement complete. SD pumps and secure well. oroduction. !~'~ ~ rJ ~,r~'~ TM ,-:. ::~,'~ c,,r.. ,. c !. ! ~. ~.: RDMO. Return well to I~.~/, .~ !..', , Pumped 21.2 bbl nitrified acid stimulation with Dowell's MSR 150 system, 12% HCL and 500 scf/bbl. N2. Preflushed job with 25 bbls N2 followed by a 3000 scf N2 spacer. Displaced acid/N2 to perforations with neat diesel. Returned well to production. t, lov -t 2 Gas Cons. O0mmiss~on CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK iW' "V.I. I Report 10 °F -10 °F I fog m..I 7 mph! COMPLETE .C, . ,,% 6 s tra da INCOMPLETE ARCO Alaska, Inc:. .... Post Office × 100360 Anchorage, .,aska 99510-0360 Telephone 907 276 1215 October 29, 1993 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 Stimulate Perforate Perforate If you. have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering -*,P, CO ,A:as,~a fnc. ;-~ a Subsidiary Of AtlanticRichheldCompany STATE OF ALASKA AL.ASt~ OIL AND G/~ ~RVATION COMMIS,~ON OF SUNDRY WELL OPERATIONS REPORT 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) AR(~O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development Exploratory _ RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-17 9. Permit number/approval number 92-130 10. APl number so-029-22314 11. Field/Pool Kuparuk River Oil Field/Pool Stratigraphic Service 4. Location of well at surface 642' FNL, 1156' FEL, Sec 33, T12N, R10E, UM At top of productive interval 1987' FNL, 1273' FEL, Sec 28, T12N, R10E, UM At effective depth 1660' FNL, 1286' FEL, Sec 28, T12N, R10E, UM At total depth 1596' FNL, 1289' FEL, Sec 28, T12N, R10E~ UM 12. Present well condition summary Total Depth: measured 8 4 5 5 feet true vertical 7 0 2 5 feet Plugs (measured) None Effective depth: measured 8 3 4 6 feet true vertical 6937 feet Junk (measured) None Casing Length Size Structural Conductor 1 21 ' 1 6" Surface 4 9 3 9' 9.62 5" Intermediate Production 83 9 8' 7" Liner Perforation depth: measured 7797'-7847', true vertical 6495'-6535', Cemented 2OO SX PFC 95O SX PF E & 480 SX Class G 270 SX Class G 7854'-7864', 6540'-6548', SSSV: Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7735' Packers and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 7699'; 13. Stimulation or cement squeeze summary 14. Measured depth True vertical depth 121' 121' 4981 ' 4281 ' 8436' 7010' 7899'-7929', 8118'-8143' 6576'-6600', 6752'-6772' Camco TRDP-4A @ 1825' Perforated "C134" Sands on 10/8-9/93. Intervals treated (measured) 7797'-7847', 7854'-7864', 7899'-7929' Treatment description including volumes used and final pressure 6 spf @ 0° phasing. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Anchorage Tubing Pressure Prior to well operation Subsequent to operation 111 ~-~24 0 750 . 43O 95 9 650 210 276 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned "~~ ~'. ~~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. O Subsidiary of Atlantic Richfield Company WELL DESCR/PTION OF WORK 1H-17 DATE 10/8/93 DAY 1 TIME 1245 1322 1410 1515 1525 1530 1545' 1630 1715 1745 Perforate C1, 3 &34 sands COlqTRACTOR / KEY PERSON Schlumberger / Rathert PBTD (RKB) LAST TAG (RKB) - DATE 8346' 8244'- 9/13/93 LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT ]AFC/CC# . SCA# ! 997625 - 80223 InZLD COSX V. ST. IACCUMULATED COST I$10,166 I $10,,166 ., ISSSV TYPE / STATUS ICAMCO TRDP-4A / In service MIRU. Held safety meeting. PT'd to 3(X)0g. NU with 1.375" RS, 18" CCL, 22"x 2.125" magnet, 10"x 2.125" gun head, 30'x 2.125" strip gun. Gun loaded with 6 spf, Enerjet llI, RDX charges at 0° phasing. 5' from CCL to to]? shot. RIH. Encountered thick fluid at 1900'. Stand by for diesel pump. RU diesel pump. PT to 3(X)0g and displace tubing while continuing running in the hole. Tied in with CBT log. Pull up and stop at 7894' CCL (7899' top shot). Open well and perforate 7899' to 7929' rkb underbalanced. SI well and log jewelry from short joints up to GLM #7. POOH. All shots fired. NU with 10' gun and 6' x 1-11/16" WB. 5' CCL to top shot. RIH. Tie in and pull up to 7849' CCL (7854' top shot). Open well. Perforate 7854' to 7864' rkb. SI well. POOH. All shots fired. Summary: Perforated C1 sands, 7854' to 7864' and C3 sands, 7899' to 7929' rkb with Enerjet III guns, RDX charges, 0° phasing, underbalanced. KUn ^ nl,~' nt-'rar,~ ~l I~ FkI~INFFRIN~ CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather Temp. I Chill Factor Visibility Wind Vel. [Signed I Report 35 °F CLR miles 2 mph[ COMPLETE .c. ,9. estrada INCOMPLETE ARCO Alaska, Inc. g} Subsidiary of Atlantic Richfield Company WELL DESCRIFTION OF WORK 1 H- 17 Perforate C 1, 3 &34 sands DATE 10/9/93 DAY 2 TIME 0800 0904 1005 1115 1153 1230 CONTRACTOR/KEY PERSON Schlumberger / Rathert PBTD (RKB) ILAST TAG (RKB)- DATE 8346' ! 8244'- 9/13/93 LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# . SCA# [ 997625 - 80223 IFIELD COST EST. IACCUMULATED COST :1 $12,078 I $22,244 ISSSV TYPE / STATUS ICAMCO TRDP-4A / In service RU. Held safety meeting. PT'd to 30(0. NU with 1.375" RS, 18" CCL, 22" x 2.125" magnet, 10" x 2.125" gun head, 24'x 2.125" strip gun. Gun loaded with 6 spf, Enerjet III, RDX charges at 0° phasing. 5' from CCL to top shot. RIH. Open well to production. Tie in with CBT. Pull up to 7818' CCL (7823' top shot). Perforate 7823' - 7847' rkb. SI well. POOH. All shots fired. NU with 26' gun. 5' from CCL to top shot. RIH. Tie in. Pull up to 7792' CCL (7797' top shot). Open well. Perforate 7797' to 7823' rkb. SI well and POOH. All shots fired. RD. Move unit to 3G- 17. Summary: Perforating C 34 sands from 7797' to 7847' rkb with Enerjet 1II guns, 6 spf, 0° phasing RDX charges, underbalanced. C 1,3 & 34 zones perforated. Hole diameter .31" Explosive load 14 grams. XUr'A~UK PE'(RULbUM ENGINEERING CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK W th r F c or [v a m y Report 33 °F 12 °F [ Fog miles 15 mph[ COMPLETE .13. ~. ~ s trada INCOMPLETE STATE OF ALASKA ~ OIL AND GAS CONSERVATION ~MIS,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing ~ Alter casing Stimulate ~( Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 642' FNL, 1156' FEL, Sec 33, T12N, R10E, UM At top of productive interval 1987' FNL, 1273' FEL, Sec 28, T12N, R10E, UM At effective depth 1660' FNL, 1286' FEL, Sec 28, T12N, R10E, UM At total depth 1596' FNL, 1289' FEL, Sec 28, T12N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 4 5 5 feet true vertical 7025 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1H-17 9. Permit number/approval number 92-130 10. APl number 50-029-22314 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8 3 4 6 feet true vertical 6937 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 121' 16" 4939' 9.625" 8398' 7" measured 8118'-8143' true vertical 6752'-6772' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7735' Packers and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 7699'; Cemented Measured depth True vertical depth 200 SX PFC CMT 950 SX PF E CMT & 480 SX Class G CMT 270 SX Class G CMT 121' 121' 4981 ' 4281 ' 8436' 7010' RECEIVED SSSV: Camco TRDP-4A @ 1825' OCT - 1 1993 Alaska 0il & Gas cons. [;ornmissi~ Anchorage 13. Stimulation or cement squeeze summary Fractured "A" Sands on 9/9/93. Intervals treated (measured) 81 18'-8143' Treatment description including volumes used and final pressure Pumped 24 Mlbs of 16/20 & 110 Mlbs of 12/18 Carbolite ceramic proppant~ ftp was 6580 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1 49 ~J~'3 5 3 1150 120 /- 1 5 0 2 0 0 700 250 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector_ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned "~~~' '~t'/~~ Title Senior Engineer Form 10-404 Rev 08/15/88 SUBMIT IN DUPLICATE ~/D~ILLINb Procedure Date: Service Co: Annulus Press: AFE: - Zone' ~ , Test Lines To: (/~/_~0 . . KUP/',,,RUK P'ETRC~LEU~ ENGINEERING _ · __ STAGE VOL FLUID PROP ~0 ISIP. _~?o _ Fluid to Recover: RATE PRESSURE · ,,,,,,! {~... Sand In Csg: Job Compl e te: ADC' $' ---- i! TA/mJ k/3100/104 2127187 · - m . OCT - 1 199~ Alaska 0il & Gas Cons. L;ornrfliss~u,- Anchorage ig SuperV~- RECEIVED 15 Min: T_9,a,o ., Avg Press: ' ~q'?O psi ~:ez.',,LQ Sand In Zone- 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~ items. receipt and return one signed copy of this transmittal. Please acknowledge 1 H-15 ,"CDR Enhancement 2-27-93 LWD/Depth Corrected 1H-1 7 --"'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 Receipt Acknowledged: DISTRIBUTION: D&M Drilling 5-02-93 1-21-93 1-12-93 3-26-93 4-05-93 4-12-93 4-14-93 Date: 9678-10337 7848-8422 7052-7320 9568-9802 8398-8993 7988-8632 4392-7512 5960-9772 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 Classification of Service Well O,L ~ GAS [--1 SUSPENDED I--1 ABANDONED [] SERV,CE I--I ~)~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 92-130 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22314 ;1 ~~~. 9 Unit or Lease Name 4 Location of well at surface hl ~,d,~-.,'~-'~"l~ ~' 642' FNL, 1156' FEL, SEC 33, T 12N, R 10E, U,~, --DATE. ~ KUPARUK RIVER At Top Producing Interval ~ ~'~ '~'~'~-~. l ~. ~.~r ! 10 Well Number 1987' FNL, 1273' EEL, SEC 28, T 12N, R 10E, 1EI."M ~t~FIEO ~ 1H-17 At Total Depth"~ ...."'-'"~._~.~.~-~ ~~ 11 Field and Pool 1596' FNL, 1289' FEL, SEC 28, T 12N, R 10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 96', PAD 54' GL ADL 25639 ALK 464 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 29-Dec-92 05-Jan-93 06/14/93.(0omp)I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost 8455' MD, 7025' TVD 8346' MD, 6937' TVD YES ~ NO L_J 1819' feet MDI 1600' APPROX 22 Type Electric or Other Logs Run CDR, CDN, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SE'firING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF 121' 24" 200 SX PFC CMT 9.625" 36# J-55 SURF 4981' 12.25" 950 SX PF E CMT, 480 SX CLASS G CMT 7" 26# J-55 SURF 8436' 8.5" 270 SX CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9.3# J-55 7735' 7699' 8118'-8143' @ 4 SPF W/4.5" CSG GUN MD 6753'-6773' TVD 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.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ¢~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .R..~____~_~., ,~ V., .~.~. .~il!_ 1 .~ 1993 Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, ~ MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . :. TOP OF KUPARUK C 7794' 6492' BASE OF KUPARUK© 791 6' 6590' TOP OF KUPARUK A 8089' 6729' BASE OF KUPARUK A 8199' 6818' ~ ,_, *-,1~ ~. :: :~. 31. LIST OF ATTACHMENTS 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 ~L.~¢--,)'~ ~___¢---'.~ . DATE ~~ - /. / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1H-17 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL25639 ALK 464 50-029-22314 92-130 ACCEPT: 12/29/92 08:30 SPUD: 12/29/92 02:30 RELEASE: 06/14/93 03:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 12/30/92 (1) PARKER 245 TD: 2090'( o) 12/31/92 (2) PARKER 245 TD: 4865' (2775) 01/01/93 (3) PARKER 245 TD: 5005' ( 140) DRILLING MW:10.5 VIS: 68 MVE RIG F/1H-20 TO 1H-17. ACCEPT RIG @ 0830 ON 12/29/92. NU 20" ANNULAR & DIVERTER LINES. FUNCTION TEST ANNULAR & DIVERTER SYSTEM. TEST WITNESSSED BY STATE-JOHN SPAULDING. PU BHA & ORIENT. CLEAN OUT 16" CSG TO 121'. SPUD @ 121' AND DRILL TO 376' LINE PLUGGED W/GRAVEL. CLEAN OUT DISCFLO TANK AND REPLACE DISCFLO PMP. DRILL F/376'-1569' CIRC & RAISE MUD WT TO 10.5. DRILL F/1589'-2090' SLIDING AS NEEDED. ADT=l.25 DRILLING MW:10.8 VIS: 61 DRILL TO 2210'_ CIRC GAS CUT MUD, CUT- TO 7.9 PPG. DRILL & MWD SURVEY TO 3624' CBU. MUD GAS CUT TO 9.5 PPG. DRILL TO 3717' CBU. MUD GAS CUT TO 9.6 PPG. DRILL & MWD SURVEY TO 4279' CBU. MUD GAS CUT TO 9.5 PPG, & SMALL AMT OF OIL @ SHAKERS. DRILL & MWD SURVEY TO 4580'. CBU. MUD GAS CUT TO 9.6 PPG. DRILL & MWD SURVEY TO 4865' RUNNING 9-5/8" CSG 9-5/8"@ 4981' MW:10.8 VIS: 52 CIRC OUT GAS CUT MUD, CUT TO 9.5 PPG. DRILL TO 5005' CIRC & COND MUD FOR SHORT TRIP, PMP SLUG. PULL OUT OF HOLE, TIGHT F/3870'-3722' AND TIGHT AND TRYING TO SWAB F/1800'-1600', UNABLE TO RUN BACK IN HOLE. WORK PIPE OUT OF HOLE, LD MOTOR AND MWD. BHA VERY BADLY BALLED UP. MU SEC. BULL NOSE HO, RIH TO BRIDGE @ 1789'. FILL PIPE, WASH & REAM F/1789'-1825' AND F/2146'-2176' RIH TO 5005' CIRC & COND MUD & HOLE, MUD GAS CUT TO 10.0 PPG. DROP SURVEY, PMP SLUG, POH, RETRIEVE SURVEY. LD STABILIZERS & HOLE OPENER. RIG TO RUN 9-5/8" SURF CSG. HOLD SAFETY MEETING. RUNNING 9-5/8" CSG @ RPT TIME. J U L '/5 199;: Alaska Oil & 6as Cons. Commission Anchorage WELL: 1H-17 API: 50-029-22314 PERMIT: 92-130 PAGE: 2 01/02/93 ( 4) PARKER 245 TD: 5005'( 01/03/93 (5) PARKER 245 TD: 5005'( o) o) 01/04/93 ( 6) PARKER 245 TD: 7775' (2770) 01/05/93 ( 7) PARKER 245 TD: 8310' ( 535) 01/06/93 ( 8) PARKER 245 TD: 8455' ( 145) PU BHA 9-5/8"@ 4981' MW: 9.8 VIS: 41 FIN RUNNING 9-5/8" CSG. MU LANDING MANDREL, LAND CSG W/SHOE @ 4984.96' MU CMT HEAD, BREAK CIRC SLOWLY, RECIP CSG & CIRC @ 9.6 BPM. RECIP CSG & CMT AS PER CMT DETAIL, CSG HUNG W/SHOE @ 4981' AFTER PMP 150 BBLS DISPLACEMENT. ND 20" ANN BOP. PU TO SET SLIP, COLLAR IN WAY. CUT 18" OUT OF 20" CONDUCTOR, REWELD STARTING HEAD, SET SLIPS WITH 330 K GROSS(255K NET). LD LANDING JT, SET ANN ON STUMP, INSTALL HGR & WELLHEAD, TORQUE 9-5/8" HGR, SPOT WELD, TORQUE SPPEDHEAD TO 12K, LD TOOLS. NU BOP. RUN TEST PLUG, RU TEST EQUIP. TEST ALL TO 250 PSI LOW & 3000 PSI HIGH. UPPER TOP DRIVE IBOP FAILED, WILL BE REPLACED & TESTED BEFORE DRILLING OUT. PERFORM KOOMY TEST, PULL TEST PLUG, RUN WEAR BUSHING. PU BHA. BOP TEST WAIVED BY AOGCC INSPECTOR JOHN SPAULDING. DRILLING ON PLUGS 9-5/8"@ 4981' MW: 9.8 VIS: 40 PU BHA, ORIENT MWD, LOAD SOURCE IN LWD, PROGRAM LWD, TEST MWD @ HWDP. RIH & TAG @ 4896' CBU. COND THICK MUD, DROP MUD WT TO 9.8 PPG. TEST CSG TO 2075 PSI FOR 30 MIN, LOST 25 PSI. BLOW DN LINES. SLIP & CUT DRLG LINE 90' REPLACE BAD HYDRIL VALVE ON TOP DRIVE WITH OMSCO VALVE, TEST TO 300 & 3000 PSI, GOOD TEST, BUT VALVE HARD TO OPEN & CLOSE. REMOVE VALVE, MACHINE SHOULDER ON MUD SAVED SUB, REINSTALL VALVE, TEST 300 & 3000 PSI, GOOD TEST. INSTALL CLAMPS. START DRILLING ON WIPER PLUGS @ 0600 HRS. DRILL, LOG, & SURVEY 9-5/8"@ 4981' MW: 9.8 VIS: 40 DRILL PLUGS, FC, CMT, FS, CLEAN OUT TO 5005' DRILL 10' NEW HOLE TO 5015'. CIRC & COND THICK MUD OFF BTM. PERFORM FORMATION INTEGRITY TEST, 9.85 PPG MUD TVD=4317', PRESS FORMATION 625 PSI STABILIZED @ 610 PSI FOR 5 MIN, EMW=12.57 PPG. DRILL, LWD LOG, & MWD SURVEY. DRILL, LOG, & SURVEY 7"@ 8435' MW: 9.8 VIS: 42 DRILL, LOG, & MWD SURVEY. SERV RIG & TOP DRIVE. DRILL, LOG, & MWD SURVEY. POH, REMOVE SOURCE FROM CDR, DOWNLOAD INFO, BREAK OFF BIT, LD TURBINE. PU NAVI-DRIL, MU BIT, INSTALL SOURCE, TEST MWD @ HWDP, RIH, FILL PIPE @ 3000' & 6000', BREAK CIRC @ 8131', REAM F/8132'-8185' FOR LWD LOG. DRILL, LOG, & SURVEY. PREPARE TO CMT 7" CSG 7"@ 8435' MW: 9.8 VIS: 39 DRLG, LOG, & SURVEY TO 8455' TD. CIRC & COND MUD. MADE 10 STD SHORT TRIP TO 7570' NO FILL. CIRC & COND HOLE FOR 7" CSG-SLUG DP. POH TO RUN 7" CSG. SERV RIG. POH. DOWN LOAD LWD TOOLS. LD BHA. PULLED WEAR BUSHING. RU CASER. HOLD SAFETY MEETING. RAN 7" CSG AS PER WELL PLAN. CIRC @ 4600' & 6600' CIRC W/CSG ON BTM @ 8435'. HOLE TIGHT & PACKING OFF. WORK PIPE AND CLEAN UP HOLE CIRT~-~fPMV D (STARTED BATCH MIXING CMT @ 0430). '~ ~-C~'I ~ J U L 7,5 t99;5 Alaska 0il & Gas Cons. Gommissio~~, Anchorage WELL: 1H-17 API: 50-029-22314 PERMIT- 92-130 PAGE: 3 01/07/93 ( 9) PARKER 245 TD' 8455' ( 06/13/93 (11) TD: 8455 PB' 8346 06/14/93 (12) TD: 8455 PB: 8346 RIG RELEASED-FINAL RPT 7"@ 8435' MW: 9.8 ViS: 0 o) TEST LINES TO 4000 PSI. SET & CMT 7" CSG @ 8435'. HALLIBURTON CMT'D PUMPING 20 BBLS PRE-FLUSH, 50 BBLS SPACER, 270 SX CLASS G W/ADDITIVES. DISPLACED W/319 BBLS 9.8 PPG BRINE. RECIP PIPE W/FULL RETURNS THROUGHOUT JOB. BUMPED PLUB W/3500 PSI. HELD 3500 PSI FOR 30 MIN FOR CSG TEST. HELD. CIP @ 07:45 01/06/93. PU BOP'S. LANDED 7" CSG W/150, 000% ON SLIPS. BLEW BRINE OUT OF CSG. CUT OFF 7" ND BOPS. NU 7-1/16" -5,000 TBG HEAD. TEST TBG HEAD TO 3000 PSI FOR 15 MIN-OK. FREEZE PROTECTED 9-5/8" X 7" ANN W/100 BBLS WATER & 70 BBLS DIESEL. RELEASED RIG @ 1500 HRS 01/06/93. TEST BOP 7"@ 8435' MW: 9.8 NaCl/Br MOVE RIG F/1H-16 TO 1H-17. ACCEPT RIG @ 0400 HRS 06/13/93. ND TREE, SET TEST PLUG, NU BOP. PERFORM FULL BOP TEST. WITNESS OF TEST WAIVED BY BOBBY FOSTER. RELEASED RIG. MOVE TO 1H-19 7"@ 8435' MW: 9.8 NaCl/Br RU SWS, TEST LUB TO 1000 PSI. PU PERF GUN #1. PERF F/~118'-8143' W/4-1/2" CSG GUNS @ 4 SPF, 180 DEG PHASING, 43C UP CHARGE DOWN AND 34B HJ2 CHARGE UP. ORIENT 1 DEG CCW. CORRELATE TO CET LOG DATED 01/31/93. MU 5.95" GAUGE RING & JB & RIH TO 8300'. POH. MU BAKER D PERM PKR W/TAILPIPE. SET PKR W/TOP @ 7686' WLM & TBG TAIL @ 7722' WLM. RD SWS. RU FLOW RISER & TBG RUNNING EQUIP. MU BAKER HB PKR & TAILPIPE ASSY. RIH ON 3-1/2", 9.3#, J-55, ABM-EUE, IPC TBG. CONT RIH W/3-1/2" TO CAMCO SSSV. HOOK UP CONTROL LINE & TEST TO 5000 PSI. SPACE OUT 2-1/2' ABOVE PERM PKR. MU FMC HGR & HOOK UP CONTROL LINE & TEST TO 5000 PSI. LAND TBG. RILDS. PRESS TBG & ANN TO 1000 PSI. CLOSE SSSV & BLEED TBG TO 500 PSI. HOLD FOR 15 MIN. PRESS TBG TO 1000 PSI & OPEN SSSV. PRESS TBG & ANN TO 2500 PSI FOR 15 MIN. INCREASE TBG TO 3000 PSI, HOLD FOR 15 MIN. INCREASE TO 3200 PSI & BALL SHEARED. SET BPV. ND FLOW RISER & BOP. NU FMC LOWER & UPPER TREE, TESTED PACKOFF TO 5000 PSI, TESTED TREE TO 250 PSI & 5000 PSI, PULLED TEST PLUG. RU & PMP LINES, PMP 12 BBLS DIESEL DOWN ANN & 4 BBLS OF DIESEL DOWN TBG. SECURE WELL. SIGNATURE: ) ( dr~pe r int ~_~ent DATE · REEE VED J U L 1,5 Alaska Oil & Gas Cons. Cornmissio'" Anchorage SUB - S URFA CE DIRECTIONAL SURVEY r~] UIDANCE r~ ONTINUOUS ~ OOL ,a,/a$.~ Oil .& Gas Co~s..6ornrr~issi. r~ Company Well Name Field/Location ARCO ALASKA, INC. 1H-17 (642' FNL, 1156' FEL, SEC 33, T12N, RIOE, UM) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 93052 Locjc~ed BV: SARBER * SCHLUMBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 31-JAN-g3 ENGINEER' SARBER METHODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION' LINEAR VERTICAL SECTION- HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH I DEG 10 MIN WEST ARCO ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE' 9-FEB-93 PAGE 1 DATE OF SURVEY: 31-JAN-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 2OO O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 99 86 199 86 299 86 399 85 499 85 599 85 699 85 799 85 899 70 -96.00 3.86 103.86 203 86 303 85 403 85 503 85 603 85 703 85 803 70 0 0 N 0 0 E 0 14 S 16 44 W 0 20 S 11 34 E 0 12 S 13 44 W 0 22 S 13 30 W 0 21 S 8 49 E 0 15 S 12 56 E 0 7 N 25 55 W 1 21 N 10 7 W 4 39 N 4 12 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 998 90 O0 1097 O0 1194 O0 1290 O0 1385 O0 1479 O0 1572 O0 1664 O0 1753 O0 1838 902 90 03 1001 27 1098 58 1194 78 1289 63 1383 67 1476 56 1568 17 1657 88 1742 9 31 03 12 17 27 14 38 58 16 41 78 19 4 63 21 10 67 21 58 56 25 11 17 30 0 88 31 31 N 3 45 W N 3 48 W N 442W N 4 33W N 3 54 W N 2 36W N 1 42W N 0 17 W N 2 43 E N 3 50 E 0 O0 0 O0 -0 55 -0 99 -1 44 -2 10 -2 65 -2 80 -2 08 3 O3 2000 O0 1922 47 1826 47 35 8 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2002 O0 2081 O0 2159 O0 2238 O0 2316 O0 2394 O0 2472 O0 2550 O0 2628 51 1906 24 1985 95 2063 48 2142 56 2220 57 2298 64 2376 72 2454 88 2532 51 38 2 24 38 4 95 38 7 48 38 28 56 38 45 57 38 40 64 38 40 72 38 37 88 38 31 N I 58 E N 2 54 E N 3 25 E N 3 42 E N 2 25 E N 0 24 E N 0 23 E N 0 26 E N 1 41W N 2 8 W 15 29 34 50 57 74 84 59 115 12 149 60 186 25 225 66 271 89 323 21 3000 O0 2707 36 2611 36 38 3 3100 O0 2786 3200 O0 2865 3300 O0 2944 3400 O0 3024 3500 O0 3103 3600 O0 3183 3700 O0 3265 26 2690 48 2769 88 2848 37 2928 57 3007 78 3087 11 3169 26 37 44 48 37 31 88 37 25 37 37 23 57 37 33 78 35 48 11 35 30 3800 O0 3345 52 3249 52 37 52 3900 O0 3424 13 3328 13 38 5 377 92 437 72 499 19 560 67 622 37 684 81 747 35 809 83 872 29 934 65 N 2 23 W 996 62 N 2 23 W 1058 04 N 2 21W 1119 06 N 2 12 W 1179 84 N 1 55 W 1240 50 N 1 38 W 1301 56 N 1 11W 1361 27 N 0 49 W 1419 45 N 0 2 E 1478 88 N 0 7 E 1540 67 0 O0 0 oo 0 21 0 21 0 2o 0 20 0 17 0 27 0 83 2 31 O00N 000N 0 55 S 0 99 S 1 44 S 2 10 S 2 65 S 2 80 S 2 09 S 3 O1 N 0 O0 E 0 O0 E 0 02W 0 06 E 0 10 W 0 10 W 0 05 E 0 05 E 0 17 W 0 66 W 0 O0 N 0 0 E O0 N 0 0 E 55 S 1 45 W 99 S 3 15 E 45 S 3 55 W 10 S 2 37 W 65 S 0 59 E 8O S 1 0 E 09 S 4 33 W O8 N 12 26 W 2 41 3 36 3 16 2 48 2 23 2 24 1 91 2 O3 2 61 2 85 15 27 N 34 45 N 57 66 N 84 47 N 114 96 N 149 40 N 186 04 N 225 44 N 271 69 N 323 10 N 1 49 W 2 4 6 8 10 12 12 12 8 15 34 N 5 34 W 81W 34 53 W 57 72 W 84 98 W 115 92 W 149 26 W 186 95 W 225 11W 271 86 W 323 57 N 4 40 W 84 N 4 29 W 74 N 4 33 W 31 N 4 28 W 80 N 4 11 W 45 N 3 46 W 82 N 3 17 W 96 N 2 33 W 22 N 1 34 W 3 35 3 33 2 23 1 65 0 89 0 68 0 61 0 58 0 45 0 44 377 87 N 437 73 N 499 29 N 560 86 N 622 65 N 685 12 N 747 69 N 810 18 N 872 65 N 934 99 N 6 23 W 377 92 N 0 57 W 64 W 437 26 W 499 58 E 56O 28 E 622 27 E 685 69 E 747 15 E 810 92 E 872 73 E 935 75 N 0 29 W 29 N 0 2 W 87 N 0 22 E 7O N 0 4O E 17 N 0 42 E 74 N 0 4O E 23 N 0 39 E 70 N 0 35 E O1 N 0 25 E 0 75 0 65 0 52 0 33 0 22 0 27 0 63 0 80 ] 16 1 23 996 91N 1058 3O N 1119 27 N 1180 02 N 1240 65 N 1301 69 N 1361 38 N 1419 55 N 1478 98 k 1540 79 N 4 30 E 996 92 N 0 15 E 1 72 E 1058 0 76 W 1119 3 17 W 1180 5 34 W 1240 7 21W 1301 8 75 W 1361 9 70 W 1419 lo 17 W 1479 lO Ol w 154o 30 N 0 6 E 27 N 0 2 W 03 N 0 9 W 66 N 0 15 W 71 N 0 19 W 40 N 0 22 W 59 N 0 23 W 02 N 0 24 W 82 N 0 22 W COMPUTATION DATE' 9-FEB-93 PAGE 2 ARCO ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 31-JAN-93 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' SARBER 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 3502 88 3406 88 .37 59 N 0 2 E 1602 29 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3581 O0 3661 O0 3740 O0 3820 O0 3900 O0 3979 O0 4058 O0 4138 O0 4217 81 3485 03 3565 44 3644 O9 3724 O8 3804 75 3883 96 3962 62 4042 63 4121 81 37 47 N 0 2 W 1663 03 37 31 N 0 9 W 1724 44 37 20 N 0 2 E 1785 09 37 4 N 0 12 W 1845 08 36 44 N 0 40 W 1905 75 37 41 N 0 52 W 1966 96 37 22 N 1 2 W 2027 62 37 10 N 1 12 W 2087 63 38 23 N 1 17 W 2149 68 70 45 91 92 35 40 84 13 0 89 1602 42 N 0 79 1663 0 26 1724 0 21 1785 0 25 1846 0 3O 1906 0 42 1966 0 49 2027 0 55 2087 0 71 2149 9 93 W 1602 45 N 0 21W 82 N 9 99 W 1663 85 N 10 08 W 1724 62 N 10 17 W 1785 08 N 10 23 W 1846 09 N 10 68 W 1906 53 N 11 49 W 1966 56 N 12 50 W 2027 99 N 13 68 W 2088 27 N 14 99 W 2149 85 N 0 21 W 88 N 0 20 W 65 N 0 20 W 11 N 0 19 W 12 N 0 19 W 56 N 0 20 W 60 N 0 21 W 04 N 0 23 W 32 N 0 24 W 5000 O0 4296 15 4200 15 38 1 N 1 48 W 2211 06 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4374 O0 4453 O0 4531 O0 4609 O0 4688 O0 4766 O0 4844 O0 4921 O0 4998 79 4278 22 4357 58 4435 86 4513 09 4592 27 4670 21 4748 70 4825 93 4902 79 38 16 N 2 4 W 2272 22 38 25 N 2 10 W 2334 58 38 26 N 2 28 W 2396 86 38 32 N 2 37 W 2459 09 38 32 N 2 55 W 2521 27 38 37 N 3 12 W 2583 21 39 1 N 3 29 W 2646 70 39 20 N 3 41 W 2709 93 39 30 N 3 45 W 2772 82 85 96 18 44 77 37 52 99 0 64 2211 18 N 16 57 W 2211 25 N 0 26 W 0 60 2272 0 64 2334 0 50 2396 0 34 2459 0 17 2521 0 17 2583 0 23 2646 0 3O 2709 0 32 2772 91N 18 68 W 2272 91 N 20.94 W 2335 98 N 23.48 W 2397 15 N 26.26 W 2459 37 N 29.24 W 2521 64 N 32.50 W 2583 18 N 36.18 W 2646 26 N 40,12 W 2709 66 N 44.25 W 2773 99 N 0 28 W O1 N 0 31 W 10 N 0 34 W 29 N 0 37 W 54 N 0 40 W 85 N 0 43 W 43 N 0 47 W 56 N 0 51 W 02 N 0 55 W 6000 O0 5076 04 4980 04 39 34 N 3 57 W 2836 58 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5153 O0 5231 O0 5310 O0 5389 O0 5469 O0 5548 O0 5628 O0 5707 O0 5787 10 5057 31 5135 14 5214 32 5293 O0 5373 72 5452 21 5532 65 5611 17 5691 10 39 27 N 3 54 W 2900 31 38 3 N 2 34 W 2962 14 37 52 N 2 52 W 3024 32 37 22 N 3 16 W 3085 O0 36 59 N 3 46 W 3145 72 37 14 N 4 4 W 3205 21 37 25 N 4 14 W 3266 65 37 21 N 4 23 W 3326 17 37 15 N 4 36 W 3387 24 52 O3 O7 44 74 34 99 52 0 28 2836 18 N 48 51 W 2836 60 N 0 59 W 21 2899 8O 2961 84 3023 93 3084 52 3144 43 3204 39 3265 22 3326 19 3386 77 N 52 99 N 56 45 N 59 44 N 62 75 N 66 98 N 70 50 N 74 07 N 79 51 N 83 9O W 29OO 22 W 2962 12 W 3024 35 W 3085 03 W 3145 15 W 3205 55 W 3266 09 W 3327 86 W 3387 25 N 1 3 W 52 N 1 5 W 03 N 1 7 W 07 N 1 9 W 45 N 1 12 W 74 N 1 15 W 35 N 1 18 W O1 N 1 22 W 55 N 1 25 W 7000 O0 5866 66 5770 66 37 27 N 4 43 W 3448 09 7100 72OO 7300 740O 7500 7600 7700 7800 7900 O0 5946 O0 6024 O0 6102 O0 6180 O0 6258 oo 6337 oo 6417 oo 6496 O0 6577 11 5850 84 5928 76 6006 74 6084 99 6162 72 6241 09 6321 96 6400 02 6481 11 37 25 N 4 44 W 3508 84 38 43 N 3 14 W 3570 76 38 52 N 3 17 W 3632 74 38 43 N 3 26 W 3695 99 38 16 N 3 17 W 3757 72 37 45 N 2 51 W 3819 09 37 10 N 2 10 W 3880 96 36 48 N 2 I W 3940 02 36 51 N 2 6 W 4000 69 26 90 45 68 3O 11 28 19 0 16 3446 99 N 88 79 W 3448 14 N 1 29 W 20 3507 90 3569 80 3631 65 3694 50 3756 33 3817 49 3878 54 3938 46 3998 50 N 93 O0 N 98 58 N 101 07 N 105 23 N 109 80 N 112 58 N 114 71N 117 59 N 119 85 W 3508 17 W 3570 71W 3633 36 W 3695 O0 W 3757 28 W 3819 83 W 3880 04 W 3940 18 W 4000 76 N 1 32 W 35 N 1 35 W O1 N 1 36 W 57 N 1 38 W 81 N 1 40 W 45 N 1 41W 28 N 1 42 W 45 N 1 42 W 37 N I 42 W COMPUTATION DATE: 9-FEB-93 PAGE 3 arco ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SARBER 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 8000 O0 6657 18 6561.18 .36 31 N 2 14 W 4059 97 8100 O0 6737 72 6641.72 36 12 N 2 27 W 4119 23 8200 O0 6818 55 6722.55 36 2 N 2 31 W 4178 09 8300 O0 6899 51 6803.51 35 54 N 2 30 W 4236 77 8400 O0 6980 65 6884:65 35 54 N 2 30 W 4295 20 8455 O0 7025 20 6929.20 35 54 N 2 30 W 4327 43 0.31 4058 33 N 121 46 W 4060 15 N I 43 W 0.37 4117 56 N 123 85 W 4119 42 N I 43 W 0.31 4176 38 N 126 38 W 4178 29 N I 44 W 0.24 4235 02 N 128 98 W 4236 99 N I 45 W 0.00 4293 40 N 131 59 W 4295 42 N I 45 W 0.00 4325 62 N 132 99 W 4327 66 N 1 46 W COMPUTATION DATE: 9-FEB-93 PAGE 4 Arco ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-g3 KELLY BUSHING ELEVATION: 96.00 FT ENGTNEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET DF 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 DF_PIN DEPTH DEG MZN DEG MIN FEET ,DEG/IO0 FEET FEET FEET DEG ~IN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 8455 0 O0 -96 O0 0 0 N 0 0 E O0 998 90 902 O0 1922 47 1826 O0 2707 36 2611 O0 3502 88 3406 O0 4296 15 4200 O0 5076 04 4980 O0 5866 66 5770 O0 6657 18 6561 O0 7025 20 6929 90 9 31 N 3 45 W 47 35 8 N 1 58 E 377 36 38 3 N 2 23 W 996 88 37 59 N 0 2 E 1602 15 38 1 N I 48 W 2211 04 39 34 N 3 57 W 2836 66 37 27 N 4 43 W 3448 18 36 31 N 2 14 W 4059 20 35 54 N 2 30 W 4327 O. O0 15 29 92 62 29 06 58 O9 97 43 0 O0 2 3 0 0 0 0 0 0 0 41 35 377 75 996 89 1602 64 2211 28 2836 16 3446 31 4058 O0 4325 0.00 N 15 27 N 1 87 N 6 91N 4 42 N 9 18 N 16 18 N 48 99 N 88 33 N 121 62 N 132 0 O0 E 49 W 15 23 W 377 30 E 996 93 W 1602 57 W 2211 51W 2836 79 W 3448 46 W 4060 99 W 4327 0 O0 N 0 0 E 34 N 5 34 W 92 N 0 57 W 92 N 0 15 E 45 N 0 21 W 25 N 0 26 W 60 N 0 59 W 14 N 1 29 W 15 N 1 43 W 66 N I 46 W COMPUTATION DATE- 9-FEB-93 PAGE 5 ARCO ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 31-JAN-93 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER- SARBER INTF_RPOLATED VALUES FOR EVEN 100 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 BIN 0 O0 96 196 296 396 496 596 696 796 896 0 O0 -96.00 0 0 N 0 0 E 14 96 14 196 14 296 15 396 15 496 15 596 15 696 15 796 29 896 O0 0.00 0 13 S 23 2 W O0 100.00 0 21 S 10 12 E O0 200 O0 0 12 S 11 48 W O0 300 O0 0 21 S 14 20 W O0 400 O0 0 21 S 8 47 E O0 500 O0 0 16 S 13 40 E O0 600 O0 0 7 N 26 58 W O0 700 O0 1 15 N 10 45 W O0 800 O0 4 31 N 4 19 W 0 O0 0 O0 -0 53 -0 97 -1 42 -2 07 -2 64 -2 81 -2 18 2 72 0 O0 0 O0 0 22 0 21 0 2O 0 20 0 17 0 26 0 79 2 25 000N 000N 0 53 S 0 97 S 1 42S 2 085 2 64 S 2 80 S 2 18 S 2 70 N 000 E 0 O0 E 0 02 W 0 06 E 0 09 W 0 10 W 0 04 E 0 05 E 0 15 W 0 64 W 0 O0 N 0 0 E O0 N 0 0 E 53 S 2 19 W 97 S 3 29 E 42 S 3 45 W 08 S 2 45 W 64 S 0 53 E 81 S 1 4 E 19 S 3 57 W 78 N 13 21W 997 05 996 O0 900 O0 9 22 N 3 44 W 1098 95 1096 O0 1000 1201 78 1196 O0 1100 1305 67 1296 O0 1200 1410 81 1396 O0 1300 1517 56 1496 O0 1400 1625 18 1596 O0 1500 1734 99 1696 O0 1600 1849 80 1796 O0 1700 1967 90 1896 O0 1800 14 80 O0 12 15 N 3 48 W 34 O0 14 41 N 4 43 W 58 O0 16 47 N 4 31 W ,.,~,, 86 O0 19 23 N 3 48 W 118 O0 21 15 N 2 24 W 155 O0 22 23 N 1 21W 195 O0 26 41 N 0 15 E 241 O0 31 11 N 3 51E 297 O0 33 55 N 2 18 E 359 27 19 24 64 96 73 O1 2O 8O 2 36 .3 36 3 15 2 45 2 24 2 19 1 86 2 23 2 84 3 15 14.78 N 34.22 N 2 58.11N 4 86.12 N 6 118.48 N 9 155.77 N 11 195.51N 12 240.80 N 12 297.05 N 10 359.73 N 6 1 46 W 14 85 N 5 38 W 80 W 34 56 W 58 85 W 86 22 W 118 18 W 156 53 W 195 94 W 241 62 W 297 92 W 359 34 N 4 40 W 29 N 4 29 W 39 N 4 33 W 84 N 4 27 W 17 N 4 6 W 91 N 3 40 W 15 N 3 5 W 24 N 2 3 W 80 N 1 6 W 2091 74 1996 O0 1900 O0 38 0 N 2 52 E 432 64 2218 2345 2473 2601 2729 2857 2985 3112 3238 74 2096 84 2196 64 2296 83 2396 93 2496 95 2596 55 2696 31 2796 45 2896 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 38 4 N 3 29 e 510 O0 38 13 N 3 45 E 588 O0 38 44 N 0 26 E 668 O0 38 40 N 0 23 E 748 O0 38 41 N 0 19 E 828 O0 38 36 N 2 7 W 908 O0 38 7 N 2 21W 987 O0 37 41 N 2 22 W 1065 O0 37 26 N 2 18 W 1142 71 89 32 49 52 45 7O 57 44 3 37 2 03 1 27 0 70 0 61 0 56 0 43 0 66 0 0 432 65 N 510 589 668 748 828 908 988 64 1065 46 1142 82 N 12 N 63 N 83 N 88 N 79 N O0 N 83 N 65 N 3 90 W 432 67 N 0 31W 44 E 510 42 E 589 15 E 668 70 E 748 26 E 828 69 E 908 67 E 988 41 E 1065 71W 1142 82 N 0 3 E 15 N 0 32 E 68 N 0 42 E 88 N 0 4O E 93 N 0 38 E 83 N 0 29 E 01 N 0 16 E 83 N 0 5 E 65 N 0 5 W 3364 32 2996 O0 2900.00 37 17 N 2 1 W 1218 87 3490 3615 3738 3864 3991 4117 4244 4369 4494 45 3096 05 3196 06 3296 22 3396 27 3496 93 3596 07 3696 79 3796 90 3896 O0 3000.00 37 39 N 1 40 W 1295 O0 3100.00 35 42 N 1 5 W 1370 O0 3200.00 35 58 N 0 39 W 1441 O0 3300.00 38 17 N 0 11E 1518 O0 3400.00 38 0 N 0 3 E 1596 O0 3500.00 37 42 N 0 3 W 1674 O0 3600.00 37 26 N 0 7 W 1751 O0 3700.00 37 10 N 0 6 W 1827 O0 3800.00 36 45 N 0 39 W 1902 74 O5 69 56 92 64 5O 69 87 0 23 1219 03 N 27 1295 67 1370 84 1441 35 1518 91 1597 68 1674 22 1751 24 1827 29 1903 4 60 W 1219 04 N 0 13 W 87 N 7 16 N 8 78 N 9 67 N 10 05 N 9 78 N 9 66 N 10 86 N 10 04 N 10 05 W 1295 91W 1370 98 W 144% 07 W 1518 93 W 1597 99 W 1674 14 W 1751 19 W 1827 65 W 1903 88 N 0 19 W 19 N 0 22 W 82 N 0 24 W 70 N 0 23 W 08 N 0 21 W 81 N 0 21 W 69 N 0 20 W 89 N 0 19 W 07 N 0 19 W COMPUTATION DATE: 9-FEB-93 PAGE 6 ARCO ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-93 KELLY BUSHING ELEVATION: 96.00 ET ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 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 HIM 4620 54 3996 O0 3900.00 ,37 48 N 0 54 W 1978 91 4746 4872 4999 5127 5254 5382 5510 5638 5766 55 4096 45 4196 81 4296 02 4396 59 4496 28 4596 11 4696 O9 4796 79 4896 O0 4000.00 37 10 N 1 7 W 2055 O0 4100.00 38 10 N I 15 W 2132 O0 4200.00 38 I N I 48 W 2210 O0 4300:00 38 19 N 2 5 W 2289 O0 4400.00 38 23 N 2 23 W 2368 O0 4500.00 38 32 N 2 36 W 2448 O0 4600.00 38 32 N 2 55 W 2527 O0 4700.00 38 44 N 3 21W 2607 O0 4800.00 39 15 N 3 37 W 2688 0 46 1979 08 N 11 68 W 1979.12 N 0 20 W 58 0 O7 0 95 0 57 0 76 0 14 0 74 0 55 0 50 0 55 2055 65 2132 64 2211 66 2289 56 2368 37 2448 17 2527 19 2607 28 2688 74 N 13 21_. N 14 07 N 16 65 N 19 80 N 22 13 N 25 67 N 29 40 N 33 27 N 38 02 W 2055.78 N 0 22 W 62 W 2132.26 N 0 24 W 57 W 2211.13 N 0 26 W 28 W 2289.73 N 0 29 W 28 W 2368 91 N 0 32 W 76 W 2448 26 N 0 36 W 56 W 2527 84 N 0 40 W 86 W 2607 62 N 0 45 W 79 W 2688 55 N 0 50 W 5896 21 4996,00 4900 O0 39 30 N 3 45 W 2770 58 6025 6155 6282 6408 6533 6659 6785 6911 7036 89 5096,00 5000 09 5196.00 5100 09 5296.00 5200 41 5396.00 5300 84 5496.00 5400 45 5596.00 5500 35 5696.00 5600 10 5796.00 5700 95 5896.00 5800 O0 39 37 N 3 59 W 2853 O0 38 19 N 2 49 W 2934 O0 37 55 N 2 48 W 3013 O0 37 21 N 3 18 W 3090 O0 37 8 N 3 52 W 3165 O0 37 24 N 4 11 W 3241 O0 37 21 N 4 20 W 3318 O0 37 16 N 4 37 W 3394 O0 37 23 N 4 49 W 3470 O6 77 04 17 82 74 12 23 49 0 32 2770 25 N 44.09 W 2770 61 N 0 55 W 0 26 2852 0 57 2934 0 83 3012 0 94 3089 0 43 3165 0 43 3240 0.24 3317 0.18 3393 0.16 3469 64 N 49.65 W 2853 07 N 1 0 W 26 N 54.93 W 2934 77 N 1 4 W 47 N 58.57 W 3013 04 N 1 7 W 53 N 62.64 W 3090 17 N 1 10 W 11N 67.39 W 3165 82 N 1 13 W 93 N 72.74 W 3241 74 N 1 17 W 21N 78.41W 3318 13 N 1 21W 21 N 84.40 W 3394 26 N 1 25 W 36 N 90.65 W 3470 55 N I 30 W 7163.14 5996 O0 5900 O0 38 21 N 3 45 W 3547 32 7291.32 6096 7419.55 6196 7547.09 6296 7673,'52 6396 7798.80 6496 7923.72 6596 8048.25 6696 8172.11 6796 8295.67 6896 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 38 53 N 3 18 W 3627 O0 38 39 N 3 24 W 3707 O0 38 8 N 3 4 W 3786 O0 37 17 N 2 9 W 3864 O0 36 49 N 2 1 W 3939 O0 36 49 N 2 9 W 4014 O0 36 21 N 2 18 W 4088 O0 36 3 N 2 27 W 4161 O0 35 54 N 2 30 W 4234 46 66 77 10 56 41 62 69 24 0.40 3546 08 N 96 77 W 3547 40 N I 34 W 0.82 3626 0.62 3706 0.38 3785 0.46 3862 0.54 3937 0.43 4012 0.30 4086 O.33 4159 O.24 4232 15 N 101 26 N 106 31N 110 58 N 114 99 N 117 80 N 119 97 N 122 99 N 125 49 N 128 40 W 3627 09 W 3707 61W 3786 23 W 3864 O1W 3939 71W 4014 60 W 4088 67 W 4161 87 W 4234 56 N 1 36 W 78 N 1 38 W 92 N 1 40 W 26 N 1 42 W 73 N 1 42 W 58 N 1 43 W 81 N 1 43 W 88 N I 44 W 45 N I 45 W 8418.95 6996.00 6900.00 35 54 N 2 30 W 4306.30 8455.00 7025.20 6929.20 35 54 N 2 30 W 4327.43 0.00 4304.50 N 132.07 W 4306.53 N 1 45 W 0.00 4325,62 N 132.99 W 4327.66 N 1 46 W COMPUTATION DATE: 9-FEB-93 PAGE 7 ARCO ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A ,LAST READING GCT PB~ 7" CASING DATE OF SURVEY: 3I-JAN-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 642' FNL ~ II56' FEL~ SEC33 TI2N RIOE U~ MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4981 O0 7794 O0 7916 O0 8089 O0 8199 O0 8300 42 8346 O0 8436 O0 8455 O0 4281.I9 6492 I5 6589 82 6728 84 6817 74 6899 98 6936 90 7009 81 7025 20 4185 19 6396 15 6493 82 6632 84 6721 74 6803 98 6840 90 6913 81 6929 20 2199 47 N 3935 12 N 4008 18 N 4111 06 N 4175 79 N 4235 07 N 4261 77 N 4314 49 N 4325 62 N 16 21W 116 91W 119 54 W 123 57 W 126 36 W 129 04 W 130 21W 132 50 W 132 99 W COMPUTATION DATE: 9-FEB-93 PAGE 8 ARCO ALASKA INC. 1H-17 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A ,LAST READING GCT PBTD 7 II CASING TD DATE OF SURVEY: 31-JAN-g3 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SARBER ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 642' FNL A 1156' FEL, SEC33 T12N RIOE U~ MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4981 O0 7794 O0 7916 O0 8089 O0 8199 O0 8300 42 8346 O0 8436 O0 8455 O0 4281 19 6492 15 6589 82 6728 84 6817 74 6899 98 6936 90 7009 81 7025 20 4185 19 6396 15 6493 82 6632 84 6721 74 6803 98 6840 90 6913 81 6929 20 2199.47 N 3935 12 N 4008 18 N 4111 06 N 4175 79 N 4235 07 N 4261 77 N 4314 49 N 4325 62 N 16 21W 116 91W 119 54 W 123 57 W 126 36 W 129 04 W 130 21W 132 50 W 132 99 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8455.00 7025.20 6929.20 4327.66 N 1 46 W DIRECTIONAL SURVEY CO~A~ ARCO ALASKA INC. F;E,n KUPARUK RIVER ~ 1H-17 COUNTRY USA RUN 1 DATE LO<~ED 31 - JAN - 93 DEPTH UNIT FEET ~.,=,,~,~c; 93052 WELL' (642' 1t(-17 FNL, 1156' FEL, SEC 33, T12N, RIOE, UN) 1(ORIZONTAL PROJECTION ......... r ........ ; ..... : ......... : .......... I"; ........ : ......... :'":"; ................... ; ..... ; ........... :'": .......... :" ;"; .... : ....................... ~ .................... I .............................. -44~)0 -30~Cm -;~t~)0 -1000 0 1000 ~000 3,000 4000 WELL' 1H-17 (642' FNL, 1156' FEL, SEC 33, T12N, RIOE, UM) VERTICAL PROJECTION ARCO Alaska, Inc. Date: May 07, 1993 Transmittal #: 8732 RETURN TO: ARCO Alaska, Inc. Attn: NikkJ Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the folloWing Open hole items. acknowledge receipt and return one signed copy of this transmittal. Please H-16 ~'-,d~~ H-19 H-19- ~--' ~0~ /1H-17 ~. ~ ~--*,,.1H-17 "fa~ M-O 1 ~M-12 M-O4 ~ .~._.2M-14 q;,~ffo,~ _.2M-08 c~_.~,3 ~/2_ M-02 ~M-02 CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth Corrected 1/8-10/93 2671-7510 Corrected 1/8-10/93 2671-7510 Corrected 12/13-16/92 5364-8990 Corrected 12/13-16/92 5364-8990 Corrected 1/2-5/93 4981-8185 Corrected 1/2-5/93 4981-8185 Corrected 10/25-29/92 3347-9800 Corrected 9/6-8/92 2801-4766 Corrected 9/23-26/92 4260-12370 Corrected 7/14-17/92 3664-9811 Corrected 11/3-7/92 4253-12151 Corrected 8/31 to 9/3/923437-10003 Corrected 8/31 to 9/3/923437-10003 Receipt Acknowledged: DISTRIBUTIQN: D&M Drilling Date' R ~LC~! IV/ED MA Y 1 4 1993 Ala$~ 011 & ~as Cons. C°rnrnission Anchorage VendorPackage(Johnston) NSK State of Alaska(+Sepia) Kathy Worley(Geology) ARCO Alaska, Inc. Date: April 2, 1993 Transmittal #: 8701 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 items. one signe.~opy of this transmittal. -1 H- 1 6 ¢--~o"~ LIS Tape and Usting c~"Z.-~'5 -2M-04 ~-~S"/[ cJ2.-?~. 2M-09 ~ o~?.....lO5 .-2M-01 ~r~l 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 CDPJCDN In 2 Bit Runs. 1 Mad-Pass & Resistivity --.1 H - 2 0 ~%'77.. LIS Tape and Usting 1 2 - 2 7'- 9 2 CDR/CDN In 3 Bit Runs. Phasor Enhanced ef.~...O~ -1 H-01 S~'7~,LIS Tape and Listing 01- 2 9- 9 3 ~CDR/CDN In 2 Bit Runs/Enhanced Resistivity c[~..O~._---.-1 H - 0 2-'~'~.ob 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 93013 93007 93038 92735 93045 93056 92586 92511 92640 ReCeipt Acknowledged' - ............................ Date' - ......... DISTRIBUTION: Bob Ocanas State of Alaska RECEIVED APR 0 2_ 199~ Alaska 0il & 6as 0OHS. Commission Anchorage ARCO Alaska, Inc. Date' March 12, 1993 Transmittal #' 8682 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. return one signed copy of this transmittal. Cement Bond Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Receipt Drilling Please acknowledge receipt and 03-02-93 03-02-93 01 -31 -93 01 -31 -93 01 -31 -93 01 -31 -93 Ack now ledge' _..,-..~_. ~-.~-~ Date' State of Alaska(+sepia) 6800-8518 6800-8541 6480-8313 6480-8332 5090-7373 5090-7382 NSK RECEIVED & 6as Cons. ComraissJon Anchorage ARCO Alaska, Inc. Date: February 19, 1993 Transmitlal #' 8667 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. Receipt Sub-Surface Directional 01-10-93 93016 Survey Sub-Surface Directional 01-31-93 93052 Survey Sub-Surface Directional 01 - 1.0-93 93017 Survey DISTRIBUTION: D&M State of Alaska (2 copies) Date: .............. RECEIVED FEB 2. 2 199;) Alaska Oil & Gas Cons. Commission Anchorage . MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh Griffin-~'- Commissioner date: file: January 11, 1993 JOH12291.DOC thru: Blair E Wondzell ih~('~ Sr Petr Engineer ~ o~hn Spaulding from' Petr Inspector subject: Diveder Test ~¢,, O. Parker 245 Arc~zr'P-'--'~~-17 PT~?~ Z."' Thursday, December 29, 1992: I traveled to Arco KRU well 1H-17 to inspect the diverter system and to witness a diverter function test on Parker Rig #245. SUMMARY: I inspected the system and witnessed a successful diveder function test with no failures. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISblON Rig/BOPE Inspection Report OPERATION: QrlgL'~'-~ Compl Wkvr__ UIC Operator..~.~_.---~- -- Permit # ~-/~_~D Location: Se~ S~ T /~J R /~ M ~ Drlg contr ~/~.~.~ Rig~ ~1~' Location (gan'l) ~ Well sign ~ IN COMPLIANCE; yes n~ n/a A. DIVERTER 1. ~ ( ) 2 () 4. ~ ( ) 5 () ~. (X) () line sz & length line conn& anchored bifurcated & dwn wind 90° targeted turns vlvs: auto & simultaneous annul ar pack-off condition B. BOP STACK wellhead flg wkg press stack wkg press annul ar preventer pi pe rams bl i nd rams stack anchored chke/kill line sz 90° turns targeted (chke & kill In) HCR vlvs (chke & kill) manual vlvs (chke & kill) connections (flgd, whd, clmpd) drl spool flow nipple flow monitor control lines fi re protected C. CLOSING UNITS wkg press fluid level oprtg press press gauges sufficient vlvs regulator bypass 4-way vlvs (actuators) blind handle cover driller control panel remote control panel 8.() () 9.() () 10. ( ) ( ) 11. ( ) ( ) 12.() () 13.() () 14.() () 15. ( ) ( ) 16. ( ) ( ) 17, ( ) ( ) 18. ( ) ( ) 19. ( ) ( ) 20. (.) ( ) 21. ( ) ( ) 22. ( ) ( ) 23. ( ) (-) 24,() () 25. ( ) ( ) 26.() () 27. () ( ) 28. ( ) ( ) 29. ( ) () 3o.() () 31.() () 32. ( ) ( ) DATE: / ~--,~- Representative Wel 1 name / Representative Phone No: IN COMPLIANCE; yes no n/a 33. ( ) 34. (.) 35. ( ) 36. ( ) 37. ( ) 38. () 39. ( ) 40. ( ) 41. ( ) 42. ( ) 43. ( ) 44. ( ) 45. ( ) 46. ( ) 47. ( ) 48. ( ) 49. ( ) 50.() 51. ( ) 52.() 53.() 54.() 55.() 56.() 57. ( ) 58.() ( ) ( ) firewall ( ) ( ) nitrogen power source (back-up) ( ) ( ) condition (leaks, hoses~ etc) D. MUD SYSTEM ( ) ( ) pit level floats installed ( ) ( ) flow rate sensors ( ) ( ) mud gas separator. ( ) ( ) degasser ( ) ( ) separator bypass ( ) ( ) gas sensor ( ) ( ) chke In conn ( ) ( ) trip tank E. RIG FLOOR ( ) ( ) kelly cocks (upper,lower~lBOP) ( ) ( ) floor vlvs (dart vlv, ball vlv) ( ) ( ) kelly & floor vlv wrenches ( ) ( ) driller's console (flow monitor, flow rate indicator, pit level · indicators, gauges) ( ) ( ) kill sheet up-to-date ( ) ( ) gas Cetection monitors (H-S & methane) ( ) ( ) hydr chke panel ( ) ( ) chke manifold F. MISC EQUIPMENT ( ) ( ) flare/vent line ( ) ( ) 90° turns targeted (dwn strm choke lns) ( ) ( ) reserve pit tankage ( ) ( ) personnel protective equip avail ( ) ( ) all drl site suprvs trained for procedures ( ) ( ) H2S probes ( ) ( ) rig housekeeping REMARKS: RECORDS: C.0013 (rev 06/30/92) Date of last BOP inspection: Date of last BOP test: Resulting non-compliance: Non-compliances not corrected & why: /~ Date corrections will be completed:~,~, / // BOP test & results properly entered on daily record? /!//,.:' Kill sheet current? : ,. / · / /; I nspec tor"'--~ / WALTER J. HICKEL, GOVERNOR ALASI~A OIL AND GAS CONCElebrATION CO~I~IISSION /' December 16, 1992 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A W McBride P O Box 100360 ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1H-17 ARCO Alaska, Inc. Permit No: 92-130 Sur. Loc. 642'FNL, l156'FEL, Sec. 33, T12N, RiOE, UM Btmhole Loc. 1601'FNL, 1243'FEL, Sec. 28, 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 %est. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AI_A~KA OIL AND GAS CONSERVATION COMM I,~ION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~] lb Type of Well Exploratory ~] Stratigraphic Test ~] Development Oil X Re-Entry [~ Deepen r~ Service r'l Development Gas r-1 SinQleZone X Multiple Zone 2.. Name of Operator 5. Datum ElevalJon (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 96', Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25639, ALK 464 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 642' FNL, 1156' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2,038' FNL, 1,235' FEL, Sec. 28, T12N, R10E, UM 1H-17 At total depth 9. Approximate spud date Amount 1,601' FNL, 1,243' FEL, Sec. 28, T12N, R10E, UM 12/21/92 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) property line 1H-20 8,455' MD 1,601 (~ TD feet 90'~ 300' MD feet 2560 6,995' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 900 feet Maximum hole angle 39° Maximurnsurface 2.530 osk3 At totaJ denth FI'VDi 3~185 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MO TVD linclude stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' dr.2.00 CF 12.25" 9.625" 36.0# J-55 BTC 4,934' 41' 41' 4,975' 4~.273' 590 Sx Permafrost E & HF-ERW 480 Sx Class G 8.5" 7" 26.0# J-55 BTCMOE 5,014' 41' 41' 5,055' 2,203' HF-ERW 8.5" 7" 26.0# J-55 BTC 3,400' 5,055' 2,203' 8,455' 6,995' 210SxClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Redrill. Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented~ ~ ~ ~. ~ ~-% Measured depth True Vertical depth Structural ~-~ ~ ~ ~ ;~ ,~. ~ ~ Conductor ~ ~ A~..~ ~ ~ Surface ~ % ~ Intermediate Production .... ~ Liner ?~.;~j '~ ~ ~ '~ ' . Perforation depth: measured r,~,~ 0~.~' ~. ~',~-$ " 20. Attachments Filing fee X Property plat r'l BOPSkeI~h X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~ Refraction analysis r~ Seabed report D 20 AAc 25.050 requirements X 21. I hereby certify that bhe foregoing is true and correct to the best of my knowledge Signed ~"~~~~ Title Area Drillin, ,n,ineer Date /"~/~/~'Z._/'/ Commission Use Only Perm~m~_~r I API number I Approval date /47~' ~)~ See cover letter for 3~ 50- 0;z~/-' ~3J'-/ '-/~ -- othe~ requirements Conditions of a~.rov~' Sam~es r~uired I--I Yes 13[ No M~d ~g reguired I--I-Yes ~ No Hydro,en sulfide measures [~] Yes [~ No Directional survey required [~ Yes ~] No Required working pressure for BOPE [] 2M //~ 3M ~ 5M r~ 1OM [~ 15M Other: Original ~Gned By David VV. johnston by order of Approved by Commissioner the commission Date ~,,l~rwif in fri~dJ~,~t~ Form 10-401 Rev. 7-24-89 DRILLING FLUID PROGRAM Well 1H-17 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 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 9.9 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/ff. This shows that formation breakdown would occur before a surface pressure of 2,530 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1 H-17 is 1H-20. As designed, the minimum distance between the two wells would be 90' @ 300' MD. The wells would diverge from that point. Incidental fluids developed from drilling 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 175 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 ddll gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 1H-17 . . , 10 11 12 13 14 15 16 17 18 Move in and rig up Parker #245. Install diverter sYstem. Drill 12-1/4" hole to 9-5/8" surface casing point (4,975')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 (8,455') 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. Casing Design / Cement Calculations 13-Nov-92 Well Numbe~: ..... 1H~ ~ ........................ I Surface Csg MD: 4,975 ff I Surface Csg TVD: 4,273 ft 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: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 5,055 ft 4,336 ft 8,455 ft 6,995 ft 4,049 ft 7,753 ft 6,446 ft 9.8 ppg :"'"'~:~:~ ............... ::::::::::::::::::::::::::::: ................. ~:~:~ ........... :::::::::::::::::::::::':::: For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5*0.052)-0.11}*TVDshoe Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =1 4,273 ft ,53o 9.8 ppg 6,446 ft 3,285 psi 3185 psij Surface lead: Top West Sak, TMD = 4,049 ft Design lead bottom 500 ft above the Top of West Sak = 3,549 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,112 cf Excess factor = 15% Cement volume required = 1,278 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 590 sxJ Surface tail: TMD shoe = 4,975 ft (surface TD - 500' above West Sak) * (Annulus area) = 447 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 481 cf Excess factor = 15% Cement volume required = 554 cf Yield for Class G cmt = 1.15 Cement volume required =1 480 sx] Casing Design / Cement Calculations 13-Nov-92 Production tail' TM D = 8,455 ft Top of Target, TMD = 7,753 ft Want TOC 500' above top of target = 7,253 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 210 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 227 cf Excess factor = 15% Cement volume required = 261 cf Yield for Class G cmt = 1.23 Cement volume required =1 210 sxI TENSION - Minimum Design Factors are- T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 564000 lb 4,975 ft 36.00 Ib/ft 179100.0 lb 25969.9 lb 153130.1 lb 3.71 639000 lb 4,975 ft 36.00 Ib/ft 179100.0 lb 25969.9 lb 153130.1 lb 415000 lb 8,455 ft 26.00 Ib/ft 219830.0 lb 32491.9 lb 187338.1 lb 2.2J 490000 lb 8,455 ft 26.00 Ib/ft 219830.0 lb 32491.9 lb 187338.1 lb 2.61 Casing Design / Cement Calculations 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 Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 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 Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 BURST- Minimum Desicjn Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 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 Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor 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 Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE- Minimum Design Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2. External pressure =Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =! Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 13-Nov-92 415000 lb 3,400 ft 26.00 Ib/ft 88400.0 lb 13065.9 lb 75334.1 lb 5.5J 490000 lb 3,400 ft 26.00 Ib/ft 88400.0 lb 13065.9 lb 75334.1 lb 6.51 3520 psi 2529.6 psi 1.4J 4980 psi 5710 psi 2007 psi 3703 psi 1.31 4980 psi 7065 psi 3237 psi 3827 psi 1.31 2020 psi 0.510 lb/fi 2178 psi 0.91 4320 psi 0.510 Ib/ft 2210 psi 2.0J 4320 psi 0.510 Ib/ft 3565 psi 1.2J Casing Design / Cement Calculations 13-Nov-92 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 7240 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi 4980 psi KUPARUK RIVER Uh, l' 20" DIVERTER SCHEMATIC 5 6 4 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION 3 , 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-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 1(7' OUTLETS. 5. 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 6. 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10,'92 13 5/8" 5000 BOP STACK 7 , 6 5 4 ~,CCUMULATOR 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 WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(X)0 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. 10 CLOSE BLIND RAMSAND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. UNES 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 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13,5/8" - 5000 PSI SPACER SPOOL 4. 13-5'8"-5000 PSI PIPE RAMS 5. 13-5/8" - 50(X) PSI DRLG SPOOLW/ CHOKE AND KILL LINES 6. 13-5/8"-~ PSI DOUBLE RAMW/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22./89 iCREkTEO BT : ~ONES For: D STOLTZ DATE PLOTTED : S-NOV-92 PLOT REFERENCE IS 17 VERSION #4. COORDINATES ARE IN FEET REFERENCE SLOT #17. :~TRUE VERTICAL DEPTHS ARE REFERENCE WELLHEAD. EASTMAN O 300 ,, 6O0 900 - 1200_ - 1500_ 21oo 2~oo_ _ 270o_ 3000- - 3300- 360( 390£ 420C 450C - 4800_ - 5100_ 54-00 - 5700_ _ 6OOO_ RKB ELEVATION: 96' _ 6300_ A] CO ALASKA '][nC. Structure : Pod 1H Well : 17 Field : Kuporuk River Unit Location : North Slope, Alaska N 1.17 DEG W 3885' (TO TARGET) 6900 - 7200- KOP TVD---900 TMD=900 DEP=O 6.00 BUILD 3 DEG / I00' 2.00 1 8.00 '~ 24.00 B/ PERMAFROST TVD=1618 TMD--1636 DEP=14-O k,k 30.00 " 36.00 EOC TVD=2090 TMD=2184- DEP=4-16 ITD LOCATION: ] 1601' FNL, 124-4' FEL SEC. 28, T12N, RI OE AVERAGE ANGLE 38.53 DEG T/ UGNU SNDS TVD=3112 TMD=34-91 DEP=1230 T/ W SAK SNDS TVD--354-8 TMD=4-049 DEP=1577 ITARGET LOCATION: I 2038' FNL, 1235' FEL SEC. 28, T1 2N, R1 0E TARGET TVD=64.4.6 TMD=7753 DEP=3885 NORTH 3884 WEST 79 B/ W SAK SNDS TVD=4073 TMD=4720 DEP=1995 9 5/8"CSG PT TVD=4273 TMD=4975 DEP=2154 A/B MODIFIED CSG TVD=4336 TMD=5055 DEP=2204 K-lO TVD=4516 TMD=5286 DEP=2348 K-5 TVD=6026 TMD=7216 DEP=3550 TARGET TVD=6446 TMD=7753 DEP=3885 T/ ZONE C TVD=6506 TMD=7830 DEP=3! 500 SURFACE LOCATION: 642' FNL, 1156' FEL SEC. 33, T12N, RIOE T/ ZONE A TVD=674-8 TMD=8139 DEP=4-125 B/ KUP SNDS TVD=6839 TMD=8255 DEP=419~ TD / LOGGING PT TVD=6995 TMD=8455 DEP=4322 I I ..... I 12100 I lo I I0 I 2~100 I I I lo I I0 I 33100 I lo 0 300 600 900 15 0 18 0 2+o0 27 0 30 0 36 0 SCALE 1 : 150.00 Vertical Section on 358.85 azimuth with reference 0.00 N, 0.00 E from slot #17 I39100 i 4;o0 I 4.51oo i <-- West ..... 250 O 250 I I I I I I 4.500 - _4250 - _4000 - -3750 - --3500 - -3250 _ --3000 - .-2750 - -~500 - -2250 - -2000 _ _1750 - _1500 A I I z 0 7.5O (") 500 ~ Frl 250 ~ .. O 250 O <- West 4-00 1350 1300 1 250 1200 1150 1100 SCALE 1 : 50.00 1 050 1 000 95O 1100 4-100 900 1 700 11 39OO 70, 50O E 1500 300 3700 1300 1100 35o~ ~9oo ~oo ARCO ALASKA, Inc, Structure : Pad 1H Well : 16/17/19/20 Field : Kuparuk River Unit Location · North Slope, Alaska 350 _400 -, _450 --500 __550 _600 _650 - I _700 I - V _750 _..800 _850 State: Aiaska Borough: Well: 1H-17 Field: Kuparuk River St. Perm; 92-130 Date 12/7/92 Engr: M. Minder 1H-17.×LS Casing Interval Interval $~e Botlom Descriptionescriptionescription Tension Top Length lA 16 121 41 8O :MA 9.625 4273 41 4934 3A 7 6995 41 8414 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread 62.5 H-40 WELD $6 J-55 BTC 26 J-55 ~ITC MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Lbs 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9t9 lOB Mud ,Hydraulic Wieght Gradient ppg psi/It 9.6 0.499 9.6 0.499 9.9 0.515 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 o.0 0.0o0 Maximum Minimum Pressure Yield psi psi BDF N/A 1640 ####### 2530 3520 1.4 2530 4980 2.0 0 0 #DIV/0.1 0 0 #DIVI0I. 0 0 #DIV/O! 0 0 #DIVI0! o 0 #OlVlO! 0 0 #DIVIO! 0 0 #DIV/O! Tension Strength KJLbs 1C 5 2C 177.624 3C 218.764 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 736 147.20 564 3.18 415 1.90 0 #DIVjO! 0 #DlViO! 0 #DIV/0! 0 #DIV/O! 0 #DlVl0! 0 #DIV/0! 0 #DIV/0! Collapse Collapse Pr-Bot-Psi Resist. CDF 60 670 11.092 1280 2020 1.578 2166 4320 1.995 0 0 #DIV/O! 0 0 #DIVi0.I 0 0 #DIV/0! 0 0 #DIVIO! 0 0 #DIVI0! 0 0 #DIVi0! 0 0 #DIVI0! 15o IH- /'I ITEM APPROVE DATE (1) Fee , (2) Loc ,,~ [2 thru 8] (3) Admin [9 thru 13] [ 10 & 13] ** CHECK LIST FOR NEW WELL PERMITS ** Company YES 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 wel]bore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ [14 thru 22] 9 10 11 12 13 14. Is 15. Wi to 16. Is 17. Wi 18. Wi 19. Wi 20. Is 21. Is 22. Is · Does operator have a bond in force ................................... · Is a conservation order needed ....................................... · Is administrative approval needed .................................... · Is lease number appropriate .......................................... · Does well have a unique name $ number ................................ conductor string provided ......................................... ~ ll surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. enough cement used to circulate on conductor & surface ............ ll cement tie in surface & intermediate or production strings ...... ll cement cover all known productive horizons ..................... ll all casing give adequate safety in collapse, tension, and burst· well to be kicked off from an existing wellbore ................... old wellbore abandonment procedure included on 10-403 ............. adequate wellbore separation proposed .......... 23. Is a diverter system required ..................... 24. Is drilling fluid program schematic & list of equi 25. Are necessary diagrams & descriptions of diverter 26° 27. 28. ·e®e®eeele®eeeee®ee eeIee.ee~ee®eeeeeee pment adequate ..... & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~m psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... [23 thru 28] Lease & Well NO REMARKS (6) Other ~,~ ~3 ~ ~2~ 29. [29 thru 31] 30. 31. (7) Contact /V/~/ 32. [~32] (8) Addl ~Z',~_'~.,'~.(}~-7-'~2:--- 33. geo 1 ogy ' DWJ~ RPC ~ eng i neer ing,: MTM~.~ ~''' RAD_~ ~ Z -, o BEW JDH~- ~2~ rev 08/18/92 jo/6.011 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 number of contact to supply weekly progress data ...... Additional requirements ............................................. Additional 'I'NITIAL " 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. ,.....-- SCH~DMBERGER '''-'''* ****************************** FIELD N~'ME : KiJP~R~JK ~IVER BOROUG~ : NORT~ SLflPE ~.PI NU~BF.R : 50~029'223~.4'00 ~EFERENCE NO : 93007 IC OFIL ,E RECEIVED APR 02, 1995 Naska 011 & Gas Com~, ~~ ,I$ TaPe veri.~i.¢~tl, oD Listl~q ~c~],u~e.r~er A.]..~ Computinq Center SERVICE .~:Ai~YE : EDIT DAT~ : ORIGIN : FhIC REEL MA,~E : 93007 CONTINUATION ~ : P~EViOUS PEEb : CON~.~EF~T : ARC[) ALASKA, INC.,K. UPAPUK ~i. VER L!NIT,IH-t7,50-029-22314-()0 **** T h [,'. D: HEADER **** S~RVICE Na..k~E : Ei)IT DATE: : 93102126 O¢IGIN : ~'blC TAPE ~E : 9.]007 CONTIMU~TIr~.J ~ : !. PREVIOUS T.A~E : , COM~'E~blT : :ARCO ALASKA, INC.,K. UPARU~ R'.'[V~R !J~/IT,1N-!7,50-029-22314-00 TAP.~ KUPbRUK R.:I'ktER !J~.tT WEbL NA~E:. [JPEPATOR bOGGING ',rAPF CR, EATI~N DATE: JOg SURFACE [.~OCa TI[t~,~ SECT'i[~.~: TOWn, SHIP: RANGE: FNL: FEL: ~LEVAT!ON(FT F~[3~ ~S~.., O] KFLbY BUSHING: DERRICK Ft, OOfi: ~FLI, CASI~!G REC[DRD ~!T RUN 1 g3 0 ST. AMflIIP t{ H I T %; I2 Y 1 ST STRI:~IG ?ND STDI~;G BIT RUN 2 0 S 33 A ';'~ !'3 U ~ W H ~ T F b Y BIT RUN 3 3 2N iOF.. 642 !,156 q 6, f) 0 96.00 54.00 ~IS Tar~e Verification [,ist,~n,-.,~ ;cblt~berger A]aski'a Coml..>ut.,il%q Center 26-FEB-I, 993 I3:14 STRING ,r,~R O,D. U CT I o b, ********** RO~ 1 ********** ,~***,***** []u~ 2 ********** ' 55.2 BIT T[.] )[.~ 1~,2 I ~,,g~VA[, 8185 TO 845 ' ' I T ..... ' '3 WAS~{DO~,~t I~.,l e, RVAL .8164 ,l,.~ k,.ATRIX DE~ISI'TY 2 65 (G~/Cc), FL(.I~:D DENSITY 1,.0 {GM/CC] . SOFtPC'ARE VERSIO~Z V4.0C. S S **** FILE HEADER **** FIL[~ NA,~,E : EDIT .001 SERVICE : F[,IC VERSION DAT~ : 93/0~/26 ~,~.X REC SIZE ,: FILE TYPE : bO t,~ S'r FiLE PAGE EDITED ~ERG~:D Depth shifted and cl, ip~ea cu, rves: a:l.,1; hit ru~s ~erqed, DEPT~ I~CRE~BNT 0.5000 FILE SU~ARY ~R[,] TOOL CfTD~7 START D~PTN STOP DEPTH -;; ...................... C 4~81.0 CDR 4.98 ~ . 0 8420.0 ~S~'.[.,~,~g C[,:RV~7 FOR SHIFTS: CI!RVE SNIFT DATA (~,,~2ASORP:D D~PT~) 8g . 8~96.5 ~301.0 83(-)q. 5 8196.0 2202,0 ~59,5 8152.0 &~57.5 S137.5 8141.5 2~26.5 ~O~.0 ,IS Tal°e VerlfJ..catl. on I, isti. nq ;chl,.]~ber~er Alaska Computi. nq Cent, er 1.3.'. !4 80 41.0 79~4..0 7 9 2 .] .. '0 7qOa. 0 7897 , 0 7~7.3.0 7 ~63.5 7821.0 7795 5 776~15 7736 · 5 770g, 5 76~3 0 ~579 5 7564 5 7554 5 750t 0 7477.0 7.407.5 7394~5 7354 0 7318.0 7282.0 7253 ' 5 7235'0 719~.5 7190.0 7156.5 714],5 7~.2~.5 7122.5 708~.5 7065.0 7025.0 6992.5 100.0 {~ER~ED DATA, S[)UPCE TOOt, CODE "WD W 9 804,6.5 8003.5 7990.5 70.29.5 7912.5 789~.5 7879.0 7~68,5 7826,0 7801..5 '1775.5 7742.5 77!5.0 7698.5 765].5 7604.5 75 a 4.. 5 7569.0 7558.5 7508.0 746 ]. 5 741.2.0 7398.5 7358.5 7341]. 5 732.1. ,5 7285.$ 7256.5 7238.0 7~96.5 7192o5 7158.0 7145.5 713~ .n 7124.0 7084.0 7066.0 7024..5 699~.5 !00.0 1 4o61..0 2 8185.0 ~455. c: wIREI.,INK G~ OF' 21-FE~-93. ~Lb Ct'?HE[~ C'}~VES WERF; C.~RRIFO ~ITP THE CR SMIF'T. TMk SA~P[.,IN(; 'I~ICKS CO,qTAI,~:aD I.N THIS FILE IS ,.ape Ver~flcat.i.,on bistlna .~chlt,~mber<~.~er A,.!,,as~a Computinq Center 26-FE,;~-..1993 1.. 3: ,!: 4 PAGE: # · w, C ...... ~ 66 0 3 73 80 4 66 5 66 7 65 ~ 68 9 65 11 66 12 1.~ 1~ 66 ),4 65 FT 15 66 16 66 0 66 0 ** SET TYPE - CI~iAD ** N. F SERV !.,INT ] PI P API API F NU $ R P ID ORDEF~ ~ LOG TYPE CLASS ~OD ~l.l~g SAMP Et,,E?~ CODE (HEX) DEPT FT 618984 O0 OOO 00 0 i 1. 1 4 68 RHUD MwO G/C3 618984 O0 000 O0 0 1 1 1 4 68 DPH~ ~WD G/C3 61,~984 O0 000 OO O 1 1. 1 4 68 PFF ~D 618984 OD OOO O0 0 ] 1 1 4 68 Ca[,,~ MWD IN 612984 O0 000 O0 0 1. 1. I 4 68 MP~I ~WD PU-S 61~994 O0 000 O0 0 i. !. ! 4 68 ~a ~wO 0~ 618984 O0 0o0 OO 0 1 ! ~ 4 68 RP ~WD O~M~ 618984 O0 000 O0 0 1 ! 1. 4 68 ROP ~D F/HR 618984 O0 000 O0 0 1 1 1 4 68 GP ~WD GAPI 6189~4 O0 OOO O0 0 1 1. 1. 4 6~ [;$~ ~WD 6189~4 O0 OOO O0 0 1 I 1. 4 68 RSI ~WD 518984 O0 OOO OC 0 1 ] ~ ~ 68 HE[ia ~b CPS 61~9~4 OB O00 O0 <) 1 1 1 4 68 HE~.~ ~WD CPS 618984 00 006 00 0 1 1 1 4 68 T~B ~W~ 6189~4 00 000 00 0 1 I 1 ~ 69 TABU MWD 61~9~4 O0 000 O0 0 ]. 1 1 4 68 GTC~ ~wO $ 618924 O0 000 O© 0 1 1 ]. 4 68 NTCK MWD S 618984 O0 000 Ot~ 0 1 1 1, 4 68 D~CK ~wD $ 61. gg84. O0 OOO O0 (3 ~. 1 ] 4 68 RTC~ ~'~P S 61~q~. O0 (50(3 00 0 1 1 1 4. 68 O0000oOoOu 0000000000 0000000000 00©0000000 0000000000 OOO0000000 0000000000 nooo0000oo 000O0000f~0 n00000o000 O000000000 0000000000 0000000000 o000000000 0000000O00 0000000000 0000000000 0000000000 OoO00000nO OO(>O00OO0,') ;chlttmberger AlasKa ComDtlt~,nO Cen. ter DEPT. 8463.500 P'i'IOB. MI~D -999.250 DPHO.~WO -999.250 CAL~,3. MWD -999.250 NPNI.i~WD ~999.~50 R A..~'q'WD -999.~50 ~OP,MWD 115.,]89 GR.MWD 999.~50 h~SI. MWD 1.000 NF,'~N a. M~D -999,000 HEFA.MWD -999.250 TAB. ~qWD -999.250 GTCK,~W0 -999.250 ~TC.K. ~,~WD -999.:~50 DTCK. ~,~WD -999.~50 DEP T . 8400 . 000 R H OB. M W D - ~ 99.250 D R H O . .!4W D - 999 . ~ 50 C a [,~.~, ~WD '999,250 ~PH I, ~D '~9,~50 RA, ~q~D ~.60~ HFN~..~:WD -999,250 HKFA., ~WD -999.~50 TA:B. b~W0 0.601 GTCK. ~WD 1, .000 NTCK. MWD -999.250 DTCK. MWD -999,250 D ~ P 'r., 8200,009 R H [,!, B . tqW f) 2 ,44. 7 D ....... R H t'l, ~Wi) 0 ,0J4 1 o.ooo D E P T ,. B 0 0 0 , (') O O R ~I O 8 . 0~ W D 2 4 ~ 1 D R H O . ~,'l W D 0 . 0,1, 7 C ~ b N. ~ W D ~. 872 ?~ P }'{ .1. Y, W P 0 ] ~. l. a A. HFT~:A. ~WD 296.68~3 ~q~FA. YWO 8.331 'I'AB, ~.lWO ~..229 GTCO. ~W~, -999.250 NTCK. ~Wo 1.000 DTCK.~qWD -999.250 [)~;PT. "1800. 000 R!4OB ~qW[) 2.471 DR~O. MWD 0.011 C a b N .. 'M w D 9,020 ~,~ P a I ~ Y w D 0.222 R a. ~ W D 4,479 ROP.~WO 50,991 GR.~WD 49.39] NS!.~WD 0.000 f~ENA.MW0 339.500 H~FA. ~,~ND 10.9(;5 TAB.~WD 0.597 GTCK. 5~WD -9~9 250 NTCK. ~,'~WD -999.250 DTCK. ~,.,~ D 1.000 D~PT. 7600.00, fl RHC'lO. ~'~WO 2.376 DRH C ~ [J t~''M ~r P ~ ' 79 '7 N P N 'I ' ;;'{ W D 0 ' 389 ~.sWU 105 904 NSI,.'~WO 0 000 HgNa.~p 249.750 uEFA .... . . . ~, ~[., 5 545 GTCK,NWD 1 .000 a;TCK. ,'qWD -999.250 DTCK.. ~WD -999.250 DFPT. 7400.O00 P HIqI5. ~:' W 1.) ~. 5,,17 DRiil3. MWIL) -O.0u$ · · .... o ..... .,~ . ~OP. M~.,,D !66.66~ G R. i~.w f) ~ 59.055 NSI. ~,;WD 0.000 G'FCK. ~D -9qQ.~50 ?;TCK. ~'WD -990.P50 DTCK.SWD -999.P50 UEPT. 7200.0o0 R;{OF. Y:WD 2.366 D~? NC}. ~%q'O CaLN. ~wO 8. 706 ~'?PH [. ~Wf) n. 395 RA. 8WD 2. 444 H~?l ~. ~-', wO 259.500 HE;F %. ,~'t ~ O 5.608 TAB.;qwD 0.434 GTCK. 5~,o -999.25~ :~TCK. ,~k~D -999.250 BTCK. ~5',¢D 1.000 PEF,MNP RP,MWD TABD[:~WD RTCK.~WD Pg~.~WD RSI.~D TABD.~WD RTCKoMWD PEF.~WD RP.~WD R$I.~WD TADD.NND RTCK.~WD PEF.~WD RP,~WD RS!,~WD TAI~D,~WD RTCR,~WD PgF,~WD RP.MwD RSI.~WD fA~D.M~D RTCY.~WD PEF.k:WD TABD.~twf) RTCK.~WD -999.250 -999.250 1,000 -999.250 -999'250 -999.250 2,460 -999.250 -999.250 1.000 3.057 0.000 0.929 '999.250 2.753 4,035 0.000 3.073 -999.250 2.724 6.003 0.000 2.400 -999.250 2,886 1.350 0.000 4.026 !.000 3.376 2,~90 0.000 2.354 1.OEO 3.337 2.41.4 0.000 -999,250 15 Tape vert~icetlon Listino ~ch].umberger Alaska Computing Center [) Y: P T ,~ 7000,000 R bi O B, M' W D C/~ I...~N · b!WD 8,669 NPNI, ~iWD ~GP, ~%'~D 279,055 GR. H E N a. ~' W D 278.250 H g F h. ~'~ W D GTCg.~WD -909.250 ~TCK.FtwD D E P T, 6600, O00 P'H 06, ~ W D ChLN,~WD 8,526 ~OP,MWD 2~. 3,496 GR, ~ENA.~WD 264.750 HEFA.gW'D GTCK,~aWD -999,250 N'TCK, ~:WD D E P T, b 600,000 ~ ~' O ~:~., ~'~ w D CALM,~WD 8.717 POP' ~,sWD 334.936 HENA. ~(WD ~71, .000 HEFA. ~,~D GTCK. ~WD -999. ~50 NTCK. DFPT. 640(), 000 ~HO8. CALM,MWD 8.626 NP!tI. MWD RCP.M~D 189. lO0 HEM ~,. MWD 275. 500 HEF'~. ~WD GTCK.MWD -999.250 NTCK. ~WD D E P'f. 6200.000 R ~ O B. P; w D C~LN. fa~/D 8.573 ~OP. MWD 353,625 H~INA .M'WO 281, 000 HEFh..MWD GTCK', ~.~WP -9991250 MTCK. ~,4wO [)57pT, 6000.000. C~LN,~WD 8.500 NPHI, ~IWD ROP.~,,~D 405. 585 GR HENa,~WD 280,250 HEFA,aWD G'!'C~, ~.'WD -999,250 NTCK,MWD DEPT. 5800,000 C~LN,HWD 8,661 mOm,MwO 458,.12,t GR.~wD HEbA.MWD 287,189 HEFA,~WD GTC~.MWD -999,~50 NTCK,MWO CALN.~WD 8.556 NPHI,~WD ~OP.MwO ~]8.~14 GR,MWD GTC~. ~;WD -999,250 NTCK. DFP~. 5400,000 PHOB, C ~, LN..WD 8.66~ H~N a. ENg 2g I. 750 HK~A. GTC~. ~WD -999. 250 NTCK. 26-FE5-1993 13:~4 2 . 4, 78 [> IR H 0. !,4 W D 0 306 P a . a W P 88:031 NS!. MWO 7.133 1,000 DTCK.~WO 2,359 ORHr:), t4k D ~3 916 NSI'. 5,798 -999,250 DTCg,.~'~WD 2,475 DPHO,~WD 0,328 110.910 ~. 000 DTCK. 2.365 0,340 1 37,759 6.~0 TAB.~WD -999. ~ 0 DTCK. 2,407 DPHO.MWD 21 R. a. , O -999; ~50 DTC~ 2. 364 0.304 92. 049 7,255 ~, ()00 DTCK. MWD 2.394 0. 325 RA.,~WD 80.809 NSI..M~D 6.973 -~99,250 DTCK. ¢4w0 2,342 D~Hq. 6.855 TAE,.MWO -99~.250 DTC~, 2.353 DRHO.~4WD 0.317 6.758 TA,~. Mw9 1.OOO [>TCK. YWD 0. O04 2,79O f!. 0 00 O, 38 3 -999: 250 - 0.002 2.821 0,000 0 464 -999: 250 -0.003 3. 115 0.000 0.325 -999.250 -0.013 1 959 o :' o o o 0,465 -999'250 0,000 2 0: 000 0 294 -999:250 0.007 3,140 1.00o 0.305 -999.~50 0,001 3,6~3 0.000 0.315 -999.~50 -0.006 2.916 0,000 0.214 1. O00 -0.0.1.9 3.442 O. 000 O. 3! 4 -99o.250 PAGE: 3,387 2,613 0,000 1,169 -999.250 3.762 3,045 0,000 0,710 -999.250 3.371 2.843 0,000 0.5!1 -999.250 3.317 2.228 0.000 0,886 1.000 3.211, 2.151. 0,000 0 706 -999:250 3,143 3.013 0,000 0,670 -999,250 3.320 3.344 0,000 0.664 1.OOO 2,928 2,745 0,000 0.491 -999.250 3.01.9 3.2~2 0.000 0,489 -999,250 ':IS TaPe Ver~,cat;,!on L'f. st.~,n~ ~chlU~ber~_er AlasKa Comput, i~g Center 26-FEg-i, 993 !,3:14 PACE: DE:PT. 5200,O00 RHOB, MWD CALM.MWD g.606 ROP. Mg~D 2~9. 671 GR. M'WD N~N~ .~WD 273,632 GTC~.MWD -999,250 P K p T. 5000. 0 (.} 0 R ~'1 (] B '. ~,~ w '0 C a t, N. ~' W D 9.727 'N P ~ I. M W P ROP. ~WD -999. 250 GR. NEN A. ~:'~D 233.750 HEFA.MWD GTCK. ~W'D -999,250 NTCK [) K p T. 4981.000 CALN, ~WD 9,472 NPHI. R[]P. ~WD -999,250 G{:{, F~WD ~.JEN ~ ..MWD 222.750 HEFA.MWD GTC~'.MWD -999.250 NTCK.MWO ** END OF DATA 0.3 1 4 6.865 -999.250 2.031 0.4 5 7 74,789 4,670 -999,250 2.377 0.500 48.18 ] 0,000 3.485 0.000 0,357 -999,250 -0 022 3 348 0 000 -999 250 1.000 -0 461 0.000 -999 -999.~50 2.82i 3,359 0,000 0,650 -999,250 3,0~0 3,i65 O.OOO -999.250 -999.250 -999.250 -999.250 0.000 -999.250 -999.250 **** Elbe TRAIbER **** F'![,,,E NA~E : EDIT .00~. SERVICE : FbIC VERSION : O01A07 DATE : 9:]102/26 MAX REC SIZE : FILE TYPE LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT ,002 SERVICE : wLIC VFRSIOM : O01A07 D~T~ : 93/02/~6 M~X R~C STZK : 1024 F].LF TYmE : bO I,hS~' FILE : F l .t.':F FILE NU'~6FR Curves and lo~ [~I'V RI. IN D~PTH INCREUENT: 2 header data for Tf]OL C (:) D I;: START each bit run i.n seoarate files. S. Tf~P bEPTH I~ Tope Verif!cation !,,isti~ ~chl~berqer .~l,,ask~ Co~puti,,nq Center 26-~'~;B-1993 ~3:14 CON 4981.0 LOG HEADER DATA DATE!] LOGC.,ED: SOFTWARE: SURFACE $OFTWA.~E VERSION [>O'~'~H[)L:E SOFTWARE', VERSIONS: DATA, TYPE (~,!EaORY OR ?L, D~ILLER (FT): TOP LOG IN'TE~VAb ~C~TTO~. LOG INTERVAL (PT) BIT ROTATING SPEED HOLE .INCLINATION ( ~4AXI~,UN ANGLE;I 8455,0 L ? G~!. S- 1 F,, S ,t~ V 4 8455, () 49~1.0 84,55.0 V'~iNDOR TOOL CO[) ...... TOO[, T,,,PE C P N i',~ R . 0 R [J S I '.'t Y CP~ RESISTIVITY S BOREBOLE AND C~a. SIN'G DATA OPEM HQLE ~%IT S~ZE DRILLERS CASI~'~,G DEPTU BO~ EHO[..,E CONDITIONS MUD TYPE: DENSITY (LB/G): VISCOSITY ($) C~5ORIDES (PP~I) FLUID LOSS (C]): RESISTIVITY (OH~'*~ .AT TEuPFRATURE DEGF) ~UD ~T ~,~EASU~ED TE~PER~'FIIRE ~ltD AT NAX CIt~CULATIS!G TE~PERATORE~ >~IjD FILTRATE; AT ~q~.lD CAKE AT TDI'?L NUMBER ~i' D S 0 l 8 RGS058 8.500 4981.0 9.~0 2.110 2.230 84.0 ~;E!iT¢O~! TOn!,,, ~ATPlX DE~iSITY: HOLE CCRRECTIO~ TOOL, S'Ft~;DOFF (IN): F~.'~R FREC4I~ENCY (H7): 1 .Il) TW!S FIL,~: CONTAINS TiIP; S~'.~PI..,ING TICKS ..',~t,:D FII.,E. ]'HIS [)AT& IS ,~S CLOS~ Tfl THE ACTUal., RATF AOUISTTIr~-',~ ~S POS.qi¢b~. $ · ,IS Ta~e verification L!stinm ~ch.l, Umber~er ~].aska Com~)ut. inO Center 26-FEB-1993 .~ 3:~4 P~GE: ** SET TYPE - 64:EB ** TYPE REP~ CODE ,,1, 66 2 66 3 73 20 4 66 255 5 66 6 73 7 65 8 6~ 0.1 9 65 FT Il 66 51 13 66 0 14 65 FT 15 66 68 16 66 0 66 1, ** SET TYP~] - CMAM ** N ~E SERV UNIT SERV PI AP,[ h I F . ' gE ~EPR C SS DEPT FT 61,8984 00 000 O0 0 2 l 1 a 68 OO000O0000 GTCW 005 $ 618984 00 000 00 0 ~ ~ 1 4 68 0000000O00 NTCK 005 S 618984 O0 000 O0 0 2 ~ 1 ~ 68 0060000000 DTCK 005 S 6189g4 ~O DO0 0O 0 2 1. 1 .~ 68 OO00000¢/00 RTC~ 005 $ 61fl984 00 OOO O0 0 2 1, 1 4 68 0000000000 ** DAT~ ** DEPT. 4865,P~0 GTC.K.005 -q9~.250 c{TCM,005 !.00o DTCM.O05 RTC~,OO5 -999.250 DEPT. 4999,90!) GTCK.O{)5 -99m,250 ~:,iTCK,005 -990,250 OTC~.005 RmCR.005 -999.~50 DEPT. 50OO.lOl GTCK.OOb 1.000 c!TCK.OO5 -q9q.250 DTCK.O05 RTCK.O05 -999.25(.) -999. 250 -999,~50 -Q99,250 ~IS .T.a~e 'V'erification b!,st:,ir~g ~chlumberqer .Alaska Comput, ino Center DEPT. 5200,10i GTCK,005 RTC[, 005 -999,250 D~pT S~99 90~0 (;TrK. OOS DEPT. 5400. 101. GTCK o 005 RTCK..005 -999,250 D~PT. 5599,900 GTCK.005 RTC~.005 -999,250 DEPT. 5600o101 GTCK.005 ~TCK.00$ -999,250 DEPT 5799.900 GTCK.005 RTC~::005 -909,250 ' D~P,. ssoo.~ot ~TC~.OOS RTCK. 005 -999,250 DEPT, 5999,900 GTCK. 005 R~C~. 00S -,~9. 250 RTC~,005 -999,250 DE:PT 61~9,900 GTCK.005 PTC~:005 -999,250 DEPT. 6200,101 GTCK.005 RTCW.005 -999,250 DEPT. 6399,~00 GTCK,005 RTCK,005 1,000 i)~PT, 6900,10I GTCK,005 RTCK,O05 1,000 OKpT, 6599,g00 GTCK,005 RTCK,005 -999,250 DFPT, 6600,101 GTCK,005 RTCW,005 -999,250 DKPT. 67~9,900 GTCK,005 PTCK,005 -999,250 26-FEB-l. gg3 13:I4 -g99,250 ~TCK.005 -999.250 NTCK.005 -999.250 NTCK,005 -999,25(! NTCK:,OO5 -999,250 MTCK,O05 -999,250 NTCK,O05 -999,250 MTCK,O05 -999,250 'MTCR,O05 -999,250 ~ITCK,O05 -999,250 NTCK,005 -999,250 MTCK.005 -999.250 NTCK,905 -999.250 NTCK.005 -~99.250 ~TC~,O05 -999.250 NTCK.O05 -999,250 ~TCK,O05 -999,250 '99go250 -999.250 -999,~50 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.~50 -999.~50 -999.~50 -99~.250 -999.~5o -999.25o -99q.250 -909.250 DTCK',O05 DTCK.O05 DTCK.O05 BTC~,O05 DTCK.005 DTC~'.005 OTCK.005 DTCK.005 !)TCK.005 DTCK.O05 DTCK.O05 DTCK.005 DTC~.005 D*C~.O05 DTCK.O05 {)TCK.0~)5 PAGE: 10 -999,250 -999,250 -999.250 -999,250 -999.250 1.000 -999.250 -999.250 -999,250 -999,250 -909,250 -999,250 -~99,250 -999,250 -999,250 -999.250 -999.250 3chlumber~er .AlaSka Comput,~.ng Center DE¢?. 6800. 101,. GTCK,O05 [~TC~: 005 -999. 250 O~]pq' 6999,900 GTCK. 005 lqT~g~: 0OS '999.~50 [)~P... 7000 IO1 (';TCK,005 ~ .... c~:oos -999 ~,5o D E'p'r 7 1 09,9 00 G T C K. 005 RTC~ :005 -999,250 RTC~:OO5 -999. 50 DEPT 7399 900 ..,TCK 005 ~C~. 005 -999,250 DEPT, 7400. 101 GTCK. ¢0S RTC~', 005 -999. 250 DEPT 75q9.900 GTCK.O05 ~TCK'005 -909 ~50 D ~.l P T, 7600,101 G T C :~'. 005 RTC~',005 1,000 [)EPT. Z799,90() GTCK,O05 RTCK,O05 999,250 DFPT, 7800,1.01 GTCK.O05 RTCK. 005 ~., ()00 DEpT. 1999 900 C a,c~. o05 99,9 D~:P*.. ~0o0,101 GTCK.005 RTCF. 0~5 1, D;SpT, 81~9,900 GTCK.005 RTC~,O05 -999,250 DEPT, 8200,100 GTCK.005 ~TC~. 005 !. 000 DEP~, ~309,900 GTCK.O05 RTC~. 005 -999,250 DFPT, R400,100 GTCK.005 RTC~, 005 ~ , D~PT. a409,701 GTCK,OOb PTCF. 005 1,000 26-F'EB-,1993 t. 3:24 -999,250 ~TCK,O05 -999,250 NTCK,O05 -999,250 ~iTCK,O05 '999,250 NTCK,O05 -999,~50 NTCK,O05 -999,250 NTCK,O05 -999,250 NTCK.O05 -999,~50 NTCK,O05 ~,000 NTC~,O05 -999,~50 NTCK,O05 -999.~50 NTCK,O05 -99q,~50 NTCK,O05 -999,~50 ~TCK,OOb 1,000 NTCK.O05 2,00(t NTCK,OO5 -999,~50 NTCK.O05 -999,~50 ~TCK,O05 -999.250 -999.250 1,000 -999,250 1.000 -999.~50 -999,25O 1.000 -999.250 -999.~50 -999,250 -999,250 1.ooo -999.250 -999.~50 -999,950 -990.~50 [.~TCK,005 ~TCK, 005 DTCK, O05 DTC~:.O05 DTCK. 005 [) T C K , 005 DTCK° 005 DTCK.O05 D'fCK, 005 [)TC~'.005 [,:)T C g. 005 DTCK, 005 P: CK. 005 ~TC~ .005 D'I?CK, 0o5 DTCg. 0O5 DTCK. 005 DTCK, 005 PAGff: 11. -999.250 -999,250 -999,~50 -999,25() -999,250 !,ooo -999,~50 -999,250 -999.250 1..000 -999,2~0 1.000 1,000 -999,250 -999.250 -999.250 -999.250 -999,250 ,;cblu.mberger ~!aska Com~ut, l, n9 Center 26-~'EB-1993 1,3:14 12 **** FILM TRIi!,.,ER **** FILE M.~ME : EO,,"I 002 .... , SERVIC~ : FblC DATE : 93102/26 $~X ~C S!iZE : 1024 V'I'[~ TYPE : L~S? FILE **** FII, E HEADER **** FILE NA~E : EDIT SERVICE : FI, lC ¥'ERSI, OM : 00lA07 D~TE : 93/0~/26 MI× REC SIZE : FILE TYPE : bO L~ST FILE F I [., ..F, HEADER FILM NU~.' [%E R 3 Curves and lo~ header data ~or each bit run in separate files. BIT R!..I!'~ NIJ~BER:, 1 DFPT},! IMCRE'~E~!'T: 0.5000 F!bE VENDOR TOOT., CODE START DEPTFI ................. .... C U R ~ . ....... CDN 'i98 1.0 LOG HEhDER. DATA DATE LOGGED: ~OFTWAmE: S[.IRWACE SDFTWAR~ VERSION: DOWNHSLE SOFTWARE VKRSION: DATA TYPF (N~N~ORY OR RMAL-TI'~..~E): T~ D~IbL~R (FTI: TOP LOG INTERVAL BOT7'O{,! bOG I~'r~aVa!., ~IT ROTATING SPEF]D (PPis): NOLE INCI,I~IATION (OFG) STOP UEPTI-,' 81,85,0 02-JA~-9~ 8185.O 4981.0 ~185.0 ,~;~S TaPe Yerification bist!.n~ ~c~lum~er~er Al, as~a ComPutinq Cent, er 26-~'EB-1993 1.3; TOOL STPING (TOP TO BOTTOM) VENDOR TO(3L CODE TOOL TYDE C D ,,~ P 0 CDR NES~STIVITY B~REHOLE AND CASING DATA OPEN ~q[,]LE BIT SIZE DRILLERS CASING DEPTH' RORL~HO[,,E MUD TY~E: ., '*~ .. ~UD O~.~SITY (LB/G): MUD VISCOSITY (S): ~I..!D CNLOR,IDES (PP~'~): FLUID bOSS (C,])~ RRSIST,[YlTY (OH~4 ~T TE~PER~,...IR~. ~UD AT )~AX CIRCOLATIMG TE~PE~ATURE: ~UD FIL"r~ATC AT MIlD CAKE AT NEUTRON TOO[,, ~qAT~I~: ~4ATRI% OE~SITY: HOI,,,~ Cg~RECTION (IN): TOOL STANDOFF fIN): 8 ,5 0 2.1,10 2.230 24.0 65.0 2.65 5 1 . 0 REMARKS'. ****;***** RUN 1. BIT TO RES 65.8', HIT TO G~ 76.2', BIT TO DEN 132,9' BIT TO ?~EUT 139 9' DRIL!,,E~t) if;T'ERVAL ,49B1' TO 8185' MATRIX DE~I,$ITY ~.6~ (G~/CC), FLU.ID DEMSI.:TY 1.0 (G~4/~C) ~OTATIONAL BULK DEr',)SITY PROCESSI~qG I~SED. TO ~UD SYSTE~. DATA SOFT~,~ARE VERSION V,~:.0C. S LIS FORMAT DATA ** DaTA POR~!AT SPECIFICATI(I~; qF:Cr]RL) ** ** SET TYP~ - 6~E~ ** TYPE ~EP~ CODE VAbUE t 66 u 2 66 0 ;IS ?spe Verificati.,on bl, st'i, nq -~chl, umberc~er Alaska Comput, l,n~ Center 993 13: 14: 5 66 6 73 7 65 8 68 0%5 9 65 ~'" I1 66 17 12 6~ 1,,3 66 0 14 65 P"T 15 66 6~ 16 66 1 0 66 1 ** SET.TYPE - CNaN ** NAhE SERV UNIT SERVICE API AP1 APl APl F,IibE NPM~ N[.I~iB SIZE REPR PROCESS ID ORDER # bOG TYPE CbASS ~OI) ~ll~B SghP EbE~ CODE (HEX) O~PT FT 61898 0 0 3 I, 1 6 00 0 R}~OB I,,W~ G/C3 618984 00 000 00 o 3 I 1 4 68 0000000000 P~aO LW! G/C3 618984 O0 000 O0 0 3 1. I 4 6~ 0000000000 PEF LWI 6189~4 00 000 00 0 3 1 1 4 68 00OO000000 DCAL bWl IN 618984 O0 oeo O0 0 3 1. 1 4 68 0000000000 DPHI I.,~l PU 618984 O0 000 O0 0 3 1 1 4 68 ()000000000 TNPD LW1 PU 6189~4 O0 000 O0 0 3 1 1. 4 68 0000000000 ATR LWl O}.IMM 61~984 O0 000 O0 0 3 1. 1 4 68 O00000OO00 PSR [,WI OHM~ 618984 O0 000 O0 0 3 1 1 4 68 0000000000 ~OpF I.,W~ F/RR 61~984 O0 000 00 0 3 1 1 4 68 0000000000 G~ [.,Wl GAPI 6189~4 00 000 O0 O 3 1 1 4 68 0000000000 HEN~ LWl. CPS 618984 O0 000 O0 0 3 I 1 4 6~ 0000000000 HEF~ L~,I CPS 618984 O0 000 O0 0 3 1 1 4 68 0000000000 TAB [,~1 6!~984 O0 000 O0 0 3 I 1 4 68 O000OO0000 TIBD I.,w~ 618984 O0 000 O0 0 3 1 1 4 68 O00OO00000 I~EPT ~184.500 R[40[~. [:W 1 -990.250 DF' He.). I..,W 1 -99o 250 OCA[,; ~,w~ -999.250 OPHI.I,wI -999.~50 ~'NPH.SWl -990:250 AT~.LWl PS~.LWl -909.250 ~rlPg. LWl ~. 85'P G~.LW1 -999.250 HE~ A .I,~1 F{~F~.T,Wl -999.250 '.F~B. [,W1 -999.250 TAgD.)5~I -99g.250 DF, pT. ~000.000 ~uOB. i..,W 1 2.460 bI~ HO. I.,w ! O..0, g I PEF.I,wl DCA L. 1.,¢"~. 0.416 DPitI.LWl 11.500 TNPH.LW1 30.100 DSP. I..,W 1 3,828 R(JP~. Lw I 96.251 GR. [.,w l 70.118 -999.250 -999.250 -999,250 2.891 3.915 283,20~ Tame ver!,fi, catio~ !.,isti. no ;chlumber{~er A],asKa Computing Center DEPT. 7800.000 OCAL. I.,wl 0.390 DPHI.LWI PS~. [,,!'.~ 1 :3.344 H~FA. LW 1 9,045 TAB. [.,W1 D~PT. 7600.000 RHOB:.)3Wl D C ~ L. I, W 1 0.690 0 P ~ I. L W 1 PS~.l~w~. 2'1.08 R[~PE.LW1 H E F ~. L ~ 1 5., 521 T A (~. DE'PT 7400. 000 R.U ~ 6. DCAL:hWl 0,535 OPaI,LWl PS~.LWl 1,790 ROPE,[,W1 H~F~, LW 1 5,238 '~A[:~. LW DFPT. 7200.000 DCAL,LWl 0,237 DPHI PS~. [.,Wz ! 2 429 R ..]PE. LW l N~F ,5.. l,, ~ 1. 5.698 TAa. LW D~P~ 7000 000 ~HOB,bW1 PSR.L~:I 2 639 ROPE, DEPT. 6800.000 9CA. L.LWl. 0,0~6 PPH.I.LW1 PSR.LW1 3.045 ROPE.I..Wl HFF~.LWl 5. 798 TAa. LW DFPT, 6600,000 DC&I..,LW1 0,217 DP~ I. I..,W 1 HEF'I. LW}. 6.723 TAB. LW D~pT. 6400.000 RHOB.LWl DCA!.,. Lw~ ('!.126 DPHI. I,.~W 1 PSP.LWl 2,2~8 ROPE,LWI ~FF~. bW1 6,6~0 TAM. D~PT. 6200,000 RHO%. DCAL. L~ 1 O, 073 DPHI. L PSP.[.W1 2.151 HMFa. b~ 1 6. 930 V~. bw DKPT. 6000.000 RHD~.LW1 PSm.LWl 3.013 H~FA. I.~..~' 1 7. 255 TAB. Lw DFpT. 5800.000 DCAL. l,,W 1 O. 161 UPH I. Lw DS~.LWl ].344 ROPE.Lwl HEFA, LW 1 6. 973 TA~, 13:1.4 2. 447 DRHO, bW 1. 12.300 Ti'.tPN, LW 1 35.92a' GR. bW 0,:42.~ TABD,LWl 2,769 DRHO,LW1 7,200 T'N P H', b W 1 99,444 0.849 T 2.467 DRHO.L~I ~. 1,100 TNPH 171.421 Ga 1,322 TABD,bWl 2.407 DRHO,LWl ! 4.700 T i'q' P H. b ~ 1 208,619 GR,LW I 0,431 TABD,LWi ~. a, 81, 10.300 T 278. 224 0,383 TIBD,Lwl 2,359 [)RHa, I.~W 1 17.600 T~PH,LWl 913. 496 GR C,464 2..475 10,600 T 334.936 0,325 TABD,LW1 2.365 [)RHO, L'W1 17.300 TNPH.L~I 189.100 GR, L:~ I 2.407 DRHO,LW1 ! 4. 800 TNPH.I,,W 1 353,625 GR, LW 1 2,364 17,300 T~PM, L~..{ 1 405,5d5 GR,Lwl ~.305 T~.~D,Lwl 2.394 DPWO,LW1 15.500 ~5~, ~ 2~ 0.315 TAP~D.LWl 0.021. 24. 200 53'304 2.299 0.018 38.700 80.335 4.04,9 0 000 43: 167,561 2. 363 -0.002 38. 700 1.44.324 0.~22 0 0 04, 4,0o 87 790 -O.OO2 38.80O 11.3.816 0.710 -0. O03 32,800 110.910 0.511 -0.01.3 3 4. o 00 .!37.759 0.~86 0.000 32.100 79.960 0.706 0.007 30.400 92.049 0.670 0.001 32.500 80.809 0.66,i PAGE: 1.5 2,584 3,665 303,938 4,132 1.5 4:8 250,000 3 4.21 21 o7 254,125 3,436 2,490 258.250 3,372 2,821 278,250 3,762 2,82! 264,750 3.371 3.3~7 ~,959 275.500 3.21.1 2,271 281.000 3.143 3.140 2a0,250 3.320 3.613 287.1~9 ~Ia 'fane Veriticatlon L, isting ~chlUmberoer .~lasKa Computfno Center D.E P t 5 6 0 0.0 0 0 PSR.LW.1 2,745 ~OPE.LWI OFPT, 5400.000 O C A 1.::. t., w 1 0.169 D P'F! I. L w 1 P S'~. L w 1 3,282 'a o p E. L w 1 HEFI.I,,w~ 6. 758 T!S.LW B E P T. 5200,000 ~ H C? ~. b ~ 1, De~LiLWl 0.106 DPH I. I,,,W 1. PS~.LW1 3.359 POPE.LWl H~F~.LWl 6. 865 TtB.LWl D~TPT. 5000,000 RH:O~. LW1 OCAL.LWl 1.227 PSR' I,,'W 1 3.165 ROPE.LW1 H ~ F ,a. L ~' 1. 4.670 'I.'~ A 8. t, w 1 DEPT. 4865.000 DCAI.,.BWl -999.250 DPHI.LWl P~ LW1 -999,250 HE~ a'' w ' ' . .,.., 1 4.262 rA ** END [.]F DATA * * * * F I L E FIL~ NA~E SERVICE VERSION D A T E: {~t~X REC SIZE F l LF.. TYPE LAST FILE TRAIl, ER **** EDIT .003 ~'LIC 00lA07 93/02126 1. 024 **** FILE FILE NA,~E SFRVlCE VER$IOH F!bM TYPE L~ST FILE HEADER **** : EDIT .004 : FLIC : 00lA07 : 93/02/26 : 1024 : F'TLF ~EAD~R 26-FEB-I, 903 !3:!4 2.342 41,8.~14 GR.LWl 0. 214 TABD. LW 2.353 DRHO.LW1 I~ OOO TNPtt. Lwi 4381161 Ca.Lwl 0.314 T l a  304 D~H'O.LWl ,2 ~ o 00 229.8~1 ~R. 2.0-31 DRHO,LWl, 37. 500 TNPH. L'Wl '990. 250 f;R, LW1 -999.250 TAi~D,LW1 '999.250 DRHO.LW1 '999,250 '999,250 (;R, LWI '999. :250 TABD.LW1 -0 : 2:7oo 80349 0~491 -0.019 31.700 88.304 0.489 0,00o 31.4:00 79.703 0.650 -0.022 45.700 74.789 -999.250 -999 250 g 12so P,~GE: ! 6 2,928 2.91,6 281.000 3.01,9 3.442 2,821 3"485 273,632 3.0~0 3.348 ~33.750 -999 250 -999~50 -999,~50 i~,I$ ~a:~e Veri~ication ~ch]um,~erger A].aska ComputJ. nq Cent, er 26-FEB-1993 13:14 RAW Curves and .,loc~ header data for each bit run lm se~)arate files. BIT RUN NUMBE[~:. 2 DEPTH INCRE~EMT: 0,5000 F II,,~ SUM~ARY VENDnR TOO[, CODE START DEPTN STOP D:EPTH a185.0 84,55.0 $ bOG HE.~:DER DATA DATE bOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHObE SOFTWARE 'VERSION: DATA TYPE (I~E~ORY OR .REAb-TI~E) TD DRILLE~ (FT): , TOP [,,[)G INTF ...... VAL (FI): BOTTOM bOG INTERVAI,~ ~iT ~OTATING 8PE~D (R'P~I): MOL~; INC!,INITIOa (DEG) ~INIMU~ ANGbE: ~'A X IM!..tM AN'Gb'C ~ TOOb STRING (TOP TO BOTTO~) VENDOR TOOL CODE TOOL TYPE CDN NE[ITR(]h~/POROSI~'Y CDR RESISTIVITY ~OREHO[,E AND CASING DATA OPE~ HOl.~E BIT SIZE DRILLERS CA. SING DEPTH (FI): FOREHOT.,E CONDITIONS ;~!ID TYPE; ~qUD DENSITY (LB/G): ~UO VISCOSITY {S): ~UD PH: ~[ID CHbORIDM5 (PP~!): F!.,UID bOSS (C3): RESISTIVITY (OH~,!~ AT TEMPER~TI!RE DEGF) ~UD AT gEASURFD TE~{PERATURC MUD AT P~AX CIRCULATING ~IJD FI[.,TRATE AT ~T: ~L~D CAKE AT ~ATRIX: gATglX DENSITY: HOLE CORRFCT!(.;~ 8.500 4981..0 2.110 2,23o 65.0 SA NDSTON 2.65 8,500 .c :lumberger Alaska ComDutiDg Center 26-FE:B-1993 13:14, 'rOOf., ST.~NDOF? f. IN): k. IT TO GR 55, ~!T TO ~EX~T 1{9,6' D~Ib~tD ~N'i'E~:VAL 8185' TO 8455', WASHDOWN' XNTERVAt~ ~164'" TO .... 8185'. .... Ar~IX DEN,,IrY ~.65 (GM/CC)..FbUID DE:NSlTY 1 0 (G~/CC) ROTATIONAL ~[.JI~K [)EMSITY 9Ri.)CESS. I~'~IG USED, BAritE ADDED TO ~I, ID SY'S'rEa BATA FR ~ DC)W~H[]i~E M~sM[)RY D ..... SO~'r'~l~ VE~SiH~ V4.0C .!.,8 ** !~ATA FORMAT SPECIFI' ("l?IOD:! RECORD ** oET TYPE- 64EB ** TYPE REDR CODE V.A L,U E } 66 0 2 66 0 3 73 60 4 66 5 66 6 73 7 65 8 6 g 0,5 9 65 11 66 17 13 66 0 14 65 FT 15 66 16 66 1 0 66 DF'PT FT 61.8984 EPOB I.,.W? G/C3 618984 O0 000 O0 C, 4 1 D~Ho Lw~ G/C3 618984 O0 PFF L,~ 618984 O0 OOO O0 0 4 I 1 4 6~ DCAL Lw2 IN 618984 O0 DDH'I LW~ PU 618984 O0 ~00 O0 ~ 4 ] I a. 68 Ttx: pH L~2 PU 618984 O0 000 O0 C, 4 ] 1 4 68 .h. TR [.., W ~ O H ~,,1 ~ 618984 OO OOO ~0 ('} ~ 1 1 4 68 00oo000000 O00000OO00 0000000000 O0000OO000 0000000000 0000000000 0009000000 ~chlUmberger .Alas~'a Computing Center 1,9 DATA DCAL.b~2 -999.250 OPHI,bW2 -999,250 T~,~P~. bw2 999 ~50 ATR.L~'2 "PS~,LW2 -999,250 R f.'.lPE, L ~.~ 2 J. ]. 5 ,i.389 GR.Lw2 2999:250 ~{ ~ ~?I ~ , Ii' ~ 2 DKp'r ~4.00.000 P, ItOB.LW2 -99c~ ~5o DRH0 LW2 c~99 250 DC AL' z * '~ ,LW2 -999,250 DPHI,LW2 -99~', .50 ,TbtPH. I,.,~2 -999. .250 A':rR.L~2 PSR [,:,W~ 2 273 "~ ;' . HEF~.I.,W2 -999.250 TAB.bW2 0.581 'P,~BD. h'~ 2 -999.250 DKPT. g200,000 RHOB.L~2 2. 474 DRHO. b~2 -0. 014 PS~ LW2 1.975 ROPE; b~2 1,05.063 G'R,L, 2 89.918 D~PT 8007 506 ~0~ [,,~2 '99~ 250 DR~,]O hw2 -099 250 P~;F LW2 Al,, I, W2 999.250 DPHI. L%12 -99~:250 T ~II P g., LI~< 2 -999,250 A TR. I,.,~i2 PS~. I,,W2 ROPE.LW2 999.250 GR.Lk2 -999.250 HENb. I.,~2 . '99o,250 ~D LW -9 0 }-JEFA,L~2 7.497 TABob~2 TA . 2 99.25 ** Eh!i;) 01~ [JAVA ** -999.250 -999,250 -999.000 -999 250 -999.250 3.235 2.1,48 277.000 -999.250 -999.250 -999.250 **** FILE FILM NAME SFRVICE VFRSIOM DATE ~aaX REC SIZE FTI,,,E TYPE L~St TRAILEP, **** EDIT ,0o4 FLIC 00.! A07 9]/02/26 1024 I.,O ~15 TaPe Verification List].~ ;c~lU~erger A!~ska ~om~utinO Center FILE NAME : EDIT ,005 SERVICE : ~L, IC ¥ ~RS10174 : O0~,A07 M~,X REC SIZE : 1024 FIL~ TYPE : LO LAST FILE :' 26)~'~,':B-~, 993 1,3:],4 P~GF~: ,2., 0 E[~ITED MERGED MWD Depth shifted add CliDped cl~rves; al1 bit DEPT~ I ~CRE~E~T 0.5000 F % [,~ SUMMARY KRU TOOL COD~.' START DEPT),~ STOP DEPTH CDR 842 7. )~AS~LI~4~ CU~V~'] FOR SHIFTS: C!)RVE SHIFT DATA (~EASUPED DEDT~} ----------E~7}i.I!VALE{~'~':~T [)NSH!FTED DEPTH'---------- B ASE[.,I ~,IE DEPTH. i'~'.E~GED DATA $(}U~CE KP[) TOOL CODE BIT PiiN ~0. S~'.~P~E TOP ~ER~E BASE ~E~:~A. RKS~ T}{IS FtbE CO{~TAI{'{S ~'IG~'~ ~'.ESObUTID~I RESISTIVTY DATA. S LIS FORMAT DATA ** D~,TA FOP~AT SDECTS'IC.aTTt]~Y PECf.IPU~ ,iS 'rave verifi, cat.i.o, r,i. st~..n~'~ ;chlumberger AlasK'8 Com~uti. nq Center P A G E: 21 ID ,ATpH 001 P,SP~ 001 ATER 001 F'SE~ 001 OHMM ATV~ OO1 TYPE;- CHAN ** E API ~PI APl t~P'i FII,,E i,,i:ld N g PR PROCESS ORDEP ~ hOG TYPE CL~88 ~iOP 'MUMB SAMP EI_,EM CODE (HEX) .... ..... .......,.....,....-.,.... ..... ,. ...... 61. ~ 4 () 00 0 5 1 : 6 0000000000 6189~4 06 000 00 0 5 ~ 1 4 68 0000000000 618984 00 000 00 0 5 1 ~ 4 68 0000000000 6189.8a O0 000 00 0 5 1 I 4 68 0000000000 61,8984 O0 000 O0 0 5 1 1 4 68 0000000000 61~9~4 O0 000 OO 0 5 1 1 4 68 0000000000 ** DATA DEPT, 84!9.500 A .2'P!.'{. 0() I 8.069 PSPF~.001 7.603 ATE~,O01 PSE~,OO~ 100,826 ATVR.001 ~87,396 PSVa,001 ~q87.174 DEPT. 8400.000 l~TP.i.t. 0 0 1 2.620 PSPH.O01 2.445 ATEP.00!. PSER.00~ 2,467 ,t~TV~, 001 2.639 PSVR.O01. 2.459 DIE, pT. 820(.), (~00 ATPH.001 3.380 PSP~4. 001 3.210 ATEP,001 PSEP.O01 3.068 ATVR.O0! 3.06B PSVR.O01 ?.918 D~:PT. 8000.OOU ATPH.O01 3.978 PSP.H. 001 3.841 ATER.()01 PSEP.O0~ 4,003 ATVR.001 4.232 PSV~,O01 4.081. DEPT, 7850,500 ATPt{.O01 3.044 PSPF!,001 2.g33 PSEP,OOi 2.916 ,ATVR.001 3.035 PSVR.()O1 ~.917 173.54'1 2.644 322 4.152 ** END OF DAT~ ** ~I$ Ta~e Ve~ificatlon ;chlumberger ~lasKa Computino Center 26-FEB-1993 13:1,4 PAGE: 22 **** FILE TRAILER **** FILE MAttE : EDIT .005 SERVICE : FLIC V~.iRSlOM : 001A07 ~X ~C SlZ .... ~.024 **** TAPE TRAILER **** SERVICE MA~I~ : EDIT DATE : 93/02/26 T,~P~ ~4ANE : 93007 CONTINU~TIO~t ~ : PREVIOUS TAPE CO~EMT : ARCO AbASK,A, I~C,,KUPARUK RIVER UNIT,l~'{-~,7,50-029-~2314-0o **** REEl, TRAILER **** SF~VICE NA~E : EDIT D,~ T~7 : 93/0~/~6 ORIGIN : FLIC REEL NA.,~E : 93007 CONTINUATION ~ : PRE~!IOUS REEL : CO'~.MEMT : ARCO A,I,,~SKA, INC,,KUPARUK RIVEP l,iNI, T,l[t-17,50-O2q-22314-00