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185-169
STATE OF ALASKA ALP. OIL AND GAS CONSERVATION COM1IIIION REPORT OF SUNDRY WELL OPERATIONS Other Install Operations Performed: ' "'"n Abandon r Repair w ell r Rug Perforations r Perforate Alter Casing r- Rill Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n f Stimulate - Other r Re -enter Suspended Well j 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j;r` Exploratory r _ r 185 - 169 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25587 -• 2H -06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,. none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9024 feet Plugs (measured) None true vertical 6342 feet Junk (measured) None Effective Depth measured 8894 feet Packer (measured) 8259, 8277, 8313, 8543 true vertical 6258 feet r.. ,e vertical) 5841, 5853, 5877, 6032 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 111 111 SURFACE 3333 9.625 3368 2799 PRODUCTION 8948 7 8981 6315 SCANNED MAR 1 12013 R E NOV 2 8 2012. Perforation depth: Measured depth: 8454 -8490, 8590 -8596, 8612 - 8642', 8668 -8699 AOGCC True Vertical Depth: 5972 -5996, 6063 -6067, 6077 -6097, 6114 -6134 Tubing (size, grade, MD, and TVD) 2.875, J - 55, 8561 MD, 6043 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 8273 MD and 5851 TVD ) PACKER - WEATHERFORD ER PACKER @ 8299 MD and 5868 TVD PACKER - BROWN HB PACKER @ 8313 MD and 5877 TVD PACKER - BROWN 1B PACKER @ 8543 MD and 6032 TVD SSSV - BAKER FVL SSSV @ 1812 MD and 1728 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation 208 670 550 -- 208 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Developm ent "' Service r Stratigraphic E 16. Well Status after work: - Oil (J Gas r WDSPL r' Daily Report of Well Operations xxx GSTOR j- WINJ E 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: none Contact John Peirce tom. 265 -6471 Email John.W.Peircetu conocophillips.com Printed Name John Peirce Title Wells Engineer Signature , ,,, ` �'°. _ Phone: 265 Date 1 I /�' a Form 10/04 Revised 1 01 °S NOV 2 8 2012 Submit Original Only DATE SUMMARY 2H -06 Well Work Summary 7/23/12 (AC EVAL) TIFL (FAILED) IN IOW OF 2213' 7/29/12 `BRUSH AND FLUSH TBG Tdil6P OF TBG PATCH @ 8278' RKB, RAN EST TOOL, MIT -T TO 2500 PSI PASS, BLEED IA 500 PSI BLOW TBG PRESSURE, WILL RETURN IN A.M. TO DETERMINE IF FURTHER ACTION IS NEEDED. 9/5/12 BRUSH & FLUSH / GAUGE TBG TO 2.28" TO PATCH @ 8278' RKB. SET ER TEST TOOL © 8278' RKB. MIT TBG 2500 PSI, PASSED. PULLED TEST TOOL, UPPER ER PACKER & SPACER ASS'Y @ 8278' RKB. BOTTOM OF STINGER FLOW CUT. IN PROGRESS. 9/6/12 PULL LOWER ER PACKER @ 8300' RKB (MISSING ONE ANCHOR), RAN BRUSH AND 1.75" SAMPLE BAILER TO MERLA PATCH © 8396' RKB, ABLE TO GET 2' INTO PATCH, RAN 1.5" MAGNET w/ 1.70" X/O TO TAG @ 8664' SLM, SLIP NOT RECOVERED WITH MAGNET. IN PROGRESS. 9/7/12 RAN 2.12" MAGNET TO MERLA PATCH @ 8396' RKB; SLIP NOT RECOVERED. JOB SUSPENDED. 10/11/12 PERFORMED STATIC BOTTOM HOLE PRESSURE SURVEY AND 100' TVD PRESSURE SURVEY. STATIC BOTTOM HOLE PRESSURE AT 8645' IS 3238 PSI. STATIC PRESSURE AT 8494' (100' TVD) IS 3195 PSI. TAG FILL AT 8684' ELMD. SET WEATHERFORD ER PACKER MID - ELEMENT AT 8280'. CCL TO MID - ELEMENT OFFSET OF 15.7'. CCL STOP DEPTH OF 8264.3' 10/28/12 SET 2 7/8 ER TEST TOOL IN LOWER ER PACKER @ 8299' RKB. IN PROGRESS. 10/29/12 ATTEMPT TO CIRC OUT AND UNABLE TO GET ENOUGH RATE THRU LEAK. PULLED OV @ 8258' RKB; CIRC OUT TUBING TO IA; FAILED CMIT AGAINST TEST TOOL; FAILED CMIT W/ HOLEFINDER ( SUSPECT GAS BREAKING OUT ). LRS CIRCING OUT ADDITIONAL 70 BBLS. JOB IN PROGRESS 10/30/12 COMBO MITd, PASSED. ATTEMPTED SET OV @ 8258' RKB, LOST SPANGS, UNABLE TO WORK FREE. DROPPED 2 CUTTERBARS. WIRE NOT CUT, TOOLS KNOCKED LOOSE. RECOVERED ALL TOOLS, LOST OV. IN PROGRESS. 10/31/12 CONFIRMED OV @ 8258' RKB IN POCKET WIH LIB & PINNED RT. PULLED ER TEST TOOL @ 8280' RKB. IN PROGRESS. 11/1/12 SET 25' -10" UPPER PATCH AS S 'Y @ 8273' RKB. MIT TBG 2500 PSI, PASSED. CMIT 2500 PSI, PASSED. COMPLETE. 11/6/12 (RE- TIFL)(PASSED) ,' KUP 2H -06 Conoco Phillips o Well Attributes Max Angle & MD TO Alaska Inc, \ \ Wellbore API /UWI Field Name Well Status Inc' (°) MD (ftKB) Act Btm (ftKB) '5 501032004400 KUPARUK RIVER UNIT PROD 54.37 5,300.00 9,024.0 «afi c_rx„iups 3 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: LOCKED OUT I 40 1/17/2010 Last WO: 35.99 12/29/1985 Well CUnfi9: - 2H-06, 111820127: 59.19 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,664.0 9/6/2012 Rev Reason: SET PATCH ASSY, GLV C/O ninam 11/8/2012 s Casing Strings HANGER, 31 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 35.0 111.0 111.0 62.50 H - 40 WELDED ,� r ,.. Casing Deseript'on String 0... String !D Top (ft) Se Depth (.. Set Dept V String Wt... Sting . String Top Thrd SURFACE 95/8 8.g 21 ... 34.5 3,367.8 2,79 3600 Jr, 55 BTC �. Casing Description String 0... String ID ... Top (ttKB KB) Set t Depth (f. f ... Set Dept h h (TVD ) .. ... . Siring Wt... Sting .. .. . String Top Thrtl PRODUCTION 7 6.276 33.2 8,980.8 6,314.8 26.00 J 55 BTC Tubing Strings _ Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I TUBING 27/8 2.441 31.5 8,561.5 6,043.8 6.50 J-55 EUE -8rd Completion Details Top Depth CONDUCTOR, _ (TVD) Top Inc! Nomt... 35111 Top (ftKB) (ftKB) ( °) Item Description Comment 10 ('n) 31.5 31.5 0.25 HANGER FMC TUBING HANGER 2.875 SAFETY VLV, 1,811.9 1,727.6 35.48 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 8/5/97) 2.313 1.812 agg 8,301.5 5,868.5 46.74 PBR BROWN PBR 2.500 GAS LIFT, 8,313.1 5,876.6 46.83 PACKER BROWN HB PACKER 3.500 2'511 8,457.3 5,974.5 48.01 BLAST RINGS RICKERT BLAST RINGS (2) 2.441 8,541.3 6,030.5 48.52 SEAL ASSY BROWN LOCATOR SEAL ASSEMBLY 2.440 8,542.8 6,031.5 48.53 PACKER BROWN 1B PACKER 3.250 8,555.1 6,039.5 48.60 NIPPLE CAMCO D NIPPLE 2.250 SURFACE, 35 - 3,36 8 8,560.6 6,043.2 48.63 SOS BOT SHEAR OUT, TTL ELMD @ 8542' PERF 10/5/1992 2.438 GAS LIFT, Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 4,951 lir Top Depth 1 (TVD) Top Inc! GAS LIFT, Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 6,521 - 8,259 5,840.8 47.88 PACKER WEATHERFORD ER PACKER 10/11/2012 1.460 8,261 5,842.5 47.88 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 11/1/2012 1.300 GAS LIFT, 7,387 8,277 5,853.4 47.83 PACKER WEATHERFORD ER PACKER 11/1/2012 1.500 8,396 5,933.3 47.47 PATCH 21.6' MERLA/OTIS TUBING PATCH 12/14/1992 1.875 GAS LIFT, ' ,- 8,555 6,039.6 48.60 REDUCER AVA 2.25 X 1.81 12/10/1992 1.812 7,716 at GAS LIFT, Perforations & Slots 8,065 Shot a Top (TVD) Btm (TVD) Dens Top MKS) Btm (ftKB) (ftKB) (ftKB) Zone Date (ch..• Type Comment _ 8,454 8,490 5,972.3 5,996.4 C-4, 2H -06 2/8/1986 12.0 IPERF 5" Csg Guns; 120 deg. Ph PACKER, 8.259 8,590 8,596 6,062.7 6,066.6 A -5, 2H -06 10/5/1992 4.0 APERF 2 1/8" Dynacap; 180 deg. Ph GAS LIFT, 7. 8,612 8,642 6,077.2 6,096.8 A-4, 2H -06 10/5/1992 4.0 APERF 2 1/8" Dynacap; 180 deg. Ph PATCH, 8,281 l 8,668 8,699 6,113.7 6,133.8 A -3, 2H -06 2/8/1986 4.0 IPERF 4" Csg Guns; 90 deg. Ph PACKER, 8 Clement Squeezes `: . Top Depth Btm Depth (TVD) (TVD) fa Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment PBR, 8,301 8,454.0 8,490.0 5,972.3 5,996.4 Cement Squeeze 9 /23/2000 PACKER, 8,313 Notes: General & Safety -- End Date Annotation ?. 9/13/1998 NOTE: Use 3' weight, 1.5" bar between knuckle joints. PRODUCTION, 8,351 ION, 9/13/1998 NOTE: Possible corkscrewed TBG @ 7900' - 8360' WLM. 10/26/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PATCH, 6,396 9/6/2012 NOTE: SLIP FROM ER PACKER IN HOLE, 2.5" x 0.7" PRODUCTION, 8,420 III IPERF, 8,454 -8,490 1 soz, 8,454 MB IR PRODUCTION, II 8,525 11 ' SEAL ASSY, r• 8,,547 1 NIPPLE, 8,555 REDUCER. 8,555 505, 6,561 Mandrel Detail$ Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run APERF, Stn Top (ftKB) (MB) ( °) Make Model (in) Sery Type Type ('n) (psi) Run Date Com... 8,590 - 8,596 1 2,511.3 2,239.6 49.36 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,306.0 7/20/2007 2 4,950.6 3,764.7 53.86 ' CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,304.0 7/20/2007 3 6,521.4 4,709.7 52.10 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,330.0 7/20/2007 APERF, 8,612 al IN 4 7,367.2 5,250.6 49.45 CAMCO KBMG 1 GAS LIFT DMY BK '0.000 0.0 2/9/1986 5 7,715.6 5,478.8 48.92 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,321.0 7/19/2007 8668-8,699 M IN 6 8,064.8 5,711.5 48.43 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/19/2007 7 8,258.1 5,840.6 47.88 MMH FMHO 1 1/2 GAS LIFT OV RK 0.250 0.0 10/30/2012 8 8,351.1 5,902.8 47.12 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 9/17/2000 9 8,419.9 5,949.2 47.79 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 10/15/1992 PRODUCTION, 33 -8,961 -\ + 10 8,524.6 6,019.4 48.42 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 1/26/1992 TD. 9.024 STATE OF ALASKA . ALQ OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r., Reset tubing patch After Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J Exploratory r _ - 185 -169 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50- 103- 20044 -00 — 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25587 e — 2H - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9024 feet Plugs (measured) None true vertical 6342 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8259, 8261, 8277, 8313 true vertical 0 feet (true vertical) 5841, 5842, 5853, 5877 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 111 111 SURFACE 3333 9 5/8 3368 2799 PRODUCTION 8948 7 8981 6315 •P' NOV 13 2012 Perforation depth: Measured depth: 8454 -8490, 8590 -8596, 8612 -8642, 8668 -8699 A(°�,��ii (� GC True Vertical Depth: 5972 -5996, 6063 -6067, 6077 -6097, 6114 -6134 VV Tubing (size, grade, MD, and TVD) 2.875, J - 55, 8561 MD, 6043 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 8259 MD and 5841 TVD PATCH - SPACER PIPE, SNAP LATCH SEAL ASSEMBLY @ 8261 MD and 5842 TVD PACKER - WEATHERFORD ER PACKER @ 8277 MD and 5853 TVD PACKER - BROWN HB PACKER @ 8313 MD and 5877 TVD SSSV - Baker FVL 1728 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 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 N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r « Service r Stratigraphic r 16. Well Status after work: � Oil 17 Gas r WDSPL r Daily Report of Well Operations x GSTOR WIND 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: N/A Contact Kelly Lyons / Brent Ro• Email n16170,conocophillips.com Printed Name Kell ons Title Problem Wells Supervisor Signature ' / Phone: 659 -7224 Date Form 10 -404 Revise. 10/ 'I-2 �r 2 C1� ! f } LF ,(1 / Submit Original Only • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 November 9, 2012 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2H -06 (PTD 185 -169) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659 -7224 if you have any questions. Sincerely, 1 1. Kelly L , ons ConocoPhillips Problem Wells Supervisor Enclosures 2H -06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/23/12 (AC EVAL) TIFL (Failed), Initial T /I /O= 280/1260/600. Shot initial IA FL © 4450', (between Sta #1 GLV and Sta #2 4950 GLV). Shut in well and LG, stacked out tubing with LG T /I /O= 1300/1230/580 Bleed IA down T /I /O= 1120/430/550, shoot 2nd IA FL @ 2577' (Inflow of 1873'). 1 hour monitor, T /I /O= 1200/560/550. IA FL © 2237' (Inflow of another 340', total inflow of 2213'). Final T /I /O= 1200/560/550. 09/05/12 BRUSH & FLUSH / GAUGE TBG TO 2.28" TO PATCH @ 8278' RKB. SET ER TEST TOOL © 8278' RKB. _MIT TBG 2500 PSI,, PASSED. PULLED TEST TOOL, UPPER ER PACKER & SPACER ASS'Y @ 8278' RKB. BOTTOM OF STINGER FLOW CUT. IN PROGRESS. 09/06/12 PULLED LOWER ER PKR @ 8300' RKB (MISSING ONE ANCHOR). RAN BRUSH AND 1.75" SAMPLE BAILER TO MERLA PATCH © 8396' RKB, ABLE TO GET 2' INTO PATCH. RAN 1.5" MAGNET w/ 1.70 X/O TO TAG © 8664' SLM; SLIP NOT RECOVERED WITH MAGNET. IN PROGRESS. 10/11/12 PERFORMED STATIC BOTTOM HOLE PRESSURE SURVEY AND 100' TVD PRESSURE SURVEY. STATIC BOTTOM HOLE PRESSURE AT 8645' IS 3238 PSI. STATIC PRESSURE AT 8494' (100' TVD) IS 3195 PSI. TAG FILL AT 8684' ELMD. SET WEATHERFORD ER _PACKER MID - ELEMENT AT 8280 '. CCL TO MID - ELEMENT OFFSET OF 15.7'. CCL STOP DEPTH OF 8264.3' 11/01/12 SET 25' -10" UPPER PATCH ASS'Y @ 8273' RKB. MIT TBG 2500 PSI, PASSED. CMIT 2500 PSI, PASSED. COMPLETE. **MITT pass: preTIO= 1075/550/670, initialTIO= 2560/575/670, 1 niin =2490/575/670, 30min= 2480/575/670. CMIT pass: preTIO= 1160/560/670, initialT10= 2695/2560/700, 15min= 2590/2440/690, 30min= 2540/2400/690 * ** 11/06/12 Initial T /I /O= 250/1250/760. Re- TIFL(passed). Shut in WH and shot IA FL @ 5845'(658' above station #3). Stacked out T w/ lift gas. T /I /O= 1250/1175/700. Bled IA for 60 min. T /I /O= 1375/475/680. Shot IA FL © 6845'(658' above station #3). 60 min reading T /I /0= 1375/475/680. IA FL @ 5845'(658' above station #3). Final T /I /O= 1375/475/680. Summary Pulled existing tubing patch and replaced with new WeatherfQrcl retrievable gatcn. TILL ,passed to confirm integrity ~ .~+i STATE OF ALASKA ` ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~~S~~ ~~~ ~ ~~' (~, /zr~cf~E~,... 1. operations Pertormed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ®eveiopment^ Exploratory ^ 185-169 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20044-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 129' 2H-06 8. Property Designation: 10. Field/Pool(s): ADL 25587 ALK 2673 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: ,gyp f~~,;,~ ~. (7 ~ ~ ~ X3, ~G~ G~ G~'' 1 ~~G . T t l D th ~ /, ~~~ '~ ''`~~ o a ep measured feet I ~ true vertical 6342' Z ~ ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 111' 16" 111' 111' SUR. CASING 3239' 9-5/8" 3368' 2799' PROD. CASING 8852' 7" 8981' 6315' Perforation depth: Measured depth: 8454-8490, 8590-8596, 8612-8642, 8668-86 ~ JA~ ~ ~ Z~d~ true vertical depth: 5972-5996, 6063-6067, 6077-6097, 6114-6134 Tubing (size, grade, and measured depth) 2-7/g", J-55, 8566' MD. Packers &SSSV (type & measured depth) pkr= BROWN 'HB' ; BROWN '1-B' pkr= 8294' ; 8524' SSSV= Baker'FVL' SSSV= 1793' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone 659-7224 Date 12/27/2007 ~ ~y~`.:~Ng ~ . ~ x ?DOD E Form 10-404 Revised 04/2004 ~~,.'~ Submit Original Only r~ ~ ~ 2H-06 ' DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11 /26/07 12/03/07 12/14/07 12/26/07 BRUSH & FLUSH TUBING FROM 8200' SLM TO 8320' SLM. DRIFT W/ 2.3" TO 8350' SLM W/ NO PROBLEMS. SET LOWER WEATHERFOR ER PATCH PACKER -CENTER OF ELEMENT AT 8281' IN CENTER OF 4' PUP FROM 8279'-8283'. TAGGED ER PKR WITH 2.25" LIB @ 8259' WLM. SET WEATHERFORD ER PKR & SPACER ASS'Y @ 8281' ELM (21.34' TOTAL LENGTH). TESTED PATCH TO 2500 PSI, GOOD. COMPLETE. TIFL -passed ,Initial T/I/0= 290/1260/450. Shut in the WH and GL upon arrival. Shot the initial IA FL @ 7697' sta. # 5 GLV. Stacked out the TBG with LG. Bled down the IA and shot the 2nd IA FL @ the same location. Final T/I/0= 1200/600/420 Summary Set 22' Weatherford retrieveable patch from 8259' - 8281' followed by a passing TIFL. • • ConocoPhillips Alaska, tnc. KRU 2H-06 ~ 2H-06 API: 501032004400 Well T e: PROD An l TS 48 d 8 455 SSSV Type: Locked Out yp Orig Com letion: 12/29/1985 k e : Angle @ TD: e _ 50 deg @ 9024 Annular Fluid: Last W/O: / Rev Reason: SET PACKER & PATCH Reference Lo Ref Lo Date: ~ p • Last U date: 12/20/2007 Last Ta : 8702 TD: 4 ftK6 Last Ta Date: 7/20/2007 Max Hole An le ~ 54 de 5300 _ Casin Strin -ALL STRINGS Description _ _ Size To _ Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 111 _ 111 62.50 H-40 SUR. CASING 9.625 0 3368 2799 36.00 J-55 PROD. CASING 7.000 0 8981 6315 26.00 J-55 Tubin Strin -TUBING Size To _ __ Bottom TVD Wt Grade Thread 2.875 0 8566 6047 6.50 J-55 EUE 8RD Pertorations Summa Interval TVD Zone Status Ft SPF Date T e Comment 8454 - 8490 5972 - 5996 C-4 C 36 0 9/23/2000 S z 8590 - 8596 6063 - 6067 A-5 6 4 10/5/1992 APERF 2 1/8" Dynacap; 180 deg. Ph 8612 - 8642 _ 6077 - 6097 A-4 30 4 10/5/1992 APERF 2 118" Dynacap; 180 deg. Ph 8668 - 8699 6114 - 6134 A-3 31 4 2/8/1986 IPERF 4" Cs Guns; 90 de . Ph Stimulations & Treatments Interval Date 8454 - 8490 9/23/2000 T e SOZ Comment S zd off C Sand throw h leakin mandrel. Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type _ V Mfr V Type V OD latch Port TRO Date Run Vlv Cmnt - 1 2492 2227 Camco KBUG GLV 1.0 BK 0.156 13 06 7/20/2007 2 4932 3754 Camco KBUG GLV 1.0 BK 0.156 _ 1304 7/20/2007 3 6503 4698 Camco KBUG GLV 1.0 BK 0.188 1330 7/20/2007 4 7348 5238 Camco KBUG DMY 1.0 BK 0.000 0 2/9/1986 5 7697 5466 Camco KBUG GLV 1.0 BK 0.188 1321 7/19/2007 ~ 6 8046 5699 Camco _ KBUG DMY 1.0 BK 0.000 0 7/19/2007 ~ 7 8239 5828 MMH FMHO OV 1.5 RK 0.250 0 8/2/2007 Pro duction Ma ndrelsNa lves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 8 8332 5890 Camco KBMG DMY 1.0 BK 0.000 0 9/17/2000 Closed 9 8421 5950 Camco KBMG 'Patched' PackOff DMY 1.0 BK 0.000 0 10/15/199 Closed 10 8506 _ 6007 Camco KBMG DMY 1.0 BK 0.000 0 11/26/199 Closed Other elu s e ui ., etc .) -COMPLETION De th TVD T e Descrf lion ID 1793 1713 SSSV Baker'FVL' Lock Out 8/5/97 2.313 8258 5840 PACKER UPPER WEATHERFORD ER PACKER set de th 8261' 1.460 8261 5842 PATCH LENGTH BETWEEN PACKER ELEMENTS = 20.52" 1.630 8278 5854 PACKER WETHERFORD ER PACKER SET DEPTH 8281' ON 12/3/2007 ID = 1.465, SNAP LATCH STINGER ID = 1.31" 1.310 8283 5857 PBR Brown 2.500 8294 5865 PKR Brown'HB' 3.000 8396 5933 PATCH 21.6' Merla/Otis Tb Patch set 12/15/92. 1.875 8524 6019 PKR Brown '1-B' 3.250 _ - 8536 6027 NIP , Camco 'D' Ni le NO GO 2.250 -_ 8537 6028 NIPPLE REDUCER AVA 2.25 X 1.81 1.813 8542 6031 SOS Brown 2.438 8543 6032 TTL 2.438 General Notes Date _ Note 8/1/1997 NOTE: PER E-LINE LOGS JEWELRY DEPTHS HAVE BEEN ADJUSTED ON SCHEMATIC 9/13/1998 NOTE: Use 3' wei ht, 1.5" bar between knuckle "oints. 9/13/1998 NOTE: Possible corkscrewed TBG C~ 7900' - 8360' WLM. Perf (8672642) • • Memory MultfFinger Galiper• S Log Results summary Company: ConocoPhillips Alaska, Inc. Well: 2H-06 Log Date: September 21, 2007 Field: Kuparuk Log No.: 8832 State: Alaska Run No.: 1 API No.: 50-103-2004400 Pipet Desc.: 2.875" 6.51b. J-55 Top Log Intvll.: Surface Pipet Use; Tubing Bot. Log Intyl1.: 8,377 Ft. (MD) Inspection Type : Con~asive 8 Mechanical Damage -nspection Ct?MMENTS This tog is tied into the GLM 8 ~ 8,332' (Driller's depth). This log was run to assess the condition of the 2.875" tubing with respect to corcosive and mechanical damage. The caliper recordings indicate that the 2.875" tubing interval logged is in good condition with respect to corrosive damage, EXCEPT that a hole is recorded in joint 262 CCU 8,278. No areas of significant cross-sectional metal loss or I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: HOLE (100%) Jt 262 i~ No significant wall penetrations (> 14°~}are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 11°~) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D restrictions are recorded. ~~~ NQV ~. 3 20Q7 8,27$ Ft. (MD) ~~~ ~: QCT ~ 2 2007 ,~ Oif ~ ~~ Cons, t;arr,mission Anchorage Field Engineer: K. Miller Analyst: B. Qi Witness: C. fitzpatric ProActive Diagnostic Services, ?nc. / P,(]. Box 1369, Stafford, TX 77497 Phone: {281) or (888) 565-9085 Fax: {281) 565-1369 E-mail: PDSi~'memoryiog.com Prudh©e Say Field gffice Phone: (907) b59-2307 Fax: (907) 659-2314 ~`65~_ ~~0~ ~ IS~i'6`r/ ^ Pipe 1 • Correlation of Recorded Damag 2.875 in (8.5' - 8368.9') Web: Field: Company: Country: Survey Date: ;e to Borehole Profile 2H-06 Kupa ruk ConocoPhillips Alaska, Inc. USA September 21, 2007 ^ A pprox. Tool D eviation ^ A pprox. Borehd e Profil e 13 788 1568 GLM 1 2366 3155 3932 ~ _c s n. 4714 ~ GLM 2 5500 6286 GLM 3 7069 GLM 4 GLM 5 7859 GLM 6 GLM 7 GLM 8 265 8369 0 50 1 00 Dam age Pr ofile (% wall) / Tod D eviatio n (degr ees) Bottom of Survey = 265 1 25 .i0 75 100 a ~ 125 'P Z '0 150 175 200 225 2 50 • • PDS Report Overview ~~ ~. Body Region Analysis Well: 2H-06 Survey Date: September 21, 2007 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal t: 6. i Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f -55 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body Apr- metal loss body 250 200 150 100 50 ~ 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of ~oints anal se d total = 270 pene loss . 0 249 20 93 175 2 0 0 1 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion conosion corrosion iWe hole Number of'oints dama ed total = 1 0 0 0 0 1 Damage Pro61e (% wall) ~ penetration body metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 (:IMF GLM 8 ~ Bottom of Survey = 265 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 WeY: 2H-06 Body Wall: 0.217 in Feld: Kuparuk Upset Waq: 0.217 in Company: ConocoPhillips Alaska,lnc. Nominal I.D.: 2.441 in Country: USA Survey Date: SepO~mber 21, 2007 Joint No. Jt. Depth (Ft.) Pen. U!x<~I Ilns.) Pen. Body (Ins.) Pen. % Metal I ins °~~ Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 9 ti 0.01 3 2.44 PUP 1 13 U t3 ~i 2.42 1. 44 t~ 0.01 11 2.42 PUP - 1.2 59 t) 0.02 11 11 2.42 PUP 2 69 a 0.0 13 £t 2.41 3 100 a Q.0 ~) ~> 2.41 4 131 u 0 t3 ~~ 5 16 t ~ 0.02 £f ~~ 2.41 6 193 t) 00 £~ t3 2. 7 2 U 0.02 £3 t3 .41 8 56 t~ 0.02 8 t> 2.41 9 87 O 0.0 1l1 ~~ 2.41 10 31 U 0.01 6 ~ 2. 1 11 349 t~ 0.0 8 ~ 2. 1 380 U 001 V G .41 13 412 t ~ 0. 1 6 t, 2.41 14 443 t ~ 0.01 4 ~ 2. 15 75 t~ .0 6 is 2.40 1 506 l) 0. 1 7 2.41 1 537 i) 0. 1 4 is .41 18 568 0 0.0 ~~ t t 2.42 1 6 U 0.02 £i 7 .41 0 31 U 0.02 ri 2.42 21 663 U 0.01 6 Z 2.41 t) 0 7 23 725 t~ 0.01 6 t~ 2.40 4 757 U 0.02 I1 2.41 25 788 O 0.01 6 ~' 2.41 819 U OA ~) t~ .41 27 851 U 0.01 ~ 2.41 28 882 0 0.01 0 2.41 29 913 ti 0.02 ft ~ 2.41 30 945 t~ 0.01 6 ~i 2.41 31 976 It 0.01 4 2.41 32 1008 t 1 0.0 9 ~' 2.41 33 1039 tJ 0.01 v 3 2.41 4 1070 0 0.01 ~ 2 2.41 35 1101 t~ 0.01 t, 2 2.41 36 113 t 1 0.02 t3 ~ 2.41 37 1163 i? 0.01 i 2.41 38 1194 U 0.01 U 39 1225 t1 0.01 4 ~' 2.42 1 56 t~ .01 ~ 3 .41 41 1288 a 0.01 7 2 2.41 1 18 t1 0.0 `~ ' .41 43 1349 0 0.01 6 1 2.40 44 13 1 c 1 0.01 6 1 2.42 45 1412 a 0.03 12 2 2.41 46 144 t } .01 7 2.41 47 1474 ~'~ 0.03 1-l 2.41 Penetration Body Memel Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf )-55 WeN: 2Fi-06 Body Wall: 0.217 in Field: Kuparuk Upset WaN: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 21, 2007 Joint No. )t. Depth (Ft.) Pen. Up<~i (In1.) Pen. Body (Ins.) Pen. % titc•t,~l Ic~ss °'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1505 a 0.0 ~~ 2.41 49 1537 ~~ 0.0 9 2.41 50 1568 ~ ~ 0.01 7 ~ 2.41 51 159 t . 0. 7 2.41 5 16 0 U 0 01 7 2.40 53 1661 ~ ~ 0.01 (i Z 2.41 4 1692 ~ ~ 0.01 4 ~ .41 55 17 4 U 0.01 7 _' 2.41 56 1755 U 0.0 1l1 ? 2.41 56.1 17 6 t i .01 7 I .43 PUP 5 .2 1790 !' 0 U l1 2 31 S V 57 1802 ~ ~ 0. 1 1 2 41 58 1833 ~ ~ 0.02 ~) _' 2.41 59 1864 ~ i 0.01 4 Z 2.4 60 189 ~ ~ 0.02 ~~ .42 61 1927 a 00 1U Z 2.40 62 1958 0 0.0 ~ 2.41 3 1990 U .0 7 2.41 64 021 c ~ 0.01 U 2 41 5 2053 a 0.01 7 Z .41 66 2084 a 0.01 7 1 .41 67 2115 a 0.0 (~ ? 2.41 6 2147 t) 0.01 4 s 2.41 69 2178 a 0.01 6 ? .41 ~ ~ 0 6 ' 4 71 2241 t) 0.01 7 3 2.42 2 27 U 0.0 ~ .4 73 2303 t) 0.01 U ~' 2.42 74 2335 U 0. 2 8 5 2.41 75 23 6 U 0.02 8 _' 2.41 7 398 1) 0.01 7 _' 2.41 77 2428 a 0.01 6 2.40 78 2459 U 0.02 ti _' .41 78.1 2490 U 0 U U N A GLM 1 Latch ~ 10:30 7 2497 a 0.01 ~ 2 2.40 80 2529 t~ 0.01 7 1 2.39 81 560 U 0.0 1 U 3 82 2591 U 0.02 ti ? 2.41 83 623 a 0.02 9 1 2.41 84 2654 U 0.02 `) s 2.41 85 2686 U 0.0 ti 3 .41 86 2717 U 0.02 9 ? 2.41 7 749 l) 0.01 ~ ~ 1 88 2 780 t) 0.01 U ? 2.41 9 811 U 0.0 8 ~ .41 90 2842 t) 0.01 4 t 2.40 Lt. De sits. 91 2874 (~ 0.01 7 _' .39 92 2905 ~~ 0.01 6 3 2.39 93 9 7 ~? 0.01 6 ~ 2.4 94 2968 ~ ~ 0.01 - _' 2.40 Penetration Body _ Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 Body Wall: 0.217 in Upset Watl: 0.217 in Nominal I.D.: 2.441 in Wefl: ZH-06 field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: SepfQmber 21, 2007 Joint No. Jt. Depth (Ft.) N~•n. UI~sPt (Ins.) Pen. Body (Ins.) Pen_ °4, ~~tet.il loss °'<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 2999 t 1 0.0 9 2.41 96 3030 U 0.01 6 3 2.39 97 306 t) 0.0 9 ' 2.40 9 3092 t i 0.02 8 ~ 2.39 99 3124 t) 0.01 i ' 2.41 1 3155 t) 0.02 lt) ' .39 101 3186 ~? 0.01 6 1 2.40 102 3217 t t 0.02 t3 2.40 103 3248 t) 0.01 ~ 2.41 1 4 3279 U 0.02 £3 1 2.41 5 3310 a 0.02 t3 1 2.4 10 341 U 0 3 12 2 2.39 10 3 72 U 0.0 ti 1 2.41 108 3403 t) 0.02 t U 2 2.3 109 3434 t) 0.03 I -1 _' 2.41 110 3465 l) 0.0 ~ ' .39 111 3496 a 0.02 I t) _ 2.40 11 35 7 ~) 1 ~ ' .3 113 3558 ~ ~ 0.02 ~~ 2 2. 114 3589 ~ ~ 0.02 I 1 Z 2.41 115 36 0 t) 0.01 6 ,' 2.42 116 3652 t) 0.01 6 2.40 11 368 t) 0.01 U ~ 2.41 118 3713 t) 0.02 1O ? 2.41 11 745 t t 0.01 (~ ~> .40 120 3776 t) 0.02 3 I 2.41 12 3808 t) 0.01 ~ 3 2.40 122 3838 U 0.02 1 U G 2.40 123 3870 i1 0 O1 -l 1 2.41 124 3901 l) 0.02 1 U ? 2.41 12 3932 11 0.02 1 U 2 .4 126 3963 U 0.02 1l1 G 2.41 127 3994 U 0.02 ~) 1 2.42 128 4025 U 0.01 i, 2.41 129 4057 t1 0.0 ti 4 2.38 130 4089 a 0.02 ri _' 2.41 31 411 t) 0. 1 1 2.40 132 4151 tl 0.02 ') I 2.41 133 4183 t) .02 '~ _' 2.43 134 4214 a 0.03 12 3 2.40 13 4245 t 1 0.02 8 ? .41 136 4277 t) 0.01 6 1 2.40 137 4309 ~) 0. 1 V ' .41 138 4340 t) 0.01 7 ' 2.41 139 4371 U 0.01 4 ? .40 140 4403 t) 0.01 6 2.41 141 4433 t1 0.01 4 I 2.41 142 4464 U.t)6 0.03 13 1 2.40 143 4496 U 0.03 1 z .39 144 4527 U 0.02 t 2.41 Lt. De sits. Penetration Body Metal Loss Body Page 3 Pipe: Body Wall: Upset Wad: Nominal I.D.: • • PDS REPORT JOINT TABULATION SHEET 2.875 in 6.5 ppf }55 Well: 2Fi-06 0.217 in Field: Kuparuk 0.217 in Company: ConocoPhillips Alaska,lnc. 2.441 in Country: USA Survey Date: September 21, 2007 Joint No. Jt. Depth (Ft.) I'r~n. (lls~•t (hrs.) Pen. Body (Ins.) I'en. %> tite•t,rl Loss °'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4558 (r 0.02 l U 2.41 146 4589 U .03 12 Z 2.39 147 4619 tt 0.0 ~? .39 148 465 I ? 0.01 I 2.40 149 4682 ~ ~ 0.01 7 ~ 2. 150 4714 a 0.01 6 1 2. 1 151 4745 U 01 6 1 2.40 152 4776 (? 0.02 8 4 2.41 1 3 4808 i? 0.0 11 1 2.41 154 48 9 ~ ~ 0.01 7 > 2.41 155 9 ~ I 0.0 tf 2.41 156 4900 I I 0 ~~ I 2.41 156.1 4930 I~ 0 U U N A G 2 Latc ®. 0 1 7 4938 ±~ 0.02 1O ~~ 2.41 1 8 4970 I~ .01 4 I 2.4 159 5001 ~ ? 0.02 `3 2.39 160 5033 ~) 0.0 -1 .38 161 5063 U 0.02 ~~ 1 2.40 16 5094 U 0.0 1O ~ .41 163 5126 t) 0 01 (~ I 2 164 5157 i ~ 0.01 ~ 1 .42 165 5188 ~ ~.U I 0.01 7 2 .41 166 219 l1 0.01 (i 1 .42 167 5250 0 0.01 7 1 2.41 168 5281 t) .0 ~> 9 169 5313 t LU 1 0.02 `~ 1 2.41 170 534 ~ ~ 0.0 ti I 40 171 5374 ~ I 0.02 t3 1 2.40 172 5406 c I 0.01 7 ~' 2.41 173 5437 a 0.01 6 1 2.40 174 5468 O 0.02 9 I 2.41 175 5500 U 0.01 (i ? 2.40 176 5531 t ~ 0.01 (~ I 2.41 177 5563 U 0.01 b 1 2.41 178 5594 ~ ~ 0. 2 9 I .41 179 5626 ~> 0.01 7 2.42 180 6 7 O 0.01 7 1 2.4 181 5689 U 0.01 (> I 2.41 182 57 1 t1 0.0 t3 t 2.41 183 5751 ~~ 0.02 ti I 2.40 84 5783 ~ ~ 0.01 (~ I .40 185 5814 ~ ~ 0.01 6 1 2.41 186 5845 ~ ~ 0.02 ti 1 .4 187 5877 ~1 0.01 ~ I 2.40 188 5909 U 0.01 (> I .41 189 5941 ~ I 0.01 (, _' 2.40 190 5972 t I 0.01 7 I 2.41 191 6003 ~ ~ 0.02 i3 I 2.41 192 6034 0.01 ~ ~ I .40 193 6066 0.02 ~ I 2.41 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf J-55 Well: 2H-06 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 21, 2007 Joint No. Jt. Depth (Ft.) I't~n. tll>sc~t (Ins.) Pen. Body (Ins.) Pcn. %> Mc~ti~l Ic~ss `io Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 194 6098 l) .O1 7 ~ 2.41 195 1 9 U 0.0 8 Z 2.41 1 6 160 t) 0.01 6 1 2.42 197 6191 U 0.02 ') I .41 198 6223 U 0.01 i> 1 2.39 19 6255 U 0.02 ~) I 2.40 200 6286 U 0. 2 I1 _' 2.39 201 6317 U 0.02 I t) 2.40 20 6348 U 0.03 1 Z _' 2.40 203 6379 U .Ol 7 I 2.39 04 6410 t) .0 10 9 205 644 U 0.02 F3 I 2.39 206 6473 a 0.02 t3 1 2 41 206.1 6503 l! 0 U t) N A GLM 3 Latc ~ 11:00 2 6510 t) 0.02 IU I 2.4 2 8 6541 U 0.02 11 Z 2.39 09 6573 t) 0.02 ~> I 2. 210 6604 t) .02 I U .41 11 6635 U 0 01 7 I 2.39 212 6666 U 0.01 7 I 40 213 66 U 0.01 (i _' 2.39 214 6727 U .0 (i I .40 215 6759 U 0 01 7 ? 2.41 216 6789 a 0.01 6 I 2.40 217 68 2 t) 0.02 ~> I .41 218 6851 U 0.02 II 1 2.40 219 6 t) 0.01 (> .41 220 6914 O 0.02 1 t! I 2.38 221 69 7 U 0. 1 6 ,' 2.41 222 6976 n 0.01 4 2.40 223 7007 t! 0.01 G 1 .41 224 7038 t! 0.01 (~ I 2.40 225 7069 U 0.01 _' 2.40 226 7100 a 0.01 6 ~ 2.40 27 7131 U 0.01 -1 2.40 228 7163 ~! 0.02 ti 2.41 2 194 l t 0.0 ~ 1 2.41 30 7225 t) 0.01 7 I 2.41 231 7 55 i! 0.01 U 1 240 232 7286 t) 0.02 11 U 2.41 233 7317 t) 0.01 6 1 2 38 233.1 7348 t! 0 U O N A CLM 4 Latch ®6fl0 34 7356 ~ ! 0.01 7 1 2.40 235 7387 t! 0.01 b _' 2.40 6 7418 U 001 b ~' 2.41 237 7448 a 0.02 1O I 2.38 238 7480 t) 0.02 ti I 2.41 239 7510 n 0.02 10 1 2.39 2 7541 ~ ! 0.01 2. ~~~~~~--~ 241 7573 0.02 2.41 ' ~ ' ~ _. _ , . __ Penetration Body Metal Loss Body Page 5 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 Well: 2Fi-06 Body Wall: 0.217 in Field: Kuparuk Upset WaN: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 21, 2007 Joint No. Jt. Depth (Ft.) I'e~n. Uls~~; (lii.! Pen. Body (Ins.) f'c°n. °4 ~t,1,~1 In~< ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 42 7604 ~ ~ 0.01 7 2.40 4 7636 t) 0.02 is 2.41 244 7665 U 0.01 =1 I 2.41 244.1 7696 (? 0 U ;1 N A GLM 5 Latch ~ 4:00 245 7704 U 0.01 G 1 2.41 2 7735 a 0.02 ~~ 1 2.42 247 7767 ~) 0.02 t3 3 2.40 248 7796 U 0.01 (> > 2.40 249 7828 U 0.01 ~ I 2.40 250 7859 U 0.02 ti I 2.41 251 7891 t~ 0.02 ~~ 1 .41 252 7922 t) 0.01 _' 2.40 253 7952 ~) 0.01 ~~ I 2.39 254 7985 a 0.02 t; ~ ~ 2.41 255 8014 U 0. 1 - 2.41 255.1 8045 ;) 0 U ~) N A GLM 6 atch ~ 5:30 256 8053 i~ 0. 2 ~~ 1 2.42 257 80 3 ~ ~ 0.01 ~ I 2.40 258 8115 a 0.01 a ~ 2.4 259 8147 a 0.01 a 2.39 260 8178 a 0.02 ti I 2.41 261 8208 ~) 0.02 ~~ 2.41 261.1 8240 u 0 U ~i N A GLM 7 atch 4:30 262 8246 ~) 0.22 1 UO ,~ 2.41 HOLE 262.1 8279 a .O1 6 ~! .41 UP 262.2 8282 U 0 U ~ ~ 2.50 PBR 262.3 8291 U 0 U ~ ~ 3.00 Packer 263 8301 U 0.01 U Z 2.41 263.1 8332 ;~ 0 l) U N A L 8 Latch ~ 3:30 264 8337 i ~ 0.01 I 2.39 265 8369 c) 0.01 ~~ _' 2.39 _ Penetration Body Metal Loss Body Page 6 PDS Report Cross Sections ~~u -'~ ,. Weil: 2HA6 Survey Date: September 21, 2007 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Site: 1.69 Country: USA No. of Fingers: 24 Tubing: 2.875 ins 6.5 ppf 1-55 Analyst: B. Qi Cross Section for Joint 262 at depth 8277.764 ft Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 91 % Tool deviation = 46 ° Finger 5 Penetration = 0.274 ins HOLE .22 ins = 100°~6 Wall Penetration HIGH SIDE = UP • Cross Sections page 1 w i °"'W°~ KRU 2H-06 PHILLIPS Alaska, Inc. Scblumbel'U81' (JJJ 08/22/07 NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 2, '7 ZOO7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 cornrnission &. ~ 1 1\)\)1 ,.~\~~t> j\Ub SCf"i ' Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R-27 11850425 FPIT ¡q / -/();). 08/18/07 1 31-08 11839638 LDL J-1r(" -rWÀ 07/28/07 1 2M-19 11813070 INJECTION PROFILE I JT{\ IC\ I-~-::l 07/29/07 1 3G-26 11813071 LDL Jo,q_^~:.( 07/30/07 1 1R-18 11837482 SBHP/DDL ¡O¡,..: ^ <fs-':f 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U~ - /'S!-3---ce\ó 07/31/07 1 2C-08 11813073 INJECTION PROFILE' OT{\ J1r.7. -(~,"", 08/01/07 1 3H-32 11837483 LDL .:-'IN.., _~"\ I 08/01/07 1 1Y-10 11837485 INJECTION PROFILE . U:tL\ /?r'~ - r-£"" ) 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' 1~(') - (J "5"" 08/04/07 1 1A-06 11837486 INJECTION PROFILE i )T{\ I"K -/Il. 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE . f:)tV ~ -If A' 08/06/07 1 2U-08 11813076 LDL &1I'I1r. ~ - ~ ( 08/06/07 1 1 G-12 11837490 PRODUCTION PROFILE It~ - ?,;::).. 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE . ()I(' ¡c;"1(' -I"'A.:J 08/08/07 1 2N-327 11837491 SONIC SCANNER ðb~-O<O~ 08/08/07 1 2N-327 11837491 SONIC SCANNER-FMI :"-¡",'"l ",F L:l 08/08/07 1 3K-01 11632749 PRODUCTION PROFILE . J*(o - ,,), 08/12/07 1 2X-04 11846430 INJECTION PROFILE ()'7-(\ I'X~ -II*' 08/13/07 1 2Z-29 11850419 SBHP SURVEY /1f1f ":");Jf:::¡ 08/13/07 1 2X-19 11850420 SBHPSURVEY ,qé>-/~.~- 08/13/07 1 1A-20 11850421 SBHP SURVEY J'1f> - /L:::J 08/14/07 1 1F-13 11850422 SBHP SURVEY LJ 'J:.f' JSr~ -li./lJ 08/14/07 1 1H-10 11846432 SBHP SURVEY /A-:;, - f"'\.-:q-..., 08/14/07 1 1Q-10 11846431 SBHP SURVEY /4Jf" '/- let "$r 08/14/07 1 2U-05 11846433 INJECTION PROFILE I 1 ':I:1" _ llif.L\ -Iìl~ 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE I fJ'-l -1"'A4 08/16/07 1 2H-06 11846435 LDL /~.C; -/{...CJ, 08/17/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ';)7f' . . ') ) @ ~ ~ ~ 1: ~.1: ffJ\ - ~ @ ~ r¡ ,~ @ ~ tru ~ ,J: ~ J /JlJ ~tru è0 ~~JL AI,A.SKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 26,2004 tf~"t~ Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) te'st report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 1 0, 2004. Attached is a copy of the SVS Test Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, "as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, cf~ß~~c. James B. Regg - L I Petroleum Inspection Supervisor Attachment SCANNED J \f\oç 1. ¿u <..1 ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report ') Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: Waived Submitted By: Brad Gathman FieldlUnitlPad: KRU 2H Separator psi: LPS Date: 11/10/2004 96 HPS ~?;~ql~f1;l~~l/~~1~~"N"" Well Permit Separ Number Number PSI 2H-Ol 1840770 2H -02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H-09 1852590 96 2H-I0 1852600 96 2H-ll 1852610' 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H-15 1840860 2H-16 1840870 2H-17 2000190 , '::~r~;:~{~fi(~~~:~, " "'., xt$~~(~~:S~;SJ111ii~t41~ti~tt~lj/!ì~1~ .J!fl¡l~1r¡¡yR~,: '''¡ Set LIP Test Test Test Date Tested and or PSI Trip Code Code Code Passed Retest or SI 70 50 P P 70 65 P P 70 70 P P 70 50 P P 70 55 P P 70 50 P 4 70 55 P P 70 60 P 4 70 50 P P Oil, WAG, GINJ, GAS, CYCLE, SI WAG WAG WAG WAG OIL OIL OIL OIL OIL 11/11/2004 OIL OIL 11/11/2004 OIL WAG OIL WAG WAG WAG 96 Wells: 9 Components: 18 Failures: 2 Failure Rate: 11.11 o/B 90 Day Remarks: 2H-I0 & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-10-04.xls 01/29/04 Schlumberger NO. 3109 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ( Well Job # Log Description Date BL Color CD 3N-11 , ~, n 'f')7'+ 10709696 JEWELRY WITH PRESS & TEMP 01/25/04 1 1 F-05 \ '? ~ -- /,-:1& 10709698 INJECTION PROFILE 01/27/04 1 1Y-13 ',<:= "Ok~ 10709699 INJECTION PROFILE 01/27/04 1 3K-17 ¡c; flo-I~,~ 10709697 LDL 01/26/04 1 1 F-01 ~~ '~I~ II 10709693 LDL 01/22/04 1 3J-14 ~:~)-i9rS~ 10709690 PRODUCTION PROFILE 01/17/04 1 2H-06 . ßf5-) (l?C¡ 10709694 SBHP SURVEY 01/23/04 1 I ( :., .... '*" , "," ."', ,:.' ". " , ,,", . "., '. '. RECEIVED SIG NE~~":"~~~<-r":» \ ~..Q.~~-\'--À 0 ~~^' ('- , DATE: --- w -' ,,.J..-.;',.' ;t. , :~~~, . , '. . ' Please sign and return one copy of this transmittal to Beth at the above address orfax to (907) '561-8317.:ihån,k'~t10U&GasConS.Co\1U11ision , :., /' '. ,"::'" ":,~"":>..,::,,,,,' An_e ~~ ((" 1'1, ¡~~ ¡~ ~ It:: ~-j w::: IL,'" {(,'~ (!i ~~~ 6) n 0 ß '-. ',,' ~ \'~''ð#/f'''t,Ð'Er.'U!,;:,,~¡... ~-l,~[) tJi ~ LIJ "if "',, ~ ,,\(''\~ I ~ 'r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well_ Other_X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 169' FNL, 136' FWL, Sec. 36, T11 N, R8E, UM At top of productive interval 1408' FNL, 1433' FEL, Sec. 25, T11N, RSE, UM At effective depth At total depth 1152' FNL, 1104' FEL, Sec. 25, T11N, RSE, UM 5. Type of Well: Development ~X Explorato~ Stratigraphic__ Service__ (asp's 498535, 5948694) (asp's 502245, 5952736) (asp's 502573, 5952992) 6. Datum elevation (DF or KB feet) RKB 129 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2H-06 9. Permit number / approval number 185-169 10. APl number 50-103-20044 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 111' SURF CASING 3239' PROD CASING 8852' 9024 feet Plugs (measured) 6342 feet 8795 feet Junk (measured) 6196 feet Size Cemented 16" 195 SxAS II 9-5/8" 1000 SxCS III & 510 CS II 7" 450 Sx CIG & 175 CS I Tagged Fill (10/19/00) @ 8795' MD. Measured Dep~ 111' 3368' 8981' True vertical Depth 111' 2799' 6315' Perforation depth: measured 8590 - 8596'; 8612 - 8642'; 8668 - 8699' true vertical 6063 - 6067'; 6077 - 6097'; 6114 - 6134' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55, Tubing @ 8566' MD. RECEIVED ? ZOO1 Alaska 0il & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) BROWN 'HB' @ 8294' MD; BROWN 'I-B' @ 8524' MD. BAKER 'FVL' (LOCK OUT 8/5/97) @ 1793' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 514 Subsequent to operation 303 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 4016 3580 138 420 Casing Pressure Tubing Pressure - 257 232 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE.~ 2H-06 CEMENT SQUEEEZE DESCRIPTION OF WORK COMPLETED 9/15/00: RIH & tagged fill at 8677' MD. 9/19/00: RIH w/CT & pumped gelled sand slurry containing 4000 lbs of sand, to spot an isolation sand plug across the lower open 'A' Sand perforation intervals located at: 8590 - 8596' MD 8612 - 8642' MD 8668 - 8699' MD 9/20/00: RIH & tagged top of sand plug at 8436' MD. 9/21/00 - 9/24/00: Performed a Cement Squeeze for Water Shutoff as follows: MIRU CTU & PT equipment. RIH & tagged sand top at 8522' MD. Pumped slurry containing an additional 300 lbs of sand to raise sand top to 8509' MD. Swapped to pumping cement to squeeze the open 'C' Sand perforation interval located above the sand plug at: 8454 - 8490' MD Pumped 36 bbls of Latex Acid Resistive Cement, and attained 1000 psi maximum squeeze pressure, but squeeze pressure kept bleeding off over 1000 psi. Contaminated cement w/biozan & jetted contaminated cement from wellbore to top of sand plug. POOH w/jetting nozzle. Mixed & pumped another 26.5 bbls of LARC w/3% MgO2. Squeezed 2 more bbls of cement behind pipe & attained 3000 psi squeeze pressure held 1 hour. Contaminated cement w/biozan & jetted contaminated cement from wellbore to 8512' MD. POOH w/nozzle. RIH w/1.8" milling BHA & milled through hard cement and into sand plug to 8529' MD. POOH w/BHA. Rigged down. 9/28/00: PT squeeze w/2500 psi on tubing. Lost 100 psi in 30 minutes. 9/30/00: RIH w/CT & jetted out sand plug to 8810' MD. 10/19/00: RIH & tagged fill at 8795' MD. Placed the well back on production and obtained a valid welltest. MEMORANDUM TO' State of Alaska Alaska Oil and Gas ConserVation Commission · Julie Huesser, ~,?'~ DATE: December 2, 2000 Commissioner ~ THRU: Tom Maunder, ~(~,~b~.~_\ P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit~ 2H Pad Saturday, December 2,-2000: I traveled to the KuParUk River Field and Witnessed the semi annual safety valve system testing on 12H Pad. As the attached AOGCC Safety Valve SYstem Test Report indicates .I witnessed the testing of 9 wells and 18 components with four failures observed. The Iow pressure pilots on wells 2H-5,2H-6 and 2H-12 tripped well below the required set point and the surface safety valve on well 2H-12 failed to pressure test. The three failed Pilots · were adjusted and retested at the time of this test. The failed valVe will be rePaired _ and retested by the operator. . The 22.2% failure rate will require a retest of this PadS Safety Valve SyStem in 90 days rather than the normal~~,~day cycle. Earnie Barndt conducted the testing today he demonstrated go°d test procedure and was a pleasure to work with · Summary: I witnessed the semi annUal SVS testing at 2H Pad in the KuParuk River Field. KRU 2H Pad, 9 wells, 18 components, 4 failures 22% failure rate Attachment: SVS KRU 2H Pad 12-2-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2H Pad 12-2-00 CS.doc .f Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Submitted By: Chuck Scheve Date: 12/2/00 Operator Rep: Ernie Bamdt Field/Unit/Pad: Kupamk / KRU / 2H Pad AOGCC Rep: Chuck Scheve Separator psi: LPS 96 · HPS . Well Permit Separ Set L/P Test Test Test Date Oil, wAG, Gl]NJ, Number Number PSI PSI Trip Code Code Code I Passed i GAS or CYCL~ 2H-01 1840770 2H-02 1840730 ~ 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 70 20 3 P 12/2/00· OIL 2H-06 1851690 96 70 10 3 P 12/2/00 - ' OIL 2H-07 1851700 96 70 60 P P OIL 2H-08 1851710 96 70 60 P P . OIL! 2H-09 1852590 96 70 50 P P ' -OIL 2H- 10 1852600 96 70 50 P P -. - OIL 2H-11 1852610 96 70 50 P P : OIL 2H-12 1852620 96 70 10 3 4 remarks 2H- 13 1840960 2H- 14 1840950 96 70 60 P P OIL 2H- 15 1840860 2H- 16 1840870 ' ~ ' 2H-l~ 2000190 · · Wells: 9 Components: 18 FailureS: 4 Failure Rate: 22.0% [~90 var Remarks: three failed pilots repaired and retested, failed SSV to be repaired and retested bY op Pad on 90 day test cycle 12/4/00 Page 1 of 1 SVS KRU 2H Pad 12-2-00 CS.xls ADDENDUM WELL: 1/07/86 1/~o/s6 2H-6 Arctic Pak well w/175 sx CS I, followed by 60 Arctic Pak. Rn CET log & GCT gyro. Alaska Oil & Gas Cons. commissio~ Anchorage ~illing S~perintendent I~te ARCO Oil and Gas Company Daily Well History-Final Report Itl,Hruclions: Prepare and suOm~! ,ne "Fi,al Report" on the firS1 Wednesday after al!owable has been assigned or weii is Plugged. Abandoned. or Sold. "Final Rel~ort" should be suOm~tte~ also when operations are suspended for an inde!imte or appreciable iength of time. On wort(overs when an official test is r~ot required upon completion, report completion' and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operahon ,I space is avadaOle Accounting cost center code District ICounty or Pamsh State Alaska Alaska North Slope Borough I Field ILease or Unit [We,I no. Kuparuk River ADL 25587 2H-6 Auth. Or W.O. no. ~ Title AFE AK0014 I Completion Nordic 1 API 50-103-20044 Operator ~A.R.Co. W I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun Date Complete 2/8/86 Date and depth as of 8:00 a.m. 2/08/86 thru 2/1018 Complete record for each day reported Iotal number of wells (active or inactive) on this Pst center prior to plugging anti [ bandonment of this well our 1045 hrs. [Prior status if a W.O. 7" @ 8981' 8894' PBTD, RR 6.8 ppg diesel in tbg & ann A~cept ri~.@ 1045 hfs, 2/8/86. ND tree, NU & tst BOPE. RU Schl, perf w/4" gun, 4 SPF, 90° phasing f/8668'-8699'. Perf w/5" gun, 12 SPF, 120° phasing f/8454'-8490'. RIH, set lB Pkr @ 8524' WLM, RD Schl. RIH w/268 jts, 2-7/8", 6.5#, J-55 EUE 8RD IPC tbg w/SSSV @ 1812', HB pkr @ 8313', lB pkr @ 8543', TT @ 8562'. Set pkr, tst tbg, shear PBR. Tst pkr & SSSV; OK. shear out ball. Set BPV. NU & tst tree. Displ well to diesel. RR @ 1300 hrs, 2/9/86. Old TD New TO PB Depth 8894' PBTD Released r~g Date Kind of rig 1300 hrs. 2/9/86 Rotary Classificat,ons (oil, gas, etc.) Type completion (single, dual. etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potent,a~ test dala we'll no. Date Reservoir Producing Interval Oil or gas Test time Produ'cticn Oil on test Gas per day . Pump size. SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above ,s correct Signature,~7~// ~--~.~' ~'",:._~.~----~t~' .] For form preparation and dit~.~ribulion, see Procedures Manual. SeCtion 10, Drilling. Pages 86 and 87. Oate / ITitle Drilling Superintendent ARCO Alaska, Inc. Post Offic ~x 100360 Anchorage,-,.~'iaska 99510-0360 Telephone 907 276 1215 Date: February 26, 1987 Transmittal # 5926 ---RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-8 2H-6 2H-5 3F-13 3F-12 2H-8 2H-7 3F-14 3K-5 3K-3 3K-4 3F-12 CBL 2-16-87 6195-9264 CET 1-17-86 7400-8873 CET 1-16-86 6525-7959 CET 1-7-86 6160-7920 CET 1-23-86 6946-7250 CET 1-1-86 8000-8650 CET 1-1-86 6800-7938 CET 1-7-86 4700-6760 CET 7-16-86 6988-7990 CET 7-14-86 7595-8800 GET 7-14-86 7793-8787 CET 1-7-86 6050-7416 NSK , Drilling State (+ sepia) BPAE Chevron SAPC Mobil Unocal Vault (film) ARCO Alaska, Inc. Is a Subsidiary of AllanticRichfieldCompany' ARCO Alaska. Inc. Post Office ~ 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETUP~N TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 02-26-86 ~SMI~"~L ~, 5579 Transmitted herewith are the following item~. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ Open Hole/ One * of eac~h 3J-12 ~52',: DIL/SFL-GR 01-01-86 Run~ DIL/SFL-GR 01-0'i-86 Run #1 ~f)~~" ' Don/Nou-GR (poro) 01-01-86 " Den/Neu-GR (poro) 01-01-86 " Den/Neu-GR (raw) 01-01-86 ~2" Den/Neu-GR (raw) 01-01-86 ~ cyberlook 3F-16 ~5" DIL/SFL ~_ 2" DIL/SFL Den/Neu t ~ ~2" Den/Neu ~ 5" Den/Neu ~ 2" Den/Neu ~Cyberlook 2 -6 Den/Neu-GR (poro) 12-28-85 ~2" Den/Neu-GR (poro) 12-28-85 '~5" Den/Neu-GR (raw) 12-28-86 '~2" Den/Neu-GR (raw) 12-28-85 01-01-86 01-07-86 01-05-86 (poro) 01-07-86 (poro) 01-07-86 (raw) 01-07-86 (raw) 01-07-86 01-07-86 12-28-85 ~Cyberlook 12-28-85 2A-12 ~5" DiL/SFL-GR 0i-17-86 ~2" DIL/SFL-GR 01-17-86 5" Den/Neu (poro) 01-17-86 " Den/Neu (poro) 01-17-86 " Den/Neu (raw) 01-17-86 ~ 2" Den/Neu (raw) 0!-!=,-86 -~yber look 01- ! 7- 86 2000-8283 2000-8283 R=n #1 3991-8258 Run #1 3991-8258 Run #1- 3991-8258 R~un #1 3991-8258 Run #1 7550-8234 Run #1 1800-8432 Run %1 1800-8432 Run #1 4400-8407 Run #1 4400-8407 Run #1 4400-8407 Run #! 4400-8407 Run #1 7900-8400 Run #1 2300-9016 Run #1 2300-9016 Run #1 4000-8991 Run #1 4000-8991 Run ,'--.' 1 4000-8991 R~un #1 4000-8991 - Run %1 8250-9070 Run #1 6659-7110 R~.n #1 6659-7110 Run #1 6659-7084 R=n #1 6659-7084 Run #1 6659-7084 Run %1 6659-7084 R~n %1 6690-7050 Receipt Acknowledged: _ . . Date: NSK C!erk*bl Rathme!!*bl ARCO Alaska, Inc. Post Office B'6"~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 24, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2H-6 Dear Mr. Chatterton' Enclosed are the 2H-6 Well Completion Report and gyroscopic survey. I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L156 Enclosures RECEIVED FEB 2 8 986 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (~'T'L AND GAS CONSERVATION COi~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-169 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20044 4. Location of well at surface 9. Unit or Lease Name 169' FNL, 136' FWL, Sec.:~6, T11N, R8E~ UN ~LOCATIQNS] Kuparuk River Unit At Top Producing Interval VErIFiED I 10. Well Number 1408' FNL, 1433' FEL, Sec.25, TllN, R8E, UM Surf. 2H-6 At Total Depth I 8. Pl. ~ 11. Field and Pool 1152' FNL, 1104' FEL, Sec.25, T11N, R8E, UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 129' RKB ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 1 2/20/85 1 2/27/85 I 2/29/85*I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9000 'MD ,6325 'TVD 8894 'MD ,6258 'TVD YES ~ NO []I 1812 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE;WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 111' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 3368' 12-1/4" 1000 sx CS Ill & 400 sx CS II Performed top job w/110 sx CS II 7" 26.0# J-55 Surf 8981' 8-1/2" 450 sx Class G & 175 sx CS I 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) 8668' - 8699' w/4 spf, 90° phasing 2-7/8" 8562' 8313' & 8543' 8454' - 8490' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OiL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED,a~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED FEB 2 8 [986 Aia¢~ 011 & 6as C~. ~ Form 10-407 * NOTE: Tubing was run & the well perforated 2/9/86. DAM/WC49 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUEVERT. DEPTH Top Kuparuk C 8452' 5970' Base Kuparuk C 8498' 6000' Top Kuparuk A 8580' 6055' Base Kuparuk A 8798' 6196' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Associ ate Engineer Title 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:..A~ac~¢ckSUpl~_ler~. ental records for this well should show the details of any multiple stage cement- ing and t~8 ]~)6atio.~ o~.~icementing tool. Item 27' Method,:'.of. Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I nject~)n, Shut-in, Other-explain. Item 28: If n~,cor.-.es,~.aken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Box .~._.~360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for each of the following wells' 2H-5 2H-6 2H-7 2H-8 I have not yet received the 2H-7 and 2H-8 Well Histories. When I do, I will forward them to you. Also, bottomhole locations, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic surveys are run and the wells completed. If you have any questions please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L72 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany STATE OF ALASKA ALASKA,. _ANDGAS CONSERVATION C~' i~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 85-169 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20044 4. Location of well at surface 9. Unit or Lease Name 169' FNL, 136' FWL, Sec.36, T11N, R8E, UN (approx.) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2H-6 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kup'aruk River 0i 1 Pool 129' RKB ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/20/85 12/27/85 12/29/85J N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9000'HD 8894 'ND YES [] NO ~ N/A feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 111' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 3368' 12-1/4" 1000 sx CS III & 400 s~ CS II Performed top job w/11£ sx CS II 7" 26.0# J-55 Surf 8981' 8-1/2" 450 sx Class G & 175 s~ CS I 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) NONE N/A 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A -- 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I "'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ ., Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ......... Form 10-407 TEHP3/WC68 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,1 29. ~ 30. ' ~ ~' , GEOLOGIC MARKERS - ;, ~FORMATION:TESTS: ; · NAME Include interval tested, pressure data, ali fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/^ 31. LIST OF ATTACHMENTS 32. I hereby certify that the~oregoing is true and correct to the best of my knowledge Signed //~ ~_~ Title Assooi ate Engineer Date 2'0-~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO 011 and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty. parish or borough North Slope Borough ILease or Unit ADL 25587 ITit,e Drill State Alaska Kuparuk River Auth. or W.O. no. AFE AK0014 Nabors 26E AP1 50-103-20044 IWell no. 2H-6 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Ioate 12/20/85 IHOur Date and depth as of 8:00 a.rn; 12/2o/85 thru 12/23/85 12/24/85 [2/25/85 thru 12/26/85 12/27/85 Complete record for each day reported IARCO W.I. PHor status if 56.24% a W.O. 1330 hrs. 9-5/8" @ 3368' 3390', NU BOPE Wt. 8.8, PV 2, YP 2, PH 9.0, WL 30, Sol 2 NU diverter sys. Accept ri~ @ 063Q. hrs, 12/20/85. 16" @ 110'. Spud well @ 1330 hrs, 12/20/85. Navi-Drl, drl & surv 12~' hole~ to 3390', short trip, C&C, POE.' RU'& rn 85 ~ts, 9-5/8", 36~, J-55 BTC csg w/FC @ 3286', FS @ 3368'. tm/ w/1000 sx CS III w/10#/sx Gilsonite, followed by 400 sx CS II. CIP @ 2345 hfs,. 12/22/85. ND diverter sys. Perform 110 sx CS II top job. NUi BOPE. 448', .60°, N47.2E, 448.0 TVD, 2.3 VS, 1.6N, 1.7E 1170', 18 20°, N40.2E, 1159.0 TVD, 107.9 VS, 80.9N, 71.5E 1541', 27.50°, N37.2E, 1500.5 TVD, 251.9 VS, 188.1N, 167.6E 2109', 41.8°, N42.2E, 1964.3 TVD, 577.1VS, 429.3N, 385.8E 2836', 49.4°, N41.2E, 2457.1TVD, 1110.0 rS, 838.4N, 728.3E 3345', 49.2°, N41.2E, 2788.9 TVD, 1495.9 VS, 1126.6N, 985.0E 9-5/8" @ 3368' 5210', (1820'),_Navi-Drl Wt. 9.1, PV 7, YP 7, PH 10.0, WL 9.6, Sol 6 NU &tst BOPE. RIM, tst cst to 2000 psi. DO flt equip + 10' new hole. Conduct formation tst to 12.7 ppg EMW. Navi-Drl f/3400'-5210'. 3466', 48.5°, N42.2E, 2868.6 TVD, 1587.0 VS, 1194.6N, 1045.6E 3934', 51.9°, N40.2E, 3162.5 TVD, 1951.0 VS, 1465.0N, 1289.4E 4756', 52.8°, N40.2E, 3658.7 TVD, 2605.6 VS, 1965.5N, 1712.4E 5102', 53.4°, N40.2E, 3866.4 TVD, 2882.0 VS, 2176.9N, 1891.0E 9-5/8" @ 3368' 8213', (3003'), Navi-Drl Wt. 10.4, PV 13, YP 10, PH 9.0, WL 6, Sol 13 Navi-Drl & surv 8½" hole to 8213'. 7333', 49.7°, N44.2E, 5241.9 TVD, 4637.2 VS, 3449.5N, 3099.8E 7990', 48.1°, N43.2E, 5673.5 TVD~5132.4 VS, 3809.2N, 3440.4E 9-5/8" @ 3368' 8828', (615'), Drlg Wt. 10.6, PV 16, YP 10, PH 9, WL 5.6, Sol 14 Drl & surv 8½" hole to 8828'. 8148', 48.5°, N44.2E, 5778.6 TVD, 5250.4 VS, 3894.5N, 3521.9E The above is correct Signature /,~ For form preparation and~llstribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I AccOunting District JCounty or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25587 Auth, or W.O. no. ~Title AFE AK0014 J Drill Nabors 26E API 50-103-20044 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 12/20/85 Date and depth as of 8:00 a.m. Old TD Released rig 12/28/85 thru 12/30/85 Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our I Prior status if a W.O. 1330 hrs. I cost center code Alaska JWell no. 2H-6 2200 hrs. 7" @ 8981' 9000', (172'), 8894' PBTD RR 10.6 ppg NaC1/NaBr Drl to 9000', wiper trip, circ, POH. RU Schl, log w/DIL/GR/SP/SFL f/9000'-3368', cont w/GR to 2300'. Log FDC/CNL f/9020'-8250', CAL f/9020'-3368', RD Schl. RIH, C&C, POH, LD DP. Rm back thru ratty spots, C&C, POH. Chg rams to 7", tst to 3000 psi. RU & rn 208 jts, 7", 26#, J-55 w/FS @ 8981'. Cmt w/150 sx Cl "G" w/2% A-2 & 1% R-7, followed by 350 sx C1 "G" w/l% FL-19, .5% CD-31 & .3% A-2. Displ w/10.6 ppg NaC1/NaBr. Bump plug. CIP @ 1430 hrs, 12/29/85. ND BOPE, NU tbg spool & lower tree. Tst pack-off to 3000 psi. Pmp 35 bbls diesel cap. RR @ 2200 hr$, 12/29/85. New TD 9000' TD 12/29/85 PB Depth 8894' PBTD K nd of rg Rotary Date Classifications (oil, gas, etc.) Oil Producing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval' Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparatio~and distribution, see Procedures Manual, Seclion 10, Drilling, Pages 86 and 87. Drilling Superintendent SUB.~URFACE DIRECTIONAL ~URVEY ~]UIDANCE ~ONTINUOUS [-~"~ COL RECEIVED F E B 2 8 Alaska 0ii & (;as Cons. Commission Anchorage ARCO ALASKA INCORPORATED Company , , Well NameWELL 2H-6 (169' ~, 136' 7~L, S36, TllN, R8E) i i · i l Field/Location ~u~ARu~, NORTH SLOPg, ALASY.~ I! Job Reference No. 71233 Lo~3ged By: BEUTLER Date · , 11-FEB-1986 Computed By: CUDNEY GCT DIRECTI3NAL SURVEY CUSTOMER LISTINS FOR ARC] .ALASKA, INC. KU~6RJK NORTH SURVEY SLOPE,AL6SKA gATE: 17-JAN-85 METHD3S O~ CDMPUTATIOq TOOL LO'ATI2N: TAN~ENTIAL- INTE~P2LATION: LINEAR VERTICAL SECTI3N: flORIZ. DIST. ENGINEER: BEUT'LER AVERAGED DE¢IATIDN PROJECTED D~TO ~ TARSET &ZIMUTH AZIMUTH OF NOR T-I 42 DES 48 ARSO ~L&SK~, I~C. 2q-6 NEATH SLDPE,AL~SK& COMPUT&TI3~ INTERPOL4TED V~LUES FOR TRUE SJB-SEA ME~SURE3 VERTICAL VERTICAL 3EPTH DEPTq DEPTH O,OD 0,00 -129.00 100,00 99,70 -29,30 200,00 199,70 70.70 300,00 299,70 170,70 ~O0.OD 399,70 270.70 500,00 499,70 370.70 500,02 599,66 ~70,66 700.00 599.~1 570.41 530,30 798,57 569,67 9DO.OD 897,21 768,21 1000.00 994.91 365.91 1100.93 1091.34 962.34 1230.00 1186.43 1057.43 1300.00 1279.75 1150.76 1400.00 1371.53 1242.53 15DO.OD 1461,56 1332.56 1500.00 1549.51 1420.61 1700.00 1635.34 1506.04 1BO0.O0 1?18.31 1589.31 1900.09 1798,)0 1669.90 2000.00 1877.15 1748,15 21OO,OO 1953,17 1824,17 2200,00 2026,31 1897,31 2300,00 2097,98 1968,08 2~00,00 2165,41 2035,41 2500,00 2231,46 2102,46 2500,00 2296,~6 2167,~6 2700.20 2361,52 2232.62 2800.00 2426,5? 2297.6? 2900.00 2492,03 2363,03 3000,00 2557,35 2428,35 3100,00 2622,51 2493,51 3ZOO,DO 2587,57 2558,67 3300.00 2752,95 2623,9.5 3400,00 2818,59 2589,69 3~00.00 2884,35 2755.85 3500.00 2949,25 2820,25 3700,00 3011,59 2882,59 3~00.00 3073.16 2944.16 3700,90 3135,34 3005,04 CDJRSE DEVIATION AZIMUTH lEG lin DEG 0 0 2 5 8 10 o o N 0 9 0 13 S 10 3 0 11 S lO 7 0 16 S It 41 15 S 24 13 14 S 55 49 ~2 N 44 23 22 N 36 26 31 N 34 35 59 N 40 45 13 q. 5 N 43 52 E 1637 N 41 37 E 19 36 N 40 4 E 22 21 N 43 23 E 24 28 N 42 43 E 26 58 N 38 32 E 29 50 N 39 17 E 32 31 N 43 Z3 ~ 34 55 N 45 38 E 37 Z2 N 43 58 E 39 31 N 43 41 t6 N 42 43 58 N 42 45 55 N 43 47 51 N 40 49 13 N 39 49 22 N 40 49 23 N 41 49 24 N 41 49 7 N 42 52 E 59 E 21 E 37 E 20 E 53 E 13 E 33 E 3 E 49 17 N ~2 49 20 N 42 49 16 N 42 49 10 N 42 48 37 N 42 48 54 N 41 50 49 N 42 51 53 N 41 51 53 N 41 51 43 N 40 7 7 10 5 51 19 51 Zl 57 D~E: 6-FEB-B5 £VEN 100 FEET OF VERTICAL DOG' EG S:CTION SEVERITY FEET DEG/IO0 0,00 0,00 -0,07 D.09 -0.34 0,15 -0,56 0.12 -0,80 D.05 -0.92 0.93 1.15 2.95 8.06 3.03 20,00 2,45 36.93 2,75 58.16 3.38 84,59 2,42 115.44 3.39 151.30 2.5~ 191,01 3.11 234.44 2.5~ 281.68 3.35 333.59 3.42 388.90 3.25 448,05 2.31 510,28 Z,O1 575.23 Z.77 643.41 2.35 714.04 1.97 785.98 2,27 861,93 1.52 937.83 3,77 1013.55 9.17 1089.58 0'51 1165,25 0,31 12~0,96 0.17 1315,82 0.07 1392.67 0.33 1458,42 0,3) 1543.76 0,36 1618,?~ 1.49 1695.23 1.45 1773.41 0.93 1852.19 D,3B 1930.71 0.39 m~GE 1 DATE DF SUR~EY: l?'J~N-85 KELLY BUSHING ELEVATI3N: 129.00 ENGINEER: BEUTLER FT MEASURED DEPTH RE'TAN,~ULAR COORO NERTH/SOOTH E&ST! FEET FEET 0.00 N 0.0 0.14 S 0.0 0.50 S O.O 0.~9 S 0.1 1,35 S 0,2 1,70 S 0.4 0.39 S 2.1 4.i)1 N 5.5 14.75 N 13.5 28.19 N 23.9 43.56 N 38.4 52.96 N 56.5 86,57 N 76.4 113.39 N 100.2 142,.25 N 127.7 175.12 N 155.9 212.29 N 185.3 251.35 N 219.5 290.35 N 258,7 332.36 N 300.5 377.~ 26 N 343.6 ~24.~8 N 388.2 474.¢5 N 434.6 52.7.43 N 481,3 582.92 N 528,7 540.85 N 576.5 59~,03 N 625.4 756.17 N 675.3 ~13.19 ~ 725.4 869.54 N 775.9 925,72 hi 826.7 981.99 N 877.6 1338,23 N 928.5 1094.35 N 979.4 1150.18 N 1030.0 1205,96 N 1080,1 1262.73 N 1131,4 1320,64 N 1183,9 1379.53 N 1236.1 1¢38,T6 N 1287,8 IqATES H]RIZ. DE,~RTURE WEST DIST. AZIqUTH FEET DES MIN 0 E 0.00 '~ 3 0 E 4 E 0.15 S 17 14 E 4 E 0.50 S 4 40 E 8 E 1.38 S 11 37 E 8 E 1.75 S 15 44 E 1 E 2.15 S 79 5 E 8.19 N 53 1 E ZO,O0 1 E 36.97 5 E 58,18 N 41 21 0 E 84,60 N 41 54 E 2 E 115,47 ~ 41 26 E 4 E 151.34 N 41 28 E 2 E 191.03 q 41 57 E 3 E 234.49 ~ 41 40 E 2 E 281.80 N 41 7 E 4 E 333.73 N 41. 8 E 9 E 388.97 N 41 42 E 2 E 448.08 ~ 42 7 E 2 E 510.30 N 42 19 E 2 E 575.24 N 42 26 E 1 E 543,~2 N 42 29 E 5 E 714..06 'q 42 23 E B E 787,02 N 42 12 E 3 E 362,02. N 41 58 E 1 E 937.97 N 41 49' ' 1 E 1313.~32 ~) 41 4~L 8 E 11389.77 N 41 44 E 9 E 1165.45 N 41 44 E 5 E 1241.15 N 41 46 E ¢ E 1317.02 3 E 1392.87 N 41 48 E 2 E 1~6~.'63 2 E 1543.98 M 41 50 E 3 E 1518.96 N 41 50 E 0 E 1595.45 N 41 51 E 3 E 1773.64 N 41 52 E ~ E 1852.44 N 41 51 E 9 E 1930.98 N 41 49 E CO~PUT~TI3~ D~TE: 6-FE~-85 A~CO ALASKA, INC. 29-6 KUmARUK NINTH SLDPE~L&SK& INTERPOLATED VALJES FOR TRUE SOB-S:& C3URSE ME&SURE2 VERTICAL V:RTI'AL 3EVI~TIDN 3EPTfl DEPTq DEPTH lEG WIN DEG 4000.03 3196,78 3067.78 52 26 N 40 48 4tOO.OD ]256.52 3127.62 53 40 N 40 59 4200.00 3315.B3 3186.83 53 42 N 40 56 4300.00 3375.01 3246.01 53 %0 N 40 49 44]0.00 3434.38 3305.33 53 25 N 40 46 4590.03 3494.11 3365.11 53 16 N 40 44 4500.39 3553.~8 342~.98 53 ~1 N 40 25 4700.00 3614.03 3485.03 52 57 N 40 29 4BDO.OD 3674.38 3545.38 53 8 N 40 53 4930.3~ 3733.59 3604.69 53 ~1 N 41 33 5000,00 3792,58 3663,68 53 42 N 41 3¢ E 5130.00 3852.t4 3723.14 53 22 N 41 lO E 5200.00 3911.~0 3782.40 54 0 N 41 34 E 5300.00 3969.90 3840.90 54 22 N 42 10 E 5%20.00 4028.18 3899.18 54 15 N 42 13 E 5500,00 ~086,90 3957,90 53 ~9 N 42 B E 5590,30 4146,27 4017.27 53 14 N ~3 25 E 5700.00 %206.37 ~077.37 52 56 N 4~ lZ E 5~00.00 4266.~6 4137.86 52 39 N 4~ 15 E 5930.30 4327.52 %198,62 52 32 N 4~ ~ E 6000,00 ~388,50 4259.50 52 27 N 44 6100.00 %449.42 %320.42 52 27 N 44 lO 6200.00 4510.51 ~381,51 52 11 N 44 21 6300,00 4572.07 4443.07' 51 54 N 43 55 6¢00,00 4633,~0 %504.80 51 ~3 N 43 33 6500,00 4595,31 ~566,31 52 13 N 43 23 6600,00 4756,82 4627.82 51 6700.00 %819.~9 4593.49 50 37 N 43 46 6800.00 4883.35 ~75¢.35 50 13 N 43 52 6900.00 4947.58 4818.58 49 57 N 43 36 7330.00 5011,92 4882.92 49 56 N 43 27 E 7100.03 5076,38 4947,38 49 ~6 N 43 35 E 7200,00 5140,93 5011,93 49 ~8 N 43 50 E 7300.00 5205.53 5076.53 49 37 N ~3 50 E 7400.00 5270.50 5141,50 49 22 N 43 39 E 7500.00 5335.58 5205.68 49 17 N 43 29 E 7500.00 5400.96 5271.95 49 5 N 43 22 E 7700,00 5466,56 5337.66 48 51 N' 43 Ii'E 7BDO.O0 5532.74 5403.74 48 20 N 42 57 E 7900.00 5599.55 5470.65 47 38 N q2 37 E EVEN 100 VERTICAL SECTION FEET E ~D09,32 E 2089.40 E 2169.95 E 2250.50 f 2330.92 E 2411.07 E 2491.11 E 2571.01 E 2550,69 E 2731,1? 2811.90 2892.28 2972.80 3053.89 3135.15 ~215.08 32~6.55 3375.45 3456.06 3535,46 E 3614.77 E 3694.05 E 3773.20 E 3~51,98 E 3930.63 E 4009.48 E ~088.31 E 4165.24 E ~243.17 E 4319.80 %395,36 %472.80 %5~9.17 %625.49 ~701.49 ~T77.33 ~853,08 %928.46 5003.51 5077.83 FEET 0= DOGLEG SEVERITY OEG~IOD 1.83 D.11 D.11 0.15 0.41 0,20 0.1~ 0.34 1.41 O.l~ 0.49 0.1~ 9.70 0.37 0,25 0.45 1.95 0,37 0.17 0.10 0.15 0,49 0,34 3.35 0.47 0.72 0.95 0.35 3.31 0.21 0,20 0,28 0,48 0.34 0.35 0,50 D,2D 0.58 0.47 P~GE 2 D&TE OF SURVEY: 17-J~q-85 KELLY BUSHIN3 ELEVATIDN: 129.00 ENGIiEER: BEJTLER Fl', ME&SURE3 DEPTH RECTANGULAR CDgRDIN&TES HDRIZ. DEP&RTURE NORTH/SOUTH E&ST/WEST DIST, ~ZIMUTH FEET FEET FEET DE3 MIN 1498,29 N 1339.31 E 2009.53 t 41 47 E 1558.84 N 1391,77 E 2389.74 N 41 45 E 1519,59 N 1444.61 E 2170.32 N 41 43 : 1580.64 N 1497.35 E 2250.92 N 41 41 ~ 1741.56 N 1549.93 E 2331.38 N 41 40 E 180Z.30 N 1602.31 6 2%11.57 q 41 38 E 1 3.1o 155 .45 E z 91.55 1923,98 N 1706,30 E 2571,50 N ~1 3 4( 1384,53 N 1758,18 E 2551,33 ~ 41 32 ~ 2044o99 N 1811,34 E 2731.83 ~ 41 31 E 2105,36 N 1864.96 E 2812.58 ~ 41 32 E 2165.68 N 1918.13 E 2B92,99 ~ 41 31 E 2226.22 q 1971.25 E 2973.54 q 41 31 E 2286.56 N 2025,44 5 3054.63 N 41 32 E 2346.70 N 2080.09 E 3135.89 ~ 41 33 E 2406.72 N 2134.40 E 3216.82 N 41 34 E 2%66.02 N 2188.79 E 3297.28 ~ 41 35 E 2523.~5 N 2244.37 E 3377.13 N 41~ 39 E 2580.50 N 2299.93 E 3456.69 N 41 42 E 2537.44 N 2355.31 E 3536,04 N 41 45 E 2594.42 N 2410.50 E 3515.30 N 41 48 E 2751.32 N 2465.?3 E 3594.54 N 41 51 E 2808.00 N 2521.01 E 3773.54 N 41 55 E 2864.51 N 2575.95 E 3852.39 N 41 57 E 2921.30 N 2630.38 E 3931.02 N 42 0 E 2978.50 N 268~.64 E 4009.34 ~ 42 1 E 3035,36 N 2738,74 E 4088,66 ~ 42 3 ~ 3092.43 q .2792,33 E 4165.57 ~ 42 4'[ 3147.36 N 2845.70 E 4243.%8 ~ ,2 3203.23 N 2898.70 E 4320.09 N 42 8 E 3258.75 W 2951,42 E 4396.63 ~ 42 10 E 3314.20 N 3004.04 E 4473.05 3369.41 N 3056,83 E 4549.41 ~ 42 12 E 3424.42 N 3109.74 E 4525.70 ~ 42 14 E 3%79.33 N 3162.32 E 4701.70 N 42 16 E 3534.27 N 3214.59 E 4777.52 N 42 17 E 358'9.27 N 3266.69 E 4353.26 N 42 18 E 3544.14 N 3318..38 E 4928.63 N 42 19 E 3598 95 N 3359 65 E 5003 58 N 42 19 3753.~8 N 3420.14 E 5~77.99 CD~PUTATIDN ARCO ALASKA, INC. 2"1-6 KUPaRUK NDRTH SLOPE,aLaSKA DATE: 6-FEB-85 PAGE 3 3aTE OF SURVEY: l?-JaN-85 KELLY BUSHING ELEVATION: 129.00 ENGINEER: BEJTLER INTERPOLATED VALUES FOR EVEN 100 FEET O= MEASURED DEPTH TRUE SJ3-SSA CDORSE VERTICAL MEASURE] VSRTIC~L VERTI'AL DEVIaTIgN AZIMUTH SECTION DEPTH DEPTfl DEmFH DEG MIN DEG MIN FE~T 8OO0.OO 5666.82 5537.82 48 8 N 43 8 E 5151.91 8130.03 5733.39 5506.39 48 19 N 43 45 E 5226.53 BZO0.OD 5800.02 5671.02 48 1 N ~4 12 E 5301.08 8330.03 5867.06 5738.06 47 ~5 N 45 53 E 5375.20 8~30.33 5934.%8 5805.48 ~7 30 N 49 56 E 54~8.67 $500.00 5001.57 5872,67 48 16 N 5! 18 E 5521.99 85~0.93 5057.84 5938.84 48 52 N 51 ~ E 5596.10 8700.0~ 5133.09 $00%.09 49 %2 N 51 33 E 5670.96 8800.00 5197.35 5055.35 50 4 N 52 ~O E 57~5.62 8~00.00 5261.%1 5132.41 50 10 N 52 4Z E 5SZZ.Z6 DOGLEG RECTaNGULaR CO SEVERITY NORTH/SDOTH EA DES/lO0 mEET F 0.67 3807.82 N 347 9.47 3862.03 N 352 1.07 3~15.75 N 357 2.55 3967.92 N 362 1.95 %016.79 N 368 0.89 ~363.~9 N 373 0.95 %110.15 N 379 1.2% ~157.38 N 385 5.88 ~204.¢0 ~ 391 0.03 ~Z50.91 q 397 0.00 %Z97.4~ ~ 403 9000.00 6325.~4 5195.4~ 50 10 N 52 %2 E 5897.92 FT 3RDIIITES H]RIZ. DEPARTURE ST/WEST DIST. &ZIMUTH EET FE:T DE3 MIN 0.~9 E 5152.07 N 42 20 E 1.78 E 5226.68 ~ 42 21 E 3 49 E 5301 22 6.25 E 5375.32 1.SD E 5~48.7~ N 42 30 E 9.08 E 5522.02 N ~2 37 E 7.75 E 5596.10 ~ ~Z ~4,.= ?.52 E 5746.65 N 8.62 E 582'2.34 N 43 6 E g.72 E 5898.08 ~ 43 13 E 4~C0 ~L~$KA, I~C. NgRTH SLD~E,~L~SKA COMPUTATION DATE: 6-FE~-85 DaTE O~ SURVEY: 17-J~N-85 KELLY 6USHING ELEV&TION: 129.00 ENGINEER: 3EJTLER ~T ME~.S DE INTerPOLaTED V~LUES FOR TRUE SJ3-SE& URED VERTICAL VERTICAL PTH DEPTq DEPTH 0 1000 20~0 3000 4000 5000 6000 ?000 8000 DODO COJRSE ]EVICTION gEG MIN D~G · 00 0.00 -129.00 · 00 99¢.91 865.91 · 00 1877.15 17~8.15 .OD 2557.35 2¢28.35 .00 3195.78 3057.78 · OD ~792.58 3563.68 .DO ~358.50 ~259.50 .OD 5011.92 ~882.92 .DO 5666oB2 5537.82 · 0~ ~325.~4 5196.¢~ 0 0 N D D 13 ~5 N ~3 52 39 31 N ~3 52 49 17 N ~2 ? ~2 26 N ~O 48 53 ~2 N 41 3~ 52 2T N ¢~ 5 49 56 N ~3 27 48 8 N ~3 8 50 10 N 5Z ~ EV'EN lOOO FEET VERTICAL DOGLEG SECTION SEVmRIT¥ FEET DES/lO0 RE'TA NORTH FE 0.00 O.OO 0 58.16 3.3B 43 510.28 2.01 377 12~0.95 0.11 925 2009.32 1.83 1~98 2811.90 0.~9 2105 351~.77 O.ID 2594 ~395.36 0.21 325~ 5151.~1 0.67 3807 5897.92 0.00 ~297 RED DEPT N3UL~R COORDINATES H3RIZ. DEPARTURE /SOdTH E&ST/WEST DIST. aZIMUTH ET FEET FE:T OEG MIN .00 N 0.00 E 0.00 ~1 0 0 E .56 N 38.45 E 5~.lB ~t ,1 21 E .25 N 3,3.62 E 510.30 .q 42 19 E · 72 N 825.?5 E 1241.16 N 41 46 E .29 N 1339.31 E 200~.53 N 41 47 E .36 N 1B64.',5 E 2312.,8 ~ 41 32 E .,2 ~ 24lO.SD E 3515.30 .75 N 2951.42 E 4396.63 ,~ 42 1 ol · 82 N 3470.49 E 5152.07 .4~ N 4039.72 E 5398.08 cID COMPUTATI]N DATE: 6-FE8-85 A~CO ALASKA, I~C. 24-5 N]RTM SLOPE~L~SKA INTERPOLATED VALUES FOR EVEN 100 FEET OF TRUE SJ'B-SE~ CDJRSE VERTICAL DOGLEG ME~SURE] V:RTIC~L VERTI'AL ]EVI~TIDN AZIMUTH SECTION SEVERITY DEPTH DEPTH DEPTH 2EG ~IN DEG MIN FEET DE~/IOD O.OO 0.00 -129.00 0 0 N 0 O E O.O0 0.00 !9.22 29.20 -100.00 0 5 ~ ?O 55 E 0.00 0.68 129.30 129.00 0.00 0 13 S I I W -0.15 D.50 229.30 229.00 lOO.O0 0 13 $ 15 5) E -0.~0 0.15 329.30 329.00 200.00 0 16 S 13 37 ~ -0.63 0.0¢ ~29.30 429.00 300.00 0 14 S 25 36 : -0.85 0.07 529.30 529.00 ~OO.O0 0 ~6 N 68 2~ E -0.80 2.47 $29.38 529.00 500.00 3 24 N ~2 7 E 2.72 Z.2~ 729.?~ ?29.00 600.00 6 14 N 35 37 E 11.05 2.81 830.70 829.00 '70~.00 9 17 N 35 2 E 24.71 2.91 932.4~ 929.00 800.00 11 ~7 N ~2 ~D E ~3.33 2.63 1035.20 1029.00 900.00 14 53 N ~3 2~ E 66.91 3.25 1139.39 1129.00 1000.00 17 ~6 N ~0 20 E 96.12 2.95 12~5.~0 1229.00 1100,00 20 57 N 41 27 E 131.18 3.09 1353.49 1329.00 1200.00 23 24 N 43 50 E 172.18 1.96 1~63.58 1429.00 1300.00 26 9 N 39 ~8 E 218.16 3.15 1576.37 1529.00 1600.00 29 6 N 38 4~ E 270.14 3.3~ 1592.83 1629.00 1500.00 32 21 N ~3 3 E 329.73' 3.53 lB13.0? 1729.00 1600.00 35 17 N 45 30 E 396.42 3.25 · ~ 1~38.05 1829.00 1700.00 38 14 N ~3 4; : 471.33 2.52 2057.85 1929.00 1BO0.O0 40 57 N 43 ID E 55¢.05 2.60 2203.7~ 2029.00 1900.00 44 3 N 42 17 E 645.01 2.35 2346.23 2129.00 2000.00 46 ~8 N 40 31 E 747.45 1.99 2~96.2~ 2229.00 2100.00 49 11 N 39 12 E 859.09 1.48 2549.91 2329.00 2200.00 49 20 N 41 7 E 975.65 2803.58 2429'00 2300.00 49 24 N ~1 35 E 1092.30 0.53 2956.56 2529.00 2400.00. 49 13 N ~2 5 E 1208.05 0.15 3109.95 2629.00 2500.00 49 20 N 42 7 E 1324.37 O.OT 3253.32 2729.00 260~.00 49 15 N ~2 lZ E 1440.63 0.13 3~15.59 2829.00 2700.00 48 34 N 42 2 E 1555.45 0.25 3558.05 2929.00 280~.00 50 17 N 92 11 E 1670.51 3728.~8 3029.00 2900.00 51 59 N 41 3~ E 1795.69 0.63 3890.26 3129.00 3000.00 51 ~3 N 40 59 E 1923.07 0,43 4053.40 3229.00 3100.00 53 20 N ~0 5¢ E 2051.88 1.44 4~22.25 3329.00 3200,00 53 ~2 N 4~ 53 E Z187.87 0.05 4390.98 3429.00 330~.00 53 27 N 40 46 E 2323,69 0.51 4558.29 3529.00 3400.00 53 12 N 40 3~ E 2457.74 0.37 4?24.83 3629.00 350~.00 52 52 N 40 3'1 E 2590.80 0.2~ 4892.04 3729.00 3600.00 53 ~0 N 41 32 E 272~.74 0.20 5051.2D 3829.00 3700.00 53 28 N ~1 19 E 2861.14 0.62 'm~$E 5 DATE DF SURVEY: 17-J~N-85 KELLY BUSHING ELE~ATI3N: 129.00 ENGINEER: BEJTLER FT. SUB-SEA DEPTH RECTAN NORTH/ FEE SULAR CO3RDI~TES H]RIZ. DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH T F=ET FEET OEG MIN . O. O. O. 1. 1. 1. O. 7. O0 N 0.00 E 0.00 N 0 0 E ~1 N O.O1 W 0.01 ~ 31 36 ~ 26 S 0.05 E 0.28 S 13 20 E 51 S 0.07 = 0.61 S 5 12 E 03 S 0.18 ~ 1.05 S ~ 56 E ~.6 S 0.33 E 1.50 S 12 43 E 58 S 0.$~ E 1.~0 S 20 57~,"' 75 N 3.18 E 3.27 ~ 75 41~ 36 N 8.32 E 11.11 N 48 31 = 64 N 15.24 E 24.73 ~ 41 4 E 32. 49. T1. 98. 128 · 162. 203 · 248. 29.5. 349. 95 N 28.18 E 43.36 ~ 49 32 E 97 N 44.51 E 66.92 ~ 41 41 E 58 N 64.05 E 96.13 ~ 41 47 E 54 ~ 86.66 E 131.23 ~ 41 1:9 E 41 N 114.75 E 172.21 N 41 47 E ~0 ~ 1~5.71 E 218.19 N 4~ 5,3 E 28 N 1T8.~T E 270.26 ~ 41 13 E 55 N 216.88 E 329.87 N 41. 6 E 65 N 264.17 E 396.48 N 41 46 E 21 N 315.50 E ~71.36 N 42 11 E %08. 476. 552. $38. 727. 815. 901. )87. 1073. 1158. 98 N 373.79 E 554.06 N 42 25 E 37 N 435.37 E 546.02 N 42 29 E 88 N 503.04 E 747.~ ~ 4Z 17 E 63 N 574.74 E 959.17 ~ 41 59 E 55 N 650.28 E 975.80 N 41 47 E 22 N 727.28 E 1092.~9 N 41 44 E 31 ~ 804.69 E 1208.25 N 41 45~" 59 N 882.70 E 1324.57 H 41 47~ 77 N 960.76 E 1440.~4 ~ 41 49 ~ $6 N 1037.85 E 1555.$7 ~ 41 50 E 1244. 1337. 1432. 1530. 1533. 1736. 1837. 1939. ZD40. 21~2. 46 ~ 1116.76 E 1570.74 N 41 51 E 28 N 1198.75 E 1795.93 q 41 52 E 98 N 1282.89 E 1923.34 N 41 50 E 51 N 1367.15 E 2~52.21 N 41 46 E 25 N 1456.35 E 2188.26 N 41 43 E DS N 1545-21 E 2324.14 N 41 40 E 70 N 1632.75 E 2458.26 N 41 37 E 04 N 1719.17 E 2591.~1 ~ 41 33 E 18 N 1807.08 E 2725.41 ~ 41 31 E 24 N 1897.51 E 2861.~4 ~ 41 32 E A~CO ~LAS;~A,~ I~C. 2~-6 KJPARJK N3~TH SLD~E,AL~.SKA CDMPUTATI3N DATE: INTErPOLaTED VALJES FDR EVEN 100 TRUE SUB-SSA IE~SURE2 VERTICAL VERTICAL DEPTH DEPTM DEPTH 5229.98 3929,00 3800.00 5491.43 4029.00 3900.00 5571.04 4129.00 ¢000.00 5737.49 4229.00 4100.00 5932.Z? 4329.00 ~200.00 6356.47 4429.00 4300.00 6230.11 4529.00 4400.00 6392.22 4629.00 4500.00 6554.98 4?29.00 4600.00 6714.94 4829,00 ~70D.O0 6871.14 4929.00 ~803.00 7026.55 5029.00 4900,00 71~1.53 5129.00 5000.00 7336.1B 522~.00 510D.00 7489.7? 5329°00 5200.00 7542.74 5¢29.00 5300.00 77~4.37 5529.00 5400.00 7943.49 5629,00 5500.00 8393.4~ 5729.00 5600.00 8243.26 5829.00 5700.00 8391.90 5929.00 5800.00 8541,22 5029.00 5900.00 8593.70 6129.00 5000.00 8849,40 5229.00 5100.00 9DDO.DO 5325.44 5195.~ CDJRSE VERTICAL DEVI~TI3~ AZIMUTH SECTION )EG lin DEG Mit FEET 54 5 N 41 47 E 2997.06 54 14 N 42 13 E 3135.28 53 26 N 42 51 E 3273.30 52 48 N 44 14 E 3405.33 52 32 N 44 8 E 3537.26 52 28 N 44 9 E 3657.46 52 4 N 44 17 E 3795.95 51 53 N 43 40 E 3924.51 52 O N 43 18 E 4052.92 50 31 N ~3 59 E 4177.75 49 57 N ~3 41 E 4297.73 49 54 N 43 28 E 4416.70 49 48 N ~3 47 E ~535.03 49 29 N 43 45 E ~653.02 49 17 N 43 29 E 4769.57 48 56 N 43 17 E 4835.32 48 22 N 42 53 E 499~.30 47 ~3 N 42 ~5 E 5109.92 48 18 N 43 42 E 5221.60 47 54 N 45 ? E 5333.18 47 29 N 49 45 E 5442,76 48 31 N 51 Z? E 5552,~9 49 39 N 51 35 E 5665.22 50 10 N 52 42 E 5783.97 50 lO N 52 42 E 5897.92 6-FEB-85 PaGE 5 DATE OF SURVEY: 17-J~N-85 KELLY BUSHING ELEVATION: 1Z~.O0 ENGINEER: BEJTLER F:ET OF SUB-SE& DEPTH DOGLEG RECTANGULAR SEV:RITY N3RTH/SOUTH DEG/IOD FEET C23RD!NATES H2RIZ. EAST/WEST DIST. FEET FE:T 3.55 2244.35 0.28 2347.54 1.63 2449.91 0.27 2544.87 0.19 2538.?3 0.13 2732.24 0.5~ 2925.00 0.33 2916.87 D.79 3010.09 3.84 3100.74 1987.39 E 2997.81 2083.95 E 3137.02 2172.95 E 3274.04 2265.22 E 3~06.99 2355.56 E 3537.84 2447.20 E 3567.~6 2537.63 E 3797.39 2525.15 E 3~24.90 2714.47 E 4053,27 2800.32 E 4178.08 0.42 3187.25 D,38 3273.53 0,28 3359.Z0 9.35 3444.29 0,32 3528.55 0.2~ 3512.73 3.57 3595.87 1.10 3777.11 0.53 3858.45 2.17 3938.56 2883,47 E 4298.02 2965.40 E 4415.96 3047.04 E 4535.27 312~.~0 E 4553.23 3209.25 E 4769.77 3288.82 E 4885.50 3355.78 E 4~99.~7 3441,~5 E 5110.08 3518.37 E 5221.75 3596°00 E 5333.32 2.04 4012.97 0.58 4382.75 1.14 4154.10 D.O0 4227.37 3.OD 4297.44 3677.02 E 5442.83 3763,17 E 5552.51 3853.51 E 5556.22 3947.70 E 5784.02 4039.72 E 5898.08 DEPARTURE ~ZIMUTH DES MIN N 41 31 E ~ 41 33 E N 41 34 E N 41 40 E N 41 45 E ~ 41 50 E N 41 5 z '442 8 E N 42 10 E N 42 12 E ~ 42 15 E N 42 17 E N 42 18 E ,4 42 19 E N 42 20 E N 42 21 E ~ 42 23 E N 42 29 E N 42 4O E N 42 51 E N 43 Z E W 43 13 E ARCO ALASKA, INC. KJ~ARJK NS~TH SLOPE,ALaSKA TOP tOP 3ASE PBTD TO MARKER KUP~RUK S KU~ARUK C KUP~RUK ~ KUP&RUK A COMPUTATI3N INTERPOLATED VALUES FOR qEASJRED DE~TH BELO~ K& 8452.00 8498.00 8580.00 ~798.00 8894.00 9000.OO DATE: 6-FSB-85 CMDSEN HORIZONS :ROM KB 5969.57 5000.34 6054.66 5196.06 5257.55 6325.44 ORIGIN: TVD 159' SJB-SEA 5~40.57 5B71.)4 5925.56 5067.06 512B.56 5196.4¢ P~§E 7 D~TE OF SURVEY: 17-J~N-85 KELLY BUSqING ELEVATI3N: 129.00 ENGINEER: BEJTLER :NL,136' SJRFACE ' 2C&TION' ~T FWL,SEC 3$,TllN,R8E,UM RECTANGULAR COORDINATES NDR~H/SDU'Tq EAST/WEST 4041.15 N 3711.Z5 5052.55 N 3737.92 4100.34 N 3785.95 4203.4? N 3915.31 4258.12 N 3974.95 F9 INC. 24-6 KJPARJK N3RTH SLDPE~L&SKA M~RKER TOP KUP~RUK S SASE KUP~RUK C TOP KUPARUK ~ BASE KUP~ROK ~ mBT3 TD COMPUT~TI3N DATE: MEASJRED DEPTH BELOW KB 8~52.00 8~98.00 8580.00 8798.00 8896.00 g900.O0 6-FEB-B5 ~&GE 8. D~TE 3F SURVEY: I?-J~N-$5 KELLY BUSHING ELEVATION: 129.00 :N$I~EER: BEJTLER ORIGIN= 159' TVD :ROM KB SJB-SEA 5969.57 5B40.57 6000.34 5571.34 6054.66 5925.66 $195.06 5067.06 5257.56 5128.56 $325.~ 5195.44 FNL,136' S FWL JRF ,SE RECT&NG NORTH/ O~l. 052. 100. 223. 2~8. 297. A"E .OCli'ION C 36,Tll~,RBE~,UM UL~R COORDINATES S3UTq E&STYNEST 1~ N 3Tl1.25 55 N 3737.92 $~ N 3785.95 47 N 3916.31 1Z ~ 3974.95 4~ N 4039.?2 F1 FINAL ME~SdRED DEPTH gOOD.OD WELL LgC~TI2N TR~E VERTIC&L DEPTH 5325.44 ~T TD: SJ~-SE~ VERTICAL DEPTH $196.~4 HDRIZONT4L ]EP~RTURE DIST'ANCE ,~ZIMUTq FEET 3EG 5898.08 ~ 43 13 E SCHLUMBEROER. O l~ RECT [ ONAL SURVEY COMPANY ARCO ALASKA INC. 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H'-'f¢--;'"H"ff'--i ..... f-Hq ...... ~...i...~ ...... ~...;..~..¢.. %¢4...i ..... ~.i...~..-i ..... i--.~+-~ .... ~+.~---~-~-,44.-ki-. bi-~-~4--H+f-i ..... ~+H+-~-H+:---~+H--H--H---~.~.+H--H--i+-~--~.- · .+~..-f-.~ ...... ~.-.f.-t--.~ ....... t'T-~"'! ..... ~'t"t'ff .... :::::::::::::::::::::::::::::::::::::: :::~:::i:::~:T ~:::Fi:::~:::~:::~ ::~:~::~:::~:::: ::~qq::~: ~::~i:74::~:~: ::::::::::::::::::::::: q::~:¢q::i:~:i::?~:~:'':''~'-h'-~'''i:~''!'''~''~ ...... !---~-~+i---H---h -2000 - 1000 0 1000 2000 3000 4000 S000 6000 EAST WELL 2H-6 (169 FNL, 136' FWL, S36, TllN, R8E) VERTICAL PROJECTION - 1ooo o --"...'-'~TT'F'.c"r'T'"?."-T'" --.;.--+'--S'-.~ ...... :-'-~"':'"?' ~ : : : · : -T'"Z"'T'"t ..... T"?T"T ..... · ..:-..:...:...: ...... ~ ....... ~...: ..... -~'"+-'+'"~ ..... : . : : ~ , ~ ~ ~ : ~ : : : : --+-+.-¢...~ ...... ~---;-..H ..... · .-~--.~-,-...-~:: . : ...... ~.-.$...;...$::: ..... "'~".~"-;'..;.-. f.-.-;-..;-.-:.--* ............. --.t .--~---?-+-.-* ..-+--.+---+.-.~ ..... -.:...;,..:...;...~...;...:...:...: ...... ...~--.~.-.;-.-~.--f.-++-¢-..+ ..... · "t'"?'?'f ...... t'"f'"~"'~ ..... ...,_,...,...???., "'%'T"T"%'~'"T"T"T"T ..... · "~-+"?-~'-'t-'+--?+"~ ...... -'{'"f"f +-+'-fl'flf"i"' "T"~'";'";"'h;'";'"'"'~ ...... "'~---~'"?-?'~'-'?--* ...... i"- ..+..+..t-.-+ ....... ~ ?-.f'"~..~.'- .+.,--~-~.-~..;- ~.--~-.-~ ...... .+..*...,...,...~...,.-.,...,..4 ...... · .+..~...;.-.;...~...~..-;...;.-.; ...... .... H-.~..¢4-..~.--;-~ ....... · ......4...4.-.&...&...;....L..4...4 ...... .... +--~..-f..-+..-t-...;..-. f ..~ f ...... i ~..~ ; I ~--;~ .... H..-~...H$.?..~.~ ...... .... ?+"T"T"~"':-'"'~ ...... .... t'"?",'"','",'","','",'", ....... '"hi"'~ ....... 1 ......... ~ : ' ~ : ~ ~ .... ~.4.,.+.-.;...~...~-.-~..~ ....... :::::::::::::::::::::::::::::::::: c~...~.4..4., t.4.~.~...;.4 ...... i ~ ....x. ~ L..:..u.~ ...... .... ?-~.q'"~-"!--'f"~'-'?--~ ...... .... T"F'F'~ ....... t r ....... ;"'~ ....... .... f'";'"~'"t ...... ?'~'"? ...... ,-,~...$,..;... :...~...~.,.~...~...~ ....... .. % i...:....i., i..~...!...L.:. ...... .... [..L i-..;...L.i...L.!...~ ...... ,:::i:::;:: .... F'~'"F'~"T"?'T"~ ...... PROJECT,ION ON VERTICRL PLRNE 42. - 222. SCPJ-EO IN VERTICRL DEPTHS HORIZ SCALE = 1/1000 IN/FT RECEIVED FEB 2 8 Al~tka 011 & Gas Cons. Gommlsston Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · ·. ~.£L ~ 'AiqD ~uJiBER- , Reports and Haterials to be received by** /'--~..~ Date · .. Required "D~:e Rece:i~ed Rem~:~s · , · . Hud Log ..... , -Core Chips Cbr~ 'Description ..... . , . . , . . . , . . t Inclination Survey 9 ',-:-',;'- Drill ~}em Test Reports . . ProduCtion Test Reports · L. FJ. 04 ARCO Alaska, Inc. Post Office 50 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells' 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-!9 1H-4 2H-9 3A-16 3F-15 4-24 16-20 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 4 1986 Oil & Gas Cons. (;omm~on ARCO A?esl.:a. Inc. is a Subbed/ar'.-.' of AtlanlicR~chfic!~Compmny STATE OF ALASKA ALASKA O~..,AN D GAS CONSERVATION CON.~tlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling wel~(~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-169 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-200#4 4. Location of Well at surface 169' FNL, 136' FWL, Sec.36, T11N, R8E, UM (approx) 5. Elevationinfeet(indicate KB, DF, etc.) 129' RKB 6. Lease Designationand SerialNo. ADL 25587 ALK 2673 9. Unitor Lease Name Kuparuk River Unit 10. Well No. 2H-6 11. Field and Pool Kuparuk River Fi eld Kuparuk River 0il Pool For the Month of. December ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1330 hrs, 12/20/85. Drld 12-1/4" hole to 3390'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 9000'TD (12/27/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 8894'. Secured well & RR ~ 2200 hrs', 12/29/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, Weld conductor set @ 111'. Cmtd w/195 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3368'. Cmtd w/1000 sx CS Iil & 400 sx CS I!. Top job performed w/110 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 8981'. Cmtd w/450 sx. Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/9000' - 3368'; GR to 2300' FDC/CNL f/9000' - 8250' Cal f/9000' - 3368' RECEIVED JAN 1 ~ 1986 6. DST data, perforating data, shows of H2S, miscellaneous data None Alaska 0il & Gas Cons. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Associ ate Engi neet J-t4--~t.~ SIGNED _ TITLE DATE NOTE--Report or'this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP3/MR19 Submit in duplicate Post Office Box · Anchorage, AI~ 99510 Telephone 907 ~7"7 5637 RETURN TO: Date: 01-07-86 Transmittal No :5504 · ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. BOX 100360 'Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge re6eipt and return one signed copy of. this transmittal. Open Hole LIS Tapes ,Plus Listingsr-One copy of each Schl - '"',..~.H- 6 12-28-85 Run #1 2300.0-9016.0-"-~d~, 3A-16 12-26-85 Run #1 1890.0-9142~0--~.~_~/ -~ --~/)~/~-- /~ -~/~ '3F-13 12-19-85 Run ~1 1688.5-8112.0~0~3~ -3-6pe~- /~--~//~. 3F-14 12-2,1-85 Run ~1 1700 0-6966 - ~ AlaS. Oil & Ga.':~ Cons. Con]mission Anchora,3e Receipt Acknowledged: -'B. Currier BPAE Chevron D &M DISTRIBUTION Drilling Geolog~L.Johnston Mobil NSK Drill Clerk W. Pasher Exxon Phil~ios Oil -- · J. Rathmell Date: $ohX~ Union K. Tulin/¥ault ARCO Alaska, Inc. Post Office Bo~"-t'00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 2H Pad Wells 5-8 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L23 Enclosure If RECEIVED AUG 0 ;1985 Alaska Oil & Gas Cons. Commissio. Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanflcRichfieldCompany ~ 0 ~0 ?o 013 014 016 OI 04 DRILL SI1'~' 2-H CONDUCTORS AS. BUILT LOC, ATIONS WELL 5 Y= 5,9~8,693.29 LAT= 70°16'I5.795~,, X= ~§8,594.98 LONG= I50°00'~0.907'' ]69' FNL, ]96' FWL, 93.0'05, 98.8' P49 WELL 6 Y: 5,948,693.32 LAT= 70°16' 15.7955'' X= 498,534.96 LONG: 150°00'a3.5~5'' 169' FNL, 136~ .FWL, 93.00G, 98.8 PA9 WELL 7 Y= 5,9a8,6 X: ~98,~ 169' FNL, WELL 8 Y= 5,9~8,6 X= ~98,4 169' FNL, 93.27 LAF= 70°16'15.7950' 74.97 LONG= 150°O0'~.aOl'' 76' FWL, 92.30G, 98.8 P~O 93.2~ LAT= 70°16'15.7946'' l~.g8 LONG= 150°00'~6.1~8'' 16' FWL, 91.5'0G,98.8' PAD L 0 C ATE D IN SECTION 36 TII N, R8E~ UMIAT MERIDIAN. RECEI E AUG ) o l( B5 Alaska Oil & Gas Co.s Commission Anchorage jZ6 THIS SURVEY 3O t Io.s 2. H 2 I c°l~ 6 i D.S. AB -ERE~)¥ :ERT =Y *'-;," :,¥ .~RCPERLY REGISTERED 5 ~;CENSED TC PRACTICE ~.AND SURvEYiNG iN THE STATE OF ALASKA ~ ~AT THIS P'AT ~EP~ESENTS A SURVEY MADE ~N;E~ MY - ~ECT SU;E~'w S.CN ~ THAT ALL DETA)LS ;~E SCRRECT AS ~= 8SSO .- ARCO Alaska, Inc. ~-.ec' North S;c~e-r::;'ng DRILL SITE Z-H CONDUCTOR AS. BUILT LOCATIONS AUGI6,1985 scale: I"= soo' Draughtsman: MC I)wo. no.:NSK 05-15 July 29, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2H-6 ARCO Alaska, Inc. Permit No. 85-169 Sur. Loc. 169'FNL, 136'FWL, Sec. 36, TllN, R8E, UM. Btmhole Loc. ll15'F~, ll30'FEL, Sec. 25, TllN, R8E, L~. Dear ~. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title ].8, Alaska Administrative Code, Chapter 70) amd by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Enviro~mental Comservatiom. Mr. Jeffrey B. KeWz~ Kuparuk River Unit 2H-6 -2- July 29, !985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advande notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Posl Office Bo~00360 Anchorage, Alaska 99510-0360 'l'elephone 907 276 1215 July 11, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2H-6 Dear Mr. Chatterton: Enclosed are: o An application for Permit to a $100 application fee ° Diagrams showing the proposed projections of the wellbore o A proximity plot ° Diagram and description of the system o Diagram and description We estimate spudding any questions, please Sincerely, Area Dril ling Engineer JBK/TEM/tw PD/L124 Enclosures Drill Kuparuk 2H-6, horizontal and surface hole of the BOP equipment this well on August 25, 1985. call me at 263-4970. al ong wi th vertical diverter If you have ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA · ALASKA AND GAS CONSERVATION CO ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL FX~X lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC~ REDRILL [] DEVELOPMENT OIL[~X SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE)~J~, 2. Name of operator ARCO Alaska~ Inc. ~'~, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface '-- 9. Unit or lease name 169' FNL, 136' FWL, Sec.36, T11N, R8E, UM (Approx.) Kuparuk River Unit ~ '~/~ At top of proposed producing interval 10. Well number 1~13' FNL, 1~06' FEL, Sec.25, T11N, R8E, UN 2H-6 At total depth 11. Field and pool 1115' FIiIL, 1130' FEL~ Sec.25, T11N, R8E, UN ~ . Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Kuparuk River 0i 1 Pool RKB 129', PAD 98' ADL 25587 ALK 2673 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500~000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1115' ~ TD feet 2H-5 well b~b~ ~ 890'TVD feet 16. Proposed depth (MD ~ TVD) 17. Number of acres in lease 18. Approximate spud date 8963~ MD, 6308' TVD feet 2560 08/25/85 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 29~,~, psig@___80°F Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE' ' 50 o (see 20 AAC 25.035 (c) (2) 3370 psig@ ~97{3 ft. TD (TVD) 21 .' Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 2b,' 16" 62.5# H-b,0 Weld 80' 29' L 29' 109! 109' ± 200 cf 12-1/M' 9-5/8" 36.0# J-55 BTC 3~,15' 29' I 29' 3~b,1~ 2780' 825 sx AS III & HF-ERW ~ I ~00 sx Class 8-1/2" 7" 26.0# ,-55/HF-EI'.W BTC 8306' 28' II 28' 833b,'[ 5906' 165 Sx Class G blend 6-1/8" 5" 15.0# K-55 FL~,$ 829' 813~'1~ 5778' 8963'11 6308' 100 sx Class G blend 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8963' kiD (6308' TVD). A 20"~ 2000 psi annular dfverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8' casing will be set through the West Sak sands at approximately 3~b,b,' ND(2780' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be ~nstalled on the 9-5/8" surface pipe. it will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Due to gas injection at 2A Pad, Kuparuk 'C" Sand pressures are presently near 3500 psi (~ 6200'SS TVD) and st~11 increasing. To drill the well safely, 7" casing will be set at 833b,'MD (5906'TVD) (approximately 100' above the 'C' Sand). The 13-5/8", 5000 psi, RSRRA BOPE stack equfpped with 3-1/2" rams will be reinstalled and the rams tested to b,000 psi, the annular to 3000 psi. A 6-1/8" hole will be drilled to TD. A 5" liner wtll be set at TD with a 200' overlap. Expected maximum surface pressure ts 29~,~, ps~. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, (see attached sheet) 23. I hereby cern// that the foregoing is true and correct to the best of my knowledge SIGNED / /.~/~_.~'..~,~.~.~, TITLE Area Drilling Engineer DATE The space.~v~ f(~(~ssiO~s'~''~ CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number []YES ~f-N O I--lyES ~tI~LO [~ES []NOI 50- / O~- '%.o ~ Permit number Approval date ~.;~-¢N~~--, 07/2.~~ 9/85 SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BYY~......~./~f..~ ./~~-~..~. ~.~_ .~--~.A/ ' ,COMMISSIONER DATE ..TI~].. 2(~. '"f '~,__.,~"~*~4~'~' by order of the Commission Form 10-401 (TEN) PD/PD12~, ~ Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL 2H-6 (cont'd) including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 2H-6 will be 44' away from 2H-5 at 890'TVD. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 7434'MD, approximately IO00'MD above the top of the Kuparuk Sands. The 5" liner will be cemented from TD through the liner lap. After WOC, the liner will be cleaned out and the lap tested to 3000 psi. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well may be fracture stimulated. ~\asXs 0~ & G2S Goos. _ ,' .... .PAD ]2H; '"WELL :NO'--."~'~_-': PROPOsED~7_-_ ~ .... ~__ ~ . KUPARUK F~ELD.'--NORTH .... ~---~ . : .............. ~ ....... ~. ~ ~ - . -. . ~ : .... ~ - : ~ ~ .~ : , ' ": ~ ....~ ........;~ ' ~-~-'-T T~-~ - : ,. ,' .... ~ ~ ......... : ...... ~ ........ ~ -~.-;~.-:~-~ , . : ~ . : -~--~ ~ ;- : ...... , . ........................... } ......... ~ ....~ t.... ~ : .... ~ ...... ~: . ~._. ................. ~ ............ · .... ~ ......... ~'.' ~A~ - - ~ .... "-; ........ ~ ' ' ~ ; ~ : ..... . . . ; : i . . ' ~ ............ ~ ........... : --;; '; '~ L:i~;;; .... : ............ ; __.~__ , . ~ ........ ~ : ~ . , ~ i . ~ ~ , : . ...... ~ ........................ BUILD ~ 'DEe--:-~ -~ ......... ? ..... . ........ ~ .............. ....... ;-7---;--- 1000_ L~,S':~; _PELI.~FT ';:-~--:'-~ .... 2~7;~: - ..;~.&~ · ~ ~ . . · , ~ ....... ~ ..... ~2221 ' ; ...... }~-;---~-: .... F .............. ; ................. ~-~ ..... ' .... ~ ............... ; ....... ~ ~. TOP---UGNU .SNDS~-TV.D~1580.JMD 1 648- DEP ' '' ~ ;9 S/8' CS~ PT TVD=2?80 TMD=~444-DEP=1665 m 3000_ > ........... -- ................. ........ &~ ...... : ........ ; ...... : .... ~ .......... : ~_ - ....... ~ ............. ~ ......... : .... ..... ~ ..... : : .... : .... ; ....... : ........... ; ......... ~ ......... ........ ;--O .......... . ......... ::> .... AVERAGE AN~I-~--- .... ~ - ; :__---~-:.'~:'_F_ -__-~:. ....................... ~ ........... -- ".~_ 4000_ 50 DEC 15 MIN .......... ' .............................. . _ : ~..' .... · .~ ..... _ ......... ~ .......... ~ ........... i . , .... -' -'K~S~D~4-5OO~~I~5~EP~ ~ ..... ~ ................ ~ ............ ~ ~000~ ......... : .... 2:2L~~ --:~--~'~-~-~ L ~ 2~! ' - - ' '~ ': ~ ....... .;_ ........ .. ...... ~ _ .......... ~-~-~-.-~--~ .:. ~ -~-~ ........ .. ~. _ ~ ..... ~ ........................ ~ _ .......... ] ............ ; .............. ~ t .......... ~ ~ ......... ~ ...... ........ :~.;- ~ .... ~ . _ ~ ........... . : . ............ ~ ........ : ..... ......... ~"~'-~'-: - ' :?'" CSG PT ---TVD-5906~.-TMD-8~34 DEP=S42~ .....~ ~-- '~ ~ ' -' ;TOP- UPPR SNDS '-TVD-S9?_O_~=84~4sDEP=;SS01- . . ~ _ 000 ---TOP-.LO~R -SNDS .... -TVD-6e42-TM~e~4~----DEP-5588 ............... TARGET CNTR TVD=60T5 TMD=8598. DEP=S628 · __~ ........... i : , ......... BASE KUP-SNDS -: T-VD-6180~TMD=87-63--DEP~5754 , - ............ ~ ' ~ -F ~ ; - , ~D__L(LO~_T~ ~_D~ 6~08~MD 8_96~EP~5908~ ~ ......... ~ .... ~ . ~ . · . ~ ............. . _~' LL'L-. ~ ' ' ........ " ........ ?000 ....... :' '-' ....... ~ ......... ~ ~ ~' ........ ' ...... - i ..... ~ .......... ~ ~ ..... ~._~ .__ ...... ~ .....~, ~ ...... ~ . .; ! ..... , -. . . ; .... i. : :~ --~ ~ _ ~. ? .... ...... ~ ........ '-' O' :':L':_ ' · :"~ ooo':-::~: .: :- ':;L~OOO~L~:,:-_::::'- ~000;::~ ..... 4000 F--.:-.~;S~O00~-~ ::':::-' .......... ........ ...... .... .... ; .... ....... ........ ....... : ..... --- --' ...... ~ ............ ~. :- : -- . ..... ...... ; ........ ~ ............. ~ .- : .-_~ .... . :. ---~ ~ ....... ~ ..... : ..... : ...... ........ ~ ..~ ..... ~ ...... ~ ..... :_~ ~ .... + ..... I ...... :. - . :. ........ ~ ......... _ ......... : . ~ ..... ~ ......... ~ ....... ~- .- ~ ....... __ : .. . ~ -, . ~ - ; - _ ._ _: ..__,.. .................. -._..,LE ..... £__ ' i J -- ' ' ' :' ',' ...... ,: , ~ - ~ . ~ . ._ _.J. ...... . ..... ~_..4 .......... ' .... ' ' ~ 4' ' ' ~ ' I . , I ........ ' _l, ......... ! ...... !._~.~_: .... ..... ARCO ALASKA,'-INC-- ...... PAD 2H, WELL NO 6. PROPOSED-:, -~-:-: i KUPARUK F-IELD,~-NORTH-!SLOPE,-. ALASKA---~~--:-.--~:~ --.-- -i-: ............. ~ ........... : ................. , . · _ ...... ~ ooo_;~ '_: - - -.:o '-- -.-_ :::.'_.-:;_ ._--~_,'. ooo:_::--. ......... ~ ...... ,sooo:: ............ i ............ i ..... . t · : ---' ! .... ! ............... : i . t.320' - FNL:,--!320" ,. , ' -' ......................... t .......... ----~. -- CZ.:_': -- - ..'- ........ · . -,--. --4 .......................................... : . .... ?- .............................. -~ ' - ..... ~ ..... ~ .......................... . . _ -: ..... ~ - . ............... = .............. ~ ...... . , . .... . ....... : .......... · '="'1 ~ 2000__, .... ': ~,ZJ ........................... - ................. - t -- :' ........................ ~ ...... ! ...... · . .~ ............. -~ .............. .............. ~ - _ _ . . _~. ............ ............................................ ~ ............. ~ .......... .... _. ....................... - -] -- ................. ~ - -: ...... ~.-;_.- ........ · - f --1 69"-'FNL-;-~'l~6"--FlIL ' _ . ................. __ · ...................... '-- i:__:SEC._ 36. _T_I]N,_R~E: , : , : ......... . : '~.' ,---~-i --~-'~--~ ~ ...... ....... : ...... ~ .............. , ........ :. , ~. , . _ i . .. ' ' ' . ,47~T 'KUPARUK RI VER UNIT 20" DIVERTER SCHEMATIC DE SCR I PT I ON · I. 16' C~TOR. 2. TANI(O STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER QUICK-C~CT ASSY. 5. TAI~I(O UPPER QUICK-C~CT ASSY. 6. 20" 2000 PSI DRILLING SP(X3L W/I0' OUTLETS. 7. I0" HCR BALL VALVES W/lO' DIVERTER LIFESo VALVES OPEN AUTOMATICALLY UPON CLOSURE ANNULAR PREVENTER. 8. 20" 2000 PSI ANNULAR PREVENTER. 4 3' 2 MA! NTENANCE & OPERAT ! ON. I. UPON INITIAL INSTALLATION,, CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE A~I~ULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE At~'~JLAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLB(3RE FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANUALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHIEVE DOt~NWIND DIVERSION. RECEIVED Do NOT SHUT IN V~LL jUL 17 1,9~SUN[~R ANY CIRCU~TA~ES, _ &l~ R4 7 6 DIAGRAM #1 13-5/8""-'~50Q0 PSI RSRRA BCP STACK I. 16' - 2000 PSI TAM, CO STARTING 2. II" - 3000 PSI CA~IN6 PEAD 3. I1' - 3000 PSI X 13-.%/8' - .~300 PSI SPA~:J~ 4. 13-5/8" - 5000 PSI PIPE 5. 13-5/8' - 5000 PSI DRILLING SPCOL W/GHCKE AhD KILL LI~F_S 6. 13-5/8' - 50(30 PSI DOUBLE RAM W/PIPE RNv~ ON TCP, ?. 13-5/8' - 5000 PSI AN~LLAR ACCtJVtJLATOR CAPACITY TEST I. CHECK At~ FILL A~TOR RESERVOIR TO Pf;a:PER LEVEL WITH HYDRAULIC FLUID. 2. ~ THAT ACCLIVlJLAT~ PRESSURE IS 3000 PSI WITH 1500 PSI D(~TREAM OF THE RE(llATCR. 3. 08SF_RVE TIN[, THEN CLOSE ALL UNITS SI~t. ITA~EOUSLY AhD RE(~ THE TIN~ AhD PR~ REi~AINING AFTER ALL UNITS ARE CLO~ WITH Q-~ING PL~ OFF. 4. RE(~ ON NADC REPC~T, TH~ AC~TABLE L(~ LIMIT IS qS ,~(~ CLO~ING TIN~ AhD ~200 PSI RE~ININO PRES,.~. 5 4 2 13-5/8" BCP STACK TEST 1, FILL BCP STACK ~ CHOKE MANIFCLD WITH ARCTIC DIESEL. 2. (]-IECK THAT ALL LOQ< ~ ~ IN WELLHEAD ARE FULLY RETRACTED. SF_AT TEST PLUG IN WELLHEAD WITH RUNqlNG JT mN:) RUN IN LO(~ S~. LIhE VALVES ADJACENT TO BOP STAQ(. ALL OIl-ER VALVES A~D CHCI(E,S SHOULD BE OPEN. 4. PRESSURE UP TO 250 PSI AI~D HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI AhD HOLD FOR I0 MIN. BLFFr) PRESSURE TO 0 PSI. 5. OPEN AMqULAR PREVENTER AhD MANUAL KILL AhD Q-K]KE LIhE VALVES. CLOSE TOP PIPE RAMS At~) HOR VALVES ON KILL AhD CHOKE LIhES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. ?. CONTINUE TESTING ALL VALVES, LIhES, A~D Q-K]KES WITH A 250 PSI LCW AbE) 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRE.q-~ TEST ANY ~ THAT IS NOT A FULL CLOSING POSITIVE SEAL Q-E]KE. ON_Y F-UNCTION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS AhD CLOSE Boq-rcM PIPE RAMS. TEST BOTTcM PIPE RAMS TO 250 PSI ~ 3000 PSI. 9. OPEN BOTTcM PIPE RAMS, BACK OUT RUMqING JT PiLL OUT OF HOLE. I0. CLOSE BLIhD RAMS AbE) TEST TO 250 PSI AhD 3000 PSI. II. OPEN BLIhD RAMS AhD RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AhD LIhES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAhDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AbE) INSIDE BOP TO 250 PSI AhD 3000 PSI. 13. RECCRD TEST IM=(]~VATION ON BLOWOUT PREVENTER TEST FORM, SIGN, AbE) SEhD TO DRILLING SUPERVISOR. !~, E C ~ iV Eg PERFDRM CQvlM_ETE BOPE TEST AFTER NIPPLING UP , WEEKLY THEREAFTER FUNCTI~LLY OPERATE BOPE DAILY. ~.!-, _.:! 510084 2 MAY 15,1985 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee./,~..--. ... 7'~/'~-~'~'-· Loc (5 thr'u 8) . . 3. 4. 5. 6. 7. (8) (3) Admin .~;/,f,,--~' 12) 10. (10 and 1 12. Company (4) C asg (13 t~'ru/21~ (22 thru/ 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. Lease & Well No. (6) Add: YES NO ,, ~ Is the permit fee attached ............... ' ........... ............. ./~. Is well to be located in a defined pool ..~ ................ Is well located proper distance from property line ........ Is well located proper distance from other wells ......... Is sufficient undedicated acreage available in this pool ' . . Is well to be deviated and is wellbore plat included .... Is operator the only affected party ................................. Can permit be approved before ten-day wait ........................ REMARKS Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Is conductor string provided ............................. .~ Is enough cement used to circulate ~.n co~u~;~; and ;u;f;ce ..i .... Will cement tie in surface and intermediate or production strings .,. Will cement cover all known productive horizons .. ' .............. ',~ zone, .... ii .... ii... i .... Will all casing .give adequate safety in collapse, tension and burst.. ~ Is this well to'be kicked off from an existing wellbore ............. ,, ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~. 22. Is a diverter system required .......... , ............ 23. Are necessary diagrams of diverter a;~ {~{'equip;e~t at;a~;~ 24. Does BOPE have sufficient pressure rating , Test to . .---~ .... psig ..~z~ 25. Does the choke manifold comply w/API RP-53 '(Feb. 78) ...... 26. Is the presence of H2S gas probable ................................. 7~ ~/~~' 27 Additional requirements _ Ad d i.t iona 1 Remarks :._~~...~.:. o H 0 Geology: JAL ~ Eng~n_eering: MTM ~ ,HJH ~-/~. rev: 03/13/85 6.011 INITIAL GEOi'. UNIT ON/OFF POOL CLASS STATUS AREA NO. ,' SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. · ----SCHLUMBBRGER .... ~ LIS TAPE VERIFICATION LISTIi'4G bVP 010,,~02 VEi'RIF!CATIO~,.i [.IS'I'iNG .PAGE SERVICE N Ag~.E : ~]{)IT )ATE :86101/ 3 ]RIGIN ; ~EEL, ~',~AME: :142636 %()MME~TS :LIBRARY TAPE 5~%RV ICE NAME :EDIT 3ATE :86/01/ 3 ]RI~IN ~APE NAME .~ONT INUAT'ION '~ ~REvIr]us TAPE .~OM~gNTS :LIBRARY TAPE ~* FII, E HEADER ** ~Ibg N"AME ;EDIT ,001 SERVICE N At~E ~ERSION ~ ~AXIMU~ LENGTH : 1024 ~REVIODS FILE ~* INFOR~!ATION RECORDS 2N : ARCO At, ASKA, INC, ~'~ : K [!PARUK RIVER RANG: SECT: 36 ~OUN: NORTH ~T.~T: ~LASKA PRES: E UNIT TYPE CATE SiZE CODE 000 000 018 065 000 000 004 0~5 o00 000 014 065 000 000 002 065 000 000 004 0~5 DO0 000 002 065 000 000 012 065 000 000 006 065 U~IT TYPE CATE SIZE CODE mmmm mmmm mmm~ mm~ N~m 000 000 00! 065 ~ V P 0 1 0, H 0 2 v ~: ~{ I F I C A ~ I O ~',,~ b 1 S T I t~ G P A GE 2 ~C !,'~ L, [~ ~,~ [....[., IR(,[}, R Al,ASK& COMPUTING CENTER ************************************************************************************** ~ELL : ~IEI, D = ~dPARUK 20UNTY = NORTH SLDPE BOROUGH ST~T~: = al.,~SKh. JOb p~u;~gER AT ACC; 7.t126 RUN ~.~ DATE Lf]GGEiD~ 2a DEC lg85 2ASING gI$COSI rY PH fLUID LOSS '= 9.625" fa 3368.t.~' - +~IT SIZE = 8.5" 1'0 9000,0' = LSNO = 10,60 .,,.,~/G RM = 3,020 (~. 68,0 DF = ~.o ~ ~' = ~.o~s ~ ~.~ ~ = q,O R~iC = 2,87 DF = 5,0 C3 R~ AT B~T = 1,57] ~ I]~ DF ~,ATPIX = ,)AND ]VP OlO,,l~tP2 ¥~]~',IFIChTIC}!~ I~ISTiii!C PAGE * ~C~bUb~BERGER bOGS I~CbSDED WiTH THIS MAGNETIC TAPE: * * DUAh INDUCTI(])~t SF~JERICAIi~I,,Y FOCU~EO bOG (DI~) * DAT~ AVATbABL~:: 90:16,0 TO 2300,0 ~ ~"Ot~4~T~[[]~ DENSITY CO~PENSATED LOG [FON) * COMPENSATED NEUTRON bOG (FDIC') ~ DATA AV~,~[,ABbM~ 8991,0' TO ~000,0' DATA FORMAT RECORD ** TYPE SIZE ~' E M .R CODE ENTRY 2 1 66 0 4 1. 66 8 4 73 60 9 4 65 ,1 IN 16 1 66 0 I 66 0 ~EM SERVICE SERVICe:: U~II gP_,I gPI AP1 ~PI Fl, bE SIZE SPb R~PR PROCESS ID ORDER ~ .hO=(' ~YDE Cl.,ASS HOD ~0. CODE (OCTAL) )EPT FT ()0 000 O0 0 0 4 I 68 00000000000000 5FLU OIL 0}~~ OD 220 Ol 0 0 4 1 68 00000000000000 ILD Dill, O ~ M ~ O0 120 46 0 0 4 1 68 00000000000000 lbt*J OIL OE.~,~" OD J20 44 0 0 4 1 68 00000000000000 5P DIb :~V O0 OlO Ol 0 0 4 1 60 00000000000000 ...... ~ ,. ) ~) gR :"~I~ (.,i~ [ 0 310 O1 0 0 4 1 68 00000000000000 (;AP1 O0 310 01 0 G/C3 O0 350 02 0 G/C3 00 356 Ol 0 O0 42O Oi 0 oO 000 O0 0 PU O0 ~90 Oo 0 C P S 0 o 330 .] 1 0 CPS O0 330 30 0 G~PI oo 310 Ol 0 i 68 000000~000000~ 1 68 0000o0 000000 1 68 00000000000000 I 68 00000000000000 I 68 O00000§~O00~U , oooooo , oooooooooooooo , oooooooooooooo oooooooooooooo , oooooooooooooo ~* ~ATA ~IPH 1 )~PT ~P ~.PH I )EPT ~tPHI )EPT 3P ~0~ 3P 'J P H T 3 E P 'r ~PH, 1 33 9375 '999 25(.)0 -999,2500 · 00 (.) 0 9000, .. '247 , 9375 2,1~87 42,089~ 8900 0000 -259,~59~ 2,4:534 45,752{) US00 0000 -430,3594 2,51,00 43,~7"7 8700,0000 '454 6094 2'~3518 30.4199 -6]1,6875 2,4397 27'6355 500 OOOo 2,4553 -494 45.6(355 NCNL ~ C N 1,., SFLU GR .dCN L S~LI) GR DRHO N C N L S F L 0 D ~. H [) ~'J C N [., SFL~* DRHO NCNb GR SFb(J GR 0 R H 0 3 1 O6 -999 -999 3 I O2 0 ~.085 0 1716 2 1,04 0 20al 9 82 0 2531 12 76 0 2511 5~ 0, 2339. 1.685, ,8518 500 2500 7366 1523 1 ~0'? 50OO ,3577 ,5273 ,147o ,6875 ,5334 .1523 0562 '5OHO ,7363 .1523 0254 5 (')00 .7285 898 '<~371. ,5000 lbo GR 999, O0 CALI -999, NRAT "999'2500 RNRA -999,2500 FC. NL -999,2500 GR -999,2500 I GR NRAT F C N b 1 L, D FCN L 102, 99' 480, 3 104, ], 583, 355~ 152] 3069 3125 0745 527~ 7834 097q 1523 6155 3125 3,5354 RNRA 3010 GR .,999'~500 Ih~ ] 2874 CAbI 1]:2520 RNRA ,5702.5 GR '999,25 0 3,0530 RNRA 56 GR '999,2500 ILO 10 8535 IbM 10,~895 GR 82:1523 CANI 9,~,~85 NRAT 2:8284 RNRA 2,6545 FCNL 952. 8125 GR -999,2500 IbD 7,4968 IbM 9,392b G~ 7b,5898 CALl 9,0879 NRAT 2,6350 RNRA 2,5784 FCNL 973,8~25 GR ~999,2500 5476 ILO 75 5~98 ..,R 8. ,4148 ibM 5 6687 ~ ,5898 CAhI 9 4707 0322 NRAT $ 0823 RNRA 2 8069 5000 FC~L 832~8125 GR -999,2500 5870 714~ 6877 040(> I L 0 F C N b 72U8 7148 0264 6875 · 123. 3. 467, IbM 1,70t2 CALl 9,1816 RNR~ 3,6038 GR -999,2500 DEPT 8200 o0oo I~DHI -999 2500 3 194 -999 - 999 9EPT 7900 0000 SFLU SP -,5'72 J.[]75 GR RHOB -999 2500 DRHO NPHT -999 2500 NCNL 3 228 -999 -999 2 -99 -999 O~PT 7800, OO00 SFLU 4 SP -662,6875 GR 106 RHOB -999,2500 DRH,.. -999 NPHI -999,2500 NCN [,, -999 DEPT 7700 OO00 SFLU ~P -661:1875 GR 101 RHOB -999,2500 DRHCi -999 NPHI -999,2500 NC~[ .... 999 DEPT ~00 CO00 S FI.,~ 5 SP -637:6~75 GR 111 R~O~ -999.2500 DRHO -999 NPHI -999,2500 ~CNL -999 DEPT 7500,0000 SFI.,0 2 SP '634,6875 GR 1t7 RhOB 999 2500 DRHLI -999 NPi~I :999: 2500 NCi~b -999 DEPT 7400,0909 SFI, U 3 SP -581,6~75 GR 112 R~O~ -999,25uo r~ -999 NPHI -999.2500 NChL '999 DEPT Z3oo 0000 SFLU SP -59b: 1875 GR 121 ~Ot~' '999,250(' D"HO '999 H! '999,~500 NCNb -999 ,3459 375 ,O313 t!{ 75 :!, 663 ,8125 , 0 6702 '0625 :2500 , ~500 ,5764 , 0 i) ,250.O ,445b 875 1500 2600 325o ,1523 ,2500 ,2500 P233 , 2773 2500 * 2500 6062 9648 2500 2500 4260 ,6523 ,2500 ,2500 ,7620 ~0273 2500 ,2500 ;21. 17 2i4a .2500 ,2500 I h L) GR ? C ~'i L t,,)R AT I I,D G R NRAT FCNL ILO GR NRAT FCNL ILO GR NRAT 2,~.448 133, 3'75 3,~374 536..125 3 .2307 194 8125 -999 2500 -999 2500 ALI R NRA GR lb~ CALl RNRA GR 2 5237 IbM 220 0625 CibI -999 2500 RNRA -999 2500 GR 3,2581. I'L~ 2~B,6875 CAbI -999,2500 RNRA -999,2500 GR 2 2561, 1 52 1~75 -99 9 ,25'00 9 9 25O0 IbM RNRA GR , 6531 tO ,1523 CAL.I :999,2500 RNRA 999,2500 GR 3 5275 ILM 101' C'' ,27't3 ..aLI -999,2500 RNRA -999.2500 GR 4 2742 IbM 1.11,9645 CALl -999,250r) RNBA -999,~500 GR 2 4163 ILM 11.716523 CALI -999 2500 RNRA -999 2500 GR 3,4846 ~2,0273 CALI m999.2500 R~RA '999,2500 GR 3,9143 121.214~ C~LI -999,2500 RNRA -999,250n GR 5374 -99 2500 3 0354 10 5332 -999 2500 -9'99 2500 ,,999',2500 -999,2500 .5! o 3'2§~j6 2 oo 99 2500 2,$674 10,0723 '999,2500 '999,2500 4,6765 0 '999:500 11, 98 -999'2500 -999,2500 4,3796 9,54'98 -999e2500 -999,2500 2,5042 10,0488 -999,2500 -999,2500 3,6213 1~,8066 '99 ,2500 '999,2500 1,0125 i0,6973 :~99.2500 99.2500 .,VP 0!.0,Pi02 VERIF,[CATI'O.~ [,ISTI.~G PAGE 6 '7200, O001J SF[JU -600,6B75 GR -9q9,250~ DRHO -999,2500 NCNb ) E P T 6900,0000 ,, [- ...~ u ~P -622,~87b GR ~,gOB -999, 500 DRMO ~PNI -999,2500 NCNL )E]PT 6800,0000 SFLU SP -621,1.875 GR {MOB -999,2500 DRH'C qPHI -999,25{10 NCNL )EPT 6700. 0000 SFI,U ~P 603.6~J75 GR t!'.{OB '-999.2500 D~FtO ~lPHI -099. 2500 ~CN[, )~:PT a600 0000 ~P -552:1§75 GR { H. rl 6 ., 999,2500 D R ~PHi -999.2.500 NCNb '[~ T . .) ~ P 6500, () t) 00 S F b U 5P 535 6'[t75 Ga . 999,2500 DRHO ~t P Fl 1. -q99,25 (,)0 MCNT, .)Epm 6400,t)000 SFI.~U 5P . 593,1875 RH(:,[3 "-999.2500 ~PMI -099.2500 NCNL ]EPT 300.0000 SFLU ~P ~567.1875 GR R~OB 999,2500 DRHO ~) ~: .P- T {',200 0000 SFL t,l SP -550:1875 GR 13 2229 'I 98 5273 GR -999 250 ("} -999 2500 1. 0 3 R 3,464~ GR 1'0l'2500 -999, '~RAT ,2 ,., 0() '999 ~; "' 3, q 045 I I... D 94,9648 G R -909,2500 -999.2500 FCNL 2.7502 t.[tD 107,4648 GR -999,~500 999, 500 F C i'~ l., 3 64;28 II.,D ~ 3,1.9375 ' 999,2500 tq R A 'r '999.2500 FCNL 4,9304 7773 G~ 112'2500 ~ ~ a',r -999, -909.2500 FCI~ L, 3,7639 .II.O 175,~!25 (;R -999.2500 ~qAT -999,2500 FCMb !,8819 I[.,D 122,214~ G~ - 2500 NRAT 999, c~. .... 8 1.035 ILO 198' 999,0625 GR - 2500 -999'2500 ~CNI, ! 4962 ILD 118i2773 GR -999 2500 -999,2500 FCNL b 5a37 II,f) 0.0 0 24 ~',~ R A T 3,3459 II.,M 98'5273 CAI~I :999,2500 RNRA 999,~500 GR 2 8381 IbM, 1. o1~4648 CALl -999,2500 RNRA -999.2500 GR 2 9827 94 9648 -999 2500 -999 2500 CAbI ANRA GR ,8850 IbM 10 ,4648 CA[,I '99~,.2500 RNRA -99 ,2500 GR 3 7795 13! 9375 CAbI -999 2500 RNRA -999 2500 GR 3,7444 1l~,7773 CALI -99 ,2500 RNRA -999,2500 GR 3 4924 1[.,~ 175,8125 CAbI -999.2500 RNRA -999,2500 GR 2 0315 iL~ 12212148 CAb.I -999 2500 RNRA -999 2500 GR 7.1570 IL~ 198 0625 CALI -999i2509 -999 2500 GR ! 7559 ILM 11~,2773 CALI -999,2500 RNRA -999.250o GR 4 5906 Ib~ 198i8125 CAbI 3 1,077 RNRA 3,4280 .9~9 4785 999 ,2500 ,2500 2,29084 '99 2'500 -99:2500 3,07'64 .9~90'0020 2500 -999',~500 I , 363 '999,2500 ,.999,2500 -999,25 0 '999,2~00 ,, 11I 2 -999, O0 3,6213 10,8145 -999,2500 -999,2500 2,0237 10,6816 '999,2500 '999,2500 7,9539 10,5488 -999,2500 -999,~500 1,7930 10,4395 -999,~500 -999,2500 5,0984 10,6035 3,0745 . ',..10.,, [.ISTI{~[; PAGE 7 ~'~{PH I 32,9102 r~CNL DEPT 6100, t3<)00 S FI.,:U SP -56~ 6875 RgOB ~,: 3596 ~i BH I' 39,7461 NCNL DEPT 5900,0000 SFLU SP -580,].~75 GR MOB -999,2500 DRHO PHI -999.2500 NCNL OEPT 5800,0000 SFLU SP -567,1.875 GR RHOB -999,~.()0 DRHO ~ P H I - 999, () 0 N C N L, 2231 2 ~.10 0 2207 3 11.4 -999 -999 3 108 -999 -999 2 117 -999 -999 DEPT 5700 0000 SFLU 3 SP -565:.6875 GR 94 RffOB -999 ~500 DRHO -999 NPHI -999:500 !~CNb -999 9EPY 560(:) OOUO SFLLi SP -567' RqOB .999,1875 GR · , ,2!300 D.RHO NPHI -999,2500 NCNb DE,PT 5500 0o00 SFbU SP -575,1~75 GR OB -999,2500 ~ PHI -999.2500 NCNL DMPT 5400 0000 SFLU $~ -575i6875 GR R~Oq -999 250() DRHO NPHi -999 2500 NCNb 0000 SFLU 1~75 Ge 2500 DRHO 2500 ~CNb O~PT 5300 SP -572 RHOB -999 NPHI -999 OEPT 5200 0000 SFLU S? 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T ,,999,2500 NRa -999,2500 FCNL -999,~500 -999,2500 GR -999 ~ 2500 NRAT -999,2500 FCNL -999~:i5(10 ILO .,999 500 GR -999 500 -999 500 FCNb -999,2500 iLD -999,2500 GR "999,2500 NRAT -999,2500 FCt~L -999,2500 i [..,D -999~2500 GR -999,2500 NRAT -999,2500 FCNL -999 2500 lbo -999:2500 -999,2500 NRAT -999,2500 FCNL -999 2500 IL9 -999,2500 GR -gq9,25()() NRAT -999,2500 FCNL ** FII,E TRAILEP ** FILE NA~E :EDIT .001 VERSION ~AXIMUM LENGTH ~ 1024 FTLE TY~E :~EXT WILE i.~A~E : EOF ** 'I'A[:R T{AT, bER .** -9~9,2500 IbM -9. ii2500 CALl -99 2500 GR -999,2500 IbM '999,2500 C~bI '9999,~500 RNR~ '99 , 500 GR '999,2500 ILM -99~!2500.99 , CAI,I -99 ~500 RNRA 500 GR -999,2500 -999,2500 CAb! -999,2500 RNRA -999'2500 GR ~999,2500 IbM 999,2500 CALl -999,,2:500 R:NRA -999,2500 GR -999 250O -999 250.0 -999 2500 -999 2500 IbM CALl RNRA GR -g99 2500 Ib~ -999'2500 CAI, I -999,2500 RNRA -999,2500 GR -999,2500 -999,2500 CALI '999,2500 RN~A '999,2500 GR - .Zsoo '99 ,2500 -999'25:00 65,7773 '999 2500 '9:99 2500 '999 2500 6~ 01~7 :999. 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