Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
185-270
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned'during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. / ~--~_/~_~ Well History File Identifier Organization (done) ~'~wo-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: D Diskettes, No. D Ma ps: [] Grayscale items: [] Poor Quality Originals: Other: Other, No/Type TOTAL PAGES: ORGANIZED BY: BEVERLY BEEN VINCENT SHERYL MARIA LOWELL [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing PROOFED BY: BEVERLY By: Date: BEEN VINCENT SHERYL MARIA LOWELL SCANNED BY~REN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BEEN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: PAG ES: Quality Checked (done) Rev1NOTScanned,v4xl STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair w ell ❑ Plug F rforations ❑ Stimulate ❑ Other G wtr chem Pull Tubing Perforate New Pool Waiver treatment Alter Casing ❑ 9 G [.! ❑ Time Extension ❑ Change Approved Rogram ❑ Operat. Shutdow n C Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory ❑ _ ' 185 -270 3. Address: 6. API Number: Stratigraphic ❑ Service ❑ P. O. Box 100360, Anchorage, Alaska 99510 f' 50 - 029 - 21480 - r 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL -25632 and ADL -25643 - 3F - 9. Field /Pool(s): e Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7785 feet Plugs (measured) None true vertical 6237 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6364, 6401, 7169 true vertical 0 feet (true vertucal) 5120, 5148, 5743 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3372 9.625 3414 3000 PRODUCTION 7103 5.5 7138 5719 PRODUCTION 7568 7 7603 6092 g L-e-- Perforation depth: Measured depth: 7,252.0 7,343.0; 7,424.0 7,454.0 True Vertical Depth: 5,809.8 - 5,883.3; 5,948.4 - 5,972.4 1 Qd fr. 6 �1 Tubing (size, grade, MD, and TVD) 3.5, J - 55, 7407 MD, 5934 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 6364 MD and 5120 TVD PACKER - LOWER WEATHERFORD ER PACKER @ 6401 MD and 5148 TVD PACKER - OTIS RRH PACKER @ 7169 MD and 5743 TVD 11. Stimulation or cement squeeze summary: 1 0 ^ J Intervals treated (measured): 7,252.0- 7,343.0; 7,424.0 - 7,454.0 !(' , 2.I/ Treatment descriptions including volumes used and final pressure: Pumped HES fullbore WaterWeb treatment. Injected a total of 786 bbl of WaterWeb, 385 bbl seawater flush and 65 bbl of diesel freeze protect. Average treatment pressure and rate was 2.0 bpm @ 1078 psi. 12. Representative Daily Average Production or Injection Data Oil - Bbl , Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 4/19/11 3 174 4783 165 Subsequent to operation 12/24/11 6 4 3712 168 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development M - Service ❑ Stratigraphic ❑ 15. Well Status after work: Oil G Gas ❑ WDSPL ❑ Daily Report of Well Operations GSTOR r WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: - None - Contact Mark Kovar Printed Name Mark Kovar Title Petroleum Engineer 7 ,� / Signature / ^� Phone: 265 -6097 Date / — / G / 2 Form 10-404 Revised 10/ L " i MS JAN 1 8 1011 /. f Q.-, Sub �i ri i al Only KUP 3F -09 ConocoPhillips eil Attributes ax Angle & MD TD no Ill , We API /UWI Field Name Well Status Inc' ( °) MD (ftKB) Act Wm (ftKB) CQ10W Ph e kp9 5 00292148000 KUPARUK RIVER UNIT PROD 47.02 5,100.00 7,785.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: NIPPLE 100 11/29/2009 Last WO: 7/8/2005 41.79 11/18/1985 Well Cone, -3F -094/30/20117.45.36 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,463.0 4/14/2011 Rev Reason: PATCH UPDATE Imosbor 4/30/2011 HANGER, 35 Casing Strings p Casing Description String 0... String ID .. Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED _" i, , I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt.. String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,413.5 2,999.8 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (6... Set Depth (TVD) ... String Wt.. String ... String Top Thrd III PRODUCTION 7 6.151 35.0 7,603.2 6,091.9 26.00 J - 55 BUTT ar Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 35.0 7,138.0 5,718.5 15.50 L-80 HYDRIL coNOUCroR. _ SCAB LINER 38 -115 5.5 "x3.5" NIPPLE. 471 S" Liner Details ■■ ■ ■■ Top Depth (TVD) Top Intl Nom'... ;� I Top (ftKB) (RKB) (°) Item Description Comment ID (in) 7 5,645.9 37.87 SBE BAKER 80 -40 SEAL BORE EXTENSION 4.000 GAS LIFT, 7,066.7 5,661.8 37.68 X0 Reducing CROSSOVER 5.5 x 3.5 ", ID 2.992, 9.38, L -80, EUE 3.500 2,944 Mt 7,079.4 5,671.8 37.56 PACKER BAKER PREMIER PACKER 2.875 7,129.0 5,711.3 37.08 NIPPLE HESXNIPPLE 2.813 7,136.5 5,717.3 37.01 OVERSHOT BAKER POORBOY OVERSHOT 2.935 Tubing Strings SURFACE. 4 ■ Tubing Description Str ng 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt... String ... String Top Thrd 37 - 3,414 TUBING WO 3 1/2 2.992 I 35.0 7,037.2 I 5,638.6 I 9.30 L -80 IBT MOD GAS LIFT, O Completion Details 4895 Top Depth _ (TVD) Top Intl Noml... - Top (ftKB) (ftKB) (°) Item Description Comment ID (In) 35.0 35.0 0.23 HANGER FMC 5M TUBING HANGER 3.500 MN GAS LIFT, 471.0 471.0 0.19 NIPPLE CAMCO DS LANDING NIPPLE 2.875 5'747 7,014.3 5,620.8 38.17 NIPPLE CAMCO DS NIPPLE 2.813 7,021.9 5,626.6 38.10 SEAL ASSY BAKER CSR SEAL ASSEMBLY 3.850 ilr PACKER, 6,364 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PATCH, 8,387 1 1 TUBING ORIGINAL I 31/2 !String I 7,138.0 I 7,407.2 I 5,935.0 I 9.30 I J -55 I BUTT PACKER, 6,401 -. Completion Details le 1 Top Depth + (ND) Top Inc' Norni... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) GAS LIFT 7,151.5 5,729.3 36.87 SBR OTIS SBR 3.000 6,415 A. I 7,168.6 5,742.9 36.71 PACKER OTIS RRH PACKER 2.970 7,243.5 5,803.0 35.92 BLAST RINGS BLAST JOINTS 2.992 665 L Or 7,3732 5,907.6 36.58 NIPPLE IAVA BPL w/SLEEVE (OPEN 4/4/2011) 2.750 6'96' t 7,376.1 5,909.9 36.60 XO Reducing CROSSOVER 3.5 x 2.875" ID 1.995" 2.875 f 7,382.3 5,914.9 36.63 LOCATOR LOCATOR SEAL ASSEMBLY 3.000 aa� 1 7,383.3 5,915.8 36.64 PACKER OTIS WD PACKER 3.000 NIPPLE, 7,014 ay 7,399.1 5,928.4 36.72 NIPPLE CAMCO D NIPPLE NO GO 2.250 AL 7,406.5 5,934.4 36.81 SOS CAMCO SHEAR OUT SUB 2.441 SEAL ASSY. 7.022 - Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 6,364.0 5,119.7 41.04 PACKER WEATHERFORD ER PACKER 4/4/2011 1.750 6,367.0 5,121.9 41.03 PATCH PATCH ASSEMBLY -JJ RECEPTACLE, SPACER PIPE & 4/4/2011 1.750 SNAP LATCH (OAL= 27.88) I 6,401.0 5,147.6 40.81 PACKER LOWER WEATHERFORD ER PACKER 3 /19/2011 1.750 7,373.2 5,907.6 36.58 SLEEVE -O BPC SLEEVE SET IN BPL NIPPLE 4/4/2011 2.310 ii. Perforations & Slots ill Shot PRODUCTION Top (NDI Bhri (TVD) Dens SCAB LINER _ Top (ftKB) Btm (IIKB) (11K13) (ftKB) Zone Date (Rh.-- Type Comment 5.5 - ,. 7 7,343.0 5,809.8 5,883.3 C C - 3, C 1/17/1986 12.0 IPERF 5" Scalloped HJ II Csg Gun; 120 deg. SBR, . 7,136 7,152 ,. 3 7,152 UNIT B, 3F-09 phasing PACKER, 7,169 "" "' 7,424.0 7,454.0 5,948.4 5,972.4 A -2, 3F-09 1/17/1986 4.0 IPERF 4" Carrier HJ II Csg Gun; 90 deg. phase PRODUC 72D0N, Notes: General & Safety 1 End Date Annotation ii 1/30/2006 NOTE: WAIVERED WELL-00A x ATMOSPHERE COMMUNICATION-SEALTITE REPAIR SUCCESS IPERF, 1/30/2006 NOTE: WAIVERED WELL:OA x OOA COMMUNICATION 10"x COND; 7'x10" COMMUNICATION 7,252 - 7,343 1/30/2006 NOTE: WAIVERED WELL: IAxOA- GOOD 5.5 "x7' Tx IA- GOODTx5.5" 3/16/2010 NOTE: Tubing x IA LEAK DETECTED @6293', POSSIBLE SECOND LEAK @ 6721' 11/9/2010 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE, 7,373 SLEEVE -O, N. 7,373 Mandrel Details t. Top Depth Top Port (TVD) 1061 OD Valve Latch Size TRO Run LOCATOR, Stn Top (ftKB) (ftKB) ( °) Make Model (In) Sery Type Type (in) (psi) Run Date Com... 7,382 1 2,944.0 2,655.7 44.08 CAMCO KBG - 2 - 9 1 GAS LIFT GLV BTM 0.156 1,230.0 4/14/2011 PACKER, 7,383 .� ' 2 4,644.8 3,885.6 43.61 CAMCO KBG -2 -9 1 GAS LIFT OV BTM 0.188 0.0 4/14/2011 NIPPLE, 7.399 3 5,747.2 4,664.2 43.88 CAMCO KBG -2 -9 1 GAS LIFT DMY BTM 0.000 0.0 2/27/2010 - 4 6,415.4 5,158.5 40.77 CAMCO KBG -2 -9 1 GAS LIFT DMY BTM 0.000 0.0 1/4/2009 SOS, 7,407 - s. 5 6,967.3 5,5833 38.26 CAMCO KBG -2 -9 1 GAS LIFT DMY BTM 0.000 0.0 4/29/2010 61 7,205.8 5,772.3 35.73 CAMCO KBUG 1 PROD DMY 'BK -2 0.000 0.0 7/5/2005 PERF, 7,4247,454 PRODUCTION. 35 -7,803 TD, 7,785 KUP • 3F -09 Conoco Phi I I i ps Alaska. Inc ca ocornimps '—•' KBGrd (ft) Rig Release Date ••• Well C4nfl0 • 3F-09, 4i30 - - -- 41.79 11/18/1985 Schematic - Act20ual 1 7 45 36 AM HANGER 35 Notes: General & Safety , ' / End Date Annotation 2/22/2011 NOTE: RBG LEAKS @ 6276' 8 6293' I I 4/4/2011 NOTE: TUBING LEAKS @ 6276' 8 6293' CON DUCTOR, 38 -115 NIPPLE, 471 Y - GAS 111 IK 2,9,9 44 4 SURFACE, A 37 -3,474 GAS LIFT, 4.645 GAS LIFT, 5,747 PACKER. 6,364 PATCH, 6,367 t I 1 PACKER. 6.401 1 w GAS LIFT, 6,415 I i Mr I GAS LIFT, 6,967 Har. NIPPLE, 7,014 SEAL ASSY, 7,022 PRODUCTION li_S1 SCAB LINER 5 5N3 5 35 -7,138 SBR, R, 7,152 7,152 2 PACKER, 7,169 PRODUCTION, r, 7,206 IPERF, R 7,252 -7,343 NIP, 7,373 SLE -O, _ -- -- 7,373 IL LOCATOR, 7.382 PACKER, 7,383 1" NIPPLE. 7.399 SOS. 7.407 IPERF, 7,424 -7,454 PRODUCTION. 35 -7,603 T0, 7.785 STATE OF ALASKA RECENED ALASKA OIL AND GAS CONSERVATION COMMISSIOP MAY 2 7 ?HP REPORT OF SUNDRY WELL OPERATIONS {{ 1. Operations Performed: Abandon 17 Repair well 0 Plug Perforations 17 Stimulate El A1asta3 `C tl?err ' Coif t atc %si n Alter Casing ❑ Pull Tubing ❑ Fbrforate New Pool ❑ Waiver ❑ Time Bctension .'x11111 r;, nr, Change Approved Program ❑ Operat. Shutdow n ❑ Perforate ❑ Re -enter Suspended Well ❑ 1 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. - Development Exploratory ❑ 185 -270 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service 17 50 - 029 - 21480 - . 7. Property Designation (Lease Number): 8. Well Name and Number. ADL0025643' 3F - 09 • 9. Field/Pool(s): Kuparuk River Field / Kuparuk River oil Pool • 10. Present Well Condition Summary: Total Depth measured 7785 • feet Plugs (measured) None true vertical 6237 . feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 7022 true vertical 0 feet (true vertucal) 5627 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 0 1640 630 SURFACE 3377 9 -5/8 3414 3000 3520 2020 PRODUCTION 7568 7 7603 6092 4980 4330 PRODUCTION 7103 5-1/2 7138 5718 7000 4990 Perforation depth: Measured depth: 7252 - 7343, 7424 - 7454 JUN 0 1 ) True Vertical Depth: 5810 -5883, 5948 - 5972 °"` • Tubing (size, grade, MD, and TVD) 3.5, J -55, 7037 MD, 5639 TVD, WEATHERFORD 1.750" ID ER PATCH FROM 6367 -6404 MD Packers & SSSV (type, MD, and TVD) PACKER - BAKER CSR SEAL ASSEMBLY @ 7022 MD and 5627 TVD NIPPLE - CAMCO DS LANDING NIPPLE @ 471 MD and 471 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development E - Service ❑ Stratigraphic ❑ 15. Well Status after work: Oil p • Gas ❑ WDSPL 0 Daily Report of Well Operations X GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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 or Sundry Number required here Contact Martin Walters / Brent Rogers Printed Name Martin Walters Title: Problem Wells Supervisor Signature % ; Phone: 907- 659 -7224 Date 5/22/11 . 1 3/' / ?.4 4-/-1( , . Form 10 -404 Revised 10/2010 Submit Original Only • • 3F -09 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 2/1/2010 (WAIVER COMPLIANCE TIFL FAILED I LOGGED CALIPER SURVEY f/ 7115' RKB TO SURFACE; GOOD DATA. SET CATCHER 3/7/2010 ON XX PLUG @ 7129' RKB. PULLED GLVs @ 6967', 4655' & 2944' RKB. SET DVs @ 4655' RKB & 2944' RKB. READY TO LOAD CSG. LOAD TBG & IA W/ DSL. PERFORM TBG X IA CMIT, PASS. SET DV @ 6967. ATTEMPT 3/9/2010 TO PT TBG, IA TRACKING IMMEDIATELY. ESTABLISH LLR OF 2 BPM @ 1050 PSI PUMP PRESSURE. READY FOR ELINE LDL PERFORMED LEAK DETECTION LOG. FOUND TUBING TO IA LEAK AT 6393' AND 3/16/2010 POSSIBLE 2ND LEAK AT 6376'. COMPLETE. 5/25/2010 PERFORMED HOISTING OPERATIONS FOR BAKER CORROSION MICRO VERTILOG FROM A DEPTH OF 7021' TO SURFACE. DRIFTED TBG WITH 25' X 2.74" DUMMY PATCH TO 6400' SLM; NO PROBLEMS 2/23/2011 ENCOUNTERED. READY FOR E -LINE. PERFORM FCO FROM INITIAL TAG @ 7410 CTMD TO HRD TAG @ 7461 CTMD, 3/4/2011 UNABLE TO JET PAST THIS DEPTH DUE TO HRD PACK, SAW LITE FORMATION SANDS IN RETURNS, FP WELL, READY FOR SL, IN PROGRESS, 3/18/2011 SET 3.5" WEATH RFORD ER P CKER AT 6404'. READY FOR SLICKLINE TO SET UPPER ELEMENT. TESTED LOWER ER PKR @ 6404' RKB 2500 PSI, PASSED. SET MIDDLE PATCH ASS'Y (JJ RECEPTACLE, SPACER PIPE & SNAP LATCH, OAL= 27.88') @ 6377' RKB. TESTED 4/4/2011 2500 PSI, PASSED. SET UPPER PATCH ASS'Y (ER PKR, SPACER PIPE & SNAP LATCH ASS'Y, OAL= 10.5') @ 6367' RKB. BLED IA f/ 1100 PSI TO 300 PSI, HOLDING.LRS MITIA TO 2500 psi PASSED COMPLETE. 4/14/2011 TAGGED @ 7463' SLM (EST. 28' OF RAT HOLE) PULLED DV'S @ 2944' RKB & 4655' RKB. SET GLV @ 2944' RKB & OV @ 4655' RKB. PULLED CATCHER SUB. COMPLETE 4/24/2011 I TIFL PASSED STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT�F SUNDRY WELL OPERATI S 1. Operations Performed: Abandon r Repair w ell l Rug Perforations r Stimulate r Other YT Install Patch Alter Casing r Rill Tubing r Perforate New Pool fl Waiver r Time Extension Change Approved Program [ Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 185 - 270 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 F -- 50 029 - 21480 - 00 "00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25643 `' 3F -09 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7785 feet Plugs (measured) None true vertical 6237 feet Junk (measured) None Effective Depth measured 7512 feet Packer (measured) 6364, 6401, 7079, 7169, 7383 true vertical 6018 feet (true vertucal) 5120, 5148, 5672, 5743, 5916 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3377 9.625" 3414 3000 PRODUCTION 7568 7" 7603 6092 LINER 7103 5.5" 7138 5719 Perforation depth: Measured depth: 7252'-7343', 7424'-7454' 3 ki 9 2, ;I ii' True Vertical Depth: 5810'- 5883', 5948' 97 and ) 3 L ' Nitska Oil & r ra Cans. Genl�raasio�ro Tubing (size, grade, MD, and TVD) 3.5, L -80, 7037 MD, 5639 TVD F' I"dct49rb Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 6364 MD and 5120 TVD PACKER - WEATHERFORD ER PACKER @ 6404 MD and 5148 TVD PACKER - BAKER PREMIER PACKER @ 7079 MD and 5672 TVD PACKER - OTIS RRH PACKER @ 7169 MD and 5743 TVD PACKER - OTIS WD PACKER @ 7383 MD and 5916 TVD NIPPLE - CAMCO DS LANDING NIPPLE @ 471 MD and 471 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Si Subsequent to operation 23 224 4539 -- 176 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ° Service r Stratigraphic 15. Well Status after work: ..Oil 17 Gas fl WDSPL Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 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 @ 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 - 6471 Date S/2 - a I Form 0 - Revised 10/2010 Re MA Y 0 3 n 7,,„0, __ �. _ S 3 Submit Original Only , %4 • 3F -09 Well Work Summary • DATE SUMMARY 3/18/11 SET 3.5" WEATHERFORD ER PACKER AT 6404'. READY FOR SLICKLINE TO SET UPPER ELEMENT. 4/4/11 TESTED LOWER ER PKR @ 6404' RKB 2500 PSI, PASSED. SET MIDDLE PATCH ASS'Y (JJ RECEPTACLE, SPACER PIPE & SNAP LATCH, OAL= 27.88') @ 6377' RKB. TESTED 2500 PSI, PASSED. SET UPPER PATCH ASS'Y (ER PKR, SPACER PIPE & SNAP LATCH ASS'Y, OAL= 10.5') @ 6367' RKB. BLED IA f/ 1100 PSI TO 300 PSI, HOLDING.LRS MITIA TO 2500 psi PASSED COMPLETE. 4/14/11 TAGGED @ 7463' SLM (EST. 28' OF RAT HOLE) PULLED DV'S © 2944' RKB & 4655' RKB. SET GLV @ 2944' RKB & OV @ 4655' RKB. PULLED CATCHER SUB. COMPLETE 4/24/11 TIFL ( PASSED ON PRESSURE PERFORMANCE POST IA BLEED WITH INFLOW ) hi, 1 h�l1P 3F -09 Conoco Phillips Well Attributes Max Angle & MD !TD A(so08.frx, a. Wellborn APSUWI I Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) c r7na�aPtlilNpf . 500292148000 i. 0 UPARUK RIVER UNIT ,PROD 47.02 5,100.00 7,785.0 ' " "' Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Dab SSSV NIPPLE i 100 11/29/2009 Last WO: 7/8/2005 41.79 11/18/1985 Well corM�_ 3F-09,4M.01 79536 AM - -. _� -_ _ _ S Hn I�AC iai _... Annotation Depth ttKB) End Date Annotation Lest Mod... End Dab Last Tag SLM 7 4f,i 0 4/14/2011 Rev Reason: PATCH UPDATE lmosbor 4/30/2011 Casing Strings HANGER. 35 _. :v: g � '. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H - 40 WELDED I C ing De pt String 0... String ID ... Top (NCB) Set Depth (f... Set Depth (ND) Str rig Wt... String ... String Top Thtd SURFACE 9 5/8 8 921 37.0 3,413.5 2,999.8 36.00 J - BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) String Wt... String ... String Top Thnt ilk PRODUCTION 7 6.151 35.0 7,603.2 6,091.9 26.00 J - 55 BUTT I Casing Description String 0... String ID ... Top (11(8) Set Depth (E.. Set Depth (ND) ... String Wt... String ... Sating Top Thrd PRODUCTION 51/2 4.950 35.0 7,138.0 5,718.5 15.50 L -80 HYDRIL CONDUCTOR, SCAB LINER 38.115 5.5"x3.5" NIPPLE, 471- Liner Details t Top Depth (ND) Top 1 cl Norm_ Top (611(8) (RK6) O item Deso iption co not ID (in) 7,046.5 5,645.9 37.87 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT, - 7,066.7 5,661.8 37.68 XO Reducing CROSSOVER 5.5 x 3.5 ", ID 2.992, 9.30, L-80, EUE 3.500 1 2,944 '�z - ..._..__. __ - _ _....._. 7,079.4 5,671.8 37.56 PACKER BAKER PREMIER PACKER 2.875 7,129.0 5,711 -3 37.08 NIPPLE HES XNIPPLE 2.813 - -- - -- E - ` 7 136 -5 5 71 ; 7 01 OVERSHOT BAKER POORBOY OVERSHOT 2.935 Tubing Strings SURFACE, Tubing Description 'String 0._ 'String ID ...Top (ftKB) Set Depth (t Set Depth (TVD) String Wt... String String Top Thrd 37 -3,414 TUBING WO 31/2i 2992 350 1 .7,0372 1 5,6386 9.30 L-80 [String MOD GASUFT Completion Details 4,645 -_ V Top Depth ,'. (TVD) Top Intl Nomi... Top (NCB) (ftKB) ( °) Kern Description Comment ID (in) 3 5.0 35.0 0.23 HANGER FMC SM TUBING HANGER 3.500 GAS LIFT. 471.0 471.0 0.19 NIPPLE CAMCO DS LANDING NIPPLE 2.875 5.747 ! 7,014.3 5,620.8 38.17 NIPPLE CAMCO DS NIPPLE 2.813 7,021.9 5,626.6 38 10 SEAL ASSY BAKER CSR SEAL ASSEMBLY 3.850 _ - PACKER, 6,364 4 Tubing De pt n I Str g 0... String ID nag KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... Strng Top Thrd PATCH, 6,367 j TUBING ORIGINA I 31/2 2992 7,138.0 7,407.2 5,935.0 9.30 J -55 BUTT PACKER,6,401 ': Completion Details . = � - ,,, o _ -,_. - -. : Top Depth - (ND) Top Inc' Nomi... - GAS LIFT, '� Top (ftKB) (ftK6l (°) hem Description Comment ID (in) 7,151.5 5,729 3 36.87 SBR OTIS SBR 3.000 6,415 7,168.6 5.742 9 36.71 PACKER OTIS RRH PACKER 2.970 7,243.5 5,803.0 35.92 BLAST RINGS BLAST JOINTS 2.992 GAS LIFT, - 7,373.2 5,907.6 36.58 NIPPLE AVA BPL w /SLEEVE (OPEN 4/4/2011) 2.750 6,967 r ,. 7,376.1 5,909.9 36.60 XO Reducing CROSSOVER 3.5 x 2.875" ID 1.995" 2.875 7,382.3 5,914.9 36.63 LOCATOR LOCATOR SEAL ASSEMBLY 3.000 j 7,383.3 5,915.8 36.64 PACKER OTIS WD PACKER 3.000 NIPPLE, 7,014 - - -� � - -- 7,399.1 5,926.4 36.72 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,406.5 5,934.4 36.81 SOS CAMCO SHEAR OUT SUB 2.441 SEAL 7, 22- -- `° Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc' Top (NCB) (ftKB) C1 Description _ Comment _ Run Date ID (In) 6,364.0 5,119 7 41.04 PACKER WEATHERFORD ER PACKER 4/4/2011 1.750 6,367.0 5,721 9 41.03 PATCH PATCH ASSEMBLY -JJ RECEPTACLE, SPACER PIPE & 4/4/2011 1.750 SNAP LATCH (OAL= 27.88') 6,401.0 5,147.6 40,81 PACKER LOWER WEATHERFORD ER PACKER 3 /19/2011 1.750 7,373.2 5,907 6 36.58!SLEEVE O BPC SLEEVE SET IN BPL NIPPLE 4/4/2011 2.310 ilk Perforations & Slots Shot PRODUCTION Top (TVD) Btm (TVD) Dens SCAB LINER Top (ftKB) Btm (ftKB) (81(8) (ftKB) Zone Date (06... Type Comment 5.5''3.5', 7,252.0 7,343.0 5,809.8 5,883.3 C-4, C -3, C -1, 1/17/1986 12.0 IPERF 5" Scalloped Hi 11 Csg Gun; 120 deg. 357'136 UNIT B, 3F -09 phasing SBR, 7,152 PACKER, 7,169 - r 7,454.0 5,948.4 5,972.4 A -2, 3F -09 1/17/1986 4.0 IPERF 4" Carrier HJ II Csg Gun; 90 deg. - w 7,424.0 phase PRODUCTION, p - Notes: General - - - - -- -- -_ -� - - -- -_.__ & Safety '' End Date Annotation 1/30/2006 11n l0: WAIVERED WELL-00A x ATMOSPHERE COMMUNICATION-SEALTITE REPAIR SUCCESS _ I. 7252 7PE34 RF3 1/30/2006 NOI h!: WAIVERED WELL - OA x 00A COMMUNICATION 10 "x COND; 7"x10" COMMUNICATION ,w 1!30/2006 NO l L WAIVERED WELL IA OA GOOD 5.5 "z7" TxIA- GOOD Tx5.5" 3/162010 NO I E Tubing x IA LEAK DETECTED (6293', POSSIBLE SECOND LEAK @ 6721' _ , 11/9!2010.Jfj I 0 View Schematic w/ Alaska Schematic9.0 NIPPLE, 7,373 SLEEVE -0, __. _.... _..- _. - _ -... _ - ........ 7,373 Mandrel Details Top Depth Top 1 Port (TVD) Inc! OD Valve Latch Size TRO Run LOCATOR, Stn Top (ftKB) (ftKB) (°) Make Model (in) Saw Type Type (in) (psi) Run Dab Cam... 7,382 ' 1! , ^ 1 2,944.0 2,655.7 44.08 CAMCO KBG - 2 - 9 1 GAS LIFT GLV BTM 0.156 1,230.0 4/142011 PACKER, 7,383 II t 2 4,644.8 3,885.6 43.61 CAMCO KBG -2 -9 1 GAS LIFT OV BTM 0.188 0.0 4/14/2011 NIPPLE, 7,399 ig -- 3 5,747.2 4,664 2 43.88 CAMCO KBG -2 -9 1 GAS LIFT DMY BTM 0.000 0.0 2/27/2010 4 6,415.4 5,158.5 40.77 CAMCO KBG -2 -9 1 GAS LIFT DMY BTM 0.000 0.0 1/4/2009 SOS, 7,407 Ite, 5 6,967.3 5,583.3 38.26 CAMCO KBG -2 -9 1 GAS LIFT DMY BTM 0.000 0.0 4292010 6 7,205.8 5,772.3 35.73 CAMCO KBUG 1 PROD DMY BK -2 0.000 0.0 7/5/2005 IPERF, 7,424. 7.454 _... PRODUCTION, 35 -7,603 TD, 7,785 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 23, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3F -09 Run Date: 3/18/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21480 -00 .APR 1 8 201; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 /16" 9- klinton.wood @halliburton. com Date: Signed: . 7 ) ' 3S ":' WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3F-09 Run Date: 3/16/2010 March 19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F-09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21480-00 kit ~ a k~CC-~kI H~:~ l~ ~t L_E.~i~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 ~. 0 i~~ 1 `~~ ~c,~"~' ~ t rafael.barreto ~~ ~;, ~.~ ~' Date: MAR ~ ~ 201Q Signed: J PrtoACrive D'u~gnostic SERVICES, INC. 1/IfELL LQG TRAN~'NIfTTAL To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing lnspection(Caliper / MTT) The technics{ data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Raad Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 07-Mar-10 2) 3F-09 1 Report/ EDE 50-029-21480-00 ~~ 1~~ i ~ 5 R~,C~l~ MAR ~ 3 2Q10 Signed Print Name: Date PROACTIVE DIAGNOSTIC SERVICES, INC., 1S0 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (807)245-8961 FAx: (807)24588952 E-xIAIL : pdsanchorage(~Dmemorvloa.com WEBSRE : vrvvw.memorvloa.com C:\Aoamienffi and Settings\Diane Williams\Desktop\Tim~stuit_Conoco.docic • • Memory Mult~Finger Caliper ,~ LOg Results Summary ,.. Company: ConocoPhillips Alaska, Inc. Well: 3F-09 Log Date: March 7, 2010 Field: Kuparuk Log No.: 6786 State: Alaska Run No.: 1 API No.: 50-029-21480-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 IBT MOD / EUE Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 7,086 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the Camco DS-Nipple @ 7,094' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage, particularly in the vicinity of a suspected tubing leak between 6,380' and 6,396'. The caliper recordings indicate the 3.5" tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. A 3-D log plot of the caliper recordings across the interval of a suspected tubing leak is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 12%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. ,~. Field Engineer: N. Kesseru Analyst: C. Waldrop Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 IBS -2~-e ~`~L~~s • \~~ PDS Multifinger Caliper 3D Log Plot ""~~' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3F-09 Date : March 7, 2010 Description : Detail of Caliper Recordings Across Suspected Leak (6,380' to 6,396 in 3.5" Tubing. Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D Log Image Map 1ft:240ft 0 100 2.5 3.5 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 2.5 3.5 Nominal I.D. {ins.) 2.5 3.5, Joint 211 ~ 6340 6350 6360 ' Joint 212 6370 '. 6380 Joint 213 6390 6400 Pup Jt. 6410 ~j ! __ GLM 5 6420 - - .u Pup Jt. ~ 6430 ~ : _'.. Joint 214 16440 Nominal I.D. (ins.) :..................................................: 2.5 3.5 Min. I.D. (ins.) 2.5 3.5 Comments Depth Max. Pen. (°l6) Max. I.D. (ins.) 3-D Log Image Map 1ft:240ft `0 100 2.5 3.5 0° 0° 90° 180° 270° 0° • Correlation of Recorded Damag Pipe 1 3.5 in (18.1' - 7067.5') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 3 F-09 Kuparuk ConocoPhillips Alaska, Inc. USA March 7, 2010 ^ A pprox. Tool De viation . A pprox. Borehol e Profil e 1 29 25 755 50 1487 75 2230 GLM 1 100 3012 O v '- E Z 125 ~ 3748 s c Q- a, o 150 4484 GLM 2 175 5240 GLM 3 200 5997 GLM 4 225 6749 GLM 5 233 7068 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 233 • • PDS Report Overview ~,. ~~~ Body Region Analysis Well: 3F-09 Survey Date: March 7, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. lower len. 3.5 ins 9.3 f L-80 IBT MOD EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~~; metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of "oints anal sed total = 253 pene. 13 234 6 0 0 0 loss 195 58 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body rnetal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 233 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 IBT MOD / EUE Well: 3F-09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: March 7, 2010 Joint No. Jt. Depth (Ft.) I'c•n. Ul~sel (Ins.l Pen. Body (Ins.) P~~n. % Mc•t~l Loss °/~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 18 t) 0.03 11 -1 2.94 PUP .2 22 ~ 0.01 6 1 2.92 PUP 1 29 U 0.01 2 1 2.93 1.1 57 U 0.01 ? U 2.96 PUP 1.2 66 U 0.01 3 I 295 PUP 2 69 O 0.01 -1 I 2.94 3 98 ! 1 0.01 ~ I 2.94 ~ 4 127 a 0.01 ~' l 2.93 5 156 0 0.01 4 1 2.93 6 186 ~ ~ 0.01 4 1 2.94 7 215 0 0.01 2 ~' 2.93 8 244 (1 0.01 2 1 2.94 ~ 9 273 a 0.00 1 1 2.94 ' 10 303 U 0.01 Z I 2.93 ~ 11 332 (! 0.01 2 1 2.93 12 361 (? 0.01 2 1 2.93 13 391 U 0.00 1 I 2.94 14 419 l) 0.01 ? I 2.95 14.1 448 (! 0.01 ~ 1 2.92 PUP 14.2 454 (1 0 O ~! 2.88 Camco DS-Landin Ni le 14.3 456 (1 0.00 _' I 2.93 PUP 15 462 U 0.01 ? 1 2.94 16 492 t) 0.01 2 ~ 294 17 521 l) 0.01 2 2.94 18 551 (1 0.01 Z ( 2.94 19 579 ~? 0.01 2 I 2.92 20 608 U 0.01 ~' ? 2.93 ~ 21 637 (~ 0.01 1 1 2.94 22 667 i? 0.01 ? 1 2.94 23 696 i) 0.01 ~~ 2.95 24 726 i! 0.01 2 I 2.94 25 755 O 0.00 1 ~ ~ 2.93 26 784 U 0.01 Z 2.93 27 814 t! 0.01 4 ! 2.92 28 843 ~! 0.01 4 2.92 29 872 (! 0.00 1 i 2.95 30 903 (! 0.01 1 ' 2.92 31 932 U 0.01 2 1 2.92 32 962 i) 0.01 4 1 2.94 33 991 i! 0.01 4 ~' 2.93 34 1020 i) 0.01 ? 2.94 35 1049 t~ 0.01 1 I 2.94 ' 36 1079 U 0.01 ~' 1 2.93 ~ 37 1 108 U 0.01 2 I 2.94 38 1137 U 0.01 Z I 2.92 39 1166 U 0.01 -1 ~' 2.95 40 1195 U 0.01 4 1 2.95 41 1225 O 0.01 Z ~' 2.95 42 1254 U 0.01 2 Z 2.95 ~ 43 1283 ~! 0.01 ? 2 2.94 _ Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 IBT MOD / EUE Well: 3F-09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoNhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 7, 2010 Joint No. Jt. Depth (Ft.) Pen. Ul~sr'I (Ins.) Pen. Body (Ins.) Pen. %> Metal Loss `7~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 10O! 44 1312 t) 0.01 I 2.94 I 45 1341 U 0.01 Z f 2.91 46 1370 U 0.01 2 2 2.93 47 1400 0 0.01 2 1 2.94 48 1429 !~ 0.01 Z 1 2.93 49 1458 U 0.01 1 ? 2.94 50 1487 ~) 0.01 4 ~ 2.94 51 1516 i) 0.01 ' ~ 2.96 52 1547 t1 0.01 -1 2.94 53 1580 U 0.01 2 ~ 2.94 54 1611 O 0.01 2 2.96 55 1642 U 0.00 1 u 2.95 56 1671 !) 0.01 2 tl 2.92 57 1702 t1 0.01 2 1 2.94 58 1733 U 0.01 2 1 2.97 59 1765 U 0.01 ? I 2.94 60 1792 U 0.00 1 i 1 2.95 61 1822 t) 0.01 4 I 2.94 62 1851 t) 0.01 5 ~ 2.92 63 1881 U 0.00 1 ~ ~ 2.93 64 1910 ! ~ 0.01 2 2.94 65 1940 t ~ 0.00 1 I 2.94 66 1968 U 0.01 2 1 2.94 67 1998 t) 0.01 2 1 2.94 ~ 68 2026 U 0.01 2 2.93 69 2056 t i 0.01 2 I 2.94 70 2086 (~ 0.02 f3 2.93 71 2116 U 0.01 4 ? 2.94 72 2144 ~ ~ 0.01 ? 1 2.93 73 2174 t? 0.01 1 i 2.93 74 2201 0 0.01 _' I 2.93 a 75 2230 !) 0.01 ~1 1 2.91 76 2259 U 0.01 _' _' 2.93 77 2289 t) 0.01 l ? 2.95 78 2320 O 0.01 Z u 2.94 79 2352 O 0.01 Z u 2.95 80 2383 t) 0.01 4 1 2.96 81 2414 U 0.01 ? i) 2.93 82 2445 (~ 0.01 2 1 2.94 83 2476 !~ 0.01 2 1 2.95 84 2508 li OA2 9 2.93 85 2538 a 0.01 ; ~ 2.95 86 2569 !! 0.01 2.94 87 2598 (_) 0.01 2 _' 2.91 88 2628 n 0.01 c t) 2.94 89 2659 U 0.01 1 1 2.93 90 2688 !) 0.01 2 I 2.93 91 2 718 U 0.01 4 _' 2.93 92 2747 ~~ 0.00 1 i? 2.93 93 2776 a 0.01 I 2.94 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 IBT MOD / EUE Well: 3F-09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 7, 2010 Joint No. Jt. Depth (Ft.) I'en. Ut~sc°t (ln~.) Pen. Body (Ins.) Pc°n. `%~ ~~Ictal I oss °~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 94 2806 t) 0.01 ~ i 2.94 95 2835 t1 0.01 2 ~' 2.92 96 2864 l1 0.01 4 1 2.93 97 2894 i a 0.01 ? ~' 2.93 ` 97.1 2923 U 0.01 ~' I 2.97 PUP 97.2 2933 U 0 U tt N A GLM 1 Latch @ 6:00 97.3 2940 t) 0.01 2 2.96 PUP ~ 98 2949 U 0.01 2 I 2.95 '° 99 2980 U 0.02 is (1 2.94 100 3012 (~ 0.01 ? 1 2.95 101 3042 O 0.01 ? 1 2.91 ~~ 102 3071 t) 0.01 _' i 2.95 103 3100 l) 0.02 t_~ I 2.94 104 3130 t) 0.01 ' i) 2.94 105 3161 t) 0.01 4 2.95 106 3193 t! 0.03 11 i 2.93 107 3221 n 0.01 I 2.94 108 3251 U 0.01 ~' 2.94 109 3280 U 0.01 ~' I 2.95 ~ 110 3308 U 0.01 ? 1 2.93 111 3338 t) 0.01 2 Z 2.94 112 3367 U 0.01 2 1 2.93 1 13 3396 U 0.01 2 t) 2.92 114 3425 U 0.01 2 2.94 1 15 3454 ~) 0.01 _' I 2.94 116 3484 ~) 0.01 ~ i 2.92 117 3513 a 0.01 ~ 2.94 118 3543 t) 0.01 2 ? 2.94 119 3573 t) 0.01 2 u 2.93 120 3602 O 0.01 2 0 2.93 121 3631 U 0.01 2 1 2.93 122 3660 O 0.01 2 1 2.93 123 3690 (~ 0.01 2 t1 2.93 124 3718 t) 0.01 2 2.93 125 3748 t) 0.01 > I 2.93 126 3777 l) 0.01 ~1 ~~ 2.93 127 3806 U 0.01 1 2.94 128 3835 t) 0.01 Z 1 2.94 129 3865 U 0.01 ~ 1 2.93 130 3894 t) 0.01 Z _' 2.93 131 3923 t) 0.01 .' 1 2.92 ' 132 3952 U 0.01 4 O 2.92 ~' 133 3982 O 0.01 ~' I 2.94 t 134 4012 ~) 0.01 2 1 2.91 135 4041 (~ 0.01 2 1 2.94 t 136 4070 n 0.01 Z 2.94 137 4100 l) 0.01 2 I 2.94 138 4130 U 0.01 2 I 2.91 139 4159 U 0.01 2 .' 2.94 140 4191 l) 0.01 2 .' 2.95 Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 IBT MOD / EUE Well: 3F-09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. I~lominal I.D.: 2.992 in Country: USA Survey Date: March 7, 2010 Joint No. Jt. Depth (Ft.) I'c~n. Upset (Ins.) Pen. Body (Ins.) Pen. % Mc~,~l I oss S4. Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 141 4222 ~) 0.01 2 1 2.93 142 4252 ~) 0.01 4 I 2.93 143 4281 U 0.01 2 ~ 2.94 144 4310 h 0.02 ti 1 2.93 145 4340 (~ 0.01 4 1 2.93 146 4367 U 0.01 2 I 2.93 147 4396 ~? 0.01 ~ 1 2.92 148 4426 U 0.02 £i t~ 2.91 149 4455 U 0.01 1 2.94 150 4484 t~ 0.02 8 I 2.94 151 4514 i ~ 0.01 2 ~ ~ 2.94 152 4543 U 0.02 ~) ~' 2.94 153 4572 l } 0.03 1(i I 2.93 154 4601 ~ ~ 0.01 ~' I 2.92 154.1 4631 l) 0.00 2 I 2.95 PUP 154.2 4641 O 0 t) U N A GLM 2 Latch C~ 1:30 154.3 4646 t~ 0.01 d 2.96 PUP ~ 155 4657 U 0.01 Z 2.93 156 4685 U 0.01 l I 2.93 157 4715 t~ 0.01 4 1 2.93 158 4744 ~) 0.01 4 I 2.93 159 4774 U 0.01 4 1 2.93 160 4802 O 0.01 3 I 2.93 161 4831 tt 0.02 ~~ I 2.92 162 4861 t) 0.01 5 11 2.93 163 4890 t ~ 0.02 t3 l 2.92 164 4919 ;~ 0.00 i 1 2.93 165 4948 t) 0.00 ? (i 2.91 166 4978 O 0.02 9 (~ 2.92 167 5007 O 0.01 2 i 2.93 168 5036 U 0.02 9 1 2.93 169 5065 t) 0.02 9 0 2.92 170 5094 t~ 0.01 2 1 2.94 171 5123 (1 0.01 ~ 2 2.92 172 5153 U 0.01 ~ 1 2.92 173 5182 ~) 0.03 11 1 2.92 174 5212 U 0.01 ~ 1 2.90 175 5240 U 0.01 a 2.92 176 5269 U 0.01 4 1 2.93 177 5298 I? 0.01 2 I 2.91 178 5328 i? 0.01 <1 c1 2.90 179 5356 ~? 0.02 8 U 2.93 180 5386 t~ 0.01 2 0 2.93 181 5414 ~ } 0.00 2 1 2.92 182 5444 i ~ 0.02 9 I 2.92 183 5472 U 0.02 ~~ 1 2.90 184 5502 ~? 0.01 4 U 2.92 185 5531 a 0.02 9 1 2.93 186 5560 U 0.01 2 1 2.93 187 5590 tt 0.01 ? 1 2.93 _ Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 IBT MOD / EUE Well: 3F-09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 7, 2010 Joint No. Jt. Depth (Ft) I';~n. 11I;5c~t (lnc.) Pen. Body (Ins.) Pen. % :Metal loss ~- Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 188 5619 t) 0.02 9 I 2.94 189 5648 i) 0.00 i r) 2.92 190 5676 U 0.02 ~~ I 2.93 191 5706 O 0.02 9 I 2.94 191.1 5735 O 0.01 Z 2.95 PUP 191.2 5745 l) 0 (1 0 N A GLM 3 Latch ~ 6:30 191.3 5750 O 0.03 ! I I 2.94 PUP 192 5762 O 0.01 2 I 2.92 193 5791 U 0.01 4 1 2.94 194 5820 0 0.02 8 l) 2.92 195 5849 t) 0.02 8 l) 2.93 196 5878 O O.DO 2 I 2.93 197 5908 (1 O.D2 t3 I 2.92 198 5938 O 0.02 ~) 2.93 199 5967 t) 0.01 4 1 2.92 200 5997 0 0.01 Z 1 2.94 201 6026 t) 0.01 1 ! ~ 2.92 ~ 202 60 6 U 0.03 1 U 1 2.93 2D3 6085 O 0.01 ~ u 2.91 204 6114 (I 0.01 2 (~ 2.93 205 6144 (~ 0.01 _' 1 2.94 206 6173 U 0.01 ~' i 2.91 207 6202 U 0.00 1 I 2.9 3 208 6231 O 0.01 Z 2.93 209 6260 t) 0.01 ? 2.91 ~ 210 6289 n 0.00 1 t) 2.92 211 6319 U 0.01 ~ 1 2.93 212 6348 O 0.01 4 D 2.92 213 6377 (~ 0.01 2 1 2.92 213.1 6405 i) 0.01 2 1 2.95 PUP 213.2 6415 0 0 C) c) N A GLM 4 Latch @ 6:30 213.3 6419 (1 0.01 ? I 2.96 PUP 214 6430 ~ ( 0.01 2 1 2.92 215 6460 t) 0.01 2 I 2.92 216 6489 O 0.01 ;' I 2.93 217 6518 U 0.01 ~' I 2.93 218 6547 l ~ 0.01 2 i) 2.92 219 6577 U 0.01 2 I 2.91 220 6606 O 0.01 ? i) 2.92 221 6634 (~ 0.01 1 I 2.94 222 6662 U 0.01 ? I 2.91 223 6691 i ~ 0.01 ? 1 2.92 224 6720 t) 0.01 ? l) 2.92 225 6749 l) 0.01 2 U 2.93 226 6781 0 0.01 ~ O 2.92 227 6810 O 0.01 ~ I 2.91 228 6840 0 0.01 ~' t) 2.91 229 6868 O 0.01 a 2.91 230 6898 i) 0.01 I 2.93 231 6928 i ~ 0.00 1 1 2.93 _ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 IBT MOD / EUE Well: 3F-09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 7, 2010 Joint No. Jt. Depth (Ft.) I'en. Upset (Ins.) Pen. Body (Ins.) I'en. % Metal los `70 Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 231.1 6957 l) 0.01 2 1 2.95 PUP 231.2 6967 0 0 0 0 N A GLM 5 Latch @ 9:30 231.3 6973 U 0.01 3 ~' 2.94 PUP 232 6983 O 0.01 2 ii 2.92 232.1 7014 U 0 t) U 2.81 Camco DS-Ni le 232.2 7016 l) 0.01 ~' i? 2.94 PUP 232.3 7021 i) 0 ti ti 3.85 Baker CSR Seal Assembl 232.4 7038 ti 0 ~) ti 4.00 Baker 80-40 Seal Bore Extension 232.5 7044 ~) 0.03 11 t) 2.88 PUP 232.6 7050 (1 0.01 4 O 2.91 PUP 232.7 7055 U 0 0 U 2.88 Baker Premier Packer 232.8 7062 (~ 0.02 is 0 2.90 PUP 233 7068 U 0.03 12 2 2.93 _ Penetration Body Metal Loss Body Page 6 ~~~ KUP ~ 3F-09 ConoeoPFtillips } II Attributes An le 8 NID TD al.:;.,.....,.; i 1 - •-,. WNPoare APWYYI eltl Name Well Status Ind P) 500292148000 KU PARUK RIVER UNIT PROD 47.02 ND (RKB) 5.100.00 Ad 86n IttKB) 7,785.0 ell Canfi : -3 -0 2 108:40:07 AM CommM M2S (ppm) Date Amotatltxt SSSV: NIPPLE 100 11/29/2009 Last WO: Entl Dale 7!8/2005 -Crtl (Ig 41.79 Rig Release Daze 11!1811985 smemetic -ACiu Artnotatlon Depth (RIB) End Dale Artrtotatlon LastNbtlBy End Dale Last Tag: ELMD 7,430.0 11/6/2008 Rev Reason: GLV C/O, SET PLUG Imosbor 312!2010 ~, Casin Strin s CONDUCTOR, Gsirtg Descrlptlon 5[nrg W (In) S[tlng ID (in) Top (RICB) Set Depm (RKB) Set Depth (TW)) (NKB) nng W[ Qbs4q Sttlng Gfatle SItMg Top TtN 175 CONDUCTOR 1 6 15.062 0.0 115.0 115.0 62.50 H-00 WELDED wPPl an e SURFACE 95 /8 8.765 0.0 3,415.0 3,000.9 36.00 J-55 . . PRODUCTION 7 6.151 0.0 7,603.0 6.091.7 26.00 Jb5 BTC PRODUCTION 5 1 !2 4.950 0.0 7,046.0 5.645.5 15.50 511 HYDRIL Tubin Strin s GAS LIFT 2 9iA nrdn Desai tlon Stn1g O Ilnl D String ID (ln) To (RKB Set Depth IRKeI bet DepN 171/0) 161 Stdrtg WI (Ibs4q String Grade tx l l ThN SURFACE g p TUBING 31 /2 2.992 p ) 0.0 7.022.0 5.626.8 9.30 L-80 r tg ap IBT MOD , 3,a15 TUBING 31 12 2.992 7,022.0 7,136.0 5,716.9 9.30 L-80 EUE TUBING 3 1 12 2.992 7,136.0 7,376.0 5.909.9 9.30 735 EUE cASLIFT, a sss c TUBING 27 /8 2.441 7,376.0 7,407.0 5,934.8 6.50 J35 , Otller In Hole All Jewel .Tubin Run 8 Retrievable Fish etc. GAS LIFT, 5,747 Tophb(B) Top Depth CND) MKBI lop Ind (°) Destxiption Comrtxrtt Rut Dale IDpn) 471 471.0 0.19 N IPPLE CAMCO DS LANDING NIPPLE 7(7/2005 2.875 2,944 2,655.7 44.08 G AS LIFT CAMCO/KBG-2-971/GLV/BTM7.156/1238/Commen7: STA 1 1/4/2009 2.900 Gas uFr, 6 415 4,655 3,893.0 43.57 G AS LIFT CAMCO/KBG-2-911/OV/6TM1.25// Comment: STA 2 2/26/2010 2.900 5,747 4,664.1 43.88 G AS LIFT CAMCO/KBG-2-9/11DMY/BTM/7/ ComnenC STA 3 2/27/2010 2.900 6,415 5,158.2 40.78 G AS LIFT CAMCO/KBG-2-9l1lDMY/BTMI/! Comment: STA4 1/4/2009 2.900 GAS LIFT. 6,967 5,583.1 38.26 G AS LIFT CAMCOlKBG-2-9/1lDMY18TM//! Comment: STA #5 7!7!2005 2.900 6 ss7 7,014 5,620.5 38.18 N IPPLE CAMCO DS NIPPLE 7/7/2005 2.813 7,021 5,626.0 38.11 C SR BAKER CSR SEAL ASSEMBLY 7(7/2005 3.850 NIPPLE, 7 0,4 7,046 5.645.5 37.87 S BE BAKER 80-40 SEAL BORE EXTENSION 7!7/2005 4.000 7.079 5,671.5 37.56 P ACKER BAKER PREMIER PACKER 7!7/2005 2.875 7.129 5,711.3 37.08 P LUG 2.81"XX PLUG w/FILL EXT 3/1/2010 0.000 wR.7,o21 7,129 5,711.3 37.08 N IPPLE HES 'X'NIPPLE 7/7/2005 2.813 7,138 5,718.5 37.00 T BG CUT TBG CUT FOR WORKORVER 776/2005 2.992 PRODUCTION 7,138 5,718.5 37.00 O vershot BAKER POORBOV OVERSHOT 7/7/2005 2.935 Boas SBE lUa6 7.152 5.729.7 36.87 S BR SBR 1/19/1986 3.000 , 7,169 5,743.3 36.70 P ACKER 01is'RRH'PACKER 1/19/1986 2.970 7.373 5.907.4 36.58 N IPPLE AVA BPL NIPPLE 1/19/1986 2.750 PACKER, 7 ots 7,373 5,907.4 36.58 S LEEVE-0 PRE-WORKOVER BELOW TBG CUT AVA BPC SLEEVE - OPEN 7/25/2006 -OPEN. 1/9/1998 2.441 7,383 5,975.5 36.63 P ACKER O[is wD' PACKER 1/19/1986 3.000 NIPPLE. 1,129 7.399 5.928.3 36.71 N IPPLE Camm'D' Nipple NO GO 1/19/1986 2.250 PLUG, 7.12s 7,406 5.934.0 36.81 S OS Cameo 1!19/1986 2.441 7.407 5,934.8 36.87 T TL 1/19!1986 2.441 Perforations S Slots Ovamha, 7,138 TBC CUT s T°P IRKS) BUn IRIS) Top lTVDI (~B) Btm lTwl (~W Zone Date she! Dens (sh... 7ype Conmenl . 7.13e 7,252 7,343 5,909.8 5.883.3 C-0, G3, C-1, UNIT B. 3F-09 1/1771986 12.0 IPERF 5" Sploped HJ II Csg Gun; 120 deg. phasing 7.424 7,454 5,948.4 5,972 4 A-2, 3F-09 1117!1986 4.0 IPERF 4" Carrier HJ II Csg Gun; 90 deg. phase sBR. ~,SZ Notes• General & Safe d Dale Amotatlon 1/30/2006 NOTE: WAIVERED WELL: IAx OA-GOOD 5.5"x7" TxIA-GOODTx5.5" 1/30/2006 NOTE: WAIVERED WELL-0OAx ATMOSPHERE COMMUNICATION-SEALTITE REPAIR SUCCESS PACKER, 7,1ss 7/30/2006 NOTE: WAIVERED WELL:OAx OOA COMMUNICATION 10"x COND; 7"x10" COMMUNICATION TUBI^IG, ],138 IPERF. ],252-7,343 NIPPLE. ],3]3 SI FEVEd. 7 3]3 PACKER, 7,383 NIPPLE, 7,399 sos, t,aos rn, tpm IPERF ~ 7 424-7 454 PRODUCTION 1 603 TD. ] ]85 ' • • Page 1 of 1 I~i~rZ~U Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~~~ Sent: Thursday, February 04, 2010 8:12 AM ~~~ To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF3 DS Lead Techs; CPF3 Prod Engrs; Poletzky, Isabel C; NSK Problem Well Supv; NSK Well Integrity Proj Subject: KRU 3F-09 (PTD# 185-270) Report Of TxIA Communication Attachments: 3F-09 Wellbore Schematic.pdf; 3F-09 TIO Plot.pdf Guy/Tom/Jim, :/ Kuparuk gaslifted producer 3F-09 (PTD# 185-270) is suspected of having TxIA communication based upon a failed waiver compliance TIFL. It is assumed that a leaking aaslift valve is the source of communication so slickline wi attempt to repair if possible. The well will be added to the SCP report and will be fixed or shut in by 03/01 /10. Attached is a wellbore schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 ~.,~; /~, ~~~ ~ ~~.i Cell 907-943-1720 / 1999 ~"~%y Pager 907-659-7000 #909 2/4/2010 I ~S -z~~ Well Name 3F-09 Notes: Tx1J~ Report to AO~"~~'G End Date 2;'1512010 Days 120 Start Date 1018!2009 Annular Communication Surveillance 1600 -- -- - _ .... _ . ..._ ..__._._.~.._.__..__.__._._- __ r 160 W H P ___~_.._...______. _._- - IAP ~t"' OAP 140 1400 W HT 120 1200 .~A- 100 1000 .y LL 80 800 Q - - 60 600 - 40 400 200 L~ C~F~ 6J - ~ 20 - 0 0 Oct-09 Nov-09 Dec-09 Jan-10 Feb-10 asap DGI ' aooo ~MGI 3soo PWI ^ 3000 ~~SWI m 2500 ~BLPD zoao U ` I !. .00 __ u • _ _ __ _ _ ~ KUP ~ Cor~act~F~hiilips ( ~ Att~lbutes - uL-rc tir~HUWI 1 aCM<s, Rl•:. ~ J ~'~~i;g000~ _ _ - Fleld Nalra KUPARUK RIVER UNIT 'Yell Status (PROD Commerrt H2S (ppm) Date Anne "' -- __._. SSSV: NIPPLE 60 1/1/2008 Lasl _ Well COn iA~=3F-0~1I5/2009 '.:~~~-1J AM - schamatic~ Annotation Depth (RKB) End Date Annotation Las, Tag: ELMD 7.430.0 11/62008_ Rev_Reason: GLV C/O ~ ~ ~~ ~ Casing Strings 5tnng UD String ID 15e Dep CONDUCTOR I Casing Descriptloh Unl ON Top (RKB) (RKBI 115 ~ ~ CONDUCTOR i6 15.062 0.0 1' SURFACE 95/8 8.765 0.0 3,4' NIPPLE, n1 ;~ PRODUCTION 7 6.151 0.0 7,6( PRODUCTION 51/2 4.950 0.0 7,Or Tubing Strings GAS LIFT, 2,944 SURFACE, 3.415 GAS LIFE, 1 i ((B 4,655 GA6 LIFT, 5,747 ~i ~ GAS LIFT, 6,415 GA6 LIFT, ~~ 6,%7 NIPPLE, 7,014 ! ~1 E CSR. 7,021 3 g( PRODUCTION, ~ I -J ` 7.046 SBE, 7,046 L _ , PACKER. 7,079 c _ 1~ NIPPlE, 7,129 ~~ F Overshot, 7,138 TBG CUT, _ 7.138 i i SBR, 7,152 ' I r. PACKER, 7,169 Y TUBING, 7,138 . IPERF, 7,252-7,343 ~I k._ .~ NIPPlE, 7.373 SLEEVE-O, Y,!,~` 7,373 11 PACKER, 7,383 NIPPLE, 7,383 -~ SOS, 7,406 (L 1 f ~ TTL, 7,407 { IPERF, 7,4za7,4sa ' PRODUCTION, 7,603 TD. 7,785 In Perforati Set Dep[h (ftK8) ievable, Fish, etc.) 7/252006 -OPEN. ng Wt Strong stttl I Grade Shot Top (ND) Bim (ND) Dens (RKB) (RKB) Zone Date (sh.^ Type 5,809.8 5,883.3 C-4, C-3, C-1, 1/17/1986 12.0 IPERF 5" Scallc UNIT B, 3F-09 phasing 5,948.4 5,972.4 A-2, 3F-09 1/17/1986 4.0 IPERF 4" Carric phase &_Safety _ _ _ Annotation fE: WAIVERED WELL-OOAxATMOSPHERE COMMUNICATION-SEALTITI fE: WAIVERED WELL:OA x OOA COMMUNICATION 10"x COND; 7"x10" C( fE:WAIVEREDWELL:IAxOA-GOOD5.5"x7" TxIA-GOODTx5.5" _ 3F-09 ax Angle & MD 'TD In~l i , :dD (ttk~.8) Ac[ 8Im (ttK8)~ 47.02 5,100.00 7,785.0 rte KB-0rtl (ft) Rig Releue Dete '/8/2005 41.79 11/18/1985 End Date 1/52009 n(ND) String Wt r String B) Illu/rtl Grade Strina Too Thrtl 5~~~11b~t'~1~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth L ~~~ ,,... ~_~ ~.~ G~ 3~ oq Well Job # Log Description ~;~- N0.4985 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11 /25/08 2V-07 12096561 INJECTION PROFILE - ~ 10/31/08 1 1 3A-11 12100434 INJECTION PROFILE - 10/31/08 1 1 iG-09 12100434 INJECTION PROFILE 3 ~- 11/01/08 1 1 2V-11 12061724 PRODUCTION PROFILE ~ 11/02/08 1 1 2C-14 12096565 PRODUCTION PROFILE L~ - 11/04/08 1 1 30-01 11975792 LDL 11/05/08 1 1 3F-09 12100435 PRODUCTION PROFILB ° 11/06/08 1 1 2V-12 12096567 PRODUCTION PROFILE - 11/06/08 1 1 3A-07 12096568 INJECTION PROFILE - 3 11/07/08 1 1 2A-20 12100434 INJECTION PROFILE • - 11/08/08 1 1 iG-17 11975792 LDL 11/09/08 1 1 2U-04 12100434 INJECTION PROFILE f~- 11/10/08 1 1 2U-05 12096572 INJECTION PROFILE 11/12/08 1 1 1F-06 12100457 PRODUCTION PROFILE 11/13/08 1 1 1B-06 12080456 PRODUCTION PROFILE 11/13/08 1 1 1B-05 12080457 INJECTION PROFILE (f(~ 11/14/08 1 1 2U-10 12080459 PRODUCTION PROFILE - ~ 11/16/08 1 1 2C-15 12100462 PRODUCTION PROFILE Z 11/18/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder SCANNED SEP 082006 Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: . \ I! 5-' 'J-1° Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043",1{you have any questions. /' / Sincerely,(/' Il' / fi ~,¿;? t/b /{ /' þ/ .ß~';I/ _ j(f / . . "~/ I/~~/"'~ ?' /,",í' / 'I M.J.loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date .' .' 3.F~Ø,t . r.1&5.¡;'2~~ -'. .. NA . . ~ r 1.5'. '.' ,8/21'f~Q()ß 5 . . 3F-02 1 85-226 24' 7.0 8/14/2006 7.5 8/21/2006 ßP,f.O~ ;: .··.1$~2:21 .' ~c;,·~_ J3~4:ì' . .- .... ·2:3 . ". - 8Jt~f2Q.Pß J"H~'3' . . S/Z1lZflÐ.ô: ; . ...' .'_ _i~__ ".Ä» .'~_ -Yo, ,-t 3F-04 185-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 jJi1'iQ5c/; ~ .... .'5.1 . ". ",:' ". > 81t"4'/2!JÐ'6 f '1:5,· '. . . "S/:.2ff2Øð6" 3F-06 Did not modify 3F,:a7 <', '.'1$Z~;> ..' .. " .. 6,6 . S/f4120Øô .'. . 7~5 . '; 8/21l~flQ6 '.' 3F-08 1 85-246 1 1 '4" 2.6 8/1 4/2006 6.6 8/21/2006 . ·3F-~~$ . . .' . :,H3~7t\.i Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 3/ž-11 . : . 185i:ž't2 L<·S·F .:'. .,' NA.. N~~. .... c" 1.T . ,~¡2~/~ºD.Q, . ~,' -";_0.,, 0 '_ ~" ..;- -C'-'_'_'c,,¿'·__ 3F-1 2 1 85-273 7'4" 1 .8 8/14/2006 6.2 8/23/2006 . . ·.1~~Þ"1~1't;;-{... ! . . NA ": . . . . :2j'! . ,.~ ' ·'·Y' .:: èBI2Sf2'0Q~' . .' ~ 1 85-292 Did not "'UUII . 6" ! = 2:4'. .,' .- '.. . i . 8'J't4fl2Q.Ó6/~ :" '. 9.7.·.', ., af~3Z2PQ6. '. 3F-16 196-151 NA NA 2.7 8/23/2006 3E.:;t7 ' ~. ··.·;{·.ot,,· : " 3:1·. .' 'Slm¡20fl6: " 8 .. ..' 8Iz~12jj~6::: .' '.' <' , '. ' 3F-1 8 196-112 4' NA NA 28 8/23/2006 ª1!~t9: .' .' ':,2~4;001:ß'< I' . { . '; ··.····.N'A .... . 8n NA .. . . ' 2. . . ,.j8Þ~Wl20'ØÉ),· 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F-21 20~2.Ð3 . '45" . NÄ NA 31 .·8IZ1Î2Öþ6 . ~ ( Jim Ennis Staff Wells Engineer Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 August8,2005 RECEIVED AUG 1 6 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Comm¡~s¡or; Anchorage Subject: Report of Sundry Well Operations for 3F-09 (185-270/305-127) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the Kuparuk well 3F-09. If you have any questions regarding this matter, please contact me at 265-1544. Sinc~ ~%.f4-- V~-- , Jim =:nnis Staf Wells Engineer CPAI Drilling and Wells SCANNED AUG 1 7 2005 J E/skad 1. Operations Performed: ( STATE OF ALASKA R.ECE:IVED ALASKA OIL AND GAS CONSERVATION COMMISSION AU G 1 6 2005 REPORT OF SUNDRY WELL OPERATIONS Stimulate D A;ä~ké! Oil ~~ï~ Cons.~!lllnission . Anchoraoe D Waiver D Time 'Èxtenslorf Re-enter Suspended Well D Abandon D Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Perforate D 4. Current Well Status: Development 0 Stratigraphic D Service Plug Perforations D Perforate New Pool D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 93' 8. Property Designation: ADL 25643, ALK 2574 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING PROD. CASING Perforation depth: 5. Permit to Drill Number: 185-270 1 305-127 6. API Number: 50-029-21480-00 Exploratory D D 9. Well Name and Number: 3F-09 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 7785' feet true vertical 6237' feet measured 7439' feet true vertical 5960' feet Length Size MD 115' 16" 115' 3322' 9-5/8" 3415' 7510' 7" 7603' 7011' 5.5" 7046' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 3001' 6092' 5645' Measured depth: 7252'·7343',7424'-7454' true vertical depth: 5810'-5883',5948'·5972' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, IBT Mod @ 7022' MD; 3.5", 9.3#, L-80, EUE @ 7136' MD; 3.5", 9.3#, J-55, EUE @ 7376' MD; 2.875",6.5#, J-55 @ 7407' MD Packers & SSSV (type & measured depth) Baker Premier 7" x 3.5" pkr, Otis 'RRH', Otis 'WD' pkr= 7079', 7169', 7383' Cameo DS landing nipple @ 471' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none RBDMS BFl AUG 1 7 2005 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1780 3192 1383 3352 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl 749 851 Casinç¡ Pressure Tubinç¡ Pressure 223 226 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Jim Ennis @ 265-1544 ~iS Form 10-404 Revised 04/2004 Contact Printed Name Signature WDSPL D Title Phone Date f3 ~fj/)5 Prepared b~:~;l ~IISUP-Drake 263-4612 ORIGINAL ,,,/ u \ t . .,,' ~ \;¡ Submit Original Only ( Page 1 of 3 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-09 3F-09 WORKOVER/RECOMP n3scm@conocophillips.com Nabors 3S Date From- To Hours Code Sub Code Phase DMOB I MOVE MOVE MOVE 6/29/2005 15:00 - 20:00 20:00 - 00:00 5.00 MOVE 4.00 MOVE 6/30/2005 00:00 - 03:30 3.50 MOVE RURD MOVE 03:30 - 04:00 04:00 - 08:00 08:00 - 16:30 0.50 MOVE SFTY MOVE 4.00 MOVE RURD MOVE 8.50 WELCTL NUND DECOMP 16:30 - 17:00 0.50 WELCTL NUND DECOMP 17:00 - 00:00 7.00 WELCTL BOPE DECOMP 7/1/2005 00:00 - 02:45 2.75 WELLSR PLGM DECOMP 02:45 - 09:00 6.25 FISH PULL DECOMP 09:00 - 17:00 8.00 FISH CPBO DECOMP 17:00 - 20:30 3.50 FISH PULL DECOMP 20:30 - 00:00 3.50 FISH OTHR DECOMP 7/2/2005 00:00 - 09:30 9.50 FISH OTHR DECOMP 09:30 - 17:30 8.00 WELCTL BOPE DECOMP 17:30 - 18:00 0.50 WELCTL SFTY DECOMP 18:00 - 21 :15 3.25 WELCTL BOPE DECOMP 21 :15 - 22:15 1.00 FISH PULL DECOMP 22:15 - 22:30 0.25 FISH PULL DECOMP 22:30 - 00:00 1.50 FISH PULL DECOMP 7/3/2005 00:00 - 03:30 3.50 FISH PULL DECOMP 03:30 - 12:00 8.50 FISH PULL DECOMP 12:00 - 14:30 2.50 RIGMNT RGRP DECOMP Start: 6/29/2005 Rig Release: 7/8/2005 Rig Number: Spud Date: 11/11/1985 End: 7/8/2005 Group: Description of Operations I Finish rigging dwn workover rig. Prepare to move. Move Rig from 3N-09 to 3F-09. Rig on location at 3F-09. Prepare to spot rig. Rig spotted at 24:00. Rig spotted. Crews taking lunch. Peak still delivering loads from 3N-09. Crew installing spill containment. Begin wiring rig. Safety meeting prior to raising derrick. Raise derrick, and rigging up Rig accepted @ 08:00. Nipple down wellhead install blanking plug. Nipple up BOP's Continue to nipple up BOPE. Prepare to perform BOPE test. Change out Rams on single gate to 5.5". Rig up to test BOPE. Blanking valve not holding. Work all air out and re-attempt. No luck. Screw in landing joint and attempt to test. No luck. Threads too corroded to test. We are able to screw in though. Pressure leaking by threads. Call State and talk to Chuck Scheve for waiver to pull tubing to 100' and run a storm packer for BOPE test. Pull BPV. Unable to pull after several attempts. Change out pulling tool and able to finally pull. Prepare to pull tubing. Pull tubing to 114K + 1 OK for Block wt. No indication of pipe movement. Exercise while awaiting SWS Chemical cutter. SWS called at 03:30. SWS confirmed leaving Dead horse at 05:30. Ordered 6' PUP from warehouse for extension. SWS on loc. @ 09:00 Rigging up and safety meeting pre cut. Chemical cut tubing @ 7135' RKB with over pull on tubing, positive indications of cut. 16: 10 SLB OOH pulled 105K on tubing successful cut. Rig SLB down and pull two stands to run and set storm packer. Prepare to re-arrange rig for setting packer. Set down all SWS lubricator equip and redress for standard running. Set storm packer at 20' below tubing hanger. Pressure test storm packer against BOPE blinds to 3,000 psi. Test passed. Prepare to nipple off BOPE and Casing head adapter. 7" casing raised as we are ND 11" 3000 casing spool. Cut 18" of 7" casing off. NU casing and tubing spools. Offset injectors are injecting at 3F-11 4774, 3F-12 830, 3F-4 2700 BWPD, 3F-03 5.4 mil GPD 2U-11 3125, 2U-14 5045 BWPD. Informed CPF2 and CPF3 to not increase rates until we get NU. Test BOP's Rams, blinds, control valve and choke manifold to 250/3000 psi. and annular to 250/2500. Pre-Tour meeting. Continue testing BOP's, Floor valves, annular. Pull storm packer. 62,000# up wt. Inspect packer, all seals and slips in place. Prepare to pull tubing OOH. Re-rig to pull tubing. Stage floor valve. Pre-job safety meeting about pulling tubing with manual back-ups. Raise SWS spool to rig floor and install control line for retrieval. Chain dwn to rig floor for safety. Test all rig alarms. Begin pulling tubing to surface laying down sideways. Up WT = 62,000#. Continue to POOH laying down sideways. Monitoring hole fill. Pulling completion. Switch generators due too lack of power. Prepare to change out break out ram during fishing turnaround. Returned SWEENY to Nabors 7ES. Recovered 36 Bands off of control line. Old completion OOH, empty pipe shed and prepare to run fishing string for remaining completion. Chemical cut is very clean. Rig maintenance Printed: 7/15/2005 2:12:37 PM Page 2 of3 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-09 3F-09 WORKOVER/RECOMP n 3scm@conocophillips.com Nabors 3S Date From - To Hours Code ~~dbe Phase 7/3/2005 12:00 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 18:00 18:00 - 20:00 2.50 RIGMNT RGRP DECOMP 1.00 WAlTON OTHR DECOMP 1.00 RIGMNT OTHR DECOMP 1.50 FISH PULD DECOMP 2.00 FISH PULD DECOMP 20:00 - 00:00 4.00 FISH TRIP DECOMP 7/4/2005 00:00 - 02:00 2.00 FISH TRIP DECOMP 02:00 - 02:30 0.50 WELCTL SFTY DECOMP 02:30 - 06:30 4.00 FISH TRIP DECOMP 06:30 - 09:30 3.00 FISH TRIP DECOMP 09:30 - 15:30 6.00 FISH CIRC DECOMP 7/5/2005 15:30 - 00:00 8.50 FISH PULL DECOMP 00:00 - 02:30 2.50 FISH PULL DECOMP 02:30 - 03:45 1.25 FISH PULD DECOMP 03:45 - 05:15 1.50 CASE SFTY CMPL TN 05:15 - 09:00 3.75 CASE RUNC CMPL TN 09:00 - 00:00 15.00 CASE RUNC CMPL TN 00:00 - 01 :00 1.00 CASE RUNC CMPL TN 01:00 - 03:15 2.25 CMPL TN CIRC CMPL TN 7/6/2005 03: 15 - 07:00 3.75 CMPLTN PCKR CMPLTN 07:00 - 18:00 11.00 CMPL TN NUND CMPL TN Start: 6/29/2005 Rig Release: 7/8/2005 Rig Number: Spud Date: 11/11/1985 End: 7/8/2005 Grou p: Description of Operations on derrick ram, Wait for Drill site operator for hot work permit. Continue to replace hyd. ram for break out. Pick up BAker fishing string and make up to Baker hand specs, Old completion OOH, empty pipe shed and prepare to run fishing string for remaining completion. Chemical cut is very clean. Pipe strap length on old tubing string 7138.38'. Making up fishing tools by Baker. RIH with PH6 make up torque = 7,000#. Average 20 JTS per hour. Enviromental walk thru on rig. Looks good, some water puddled up in motor room. Cleaned up. Continue to RIH with 3.5" PH6 Hydril torque value 7,000#. BOP drill. Safety valve on in 30 sec. Brine at 9.6 PPG. All personal in position within one minute. Concerns about the Hydromatic clutch. Called out Nabors mechanic to replace. At the same time we will replace the Hydromatic glycol butterfly valve, It is currently all or nothing. Continue to RIH with fishing string. Nabors mechanic in route to change out hydromatic clutch asym. Shift CO Nabors mechanic on Location. @ 7084. H2S alarms going off constantly mustered several times bad sensor suspected. Hand held sensor is reading normal. At 7084' with fishing string reverse circulating two hole volumes. Pickup one joint and Circulate down to fish with Baker overshot grapple 6 collars, Oil Jars and accelerator. Up WT prior to washing over fish is 95K, Wash down to 7135' pump pressure increase indicating overshot on fish. Work pipe down to 7142' WT. indicator at 30K from 55K down WT. Hit 5 Jar licks and SBR came free last hit was 175K pull. Pull one joint and circulate bottoms up. POOH with fishing string laying down PH·6. Up WT 1 OOK 4K to 5K increase per jarring. Electrician, on location, repairing H2S alarm. Hole condition stable. OOH with work string begin laying dwn drill collars. No fish on end of pipe. Marks inside of grapple indicate l' of fish swallowed. Prepare to pick up 51/2" casing completion with 6" PBOS. Fire drill. Continue to prepare for 5 1/2" completion. Continue preparing to prep to run 5 ? casing. Change SBR to poor boy overshot. Running new 5-1/2" casing with Poor boy Overshot, X Nipple, SSE and Premier Packer. Run remainder of 5-1/2" casing; tag up 7118' 7130' RKB D-9. Begin rigging up to circ head to casing. Begin pumping 2.5 bpm, ease down onto stub. See 20 psi increase in circulating press; RIH approx 5' to no-go. Pick up 1'. Prep to rev-circulate inhibited brine. Close bag and circulate 41 bbl inhibited brine followed by 23 diesel down 5-1/2"x7" annulus. Shut down. Drop ball & rod; let fall for 1/2 hour. Bleed off annulus (hydrostatic) to zero to make sure ball is seated; open up bag an bring up 5-1/2" casing pressure to 4000 psi to seat pkr. MITIA 5 1/2 X 7" to 3000 psi--good. Begin nippling down BOP stack to prep to cut off casing. Cut casing, Printed: 7/15/2005 2:12:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 7/6/2005 07:00 - 18:00 18:00 - 22:30 7/7/2005 22:30 - 00:00 00:00 - 13:30 13:30 - 18:00 ( Pag e 3 of 3 ConocoPhillips Alaska Operations Summary Report 3F-09 3F-09 WORKOVER/RECOMP n3scm@conocophillips.com Nabors 3S Sub Hours Code Code Phase Start: 6/29/2005 Rig Release: 7/8/2005 Rig Number: Spud Date: 11/11/1985 End: 7/8/2005 G rou p: Description of Operations 11.00 CMPL TN NUND CMPL TN 2.51' off jt #170. Change out tubing spool with reconditioned one with bushings for the 5-1/2" casing. 4.50 CMPL TN SEaT CMPL TN Test new packoffs to 3k psi, held for 10 mins-good.Test BOP stack to 3500 psi-- good. Prepare to Run completion. 1.50 CMPL TN RUNT CMPL TN Conduct pre-job safety meeting. Begin running new 3-1/2" completion. 13.50 CMPL TN RUNT CMPL TN (cont.) Running new 3-1/2" completion. Note: Nabors 3S RKB w/ new spool: 18. 92'. 4.50 CMPL TN CIRC CMPL TN Completion ran 56K preset weight. Pump 15 bbls inhibited brine followed by 60 bbls of brine displacement down the tubing up the IA. Space out with joint 232 using (1) 9.82 pup and 1 2.85 pup below. And (1) 6.06 CO pup to 8rd and hanger with a 4.12 8 rd pup on top to space out. RILDS. Test tubing to 2500 PSI for 30 mins -- good. Bleed tubing to 1500 psi. Test IA to 2500 psi, hold for 30 mins -- good. Bleed pressure off tubing and shear SOV. Install BPV and begin nippling down stack. (cont) Finish nippling down stack Replace pack-offs, set tree / tubing head adaptor. Having difficulties getting tree / tbg head over seals. Land tree. Install test plug and pressure test tree and packoffs to 5000 psi-- good. Pull test plug and install BPV. Release rig at 06:00 am. Begin prepping for rig move. 18:00 - 20:00 2.00 CMPL TN DEaT CMPL TN 20:00 - 00:00 4.00 WELLSR PLGM CMPL TN 7/8/2005 00:00 - 03:00 3.00 WELCTL NUND CMPL TN 03:00 - 06:00 3.00 CMPL TN SEaT CMPL TN 06:00 - 12:00 6.00 MOVE DMOB MOVE Printed: 7/15/2005 2:12:37 PM ConocoPhiUips Alaska, Inc. 3F-09 TUBING (0-7022, 00:3.500, 10:2.992) "ROOUCTION (0-7046, 00:5.500, Wt:15.50) TUBING (7022-7136, 00:3.500, 10:2.992) Overshot (7138-7139, 00:6.000) TUBING (7138-7373, 00:3.500) TUBING (7136-7376, 00:3.500, 10:2.992) Perf (7252-7343) TUBING (7376-7407, 00:2.875, 10:2.441 ) SOS (7406-7407, 00:2.875) Perf (7424-7454) __4Þ_ ~ .~;~~~~:;j :~:~:, Annular Fluid: Reference Loq: 35' RKB Last T aq: 7439 Last T aq Date: 7/23/2005 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 PRODUCTION 5.500 Tubing Strin~ - TUBING Size Top 3.500 0 3.500 7022 3.500 7136 2.875 7376 Perforations Summary Interval TVD 7252 - 7343 5810 - 5883 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr Mfr 1 2944 2656 CAMCO KBG-2-9 2 4655 3893 CAMCO KBG-2-9 3 5747 4664 CAMCO KBG-2-9 4 6415 5158 CAMCO KBG-2-9 5 6967 5583 CAMCO KBG-2-9 Other (plu~s, equip., etc.) - JEWELRY Depth TVD Type 471 471 NIP 7014 5620 NIP 7021 5626 CSR 7046 5645 SBE 7079 5672 PACKER 7129 5711 NIP 7138 5719 TBG CUT 7138 5719 TUBING 7138 5719 Overshot 7152 5730 SBR 7169 5743 PKR 7373 5907 NIP 7373 5907 SLEEVE-O 7383 5915 7399 5928 7406 5934 7407 5935 General Notes Date Note 4/13/2004 WAIVERED WELL: (1) OA x ATMOSPHERE COMMUNICATION - REPAIRED W/SEAL TITE 4/7/2004 (2) IA x OA COMMUNICATION API: 500292148000 SSSV Type: NIPPLE 7424 - 7454 5948 - 5972 PKR NIP SOS TTL KRU 3F-09 Well Type: PROD Orig 11/18/1985 Completion: Last W/O: 7/8/2005 Ref Loq Date: TD: 7785 ftKB Max Hole Anqle: 47 deq @ 5100 Anqle @ TS: 36 deg @ 7254 Angle @ TD: 37 deg @ 7785 Rev Reason: REFORMAT Last Update: 8/10/2005 Bottom 7022 7136 7376 7407 Top Bottom TVD Wt Grade Thread 0 115 115 62.50 H-40 WELDED 0 3415 3001 36.00 J-55 0 7603 6092 26.00 J-55 BTC 0 7046 5645 15.50 511 HYDRIL TVD Wt Grade Thread 5626 9.30 L-80 IBT MOD 5717 9.30 L-80 EUE 5910 9.30 J-55 EUE 5935 6.50 J-55 Status Ft SPF Date Type Comment 91 12 1/17/1986 IPERF 5" Scalloped HJ II Csg Gun; 120 deq. phasinç¡ 30 4 1/17/1986 IPERF 4" Carrier HJ II Csg Gun; 90 deq. phase Zone t.C-3,C-l,Ur B A-2 V Type VQD Latch Port TRQ Date Vlv Run Cmnt DMY 1.0 BTM 0.000 0 7/7/2005 DMY 1.0 BTM 0.000 0 7/7/2005 DMY 1.0 BTM 0.000 0 7/7/2005 DMY 1.0 BTM 0.000 0 7/17/2005 DMY 1.0 BTM 0.000 0 7/7/2005 Description CAMCO DS LANDING NIPPLE set 7/7/2005 CAMCO DS NIPPLE set 7/7/2005 BAKER CSR SEAL ASSEMBLY set 7/7/2005 BAKER 80-40 SEAL BORE EXTENSION set 7/7/2005 BAKER PREMIER PACKER set 7/7/2005 HES 'X' NIPPLE set 7/7/2005 TUBING CUT FOR WORKOVER 7/7/'2.00~ 7/1/0t: 10 2.875 2.813 3.850 4.000 2.875 2.813 2.992 2.992 2.935 3.000 2.970 2.750 2.441 BAKER POORBOY OVERSHOT set 7/7/2005 Otis Otis 'RRH' AVA BPL NIPPLE AVA BPC SLEEVE Set on 1/9/98 - OPEN. Unable to pull 6/20/2001 due to scale. Otis 'WD' Cameo 'D' Nipple NO GO Cameo 3.000 2.250 2.441 2.441 SPHILLIPS Alaska, Inc':- ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Well Name API # PTD# AFE Number 3F-09 500292148000 Producer Injector WELLS 10083389 DIRECTIONAL INFORMATION Original RKB 35' Doyon 9 Max angle of Hole Angle @ TO SITP _ç-º-r-Iº-U~T9.R LSURF CA§ING !-~-ºº--~~SlNG _ -L_._ ! PROD CASING I P:~~g' - - - ¡ - Tu~ng ! ; Tubing . i : Tubing I' Top 7252 7424 Depth (Top) 471 2.944 4655 5747 6415 6967 7014 7021 7046 7079 ~7129. 7138 7152 7169 7373 ~ .1383 _._---.13!j9 __ Z406 . 7407 47.0 36.4 @ WELL INFORMATION lAP OAP Description ----- -- - ---~-- - -._----- CASING I TUBING DATA ! Size IQL - : . 16 -- - - 0 9.62~ --t ----º--- 7_ --I 0 5.5 i 0 . 3.5 _ _ -=L:.~_~ -0 3.5 702.L . 3.5. . __ _ _ -----.L1~ 2.87~ 7'}~_ -- f -- Revised WELL HISTORY HANDOVER FORM x New Well Workover Sidetrack To Production To Drilling Completion Date x <c"~,~ x KOP 1100 DOWNHOLE INFORMATION Drillers TO 7785 PBTD !fop of fill or Junk 7445 RKB Date Tagged 11/04/04 5241 DOWNHOLE PLUGS BHP I Depth I Date Ilnsl. (X or comment) BPV Installed X 2 Way Check Weight (ppg) Top (MD) Bottom (MD) Downhole Plug X 6.90 0 2500 IA VR Plug 9.60 2500 7135 OA VR Plug 9.60 0 5775 9.60 5775 7037 9.60 0 6500 Other 9.60 6500 7037 Other Bottom TVD Wt Grade Thread Remarks 115 115 62.58 H-40 3415 3001 36 J-55 7603 6092 26 J-55 BTC 7046 5646 15.5 511 Hydrill 7022 5626 9.3 L-80 IBT MOD 7136 5717 9.3 L-80 EUE 7376 5910 9.3 J-55 EUE 7407 5935 6.5 J-55 PERFORATION INFORMATION (All Active Intervals) Bottom 7343 7454 SPF 12 4 Casing fluid ¡ Diesel ~1/~"XZ" ! Inhibit~d Brin~u Casing fluid ! Brille _ _1.-1j~"x5-1/2" _ t InhLbited Brine Tubing fluid I Brine i Inhibited Brine I - ¡-. I --------- Gun Type I Charç¡e I Orientation 5", 12 SPF, HJ II 4", HJ-II Date 01117/86 01/17/86 COMPLETION INFORMATION (Use default or pick list) Tree FMC - 5M - 3-112" (Manufacturer I Modell Type 1 Pressure Rating) Packott Assembly _ __1_ New (X) TlJQi!1g _ --. _ -f- ~ Proßuc:tion gasing. I Surface Casinç¡ I Mechartical Integrity _ .J'ubiIl9. Prod Anl1ulus. Surf Annulus __IeslPfessure 2500 2500 Valve Size Latch Length 4.12 1" DV 1" DV 1" DV 1" SOY 1" DV Bottom Bottom Bottom I Bottom ¡ Bottom I I ì ! Tree Cap Connection 5-3/4" ACME Tubing Hanger Connection 3-1/2" 8RD EUE Replaced (X) X X Test Pressure 5000 3000 7/8/2005 7/6/2005 Pass? (Y/N) Y Y State Witness (X) Comments KNOWN Communication (X for known comm) Tbg X IA IAXOA Other X Note: All boxes checked require additional comments below 0.0. 3.5" 3.5" 4.725 4.725 4.725 4.725 4.725 4.620 4.500 5.0" 5.980" 4.49" 6.0" 3.500 3.5" 3.5" 3.5" 2.875" 2.875 Arctic Pack (Y/N) I y I Cmnt Shoe (Y/N) I GENERAL COMMENTS ~Çleakinto con~uctor. _ _ __.. _G.he.l1lc:u.LmadeªtI13.!)'Jlli~ ¡JQQrboy.oversh.QI. wI ne~5-1/2" covering tubing nub approx 4' . .1/I.IBJ:set at 7171' (midelerTlent d¡¡ptj1). of.8.tedj()plJ!..§lips 1.5' up from bottom of packer, seal element is 3' up from bottom of packer RHC .Y>'~hJ3.odanc!.BaILoDseßt aU12~'J~~B X nipple witt) a 1 1/8 fishing neck Item Manufacturer Type I Model Tubing Pup u _ __ I _LAJ'JºJ\JIf'P_L_~ ~ -º-~!!'-Co ! OS GLM #1 _ _ C_al!l(~o_ i KBG 2-9 GI,Mj 2___ _ Camco I KBG 2-9 GLM #3._ Camco I KBG 2-9 _GLM 1t4 Camco i KBG 2-9 GLM!5 ___ Camc:o_ ! KBG 2-9 _NIPp~ __ g-ª-mco ¡OS ÇSR Seal A.ss'ªrT1bIL B~~_ i nSeal E!()f'e E~._ _ _ Baker. __ 180-40 PackE;!r.____ ªª-ker ¡Premier _ NippjE¡ _ _ __ IiE~_ i X .OvershoL Baker ~ Poorboy P::~~~Fi___ ~~~S ._- IRRH SLOG ~L~. ~=- AV¡;------¡¡ BPC NIPPbE. ___ AVA _ BPL PACK~B __ ~_ iWD . NIPPLE ._ ç<!f11~ iD _ _ _SIjEAR'sUEL__ ç-ª!!1co I __WLE_G_ __~_~ I EQUIPMENT DETAIL Rig Name Nabors 3S Drilling Representative Wells Group Representative (Yoakum/Kennedy) Title Riç¡ Supvr (Ty Senden) Title Wells Spvr (For handover from Drilling only) Title Prod. Enqr Revised 03129/02 Production 1 Operations Representative Signatures Required 1.0. 2.992 2.875 2.900 2.900 2.900 2.900 2.900 2.812 3.850 4.0" 2.875" 2.813" 2.935" 3" 2.97" 2.441 2.75" 3" 2.25" 2.441" 2.441" Date 07/08/05 Date Date Return completed form to Wells Aide ) ) e~,,:"~ ~ll::Jb~' l~ ~"""';;:'B ,!,I i¡""L.~ (.! . i 111',', ' I! 'I iii il. \..,. 'I' ¡\ ,I (l '6 ,,·<;\~l.¡ /.., 't1 II i :~. ~ ; ru 1 ':1: ! i-~\\ II! ¡ ~I '.......:.II, '.~;¡:, ;W '. ~ ~IJ.¡¡,;, ~~ if'~r'¡i fir' ¡ fi : :11'1 L....,1 ~ 't ¡ ! ¡ I':....:J \' .l'Vi ¡¡II \.l~ ( ¡ iI ,,_, ¡:..oJ mil ¡)',,\\, iIl.i . '¡', 'I ¡ jJ ì, ~ J j' ,: \ 1.1 'I JJu¡i.:~ FRANK H. MURKOW5KI, GOVERNOR AIfASHA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. P.o. Box 100360 Anchorage, AK 99510 'flfJ(fg};fØ . Re: Kuparuk 3 F -09 Sundry Number: 305-127 CC'/1hn~'iE'-r"" WlRA'Y 2. 6 2005 ~.J' ,,;M!1~~ ~,~,,~ I\f! ~ Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior C rt unless rehearing has been requested. / '\ { tce '~ . orm Chairman DATED thisil day of May, 2005 " Enc!. ) " é:onoc~hillips Alaska ') P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED MAY 1 8 Z005 AjastŒ m, & GtlS Cons. Gommj$sion ~~m.:horage May 17, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3F-09. The purpose of the proposed 3F-09 workover will be to run new 5.5" casing to surface to create a new inner annulus, and to run a new 3.5" completion. 3F-09 has OA x OOA communication via a surface casing leak, and recent attempts to repair the casing leak using sealant per Sundry # 305-024 have failed. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-1544. Sincerely, \if- Jim Ennis We ~s Engineer CPAI Drilling and Wells ¡ .., L \...,} ~ .. I "'"-'" ¡ ¡ 'J r·"\ \ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLiCATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D ') 1. Type of Request: D «CbM Suspend D ~ fð" Repair well 0 D Pull Tubing 0 Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 93' 8. Property Designation: ADL 25643, ALK 2574 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7785' 6237' 7433' Casing Length Size CONDUCTOR SUR. CASING PROD. CASING 115' 3322' 7510' 16" 9-5/8" 7" Perforation Depth MD (ft): 7252'-7343',7424'-7454' Packers and SSSV Type: pkr= OTIS 'RRH'; OTIS 'WD' SSSV @ 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Re-enter Suspended Well D 5. Permit to Drill Number: 185-270 ./" 6. API Number: /" 00;-;'/ ø -"tJ~ ) Perforate D D Stimulate 4. Current Well Class: Development Stratig raph ic o D Exploratory D D Service !1""""CE ~ ~~""' "" - ,-'VED <'6 MAY I 8 Z005 \ ,E~ G:\j:~ Gmu!;" r..;¡mn1~~~M W~~rehltm~ Annular Disp. D Time Extension D Other D 50-029-21480-00 9. Well Name and Number: 3F-09 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD TVD Burst Collapse 115' 115' 3415' 3001' 7603' 6092' Perforation Depth TVD (ft): 5810'-5883', 5948'-5972' Packers and SSSV MD (ft) pkr= 7169'; 7383' 1837' Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name :3o~ I, Zco5 Date: Signature ~ J~~~iS .~~ Tubing Size: 3.5" / 2-7/8" 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Contact: Title: Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D Mechanical Integrity Test D Location Clearance D 2 \ ...... '" 1M. "6ö \> Tts \- ~L-\ ~ Form 10-403 Revised 12/2003 Tubing Grade: J-55 Tubing MD (ft): 7376' / 7407' Service D Plugged D WINJ D Abandoned D WDSPL D Jim Ennis @ 265-1544 Wells Engir:¡ ,J Date 5(/7(05 Sundry Number: 30 s:- /.:? '7 ReDMS 8Fl MA Y 2 ::1 JOD5 ORIGINAL COMMISSIONER BY ORDER OF THE COMMISSION INSTRUCTIONS ON REVERSE Date~ /£ Submit in Duplicate ) ) Kuparuk 3F-09 General Workover Procedure Pre-Ria Work 1.) Shut In well and obtain a SBHPS. 2.) Perform a string shot at 7135' RKB for tubing scale removal just above the SBR. 3.) Set an XX Plug in the X Nipple at 7152' RKB. PT plug to 2500 psi. 4.) Pull DV in GLM # 7 at 7111' RKB and leave pocket open. 5.) Circulate well to 9.6 ppg Brine down tubing and up the IA through open GLM #7. 6.) PT casing to 2500 psi then bleed to zero. 7.) Prep location for Workover Rig. 8.) Set BPV within 24 hours of rig arrival on location. General Workover Procedure 1.) 2.) 3.) 4.) 5.) 6.) 7.) 8.) ç \-..)~~'O""-~ 9.) 10.) 11.) 12.) 13.) 14.) 15.) 16.) 17.) 18.) MIRU Workover Rig. NO tree. NU 13-3/8" 5M BOPE with VB rams. Pull BPV. Test BOPE. PU on tubing hanger. Cut tubing at 7135' RKB if tubing won't pull free from SBR. POOH with tubing to SSSV spooling control line. MU storm packer & RIH with tubing to 100'. NO BOPS, NU 5.5" Casing Head onto 7" Casing Head. Energize packoffs & PT void space. NU BOPS, run test plug, & test below blind rams. "\' I '(g \\ "fc..~cl Pull storm packer and lay down remaining 3.5" tubing. Make one fishing run to attempt to retrieve remaining stub if tubing was cut. Run new 5.5" Casing with overshot over SBR Stick or the remaining tubing stub to surface. Drop ball & rod to set Packer at - 7103' RKB. Bleed pressure off casing. NO BOPS. Set 5.5" slips. Cut off top section of 5.5" casing. Set packoffs on 5.5" casing stub. NU 3.5" tubing head on top of 5.5" casing head. Energize packoffs and pressure test. NU BOPS. Run test plug, close blind rams, and PT below blind rams. Open blinds & pull plug. Run new 3.5" completion and stab into Casing Seal Receptacle. Space out and land hanger. Pressure test tubing and new inner annulus. Shear out SOV. Pull landing joint, install BPV, NO BOPS, NU tree, pull BPV, set test plug, test tree & packoff. Pull test plug and set BPV. RDMO workover rig. Post-Ria Work 1.) Pull BPV and displace well over to Seawater & Diesel FP through SOV. 2.) RU Slickline. Pull RHC & ball/rod. Pull XX Plug at 7152' RKB. Pull SOV & install GLV design. 3.) Reset wellhouse and return well to production. ') 3F-09 Proposed Workover Current Completion I~ II ..... !!!.... a --. au ~~ .. II ~ ~ . . . . ..... ... Original SBR with X Profile Original Otis RRH Packer Original Otis WD Packer Original 2.25" Cameo D-Nipple 7" Liner ) Proposed 2005 Completion ..... ~~ I II II ... -'~¡Y¡ \ / . · . · -- \ / - . n . . II III · ..... ... 2.875" Cameo DS Nipple New 3.5" Tbg 5 KBG-2-9 GLMS New 5.5" Csg 2.813" Cameo DS Nipple 5" OD SBE (4" ID) 3.5 x 7" Premier Packer 2.813" Otis X Nipple 3.5" Tbg 10' HES SBR Skirt ) STATE OF ALASKA ) RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 REPORT OF SUNDRY WELL OPERATIO~aOiI&. 1 2005 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other Gas C~, C . . Aa"hlfll~K;;],,' omrmssion Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extensi'ð\'lUQ ~ Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development _ 0 Exploratory D 185-270 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360 50-029-21480-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 93' 3F-09 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: 10. Field/Pool(s): Kuparuk Oil Pool measured 7785' feet true vertical 6237' feet measured 7512 feet true vertical 6276' feet Length Size MD 115' 16" 115' 3322' 9-5/8" 3415' 7510' 7" 7603' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 3001' 6092' Measured depth: 7252-7343',7424-7454' true vertical depth: 5810-5883',5948-5972' . (. r"ò.Hl.iE"b'\, tV" C\V S· ;¿,\hü'! n.,,· i !I-\\ ,\ Ii 1 2005 Tubing (size, grade, and measured depth) 3-1/2" /2-7/8", J-55, 7407' MD. Packers & SSSV (type & measured depth) pkr= OTIS 'RRH'; OTIS 'WD' pkr= 7169'; 7383' SSSV= SSSV SSSV= 1837' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS BFl MAY 1 1 2005 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run_ Oil-Bbl 658 658 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 1145 2839 46 1145 2839 46 15. Well Class after proposed work: Exploratory D Development 0 Service D Tubinq Pressure 220 220 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 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: 305-024 Brad Gathman/MJ Loveland @ 659-7224 Jerry Dethlefì'-'\ _ f27:2s? Title ¿,..s-:; - f~ C-'~) Phone 7ð~~ o R \ G \ i~ ~A L Contact Printed Name Signature WDSPL D Problem Well Supervisor 907 -659-7043 Date f?"hS Form 1 0-404 Revised 04/2004 Submit Original Only ) ) ConocoPhillips Alaska, Inc. Kuparuk Well 3F -09 (PTD 1852700) REPORT OF SUNDRY OPERATIONS May 7, 2005 On February 7,2005, Sundry #305-024 was approved for ConocoPhillips Alaska, Inc. (CPAI) to attempt to repair a leak in the surface casing. The repair was to be performed by a vendor (SealTite International) using a proprietary sealant technology. Although significant reductions were made in the leak rate, the operation did not fully seal off the leak. A passing repair was to be judged by the ability to pass an MIT on the outer annulus (OA), but the repair did not hold over 200 psi without leaking. CP AI now intends to perform a workover on this well since the leak repair with sealant was unsuccessful. A log of the sealant repair operation is as follows: 2/4/2005 Vac out OA to 35', R/U 50' hose into OA for pressure monitoring after "Flex Plug II is pumped into OA. T 11/0=2401010. Replaced patches on cut-outs on conductor 2/25/2005 Seal-tite OA prep, Strap OA FL @ 35', Pull OA communication hose and re-install with weights on bottom to ensure hose is hanging straight down. ready for seal-tite. 2/28/2005 Seal-tite OA xOOA Leak, Double check OA FL @ 351, Rig up to OA with Seal-tite pump and pump 10 gallons of "Flexplug UL" to what should be approx l' below hole in OA and let sit, catch sample to verify solidity. After "UL" set, pump 3.5 gallons "Flexplug AL" which should have set accross OA hole to approx l' above. Let plugs cure overnight. RDFN 3/1/2005 Seal-tite OA x OOA leak - continuation and completion, Initial T/I/O= 180/2/vac Pull OA annulus jewelry and rig up Seal-tite equipment, Strap OA Seal-tite plug at 25' 8". Decide to pump another 4 gallons "Flexplug AL" combination as it appears OA hole may not be covered. (true location of OA hole is subject due to N2 blowdown and strapping conditions) Let sit 4 hours and strap OA Flexplug AL top at 23', OA hole should now be covered. Top off from 23' to surface with "Flexplug UL" Re-install Annulus jewelry, let Flexplugs cure for 24 hours before strapping top of plugs or pressure testing. 3/3/2005 MITOA failed (post Flex Plug treatment). T/I/0=290/5/0. Pulled VR nipple and strapped top of Flex Plug @ 10' 10". Left equalizing hose disconnected and re-installed VR plug. Rigged up tri-plex to opposing side. Pressured up OA to 100 psi. Shut down and let above and below Flex Plug equalize. Pressured up to 200 psi and repeated equalization procedure. Pressured up to 500 psi and shut down to equalize. Began to get fluid out of down spout on conductor. Monitored pressure for 15 min and OA pressure fell off to 300 psi. Bled OA down to 0 psi. Pulled VR plug and strapped top of Flex Plug @ 10' 10". Re-installed hose to VR nipple. Rigged up N2 above Flex Plug and rigged up the tri-plex to hose below Flex Plug. Pressured up above and below Plug to 300 psi. Began to get fluid returns out of down spout. Fluid returns quickly changed to N2 and fluid. OA bled down to 250 psi in 8 min and returns were N2 only. Monitored OA for 15 min and pressure above Flex Plug fell to 200 psi and pressure below Flex Plug was 295 psi. Bled both above and below Plug to 0 psi. Final T 11/0=290/5/0. 4/3/2005 Prep OA for further Seal-Tite treatment. T/I/O=290/9/0. Strapped top of Flex plug @ 10'10". There appears to 6" of diesel on top of flex plug. ) ) 4/4/2005 Seal-tite OA x OOA. T/I/0=290/3/0. Pulled OA VR nipple. Strapped top of Flex-plug @ 11'. Pumped 1 112 gallons of Ultra-lite (Flex-plug) down OA. Let sit for 4 hours. Strapped top of new Flex-plug @ 9' 10". Pumped 4 gallons of Amber-lite down OA. Let sit for 2 hours. Strapped top of Amber-lite plug @ 6' 4". Pumped 5 more gallons of Ultra-lite (Flex-plug) down the OA. Strapped top on new Flex-plug @ 2'. Rigged down Seal-tite equiptment and let treatment cure. Re-installed hose to VR nipple jewelry and normaled up the tree. Final T .1.0=2901010. 4/5/2005 MITOA post Seal-Tite - Failed. T/I/O=290/2/0. Rigged up hyd fluid to hose that runs through the Flex-plug. Pumped hyd fluid down hose to ensure hose is clear. Re-installed VR nipple and plug leaving hose disconnected for equalization above and below Flex-plug. Rigged up tri-plex to opposing side. Pressured up OA with diesel to 200 psi. Fluid came to surface through conductor down spout into drum. After 5 min, OA pressure bled down to 150 psi. Pressured OA up to 250 psi and had steady stream of fluid coming from down spout. After 4 min, OA pressure bled down to 220 psi. Bled OA down. Final T/I/O=290/2/0. 4/6/2005 Leak detect of Seal-tite failure of OA. T/I/O=290/3/9. Bled OA to 0 psi and pulled VR nipple. Evacuated fluid down to top of Flex-plug@ 21. Re-installed OA hose to VR jewelry. Rigged up N2 to valve above Flex-plug and tri-plex with diesel to hose that goes below Flex-plug. Pressured up below plug with diesel to 100 psi. Pressured up above plug with N2 to 100 psi. Held those pressures for 5 min. Pressured up below plug to 200 psi and began to get diesel returns out conductor down spout into drum at a LLR of 100 ml per min. Bled below plug down to 0 psi and left 90 psi above plug. Conductor returns stopped. Pressured up above plug with N2 to 250 psi and began to get returns from both the hose below the plug and down spout on the conductor. Bled both above and below the plug to 0 psi. Strapped top of Flex-plug @ 2'. Discpnnected hose from VR jewelry to use as equalizing hose above and below plug. Pressured up OA to 500 psi and began to get returns out of the conductor down spout at 200 psi. At 500 psi the LLR from the conductor down spout was .35 gpm. Pressured up OA to 700 psi and LLR was .5 gpm out of conductor down spout. In 1 min OA pressure had bled down to 600 psi. Bled OA to 0 psi. Final T 11/0=290/3/0. 4/9/2005 Continue Seal-tite treatment of OA. T/I/O=290/8/4. Bled OA to 0 psi. Pulled VR nipple and evacuated fluid down to top of Flex-plug @ 2'. Poured in 1 gallon of Max-flo and 1/2 gallon of Max-flo 1 above Flex-plug. Connected hose to VR nipple jewelry and re-installed OA. Pumped 1 1/2 gallons of Gel-seal down hose below plug. Pressured up below plug with diesel and above plug with N2 to 250 psi. Began getting diesel returns out of the conductor down spout at a LLR of .17 gpm. Bled above and below plug to 0 psi. Pumped another 2 gallons of Gel-seal with 1/2 qt. of Gel-seal concentrate and 1/2 qt of Gel-prop below plug. Blew down hose with N2. Pressured up on top of plug with N2 and below plug with diesel to 300 psi. In 15 min there was no returns from conductor down spout. Started to get diesel returns from down spout. Pressured up to 450 psi and got a LLR of .17 gpm from conductor down spout. In 8 min the pressure below plug bled down to 360 psi and above the plug held at 450 psi. Pressured up to 500 psi above and below plug and got a LLR of .25 gpm from conductor down spout. In 20 min the pressure below the plug bled down to 300 psi and remained at 500 psi above the plug. Rigged down epuiptment and secured well for night. Vac truck to remain on location to monitor conductor down spout drum. Final T/I/O=290/8/470 above plug/300 below plug. 4/10/2005 Pumed OA Seal-Tite treatment for OAxConductor communication. T/I/O = 280/8/280/180 Upon arrival the OA had depressured over night but was not leaking into the conductor down spout. Did several pressure treatments with N2 on top of OA plug, and diesel on the bottom to 500 psi. The OA pressure steadily fell off to 380 psi during a 20 minute monitor period. Seal-Tire represenative mixed a Gel treatment to place below plug through the OA vent line. Pumped 5 liters of sealnt down the OA followed by 1.5 liters of Gel-Pro and Gel-Seal. Purged liners out with N2 and immedietly followed with diesel to pressure up OA to 500 psi. There was an immediate improvement from proir days results, Conductor sealed off for 22 minutes before diesel started coming from down spout again. Started having a small amount of N2 breaking out of conductor from what appeared to be from the top of the plug. Mixed a 4 liter mix of Tur-flow to place on top of the Plug and pressured it up to 950 psi. The sealant on top of the plug seemed to be slowly falling away then held @ 850 psi. Re-pressured up below the plug to 900 psi with Diesel and allowed well to stand alone for the night. Will return ) ) in the morning to continue. Final pressures; 280/8/850/900 4/1112005 Continue Seal-tite treatment of OA. T/I/O=290/9/560 above/350 below. Upon arrival conductor down spout was still dripping. Conductor drum had 6 gallons of returns in 12 hours. Pressured up above plug with N2 and below plug with diesel to 900 psi. We got a LLR of 170 ml per minute from conductor down spout. After 1 hour the pressure below the plug dropped off to 700 psi and the pressure above the plug was 870 psi. Pressured up above the plug with N2 and below the plug with diesel to 1000 psi. Established a LLR of 300 ml per minute from conductor down spout. Bled above plug down to 500 psi and attempted to bleed below the plug to 0 psi and got Gel-seal sealant returns from bleed at 200 psi and shut in bleed. Pressured up below plug with N2 to 720 psi, at 600 psi we started getting fluid returns from conductor down spout. Possibly another hole below plug. Pressured up below plug with N2 to 900 psi and then up to 1000 psi with diesel in attempt to shift sealant up and down across leak. Conductor returns started as fluid and became N2 when pressure had dropped to 600 psi. Re- pressured below the plug with N2 to 720 psi and to 1000 psi with diesel. At 840 psi below the plug, all returns stopped from conductor down spout. Leak stopped for 45 min and then broke down and started getting small amounts of fluid and N2 returns. Re-pressured below plug with N2 to 1000 psi and then up to 1200 psi with diesel. Established a LLR of 290 ml per min at 1200 psi. Pressure bled down to 1060 psi and returns stopped coming from conductor down spout for 40 min before sealant broke down again. Sealant would spuratically hold and break down. Pressure below plug bled down to 920 psi and leak had stopped. Rigged down for night and continue tommorrow. Final T/I/O=290/9/400 above/920 below. 4/12/2005 Continue with Seal- Tite treatment. T 11/0 = 280/8/850 above/520 below. OA had bleed off slightly from night before, but appeared to be holding upon arrival. Pressured up below the OA plug to 1000 psi with N2, followed by diesel to pressure up the OA to 1200 psi. (Top pressure increased to 1100 psi during this process). Started getting N2 and diesel returns out of down spout of about 170 ml per minute. Repeated process two times with simular results. Will return in a week to place additional Flex-Plug below current patch to cover leak area. Final pressures; 280/8/1030 above/860 below. 4/13/2005 Monitor down spot drum and WHP's T/I/O = 280/9/320 above/280 below. Drum is empty and there is nothing coming from the conductor down spout. 4/26/2005 Continue Seal-Tite treatment on OA. T/I/O=290/21/200 above and below plug. Pressured up below the flex-plug with diesel to 520 psi. Shut down for 5 min and began to get returns from the conductor down spout. Bled below plug down to 20 psi, approx. 30 gallons of foamy diesel. Pumped 4 gallons of gel-seal down below plug and then pressured up below plug with N2 to 580 psi. Monitored pressure for 15 min. Pressure fell off to 490 psi with small amount of N2 returns coming from conductor down spout. Attempted to pump 5 gallons of flex-plug ultra-lite. Pressured up to 1700 psi while pumping flex-plug. Appeared to have pumped all 5 gallons so immediately started pumping diesel. Vent hose pressured up right away. Tried bleeding hose down and repressuring several times and hose kept pressuring up. Hose appeared to plug off. Pressured up on top of plug with N2 to 400 psi. Above and below plug have communication and vent hose is not totally plugged off. Surged N2 from above the plug through the vent hose to try to clear the hose. After cleaning injection cylinders, appears that we hardly pumped any flex-plug down vent hose. Pressured up above plug with N2 to 600 psi. Rig down equiptment for the day and continue tom morrow. Final T/I/O=290/21/580 above and below plug. ) ) 4/27/2005 Continue with OA Seal-tite treatment. T/I/O=290/23/600 above plug. Bled above plug and vent hose down to 0 psi. Pulled VR nipple and disconnected hose. Rigged up enerpac to vent hose and attempted to pump hyd fluid down hose. Pressured vent hose up to 1500 psi and unable to pump down hose. Pushed wire down vent hose and found hose to be plugged at 8'. Final T/I/0=290/23/0. 4/28/2005 Continue Seal-tite on OA. Attempt to clean out vent hose. T 11/0=290/23/0. Attempted to clean out plug in vent hose that goes below flex-plug. Tried several times unsuccessfully. Rigged down and sent Seal-tite equiptment to shipping. Final T/I/O=290/23/0. ) ) ~u~uŒ w~ !Æl!Æ~rA!Æ AIfASIiA. OIL AND GAS ~OlVSERVATlOlV ~OMMlSSIOlV FRANK H. MURKOWSKI, GOVERNOR 333 W. "fTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage,AJ( 99510 Re: 3F-09 305-024 l '15~~g..ltJ Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected ~y it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on oliday or weekend. A person may not appeal a Commission decision to Superi CO"Jrt unless rehearing has been requested. , 1 ./ ;n. ~', II J~ o~ hairman DATED this 1'day of February, 2005 Enc!. SCANNED FEB 112005 ) .. y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 30, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AJ( 99501 ) FE8 0 3 2005 AlasKa 8A Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 3F-09 (PTD 1852700) and 3Q-21 (PTD 1951930). Both approval requests regard repairs for casing leaks. Please call Brad Gathman or MJ Loveland at 659-7224 or me at 659-7043 if you have any questions. Sincerely, f~LO~ Jerry Dethlefs q>l\'"I "'-to'" ~M.~~'{~J ..~\~\t... ~~~ (() '" ~..:x¿ \Cl \ w £. \ \ ~~ \'-J I ~ '-.) <-<:f- ~ ~.:- \30.~~. <Dt'-..-\Nt\ ,~\o. S "as"h'-. "ì 1'...\o,N'()\'m"-l ..\..,,~ ~Q'-..)Cè a ~~. ~ ~l(òv\oNk, " \0\ 'S.-.:)~'-~S ~ , r ~(JM..,,",,-~ {"-'8. o.~~\ k2-~ ' d-/s-V~ Problem Well Supervisor Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVREC I 20 AAC 25.280 Operation Shutdown 0 Perforate 0 I-I::!j Q¡Je,lOOêJ Annular Disp. 0 Plug Perforations 0 Stimulate A~ka Oil 81ï~åNt:t9ñi~~ C!;hmissionOther 0 Perforate New Pool 0 Re-enter SusA'~e~t~\e 0 4. Current Well Class: 5. Permit to Drill Number: ) 1. Type of Request: 0 0 0 Suspend 0 Repair well 0 Pull Tubing 0 Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 93' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total DepthTVD (ft): Effective DepthMD (ft): 7785' 6237' 7512 Casing Length Size ~~ ~3 ~ Development - 0 Stratigraphic 0 Exploratory 0 SeNice 0 185-270 6. API Number: 50-029-21480-00 9. Well Name and Number: 3F-09 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): 6018 MD Junk (measured): TVD Burst Collapse CONDUCTOR 115' 16" 115' 115 SUR. CASING 3322' 9-5/8" 3415' 3001 PROD. CASING 7510' 7" 7603' 6092 Perforation Depth MD (ft): 7252-7343',7424-7454' Packers and SSSV Type: pkr= OTIS 'RRH'; OTIS 'WD' SSSV= SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~rry_De~~S ~ Signature 7~ <- (:...4"/ '\ Commission Use Only Perforation Depth TVD (ft): 581 0-5883', 5948-5972' 22-Feb-05 Date: Tubing Size: 3-1/2" /2-7/8" Tubing Grade: J-55 Tubing MD (ft): 7407' Packers and SSSV MD (ft) pkr= 7169'; 7383' SSSV=1837' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 ~D WAG 0 GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Contact: Title: Gathman/Loveland 659-7224 Problem Well Supervisor Date ~..?A~ Phone 659-7043 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Sundry Numb:1ð5- 6''z 'f 0 Conditions of approval: Notify Commission so that a representative may witness Other: RBDMS BFl FEB 0 8 2005 0,-\ w{ o-\\Qdl''-~'-~ &c011--\,o'-~\"-.~n~\"ð~1^N A L BY ORDER OF ' ,I{ - ..-/ COMMISSIONER THE COMMISSION Date: "J' 1'( (J Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate ) ) ConocoPhillips Alaska, Inc. Kuparuk Well 3F -09 (PTD 1852700) I FEB 0 3 2005 SUNDRY NOTICE 10-403 APPROVAL REQUEST 01129/05 Alaska & The purpose of this Sundry Notice request is for approval to repair a surface casing leak with sealant. ConocoPhillips Alaska, Inc. (CPAI) proposes to repair a known surface casing leak with a product from the SealTite International Company. The repair should reduce the potential for an accidental release from the surface casing. 3F-09 has a known surface casing leak, first noted in 1994. Originally the problem was controlled by keeping the Outer Annulus (OA) pressure minimized by bleeding and restricting the well from gaslift. During April 2003 diagnostics were performed to quantify the severity and depth of the leak. The tests showed 9 gpm @ 375 psi flow rate at a depth of 24' down from the surface. Returns were captured at the top of the conductor. " During April 2004 an attempt was made to repair the leak with sealant by pumping it into the OA and taking returns up the conductor. Subsequent diagnostic testing indicated the repair was successful, passing Mechanical Integrity Tests five times over the next five months. On August 30, 2004, liquids around the wellhead indicated the sealant had failed and the leak was again active. Testing indicated a leak rate of 12 gpm @ 1700 psi, which apparently is too high for sealant to be effective. On September 14, 2004, a conductor cement top-off was performed to fill the 24-foot void in the surface casing by conductor annulus (OOA). The intent was to either seal the leak with cement, or at least reduce the leak rate so that sealant may again be effective. On October 1, 2004, an MIT was performed to test the cement repair for integrity. The MIT failed, but at a lower leak rate (2.75 gpm @ 1000 psi). The lower leak rate suggests sealant may again be an option for repairing the casing leak. PROPOSED PLAN 1. AOGCC approval of the plan to repair the surface casing leak with sealant; 2. Repair the casing leak with a sealant provided by the SealTite International Company; 3. MIT the repair after sealant operations, not to exceed 70% of internal yield pressure of the conductor (16" 62.5# H-40, 1650 psi); 4. Continue to waiver the well as notice to Operations of the presence of the surface casing leak; 5. Review other options with the AOGCC should the MIT fail, up to and including a workover. NSK Problem Well Supervisor 01/29/05 0PlC:iF\, \." < SSSV (1837-1838, 00:3.500) SBR (7152-7153, 00:3.500) PKR (7169-7170, 00:6.151) Perf (7252-7343) SLEEVE-O (7373-7374, 00:2.750) PKR (7383-7384, 00:6.151) NIP (7399-7400, 00:2.875) TUBING (7376-7407, 00:2.875. 10:2.441 ) Perf (7424-7454) ) çQl1qçQPhiUips.AI~~ké1.,I...~* .. III:" .. l III.". '~I .<i" B8I .w;. . ) KRU 3F-09 API: 500292148000 SSSV Type: Locked Out Angle @ TS: 36 deg (ã) 7254 Angle @ TD: 37 deg @ 7785 Annular Fluid: Reference Log: Last Tag: 7330 LastTagDate: .6/20/2001 CašhlgSttitig;'ALLYSTRINGS Description CONDUCTOR SUR. CASING PROD. CASING TubingStdng'."'.TUSING Size Top 3.500 0 2.875 7376 . PeH'åratlåns :Summary " Interval TVD 7252 - 7343 5810 - 5883 7424 - 7454 5948 - 5972 Gås Lift MandtelsNalves St MD TVD Man Mfr 1 2434 2292 Cameo 2 4312 3647 Cameo 3 5383 4406 Cameo 4 5910 4782 Cameo 5 6321 5087 Cameo 6 6732 5400 Cameo 7 7111 5697 Otis Ptòduction.MandrelslVåNes St MD TVD Man Mfr 8 7206 5773 Cameo 1. CLOSED Well Type: PROD Orig 11/18/1985 Completion: Last W/O: Ref Log Date: TD: 7785 ftKB Max Hole Angle: 47 deg (ã) 5100 Rev Reason: WAIVERED WELL Last Update: 5/22/2004 Size 16.000 9.625 7.000 Bottom TVD Wt Grade Thread 115 115 62.50 H-40 3415 3001 36.00 J-55 7603 6092 26.00 J-55 TVD Wt Grade Thread 5910 9.30 J-55 8RD EUE 5935 6.50 J-55 Ft SPF Date Type Comment 91 12 1/17/1986 IPERF 5" Scalloped HJ II Csg Gun; 120 deg. phasing 30 4 1/17/1986 IPERF 4" Carrier HJ II Csg Gun; 90 deg.phase V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK 0.000 0 3/9/1997 DMY 1.0 BK 0.000 0 3/9/1997 DMY 1.0 BK 0.000 0 12/3/1991 DMY 1.0 BK 0.000 0 3/9/1997 DMY 1.0 BK 0.000 0 1/18/1986 DMY 1.0 BK 0.000 0 1/18/1986 DMY 1.5 T-2 0.000 0 3/21/2004 V Type VOD Latch Port TRO Date VI v Run Cmnt DMY 1.0 BK 0.000 0 8/29/1998 (1) Top 0 0 0 Bottom 7376 7407 Zone ~,C-3,C-1 ,ur B A-2 Status Man Type V Mfr KBUG KBUG KBUG KBUG KBUG KBUG LBX Merla Man Type V Mfr KBUG Description (Locked Out TRDP on 3/20/96) ID 2.812 3.000 2.970 2.441 1811 7152 5730 SBR 7169 5743 PKR 7373 5907 SLEEVE-O 7373 5907 7383 5915 7399 5928 7406 5934 NIP PKR NIP SOS TTL Cameo'TRDP-1A-SSAt Otis Otis 'RRH' AVA BPC SLEEVE Set on 1/9/98 - OPEN. Unable to pull 6/20/2001 due to scale. AVA BPL NIPPLE Otis 'WD' Cameo tD' Nipple NO GO Cameo 2.750 3.000 2.250 2.441 Date Note 6/27/2001 CORKSCREWED TUBING (ã)6472; COIL STUCK ATTEMPTING TO MILL SCALE, SEE WSR 6/27/01 4/13/2004 WAIVERED WELL: ((1) OAx ATMOSPHERE COMMUNICATION - REPAIRED W/SEAL TITE 4n/2004 (2) IA x OA COMMUNICATION FEB 0 ,3 '2005 DRI GI NAt'-' ~ Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth -'.- Well Job# / ð' /-65'1' 1A-01 'K(- //uj- 27C 3F-09 I'$.' - D2~' 3N-07 l.~'~·-IL/D 1G-13 /Cffs -Z~~ 3F-06 /85- D Ii /' 2W-03 /å- 1_-3F-02 uJ -2 ~!f:'/ 1 E-114 L 1 ;<0,/- /7/ 10922488 10922490 10922491 10922487 10922489 10942791 10942790 10687709 7"",:,,:"~ Log Description Date NO. 3267 Company: 11/19/04 -'1 0 '\ ttJt&"' iJ., I Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL 1 1 1 1 1 1 1 A - 1 /' r- V~.j};· S~D: / UO .' 1¡J:v4¡~'1r-- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. LEAK DETECTION LOG PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG PROD PROFILE/DEFT USIT 11/08/04 11/10/04 11//11/04 11/07/04 11/09/04 10/30/04 10/29/04 10/07/04 . .-, ~..-.'~ 20 ü;S r "NE' fl. ~;R ~ '": -- SCAr:, : ~~;~, DATE: Color CD 1 /¡Þ /0 'I RE: OOA Cement Top-offs Subject: RE: OOA Cement Top-offs From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Mon, 27 Sep 2004 16:45:56 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> ~\) LId' \q{J Tom, There is a couple reasons for the excess cement. The depth is calculated by a string, so if that hangs up on any debris in the DCA, it may give us a false depth. Also since there is no way to circulate, your right, we rely on the hose to fill up the DCA. We just wanted to make sure we had enough cement to fill to surface. Brad Gathman Problem Well Supervisor 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom Sent: Monday, September 27,2004 To: NSK Problem Well Supv Subject: OOA Cement Top-offs maunder@admin.state.ak.us] 9:44 AM MJ and Brad, I was looking at the packet recently sent on the 6 wells that had the OOAs topped-off. It appears that the pumped volumes varied anywhere from 1.3 to 2.2 times calculated. Was XS cement circulated to assure that the OOA was full?? That would seem prudent, since it may not have been possible to get the hose all the way down. Thanks in advance for your reply. Tom Maunder, PE AOGCC <-Q:IIV'ù~ '-.,)0 \~~Iè d-C:>-C):d \\ ~ ~ C:p,~~ d W- ~'-\. \ \ l 0 ?:,ß-OCO \ \. ¥ .~ \=- - 0(, d~d ~ç:-O,\ \,~ ~ ?,\-\ - 0 S' ,~~ 1 of I 10/1120048:28 AM . ConocJP'hillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 15, 2004 .......fi:...;;.~.".,.........L. '1«;):-1 () t117 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RECEIVED SEP 1 7 2004 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the~;~ü'p¡~ and Tam fields. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor, or in some cases holes were cut in the conductor to facilitate fill-up. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The top-fill operation was completed on September 14, 2004. Dowell-Schlumberger batch- mixed Arctic Set I cement to 15.8 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Note that in most cases thesewells<1}ave been previously reported as having surface casing leaks and have either been repaired by ~xc;avation and patching or injection of sealant material. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, ç. Jc ~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor SCANNEr, NOV 1 5 2001~ Attachment ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off .. '" Kuparuk and Tarn Fields September 14, 2004 WELL PTD# SERVICE CEMENT TOP VOLUME REASON NAME TYPE ft Bbls . 2G-02 1841210 Producer 82 14.5 SC leak @ 32' previously sealant repaired 2N-341 1981030 Producer 3 0.5 Wobbly tree 38-06 1850760 Producer 8 2 Post SC leak patch repair; Sundry 304-225 3F-06 1852440 Producer 40 11.8 SC leak @ 64' previously sealant repaired 3F-09 1852700 Producer 17 3.9 SC leak @ 24' previously sealant repaired 3H-05 1870770 Producer 8 2 Post SC leak patch repair; Sundry 304-228 All cement pumped is Arctic Set I 15.8 PPG Cement This report is submitted in substitution for Sundry 10-404, Report of Sundry Operations . SCANNED NOV 1 5 2004 NSK Problem Well Supervisor ) KRU 3F-09 ConocoPhilUps Alaska, Inc. 3F-09 SSSV (1837-1838. OD:3.500) SBR (7152-7153. OD:3.500) PKR (7169-7170. OD:6.151) Perf (7252-7343) SLEEVE-O (7373-7374. OD:2.750) PKR (7383-7384. OD:6.151) NIP (7399-7400. OD:2.875) TUBING (7376-7407. OD:2.875. ID:2.441) Perf (7424-7454) ~ -- -=-....',..''''''''" :~ ~ .;: ',- -- -- -- ",;,.'.""...'.';....(~'.....'...'.;... - --- -- ~ API: 500292148000 SSSV Type: Locked Out Well Type: PROD Orig 11/18/1985 Completion: Last W/O: Ref Log Date: TO: 7785 ftKB Max Hole Angle: 47 deg @ 5100 Angle @ TS: 36 deg @ 7254 Angle @ TO: 37 deg @ 7785 Annular Fluid: Reference Log: Last Tag: 7330 Last Tag Date: 6/20/2001 Casing StrIng - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Tubing String - TUBING Size Top 3.500 0 2.875 7376 PerforatIons Summary Interval TVD 7252 - 7343 5810 - 5883 Rev Reason: WAIVERED WELL Last Update: 5/22/2004 Size Top Bottom TVD Wt Grade Thread 16.000 0 115 115 62.50 H-40 9.625 0 3415 3001 36.00 J-55 7.000 0 7603 6092 26.00 J-55 Bottom TVD Wt Grade Thread 7376 5910 9.30 J-55 8RD EUE 7407 5935 6.50 J-55 Zone Status Ft SPF Date Type Comment ~,C-3,C-1,W 91 12 1/17/1986 (PERF 5" Scalloped HJ II Csg Gun; B 120 deg. phasing A-2 30 4 1/17/1986 IPERF 4" Carrier HJ II Csg Gun; 90 deg.phase 7424 - 7454 5948 - 5972 Gas LIft MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2434 2292 Cameo KBUG DMY 1.0 BK 0.000 0 3/9/1997 2 4312 3647 Cameo KBUG DMY 1.0 BK 0.000 0 3/9/1997 3 5383 4406 Cameo KBUG DMY 1.0 BK 0.000 0 12/3/1991 4 5910 4782 Cameo KBUG DMY 1.0 BK 0.000 0 3/9/1997 5 6321 5087 Cameo KBUG DMY 1.0 BK 0.000 0 1/18/1986 6 6732 5400 Cameo KBUG DMY 1.0 BK 0.000 0 1/18/1986 7 7111 5697 Otis LBX Merla DMY 1.5 T-2 0.000 0 3/21/2004 Production MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 8 7206 5773 Cameo KBUG DMY 1.0 BK 0.000 0 8/29/1998 (1) 1. CLOSED Other (plugs, equip" etc.) - JEWELRY Depth TVD Type Description ID 1837 1811 SSSV Cameo'TRDP-1A-SSA' (Locked Out TRDP on 3/20/96) 2.812 7152 5730 SBR Otis 3.000 7169 5743 PKR Otis 'RRH' 2.970 7373 5907 SLEEVE-O AVA BPC SLEEVE Set on 1/9/98 - OPEN. Unable to pull 6/20/2001 due to 2.441 scale. AVA BPL NIPPLE 2.750 Otis 'WD' 3.000 Cameo '0' Nipple NO GO 2.250 Cameo 2.441 2.441 7373 5907 7383 5915 7399 5928 7406 5934 7407 5935 General Notes Date Note 6/27/2001 CORKSCREWED TUBING @6472; COIL STUCK ATTEMPTING TO MILL SCALE, SEE WSR 6/27/01 4/13/2004 WAIVERED WELL: ((1) OA x ATMOSPHERE COMMUNICATION - REPAIRED W/SEAL TITE 417/2004 (2) IA x OA COMMUNICATION NIP PKR NIP SOS TTL SCANNEr, NO\! 1 5 2001+ ARCO Alaska, Inc. Date: February 23, 1989 Transmittal Ct: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F-15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1 E-08 3M-18 Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Ku ~aurk Ku aaurk Kuaaurk Ku 3aurk Kuaaurk Ku aaurk Ku ~aurk Ku 3aurk Ku aaurk Ku aaurk Kuaaurk Ku aaurk Ku aau rk Ku 3aurk Ku ~aruk Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Well Level Re~ Level Re~ Level Re Level Re, Level Re, Level Re: Level Re, ~ort 3orr ~ort 3ort 3orr 3orr 3oft Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Pressure Report Ku ~aruk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12-03-87 12-18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 12-04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-20-89 2-19-89 2-15-89 Casing Casing Tubinc. Tubinc. Tubinc. Tubinc. Tubinc. Tubinc_ Tubinc_ Tubinc_ Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing Tubin~"~-~ Casin~L Casin(]"~ 3 H-01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B- 1 3 Kupaurk Fluid Level Report 2-17-89 Casing 1 E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M- 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N -05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Ku~aruk Ku ~aruk Ku ~aruk Ku~aruk Ku3aruk Ku~aruk Ku3aruk Kuaaruk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Leyel Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report 9-11-87 12-06-86 9-11-87 10-11-87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 Acknowledged: ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing DISTRIBUTION: D&M State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3F-1 I Sub-Surface Pressure Survey I 0-06-88 3 H - 1 2 Kuparuk Well Pressure Report 8- 2 9 - 8 8 30-07 Kuparuk Well Pressure Report 12-20-88 3 F- 1 0 Kuparuk Well Pressure Report 8- 2 9 - 8 7 3 F- 0 6 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 9 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7 - 8 7 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7- 8 7 3 F- 1 I Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 4 Kuparuk Well Pressure Report 6 - 2 6 - 8 7 3 F- 0 5 Kuparuk Well Pressure Report I 2 - 1 2 - 8 8 3 F- 1 3 Kuparuk Well Pressure Report I 2- 3 1 - 8 8 3N- 1 0 Kuparuk Well Pressure Report 6- 1 1 - 87 3 N- 1 0 Kuparuk Well Pressure Report 6- 1 1 - 8 7 3 N - 0 4 Kuparuk Well Pressure Report 9 - 01 - 8 7 3 N - 0 9 Kuapruk Fluid Level Report 5 - 0 4 - 8 7 30-1 4 Kuparuk Fluid Level Report 2- 1 3 ~ 8 9 3 O- 1 4 Kuparuk Fluid Level Report 2 - 1 0 - 8 9 3 M - 1 8 Kuparuk Fluid Level Report 2- 1 0 - 8 9 3 F- 1 6 Kuparuk Fluid Level Report 6 - 0 5 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 0 9 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6- 1 8 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 ~ 1 6 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 21 - 8 7 3 F - 0 8 Kuparuk Fluid Level Report 5 - 0 8 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8- 1 8 - 8 7 3 F ~ 1 6 Kuparuk Fluid Level Report 8 - 2 4 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6- 0 5 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6- 2 / 3 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8- 5 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 5 - 8 7 3 F ~ 1 4 Kuparuk Fluid Level Report 9- 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Cas~r~ka Oil & Gas Cone. Casing Tubing Casing Casing ARCO Alaska. In~. Post Office Bo:c 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 P~ETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: lA-7 12-03-85 Run ~3 7585-8532 lA-14 .12-05-$5 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run ~3 7875-8368 1H-8 12-09-86 Run ~4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run ~1 5300-7621 2C-16 02-19-85 Run ~1 7200-8294 2E-9 01-14-85 Run #1 6780-8052 2E-15 01-12-85 Run ~1 3350-6874 2E-16 01-12-85 Run #Ir 4840-7578 2H-10 12-05-85 Run ~1 6500-7863 3A-7 11-04-85 Run #I 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 DATE 09-15-86 TPJ~NSMITTAL # 5761 Please acknowledge receipt and One * of each Receipt Acknowledged: Vault*films Alaska Oil & Gas Cons. Date:Anchorage NSK Files*bl ARCO AIII"'I. Inc. ri, · SuDI,chary of Alllt~tlcRicl~ftef¢ComDl~Y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~ GAS '~ , , SUSPENDED ~ ABANDONED ~ SERVICE __ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-270 3. Address 8. APl Number P. 0. BOX 100360, Anchorage, AK 99510 50- 029-21480 Classification of Service Well 4. Location of well at surface 12' FSL, 67' FEL, Sec.19, T12N, RgE, LIN. At Top Producing Interval 1545' FSL, 650' FEL, Sec.30, T12N, RgE, UN At Total Depth 1232' FSL, 704' FEL, Sec.30, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 93' RKB J ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 11/11/85 11/1 6/85 11/1 8/85* 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 7785 'ND,6237 'TVD 7512'MD,6018 'TVD YE~;~ NO ~ 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3F-9 11. Field and Pool Kuparuk River Fi eld Kuparuk River 0il Pool 15. Water Depth, if offshore J 16. No. of Completions N/A feet MSLI 1 20. Depth where SSSV set 21. Thickness of Permafrost 1837 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, RFT, GR/CCL/CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE 9-5/8" 7" WT. PER FT. 136.0# 26.0¢ GRADE H-40 J -55 J -55 TOP Surf Surf Surf 24. Perforations open to Production (MD+TVD of Top and BOTTOM 115' 3415' 7603 ' lottom and HOLE SIZE 24" 12-1/4" 8-1/2" CEMENTING RECORD IAMOUNTPULLED 289 sx AS II 880 sx PF "E" & 420 sx qF "C" 200 sx Class C & 175 sx/PF "C" 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7407' 7169' & 7383' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A interval, size and number) 7424' - 7454' w/4 spf, 90° phasing 7313' - 7343' w/12 spf, 120° phasing 7252' - 7312' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) i Date of Test Hours Tested TEST PRODUCTION PERIOD ~FOR OIL-BBL GAS-MCF WATER-BBL . CHOKE SIZE IGAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 124-HOUR RATE ~ 28. CORE DATA Briefdescription oflithology, porosity, fractures, apparentdipsandpresenceof oil, gasorwater. Submitcorechips. None , .- _. ~ - _. Form 10-407 * NOTE: Tubing was run & the well perforated 1/19/86. WC1/051 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKEF~S NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH 7252' 7344' 7423' 7502' TRUE VERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, i5809' ii5884' ii5947 ' 601 O' GOR, and time of each phase. DEPTH HYDRO. PRESS. BUILD-UP PRESS. 7270.9' 7260' 7362.!' 7339' 7335.5' 7311.8' 7304' 7296.5' 7280.5' 7272.4' 301 7 psi 3020 psi 3060 ps~ 3045 pst 3044 ps~ 3039 psi 3036 psi 3032 psi 3029 psi 3028 pst 2848 ps~ 2845 ps~ 2891 ps~ 2868 ~s 2867 ~s 2857 )si 2856 ~si 2854 )si 2851 )si 2848 )si 31. LIST OF ATTACHMENTS None 32 I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Associate Engineer S'gned (~ ~ Title INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,~MISSION '~--- WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well / , 1. Status of Well OIL _ GAS __ SUSPENDED _ ABANDONED __ SERVICE __ 7. Permit Number 85-270 2. Name of Operator ARCO Alaska, Inc. 3. AddCess 8. APl Number P. 0. Box 100360, Anchorage, Al( 99510 50 029-21480 9. Unit or Lease Name Kuparuk River Unit 4. Location of well at surface 12' FSL, 67' FEL, Sec.19, T12N, R9E, UM At Top Producing Interval 1545' FSL, 650' FEL, Sec.30, T12N, R9E, UM At Total Depth 1232' FSL, 704' FEL, Sec.30, T12N, R9E, UM 10. Well Number 3F-9 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 93' RKB I ADL 25643 ALK 2574 12. Daze Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 11/11/85 11/16/85 i 11/18/85' 17. Total Depth (MD~TVD) 7785 ' MD ,6237 ' TVD 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool 15. Water Depth, if offshore ! 16. No of Completions N/A feet MSL 1 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21 Thickness of Permairost 751 2'MD,6018'TVD YESX~_ NO _-- 1837 feet MD I 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/¢NL, Cal, RFT, GR/CCL/CET, GCT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 6" 1 ~ 9-5/8" WT. PER FT. 62.5# 36.0# GRADE H-40 J -55 i 7" 26.0# J-55 SETTING DEPTH MD TOP BOTTOM Surf Surf Surf HOLE SIZE CEMENTING RECORD AMOUNT PULLED 115' 24" Conductor report not yet received. 3415' 7603' 1 2-1/4" ' 24. Perforations open to Production (MD-TVD of Top and Bottom and interval, size and number) 7424' - 7454' w/4 spf, 90° phasing 8-1/2" 880 sx PF "E" & 420 sx PF "C" 200 sx Class G & 175 sx PF "C" 25. TUBING RECORD 7313' - 7343' w/12 spf, 120° phasing 7252' - 7312' I SIZE I DEPTH SET (MD) PACKER SET ,~.rlDi 3-1/2" ti 7407' 7169' & 7383' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH iNTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. J Method of Operation (Flowing, gas lift, etc.) TESTPRODUCTION PER OD I~FORIOIL-BBL I GAS-MCFi ,~ CA LCU LATED OIL-BBL GAS-MCF !24-HOUR RATE ~ i ~ CORE DATA WATER-BBL CHOKE SIZE GAS-OIL RATIO , !OIL GRAVITY-APl (corr) WATER-BBL i Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED MAR 1 4 ]986 ~,~as~a 0~; & Gas Cons. Comm~ Anc~rage Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run & the well perforated 1/19/86. DAM/WC73 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS FORMATION TESTS N AM E Top Kuparuk C Base Kuparuk ¢ Top Kuparuk A Base Kuparuk A MEAS. DEPTH 7252' 7344' 7423' 7502' 31 LIST OF ATT.~,CHMENTS Cyroscopic Survey (2 copies) TRUE VERT. DEPTH ,SZ 5809' 5884 ' 5947 ' 6010' tnclu(:e interva, testeo, pressure data, alt fluids recove,e: aqd _qra. ,fy. GOR and time c~f each phase DEPTH HYDRO. PRESS. BUILD-UP PRESS. 7270.9' 7260' 7362.1' 7339' 7335.5' 7311.8' 7304' 7296.5' 7280.5' 7272.4' I here:?~, certify that the foregoing is true and co'rect :o the best 3017 ps~ 3020 ps~ 3060 psi 3045 )si 3044 ~si 3039 )si 3036 )si 3032 )si 3029 )si 3028 )si 2848 ps~ 2845 ps~ 2891 ps~ 2868 psi 2867 psi 2857 psi 2856 psi 2854 psi 2851 psi 2848 psi S~gne,: Associate Engineer INSTRUCTIONS Wale General: This form is designed for submitt ng a complete and correct well complet on report a~d !o.q on ali types of lands and leases in Alaska. Item I: Classification of Service Wells: Gas injection, ,~.ater injection, steam injection, air injectior, sa!t 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 interva! 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.). should show the details of any multiple stage cement Rod Pump, Hydraulic Pump, Submersible, Water In Item 23: Attached supplemental records for this wel ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none' Form 10 407 ADDENDUM WELL: 12/o9/85 12/20/85 3F-9 Arctic Pak w/175 sx PF "C", followed by 54 bbls Arctic Pak. RU SOS, RIH w/GR/CCL/CET & gage ring, log 7496'-6188'. Rn GCT gyro f/PBTD-surf. Alaska Oi~ & Gas Cons. Commission Anchora§e Drilling Superintendent / Da~e ARCO Oil and Gas Company Daily Well History-Final Report Instructions: D,e:are and SL;~mlt the "Final Report" an "'e ',,st Wedresca¥ afte, a c~.aO e "as been assig."ec or he ;s ~'ugged Abut, Coned or Sold "Final Remo~" should De s~3~,ttec also when ooerat~ors are susDePced 'c' an :n~E* n'te 3' aocrec:ame ~engt~ 3~ time On ,o,,o~e~s *~e- ar official test ~s not reculrec ~Don come!erich, reoo~ completion and -ecresen:at~ve test =ata ~n ='cc<s =-av~cec The "Final Repod" 'orm may De used for 'eCort n~ the en'.lre operation f stage .s a,a,.ae~e Accounting cost center code District Cc~ty c' ma' s~ [ State Alas~ North Slope Borough ] Alaska Fiei~ Kuparuk River Au:h. or W.C. no. AFE AE0472 Lease or ADL 25643 3F-9 Title Comp let ion Nordic 1 API 50-029-21480 Cberalor ARCO Alaska, ;[nc. SpJCded or W C begun AR.Co W I 56.24% IDate 1/17/86 I otal number of wells (actwe Or ~nact,ve) on this OSt center prior to plugging and bandonment of this well our 0030 hrs o Prior status if a w.o Complete Date and as of 8 O0 a 1/17/86 1/18/86 thru 1/19/86 Compiete recor,,t for each day reoo~ec 7" @ 7603' 7512' PBTD, Tally 3½" tbg 9.9 ppg NaC1/NaBr Accept rig @ 0030 hrs, 1/17/86. & tally 3½" tbg. ND tree, NU & tst BOPE. Load 7" @ 7603' 7512' PBTD, RR Diesel RIH w/6-I/8" bit/csg scrpr/JB to 7512', POOH. RU Schl, perf w/4" gun, 4 SPF f/7424'-7454'. Perf w/5" gun, 12 SPF f/7313'-7343' & 7252'-7312'. Make gage ring/JB rn. RIH & set ~]D pkr. RU & rn 3½", 9.3#, J-55 EUE 8RD tbg w/SSSV @ 1837', WD pkr @ 7383', "D" Nipple @ 7399', RRM. pkr @ 7169' TT @ 7407' Set RRH pkr & tst. Tst SSSV. SBR pre-sheared while seeting pkr. ND BOPE, NU & tst tree to 250/5000 psi. Tst pack-off to 5000 psi. Displ well to diesel. RR @ 0130 hfs, 1/19/86. Old TD New TD Re!easec r:g Date 0130 hrs. Class~ficaticns ~oH gas etc Oil RECEIVED F E B 2 8 1986 Alaska 0it & u.~:~ ~, ~- v .... ;ntSsion Anchor:~qe /19/86 ~ ...... g Type compiet,,om ,smg;e. cua! etc Single Praducmg '~ethod C'fic,a~ -ese,-vo,, ~ame(s Flowing Kuparuk Sands Pote,,t,a test ca:a 7512' PBTD Rotary Fcc '¢~ei: no Date Reservoir P-ocuc,"g :~te~a C., or gas Test t,me mrocuct c~ C~ ct- test Gas per day Pump size. SPM X length Choke s~ze T ~ C.P. '.',ater % GCR Gravity A~Jowac e E~fect~ve =ate ccrrected The above ~s correct Signature Fo~ for~ p:e~ar;tio~n-a~d distr,b see Procedures Manual. Section 10. Drilling. Pages 86 and 87 Drilling Superintendent ARCO Alaska, Inc. Post Office Box 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' Well Completion Reports Dear Mr. Chatterton' Enclosed are the Well Completion Reports for the following wells- 2X-8 3F-9 if you have any questicns, please call me at 263-4944. Sincerely, ~ Gruber Associate Engineer JG/tw GRU13/L158 Enclosures A~CO Alcl$,~cl nc ~$ a Su,'~s,c:~ar~, ot At an!,c~, c":'.eldComDanv STATE OF ALASKA - ALASKA IJ~L AND GAS CONSERVATION CO,,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL --XX GAS -- SUSPENDED ~ ABANDONED -- SERV!CE -- 2. Name of Operator 7. Perm,t Number ARCO Alaska, Inc. 85-270 3. Add'ess 8. APl Number P. 0. BOX 100360, Anchorage, AK 99510 50- 029-21480 Classification of Service CJell 4. Location of well at surface 12' FSL, 67' FEL, Sec.19, T12N, R9E, UH 9. Unit or 'ease Name Kuparuk River Unit At Top Producing Interval TO be submitted when gyro is received. At Total Depth To be submitted when gyro is received. 5. Elevation in feet (indicate KB, DF, etc.) 93 ' RKB I 6.ADLLease25643Designati°nALKand2574Seriai No. 12. Date Spudded 13. Date T.D. Reached i 14. Date Comp., Susp. or AUar'O. 11/11/85 11/16/85 ~ 11/18/85- 17. Total Depth iMP-TVa) 7785 'MD !0. Well Number ,, 3F-9 i !1 F,eld and Pool . Kuparuk River Fi eld . Kuparuk River Oil Pool 15. Water Depth. ~f offshore 16 No of C3mp~e.'.'o~s N/A ~eet MSL 1 18. PlugBack Depth!MD-'I'VD) 19. Directional Survey 20. Depth where SSSV set [ 21 ThicKness of Permaf-ost 7512'MD YEsL~ No- ! 1837 feet,MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, RFT, GR/CCL/CET, GCT 23. CASING, LINER AND CEMEN'rlNG RECORD E I !J SETTING DEPTH MD CASING SIZ WT. PER FT. .GRADE jTOP BOTTOM J Surf 115' HOLE SIZE i CEMENTING RECORD AMOUNT PULLED 16" ! 62.5# H-40 24" :. Conductor report not yet received. 9-5/8" 36.0# . J-55 i Surf 3415' 12-1/4": 880 sx PF "E" & 420 sx PF "C" 7" 26.0# i J-55 i Surf ! 7603' 8-1/2" 200 sx Class G & 175 sx PF "C" : 25. 24. Perforations open to Production ~MD-TVD of Top and Bottom and ,nter,,al, size and number) 742/~' - 7454' w/4 spf, 90° phasing 7313' - 7343' w/12 spf, 120° phasing 7252' - 7312' SIZE 3-1/2" TUBING RECORD " DEPTH SET .MOt ~PACKER SET 7407' I 7169' & 7383' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH iNTERVAL ,MD) L AMOUNT & KIND OF MATERIAL USED N/A f i 27. N/A PRODUCTION TEST Date F rst Production i Method of Operation (Flowing, gas lift, etc.! 1 DateofTest 1' Hours Tested ~!PRODUCTIONTEsT PERIOD~__FOR OIL-BBL i'iGAS-MCF Press.Fi°w Tubing jlCasing Pressure 'CALCULATED24.HOUR RATE I~,[OIL'BBL i GAS-MCF 28. CORE DATA . WATER-BBL i CHOKE SIZE GAS-OIL RATIO I , WATER-BBL OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ,.*~ater. Submit core ch.ps. None Form 10407 * NOTE: Tubing was run & the well perforated 1/19/86. DAM/WC30 SuOm,t indupl,cate ) Rev. 7-1-80 CONTINUED ON REVERSE SIDE "'"' 29 t 30. GEOLOGIC MARKERS FORMATION TESTS Include interva~ tested, pressure oata all flu,ds recovered and gra¥~¥, GOR. and t~me of each phase DEPTH HYDRO. PRESS. BUILD-UP PRESS. 11 NAME I MEAS. DEPTH j ~ TRUE VERT. DEPTH // To be submitted w~n gyro is receii~ed. ;i 7270.9' 7260' 7362.1' 7339' 7335.5' 7311.8' 7304' 7296.5' 7280.5' 7272.4' 3017 >si 3020 )si 3060 )si 3045 )si 3044 )si 3039 )si 3036 )si 3032 )si 3029 )si 3028 )si 2848 ps~ 28~,5 Ds 2891 )si 2868 )si 2867 2857 2856 )si 2854 )si 2851 )s 2848 3~,. LIST OF ATTACHMENTS Well History (completion details) 32. I hereby certify th~.t -.he fo.ego,rig ~s true and correct to the best of my _~ ~,~ ~ Associate Engineer _ _-2/ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and tog on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam inlection, air inlection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.~. Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10407 __ ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 0350 Telephone 907 276 !215 January 3, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-9 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3F-9. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/mh GRU12/L163 Enclosure RECEIVED ; ARCC A:as,.a ,nc ~ ~ _--...~-_- ; e.-. j At _~ ' z : - STATE OF ALASKA - ALASKA(- _AND GAS CONSERVATION CO /IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL['-] GAS [] SUSPENDED [~ ABANDONED ." ,' SERVICE Classification of Service Well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 Location of well at surface 12' FSL, 67' FEL, Sec.19, T12N, RDE, UH At Top Producing Interval To be submitted when gyro is run. At Total Depth To be submitted when gyro is run. 7. Permit Number 85-270 8. APl Number 50- 029-21480 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3F-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Poo] 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. 93' RKB ADL 25643 ALK 2574 ~3. Date T.D. Reached ~-~4. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 1~. No. of Completions -~. Date Spudded ]~ 1/16/85 L 11/!8/85 / N/A feet MSL ~ N/A 11/11/85 I 20. D'epth where SSSV set ~-21. Thi-~ness of Permafrost '~7. Total Depth (MD+TVD) I~.P~~e--~-~D+TVD)I ~~ ~ ............ 7785'MD J 7512'"D JMES[] No.~X ) N/A feet MD 1_ 1500' (approx) ~. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, RFT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE GRADE 9-5/8" 36.0# J-55 7" 26.0# J-55 SETTING DEPTH MD TOP BOTTOM Surf 115' Surf 3415' Surf 7603' Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) None HOLE SIZE 24" CEMENTING RECORD Conductor report not y_~ AMOUNT PULLED -~ received. ~ ,iCi! 12-1/4" 880 sx PF "E" & 420 sx 8-1/2" 200 sx Class G & 175 s PF "C" 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 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 [Method of Operation (Flowing, gas lift, etc.) DateofTest H---~ursTested IPRODUCTION FOR~'~IL-BBL ~'~AS-MCF ~ATER-BBL ICHOKESlZE ~AS'OILRATIO F,o~T~bi.~ Ca~i~P.~e ~CALCULATED '~O'L'B~L FAS-MCF ~WATeR-B~L ~O'LORAV'~Y-AP'(~°'~ Press. ~24-HOUR RATE ~ 28. CORE DATA Brief description of lithologv, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED Alaska 0ii & Gas Cons. O0mmiss~0n Anch0raqe Form 10407 Rev. 7-1-80 TEHP/WC95 CONTINUED ON REVERSE SIDE Submit in duplicate 29. N/A GEOLOGIC MARKERS 30. FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RFT data to be submitted when received. 31. LIST OF ATTACHMENTS Well Hi story 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Dat.; INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-4~7 ARCO OII and Gas Company Well History - Initial Report - Dally Prepare and submit the *'lei~lal Rel~' oft the first Wednesday attar a well is spudded or worl~over operationl are started. Dilly wo~ prior to sl:~d~ing should be summarized on the form giving inclulive dates only. l Co~n~, ~ or t~orougl~ I North Slope Borough Field ILea~e or Unit ADL 25643 Kuparuk River I Auth. or W.O. no. ITit~e AFE AK0472 I Drill Doyon 9 API 50-029-21480 State District Alaska Alaska Well no. 3F-9 Ol~erator ARCO Alaska, Inc. ARCO W I Prior status ~f a W.O. Spudded 11 / 11/85 56.24% 2245 hrs. Date and depth as of 8:00 a.m. 11/12/85 11/13/85 11/14/85 11/15/85 Complete record for each day reported 16" @ 115' 1102', (987'), POH Wt. 9.6, PV 20, YP 26, PH 9.0, WL 13.6, Sol 8 Accept rig @ 1900 hrs, 11/11/85. NU diverter sys. 2245 hrs, 11/11/85. Drl 12¼" hole to 1102'. Spud well @ 16" @ 115' 3433', (2331'), Prep to rn 9-5/8" Wt. 9.4, PV 13, YP 16, PH 9.0, WL 13.2, Sol 7 Navi-Drl & surv 12¼" hole f/1102'-3433', CBU, short trip to HWDP, POH. RU to rn 9-5/8" csg. 1209', 3.7°, S 2.75E, 1208.9 TVD, 3.4 VS, 3.5S, 0.2E 1363', 8.1°, S24.25W, 1362.1TVD, 19.1VS, 18.9S, 2.8W 1837', 27.2°, S25.25W, 1812.7 TVD, 154.6 VS, 147.2S, 58.2W 2403', 42.4°, S 8.25W, 2270.5 TVD, 478.8 VS, 458.6S, 163.3W 3178', 43.0°, Sll.25W, 2828.7 TVD, 1016.3 VS, 987.7S, 258.3W 9-5/8" @ 3415' 3448', (15'), Prep to TOH Wt. 8.5+, PV 3, YP 2, PH 9.5, WL 10.6, Sol 2 Fin short trip & cond hole f/csg, TOH. RU & rn 86 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3415', FC @ 3332' & cmt same w/880 sx PF "E" & tail w/420 PF "C". Displ using rig pmps, bump plug. ND diverter. NU &tst BOPE. TIH, tst csg to 2000 psi. DO cmt & conduct formation tst to 11.9 ppg EMW. Prep to TOH. 3373', 41.6°, Sll.25W, 2972 TVD, 1147 VS, 1116S, 284W 9-5/8" @ 3415' 6364', (2916'), Navi-Drl Wt. 9.4, PV 8, YP 3, PH 9.0, WL 8.2, Sol 8 TOH, PU Navi-Drl, drl & surv 8½" hole to 6364'. 3570', 41.2°, S9.25W, 3120 TVD, 1277 VS, 1244S, 307W 4011', 45.0°, S7.25W, 3436 TVD, 1585 VS, 1549S, 350W 4641', 43.7°, S8.25W, 3886 TVD, ~26 VS, 1986S, 408W - 5241', 47.0°, S4.25W, 4307 TVD, 2452 VS, 2410S, 454W 5769', 43.6°, S4.25W, 4679 TVD, 2826 VS, 2784S, 486W RECEIVED Alaska Oil & Gas Cons. Commission Anchorage The above is correct Signature For form Dreparation and distri~tion, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. Date I Title 12-/3-~ Drilling Superintendent ARCO Oil and-Gas Company Daily Well History-Final Report Inatr~ction$: Prepare and submit the "Final Report" on the first Wednesday after al!owabte has been assigned or weil is Plugged. Abandoned. or Sold "Fillal Rel~ort" should be suOmitted also when operations are suspended ~or an indefinite or appreciable length of time. On worl~overs when an official test is not required ucon completion, report completion and representative test data in blocks provided The "Final Report" form may de used for reporting the entire operation ~f space ,s ava,laDle. District Alaska County or Parish Field Lease or Umt Kuparuk River Auth. or w.o.AEEno. &K0332 T tie Doyon 9 North Slope Borough ADL 25643 Drill tAccountmg cost center code State Alaska IWetl no 3F-9 API 50-029-21480 Operator ARCO Alaska, Inc. Spudded or W O. begun Spudded IARCo. WI 56.24% Date 11/11/85 Date and eeDth as of 8:00 a.m Complete record for each clay reported Old TD Released r~g 11/16/85 thru 11/18/85 11/19/85 I otal number of wells (achve or reactive) on th~s dst center prior to plugging and I bandonment of this well our [Prior status ~f a W.O. 2245 hrs. 7" @ 7603' 7512' PBTD, 7785' TD, (1421'), ND BOPE 9.9 ppg Brine Navi-Drl & surv 8½" hole to 7785' TD, 35 std short trip, C&C, TOH f/logs. RU Schl, rn DIL/GR/SP/SFL f/7778'-3410', EDC/CNL f/7778'-7050', CAL @ 7778'-6050' & RFT @ selected depths, RD Schl. TIH, make cond'g rn, TOH, LD DP. RU & rn 176 jts + 2 marker jts, 7", 26#, J-55 BTC csg w/FS @ 7603', FC @ 7513'. Cmt w/200 sx C1 "G". Displ & bump plug. CIP@ 0435 hrs, 11/18/85. Chg rams to 5" & ND BOPE. 6084', 42.4°, S 4.25W, 4909 TVD, 3040 VS, 2998S, 502W 6620', 40.1°, S 8.25W, 5313 TVD, 3391VS, 3350S, 529W 7247', 36.2°, S 8.25W, 5805 TVD, 3779 VS, 3734S, 579W 7725', 36.5°, S12.25W, 6190 TVD, 4062 VS, 4013S, 629W 7" @ 7603' 7512' PBTD, 7785' TD, (0'), RR 9.9 ppg Brine Fin ND BOPE. Instl pack-off & lower wellhead. Tst pack-off to 3000 psi. RR @ 0815 hfs, 11/18/85. I New TD DB Depth 7785' TD J Date Kind cf r g 0815 hrs. 11/18/85 Rotary C;assifications (OH. gas. etc. 011 Type comcletlor~.s~gle, dual. etd ~ Single 7512' PB~ Producing method Official ,eservoir name(s) Flowing Kuparuk Sands Poten:ia~ test data Well no. Date Reservoir 'P-oducipg Interval Oii or gas Test time Procuc!!cn Oil On test Gas per day Pump size. SPM X length Choke s{ze TP. C.P. Water % GOR Gravity Allowable Effectwe date corrected The above is correct Signature Date ITitle /.zJ.,z For form preparation anti'distribution, see Procedures Manual. Section 10. Drilli~'g. Pages 86 and 87. Drilling Superintendent SUB-SURFACE DIRECTIONAL ~URVEY ~]UIDANCE [~JONTINUOUS [-~"~ OOL RECEIVED Company Well Name , Field/Location ARCO ALASKA INCORPORATED WELL 3F-9 (12' FSL, 67' FEL, S19, T12N~ R9E~ KUPARLrK, NORTH SLOPE; ALASKA ! Job Reference No. 71269 Loaaed By: WEST Date 12-FEB-1986 Computed By: OGDEN GeT D~ECTi]q.~L SU:~q=Y 'USTJ _ 9. KJ~JK $~Q¢=Y ]AT:: 1)-D:--q3 MET-~3]S 3:C]qPUT~TIO'4 IqT=QP]_~TI3'J: LZN:_~q V~qTZC~L S:_CTI]N: q]QlZ, gIST, IZi~JTH ~ZZMUTH ',.,) g:.l, 12 ~iI'J NEST 3:-9 CgMmdT~TI]~ O6r:: 12-FEB-SS [~T=~P~LAT23 VALJ:3 =9~ EVEq 100 F~=T ~= TRJE SJ~-S-~ ~4E~S]R=3 VERTIS~L V:~TI-~L DEmT4 DEPT t 0.03 O.O0 -'i33.00 130.33 100.30 7.00 230.33 200.00 107.00 300.33 300.30 20~.00 ;30.90 ~00.30 307.00 530.33 500.00 407.00 $30.]3 500.00 50?.0) 700.00 53~.99 500.9~ 330.00 ?)'~.~9 )00.33 899.39 805.99 1330.30 999.39 905.'33 ll20.3O 1099.35 1035.95 1~00.33 1199.37 1105.87 1330.00 1239.~6 1205.45 1~D0.03 13~8.51 1305.51 1530.30 14~6.~2 l&O~.~2 1530.93 1593.04 150~.0~ 1700.99 1507.21 15~4.21 1~30.~D 1778.5~ 1900.99 1356.32 1773.92 2]]0.09 1951.$5 1859.85 2130.33 Z033.$5 1~0.55 2200.00 2113.57 2023.57 2300.00 2191.59 2~30.]3 Z267,36 217~.30 2~00.00 23~9.1~ 2500.~ 2~09.77 Z315.77 2720.00 2~80.$3 2387.53 2~20.00 2551.59 2330.00 2523.30 Z532.30 C]JRS~ V:RI,I'&L O]G_EG ]~G MI>~ OEG MI'~ ~E~T DES/lO] 0 13 S 15 21 W 0.09 O I1 S 3 5 'N 0.43 O.lO 0 13 S 5 5% ~ 3.~1 ].1~ 0 10 S 15 Z'3 ~ 1.21 3.32 0 13 S ~2 3 E 1.32 ~.30 0 13 S ~3 1~ '~ 1.30 3.03 0 24 S'$3 3~ £ 1.39 ].12 0 2,~ S ~'3 48 ~ 1.71 0.05 0 ~1 S 4] 55 ~ 2.2J 3.23 0 1 5 1J 13 17 21 25 52 S 4! 4& J 2.91 3.35 13 5 ~$ 5~ ~ 3.94 1.12 O S ~ D N 7.35 5.0.5 5~ S 17 52 ,~ 15.30 1.93 g S 25 53 '~ 2~.45 ~.~ 10 S 22 57 ~ ~3,02 3.43 4 S 21 3~ ~ 7~.09 5.35 50 S ~ ~ 55 ~ 105.77 ~.2~ 1 S 2% 4% ~ 145.05 3.9) %9 5 23 53 ~ 191.12 3.83 33 35 37 3') ~2 44 ~5 %1 S 22 5~, W 242.31 3.70 35 S 20 31 W 235.30 3.31 ~5 5 15 47 ,' 357.52 3.59 25 S 1D 1~ W 419.~9 3.77 39 S 3 ~7 ~ 485.23 3.53 31 S 3 3~ W 55;.3~ 3.73 1 5 ~ 51 ~ 525.53 3.77 51 S ~ 1~ '~ 695.13 17 S ~ 27 W 755.55 3.47 5 S ~ 2~ ~ 835.~5 ~.35 4j 43 41 41 41 45 ~ S ) ~3 ~ 305.75 3.35 lO S 9 51 '~ 974.74 ;~ S 12 5 ~ 1.]43.00 3.55 53 S 1D 23 W 1110.45 1.1~ ~2 S 13 37 W 1!75.~3 11 S 13 15 W 12~2.71 ~.1~ 56 S lO 13 ~ 130~.65 1.85 13 S ~ ~3 N 1375.38 3.5Z ~1 ~ 7 ~2 ~ 1447.20 ].35 3090.00 2695.28 2502.2~ 3130.03 2757.58 £57~.58 3230.00 2840.76 27~?.?~ 3330.~0 2914.57 2321.57 3~00.3D 2989.30 2395.30 3530.33 306~.55 Z~71.56 3530.00 3~39.72 30~5.72 313D.]3 3213.~7 3123.27 3530.90 3283.96 3900.33 335~.39 3251.09 O~TE 3; SURV=Y: 19-0:C-~5 <5LLY SUSHINS ELECaTI3N: ~NGZ~ER: T. WES?, 1 ~3.00 M:aSURE RE~'T&N O. O. O. 0 . 1. 1, 1. 1. /, 3. 17. 4.~. 71. 102. 140. 1 ',~Z · 231 · 284. 341. 402. ~66 · 535. 505. 575. 144. ~13. ~ ~ 1. 949 . 1)17. 13~3. 1 l~J. 1,1~ 1278. 1345. 1~15. 1~35. ] D:PTH %UL&R COORDiq&T~S fl]qIZ. SOtJTq E2ST/WSST DIET. FE:T O0 N O.OO 5 Og S 0.02 W %3 S 0.07 W 0.43 ~,3 S 0.11 W 0.31 21 S 0.1~ '~ 1.21 35 S 0.13 :- !,35 ~2 S S.53 : 1.55 51 S 1.23 E 2.02 O~ S 1.q5 E 2.75 53 S 2.~7 ~ 3.51 47 S 3.21 E ~.73 73 S 4.53 E 6.55 38 3 5.75 E 10.17 11 S 3.53 E 17.30 5'~ S 1.3~ W 2~.53 35 S 9.32 W 4'9.37 ~9 $ 1'3.52 W 74.49 36 3 21.11 W 107.85 07 S 48.53 W 14'3.29 57 $ 58.15 w 19a.3~ DB S 88.8~ W 25 S 110.73 W 305.35 23 S 12~.33 W 364.32 14 S 143.42 57 S 153.65 W ~91.32 ~6 S 164.33 w 569.11 ~6 S 174.'33 ~ 533.22 11 S 185.16 W 700.30 53 S 197.55 W 77~.32 3'3 S 209.11 W 33~.~3 32 S 220.58 W 303.02 ~0 S 232.43 W 977.32 33 S 2~4.25 W lj45.35 ~3 S 255.19 W 1113.31 75 5 26~.3b ~ 1173.50 51 S 280.2~ ~ 1!45.45 %0 S 29Z.09 W 1311.35 1'~ S 3D3.42 W 137~.~7 35 S 313.05 W 1~43.56 ~0 S t22.55 W 1520.51 ~12 I ~UT-~ OE3 S 13 1'9 ~ S 5 20 : $ 43 17 : S 42 46 E S 3~ 28 : s lZ 9 S 11 3'9 g S 17 1'9 ~ S ZO 23 ~ S 21 S 21 17 ~ S 22 45 ~ 3 19374 S 15 13 .4 317 3 ' S 15 6 S 15 24 $ 1~ 52 ~ 3 1~. 25 ~4 3 1 ~ 3 4 S 13 45 W S 13 30 ~ S 13 15 ~ ~ 13 3 ~ 313 0 ~ % 12 52 ~ S 12 42 ~ 5 12 28 4 5 12 14 d Fl' COMPUT4TIDW 0~T:: ~,3E 3~TE 3F SJRVE¥: 19-3~:-35 ~ELLY BJSqIqS ELE¢&TI$N: ~3I'~EER: T. WES1, 2 93.0O ~T [NT:R°Ol ~T:3. VALJES :OR _=VEX lO0 =E:T O= ~:~SUR:3 3EPTH TR~E SJ5-S:4 ~E~SUR:] V:RTI-~L V'qTI"~L 3EPTH DEPTq ]EP1'H 4090.00 3~2~.59 3331.59 ~190.03 3495.34 3402.34 4200.3] 35~6.]9 3473.29 4300.30 3~37.~5 354~.45 4500.03 3780.~$ 35~7.4~ 4500.~3 3852.55 375~.55 47)0.33 3925.00 3932.00 4~00.02 3997.~1 5000.00 ~141.7~ ~048.78 5100.03 ~211.}~ ~11~.0~ 5200.03 ~279.£8 ~laS.Z~ 5300.03 ~348.12 ~255,12 5~90.00 ~417.50 ~32~.50 5530.32 ~55~.33 ~455.33 5100.00 ~921.5~ ~823.53 6230.~3 ~9~5.98 ~902.53 5330.33 5070.36 5~30.33 5145.Zl 5053.21 5530.90 $221.~8 512~.93 6530.33 5298.34 5205.0~ 6700.93 5374.57 3281.57 5990.~0 5G51.~4 535~.9~ 6900.00 5529.]9 5~35.q9 7990.09 5508.37 5515.37 7190.30 5687.%5 559~.45 7Z]0.3] 5767.~0 557%.30 7300.09 5848.35 5755.05 7~3.]~ 5928.%9 5~35,4~ 75~0.00 $008.55 3915.56 7590.39 608~.$£ 59'~5.62 7700.00 5158.59 5075.6~ 7795.00 5236.74 5143.74 C3JRS: VERTI'~L 3'35LE3 3EVZITI3N ~ZIMJ1,~ SECTION S~V-~iT¥ 45 4 S 7 47 ~ 1589.25 3.27 ~4 53 S 7 ~9 ~ 1559.90 44 42 S 7 52 N 1730.36 0.22 44 ~3 5 7 5l ~ 1~0~.60 44 23 5 7 5] N 1870.67 44 1 S 5 ~ ~ 1940.35 0.33 43 ~5 S 3 23 W 200~.66 3.33 43 !3 % ~ 25 W !07~.59 43 1 S 3 3~ N Z147.02 3.2~ 45 3 S 5 33 ~ 2235.35 1.53 47 1 S 5 21 J 1357.~3 3.69 46 25 S 5 15 a 2233.79 9.63 46 13 S 5 1] ~ Z$03.14 0.61 45 ~7 S 5 7 ~ 157~.9B 3.55 45 1) S ~ 59 J 2545.05 0.37 ~4 ~5 S ~ 57 N ~716.61 ~ 1~ ~ ~ 57 ~ 17~5.53 ~.8~ ~3 29 S ~ 57 ~ Z855.56 ~3 0 S ~ 53 R 2)23.99 3.33 42 38 S ~ 5) ~ Z991.75 42 19 S ~ ~5 N 305~.15 3.57 ~1 ~1 S ~ 39 N 3125.88 41 1~ S ~ 37 ~ 5191.8~ 0,3~ ~0 54 S ~ 35 N 3257.37 40 34 S 5 5 J 33J2.42 1.45 ~0 21 S ~ I W ~3~7.26 1.52 39 ~2 S 9 23 ~ 3451.53 3.?5 39 1 S ? 12 ~ 3514.96 ~.33 3~ 31 S 7 51 J 3577.60 ].53 33 2 S 7 33 W 3539.55 3.49 37 Z1 S 7 ~Z N 3700.72 36 24 S 7 53 W 3700.?0 1.~3 36 12 S ~ 59 W ]~19.37 i.27 36 ~2 S ~ 55 ~ 3~7~.28 D.63 35 %8 S 9 55 d 333'9.19 3.00 36 ~ 5 ) 55 W 39~9.10 $.03 36 ~8 5 9 55 ~ ~059.01 36 ~8 5 ? 55 W ~109.93 FEE 31JL4R C3]P, OI'4:~TES H]RIZ. S3JTH EasT/N:ST 1' '-E~T- ~-:,- T 1556. 1526. 1595. 1755. lq. 35. 1~0~. 1972. 2340. 213~. 2175. 18 S 332.35 W 1391.21 19 S 3~1.6:~ ,4 1561.?0 3! S 351.31 W 1732.D1 51 S 350.'91 W 1~02.12 35 S 370.~,7 W lq72.07 06 S 3~0.19 '~ 1~41,65 55 S 390.22 W 2310.44 95 S a09.33 N 2073.73 52 $ 410.42 W 21~.10 ~,0 S 420.23 W 2215.51 22~5. 2317. 2.390. 2~,62. 2536. 2505. 2575. 2746. 2815. 2'383. 21 S ~28.70 W 2285.75 91 S ~35.17 W 235~.59 7~ S 44Z.'~5 W 2%31.~,1 96 S 44~.45 W 2503.53 53 S 455.~0 N 2575.27 5q S 462.1~ W 2546.35 15 S 46~.2~ W 2715.82 11 S ~7~.33 W 2765.79 07 S 460.37 W 2555.75 3~ S 486.25 W 292~.05 2951 · 3333 · 3151 · 3215. 32~1 · 3345. 3~09. 3~72. 3336. 05 S 492.0~ W 2991.75 ~1 S 497.71 W 3~5~.17 12 S 503.17 W 3125.99 O? $ 503.53 W 3191.~4 50 S 513.33 W ~257.38 5~ S 51~.07 N 3322.44 13 S ~26.47 N 3387.29 ~0 S 535.98 W 3~51.65 49 S 545.05 W 3515.~1 51 S 553.8{ W ~5~7.55 3595. 3555. 3715. 3774. 3333. 3992. 3~51. 6310. ~.362. 9~ S 562.13 W 3539.51 59 S 570.25 W 3700.7~ 2~ S 579.33 W 3763.97 51 S 585.75 ~ 301q. 95 19 S 595.72 W 3~79.33 ZO 3 607.01 W 3J3~. Z1 S 517.~1 W 3~9~.15 23 5 527.75 W 4~59.07 39 S 536.55 W O6~&RTURE aZIMUTH 953 S 1Z S 11 51 ,4 S 11 42 N S 11 33 S 11 24 ,4 S 11 17 S 11 11 S 11 5 s 11 S 13 55 g 53,4 51 ,4 50 N 51 N 52 ~ 53 N KJP~RJ~ ND~TH SLOPE~L&SqA CDMPUT&TI]N DATE: 12-:EB-35 PA}~ DATE ]F SJR~EY: 1~-3~C-95 ~LLY 3USqlN3 ELEV&TIDN: ENGINEER: T. WEST 3 ~3.00 FT INT=qDDLIT~] V~LJSS :DR :V=q 1003 TRUE SJ5-SS~ ~E~SURED V=RTZ'~L DEPTH DEPTq DEPTH O.OD 0.00 -g).O0 1000.00 9g~.~8 ~05.9~ 2000.00 1951.~5 1853.85 3030,00 2695,28 2502.23 ~OOO.O0 3~2~.59 3331.5~ 50DO.~O ~1~1.75 ~04~.78 6000.00 ~7.~0 ~75~.90 7300.~3 5608.37 5515.37 77B5.00 5236.74 $1~.T4 CDgRSE DEV!~TI]N 6ZIMJTq D~'G MIN DES ~Iq V_~RTI-AL SECTION FEET 0.00 2.91 2~2.31 935.75 1589.25 2235.85 29'91.75 353~.55 ~10'~.93 FE=T 3: ~E~SJR CD DEPT DOS.E3 R:'TA~SIJLAq C3 SEV-RITY NDRT'~/SDUTq EA 0E5/103 ~E:ST ,: 0.00 q 3.~7 S 231.3~ S 8 381.92 S 22 1555.18 S 33 2Z~6.21 S ~2 2151.35 S ~9 3595.~4 S 55 ~060,39 S 63 O.OD 3.35 3.7::) 3.35 D.27 1.53 0.22 3.00 ]RDI~ATES ST/NSST 0.30 E 3.21 E 0.58 W 2.05 W 8.70 m 2.0~ 'N 2.13 W 5.55 W HD~IZ. O!ST. FE:T ~ZIq:JTH O.DO ~ 0 0 5 4.73 5 42 46 E 247.58 5 21 2 ~ :)0~.92 5 1~ 3 N 1591.21 5 12 2 ~ 228o.76 5 13 4'~ 2~1.7~ S ~ 27 353'~.51 5 ~ 53 ~109.'~9 S 3 54 ~ KJP4R,J~ NINTH ']~PUTaTI]q DATE: 12-FEB-3$ DATE ]F SJRVEY: 19-DES-SS KELLY 5USHINS ELEVATE]N: ENSINE~R: T. WEST 4 [NT=RPGL~TED V~.JES ;ER EVEN 103 :EET O: TRUE SJE-Sk& ~E~SURE] VZRTIC~L V:RTI~L ]EPTH DEPT4 DEPTH 0.03 0.00 -93.00 93.00 93.}0 0.00 193.]~ 193.00 lOD.O0 2~3.33 293.30 ZOO.Od 393.~D 393.30 303.09 ~3.3D ~3.00 ~00.00 ~g3.99 593.00 503.00 5~3.31 6~3.30 50O.OO 793.01 793.90 703.00 ~3.01 ~93.00 890.00 )93.02 993.30 900.00 1~93.0% 1093.00 1000.00 1193.11 11~3.~0 1100.00 1~93.50 1293.30 1203.00 1394.~3 1393.00 1300.00 1~95.~ 1493.00 l~OO.O0 15~9.95 15)3.00 150~.00 1705.25 1693.00 1600.00 1315.03 1793.00 1703.00 1930.33 1~93.00 1800.00 2050.33 19'~3.00 1~03.00 2173.92 2093.90 2OOO.O0 2331.5~ 2193.00 Z103.90 2~35.21 22~3.00 2200.00 2576.23 23~3.90 230].00 2717.~5 2~3.00 2~0].90 2357.75 2593.00 2303.00 2~6.83 2693.00 2503.0J 313~.75 2793.00 2703.00 3270.~9 28~3.00 Z~OO.O0 3~3~.93 2993.00 2903.00 3537.33 3093.00 3003.00 3S71.97 3193.00 3193.00 3313.02 3293.00 3203.00 3955.22 3393.00 3303.03 4096.59 3~93.30 3~00.90 4Z37.55 35~3.00 3503.00 4377.~1 36~3.J0 3503.03 ~517.~3 3793.00 3733.90 4555.91 38~3.00 3500.OJ C3J2SE VERTI'4L ]EVI~TI]W ~ZIM3T4 S~CTION SEV:qlT¥ ]~G ~f',~ DE3 MIX FEET DE3/lO3 0 0 W O O ~ O.OO D.OO 0 13 S 1~ 15 W 0.05 D.I~ 0 11 S 3 ~ ~ 0.41 3.10 0 13 S 7 ZZ W 0.7~ 2.17 0 11 S 1Z 22 ~: 1.19 3.23 0 12 S 81 37 E 1.32 3.23 0 18 3 qO 1D ~ 1.39 0.10 ,2 23 S 54 45 ~ 1.38 3.17 0 Z~ S ~9 2~ ~ 1.6~ 0.19 0 30 $ ~1 ~3 ~ 2.15 '3.2~ 0 1 3 5 13 17 ~2 30 51 S ~2 49 = 2.95 3.45 ~ 3 ~7 33 E 3.86 0.85 %2 S 1 9 N 5. Rq 5.37 51 S 17 2~ ~ 15.6~ 1.89 5b S 25 49 W 23.52 3.63 3 S 23 2 ~ ~8.25 3.52 ~ S 21 ~ ~ 7~.OB 5.35 5 S 23 5 ~ 10~.03 ;.27 ~0 S 2~ 52 R 152.~2 59 S 23 2~ ~ 235.37 3.99 35 37 39 43 44 ,~ 4 43 43 9 S 22 Z~ ~,{ 259.90 2.81 Z1 S 15 5~ R 351.74 3.53 2,5 3 13 1~ ~ ~23.95 3.73 4 S ~ ~2 W 508.79 '3.4~ 50 S 9 21 ~ 7,3~.52 0.43 l~ S ~ 25 ~' ~5.'~2 ~.35 ~9 S ~ ~5 ~ 903.57 2.35 9 S ~ 55 N 999.55 41 41 43 45 45 43 ~3 lO S 19 35 ~ i130.1~ 12 S 13 17 W 1257.61 3.1~ 19 S ~ 11 W 1357.0~ 3.71 Z3 S 7 ~2 W 1455.47 :).27 ~ ~ 7 ~2 ~ 1557.53 0.23 53 S 7 4~ W 1657.57 ~3 S 7 51 R 1~55.76 3.15 ~ S 7 ~ ~ 1B55.2! 3U3-SEa qE'T&q 3:JLAR SOUTH T O. O0 'J 0.35 S 0.~0 S 0.77 S 1.1~ S 1.35 S 1.~1 S 1.59 S 2.30 S 2.53 S 3.3) S ~.53 3 7.91 S 15.4~ S 23. 71 S 47.32 S 71.88 S 105.15 S 1~6.~5 S 196.72 S 257.23 S 3£5.98 S ~03.19 S ~90.52 S 5~8.30 S 537.28 S 7a4.34 S 37').56 S ~73,25 S 136~.1~ S 1151.95 S 123H.32 S 1325.37 S 1~24.54 S 1>2~.74 S 1523.9~ S 1722.17 S 1319.72 S 1~16.~2 S 2313.55 S C33R /~:ST T 0.00 0.01 O · O 7 O.11 O.ID 0.12 0.5~ 1.1~ 1.92 2.43 3.1<, ~+.43 5.79 3.~9 1.11 9.50 1~.52 3~.05 5!.~, 74.31 ':J :J. 93 12~+.81 1~,3.51 157.38 172.33 188.15 204.29 ZZD. 31 235.53 252.71 268. 284. 300. 314. 327. 3~1. 35~. 353. 3~1. 3~5. 97 W 72 W 33 W 31 ',~ 79 ,~ 37 W 35 W -~]~IZ. OIST. 0.37 0.~.1 0.7'-3 1 · 1 ~ 1.35 1.53 2.7O 3.55 4.53 5.41 15.93 2,~.73 ~.Z) 7~.~8 11,).22 155.2') 21~.23 275. ~6 3,~. 06 515.15 513.52 712.57 310.51 ?05 · '-33 1~01.59 13~3.7~ 11~2.)4 1273.33 1359.57 1~57.90 155).57 1559.37 175~.35 1355.53 1~53.72 234).~4 3E~&RTURE &ZI~UTH 3E3 3 0 1317 9 5 5 0 ~ lB 22 34 35 41 ~2 18 S 21 13 ~ S 23 57 ~ 3 1) 35 ~ S 17 47 ~ S 15 19 ~ S 15 18 ' S 1~ 35 S 1~ 3 5 13 39 ~ S 13 21 ~ 3--'-9 ND~TH SLD~E, CgMPUTATIgi DATE: 12-=EB-g5 iNT:RPCLAT:D VALJES :OR EVEq 100 TRU~ SJD-S:A ~E~SURE3 VERTI-~L V:RTi'~L DE~TH 3EPTq 3EPTq 4793.29 3993.00 3900.00 4931.30 5093.00 5073.51 ~193.30 %100.00 5~20.01 5293.00 ~233.00 5354.55 ~393.00 5537.51 ~93.00 ~50J.09 5558.B2 ~593.00 5503.00 57BB.01 5593.30 ~03.00 59~$.23 5793.30 6351.27 ~893.00 61~5.15 &9}3.gO 5903.00 6329.&2 5093.00 5000.00 6551.?~ 5193.00 5100.00 6593.38 5293.30 5203.90 6723.~ 5393.00 5300.30 6~52.77 5493.90 5&OD.O0 5930.53 5593.00 5500.0~ 7105.97 5693.00 5503.00 7231.~I 5793.30 5703.00 7355.79 5893.00 5~0~.03 ,,OJRS-~ VSRTI~AL ]~.V! ~Ti ]N AZI~JTH ~£' TIO'q 5EV=PITY ]::G 'lin D53 ~4I'4 FE:_T DE7.,/IO] 43 1 S B 3% W !142.45 0.33 44 35 S 7 ~ W 2237.53 1.15 46 3} S 5 38 4 233~.51 2.07 46 ~5 S 5 15 w 2545.32 3.63 45 55 S 5 7 W 15~.38 3.29 45 17 S 4 5~ 4 2651.45 0.42 44 37 $ 4 5B '4 275].38 0.55 43 32 S ~ 57 W 2957.43 3.25 42 54 S ~ 53 4 1~1.14 }.4~ 42 30 S ~ ~9 ~ 3033.10 ~.3~ 41 53 S 5 3~ 4 3123.33 }.72 %1 ~ S 4 37 ~ ~211.15 0.1~ 43 %2 S ~_,=7 W 33'97_ .$0 0.39 ~0 !2 S 7 5~ ~ 33~2.97 1.6~ 39 29 S ~ 15 ~ 3~°5.87 0.92 33 9 S 7 3~ W ~627.55 0.93 37 19 ~ 7 ~1 ,~ 3704.94 3.55 3~ 11 5 7 59 ~ 3779.6~ 9.49 36 !3 S ? ~5 4 3:~52.92 9.55 36 ~3 S 9 35 W 3'927.56 ]5 ~3 S 3 55 '~ ;332.31 O.OO 36 ~8 S ~ 55 d ~277.20 35 ~ S ~ 55 4 ~109.93 ~.00 7580.55 5993.D0 5~03.00 7505.~5 5093.00 7730.37 61~3.00 510J.O0 ?785.~D 5236.74 5143.74 (EL.~ 3J5-1I,'15 ELE.~ATIDN: -_-NgI~ESR: T. WEST 5 SU~-S-& R:"TAN F= : ': ~ L~,~ T 2104.00 22'~.54 2505.24 130~.33 2511.07 2710.%0 2306.05 Z ~0~. ~? 2~9£.37 3D,~2.57 5 3170.38 S 3255.~ S 3341.39 S 3624.39 S 3505.Z9 5 35~4.04 5 3550.77 S 373~.~3 $ 3307.21 S 3~80.73 S 3)5~.~4 5 532~.15 S ~350.39 S C 3 ]q3 I q 4T: S F;==T 409.75 423.02 43~.33 44~,.1{ 453.51 '6£.65 471.27 47 ~.65 4'~ ~.7Z MDaIZ. ~T. 2143.53 2234.51 233~.31 2445.91 2550.00 2551.74 2751.05 2~47.5~ 2141.19 3~33.12 32.~5 13.3~ 17.33 25. 3~.13 ~'). 77 5'3. 70.31 80. '~ 1 9Z.2~ 3123.33 3211.15 3297.52 3333.31 3~56.91 354~].15 3527.51 3705.01 3779.73 05.95 17.~8 30.90 35.35 3~27.51 4002.43 4277.26 ~ZIqUTM 3ES MIN 11 1 ,4 1} 53 W 19 41 ~ 1~ 27 ~ S 12 14 & } 51 ~ 41 ~) 32 & i) 244 S g 16 W S ~ 8 W S g 1 W S ~ 56 w S ~ 55 W S 3 54 ~ S 3 53 ~ ~ 8 50 W 5 ~ 50 4 5 9 51 4 S 9 52 ~ FT 3:-9 KJ~RJ~ ~]~TH S3~PJTaTI]q 9&I'E: 12-::B-~5 DATE 3~ SURVEY: KELLY ~US~IN3 EL6VATI3N: ~.00 ~NSI~EER: T. WEST FT 5&S: KJ~RJ< C TOP qJP~RUK ~ 3~S~ KU~RU( ~ ZNT:~OgL~T=D V~C]ES =2R ME&SJRE3 DE~TH g:LOW K5 7252.30 73~.00 7~23.D0 ?302.30 7512.00 7735.')0 TV9 5B09.30 5883.5£ 5946.92 5010.16 501~.17 5236.7~ 12 ' :SL, SJ_3-S:a 5715.30 57q,9. 52 5B53.~2 3~17.15 5925.17 514.~. ?~ 67' S JR= :::L, SEZ 1 RECT~NG 37~6. 33~0. 38~5. 39)3. 33~9. ~050. AZE _]C~TI]N ~T ~, T1ZN, q)E, JM ULtlR '30R]IN&I'ES S]UT4 E&ST/WEST fiRS] ~fSq~, I~C. 3=-9 KJP~RU( NINTH SLO~E,&L1Sq~ ~]MPUT&TI]q 12-F:5-B$ P6SE D&TE 3F SURVEY: 1~-3EJ-35 <ELLY ~JSHINS ELE¢6TI]N: ENSI~EE~: T. W:ST 7 )3.0,3 TOP 3~SE TOP 3~SE TD qUP~RJK KJ~RUq C ~E~SflRE3 DE~Tq 7252.20 7~23.00 7502.00 7512.20 7795.00 SJ~RY FRDM TV2 5~09.30 5853.52 59~6.92 5010.16 5018.17 5235.74 12 ' :SL, 5716.30 5790.52 5~53.92 9~17.16 5925.17 5143.74 67' SJ F~L, 3E~ 19, RECT&NGU_ NSRTH/S] 37~5.52 3~g0.31 3~6.75 3~.3g 3~9.23 ~'350.39 E .']CfiTION ~T TIZN, RgE, JM UTi E~ST/REST S 532.53 S 5~1.32 S 5~.OB S $37.17 S 503.31 S 535.35 :IN&L ME~SJRE] DE~TW 7785.03 WEL~ L]~TION TqJE CETTIC~L 5235.7~ TO: SJB-S"~ 51~3.?~ t2RIZg~T~L gIST~SE 41~9.99 &ZI~JTH 3ES MI~ S 3 5~ Cia L.LJ SCHLUMBERGER O I RECT [ ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3F-9 F I ELD KUPARUK COUNTRY USA RUN ONE OATE LOOOEO REFERENCE 00007]269 WELL 3F-9 --. (12' FSL, 67~ FEL, S19, 2N, R9E) HORIZONTAL PROJECTION SCI::R_£ = 1/!000 !N/FT -40OO ~EST ' I - ~- ..... · .................. ~ ................... L ~71~7~';7~7 ......................... ~ ........... ' ............ ~ .............. ......................... . ....... ~ .......... . ...... , i ~ . ~ - . ' ~.~ ..... ~ ............ ~ ...... ~ ............ ~ ........................... ~ ................. ~_..~ ................. ~ ................. ~ ........................... ~.~ ..... ~ .......... ,~ ........ ~. ~ .... ~ ....................... ~ ................ ~:.. ~ ................... ~ ....... ~ .......... ~ .............. ~ ...... ~ .... ........... ~ ............ ~ .... ~ ....... , ........ ~ ......... ~ .............. ~ ~ ........... ~ ...... ~ ..... ~ ..... ~ ......... , ..... ~ ..... . ~ . , , . , ~ , , , ~-~ ...*. L.~..--~ ........ + ............. ~- ........ ~ ......... ~ ...... ~~ ................... ~ ...................... + ........... ~ ....... ~ ...................... , ...................... ~ ....... : ....... ~ ..................................... ~ ........... ~ ........ ~ ................ ~ .... ~ .... ~ .......... ~ ..... ~ ......... ~= ........ ~ ............. ~ ........ ~ ..... __+ ..... ~_~ ..... ~ ........... ~ ......... ~ ..... ~ .......................... - ~ ...... ~ ............. ~ ............. ~ ........: ~ ~ .... ~ ........ i ........... ~ ....... t .....+ .... ' .... t .... ~ .... 1 .... .... ............ ............ ......... ............. .... .......... . .................. .............. , ................... _~...~._:.~ ........... ~....: ...... ~ ............. ~ ........... ~._~ ...... F~ ....... ~..? ......... ~.= ....... : .............. ~ ......................... :::.:.::::~:::::::::-:::~, ....................... ~ ............................. ~"*'"; ...... ;'~"~ T ......................... T ................ ' ........ ~ ...................... : .... : ....... ~ ......... ~... , .... , , · . -~ ...... ~ ........~-.~ .......... ~ ........... j ........~ -~ ..................... ~ ..........~ .............. ; ..........~ ......... ~ ................ t .... t ..... . -4~ -~ -~ - 1 ~ 0 I O~ 20~ ~0~ 4000 E~ RECEIVED Oil & Gas C,:'.:~s. Comm::sio.rl WELL 3F-9 (12' FSL, 67' FEL, S19 ~ ~N, R9E) VERTICAL PROJECTION PROJECTION ON VERTICAL PLANE 189. - 9. SCALED IN vERTICAL OEP?HS HORIZ SCALE = 1/1000 IN/FT Suggested fom to be inserted in each "Active" well folder to check for timely compliance with our regulations. · . OPERATOR, WEL~ NAME A~D NUMB~.R Reports and Materials to be received by: Date Required Date Received Remarks Samples ,..f/.~ ~ ~ Core Chips c6re 'Description Production Test ReportsI U ~ 0 / ' / ,/' = '- "" f") ~ ~ El tD LD U ~ 13J {ti I. rj ~ H H ~J21 8 C~ C~d C~ IL~ k~l I '-~ "-~ 0 0 ?////// /f///// . . . - .. . .. .. f.¢} f.~ ~-<: [L~ [rJ [Ti Ir1 H H ~n ~ O' Z Z ~ ~; t~ t~ ~ td t~ td t~ ~d 0 ~ I-~ i-~ i--~ t~ ~ I-.~ I--~ ~ I I I I I I I I I I-J F-, 0 0 0 0 0 0 0 I I I I I I I I I 0 0 t~ ~::~ ¢:,, ,,1::~, 4:~ 0 0 I'.o f.,.~ 0 0 0 0 0 I,,.) I',,.) 0"~ O~ 0 0 0 0 0 (~ O~ I I I I I I I I I 0 0 LO O0 0 0 0 0 t'o I~ 0 Ul Ul Mi Ul 0 0 O~ t.~ 0/ 0'~ 0'~ 0'~ 0"~ 0'/ I-,, I-.., t'O 0 0 0 0 0 0 0 O0 O0 I-.J LO 0 0 0 0 0 0 0 0 0'10000000000 I I I I I ,I I I I I / I~· 0 0 0 0 0 U fL~TCj # T~,T.j~I~S~ ' S8-6I-~I HJ~YG 09£0-0IS66 NY 09~00I xo~ '0 '6 6Iii ~{z~ID sp.~oo~H yru~dnx ~uedwo:3ple!ltl3!t:13!lUell~ Io ,(Je!p!sqns e s! '3Ul 'e~lSel~' 05t~¥ · ~SLl7 s~nso[3u3 6giq/glnu9 .~aaU.L6U3 a:~e.LOossv ~aqn~9 ~ ' X'[aaa3u.LS 'NN6~-g9g %e am LLOO asoaLd 'suo~Isanb £uo aAeq no£ ~I Og-dSM gl-dSM 8I-9I OI-PG Z-JG OI-V~ SI-Gq §1-91 6-P~ 9-3G gl-Hg IS-gl Z-9I OI-d~ ~I-¥~ ll-Hg G-gl 6g-~ 6-JG gI-V~ OI-Hg 6l-9[ 2g-~ 8-Jg II-Vg 6-Hg '$LLa~ §u~OLLO$ aql ~o~ s~aodaa £Lqluom aaqmaAoN aq~ aae pe$oL~u3 sl~oda~ ale,S '133P~flS 10§66 )iV 'a6e-~oqouv a^.L.~fl au.Ldno.~Od [OOg UO.L SS.LmmO3 UO.L3, eAaaSU03 se9 ~ [.[0 e>lSelV ~>iSeLV .~o a:te~S Jauo L SS .LtUtUO3 uo:~.~alleq3 'A '3 'aN §86I 'Gl aaqma3aQ SLZI. 9ZE Z06 euoqdeleJ. ogso-oLs66 e>lSelV 'eBe~oqou~/ 09gO~ "o1~ cO!IlO lSOd _ 'OUl 'mlSelV 03Ur - STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION COl, ,IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drillirgwell~ 2. Name of operator ARCO Alaska, Inc. !3. Address P. O. Box 100360, Anchorage, AK Workover operation I 7. Permit No. 85-270 4. Location of Well 99510 atsurface 12' FSL, 67' FEL, Sec.19, T12N, R9E, UH 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. 93' RKB ADL 25643 ALK 2574 18. APl Number ;50- 029-21480 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3F-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2245 hrs, 11/11/85. Drld 12-1/4" hole to 3433'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 7785'TD (11/16/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7512' Secured well & RR C 0815 hrs, 11/18/85. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62·5#/ft, H-40 weld conductor set ~ 115'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3415'. C~td w/880 sx PF "E" & 420 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/shoe @ 7603' Cmtd w/200 sx Class 6. 14. Coring resume and brief description [;one 15. Logs run and depth where run DIL/GR/SP/SFL f/7778' - 3410' FDC/CNL f/7778' - 7050' Ca1 f/7778' - 6050' RFT - depth are not available 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~ ~ ,,~~/2L/ TITLE Associate Engineer DATE /~"/~'~' NOTE ReportCn 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 TEMP2/MR74 Submit in duplicate MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATIOt~ COI-~ISSION TO: C. V/.' ,~terton DATE: November 19, 1985 THRU: Lonnie C. Smith Commissioner FILE NO: D.HRH. 95 TELEPHONE NO: FROM: Harold R. Hawkins ,~,.,~_.../'~ Petroleum Inspector SUBJECT: BOPE Test ARCO K.R.U. 3F-9 Permit No. 85-270 Kuparuk River Field Wednesday,. November 13, 1985: I left DS 3J, subject of another report, to DS 3F to witness ~ BOPE Test. I witnessed the BOPE Test on 3F-9 K.R.U.; there were no failures. I filled out an A.O.G.C.C. Report which is attached. In summary: I witnessed the BOPE Test that Doyan 9 crew performed for ARCO on D.S. 3F-9 K.R.U. The tests were satisfactory. Attachment 5/S4 .Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Well Operator_ .~ /~ ~-~, , ~/~/_~ f/f~ Wen Location: Sec]~ T/~~ M Drilling Contractor ~>/~ Ri Location, General J /~ Well Sign. o/1' General Housekeeping O/~ __Rig .... ~P/~ Reserve Pit j/~ Mud Systems Visual Trip Tank Pit Gauge Flow Monitor Gaf Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Representative~_ 7"0 m Permit ~__ ~-- ~ 70 asing set ft. tative ~-z~z ~'t~'£P Audio Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge Pressure'Attained: N2X~- /~I~/A~ /i~l~ ~~ ~ psig Controls: Master ~/~ Remote Blinds switch cover Choke Manifold No. Valves_ t J-- No. flanges_~ Adjustable Chokes_ 7~Rz/ O/q- Hvdrauicallv operated choke Test Time _ _/, hrs. -- days and Inspector/ ~ Kelly and Floor Safety Valves Upper KellL ,~ Test Pressur~ Lower Kelly Test Pressure~ Ball Type Test PreSsure_ Inside BOP Test Pressure Test Pressure Test Results: Failures /Z/J~/~--~ .... Repair or Replacement of failed equipment to be made within Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Movember 8, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska q9510-0360 Re: Kuparuk River Unit 3F-9 ARCO Alaska, Inc. Permit Mo. 85-270 Sur. Loc. 12tFS!., 67'FEL, Sec. 19, Tl?M, RgE, IQ. Btmhole Loc. 1053'FSL, 753'FEL, Sec. 30, T]2N, R9E, ~f. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. ~Vq~e permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. 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. !-~here 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. V~.r?-., t ru ~y _p~s. ur s, C. V. Chatterton' Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO?SMISS!OM be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowell ARCO Alaska, Inc. Post Office Bo~ ~00360 Anchorage. Alaska 99510-0360 Telephone 907 276 !215 November 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3F-9 Dear Mr. Chatterton- Enclosed are' An application for Permit to Drill Kuparuk 3F-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot Diagram and description of the surface hole diverter system o Diagram and description of the BOP equipment We estimate spudding this well on Nove~er 11, 1985. If you have any questions, please call me at 263-4970. S i ncerely, Regional Drilling Engineer JBK/LWK/tw PD/L185 Enclosures STATE OF ALASKA ALASKA UwL AND GAS CONSERVATION CO,v~MISSION PERMIT TO DRILL la. Type of work. DRILL ~ lb. Type of well EXPLORATORY _ REDRILL ~ DEEPEN__-- DEVELOPMENT OIL ~X -- DEVELOPMENT GAS 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 12' FSL, 67' FEL, Sec.19, T12N, RgE, UN At top of proposed producing interval 1332' FSL, 708' FEL, Sec.30, T12N, RgE, UN At total depth 1053' FSL, 753' FEL, Sec.30, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) RKB 93', PAD 56' 6. Lease designation and serial no. ADL 25643 ALK 2574 9. Unit or lease name Kuparuk River Unit 10. Well number 3F-9 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 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 12' (~ surface feet ;3F-8 well 75' (~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7889' MD, 6195' TVD fept 2560 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 1100 feet. MAXIMUM HOLE ANGLE 45 o (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 11/11/85 2714 psig@_80°F Surface 3116 psig@ 6053 ft. TD (TVD 21 Proposed Casing, Liner and Cementing Program SIZE QUANTITY OF CEMENT Hole j Casing 24" i 16" 12-1/4" 9-5/8" CASING AND LINER Weight ~ Grade Coupling Length 62.5# j H-40 ! Weld ! 80' 36.0# ~-55/HF-EI~W BTC i 3388' 8-1/2" 7" 26.0# J!-55/HF-EI:~/ BTC SETTING DEPTH MD TOP TVD I MD BOTTOMTVD 35' [ 35' I 115'! 115' 35' 35' t 3423' 3033' (include stage data) ± 200 cf 880 sx PF "E" & 420 sx PF "C" ! 7855' 34 I 34' 7889'~ 6195' 300 sx Class "G" neat i , 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7889' ND (6195' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2714 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F-9 will be 75' away from 3F-8 at surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED .~~ 4,,.~~A ~,~ TITLE The space ~oetow for Commission use Regional Drilling Engineer DATE CONDITIONS OF APPROVAL Samples required Mud tog required Directional Survey required APl number ----YES ~--~)t~O ZYES ~',JO ~(-Y. ES ~'NO 50-C' :V - ~ '~ i~ Permit number Approval date ~ ,~~ ~1/~5 SEE COVER LETTER FOR OTHER REQUIREMENTS (LWK) PD/PD~5 APPROVED BY Fo~m ! 0-401 ,COMMISSIONER DATE by order of the Commission November _,~, 1 985 Submit in triplicate PERMIT TO DRILL 3F-9 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. · ARCO ~ALASKA,--INC. ---- !- ........... PAD _;_3E;, :14ELL: NO,;-9~ PROPOSED --' -- KUPARUK' FI'ELD ,:-NORTH SIJOPE ,-~-ALASKA ...... EASTt4AN WHIPSTOCK,. INC-- -- i_'~_:~--: _-[ -- __ _ _ ~-'-KOP---'TYD~I-TOO-THD=-T'I-OO''-DE~=-O _ - : _ 3 _- ~U[LD 5 DEG PER I DO F'T .... -- _9 _BASE__,PERMAFROST~__T_VD= 1523 -TMD= 1 527' DEP=47 ~ 21- TOP: UGNU SNDS -TVD=1883 Tl"ID=1907' DEP=168 .... : _2_QO '.. ar- : }-- : ...................... _ _ .. \~ ;:-: ;: ..... : -: :_ :; -' "~ 39- ' ' = ; - .., - - - %..- EOC TVD 2449 TI'ID 2598 DEP 558 ........::=4- -TOP-14- SAK 'SNDS- -_TVD=2493 :TI'ID=2660- DEP=602 C ~ .K'I 2 TVD=28;~3 TI"ID=31 40 DEP"941 .......... 3000_ _ _: .... ._'~__9_5/8?_CSG_PT .... ,.: ................ m< . ._ _ . ./~033 TMD=3423 DEP=1141 __. ............... _T_VD=4503_ THD=5499 DEP=2607 ] AVERAGE ANGLE i _ ~---: - - ...... : -sooo__ 44 DEG 56 H]:N-~_ - ...... r/ zONE. O :-TVD=sT'93:~-"D=7~,:21 D£p~894- % . -- -: :-- f/ ZONE A :-TVD'5911 'rlID=7488 DEP=4012 X '~--'. _ -'_-7L7_ . - - -- BASE KUP- SNDS- -TVD=6053 - THD=7689-DEP=4153 r F E_ b;-.:- . .... i ..... - TD_ .(LDI:;-PT) _ TVD=61951THD=7.889 :DEP=4295 '- --' -. ..... ---- 7'000 ~ .... ..;: :-.:~,. ?.- u~s ',~'~- ~-~:"~- - ....... 4 ......... -:-:27D __ IOOO ..... 2.000 ..... ~OOOLZ:.-- 4000. __ -5000 - . _ : ....... ~- ..... ~ ........... ~. ! .... SCALE l ~I N. -- h=~_] 0 00-ZE'EET ....... ..... ; ........ EASTt'IAN -w~.~$TocK]~£ I NC;. ! -- _ ARCO-ALASKA,- _--__PAD_;3F; - ~/EL-L--_N 0 ;--9 -.'-PRDF'O S,ED -- KUPARUK-- F I ELD.--NOR T H ~-SLOPE .............. WES~S-T _ _ _ 2000 ....... l DO0 .... DZi_-_;:: - . ;.1 000 2000 L'~ _LOCA'rl ON ' 1900 - --SEC.- t9. Tt2N,- R~E , ........................ 5_nnn _' ,. i .z024 ~T 0 -- T A.gP.,.BT) , '700'I:~''600 ' ' 500 ~00 :,',,300~' ' 200 ......... ~' ..... ,- "~'~ .... ~ ..... ~'" ~ .... ~ : ..... ~ ..... ~'~ .... * ~ ' ~ '~ ..... , : , , : , , ' ; : ', , ; /] , '. , ~ , ; , ' ~ ~ ; ~ ~ ; , , , ~ , j : ; ~ , , ,,' ~ ~'~ -;ARGO ALA~KA,~ I NO, ; I ~ ' ,, ~ ~, , ~ .... : '~ ']--~ I ....... ~'~ .... ~:4~-.-~ ..... ~ ........ ' ' , ; , ,, ; ',~ , , T 1- I ' ~ : I : ' , ' ' ~ i ' ' : ~ ~ ' I ~ ~ .... ' i ~ : ' PAD ~SE,i WELL, N'O, 9-10-1 IF12 PROPOSED ~ ,: :, ': ', i ' ~ ~ ' ' '' ' ~ tI ' ' i . ~ , ' '. ~ t ' '/ ' ' I . , i ' . '. ' ' ' ' , . ' I ' ~ 't ' , ' ' "1 ...... t '1 ' ' : ..... r. ] .... ,"'~'r ...... 1-~ 't ....... T~ ...... f-~- ' EAS~ AN NH[PSTOCK, iNC. ' ' i ~, . . ; '~ , . . ~ , , : ; . : ' , : ) , :, i'~- ~ ,~ ~ ~ . . ~. . ,, , , ~ , ,~ ~. .. , , .. L - ' . ; ' .'t '" ' ' ' ' ' ' ~ ' ' ' ' ' ~ "' ..... ' ' , I ;'': ': ,' '~,' ,''''~,,,' ,' I ~', ~ ' ..... r ....... ~ ........ :"t ' ....... r .... ~' ......... t . .... ~ ~ ) ' ..... ~-h, ~ .'-: '~ .... I~. : * , ~ ' 'f'-t~ .;.'.,.'..; J ,..4..~ ...... ~--~--k..-' ........ ~: .... :-~--f.- ' I : ~ ~ ' ' , / , ;I ' ' ' ' ' ' I ; ~ , I [ ~ I: [ , I' '' , , ff~ ,i' 2 I ~' , 1, ,;~ 1, 2 ~ Ii, ',, , ~' ii ........................... , [ : , , ' t ' ,~ ~, ~ ~ , ,~'~ , i' I ~ ............ , , ~, , ,, ,, , ~., ~ .... ,..,' , '/,./ -'---~-; ; ' : ~ ' ' ' , ' ~ ~ ' L~ ' ~ '/ ' ' ~ ' LL J ' ,...................... , ~ ~ ................. .... ~ ...... . .... , , , .... / ..... , ~ ~ . ~ ........ r ................................ ~ ,~ 1.-. , ,,,, ,- , ,, ,I,; ,,, , , ,, . , ., ...... , ..... ., ., , ... ;-~. ~, ,, .. ~ .,...-: ............. , ..... ~.., .... .. .., : .......................... ,..~ ....... : ....... , ..... ~ ......... ~..~ ..... , ,,~ , ~ , , , , ] ; , ~ { , , , , ..... ,, o L. ,, .... ~ ..... ,, /t~./ . .... t f . t~ :t, ~ 1 .... , : ' ~ ' ' ' ' i t : ' ' ; ' .' ~ ' ' ! , / ''z / ' , , . . ,, ,,, ~ t / '. ' ./ ........ ~ ~t , / '/ ,.' I . ~. , . I .. ...... ,:~.:.; . . .'. I., x] ~ 2055 . ~ ...... ~.,.. ...... ~,.,.I ..... ~ ......... , ;.. ' ~ : t I ~ , : , ' I : : ', l.'.~l~'/ ' ' : , , ' ' ' ,' I ' ' I , ' : '. , : : ' t , , , ' ' ~ ' '. j / .. ~ : ~ ' ~ r I ' ' ~ ' ' ' J , I I ' , · -*~ ..... - -~' -fi--' ~ ;..~ ~ ........ - : - -. ~ ' , .~. F; ~ ..... , ~ ............ 't"~ ...... ~ -' ; ' ~ .... ~ 7 ,',I ~; . '. :1~'. I1~o 1,] :. 5 T ~[ '~ , ii, ,'' , ~O0101/IPO01001~ ~ 't~~' ~ ~, ~ ' ~O00e~:' r ~ , , ' , I 1, ] , I ~ i ' 0 !;' i:i~ i;'i' I: '{',,i, :.' f ':~.:::I; :;'f'' 'I,':, ',' ~:I ...... ~,, 'I'.,,' ~'0~ ~'sO'O ~OOi hO0 , :, ~00~ ~': :200 !~tllll/: !1II' ~1;,''t, ~'~ ~ /l'.:!l!/l'l'' ~';",' ;, KUPARUK RI VER UNIT 20" DIVF_J TER SCHEMATIC DE S CR I P T I ON I. 16' C~CTOR. 2. TANI,(O STARTER HEAD. 3. TAI~O SAVER SUB. 4. TANKO LOWER QUICK-C~CT ASSY. 5. TAhaKO UPPER QUI CK-C~CT ASSY. 6, 20' 2000 PSI DRILLING SPOOL Vi/I0' OUTLETS. ?. 10' HCR BALL VALVES W/lO' J DIVERTER LI~ESo VALVES OPEN AUTOMATICALLY UPON CLOSURE OF AhZ~ULAR PREVENTER. 8. 20' 2(::X:~ PSI A~,,LILAR PREVENTER. MAINTENANCE & OPERATION 2 I. UP-ON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE ANINULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CL(}SE At,~NULAR PREVENTER I N THE EVENT THAT AN INFLUX OF WELLBOI~E FLUIDS OR GAS IS DETECTED. IF NECESSARY, MAI~JALLY OVERRIDE AND CLOSE APPROPR I ATE VALVE TO ACHIEVE ~IND DIVERSION, DO NOT SHUT IN ~LL i~. E',.. ,-, '~ ~- '"' U~R ANY ClRCUI~TA~ES. < < 6 i h 5 4 2 DIAGRAM #1 13-5/8" 5000 PSI RSR~A BCP STACK I. 16' - 2000 PSI T~ ~I~ ~ 3. I1' - ~ ~I X 1~8' - ~ ~ ~ ~ 4. 1~8' - ~ ~ P~ ~ 5. 1~8' - ~ ~I ~I~ ~ ~~ ~ KZ~ L~ 6. 1~8' - ~ ~ ~ ~ W~ ~ ~ T~, A~'CLI~TCR CAPACITY TEST 13-5/8" BCP STACX TEST 1. FILL BCP STACX AN:) ~ MANIFO_D W2TH ARCTIC DIESEL. ~ (~(:X THAT ALL LOCK O(31~ S~ IN ~F~ ~ ~F_AD A~ FULLY RETRACTED. SF_AT TEST PLUG IN WITH RUI~I~ JT AhD ~ IN LO~ L21~ VALVES AD~ TO BCP STACX. ALL OT~ 4. PRESSLtaE UP TO 250 PSI AN:) HaD FCR I0 MIN. IN- CR~ PR~ TO _3C00__ PSI AN:) HCLD F(:R I0 MIN. Blrrn Pl~ TO 0 PSI. LII~ VALVES. CLCE~ TCI3 PIPE ~ AAD HC~ VALVES CN KILL AI',D Q-ICKE LI~,S. 6. TEST TO 250 PS! AhD ~ PSI AS IN STEP 4. '7. COVTINJE TESTING ALL VALVES, LIr~F_S, AhD O-CKES WITH A 250 PSI LON AND 3000 PSI HIGI-t. TEST AS IN STEP 4. DO r,,13T PR~'~ .'TEAT ANY C~ THAT IS NOT A FULL (~=OSING PC~ITIVE SEALQ~ Ct, LY 8. C~ TCI3 PIPE ~ A/~ CL__r~_ BOTTC~ PIPE RAMS. TEST BOTTC~ PIPE ~ TO 250 PSI A/~ 30C~ PSI. 10. CLOSE BLZM3 ~ ~ TF_ST TO 2.50 PSI ~ 3030 'MANIF~I.D AAD LI~E:S ARE FLLL CF FLUID. SET ALL VALVES IN CRILL~NG POSITICN. 12..TEST STAI'~IPE VALVES, KF1LY, K~-IIY COCXS, PIPE SAFETY VALVE, A~D I~I:E BC~ TO 250 PSI AhD 13. RECC~ TEST IN:'(~TION CN BLC~ P~ TEST FCI~a, SIGN, AN:) SE~D TO ERILLING ~ISC~. 14. PERFC~ C~ BC~ TEST ~ NIPPLING UP A~ W~EXLY T~ FLIqCTIGNALLY CPERATE ~ DAILY ARCO Alaska. Inc -- Post Office ~ .,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 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 Plat - 3F Pad Wells !-16 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 GRUII/L22 Enclosure If OCT 2 !g 5 A!as~ Oil & G~s Cons. Comm!ssion i 1- Y=5, 22 20.0858" X= 508,662.35 LONG=149°55,46. 549'' 89 FNL, 162 FWL, 52 O.G., 56.1 PAD- 2- Y=5,985,745.10 LAT=70°22,20. 1856,, X= 508,638.99 LONG=149°55,47.233,, 78 FNL, 139 FWL, 52 O.~., 56.3 PAD 3- Y=5,985,754.79 LAT=?OO22'20.2812" X=. 508,616.29 LONG=149°55,47.896,, 69 FNL, 116 FWL, 52 O.G. 56.3 PAD 4,- Y=5,985,764.77 LAT=?O°22'20.3796,, X= 508,593.66 LONG=149°55' 4,8. 558- 59 FNL, 93 FWL, 52 O.G. 56.2 PAD 5- Y=5,985,774.87 LAT=70°22,20. 4792,, X= 508,570.43 LONG=149o55,49. 237 49 FNL, 70 FWL, 52 O*.G. 56.2 PAD 6- Y=5,985,784.84 LAT=70°22,20.5776,, X= 508,547.58 LONG=149o55,49. 906,, NOTES 39 FNL, 48 FWL, 52 O.C. 56.1 PAD I. COORDINATES ARE A.S.P.,ZONE4. 7- Y=5,985,794.93 LAT=70°22,20.6771,, 2..SECTION LINE DISTANCES ARE TRUE. X= 508,524.4,4 LONG.14,9°55,50.582,, 28 FNL, 24 FWL, 52 0.G.,55.9 PAD 3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED 8- Y=5,985,804.81 LAT=70°22' 20. 774,4" ON MONUMENTS SF-MIDDLE & 3F-EAST PER L.H.D.& ASSOC. '. X= 508,501.4,1 LONG=149°55,51.256,, 4.0. G. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. 18 FNL, 1 FWL, 52 0.G.,55.9 PAD CED- RIXX-30:50~"~.RE~V~"L~~'"'I~ ' 9'AS E~U IIKT~Ye CONDUCTORS 9-16 IN SECTIgN 19 4. ."'- OF A~ -b - Y=5 5,834,.85 LAT=70o22'2i.O?08,, ~,R..--.... ~-~ ' '~_'- : _-~k'~"'.".' A-....~O.,~%,~ X= 508,432.81 LONG=149°55,53.265,, ,~",,";;.r~tH:~pj~'~' -.-~e 12 FSL, 67 FEL, 51.20.G., 56.1 PAD w~r: z,+~.,,--,~ · ~- ~ 10- Y=5,985,84,G.70 LAT=70°22,21.1678,, · . ~..,g4,,,o.,,,~,,,~...:... ~ · '~'~"...OWA-~..-~""^~ ..'.~_,~' -' , 11- Y=5,985,855.14 LAT=70°22'21.2708,, · tf~j-. ,~eo.s .-' ~"-' x= 508 387 4,1 ~.0~s=14,9°55,5z,.590,, ~.~ '.. , ..' c~L' ' ' · ~'~Y~-"---.." .1%%..' 32 FSL, 112 FEL 51 2 0 O. 56 3 PAD ~m. ~ ~,~,... . % 9.~%~ ~ ~ ' · ~ ' q%;~'~~.~"'~;~ - 12- Y=5,985,865.19 LAT=70°22,21.3699,, '~ ~'~,,'~'" X= 508,364.05 LONG=149°55,55. 273,, I HEREBY'CERTIFY THAT I AM PROPEI'II.Y MG4tTERED 4,2 FSL,136 FEL,51.1 0.G.56.2 PAD AND LICENSED TO PRACTICE LAND ~.I.I~~~'IN 13- Y=5,985,874.97 LAT=70°22'21.4663" THE .STATE OF ALASKA, TMAT THII I~L~T A~PI~I~NTS X= 508,34,1.36 LONG=149°55 ' 55. 937" A SURVEY MADE UNDER MY DIRECT ~4,'~R~'1~1Ot¢ AND. 52 FSL, 158 FEL, 51.10.G., 56.3 PAD THAT CONDUCTORS I T~ B AR~.COI~I~'~T AS OF 14,- Y=5 985 885 08 LAT=70°22'21 5660" SEPTEMBER 19,198S ANO.COflDUCTC)IK~ I THRU 1~ ' ' ' · ARE CORRECT AS OF ~R, EPI'*EM~ER ~1,111~. X= 508,318.27 LONG=14,9°55,56.612,, , . ' 62 FSL, 181 FEL, 51.1 O.G.,56.3 PAD ~~~ \~' ' 15- Y=5'985'894,'96 LAT=70°22'21'6635" FIVFD x: · 30" ~-x , Oc q~oC 16- Y=5,985,904.95 LAT=70°22,21.7619,, c..., AO0;./ X= 508,272.74 LONG=14,9°55,57.943,, , ,.~j..!..~. ~ _ . , ..... .82 FSL, 227 < '.lUll ' CONDUCTOR AS BUILT "~""" " LO ATI , ,JUll// c CONDUCTORS I THRU 8 LOCATED IN PRO'TRACT'ED ". $EC. 29, T. I2N.,R.g E., U. MER. ilSSI[ Dlt.: October ll,1985 $=.1~: N.T.S. CONDUCTORS g THRU 16 LOCATED IN PROTRACTED SEC. lg, T. IZN.,R. gE.,U. MER. .-.-.~ -- -.., ,...,.,, Drltt®d by: Sydney2 I:)~1. Ne. NSK 85-26 ,__ I i i DO NOT WRITE IN THIS SPACE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx- No special effort has been made to chronologically organize this category of information. Smmemm#mmmmmmmmmmmm#m~ ~mmmmmmm~mmmmme~mmem~ LIS TAP~ YF~FTCATT()P! T,1STTNC *,VP nlno~09. VEOlrlrAn'InN L?$?I~G PAGE SE~VTCr ~AuE I~DTT ~RTGTN 10000 TAP~ N~ IngqO ~ONTTNIIATI~N # PR~VTUI~ TAP~ ~O~M~NT$ ST, IflRERY rILE NR~ ImOTT .001 REPVTCr NAME VEPSION # nA?~ t UAXIMUM T,ENGT~I I 1024 rILE TVpr PRmVTOtI$ FTb~ ** INFnR~A?InN ~FCflRBS ** CN : AR~O At,ASKa TNC WN ! ~F-g PN ! KUPA~IIK TOWN! 12" ~ECT{ 19 qrlllh! H, q'raTt ITNTT TYPE CATE SIZE CODE 000 000 016 065 000 000 004 0~5 000 000 008 065 000 000 002 0~5 000 000 004 065 0o0 000 002 065 000 000 012 065 OhO ()00 006 0~5 0o0 000 On4 0~5 I~N?T TYnE CA?g MIME Cf)~E uno 00(I 001 O~,b },VP nIo.~{O? ~rF. PlFICATInN [,{S?I~'G PAGE] 2 ' ~UN #Oh'g. nA~'k; bnGC. Eh: i?-NEiv-l~5 CASING = _q b'2...5" ~ 3415 O" - ATT SYZ~T m ~.5" 'T?] 77R5,0' TYPE Ff,I.ITD = i.,,~Nh/PI, jY,YME:P ' {')F..~SZZ'Y = 9 90 t,FI/G lam = 3.BgO ~ b8.0 DF VI,e;CnSTT¥ = 4~ 0 ,.q. ~Mr ;; 4,270 ~ 68.0 OF mH = 9,~ ~M? · 3,1~0 (~ 6m 0 DF mbi~Ir~ LOSS = b,b C'4 RM AT FHT = 1,932 ~ 14~, r)F ~i'rRT X SA NI3STO~,~i · $*** THT8 c)aT/~ HA,q NCj? REF'N DIrPTH SM{,FrI'F'L) ,,, OVERLAYS {rl~.£,t) PHTNTS *$*$* t,¥P oln.~o? vEPI~."I~'A'~LnN I..,T$?IN(j PAGE 3 ~CHb)IMRERGEP [,~G~ TN~I,I~DFD WTTH THT$ MAGNETIC ?APE) ~OP~TTON ~EMSTTY COMPFNSA?g~ LOG CF~N~ ~O~'P~NSATEn N£11TRO~, t,O~ (FDN) Nil?E! FTEt. D [)~TA ([)TL) TS 2R' L~S~ ~H~N THE BLUELTNF DEPICTS. (TN CASTNG ZONE) ~N?RY RLnC~S TYPE SI~E PEPR CnDF g~T~Y 2 I 66 0 4 1 6~ 1 8 4 73 ~0 9 4 6~ ,tTN 16 I 66 1 0 1 b6 0 r)ATtJ'~ SPECTF'TCfl'rTo~' r~br~CKS MNc'fu SF'RVICE S~,RVICE IINTI' APl APl APl /~PT FILE SIZE SPI,, REPR PROCESS ~ if - Illl Pit, mit, r~ IL I~' t) I~l ~ I")N r D~~ r DN fLoSS uOD NO. n() 0 0 4 nl 0 0 4 46 0 0 4 44 0 0 4 Ol 0 0 4 O1 0 0 4 A1 0 0 4 O1 U 0 4 02 0 n 4 O1 0 ~ 4 O1 0 0 4 O0 0 0 4 no 0 0 4 t1 0 O 4 lO 0 0 4 CODE (OCTAL) I 68 OnOOOOOOOOOnOn I 68 O00nO000000000 1 68 00000000~00000 1 68 00000000 00000 1, 68 0000000O000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 OHO00000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 onooooooooonoo 4 ' ~EPT ~P qHnB qP~I m~:p,1, qP qHnB ~P ~Hn~ qP~I 7796.0000 8FT,U -2R.A514 ~R -3.4919 ORHO 151.47n9 NCVL 7~On nO00 . -35.5870 ~,411q DRMO ~.7801 s$CNl, 7AOO.n()O0 -2~.104b 34.1797 NC~'L ~EPT ~P SP ~P~l r)EpT 7400.0000 ~Ft,U 2.4026 ~"0 31.W918 ~'CS~t, 7t00.0000 SE'r.~l -6~.$602 GR )4.42t8 ~C~L 7?on.nooo .qFt,l.I -]1.13R'7 ~R 40.n2~4 ~'C~'L 3.7659 Tbn O.O000 gR T -7.q4R5 ~RA 1n.78~2 ~CNI, ].5178 TLn 124.9648 ~R n 0]07 NH~T 2~7q:sooo rc.b 7.7307 Tbn 117.8308 ~R n.0073 ~R~T 204~.6875 ~CNL ].t2~5 118.4648 n.0264 1~86.6875 5.4656 Tbn 95.0808 ~R 0.00?9 NRtT 2347.50n0 mCNl,, 8n.oBqB TLn 64.7148 ~R n.nSt2 ~R~'F 21)q.~000 rCNL 1.5958 2.7249 0.0000 9.4160 0.0000 760 .9648 25 2.4846 117.n]~8 3.0745 1.3702 1)g.4648 518.P175 4.68n2 2.8928 740.3125 t.0 q 60q. R125 Th" 4.6{35 tALl RNRA 10, CALl q.1035 ~N~A 3.2854 ! L,M 2,5667 ~NImA PAL1 9.306b ~N~A 3.6370 Ib~ 4 9343 CALl q:~56b mNRA 3.1702 TL,u 72,A523 PAL1 9,43q5 PNPA 3,50A1 1.61~4 Ti~M 1.6778 144.o375 CAI,'[ 0,8976 lPt.lOOh LVP Oln.HO? VEr~Ilrl("A~InN LTS?I~,G PAGE SP OEOT SP OEOT SP ~HNB SP ~P~I ~P NPHI DEbT ~P NONI r) Eo'r O£PT ~P r~EDT RHr~H ~p ~HnE~ SP 47.Ol09 NC~,L 1"~6~ 7noo oOOO -41.)b~3 -o00,7500 ~CNL 6aOn 0000 RFLU 670n nono ~FI,IJ -4)~B945 gR -090' .~5~0 ~CNL 6600 0000 SFI,U -47,0508 ~R "09q.~bO0 DRuO -~90,75D0 NCNb 6500 0000 qFLU -54~6445 ~R -090.95n0 DROO -o90.7500 KICNL 6400.0000 ~FI,U -090.95n0 DRHO -090.?LnO b'tOn.non~) ~FI,U -4R.1445 ~R -q~q.?5nO DRHO -qqq.95nt) DRHO hl on.oK)nO ~k" I, U -4~.~OnH ~H -090 .=090 5 -~.99 -q~q 4 -999 4 129 -990 -099 t 100. -q9q. 1 -090. 'q9q. 12]. -090, -O9q. 11~. -090. -090 · 154. .9317 .~1~5 ~3~7 ~6875 .9612 .n6~5 .2500 .~500 ? 390 .371.8 ~500 ,7500 lb~4 · .~375 .~500 .~500 4773 .4375 .~LnO .~500 RbO4 0808 7500 ~500 75n0 )917 6593 2500 ?5OO 7U15 1573 9500 n979 t1~5 ~R NRaT ~R NRaT rCNL Ibm NRAT rCNL Tbn ~R ~R NRAT rCNL ThO NRaT FCNL TI,F) NRAT ~'CNL TLD NRAT rCNI, TL, D NRaT l~bn ~R NRAT l 1..07~7 144.~125 ~.5940 441.~40b 1.3713 -090.~500 -090,]500 -090, 500 3.6467 -999.~500 -990 ~500 4.03~9 -099.2500 -999,~500 -090,2500 ). 69 -099.~0500 -99~,7500 -990.2500 ..'t.~967 .-990.2500 090.25O0 -090.7500 4 4800 · -o90.2500 -99~.2500 4.32R9 09o.7500 ~090.2soo -990.~500 -990.2500 -099.25n0 -090.7500 2 6917 =09~:7500 -090.2500 -09~.7500 -090.2500 CAt, I CALl RNRA CAI,I CALI RN~A DN~A RNRA CALl ~NPA IbM CALl RNRA ('AL1 ~NRA rAT, I RNI~A ~AI, I q r.l r~ A 2.0374 9.8145 4,00n7 3,4475 -099,2500 -090,2500 ) 8030 -99g'2500 =099' .~500 4.1453 -090,25~0 -990.2500 2.FIB50 .999.2500 099,2500 3.9768 099 2500 {179 500 ~999.2500 4,38]5 '999,2500 -99m.25oo 3,4553 -090 2500 -999' .2500 2.0440 .090.75n0 -099.9500 ?,9553 -099.2500 -q9q.?Lno LVO ~l~.uO9 VF.'.P[W[CATInN [.,TS'rING oAGE 6 qP 4P~I ~P vP~l OEDT SP 4PHI ~/pH 1 ~EPT ~p OF, uT SP 'qPH [ qHDB r)F~OT ~P~l DEPT ~p ~EPl' qP briO0 oono -50i~008 -qgq ~SnO 5800.0000 S~[,U -5~ 76e5 GR o~99:¢500 ~RHO -09q.7500 NCNL 570o.oono SFf.,U '33,3320 ~R -ggq,~5OO DRHL} -~g4.~500 4Ch'6 42.5B~0 -q9q,~SnO -090.7500 NCWL 50n nOOO ~F't.U -39'ROOU ~R ~9q:~500 nRMO -qgq,~500 NCV6 5400.0000 ~FI,U -~9q.?5nO DRHO -09q.7500 vC~,6 · -50.58~0 GR -qgq,?500 ~RHU -q~q.?500 NCNL ?00.0000 RFI,U 9q.25nO DR;~O -09q.~5~0 NC~L 510n. O000 ,~1,' t, U -45.769b -qgq.~,500 -Oqe~.?SnO NCN[, bO0o 0000 ,qFLU -090.250LI PCN6 3 7249 {6n 1,{7'1B75 -09q.7500 ] ?b?8 T6n 161.3125 ~R -q~q,?snO NRAT -q9~,9500 ~CML 3.B030 YbO 14~,]125 ~R -q9~,2500 NRAT -q99,25~0 FCNL 2.OB42 Ybn 145.56~5 ~R -qgq.2500 NRAT -q90.~500 WCN6 1 4835 Ybn · {40.4~15 ~ -~9q.25nO NRAT -q9u,~500 FCNL 1.8975 TbO {50,6875 ~R -999.2500 NRaT -090.2500 rCNl., 177.3195 ~R -qgg.~5nO A'RaT -09q.7500 ~C~6 0999 ThO -q9q:2500 NRAI -~~q,~bO0 FCNL 1523 -.Qg~"25nO qgq:~.St%0 IrCNL ?.]557 Tbh 11q.6573 ~R -qgq,~500 3.7542 t6~ q99.2500 CAt, I 999,2500 RNRA q9o.2500 3,6272 IbM -999,2500 CALl -qgm,2500 ~NRA -q99,2500 4,t570 -~{99,;~00 CALl -q9q, O0 RNRA ..q~q,~SO0 I 68]7 Y6~ -999',2500 CALl -q99 ;500 RNRA · ,~~q: 500 2.2834 th" -990.~500 CALl -q99,9500 RNRA '09q.2500 1,748! I6~ -q9q.2500 CALl -U~q.~500 RNRA ,q~m, 500 -qgg.~500 ~AL! -g~q ~500 ~NmA -q9~:2500 ],49m3 TbM -999,2500 CAt, I :09q,7500 ~N~A q~e,250o 2,3772 -q9~,2500 CALl -999,~500 -qg~.?500 ~.6116 TLM -q9~.2500 CALl -qgq.~500 -qgq.?500 3,777b q9~,2500 :v9, .se oo -999, 500 'q9q, 500 -999, O0 -999, O0 i.8848 :999,2500 ,m99.25oo 2,~874 -q99, 500 -999, 5nO -999. O0 -99m,2500 2 0608 2,,9,,::,500 099,2500 'q99, 500 '999.2500 2,3596 'q9q,2500 'q99,~500 099,7500 2,W940 -qgq,2500 [,VP nln.HO? VEPIW[CA'I'IFIN I.,?Sq'ING PAGE 7 qHnB 'IPHI ~P RHnB ~P qHn~ ~PH! ~P qP~I DE'PT qHnE~ 'tP~I SP ~PHI ~P NPHI RP RHnB DHDI' qHn~ NPHI nEpT qP pHnb nF. PT -09q.~500 qO0.nOOU ~Ft,U ~40.~320 ~ 99.7500 DRHO -qgq.?SAO ~.!CNG 4700 OOnO qFV,iJ -50:5508 -099 2500 nRHD -o90:2500 460n.flOnO ~Ff.,U -54 tOOB ~R .99Q'75n0 DRHtj 4~00 0000 SFt,U =999.9500 ~'CNL OOnO00 54~o008 099.2500 DRHO -oqq.~SO0 410n noou 8FI.,U -099.7500 NC~'L 4?on.no00 SD't..,IJ -50.55nB 410n.nuol~ ~h'l,U -67.100~ ~R -oqo.?bno nR~lO 4non.nono ,qFT.t{ -qgq.?~nu DRHLi -~9~.~5Ar) '.'C"I., loon. ql)PO ~i,."f d -o99.2500 NRAT -Ogq.?SO0 rCNI, 2.R772 Tbn 131.6875 6R -q~q.2bO0 *tROT -999.75n0 tCNb 2.9260 tun 130.6875 CR -099 2500 NRAT -090~500 rCNL 1.527b 120,0025 GR -.090:2500 NRIT ego ~ 9500 ~'CNL )14:9648 ~R -999.2500 ~R~r -999.2500 FCNL ?.3245 TLr) 122 02'/3 ~,R -09~.25n0 rCNL 3 0393 Tun 11117773 ~R -090.2500 NRAT -090.2500 rCNb 7.7542 Tun 116.0898 ~R -099.7500 NR~T -Oq9.?5OO rCHL 4.14~2 TI, l) lOn.6Sg~ ~R -qgq.2500 NR~T ].o768 lbn -o'~o.?sPu ~CNL 3.92?9 TI.,n -099.2500 -090.9500 3.2542 -~99.2500 :99,:,. soo qgq.2500 3.4534 -099.2500 =~99.2500 -099.2500 3.75 -qgQ.'~5~O -999.~500 -q9q,. 500 -99~.25no .999.75oo =q9q.2500 =999. O0 -qgq.2500 -q99.7500 ?.6252 -990.2500 =999.)500 -Q90.2500 1,4749 -099.{500 =q9q 500 -990:2500 2.4084 -990.~500 -qgq. 500 -q9o.~500 4.3953 099 2500 4.4578 -999.7500 ~.7~nu ~NRA CALl RNI~A ~AI,I RNRA K'ALI RNRA CA[,I ~NPA CAI, I RNI~A CALl RN~A CALI PN~A ~AI, I DNRA ("A f, 1 ONRA -099.~500 3.t760 : 99. 5 o 99q.25nO 3.{94U -q9q 500 -999:9500 2.99R3 '999,2500 -999.2500 3.R557 : 99.2$oo 4.0320 :q99.~500 q99,~500 2.5647 -999.~5n0 -999. 500 t.3 3 so 999,2500 :090.2500 099.2500 4 1835 -999.~.500 4. )367 -.090.2.5n0 99q.25oo 1.64~7 [ l{ L,' ', Old.HO? VEuI~IrA?InN I,ISTI~'G PAGE 8 ~P -6d.78~2 CR qpH] -ogo.?5OU NC~'L -Ogg.?~O0 ].ThiO TLn 4]75 -ggq:2500 -g90.7500 ~CHi, UpUl -~90.~500 ~)C~L · 12~,~148 -090.2500 -090.~500 ~CNL 4.0085 T6r) 104.qb48 CR :qvo.;sno .RAT o90.~500 ~CNL nEDT 3'~on nUN0 ,q l," T, U ~P -74:2852 I~Hr},~ -qgq.~.SO0 nRHO ",ipHI -09q.950U 4 6140 T6D 86'7773 ~R -09n:2500 VRKT -090.2500 ?CUb DEPT 3408 0000 RFT,iJ gP -5n:8870 GH RHnt~ -qg~.~500 BrUO uPul -090.75o0 NCVL 71 . 7] -qgq.?500 -ego. ~5nO 1024 ~RTGTN TAPE NAMF C['iN]'TNI~ATZON # 101 N~YT TAPF NAM~ -agO.2500 -qgg.2500 -ogo.?SnO 4.1257 m~9,~500 ].SBll -~g9.2500 -qgq.?500 -qg9.2500 4.8945 -990.~5n0 -~9q.~500 -090. 500 2546 -g99.~500 -999.~500 -09q.~500 -~9g.7500 -qgq.2500 -~9~.~500 CALl PUPA I6v rA[,I ~NmA TbH CAI, J: RNRA T I,M T6M ?ALI RNRA :qgq.2500 q9~,~5no 1,9983 -099.2500 -qgq,2500 -999, O0 -ogq, ,500 4.{7~7 :99 . ~99,7500 .~.2117 : 99.;5oo 099,~.500 000.6875 ~990 2500 -099:~500
