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
189-109
• • Regg, James B (DOA) (s3Ct tog b From: NSK Fieldwide Operations Supt <n2072@conocophillips.com> Sent: Friday, October 28, 2016 9:08 AM To: Regg,James B (DOA) Subject: Kuparuk 2K-19 Missed Test Jim, This morning we discovered that we missed a SVS test on 2K-19 that should have been conducted by October 2"d. The well was shut in at the time of the pad test completed on September 17th, and was returned to service on September 28th after an initial but unsuccessful restart attempt late on September 27th. At that time, it should have been identified as requiring a MISC test, but was not correctly noted and was not discovered until this morning. We are initiating an investigation into the cause of this and will provide you with an explanation when we complete our review. We are currently working to contact the inspector to see if we can complete a test today, otherwise we will shut in the well until a test can be scheduled with your staff. Scott Fahrney/Larry Baker NSK Fieldwide Operations Superintendent (907) 659-7042NS JUN 0 8 201*! 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. Number We,, H,s,o PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Bevedy Br~athan Lowell [] TO RE-SCAN Date: ~ '~''~ Is/ Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: /si NOTScanned.wpd 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION ❑ Other ❑ ETION OR RECO D Well REPORT LOG 1 a. Well Status: oil ❑ 20AAC 25.105 20AAC 25.110 Development is Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: 9pr-il -82011 189 - 109 / 311 - 058 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 November 4, 1989 - 50 103 - 20118 - 00 ~ 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 219' FNL, 94' FEL, Sec. 11, T1ON, R8E, UM November 10, 1989 - 2K - 19 Top of Productive Horizon: 8. KB (ft above MSL): 40' RKB 15. Field /Pool(s): 1580' FSL, 1264' FEL, Sec. 10, T1ON, R8E, UM GL (ft above MSL): 114' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1387' FSL, 1622' FEL, Sec. 10, T1ON, R8E, UM 9979' MD / 6164' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498310 y 5938085 Zone 4 10659' MD / 6576' TVD ADL 25589 TPI: x - 491863 y- 5934608 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 491505 y 5934416 Zone 4 SSSV @ 1798' MD / 1726' TVD 2675 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1400' MD / 1379' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 170 sx AS II 9.625" 36# J -55 Surf. 3789' Surf. 2898' 12.25" 1200 sx AS III, 450 sx Class G 7" 26# J -55 Surf. 10557' Surf. 6508' 8.5" 450 sx Class G 24. Open to production or injection? Yes ❑ No El If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 3.5" 10084' 10016' MD / 6185' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED squeeze 23 bbls 17 #ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) squeezed off Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per , AC 25.071. NONE >> ,,,. ' ;, k� I Vet N {� Form 10 - 407 Revised 12/2009 CONTINUED • .r �y : ` 6. Submit original only RBDMS MAY 0 3 10 Go 6 7 7, • e: _.„ .4 -. - 70; 6 '28. GEOLOGIC MARKERS (List all formations and markers Altered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1400' 1379' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. Gary Eller 3 Printed Na - V _ awv Title: Alaska Wells Manager �— � ..� _ / Signature _ A �, li. ; ' \ �: r Phone 265 -6306 Date 'J 1/ tie t� Sharon Allsup -Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). • Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 r e • KUP • 2K-19 .11�� > tit r� �Fl , Well Attr&utes IMax Angle & MD TD 1,, I * Y WellboreAPI/UWI F eld Name Well Status Inc! ( °) MD (ftKB) Act Ban (HKB) wisoisammiammea r.SSnnc01^1n4p5 501032011800 [KUPARUK RIVER UNIT (PROD I 60 - 52 I 3,879 99 10,659 0 _ ' C �� ment H2S (ppm) Date - Annotation End Date KB G d (ft) Rig Release Date '•' SSSV: TRDP 90 1/17/2010 Last WO: 39 99 11/14/1989 WEt Canty Schematic Actua2y.194T79511l 104842AM _ An tation Depth ( Dale Annotation L Last Mod .. Last Tag_ TOC 9,979 0 4/11/2011 Rev Reason: PRE CEMENT, TAG TOC Imosbo 'End Date 4/17/2011 Casinq Strin C asin g Descri String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ... String Top Thrd HANGER, 31 CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 ; - Gating Description String 0... String ID ... Top (INKS) Set Depth (t.. Set Depth (MD) ... String WI... String ... String Top Thrd ( SURFACE 95/8 8.765 34.7 3,789.0 2,912.3 36.00 J - 55 BTC r Casing Description String 0... String ID Top (ftKB) Set Depth (f . Set Depth (TVD) .. Stri g Wt... String String Top Thrd PRODUCTION 7 6.151 33 0 10,557.0 6,522.1 26.00 J-55 BTC Tubing Strings "`' " " Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f.. Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING 3 1/2 2 992 31.1 10 084 0 I 6,224.1 9.30 3 - 55 EUE8rdABMOD CONDUCTOR. l'_'.: I Completion Details 35-115 35-115 P Top Depth (ND) Top Inel Nomi... Top (ftKB) (ftKB)(1 item Description Comment ID (in) SAFETYStV, 31.1 31.1 -0.85 HANGER FMC GEN IV TUBING HANGER 3.500 1 1,798.1 1,726.1 32.61 SAFETYVLV CAMCO TRDP -1A SSSV 2.812 � . '` `- �-- -- 10,002.7 6,177 2 55.71 PBR BAKER 80-40 wl10' Stroke PER 2.890 �..,. .� -- - GAB LIFT, -- 10,016.4 6,1849 55.23 PACKER BAKER HB REVTRIEVA BL E PACKER 2.890 2,675 10,052.0 6,205.5 54.23 NIPPLE OTIS XN NIPPLE w/2.81" POLISHED BORE; MILLED OUT TO 2.79" 2.790 3/30/2011 10,083.2 6,223.7 53.74 SOS BAKER SHEAR OUT 2.992 Perforations & Slots i.:;' ...... Shot SURFACE,_ Top (TVD) Btm (TVD) Dens 35 -3,788 Top (ftKB) Ban (VCR (ftKB) (ftKB) Zone DMa (sh.. Type Comment _ 10,157.0 10,159.0 6,267.2 6,268.4 A-6, 2K -19 3/29/2011 6.0 APERF 2.5" Millenium HMX DP charges 60 GAS LIFT, deg phase 5,530 10,169.0 10,189.0 6,274.4 6,286.4 AS, 2K -19 3/1/2010 6.0 APERF 2.5" Millenium HMX charges, 60 degree phase GAS LIFT, 7,062 - -- 10,172.0 10,182.0 2.0 6276.2 6,282.1 AS, 2K -19 3/29/2011 6.0 RPERF 2.5" Millenium HMX DP charges 60 -- deg phase 10,210.0 10,250.0 6,299.0 6,323.3 A-4, 2K -19 5/1/1990 4.0 IPERF 180 deg. Phasing; 4.5" HLS Casing GAS LIFT, ' . Guns 7.833 I Notes: General & Safety _ -- _ -_ -- --_ -- '! End Date Annotation GAS , ,IFT577 10/24/2004 NO TE: WAI VERED WELL: IA x OA COMMUNICATION 8 9/24/2009 NOTE Repair SURF CSG of 95!8" hanger, weld 38" sleeve Wl10" .500 wall API SL -X65 pipe 11/4/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 9,298 . 190848 l : GAS LIFT, _.._. ' 9,959 PBR, 10,003 - - PACKER, .._.._ 10,016 NIPPLE, 10,052 ,:.:, l SOS, 10,083 - 0 11 APERF, 10,157- 10,159 RPERF, Mandrel Details 10,172- 10,182 - Top Depth Top Port APERF, 10,189- 10,189 (TVD) Inc! OD Valve Latch Size TRO Run -' Stn Top (ftKB) (ftKB) ( °) Yaks Model (in) Sent Type Type (i ^) (psi) Run Date Com... 1 2,674.9 2,329.4 56.08 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 2 5,529.7 3,800.4 58.91 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 IPERF, - 3 7,061.6 4,615 1 57.95 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 10,210 - 10,250 :~y 4 7,833.2 5,023.6 58.58 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/3/1990 CEMENT - 5 8,576.8 5,412.8 58.71 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/27/2011 PLUG, 9,979 6 9,298.5 5,789.3 58.71 CAMCO MMG -2 1 12 GAS LIFT DMY RK 0.000 0.0 9242003 7 9,959.4 6,152.5 55.91 CAMCO MMG -2 1 12 GAS LIFT DMY RK 0.000 0.0 3272011 PRODUCTION,_ 33- 10,557 TD (24.19), 10,659 IK, .Ii. I P • 2K-19 ConocoPhillips / $ Well Attribu Max Angle & MD TD : Wellbore Anil WI f Id Name Well Status I CI ("I MD (ftKB) Act Bim (ftKB) ' "' Lkx+rriaphtlhC ( 501032011801 F LIPARUK RIVER UNIT PROD 60.52 3,879.99 10.659.0 - - _ ___n r _ Cam ent K25 (pp m) Deb Mnotatbn End Data KB (ft) Rig Release Dale :ai.K r. st2�].1 SSSV TRDP 90 1/17/2010 Last WO: . 39.99 11/14/1989_ S31 l e t _01i +:' „`.,. Annotation Depth(KKB) End Date Annotation - L tMori ... End D to Last Tag_ELM t 10,311.0 3/14/2011 Rev Reason: GLV C /O, PERF, MILL NIPPLE Imosbor 4;1/2011_ Casing Strings Casing Description Str 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. Strung Wt... 'String ... String Top Thrd HANGER,91 V CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 ._.� ---,- - - Gating Description String 0... String ID ... Top (TIKE) Set Depth (f.. Set Depth (TVD) .. String WI.. String . String Top Thrd SURFACE 9 5/8 8.765 34.7 3,789.0 2,912.3 36 00 J BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (T... Set Depth (TVD) .. String Wt... String .. String Top Thrd PRODUCTION 7 6 151 33.0 10,557.0 6,522 1 26.00 J-55 BTC Tubing Strings r Tubin Descr ptiev ' String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TV DI .. String Wt_. St g String Top Thrd 1 UBING (OC) 3 1 /2 2.992 31.1 10,084.0 6,224 9 J 55 EUEBr4ABMOD CONDUCTOR, - Completion Details 35 -115 Top Depth (ND) Top Inc! Komi... Top (ftKB) ( ___B) ( °) Item Description Comment ID (in) 31.1 31.1 -0.85 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV, - -_ -- „c >. 1,798 1,798.1 1,726.1 32.61 SAFETYVLV CAMCOTRDP- 1ASSSV 2.812 10,002.7 6,177.2 55.71 PBR BAKER 80-40 w110' Stroke PBR 2.890 GASLIFr 10,016.4 6,184.9 55.23 PACKER BAKERHB REVTRIEVABLE PACKER 2.890 2,675 10,052.0 6,205.5 54.23 NIPPLE OTIS XN NIPPLE w/2.81" POLISHED BORE; MILLED OUT TO 2.77" 2.770 3/30/2011 10,083.2 6223.7 5334 SOS BAKER SHEAR OUT 2.992 1 ' Perforations & Slots Shot Top (TVD) She (ND) Dens SURFACE, _____. _ Top ( ftKeZ B1mLHKB� „ (ftKB) (ftKB) Zone Date J (sh.-. Type Comment 3s -3,789 - 10,157.0 10,159.0 6,267.2 6,268.4 A-6, 2K -19 3/29/2011 6.0 APERF 2.5" Millenium HMX DP charges 60 deg phase GAS LIFT, 10,169.0 10,189.0 6,274.4 6,286.4 AS, 2K -19 3/1/2010 6.0 APERF 2.5" Millenium HMX charges, 60 5,530 degree phase 10,172.0 10,182.0 6,276.2 6,282.1 A-5, 2K -19 3/29/2011 6.0 RPERF 2.5" Millenium HMX DP charges 60 GAS LIFT, deg phase 7,062 10,210.0 10,250.0 6,299.0 6,323.3 A-4, 2K -19 5/1/1990 4.0 IPERF 180 deg. Phasing; 4.5" HLS Casing Guns GAS 7639 , Notes: G eneral Y & � & Safety litt End Date Annotation 1 0/24/2004 '40I E: WAIVERED WELL: IAx OA COMMUNICATION GAS uFr, ] 8,5] lit.-- 9/24/2009 NOTE: Repair SURF CSG of 9 5/8" hanger: weld 38" sleeve W/l 0" .500 wall API SL -X65 pipe 11/4/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, _._ ,.T 9,298 IF GAS LIFT, __- 9,959 f I - - - PBR, 10,003 - " - -- (+ 1 PACKER,____. �, 10,016 NIPPLE, 10,052 605, 10,063- - APERF, ._ .:....: 5 10,157- 10,159 Mandrel Details RPERF, mar Top Depth Top Port 10,172 - 10,182 (TVD) Teel OD Valve Latch Size TRO Run APERF„ Stn Top (MB) (ftKB) ( °) Make Model er del (in) Se Type Type (in) (psi) Run D to Com... 10,169 10.189 1 2,674.9 2,329.4 56.08 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 2 5,529.7 3,800 4 58.91 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 3 7,061.6 4,615.1 57.95 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 IPERF,- - 4 7,833.2 5,023.6 58.58 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/3/1990 10,219- 10,250 _ "" 5 8,576.8 5,412.8 58.71 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/272011 6 9,298.5 5,789.3 58.71 CAMCO MMG -2 1 12 GAS LIFT DMY RK 0.000 0.0 9/24/2003 7 9,959.4 6,152.5 55.91 CAMCO MMG -2 1 12 GAS LIFT DMY RK 0.000 0.0 3/27/2011 PRODUCTION, 33- 10,557 TD (2K -19), 10,659 2K -19 Well Work Summary DATE SUMMARY '3/1211 f MITOA - PASSED 3/14/11 BRUSHED TRDP & DRIFT /BRUSH TBG 2.73" & TAGGED @ 10311' SLM. PERFORM 30 MIN NO FLOW TEST ON CLOSED TRDP -1A -SSA, GOOD, REOPENED TRDP. IN PROGRESS 3/15/11 RAN PDS 24 ARM EXTENDED REACH CALIPER f/ 10240' SLM TO SURFACE. GOOD DATA. COMPLETE 3/25/11 SET 2.81" XXN PLUG @ 10052' RKB. ATTEMPTED TEST TBG, FAILED. SET BAITED HOLE FINDER W/O SLIPS ON PLUG @ 10035' SLM. TESTED TBG, PASSED. IN PROGRESS. 3/26/11 PULLED OV @ 9959', GLVs © 8577', 7062', 5530', 2675' RKB. SET DVs @ 2675', 5530', 7062' RKB. IN PROGRESS. 3/27/11 SET DV @ 8577' RKB. LOAD TBG & CSG WITH 400 BBL DSL, TAKING RETURNS OFF IA TO PROD. SET DV @ 9959' RKB; CONFIRMED SET. IN PROGRESS. 3/28/11 MITIA 2500 PSI, PASSED. PULLED HOLEFINDER @ 10035' SLM. PULLED 2.81" XXN PLUG @ 10052' RKB. READY FOR E/L PERFS. 3/29/11 PERFORM CORRELATION PASS WITH GR /CCL PERFORATOR FROM 10,300' TO GLM AT 9959'. PERFORATED AT 10172'- 10182' USING A 2.5" X 10' GUN WITH PROSPECTOR DEEP PENETRATING CHARGES, WITH 6 SPF AND 60 DEG PHASING. PERFORATED TUBING TAIL IN THE MIDDLE OF THE JOINT JUST BELOW THE XN NIPPLE AT A DEPTH OF 10057'- 10059' ELMD, USING A 2" X 2' GUN WITH MILLENIUM BIG HOLE CHARGES, WITH 6 SPF AND 60 DEG PHASING. CORRELATED TO HES GR /CCL LOG DATED 26 -FEB- PERFORMED A BHPS FROM SURFACE TO A DEPTH OF 10300'. MAX RECORDED PRESSURE AT 10300' WAS 2976 PSI AT 165 DEG F. 3/30/11 RIH TO 10062.4 CTMD TAGGED NIPPLE, PUH AND STARTED MILLING, MILLED OUT NIPPLE AT 10062.4 CTMD, DRIFTED DOWN TO 10113 CTMD AND UP REAMED. NIPPLE MILLED OUT OF TUBING, MILL DRIFTED 2.77 ", POSSIBLE DRIFT RUN NEED BY SLICK LINE 3/31/11 (PRE -RWO) PT & DD TEST. MV- PASSED; SSV- SV- DD TEST SSSV- (IN PROGRESS) 4/1/11 GAUGED TBG TO 2.795" THROUGH MILLED -OUT NIPPLE. TAGGED @ 100331' SLM. COMPLETE. 4/7/11 SPOTTED EQ. OVER WELL. TOO LATE TO START JOB LATE NIGHT BEFORE. IN PROGRESS 4/8/11 PERFORMED CEMENT SQZ, PUMPED 23 BBLS 17# PPG TYPE G CMT SQZ'DAPPROX 9 BBLS CMT TO FORMATION. LAID IN CMT FROM 10378 CTMD TO 10040 CTMD IN TBG, WASHED TBG FROM 10040 TO SURFACE W /2# BIO, WELL FP, IN PROGRESS 4/11/11 PRE- CTD - -PT & DD TEST (MV- PASSED), (SV- PASSED), (SSV- PASSED), DD TEST ON (SSSV- PASSED) 4/11/11 TAGGED TOC @ 9979' SLM WITH 2.25" BAILER • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 30, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey & Perforating Record: 2K -19 Run Date: 3/29/2011 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 2K -19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20118 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 103 - 20118 -00 i D APR 1 8 2.01' 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 )/f°)-1°°? c ;d (D 3 klinton.wo• �° col �• 4r Date: Signed: v.t II III • IF ----- r_t,3 WELL LOS TRANSMITTAL PROACrivE DiAgNOSuc SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 \AAR342011 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey fob �3 130 West International Airport Road J �� Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 #il 5 - 03 - 4 - -®`7f q r� 1) Caliper Report 15- Mar-11 2K -19 1 Report / EDE 50 -103- 20118 -00 2) Caliper Report 16- Mar -11 2V -09 1 Report Atdn2lei Signed : 0_, Date : M&R 2 q ?0a Print Name: r sY r. ti Cons. C PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E -MAIL : odsanchorage aememorvloq.com WEBSITE : www.artemorvloq.com C:\Documents and Settings\Diane Williams \Dessktop \CPAI_Transmit.docx 1 • 0 I a Memory Mult - F Caliper �r � Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 2K -19 Log Date: March 15, 2011 Field: Kuparuk Log No.: 10139 State: Alaska I Run No.: 1 API No.: 50-103-20118-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 AB MOD Top Log Intvll: Surface Pipet Use: Tubing Bot. Log Intvll: 10,084 Ft. (MD) I Pipe2 Desc.: 7" 26 Ib. J -55 Pipe2 Use: Production Casing Top Log Intvl2: 10,084 Ft. (MD) Bot. Log Intvl2: 10,285 Ft. (MD) Inspection Type : Pre -CTD Sidetrack Inspection 1 COMMENTS : This caliper data is tied into the Tubing Tail at 10,084' (Driller's Depth). 1 This log was run to assess the condition of the tubing and production casing with respect to corrosive and mechanical damage prior to CTD sidetrack operations. I The caliper recordings indicate the 3.5" tubing appears to be in good condition with respect to internal corrosive and mechanical damage, with the exception of a 21% wall penetration recorded in a line of pits in joint 297 (9,268'). The remainder of the 3.5" tubing appears to be in good condition with no other significant wall penetrations or areas of cross - sectional wall loss recorded. Although no significant I.D. restrictions are I recorded, the caliper recordings indicate light deposits throughout the tubing. A graph illustrating minimum recorded diameters on a joint-by-joint basis of the 3.5" tubing is included in this report. Slight corkscrewing of the 3.5" tubing is recorded from — 6,000' to 9,960'. I The caliper recordings indicate the 7" production casing logged appears to be in good to fair condition with respect to corrosive and mechanical damage, with a maximum wall penetration of 24% recorded in an area of line corrosion and apparent erosion (10,130'). Other recorded damage in the 7" production casing Togged appears as line corrosion, line of pits and apparent shallow erosion throughout the casing logged. No ' significant areas of cross - sectional wall loss are recorded throughout the casing logged. The caliper recordings indicate heavy deposits within the perforation interval from — 10,232' to — 10,258', restricting the I.D. to 5.02" in joint 6 (10,240'). 1 A 3 -D log plot of the caliper recordings across the 7" production casing logged and a graph illustrating minimum recorded diameters on a joint-by-joint basis of the 7" casing logged is included in this report. 3.5 "T BIN - TUBING MAXIMUM RECORDED WALL PENETRATIONS I Line of Pits ( 21 %) Jt. 297 9,268 Ft. (MD) No other significant wall penetrations (> 19 %) are recorded. I 3.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall Toss (> 11 %) are recorded. 1 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com I Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 /19.-109 ab603 1 • • 7" CASING - MAXIMUM RECORDED WALL PENETRATIONS : Line Corrosion / Apparent Erosion (24 %) Jt. 3 @ 10,130 Ft. (MD) Line Corrosion / Apparent Erosion ( 24%) Jt. 1 @ 10,097 Ft. (MD) Line of Pits / Apparent Erosion ( 21 %) Jt. 4 @ 10,157 Ft. (MD) No other significant wall penetrations (> 20 %) are recorded throughout the casing logged. 7" CASING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : 1 No significant areas of cross - sectional wall loss (> 10 %) are recorded throughout the casing logged. 7" CASING - MAXIMUM RECORDED ID RESTRICTIONS : Heavy Deposits Minimum I.D. = 5.02" Jt. 6 @ 10,240 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. 9 9 gg 1 1 1 1 1 1 1 1 1 1 Field Engineer: E. Gustin Analyst: HY. Yang Witness: R. Ober 1 ProActive Diagnostic Services, Inc. / 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 1 I • • Correlation of Recorded Damage to Borehole Profile I Pipe 1 3.5 in (39.7' - 10083.9') Well: 2K -19 ® Pipe 2 7. in (10083.9' - 10253.1') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. I Country: USA Survey Date: March 15, 2011 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 - 44 i oil 50 III 1555 I 100 3123 I 150 4654 E v E c Z 200 6198 - I a . Q I 250 7808 __ - I 1 300 1 ^ 9375 1 10084 7 10253 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 7 I I I • i PDS Multifinger Caliper 3D Log Plot I ct _‘ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2K -19 Date : March 15, 2011 I Description : Detail of Caliper Recordings Across 7" Casing Logged Comments Depth Max. Pen. ( %) Maximum I.D. (ins.) 3-0 Log Image Map 1 l ft:150ft 0 100 5.75 6.75 �^ 0° 0 90° 1 180° 270° 0° I Minimum 1.D. (ins.) 5.75 6.75 I Nominal ID. (ins.) 6.75 Tubing Tail ' _ • I Joint 1 - 10090 j i _ Line Corrosion ! l =- 1 App. Erosion I. 10100 — -s _ _ - l : / Joint 2 ma- Shallow Line I Corrosion / � Shallow App. 101 1 O 1 Erosion e 7 Oa- i I w 10120 I Joint 3 1 LI 4/ Lin C / I A pp. orrosion Erosion 10 0 I i I JO- r 1_ 1 10140 : i ... 10150 ! _' •t I Joint t Line of Pits ! F / App. Erosion 10160 ► i 1 I ,_ r 1 10170 1 F i I .. — — I I ! 0 I 10180 4 ■ ■ ■ ■m .- ■■ ■■ritim _ y j Illidial I 10190 _ - ■■ ■■ ii-1 "' Perforations ■ ■ ■ ■ ®liaM111- I Joint 5 i •••111111i111111111 II Perforations I _ !AMMO 10200 `.._ ■ ■ ■ ■I!■ ■■■■L1! ■ 10210 11111111.111 ■ ■ ■■ ,i!a ! ■ ■t' _ mmim. ilia i■■■� t 10220 _ - - , , '! • - ■ ■■6aa1M_�.■ ■ ■■F7� Joints 10230 M•1111111116-iii - - ■ ■IE'IE ■� +� Perforations ^ - r- _ ■�� . H eavy Deposits `- - : ■E .� Min. I.D. = 5.02" ■ - 10240 C•�- �mr �- , Perforations ■ ■``'! ! ■■ ■ate _ I 10250 ■ ■ ■ ■i�. a " � P!i ■■iMMi _ X1111111 11� 10260 '--- ■aw tiiiiam ■ ■ ■! ■■ Perforations 1 0270 uutii■ ■ ■ ■ia. _ ?' ,. ■ ■ ■@1I■ s ■ ■ ■ • 10280 11' - . -- - -17- --"' - : ; . i Nominal I.D. (ins.) 5 6.75 Minimum I.D. (ins.) I I 5.75 6.75 Comments Depth Max. Pen. ( %) Maximum I.D. (ins.) milit, Log Image Map I1ft:150R 0 100 5.75 + 6.75 " 0° 180° 270° 0 ° I I I • i I PDS Report Overview IP Body Region Analysis I Well: 2K-19 Survey Date: March 15, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf J -55 EUE 8rd ABMOD Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf J -55 EUE 8rd ABMOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) ii 400 am Penetration body elm Metal loss body 0 50 100 I 300 200 1 100 50 0 II 0 to 20% 20 to 40 to over GLM 1 40% 85% 85% 98 Number of joints analysed (total = 329) 1 328 1 0 0 148 - I Damage Configuration ( body) GLM 2 150 -- 198 100 GLM 3 1 I 50 GLM 4 - GLM 5 0 I Isolated General Line Other Hole/ ... Pitting Corrosion Corrosion Damage Pos. Hole GLM 6 29 Number of joints damaged (total = 109) GLM 7 1 108 0 1 0 0 Bottom of Survey = 321.1 I I I I • • I Minimum Diameter Profile Well: 2K -19 Survey Date: March 15, 2011 Field: Kuparuk Tool: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country USA Tubing I.D.: 2.992 inches ' Minimum Measured Diameters (In.) 1.69 1.94 219 2.44 2.69 2.94 0.1 8 16 24 30 40 48 56 61 69 77 85 92 100 108 116 124 132 140 i 148 - 156 Z 164 172 O 179 187 195 203 211 219 226 234 242 250 257 265 273 280 288 296 301 309 317 1 320 I E I 0 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8rd ABMOD Well: 2K -19 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 15, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 40 0 0.01 6 1 3.00 Pup 1 44 0 0.03 10 3 2.95 2 75 0 0.02 8 2 2.95 3 106 0 0.02 8 2 2.96 4 136 0 0.03 11 3 2.95 I 5 166 0 0.03 12 2 2.96 Shallow Pitting. 6 196 0 0.03 10 2 2.97 7 227 0 0.03 12 3 2.94 8 258 0 0.02 8 2 2.96 I 9 288 0 0.02 7 3 2.95 10 319 0 0.02 7 2 2.95 11 350 0 0.03 12 4 2.96 Shallow Pitting. 12 381 0 0.03 12 3 2.96 Shallow Line of Pits. I 13 411 0 0.03 11 2 2.94 14 442 0.04 0.03 11 4 2.94 15 471 0 0.03 12 4 2.95 Shallow Pitting. 16 502 0 0.03 12 4 2.97 Shallow Pitting. I 17 532 0 0.02 9 2 2.98 18 562 0 0.03 10 2 2.98 19 593 0 0.03 10 3 2.95 20 622 0 0.03 11 2 2.96 21 652 0 0.03 11 2 2.95 I 22 682 0 0.03 12 3 2.95 23 713 0 0.03 13 4 2.96 Shallow Line of Pits. 24 744 0 0.02 7 4 2.96 25 774 0 0.02 7 2 2.96 I 26 805 0 0.02 7 3 2.96 27 836 0 0.02 7 2 2.97 28 867 0 0.02 9 4 2.94 29 897 0 0.02 9 2 2.94 I 30 927 0 0.03 12 3 2.96 Shallow Pitting. 31 958 0.03 0.03 11 4 2.94 32 988 0 0.02 9 3 2.96 33 1019 0.03 0.03 11 2 2.95 34 1049 0 0.03 12 2 2.96 I 35 1080 0.03 0.04 14 4 2.96 Shallow Pitting. 36 1111 0 0.03 12 2 2.95 37 1 141 0 0.03 12 3 2.98 Shallow Pitting. 38 1172 0 0.02 7 2 2.95 I 39 1204 0 0.02 9 2 2.94 40 1237 0 0.02 9 2 2.96 41 1269 0 0.01 6 1 2.95 42 1302 0.10 0.02 8 2 2.95 I 43 1334 0 0.02 7 2 2.94 44 1367 0 0.02 9 2 2.95 45 1399 0 0.02 9 2 2.95 46 1431 0 0.03 10 2 2.95 I 47 1464 0 0.03 11 3 2.96 48 1494 0 0.03 12 4 2.94 Shallow Pitting. 49 1525 0.03 0.03 12 4 2.96 Shallow Line of Pits. I Peation Meta l Loss Body Page 1 1 I I 0 M PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8rd ABMOD Well: 2K -19 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 15, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 50 1555 0 0.03 11 4 2.96 ■ 51 1586 (1 0.03 11 3 2.96 ■ 52 1616 l) 0.03 11 3 2.95 • 53 1647 0 0.03 13 3 2.95 Shallow Line of Pits. 54 1678 0 0.02 7 2 2.95 I 55 1708 0 0.03 11 3 2.96 56 1739 0 0.02 7 2 2.96 57 1770 0 0.02 8 3 2.94 57.1 1800 0 0.02 7 2 3.00 Pup I 57.2 1806 0 0 0 0 2.81 Camco TRDP-1A-SSA 57.3 1817 0.04 0.03 10 11 3.03 Pup 58 1818 0 _ 0.02 9 4 2.95 59 1848 0 0.03 10 3 2.94 ■ I 60 1879 0 0.02 9 4 2.94 ■ 61 1910 0 0.03 11 2 2.95 ■ 62 1939 0.03 0.03 11 2 2.95 ■ 63 1970 0 0.03 12 3 2.94 • I 64 2000 0 0.03 12 5 2.95 Shallow Line of Pits. ■ 65 2031 (1 0.03 11 3 2.93 66 2062 0 0.02 7 2 2.96 67 2093 0 0.03 10 3 2.94 ■ 68 2124 0 0.03 11 4 2.95 ■ I 69 2154 0 0.03 11 4 2.94 ■ 70 2185 0 0.03 12 4 2.96 Shallow Line of Pits. N 71 2216 0 0.01 6 2 2.95 72 2247 0.03 0.03 11 3 2.95 ■ I 73 2278 0.01 0.02 9 2 2.93 Lt. Deposits. • 74 2309 0 0.03 13 3 2.93 Shallow Pitting. Lt. Deposits. • 75 2338 0 0.03 10 3 2.95 • 76 2369 0 0.03 12 2 2.94 • I 77 2398 0.03 0.03 10 3 2.94 • 78 2429 0.04 0.02 9 2 2.95 79 2460 0 0.02 7 2 2.95 80 2490 0 0.02 7 3 , 2.95 il 81 2523 0 0.02 6 2 2.95 I 82 2555 83 2588 0 0.01 6 2 2.96 0 0.02 7 1 2.94 84 2620 0 0.02 7 I 2.96 85 2652 0 0.03 11 2 2.93 Lt. Deposits. I 85.1 2682 0 0 0 0 2.90 GLM 1 (Latch @ 1:30) I 86 2690 0 0.03 12 3 2.93 Lt. Deposits. ■ 87 2718 0 0.03 11 2 2.92 Lt. Deposits. • 88 2 749 0 0.03 10 2 2.94 • I 89 2780 0 0.03 12 3 2.94 • 90 2811 0 0.03 11 2 2.93 91 2842 0 0.01 6 1 2.95 92 2874 0 0.02 7 2 2.93 Lt. Deposits. I 93 2907 0 0.02 9 1 2.94 94 2939 0 0.02 9 2 2.93 Lt. Deposits. 95 2970 0 0.02 8 2 2.93 Penetration I Metal Loss Body Page 2 I I 1 • 9 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8rd ABMOD Well: 2K -19 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 15, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) 0 /,, (Ins.) 0 50 100 96 3001 0 0.02 9 2 2.92 Lt. Deposits. ■ 97 3031 0 0.03 11 2 2.92 Lt. Deposits. II 3061 0 0.03 11 3 2.93 ■ 99 3091 0 0.02 8 3 2.93 Lt. Deposits. J I 100 3123 0 0.03 11 2.94 ■ 101 3153 0 0.03 10 i 2.92 Lt. Deposits. ■ 102 3184 0 0.02 9 3 2.93 ■ 103 3215 0 0.03 11 3 2.92 Lt. Deposits. is 104 3246 0 0.03 12 4 2.93 Lt. Deposits. I 105 3276 106 3307 0 0 0.02 9 2 2.93 Lt. Deposits. 0.03 10 2 2.92 Lt. Deposits. 107 3338 0 0.02 9 2 2.92 Lt. Deposits. 108 3369 0 0.03 11 4 2.94 ■ I 109 3400 (1 0.03 10 3 2.94 ■ 110 3428 0 0.03 12 4 2.92 Shallow Line of Pits. Lt. Deposits. • ■ 111 3460 0 0.03 11 4 2.92 Lt. Deposits. ■ 112 3490 O 0.03 12 2 2.91 Lt. Deposits. s I 113 3521 0.05 0.03 11 4 2.92 Lt. Deposits. 114 3552 0 0.02 8 2 2.94 115 3583 0 0.03 11 4 2.93 116 3614 t) 0.02 8 3 2.92 Lt. Deposits. I 117 3644 0 0.02 9 3 2.96 ■ 118 3674 0 0.03 11 2 2.94 ■ 119 3705 0 0.03 12 4 2.93 Shallow Line of Pits. Lt. Deposits. ■ 120 3735 0 0.03 10 3 2.93 Lt. Deposits. ■ 121 3765 0 0.03 10 3 2.94 ■ I 122 3796 0 0.03 11 4 2.93 Lt. Deposits. • 123 3827 0 0.03 11 4 2.92 Lt. Deposits. ■ 124 3858 0 0.02 9 2 2.93 Lt. Deposits. • 125 3889 O 0.03 10 3 2.93 • I 126 3919 0.04 0.03 11 3 2.92 Lt. Deposits. ■ 127 3949 0.04 0.03 11 2 2.94 128 3979 0 0.03 11 2 2.93 Lt. Deposits. ■ 129 4010 0 0.02 , 9 2 2.94 ■ 130 4041 () 0.03 10 3 2.93 Lt. Deposits. I 131 4072 0 0.02 8 3 2.94 132 4101 0 0.02 9 2 2.94 3 133 4132 0 0.03 11 3 2.94 ■ 134 4163 O 0.03 11 3 2.94 • I 135 4193 (1 0.03 13 3 2.92 Shallow Line of Pits. Lt. Deposits. • 136 4225 0.03 0.03 11 2 2.94 • 137 4255 0 0.03 11 2 2.95 138 4286 0 0.02 8 2 2.90 Lt. Deposits. I 139 4316 0 0.03 11 2 2.93 Lt. Deposits. 140 4346 0 0.03 10 3 2.89 Lt. Deposits. ■ si 141 4377 0 0.03 10 3 2.93 Lt. Deposits. • 142 4408 (1 0.02 9 3 2.92 Lt. Deposits. I 143 4438 0 0.02 6 2 2.97 144 4470 0 0.03 10 2 2.92 Lt. Deposits. 145 4501 0 0.03 11 2 2.92 Lt. Deposits. ti on Body sii I Metal Loss Body Page 3 Penetra I I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8rd ABMOD Well: 2K -19 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 15, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 146 4531 0 0.03 11 3 2.92 Lt. Deposits. • 147 4561 0 0.03 13 4 2.93 Shallow Pitting. Lt. Deposits. • ■ 148 4592 0 0.03 10 3 2.92 Lt. Deposits. • 149 4623 0 0.03 10 4 2.92 Lt. Deposits. 150 4654 0 0.02 7 3 2.93 Lt. Deposits. il I 151 4683 0 0.03 10 3 2.92 Lt. Deposits. • 152 4711 0 0.04 14 1 2.92 Shallow Pitting. Lt. Deposits. ■ 153 4742 0 0.02 9 3 2.92 Lt. Deposits. • 154 4772 0 0.02 9 3 2.93 Lt. Deposits. • I 155 4803 0 0.03 10 2 2.91 Lt. Deposits. • 156 4834 0 0.02 9 2 2.94 ■ 157 4864 0 0.02 9 3 2.93 Lt. Deposits. • 158 , 4895 0 0.03 11 3 2.93 Lt. Deposits. ■ I 159 4926 0 0.03 12 4 2.93 Lt. Deposits. • 160 4956 0 0.04 17 2 2.90 Shallow Pitting. Lt. Deposits. • ■ 161 4987 0 0.03 11 3 2.94 • 162 5015 0 0.03 12 3 2.93 Shallow Line of Pits. Lt. Deposits. • I 163 5046 0.03 0.02 9 , 4 2.93 • 1 164 5077 0 0.02 9 4 2.93 • 165 5107 0 0.03 10 2 2.91 Lt. Deposits. ■ 166 5137 0.03 0.04 16 4 2.92 Shallow Line of Pits. Lt. Deposits. • 167 5167 0.04 0.03 10 3 2.92 Lt. Deposits. I 168 5197 0 0.02 8 2 2.93 Lt. Deposits. 169 5228 0 0.02 9 3 2.92 Lt. Deposits. 1 II 170 5259 0 0.03 11 2 2.92 Lt. Deposits. • 171 5290 0 0.03 13 4 2.92 Shallow Pitting. Lt. Deposits. • ! 1 172 5321 0 0.04 15 3 2.94 Shallow Line of Pits. • 173 5352 0 0.02 9 2 2.92 Lt. Deposits. • 174 5383 0 0.03 12 3 2.92 Lt. Deposits. • 175 5412 0 0.03 13 2 2.94 Shallow Line of Pits. 176 5443 0 0.02 9 1 2.92 Lt. Deposits. 177 5473 0 0.03 11 4 2.90 Lt. Deposits. • 178 5504 0.03 0.03 11 4 2.91 Lt. Deposits. 178.1 5535 0 0 0 0 2.88 GLM 2 (Latch @ 8:00) 5542 0 0.04 14 3 2.89 Shallow Line of Pits. Lt. Deposits. I 179 180 5573 0 0.02 9 3 2.91 Lt. Deposits. 181 5604 0 0.02 7 2 2.92 Lt. Deposits. 182 5635 0 0.02 , 9 3 2.94 • 183 5666 0 0.03 11 4 2.93 I ill 184 5695 0.04 0.02 9 3 2.94 185 5725 0 0.03 13 4 2.94 Shallow Pitting. • 186 5755 0 0.03 11 4 2.94 ■ 187 5787 0 0.03 12 3 2.93 Shallow Pitting. • I 188 5817 0 0.03 11 3 2.92 Lt. Deposits. 189 5848 0 0.02 7 2 2.91 Lt. Deposits. 190 5878 0 0.03 13 3 2.93 Shallow Pitting. Lt. Deposits. 7 191 5911 0 0.02 9 2 2.95 I 192 5943 0.03 0.03 13 4 2.92 Shallow Pitting. Lt. Deposits. ■ 193 5974 0 0.02 9 2 2.93 ■ 194 6006 0 0.04 16 6 2.91 Shallow Pitting. Lt. Deposits. rat I Metal Loss ion Body Page 4 Penet I I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8rd ABMOD Well: 2K -19 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 15, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 195 6037 0 0.04 15 3 2.93 Shallow Line of Pits. • 196 6068 0 0.03 12 4 2.94 Shallow Pitting. ■ 197 6100 0 0.02 9 2 2.94 • 198 6132 0 0.03 10 3 2.90 Lt. Deposits. ■ 199 6165 O 0.03 11 2 2.96 ■ I 200 6198 201 6230 0 0.03 11 4 2.93 0 0.02 9 3 2.94 202 6262 0 0.03 13 4 2.93 Shallow Pitting. ■ 203 6295 0 0.02 9 3 2.94 • I 204 6327 0 0.03 12 2 2.92 Shallow Pitting. Lt. Deposits. is 205 6359 0 0.03 13 4 2.94 Shallow Pitting. ■ 206 6392 0 0.03 12 4 2.93 Shallow Pitting. Lt. Deposits. ■ 207 6424 0 0.03 13 3 2.93 , Shallow Pitting. Lt. Deposits. ■ I 208 6457 0 0.03 12 3 2.89 Shallow Pitting. Lt. Deposits. ■ 209 6490 0 0.03 13 4 2.93 Shallow Pitting. Lt. Deposits. ■ 210 6521 0 0.03 10 3 2.92 Lt. Deposits. • 211 6553 0 0.03 12 4 2.94 Shallow Line of Pits. • I 212 6586 0 0.03 11 4 2.92 Lt. Deposits. ■ 213 6617 0 0.03 10 4 2.93 ■ 214 6649 0 0.03 11 3 2.94 ■ 215 6683 0 0.03 12 3 2.92 Lt. Deposits. is 216 6713 0 0.03 11 3 2.93 ■ I 217 6743 0 0.03 10 4 2.93 Lt. Deposits. ■ 218 6775 0 0.02 9 3 2.94 ■ 219 6808 0 0.03. 13 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ 220 6840 0 0.03 12 2 2.92 Lt. Deposits. ■ I 221 6873 0 0.02 9 4 2.92 Lt. Deposits. ■ 222 6906 0 0.03 11 3 2.91 Lt. Deposits. ■ 223 6937 0 0.02 9 3 2.88 Lt. Deposits. • 224 6970 0 0.03 11 4 2.93 Lt. Deposits. ■ I 225 7003 0 0.03 11 3 2.93 • 226 7035 0 0.03 11 3 2.95 226.1 7065 0 0 0 0 2.89 GLM 3 (Latch @ 11:00) i 227 7072 0 0.02 9 2 2.95 • I 228 7105 0 0.03 10 3 2.92 Lt. Deposits. ■ 229 7138 0 0.03 10 2 2.93 ■ 230 7170 0 0.03 11 2 2.92 Lt. Deposits. ■ 231 7203 0 0.02 9 3 2.92 Lt. Deposits. ■ 232 7233 0 0.04 14 3 2.93 Shallow Pitting. Lt. Deposits. ■ I 233 7265 0 0.04 15 3 2.91 Shallow Pitting. Lt. Deposits. NI 7296 0 0.03 12 3 2.91 Shallow Pitting. Lt. Deposits. ■ 235 7329 0 0.02 9 4 2.93 ■ 236 7361 0 0.03 11 .3 2.93 Lt. Deposits. ■ I 237 7393 0 0.04 15 3 2.94 Shallow Pitting. ■ 238 7427 0 0.04 15 2 2.93 Shallow Line of Pits. Lt. Deposits. II 7458 0 0.03 10 3 2.93 is 240 7491 O 0.03 11 3 2.88 Lt. Deposits. ■ 241 7525 t) 0.03 11 4 2.93 Lt. Deposits. • I 242 7556 0 0.03 11 4 2.94 ■ 243 7589 0 0.03 11 2 2.94 ration Body Metal Loss Body Page 5 Penet I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8rd ABMOD Well: 2K -19 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 15, 2011 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I oss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 244 7621 0 0.03 11 3 2.92 Lt. Deposits. • 245 7653 0.04 0.04 14 3 2.91 Shallow Pitting. Lt. Deposits. • 246 7685 0.04 0.04 17 5 2.91 Shallow Line of Pits. Lt. Deposits. ■ 247 7715 0 0.03 13 4 2.91 Shallow Pitting. Lt. Deposits. ■ 248 7747 0 0.03 11 3 2.92 Lt. Deposits. ■ I 249 7776 0 0.04 14 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ 250 7808 0.03 0.04 16 4 2.90 Shallow Line of Pits. Lt. Deposits. 250.1 7838 0 0 0 0 2.86 GLM 4 (Latch @ 10:30) 251 7845 0 0.03 12 4 2.92 Shallow Pitting. Lt. Deposits. ■ I 252 7877 0.03 0.04 16 5 2.92 Shallow Line of Pits. Lt. Deposits. 253 7906 0 0.02 9 3 2.94 ■ 254 7938 0 0.03 11 4 2.91 Lt. Deposits. is 255 7970 0 0.03 13 3 2.92 Shallow Line of Pits. Lt. Deposits. ■ I 256 8000 0 0.03 12 4 2.92 Lt. Deposits. • 257 8030 0 0.04 15 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ 258 8062 0.04 0.04 15 5 2.90 Shallow Line of Pits. Lt. Deposits. ■ 259 8092 0 0.04 17 4 2.91 Shallow Line of Pits. Lt. Deposits. ■ 260 8122 0.03 , 0.05 19 3 2.89 Shallow Line of Pits. Lt. Deposits. ■ I 261 8153 0 0.03 11 3 2.91 Lt. Deposits. • 262 8183 0 0.03 12 4 2.90 Shallow Pitting. Lt. Deposits. ■ 263 8213 0 0.04 17 3 2.91 Shallow Line of Pits. Lt. Deposits. • 264 8245 0 0.03 12 3 2.91 Lt. Deposits. ■ I 265 8274 0 0.03 12 3 2.92 Shallow Pitting. Lt. Deposits. ■ 266 8307 0 0.03 11 4 2.91 Lt. Deposits. ■ 267 8337 0 0.03 12 3 2.89 Shallow Pitting. Lt. Deposits. is 268 8368 0 0.03 13 3 2.92 Shallow Pitting. Lt. Deposits. ■ I 269 , 8398 0 0.03 10 3 2.91 Lt. Deposits. ■ 270 8426 0 0.03 12 3 2.92 Shallow Pitting. Lt. Deposits. ■ 271 8458 t) 0.03 11 2 2.91 Lt. Deposits. ■ 272 8488 0 0.02 9 3 2.92 Lt. Deposits. ■ I 273 8521 0 0.04 15 6 2.89 Shallow Pitting. Lt. Deposits. 274 8552 0 0.04 14 4 2.92 Shallow Line of Pits. Lt. Deposits. 274.1 8580 0 0 0 0 2.87 GLM 5 (Latch @ 11:00) 1 275 8587 0 0.03 10 3 2.90 Lt. Deposits. is 276 8619 t) 0.04 15 4 2.90 Shallow Line of Pits. Lt. Deposits. ■ I 277 8648 0 0.03 12 4 2.89 Shallow Pitting. Lt. Deposits. • 278 8679 0 0.03 12 4 2.93 Shallow Line of Pits. Lt. Deposits. ■ 279 8710 0.04 0.04 14 3 2.91 Shallow Line of Pits. Lt. Deposits. is 280 8739 0.03 0.03 13 7 2.93 Shallow Pitting. Lt. Deposits. I 281 8770 0 0.04 15 , 4 2.91 Shallow Line of Pits. Lt. Deposits. ■ 282 8801 O 0.03 13 4 2.90 Shallow Line of Pits. Lt. Deposits. ■ 283 8832 0 0.04 15 5 2.90 Shallow Line of Pits. Lt. Deposits. ■ 1 284 8863 0 0.04 15 4 2.89 Shallow Pitting. Lt. Deposits. • I 285 8892 0 0.03 13 3 2.87 Shallow Line of Pits. Lt. Deposits. • 286 8924 0.03 0.04 16 5 2.90 Shallow Line of Pits. Lt. Deposits. ■ 287 8955 0 0.03 13 3 2.92 Shallow Pitting. Lt. Deposits. ■ 288 8986 0 0.03 12 3 2.88 Lt. Deposits. • I 289 9017 0 0.04 15 4 2.90 Shallow Line of Pits. Lt. Deposits. ■ 290 9048 0 0.04 14 5 2.91 Shallow Pitting. Lt. Deposits. ■ 291 9077 O 0.04 17 5 2.86 Shallow Line of Pits. Lt. Deposits. rat I Metal Loss ion Body Page 6 Penet I I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8rd ABMOD Well: 2K -19 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 15, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I oss I.D. Comments (% wall) (Ins.) (Ins.) `% (Ins.) 0 50 100 I 292 9109 0.03 0.04 16 5 2.88 Shallow Line of Pits. Lt. Deposits. ■ 293 9141 0 0.03 12 2 2.88 Shallow Pitting. Lt. Deposits. ■ 294 9172 0 0.03 12 3 2.90 Lt. Deposits. ■ 295 9201 0 0.03 11 2 2.90 Lt. Deposits. • 296 9231 0 0.03 13 3 2.86 Shallow Pitting. Lt. Deposits. • 297 9263 0 0.05 21 4 2.91 Line of Pits. Lt. Deposits. ■ 297.1 9293 (1 0.03 11 6 2.96 Pup 297.2 9302 0 0 0 0 2.94 GLM 6 (Latch Q 7:30) 297.3 9310 0 0.02 9 1 2.97 Pup I 298 9314 0.03 0.04 15 0 2.89 Shallow Line of Pits. Lt. Deposits. II 299 9345 0.03 0.04 16 3 2.88 Shallow Line Corrosion. Lt. Deposits. • 300 9375 0 0.03 13 3 2.91 Shallow Pitting. Lt. Deposits. • 301 9406 0 0.03 13 2 2.88 Shallow Pitting. Lt. Deposits. • I 302 9436 0.03 0.04 14 3 2.90 Shallow Pitting. Lt. Deposits. • 303 9465 0 0.04 14 4 2.89 Shallow Pitting. Lt. Deposits. • 304 9497 0 0.04 16 4 2.90 Shallow Line of Pits. Lt. Deposits. • 305 9527 0.03 0.04 15 5 2.88 Shallow Line of Pits. Lt. Deposits. ■ I 306 9557 0 0.03 12 4 2.88 Shallow Pitting. Lt. Deposits. ■ 307 9588 0 0.02 9 2 2.91 Lt. Deposits. IN 9618 0 0.03 13 3 2.91 Shallow Line of Pits. Lt. Deposits. • 309 9648 0 0.04 14 5 2.88 Shallow Pitting. Lt. Deposits. ■ 310 9681 0 0.03 11 4 2.89 Lt. Deposits. • 311 9709 0.03 0.04 15 4 2.87 Shallow Line of Pits. Lt. Deposits. ■ 312 9740 0 0.04 14 4 2.88 Shallow Pitting. Lt. Deposits. ■ 313 9769 0.03 0.03 13 5 2.89 Shallow Pitting. Lt. Deposits. ■ 314 9800 0 0.04 14 3 2.92 Shallow Line of Pits. Lt. Deposits. • 315 9831 0 0.03 12 4 2.88 Shallow Pitting. Lt. Deposits. • 316 9864 0 0.03 11 2 2.91 Lt. Deposits. is 9896 0 0.04 14 4 2.90 Shallow Line of Pits. Lt. Deposits. ■ 318 9926 0 0.04 15 3 2.90 Shallow Line of Pits. Lt. Deposits. I 318.1 9956 0 0.02 7 2 2.93 Pup Lt. Deposits. 318.2 9960 0 0 0 0 2.86 GLM 7 (Latch @ 9:00) 318.3 9969 0.03 0.02 7 1 2.90 Pup Lt. Deposits. 319 9973 0 0.04 15 4 2.88 Shallow Line of Pits. Lt. Deposits. 319.1 10004 0.05 0.02 8 3 3.00 Baker '80/40' w/ 10" Stroke PBR I 319.2 10016 0 0 0 0 2.89 Baker'HB' Retrivable Packer 320 10023 0.04 0.03 12 7 2.91 Lt. Deposits. 320.1 10053 0 0 0 0 2.75 Otis XN Nipple (No Go) d 321 10054 0 0.04 15 4 2.92 Shallow Pitting. Lt. Deposits. 1 321.1 10084 0 0 0 0 2.99 Tubing Tail I Penetration Body Metal Loss Body I I I Page 7 I I I • • I 1:174-5 PDS Report Cross Sections I Well: 2K -19 Survey Date: Tool Type: March 15, 2011 Field: Kuparuk UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf J -55 EUE 8rd ABMOD Analyst: HY. Yang 1 I Cross Section for Joint 297 at depth 9267.511 ft Tool speed = 50 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 52° I 1 I I II, I Finger = 7 Penetration = 0.054 ins Line of Pits 0.05 ins = 21% Wall Penetration HIGH SIDE = UP ' I I I 1 I 1 • • I PDS Report Overview 11 . Body Region Analysis I Well: 2K -19 Survey Date: March 15, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 7 ins 26 ppf J -55 Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. III 7 ins 26 ppf J -55 6.276 ins 7 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) 10 Now Penetration body w Metal loss body 1 0 50 100 1 1 IIII 5 1 0 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 4) 1 0 4 0 0 II Damage Configuration ( body ) 10 5 1 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 4) 1 0 3 0 0 Bottom of Survey = 7 I I I I I 0 • I c 1 4 . Minimum Diameter Profile i Well: 2K -19 Survey Date: March 15, 2011 Field: Kuparuk Tool: UW MFC 24 No. 212330 I Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country USA Tubing I.D.: 6.276 inches 111 Minimum Measured Diameters (In.) 1.69 2.19 2.69 3.19 3.69 4.19 4.69 5.19 5.69 6.19 1 I I 2 I 1 3 L E = Z 4 II 0 c I I 5 I '. 6 1 1111 1 7 1 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26 ppf J -55 Well: 2K -19 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in USA Survey Date: March 15, 2011 I Joint it. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 Ii 10084 0.00 0.09 23 10 6.28 Line Corrosion / App. Erosion. 2 10099 0.06 0.07 20 7 6.26 Shallow Line Corrosion / Shallow App. Erosion. 3 10118 0.06 0.09 24 0 6.24 Line Corrosion / App. Erosion. 4 10138 0.05 0.08 21 8 6.25 Line of Pits / App. Erosion. 5 10177 0 0 0 0 6.20 Perforations. Lt. Deposits. I 6 10215 0 0 0 0 5.02 Perforations. Heavy Deposits. 7 10253 0 0 0 0 5.91 Perforations. Lt. Deposits. rt I Penetration BoBody dy I I I I I I I I I I Page I I I • • I PDS Report Cross Sections I Well: 2K -19 Kuparuk Survey Date: March 15, 2011 Field: Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 7 ins 26 ppf J -55 Analyst: HY. Yang I I Cross Section for Joint 3 at depth 10129.900 ft Tool speed = 51 ii ,,, Nominal ID = 6.276 I Nominal OD = 7 "—s Remaining wall area = 93% Tool deviation = 50° I I I I 1 I Finger = 4 Penetration = 0.087 ins Line Corrosion /Erosion 0.09 ins = 24% Wall Penetration HIGH SIDE = U' I I I I I I • • I PDS Report Cross Sections Well: 2K -19 Survey Date: March 15, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 7 ins 26 ppf J -55 Analyst: HY. Yang I I Cross Section for Joint 1 at depth 10097.200 ft Tool speed = 55 Nominal ID = 6.276 I Nominal OD = 7 , Remaining wall area = 92% Tool deviation = 51° I 1 I / / 1 1 I Finger = 1 Penetration = 0.085 ins Line Corrosion /Erosion 0.09 ins = 2% Wall Penetration HIGH SIDE = OF I I I I I • • ■ PDS Report Cross Sections I Well: 2K -19 Kuparuk Survey Date: March 15, 2011 Field: Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 7 ins 26 ppf J -55 Analyst: HY. Yang I I Cross Section for Joint 6 at depth 10240.380 ft Tool speed = 50 Nominal ID = 6.276 I Nominal OD = 7 Remaining wall area = 100% Tool deviation = 54° I • I 1 I Minimum I.D. = 5.018 ins Heavy Deposits Minimum I.D. = 5.02 ins HIGH SIDE = UP I I I I �, KUP I COflOCOPhilli a ps !Attributes An , le & is TD #i Welihore APlIUW1 Field Name Well Status Ind 11 - 2K -19 Act Sim (MB) Alaska, Inc. 501032011800 KUPARUK RIVER UNIT PROD 60.35 3,700.00 10,659.0 lonomRdLp, Comment H2S (ppm) Date Annotation End Date KB-t1d pt) . , ....- - .. - -. SSSV: TROP 200 1/13/2009 Last WO: 39.99 ' I . .. Well Confiq: - 2K -19 32/2010 10:3330 AM - schematic - Actual Annotation Depth SUB) Bb Date Annotation Last Mod By Ent' Date Last Tag: SLM 10,346.0 2114/2010 Rev Reason: PERFORATIONS Imosbor 3/2/2010 Casing Strings I Std OD String ID Set h (1ki Sing Casing Description (In ) (In) Top Depth (IKE) (1KB Set Dept ( ) YD) S p bsllry ing Wt String Grade suing Top Tlaa I CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-40 _ CONDUCTOR, SURFACE 9518 8.765 0.0 3,789.0 2,897.5 36.00 J -55 115 PRODUCTION 7 6.151 0.0 10,557.0 6,!i08.0 26.00 J-55 Tubing Strings Safety Valve. i OD smog ID set Depth Set Deem (TYD) String Wt String 1/98 1 Tubing Description (In) pn) T op (IKB) p1KB) piKB) pbsnq Grade smog Top ThN TUBING 3 i/2 2.992 0.0 10,084.0 6,209.0 9.30 J -55 EUEBndABMOD Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth (TVD) Top Ind GAS LIFT Top (1KB) (a) P) Desnelpilon Comment Run Date ID (In) I 2,675 1,798 1,721.8 33.62 Safety Valve Cameo TROP- IA-SSA 5/3/1990 2.812 2,675 2,317.5 56.05 GAS LIFT MERLPITMPD /1/GLV/BK/.1 2 511 3 5 0/ Comment: STA 1 9/21/2003 2.875 5,530 3,784.8 58.98 GAS LIFT MERLA/TMPD /1 /GLV /BK/.156/1363/ Comment: STA 2 9/21/2003 2.875 SURFACE, 3,789 7,062 4,598.8 57.84 GAS LIFT MERLAfTMPD /1/ GLV /BK/.156/1341/ Comment: STA3 9/21/2003 2.875 I 7,833 5,007.4 57.73 GAS LIFT MERLAITMPD/1 /DMY /BK/ // Comment: STA4 5/3/1990 2.875 L,_,,s,? 8,577 5,397.1 58.70 GAS FT MERLA/TMPD /1 /GLV /BK/.188/1355/ Comment: STA5 9/21/2003 2.875 GAS LIFT, C 9,298 5,773.2 57.98 GAS UFT CAMCO /MMG- 2/1 .5 /DMY /RK// /Comment: STA6 9/24/2003 2.921 5,530 U 9,959 6,136.9 55.24 GAS LIFT CAMCO /MMG- 2/1.5/OV /RK/.25// Comment: STA 7 5/14/2009 2.921 10,003 6,163.4 55.48 PBR Baker '80-40' w/ 10' Stroke PBR 5/3/1990 3.000 I 10.016 6,170.5 55.28 PACKER Baker'HB' RETRIEVABLE PACKER 53/1990 2.890 10,052 6,190.6 54.76 NIPPLE Oils'XN'Nipple NO GO w2.81 "POLISHED BORE 5/3/1990 2.750 10,083 6,208.4 54.30 SOS Baker 5/3/1990 2.992 10,084 6.209.0 54.29 TTL 5/3/1990 2.992 I GAS 3FT- Perforations & Slots _ / a3d Top (TVO) Mtn flVD) Dens Top (6KB) 010 MKS) (�) ( K Shot B) Zone (ski... Type Comment 10,169 10,189 6,259.4 6,271.4 A-4, 2K -19 3/1/2010 6.0 APERF 2.5" Millenium HMX charges, 60 degree phase ' ens `' - 10,210 10,250 6,285.3 6,309.1 A-5, 2K -19 5/1/1990 4.0 IPERF 180 deg. Phasing; 4.5" HLS Casing ,L1 , Guns 5 8 - 7 Notes: General & Safety End Date Annotation 10/24/2004 NOTE: WAIVERED WELL IA x OA COMMUNICATION I 9/24/2009 NOTE: Repair SURF CSG of 9 5/8" hanger; weld 38" sleeve W /10" .500 wall API SL -X65 pipe GAS LIFT, I GAS LIFT 9,959 I PBR, 10,003 I PACKER, j 10,016 ,.&';',::,:, 1,,,id4 • I NIPPLE, 10.052 I SOS. 10,083 l J Di, 10.084 I APERF. 111 II 10,189- 10,189 I IPERF 10,210 - 10,250 . I I PRODUCTION. 10,557 TO, 10 659 • • SU-0'E 0[F AELASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Gary Eller Wells Engineer ConocoPhillips Alaska, Inc. r 1061 P.O. Box 100360 a Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -19 Sundry Number: 311 -058 Dear Mr. Eller: mARu ZipGi Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. S'ncerely, Daniel T. Seamount, Jr. r"- Chair DATED this? day of March, 2011. Encl. Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art V or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: / /F: \Daily_Document_Record \Procedures Instructions \FW INTENT PLUG for RE- DRI... 3/3/2011 ' , STATE OF ALASKA r r ALASKIIOIL AND GAS CONSERVATION COMMISSS APPLICATION FOR SUNDRY APPROVALS 20 /NAG 25.280 1. Type of Request Abandon r Rug for Redrill 17 / y_ Perforate New Pool l Repair well Change Approved Program r Suspend r Rug Perforations F! • Perforate r' Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 . Exploratory r 189 -109 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20118 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No '.,. 2K -19 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25589 ` Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10659 - 6576 10500' 6474' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 3754 9.625" 3789' 2898' PRODUCTION 10524 7 10557' 6508' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10169'- 10189', 10210'- 10250' 6259'- 6271', 6285 3.5 J - 10084 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'HB' RETRIEVABLE PACKER MD= 10016 TVD= 6185 TRDP - CAMCO TRDP -1A -SSA MD= 1798 TVD= 1726 12. Attachments: Description Summary of Proposal F/ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory ]W Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/15/2011 Oil %Sa� y /,, t Gas WDSPL Suspended ^ 5 1( " . �' 16. Verbal Approval: Date: WIND r = GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certi that the foregoing i true and correct to the best of my knowledge. Contact: Gary Eller @ 263 -4172 Printed Name Gary Eller Title: Wells Engineer Signature Cl Phone: 263 -4172 Date 7 \\ Commission Use Only 1 Sundry Number:3 i 1 ../063 Conditions of approval: Notify Commission so that a representative may witness w Plug Integrity r BOP Test IX Mechanical Integrity Test r Location Clearance r RECEIVED * 3sop P s- 6d P e s1 — 1 MAR 0 2 2011 Other: e n / ,'If Z cob psi. A n t�c, -4. �- J ` 0 1, ""•- / Alaska Gil & Gas Cons, Commission Subsequent Form Required: / — 7 b 7 Anchorage / 7 APPROVED BY � �� Approved by: I 7 COMMISSIONER THE COMMISSION Date3 Form 10 -403 Revised /ZOM MAR 0 7 2011 . s. 3. q Submit fn Duplicate ORI r ,. . . �,. ,, • KUP • 2K -19 ConocoPhIUips a , ' Well Attributes Max Angle & MD TD Wellbore APUUWI Field Name Well Status Ind ( °) MD (ftKB) Act Bbn (ftKB) A.a ,lnc. 501032011800 KUPARUK RIVER UNIT PROD 60.35 3,700 00 10,659.0 • LOnneollIdele -- C p nt H25 (ppm) Date An f t on End Date KB -Grd (fh Rig Release Date - -' 200 U 132009 Last WO Welk ig emaiic Actual ti Y 34 AM _ SSSV 1 0 A no08 non: PERFORATIONS 39.99 1 Schematic Actual Annotation Depth ( ftKB ) End nd Date t e Annotation Last "rod d By By Entl Date to Last Tag: SLM 10.346 0 ' L ONS Imosbor t- 3/2/2010 Casing Strings ' C Description I String OD String ID Set Depth Set Depth (TVD) String Wt String s Casing De P n (in( ) (in) Top(ftKB) (ftKB) �._.,. (HK8) (Ibs/ft) Grade String Top Thed D .CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-40 C0NDUC7oR.__- SURFACE 95/8 8.765 0.0 3,789.0 2,897.5 36.00 J -55 15 PRODUC ION 7 6.151 0.0 10,557.0 6,508.0 26.00 J -55 , Tubing Strings Satisfy Verve, ' String OD ' String ID Set Depth Set Depth (TVD) String Wt String H 1798 ' Cy Tubing Description On) (in) Top(ftKB) (ftKB) (ftKB) (Ibs /ft) Grade String Top Thrd TUBING 31/2 2.992 00 10.084.0 6,2090 9.30 J -55 EUE8rdABMOD Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth (f VD) Top Inc) GAS LIFT, Top ' B) (ftKB) (7 Desc ription Comment Run Date ID (in) 2,670 1,798 1,721.8 33.62 Safely Valve Camco TRDP -1ASSA 5/3 /1990 2.812 2,675 2,317.5 56.05 GAS LIFT MERLA/TMPD /1 /GLV /BK/.125 /1350 / Comment STA 1 9/21/2003 2.875 5,530 3,784.8 58.98 GAS LIFT MERLAJTMPD /1 /GLV /BK/.156 /1363 /Comment STA2 9/21/2003 2.875 SURFACE, - -- 3,789 7,062 4,598.8 57.84 GAS LIFT MERLA/TMPD /1 /GLV /BK/- 156 /1341 /Comment STA3 9/21/2003 2.875 7,833 5,007.4 57.73 GAS LIFT MERLA/TMPD /1 /DMY /BK/ // Comment: STA 4 5/3/1990 2.875 8,577 5,397.1 58.70 GAS LIFT MERLA/ TMPD/ 1/ GLV /BK /.188/1355 /Comment STA5 9/21/2003 2.875 9,298 5,773.2 57.98 GAS UFT CAMCO /MMG- 2 /1.5 /DMY/RK// /Comment: STA 6 9/24/2003 2.921 9,959 6,136.9 55.24 GAS UFT ° CAMCO /MMG- 2 /15 /OV /RK/.25/ /Comment STA7 5/14/2009 2.921 10,003 6,163.4 55.48 PBR Baker '80 -40' w/ 10' Stroke PBR _ 5/3/1990 3.000 ' 10,016 6,170.5 55.28 PACKER Baker 'NB' RETRIEVABLE PACKER 5/3/1990 2.890 GAS LIFT, -. �- 10,052 6,190.6 54.76 NIPPLE Otis 'XN' Nipple NO GO w/2.81" POLISHED BORE 5/3 /1990 2.750 7,062 10,083 6,2084 54.30 SOS Baker 5/3/1990 2.992 10.084 6,209.0 54 i 1 L 5/3/1990 2.992 Perforations & Slots _ Shot GAS 7,6 LIFT, 33 _ Top (TVD) Btm (TVD) Dens Top (ftKB) Btrn (ftKB) (ftKB) (ftKB) Zone Data (FR... Type Comment 10,169 10,189 6,259.4 6,271.4 AA, 2K -19 3/1/2010 6.0 APERF 2.5" Millenium HMX charges, 60 degree phase 10,210 10,250 6,285.3 6,309.1 A -5, 2K -19 5/1/1990 4.0 IPERF 180 deg. Phasing; 4.5" HLS Casing , GAS LIFT.. _ ¢ Guns ,,,2, Notes: General & Safety ,. End Date Annotation 10/24/2004 NOTE: WAIVERED WELL IA lt OA COMMUNICATION 9/24/2009 NOTE: Repair SURF CSG of 9 5/8" hanger; weld 38" sleeve W /10" .500 wall API SL -X65 pipe GAS LIFT, _ ___ -- 9.299 , 5- l GAS LIFT, f ,-„...1)„, 9,959 P8R, 10,003 - - - ' 1 I PACKER, 10,016 ■ NIPPLE, 10,052 -- - - .1 00S, 10,083 -- TfL, 10,086 --'- f APERF,__ 10,169- 10,189 I IPERF, 10310- 10.250 PRODUCTION, 10,557 �_ . l TD, 10,659 • • KRU 2K -19 CTD Summary for Plugging Sundry (10 -403) Summary of Operations: Well 2K -19 is a Kuparuk A -sand production well equipped with 3 tubing and 7" production casing. Three proposed A -sand CTD laterals will increase reservoir exposure and offset the planned 2K -13 CTD injection laterals. Prior to drilling, the existing A -Sand perfs in 2K -19 will be squeezed with cement to provide a means to kick out of the 7" casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 10,220' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2K -19A sidetrack will exit the 7" casing at 10,170' MD and will target the A4 sand west of the existing well with a 3030' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,200' MD with an aluminum billet at . 12,350' MD. The 2K -19AL1 lateral will kick off from the aluminum billet at 12,350' MD and will target the A4 sand west of the existing well with a 750' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,100' MD with an aluminum billet at 11,600' MD. The 2K -19AL2 lateral will kick off from the aluminum billet at 11,600' MD and will target the A4 sand west of the existing well with an 850' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,450' MD with the final liner top located just inside the 3%2" tubing at 10,060' MD. CTD Drill and Complete 2K -19 Laterals: April 2011 Pre -CTD Work 1. Positive pressure and drawdown tests on master valve & swab valve 2. RU slickline. Obtain updated static BHP on A -sand. Dummy off all GLMs. RD slickline. 3. RU e -line. Perf holes in 3 tubing tail at 10,070' MD. RD e -line. 4. RU coil. Mill out XN- nipple in tubing tail to 2.80" ID. Plug the A -sand perfs with cement up to 10,070' MD. RD coil. 5. RU slickline. Tag top of cement. RD slickline. • 6. Prep site for Nabors CDR2 -AC, including setting BPV t Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. �/61 2. 2K -19A Sidetrack (A4 sand, west) a. Drill 2.80" high -side pilot hole through cement to 10,220 MD'. b. Drift pilot hole with whipstock dummy c. Set whipstock at 10,170' MD with high -side orientation. d. Mill 2.80" window with high -side orientation at 10,170' MD. e. Drill 2.70" x 3" bi- center lateral to TD of 13,200' MD f. Run 2%" slotted liner with an aluminum billet from TD up to 12,350' • 3. 2K -19AL1 Lateral (A4 sand, west) rrj7 a. Kick off of the aluminum billet at 12,350' MD b. Drill 2.70" x 3" bi- center lateral to TD of 13,100' MD c. Run 2 slotted liner with an aluminum billet from TD up to 11,600' Page 1 of 2 February 28, 2011, FINAL • • 1 4. 2K -19AL2 Lateral (A4 sand, west) a. Kick off of the aluminum billet at 11,600' MD b. Drill 2.70" x 3" bi- center lateral to TD of 12,450' MD c. Run 2 slotted liner from TD up to 10,060' MD, up inside the 3'/2" tubing tail 5. Freeze protect. Set BPV, ND BOPS. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production CA/41 le ® _ l 4ter 1 1�d trP� l; "ref ha ck /14 IV eX.sn Hf eo/ef l 4Pref0 fir fcrGt 715 � eU- tn,Q(��ol e Co and Te� tt,'.z � ` ny `e$ er G t The Cvwr f tocQt-r`av? 5''000 he Cfrt/ re c 1 the_ y ew vt,e /l 6otof '04 Page 2 of 2 February 28, 2011, FINAL t , 2K -19 Proposed CTD Sidetrack Updated: 28 Feb - 11 , �r 3-1/2" Camco TRDP -1A SSSV @ 1721' RKB 16" 62# H -40 � 3-1/2" 9.3# L -80 EUE 8rd Tubing to surface shoe @ 115' MD 3-1/2" Camco MMG gas lift mandrels @ 2675' 5530', 7062', 7833, 8577', - 9-5/8" 36# J -55 shoe 9298', 9959' RKB @ 3789' MD . W • Baker 3-1/2" 80/40 PBR @ 10,003' RKB ii i Baker 3-1/2" x 7" HB retrievable packer @ 10,016' RKB ■ ° 2 -3/8" liner top 10,060' MD Perfs in 3-1/2" tailpipe at • n (Note: Will be milled out to 2.80" for CTD) "- 3-1 /2" Otis'XN' nipple @ 10,052' RKB (2.75" min ID) 10,070' MD Planned top of cement at - = 3-1/2" tubing tail @ 10,084' RKB 10,070' MD A5 -sand perfs 10,169' KOP @ 10170' MD A ,. 10,189' MD • A4 -sand perfs Anchor- billet TD @ 12,450' MD 10,210' - 10,250' MD % @ 11,600' MD , 2K -19A - - - I TD @ 13,200' MD 2K -19AL1 - - TD @ 13,100' MD 2.80" cement pilot Anchor - billet @ hole to 10,220' 12,350 MD 7" 26# J -55 shoe (d) 10557' Mn - • C€rcoPhillips P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 Apri117, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 '~ ~~~i'" '*._ ~; ice. ~"~~ APR 2 ~ 2010 ,i'asYc~ iii #~ has Cons. C,ommissiar, ~nct,ar~a~ ,~~, X09 a-~~ Dear Mr. Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped April 15, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 26.2E. 2G. 2H. 2K. 2M. 2V. 2W. 2X. 2Z ~ 3S PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-05 50029210670000 1840040 24" n/a 24" n/a 4.2 4/16/2010 2B-08 50029210790000. 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 2B-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF n/a n/a n/a 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF n/a 22" Na 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" n/a 2.1 4/15/2010 2H-09 50103200500000 1852590 SF n/a 17" n/a 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" Na 2.5 4/15/2010 2K 19 50103201180000 1891090 53" 0.50 9" 1/162010 2.1 4/15/2010 2M-07 50103201780000 1920800 SF n/a 17" n/a 3.4 4/15/2010 2M-08 50103201840000 1921010 SF Na 17" n/a 2.1 4/15/2010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/15/2010 2M-22 50103201700000 1920490 SF n/a 17" Na 2.5 4/15/2010 2M-28 50103201740000 1920700 SF Na 18" Na 2.1 4/15/2010 2V-06 50029210540000 1831790 SF n/a 19" Na 7.6 4/16/2010 2V 10 50029213100000 1850480 SF Na 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" n/a 5.1 4/16/2010 2W-03 50029212740000 1850110 SF n/a 3T' Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF Na 17" n/a 6 4/17/2010 2Z-11 50029213790000 1851380 SF n/a 19" Na 2.5 4/15/2010 2Z-12A 50029213800100 1951480 SF Na 19" n/a 2.5 4/15/2010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881.300 SF n/a 16" n/a 2.1 4/15/2010 3S-09 50103204320000 2022050 SF n/a 45" Na 23 4/17/2010 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS~J REPORT OF SUNDRY WELL OPERATIONS MAR 1 6 2010 ~. operations Performed: Abandon ~° Repair w ell ~ Plug Ft?rforations ~"` Stimulate ~` ~I~Ica A~'~Cons. Commission Alter Casing Pull Tubing `"' Ft'rforate New Fbol ~ Waiver r Time Extensior~,1l~jg Change Approved Program Operat. Shutdown ~""' Perforate Re-enter Suspended Well ~` 2. Operator Name: 4. Current Well Status: .Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ~ Exploratory ~"" 189-109 3. Address: Stratigraphic j"" Service 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-103-20118-00 7. Property Designation: 8. Well Name and Nu,~nber. ADL 25589 2K-19 9. Field/Pool(s). Kuparuk River Field /'Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured ~ 10659 feet Plugs (measured) None true vertical ~ 6576 feet Junk {measured) None Effective Depth measured 10500 feet Packer (measured) 10016 true vertical 6474 feet (true verucal) 6169 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115 115' SURFACE 3789 9.625 3789 2898 PRODUCTION 10557 7 10557 6508"""' " Perforation depth: Measured depth: 10169'-10189', 10210'-10250' _- ~ ~o~ ' ~~~~''" ~A~ k ' ' ' True Vertical Depth: 6259 -6271 , 6285 -6309 Tubing (size, grade, MD, and TVD) 3.5, J-55, 10084 MD, 6209 TVD Packers 8~ SSSV (type, MD, and TVD) PACKER -BAKER 'HB' RETRIEVABLE PACKER 10016 and 6169 TVD TRDP - CAMCO TRDP-IA-SSA @ 1798 MD and 1722 TVD 11. Stimulation or cement squeeae 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 weft operation 161 768 111 -- 203 Subsequent to operation 295 748 362 -- 197 43. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory ]'`` Development ~` Service . Well Status after work: Oil ""/ Gas WDSPL Daily Report of Well Operations XXX GSTOR r WAG "` GASINJ WINJ ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none Contact John Peirce tp7. 265-6471 Printed Name John Peirce Title Wells Engineer / Phone: 265-6471 Date Signature ~/~~ ~~ ~ r !~N RBDMS MAR 17 2010 ~i ~'1 Form 10-404 Revised 7/2009 Submit Original Only 2K-19 Well Events Summary SATE ~ SUMMARY 2/14!10 RAN 2.5"x.10' DUMMY GUN, TAG~10,346' SLM. READY FOR E-LINE. 2/26/10 PERFORM CORRELATION PASS WITH GAMMA RAY /CCL PERFORATOR FROM TD TO GLM @ 9959' AND PRESENT JEWELRY LOG. P,F.~ZFORATE THE A-5 SAND FROM 10179-10189'. PREPARE FOR THE NEXT SET OF PERFORATIONS ON THE FOLLOWfNG DAY. 3/1/10 PERFORM CORRELATION PASS WITH GAMMA RAY /CCL PERFORATOR FROM TD TO GLM @ 9959'. PERFORATE THE A-5 SAND FROM 10169-10179'. AFTER PERFORATING RIH WITH THE PRESSURE TOOL AND MONITOR PRES URE FOR 30 MINUTES AT 10179' (2933-PSF, 1$7- DEG F) AND 10008' (2889-PSI, 163-DEG F) . i ~earr~ctiF'hillips Aia•Sit;;l. fna. _ _ WeA Ca __ nflg 2K-19, 312Y101 Schematic-ACli Nrtwr&nin CONDUCTOR, „': 115 Safety Valve. 1,798 GAS LIEF, 2.675 SURFACE. 3.789 GAS LIfT, 5.530 GAS LIFT. 7 062 GAS LIFT. E33 GAS LIFT, ,. GAS LIFT. _ ___ - 9,298 GAS LIFT. 9,959 PBR. 10,003 PACKER, C 10,016 NIPPLE, 10,052- -- - SOS. 10.063- --- - - TTL, 10.08a-- APERF,_ '10,189-10.189 IPE RF. 10,210-10.250 PRODUCTION. 10,557 TD, 10,659 i KUP 'Well Attribut ~6~ WeIIM>re APIIU WI es _ Field Name 5(1111"x2011800 ~KUPARUK F+:I/FR UNIT C ent H25 (ppinl Date J SSSV:IRDP UJG I U I A Cation Depth (ftKB) 'End Date Anm Last Tao: SLM l 10,346.0 2ll h~2i: 10 Rev fi.151 1 2 70,210 1 ~I Notes: Ger End Date 10/2412004 912412009 Top Inc! (°) Description 33-62 Safet;~ L'alve 56.05 GAS LIFT 58.98~~GAS LIFT 57.84 GAS UF~I 57.73 GAS LIF I 58.70 GAS LIFT 57.98 GAS LIFT 55.24 GAS LIF I 55.48 PBR ~r'80-00' w/ 1 ~r'HB' RETRI 'XN' Nipple t\ 2 K-19 Max Angle 8 MD I TD . Inc1 (") MD (fiKB) '.~ACt Bim (fiK8) G6 "SS ~ 3,700.00 ~ 10,fi5J 0 t KB-Grd (k) i Rig Release Date 39.99 11/14/1989 last Mod By End Date ~ Imosbor , 322010 6,508-0' Depth (ND) 51 omment Run Data ID (in) 5/317990 2.812 125/1350/ Comment: STA 1 9/212003 2.875 156/1363/ Comment STA 2 9121/2003 2.875 156/1341! Comment STA3 9/21/2003 2.875 '/Comment: STA4 513/1990 2.875 1 8 811 3 55/Comment: STAS 9/21/2003 2-875 RK///Comment STA6 9/24/2003 2.921 K/.25//Comment STA7 5/14/2009 2.921 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record /Shut-in Bottom Hole Pressure: 2K-19 Run Date: 3/1/2010 March 15, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K 19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20118-00 ~~~~W 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 rafael.barretoa~i~allburkon,com Date: _. _ /~~-~~ ~ ~ ~C~S~' Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jewelry Log: 2K-19 Run Date: 2/26/2010 March 12, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20118-00 ~~ PLEASE ACKNOWLEDGE RECEIl'T 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 rafael.barretoia lalliburtc~n.corn t ~ L`S 9 Date: `" Signed: • ~ • • ConocoPh ~ I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 11, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Alas~Ca Qii & Gas Cons. Commis~ion Anchora~e Enclosed please find the10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. we112K-19 PTD 189-109 sundry 309-169 surface casing repair. Please call Perry Klein or MJ Loveland at 659-7043 if you have any questions. Sincerely, ~, ~ ~ ~ ~~ ~~ ~ ~ ' T~~~ ~ ~ ~-- Perr~n ConocoPhillips ,~,~, . ' • ~ECE~ V ~Q OCT 1 3 Z~lpg Well Integrity Projects Supervisor ~~~C~~~~ ~ U ~ OCT 1 ~ 200~ STATE OF ALASKA p~~~~a pil & Gas Cnns. Comrnis~ion ALASKA OIL AND GAS CONSERVATION COMMISSION pnchoraqe REPORT OF SUNDRY WELL OPERATIONS _ 1. Operations Performed: Abandon ^ Repalf Well ^~ Plug PerForations ~ Stimulate ~ Othef ~ SC Repair Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status S. Permit to Drill Number. ConocoPhillips Alaska, Inc. ^~ ~aele~opme:~,~ Exploratory ^ ~ 189-109 3. Addfess: Stratigraphic ^ Service ^ 6. API Numbe~: P. O. Box 100360, Anchorage, Alaska 99510 ~ 50-103-20118-00 7. KB Elevation (ft): 9. Well Name and Number: KB 154' ~ 2K-19 8. Property Designation: ~ 10. Field/Pool(s): ~` ~ ADL 0025589 ALK 2675 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: ~ Total Depth measured 10659' feet ~ true vertical 6576' feet Plugs (measured) Effective Depth measured 10438 feet Junk (measured) true vertical 6429 feet Casing Length Size MD ND Burst Collapse Structural CoNDUCTOR 115' 16" 115' 115' SURFACE 3635' 9-5/8" 3789' 2898' PRODUCTION 10403' 7" 10557' 65~8' SC Sleeve 38" 10" 38" 38" Perforation depth: Measured depth: 10210-1 Q250` true vertical depth: 6285-83~9' Tubing (size, grade, and measured depth) 3-~/~" ,,~-~~, ~p{}$4' ~jp, Packers & SSSV (type & measured depth) pkr= BAKER '1-18' R ETR. pkr= 1 Q~16' SSSV= Camco 1"RDP 1A 5~A SSSV= 1798' 12. Stimulation or cement squeeze summary : Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbi Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Weli Operations X 16. Well Status after proposed work: _ ~ Ga~ WAG~ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or N/A if C.O. Exempt: 309-169 contact erry Klei MJ and Printed N e._. Perry Kle' ~ Title WI Project Supervisor -_, Signature Phone 659-7043 Date 10i11 /2009 ° ~- ~ D~~S f ~~ ~~~ ~~ e; Form 10-404 Revised 04/2004 ~U'~y'~I Submit Original Only • • 2K-19 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/11/09 Cut and removed 53" of conductor and landing ring. Dri{led and tapped one 1/2" hole where leak is. Cleaned surface casing with wire wheel and marked "A" and "B" bands. Need vac truck for any cellar work. Ready for inspection. Final T/I/O = 0/0/0. 09/16/09 Notified state man Jeff Jones opportunity to witness demage to SC - he wavied. 09/22/09 09/23/09 Pre heated starter head using cooper heat. Welded a 38" sleeve made from 10" .500 wall API 5L-X65 pipe. QC performed visual inspection of welds. Wrapped upper weld with insulation to assist cool down of weld. MT/UT to take place in AM. Photos taken for records. Verified conductor length @ 53". T/I/O = SI/0/0. Surface casing MT/UT inspection by Kakivik. MIT-OA (passed)- Initial T/I/O = SI/0/0. Pressured up OA to 1800 psi with 1.0 bbl of diesel. Start T/I/O = SI/0/1800, 15 min T/I/O = SI/0/1740, 30 min T/I/O = SI/0/1730. Bled OA to 0 psi. Final T/I/O = SI/0/0. Wrapped surtace casing with denso wrap, photos taken for records. Ready to install 53" conductor. 09I24/09 Welded 53" X 16" .375 wall pipe for conductor annulus. T/I/O = SI/0/0. :~<~ :;r ~~. ,;;,. ~ Ili~i~l ~~ ~ ~ ~: ~~~,~ ~ ..,. ~ _ . F~~' ~ ~ ~~., ~ ~ . ~. ; ~.-.5 ~~ .~`° : :~~ k, ~• ~ ~. S` .. ~ . , ~:. ~. .. ..k,. ' _ ~ ~:.. ~ . ~ ., ~~ ~ ~ , ~ { ~ ~~ i' . ~.- ~ ~ ~'~4 . ~ ~ - i~~~ ~•&.~. rr n 4 -I~ ~~_ .~~, r , ' ~ " ` z ~i~ ~~ ~ ~, .! L* b i ~ I~.,. ~: ~~. *R ~: ~~ a~„ .r. K ry~. r t .~X ~ . ~ ~ rtis ~ . t~~ . . f~ ~~7~q4,~U,M ~ ,- . ~~:,~ ~, "t ~ . ~..~'s',y Y ',~:K I~.':~~' 1 °x ,. s ..Y.t~ '^1 '.-'~, ~~~~~' ~ ; ~ ~~;w ~~.`~:*~~~. k. s~~` • i . , -.°j~` . +... ~ : . ~. ~'~ ~, f ,:.. , ~" ' i ~" ~, ~',~ . . . . ~ - ~ t~..': ~ , wt„ ~~ , ` ~~ ~~ » ~ ~ .' ~a-s~~ ~k~...~. ~ ._ ~: ,:.~..~ ti_ S'' ~~: , ~ I A r . .. . _ f.. . ~~ _ 1 sxt-, ~6~yy ` i~-.. ;~. ` f ' "E ~~~ t1.~~ ' _ , P• `w ~ ~ ` ~ ~::. ~,~ i~ ~ ~ ~ ~ ~ ~+:'„-,~' ,~ d. . - . 4 ~+ } i~~,~^~ ~` ' R i ~ a .'y: ~6i ~', ~,j~3t~~^:Y~ .. .. t ~ R~ ~ ~ ~ t . i . ~'°. ` ~ ~ ~ X~S ' i }' 4~' o.'' ~ ~ - ~' ~ : ~ ~ ~„~ C~ i i ~ ~ : . ~a „ '~ ~ ~' ;~ ,.~. I •i ~I ~I t °. .~~. ' i ! ~'~ %` i" ~,x :; ~ f. ~~~ ~ ~ ~ ~ ~~~~..~ w Yv ~ ~ ~ k ~,~~~~~~ . . ~~ - ;~ ~~ _ ~ . • • ~+ SARAH PALIN, GOVERNOR ALASSA OIL A1~TD „_ , ~~ , 333 W. 7th AVENUE, SUITE 100 } '; CO1~T5ERQATIO~T COMDII551O1~T ~, ANCHORAGE, ALASKA 99501-3539 , PHONE (907) 279-1433 M.J. Loveland FAx (907) 276-7542 Well Integrity Projects Supervisor ConocaPhillips Alaska, Inc. P.O. Box 100360 ~,~ >~~~ j ~T~,` ~ ~ro ~~rSE r, 3 ~ ~, Anchorage, Alaska 99510 _ ~ ~~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 2K-19 Well Sundry Number: 309-169 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced. well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster Commissioner DATED this ~~ S day of May, 2009 Encl. • r ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 9, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~ ~Aat ~ z ~~o ~~~~ska ~lil & Gas Oars. Onmmiss~~; Ancharage Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we112K-19 (189-109) surface casing excavation and repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ~~~ 9 M Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures `;. • STATE OF ALASKA • ~~ ry~ I~ ALASKA OIL AND GAS CONSERVATION COMMISSION "~IaS~a ~l~ ~aS ~a~s. ~Off'tr-ilSS10l~ ~~ APPLICATION FOR SUNDRY APPROVAL Anchorage ~V~,a~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^~ Plug Pertorations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ SC patch Re-enter Suspended Welf ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development^ . Exploratory ^ 189-109 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20118-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q 2K-19 , 9. Property Designation: • 10. KB Elevation (ft): 11. Field/Pool(s): ADL 0025589 ALK 2675 RKB 154' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10659' 6576' 10438' 6429' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 3635' 9-5/8" 3789' 2898' PRODUCTION 10403' 7" 10557' 6508' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10210-10250' 6285-6309' 3-1 /2" J-55 10084' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'HB' RETR. pkr= 10016' SSSV= Camco TRDP 1A SSA SSSV= 1798' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 1, 2009 Oil^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of,my knowledge. Contact: Perry Klein / MJ Loveland Printed Name MJ Lovela d ~ ,.~-~ ' Title: Well Integrity Projects Supervisor ~ Signature a .n ,.r -~ ` ~ Phone 659-7043 Date ~- ~, ~ ~; <- Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness - Plug Integrity ^ BOP Test [] Mechanical Integrity Test ^ Location Clearance ^ \' Other. ~ ^`~V~ rK. p ~U~~ C`~v MkY\~~~`~ © ~~G. ` ~ ~ ~~ ~~ T ~h5 ~~ N~~,~ ~ cis P~,G~V~ =~~~ ~ I~~~ ~ t~ ~~o Subsequent Form Required: ~~~ . Approved by: C M ISSI E APPROVED BY THE COMMISSION Date: ~' Z~ Form 10-403 Revis~d 06/2006. q ~ I ~ ~~, ~ ~ ~-•~ ((~ I ~\ ~ ~ Submit in D~ te~i ~ / t \ tJ Y ~ A``~ I~'1 U ConocoPhillips Alaska, Inc. Kuparuk Well 2K-19 (PTD 189-109) SUNDRY NOTICE 10-403 APPROVAL REQUEST OS-09-09 This application for Sundry approval for Kuparuk we112K-19 is for the repair of a surface casing leak. The well is a producer and was drilled in 1989 and completed in 1990. On 09/29/07 a surface casing leak was confirmed and reported to the AOGCC. Diagnostics confirmed a leak in the surface casing approximately 2 feet below the starting head., With approval, repair of the surface casing will require the following general steps: 1. Shut-in and secure well. Set positive pressure plug and fluid pack the IA as needed to remove all gas. Freeze protect the T and IA as needed. PT plug to verify barrier. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. 2K-19 (PTD 1891090) suspect surface casing leak • Maunder, Thomas E (DOA) Page 1 of ~l' • ~ From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Tuesday, October 30, 2007 4:19 PM To: Maunder, Thomas E (DOA) Subject: RE. ~ ~ ~ ~^, `~ Q~ Tom, y With our conductor sealantlcorrosion inhibitor campaign we have found pin holes fiairly common in the conductors either from corrosion or more often from sloppy welders cutting off the circulation nipples or the standing boards so that floor kits can be installed. But I believe this is the first one that has caused aspill -normally the diesel would have come out ofi the top of the conductor (which was still buried in gravel so the result may have been the same). FYI we have made it an SOP to dig down at least 3 feet below the conductor top to inspect the conductor before we add sealant - so we don't create a spill by trying to mitigate one... Have a great week! From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 30, 2007 4:02 PM To: NSK Well Integrity Proj Subject: RE: - ~ ` MJ, You are correct about those of us who know that there are multiple pipe sizes employed in a well. Jim and I were just talking, is this the first situation where there has been a leak in both the surface casing and conductor? 'I can't remember a conductor problem before. (guess it makes sense that the interior of the conductor would like experience the same problem as the surface casing. Tom From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, October 30, 2007 3:55 PM To: Maunder, Thomas E (DOA) Subject: - Tom, l find it some what entertaining that DEC (who may have been miss guided by our environmental folks) thought the belzona on the conductor repaired the leak. l guess it technioally did stop the leak to the gravel..., Wish all our leaks were fixed that easy :-) But getting passed the humor of it, we will do a betterjob of communicating with the non well savvy folks to avoid miss communication in the future. MJ °S~ ~~~ ~~ 2/9/2009 ~ ~~ 2K-19 (PTD 1891090) suspect surface casing leak Page 2 of From: NSK Problem Well Supv Sent: Tuesday, October 30, 2007 3:20 PM To: 'Maunder, Thomas E (DOA)'; 'jim_regg@admin.state.ak.us' Cc: NSK Problem Well Supv; NSK Well Integrity Proj; NSK Env Coord Moser&Platt Subject: RE: 2K-19 (PTD 1891090) suspect surface casing leak Tom, I apologize for the miscommunication. The repair was done on the conductor and not the surface casing. We patohed 2 pinholes an the conductor with elzona to have a controlled leak point for our diagnostics. The diagnostics confirmed a surfiaoe casing leak to be approximately 2` down. The spill clean up is still under way and we do not have a final volume that was spilled. There has been no repair attempted on the surface oaring and we will send in a 10-403 Sundry application when we are ready to proceed with a surface casing excavation and repair. I hope this clarifies the miscommunication in what release point was patched. If you have any questians or need any more information, please let me know. Brent Rogers Problem Wefls Supervisor ConoooPhillips Alaska, Ino. Desk Phone {907} 659-7224 Cell Phone {907) 943-'1999 Pager (907) 659-7000 pgr. 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 30, 2007 2:24 PM To: NSK Problem Well Supv; NSK Well Integrity Proj Cc: Regg, James B (DOA) Subject: RE: 2K-19 (PTD 1891090) suspect surface casing leak Brent, et al, We received your notice of the suspected surface casing leak on this well in late September. It was indicated that diagnostics were planned following "cleanup". We have been copied on an email from DEC and DNR representatives indicating that some 50 yards of gravel has been excavated and a patch was installed on the release point. I have checked our 403 fag and do not find that any application has been made to install an external patch on this well nor have any follow-up messages been received by either me or Jim Regg. Please provide ... 1. Reports of what work has been accomplished since the message of September 29. 2. An explanation why no Sundry application was filed to conducted work on this well. We look forward to you early reply, but not later than noon November 2, 2007. Tam Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, September 29, 2007 5:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2K-19 (PTD 1891090) suspect surface casing leak ~~ ~~~ ~ ~ ~~ 2i9i2oo9 2K-19 (PTD 1891090) suspect surface casing leak Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, September 29, 2007 5:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2K-19 (PTD 1$91090) suspect surface casing leak Tom & Jim, ~~ , lal~'u~ ~~ Page 1 of 1 Today, 09/29/07, we reported a spill on 2K-19 (PTD 1891090) in the well cellar. It is suspected to have a surface casing leak with diesel coming out of the gravel in the cellar. We found it during a MITOA for waiver compliance testing. It passed a TIFL immediately following the failed MITOA and it will remain shut in until further diagnostics can be completed. The volume at this time is unknown but is more than 1 gallon. We are correlating clean up measures with ACS and operations and then will proceed with diagnostics to confirm a surface casing leak. Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor 659-7224 ~~~ ~ ~~~~ 10/1/2007 ) ConocóP'hillips ) Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 15, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 FEB 1 6 Z005 Subject: Report of Sundry Well Operations for 2K-19 (APD # 189-109) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 2K-19. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )l[tN[~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad , Ea.."~ 8 r¿o ü~ SCANNEi) F ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 6 2005 REPORT OF SUNDRY WELL OPERA TION~ {F "~ Gæ~~ CG¡':', Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate [2] Aiaskø¡ ðbam~m~h~ra9 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [2] Exploratory 0 189-109 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20118-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 154' 2K-19 1. Operations Performed: ) ) 8. Property Designation: ADL 25589, ALK 2675 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 10659' feet true vertical 6579' feet measured 10438' feet true vertical 6429' feet Length Size MD 115' 16" 115' 3635' 9-5/8" 3789' 10403' 7" 10557' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 2898' 6508' Measured depth: 10210'-10250' true vertical depth: 6284'-6309' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 10084' MD. R8DAfs 8Ft Æ8 I 6 lOllS Packers & SSSV (type & measured depth) pkr= BAKER 'HB' RETR. pkr= 10016' Cameo TRDP-1A-SSA SSSV= 1798' 12. Stimulation or cement squeeze summary: Asphaltene treatment Intervals treated (measured) 10210'-10250' 13. Treatment descriptions including volumes used and final pressure: 114 bbls of Pep 7 treatment Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl 1195 80 917 87 15. Well Class after proposed work: Exploratory 0 Development [2] Service 0 16. Well Status after proposed work: Oil [2] GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Oil-Bbl 181 145 CasinQ Pressure TubinQ Pressure 221 215 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X Contact Printed Name Signature WDSPL D Mike Mooney @ 263-4574 Mike Mooney !1+ #~ Wells Group Team Leader 907 -263-457 4 Date L/I 5/05 Prepared bv Sharon "AllsuP-Drake 263-4612 RBDMS 8Ft FER 1 t17~ \ G ~ ~\j p~ L." Submit Original Only Title Phone Form 1 0-404 Revised 04/2004 ) 2K-19 Well Events Summary ) Date Summary 01/19/05 COMPLETED PEP7 TREATMENT PER PROCEDURE. PUMPED A TOTAL OF 114 BBLS OF CHEMICAL IN 4 STAGES. SAW GOOD DIVERSION WITH 500 PSI INCREASE. LEFT WELLBORE & FLOWLINE FREEZE PROTECTED WI DIESEL. REQUIRES 24 HR SII TIME BEFORE WELL CAN BE RETURNED TO PRODUCTION. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24 2000 P M C:LOREMFILM.DOC E E L E W A T E R IA L U N D ER TH IS M A.R K ER STATE OF ALASKA ALAo,,A OIL AND GAS CONSERVATION o, 1 Status of Well Classification of ~i~W~l OIL J'~ GAS [--J SUSPENDED r--J ABANDONED r'-J SERVICE J-'--J 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-109/9-1095 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 50-103-20118 4 Location of well at surface 9 Unit or Lease Name 219' FNL, 94' EEL, SEC 11, T10N, R8E ua ~~' ?['ii:i ".::;~' i";:i.~'.: i::i'i ~' KUPARUK RIVER At Top Producing Interval ~ ...~~, i ,..~:,_:~:,:.- .....--~ ~ 10 Well Number 1580' FSL, 1264' FEL,SEC 10, T10N, R8E UM i .'-=.~-'- ~-' ~ 2K-19 At Total Depth--z..t.L~,-~ ,~!!'"~t :i ~ii ?'~-i~l 11 Field and Pool 1387' FSL, 1622' FEL, SEC 10, T10N, R8E UM ~ KUPARUK RIVER FIELD · S Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 154'I ADL: 25589 ALK: 2675 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Abend. I 15 Water Depth, if offshore 116 No. of Completions 11/4/89. 11/10/89. 6/18/90.I NA feet M SL]' 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 10659' MD 8, 6579' TVD 10500' MD & 6474' TVD YES ~ NO I--]] 1798' feet MDJ 1400' APPROX 22 Type Electric or Other Logs Run DIL/SFLIGRISP/.FDCICNLICALICBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 170 SX AS II 9 5/8" 36# J-55 SURF 3789' 12-1/4" 1200 SX AS III, 450 SX CLASS G 7" 26# J-55 SURF 10,557' 8-1/2" 450 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and ~25 TUBING RECORD interval, size and number) SIZE DEPTH SET {MD) PACKER SET (MD) 3-1/2" 9.3#, J-55 10083' 10016' 10210'- 10250' W/4-1/2" @ 4 SPF MD 6289'- 6313'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production ]Method of Operation (Flowing, gas lift, etc.) I ,= Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATF ,,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10~407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS , NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARU K C TOP i10128' 6239' NA KUPARUK C BOTTOM 10134' 6243' KUPARUK A TOP 10146' 6250' KUPARUK A BOTTOM 10351' 6376' 31. LIST OF ATTACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowl'edge Signed_...,/~-~--'/~~~-,'~,------./ _ _ Title AREA DRILLING ENGINEER Date '-~/~/~////~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO 011 and Gas Company Well History - Initial Report - Dally Inel~lCflOl~l: Prepare and submit t~l "~1111~11 RIIN~' on the .fir~. Wednesday after a well Is spudded or workover o~iitlons are Iterted. Dally work pl~or to 1131~ll~:~ld; I~ lummenzeo on the form giving Inclusive dates only. ' District -~:.~i:!;: I County. parish or b .... gh ARCO ALASNA INC. I NORTH SLOPE Field ILease or Unit KUPARUK RIVER ~NIT I ADL: 25589 ALK: 2675 Auth. or W.O. no. ITM ,M;4338 I COMPLETIONS IState KRU Well no. K-19 Operator IARCO w.I, ARCO I 55. 8533 Spudded or W.O. begUnSPUD IDate 11/04/89 ]Hour 00: 00lPrlor status ,, a w.o. Date and depth as of 8:00 a.m. 04/28/90 (12) TD:10659 PB:10500 SUPV:DB 04/29/90 (13) TD:10659 PB:10500 SUPV:DB Complete record for each day repoAed NORDIC #1 04/30/90 (14) TD:10659 PB:10500 SUPV:DB 05/01/90 (15) TD:10659 PB:10500 SUPV:DB 05/02/90 (16) TD:10659 PB=10500 SUPV:GB 05/03/90 (17) TD:10659 PB:10500 SUPV:GB DRLG CMT @9810' 7"@10557' MW:10.2 NaCl MOVE RIG FROM 2K-18, ACCEPT RIG AT 14:30 4/27/90, .LEVEL RIG, ND DRYHOLE TREE, NU BOPE AND TEST TO 3000 PSI, MU. AND RIH W/ 6-1/8" BIT AND 4-3/4" DC ON 3-1/2" DP, DRILL CMT F/9630-9810 DAILY:S34,396 CUM:$1,073,009 ETD:S1,073,009 EFC:$1,481,0000 MU BIT AND CSG SCRAPER 7"@10557' MW:10.2 NaC1 CONT. DRLG CMT F/9810 TO FC AT 10479, CIRC, POH, MU BIT AND CSG SCRAPER DAILY:S28,147 CUM:$1,101,156 ETD:S1,101,156 EFC:$1,481,0000 MU GYRO TOOL ON E-LINE 7"@10557' MW:10.2 NaC1 RIH W/ BIT/CSG SCRAPER, TAG BTM AT 10479, REVERSE CIRC AND FILTER BRINE UNTIL HOLE CLEAN, POH LD 89 JTS DP AND STAND BACK REMAINDER, PULL WB, RU HLS E-LINE, MU PET CMT LOG TOOL, RIH, TOOL MALFUNCTIONED, POH, LD PET TOOL, MU GYRO SURVEY TOOL DAILY:S31,936 CUM:$1,133,092 ETD:S1,133,092 EFC:$1,481,0000 MU 3-1/2" COMPLETION ASSY. 7"@10557' MW:10.2 NaCl CONT. MU GYRO LOGGING TOOL, RIH TO 10479, POH LOGGING 100' STATIONS, MU PET CMT EVAL TOOL, RIH, TOOL MALFUNCTION, REPAIR LOGGING TOOL, RIH, LOG F/10476-8100, POH, MU PERF GUN 91, RIH, PERF 10230-10250, POH, ASF, MU GUN #2, RIH, PERF 10210-10230, POH, ASF, RD HLS E-LINE UNIT, RU TO 3-1/2" SINGLE COMPLETION ASSEMBLY DAILY:S76,111 CUM:$1,209,203 ETD:S1,209,203 EFC:$1,481,0000 RIH W/ BIT/CSG SCRAPER 7"@10557' MW:10.1 NaCl CONT. RIH W/ 3-1/2" SINGLE COMPLETION ASSEMBLY, PACKER P~TURELY SET AT 4928', ATTEMPT TO WORK PKR FREE - NO SUCCESS, SHEAR OFF PBR, POH W/ TBG, PU AND RIH W/ PKR RETR TOOL ON DP, LATCH INTO PKR, ROTATE RELEASE PKR, POH, LD PKR, MU BIT/CSG SCRAPER, RIH DAILY:S28,147 CUM:$1,237,350 ETD:S1,237,350 EFC:$1,481,0000 RIH W/COMP. ASSY. 7"@10557' MW:10.1 NaCl CONT. RIH W/BIT/CSG SCRAPER TO 10072', REV. CIRC., POH LD 76 JTS DP, STAND BACK REMAINDER, RU E-LINE, RIB W/GR/JB TO 10100', POH, RECOVERED RUBBER AND METAL PIECES, RERUN GR/JB TO 10100', POH, RD E-LINE, RU & RIH W/ 3-1/2" SINGLE COMPLETION ASSEMBLY DAILY=S38,470 CUM:$1,275,820 ETD:S1,275,820 EFC:$1,481,0000 The above is correct Signature ~/''~ For form preparation ~F[d,/distributlon, see Procedures Manu~tt,-'Sectlon 10, Drilling, Pages 86 and 87. AR3B-459-1-D Number all dally well history forms consecutively Page no. as they are prepared for each well. ARCO O,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. IAccounting cost center code state AK District County or Parish ARCO ALASKA INc, NORTH SLOPE Field Lease or Unit KUPARUK RIVER UNIT ADL: 25589 ALK: 2675 Auth. or W.O. no. Title AK4338 COMP LET IONS J Well no. K~U 2K-19 Operator AR.Co. W.I. ARCO 55. 8533 Spudded or W.O. begun JDate SPUD J 11/04/89 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC #1 05/04/90 (18) TD:10659 PB:10500 SUPV:GB Old TD New TD Released rig Date Iotal number of wells (active or inactive) on this ost center prior to plugging end bandonment of this well our I Prlor status if a W,O, I 00:00 RIG RELEASED 7"@10557' MW:10.1 NaCl FINISH RUNNING COMP STRING OF 3 1/2", 9.3#, J-55, EUE 8RD, AB-MOD, IPC TBG, W/ TBG TAIL @ 10,084', BAKER 'HB' PKR @ 10,016, PBR (SHEARED) @ 10,003' & SSSV @ 1798', RELAND TBG, TEST SSSV, LD LDG JT, SET BPV, ND BOP, NU XMAS TREE, PULL BPV, SET TP & TEST TREE TO 5000 PSI, TEST 3 1/2"X 7" ANN TO 2500 PSI, PRES TBG TO 4250 PSI AND SHEAR BALL FROM SOS, DISP DOWN ANNULUS W 6 BBLS DIESEL & BULL HEAD 2 BBLS DIESEL DOWN 3 1/2" TBG FOR FREEZE PROTECT, BLOW DOWN ALL LINES, SECURE WELL, RELEASE RIG @ 1730 5/3/90. DAILY:S184,614 CUM:$1,460,434 ETD:$1~460,434 EFC:$1,481,0000 PB Depth K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest iime Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date / / Ti For form preparati and distribution see Procedures Manual, Sechon 10, Drilling, Pages 86 and 87. Number all dally well hiato~ forms consecutively I Page no. AR3B-459-3-C as they are prepared for each wel.Dl~i~on ADDENDUM WELL 2K-19 5/27/90 Frac Kuparuk "A" sand perfs 10210'-10250' 180 deg oriented 25 deg ccw in ten stages as follows. Stage 1: Stage 2: Stage 3: Stage 4: Stage 5: Stage 6: Stage 7: Stage 8: Stage Stage Pmp 200 bbls YF240 (Non XL) prepad @ 22-25 bpm 7500-4505 psi 80 bbls YF240 (Non XL) prepad @ 20 bpm 7562-5450psi 90 bbls slick diesel flush @ 20-25 bbm 3790-6850 psi 1500 bbls YF240 pad @ 25 bpm 7562-5450 psi 120 bbls YF240 w/2 ppg 16/20 Carbolite @ 25 bpm 5450-5330 psi 128 bbls YF240w/4 ppg 16/20 Carbolite @ 25 bpm 5330-5415 psi 134 bbls YF240 w/6 ppg 16/20 Carbolite @ 25 bpm 5415-5570 psi 133 bbls YF240 w/8 ppg 16/20 Carbo]ite @ 25-23 bpm 5570-5490 psi 83bbls YF240 w/10 ppg 16/20 Carbolite @ 23 bpm 5490-5670 psi 9:60 bb]s YF240 w/12 ppg 16/20 Carbolite @ 23-21 bpm 5670-5940 psi 10:33 bbls Slick Diesel flush @ 21-20 bpm 5940-6240psi Fluid to recover: 2551 bbls Sand in zone: 156,000lbs Sand in csg: 18,8001bs Avg pressure: 5600 psi Drilling Sh:tpervisor Date GYRODATA SERVICES, INC. for ARCO ALASKA, INC. 05/24/90 Report by.: ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : 2K-19 (11-10-8) Section at: S 60,06 W Engineer ..: RECORD OF SURVEY Computation...: RADIUS OF CURVATURE Survey Date...: 05/09/90 RKB Elevation.: 154.00 ft Reference ..... : 50-103-20118 S MEAS INCLN C DEPTH DEG MN 7 111 0 29 7 211 0 40 7 311 0 37 7 411 0 59 7 511 1 21 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 111.0 -43.0 0.0 N 62 48 W 0.4 N 0.2 W 211.0 57.0 0.7 N 84 57 W 0.7 N 1.2 W 311.0 157.0 1.6 N 78 7 W 0.8 N 2.3 W 411.0 257.0 2.7 S 85 14 W 0.9 N 3.7 W 511.0 357.0 4.6 S 87 59 W 0.8 N 5.7 W CLOSURE DISTNCE DEG MIN /lOO 0.5 N 31 24 W 0.44 1.4 N 60 58 W 0.17 2.4 N 70 13 W 0.04 3.8 N 76 5 W 0.36 5.8 N 82 6 W 0.37 7 611 1 37 7 711 2 34 7 811 7 11 7 911 9 1 7 1011 11 28 610.9 456.9 6.8 S 88 51 W 0.7 N 8.3 W 710.9 556.9 10.2 S 74 11 W 0.2 N 11.9 W 810.5 656.5 18.5 S 70 2 W 2.4 S 20.0 W 909.5 755.5 32.5 S 68 7 W 7.5 S 33.1 W 1007.9 853.9 50.1 S 67 8 W 14.2 S 49.6 W 8.3 N 85 2 W 0.26 11.9 N 89 7 W 0.96 20.1 S 83 5 W 4.62 34.0 S 77 19 W 1.82 51.6 S 73 59 W 2.45 7 1111 15 25 7 1211 18 49 7 1311 20 58 7 1411 22 55 7 1511 28 26 1105.1 951.1 73.1 S 68 10 W 23.1 S 71.1 W 1200.7 1046.7 102.2 S 69 37 W 33.7 S 98.5 W 1294.7 1140.7 135.6 S 71 33 W 45.0 S 130.6 W 1387.4 1233.4 172.2 S 72 33 W 56.5 S 166.1 W 1477.5 1323.5 214.5 S 72 43 W 69.4 S 207.5 W 74.7 S 72 1 W 3.95 104.1 S 71 8 W 3.4." 138.1 S 71 0 W 2.16 175.5 S 71 13 W 1.95 218.8 S 71 30 W 5.52 7 1611 29 32 7 1711 32 37 7 1811 33 38 7 1911 39 5 7 2011 41 49 1565.0 1411.0 261.8 S 72 31 W 83.9 S 253.7 W 1650.7 1496.7 312.3 S 71 13 W 100.0 S 302.7 W 1734.4 1580.4 366.1 S 68 38 W 118.7 S 354.1 W 1814.9 1660.9 425.1 S 62 35 W 143.2 S 408.0 W 1891.0 1737.0 489.9 S 63 29 W 172.6 S 465.8 W 7 2111 43 53 7 2211 46 56 1964.3 1810.3 557.7 S 65 40 W 201.8 S 527.3 W 2034.5 t880.5 628.6 S 64 44 W 231.6 S 591.9 W *Survey Codes: 7/GYRO 267.2 S 71 42 W 1.~ 318.8 S 71 44 W 3 373.4 S 71 28 W 1~ 432.4 S 70 40 W 5~6 496.8 S 69 40 W 2(~ 564.6 S 69 4 W 2~ 635.6 S 68 38 W 3~9 (KRU2K19) 2K-19 (11-10-8) S MEAS INCLN C DEPTH DEG MN 7 2311 47 48 7 2411 51 35 7 2511 52 50 7 2611 55 52 7 2711 56 7 7 2811 56 24 7 2911 56 31 7 3011 56 41 7 3111 59 22 7 3211 59 49 7 3311 59 36 7 3411 59 15 7 3511 59 32 7 3611 59 53 7 3711 60 21 7 3811 60 2 7 3911 60 6 7 4011 60 8 7 4111 59 51 7 4211 59 38 7 4311 59 9 7 4411 59 17 7 4511 58 48 7 4611 58 31 7 4711 59 28 7 4811 59 29 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 2102.2 1948.2 701.9 S 64 25 W 263.2 S 658.3 W 2166.9 2012.9 778.0 S 63 36 W 296.6 S 726.9 W 2228.2 2074.2 856.9 S 63 50 W 331.6 S 797.7 W 2286.5 2132.5 938.0 S 61 33 W 368.9 S 869.9 W 2342.4 2188.4 1020.9 S 62 5 W 408.1 S 943.0 W 2397.9 2243.9 1104.0 S 62 39 W 446.6 S 1016.7 W 2453.2 2299.2 1187.2 S 62 58 W 484.7 S 1090.8 W 2508.2 2354.2 1270.6 S 63 43 W 522.2 S 1165.4 W 2561.2 2407.2 1355.3 S 60 44 W 561.7 S 1240.4 W 2611.8 2457.8 1441.6 S 60. 29 W 604.1 S 1315.6 W 2662.2 2508.2 1527.9 S 61 7 W 646.2 S 1391.0 W 2713.1 2559.1 1614.0 S 61 38 W 687.4 S 1466.5 W 2764.0 2610.0 1700.0 S 62 5 W 728.0 S 1542.4 W 2814.4 2660.4 1786.3 S 62 38 W 768.1 S 1618.9 W 2864.3 2710.3 1872.9 S 63 13 W 807.5 S 1696.1 W 2914.0 2760.0 1959.6 S.62 47 W 846.9 S 1773.4 W 2963.9 2809.9 2046.1 S 62 38 W 886.7 S 1850.4 W 3013.7 2859.7 2132.7 S 62 47 W 926.4 S 1927.5 W 3063.7 2909.7 2219.3 S 62 11 W 966.4 S 2004.3 W 3114.1 2960.1 2305.6 S 61 37 W 1007.1 S 2080.5 W 3165.0 3011.0 2391.6 S 60 48 W 1048.6 S 2155.9 W 3216.2 3062.2 2477.6 S 60 20 W 1090.8 S 2230.7 W 3267.6 3113.6 2563.3 S 59 54 W 1133.5 S 2305.1 W 3319.6 3165.6 2648.7 S 59 25 W 1176.7 S 2378.8 W 3371.2 3217.2 2734.4 S 60 23 W 1219.6 S 2452.9 W 3422.0 3268.0 2820.6 S 59 58 W 1262.5 S 2527.7 W Page 2 05/24/90 . CLOSURE DL DISTNCE DEG MIN /100 709.0 S 68 12 W 0.89 785.1 S 67 48 W 3.82 863.9 S 67 26 W 1.2~ 944.9 S 67 1 W 3.4 1027.5 S 66 36 W 0.44 1110.4 S 66 17 W 0.48 1193.6 S 66 2 W 0.25 1277.0 S 65 52 W 0.55 1361.7 S 65 38 W 3.46 1447.6 S 65 20 W 0.50 1533.7 S 65 5 W 0.52 1619.6 S 64 53 W 0.52 1705.6 S 64 44 W 0.43 i791.9 S 64 37 W 0.55 1878.5 S 64 32 W 0.63 1965.3 S 64 28 W 0.45 2051.9 S 64 24 W 0.1 2138.6 S 64 20 W 0.1~ 2225.1 S 64 15 W 0.53 2311.4 S 64 10 W 0.47 2397.4 S 64 4 W 0.77 2483.1 S 63 57 W 0.37 2568.7 S 63 49 W 0.58 2653.9 S 63 41 W 0.45 2739.4 S 63 34 W 1.19 2825.4 S 63 28 W 0.30 'Survey Codes: 7/GYRO 2K-19 (11-10-8) Page 3 05/24/90 RECORD OF SURVEY S MEAS INCLN C DEPTI{ DEG MN 7 4911 58 55 7 5011 58 42 7 5111 58 28 7 5211 59 28 7 5311 60 5 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 3473.2 3319.2 2906.4 S 59 40 W 1305.7 S 2601.9 W 3525.0 3371.0 2992.0 S 59 20 W 1349.1 S 2675.6 W 3577.1 3423.1 3077.3 S 58 52 W 1392.9 S 2748.9 W 3628.6 3474.6 3163.0 S 59 46 W 1436.6 S 2822.5 W 3679.0 3525.0 3249.4 S 61 0 W 1479.3 S 2897.6 W CLOSURE DL DISTNCE DEG MIN /100 2911.1 S 63 21 W 0.60 2996.5 S 63 15 W 0.32 o 3253.4 S 62 57 W 1.12 7 5411 59 31 7 5511 59 10 7 5611 58 33 7 5711 58 44 7 5811 58 9 3729.3 3575.3 3335.8 S 60 4 W 1521.9 S 3780.3 3626.3 3421.8 S 59 24 W 1565.2 S 3832.0 3678.0 3507.4 S 59 8 W 1609.0 S 3884.0 3730.0 3592.8 S 60 37 W 1651.8 S 3936.4 3782.4 3678.0 S 61 38 W 1693.0 S 2972.9 W 3339.8 S 62 53 W 0.89 3047.2 W 3425.7 S 62 49 W 0.60 3120.8 W 3511.1 S 62 44 W 0.65 3194.6 W · 3596.4 S 62 39 W 1.10 3269.2 W 3681.6 S 62 37 W 0.94 7 5911 57 43 3989.5 3835.5 3762.7 S 63 18 W 1732.1 S 3344.4 W 7 6011 58 3 4042.6 3888.6 3847.2 S 64 4 W 1769.7 S 3420.3 W 7 6111 58 1 4095.6 3941.6 3931.8 S 63 46 W 1807.0 S 3496.5 W 7 6211 57 59 4148.6 3994.6 4016.5 S 64 3 W 1844.3 S 3572.6 W 7 6311 57 44 4201.8 4047.8 4101.0 S 63 28 W 1881.7 S 3648.6 W 3766.3 S 62 37 W 1.27 3851.0 S 62 39 W 0.65 3935.8 S 62 40 W 0.22 4020.6 S 62 42 W 0.20 4105.2 S 62 43 W 0.48 7 6411 57 14 4255.5 4101.5 4185.2 S 62 43 W 1919.9 S 3723.8 W 7 6511 57 37 4309.4 4155.4 4269.4 S 62 17 W 1958.8 S 3798.5 W 7 6611 58 21 4362.4 4208.4 4354.1 S 62 53 W 1997.8 S 3873.8 W 7 6711 57 55 4415.2 4261.2 4438.9 S 62 17 W 2036.9 S 3949.2 W 7 6811 57 28 4468.6 4314.6 4523.4 S 61 31 W 2076.7 S 4023.7 W 4189.6 S 62 44 W 0.74 4273.8 S 62 43 W 0.5 4358.6 S 62 43 W 0. 4443.6 S 62 43 W 0.62 4528.1 S 62 42 W 0.70 7 6911 57 14 4522.6 4368.6 4607.6 S 61 13 W 2117.1 S 4097.6 W 7 7011 57 33 4576.5 4422.5 4691.8 S 60 45 W 2158.0 S 4171.3 W 7 7111 57 50 4629.9 4475.9 4776.3 S 60 44 W 2199.3 S 4245.0 W 7 7211 57 50 4683.2 4529.2 4861.0 S 60 34 W 2240.8 S 4318.8 W 7 7311 57 40 4736.5 4582.5 ~ 4945.5 S 60 31 W 2282.4 S 4392.4 W 4612.2 S 62 41 W 0.32 4696.4 S 62 39 W 0.46 4780.9 S 62 37 W 0.29 4865.5 S 62 35 W 0.12 4950.0 S 62 33 W 0.17 7 7411 57 7 4790.4 4636.4 5029.8 S 60 19 W 2323.9 S 4465.7 W 5034.2 S 62 30 W 0.57 'Survey Codes: 7/GYRO 2K-19 (11-10-8) Page 4 05/24/9.0 RECORD OF SURVEY S MEAS INCLN C DEPTH DEG MN 7 7511 57 41 7 7611 58 26 7 7711 58 32 7 7811 58 41 7 7911 57 49 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 4844.3 4690,3 5114,0 S 59 59 W 2365,9 S 4538,8 W 4897,2 4743,2 5198,9 S 59 47 W 2408.5 S 4612.2 W 4949,4 4795,4 5284,1 S 59 22 W 2451,6 S 4685,7 W 5001,5 4847,5 5369,5 S 58 37 W 2495,6 S 4758,9 W 5054,1 4900,1 5454,5 S 58 29 W 2540,0 S 4831.4 W CLOSURE DISTNCE DEG MIN /lOO 5118.4 S 62 28 W 0.61 5203,2 S 62 26 W 0,77 5288,3 S 62 23 W 0,. ~ 5373,5 S 62 20 W 0,56 5458,4 S 62 16 W 0,87 7 8011 57 57 7 8111 59 14 7 8211 58 52 7 8311 58 10 7 8411 58 25 5107,3 4953,3 5539.1 S 58 57 W 2584,0 S 4903,8 W 5159,4 5005,4 5624,5 S 62 26 W 2625,8 S 4978,2 W 5210,8 5056,8 5710,2 S 62 17 W 2665,5 S 5054,2 W 5263,1 5109,1 5795,4 S 62 5 W 2705,3 S 5129,6 W 5315,6 5161,6 5880,4 S 61 49 W 2745,3 S 5204,7 W 5542,9 S 62 13 W 0,36 5628,2 S 62 11 W 2,88 5714,0 S 62 12 W 0,39 5799,3 S 62 12 W 0,72 5884,3 S 62 11 W 0,31 7 8511 58 35 7 8611 58 44 7 8711 58 43 7 8811 58 37 7 8911 58 45 5367,9 5213,9 5965.6 S 61 49 W 2785,6 S 5279,8 W 5419,9 5265,9 6051,0 S 61 49 W 2826,0 S 5355,1 W 5471,8 5317,8 6136,4 S 61 21 W 2866,6 S 5430,2 W 5523,9 5369,9 6221.8 S 60 52 W 2907,9 S 5505,0 W 5575,8 5421,8 6307,3 S 60 55 W 2949,4 S 5579,7 W 5969,6 S 62 11 W 0,17 6055,0 S 62 11 W 0,15 6140,4 S 62 10 W 0,34 6225,8 S 62 9 W 0,36 6311,2 S 62 8 W 0,14 7 9011 58 44 7 9111 58 34 7 9211 58 6 7 9311 57 58 7 9411 57 19 5627,7 5473,7 6392,7 S 60 40 W 2991,2 S 5654,3 W 5679,8 5525,8 6478,1 S 60 12 W 3033,3 S 5728,5 W 5732,3 5578,3 6563,2 S 59 50 W 3075,8 S 5802,3 W 5785,2 5631,2 6648,1 S 59 23 W 3118,8 S 5875.4 W 5838,7 5684.7 6732,5 S 59 4 W 3162,0 S 5948,0 W 6396,7 S 62 7 W 0,1" 6482,1 S 62 6 W 0,3 6567,1 S 62 4 W 0,53 6651,9 S 62 2 W 0,34 6736,3 S 62 0 W 0,69 7 9511 57 20 7 9611 57 20 7 9711 55 51 7 9811 55 47 7 9911 55 37 5892,7 5738,7 6816,7 S 58 22 W 3205,7 S 6020,0 W 5946,7 5792,7 6900,8 S 57 52 W 3250,1 S 6091,5 W 6001,7 5847,7 6984,2 S 57 32 W 3294,7 S 6162,0 W 6057,9 5903,9 7066,9 S 57 11 W 3339,4 S 6231,7 W 6114,3 5960,3 7149,3 S 56 40 W 3384.5 S 6300,9 W 6820,3 S 61 58 W 0,50 6904,3 S 61 55 W 0,36 6987,5 S 61 52 W 1,50 7070,0 S 61 49 W 0,25 7152,3 S 61 45 W 0,39 7 10011 54 58 6171,2 6017,2 7231,4 S 56 25 W 3429,8 S 6369,5 W 7234,2 S 61 42 W 0,67 ~Survey Codes: 7/GYRO 2K-19 (11-10-8) RECORD OF SURVEY S MEAS INCLN C DEPTH DEG MN 7 10111 54 3 7 10211 52 35 7 10311 51 2 7 10411 49 17 7 10490 48 15 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE DEG MIN FROM-WELL-HEAD 6229.2 6075.2 7312.7 S 58 25 W 3473.6 S 6438.1 W 6289.0 6135.0 7392.9 S 59 46 W 3514.8 S 6506.9 W 6350.8 6196.8 7471.5 S 60 11 W 3554.1 S 6574.9 W 6414.9 6260.9 7548.3 S 61 59 W 3591.3 S 6642.1 W 6466.9 6312.9 7607.6 S 63 48 W 3618.3 S 6695.0 W X 10659 48 15 6579.5 6425.5 7733.4 S 63 48 W 3674.0 S 6808.1 W 'Survey Codes: 7/GYRO X/EXTRAPOLATED Page 5 05/24/90 · CLOSURE DL DISTNCE DEG MIN /100 7315.4 S 61 39 W 1.61 7395.5 S 61 37 W 1.70 7474.1 S 61 36 W 1 5~ 7 o.8 s . > 7610.2 S 61 37 W 1.83 7736.2 S 61 39 W 0.00 2K-19 (11-10-8) Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 6 05/24/90 SUBSEA DEPTH 0 100 200 300 400 5OO 600 700 8OO 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 MEAS BKB MD-TVD VERT DEPTH DEPTH DIFF CORRECT 154 154 0 0 254 254 0 0 354 354 0 0 454 454 0 0 554 554 0 0 RELATIVE COORDINATES FROM WELL HEAD 0.54 N 0.60 W 0.72 N 1.68 W 0.90 N 2.82 W 0.86 N 4.48 W 0.76 N 6.77 W 654 654 0 0 0.62 N 9.66 W 754 754 0 0 0.59 S 14.47 W 855 854 i 1 4.45 S ~25.42 W 956 954 2 i 10.28 S 40.10 W 1058 1054 4 2 18.13 S 58.93 W 1162 1154 8 4 1268 1254 14 6 1375 1354 21 7 1484 1454 30 10 1598 1554 44 14 1715 1654 61 17 1835 1754 81 20 1962 1854 108 27 2097 1954 143 35 2240 2054 186 43 2390 2154 236 51 2554 2254 300 64 2732 2354 378 77 2912 2454 458 81 3097 2554 543 85 28.29 S 84.34 W 40.08 S 116.19 W 52.31 S 152.89 W 65.74 S 195.67 W 81.99 S 247.78 W 100.61 S 304.77 W 123.19 S 366.64 W 158.28 S 436.86 W 199.11 S 517.59 W 240.50 S 610.88 W 288.63 S 712.91 W 345.38 S 829.76 W 416.44 S 958.14 W 485.32 S 1091.88 W 546.42 S 1233.88 W 2500 3295 2654 641 98 641.62 S 1377.36 W 2K-19 (11-10-8) Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/24/90 SUBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 3491 3690 3891 4092 4289 4485 4677 4874 5067 5261 5460 5653 5844 6032 6221 6408 6595 6784 6969 7156 7344 7529 7720 7911 8100 2754 737 ' 97 2854 836 99 2954 937 101 3054 1038 100 3154 1135 98 3254 1231 95 3354 1323 93 3454 1420 96 3554 1513 93 3654 1607 94 3754 1706 98 3854 1799 94 3954 1890 91 4054 1978 88 4154 2067 89 4254 2154 87 4354 2241 87 4454 2330 89 4554 2415 85 4654 2502 87 4754 2590 87 4854 2675 86 4954 2766 91 5054 2857 91 5154 2946 90 RELATIVE COORDINATES FROM WELL HEAD 721.74 S 801.91 S 877.95 S 955.20 S 1034.70 S 1526.45 W 1678.69 W 1835.59 W 1991.09 W 2142.11 W 1119.66 S 1210.47 S 1287.75 S 1370.88 S 1464.24 S 2286.93 W 2424.28 W 2575.32 W 2717.95 W 2855.56 W 1539.16 S 1633.76 S 1712.30 S 1776.78 S 1847.22 S 3010.91 W 3146.47 W 3289.41 W 3437.05 W 3580.78 W 1907.92 S 1998.73 S 2057.04 S 2136.49 S 2216.83 S 3725.99 W 3857.33 W 4007.09 W 4142.52 W 4279.04 W 2294.81 S 2372.93 S 2454.22 S 2537.51 S 2650.18 S 4416.98 W 4552.48 W 4692.66 W 4832.59 W 4914.54 W 5100 8294 5254 3040 93 2694.94 S 5118.34 W 2K-19 (11-1o-8) Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 8 05/24/90 SUBSEA MEAS BKB MD-TVD VERT DEPTH DEPTH DEPTH DIFF CORRECT 5200 5300 5400 5500 5600 5700 5800 .5900 6000 6100 6200 6300 6400 8484 8677 8869 9062 9252 9439 9625 9804 9981 10153 10316 10471 10621 5354 3130 91 5454 3223 92 5554 3315 92 5654 3408 93 5754 3498 91 5854 3585 87 5954 3671 85 6054 3750 80 6154 3827 77 6254 3899 72 6354 3962 63 6454 4017 54 6554 4067 50 RELATIVE COORDINATES FROM WELL HEAD 2774.72 S 5259.85 W 2845.94 S 5407.34 W 2932.47 S 5547.97 W 3006.90 S 5694.35 W 3089.18 S 5834.39 W 3169.46 S 5970.45 W 3255.18 S 6101.64 W 3328.27 S 6231.11 W 3411.85 S 6351.48 W 3501.11 S 6455.65 W 3557.50 S 6576.48 W 3629.89 S 6653.50 W 3661.40 S 6782.53 W 2K-19 (11-10-8) Page 9 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 05/24/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH DEG MN BKB SUB-S DIST DEG MIN FROM-WELLHEAD DIST DEG MIN DL/ 100 1000 11 11 997 843 48 S 67 14 W 13 2000 41 31 1883 1729 483 S 63 23 W 169 3000 56 40 2502 2348 1261 S 63 38 W 518 4000 60 8 3008 2854 2123 S 62 46 W 922 5000 58 43 3519 3365 2983 S 59 23 W 1344 6000 58 1 4037 3883 3838 S 63 59 W 1766 48 W 50 S 74 51 W 2.5 459 W 490 S 69 46 W 2.8 1157 W 1268 8 65 53 W 0.6 1919 W 2129 S 64 20 W 0.1 2668 W 2987 S 63 15 W 0.3 3412 W 3842 S 62 38 W 0.6 7000 57 31 4571 441~ 4683 S 60 48 W 2153 S 8000 57 56 5101 4947 5530 S 58 54 W 2579 S 9000 58 44 5622 5468 6383 S 60 42 W 2987 S 10000 55 2 6165 6011 7222 S 56 26 W 3425 S 4163 W 4687 S 62 39 W 0.5 4896 W 5534 S 62 13 W 0.4 5646 W 6387 S 62 7 W 0.2 6362 W 7225 S 61 42. W 0.7 by GYRODATA SERVICES, INC. for ARCO ALASKA, INC. 05/24/90 Report by.: GREAT LAND DIRECTIONAL DRILLING, INC. Field ..... : Kuparuk River Unit Well ...... : 2K-19 (11-10-8) Section at: S 60,06 W Engineer..: Computation...: RADIUS OF CURVATURE Survey Date...: 05/09/90 RKB Elevation.: 154.00 ft Reference ..... : 50-103-20118 INTERPOLATED MARKERS REPORT Surface Location: 219 SNL 94 WEL Sll T10N RSE MARKER IDENTIFICATION MEAS INCLN DEPTH DEG MN KB 0 0 0 9-5/8" CASING 3789 60 6 TOP KUPARUK C 10128 53 48 BASE KUPARUK C 10134 53 43 TOP KUPARUK A 10146 53 32 BASE KUPARUK A PBTD 7" CASING TD EXTRAPOLATED VERT-DEPTHS SECT BKB SUB-S DIST 0 -154 2903 2749 6239 6085 6243 6089 6250 6096 DIRECTION REL-COORDINATES DEG MIN FROM-WELLHEAD 10351 50 20 6376 6222 10500 48 15 6474 6320 10557 48 15 6512 6358 10659~. 48 15 6579TM 6425 0 N 0 0 E 1941 S 62 53 W 7326 S 58 39 W 7331 S 58 44 W 7341 S 58 53 W 0 N 0 E 838 S 1756 W 3481 S 6450 W 3483 S 6454 W 3488 S 6462 W 7502 S 60 54 W 7615 S 63 48 W 7657 S 63 48 W 7733 'S 63 48 W 3569 S 6602 W 3622 S 6702 W 3640 S 6740 W 3674 S 6808 W Sneak Land Direckional D,~illing. <KB>O 225o 750 ...... , oo 3OOO 3750 4500 5250 6000 6750 750O 8250 9000 9750 VERTICAL SECTION VIEW ARCO ALASKA. INC. 2K-i9 [il-lO-8) Section at: S 60 6 W TVD Scale.: 1 inch = 1500 feet Dep Scale.: 1 inch = 1500 feet Dpawn ..... : 05/24/90 4arker Identification 4) KB B) 9-5/8" CASING ~ TOP KUPARUK C D) BASE KUPARUK C ~ TDP KUPARUK A F) BASE KUPARUK A G) PBTD H) 7" CASING MD TVD DEPRT INCLN 0 0 0 0 O0 376g 2903 t94i 60 10 10128 6239 7326 53 BO 10134 6243 7331 53 7t 10146 6250 734t 53 54 10351 6376 7502 50 34 10500 6474 76t5 46 25 10557 6512 7657 46 25 --'-t336~--6!37g--' 7733-'--~ 25 10500 750 75O tSO0 2250 3000 3750 Depar'tupe 4500 5250 6000 6750 7500 8250 Marker Identification MD N/S E/~ A) KB 0 0 N 0 B} 9-5/B' CASING 3789 838 S t756 C) TOP KUPARUK C ~0t28 348~ S 6450 D} BASE KUPARUK C ~0t34 3483 S 6454 ~ TOP KUPARUK A ~0t46 3488 S 6462 E) BASE KUPARUK A 10351 3569 S 6602 Gl PBTD ~0500 3622 S 6702 ~ 7" CASING ~0557 3640 S 6740 II TD EXTRAPOLATED ~0659 3674 S 6Boa PLAN VIEW ARCO ALASKA. INC. 2K-19 {11-10-8) CLOSURE ..... : 7736 ft S 61 39 N DECLINATION.: O. 0 E SCALE ....... : 1 inch = 1300 feet DRA~N ....... : 05/24/90 65O 0 65O 2600 3250 3900 4550 5200 5~)50 6500 7i50 7BO0 8450 7i50 II __ 6500 5850 5;]00 4550 3900 3250 2600 i950 i300 650 0 650 <- NEST ' EAST -> PERMIT ~ O0 ~ - /O ~ WELL NAME /~/~ ~,~i~"'//~ I AOGCC GEOLOGICAL MATERIALS INVENTORY LIST [ check off or Iist~lata as it is re~ceived ) ~red inte~als rare anal~is d~ ditch inte~als digital data ,, LOG TYPE RUN INTERVALS SCALE NO. ~!~.~/ ~J.~- - ~Fc / ???~ ~- ~ ~Z~ --~,, ~-~rG d~) / ,,, ~o, ,- /~~/ ~ ~ ~ 1 i] 13] , ,, ,,, ,, ARCO Alaska, Inc. Date: May 18, 1990 Transmittal #: 7762 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File 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. 2 K - 1 9 Pulse Echo Cement Evaluation PET 4 - 3 0 - 9 0 81 0 0 - 1 0 4 6 6 2 K - 1 8 Acoustic Cement Bond Log 4 - 2 4 - 9 0 71 0 0 - 7 7 8 0 2 K - 0 9 Acoustic Cement Bond Log 4 - 6 - 9 0 5 9 5 6 - 6 7 0 7 2K-09 Collar Log 4-8-90 6000-6685 Receipt Acknowledged: ..... ~- Date' DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) ~R-29-'90 11:!~ ID:NC?BIC RIG I TEL NO:90?~5971D3 5lt;~ ALASiL~. O. p. g' .. ~Ufi ~gons.~°~t~s~Ofi Inspection ~.~pott ........ Location: Sec '/? T/~ R ~ H ~ Y'- Casing SeC ~ ~~ f~. L~caCion, ~aner~l ~ Well St A~UMULA~OR 8YST~I ~ ' ~-,. -- -/ ~U~ SyStemS ....... Y~ua~ ...Audio ._ ~ump in=r. =los. p=es. 200 p~i~ ~' mi~~,=, 7 ~ J'.7. ~&-" ~ - _ .... -- --. ' ~ ~W- :' t , ~'~ ..... ,,',',; '. _ :.~ .. _ _.. · .... _~ellY and ~.looT Safe_cy,. V~Ives Tear., r_:eee,ure Uppe: ~elly / ~est P:essur, __~::) . j~_ -: -. --; .... ~OnOPSJ. ._ ~alZ Type ..... ~_,,, ...... Teac P:~su~, ~~~ _ _' Chok~ t.l..~oZd__./._ ~eat ~essure_~~ .... ~o. Va~v~ /~ ' . ...... _ .... ,- ~ = ..= ~ No, flange~ _ . - __ ..- _ .,, -- ...... - ....... _ L . , I I AdJusCab!~ Cl,oke~ ~ U~ , . ......... ,~ Te~-C Time .. ),"': · ~ ................... days at~d In~fector/ ' Ra~ G: Replaclm~C of failed e~uipmenc'to ba made w/thin. R~azks ' J IL. Ii I , I . _ :111 II i i I _ I IIl ~ II orig. - AO&GC: 'cc' - Op~r'a Co~ cc - Supervisor STATE OFALASKA 0 J~ ~'~ J N ~ Al_Abr~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Change approved program_ Repair well _ Plugging Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphic 99510 Service 2. Name of Operator ARCO Alaska, lnG, 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown ~ Re-enter suspended well _ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) Plugs (measured) None 4. Location of well at surface 219' FNL, 94' FEL, Sec. 11, T10N, RSE, UM At top of productive interval 1423' FSL, 1130' FEL, Sec. 10, T10N, RSE, UM (approx) At effective depth 1280' FSL, 1419' FEL, Sec. 10, T10N, RSE, UM (approx) At total depth 1227' FSL, 1525' FEL, Sec. 10,T10N, RSE, UM (approx) 12. Present well condition summary Total Depth: measured 10659' feet (approx) true vertical 6586' feet . RKB 154' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-19 9. Permit number 89-109 10. APl number , 50~103-20118 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical 10500' feet Junk (measured) 64 8 0' feet None 13. Casing Length Structural 8 0' Conductor Surface 3 7 5 4' Intermediate Production 1 0524' Liner Perforation depth: measured Size Cemented 16" 9 5/8" 1200 Sx AS III & 450 Sx Class G 7" 450 Sx Class G None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Attachments Description summary of proposal Measured depth True vertical depth 115' 115' 3789' 2906' (approx) 10557' 6518' (approx) RECEIVED Detailed operation program X BOP sketch 14. Estimated date for commencing operation . February, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas m Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ '~ ~.t,~~ Title Area Drilling Engineer / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require URIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Form 10-403 Rev 06/15/88 Commissioner IApproval No. Date /,~ ,- ,,3- ~ ~ SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructione: Prepare and submit the "initial Rel3ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field County. parish or borough NORTH SLOPE ILease or Unit ADL: 25589 ALK: 2675 ITitle DRILLING State AK I Well no. KRU 2K-191 KUPARUK RIVER FIELD Auth. or W.O. no. AK4338 Operator ARCO Spudded or W.O. begun JDate Hour SPUD I 11/04/89 06:00 Date and depth as of 8:00 a.m. 11/04/89 ( 1) TD: 115'( 115 SUPV:CD 11/05/89 (2) TD: 3070'( 2955 SUPV:CD 11/06/89 (3) TD: 3809' ( 739 SUPV:CD 11/07/89 ( 4) TD: 4246'( 437 SUPV:CD 11/08/89 (5) TD: 7665'( 3419 SUPV:CD 11/09/89 ( 6) TD: 9815'( 2150 SUPV:CD 11/10/89 (7) TD:10088'( 273 SUPV:SC Complete record for each day reposed DOYON 14 IARCO WI. 55.8533 Prior statue il PU KELLY TO DRILL MW: 8.5 VIS: 72 MOVED RIG F/ 2K18 T/ 2K19, RIG ACCEPTED @ 0130 HRS, 11/4/89, NU 20" DIVERTER PU KELLY DAILY:S30,786 CUM:$30,786 ETD:S30,786 EFC:$1,481M DRLG MW: 9.3 VIS: 93 PU BHA, FUNCTION TEST DIVERTER, DRLG F/ 115 T/ 3070' DAILY:S66,728 CUM:$97,514 ETD:S97,514 EFC:$1,481M LD 12.25" BHA MW: 9.8 VIS: 98 DRLG T/ 3809, CIRC, SHORT TRIP, POOH TIGHT SPOT @ 1500', CHANGE BHA AND RIH TO REAM, CONT RIH, POOH , LD BHA DAILY:S56,855 CUM:$154,369 ETD:S154,369 EFC:$1,481M DRLG F/ 4246 MW: 8.5 VIS: 36 RUN 98 JTS OF 36#-J55-BTC CSG, CIRC, CMT CSG W/1200 SX ASII & 450 SX CLASS G CIP @ 1330, ND DIVERTER, NU BOPE,TEST-OK, PU BHA, RIH AND TAG FC, TEST CSG-OK, DRILL OUT 10', RUN EMW TEST TO 12.5-OK, DRLG F/ 3819' T/4246'. DAILY:S254,552 CUM:$408,921 ETD:S408,921 EFC:$1,481'M DRLG DRLG F/ 4246 T/ 7665 MW: 9.5 VIS: 40 DAILY:$.51,523 CUM:$460,444 ETD:S460,444 EFC:$1,481M a W,O. DRLG MW: 9.5 VIS: 35 DRLG, SHORT TRIP, TEST FORMATION TO 10.6 EMW, DRLG, POOH LOOK FOR HOLE IN PIPE RIH, DRLG T/ 9815 DAILY:S55,931 CUM:$516,375 ETD:S516,375 EFC:$1,481M DRLG @ 10088' MW:10.1 VIS: 42 DRLG, POOH, CHANGE OUT BHA, RIH, WASH AND REAM 9810 TO 10034, DRLG F/ 10034 T/ 10088, RAN EMW TEST TO 10.6 - 11/11/89 ( 8) TD: 10659' ( 571 SUPV:SC 11/12/89 (9) TD: 10659' ( 01 SUPV: SC OK, TIGHT HOLE @ 9810'. DAILY:S66,220 CUM:$582,595 POOH F/ LOGS DRLG, SHORT TRIP, POOH FOR LOGS DAILY:S58,171 CUM:$640,766 POOH W/ LOGS ETD:S582,595 EFC:$1,481M MW:10.1 VIS: 41 ETD:S640,766 EFC:$1,481M MW:10.1 VIS: 38 POOH, RU LOGGERS AND RUN TLC LOGS ON DP, POOH W/ LOGS. DAILY:S53,998 CUM:$694,764 ETD:S694,764 EFC:$1,481M The above is correct For form prepa,~11~n 'an~"~istributY~,~, see Proceduret~.Nl'anual, Section 10, Drilling, Pages~86 and 87. AR3B-459-1-D ~' ~% {'~ ~ Nurnber ail daily well history forms ....... tively =,:' as they are prepared for each well, ~r. iPege no. ARCO Oil anu Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ali drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets un~il final completion. Report official or representative test on "Final" form 1) Submit "Interim" sheets when filled out but nnt less trequently thee every 30 {;ays. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil siring until complehon District ICounty or Parish I ARCO ALASKA INC. ~ NORTH SLOPE Field ILease or Unit I KU?ARUK RIVER FIELD J ADL: 25589 ALK: 2675 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. DOYON 14 11/13/89 ( TD:10659' ( )) SUPV:SC State I Well no. KRU 2K-l~ POOH LDDP MW:10.1 VIS: 41 LD LOGS, RIH, WORK TO BOTTOM @ 10592,CIRC,SHORT TRIP,CIRC,POOH LDDP DAILY:S125,134 CUM:$819,898 ETD:S819,898 EFC:$1,481M The above is co~ect Signature,/~~ ~ For form preparation/~0Jd dist,fibution ~ see Procedures Mani~'f Section 10, Drilling, Pages 86 and 87 Date ,,AR3B-459-2-B I 'Number all daily well hislory torres conseculively as they are prepared for each well IPHqe no ARCO Oil and Gas Company Daily Well History-Final Report / Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been ass*gned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time On workovers when an o~ficial lest is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code District County or Parish ~1~ate ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit no. KUPARUK RIVER FIELD ADL: 25589 ALK: 2675 KRU 2K-19 we~l Auth. or W.O. no. T t e Operator AR.Co. W.I. ARCO 55.8533 Spudded or W.O. begun Date SPUD 11/04/89 Date and depth as of 8:00 a.m. 11/14/89 (11) TD:10659 PB:10476 SUPV:SC Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prlor status if a W,O. I 06:00 CUTOFF 7" CASING 7"@10557' MW:10.1 NaCl TOH LDDP,LD BHA, PULL WEAR BUSHING, RU & RUN 268 JTS 7" 26# J55 BTC CSG, CSG SET DOWN @ 10557,BRK CIRC,COND HOLE/MUD, RU DOWELL, TEST LINES,MIX & PUMP 10 BBLS CW100,25 BBLS SPACER 3000,450 SX(92 BBLS) CLASS G W/ ADDITIVES, 15.8 PPG, DISP W/ 20 BBLS WATER, 360 BBLS 10.2 BRINE,BUMP PLUG, OPEN CTC CMT INFLATABLE PKR W/ 2200 PSI,INFLATE W/ 1/2 BBL CMT, BLED OFF,FLOATS OK, ND FLOWLINE,BOP'S,SET 7" SLIPS,CUT AND DRAIN LANDING JOINT. DAILY:S218,715 CUM:$1,038,613 ETD:S1,038,613 EFC:$1,481M New TD Date P8 Depth Kind e r g Type completion (single, dual, etc. I Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form prepar¢,o~ an% distribution, see Proc~ures ~nuat, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvl~on of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date- December 19, 1989 Transmittal #: 7628 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File 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. 2 K - 1 9 OH Edit Tape and Listing 1 1 - 1 1 - 8 9 # 7 3 5 5 0 Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger state of Alaska RECEIVED 2 z t989 Anchorage ARCO Alaska, Inc. Date: November 28, 1989 Transmittal Ct: 7612 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK . 99510-0360 Transmitted herewith are the following items. one sign_oJ copy of this transmittal. '~'%v~'"?~°/~._.. , ,., MWD Resistivity Gamma 2K-19 2K-19 2K-19 2K-19 2K-19 2" Dual Induction- SFL 5" Dual Induction-SFL Raw FDC 5" Cyberlook Porosity FDC Please acknowledge receipt and return 12-02-88 11-11-89 11-11-89 11-11-89 11-11-89 11-11-89 3500-6005 9790-10620 9790-10620 9790-1O594 9800-10500 9790-10594 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnson) NSK State of Alaska(+Sepia) ~' Vtlual Audio Trip tank_. o-" Flow eont~or Iltfld rems NCR valve X{11 11ne valvee Ch~k valve Low. Ke11~ ~ Ts' pf'ee.u. ~ b l, t,p, ~ f. mtp,....,. ~ Teat preilUre~ Choke man~fold .... Numb,, v, lv,, / ~ ........ __ _.. . Repair or r~plaaem4~ of ~alled equll~Aent U be wde wtthth RECEIVED Alaska Oil & Gas Cons. Comr~issiOi1 October 13, 1989 Telecopy: (907) 276-7542 P. J. Archey Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2K- 19 ARCO Alaska, Inc. Permit No. 89-109 Sur. Loc. 219'FNL, 94'FEL, Sec. 11, T10N, RSE, UM. Bnmhoie Loc. lI82'FSL, 1560'FEL, Sec. 10, T10N, RSE, UM. Dear Mr. Archey~ E' closed is the approved application for permit to drill the above referencedwe~ II. The permit to drill does not exempt you from obtaining additional permits required by iaw from other goverlunental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 tile equipment before che surface casing shoe is drilled. ~ere 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 ~he shoe of the conductor pipe. V ~ C. V. Chau[erton Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF ~E CO~R~{ISSION dlf Enc lo sure cc: Departmen~ oi Fish & Game, Habi~a~ Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA , AI_A~KA OIL AND GAS CONSERVATION COMMI~::LSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory __ Stratigraphic Test __ Development Oil X Re-Entry __ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 154. Pad 118' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25589 ALK 2675 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) · 219' FNL, 94' FEL, Sec. 11, T10N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1320' FSL, 1320' FEL, Sec. 10, T10N, R8E, UM 2K-19 #U630610 At total depth 9. Approximate spud date Amount 1182' FSL, 1560' FEL, Sec 10, T10N, R8E, UM 10-18-89 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K-18 10764' MD 1182' @ TD feet 25' at SURFACE' feet 2560 6556 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 800'feet Maximum hole angle 59 ° Maximum sudace 1685 pslg At total depth (TVD) 3443 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement "Hole Casing Weight Grade Couplin~l Lenc~th IVD TVD IVD TVD linclude stac~e data/ 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625 36.0# J-55 BTC 3658 35' 35' 3693' 2914 1000 Sx AS III & HF-ERW! 550 Sx Class G ...... 8.5 7" 26.0# J-55 BTC 10730' 34' 34' 10764' 6556 200 Sx Class G ..,, HF-ERV Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sC~r~dacUeCt°r R E C E IV E D Intermediate Production · ..., OCT 1 11989 Perforation depth: measured ~Ja$~3, 0il & Gas Cons. C0mmlssl0rl true vertical , /~ich0rag~ 20. Attachments Filin9 fee X~ Property plat __ BOP Sketch _X__ Diverter Sketch X Drillin9 program X Drilling fluid program ~ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~_"~' ~~.,e.~,- Title Area Drillincj Engineer Date ' / Commission Use Only Permit Number I APl number I Approval date I See cover letter for ~;~--/'~) ~ 50- /("~,~' -- -,~-O ~'//~ ]. 0 / ]. 3 / 8 9 other recluirements Conditions of approval Samples required __Y e s ,,~N o Mud log required__ Ye s ~ N o Hydrogen sulfide measures __ Yes ~ N o Directional survey required ~Yes __ N o Required working pre~e ,or/B'pPE~2M: ~t~l~3M: __ 5M' __ 10M' __ 15M Other: ~' /~,~ (j~)~~ /~/~ by order of ,,,A,,pproved by ~ ~,/ · ~,~ _J~j~ ~-~¢'-~'J~t Commissioner the commission Date Form 10-401 Rev. 7-24-89 it in triplicate ? r- _.. o ........ 4.000L_ -t,' 500.0_.. 6000__ ............ ~ ..... 1~-5~ ..... TYD-4531 THD-6832 DEP-441 1 .... : .... AVERA'OE-''ANGLE 59 DEO T/ ZONE C TVD-6314 THD-10294 DEP-7378 T/ ZONE A TVD-6327 THD-10319 DEP-7400 TARGET CNTR TVD-6390 THD-10442 DEP-?505 B/ KUP SNDS TVD-6453 THD-10564 DEP-7610 TD (LOG PT) TVD-6556 THD-lO764 DEP-?*781 __?000 ..... I I 0 1 000 2000 I I I :3000 4000 5000 VERTICAL SECTION 6000 7000 I 8000 150 2OO 350 40O 450 35O 300 25O ....... I I I - m I I / 200 150 I I lOO I ? ~oo / I 5O 1700 500 / / / I / / / / / 2100 / / / / / ,/ 1900 / ~1700 \ \ \ \ \ \ I I i 'i !.:: (5 I 0 0 50 5O - 200 _ 25U _ 300 _ 350 _ 400 _ 450 1000 ~, 1 000 . 2000 _ ~000 . 4000 _ HORIZONT SCALE I ARCO ALASKA. ln~. 19 P.d 2K. Well Kuperuk Field North Slope, Al ' 7000 6000 5000 I I TARGET CENTER TVD,,6390 THD- 10442 DEP=?50$ SOUTH 37'41 blEST 65O6 TARGET LOCATION ' 1320' FSL, 1320' FEL SEC. 10. TION. RSE TD LOCAT ! ON · I 182' FSL. 1,560' FEL SEC:.IO. TION. RSE ~.L PRO. JECI!.O.N IN. - 100~ FEE mkm WEST'EAST 4000 3000 2000 1000 0 I I S 60 DEG' 6 M[N 14 7505' (TO TARGET) SURFACE LI 219~ FNL. FEI. DRILLING FLUID PROGRAM (2K-19) Spud to 9-5/8" Drill out to Weight up surface casing weight UP tO TD Density 8.8-9.0 8.7-9.2 10.1 PV 15-30 5-15 11-16 YP 20-40 8-1 2 8-1 2 Viscosity 70-80 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 APl Filtrate 10-15 10-20 6 pH 9- 1 0 9.5-1 0.5 9.0-1 0.5 % Solids 10 +/- 4-7 12-15 Drillin(:] Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes' Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The closest well to 2K-19 is 2K-18. This well is 25' away at surface which would be the closest point. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-i/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin~. Pressure test to 3500 psig. 11) Oownsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTO. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. OEGASSE MUD CLEANER SHALE SHAKERS STI STIR STIR MUD CLEANER CENTRIFUGI TYPICAL MUD SYSTEM SCHEMATIC 7 , 6 l3 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 P°oi DOWNSTREAM OF THE REGULATOI::[ 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER MMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOM:) WITH ARCTIC DIESEL 2. CHECK THAT ALL HOLD-[X:)WN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE MNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)0 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTFOM PIPE RAMS. TEST BOTFOM RAMS TO 250 PSI AND 3(X)0 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3(X)0 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11' - 3(XX) PSI CASING HEAD 3. 11 ' - 3(X:)0 PSI X 13-5/8' - 5000 PSI SPACER SP(:X:)L 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8' - 50(X) PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W! PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5(X)O PSI ANNULAR SRE 8/22/89 DOYON 14 KUPARUK RIVER UNIT 20 DIVERTER SCHEMATIC DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~3N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1116' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRIM. ING SPOOL WI10" OUTLETS 5. 10' HCR BALL VALVES WI10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEi:L VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, IN~., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.03S(b) MAINTENANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DE-I~.CTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES · ... JG 4/26/88 ARCO Alaska, Inc. Posl Office Bo~ 100360 ^nchora,qe, Alaska 99510,-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat- 2K Pad /~ (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the any questions, please call me at 263-4618. Sincerely, subject wells. If you have D. Martin Engineering Aide DM' hf Enclosure RECEIVED DEC 1 1988 Alaska 0il & Gas Cons. C0mmissiml Anchorage GRU13/010 ARCO Alast~a, Inc. is a Subsidiary o! AtlanticRichfieldC~m~l~,'lnY , ,,, c~,~-J WELLS 1-12 ARE LOCATED IN ~' ) SECT)ON 2, T. )0 N., R. 8 E., ss ~ ~i' UMIAT MERIDIAN. ~ ~'~ SECTION II,T. ION., R. 8 E., TION .~ " UMIAT MERIDIAN. N.TS. t:) ~URV~ ~ACTED~ Vl~m ~IT~ MAP I"-Imi~ ~ '~ ~SECTION CORNER ~teS: .... 't~ I. CO0~INATES ARE ~SP ZONE 4. S~CT~ON ~ ~e~9 m SECTION f~ . ~:~t 3. ELEVATIONS ARE B.P.M.S.L. ~Z:zs 5. HORIZONTAl_ POSITION BASED ON ~-K CONTROL MONUMENTS PER ~NSBURY & A~OGIATES. Well , ASp's A~as~a UH & C~ Cui,~,. C~~ , , , ' ......... Dist Dlst. O.G ~ Y X ~~J ~NGITUDE F.S.L. E E.L. Elev. Elev. I j 5,9~8,600.18 ~ 498,~10'.~7 70°14'56.519" 150°00'49.1~'' ~96' 94' 114.0 118.5 2 5,9~8,575.14 ~ 498~10.~8 70°14' ~6.27~" 150°00'49.1~0" ~71' !1~.9 ~ 5~9~8,550.~0 498,~10.~5 70°14' ~6.029' 150°00'49.128" ~46' I 1~.8 4 5~9~8~5~5.46 498~10.06 70°14' ~5.784" 150°00'49.1 ~6'' 2~~ 11~.8 II I I : 5 5,958,500.19 498,~10.12 70°14' ~5.556 150°00 49.1~4" 196' ~ 11~.8 I 6 5 9~8,475.14 498~10.5~ 70°14 .... , ~5.~89" 150°00, 49.1~8 I? 11~.8 r ~ ~5.046" 150o00 49.1~? 146' j 11~.8 7 5~9~8~450.~6 498 ~10.56 70°14' ,, 8 5~9~8,4~5.50 498,~!0.18 70°14'~4.799'' 150°00'49.1~g'' I 121' i 11~.8 j 9 5,9~8,400.50 498~09.98 70°14'~4.555' 150°00'49.1~?",J 96' I 11~.8 I0 5~9~8,~75.19 498~10.14 ] 70°14']4.~06" 150°00'49.1~' 71~ ] 11~.9 t I 5~9~8~50.22 498~10.14 70°14' ~fl.061" 150°00~49.1~' ' 46 11~.9 I~ 5,958~25.20 ~ 498,~10.17 ~ ?0°14'~.815' 150°00~49.1~1'' ~1~ 94' ] 11~.9 118.5 ! : ' F.N.L. I~ 5~9~8,2~5.~1 498,~10.~7 70°14'~2.9~0'' 150°00'49.1~5" 69' 94' I I~.? 118.5 14 5~958,210.14 498~10 t6 70°14~ ' . , 15 5,958,185.1~ . 498,310.16 70°!4' 3~.437'' ' 150°00 49.131 II 113.8 9' 16 5,938, 160.11 i 498,310.20 70°14' 32. 191'' 150° 00' 49. 130'' ~ 144' 113.8 17 5,938, 135.21 498,310.18 70°14'31.946" 150°00'49.130'' ; 169' ~ , 113.9 18 5,938, 110.19 498,310.29 70014' 31.700" 150°00'49.127'' 194' 114.0 19 5,938,085.20 498,310.27 70°14'31.454'' 150 ° 00' 49.12~'' 219' 114.0 , 20 5,938,060.14 ! 498,3]0.22 70°!4'31.207'' i 150°00'49.128'' 244' 114.1 21 5,938,035.16 ~ 498,310.16 70o14'30.962" ~ 150o 00'49.130'' 269' ,r 114.0 ' '22 5,938,010.40 ~ 498,~10.19 70°14'30.718'' 150°00'49. 129" 294' 94' 114.0 23 5,937,985.~] 498,310.13 70°14'30.471'' 150°00'49.130'' 319' 95' 114.0 J~4 5~937,960.29 498,310.08 70°14'30.2Z5'' 150°00'49.132'' J 344' 95' I 113.9 j 118.5m PROPERLY REGISTERED AND LICENSED ~ ~. ~TATE OF ALASKA AND THAT THIS ~...,.,, ................... ~ .,~ P~AT R~PaaS~NTS ASURVa~ ~AOE~~~_a DRILL SITE 2'K VISION AND THAT ALL DIMENSIONS'~--' - ' "~e~'.~mO-'b~/_~ CONDUCTOR AS-BUILTS I.;~'. a-6~9 ."~,~ AND OTHER DETAILS ARE CORRECT ~,~'... ,,."5~~ J ~,~. ~.'~;,"'~.'~, '" ~,.'~,/av,, J~.,o. NS~.a~ ~ , , ,,, , ~ i, i, J ,, , , m, ,,'" , , ~" ,,,, , ' '' ' ,', .1 ASP's , , Alasl a UH & C.,~t.,.~ r.;,.,,..:,., uon'm;~,s;;;: Dist. Dist. O.G. Pod 'Y' X I-~'~t;~d .[~ LONGITUDE F.S.L. F.E.L. Elev. Elev. I 5,938,600.18 498,$10'.17 70°14'36.519" 150°00'49.133'' 296' 94' 114.0 118.5 2 5,938,575.14 498,310.28 70° 14' 36.275" 150°00'49.130" 271' !13.9 3 5,938,550.30 498,310.35 70° 14.' $6.029" 150°00'49.128'' 246' 113.8 4 5,938,5£5.46 498,310.06 70o14. 35.784" 150°00'49.136'. 2::)5' 113.8 5 5,958,500.19 498,310.1z 70°14'35.536'' 150°00'49.134'' 196' 113.8 6 5 938,475.14 498,310.:33 70o14 .... , 35.289" 150°00, 49.1~8 17 115.8 r o 7 5,938,45O.$6 498,310.36 0 it , 70°14 .... 35.046" 150°00, 49.1::'7 146' 113.8 8 5,938,425.30 498,310.18 70°1 34.799" 15000 49.132 121 ! 113.8 9 5,938,400.30 498,309.98 70°14'34.553'' 150°00'49.137" 96' 113.8 I0 5,938,375.19 498,310.14 70° 14' 34.306'' 150°00' 49.133'' 71' i 113.9 t I 5,938,350.22 498,310.14 70°14' 34.061" 150°00'49.133'' ' 46 113.9 12 5,938,325.20 ! 498,310.17 70014'33.815'' 150°00'49.131'' 21' 94' 113.9 118.5 ! ' EN.L. 13 5,938,235.31 498,310.37 70°14'32.930" 150°00'49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310 t6 70°14' " · 3Z.683" 150° 00' 49. 13l 94' ~ 113.7 15 5,938,185.12_. . 498,310.16 70°!4' 32.437'' ' " 150°00 49.131 II 113.8 9' 16 5,938, 160.11 i 498,310.20 70°14' 32. 191" 150°00'49.130'' ~44' 113.8 17 5,938, 135.21 498,310.18 70°14'31.946" 150°00' 49.130'' 169' , 113.9 18 5,938, 110.19 498,310.29 70014' 31.700" 150°00'49.127'' 194' 114.0 19 5,938,085.20 498,310.27 70°14'31.454'' 150°00'49.127" 219' 114.0 , 20 5,938,060.14 ! 498,3~0.22 70°!4' 31.207'' 150° 00'49.128'' 244' 114.1 21 5,9 38,035.16 J 498,310.16 70°14' 30.962'' 150° 00'49. 130'' 269' ,r 114.0 22 5,938,010.40 ~ 498,310.19 70o14. 30.718" 150°00'49. 129" 294' 94' 114.0 23 5,937,985.3:::,] 498,310.13 70°14'30.471'' 150°00'49.130'' 319' 95' 114.0 2,,4 5 ~937,960.29 498,310.08 70 °14' 30.225'' 150° 00'49. 132'' 344' 95' I 113.9 118.5 (2) Loc LIST FOR NEW WELL PERMITS APPROVE DATE 2 thru 8) (8) (10 and 13) (4) Casg ~.,~,~, /~-/z-g~ (14 thru 22) (5) BOPS. (23 thru 28) le Company Is the permit fee attached .......................................... Lease & Well No. ~A YES NO 2. Is well to be located in a defined pool ............................. 3 Is we~] located proper distance from property line ..... 4 Is We~,l !ocated proper distance from other wells ....... 5 Is suZ~iCient undedicated acreage available in this pool 6 Is well to be deviated and is wellbore plat included .... 7 Is operator the only affected party ..................... 8 Can permit be approved before fifteen-day wait ......... REI~RKS 0 10. 1I. 12. 13. Does operator have a bond in force ........... ......... .............. ~ Is a conservation, order needed ...................................... ~ Is administrative approval needed ................................... Is the lease number appropriate ................................... ... ~ Does the well have a unique name and number ......................... ~-. ....... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........ ~ ............................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~/~t Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to j~l_~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. / -/ j (6) OTHER (29 th~ 3~~i rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. .o CONPAN¥ NA~E I ARCO &.:~&~KA~ INC, 2K' ~EL~ NANE I KUFAR~kU FZ. EbD NAM:E aOROUGH I NORTH"~$bOPE tTATE _ _ I AbASKA REFERENCE NO ~ ?3550 13-D£C-1989 21=17 0 R~ NA#~ ~ 73550 P~KYZOUS REEL COM#ENT i ARCO AbASKAe INCe,KUPARUKt2K - 19~50"103"20~1e-00 ,$~, TAPE HEADER &ERVZCE NAME i EDIT D~?E I 89/12/13 O~iGI# ! FLZC TAPE NA#E~. I ?3550 REY~OU& ?APg ~OM#E~? I ARCO ALASKA.; ~NCe,KUPARUK~2K - 19~50-I03~201A8-00 PAGEI COMPANY NAMEI STA~EI AP! NUMBERI ARC~ ALASKA, 2K 19 KUPARUK NORTH SLOPE ALASKA 50~103m20~Sm.O0 LOCATXONt 219' FNL & 94" rgb SECTiONI 11 TOWNSHIPi RANGEI 8E PERMANENT DAI~UMI LOG MEASURED FROM RKB 154e ABOVE PERMANENT DATUM 13-DEC-1989 21:17 PAGEI ELEVATIONS DATE bOOGED~ RUN NU~BER~ ?~ bOGO~R~ KBt 154' 11-NOV-1989 0659' ~0628' DF~ 153' GLt 113' 9 5/8" bB 9 DRILLER DEPTH OF 3789* BIT SIZE I I 8 1/2" ~ 10659' TYPE FLUID IN HOLEI bZND EZ MUD DENSlTY~ PHI 9 !ME CIRCULATION ENOEDi NE LOGGER ON BOTTONI ,X~NUN ~ENP RECORDEDI TOOL NUMBER~! ~ ~40 ViSCOS~TYI 44 20~ II.NOV-9~9 PRUDHOE BAY T~NKHAM de STRAT?ON/$e~ CAMERON DIC 2 ~9 'FIELD REMARKSi ~DEN ~ 2,65 G/C3~ FDEN ~il,'O G~C3, .HC ~:i'CALX. MAT~.~ SAND ~'OB RE~ERENCE NOt 7355,0 bDP/AN~I R.~KRUNEbb * 'FILE ' EDIT,O01 "HIGH RESOLUTION'PASS~ TaPe Verification histin9 ehlumber~er AlasRa Computing Center 13'DUC-1989 21~17 PAGEt DATA SAMPLED EVERY DATA INCLUDED - TOOL EXTENSION TYPE USED FDC ,FDH CNT'A/D/H ,CN~ -,I000 FEET TOOL SAME FOR#ATION PENalTY COMPENSATED NEUTRON TABLE TYPE I CONS TUNI VALU PEri ~ Name R O A~ASKA, INC, UPARU~ ~o~03'20tlem~O 2t9 :FNL & 94 FEL ALASKA USA. AP SertaX_.~umber r~eld LoCOt O~ '5ectton~ TownlhtP morley ., tate or Provtnee atton Wttnesl'.Name · servtce order Number Permanent datum Log Measured From FT , Bottom ~Og zncervaz r~ 0 il-NOV"S9 Txme clreuXlttSfi StOPPed TABLE TYPE I CURV DErX r Raw FaF FDC Count Ra~e Raw Near FD¢ Count Rate Tape VeFiflcation bistlng ehlumeerqer AlasKa ¢omput!nq Center 13-DBC-1989 21917 DEr! F O~ ~at rD¢ Count Rate ~[~ C.~IperN''t~rDC Count Rate Gamma Ray T~ermal Neutro~ Raw Thermal Neutron Ratio T#R~ Calibrated ~et~al Neutron Ratio NeOR Neutron Porosity Output From an AppliCation Program !~ii R&~ NEAR CNT .COUNTS Near Thermal Count~ eCt:ee rat Thermal Counts DATA KORMAT SPEC:ir!CAT,ON RECORD SET TYPE - 64EB e, TYPE ,REPRCODE VAbUE 4 66 5 66' · 66 .0 .14 65 · I~ 66 68 66 ! O, '66 O *$ $~T TYPE o CHAN ** APl A ! AP! APl FZbE NUmB NUMB $~ZE REPR PROCEIi8 HANK SKRV UNIT'SERVICE P ~D' ORDER # bOG, TYPE CHASE MOD NUMB 5A~P. EbEM CODE, CHEX D~P? r? 549135 O0 000 O0 0 I 1 ! 4 68 0000000000 RHOB FDH G/C3 549135 O0 000 O0 0 1 1 I 4 68 0000000000 OPH! rOH Ptl 549135 O0 000 O0 0 I 1 1 4 68 0000000000 eh[ttmlOel'ger AlaSKa ComPut.!.n~ Cent. er 13-DEC-1989 NAME SERV UNIT SERVICE APl AP! APl AP1 rlbE NUMB NUMB SIZE REPR PROCESS ~O ORDER I bOG TYPE CbASS NOD NUMB SA~P EbEN CODE (HEX) ooooo ooo~ ~ ~ . ~ oooooooooo [~~'¢~P. ~I11.~ ooooo ooo~ ~ ~ . 6.oooooooooo ~'~'~.~ ~ ooooo ooo oooooooooo ,o, .$,~oo o,oooooooooo ooo oooI I I ~ .~ ooooo oo o t ,o, ~,,~ t I I oooooooooo 00OO000000 0 0 00 0 r°l ~ I ~ oooooooooo ~'° ~u~" .,.~'"~'*'~ OOoooo ~ oO°°oo o°° ~:~· ~ ~1" ~oooooooo°°°°°°°°°° FU O0000000g 0000000~00 , ooooo o i! i, oooooooooo .. .~,,t ~§~ oo o 0000000000 NH 5&9~ 15 O0 000 O0 0 [ 4 0000000000 oo ooo oooooooooo NH 549 00 I t 4 ¢~N hB $~ O0 000 O0 ~ 1 ~ ,,,0000000000 DATA R~ NH NH D~PT~ RC.N~,CNH GR,CNH O' ~, ~.~..c.. RCNT,CNH GRtC~ DEPT. L,eF H ~N 'H., NH GR ,CNH 10600.000 822~,~00 3~,007 ~ ~ ,602 ,375 ~,ooo l~lul:ooo 1846,090 lO400,000 940~500 8~594 20~ '499 ~182 [13*375 RHOB,.FDN RNFD+FDH R,F H R,FT,,NH RHOBiFDH RN~.FDN RCFT,.N TENS.. RHOB~FDN RNFD,FDH GR,FDH RTNRiC~H R~T~H RHOB,FDH RTNR,CNH TENS. 214~,590 P ~.rON .000 4t,590 21_8,000 ~09,375 ,0~0 NO00 ~oo0 PHI,FDH T Ell ,,t ,: rD N :~ A, NN OPH ]: FDH FEDC~ FDN ~g N s ~ O H ~NRA CNH CNTC CNH DpH I, FDH FFDCbFDH TEN&~FDH TNRA~CNN CNTC,CNH N, DC* ..o.,ooo CFTC;CNN 64,239 DRHO,FDH 40'7 ,, O0 ND DRH , DH CFTCeCNH PAGEt 0 Tape Verification Listing ehlum~erqer Alaska Computtnq Center 13-DEC-1989 21t17 DiPT, 103000000 RHOB,FDH FD,FDH 928,000 RNFDeFDH ~ bZ,FDH 8.8-/5 GR~FDH T~P~tCNH 3 t569 RTNRoCNH RCN?tCNH 235~,084 RCFTtCNH GR,CNH 94e56~ TEN$oCNH D ~ e tOtO0,O00 RHOB4FDH ,CNH 130, TENS~C~H RA ' ~ D RNFD,,FDH trDH ~O-/g GR~DH ft,,NH .,000 RTNR~CNH GReCNH 1: ~ 8 TENStCNH F e DH ~000 RNFD+FDH 'T~PHeCNH ~!,.,c., 6i GReCNH TEN$OCNH END OF DATA .443 DPHI.FDH 0000 FFDCjFDH TNRk~C~H '/2 e405 CNT~6CNH 905 ~000 8~&S48 OPH: rDH 0448 114~,000 DPH]*FDH 48~;g~8 [2~S'O00 ' ,465 107~,000 Fro' 259~750 TEN ~FDH 435,6~.t ~NH CNTa,C 94S,0O0 i~' 4~6 DPHI'rDH 1 ! e~O KFDC, FDH ,~15 TENS.'FDH ,2.1:?~g 524 10,106 4486000 t46~,000 t2,016 445,250 ta3S,O00 t85t~t48 ~:~o 4~916 ,~00 °'ilI o,o. S e o0~ :50 e i IlS Tape VerltlCation Listing ehlumDerqer Alaska Computlng Center S~s FILE TRAIbER ~ FILE NAME = EDIT ,001 $~R¥ICE = FLIC VERSION z OOXA04 DATE I 89/12/13 mAX REC SIZE I 1024 FiLE TYPE I LO **** FZbE HEADER ,sS, EDiT 002 VERSION 8 i~}A04 DATE 8 12/13 XAX REC SIZE Z 2 rlLg TYPE 8 ~0 13-DEC-1959 21817 PAGEt $ $ FiLE - EDIT,O02 "NAIN PASS ~OG DATA" DATA EAHPbED EVERY -,5000 FEET DATA INCEUDED - TOOl, EXTENSION TOOL TYPE USED NAME TABLE: TYPE I CONS TUN! VALU DEF! ARCO ALASKA,'XNC. Cdmpan¥ Name KUPARUK ' r;eld. Name ~o~o)-2oil8-Oo ApI.seriat um er 2t9 FNL & 94* FEL rte~Zd LoCation I~N ~ section Township Tape Verification ~stlnq ChlUmberqer Alaska ¢omputtnq Center TUNI VA~U D~! County SYAT ALASKA State or Province # I 54135~'9STRATTON/$* CAMERON Witness~* Name_ SPN ~ervlce.oFaer Number PPAT permanent datum · M D~Gr '" · TABLE TYPE I CURV L~m ]nduct~on:S~andard processed nes Iv ntaneous Potent~az ~ei~szon B~l, Den$it rat ~DC count~Rate NeaF~FDC Co,~ Rate: Raw Far FDC. Cou~t Rate Raw:Near FDC Count Ra~e Gsmm~ ~a¥ TenSion Neu~ro~ Poros y_ Thermal Neu~ Ca~bra~ed T~ermal. Neu~on Raw ~hermal:Neutron Ra~o Neutron porosLt¥ OUCpot'From an AP'PIIca~on Prooram RAN NEAR CNT COUNTS iAW FAR CNT COUNTS, O~rec~ed Near Thermal orrec~ed Far Thermal Counts ammq Ray end{on Tape Ver.~t~cat:-~on Lllt.~ng ehl~mbe~ger Alasl<& Computl. nq center 13-DEC-t989 21=1'7 PAG[I DATA FOR#AT-$PECXFXCATXON RECORD SET TYPE - 64EB Ir TYPE REPR,CODE VALUE ~ 66 0 ~ SET TYPE - CHAN NAME 8ERV UNXT SERVX~E APZ APl :AP! A~X F~LE NU'M~ NUMB SXZE R~PR PROCEI8 iD. ORDER ~ LOG TYPE CLASS M.D-NUMB SAMP EL.EM .CODE~. (HEX) ., ,PT FT ~5' O0000O0 0 2 ! t'4 B8'0000000000 ' ,,oooo o o ~ . .ooooo ooo OHM~ oo~ ~oot t I ~ ~1ooooo~.oo~o o~.,,1~ oo oo oo~.~~~ i~, ooooo.~o ~' oo°° ~oo oo eo~o~oo~ il OOoo ooo oo oo ooo ooo ~!i oo ooo oo o a ~ ~ ~ ~ ooo0oooooo ~PcpS~ O0 000 O0 0 ~ ! .'t 4 68 0000000000 O0 000 O0 0 2 I I 4 68 0000000000 CPS 549~ O0 000 O0 0 2 ! -I 4 68 0000000000 ~' ~ ,,,~,~ ooooo o,oo, ~,~ , ..oooooooooo eu549O0000 O0 02 ~t 4 6e0000000000 Pu 54~ ~ oo o0o oo o 2 ! t 4 68 oooooooooo NL 549~$ OO 00o O0 ,0 z t t 4 68 oooooooooo Nb 549 ~5oo ooo oo o z ~ ~ 4 60 oooooooooo , ~ oo ooo ooo~ ~.~, ,,oooooooooo ooo ooo~ ~ ~ , ,.ooo~oooooo ~ II~ oo -, ~ ~ ,~ oo ooo ooo~~~.~, oooooooooo Tape Verification btstlnq ehlumeerqeF Alaslca Computlnq Center 13-DgC.1989 2t117 NANE SERV UNiT SERVICE AP1 AP1 AP1 APl FIbE NUMB NUMB SIZE REPR PROCE86 XD ORDER # LOG TYPE CbA$$ MOD NUNB SANP~EbEM CODE (HEX) N~¢c.b cps 54~$s OD ooo OD o ~ ~ 4 68 oooooooooo rteCN~ CPS S4~S oo 000 O0 0 2 ~ ~ 4 68 0000000000 4 0000000000 I~AGEI tO DATA DEPT tCNL 10627,000 ILD.DIb RNFDeFDC NPH~iCNb NPOR,CNb CrTC~CNb- RTNR~ CNTC, RNIFD ~, DC 10400,000 ! 9~000 RTN,.~ CNTC* 240~ 00 75 000 DEPT. I TiENS.F_OC IbP RNFD rD~ NPHZ CNb CPT¢ IbD.DZb DRHO*rDC RNFD*FDC NPHIoCNb NDOReCNb 666et ~ 40e028 2~_8,000 94,7?5 R · OR * DC TR . N TIENAeCNI, Nb Nb' TENS,DIb FFD:.rD TNP,~CN GR, CNb 109~,158 srbuoo~b RH e,.r GR.FDC TNRA.CNb RCFT. N TEN~.~N~ · TEN:a~ · .000 R OB,,.D CAb~,rO ,e83 GR.FDC TNRAiiN 1 5t 16 Tape VerSt!cation List1ng ehlumberqer Alaska Comput!~q Center 13"DEC-1999 21=17 PAGEt DEPT. 10 00,000 IbOoDIL 605 ZEM,DIb 105, ~.~ ~.o~ ~.~ !.~oo. TEN$eDI~ DPH .FDC 80859 DRHO~DC e~7 R~FOeFDC 905,500 RNFD.FDC 11~ ._~ CALI, TgN~,FDC ~479.000 NPHZ,CN~ $~2~J ~NPHeCNb RTNR,¢N~ 3,361 NPORoCNE 33,6]0 RCN?.CNb CN~C,CNb 2415,452 CFTCoCN~ 827,5~2 GRoCN~ 79,000 RHOBeFDC ' ~ ~so.~oo .~oc..~oc ~ ~:I~~..~.c ~o,. TNRAtCN~· 2303e203 RCrT.CNb 100.500 TEN~CN~ ~4~ : DEPT,.DPH~eSPODILD 101~.000.§68 DRHOerDcIbD*DIbGR*DIE 124.625 20479 0,028 FFDC~T~:DIbFDboIC 1456*000489~500'26490 &FbUoD~RHOB.FDCNFDCeFD¢ $ :~e'~J~e ~,.;[.~ ~t'~ t: RNFDoFDC 115~000 CALI,rDC 9.391 GR,FDC PO00 NPHI,CNh ~eO~ TNPHiCNb 4~,4~7 TNRAeCN~ T~NSoFDC 1 45~'000 CNTC,CNb 196~,2 4 CFTCeCNb 56~,491 OR, 124,625 TENS,CNL 1456e000 0000,000 1204~000 4, 78 1961,~83 IbD,DZb GR~D DRHO,r~ RNFDirDC NPHZiCNb NPOReCNb CrTC,CNb 9~00'000 IbD,DIb 19'109 DRHO,FD~ 9,853 GR,DI 865~000 RNFDe~DC 1216,000 NPHI,.CNb 40012 NPOR,CN~ 1854'053 .CFTC.CH~ 98oo,ooo 'IbD,O~b ,$49 DRHO,.FDC ,000 RN~D,FDC ~ 0 ~PXI*CHb 1975,844 u~,c~b 9769~ 0 IbDeDIb RNFDeFDC · NPOReCNb 160~:256 CrTC.C.b *0,009 ' C,FD~ 961~500 CALIo~D~ 49,8~0 TNPHeCNL 47.27 RCNToCNL 537,518 :GR.CNb ,NS,DI :i#:PH e Nb 52Se2 t ,GR.CNb 26~. 7 ZL~.DZb 4,857 200e~750 0,0~6 FFDC,rDC ~I?0,0=0 40,194 TN~HeCNb 4~ ,999 RCNTeCNb 49~0674 GReCNE r U,DX TNRAe N 1.~ 480 R FT.~N 625 T~NS,CN iSrbU,OlL RHO.Be .O IR , N 119~93 TENSeCNL .~o.tl~ ~... ~ ,9 ::tI~ .ct, 4,i~6 8FbU.D~b ~ ~ 0 N~DCeFDC · ,391 GReFDC ,~76 TNRAe N: END.OF DATA IS Tape Verltlcat~on L~stlnq Chlum=erqer AlasKa Computing Center PAGEt ~2 ~ILE NA~E : EDIT .002 SERVIC£ VER$,ON , OO1A04 DATE FXLE TYPE I LO LAST FILE Se,, 'TAPE TRAZLER 8ERVICE NAME I E, DZT TAP~ NAME s 73550 C~NTINUATION ~ P~EV~OU$ TAPE COMMENT I ARCO ALASKA~ ZNC.~KUPARUK~2K - 19.$0'~030201~8000 ~IRVICE NAME TRAI NAME I 73550 CONTINUA, TZON # P~EVXOU8 REEL CONMEN?' $ ARCO AbASKA~ ZNCe,KUPARUKw;2K - ~9,5e~'203-20~18000
