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Home My WebLink About186-032Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-26 50-103-20208-00 906832308 Kuparuk River Patch Setting Record Field- Final 23-Nov-20 0 1 2 3K-27 50-029-22751-00 906831229 Kuparuk River Multi Finger Caliper Field & Processed 20-Nov-20 0 1 3 3K-27 50-029-22751-00 906831376 Kuparuk River Leak Detect Log Field- Final 21-Nov-20 0 1 4 3M-17 50-029-21729-00 906811709 Kuparuk River Leak Detect Log Field- Final 28-Nov-20 0 1 5 3N-02A 50-029-21527-01 906813982 Kuparuk River Leak Detect Log Field- Final 30-Nov-20 0 1 6 3N-02A 50-029-21527-01 906804224 Kuparuk River Packer Setting Record Field- Final 5-Nov-20 0 1 7 3S-07 50-103-20430-00 906801235 Kuparuk River Leak Detect Log Field- Final 4-Nov-20 0 1 8 3S-07 50-103-20430-00 906806709 Kuparuk River Packer Setting Record Field- Final 7-Nov-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 1860320 E-Set: 34562 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-26 50-103-20208-00 906832308 Kuparuk River Patch Setting Record Field- Final 23-Nov-20 0 1 2 3K-27 50-029-22751-00 906831229 Kuparuk River Multi Finger Caliper Field & Processed 20-Nov-20 0 1 3 3K-27 50-029-22751-00 906831376 Kuparuk River Leak Detect Log Field- Final 21-Nov-20 0 1 4 3M-17 50-029-21729-00 906811709 Kuparuk River Leak Detect Log Field- Final 28-Nov-20 0 1 5 3N-02A 50-029-21527-01 906813982 Kuparuk River Leak Detect Log Field- Final 30-Nov-20 0 1 6 3N-02A 50-029-21527-01 906804224 Kuparuk River Packer Setting Record Field- Final 5-Nov-20 0 1 7 3S-07 50-103-20430-00 906801235 Kuparuk River Leak Detect Log Field- Final 4-Nov-20 0 1 8 3S-07 50-103-20430-00 906806709 Kuparuk River Packer Setting Record Field- Final 7-Nov-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/07/2021 01/11/2021 Abby Bell PTD: 1860320 E-Set: 34561 Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR 2 3 2020 AOGCC WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE 1 1E-20 50-029-20895-00 906260886 Kuparuk Multi Finger Caliper Field&Proc 23 -Jan -20 2 1E-12 50-029-20736-00 906207895 Kuparuk Leak Detect with ACX Processed 30 -Dec -19 3 1E-12 50-029-20736-00 906190298 Kuparuk Plug Setting Record Final -Field 19 -Dec -19 4 1F-05 50-029-20807-00 906223186 Kuparuk Injection Profile Log Field&Proc 8 -Jan -20 5 1R -23A 50-029-22200-01 906228630 Kuparuk Multi Finger Caliper Field&Proc 7 -Jan -20 6 WSW 11 50-029-20882-00 906310488 Shallow Sand Plug Setting Record Final -Field 12 -Feb -20 73G -O5 50-029-20132-00 906174377 Kuparuk Packer Setting Record Final -Field 26 -Dec -19 8 3M-17 50-029-21729-00 906210841 Kuparuk Leak Detect Log Final -Field 29 -Dec -19 9 TN 02A 50-029-21527-01 906192001 Kuparuk Leak Detect Log Final -Field 23 -Dec -19 10 30-01 50-029-21836-00 906193765 Kuparuk Plug Setting Record Final -Field 20 -Dec -19 i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com Date: Signed: 186032 32816 13 -Mar -20 PRINTS # CD # 0 1 0 1 III PrP /9(, —o37- Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, December 7, 2019 11:32 AM To: Loepp, Victoria T (CED) Cc: CPA Wells Supt Subject: KRU Producer 3N-02A(PTD#186-032) Report of Sustained IA Casing Pressure Attachments: 3N -02A Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Dear Victoria, Kuparuk gas lifted producer 3N -02A (PTD#186-032) has been shut in since 9/18/19 due to TxIA communication via a tubing leak identified during troubleshooting operations on slickline. The IA pressure has exceeded DNE and has risen to 2050 psi as of this morning. The production casing is 7" 26# J-55 with an internal yield rating of 4,980 psi (45% is 2,241 psi). Significant scale was encountered during the slickline troubleshooting operations thus requiring coiled tubing to remove scale prior to installing a patch. CPAI intends to monitor the pressure while progressing coiled tubing work to eliminate the scale so that the well can be secured then repaired. Please let me know if you have any questions or disagree with this plan forward. Attached is a wellbore schematic. Sincerely, Sam,CA.4'lt%gev(}fask4l) /%ZGi.che lKautk Well Integrity & Compliance Specialist, WNS & C13173 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop com Cell: 907-331-7514 ( sara.e.carlisleCcbcop.com • • Page 1 of 1 Regg, James B (DOA) (~ I P~6 - n ~~ From: NSK Problem Well Supv (n1617@conocophillips.com] Sent: Saturday, April 10, 2010 7:58 AM ~~1~ ~' 1 Z~I~ To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 3N-02A (PTD 186-032) Report of failed TIFL Attachments: 3N-02A schematic.pdf Guy, Tom, Jim Kuparuk gas lifted producer 3N-02A (PTD 1861032) failed a diagnostic TIFL on 04/09/10. The TIO prior to the test was 110/1180/930. A leaking GLV is suspected. SL will troubleshoot the leak and repair if possible. Attached is a 90 day TIO plot and a schematic. :/ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ,, F~"' ~,~; t• r Wit,., t: e. 4/12/2010 KRU 3N-02A PTD 186-032 4/10/2010 TIO Pressures 3000. SC i'??~.P~F WLICRU3N-D2 20D. 3000 ~ __ - _ - - - -_-~ 3000. 30t~t1. 2y00 ~ 3D~4~i. 3000 2400 j . 2100 i 1800 ~ - ~F~ ..i.' 1500 __ __- - - 1200 •Y• ,~• ••_,~-k • - ~•~ • ~- ~- -~ •• •1- ,k1r-ACj-- •- ~ • Y • ti'1 • • l~tlr"k•` • ~ • ,Y i"t i~k-t Y ~•-. . 900 ~' i ~ 0. 0 600 ' ' . 0. 0, ' 300, 0' PLOT START TIME MINOR TIME PL~)'T 1)UItFsTION FLOT ~~NI? TIML•' 09-JAN-10 22:16 MAJOR TIME WEER +02160:DO:DO HRS09-APR-10 22:16 - ~~~~~~ ~~~ PICK TIxL APR-10 12:56: 09 33 '~C TAG NAHE DESCRIPTION ~'-ViL17k? LATEST ~ WL3N-02-CHOKE FLOW TUBING CHOKE ?77???? DRILLSITE WELL ~ PREV WELL SCRATCH 32 FLOW TUBING PRESSURE ~p?7~~7 3N 02 ~ SCRATCH_32 FLOW TUBING TEMP ~~~~~~~ NEXT WELL AI-P3N5002-02 GL CASING PRESSURE ??????? ~' ??????? ENTRY TYPE OPERATOR ~ ??????? ~ OPERATOR VERIFIED ~ SCRATCH_32 INNER ANNULUS PRES ?????~? ~ SYSTEM AUTO ENTRY SCRATCH_32 OUTER ANNULUS PRES ??????? ~ BOTH C/~ • • _ __ _ ~ KUP ~ 3N-02A ~ ~ ~ Well Attributes ___~_~Max An le 8 MD 'TD ^~ ConocoPhillips 1I g """'""'''' ~' .. / ! ... ..r, o~rr ~,.rr~r,,, r,e,e name ..r:,,,.~.~. ,,,~„ , ~,~,,.~o, 500292152701 KUPARUK RIVER UNIT PRODUCING 50.47 4,100.00 ..~. ~.,,,,,.~~, 8,898.0 Comment H3S (ppm) Date Annotation End Date KB1ird (R) Rig Release Data ° TRDP 120 12/19/2008 SSSV 38.78 1/28/1986 N ii oq~re arv ozn i s rre aric ~sr~oro toss ti I ai ,a3 nM . A .~, ,., ~ Depth (RKB) End Dato Annotation Last Mo d... End Date Lasl' .~- 13LM 8,579.0 7/10/2009 Rev Reason: GLV C/O - Imosbor 11262009 - Casing Strings ~ - _ 3 i ~ on g String 0.. . Stnng IL ... Top (RKeI Set Depth {L.. S al Depth (TVDI .. String Wt .. tr ng ... String Top Thrd HANGER, a2 ~ ~ CONDUCTOR 16 15.062 38.0 60.0 60.0 62.50 H-40 ` ` ~ Casing Deacr4pdon String 0.. . String ID ... Top (RKB) Set Depth (L.. S et Depth INDI ... String Wt... String ... String Top Thrd "" "- SURFACE 95/8 8.765 37,0 4,544.8 3,574.5 36.00 J-55 j Casing Description String 0.. . String ID ... Top (RKB) Set Depth (f... S et Depth (ND) ... String Wt... String ... String Top Thrd ~' '+ PRODUCTION 7 6.151 35.0 8,890.0 6 673.5 26.00 J 55 BTC ~ 1 Tubing Strings _ _ -- - -- coNDUCroR. F I Tubing Description String 0... IString ID ... Top (RKB) Se[ Depth (f... Set Depth (TVD) St 'ng Wt... St -ng .. String Top Thrd TUBING 2 7/8 2.447 32 5 8 506.3 6 369.9 C.50 I J 55 EUE 8rd AB ~ 38-80 l 1 _ _ MOD _____. sAFErvvl.v, ~ Com letion Details 1,783 ~ T Top Depth - - ~-~ ~--~ { i (ND) Top Inel Nomi... GAB LIFT, r~~ ~~ Top (RKB) (RKB) (°) I tem Descriptio n Comment ID (in) 2,537 ~ ~_ 32 5 32 5 37 H 0 ANGER FMC Tubing Hanger w/Pup 2.441 : . . . 1,782.8 1,702.0 34.85 S AFETY VLV Baker FVL SSSV 2.310 8,276.9 6.188.0 37.44 P BR Brown PBR w/ 4.09' Pup 2.500 GAS LIFT, 8,292.7 6,200.5 37.46 P ACKER Brown HB-1 Pkr 2.441 as3s ", L-~ 8,486.0 6,353.8 37.58 P ACKER BrownlBPkr 3.250 '~__ _-? 8,498.1 6,363.4 37.58 N IPPLE 2 7/8" CAMCO'D' Nipple (2.2501D) 2.250 SURFACE I ~ 8,505.6 6,369.3 37.58 S OS 2 7/8" CAMCO Shear Out Sub (Pinned for 3500) _ 2.441 , 37415 i Other In Hole j _ __ _.. Wirehne retrievable lu s, valves1 pumps, fish, etc.) _ _ _ Top Depth - -- -_ GAS LIFT, ~" ~ ` (ND) Top Inel 5,588 ~y i To (RKB) (RKB) (°) Desert lion Comment Run Date ID (in 7,819 5,825.0 37.74 P ACKER 2.24" WEATHERFORD ER UPPER PATCH PACKER 10/30/2009 1.460 GAS LIFT. ~ 7 g21 826 5 6 37 73 P ATCH SPACER PIPE/SNAP LATCH SEAL STINGER 10/30/2009 1.613 6,058 , , . . , 7,848 5,847.9 37.70 P ACKER --~ 2.24" WEATHERFORD ER LOWER PATCH PACKER -- _ ~_-- 10/26/2009 1.320 GAS LIFT, r ~~ 6,525 ' PerfOra tlOrt$ 8, S101S _ - I _..____ - _.. Shot GAS LIFT. - Top (ND) Btm (ND) Dens 6,993 ~ ~ Top (ftK8) Btm (RKB) (RKB) (RKB) Zone Date (ah••• Type Comment I 8,446 8,458 6,322.1 6,331.6 C -1, UNIT B, 4/18/1986 12.0 IPERF 5" HJ II Csg Gun GAS LIFT, 7 az7 ~ ' ~ 3 N-02A , L f -~ 8,564 8,584 6,415.6 6,431.5 A -3, 3N-02A 426/1990 6.0 APERF 0 deg. phase, 21/8" Dyna Strip PACKER, 7,819 ~ 8,575 8,576 6,424.3 6,425.1 A -3, 3N-02A 4/18/1986 1.0 IPERF 4" HJ II Csg Gun - I 8,579 8,580 6,427.5 6,428.3 A -3, 3N-02A 4/18/1986 1.0 IPERF 4" HJ II Csg Gun PATCH, 7.fizt _ 626 6 439 4 6 464 7 A 8 594 8 3N-02A -2 4/18/1986 4 0 IPERF 4" HJ II Csg Gun 90 deg. phase GAB LIFT, L , . , , , . , , . , 7,832 Notes: General & Safety ____ ____ Entl Date Annotation PACKER, 7,848 ~~~-KM~- yt/1986 NOTE: WELL SIDETRACKED _ j -~ 4/142006 NOTE: TUBING IS CORKSCREWED, BE AWARE FROM 5000' RKB DOWN GAB LIFT, ' ~ 4262006 NOTE: WAIVERED WELL IAxOA COMMUNICATION 8,238 ~~ ~ s,."_ 6282009 NOTE: UNABLE TO WORK 1.7"THROUGH RESTRICTION 8181' PBR, 8,277 722009 NOTE: VIEW w/Alaska Schematic9.0 (2 pages) PACKER, 8,293 GAS LIFT, ~~ ~~ ~ 8,331 ~ GAS LIFT, ~ i 8.399 ~ II 4_ .~~ IPERF, 1 1 8,44G8,458 = i I GAS LIFT, 8,472 1 ~~ i Locator SUb, 8,485 ---. PACKER. 8,486 -~ _ J i NIPPLE, 8.498 ~ ~ TUBING PUP, .~ + 8,500 506 BOB 8 r - '~ , , ~ Mandrel Details __ _ _ I APERF Top Depth Top _ Port , 8,564A,584 ~~ (ND) Inc! ` OD Valve Lateh Size TRO RUn IPERF, Stn To (ttKBI (RKB) ( ) Make Model (in) Serv Type Typa Iinl (pail Run Date Com... 8,575A,576 1 2,536.8 2,251.2 46.56 Marla TMPD 1 GAS LIFT GLV BK 0.156 1,348.0 11/82009 IPERF 2 4,536.5 3,568.9 48.44 Meda TMPD 1 GAS LIFT GLV BK 0.156 1,331.0 11/82009 , e,57s-6.sfio 3 5,588.0 4,253.0 48.51 Marla TMPD 1 GAS LIFT GLV BK 0.156 1,314,0 11/82009 4 6,058.1 4,565.8 48.31 Marla TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/18/1986 P RF 5 6,524.9 4,879.1 46.62 Marla TMPD 1 GAS LIFT GLV BK 0.188 1,336.0 11!82009 , I E 8,5946,626 6 6,992.7 5,204.6 44.85 Marla TMPD 1 GAS LIFT DMV BK 0.000 0.0 4/62004 7 7,427.5 5,523.4 42.04 Marla TMPD 1 GAS LIFT OV BK 0.250 0.0 11/8/2009 8 7,832.2 5,835.4 37,72 Marla TMPD 1 GAS LIFT Patch 0.000 0.0 10/16/2009 Patch 9 1 8 238 157 2 6 37 40 McMu 1 GAS LIFT DMY RK 0.000 0.0 10242009 PRODUCTION, , . . , . ... 3s-e.89o 10 8 330 7 6 230 7 37 50 Marla TMPD 1 PROD OPEN 0.000 0.0 10/202009 TD (3N-02A), , . , . . 8,898 _ ,-. ConotoPhillips ~ ~ ,~ • Well Canfla_ - 3N-02A. 1 1 262009 1 0:53:43 AM Scbemal~c -Actual HANGER, 32 ~' F. ' i } k ~._, J CONDUCTOR, ~ ~ 3&80 SAFETY VLV, ~' o 1,783 GAS LIFT, f ~~ 2,537 } GAS LIFT, 4,536 L?I ~-,..! SURFACE, I I 1 37-4,545 ~ I I GAS LIFT, ~ 5,586 ~__~ GAB LIFT, 6,058 ~ ~~ ~ GAS LIFT, ~ ~~--2 6,525 ~_,~, I GAS LIFT, 6,993 I y-` GAS LIFT, 7,427 r ~~~ PACKER, 7,819 [~- ..~ 't+`p~ ~ PATCH, 7,821 ~ ~~ GAS LIFT, i I 7,832 ~_~ 1 r PACKER, 7,848 t~_3+1 ' GAS LIFT, L ~Y 8,238 ~ _.~', PBR, 6,277 ~ ~' ~__i PACKER, 8.293 ~- -~ GAS LIFT, I 8,331 ~_ GAS LIFT, e.39s -,1- i ~_,~ 7 IPERF, 8,446-8,458 ', L1 GAS LIFT, 8,472 ~ ~ Locator Sub, , B,4B5 PACKER, 6,486 + NIPPLE, 8,498 4 TUBING PUP, } 8,500 r -., SOS, 8,506 ~ ~ IPERF, 8.579-8.580 IPERF, 0,594-8,626 PRODUCTION, 35-8.890 TD (3N-02A), 8,898 KUP Mandrel Details Top Lrrylh i ep (ND) Incl Stn Too INKRI (RKB) (~) 3N-02A r 38.78 I 1/28/1986 Sarv TYPa iYPe (10) TR pBRI -- -- - -- - - - - - =- iECEIVED r � DEC 0 R Wl; —, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Gil & Gas Cons. CO'm lssic5 i REPORT OF SUNDRY WELL OPERATIONS pncn°fage 1.Operations Performed: Abandon ❑ Repair Well ❑✓ Plug Perforations ❑ Stimulate ❑ Other 0 Set tubing patch Alter Clising ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter S pended Well ❑ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory ❑ 186-032/ 3. Address: Stratigraphic ❑ Service ❑ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029- 21527 -01 KB Elevation (ft): Well Name and Number: RKB 6T 3N -02A Property Designation: 0. Field/Pool(s): ADL 25521 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8898' feet true vertical 6680' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 47' 16' 80' 80' 1640 630 SURFACE 4512' 9 -5/8" 4545' 3575' 3520 2020 PRODUCTION 885T T' 8890' 6674' 4980 4330 Perforation depth: Measured depth: 8446 -8458, 8564-8584, 8575 -8576, 8579- 8580, 8594 -8626 true vertical depth: 6322 -6332, 6416 -6431, 6424 -6425, 6427 -6428, 6439 -6465 Tubing (size, grade, and measured depth) 2 -7/8 ", J-55, 8506 Weatherford ER Patch (2.24 ID) from 7819-7850' RKB 'ackers & SSSV (type & measured depth) Packer = Brown HB -1 at 8293' RKB SSSV = Baker FVL at 1783' RKB 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mof Water - Bbl Casing Pressure Tubin a Pressure Prior to well operation Subsequent to operation - 14. Attachments . Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development 0 Service ❑ Daily Report of Well Operations X Well Status after work: Co Gaso WAG[] GINJ ❑ WINJ ❑ WDSPL ❑ 17.1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Printed Name Martin Walters Title: Problem Wells Supervisor Signature Phone: 659 -7224 Date: 12105/09 8wared by Me Wallas 659.7224 1Z /a• Form 10404 Revised 04/2006 Submit Original Only 3N -02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/26/2009 2.24" WEATHERFORD ER PACKER SET WITH MID - ELEMENT AT 7850' CORRELATED [ TO HES LDL DATED 13 JUL 2009. PT LOWER ELEMENT ER PACKER @ 7850' ELM. SET 2.24" UPPER ER PATCH 10/30/2009 ASSEMBLY. BLEED IA TO 380 PSI FOR 1000 PSI DIFFERENTIAL; PATCH APPEARS TO BE HOLDING SOLID. COMPLETE. 111612009 ISET CATCHER SUB ASSEMBLY @ 7819' RKB. IN PROGRESS. 11/7/2009 PULLED GLVs @ 4536',6525',7427', AND DV @ 5588' RKB. SET GLVs @ 4536' AND 5588' I RKB. IN PROGRESS. 11/8/2009 PULLED GLV @ 2537' RKB. SET GLVs @ 2537', 6525', AND OV @ 7427' RKB. PULLED CATCHER SUB @ 7819' RKB. COMPLETE. ReTIFL - Passed, Initial T /I /O= 200/1300/560. Shot initial IA FL @ 7427' (Sta #7 OV). Shut in 11115/2009 well and gas lift, stacked out tubing with lift gas, T /I /O= 1025/1100/450. Bled IA down and shot 2nd IA FL @ same location. Final T /I /O= 1075/410/350. Summary Set Weatherford ER Patch (2.24" ID) from 7819'- 7850' RKB. Ran new gaslift design and conducted passing ReTIFL. I WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 5, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3N -02A Run Date: 10/26/2009 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 3N -02A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 21527 -01 t fi kjED, N O l 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto f (o 6900 Arctic Blvd. Anchorage, Alaska 99518 t6(� Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto 1 alliburton.opnt__ Date: `t 200 Signed: ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3N-02A Run Date: 7/13/2009 September 4, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-02A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21527-01 . r;=~F:,~.. ~~_ ,tI ~µ 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.barreto@halliburton.com Date: - r~~ ~~~~ ~ ~ ~~s~ .~ ,~ ~ j' , j •~ ~E Signed: ~ i ~', ~ ~ ~ • Memary Multi-Fing~r Cafiper S Lo Resui~ ~umma , 9 ~l Company: ConocoPhillips Alaska, Inc. Weli: 3N-02A Log Date: August 16, 2009 Field: Kuparuk Log No. : 10583 State: Alaska Run No.: 1 API No.: 50-029-2~527-01 Pipe1 Desc.: 2.875° 6.51b. J-55 EUE 8RD ABMOD Top Log {nfirl: Surtace Pipe1 Use: Tubing Bot. Log Intvi: 8,935 Ft. (MD) Inspection Type : Patch CandidacyAssessment COMMENTS : This catiper d~ta is tied Into the hottom of the tubing tafl @ 8,935' (Driller's Depth). This log was run to assess the condition of the tubing in the vicinity of GLM station #8 witn respect to corrosive and mechanical damage to determine potential for patching operations. The caliper recordings indicate the 2.875" tubing logged is in good condition. No significant wall penetrations, areas of cross- sectional wall loss or I.D. restrictions are recorded throughout the log interval. A 3-D iog plot of the caliper recordings across GLM station #8, the proposed patch interval, is included in this report. MAXiMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 18%) are recorded throughout the 2.875" tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross$ectional wall loss (> 6°~) are recorded throughout the 2.875" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significar~t I.D. restrictions are recorded throughout the 2.875" tubing logged. ._ ` ~r " ~, ~~~'n ~~ ;~,t~.:~~~~':,~ U E.1 t~ ..~ v.~ Field ~ngineer: G. Efherton Analyst: M. Lawrence Witness: C. Fitzpatrick PraActive Diagnostlc Services, Inc. ! P.O, B~x 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~c memorylog.cam Prudhoe Bay Field Office Phone: (907) 659~2307 fax: (907) 659-2314 i~'f~~~ I~z~~ - • • PDS Multifinger Caliper 3D Log Plot ~, - ,~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3N-02A Date : August 16, 2009 Description : Detail of Caliper Recordings across Proposed Patch /nterval at GLM #8 • • Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 2.875 in (-11.2' - 8435.5') Well: 3N-02A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 16, 2009 ~ A pprox. Tool De viaUon ~ iA ppro~. (ic~rc~ix~ l~~ I'rc~fil ~~ 1 t3 75F~ I 52 i 2306 GLM 1 3082 ~ ~ 3852 " ~ c GLM 2 . ~ Ac p 'FlJ2V ~ ~ 5397 GLM 3 GLM 4 6184 GLM 5 GLM 6 6959 GLM 7 GLM 8 7739 GLM 9 ~~~ ~Q 271 8436 0 5 0 1 00 Dam age Pr ofile (°/a wall) / Tool D eviatio n (degr ees) Bottom of Survey = 271 1 25 50 75 100 v 125 ~ E ~ Z _~~ Y [ ~ ~ JO ~ 175 ' ' :..~ ' ~ - 200 • • PDS Report Overview ~~, sw Body Region Analysis Well: 3N-02A Survey Date: August 16, 2009 Fieid: Kuparuk Tooi Type: UW MFC 24 No. 212330 Company: ConocoNhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of fingers: 24 Ana) st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 >f -55 EUE 8rd AB MOD 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 200 150 100 50 ~ 0 to 1 to 10 to 20 m 40 to over 1% 10% 20% 90% 85% 85% Number of ~oints anal sed total = 2 76 pene. 4 150 122 0 0 0 loss 147 129 0 0 0 0 Damage Configuration ( body ) 30 ZU 10 0 isolatF~~1 ;~,r•n<~nl line ri~5 hole / poas pitting corrosion corrosion corrosion iblehole Number of 'oints dama ed total = 35 27 7 1 0 0 Damage Profile (% wall) ~ penetration body ~ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 CLM 5 GLM 6 GLM 7 GLM 8 GLM 11 Bottom of Survey = 271 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8rd AB MOWeII: 3N-02A Body Wali: 0.217 i~ Field: Kuparuk Upset Wail: 0.217 in Cornpany: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 16, 2009 Joint No. Jt. Depth (Ft.) I'c~n. UFx~~t (In~.) Pen. Body (Ins.) I'c~n. % Mcl,~l Ic~s~ °~t~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -11 u 0.01 3 ; 2.42 PUP .2 -7 t~ 0.01 ~ -3 239 PUP .3 4 u 0. 1 s ; .41 PUP .4 10 i~ 0.02 1~) 2.37 PUP 18 t) 0.02 1 1 . 8 2 49 ll 0.03 11 ' 2.38 3 81 ~) 0.02 1 1 ~ 2.41 4 112 ~~ 0.02 1u o 2.39 5 143 t~ 0.0 12 ~~ 2.38 6 175 U 0.0 ~) t~ 2.39 7 206 (~ 0.02 ( 1 -3 2.37 8 236 U 0.03 13 ~ 2.39 9 265 i~ 0.03 I~ ~ 2.39 10 296 l~ 0.02 ti -1 237 11 327 u 0.02 ~~ 2.41 12 358 l~ 0.02 Ei t, 2.40 13 389 i) 0.02 ~) 2.40 14 421 ~~ 0.03 1? S 2.37 15 450 (~ 0.03 14 ~ 2.39 16 480 ~ ~ 0.02 ~) ~> 2.40 17 511 ~~ OA ft I 2.37 18 542 t 1 0.01 2.40 1 573 U 0.02 9 t 2.42 20 604 lt 0.02 t3 Z 2.38 21 6 l~ 0. 2 1 1 ; .39 22 664 U 0.03 11 > 2.38 23 695 U 0.0 1~ -1 2.38 24 725 t~ 0.02 lU 5 237 25 756 i~ .02 1 I -1 2.39 26 787 r~ 0.01 (> ~~ 2.39 27 817 t~ 0.02 ~~ 5 2.41 28 847 t~ 0.01 6 2.40 29 F377 ~~ 0.02 ~~ -1 238 30 908 ~~ 0.02 ~) ~~ 2.42 31 940 ~~ 0.~3 I~' ~ 2.39 32 971 (~ 0.02 ~) -~ 2.40 33 1002 ~~ 0.02 1l) ~3 2.39 34 1032 ~~ 0.02 ~~ ~~ 2.41 35 1064 ~> 0.01 ~3 238 36 1094 ~~ 0.02 '> ~~ 2.39 37 1126 u 0.01 (~ _' 2. 38 1157 ~ t 0.03 12 i 2.38 39 1187 t~ 0.02 11 Z 237 40 1218 ~ 1 0.04 1 i (, 2.39 Shallow corrosion. 41 1249 l~ 0.03 1 Z ~ 2.39 42 1280 cl OA2 11 -~ 2.40 43 131 1 U 0.07 (~ ~~, 238 44 1342 ~ ~ 0.02 ~> ~ 2.39 45 1372 i 0.03 I_' 2.38 46 14{)3 ~ 0.03 I' ~ 2.37 ~Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8rd AB MOWeII: 3N-02A Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Co~mtry: USA Survey Date: August 16, 2009 Joint No. Jt. Depth (Ft.) I'~~n. ~ ~E~s~~l Ilrn.) Pen. Body (Ins.) I'~~n. °/, ~1ci,~l L~~ss ~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1433 ~1 0.03 14 t, 2.39 48 1462 l1 0.03 15 2.37 Shaflow corrosion. 49 1 92 u 0.03 13 ~~ 2.33 Shallow itfin . 50 1523 i~ 0.01 ~ -t 2.39 51 1555 U .02 9 ' 2.40 52 1584 c~ 0.02 ~) s 2.42 53 1615 i1 OA2 ~) ~ 2.37 54 1646 i~ 0.02 ~~ 2 39 55 1676 ~~ 0.03 1-1 i~ 2.38 56 1706 u 0.02 1 U "~ 2.39 57 1736 (~ 0.02 t 1 238 58 1767 u 0.03 1 5 (~ 2.38 Shallow corrosion. 58.1 1797 t1 0 ll i1 231 SSSV 9 1809 U 0.04 1 ~ 6 2.39 Shallow corrosion. 60 1840 ~1 0.02 t~ t, 238 61 1871 u 0.01 3 u 2.40 62 190 ~1 0.01 3 t~ 239 63 1933 l~ 0.01 4 b 2.40 64 1 64 u 0.02 1 U > 2. 8 65 1994 ~ ~ 0.01 ~ ' 2.38 66 2026 ~~ 0. I i~ ~~ 2.41 67 2057 ~~ 0.01 ~3 6 2.41 68 2088 t~ 0.01 6 5 2.41 69 2119 ~~ 0.01 ~~ 6 2.41 0 2150 0 0.01 (, ~s . 1 71 2181 ~) 0.02 ~i 6 2.41 72 2212 ~) 0.0 3 ~ 2.39 73 2244 l) O.D1 6 5 2.40 74 2275 ~~ 0.02 11 I 239 75 2306 t) 0.01 7 t~ 2.40 76 2336 (1 0.01 6 3 .41 77 2367 u 0.00 1 4 2.39 7$ 398 O 0.01 3 ~1 2.41 79 2429 (1 0.01 3 1 2.37 80 2461 ~) 0.01 E~ -~ 2.39 81 2492 c~ 0.02 Il) 1 238 81.1 2523 t~ 0 ~~ (1 N A GLM 1 atch ~ 3:00 82 2 52 9 (~ 0.01 6 -~ 2.40 83 2560 ~~ 0.01 3 1 2.38 84 2591 U 0.04 1 t3 I 2.38 Shallow ittin . 85 2622 l~ 0.02 1 1 -1 2.40 86 2653 U 0.01 6 4 2.41 87 2683 ~~ 0.01 ~ I 2.41 88 2714 U 0.03 13 (~ 2.41 89 2 744 u 0.01 6 ~_' 2.41 90 2775 U 0.02 9 ,' 2.41 91 2805 t) 0.03 12 5 239 92 2836 U 0.01 6 (~ 2.41 93 2867 ~~ 0.01 t~ 2.41 94 2898 ~ ` 0.00 ~ ~ 2.39 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 LUE 8rd AB MOWeII: 3N-02A Body Wail: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 16, 2009 Joint No. Jt. Depth (Ft.) f'c~n. UE~sF~r (In,.j Pen. Body (Ins.) I'c~n. % Mc~t,il Loss °~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 SO 100 95 2929 U 0.01 ; I 2.39 96 2960 0 0.02 ft ' 2.41 97 2990 ~1 0.01 4 ,' 2.40 98 3020 t) 0.01 ; I 2.40 99 3052 U 0.01 ~ 2.40 100 3082 t~ 0.01 (> ; 2.40 101 3114 i? 0.02 I~~ _' 2.38 102 3'145 U 0.02 ~~ _' 2.3F3 103 3176 (~ 0.02 ') ? 2. 104 3 06 ~~ 0.02 9 ~3 2.39 1 5 3237 U 0.01 i Z 237 106 3268 l~ 0.02 ti ~~ 2.35 107 3299 ~~ 0.01 t> 2.37 10 3329 tt 0.02 ti 1 2.37 109 33 9 ~l 0.03 I-l 2.39 110 390 U 0.02 `> 239 111 3420 l~ 0.03 I_' I 238 712 3452 t) 0.01 -1 2.40 113 3483 u 0.04 I~i 1 2.35 Shallow corrosion. 114 3514 U 0.02 9 1 2.36 115 3544 t~ 0.04 1 ~ ? 2.38 Shallow corrosion. 116 3575 U 0.01 b I 2.38 117 3606 U 0.03 13 1 2.38 118 3638 t> 0.02 ') (~ 2.38 119 668 u 0.03 13 2 235 120 3699 ~~ 0.02 ~) (~ '1.40 121 3729 ~~ 0.04 17 ~' 2.36 hallow ittin . 122 3760 (~ 0.01 7 1 238 123 3790 (~ 0.02 IO U 2.37 124 3821 (~ 0.01 (~ 2.37 125 3852 ~~ 0.00 I 238 126 3883 n 0.02 t~ u 2.38 127 3914 t~ 0.01 -1 _' 2.38 128 3945 ~~ 0.01 t~ I 238 129 3973 U 0.00 1 (~ 2.37 130 4004 ~~ 0.0 1 U Z 2.40 131 4035 U 0.02 ~) 4 2.40 132 4066 t~ 0.01 7 I 239 133 4096 (~ 0.03 1 Z 2.39 134 4128 ~~ 0.02 t9 1 2.40 135 415 ~) 0.01 ~1 i i 2.38 136 4190 t? 0.02 ti -1 2.39 137 4219 u 0.03 15 I 238 138 4251 U 0.02 ti I 2.37 139 42 2 t1 0.01 7 ~1 .38 140 4313 ~~ 0.02 ~) u 2.38 141 4344 ~) 0.03 I~ ~ 238 142 4374 U 0.01 6 ~ 2.39 143 4 ~~ 0.04 1; 2.37 Shallow co rosion. 144 4435 11 0.01 i I 2.39 Penelration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf )-55 EUE 8rd AB MOWeII: 3N-02A Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 16, 2009 Joint No. )t. Depth (Ft.) I'~~n. i lFrsc~t ~1n~.) Pen. Body (Ins.) Pen. % :'vlet~il I oss °~<, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4466 ~~ 0.01 5 ~~ 2.38 146 4496 t~ 0.01 ; ' 2.38 146.1 4528 ~~ 0 i1 ~) N A GlM 2 Latch ~ 8:00 147 4534 U 0.0 6 I 2.39 148 4566 ~~ 0.01 7 t 2.38 149 4597 ~~ 0.01 3 ~' 2.37 150 4628 U 0.01 ~~ t~ 2.37 151 4659 u 0.02 11 I 2.38 152 4689 t~ 0.01 6 u 2.36 153 4720 ~~ 0.03 12 3 2.36 154 4750 ~~ 0.01 4 ~? 2.38 155 4781 t~ 0.01 I 2.38 156 4813 t~ 0.03 12 I 2.38 157 4843 ~> 0.02 £3 I 2.38 158 4874 t~ 0.01 ~1 1 2.36 159 4905 ct 0.01 ~ I .36 160 4936 l) 0.02 11 ~s 239 161 4966 ~> 0.02 8 ~~ 2.38 16 4997 t~ 0.01 6 I 2.37 163 5028 c) 0.02 9 2.38 164 5059 u .02 1 u ~~ 2.36 165 5089 i~ 0.02 I t? I 2.37 166 5120 ~~ 0.01 ti 1 2.3 167 5151 t~ 0.02 8 I 239 168 51 3 U 0.01 i; ~! 2.37 169 5214 l~ 0.02 ~~ I 2.38 170 5244 ~! 0.01 !? 2.37 171 5274 (1 0.02 1~) ~~ 2.37 172 5305 c~ 0.01 G I 237 173 5337 ~~ OA2 1~) I 2.35 174 5367 c~ 0.01 E, I 2.37 175 5397 ~ ~ 0.02 1 U ' 2.36 176 5428 t~ 0.02 7 t) 2.36 177 5458 u 0.02 11 U 238 178 5489 O 0.01 6 ~) 2.38 179 5520 ~l 0.02 11 ~) 238 180 5551 (1 0.01 4 ' 2.39 180.1 5583 ~1 0 i~ i~ N A GLM 3 Latch ~ 7:30 1 1 5589 i~ 0.0 12 ~~ 2.36 182 5620 U 0.02 1 U u 2.38 183 5651 ~~ 0.02 11 U 236 184 5680 t) 0.02 1(~ 1 2.36 185 5712 U 0.03 1~~ ~) 2.38 186 5743 U 0.02 11 1 2.37 187 5775 ~1 0.02 ~3 I 2.37 188 5805 i~ 0.02 I il I 2.37 189 5836 11 0.02 Il I 2.3E3 190 586$ U 0.02 11 (1 2.37 1 1 5899 ~~ 0.02 10 U 237 192 5930 U 0.01 7 U 2.35 Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEEf Pipe: 2.875 in 6.5 ppf J-55 EUE 8rd AB MOWeII: 3N-02A Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 16, 2009 Joint No. )t. Depth (ft.) N~~n. llp,c~t ~In~.~ Pen. Body (Ins.) Pen. `7<> Mct,~l I~„s °'~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 193 5962 ~~ 0.02 ~) l~ 2.37 194 5991 U 0.01 G t) 2.38 195 6022 c~ 0.01 7 1 2.39 145.1 6054 ~1 0 l~ ~~ N A GLM 4 Latch ~ 7:30 196 061 t) 0.03 11 1 38 197 60 1 t~ 0.0 1t1 I 237 198 6122 ~~ 0.02 1 I I 2.37 199 6153 i? 0.02 1 1 I 2.38 200 6184 ~? 0.02 ll 2.38 201 6 15 ~~ 0.03 I i u 237 202 6247 U 0. 2 11 ~) 2.36 203 6278 l) 0.02 1t) t~ 2.38 204 b308 U 0.02 11 U 236 205 6338 U 0.02 1 u 1 2.37 206 6369 U 0.03 1" u 2.37 207 6400 i~ 0.02 1 l) 1 2.3 208 6430 c) 0.02 I1 I 2.37 09 6461 U 0.02 1 U ~~ 2.36 210 6490 U 0.03 13 U 2.35 210.1 6522 t~ 0 0 ~1 N A GLM 5 Latch ~ 12:30 211 6529 tt OA2 1~l ~l 2.36 12 6560 U 0.02 1 1 ~ 1 2.36 213 65 0 t) 0.04 1' U 2.36 S Ilow ittin . 214 6622 (~ OA2 11 ~~ 2.36 215 6~ 53 ~ ~ 0.03 I_' ~~ 2.36 216 6683 ~~ 0.03 1_' ~~ 236 17 6714 i1 0.03 14 l~ 2.36 218 6746 (1 0.02 11 1 2.36 219 6777 r~ 0.03 1? ~~ 2.37 220 6808 l~ 0.03 1-1 O 2.37 Shallow ittin . 221 6838 ll 0.03 12 O 2. 5 222 6868 ~~ 0.03 15 1 2.37 5hallow ittin . 223 6898 U 0.02 11 l~ 2.36 224 6929 u 0.03 1~ U 2.34 Shallow ittin . Lt. De sits. 225 6959 ~~ 0.03 1? I .37 225.1 6991 ~~ 0 U i I N A GLM 6 Latch ~ 1 1:00 226 6998 U 0.02 1I I .36 227 7028 l) OA2 1~I U 2.37 228 7059 U 0.03 I Z ' 2.38 229 7088 i~ 0.03 14 1 2.37 Lt. De osits. 3 7118 t) OA2 II I 2.3 231 7149 U 0.02 I(1 (i 23 232 7180 t? 0.02 It) i~ 2.37 233 7209 t~ 0.03 1; t~ 2.37 234 7241 U .0 13 I 236 235 7271 U 0.03 13 I 2.37 236 7302 t~ 0.04 1 ~ ~~ 236 Shallow it i. 237 7333 ~1 0.02 11 I 2.37 238 7363 ~? 0.03 14 U 2.37 239 7394 ~~ 0.01 7 I 235 Penetration Body Metal Loss Body Page S ~ • PDS REP~RT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8rd AB MOWeII: 3N-02A Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 16, 2009 Joint No. Jt Depth (Ft.) I'~~n. l l~~~c•i ~In..) Pen. Body (Ins.) Nc~n. °r~ ~ic~t,~l I~~ss ~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 239.1 7425 i~ 0 l1 U N A GLM 7 L tch ~ 11:30 240 7433 U 0.0 12 1 2.36 Shallo ~ttin . 241 746 T ~ ~ 0.03 14 i~ 2.35 Shallow itti . 24 7493 t ~ 0.03 15 U 2.35 Shall w ittin . 43 752 ~) 0 03 14 I .36 Shallow ittin . L. De sits. 244 7553 U 0.03 4 I 236 Shallow ittin . Lt. D sits. 245 7583 U 0.03 1 t I 2.35 Shallow ittin . l.t. De sits. 246 7616 t> 0.03 15 I 2.3£3 Shallow ittin . 247 7644 U 0.03 1~l I 2.34 248 7677 ~~ 0.03 I Z I 2.38 249 7708 ~1 0.03 1 t I 2.36 Shallow ittin . 250 7739 U 0.02 11 I 2.36 Shallow ittin . 251 7769 ~i 0.03 I2 I 2.37 252 7801 ~1 0.03 14 I 2.37 Shallow ittin . 252.1 7831 l1 0 U U N A GLM 8 Latch ~ 8:00 253 7836 ~~ 0.03 14 I 237 Shallow ittin . 254 7867 U 0.03 1~ t~ 236 Lt. De osits. 2 5 7898 U 0.01 6 1 2.37 256 7928 t) 0.03 14 U 2.37 Lt. De osi . 257 7960 U 0.03 l:i 1 237 Shallow ittin . 258 7992 t~ 0.03 I 2 ' 2.35 Shallow ittin . Lt. De sits. 259 8022 ~~ 0.03 13 ~~ 2.34 Lt. De osits. 2 0 8053 (1 0.03 l i I 2.37 Shallow ittin . Lt. De sits. 261 8084 ~~ 0.02 11 I 2.36 262 81 14 ~? 0. 3 13 1 .33 Line shallow c rrosion. Lt. De osits. 263 8144 ~1 0.04 17 1 2.36 Shallow ittin . Lc De sits. 264 8177 ~~ 0.03 I i 1 2.34 Shallow ittin . Lt De sits. 265 8205 U 0.02 11 3 2.40 Shallow ittin . 265.1 8238 U 0 U U N A GLM 9 Latch ~ 130 266 8246 l1 0.02 I1 1 .37 266.1 8275 ~~ 0.01 ~i _' 2. PUP 266.2 E3279 i~ 0 ~~ ~~ 2.50 Brown PBR 2663 8289 U 0 O U 2.44 Brown HB-t Packer 267 8297 n 0.03 1 i 1 233 Shallow ittin . Lt. De sits. 267.1 8329 t~ 0 tl t~ N A GLM 10 Latch 430 268 8337 ~~ 0.03 14 U 235 Lt De osits. 269 8367 U 0.03 14 U 235 269.1 8399 i~ 0 l) ~1 N A GLM 11 Latch ~ 830 270 8404 ~~ 0.03 1 i I 2.36 Shallow ittin . Lt De sits. 271 8436 ~) 0.03 12 1 2.37 Nenetration 6ody Metal Loss Body Page 6 ~~~ KUP ,~ 3N-02A ~OP10C0~'II~~Ip S ^ U Attribu6es A le 8 N~ TD ,11~~i~hn.l ~ iu I e116oreARNWI 50029215270~ f1Ad ane W 8tatuc Ind~•) KUPARUK RIVER UNIT PROIXJCIN6 50.47 ND B~ 4.100.00 Act 8.898.0 - Commpk H2E~pp'ry SSSV:TRPD 120 Date 12/192008 Anndatlon 6itlDate 1~-p'U(tt) 3878 RlgRekauDete 128/1986 . -3 c 9/Zn^..~ - a~y> _'__ -~ _._ na[al6on Dep1~ Ye ion LastNbtlBy te Last Tag~ SLM 8.579.0 7/102009 Rev Reason: TAG. SET PLUG. GLV C/O tnplwj 7/192009 Casin SUin s ca~os ~~ surg o... emB p... rov mKS~ sN o~m p... s e oepm frw~. s~.e,e wc.. a~ -. mn~ uv m.a ~ CONDUCTOR 16 15.062 38.0 80.0 - 80.0 62.50 H-40 HIWGER.37 CaS11gDe5CiiptlOn SURFACE _ 85B St~InBD... 8765 op 0.0 6B[ R._ 4,545.0 CepC~ 3,574.6 MR_ 36.00 S[M6... J-55 ~mDTOP ~ sing scripdon PRODUCTION _ 7 6I~Ng ... 6.151 ap DI 0.0 Set .' 8,890.0 6el ' 6,673.5 " 26.00 "' J-55 etARq ~ Tubin Strin s coNOUCroR. 38-80 ~ ntlwn9oes«iptlon TUBWG(QC) arppa.. 2718 SUInDID... 2.441 rovlltlC~ 32.5 R- 8,506.3 ae1DePN ... 6,369.9 iM~9 ... 6.50 stMg... J-55 st~InY aP a EUEBrdAB MOD sssv.,,e3 o Cpm le don Det ails GASUFf T~P~ aP ~M (Tw) ~ Top Mr! (7 h MID~lCfl~la ll CiWlmd! DI~ . zsa~ ` 32.5 32.5 0.37 H ANGER FMC Tubing Hanger w/ Pup 2.441 1.7B2.8 1.702.0 34.85 S SSI/ Bekei FVL SSSY 2.3'IO ~~ ~~~. 8,276.9 6.788.0 3.44 P BR ~o~n PBR w/ 4.09' Pup 2.500 a sss B. 92.7 6.200.5 37.46 P ACKER &wm H&1 Piv 2.441 suRrr,c~, IN Yi5 8.486.0 6,353.8 3Z58 P ACKER B~am 18 Pkr 3250 ~ 8.498.1 6.363.4 37.58 N IPPLE 7/8`CAMCO'D'Nipple (22501D) 2250 cas uFr, 5 SPB 8,505.6 6.369.3 37.58 S 2/8 CPMCO Shear Out SLb (Rnned fa 3500) 2.441 Other I n Hole reline ratrievable u flsh ~c GASLIR. 6p56 T 8 Top Deqh (ND) ~~ TopIfIG r) COIIl11dY NWID~! ID 8,498 6 363.3 37.58 P IUG SET CA-2 PLUG IN D NIPPLE 7N02009 0.000 G0.S LIF1. 6 575 P~~ A$ S ~t5 TOP~I ~~pIKB) TavIT'q O~I amlNq O~I ZOII! DYe Sllot ums ~~- 1~t COC1111A GASLIFT. s,ssa B,446 8,458 6.371.1 6,331.6 G 3 1. UNIT B, N-O1A 4/18/'1986 12.0 IPERF 5" HJ II Csg Gun GAS LIFT 8.564 8.584 6,415.6 6.431 S~ 43. 3NAZA 426N990 6.0 APERf 0 deg. phnse. 2 1B" Dyne Sfip , iAZ~ 8.575 8,576 6,4 4.3 6,125.1 A 3, 3N-02A 4/78/1986 1.0 I RF 4" HJ II Csg Gun 8,57 8.580 6,427.5 6,428.3 1 ~3, 3N-02A 4/18/1986 1.0 IPERF 4" HJ II Csg Gun ~ns uFr. ~ ess 0,594 8,626 6,439.4 6,464.7 h 2, 3N-02A 4/1B/1988 4.0 IPERF 90 deg. phase, 4" HJ II Csy Gun Notes: General 8 G/SLIFf, 8 238 Z/7/iBHG NOT ~WEILSI RACK , 17/15/1989 NO E MANDREL A ON(5) B&10 VALVES HAVE «< EXTENDED PACKING» > 4/142006 NOTE: TU&NG IS CORKSCREWED. BE AWARE FROM 5000' RKB DOWN aea, e.z» 4/262006 NOTE WAINERED LL WxOA COMMUNICATION PACS(ER, B 293 6282009 NOTE: UNABLE TO VNDRK 1.7' THGOUGH R TRICTION 8181' ~rzrzoos rrorE:wewwinusKnscH~+nncs.o GAS LIFT, 8 331 GAS LIFT 8:90 IPERF. 844GF458 GAS LIFT, enrz ~o~ca s~o, 8 h85 VA('NFH N1Hti PLUG, 8098 NIP7tE. B 498 ~ ~~(@~ ~~~$ TUBINGPUP. ~ T ~(~ opDep~ ~1vW ~d) Top tr~a ~ ~~ ~pp~ ou (Y1~ $~yy vave 7~e ~ma~ l~Q! Part s~~ (M moa~n ~Q R1~1~~! CppL_ e wo ~ 1 2,536.8 2,2512 46.56 Merle TMPD 7 GAS LIFT GLV K 0.156 1.356.0 4/74/2006 SVS.B$OB 2 4,536.5 3,568.9 48.44 Mats TMPD 1 GJ~S LIF'f GLV BK 0.188 1,380.0 4/142006 3 5,588.0 4,253.0 48.51 Merla TMPD t GAS LIFT DMY BK 0.000 0.0 4/18/1986 ~RF 4 6,058.1 4,565.8 48.31 Mede TMPD 1 GhS LI DMY 8K 0.000 0.0 4fl8/1986 8'~$ ~'6 IPERF. 5 6,524.9 4,879.1 46.62 AAeAe TMPD 1 GAS LIFT GLV &C 0.188 ~,3fi8.0 4/142006 6.5]58.576 6 8,9927 5,204.6 44.85 Merle D 1 G~AS LIFT DMV BK 0,000 0.0 Ai62 7 7,427.5 5,523.4 42.04 Aa PD 1 GAS LI GLV BK 0.250 1,463.0 4/742006 ~F~ e.s~sa.seo 8 7,832. 5,835.4 37.T2 Merle MPD 1 GlaS UFT DMY BK 0.000 0.0 7282009 ext Pk9 9 8,238.1 6,15Z2 37.40 McMu... 7 IIFT OV BK 0.250 0.0 1224l2007 IPERF, 10 8,330.7 6,230.7 37.50 MeAe TMPD 1 PROD DMY BK 0.000 0.0 1/42008 ext Pk9 8,5948.676 PfEOWC~ION. ~~ 8,399.1 6.284.9 3.58 AAerle i PROD DMY BK 0.000 0.0 12/15/1989 08'69D TD (3N-07A~. 12 8,472.1 6,342.E 37.57 Nbrle TMPO 1 PROD DMY BK 0.000 0.0 72/7511989 8.99B Sent'. Wed e day Junell24u 2009 9:5 @ Mnocophillips.com] ~Q~~ ~,~ ~~b 9 To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Probiem Well Supv; NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs; Glessner, Dana Subject: KRU 3N-02A (PTD# 186-032) Report of TxIA Communication Attachments: 3N-02A TIO Plot.pdf; Jim/Tom, ~ ~~ ~--~,i~ ~t?U~~d~~ ~ ~e ~;~~..s ~tt.~l r cu,,E~ c~ ~~-C~ ~lt;~- Kuparuk gaslifted producer 3N-02A (PTD# 186-032) is suspected of having TxIA communication based upon observed pressures during routine wellwork. A leaking gaslift valve is suspected so slickline wili troubleshoot and repair if possible. The well wiil be fixed or shut in by 07/20/09 and will be add to the SCP report. Attached are a wellbore schematic and 90 day TIO plot. «3N-02A TIO Plot.pdf» « - ;j Please contact me at your convenience if you have questions or comments. .,_ Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhiliips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~ r ' p~,~~ ~°: ~~~`'. t,~ v i',,~ ~,~ J'~~~.i ~. ~.i i :ti - J ~ ~~ 8/6/2009 ~~Izai~r P~ ~ `~6 -c 3~Z Well Name Notes: End Date 7 1 ~009 Days 120 Start Date 3 3-2009 Annular Communicaton Surveillance 1400 WHP - _------ 100 IAP OAP 90 1200 WHT - 80 1000 - - 70 60 800 LL ~Vl ~ 50 y a soa 40 400 _- _ 30 20 200 -- - -- - - - - - -- 10 0 0 Mar-09 Apr-09 May-09 Jun-09 - -~---- ~oo ~ ~DGI~~ -- ----- soo ~MGI I ~ aoo 0 pyy~ m ~SWI aoa ° ~BLPD aoo U ~ '~ ?(~ ~ C "_. _ . 100 - 0 ~ i `~ ConocoPh ~ I I ~ ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 1 ~' ~~~- Y~ f- ,3.N ~ o a- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRTJ}. 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 October 19, 2008 and the corrosion inhibitor/sealant, was pumped October 21, 2008..The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. I Sincerely, ,~~ ~ ~ ~ ~Q~~ MJ La eland ConocoPhillips Well Integrity Projects Supervisor • r~ L_J ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Hato 10/22/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4" 2" 10/19/2008 10.2 10/21/2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 09/15/08 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • ~~ Well Job # a~ +i~~il+.3~lrai; ~ ~~ ~ •~.r , s," . ~,s~ ~ s ~8 ~~~ Log Description NO, 4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD iC-172A 11978478 PRODUCTION PROFILE ~ ~- Q 08/19/08 1 1 1 C-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY 08/20/08 1 1 3C-17 11996657 SCMT ~ - /(n 9iL/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ~aO~S-p~~ IIOG/~~~' 08/27/08 1 1 2U-06 12080428 LDL _p( 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE ~ -O 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - j / Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE (p 09/05/08 1 1 iC-174 12096539 INJECTION PROFILE - ~- 0 09!07/08 1 1 2H-12 12096540 PRODUCTION PROFILE ~ 09/09/08 1 1 30-01 11975792 LDL ~-per 09/09/08 1 1 3F-10 11975789 LDL ~ 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 7, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~~~~ JAN ~ ~ 2~0~ A18Ska 0!1 ~ Cg's C~n~t ~~a-tt~rt+sSi~t .. Anchorage Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3N-02A PTD 186-032 surface casing starter head weld. - Please call Brent Rogers or myself if you have any questions. Sincerely, Martin Walters ~~~ JAN ~ ~ 204 Problem Well Supervisor • • Name of Recipient Page 2 of 2 O 1 /07/08 Delete the section break above to remove the second page ~ R~c~~vD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~AN O ,~ ~(~~$ REPORT OF SUNDRY WELL OPERATION,~_,._ h:, d ~,_. ~: .~ 1. Operations Performed: Abandon ^ Repair Well ^ ~ Plug Perforations ^ Stimulate ^ .Other ~~~ a~~n ~ Alter Casing ^ Pull Tubing ^ Pertorate New Pooi ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnocoPhillips Alaska, InC. Development 0 Exploratory ^ 186-032 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21527-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 6T ~ 3N-02A 8. Property Designation: 10. Field/Pool(s): ADL 25521 ~ ALK 2557 Kuparuk River Field /Kuparuk Oil Pool - 11. Present Well Condition Summary: Total Depth measured 8898' `' feet true vertical 6680' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 4478' 9-5/8" 4545' 3575' PROD. CASING 8823' 7" 8890' 6673' Perforation depth: Measured depth: Intervals from 8446' to 8626' true vertical depth: Intervals from 6332' to 6465' Tubing (size, grade, and measured depth) 2_7/g~~, J_55, 8506' MD. Packers &SSSV (type & measured depth) pkr= BROWN 'HB-1' ; BROWN '1 B' pkr= 829 3' ; 8486' SSSV= Baker'FVL' SSSV= 1783' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OiIO ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name nt Rogers Title Problem Well Supervisor Signature Phone 659-7224 Date 1/1/2008 ~ - Form 10-404 Revised 04/2004 ~~~ :~ ~ ,~d~~f ~;) °y Submit Original Only 3N-02A • DESCRIPTfON OF WORK COMPLETED SUMMARY ,:Date Event Summary. 12/27107 BH seal weld, N2 purge for well safe out. Initial TIUO= 50/80/0. Bfed T; }A to zero. Rigged up N2 and purged IA, OA and Conductor. Cut top of Tanko head off. Rigged up Cooper heat. Made 3 pass BH seal weld. Rigged down purge hoses. Secured well. Final T/I/0= 0/0/0 12/28/07 NDE MT test of the weld assed. 12/28/07 MITOA-(PASSED); NORMAL UP WELLHEAD POST BH WELD; Initial T/U0=0/7510; Bled down IA to 0 psi; Removed purge jewelry from IA and OA; Installed VR plug in OA (opposing side); Pressured up OA with .5 bbls of diesel; T/I/0=0/0/1800; 15 min. T/I/0=0/011720; 30 min. T/I/0=0/0/1700; Sled down OA; (No teaks from BH weld. during MITOA); Final T/I/0=0/0/0.(Note: Replaced floor grating around wellhead also.) Summary Made a 3 pass seal weld repair on the casing starter. head and the MITOA passed following the repair. • ConocoPhillips Alaska, Inc. KRU 3N-02A 3N-02A API: ---- 500292152701 Well Tye PROD Angle_@ TS: @ 8401 38 deg sssv (t7a3-t7aa SSSV Type: -- TRDP Orig Com letion: 2/1/1986 _ Angle @ TD: _ _ -- 38 deg @ 8898 , OD:2.875) Annular Fluid: Last W/O: Rev Reason: TAG, GLV C/O Reference Lo og Date: Ref L Last U ate: 1/5/2008 Gas Lift Last Ta : 8560' SLM _ T D: 8898 ftK6 MandrelNal~,e Last Ta Date: 11!29/2007 _ _ Max Hole An le: _ 50 de 4100 2597 253s Casin Strin -ALL STRINGS ( - , Descrl tlon - Sfze To Bottom TVD -- VVt -- Grade -- Thread Gas Lift CONDUCTOR 16.000 0 80 80 62.50 H-40 MandrelNal~,e SUR. CASING _ 9.625 0 _ 4545 3575 _ 36.00 J-55 z a598 a~7 PROD. CASING 7.000 0 8890 6673 26.00 J-55 ( - ' Tubin Strin -TUBING Size _ Top Bottom TVD Wt Grade _ __ _ Thread 2.875 0 8506 6370 _ 6.50 _ J-55 EUE 8RD AB MOD Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 8446 - 8458 6322 - 6332 C-1,UNIT B 12 12 4/18/1986 IPERF 5" HJ II Csg Gun 8564 - 8575 6416 - 6424 A-3 11 6 4/26/1990 APERF 0 deg. phase, 2 1/8" Dyna Stri Gas Lifl MandrelNalee 5 8575 - 8576 6424 - 6425 A-3 1 7 4/26/1990 APERF 0 deg. phase, 2 1/8" Dyna $tfl (s5z5~5zs, 8576 - 8579 6425 - 6428 A-3 3 6 4/26/1990 APERF 0 deg. phase, 2 1/8" Dyna Stri 8579 - 8580 6428 - 6428 A-3 1 7 4/26/1990 APERF 0 deg. phase, 2 1!8" Dyna Stri 8580 - 8584 6428 - 6431 A-3 4 6 4/26/1990 APERF 0 deg. phase, 2 1/8" Dyna Stri Gas Lifl MandrelNal~,e 7 8594 - 8626 6439 - 6465 A-2 32 4 4/18/1986 IPERF 90 de hase, 4" HJ II Cs 9• P 9 Gun (7a27-7a2s, Gas Lift MandrelsNalves St MD TVD Man Mfr Men Type V Mfr V Type _ V OD Latch Port TRO Date Run Vlv Cmnt 1 2537 2251 Merfa TMPD __. Macco GLV 1.0 BK 0.156 1356 4/14/2006 2 4536 3569 Merla _ TMPD Macco GLV 1.0 BK 0.188 1380 4/14/2006 Gas Lift 3 5588 4253 Meda TMPD DMY 1.0 BK 0.000 0 4/18/1986 MandrelNalee 4 6058 4566 Mena TMPD DMY 1.0 BK 0.000 0 4/18/1986 9 5 6525 4879 Merla TMPD GLV 1.0 BK 0.188 1368 4/14/2006 (sz9a~g29s' 6 6993 5205 Merla TMPD Macco DMY 1.0 BK 0.000 0 4/6!2004 pgR 7 74 27 5522 Merla TMPD GLV 1.0 BK 0.250 1463 4/13/2006 (sz77~27s 8 _ 7832 _ 5835 __ Merla TMPD Macco DMY 1 0 BK 0 000 0 4/6/2004 , OD:2.875) 9 8238 6157 MMH _ 2.875x1.5 OV . 1.5 RK . 0.250 0 12/24/200 Pro duction MandrelsNalves PKR (s299-a29a, St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt OD:8.151) 10 8331 6231 Merla TMPD __ DMY 1.0 BK 0.000 0 1/4/2008 1 11 8399 6285 Meda _ TMPD DMY 1.0 BK 0.000 0 12/15/198 12 8472 6343 Meda TMPD DMY 1.0 BK 0.000 0 12/15/198 7. EXTENDED PACKING Other lu s e ui .etc. -JEWELRY De th TVD T e Descrl tlon ID 1783 1702 SSSV Baker'FVL' 2.310 8277 6188 PBR Brown 2.500 8293 6201 PKR Brown'HB-1' 2.441 pert 8486 6354 PKR Brown '1 B' 3.250 (eaasa34ss) 8498 6363 NIP Camco'D' Ni le NO GO 2.250 8506 6370 TTL 2.441 8506 6370 SOS _ Camco 2.441 General Notes Date Note 4/14/2006 NOTE: TUBING IS CORKSCREWED BE AWARE FROM 5000' RKB DOWN PKR 4/26/2006 NOTE: WAIVERED WELL IAxOA COMMUNICATION (sass-sas7, OD:8.151) NIP (8498-8499, OD:2.875) TUBING (0506, OD:2.875, ID 2.441) Pert (8564584) Perf (8694626) ., at ~ 'r ~_ F •. .:7< . . r . 5 w: „ .. . ~ t ~ .,d,, ~.. ~ r! ~ ~4~~,~ err "~ ,I a • a a • _ ,c ~ ' ~` ~ o • a • a { x ::. a x ~ ,,.: , ~ ~ r . ...~~., .. ~ ~.,: ~, , _. ~ .: ~;.; _- .~ _ .~: -- ^ ~, ., . ~~ w ;, ~ - ' ~CI~~~~~'Ih Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ !~~'a. _ Log Description 12/20/07 NO.4532 ~~ ~~ Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1J-105 11837540 INJECTION PROFILE ~~'}-(~'~.- 11/20/07 1 1A-06 11837542 _ RST WFL °~'~ _~JG i 11/22/07 1 1Q-05 11837537 _ LDL C - ( 11/17/07 1 1B-12 11970607 INJECTION PROFILE v"f' 12104/07 1 2N-327 11996582 OILPHASE SAMPLER Q~- (0 12/15/07 1 1D-132 11994588 SBHP SURVEY ~.'(_ - ~ 12/17/07 1 3H-10B 11996580 PATCH EVALUATION = ~ 12/13/07 1 3N-02A 11970609 LDL 12105/07 1 1C-125 11964553 INJECTION PROFILE 12/01107 1 2M-15 N/A PRODUCTION PROFILE ( r " 12/10/07 1 2M-11 N/A PRODUCTION PROFILE ~q ~ I 12108/07 1 3A-03B 11970604 SCMT ''-f-- J 12/01/07 1 2T-217A 11978431 SCMT 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER 11127/07 1 2L-330 11837544 SONIC SCANNER 11/27107 1 L J • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MICROFILMED 9/j J/00 DO NOT PLACE ANy NEW MA TERiA UNDER THIS pAGEL ': STATE OF ALASKA AL~ A OIL AND GAS CONSERVATION COMM,. .3N REPORT OF SUNDRY WELL OPERATIONS Stimulate X Plugging Perforate _ Repair well Other 6. Datum elevation (DF' or KB) 1. Operation Performed' Operation Shutdown ~ Pull tubing Alter casing 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK Location of well at surface 11562' FSL, 429' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1789' FSL, 505' FEL, Sec. 32, T13N, R9E, UM At effective depth 1523' FSL, 422' FEL, Sec. 32, T13N, R9E, UM At total depth 1460' FSL, 388' FEL, Sec. 32, T13N, R9E, UM Present well condition summary Total Depth' measured 8898' feet true vertical 6673' feet Oi lb J L feet 67' RKB 7. Unit or Property name Kuparuk River Unit $, Well number ;~N-Q2A Plugs (measured) Effective depth' measured 7243' feet Junk (measured) true vertical 6463' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9. Permit number/approval number ~6-32 10. APl number 50-029-21 527-01 11. Field/Pool Kuparuk River Oil Pool Length Size Cemented Measured depth True vertical depth 80' 1 6" 231 Sx CS II 80' 80' 4545' 9 5/8" 1340 Sx PF"E"& 4545' 3575' 310 Sx Class G 8890' 7" 350SxClassG& 8890' 6674' 175 Sx PF "C" measured 8446'-8458', 8564'-8584', 8594'-8626' true vertical 6323'-6332', 6416'-6431', 6439'-6465' 12. Tubing (size, grade, and measured depth) RECEIVED J LiN 1 0 !992 BROWN HB-1 ,l-B; 8293' & 8486' I~ska 0il & Gas Cons. Anuhu[~U~ 2 7/8" 6.5#, J-55, ABMOD, 8506' Packers and SSSV (type and measured depth) SSSV' BAKER FVL; 1783', Packer: 13. Stimulation or cement squeeze summary Tubing A-sand Refracture Treatment Intervals treated (measured) 8564'-8584', 8594'-8626' Treatment description including volumes used and final pressure 103MIbs of 12/18 Mesh Proppant in Formation; Final pressure @ 5900 psi Representative Daily Average Produ(;tion or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure ssure 50O 350 5 1100 140 Prior to well operation 950 1200 40 1250 125 14. Pre 15. Subsequent to operation Service 17, Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector __ Daily Report of Well Operations X,, Oil X Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. Operations Engineer Date ~>/~'/? ~...-- SUBMIT IN DUPLICATE Si~lned ~"'~'~. ~ Form 10-404 Rev 09/12/90 Title '~-4PBDT I FIELD - DISTRICT. STATE QONTRACTOR j OPER~;I'I-'~-~ A~~IM E REMARKS ATE z, L,~.,I. ! v L JUh~ 10 1992 Alaska Oil & Gas Cons. Commission Anchorage ~ CHECK THIS BLOCK IF SUMMARY CONTiNUED ON BACK WeatherReport Temp. °F Chill FaCt~F!VIsIbility mile~ jWlndVM. · r .... STATE OF ALASKA -'~'~ ALASKA OIL AND GAS CONSERVATION ~,,J~IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~ (/i/- REV 15ED OIL [-X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-32 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21527-01 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 429' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1789' FSL, 505' FEL, Sec.32, T13N, R9E, UM 3N-2A At Total Depth 11. Field and Pool 1460' FSL, 388' FEL, Sec.32, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 68' ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/29/86 01/30/86 02/01/86' N/A feet MSL 1 17. Total DePth (MD+TVD) 18.Plug BaCk Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 8898'MD, 6673'TVD 8801 'MD, 6596'TVD YES~ NO [] 1783' feet MD] 1700' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR, FDC/CNL, GR/CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 231 sx CS II 9-5/8" 36.0# J-55 Surf 4545' 12-1/4" 1340 sx PF "E" & 310 sx Class G 7" 26.0# J-55 Surf 8890' 8-1/2" 350 sx Class G & 175 s; PF "C" 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) 2-7/8" 8506' 8293 ' & 8486' 8446'-8458' w/12 spf 8575 '-8579' w/1 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 8594'-8626' W/4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Addendum atta:hed to Well Completion Report, dated 6/2~/86 for fracture data. ,,. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~l~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. coRE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RE£EIVED Oil & Gas Cons. Commission Naska *Note: Tubing was run and the well perforated 4/19/86. Form 10-407 Rev. 7-1-80 WC3/s1 :UANI CONTINUED ON REVERSE SIDE Submit in duplicate/(~ 29. i) 3O,. GEOLOGIC MARKERS ¥'O MATIONTESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8:327' 6221 ' N/A Base Kuparuk C 8458' 6325' .. Top Kuparuk A 8551 ' 6399' Base Kuparuk A 8701' 6517' 31. LIST OF ATTACHMENTS None , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge , //~ (~/)~,f~(~.t ~.~C'/~(~(_~/t_, Title Associate Engineer Date ~-~-..--z Signed 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 for timely compliance with out ~esulattonu. ' . ~,qui~ed ~ate ~eeelved : . ' Hud Lag "-Core lncll.utton llurvey · · · Lug Run .......... ,-~ ~ .'~. , .~ V~.~_ .;-:,~z~. :~_ ._ ~/~ · o ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal # 5943 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3I-3 3I-4 3J-10 3J-11 3I-8 3I-7 3I-5 3N-2A CET 2-12-86 6100-7610 CET 2-12-86 6300-8280 CET 2-11-86 5686-7181 CET 2-11-86 6084-7520 CET 3-8-86 7400-9176 CET 3-8-86 4950-7238 CET 3-7-86 6100-9948 CET 2-15-86 7315-8761 ... Receipt Acknowledged: DISTRIBUTION: Drilling Mobil NSK ~~~ BPAE Ancn~t~ron SAPC Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary o! AllanlicRIchfleldCompany STATE Of ALASKA .... ALASKA ~,- AND GAS CONSERVATION Ct.,~¥,,vIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG v 1. Status of Well Classification of Service Well OIL Yt~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Opera:~o'r 7. Permit Number ARCO Alaska, Inc. 86-32 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-- 029-21527-01 , , 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 429' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1789' FSL, 505' FEL, Sec.32, T13N, R9E, UM 3N-2A At Total Depth 11. Field and Pool 1460' FSL, 388' FEL, Sec.32, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 68' RKBI ADL 25521 ALK 2557 12. Date Spudded01/29/86 13. Date TiD. Reached01/30/86 14' Date C°mp" Susp' °r Aband' I 15' Water DePth' if °ffsh°re 116' N°' °f C°mpleti°ns02/01/86*... N/A feet MSL 1 17. Total Depth (MD+TV'D) 18.Plug Back DePth (MD+TVD) 1'9'. Directional Sur'vey '20. Depth where SSSV set I 21. Thickness of Permafrost 8898 'MD ,6673 'TVD 8801 'MD,6596'TVD YES~ NO [] 1783 feetMDI 1700' (approx) 22. TYpe Electric or Other Logs Run ' ' D IL/SFL/SP/Cal/CR, FDC/CNL, GR/CET, GCT ~23. CASING, LINER AND CEMENTING RECORD " SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6" (~Z.~ H-40 Surf ' '80" " 2b~" Conductor report; not yet received 9-5/8" 36.0# J-55 Surt~ '' 4'5'45'' ' 12-1/4" 134© sx PF "E" & 310 sx Class G 7" 26.0# J-55 Surf 8890' 8-i/2" 350 sx Class G & 175 sx PF "C" r, ,, , '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) 8446' - 8458' w/12 spf 2-7/8" 8506' 8293' & 8486' , 8575' - 8579' w/1 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. , , DEPTH INTERVAL (MD) AMouNT'& KIND OF MATERIAL uSED , , 8594' - 8626' w/4 spf See attach, ed Adden~ium', .... dated 6/9/86, for frac summary/. , , 27. N/A PRODUCTION TEST Date First Production " ' I Method of Operation (FI0w'ing, ga;' lift, etc.) I . . PRODucTiON FOR OIL'BB'L ' GAS_MCF . WALFER.BBL Date of Test Hours Tested cHoKE SiZE i GAS-0'i"L RATIO .... TEST PERIOD ~ I Flow Tubing Casing Pressur'e ' CALcuLATED OIL-BBL ' GAS-M(~F WATER-BBL OIL GF~AvITY-AI~I' (corr')' Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . . Form 10-407 * NOTE: Tubing was run and Well perforated 4/19/86. WC1/072 Submit in duplicate -. Rev. 7-1-80 ' CONTINUED ON REVERSE SIDE ~ 29. 30, ' ~, ~ . GEoLOGIc MA~':K~F~s 'FORMATION TESTS L' "-... : . . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,,, Top Kuparuk C 8327' 6221' N/A Base Kuparuk C 8458' 6325' Top Kuparuk A 8551' 6399' Base Kuparuk A 8701 ' 6517' '1 31. LIST OF ATTACHMENTs Addendum (dated 6/9/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~~/~ TitleAssOciate 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 ADDENDUM WELL: 2/18/86 5/27/86 3N-2A Arctic Pak w/175 sx PF "C", followed by 58 bbls Arctic Pak. Rn GR/CET f/8737'. Rn GCT f/19'-8720'. Dowell frac'd Kuparuk "A" sand perfs 8575', 8579' & 8594'-8626' in 7 stages per 6/8/86 (revised) procedure using diesel, Musol, gelled diesel, 100 mesh & 20/40 sand. Press'd annulus to 2100 psi w/diesel. Test ins to 7700 psi; OK. Stage #i: Pmp'd 20 bbls 140° diesel w/5% Musol @ 5 BPM w/2300 psi. Stage #2: 52 bbls gelled diesel speacer @ 20 BPM w/3800 psi. Stage #3: 18 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM w/3800-4400 psi. Stage #4: 59 bbls gelled diesel pad @ 20 BPM w/4400-4150 psi. Stage #5: 18 bbls gelled diesel w/3 ppg 20/40 @ 20 BPM. w/4150-4200 psi (on fly). Stage #6: 26 bbls gelled diesel w/8 ppg 20/40 @ 20 BPM w/4200-6000 psi (batch mix). Stage #7: 50 bbls gelled diesel flush @ 20 BPM w/6000-5800 psi. Pmp'd 750# 100 mesh & 10,460# 20/40 in formation leaving 540# 20/40 in casing. Load to recover 243 bbls of diesel. Job complete at 1100 hrs, 5/27/86. Turn well over Production. Drilling Superintendent .... ~- STATE OF ALASKA .... ~ ALASKA ~,~ AND GAS CONSERVATION COw, MISSION ,t/-- · WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-32 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21527-01 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 429' FEL, 5ec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1789' FSL, 505' FEL, Sec.32, T13N, RgE, UN 3N-2A At Total Depth Surf i[?~' 11. Field and Pool 1460' FSL, 388' FEL, Sec.32, T13N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Se"r~ial~--~o. Kuparuk River 0i 1 Pool 68' RKB ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 01/29/86 01/30/86 02/01/86*I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost 8898'MD,6673'TVD 8801 'MD ,6596 'TVD YES [~X NO []I 1783 feet MD 1700' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR, FDC/CNL, GR/CET, GCT 23. CASING, LINER AND CEMENTING RECORD -. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" Conductor report not y~t received 9-5/8" 36.0# J-55 Surf 4545' 12-1/4" 1340 sx PF "E" & 310 st Class G 7" 26.0# J-55 Surf 8890' 8-1/2" 350 sx Class G & 175 s~ PF "C" - 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) 8446' - 8458' w/12 spf 2-7/8" 8506' 8293' & 8486' .... 8575' - 8579' w/1 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8594' - 8626' w/4 spf N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (~orr) Press. 24-HOUR RATE "~ 28. CORE DATA ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . Form 10-407 * NOTE: Tubing was run and well perforated 4/19/86. ' DAM2/WC42 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk ¢ Top Kuparuk A Base Kuparuk A GEOLOGIC MARKER~' TRUE VERT. DEPTH 6221' 6325' 6399' 6517' 30. 'FORMATION TESTS MEAS. DEPTH 8327' 8458' 8551' 8701' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge i ~_~.~ 2~ Associate Engineer Signed----i~ 'i i - ~ Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' 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 Oil 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. District ICounty or Parish Alaska Field ~Lease or Unit Kuparuk River I ADL 25521 Auth. or W.O. no. ~Title AFE AK1096 I ComPletion Nordic #1 API 50-029-21527 Operator ~ A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~ Date Complete I 4 / 18/86 Date and depth aa of 8:00 a.m. 4/18/86 thru 4/19/86 Complete record for each day reported Accounting cost center code State North Slope Borough Alaska I otal number of wells (active or inactive) on this DSt center prior to plugging and ~ bandonment of this well I our I Prior status if a W,O. 1530 hrs. 7" @ 8890' 8800' PBTD, RR Diesel in tbg & ann Accept ris @ 1530 hrs, 4/18/86. ND tree, NU & tst BOPE. Perf "A" sand f/8594'-8626' w/4", 4 apl, 90° phasing, 8575 A 8579' w/4", 1 spf. Perf "C" sand f/8446'-8458' w/5", 12 SPF, 120° phasing. Make ]B/gage ring run~ Rn & set lB WL pkr @ 8486'. RU & rn 270 ]ts, 2-7/8", 6.5~, J-55 RUE, 8RD AB Nod comp1 w/S$SV @ 1783', HB-1 pkr @ 8293', lB Pkr'@ 8486', TT @ 8506'. Set pkr 7 tat. ND BOPE, NU & tst tree. Displ tbg i ann to diesel. Set BPV. RR @ 1600 hfs, 4/19/86. no. 3N-2A Old TD New TO [ PB Depth 8800 ! PBTD I Released rig Date ]Kind of rig 1600 hrs. 4/19/86 I Rotary Classifications (otl, gas, etc.) I Type completion (single, dual, etc.) Oil I ' Single Producing method I Official reservoir name(s) Flowing "I Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII 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 Date ]Title Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 1/30/86 9-5/8" @ 4545' 7923', (1125'), Drlg - Sidetrack 3N-2A Wt. 9.4, PV 12, YP 5, PH 10, WL 5.2, Sol 8 Cond mud, POOH. RIH w/BHA to 6798', Navi-Drl sidetrack to 7829', drl to 7923'. 6798' KOP 6861', 45.9°, S .25W, 5105.5 TVD 4126.8 VS, 4126.4S, 260.8W 7174', 43.2°, S 7.75W, 5329.0 TVD, 4344.7 VS, 4344.3S, 240.8W 7487', 41.0°, S10.75E, 5562.7 TVD, 4550.8 VS, 4550.4S, 211.8W 7769', 37.5~, SlT.75E, 5780.6 TVD, 4724.2 VS, 4724.0S, 168.5W The above is correct For torm preparation and ~j~tr~bution see Procedures Manull Section 10. IOale ITitle l¢lw , . Drilling Superlntefident AtlanticRichfieldCompany .~, Daily Well History-Final Report Inatl'tlctlona: 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 Ral3ort" form may be used for reporting the entire operation if space is available. I Accounting cost center code District IC°unty or Parish State Alaska I North Slope Borough A las ka Field JLease or Unit Well Kuparuk River ADL "~N-2/3N-2A Auth, or W,O. no. ~Title AFE AK1096 J Drill Doyon 9 Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun I Date Spudded I API 50-029-21527 W.I. JTotal number of wells (active or inactive) on tflis 56.24% Icost center prior to plugging and labandonment of this well JHour ~Prior status if a W,O, 1/20/86 / 1230 hrs. / Date and depth as of 8:00 Complete record for each day reported 1/31/86 2/01/86 Old TD Released rig !L~30 Classifications (oil, gas, etc.) Oil Producing method Potential test data ..... 9-5/8" @ 4545' 8898', (975'), Logging Wt. 10.1+, PV 13, YP 6, PH 9.5, WL 4.2, Sol 12 Drl & surv 8½" hole to 8898', C&C, short trip, POH. RU Schl, rn OHL. 8144', 37.5°, S19.75E, 6078.1TVD, 4940.3 VS, 4940.1S, 95.1W 8683', 37.8°, S19.75E, 6505.0 TVD, 5249.7 VS, 5249.7S, 16.1E 8863', 37.8°, S19.75E, 6627.5 TVD, 5339.0 VS, 5339.1S, 48.2E 7" @ 8890' 8890', (0'), RR 10.1 ppg Brine Fin rn'g DIL/SFL/SP/CAL/GR/FDC/CNL (no depths rept'd). Make wiper trip, POOH. RU & rn 205 its, 26#, J-55 BTC csg w/FS @ 8890' & FC @ 8801'. Cmt w/100 sx 50/50 Pozzolan & 250 sx C1 "G". Displ w/lO.1 ppg brine, bump plug. ND BOPE, NU & tst tree. RR @ 1430 hrs, 2/1/86. INew TD Date I PB Depth I Kind of rig ;z/i/~ I JTyPe completion (single, dual, etc.) / Single IOfficial reservoir name(s) ~up~uk Sands Rotary Well no. I Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size IT,P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signatu re I Date I Title ~or ,orm pre;station ;nd di~rib,,,tion, ' see Procedures Manual, Section 10, Drilling, Pages 86 an~ 87. Drilling Superintendent ARCO Alaska, Inc Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE 03-][9-86 TRANSMITTAL # 5604 RETURN TO: ARCO ALASKA, INC. ATTN: KUparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes Plus Listings/ Schl/ One of each Receipt Acknowledged ~tate of Alaska ARCO A/lika. Inc. ~$ 4 Subl~diary of AllanticRich¢ielclComDan¥ ARCO Alaska, Inc. Post Office E,,... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 02-26-86 TRANSMITTAL M 5580 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ Open Hole/ 3N-2A ~-~ 5" DIL/SFL-GR ~ 2" DIL/SFL-GR ~5" Den/Neu (poro) 9~2" Den/Neu (poro) ~5" Den/Neu (raw) ~2" Den/Neu (raw) ~Cyberlook 3N- 2 ~5" DIL/SFL-GR ~2" DIL/SFL-GR ~ 5" Den/Neu (poro) ~- ~2" Den/Neu (poro) '~5" Den/Neu (raw) x~2" Den/Neu (raw) ~Cybe r look 3N-! -"-5" DIL/SFL-GR -~ 2" DiL/SFL-GR '"-..%" 5" Den/Neu (poro) '2" Den/Neu (poro) "-5" Den/Neu (raw) ~ 2" Den/Neu (raw) '"12yb e r look 3J-!4 "05" DIL/SFL-GR k~2" D!L/SFL-GR 'X~ ~"-i 5" Den/Ne u-GR (po ro ) <, 2" Den/Ne u-GR (poro) ~ '~5" Den/Neu-GR (raw) ~2" Den/Neu-GR (raw) ~' Cyberlook 3J- 13 ~5" DIL/SFL-GR ~2" DIL/SFL-GR ~ ~" DeR/NeR-GR (poro) ~ " Den/Neu-GR (poro) ~5" Den/Ne u- GR (raw) ~-2" Den/Neu-GR (raw) Cybertook Receipt Acknowledged: One * of each 01-31-86 Run MI 4544-8882 01-31-86 Run #1 4544-8882 01-31-86 Run #t 8198-8856 01-31-86 Run MI 8198-8856 01-31-86 Run #1 8198-8856 01-31-86 Run ~i 8198-8856 01-31-86 Run #1 8300-8830 01-27-86 Run Mi 2550-9064 01-27-86 Run #1 2550-9064 01-27-86 Run #1 8350-9037 01-27-86 Run Mi 8350-9037 01-27-86 Run Mi 8350-9037 01-27-86 Run Mi 8350-9037 01-27-86 Run #1 8400-9000 01-18-86 Run M1 1550-9476 01-18-86 Run Mi 1550-9476 01-18-86 Run #1 4583-9450 01-18-86 Run M1 4583-9450 01-18-86 Run #1 '4583-9450 01-18-86 Run #1 4583-9450 01-18-86 Run #1 8750-9420 01-24-86 Run Mi 1990-8114 01-24-86 Run Mi 1990-8114 01-24-86 Run #1 7350-8089 01-24-86 Run #1 7350-8089 01-24-86 Run Mi 7350-8089 01-24-86 Run #1 7350-8089 01-24-86 Run Mi 7350-8050 01-12-86 Run MI 1990-7654 01-12-86 Run #1 1990-7654 01-12-86 Run #1 6990-7629 01-12-86 Run #1 6990-7629 01-12-86 Run Mi 6990-7629 01-12-86 Run Mi 6990-7629 01-12-86 Run Mi 6990-762.,~ ~D~O NSK Clerk*bl A~/~me 11 .b 1 State of AK*bi/se D & M*bl Drilling*bi Vault*films ARCO Alaska. lnc ,$ · Sub$~diat'~, o! AllartlicRichf~eldCom~an¥ ARCO Alaska, Inc. Post Office B~^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 20, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3N-2A Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3N-2A. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well is completed. A1 so, I have not yet received the Well Hi story. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L176 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -- ALASKA ~,~ AND GAS CONSERVATION CO,v, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED~/~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-32 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21527-01 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 429' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3N-2A At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 67' RKB ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/29/86 01/30/86 02/01/86 N/A feet MS L N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set i 21. Thickness of Permafrost 8898'HD 8801 'MD YES [] NO ~X N/A feet MDI 1700' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR, FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" Conductor report not y.~t received 9-5/8" 36.0# J-55 Surf 4545' 12-1/4" 1340 sx PF "E" & 310 s< Class G 7" 26.0# J-55 Surf 8890' 8-1/2" :~50 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) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . r '" ' ' i"i: :": ';' i; :.'. - i . ,' ' ' Form 10-407 DAH/WC24 - Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. N/A GEOLOGIC MARKERs' NAME MEAS. DEPTH TRUEVERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. t hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Associate Engineer 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 ~UB.~URFACE DIRECTIONAL ~URVEY r~UIDANCE ~'~ONTINUOUS ~OOL Company Well Name Field/Location ARCO ALASKA INCORPORatED WELL 3~q-2A (156~,' FSL. ,4~9'FF, I...~29. ~-[3N- RQF) ,KUPA~UK~ NORTH SLOPE. A?,A.qWA Jo13 Reference No: 713335 Loaaecl WEST Oat,e, 12-~R-86 Comput~ OGDEN GCI 2I~CTI]N~L .~US T]MSR LISTIN] F]~ 3N-2 ~ SL]~:,~LaSK.~ METHD]S O: C]'4~UT~TIO~ TI3_ L]-&T[]~: r&NS:NFI~L- INT=RP].~TI]~: VERTICAL S:CTI]N: qg~ZZ, OIST, :N]iqE:~: T, W:ST ~Z IMJT'-t S']JTq 13 31 KJ~,RJK N3RTH SLO°E~kL~SKa u j Vll.'u I ~ I 1 j'~ [NT=~POL~TED V~LJE$ FgR EYE~ 103 cEET TRUE SJS-S:& ME&SURE3 VERTI:~L V:~TI'AL )EPTd DEPT~ O.OD 0.00 -59,00 130.33 100,00 32.03 200.03 199.3~ 131.99 330.00 299.9g 231.99 ~g0.33 3~9.~ 331.'~3 5~O.OO ~39.~3 ~31.33 500.OJ 599.35 531.95 730.33 599.57 531.57 0.33 738.3'3 733.9~ .0.03 ~7.~3 92~.43 1000.30 1130.30 1200.03 1300.33 1~30.00 1530.33 1530.33 1700.03 1330.33 2030.33 2100,00 2Z)O.OO 2330.00 Z~O0.03 2530.3;) 2530.33 2700,D0 994,53 1090,~5 1134,J4 127~,31 1359,50 1~+59, $3 1547,51 1633.11 1715.34, 1795..)7 IB72.~5 19~5.30 Z015,23 2083.50 2151. ?4, 2220,32 22~8,72 2357.54 2~Z6.25 249~,~3 ;~562,32 Z629.07 2695°]6 Z?6Zo38 2829,33 Z89¢.59 2958.~6 3022.34 3087.2~ 3152. q,Z COJRS: V:RTICAL ]SGLEG ]:VI~TI3q AZIMJTt SECTI]~ S:V:IIT¥ 0 O N 0 0 r- 0.00 0 ]3 q Z~ 3~ W -D.55 3.32 0 24 q 13 Z? 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W 17.~5 3.99 11 +9 S 1 51 ~ 34.54 ~25.63 1322.¢5 1115.84 1210.01 1301.60 1t31.53 1~79,51 1555.11 154~.04 172~.07 189~.45 1877.3D 1~47.23 Z31~.50 2152.02 2220,72 2353,25 2~+25,43 2~9~,02 2551.07 Z527.~5 259~,38 2751,03 2825,59 Z~9g.86 Z~5~.34 3019.29 15 8 S 2 31 = 57.,,~'5 ~ 9a 13 0 S 1 21 : 8~.43 Z.5~ 20 18 S O 5~ ~J 115.95 !.9~ 22 25 S 1 23 -~ 150.31 2.70 Z~ ~5 S 2 5 ~ 187,8~ 1.~5 26 56 S 1 Z ~ 22~.7Z 2.7~ 32 ~O S 1 15 .~ 322.72 35 18 S Z 51 4 375.04 33 Z5 S 5 lO ~ 430.40 3.9~ ~1' ~l S S 37 ~ 439.01 3.10 a~ 32 S 5 31 W 550.95 Z.23 a5 31 S ~ 53 d 615.16 1.35 46 55 S 4 13 ~ 5d3.47 3.43 47 g _- ~ 35 W 75'3.7~._, 3.25' 46 ~4 S 4 5~ J 317.8~ 0,71 4~ 32 S 5 25 d 3~.4~ 46 29 S 5 Z~ W )50.43 3,55 46 ~ S 5 5; .~ 1'315.28 3.54 47 14 S 7 Z) ~ 10~2.17 47 ~2 S ? 53 ~ 1t~3.30 3.51 4l 59 S 5 Z~ W 121~.64 0,55 ~5 15 S 8 4~ ~ 1~9~ ~.3 O. ~ 15 S B 5~ W 13~7.21 9,35 43 11 S 9 3 W 1413.23 3.93 4'9 3) S u Z 'd 14~3.29 1.7~ 50 1~ S t 15 ~ 15~9.Z3 3.13 50 6 S 7 13 a 1519.a5 3.53 49 31 S 8 1~ ~ 15~7.!4 1.5~ ~'9 Z7 S 7 53 ~ 1754.70 Z.25 3330.00 3190.33 3ZO0.O0 3300.30 3~00.03 3500.0;) 35;)0.33 3700.00 3800.03 3930.,30 NgRTH! 6T~ 3: SJRVEY: 1$ .=:-3 35 ELLY 9JSHIN3 ELE~aT[]N: 59,00 ~T =MSI'4r'ER: T. WEST 3'JL&R C]]~DI~TES H3RIZ, DEPaRTUrE SOUT-~ E~ST!'~ST DIST, ~ZIqUTH I FEr-T -:: ~-__T nEC, 30 q O.OO E 0,30 q O 0 E 59 q 0.27 W 0.55 25 '~ 0.51 W 1.36 30 ~'l 3.59 W 2.06 N 13 55 W ~3 q 0.13 W 2.~4 37 ~ 3.,37 Za '~ 0.25 : 3.35 ~ 45 IZ E Z5 S 3.35 74 S 0.29 ~5 ~ 3.51 : ~5.Z5 S 3 48 : 5~.54 S 4 3.20 'S l~I.l~ 157.~ S 1~7.57 S ~41.J5 S 340.3g S 3~5.23 S ~S5.99 S 520.1Z S 5~.13 S 559.25 S 732.11 S 394.98 S 377.79 S 950.17 S 13Z2.Za S 1 ~94.50 S 1167.07 S 1240.11 S 1313.56 S 1387.14 S 1 ~50.92 S 1534.52 S 1509,37 S 15~5,11 S 1751,35 S 1~37,~5 S 1912.18 S 1.51 E 59.55 S I 32 2.4~ E 33,Z3 S 1 36 E 3.2~ 6 121.24 S 1 31 E 3.09 E 157.51 S 1 7 E 1.59 E 197.57 S 0 29 E 0.43 E 241.05 S 3 6 0.23 : Z~8.55 S O.l~ W 3a3.39 S 3 I W Z.lO W 395,21 S O 18 W 5.23 W ~55.33 S 3 47 W 13.2] W 520.29 S 1 27 d Zl. Z8 W 585.52 S Z 4 d 2~.30 W 559.~)6 S 2 27 W 33.91 W 732,89 S m, 39 ~ 39.55 W 305.95 S Z 48 W 45.5~, W 378.)8 S 2 58 W 52.19 W 951.50 S 3 8 W 59.51 W 1323.9~ S 3 ZO a 68,02 W 1096.51 S 3 33 ~t 77.23 W 1169.52 S 3 47 4 87.0~ W 1243.16 S ~ 1 4 97.52 W 1317.17 S ~ 14 d 109.68 W 1391.~,0 S ~ 28 ~ 120,13 ~ 1~65,85 S % ~2 ~ 132.01 W 1540.19 S ~ 55 W 143.4~ W 1515.45 S 5 5 W 153.~,3 W 1592.09 S 5 12 ~ 163.10 W 1768.8~ S 5 17 W 173.15 W 1345.29 S 5 23 W 184.45 W 1921.05 S 5 30 W 3~i-2A KJ:~AR J~, NERTH SLO°E~L~SK~ TRUE ~E&SURED V:RTIC~L 4320,02 3217,17 4[)0.33 3251,32 4200,00 3345.33 4300.'20 3408.35 4400.20 3~73.0~ ~500.00 353B.~6 ~5~0,00 3505,10 ~7~O,DD 3671,30 ( ~0,03 3735.35 5000,03 3854,50 5100.03 3928.5') 5200.03 39:~3.04 5300,:.}3 $057.74 5~DO,D] ~122,35 5500.00 ~188.52 55~0,80 ~254.50 5?00.03 ~321.33 5BDO.OO ~3a7,84 6000.00 ~521.~)1 5100.00 4587.40 5Z00.00 4,653. :)6 5330.3~ 4720,54 6~00,00 4787.5'9 6530.03 ~855.33 6.'~ ~.00 ~063.~0 6~, ~.30 5132.53 7000,00 ~202.35 71'20,00 7300.00 542.0.36 7400.00 5~95.3T 7530.33 5570.70 7530.33 5646,39 7700.30 577.4,31 7~00,03 ~803,28 Ti)O0.O0 5882,~2 [NT:~DL~T:~ V~LJES FOR ~VE~ log :EEF O: SJB-S:~ V~-RTI'.~L 3EP~'H C3JRSE VERTI'&L ):Vi~TIE~ ~ZIMUTq SECTION SEV~RIT~ }EG ~Iq DE3 ~I~ :EET D:~/13J 314:9.17 3213.32 3277 3340.95 3405.04 34?.}.45 3537.10 3503.50 355'3.35 3732.73 49 ~5 S 5 21 ~ 1323.58 3.45 50 28 S $ 23 ~ 1~93.15 2.39 50 14 S $ 5? W 1952,87 3,51 50 22 S 7 19 4 ]032.28 0,4l 49 39 S ~ 12 W !101,22 1,65 4~ 39 S 9 ~7 ~ 2158.2~ 1.53 4~ 4 S lO ~l W !233.55 3,29 43 55 S 9 2] ~ 2~.03 2,87 49 ~g S 5 ~ ~ 2357,35 5J 12 S 3 2~ ~ ~37,65 !,55 3795.6'0 3850,53 3925.04 398g,74 ~120,52 ~185.50 425~.0~ 4319.84 ~,385.53 50 lg S I 7 W 2509,73 0,71 50 0 S 3 39 ~ 25~2.25 49 :,8 S 0 13 w Z65~,.55 3.44 49 32 S 3 Ia. -: !725,87 0,41 49 9 S 0 Z7 E !799.01 3.55 4.~ ~5 S O 45 : 2~73.T7 3.52 48 Z~ S D 52 ~_ Z~2,29 0,50 48 12 S I 7 E 3J13,51 0.71 48 v S I 22 E ~084.53 3.04 43 12 S 1 31 5 3155.85 0.33 4453.01 ~51).40 ~585.35 4552.54 ~713.59 4737.33 ~55,32 ~925.70 ~995,10 ~8 28 S 1 *? £ ]227,35 3.33 4a 15 S 2 5 : 3299.02 ~.33 4,3 16 S 2 33 E 3370.77 4~ 5 ~ Z 42 ~ 3~42.45 3.17 47 ~0 ~ Z ~ E 3515,85 3.4Z 4~ ~3 S 1 55 E 35~,57 45 ~0 S 1 ~ : ]553.80 t.33 ~5 ~6 S O 55 ,4 5722.07 0.3~ ~6 ]2 S 1 ~ ',~ ]789.~9 1.6] 45 L4 S 0 53 E 5857.~7 Z.ET 513~,95 5205,49 5279,04 535.2.35 542'7.37 5502,70 5578.39 5555.31 5735.2~ 5814.42 44 ~9 S 4 55 E 3925.30 3.0~ 44 0 S 5 15 E 3~9~.43 1.32 43 $ S ? 3 ? ~051,82 3,3~ 42 T S 5 ~] E ~12~,~2 2,25 ~1 12 S T 21 E ~133,15 1,~3 ~1 5 S 13 45 : 425~,07 3.35 39 ~5 S 13 ! ~ $322,9a ~.05 38 ZO S 15 1 E ~385,~ 1,65 37 ~1 S 15 43 E ~4~5,73 3,51 37 35 ~ S 17 13 ~ ~307.8~ ~.$5 'q~: ~SURE RE'T~N N]~Tq/ 1~$7, 2140. 2215, 2293. 2367, 2~1. 2514. 2590. 2566. aTE 3.= SJR~EY: 15 ::3 35 ELLY 3USfllNS ELECAr[EN: 5q,O0 FT ENGINEER: T. 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Z~ZO.02 S 23)5,~1 S 290. 2)72,73 S 290, 3}4~.$3 S 3124.04 S 31g~,~ S 297. 3273.75 S 286. 33~8,21 S 284, 3~22,70 S 282. 3~97,37 S 280. 3572,11 S 278, 3545,77 S 275, 3721,21 S 271. 3795.32 S 253. 336t.~0 S 25~. 3941,18 S 252, ~013,18 S 253, ~)85,17 S 264. ~157,12 S 254, 4223.30 S 261. g297.50 S 256. g355.34 S 245. 4~33.35 S 238. ~99.32 S 230, ~63.90 S 219. 4527.92 S 205, ~5~8.55 S 191, ~747.59 S 17~. ~895.09 S 155. 35 W 275B.30 S $ 0 & 4~ W 2,33~.84 S 5 51 ~ ]7 W 2913.97 S 5 43 W OZ W 2~5.84 S 5 34 d 49 W 3362.34 S 5 25 4 ?Z W 3137.35 S 5 16 ~ 5~ W 3211.~3 S 5 8 W 37 W 32q5,28 S ~ 59 d 55 W 3360,29 S ~ 51 W 52 W 3~34.37 S ~ 43 W 54 W 350A.51 S ~ 35 W 14 W 3582.g2 S ~ 27 d 13 W 3557.14 S ~ 18 4 68 W 3731.11 S ~ 10 ~ 17 W 380~.7~ S ~ 2 W 8~ W 3~77.85 S 3 55 W 99 W 3949.34 S 3 49 W Ol W 4021.79 S 3 44 ~. 42 W 4093.71 S 3 42 W 88 W 4165.55 S 3 38 W 40 ~ g235.0~ S 3 32 W 36 W 4305.02 S 3 23 d 24 W 4372.78 S 3 13 4 09 W 4~39.74 S 3 4 ~ 35 W 4504.~2 S Z 55 ~ 62 W 456~.1B S Z 45 ~ 56 W 453!.53 S 2 33 d 05 W ~5~2.54 S 2 20 ~ 11 W 475~.~0 S 2 6 ~ 32 W 480,~.53 S 1 51 ~ INT:~PCL~T=) V&LJES FOR =VEN 100 FE=T 3= TRJE SJS-S=a ~EaSURE2 V=RTIC~L V=~TI-&L CJJRS~ VzqTI'4L D=V!~TIDq dZI~JTH 3ECTION SzV:RITY D=G q!N 3~3 MI~ ~ET D=3/1J3 5993.66 5973.00 5052,31 5131.57 5210.9) 5293.20 b35).45 $443.4~ $SZT.ql 5504.~3 37 30 S 17 45 ~ $558.32 J.37 37 33 S 13 7 5 ~$29.59 3.11 37 27 S 13 23 E i$90.59 3.39 37 RO S 13 27 E 1751.44 9.25 37 35 S 18 43 5 ~n12.'35 3.33 37 g5 S 19 1) 5 $~73.37 D.33 37 35 S 19 43 E $935.35 3.35 37 $4 $ ZJ 1 E +)~5.60 1.11 37 ~g S 20 1 ~ 5955.95 3.3D 37 ~ 5 20 1 E 3115.71 0.00 8330.03 5951.56 8130.30 5041.00 8200.30 5120.31 8300.30 5199.57 8~00,90 $278,39 9530.30 5358.20 8500.03 5437.~5 8730.33 $515.~9 0.33 $5~5.31 3.33 5672.~3 q= 'T~NI ~+354. 5337. 5D93. 5153. 3ZlO. 5258. 3323. 5332. ~TE 3~ SJRVEY: 15 F'3 95 =LLY 9USHING 5LECaT[3N: 59.00 FT E'4'31~IEER: T. ;4-ZST 24 S 137.92 W 4355.19 S. I 37 W 1,5 S 11,~.19 '~ 4923.50 O1 S 133.15 W 4981.02 S 1 74 S g0.93 W 5~33.39 S ~ 55 d 4'~ S 51,50 W 5395.~5 S ] 41 W 15 3 41.59 4 5153,33 S 51 S 21,14 W 5210,55 S 3 13 Z5 S 'J.3~ W 515~,25 S 3 0 aO S 23 ~5 6 53~5 ~4 S 3 13 Z5 S ai.24 E 53,32.~1 S 0 Z6 E 3Ut~q C33RDI~TES H]RIZ. ]EPqRT~E S.]JTq EnST/~=ST 9IST. &ZI~UTH T F~:T F~:T 0~3 MIN .; 3E~TH INC. INT:~PgLSTED V~LJES :DR :VEN 1003 FEET ]= T~U: SJS-S-a ~E~SUR=3 V:RTI-~L VSRTI'aL COJRSE V=RTI'aL DDSLEg )EVI~TI]~ ~ZIMJTH S=CTIgN SEV=~iTY ]E,3 MIN 953 ~Iq ;EET 353/100 0 0 N O 3 : 0 O0 3 03 15 B S Z 31 ~ 57.05 2.93 41 57 S $ 3? ~ ~8~.01 3.1~ 47 ~2 S 7 53 4 11~3.30 0.51 49 ~6 S 5 Z? W 1~23.5~ 50 19 S I 7 4 Z50).73 3.71 ~8 2~ S i a? : 3227.35 3.33 44 ¢9 S 4 55 ~ 3925.30 3.0~ 31 33 S 17 45 = ~555.~2 0.03 0.00 -5~.00 1330.03 994.53 )25.63 2300.33 1872.~5 180¢.45 3000.90 2552.32 2494.02 4030.33 3217.17 3149.17 5330.30 3854.50 3795.53 6330.00 ~521.31 5453.01 1330.33 5232.~5 513~.95 00.03 5951.55 5~93.55 ~8.03 5572.~3 5604.93 ME -~SJR D~TE 3= SURVEY: 15 FE3 35 KELLY 3J54I~3 5LE¢~TISN: EN3INEER: T. WEST F--6E -:j o L~q C2]RDIqaT=S H]RIZ. SJJT-4 E~ST/4EST DIST. f ::ET F::T 33 hi 3.]0 E 3.00 54. S 1.61 E 5).55 12 S 13.ZZ w 523.29 11 S 87.09 ~I 1243.16 94 5 193.50 W 1~97.24 1~ S 2q3.35 W Z~3~.30 37 S 2.3.3.5~ W 350'3.51 )0 S 251.~ W ~235,08 Z; S !31,)Z W ~55.19 25 'S 41.24 E 3~:3~.~1 5~. 529. 1240. 1)37. 2143. 3~7. ¢229.. 436~.. 5332. 53.00 F' D;P~RTURE ~ZI~UTff DE3 MIN ~ 0 0 6 $ 1 32 E 1 27 ~1 S :, I W S 5 33 ~ S $ 0 W 5 S 3 32 W S I 37' ,4 $ 3 26 E 3q-ZA K J:~6RJ¢, N3RTH [NT:~SL4TED V&.JES ~3R :VE`4 109 TRUE SJ3-S:~ ME&SUR:] V=RTI-6L V=RTI-4L ]EDTd D=DTt D=~TH 0.33 58.23 58.D0 158.00 158.20 ]58.91 358.20 458.31 458.20 55~.3Z 558.30 ~53.21 6SB.O0 8.73 75a.30 ~9.~ 858.90 ]72.¢5 968.30 1376.~S 1058.00 1132.35 1168.~0 12~9.1, 1253.20 13,8.2, 1358.00 1539.,1 1458.00 ~.~8 2858.00 -$~.00 0.00 102.00 200.00 300.00 ~03.00 503.00 500.00 703.00 ~33.00 =::T 9: 900.00 1003.00 1103.00 1203.00 1300.00 1500.00. 1509.00 1702.30 1833.03 1)03.00 2003.02 2100.09 2203.00 2303.00 Z~O3.O0 ZSOD.OO ZSOD.O0 2703.00 2303.00 CDJ?SE V:RTI-~L OSO_ES D:VI1TI~q= aZI~Jtq SECTIOq S:V:OlTY, )~G ~IN DES ~I~ FE~T 3:3/103 3514.33 2968.00 Z~30.00 3770.Z0 3068.30 3333.00 3)23.05 3158.00 310J.O~ ~219.0~ 3258.00 3203.00 6235.~1 3358.30 3300.00 ~392.2~ 3~$8.20 3~DD.O0 ~5~.~ 3568.30 3500.00 65)~.58 3668.D0 3503.00 4~8.~7 3768.30 3703.00 5335.33 3~58.30 3B03.00 O 0 '4 0 3 E 9.00 9 ZO N 35 13 W -0.45 0 ::'6 NI 15 52 W -1.14 0 !5 N 5 5 E -1.35 0 I? N ~q, 47 F_ -~.." 32 0 6 S 16 ~3 : -2.32 I 39 S 3 3~ : -1.Z~ 4 '51 '.S 3 5~ J 6.23 7 5 S 0 Z-~ '.,~ 13. 13 5'9 S 1 22 E, 23.39 r- 53.25 i~ 15 S Z 55 _ 17 Z1 S I 31 r. 77.54 19 57 S I 13 '~ 110.01 22 9 S I 7 ~ 1~5.67 24 ~;~ S 2 ; .4 187.20 27 Il S 3 52 W Z3Z.T9 30 Z~ S 3 3 w 33 +5 S 1 51 ~ 3~.2Z 37 l~ S ~ 17 w ~10.~1 41 ~5 S 5 ~5 W 45' 13 'S 5 5~ W 571.55 46 53 S ~ 15 W 558.23 ~6 S~ S ~ ~3 W 756.82 66 35 S : 13 ~ '~5~.~2 45 32 S 5 25 W 9~0.35 ~7 3 S 7 17 ,~ 1055.5a &7 ~ S 7 55 ~ 115%.20 ~3 7 S 5 39 ~ 1253.15 4'3 15 S ~ 1 ~4 !352.30 49 5 S ,~ 37 ,4 l~SZ.51 ED 14 S ? 15 ,~ 1~5!.13 49 ~3 S 7 1Z 4 1771.07 50 1~ S 6 ZZ ,4 1373.5~ 50 16 S 7 Z ~ 1}87.70 49 ~4 S ~ 5 ~ ]095.~5 4~ 13 S 1~ 21 4 21~7.49 ~8 51 S 9 31 ~ 22~5.50 ~9 J3 S ~ 53 4 2401.51 50 l~ S 1 3 ',~ 1513.5~ 3.00 3.24 3.23 D.ZZ 3.35 3.55 3.2'~ 3.31 1.95 2.5~ I .95 2.81 2.7:) 2.6~ 3.57 3.0~) Z.5Z ~.6~ ].27 3.3~ 3.63 D.SZ 3.51 0.55 ~.3~ 1.?I 2.12 1.17 1.95 }.31 1.5,~ 1.1Z 1.55 1.93 D~TE ]= SJRV:~: 15 ~EB 85 q:LLY 3USHI~3 ELEV~TISN: 53.00 FT =N$[qEER: T. ~EST SU~-SE~ O6DTH ~:: 3~JLaR CD]~Jlq~T:S q]qll. S ]UT-4 EaST/2:ST DIST. T ~EET F~:T DEPARTURE ~ZI~IUTH O:3 MIN . O. 1. 1. Z. 2. 1. la. 30. OO N 0.00 E 3.00 ~,2 ~ O.1S W 35 N 0.45 W 1.14 77 '4 0.55 W 1.35 35 t) 0.~ W _~.37 3~ ~ 9.1D E 1.40 3~ S 0.39 E ~.~0 53 S 0.32 : 1~.5~ 35 S 3.35 ~ 30.33 '4 3 0 E q 23 27 W q 17 S 5 8 E S 1 14 = s 52.57 S 81.10 S 114.~6 S 153.39 S 1~6.84 S "45.37 3 3OD.Z~ S 353. Z7 S ~34.30 S 516.19 ~ 610.58 S rl~.SZ S ~22.36 S 92~.37 S 1}33.11 S 1138.~1 S 1Z~6.52 S 1355.32 5 1~57.15 S 157~5.26 5 1.27 : 52.59 Z.31 2~ 81.14 3.13 E 115.00 3.1) E 153.~3 1.72 ~ 195.~5 0.37 E 245.37 O..Z3 E 300.Z3 9.81 W 353.27 4.4~ W ~34.33 12.77 W 516.35 S 1 22 E S 1 37 : S I 33 S I 11 E S 2 30 : S 0 5 : S 3 3 6. S 3 7 ~ S O 35 W ~ 1 25 [4 23.75 W 511.15 32.5~ W 715.37 ~0.97 W 323.35 50.17 t~ ~29.73 60.~3 ~ 1]34.~0 73.55 W 1141.18 ~9.00 W 12(+-.).72 103.95 W 1~60.50 121.12 W 1~72.14 138.92 W 158~.35 2134 )_ 35 W 2 51 W 3 5 ,~ 3 22 ;,I 3 41 ~l ~ 22 4 5 1 W 1596. 1314. 1;)30. 2167. 2400. '.510. 2527 · 27~?. 32 55 23 35 20 57 Z) 154.83 W 1703.08 170.02 ~ 1,'322.59 186.83 ;d 1-)39.26 ZOO.Z6 id 2,.357.33 21~.37 W 217d.~8 229.71 ~4 2298.71 Z4:l.Z,~ W 2~13.29 269.67 W 2525.00 292.91 W 2542.~3 2?8.44 ~ 2752.3~ S 5 12 W S 5 21 ~ S 5 31 w S 535,4 S 5 38 d S 5 44 ,4 S 5 54 ~ S 5 5 d S 5 8 W S 559,,/ a~S3 ~L~$K~, IqC. 3~1-2A KJ;>ARJK ND~TH SLG ~":, ~L ~SK.~ INT:~3OL~TCg V~LJES ~3R EVEN TRU: SJ3-S:a ME~$URE) V:RTI'~L V:RTI'AL ]EPTq DEPTH DE~T~ 5151,17 3959,30 5315,83 ~05~,30 5~58.32 ~15~,00 5520.21 5170.2~ ~358.00 5~20.21 6370.~5 ~558.~0 6~21.2~ ~55a.~0 .9,33 ~85~.00 3)03,0J ~OOJ,O0 %193,00 %200,00 %303,00 %¢00,03 ~533.00 ~500,03 ~703,03 ~03.03 6553.15 6~07.15 3058.30 5000.00 5~50,3~ 515],00 5103.00 ?J~9,~ 525~,30 5200,00 72~$,59 535~,30 5303.00 7353,53 5~5~,39 5~33,00 7¢~5,~2 5553.00 5503,00 7527.~2 5668.30 5500.00 ?755,~5 576~.00 $?OD,OD 79~1.80 5858.00 5903.00 C]JRSE V:~rI'~L OGD' :3 )=VIITI]~ &ZIMJTq SECTIgN SEV:qIT~ 8937,09 5963,30 ~134.37 5058,90 8250,0~ 5153,30 83~$.1~ 5258,90 8512,37 535~,00 8538,53 5459,30 8755.1~ 5558,30 8~1.75 5668.00 8i ',33 5672.~3 ~9 51 S J 25 W 2625.47 49 29 S J 23 = !733.29 ~ S O 3~ : ~ 23 S O 53 ~ 2~55.71 0.53 43 7 S 1 21 : 3353.49 48 1~ S I 35 E 3170.25 43 21 S 1 5~ ~ ~273.16 4~ 13 S 2 35 - 3355.00 9.3~ 47 ~? S 2 43 :. 34~3.13 46 33 S 1 4~ - 3591.31 1.1B 45 57 S 3 22 ~ 35~?.15 2.03 45 35 S I ? W 37~g.30 1.35 45 17 $ 2 ~5 2 _~2.15 3.5~ 4~ 5 S 5 3 : 3~33.31 1.23 43 I S 5 57 : ~081.00 0.37 41 12 S 5 43 E ~159.70 41 5 S lO ~3 E 4255.74 1.05 39 3 S 13 3~ -- %340.55 2.53 37 %~ 5 lb 11 ~ %~19.54 1.53 37 33 S 17 5 ~ %~)6,73 J.a2 3)33,00 5303,00 5tOJ.O0 5203.00 5303.00 ~403.00 5503,00 5503,00 563~.~3 37 _~9 S 17 ~7 ~ ~,573.5~ 0.3! 3? 33 S 15 ll : ~55J.~5 ].19 3'? 2S S 13 25 ,J ~727.17 '3.15 37 34 S 13 4~ : $303.90 ~.32 37 35 S 1) 2~ = ~80.92 ~.43 37 ~7 S 19 51 : ~937.~3 ].5~ 37 ~3 S 2~ 1 : 5335 51 9 37 ~3 S ~3 I ~ 5113 37 ~9 3 lO I i ;115.~1 3.03 35T: Dm SJ~¢EY: 15 ~:3 36 K:LLY BUSqlflS EL~V~TIDN: 53.00 :T =~S~:ER: T. WEST SU3-SEa 9=PTH RE'T&~ xl]~Tq/ 3UL~IR ,S23ROIq~TcS H]RIZ. SSJT-~ F_aST/~:ST DIST. T F E-_- T ,~::T ]ES MIN 2355. 2934. 3100. 3~_14. 3325. 3~7. 3550 · 3562. 3?73. 3_q32. '31 S ~39.'91 W 2331.~3 S 5 46 W ?~ S 2~9.94 W 2993.19 S 5 32 W 57 S 2B9.JO W 311~.01 3 5 19 ,~ 21 S 287.33 W 3227.03 S 5 6 d ]~ S 2~5.1~ W 333,3.19 S ~ 54 d ~5 S 2~Z.~O W 3~a9.3~ S ~ 41 W 37 S 273.91 W 3551.31 ~ ~ 29 W 50 S 27&.46 W 35/2. ~7 S % 17 d ~2 S 259.23 '~ 3783.%1 3 ~ 4 d 11 S 26~.52 W 3391.11 ~ 3 53 ~ 3~35.77 '~ 252.52 W 39)5.e, 1 S 3 46 '4 ~,39J.39 S 254.3~, W ~933.93 S 3 42 d ~1~2.~2 S 253.34 W 4201.11 S 3 35 W ~291.2~ 3 235.06 W 4293.55 S 3 24 W ~3'33.27 ~ Za3.85 W ~39Z.O~ S 3 10 ~ ~75..2'.3 S 233.19 W 4~81.32 S 2 59 W %551.5~ S 220.07 W &366.J9 S 2 45 ~ 4545.10 S 202.3~ W ~549.51 S 2 29 W &~21.54 S 131.39 d 4?25.03 S Z 12 ~ ~7~5.~6 S 15~.57 W ~93.12 S 1 54 ~ ~6~. 4941. 5314. 5150. 3232. 5305. 5378. 33.52. 37 S 135.43 W 4370.78 S I 36 W 90 S 112.73 W 4943.18 S I 13 W 72 S ~3.50 W 5315.50 S 1 0 ~ ~? s 6~.22 w 5o~?.~ s 3 43 a 29 S 39.09 W 5160.~3 $ 3 26 a 31 S 13.15 W 3232.~3 S O 3 a 75 S 13.35 ~ 5305.75 ~ 0 ~ E 56 S 39o93 E 5373.~1 S D 25 z 25 S 41 2~ ~ 533~ ~1 S 3 Zq : 3~-2~ KJP~RJ( NINTH SLO~E,~L~SK~ M~K~R TOP (UPARUK ' ~SE KU~K C TgP KUP~RgK ~ Cg~PJT~TI]~ [NTZ~'~gL~TED V~Lj=$ cDR ME~$JR:3 DE~TH 8327.00 8~58.00 8~01.20 13-M~R-35 :~0~ K3 5221.10 532~.92 $39~.61 5517.27 5595.30 5572.~3 1552' SJB-S:~ 5153.10 5255.92 5330.51 5~49.27 5529.30 K~LL¥ ]USHZN$ ELEV~TI2~: SB.O0 ENS[~EER: T. WES~ FT S JR 429' FEL RECT~N ~T , SEC 29, T13~l~ RgE,U 'Z,U L & R SOgq]IN~TES /SDdT~ E~ST/W;ST 5053.32 S 75.73 W 5128.95 S 50.31 W 5132.~g S 31.21 W 525~.9Z S 0.13 W 5]26.33 S 20.37 E 53~2.25 S ~1.2~ E ~C3 ~L~SK~, I~ICo 3~1-2~ KJ:~RJ( NDRTH SL'D:~E ~ I~L ~SK~ D~T= 3~ SU~=Y: 15 <ELLY 3USHIN3 ELECaTI3~: EN,~I~ER: T. WEST $3.00 VT TOP 3~S:- TOP :~BTD TO K~P~RUK ' KU~RUK C =IN~L 4EL. L3'~TIDH ~T ~E~SJRED D~OTH BELOW K3 :ROM KB ]~IGI~= 1;6Z° TVD SJ~-S:~ TO: S327.OO 5gZl.lD 5153.10 g~58.00 $3Z4.gZ 5~55.~2 8551.30 $398.61 5130.51 STOl. OD 5517.Z? 5~g. Z7 9~91.30 5595.30 5529.30 3~9S.00 5672.93 :SL, SJRF~E .3CATION ~T ¢29' TEL, SEC 29, r13~, RgE,U RECT&N'SU' ~R CDORDIN&TES NSRTH/S]UTN E~ST./WzST 5353.3Z S 1'5.73 W 5128.96 S 50.01 W 5258.8Z S 0.13 W 53Z6.38 $ ZO.ST E 53~~_.25 S ~1.~ ,_~ ME~SJRED DE~TH TRJE DEPTH $672.~3 SJ~-S:~ V:~TI=~L 5504.~3 qDRIZONT~L ]EPa~TU~: giSTaN:~ &ZIqUTH :=:T 3;3 MIN 5)~Z.~l S 0 25 SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. WELL BN-2A FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO WELL 3N-2A (1562'FSL, 429.-~-~L, S19, T13N, R9E) $CI:II.E = ! / !000 ! HORIZONTAL PROJECTION lo00 -6000 -4000 "EST -3OOO -20OO -Ioo0 o ]ooo 2000 3OO0 40OO WELL 3N-2A ('1562'FSL, 42~-~ FEL, S29, TI3N, R9E) -1000 0 0 VERTICAL PROJECTION 161. PROJECTION ON VERTICI:)L PLI:INE 161. - ~41. ~CI~.£D IN V£RTICI:iL O£PTN$ HORIZ SCALE = I/1000 IN/FT ARCO Alaska, Inc. Post Office Be 30360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the January Monthly Reports for the following wells' 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 .Ugnu State #1 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfieldCompany RECEIVED F E B '! 198G AlasKa Oil & bus C(ms. Commission Anchorage ..... STATE OF ALASKA .... ALASKA C AND GAS CONSERVATION COI,..AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-32 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21527-01 4. Location of Well atsurface 1562' FSL, 429' FEL, Sec.29, T13N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 67' RKB ADL 25521 ALK 2557 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3N-2A 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of January , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0430 hrs, 1/29/86. Drld hard cmt f/6740' - 6797'. Kickoff ~ 6798'. Drld 8-1/2" hole to 8898'TD (1/30/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 8801'. Secured well & RR ~ 1430 hrs, 2/1/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8890'. Cmtd w/350 sx Class 14. Coring resume and brief description None 15. Logs run and depth where run DI L/SFL/SP/Cal/6R f/8890' - 4545 FDC/CNL f/8890' - 8250' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SNI(~TNEE__DR e p o r t ~n ~ TITLE Associate Engineer DATE this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM/MR15 Submit in duplicate January 29, 1986 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kupar~ River U. nit 3N-2A ARCO Alaska, Inc. Permit No. 86-32 Sur. Loc. 156'2'FSL, 429'FEL, Sec.29, T13N, R9E, UH. Btmhole Loc. 1516'FSL, 386'FEL, Sec.32, T13N, RgE, UH. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govermnental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, l~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 the shoe of the conductor pipe. Very trulM yours, . C. V. Chatterton Chairman of Alaska Oil and Gas' Conservation Commission BY ORDER OF THE CO~ISSION dif Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office ~..~x 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 January 29, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3N-2A Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 3N-2A, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore ° Proximity plots ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment If you have any questions, please call me at 263-4970. .~cerely, , /~;o.E. K~win Regional Drilling Engineer JBK/LWK/tw PD/L220 Enclosures RE£EIVED JAN 2 9 1986 Ata~ Oi~ & Gas Go~s..Commission Anchorage. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -- ALASKA OIL AND GAS CONSERVATION C~,MMISSION I =FIMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONEJ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P, 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1562' FSL, 429' FEL, Sec.29, T13N, R9E, UN At top of proposed producing interval 1715' FSL, 452' FEL, Sec.32, T13N, R9E, UM At total depth 1516' FSL, 386' FEL, Sec.32, T13N, R9E, UN 9. Unit or lease name Kuparuk River Unit 10. Well number 3N -2A 11. Field and pool ri Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation a.nd '~¢~.Q .,*~- ..... RKB 67', PAD 33' ADL 25521 ALK 2557 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi o NW of Deadhorse miles 429 feet 16. Proposed depth (MD & TVD) 8833' MD, 6630' TVD feet 17. Number of acres in lease 2560 Kuparuk River Oil Pool Amount $500,000 N. Distance to nearest drilling or completed 11 well 25' ~ surface feet 1 Approximate spud date 01/20/86 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2899 KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 47 oI (see 20 AAC 25.035 (c) (2) 3329 psig@ 80VF Surface ..psig@ 6472 ft. TD (TVD) Hole ~-i/Zii Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Casing Weight55/HF BTC Grade_E wCoupling Length MD TOP TV D MD BOTTOMTVD (include stagedata) 7" 26.0# J- 8799' 34' I 34' 8833'1 6630' 300 sx C1 ass "G" neat I · l ~ I I I 22. Describe proposed program: ARCO Alaska, Inc., proposes sidetrack from the existing 3N-2 wellbore at a depth of about 6863'MD and directionally drill 8-1/2" hole to approximately 8833'MD(6630'TVD). A 16" conductor is presently set at 115'MD, 9-5/8", 36.0#, J-55 casing is set at 4545'MD and is cemented to surface. The presently installed 13-5/8" BOP stack will remain unchanged. If necessary, the BOP stack will be tested to 3000 psi per the schedule established by the installation on 3N-2. Expected maximum surface pressure is 2899 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpected gas bubble at surface, including temperature effects. Selected intervals will be logged. Casign will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3N-2A will be 25' away from 3N-1 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. (cont'd on attached sheet) 23. I hereby ce~r.t.~y that the foregog~g' is true and correct to the best of my knowledge SIGNED/' //~,'.~,/~;~~.~,.,/,~:~,-"k.~, TITLE Regional Drilling Engineer DATE The s f ssion us~ CO~DITIOSS OF Samples required Mud log required []YES ~NO []YES Permit number Approval date ,_-'¢/0-~_~..~ ~ 011.29186 Form 10~01 (L~K) PD/PD229 / / Rev. 7-1-80 Directional Survey required APl number ~/E S r-]NO 50- ¢ Z ~/~ - ~/,5-,~, ¢'- O/ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission January 29, 1986 Submit in triplicate PERMIT TO DRILL 3N-2A (cont'd) The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED .JAN 2 9 1986 Alaska Oil & Gas Cons. Commissar, A~chomoe j, , 7 5 4 3 2 RECEIVED Gas" - _.~ DIAGRAM #1 15-5/~ 3-{X]O PSI RSRRA BOP STAQ< 1. 16' - 2CC0 PSI TAN<CO STARTING FF_AD 2. I1' - 3CX:)O PSI CASI~ FE. AD 3. I1' - 3000 PSI X 13,--.~/8' - ~ PSI SPACE~ S~ 4. 13-5/8' - EO30 PSI PiPE RAMS 5. 13-5/8' - 5000 PSI DRILLING SPOCI_ W/CN(XE AhO KILL LI~,S 6. 13-5~8' - 5000 PSI DOUBLE RAM W/PIPE RAMS C~ TCP, BLIN] RAMS ON BOTTC~. 7. 13-5/8' - 5000 PSI ANNJLAR ACCLMJLATOR CAPACITY TEST I. C~EO< AN] FILL A~TCR RESE3A"VOIR TO PRO>ER LEVEL WI'TN HYDRALE. iC FLUID. 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ I~ ~i ~T~ ~ ~ ~~T~. 3. ~~ TI~, ~ ~ ~ ~ITS SIXThlY ALL ~ITS ~ ~~ MI~ ~I~ ~ ~. 4. ~~ ~ ~ ~T, ~ A~T~E L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~INI~ P~~. 13-5/8" BOP STACK TEST 1. FILL 8C1= STACX AN] CHQ<~ MANIFCI_D WITH ARCTIC DIESEL. 2. Q-E~ TNAT ALL LOCX ~ SCREMS IN t~EI_U-F_AD ARE F'tLLY RETRACTED. SEAT TEST PLUG IN ND..LPEAD WITH RUANING JT AND RUN IN L~ 3. CL~ ~ ~ ~ MA~&J~ K~[LL AND CHCI<E LIN~ VALVES ADJACE3VT TO BOP STAOQ ALL OTFF_R VALVES AND Q-EXES SHOJLD BE 4. PI:~~ UP TO 250 PSI AJ~ I-O_.D FOR I0 MIN. IN-- ~ PRE~ TO $000 PSI AN;> HCLD FOR I0 MIN. BLUFf3 PI~~ TO 0 PSI. 5. CPE.N ~ PR>EVENTE. R AND N~",iJAL KJLL LINE VALVES. CLCSE TCP PIPE P,/V~ AND ~ VALVES ~ KILL AND CHO<E LINES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. 7. COWT[I'4JE TESTING ALL VALVES, LINES, AN~ CHCKES WITH A 7.50 PSI LO~/ AND 3000 PSI HIG-I. TEST AS IN STEP 4. DO NDT P~S,SLF~ TEST ANY C~O<E THAT IS NOT A FU,.L C_0SiNG POSITIVE SEAL Q-IOKE. ~ICN TEs'r CHO<ES THAT DO NOT FLI..LY CLOSE. TEST BOTTOvl PIPE RAMS TO 250 PSI AND 3.000 PSI. G:>EN BOTTQvl PIPE RAMS, BACX GJT ELIDING JT AN~ Q_DSE BLIND RAMS AN~ TEST TO 250 PSI PSI. Ii. ~ BLIND RI:WE; AI~ RETRIEVE TEST PLUG. MAKE SURE M~NIFOLD A~ LINES A~ FULL. ~ FLUID. SET ALL VALVES IN DRILLING POSITIDN. TEST STAhi~IPE VALVES, KELLY, KELLY COQ<S, DRILL PIPE SAFETY VALVE, AN~ INSICE BO:> TO 2.50 PSI AhD 5000 PSI. 13. RECCRD TEST IN=Ct~MATION ON BLCINOJT PREVENTER TEST FO~, SIGN, AND ~ TO DRILLING SUPERVISOR. 14. PFERFO;NI O:M::~ETE BO::'E TEST AFTER NIPPLING UP AN;) IhEEKLY THERE. AFTER ~IG',,IALLY D°ERATE BCPE DALLY. KuPARUK RE[VER UNIT 20" .DIVESTER SCHEMATIC DESCR I PT I ON ~. ~6. CON::~CTO~. 2. TAhI<O STARTER HEAD. ~. TAN<O SAVE~ SUB. 4. TAhI<O LO~'~ER OMICK-CC~CT ASSY. 5. TANI<O UPPER OUICK-CC~CT ASSY. 6. 20' 2000 PSI DRILLI~ SPOOL t~/I O' OUTLETS. 'f. I0' HCR BALL VALVE,~ ~f/lO' DIVERTER LI~JI'o V'ALVEI~ OPEN AUTOMATICALLY UPON CLOSURE OF A~AR PREVENTER. 8. 20" 2000 PSI ANNULAR PREVENTER. MAINTENANCE & OPERAT.]ON RECEIVED I. UP-C~N INITIAL INSTALLATIOf~ CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY, 2. CLOSE AINNJLAR PREVENTER AI~) BLOW A I R THROU~ D I VERTER L IINES EVERY 12 HOURS. CLOSE ANI'C3LAR PREVENTER IN THE EVENT 'THAT AN II, FLUX OF WELLBORE FLUIDS OR GAS IS DETECTED, IF NECESSARY, MAf~JALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHIEVE BO~NWlND DIVERSION. DO NOT SHUT IN ~ELL UNDER ANY CIRCUN~TA~ES. HOR. I_ZON~AL .... PROJEC T.I.ON SCALE I N, . = . 1000 FEET .... ; WELL' 2A PROPOSED' "- :' SLOT'2 WEST,EAST .......................... 2OOO I '" ' CEIVED .......... = _ 3000...,, .................. . ....................... ~.._: ............ ~..i .... '.__L ................ ~-..~ ... ................ '" .............................. ! ..................................... · ..................... ~_. _. _.i ............... 4.000 . - .......... '- ..; ~:: . "_ ::' .................. .'-~:" r"~O-p ...... ~V'~'s'i OS'"T',~'~e$~ ~ ............... , ..... _ i~_.'..".. 'i : _. : $4.12g ~26~ (S2' ................. ' -i :. -i..~ ......... -L.'.: .' '_"' '. ' i- '-'" ET OENTER ' ~ -' ' - .~'~._ -_~':'_."~--- -~ -'..'.-' ~' . ..... . TVD 6~6 T~R~T LOC~TIO~, -- -' ~ .~_ _ ~' ~OUTH ~16g ..................- : '-':" ..... '---'-"-'~ ''-:"-: '-_ . - _ ~ ~ ':. .... _ -. . TD L~OATtO,, r ..... oo ..... : .... ~c. ~. ;~.. .~ ............. :... .................... TARGET---D ~REOT ~ ON': ............................... ....... 2000 ..... 1000 _ . . 0 1000 ....... - ......... 1000_. ' " . · .- .......... . '~'."-~' -- .".'-~L-~ ........ -~ ........ i.i ....... ._i .................. ~_--t~ ......... _-.~-_-._i'-. ......................................... . ._ . 1000 .., ............. ......... .... . .... , ....... . . ............... · · 2000. ......: .............. :. ...... r '" .... ' :----:"--':PLANE'!~ .... OF': .......... PROPOSAL ..... S WELL' 2A PROPOSED .... ~ - - - ~ · ~ ........;----~ .... ~ ..... ~v ' ' - .... ~ ~ -- , , . _ . ~. ............... , ......... ~ .... ~ ~ '- _~ .... ~ .......... ~ ~ ~ ............ ....................... ~ ............. . _ .~ . ~ ................ . . ..... .......... . .. ~ _ . ,. .................... ~ ....... . .......~ ........ ~ . - ......... - ......... IAROE'T- ANGLE ........ ' - 37 DEG 36 MI N ...... ~ .... - , ~ ........ : _ . ~ .................. ............. ~ ........ . ........ , ..... ~ ............. . ......- . ....... 4000 . .... ; ................. Alas~<a Oil, & Gas KOP ....... ,TVD~51'OS-'THD=6863'--DEP~"41-'38'-'.' .......:"'-; ....... . ~-o;~go .-. .S2 15U~ . 47 DEC ~24 .H~N - -~ . . _~ .... - 2.5 DLS/PER 100 FT--; ...... :- - EOC' .~TVD=5609-T,D=7544 DEP"'4583 ........ 7-;-';--; ........ j ....... ~-+-. ..... TI-ZONE-D-<---.TVD=6162--THD=8242.-DEP'49~ ...... ~_L~ - TI ZONE C : TVD=6212 T,D=8305 DEP=5013 --~- - TI ZONE A~ TVD=6359 THD=8490 DEP=5118 TARGET CNTR ..... T D .6416._THD=8562..DEP=5158_'~L; ....... ~ .... B/ KUP SNDS TVD=6472 THD=8633~DEP=5198 ~--- -. '._ . TD (LO~ PT.) TVD=6630 T,D=8833 DEP=5311 '-'~_ j I I I I ' -'~ ......... ~ ~- ~ 000' ~- ~0~0 ....... ~000. - ~000 5000 ................ ~ ................ . . . ............ ~ ..... ~- .... , ..... .... ~ ~ ......... . 6000 STATE OF ALASKA ALASKa' "IL AND GAS CONSERVATION C-MMISSION SUNDRY NOTICES AND REPORT ON WELLS DRILLING WELL~I~ COMPLETED WELL I-3 OTHER [] 2. Nameof Operator ARC0.A]askas Inc. 3. Address Po O. Box .100360s Anchorages AK 99510 4. Location of Well Surface= 1562' FSLs ~29' FELs Sec.29, T13N, RgEs UN 5. Elevationinfeet(indicate KB, DF, etc.) RKB 67~ PAD 33~ 12. Perforate Stimulate Repair Well 7. Permit No. 86-15 8. APl Number 50-- 029-21527 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3N-2 11. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk River 0tl Pool ADL 25521 ^LK 2557 Check Appropriate Box To Indicate Nature of NOtice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) [] Alter Casing [] [] Abandon ,~' [] Change Plans [] Perforations Stimulation Repairs Made SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other Pull Tubing r-I Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). Verbal approval was received from Lonnie Smiths AOCCCs on 01/27/86 to plug the eXisting wellbore across the Kuparuk Sands interval. The procedure was as follows: 1. Ran in hole with open-ended DP to 8820'.. CBU. 2. PumPed 185 sx Class 'G' cement. 3. P0H to 7000~ and pumped 120 sx Class 'G' cement. POH~ WOC, RIH. 5. Brld cmt to 6797~ and prepared to sidetrack. (CIP ~ 16:37 1/28/86,) RECEIVED JAN 2 9 1S8,g Alacka 0il & Gas Cons, Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'~ ~ Associ a~:e Engineer Signed ~: ~/;' ~'~ ~t (,.~., , . ,,./,~[ C.~_~,/,-C ~,~.fi Title The space belo~ for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the commission Date Submit "Intentions" in Triplicate Form 10-403 (LWK) SN/128 Rev. 7-1 ~80 and "Subsequent Reports" in Duplicate I.z9-$ ~-"' '~' (2 thru 8) (!0 and ~2) '~ (13 thru 21) (22 thru 26) ::':-'::' - ' " YES 1. Is the permit' fee attached . · · IlltltlilitilteItl IeltllllOeltlltllltitteI · . 1 5.' 6. 8. Is' well to be located in defined pool ' a eeeeeeeeeeeeeeeeeeeeeeeeeeeee · Is well located proper distance from property line .................. Is well located proper distance from other wells .................... ~9/C .... Is'sufficient undedicated acreage available in this pool .., ......... Is well to be deviated and is wellbore plat included ................ Is operator the only. affected party ................................. Can permit be approved before ten-day wait .......................... ~ . . e 10. 11. 12. Does operator have a bond in force .................................. Isa conservation order needed ' eeeeeeeee,eeeeeeeeeeeeeee®eeeeeeeeeee Is administrative approval needed ' eeeee®eeeeeeeeeeeeeeeeeeee®e®®~eee® Is the lease number appropriate ..................................... 13. -14. 15. 16. 17. 18. 19. 20. 21'. Is conductor string provided .......................... Is enough cement used to circulate ~ ~ondu~or ~nd ~u~fac~ i.iii.i Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ........... ,,,,,, ...... Wlll all casing givu 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 adequat9 wellbore separation proposed ................ ' ............ 22. 23. 24. 25. 26, Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ __ Does BOPE have sufficient pressure rating - Test to 5000 psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. I~ the pre~ence of H2S gas probabl~ , ................................ ~ 27. Additional requirements ............................................. ~ . - Additional Remarks: REMARKS O. 0 H o Geology: HWK WVA ~ JAL -- Engingerin~: LC~ rev: 03/13/85 6.011 .,. INITIAL GEo. UNIT' ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi ., No special'effort has been made to chronologically organize this category of information. ;. o .o ~-.--$CHLJ~SERG~ LIS T6.~E ,/ERIFIC~I~:~ L!ST!N3 LYP OlO.H02 V={I=iC~TiD~ LiST!N3 ~ADE SER¢iCE NAME :EDIT 3~Tf :35/03111 REEL N~E :1&9351 CO~TINJ~T!DN ~ :gl ~EVIOJS REEL : CS~ENTS :LIBRARY T~PE ',--,- FILE Hr.~DER.,. :IL5 N~ME :=DiT .3Ol SERVICE N6'qE : VERSIO~ ~ : DArE : MAXIMUM LENGTH : 102~ :i~'~ E TyD:. : OREVIOOS FILE : ', .... ~NFDRM6TION RE~ORDS ~..,. V~NE ~I CONTENTS JNIT TYPE SN : 4R'O 4L4S'<4 INS B-2 000 ~N : 3N-2~ 000 FN : KUP~RUK 000 qA~3: 9E 000 TONN: 1.'DN OOO SEST: 29 000 CD3~: N.SL3PE 000 ST&T: ALASKA OOO CTRY: USa ODD MNE~ CO~TENTS JN!T TYPE PRES: E C~TE SIZE CODE IIt~ ~!~ --III 000 019 065 DO0 005 065 DO0 005 055 DO0 002 055 DO0 00~ 065 DO0 002 065 DO0 012 055 000 006 065 DO0 003 065 C~TE SIZE C3DE DO0 00! 065 LV~ OlO.M02 VERIFIC&TID'~ LiSTINS PAGE 2 JO& NUMS~ER AT ACC: 11235 ~d~ ~1, DAT~ Lg~GE3: 31 J&~ 86 LDP: H3R&R2 5DL&M '~SING TY~E FLJID 2EWSIT¥ VISSOSIfY =LJiJ L2SS MATqIX S~N2 : 9.525" 3 45~4.0' - 81T. SIIE : 8.5" TS : ~IESqTE] PSLfMER : ~0.1D LS/G RM : 3.62~ ~ 5~o0 DF : 38.0 S RMF : 3.172 @ 6~.0 DF = 9.5 ~MC = 3.020 ~ $~.0 DF = 6.Z 23 ~M ~ 8HT = .1.702 ¢ 1~4. DF LV? 013.N02 VER,tFIC~iTID~J LISTIN3 oAS~ 3 ¢ DjAL.~NDJ'TiD~ SPflERI~ALLY~ ,:3'US:D_ LDO, (DIL) ~: ~: DATA AVAILABLE: 8882.0' TJ 45~.D' ~: ¢ :DRMATIO~ O~SITY COMPENSATED LOS (FDN) ~ ,, ~2MPE~SAT:D N~dTR]N L]G (FDN) 'm ¢ DATA AVaiLABLE: 8555.0' Tg ~198.:3' :x ..-, DATA FOqMAT qESO~D ¢~" ENTRY 3LOC~S TY~Z.: SIZE1 R~PR C33E65 ~NTR¥o ~ 4 73 6~ 15 1 55 t ) 1 66 0 TYPE CLASS M3D ~. PRDSESS CDDE (OCTAL) FF O0 000 O0 3qMM O0 220 3qMM O0 ilo ]qMM O0 120 ~:~ O0 010 ~PI O0 310 O1 91PI O0 310 O1 IN' O0 280 01 S~C3 O0 350 02 3/C3 O0 355 O1 O0 420 O0 000 O0 PJ~ O0 890 03 C~.S O0 330 31 S~S O0 330 30 0 0 4 9 0 ~. D 0 4 D 0 A, 0 0 ~ 0 0 4 0 0 4 0 0 q. D 0 4 0 0 4 0 0 4 1 5~ O000000000OO00 1 58 OOO00000000000 t 5~ OOOOOOgO00OO00 1 5~ 00000000000000 i 5~ OODOOOgOOODO00 1 58 00000000000000 1 5~ 03300000000000 1 58 OOgOOOO0000000 I 5~ OOOOOO00000000 1 58 00000000000000 1 5~ 00000000000000 t SB 00000000000000 1 5~ O00000OO000000 i 5~ O000000OOOO000 1 5~ OOOO00DO000000 LV: OIO.HOZ VE~IFIC~TlPq LISTINi PaGE SP -51.1~45 SR RH]3 2.4182 DRg] ~P~ 3Z.3Z42 NC~ OE~T 3900,0000 SFLJ SP -5!.3945 SR N~HI 32,714~ NCN~ 3E~T 8~OO.O00D SFLJ SP -43.9533 GR RHD5 2.4531 DRH3 ~Pqi 35,B16~ NC~_ 3E=T 8700.0000 SFLJ SP -2.8530 SR ~H33 2.~$51 DRq2 NPql 3~,7555 NC~.~ 3E=T 8500,0000 SFLJ SP 11.8379 GR RH35 2.3538 OR,D NPqZ 31,2012 NC~L. 9E:T 8500.0000 SFL~ SP -20.151~ SR RHDB 2.4345 0R93 NPHI 32.6660 NCNL ~E~¥ 8~00'0000 SFLJ SP -37.2595 SR RH35 2.5198 0R93 ~Pqi 33.2031 NCNL gE~T 8300.00001 SFLJ SP -51,300~ SR RH3~ 2,4570 DRq3 NP~I 39.0525 NC~L DE~T 8200,0000 SFL~ SP -59,,~25~ SR RH]5 2.3733 DRH3 ~PgI 48,~281 NCNL 3EPT 8100,0000 SFLJ SP -44.3329 SR RH33 -999.2500 DRH] NPHI -999.2500 DE~ 8000,0000 SFkO SP -~9,3320 GR RH35 -999.2500 ORHD ~Pqi -999,2500 NCN~ 2.$358 iLD 130.2148 O.O~ZO NR~T 2139.5300 FC~L 2.4338 ILD 130.21~8 GR O.D$ZO NR~T 2139.5000 FCN_ 3.0042 99.6523 2035.5575 ~.~579 IL3 g0.4548 GR 0.0718 NR~T 1657.5875 FCNL 13,6560 38.9023 0,3239 NR~T 2435.5000 6.7976 ?6'5523 GR 0.0234 2285,5000 FC~ 3.8713 iLl 97,5898 SR 0.0~35 NR~T 2571.5000 FC~L 2.5~32 ILD tZ0,~5~8 GR 0,0308 NR~T~ 1935.5375 FCNL 1.7589 ILD 114,5523 GR 0.0234 NRAT 1588.6~'75 FCNL 2.3~20 ILD 1~1.5273 GR -9~9,2300 NR~T -999.2500 FCNL ~.5593 iLD 123.95~8 GR -999.2500 NR~T -999.2500 FCq~ 1~0.2145 2.8367 ~.3393 100.2148 583.3125 2.7307 99. 6523 3.1370 529.8125 4.4031 90.4548 3.0559 459.6905 14.4004 58.9023 2.8127 774.3125 6.2507 76.65!3 2.9573 715.3125 3,6~$7 97.539~ 3,0322 793.3125 2.3967 120'4548 3.3323 534.31~5 1.6553 114.6323 3.8538 ~22.1~06 2.t~87 -999,2500 -999.2500 -9~9,2500 2,7268 -9'99,2500 -999,2500 CALI RNR~ IL~ SALI RNR~ IL4 CALI !LM RN~ IL4 ~ALI RNR& ILM CALI RNR~ ILM CALI RNR4 ILM CALl RNR~ ILM ~ALI ILM RNR& !LM CALZ RNR~ Z.2854 5.5020 3.1292 2,2854 8.1~95 3.1292 2.7932 g.3223 3.2327 4.15~7 ~,7207 3.5~91 13.5504 $. 3848 3.1448 6.4148 8.9551 3.1936 3.5526 9,0545 3.2605 2,6¢~8 9.1895 3.5233 1.7422 9.0723 4.0007 2.2268 -999,2500 -999,2500 2.8792 -999.2500 -999.2500 35~T 7900.9;300 SP -45.'3533 :~]~ -')99.2500 NP~I --)-39.2500 DEPT 7300.0000 SP -41.9253 RH35 -999.2500 NPqI -9`39.2503 35~T 7700.0000 SP -39.1133 qH]5 -")99.2503 WPHI -999.2500 DE:~T 7500.0000 SP -~8.925~ qH]5 -999.2500 WPqI -999.2500 ]E~T 7500.0000 SP -25.931~ RH35 -999.2500 ~PqI -~99.2500 DE~T 7400.0000 SP -45. 1755 RHD5 -999.2500 qPqI -~99.2500 DE:~T 7300. 0000 SP -35.0820 RH]5 -`)99. 2500 ~PqZ -999.2500 DE~T 7200.0000 S'P -35. 330~ qH35 -999.2500 NPqI -999. 2503 DEPT 7100.0000 SP -43.1133 RH35 -~99.2500 ~PHI -999.2500 ~]EPT 7000. 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