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185-170
STATE OF ALASKA ALA"OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations fl Fracture Stimulate r Pull Tubing r Operations Shutdow n Performed: Suspend Perforate p � n Other StimulateAlter Casing r Change Approved Program Plug for Redrill fl Perforate New Pool r Repair Well Re-enter Susp Well rOther: Set)fat insg 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill`Number:J ConocoPhillips Alaska, Inc. Development Exploratory r _ 185-170 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20045-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25587 KRU 2H-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8060 feet Plugs(measured) 7519' true vertical 6302 feet Junk(measured) none Effective Depth measured 7953 feet Packer(measured) 7424, 7442, 7486, 7709 true vertical 6228 feet (true vertical) 5857, 5869, 5901, 6058 Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 106 106 SURFACE 2868 9.625 2902 2810 PRODUCTION 8012 7 8046 6293 RECEIVED Perforation depth: Measured depth: 7641-7675, 7732-7742, 7757-7787 AUG 18 2015 True Vertical Depth: 6011-6035,6075-6082,6092-6113 scoviE'J NOV 1 2 2015 AOGCC Tubing(size,grade,MD,and TVD) 2.875,J-55, 7727 MD,6071 TVD Packers&SSSV(type,MD,and TVD) UPPER PACKER-OLGOONIK PARAGON TTS UPPER PACKER @ 7424 MD and 5857 TVD LOWER PACKER-OLGOONIK PARAGON TTS LOWER PACKER @ 7442 MD and 5869 TVD PACKER-BROWN HB PACKER @ 7486 MD and 5901 TVD PACKER-BROWN 1-B PACKER @ 7709 MD and 6058 TVD SAFETY VLV-BAKER FVL SAFETY VALVE(LOCKED OUT 1/8/87)@ 1813 MD and 1809 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 103 584 330 207 216 Subsequent to operation 124 590 253 191 200 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I✓ Exploratory fl Development e Service fl Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil 1 Gas r WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Tyson Wiese C ,263-4250 Email Tyson.M.Wiese(a�conocophillips.com Printed Name Tyson Wies Title Sr. Wells Engineer Signature 2( Phone:263-4250 Date 5 --Lv 1 Uri- 9/z715 Form 10-404 Revised 5/2015 �� Submit ri inal Only RBDMS AUG 1 9 2015 KUP PROD • 2H-07 Conoc©Phil ips Well Attributes Max Angle&MD TD A1,3„,,,,)tlz; Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) -Act Btm(ftKB) [drlom,iim 501032004500 KUPARUK RIVER UNIT PROD 53.16 3,400.00 8,060.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 29-07,7/28/20152:15:10 PM SSSV:LOCKED OUT Last WO: 36.71 12/20/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _ _ ,..... ,....Last Tag:SLM 7,821.0 5/6/2015 Rev Reason:SET PATCH hipshkf 7/28/2015 HANGER,31.4 IIII it teasing strings Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ° CONDUCTOR 16 15.062 35.0 106.0 106.0 62.50 H-40 WELDED anlU Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 34.6 2,902.4 2,810.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 34.5 8,046.2 6,292.6 26.00 3-55 BTC I Tubing Strings Tubing Description String Ma...l ID(in) [Top(ftKB) Set Depth(ft-1 Set Depth(ND)1...Wt(Ib/ft) Grade Top Connection TUBING 27/8 2.44111 31.4 7,727.51 6,071.5 6.50 J-55 EUE-8rd -A-Ai CONDUCTOR;35.0-106.0• Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) � 31.4 31.4 0.16 HANGER FMC TUBING HANGER 2.875 SAFETY VLV;1,812.8 Ot.: 1,812.8 1,809.1 11.92 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 1/8/87) 2.310 7,474.5 5,892.6 45.08 PBR BROWN PBR 2.312 GAS LIFT;2.261.5 7,486.1 5,900.8 45.07 PACKER BROWN HB PACKER 3.250 7,630.8 6,003.4 44.88 BLAST JT BLAST JOINTS(2) 2.441 7,707.3 6,057.3 45.42 LOCATOR BOT LOCATOR w/SEAL ASSEMBLY 2.440 7,708.8 6,058.4 45.42 PACKER BROWN 1-B PACKER 3250 7,721.1 6,067.0 45.48 NIPPLE CAMCO D NIPPLE NO GO 2.250 SURFACE;34.6-2,902.4- 7,726.6 6,070.8 45.51 SOS BOT SHEAR OUT SUB,TTL ELMD @ 7716'SWS 2.441 PPROF 9/25/2000 GAS LIFT;4,291.2 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) illTop(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) GAS LIFT;5,699.9 _ 7,424.0 5,856.9 45.15 UPPER OLGOONIK PARAGON TTS UPPER PACKER 7/23/2015 1.370 PACKER 7,426.2 5,858.5 45.15 SPACER PATCH SPACER PIPE 7/21/2015 1.810 GAS LIFT,6,514.8 t.' PIPE I 7,441.7 5,869.4 45.13 LOWER OLGOONIK PARAGON TTS LOWER PACKER 7/21/2015 1.370 PACKER GAS LIFT;6,988.5 7,519.0 5,924.0 44.97 PLUG 2-7/8"PARAGON RBP W/DEBRIS SUB(2.28"OD, 6/5/2015 0.000 8.5'OAL) vUPPER PACKER;7,424.0 !t Perforations&Slots SPACER PIPE;7,426.2 Dens Dens GAS LIFT;7,431.2 Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com J7,641.0 7,675.0 6,010.6 6,034.6 C-4, 2H-07 2/9/1986 12.0 IPERF 5"Casing Gun LOWER PACKER;7,441.7 . Lit 7,732.0 7,742.0 6,074.6 6,081.6 A-5,2H-07 10/22/2011 4.0 IPERF 2.125"Deep Millenium I Strip Gun,90 Deg Phase,(91-45 deg), Orientated Low Side PBR;7,474.5 i 7,757.0 7,787.0 6,092.1 6,113.1 A-4,2H-07 2/9/1986 4.0 IPERF 4"Casing Gun PACKER;7,486.1 •' Mandrel Inserts I St ati on Top(TVD) Valve Latch Port Size TWO Run PLUG;7,519.0 ' N. Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,261.5 2,240.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,310.0 5/8/2015 12:00 GAS LIFT;7,523.5 filwill0 2 4,291.2 3,773.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,338.0 5/8/2015 12:00 • 3 5,699.9 4,700.7 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,324.0 5/8/2015 4:30 4 6,514.8 5,237.3 CAMCO KBMG 1 GAS LIFT OV BK 0.188 0.0 6/6/2015 2:30 GAS LIFT;7,593 0 ;_ 5 6,988.5 5,553.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/14/2008 2.00 I 6 7,431.2 5,862.0 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/7/2015 6:00 7 7,523.5 5,927.2 CAMCO KBMG 1 PROD 'HFCV BEK 0.000 0.0 5/9/2015 8 7,593.0 5,976.5 CAMCO KBMG 1 PROD HFCV BEK 0.000 0.0 5/9/2015 9 7,696.4 6,0496 CAMCO KBMG 1 PROD HFCV BEK 0.000 0.0 5/9/2015 IPERF;7,641.0-7.R75.0�� Notes:General&Safety -- --4 End Date Annotation a 10/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;7,696.4 I LOCATOR,7,707.3 gl' PACKER;7.708.8 NIPPLE;7.721 1 SOS;7,726.6 it IPERF;7,732.0-7,742.0 IPERF;7,757.0-7,787.0 PRODUCTION;34.5-8,046.2 2H-07 WELL WORK SUMMARY ,DATE . SUMMARY 4/23/2015 (AC EVAL) : PROACTIVE TIFL FAILED, IA INFLOWED 1657' DURING IA BLEED. 5/6/2015 DRIFT TBG &TAG TD @ 7821' RKB; LEAK DETECT W/ HOLEFINDER & DETERMINE OV LEAKING @ 6515' RKB; SET CATCHER @ 6730' RKB; MAKE SEVERAL ATTEMPT TO PULL OV @ 6515 (NO SUCCESS). IN PROGRESS. 5/7/2015 PULL OV& REPLACE IN KIND @ 6515' RKB; W/HOLEFINDER OBTAIN GOOD P.T. ON TBG. IN PROGRESS. 5/8/2015 PULLED GLV's FROM 5700', 4291', &2262' RKB. SET NEW GLV's AS PER DESIGN. RAN HOLEFINDER TO 6724' SLM, PT TBG 2500 PSI (PASSED). IN PROGRESS. 5/9/2015 PULLED TBG STOP @ 6723' SLM. PULLED DPHFCV's & REPLACED IN KIND @ 7697', 7593', & 7534' RKB (NO EROSION); JOB COMPLETE. 5/17/2015 (AC EVAL): RE TIFL-FAILED DUE TO IA INFLOW& PRESSURE INCREASE DURING BLEED. 6/5/2015 MEASURED SBHP @ 7767' RKB (6099' TVD)2732.2 psia, 157.8* F; GRADIENT STOP @ 7625' RKB (5999'TVD)2688.8 psia, 155.6* F. DRIFTED TBG TO 7550' RKB FOR RBP AND BRUSHED BETWEEN 7486' RKB AND 7524' RKB WHILE LRS PUMPED 52 BBLS DIESEL. SET PARAGON 2 7/8" RBP W/ DEBRIS SUB (2.28" OD, 8.5' OAL) © 7519' RKB. *JOB IN PROGRESS. 6/6/2015 DEPLOYED 2.25"x 8' CATCHER ONTO RBP PLUG @ 7519' RKB. PULLED ST#4 OV© 6515' RKB. LRS CIRC'd OUT TBG/IA W/ 163 BBL SW&78 BBL DIESEL & U-TUBED. REPLACED ST#4 IN KIND. *JOB IN PROGRESS. 6/7/2015 LRS ATTEMPTED MIT-T TO 2500#, BUT IA TRACKED, THEN ATTEMPTED CMIT TxIA, FAILED. PERFORMED LEAK DETECT LOG FROM 7500' RKB. FOUND LEAK @ 7431' RKB (APPEARED TO BE TOP COLLAR OF GLM ST#6). PULLED DMY VLV IN ST#6 (GOOD CONDITION)AND REPLACED IN KIND. LRS ATTEMPTED MIT-T TO 2500# BUT IA TRACKED. WILL T/S FAILED CMIT NEXT DAY. *IN PROGRESS. 6/8/2015 Performed TxIA combo to 2500 psi passed. T/I/O starting PSI 2500/2100/790. 15min. results 2425/2025/790. 30min. results 2400/2000/790. Job complete. 6/10/2015 LOG 24 ARM CALIPER FROM 7480' TO SURFACE. TAGGED CATCHERSUB AT 7511'AND HAD TO PULL 2225 LBS OF TENSION TO FREE TOOLS. PULLED CATCHER WITH TOOL STRING. 7/20/2015 PULL RBP FROM 7519' RKB, BRUSH PATCH SETTING AREA FROM 7350' -7500' SLM...JOB IN PROGRESS. 7/21/2015 B&F TBG & DRIFT FOR PATCH, SET 2-7/8" PARAGON TTS LOWER PACKER....JOB IN PROGRESS. 7/22/2015 CMIT-TxIA TO 2500# USING TTS TEST TOOL SET IN LOWER PACKER, SEALS DIDN'T COME BACK ON TEST TOOL, RUN DRIFT THROUGH PACKER & FLUSH TBG W/68 BBLS OF DIESEL....JOB IN PROGRESS. 7/23/2015 SET 2.29" OLGOONIK PARAGON TTS PATCH ( OAL = 23') @ 7424"-7444' RKB, PERFORM 30 MIN PASSING MIT-T TO 3000#, PERFORM PASSING DRAW DOWN ON IA TO 0# FOR 30 MIN JOB COMPLETE. 7/28/2015 (AC EVAL): RE TIFL-PASSED. 2,59 4C7 WELL LOG TRANSMITTAL DATA LOGGED M4/2015 .i K.BENDER To: Alaska Oil and Gas Conservation Comm. June 18, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 " .: VI JUN 2 6 2U1j RE: Multi Finger Caliper(MFC) : 2H-07 Run Date: 6/10/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2H-07 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20045-00 SCO�e) 11,��_ GUIs PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: /Ai ,/, Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. _J ~ ~- i ~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: o Diskettes, No. r; Maps: Grayscale items: Q Other, No/Type [] Other items scannable by large scanner Poor Quality Originals: ~)-[(.~' · ?' '] OVERSiZED(Non-Scannable) Other: . ,_.. ~ [] Logs of various kinds [] Other TOTAL PAGES: -"~ ~) ORGANIZED BY: NOTES: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: '"7 ~::) (at the time of scanning) SCANNED BY; BEVERLY I~'~VlNCENT SHERYL MARIA LOWELL DATE: ReScanned (done) RESCANNEDBY: BEVERLY BREI~ VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Qua lity Checked {done) RevlNOTScanned.wpd TATE OF ALASKA ALASKA OIL AN A S CONSERVATION COMMISSION • . REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perforations r Stimulate r Other r Alter Casing r Pull Tubing `°" Perforate New Pool r Waiver (- lime Extension r Change Approved Program r Operat. Shutdown r Perforate Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r - 185 - 170 3. Address: 6. API Number: Stratigraphic j- Service r P. O. Box 100360, Anchorage, Alaska 99510 — 50 - 103 - 20045 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25587' .- 2H - 9. Field /Pool(s): .. Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8060 feet Plugs (measured) None true vertical 6302 feet Junk (measured) None Effective Depth measured 7953 feet Packer (measured) 7476, 7699 true vertical 6228 feet (true vertucal) 5894, 6051 Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 106 106 SURFACE 2868 9.625 2902 2808 PRODUCTION 8012 7 8043 t 'Lt x.91 I . 4 °� ` ,...,,. uiar Perforation depth: Measured depth: 7641'- 7675', 7732'- 7742', 7757' -7787' NOV 9 8 2 011 True Vertical Depth: 6011'- 6035', 6075'- 6082', 6092' -6113' \Ia ka Oil & ria C6n,. 0/11 ' 11 USSion 9 (size, grade, TVD) 2.875, J - 55, 7717 MD, 6064 TVD �f�CF a Tubin size, rade, MD, and TVD . � Packers & SSSV (type, MD, and TVD) PACKER - BROWN HB PACKER @ 7476 MD and 5894 TVD �, PACKER - BROWN 1 -B PACKER @ 7699 MD and 6051 TVD SSSV - BAKER FVL @ 1803 MD and 1800 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 96 590 233 -- 193 Subsequent to operation 147 603 288 -- 192 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development • Service r Stratigraphic r 15. Well Status after work: Oil f . Gas F WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG " GINJ '" SUSP 1 SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce i'p 265 -6471 Printed Name John Peirce Title Wells Engineer Signature reec Phone: 265 -6471 Date .ii ,.., i Form 10 -404 Revised 10/2010 FISDAIlS NOV 0 9 Bill 7 / /• �? . ((Submit Original Only 2H -07 Well Work Summary DATE SUMMARY 10/10/11 DRIFTED TBG WITH 10' x 2.125" TO 776n.M. PROPOSED PERFS: 7732 - 7742' R.. READY ' FOR E /L. 10/22/11 PERFORATED A -5 SAND AT A DEPTH OF 772'- „�Z.42' WITH 2 -1/8” X 10' STRIP GUN LOADED, DEEP STAR MILLENIUM CHARGES, 90 DEG ( + -45 DEG) PHASING, 4 SPF. RAN DECENTRALIING MAGNET TO ORIENT 90 DEGREE PHASEING TO LOW SIDE. RIGGED DOWN AND TURNED WELL OVER TO DSO. .U • 2H -07 COnocOPhtllips s L Well Attributes Max Angle & . MD TD - Ala aari a y "" Wellbore API /UWI Feld Name Well Status Inorode) I MD OMB) Act Bbn (868) ( 'i' 501032004500 KUPARUK RIVER UNI f I PROD 53.16 3,400 00 8060 0 ok. '• ' Comment H2S (pp n) Date Annotation End Date KB (ft) Rig Release Date "• 21 ±81, SSV. LOCKED OUT 100 L 7/11!2009 1 Last WO: 36.71 12/20/1985 Weli C0nfiy SG1emetc11 5/1 - 317:66 PM _ A notation [Annotation 11 !Depth [End Date [Annotation ( Last Mod. [End Date Last Tag - SLM 7/62.0 10/10/2011 Rev Reason: ADD PERFS __ 1 ninam 11/2/2011 HANGER 22 Casing Strings �` - Casing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) .. [ String Wt... String ._ [String Top Thrd 1 CONDUCTOR 16 15.062 35.0 106.0 106 0 62.50 Ii110 WELDED , ip g_ _._ gI (KB Casing Description String 0... String ID ... Top (ftKe) Set Depth (f... Set Depth (TVD) .. String W[... String ... String Top Thrd SURFACE 95/8 8.921 34.6 2,902.4 2,807.9 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftK6) Set Depth (9... Set Depth (ND) String Wt... String String Top Thrd PRODUCT ION 7 6 276 31 5 8,043 2 6,290.6 26 00 J-55 BTC ` Tubing Strings T ub i ng Description String 0... String ID ._ [Top (HKB) 27/8 2.441 [Set Depth (1. [Set Depth (TVD) !String Wt... [String .,. String Top Thrd 'TUBING 21 7,717.7 6,064.5 6.50 J -55 EUE -8r0 Completion Details Top Depth (ND) Top Inc' Nomi._ Top (/KB) (°) Item Description -_. Comment _ -_ ID (in) CONDUCTOR, 21.6 21.6 0.15 HANGER FMC TUBING HANGER 2.875 35.180 i 1,803.0 1,799.5 11.81 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 1/8/87) 2.310 7,464.7 5,885.7 45.19 PBR BROWN PBR -_- 2.312 SAFETY VLV , � 7,476.3 5,893.9 45.14 PACKER BROWN HB PACKER 2.347 1 8113 7,621.0 5,996.4 44.80 BLAST JT 2.441 7,697.5 6,050.4 45.36 LOCATOR BOT LOCATOR w/ SEAL ASSEMBLY 2.441 GAS LIFT „_ ' -- 2,252 7,699.0 6,051.5 45.37 PACKER BROWN 1 -B PACKER 2.347 ". 7,711 -2 6,059.9 45.54 NIPPLE CAMCO D NIPPLE NO GO 2.250 i iii 7,716.8 6,063.8 45.56 SOS BOT SHEAR OUT SUB, TTL ELMD @ /716' SWS PPROF 9125!2000 2.441 Re one & Slots Shot SURFA _ CE, „_ - Top (TVD) Btm (TVD) Dens 35 - I ,Top (AKB„)_Bhn (18031 (HKB) Zone Date ( Tyr Comment 7,641 7,675 6,010.5 6,034.6 C -4, 211-07 2/9/1986 12.0 IPERF 5" Casing Gun GASIT8ti, - _ " .. 7,732 7,742 6,074.6 6,081 6 A -5, 211 -07 10/2212011 4.0 IPERF 2.125" Deep Mdlenium Strip Gun, 90 It Deg Phase, ( +/ -45 deg), Orientated Low Side GAS LIFT, - 5,690 7,757 7,787 6,092.1 6,113 -1 A -4, 2H -07 2/9/1986 4.0 IPERF 4" Casing Gun Notes: General & Safety GAS LIFT, ___ 7, End Date Annotation 6.505 0/ 10/26/2010 NO I 0 View Schematic w/ Alaska Schematic9.0 GAS LIFT. 6,975 GAS L ,621 IFT.__.__ -.__ : ma4i ] L : PBR 7,465 Y ■ PACKER, 7,476 - GASLIFT, -�.-: 7,514 - GAS LIFT, 7,583 IPERF, 7,641-],6]5 I. GAS LIFT, 7,687 LOCATOR, ],698 PACKER, 7,699 I NIPPLE, ].]11 -'-_ -- - Man drel Details - ;:',. , %4141g - ft - 4,1:, ' Top Depth Top Port (TVD) Inc/ OD Valve Latch Size TRO Run SOS,7,717- _____.._..._ : Stn Top(ftKBJ - __MftKS) r) Make i Model (in) Sere Type Type En) (psi) Run Date Com... 1 2,251.6 2,231.5 20.50 CAMCOIKBMG 1 GAS LIFT GLS BK 0.125 1,317.0 7/12/2008 IPERF, 2 4,281.4 3,767.4 48.12 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,332.0 7/12/2008 7,732 r - - 3 5,690.1 4,694.1 47.84 CAMCO KBMG 1 GAS LIFT GLV �. BK 0.156 1,315.07/12/2008 4 6,505.0 5,231.0 48.84 CAMCO KBMG 1 GAS LIFT OV BK 0.188 0.0 7/12/2008 7,75.7 5 6,9783 5,547.0 46.99 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/14/2008 - 6 7,421.4 5,855.4 45.36 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/142008 1 7 7,513.7 5,919.4 44.02 CAMCO KBMG 1 PROD DHFCV BEK 0.000 0.0 7/112008 8 7,583.2 5,969.5 44.53 CAMCO KBMG 1 PROD DHFCV BEK 0.000 0.0 7/112008 PRODUCTION, 9 7,686.5 6,042.7 45.28 CAMCO KBMG 1 PROD DHFCV BEK 0.000 0.0 7/11/2008 31-8,043* TD, 8,060 _ -_ - • Conac~hillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: <; ~ ~~;F LJ ~~~~ °~~ .. APR 2 '~ 2010 . ,asks tJir ~ has Cons. Ccrnmissinr Anohaaae ~ ~s-X70 a ~~'7 Enclosed please find a spreadsheet with a list of wells from the Kuparulc field (KRIJ). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped April 15, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 2B. 2E. 2G. 2H. 2K. 2M. 2V. 2W. 2X. 2Z ~ 3S PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-05 50029210670000 1840040 24" n/a 24" n/a 4.2 4/16/2010 2B-OS 50029210790000 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 26-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF n/a n/a Na 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF n/a 22" n/a 3.4 4/16/2010 2H-07 50103200450000 1851700 SF Na 17" Na 2.1 4/15/2010 2H-09 50103200500000 1852590 SF Na 17" n/a 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" Na 2.5 4/15/2010 2K 19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 4/15/2010 2M-07 50103201780000 1920800 SF n/a 17" n/a 3.4 4/15/2010 2M-08 50103201840000 1921010 SF n/a 17" Na 2.1 4/1512010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/15/2010 2M-22 50103201700000 1920490 SF n/a 17" Na 2.5 4/15/2010 2M-28 50103201740000 1920700 SF Na 18" Na 2.1 4/15/2010 2V-06 50029210540000 1831790 SF Na 19" Na 7.6 4/16/2010 2V-10 50029213100000 1850480 SF Na 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-03 50029212740000 1850110 SF Na 37" Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF Na 17" n/a 6 4/17/2010 2Z-11 50029213790000 1851380 SF n/a 19" Na 2.5 4/15/2010 2Z-12A 50029213800100 1951480 SF n/a 19" n/a 2.5 4/15/2010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF Na 16" n/a 2.1 4/15/2010 3S-09 50103204320000 2022050 SF Na 45" Na 23 4/17/2010 ...._".....,-.~.... Schlumbel'ger /¿;ó--I1D , N ~ 1 2007 S{;A,NNED j\J ' 06/14/07 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NO. 4300 ;~ 0 ZO(J7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 " 4:'<? Field: Kuparuk Well Job# Log Description Date BL Color CD 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-OS 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ') ') ~~!Æ~! :} !Æ~!Æ~~~ffiu AI4ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR November 26, 2004 333 w. -¡rn AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27~7542 ~;O , .'5'(/' \ "'......Ûl,....."'.. '.' ..., I \11 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) test report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 1 0, 2004. Attached is a copy of the SVS Test Repol1. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, -'as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, (f~B~~c. James B. Regg -ll Petroleum Inspection Supervisor Attachment <~'C-"A" N. N' Ef'" . íA" N ¿I' 1 2005 ~ . .,~~. ,J ." ~ ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report ) Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: Waived Submitted By: Brad Gathman Field/Unit/Pad: KRU 2H Separator psi: LPS Date: 11/1 0/2004 96 HPS ,..-,.fflil~'~~{L, ':>'-"0" '.' , Well Permit Separ Number Number PSI 2H-Ol 1840770 2H-02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H-09 1852590 96 2H-10 1852600 96 2H-11 1852610 I 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H-15 1840860 2H-16 1840870 2H-17 2000190 '~;¡fÎ?r(l,pi~tt Set LIP PSI Trip \~l~:cfJ9j':é ;';ttcr'c"y'-r~' fþ:,v;'!;.'/'ci;;;'~~'"?'~);bi4:ñ;r$"~W fUÆ'" "'~~1~4jr¡¡]' ";¡";~>"'~f?:~ '~"Ø¡,J;.~i~:;~, 'JJðk>:Y~¥ l.-.eì:lv:n.e"eSllil.LN:lJa"e : ,4c.U¡''.. , ..e':!¡~;, .':~.;...,.,~,.,.:.t;""',.!.!..:. 'i"':' ',"'.~~,.y:.,¡,:,..:',.,.'.",,' . <j".;1' :'~<;::r~:,,,:,,"k");..{:,;'. <, ,.'h.,¡;::,::;.,t~~',7.' ,,~"'i~'!¡'~' Test Test Test Date Tested and or Oil, WAG, GINJ, Code Code Code Passed Retest or SI GAS, CYCLE, SI WAG WAG WAG WAG OIL OIL OIL OIL OIL 11/11/2004 OIL OIL 11/11/2004 OIL WAG OIL WAG WAG WAG 70 50 P P 70 65 P P 70 70 P P 70 50 P P 70 55 P P 70 50 P 4 70 55 P P 70 60 P 4 70 50 P P 96 Wells: 9 Components: 18 Failures: 2 Failure Rate: 11.11°1B 90 Day Remarks: 2H-IO & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-10-04.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimutate_X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 129 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchora.ge, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 169' FNL, 76' FWL, Sec. 36, T11 N, R8E, UM (asp's 498475, 5948694) 2H-07 At top of productive interval 9. Permit number / approval number 1341' FNL, 1441' FEL, Sec. 36, T11 N, R8E, UM (asp's 502238, 5947522) 185-170 At effective depth 10. APl number 50-103-20045 At total depth 11. Field / Pool 1448' FNL, 1159' FEL, Sec. 36, T11 N, R8E, UM (asp's 502521, 5947416) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8060 feet Plugs (measured) Tagged PBTD (9/25/00) @ 7774' MD. true vertical 6302 feet Effective depth: measured 7774 feet Junk (measured) true vertical 6104 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 106' 16" 205 Sx AS II 106' 106' SURF CASING 2773' 9-5/8" 850 Sx CS III & 480 Sx 2902' 2810' CS II PROD CASING 7914' 7" 435 Sx Cl G & 175 CS I 8043' 6290' Perforation depth: measured 7641 - 7675'; 7757- 7787' ~:/[~. ~. '7 true vertical 6010 - 6035'; 6092 - 6113' Alask~ Oii& Gas Co~-%. C:ornro. issiov Ar~chorage Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55, Tubing @ 7718' MD.k.~~-"/i~-" 'i [~'~ '[ i~t ¢:'' } /~/i ,i Packers & SSSV (type & measured depth) Brown 'HB' Packer @ 7486' MD; Brown 'I-B' Packer @ 7699' MD. ' ~" ~- ~' Baker'FVL' (Locked Out 1/8/87)@ 1813'MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Da y Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 371 335 203 - 206 Subsequent to operation 831 624 413 - 198 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Dally Report of Well Operations ___X Oil __X Gas __ Suspended __ Service 17' I hereby certify t~,~//~the f°regoing is true and c°rrect t° the best °f mY knowledge' e~ ,~/~ ,,~/,~ ] ' Signed /,~~,, /~~ Title: D at r'repa'fed'by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 21-1-07 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATIVI ENT 6/7/00: RIH & tagged fill at 7784' MD. 6/8/00: RIH & set a CA2 Plug in the 'D' Nipple at 7711' MD, to isolate the open 'A' sand perforation interval at: 7757 - 7787' MD 6~27~00: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 16/20 mesh proppant, through the 'C' sand perforation interval at: 7641 - 7675' MD Pumped Breakdown: a) 195 bbls 20# Gel @ 17 - 20 bpm, followed by b) Shutdown. ISIP @ 1994. Resumed pumping Scour Stage: c) 100 bbls 40# Crosslinked Pad, followed by d) 50 bbls Crosslinked Gel w/lppa proppant, followed by e) 92 bbls 20# Linear Flush @ 15 bpm, followed by f) Shutdown. Resumed pumping Data Frac: g) 100 bbls 40# Crosslinked Gel, followed by h) 46 bbls 20# Linear Gel Flush, followed by i) Shutdown. ISIP @ 2357. Resumed pumping Frac Treatment: j) Crosslinked Pad stage, followed by k) Crosslinked Slurry stages w/proppant ramped up in stages from 1 to 10 ppa, followed by I) Flush stage, followed by m) Shutdown. Placed a total of 75,000 lbs of proppant into the formation. RE). 7/2/00- 8/27/00: Performed multiple bailing operations to bail proppant fill in tubing down to CA2 Plug set in 'D' Nipple at 7711' MD. Pulled Plug - 8/27/00. 9/25/00: RIH & tagged fill at 7774' MD. Returned the well to production w/gas lift & obtained a valid well test. %. MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 2, 2000 THRU' Tom Maunder, P. I. Supervisor FROM- Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 2H Pad Saturday, December 2,-2000: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2H Pad. As the attached AOGCC Safety Valve System Test Report indicates .I witnessed the testing of 9 wells and 18 components with four failures observed. The Iow pressure pilots on wells 2H-5,2H-6 and 2H-12 tripped well below the required set point and : the surface safety valve on well 2H-12 failed to pressure test. The three failed pilots were adjusted and retested at the time of this test. The failed valve will be repaired and retested by the operator. The 22.2% failure rate will require a retest of this Pads safety valve System in 90 days rather than the normal ,120~day cycle. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with · Summary: I witnessed the semi annual SVS testing at 2H Pad in the KuParuk ' River Field. KRU 2H Pad, 9 wells, 18 components, 4 failures 22% failure rate Attachment: SVS KRU 2H Pad 12-2-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2H Pad 12-2-00 CS.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: Emie Bamdt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 2H Pad Separator psi: LPS 96 HPS 12/2/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2H-01 1840770 2H-02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 70 20 3 P 12/2/00 OIL 2H-06 1851690 96 70 10 3 P 12/2/00 ' OIL 2H-07 1851700 96 70 60 P P OIL 2H-08 1851710 96 70 60 i) P ' OIL 2H-09 1852590 96 70 50 P P ' -OIL 2H-10 1852600 96 70 50 P P . OIL 2H-11 1852610 96 70 50 P P OIL 2H-12 1852620 96 70 10 3 4 remarks 2H- 13 1840960 2H- 14 1840950 96 70 60 P P oIL 2H- 15 1840860 . 2H-16 1840870 2H- 17 2000190 Components: 18 Failures: 4 Failure Rate: 22.0% ~]90 oar three failed pilots repaired and retested, failed SSV to be repaired and retested by op Pad on 90 day test cycle Wells: 9 Remarks: 12/4/00 Page 1 of 1 SVS KRU 2H Pad 12-2-00 CS.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate X Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 169' FNL, 76' FWL, Sec 36, T11 N, R8E, UM At top of productive interval: 1341' FNL, 1441' FEL, Sec 36, T11N, R8E, UM At effective depth: 1420' FNL 1231' FEU Sec 36, T11N, R8E, UM At total depth: 1448' FNL 1159' FEU Sec 36, T11N, R8E, UM 5. Type of Well: Development Exploratory Stratagrapic Service 6. Datum of elavation (DF or KB feet): 130' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 2H-07 9. Permit number/approval number: 85-170 10. APl number: 50-103-20045-00 11. Field/Pool: Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 8060 feet true vertical 6302 feet Effective Deptl measured 7953 feet true vertical 6302 feet Casing Conductor Surface Length Size 80' 16" 2867' 9-5/8" 8012' 7" Production Liner Plugs (measured) None Junk (measured) None Cemented Measured depth 205 Sx AS II 106' 850 Sx CS III & 2902' 350 Sx CS II w/130 Sx CS II top job 435 Sx Class G & 8043' 175 Sx CS I True vertical depth 106' 2810' 6289' Perforation Depth measured true vertical 7641'-7675',7757'-778; 6010'-6034',6092'-611~ ORIGINAL Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 7718' Packers and SSSV (type and measured depth) Pkrs: Brown HB @ 7486' & Brown 1-B @ 7699'; SSSV: Baker FVL (locked out) @ 183~ 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 3/14/98. Intervals treated (measured) 7757' - 7787' Treatment description including volumes used and final pressure Pumped 237762 lbs of 20/40 and 12/18 ceramic proppant into the formation, final pressure = 7500 psi. 14. Prior to well operation Subsequent to operation Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 519 331 94 863 611 608 Casing Pressure 875 897 Tubing Pressure 269 266 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _~X 16. Status of well classification as: Oil _~X Gas _ Suspended __ Service _ 17. I hereby certify~hat the foregoing is true and correct to the best of my knowledge. Signed ~~~~L ~ / Title: Wells Superintendent lO-4O4 Date ' SUBMIT IN DUPLICATE ARCO Alaska, Inc. ,~UPARUK RIVER UNIT A K1 (2H-07(W4-6)) WELL JOB SCOPE JOB NUMBER 2H-07 FRAC, FRAC SUPPORT 0117981319.1 'DATE DAILY WORK UNIT NUMBER 03/14/98 "A" SAND REFRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes (~ No (~) Yes (~ No DS-YOAKUM CHANEY FIELD AFC# CC# DAILY COST ACCUM COST Signed... ESTIMATE KD1863 230DS28HL $140,101 $149,884 ... ~.r/, . , Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer~nn DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 237762 LBS OF PROP IN THE FORMATION W/12# PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 7500 PSI & F.G. (.70). FREEZE PROTECTED TBG DOWN TO 3400' RKB W/20 BBLS OF DIESEL. TIME 06:30 09:00 09:25 10:35 11:30 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, AND APC VAC TRUCK. HELD SAFETY MEETING (13 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO15 BPM. MINIMAL PRESSURE CHANGE ON WHTP DURING INITIAL BREAKDOWN (300 PSI DECREASE). SLURRY VOLUME PUMPED 388 BBLS. USED 5871 LBS OF #20/40 PROP FOR SCOURING. MAXIMUM PRESSURE 7500 PSI AND ENDING PRESSURE 3600 PSI. STEPPED RATE DOWN AT THE END OF THE STAGE. S/D AND OBTAINED ISlP OF 1584 PSI W/F.G. @ (.70). MONITORED WHTP AND PULSED TO CLOSURE. CLOSURE TIME 18.8 MINS @ 1275 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 158 BBLS. MAXIMUM PRESSURE 6000 PSI AND ENDING PRESSURE 3900 PSI. S/D AND OBTAINED ISIP OF 1776 PSI W/F.G @ (.73). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 12 MINS @ 1473 BBLS. PAD VOLUME = 415 BBLS. PUMP FRAC W/50#-->40# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. SLURRY VOLUME PUMPED 1631 BBLS. MAXIMUM PRESSURE 5500 PSI AND ENDING PRESSURE 5000 PSI. PUMPED 238894 LBS OF PROP (27952 LBS OF #20/40 & 210942 LBS OF #12/18). INJECTED 237762 LBS OF PROP IN THE FORMATION W/ 12# PPA OF #12/18 @ THE PERF'S. LEFT 1132 LBS OF PROP IN THE WELLBORE AND EST FILL TO BE @ 7757' RKB. EST BHP TO BE 2150 PSI. FREEZE PROTECTED TBG DOWN TO 3400' RKB W/20 BBLS OF DIESEL. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $680.00 APC $6,100.00 $6,850.00 DIESEL $400.00 $400.00 DN HOLE EQUIP PURCH $0.00 $706.00 DOWELL $131,621.59 $131,621.59 HALLIBURTON $0.00 $5,047.00 LITTLE RED $1,980.00 $4,580.00 , TOTAL FIELD ESTIMATE $140,101.59 $149,884.59 TIME 13:30 14:30 15:30 LOG ENTRY STARTED R/D. DEPRESSL _.:D INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. REMOVED TREESAVER (ALL CUPS I~ETURNED). CONTINUED R/D. R/D COMPLETED AND ALL WELL SERVICE GROUPS LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. ARCO Alaska, Inc. April 30, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION 2B-03 Stimulate 2 H - 0 5 Stimulate 2 H- 0 7 Stimulate If you have any questions, please call me at 263-4241. P. S. White Senior Operations Engineer CC; J. R. Brandstetter ATO 1120 L. L. Perini ATE) 1130 KOE1.4-9 w/o attachments STATE OF ALASKA : ALASKA OIL AND GAS CONSERVATION COMMIssION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, In(;;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stra'tigraphic _ Service 4. Location of well at surface 169' FNL, 76' FWL, Sec. 36, T11N, R8E. UM At top of productive interval 1341' FNL, 1441' FEL, Sec. 36, T11N, R8E, UM At effective depth 1430' FNL, 1220' FEL, Sec. 36, T11N, R8E, UM At total depth 1448' FNL, 1159' FEL, Sec. 36, T11N, R8E, UM Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8060' 6302' 12. 7953' 6228' feet feet feet feet Plugs (measured) Junk (measured) None Casing Length Size Cemented Structural Conductor 1 0 6' 1 6" 205 Sx AS II Surface 2902' 9 5/8" 850 Sx CS III & Intermediate 350 SX CS II Production 8 0 4 3' 7" 435 SX Class G Liner 175 Sx CS I Perforation depth: measured 6. Datum elevation (DF or KB) RKB 129 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-07 9. Permit number 10. APl number 5o-103-20045 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True ve~ical depth 106' 106' 2902' 2810' 8043' 6291' 7641'-7675' (C Sand), 7757'-7787' (A Sand) MD true vertical 6010'-6035', 6093'-6113' TVD Tubing (size, grade, and measured depth 2 7/8" J-55 EUE, 6.5 Ib/ft, set @ 7718' Packers and SSSV (type and measured depth) Packers: BOT HB 7476', BOT lB 7699', Otis BXE @ 1803' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 7666'-7694', 7772'-7748' Treatment description including volumes used and final pressure 1615 bbls gelled diesel, 106,000 lbs of 16/20 CarLo-Lite, Final pressure 4676 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 517 874 0 825 158 Subsequent to operation 1343 2109 15 750 178 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned ~~~. P~----~' Title SR. OPERATIONS ENGINEER :orrn 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL ,NTRACTOR REMARKS IPBDT FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT 1360 ~ oo ~ a L~ lLqo - J 200 I-1oo -- :~qoO ........ _ _. ~_.4~A w ~r~/ / / g Coo · CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, I~ Post Office ,cox 100360 Anchorage, /alaska 99510~0360 'Telephone 907 276 1215 August 21, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells: W(~ II Actio.n.. Anticipated.. Start Date 2 F~ 0 8 Refracture 2 G- 0 4 Refracture 2 H - 0 5 Refracture 2 H ~ 0 7 Refracture 2 T- 0 8 Refracture 2 T o 0 3 Refractu re 1 A-1 6a Conversion 1 A-1 6 a Tbg. Leak 3 K - 0 8 Conversion August, 1989 August, 1989 September, 1989 September, 1989 August, 1989 August, 1989 August, 1989 August, 1989 August, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. S~allwood Senior Operations Engineer CC: 'J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 RECEIVED w/o attachments AFICO Alaska, Inc, is a S(ibsidi~ry of AtlanticRichfieldCompany STATE OF ALASKA Au-VSi',,A OIL AND GAS CONSERVATION COMr~S,5~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 169' FNL, 76' FWL, Sec. 36, T11N, R8E. UM At top of productive interval 1341' FNL, 1441' FEL, Sec. 36, T11N, RSE, UM At effective depth 1430' FNL, 1220' FEL, Sec. 36, T11N, RSE, UM At total depth 1448' FNL, 1159' FEL, Sec. 36, T11N, R8E, UM 12. Present well condition summary RKB 129 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-07 9. Permit number 85-170 10. APl number 5o-103-20045 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Total Depth: measured 8060' feet Plugs (measured) true vertical 6302' feet Effective depth: measured 7953' feet Junk (measured) true vertical 622 8' feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 0 6' 1 6" 205 Sx AS II 1 0 6' 1 0 6' Surface 2902' 9 5/8" 850 Sx CS III & 2902' 281 0' Intermediate 350 Sx CS II Production 8 0 4 3' 7" 435 Sx Class G 8 0 4 3' 6 2 91 ' Liner 175 Sx CS I Perforation depth'measured RECEIVED 7641'-7675' (C Sand), 7757'-7787' (A Sand) MD true vertical 6010'-6035', 6093'-6113' TVD Tubing (size, grade, and measured depth 0il& Gas C0rls, (~Olllm~sJQi~ 2 7/8" J-55 EUE, 6.5 Ib/ft, set @ 7718' Packers and SSSV (type and measured depth) ,~rJc~0mge Packers: BeT HB 7476', BeT lB 7699', Otis BXE @ 1803' 13. Attachments Description summary of proposal _ Refrac A Sand with 111,500 lbs of 16/20 mesh carbolite. 14. Estimated date for commencing operation September. 1989 16. If proposal was verbally approved Detailed operation program ~ BOP sketch _ (Procedure and Wellbore schematic attached). 15. Status of well classification as: Oil X Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the f0egoing islrue and,c~rect to the best of my knowledge. Signed, "-~c~, /')') /:",,~ //)"t,'4-~-'~'i~ Cf---"r'-/'/-' Title Sr. Operations Engineer ~ FOR COMMISSION USE ONLY Conditions of approval: Plug integrity __ BOP Test Mechanical Integrity Test_ Notify Commission so representative may witness Location clearance Subsequent form require Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 5/03/89 {Approval N o~::~ , 10- ,~-u .,~ ,o,~ ec~ OOP'¢ C~sioner Date ~~~ SUBMIT IN TRIPLICATE Messrs Sloan and August 18, 1989 Page 3 Kuparuk Well 2H-07 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K80542 1. MIRU Slickline unit. Tag bottom. . . Pull GLV's at 2252', 4281', 6505, and 7421'. Pull CV's at 7514', 7583', and 7687'. Run DV's at 2252', 4281', 6505', 7514', 7583', and 7687'. Circulate 2 7/8" tubing and 7" annulus with 9.8 ppg brine with a 500' diesel cap. Set DV in GLM at 7421'. Note that DV's are already run in gas lift mandrels at 5690' and 6979'. Set standing valve in Camco 'D' nipple at 7711' MD-RKB. Pressure test the tubing. Pull standing valve. RDMO. 4. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. . . . Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. Pump the 200 Bbl pre-pad at 20 BPM. Shut down and determine the ISIP. The A Sand was perforated with 120 shots, 4 spf, at 90 degree phasing. Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 5200 psig Fracture Gradient = 0.72 psi/ft (6103' TVD) Tubing Friction = 400 psi/1000 ft (7718' MD) * If excessive treating pressures are experienced, try reducing the rate in small increments adjusting additive rates as appropriate. If treating pressure exceeds 6000 psi, begin flush stage. With brine on the backside, the maximum recommended treating pressure is 6500 psi based on analysis of tubing strength and Brown PBR type. 8. Rig down fracture stimulation equipment. Follow attached flowback schedule. RECEIVED r ieska 0il & Cons, Co amissio Anchorage KUPARUK WELL 2H-07 A SAND FRACTURE PUMP SCHEDULE 8/18/89 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. ~C. PROPPANT PROPPANT WT DIRTY VOLUME H IT PERFS DESCRIPTION BBLS B°M PPG DESCRIPTION LBS STG/CU M BBLS I GW PRE-PAD 200.0 20 0 - - 0 200 / 200 46 ............................................. SHUT DOWN FOR ISlP, FLOW METER CALIBRATION ................................................ 2 GWPAD 900.0 20 0 - - 0 900 / 1100 246 3 GW w/2 PPG 55.1 20 2 16/20 M CARBO-LITE 4632 6 0 / 1160 1146 4 GW w/4 PPG 59.5 20 4 16/20 M CARBO-LITE 9998 70 / 1230 1206 5 GW w/6 PPG 63.3 20 6 16/20 M CARBO-LITE 15944 80 / 1310 1276 6 GW w/7 PPG 68.8 20 7 16/20 M CARBO-LITE 20222 90 / 1400 1356 7 GW w/8 PPG 66.5 20 8 16/20 M CARBO-LITE 22357 90 / 1490 1446 8 GW w/10 PPG 52.1 20 10 16/20 M CARBO-LITE 21864 75 / 1565 1536 9 GW w/12 PPG 32.7 20 1 2 16/20 M CARBO-LITE 16483 50 / 1615 1611 1 0 SLICK DIESEL FLUSH 44.0 +SV 20 0 - - 0 44 / 1659 1661 TOTAL DIESEL = 60.7 BBLS TOTAL GELLED WATER = 1437.3 BBLS (excluding diesel) TOTAL GELLED FLUID= 1498.0 BBLS TOTAL SLICK DIESEL FOR FLUSH = 44.0 BBLS +SV 16/20 M CARBO-LITE = 111499 LBS NOTES: Stage 1 is Gelled Water. ~,,. Stage 2 is Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a 6 hour break. Stage 3 through 8 are Gelled Water with 6 hour breaker WITHOUT silica flour. ~ Stages 1 through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. ,~ {~, ~, Stage 10 should include a volume adjustment for surface equipment between the wellhead and densimeter. This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. < .~. SUNDRY NOTICE - WELL 2H-07 NO BOP'S WILL BE UTILIZED DURING THIS PROCED~. BOTTOM HOLE PRESSURE (6200' SS) = 3300 PSI NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. RECEIVED A!JG2e t989 ~q~aslla Oil & 13as Cons. uommissioi~ Anct',or~ge , , r 1 Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown __ Stimulate X Plugging ~ Perforate Pull tubing ~ Alter casing Repair well Pull tubing Other 2. Name of Operator .ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 169' FNL, 76' FWL, Sec. 36, T11N, R8E, UM At top of productive interval 1341' FNL, 1441' FEL, Sec. 36, T11N, At effective depth 1430' FNL, 1220' FEL, Sec. 36, T11N, At total depth 1448' FNL, 1159' FEL, Sec. 36, T11N, R8E, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured 8 0 6 0' true vertical 6302' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 130' 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-07 Producer 9. Permit number/approval number 8-329 10. APl number 50-103-20045 11. Field/Pool Kuparuk River Oil Pool feet Effective depth' measured 7 9 5 3' true vertical 6228' feet Junk (measured) feet Casing Length Structural Conductor 1 0 6' Surface 2902' Intermediate Production 8 0 4 3' Liner Perforation depth: measure Size Cemented 1 6" 250 Sx AS II 9 5/8" 850 Sx CS III & 350 SX CS II 7" 435 Sx Class G & 175 Sx Sx CS I 7461'-7675', 7757-7787' MD Measured depth 106' 2902' 8043' True vertical depth 106' 2810' 6291 ' true vertical 6010'-6035', 6093'-6113' TVD Tubing (size, grade, and measured depth) 2 7/8", 6.5 Ib/ft, EUE, IPC, J-55, 7718' Packers and SSSV (type and measured depth) SSSV: Baker FVL 1803' Pakers: BOT HB 7476', BOT lB 7699' 13. Stimulation or cement squeeze summary Intervals treated (measured) 7461'-7675' MD Treatment description including volumes used and final pressure Acidize C Sand with 1000 gallons of 12% HCI. Final Pressure- 3500 PSI 14. Representative Daily Average Production or In!ection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Produce 493 488 0 --- 145 PSlG Subsequent to operation Produce 542 681 0 --- 150 PSIG 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations . X 16. Status of well classification as: Oil X_. Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10~404 R~(~ 06/15'/88 Date T'..~ ~', ~ ~ SUBMIT IN DUPL'~CATE ARCO Alaska, In(: Subsidiary of Atlantic Richfield Company WELL 1PBDT CONTRACTOR REMARKS FIELD-DISTRICT-STATE OPERATION AT REPORT TIME WELL SERVICE REPORT DATE vlf E, LL. ~ll~ E. ..... ' 0~$0 ' 15 aziza I,,30 q i.11 I /,,~ I Zt S ~ ,,.,,,',',.,'.,vt CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA AL, OIL AND GAS CONSERVATION CO, ...... -5SION APPLICAIION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ' ' Operation Shutdown ;3 Re.enter suspended well ~ Alter casing [] Time extension Change approved program ;__~ Plugging ..73 Stimulate/~ Pull tubing'' Amend order F~_ Perforate E'; Other 2. Name of Operator 3. Address 4. Location of well at surface 169' FNL, 76' FWL, Sec. 36, T11N, R8E, UM At top of productive interval 1341' FNL. 1441' FEL, Sec. 36, T11N, R8E, UM At effective depth 1430' FNL, 1220' FEL, Sec. 36, T11N, R8E, UM At total deptli 11. Present well condition summary Total depth: measured 8060' feet true vertical 6302' feet 5. Datum elevation (DF or KB) RKB ]30' 6. Unit or Property name Kuparuk River Unit 7. Well number 2H-07 8. Permit number 85-170 feet 9. APl number 50-- 103-70¢)4~ 10. Pool Plugs (measured) Effective depth: measured 7953' feet true vertical 6228' feet Junk (measured) Casing Length Size Structural Conductor 106' 16" Surface 2902' 9-5/8" Intermediate Production 8043 ' 7" Liner Perforation depth: measured 7461'-7675' Cemented Measured depth 205 Sx AS II 850 Sx CS III & 350 Sx CS II 435 Sx Class "G" 175 Sx CS I 7757'-7787' MD 106' 2902' 8043' true vertical 6010'-6035' 6093'-6113' TVD Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Kuparuk River Oil Pool 12.Attachments True Vertical depth 106' 2810' 6291' 2 7/8" 6 5 lb/ft EUE IPC J 55 77i8'" ~ '~:~' ~ · ~ ~ ~ i ~ -L:~..,~ , , ~¢¢~.~,,~,,,.,~*'"~' ,~/~. ~'~°n~' .°~¢'~ ~nT u~ ,~,, B0T !B 7699' . Description seCreCy of proposal ~ Detailed'~'eT~ti~'p¢~r~m' BOP sketch ~ 13. Estimated date for commencing operation Date approved 14. If proposal was verbally approved Name of approver Z- -~! 15. I hereby certify that the foregoing is true and~.correct to th~. best ,of my knowledge Signed, Commission Use ~nly Conditions of approval ORIGINAL SIGNED BY LONNIE C. SMITH Date Approved by Notify commission so representative may witness ! Approval [] Plug integrity [] BOP Test ~ Location clearancel ',,pproved Copy Returned Commissioner by order of the commission Submit in triplicate Form 10-403 Rev 12-1-85 Messrs. Gerlek and Ho~ April 4, 1988 Page 2 Kuparuk Well 2H-07 Acid Stimulation Procedure (4/4/88) Pre-Stimulation 1. MIRU slickline unit. 2. RIH and pull SSSV (Otis Ball Valve) from 1803' 3~ RIH and pull GLVs from 2252', 4281', 5690', and 7421' and replace with DVs. 4. RIH and pull HFCVs from 7514', 7583', and 7687' and replace with DVs. 5. RIH with A2 BP and place in D-nipple. 6. Pressure test tubing. e . 9, Open well to production. Note' Contact Operations Engineering if well does"l~6~tc"~flOw with C Sand only production. ' · . ' ~- Obtain oil sample and have operations engineering pick up for use in determining if a non-emulsifying agent is needed in the treatment. (Ensure two tubing volumes have been produced so that a representative sample wi 11 be obtai ned. ) ,,,%~; Check Ph of oil sample with litmus paper and record. Stimulation · Ensure 2-7/8"X9-5/8" annulus is filled with diesel and pressure same to 3000 ps i. e MIRU acid pump truck and frac tank. RU lines from wing valve through choke manifold into frac tank to allow immediate flowback after job is pumped. Pressure test equipment with diesel. Prior to performing acid treatment contact operations engineering to perform normality check of acid to verify the strength is at 12% HCL by weight. · Establish injection into tubing with diesel to ensure ability to pump into zone. Pump +/- 20 BBL and SD. **Note' With 3000 psi on the annulus, the maximum treating pressure is 4800 psi Messrs. Gerlek and Hot ~ April 4, 1988 Page 3 . Pump the following acid schedule at maximum rate. 1000 gal 12% HCL MSR 100 W/ 2 gal per 1000 A-250 (inhibitor) and i gal per 1000 J-237 (oil soluble resin) e Displace acid to perforations with 48 BBL of diesel at maximum rate. (This is an over displacement of 2 BBL to ensure all acid will be placed in the formation.) . RD&R treaters and begin flow back treatment to tank immediately. Treatment should be flowed back at moderate rate. NOTE' Maintain all personnel upwind of frac tank. Although this well is not known to contain scale, trace amounts of iron sulfide could exist, which would result in H2S liberation when brought in contact with acid. 7. Reduce pressure on annulus to normal operating range. e After well has cleaned up to tank put well in test separator and obtain stabilized test. Report results to operations engineering. Note' Compare Ph of samples with prior Ph to determine when well has been flushed adequately. 9. MIRU slickline unit. 10. RIH with SSSV (Otis Ball Valve) and place at 1803'. 11. RDMO slickline unit. ARCO Alaska, Inc. Post Offic ')x 100360 Anchorage, ..,laska 99510-0360 Telephone 907 276 1215 Date: February 26, 1987 Transmittal # 5926 --RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. and return one signed copy of this transmittal. 3Q-8 CBL 2-16-87 6195-9264 2H-6 CET 1-17-86 7400-8873 2H-5 CET 1-16-86 6525-7959 3F-13 CET 1-7-86 6160-7920 3F-12 CET 1-23-86 6946-7250 2H-8 CET 1-1-86 8000-8650 2H-7 CET 1-1-86 6800-7938 3F-14 CET 1-7-86 4700-6760 3K-5 CET 7-16-86 6988-7990 3K-3 CET 7-14-86 7595-8800 3K-4 CET 7-14-86 7793-8787 3F-12 CET 1-7-86 6050-7416 Please acknowledge receipt / AJask~ Oil & Ga, s Cons. Commission Am, h0,"age Rec~ip.t Acknowled~ _ ,1. Date: DIS~ . NSK , Drilling State (+ sepia) BPAE Chevron SAPC Mobil Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtianticRichlieidCompany ADDENDUM WELL: 1/03/86 2H-7 Arctic Pak well w/175 sx CS I, followed by 53 bbls Arctic Pak. Drilling ~uperintendent / DaZte ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the tirst Wednesday after a well is spudded or worKover operations are started. Daily work prior to SPudding should be summarized on the form giving inclusive dates only. District Alaska County, parian or oorough State North Slope Borough Field Lease or Unit . Weii no. Kuparuk River ADL 25587 2H-7.j · ~ Auth, or W.O. no. Tit e AFE AK0022 Completion Nordic 1 AP1 50-103-20045 Operator IARCO W I ARCO Alaska, Inc. I 56.24% I Pr~or status d a W.O, Alaska Spudded or W.O. begun Date IHour Complete 2/5/86 I 2145 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 2/06/86 2/07/86 7" @ 8043' 7953' PBTD, TIH w/lB Pkr 10.7 ppg NaC1/NaBr Accept rig @ 2145 hrs, 2/5/86. NU &tst BOPE. Wt up brine to 10.7 ppg. RU Schl, perf w/4" gun, 4 SPF, 90° phasing f/7757'-7787'. Perf w/5" gun, 12 SPF, 120° phasing f/7641'-7675'. Make gage ring/JB rn. RIH w/lB pkr. 7" @ 8043' 7953' PBTD, Set BPV 6.8 ppg diesel in tbg & ann Set' pkr @ 7699'. Rn 241 jts, 2-7/8", 6.5#, J-55 EUE 8RD tbg w/SSSV @ 1813', HB Pkr @ 7486' pkr @ 7709 & TT @ 7728'. Space out & ind. Set pkr. Tst tbg, shear PBR, tst pkr & SSSV. Set BPV. NU &tst tree. Displ well to diesel. Unable to set BPV. RU S/L to set BPV. The above is correct Signature For form preparation and distribution, see Procedures Manual, Secfl'on 10, Drilling, Pages 86 and 87. Date . Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History- Final Report Instructions: Prepare and suom~; '`he "Final Report" on the *irst Wednesday after allowable has been assigned or well ,s Plugged. Abandoned or Sold "Filial Report" should be submitted also when operations are suspended for an indefimte or appreciable length of '.;me. On worKovers when an official '.est is not required upon com0ietion, report completion_ and representative test data in blocks provided. The "Final Report" form may de used for report,rig Ihe enhre operalion if soace ,s availaeie. District Lease or Parish Alaska County Fieid or Unit Kuparuk River Auth. or w.O.AFEnO. AK0022 T Nordic 1 North Slope Borough APL 25587 Accounting cost center code S ate Alaska we,, n~H_7 Completion API 50-103-20045 Operator ARCO Alaska, Inc. A.R Co. W.L 56.24% Spudded or W.O. begun Date Complete 2/5/86 Date and depth Complete record for each day reported as of 8:00 a.m 2/08/86 thru 2/10/86 I otal number of wells (active or ~nactlve) on this dst center prior to pluggmg and bandonment of this well our Prior status ~! a W.O. 2145 hrs. 7" @ 8043' 7953' PBTD, RR 6.8 ppg diesel in tbg & ann Unable to pull BPV w/S/L. Set plug in "D" nipple. Displ well tO 10.7 ppg brine. ND tree, NU stack, pull hgr & chg out. Lnd tbg & tst tbg to 2500 psi, SSSV to 1000 psi, pkr to 2500 psi. ND BOPE, NU & tst tree to 250/5000 psi. Displ well to diesel. RU S/L, pull plug, RD S/L. RR @ 1030 hrs, 2/8/86. Old TO New TO Released r!g Date 1030 hrs. Classifications foil. gas, etc.) Oil ~'B Oeoth 2/8/86 l~in~ o: ,ig Type completion (single, dual. etc ) Single Producing method Official reservoir name(st Flowing Kuparuk Sands Potential Test data 7953 ' PBTD Rotary Well no. Date Reservoir Producing interval Oil or gas;Test time Production Oil on :est Gas ~er day Pump size, SPM X length iChoke size T P. ~C.P. Water % CdR Gravity AIIowaPle Etfective date corrected The above is correct Signature I Date Title For form prep .... , .... ddistdl:~tion. see Procedures Manual. Section 10. Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office b~x 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 12!5 February 26, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2H-7 Dear Mr. Chatterton. Enclosed are the Well Completion Report and gyroscopic survey for 2H-7. I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L181 Enclosures ARCO Alaska, Inc, is a Subsidiary o! AllanticRichfieldCompany STATE OF ALASKA ALASKA Oil_ AND GAS CONSERVATION COi~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~r~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-170 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of well at surface 169' FNL, 76' FWL, Sec.36, T11N, R8E, UN At Top Producing Interval 1341' FNL, 1441' FEL, Sec.36, T11N, R8E, UM At Total Depth 1448' FNL, 1159' FEL, Sec.36, T11H, R8E, UN 5. Elevation in feet (indicate KB, DF, etc.) 130' RKB 6. Lease Designation and Serial No. ADL 25587 ALK 2673 8. APl Number 50-- 103-20045 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2H-7 11. Field and Pool Kuparuk River Fi eld Kuparuk River 0il Pool 12. Date Spudded 12/13/85 17. Total Depth (MD+TVD) 8060 ' MD ,6302 'TVD 13. Date T.D. Reached 12/17/85 18. Plug Back Depth (MD+TVD) 7953 'HD,6228 ' TVD 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 2/20/85* N/A feet MSL 1 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES [~X NO [] 1813 feet MD I 1500' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, OCT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 16" 9-5/8" WT. PER FT. 62.5# 36.0# GRADE H-40 J-55 SETTING DEPTH MD TOP BOTTOM Surf 106 ' Surf 2902' Surf 8043' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 7757' - 7787' w/4 spf, 90° phasing HOLE SIZE 24" 1 2-1/4" CEMENTING RECORD 20~ sx AS II 850 sx CS III & 350 sx Performed top job w/13 AMOUNT PULLED CS II sx CS 11 7" 26.0# J-55 8-1/2" 435 sx Class G & 175 s CS I 25. TUBING RECORD 7641' - 7675' w/12 spf, 120° phasing SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7728' 7486' & 7709' 26. ACID, FRACTURE, CEMENT SOUEEZE, 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 Flow Tubing Press. Casing Pressure PRODUCTION FORIOIL-BBL TEST PERIOD ~ CALCULATED . OIL-BBL 24-HOUR RATE I~ GAS-MCF GAS-MCF 28. CORE DATA WATER-BBL CHOKE SIZE GAS-OIL RATIO WATER-BB L OIL GRAVITY-APl (corgi BriefNoNEdescription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit R~~-¢''' ~' ~c°-re chip, s, ~i I~.. g FEB 8 1986 Form 10-407 * NOTE: Tubing was run and the well perforated 2/8/86. DAM/WC07 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH TRUEVERT. DEPTH 6009' 6036' 6065' 6213' 30. FORMATION TESTS 7639' 7677' 7719' 7932' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 supldlem~n~al 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 "~' Well History- Initial' Report Daily Inltructlonl: Prepare and submit the "Initial Report" on the first Wednesday afte! a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish Or borough North Slope Borough JLease or Unit A.DL 25587 Title Drill JState Field Alaska Kuparuk River Auth. or W.O. no. AYE AK0022 Alaska JWell no. 2H-7 Nabors 26E AP1 50-103-20045 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded~. iD-re 12/13/85 Date and depth. aa of 8:00 a.m. 12/14/85~: thru: 12/16/85 12/17/85 12/18/85 12/19/85. Complete record for each day reported 0600 hrs. ARCO w.I. IPr or status if a W.O. 56.24% 16" @ 106' ' . 5459' (5353'): Wt. 9.2, PV I3, YP 9, PH 9.5'~ WL:.8.6~ iSO1 9 Accept ri~ @ 0001 hfs, 12/13/85.: NU diverter, sys, .S~ud well 0600 hfs, 12/13/85.. Drld' to 2919' Rami:73:Jts, 9-5/8 36.0#/ft, J-55, BTC csg w/FC @ 2820.' & FS @ 2902'. Cmtd w/850 sx CS III & 350 sx CS II.-~ Drld to 5459'; ~- 9-5/8" @ 2902' 7326', (1867'), Rm to 7326' Wt. 10.2, PV 11, YP 9, PH 9.0, WL 6.8, Sol 11 Navi drl to 7326', trip f/rotary assy. 5700', 47.9°, S73.8E, 4713.8 TVD, 2506.9 VS, 745'.4S, 2393.8E 6488', 48.7°, S73.8E, 5236.2 TVD, 3096.8 VS, 910.0S, 2960.3E 7241', 45.7°, S76.8E, 5747.6 TVD, 364'9.3 VS, 1060.1S, 3492.0E 9-5/8" 8060 ' ,. Wt. 10 Drl to @ 2902' (734'), POH to log 7, PV 12, YP 10, PH 10, WL 5.8, Sol 12. 8060', make wiper, trip, C&C, POH. 9-5/8" @ 2902." 8060', (0'), POOH, LD DP Wt. 10.7, PV 13, YP 9, PH 10, WL 6.0, Sol 12 Log DIL/GR/SP/SFL f/8057'-7400' WLM, FDC/CNL f/8057'-7400' WLM, 6300'-6000' WLM & 5450'-5000'WLM, CAL f/8057'-5000' WLM. Attempt to run RFT log; unable to get to btm. Make wiper trip, CBU, cond f/csg. POOH, LD DP &BHA. The above Is correct Signature !j )_.4 ~,~ ~ For I[orm preparation and distribut[ol~, see Procedures Manuel, Section 10, Drilling, Pages 86 and 87. jTitle Drilling Superintendent A ARCO Oil and Gas Company Daily weft-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 submilted also when operations are suspended for an indefinite or appreciable length of time. On workover$ when an official test is not required upon comoletion, 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 Alaska Field Kuparuk River County or Parish Lease or Unit ITte Auth. or W.O. no. AFE AK0022 IAccounting State COSt center code Alaska North Slope Borough ADL 25587 IWell no. 2H-7 Drill Nabors 26E A?I 50-103-20045 Operator ARCO Alaska, Inc, Spudded or W.O. begun JA.R.Co. W.I. 56.24% . IDate 12/13/85 I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prior status if a W,O, 0600 hrs. Spudded Date and depth Complete record for each day reported as of 8:00 a.m. 12/20/85 12/29/85 7" @ 8043' 7953' PBTD, RR 10.7+ NaC1/NaBr Rn 185 its, 7", 26#, J-55 BTC csg w/FC @ 7953', FS @ 8043', FC @ 7953' Mkr @ 7652'. Cmt w/100 sx C1 "G" + 2% A-2, 1% R-7 & 2 gal/sx FP6L & addl 335 sx Class G. ND BOPE, NU tbg spool & lower tree, tst to 3000 psi. RR @ 0030 hrs, 12/20/85. Moving to 2H-6. Arctic packed well w/175 sx CS I. Old TD j NewTD I PB Depth 8060' TD ' 7953' PBTD Released rig I Date IKind of rig 0030 hrs. 12/20/85 Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method J Official reservoir name(s) Flowing I Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time ProduCtion Oil on test Gas per day Pump size. SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distributio(f{, see Procedures Manual, Section 10, Orillincj, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Bc .d60 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for each of the following wells' 2H-5 2H-6 2H-7 2H-8 I have not yet received the 2H-7 and 2H-8 Well Histories. When I do, I will forward them to you. A1 so, bottomhole locations, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic surveys are run and the wells completed. If you have any questions please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L72 Enclosures ARCO Alaska, Inc, is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA '~ ALASKA .... AND GAS CONSERVATION CL.~,VIISSION '1WELL 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. 85-170 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20045 4. Location of well at surface 9. Unit or Lease Name 169' FNL, 76' FWL, Sec.36, T11N, RSE, UM (approx.) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2H-7 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.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 129' RKBI ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 1 2/13/85 I 2/1 7/85 1 2/20/85I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TX/D) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 8060 'MD 7953 'MD YES [] NO [~]X N/A feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ~b~ 62.5# hl-~U 5urt 106' 24" 205 sx AS II 9-5/8" 36.0# J-55 Surf 2902' 12-1/4" 850 sx CS Ill & 350 sx CS II Performed top job w/13C sx CS II 7" 26.0# J-55 Surf 8043' 8-1/2" 435 sx Class G & 175 s~ CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested P~RODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "Ir - · 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE . : '7: ~' ". ~ · Form 10-407 TEHP3/WC69 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. -' -~ 30. ~ .! . GEOLOGIC MARKERS FoRMATI'ON TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ,~O~¢.~j Title Associate 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 SUB-SURFACE DIRECTIONAl. ~URVEY [~UIDANCE [~ONTINUOUS rllOOL Company Nco AL~S~ ~NC.,, Well Name 2H-7 169'~NL, 76' FWL, S36,TllN,[SE Field/Location ~:uP~ R~wa, NO[TH SsOP~, ~S~s~ Job Reference No. f~71184 Log~3ed By; Date 02-JAN -1986 Computed By: HO WAP,_D 3OL_A~ SCT 'DI:~--CTi ]NAL "'UST ]q=R LIST'S- FO:~ 6RC] ~L-~ SK~, ~UP~RUK '4ETHODS OF C]'4PUT~T!Oq TOOL LOS4TIDN: T4NSENT I,,~L- INTERPOL&TI]N: LINEAR VErTICaL SECTION: 40RIZ. DIST. ~R3JEC, TE3 ~Zi .3F $:0~JTH 73 OS.S 30 ~411'q :&ST ~3MPUTATI]q D~TS: ZT-J6, N-85 :~SS ARSU ~L~S<4, I~C. 2q-7 N]RTH SLSPE,&L~SK2 INTZqPOL&T:D V~LJES FOR :VEN 100 =EET Oz TRU= SJB-S~A ME&SURE] V=RTIZAL V:RTI'AL DEPT~ DEPTW OEDTH 0.99 O.O0 -130.00 100.33 lOg.C0 -OO.OO ZOO.OD 290.00 73.00 300.00 300.00 170.00 ~DO.OO 400.00 270.00 530.00 500.00 373.00 500.00 600.00 ~70.00 700.00 639.99 569.99 BOO.OD 799.99 66).99 930.03 899.99 769.9~ 1900.00 999.)8 869.9~ llDO.O0 1099.~ 959.9~ IZDO.OD 1199.97 1059.97 1300.00 1299.~$ 11~'~.96 1~00.00 1399.35 I26~.95 1500.33 1499.~6 1369.86 1500.00 1599.~3 146~.43 1700.33 1598.32 1553.32 1800.00 1796.~7 1665.~7 l~O0.O0 1894.17 176~.17 2000.00 1991.02 1551.42 2100.00 20~7. ~0 1957.90 2200.00 2183.06 2053.05 2300.00 2276.73 2145.73 2~00.00 2368.56 223~.85 2500.00 2~59.51 2329.61 2500.33 2548.83 2413.~3 2700.00 2635-~3 2505.43 28D0.00 2]22.88 2592.88 2900.00 2807, 95 2577.95 30~8.9O 3118.52 3181.14 3242.~7 3309.22 3375.75 3442.55 3509.75 3000.00 3100.00 3200.90 3300.00 3~00.00 3500.00 3530.00 3700.00 3800.03 3900.00 C'~JRS=- ~. V=RTIC~L 305' ]=VI'~TI3~ AZI'~UTfl, q:"TION.._~. S-'V-RITY '43R74/ D=G qZN DES 0 0 N 0 0 E 0.00 3.00 0 12 S 55 51 E 0.16 0.3'3 0 lZ S 29 18 4 0.27 3.29 0 5 S ~ 33 E 0.41 0.45 0 13 S 2~ 1D ~ 0.49 ~.21 0 14 S 27 1~ = 0.63 '3.49 0 20 S O 39 ~ 0.75 0.71 0 ~3 S 2 2~ W ~ ~ 1 11 3 ?1 0 2~ ~ 4 ~ £ 1.~ :J.7~ 0 29 ,~ ~ 33 ~ 1.69 3.49 0 33 S 5 27 W 1.7~ 0.73 0 33 S 20 59 W 1.79 3.2'~ 0 38 S 25 27 W 1.74 0.2:3 0 ~7 S 20 ~ J 1.70 2.59 1 16 S 25 3) ~ 2.10 1.75 3 31 S 5B lO E 5.59 ~.39 = 1~.60 ~.37 6 33 S 50 7 = 9 52 S 51 ~ !:': 2:3. 51 '3.11 11 ~6 S 52 15 _.- 45.99 2.6q 12 53 S 65 3 ~ 56.55, 3.47 89.74 1.97 11~ 95 2 9'3 - . · la5.59 2.~3 22 o. ~ 3 2.07 232.37 2 · 65 353. 53 1.40 a,] 5.64 I · '~ 5 45 ~ · J 7 1 · O 3 512.55 g · 5 570 73 5 · 53'5 . 71 5. a 7 707 ':6 5.52 735.34 1.05 353. :~ 5 ~. 05 9 ~8.73 3. ,,27 087.73 1!6~ .7~ 3.35 2761.71 2842. '95 2918.90 298~.62 3051.14 3112.97 3179.22 3245.75 3312.55 3379.75 _ , ~' - . " FY <:' ~ Y :,jSq;W- U-¢A'iS'~: 132 3a 10 S 77 21 ]7 ~0 S 75 1 43 17 S 73 ~ 48 17 S 72 30 53 '9 S 72 lO 49 20 S 71 39 48 20 $ 71 41 4~ 15 S 71 3~ 47 56 5 71 41 ~7 35 $ 71 33 1i. i5. 37. 65. 70. ') 9. 111. 121. I 3 ! . la!. 153. 155. 178. 196. 217. Z 41. 25,3. 23 ~. ~13. 32,5. O0 Z$ 15 13 77 56 75 2S 3 ! ~3 J7 3O $2 5~. OZ 15 37 15 O3 ~ 5 5'7 70 56 ,JL4 .~ 3 j T'-i C3'~RDI1~T. ~ Z'" T O.SO O. 13 0.~0 ,3.2'~ 3.27 3.31 0.3~ O. 5.3 3.55 ,]. JO '3. ? 3 ,) · 33 0.35 !. ,Z 0 i.57 "~ 20 2.95 3..35 3.44 0.1 9 '3.14- 3.5~ 3 · 5 Z 2. ;' 7 13.&l 22. ~'~ 55.13 4. 7'9 5.57 ,5.51 7. 3.36 1Z. Z1 19.31 33.42 52.45 7'3. Z 9 75.T5 101.37 1,~0.23 153 · ? ~{, 200.35 240.75 284.75 331.88 381.0~ 432.37 485.68 542.33 60~.'71 673.18 747.49 922.10 593.23 96~+. 1 O 10~4,75 1105.3~ 95.51 1 Z 0 · '.~ 9 1 f; :3 · 93 Z .:55.12 30 :~ . :+ '5 ;05.50 512. ~ 5 570. ~9 535.9 ~ 707.5~ 795. 5 ~ 13 ~, '~. 11 fl 5 3 28 " S 5 5 5 ,~" ,_ > .5 '~ "_',? :: 5 I 47 '- S $ 5 .57 S 5'~ '2~ S 7 3 2 ~ 5 7 l aS ~ T1 53 . - $ 72 4 - - .5 7 t -57 2"1-7 C3qPJTATI3'~ '~T:~PSL~TE3 VaLJ:.5 :,'IR -V=N 100 F~:T OF TRUE SJ~-SEA V:RTI'~L V:RTI'AL 4330.90 3577.35 3~47.35 4100.00 3545.35 3515.35 '4ZO0.OO 3712.~0 3552.40 ~300.03 3779.10 35~9.10 4%00.00 3~45.~4 3715.94 4530.03 391i.7'~ 3781.72 4500.0~ 3977.15 3947.15 4700.00 %043,14 3913,14 4~O0.OD %199.29 ~979.2~ 4~00.00 %17~.35 5300.00 $239.73 5100.00 4305.46 ~175.46 5200.02 4371.57 ~241.67 5300,00 ~437.~5 ~307.95 54DO.OD %502.77 %372.77 5500.00 %567.33 %437.83 5600.00 %533.50 %503.50 5700.00 ~700.34 4573.04 5800.00 %757.11 ~537,11 5900.00 ~832.~9 ~701.49 C2JqS2 V:RTICAL 3=Vi~TI3',~ AZI~JTq S~CTiON 'S:V:RiTY 32'3 '41'q 3:S ~i~ =~T 3'-31193 47 17 S 71 37 ~ 1235.39 0.35 ~7 la. S 7'~ 3P_ :,_ 1303.6c, !.07 4~ 12 S 71 ~3 ~ 13,~2.82 3.17 ~ 6 S 71 35 ~: 1457.2~ 45 8 S 71 9 ~ 1531.62 3.35 49 17 3 7i 5 ~ ~506.31 2.15 ~9 1 S 73 ~ £ 1632.42 0.56 48 !7 S 71 1 - 1757.48 49 ~1 S 72 ~9 ~ 19,]'q.. 33 ]· ~,'-)1 S 72 20 E 1'9,~3.99 '3.31 43 38 S 71 33 E 205-~.35 ..3.72 43 27 S ~2 27 E !134.28 3.23 &9 7 5 7° 2) ~ ~0a 14 " 4? 38 S 72 5! ~ 2155.27 0.15 ~9 9 S 72 42 ': ~351.21 48 37 S 72 ~1 g 2935.5'2 ~7 54 S 72 43 : 2511.27 0.32 4~ 34 S 73 ~ E 2585.43 Z.67 a'? 10 S 72 52 ~: ..... ~661.09 3. c 4.9 ,9 S 72 43 ~_ 2736.58 0.2~_ AS gO S 72 45 : ~3!1. 92 3.54 49 3 S 7~ ~3 :~_ 23:37.32 0.45 48 56 3 73 9 g952.75 3.63 4~ ~,9 S 72 59 '~. ,3933.05 0.25 4~ ~3 S 7! 49 ~113.23 3.15 43 ~0 S 'T3 43 ~ 31~3.32 1.4~ 48 'g9 S 74 17 '..J ~,16~.32 48 7 S 7~ 29 E 3337.89 3.95 47 ZO S '7; 53 5 34tl.59 0.2~ 46 51 S 7~ 4~ S 34S5.02 46 12 S 75 15 ~ 3557.54 1.7B 46 :] S 75 58 E 3629.74 0.55 45 B S 77 19 : 3701.18 1.'87 45 11 S 75 13 E 3771.86 1.63 45 g S 73 35 : 334~..53 2. i3 45 22 S '59 23 ~ 39,33.73 0.6.2 6000.00 4897.26 ~767.96 6130.00 4963.32 %833.82 6200.00 5029.50 ~892.50 6300.00 50'95-12 ~965.12 6~00.00 5160.~6 5030.95 65~0.00 5226.89 50'95.89 6500.00 5292.~2 51.52.92 6700.09 5359.06 5229.06 6~00.00 5425.57 5295.67 7 o o o. o o iS i: 'i'i 3 t. i 1 71DO.O0 5'62!:9s94 54'99.94 7200.00 5699-03 5569.03 7300.00 5258.~5 5638.85 7~OO.OD 5839.~6 5709.46 7500,00 5910.~8 5780.08 7500.00 5980.57 5~59.87 7700.09 5051.58 5921.6~ 7~00.00 5121.54 5991,64 7~00.00 5191.31 5061.01 3~3 . ¢,}5. ~Z~. 5S1 · '5~ 3 · 57~. 523. 542. 6.45. 5.33. 71'3. 732. 755. 777. 79 .~. 821 . 343 · ~ 0 '?. 975. ~ 95. 1315. 1335. 1055. 1074, i091. 1107. 1122. 1.14~ 1i62. 11~5. 121! · 1237 · $]UT-! :~.$T/~' 5T T :: ::: T 1255.~ 13~3.36 1532..1~ 1537.~ 1T53.2~ 1{33.27 3~ 5 !~35.53 ~0 3 1~57.36 33 5 2023.~F 31 S 2100.lZ 5~ :5 2172.95 ~7 3 2245.5.1 45 S !317.50 6I S 23~.75 $ 15~2.81 i):~4. ?'.7 2360.23 2!35.17 22,35.17 235~.11 £~37.52 Z 512.1 ~ /585, 31 2 o '~ !. 37 97 S 2604.22 31 S 2675.08 ~,,':1S 2392.31 )2 S 2964.37 91 ~ 3035.18 31 S 3108.35 90 S 3251.B8 38 S 3322.17 32 S 3392.19 07 S 3452.~ 33 ,S 3532.23 97 S 3601.22 31 S 3659,59 ~'~ '5 3735.)7 45 5 3,303.39 73 S 3~70.23 31 S 355:,16 3530.2,3 3701.54 377!.24 3~2.~,~ 3~g'g.!5 4127.37 S '71 ~7 < T 1 5 :? S 71 51 S 7I 53 S '7 ,,.5: - T ! 56 S 71 5 'S 'T I 5 ?, .: '72 1 INC. KJ~RJ~ N37TH TRUE ME~SURTD V:RTIZ&L 8000.30 5250.17 8USO.D3 5301.57 :NT:7~DL~T:2 V~LJ~S F3R V:RTi:~L 3EVZ~TI]~ AZI~JT~ D~T~ DE3 ~I1 DES 'qlW 5133.17 46 14 S 5171.57 V~RTIS~L 3~CTi3N ~2~2.02 -::f SEV-RZTf DES/II)] 3.03 "':T 3:: '-l J?',/-'f' 27-J :',,-! 5 < q ~f'-TZN;'J~ C: L-. i 1' =~ST/./:$T ]iST. ~ZI,1JTfi F::- =£:T ):' 175~.!7 ARgO ALAS~.q, I~C. 2q-7 KJ~ARJ~ NgRTH SLJ°~,AL~SK~ CS~UT~TZS~ DAT~: 27-J~q-B5 TRUE MEASURE3 VERTICAL ]:PTq DEPTt O,O0 O,O0 IOOO,DD 999,95 2000,00 19~1,~2 3000,00 2891.71 ~O00,OO 3577,35 ~SOO.90 ~239.73 6000,03 4897,95 7030,00 5551.11 8gOO,OD 6260,17 8050,00 5301,57 INT=R~JL~T=O VALUES :3R VERTICAL CSJRSE 3=Vi~Ti_nq ~.ZIMOT4 3"-G qI'q Or-_G MI.N -130.00 1951.42 2731.71 3447.33 ~109.73 $757.95 5431.11 513],17 5171,67 0 0 N 0 O 0 33 S 5 27 14 7 S 5~ 11 3~ 10 S 77 21, 47 17 S 71 37 ~9 0 S 72 43 45 1~ S 59 1 a6 1~ S 59 1 =V~N 1003 F~='T =EET 0,00 0.00 1,7B 0,73 Bq.74 1.97 512.56 1235.39 .0,35 I~83,99 D, 31 !735.68 ~.22 3485.92 0.72 ~19'~ ~ O.OO ~2'42.02 O. 03 W]RTM/ _ . O. 55. 15~. 3~. 1055. 1253. . _, , -', . S~:JTH r-.'-~ST/,,~=SY Df. ST. ~-I~UT~, -- ?. ---T --E!-T '= ~- -T J ~:o ~"~.~,~ ARCO ~LASKA, INC. 2~-7 ND(TH SLD~E,ALASKA COqPJTATZ3'~ DAY=: i',,~r- 3.= SJR~''f: ')-.J:'4-I~?.5 =T TRU: SJB-S~A MEASUR:D VERTICAL V:RTICAL D;mTq DEPTH DEPTH 0.03 O.O0 -133.00 30.33 30.00 -102.30 130.03 130.00 0.00 230.03 230.00 103.00 330.00 330.00 20S.03 ~30.00 ~30.OO 300.00 530.00 530.00 ~00.00 $30.00 630.90 500.00 730.01 730.00 g30.Ol 830.00 700.00 230.01 930.00 803.00 1030.02 1030.00 900.00 1130.02 1130.00 lOOO.O0 1230.03 1230.00 1100.00 1330.04 1330.00 1ZO].O0 1~30.05 1430.00 1300.00 1530.21 1530.00 1~00.00 1530.83 1630.00 1503.00 1732.20 1730.00 1600.00 1~34.2~ 1~30.00 1700.00 1936.80 1930.00 1803.00 2039.85 2030.D0 1900.00 21~4.07 2130.00 2209.8~ 2230.00 2100.00 2357.62 2330.00 2200.00 2457.21 2430.00 Z30O.OO 2578.72 2530.00 2692.50 2630.00 2500.00 2808.32 2730.00 2~00.00 2~26.13 2830.00 Z70O.O0 ] , 30~6.$Z Z,9'50;~00 2~o3.00 3174.25 3030.00 2900,00 3317.37 3130~00 3003.00 3~80.00 3Z30.00 3100.00 3531.25 3330.00 3200.00 3781.25 3430.00 3303.00 3930.00 3530.00 3400.00 4077.~0 3630.00 3503.03 4226.41 3730.00 3500.00 4376.16 3830.20 3703.00 C2J~SE V = R T I".'~L 9332--:3 ]~VIATiD',J '.iZIM,JTq S=CTZ']N ,S-V=RZTY qD~,T-I/SDUT1 D=G qlN '3~3 ~II'J FC~T '3:3/10D =:' 31 S 1~ 7 W 1.74 29 S ~ ~7 N 1. 35 S 13 iI W 1.78 ~+3 S 21 55 ~ 1.69 52 5 16 49 W 1.67 ~8 S 38 53 ~ 2.70 35 S 62 35 ~: 7.55 55 S 55 10 ~ 18.43 ~5 S ~S 45 ~ 33.81 9 S 55 32 { 52.70 0 0 0 0 0 1 4 10 12 55 S 59 20 : :)9.72 g~ S 71 S ': !63.4.6 6 :l ?g 5 ,: 293..43 5 S 7~ ~'~0 '-... ~'5.30 :Z'~ S 77 23 : 2:~7.55 28 S 77 59 _ 351.3) 3 S 77 39 x 407.93 39 S 77 2B ~ ~1':'.05 27 S 76 ~3 =-- '539.'3~ 0 S 73 15 _ 518.23 14 S 72 23 ~ 720.49 18 S 71 38 ~ 17 5 71 43 2 952.07 5~ S 71 41 '- 1073. ~2 32 S 71 3~ ~ 1183.86 8 S 71 27 E 1292.0'9 11 S 71 ~8 E 1~02.51 Z S 71 11 ~ 1513.90 13 14 17 23 25 '27 29 31 35 42 5O 4? 47 --A.'S T/~-ST :2i5 r. A Z i ',1'J T-~ F ' 'T "';-: T C'23 0.00 O.O} O. 47 3. '91 S . 51 2 . 1 '~ ~l ~ ~ ..' 3. ~5 :). 54 3.55 1.25 0.3 ] !. 72 O.a~ 2.35 9.49 3.17 . O. O. O. O. O. 0.52 ~.05 3.2~ 5.9:, 1.13 5. ~'~, J.4~ ~.10 2.41 13.00 3.87 13.33 3.83 13.36 2.77 23.54 3.1 ~ al. 3:~ 1.49 51.33 S' 2.17 50.40 S 2. 31 70.:~6 S - · ,., , ~').~'~ 94. 5~ S ,Z.~? 1,]7.~$ S 2.5~ i1~.0'3 S 1.43 130.52 3 !. 53 142.50 5 1.57 15~.20 5 ~.35 170.94 S 5.95 1~1. 77 S 5 4~, ~ ~1.57 5 5.42 2,51,4,] S 3.55 ~97.95 5 0.~3 332.1~ S 0.45 401.14 3 ~.17 ~35.72 5 3.2~ ~71.,33 S 52. 85. 113. I~5. 154. ' 227. 275. 32,~. 385. 446. 511. 587. 685. 807. 915. 1021. 1126. 1226. 1333. 1 a 3 :R. ~'J ~LAS(A, IWC. 2'1-7 KJP4RJ< N3RTH SLJDE,ALASK& CO~PJY~TI3N 3AT.:_: ?7-J~N-~$ !NT=R~OLAT'=3 V~LJFS FOR EVEN 100 TRJ= SJE-S:A ME~SgRE] V=RTICAL ~527.91 3930.00 3800.00 4580.17 ~030.OO 3903.00 49B5.15 ~230.00 ~lgD.O0 5137.13 ~330.00 ~2OO.O0 52B7.~2 ~30.00 ~30O.O0 5~2.02 ~530.00 ~&OD.O0 5594.71 ~630.30 4503.00 57~.50 ~730.00 ~SOD.OO 5~95.18 ~830.00 ~700.00 60~8.78 4930.00 ~300.00 6200.75 5030.90 ~903.OO 6353.00 5130.00 5003.0J 6504.72 5230.00 5100.00 6556.10 5330.00 5200.00 6~06.~ 5430.00 5300.00 695~.37 5530.00 5403.00 7100.09 5630.00 5500.00 72~4.58 5730.00 5500.00 73B6.57 5830.00 5703.00 CDJ~SE D~VI~TiDN AZI~UT'1 ~9 1~ S 71 2 E 4~ 32 $ 79 5~ ~ &9 Z$ S 72 27 49 2 5 72 22 E ~'B 3~ S 72 3& Z a;5 53 S 72 25 ~ 49 23 S 72 53 ~3 39 S 72 41 ~ ~9 11 S 72 52 ~8 $7 $ 72 43 = ~ 9 3 S 73 23 '~._ 4:~ ~3 S 72 49 '= - 48 34 S 7~ 19 ~- 43 2 S 75 3] ~ 47 10 5 7~ 51 ~2 46 12 $ 75 15 ~ ~5 48 S 77 ~ ~: 45 11 S 75 29 ~ 45 4 S 72 5~ ~5 5 S 5~ 4~ ~ ~5 55 S 5~ 1~ ~ ~5 14 S ~:? I 7528.19 5930.30 580J.00 7559.23 5030.00 5903.00 7812.02 5130.00 5000.OO 7956.37 5230.00 5103.00 8050,00 5301,57 5171,67 V'-RTi-Z1L O3'$LEG R =' Ta,:,!- S:CTI2N S-V--RITY ',~ 3 R T =_=ET S:2$/IOD -'~T 1627.94 O. 3 1742.5~ 3.3 ~ ~J. 1 ~ 55..53 19 7 ~ ~ 0 2037,16 'D.37 551. ZgO0.05 2.29 5'~5. 2317.28 2432.A5 ,J. 6D 75~.27 ! 5 a a. :g ,~ D. ,53 737. 2773.45 0.75 95~.'59 ~:~7.'gO J.a7 ;3a,s._" 35 ~002.6~ 0.39 ~2!.~6 3116.77 0.1~ ')54.2'5 ~39 42 ) 4~ ,5'7.~ 3~42.71 1.25 1~17.57 '3~51.55 0.32 13~o.35 3557.60 1.79 1374.'33 ~6,61.75 1.05 1098.29 3762.34 1.El 1120.7.$ :J t .~ R '3 :J T -"t i3~IZ. ~z:T -- - 1547.41 I~55,9! 17e3,~5 Im74..~5 19,5 N. 90 ~0")1. ~ ~ 2203.5~ ~i~ 71 2~2:J.52 252).25 1523.54 i357.40 i;73. 57 231 ~. 1,~ 2;33.35 25~.19 255~). 0~ 2743. 79 2;7,58.73 29,~7.75 3075.'57 33 ~ 2.2 ~ 3493.5~ 3591. ~95 27 7~,. 33 ,:23:3 ::~ . 77 3303.Sa 3117. 52 32}1.!4 3452.33 355~.22 3662, 25 375!.74 3782. ~,~ 3 975. '5 ~ 40~5.~5 ._ S 7~ ~'~ . i, 'F'2 3.o ... 3 7~' 31 .... - .5 ? ) ') 7 , iNC. 24-7 N3RTH ,S g~P'JT ~.TI ] si D~E: 27-J&N-35 TOP B~SE TOP B~SE PSTD ~JP~RJK ' KJm~RU< C KUm&~UK ~ £NT:~PJL~TED V~LJES 7539.00 7577.90 7719.00 7932.9C 7953.30 - MD S ,'=_N =~OM K3 5035.5i 5055.01 6213.14 '3~7.,57== 5301.67 i59' TVS S J~,-S-'~ 537~.51 5.:35.5i 5)35.31 5171.5'7 ~T =',IL, 75' 1171.50 11~1.21 S 3~!5.35 12~5.5,~ ) 395?. 13 12~1.}I C]4PUTfiTZ]N D&f=: 27-J.~lU-D5 ~L'3= ,~ TOP qLJP&~Uq ' ,.., TOP K, UP~RUK a BASE KJD~RU< A ~'5TD TD qE&S. JRE) DEPTH S=LJ~I KS 7539.00 7577.00 7719.00 7.~3Z.~0 7953.00 5JOP.51 5035.51 5085.01 5213.1~ 5227.57 5301.67 TV3 .S J :'.' - S -'~ 5995.;1 5}35.01 53'}7.57 5t7i.57 75' SJq= , S ~T-~/ I171. liaO . 11~1. 1 2S5. I~51.= 127B. ~- - _C],..T? ]~, ~r "- .!3, TiiN, SDJT'~ : a .qT./4- }T =lNa~ DEPTH WE~_ LDS&TIDN ~f TO: TRJE SJB-SEa V~ITiC~' VE~Tt-~L 9=OT:q DEPTH 8060.03 5331.57 5171.57 .3iST2NCE aZIMUTH FEET 42~.T~.~.7,_ '* S 72 27 ,%. SCHLUMBERGER O [ RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. WELL 2H-7 FIELO KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 00007]]84 HORIZONTAL PROJECTION 2H-7 169' FNL, 76' FWL, S36, TllN, R8E N01~H 412120 ~F O00071 I1~1 2ot;)0 1000 -4000 -2000 WEST SCI:LE = 1/I000 IN/FT [ i - 1000 0 1000 2000 3000 4000 SO00 GO00 EAST VERTICAL PROJECTION 2H-7 169' FNL~ 76' FWL, S36, TllN, R8E -gO~O -1000 0 0 1__no0 ~ ~000 3000 4000 5000 8000 ........... ii'' ~ .... ~ i~ ~ .... ~ ............ ~'' '' · ~ ~ ~ ~ , ..: ~ ~q~ ~ ~ ~ ~ ~ , ~, ~ ~-~r' ~ ~ ~-~"F'~r~"r'FF?~-'~"'~ ...... F~Y?~ ~ ~i i~ ~ ~il ~ ~ ~ ~ ~i ~ ~ ~ i f~'T~t~'-'~-~-~'~f'?-~'t-?'~-'t~'t"f- : ! ~ ~ ~ ~~l~]~ ~ i i ~ : : ; ] ~ ~ ~ ~ : , : :: ~ : :: : : : j : : : : : ~ ; ~ : ~ - : : : : : . : : : ; ; : : : : : : : : ; :~ ~ : ; : : . : :: : ; . ~ . ; ; ; : ; , i : · : : : ; · ~ : : : : : : . .. : ......... : , . : . :. ~ i :. . : : : : . :i . : : : I ; : :[:] L L~_~~~. 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L..LLIZ ..L.LLL.LL-LLL --~?.?'-~ .... t~-.~-5~--~---t--'--t--:--~--.t~ : ~ , ~ ~ t-~-"--~r--~'r'h~: '?"?'r"r-"'~'r"~'r"-r-'r"~'"? ..... :-"v-F'~ .... ~ · -~ht~?'?¢?-?,?--??-~-t'--? ..... tt~u~ i~ }~ ~-"'-?-"t--~-'?'"'*-~{'-?--~'-'t ..... ?'?'-: ..... ?T"~ .... t-~--.~--~ ..... ~.--~--~..~.-.~ '~"P-F~'~"'"'~'~'?l?'fl'~"?-~--~ ...... ?'~--?['?'?'?'~ '~ ~ [ ] i ~ ~ ~ ~ ':'-~'Tl'''''5-'~:-T'l '~W~P't'-TT'~'": ..... r..}...r.1, ...... %.v.:..1, ..... :'"T"T"?"T' :'"V ,'": .... · --~+-~--+--H-+-f-'--~-'t-+--+--H-~---~-'~ ....... ;-H-t.--)-.---!-+-.-~-~- ~-~%+--5---H-~?--t---H-~---+'-'i'-- -~H.~---+---H-H-+---+--.* ...... ~--,.--i...~ ...... +-+---+----} ..... +-T--+-.-5-'~---7-'+ .-;--.: .... ...¢4.4-4-1-&.i-¢-} ....... ~.. ~...H.~-I-Z.-LH.} ...... L.4-..~.-.;...¢4-;---~---~- r...*~.4--i-.¢~-.~-.Z-4 ~..Z-L..*-..t.--~..*...:.-.* .... ~-H-~-~--4--4---¢...¢...~ ...... +...}...;..., ...... ,_.L..+...i .... ;...?.,..-=-.J ....... r :...+ -&.;4...b-bbC4-} ....... H--.H.--i-.-;-~--b-¢ ....... H-;-H-.;-¢+--b~4-.4.-4...L¢¢+¢4 ..... ¢-..¢-;-H.--bLH ...... H-~.-4.--b+--4.-., ..... ;--.;.--H ...... i-.H.-.: .... t-bt ....... F H.-:; [.~.-.¢+-¢*-+-~--¢.-~?~-.-+-+++--~1.4-1.+ ....... ~l''~l--.+l.l+'l'~'+++'~l b+l..~++.4...5.t.~_, ...... *--ll*l'?y''tl+l'~l'+''y' --~--'?~+'''.'ll?lS+''t ...... e' t'''fl':''f''+--'t'--r'''* ..... t ...... ?'''' t' +''?' ; ...... -~.~...~--~.-L--g.4-¢..-~.~-}---&--L--~-.4--.;.--*-.-&.-, .-4.--}--}-..g--.~-.&..~..~4..-.--4~..¢...~-{.--~-*-}-4 ...... ¢---*...¢...*.4...~-.&-.L*... ~-*---~-.i---H.*.--+ ....... * ....... H4..-; ...... ~..-* ...... ;...+ ....... *--.;...H-,..-r"+ ..... b.~4-.~4...~..Z.L4-; ....... LA-L-;...:...;...L.L4 ....... ;...L.L.L+~_L.L..~-....L.~..L.;.--¢4 ...... L-.}...¢.-.L-}...t-.b.}-} ..... H¢-.HL4.--;.-.b~...~ ......... ,...:. ;.4.--b.}.-*.-., ....... ;.. ,..-L4.4 ............. ~ ~ ~ ~ ~ ~ ~ ~ ~L¢.L..~ .... :...:. L..: ..... ~ ~ ~ ~ [~ ~ [ ~:.~...L..L_~ .. :...:...L..; ...... ~]~ ~ ~.: .... .}-g...~....-}.--}--$...¢.-.~-.~ 2...;...g ~ ~ ~ ~ : ~ ~ ~ ~ ..... L-.}..4...L.-}...~...¢..~.-.g-~ ....... -¢---L..}.-.: ...... t ¢'"~ ...... ....... ~ .......... +...L.4.. i...L..;j ..... .... * ...... ~...L..:...~--~: ! ............. ]' PROJECTIDN DN VERT. ICAL PLANE 106. - 28S. SCALEO IN VERTICAL I~PTI'-I~ HORIZ SCALE = 1/1000 IN/FT RECEIVED 2 8 lg86 Oil & Gas Cons. Ct~mmisston SusGested form to be inserted in each "Active" yell folder to check for timely compliance with our regulations. Reports and Haterials to be received byI ~ Date Receive Requ~t re--~----- ~ Remarks Drill Stem Test Reports ~~. _ L. FJ · 04 ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 //~. O. Box 100360 ~~ . Anchorage AK 99510-0360 ~ Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints/ Schl/ Open Hole/ One * of each 2H-7 5" DIL/SFL-GR 12-18-85 2" DIL/SFL-GR 12-18-85 5" Den/Neu (poro) 12-18-85 2" Den/Neu (poro) 12-18-85 5" Den/Neu (raw) 12-18-85 2" Den/Neu (raw) 12-18-85 Cyberlook 12-18-85 _~ 2H-8 2H-9 5" DIL/SFL-GR 12-11-85 2" DIL/SFL-GR 12-11-85 5" Den/Neu (poro) 12-11-85 2" Den/Neu (poro) 12-11-85 5" Den/Neu (raw) 12-11-85 2" Den/Neu (raw) 12-11-85 Cyberlook 12-11-85 5" DIL/SFL-GR 12-02-85 2" DIL/SFL-GR 12-02-85 5" Den/Neu-GR (poro) 12-02-85 2" Den/Neu-GR (poro) 12-02-85 5" Den/Neu-GR (raw) 12-02-85 2" Den/Neu-GR (raw) 12-02-85 Cyberlook 12-02-85 DATE 01-28-86 TRANSMITTAL ~ 5531 Please acknowledge receipt and Run #1 2905-8049 Run ~1 2905-8049 Run ~1 2905-8024 Run ~1 2905-8024 Run ~1 2905-8024 Run ~1 2905-8024 Run #1 7400-8000 Run ~1 1000-8786 Run #1 1000-8786 Run #1 8150-8760 Run #1 7350-8760 Run #1 8150-8760 Run #1 7350-8760 Run ~1 8150-8730 Run ~1 1800-8113 Run ~1 1800-8113 Run #1 3450-8088 Run ~1 3450-8088 Run ~1 3450-8088 Run #1 3450-8088 Run ~1 7450-8088 Cons. Ancho~39e, Receipt Acknowledged: State of AK*bl/se NSK Clerk*bl Rathmell*bl [~ & M*bl Drilling*bi Vault*films Date: ARCO Alaska. Inc. ,s a Subsidiary o! AllanticRicttfieldCompany ARCO Alaska, Inc. Post Office 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr..Chatterton: Enclosed are the December monthly reports for the following wells: 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-!4 2H-8 3A-15 3F-14 4-23 16-19 L3-!9 1H-4 2H-9 3A-16 3F-15 4-24 16-20 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions., please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 4 1986 011 & Gas Cons. Uommms~on ARC -- -' !sska. Inc. is = Sub'.-idiary of A.'.lan!icRichfie!dCompany STATE OF ALASKA ALASKA C¢- AND GAS CONSERVATION COi~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS IT. Drilling wel~(~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-170 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20045 169' FNL, 76' FWL, Sec.36, T11N, RSE, UM (approx) 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 129' RKB I 6. Lease Designation and Serial No. ADL 25587 ALK 2673 For the Month of. December , 19 85 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2H-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0600 hfs, 12/13/85. Dr]d 12-1/4" hole to 2919'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8060'TD (12/17/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7953', Secured well & RR ~ 0030 hrs~ 12/20/85. 13. Casing or liner rL~n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 106'. Cmtd w/205 sx AS 11. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 2902'. Cmtd w/850 sx CS Ill & 350 sx CS Il. Top job performed w/130 sx CS Il. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 8043'. Cmtd w/435 sx Class G & 175 sx CS I. 14. Coringresumeandbriefdescription None 15. Logsrunand depth whererun DIL/GR/SP/SFL f/8057' - 7400' FDC/CNL f/8057' - 7400', 6300' - 6000', 5450' - 5000' Ca1 f/8057' - 5000' 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby c~riify that the foregoing is true and correct to the best of my knowledge. ~ ~ .~ Associate Engineer //'7-~/ SIGNED ~ ~ TITLE DATE NOTE~.Report on s form is required for each calendar month, regardless of the status of operations, an~ ~us~ be filed in duplicate with [he Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. TEMP/MR08 Form 10-404 Rev. 7-1-80 Submit in duplicate ARCO Alaska, Inc. Post Office ~_ . 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 ¢ DATE 12-31-85 TRANSMITTAL # 5495 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes Plus Listing/ schl/ One of each 2H-7 12-18-85 Run #1 2H-8 12-tl-85 Run #1 3A-15 12-17-85 Run #1 3B-7 05-25-85 Run #1 3F-12 12-11-85 Run #1 3J-11 12-20-85 Run #1 2875.0-8087.5~.~F~/~ 0992 5-8821 0~~F~-~ ~ 1770 0-7889 u~ 3296 0-727~ ~~~'~-~~ 3295.0-7570.0 1995.5- 7680.0~ ~ ~--~ Gas Cons, Commission Anchorage Receipt Acknowledged: STATE OF AK. Date: ARCO Alalkl. Inc. il -, Sublldiary of AllanlicRichtiel;ICompan¥ ARCO Alaska, Inc. Post Office Bo~,-700360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 2H Pad Wells 5-8 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L23 Enclosure If RECEIVED AUG o ],985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfleldCompany ~2 0 0~ ~ 0 0~4 ~o0 90 OI O~ O~ 04 DRILL Sl'l-,~' 2.H CONDUCTORS AS- BUILT LOCATIONS WELL 5 Y= 5,948,693.29 LAT: 70°16'15.795~'' X= 498,594.98 LONG= 150°00'~0.907'' 169' FNL, 196' FWL, 93.0'05, 98.8' PZ9 WELL 6 ¥: 5,948,693.32 LAT= 70°16' 15.;955'' X= ~98,534.96 LONG: 150°00'~2.5~5'' 169' FNL, 136' .FWL, 93.00G, 98.8 PA~ WELL 7 Y= 5,948,693.27 LAT: 70°16'15.7950'' X= ~g8,474.97 LONG= 150°00'44.401'? 169' FNL, 76' FWL, 92.3 OG, 98.8 PaO WELL 8 Y= 5,948,693.24 LAT= 70°16' 15.7946'' X= 498,414.98 LONG= 150°00'46.1~8'' 16g' FNL, 16' FWL, g1.5'OG,98.8' PAD LOCATED IN SECTION $6 TIIN, RSE, UMIAT MERIDIAN. RECEI ED AUG 3 0 i8~ Alaska Oil & Gas Co.s Commission Anchorage /'~d -E'~E~)Y 3ERT :Y '-:.'" CM' PRCPERLY REGISTERED /~ ~_~CE.NSED TO mRACT[C.E ~_AND SURVEYING iN THE STATE /I ,.t~_,.tSK~ O 'r~,,~T -r,..(.,S PLAT :~EP,ESENTS ~ SUR,..~E¥ ¥~DE F J .,N.~E:~ MY 2 ~ECT SumER', S CN E~ THAT ALL uETA[LS ~ SC~RECT AS S: !! ,- ~ , ~~ ' ARCO Aiosko, Inc. : /! m' mm m~' DR~LE SiTE z., .... / !~11 ~ CO.DUCTO. ~s. U~Ii~' LOCATIONS ,, ' , '- July 29, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2H-7 ARCO Alaska, Inc. Permit No. 85-170 Sur. Loc. 169'FNL, 76'FI.~, Sec. 36, TI!N, R8E, UM. Btmho!e Loc. 1388'F~=, 1090'FEL, Sec. 36, TllN, R8E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 ~AC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated therettnder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kew~ Kuparuk River Unit 2H-7 -2- July 29, 1985 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. %~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing before, drilling below the shoe of the conductor pipe. In the event of suspension or abandor~ent, please give this office adequate advance notification so that we may have a witness present. V%r_y truly yours, /~---; ).x.~ ;,~-~ × / C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI,~-{ISS!ON be Enclosure CC: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Posl Office Bo.. ,00360 Anchorage, Alaska 99510-0360 -i'elephone 907 276 i215 July 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2H-7 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2H-7, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot Diagram and description of the surface hole diverter system ° Diagram and description of the BOP equipment We estimate spudding this well on September 4, 1985. any questions, please call me at 263-4970. S/~re 1 y, jBK/TEM/tw PD/L125 Enclosures If you have ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CO,~zMISSION PERMIT TO DRILL DRILL REDRILL DEEPEN 20 AAC 25.005 lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRAT I G R AB~.'~ I SINGLE ZONE [] :' ~ '~' I MULTIPLE ZON~:)~ ? ~--:~4 ~;.,,, / 2. Name of operator ARCO Alaska, Inc. _ ~3. Address P. 0. Box 1002,60, Anchorage, Alaska 99510 4. Locati'on 0-f well at surface 169' FNL, 76' FWL, Sec.36, T11N, RaE, UN (APprox.) At top of proposed producing interval 1292' FNL, 1413' FEL, Sec.36, T11N, RaE, UN At total depth 1388' FNL, 1090' FEL, Sec.36, T11N, RaE, UN 5. Elevation in feet (indicate K.B~DF etc.) I 6. Lease designation and serial no. RKB 129', PAD 98' I ADL 25587 ALK 2673 -~-B--ond information (see 20AAC 25.025) Federal Insurance ComPany Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit '¥;':"". ' ':':': -'2 10. Well number ,5 2H-7 11. Field and pool Kuparuk R~ver Field Kuparuk River 0il Pool Amount $500,000 13. Distanceand~ir~ctionfrom nearesttown 30 mi. NW of Deadhorse miles 16. Proposeddepth (MD-& TVD) 8060' ND, 62,18' TVD fe~t 14. Distance to nearest property or lease line 1090~ 8 TD feet 17. Number of acres in lease 256O 15. Distance to nearest drilling or completed 2H-6 well 60~ @ surface feet 18. Approximate spud date 09/04/85 19. If deviated (see 20AAC 25.050) 120. Anticipated pressures 2956 psig@ 80°F Surface KICK OFF POINT 12,91 feet. MAXIMUM HOLE ANGLE 46 oI (see 20 AAC 25.035 (c) (2) 2,2,84 . psig@ 5995 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" -16" ..... 62.5# H-40 Weld 80' 29' I 29' 1091 109' + 200 cf '12-1/4" 9-5/8" 36.0# J-55 BTC 2902,' 29' I 29' 292,2'I 2770' 800 sx AS Ill & I HF-ERW ~ I 340 sx Class G 8-1/2" 7" 26.0# J-55/HF-EEW BTC 7465' 28' II 28' 749~'1 5926' 165 sx Class G blend I _K-_55~ FL4S 767' 7293" 5788' 8060" 62,18' 100 sx Class G blend 6-1/8"'5" 15.0# 22. Describe proposed program: AR60 Alaska~ Irc., proposes 'co drill a Kuparuk River Field development well 'co approxima'cely 8060' MD (6318' TVB). A 20"~ 2000 psi annular diver'cer will be ins'called on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through 'che Wes'c Sak sands a'c approximately 2932~ HD(2770' TVD). A 12,-5/8", 5000 psi, RSRRA BOPE stack will be ins'called on 'che 9-5/8" surface pipe. It will be tested upon ins'calla'cion and weekly thereafter. Test pressure will be 3000 psig. Due 'co gas injection at 2A Pad, Kuparuk "C" Sand pressures are presen'cly near 2,500 psi ((~ 6200'SS TVD) and s'ci11 increasing. To drill the well safely, 7" casing will be set at 7492,'MD (5926'TVD) (approxima'cely 100' above the "C" Sand). The 12,-5/8"~ 5000 psi~ RSRRA BOPE stack equipped wi'ch ~-1/2" rams will be reins'called and 'che rams tested 'co 4000 psi, 'che annular to 2,000 psi. A 6-1/8" hole will be drilled 'co TB. A 5" liner' will be set a'c TB wi'ch a 200~ overlap. Expec'ced maximum surface pressure is 2956 psi. Pressure calcula'cions are based on la'ces'c reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble a'c surface, (see attached shee'c) 23. I hereby certify~e foregoing is true and correct to the best of my knowledge SIGNED ~ /////~~ ~. ~¢~_~ TITLE Area Drilling Engineer DATE Samples required ~YES ~4xlO Permit number Form 10401 (TEM) PD/PD125 Rev. 7-1-80 CONDITIONS OF APPROVAL Mud log required Directional Survey required APl number [~YES [~O Approval date i SEE COVER LETTER FOR OTHER REQUIREMENTS 29~ 1985 J~ly ,COMMISSIONER DATE by order of the Commission Submit in triplicate PERMIT TO DRILL 2H-7 (cont'd) including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 2H-7 will be 60' away from 2H-6 at the surface. 2H-7 is also 118' away from 2H-5 at 1650'TVD. Top of cement for the production string will be placed at 6593'MD, approximately IO00'MD above the top of the Kuparuk Sands. The 5" liner will be cemented from TD through the liner lap. After WOC, the liner will be cleaned out and the lap tested to 3000 psi. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well may be fracture stimulated. .0" Z PROPOSELI -Wd~"~JK. F[_E_LD,: NORTH SLOPE, ALASKA F.A~Ttl411, I,~.IItSTOCK. INC. KOP TVD*.1391 THD-1;391 DEP-O 3 BASE"'PERHAFROST' TVD-1465 TIID-1465 DEP=1 9 TOP UGNU SNDS 'TVD-1.S70 TIID-1570 DEP-8 ~UILD 3 t $ _ . PE]I._LOO_.F_I_ . ;a~ TOP' i,/ SAK SNDS fYO-2l?~ K-12 TVD,,2$ZO' TI'ID-2662 DEP-40? .... 45 EO¢ (9 5/8" CSG PT)i TVD-2?7'O TIID=2932 DEP=SBg K-5 TVD-4$30 THD-5~6 DEP-2425 AVERAGE ANGLE 46 DEG 13 MI N 7" CSG PT TVD"Sg26 TflD-7493 DEP"3682 TOP UPPR SND$ TVD"Sgg5 TI'1D'.7593 DEP-3954 TOP-LOgR '9N'BS TYD-604,0--TflD-7658-DEP~'4(~- TARGET CNTR TVD-6088 THD-7727 DEP~4051 .- BASE- KUP SNDS TVD'6ISO THD'?860 DEP'4't47 TD (LOG PT) TVD=~'3t8 ~-8060_.DEP=_.~ 1000 2000 3000 VERTICAL SECTION ! I 4000 5000 f PAD 2..,WELL NO.,? PROPOSED . . KUPARUK'F[ELD, NORTH SLOPE, ' i ~ASTHAN-WHIPSTOCKi [NC, ....... · . . ....... ~ i , · . { · . '~ ' i_..lbOO_. ............ ,__~.!=, '_]:-_._~ ooo_ ¢,,~. . ................ 2,)00 .......... '.~3000 ~ 1000 ...... !. SURFACI . . .. .. i ooo . L ~ SURFACE LOCATION, 169' FI,IL, :76' FVL SEC; 36, Tllti, RSE ~ ' '' t · . 2000 3000 ~000 5000 ' , !,,I TAROET LbCAT[O., ; ! ' Lj1320' FNL, 1320': FEL i-i--;.. .... .-'l T-:'-i-1 ...... ,"'gEC.' 3~. TI ! N, ii' !-I T-';'"-"I ..... r ...... I" .... t ........ t'-.~ 'TVD-6088 ~ ~ ' ~ ~ .~; DEP-4051 ..... ;'- ...... ~ , I . '-S'i"73 DEO 3'0 'HI N E 405'1' TO TAROET) ] . . EAST 38:84 )00 , ~00 - t i 1 ARCO AL A~._.KA.? '.I,~ C. PAp ~. NO, -?-8 PROROSED 'EAST.AN .'C.: 344S' . . . i ) KUPARUK R I VER UNIT 20" DI VERTER SCHEMAT I C 8 DE SCR I PT I ON I. 16' C~TOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER QUICK-C~CT ASSY. 5. TANKO UPPER QUICK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/I O' OUTLETS. 7. I0" HCR BALL VALVES W/I O" DIVERTER LINES. VALVES OPEN AUTOMATICALLY UPON CLOSURE OF Ah~U. AR PREVENTER. 8. 20" 2000 PSI ANNULAR PREVENTER. 2 MAI NTENANCE & OPERA'T I ON,, UPON INITIAL INSTALLATIO~ CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE ADaNULAR PREVENTER ADD BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE AI~LAR PREVENTER I N THE EVENT THAT AN INFLUX OF WELLB(3RE FLUIDS OR GAS IS DETECTED. IF NECESSARY. MANUALLY OVERRIDE ADD CLOSE APPROPR I ATE VALVE TO ACHIEVE DOI~NWIND DIVERSION. NOT SHUT IN VNiELL ANY C I RCUMSTAI',,K::E$ -7 6 ACO,,M,,E. ATOR CAPACITY TgST 1. CHECK A~ FILL AC~TOR RF.~OIR TO Pi~ LEVEL WITH HY~IC FLUID. 2. ~ ~T A~T~ ~ IS ~ ~I WI~ 3. ~~ TI~, ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~~E L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~INI~ 5 ) 4 L · 2 13-5/8" BCP STACK TEST I. FILL BOP STACK A~ (C~ MANIFOL~ WITH ARCTIC DIESEL° 2. ~ ~T ~ L~ ~ ~ IN ~~ ~Y ~RA~. ~T ~T ~ IN WI~ ~I~ ~ ~ ~ IN L~ 3. ~ ~ ~ ~~ KI~ ~ LI~ V~VES ~~ TO ~ STA~ ~ V~S ~ ~ ~~ ~. 4, ~~ UP TO ~ ~I ~ ~ F~ I0 MIN. ~ ~~ TO ~ ~I ~ ~ F~ I0 MIN, ~ ~~ TO 0 ~I. 5. ~ ~ P~~ ~ ~~ KZ~ ~ ~E L~ V~VES, ~ T~ PI~ ~ ~ ~ V~VES ~ KI~ ~ ~ LI~S. 6. TEST TO 2~ PSI ~ ~ ~I ~ IN S~ 4. 7. ~I~ TESTI~ ALL V~VES, LI~S, ~ WI~ A ~ PSI L~ ~ ~ PSI HI~. TEST AS IN ST~ 4. ~ ~T ~~ ~T ~ ~ ~T ~T A ~L ~I~ P~ITIVE ~ ~. ~Y ~I~ TE~T ~S ~T ~ ~ ~LY ~. 8. ~ T~ PI~ R~ ~ ~ BO~ PI~ TEST B~T~ PIPE R~ TO 2~ ~I ~ ~ ~I. 9. ~ B~ PI~ R~, BA~ ~ ~I~ ~ 10. ~ ~I~ ~ ~ TEST TO 2~ '~I ~ PSI. II. ~ ~I~ R~ A~ ~RI~E TEST ~. ~ ~IF~ A~ LI~S ~ ~L ~ ~UID. ~ A~ VALVES IN ~ILLI~ P~ITI~. 12. TEST ST~I~ VALVES, ~Y, ~LY ~S, ~ILL PI~ S~ETY VALVE, A~ I~I~ ~ TO ~ PSI 3~ ~I. ~.?1~.~ ~~ ~ETE B~ ~ST ~ NI~I~ ~ A~ 5 i 0084001 REV. MAY 15, 1985 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. //--/l ~/~ ITF, M APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin(~~ ?-t~-~/ (~ thru 12) (10 and 42) asg (13 thru. ' (22 thr~ 2/6) z / i · . 3. 4. 5. 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO REMARKS Is the permit fee attached .......................................... Is well to be located in a defined pool ............................ Is well located proper distance from property line .... Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ ~_ __ Is operator the only affected party ................................. f'~ Can permit be approved before ten-day wait .......................... ~ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all kno~ productive horizons ................... Will surface casing protect fresh water zones .. i i . Will all casing give adequate safety in collapse, te sio .and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ A/,~, Is a diverter system required .................................... Are necessary diagrams of diverter and BO; equipment &~tached .. Does BOPE have sufficient pressure rating - Test to ---~ psig .. ~.~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. o ~z Geology: Engineering: WV MTM ~ HAH N,~/~ ' JAL~ 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 APPENDIX. , No special effort has been made to chronologically organize this category of information. RECEIVED JAN 0 8 !ggG Alaska Oil & Gas Cons. Commissior~ Anchorage DATE :P511'71'2.:t REEl_, .~h~;{,: :1.42634 PREVIOUS ~ F El.., : DATF, 185/12/2.'1 ORIr.;Ir~ :0000 TAPE :.~ ~ ~-: K :1109 PR~vlO~}S T~,PE COM~E~,T5 D.~TF : ~l~'~l~J{~M bE::~J~TH ~ 1024 F!L[C TYPE PREVIOUS F':[ L ~: M N' F~ ~ CDNTK~IT$ W M : 2 H '- 7 TOWN: 1 IN SECT: 36 COU~: ~v,SbOPE ST,~T: CTRY ~ USA PRES: E UNIT TYPE CATE SIZE CODE 000 000 018 065 000 000 004 065 000 000 014 065 000 000 002 065 000 000 004 065 000 000 00~ 065 000 000 012 065 000 000 006 065 ~00 000 003 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 LVP 010,~!02 VERIF'ICAI"[O,~ L'[STIb~i.; PAG~J .'2.. SCHLU ~t3ERGF.~ ************************** ************************************************************ ~I~[., = 2H-7 FIEI~D = KIJP ARiJ~, C~UUTY = ~?ORTN Si,(~PE ST,~ WE = .~hASKA CA$1N(; = 9,625" TYPE D~ENSIT¥ = I0,7 VT. SCOS!TY = 4,2,0 S PH = 10.0 FLUID LOSS = 5,8 C3 2902' BIT SIZE = 8,5" '.~O 8060' 2 66O 2:860 2.81,0 !o523 ~ 76, ~ 76 ,0 OF OF D F RECEIVED ~A i\~ 0 8 !9 8 6 Alaska OI~ & ~as Cons,, Cormissior~ Anchorage HOI.~F cr~P.E¢'Fl.,rl~ = CAI,I ***** '.FHIS DATA HA,"; ~(';,i' 6EE;)~ D~.,F"];!~ ,%H'IF?~']t) - [)V~RI.,AY$ FIELD PRINTS *********************************************************************************** * , * SCfiLb~;,BH]RfiEi.~ LOGS ]'~.~Cf..L~OEt..')WITH THIS I~AGNMTIC TAP~I * ~ I.)A'.fA AVAiLARI~F]I 8049' TO 2905' * * C9~6'~;NSA'IBO I~EIJTRt).I~;i .L,[;O (FD~) , * i)ATA &V~!I.,~LF~ 8049' TO 2905' , * , ** DATA FBRMAT RECORD ** T~' P ~; SIZE R. EPR CODE ENTRY 2 I, 66 0 4 ~, 66 I LVP 0.1.0,M02 YERIFICATi~N LISTING PAGE 4 8 4 73 60 9 4 65 , 1 lin 16 1 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS MNE~ SERVICE SERVICE UNIT AP1 API AP1 AP1 FILE SIZE SPb REPR ID ORDER # LOG TYPE CLASS MOD NO. DEPT FT O0 000 O0 0 0 4 SFLU DIL OMMM O0 220 O1 0 0 4 ILD PlI. OHMM O0 t20 46 0 0 4 IbM OIL OHM~ O0 120 44 0 0 4 SP DIL MV O0 Ol 0 Ol 0 0 4 GR DIL GAPI 00 310 01 0 0 4 GR FDN GAPI O0 310 01 0 0 4 PROCESS CODE COCTAL) I 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ! 6~ 00000000000000 1 68 00000000000000 I 68 00000000000000 ** DATA ** DEPT q~78 5000 SFLU 3.5315 RHOB . 17 DRHO O, 8 NRAT NPHI 44.531] NCNb 1909,6875 FCNL DEPT 8000. 0000 SFbO ~t, 0940 SP -17.5264 GR 108.9648 GR RHOb 2.2327 DRHO 0,.11~6 ~RAT NPHI 45,8984 NCNb 1932.6875 FCNL DEPT 7900.0000 SFLU 3 6858 $.P -2 RHOR, : 05 DRHO 0 43'9 NRAT NPHI 42.6758 NCNb 2213 5000 FCNb 2 5940 ILS 3, 5 RNRA 505,1406 2.6760 IbM 108,9648 CALI 46~.?092 RNRA .6406 2 9299 IbM 107 _7 48 CALI 3 ~ ~64 RNRA 595 8125 3,2542 8,~020 3, 795 2,8069 9,2598 4,1218 2,9';49 3. ! 39 4 7 oo oooo sr u 78s9 $.P -17:5t07 GR ,~' 8~'464'8 ~I 9 ,4648 , , RHO8. ~,4084 DRHO 0,01~ ~RAT 2.~31 RNRA 2.9553 , 25 NPH~ 3 .7871 NCNb 262'3 50 FCN5 887. 4.2703 IL~ 108.8398 CALI 2.9553 RNRA 717.8125 DEPT 7700 0000 SFLU 4 8445 IbD SP -25 0107 GR 108:.8398 GR RHOB 2 5061 DRHO 0,1348 NRAT NPHI 31 9824 NCNb 2375.5000 F'CNL DEPT 7600,0000 SF'LU 2,.2014 IbD ~ ~}80 IbM SP '32.9"83 GR 126.7148 GR 12 :,, .,48 CALl RHOB 2.3948 DRFiO O' 0308 NRAT 4.0164 RNRA 4.3718 3° 1,9903 10,1738 4. 6531 LVP 010,1i02 VERIFICATION I,;ISTING PAGE 5 NPHI 50,1465 NCN[, 2009 DEPT 7500 SP -45' , RHOB 2, flPHI 0000 SFLU 2, 5820 ~R 115. t850 D~HO 6563 NC~L 1937. 00O0 SFLU 4 5195 OR 192~ 4006 ~R~O O, 2402 NCNb 2041, 0000 SFbU 4 5508 UR 237' 2500 DRHO '999, 2500 NCNL -999, DEPT 7400, SP RHOB 2, NPHI 46, DEPT 7300 SP '52. RHOB -'999, NPHI -999, OEPT 7200 0000 SFLU 4 '53i1445 GR 182 ~POR '99g 2500 DRHO '999 NPHI '999 2500 NCNb '999 DEPT 7100,0000 SP 59,4883 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNb 4 151 -999 -999 8 106 -999 -999 D{gPT 7000 0000 $ r[.,U HOR -999,2500 OR. HO [4.PHI -999.2500 NCNb PT 6900,0000 SFLU -70,2227 GR 'RHOB -999,2500 DRMO NPHI -999,2500 NCNb 4 I10 -999 -999 4 14:4 '999 '999 4 14.7 -999 DEPT 6800 0000 SFLU BP -57 9883 GR RHOB -999 2500 DRHO NPH! -999. 2500 NCNb DEPT 6700,0000 SFLU SP .,74,7852 GR ..o 9.25oo DR.O NPHI 9.,9'2500 NCNL D~PT 6100,0000 SFLU S:P 73,9727 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNb DEPT 6.5~g,0000 SFLU SP ,472'1 GR ,6875 5530 9648 0029 6875 1843 0625 0234 6875 2468 8125 2500 2500 2429 4375 2500 2500 9695 9375 2500 2500 0645 6523 2500 2500 , 23 ,2500 ,2500 ,0007 ,93'75 .2500 ,2500 39 , 0 ,8928 ,9648 ,2500 ,2500 FCNb IbD G~ NRAT FCNL ILD GR NRAT FCNL GR NRAT FCN5 GR NRAT FCNL GR NRAT FCNL NRAT FCN~ N:RAT FCNL GR NRAT FCNL NRAT FCN~ ILD NRAT f'CNb 431.8906 2,2874 IbM 115,9648 CAbI 3,8850 RNRA 454.8906 3,0745 IbM i92,0625 CALI 3.8147 RNRA 482,6406 1233 9,2500 RNR 99,2500 3.5627 182,4375 CALI -999.2500 RNRA '999.2500 2,9323 Ib~ 151. 375 CALl -999,2500 RNRA '999.2500 6,~710 lbM , 0 RNRA '999,2500 11~,863 ,402~ I CAb "999,250 RNRA -999.250~ ,53 IbM 14 ,93~4 5 CALl 2500 RNRA .999, .999,2500 147,81 "999 2.500 '999' .2500 3,7170 11I, hi 2,4319 10,2363 4,2585 3,4377 10,2988 4,2273 3,2991 9,7285 -999,2500 1 O, Ol '999,2500 3,~834 10, 035 -999,,2500 6,0671 lo,8!45 '999,2500 4,0437 '9 ,2500 ,6370 '9~ ,5098 ,2500 3,9221 10,:6582 -999,2500 3,8362 ,2500 LVP OlO.H02 VERIFICATION LISTING PAGE 6 RHOH :999.2500 DRHO NpHI 999,2500 NCNb. DEPT 6400 0000 SFbU SP -35' ,2383 GR RHO~ -999.2500 ORHO NPHI -999,2500 NCNb OEPT 6300.0000 ,FbU ,P -35,2383 GR RMOB 2.4104 OREO NPHI 30.9570 NCNb OEPT 6200 0000 SFLU SP -39,3008 GR RHO8 2.3127 ORHO NPHI 38,3789 NCNB OBPT 5100,0000 SFbU ,P -38,5195 OR RHOB 2,3577 DRHO NPHI 35.7422 NCNI., ooo oooo RHOB .4045 DRHO NPHI 36.328! NCNb DEPT 5900 0000 SFLU ,5195 GR RHOB 999,2500 DRHC] NPHI 999,2500 NCNb DEPT 5800 0~000 SFLU SP -50 7383 GR RHOB -999 2500 DRHO NPHI -999 2500 NCNb OEP? 5700,000 ~R 'P "39 .26'9~ 8FbU :HOB ' O0 9 g. O0 NCNL, DEPT 5600 0000 SFL. U .SP -43.4883 GR RHOB -999,2500 DR,~O NPHI -999,2500 NCNL DEPT 5500 0000 ,P -45'5195 RH08 -999,2500 DRHO NPHI -999,2500 NCNb 5400,0000 :9q99 99 ,2500 ,2500 , 88, -999. -999. 4 98. O, 2 9' , 0° 2415. 3, 105, O, 2.315, 2, 109, O. 2305. 3, 126, "999, "999. 2, 148, -999, '999. -999. "999. 2 174, '999, -999. '999, '999. 2073 2773 2500 2500 1375 5898 0181 5OOO 6721 1523 0273 5000 0549 6523 O200 5000 8420 148 ~96 ,5000 131 398 2500 2500 7659 9375 :2500 2500 2.073 5899 2500 ,2500 ' soo 2500 509~ 152 2500 2500 8679 NRAT FCNI., ILO GR FCNL GR NRAT FCNL IbD GR NRAT FCNb IBD GR NRAT FCN[, GR NRAT FCNb R NRAT FCNI, GR NRAT FCNE I bD GR R ' N. FCNL GR NRAT FCNB b t) NRA F'CN~ I bD -999 O0 3.0745 88.2773 '999.2500 -999,2500 3.3557 98.5898 857. 5 2,7678 99,1523 3.3752 b67,3~25 , 523 , 561 64 ,3125 3,0784 . 834 630, ~25 ,50 -999, 0 1 21 'o -999. ~508 '999, ~ 50 · 3479 "'999.2500 -9 ~,2500 -9. ,,2500 4.7859 RNRA IbM CAEI RMRA IbM CABI RNRA CAb! RNRA IBM CAL! RNRA IbM CAbI RNRA RNRA IbM CAb! R NRA IbM CAb! RNRA RNRA RNRA IbM -999.2500 3.2522 -9 ,2500 3,~8 9 9, 7~0 3.0061 2,8401 10,1816 3,6194 3,0979 10,5020 3,6038 3,1272 '999: 2500 ,:7989 ,3066 - 999: * 2500 4,7976 LVP 010,H02 VERIFICATION I, ISTING PAGE 7 SP NpHI DEPT SP RHDB NPH! -6~!7852 GR 167 3752 DRHO O: 38 ]789 NCNL 2141 4375 0142 5000 sLoo oooo s,' u 2,3342 DRHO 0.0854 40.4297 NCNL 2069,5000 DEPT 5200 0000 SFLU ) P -55,738& GR 120, S~OB 2.3147 DRHO O, ~PHI ]7,2559 NCNb 2473, RHOB NPHI 5100,0000 SFLU 2, -58,4883 GR 49, 2.3870 ORHO O, 36.4746 NCNb ]527, 5000.0000 SFLU 3, -6~.9883 GR !33, .34.79 DRHO O, 44,5313 NCNb 2223, DEPT SI:' RHDB NPHI DEPT 4900,0 0 SFLU RHOB "999,2500 DRHO NPHI '999,2500 NCNb 999, DEPT 4800,0000 SFLU 3, RH'P[ -63,23~3 GR I 14. lB -999,2500 DRHO .,999. NPHI "999,2500 NCNb .,999, DEPT 4700,Q000 SFLU SP -61,7695 GR 108. RHOB ...999,2500 DRHO ~PHl -999,~00 NCN5 DEPT 4600.0000 SFbU 3, 999' ~500 DRHO '99~' NPHI 999,2500 NCNb 6721 7148 0522 5000 5979 9805 1177 5000 RHOB DEPT SP RHOB NPHI 3733 0625 0381 5OOO 635 648 22500 5OO 4592 65023 0 065 648 5 O0 2500 5022 0898 2500 25 00 oooo 450 ,9727 GR 11 3 '670'~5.00 DRHO -99:2500 "'999 ' "999: 500 NCNL -999..9500 4400,0000 SFLU 2 -999, O0 DRHO -99 , '999. 2500 NCNb -999. 4631 O0 2500 GR N R A T FCNb ILD GR NRAT FCNh GR NRAT FCNh GR NRAT FCNb ILO GR NRAT FCNb GR NRAT FCNL IbD GR NRAT FCNL ILD GR NRAT FCNL ILD NRAT FCNL IbD GR NRAT FCNb GR NRAT FCNL 167,4375 3,3752 559,3125 122. 3 3,3342 594,8125 3,9202 120,7148 3,181g 683.3125 4~'4963 ,9805 3.0569 1080,6875 3 3870 133 ".0625 3; 5959 539,8125 ,0295 11 ,4648 "999,2500 '999,2500 3,5940 ,25 0 999,25~0 3,,0803 4648 -999, -999, 99,2500 '999,2500 "'999:2500 '999,2500 3 1038 -999'2500 CALl RNRA IbM CALl RNRA IL~ CALI RNRA IbM CALl RNRA IbM CALl RNRA CALI RNRA CALI R.NRA RNRA CALI RNRA CALl RMRA CALl RNRA 10,~895 3. 600 2,8694 8,2988 3,4788 3,9866 8,5723 3,6194 3,5881 7,4812 3.2639 3,4670 8,7598 4,1179 .~,~0627 ,3926 ',999,2500 3,6702 -999 500 3,5979 8,,4 95 -999;2~00 ,~, 0784 .999:40828 2500 2,9006 9,0488 -999,2500 bVP OlO.H02 VERIFICATION I. ISTING PAGE DEPT NPHI DEPT RHO~ NPHI DEPT RHOB NPHI SP RHO~ NPHI DEPT SP RHOB DEPT NPHI -p DE~ T SP NPHI DEPT NPH! N'PHI D~PT RHOB NPHI D.,,,PTE' SP RHOB NPH. I 4300.0000 -67.4727 '999.2500 '999.2500 SFLU GR DRHO NCNb SFLU GR DRHO NCNb SFbU GR DRHO NCNL SFUU DRHO NCNU SFbU GR DRHO NCNU S F L U DRHO NCNb DRHO NCNb SFLU DRHO NCNb FL.U DRHO NCNb $ F b U DRHO NCNb SFLU DRHO N C N D 4200 00OO '70.2227 -999.~500 -999.2500 4100 0000 -72' ,0352 -999.2500 -999.2500 4000.0000 -74.9727 -g99.2500 -999,2500 3900. 0000 -76.4727 ..999 2500 .9 9:2soo 3800 0000 -78:22~7 -999.2500 '999.2500 3~00,0000 81.4727 '999,2500 '999,2500 3600 O000 . ,250 -999.2500 3500,0000 -87,97~7 -9:9 9, _2500 -'999,2500 3400,0000 -85.7227 -999.2500 '999.2500 3300,0000 '87,2227 ,2500 3 1174 ILD 112!4648 G~ -999 2500 NRAT -999 2500 FCN[. 2 8401 IbD 103,3398 GR -g99.2500 NRAT -999.2500 FCNL 2 9670 101:7148 GR -999.2500 NRAT -999.2500 FCNE 2 7659 105,1523 GR -g99,2500 NRAT -999,2500 FCNL 2.8264 IUD 107.589~ GR -999,2500 -999.2500 FCNL 3,0295 1~,0273 GR :9. ,2500 NRAT g99.2500 f'CNI. ~,508~ g ,902 GR '999,~00 NRAT -999. O0 FCNL 3.2795 IbD 89.~398 '999. 500 RAT '999,2500 FCN5 85. ~R -99~,.2500 NRAT -99 ,2'~00 FCNL . og: 999..2500 FCNL 4.2781 IbD 89,1523 3,3772 112.4648 -999,2500 -999,2500 3 1409 -99 .2500 ~999.2500 3,2542 101.714B -999,2500 -999.2500 3,1292 ' 99, 500 '999,2500 . 898 99 ,2500 -999:2500 -999~25'00 -999'2500 3,2815 . 89,3395 9'99,2500 -999.2500 99;2500 3,6'252 .100,0273 999.2500 -999.2500 8 , 23 99,,2'500 IbM CALI RNRA IbM CALI RNRA RNRA IbM CALl RNRA RNRA CALI RNRA CALl RNRA CALI RNRA CAb I RNRA CAUI RNRA RNRA 3 ]342 9:598 -999.2500 3,0745 9,~035 '999. 500 3,1897 9,0176 .999,2500 3,1155 9,4082 -999,2500 -999,2500 3,2034 -999, , 7502 ,4082 -999,2500 2,965! -999, 6,8640 9,6270 -999,2500 4,'~570 9. 910 '999.2500 LVP 010,HO~ VERIFICATIO?I LISTING PAGE 9 DEPT 3200,0000 SFLU SP -88,7227 GR NPHI -999.2500 NCNb 5 9304 , 74,4023 GR -999.2500 NRAT -999.2500 FCNL DEPT 3100 0000 SFLU SP '90:2227 GR RHOB "999.2500 DRHO ~PHI -999.2500 NCNb 2 1526 111.214B GR -999,2500 NRAT -999.2500 FCN[. DEPT 3000 0000 SFLU SP -93i2227 GR RHOB -999 2500 DRHO NPH! -999 2500 NCNb 4.3015 -999 500 NRAT -999,2500 FCNL DMPT 2900,0000 SFLU SP -59.2383 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNb 200~,6875 XLD 5 ,8555 GR -999.2500 NRAT -999,2500 FCNL DEPT' 2875.0000 SFLU SP -56,4883 GR RHOB -999,2500 DRHO ,NPHI -999,2500 NCNb 2000 6875 ..999,2500 NRAT -999,2500 FCNL ** FILE TRAII~ER ** FILE I~AME :EDIT ,001 SERVICE NA~E VERSION ~ DATE ~ AXI~[)M LENGTH : 1024 ~Xl FI[.E. NAME EOF 6 0046 IbM 74:4023 CALI '999,2500 RNRA -999.~500 3.3518 111.2148 CALl -999,2500 -999.2500 5 32~0 IbM 93:08 8 CAbI -999,2500 RNRA -999.2500 6,6609 IbM 54,8555 CALX -99~,2500 RNRA -99 ,250o 5 305 CAbI "999 500 RNRA . 9 : soo 5,5359 1~,1895 -99 ,2500 2,9534 10.8145 -999,2500 4,9734 9,6426 -999.2500 87 -999:2500 2000,6875 -999, 0 ** TAPE TRAILER ** SERVI ~EDI CONTINUATION # NEXT TAPE NAME COMMENTS :LIBRARY TAPE ** REEb TRAILER ** , ~ ,- ~'f 3ERVIC~,. ,~A~E. DATE :85/12/23 :ORIGIN :' R~Eb NA~E :1426'34 LVP 010.H02 VERIFICATION I, ISTING PAGE 10 C[]NTINI~ATION # NEXT R~2EL NAME CUMMENTS :LIBRARY TAPE RECEIVED JAN 0 8 1986 Alaska Oil & Gas Cons. Commission Anchorage
