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Home My WebLink About184-224By Samantha Carlisle at 11:16 am, Oct 29, 2020 Brian Lewis Digitally signed by Brian Lewis Date: 2020.10.29 08:52:07 -08'00' SFD 11/2/2020 184-224 Set Patch DSR-11/10/2020VTL 11/03/20 X RBDMS HEW 10/29/2020 Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR 2 3 2020 /^ 2"1OGCC 184224 32798_ 23 -Apr -20 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPEj28-Dec-19 OGGING DATE PRINTS # CD # 12N-309 50-103-20293-00 906207893 Tarn Packer Setting Record Final -Field 02 2W-12 50-029-21240-00 906212841 Kuparuk Packer Setting Record Final -Field -Jan-20 03 3H -14B 50-103-20092-02 906340305 Kuparuk Packer Setting Record Final -Field Mar -20 0 1 4 3H-26 50-103-20208-00 906340306 Kuparuk Leak Detect Log Final -Field 28 -Feb -20 0 1 5 3H-35 50-103-20805-00 906363845 Kuparuk Radial Cement Bond Log Final -Field 4 -Mar -20 0 1 6 3H-146 50-103-20092-02 906349140 Kuparuk Multi Finger Caliper Final -Field 29 -Feb -20 0 1 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date Signed: T.,i 0 0 >M �_ ? M X aJ cd bvot, 7 \' U - _ > L U a .a O N O C u 4 >, V a fl o C C a +� C C +� o ro▪ C a C C L 10 LL 0 z u °' >' Q O JLLI�'WO w r` r` ti r` r` N N cu 0 6 m -+ d C7NZ (.2 +C U O LI) d O W O U U U 0 U U U U E -6 +� -0 N 5. cC <-,- - 0 0 0 0 O O O O C -C ro o N Q P Y r N M er u7 Co Co O C +U+ i C un Z pJ5 u Z d O. v > -0 v il 011 0. o C � U▪ U a"' ro O 0 o 0 0 0 o 0 o a o w. J J J J J J J J tiA C o > W W W W W W W W .N a1 'C U `- I- LL LL LL LL LL LL LL LI. +' a1 a1 t!: t-'Q Q < < d d d d n O .0 0 O) 4' cl'Z Z Z Z Z Z Z Z v L aJ 0 a1 CI: LL LL LL LL LL LL LL LL m :CI >C-CO Q n +U+ +.+ a)E 4i u O C3 z a u v «.. U t0 0, C O O S r0 . ., H Y c".."; Op a; F- > u O .� C ro a O O U z < a) a o CO. J L 00 a. 1 W O LL LL LL y LL LL a. Z. O o C O 0 0 a 0 N 4i mC _ la as CL � 7 m f- a c) a 0 v: V IX c4W: • > CO 4) t°U rbRILI v WV > Q I \ U s+ fl. t� O r a , I �P" Z1 41 x W O Otl - a ' J J J J J J J J �� p Gl I a' a' ceccacecer £ W W W W W W W W 7 LU > > > > > > > > t z Y Y Y Y Y Y Y Y 0 ,�' aaaaaaaa -st a o.O ti Y Y Y Y Y Y Y Y 0 DDDDDD = D on ro sX .� CV U o Co M M CO M M M M M X NCO W O 0 0 0 0 0 0 0 0 0 0 4J O O O O O O O O !'V U tlt o r` r` ro Co ti r r` C O rb ao 0o ao w CO rb W V 0 0 7 0 0 0 7 7 asC 0ii< xu no too 0 \ Cr C Co 0 0 0 0 0 0 0 0 00 r•-- 6 °o 6 o v o co o .I F N O F- u) M < I.- CO 0 M :.'' O N 0 0 N N N 0 U r` pO O O - M M _0N a) vi F...- , N N N O N N N NC �j 0 0 0 - 0 0 0 0 7 IIIIIIII 0 0 0 0 0 0 0 0 V 0 a1 Ora C U) rn r() N N rf) r[) N G U C as EL l!1 a) tO aJ C- I-z rn L a Y r. Z Y 0 a' C _ L 1.1 al d 3 a_ d z �+ m 0 0 0 0 0 ! 4, E a) H 2 2 E co a m = a n N N U 2 N > z a ca C a < O N N N N N rn t C c fd = Ca N , ^ k., f`0 .L a/ N OCA aL a - ~ a n 22.4 2- 359 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 15, 2015 Attn.: Makana Bender DATA LOGGED 2i.S2 � 333 West 7th Avenue, Suite 100 ivi.K. ENo�D R Anchorage, Alaska 99501 RECEIVED FEB 0 5 2015 RE: Production Profile: 2W-12 ` S)GCC Run Date: 12/27/2015 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 2W-12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21240-00 Production Profile Log 1 Color Log 50-029-21240-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'IThNTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 SCOW LL Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Ima~roject Well History File' Cover~cje XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ]_ ..~ _/2/. ~.~'~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] /--Grayscale items: [] Other, No/Type D Other items scannable by / large scanner [3' Poor Quality Originals: [] Other: .... OVERSIZED (Non-Scannable) · ~' ' Logs of variou9 kinds NOTES: [] Other BY: ~REN VINCENT SHERYL MARIA LOWELL DATE:7--~ Isl Project Proofing ., BY: BEVERLY BRE~SHERYL MARIA LOWELl_ Is/~_ Scanning Preparation x 30 = + "' TOTAL PAGES ' ' Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ~X~ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~'~YES BY: BEVERLY BREN VINCENT~MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDiVIDUAL PAGE BASIS DUE TO QUALIT~ . GRAYSCALE OR COLOR NO ReScanned (individual page [special attention] scanning completed) RESCANNED BY.' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Re~3NOTScanned.wpcl STATE OF ALASKA ,%4.' `'' ^'. 4 • ALI•(A OIL AND GAS CONSERVATION COIb�SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon F Repair well F`" Rug Perforations f Perforate E Other j .. ,;C' f 7, Alter Casing r Pull Tubing I✓ Stimulate - Frac E Waiver r Time Extension E Change Approved R - ogram "" Operat. Shutdow n E Stimulate - Other fl Re -enter Suspended Well F- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I✓ . Exploratory F — 184 -224 • 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50 029 - 21240 - 00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25642 2W - • 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 8092 ' feet Plugs (measured) 7505 true vertical 6314 feet Junk (measured) 7900, 7908 Effective Depth measured 7982 feet Packer (measured) 7482, 7678 true vertical 6221 feet (true vertical) 5818, 5972 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110 110 SURFACE 2690 9.625 2721 2427 PRODUCTION 8042 7 8068 6294 SCANNED JUN 18 2013 Perforation depth: Measured depth: 7570 -7808, 7827 -7831, 7840 -7848, 7872 -7877 True Vertical Depth: 5887 -6078, 6093 -6097, 6104 -6111, 6131 -6135 Tubing (size, grade, MD, and TVD) 3.5, L -80, 7470 MD, 5909 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER HB PACKER @ 7482 MD and 5818 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 7678 MD and 5972 TVD NIPPLE - CAMCO'DS' NIPPLE @ 520 MD and 520 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory I Development 1 ' Service r - Stratigraphic E 16. Well Status after work: Oil 9 — • Gas .°" WDSPL E — Daily Report of Well Operations x GSTOR E WINJ f WAG E GINJ r SUSP r SPLUG V 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 Erik Nelson a 263 -4693 Email Erik.Nelsonacop.com Printed Name rik Nel Title Sr. Wells Engineer Signature Phone: 263 -4693 Date�j / / • c lY� RBDMS JUN 12 20' Form 10 -404 Revised 10/2012 �� / � � J3 Submit Original Only KUP 0 2W -12 v 1 -, ' Well A ttributes Max Angle & MD TD ConocoPhillips g r Ids,a li?, Wellbore APIIUWI Field Name Well Status Inc! 11 MD (960) Act Bim (RKB) ,clap, 500292124000 KUPARUK RIVER UNIT PROD 47.68 2,500.00 8,092.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date -' SSSV: TRDP 85 12/6/2011 Last WO: 6/8/2013 34.19 12/31/1984 Well COnHq'. - 2W -12. 6/11/20138 23: 24 AM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag SLM 7,894.0 4/16/2012 ' Reason: •' • haggea 6/10/2013 HANGER,24 ... Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd CONDUCTOR 16 15.062 31.0 110.0 110.0 62.58 H WELDED X0 THREAD, I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 26 SURFACE 95/8 8.921 31.1 2,721.2 2,427.2 36.00 J - 55 BUTT Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 25.4 8,067.7 6,294.1 26.00 J -55 BUTT Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, TUBING 2013 W0 I 3 1/2 2.992 23.9 7,470.1 I 5,808.8 I 9.30 L - 80 EUE Bid ABM 31 -110 ' Completion Details Top Depth NIPPLE, 520 (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) ® 23.9 23.9 0.27 HANGER HANGER FMC Gen VI w/PUP JOINT 3.478 520.2 520.2 0.32 NIPPLE CAMCO"DS" NIPPLE 2.875" PROFILE(used) 2.875 SLEEVE, 1,891 7,457.5 5,799.0 38.97 SEAL ASSY BAKER SEAL ASSY GBH -22 2.990 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd j, TUBING 1992 WO 4.6 3.867 7,462.4 7,704.8 5,994.9 9.30 L -80 EUE -ABM I 4 "x3.5" SURFACE. , IL Completion Details Top Depth 31 -2'721 (TVD) Top Incl Nomi... Top (ftKB) (ftKB) (9 Item Description Comment ID (in) GAS LIFT, 7,468.6 5,807.6 38.89 PBR BAKER PBR w /10' STROKE 3.000 2,900 ® 7,482.3 5,818.2 38.79 PACKER BAKER HB PACKER 2.890 ® 7,563.6 5,881.9 38.22 BLAST RING BLAST RINGS (3) OD 4.6 / ID 3.867 3.867 MI GAS LIFT 7,664.3 5,961.6 36.91 SLEEVE -O CAMCO CB-1 SLIDING SLEEVE (Modified) Shift OPEN 9/15/97 2.812 4,667 7,677.0 5,971.7 36.74 SEAL ASSY BAKER GBH -22 LOCATOR SEAL ASSEMBLY IS 'FLUSH' 3.000 Ur TIF 7,678.0 5,972.5 36.73 PACKER BAKER FB-1 PERMANENT PACKER 4.000 AK 7,681.3 5,975.2 36.69 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT, 5,952 L-- 7,694.4 5,985.6 36.52 NIPPLE CAMCO D NIPPLE 2.750 MIEF 7,703.9 5,994.2 36.73 SOS BAKER SHEAR OUT SUB 2.992 Elk Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, _ Top Depth 6,856 (TVD) Top Intl Top (RKB) (RKB) ( °) Description Comment Run Date ID (in) - - -- 1,891.0 1,825.4 33.86 SLEEVE 3.313" x 1.85" ID ISO SLEEVE ACROSS SSV 5/21 /2013 1.850 GAS LIFT _ 7 7,496.0 5,828.9 38.70 CATCHER 2.73 x 123" CATCHER ON WRP 5/21/2013 0.000 7.405 ® 7,505.0 5,835.9 38.64 PLUG WEATHERFORD SPECIAL CLEARANCE WRP 5/19/2013 0.000 MN 7,900.0 6,153.8 33.55 FISH 1" DMY LOST IN RATHOLE 4/26/2004 4/26/2004 0.000 7,908.0 6,160.4 33.51 FISH 1 1/2" DMY Lost in rathole 6/12/1997 6/12/1997 0.000 SEAL ASSY, ,457 7457 Perforations & Slots Shot PBR, 7,469 Top (TVD) Btm (TVD) Dens PACKER, 7,482 -L Top (ftKB) Btm (ftK8) (ftKB) (RKB) Zone Date (sh... Type Comment 7,570.0 7,573.0 5,886.9 5,889.2 C-4, 2W -12 10/27/1992 5.0 RPERF 4.5" SWS HJ II; 60 deg. ph CATCHER. 1 7,573.0 7,600.0 5,889.2 5,910.5 C-4, C -3, 2W -12 10/27/1992 0.0 SQEE... SQUEEZED OFF 7,496 PLUG, 7.505 7,758.0 7,760.0 6,037.2 6,038.8 A-4, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ II; 120 deg. phasing 7,760.0 7,800.0 6,038.8 6,071.2 A-4, A -3, 2W -12 10/27/1992 8.0 RPERF 4.5" SWS HJ II; 180 deg. pH 7,800.0 7,808.0 6,071.2 6,077.5 A -3, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ II; 120 deg. phasing ig 7,827,0 7,831.0 6,093.2 6,096.5 A -2, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ II; 120 deg. phasing BEEBE. II 7,570 - 7.573 7,840.0 7,848.0 6,103.9 6,110.6 A - 2, 2W - 12 1/31/1985 4.0 IPERF 4" DA JJ II; 120 deg. phasing SOEEZE, 7,573 - 7,800 7,872.0 7,877.0 6,130.5 6,134.6 A -2, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ II; 120 deg. phasing Cement Squeezes SLEEVE -0, Top Depth Btm Depth 7.864 (TVD) (TVD) Cement Top (ftKB) Btm (ftKB) Description Start Date Comment squeeze. 7,573 7 ,573.0 7,673.0 5,889.2 5,968.5 Cement Squeeze 10/29/1992 Squeezed Cement SEAL ASSY, 7,.677 7 - .r µ Notes: General & Safety PACKER, 7,678 End Date Annotation SSE, 7,681 rBMW 10/29/1992 NOTE: WORKOVER 1/11/2011 NOTE: View Schematic w/ Alaska Schematic9.0 6/24/2012 NOTE: 1/2 OF FISHNECK ON GLV @ 5821' IS STRIPPED NIPPLE. 7,894 li 8/17/2012 NOTE: SMALL LEAK @ SSSV 1891' RKB, VERIFIED w/ ELINE TECWEL LOG SOS, 7,704 2/4/2013 NOTE: BAILED ASPHALTENES FROM 7411 TO 7421 SLM IPERF, 7,758-7,760 \ t" RPERF, � q L T 7.780.7.800 W _ew.y 0.? ,.lp `,��1 - i .. : . u»i. ;1 "' mod ^+ "'''' , `'I IPERF, Top Depth Top , Port 7,600 -7,808 5... (TVD) Inc! OD Valve Latch Size TRO Run IPERF, M N... Top (RKB) (ftKB) ( Make Model (in) Sery Type (in) WA) Run Date Com... 7,827 - 7,831 1 2,900.0 2,549.4 46.75 Camco KBMG 1 GAS LIFT DMY BK -5 Type 0.000 6/7/2013 7,840 IP-7,64ERF, 8 2 4,666.6 3,792.0 46.29 Camco KBMG 1 GAS LIFT DMY BK -5 - 0.000 6/7/2013 3 5,952.0 4,693.1 44.65 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 6/7/2013 PERF, 7,87z -7,577 4 6,856.3 5,346.5 42.68 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 6/7/2013 5 7,405.2 5,758.7 39.33 Camco KBMG 1 GAS LIFT SOV BEK 0.000 6/7/2013 FISH, 7,900 FISH. 7,908 PRODUCTION. 25 - 8,088 \ 4 _ TD, 8,092 2W -12 Pre -Rig Well Work Summary DATE SUMMARY • 5/11/2013 BAILED DRY HARD PACKED ASPHALTENES FROM 7411' SLM TO 7432' SLM. IN PROGRESS. 5/12/2013 BAILED —40' OF ASPHALTENES & PULLED 3 1/2 WRP @ 7505' RKB. IN PROGRESS. 5/13/2013 MEASURED BHP ( 3307 psi ) @ 7673' SLM; BRUSHED & FLUSH TBG FROM 7500' SLM TO 7300' SLM. READY FOR E -LINE CALIPER & WRP. SLICKLINE TO FOLLOW AFTER. 5/18/2013 LOG 24 ARM CALIPER FROM 7800' TO SURFACE. HAD TO WORK TOOLSTRING FROM 7500' TO 7800'. APPEARED TO BE PUSHING DEBRIS /ASPHALTINES DOWNHOLE. NOTICED ANOMALY AT 6355' ON CALIPER LOG THAT SHOWED APPROX 2.5" RESTRICTION, RELOGGED AND DID NOT REPEAT, POSSIBLY MORE DEBRIS THAT WAS KNOCKED LOOSE BY CALIPER. DATA SENT TO ANCHORAGE FOR PROCESSING. READY FOR WRP. 5/19/2013 RUN 1: RIH W/ 2.785" GAUGE RING, FALL FREELY TO 7357', WORK TOOLS DOWN TO 7615'. RUN 2: RIH W/ CCL AND WRP. SET WEATHERFORD 2.69" SPECIAL CLEARANCE WRP AT 7505', LOG CORRELATED TO TUBING DETAIL RECORD DATED 29 OCT 1992. JOB COMPLETE, READY FOR SLICKLINE. 5/21/2013 TESTED WRP 1500 PSI, PASSED. SET 2.73" x 123" CATCHER ON WRP @ 7505' RKB. PULLED DV @ 7408' RKB. BLED TBG f/ 900 TO 700 PSI. SET 3.313" x 1.85" ID ISO SLEEVE ACROSS SSSV @ 1891' RKB. DHD TO BLEED TBG. 5/23/2013 (PRE RWO): BEED TBG AND IA TO 0 PSI (IN PROGRESS). 5/24/2013 (PRE RWO): TUBING DRAWDOWN TEST FAILED. • • S Conoco Phillips Time Log & Summary We!Mew Web Reporting Report Well Name: 2W - 12 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 5/29/2013 9:30:00 AM Rig Release: 6/8/2013 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/27/2013 24 hr Summary Rig was released frorm 1J -135 at 1500 HRS. Called for Peak trucks. Load the Satellite camp, Pit module and the Mechanics truck shop, move to 2W -pad. 15:00 00:00 9.00 MIRU MOVE MOB P Rig was released form 1J -135 at 1500 HRS. Load up the Pit module, Mechanics shop and the Satellite camp. Mobilze same to 2W pad. Prepare sub base and lower derrick. Continue mobilze equipment to 2W pad. 05/28/2013 Continue mobilize Pit Module. Shop, and Satellite camp to 2W pad. Arrive on location at 0500 HRS. Rig moving from 1J pad. Set pit liner, spot camp, and berm same. Continue rig move. AOGCC notified with 48 HR notice. 00:00 12:00 12.00 MIRU MOVE MOB P Continue moblize pit module, shop, and satellite camp to 2W pad. Set pit liner, spot camp, and berm same. Continue move rig to 2 W pad. Prepare 2W location for matting boards. 12:00 00:00 12.00 MIRU MOVE MOB P Continue move rig to 2 W pad. Prepare 2W location for matting boards. Set herculite and matting boards for Satellite camp. SPot camp. RU Same. 05/29/2013 Continue mobilize the Sub base to 2W pad. Lay Herculite and matting boards, and spot rig over well, and pit module. Continue rig up bleed tank and lines. Shut in well: SITP =120, SIIA =30, SIOA= 220psi. Bleed down pressure on IA to 0, bleed tubing on tubing to 0 in 30 minutes. Circulate tubing to IA initial pressures; 1 BPM = 40 psi, 2 BPM = 50 psi, 3 BPM = 65 psi. Pump 11.1 ppg at 3 BPM, Tubing to IA with 1400 strokes away, tubing vol., 65 psi pump pressure, 3400 strokes; 260 psi, 4400 strokes; 350 psi, 4510 strokes, S2S; 340 psi. FCP = 340 psi. Slowed pumps to 2 BPM at 5365 strokes with 130 psi. Weighed returns at the choke until 11.0 on return. Shut in to monitor well for 30 minutes; SITP = 0, SIIA = 6 psi. 00:00 02:00 2.00 MIRU MOVE MOB P Continue move rig to 2 W pad. Prepare 2W location. Rig on loaction at 0200 HRS. 02:00 06:00 4.00 MIRU MOVE MOB P Set herculite and matting boards. Spot rig over well. Spot pit module. Set berm for bleed tank. Set bleed tank. Rig up choke house & hardline from cellar to bleed tank. Set MI Mud engineers shack. 06:00 08:00 2.00 MIRU MOVE MOB P Berm rig and pits, set cuttings tank and shop. Hook up interconnect. 08:00 09:00 1.00 MIRU MOVE MOB P Raise derrick and pin legs. 09:00 11:00 2.00 MIRU MOVE MOB P Hang bridal lines and bring on fluids to pits. Rig accepted at 09:30 HRS Page 1 of 13 • • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 11:00 14:00 3.00 SURPRI WHDBO RURD P Prepare cellar and well head; change flange on IA, RU hardline and choke house to Tiger Tank. 14:00 16:00 2.00 SURPRI WHDBOOTHR T Standby, waiting on FMC rep with lubricator. 16:00 19:30 3.50 SURPRI WHDBO PULD P RU lubricator, Pulled BPV with lubricator. 19:30 20:00 0.50 SURPRI WHDBO PRTS P RU circulating equipment and pressure test to 1000 psi. Pressure tested surface to 1000 psi, RU lines in the cellar to bleed tank to choke and bleed tank. Loaded and pressure tested hard lines through choke to bleed tank to 1000 psi. 20:00 23:00 3.00 SURPRI WHDBO KLWL P Shut in well: SITP =120, SIIA =30, SIOA= 220psi. Bleed down pressure on IA to 0, bleed tubing on tubing to 0 in 30 minutes. Circulate tubing to IA initial pressures; 1 BPM = 40 psi, 2 BPM = 50 psi, 3 BPM = 65 psi. Pump 11.1 ppg at 3 BPM, Tubing to IA with 1400 strokes away, tubing vol., 65 psi pump pressure, 3400 strokes; 260 psi, 4400 strokes; 350 psi, 4510 strokes, S2S; 340 psi. FCP = 340 psi. Slowed pumps to 2 BPM at 5365 strokes with 130 psi. Weighed returns at the choke until 11.0 on return. Shut in to monitor well for 30 minutes; SITP = 0, SIIA = 6 psi. 23:00 23:30 0.50 SURPRI WHDBO OWFF P Open well and monitor for 30 minutes SITP = 0, SIIA = 6 psi. 23:30 00:00 0.50 SURPRI WHDBO RURD P Blow down lines and continue to monitor. 05/30/2013 Bleed off pressure from IA and tubing, pressure building on IA to 40 -45 psi. Lined up to take returns to pit through rig secondary choke. Bled off OA pressure from 900 to 125 psi. Circulate 3000 strokes to get repeated 11.1 returns to pits. Shut down pumping and bled 5 psi off IA. Opened well and fluid levels monitored static. FMC rep set BPV and test to 1000 psi. ND Tree and NU BOP stack with adapter flanges. Corroded threads on hanger mitigated and blanking plug installed. Continued to NU BOP stack and stack control equipment. Body tested stack to 4000 psi to ensure blanking plug integrity - good test. PU and MU testing equipment, fill stack and lines for testing. Started BOP tests. Test Witness waived by Bob Noble 06:20 5/30/2013. Released Halliburton and Weatherford from standby contingency. 00:00 02:30 2.50 SURPRI WHDBO RURD P Finish blow down of all lines. Continue monitor well. Observed fluid continued to flow to bleed tank. Shut in pressure was 50 PSI on the IA. Tbg = 6 PSI. Rig up lines. 02:30 05:00 2.50 SURPRI WHDBO KLWL P Continue to pump 11.1 Brine down tbg taking returns through the IA to the pits, until observed good 11.1 PPG brine back to pits. 05:00 05:30 0.50 SURPRI WHDBO OWFF P Monitor well - static. IA = 0 PSI. Tbg = 0 PSI. Page 2 of 13 • Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:00 0.50 SURPRI WHDBO NUND P Install BPV as per FMC rep. Pressure test down IA in the direction of flow for the BPV to 1000 PSI. Good test. 06:00 07:00 1.00 SURPRI WHDBO PULD P Secure well set BPV, test to 1000 psi - good. Remove and blow down lines. 07:00 11:00 4.00 SURPRI WHDBO NUND P Open tree and drain all fluids, ND Tree, hanger threads corroded and pitted. Consult town, clean threads and install blank plug (11 turns). 11:00 21:30 10.50 SURPRI WHDBO NUND P NU BOPE, MU adapter spool, set stack and torque flanges, connect control lines, Welder MU Bell nipple, test Sierra gas monitoring system - good test, Install bell nipple 21:30 22:30 1.00 SURPRI WHDBO BOPE P Fill stack and test against blanking plug to 250 / 4000 psi - good. 22:30 23:30 1.00 SURPRI WHDBO BOPE P PU test tools, MU 3.5" IBOP, FOSV, and ported sub, fill stack and choke manifold. 23:30 00:00 0.50 SURPRI WHDBO BOPE P Test BOPE - 2 7/8 "x5" UBVR, chokes 1 -6, Kill Demco, HCR Kill, FOSV => 250/4000 psi - good test. 05/31/2013 Test BOPE, Test Witness waived by AOGCC Bob Noble 06:20 5/30/2013. Tested CH valves 7 -11, 14 and 15. 14 failed, greased and fuCtion passed. Test annular with 3 1/2" Test jt. 250/3500 good. LD 3 1/2" and MU 4" test jt, test FOSV and IBOP good. LD 4 "and measure RKB. Test 2 7/8 "x5" UVBR, HCR choke, and Manual choke, hydraulic IBOP, LKV with 4" test jt 250/4000; good. Perform Koomey drawdown test; good. Test Blinds, CH valves 12 and 13; fail. Change ram rubber seals, During change ram door actuator bent. Get parts from Deadhorse and repair same. Fill stack and attempt testing again. Chasing leaks 00:00 05:00 5.00 SURPRI WHDBO BOPE P T estin BOP 's 250/4000 on equipment tests, 250/3500 annular. Tested CH valves 7 -11, 14 and 15. 14 failed, greased and fuctioned passed. Test annular with 3 1/2" Test jt. 250/3500 good. LD 3 1/2" and MU 4" test jt, test FOSV and IBOP good. LD 4 "and measure RKB. Test 2 7/8 "x5" UVBR, HCR choke, and Manual choke, hydraulic IBOP, LKV with 4" test jt 250/4000; good. 05:00 05:30 0.50 SURPRI WHDBO BOPE P Perform Koomey test. Init. P= 3000 psi, after closing = 2100 psi. Observed first 200 PSI increase in 11 seconds, with full 3000 PSI obtained in 51 seconds. 5 Nitrogen bottles with an average PSI of 2000. Closing times; UVBR = 3 sec, Blinds = 4 sec, Annular = 17 sec, HCR choke and Kill = 1 sec. 05:30 06:00 0.50 SURPRI WHDBO BOPE P LD test tool and RD top drive, LD test jt. 06:00 09:30 3.50 SURPRI WHDBO BOPE T Test Blinds, CH valves 12 and 13; fail. Trouble shoot and change out test pump valves 09:30 11:00 1.50 SURPRI WHDBO BOPE T Change out Blind ram rubber seals Page 3 of 13 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 20:30 9.50 SURPRI WHDBO BOPE T During change out of seals, activator bent during clsing of the ram doors. Inform town and wait on parts from Deadhorse NOC. Parts and mechanic arrive with parts. 20:30 21:30 1.00 SURPRI WHDBO BOPE T Attempt to test blinds; fail. Troubleshoot equipment. 06/01/2013 Attempt to test Blinds and trouble -shoot leaks. Pull the FMC blanking plug observed ball seat dirty, and redress plug. Make up and reset blanking plug with crossover. Retest Blinds and choke manifold valves. No low test. Replaced #12 Choke manifold valve. Retest blinds and choke manifold valves to 250 / 4000 PSI - Good test. Pull balninking plug and crossover. Pull BPV. Well static. Rig up to pull tubing. Make up 3.467" grapple on a sirigle spear, no packoff. RIH to observe grapple would not pass through hanger, but would engage the hanger. Engage hanger. BOLDS, and pull to observe hanger free and 8' of pipe stretch, but would pull seals free. Repeat attempts. Max pull 150K. Continue work tubing. 00:00 07:30 7.50 SURPRI WHDBO BOPE P Continue trouble- shooting blinds, choke valves #12 and #13 leaks. 07:30 08:00 0.50 SURPRI WHDBO BOPE P Rig up on secondary kill line, pump down IA to check integrity of BPV and re -seat, good to 1000 psi. 08:00 12:00 4.00 SURPRI WHDBO BOPE P Continue trouble shoot leaks on blinds and valves, pull blank plug and re- dress. Continue trouble shoot change out #12 Valve. 12:00 15:30 3.50 SURPRI WHDBO BOPE P Blow down lines. Held PJSM, replace choke valve #12 15:30 16:30 1.00 SURPRI WHDBO BOPE P Pressure up on Blanking plug from IA leaking to 1000 psi. to re seat the ball. 16:30 18:00 1.50 SURPRI WHDBO BOPE P PT blind rams, kill HCR, kill lines, flare line, 18:00 19:30 1.50 SURPRI WHDBO BOPE P LD blanking plug and pull BPV. Observed crossover remained in the hanger. Lay down blanking plug. Make up joint of 3 1/2" 8rnd tbg, to RIH and recover crossover left in hanger. 19:30 20:30 1.00 SURPRI RPCOM RURD P RU GBR equipment power tongs etc.., change elevators, 20:30 21:00 0.50 SURPRI RPCOM FISH P MU BOT 3 1/8" spear with 3.467" Grapple, on one joint of drill pipe. 21:00 22:00 1.00 SURPRI RPCOM FISH P RIH & set down on spear take weight at 25.5', SO 20K down, no travel.release grapple 1 rt turn. Pull 10K to release. 22:00 23:00 1.00 SURPRI RPCOM FISH P POH with spear and dress galling on helical threads. Pull one BBL down tubing to IA 65 psi no obstruction. 23:00 00:00 1.00 SURPRI RPCOM FISH P Make dummy run without grapple to no -go at 35'. RIH with spear SO 10K at 25.5' no down travel. Release and OH with spear.Verify hanger and tubing free of debris. Page 4 of 13 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/02/2013 24 hr S umma ry Continue to work tubing with spear engaged in tubing hanger, pullled 30K to test grapple, and backed out lock -down screws. Max pull to 150K on weight indicator. Seals would not pull free with repeated attempts. Call for E -line to RU to cut tubing. Set the hanger ran in lock -down screws and released grapple. Laid down the spear assembly. Rigged up for E -line work and serviced rig. Due to the ID (1.85 ") of the Frac sleeved installed at 1891' discussion with town was engaged to decide the course of action. Cutter size and availablility was discussed and decided to bring a 1.75 ". HES rep. was very concerned with the success of the low clearance for the run. Also discussed was the option of running without centralizers. HES rep. stated there was no success with an un- centered assembly. Made runs with E -line to locate and fire for cleaning area from 7437' to 7432' with string shot, also a run with the tubing punch and fired a hole in the tubing at 7436.8'. 00:00 03:30 3.50 SURPRI RPCOM FISH P Continue work tubing string to free seal assembly pulling to max pull of 150K. Observed hanger movement free and 8' of strectch in tubing string. Seals would not come free. Notify E -line crew. Release spear grapple. POOH lay down same. 03:30 09:00 5.50 SURPRI RPCOM RURD P Make up 1 joint of 4 1/2" 8rd landing joint with 4 1/2" NU 8rd to the tubing hanger, for E -line rig up. MU crossovers to accomodate E -line. Service rig and prep rig for E -line work. 09:00 12:00 3.00 SURPRI RPCOM ELOG P PJSM, Rig up wireline for cutting operations. Hang sheaves and wireline. 12:00 13:30 1.50 SURPRI RPCOM ELOG P Assemble E -line tools and test. 13:30 15:30 2.00 SURPRI RPCOM ELOG P Ran in the 200' with CCL and string shot to pressure test. Pressure tested to 500 psi. Ran in hole and correlated depth for 1st full joint above sliding sleeve. Fired 5' string shot at 7437' to 7432'. 15:30 17:00 1.50 SURPRI RPCOM ELOG P Pull to surface and confirm shot fired. 17:00 18:00 1.00 SURPRI RPCOM ELOG P HES made up tools with Electro - Mechanial Anchor, Radial cutting torch and CCL. EMA failed on surface, tool shorted and would not actuate. Tool sent to shop. Called for another tool. 18:00 21:00 3.00 SURPRI RPCOM ELOG P Wait on tubing punch tools for eline. 21:00 21:30 0.50 SURPRI RPCOM ELOG P Rig up tubing punch. 21:30 22:30 1.00 SURPRI RPCOM ELOG P Run in the hole with CCL and tubing punch to 1891' unable to get past frac sleeve. 22:30 23:00 0.50 SURPRI RPCOM ELOG P Pull out and assemble tapered nose on assembly. 23:00 00:00 1.00 SURPRI RPCOM ELOG P Run in the hole with tubing punch, locate collar at 7436.8' Page 5 of 13 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/03/2013 24 hr Summary Continue E -line runs with successful tubing punch run and RCT cutter run. E -line had a surface failure of the Electro- Mechanical Anchor and had to employ centralizers in its place. A run was made with the RCT cutter and successfully fired on depth of 7433.5'. While pulling out of the hole PU weight increased 150 lbs. overpull at 1891' frac sleeve. After extra weight was realized it was suspected the frac sleeve was pulling to the surface. Pulled to the surface with assembly, the frac sleeve was on the RCT housing and centralizers. Laid down frac sleeve and E -line tools. Pulled back the E -line equipment and secured. Made up the landing joint to the tubing hanger, backed -out the lock -down bolts and pulled 125K and tubing freed. Pulled 90K tubing free PU weight. Circulated until 11.1 ppg in and out at 6 BPM with 685 psi, then monitored the well for 15 minutes - static. Rigged up handling equipment to pull 4" IPC 11 #; PU = 87K, SO = 68K. Laid down Hanger, 2 pup joints and 6 joints. Made up and landed test plug with 40K hanging on it to test the lower rams. Tested 250/4000 psi with 3.5" and 4" test joints. Rigged down test equipment and pulled 4" tubing. At midnight 105 joints, 2 pups, SSSV and GLM's. Control line was spooled and removed from floor, NORM'd good, 23 1/2 of 35 SS bands recovered. 00:00 01:00 1.00 SURPRI RPCOM ELOG P Locate & fire tubing punch at 7436.8' WLM. WLOH. 01:00 01:30 0.50 SURPRI RPCOM ELOG P Lay down tubing punch assembly. Make up 1.79" RCT cutter assembly. 01:30 04:00 2.50 SURPRI RPCOM ELOG P WILIH with RCT cutter and locate to cut 3 1/2" tubing at 7433.5' WLM.Observed weight loss of 150 lbs. 04:00 05:00 1.00 SURPRI RPCOM ELOG P WLOH with RCT cutter assembly, to the SSSV, and observed picking up the frac sleeve that was previously set. Observed drag increase through collar areas. Pull tools to surface and verify that we did have the frac sleeve. 05:00 05:15 0.25 SURPRI RPCOM SFTY P Held PJSM with crew. Discuss safety & hazard recognitiojn issues. Discuss laying down tools and equipment and rigging up to pull on tbg. 05:15 06:30 1.25 SURPRI RPCOM PULD P Lay down wire line tools, including RCT assembly, and frac sleeve. Breakout and lay down crossover from landing joint. 06:30 07:00 0.50 SURPRI RPCOM PULD P Rig down E -line equipment and line. 07:00 08:30 1.50 SURPRI RPCOM PULD P Make up landing joint to hanger, back out lock -down bolts and pull 125K to free string. Tubing free with 90K PU weight. 08:30 10:30 2.00 SURPRI RPCOM CIRC P Circulated and condition tubing and until 11.1 ppg in and out. Circulated at 6 BPM with 685 psi, then monitored the well for 15 minutes - static. 10:30 13:00 2.50 SURPRI RPCOM PULL P Change out handling equipment and pull 4" tubing and lay down same. PU = 87K, SO = 68K. Pull 2 pups and 6 joints. 13:00 15:30 2.50 SURPRI RPCOM BOPE P Make up test pllug to 4" tubing and land plug, PU test joint. Page 6 of 13 Time Logs • • 9 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 17:00 1.50 SURPRI RPCOM BOPE P Pressure test bottom rams to 250/4000 psi for 5 minutes with each 3.5" and 4" test joints. 17:00 18 :30 1.50 SURPRI RPCOM PULD P Lay down test joint, pull and lay down test plug, blow down lines and test pump. 18:30 00:00 5.50 SURPRI RPCOM PULL P Pull and lay down 105 joints 4', 2 pups, SSSV and control line, and 2 GLMs. Recovered 23 1/2 of 35 SS _ bands. 06/04/2013 Continue to pull 4" tubing. Cut and slip 164' and service rig with 138 joints laid down. Resume pulling 4" tubing to x/o and begin LD 3.5" tubing. Finish laying down 3.5" tubing and inspect tubing cut. 75 -80% appeared to have been cut with the remainder similar to tear failure. Pictures sent to engineer. Tubing strapped and equipment inventoried. 163 joints of 4 ", 74 joints of 3 1/2" laid out with 4 GLMs. Load and strap 3.5" drillpipe in the shed, Make up Baker fishing assembly with overshot, bumper sub, pump -out sub, and crossover per Baker Rep. Make up test joint and run in hole to function rams to attempt to clear stack and fish SS bands. 1 band recovered. Lay down test plug and install 6 1/2" ID wear ring. PU 3.5" drill pipe and run in the hole. At 2840', PU weight 65K, SO 65K. Continue to load and strap DP, then RIH. 00:00 02:00 2.00 SURPRI RPCOM PULL P Continue to pull 4" tubing and lay down. 02:00 03:00 1.00 SURPRI RIGMNT SVRG P Cut and slip drill line 164' while there was sufficient weight in the string to do it safely. 03:00 03:30 0.50 SURPRI RIGMNT SVRG P Service rig; top drive, reset crown -o- matic, and set block height. 03:30 05:00 1.50 SURPRI RPCOM PULL P Continue to pull 4" tubing and lay down. 05:00 10:30 5.50 SURPRI RPCOM PULL P Chnage out handling equipment and continue to lay down 3.5" tubing. 74 joint and 4 GLMs. 10:30 11:30 1.00 SURPRI RPCOM PULD P RD tubing handling equipment, clean and clear floor, work drill pipe in shed. 11:30 13:00 1.50 SURPRI RPCOM PULD P Strap LD tubing and equipment and strap DP in shed. 13:00 14:30 1.50 0 0 SURPRI RPCOM PULD P Strap DP and bring Baker tools to rigfloor. 14:30 16:00 1.50 0 0 SURPRI RPCOM PULD P Make up BOT overshot, bumper sub, pump out sub and xo per Baker Rep. 16:00 18:30 2.50 0 0 SURPRI RPCOM PULL P Observed SS band in the hole across the tubing spool; attempted to fish out, no good. MU test plug and set to function rams and annular. Recovered one SS band, LD test joint and plug. Ran in and set 6.5" ID wear ring with 2 LDS. Note: 26 1/2 of 35 SS bands recovered. 18:30 21:00 2.50 0 1,451 SURPRI RPCOM PULD P Ran in the hole with overshot assembly and picked up DP. 21:00 22:00 1.00 1,451 1,451 SURPRI RPCOM PULD P Load and strap pipe in shed. 22:00 23:30 1.50 1,451 2,840 SURPRI RPCOM PULD P Run in the hole with DP to 2840'; PU =65K, 50 =65K. 23:30 00:00 0.50 2,840 2,840 SURPRI RPCOM PULD P Load and strap DP in shed. Page 7 of 13 • Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/05/2013 24 hr Summary Load, strap DP and run in the hole with Baker overshot. Obtain parameters, swallow 5' of fish (TOF @ 7433'). Work pipe to 60k overpull, apply 1500 psi, came free. POOH 2 stands, obtain SPR's, circ surf-surf, monitor well, UD two singles. POOH w/ fish and UD same. Lay down 12.79' seal assembly, pup jt 6.14', cut jt 20.58'. Pressure tested packer, WRP and 7" casing to 2500 psi - good test. Changed out the top drive saver sub to HT38. Started making up Baker BHA #3; Jet Basket 6" OD assembly. 00:00 01:00 1.00 2,840 2,840 SURPRI RPCOM PULD P Load shed and strap pipe. 01:00 01:30 0.50 2,840 3,176 SURPRI RPCOM PULD P Run in hole with Baker overshot assembly f/ 2840' to 3176'. PU wt 65k, SO wt 65k. 01:30 02:30 1.00 3,176 3,176 SURPRI RPCOM PULD P Load shed and strap pipe. 02:30 03:30 1.00 3,176 4,279 SURPRI RPCOM PULD P Run in hole with Baker overshot assembly f/ 3176' to 4279'. PU wt 84k, SO wt 72k. 03:30 04:30 1.00 4,279 4,279 SURPRI RPCOM PULD P Load shed and strap pipe. 04:30 05:30 1.00 4,279 5,699 SURPRI RPCOM PULD P Run in hole with Baker overshot assembly f/ 4279' to 5699'. PU wt 107k, SO wt 80k. 05:30 06:30 1.00 5,699 5,699 SURPRI RPCOM PULD P Load shed and strap pipe 3 -1/2 ". 06:30 07:30 1.00 5,699 7,119 SURPRI RPCOM PULD P Run in hole with Baker overshot assembly f/ 5699' to 7119'. PU wt 127k, SO wt 90k. 07:30 08:00 0.50 7,119 7,119 SURPRI RPCOM PULD P Load shed and strap pipe 3 -1/2 ". Total of 340 joints. 08:00 09:00 1.00 7,119 7,403 SURPRI RPCOM PULD P Run in hole with Baker overshot assembly f/ 7119' to 7433'. PU wt 130k, SO wt 87k. 09:00 09:15 0.25 7,403 7,403 SURPRI RPCOM OTHR P Make a top drive connection w/ two single of drill pipe (jts 235 & 236). Obtain parameters @ 7403': PU wt 130k, SO 97k w/o pumps. With pumps 3 bpm w/ 435 psi: PU wt 132k, SO wt 97k. Rotating w/ pumps @ 3 bpm w/ 435 psi, rotating 40 rpm w/ 5k ft Ibs of torque. Rotating wt 112k. Pumping 35 spm (2 bpm) w/ 257 psi. 09:15 09:45 0.50 7,403 7,472 SURPRI FISH FISH P Slack off to locate top of fish @ 7433' w/ 5k wt. Engage rotary, rotate over top of fish, swallow 5' to 7438' (bottom of Seals @ 7472.5'), . Set down 7k to 190k on weight indicator. Pull 10k to 140k, set down 10k to 87k. Set down 20k. Pick up w/ 135k drag. Verify with pumps over fish: 15 spm w/ 350 psi, shut down pumps, set down 20k to 77k on weight indicator. 09:45 11:45 2.00 7,472 7,472 SURPRI FISH FISH P Work fish, working pipe w/ bumper sub (up & down). Noticed bumper sub movement w/ 135k on weight indicator. Working f/ 175k to 85k. Increased range to 185k PU wt (50k overpull). No movement. Page 8 of 13 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 12:00 0.25 7,472 7,443 SURPRI FISH FISH P Increased overpull to 195k (60K Overpull), applied 1000 psi while pulling a few times- no movement. Applied 1500 psi while pulling to 190k on weight indicator(55k overpull) - came free.Verified with pump pressure that seals were still in PBR. Pulled Seals out of PBR. After pulling two singles, pumped 35 spm w/ 257psi confirming seals were free of PBR. 12:00 13:00 1.00 7,443 7,443 SURPRI FISH CIRC P Obtain slow pump rates. both 1 and 2 pumps @ 2 bpm =190 psi, 3 bpm = 390 psi. Circulate surface to surface pumping 8 bpm (139 spm) w/ 2450 psi. Circulated 244 bbls. 13:00 13:15 0.25 7,443 7,443 SURPRI FISH OWFF P Monitor well- static. 13:15 14:00 0.75 7,443 7,443 SURPRI FISH PULD P Lay down two singles of 3 -1/2" HT 38 dp. UD crossover. PU wt 125k, SO wt 100k. 14:00 18:00 4.00 7,443 21 SURPRI FISH TRIP P Trip out of the hole f/ 7443' to BHA; 21'. 18:00 20:00 2.00 21 0 SURPRI FISH PULD P Lay down Bumper sub, Circ sub, X /O, and Overshot. Service break Overshot; LD fish; Seal assy. 12.79', Pup jt 6.14', cut jt 20.58' 20:00 22:00 2.00 SURPRI FISH PRTS P Pressure test 7" casing, packer, WRP to 2500 psi for 15 minutes - good test. 30 minutes total charted to attain stabilty on pressure. 2.3 BBLs 11.1 PPG bromide; Bled off pressure 2.7 BBLs retruned. 22:00 00:00 2.00 SURPRI FISH RURD P Change out top drive saver sub 3 1/2 IF to 3 1/2 HT38, grease and maintenance same, install missing safety wires on top drive, grease wash pipe. 00:00 00:30 0.50 SURPRI FISH PULD P MU BHA #3 as per Baker Rep. 06/06/2013 Finish making up BHA #3; run in the hole with HWDP and DP, circulating every 2000'. Tag top of Baker PBR @ 7455' while circulating w/ rev basket. PU 5', rotate and reciprocate from 7450' to 7390' while circulating bottoms up. Monitor- static, UD two joints to 7396'. Circulate to balance brine. Monitor well - static. Pull out of the hole and lay down BHA #3; Jet Basket, no recovery of SS bands. Rig up tubing running equipment and order GLMs in shed. 00:00 02:00 2.00 28 487 SURPRI FISH PULD P MU BHA #3 as per Baker Rep. and RIH with HWDP 02:00 06:00 4.00 487 7,396 SURPRI FISH PULD P RIH with DP to 1906' pumped 8 BPM with 1500 psi BEFORE ball drop. At 8 BPM BALL ON SEAT with 2300 psi, Torque with 30 RPM = 1.2K. RIH to 3800' pump 8 BPM with 2500 psi and Torque with 30 RPM =1.6K. RIH to 5700' pump 7 BPM with 2500 psi and Torque with 30 RPM =3K. RIH to 7396'. PU wt 127k, SO wt 100k , Rot wt 113k. Rotate 30 rpm w/ 4k ft lbs. Page 9 of 13 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 7,396 7,455 SURPRI FISH CIRC P Make a top drive connection. Wash down f/ 7396' to 7455', tag top of PBR while pumping 69 spm (167 gpm) w/ 1162 psi. After tag, PU 5', rotate 30 rpm w/ 4.5k ft lbs of torque. Pumping 170 spm w/ 2600 psi. Circ 4750 strokes while reciprocating f/ 7450' 7390'. Obtain slow pump rates. #1 34 spm w/ 320 psi, 51 spm w/ 630 psi. #2 34 spm w/ 310 psi, 51 spm w/ 640 psi. 07:00 08:00 1.00 7,455 6,685 SURPRI FISH CIRC P Lay down two joints of 3 -1/2" dp from 7455' to 7396'. PU weight 127k. Monitor well for 10 min- static. Trip to 6685 and fluids became out of balance and flowed back up the DP. 08:00 10:00 2.00 6,685 6,685 SURPRI FISH CIRC P Monitor well f/ 10 min- static. Circ to balance brine. 260 GPM with 2400 psi, 30 RPM with 3K torque. PU =127K, SO =100K, Rot =113K. 10:00 12:00 2.00 6,685 6,134 SURPRI FISH OWFF P LD drill pipe from 6685' to 6134'. Monitor well f/ 10 min- backflow from DP. Mix and pump 9 bbls, 12.3 ppg dry job. 12:00 19:00 7.00 6,134 1,244 SURPRI FISH PULL P Blow down top drive and LD drill pipe from 6134' to 1244'. PU =50K, SO =48K. 19:00 21:00 2.00 1,244 486 SURPRI FISH PULL P RIH with 5 stands out of the derrick and continue out of the hole from 1244' to 486'. 21:00 22:00 1.00 486 0 SURPRI FISH PULD P Pull to the BHA and check Jet basket for recovery; no bands were found in the basket. 22:00 23:00 1.00 0 0 SURPRI RPCOM RURD P Pull FMC wear ring and lay out. 23:00 00:00 1.00 0 0 SURPRI RPCOM RURD P Rig up tubing handling equipment. Line up tools for running order and double check tubing running order. Drift and strap pups, drift GLMs and Seal assembly 2.91 ". 06/07/2013 PJSM with Baker Rep., GBR, and rig crew for running tubing. Run completion following running order, to Jt # 238 in the hole and make up jt # 239, MU top drive and land seal assembly. Calculate space out and land tubing hanger. Locate Baker seals w/ Baker PBR @ 7473.17' w/ 12k set down. Make up FMC 4 -1/2" IBT landing joint. PU wt 80k, SO wt 67k. Rig up to circulate. Slack off pumping to locate seals in PBR. Pumping 1 BPM w/ 67 psi. Seals entered PBR @ 7461.78'. Pick up to 7460'. Land tubing w/ Baker GBH -22 80 -40 seal assembly WLEG bottom @ 7470.13' (3.04' f/ fully located). RILDS, torque to 450 ft lbs. FMC replaced one lockdown screw. UD landing joint. Rig up to test 3 1/2" tubing, test w/ blind rams. Pressure test 7" x 3 -1/2" tubing (IA) to 2580 psi for 30 Q minutes- good test. Blow down Iines. Rig down testing equipment. Prep and install BPV per FMC. Change upper rams to 7" and Nipple down BOPE. 00:00 00:30 0.50 0 0 SURPRI RPCOM SFTY P PJSM for running tubing with rig crew, Baker Rep., and GBR crew. Discussed safety while running, running order and and tally flags. Page 10 of 13 Time Logs • • 9 Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:30 05:00 4.50 0 4,511 SURPRI RPCOM RCST P Made up Baker GBH -22 80-40 Seal assembly and inspected by Baker Rep., ran in the hole picking up tubing and GLMs according to tally. 05:00 10:00 5.00 4,511 7,446 SURPRI RPCOM RCST P Continue to PU /MU /RIH w/ 3 -1/2" 9.3 ppf L -80 EUE -m tubing, following running order, f/ 4511' to 7446' (Jt # 238 in the hole). Make up jt # 239, MU top drive. 10:00 10:30 0.50 7,446 7,460 SURPRI RPCOM RCST P Locate Baker seals w/ Baker PBR (estimated to be found @ 7460.12'). Pumping 1 bpm w/ 70 psi. Seals started into PBR @ 7461.78'., observed prerssure increase. Stop pumps. Open bleeder line, slack off to locate @ 7473.17' w/ 12k set down. Pick up to 2' above PBR. 10:30 13:00 2.50 7,460 7,443 SURPRI RPCOM HOSO P Calculate space out, then lay down jts # 239, 238, 237, 236, 235 and 234 (Total of 6 jts). Replace jt # 234 and # 235 with two joints shorter f/ outside. Re -run jt # 236, replace jt # 237 w/ jt # 248, then rerun jt # 238 (Total of 5 jts).Replaced seals in all jts that were rerun. Total of 238 joints in the hole. 13:00 15:00 2.00 7,443 7,460 SURPRI RPCOM HOSO P Make up FMC gen IV hanger (AS82- 744 - 294 -A) w/ a 4" DSS -HT pin pup x 4" Non upset 8 rd pin, and a crossover f/ 4" non upset to 3 -1/2" EUE (Baker locked). Make up FMC 4 -1/2" IBT landing joint. PU wt 80k, SO wt 67k. Rig up to circulate. Slack off pumping to locate seals in PBR. Pumping 1 bpm w/ 67 psi. Seals entered PBR @ 7461.78'. Shut down pumping. Pick up to 7460'. 15:00 15:30 0.50 7,460 7,460 SURPRI RPCOM CIRC P Pump 25 bls of corrosion inhibited 11.1 ppg sodium bromide, followed by 67 bbls of uninhibited 11.1 pb sodium bromied. Pumping 242 gpm w/ 650 psi. Leaving 3 bbls of inhibited brine in the tubing. Shut down pumps, open bleeder. 15:30 17:00 1.50 7,460 7,460 SURPRI RPCOM RCST P Land tubing w/ Baker GBH -22 80-40 seal assembly WLEG bottom @ 7470.13' (3.04' f/ fully located). RILDS, torque to 450 ft lbs. FMC relaced one lockdown screw. UD 4 -1/2" IBT landing joint. Page 11 of 13 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:30 3.50 7,460 7,460 SURPRI RPCOM DHEQ P Rig up to test 3 -1/2" tubing, fill lines, bleed air. Test w/ blind rams. Pressure test the 3 -1/2" tubing to 250 psi f/ 5 minutes, then increase pressure to 3020 psi. Lost 90 psi in 30 minutes to 2930 psi- good test. IA was open to atmoshere. Bleed off tubing to 1500 psi. Pressure test 7" x 3 -1/2" tubing (IA) to 2580 psi f/ 30 minutes. Lost 40 psi in 30 minutes to 2540 psi. Chart test - good test. Blow down lines. Rig down testing equipment. 20:30 22:00 1.50 7,460 7,460 SURPRI RPCOM RURD P Blow down, RD test lines, pump out stack, blow down choke, manifold, choke and kill lines. 22:00 22:30 0.50 0 0 SURPRI WHDBO RURD P Prep and install BPV per FMC. 22:30 23:30 1.00 0 0 SURPRI WHDBO RURD P Change upper rams to 7 ". 23:30 00:00 0.50 SURPRI WHDBO RURD P Nipple down BOPE. 06/08/2013 Continue to ND BOPE. Nippled up tree with orientation confirmed by the Lead Drillsite Operator. FMC tested tree adapter seal and seals to 250/5000 psi good. Continue wellhead work, attempt to pull BPV with dry rod. Noticed pressure evidence and rigged up lubricator to pull BPV. Test Lubricator to 1500 psi and pull BPV. RU bleed tank and bleed tubing to 0 psi, then shut -in and monitor for 15 minutes. 5 psi was accumulated in that time, bled off pressure and installed tree test plug. Tested tree; 250/5000 psi for 10 minutes each -good test. Pulled tree test plug with lubricator, RD. RU to pump down IA, shear SOV at 2000 psi while circulating 10 BBLs of 11.1 brine at 2 BPM; 1475 psi. Rig up Little Red and pressure test lines to 2500 psi. Pump with LRHOS at 2 BPM; 2100 psi. 262 BBLs pump down IA and 262 BBLs returned to pits. RD LRHOS, MU lubricator, PT to 1000 psi and install 4" BPV`. Rig down all equipment from tree and put on gauges; IA =0 psi, OA =240 psi, Tubing =0 psi. Prep rig for move. Rig Released at 23:59 6/8/2013 00:00 01:30 1.50 0 0 SURPRI WHDBO NUND P Continue to nipple down BOPE. 01:30 03:30 2.00 SURPRI WHDBO NUND P Nipple up CIW 4 -18" FLS tree with orientation confirmed by Lead Drillsite Operator, Mike Alston at 02:30. 03:30 04:30 1.00 SURPRI WHDBO THGR P Test FMC tree adapter to 250/5000 for 10 minutes good test by Eddie Kirby 04:00. 04:30 08:30 4.00 SURPRI WHDBO NUND P Continue well head work, attempting to pull BPV with T -bar. Noted slight pressure under BPV. Rigged up lubricator. 08:30 11:30 3.00 SURPRI WHDBO MPSP P Bleed tubing to bleed tank, bleed to 0 psi. Shut in and monitor for 15 minuteswith 5 psi built in 15 minutes. Bled off to 0 and install tree test plug. 11:30 13:00 1.50 SURPRI WHDBO MPSP P Test tree to 250/5000 psi for 10 minutes each test. 13:00 14:30 1.50 SURPRI WHDBO MPSP P RU lines and lubricator, pull test plug as per FMC rep. RD lubricator. Page 12 of 13 . • Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:30 15:00 0.50 SURPRI WHDBO CIRC P Line up rig to pump and shear SOV. Pump down IA, shear SOV at 2000 psi while circulating 10 BBLs of 11.1 brine at 2 BPM; 1475 psi. Blow down lines. 15:00 18:00 3.00 SURPRI RPCOM FRZP P Rig up Little Red and pressure test lines to 2500 psi. Pump with LRHOS at 2 BPM; 2100 psi. 262 BBLs pumped down IA and 262 BBLs returned to pits. 18:00 21:00 3.00 SURPRI MOVE DMOB P Rig down Little Red, Make up lubricator, Pressure test to 1000 psi; IA =0 psi, OA =200 psi, Tubing =0 psi, install BPV. Rig down lubricator 21:00 22:00 1.00 DEMOB MOVE DMOB P Remove auxillery valves and replace Otis adapter flange, install new gauges on tree. IA =0, OA =240 psi @ 23:00 hours. 22:00 00:00 2.00 DEMOB MOVE DMOB P Prep rig floor for move, prep pit module for move. Rig down plumbing on the rig; standpipe, cement lines, rig down tongs. Release rig at 23:59 hours. Page 13 of 13 r6 -2.2_1 • 2l °\ z WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED JUN 19 2013 RE: Plug Setting Record: 2W -12 Run Date: 9/30/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2W -12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21240 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: \O ' (p V . Signed: / L 3ei4 WELL LOG TRANSMITTAL I PROACTIVE DiAgnosric SERVICES, INC. To: AOGCC Christine Shartzer 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 SCANNED JUN 1 9 2.013 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTf) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Shay Phillips LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak PointTm Survey 16- Aug -12 2/412 1 CD 50-029 - 21240 -00 IA.) 2) Signed : ..$. 1 „ / _._ , / r Date : 1,0 �- 1 ').- Print Name: LA V--\-- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E -MAIL : PDSANCHORAGE(57MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets \Cook Inlet Transmit.dOCX -22 i • WELL LOG _ S TRANSMITTAL PROACTIVE DiAgNOSTic SERVicES, Inc. To: AOGCC Christine Shartzer S 333 West 7th Avenue SCANNED JUN 19 2D13 Suite 100 Anchorage, Alaska 99501 [907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Point Survey 15- Sep-12 2W -12 1 CD 50 -029- 21240 -00 2) Signed : j 4 � Date : Z- d2„— Print Name: V PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E -MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\Di�ibution \Transmittal Sheets \ConocoPhillips_Transmit.docx Z • • 2\% WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 30, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED JUN 1 9 2013 RE: Multifinger Imaging Tool (MIT) : 2W -12 Run Date: 7/26/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2W -12 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21240 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907- 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 1 / 2 -7/1Z-. Signed: 6,4,4 • \` `f,- 224 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 1, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED JUN 19 Z013 RE: Production Profile: 2W -12 Run Date: 4/17/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2W -12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 21240 -00 Production Profile Log 1 Color Log 50- 029 - 21240 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: q\-7/19-- Signed: _� Regg, James B (DOA) • Page 1 of 1 P 1 54 _ ZzA- From: NSK Problem Well Supv [nl617 @conocophillips.com] Sent: Sunday, December 19, 2010 9:30 AM Z� Zti�� ► u To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2W -12 (PTD 184 -224) Report of suspected TAA comm Attachments: 2W -12 schematic.pdf Tom, Jim, Guy Kuparuk gas lifted producer 2W -12 (PTD 184 -224) is suspected of having TAA communication due to recent well pressure trends. A leakin GLV is susp ected. Slickline will troubTe if possible. Attached is a schematic and 90 day TIO plot. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 7 2 0 111 I I 12/20/2010 i KRU 2W -12 PTD 184 -224 12/19/2010 TIO Pressures Plot TRNANNL ANNULUS PRESSURE TRENDS 00 . WELL NAME WLKRU2W -12 3000. 3000 200- 3000. 3000. 27001 3000.- "On., 2400 3000. • 2100 � _ - _ _ _ _ A A 1800 ------- 1500 - - - - --- 1200 _ __ '/ r� 900 I 1 0, 600 - - - -- - -- -- - - -- �, - -- - - -- -- _ ._ ----------- - 0. i 300 - .- ° ° -_ °- -- - - - -_ - - °..... r 0. 0. 0 ----------- - ---- --- - - -- -- -- - - -- --- - ---- --------------- ---------- ------ ---------------------------------------- -- --- -- -- - --- - ------------------------- - - 0 0. PLOT START TIME MINOR TIME N P1.o Fm) T'1ME 20- SEP -10 09:26 MAJOR TIME WEEK +02160:00:00 HRSI9- DEC- 10 -09 :26 PICK TIRE F— rr1 -1.-, M Sc TAG RARE DESCRIPTION P -VALUE LATEST WL2W -12 -CHOKE FLOW TUBING CHOKE 17 ? ? PREY WELL DRILLSITE WELL SCRATCH 58 FLOW TUBING PRESSURE 7?????? 2w 12 SCRATCH FLOW TUBING TEMP ? ? ? ? ? ?? W i NEXT WELL pw AI- P2W5002 -12 GL CASING PRESSURE ? ? ? ? ? ?? pm ? ? ? ? ? ?? ENTRY TYPE OPERATOR pm ? ? ? ? ? ?? OPERATOR VERIFIED pw SCRATCH INNER ANNULUS PRES 7 ?7727 SYSTEM AUTO ENTRY PR SCRATCH OUTER ANNULUS PRES ? ? ? ? ? ?? BOTH KUP 2W-12 C+�ra►ca�Fril[�p w�ittr.p>�te Af85kt, I nc. IWellbore API /UWI Fleld Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) 500292124000 KUPARUK RIVER UNIT PRODUCING 47.68 2,500.00 8,092.0 Comment 1-12S (pp-) Date lAnnotation End Date KB -Grd (ft) Rig Release Date wen 12 tr2a495o3;a�1> SSSV: TRDP 320 1/1312009 Last WO: 10/29/1992 34.19 12/31/1984 Schematic - Actual , . „Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: RKB 7,899.0 4/30/2009 Rev Reason: TAG triplwj 5/1/2009 String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (in) (in) Top (ftKB) (ftKB) (ftKB) (Ibslk) Grade String Top Thrd CONDUCTOR, I CONDUCTOR 16 15.062 34.2 110.0 110.0 62.58 H40 110 A SURFACE 95/8 8.765 0.0 2,720.0 2,426.4 36.00 J -55 SAFETY VLV, PRODUCTION 7 6.151 0.0 8,065.0 6,291.8 26.00 J -55 1,891 TUb'n $trite 4 - - SURFACE, String OD String ID Set Depth Set Depth (TVD) String Wt String 2'720 Tubing Description (in) (in) Top (ftKB) (ftKB) (ftKB) (Ibs /k) Grade String Top Thrd GAS uFr, TUBING 4 3.423 0.0 5,022.0 4,037.9 11.00 J -55 DSS -HTC 2.1939 TUBING 31/2 2.992 5,022.0 7,480.0 5,816.4 9.30 J -55 ABM -EUE TUBING 31/2 2.992 7,480.0 7,686.0 5,978.9 9.30 L -80 ABM -EUE GAS LIFT, TUBING 31/2 2.992 7,686.0 7,705.0 5,995.1 9.30 J -55 ABM -EUE 4,152 lther r Hta Ati newel :f TUblr "ii i 0"1 �trhwab 0, ` FN l , Top Depth GAS LIFT, - - (TVD) Top Incl 4'713 Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 1,891 1,825.4 33.86 SAFETY VLV AVA'ACGA' 10/29/1992 3.312 2,939 2,576.3 46.53 GAS LIFT CAMCO /KBMG -7/1 /GLV /BK/.156 /1270 /Comment: 4/27/2005 3.351 GAS LIFT, 4 ,152 3,432.1 44.87 GAS LIFT CAMCO /KBMG -7/1 1DMY /BK/ // Comment: 4/26/2004 3.351 5,277 4,713 3,824.1 46.30 GAS LIFT CAMCOIKBMG -7/1 /GLV /BKI.188 /1313 /Comment: 4/27/2004 3.351 5,277 4,216.0 45.29 GAS LIFT CAMCO /MMG -2/1.5 /DMY /RK/ // Comment: 4/25/2004 2.920 GAS LIFT, 5 ,821 4,600.3 45.02 GAS LIFT CAMCO /MMG - 2/1.5 /GLV /RK/.25 /1275 /Comment: 4/25/2004 2.920 5,821 6,372 4,993.6 43.83 GAS LIFT CAMCO /MMG- 2/1.5/OV/RK/.25/ /Comment: 4/25/2004 2.920 GAS LIFT, 6 ,924 5,396.4 42.28 GAS LIFT CAMCO /MMG -2/1.5 /DMY /RKI // Comment: 4/25/2004 2.920 6,372 F77,518 5,756.2 39.36 GAS LIFT CAMCO /MMG -2/1.5 /DMY /RK/ // Comment: 4/25/2004 2.920 5,800.9 38.95 SBR Baker 10' stroke 10/29/1992 3.000 GAS LIFT, - 5,811.8 38.85 PACKER Baker'HB' 10/29/1992 2.890 6,924 5,846.1 38.54 PRODUCTION CAMCO /MMG /1.5 /DMY /RK1 // Comment: W /EXTENDED 9/8/2005 2.920 PKG GAS LIFT, 7,402 - 7,664 5,961.3 36.91 SLEEVE Camco'CB -1' Sliding Sleeve (Modified); Shift OPEN 9/15/97 9/15/1997 2.812 7,678 5,972.5 36.73 PACKER Baker'FB -1' 10/29/1992 4.000 SBR, 7,460 7,694 5,985.3 36.53 NIPPLE Camco'D' Nipple NO GO 10/29/1992 2.750 7,704 5,994.3 36.73 SOS Baker 10/29/1992 2.992 7,705 5,995.1 36.71 PACKER, 7,474 TTL 10/29/1992 2.992 7,900 6,153.8 33.55 FISH 1" DMY LOST IN RATHOLE 4/26/2004 4/26/2004 7,908 6,160.4 33.51 FISH 1 1/2" DMY Lost in rathole 6/12/1997 6/12/1997 ,�- PRODUCTION, Shot 7'518 _ Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ft KB) (ftKB) Zone Date (sh••• Type Comment RPERF, 7,570 7,573 5,886.9 5,889.2 C-4, 2W -12 10/27/1992 5.0 RPERF 4.5" SWS HJ 11; 60 deg. ph 7,570 -7,573 7 ,573 7,600 5,889.2 5,910.5 C4, C -3, 2W -12 10/27/1992 0.0 SQEE... SQUEEZED OFF SOEEZE, 7,573asoo 7,758 7,760 6,037.2 6,038.8 A-4, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ II; 120 deg. phasing 7,760 7,800 6,038.8 6,071.2 A-4, A -3, 2W -12 10/27/1992 8.0 RPERF 4.5" SWS HJ II; 180 deg. pH SLEEVE, 7,664 7,800 7,808 6,071.2 6,077.5 A -3, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ 11; 120 deg. phasing 7,827 7,831 6,093.2 6,096.5 A -2, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ II; 120 deg. phasing Cement 7,840 7,848 6,103.9 6,110.6 A -2, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ 11; 120 deg. phasing squeeze, 7,573 7,872 7,877 6,130.5 6,134.6 A -2, 2W -12 1/31/1985 4.0 IPERF 4" DA JJ 11; 120 deg. phasing PACKER, 7,678 Top Depth Bt m Depth (TVD) (TVD) Top (ftKB) Sim (ftKB) (ftKB) (ftKB) Description Start Date Comment _y 7,573.0 7,673.0 5,889.2 5,968.5 Cement Squeeze 10/29/1992 Squeezed Cement NIPPLE, 7,694 SOS, 7,704 TTL, 7,705 - IPERF, 7,758 -7,760 RPERF, 7,760 -7,800 IPERF, 7,800.7,808 - IPERF, 7,827 -7,831 IPERF, 7,840 -7,848 IPERF, 7,872 -7,877 FISH, 7,900 FISH, 7,908 PRODUCTION, 8,065 TD, 8,092 05/12/09 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 9 o ,~_ ~ ~- SAY ~ ~ 2069 ~i~s~~ ~56f ~ ~~s ~~n~,. ~nr~migsi~€~ ~rvch~r~~~ NO. 5228 ~ ~ ~ r_~©~-- Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 3A-18 AYS4-00069 PERF/SBHP SURVEY - l °" 04/26/09 1 1 3C-08 6148-00033 GLS ~ ( 04/21/09 1 1 2M-25 B14B-00034 GR/TEMP LOG 19 (- 04/22/09 1 1 1R-19A AYS4-00065 SBHP SURVEY -r 'L ~~ 3~, ~ 04/23/09 1 1 3G-13 AYS4-00067 SBHP SURVEY - ` 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 B14B-00038 SBHP SURVEY _ ~ 04/24/09 1 1 3F-08 6146-00037 SBHP SURVEY _ 04/24/09 1 1 3M-25A 6146-00040 SBHP SURVEY 04/25/09 1 1 3K-08 B14B-00039 SBHP SURVEY C/ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -Q 04/27/09 1 1 2Z-07 8148-00045 SBHP SURVEY L 04/29/09 1 1 2Z-01A 6146-00044 SBHP SURVEY ~-_ ~ 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 2W-12 3C-02 604C-00036 B04C-00037 B04C-00045 PRODUCTION PROFILE PRODUCTION PROFILE ~~ POWERCUTTER W/SBH SU VEY 05/02/09 05/03/09 05/09/09 1 1 1 1 1 1 1J-120 B04C-00043 GLS ~ Q ® 05/08/09 1 1 31-11 B04C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above addressor fax to (907) 561-8317. Thank you. C~ ~~~ • • Page 1 of 1 Re99, James B (DOA) ~ ~ti ~wP--I j (~' ~ lam -z~W From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, April 08, 2009 8:35 AM J~' l g L~ ~g~~,~~ To: Regg, James B (DOA) l Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 DS Lead Techs NSK; CPF2 Prod Engrs Subject: FW: KRU 2W-12, 2W-13 high OA pressures Attachments: 2W-12 TIO Plot.pdf; 2W-13 TIO Plot.pdf Jim, CPF2 experienced aslant upset on 3/29/09 at 14:35 due to a PW Tank HiHiHi Level that shutdown all of the water injection pumps and subsequently all production including DS2W. There was also a second infection pump event the next day . When the wells were brought back online their performance was at an elevated temperature as illustrated in the attached TI nlnts. Due to inclement weather, the Drillsite Operator was not able to perform well walks until the day of the inspection (4/1/09) when the IA pressures above 1000 psi were discovered. Both wells were bled down and appear to have stabilized below their pre-bleed pressures. Attached are 90 day TIO plots and wellbore schematics. „~_ Please contact me at your convenience if you have questions or comments. ., Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~p .. ~ ~ 1?; h "~ r° .' From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, April 06, 2009 10:31 AM To: NSK Problem Well Supv ',~~ Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) h{j ~ ~ ~ I Subject: KRU 2W-12, 2W-13 high OA pressures ~~ Inspector found both wells with OA pressures >1000psi while performing SVS tests; no waiver posted for wells. Inspection report attached. Please check into this and reply with findings. Also provide TIO plots for both wells. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 4/8/2009 Name 2W-12 Notes: Date 4/15/2009 120 :Date 12/16/2008 Annular Communicaton Surveillance 1600 1400 1200 1000 .Q 800 600 400 200 0 Jan-09 ~ooo soon 5000 D a m 4000 LL 3000 v 2000 i o00 0 Jan-09 I ~~1- zz4 130 127 124 121 LL 118y a 115 112 109 106 r L_J Feb-09 Mar-09 Apr-09 Feb-09 Mar-09 Apr-09 Date ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 €~ LL'<. R, ~!" March 5, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 G~~~~~~~~~' MAC ~ ~ 20~ Dear Mr. Maunder: t~ ~~.~ ~~ ~, ~ ~ m~,, y~1 ~~ ~~ l~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23~d , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i~ ~~~~ C M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/5/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'5" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1 /18/2009 12.3 2/21 /2009 2W-04 185-012 55' 8.10 5'4" 1 /18/2009 15.1 2/21 /2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21 " 1 /24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18!2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1!18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 Ç) 11/10/06 Sc~lInbøpglP NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 r'~' A Tl~ lieth ¡ ,,~ : ¡ ;:jtilj\~'\iNt;;.U no l L 6 NO\! :1 3 2006 !~I~~ ()II &. (~as Qms. eommissiOO A\1~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /~Lj - dd4 Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R·26 11416225 INJECTION PROFILE 10/23/06 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K,28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G..16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 2F1-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE WIDEFT 10/27106 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28106 1 1 0-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N..305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 21.:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2Kp27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ) ') FRANK H. MURKOWSKI, GOVERNOR AI~ASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276·7542 November 9, 2005 .\v').rLf \ 'ð '-f d-. vJ... I :J- Mr. Paul Dubuisson Kuparuk Field Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Dubuisson: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2W ("KRU 2W") pad on October 2, 2005. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 in conjunction with Conservation Order 348 requires all wells in the Kuparuk River field to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting ofT flow at the wellhead and shutting down any artifìciallift 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 15 percent was identified during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a fàilure rate exceeds 10 percent. EfJective October 2, 2005 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2W must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector (907-659-2714) at least 24 hours in advance to provide an opportunity to witness the SVS test. Sincerely, ,..-¡-' '~ ,--; ~'~l1é\1 b.· 1\ Cì(c(" ' James B. Regg Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors ~c;ANNED NOV 1 '7 2005 Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv Comm Pad; KRU__2W Insp Dt ]0/2/2005 Inspected by John Crisp Interval 90 Days InspNo sysJCr051004204247 Field Name KUPARUK RlVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Related Insp: Reason 180-Day Src: Inspector r-- ----,i/~/I D;l~--o-- ì- - -- OOp¡j~ïs------n-oloSSV-1 SiS1/ I Shut/II Dtr "Ietl Type T- 'Veil Pressures 01 G~s L/fiTira/t'er I~___o_________ Well Permit Seµar Set LIP Test Test Test Date S1 Oil,WAG,GlNJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS,CYCLE, SI PSI PSI PSI Yes/No Yes/No ~~-~~~~+-~-~-- ~l :~*ii~-~ - -:~- -~~ -- ~:- ~- ~~=-:---~fn--------[-_-=-~_H-=~---=---;~~~f~ ~--~__Ii~o~_~~~)~~-~~ J3-0 - =_~Oy ei_=-=_~~;_~!~~~A ~_ -~~~_ _=_= o-~ -- -- - -2W=05 1841910 2650 2000 2000-P---P- -0- --- ----WAGJN------- --- ------1-------------~------------- ------ -------- - o _____0___ __ 0_ no_ _________ .. 0_______ ________ _____o____~__n___H_____O____________O___I---O----------____u __ _0___________________ ___o__n_o__ _ _un 2W-06 1841940 95 70 65 P P I-OIL 1250 1000 I 230 Yes Yes lA x OA I 2W-07 1842040 95 70 55 IO P I-OIL 300 580 j 250 No Yes 1AxOA ---------,-- - ----------- ---- -~ --- _._~-- --.--.------.--- - - ------------ --- ---~----- ------------- ---------- ---- ---- ~-----------~-- 2W-II 1~42220 95 70 65 P P I-OIL --------- -- --- - ------ -- - - ---.-~-------- --------~----~-----------~-------- --~-------------------- -------"---- 2W-12 1842240 95 70 50 P P I-OIL ------- ------ -- -~--- - -~ ------ -----,--------- ,------ ------ ---- ---- - --------- --~--- --- ----- --- --- --- --- ---- 2W-13 1~42360 95 70 50 P P I-OIL ----- -------- ---- ----- -------- ------------- -------~----- ---- -~--~-------------- ------~-- --- ~---- -~~--~--- -- ~- i;~:; __ _ :- :~~~l~ - 2:~0_-2~~:_-~=l~__=_-~~=__-~-;=~_ o-~j~_=__=-~==--- ~ ~~N--=_-L400_~~ ~~o 750=-~ I 8~=_=_Uy~~=~=__yes -=~A x ~~~~~~~~~___-~=~-j - ---- --- ---- ~ - ------- ---- -"- ---- -- - Comments Performance -- --~-- - -----~-- -- -------- --- ------- ------------- Wells Components Failures Failure Rate _lit __ ____..2Q_____--..-l_________..uo'Y~____ - --------------- -- -~---------,-- --------------- ---- -------- _00 íF 0 !i?<. l' l, lõ u Wednesday, Ocwb(;f 05,2005 Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # I 81.- ").. {( 1 F-02 /95 "0 '11_ 2T -23 :;¡- 2W-12 I~'f.. 2.Zlf 2Z-19 If~-r!;f) 1C-111 ~/"'12.. <6 1C-117 )...e{- /2. r 3F-14 I 'ð 5· ;2..72 2K-07 Q 2Z-12A I 0 7-- 07 { f 15- /cf<l 10922513 10952507 10942806 10922502 10922504 10922505 10922499 10922503 10922501 Log Description Date \ L6 \.{- ~ IVY' 12/23/04 INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG 12/14104 12/08/04 12/15/04 12104/04 12/06/04 12106104 12/03/04 12/05/04 12/04/04 NO. 3292 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ BL Color CD 1 1 1 1 1 1 1 1 1 '_/ Please sign and return on copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate __ Plugging __ Perforate Alter casing Repair well Other X I 6. Datum elevation (DF or KB) 1. Operations performed: Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address 5. Type of Well: Development Exploratory Stratigraphic Service P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 412' FNL, 235' FEL, SEC 33, T12N, RgE, UM At top of productive interval RECEIVED 1529' FNL, 1233' FEL, SEC 28, T12N, RgE, UM At effective depth 1298' FNL, 1306' FEL, SEC 28, T12N, R9E, UMDEC At total depth 1240' FNL, 1323' FEL, SEC 28, T12N, RgE, UIV~lask~ UII & Gas Gens. Commissi0r 12. Present well condition summary Anchorage X RKB 95', PAD 65' 7. Unit or Property name Kuparuk River Unit 8. Well number 2W-12 9. Permit number/approval number 84-224 10. APl number 50-029-21240 11. Field/Pool Kuparuk River Oil Pool Total Depth: measured 8092' feet Plugs (measured) true vertical 631 3' feet Effective depth: measured 7982' feet true vertical 6221' feet Junk (measured) 7964' Tagged 10/27/92 Casing Length Size Cemented Measured depth True vertical depth Structural 9 0' 1 6" 337 SX CS I 90' 90' ' Conductor Surface 2690' 9-5/8" 610 SX AS III 2720' 2426' Intermediate & 500 SX CLASS G- Production 8 0 3 5' 7" 925 SX CLASS G 8 0 6 5' 6 2 9 0' & 250 SX AS I Liner Perforation depth' measured 7570'-7600'(reperfed C Sand-old C sand perfs-7573'-7643'- squeezed), 7760'-7800'(new perfs-A Sand), 7758'- -7808', 7827'-7831', 7840'-7848', 7872'°7877' MD. true vertical 5885'-5909', 6037'-6070', 6036'-6077', 6092'-6095', 6103'-6109', 6129'-6133' TVD Tubing (size, grade, and measured depth) 4" 11# J-55 @ 5022' & 3-1/2" 9.3# J-55/L-80 @ 7705' Packers and SSSV (type and measured depth) BAKER HB RETR PKR @ 7474',BAKER FB-1 PERM PKR @ 7674' (E-line meas), AVA 4" ACGA SSSV @ 1891' MD 13. Stimulation or cement squeeze summary Treated Cl Sand with MARCIT gel while simultaneously Intervals treated (measured) pumping diesel into C34 Sands. Treatment description including volumes used and final pressure: Pumped 456 bbls of diesel and 987 bbls of MARClT ~lel. Initial treating pressure was 1300 psi and final pressure was 2050 psi. 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 181 // 88 6144 1250 psi Subsequent to operation 115¢/ 56 365 1375 psi 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector Daily Report of Well Operation X Oil X Gas Suspended 17. I hereby ce.d. ify that the foregoing is true and correct to the best of my knowledge. Si,ned ~~~' ~ Title$~En~lineer I~tarm 1 ¢~.LtC~Lt ~,~t l~,~/1 260 psi 2000 psi Service Date ~1 II~h~lT lEI 1'31 I1::)1 I~ATI:: ARCO Alaska, Subsidiary of Atlantic Richfield Compar~y WELL SERVICE REPOR1 WELL IPBDT QONTRACTO~r.j~~~ REMARKS -FIELD- DISTRICT- STATE OPERATION AT REPORT TI~ :DATE I/-IZ-O3 g;:zo ,.. ,.. ,-,-. 11 I r-D KI-LrlVE d~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Temp' I Chill Fact°r J Visibilily Wind Vel. knots I Signed A orafle REMARKS CONTINUED: DESCRIPTION DAILY i ACCUM. TOTAL CAMCO OTIS I SCHLUMBERGER DRESSER-ATLAS I DOWELL hALLIBURtON aRGtiG COil TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown ~ Stimulate X Alter casing Repair well 5. Type of Well' Development ~ Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 412' FNL, 235' FEL, SEC 33, T12N, RgE, UM ORIGIN L· Plugging __ Perforate __ Other 6. Datum elevation (DF or KB) RKB 95'. PAD 65' 7. Unit or Property name Kuparuk River Unit 8. Well number 2W-12 interval I;[EEEIVED 9, Permit number/approval number Attop of productive 1529' FNL, 1233' FEL, SEC 28, T12N, RgE, UM 84-224 At effective depth 10. APl number 1298' FNL, 1306' FEL' SEC 28, T12N, R9E, UM DEC 1 61992 I 50-029-21240 At total depth £1~1. Field/Pool 1240' FNL, 1323' FEL, SEC 28, T12N, RgE, UM~,laska 0ii & Gas Cons. L;or~il~listt°l'Kuparuk River Oil Pool 8092' feet 631 3' feet 12. Present well condition summary Total Depth: measured true vertical Anchorage Plugs (measured) Junk (measUred) 7964' Tagged 10/27/92 Effective depth: measured 7982' feet true vertical 6221' feet Casing Length Size Cemented Measured depth True vertical depth Structural 9 0' 1 6" 337 SX CS I 90' 90' ' Conductor Surface 2690' 9-5/8" 610 SX AS III 2720' 2426' Intermediate & 500 SX CLASS G- Production 8035' 7" 925 SX CLASS G 8065' 6290' & 250 SX AS I Liner 13. Perforation depth: measured 7570'-7600'(reperfed C Sand-old C sand perfs-7573'-7643'- squeezed), 7760'-7800'(new perfs-A Sand), 7758'- -7808', 7827'-7831', 7840'-7848', 7872'-7877' MD. true vertical 5885'-5909', 6037'-6070', 6036'-6077', 6092'-6095', 6103'-6109', 6129'-6133' TVD Tubing (size, grade, and measured depth) 4" 11# J-55 @ 5022' & 3-1/2" 9.3# J-55/L-80 @ 7705' Packers and SSSV (type and measured depth) BAKER HB RETR PKR @ 7474',BAKER FB-1 PERM PKR @ 7674' (E-line meas), AVA 4" ACGA SSSV @ 1891' MD Sand with crosslinked gelled water and LDC proppant. Stimulation or cement squeeze summary Hydraulically fractured the A Intervals treated (measured) Treatment description including volumes used and final pressure: Pumped 12 Mlbs 16/20 Mesh LDC, 96 Mlbs 12/18 Mesh LDC, 66 Mlbs 10/14 Mesh LDC and 1355 bbl gelled water. Final pressure = 4430 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 181 psi 209 psi Service Prior to well operation 765 381 13 1400 psi Subsequent to operation 3565 // 3297 984 900 psi 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector Daily Report of Well Operation X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C: ~/~. ~ Title Engineer Date ~2./~ RI I~/IIT lEI I'ti IDI ARCO Alaska, A Subsidiary of Atlantic Richfield ComDany WELL SERVICE REPOF , J DATE IPSDT I FIELD- DISTRICT-STATE DAYS WELL ~1~/ *' {2- I '/~ I KIP. L[ [ cONTRACTOR ' IOPERATION AT REPORT TIME REMARKS A~ NON ~:L. C~Ud '2.5 eP~ '~,5 6et.. ,~q~ Ps; 155'5 PLu, SH SLY., DIESP..,L. ?-.5 eP~ 2~rb6a '{ffSOP>i E. HD C4:: !1. FPA ~ P~Tmd: I'B: t"tO~s 'TOTA. L. e:~U: 135~ 105' r--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather [Temp. I Chili Factor Visibility Wind Vel. i Signedc,~¢~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing x Alter casing Stimulate __ Plugging __ Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 412' FNL, 235' FEL, SEC 33, T12N, R9E, UM At top of productive interval 1529' FNL, 1233' FEL, SEC 28, T12N, R9E, UM At effective depth 1298' FNL, 1306' FEL, SEC 28, T12N, R9E, UM At total depth 1240' FNL, 1323' FEL, SEC 28, T12N, R9E, UM 12. Present well condition summary 6. Datum elevation (DF or KB) RKB 95', PAD 65' 7. Unit or Property name Kuparuk River Unit 8. Well number 2W-12 9. Permit number/approval number B4-224(Conserv Order No, 261). 10. APl number 50-029-21240 11. Field/Pool Kuparuk River ~il~o,,al Total Depth: measured 8092' feet true vertical 631 3' feet Effective depth: measured 7982' feet true vertical 6221 ' feet Plugs (measured) NOV 1 9 1992 Junk (measured) 7964' Ta~[~..k~..o~_7.~a.s Casing Length Size Cemented Measured depth True vertical depth Structural 9 0' 1 6 · 337 SX CS I 90' 90' ' Conductor Surface 2690' 9-5/8' 610 SX AS III 2720' 2426' Intermediate & 500 SX CLASS G- Production 8035' 7 · 925 SX CLASS G 8065' 6290' & 25O SX AS I Liner Perforation depth: measured 7570'-7600'(reperfed C Sand-old C sand perfs-7573'-7643'- squeezed), 7760'-7800'(new perfs-A Sand), 7758'- -7808', 7827'-7831', 7840'-7848', 7872'-7877' MD. true vertical 5885'-5909', 6037'-6070', 6036'-6077', 6092'-6095', 6103'-6109', 6129'-6133' TVD Tubing (size, grade, and measured depth) 4' 11# J-55 @ 5022' & 3-1/2' 9.3# J-55/L-80 @ 7705' Packers and SSSV (type and measured depth) BAKER HB RETR PKR @ 7474',BAKER FB-1 PERM PKR @ 7674' (E-line meas), AVA 4' ACGA SSSV @ 1891' MD 13. Stimulation or cement squeeze summary Squeezed C Sand perfs 7573'-7643' Intervals treated (measured) w/ total of 51.75 bbls cmt slurry in 2 squeezes Treatment description including volumes used and final pressure ISlP: 600 psi in final squeeze 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~/~ ~ Form 1~'-4(~4 Rev 05/17/8~J' v Title Area Drilling Engineer Dat e¢',/~'/~_~. SUBMIT I/'N DLIPUCATE ARCO. ALASKA INC. DAILY OPERATIONL PAGE: 1 WELL: BOROUGH: -UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2W-12 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-21240 84-224 ACCEPT: 10/15/92 06:10 SPUD: RELEASE: 10/29/92 10:10 OPERATION: Workover DRLG RIG: NONE WO/C RIG: NORDIC 1 10/15/92 (1) TD: 8092 PB: 7982 MVING TO 2W PAD MW: 0.0 MOVE RIG F/1Y-09 TO 2W-12(12 MILES) RIG ON ROAD BETWEEN 2U & 2W @ REPORT TIME. 10/16/92 (2) TD: 8092 PB: 7982 BULLHEAD DN ANN W/12.3 BR MW:12.3 NaCl/Br COMPLETE RIG MVE F/1Y-09 TO 2W-12. ACCEPT RIG @ 6:30 HRS 10/15/92. PAD UNEVEN. WORK ON LEVELING RIG UNTIL 7:40. RU HARD LINES. TEST TBG TO 5000 PSI-SEALS OK. ND BLIND FLANGE ON TREE & NU CIRC FLANGE & SWEDGE. GET BOPE & ADAPTER READY TO SET. BRING 11.7 PPG VISC BRINE INTO PITS & WT UP TO 12.7 PPG.. PRESS DN HARD LINE TO ARCO FLOWLINE TO MANIFOLD, CK F/LEAKS. FIX 2 LEAKS-OK. CIRC DN TBG TAKING RETURNS THROUGH CHOKE & DN FLOWLINE @ 30 SPM W/12.7 PPG BRINE. NO RETURNS TO FLOWLINE, ANN PRESS=LINE PRESS=200 PSI. AFTER PMPING 83 BBL(REACHED FIRST GLM). SI ANN & BULLHEAD DN TBG. TP=1650 PSI, CP=1400(INCREASED IMMEDIATELY ON SI ANN-GLV IS LEAKING F/TBG TO ANN DNHOLE) PMP 91 BBL TOTAL DN TBG. FINAL TP=975 SPI, CP=900 PSI. SD PMP, TBG FALLS TO TP=0 PSI, CP=800 PSI. BLEED PRESS F/ANN, BUILD TO 700 PSI ON ANN. CHECK TBG, ON VACUUM. ND TREE. REMOVE SPEAR F/TOP OF FISH & CLEAN OFF-DRESS TOP. NU X/O FLANGE, BOP, FLOW NIPPLE. BRING ON 140 BBLS 11.7 PPG BRINE & MIX W/12.7 PPG BRINE IN PITS TO GET 12.3 PPG VISC BRINE. REVIEW OPTIONS FOR RETRV FISH/FINISH WELL KILL ON BACKSIDE. RIH W/i-Ii/16" PIPE TO 5' BELOW TBG HGR TO CHECK OPEN. TRY TO SCREW INTO TOP OF TBG HGR W/LDG JT, WOULD NOT GO. START PMPING DN ANN W/12.3 BRINE @ 2-3/4 BPM & 2200 PSI. WELL OPERATION: 2~-~2 RIG : NORDIc 1 PAGE: 2 10/17/92 (3) TD: 8092 PB: 7982 10/18/92 (4) TD: 8092 PB: 7982 COND & WT UP BRINE TO 12.6 PPG FLOWING. MW: 12.6 NaC1/Br ~u ANOTHER 40 BBLS 12. SIDE BULLHEAD DN TBG 42 BBL SI & MONITOR. BOTH UP & COND BRINE · SI & M 3 PPG BRINE DN ~. ~ ~D~z o~o F/~u~__~~u ANOTHER ~ _u~ TBG. -' ._nULLHE F _~'~'CH & PU ~J~ ~£H W/OVE~e,~ ~ ~-Mn~,~' BLEED OF 9 6 ~ "~u z' -" ~-OR F. ,..~- B~AK ~_~ POOH ~O ~,~ -& 6-1/8. n~ ._ FLO~ OF ~,, VALVE _~'~' DC ~'~ JT TB SEEN V , ~u FISH. - *'u BREA LL =~ _ "- TO ~T~._==~CULT Tn .... "~' UP ~/ .... ~u FLOOR ouu PSI ~=u~u B ~ r~ ~v~C B ' UP & S TO UP PITS 12.6 PPG ' 4.5 PBM CO~ OF ~ ~IGHT T~K '_ CIRC 150 CO~ & ~T UP B 1ST BATc .... R/NE TO ~ Rmv, ..... ~ BRINE · .... -~'J PPG LOST 10 ~2l~J4 NaC1/Br - & ~ C~-- DURING CIRC SPM & 700 PSI SU~ TO SU~ ' ~ INTO PITS, - ~u~p. ' ~s~ s~ · ~o~o Sp.~_~r~-OK. AC~ .... ~'~ TBG ST~T~t~~HT VAC ~_SPAPE) & RIH W/9 ~' TAG PRD m~' -~ TBc ~-'iY_ u-r D ~' POOH ~ W/SW n~ !'~OUBLE G~m~..~u OTIS ~SSE~ ~._ & ~ OTr~ E~u~ TOn _ _ --~ ~,, - TOp ~_CUT BEFo~ ~ JET CUT~"'~5 ~I~LT~,~-~ W~, . RECEIVED NOV 1 9 I(392 Alaska 0il & Gas Cons. ~ommiss~on Anchorage WELL. · 2W-12 OPERATION' RIG : NORDIC PAGE: 3 10/19/92 (5) TD: 8092- PB: 7982 10/20/92 (6) TD: 8092 PB: 7982 POOH ON 3-1/2" DP W/RETR PKR MW:12.4 NaCl/Br CBU @ 4-1/2 BPM & 700 PSI. PMP DRY JOB. POOH W/3-1/2" TBG. REMOVE SSSV CONTROL LINE-RECOVER ALL 34 SS BANDS. STRAP PIPE-AS STAND BACK & LD JEWELRY. RD TBG EQUIP. RU TO RUN DP. SET WEAR BUSHING. MU BAKER PBR RETRV SPEAR & RIH ON 3-1/2" DP. WASH DN LAST 2 JTS. CIRC 70 BBLS 12.3+ BRINE. TAG PBR @ 7398'. WORK & ROTATE PKR, FINALLY STRAIGHT. PULL FREE @ 210K#. REVERSE CIRC OUT THROUGH CHOKE. MUD GAS CUT. LD SINGLE, WORK PIPE. PKR DRAGGING JUST SLIGHTLY. PMP DRY JOB. POOH SLOWLY TO AVOID SWABBING, WORKING THROUGH TIGHT SPOTS. POOH W/ELINE TBG JET CUTTER MW:12.4 NaC1/Br SERV RIG EQUIP. CONT POOH W/3-1/2" DP & 4-3/4" COLLARS. POOH & LD FISH: BAKER PBR, BAKER FHL RETV PKR, 3 JTS TBG, 2 MERLA GLMS, 9.75" TBG STUB CUTOFF. +1/8" SCALE BUILDUP ON TBG. SET WEAR BUSHING. RU TO RIH ON 3-1/2" TBG. MU FTA #3. RIH W/FTA ~3 ON 3-1/2" TBG. WASH DN LAST 2 JTS. TAGGED @ 7546'. DRESS DN TBG CUT W/OVERSHOT EXTENSION, GRAB TBG STUB. WORK FISH, PULL MAX OF l16K# W/OUT FREEING FISH. HOLD l16K# F/ONE-HALF HOUR WHILE WAIT ON SLINE. CANNOT CIRC THROUGH BTM GLM. RU F/SLINE. SET TBG IN SLIPS HOLDING 14K OVER STRING WT. RU OTIS SL. TEST LUB TO 1000 PSI. RIH W/2.775" GUAGE RING TO 7678' WLM. RIH & PULL GAS LIFT VALVE IN BTM GLM @ 7652' WLM. CIRC DN TBG TAKING RETURNS UP ANN. RIH & SET CAT VALVE @ 7684' WLM TO CIRC AGAINST. TRY TO WORK PIPE FREE WHILE CIRC @ 2BPM, 800 PSI W/OUT SUCCESS. PU PIPE & SET SLIPS HOLDING 14K# OVER UP WT. RU SWS ELINE. TEST LUB TO 1000 PSI. RIH W/JET CUTTER F/3-1/2" TBG TO 7650.75' AND FIRE. CANNOT SEE CUT W/CCL, DID NOT FEEL OR SEE CHARGE IN ELINE UNIT. POOH W/SWS & ATTEMPT TO PU ON TBG TO l16K#. WORK PIPE & CIRC W/OUT SUCCESS. RIH W/SECOND JET CUTTER & ATTEMPT CUT IN SAME PLACE. POOH. WELL. : 2W-12 OPERATION: RIG : NORDIC 1 PAGE: 4 10/21/92 (7) TD: 8092 PB: 7982 10/22/92 (8) TD: 8092 PB: 7982 10/23/92 (9) TD: 8092 PB: 7982 POOH. LD CBR JTS. MW:12.4 NaCl/Br FIN POOH W/ SCHLUMBERGER JET CUTTER. RD SCHLUMBERGER EQUIP. RELEASE SCHLUMBERGER WL SERVICE. WORK/PULL PIPE TO l16K# WHILE CIRC @ 3 BPM @ 950 PSI. FISH WOULD NOT COME FREE. ATTEMPT TO RELEASE FISH, UNSUCCESSFUL. CALL OUT ALTAS WL SERVICE. CONT WORK PIPE WHILE WAIT FOR AWS. RU AWS EQUIP. SET 25K~ OVER STRING ON SLIPS. RIH W/2.70" JET CUTTER. ATTEMPT TO TIE IN, COLLAR LOCATOR MALFUNCTION. POH, CHANGE OUT COLLAR LOC. RIH. TIE IN COLLAR LOC. CUT TBG @ 7663'. POOH W/AWS JET CUTTER. WORK PIPE TO 60K OVER. GRAD PULL FISH FREE. CBU. RECOVER TRACE OF SAND ON SHAKER. SLUG PIPE. POOH. LD 3-1/2" TBG. NORM TEST SAME. SEND OUT TBG. LD 5-3/4" O/S. UNABLE TO BACK OUT HEX SCREWS F/RETAINER RINGS. GET HOT WORK PERMIT FROM CPF-2. CUT RET RINGS W/GRINDER. RECOVER CARBIDE BLAST RINGS. LD 3-1/2" TBG X/O 8RD EUE B X FL4S P. CBU MW:12.4 NaC1/Br CONT BREAK OUT TBG FLUSH JT. REMVE CARBIDE BLAST RINGS. LD TBG FLUSH JTS. RECOVER ALL JEWELRY DN TO SEAL ASSY. SWS APPARENTLY FIRED THE JET CUTTER RIGHT IN THE MIDDLE OF TBG COLLAR; FAILED TO MAKE A CUT. AWS JET CUTTER MADE PARTIAL CUT(i/4" CIRCUMFERENCE). MU 6" PKR MILL ASSY. RUN 2 STDS DP. SLIG & CUT 50' DRLG LINE. SERV RIG. CONT RIH W/6" PKR MILL ASSY. TAG UP @ 7590'. PU KELLY. WASH/REAM F/7590'-7670'. MILL OVER BAKER PERM PKR. TEST UPPER & LOWER KELLY COCK TO 3000 PSI. CONT MILL OVER PERM PKR. CUT PKR REE. CHASE DN PKR TO 7810'. CIRC BU 100 SPM, 1100 PSI. PMP SLUG. BLOWDN KELLY. STAND KELLY BACK. POH W/6" PKR MILL. SLIGHTLY WET; SMALL PORTS IN PKR MILL. LD MILL & JUNK BASKETS. RU 3-3/16" SPEAR DRESSED W/4.04" GRAPPLE & PMP OUT SUB. MU FTA #4. RIH ON 3-1/2" DP. PU KELLY. ENGAGE SPEAR INTO FISH. PULL FISH LOOSE W/40K OVER. BLOWDN KELLY. DROP BAR. SHEAR PMP OUT SUB. CBU. TESTING LUB TO 500 PSI MW:12.4 NaCl/Br PMP SLUG. CHECK CROWN-0-MATIC. POH W/FTA #4. RECOVER BAKER FB-1 PKR & TALL PIPE ASSY. LD SPEAR & PMP OUT SUB. PU 6" BLADED MILL. RIH TO 7400'. PU KELLY. WASH/REAM F/7400'-7818' (TOP OF FILL/FISH). MILL/PUSH FISH DN TO 7970', WOULD NOT MILL FURTHER DN. CIRC HOLE CLEAN(WHILE ATTEMPT TO MILL DN FURTHER, UNSUCCESSFUL). SPOT 20 BBLS CLEAR BRINE @ BTM(APPOX F/7450'-7970') BLOWDN & STAND BACK KELLY. POH 9 STDS DP. PMP SLUG. CONT POOH. LD BLADED MILL & ASSY. RU SCHLUMBERGER LUB & EQUIP. TEST LUB TO 500 PSI. WELL : 2W-12 OPERATION: RIG : NORDIC PAGE: 5 10/24/92 (10) TD: 8092 PB: 7982 10/25/92 (11) TD: 8092 PB: 7982 TESTING BOPE MW:12.4 NaCl/Br FIN TESTING SCHLUMBERGER LUB TO 700 PSI. RUN 5.8" GAUGE RING/JB TO 7800' MU 7" EZSV & SETTING TOOL. RUN & SET 7" EZSV @ 7650'. RD SCHLUMBERGER EQUIP. LOAD 42 JTS 2-7/8" TBG INTO PIPE SHED WHILE RUNNING E-LINE. PU 42 JTS 2-7/8" TBG TAIL PIPE. RIH ON 3-1/2" DP. TAG EZSV CMT RETAINER @ 7652'. RU HALLIBURTON CMT LINE. CBU. ESTABLISH INJECTION RATE 1 BPM @ 500 PSI, 2 BPM 750 PSI. BATCH MIX CMT SLURRY WHILE CIRC WELL @ 2 BPM. MIX 140 SX CLASS G CMT + ADDITIVES. SLURRY @ 15.8 PG & ADDING PERFECT SEAL AGRREGATE. SWITCH LINE TO HALLIBURTON. PMP 5-1/2 BBLS WATER. TEST LINE TO 3500 PSI. PMP 5 BBLS MORE WATER BEHIND. DISPLACE W/41 BBLS BRINE TO SPOT CMT AS BALANCE PLUG. HELD 100-200 PSI BACK PRESS WHILE SPOTTING CMT. LD SINGLE & 2 PUPS, PULL 16 STDS. REVERSE OUT CMT CONTAMINATED WATER & BRINE TO CLEAR DP. CLOSE PIPE RAMS. BRADENHEAD SQUEEZE CMT @ 1 BPM. PRESS UP TO 2400 PSI, THEN BROKE BACK. SQUEEZE AWAY 12 BBLS CMT SLURRY @ 1 BPM, FROM 1500 PSI TO 2650 PSI. SHUT IN. RESUME PMP SLOWLY, PRESS UP TO 3000 PSI MAX WITH 13-3/4 BBLS SQUEEZED. CONT HEST SQUEEZE, STOPPING @ 3000 PSI SEVERAL TIMES. SQUEEZE TOTAL 15-3/4 BBLS CMT SLURRY. KEEP WELL SHUT IN/HOLD PRESS. MONITOR PRESS. BLEED OFF PRESS. OPEN PIPE RAMS. PMP SLUG. POH. LD 15 JTS 3-1/2" DP. STAND BACK 2-7/8" TBG. RD DP & TBG EQUIP. PULL WEAR BUSHING. SET TEST PLUG. TEST BOPE POH W/6-1/8" BIT MW:12.4 NaCl/Br FIN TEST BOPE. PULL TEST PLUG. INSTALL WEAR BUSHING. SLIP & CUT DRLG LINE. MU 6-1/8" BIT & BHA. RIG REPAIR. DEAD LINE SHEAVE BLOCKS NOT TURNING DUE TO LINE TAR. REMOVE LNE TAR N BLOCKS. CONT RIH W/6-1/8" BIT & BHA. TAG CMT STRINGER @ 6625'. PU KELLY. PU SINGLES. WASH/REAM F/7008'-7327'. BLOWDN & STAND BACK KELLY. LD 10 JTS DP. RIH W/5 STDS. PU KELLY. WASH/REAM TO 7395'. CLEAN OUT FIRM CMT F/7395'-7460'. DISPLACE HOLE W/NEW CLEAN BRINE. PRESS TEST CSG TO 2000 PSI FOR 30 MIN. FLUSH LINE & PITS W/CLEAN BRINE. CONT CLEAN OUT CMT F/7460'-7650'. CIRC HOLE CLEAN. CLOSE PIPE RAMS. PRESS TEST SQUEEZE CMT. PRESS UP TO 1600 PSI, THEN BREAK DN; START PUMPING @ 1 BPM. INJECTION RATE 1 BPM @ 850 PSI, 2 BPM @ 1130 PSI, 3 BPM @ 1500 PSI. BLOWDN & STAND BACK KELLY. POH W/6-1/8" BIT. STRAP PIPE. WELL. : 2W-12 OPERATION: RIG : NORDIC PAGE: 6 10/26/92 (12) TD: 8092 PB: 7982 10/27/92 (13) TD: 8092 PB: 7982 SINGLE IN HOLE W/KELLY MW:12.4 NaCl/Br SERV RIG. FIN POH W/BHA #1. RU & RIH 21 STDS 2-7/8" TBG. POH-LD 2-7/8" TBG. RD FOSTER TONGS. MU HOWCO SETTING TOOL ON DP. MU EZSV RETAINER. RIH ON 3-1/2" DP. BREAK CIRC & CIRC 10 MIN. SET EZSV RETAINER @ 7506'. START RU HOWCO CEMENTERS. ESTABLISH INJECTION RATE W/RIG PMP. (2 BPM @ 1150 PSI, 3 BPM @ 1500 PSI. UNSTING FROM EZSV & CIRC W/CHARGE PMP WHILE FIN RU & VERIFY THICKENING TIME TEST #2 RESULTS FOR LEAD SLURRY. BATCH MIX 60 SX MICRO MATRIX CMT & ADDITIVES. BATCH MIX 95 SX PREMIUM G. PMP 10 BBLS WATER. TEST LINES TO 4000 PSI. PMP 10 BBLS MORE WATER, 2-1/2 BPM, 600 PSI. PMP 18 BBLS, 12 PPG MICRO MATRIX LEAD SLURRY, 3 BPM, 1000 PSI. PMP 8 BBL, 15.8 PPG CLASS G TAIL SLURRY @ 2-1/4 BPM, 850 TO 750 PSI. STAB INTO EZSV. PMP 12 BBLS MORE TAIL SLURRY. CHASE W/2 BBL$ WATER & 45-1/2 BBL BRINE, 2-1/2 BPM, 1100-900-1150 PSI. SHUT DN & MONITOR PRESS(ISIP: 600 PSI, 5 MIN SIP=530 PSI. UNSTING F/EZSV W/2 BBL TAIL CMT IN DP. PULL 2 STDS. REVERSE OUT 3-5 BBLS CMT CONTAMINATED BRINE & WATER, UNTIL CLEAN BRINE RETURNS. RD HOWCO. POOH-LD HOWCO SETTING TOOL & STINGER. MU BIT #2. RIH W/BHA #2 TO 7360' MU KELLY. BREAK CIRC & CIRC @ 100 SPM, 1000 PSI. TEST ~ASING TO 3000 PSI, LOST 80 PSI IN 30 MIN-0K. WASH & REAM W/KELLY-LOOKING FOR T.O. CMT/RETAINER. RIH W/BIT & 7" CSG SRPR MW:12.4 NaCl/Br SERV RIG. WASH & REAM-TAGGED EZSV RETAINER @ 7506' NO CMT ON TOP OF RETAINER(REVERSED OUT). CBU @ 4 BPM,'ll00 PSI-SOFT. CMT IN RETURNS-CIRC CLEAN. WOC. DRILL OUT EZSV-RETAINER @ 7506' & DRILL FIRM CMT TO 7629'. BROKE OUT OF CMT @ 7629'-WASH & REAM TO EZSV-BP @ 7652'. CIRC HOLE CLEAN, 3-3/4 BPM, 1000 PSI. TEST C SAND PERF TO 500 PSI, LOST 60 PSI IN 15 MIN. RETESTED W/PMP ISOLATED, SAME RESULTS. DRILL OUT EZSV-BP @ 7652' & PUSH DN TO 7713' BLOWDN & STAND BACK KELLY. RIH 4 STDS & PUSH REMAINS ~F EZSV-BP TO BTM @ 7964'. REVERSE CIRC HOLE CLEAN @ 2 BPM, 450 PSI. DUMPED 15 BBL VISCOUS BRINE OFF BTM, OVERBOARD INTO CUTTING BIN. CLEAN PIT #3 WHILE REVERSING. RD MI SOLIDS VAN & RU FILTRATION UNIT. POH W/BHA #2. LD 21 JTS FOR REAMING. MU BIT #1RR + 7" CSG SCRAPER + 2 JUNK BASKETS. RIH W/BHA #3. WELL. : 2W-12 OPERATION: RIG : NORDIC 1 PAGE: 7 10/28/92 (14) TD: 8092 PB: 7982 10/29/92 (15) TD: 8092 PB: 7982 PERF-RIH W/GUN #3 MW:12.4 NaCl/Br SERV RIG. CONT RIH W/BIT & SCRAPER TO 7306'. PU & SERVICE KELLY. REAM CSG F/7306' TO BTM @ 7964' BREAKOUT & LD KELLY. RIH 10' & 15' PUPS. MU CIRC H~AD. REVERSE CIRC FILTERED BRINE INTO HOLE & FILTER DIRTY BRINE RETURNS UNTIL CLEAN BRINE RETURNS(INSTALL NEW PACKING IN KELLY SWIVEL WHILE REVERSING). WELL OUT OF BALANCE. CIRCULATE 20 BBLS 12.3 PPG & 25 BBLS 12.5 PPG FILTERED BRINE DN TBG TO BALANCE OUT. CLEAN PIT 92 & CONT FILTERING SURF SYSTEM. RD CIRC HEAD. LD PUPS. POH-LDDP & DC'S, BHA #3. FIN CLEANING PITS & FILTERING SURF SYSTEM WHILE LDDP. PULL WEAR BUSHING. CLEAR TOOLS OFF RIG FLOOR. RU SWS. MU GUN #1, SURF ORIENT SHOTS 153' CCW F/HI-SIDE. SET LUB IN BAG & TEST TO 500 PSI. PERF A SAND F/7800'-7760' IN 2 GUN RUNS. MU GUN #3, 30' GUN, TO REPERF C SAND. START RIH W/GUN #3. HGR LANDED, PREP T/SET PKR MW:12.4 NaCl/Br RIH W/GUN #3 & PERF C SAND F/7600'-7570'. RUN 6.00" GUAGE RING & JB TO 7800'. RECOVERED 1/2 GALLON PERF DEBRIS IN JB. RE-RUN GR & JB TO 7800'. RECOVERED 1/2 CUP PERF DEBRIS. MU BAKER FB-1 PERMANENT PKR & 3-1/2" TAILPIPE ASSEMBLY ON WL SETTING HEAD. RIH, TIE-IN, & SET TOP OF PKR @ 7674' ELM. RAN W/BALL IN PLACE IN SOS. POH W/WL. RD SWS. SCRAPE & WIRE WHEEL RUST OFF 1ST JT FOR BLAST RINGS-INSTALL RINGS ON SAME. SLIP & CUT 50' DRLG LINE. RU FOSTER TONGS & TOOLS TO RUN COMPLETION ASSEMBLY. RUN 4" X 3-1/2" SELECTIVE SINGLE COMPLETION ASSEMBLY. STAB SEALS INTO FB-1 PKR & VERIFY W/400 PSI. SPACE OUT-INSTALLED PUPS 1 FULL JT BELOW HGR. MU FMC GEN lV, 4" TBG HGR. TESTED SSSV CONTROL LINE TO 5000 PSI FOR 15 MIN WHEN MU TO SSSV & HGR. LAND HGR. RILDS. WELL : 2W-12 OPE RAT I ON: RIG : NORDIC PAGE: 8 10/30/92 (16) TD: 8092 PB: 7982 RIG RELEASED MW:12.4 NaCl/Br PRESS TBG TO 2500 PSI & SET PKR. HOLD TBG & PRESS ANN TO 1000 PSI. BLEED OFF ANN, BLEED TBG TO 1300 PSI. BOLDS. PU & SHEARED PBR @ 98K#. BLEED OFF PRESS. RELAND HGR. RILDS. PRESS ANN & TBG TO 1000 PSI, CLOSE SSSV, BLEED TBG ABOVE SSSV TO 450 PSI. TEST SSSV 15 MIN, OK. EQUALIZE & REOPEN SSSV. TEST ANN TO 2500 PSI, LOST 40 PSI IN 15 MIN-OK. HOLD ANN, PRESS TBG & SHEARED SOS @ 3600 PSI. LDJT. SET BPV. ND FLOW NIPPLE. ND 11" 5 SKI BOPE & ADAPTER FLANGE. BREAK PRODUCTIONS 4-1/8" VALVES & ADAPTER OFF 3-1/8" SSV & REMOVE OLD TREE F/CELLAR. BRING NEW TREE INTO CELLAR & STREAM OFF. PRODUCTION WING VALVE ON WRONG SIDE OF TREE-BREAKDOWN & REASSEMBLE TREE. NU TREE. TEST PACKOFF TO 5000 PSI. TEST TREE TO 250 PSI & 5000 PSI. OK. PULL TP. OPEN SSSV. RU CIRC LINES. REVERSE CIRC 90 BBLS SW SPACER, FOLLOWED BY DIESEL, TAKING RETURNS OUT TBG THRU CHOKE UNTIL CLEAN DIESEL RETURNS. BLEED OFF ANN-CHECK VALVE IN GLM'S @ 7408' HOLDING. RD CIRC LINES. SECURE WELL. CLEAN PITS. FLUSH LINES WITH WATER & BLOWDOWN SAME. VACUUM OUT CUTTINGS BOXES. BACK RIG OFF WELL @ 21:30 HRS. PU MEETING BOARDS & PTT LINER. CLEAN UP PAD AROUND WELL AREA. RELEASE RIG. RIG RELEASED @ 22:30 HRS 10/29/92. (MVING CAMP & RIG TO 2B PAD-PLAN A FEW DAYS OF MAIN WORK, THEN "COLDSTACK". MOVED CAMP AHEAD OF RIG & SET UP ON SW CORNER OF 2B PB PAD. MOVED RUG F/2W TO 2B PAD, 7.6 MILES. REMOVE GROUND SUPPORT FOOT FROM CELLAR/SUB-BASE SUPPORT & LOAD SAME INTO PIPE SHED. LD KELLY. REMOVE GUY LINES & RU TO LD WINDWALLS. SIGNATURE: DATE: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 5, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Verbal approval was obtained from Mr. Russ Douglass on November 5,. 1993. Well Action. Anticipated Start Date 2w-12 Other 11/12/93 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attach ments NOV 'l 0 ~995 Oit & Gas Cons. c~mmissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany : P2;:: ;~'; 2:" '--' STATE OF ALASKA .... ALASYv~, OIL AND GAS CONSERVATION COMMIS,_. ')N '~.,.~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well - "~' Alter casing Repair well Plugging ~/i~;an~Xetension PerfoS~ia~;late _ ;41 Change approved program _ 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 412' FNL, 235' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 1529' FNL, 1233' FEL, Sec. 28, T12N, R9E, UM At effective depth 1298' FNL, 1306' FEL, Sec.28, T12N, R9E, UM At total depth 1240' FNL, 1323' FEL, Sec. 28, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 8092' feet Plugs (measured) true vertical 631 3' feet None Effective depth: measured 7982' feet Junk (measured) true vertical 6221 ' feet None Casing Length Size Cemented Structural Conductor 9 0' 1 6" 337 Sx CS I Surface 2690' 9 5/8" 610 Sx AS III & Intermediate 500 Sx Class G Production 803 5' 7" 925 Sx Class G & 250 SX AS I Liner Perforation depth: measured 6. Datum elevation (DF or KB) RKB 95 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2W-12 9. Permit number 84-224 10. APl number 5o-029-21 240 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool RECEIVED NOV 1 0 1993 ~s~,a u~l & Gas Cons. Commission Measured depth ~-~)r{l~l~ical depth 90' 90' 2720' 2426' 8065' 6290' 13. 7570'-7600'(reperfed C Sand-old C sand perfs-7573'-7643'- squeezed), 7760'-7800'(new perfs-A Sand), 7758'- -7808', 7827'-7831', 7840'-7848', 7872'-7877' MD. true vertical 5885'-5909', 6037'-6070', 6036'-6077', 6092'-6095', 6103'-6109', 6129'-6133' TVD Tubing (size, grade, and measured depth) 4" 11# J-55 @ 5018' & 3-1/2" 9.3# J-55/L-80 @ 7705' Packers and SSSV (type and measured depth) BAKER HB RETR PKR @ 7470',BAKER FB-1 PERM PKR @ 7674' (E-line meas), AVA 4" ACGA SSSV @ 1887' MD) Attachments Description summary of proposal _~ Detailed operation program ~ BOP sketch _ Inject polymer into Cl Sand with CTU. 14. Estimated date for commencing operation 15. Status of well classification as: November 12, 1993 Oil ;K Gas __ 16. If proposal was verbally approved ~ Name of a~prover ¢645'.4 .].~O~¢~ 5 $/ //- ~' - c~ Date approved Service 17. I hereby~c~rtify tha~ th..e foregoing is true and correct to the best of my knowledge. Si~ned '~~~' ~' /¢//~ Title <~~ )¢;3'/~'- ~_~,,fl ~'/I E_. ~ FOR COMMISSION USE ONLY ~' Suspended _ Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test _ Subsequent form Approved by order of the Commission Form 10-403 Rev 09/12/90 Original Signed By David W. Johnston IApproval No. I ?~ '- 3o q require 10-~f{)~'/ Approved Copy Returned Commissioner Date / / / / 9 / ¢ 9 SUBMIT IN TRIPLICATE Attachment 1 Request for Polymer Treatment KRU Well 2W-12 ARCO Alaska Inc. requests approval to place polymer gel into KRU Well 2W-12 as a water shut-off technique. The C1 interval in this well is producing at a WOR of greater than 30 and this treatment is needed to reduce water production and increase recovery from the C34 Sands. The treatment will be performed by selectively injecting MARCIT gel into the prolific watered out C1 interval in Well 2W-12. MARCIT is MARathon Oil Company's C__onformance Improvement Treatment and consists of a polyacrylamide crosslinked with chromic acetate for treating a variety of conformance problems in both injection and production wells. The MARCIT gel technology was selected based on robust gel chemistry, controllable gellation rates and field successes in treating fractures, matrix or both. The goal of this treatment is total C1 shutoff. If achieved, the squeeze would eliminate over 6000 BWPD coming from the C1 zone and would allow the C34 zone to produce commingled with the A Sand. This job will be pumped via 2" coiled tubing into the C1 Sand below an inflatable packer while simultaneously injecting diesel down the CT/tubing annulus. The planned 1300 bbls of gel is designed to treat an approximate 40' radius. This multi-stage treatment should be sufficient to stop water production from the C1 interval. The MARCIT gel system could have wide application at Kuparuk if successful. Thin zones are cycling both water and gas from which the vast majority of recoverable oil has been produced. The DDG project was executed to reduce the amount of water entering the thief zone in the injectors and to divert the waterflood to unswept pore volumes. This MARCIT job will not interfere with the DDG test currently underway at Drill Site 2W. ~O'q 1, 0 MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh A Griffin ~ date: Commissioner file: thru: Blair E Wondzell ~1~.') subject: Sr Petr Engineer from: "~ou Grimaldi Petr Inspector October 29, 1992 LOU10213.DOC RIG/BOPE Inspection NORDIC Rig #1 ARCO Well #2W-12 Kuparuk River Field Wednesday, October 21, 1992: John Spaulding and I traveled to NORDIC Rig #1 in the Kuparuk River Unit to make a Rig/BOPE Inspection while crews were working on ARCO's Well #2W-12. I found the NORDIC Rig to be in very good shape with the appearance of regular maintenance. The area surrOunding the rig was neat and orderly and provided good access. Don Breden (ARCO representative) and Lance Johnson (NORDIC representative) were very congenial and as usual, welcomed our visit. In summary, the Rig/BOPE Inspection on NORDIC Rig #1 revealed all to be in compliance. Attachments ~-LAS KA OIL CON S E RVAT I ON AND GAs COMb4ISSION TO: ~rTr~ W Johns t~ THRU' Blair E Wondzell P.I. Supervisor DATE - SUBJECT- FROM' Lou Grimaldi Petr Inspector OPERATION: Drlg Operator_ Locati on: Sec T Drlg contr /~---~C- Location (gen'l) Compl__ Wkvr? UIC . Permit # R M Ri g# / _ Well sign IN COMPLIANCE; yes no n/a A. DIVERTER 1. ( ) ( ) O0 line sz & length 2.() Z.() 4.() () 5.() () 6.() () 7. ( ) ( ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Rig/BOPE Inspection Report Representative ~)~5)/0 Well name ~ ~ Representative ~~C~ 9.~ () 10. ( ) ~.bO () 12.~ () ~3. Od () l~+.~. ~ ( ) 15. ~ ( ) ~6.~) () -~7. ~l ( ) 18. O~ ( ) ~9. (X) () () 21. ~Q) ( ) 22. c~. () line conn& anchored bifurcated & dwn wi nd 90° targeted turns vlvs: auto & simultaneous annul ar pack-off condition B. BOP STACK wellhead flg wkg press stack wkg press annul ar preventer pi pe rams bl i nd rams stack anchored chke/kill line sz 90° turns targeted (chke-& kill ln) HCR vlvs (chke & kill) manual vlvs (chke & kill) connections (flgd, whd, clmpd) drl spool flow nipple fl ow monitor ~ control lines fi re protected C. CLOSING UNITS 23. ('/~) ( ) wkg press 24. (>~D' ( ) ( ) fluid level 25. ~0 ( ) ( ) oprtg press 26. ~ ( ) ( ) press gauges 27. ( ) . ( ) sufficient vlvs 28. ~t ( ) ( ) regulator bypass 29. ) ( ) ( ) 4-way vlvs (actuators) '30. ~) ( ) ( ) blind handle cover 31. ~ ( ) ( ) driller control panel 32 · ( ) ( ) remote control panel i N COMPL I ANCE; 7es n._~o nta. 33. (~ ( ) ( ) fi rewall 34. ~ ( ) ( ) nitrogen power source (back-up~ 35. (~) ( ) ( ) condition (leak,s;,'hOses, etc) D. MUD SYSTEM 36. ~. ( ) ( ) pit level floats installed 37. (~ ( ) ( ) flow rate sensors 38. ~X~ ( ) ( ) mud gas separator 39. ~)<) ( ) ( ) degasser 40. ( ) ( ) ~k~) separator bypass 41. ~ ( ) ( ) gas sensor 42. ~ ( ) ( ) chke In corm 43. ( ) ( ) trip tank E. RIG FLOOR 44. (~ ( ) ( ) kelly cocks (upper,lower,IBOP) 45. ~ ( ) ( ) floor vlvs (dart vlv, ball vlv) 46. (~ ( ) ( ) kelly & floor vlv wrench..e_s. 47. (~ ( ) ( ) driller's console (floWlmonit°r- flow rate indicator, pit~le~e: .~. indicators, gauges) 48. ~ ( ) ( ) kill sheet up-to-date 49. (~) ( ) ( ) gas ~etection monitors ~ & methane) :" "' 50. ~ ( ) ( ) hydr chke.panel . ' , 51. ~ ( ) ( ) chke manifold F. MISC' EQUIPMENT 52. ~ ( ) ( ) flare/vent line . ' 53. ~ ( ) ( ) 90° turns targeted (dwn strm choke lns) 5~. ( ) ( ) j~J reserve pit tankage 55. (x3 () SG.O~ () 57. () ( ) s8.~ () personnel protective equip avail all drl site suprvs trained for procedures H2S probes rig housekeeping RECORDS: Date of last BOP inspection: Resulting non-compliance: Non-compliances not corrected & why: Date corrections will be completed: BOP test & results properly entered on daily record? Date of last BOP test: Kill sheet current? Inspector~ ARCO Alaska, Inc. ~ Post Office B ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 17, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following wells' 3B-13 2U-10 2W-12 2X-10 If you have any questions, please call me at 262-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L64 Enclosures RECEIVED S EP ! 9 ]985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ~- ALASKA L _ AND GAS CONSERVATION CO, ,41SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E]XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. : 84-224 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21240 4. Location of well at surface 9. Unit or Lease Name 412' FNL, 235' FEL, Sec.33, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1529' FNL, 1233' FEL, Sec.28, T12N, RgE, UM 2W-12 At Total Depth 11. Field and Pool 1240' FNL, 1323' FEL, Sec.28, T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF' etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 94' RKBI ADL 25642 ALK 2573 ., 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/23/84 12/29/84 1 2/30/84*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8092'MD,6313'TVD 7982'MD,6221 'TVD YES [~[X NO []I 1891 feet MD 1460' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 90' 24" 337 sx CS I 9-5/8" 36.0# J-55 Surf 2720' 12-1/4" 610 sx AS Ill & 500 sx Class G 7" 26.0# J-55 Surf 8065' 8-1/2" 925 sx Class G & 250 s; AS 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) 7872' - 7877' 7573'-7643' 3-1/2" 7689' 7670' & 7411' 7840' - 7848' 7827'-7831' w/12 sPf,_ 7827' - 7831 ' 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7798' - 7808' w/4 spf, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7778' - 7799' 120° phasing See attached Addendum, dated 7/26/85~ for frac data. 7758' - 7779' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ I .. Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE alF 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None '-- ~ ,,~ " i 'i Form 10407 * Well was perforated and tubing ran on 01/31/85. GRUll/WC03 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7565! 5881' N/^ '- Base Upper Sand 7628' 5931' Top Lower Sand -~:- -..7741' 6022' ~ ,-'- '- ..' Base LOwer Sand 7906' 6157' .. : .: . .. 31. LIST OF ATTACHMENTS :. _ Addendum -: 32. I hereby certify that ~he for~g0ing is true and Correct to the best of my knowledge Signed //~ ~ ~~ 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 Alask:a. 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: Flbwing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 6/~1/85 2W-12 Frac well w/315 bbls gelled diesel in 8 stages w/700# 100 mesh & 15,100# of 20/40 sand. D illing ~uperintendent bate Alaska 0i1 & Bas Cons, Con, mission '~,mchoraoe ARCO Alaska, Inc. ~ ~_..~ Post Office Box 1 Anchorage, Alaska 99510 Telephone 907 276 1215 HoYember 14, 1984 · Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation~ Commission 3001 Porcupine Drive- Anchorage, AK 99501 SUBJECT: conductor As-Built Location Plats - 2W Pad Wells 1-8, 9-16- Dear Elaine: ' Enclosed are as-built location plats for the subject.wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer ,, JG/tw .GRU2/L93 Enc)osures If ARCO Alaska, Inc, is · Subsidiary of Atl=nficRIchlleldCompany PHASE IE AS-BUILT WELLS 9 Thru 16 28 27 3-4 E I AS-BUILT WELLS I Thru 8 (NSK 9. O5.223dl) LOCATED IN. PROTRACTED SECTIONS 33 & 34 TOWNSHIP 12_ N., RANGE 9 E.,.,.UMIAT MER. NO SCALE BASIS OF POSITION IS MONUMENTATION 2W NORTH AND ?_W SOUTH PER LHD E ASSOCIATES. NOTE' ~£LL 9 Y - S,gTg,~a3.a$ LAT. 70021'23.33~3" X - $18.,7~2.~1 LOIG. Z&g°SO'SO.86&7" PAD ELEV, 83.! 0.G. £LEV. 59.7 30~ FEL 57~ F~L SEC. 33 M£LL lO Y - 5,390,039.~g LAT. 70e21'23.8830. X . 518.805.09 LONG. 1~g=$0'53.2033" P&~ [LEV, 53.8 O.~. £LE¥. E~.3 28! FEL 523 F~L SEC. 33 JELL !! 5,980,095.05 LAT. 70°21'2~.4258. 518.~27.81 LONG. I~9°50'~9.~08. [LEV. 53.8 0.~. [LEV. 50.2 ~58 FEL ~88 rilL SEC. 33 ~£LL 12 Y - 5,980,150.70 LAT. 7~2t"2~.9757, X - 518,850.03 LONG.'l&9350'~8.~8[!. PAD ELEV. 53.3 0.~. [LEV. 59.8 235 FEL 412 FNL SEC, 33 '~ELL 13 Y - 5,380.~1~.55 LaT. ?0321,23.6390,, X . 519,183.71 L3NG. 1~9°50'39.1355,, PAD EL[~. 52.7 0.~. [LEV. 57.7 38 F~L 5~8 FNL SEC. 3~ ' 11 ~E.. 1~ ~ - 5.373.960.05 LAT. 70°21'Z3.0927. X . 519,151.31 LONG. 1~°50~39.7~,, PAD [LEV. 52.3 ~.~. [L[V. 57.7 75 ~L 503 ~NL SE;. 3~ ~ELL 1~ Y - $,~7~,~0~.~a LAT. 79~21,22.~7- X . 519,138.80 LON6. ;~9°50';C.4557. PAO ELEV. ~2.0 0.;. EL£¥. 5~.0 52 ?WL 553 F~L SEC. 3~ ~ELL 28 ¥ - 5,979,8&8.89' LAT, 7002['22.3005. X . 5[9.116.25 LONG. PAD £LEV. 52.g 0.~. EL£V. 58.~ 29 F~L 715 FNL LICENSED, ~")F.~-C"ICE L~I'JD ~UF, VEV'NG IN THE STATE OF A'.ASK;, C:;O THAT T~.IS ~'_AT ~PRE"ENTS A SURVEY M&DE UNDER MY ~.IRECT SUFERV;SION 't;[ ~,HAT g, LL DETAILS ARE C~FRECT ~.~ OF OCTOBER 14, 1984. Dote gr3wn ~- i, ARCO Alaska, Inc. ~rOleC' ~Jorth SlODe ~_..r,i~-~ DRILL SITE 2W CONDUCTOR AS-BUILT LOCATIONS Oct. 23, 1984 J Sco~e AS S~OWN I AR6~Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO- 1 ! i 5B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERD.'~ITH ARE THE RECEIPT AND RETURN ONE SIGNED PRESSURE TEST FINALS DATE: 07-02-S5 TfqANSMITTAL NO: 5237 ENGINEERING FOLLOW ING COPY OF · ~'C KN OW ITEMS LEDGE THIS TRANSMITTAL. CAMCO lQ-9 PBU 03-30-85-' 1Y-12 . ~,LL-OFF 05-05-85// OTIS 2E-'9 STATIC GRADIENT 2E-!3 STATIC GRADIENT 2E-14 STATIC GRADIENT 2E-!5 STATIC G Fu'%D IE NT 2U-I~ PRESSURE BUiLD-UP oU-i6 PRESS U.~,.. BUILD-UP 2U-16 STATIC GRADIENT 2U-!6 PRESSURE BUiLD-UP STATIC GRADIENT 3D-13 STATIC G~RDiENT 06 -10-85 06-10-85 o -o9-85/ 06-17-85 06-06-85 06-!3-85 06-i~-85 06-0 8-,9 5 05 -29 -85/ "~ ~ P ~'r'~' TU ~ ~-,.~-'~, ~ RN 2C-3 STATIC TEST 2D-2 24 HR PBU 03-30/31-85 04-21/22-85 GAUGE .~63132 ' GAUGE ~,f63137 / LYNES !t{-3 PRESSURE BUILD-UP 03-03/04-85 GAUGE ~, 2059 SO:; .'tO~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATr-:': 05-07-8':~ TI:;:AN3'HITTAI_ N0:5t78 I:i:ETUI;.:N l'O: T RAN:<;H I TTEi) RECE I !:"1" AND ARCO ALA,S'I<A, INC ATTN: RECOI:(I)$ CLERK A '¥ O- t 1 t .5 l"-~ I::' .-0. BOX ANCI-iORAGE, Al< 995 i"11E R E W I 1' I"i A R IE 'f'i"l E I:: 01... [. 0 W I N (:; I:;;E'I'Ui~N ONE ~'IGNED COF'Y OF' ACKNOWLEDGE T I-I ]' 3" T R A N,3~ H I '¥ T A L. l::'Z N¢iL PR I N'I':'; CBL ' $/ZCI-'iLUMBEi:?GEi:( I liE-t 2C-tS '"""-' 2C- 2C-t5 2C-t 6 2(;-t 5 26-16 2U-t 2W-9 2W--1 t~/ :.'?.u- 2W-t6,~ 2X-1 4,,,,,~ t o-30-84 0"~-05--8!5.:. ¢)2-06-85 un2-o8--85 G2-.~8-85 1 ()-2'?-84 I 0-~7-84.~ ':,:'),....'~ -' t 0 - 85 0 t -0 t --82 0t -02-'3'5 0t -02-85 02-0t -85 t t -.t ',;-84 F;;LJN R U iq RUN R LJ N R LJ N RtJN RtJN RtJN RUN RUN RLJN RUN RUN .... t 7300-7895 ...... ~ 550'0--7262 'Il' .,.n... ~-. 380 O- 6 ¢) 3 O :,",:t 2450-7f ~:t 7t 75'"8280 ::'t 4'790"6882 ~: t '~' 0-7736 :~ t 6400-6985 ~:t 5700-7786 ,,.'"'t 2~66-6640 :~: t 264 43~6-7874 I:;:ECE I F'T ACI<NOWI_EDGED ' Ii~ F'A E B . C U R R I E R C H E V R 0 iH D & M * D I:;: I I I_. I N [;- .-- B I... L ~ JOt-IN.':~TON MOB]~. ,NS'K ,3LEF;.'I(-BI... I) 15..' T R I Ii{ Li T I 0 N · W. I::'AS'I'IER Iii: X X 0 N ' F'I"I I I_i_ I t::'.S' 01 L J. RATHHr-ZLL DATE: Alaska Oii&- -6:~s Cons. Oo;nm!ssior, *..k"I' A'F IE [iF .S 0 H I 0 / 3' E UNION ,1(. TULI i',I/VA ULT--F I [.H To, _ /~LA.flail TNC. I~e wish to brl.§ to your attention that tile Oo~ntssion has yet received the following required ttem~ on the subject .ell ~hich our record0. ~.dicaCed .80 completed _./~',~-. ~ Article 5JS(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material si]ail be filed within 30 days after completion o£ a drilled.well. Please submit the above missing materta.1, Chairman lc~C.024 ARCO Alaska, Inc. Post Offi/"~iox 100360 Anchorage=, Alaska 99510-0360 Telephone 907 276 1215 DATE' APRIl_ 2'2, TRAN,.~M ITTAI. NO: i Si 48 RETURN TO' ARCO AL. AEt<A, INC, ATTN- RECORD£ r:Lr-:RK ATO-i i i 5B F:', (:)~ BOY i 0'E:'S60 ANCHORAC-E, AK 995I 'f'n'ANSH I T T~:.~. RE(.i:E !F"f' AND HEr.;,'r.."I,.!TTH ,~-,r.- . ...... , --, ......... , . ........~-,I-,,.-. THEE F'OI.LFil,.ItN. G ITEHS. FI_EH~'E AF;KNF~WLEDGE RETIIF,:N ONE SIGNED C-OPY OF THIS TR,-~NCMI'FTAL, ~OE/INI'ERHITTENT LIF'T '"='~' F F'.,'- ~ ,S'O'U'./PROD LOG & 'A' SAND F'BU SOE/F'BU (INITIAL F'RES~;URE) SOE/PBU £OE/PBU SOE/PBU ,?0IS/' C ' '~'-~"~' .. ., HH'-,' F'BU SOE/SBHP - 'A' & 'C' SANDS STATIC BHP DATA STATIC BHP DATA STATIC BHP DATA STATIC BHP DATA STATIC BHP DATA STATIC BHP DATA ~TATIC BHP DATA STATIC BHP DATA ~'f'ATIC BHP DATA ~TATIC BHP DATA ¢ *- ?IR DATA ~, T,~TIC r' STATIC BHP DATA STATIC BHP DATA STATIC BHP DATA STATIC BHp DATA ~TAT!C BHP DATA ~TAT~C BHP DATA ~TATIC BHF' DATA ~T~,TIC r~l-IP DATA ~TATIC BHP DATA ~'f'ATIC BI-IP DATA .... ~ M/~I SURVEY ~., RIBIITi0 DRILLIHG W. PA£HER L. .JOF~N2. TON EXXON MOBIL PHILLIPS OIL NSK CLERK J. RATHHELL ARCO ,Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 416-7/85 3/i i/85 '. ~./~.&/o,_, ~/2/85 -~/a/8~ ~/1 8/8~ t/24/85 t/24/8D, 5/~/85 ~/2/8~ ~/2/8~ S/2/8~ 9/o_, 3/t '"~'- S/2~/85 ~/24/~5 -'.'/'" 6 / ~5 ~ /,'~/o~. t/25/85 t/,~_~./SY t/~i '~'~ i/5'/8~:.,- i/ii '~ / b5 t / 2 4-/P ~';_, _ '- t /'--'J /'°-r4 i/'~ t/2O/85 RECEIVED APR 2 5 lS85 Alaslra 0~! & Gas___C0ns. Commission D A T E: Anch?_a~.e_ · · U i"~ I._,ri t"', K.TWLIN/VAULT ARcO Alaska, Inc."-" Post Office L,,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 NCr : . . I'".0., BOX iO() 6 A ? !C ~ !0 F:; A (:;, E, A K , 'T'F'f~ ~iF'r:;Fq,ll'i'H ARE: T C L. IE R K !) A 'T'r_] ·..¥;~ ..... i 0---8 .... I I',.,..,r~:2H]:'I"TAL. NO' ¢'1, ¢"~ i:' .,:. '," ; ,..'. I I'tr:' '::"-;' Il ¢"ll 11' NED COPY .... , .... ~ I i 0 P Y 0 Fl' .. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 3, 1985 Mr. C. V. Chatterton Commi s s ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2W-12 Dear Mr. Chatterton: Enclosed is a copy of the 2W-12 Well History (Completion Details) to include with the ~/ell Completion Report, dated 02/21/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L85 Enclosure RECEIVED Alaska Oil & 8as Cons. Commission ARCO Ataska, Inc. is a Subsidiary of AtlanticRichfieJdCompany ARCO Alaska, Irt"'-' Post Offic~ =ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ~ J '~;- STATE OF ALASKA '-', ~ ALASKA OIL AND GAS CONSERVATION C~,,vlMISSION WI=LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I SED OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 84-224 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21240 4. Location of well at surface 9. Unit or Lease Name 412' FNL, 235' FEL, Sec.33, T12N, R9E, UM Kuparuk River Unit 10. Well Number Alt]2o¢, Producing Interval FNL, 1233' FEL, Sec.28, T12N, RgE, UM 2W-12 At Total Depth 11. Field and Pool 1240' FNL, 1323' FEL, Sec.28, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 94' ADL 25642 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 1 2/23/84 1 2/29/84 1 2/30/84* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. D~ectional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8092'MD, 6313'TVD 7982'MD, 6221 'TVD YES I~ NO [] 1891 feet MD 1460' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CNL/Cal, Gyro (GCT), CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:: bZ.:~ H-",U Surf 90' 24" 337 sx CS I 9-5/8" 36.0# J-55 Surf 2720' 12-1/4" 610 sx AS Ill & 500 st Class G 7" 26.0# J-55 Surf 8065' 8-1/2" 925 sx Class G & 250 sx AS 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) Perforated w/12 spf, 120° phasing 3-1/2" 7689' 7670' & 7411' 7573 ' -7643 'MD 5888 ' -5943 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. Perforated w/4 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7758'-7808'MD 6036'-6077'TVD See attached AddenCum, dated 12/29/87, 7827'-7831'MD 6092'-6095'TVD for fracture Cata. 7840 ' -7848 'MD 6103 ' -6109 'TVD 7872'-7877'MD 6129'-6133'TVD 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED i* AR 2 Alaska Oil & Gas Cons. Commission *Note: Well was perforated and tubing ran on 1/31/85. Fractured well 6/10/85. Anchorage Submit in duplica~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30: ' . Li".,. . .i GEOLOGIC MARKERS - "--'. - ~ "FORMATION TESTS NAME include interval tested, pressure da~a, all fluids ~ecovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7565' 5881' N/A Base Upper Sand 7628' 5931' Top Lower Sand 7741' 6022' , ~i~., , Base Lower Sand 7906' 6157' : : · . . 31. LIST OF ATTACHMENTS Addendum (dated 12/29/87) 32. I hereby certify that the foregoing i's ~rue and correct to .the best of mY knowledge ~0 ~'~ ~L~L.~ Title Associate Engineer Date Signed // .. INSTRUCTIONS G~neral: 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, °bservation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none"'. Form 10-407 A D D~N D_U_M__ WELL: 6/10/85 2W-12 Frac Kuparuk "A" sand perfs 7758'-7808', 7827'-7831', 7840'-7848', and 7872'-7877' in 8 stages per procedure dated 6/3/85 as follows' Stage 1' 40 bbls 130° diesel w/5% j40 @ 5 BPM, 2230 psi Stage 2' 65 bbls gelled diesel @ 20 BPM, 3020 psi Stage 3: 5 bbls gelled diesel @ 20 BPM, 2920 psi Stage 4' 36 bbls gelled diesel @ .5# 100 mesh @ 20 BPM, 2920 psi Stage 5' 20 bbls gelled diesel @ 20 BPM, 2900 psi Stage 6' 27 bbls gelled diesel 3# 20/40 @ 20 BPM, 2820 psi Stage 7' 49 bbls gelled Oiesel 8# 20/40 @ 20 BPM, 2800- 3600 psi 73 bbls gelled diesel flush @ 20 BPM, 3600- Stage 8: 3200 psi LOad to recover: 298 bbls of gel Pumped 700# 100 mesh & 15,100# 20/40 sand in formation leaving .. zero in casing. - RECEIVED ., Alaska OiJ & Gas Cons. CommissJor~ Anchorage ARCO Alaska, Inc. Post Office ~"-'~360 Anchorage,/-,._,~ka 99510 Telephone 907 277 5637 RET~N TO: Date: 03/06/85 Transmittal No: **Page 1 of 2** 5077 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.~. Box 100360 . / ~chorage, AK ~9510 - /~ansmitted herewith are the following items. Please Wand return one signed copy of this transmittal. ¢ FINAL PRINTS OPEN HOLE (Onesepia of each) Blueline Schlumberger acknowledge receipt lQ-12 2'I 211 11 11 .. DIL/SFL-GR 12/25/84 DIL/SFL-GR 12/25/84 Density/Neutron 12/2~/84 (Porosity) Density/Neutron 12/25/84 (Porosity) Density/Neutron 12/25/84 (Raw Data) Density/Neutron 12/25/84 (Raw Data) Cyberlook 12/25/84 · .. 511 2" 5" 2" 5!1 DIL/SFL-GR Density/Neutron-GR Density/Neutron-GR Density/Neutron-GR Density/Neutron-Gr Cyberlook 12/29/84 12/29/84 12/29/84 12729/84 12/29/84 12/29/84 12/29/84 Run #1 3570-6992 Run #1 3570-6992 Run #1 5570-6966 Run #1 5570-6966 Run #1 5570-6966 Run #1 5570-6966 Run #1 6450-6950 Ru~ #1 '2717-8038 ~n #1 2717-8038 Run #1 2717-8012 Run #1 2717-8012 Run #1 2717-8012 Run #1 2717-8012 Run #1 7450-7950 (Raw Data) (Raw Data) (porosity) (Porosity) 2C-15 2" DIL/SFL 5" DIL/SFL 2" Density/NeUtron-GR 5" Density/Neutron-GR Receipt Acknowledged: B. Currier BPAE 12/30/84 Run #1 12/30/a5 Run #1 12/30/$4 Run #1 12/30/84 Run #1 **CONTINUED** DISTRIBUTION Drilling W, Geolog~L.Johnston Exxon 3154-7154 3154-7154 6545-7129 ~w Dat~) . Date: · ..... ~ .:" -':- , .- .-,."~ Pasher State Sohio Chevron Mobil Phillips Oil Union D &M NSK Drill Clerk J. Rathmell K. Tulin/Vault ARCO Alaska. Inc. is a subsidiary ol AllanticRichlieldComo-nv ARCO Alaska, Inc. Post Office B~.,~ 360 Anchorage, ~ ka 99510 Telephone 907 277 5637 RETUP~N TO: Date:03/06/85 Transmittal No:5077 **Page 2 of 2*** ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 _/chorage, ~ 99510 - 7~ansmitted herewith are the following items. !/~nd return one signed copy of this transmittal. FINAL PRINTS OPEN HOLE (One Sepia. Blueline Schlumberger 2C-15-LCONTIN~ED from previous page. 2" Density/Neutron-GR 12/30/84 Run #1 5" Density/Neutron-GR 12/30/84 Run #1 5" Cyberlook 12/30/84 Run #1 of each) Please acknowledge receipt 6545-7129 (Porosity) 6545-7129 (Porosity) 6545-7114 2C-16 1! 5'Y 2" 5tt 2" 5!t 5t! DIL/SFL-GR 12/22/84 Run #1 DIL/SFL-GR 12/22/84 Run #1 Density/Neutron-GR 12/22/84 Run #1 Density/Neutron-GR 12/22/84 Run #1 Density/Neutron-GR 12/22/84 Run #1 Density/Neutron-GR 12/22/84 Run #1 Cyberlook 12/22/84 Run #1 3853-8392 3853-8392 3853-8392 (Raw Data) 3853-8392 (Raw Data) 7650-8392 (Porosity) 7650-8392 (Porosity) 7850-8320 RE-10 - 5'! Cyberlook 12/28/84 Run #1 2" DIL/SFL-GR 12/28/84 -Run'#1 5" DIL/SFL-GR 12/28/84 'Run #1 2" Density/Neutron 12/28/84 Run #1 5" Density/Neutron 12/28/84 Run #1 2" Density/Neutron 12/28/84 Run #1 ~" Density/Neutron 12/28/84 Run #1 6090-6605 3306-6652 3306-6652 6100-6623 (Raw Data) 6100-6623 (Raw Data) 6090-6623 (Porosity) 6090-6623 (Porosity) Receipt Acknowledged: B. Currier BPAE Chevron D &M DISTRIBUTION Drilling W. Pasher Geolog~L.Johnston Exxon Sohio Mobil Phillips Oil Union NSK Drill Clerk J. Rathmell K. Tulin/Vault · ARCO Alaska, Inc. is a subsidiary of AllanlicRIchfieldCompany ARCO Alaska, Inc. Post Office B~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 21, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2W-12 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic the subject well. I have not received the portion of Well History covering the completion details. When I forward a copy to you. survey for the 2W-12 do, I will If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L182 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /.-.,.-._ STATE OF ALASKA ~ ALASKAL .AND GAS CONSERVATION CO AISSION - COMPLETION OR RECOMP'LETION REPORT AND LOO Classification of Service Well 1. Status of Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-224 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21240 4. Location of well at surface 9. Unit or Lease Name . Kuparuk River Unit 412 FNL, 235' FEL, Sec.33, T12N, R9E, UM ~rL©CATI©NSt 10. Well Number At Top Producing Interval I VE~-dFiED 1529' FNL, 1233' FEL, Sec.28, T12N, RgE, UM ISurf' ~--~i 2W-12 At Total Depth 3. H. ~,~ ~ 11. Field and Pool 1240' FNL, 1323' FEL, Sec.28, T12N, R9E, UM , · .. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 94' RKB ADL 25642 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 2/23/84 1 2/29/84 1 2/30/84* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey [ 20. Depth where SSSV set I 21.Thickness of Permafrost 8092'MD,6313'TVD 7982'MD,6221 'TVD YES [~X NO [] 1891 feet MD 1460' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 90' 24" 337 sx CS I 9-5/8" 36.0# J-55 Surf 2720' 12-1/4" 610 sx AS Ill & 500 sx Class G 7" 26.0# J-55 Surf 8065' 8-1/2" 925 sx Class G & 250 s; AS 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) 7872' - 7877' 7573'-7643' 3-1/2" 7689' 7670' & 7411 7840, - 7848, 7827'-7831' w/12 spf, ,. 7827' - 7831 ' 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7798' - 7808' ' w/4 spf, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7778' - 7799' 120° phasing N/A 7758' - 7779' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Alaska Oil & Gas Cons. Anchorage "ommtSSion Form 10407 Rev. 7-1-80 * Well was perforated and tubing ran on 01/31/85. GRU4/WC41 CONTINUED ON REVERSE SIDE Submit in duplicate NAME Include inte~al test~, pressure data, all fluids r~over~ and gravity, MEAS. DEPTH TRUE VERT~ DE~T~H ~:,. GOR, and time 0Leach phase. : ~ ? - .... .- ' Top Upper Sand 7565~' .~ 5881~ N/A ' Top Lower Sand :) :-77~1~ ' 6022~ - ..... ........ ....... ......... '31.-LIST OF A~ACHMENTS ' " - '- · ' ..... Signed ~0/~/-, . . Title Associate EngineeF Date INSTRUCTIONS General; This form is designed for.submitting a complete and correct well completion report and log on all types of lanSs an~l leases in AlaSka. Item 1' Classifica.tion 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 '. Iqdicate-whether from ground level (G L) 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". . · ARCO Oil and Gas Company Daily Well History-Final Report fnslructfons: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is ~vailable. District IC°unty or Parish I Alaska Field lLease or Unit I Kuparuk River Auth. or W.O. no. JTitle I AFE 203653 North Slope Borough ADL 25642 JAccounting coat center code State Alaska IWell no, 2W-12 Completion Roll'N #4 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. Complete A.R.Co. Date record for each day reported API 50-029-21240 W.I. rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well I IH°ur I Prior status if a W.O, 1/29/85 / 0500 hrs. I / Old TD Released rig 1/29/85 1/30/85 1/31/85 2/01/85 7 @ 8065' ~g 7982' PBTD, 8092' TD, Fill pits w/brine ~ 10.2 ppg NaC1/NaBr ¥(~,~ Accept ri~ @ 0500 hrs, 1/29/85. ND tree. ~/~. 7982' PBTD, 8092' TD, Prep to RIH w/FB-1 pkr '~, ~, , 10.2 ppg NaCl/NaBr ' ';'~ ' RU ~, perf w/4" csg guns, 4 SPF, 120° phasing f/7872'-7877', 7840'-7848', 7827'-7831', 7758'-7808'. Perf w/5" csg guns, 12 SPF, 120° phasing f/7573'-7643'. Rn 6.125" gage ring/JB to 7780'. MU Bkr FB-1 pkr & tailpipe assy. 7" @ 8065' 7982' PBTD, 8092' TD, Displ'g w/crude oil 7.2 Crude oil Set WL pkr & tailpipe (top of pkr @ 7670'). Rn 3½", 9.3#, J-55 IPC 8RD EUE tbg. Set pkr. Sheared SBR, set BPV. ND BOP, NU & tst tree. Displ well w/crude. 7" @ 8065' 7982' PBTD, 8092' TD, RR 7.2 crude oil Cont displ'g to crude. Test SSSV; could not get tst on orifice vlv. Sheared ball & set BPV. RR @ 1300 hrs, 1/31/85. TT @ 7689' - "D" Nipple @ 7685', FB-1Pkr @ 7670' 1300 hrs. Classifications (oil, gas, etc.) Oil JNew TD I PB Depth 8092' 7982' PBTD JDate Kind of rig 1/31/85 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing 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 I The above is correct Signature j Date JTitle ~,2~ ~.~ 2125/85 For form preparatio~ and distribul~on, ' see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent "ARCOOil~andGasCompany ,~ Well History- Initial Report - Dally Prelate and 9ubmtt the "!Mli!I~ _Rq~rt" on the first WednesdaY after a well is spudded or workover operations are star,ed. Dally wo~ I~Or to a~.l~~d-be ~ummarlzed on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 203653 Parker 141 ICounty, pariah or borough North Slope Borough ILeaes or Unit ADL 25642 ITItle Drill & Perforate Complete IState Alaska JWell no. 2W-12 API 50-029-21240 Operator IARCO W.I- ARCO Alaska, Inc. Spudded or W.O. bagUnspudded IDa' 12/23/84 IH°ur 2300 hrs IPri°rstatusilaW'O' Date and depth aa of 8:00 a.m. 12/26/84 12/27/84 12/28/84 thru 12/30/84 Complete record for each day reported 56.24% 9-5/8" @ 2720' 3767', (3677'), Winterize BOPE Wt. 8.4, PV 2, YP 2, PH 8, WL 30+, Sol 1 Accept ri~ @ 1700 hrs, 12/23/84. NU Hydrl & diverter lns. Spud well @ 2300 hrs, 12/23/84. Drl, DD & surv 12¼" hole to 3767', circ hole, POH. RU & rn 68 its, 9-5/8" csg to 2735', stopped on ledge. Circ & att to wrk csg. Hang off 9-5/8" csg on fluted hgt. Pmp 610 sx AS III w/1/2#/sx D-29. Pmp 500 sx Cl "G" w/2% S-1 & .2%'D-46. Displ w/195 bbls mud, bump plug. Circ 70 bbls cmt to surf. ND 20" Hydrl, NU & tst BOPE. 864' 3.4° N21.5W, 863.95 TVD, 3.36 VS, 3.15N, 1.24W 14041 19 ;o N13.5W, 1390.82 TVD, 113.86 VS 111.99N 21.46W 1867', 32.5°, N13W, 1809.14 TVD, 309.36 VS, 301.63N, 69.00W 2690', 47.2°, N8.5W, 2415.42 TVD, 860.70 VS, 845.13N, 166.00W 3631', 44.2°, N10W, 3068.21TVD, 1524.79 VS, 1515.60N, 261.91W 9-5/8" @ 2720' 5620', (1853'), Drlg Wt. 9.3, PV 11, YP 12, PH 10, WL 9.8, Sol 7.3 RIH w/BHA to 2635', tst csg to 1500 psi. DO cmt & flt equipment. Conduct leak-off tst to 11.9 ppg EMW. Drl & surv 8½" hole to 5620'. 3927',-44.1°, N9.5W, 3280.60 TVD, 1740.42 VS, 1718.90N, 296.83W 4279', 45.5°, N10.5W, 3530.97 TVD, 1987.23 VS, 1962.50N, 339.53W 4713', 46.3°, N12.5W, 3833.07 TVD, 229~.5~ VS, 2267.86N, 401.47W 5026', 46°, N14.5W, 4049.91TVD, 2524.24 VS, 2487.35N, 454.16W 9-5/8" @ 2720' 7680', (2060'), Drlg Wt. 10.3+, PV 15, YP 8, PH 9.5, WL 6.6, Sol 13 Drl & surv 8½" hole to 7420', POH, chg BHA. RIH, break circ @ 4000', wsh & rm 60' to btm, drl to 7420' 5560', 44.9°, N18.5W, 4424.53 TVD, 2904.41VS, 2852.23N, 562.24W 6063', 44.2°,-N20W, 4782.99 TVD, 3255.76 VS, 3185.37N, 681.58W 6562', 43.5°, N21W, 5142.85 TVD, 3599.18 VS, 3509.17N, 802.64W 7062', 41.8°, N22W, 5510.60 TVD, 3934.99 VS, 3824.36N, 926.80W 7345', 40.3°, N20W, 5724.02 TVD, 4119.43 VS, 3997.87N, 993.40W RECEIVED FEB 2 2 1985 OH & Gas Cons. Commission Anchorage The above is correct Signature ,/~ For form prepm'atl0~]~rand ~ist~'-butlon, see Procedures Mmfual, Section 10, Drilling, Pages 86 and 87. Date 1/08/84 Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Fie~d Kuparuk River Auth. or W.O. no. AFE 203653 Parker 141 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. Old TD 12/31/84 Released rig County or Parish Lease or Unit Tte Accounting cost center code State North SloPe Borough Alaska ADL 25642 Drill, Complete & Perforate API 50-029-21240 IA.R.Co. W.I. 56.24% IOate 12/23/84 Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 2300 hrs JWell no. 2W-12 7" @ 8065' 7982' PBTD, RR Brine Drl 8½" hole to 8055', 10 std short trip, C&C, POH. RU Schl, att to log triple combo; unable to get tls below 7039', POH, RD Schl. RIH, drl to 8060', circ & sweep hole w/hi-vis pill & Lube 106 pill, POH. RU Schl, rn triple combo to 8042'. Drl to 8092', circ & sweep hole w/hi vis pill & Lube 106 pill, pull 20 ~t~s. Chg rams to 7" & tst. RU & rn 201 jts, 7", 26#, J-55 butt csg to 8065', C&C. Cmt w/550 sx Cl "G" w/1.5% D-79, 1.2% D-112, .5% D-65, .2% D-46 & .25% D-13, followed w/375 sx Cl "G" w/3% KCl, .8% D-60 & .2% D-46. Displ w/295 bbls brine, bump plug. Chg top rams to 5", blow brine out of 7" to 120' RKB. ND BOPE, NU wellhead & pack-off, tst pack-off to 3000 psi. RR @ 2300 hrs, 12/23/84. Arctic Pak w/250 sx AS I, followed w/55 bbls Arctic Pak. New TD PB Depth Knd of rg 7982' PBTD Date Rotary Classifications {oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data IWell no. Date Reservoir Producing Interval Oil or gas Test time Production t' !il~n ~t E i a Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity A)lo. wable E)fective date c ..... ted '~ 2 ~ 19B5 The above iS correct Signature I Date ITitle ~'_J~,Y' _ _~_-~_ -Y.,.,¢./· 1/08 / 85 Drilling Superintendent For form preparation and ~llstribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. SUB-SURFACE DIRECTIONAL SURVEY F-~ UIDANCE ~-~ONTINUOUS ~"~ CO l COmpany ATLANTIC RICHFIELD COMPANY Well Name- Field/Location 2W-12 (412'- FNL, 235' FE-L, S33~ T12N, R9E~ UM) KUPARUK. NORTH SLOP[, ALASKA Job Reference No. 69993 Lo{313ed By: MURTLAND RECEIVED FEB 2 2 Date 22- J AN- 1985 Computed By: Alaska 0ii & 6as Cons, Commission Anch0ra,q~ STEVENS GCT OIRECTIONAL SURVEY CUSTONER LISTING ARCO ALASKA~ INC. ZW-lZ KUPARUK NORTH SLOPE, ALASKA SURVEY DATE:; 3-JAN-B5 ENGINEER: MURTLANO NETHODS OF COMPUTATION TOQL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH IN'TERPOLAT~ON: LINEAR VERTICAL SECTION: HQR~Z. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH IRCO ALASKAp INC. !W-12 C UP AR UK IORTH SLOPEr ALASKA COMPUTATION DATE: 22,-JAN-aS TRUE SUB-SEA COURSE ~ASUREO VERTICAL VERTICAL OEVIATION AZ[HUTH DEPTH DEPTH OEP'TH ,DEG H[N DE,G 0.00 100.00 200000 300.00 ~00.00 500.00 600o00 700.00 800.00 900°00 DATE OF KELL~ BUS'H[NG ELEVATION:/ ENGINEER: HURTLAND [NTERPOLATED VALUES FOR EVEN 100 FE~T OF ,MEASUREO DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECT[ON SEVERITY NORTH/SOUTH EAST~'WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET, .,DEG 0.00 -94.00. O 0 N 0 0 E 100..00 6.00,~ 0 21 N 60 30 W 200.00 [06.00 0 27 S 6¢ 3 ii 300..00 206.00. 0 15 N 60 5 W 399.99 3'05.g9 0 2~ S 67 ~5 W ¢99.99 ~05.99 0 20 N ~8 37 W 599.99 505.9'9 0 18 S 73 11 W 699.99 605099 0 33 N 48 45 W 799.94 705.9~ 3 0 N 18 15 ii 899.73 805.73 4 50 N 16 52 W 0.00 0o00 0.05 0.39 0.16 0.08 0.40 0.¢2 0.76, 0.¢7 0.25 .0.75 0.34 1.1.6 0.63 3.80 1.8.2 10.20 ~.26 LO00.O0 998.95 90~.95 ,8 56 LIO0.O0 1097.28 10,0 3.28 11 54 LZO0.O0 1194.47 1100.47 15 6 1300.00 1290.46 1196.46 17 18 1.600.00 1385.36 1291.36 19 26 [500000 14.79.03 1385.03 21 37 L600.00 1571.25 14.77.25 23 55 170'0000 1661.37 1567.37 27 34 1800.00 174.8.52 1656052 30 59 1900.00 1832.71 1738071 34, 6 N 12 12 W 22.4'7 3.~1 N 7 19 ~ ¢0.$4 3.06 N 3 58 '~ 6.3.75 3.00 N 7 10 W 91046 2.25 N 11 27 W 122.83 2.57 N 1¢ ~ W 15'7.85 1.'99 N 13 19 'ii 196.17 3.17 N 9 25 ~ 239.'70 N 9 1[ ~ 288.53 3.06 N 10 25 ~ 3~Z.32 2.23 N 9 20 W N 8 49 d N 82'7 N 7 51 ~ N 7 b N .6 47 N 6 37 ~ N 6 37 W 0.00 N 0.0,0 0.05 N 0.01 0.03 S 0.79 0.23 S 1.26 O. 02 S 1.84 0.08 S 2.31 0.05 N 2093 0.,35 N 3.41 2.77' N 6.,61 8.8.9 N 6.5,3 94* 0.00 FT' Z000o00 1916.26 1820.26 36 44 2100o00 1992.87 1898.87 39 31 Z20000.0 Z068.52 1974.52 42 17 2300000 2140.71 2046.71 45 12 7400..00 2209.39 2115.39 ~7 30 ZSO0.O0 2276.77 2182o77 47 41 Z600.00 234.4.25 2250.28 ~7 24 Z700000 2412.12 2316.12 47 Z800.00 2480.32 2386.32 46 0.7.,9': ,::": ",' S, 8 l' 5,8; W !.,28 S 1'9 4,4 :W ~..8~ S 8'~,' 20' ~ 2°32 S 67 53 W, 2.93' N 89, 0 ii 3.4*2 N 84 ii U 5.,37' N 58 59. I~, ') '11.0Z N 36. IT" W 400.07 2.65 461..69 2.83 52~.a5 3.33 595.73 3.03 668.03 0. ?3 76L .46 0.65 c%14.67 0.37 887.56 0.37 960.08 0.22 2900.00 2548.79 24.56.79 46 45 3000.00 2617.46 2523.~,6 46 11 3100.00 2686.59 2592.59 46 18 3200.00 2755.66 2661.66 4,6 15 3300.0,0 2824.96 2730.96 4.6 6 3400.00 2894.58 2800.58 ' 45 31 3500000 2965.03 2871.03 44 52 3600000 3036.23 294,2.23 4,6 17 3700000 3107.95 3013.95 44 1 3800.00 3179.86 3085.86 44 5 3900000 3251.60 3157060 44 16 N 6 4:6 W 1032.40 0.25 0 0.50 0.91 0.21 1.00 0.68 0.71 0.33 0 047 0 20.76 N 9.64 W 38.66 N 12.62 W 62.03 N 89.95 N 121. O0 N. 155.13 N 1 92.57 N 235.04 N 283,65 N 336.60 N Z2.88 N 24 56 W 40.65 N la 4 W 14.70 W 63.75, N I'3 19 W 17.28 W 91.59 N 10 52 W , 22.40 W 123.05 N 10 29 W 30.26 W 158.05 N 11 '2 W 39'72 a 196.63 N 11 39 · ~8.10 ~ 239.91 N 1[ ~3 H 55.72 ~ 2880.87 N 1[ 7 a · 54.88 ~ 362.80 N 10 54 H 393.49 N 75.42' W 400.65 ,N 10 .-51W 4.54.40 N ~35.81 W 462.43 N, lO 41 W 518.98,N 96.11 W 527.80 N 10 29 W 587.36 N 106'52 W 596,,,,94 N 10 16 W 659.30 N 116.81 W 6'69.51' ,N 10. 2 W 732.58 N 126.32 W 743039 N 9 47 W 805.81 N 135.25 W 817.,0~ N 9. 31 W 878.78 N ~e3.83 W 890.¢7 N 9 17 W W 963052 N 9 S I,.)' 951.42 152.22 1023.81 N. 160.76 W 1036..36 N 8 55 W 1095.99 ¼ 169.33 W 1109100 I% 8, 46 W 1167.75 N 177.84 Ii:1181.21 N 8 39 W,' 1239.53 N 186.65 W 1253.,5~ N a 33 W 1311.03 N 195.89 W 1325.,58 N 8 29 'W 1382.18, N 205.35 W 1397.3~ N a' 27 W. 1452.48 N 215.10 W 1668.32 N q 25 W 1521.98 N 225.1.5 W 1538.5~ N a 24~ W 1590.92 1~ 235.28 W 1608023 N 8 Z4 W 1659.61 N 245.74 W 1677.71 N 8 Z5 W, 1728.42 N 256,76 W 1747.38 'N ~ 16 W COMPUTATION DATE: 2Z-JAN-85 ARCO ALASKA, :[.NC0 2id-12 KUPARUK NORTH SLOPEr ALASKA DATE OF &URV~:¥: 3-JAN'-85 KELLY' t3USH.[NG ELEVATIOhi: ENGINEER: HURTLAND INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SU~-SEA COURSE EASURED VERTZCAL VERTICAL DEVZATIDN AZIHUTH DEPTH DEPTH DEPTH DEG MIN DEG PA~,E Z 4000.00 332.3.05 3229.05 44 32 4100.0,0 3394.19 3300.19 44 42 4200.00 3465.12 3371.12 45 2 4300.00 3535.43 344,1.43 45 36 ¢40,0.00 36,05.40 3511.40 4.5 33 4500.00 3675.29 3581.29' 45 46 4600.00 3744.83 36:50.83 46 6 4700.00 3814.03 3720.03 4,6 18 4800,.00 3883.09 3789.09 46 19 4900.00 3952.21 3858.2.1 46 12 94.00 FT 5000.00 4021.52 3927.52 46 4 5100.00 4091o03 3997.03 45 48 5200.00 4160.85 4066.85 45 35 5300.00 4231.03 4137.03' 45 16 5400.00 ~301.45 4207.45 45 11 5500.00 4372.02 4278.02 45, 4 5600.00 4442.70 43480'70 4,4 59 5700.00 4513.40 4419.40 45 2 5800000 4584.06 4490.06 44 5~ 5900.00 4,654.90 4560.90 44 48 VERTICAL DOGLEG RECTANGULAR COORDINATES HORiZ- DEPARTURE,' SECTION SE'VEi~TTY,NORTH/SOUTH EAST/blEST DIS1'., AZIMUTH F~ET DEG/IOO FEET FEET FEET DEG H~N 6000.00 4726.00 ,4632.00 44 31 6100.00 ~.797.35 4703.35 6200.00. 4868.75 4774.75 44 19 6300.00 6940.41 4866.41 44 1 6400,000 5012.45 4918.45 43 45 6500.00 5084.79 4990.79 43 34 6600.00 5157.34 5063.34 43 16 6700.00 5230.37 5136.37 43 6800.00 5303.57 520 9..~7 42 44 6900.00 5377.14 5283.16 42 28 N 9 17 W 18,09.09 N 9 21 W 1879.16 N 10 6 W 1949.44 N 12 4 W 2020.47 N 13 43 W Z091.89 N 13 59 W 2163.41 N 14 12 id 2g35o28 N 14 34 ~ 2307.46 N 14 4~ ~ 2379.78 N 14 53 bl 245Z.04 .N 15 ~ bl 2524.11 N 15 33 d 2595.98 N 15 59 ~ 2667.53 N 1,6 25 ~ 2738.72 N 16 48 ~ 2609.63 N 17 5 bl 2480.39 hi 17 31 ~ 2951.01 N ~7 54 id 3021058 N 18 15, ~ 3092.15 N 18 31 bl 3162.51 18 43 ~ 32.32.60 18 55 id 3301.½1 19 10 id 3372.14, 19 30 hi 19 4.3 id 3510.59 19 4~ W 3579.28 19 ~3 ~ 19 51 W 3715.70 ZO 5 ~ 3783.~5 2'0 21 d 3450.77 7000.00 5451.16 5357.16 42 O' N 2.0 32 W 3917.58 7100.00 5525.67 5431067 41 38 N ZO 54, W 3983.81 7200.00 5600.73 5506.73 41 1 7300.00 5676.58 5582.58 40 7400.00 5753.01 5659.01 39 51 7500.00 5830.44 5736.44 38 40 7600.00 5908.87 5814,.87 37 7700.00 5988.45 5894.45 36 27 7800.00 6069.55 5975.55 35 10 7900000 6152.16 6058.16 33 33 N 21 5 ~ 4049.36 N 21 21 id 4114.01 N 21 9 id 4177.95 N 18 33 bl 4240.48 N 17 55 id 43,02.75 N 17 51 W 4363.17 N 17 49 ~ 4~21.53 N 16 58 W 4477.77 0.53 0.10 1.05 0054 .0.37 0.38 0.25 0.12 0.36 1797.46 N 267.9:~,~ W 1817.32,: #~ ii 28. bi 1866.82 N 279.38 ki 1887.&,1.' '# 8, 30 bi 19,3,6.34 N 291.00 W 1958.,,0:~: N 8 32- W Z006.0~ N 304.95 W 2029.1~, :N a 38 W Z075.69 N 320.91 ~ Z100.36~, N 8 ~7 ~, 2145.12 N 338.10 ~ 2171.60 N: 8 5~ ~ 221~.82 N 355.59 ~ Z243,I8 N 9 ~ W 228~.7, N 373.55. ~ 2315.,,07 ~ 9, 17 ~ 2354,.69 N 39.1.95 ~ 2387.D8 N 9 Z.7 k ) · Z&Z4.5~ N 410.45 ~ 2~59.,0~ N 9 36 ~ 0.14 0.53 0.37 0.47 0.20 0.34 0.3,3 0.51 0.26 24'94.17 N 4,29.11 W 2530.~8I ,N '9 45 W 2563.51 N 448.09 W 2602.38 N 9 2632.3'9 N. 467.54 bi 2673.6.0 N 10 4 id 270'0.81 N 447,.45 bi 2744'45 N, 10 13 2768.84 N 507.7~ W 2,815,01 N 10 23 2836.6~ N 528.43 W 28~5.41 N 10 33 0 0.1'9 0090 '0.85 0.80 O.ZZ 1.01 0.26 0.27 0.22 3172.40 N 637.67 bl 3235.,45 N 3238.71 hi 660.29 W 3305..33 ,N I,L 31 3304.88 N 683.15 ,id 337:4..15 3370.70 N 706.2-5 bi 3443.89 N 11 50 ¼- 3436002 hi 729.5.5 bi 3512.62 3500.99 N 7:i1.93 Id. 3581.04 N 12 8 3565.76 N 776.18 id 364,9.26 N 12 16 id 3630.03 N 799.34 id 3716'99 3694.06 N 822.61 Id 3784.55 3757.61 hi 846.05 bi 3851.68 N 12 41' Id, 0.34 3820.62 At 859.5.'2 bl 3918.32 N 12 49 Id 0.59 3883.01 N 893.10 bi 39,:1:14.39 N: 12 53' Id 0.74 3944066 N 916.83 W 4049.81 N I3 5, W 0.50 4005.43 N 940.38 W 4114.34 N 1'3 12 id 1.38 4065.46 N 963.93 id 4178017 N 13 ZO bl 1.52 4124.95 N 985.44 bi 4241.04 N 1'3 26 bi 1.21 4183.93 N 1004.Z0 bi 4302.87 .N:13 30 bl 1.73 4241.57 N 1023.28 , 4363.26 N I3 33 bi' 1.85 4297.25 N 10~1.19 b 4421.59 N 13 3~' ~ 1.85 4350.94 N 1058.19 ~ 4477.8~ N 13 40 ~ iRCO ALASKA~ INC.. :.U P A R U K iORTH SLOPE~ ALASKA C:~MPU'TATION DATE: 22--JAN-SS DATE OF .SURVEY: 3-JA~-.a.5 KELLt' BUSHINg ELEVAT~EDN:* Et~GINEER:* MUR~LANO ~ERPOLATED VALUES FOR E~E~ ~00 FE~T OF ~EASU,~ED DEPTH TRUE SUB-SEA .Ci3.URSE VERT,[CAL DOGLEG RECTANGULAR COORDINATES H.O.R~Z,,,. .DE. PA:.RTURE !ASURED VERTICAL VERTICAL DEVIATION AZ~HU'TH SECTION SEVERITY NORTH/SOUTH EAST/BEST DZ,ST' ~',Z'ZNUTH DEPTH DEPTH DEPTH 'DEG MZ.N DEG M~N F~ET OEG/IO,O FEET FEET FEET DE"G ~Z, IO00. O0 6235.89 61al.89. 33 2 N ~6 9 ~ ~532.,39 O.OO ~03.~,5 N 10Z3,55 ~ 1092.00 6313.00 '6Z19..00 33 2 N 16 9 ~ ~58Z.SZ 0.00, ~5,1.6~ N 10a7,51 ~ ~582.5;'~ ~3, , , . ARCO ALASka, 1NC,. ZW-12 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 22-JAN-a5 PAGE DATE OF SURVEY: 3-J, AN-,'S5 KELLY aUSHING ELEVATION: 94,.0:0 FT" 0.00 0.00 -94°00 0 0 1000°00 998.9.5 904.95 8 56 2000°00 1914.26 182 0,,26 36 46 3000.00 2617.46 2523°66 4.6 4000°00 3323.05 322 9,. 05. 44. 32 5000,,00 6021°52 3927.$2 66 6000°00 ~726.00 4632°00 44 31 7000.00 5451.16 5357.16 62 0 80~00°00' 6235o89 6141.89 33 2 8092.00 6313.00 6219o00 33 2 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUa-SEA COURSE IEASURED VERTICAL VERTICAL DEVI,ATXDN AZXMU'TH DEPTH OEPTH DEPTH OEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HBRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST., AZIMUTH FEET DEG/XO0 FEET FEET FEET DEG N 0 0 E 0.00 N 12 12 W 22.47 N 10 3 W 400.07 N 6 40 W 1106.52 N 9 1'7 W 1.809.09 N 15 7 W 2526°11 N 18 43 W 3232-60 N ZO 32 W 3917.$8 N 16 9 W 4532.39 N 16 9 W 4582.52 2.65 0.95 0.53 0.16 0.26 0.00 0.00 0o00 N 0o00 E 0..00:' ~N 0 0 E 20.76 N 9.6"6 W ?.2°8&':':#', 24 .56 W 393.49 ~ 75.62 W' 600',65 1['10 51. W 1095.99 N 169.33 W 1109,,.0~ ,:/Ii'8" 66 W 1797.46 N 267o95 W 1817.32 ::N ~3 28 W 2694.17 N 429.11 W 2530,82 N 9 45~ W 3172.4,0 N 637.67 W 3235-85 N 11~~ 21, W 3820o62 N 86,9..52 W 3918..32 4,603°65 ti 1'073.55 W 6532°62 6451.66 N 1097.51 W 6582.55 N 13,63 W ENGINEER: MURTLAND ARCO ALAS&A· INC. 2W-12 KUPARUK NORTH SLOPE· ALASKA COMPUTATION DATE: II-JAN-SS TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG PAGE DATE OF SURVEY: 3.-J,AN'-85 KELLY BUSHING ELEVATION:: ENGINEER::' HURTLAND INTERPOLATEO 'VALUES FOR EVEN 100 FEET DF SUB-SEA OEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. O'EPARTUR:£ SECTION SEVERITY NORTH/SOU'TH EAST/WEST DZST, ~ZIMUTH 0.00 0.,00 94000 94.00 194o00 194.00 100.0,0 294.00 294.00 ZOO.O0 394.01 394000 300°00 494o01 494.00 400.00 594.01, 594.00 500.00 694.01 694.00 600.00 794.05 794.00 700.00 894°25 894.00 800.00 FEET OEG/LO0 FEET FEET FEET DEG I~:ZN -94.00 o o 0.00 · 021 N 0 0 E 0.00 0.00 0.00 ~ 0.00 E N 60 42 W O.OZ 0.21 0.03 N: O.OZ E 0 27 $ 67 1 W 0.17 004:5 0.01 S 0.74 d 0 13 N. 64 29 W 0.06 0.52 0.24 S 1.23 W 0 25 $ 73 25 WI 0043 0.75 ~0,.01 S 1.80 Wi 0 19 N 49 2 W 0.45 0.26 '0"*1I S 2.2'9 W O 19 S 71 2 W 0.76 0.45: 0..06 N 2..90 W 0 31 N 47 33 W 1.12 0.7.8 0.31 N 3.36 W Z 53 N 19 1 W 3.49 Z.35 2.48 N 4.51 W 4 36 N 16 58 Ill' 9.73 3.90 8.44 N 6.39 W N 12 3?. w 21.69, 3°57 ZO.O0 N 7 29 W 39.86 2.76 37.96 N 3 58 W 63.62. 3.01 61'90 N 7 1'9 W 92.56 2.27 91004 N 11 ,47 W 125.89 2.29 12.4.00 N 14 16 W 163.84 2.10 16,0.94 N 12 18 W 206.69 4.24 202.,54 N 8 49 d 252.17 3.12 252.35 N 9 45 W 316.63 3.92 311.26 N 10 20 W 385.18 2090 3'78-80 N 9 20 w 462.61 N 8 41 W 550.42 N 7 59 W1 651o34 N 7 0 W 76002.2 )4 6 41 W a68.2o N 6 ~0 ~ 97~. 56 N 6 ~4 W 1080.12 N 6 52 W 1183.90 N 7 20 ~ 1287.69 N 7 ~Z ~ 1390.38 N 8 12 W 1490.12 N 8 23 W 1587".36 N 9 0 W 1663.61 N 9 12 W 1780.68 N 9 Zl W laTa. 98 N 11 13 W 1978.42 N 13 30 W 208002-8 N 14 3 W 2182.67 N 14 28 W 22.86.49 N 14 49 W 2391.Z0 994.99 994.00 900.00 8 47 1096.65 1094.00 1000.00 11 49 1199051 1194.00 110000,0 15 5 13.03.71 1294.00 12.00.00 17 22 1409.16 1394.00 130 O. 0,0 19 36 1516013 1,494.00 1400.0,0 21 58 1624.94 1594.00 1500o00 24 43 1737o04 1694.00 1600. O0 28 57 1853.51 1794.00 170 0,. O0 32 47 1974.83 1894.00 1800000 3:6 3 2101.46 1994..00 1900.00 39 33 2234.78 2094.00 2000.00 43 18 2377.23 2194.00 2100000 47 18 2525.58 2294000 2200.00 47 36 2673.37 Z394.00 2300000 47 11 2820.00 2494.00 2400.00 46 50 2966.01 2594.00 2500.0.0 46 33 3110.72 2694.'00 2600000 46 17 3255.38 2794.00 2700.00 46 3399.17 2894.00 2800.00 45 32 3540.80 2994.00 2900.00 44 39 3680.61 3094.00 3000.00 44 7 3819.69 3194.00 3100.00 44 3959.29 3294.00 3200.00 44 23 4099.74 3394.00 3300.00 44 42 4240°95 3494.00 3400.00 45 15 4383.72 3594.00 3500.00 45 32 4526.85 3694.00 3600.00 45 51 4671.00 3794.00 3?00.00 46 15 4815.79 3894.00 3800.00 46 18 2.86 2- .71 1.47 0.71 0.64 0.25 1.26 0 · 40 0.66 1.02 0.93 0.30 0.14 0o10 1.64 1.05 0.30 0.41 0.09 9*47 W 22.I, 3 N 2i' 20 W 12.53 W 39.97' N 18 15 W 14.69 W, 63.62 ,N, 13 20' W 17.4'2. W 92,.69' N 10 49 W' , Z3.0Z W 126..12 N lO 3I W 31.73 M 16401:)4 N 11 9 W 42.02 W 20608.5 'N i1 50.85 W 257.42 N i~1 23 lil 60.36 W 317-06 N 10 72.*/8 W 3850,73 N 10 52 W 455.31 N 85.,9~ W 463.35 N 10 41 W' 542.37 N 99.70 W 551.46 'N IO ,24 .W. 642068 N 114.48 W 6'52.80 N 10 5 W 751.35 N, 128.64 W 762.,28 N, '9 42 W .859.40 M 1'~1.57 W 8~".0,~9a N 9 ZI W 965.92 N 1~3,91 W 978.,1"1 N 9 3 W 1071.56 N 166.~ ~ 1081.1i N 8 19 W, lllS,ll N 178,7~ W 1188.9~ N 8 38 W 1279.16 N 191.73 W 1293.4i~ N t 31 k ) 1381.60 ~ 205.27 ~ 1396.77 N 8 27 ~ 1480.92 N 219.16 W 1497.05 N tt 25 W 1571.59 N 233.32 W 1594.75 N 8 24 W 1673.16 N 247.88 W 169I,,42 N 8 25 W 1769.33 N 263.37 W 1788.82 N tt 27 W 1866.64 N 279.35 W 1887.43 N 8 30 W 1964.86 h 296.60 W 1987.10 N 8' 36 W 206,.41 N 318.17 W 2088.78 N 8 45 W 2163.80 N 3~2.77 W 2~90.78 N 9 0 W 2266.~¢ N 3~8.29 W 2294..,~9 N. g ~6 W 2365.73 N, 394.8~ W Z398.4~ N t 28 W kRCO ALASKA~ INC. :UPARUK IORTH SLOPE~ ALASKA COHPUTATION DATE: 2.2-.JAN-a5 P'AGE 6 DATE DF SURVEY: 3-J'A~-85 KELLY &USHING EL~V'AT[ON::' 940,00 FT' ENGINEER: MURTLA.NO INTERPOLATED VALUES ,FOR EVEM 100 FEET OF SU&-SEA DEPTH TRUE SU&-SEA COURSE ~ASUREO VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH OEG gin DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES H. OR['Z. DEPARTURE S~CT[ON SEVERITY NORTH/SOUTH EAST#'~EST DISTo AZ[NUTH FEET OEG/ZO0 FEET FEET FEET DEG #IN 1960.33 3994. O0 3900. O0 L~: '46 6 i104.26 ~094.00 4000.00,i AS 47 ~247.31 4194.00 4100.00 45 27 ~389.43 4294000 4200000 45 12 ~531,,, 12. ~394.00 4300.00. 45 Z i672056 4494°00 4400000 4,5 0 ~814.04 ~594.00 4500.00 44 .57 N 15 34 ~ 2599004 N 16 10 ~ 2701026 N 16 45 ~ 2~02o15 N 17 11 ~ 2902.39 N 1'7 47 g 3002.Z[ N 18 18 ~ 3102003 i955o07 4694.00 46.00.00 44 4.0 N 18 38 ~ 3201.17 ~09S031 ~794.00 4700.00 44'27 i N 18 55 ~ 3299014 5135o23 4894000 4800.00 44 16 N 1'9 17 id 3396.61 5374.40 4994.,00 4900.00 43 $512.71 5094.00 5000.00 43 32 5650.20 5194.00 5100.00 43 5 5786.97 529;,000 5200°00 42 46 $922o8S. 5394.00 5300.00' 42 24 r057.57 5494000 5400.00 41 47 t'191o08 5594.00 5,500.00 41 i'322.84 5694.00 5600.00 40 16 7453.17, 5794.00 5700,,,0'0 39 12 1581o09. 5894.00 5800000 38 8 N 19 40 b 3492.94 N 19'45 ~ 358B.00 N 19 SO ~ 3681.86 N ZO 3 ~ 3774066 N 20 23 ~ 3866.09 N 2~0 43 W 3955.77 N 21 & W 4043056 N 21 13 ~ 4128.66 N 19 48 ~ 4211.59 N 17 5~ ~ 4291o~0 1706090 5994.00 5900.00 36 20 7829.8! 6094.00 6000.00 34 39 7950003 6194000 6100000 33 2 B069.33 6294.00 6200.00 33 2 8092000 6313.00 6219.00 33 2 N 17 51 ~ 4367.25 N 17 43 bi 4438.54 N 16 9 bi 4505.15 N 16 9 ld 45700/.7 N 16 9 id 4582.52 0.30 0.53 0.23 0.32 0.37 0037 0.47 0o17 '0.55 2466.58 N '421.68 bi Z502.3~ /:N 9 2566.46 N 448.91 id 2605.:42:~,...,~::~ ':9:,95 bd 26 64.83 N 476.93 2761.66 N .505-60 2857.6b; N 534.93 30~8.20 N 596.03 31aZ. 52 N 627.56. 323.5.61 N 659023 3318.08 N 69~.2~ ~ 3399.11 N ~.1 4~ .~' 0 0.18 0.22 O. 4'9 0o31' 0047 0.81 0.34 2.42 0.49 34/.9032. N 713057 bi 3495.04 N 11 ,56' Id 3509.24 N 7,55.9~i' id 3589.73 N 12 9 Y 359~8.0~ N 7~7-:79 W 36:83'Z~" N 12 ZOW 3685.76 N 819.58 W 3175~.78 N 11 31. W . 3772.07 N 851.~1 W 3866,96 N 11 ~3 M 3856.61 ~ 8a3.06 ~ 3'956~1 N ~Z 53 ~ 3939.21 N 914.72 W 4044.02 N 13 ,4 ~, 4019.1~ N 9~5.78 M 41.28096 N 13 14 ~ 4,097.17 N 975.84 M 4111.77 N 1,3:23 . 4172.82 N 1001.10 ~ 4291.23 N I3 29 ~ 1.67 42.45.47 N 1024.53 bi 4367.34 N ,tS 34 hi 1.6a ' 4313.49 a i0~6.40 W 4438.60 N 13 38 id 0.00 4377.27,N 1065.96 id 4505,,,20 N 13 41 Id 0.00 4439.76 N 1084..07 id 457002.0 N 13 43 hi 0.00 445/..64 a 10a~.51 ~,'4Se12..S5 N ];:3:43 id I~RCD ALASKA~ INC. r,,UPARUK WORTH SLOPE, ALASKA MARKER TOP UPPER SAND BASE ,UPPER SAND TOP LOtMER SAND BASE LOtdER SAND PaTO TOTAL OEP'TH COHPUTATIDN'.DATE: 22-JAN-85 PAG'E ~ ZNTERPOLATED VALUES FOR CrlOSEN ttOR]:ZDNS DATE OF SURVEY: 3-JAN-85' KELLY a,USHZNG ELEV'ATZ:DN:' ENGINEER~ MURTLAND @.~.,00 FT MEASURED DEPTH aELO~ KB 7565°00 7628.00' 7741o00 7'906.00 7'982.00 ao92ooo SURF~:CE ~,DCATZON A,T',, OR~GZ:N= ½12' FNL, Z35' F~L. SEC 331 TIZN,~,_R,~,~",. ,UN TVD RECTANGULAR, C,'OOiD~NATE$ FROM 588]..35 5931.00 6021.56 6157.16 6Z20 .ltO 6313.00 SUa-SEA 57ar7o35 5837.00 59Z7..5'6 6063.16 6'126.80 62:19.00 4ZOO.ZT N 1009.97 · Z6'4.58 N 10307°69 ~39~oOZ:N ¢'~51o6~ N 10g~.5.1 ), , ARCO ALASKAt [NC. KUPARUK' NORTH SLOPEe ALASKA COMPUTAT.I: ON DATE: *****.*****,**: STR AT ',[GRAPH 2. Z-.JAN- a5 SUMMARY PAGE DATE OF SURVEY: KELLY BUSHZNG ELEVATION:; ENG£NEER:' MURTC. A..ND 94-00 FT MA RK ER HEASURED DEPTH BELOW KB TOP UPPER SAND BASLE UPPER SANO TOP LONER SAND BASE LOWER SAND PBTD TQTAL ;DEPTH ?565°00 7628,00 71~1.00 7906.00 7982.00 8092.00 F]:NAL HELL LDCATZDN AT TO: TRUE S,U$-SIEA MEASURED VERTICAL VERT~,CAL DEPTH DEPTH ' DEPTH 'DR~Gt:N= 4~Z' T¥O FROM KB SUB-SEA 5a81,35 5787,35 5931,00 5837,00 602Io56 5927,56 6157,16 6'063o16 6220.a0 6126.80 6313o~0 6219o00 HOR T. 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[...¢....~-..~.--4...i...~..-¢.-.*...; ......... ¢...}...~...I....L.L..i...~ ...... +...,,-.~...~...1....}...}--½.. ¢... · . : : : ~ . : : : : : . : : . ~ : : : : : . : : : . : : . : ~ : . . . ~ . . . : . . : : . : : . : : , . . : . . ~ . . . --f-~--++--{-~-.~:---?'.----t~i-+-:f--.¢+-~-+-+- -+.~-~.'. +-~ .f-?~-* ..... t-f+-f-I.-f-,.'.--?!--..-5--+--?.f.-t-.fff"-i---f--i--.~-?ff---t'-F'?-?-f ~ ....... f---....-?i-.-F-t-.t..t--t..{.-.?-t'.t--?.t.-t.'?-f-5-.-, -t--t'?i-i-'-t-id---?:-'-'-tff--!--tTi--t-i---5-1"-?"-tff'+-yt?~--i ....... ~...t-.~:..t.[.t..:...t..t.....~-~.t....H..tt.t..~...[...t..?..t..~..i...t..t..t.i ...... .-::"-t'i"ti"-~'--~'"t"?.'-""'~--!'-'t'":'i'-~-"t'"~"'+ -~000 -7000 -SO00 -SO00 -4000 -3000 -2000 -lO00 0 IO00~STE NEST Required Date Received Remarks Core ~scrip~on · /< J ../ .t ARCO Alaska, Post Offic,. Sox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: ARCO ALASKA, INC. ~TTN: Records Clerk //ATO-1115B / P.O. Box 100360 Anchorage, AK 99510 ' Transmitted herewith are the following items. and return one signed copy of this transmittal. Date: 1/22/85 Transmittal No: 4989 Please acknowledge receipt OH LIS TAPES Schlumberger _. #69930 2C-15 ..... 12/30/84 . #69925 2W-1'2 J 12/29/84 Run 1 3090 - 7178 #69956 Run 1 #69944 i, " 27 05 - 8064 #69923 2W-ii-';'-12/22/84 Run 2 2467 - 6660 : 2W-13 j .ol/06/85 1Qil / 1/04/85 4117.5-9151.5 3625 - -7723.5 #69943 2E-9-j' 1/04/85. " 3856.5-8143 (Computed 1/19/85) (Computed 1/18/85) (Computed 1/16/85) (Computed 1/21/85) (Computed 1/21/85) (Computed 1/20/85) Receipt Acknowledged: DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 14, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports - December, 1984 Dear Mr. Chatterton- Enclosed are the December monthly reports wells' for the DS 6-11 (Workover) 2C-15 1Q-12 DS 11-12 2C-16 2W-9 DS 11-15 2D-13 2W-10 DS 15-16 (Workover) 2E-10 2W-11 DS 15-17 (Workover) 2E-11 2W-12 DS 17-13 2E-12 CPF-1A DS 17-14 2E-13 WSP-3 If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRU3/L68 Enclosures following 2X-9 2X-10 263-4944. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RFCEIVED JAN'I_.~]~ A~asi~8 uti ~ Gas Cons. Commisdoa Anchorage STATE OF ALASKA ~-- ALASKA O,~ AND GAS CONSERVATION COk ,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~X Name of operator ARCO Alaska, Inc. Workover operation [] 7. Permit No. 84-224 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21240 4. Location of Well atsurface 412' FNL, 235' FEL, Sec.33, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 95' RKB 6. Lease Designation and Serial No. ADL 25642 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2W-12 11. Field and Pool Kuparuk River Field Kuparuk River0il Pool For the Month of. December , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilli~ng problems, spud date, remarks Spudded well @ 2300 hfs, 12/23/84. Drld 12-1/4" hole to 3767'. Ran, cmtd & tstd Drld 8-1/2" hole to 8065'. Ran OH logs. Drld 8-1/2" hole to 8092'TD (12/29/84). csg. Secured well & RR @ 1600 hfs, 12/30/84. 9-5/8" Ran 7" 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 90' Cmtd w/337 sx CS' I 9-5/8", 36.0#/ft, J-55, BTC csg w/FS ~ 2720' . Cmtd w/610 sx AS Ill & 500 sx Class "G" cmt. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8065'. Cmtd w/550 sx Class "G" cmt & 375 sx Class "G" cmt. Arctic packed w/250 sx AS I & 55 bbls Arctic Pak. 14. Coring resume and brief description None 15. Logs run and depth where run D I L/SFL/GR/SP/FDC/CNL/Cal f/8042' - 2720' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED JAN 1 5 19 5 Alaska Oil & Gas Cons. C~mmission Anchorage SIGNED & &"'7~ ~,~..~ TITLE Associate Engil~eer DATE /-//-~:~ NOTE--Repo on this form is required for each calendar month, regardless of the status of operations, and must be flied in dupHcate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Submit in duplicate November 30, 1984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2W-12 AP. CO Alaska, Inc. Permit No. 84-224 ~ Sur. Loc. 412' FNL, 235' FEL, Sec. 33, T12N, R9E, LR-~. Btmhole Loc. 1039' FIJ]L, 1392' FEL, Sec. 28, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the .approved application for ~ermit to drill the above referenced well. if coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25,050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter su~eys. Many rivers in Alaska and their drainage 'systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you ma~ be contacted by a representative of the Department of Environmental Conservation. To 'aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. Kewin Kuparuk River Unit 2W-12 -2- November 30, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe-is drilled. ~rhere a diverter system is required, please also notify this office 24 hours prior to co~rmn~ encing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver3L truly yours, C. V. Chatterton Chai~n of Alaska Oil and Gas ~onse~ation ~o~ission BY O~ER OF THE CO~ISSION lc Enc 1 o sure CC' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Doug L. Lowery ARCO Alaska, Inc. Post Office b__. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2W-12 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2W-12, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on December 17, 1984. any questions, please call me at 263-4970. S i~e)r e 1 y, /Area Drilling Engineer JBK/JG/tw GRU2/L95 Attachments If you have RECEIVED Alaska Oil & 6a.s Cons. CCm'~;ission Anci-~ora..:ja ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~-~ ALASKA ulL AND GAS CO.NSERVATION CUMMISSION ERMIT TO DRILL 2O AAC 25.0O5 la. Type of work. DR ILL I~X REDRILL [] DEEPEN [] 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC ~ SINGLE ZONE [] MULTIPLE ZONE~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 412' FNL, 235' FEL, Sec.33, T12N, RgE, UH (Approx.) At top of proposed producing interval 1434' FNL, 1294' FEL, Sec.28, T12N, RgE, UN At total depth 1039' FNL, 1392' FEL, Sec.28, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 95', PAD 65' 12. Bond information (see 20 AAC 25.025) 6. Lease designation and serial no. ADL 25642 ALK 2573 Federal Insurance Company 9. Unit or lease name * A~O~- Kuparuk River Unit 10. well nu~ka 0ii & L4as C0,qs. O0mmJs 2W-12 Anchorage 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 8190' MD, 6265' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 750 feet. 21 14. Distance to nearest property or lease line miles 1039' ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 45 o (see 20AAC25.035(c) (2) Amount $500,000 15. Distance to nearest drilling or completed 2W-11well 60' @ surface feet 18. Approximate spud date 12/17/84 2746 psig@ 80°F Surface 3153 .psig@ 6125 ft. TD (TVD) Hole Weight i24" 62.5# 112-1/4" 36.0# 8-1/2" 7" 26.0# SIZE ICasing 16" 9-5/8" 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW Length SETTING DEPTH MD TOP TVD 80' 29' I 29' 3704' 29' I 29' I I 28' I I 28' 8162' MD BOTTOM TVD 1091 109' 3733~ 3140' I 8190~ 6265' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 814 sx AS III & 500 sx Class G 400 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8190' MD (6265' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3733' MD(3140' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2746 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, 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 (see attached sheet) ;ion 23. I hereby c_,¢r-'~y that the foregoing is true and correct to the best of my knowledge SIGNED ~ TITLE Area Drilling Engineer CONDITIONS OF APPROVAL DATE Samples required I~IY ES [~O Permit number APPROVED BY Form 10~01 ,?. ( GRU2/PD34 Mud log required Directional Survey required IAPl number E]YES ¢~LNO ~ES F-INO I 50-- Approval date · , .-~, 11,~/30,/84,, . SEE COVER LETTER FOR OTHER REQUIREMENTS ///_I~--~~~~MMISSIONER/~ DATE November 30, 1984 J¢~/~~ by order of the Commission Submit in triplicate PERMIT TO DRILL 2W-.12 installed and tested upon completion of the job. 2W-12 will be 60' away from 2W-11 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 6619'MD, approximately IO00'MD above the top of the Kuparuk Sands. 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 will be fracture stimulated. Al~tskr~ Oil & 6~.s Co.s, Oorr~m~ss~o~ Anchorage . i i . Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lO" si de outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & Ooeration 1. Upon'initial installation close annular preventer and verify Ehat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid ~low to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 6" Conductor I A~NULAR 9 PIPR RAM~ DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" - 5000 psi annular BLIND ' ~ ~. ~~DRILLING ~ ~ PIPE ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTRE.a,M OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAd:). 3, CLOSE ANNULAR PREVENTER AND lj'~k~LVJ~S D1)S~ OF C}-IO~S. DON~T TEST AGAINST CLOSED CIt3~S 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 8. ~~'PRESSbI~E DOWNS--4 OF CHOKE ISOLATION ~.AJb.'V'~S: TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING jOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSl WITH KOOMEY PUMP. lS.RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. o,c A HD 2 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. /<. t'L, ~. ~. &O,--! YES NO REMARKS (1) Fee (2) Loc "'?'~ ': // .; ~:~ . >' ',42 (2 thru 8) 3. 4. 5. 6. 7. (~) (3) Admin '~ .... Il-' z~-f¥" 9 (9~thru 12) 10. (10 and 12) 12. 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 ................ ./g~- Is operator the only affected party ................................. 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 ..................................... (4) Casg (13 thru 21) (5) BOPE ,>57'}'?' (22 thru 2'6) 13. 14. 15. 16. 17. 18. 19. 20.' 21. 22. 23. 24. 25. 26. 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 known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required .................................... ~ .,~ Are necessary diagrams of div~rter and ~6~ equipment attached .. . L/~,[! 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 ................................., ,,,, fiE>/ Additional, requirements eeee.lleeeleeeleeeeeeeeeeeeeeeeeeeeee~eeeeeee , o Geology: , Engineering: I~A~, JI{T~JI-I ~ rev: 10/29/84 6. CKLT POOL IN IT IAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not pa[ticulady 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. YE[{IF~C~TIOg LISTING LVP 0lO.H02 vE'~I~.ICATIO!',i LISTING PAGE I DATE OR'IGIN ~NTIN,,A,ION ~ :01 ** TAPE SERVICe] N&ME :EDIT DATE : ~5/()1t1.8 ORIGIN :0000 CONTINUATIm~ PREVTOUS TAP~ : ** F'ILF HEADER ** WlbE N~i~ SERVICE NA~E : VERSIUM # : DATE : MAXI~U~ I,,~NGTH : PREVTO~S FI[~E .00:1 1024 ** INFORMATION RECORD5 ** UNIT TYPE CATE SIZE CODE CN : ARC[] ALASKA INC 000 000 016 065 WN : ~W-lP 000 000 006 065 FM ~ gOPA~LJK 000 00O 008 065 RANGJ ~E OOO 000 002 065 TOWN~ 1.2N 000 000 004' 065 SECT: 33 000 000 002 065 COUNI N,SL~PE 000 000 012 065 STAT: ~L~SW~ 000 000 006 065 CTRY: US~ 000 000 003 065 ** COMmEnTS ** **************************************************************************** L'VP Q10.}40~ VERIFi, CA'VI{]t,~ bTST1]~,~(] PAGE 2 * hl,,,~S~(A COtqPUTi~[[G CENTER * ************************************************************************************** COMPANY : ATLAf~TIC RIC!.{FI~L.9 CO~PANY WELL = 2w-12 FIELD : ~UPARUK COUNTY = N{~RTH ST, OPE ~OROtJGM STATE : A [.,,AS~.:A JOB NIJPBER hT hCCI 69925 RUN ~ONE, DATE [,DP: CAglhlG : 9.6 5" ~ 2720' - BlT ~.ZE : 8.5" TO 8055' TYPE ~LOlD : POL ~{,~Ea VISCOSITY =4~.o S RMF = ~ 600 974;0 DF P,~ = 9,o ~C :z:570 g ~ 0 DF FLUID LOSS = 6.6 C3 R'M AT 8HT = 2.313 8 132:0 DF l"'T~ i"11111 k i kI:t ii! [:.]2 bVP 01. o.~,I02 VEPI~,'ICATI~t,N LISTING PAGE * SC},ib[I~BENG~R LOGS INCLIIDEO ~aITH THIS M~GMETiC T~PE~ * , ~ * DUmb IMDUCTION SPHERICaL, bY FUCUSED bOG (OIL) * * FORM~T'ION DE'~SITY Cfl~PFNSATED LUG fFDN) * * COMPENSATED NEUTRON LOG (FDN} * ** DATA F[1RH~T RECORD ENTRY BLOC¢S TYPE SIZE RE;PR CODE ENTRY 2 I 66 0 4 1 66 I 8 4 73 60 9 ~ 65 ,liN 1.6 I 66 1 0 I 66 0 DATU'M SPMCIFICATION BbOLK,. MNEM SERVICE; $~..~RVICE {.JNI~[' AP1 AP1 API ~?I FILE ID ORDER ~; I.,0(; TYPE ChASS ~OD NO, DEPT FT O0 000 O0 0 0 SFLU DIL Oti~i~ O0 220 Ol 0 0 IbD mil rlHMM O0 120 46 0 0 Ib~ DIL 9},~ ~ O0 120 a. 4 0 0 SP DIL ~V' O0 010 Ol 0 0 GR OIL CAPI OO 31.~ O1 0 0 GR FDN GAPI O0 3IO Ol 0 0 CAbI F'ON IN 00 ~80 01 0 0 RHOB FD~ G/C3 O0 350 02 0 0 ORHO ~'DM G./C3 00 356 Ol 0 0 WRAT FOM O0 420 Ol 0 0 RNRA F!)N 00 OOO 00 0 0 MpHI FDN' PU O0 890 O0 0 0 NCNL ~[,)~' CPS 00 330 31 0 0 SIZE SPL REPR CODE (OCTAL) 68 00000000000000 68 00000.000000000 68 00000000000000 66 O000000000000O 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 LVP 010 F~02 VERIFtCATIn.I',~ I.,,TS~I~G .PAGE ~ F C iV L *' D N C P S RHOB 2,3770 ~PHI 4fl, 1.445 OE.~' 7~00 0000 RHOB ,~. 51 NPHI 37.1.582 OEPT '7800.625~ SP -48,090' RHOB 2,3672 MPHI 31,2988 OEPT 7700.~000 SP RHOB 2,4'766 RHOB 9-,3691 MPHI 24.9512 OEPT 7500 o000 SP -44.6563 R.HOB ?,4258 NPHI 49.8047 OEPT 7400 0000 SP '45' .0000 RHOB 2.3984 MPHI 45.~008 DEPT 'I~O0 0000 SP .54:5000 RH00 -999.2500 NPHI -999,2500 OEPT 7~00 0000 SP ' RHOM -999.2500 ~PHI -090,2500 $ F L 0 NCNb $ F b 0 GR DRHO N C N L NCNb SFLU GR DRHO q CNI.., S F L U DRHO NC N h SFI.,0 DRHO NCNb S F L U {') R U b WCNb SFLiJ ~C ~I[,., GR NCNb SFLU GR DRHU 00 330 30 0 0 5 0078 13 ,1465 ,2500 0.~410 NRAT ooo 3,4395 425 ~T 2458'0000, ~:C' 'NL 86.312 2784,00o0 5,~3.44 Ihn 88.18:75 2572.0000 FCNL 13,8359 lbo 67,7500 -0~002~ NRAT 3118.0000 ~CNh 1.5566 112,0625 q,05~8 1888.0000 FCNL ~.398~ 118,~250 0,0220 1900,0000 3,0664 1~0o3750 GR '999,2500 NRAT -999,2500 FCML 3,01.37 ~2~,1250 -999,~500 MRAT -99~, 50b FC.I.L 4 1 68 t 66 3 286 7'~54 93:75CAbi 7656 250:0 1,3 :6055 I.bP4 2500 CALl 3,8477 RNRA 51,0,7500 3.2871 9~ 1875 CALl '2500 RNRA 713,5000 .6016 IbM ';3125 CALl 2,8770 RNRA 936.0000 4.9922 88.1.875 CALI ~.9785 RNRA 836.0000 , O0 CALI 2,4492 RNRA 1252. 0000 1.5361 IbM 112 0625 CALI 3; 9297 R6II~.A 488.250O 2.1094 IbM 1.!8.1250 CALl 3.8066 RNRA 471.0000 2,9570 IbM 140,3750 CALl -999.~500 RNRA -999,2500 2.0117 IbM ~21.1250 CAL'I -999,2500 RNRA -999,2500 00000000000000 4,9844 1~,2500 ,q746 ,71~9 ,4531 4.0273 3,3359 9,4688 3,4434 1~,49.22 ,1094 2,,9727 4 ;093,8 ,~.953t .0762 0,8750 19,0469 2,4902 1,6221 9,3516 3.8652 2,.1914 I0,4922 4,0313 3,0449 10.2656 -999,2500 2 1055 9~6016 -999.2500 LVP O]O.H'O? VERIFI. C~TIP,.N .L,!STING .AGE 5 # SP -63,4375 R,,HOB -999,~500 DRHO NPHI -q99,2500 NCNiL, DEPT 7000,0000 SFLB SP ' 64. ~ ~75 RHOB -999,~500 ORHO OEPT 6900,0000 SFLU . o o n R H ~P~l :999:25o0 NCNL DE, ~ 6 0000 8P ,2500 RHOB -999,2500 DRHO gPgI -o99.2500 uCNL DEPT 670o, 0000 SFLU SP -13.750o RI-IOB -q99'~500 DRHO NPNI -~99.~500 CNL OEPT 6609,0000 SP ' 7 ,~320 R H [] B 999,2500 I) gpBI 999... ~500 r,~CNL DEPT 6500 O00O SFLU SP -13.~797 RMOB -099,2500 DRHO MPHI -99g.~500 gCNL, 9EPT 6400 0000 RHOB -999,2500 ORHO gPHI -99~.2500 gCNb DEPT 6300 0000 SFLU BP -~.2109 RHOB -999,2500 DRHO NPHI -999.2500 DEPT 6200. 0000 SFbU SP -15.3750 RHOB -999.2500 DRNO NP~! -999,~500 ~]CNL OEPT 6100. 0000 SF~.U ~HOB .. 999.250() DRHO 3,8926 1~4,0000 :9 9,2500 999,2500 I1~. 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[:-1 iI LVP 01o HO .... VEPlFICATI'O,~,,~ LISTING PAGE 7 RHOB .,.~9 , ...... 500 NPMI -q9. o2500 -q99,2500 NRAT -99q, 250{) PCML DEPT 4900 0000 SFLU SP -43 5000 GR RHOB -q99 9500 ORHO MPHI -999 9500 NCM[, 2,468~ IL, D 95,5000 GR -~99,9500 NRAT -999~500 FCNL DEPT ,1800 ~000 $~'LU 'Q687 CR SP -~5, ~HO[~ -999,~500 DRHO ~P~I -999,~500 NCML 1250 IbD .to 17.5oo ca -999,2500 NRAT -999,2500 FCNL DEPT 4700,0000 SMI.,L) SP -50,2187 GR RH,~B -~99.~500 ~PHI -099.2500 NCNL 0000 G R -99. . 2500 NRAT '999,·2500 ~ C ~L OEPg' 4600,0000 SFLU SP -48'5000 RHOB -9~9,~500 NPM1, -Ow9.2500 WCNL 2 59~ IbD 96,06 '999 2500 NRAT '999' ,250() FCNL 3 0859 ILO 93,1875 ~R -999,2500 NRAT -999.2500 FCML OEPT 4, aO0 0000 SFIu $P -65' ,nO00 GR RHOB -~99,2500 DRHU 9~,6953 ILD .3125 CR -999,2500 NRAT -g9q.2500 FCNL DEPT 4300,0000 SFI, U SP -63 2187 GR RNOB -099'2500 DRHO gPM1 -O99 ,..500 ~CNL 3,8379 ILO 104.43';5 GR -999.2500 NRAT -qg9.250U FCNL OEPT 4~00,O000 SFLU SP 57.0000 GR RHO8 -999,2500 DRHO NPHI -99q.~500 ~,!C~b 3 1445 1:1,,, D cio' . ,0000 GR '999,2500 NRAT '999,~500 FCNL DEPT 4~.00 0000 SFLU SP ' b3:2500 GR RHOB ~99.2500 DRNC! ~PHI -999.2500 NCNb 3.5059 ILO 110.9375 GR -999'2500 gRiT -999.2500 FCNL DEPT 4000 O00O SFI,.U SP -64i5000 GR RHOB -999 2500 DRgO ~PHI -099 2500 NCN[.., 110" .3750 -999.2500 NRAT -09° ~5no FCNh DEOT 3000.0000 '999,2500 '999.~500 2.7871 9:5,5000 -99~.2500 #999.~500 2,4258 ,~08,7500 999,~5:.00 -~99.'~500 91. 0000 -999,2500 -999,,~500 999 , 2500 -999..2500 ,4355 9 ,1875 -999,2500 '999.'2500 4,027:3 9_1..3125 90,2500 4.3438 104,4375 '999.2500 'q99,~500 3.7539 90,0000 -999.2500 -999,2500 3,9902 110.9375 -999.2500 -999.~500 3 191.4 1.10}3750 -999 2500 -gg9 2500 4,8203 RN'RA IbM CALI RNRA I I.,'~ CALI RNRA IL~ C:AL I, RNRA · A L I R N R A Ib~ C ALI RNRA I CALl RNRA IL~ CALl RNRA IbM CALl RNRA IbM CALl RNRA RNRA -999.250'0 2,7168 9,8828 -999,~500 9;67 -099,2500 3,2852 10,:~359 -999, 500 2,640.6 1 0 ~4375 ,,999,~500 3,3691 o ~ 12 5 -999."' 500 3,914:1 10,8203 -999,2500 4.1758 i0,~422 -999, 500 3 $766 lo: 5oo -999'~500 3,8418 10.9687 -999,2500 3,0332 10.7500 -999,2500 4.6055 I, ¥ P 01 O H 02 V E R I ~:" I C l T I O ~'.; I., I o .C ! I~! G P.A G [< 8 RHOB 999 ..~,.PT 3~00 SP ~67 RHOB '99? ~PHi '999 DEPT 1!00 sp 75 RHOB q99 NPHI -g99 DEPT 3600 SP -74 ~HOB 2 NPHI 45 DEPT 3500 SP -76 RHOB ~PT. 34,00 '77 RHOB 2 NPHI 47 OEPT 3~00 SP RHOB NP~I 40 DEPT 3200 SP -84, RHOB UPHI 46 DEPT 3 ~ 00 SP -103 RHO6 2 NPHI 38 ~EPT 3000 SP -107 RHOB WP~I 50 DEPT 2900 SP RNOB ~PHI 44 :? 500 2500 D R H t.) 2500 0000 S F b U .6875 GR 2500 DRHO 2500 NCNL ,0000 SFI.,U 250O 2500 DRN[J ,2500 0000 0000 G R "~ 996i NC'~L 000o 0000 GR 1. 250 8}7 1 NCNb 000 U 2500 1895 ,O000 ,O000 ,2305 DRHL) .72~5 nO00 SFI..,U ~7500 .1.914 ,3301 0000 SFY,LI ~~4;175 ~R 0293 DRHO 6836 0000 SFI.U . ,8125 GR 3184 DRHO 94,1875 GR -990,2500 NRAU -999,2500 FCNh 3,8926 ILD 88,2500 GR '99q,2500 NRAT -99~.2500 FCNL 6,0742 IL{') 73,~500 GR 500 NRAT -999, F ' '999,2500 ..CNI.~ 4,4805 82,5000 GR 0,0146 ~R:AT 2336,0000 ..C~L ,6250 GR 6~'7109 ,0044 NRAT 2106.0000 FC L 7~,3086IhD ,7500 GR. 0,0088 NRA7 21.50~0000 FC~.tl, 6 7266 67,3750 GR 0.0308 URAT 214~.0000 4,1719 IGD 7~.~875 GR 151 NRAT 1281: 000 FCHb 8.4844 ILD 59 5938 GR 2.0000 FCNL 15 6719 I.[~D 50271~.8 GR -0,8 1 NRA1'.' 2056. (~O FCNL 94.1875 -999,2500 -999-~500 .250 -999,2500 -999.2500 8,320'3 '73,2500 '999,2500 -999,2500 000 52~''9355 ,5000 8,2500 .6250 6~,8301 5:37,0000 2500 7,9258 67,3750 3.6855 5:50,5000 7,2656 75,1875 4,0078 432.7500 10.7500 59 5938 2so59 526,5000 18.8750 50.7188 4.1680 483,5000 10.2266 79 6250 3:8926 5O3.OOOO CALl R N R A CAI,,,I RNRA CA[,I RNRA CA. I RNRA CALl R[~R A I.hM CAI,,I R NRA Ih~ CAb I RNRA IbM CALi RNRA IbM CAbI RNRA Ih~ CALI RNRA CALl RNRA ,g~'~,6406 .2500 -999 ,2500 7,7891 1'4.7109 '999.2500 5,5664 4 ' 6'094 4,4336 8,1641 1~,0000 9199 '5. 0156 5 ,0703 4' 2109 7.6250 1~,87§0 ,8906 6,0000 15,7891 4.3438 10.3750 14,1953 3.68'75 20,9531 13,6797 4,2500 9.0859 0313 LVP 01o.}.{02 1/ERIPiCTATIO(,~ :(,IS?lNG PAGE 9 DEPT 2800 0000 S¥[.,u SP -95 ~ o00o GR RHOB 2,1953 .DRHO g 1875 .0,0938 1~1,00~5 NRAT ... .0000 DEPT 2705,00nO SP -83,~500 RHO[+ -ggg 500 NPNI -999;5500 29 7813 .q34 7188 GR,. .. 99 2500 -~9g 2500 FCNL ** FIL~ TRAILEP, ** FILE NAME :EDIT . {.)01 SERVICE N~ME VER$IO~ # : DATE : ~AXI~U~ LE...GTH : 1024 FiLE TYPE : NEXT FIbF NAME : ** TSPE TRAILER ** ~V]C~ NA~ :EDIT .E :85/01/18 ORIGIN :0000 TAPE N~E :g9~5 CONTINUATION ~ NEXT T~PF NA~E : COMMENTS: ~,0938 CALI ],7227 RNRA 507.7500 13.5469 Ib~ 3:4,7188 CALl 999,'25'00 ~NRA -g9g,2500 14 3 O°i,O000 99 ,5469 '2500 ** RFEL TRaiLER SERVIC~ NA~E :EDIT DATE ORIGIN : REEL Na~E : CONTINUATION # :0! NEXT REEL NA~E : COMMENTS :