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Home My WebLink About184-208By Anne Prysunka at 9:06 am, Oct 17, 2022 5HJJ-DPHV%2*& )URP&R]E\.HOO\.HOO\&R]E\#QDERUVFRP! 6HQW0RQGD\6HSWHPEHU$0 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*&16.5:2&0 &F+HQVRQ-DPHV0RUDOHV7RQ\<HDURXW3DXO0DUPRQ-LP+REEV*UHJ6.QHDOH0LFKDHO/ 6XEMHFW1DERUV(6%23 $WWDFKPHQWV1DERUV(6[OV[ dŚĂŶŬƐ͕ <ĞůůǇŽǌďǇ EĂďŽƌƐůĂƐŬĂƌŝůůŝŶŐ ZŝŐϳ^ZŝŐDĂŶĂŐĞƌ KĨĨŝĐĞϵϬϳͲϲϳϬͲϲϭϯϮ ĞůůϵϬϳͲϳϭϱͲϵϬϱϱ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ 1$%256(0$,/127,&(7KLVWUDQVPLVVLRQPD\EHVWULFWO\SURSULHWDU\DQGFRQILGHQWLDO,I\RXDUHQRWWKHLQWHQGHG UHFLSLHQWUHDGLQJGLVFORVLQJFRS\LQJGLVWULEXWLQJRUXVLQJWKHFRQWHQWVRIWKLVWUDQVPLVVLRQLVSURKLELWHG,I\RXKDYH UHFHLYHGWKLVLQHUURUSOHDVHUHSO\DQGQRWLI\WKHVHQGHURQO\DQGGHOHWHWKHPHVVDJH8QDXWKRUL]HGLQWHUFHSWLRQRIWKLV HPDLOLVDYLRODWLRQRIIHGHUDOFULPLQDOODZ7KLVFRPPXQLFDWLRQGRHVQRWUHIOHFWDQLQWHQWLRQE\WKHVHQGHURUWKHVHQGHU V SULQFLSDOWRFRQGXFWDWUDQVDFWLRQRUPDNHDQ\DJUHHPHQWE\HOHFWURQLFPHDQV1RWKLQJFRQWDLQHGLQWKLVPHVVDJHRULQ DQ\DWWDFKPHQWVKDOOVDWLVI\WKHUHTXLUHPHQWVIRUDZULWLQJDQGQRWKLQJFRQWDLQHGKHUHLQVKDOOFRQVWLWXWHDFRQWUDFWRU HOHFWURQLFVLJQDWXUHXQGHUWKH(OHFWURQLF6LJQDWXUHVLQ*OREDODQG1DWLRQDO&RPPHUFH$FWDQ\YHUVLRQRIWKH8QLIRUP (OHFWURQLF7UDQVDFWLRQV$FWRUDQ\RWKHUVWDWXWHJRYHUQLQJHOHFWURQLFWUDQVDFWLRQV &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .584 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:7ES DATE: 9/2/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1842080 Sundry #322-424 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2822 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1FP Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T90 P Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2 7/8' x 5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate FP System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1600 P Check Valve 0NA200 psi Attained (sec)21 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)110 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 5@2050 P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 30 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:14.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/31/22 11:45 Waived By Test Start Date/Time:9/1/2022 22:00 (date) (time)Witness Test Finish Date/Time:9/2/2022 12:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nabors Test with 3 1/2" jnt. HCR Kill valve and upper IBOP failed. Both were replaced & tested - Pass Kelly Cozby/Paul Yearout ConocoPhillips Lenward Toussant/Dale Rowell KRU 1Q-06 Test Pressure (psi): kelly.cozby@nabors,com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022) 2022-0902_BOP_Nabors7ES_KRU_1Q-06 9 9 9 9 9 9 999 9 9 9 9 $QQXODU3UHYHQWHUFORVHWLPHDWDOORZHGOLPLWVHF 9 9 -5HJJ $QQXODU3UHYHQWHUFORVHWLPHDWDOORZHGOLPLWVHF 30 FP FP ! " # $! % " & '$ ("" )*$ +, *# - # ./$ 0/ 1$$ " ## ! 2 ,2 3 $ 4* 56 $7 8&5 7 * 9*5 7 * :*5 7 + #* 9* + #* :* 95 7 59*7 ;<59*7 1.()=1.88= " / %>< < : < :9*5 7:*5 7 ' -" !< * >< +, *# # (+ * ) !< " /6 /$; *6 .:# * ? ? ? 6@? ?"" #?/$; ! 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ATTN: Natural Resources Technician 11 rl Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 ---.ib. Anchorage, AK 99501 7TRANSM71-IrTAILDATE TAL# 18 42 08 NAM 2B-10 11-1-108 1H-105 1J-156 1A -04A 3H-18 API # 50-029-21084-00 50-029-23608-00 50-029-20727-01 50-029-23311-00 50.029.20621-00 50-103-20095-00 SERVICE ORDER EOSH-00034 E540-00064 E540-00065 EA18-00008 E540-00066 EBLV-00002 FIELD NAME KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER SERVICE DESCRIPTIONDELIVERABLE WL WL WL Memory WL WL DESCRIPTION IPROF (PROF (PROF (PROF Caliper IPROF DATA TYPE FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD Color DATELOGGED Prints 26-Mar•19 27 -Mar -19 28 -Mar -19 29-Mar•19 4 -Apr -19 6 -Apr -19 , 1 1 1 1 1 1 2K-26 1Q-06 50-103-20126-00 50.029.21224-00 EBLN-00004 EBSI-00001 KUPARUK RIVER KUPARUK RIVER WL WL Caliper PPROF FINAL FIELD FINAL FIELD 8 -Apr -19 10 -Apr -19 1 1 n 8 Name Signature Please return via courier or sign/scan and email a copy Date mberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. V) c n I o� a w v Nr W Y " > ? 0 0 x u a) > • " y h 1r - Q Q y, oci• ; °az c..,1 III a o o a• ° a) c . a G' y c -O " 0 J W' t0 cD tp ro O cu E Z -I Q O _C u Y " Y In c� Y — < ~ O o_ re o. " _ c c io H 2 J'. Q E Q E ''' ro N Z cr N ,- C.3 G (O 41O- a) Z < OU -O O T Q i- U Y a Y U t W i•ii 7) 4-, O 0 0 a) U } W W W CIO c yo O ... I- IL LL LL ." a) E -o " o Q J J J Q O ( a) 5 0) Q Q Q Q v " " Y Z Z Z rp ° 1 11 °j LL LL LL a) -c N K Cro U > _C u M y c O ,„ a v O U ° O' c o c a, a > • O a > ~ > 00 0 0 U oC W Q CU r u > �. • o OW, ocS O W' n. ad 0 o 'O j a N0 ccc a 114 PI 8 al cn , QO W gV > �I Zo rt x "" r. z x gW 0 at .x v i= I X zaC & 333 W .)4......1").--,11 0 C OA W = = N '1-$ d d Q > >_ > E o = Q1 O V o W N LL > R > Q O N a 0 W a7Oa7 X C Cw o 000 NEM cr4 U 0 000 CO LU 4:::, vs` 00 do03 asE o 0 � � � c Cr 8 0 0 o u 0 0 0 ra v+ ob n m N ClE N 3t7 N_ I� - O r. O O U N m N N N I M O) M O 0 N 0 c v Q1 a- O @. O O O v, in of o a) rre 03�_ �„� C G u Cid ° E f9 U E a) > Y �� N ` N O N CO ��yyy a) 3 d 8 e P g n N C . Eo C 2 Q p N aU U Z a) ro •i "= .ti y ^ c c v it • 0 Ima ect 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. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ~, OVERSIZED (Non-Scannable) [] Other: , NOTES: [3 Logs of various kinds [] Other Scanning Preparation x 30 = + -- TOTAL PAGES Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~'~YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES DUE TO QU~. ~YSC~ OR C~OR NO NO ReScanned (individual page [special attention] scanning completed) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA General Notes or Comments about this file: LOWELL DATE: IS/ Quality Checked (done) 10/25/02 Rev3N OTSca n ned.wlX:l STATE OF ALASKA • RECEIVE ALASKA OIL AND GAS CONSERVATION COMMISSION JUL. 2 3 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r-- Repair w ell j Rug Perforations J'-" Perforate E Other f C G CO Alter Casing jr1 Pull Tubing W0 Stimulate-Frac f Waiver r Time Extension t- O erat. Shutdown Stimulate-Other T Re-enter Suspended Well J`" Change Approved Program � P 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number:. ConocoPhillips Alaska, Inc. ' Development p . Exploratory 184-208 3.Address: 6.API Number: Stratigraphic r Service 50-029-21224-00 P.O. Box 100360,Anchorage,Alaska 99510 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25641 1Q-06 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 8645 • feet Plugs(measured) 7755 true vertical 6556 feet Junk(measured) 8600 Effective Depth measured 8544 feet Packer(measured) 7607, 7738, 8060 true vertical 6485 feet (true vertical) 5805, 5902,6141 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 103 103 SURFACE 4370 9.625 4406 3584 PRODUCTION 8592 7 8625 6542 SCANNED NO V 0 8 V.)1:-!, Perforation depth: Measured depth: 7920'-7961',7985-8005',8170'-8220', 8300'-8316' True Vertical Depth: 6038'-6069',6086'-6101',6221'-6257',6314'-6324' Tubing(size,grade,MD,and TVD) 3.5, L-80, 7715 MD, 5885 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER @ 7607 MD and 5805 TVD PACKER-BAKER FHL PACKER @ 7738 MD and 5902 TVD PACKER-BAKER FB-1 PERMANENT PACKER @ 8060 MD and 6'141 TVD NIPPLE-CAMCO DS NIPPLE @ 535 MD and 535 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-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development j • Service r Stratigraphic 1-` 16.Well Status after work: Oil 1✓ • Gas 1 WDSPL j-- Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ 1- SUSP SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-186 Contact Ian Toomey 263-4773 Email Ian.A.Toomeyaconoeophillips.com Printed Name Ian Toomey Title Wells Engineer Signature .= Phone:263-4773 Date --� RBDMS JUL 2 4 20 doe 77.7(‘: Form 10-404 Revised 10/2012 -7- l 3i / 13 Submit Original Only 1 NM KU P 1 Q-06 - Angle&MD TD COnocoPhillips ':a ', Well Attributes Well Status Max Ma°) gle& ActBlm(ftKB) --�$$ Wellbore API/UWI Field Name WeOD 48.33(°) 1MD(ftKB) 00 8,645.0 Alaska.Inc. rr 500292122400 'Field RIVER UNIT G+wNaIN 7 H25 m Date Annotation End Date KB-Grd(ft) Rig Release Date • SSSV:Comment (pp m) 41.79 2/25/1985 ••• SSSV:NIPPLE 40 9/4/2011 Last WO: 6/27/2013 Last Mod...End Date Well Con(o:Schematic-Actual6:41'.06 AM Annotation Depth(ftKB) End Date Annotation Last Mod End Date- Last Tag:SLM 8,254.0 12/25/2011 Rev Reason:WORKOVER HANGER,25 a flat 'r/, 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 36.0 103.0 103.0 62.50 H-40 WELDED i; /G,, p Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 95/8 8.921 35.6 4,405.7 3,583.8 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR. ' PROD TIE-BACK 7 6.276 26.8 1,703.2 1,656.2 26.00 L-80 TC-Il 36--103 103 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd MI PRODUCTION 7 6.276 1,696.0 8,624.8 6,542.3 26.00 J-55 BTC NIPPLE,534 IP MI Tubing Strings 4�e Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...string Wt...String...String Top Thrd TUBING WO 2013 , 3 1/2 I 2.992 I 24.9 I 7,715.0 I 5,885.0 I 9.30 I L-80 'String 8rd Completion Details Top Depth PROD Nomi... ... 0(TVD) Top Inc! (ftKB) ( Item Description 3.500 Comment ID(in) TIE-BACK, I - - 24.Top(ftKB)9 24.9 0.25 HANGER FMC GEN IV TUBING HANGER w/PUP.53'(3.68') 2 875 3,085 7,576.8 5,783.2 42.98 LOCATOR BAKER LOCATOR SUB 27-1,703 534.5 534.5 0.41 NIPPLE CAMCO DS NIPPLE GAS LIFT. 2.990 2 990 7,577.9 5,783.9 42.97 SEAL ASSY Space out above PBR locator sub"Expected space out" i 7,584.4 5,788.7 42.93 PBR BAKER 80-40 POLISHED SEAL BORE RECEPTACLE 40,000 Shear 4.000 force SURFACE, 2.870 36FACE. 7,606.5 5,805.0 42.60 PACKER BAKER FHL PACKER-60,000 PSI Shear Release 2 813 7,659.1 5,843.6 42.34 NIPPLE CAMCO DS NIPPLE 2.813"8rd EUE-Mod W/RHC Plug GAS LIFT,.60 dill=" 7,707.6 5,879.5 2.09 OTs RSHOT POORBOY TUBING OVERSHOT 6"OD x 31s.62"ID Swis llowed 6'of tbg 3.620 stub. Tubing Descri lion rin 0... tring ID...ITop(ftKe) Set Depth(f...Set Depth(ND)... tring Wt... tring...String Top Thrd GAS LIFT, TUBINGWOp1994 Is:31/2 2.992 7,702.4 7,737.6 I 5,901.8 9.30 J-55 I EUE8RDMOD 5,746 Completion Details Top Depth Nomi... GAS LIFT, _ (ND) Top loot Comment ID(in) 6.637 Top(ftKB) (x891 (2 Item Description BAKER PBR-STABBED INTO ORIGINAL TUBING COMPLETION 2.938 7,723.9 5,891.6 42.01 PBR Tubing Description String 0... String tD...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd GAS LIFT, TUBING Original I 31/2 I 2.992 I 7.737.6 I 8,087.1 I 6,161.2 I 9.30 I J-55 I FL4S INII IN: IMM 7.zeo i _ CompleT000Details Nomi... (TVD) Top Inc/ Comment ID(in) GAS LIFT, Top(ftKB) (ftKB) (") Item Description ID(in) 7,523 � 7,737.6 5,901.8 41.94 PACKER BAKER FHL PACK 2.992 LOCATOR, 7,886.1 6,012.6 41.46 BLAST RINGS BLAST RINGS(4) 2.992 7.577 SY, 8,059.1 6,140.7 43.04 LOCATOR BAKER LOCATOR SEAL AS - 4.000 7,57a 8,060.0 6,141.3 43.04 PACKER BAKER FB-1 PERMANENT PACKER PBR.7.584 l i _.. � 3.000 PACKER,7,607 8,0633 6,143.8 43.07 SBE BAKER SEAL BORE EXTENSION 2.750 88,076.9 6,153.7 43.19 NIPPLE CAMCO D NIPPLE NO GO 1♦ 2.984 8,086.3 6,160.7 43.27 SOS BAKER SHEAR OUT SUB NIPPLE,7,659 MI Other In Hole ireline retrievable a lu e s valves, a um rs fish etc. II Top Depth (ND) Top Inc! Comment Run Date ID(in) Top(ftKB) (ftKB) (1 Description 5/RunDat 0.000 OVERSHOT, 'ai 7,746.0 5,908.0 41.90 CATCHER CATCHER @ 7755' 7,70a 7,755.0 5,914.7 41.85 PLUG WEATHERFORD WRP TOTAL LENGHT 34.91' 5/17/2013 0.000 9/29/1997 2.375 PBR,7,724 7,940.0 6,052.8 41.97 PATCH 20'HES Tubing Patch;Set over GLM#9(7775') 929/1997 2.375 PACKER,7,738 .-' 7,990.0 6,090.0 42.41 PATCH 25'HES Tubing Patch 4/10/1994 1.813 CATCHER, 8,076.9 6,153.7 43.19 REDUCER AVA NIPPLE REDUCER 4/10/1994 7.746 •y°r•�•. PLUG.7,755 h. 8,600.0 6,524.9 45.55 FISH 1"DV w/BK latch Lost in Hole 10/3/1988 PRODUCTION. 7I775 Perforations&Slots I Shot PRODUCTION. Top(ND) Btm(TVD) Dens 7,�` Btm ftKB (ftKB) Zone Date (9h.- Type Comment Top(ftKB 7,920.0 7,961.0 6,037.8 6,068.5 C-4 C-3,1Q-06 4/13/1985 12.0 IPERF 5"Sequential HD Gun IPERF, 7,920-7,961 7,985.0 8,005.0 6,086.3 6,100.7 C-1,UNIT B, 4/13/1985 12.0 IPERF 5"Sequential HD Gun PATCH,7,940 1Q-06 8,170.0. 8,220.0 6,221.2 6,257.1 A-4,A-3,10-06 4/13/1985 4.0 IPERF 4"JJ II Csg Guns IPERF. - 8,300.0 8,316.0 6,313.8 6,324.4 A-2,1Q-06 4/13/1985 4.0 IPERF 4"JJ II Csg Guns 7,985$005"\ PATCH,7,990 l. I Notes:General&Safety Annotation j_. End Date 4/14/1994 NOTE:WORKOVER 10/6/2010 NOTE:View Schematic w/Alaska Schematic9.0 6040 PRODUCTION, ' 1/17/2012 NOTE:WAIVERED WELL OA x FORM,NO GAS LIFT ALLOWED LOCATOR,OR. 8.059 PACKER,8,060 Mandrel Details Port SSE,6063 Top Depth Top Valve Latch Size TRO Run -_: 5... (ND) Inc/ OD NIPPLE,8077 VIF N...Top(ftKB) (ftKB) r) Make Model (in) Sery Type Type ON (Pell Run Date Corn... REDUCER, 8,077 1 3,085.2 2,669.5 47.37 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/26/2013 , 2 4,603.2 3,718.4 48.49 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/26/2013 SOS,8,086 .- 1 GAS LIFT DMY BK-5 0.000 0.0 3 5,745.9 4,498.5 46.63 CAMCO KBMG 4 6,636.6 5,113.0 44.81 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6262013 IPERF, ' 5 7,280.4 5,568.8 44.79 CAMCO KBMG 1 GAS LIFT SOY BKK 0 000 0.0 626 2013 DCK-2 8,1708,220 6 7,522.5 5,743.8 43.35 CAMCO KBMG PERF. 8,3091.79 - 8 7,774.8 5,929.5 41.96 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 8/14/1997 9 7,844.8 5,981.8 41.65 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 5/172006 Closed FISH.8,600 • 10 8,039.7 6,126.4 42.87 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 4/10/1994 Closed PRODUCTION, 1.668-8,625 TD,8,645 • • KUP 1Q-06 ConocoPhillips AiaskR,CT. Conoco MOOS KB-Grd(ft) Rig Release Date ••• 41.79 2/25/1985 Well Conk, -10-06,7/2/2013 6:41:08 AIN Schematic-Actual HANGER,25 Notes:General&Safety End Data Annotation 4/28/2013 NOTE: UPPER C-SAND MERLA PATCH DROPPED DOWN HOLE APPARENTLY-175 FT. - 1 CONDUCTOR,_ 1 1 36-103 NIPPLE,534 0 OM PROD TIE-BACK, 27-1,703 GAS LIFT, 3,085 SURFACE, 36-4,406 GAS LIFT, 4,603 GAS LIFT, 5,746 NM GAS LIFT, 6,637 NMI GAS LIFT, 7,280 EMI GAS LIFT, __- •_ 7,523 LOCATOR NEI 7,577 SEAL ASS Y, 7,.588 8 PBR,7,584 1 PACKER,7,607 MN NIPPLE,7,659 •;1.-J OVERSHOT, --I 7,708 P6R.7,724 ft PACKER,7,738 CATCHER. 7,746 -� PLUG,7,755 Stit PRODUCTION, 7,775 PRODUCTION, 7,845 IPERF, - - 7,920.7,961 PATCH,7,940 IPERF. _ 7,985.8,006 - 1 PATCH,7,990 = _. � I PRODUCTION, 8,040 LOCATOR, 8,059 PACKER,8,060 SSE,8.063--- NIPPLE,8,077 REDUCER, ofi.t: 8,077 SOS,8,086 IPERF. m 8,170-9,220 171 IPERF, .^i 8,300-8,316 .._. )^ FISH,8,600 -� PRODUCTION, 1,668-8,625 TD,8,645 - • • • 1Q-06 Pre-Rig Well Work Summ410 _ DATE SUMMARY 3/27/2013 (PRE RWO): RIG WORK-MITIA(PASSED) @ 2500 PSI, T POT(PASSED), T PPPOT(PASSED), IC POT (PASSED), IC PPPOT(PASSED), FUNCTION TEST LDS (ALL FUNCTIONED PROPERLY). 4/27/2013 MEASURED BHP @ 8109' SLM: 2703 PSI. DRIFTED TBG TO PATCH @ 7765' RKB WITH 2.79" DUMMY WRP. IN PROGRESS. 4/28/2013 PULLED DV @ 7675' RKB. PULLED CATCHER/WRP DRIFT OFF PATCH TOP @ 7917 SLM. NOTE: C SAND PATCH APPEARS TO HAVE MOVED DOWN HOLE. COMPLETE. 5/13/2013 RAN IN HOLE TO SET A WRP AT 7755'. HUNG UP AT THE SSSV ON THE WAY DOWN AND HAD TO GET PUMPED FREE BY LRS. MADE IT TO BOTTOM, AND WAS NOT ABLE TO PULL UP HOLE DUE TO THE PLUG HANGING ON A GLM AND HAD TO MOVE THE PLUG DOWN TO 7801'. 5/16/2013 PULLED WRP @ 7801' RKB. DISPLACED TBG WITH HOT DSL & BRUSH'n FLUSH DESIRED WRP DEPTH. DRIFT TO 7800' MD WITH DUMMY SETTING TOOL &WRP, NO PROBLEMS. READY FOR E/L. 5/17/2013 SET WRP AT 7755', IN FIRST FULL JOINT BELOW THE UPPER PACKER. CORRELATED TO TUBING TALLY, CCL TO MID-ELEMENT 10.8'. READY FOR S/L 5/18/2013 ATTEMPTED COMBO MIT; CSG LARGLY GAS, WILL REQUIRE CIRC OUT. SET CATCHER @ 7155' RKB. IN PROGRESS. 5/24/2013 Cirtculated tubing and IA to inhibited seawater with diesel cap freeze-protect in both to 1900'TVD. Performed three failing CMITs; see attached pump report and MIT Form. S • ConocoPhiIIirs Time Log & Summary Wellview Web Reporting Report Well Name: 1Q-06 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 6/11/2013 6:00:00 AM Rig Release: 6/27/2013 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/09/2013 24 hr Summary Move Rig from 2W to 1Q pad. 00:00 00:00 24.00 MIRU MOVE MOB P Move rig and equipment to 1Q pad 36/10/2013 Complete move to 1Q and stage and prep equipment. Rig on location 16:30. Move over well and set pit module. 00:00 16:30 16.50 0 0 MIRU MOVE MOB P Move rig to 10, Rig on the pad 16:30. 16:30 00:00 7.50 0 0 MIRU MOVE MOB P Prep location for rig spotting. Spot rig over well and lay Herculite. Set pits and Herculite same. 36/11/2013 Set up berms, raise derrick,set up rig,tiger tank and hard lines. Rig up on well.Accept Rig @ 06:00 hrs, 6-11-2013.Test lubricator,pull BPV,test circ lines,displace well to 8.6 ppg brine, monitor well-static, install BPV,blow down lines, Nipple down 3-1/8"5m tree and tubing head adapter, NU BOPE. 00:00 02:00 2.00 0 0 MIRU MOVE RURD P Raise Derrick, Bridle down, Pin blocks to Top Drive, Hook up innerconnects lines, Plug in electrical lines to pit complex, start berming rig. 02:00 06:00 4.00 0 0 MIRU MOVE RURD P R/U rig floor, Hook up stand pipe and cement line, Continue berming rig, Move x-over's to sub rack, Bring on load of water to pits, R/U Circ manifold and lines in cellar for well kill. Rig accepted @ 0600 hrs 6/11/2013. 06:00 07:30 1.50 0 0 COMPZ RPEQP1COND P Bring on 8.6 ppg Seawater and build volume. Blow through hard line to tiger tank and secondary kill line. 07:30 10:30 3.00 0 0 COMPZ RPEQP1OTHR P P/U lubricator and M/U to tree,Test to 1000 psi, pull BPV,TBG= 100 psi, IA=20 psi, OA 20 psi. 10:30 11:00 0.50 0 0 COMPZ RPEQP1OTHR P Rig up to TBG on tree. 11:00 11:30 0.50 0 0 COMPZ RPEQP1OTHR P Fill Mud Lines and test to 3500 psi, good.Test lines to Tiger Tank to 3500 psi, Good. 11:30 12:00 0.50 0 0 COMPZ RPEQP1CIRC P Pump 40 bbls down IA,with returns to Tiger Tank, Start IA=20 psi, TBG=100 psi,2 bpm ICP=200 psi, FCP=350 psi. 12:00 14:30 2.50 0 0 COMPZ RPEQP1CIRC P Pumped 35 bbls of Deepclean down TBG followed by 282 bbls of 8.6 ppg 95°Seawater©3 bpm and 460 psi. 14:30 15:00 0.50 0 0 COMPZ RPEQPI OWFF P Monitor well for 30 mins,0 psi on IA/ OA. Page 1 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 0 0 COMPZ RPEQPI OTHR P FMC installed 3"ISA BPV and pressure test to 1000 psi 30 mins (Pumping through IA). 16:30 18:00 1.50 0 0 COMPZ RPEQPI OTHR P Blow down&RID circ lines to cellar and Tiger Tank. 18:00 20:00 2.00 0 0 COMPZ RPEQPI NUND P FMC bleed down SSSV control line (Control line is locked out), nipple down tree&adapter. Load and strap 237 jts 3.5"dp in pipe shed. 20:00 00:00 4.00 0 0 COMPZ RPEQP1NUND P Nipple up adapter(7-1/16 5m x 11" 5m),mud cross, BOP stack. Respool DS Tugger. 06/12/2013 Finish N/U BOPE, R/U testing equipment,Test all components 250 low 3500 high. 00:00 03:00 3.00 0 0 COMPZ RPEQP1 NUND P Finish Nippling up BOPE 03:00 04:00 1.00 0 0 COMPZ RPEQP1BOPE P R/U to test BOPE with 7"test joint, fill stack and lines. 04:00 12:00 8.00 0 0 COMPZ RPEQPI BOPE P Test BOPE,250 low 3500 high, Recored on chart,Tested upper and lower rams,Annulur on 3.5"test joint, Upper&lower[BOP valves, TIW&dart valves, Choke HCR, Rig floor kill&manual valves. Choke valves 1,2,3,4,5,6,7,8,9,10,11,12,13,15. 12:00 13:00 1.00 0 0 COMPZ RPEQPI BOPE T Trouble shoot Koomey system, repair Choke HCR 4-way valve. 13:00 14:30 1.50 0 0 COMPZ RPEQPI BOPE T Test kill HCR valve,failed to test. 14:30 16:30 2.00 0 0 COMPZ RPEQPI RGRP T Replace Kill HCR valves, repair choke HCR 4-way valve. 16:30 21:00 4.50 0 0 COMPZ RPEQPI BOPE P Test Blind rams,outside annulur valve on mud cross, Kill line unibolt& flange to kill HCR,Test inside annulur valve,250 low 3500 high for 5 min each,(AOGCC Jeff Turkington waived witness of test.) 21:00 22:30 1.50 0 0 COMPZ RPEQP1 OTHR P Fluid entering BOP stack from below blanking plug and BPV, open HCR, open blind rams, no flow,bubbles in fluid column, IA pressure dropped from 60 psi to 30 psi in 1.5 hrs. 22:30 00:00 1.50 0 0 COMPZ RPEQPI BOPE P Test manual choke valve, R/U 7"test jt. and fill lines. 06/13/2013 Finished testing BOPE, Pull blanking plug, pump do tbg 70 bbls,zero psi, pull BPV, M/U pups&TD,try to pull tbg free to 144K, no go, brk circ and apply 6-1/4 turns w/3K torque, no go,had 4.75'stretch with 144K up wt. Call out HES e-line&R/U, made string shot and RCT run. Cut made @ 7692.5'MD(Nabors 26E RKB=33.11'), R/D HES&CBU 1.5 times Page 2 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 COMPZ RPEQP1BOPE P Test with 7'Test joint the Hydrill, Dart, Choke valve#14 and Kill HCR valve. Perform draw down on Koomey, Manual=2000 psi,Annular =1300 psi, Koomey start=3000 psi, closed=2100 psi,200 psi= 10 sec, Final=50 sec, Function time: Bag= 7 sec,upper rams=3 sec,Blinds simulated=3 sec, Lower rams simulated=3 sec, HCR's= 1 sec,5 bottles psi avg=2000, Electric recovery=33 sec,Air recovery= 146 sec. 01:00 02:00 1.00 0 0 COMPZ RPEQP1BOPE P L/D 3.5"&7"test joints, pump out stack, P/U joint of dp and M/U blanking plug running tool. 02:00 03:00 1.00 0 0 COMPZ RPEQPI OTHR P Pull Blanking plug and L/D running tool. Rig up to circ down tubing taking returns from IA. 03:00 04:00 1.00 0 0 COMPZ RPEQP1CIRC P Pump 1 bpm with 170 psi down through BPV and tubing, Pumped 70 bbls total.Zero pressure on tubing. 04:00 05:00 1.00 0 0 COMPZ RPEQP1 OTHR P R/U FMC and pull BPV, L/D T-bar, Make up pups,x-overs, TIW valve and screw into hanger with 10 complete turns. 05:00 06:00 1.00 0 0 COMPZ RPEQP1 OTHR P Zero pressure on back side, BOLDS and unseat hanger-85 K,Continue pulling to 144 K(114 K on tubing) Work several times up to 144 K and unable to pull free. 06:00 12:00 6.00 0 0 COMPZ RPEQPI CIRC P Brk circ with 1 bpm-45 psi, continue working string to 144 K, increase pump rate to 3 bpm-250 psi,4 bpm-460 psi,6 bpm-980 psi,work 3K torque into string with total of 6-1/4 wraps put into string. Continue working string up to 144K with approx.4.75'pipe stretch from unseating hanger with 144K. 12:00 12:30 0.50 0 0 COMPZ RPEQPI CIRC P Circ with 169 gpm-450 psi, Holding tubing in tension with 144K hook load. 12:30 17:30 5.00 0 0 COMPZ RPEQPI ELOG P Set tubing in slips with 25K tension, PJSM. R/U E-Line 17:30 18:30 1.00 0 0 COMPZ RPEQP1 ELOG P RIH with E-Line and 5'string shot with CCL. Record jewelry log. Made a 4-ft(+)correction back to the Completion Tally dated 04/10/1994. Position the 5-ft String Shot to straddle the target cut depth in the middle of the first full Joint above the FHL Packer at 7,702-ft.(CCL to the middle of the String Shot=5-ft) Odometer at 7,697-ft,top of the String Shot at 7,699.5-ft,bottom of the String Shot at 7,704.5-ft. Fire String Shot. Good. Page 3of19 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 0 0 COMPZ RPCOM ELOG P POOH with string shot and confirmed shot fired. 19:30 20:30 1.00 0 0 COMPZ RPCOM ELOG P R/D string shot tools, M/U CCL, EMA, RCT on next run. 20:30 22:30 2.00 0 0 COMPZ RPCOM ELOG P RIH with CCL, EMA, RCT. Record jewelry pass. Make a 11-ft(+) correction back to the Completion Tally dated 04/10/1994. Position the RCT at 7,702-ft(CCL to the RCT =9.5-ft. Odometer at 7,692.5-ft. Set Anchor. Fire RCT at 21:45 hrs. String"jump"at surface. Good indication. Release Anchor with no problem. Log off and observe that the collars above the cut have move up hole due to the string in tension when severing the tubing. POOH with E-Line. 22:30 23:30 1.00 7,692 - 7,687 COMPZ RPCOM ELOG P up Co wtr R RCT fire , (P/U 5') nei 93K tools Top sheave. 23:30 00:00 0.50 7,687 7,687 COMPZ RPCOM CIRC P Brk circ and circ with 104 spm,252 gpm,830 psi. SPR=#1 pump @ 2 bpm, 110 psi, 3 bpm,210 psi. 36/14/2013 Finish circ, Monitor well, Pull and L/D landing pups&hanger, POOH&L/D 3.5"TBG, R/D GBR tools, Service rig,M/U Baker Wash over scraper BHA#1, Single in from shed with200 jts of 3.5"dp to 6547' 00:00 00:30 0.50 7,687 7,687 COMPZ RPCOM CIRC P CBU 1.5 times @ 6 bpm,810 psi, Mud wt in/out=8.6 ppg. 8 bubbling/Boiling on bottoms up,flow check no flow.No Pit gain. 00:30 01:00 0.50 7,687 7,687 COMPZ RPCOM CIRC P Monitor well for 30 min, (Static) 01:00 02:00 1.00 7,687 7,659 COMPZ RPCOM PULL P Pull hanger t Break do, Up wt== 90K, Dn wt= joints&L/D hanger.Attach SSSV control line to spooler. 02:00 11:00 9.00 7,659 0 COMPZ RPCOM PULL P POOH L/D 3.5"tbg, L/D 243 full joints and 1 cut joint, leng=18.09'Up wt=90K, Dn wt=65K, Recovered 30 SS bands to top of SSSV, All jewelry came out in order from previous tally. Hole took15.53 bbls over calculated displacement. 11:00 12:00 1.00 0 0 COMPZ RPCOM PULD P Rig down GBR tools, clear rig floor of pups and hanger, clean rig floor. 12:00 12:30 0.50 0 0 COMPZ RPCOM SVRG P Service Rig anf floor handling equipment 12:30 17:00 4.50 0 242 COMPZ WELLPF PULD P M/U BHA#1 as per Baker Rep. F/surface 17:00 00:00 7.00 242 6,547 COMPZ WELLPF TRIP P RIH,picking F/up 200 joints 200 oMD dp 06/15/2013 Finish RIH w/clean out BHA,tagged @ 7692'MD, Ream over stub to 7706'MD, Decision made to stop due to possible PBR damage,CBU&POOH, Found some junk from SS bands, M/U&RIH with lower 7"RBP set&test same, POOH, M/U upper 7"RBP&RIH to 3421'MD. 00:00 I 01:30 1.50 16,547 7,623 1COMPZIWELLPFITRIP P IRIH P/U wtngles F 6, wt T/7,623 MD, Page 4of19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 7,623 7,706 COMPZ WELLPF REAM P Brk circ, Rate=5 bpm, 935 psi,40 RPM, Up wt with pump= 135K, Dn wt with pump= 100K, Rot wt= 117k, Tq=5k,Wash&Ream F/7,623'T/ 7,697',(Tagged fill @ 7,692'MD and did not see the top of the stub with BHA)set 5K down @ 7,697', Rotate down F/7,697'T/7,706'set down 5K,Tq up to 6/7K,with no pump increase. P/U and shut down rotary, 5/O to 7,706'with 10K. Called town and discuss with Engineer that Baker had enough room to fish over stub(12')and avoid any possible damage to top of the PBR. 02:30 04:00 1.50 7,706 7,685 COMPZ WELLPF CIRC P P/U to 7685'and CBU 1.5 times @ 6 bpm,1500 psi,and 9 bpm,2515 psi. Shut down and monitor well(static) 04:00 07:00 3.00 7,685 0 COMPZ WELLPF TRIP P POOH F/7,685'T/surface, standing back dp and DC's, Up wt= 140K, Dn wt=105K, 13.3 bbls over calculated displacement 07:00 08:30 1.50 0 0 COMPZ WELLPF PULD P Lay down clean out BHA#1,clean out junk basket and found several partial pieces of SS bands,clear floor of tools. 08:30 10:00 1.50 0 0 COMPZ WELLPF SVRG P Clean off floor and service rig, Blocks, roughneck,Top Drive, (SIMOPS loading pipe shed with 3.5" TBG) 10:00 12:00 2.00 0 3,312 COMPZ WELLPF TRIP P M/U lower 7" RBP(Wireline set-hydraulic)as per Baker Rep., 60/90 FPM,easy in&out of slips, F/ surface T/3,312'MD, Up wt=75K, Dn wt=67K. 12:00 15:00 3.00 3,312 7,490 COMPZ WELLPF TRIP P RIH F/3,312'T/7,490'MD 15:00 15:30 0.50 7,490 7,459 COMPZ WELLPF PLUG P Set 7" RBP @ 7,490'MD,pump down 1.5"ball @ 2 bpm, 150 psi, Pressured to 2800 psi, P/U to 133K, (3K over)to shear, pulled up to 7,459' MD.Center of element @ 7490',top of fishing neck @ 7487'. 15:30 17:00 1.50 7,459 7,459 COMPZ WELLPF CIRC P CBU at 7,459'MD @ 3 bpm, 365 psi. 17:00 18:00 1.00 7,459 7,459 COMPZ WELLPF PRTS P Pressure test lower RBP to 3500 psi for 30 min and chart. Bleed off and monitor well for 30 min(Static) 18:00 22:00 4.00 7,459 0 COMPZ WELLPF TRIP P POOH F/7,459'T/surface 22:00 22:30 0.50 0 0 COMPZ WELLPF PULD P L/D Baker RBP running tool. 22:30 23:00 0.50 0 0 COMPZ WELLPF PULD P P/U Upper 7"RBP Model G assembly. 23:00 00:00 1.00 0 3,421 COMPZ WELLPF TRIP P RIH F/surface T/3,421'MD. Page 5 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/16/2013 24 hr Summary Finish RIH W/upper RBP&set @ 3979'COE,Test&monitor well, POOH&RIH w/mule shoe, Dump 21 sks of sand,TOS @3923'MD, Reverse 200 bbls 170°brine, Monitor well, POOH, L/D mule shoe, Monitor well, N/D BOPE, R/U hydrate tight and grow casing 7-5/8"w/21 cycles, R/D tools, BOLDS and remove packoff, Engage 7"with spear& P/U 132K(50K over calc.string wt)re-set slips, L/D tools, N/U BOPE. 00:00 00:30 0.50 3,421 3,979 COMPZ WELLPF TRIP P Continue RIH with upper 7"RBP F/ 3,421'T/3,979'MD, Up wt=85K, Dn wt=75K. 00:30 01:00 0.50 3,979 3,979 COMPZ WELLPF MPSP P Set Model"G"RBP,COE @ 3,979', Top of FN @ 3,974' Btm Plug @ 3,985' MD's as per Baker Rep. 01:00 02:30 1.50 3,979 3,884 COMPZ WELLPF MPSP P Rack back stand and R/U and test RBP with 51 stks to 3500 psi and chart same for 30 min. (Good) perform draw down test to zero psi and monitor well for 30 min, (Static) 02:30 04:00 1.50 3,884 0 COMPZ WELLPF TRIP P POOH and lay down running tool 04:00 05:30 1.50 0 3,914 COMPZ WELLPF TRIP P M/U 5'Mule shoe and X-O and RIH on 3-1/2"dp T/3914'MD,60'above top of RBP FN. 05:30 08:00 2.50 3,914 3,787 COMPZ WELLPF MPSP P R/U and dump 21 sacks of sand down drill pipe, 1260#,to cover 50' chase with 24.6 bbls(Pipe Volume) 2 bpm, 40 psi and pull up to3885' MD,Wait 1 hour for sand to settle, TIH and tagged sand @ 3923'MD, set down 2K WOB, POOH to 3787' Pre job safety meeting w/Little Red while sand falling. 08:00 11:00 3.00 3,787 3,787 COMPZ WELLPF CIRC P R/U Little Red and test lines and reverse circ.200 bbls of 170°brine @ 1.5 bpm, 350 psi, highest temp. seen back at flow line was 130°. Open OA to tiger tank, No fluid gained, R/D Little Red, Monitor well (Static) 11:00 12:00 1.00 3,787 1,047 COMPZ WELLPF TRIP P POOH F/3,787'T/1,047'MD 12:00 13:30 1.50 1,047 0 COMPZ WELLPF TRIP P POOH F/1,047 T Surface, L/D Mule shoe and X\O sub.clear rig floor. 13:30 14:00 0.50 0 0 COMPZ WELLPF OWFF P Monitor well(Static) 14:00 17:30 3.50 0 0 COMPZ WELLPF NUND P N/D stack and set back on stump and secure, remove adapter spool (7-1/16"5m x 11"5m). 17:30 20:30 3.00 0 0 COMPZ WELLPF OTHR P PJSM on using hydra-tight tools, R/U and release tension from 7"casing with 21 cycles, Growth=7-5/8"on high side and 7-1/2"on low side, R/D hydra-tight tools. 20:30 22:00 1.50 0 0 COMPZ WELLPF RTWH P BOLDS and remove 7"packoff. 22:00 23:30 1.50 0 0 COMPZ WELLPF FISH P M/U Baker spear assembly and engage 7"-Pick up to 132K(50K over calculated string wt)-set slips- release spear and L/D&one joint of 3.5"dp. 23:30 00:00 0.50 0 0 COMPZ WELLPF NUND P Prep cellar to nipple up BOPE. Page 6 of 19 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/17/2013 24 hr Summary N/U 11"BOPE,service rig,spot HES wireline unit, MU CBL toolstring, RIH tag sand @ 3919'WLM, POOH f/ tool string failure, Re-run CBL(Est TOC @ 2026')(free @ 1775'),string shot @ 1696'WLM, run Baker Atlas mech pipe cutter to 1665',attempt to cut 7"casing, POOH, change blade, re-run to 1666',2nd attempt was made with no success, Decision made to run Baker multi-cutter, R/D HES e-line and Baker Atlas tools, M/U Baker cutter on 3.5"dp&RIH and locate 7"casing collar @ 1573'to 1536'MD and confirm dp tally is on depth. 00:00 03:00 3.00 0 0 COMPZ WELLPF NUND P Continue to nipple up: 11"3m x 5m DSA, 11"TR3 BOP stack, Kill line, bell nipple,turnbuckles. 03:00 03:30 0.50 0 0 COMPZ RIGMNT SVRG P Service rig and top drive. Perform derrick inspection. 03:30 06:00 2.50 0 0 COMPZ WELLPF RURD P Spotting Halliburton"E"line unit, Rig up, MU tool string f/Cement bond log of cement behind 7"x 9-5/8" casing. 06:00 08:00 2.00 0 0 COMPZ WELLPF ELOG T RIH w/HES CBL toolstring 24.5': 1-7/16"x 1-3/8"OD cable head w/ 1.375"OD fishing neck,2-3/4"OD centralizer,2-3/4"OD CBL,2-3/4" OD centralizer,2-3/4"OD CCL, 2-3/4"OD GR,2-3/4"OD Centralzier ,tag sand @ 3919'WLM. POOH to change tools. (CBL tool failure). 08:00 11:00 3.00 0 0 COMPZ WELLPF ELOG P Change out CBL tool. RIH w/24.5' CBL toolstring to 3919'. Log while coming up. Estimated top of cement @ 2026'WLM per rig engineer. Clean TOC @ 1775'WLM. POOH, L/D CBL tool string. 11:00 12:00 1.00 0 0 COMPZ WELLPF ELOG P MU HES string shot tool string 22.52': 1-7/16"x 1-3/8"OD cable head w/1.375"OD fishing neck, 1.688"OD weight bar, 1-11/16"OD roller w/2"OD wheels, 1.688"OD weight bar, 1-11/16"OD Roller w/2" OD wheel,CCL, 1.688"OD 6'long shot rod. 12:00 13:00 1.00 0 0 COMPZ WELLPF ELOG P RIH w/240 grain/3 wraps string shot. Tie into the CBL dated 06/17/2013. CCL to the center of the String Shot =5-ft. Log String Shot into place and straddle the 7"Casing Collar at 1,696'WLM. Odometer= 1,691-ft, top of String Shot=1,693.5-ft,7" Collar= 1,696-ft, bottom of the String Shot= 1,698.5-ft. Fire String Shot. Good. POOH. 13:00 14:00 1.00 0 0 COMPZ WELLPF PULD P Lay down e line tool string(string shot). 14:00 15:00 1.00 0 0 COMPZ WELLPF PULD P PU/MU Baker Atlas wireline mechanical pipe cutter assembly 18.60': 1.37"A3 cable head, CCL, 2.13"OD Mechanical pipe cutter electronics, 3.25"ODMechanical pipe cutter mandrel. Page 7 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 19:00 4.00 0 0 COMPZ WELLPF ELOG T RIH w/Baker Atlas mechanical pipe cutter on HES Wireline. Correlate to the HES CBL dated 06/17/2013. Made a(+)14-ft correction. Odometer=Cutter Blade depth. Position the Cutter Blade at 1,665' WLM. Begin cutting on 7"26 ppf, J-55, BTC-m Casing at 16:45 hrs. Cutter Blade made contact with the ID of the Casing(6.276"). First half of cut went well, —50%of the wall thickness...then progress slowed down to nothing. Final depth of the cut=6.680"(0.404"). Trip out to trouble shoot. Observed some possible chipped teeth on blade. Change blade. (Note: Tool worked fine as far a responding to motor RPM changes,cutter feed rates,and voltage parameters). 19:00 21:00 2.00 0 0 COMPZ WELLPF ELOG T Trip in the hole w/Baker Atlas Cutter (second attempt)on HES wireline to 1,666-ft WLM. Begin cutting on 7" 26 ppf,J-55, BTC-m casing at 19:23 hrs. Start cutting at 5,600 RPMs, Cutter feed rate=0.20 mm/min. The second attempted cut acted just like the first attempt.. Tool responded good. The first 40-45%of the cut depth went fine,then progress slowed down to nothing. Final cut depth was once again 6.680". Note Tool was programmed for the Cutter Blade to make a maximum cut of 7.400". POOH. Discuss plan forward with Anchorage Engineer. Rig down. Release HES Wireline Unit and Baker Atlas. 21:00 21:30 0.50 0 0 COMPZ WELLPF ELOG P R/D E-line equipment,Talked to town Engineer and decision made to go in with Baker cutter and complete the cut. 21:30 22:00 0.50 0 0 COMPZ WELLPF PULD P P/U Baker Hughes muti-cutter BHA, BHA length=8.25' 22:00 00:00 2.00 8 1,573 COMPZ WELLPF TRIP P RIH F/surface T/1,554'MD, P/U wt= 55K, SOW=52K, Open cutter blades and locate 7"casing collar @1,536'and 1,573' MD(a 37'jt) three joints above the pervious cut attempt @ 1,666'MD. 06/18/2013 Space out and cut 7"casing at 1667.5'MD,Arctic pack swapping out, R/U and CBU 8.6 ppg do 7"&out to tiger tank, monitor well, POOH&M/U spear and engage 7"stub, P/U 1 foot, Pipe is free, PJSM, R/U LRS and displace arctic pack with diesel followed by 120 bbls clean sea water followed by an additional 121 bbls of 8.6 from pits, Monitor well, N/D stack and pull slips N/U stack, PJSM, R/U and L/D 7"casing, Strap and Baker both on depth @ 1667.5' MD, R/U and test BOP body and flange break 250/3000 psi,install wear ring, M/U Baker 9-5/8"scraper BHA, RIH to 1662'MD,circ 289 bbls of heat sea water to tiger tank, POOH and L/D Baker scraper. Page 8 of 19 • • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 1,573 1,667 COMPZ WELLPF TRIP P RIH and space out to cut 7"casing @ 1667.5 MD as per Baker Rep. Cut casing with 80 RPM,Tq= 1100K, PSI=550, Start cut and complete cut in 3 min, Pressure dropped to 250 psi, and smooth out. 01:00 01:30 0.50 1,667 1,667 COMPZ WELLPF OWFF P Monitor well,Arctic pack swapping R/U to circ to tiger out and bubbling, 9 tank. 01:30 02:00 0.50 1,667 1,667 COMPZ WELLPF CIRC P CBU @ 3 bpm with 275 psi. 02:00 03:00 1.00 1,667 0 COMPZ WELLPF TRIP P POOH F 1667'MD and L/D Baker cutter. 03:00 03:30 0.50 0 0 COMPZ WELLPF FISH P P/U Baker spear and engage 7" stub, Pull free with 70 K up wt, Picked up 12"to confirm casing was cut. 03:30 04:00 0.50 0 0 COMPZ WELLPF SFTY P PJSM with Crews, Little Red and Truck Drivers on displacing arctic pack. 04:00 06:00 2.00 0 0 COMPZ WELLPF CIRC P Pressure test lines with Little Red to 2500 psi, LRS pumped 170 bbls of 100°LEPD diesel down 7"out the OA to tiger tank, ICP with 2.5 bpm 250 psi, FCP with 2.5 bpm 200 psi, shut down and empty tiger tank, 06:00 07:00 1.00 0 0 COMPZ WELLPF CIRC P Line up on pill tank and pump 40 bbls of deepclean followed by clean sea water from truck,followed by another 121 bbls from the active system in the pits,(8.6 ppg)and clean returns back. ICP=6.5 bpm 460 psi, FCP=6.5 bpm 570 psi. Shut down pumps and monitor well (Static) 07:00 08:30 1.50 0 0 COMPZ WELLPF NUND P N/D stack and pull Cameron slips, N/U BOP stack. 08:30 11:30 3.00 1,667 0 COMPZ WELLPF PULL P PJSM with GBR, R/U and pull 7" casing, Up wt=65K, L/D 40 full joints, partial joint with spear and cut joint, (Strap= 1667.5 total)Casing pulled clean to Joint#34. 11:30 12:00 0.50 0 0 COMPZ WELLPF PULL P R/D GBR and clear rig floor. 12:00 13:30 1.50 0 0 COMPZ WELLPF BOPE P P/U test joint and set test plug,fill stack with water. 13:30 14:30 1.00 0 0 COMPZ WELLPF BOPE P Test Flange break to 250 low 3000 high and record on chart. (Good)R/D test equipment. 14:30 15:00 0.50 0 0 COMPZ WELLPF BOPE P Install wear ring(9-1/151D) 15:00 15:30 0.50 0 0 COMPZ WELLPF PULD P P/U spear joint and remove spear from 7"joint. 15:30 16:30 1.00 0 0 COMPZ WELLPF PULD P Bring Baker tools up to rig floor for scraper BHA 16:30 17:00 0.50 0 0 COMPZ WELLPF PULD P M/U 9-5/8 casing scraper BHA. 17:00 18:30 1.50 0 977 COMPZ WELLPF TRIP P RIH F/surface T/977'MD Page 9 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code WELLPF CIRC P CC Comment MD 3bpm 195 psi taking 18.30 19:00 0.50 977 977 COMPZ WELL @ returns to tiger tank. 19:00 20:00 1.00 977 1,662 COMPZ WELLPF TRIP P RIH F/977"T/1662'MD, PUW= 60K, SOW=57K. 20:00 22:30 2.50 1,662 1,662 COMPZ WELLPF CIRC P Circ hole clean @ 1662'MD,pumped 290 bbls of hot 8.6 ppg seawater and take returns to tiger tank at 4 bpm 315 psi. 22:30 23:30 1.00 1,662 0 COMPZ WELLPF TRIP P POOH with 9-5/8"casing scraper BHA F/1662'T surface. PUW=60K, SOW=57K at 1662'MD. 23:30 00:00 0.50 0 0 COMPZ WELLPF PULD P L/D Baker 9-5/8"scraper BHA and clear fllor of tools. 36/19/2013 Log with Gyrodata, Made Gamma run and Memory Caliper run from 1741'MD back to surface, R/D HES e-line unit, M/U Baker tandem string mill run and POOH and L/D BHA, R/U and test BOPE,test waived by AOGCC Rep. Bob Noble,all test 250 low 3000 high psi, R/D test equipment and drain stack. 00:00 01:00 1.00 0 0 COMPZ WELLPF PULD P Bring Baker tools to rig floor for up coming Tandem string mill run. 01:00 03:00 2.00 0 0 COMPZ EVALWE ELNE P Spot HES e-line unit and rig up same with Gyrodata. 03:00 05:00 2.00 0 0 COMPZ EVALWE ELNE P RIH with Gyrodata gamma ray tool to 1700"MD and log back to surface. 05:00 07:00 2.00 0 0 COMPZ EVALWE ELOG P L/D Gyrodata Gamma ray and M/U memory caliper tools. 07:00 08:00 1.00 0 0 COMPZ EVALWE ELOG P RIH with caliper tools to 1741'MD and log back to surface. 08:00 09:00 1.00 0 0 COMPZ EVALWE ELOG P L/D tool string tools and rig down HES e-line unit. 09:00 10:00 1.00 0 264 COMPZ WELLPF PULD P M/U Baker tandem string mill BHA T/ 264'MD. 10:00 11:30 1.50 264 1,667 COMPZ WELLPF TRIP P RIH and taP7"stub with SW=55lll @ Confirm depths and numbers, rack back one stand. 11:30 12:00 0.50 1,667 1,667 COMPZ WELLPF CIRC P Circ well with 240 bbls of hot 8.6 ppg seatwater at 10 bpm 830 psi. 12:00 13:30 1.50 1,667 264 COMPZ WELLPF TRIP P POOH F/1,667'T/264'MD, PUW= 60K, SOW=57K. 13:30 15:00 1.50 264 0 COMPZ WELLPF PULD P L/D Baker tandem string mill BHA. Clean and clear rig floor. 15:00 15:30 0.50 0 0 COMPZ WELLPF OTHR P R/U and pull wear ring. 15:30 17:00 1.50 0 0 COMPZ WELLPF BOPE P P/U 3.5"test joint and test plug withTlW&dart valves,set test plug and fill stack. 17:00 20:00 3.00 0 0 COMPZ WELLPF BOPE P Test annular,Char, Kill Des co,Da t IW 1 and 16,250 low 3000 high,Test super/manual choke,250 low 1500 high.Witness of test waived by AOGCC Rep. Bob Noble 20:00 20:30 0.50 0 0 COMPZ WELLPF BOPE P Pull test joint and remove TIW&Dart valves,set test joint,fill lines. 20:30 21:30 1.00 0 0 COMPZ WELLPF BOPE P IBOP, Lower aIBOP,2-7/8"X 5"VBR, 250 low 3000 high. Page 10 of 19 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:30 22:30 1.00 0 0 COMPZ WELLPF BOPE P Perform BOP's draw down test, manual=2000 psi,Annular= 1200 psi,Start=3000 psi,after closing= 2050 psi, Initial 200 psi=11 sec,full recovery=55 sec,Closing times, BPR=3 sec, Sim. Blinds=3 sec, Sim. UPR=3 sec, Ann= 10 sec, HCR Choke= 1 sec, HCR kill= 1 sec, Electric recovery=55 sec,Air recovery= 147 sec,5 bottles @ 2000 psi. 22:30 23:00 0.50 0 0 COMPZ WELLPF BOPE P L/D 3.5"test joint and P/U 7"test joint, M/U x-over and TIW on top,fill lines. 23:00 23:30 0.50 0 0 COMPZ WELLPF BOPE P Test upper pipe rams with 7"test joint and Cv's 12 and 13,250 low 3000 high. 23:30 00:00 0.50 0 0 COMPZ WELLPF BOPE P L/D 7"test joint and drain stack. 36/20/2013 Continue Testing BOP's. Change out Blind ram seal rubbers,and retest same. Good test.Witness of test waived by AOGCC rep Bob Noble. Make up Backoff tool assembly,and RIH with same to locate, Free point and back off w/5-1/2 turns @ 1696'MD, Open pump out sub,circ 1.5 times dp, POOH L/D back off tools, M/U spear, RIH, locate top of 7"and engage Fish, unscrew with 5 turns left, P/U 1'and circ 42 bbls of deep clean pill and circ till returns are clean, POOH with fish, length of fish 27.29'long, L/D spear&fish, Pull wear ring, PJSM, R/U&run 7"casing as per detail. 00:00 03:30 3.50 0 0 COMPZ WELLPF BOPE P Continue testing BOP's. Pull and change out seal rubbers on the Blind rams and retest same to 250/3000 PSI. 03:30 04:00 0.50 0 0 COMPZ WELLPF RURD P Rig down testing equipment,held PJSM. Discuss safety&hazard recognition issues. Discuss procedue to make up and run BOT backoff tool aassembly. 04:00 05:30 1.50 0 315 COMPZ WELLPF PULD P Make up BOT back off tool assembly as per BOT rep.Total length= 314.54' 05:30 07:30 2.00 315 1,897 COMPZ WELLPF TRIP P Trip in hole with Backoff tool assembly to 1897' (Btm of Bullnose) Top pf anchor @ 1685', Btm of anchor @ 1705' 07:30 09:30 2.00 1,897 1,696 COMPZ WELLPF OTHR P Free point and back off collar@ 1696' MD as per Baker Rep.for 5-1/2 turns. 09:30 10:30 1.00 1,696 0 COMPZ WELLPF CIRC P Drop ball rod,shear open pump out sub with 2400 psi,Pump 1.5 times dp volume with 6 bpm 400 psi, POOH to surface. 10:30 12:00 1.50 0 0 COMPZ WELLPF PULD P L/D Baker back off BHA. Clear rig floor. 12:00 12:30 0.50 0 22 COMPZ WELLPF PULD P M/U Baker spear BHA. 12:30 13:30 1.00 22 1,667 COMPZ WELLPF TRIP P RIH F/surface T/1667'MD, PUW= 55K,SOW=54K, Pick up 10K over to engage spear,slack off to 5K over, Unscrew stub with 5 turns to left while manitaining 3 to 5K overpull, P/U 1'off 7"casing string. Page 11 of 19 i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 1,667 1,667 COMPZ WELLPF CIRC P Pumped 42 bbls Deep clean pill @ 8bpm 445 psi, Circ till hole was clean. 14:30 16:00 1.50 1,667 22 COMPZ WELLPF TRIP P POOH F/1667'T/surface, PUW= 57K. 16:00 17:30 1.50 22 0 COMPZ WELLPF TRIP P L/D Baker spear assembly with Fish, Fish length=27.29'. Clear&clean rig floor. 17:30 18:00 0.50 0 0 COMPZ WELLPF OTHR P P/U test joint and pull wear ring. 18:00 20:00 2.00 0 0 COMPZ WELLPF RNCS P Bring centrailizers to rig floor, M/U TIW floor safety valve for 7", R/U GBR to run casing. 20:00 20:30 0.50 0 0 COMPZ WELLPF SFTY P Helded PJSM with crews on running 7"casing as per-detail running order. 20:30 00:00 3.50 0 COMPZ WELLPF RNCS P M/U Baker Cut Lip Guide,triple connect sub, pup,X-over pup, HES cementer, pup and 40 full joints of 7" L-80 TCII 26#casing. 36/21/2013 Make 7"tieback @ 1696'MD,Test connection to 2500 psi, R/D xo's and R/U cement head,shear open cementer w/3380 psi, cir 100 hot sea water, PJSM,turn over to SLB&cement 7"as per program, bumped plugs @ 04:35 hrs CIP,WOC for total of 4 hrs,simops:flush stack and line to cutting tank&blow do same, preform top job with 4-5gal buckets of arctic set,TOC is 3'down from casing head,set emergency slips with 50 over string wt, R/U WACHs cutter and cut 7"landing jt, N/D BOP's remove 11"3M x 5M DSA and N/U tbg head and adapter, FMC tested casing head&pack-off to 3000 psi(Good) N/U BOP stack, CIO upper ram to 2-7/8"x 5"VBR, R/U and test same, R/D test equipment. 00:00 01:30 1.50 0 0 COMPZ WELLPF RNCS P Continue run 7"casing. Change out &installing long bales.SIMOPS: Schlumberger cementers om location rigging up and spotting trucks. Set extra cuttings tank and berm same for cement returns. 01:30 02:00 0.50 0 0 COMPZ WELLPF RNCS P RIH,tag and screw into 7"casing stump at 1696'MD,torque to 10K Ft/lbs, and work string to ensure fully torqued. Pull to 115K(50K over) verify good tie in. 02:00 02:30 0.50 0 0 COMPZ WELLPF PRTS P Made up lines, and test casing to 2000 PSI-5 minutes, and then 2500 PSI-15 minutes. Good test, recorded on chart. Bleed pressure. 02:30 03:00 0.50 0 0 COMPZ WELLPF RURD P Breakout all connections and lay down crossovers from top drive to 7" casing. Make up crossover and cement head. Make up lines. 03:00 03:30 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM with crew, and cement crew. Discuss safety&hazard recognition issues. Discuss Procedure to pump cement job. Pumped at 5 bpm, 175 psi. 03:30 04:00 0.50 0 0 COMPZ WELLPF CMNT P Open up ES Cementer at 3380 PSI, and continue pump 100 BBLS of heated seawater to pits. Page 12 of 19 • Time Logs Date From To D0 S. Depth E. Depth COMPZ WELLPF CMNTde P Turn over to to Schlumberger. Pump 3 04:00 04:30 0..50 0 0 BBLS of water,test lines to 3500 PSI. Batch up and pump 97 BBLS of 15.7 ASL at average rate of 4.5 BPM -observing pressure increase form ICP-298 PSI to FCP-565 PSI. Drop plug,pump 5 BBLS water. 04:30 05:00 0.50 0 0 COMPZ WELLPF CMNT P Turn over to rig, close top pipe rams, and displace cement with seawater to outside cuttings tank at 4 BPM. Observed cement to surface at 230 STKS pumped. Slow pumps to 1.5 BPM,closing lo-torque OA valve and attempt sqeezing cement into suspected hole in 9 5/8 caisng,with 7 BBLS squeezed,continuing to pump to bump plug on depth at 982 STKS. CIP at 04:37 HRS.Continue pressure to 2150 PSI, observing ES cementer closing. 05:00 06:30 1.50 0 0 COMPZ WELLPF WOC P WOC-total of 4 HRS as planned for 500 PSI compressive strength. Flush stack with retarder pill, Drain stack, Flush lines to return tank,Blow all lines down. 06:30 09:00 2.50 0 0 COMPZ WELLPF WOC P WOC-total of 4 hrs, Open bottom and inspect for cement,They were free of cement. Close back up ram doors. 09:00 10:30 1.50 0 0 COMPZ WELLPF OTHR P Check cement top on 9-5/8"X 7" Cement was 11'down, Mix four bucket of arctic set lite and pour into annulus,TOC @ 3'below well head. 10:30 12:00 1.50 0 0 COMPZ WELLPF PULD P Set slips with 50K over string wt,R/D cement head,suck fluid out of landing joint,cut landing joint 12:00 15:00 3.00 0 0 COMPZ WELLPF NUND P N/D BOPs, Remove kill line, riser, turn buckles, Break flange on casing head and removel 1"3M X 5M DSA, Set stack back. 15:00 16:30 1.50 0 0 COMPZ WELLPF NUND P Nipple up TBG head&adapter spool, test casing head and pack-off as per FMC hand to 3000 psi for 10 min (Good) 16:30 20:00 3.50 0 0 COMPZ WELLPF NUND P Nipple up BOP's set stack on well, M/U connections,install kill line, M/U annulus valve,and turn buckles, Install riser. 20:00 22:00 2.00 0 0 COMPZ WELLPF OTHR P Change top set of rams to 2-7/8"X 5" VBRs 22:00 22:30 0.50 0 0 COMPZ WELLPF BOPE P P/U test joint and TIW and test plug, Fill stack 22:30 23:30 1.00 0 0 COMPZ WELLPF BOPE P Test upper rams with VBRs,kill line and unibolt connection with 3.5"test joint,250 low 3500 high. (Good Test) 23:30 00:00 0.50 0 0 COMPZ WELLPF BOPE P R/D test equipment and install wear ring ID=6-3/8" Page 13 of 19 • Time Logs Date From To Dur S.Death E. Death Phase Code Subcode T Comment 06/22/2013 24 hr Summary M/U Baker drill out BHA,C/O/to short bails, RIH to 1588'MD,Wash&ream to 1650'tagged cement, Drill cement to top of HES cementer @ 1672'MD.wash&ream to 1748,CBU,TIH to TOS @ 3922'MD, Pump sweep around and R/U and test casing, POOH and retest 7"casing, M/U Baker junk mill&RIH and dry drill junk up, POOH and Clean magnet and junk baskets, recovered 2 lbs sluge, M/U Baker reverse junk baskets BHA, M/U wear ring running tool, (Wear ring came out with BHA) 00:00 02:00 2.00 0 234 COMPZ WELLPF PULD P M/U Baker drill out BHA,C/O to short bails on Top Drive 02:00 03:00 1.00 234 1,558 COMPZ WELLPF TRIP P TIH F/234'T/1558'MD. 03:00 03:15 0.25 1,558 1,650 COMPZ WELLPF REAM P F/1558'T/1650'MD,Tagged cement © 1650'MD. PUW=60K,SOW= 55K, Rot=60K,Tq off=12K,Tq on 14K,WOB=2/4K, RPM=80, Pump= 6.0 bpm 450 psi. 03:15 03:30 0.25 1,650 1,672 COMPZ WELLPF DRLG P Drill il top of HES cement F/1650' TUW72 60K, SOW=55K, Rot=60K,Tq off_ Tq 12K, T on 14K WOB=5K, RPM- 80, Pump=6.0 bpm 450 •si. 03:30 06:30 3.00 1,672 1,700 COMPZ WELLPF DRLG P Drill H S cementer F/1,672'T/ 1,700'06:30 07:00 0.50 1,700 1,748 COMPZ WELLPF REAM P 6 Wabpm sh ream F/170 T/1748'MD, 07:00 08:00 1.00 1,748 3,829 COMPZ WELLPF TRIP P 9IH F/ SOW8 7/3829 MD. PUW= 08:00 09:00 1.00 3,829 3,922 COMPZ WELLPF REAM P with 1 bpm 75 psi,Tgged9sand @ 3922'MD, P/U 30'and pumped hi-vis sweep at 9 bpm 1500 psi,work pipe with 40 RPM,Tq off=2800 ft/lbs. 09:00 12:00 3.00 3,892 3,892 COMPZ WELLPF PRTS P record on chart, havi gtconsis ant 200-250 bleed off in 30 min, R/U through the head pin, purge air and pressure up to 2500 psi. 12:00 14:00 2.00 3,892 3,892 COMPZ WELLPF PRTS P Perform casing test to 2500 psi. 14:00 16:00 2.00 3,892 0 COMPZ WELLPF TRIP P POOH F/3892'T/surface. 16:00 16:30 0.50 0 0 COMPZ WELLPF PULD P Clean off string magnet and remove 6-1/8"bit and M/U 6-1/8"junk mill as per-Baker Rep. 16:30 17:00 0.50 0 0 COMPZ WELLPF PRTS P R/U and perform casing test against Blind ram to 2500 psi 17:00 18:00 1.00 0 0 COMPZ WELLPF PRTS P While erform casing l and test to 2 00 psi, (Test Good) 18:00 20:00 2.00 0 3,922 COMPZ WELLPF TRIP P F/surface T/3737'MD,Wash tdown F/3737'T/3922'MD with 5 bpm 545 psi. 20:00 20:30 0.50 3,922 3,924 COMPZ WELLPF DRLG P 3-5K, RPM3 60, P/UW=95K,SOW 75K, Rot=81K. 20:30 22:30 2.00 3,924 49 COMPZ WELLPF TRIP P PPOO SOW 974K T/49'MD,PUW= Page 14 of 19 • Time Loos Date From To D0. S9De•th E. •t COMPZ WELLPF PULD de P L/D oBHA and clean string magnet, 22:30 23:00 0.50 49 Clean out junk baskets,2 lbs of sluge recovered and brass shear out pin and one piece of aluminum. Remove junk mill. 23:00 23:30 0.50 0 0 COMPZ WELLPF PULD P M/U Baker reverse junk basket BHA. 23:30 00:00 0.50 0 0 COMPZ WELLPF OTHR P The wear ring was pulled out with the BHA, R/U test joint with wear ring running tool to set new wear ring in place. 36/23/2013 Install wear ring,TIH,Wash&ream do to 3836'drop ball&active reverse basket, POOH,clean out basket small alumium chunks,M/U basket and RIH,Wash&ream 3940'POOH,clean out reverse basket-No debris, had hand full of Brass/aluminum from boot baskets, L/D BHA, P/U RBP retrieving tool, RIH, Latch on to upper RBP, POOH L/D same, M/U lower RBP retrieving tool and RIH, latch on and release RBP,CBU 1.5 times, POOH to 5960'MD. 00:00 00:30 0.50 0 0 COMPZ WELLPF OTHR P Set wear ring(ID=6.125")and L/D 3.5"test joint and running tool. 00:30 02:00 1.50 0 3,836 COMPZ WELLPF TRIP P surface with urfwiith r very junk baskets F! 02:00 02:15 0.25 3,836 3,836 COMPZ WELLPF CIRC P SOW=70K, RPM 30,Tq off=2900 ft/Ibs, Rot wt=80K,drop ball at 02:15 and pressured up to 850 psi at 5 bpm, Increase pump rate to 6 bpm 1645 psi. 02:15 02:30 0.25 3,836 3,929 COMPZ WELLPF REAM P Tagged and @ 3922'try to keep MD wob 3/5K,T/3929'MD,Shut down pump and POOH. 02:30 04:00 1.50 3,929 236 COMPZ WELLPF TRIP P 3929POOH T with reverse junk baskets F/ 04:00 04:30 0.50 236 0 COMPZ WELLPF TRIP P POOH with BHA 04:30 05:00 0.50 0 236 COMPZ WELLPF PULD P tree items,2 pieces off basket, um found and one chunk of rubber. RIH with Baker BHA. 05:00 06:30 1.50 236 3,886 COMPZ WELLPF TRIP P RIH 2 ith Baker re PUW u 9 basket SOW=73K. T/3940' 06:30 07:00 0.50 3,886 3,940 COMPZ WELLPF REAM P MD,6.5 bpm 1650 psi,30 Tgon= 2-3K RPM=30, No WOB seen,CBU @ 7 bpm 1750 psi. 07:00 08:30 1.50 3,940 236 COMPZ WELLPF TRIP P PPOOOHOF 3940' /236'MD,PUW= 08:30 09:30 1.00 236 0 COMPZ WELLPF PULD P Rack back DCs, Clean out reverse junk baskets, recovered nothing, clean out boot baskets recovered handful of brass/aluminum, L/D BHA. 09:30 10:00 0.50 0 0 COMPZ WELLPF OTHR P M lush out Johnny Wacker and same.magnet, 10:00 10:30 0.50 0 0 COMPZ WELLPF PULD P Baker BHA Ito retrieve upper RBP and M/U same. Page 15 of 19 • • Time Logs Date From To D1. S. Depth 3 Depth COMPZ WELLPF TRIP P TIH with Baker retrieveing tool F/ 10:30 12:00 1.50 0 surface T/3892'MD. PUW=90K, SOW=73K. 12:00 13:00 1.00 3,892 3,968 COMPZ WELLPF REAM P $ash&ream psi/PUW=T/3995'M, 65K, Circ to confirm sand at shakers,Wash&ream F/3995'T/ 3968'MD, 10 bpm 1490 psi.CBU. 13:00 13:30 0.50 3,968 3,974 COMPZ WELLPF MPSP P set down 10K upper @ rotate 3974'MD one 4 right P/U with 10K overpull. 13:30 14:00 0.50 3,974 3,974 COMPZ WELLPF CIRC P Pump 20 bbl hi-vis sweep @ 10 bpm/U 5K 1490 psi, circ 14:00 14:30 0.50 3,974 3,974 COMPZ WELLPF MPSP P Release, Rotate it right g5K P U turns while maitaining string wt.,stroke up and down 15'3 times to ensure RBP was free. 14:30 17:00 2.50 3,974 0 COMPZ WELLPF TRIP P POOH F/3974'T/surface, 17:00 18:00 1.00 0 0 COMPZ WELLPF MPSP P L/D RBP and retrieving tool. 18:00 18:30 0.50 0 0 COMPZ WELLPF MPSP P P/U another Baker retrieveing RBP tool 18:30 21:30 3.00 0 7,490 COMPZ WELLPF TRIP P TIH F/SOfaceT/ 90'dMD, PUW= 143K,lower RBP, Pick up 7483'MD, 21:30 22:30 1.00 7,490 7,483 COMPZ WELLPF CIRC P 1420 Had minmal expected gas on BU, 4%flow increase with no pit gain. 22:30 23:00 0.50 7,483 7,483 COMPZ WELLPF OWFF P Monitor well for 30 min(Static) 23:00 00:00 1.00 7,483 5,960 COMPZ WELLPF TRIP P POOH O with Loower RBP. F/7483' 36/24/2013 POOH,L/D lower RBP and retrieving tool, M/U 3.5"overshot, RIH to 7692'TOF sallow 7.5"of fish and attempt to pull free, No Go,dis-engage from fish,CBU had gas back on bottoms up CBU again,monitor well, POOH, L/D overshot&P/U wash pipe BHA, RIH and wash over 3.5"TBG stub to 7714'MD,P/U and pump sweep around, No Gas. 00:00 02:30 2.50 5,960 0 COMPZ WELLPF TRIP P Continue surface and L/D Lower RBP and retrieving tool. 02:30 03:00 0.50 0 215 COMPZ WELLPF PULD P M/U Baker 3.5"overshot BHA,to 215'MD 03:00 06:30 3.50 215 7,596 COMPZ WELLPF TRIP P 1 OK/SOW/7 96 MD, PUW= 06:30 07:30 1.00 7,596 7,596 COMPZ WELLPF SLPC P Slip and cut 1 and 25 of d IIg line, Service 07:30 08:00 0.50 7,596 7,628 COMPZ WELLPF TRIP P bpm F/7 96 50, Pump Tq off=6 0 ft/ 5 PUW= 165K,SOW=95K, Rot= 120K, 08:00 09:30 1.50 7,628 7,697 COMPZ WELLPF FISH P Wash&rage top n 3/5"6 T/7692' 28 stub per Baker to 7697'MD ,Attempt to pull stub free,Max Jar Toad=40K over,(205 up wt.)Max overpull 55K over(220 up wt)unable to pull free. Page 16 of 19 i • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:00 0.50 7,697 7,677 COMPZ WELLPF FISH P Dis-engage from fish as per-Baker Rep. 10:00 12:00 2.00 7,677 7,677 COMPZ WELLPF CIRC P CBU 1x25 times at 5 bpm 825 psi, Gas seen prior and up to BUS, Monitor well for 15 min,gas and flow observed, CBU again, monitor well. 12:00 16:00 4.00 7,677 215 COMPZ WELLPF TRIP P PPOOH F/7677'T/215', PUW= 160K, SOW=90K. 16:00 16:30 0.50 215 0 COMPZ WELLPF PULD P L/D Baker Overshot BHA. 16:30 17:00 0.50 0 236 COMPZ WELLPF PULD P M/U Baker wash-over BHA T/236' MD. PUW=40K,SOW=40K. 17:00 21:30 4.50 236 7,706 COMPZ WELLPF TRIP P TIH F/236'T/7648'MD, Install blow hose.Take SPR's.Wash down to 7706'MD, 5bpm 830 psi,Tagged fill @ 7706'MD. 21:30 23:00 1.50 7,706 7,714 COMPZ WELLPF REAM P Wash&rean F/7706'T/7714'MD, WOB=2/3K, 5 bpm 830 psi,Tq off= 7/8K,Tq on=8/10K,set down 10K @ 7714'MD, Had no drill off, Picked up to 7683'MD. 23:00 00:00 1.00 7,714 7,683 COMPZ WELLPF CIRC P Pump 20 bbl Hi-Vis sweep around @ 8 bpm, 1930 psi, No gas on B.U. 36/25/2013 Pump sweep to surface, Monitor well, POOH, L/D washover BHA, M/U overshot BHA, TIH attempt jar fish loose without success,disengage from fish. POOH and lay down DP and fishing BHA. 00:00 00:30 0.50 7,683 7,683 COMPZ WELLPF CIRC P Finish circ sweep to surface, Monitor well, (Static) 00:30 04:30 4.00 7,683 236 COMPZ WELLPF TRIP P POOH F/7683'T/236'MD, Monitor well. 04:30 05:00 0.50 236 0 COMPZ WELLPF PULD P L/D Baker wash over assembly and clear rig floor. 05:00 06:00 1.00 0 215 COMPZ WELLPF PULD P M/U Baker 3.5"Overshot BHA to 215'MD. 06:00 08:30 2.50 215 7,692 COMPZ WELLPF TRIP P RIH F/215'T/7692'MD 08:30 09:30 1.00 7,692 7,692 COMPZ WELLPF CIRC P Circulate and condition mud above fish;no gas seen. 296 GPM, 1470 psi 09:30 11:00 1.50 7,692 7,692 COMPZ WELLPF FISH P Obtain parameters; PU=165K, SO= 95K, ROT=124K with 20 RPM, 8K Torque. Set grapple with 10K up pull and worked up to 185K. Gradually worked pull up to 205K up and jar numerous times with no movement. Released from fish. 11:00 11:30 0.50 7,692 7,692 COMPZ WELLPF CIRC P Circulate bottoms up at 291 GPM, 1400 psi, observed bottoms up gas. 11:30 14:00 2.50 7,692 7,692 COMPZ WELLPF CIRC P For the purpose of a Well Control Drill,the well was shut in with CRT =85 seconds. Circulate through choke at 3 BPM; ICP=370 psi. FCP Csg=360 psi, DP=60 psi. Monitor for flow at shakers; Static. 14:00 15:00 1.00 7,692 7,692 COMPZ WELLPF CIRC P Circulate and condition for 1.5 BU at 5 BPM with 790 psi;gas detected at BU. Monitor flowline for 15 minutes; minimal but constant flow at flowline. Page 17 of 19 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:001 17:00 2.00 7,692 7,692 COMPZ WELLPF CIRC P Build volume and weight,circulate at 5 BPM, 790 psi, increase weight from 8.6 to 8.8 PPG. Gas detected at BU. Monitor well for 15 minutes Static. 17:00 00:00 7.00 7,692 362 COMPZ WELLPF TRIP P Lay down drill pipe while pulling and monitor well at 7223';static. Pull out while laying dow to 362'; PU=172K, SO=95K. 36/26/2013 Monitor well-Static. Finish LD BHA; collars and overshot. Remove wear bushing,flush stack and service rig. Rig up and run completion and tubing as per running order. Spot corrosive inhibitor and circulate a BU with no gas show. Monitor-Static. Land and seat PB overshot at 7715',space out and set packer at 7606'with 2500 psi and 12K overpull to shear PBR. Land and space out tubing,assemble tubing hanger and set. Unseat tubing hanger and circulate in corrosion inhibitor;235 BBL,8.8 ppg by reverse circulating. Land tubing hanger and RILD. Pressure test tubing to 3000 psi for 30 minutes; good test. Pressure test IA to 2500 psi for 30 minutes holding 2000 psi on the tubing;good test. 00:00 00:30 0.50 362 25 COMPZ WELLPF TRIP P POOH laying down DP. 00:30 01:30 1.00 25 0 COMPZ WELLPF PULD P Lay down BHA;jars,overshot and 01:30 03:00 1.50 0 0 COMPZ WELLPF PULD P Pull wear ring and MU johnny whacker to flush stack;flush stack and LD JW 03:00 04:00 1.00 0 0 COMPZ RPCOM RURD P RU casing equipment and stage completion string. 04:00 06:00 2.00 0 45 COMPZ RPCOM RUNL P PJSM for running casing; run completion and tubing. 06:00 14:30 8.50 0 7,706 COMPZ RPCOM RUNL P PJSM for running casing; run completion and tubing. PU=92K, SO=65K. 14:30 15:30 1.00 7,706 7,706 COMPZ RPCOM RURD P Change out bails 15:30 17:30 2.00 7,706 7,705 COMPZ RPCOM RUNL P Run in and tag tubing cut at 7715', set down 30K,then pick up 10'. 17:30 18:00 0.50 7,705 7,705 COMPZ RPCOM CIRC P Circulate 10 BBLs corrosion inhibitor, chase with 70 BBLs 8.8 ppg brine. Flow detected at flow line. 18:00 19:00 1.00 7,705 7,705 COMPZ RPCOM CIRC P Circulate BU at 4.5 BPMwith 535 psi. No gas show at BU. Monitor well for 15 minutes-Static. 19:00 19:30 0.50 7,705 7,705 COMPZ RPCOM CIRC P Circulate 10 BBLs corrosion inhibitor, chase with 70 BBLs 8.8 ppg brine. Flow detected at flow line. 19:30 20:00 0.50 7,705 7,706 COMPZ RPCOM RUNL P Drop ball and rod,then space out to packer set depth. Pressure to 2500 psi to set FHL packer. Pick up to 12K over to shear PBR. 20:00 22:00 2.00 7,705 7,706 COMPZ RPCOM RUNL P Space out to land tubing hanger; LD joints 242,241,240. MU 4'pup,jt 240 and tubing hanger with 4'pup. Land hanger fto check depths-good. 22:00 23:30 1.50 7,706 7,706 COMPZ RPCOM CIRC P Reverse circulate 235 BBLs of 8.8 ppg corrosion inhibitor to displace out brine. 23:30 00:00 0.50 7,706 7,706 COMPZ RPCOM RUNL P Land tubing hanger and RILDs as per FMC. Page 18 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 COMPZ RPCOM PRTS P PJSM for PT, pressure test tubing to 3000 psi for 30 minutes-Good. Bleed tubing to 2000 psi and pressure test IA to 2500 psi for 30 minutes. 06/27/2013 ND BOP, NU Tree and test-Good. Freeze protect with LRS 75 BBL diesel and PT BPV good to 1000 psi. Tree oriented per FMC. Cleaned and cleared cellar, cleaned pits and RD rig for move. Rig released at 23:59 6/27/2013. 00:00 00:30 0.50 0 0 COMPZ RPCOM PRTS P Complete pressure tests of IA and tubing, bleed off and shear SOV at _ 2500 psi. 00:30 01:00 0.50 0 0 COMPZ WHDBO CIRC P Circulate in reverse and forward to make sure transmission from tubing _ to IA clear. 01:00 02:00 1.00 0 0 COMPZ WHDBO RURD P Rig down circulating lines and monitor well for 30 minutes;Static. 02:00 03:00 1.00 0 0 COMPZ WHDBO RURD P Drain stack and install BPV. Test BPV to 1000 psi for 10 minutes; good test. 03:00 05:00 2.00 0 0 COMPZ WHDBO RURD P ND BOP stack, Riser, surface lines. 05:00 06:00 1.00 0 COMPZ WHDBO RURD P Remove old tree and parts from cellar and prep for ND stack 06:00 08:00 2.00 COMPZ WHDBO RURD P Nipple down stack and secure on moving peg. 08:00 09:00 1.00 COMPZ WHDBO RURD P Rig down lines and remove adapter flange. 09:00 09:30 0.50 COMPZ WHDBO PRTS P Install hanger adapter and test to 5000 psi-Good. 09:30 12:00 2.50 COMPZ WHDBO RURD P Orient and Install tree as per FMC. Torque and assembly valves. 12:00 13:30 1.50 COMPZ WHDBO PRTS P Rig up tree for testing and test 250 low and 5000 psi high. 13:30 14:00 0.50 COMPZ WHDBO RURD P RU Little Red lines and equipment. 14:00 15:00 1.00 COMPZ WHDBO DISP P PJSM with LRS. Pressure test LRS lines to 2000 and pump 75 BBLs for freeze protect down IA at 2 BPM with 1230 psi. 15:00 17:30 2.50 COMPZ WHDBO DISP P Place the tubing and IA in communication and allow time to u-tube and settle to static. Final pressures; TBG=0 psi, IA=0 psi. 17:30 18:00 0.50 COMPZ WHDBO RURD P Rig down circulating equipment. 18:00 19:00 1.00 COMPZ WHDBO RURD P Install BPV per FMC and button up tree, RD LRS. 19:00 00:00 5.00 COMPZ MOVE DMOB P Install bridal lines,clean and clear cellar, clean pits, procede with rig move checklist and clear location. Rig Release at 23:59 6/27/2013. Page 19 of 19 • IQ-06 Post-Rig Well Work Summ. DATE SUMMARY 7/2/2013 (AC EVAL) : IA- DDT(INCOMPLETE) OA DDT(PASSED)WILL RETURN AND CONTINUE AT A LATER DATE. 7/6/2013 PULLED BALL& ROD @ 7659' RKB, REPLACED SOV @ 7523' RKB WITH DV. GAUGED TBG TO 2.80"TO RHC @ 7659' RKB. PULLED DV @ 6637' RKB,ATTEMPTED SET OV @ SAME. IN PROGRESS. 7/7/2013 PULLED DV's @ 5746', 4603', 3085' RKB. SET OV @ 6637' RKB AND GLV's @ 5746', 4603', 3085' RKB. PULLED RHC @ 7659' RKB. ATTEMPTED TO PULL JUNK CATCHER @ 7746' RKB. BAILED SCALE/ SCHMOO FROM 7710 TO 7720' SLM. IN PROGRESS. 7/8/2013 BAIL SCALE/SCHMOO & METAL DEBRIS OFF JUNK CATCHER @ 7746' RKB; PULLED CATCHER @ SAME; BAIL SCALE/SCHMOO FROM WRP @ 7755' RKB & PULLED WRP @ SAME (MISSING 2 ELEMENTS). IN PROGRESS. 7/9/2013 ATTEMPTED RECOVER MISSING SEAL ELEMENTS FROM WRP PULLED @ 7755' RKB WITH NO SUCCESS. COMPLETE. • • ‘,0-,,\ THE STATE T Ali sa Gil and Gas F °fl l Ll lS]��1 Commission rR, - GOVERNOR SEAN PARNELL 333 West Seventh Avenue ° • A ' AL Anchorage, Alaska 99501 -3572 ALASY' Main: 907.279.1433 Fax: 907.276.7542 Ian Toomey SCANNED MAY 0 3 2013 Wells Engineer a° ConocoPhillips Alaska, Inc. 1 Q� �" • P.O. Box 100360 ` U Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1Q-06 Sundry Number: 313 -186 Dear Mr. Toomey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this L. - day of May, 2013. Encl. STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COMOION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon j - Plug for Redrill I — Perforate New Pool r" Repair w ell I • '� Change Approved Program r Suspend Time Extension 7 �" ` Plug Perforations E Perforate �" Rill T ubin g Operational Shutdow n ('"" Re -enter Susp. Well - Stimulate r Alter casing Fl • Other: F 2. Operator Name: ✓ 4. Current Well Class: 5. Permit to Drill Number: ✓ ConocoPhillips Alaska, Inc. Development Ir.. Exploratory r 184 -208 3. Address Stratigraphic I Service { 6. API Number: ./ P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21224 - 00 • 7. If perforating, 8. Well Name and Number: V What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes I — No I✓ 1Q -06 9. Property Designation (Lease Number): 10. Field /Pool(s): it ADL 25641 • Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ' 8645 " 6556 none 8600' Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 103' 103' SURFACE 4370 9.625 4406' 3584' PRODUCTION 8592 7 8625' 6542' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7920' 7961', 7986 8005', 8170' 8220', 8300' - 8316' 6038' 6069', 6086 6101', 6221' 6257', 6314' - 6324' 3.5 J -55 _ 7738 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER ' MD= 7738 TVD= 5902 PACKER - BAKER FB -1 PERMANENT PACKER ‘ MD= 8060 TVD= 6141 SSSV - CAMCO TRDP -1A SSSV • MD =1799 TVD =1738 12. Attachments: Description Summary of R I✓ ' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch f Exploratory E Stratigraphic E Development W. • Service I 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/16/2013' Oil I✓ • Gas f" WDSPL r Sus pended f 16. Verbal Approval: Date: WINJ r GINJ r WAG l" Abandoned E Commission Representative: GSTOR E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey © 263 -4773 Email: Ian.A.Toomev conocoohiIlios.com Printed Name Ian Toomey Title: Wells Engineer Signature Phone: 263 -4773 Date y- 7) - /2 Commission Use Only 1 Sundry Number3I 3 ..... / A to Conditions of approval: Notify Commission so that a representative may witness �� Plug Integrity I - BOP Test "Mechanical Integrity Test I Location Clearance I - ` RBDMS MAY - 2 201 Other: 5 o p i - e _ s f f c' UO 0 p5 t. Spacing Exception Required? Yes ❑ No RI Subsequent Form Required: APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date;S ' pproved application Is valid tor 12 months trom the date of approval. 11 Form 10 - 403 (Revised 10/2012) 5 / 3 Submit F and Attachments in Duplicate �� -e sic= NI c;YF &1 13 ORIGINAL Vi-k= � 43 ,e • • Conoco Phillips s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 12 April 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1Q -06 (PTD 184 -208). Well 1Q -06 was drilled and completed in April 1985 as an A- and C -sand selective producer. An attempt to patch a tubing leak in April 1994 stuck the patch in the SSSV, resulting in a rig workover to fix the well. The C -sand eroded a hole in the tubing at 7,990 ft MD that was patched in 1997, along with a leaking production mandrel at 7,765 ft MD. 1Q -06 produced A -sand only until April 2000, when the C -sand production resumed. An attempt to close the C -sand in May 2006 failed. The well continued to produce until October 2001 when a surface casing leak was detected at 78'. In January 2012 the well passed a MIT- T and a MIT -IA. The well was then tested to see if it could produce without lift gas, but was unable to flow fluids to surface. The surface casing leak is too deep to remediate from the surface and requires a RWO to repair. A continuous gyro survey in the tubing did not exhibit subsidence - related buckling or cork- screwing of the tubing. The well passed another MIT -IA on May 27,2013. The proposed workover is to pull the existing tubing, cut & pull the 7" casing above the TOC in the 7" x 9- 5/8" annulus, re- install new 7" casing and circulate cement into the 7" x 9 -5/8" annulus; which will ultimately plug the leak in the 9 -5/8" casing. Then run a new 3 -1/2" gas lift completion. If you have any questions or require any further information, please contact me at 263 -4773 Sincerely, Ian Toomey Wells Engineer CPAI Drilling and Wells • • 1Q -06 Kuparuk Producer Rig Workover (PTD #: 184 -208) Current Status 1Q-06 is currently shut -in awaiting a rig workover. Scope of Work The proposed workover is to pull the existing tubing, cut & pull the 7" casing above the TOC in the 7" x 9 -5/8" annulus, re- install new 7" casing and circulate cement into the 7" x 9 -5/8" annulus; which will ultimately plug the leak in the 9 -5/8" casing. Then run a new 3 -1/2" gas lift completion. General Well info MASP: 1670 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure /TVD: 2277 psi at 7960' MD (6068' TVD) SBHP taken on May 22, 2012 Wellhead type /pressure rating: FMC Gen IV, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT Results: MIT -T: Passed on January 2, 2012 MIT -IA: Passed on March 27,2013 MIT -OA: Failed on October 14, 2011 Well Type: Producer Estimated Start Date: May 16, 2013 Production Engineer: Dana Glessner / David Lagerlef Workover Engineer: Ian Toomey (263 - 4773 / Ian.A.Toomey@ conocophillips.com) Pre -Rig Work Requested 1. RU Slickline: a. RIH with dual Panex gauges, obtain combined A &C sand 30 minute SBHP, pull up hole 100' MD and obtain 15 minute gradient stop. b. Pull DV from GLM #7 at 7675' MD and leave open. c. RDMO slickline. 2. RU E -line: a. RIH with WRP and set in the middle of the first full joint below the upper packer at 7755' MD. b. CMIT -TxIA the WRP to 3000 psi and drawdown test to 0 psi. Install catcher sub on top of WRP. c. RDMO E -line. 3. Set BPV within 24 hours of rig arrival Proposed Procedure 1. MIRU. 2. Pull BPV. Circulate KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV and blanking plug, ND tree, NU 13 -5/8" 5M BOPE and PT (including annular) to 250/3000 psi. 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 3 -1/2" tubing. a. If tubing will not pull free, RU E -line: Fire a string shot and cut the tubing in the middle of the first full joint above the PBR. 6. RIH with 7" casing scraper to the top of the PBR. Circulate well clean and POOH. 7. RU E -line. Run CBL in the 7" casing. Based on cement top, determine the depth of the 7" collar to back -off following casing cut. RIH and fire string shot across that collar. RD E -line. • • -- Proposed Procedure Continued 8. MU, RIH and set RBP below the TOC. Pressure test to 2500 psi and drawdown test to 0 psi. Dump sand on top of RBP. 9. ND BOP stack, ND tubing head and pull packoff. Spear 7" casing, pull in tension, and re -land in slips. Cut off 7" casing growth and tack weld slips to casing. 10. NU 13 -5/8" 5M BOP on 11" 3M casing head (cannot test break due to leak in the surface casing, BOP stack will be considered a diverter). 11. Cut the 7" casing above the TOC. Circulate out Arctic Pack from the 7" x 9 -5/8" annulus with heated diesel followed by heated seawater. 12. Spear 7" casing and POOH sideways. 13. Set test plug in casing head and PT to 250/3000 psi (test pressure limited by 11" 3M casing head). 14. Run 9 -5/8" casing scraper to the top of the 7" stub and circulate clean. 15. RU E -line. RIH with memory caliper and gyro. Log 9 -5/8" casing from top of 7" casing stub to surface. RD E -line 16. Run back off tool and back off casing stub. 17. Run tandem string mills to gauge the 9 -5/8" casing for the ES cementer. 18. Spear and recover backed off 7" casing stub. 19. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing. 20. Open ES cementer and pump cement into the 7" x 9 -5/8" annulus to surface (see attached cement detail). Close ES cementer. 21. WOC. ND BOP, pull casing in tension and land in slips. Cut off excess 7" casing and install packoffs. NU new tubing head. 22. NU 13 -5/8" 5M BOP and test break to 250/3000 psi. 23. Drill out cement. Pressure test casing to 2500 psi for 30 minutes and record and test chart. Continue down until tag up on top of sand, dry drill to break up debris. Circulate well clean. 24. RIH with wash shoe, boot baskets, magnets, etc. and circulate out sand on top of RBP. 25. RIH with RBP retrieving tool, release RBP, and POOH. a. If tubing was cut, RIH with overshot and pull tubing stub from PBR. 26. RIH with new 3 -1/2" tubing completion. Sting into PBR and mark the pipe. PU and load the tubing and IA with 8.6 ppg corrosion inhibited seawater. 27. Space out, land the hanger and RILDS. PT tubing to 3000 psi bleed the tubing to 2500 psi and PT the IA to 2500 psi for 30 minutes and record on chart recorder. Bleed IA and tubing to 0 psi. Ramp up the IA pressure quickly to shear the SOV. 28. Pull landing joint and install BPV. Pressure up on the IA to 1000 psi to test BPV from below. Bleed IA to 0 psi. 29. ND BOP. NU tree, pull BPV, set tree test plug, and PT to 5000 psi. 30. Pull tree test plug. Freeze protect well. Set BPV. 31. RDMO. • • — Proposed Procedure Continued Post -Riz Work request: 1. Pull BPV 2. RU slickline: a. Pull SOV and run GLD. b. Pull catcher sub and WRP. c. RD slickline. 3. Turn well over to operations. ICI KU P • 1 Q -06 Conoc i Well Attributes Max Angle & MD TD II x; Wellbore APWWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (ftKB) Alaska, 500292122400 KUPARUK RIVER UNIT PROD 48.33 4,600.00 8,645.0 canocs Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••- Well Canfg' - 10-08, 6/182012742:13 AM SSSV: Flapper Locked Out 40 9/42011 Last WO: 4/14/1994 41.79 2/25/1985 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: SLM 8,254.0 12/25/2011 Rev Reason: WELL REVIEW osborl 6/19/2012 Casing Strings HANGER, 33 Casing Description String 0... String ID ... Top (81613) Set Depth (8... Set Depth (TVD) ... String Wt... String ... String Top Thrd I CONDUCTOR 16 15.062 36.0 103.0 103.0 62.50 H WELDED I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd -- SURFACE 9 5/8 8.921 35.6 4,405.7 3,583.8 36.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 32.8 8,624.8 6,542.3 26.00 J -55 BTC • Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd 36 TUBING WO 3 1/2 2.992 33.1 7,737.6 5,901.8 9.30 J -55 EUE8RDMOD 1 Completion Details SAFETY VLV, Top Depth 1'799 (TVD) Top Inc! Noml... Top (Rim) (ftKB) ( ") Item Description Comment ID (in) 33.1 33.1 0.25 HANGER FMC GEN IV 5K TUBING HANGER 3.500 GAS LIFT, 1,799.1 1,738.1 32.66 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE (Lower Flapper Locked Out 2.812 3.059 8/7/1998) 7,723.9 5,891.6 42.01 PBR BAKER PBR - STABBED INTO ORIGINAL TUBING COMPLETION 2.938 Tubing Description String 0... String ID ... Top (R103) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd GAS LIFT, TUBING Original 31/2 2.992 7,737.6 8,087.1 6,161.2 9.30 J - 55 FL4S 4,215 Completion Details Top Depth (TVD) Top Inc' Nomi... Top (RKB) (RKB) (") Item Description Comment ID (In) 7,737.6 5,901.8 41.94 PACKER BAKER FHL PACKER 3.000 SURFACE, . . 7,886.1 6,012.6 41.46 BLAST RINGS BLAST RINGS (4) 2.992 36 -4.406 - -- 8,059.1 6,140.7 43.04 LOCATOR BAKER LOCATOR 3.000 GAS LIFT. 8,060.0 6,141.3 43.04 PACKER BAKER FB-1 PERMANENT PACKER 4.000 5,036 8,063.3 6,143.8 43.07 SBE BAKER SEAL BORE EXTENSION 3.000 MI - 8,076.9 6,153.7 43.19 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,086.3 6,160. 43.27 SOS BAKER SHEAR OUT SUB 2.984 GAS LIFT, - 5,758 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) OM Top Depth 11.1 Top Top Inc! Top (MB) (B) ( ") Description Comment Run Date ID (In) GAS LIFT, 7,765.0 5,922.3 42.01 PATCH 20' HES Tubing Patch; Set over GLM 89 (7775') 9/29/1997 2.375 6,481 - 7,990.0 6,090.0 42.41 PATCH 25' HES Tubing Patch 1/27/1996 2.375 UM 8,076.9 6,153.7 43.19 REDUCER AVA NIPPLE REDUCER 4/10/1994 1.813 GAS LIFT, 8,600.0 6,524.9 45.55 FISH 1" DV w/ BK latch Lost in Hots 10/3/1988 10/3/1988 7.106 MN Perforations & _Slots - Shot MI Top (TVD) Btm (TVD) Dens GAS LIFT, Top (ftKB) Btm (RKB) (8808) (ftKB) Zone Date Oh- Type Comment 7.675 7,920.0 7,961.0 6,037.8 6,068.5 C-4 C-3, 10-06 4/13/1985 12.0 IPERF 5" Sequential HD Gun - 7,985.0 8,005.0 6,086.3 6,100.7 1�NIT B, 4/13/1985 12.0 IPERF 5" Sequential HD Gun PBR, 7,724 -- - = 8,170.0 8,220.0 6,221.2 6,257.1 A -4, A -3, 10-06 4/13/1985 4.0 IPERF 4" JJ II Csg Guns PACKER, 7,738 c 8,300.01 8,31601 6,313.81 6,324.41A -2, 10 -06 4/13/1985 4.0 IPERF 4" JJ II Csg Guns Notes: General & Safety PATCH. 7.765 End Date Annotation PRODUCTION, d 10/6/2010 NOTE: View Schematic w/ Alaska Schematic9.0 7,775 1 1/17/2012 NOTE: WAIVERED WELL OA x FORM, NO GAS LIFT ALLOWED PRODUCTION. j 7.845 3 1- 1 IPERF, 7,920 -7,961 PERF, 7.9858.005 , PATCH, 7,990 _.__ PRODUCTION, 8,040 LOCATOR, 8,059 PACKER. 8.060 SBE, 8.063 NIPPLE, 8,077 REDUCER, U I Mandrel Details 8.077 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run SOS, 8,086 Stn Top (ftKB) (RKB) (") Make Model tin) Sere Type Type (In) (psi) Run Date Com... 1 3,059.0 2,652.0 47.81 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/31/2011 2 4,214.7 3,453.1 46.61 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/8/2008 IPERF 3 5,036.1 4,011.5 46.96 CAMCO KBUG 1 GAS LIFT DMY INT 0.000 0.0 12/31/2011 -ill 8,17° -e,22, , 4 6757.9 4,506.8 46.65 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/19/1997 8,300-0, IPERF, 378 5 6,481.1 5,004.5 45.82 CAMCO KBUG 1 GAS LIFT DMY INT 0.000 0.0 12/31/2011 = 6 7,105.9 5,444.3 44.78 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/10/1994 7 7,675.2 5,855.5 42.26 CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 1/2/2012 8 7,774.8 5,929.5 41.96 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 8/14/1997 FISH, 8,600 - . 9 7,844.8 5,981.8 41.65 MERLA TPDX 1 12 PROD 'DMY RM 0.000 0.0 5/17/2006 Closed PRODUCTION, 10 8,039.7 6,126.4 42.87 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 4/10/1994 Closed 33.0,625 TD, 8,645 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 23, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED MAY 0 3 2013 RE: Bottom Hole Pressure Survey : 1Q-06 Run Date: 5/22/2012 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 10 -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21224 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 21224 -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 X44 Date: 1 10 ? { 'L- -� Signed: / � 2-°� Al.2.0 • 2-065 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 12, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED MAY 0 3 2013 RE: Plug Setting Record: 1Q-06 Run Date: 12/30/2012 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 10 -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21224 -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: 11.7 t2. Signed: ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri123, 2410 Mr. Dan Seamount Alaska Oil ~ Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ~~:~~~. - ~~~~~~~ ~PR~ ~:.,~:.~~201Q~ . .~as~ iii ~ ~~ ~ns• Commissiar~ AnChcrav~ Ig~_a ~ . ~9 Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRil)., 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 March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru April 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since L.._ Perry ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off A~ Report of Sundry Operations (10-404) Kuparuk Field 4/23/10 1A_ 1F_ 1Q & 1Y PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off da#e Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-01 50029205900000 1810590 SF ri/a 4" n/a 2.55 4/5/2010 1A-02 50029205990000 1810710 SF n/a 9" n/a 4.25 4/6!2010 1A-05 50029206270000 1811040 SF n/a 6" n/a 4.25 4/7/2010 1A-08 50029203130000 1780400 SF Na 10" n/a 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" n/a 2.55 4/2/2010 1A-15 50029207110000 1820170 SF Na 4" n/a 2.55 4/4/2010 1F-15 50029210250000 1831490 21" n/a 21" n/a 4.25 4/1/2010 1 Q-02 50029212480200 2051420 22" n/a 22" n/a 7.2 4/6/2010 1 Q-03 50029212490200 1842330 27" Na 27" n/a 3.4 4/6/2010 1 Q-05 50029212330000 1842170 32" Na 32" Na 3.4 4/1/2010 1Q-06 50029212240000 1842080 32" Na 32" Na 2.12 4/1/2010 1Q-10 50029212150000 1841980 32" Na 32" n/a 3.82 4/1/2010 1Q-15 50029213080000 1850460 22" n/a 22" n/a 2.97 4/1/2010 1Q-16 50029213090000 1850470 25" n/a 25" Na 3.82 4/1/2010 1 Y-21 50029223870000 1931020 23" n/a 23" n/a 3.82 4/1 /2010 1 Y 24A 50029223717100 2041250 26" n/a 26" n/a 3.82 4/1 /2010 1 Y 28 50029223800000 1930890 28" n/a 28" n/a 5.52 4/1 /2010 1Y 31 50029223810000 1930900 6'8" 0.65 24" 3/21/2010 5.52 4/1/2010 12/20/05 Schlumberger RECEIVEL} NO. 3615 ì C64 - af)tù Schlumberger -DCS nr-c ') 1 '?on;::; 2525 Gambell Street, Suite 400 t-' c.. ... L .!J.... Com pany: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 . - r:,.,....~,.,..¡~~-(! Attn: Helen Warman A TTN: Beth ~ Cil& Gas Cons. ",-\,)11;\''''''-'''''' 333 West 7th Ave, Suite 100 Aochorage Anchorage, AK 99501 Field: Kuparuk -.c-~~ Well Job # Log Description Date BL Color CD 1 Y -19 11144040 PIEZO SONA TOOL 11/19/05 1 1 Y -27 11072935 PRODUCTION PROFILE W/DEFT 11/22/05 1 20-09 11072933 S6HP SURVEY 11/18105 1 1 R-15 11072932 S6HP SURVEY 11/18/05 1 3F-05 N/A PRODUCTION LOG 11/13/05 1 1 L-25 11056689 S6HP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE W/DEFT 09/10/05 1 1 Q-16 11141232 PRODUCTION PROFILE W/DEFT 12/01/05 1 1 E-33 N/A GLS & 6HP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12103/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1 C-07 11141231 PRODUCTION PROFILE W/DEFT 11/30/05 1 1 Q-09 11141233 INJECTION PROFILE 12/02/05 1 36-16 N/A INJECTION PROFILE 12/08/05 1 1 Q-06 /fJJ,. ·3JE N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1 1 Q-1 01 11144044 MDT 11/24/05 1 SIGNED: .n <, í ß\ A é)[tûR "......«'·iì..NMEP ì ~\ N ^y \,; f_.J .~, ~'èðr~ß.; -~;~'5. 'd ..~ ~ _." -- ~ DATE:&~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM State of AlaSka Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: May 17, 200t THRU: Tom Maunder, P. !. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests . Kuparuk River Unit lQ Pad May 17 ,.2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSV on 1Q-05 would not pass the DP test. The valve was serviced & would not pass the re-test. Well 1Q-05 is shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected 20 well houses on lQ Pad w/no problems witnessed. SUMMARY: ! witnessed SVS testing in Kuparuk River Field. 15 wells, 30 components tested. 1 failure witnessed. 3.33% failure rate. 20 well houses inspected. Attachments: SVS KRU lQ 5-17-01jc CC; NON-CONFIDENTIAL SVS KRU lQ 5-17-01jc Ala~.~ Oil and Gas Conservation Commis~.,oa Safety Valve System Test Report Operator: phillips Alaska Operator Rep: ,E, .mie Barndt ^oocc ,, ,jo, hn',c p Submitted By: John Crisp Date: Field/Unk/Pad: Kup.aruk,Rive. r'unit lQ P~,,. Separator psi: LPS .85_ HPS 5/17/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE , , 'iQ-02A 1~'51940 lQ-,0.3 1842330 ,, 85,, , 70! 65 ,, P P ,OIL lQ-04 1842340 85 60i , 55 p ,, P ..... OIL ~lQ-05 1842170 85 70 54 P 4 ..... OIL lQ-.06 1842080 85 60: 55 P P , ., OIL ,lQ-09 1841920 3750 200,0, 1900 P e ,. WAG lQ-10 1841980 85 70 62 P P OIL lQ, il 1841990 .......... ,,, ,, lQ-12 1841930 ...... , 1 Q- 15 1850460 lQ-16 1850470 , 85 70 , .64 p P , ,, OIL "1 ~'20A 1951560 8~ 70 60 P P .... 0IL .lQ-21 1951330 1Q-22 19514001 85 70 55 p P ' ' '0iI~ 1Q-23 195141'0: '85 ' 70 50 p e ' OIL 1Q-26. 1951520 85 ' 70 52 . P' P,' ' ' , '0IL lQ-08 1970930 3750 '2600 1850 p P . . WAG lQ-13 1850440 3750 2000 1850 p P WA,G. lQ-14 1850450 3750! 2000 1850 p p WAG 1Q-24 1951210 3750 2000 2100 ' ' 'p p , . .. . ,, , wAG, , , ~ Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.33% [~] 90 Day Remarks: 1Q-05 was serviced & re-tested, re-test failed & well was shut in for repairs, ....... RJF 1/16/01 Page 1 ofl SVS KRU lQ 5-17-01jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing Repair well Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 91' RKB 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1571' FNL, 1180' FEL, Sec 26, T12N, R9E, UM 1Q-06 At top of productive interval: 9. Permit number/approval number: 2214' FNL, 1827' FEL, Sec 25, T12N, R9E, UM 84-208 At effective depth: 10. APl number: 2276' FNL, 1404' FEL, Sec 25, T12N, R9E, UM 50-029-21224-00 At total depth: 11. Field/Pool: 2286' FNL, 1336' FEL, Sec 25, T12N, R9E, UM Kuparuk River Field / Oil Pool !2. Present well condition summon/ Total Depth: measured 8646 feet Plugs (measured) None true vertical 6555 feet Effective Deptl measured 8544 feet Junk (measured) None true vedical 6479 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 240 Sx CS II 103' 103' Surface 4366' 9-5/8" 1100 Sx CS III & 4406' 3584' 750 Sx CS II Production 8585' 7" 400 Sx Class G & 8625' 6537' 250 Sx PFC Liner Perforation Depth measured 7920'-7961', 7985'-8005', 8170'-8220', 8300'-8316' true vertical 6038'-6068', 6010'-6025', 6220'-6257', 6314'-6326' ,~ .. Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, J-55 @ 8078' '~: ~ '~%?..~ Packers and SSSV (type and measured depth) Packers: Baker FB-1 @ 8051' & Baker FHL @ 7728'; SSSV: Camco TRDP-1A @ 1783' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 5/9/98. Intervals treated (measured) 0 ~ / ~//~\// 8170'-8220', 8300'-8316' Treatment description including volumes used and final pressure I Pumped 158,581 lbs of 20/40 and 12/18 ceramic proppant into formation, fp was 5168 psi. 14. Representitive Daily Averoge Production or Injection Data OiI-Bbl Gas-Mot Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 422 435 2 1187 230 Subsequent to operation 1002 879 12 842 213 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ~X Oil _X Gas _ Suspended Service 17. I hereb,y ~:e~'tify that~the foregoing is true and correct to the best of my knowledge. Signed Title: P~oduction Engineering Supervisor Date Form 10-404 Re~l t 38 SUBMIT IN DUPLICAT~ "AI~CO Alaska, Inc. , KUPARUK RIVER UNIT --[ WELL SERVICE REPORT ~ K1(1Q-06(W4-6)) WELL JOB SCOPE JOB NUMBER 1Q-O6 FRAC, FRAC SUPPORT 0212981113.2 DATE DAILY WORK UNIT NUMBER 05/09/98 A SAND REFRAC DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 3 {~) Yes (') NoIO Yes (~) No DS-GALLEGOS JORDAN FIELD AFC# · CC# DAILY COST AOCUM COST Signed ESTIMATE KD1753 230DS 10QL $119,850 $134,280 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann ~ Initial Outer Ann J Final Outer Ann 261 PSI 0 PSI 628 PSI 500 PSII 320 PSII 320 PSI DALLY SUMMARY I A SAND REFRAC SCREENED OUT WITH 10 PPA AT PERFS' 158'581 LBS PROPPANT IN FORMATION' 21'618 LBS LEFT INIPIPE. TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - GALLAGOS. TGSM. SB FOR TREE SAVER PARTS. 10:38 PT LINES TO 7000 PSI OK. 10:43 BEGIN BREAKDOWN, SCOUR AND FLUSH. STEPDOWN TEST AT END OF BREAKDOWN STAGE. ISIP 2154. GO(: GEL SAMPLES. 11:41 PULSE TESTS. CLOSURE 1832 AT 18.5 MIN. 11:58 BEGIN DATAFRAC STAGES AND FLUSH. GOOD GEL SAMPLES. SD AND MONITOR. ISlP 2109. ADJUST PAD TO 210 BBLS. 13:17 BEGIN FRAC STAGES INTO 10PPA. GOOD FLUID SAMPLES. 14:44 PRESSURE INCREASING WITH 10 PPA AT PERFSo CUT RATE TO 13.5 BPM. SCREENED OUT WITH PEAK PRESSURE TO 5168 PSI MAX. 180,199 LBS TOTAL PROP PUMPED. 158,581 LBS IN FORMATION, 21,618 LBS PROP LEFT IN PIPE. FRAC FLUIDS LOOKED GOOD ENTIRE JOB. - : 17:00 RDMO DS FRAC UNIT. - _ SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,215.00 APC $5,500.00 $5,500.00 DOWELL $110,350.00 i $110,350.00 HALLIBURTON $0.00 $6,375.24 LITTLE RED $4,000.00 $10,840.00 TOTAL FIELD ESTIMATE $119,850.00 $134,280.24 ! 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 X 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 1571' FNL, 1180' FEL, Sec. 26, T12N, R9E, UM At top of productive interval 2214' FNL, 1827' FEL, Sec. 25, T12N, R9E, UM At FNL depth 2276' FNL, 1404' FEL, Sec. 25, T12N, R9E, UM At total depth 2286' FNL, 1336' FEL, Sec. 25, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8645' feet Plugs (measured) 6556' feet 6. Datum elevation (DF or KB) 91' RKB, 54' PAD GL 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Q-6 9. Permit number/approval number 84-208 10. APl number 50-029-21224 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical Casing L e n g t h Structural Conductor 1 0 3' Surface 4 4 0 6' Intermediate Production 8 6 2 5' Liner Perforation depth: measured 8544' 6485' Size 16" 9-5/8" 7" 7920'-7961' feet Junk (measured) feet Cemented Measured depth 240 SX CS II 103' MD 1050 SX CS III & 4406' MD 700 SX CS I (TOP JOB 100 SX CS 1) 370 SX Class G & 8625' MD 7985'-8005', 8170'-8220', 8300'-8316' True vertical depth 103' TVD 3584' TVD 6537' TVD MD true vertical 6038'-6068', 6010'-6025', 6220'-6257', 6314'-6326' TVD Tubing (size, grade, and measured depth) 3.5" 9.3# J-55 EUE tbg @ 8087' MD Packers and SSSV (type and measured depth) Baker 3.5" FB-1 Perm Pkr set @ 8060' MD(8062' E-line Depth), Camco 3.5" TRDP-1A SS,~/C~f4~4i~'~r~l~ !~ 13. Stimulation or cement squeeze summary ~'~ r ~ E I V r' ~,) Intervals treated (measured) Treatment description including volumes used and final pressure v _. 3 i994 Alaska Oil & Gas Cons. Commission 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 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. Form 10-404 Rev 05/17/89 Title Area Drilling Engineer D a t es Yi~i~T~N~U~/p Li CATE ARCO ALASKA INC. DAILY OPERATION~ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: lQ-06 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER ADL 25641 ALK 2572 50-029-21224 84-208 ACCEPT: 04/06/94 08:30 SPUD: RELEASE: 04/11/94 11:30 OPERATION: DRLG RIG: WO/C RIG: NORDIC 1 04/07/94 ( 1) NORDIC 1 TD: 8645 PB: 8544 04/08/94 (2) NORDIC 1 TD: 8645 PB: 8544 04/09/94 ( 3) NORDIC 1 TD: 8645 PB: 8544 NU BOP MW: 0.0 MOVED RIG F/2X-16 TO lQ-06. ACCEPTED RIG @ 2030 HRS 04/06/94. LEVELED RIG. RU LUB & PULL BPV. RU KILL LINES. SITP=1800 PSI. SICP=800 PSI. COND MUD. DISPLACED TBG TO PERES W/SW. KILLED TBG W/81 BBLS 11.4 PPG MUD. BLED GAS OFF OF ANN & MONITORED WELL. SITP=0 PSI SICP=0 PSI. SET BPV. ND TREE. NU BOP. COND MUD MW: 0.0 NU BOPE. PLACE 8' SPACE OUT SUB BETWEEN PIPE RAMS & ANN PREVENT. DISTANCE BETWEEN TBG HGR & BTM OF ANN IS 14.5' TEST CHOKE MANIFOLD & FLOOR VALVES. RU HARD LINE TO BLEED TANK & BLEED PRESS F/ANN. ANN CONT FLOWING SMALL AMT OF GAS. TEST BOPE & ACCUM. HOLD SAFETY MEETING. BOLDS. PU TBG & ALLOW COMMUNICATION TO ANN. PMP 20 BBLS MUD INTO ANN, SWITCH TO FW & PMP 45 BBLS UNTIL ANN FULL. ATTEMPT TO PULL SEALS F/PBR. WORK PIPE UNTIL SEALS RELEASE. CONT TO PULL TBG UNTIL TBG HGR REACHES ANNULAR W/15' OF TRAVEL, WORK PIPE SEVERAL TIMES. SEALS NOT OUT OF PBR. WORK PIPE WHILE PUMPING. NO SUCCESS. LAND TBG. RILDS. BACKED OUT LANDING JT. CLOSED BLIND RAMS. ND ANNULAR PREVENTER & FLOW LINE. ADDED 2' SPACER SPOOL BELOW ANN. MODIFIED FLOW NIPPLE & NU SAME. OPENED BLIND RAMS. CHECKED BPV. HAD PRESS BELOW BPV. KILLED TBG W/62 BBLS 11.4 PPG MUD. RETRIEVED BPV. BOLDS. PULLED SEALS OUT OF PBR. SITP=0 PSI, SICP=0 PSI. CIRC & KILLED WELL @ 2 BPM. SHUT DN & MONITOR WELL. BUILT 220 BBLS OF SURV VOL & COND SAME. POOH W/COMP ASSY MW: 0.0 CIRC WELL @ 3.5 BPM. GAS CUT RETURNS ON BU & SMALL AMTS OF GAS IN MUD. SHUT DOWN & MONITOR WELL. WELL NOT FLOWING BUT HAD GAS BREAKING OUT @ SURF. STING BACK INTO PBR & PRESS TEST ANN TO 1500 PSI F/10 MIN, LEAVING TBG OPEN TO PITS. NO FLOW OR PRESS LOSS. INCREASE PRESS TO 2000 PSI F/15 MIN. HOLDING GOOD. BLED PRESS & UNSTUNG SEALS. RAISED MUD WT TO 11.5 PPG. CIRC & MONITOR WELL. POOH W/3-1/2" TBG TO SSSV. RECOVERED 20 SS CONTROL LINE BANDS. STRAPPED & DRIFTED TBG & CHANGED OUT COUPLINGS TO MOD 8RD. RECOVERED TBG PATCH W/BLAST RINGS STUCK @ BTM OF SSSV. CONT POOH W/3-1/2" TBG & COMPLETION ASSY CHANGING OUT COUPLINGS, STRAPPING & DRIFTING SAME. ,~,., ~ ~ ~ oomm~ssion Anchorage WELL: lQ-06 API: 50-029-21224 PERMIT: 84-208 PAGE: 2 04/10/94 ( 4) NORDIC 1 TD- 8645 PB' 8544 MU SSSV MW: 0.0 SERV RIG. POOH W/3-1/2" TBG & JEWELRY. STRAP, DRIFT SAME. LD LAST 24 JTS TBG DUE TO CORROSION ON THREADS. RD GBR EQUIP. STRAP OLD JEWELRY & BAD TBG. POOH. NORM TEST ALL L/D MATERIAL. UNLOAD SHED OF ALL JEWELRY & TBG LD. LOAD SHED W/30 JTS NEW TBG & TBG JEWELRY. STRAP & TALLY SAME. RU TO RIH. MU PBR SEALS & RIH W/3-1/2" COMPLETION ASSY TO 4350' MU RTTS PKR & STORM VALVE. RIH W/SAME @ SET @ 27' TESTED PKR TO 2000 PSI. POOH W/TBG. ND BOP & TBGHEAD. INSTALLED NEW PRIMARY SEAL & NU FMC 11" 3M X 7-1/16" 5M TBGHEAD. TESTED PACKOFF TO 3000 PSI. NU BOP & FLOW LINE. TESTED BOP TO 3000 PSI. RIH & RETRIEVE STORM PKR. POH W/SAME. CONT RIH W/COMPLETION ASSY ON 3-1/2" TBG. 04/11/94 ( 5) NORDIC 1 TD: 8645 PB: 8544 RIH W/COMP ASSY MW: 0.0 SERV RIG. TEST SSSV TO 5000 PSI. CONT TO RIH W/3-1/2" COMP ASSY. RUN TOTAL OF 244 JTS 3-1/2" J-55 EUE 8RD MOD TBG. TAG PBR & VERIFY SEALS ENGAGED BY PUMPING. UNSTING FROM SEALS & CBU @ 3 BPM. SPACE OUT TBG. MU 'C' LINE TO TBG HGR & TEST TO 5000 PSI. LAND TBG & RILDS. PRESS ANN TO 1500 PSI TO TEST PBR SEALS, HOLD 15 MIN. OK. CLOSE SSSV & SET BPV. ND BOP. NU TREE & ORIENTED VALVES. RETRIEVED BPV. SET TEST PLUG. TESTED TREE TO 250/5000 PSI. ATTEMTED TO PRESS UP ON CONTROL LINE. PUMPING IN CONTROL LINE @ 3200 PSI. RETRIEVED TEST PLUG. SET BPV. ND TREE. VERIFY CONTROL LINE LEAKING BELOW HGR. NU BOP. RETRIEVE BPV. MU LANDING JT & BUILT MUD VOLUME. TEST BOP TO 3000 PSI. BOLDS. POOH TO TBG HGR. VERIFIED CONTROL LINE LEAKING DOWN HOLE. POOH TO SSSV. LEFT 8 SS BANDS IN HOLE. MU NEW CONTROL LINE , PURGED & TESTED TO 5000 PSI. TESTED SSSV TO 5000 PSI. 04/12/94 ( 6) NORDIC 1 TD: 8645 PB: 8544 RIG RELEASED MW: 0.0 SERV RIG. RIH W/3-1/2" COMP ASSY & MU SS BANDS ON 'C' LINE EVERY OTHER JT. MU 'C' LINE TO TBG HGR & TEST TO 5000 PSI F/10 MIN. CBU. DRAIN STACK & LAND TBG. RILDS. PRESS ANN TO 1500 PSI TO TEST PBR SEALS, HOLD 15 MIN. CLOSE SSSV & SET BPV. ND FLOW RISER & BOPE. NU TREE. TEST PACKOFF & FLANGE @ 5000 PSI. PULL BPV & SET TEST PLUG. TEST TREE TO 250 & 5000 PSI. PULL TEST PLUG & RU DISPLACE LINES. OPEN SSSV. PRESS ANN TO 2500 PSI & SHEAR DCR-1 VALVE, DISPLACE WELL W/SW. DISPLACE WELL TO DIESEL @ 3 BPM. CLOSED SSSV. BLED TBG PRESS TO 1200 PSI & HELD F/15 MIN TO TEST SSSV. EQUALIZED SSSV & OPENED SAME. SHUT IN WELL. RU LUB. SET BPV. RD LUB. MOVED RIG OFF WELL. CLEANED PTIS & BLEW DOWN LINES. RIG RELEASED @ 2330 HRS 04/11/94. SIGNATURE: DATE: ARCO Alaska, Inc. February 1, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED FEB - 7 1994 Alaska 0il & Gas Cons, Commission Anchorage /,, R 3 iJ ~'i,":O:.i- b':i 242-2603 Report of Well Sund~ y Operations Page 2 bxc: V. L. Ferguson P. A. Billingsley Well Files FTR020196 ATO-1228 ATO-1431 (w/o attachments) (w/o attachments) (Form 10-404 only) (w/o attachments) Subject: Report of Sundry Well Operations, 1B-05(sssv), 1E-28(sssv), 1L-02,08(sssv), 1Q-05,06(sssv) Original + one copy to AOGCC (one -sided copy) Anchorage STATE OF ALASKA -_. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate X"'~ Pull tubing Alter casing Repair well Other 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic Service RKB 91 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 1571' FNL, 1180' FEL, Sec 26, T12N, R9E, UM At top of productive interval 2214' FNL, 1827' FEL, Sec 25, T12N, R9E, UM At effective depth 2276' FNL, 1404' FEL, Sec 25, T12N, R9E, UM At total depth 2286 FNL, 1336' FEL, Sec 25, T12N, R9E, UM measured 8646 feet true vertical 6556 feet 8. Well number 1Q-06 9. Permit number/approval number 12. Present well condition summary Total Depth: 84-208/93-353 10. APl number 5 o-029-21224 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 8544 feet true vertical 6479 feet Junk (measured) None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 0 3' 1 6" 240 SX CS II 1 0 3' 1 0 3' Surface 4366' 9-5/8" 1100 SX CS III & 4406' 3584' Intermediate 750 SX CS II Production 8 5 8 5' 7" 400 SX Class G & 8 6 2 5' 6 5 3 7' Liner 250 SX PFC Perforation depth: measured 7920'-7961', 7985'-8005', 81 70'-8220', 8300'-831 6' true vertical 6038'-6068', 6010'-6025', 6220'-6257', 631 4'-6326' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 8078' Packers and SSSV (type and measured depth) Pkr: Baker FHL @ 7728' & Baker FB-1 @ 8051'; SSSV: Otis K Valve @ 1783', set @ 400# 13. Stimulation or cement squeeze summary Installed sub-surface, spring controlled safety valve in production well. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A RECEIVED FEB - 7 1994 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Anchorage Tubing Pressure Prior to well operation 1059 2867 1967 520 394 Subsequent to operation 1059 2867 1967 520 394 15. Attachments Well Schematic Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~:~~~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date Z-/""'~ ~'~ SUBMIT IN DUPLICATE :ion Well: I Q-6 ARC ALASKA INC.- KUPARUK FIELd, Spud Date: 0 2 / 1 6 / 8 5 Completion D~tte: 02/25/8 5 Maximum Hole Angle: 4 8 deg. @ Original Rig RKB: 33.11 All depth are RKB MD to top of equipment. APl# 50-029-21224-00 C Sand: OPEN A Sand: 478O MD Well Type: OIL Tree Type: MC EVOY GEN 2 5000# Tree Cap Type: Tree Cap Size: 3.5" PIN X 5.25" ACME Tree Cap O-ring ASN: Last Workover Date: Jewelry 1 SSSV: OTIS K Valve/DR Lock @ 1783' (Dome pressure 400# at 60 degrees) 2 SBR: BAKER PBR 2.992" ID @ 7715' 3 PKR: BAKER FHL @ 7728' 4 PKR: BAKER FB-1 @8051' 5 NOGO: CAMCO 'D' NIPPLE 2.75" ID @ 8068' w/2.75"x2.25" reduced AVA nipple 6 SHEAR OUT: BAKER @ 8077' 7 TUBING TAIL @8078' Minimum ID: 2.75" NOGO Casing and Tubing Size Weight Grade To_D Bottom Description 1 6" 62.5# H-40 0 1 03 CASING 9.625" 36# J-55 0 4406 CASING 7" 26# J-55 0 8625 CASING 3.5" 9.3# J55 0 8078 TUBING Gas Lift Information Depth Stn# Valve Type 1840 1 DV 1 352O 2 DV 1 4415 3 DV 1 4916 4 DV 1 '5414 5 DV 1 5857 6 DV 1 6297 7 DV 1 6705 8 DV 1 7207 9 DV 1 7677 1 0 DV 1 Sz. Latch Port Sz. 0 BK 1/8" 0 BK 0 BK 114" 0 BK 0 BK 0 BK 511 6" 0 BK 0 BK 3/8" 0 BK .5 RM Date Run 07/28/93 09/22/91 O7 28/93 09 01/91 O7 28/93 09 01/91 07 28/93 O9 01/91 O9 01/91 5 7766 1 MACCO DV I . 5 RM 7836 2 MACCO DV 1 . 5 RM 6,7 8031 3 OTIS DV 1.5 RM 07 28/93 O7 28/93 O8/07/88 Perforation Data RECEIVED Interval SPF Date Zone Comments 7920-7961 12 04/1 3/85 C-SAND FEI3 - 7 1994 7985-8005 12 o4/13/85 C-SAND 8170-8220 4 04/1 3/85 A-SAND Alaska 0il & Gas C0r~s. Commission 8300-831 6 4 04/1 3/85 A-SAND Anchorage Comments: LOST 1" D/V W/BK LATCH ON 10-03-88. STORM CHOKE set at 1783 Drilling sheet which shows SSSV ~ 1857' is incorrect. Stn. 1 GLM is at 1840' not 1907. *GLM IS "BELLY DOWN". LAST TD 8260' ON 08/27/92 PBTD:8544 PBTDSS:6485 LAST REVISION DATE: 12/06/93 LJE:CH ARCO Alaska. Inc. Pos~ O,"Iice S .00380 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 15, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission '3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action ~}-O~ 1 B-05 ¢z-, ~-~ 1E-28 9q--- 1"~1L-02 1~q-~¢¢ 1 L-08 ~.-- at~ 1Q-05 ~-- ~8 1Q-06 Variance Variance Variance Variance Variance Variance Anticipated Start Date If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments R£CEi /£D Gas GoDs. Oomrnissio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 1. Type of Request: STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI,S~-TON APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation Shutdown Alter casing _ Repair well _ Change approved program _ 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1571' FNL, 1180' FEL, Sec. 26, T12N, At top of productive interval 2214' FNL, 1827' FEL, Sec. 25, T12N, At effective depth 2276' FNL, 1404' FEL, Sec. 25, T12N, At total depth 2286' FNL, 1336' FEL, Sec. 25~ T12N~ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service R9E, UM R9E, UM R9E, UM R9E, UM Present well condition summary Total Depth: measured 8 6 4 6 true vertical 6 5 5 6 Effective depth: measured 8 5 4 4 true vertical 6 4 7 9 _ Re-enter suspended well _ Plugging _ Time extension Stimulate Pull tubing _ Variance X Perforate _ Other _ 6. Datum elevation (DF or KB) RKB 91 7. Unit or Property name Kuparuk River Unit 8. Well number 1Q-06 9. Permit number 84-208 10. APl number 5o-029-21 224 11. Field/Pool Kuparuk River Oil Field/Pool 12. Casing Length Size Structural Conductor 1 0 3' 1 6" Surface 4 3 6 6' 9 - 5 / 8" Intermediate Production 8 5 8 5' 7" Liner Perforation depth: measured 7920'-7961 ', true vertical 6038'-6068', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 8078' Packers and SSSV (type and measured depth) feet Plugs (measured) None feet feet Junk (measured) feet Cemented 240 SX CS II 1100 SX CS III & 750 SX CS II 400 SX Class G & 250 SX PFC RECEIVED ,~.,.:.:~.o u. ~ Gas Cons. Commission Anchorage Measured depth True ve~ical depth 7985'-8005', 8170'-8220', 6010'-6025', 6220'-6257', 103' 103' 4406' 3584' 8625' 6537' 8300'-8316' 6314'-6326' Pkr' Baker FB-1 @ 8051', Baker FHL @ 7728'; SSSV: Camco TRDP-1A @ 1783' 13. 14. 16. If proposal was verbally approved Name of approver Date approved Attachments Description summary of proposal ~ Detailed operation program _ Install sub-surface, sprin~ controlled safety valve in production well Estimated date for commencing operation 15. Status of well classification as: Oil X Gas Service true and correct to the best of my knowledge. Title Sr. Engineer FOR COMMISSION USE ONLY 7. I herebyr'~ertify tha, t~ the Si~ned '-~~ ,d~)· BOP sketch Suspended Date //2. -J.~-- ~'~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require IApprov. aJ_ No._ Approved b), order of the Commission Form 10-403 Rev 06/15/88 .'Jng~nal Signea By David W, Jghnstnr_, Commissioner Date ////<s/¢ ~, SUBI~IIT I1~ TRIPLICATE Approved Copy Returned Attachment 1 Request for Variance Kuparuk Well 1Q-06 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval for a variance to install a subsurface, ambient-type safety valve in Well 1Q-06. This valve replaces the original subsurface safety valve which has failed. The replacement valve operates by remaining open until flowing well pressure falls below a predetermined limit. Should such an event occur, the valve automatically closes, thus preventing uncontrolled flow. This valve, refered to as a storm choke, does not require a hydraulic control line from the surface to the subsurface valve. Its fail-safe design as normally-closed provides the same level of protection. Attached is a schematic of the "K" valve, an Otis Engineering storm choke. DEC 2 1 I993 Ai~Sk,3 Oil & 6as Cons. 6ommissi¢, Anchorage Attachment 2 Storm Choke Schematic OPEN · WELL PRESSURE CLOSED ·INTERNAL CHAMBER PRESSURE TOP SUB HOUSING VALVE HEAD O RING TEFLON RING ~-RING VALVE PISTON SPRING ROD SPACER BODY SPRING DETENT RING BALL GASKET SET SCREW CAP SCREW GASKET DEC Oil & Gas Cons. Commission Anchorage Figure 1 - Otis "K" Valve STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: 2. Name of Operator Operation Shutdown Pull tubing Alter casing ARCO Alaska. In¢, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface Stimulate m Plugging Perforate ~ Repair well Pull tubing Other X 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 91' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number feet 1571' FNL, 1180' FEL, Sec. 26, T12N, At top of productive interval 2214' FNL, 1827' FEL, Sec. 25, T12N, At effective depth 2276' FNL, 1404' FEL, Sec. 25, T12N, At total depth 2286' FNL, 1336' FEL, Sec. 25, T12N, R9E, UM R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 8 64 6' true vertical 6556' feet feet Plugs (measured) 1Q-06 Producer 9. Permit number/approval number 84-208 / 9-399 10. APl number 5o-029-21224 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8544' true vertical 6479' feet feet Junk (measured) Casing Length Size Structural 1 03' I 6" Conductor 4406' 9 5/8" Surface Intermediate Production 8625' 7" Liner Perforation depth: measured 8170'-8220', true vertical 6220'-6257', Cemented Surf-1 03' Surf-4406' Surf-8625' 8300'-8316', 7920'-7961', 6314'-6326', 6038'-6068', Tubing (size, grade, and measured depth) 3 1/2", J-55 EVE 8RD @ 8078' Packers and SSSV (type and measured depth) Baker FB-1 @ 8051'; Baker FHL @ 7740'; Baker FVL @ 1857' Measured depth 103' 4406' True vertical depth 103' 3584' 8625' 6537' 13. Stimulation or cement squeeze summary ~"- ,' ,~: Pumped barium sulfate scale inibition treatment (SOC) into C Sand. Intervals treated (measured) 7920'-7961', 7985'-8005' MD-RKB. Treatment description including volumes used and final pressure 1 drum SA 8660, SOC' 144 bbls 2% KCI w/660 gal 7.5% HCI, 9 drums SOC-2, 12 drums S-256 @ 1000 14, Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 620 966 700 1330 180 Subsequent to operation 1400 2000 2300 1375 220 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations Z 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. Form 1' 05/17/89 Title Senior Operations Engineer Date ~ SUBMIT IN DUPLICATE ARCO Alaska, Inc Subsidiary of Atlantic Richfield Company WEI"L '~TRACTOR REMARKS IPBDT FIELD- DIS¥~ICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT [--~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA AEASKA OIL AND GAS CONSERVATION COMM,~_o-,ON REPORT OF SUNDRY WELL 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate Repair well Plugging Perforate Pull tubing Other X 2. Name of Operator ARCO Alaska, In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development X Exploratory _ Stratigraphic _ Service Location of well at surface 1571' FNL, 1180' FEL, Sec. 26, T12N, At top of productive interval 2214' FNL, 1827' FEL, Sec. 25, T12N, At effective depth 2276' FNL, 1404' FEL, Sec. 25, T12N, At total depth 2286' FNL, 1336' FEL, Sec. 25, T12N, R9E, UM R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 8 64 6' true vertical 6556' feet Plugs (measured) feet Effective depth: measured 8544' true vertical 6479' feet Junk (measured) feet Casing Length Size Structural 1 03' 1 6" Conductor 4406' 9 5/8" Surface Intermediate Production 8625' 7" Liner Perforation depth: measured 8170'-8220' true vertical 6220'-6257' Cemented Surf-103' Surf-4406' Surf-8625' , 8300'-8316', 7920'-7961', , 6314'-6326', 6038'-6068', Tubing (size, grade, and measured depth) 3 1/2", J-55 EVE 8RD @ 8078' Packers and SSSV (type and measured depth) Baker FB-1 @ 8051'; Baker FHL @ 7740'; Baker FVL @ 1857' 13. Stimulation or cement squeeze summary 6. Datum elevation (DF or KB) 91' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Q-06 Producer 9.. Permit number/approval number ~°~9-399 10. APl number 5o-029-21224 11. Field/Pool Kuparuk River Oil Pool Measured depth True vertical depth 103' 103' 4406' 3584' 8625' 6537' 7985'-8005' 6010'-6025' Pumped barium sulfate scale inibition treatment (SCO) into C Sand. Intervals treated (measured) 7920'-7961', 7985'-8005' MD-RKB. Treatment description including volumes used and final pressure 1 drum SA 8660, SOC' 144 bbls 2% KCI w/660 gal 7.5% HCl, 9 drums SOC-2, 12 drums S-256 @ 1000 14. Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation ~ 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations OiI-Bbl Gas-Mcr Water-Bbl CasingPressure TubingPressure 620 966 700 1330 180 1400 2000 2300 1375 220 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. Form 10-404 Rev 05/17/89 ~,~ ;~.,~¢.'¢-~,y Title Senior Operations Engineer Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL /~-~ c""NTRACTOR REMARKS IPBDT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT IDA;S IDATE 1 AlaSka Oil & Gas Cons, E] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemP'Report OF Chill Fact°r I VisibilityI°F miles Wind Vel. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI0-N APPLICATION FOR SUNDRY APPROVALS Suspend _ Operation Shutdown _ Re-enter suspended well _ Repair well Plugging _ Time extension _ Stimulate _ Variance _ Perforate _ Other 1. Type of Request: Abandon 2. Name of Operator Alter casing _ _ Change approved program _ Pull tubing _ 5. Type of Well: Development X ARCO Al~k¢~, In(;;. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 1571' FNL, 1180' FEL, Sec.26, T12N, R9E, UM At top of productive interval 2214' FNL, 1827' FEL, Sec. 25, T12N, R9E, UM At effective depth 2276' FNL, 1404' FEL, Sec.25, T12N, R9E, UM At total depth 2286' FNL, 1336' FEL, Sec. 25, T12N, R9E, UM 8646' feet Plugs (measured) 6556' feet Cement: 101' 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 91 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Q-06 .~ ~ ~/~,- ,_' ~, 9. Permit number 84-208 10. APl number so-02~-21224 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth' measured true vertical 8544' feet Junk (measured) 64 7 9' feet None Casing Length Structural Conductor 1 0 3' Surface 44 0 6' Intermediate Production 8 6 2 5' Liner Perforation depth: measured 8170'-8220', 7920'-7961 ', true vertical 6220'-6257', 6038'-6068', Size Cemented Measured depth True vertical depth 1 6" Surf-103' 1 03' 103' 9 5/8" Surf-4406' 4406' 3584' 7" Surf-8625' 8625' 6537' 8300'-8316' MD 7985'-8005' MD 6314'-6326' TVD 6010'-6025' TVD Tubing (size, grade, and measured depth 3 1/2", J-55 EVE 8RD @ 8078' Packers and SSSV (type and measured depth) Baker FB-1 @ 8051'; Baker FHL @ 7740'; Baker FVL @ 1857' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ Pump SOC Treatment in C Sand 15. 14. Estimated date for commencing operation May 1,.3, 1989 16. If proposal was verbally approved Name of approver Date approved Status of well classification as: Oil ~ Gas __ Service Suspended 7. I hereby certify that the foregoing is true aq~d correct to the Cest of-~,mY knowledge. Title /'-j /~ FOR COMMISSION I~ISE ONLY Conditions of approval' Plug integrity m BOP Test Mechanical Integrity Test ~ Notify Commission so representative may witness Location clearance Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 dRIGINAL SIGNED BY LONNIE C. SMI,TH 10_/¢~¢~ Approved Copy Returned Commissioner IApproval No. SUBMIT IN TRIPLICATE~ Kuparuk Well 1Q-06 SOC Treatment May 8, 1989 10. 11. 1. SI Well, MIRU slickline 2. Run SV and pressure test tubing. 3. Pull DV's and replace with CV's in C Sand mandrels @ 7777', 7847', & 8042' MD-RKB. 4. MIRU pumping equipment. 5. Service company should have on location: a. 144 bbls. 2% KCI water b. 660 gallons of 7.5% HCI Note: this acid can be pre-mixed into the KCl water at the service company's facility and delivered to location. 6. Mix the SOC pill per the following volumes and in the following order: a. 144 bbls 2% KCI water containing 660 gallons 7.5% HCI b. 9 drums SOC-2 c. 12 drums S-256 7. Circulate and monitor the SOC pill. The pH should be less than 2.5. If the pH is greater than 2.5, add additional SOC-2 liquid until pH is below 2.5. 8. Add 12 drums CaCI 30% to the SOC mixture. 9. Pump a pre-flush consisting of: 3 bbls diesel + 1 bbl SA-8660 (Chemlink chemical) Pump SOC pill at 2-4 bpm. Overdisplace using 680 bbls of injection* water (7.5 ft radial penetration). * (Other Drill Sites have used the drain system to divert water from an injection 12. 13. 14. 15. 16. 17. well into the producer being treated.) Displace water using 70 bbls diesel. Allow SOC pill to remain in formation for 24 hours. MIRU slickline; Pull SV. RDMO slickline. Open well and flow back at normal rates. Test Well after flow has stabilized. Note: Reservoir pressure is estimated to be 3000 psia @ 6200' SS. or workover fluids are required for this job. No BOP equipment ARCO Alaska, Inc. Post Office B )0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 19, 1988 Transmittal f!: 7099 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. lQ-5 Kuparuk Well Pressure Report(Camco) 8-24-87 Both Sands ~~ Kuparuk Well Pressure Report(Camco) 8-24-87 Both Sands 1Y-14 Kuparuk Well Pressure Report(Camco) 1-31-88 'A' Sand Static 1Y-14 Kuparuk Well Pressure Report(Camco) 1-31-88 'C' Sand Static 1Y-3 Kuapruk Well Pressure Report(Otis)~ 2-6-88 'A' Sand Static 1Y-3 Kuparuk Well Pressure Report(Otis) 2-6-88 'C' Sand Static 2E-11 Kuparuk Well Pressure Report(Otis) 2-15-88 PBU 'A' Sand Alaska Oil & Gas Cons. Commission Anchorage Receipt Acknowledged DISTRIBUTION: .... Date: Chevron Mobil S~C Unocal ARCO Alaska, Inc. is a Subsidiary of AllanticRichfleldCompany ARCO Alaska, Inc. Post Office ,( 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 22, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate 1Q-6 as listed below: Well Action 1H-7 Perforating 1Q-6 Acidizing If you have any questions, please Sincerely, Commission are intent notices on Kuparuk Wells 1H-7 and Anticipated Start Date June 26, 1987 June 15, 1987 call me at 265-6840. G. B. Smallwood Senior Operations Engineer GBS:pg:O091 Attachments cc: File KOE1.4~9 RECEIVED 2 1987 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary el AllanticRichfieldCompany STATE OF ALASKA ALA ....A ,~IL AND GAS CONSERVATION COk_. .... .iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ,~ Suspend ~ Operation Shutdown [] Re-enter suspended well E] Alter casing [] Time extension EJ Change approved program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order [] Perforate ~, Other [] Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchoraqe, AK 4. Location of well at surface 99510 1571' FNL, 1180' FEL Sec 26 T12N, R9E UM At top of productive interval' ' ' ' 2214' FNL, 1827' FEL, Sec. 25, T12N, R9E, UM At effective depth 2276' FNL, 1404' FEL, Sec. 25, T12N, R9E, UM At total depth 2286' FNL, 1336' FEL, Sec. 25, T12N, R9E, UM · Present well condition summary Total depth: measured 8645' MD true vertical 6556' MD feet feet 5. Datum elevation (DF or KB) RKB 91 6. Unit or Property name Kuparuk River Unit 7. Well number lq-6 8. Permit number Permit #84-208 9, APl number 50-- 029-21224 10. Pool KuDaruk River Oil Pr~nl Plugs (measured)101, feet Effective depth: measured 8544' ND feet true vertical 6479' ND feet Casing Length Size Structural 103' 16" Conductor Surface 4406' 9-5/8" X X X ~41>t~rX~e~c(te Production xxx)ki4ke~xxxx Perforation depth: measured Junk (measured) None Cemented Measured depth Surf. - 103' 103' MD Surf. - 4406' 4406' MD 8625' 7" Surf. - 8625' 8625' MD 8170'-8220' MD, 8300'-8316' MD 7920'-7961' MD, 7985'-8005' MD ~ue Vertical depth 103' TVD 3584' TVD 6537' TVD true vertical 6220'-6257' TVD, 6314'-6326' TVD 6038'-6068' TVD, 6010' -6025'TVD Tubing (size, grade and measured depth) 3½" J-55 EVE 8RD ~ 8078' Packers and SSSV (type and measured depth) Baker FB-1 (a 8051 '; Rakc, r Fl-Il 0 7740'~ Baker FVL @ 1857' 12.Attachments Description summary of proposal [] Detailed operations program Acidize C Sand with 4500 qal of 15% HCL 13. Estimated date for commencing operation June 15, 1987 BOP sketch [] 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ,' (,, Sr. Operations Engineer .-"? ,o /~_..~.,~.,.~,... ~.~.,~-¢.'¢ Title Signed /--- ~'¢_~--~-~/ /.~ Dat6/12/87 Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ,~. ~-,~ ~ - ,--;-?-~ ,~- ~ i -. Commissioner IApprOVal NO' by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate RETUP~ TO: ARCO Alaska, Post Off. Box 100360 : , Anchorage, Alaska 99510-0363 Telephone 907 276 1215 DATE: 08-16-85 TRANSMITTAL NO: 5254 ARCO ALASKA, INC. KUPA~<UK OPERATIONS ENGINEERING RECORDS CLERK " ATO-1115B P.O. BOX 1U0360 ANCHORAGE, AK 99510 TRANSMITTED hEREWITH ARE THE RECEIPT AND RETUP, N ONE SIGNED COPY OF PRESSURE FINALS CAHCO lB-3 PBU 04-21/22-85 1D-8 STATIC 04-29-85 1E-5 PBU 04-26-28-85 1H-6 STATIC 04-29-85 1L-2 PBU 04-24/25-85 1L-5 PBU 04-28/29/85 lQ-6 PRESSURE FALL OFF 05-07-85 lQ-9 PBU 05-12/13-85 2A-5 PRESSURE FALL OFF 04-21/22-85.' 2A-5 STATIC 05-05-85 2C-4 PBU 04-24/25-85 2F-7 PBU 04-14-85 2F-8 PBU 04-19/20-85 2F-9 PBU 04-13/14-85 2G-! STATIC 04-17-85 2G-1 PBU 04-29-85 2U-5 STATIC 05-02-85 2U-6 STATIC '05-03-85 2U-7 STATIC 05-04-85 2U-8 STATIC 05-04-85 2X-'l 0 PBU 04-25/26-85 OTIS FOLLOWING IT~,IS. PLEASE ACKNOWLEDGE THIS TRANSMITTAL. 2A-2 STATIC 07-04-85 ': 2U-14 'PBU 06-30-85 i' 2V-2 PBU 07-27-85 2V-5 PBU 06-25-85 2V-13 STATIC 06-22-85 2V-14 STATIC 06-22-85 2W-7 PBU 07-26-85 3B-3 STATIC. 06-28-85 3B-8 STATIC 06-28-85 RECEIPT ACKNOWLEDGED: t~PAE*' B. CURRIER CtiEVRON* D & M* DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLEPJ< J. RATHMELL* ^ .STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. Pos'. Off,ce Bar I0036C' Anchorage. A~as~a 99510-036-f_ Telephone 907 27~ 1215. August 18, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - IQ Pad (Wells 1-8) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/dmr GRU1/31 Enclosure If AF. si~ O;'& Gas Cons. Oomm!ssi~ Z6 PHASE I AS-BUILT WELLS I Thru 8~ WELLS 9 Thru 16 (NSK 9.05,117d Z) 24 NO SCALE LOCATED IN PROTRACTED SECTION 2.6 WELL I Y - A4,67'/'.6:5 i.crt. 7007.2.'09.Z057 Pad Elev. 52.9 O.~ Elev. 48. Z 1~254' FEL 1,195' FNL WELL Z Y= 5,984,667.24 Lat_ ~e22'09.1014" Pad Elev. 52.6 O.G. Eiev. 47.9 i,175' FEL !~206' FNL WELL 5 Y = 5,984,656.79 ~t. ~°22'08.9965" X= 528,507.43 L~g. 149046'0~028 ~d Elev. 5~.9 O.G. Elev. 47.7 1,116 FEL 1~216' FNL WELL 4 Y= 5,984,646.54 L~t. 700~'08.8913'' X = 5~8,566.46 Long. ! 49046'04.503" ~ Elev. 5~8 O.G. Elev. 47.5 !,057' FEL 1,227' FNL WELL 5 Y = 5,984,291.S5 Lot. 70°22'05.4070 X= 528,50~93 Long. 149°46'06.171'' ~d Eiev. 53.9 O.G. Elev. 48.8 l,lZl' FEL !,561' FNL WELL 6 Y=5,984,502.22 Lat. 70°2~'05.511Z' X= 528,444.~ L~g. 14~46'07.89S' Pad Elev. 53.9 O.G. E~ev. 49.2 1,180' FEL 1~571' FNL WELL 7 Y= 5,984,3~2.65 L~f. 70°22'05.6~60' X = 5~8,385.78 Long. 149046'09.625'' ~d Elev. 53.8 O.G. Elev. 49.5 [~239' FEL 1,560' FNL WELL 8 Y=5,984,3Z3.11 Lot. 7002~'052211' X= 528,326.70 Long. ! 49°46'1 P=d Elev. 53.S O.G. Eiev. 49.8 !~298' FEL 1,549' FNL ~ OF ~ '' ~ ~ 49th TOWNSHIP 12N, RANGE 9E, UMIAT MER. J -3l~. 0;; & u~.,~ ,.,u,.o. ,..,,.,.,,,,~. NOTE: BASIS OF POSITION IS MONUMENTATION 19- AND 19-2 PER LHD ~ ASSOCIATES j / i i i i Il I ~~.2 ~ I 2:~ ~. I ""51.~,.~'~t ,~ r" i -':~ ..... '', / J /I 7 ~ 'J ! I HE-EBY CEtRT FY .'THAT ! AM PROPERLY REGISTERED AND ~'~THIS SURVEY ( J LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ',, '.'-'.L. / ! AND TH _ ARE CORRECT t ..... ALASKA AND THAT THIS .~LAT REPRESENTS A SURVEY MADE UNDER MY D~RECT SUP=-RV~SION ~ND THAT ALL DETAILS ArE CORRECT AS OF OCTOBER ~5, ~984. ARCO Aloskc~, inc. Ku~oruk Project North Slooe Drilling DRILL SITE IQ CONDUCTOR AS-BUILT LOCATIONS Date' Oct. il, 1984 Scale' AS SHOWN Drown By: H""Z Dwg. No. NSK _e,O,~.llTd I TO: Permit No. We wish to bring to your attention that the Comi~sion has hOE yet received the following required items on the subject well which our records indicated was completed ~ -~~-~~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. C. V. Chatter Chairman lc:C.024 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 07-08-85 TRANSMITTAL NO:5242 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. pLE/A~~' AcKN OWLED GE lQ-5 lQ-6 2D-7 2D-8 2}{- 3 2H-3 2H-3 3B-3 3B-3 RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS FLUID AND ACID DATA 'C' SAND ACID 06-23-85 'C' SAND ACID 06-24-85 'C' SAND ACID STIMULATION 06-21-85 'C' SAND ACID STIMULATION 06-21-85 'A' SAND ACID STIMULATION 06-23-85 'A' SAND ACID STIMULATION 06-21-85 'A' SAND ACID STIMULATION 06-22-85 FLUID I. D. FLUID I. D. PRESSURE DATA 1E-25 BHP WORKOVER lQ-13 STATIC AND MISCELLANEOUS lQ-14 STATIC AND MISCELLANEOUS lQ-15 STATIC AND MISCELLANEOUS iQ-16 STATIC AND MISCELLANEOUS 2E-9 BHP STATIC SURVEY 2E-10 BHP STATIC SURVEY 2E-11 BHP STATIC SURVEY 2E-12 BHP STATIC SURVEY 2F-10 FLOWING BHP AND MISC. 2U-14 'C' SAND PBU--START 2U-14 'C' SAND PBU--FINISH 2U-16 'A' SAND PBU--START !U-16 'A' SAND PBU--FINISH 2V-5 'A' SAND PBU--START 2V-5 'A' SAND PBU--FINISH 2V-13 INITIAL BHP & MISC. 2V-13 INITIAL BHP & MISC. 2V-14 INITIAL BHP & MISC. iV-15 STATIC BHP ;V-16 STATIC BHP ;X-2 E-LINE . BHP lX-2 E-LINE BHP lX-5 BHP FOR WORKOVER B-2 STATIC PRESSURE & MISC. B-3 STATIC PRESSURE & MISC. B-5 STATIC BHP PRIOR TO FRAC B-6 STATIC BHP PRIOR TO FRAC .ECEIPT ACKNOWLEDGED: PAE* MOBIL* 06-23-85 06-20-85 06-12-85 06-24-85 06-23-85 06-21-85 06-21-85 06-13-85 06-13-85 06-13-85 06-13-85 06-14-85 06-18-85 06-18-85 06-17-85 06-17-85 06-26-85 06-26-85 06-22-85 06-21-85 06-22-85 06-19-85 06-19-85 06-16-85 06-14-85 06-12-85 06-14-85 06-15-85 06-26-85 06-26-85 SOHIO* ~HEVRON* & M* NOWS CO/HAL L IBURTON NOWSCO/HALL IB URTON B. J.HUGHES B.J.HUGHES CAMCO/HOT OIL DOWELL NOWSCO OTIS OTIS OTIS CAMCO CAMCO CAMCO CAMCO OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO/OTIS OTIS . ]~ .[ OTIS OTIS OTIS CAMCO AI~sK~ Oi~ & G~s Cons. CAMCO kr, chorg? CAMCO CAMCO DATE: PHILLIPS OIL* ~l R~, T F"~ ~,~* J.,R, AT, HMELL* f.,,~. TATE OF A~*' K. TULIN/VAULT L. JOHNSTON WELL FILES ARCO Alaska, Inc. Post Office B 00360 Anchorage, Al~§ka 99510-0360 Telephone 907 276 1215 Commission July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- Wel I Action Date Performed 1B-2 Fracture 6 / 1 4/85 1B-4 Fracture 6 / 1 4/85 1E-lA Cancellation (Reperf) 1E-lA Cancellation (Frac) 1E-27 Cancellation (Frac) 1E-30 Polymer Proiect 1/5/85 1F-6 Cancellation (Frac) 1F-13 Cancellation (Frac) 1G-1 Cancellation (Stressfrac) 1Q-5 Acidize 6/23/85 1Q-6 Acidize 6/24/85 1Q-7 Fracture 6/25/85 1Q-11 Cancellation (Frac) 1Q-1 3 Fracture 7/2/85 1Q-14 Fracture 7/1 /85 1Q-1 5 Fracture 7/2/85 1Q-16 Fracture 7/2/85 1Y-2 Conversion 3/30/85 1Y-8 Conversion 3/30/85 1Y-12 Conversion 3/30/85 2A-2 Conversion 3/31/85 2C-8 Cancellation (Perf) 2C-14 Acidize 7/2/85 2H-15 Stimulation 6/30/85 2V-2 Conversion 5/16/85 on the If you have any questions, please · T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO',~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 1571 ' FNL, 1180' FEL, SEC. 26, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 91' (RKB) 12. 7. Permit No. 8q-208 8. APl Number 50- 029-21 224 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Q-6 11. Field and Pool KUPARUK RIVER FI ELD 6. Lease Designation and Serial No. KUPARUK R! VER O! L ADL 256ql, ALK 2572 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate Stimulate Repair Well Pull Tubing NOTICE OF INTENTION TO (Submit in Triplicate) [] Alter Casinc [] Abandon [] Change Plans [] Other SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Perforations [] Altering Casing [] [] Stimulation [~ Abandonment [] [] Repairs Made [] Other [] [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On June 24, 1985, the "C" sands of Kuparuk well Q-6 were acidized to improve production. The treatment consisted of 72 BBLS of 12% HCL. Diesel was used for flushing and nitrogen to aid well cleanup. Prior to starting job, equipment was pressure tested to 4,000psi. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KU PARU K /~a-~ ~_.~,,r.~¢¢-~'''~'''~ Title OPERATIONS COORD I NATOR Signed The space below for Commission use 7/15/85 Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate A~CO A :a, !nc. P6~,'f Off!ce Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~. ~ m: 06-? ~-85 TRANSMITTAL NO: 5227 RETURN TO- ARCO ALASKA, INC. KU?ARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANC!IORAGE, AK 99510 ~' ITTED z FJd4S M RECEIPT AND I<UPARU[[ lB-3 ~. 1C-.ix 1!!-3 ~. 1Q-i,. 1Q-3~ 1Q-4x 10-5~ 1Q-6~ !Q-7~ 1Q-S~ 2A-2k 2A-4 ~ 2C-5x 2C-9~ 2C-!0~ 2C-lira 2C-12x 2C-14~ 2G-l~ 2H-1 ~ 2H- ! ~ 2V-9~ 2V-! 0m 2V-! ! ' 2V-!2- 2X-2 - 2X-2 - ~X 5~ 2Z-6~ ii-7 ' 2 HEREWITII ARE TIiE FOLLOWING ITEMS. PLEASE AC~OWLEDGE RETURN ONE SIGNED COPY Og THIS TRANSMITTAL. WELL ?RESSURE REPORT ENVELOPE DATA DCE 04-21-85 04-25-~5 03-06'-85 05-26-85 05-26-85 05-18-85 05-14-85 06-06-85 04-23-85 04-17-85 04-03-05 05-27-85 05-11-85 04-23-85 04-06-85 04-40-85 03-29-85 03-26-35 04-23 -"85 04-29-85 05 -22 -85 05-27-85 05 ~-85 05-23-85 05-23-85 05-18-85 05-17-85 05-12-85 05 -14-~5 0o-~6-85 06-14 -85 06-!2-~5 04-08 -85 04-2 3-8 5 04-01-85 ACKN 0~,~ L['] PBU BOTH SD. CAMCO SB!IP BOTH SD. CAbICO PBU BOTII SD. CAMCO SBHP 'A' SD. CAMCO SBHP 'A' SD. CAMCO SBHP 'A' SD. CAMCO SB[iP BOTH SD. CAMCO SBflP 'C' SD. CAMCO SDfI P CAMCO SB[IP 'A' SD. CAMCO SBH? 'A' SD. CAMCO SBHP 'C' SD. OTIS SBl!P 'A' SD. CAMCO PDU 'A: SD. BAKER NORTH SLOPE SDIiP 'A' SD. OTIS SBItP BOTII SD. OTIS SB!tP 'A' SD. OTiS SB['IP 'C' SD. OTIS PBU 'A' SD. OTIS & BAKER ..... S D. CAMCO ???? ???????? CAMCO SCriP 'A' SD. OTIS ???? ???????? CAMCO SBII? 'A' SD. OTIS SD!iP 'A' SD. OTIS SDfiP 'A' SD. OTIS SBi!P 'A' SD. OTIS SBIIP 'A' SD. OTIS SB[[? OTIS S31IP BOTH SD. OTIS SBIIP BOTI! SD. OTIS SB[iP BOT!I SD. OTIS SBIiP PBU EOTi! SD. SCIIP DOTH SD. D: D'i J. ~ ~sU ~'i0~;~' DRILLING r jO[i-,~.,.;~: EXXON . BAKER NOTIt SLOPE Anchcrz23 GTIS DA _ ~ STAT~ 'OF"~ALASKA* / SOI!!O* U~,!C~* t 7~ Fl-- ,~ ARCO Alaska. In¢, Post Office b-oX 100360 Anchorage. Aiaskg 99510-0360 Telephone 907 275 1215 June 24, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field. Wel I Action Date Performed 1A-3 Fracture 5 / 30 / 85 1A-4 Fracture 6/1 /85 1C-5 Perforate 4/27/85 1E-3 Perforate 3/28/85 1E-3 Fracture 4/3/85 1 E-4 Per forate 4 / 20/85 1E-4 Fracture 5/7/85 1E-1 6 Fracture 4/1 4/85 1E-1 7 Fracture 3/26/85 1 E-29 Fracture 4/1 2/85 1F-1 6 Perforate 4/11 /85 1F-1 6 Fracture 4/1 5/85 1G-1 Fracture 4/1 /85 1L-1 5 Fracture 3/31 /85 1L-1 6 Fracture 3/31 /85 1Q-1 Fracture 5/31/85 1Q-4 Acidize 5/17/85 1Q-4 Fracture 5/31 /85 1Q-5 Fracture 5/1/85 1Q-6 Fracture 4/1 9/85 1Q-7 Fracture 4/27/85 1Q-7 Acidi ze 5/26/85 2C-10 Perforate 4/21/85 2D-3 Acidize 5/11 /85 2W-1 3 Acidize 5/20/85 2X-1 2 Acidi ze 5/1 2/85 on the If you have any questions, please call me at 263-4212. T. M. Drumm Kuparuk Operations TMD/kmc Attachment Coordinator (Duplicate) J u ?',,! o ~-: Alaska 0~i & Uas Cons. C0mmissi0~ Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanlicR chfieldCompany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COr~nvllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER I-] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 1571' FNL, 1180' FEL, SEC. 26, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 91' (RKB) 12. 7. Permit No. 84-208 8. APl Number 50- 029-21 224 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Q-6 1 1. Field and Pool KUPARUK RIVER F! ELD I 6. Lease Designation and Serial No. KUPARUK RIVER O! L ADL 25641, ALK 2572 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation J~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note' Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On April 29 1985, the "A" sands of Kuparuk well 1Q-6 were hydraulicaliy fractured and propped to improve production. treatment consisted of 259 BBLS of gelled diesel as pad and fluid and 13,600 LBS of 100 mesh and 20/40 sand as proppant. of gelled diesel was used as a flush. The carryin9 72 BBLS Prior to pumping, equipment and lines were tested to 6000 psi. Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KU PARU K Signed ,~,/,/~-- ~ Title OPERATIONS COORDI NATOR The space below for Commission use Date 6/18/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 25, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices field wells 1Q-5 and 1Q-6; gas injection well 2V-5. of intention to acidize Kuparuk fracture well 1Q-7 and convert to If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (In Triplicate) RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA Oi'L AND GAS CONSERVATION CO'I~rMIsSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 1571' FNL, 1180' FEL, SEC. T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 91' (RKB) 12. 7. Permit No. 84-208 8. APl Number 5o- 029-21 224 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number lq-6 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RI VER O I L ADL 25641, ALK 2572 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Per phone conversation 6-22-85 with Bill Van Alen proposed that the "C" sand in Kuparuk well 1Q-6 be improve production. The treatment will consist of with nitrogen and flushed with diesel.. of AOGCC, it is acidized to 12% HCL comingled The acid is to nitrogen/diesel equipment will be pumped by coil tubing unit and displaced with to aid well cleanup. Prior to starting work, be pressure tested to 4500 psi. Fluid Requirements' 12% HCL 72 BBL Diesel 100 BBL N2 2000 GAL ANT lC ! PATED START DATE. JUNE 24, 1985 RECEIVED Alaska Oil & Gas Cons, C0mmissior~- Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Signed ...~o~~' ~--~.~'"~ Title OPERATIONS COORD! NATOR The space below for Commission use Date 6/24/85 Conditions of Approval, if any: By Order of Approvedby BY BAJ~Iy W. K~,ER COMMISSIONER the Commission Returnecj Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ost Office ~ -'- 00360 /\t~chot'age, Al:~:-;k~ 99510-0360 Telephone 907 270 i215 June 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Q-6 Dear Mr. Chatterton' Enclosed is a copy of the 1Q-6 Well History (including Addendums) to include with the Well Completion Report, dated 04/01/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUg/L71 Enclosures cc' lQ-6 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office b,,x 100360 Anr..t-~.r;ra~to, Alaska 99510-0360 Telepi~one 907 276 1215 June 3, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 1Q-6 2u-2 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L34 Enclosures UNO ,~ .... ~._~ Ataska Oit & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany -.. STATE OF ALASKA ALASKA.. _~AND GAS CONSERVATION CC ..... ,ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-208 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21224 4. Location of well at surface 9. Unit or Lease Name 1571' FNL, 1180' FEL, Sec.26, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 2214' FNL, 1827' FEL, Sec.25, T12N, R9E, UM 1Q-6 At Total Depth 11. Field and Pool 2286' FNL, 1336' FEL, Sec.25, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 91' RKBI ADL 25641 ALK 2572 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 02/1 6/85 02/23/85 02/25/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 8645'MD,6556'TVD 8544'MD,6485'TVD YES i-~X NO [] 1857 feet MDI 1400' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/Cal, FDC/CNL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 240 sx CS II 9-5/8" 36.0# J-55 Surf 4406' 12-1/4" 1050 sx CS Ill & 700 s; CS I & Top job performed w/10, sx CS I 7" 26.0# J-55 Surf 8625' 8-1/2" 370 sx Class G & 250 s: Cold Set 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) 8170' - 8220' 3-1/2" 8078' 8051' & 7729' 8300' - 8316' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7920' - 7961 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7985' - 8005' w/12 spf, 120° phasing N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OtLRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA · EcEIV Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch~p.~ NONE ~ja. ska 0i~ & G-3s Cons, C°'ff¢oiss~°~ k~c?~orage Form 10-407 * NOTE: Tubing was run & the well perforated 4/16/85. GRUg/Wc08 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' · '~;' .!. ::f!:. i..-::"..: :- ;' L F'oRi~iATiON ~E~'TS :: "-';'-'., :-': '"';i 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 7920!. 6037' N/A ." Base Upper Sand 7999' 6096' Top Lower Sand ~, '-.-8184' 6205' ~ .- - · Base Lower Sand 8314' 6323' · .; . · · .. ! . · . · .. · 31. LIST OF ATTACHMENTS . 32. I hereby certify that the foregoing is true and .c.orrect to the best of my knowledge .. · Signed__ ~ ~ ,~,L/)~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injectiOn, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Daily Well History-Final Report Inslructiona: Prepare and submit the "Final Report" on the first Wednesday after allowable has Dean assigned or .vail is Prugged. Abandoned. or Sold. "Final Report" sboutd De suOmitled 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 lest data in blocks prowded. The "Final Report" form may De used for reporting the entire operation if space is available. Accounting cost center code District IICounty: or Parish State I Alaska North Slope Borough Alaska Field Lease or Unit ','Veil no. Kuparuk River ADL 25641 1Q-6 Auth. or W.O. no. Title AFE 504688 Completion Nordic 1 Operator I AR.Co. ARCO Alaska, Inc. Spudded or W.O. begun ]Date I Complete 4/13/85 thru 4115185 4/16/85 4/17/85 Date and depth as ut 8:00 a.m. Complete record for each day reported API 50-029-21224 W.I. ~otal number of wells (active or inactive) on this Icost center prior to plugging and 56.24% jabandonment of this well IHour I Prior status if a W.O. 4113185 | 0500 hrs. I 7" @ 8625' 8544' PBTD, RIH w/Bkr FB-1Pkr Wt. 9.1 ppg NaC1/NaBr · Accept rig @ 0500 hrs, 4/13/85. ND tree, NU & tst BOPE. RIH w/bit & scrpr, circ & lnd brine to 9.6 ppg. C&C, spot , BridgeSal pill @ perfs. Perf w/4", 4 SPF guns 8170'-8220~-,-~ ~3~ -73,~. Perf' w/5", 12 SPF. guns 7920'-7961' & 7985'-8005'. RIH ~' w/JB/GR. Rn Bkr FB-i perm pkr. 7" @ 8625 8544' PBTD, 8078' TT, Displ well w/crude & diesel 9.6 ppg NaC1/NaBr RIH w/Bkr FB-1 pkr & set @ 8062'. Rn 3½", J-55, EUE 8RD IPC CA. Stab into lower pkr, space out tbg, instl hgr & contrl in, set pkr. Tst tbg to 2500 psi; OK. Shear PBR. Tst ann to 2500 psi. Set BPV. ND BOPE, NU & tst tree to 5000 psi. SSSV @ 1857' - PBR @ 7715', FHL Pkr @ 7729', FB-1Pkr @ 8051', TT @ 8078' 7" @ 8625' 8544' PBTD, 80'78' TT, RR Crude Tst tree. Displ well to crude. @ 1600 hrs, 4/16/85. Tst SSSV, shear out bali. RR Old TO Released r~g I New TO t PB Depth I 8544' PBTD I Date Kind of rig 1600 hrs. 4/16/85 Rotary Classifications (oil. gas, etc.) Oil . Producing method Type completion (single, dual. etc.) · - Single Official reservoir name{s) -. Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oi! on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CUR Gravity AlJowabie c ..... ted -, The above ~s correct Signature z For form preparation and ~strlbution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 5/10/85 ITM Drilling Sup~F~(e~.~eCat.Gas -'Sons, Ooinmissior, Auuhorage ARCO Alaska, Inc Post Office's, ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 '¥F;.:AH,g'H Z T'TAL. i',~[] '~':-" I 'i" R A N :;' i' I I '[' T E D ,: El C E I P T A i",~ D AF;,'CO AI..A.5'.'I",A, Ii',~C, A '1" T N: I" E C C)R D S C I... Ii"' 17 K A '1" O - 1 t i i:.5: B F:'.r_). BL')X i0C, 36(-) ANCHORA(;-li!:, Al( (2 9 5i0 I. II:!: R E bJ ]: ]' H A 1:;: I!i: 'T'I'I Ii:: F' 0 I... 1... (:J I/J ]: N C- I:;: F:' T U I';: H · 0 N E .? I (;-i",t IZ D C 0 F;' Y 0 I:: I ]'lii:i'i,:L', I::'I...EA:;'F'~ ACK i'J. OWL. E:DE;E/ T 1'.1 :[ %' '1" I:;; A N S M i 'F T,'.'.l L. d 5' 17 / S Ii!: C~ U E i"l 1.'; F:'" 0 F:' Ii:: V E: N T 5' F-7 (; '-' '5 I._ "' 2 I._-'2 O,-7 ?.A-4 :.:.! A '-' 5 7.! A -. ? 2B-t 2 2C-.4 '7 C- 4 7 !.', -5 2 C, --'.5 ..C-i 4 .? I> - '2 2 I)"- i 0 2 I)- i ~ "~ .I7/ . C) 2 F -' ,"il 7 F'-" l i ';.! F -' t 1 7 [; --' t 2 (.; '-- 1 2.[;--.,9 ") i;. -~ o .- .... ":: El C Ii:' I F" T 3 ,. C U R R I 7 I..1 lie V R O i'./.:e R U N L.. Y N E"' 2 R E C 0 I:;: L':' E 17,!.;' R IE 1' R :[ 1=: V E L.. Y N Iii: ;!.,' F;: E C 0 F;; D E F;: ,? L Y N 17.? I::: R I::' Z7 R LJ I::~ Ii!: B 0 N B :?-I::' Ii:U ,S' B 1..11::' ' iL: ' ,S' A N D ' C' .S'AND.'i.' ONLY F:'BtJ 'C'.?AND F'BLJ 'FAG T A I; F: '[ L. L./ ,9 B I"1P 5' B H F' F:ALL OFF TE,.?T I:: A- I.. I... 0 F: F 'F E,T T ,~ B H F:' IZ ," I.. I N Ii" 5' F" I N / T C L 5; U R VIZ Y LEAK I)E1'ECT]:ON 'C'Z'?ANI) F' .B U I::' E: U F;:UN TOF~QUIE TLIRi',, ~r~l:-I.,,¢..~I)~..~,~ P B/.J - P LJ L L. T 0 I:;: C] !.J E "!' U F;: N / A M E R A I) A B 0 t"i I-) ..";' I:;:tJN 'I"(;!I'-.:(~IJF."' TLJFi:H/AHI!EI:i:ADR..? F:'I{-:U'-F'UI...L TOF;~C!UE '['LJF;;N/ AHIEF;:AI>A I"',:lJ N 'F F:.'tJi'l T(iII:;:(i~UIi.". TL.IF;:N/AHEF~:AI)A.5; I='BU-I-':'UL.L 'I" O FL: I;! L! E T'UF;:N/ ,.flHEF;:ADA I'.'10 H I-'~ S ('),-~ -" "~ I .... Iii 5 '.'3 4 .... ~.'~' ,-_ ''~ .... ,~°.,':~ '?) 4 - ''~ t "":- · ,.',. 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D A T F:i: · · x.$TATE OF ..',(. :;' 0 H ]: 0 -* U N I 0 N I<. TUI. i i'~/VAUi_T ARCO Alaska, In, Post Office Fox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I) A T F::-. ' 0 4 - 2 !S.--,?, 5 · -TI'?ANSM I 'r'l'AI._ NO. ·.;-':" t ..~,, R F; T (.1R/,! T O ·A IR C O A I... A.? I','. A: I i:.! C,, A 1' T N · R F-l: C 0 R D 5' C L. E R I< ATO"-I t i 5B i F'.(I,. BOX t 0 :~ ~_1 ...],l ANC !-I[)F..!Ai;.:U-. AK mm~ 'R(:,i'.~,9i"~T. TTED HI:!iF~I:T.L).TTH ARE THE F:'OI...!...[)WI ::"F A N D R I!.=. 'F !..I R N O N E .S' I G N E D C O I'-"Y O F F-' I t'..i A I_ I=' F;,' I N T S 0 P IT. N H 0 I_. I.=. < 0 ?..! IF..).~ 0 I-' E A C l.i ) ,.S," C I"1L U M I:'~ Iii; F;,' (; .F:!; IR .lC. T E M 5', P I..~ r.':i A .",~' IZ A C'. !< N (] 1:4 L. 1::.2 I) G E TI'/I,'g TRANSMITTAL, Ii:' I I._ / :? I:: I... "" (~. R D ]; I... ,,' .:';' F L. '-' (.i. tR I) I'Z N / N Iii U "- [; R '"' IR A {,J I) Iii' ?'.~ ,-" i'..! Iii. I.....'. · ~.1. !';: ..- R A I,,J DI.T. N/NI:TU .... GR-PORO D Iii; N /i'.l I';; I.I -.-[;. R-... F' 0 IR [) C Y B E R I._ 00 K D I L t,? r-:'l...-.g F~ I) ;i; I._ ," ,'"'.; F'" I_ "- (.'; R D E: ,,{ / N E. I.J -- [¥ R -- F;:A W i:, I.T N / N Ii..". I.J .... G I:;: .- f;; A W I) E N / N E LJ- [; R.... F'O F;: 0 D I=-. N / N .F.. U.- (; R .... F-' 0 R 0 C Y B E R I... 0 [)14 ;, ,::. --- ,.:..3 -" ,.':> .::. N U N :.":. t 02-275, .... 8.5 RUN :~:1 0,'~ ._.")"z .... o,.,-. R U i".~ ~: t ~.. K.. ".-.~ ~.-' ./ · 02..- 23-. 8~_, .RI.IN. ~: t 02.-..2~ '"'~ .... '- c;_, RI IN t 0'~- '~"3 '" 85 :,": ~:..,:. " R U N t 02"-2".2~ .... ,95 RUN :~t 02-t "' 8~':; Ui',. t .,..-. .... .. RI ,I ,~ '"., ....... .:~,.-- f :)-.-,°,'5 RUN .~ t 02-t 2-8.5 RUN Ot · 'a '~ 2 --' 8 '5 . ,~., ,....- i ..... F:,' tJN r:-,?- i"",:. "'"S RUN :~: i · .: .,~.. ~ (=., 02-i'" ~ '" ~: - R Ua i .. ~:2 C) .~. u~=-~')-.'°~';,= ,_,.., RUN ~ 4405 .... 867'?- 440'::' ,.; z - -- ..> .... <::, ,:.) -.i~ I' 440!5_,,..~ , .~ ...-' ('3 'I ..:.. 4.,.f0'=' 86t 2 440 '"-..- 86 i 440 ':';5 -- '" ~' · . C) t.) i ''') 785G-.'""S'.So. ,::} 37t ~---81 7,":. K. 37 t,:.°-8 i' 70 4-30¢:) · F't 44 · .. -' 4 S 0 0 ~ 4 4 -~ z ~.'-, m f o.>~:7"-c:,, .:}L', · "~ .") -,~ b, c 7,084- ~ t 62l 9 O ':" '?' 09' 9 6 ;590 .... 7099 6 ;~ 90 '"' '7 ('i.'. 99 6390 .... 7099 65"" ...... :;.~ ',9 "" D A T E. ' ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510~0560 Telephone 907 276 1215 April 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Q-6 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. Tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L44 Enclosures Alaska 0it & Gas Cons. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA 0. ,~-.AND GAS CONSERVATION CC .... ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED {~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-208 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21224 4. Location of well at surface 9. Unit or Lease Name 1571' FNL, 1180' FEL, Sec.26, T12N, R9E, UN ~r~:~-~ .... ~- Kuparuk River Uni~ At Top Producing Interval ~ ,,/',~,~1-- ~ 10' Well Number 221~~ FNL, 1827' FEL, Sec.25, T12N, R9E, UH~ ....'~'": 10-6 At Total Depth ~ ~ 11. Field and Pool 2286' FNL, 1336' FEL, Sec.25, T12N, R9E, UN i~'H' ~' J Kuparuk River F~eld 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. Kuparuk River 0~ 1 Pool 91~ RKBJ ADL 256~1 ALK 2572 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore ~ 16. No. of Completions 02/1 6/85 02/23/85 02/25/85~ N/A feet MSL~ N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth(M~D) 19. Directional Survey 20. Depth where SSSV set ~ 21. Thickness of Permafrost 86~5'ND,G556'TVD 85~'ND,G~85'TVD YES ~X NO ~ N/A feet MD~ 1~00~ (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/Cal, FDC/CNL, Gyro 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-~0 Surf 103' 2~" 2~0 sx CS I I 9-5/8" 36.0~ J-55 Surf ~06~ 12-1/~" 1050 sx CS III & 700 s~ CS I & Top job performed w/10( sx CS I 7' 26.0~ J-55 Surf 8625 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAS-OILRATIO 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. NONE Form 10-407 TENP/WC06 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,.,..... . .,, ':..'.' ..... .. ,:.. :.:. ...... 30 ..... ' ' - 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 7920': 6037' N/A Base Upper Sand 7999' 6096' Top Lower Sand 8184' 6205' "~' ' - ' ' -' .- Base Lower Sand 8314' 6323' . :. :.'. ~ · . . · · 31. LIST OF ATTACHMENTS · 6~,,rescep,.'c Suc-vey (2 cop,.'es) ' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .. Signed & ~ ~L~~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.)i Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telep. hor~e 907 276 1215 April 2, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: lQ-6 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 1Q-6. I have not yet received a copy of the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, ;/...x. u~(_u ... U.-- J. Gruber Associate Engineer JG/tw GRU5/L76 Enclosure RECEIVED Alaska Oil & Gas '~' uon,,, Comrn~ssmr~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA ~_~_~-AN D GAS CONSERVATION CC__,,ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED i-~× ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-208 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21224 4. Location of well at surface 9. Unit or Lease Name 1571' FNL, 1180' FEL, Sec.26, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 1Q-6 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 91.2' RKBI ADL 25641 ALK 2572 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 02/16/85 02/23/85 02/25/85I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8645'MD 8544'MD YES [] NO []XI N/A feet MD 1400' (Approx) 22. Type Electric or Other Logs Run D I L/GR/SP/Ca 1, FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5// H-40 Surf 103' 24" 240 sx CS II 9-5/8" 36.0# J-55 Surf 4406' 12-1/4" 1050 sx CS Ill & 700 s; CS I & Top .~ob performed w/10() sx CS 7" 26.0# J-55 Surf 8625' 8-1/2" 370 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ 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. · .. : Form 10A07 GRUS/WC37 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Subr~it in duplicate ' ' ..... ' .- ~' '" ~;:-:.? '-:2' i? '.~-: -:" :~: :.: ':~- , .-: ' :, ::-:. ;" .!FORMAT~iON-.'TEsTS? '~.,:~-~.~, . ::: . '. · ... _ · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH .GOR, and time of each phase. . . . N/A ·. N/A _ . · . · , . . . 31. LIST OF ATTAC'HMENTS .- .. ~,;-. Nope '- : -: - 32. I hereby certify that the fo[egoing is. true. and .correct to the best of my knowledge . _ · . . Signed /~ ~ ~ Title A$$ocJaLe Erlg~Deer- Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Rump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 ARCO 011 and Gas Company Well History- Initial Report- Daily Instruefle.~: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. DelJy work prior to sPudding should be summarized on the form giving inclusive dates only. District r.C°unW. parish °r b°r°ugh [state Alaska North Slope Borough Alaska Field ILo8~ or Unit IWell no. Kuparuk River ADL 25641 1Q-6 Auth. or W.O. no. ~Title AFE 504688 I Drill Nabors 26-E AP1 50-029-21224 Operator ARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun ]Date Spudded I 2/16/85 Date and depth as of 8:00 a.m. 2/19/85 2/20/85 2/21/85 2/22/85 Complete record for each day reported Prior status if a W.O. 16" @ 103' 4426', (4323'), Rn'g 9-5/8" csg Wt. 9.5, PV 14, YP 20, PH 9.0, WL 18.6, Sol 9 Accept ri~ @ 1315 hrs, 2/16/85. NU diverter sys. ~,fk~-~/~, 2/16/85. 4426'. RU to rn csg. 813', 6°, S67.5E, 1358', 20.7°, S79.5E, 1731', 31.8°, S81.5E, 2078', 41.1°, S84.5E, 2593', 45.7°, S83.5E, 2906', 46.9°, S82.5E, 3535', 46.2°, S80.5E, Spud well @ Drl 12¼" hole 692', DD to 2148', ND to 812.66 TVD, 11.54 VS, 3.825, 11.14E 1342.83 TVD, 129.88 VS, 39.745, 125.82E 1677.32 TVD, 293.44 VS, 68.035, 287.09E 1956.33 TVD, 498.99 VS, 99.375, 490.29E 2329.63 TVD, 857.68 VS, 138.828, 846.87E 2541.88 TVD, 1083.96 VS, 166.405, 1071.47E 2979.40 TVD, 1535.72 vS, 233.185, 1518.36E 9-5/8" @ 4406' 4426' (0') TIH , , Wt. 8.8, PV 5, YP 4, PH 9.0, WL 19.4 Rn 101 its, 9-5/8", 36#, 3-55 BTC csg w/FS @-~7-9~', FC Cmt w/1050 sx CS III, followed by 700 sx CS I. Displ using rig pmps, bump plug. Tst csg to 1500 psi. CIP @ 1430 hrs, 2/19/85. Perform top job w/100 sx CS I. ND diverter, NU 11", 3000 psi csg head & BOPE. Tst BOPE: OK. TIH w/BHA. 9-5/8" @ 4405' 6094', (1668'), Drlg Wt. 9.3, PV 11, YP 13, PH 10.5, WL 13.8, Sol 9 TIH, tst csg to 1500 psi. DO FC, cmt, FS + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 6094'. 4783', 48.2°, 881.5E, 3776.84 TVD, 2381.25 VS, 380.795, 2351.84E 5353', 47.0°, 884.5E, 4163.11TVD, 2800.32 VS, 437.995, 2767.00E 5980', 47.2°, S86.5E, 4590.73 TVD, 3258.28 VS, 473.975, 3224.t2E 9-5/8" @ 4405' 7850', (1756'), POH Wt. 9.8, PV 13, YP 9, PH 10.5, WL 6.2, Sol 13 Navi-Drl & surv 8½" hole to 7850'. 6699', 45.8°, S85.5E, 5084.49 TVD, 3780.10 VS, 512.755, 3745.27E 7642', 43°, 886.5E, 5758.27 TVD, 4446.06 VS, 567.995, 4409.678E 7850', 42°, 887.5E, 5907.94 TVD, 4582.75 VS, 575.175, 4546.63E 56.24% The above is correct Signature For form preparation and dlstrlbu#on, - see Procedures Manual, Section?O, Drilling, Pages 88 and 87. IDate 3/21/85 D~iliing,~ Superintendent ARCO Oil and Gas Company Daily WelI ~istory-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 it space is available. I Accounting District ICounty or Parish iState Alaska North Slope Borough Field ~hease or Unit Kuparuk River I ADL 25641 Auth. or W.O. no. ITitle AFE 504688 J Drill Nabors 26-E AP1 50-029-21224 Operator ARCO Alaska, Inc. cost center code Alaska IWell no. lq-6 Spudded or W.O. begun A.R.Co. W.I. 56.24% Date 2/16/85 Spudded Date and depth as of 8:00 a.m. 2/23/85 thru 2/25/85 2/26/85 Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our~-~ ll'.-~- ~'~,.~ Prior status if a W.O. 7" @ 8625' 8544' PBTD, (795'), Swg tbg spools 10.0 ppg NaC1/NaBr Drl 8½" hole to 8645', short trip, POH. Rn OHL; DIL/GK/SP/CAL~ ~/ 8645'-4405', FDC/CNL f/8645'-4800', TIH, C&C, POH, LD DP. Rn & lnd 214 its, 7", 26#, J-55 BTC csg w/FS @ 8625', FC @ 8545'. Cmt w/370 sx C1 "G" w/3% KC1, .7% D-19, .3% D-31 & .1% D-6. Displ w/10.0 ppg NaC1/NaBr. Bump plug. CIP @ 2300 hrs, 2/24/85. PU BOP, set slips, cut 7" csg, instl pack-off, NU tbg head, att to tst pack-off; no tst. ND tbg head. 7" @ 8625' 8544' PBTD, RR 10.0 ppg NaC1/NaBr ND tbg head, inspect 7" csg stub, has flat spot 180° f/ERW. Drifts, OK. NU new tbg head, energize & tst pack-off to 3000 psi; OK. RR @ 1200 hrs, 2/25/85. Old TD Released rig 1200 hrs. Classifications (oil, gas, etc.) 0±]_ Producing method Flowing New TD Date 2/25/85 PB Depth 8544 PBTD Kind of rig Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary 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 corrected The above is correct Signature I Date I Title /.~,.¢~.-~,~_...,,~ 3/21/85 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. .. · Drilling Superintend'~{~'I;!':;:~,9 ADDENDUM WELL: 3/12/85 3/18/85 lQ-6 Log w/CBL/VDL/GR/CCL f/8543'-6540'. Log w/gyro f/8543'-surf. Arctic Pak w/250 sx CS I, followed by 60 bbls 7.7 ppg Arctic Pak. - Drilfi~:~ ~u~e~'intendent ADDENDUM WELL: lQ-6 Log w/CBL/VDL/GR/CCL f/8543'-6540'. f/8543'-surf. Log w/gyro Drilling Superintendent Date March 26~ 1985 Directional Services Pressure Services Chemical Transmission Systems Mr. Randy Ruedrich ARCO Alaska~ Inc. P. 0. Box 560 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-50050 Well: 1Q-6(SEC 26 T12N ROgE) Field: Kuparuk Alaska Survey Date: March 11~ 1985 Operator: J. Samec, M. Derison Mr. Ruedrich: Please +ind enclosed the "Original" and one (1) copy o+ our Boss Gyroscopic Multishot Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely~ NL SPERRY-SUN~ INC. Ken Broussard District Manager Enclosures NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 · ':;F'ERRY-'._--;UN NELL SLIRVEYING F:OHF'ANY ANCHORAGE ALASKA ARCO ALASKA, INC. '10-6 KUPARUK ALASKA VERTICAL '-:;ECTION F:ALF:ULATED 'ALONG F:LORURE COMPUTATION DATE MARCH 13, 1985 PAGE 1 DATE OF SURVEY MARF:H 11, I'FCE:5 BOSS GYROSCOPIC SURVEY ,_lOB NUMBER AK-BO-50030 I KELLY BUSHING ELEV. = 91.00 FT. OPERATOR-,_I. SAMEC, M. DERISON .... TRUE 'SUB-SEA MEASURED VERT I CAL VERT I CAL DEPTH DEF'TH DEPTH 0 0.00 -91.00 100 100.00 '.-?. 0(} ............ -e ~ ~ ~o~ 2(}0.00 10~, 00 300 300. O0 20'P. 00 400 :~ 99. c¢ 9 '=" ' "-' ....... =,0o. .......................... 500 4~. 'P~ 408' ¢9 600 599.99 508. g9 700 69'P. 98 608. .......................... 800 799, 78 708.78 'PO0 899.06 808.06 1000 997.77 906.77 1"100 1095.67 1004 67 1200 1192 75 1101 ' 1300 1288.6._, 1197. 1"400 ' '~ 78 z ~,_,~. 1291.78 1500 1475.06 1384.06 1600 1565.45 1474.4.5 .................. 1'700 lo, o _. i~6o o9 1800 I -~:o. . 7 ..... 77 1647 77 1900 1821.4'P 17:30.4 2000 190, .1.36 ,,_,R10.36 ' o 100 1978.04 loo7.04 2200 2051.47 1960.47 ~o00°~ · =oI =~,.o~ 16 =°n')° .= 16 2400 21 'P4.2'P 2103.29 2500 '2264.93 2173.93 ~6~ ~}0 loo~,~"=. 0~ 2244 '09.. 2700 2404.7.5 2313.75 o o 0 r~ --, .-, c, c,:~ ? ? 0 = ........ ~47.:,. 90 COLIRSE I NCL I NAT I ON DEG MIN COURSE D I RECT I ON [ EuREE._. N O. 0 N 75.30 N 61. N 78.50 N 77. 0 N 84'.'60 S 66.69 S 76. 0 'S 64.30' S 66.80 S 67.89 S 72 ;' 1S/' ".~ 72. 19 0 0 0 16 O' 18 0 0 20 0 0 24 i 6 5 43 7 47 10 :33 12 52 14 50 18 2 S 78.50 21 '23 S 78;"~?' 23 51 S 79.80 26 46 S 78.80 :3 ':2 41 4:3 56 44 26 .~; .':, 44 45 1:3 45 · ...i, 46 1 46 28 46 4I S77';80 41 S 80.30 39 S 78.60 18 .... S80''0 32 S 83.10 S 83.10 ':' 82. ~"? S 82.89 · '_--; 82. :::0 S 82.50 S 82.69 S 82.30 S 82. O' DOG-LEG :SEVER I TY DEG/100 E 0.00 E 0.27 E 0.08 E 0.11 0.02 -_- 0. I0 £ 0.21 0.70 S 4.66 ' E 2.08 '-' 78 · ' ~ E' -.~' 47 E 1.97 E 3.66 E ....... ._.':". 35 E 2.51 E 2. '.'.-?5 'E .-.":' .._'.'-9. E 2.6'7 E 3.11 E 2.78 ' E 3.7.9 E 2.41 E 0.52. E 0.42 E.. 0.37 E .................. O. 48 E 0.40 E 0.5:3 E ' 0.30 ' TOTAL RECTANGULAR COORD I NATES NORTH/SOLITH EAST/WEST 0.00 0.00 0.06 N 0.2:2: 0' 24 N 0.69 0.43 N 1.21 0.56 N 1.79 0.66'N 2.4.5 0. 18 N 4.41 o o? S 9 'R 7.06 S 20.57 13 17 S '='~ 29 20 0~ ~ 54 ~9 27 '-"= '-' . .=,.j.=. 77.18 34 . .=,.J S 104.56 4I.'01 S 137.62 48.17 S 175.41 56.13 S 217.43 64.94 S ==,4 17 73.92..=,'-' 31 .J = . 44 84.24 S 370.6.5 ~ ~, .=, 429.76 04.75 S 493.23 1':' . ~. '?0 S 560. 21' 40 S 629.79 30. O'P S 6'P'P. 54 38.90 S 769.77 4o. 01 o _ '~ ~' g40.44 ,., 7.~'-'~, = S 9. 11.58 66.68 S 983.21 76.60 S 1055.17 E E E E ._ ._ _~. E E E E E E E E E E E E E E E E VERT I CAL SECT I FiN O. 00 (?) =.._, 1.14 1.69 o ~3 3.04 4.34 10.06 21 o._ 36.77 5A -- . _.._I 80 '-' 141. ?7 180.38 .--, .--, .- ~ ~-::. 09 ~7(_. 61 · ':,.=,o 63 378.74 4 q'-" :~2 5(}2.97 570. ,:,~""-' 640.52 710.81 781.57 852.83 924.57 996.81 06'P. 45 :--;F'ERRY-SLIN WELL ::;LIRVEYINI3 F:OMF'ANY ANCHORAGE ALA:RKA ARCO ALASKA, INC. 1Q-6 KUPARLIK ALASKA · . VERTICAL SECTION CALC:ULATED ~LONG CLOSURE COMPUTATION DATE MARC:H 13, 1985 PAGE '-" DATE OF SLIRVEY MARCH 11, 19:35 .. BOSS GYROSCOPIC: SURVEY .JOB NUMBER AK-BO-50030 KELLY BUSHING ELEV. = 91.00 FT. OPERATOR-._I. SAMEC:, M. DERISON TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COLIRSE D I RE~Z:T I ON DEGREE'._:: DOG-LEG SEVERITY DEG/100 TOTAL REC]'ANGLILAR COl]RD I NATES NORTH/SOUTH EAST/WE:ST VERTIIZ:AL S E C T I ~]lN :3000 2611.0/:, '25';'0.06 46 56 S 3100 2/:.79.22 '.--'.~,:--:F~ ':..'2 47 7 S . ........ :3200 ..-_'~. 7a~_,. 30 ~:o,."' .~,-'/ ~0 45 27 S · 56 .56 3300 2:-:: 18. 2727 45 16 S 3400 ~,_,o ~, o o,-,~. 86 2797 .86 4.5 ~_._':"q .=,'-' 3500 .-'~°o ~,-,.. oo. Ag_ 2867 .69 4A_ I ._, 3600 3027.87 2936, 8'7 46 '.-..'5 :":; 3700 :::0'..-77, I'F/ 3006, 19 4.5 48 S .......................... ~ ~:8o0_ .. 3166.79 0o7._ ,79 45 .. ,~, S 3900 :3236.06 3145.06 46 19 S 4000 3305.02 3214.02 46 2:3 S 41 O0:337:3.81 ._q s,o ~. ,_,_,,. 81 4A_ ._,._°.~, S ._-,.:,._ 1 42Oo 7:442 46 '-"- 56 '-"-'~ ...... o._-: .'-:; 4:_::00 '-'?, ':'?, ~._ 11. 30 3420. :_:: O. 4 A_ ._,._ S "' 4400 :~.~,,qO ~ --,~-,c~ . _ ....... · _-,-~,:, ... (-~.~ 46 ._, 4500 3648 29 :R~7 29 4'7 '-"" S 4600 o71._ :2:7 3/:,24, 37 48 20 ................. ."~"'7 0 0 '4700 ._ ,~,,. 14 3691. 14 47 ._,.-,_ :--: 4800 ::::R49.60 :--: 7.%q .60 47 1 ._, ~ S 4900 3917.81 3826.81 4/:, 44 S .'s,..O00 3986.24 3E:75 24 ...... 46 5:3 S 5100 4054, 60 .-,o .~, ._ · :,,. 6,:,. 60 46 51 .q .-_, -} .-).-,.-, 5--t 0 41~..:,'-'"'. 0'--,'. 4~..:,.~ , 09 46 41 '"._-, .............................. .... ~o00 ~' 41 91, 77 ...... 4'1 O0 "7'7 -46 ._ 5400 42A0_ . .~2 4169 . ._.'-]"-"~_ 46 .-"-'=.-, S 5500 4329. 19 4238.19 46 40 S 4~ ~7 4306.80 4I .:, . '-' Pi P .:,.z, 5700 4466 48 4o7._. 4_, 46 '-"-' - 4._ .>~ 1 '-' 4444 1:2: 46 44 S · _,,-,00 M'-'5. o . · _~00 4/_-,0.3.64 4.512.64 4/:, 46 S 81.80 81.89 81. 0 80.80 80. 0 80. 10 80. 0 79.80 79.69 79. 10 79. 0 78. ,'.--].,9 78.69 78.50 78 ,'39 78.50 78.60 80.30 81.50. 81.89 82."19 82.3'..'/ 83./:.9 '-"= 69 :-::5.50 85.30 85.19 85.30 o._,. :30 85.39 E E E E E E E E E E E E E E E E E E E E E E E EE E .. cD.. 29. 1 ::,'_/-,_. ::q :--: S 1127 . ._-.._,'-' '= E 1 142.36 0.20 197.2._5 S 1199.79 E 1215.54 1.79 207.99 S 1271.27 E 1287.81 0.24 219.25 S 12:41.5:2: E 1:R5:::.96 0..5:3 231.11 S 1411.65 E 1430.04 0.64 243.47 S 1482.16 E 1501.5:-:: 0.40 255. 'i:75 S 1553.28 E 1573.74 0.63 268.59 S 1624.2:3 E 1645.76 0.18 281.37 S 1694.89 E 1717.51 0.56 294./:.3 S 1765.78 E 1789.55 0.17 308.39 S 1836.89 E 18/:.1.88 0.13 322. :30 S 1908.12 E 19:_'-:4. ',-.':5 0. 15 3:3/".. 41 S 1979.36 E 2006.85 o .... 1.~ '-'='z.._,O. 7/_-, S 2050.55 E 2079.34 0.08 365.30 S 2121.70 E 2151.82 0.84 379.94 S 219:3.31 E 2224.77 0.95 394.66 S 2265.99 E 2298.79 I. :2:4 408. '29 S 23:_--:9.17 E 2:_::7:_--:. 15 1.09 419.97 S 2412.0!5 E 2446.94 0.59 430.5'.-.-.2 S 24:::4.41 E 2520.07 0.27 440~'61 S 2556./:.3 E 2592.99 0.15 450 . :39 S ~'>/- '-"-'_.~¢,. 96 E 2/-.AS_ _ _. 97 0.96 459.20 S 2701.28 E 2738.82 ....... 1"i'46 465,'92 S' 2773.64 E 2811.41 c}_. 1 ._,~" 471' 49 S 2:5:4 A_. <_').:,"- E 2 :---: 8:3. :::_ 9. 0. 16 477.32 S 291:::.51 E 2956.46 48:2:. 7:4 S 2991.01 E 3029.10 489.36 S 3063.44 E 3101.67 495..'2:2 S :} 1 :'::5.91 E 3174.27 501.23 S 3208.52 E .'_--:247.00 E ........................ O; 07 E 0.16 E O. 19 E ' 0~ 08 SPERRY-SUN WELL SLIRVEYING ;z:OMF'ANY ANCHC;RAGE ALASKA ARCO ALASKA· INC. lQ-6 KUPARUK ALASKA VERTIC:AL SEF:TION C:ALCLILATED ~LFING C:LCn--;URE COMPUTATION DATE MARCH 13· 1985 DATE OF SLIRVEY MARCH 11· BOSS GYROSCOPIC SURVEY ._lOB NUMBER AK-BO-50030. KELLY BUSHING ELEV.= OPERATOR-J. SAMEC· M. - TRUE S/JB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COURSE D I REC:"I' I ON DEGREES DOG-LEG SEVERITY BEG/100 TOTAL RECI'ANGULAR C:C;ORD I N ATE::-' NORTH/SOLITH EAST/WEST 6000 4671.90 4580.90 6100 4740.30 4649.30 ........ 6200 4809.16 4718,16 6300 4878.21 4787.21 6400 4947.47 4856.47 6500' 5017.0~~ 4?26.05 6600 5086.96 4995.96 6700 5157.37 5066.37 6800 5227,8? 5136~87 6900 5298.21 5207.21 7000 5368.70 5277.70 ................................... 7I'00 5439.52' 5348.52 7200 ~ ._,._10.72 5419.72 7300 5582.04 5491.04 ........... ....... 7400 5653.81 5562,81 7500 5726.37 5635.37 7600 5799.43 5708.43 7700 5873.17 5782.17 7765 5921.50 5830.50 7800 5947.58 5856.58 .......................... ~n~o ~? ~Ol. OO 7900 ..... ~ ............ ~ 8000 6096'.68 6005.68 8100 6169.87 6078.87 ~ 6242'03 ._~00 6151.03 8300 6313.07 6222.07 8400 6383.66 6292.66 8500 6454"07 6363.07 8600 6524.09 6433.09 8645 6555.61 6464.61 HORIZONTAL DISPLACEMENT = 47 7 S :]:5. :_::9 E 46 34 S 8:]:.60 E 46 "~ '-"~' .- ..:. S 50 E r', ,,S. · 46 1/--. S 82.80 E 46 ._°. S 83. z~.)'-'c E ~45 46 ._~ "~:'._.._.. 19 'E 45 45 45 45 45 44 44 44 43 43 42 42 41 41 41 42 43 44 45 44 0.34 1.42 O. 82 O. 25 0.42 O. 28 0.29 O. 50 0,41 Om '''! .-i O. 48 0.23 0.42 0.25 O. 96 0.50 0.58 0.74 O. 53 0.78 1.22 1.11 0.91 0,'85 1. 1.59 45 33 S /o.6} E i.94 45 33 S 78.60 E 0.02 45 33 S 78.60 E 0.04 5174.00 FEET AT SOUTH 82 DEG. F'AGE._,':' 91.00 FT. DER I .:,L N VERTICAL SECT I ON 3 MIN. EASI' AT MD = ,::.64._, 50 '7.0 '? S E: 281. :]: 6 E 3319...-;/.._, =' 514.07 S ::::::5::: 96 E 3392.82 ~':"::' "~= ....... fi: 94 :3465. ~:~ ...... ,:,._, S o4~._. E -'- :--,o ._ 3537,65 ._o~, 10 F; 3497, 68 E 540.83 S :E:56'?. 28 E :E:609.77 54~. 27._, ~ 3640.61 E ._, ~,_,. . _ _ 557.67 S 3711.61 E 3753.06 565.96 S 3782.14 E 3824.06 ~c'1 60 ~; 3923 28 E 3966.00 ~, o,:, 71 S :::993 '-"- .... ~.:, E 4036.88 5~5.41 ._.~ 4064.13 E 4107.42 601.90 S 4134.05 E 4177.56 608.37 S 4203.84 E 4247.58 o E 4317 14 614. f~ 1 ._, ~ 4273 .1 ,_, 620.75 S 4341.7:]: E ~.:,~._. 626.04 S 4409.80 E 4454.01 4._.~ 1 42 ~ ':' 1.z.~'~" S 4477. 14 E ~'-' 634.67 '.E; 4520.48 E 4564.81 636.42 S 4543.75 E 45.98. 11 ~4~.1._, S 4609.94 E 4654.45 649.08 S 4676.43 E 4721.26 656.44 S 4744. 16 E 4789.36 _ .~ S 4812 9M E 4c,~,:,. 672.31 S 4 E: 82.86 E 4 '? 28.9':2 681.79 S 4953.04 E 4999.73 694. ~.J'-"= ._,° ~,,.~0~'. 93 E 5070.68 708.36 S 5092.91 E 5141.9:} 714.71 S 5124.39 E 5174.00 ARCO ALASKA~ INC. 1 ~.-6 KUPARUK ALASKA SPERRY-SUN WELL :_-]URVEYING CCIMPANY ANCHORAGE ALASKA C'OMPUTATION DATE MARRH 13~ I .': F'AGE 4 DATE OF SURVEY MARC:H 11, 1'.-7,:_=:5 ,_lOB NIJMBER AK-BO-50C~30 KELLY BUS;HING ELEV. ~- 71.00 FT. I]PERATOR-._I. .SAMEC:', ' M' 'DERIS;ON INTERF'OLATED VALUE:Z; FOR EVEN 1000 FEET AF MEAS;URED DEPTH .. ]'RUE SUB-SEA TOTAL MEASURED VERT I C:AL VERT I CAL RECTANGULAR COORD INA TES MD-TVD VERT I CAL · ' DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST D I FFERENCE CORREC:T I ON 0 ....... 1000 2000 3000 4000 5000 6000 ................... 7000 8000 0.00 -?1.00 0.00 0.00 0.00 :~:.~7.77 ?06.77 13, 17.:, ~ 35.29. _ = ~.':' 23 2.2:3 1~01 36 1810.36 '-~ ~,d S 42'~;. 76 ~ '~8.64 ?6 42 2/-. 11 06 ?~'?0 06 18/-, '-"-' - ......... o o '.~ 1127 q ~ . .... ~, _ 388 ?4 2'~;0.30 '~ .... A~ A2 3m14.02 ~'~ :=:9 - o.z .... ,. - - 308.._~9. ..,° 1 o.z, z .... . 694.98 :3AA_ _. 04 3t~86 24 :z::~9~ 24 440 61 S '-'=~ .Z . . ....... ~ ._,._ z.. 63 1013 76 318 78 4671.?~0 4580.90 =l' .-. . Z ' -. . . ~, J 7 ~')9 S 3281 36 1 :'~2:-: i i"~ 314 34 59A8 70 .z77.70 ~ .... ..,L~,z, ~1 ~ 3~3 q~ = 1=,.z,I ..... z, .).z,. 60?;6 68 6005:68 64t~ 08 S 4676 43 z- 19('):N ""'- ............ :,~ 272.02 8/-,45 6555.61 6464.61 714 71 S ,_ 1 ~4. _ 208':/. 3S~ 1 o :.. 07 ................ THE CALC:ULATION F'ROCEDURES ARE BASED ON THE LIS;E OF THREE DIMENS;IONAL RADIUS OF CLIRVATURE METHOD. ARCO ALA:=-;KA, KUPARUK ALASKA INC. SPERRY-SUN WELL '.--;URVEYING F:OMPANY ANCHORA~Z~E ALA::;KA COMPUTATION DATE MARCH 1.3-, 19:E:5 DATE OF :--;I_IRVEY MARCH 11., ,_lOB NUMBER " -" ..... " AK-BU-._,Oo...O KELLY BU:_:;HING ELEV. = OPERATOR-,_i. SAMEC, M INTERPOLATED VALLIES FOR EVEN lC)C) FEET FIF SLIB-F;EA DEF'TH TRUE MEASLIRED VERT I CAL DEPTH DEPTH 0 0.00 ......... 91 91.00 191 191.00 291 291.00 ......................... 391 391.00 491 491.00 591 591.00 691 691.00 ' 791 791.00 891 891.00 993 99'I;00' 1095 1091.00 ~, 1198 1191.00 ..... '~ 1.:,0~ 1291.00 1408 1391.00 1517 1491.00 ................... 1628 1591,00 1743 1691.00 1862 1791.00 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORREC:TION -91.00 0.0,0 0.00, 0.00 0.00 0.05 N 0.19 E 0.00 100.00 0.22 N 0.64 E 0.00 200.00 0.42 N 1.15 E 0.00 :~o0 00 0 ~4 N I 73 E 0.01 400.00 0.6.5 N 2.38 E 0.01 500.00 0.58 N 3.09 E 0.01 600.00 O.~=~'N ....... 4.24 E ~3..02 700.00 1.87 S '~¢.11 E 0. 19 800.00 6.62 S 19.56 E 0.86 ~00.'00' 12:71 ~.~ ....... 34'15 'E =.~ 11 1000.00 19.70 S 53.37 E 4.21 1100.00 27.20 S 76.74 E 7.1'~? 1~o0 00 34'50' S 10._.o~ E 11 47 1:300.00 41.64 S 140.78 E 17.83 1400.00 4:~. 45 S '~"-' loz.44 E 26.47 ~ ] ~ .. ~ 1 ._,OL. O0 = ..... E 76 6~, % °~ 37 37 1600. O0 68.83 ~,':' 286.11 E 52.71 1700.00 :30.1'2 S 349.64 E 71.74 0.00 0.00 0.00 O. O0 0.00 0.00 0. Ol 0.17 0.67 2.09 ":' 9::: 4 '~R 6. :36 8.64 I 1 14.95 19.0:3 F'AGE 5 19:s:5 91.00 FT. DER I SF;N ARCO ALASKA, IQ-6 KUPARUK ALASKA MEASURED DEPTH 1786 ................... 2117 2254 23?5 2537 2680 2824 ................................. 2970 3117 3260 ....................... :3546 i 3:671 ............................ ~834 3979 4125 42'70 4415 4563 I NC. SF'ERRY-SLIN WELL :_:;URVEYING F:OMF'ANY ANCHORAGE ALA:E;KA COMF'UTATION DATE MARCH 13, 1785 DATE OF '.-]URVEY MARE:H I 1, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-]'VD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE ._lOB NUMBER AK-BFI-5o030 KELLY BLISHING ELEV. = OF'ERATOR-.J. SAMEL-:, F'AGE 6 1:985 VERT I C:AL CORREE:T I ON I ?1. O0 FT. M· DERI SON 1:3 ? 1.00 1800.00 9 .... :~. 9 A S 421 . 7 :--: E c~...~-;_..__,.-. ~._, 1'-.-~':~1... .00 1700', O0 106. lA._ ._. ~-' 504 A~'_ ~_ E 19~.... :31 ,.. ~ ....97 2091.00 2000, 00 117.51 '._:; .~'98. 2171.00 2100.00 127.68 S 6?6.:30 E 204.:B6 2291.00 2200.00 142 1'? .~ 79.~ 83 E .-4'-,. 01 2Y-:? 1. Or~ 2300.00 -.,._~ ~-~. 44 ._¢: o.7.44'-"~ E '28?. 1 2471.00 2400.00 167.10 S 1001.05 E :333.84 _ . ~_ .. .~ .q"'?.' I106 lA' E 3:7? 62 95~1 00 950¢) 00 18.. ~ ~: .... 2691.00 2600.00 19'9... 04 '-'o12 lz. '~' 36 E 426.32 27 ? 1 00 2700.00 '~' 14. or · .. .=, J S 1314.07 E 46?. :34 . ,-._1 48 ._. 1413 78 E 51'2 04 2891 ¢)0 2800, 00 '"':~ . '"'-~ '-2771.00 2?00.00 24 ?. 24 ,.$; 1515. 18 E 5.~.~ 3071.00 3000.00 267.46 :s; 161'7. ?6 E 600. 11 :B191.00 3100. ¢)0 ' ~:~.~,~._,._. 84''~._. 171.9.54 E 643 3271.00 :::200, 00_ .305.57 S 1'"'-"-',:,.' z. 39 E 688.64 33? 1.00 "'"~' ]'. ~ .... ?5 E 734. _. .:,o~O 00 'R25 8£) S 1~'-'~- -~ ~ 48-'-~ 3491.00 3400.00 o4 .... ...,.,.. ..... ,1 E 777.46 :B571.00 :3500.00 :367.62 :z; 213:'.::. 02 E 824. 3671.00 36o0.00 387.24 .S 2237.14 E 872.34 ., ......... .. . 24.10 30.46' 37.67 40.3? 41.65 43. 18 44 45.78 46.70 4:3. ~'-' 4:2.20 43.52 44 · ,_1 '43, 72 44.81 45. :37 45.44 45.46 47.41 ARCO ALASKA 1Q-6 KUPARUK ALASKA MEASURED -DEPTH 4713 4860 5006 5153 5444 5590 5?35 5881 6028 $I73 6318 6462 6605 6747 6889 7031 7172 7312 I NC. SF'ERRY-SLIN WELL '.=-;I_IRVEYING C:OMF'ANY ANC:HORAGE ALAS;KA COMPUTATION DATE MARCH 1:3, 1985 F'AGE 7 DATE ;]~F '.=;LIRVEY MARCH 11-, 19:_=:5 INTERPOLATED VALUES FCIR EVEN 10(') FEE-I" i]F :=;UB-SEA DEF'TH , . ,_lCIB NUMBER AK-BFI-50030 I KELLY BLISHING ELEV. = 91.0c~ FT. OPERATOR-,J. .:,AME_. M. DERIS:ON TRUE VERT I CAL DEPTH SUB-SEA TOTAL VERT I E:AL RECTANGULAR COORD I NATES; MD-TVD DEPTH NORTH/SOUTH EAST/WES;T DIFFERENCE VERT I CAL CORRECT I ON 3791.00 2:891.00 3991.00 4091.00 4191.00 4291.00 4391.00 4491.00' 4591.00 4691.00 4771.00 4891.00 4991.00 50~1.00 5191.00 5291.00 5371.00 5491.00 5591.00 · 2:70,["~,. 0 a, 409.94 S 2348.84 E 9'22.22 3800.00 426.51 S 2456.21 E ?69.88 3900 00 441 '~(' S '-'~ . ...... ~ =~E. 1 67 E 1015.97 4000 00 * =R ':' . ~._,._. 41 ~, 2667.44 . E 1062.21_ 41c~0 O0 465 '~¢ '~ . ,:, =, c, 2772. '="~ E 11 ¢~7.87 4200.00 474.02 S 2878.17 E 1153.36 4300.00 482.74 S 2983.83 E 1199.09 4400 00 4~1.48'~ ~ 308~.24 E 1244.66 4500_ .00 500_ .. 15 S 31'-~._, =. 11E 1290. 4600.00 508.74 S 3301.86 E 1337.07 4700, 00 5~ 36 S 3407.04' E 1382. E.=. 4800.00 ~i'~'-' 78 S :::~10 o~ E 1427 ~11 ._ ._~.~, ~ - - . . .. _ ~ . _. 5 . 0 .2:6 03 49Cx'~. 00 ._ 46 I S 14. E 1471.66 5000.00 ~ ~,,-.. 15" ~ ~ ._~71 ~, ,A'~. E 1514 .76 = 3815 57 E 1 · _,100.00 569_ . .87 S . = . 5200.00 5'-'' . ._, :7o. 75 ~ o 0.84 c,'-'3916 02 E 1 ~'- '=' ......... o,.,._. 4016.07 E 1640.55 5400.00 600.15 S 4114.82 E 1681.40 5500.00 609.'21 S 4212.64 E 1721.59 49.88 47.66 46.09 46.24 45.67 45.48 45.73 45.57 45.89 46.5'2 45.61 44.83 44.15 43.10 41.82 42.16 41.81 4("). 84 40. 1 ?' ARCO ALASKA~ INC. 1Q-6 KUPARUK ALASKA SPERRY-SUN WELL '.--;URVEYING I2:OMF'ANY ANCHfZIRAGE ALASKA COMF'UTATION DATE MARCH 13~ 1985 F'AGE,_-, DATE OF SL~RVEY MARRH 11 · 1785 ,_lOB NUMBER AI-:.']-BF~-5A03A. i<ELLY BUSHING ELEV. = 91.00 FI-. OF'ERATOR-,_I. SAMEF:~ M. DERI I NTERF'OLATED VALLIES FOR EVEN lC)C) FEET OF :z;UB-:Z;EA DEF']-H , . TOTAL RECTANGULAR COORD I NATEg: MD-TVD NORTH/SOUTH EAF;T/WEST D I FFERENCE TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH VERTICAL CORRECTION ~.600.00 7451 5671.00 = '' ............. 7588 5791.00 5700.00 7724 5891.00 5800.00 7858 59~1.00 5~00.00 ........... 7~2 60~1.00 6000.00 8129 6191.00 6100.00 8268 6291.00 6200.00 8410 63~1,00 6300,00 8552 6491.00 6400.00 8645 6555.61 6464.61 617.~? S 625.47 S 632.52 S 639.38 S 648.53 S' 658.6,3 S 669.75 S 4308.48 E 4402.01E 44~3.21E 4582.45 E 46.71.25 E 476.4.02 E 4860.75 E 682 .91 S ' ' 4.96.0.28 E 7(:)1.69 S 505'?.84 E 714.71 ._.':' .s124._ 39. E 1760.37 1797.51 183.'_::. 03 1867.24 1901.30 1938.08 1977.66 201.9.37 2061.74 2089.39 THE CAL. CULATION PROCEDLIRES USE A LINEAR INTERPOLA'FION BETWEEN ]'HE NEARERT 20 FOOT MD (FROM RADIU:--; OF CURVATLIRE) POINTS :--:7.1 :_:: · -.-, .~, .~, · .-.. 34-. 21 34.06 :'_:: 6.7'.-? 39..:_;7 4171 42.3'7 27.65 ARCO ALASKA~ INC. 1Q-6 KUPARUK ALASKA MEASURED DBPTH SPERRY-SLIN WELL SURVEYING COMF'ANY ANCHORAGE ALASKA COMPUTATION DATE MARCH 13, 1985 INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS ]'RUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER PAISE 9 DATE KIF SLIRVEY MARCH 11, 1785 JOB NLIMBER AK-BO-50030 I KELLY BUSHING ELEV. = 91.00 FT. OPERATOR-J. SAMEC, M, BERISON 7920 6037.32 5946.32 643.49 S 4623.10 E ....... 7~? 60?5.94 6004.94 64~.01S 4675,76 E 8148 6204.75 6113.75 660.06 S 4776.95 E 8314 6322.92 6231.92 673.45 S 48S>2.74 E 8500 6454.07 6363.07 6?4.25 S 5022.93 E 8544 6484.88 6:393.88 700.46 S 5053.72 E 8645 6555.61 6464.61 714.71S 5124.39 E TOP UPPER SAND BASE UPPER SAND TOP LOWER SAND BASE LOWER SAND SURVEY DEPTH PLLIG BACK TD TOTAL DEPTH DRILER ARCO ALASKA. INC. lQ-6 STRAT I GRAF'H I C SUMMARY DERIVED USING DIL DEPTHS AND ~-]PERRY :SUN SURVEY DATA MARKER MEA'.~SLIRED DEF'TH TVD THIC:KNE:--;:--; BKB BKB SUB-SEA VERT I CAL TOP UPPER SAND 7920 .......... BASE UPPER SAND 7??9' TOP LOWER SAND 8148 BASE LOWER SAND 8314 ..................... PLUG 'BACK TD 8544' TOTAL DEPTH DRILLER 8645 6037.32 5?46.32 6095.94 "6004.94 6204.75 6113.75 6:}22.92 6231.92 ~.484.88 63?3,88 6555.61 6464.61 COORDINATES WITH REF. TO WELLHEAD (ORIGIN-1571FNL 1180FEL) SEC 26 T12N"R0'PE 643.49S 4.623.10E 649.01S 4675.76E 660.06S 4776.95E 673.45S 4892.74E 700.46S 5053.72E 714.71S 5124.39E 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. ............ DA'~A' CALCULATION AND INTERPOLATION BY'RADIUS OF'CURVATURE ................... DATE OF' SURVEY MARCH 11, 1785 COMPUTATION DATE MARCH 13 ,, 1'.-~85 ,...lOB NI.,.IMBER AK-BO-50o:~:O 'KELIZ¥-'BL~H'ING ELEV. = 91. O0 FT. ~CRLE :- ~ !NC~ '-3 ~000.00 / KU~ceC.q qBC3 qLqsKR. ~NC. 8645 O. ~0 ,z.. S 3 9. O0 S555. Sl SCALE :- [ !bC~ TO '~E-~T'C.qL 5ECT-'~N IS 5t74. O0 ~LON~. ~Z. 6.08 ~8645 500.:30 / qP, c3 qkqsKq, ' 1 Suggested form to be inserted in each "Active" well folder to check for timely compliance wi_h our regulations. R, WEL~ NAME AND NUMBE~ Reports and Materials to be received by: ,_~_ r~ D~te Required Date Received Remarks Comp let._ ion Report , . S amp 1 e s Core Chips ~.- _~- - Core DescrSptSon .~. ' ,..~ ww-" .... ~v~~ -~, ~ ~ ~ ~ . Registered Survey PI~ . _ ~' ~ . .~.~ - .. Inclination Survoy Directional SUrvgy ~ j. . Drill Stem Test Reports , , Production Test Reports . Digitized Data .. ARCO Alaskal Inc. . . Post Office .Box' J60 T~- ~.~,..~ Anchorage, Alaska 99510 d\J "' ','~ ' Telephone 907 277 5637 ,.. I',1:.., [.11~.[ U . r-~l',,L,(~~..~l...r.~,.~kr.~, .I. , " , ,u.).; lIE I:;:'E; C E; ]; i::' '1" ~q ~'.~ )], I::; E;'T U ARCO Alaska, Inc. Post Office Box 360 " Anc. horage; Alaska 995,10,' · Telephone 907 277 5637 D ¢, T I!i; ' ;':;"" 2 0 .... Et'5 '1" R ~h N,S' H.I T 1" rh [. N 0 · · . 0'5"" t 0 '8 5 ' ' ' I:;:i.J I"./ :If: t 0 ~'- 'J 'J '- 8 5 i:;: t.J 11 :~: t () 3 .... 0,51- 815 I:;: I.I N .II: t 0 3 .... 0 9" .8 5~ ' I:',~t.J N :,": t I:;: Ii.". C Iii: :[' l::' 'f'" r~ C K/',I (:) H'I... E: .f..'."C; [.:. D: ...... .... · :" ,' . , BF'A["' -I)l:;~II...I..INfi .14 ~ i::'.¢.~,'.;,'I"IIiEI:;; B,. C t.!l:;:l:;: .1: E I:~[ ..... I(]I"IN,~"I'O N [i;XXON . . I:; I'1 ff. V I:;: 0 i",l ' .. ~ 0 Ii; 1: L I::' H :1: I... L ]: I::' ,~' (:1:1: L I) &.. t"i NSI( C1..E1"41(*'t BI... I",.:{~THI"t["I_I...'X't BL DATE:: ........................ · . , .. .... · /~laska 0il & u.3s Cons. Oomlnlasloa Anch0rar.ja ARCO Alaska, Inc. I.~ a subsidiary ol AllanllcRIchlieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Harch 13, 1985 Mr. C. V. Chatterton Commi s s i oner ' State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the February monthly reports for the following wells' 17-11 2C-ll 2U-1 17-12 2C-12 2U-2 L2-30 1Q-6 2U-3 L1-9 1Q-7 2U-4 2C-10 1Q-8 2W-1 2W-2 2W-3 2W-4 If you have any Sincerely, ~'.~Gruber(~J~'~ Associate Engineer JG/tw GRU5/L18 Enclosures questions, please call me at 263-4944. RECEIVED 1 1985 Alask8 Oil & Gas Cons. Oommission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA C_.AND GAS CONSERVATION CO,_..~SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellX[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-208 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21224 4. Location of Well atsurface 1571 ' FNL, 1180' FEL, Sec.26, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 91.2' RKB I ADL 25641 ALK 2572 For the Month of February ,19 85 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Q-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2115 hfs, 2/16/85. Drld 12-1/4" hole to 4426', Ran and cmtd 9-5/8" csg. Drld 8-1/2" hole to 8645'TD (02/23/85). Ran ]ogs. Ran & cmtd 7" csg. PBTD = 8544'. Secured well & released rig @ 1200 hfs, 2/25/85. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 103'. Cmtd w/240 sx CS I I. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe (~ ##06'. Cmtd w/1050 sx CS 111 (Top job performed w/100 sx CS I.) 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8625'. Cmtd w/370 sx Class G. & 700 sx CS I. 14. Coring resume and brief description None 5. Logs run and depth where run DIL/GR/SP/Cal f/8645' - 4405'(WLM) FDC/CNL f/4405' - 4800' & 7680' - 8645'(WLM) 16. 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. NOTE~-ReporCn this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/HR1 0 Rev. 7-1-80 Submit in duplicate December 4, 1984 i~~. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Bo~ 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit lQ-6 A}ICO Alaska, Inc. Permit 1~-~oo 84-208 Sur. Loc. 1571' FI~_L, 1180' FEL, Sec. 26, Ti2N, R9E, b]~. Btmhole Loc. 2242~ FSL, 1275' FEL, Sec. 25, T12N, R9E, Dear l~ir. Kewin: Enclosed is the approved application for pe~it to drill the above referenced well. If cor'~n~ is conducted, a one cubic inch chip from each foot of recovered core is requi~ed. 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 avaiiable~ a tape containing the digitized log information shall be ~ubmitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~lany 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 pro~mlgated thereunder (Title 5, Alaska Ad~ninistrative 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 pro~lgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conserwation. To aid us in scheduling =' ~ zmeld work, please notify this office 24 hours prior to commencing installation of the blowout prevention ~'.~r. Jeffrey Ii. ~..ewzn Kuparuk River Unit lQ-6 December 4, i984 equipment sc, that a ~epre,~e~-.:~lYe of the Con~niss~on may be present to witness testing of the equipment before the surface casing shoe is drilled, l-~ere a diverter system is required, please also notify this office 24 hours prior to co~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. Very truly yours, ?" ./x' "' . '~ . ?, ,' , '}'/', 1.. ' -~ " · llarry W. Kugle~ Commissioner of Alaska Oil and Gas Conservation Commission BY ORL-~R OF ~h~ C~I-a-~_~SIOr.~ lc cC: Department of F~sh & Game, tiab~~ Section w/o encI Department of Environmental Conses~vation w/o encl. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo. J0360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 2, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 1Q-6 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk !Q-6, 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 January 6, 1985. any questions, please call me at 263-4970. S i/~e)re 1 y, ~~n~~ JBK/JG/tw GRU2/L60 Attachments If you have RECEIVED NOV 0 8 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska. Inc. is ~ Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION Cu--MMISSION PERMIT TO DRILL 20 AAC 25.005 SINGLE ZONE ~ ¢:! O ~L '?~ ~, . MULTIPLE ZONE I--I '~,j,? ~f~ ~,,~ ,~-~ la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 995'10 4. Location of well at surface 1571' FNL, 1180' FEL, Sec.26, T12N, R9E, UM At top of proposed producing interval 2181' FNL, 1748' FEL, Sec.25, T12N, RgE, UN At total depth 2242' FNL, 1275' FEL, Sec.25, T12N, RgE, UM 5. Elevation in feet-(indicate KB, DF etc.) 6. Lease designation and serial no. RKB 91.2', PAD 54.2' ADL 25641 ALK 2572 9. Unit or lease name Kuparuk River Unit 10. Well number 10-6 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 30 rni. NW of Deadhorse miles 16. Proposed depth (MD & TVD) 8624' MD, 6463' TV• fe~t 14. Distance to nearest property or lease line 1275 feet 17. Number of acres in lease 2560 Amount $500,000 15. Distance to nearest drilling or completed 10-7 well 60~ L~ surface feet I18. Approximate spud date I 01106/85 I 19. If deviated (see 20 AAC 25.050) I KICK OFF POINT 700 feet. MAXIMUM HOLE ANGLE 47 o I 20. Anticipated pressures 2837 psig@ (see 20 AAC 25.035 (c) (2) :~257 psig@ ROOF Surface RR26 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) ~ 16" 62.5# H-40 Weld 80' 36' I 36' 116' I 116' ± 200 cf 12-1/4"1 9-5/8" 36.0# J-55 BTC 4370' 36' I 1 I 36' 4406' i 3566' 1050 sx Arcticset Ill & HF-ERW ~ I 700 sx Class G 8-1/2" 7" 26.0#I-55 BTC 8589' 35' II 35' 8624' I 6463' 300 sx Class G ~~HF-ERW I I 22. Describe proposed program: ARCO Alaska, Inc., proposes ~o drill a Kuparuk River Field developmen~ well ~o approximately 862#~ND (6463' TVD). Selected intervals will be logged, A 20", 2000 psi annular diver~er will be installed on ~he 16" conductor while drilling ~he surface hole. The 13-5/8", 5000 psi, RSRRA BOPE s~ack will be installed on ~he 9-5/8" surface pipe. It will be ~es~ed upon installation and weekly ~hereaf~er. Tes~ pressure will be 3000 psig (1800 psi for annular). Expeceed maximum surface pressure is 2837 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated wi~h an unexpanded gas bubble a~ surface, including ~empera~ure effeces. Casing will be ~es~ed ~o 2000 psi prior ~o releasing ~he drilling rig. Non-freezing fluids will be lef~ in uncemen~ed annuli ~hrough ~he permafros~ interval. 1Q-6 will be 60' away from 1Q-7 a~ ~he surface. There are no closer wellbores anywhere downhole. Reserve pi~ fluids will be disposed of by pumping ~hem down ~he 7" x 9-5/8" annulus of ~his well. The 7" x 9-5/8" annulus will be lef~ wi~h a non-freezing fluid during any (see a~ached shee~) 23. I hereby ce/r,~ that the foregoing is true and correct to the best of my knowledge // SIGNED ( o TITLE Area Drilling Engineer The space b~o~v fd¢ ~/~'~sion ;~e CONDITIONS OF APPROVAL DATE ~./~ Samples required ?lYES eNO Permit number Mud log required Directional Survey required APl number DYES ,~NO , /~YES I--iNO 50-- ~ 'U'~ - O~- / Approval date 12/04/84 i SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY Form 10401 GRU2/PD18 Rev. 7-1-80 ,COMMISSIONER DATE by order of the Commission December 4, 1984 Submit in triplicate Permit to Drill 7Q-6 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2',, 9.2#/ft~ J-SS, 8rd, tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job After the workover rig has moved off location, this well will be fracture stimulated. ' RECEIVED Nov o 8 !~g~ Oil & ~as Cons. Cornmlss]o~ ---4-- -ARCO iALASKA,--I. NC.---~ ........ -.~ ........ ! ...... m L'_--]:i~-]':;.;_P/d3 ~.i:0:. WELL'-.NO :-: ': PROROSED'._;'~ :5i_--_'%5_i :--~: .~L_ ~.'~_'?-' ;' ~ - ~ KUPARUK--F,~ ELD ;4 '-NIDftTH---SUOPE-;-FALAS~A .... q-- -L,/"! _ - .... ; - .... :-- 'f .......... J ! ' 'J '-~ ! i : i : ' ' .... ( ......... i ......... (-- -i .......... I ............ , ( . . ' ';':x_- ' q -~-~'-"-', ' .,_ _ _ ............. I ''- .i ' I ! --' . I ' j . -'-{ ....i nnn' ',UtLD'.~S~ ..... j ..... * ...... : ..... ~ ~ * -- : ' ..... j ...... :.: 7_7..- ~ .... ' ......... ~ ........ PF__R_ J.O0, Ft. .... ~ ........;_ ....... ..... ( ....... ' · .-'~- -2_7 ........ ,t ........ ~ ...... ~ ....... 4 ...... ' , . - ~ ~ .............. ]--].':'% - .,I.51 h..UL;_ ,! .l VL)=.~U~I¢. jt 11D .= Z, P__ b _4 _ L,t~I"---bgJ~ ....... ' ..... .-_.------]]--:_'%LLi_¥Z_TDP;'U~NIZ]SNDS;L:;.TYD',=_2296~ Tldl)=.255'7 ] OEP=81 8']'; L .-.::-_-:-J. _=--* ..... . t, ..... ....... . :-:_ _-. : :: ;,, -_ -. :-: :_' __ ~_ '_~_- ~.,_ ~ ': :_: -~:._ - -.v,,. :: :7 :. '!--_%.:_-: :_:::_: 1: :-:7: ' ':--' _-i::_-;_.._-:i : ':~. '; ' ....... i .............--4 -'%.- 4--1! .............. L. .............. t. ; ....... I .... : . . . .L ........... i .... i .... .!'-~. _; ........ . ,.., ._..-_:....~'...,. .... , ._. ; . ~ : : : ~. -~.:,~.-- ,~ - - - I ...... ; ...... ~--J J-"-"% . .4 ........... ...... !--~__.., .... ,--! .......... t ......~ ........ f ....... ~- -'~'-h' -K-lf2-- :T-~D'=~366 -TfID:'-411 5; DEP=) 950 -i - -! .... -- f--,---,---' ? .... ~ .......... 1 ....... ---t ....... , ........ ~ ................ .... ~_..~-_._ ~ ......... ~ ....... ~ ....... .~ .......i .......-4 ___%_ ~ .... i ,,-- , / i ! · ! %. ~' j - - - ~ ..... " ........ / ..... ~ ........ i ....... ! ........ ~ .... ~?- ....... '~ ......... ~ ....... '~ ....... ~ - - ; - - ," : -- ,~- · . : -..i ......... .~ ..... ~. .... ~ . : i ~ ' ' i ~ . -- - ~ ~ ~ ~- L.--~',,~' ~'...,'i.._ ]-',,~'~VL~ i ~ ' ' ' i ..... :' ' ; ' 'T ' ' · ........................... ' ' ' ~ .... -; ....... ~ ........ - t ..... -- I .............. -' ............. ~ ................. ~ ........... , - - J ...... : - , , 1 , -f , I , ~ '- 'N. - ~ ii'i ' · ½ ...... ~ ....... I ...... ~ ......... ~, ........ ~ ....... .~ ...... * ......... - ~- ..;-,,,,,, I .... : .... !. . ~ -..~ ....... ~ ---~.-. .N. .i .... _~ ,_ --~L~UU ~ - : · ~ ~ i ! , .~, · ; ... i ! .... i ...... ~ ....... -J ..... K'~5 .... TVD=5266 'Tt1D--6851' DER=;3961'!'' %t~: ' ' .... ~ ............ ? .................. ~ ........ 1 ...... .,. - - - ' .......i ......... ~ .......... ..... ~ .......... , ..... :'1 ........... ,- ........ ~. .... -4. 1 ..... 4 ............ . ~ ' . . ~ ._ , ' / ' ' - 'I ' ' .... ; 'Boon_ TOP; UP,_P~.~~D=_.7_gJSj~LD~z.Z_5] '% t- ' -- i ---~. ......... .,TARGE~T CNTR. TVD=6154-Tt1D=;8174-DEP=4g01 - .... ~ ............ ,: ........... TOP LOI,/R SNDS TYD=6205 T'IdD=8248 DEP=]4955'_ ;...~'_ ....._, ........ .~ ,. , - ....... BASE-KUP-SNDS .... FVD=6326-TfflD=8424 DEP=5083-: ] -, - ' , - .... j ........ ; ........... ,._ ;_TD.-XEDDGTNG; PT)'] TVD'~-4'6-SZ-Tt~'~.'862-g. DET~.=-b-228 i --- : - : ...... i ......... ] ............ ~ .................... ~ ! ................. ! ......... I- ....... ] ..... I .... ': ' ' ' ? ' -- : ....... ,.,.,o ...... o ......... ..... ,. ...... ,. .... ,. .... , ..... ..... :. .... :.-. ... r,,, VED - ......... 1 ....... ~ .......-~ ................. t ................. T- ...... i ..... · : .... ! .... I~ ~ ....~ ..... -'~ ...... '::x -----:i ......... .j ......... :----~::4~--:-- ......... ! ....., , - ~ .... ; I .... i ' 2OO · . ]1500 .................... I ~00.-" ........... l 1 ZOO ............... 1 80.0... ,LAS FIlL ~S~.~,N ..~H ~'OTE, WEL~ .. 5-6-7-8 H SLOPE EXT OPOSEO ALAIKA '-ND. BOND THIS VIEWINO W NDOW 3089 l I 1741..1 ....... 1623 l 17'78 i Surface Diverter 5~vstem 16"-2000 psi Tank¢o st. artin~ hea~. ~ankmo ~u~ck connect asS)'. 1G" X 20" 2000 psi douDle stuccoes) a~apter. 20" 2000 psi Qrillin~ 5poo~ w/IO" ~i~e outlets. lO" b~ll v~lves~ hyOr~ulic~liy actua~eU, ~/lO" line.. to reserve* ~it. V~lves tm open ~uto~tica]~y umon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. ~aintenance & OPeration 1. Upon in~tial installation o')use annular preventer verify Ghat ball valves have oDeneo properly, 2. Close annular preventer an¢ b'~o~ air through Civerter lines every 12 hours. Close annular preventer in :ne event that get or fluid ~l~ to ~urf~ce is Oetecte~. ~f necessary, ~nu~lly overrioe and c~ose ball va~ve to upwin~ diverter line. Do not shut in ~ll,, unOer, an~ circumstances. Conductor RECEIVED Alaska Oil & Gas Cons. Anchorso, e T- L PIPH ~b~ !3-5/8' 5000 PSi RS~A BOP STACK ~. 13-5/8' - 5000 ~S5 z 13-S/E' - 5000 ~si ~riii~nc spool 5. !3-5/~' - SO00 ~si p~e rams ~ines 7. !3-5/8' - 5000 psi' :~me ran~ 9. !3-5/~' - 5000 ~S~ annular BL I~'D ~ !. C~E~X ~ND FiLL ACCUMU~TO~ LEVEL W'?T~ HYD~ULIC 2. ~SURE T~A~ ~CCU~U~ PRESSURE ,c 3GO~ ~' ~'~ ~n~, PS] DOWNS7~ OF TME REGULATOr. ~D ZECO~ THE TIME AND ~i UN?S ARE CLOS~ W'i~ C~RGiNG P~ OFF. :. ~EC~XD ON N~C ~EPO~7. THE ACCEPTANCE LDWE~ ~.;r !5 ~5 SECONDS CLOSING T/~E '~-E/8' ~OP ~ACK ..-E-_SC ! r-~, SOP STACK AND .~dq!FOLD w':Ti~ ~RC'TiC ~-r~r: -. . . , 2. C~ECK T~AT ALL HOL~ DOw~ SC~S AEE FSLL~ ;,~CT- ~- .REDeeM!NE C'?TH T~AT TEST ~' UG .'~" M i NL:T~. 5 ]N'C~ASi '~rc~'Rc TO 'BOO =c~ ~ ~'o'r ~5R ~N ...... TOP .~ OF W:TW ~'~ PSi UPSTi, Ek~, nr YAL','[ ANC, ZERO ~' .~ ~, · . ~. OFE~ TCP S~ OF PiPE ~ ~ND CLOSE ~0~0~. [~ OF PIPE 10. INCE~E PRESSURE TO 3OOD ~5' AND MDLC FOR MINUTE5 BLE~ TO ZE~O PSi. 11. OPEN BO~ S~ OF PIPE ~.S. BACK OFF RUNNING jOiNT AND PULL O;T OF HOLE r,~s )LIND R~~ T~S7 TO ~OOO PSi FOR iD ~.iNUT[S. BLE[~ TC ZE~O PSi. ~2. OPEN BLIND ~J ~g RECOVE~ TEST PLUG. ~KE SURE ~NiFOLD AND L]N~S ARE tULL OF ARCT'C C,:ESEL AND ALL VALVES ARE S~ iN DE]LL'NG POS?:0N. TEST ~7ANDPIPE VkLvr~ TC ~OO~ TES~ K~LL* ~ AND iNSIDE BO~ TO SDO~ PS; !5.RECORD T~S7 iNFORMaTiON ON ~L0UOb~ PR~VENTE~ FO~ S~GN AND S[ND T~ D~ .... Nu 1~.PE;FO~ C~PL~ BO=E TEST ONCE ~ ~EEK ''" T~ON~LY OPE~TE )OPE DAiLT. Oil & Gas Cons. Anchorage RECEIVED CHECK LIST FOR NEW WELL PERMITS Company /"~,"~,,0 Lease & Well No. ]('i. ~...~,,i' .~(¢ ITEM APPROVE DATE <1) Fee (2) Loc (2 thru 8) 3. 4. 5. 6. 7. 8. ,/ / . (8);~ ' "':-. ;,,! '" 9. (3) Admin .,' - (9 thru 12) 10. (10 and 12)"' 12. ( 4 ) C as g ~Jz~,/~ /f~/(,f' .4',! (13 thru '~1) ' (5) BOPE ff.7,~: "o'/ig (22 thru' 26) ' 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO REMARKS Is the permit fee attached .......................................... (~_~ .. Is well to be located in a defined pool leeeeeeleeeetlleee~eeeeeeelee(~,,,,.j..,~ Is well located proper distance from property line .................. Is well located proper distance from other wells ....................... ..! Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. ~.~7~-- Can permit be approved before ten-day wait .......................... ['? ...... Does operator have a bond in force .................................. .~,~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ....................................... :.':.'-,.~. ....... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all 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 ....................................... ff~f-~ Are necessary diagrams of diverter and BOP equipment attached ....... ~/~ Does BOPE have sufficient pressure rating - Test to ..~ /?]~-~ psig .. 7~/~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ff Alb T' J ,V PlV,f TTE, O ~-~ 0 Geology: ~Engineering: JA~ ,.,??!,? "l .......... MT::'/,.,. .... ' ' .... rev: ~01~1~4 6.CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE