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183-068
Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, June 28, 2021 10:53 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: KRU 1Y-07 (PTD 183-068) Report of failed MITIA Attachments: 1 Y-07 90 day TIO trend 6.28.21.pdf, 1 Y-07.pdf Chris, KRU 1Y-07 (PTD 183-068) Failed a diagnostic MITIA (pre -state witnessed) on 06/25/21. The well has been shut in since 05/26/2018 due to needing a well line repair. The plan is for the well to remain shut in and begin diagnostics to determine the failure mechanism of the failed MITIA. The proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 11,2017 TO: Jim Rp Supervisor +` WI (12e t,/ P.I.P ' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1Y-07 FROM: Adam Earl KUPARUK RIV UNIT 1Y-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry E2_ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-07 API Well Number 50-029-20950-00-00 Inspector Name: Adam Earl Permit Number: 183-068-0 Inspection Date: 7/7/2017 -/ Insp Num: mitAGE170708061906 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-07 ;Type Inj W' TVD 5864 Tubing 2475 " 2475 ' 2490 ' 2500 " 1 PTD 1830680 'Type Test SP1jTest psi 1500 IA 165 1900 1820 1810 - BBL Pumped: 1_6 BBL Returned: L5 ' OA 250 250 ' 250 ' 250 Interval 4YRTST P/F P Notes: MIT-IA SGAHNE) SEP 2 5 2017, Tuesday,July 11,2017 Page I of 1 0 S C t4 0 v p) to u ro (�ON�Z O Q O1 L \ i Q • W R `^ o • Y O F'7. p) C - c `- c L95 O 2 Y° ° v C. u ,, v E o W Q u p C -0 M a m O J U.' 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W N O1 no N w i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 16,2015 TO: Jim Regg P.I.Supervisor �Qt c( C1.5 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-07 FROM: Chuck Scheve KUPARUK RIV UNIT 1Y-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IY-07 API Well Number 50-029-20950-00-00 Inspector Name: Chuck Scheve Permit Number: 183-068-0 Inspection Date: 9/12/2015 Insp Num: mitCS150913072443 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IY-°7 - TTypeInj W "TVD 5864 - Tubing 2085 2079 2078 - 2096 PTD 1830680 - Type Test SPT Test psi 1500 - IA 500 2910 - 2860 - 2840 Interval INITAL P/F P V OA 100 - 100 - 100 - � 100 --------_.._._..--------- Notes: Initial test post rig workover - %%OM Wednesday,September 16,2015 Page 1 of 1 • 1110 0-G1C 2(203 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 13, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 t J01�S Anchorage, Alaska 99501 END R RE: Radial Cutting Torch, Radial Cement Bond Log, Multi Finger Caliper: 1Y-07 Run Date: 07/18/2015 and 07/20/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-07 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-20950-00 -� 0 0Gd . Radial Cement Bond Log (Field Print) 1 Color Log 50-029-20950-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:d ✓el� t_ STATE OF ALASKA AUG 2 7 2015 AL*CA OIL AND GAS CONSERVATION COIVWsION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon r Rug Perforations l Fracture Stimulate fl Pull Tubing p Operations Shutdown r Performed: Suspend r Perforate Other Stimulate 1-1/01"---Alter Casing 17 Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r Other:Repair subsidence damage .17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development `"""" Exploratory r 183-068 3.Address: 6.API Number: Stratigraphic fl Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-20950-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25646 KRU 1Y-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8210 feet Plugs(measured) none true vertical 6674 feet Junk(measured) none Effective Depth measured 8099 feet Packer(measured) 6999,7300 true vertical 6575 feet (true vertical) 5864, 6056 Casing Length Size MD TVD Burst Collapse Conductor 48' 16" 78' 78' -- Surface 2219' 9.625" 2249' 2206 Production 8150' 7" 8180' 6651 SCANNED JAN 1 1 2016 Perforation depth: Measured depth: 7091-7218, 7242-7262, 7395-7402, 7415-7456, 7478-7496 True Vertical Depth: 5926-6006,6021-6033,6113-6117,6125-6149,6163-6174 Tubing(size,grade,MD,and TVD) 3.5, L-80,7368 MD, 6097 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL RETRIEV. PACKER @ 6945 MD and 5827 TVD PACKER-BAKER FHL RETRIEV. PACKER @ 7333 MD and 6076 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this workover 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(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: i. Daily Report of Well Operations Exploratory Development fl Service r Stratigraphic fl Copies of Logs and Surveys Run fl 16.Well Status after work: Oil Gas fl WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-333 Contact Jonathan Cobert .265-1013 Email Jonathan.Coberly(a,conocophillips.com Printed Name )onathan Cober Title Sr. Wells Engineer Signature Phone:265-1013 Date $,Z G-/r V'TG 9/h i J 1.5 ,fr y C'- RODMS �� Form 10-404 Revised 5/2015 -N "�►g 1 7 101 Submit Original Only KUP INJ • 1Y-07 ConocoPhillips w Well Attributes Max Angle&MD TD A 1uka,Inc P W50e02920llbore APIIU95000WI FieldKUPARUhameK RIVER UNIT Wellbore Status net(°) MD(ftKB) Act Btm(ftKB) �. INJ 53.93 7,400.00 8,210.0 � ••• Comment 112S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1Y-07,8/18/2015 3-46.53 PM SSSV:LOCKED OUT Last WO: 7/11/2015 35.01 5/15/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 7,414.0 11/27/2014 Rev Reason:WORKOVER,PULL PLUG,GLV smsmith 8/17/2015 5,;+1„ CIO *-*.:- ..g. , .:-'.'.i i 2 Casing Strings HANGER;29.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 78.0 78.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ;L SURFACE 9 5/8 8.835 29.5 2,249.4 2,206240.00 J-55 BTC F i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread TIE-BACK 7 6.267 28.2 1,716.5 1,713.4 26.00 L-80 TC-II ° WWa.•„ ,a„"." Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 30.1 8,179.5 6,651.3 26.00 K-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Tap Connection TUBING-WO 2015 31/2 2.992 29.5 7,367.7 6,096.6 9.30 L-80 EUE8rd Completion Details -AAA.CONDUCTOR;30.0-78.0ASKAA ''.a.A.W Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(°) Item Des Cent (in) 29.5 29.5 0.00 HANGER FMC GEN IV TUBING HANGER 2.992 i '; li ). 6,915.5 5,805.5 44.98 LOCATOR LOCATOR SUB 2.980 6,915.8 5,805.7 44.99 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.980 `. 6,922.3 5,810.3 45.12 PBR BAKER 80-40 PBR 4.000 TIE-BACK;28.2-1,716.5 '.3 6,945.4 5,826.6 45.28 PACKER BAKER FHL RETRIEVABLE PACKER 2.960 7,084.9 5,921.6 49.08 BLAST JTS Blast Joint 3 1/2"EUE-Mod 2.992 G 7,283.1 6,046.0 52.79 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813"BX PROFILE 2.810 (RUN CLOSED) 7,333.1 6,076.0 53.34 PACKER --- BAKER FHL RETRIEVABLE PACKER 2.960 SURFACE;29.5-2,249A-A ,. _ 7,354.8 6,088.9 53.53 NIPPLE CAMCO DS NIPPLE 2.750 - 7,366.3 6,095.8 53.63 WLEG WIRELINE ENTRY GUIDE 2.992 GAS LIFT;6,858.6 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,091.0 7,218.0 5,925.6 6,006.2 C-3,C-2,C-1, 6/8/1983 12.0 IPERF 5"Geo-Vann;120 deg. UNIT B,1Y- Ph LOCATOR;6,915.5 07 SEAL ASSY;6,915.6 7,242.0 7,262.0 6,021.0 6,033.2 UNIT B,1Y- '6/8/1983 12.0 IPERF 5"Geo-Vann;120 deg. PBR;6,922.3 07 Ph PACKER;6,945.4 7,395.0 7,402.0 6,112.7 6,116.9 A-5,1Y-07 6/8/1983 12.0 (PERF 55"Geo-Vann;120 deg. :i 7,415.0 7,456.0 6,124.6 6,149.2 A-4,1Y-07 6/8/1983 12.0 IPERF 5"Geo-Vann;120 deg. 11 Ph 7,478.0 7,496.0 6,162.6 6,173.7 A-3,1Y-07 6/8/1983 12.0 IPERF 5"Geo-Vann;120 deg. Ph GAS LIFT',6,9987 Mandrel Inserts St I at] on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(i n) Sew Type Type (in) (psi) Run Date Com GAS LIFT;7,059.6 1 6,858.6 5,764.6 CAMCO MMG 5.968 GAS LIFT DMY RK 0.000 0.0 8/16/2015 2 6,998.7 5,863.6 CAMCO MMG 5.968 GAS LIFT DMY RK 0.000 0.0 8/13/2015 4 3 7,059.6 5,904.9 CAMCO MMG 5.968 GAS LIFT DMY RK 0.000 0.0 8/13/2015 Notes:General&Safety (PERF;7,091.0-7,218.0- End Date Annotation BLAST JTS;7,084.9 6/13/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 - 12/15/2010 NOTE:RECOVERED PIECES OF SEVERELY ERODED CV@7039RKB IPERF;7,242.0-7,262.0 - -- 10/31/2013 NOTE:RECOVERED SEVERELY ERODED CV@7039RKB ill II SLEEVE;7,283.1 1 i PACKER;7,333.1 4110 NIPPLE;7,354.8 WLEG;7,366.3 IPERF;7,395.0-7,402.0- IPERF;7,415.0-7,456.0 IPERF;7,478.0-7,496.0 PRODUCTION;1,714.0-8,179.5 r 1Y-07 WELL WORK SUMMARY PRE-RIG WELL WORK• DATE SUMMARY 12/9/2014 PULLED 1" DUMMY VLV FROM STATION #2 @ 7030' SLM, READY FOR E-LINE, JOB COMPLETE 12/20/2014 SET INTERWELL HEX PLUG WITH MID ELEMENT AT 7033'. SET PLUG AT A CCL STOP DEPTH OF 7014.4'WITH A 18.6' OFFSET FROM CCL TO MID ELEMENT. **LEFT TOOL STRING IN HOLE. TOOL STRING LENGTH = 37.74', WEIGHT= 306 LBS, MAX OD = 2"AT WHEELS, 1.375" FISHING NECK LOOKING UP** 12/22/2014 RECOVERED E-LINE TOOLSTRING AND INTERWELL RUNNING TOOL @ 6972' SLM (RUNNING TOOL INDICATES HEX PLUG IS SET) . LRS TO TEST HEX PLUG. 1/9/2015 PERFORM LEAK DETECT WHILE PUMPING DOWN TBG, FIND HEX PLUG @ 7033' RKB TO BE LEAKING, ATTEMPT TO PULL PLUG, SWIVEL OFF @ OIL JARS WHILE ATTATCHED TO PLUG, READY FOR S/L **SLB TOOLS IN HOLE= 196", HEX= 70"** 1/10/2015 FISHED DIGI TOOL STRING & HEX PLUG @ 7002' SLM; BRUSHED n' FLUSH TBG FROM 7100' SLM TO 7000' SLM. JOB COMPLETE. 4/14/2015 (PRE-RWO): FT LDS/GN'S: T-PASSED; IC-6,9 & 12 O'CLOCK POSITIONS PASSED, ALL OTHERS FAILED. MITIA-PASSED. T POT-PASSED. T PPPOT-FAILED. IC POT-PASSED. IC PPPOT-FAILED. 4/15/2015 (PRE-RWO): SCLD (IN PROGRESS). 4/16/2015 (PRE-RWO): SCLD-IN PROGRESS. 4/21/2015 (PRE-RWO) : SCLD PASSED. 4/28/2015 SET INTERWELL 180-350 HEX PLUG AT 7033'. LOG CORRELATED TO TUBING DETAIL RECORD DATED 09 JAN 1988 AT PACKER. PERFORM MITT AFTER SETTING. PRE T/I/O-400/670/700 START T/I/O - 1010/670/700 15 MIN T/I/O-990/670/700 30 MIN T/I/O- 925/670/700 FAIL START T/I/O- 1000/670/700 15 MIN T/I/O - 960/670/700 30 MIN T/I/O - 940/670/700 PASS JOB COMPLETE 5/2/2015 (PRE-RWO) : MIT-T (FAILED)TO 1000 PSI, DDT-T (FAILED). 5/13/2015 RAN LDL TO TOP OF HEX PLUG @ 7033' RKB. TBG PRESSURED UP W/ .3 BBLS. PERFORMED MIT-T TO 2500 PSI.PASSED. PERFORMED DRAWDOWN TEST TO 100 PSI PASSED. SET CATCHER @ 6989' SLM. ATTEMPTED PULLING 1.5" DGLV FROM ST#6939' RKB,UNSUCCESSFUL. 5/14/2015 PULLED 1.5" RK-DGLV FROM 6939' RKB. >>»POCKET LEFT OPEN «« PULLED 3.5" CATCHER FROM 6989' SLM. RAN 2.67" CENT,8'X STEM,2.74" CENT (oal-111").TAGGED HEX PLUG @ 6989' SLM. 5/15/2015 (MISC): BLED T& IA FOR BUR. 5/16/2015 (MISC): BLED T& IA FOR BUR. 5/23/2015 PRE RWO T& IA- DDT (FAILED) 5/25/2015 LRS LOADED TBG W/50BBLS INHIBITED SEA WATER, 20 BBLS DIESEL FIRED STRING SHOT OVER INTERVAL FROM 6,953' RKB TO 6,963' RKB DEPLOYED CATCHER SUB TO 7,033' RKB CUT TBG W/CHEM CUTTER @ 6,961' RKB 5/31/2015 (PRE-RWO) : ATTEMPTED TO FREE UP SEIZED IC LDS'S & GN'S (FAILED). • • Conoc©Phillips Time Log & Summary WelIview Web Reporting Report Well Name: 1Y-07 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 7/16/2015 3:00:00 PM Rig Release: 8/13/2015 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth`'Phase Code Subcode T Comment 37/11/2015 24hrSummary RDMO 2T-07. Prep Rig complexes and sub to move. Move Pits, Satellite Camp and Shop to 2A pad. Move SUb to between 2T and 2A pad. 06:00 18:00 12.00 0 0 MIRU MOVE MOB P Prep Sub, Pits, Shop and Satellite Camp to move. Prep 2T access road and other culverts for rig move with rig mats. 18:00 21:00 3.00 0 0 MIRU MOVE MOB P Move Pits, Shop and Satellite Camp to 2A pad and move Sub base—1/2 way to 2A pad. 21:00 00:00 3.00 0 0 MIRU MOVE MOB T 2T access road collapsed beneath rig during move.Work to get rig unstuck. 37/12/2015 Move Satellite Camp and Shop from 2A pad to 1Y pad. Continue to try and move sub from 2T access road. Repair Rig Movement Electrical Connection. 00:00 01:30 1.50 0 0 MIRU MOVE MOB T 2T access road collapsed beneath rig during move.Work to get rig unstuck. 01:30 03:00 1.50 0 0 MIRU MOVE MOB P Get Rig Sub unstuck and move'-50 yards and road collapses again. 03:00 12:00 9.00 0 0 MIRU MOVE MOB T 2T access road collapsed beneath rig during move.Work to get rig unstuck. Mobilize rig mats to front of rig to assist in preventing road collapse. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Move Satellite Camp and Shop from 2A to 1Y pad. SIMOPS: Continue to work on getting rig sub unstuck. Rig Moving system hydraulic pump motor fails due to situation of being stuck. 18:00 00:00 6.00 0 0 MIRU MOVE MOB T Work on repairing Rig moving system electrical. Get repair parts to rig and repair electrical motor connections for rig movement system. 37/13/2015 Continue to try to move sub from 2T access road with Sows. Try to move sub from 2T access road with Dozers. Get Rig onto Rig mats. Begin rig mat stacking and shuffling rig mats to move Sub to 2A. 00:00 13:00 13.00 0 0 MIRU MOVE MOB T Continue work to get rig unstuck. Attempt to pull rig once mats in front of rig and rig. connected to Sows.2 attempts did not work. Mobilize Peak Dozers and move rig mat from area where Dozers can pull. Pull Rig Sub onto Rig mats using Dozers. Page 1 of 38 11110 Time Logs 1111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 00:00 11.00 0 0 MIRU MOVE MOB P Begin rig mat shuffle to get rig mats behind rig to in front of rig and shuffle rig mats moving rig to 2A pad. 37/14/2015 Continue to move the Sub from 2T access road to 2A pad shuffling rig mats. Move Pits from 2A pad to 2B pad. Move Sub base towards 4 corners shuffling Rig Mats. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Rig mat shuffle moving rig to just short of 2A pad. 06:00 10:00 4.00 0 0 MIRU MOVE MOB P Continue moving rig towards 2A pad. 10:00 20:00 10.00 0 0 MIRU MOVE MOB P Move Rig mats to cover culverts between 4 corners and 2B pad. Layout 250+ Rig mats on 2A access road in preparation for moving sub. 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Move Rig Pits complex from 2A access road to 2B pad. Move Rig sub to end of rig mats and start shuffling mats behind it to back over. 07/15/2015 Continue to move the Sub from 2T access road to 4 corners shuffling rig mats. Move Rig Sub to 2B pad. Stage Rig mats on culverts between 2B and Oliktok Y. Move Pits from 2B to 1Y pad. Move Rig Sub from 2A to Oliktok Y. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Move Sub from 2A access road to 4 corners shuffling rig mats. 06:00 14:00 8.00 0 0 MIRU MOVE MOB P Move Sub from 4 corners to 2B pad. Rig fell through road at entrance to 2B pad. Pull rig out and onto pad and repair road. 14:00 19:00 5.00 0 0 MIRU MOVE MOB P Move rig mats from 2A access road to culvert between 2B and 1Y pad. 19:00 00:00 5.00 0 0 MIRU MOVE MOB P Move pits complex to 1Y pad and stage. Move Rig sub from 2B pad to Oliktok Y. 37/16/2015 Move Rig sub from Oliktok Y to 1Y pad. Spot Rig over well. Rig Up.Accept Rig. Kill Well. Monitor Well. RIG ACCEPTED @ 15:00 00:00 04:00 4.00 0 0 MIRU MOVE MOB P Move Rig form Oliktok Y to 1Y pad. 04:00 07:30 3.50 0 0 MIRU MOVE MOB P Move rig mats to 1Y pad to allow rig to maneuver into position on well on mats. 07:30 11:00 3.50 0 0 MIRU MOVE MOB P Move rig to in front of well. Raise Derrick and pin Derrick. Spot sub over well, centered over wellhead. 11:00 12:30 1.50 0 0 MIRU MOVE MOB P Move pits into place next to sub. 12:30 15:00 2.50 0 0 MIRU MOVE RURD P Berm Up around Sub, Cellar, Fuel tank, pits. Hook up interconnects. RIG ACCEPTED @ 15:00 15:00 17:00 2.00 0 0 MIRU WELCTt RURD P Take on 8.6 ppg seawater into the pits. Raise cattle chute, bridle down. Prepare Rig floor for operations. 17:00 19:30 2.50 0 0 MIRU WELCTt RURD P Prepare Cellar and kill lines. Rig Up hard line, choke house and kill tank. Page 2 of 38 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:00 1.50 0 0 MIRU WELCTL MPSP P Rig Up lubricator and test. pull BPV. Rig DOwn and Lay Down lubricator. Tubing= 150 psi; IA=550 psi; OA= 580 psi. 21:00 21:15 0.25 0 0 MIRU WELCTL SFTY P PJSM for killing well. 21:15 21:45 0.50 0 0 MIRU WELCTL SEQP P Test lines and choke to 3500 psi. Walk lines. all good. 21:45 23:15 1.50 0 0 MIRU WELCTL KLWL P Kill Well. Bled gas cap off tubing. Lined up and killed well pumping down tubing taking returns out IA. 268 bbls pumped, good 8.6 ppg returns to surface @ 255 bbls away. ICP 780 psi. FCP 760 psi. 23:15 00:00 0.75 0 0 MIRU WELCTL OWFF P Monitor well. Well dead. Mobilize FMC to set BPV. 07/17/2015 Set BPV. Nipple Down tree. Nipple Up BOPE. Test BOPE. Pull BPV.Attempt to pull completion, unsuccessful. Mobilize E-Line to cut 3.5"tubing. 00:00 01:00 1.00 0 0 MIRU WHDBO MPSP P Set BPV. 01:00 03:00 2.00 0 0 MIRU WHDBO NUND P Nipple Down Tree. Set Blanking Plug. 03:00 07:45 4.75 0 0 MIRU WHDBO NUND P Nipple Up DSA. Take RKB measurements. Nipple Up BOPE and change out bottom Ram Bodies to 7"Rams. SIMOPS: Bleed down OA. 07:45 09:00 1.25 0 0 MIRU WHDBO RURD P Rig Up test equipment. Rig Up lines and fill with water. 09:00 15:00 6.00 0 0 MIRU WHDBO BOPE P Initial BOPE test with 3.5"and 7" test joints per AOGCC and CPAI. States Right to witness waived by Reps Bob Noble and Matt Herrera. 1) BR, Choke 1,2,3,16 RF kill, Outer test spool, Upper IBOP. pass 2)Choke 4,5,6,HCR kill, Inner test spool, Lower IBOP. Pass. 3)Choke 7,8,9,Man kill, HT 38 dart. pass 4)Super chk, Man choke, flow check &test. pass 5)Choke 10,11, Man Kill. pass 6)Choke 12,13,15. Pass. 7)Annular w/3.5"'TJ, 3.5"'8rd FOSV. choke 14. F/P 8) UPR w/3.5"test TJ, HCR choke. pass 9) LPR w/7"TJ, Floor Valve. pass 10)Annular w/7"TJ, Man choke. Draw down: Observed initial 200 PSI obtained in 18 seconds,with full 2950 PSI obtained in 93 seconds. Observed 5 Nitrogen bottles with an average pressure of 1985 PSI. Page 3 of 38 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 0 0 MIRU WHDBO RURD P Rig Down Test Equipment. Blow down lines and rig down same. Break down test joints. 16:30 17:15 0.75 0 0 MIRU WHDBO MPSP P Pull BPV. 17:15 18:45 1.50 0 0 COMPZ RPCOM PULL P Make up crossovers and landing joint. BOLDS and pull completion. Pull to max of 80%multiple times. Pipe stretch indicates pulling at bottom of string. COntact CPAI engineer. Pull to 85%multiple times, no indication of cut parting or seal pulling. Mobilize E-Line for another cut at 6966'. 18:45 00:00 5.25 0 0 COMPZ RPCOM WAIT T Pre Rig cut by SLB DSL unsuccessful and would not come apart. Mobilize next unit out(3am) with cutter. 07/18/2015 Rig Up E-Line. Cut @ 6968'wlmd. Rig Down E-Line. Pull and Lay Down 3.5" EUE8rd completion. control line broke after 5 joints, ran tubing back to bottom. Rig Up E-Line. String Shot centered @ 1784'wlmd. Cut @ 1784"wlmd. 00:00 04:45 4.75 0 0 COMPZ RPCOM WAIT T Pre Rig cut by SLB DSL unsuccessful and would not come apart. Mobilize next unit out(3am) with cutter. 04:45 10:00 5.25 0 0 COMPZ RPCOM ELNE T Spot HES E-Line Unit. Pick Up and Rig Up lubricator and E-Line equipment. E-Line unit on location @ 04:52 10:00 12:30 2.50 0 6,968 COMPZ RPCOM ELNE T RIH and cut tubing at 6968'elmd. Good indication at surface of successful cut. POOH, indication on cutter of good cut. 12:30 14:00 1.50 6,968 6,968 COMPZ RPCOM ELNE T Rig Down E-Line 14:00 14:30 0.50 6,968 6,968 COMPZ RPCOM RURD P Prep Rig Floor to pull tubing. Check Rig Up of GBR and Camco spooler. 14:30 16:00 1.50 6,968 6,747 COMPZ RPCOM PULL P Terminate control line and lay down Hanger and 5 joints with control line. Control line broken. Pull 2 more joints and observe SS bands and control line not attached. Contact CPAI engineer. Up Wt=96k; Dw Wt =58k. Recovered 5 SS bands. 16:00 16:30 0.50 6,747 6,747 COMPZ RPCOM RURD T Rig Down Camco Spooler unit and move off rig floor. Prep to RIH with tubing. 16:30 18:00 1.50 6,968 6,968 COMPZ RPCOM PUTB T Pick Up previously laid down tubing and RIH to get tubing string back on bottom. lightly tag cut joint and pick up string weight+ 1". Space out with pups and set in slips. 18:00 21:15 3.25 6,968 6,968 COMPZ RPCOM ELNE T Pick Up and Rig Up Lubricators and wireline tools. PT lubricator to 2000 psi. SIMOPS: Mobilize IBP from Weatherford in Deadhorse. Mobilize cutter and string shot from Deadhorse. Page 4 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 22:45 1.50 6,968 6,968 COMPZ RPCOM ELNE T Pick Up and RIH with 5'String Shot. Shoot centered on 1784'elmd middle of first full joint above SSSV. POOH and Lay Down String Shot. 22:45 00:00 1.25 6,968 1,784 COMPZ RPCOM ELNE T Pick Up and RIH with RCT and cut at 1784'elmd middle of first full joint above SSSV. Positive indications at surface of cut. 07/19/2015 Rig Down E-Line. Pull and Lay Down 2 joints of tubing. Rig Up E-Line. Set IBP above cut tubing @ 1776' wlmd in 7"casing.Test IBP to 1000 psi. Rig Down E-Line. Dump sand on IBP. Tag Sand. Pull and Lay Down 3.5"EUE8rd completion. PU BHA#1 (Rope Spear)and RIH. POOH and remove Control Line. PU and RIH BHA#2(Rope Spear without Bumper Sub)x3 recovering Control Line each time. RIH and RIH BHA#3 Rope Spear without Stop Ring)x3 Recovering Control Line each time. 00:00 00:45 0.75 6,968 1,784 COMPZ RPCOM ELNE T POOH and Lay Down Cutter. Positive indication of cutter successfully cutting. 00:45 01:00 0.25 1,784 1,784 COMPZ RPCOM ELNE T Rig E-Line to side. 01:00 01:30 0.50 1,784 1,722 COMPZ RPCOM PULL T Pull 2 joints of tubing and Lay Down to make space for IBP to set in 7" casing above SSSV. Up Wt=46k 01:30 01:45 0.25 1,722 1,722 COMPZ RPCOM ELNE T Rig Up E-Line. 01:45 02:30 0.75 1,722 1,722 COMPZ RPCOM WAIT T Wait on IBP from Weatherford in _Deadhorse. 02:30 07:00 4.50 1,722 1,722 COMPZ RPCOM ELNE T Check E-Line unit and E-Line power connection for IBP tool. Pick Up and RIH with 2-1/8"Weatherford IBP and set at 1766'wlmd in 7"casing. Setting went per design. POOH with setting tool on E-Line. 07:00 07:30 0.50 1,722 1,722 COMPZ RPCOM MPSP T Test IBP to 1000 psi for 10 min. 07:30 08:30 1.00 1,722 1,722 COMPZ RPCOM ELNE T Rig Down E-Line 08:30 11:00 2.50 1,722 1,722 COMPZ RPCOM MPSP T Dump sand on top of IBP with hopper. Let settle and tag. 11:00 14:00 3.00 1,722 0 COMPZ RPCOM PULL T Pull completion out and Lay Down. Large amount of control line tangled around 23rd joint out of hole.. Pictures taken. COntinue to Pull and Lay Down 3.5"completion. 56 joints pulled, cut joint 12.38'. 14:00 14:30 0.50 0 0 COMPZ RPCOM RURD T Rig Down GBR tools and floor equipment from pulling tubing. 14:30 15:00 0.50 0 0 COMPZ RPCOM SVRG P Service Top Drive. 15:00 15:30 0.50 0 COMPZ RPCOM BHAH T Pick Up BHA#1 (Rope Spear). 15:30 17:00 1.50 175 COMPZ RPCOM PULD T RIH Picking Up Drill Pipe from Pipe Shed. Set Down @ 80'. Make Up Top Drive and Push Down singling in hole to 175'. Unable to go further down hole. 17:00 17:45 0.75 175 0 COMPZ RPCOM TRIP T POOH BHA#1 and Fish. Control line completely wrapped around Rope Spear. Pictures taken. Page 5 of 38 . ! Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 19:00 1.25 0 9 COMPZ RPCOM BHAH T Remove Control Line from Spear. Remove Jar from Spear and prepare BHA#2(Rope Spear). 19:00 20:30 1.50 9 9 COMPZ RPCOM FISH T RIH with BHA#2. Make 3 trips. 1st run went to 188'. COntrol Line recovered.2nd run went to 193'. Large amount of control line recovered. Pictures taken. 3rd run stack out at 194'. No control Line recovered. 20:30 21:00 0.50 9 8 COMPZ RPCOM BHAH T Lay Down BHA#2. Pick Up BHA#3 (Rope Spear with no stop ring). 21:00 00:00 3.00 8 COMPZ RPCOM FISH T RIH with BHA#3. Make 3 trips. First trip to 216'. Control line recovered. Second trip to 226'with significant drag last 5'. Control line recovered. Third Trip completely stacked out at 237'. Control line recovered.At times had to use 20k to get down on all three runs. 37/20/2015 Run Rope Spear. Cannot pass 239'. LD BHA#3. PU and TIH BHA#4(DP Muleshoe). Cannot pass 239'. TOOH LD BHA#4. PU and RIH BHA#5(3.5"Tubing Muleshoe). Cannot pass 239'.TOOH and LD BHA#5. Process old 3.5"BTC tubing for RIH. RIH with old 3.5"BTC tubing string. TOOH with old 3.5" BTC tubing string. Rig Up to E-Line. Run CBL. Run Caliper. Run Guage Ring. Run WellTech cutter. Rig Down E-Line. Circulate out arctic Pack. 00:00 01:00 1.00 8 8 COMPZ RPCOM FISH T RIH with BHA#3(4th trip).Work to 239'with 15-20k until stack out. Decision to POOH and check for control line. Hole problems noted starting at 180'-185'and 215'-239' where string could no longer drift. No Control Line recovered. 01:00 01:45 0.75 8 0 COMPZ RPCOM BHAH T Lay Down BHA#3. Contact CPAI engineer. Decision to attempt to drift a 3.5"Drill Pipe Muleshoe around the bend that we previously stacked out on. 01:45 02:00 0.25 0 0 COMPZ RPCOM WWWH T Remove control line and debris from DSA/wellhead area. Recovered SS band.Total recovered is 30 SS bands to this point. 02:00 02:15 0.25 0 8 COMPZ RPCOM BHAH T Pick Up and Make Up BHA#4. 3.5" Drill Pipe Muleshoe. 02:15 02:45 0.50 8 8 COMPZ RPCOM TRIP T TIH with Muleshoe.Will not go past 239'with 20k down. TOOH. 02:45 03:00 0.25 8 24 COMPZ RPCOM BHAH T Lay Down BHA#4. Pick Up and Make Up BHA#5 22'3.5"Tubing Muleshoe. 03:00 03:30 0.50 24 24 COMPZ RPCOM TRIP T TIH with Tubing Muleshoe.Will not go past 240'with 15k down. TOOH. 03:30 03:45 0.25 24 0 COMPZ RPCOM BHAH T Lay Down BHA#5. 03:45 05:30 1.75 0 0 COMPZ RPCOM OTHR T Load used 3.5" BTC tubing into shed. Strap and talley for running back into hole. SIMOPS: Rig Up GBR power tongs. Page 6 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 16:15 10.75 T 0 0 COMPZ,RPCOM PUTB T Pick Up old 3.5"BTC tubing and RIH. 16:15 18:30 2.25 0 0 COMPZ RPCOM TRIP T Trip 3.5" BTC tubing standing back in Derrick. 18:30 19:30 1.00 0 0 COMPZ RPCOM RURD T Rig Down GBR power tongs and running equipment on rig floor. 19:30 19:45 0.25 0 0 PROD1 WELLPF SFTY P PJSM Rigging Up E-Line. 19:45 20:30 0.75 0 0 PROD1 WELLPF ELOG P Rig Up E-Line. 20:30 22:45 2.25 0 0 PROD1 WELLPF ELOG P Drift 4.475"OD x 9"long drift with weight bars above to bottom. Set down on bottom @—1761'. POOH and Lay Down Drift. Observed slight bobbles around 180'-190'wlmd and 225'-240'on way down. No problems coming out. 22:45 00:00 1.25 0 0 PROD1 WELLPF ELOG P Pick Up and RIH with Cement Bond Log tool from 1761'to surface. 37/21/2015 Run Caliper Log. Run WelITec 7"casing cutter. Cutter would not go past 182'. POOH. Lay Down Cutter assembly. Rig Down E-Line and Dutch Riser. Nipple Down BOP. Grow casing&stretch. Total growth 51 inches. NU BOPE. leak test. RIH with 5.5"drift run. Daily fluid loss= 17 BBL's Total loss= 17 BBL's 00:00 02:00 2.00 0 0 PROD1 WELLPF FLOG P Pick Up and RIH with Caliper tool. Log Caliper form 1761'to surface. Contact CPAI Engineer cut depth decided to be 1642'. 02:00 04:00 2.00 0 0 PROD1 CSGRC'ELNE P Pick Up and RIH with WellTech Cutter. Cutter would not pass 182'. Set down and pulled tight 3 times. Decision made to POOH and Lay Down Cutter. 04:00 05:30 1.50 0 0 PROD1 CSGRC'ELNE P Rig Down E-Line. Rig Down Dutch Riser. 05:30 07:00 1.50 0 0 PROD1 CSGRC'NUND P Nipple Down BOPE. 07:00 12:30 5.50 0 PROD1 CSGRC'NUND P PJSM RU PESI Hydra-tight system. Tighted down Tbg spool to casing spool. BOLDS. completed casing growth=25.75 inches 12:30 15:00 2.50 PROD1 CSGRC'CUTP P Spear casing and stretched and hung on slips @ 120 K. Cut 7" casing stump. 51 Inches of total growth. 15:00 22:00 7.00 PROD1 CSGRC'NUND P NU BOPE to Casing spool. 22:00 22:45 0.75 PROD1 CSGRC'BOPE P Attempted to shell test BOPE to 250 psi. unable to get above 75 PSI. @ 3 BPM do to hole in OA. fluid would hold @ annular for hydrostatic test only.2.7 BBLs loss in 10 min flow check. 22:45 23:00 0.25 0 8 PROD1 CSGRC'BHAH P Make up BHA#7: 5.5"string mill assembly for drift run. Page 7 of 38, • Time Logs 1110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 8 850 PROD1 CSGRC'PULD P RIH with BHA#7.Tagged @ 190 ft pushed by with 2K down wt. Pulled thru with 2K over. 07/22/2015 Cut 7"casing at 1714 ft. Speared casing. ND BOPE. Pull E-slips. NU BOPE. Leak test.Worked 7"casing to 340 K didi not pull free. RIH with 5.5"Multi cutter. found casing cut @ 1714.5 ft. 2 ft seperation to upper 7". Made cut at 1180 ft. Speared 7"stump. pulled free at 95K. 1180 ft=31K-. Circulated out artic pack. Pulled spear and casing to rig floor. @ 100 K Daily fluid loss= 136 BBLs Total loss= 153 BBL's 00:00 01:00 1.00 850 1,713 PROD1 CSGRC'PULD P Continue to RIH with BHA#7 01:00 02:45 1.75 1,713 1,713 PROD1 CSGRC'OTHR P Spot 5 more sacks of sand on top of IBP @ 1773 ft. Let settle. Note: Calculated 3.11'per sack of sand. 02:45 03:30 0.75 1,713 8 PROD1 CSGRC'TRIP P POOH with BHA#7. Up Wt=55K 03:30 04:00 0.50 8 6 PROD1 CSGRC'BHAH P Lay down BHA#7. Pick up BHA# 8: Multi string cutter 04:00 05:30 1.50 6 1,708 PROD1 CSGRC'TRIP P RIH with BHA#8.Worked past 190 ft with 3K down, 240 ft with 6-7 K down weight. 1235-1245' 10 K down. 05:30 06:00 0.50 1,708 1,714 PROD1 CSGRC'CPBO P Located casing coupling at 1708 ft Made cut© 1714' RKB. 06:00 06:30 0.50 1,714 1,714 PROD1 CSGRC'OWFF P Flow check 30 min's. 06:30 08:00 1.50 1,714 0 PROD1 CSGRC'TRIP P POOH with BHA#8 08:00 08:15 0.25 0 32 PROD1 CSGRC'FISH P Engaged 7"casing spear W/pack off. in 7"casing stump @ surface. 08:15 09:00 0.75 32 32 PROD1 CSGRC'CIRC P Pumped 42 BBL's deep clean pill followed 26 BBLs. of 120°fresh water @ 3 BPM @ 220 PSI.6 BBLs. to surface during circulation. 09:00 12:30 3.50 32 32 PROD1 CSGRC'OWFF P Monitor well for flow @ surface and cellar. 12:30 13:30 1.00 32 32 PROD1 CSGRC'NUND P ND BOPE stack pull 7"E slips. 13:30 15:00 1.50 32 32 PROD1 CSGRC'NUND P NU BOPE stack and leak test. 15:00 16:30 1.50 32 0 PROD1 CSGRC'FISH P Pick up on casing string.worked from 50 K to 250 K with movement. worked up to 340 K still no movement. Casing does not appear to be cut. @ 1714.0 ft. Released spear. 16:30 18:00 1.50 0 1,706 PROD1 CSGRC'TRIP T RIH with BHA#10 5.5 Multi-cutter. 18:00 18:30 0.50 1,706 1,715 PROD1 CSGRC'CPBO T Open cutter located casing coupling @ 1706'2 ft higher than RKB cut level @ 1708'. Located lower casing stump @ 1714.5 ft. upper casing stump @ 1712 ft. 18:30 19:45 1.25 1,706 1,706 PROD1 CSGRC'WAIT T Discussed with town on plan forward SIM OP's: circulated 290 BBL's of 120°fresh water @ 4BPM @ 190 psi. Page 8 of 38 Time Logs 4111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:15 0.50 1,706 1,165 PROD1 CSGRC'TRIP T POOH to 1213. ft located collar @ 1204.5 ft. located next collar @ 1164. 20:15 21:00 0.75 1,165 1,180 PROD1 CSGRC'CPBO T Dropped cutter back down to 1180 ft. 16 ft from coupling @ 1164. Engaged cutter. FT @ 75 RPM =870 FT/LB's . opened cutter @ 4 BPM @ 870 psi . cutting torque @ 1500 FT/LB. cutter stabilized @ 970 FT/Lb's and 430 psi pump pressure dropped more weight to the knifes torque increased to 1150 Ft/LB's pump pressure increased to 470 psi. Released cutter.checked cut OK. 21:00 21:30 0.50 1,180 0 PROD1 CSGRC'TRIP T POOH with BHA#10 21:30 21:45 0.25 0 16 PROD1 CSGRC'BHAH T Picked up BHA# 11: 5 3/4 ITCO spear assembly with pack off and 6.22 Nom.grapple. 21:45 22:00 0.25 16 42 PROD1 CSGRC'FISH T Engage spear into 7"casing stump @ surface. Up wt free at 95 K dragging @ 67 K. 22:00 23:45 1.75 42 1,180 PROD1 CSGRC'CIRC T Circulated 290 BBIs of 120°fresh water to clean up artic pack. @ 4 BPM @ 50 psi. lost 16K string weight during circulation. Displace well back to sea water. 23:45 00:00 0.25 1,180 1,155 PROD1 CSGRC'PULL T Pulled spear and casing to the rig floor. Dragging @ 100 K 37/23/2015 POOH with 1180 ft of 7"casing.. Make up 8 3/8"Mill gage assemblyRlH tagged @ 179 ft with mill worked down to 192 ft. Added 3.5 mule shoe jt for pilot guide. Made Mutable round with out success. Down sized milling assembly to 6 1/8".Able to work thru 186-192 ft. Dressing up parted area. Fluid Loss Daily=230 BBIs Total Loss=383 BBL's 00:00 02:30 2.50 1,155 0 PROD1 CSGRC'PULL T Continue to pooh with 7"casing. Dragging from 96K to 145K. lost drag with approx 150 ft of casing left to pull. Recovered centralizers. Casing is cork screwed and compressed out of round. 02:30 04:30 2.00 0 0 PROD1 CSGRC'OTHR P Cleared pipe shed of recovered casing.Load milling assembly 04:30 05:00 0.50 PROD1 CSGRC'MPSP P Install 9"wear ring. 05:00 07:00 2.00 0 137 PROD1 CSGRC'BHAH P Plck up BHA#12: 8 3/8 milling assembly to dress up 9 5/8 casing to top of 7"fish @ 1180 ft.do to drag on 7"laid down. 07:00 10:45 3.75 137 191 PROD1 CSGRC'MILL P Taged with mill @ 189 ft. Began milling operations @ 80 RPM 1.2 F/ TQ-3K @ 6 BPM @ 95 psi.. Milled from 189 to 191 ft. Observed formation returns, and pipe rotation eratic in the casing. Suspect separation in the 9 5/8". 10:45 11:15 0.50 191 137 PROD1 CSGRC'BHAH P POOH with BHA#12. Pick up BHA #13 Page 9 of 38 Time Logs 4110 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:45 1.50 137 186 PROD1 CSGRC'MILL P Tagged with 8 3/8 mill @ 186. F/TQ @ 80 RPM's @ 900 Ft/LB's. circulation @ 6 BPM @ 80 PSI. Unable to get mill beyond 186 ft.WI multiple attempts. 12:45 13:00 0.25 186 0 PROD1 CSGRC'BHAH P POOH with BHA 13. 13:00 14:00 1.00 0 0 PROD1 CSGRC'WAIT P Discuss options with town Eng. 14:00 15:30 1.50 0 186 PROD1 CSGRC'TRIP P RIH with BHA# 14: 8 3/8 water melon mill with DP guide jt. . Rotated @ 5 RPM's unable to drop in guide. 15:30 15:45 0.25 186 0 PROD1 CSGRC'TRIP P POOH with BHA#14 15:45 16:30 0.75 0 0 PROD1 CSGRC'WAIT P Make up mule shoe drill pipe jt. 16:30 17:00 0.50 0 158 PROD1 CSGRC'BHAH P Pick up BHA# 15: 8 3/8 water melon mills with mule shoe guide jt 17:00 18:00 1.00 158 204 PROD1 CSGRC'MILL P Able to guide drill pipe into lower 9 5/8 casing. Casing is parted @ 186.0 ft. Tagging with mill at 177 ft F?TQ @ 20 RPMs @ 1000 FT/LB's Tail @ 202 ft. Mill would work down to 179 ft and stall out. Made mutable attempts with out success. 18:00 18:15 0.25 204 62 PROD1 CSGRC'TRIP P POOH with BHA#15. 18:15 18:45 0.50 62 0 PROD1 CSGRC'BHAH P Lay down BHA#15 18:45 20:30 1.75 0 0 PROD1 CSGRC'OTHR P Up load smaller milling assembly and Drill collars 20:30 21:30 1.00 0 147 PROD1 CSGRC'BHAH P Pick up BHA#16:6 1/8 smooth OD string mill,4 3/4 DC's 21:30 00:00 2.50 147 333 PROD1 CSGRC'MILL P RIH with BHA 16:slid mill past 186 ft with 5-6K down weight. Mule to 333 ft mill to 310.0 ft pulled back thru coupling at 186 worked mill thru the damaged area. F/TQ @ 65 RPM's= 600 FT/LB's . Circulating @ 5 BPM @ 125 psi. Milling torque @ 875 to 1280 FT/LB's feathering thru 186 to 188.0 ft slid mill thru damage @ 2-3 K up/down. Pump 5 BBI Hi-Vis sweep. Got back formation. 07/24/2015 Continued to up size milling assemblies. to 6 3/4"working thru 186-189 ft Prep for BOPE testing.will began to flow.swap well to 9.6#brine. Test BOPE 250/3000 psi. Pulled test plug. Daily fluid loss=33 BBL's. Total loss=416.0 00:00 00:15 0.25 333 25 PROD1 CSGRC'TRIP P POOH with BHA#16. 00:15 00:30 0.25 25 24 PROD1 CSGRC'BHAH P Changed out 6 1/8 smooth OD string mill to 6 1/8 rough OD sting mill. 00:30 01:00 0.50 24 0 PROD1 CSGRC'TRIP P RIH with BHA#17: Rough OD 6 1/8 string mill.slid past damage @ 186 ft to 195.Tail @ 217.0. 5 K down 2-3 K up. POOH Page 10 of 38 Time Logs • r' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:001 02:15 1.25 0 217 PROD1 CSGRC'MILL P RIH with BHA#18:6.151 string mill. slid mill thru 186-189 Dragging @ 5 K down 3-4 K up. broke circulation @ 6 BPM @ 150 psi. F/TQ @ 80 RPM's=600 FT/LBs. Begin milling at 186 to 189 ft torque only. Engaged torque from 750-1150 FT/LB's. Slid thru 186-189 ft 3K down 2 K up. Pump 5 BBL 80 Vis sweep. 02:15 02:45 0.50 0 200 PROD1 CSGRC'TRIP P POOH swap mill to 6 3/4"string mill. BHA#19. RIH 02:45 03:30 0.75 200 200 PROD1 CSGRC'MILL P Slid mill thru 186-190 ft Tail @ 217.0 ft. Dressed up damage. F/TQ @ 80 RPM's=600. Engaged torque =750-1325 Ft/Lbs. Circulating @ 6 BPM @ 125 psi.slid back thru damage 2 K down/up. Pumped 5 100 Vis sweep. Spot 10 BBI Hi-Vis pill 03:30 04:00 0.50 200 0 PROD1 CSGRC'TRIP P POOH with BHA#19 04:00 05:30 1.50 0 0 PROD1 CSGRC'WWWH P Pull Wear ring and wash stack 05:30 09:00 3.50 0 PROD1 CSGRC'OWFF T Install Test plug. Open OA, oberved flow on the OA valve. Time the flow of 8.6 PPG seawater,2 mins-5 gallons =3.5 BPH. Pull test plug. Continue to monitor well. Pull test plug install wear ring. 09:00 09:45 0.75 0 777 PROD1 CSGRC'TRIP T RIH with Drill pipe to 777 ft Hole taking fluid. 09:45 10:30 0.75 777 0 PROD1 CSGRC'TRIP T POOH 10:30 11:00 0.50 0 0 PROD1 CSGRC'OWFF T Flow check well for 30 min's.we still have a small steady flow. 11:00 12:00 1.00 0 1,425 PROD1 CSGRC'TRIP T RIH to 1425.0 ft tagged gravel 12:00 13:00 1.00 1,425 1,425 PROD1 CSGRC'CIRC T Changed hole over to 9.6 Brine 13:00 14:00 1.00 1,425 0 PROD1 CSGRC'TRIP T POOH with drill pipe. 14:00 14:30 0.50 0 0 PROD1 CSGRC'OWFF P Flow check no returns at surface. 14:30 15:30 1.00 0 PROD1 WHDBO MPSP P Pulled stack. Pulled wear ring. Install test plug. 15:30 16:00 0.50 PROD1 WHDBO OWFF T Monitor OA it began to flow once more. install gauge 8 psi. 16:00 17:30 1.50 PROD1 WHDBO WAIT T Discuss with town plan forward. 17:30 22:00 4.50 PROD1 WHDBO BOPE P Test gas Alarms: prep for BOPE test 250/3000 psi. Test Waived by Mathew Herrera AOGCC. @ 10:30 Hrs. Test BOPE to 250/3000 psi with 3.5 and 7"test jts. Draw down . Good test. Page 11 of 38 • Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 22:00 22:30 0.50 PROD1 WHDBO MPSP T Attempted to pull test plug with out success. 22:30 23:15 0.75 PROD1 WHDBO WAIT T Wait On FMC 23:15 23:30 0.25 PROD1 WHDBO MPSP T Pulled Test plug with TD shaking it free. Mud cake on plug. 23:30 00:00 0.50 PROD1 CSGRC'WWWH P wash BOPE stack 07/25/2015 RIH with 7 1/2 Csg. swedge. unable to get past 235 ft. RIH with 7 3/4 mill worked down to 333 ft RIH with 8 3/8 mill.worked down to 230 ft. Daily fluid loss=0 BBL's Total loss=416.00 00:00 00:30 0.50 0 0 PROD1 CSGRC'MPSP P Install Wear ring. RILDS 00:30 02:15 1.75 0 1,381 PROD1 CSGRC'TRIP P RIH with Drill pipe.Tagged @ 1381 with 10 K down pick up to 1375 ft 02:15 03:00 0.75 1,381 1,381 PROD1 CSGRC'CIRC P Changed hole back to 8.6 PPG sea water. Circulating @ 10 BPM @ 340 psi. 03:00 03:30 0.50 1,381 1,381 PROD1 CSGRC'OWFF P Monitor well-no flow. 03:30 04:00 0.50 1,381 0 PROD1 CSGRC'TRIP P POOH with drill pipe. 04:00 06:00 2.00 0 269 PROD1 CSGRC'BHAH P Pick up BHA#21:7 1/2"swedge asembly,with 3-6 1/4"drill collars. 06:00 07:00 1.00 269 298 PROD1 CSGRC'TRIP P RIH and tag at 174'with the 7 1/2" swedge. Mule shoe depth 291'.Took weight and observed drag to 298' mule shoe depth. Picked up 2 more 6 1/4"DC's for weight. UP WT/DN WT-47K. Hole stayed full. 07:00 11:30 4.50 298 308 PROD1 CSGRC'SWDG P Begin swedging 7"casing from 298, continuing down to 186'working through to 190'swedge depths. Mule shoe 308.5'.After a solid hour at this depth with no gain,decision to POOH. Observed well, no flow. 11:30 12:15 0.75 308 121 PROD1 CSGRC'TRIP P Trip out of hole standing back 6 1/4" DC's. 12:15 12:45 0.50 121 0 PROD1 CSGRC'PULD P Continue work BHA, racking back the stand of 4 3/4"drill collars. Breakout and lay down the 7 1.2" swedge. Inspect same. 12:45 13:15 0.50 0 0 PROD1 CSGRC'SVRG P Service and inspect TD post jarring operation 13:15 15:00 1.75 0 242 PROD1 CSGRC'BHAH P Make up a 7 3/4"string mill,with a 20'-3 1/2"muule shoe on bottom. Continue make up 6-6 1/4" DC's. Total BHA=241.98. Screw into top drive. 15:00 16:15 1.25 242 373 PROD1 CSGRC'MILL P Tagged with mill at 199 ft. Est parameters 80 RPM's @ 3-3.8 K Torque @ 2 BPM @ 55 PSI. Reamed down thru 186 to 311 ft mill depth.Tail @ 373 ft. slid mill the 186-192 3-5 K down/up. 16:15 16:30 0.25 373 22 PROD1 CSGRC'TRIP P POOH with BHA#21. Page 12 of 38 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:30 2.00 22 25 PROD1 CSGRC'BHAH P Change out 7 3/4 mill to 8 3/8 mill. 18:30 19:00 0.50 25 200 PROD1 CSGRC'TRIP P RIH with BHA#22. 19:00 00:00 5.00 200 253 PROD1 CSGRC'MILL P Began Milling operations. Est Parameters F/TQ @ 80 RPM's= 1000 Ft/LB's. Circulation @ 7 BPM @ 80 PSI. Began reaming down from 176 ft.Working 186-188, 200,210, Sat down solid @ 230 ft w/10 K. picked up to 227 ft and worked mill down thru 230 ft. torque @ 2500-3050 FT/LB's Recovering metal and formation 37/26/2015 RIH with mule shoe assembly attempted to clean out fill W/O success. RIH and laid down 3.5 BTCM tbg. RIH with 5" Bull nose&5.5 string mill assembly C/O fill from 7"fish to 1720 ft. 00:00 01:30 1.50 253 471 PROD1 CSGRC'MILL P Continue to work mill @ 230 ft to 235 5 K up/down. Pulled back up thru 188-186 had to work it there 10 K over on the up reamed thru again. cleaned up to 5 K up/down. continue in with the mill. on top drive. 01:30 02:15 0.75 471 1,200 PROD1 CSGRC'TRIP P RIH with same to 7"stump @ 1180 ft . dropped mule shoe into 7"fish . 02:15 02:45 0.50 1,200 1,200 PROD1 CSGRC'CIRC P Circulate hole clean @ 10 BPM @ 270 psi.with 130 vis sea water. 02:45 03:00 0.25 1,200 1,200 PROD1 CSGRC'OWFF P Flow check 15 min's. No flow 03:00 03:30 0.50 1,200 269 PROD1 CSGRC'TRIP P POOH with BHA#22. 3-5 K pull @ 235 ft. 2-3 K pull @ 188-186.ft. 03:30 04:30 1.00 269 0 PROD1 CSGRC'BHAH P Laid down BHA#22.0. Mill worn down to 8 1/8" 04:30 05:00 0.50 0 0 PROD1 CSGRC'SVRG P Service and Inspect top drive. 05:00 07:00 2.00 0 1,370 PROD1 CSGRC'TRIP P RIH with Drill pipe W/Mule shoe Tagged fill @ 1370.00 07:00 08:00 1.00 1,370 1,370 PROD1 CSGRC'CIRC P Attempted to circulate out fill @ 10 BPM @ 300 PSI from 7"fish worked mule shoe down to 1365'unable to get any deeper. 08:00 08:45 0.75 1,370 0 PROD1 CSGRC'TRIP P POOH with D/P 08:45 09:45 1.00 0 0 PROD1 CSGRC'RURD P RD Drill pipe handling equipment. RU GBR tbg. handling equipment. 09:45 10:45 1.00 0 1,750 PROD1 CSGRC'TRIP P RIH with 3.5"X 93#BTCM tbg. 10:45 13:15 2.50 1,750 0 PROD1 CSGRC'PULL P POOH laying down tbg. 13:15 14:00 0.75 0 0 PROD1 CSGRC'RURD P RD GBR equipment/RU D/P equipment 14:00 15:00 1.00 0 PROD1 CSGRC'BHAH P Pick up BHA#23. 15:00 15:45 0.75 1,275 PROD1 CSGRC'TRIP P RIH with BHA#23 15:45 22:45 7.00 1,275 1,720 PROD1 CSGRC'CIRC P Broke circulation @ 10 BPM @ 750 PSI. reamed down to 1720 ft recovering formation. 22:45 23:15 0.50 1,720 1,180 PROD1 CSGRC'TRIP P POOH to top of fish @ 1180 ft. Page 13 of 38 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 1,180 1,180 PROD1 CSGRC'CIRC P Circulated hole clean above 1180 ft. @ 12 BPM @ 920 PSI. 07/27/2015 Cleaned out 7"fish to 1714 ft. Fished 7"casing and laid it down. RIH with 7 3/4"mill assembly.to 1714 ft with mill.Without encountering damaged areas in 9 5/8"casing. _ Rig on Hi-line @ 17:30 hrs. 00:00 00:15 0.25 1,180 1,180 PROD1 CSGRC'OWFF P Flow check 15 min's. 00:15 01:00 0.75 1,180 138 PROD1 CSGRC'TRIP P POOH with BHA#23 01:00 04:00 3.00 138 225 PROD1 CSGRC'BHAH P Swap out BHA 23 to 24. Spear assembly. 04:00 04:30 0.50 225 1,180 PROD1 CSGRC'TRIP P RIH with BHA#24, to 1170'. Up wt =58 K, Down wt=58 K 04:30 04:45 0.25 1,170 1,170 PROD1 CSGRC'FISH T Attempted circulation.,with no success. Immediately pressured up to 2500 psi, indicating assembly packed off. Bled off pressure. 04:45 06:00 1.25 1,170 225 PROD1 CSGRC'TRIP T POOH with BHA#24 06:00 07:00 1.00 0 225 PROD1 CSGRC'PULD T Breakout assembly at the bullnose and mill. Observed assembly packed off with sand and gravel to the lower section of the spear. Clean out, and verify assembly clear. Make up 7" Casing spear assembly. 07:00 08:30 1.50 225 1,180 PROD1 CSGRC'TRIP P TIH with 7"Casing Spear assembly. Break circulation at 400', and 800' verifying no sand and gravel packoff. Continue TIH to obtain parameters. UP/DN WT 57K. Circulation 2 BBLS Minute-140 PSI. 08:30 09:45 1.25 1,180 1,180 PROD1 CSGRC'JAR P Engage 7"casing at 1180'. Pull to verify catch. Pull'to open jars. Begin jarring at working up to 150K jarring, with straight pull to 350K. Observed 7"casing moving with each lick, Moved 7"casing 12',and observed free movement with 225K drag. Set back one stand. 09:45 10:15 0.50 1,180 1,180 PROD1 CSGRC'CIRC P Circulate bottoms up 1400 stks to verify sand and gravel clean from hole. Observed minimal sand and gravel across shakers at bottoms up. 10:15 12:00 1.75 1,180 550 PROD1 CSGRC'TRIP P Continue POOH with 225K Drag to observe drag fell off to 150K,then to expected up weight at 2.5 stands pulled. Continue POOH, racking back drill pipe, at slower speed.Observed casing cut at 1714', pulled by the 9 5/8"casing damage at 1200'with no major issues. Continue POOH laying down casing and observed over pull and chattering up to 80K oover through the 240' area. Page 14 of 38 S Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 13:00 1.00 550 550 PROD1 CSGRC'RURD P Pull tongs to rig floor. Rig up GBR casing tongs and equipment. 13:00 14:30 1.50 550 0 PROD1 CSGRC'PULL P Continue POOH, breakout and lay down 7"casaing. Obtain pictures and videos,downloaded on S drive file. Observed casing overpulling and chattering through the 250'area of 9 5/8"casing. Initial casing cut looked good, and in gauge. 14:30 15:15 0.75 0 0 PROD1 WELLPF RURD P Rig down GBR and swap rig tongs on rig floor. 15:15 16:00 0.75 0 0 PROD1 WELLPF PULD P Pull cut joint back to floor,and set in slips. Breakout casing spear, service break spear, and lay down same. Lay down 7"cut joint.Total 7" recovered=43 jnts and 2 cuts. 16:00 17:00 1.00 0 0 PROD1 WELLPF SVRG P Perform post jarring inspection on Top Drive and Derrick. Service Top Drive. Grease up wash pipe. Clean and clear rig floor. Prep for next BHA., 17:00 18:30 1.50 0 242 PROD1 WELLPF BHAH P Pull tools to rig floor and Make up BHA#26. 7 3/4"String Mill Assembly. Sim OP's: Rig on Hi-line @ 17:30 hrs 18:30 20:00 1.50 242 1720 PROD1 WELLPF TRIP P RIH with BHA#26. No issues incounter to 1714 ft with mill. 20:00 21:45 1.75 1,720 1,720 PROD1 WELLPF CIRC P Circulated hole clean @ 12 BPM @ 480 psi.still getting back some formation. 21:45 22:00 0.25 1,720 1,700 PROD1 WELLPF OWFF P Flow check 15 min's 22:00 23:00 1.00 1,700 242 PROD1 WELLPF TRIP P POOH with BHA#26 23:00 00:00 1.00 242 0 PROD1 WELLPF BHAH P Lay down BHA#26 37/28/2015 Clean out fill in 7"casing to 1760 ft. Set RBP @ 1749 ft. place 30 ft sand on top. RIH with 8 3/8 mill assembly to 1665.0 ft dressed up 189-192 ft, 225-248 ft. 00:00 00:30 0.50 PROD1 WELLPF SVRG P sevice TD&inspect 00:30 01:30 1.00 0 156 PROD1 WELLPF BHAH P Pick up BHA#27 01:30 02:30 1.00 156 1,650 PROD1 WELLPF TRIP P RIH with BHA#27. 02:30 04:30 2.00 1,650 1,760 PROD1 WELLPF CIRC P Broke circulation at 7.5 BPM @ 770 psi.circulated out sand/fill from 1725 to1760.0. 04:30 05:30 1.00 1,760 156 PROD1 WELLPF TRIP P POOH with BHA#27 05:30 07:30 2.00 156 15 PROD1 WELLPF BHAH P Laid down BHA#27. Pickup BHA# 28. G lock RBP. 07:30 09:00 1.50 15 1,760 PROD1 WELLPF MPSP P RIH with RBP.set plug @ 1749'top of plug. Center of Elements @ 1753.5.Tail @ 1760.0 09:00 10:30 1.50 1,760 1,749 PROD1 WELLPF CIRC P Circulate well over to clean un vis'd sea water. Page 15 of 38 110 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 17:00 6.50 1,749 1,717 PROD1 WELLPF OTHR P Dump 30 ft of sand on top of RBP. Wait on sand to fall. (SIMOP...Service Top Drive and calibrate brake blocks while waiting on sand to settle). Tagged the top of Sand at 1,737-ft (Shallow from the expected target due to sand falling into the 9 5/8"x 7"Annulus). Dump 6 additional sack of sand. Wait on sand to fall. Tagged TOS at 1,717-ft (3-ft below the top of the 7"Stump at 1,714-ft. 17:00 18:45 1.75 1,717 1,702 PROD1 WELLPF CIRC P Pick up off the top of the sand. Circulate well bore back over to Hi-Vis Sea Water. 18:45 19:15 0.50 1,702 0 PROD1 WELLPF TRIP P POOH with G lock setting tool 19:15 20:15 1.00 0 157 PROD1 WELLPF BHAH P Make up BHA#29. 8 3/8 String mill assembly 20:15 22:00 1.75 157 1,665 PROD1 WELLPF MILL P Tagged @ 189 with mill. 6 K down. EST parameters. F/TQ @ 60RPM's =900 FT/LB's. Circulation @ 8 BPM @ 110 psi. reamed mil thru 189 to 192 ft. cleaned up to 2K up/dwn. worked 225 to 248 ft cleaned up to 1-2 K up/dwn. RIH to 1665. no indication of damage @ 1235-40 ft 22:00 22:30 0.50 1,665 1,665 PROD1 WELLPF CIRC P Circulated bottoms up @ 12BPM @ 440 psi. 22:30 22:45 0.25 1,665 1,665 PROD1 WELLPF OWFF P Flow check 15 min's 22:45 00:00 1.25 1,665 450 PROD1 WELLPF TRIP P POOH with BHA#29 37/29/2015 RIH tandem milling assembly 8 3/8", 8 1/2. dressing up 9 5/8"from 177 ft thru 249 ft and gauged to 1710 ft. POOH with mill assembly. RIH with 8 1/2"Tandem mill assembly dressing up 9 5/8 casing from 177 ft thru 249 ft. RIH gauging 9 5/8 for dummy gauge run. 00:00 00:30 0.50 450 157 PROD1 'WELLPF TRIP P Continue to POOH with BHA#29. 00:30 01:45 1.25 157 156 PROD1 WELLPF BHAH P Make up BHA#30: 8 3/8 ,X 8 1/2" tandem mill assembly 01:45 06:30 4.75 156 345 PROD1 WELLPF MILL P ESt Parameters F/TQ @ 80 RPM's= 550. Circulation @ 8 BPM @ 130 Psi.Worked tandem mill assembly from 177 ft.-345-ft Torque running from 1200 FT/LB's to 2600 Ft/LB's 06:30 07:30 1.00 345 1,700 PROD1 WELLPF TRIP P Continue running in with BHA#30 from 345-ft down to 1710-ft. Encountered no further tight spots. Pick up to 1,700-ft. 07:30 08:30 1.00 1,700 1,700 PROD1 WELLPF CIRC P Circulate and condition well at 4.0 bpm/175 psi. Total pumped= 145 bbls. 08:30 09:00 0.50 1,700 1,008 PROD1 WELLPF TRIP P Trip out with 3 1/2"Drill Pipe from 1,700-ft(PUW=60K)to 1,008-ft. 09:00 09:15 0.25 1,008 1,008 PROD1 WELLPF SFTY P BOP Drill...kick while tripping. Well secured in 45 seconds. CRT=95 I seconds. AAR held. Page 16 of 38 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 09:45 0.50 1,008 157 PROD1 WELLPF TRIP P Continue to trip with 3 1/2"Drill Pipe standing back in the Derrick. BHA at surface. 09:45 11:15 1.50 157 0 PROD1 WELLPF BHAH P Lay down BHA#30. Clear and clean floor. 11:15 13:15 2.00 0 0 PROD1 WELLPF SVRG P Slip and cut Drill Line(104-ft). Inspect brake linkage and brake blocks. Set Crown Saver. 13:15 13:15 0.00 0 144 PROD1 WELLPF BHAH P Make up BHA#31 as follows: Bull Nose,XO,4 1/2"XH Pup Joint,XO,2 ea 8 1/2"String Mills, Bumper Sub, Oil Jar,XO, 3 ea 6 1/4"Drill Collars, XO. 13:15 14:00 0.75 144 194 PROD1 WELLPFTRIP P Trip in with BHA#31 on 3 1/2"Drill Pipe. Set down at 194-ft with 4K. PUW-40K. SOW=40K. Bring Pump on line at 2.0 bpm/60 psi. RPMs=80, FST=700 ft/Is. Ream down from 194'-239'at 80 rpm's, 1-3K torque, 3.0 bpm/50 psi. 14:00 17:45 3.75 194 1,700 PROD1 WELLPF MILL P Bring Pump on line at 2.0 bpm/60 psi. RPMs=80, FST=700 ft/Is. Ream down from 194'-248'at 80 rpms, 1-3K torque, 3.0 bpm/50 psi. Continue reaming.slid thru aera @ 1-3 K up/down. continue to gauge casing to 1700 ft.with no additional tight spots. 17:45 20:15 2.50 1,700 1,700 PROD1 WELLPF CIRC P Circulated well clean @ 12 BPM @ 475 PSI. 20:15 21:15 1.00 1,700 144 PROD1 WELLPFTRIP P POOH with BHA#31 21:15 22:15 1.00 144 0 PROD1 WELLPF BHAH P Laid down BHA#31. Mills still @ 8 1/2" 22:15 00:00 1.75 0 0 PROD1 WELLPF WWWH P Pulled wear ring wash BOPE sack set wear ring 07/30/2015 RIH with ES dummy assembly. Unable to get past 192 ft. RIH with triple mill assembly worked thru 177 to 245 ft RIH to 1710 ft. RIH with Dummy assembly unable to get past 182 ft.with mutable attempts With and with out DC's Test BOPE:250 3000 psi. Test witness by Lou Grimaldi AOGCC. 00:00 02:30 2.50 0 161 PROD1 WELLPF BHAH P Picked BHA#32 ES dummy drift assembly 02:30 03:30 1.00 161 0 PROD1 WELLPF TRIP P RIH with BHA 32; Drift assembly assembly.Tagged at 182 ft rotated lightly down to 192 ft @ 1000 FT/LBs torque. Unable to get beyond 192 ft. Lay down drift assembly 03:30 04:00 0.50 0 0 PROD1 WELLPF SVRG P Inspect and service TD 04:00 04:00 0.00 0 152 PROD1 WELLPF BHAH P Pick up BHA#33:8 3/8 X 8 1/2 X 8 1/2 tandem milling assembly. 04:00 04:15 0.25 152 192 PROD1 WELLPF TRIP P Trip in with BHA#33 on 3 1/2"Drill Pipe from 152-ft. Set down at 192-ft. 04:15 09:45 5.50 192 PROD1 WELLPF MILL P Continue to mill and back ream to straighten out the 9 5/8"Casing section between 192'-340'. Final torque to work through = 1-2K Page 17 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 10:00 0.25 340 152 PROD1 WELLPF TRIP P Trip out from 340-ft with BHA#33, standing back 3 1/2" Drill Pipe in the Derrick. 10:00 10:45 0.75 152 0 PROD1 WELLPF BHAH P Lay down BHA#33. Gauge Mills as follows: lead mill remains 8 3/8", center mill in 8 1/2"/8 3/8"out,top mill remains at-8 1/2"re-run. 10:45 11:15 0.50 0 0 PROD1 WELLPF SVRG P Perform Top Drive inspection. 11:15 12:00 0.75 0 139 PROD1 WELLPF BHAH P Make-up the Dummy ES-Cementer Drift BHA#34 as follows: Cut-Lip Skirt,XO Sub, 7"Casing Pup Joint, Dummy ES-Cementer, 7"Casing Pup Joint,XO Sub, Bumper Sub, Oil Jar,XO, 3 ea 6 1/4"Drill Collars,XO 12:00 13:00 1.00 139 188 PROD1 WELLPF TRIP P Trip in with BHA#34 to 188-ft. Attempted several times to work the Dummy Drift deeper with no success. (9 5/8"Casing separation alignment problem...?). 13:00 13:15 0.25 188 47 PROD1 WELLPF TRIP P Trip out with BHA#34. Set back the stand of 6 1/4" Drill Collars. 13:15 13:45 0.50 47 188 PROD1 WELLPF TRIP P Trip back in with BHA#35...Same Dummy ES-Cementer Assembly minus the stand of Drill Collars. Tagged up at 188-ft.same spot. Attempt several time to drift deeper. No-Joy. 13:45 14:00 0.25 188 47 PROD1 WELLPF TRIP P Trip back out with BHA#35, standing back the 3 1/2" Drill Pipe. 14:00 14:00 0.00 47 0 PROD1 WELLPF BHAH P Lay down BHA#35. 14:00 15:00 1.00 0 0 PROD1 WELLPF WWWH P Pull wear ring wash BOPE stack 15:00 17:30 2.50 0 0 PROD1 WHDBO MPSP P Set test plug and RU testing equipment Page 18 of 38 Time Logs • • Date From To Dur : S.Depth E. Depth Phase Code Subcode T Comment 17:30 22:30 5.00 0 0 PROD1 WHDBO BOPE P Shell Test BOPE:250/3000 psi. Test witnessed by Lou Grimaldi AOGCC. Test: 1) BR,Choke 1,2,3,16, RF kill, outer test spool, TD HCR. Pass 2)Choke 4,5,6, Kill HCR, Inner test spool,TD man. pass 3)Choke 7,8,9 Man Kill 3.5"HT-38 Dart, Pass 4)Hold/flow test Super choke, man choke.pass 5)Choke 10,11. Pass 6)Choke 12,13,15. Pass 7)3 1/2"test jt Annular, choke 14, 3.5"8rd FOSV.Pass 8)Upper VBR pipe rams W/3.5 TJ.Pass 9) LPR 7"W/7"TJ. 3.5"HT-38 FOSV.Pass 10)Annular W/7"TJ. Pass Draw down 22:30 23:00 0.50 0 0 PROD1 WHDBO RURD P RD testing equipment 23:00 23:30 0.50 0 0 PROD1 WHDBO MPSP P Pull test plug and set wear ring. 23:30 00:00 0.50 0 PROD1 WELLPF BHAH P PU BHA#36 07/31/2015 RIH with Dummy ES drift.stopped @ 233 ft with 15 K down . 10 K up. laid down ES Dummy. RIH with 8 3/8 cut lip with internal dressing mill. attempted to wash over and dress up 7"casing @ 1714.0 ft with out success. POOH RIH with 5 1/2 dressed bull noes and 6 1/8 string mill C/O fill in 7"to 1721.0 ft. 00:00 01:00 1.00 0 159 PROD1 WELLPF BHAH P Continue to pick up BHA#36. 01:00 02:00 1.00 159 233 PROD1 WELLPF TRIP P RIH with Dummy ES drift assembly. 2-3 K down wt @ 186-190, 3-5 K 190-192 ft, 7-9 k 192-196 ft 4-5 K 215-228 ft 7-15K 228-233 10 K over to pull out. 02:00 02:30 0.50 233 8 PROD1 WELLPF BHAH P POOH laid down ES dummy assembly. BHA 36. 02:30 02:45 0.25 8 137 PROD1 WELLPF BHAH P RIH with BHA#37. 7"dressing assembly 02:45 04:30 1.75 137 1,704 PROD1 WELLPF TRIP P RIH with BHA#37. Tagged fill at 1,704-ft. 04:30 08:30 4.00 1,704 1,718 PROD1 WELLPF MILL P Wash and rotate down to the top of the 7"Casing stump at 1,716-ft dpmd. Continue to wash over the 7" Casing stump down to 1,718-ft dpmd. Unable to make any further hole(for some reason). Decision made to POOH and inspect the Dress-Off Shoe and Inner Mill. 08:30 09:30 1.00 1,718 136 PROD1 WELLPF TRIP P Trip out with BHA#37 from 1,718-ft, standing back the 3 1/2"Drill Pipe in the Derrick. Page 19 of 38 9 • Time Logs • Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 09:30 11:00 1.50 136 0 PROD1 WELLPF BHAH P Set back Drill Collars. Clean Magnet...several small pieces of milled up casing and an estimated 4 lbs of mill fillings. Lay down BHA. Inspect the Dress-Off Assembly. End of the Mule Shoe shinny. Inner Mill new, indicating"no-work"as we are not getting over the 7"Casing Stump all the way. (Ready Mule Shoe to take to Baker Machine Shop to add a bit of carbide to the leading edge of the Mule shoe). Clear and clean floor. 11:00 11:30 0.50 0 0 PROD1 WELLPF SVRG P Inspect and service Top Drive. 11:30 12:30 1.00 0 43 PROD1 WELLPF BHAH P Make-up BHA#38 as follows: Dressed Bullnose,6.1"String Mill, XO, Magnet, Bumper Sub, Oil Jar, XO. 12:30 13:30 1.00 43 1,650 PROD1 WELLPF TRIP P Trip in with BHA#38 to 1,650-ft 13:30 14:00 0.50 1,650 1,650 PROD1 WELLPF CIRC T Bring Rig Pump on line. Drill String plugged. Attempt to break circulations. No-Joy. 14:00 15:00 1.00 1,650 43 PROD1 WELLPF TRIP T Trip out wet standing back the 3 1/2" Drill Pipe in the Derrick to the BHA. 15:00 16:30 1.50 43 43 PROD1 WELLPF BHAH T Clean Magnet. Clear obstructed BHA. Dressed Bullnose and the String Mill were packed solid with sand, fine gravel and mill filings. Make-up same BHA configuration for re-run. 16:30 18:00 1.50 43 1,710 PROD1 WELLPF TRIP T Trip in with Clean-out BHA. (stop to break circulations as directed on the trip in). 18:00 21:00 3.00 1,710 1,721 PROD1 WELLPF CIRC P Circulate out formation from 1714 ft to 1721 ft. Pumped 10 BBL Hi-Vis sweep. spotted 5 BBLS of 21:00 22:00 1.00 1,721 43 PROD1 WELLPF TRIP P POOH with BHA#39 Re run on 5.5 Bullnose assembly. Spot hi-vis pill acrossed damaged 9 5/8. 300-ft surface. 22:00 00:00 2.00 43 141 PROD1 WELLPF BHAH P Laid down BHA#39 and pick up BHA#40 08/01/2015 Dress up 7"casing top @ 1714 ft. Spot Hi-Vis pill at 1714 and 300 ft. RIH with 7"casing.engage patch and Begin cementing 7"tie back in place. 00:00 01:45 1.75 141 1,710 PROD1 WELLPF TRIP P RIH with BHA#40 Breaking circulation as directed to ensure circulation path is clear. Page 20 of 38 Time Logs • • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:45 04:00 2.25 1,710 1,720 PROD1 WELLPF MILL P Est Parameters: F/TQ @ 600 FT/LB's above stump. 900 FT/LB's @ 50 RPM's going over. Circulation Rate @ 5 BPM @ 185 psi.Washed down to 1719'with mule shoe engaged mill area,dress up casing top @ 1714.0 ft. Torque running from 1000 Ft/LB's to 2200 FT/LB's. Mill off .5 ft Top of casing @ 1714.5 ft. pumped Hi-Vis sweep. slide back over stump. spot 5 BBL's 300 vis. Hi-Vis pill. 04:00 06:00 2.00 1,720 141 PROD1 WELLPF TRIP P Trip out with BHA#40, stand back the 3 1/2"Drill Plpe in the Derrick 06:00 06:15 0.25 141 141 PROD1 WELLPF SFTY P Kick while tripping drill. Well secured in 42 seconds. CRT in 92 seconds. MR held. 06:15 08:00 1.75 141 0 PROD1 WELLPF BHAH P Single down the 6 1/4"Drill Collars. Lay down the remaining components in the BHA. 08:00 12:00 4.00 0 0 PROD1 CASING RURD P Clear and clean floor. Blow down Top Drive. Pull Wear Bushing. Install long bails on Top Drive. Rig up GBR equipment to handle 7" Casing. Ready Pipe Shed. Bring Cement Head to the floor and install the Circulating Manifold to same. 12:00 12:30 0.50 0 0 PROD1 CASING SFTY P PJSM and operations meeting. Review and discuss the hazzards assoicated with handling and running 7"Casing. Review the running order. 12:30 14:00 1.50 0 190 PROD1 CASING PUTB P Pick-up Shoe Track as follows: Baker 7"Casing Patch, 7"26 Ib/ft, L-80 TCII 10-ft Pup Joint, Halliburton ES-H, 7"Cementer(part number 101959328), 7"26 lb/ft, L-80,TCII 2-ft Pup Joint. Continue to single in with 7"26 Ib/ft, L-80,TCII Casing from the Pipe Shed. (Make-up torque10,100 ft/lbs). Install 8 1/4"Centralizers on every Joint. 14:00 15:30 1.50 190 342 PROD1 CASING PUTB P Set down at 195-ft.(beginning of the milled 9 5/8"subsidence section). Un-able to fall through. Lay down Joint#4. Install XO. Pick same joint back up. Make-up Top Drive. Continue in. Lightly tag up at 190-ft. Slowly rotate through to 200-ft with 2-4K negative weight. Continue in making Top Drive connections. Moving forward with slow rotations and negative weight "bobbles"as needed. 15:30 19:15 3.75 342 1,717 PROD1 CASING PUTB P Shoe Track through the tight section in the 9 5/8"Casing. Continue to single in the 7"Casing on elevators.. Up wt=67 K. Engaged patch Page 21 of 38 • Time Logs • Date From` To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 19:30 0.25 1,717 1,717 PROD1 CASING PRTS P PT casing to 2000 psi for 10 min's. Shear ES Cementer 19:30 20:00 0.50 1,700 1,700 PROD1 CEMEN-CIRCP Pumped 60 BBIs of 90° heated sea water @ 5 BPM @ 165 psi. 20:00 22:30 2.50 PROD1 CEMEN-RURD P Validated closing plug in head. Install cement manifold on casing and lines. Loaded Vacumm trucks with fluids. 22:30 00:00 1.50 PROD1 CEMEN-CMNT P PT line to 4500 psi. Begin cement job as per design. 38/02/2015 Cut casing and install pack off, New Tbg spool. PT to 250/3000 psi. Installed BOPE shell test to 250/3000 psi. RIH with bit assembly. Circulated out wet cement to 1635 ft. NOTE: Rig off High line @ 20:54 hrs do to power loss at CPF 3 00:00 01:00 1.00 PROD1 CEMEN-CMNT P Continue cement job. 10 AS-1 neat ahead, 163 AS-1 W/Pessure net, 8 bbls neat, dropped plug.4 neat behind. 5 BBIs fresh water, 56 sea water. plug did not latch up on displacement. bled back 4 bbls increased rate to 3.5 bbls latched plug closed ES cemnter @ 1200 psi. preesured up to 3500 psi. held pressure for 5 min's. bled off presssure. no flow. Cement treating pressure with OA @ 1/2 built up to 950 psi. @ 2 BPM. cement returns to surface during pumping ops. CIP @ 00:50 hrs. 40 BBLs of cement recover at surface. 86 BBLS to well and formation 01:00 02:00 1.00 PROD1 CEMEN-RURD P Flush stack and lay down cement head. 02:00 03:30 1.50 PROD1 WELLPF NUND P ND BOPE.Top of cement at 3 ft from surface. Install E-slips on casing 03:30 06:30 3.00 PROD1 WELLPF WWSP P Casing landed with 20 K over. RU Wachs cutter. Cut casing. Install Pack-Offs. Lay down 7"cut-off joint...OAL= 15.90-ft. 06:30 08:30 2.00 PROD1 WELLPF NUND P Nipple down BOP Stack and remove the Double Stub Adaptor and Spacer Spool. 08:30 11:00 2.50 PROD1 WELLPF NUND P Install Tubing Spool. Install secondary Annulus Valve. 11:00 11:30 0.50 PROD1 WELLPF WWSP P Pressure test the 7"Pack-Off at 250 x 5 minutes and at 3,000 psi x 10 minutes. Good. 11:30 15:00 3.50 PROD1 WELLPF NUND P Nipple up Double Stud adapter. Nipple up BOP Stack. Install Flow Nipple. Remove the 7"Pipe Rams from the lower gate and install 2 7/8" x 5"VBRs. Page 22 of 38 4110 Time Logs 4111 Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 15:00 16:00 1.00 PROD1 WELLPF BOPE P Rig up test equipment. Test the 2 7/8"x 5"VBR in the lower Gate and the BOP body break at 250/3,000 psi x 5 minutes each. Good. Record on chart. Lay down test joint. Rig down test equipment. 16:00 17:00 1.00 0 311 PROD1 WELLPF BHAH P Make-up BHA#41 as follows: 6 1/8" Roller Cone Bit, 2 ea Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4" Drill Collars,XO. 17:00 18:00 1.00 311 1,446 PROD1 WELLPF TRIP P Trip in with BHA#41. 18:00 18:30 0.50 1,446 1,446 PROD1 WELLPF PRTS P Test casing to 2000 psi on chart. 18:30 20:30 2.00 1,446 1,635 PROD1 WELLPF COCF P Broke circulation @ 3BPM @ 150 PSI. RIH with bit assembly looking for cement stringers.to 1635 ft got back green cement with out drilling. Kick pump rate up to BP @ 450 psi _ .circulated clean. 20:30 23:30 3.00 1,635 1,635 PROD1 WELLPF WAIT T Wait on vacuum truck to arrive and pull cutting box and pit one do to green cement recovered during circulation. Pull pit 1 and cutting box of contaminated fluids 23:30 00:00 0.50 1,635 1,635 PROD1 WELLPF COCF P Continue to clean out cement 38/03/2015 Drilled out ES cementer with 6 1/8 rock bit. PT tie back to 3000 psi for 30 Min's. RIH with 6 1/8 junk mill. stopped at 95 ft. Retested casing. RIH with 6"casing swedge. RIH to 214 ft No issues. Made mutable runs with 5 3/4 RCJB.to clean out ES junk to 1749 ft. RIH with 6 1/8 casing swedge. 00:00 03:15 3.25 1,635 1,719 PROD1 WELLPF COCF P Continued to drill out cement and ES cementer Tagged solid cement @ 1639.ft Drilled out cement and ES cementer.Wt 3 K on bit at 60 RPM's @ 700 FT/LB's torque. Circulating @ 7 BPM @ 450 psi.Tagged fill at 1719 ft. dry drilled for 5 min's. Bit was making hole,stopped dry drilling. Ensured bit was clear. 03:15 04:15 1.00 1,719 311 PROD1 WELLPF TRIP P POOH with BHA#41. 04:15 04:45 0.50 311 0 PROD1 WELLPF BHAH P Lay down BHA#41 04:45 05:15 0.50 0 0 PROD1 WELLPF PRTS P Pressure test casing and patch to 3000 psi on chart. Good. 05:15 06:00 0.75 0 95 PROD1 WELLPF BHAH P Pick up BHA#42 06:00 06:15 0.25 95 95 PROD1 WELLPF TRIP P Start to trip in with BHA#42. Set down at 95-ft. 06:15 06:45 0.50 95 95 PROD1 WELLPF TRIP T Attempted several times to work past 95-ft. No-Joy(suspect an over-torqued casing connection). 06:45 07:00 0.25 95 0 PROD1 WELLPF TRIP T Trip out with BHA#42 07:00 07:45 0.75 0 0 PROD1 WELLPF BHAH T Lay down BHA#42. Page 23 of 38 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:30 0.75 0 95 PROD1 WELLPF BHAH T Make-up BHA#43 as follows: Bullnose,6.155"Smooth OD String Mill, Bumper sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4" Drill Collars,X0. 08:30 08:45 0.25 95 95 PROD1 WELLPF TRIP T Trip in with partical BHA#43 to 95-ft. Set down. 08:45 09:15 0.50 95 95 PROD1 WELLPF TRIP T Continue to attempt to work past 95-ft. Bump down several times. Slowly rotate at 15 rpms and once at 30 rpms. No progress. Discuss plan forward with Anchorage Engineer. 09:15 09:30 0.25 95 95 PROD1 WELLPF TRIP T Trip out with BHA#43 09:30 09:45 0.25 95 0 PROD1 WELLPF BHAH Lay down BHA#43. 09:45 10:00 0.25 0 0 PROD1 WELLPF PRTS T Pressure test the 7"Casing at 3,000 psi x 10 minutes. Good. Record on chart. 10:00 10:45 0.75 0 0 PROD1 WELLPF WAIT T Order out Casing Swedges from Fishing Shop in Deadhorse. Wait on delivery...also presently there is a Rig move in progress on the BP side of the field. (SIMOPS: inspect Top Drive). 10:45 11:15 0.50 0 200 PROD1 WELLPF BHAH T Make-up BHA#44 as follows: 6"OD Swage, Bit Sub, Bumper Sub, Oil Jar, Pump-Out-Sub,9 ea 4 3/4"Drill Collars,XO. 11:15 11:30 0.25 200 200 PROD1 WELLPF TRIP T Trip in with BHA#44. The 6"Swage passed through the tight spot at 95-ft with no problem. Continue down to 200-ft. 11:30 11:45 0.25 200 200 PROD1 WELLPF TRIP T Trip out with BHA#44 11:45 12:00 0.25 200 0 PROD1 WELLPF BHAH T Lay down BHA#44. 12:00 12:30 0.50 0 324 PROD1 WELLPF BHAH P Resume Step 21 (planned ops for now). Make up BHA#45 as follows: 5 1/2"Bladed Junk Mill,2 ea Boot Baskets, Bit Sub, Magnet, Bumper Sub, Oil Jar, Pump-Out Sub, 9 ea 4 3/4" Drill Collars,XO Sub. 12:30 13:30 1.00 324 1,719 PROD1 WELLPF TRIP P Trip in with BHA#45 on 3 1/2"Drill Pipe from the Derrick. 13:30 14:00 0.50 1,719 1,721 PROD1 WELLPF MILL P Tag debris on top of Sand at 1,719-ft dpmd. Dry mill at 60-80 rpms. 700 -800 ft/lbs Top Drive torque. 14:00 14:45 0.75 1,721 324 PROD1 WELLPF TRIP P Trip out from 1,721-ft dpmd with BHA #45, standing the 3 1/2"Drill Pipe back in the Derrick. 14:45 15:00 0.25 324 0 PROD1 WELLPF BHAH P Lay down BHA#45. 15:00 15:30 0.50 0 335 PROD1 WELLPF BHAH P Make-up BHA#46 as follows: 5 3/4" RCJB, Double Pin Sub,2 ea 4 3/4" Boot Baskets, Bit Sub, Magnet, Bumper Sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4" Drill Collars,XO Sub. Page 24 of 38 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:30 1.00 335 1,715 PROD1 WELLPF TRIP P Trip in with BHA#46 on 3 1/2"Drill Pipe from the Derrick. 16:30 17:00 0.50 1,715 1,735 PROD1 WELLPF MILL P worked RCJB from 1719.ft to 1735' 17:00 18:00 1.00 1,735 350 PROD1 WELLPF TRIP P POOH with BHA#46 18:00 19:30 1.50 350 350 PROD1 WELLPF BHAH P Cleaned out JB and Boot baskets recover rock and small plug cuttings. 19:30 21:30 2.00 350 1,749 PROD1 WELLPF MILL P RIH with BHA#47 RCJB with 5 ft of extension. Circulated down @ 8 BPM @ 1180 psi.Tagged at 1737 ft rotated down to 1742. Back reamed 30 ft.slowed pump rate to 1 BPM tagged at 1744. Increased rate to 8 BPM circulated down to 1749 TOP of RBP. Corculated clean. 21:30 22:15 0.75 1,749 355 PROD1 WELLPF TRIP P POOH with BHA#47. 22:15 00:00 1.75 355 182 PROD1 WELLPF BHAH P Laid down BHA 47. recovered small pieces of ES cementer and rocks. _ Plck up BHA#48. 08/04/2015 RIH with 6 1/8 casing swedge unable to get past 95 ft. POOH with swedge. RIH with G plug retrieving tool. Pull G plug. Rig Up Slickline. RIH pull IBP. Rig Down Slickline.TOOH and Lay Down IBP. 00:00 00:15 0.25 182 182 PROD1 WELLPF OTHR P Attempt to get 6 1/8 casing swedge thru 95 ft with out success. 00:15 01:30 1.25 182 5 PROD1 WELLPF BHAH P Laid down BHA#48 swedge assembly pick up G-Plug retrieving head. 01:30 02:00 0.50 5 1,717 PROD1 WELLPF TRIP P RIH with G plug retrieving tool. 02:00 03:15 1.25 1,717 1,749 PROD1 WELLPF MPSP P Circulated over the top of plug @ 4 BPM at 260 psi.plug appears to still have some cuttings on top worked over and engaged plug. Released plug. let equalize. continue to circulate at 4 BPM. 03:15 03:45 0.50 1,749 1,743 PROD1 WELLPF OWFF P Monitor well for flow 30 min's 03:45 07:30 3.75 1,743 0 PROD1 WELLPF TRIP P POOH with G-RBP. Having to circulate out due to some remaining junk that is above the RBP. Saw a "bobble"at 95-ft(as expected)when the RBP pass through. Lay down RBP. Recover two large pieces of cast metal from the ES-Cementer. Clear and clean Floor. 07:30 08:30 1.00 0 355 PROD1 WELLPF BHAH P Make-up BHA#49 as follows: 6" RCJB Head,XO Bushing,XO Bushing w/two Cages, RCJB, Double Pin sub, 2 ea Boot Baskets, Bit Sub, Magnet, Bumper Sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4"Drill Collars,XO 08:30 09:15 0.75 355 1,776 PROD1 WELLPF TRIP P Trip in with BHA#49 on 3 1/2"Drill Pipe from the Derrick. (SIMOPS...Spot S-Line Unit). Page 25 of 38 Time Logs • Date ' From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:15 10:00 0.75 1,776 1,778 PROD1 WELLPF WASH P Wash sand and any debris off of the top of the Weatherford IBP. Work RCJB through sand from 1,767-ft dpmd at 9.0 bpm/1,705 psi.,to the IBP at 1,778.5-ft dpmd. Sand returns. 10:00 10:30 0.50 1,776 1,776 PROD1 WELLPF CIRC P Circulate and condition well bore. Pump a 30 bbl Hi-Vis sweep and chase back to surface with slick Sea Water at 9.0 bpm/1,575 psi. Returns =sand, some small gravel pieces, and a few pieces of drilled up rubber. 10:30 11:00 0.50 1,776 355 PROD1 WELLPF TRIP P Trip out with BHA#49 from 1,776-ft 11:00 12:00 1.00 355 0 PROD1 WELLPF BHAH P Set back Drill Collars. Lay down the remainder of the BHA. Clear RCJB and Boot Baskets. Recovered a fair sized rock and a few pieces of milled casing. 12:00 12:30 0.50 0 4 PROD1 WELLPF BHAH P Make-up BHA#50 as follows: 5 7/8" Overshot...w/No Grapple,XO Sub. 12:30 13:45 1.25 4 1,776 PROD1 WELLPF TRIP P Trip in with BHA#50 with 3 1/2"Drill Pipe from the Derrick. Lightly tag the IBP at 1,777-ft dpmd. Pick-up to 1,776-ft. (The Weatherford IBP top os swallowed by the 5 7/8" Overshot). 13:45 14:00 0.25 1,776 1,776 PROD1 WELLPF SFTY P PJSM with Halliburton S-Line Crew and Rig Crew. Discuss the hazards assoicated with rigging up S-line equipment. Discuss the scope of the planned job. 14:00 18:30 4.50 1,776 1,776 PROD1 WELLPF SLKL P Rig-up S-Line equipment. Pick-up Lubricator and tool string. Pressure test lubricator at 2500 psi. Run in hole with a JD Overshot on .125" wire. 18:30 22:00 3.50 1,776 1,776 PROD1 WELLPF SLKL P Slickline to retrieve Weatherford IBP. on third trip latch on and progressively pull up to 1700#. Begin to jar from 500#to 1000#. On first hit at 1000#observe movement and drag. Continue to pull IBP up string to—1090'and pulled tight to 1700#. slacked off and observed Slickline tool release. POOH with Slickline. 22:00 23:30 1.50 1,776 1,776 PROD1 WELLPF SLKL P Rig Down Slickline equipment and mobilize off floor. 23:30 00:00 0.50 1,776 947 PROD1 WELLPF TRIP P Trip out of hole to 1090'to look for IBP in string. Remove IBP from String in connection at—1090'. Continue trip out of hole 38/05/2015 TOOH and Lay Down BHA#50. Pick Up and TIH BHA#51. Mill tight spots. TOOH and Lay Down BHA#51. Pressure test casing to 3000 psi. Pick Up BHA#52(Over shot)and fish the remaining completion.TOOH with Drill Pipe. Lay Down old 3.5"completion. Pick Up BHA#53(Dressoff and overshot)and Trip/SIgnle in hole. 00:00 00:30 0.50 947 4 PROD1 WELLPF TRIP P Continue trip out of hole. Page 26 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:30 1.00 4 132 PROD1 WELLPF BHAH P Lay Down BHA#50. Pick Up BHA #51. 01:30 03:00 1.50 132 150 PROD1 WELLPF MILL P Mill spots at 94'and 134'. Up Wt= 32k; Dn Wt=32k;40-60 rpm TQ 500-800 ft lbs.Areas that were milled with string mill coincide with connections in the new 7"casing. 03:00 06:00 3.00 150 1,788 PROD1 WELLPF TRIP P Trip in with BHA#51 watching for tight/rough spots. Polished through the ES-Cementer at 1,699-ft dpmd. Continue on in and lightely tagged the top of the 3 1/2"Tubing at 1,788.5-ft dpmd. 06:00 07:00 1.00 1,788 132 PROD1 WELLPF TRIP P Trip out with BHA#51, standing the 3 1/2"Drill Pipe back in the Derrick. 07:00 07:30 0.50 132 0 PROD1 WELLPF BHAH P Lay down BHA#51 07:30 07:45 0.25 0 0 PROD1 WELLPF PRTS P Pressure test the 7"Casing at 3,000 psi x 5 minutes. Good. Record on chart. 07:45 08:15 0.50 0 PROD1 WELLPF SVRG P Inspect Top Drive. 08:15 09:15 1.00 0 315 COMPZ RPCOM BHAH P Make-up BHA#52 as follows: Cut Lip Guide, 5 3/4"Overshot Bowl(w/3 1/2"Basket Grapple), Overshot Extension,Top Sub, Bumper Sub, Oil Jar,4 3/4" Drill Collars,4 3/4" Intensifier,XO Sub. 09:15 10:15 1.00 315 1,788 COMPZ RPCOM TRIP P Trip in with BHA#52 with 3 1/2" Drill Pipe from the Derrick to the top of the 3 1/2"Tubing at 1,788.5-ft dpmd. 10:15 10:45 0.50 1,788 1,788 COMPZ RPCOM FISH P Up Weight=62K. Make-up Top Drive. Free spin torque=700 ft/lbs at 20 rpms. Pump rate=2.0 bpm/148 psi. Continue in and swallow the 3 1/2"Tubing. Plant Overshot. Lightly un-load Jars to set Grapple. Pull up to 125K(fill around fish). Fish free at the expected string weight of—110K. (Monitor Well). 10:45 11:45 1.00 6,968 5,180 COMPZ RPCOM TRIP P Up Weight= 110K. Trip out with BHA#52 and 3 1/2"Tubing Fish from —6,968-ft standing back the 3 1/2" Drill Pipe in the Derrick. Fish at surface. (hole taking correct fill amount). 11:45 12:30 0.75 5,180 4,865 COMPZ RPCOM BHAH P Lay down BHA. Fish at surface. Recovered the remaining—12-ft of Control Line, 2 ea SS Control Line Bands, and the SSSV. Release Overshot. 12:30 13:30 1.00 4,865 4,865 COMPZ RPCOM RURD P Rig up GBR equipment to handle 3 1/2"Tubing. Ready floor. Ready Pipe shed. 13:30 19:30 6.00 4,865 0 COMPZ RPCOM PULL P Single down remaining 3 1/2",9.3 lb/ft,J-55, IPC, BTC Tubing. 19:30 20:00 0.50 0 0 COMPZ RPCOM SVRG P Service Top Drive and draw works. Page 27 of 38 • 4110 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:00 1.00 0 0 COMPZ RPCOM WAIT T Waiting on part of BHA dressoff assembly was delayed due to a BP Rig move. 21:00 22:15 1.25 0 317 COMPZ RPCOM BHAH P Pick Up BHA#53(Overshot Grapple with dressoff). Overall length 316.73' 22:15 23:15 1.00 317 2,020 COMPZ RPCOM TRIP P Trip in hole with BHA#53 with stands from the derrick. 23:15 00:00 0.75 2,020 2,840 COMPZ RPCOM PULD P Single in hole with BHA#53 picking up Drill Pipe from the pipe shed. 08/06/2015 Single in the hole with BHA#53. Circulate well over to clean seawater. Fish the 3.5"OEJ and tubing stub. TOOH with Fish. Lay Down BHA#53 and Fish. Total Losses for day:296 bbl 00:00 03:30 3.50 2,840 6,950 COMPZ RPCOM PULD P Single in hole with BHA#53 picking up Drill Pipe from the pipe shed. 03:30 04:30 1.00 6,950 6,950 COMPZ RPCOM CIRC P Circulate hole over to clean 8.6 ppg seawater. Up Wt= 160k, Dn Wt= 100k, Rot\M= 120k, 7000 free Tq. 04:30 06:30 2.00 6,950 6,950 COMPZ RPCOM FISH P Engage stub at 6968'dpmd. Attempting to pull the OEJ free from the Camco Packer. Have—20-ft of travel...however Fish not free. 06:30 07:30 1.00 6,950 6,950 COMPZ RPCOM CIRC P Circulate bottoms up with clean Sea Water at 2.7 bpm/505 psi. Observed severall barrels returned just before bottoms up that were gas cut (assume Camco Packer has possibally released...but hanging up...?). Fluid weight in 8.6 lb/gal. Fluid weight out 8.6 lb/gal. 07:30 10:45 3.25 6,950 6,857 COMPZ RPCOM FISH P Resume fishing operations. Continue working Fish. Occasionally un-loading the Jars at 25K over string weight(remembering that there are Blast Ring Joints below the Packer). Total Fish movement=24-ft. Now unable to go downhole. No further progress up or down. Discuss with Anchorage Engineer the need to work Jars with a little more gusto. Resume fishing. Un-load Jars at 40K over string weight, one time. Fish now moving but dragging. Pull one stand of Drill Pipe sl000wly...observe "swabbing". Drop dart and open the Pump-Out-Sub. 10:45 11:45 1.00 6,857 6,857 COMPZ RPCOM CIRC P Circulate Well at 3.5 bpm/350 psi. No sign of gas in returns. Fluid loss during circulation= 10.5 bbls. Fluid weight in=8.6 lb/gal. Fluid weight out=8.6 lb/gal. 11:45 12:00 0.25 6,857 6,857 COMPZ RPCOM OWFF P Monitor Well. Observe a slow drop in fluid level. Page 28 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 16:30 4.50 6,857 317 COMPZ RPCOM TRIP P Trip out with the expected Fish(and most likely with the remaining completion jewelry below),standing back the 3 1/2"Drill Pipe in the Derrick. Up Weight= 180K. Presently, 20K over string weight to drag packer through casing collars. Trip Tank monitor continues to show a slow loss. (SIMOPS: load,drift, and tally 3 1/2"Tubing in the Pipe Shed). Fluid loss= 12 bbls/hr. 16:30 18:00 1.50 317 0 COMPZ RPCOM BHAH P BHA at surface. Set back Drill Collars. 18:00 23:30 5.50 0 0 COMPZ RPCOM PULL P Lay Down Cut Joint, OEJ, Packer, GLM, 5 joints of Blast Rings,2 blast joints, pups and second Seal Assembly. Bow Spring Centralizer had half of one spring ripped off.Also recovered top half of tubing patch. Set Aside Joint with Hex plug and catcher inside to be recovered by slickline personnel. Seawater losses while keeping hole full average 20-22 bph. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Rig Down Power Tongs and handling equipment. 08/07/2015 Test BOPE. Pick Up BHA#54(Overshot to fish patch).Trip in hole. Slip and Cut Drilling Line. Fish Patch. TOOH with BHA#54. 00:00 00:45 0.75 0 0 COMPZ RPCOM WWWH P Wash well head and BOP stack with stack jetting tool. 00:45 01:45 1.00 0 0 COMPZ WHDBO RURD P Pull Wear Ring. Set Test Plug. Rig Up Test Equipment. FLood stack with Water. 01:45 07:30 5.75 0 0 COMPZ WHDBO BOPE P Weekly BOPE test. Right to witness waived by AOGCC Representative Bob Noble. (Also Bob Noble granted us a couple of extra hours over the midnight deadline due to the double fish we recovered and the extra time it took to finish out of the hole and lay down the recovered components). 07:30 09:30 2.00 0 0 COMPZ WHDBO BOPE T Down time. Repair hydraulic leak. 09:30 14:30 5.00 0 0 COMPZ WHDBO BOPE T Remove the upper Well control Valve. Rebuild same. Install same. 14:30 15:00 0.50 0 0 COMPZ WHDBO BOPE P Test Upper Well control and Saver Sub at 250/3,000 psi. Weekly BOPE test completed. 15:00 15:30 0.50 0 0 COMPZ WHDBO RURD P Rig Down BOP Testing lines and equipment and blow down same. 15:30 16:30 1.00 0 303 COMPZ RPCOM BHAH P Make-up BHA#54 as follows: Cup Lip Guide, Overshot Bowl, Top Sub, Bumper Sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4"Drill Collars,XO Sub. 16:30 19:00 2.50 303 6,929 COMPZ RPCOM TRIP P Trip in with BHA#54 with 3 1/2"Drill Pipe from the Derrick. Page 29 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 19:30 0.50 6,929 7,212 COMPZ RPCOM PULD P Pick Up joints of Drill Pipe from Pipe Shed. 19:30 21:30 2.00 7,212 7,212 COMPZ RPCOM SLPC P Slip and Cut 500'of Drilling Line. 21:30 22:30 1.00 7,212 7,212 COMPZ RPCOM FISH P Work to engage fish (lower part of tubing patch). Up Wt= 163, Dn Wt= 102k, Rot Wt= 123k, Free Tq 7k, 20 rpm, 3 bpm, 300 psi. Set down 5k-7k on top of fish at 7278'dpmd. observe slight weight fluctuation pulling up. Set back down 5k putting 2 wraps into string, pull up and same indication as before. Pull fish all the way out of packer and put back in but see no indication of any tag or resistance as entering Packer,tag bottom at same depth.Attempt to pull up and put 2 more wraps into string to slightly rotate. Slide back into packer and see no tag as passing Packer and tag bottom at same depth. Continue to tag bottom at same depth indicating Top of Fish at 7278'dpmd. 22:30 22:45 0.25 7,212 7,212 COMPZ RPCOM OWFF P Monitor well.Well continuing to take fluid. 22:45 00:00 1.25 7,212 5,070 COMPZ RPCOM TRIP P Trip out of hole standing Drill Pipe back in derrick. 38/08/2015 Continue TOOH. Lay Down BHA#54. No fish. Pick Up/RIH BHA#55. Lay Down BHA#55 and 4'of fish. PU and RIH with BHA#56(2 3/8"Grapple). POOH and Lay Down BHA#56, no fish. PU and RIH BHA#57(Burn SHoe to Mill Packer). Restriction encountered at 1966'dpmd. 00:00 01:30 1.50 5,070 303 COMPZ RPCOM TRIP P Trip out of hole with BHA#54. 01:30 01:45 0.25 303 303 COMPZ RPCOM OWFF P Monitor well.Well continuing to take fluid. 01:45 02:15 0.50 303 0 COMPZ RPCOM BHAH P Lay Down BHA#54. No fish. Inspect Overshot, indications that overshot shroud could have been hitting top of patch and patch never entered overshot or got to grapple. Contact CPAI Engineer. Go in again with BHA#55 and use rotation and more robust efforts to get over top of fish. 02:15 02:45 0.50 0 0 COMPZ RPCOM SVRG P Service Top Drive. 02:45 03:00 0.25 0 303 COMPZ RPCOM BHAH P Pick Up and Re-Run BHA# 55...re-run of BHA#54 03:00 05:15 2.25 303 7,278 COMPZ RPCOM TRIP P Trip in hole with BHA#55. Page 30 of 38 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 06:30 1.25 7,278 7,280 COMPZ RPCOM FISH P Work to engage fish(lower part of tubing patch). Up Wt= 163, Dn\M= 102k, Rot Wt= 123k, Free Tq 7k,20 rpm,2 bpm, 220 psi. Set down 5k-11k on top of fish at 7278'dpmd while rotating 5-20 rpm. Observe —2.0'-2.5'of further movement into hole to 7280'dpmd. Pull up and attempt to see if any further drag observed, minimal if any. Pull fish all the way out of packer and put back into packer but see no indication of any tag or resistance as entering Packer,tag bottom at same depth of 7280'. Pump at 2 bpm 200 psi to attempt to see differential pressure indication of fish on. Pressures do not clearly indicate any change. Continue to tag bottom at same depth indicating Top of Fish at 7278' dpmd and potentially swallowed—2' into overshot and grapple. 06:30 10:00 3.50 7,280 303 COMPZ RPCOM TRIP P Trip out with BHA#55, standing back the 3 1/2"Drill Pipe in the Derrick. Up Weight= 162K. BHA at surface. 10:00 11:15 1.25 303 0 COMPZ RPCOM BHAH P Set back Drill Collars. Lay down BHA#55.. Recovered 4-ft of the "rotten"PAtch in 3 pieces jammed up inside of the Overshot. Discuss plan forward with Anchorage Engineer. 11:15 11:45 0.50 0 303 COMPZ RPCOM BHAH P Make-up BHA#56...re-run of BHA #55. However now have a 2 3/8" Grapple in the Overshot Bowel. 11:45 15:15 3.50 303 7,281 COMPZ RPCOM TRIP P Trip in with BHA#56 on 3 1/2"from the Derrick. 15:15 15:30 0.25 7,281 7,281 COMPZ RPCOM FISH P Up weight= 160K. Down weight= 100K. RPMs=25,free spin torque =6,200 ft/lbs, pump rate 2.75 bpm/280 psi. Tag the top of the Fish at 7,281-ft dpmd. Work Overshot over the Tubing Patch Fish as per the Baker Fisherman. Swallow to 7,286. Pressure increased to 350 psi. Pulled 10K over string weight. Dragged for 3-ft. Weight fell back to normal string weight. Prep to POOH. Present fluid loss= 12 bbls/hour. 15:30 19:00 3.50 7,281 303 COMPZ RPCOM TRIP P Trip out with BHA#56, standing back the 3 1/2"Drill Pipe in the Derrick. Up Weight= 162K. BHA at surface. 19:00 20:30 1.50 303 0 COMPZ RPCOM BHAH P Lay Down BHA#56. No fish.Take BHA apart and look inside. Indication of swallowed fish that then came off. Page 31 of 38 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 0 0 COMPZ RPCOM RURD P Clean and Clear Rig Floor. Prep for new BHA. Contact CPAI Engineer, Baker Fishing and Baker completions. Decision made to Mill Packer with extension above packer mill. 21:00 22:30 1.50 0 360 COMPZ RPCOM BHAH P Pick Up BHA#57(6 1/8"Washover shoe for milling packer.Washover shoe,Washover boot basket, 2 boot baskets, bumper sub, oil jar,drill collars(x9)and intensifier. Total Length 359.71' 22:30 00:00 1.50 360 1,966 COMPZ RPCOM TRIP P Trip in hole with BHA#57. Observed tight spot at 1966'dpmd. 08/09/2015 POOH and LD BHA#57. PU and RIH BHA#58(Burn Shoe without Washpipe extension). Drift to—2550'. POOH and LD BHA#58. PU and RIH BHA#59(2 1/8"grapple). Fish patch/debris. POOH and LD BHA#59 and fish(5.25'piece of patch). PU and RIH BHA#60(2 1/8"grapple). Fish patch/debris. TOOH with BHA#60 and fish. 00:00 01:30 1.50 1,966 360 COMPZ RPCOM TRIP T (After multiple attempts to by pass (restriction Contact CPAI Engineer and Discuss plan forward.Trip out of hole. 01:30 02:15 0.75 360 0 COMPZ RPCOM BHAH T Lay Down BHA#57. 02:15 03:00 0.75 0 331 COMPZ RPCOM BHAH P Pick Up BHA#58 which is the same BHA without the Washpipe above the Packer Mill Burn Shoe. New BHA length 331.08' 03:00 04:00 1.00 331 2,604 COMPZ RPCOM TRIP P Trip in hole with BHA#58. Observe tight spot which took 3-4k at 1970' dpmd. Continue in to 2604'to drift past 04:00 05:30 1.50 2,604 331 COMPZ RPCOM TRIP P Trip out of hole with BHA#58. minor drag observed passing 1970'dpmd. 05:30 06:00 0.50 331 0 COMPZ RPCOM BHAH P Lay Down BHA#58. 06:00 06:30 0.50 0 0 COMPZ RPCOM SVRG P Inspect and service Top Drive. 06:30 07:30 1.00 0 0 COMPZ RPCOM WAIT T Overshot Grapples from Baker Fishing Tool Shop in Deadhorse. 07:30 08:30 1.00 0 307 COMPZ RPCOM BHAH P Make up BHA#59 as follows: Cut-Lip Guide, 5 3/4"Overshot w/2 1/8"Grapple, Overshot Extension, Top Sub, Bumper Sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4" Drill Collars,XO Sub. 08:30 11:30 3.00 307 7,286 COMPZ RPCOM TRIP P Trip in with BHA#59 with 3 1/2"Drill Pipe from the Derrick. 11:30 12:30 1.00 7,286 7,286 COMPZ RPCOM FISH P Up Weight= 160K. Down Weight= 100K. RPMs=25, Free Spin Torque =6,100 fUlbs. Tag top of the Fish at 7,286-ft. Plant overshot. Ease up hole to 10K over. Continue to ease up in 5K increments to 45K over string weight(205K). Slack back down and cock the Jars. Begin to jar Fish. After 4 Jar cycles...Fish came free or broke off. Prep to POOH. Page 32 of 38 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:30 15:30 3.00 7,286 307 COMPZ RPCOM TRIP P Trip out with BHA#59, standing back the 3 1/2"Drill Pipe in the Derrick. 15:30 1 16:15 0.75 307 0 COMPZ RPCOM BHAH P BHA at surface. Set back Drill Collars. Lay down BHA. Recovered 5-ft of the Tubing Patch. Total cum recovered =9-ft. (Fish remaining to the Packer top—11-ft). 16:15 16:15 0.00 0 311 COMPZ RPCOM BHAH P Make up BHA#60 as follows: Cut-Lip Guide, 5 3/4"Overshot w/2 1/8"Grapple, 2 ea Overshot Extension,Top Sub, Bumper Sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4" Drill Collars,XO Sub. 16:15 19:45 3.50 311 7,250 COMPZ RPCOM TRIP P Trip in with BHA#60 on 3 1/2"Drill Pipe from the Derrick. 19:45 21:00 1.25 7,250 7,286 COMPZ RPCOM FISH P Fish remaining tubing patch. Up Wt =158k, Dn Wt: 104k, Rot Wt= 124, 10 rpm, Free Tq=7500 ftlbs. 3 bpm /340 psi. Slide down without rotation with pumps on and observe pressure build to 400 psi at top of fish 7284' dpmd. Pull off and pumps off, slide down and see weight at same spot. Pull off without grabbing fish.go down on fish at 10 rpm, once engaged slack off and see a further swallow of—2'. Pull up to engage and overpull 20k. Slowly build to straight pull of 50k over. begin wiht light hits of jars building to 70k hits. after multiple hits and working engaged fish for 30 minutes with jars of increasing intensity followed by straight pull indication that fish either came free or piece broke off. 21:00 21:15 0.25 7,286 7,286 COMPZ RPCOM OWFF P Monitor well.Well continues loosing fluid. Contact CPAI Engineer. Decision to try and get onto fish while still on bottom for potentially more fish. Then TOOH and make next run packer mill with exstension. 21:15 21:30 0.25 7,286 7,286 COMPZ RPCOM FISH P Attempt to engage fish beneath previously caught fish.Attempts with 10 rpm going down and setting up to 10k down. No significant overpull indicating no new fish attached. 21:30 00:00 2.50 7,286 2,500 COMPZ RPCOM TRIP P Trip out of hole. 10k-12k overpull 1 noted on trip out form 7100'-7080' dpmd 08/10/2015 TOOH and LD BHA#60 and fish. PU and TIH with BHA#61 (Burn Shoe with extension to mill packer). Mill Packer. TOOH and LD BHA#61. Rig Up and test Upper VBRs from shut in during packer milling. PU and TIH with BHA#62(Packer Short Catch). 00:00 01:30 1.50 2,500 311 COMPZ RPCOM TRIP P Trip out of hole with BHA#60 and fish. Page 33 of 38 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 311 0 COMPZ RPCOM BHAH P Lay Down BHA#60. Recover 4.5' piece of patch. Patch sticking up from packer—4-5'.This is small enough we can now mill the packer with burn shoe and extension. 02:30 03:00 0.50 0 0 COMPZ RPCOM SVRG P Service Top Drive and Drawworks. 03:00 04:00 1.00 0 338 COMPZ RPCOM BHAH P Pick Up BHA#61. Burn Shoe and extension. 04:00 07:00 3.00 338 7,295 COMPZ RPCOM TRIP P Trip in with BHA#61. 07:00 09:15 2.25 7,295 7,295 COMPZ RPCOM MILL P Up Weight = 160K. Down Weight= 102K. RPMs=80. FST=7,300 ft/lbs. RTW= 126K. Pump Rate= 8.0 bpm/1,700 psi. Tagged the top of the Tubing Patch at 7,290-ft dpmd. Rotate over and swallow the Tubing Patch. Tagged the Baker DB Packer at 7,295-ft dpmd. Begin milling ahead at 80 rpms, 7,500 ft/lbs torque, pump rate 7.0 bpm/1,340 psi. Starting weight on Mill=3K. (SIMOPS: add 1 drum of Safe-Lube and De-Foamer to the system. mix Hi-Vis sweep to pump when needed ). 09:15 09:45 0.50 7,295 7,279 COMPZ RPCOM MILL P Progress: Milled over the Packer 18". Torque spikes pump pressure spikes. Packer can move up but not down(friction bite). 5K on Mill. Continue to cutting out the bottom slips. Present fluid loss while milling =30 bbls/hr. 09:45 10:15 0.50 7,279 7,279 COMPZ RPCOM KLWL T While milling the Packer,we observed an increase in flow and some gas that came to surface that was trapped below the Packer. Shut in Well with the Upper Pipe Rams to secure the well. Notified all the proper authorities. Allow pressure to stabilize. 10:15 12:30 2.25 7,279 7,279 COMPZ RPCOM KLWL T SIWHP=50 psi. Bleed gas cap through Gas Buster. Circulate Well with Sea Water at 3.0 bpm/305 psi. Total volume pumped=290 bbls. Fluid loss during circulating =34 bbls. 12:30 12:45 0.25 7,279 7,279 COMPZ RPCOM KLWL T Monitor Well. Fluid dropping. 12:45 16:15 3.50 7,279 7,279 COMPZ RPCOM MILL P Resume milling operations. 80 RPMs, 6,425 ft/lbs of torque, pump rate=7.0 bpm/1,055 psi, 5K on Mill. Top Drive issues have developed (possible bearing) End rotating Prep to POOH. 16:15 19:30 3.25 7,279 338 COMPZ RPCOM TRIP P Trip out with BHA#61, standing back the 3 1/2"Drill Pipe. Page 34 of 38 I 41111 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:30 1.00 338 0 COMPZ RPCOM BHAH P Lay Down BHA#61, Mill completely spent with no carbide left on leading edge. Retrieve lots of milled up pieces of dies from boot baskets. 20:30 21:00 0.50 0 0 COMPZ RPCOM BHAH P Clean and clear rig floor. Remove wear ring. 21:00 21:30 0.50 0 0 COMPZ RPCOM VWWVH P Clean wellhead and stack of any debris with stack jetting tool. 21:30 22:00 0.50 0 0 COMPZ RPCOM BOPE P Rig Up Test Equipment, set test plug _and fill stack and lines with water. 22:00 22:30 0.50 0 0 COMPZ RPCOM BOPE P Test top VBRs to 250/3000 psi per AOGCC and CPAI regulations for after use in well control. Good test. 22:30 23:00 0.50 0 0 COMPZ RPCOM BOPE P Rig Down testing equipment. Pull test plug and put in wear ring. 23:00 23:30 0.50 0 325 COMPZ RPCOM BHAH P Pick Up BHA#62(Short catch overshot to fish milled packer). 23:30 00:00 0.50 325 999 COMPZ RPCOM TRIP P Trip in hole with BHA#62. 38/11/2015 Continue to TIH with BHA#62(Packer Short Catch). Catch Packer and push to bottom. Pull above perfs and Circulate BU. POOH and lay down fish, packer and tail pipe recovered. Make up BHA#63 clean out assembly. Trip in hole to 7,415';work through tight spot at 7,117'. Slip and cut drilling line. Continue to trip in hole to 7,505. Pump high viscosity sweep and circulate hole clean. Pull out of hole laying down drill pipe to 3,697'. Daily losses to formation 202 bbls,total lost to formation 2,089 bbls. 00:00 03:00 3.00 999 7,282 COMPZ RPCOM TRIP P Continue trip in hole with BHA#62. UpVVt= 147k, DnVVt= 110k. 03:00 03:15 0.25 7,282 7,300 COMPZ RPCOM FISH P Attempt to engage packer/fish at 7282'.After setting down on it and picking up with no indication of drag attempted to set back down. NO indication of packer holding. 03:15 04:30 1.25 7,300 7,550 COMPZ RPCOM PULD P Continue pushing fish to bottom picking up Drill Pipe from the pipe shed. Process and strap drill pipe on the go. Continue to push packer to bottom with no indication via pumping or picking up of packer attached. Find resistance at 7550' (tail pipe at—7585). 04:30 05:30 1.00 7,550 7,045 COMPZ RPCOM TRIP P Trip out of hole until packer depth is above top perfs. 05:30 06:30 1.00 7,045 7,045 COMPZ RPCOM CIRC P Circulate bottoms up. No gas _observed at botoms up. 06:30 09:00 2.50 7,045 325 COMPZ RPCOM TRIP P TOOH standing back DP with BHA #62 from 7045'to 325'. 09:00 09:30 0.50 325 0 COMPZ RPCOM BHAH P Lay down BHA#62(Short catch overshot to fish milled packer). Recovered milled packer with tailpipe fish. 09:30 11:00 1.50 36 0 COMPZ RPCOM PULL P Release overshot, lay down milled packer with seal bore extension,and 2.25"'D'nipple with pups on each side plus shear out sub. 11:00 12:00 1.00 0 0 COMPZ RPCOM BHAH P Lay down overshot, clean out boot basket, and lay down boot basket. Page 35 of 38 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 13:00 1.00 0 317 COMPZ WELLPF BHAH P Pick up BHA#63-cleanout assembly. 6-1/8" Bit, (2)boot baskets,6.151"watermelon mill, Bumper sub, Oil Jars, pump out sub. Totalk BHA Length-317'. 13:00 15:00 2.00 317 7,117 COMPZ WELLPF TRIP P Trip in hole to 7,117', encounter tight spot. Set down 20K. 15:00 15:30 0.50 7,117 7,118 COMPZ WELLPF REAM P Pick up and establish parameters PUW 145K, SOW 109K, ROTW 122K. Free torque 5.5Kft-lbs at 15 rpms. Ream down at 80 rpms with 5.5-8.5Kft-lbs of torque,WOB 1-2K. Back ream back through tight spot. Slack off and observe 1-2K bobble. 15:30 16:00 0.50 7,118 7,415 COMPZ WELLPF TRIP P Continue to trip in the hole to 7415' 16:00 17:30 1.50 7,415 7,415 COMPZ WELLPF SLPC P Slip and cut 102'of drilling line. Long Cut 17:30 18:00 0.50 7,415 7,415 COMPZ WELLPF SVRG P Service rig; inspect draw works brakes. Inspect and service top drive. 18:00 20:00 2.00 7,415 7,505 COMPZ WELLPF CIRC P Trip in to 7,505'. Pump high viscosity sweep and circulate 1.5 X hole volume to clean hole. Blow down top drive. Monitor well for 10 minutes, static loss rate 7.5 bph. 20:00 00:00 4.00 7,505 3,697 COMPZ WELLPF PULD P POOH laying down drill pipe to 3,697' 08/12/2015 Continue to POOH with clean out assembly laying down drill pipe. Lay down BHA. Pull wear bushing. Rig up and run in hole with 3-1/2"completion as per detail to 7,367'. Spot 15 bbls of corrosion inhibited brine. Drop ball and road. Pressure up to 3500 psi to set FHL packers. Pick up and shear out PBR at 35K over. No-Go seal assembly. Space out seal assembly, make up tubing hanger and landing joint. Displace well to corrosion inhibited seawater. Daily fluid lost to formation 169 bbls,total lost to formation 2258 bbls 00:00 03:00 3.00 3,697 317 COMPZ WELLPF PULD P Continue to POOH laying down drill pipe to 317'. Monitor well at BHA for 10 minutes. 03:00 04:30 1.50 317 0 COMPZ WELLPF BHAH P Lay down drill collars, break out boot baskets and lay down, break out bit. 04:30 05:00 0.50 0 0 COMPZ RPCOM SVRG P Inspect and service top drive 05:00 05:30 0.50 0 0 COMPZ RPCOM RURD P BOLDS. Pull wear bushing. 05:30 07:00 1.50 0 0 COMPZ RPCOM RURD P Rig up to RIH with 3-1/2"completion. Rig up GBR, Finish loading pipe shed with packer assembly. 07:00 07:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM,with crew, Baker rep and mud engineer. Discuss safety and Hazard recognition issues. Discuss procedure to run 3 1/2" Completion assembly. 07:15 18:15 11.00 0 7,267 COMPZ RPCOM PUTB P Pick up and RIH with 3-1/2" completion as per detail to 7267'. PUW 90K, SOK 73K. Page 36 of 38 • Time Logs 4 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 19:45 1.50 7,267 7,267 COMPZ RPCOM CRIH P Make up head pin and circulate 20 bbls corrosion inhibited brine, spotting brine in the IA and tubing from WLEG to PBR. Pump corrosion inhibited brine from truck at 3 bpm 120 psi. 19:45 21:00 1.25 7,267 7,267 COMPZ RPCOM PACK P Drop ball and road and let fall for 15 minutes. Pressure up on tubing to 2000 psi, slack of 30K to counteract hydraulic pressure, continue to pressure up to 3500 psi and hold for 4 minutes. Bleed pressure. Pressure up on IA to test FHL packers-SOV sheared. Consult with town engineer. 21:00 23:00 2.00 7,267 6,922 COMPZ RPCOM HOSO P Pick up and shear out PBR at 35K over pick up weight. No-go seal assembly and calculate space out. Lay down partial joint and two full joints. Pick up and make up space out pups. Make up full joint above it and tubing hanger. 23:00 00:00 1.00 6,922 6,922 COMPZ RPCOM CRIH P Circulate corrosion inhibited fluid at4 bpm 350 psi. X8/13/2015 Continue to displace to corrosion inhibited seawater. Land tubing, RILDS. Rig up and CMIT T/IA to 3000 psi for 30 minutes-good. Rig down and monitor well. Set BPV and test to 1000 psi-good. Perform between wells maintenance on BOPE stack. N/D Stack, N/U tubing adapter and tree. PT tree and packoffs 250/5000 -good. Pull tree test plug,freeze protect well with 72 bbls of diesel. Set BPV. Secure well. R/D and prep to move to 1Y-17. Final pressures-OA-0; IA-0; T-0 Rig released at 23:59 hrs 00:00 01:00 1.00 6,922 6,922 COMPZ RPCOM CRIH P Continue circulating corrosion inhibited fluid at 4 bpm 350 psi. 01:00 01:45 0.75 0 0 COMPZ RPCOM THGR P Land tubing. RILDS 01:45 02:45 1.00 0 0 COMPZ RPCOM PRTS P Rig up and test tubing/IA to 3000 psi for 30 minutes-good. 02:45 03:15 0.50 0 0 COMPZ RPCOM RURD P Break out and lay down landing joint. 03:15 04:45 1.50 0 0 COMPZ RPCOM RURD P Rig down GBR equipment. Clean and clear rig floor. Monitor well while rigging down. 04:45 05:15 0.50 0 0 COMPZ WHDBO MPSP P Set BPV and test to 1000 psi from below,good. 05:15 06:00 0.75 0 0 COMPZ WHDBO WWWH P Pick up jet stacking tool. Jet BOPE stack 06:00 12:00 6.00 0 0 COMPZ WHDBO SVRG P Perform between wells maintenance on BOPE. Pick up joint of 3-1/2" DP. Shut annular on it on inspect annular. Bleed Accumulator and lock out. Pull Riser. Open ram doors and inspect rams. Change out top seal on blind rams. Install rams and close door. 12:00 14:00 2.00 0 0 COMPZ WHDBO NUND P Continue to nipple down BOPE and set back on stump Page 37 of 38 Time Logs 4 Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:00 16:30 2.50 0 0 COMPZ WHDBO NUND P Nipple up adapter flange, Nipple up tree. Test tubing hanger packoffs 250/5000 psi for 10 minutes-good. 16:30 17:00 0.50 0 0 COMPZ WHDBO MPSP P Pull BPV and set tree test plug. 17:00 18:00 1.00 0 0 COMPZ WHDBO PRTS P Test tree 250/5000 psi-good. 18:00 20:00 2.00 0 0 COMPZ WHDBO FRZP P Pull tree test plug. Rig up and freeze protect well with 72 bbls of diesel 2 bpm 950 psi. Allow to U-tube 20:00 20:30 0.50 0 0 COMPZ WHDBO MPSP P Install'IS-A' BPV. 20:30 21:30 1.00 0 0 DEMOB MOVE RURD P Rig down circulating lines and blow down. 21:30 22:30 1.00 0 0 DEMOB MOVE RURD P Secure tree, Remove secondary annulus valve. Install guages. Final pressure: OA-0; IA-0; T-0 22:30 00:00 1.50 0 0 DEMOB MOVE RURD P Clean out from underneath rotary table. Steam table. Prep for rig move. Page 38 of 38 �1Y-07 POST RIG WELL WORK 8/16/2015 SET BAITED P/T ON BALL & ROD @ 7330' SLM. PULLED SOV @ 6859' RKB, REPLACED WITH DV. MIT TBG 3000 PSI: PASSED. MIT IA 3000 PSI: PASSED (CHARTED). PULLED BALL & ROD, RHC PLUG BODY© 7355' RKB. COMPLETE. pry Loepp, Victoria T (DOA) From: Coberly,Jonathan <Jonathan.Coberly@conocophillips.com> Sent: Monday,August 10,2015 3:06 PM To: Loepp,Victoria T (DOA) Subject: FW: Nabors 7es Well Control Notice I _b Follow Up Flag: Follow up Flag Status: Flagged From: Nabors 7ES Company Man Sent: Monday, August 10, 2015 10:48 AM To: AOGCC(AOGCC.Inspectors@alaska.gov) Cc: Rauchenstein, Rock D; Coberly, Jonathan; Herbert, Frederick 0; Whitlock, Guy D (SolstenXP); Chapman, David J (SolstenXP) Subject: Nabors 7es Well Control Notice Gents; 1Y-07 Kuparuk River Unit...Nabors 7es. Operations in progress prior to the event: Milling up a Packer at 7,295-ft. Sea Water fluid loss while milling was 30 bbls/hr. At 09:40 hours,08/09/2015 we observed an increase flow and some gas to surface while milling up the Packer. The well was shut in with the Upper Pipe Rams. Stabilized shut in pressure, 50 psi. Pit gain, 12 bbls. No injuries or spills. Present status...slowly bleeding the gas cap through the Gas Buster. Once the pressure has dropped to zero psi we will circulate the well with Sea Water(bottoms up++)and monitor well for flow. At this point it is expected that we will be able to return to milling and complete the planned operation. Once we tripout of the hole with the millingassemblywe will test the Upper Pipe Rams at 250/3,000 si with a 3 pp pp Test Joint. 4774 Should you have further questions I can be contacted at 7247 or7844. Lee H. Lee Hinkel/ Edward Oglesby Rig Supervisor/Nabors 7ES Office 659-7844 Rig 659-7247 1 VIAy-o7 Pm i cb306 Regg, James B (DOA) From: Nabors 7ES Company Man <n2364@conocophillips.com> Sent: Monday, August 10, 2015 10:48 AM 'epci (4`6(6- To: ct(icTo: DOA AOGCC Prudhoe Bay Cc: Rauchenstein, Rock D; Coberly, Jonathan; Herbert, Frederick 0; Whitlock, Guy D (SolstenXP); Chapman, David J (SolstenXP) Subject: Nabors 7es Well Control Notice Gents; 1Y-07 Kuparuk River Unit...Nabors 7es. Operations in progress prior to the event: Milling up a Packer at 7,295-ft. Sea Water fluid loss while milling was 30 bbls/hr. At 09:40 hours, 08/09/2015 we observed an increase flow and some gas to surface while milling up the Packer. The well was shut in with the Upper Pipe Rams. Stabilized shut in pressure, 50 psi. Pit gain, 12 bbls. No injuries or spills. Present status...slowly bleeding the gas cap through the Gas Buster. Once the pressure has dropped to zero psi we will circulate the well with Sea Water(bottoms up++) and monitor well for flow. At this point it is expected that we will be able to return to milling and complete the planned operation. Once we trip out of the hole with the milling assembly we will test the Upper Pipe Rams at 250/3,000 psi with a 3%2" Test Joint. Should you have further questions I can be contacted at 7247 or 7844. Lee H. Lee Hinkel/ Edward Oglesby Rig Supervisor/ Nabors 7ES Office 659-7844 SC.01E© Rig 659-7247 1 p7`D /83 —G‘, Loepp, Victoria T (DOA) From: Coberly,Jonathan <Jonathan.Coberly@conocophillips.com> Sent: Tuesday,July 21, 2015 4:40 PM To: Loepp, Victoria T (DOA) Cc: Packer,J.Brett; Nabors 7ES Company Man Subject: RE: 1Y-07 Update PTD 183-068 Attachments: 1Y-07 (PTD# 183-068) Sundry Well Info (AMENDED).pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for the review. Here is the amended RWO program outline. Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1504) Anchorage,AK 99501 Phone:907.265.1013 SCORED AUG 1 3 2 01 , Celt:907-538-8398 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov1 Sent: Tuesday, July 21, 2015 4:01 PM To: Coberly, Jonathan Subject: [EXTERNAL]RE: 1Y-07 Update PTD 183-068 Jonathan, Please send me the amended procedure. The plan forward outlined below is approved. Please include PTD# in subject line in the future. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCaaalaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoe@alaska.gov 1 From: Coberly,Jonathan [mailto:Jonathan.Coberly@)conocoDhillips.com] Sent:Tuesday, July 21, 2015 3:41 PM To: Loepp, Victoria T(DOA) Cc: Packer, J.Brett Subject: 1Y-07 Update Victoria, We encountered subsidence damage in the production casing while pulling the original completion tubing through the damage. This resulted in us cutting the tubing above the SSSV and recovering the tubing and control line from the SSSV to surface. There is currently a tested plug in the production casing at 1,761' MD above the SSSV and remaining completion tubing. Substantial helical buckling has been measured down to 1,600' MD. A TOC in the 7"x 9-5/8" annulus was not located above the plug in the production casing. To minimize risk I currently plan on amending the submitted procedure(sundry#315-333)to cut and pull production casing from 1,642'—1,726'to surface instead of locating TOC and tying back from that point. I will continue the sundried plan, running casing and cementing back to surface,from that point forward. Please let me know if you have concerns with this plan. Thank you, Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1504) Anchorage,AK 99501 Phone:907-265-1013 Cell:907-538-8398 2 1 Y-07 Rig Workover, Subsidence and Upper Selective Repair (AMENDED) (PTD #: 183-068) Current Status: The well is currently shut in post workover setup tubing cut awaiting a RWO. Scope of Work: (1)Pull Completion String,(2)Repair Subsidence Damage,(3)Pull and Replace Upper Selective, and(4)Run New Tubing. General Well info: MPSP: 1,828 psig(using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Combined Kuparuk A,B&C-Sands—2,433 psig/6,052' TVD (7.8 ppg EMW)measured 11/27/2014. Wellhead type/pressure rating: FMC KRU Gen II Retrofit,7 '/16°5M Top x 11"3M Bottom Nabors 7ES BOP Configuration: Annular/VBR /Blind Rams/Mud Cross/VBR(or 7") MIT results: MIT-IA—Pass(4/14/2015) MIT-T—Pass(5/13/2015) MIT-OA—Failed(7/20/2009);Passing SCLD(10/12/2013) Well Type: Miscible Gas/Water Injector Estimated Start Date: July 11,2015 Production Engineer: David Lagerlef/David Haakinson Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly@conocophillips.com) Proposed Procedure: Pre-Rig Setup: 1. RU DSL. Cut tubing at 6,961' MD. RDMO DSL. Set BPV. RWO Procedure: 1. MIRU. Pull BPV. Circulate killweight fluid. Install BPV. ND Tree. 2. Install blanking plug. NU BOPE and test to 3,000 psig. Pull the blanking plug. Pull the BPV. 3. BOLDS. Attempt to pull completion tubing. Unable to pull. Land tubing on tubing stub. 4. RU E-line and cut tubing above SSSV. PU tubing—2 jts. RU E-line and run IBP above SSSV in production casing. Dump sand on IBP. POOH with tubing. 5. RIH and fish control line. RIH to sand top w/old tubing to ensure hole is clean. POOH. 6. RU E-line. Run CBL and caliper. No TOC located above casing plug. Run casing cutter. Unable to drift damaged casing. RDMO E-line. 7. Remove tubing head. Cut excess casing growth, re-land the casing in slips, and NU BOPE. (Cannot test BOPE until the 7"casing is pulled due to failing MIT-OA). 8. RIH on DP to drift casing and dump more sand on IBP. RIH and cut casing above sand top. POOH with casing. Cut and fish sections of production casing if unable to pull all at once. Mill surface casing as necessary to fish production casing. Shell test BOPE to 3,000 psig. 9. RIH and remove any surface casing restrictions to the production casing stub with string milling assemblies. 10. RIH with cementer drift/mill and dress off the production casing stub. TOOH. 11. RIH and engage casing assembly onto the casing stub. Land the casing in slips. PT the casing. 12. Cement behind the production casing to surface. PT the cement plug. NFT. a. 5 bbl fresh water b. XX bbls ARCTICSET* 1 (calculated annular volume+ 100%excess;PressureNet added) c. Displace w/2 bbl ARCTICSET* 1 d. 5 bbls fresh water followed by XX bbls of seawater as displacement fluid 13. ND BOPE. Cut excess casing. Install packoff. NU new tubing head and BOPE. Shell test the BOPE to 3,000 psig. 14. RIH and mill cement plug. TOOH. PT the casing. RIH and dry mill remaining debris. TOOH. 15. RIH and cleanout sand. TOOH. RIH and release IBP/RBP. TOOH. 16. RIH and fish remaining completion tubing to tubing stub. 17. RIH and fish tubing stub. TOOH. RIH and retrieve packer and upper selective completion. TOOH. 18. RIH and fish remaining tubing patch equipment from lower selective completion. TOOH. 19. RIH and cleanout to the lower packer. POOH. 20. RIH and land new upper selective completion and completion tubing. Space out and circulate corrosion inhibitor. Set the packer. PT the IA. 21. Shear the PBR. Space out the pipe. Circulate corrosion inhibitor.Land the hanger and RILDS. 22. PT the tubing. PT the IA. Shear the SOV. NFT. 23. Install BPV. PT BPV. ND BOPE. 24. NU the tree. Pull BPV. Install tree test plug. PT tree and packoffs. 25. Freeze protect. Set BPV. 26. RDMO. Post-Rig Wells Work: 1. Pull BPV. 2. RU Slickline: a. Pull ball and rod. b. Pull SOV and install DV. c. Pull RHC plug. PTD /83- 06,g Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Tuesday,June 16, 2015 2:03 PM To: Coberly,Jonathan (Jonathan.Coberly@conocophillips.com) Subject Well KRU 1Y-07 RWO(PTD 183-068, Sundry 315-333) Revised BOP Test Pressure Jonathan, Please revise the BOP test pressure on the approved Sundry to 3000 psig. Include this revision with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 SCANNED jUL 0 I -U 15 Work. (907)793-1247 Victoria Loepp@alaska gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo©alaska.aov 1 • OF Ty ' w\���//jy',v THE STATE Alaska Oil and Gas of7ThC KIA Conservation Commission ;Eit#x_;_ _= 333 West Seventh Avenue BILL WALKER Anchorage, Alaska 99501-3572 , Main: 907 279 1433 O44'ALAS16'3' Fax 907.276 7542 R Q ‘G`, www.aogcc alaska.gov Jonathan Coberly Nl" `1 JL `► Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1Y-07 Sundry Number: 315-333 Dear Mr. Coberly: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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 J?day of June, 2015 Encl. STATE OF ALASKA �\`L,`( f. ,KA OIL AND GAS CONSERVATION COM, ;ION rt)(''' \ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request. Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing F, Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r- Change Approved Program r Rug for Redrill r Perforate New Pool r CrfiCA- 1, air Well 1 . Re-enter Sus Wellr Other Repair subsidence damage 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc: Exploratory r Development r 183-068' 3.AddressStratigraphic r Service r;, , 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-029-20950-00 . 7.If perforating, 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception') Yes r No F..7 KRU 1Y-07 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25646 - 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): 8210 6674 8099' 6575' none 7614' Casing Length Size MD TVD Burst Collapse Conductor 48' 16" 78' 78' Surface 2219' 9.625" 2249' 2206' R E C I V S D Production 8150' 7" 8180' 6651' „� �/ MAY 2 2015 AO CC Perforation Depth MD(. 7091'-7218', Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7242-7262,7395-7402,7415-7456,7478-7496. 5926-6006,6021-6033,6113-6117,6125-6149,6163-6174 3.5 x 2.875 J-55 7336 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-CAMCO HRP-1 SP PACKER • MD=6999 TVD=5864 PACKER-BAKER'DB'PACKER % MD=7300 TVD=6056 SSSV-CAMCO TRDP-1A • MD=1803 TVD=1796 12.Attachments: Description Summary of Proposal Fr, 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r- Exploratory r Stratigraphic r Development r Service p-. 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work' 6/14/2015 OIL r VVINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG F, • GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265-1013 Email: Jonathan.Coberlv@conocophillips.com Printed Name Jonathan Coberly/ Title. Sr. Wells Engineer Signature tji D Phone:265-1013 Date C-27-ZO/5 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315-337- Plug (5-?33,Z,Plug Integrity r BOP Test l'`Mechanical Integrity Test f ' Location Clearance r Other. sop it -' 35-00 )>5 r (A/1. P5 P 15 /825 l)5, ) . , f-a tz w ,'th 7-55x6/ A4) 7-- //i /"--- v metol' , 7Ctt r la- bi'lr (/ l fl 1:1:--, j [2(Spacing Exception Required? Yes ❑ No � Subsequent Form Required: /7- y G' 9- 411°/ APPROVED BY I ,2 1 u , G Approved by: COMMISSIONER THE COMMISSION Date: ! A v a Il for 12 month ttr9m the date of approval. Submit Form and �� Form 10-403 Revised 5/2015 U a II v Attachme"�sLn Duplicate vrL 6/i2-/r5- ,Il, .b7 4- RBDMS3 JUN 1 5 2015 RECEIVED Irry MAY 272015 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 26,2015 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Foerster: ConocoPhillips Alaska, Inc.hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 1Y-07(PTD: 183-068). Injector 1Y-07 was spud in 1983 as a single packer commingled Kuparuk A&C Sand producer. A rig workover in 1985 installed a selective completion. In 1986 the well was converted in injection and in 1988 a second rig workover replaced the tubing and retrofitted the wellhead to a 5,000 psi rated system to allow for gas injection. In 2006 it is theorized that the selective began to leak making the injection into the C- sand uncontrollable and the leak was patched. In 2007 the C-sand injection mandrel washed out and injection into the C-sand was once again incontrollable. In 2009 it was noticed that a dummy 2.78" OD WRP would no longer drift the tubing past 164' RKB. Multiple drift attempts since then resulted in many passing and failingdrift runs with 2.69"OD dummyWRP's and other sizes. Prior to beingshut in the well P g injected an average of 6,000 BWPD into mostly the Kuparuk C-sand. With currently passing MIT-IA SCLD, and MIT-T's there are no known containment issues that would keep this well from injection. The objective of this workover is to be a proactive workover to repair the leakier selective and to repair the subsidence damage prior to not being unable to drift the tubing if subsidence gets much worse. The tubing will be pulled,the subsidence damage will be repaired,the upper selective will be pulled,and an upper selective and new tubing will be installed. If you have any questions or require any further information,please contact me at 265-1013 or Jonathan.Coberly@conocophillips.com. Sincerely, Jonathan Coberly Senior Wells Engineer ConocoPhillips Drilling and Wells 1Y-07 Rig Workover, Subsidence and Upper Selective Repair (PTD #: 183-068) Current Status: The well is currently shut in post workover setup tubing cut awaiting a RWO. Scope of Work: (1)Pull Completion String, (2)Repair Subsidence Damage, (3)Pull and Replace Upper Selective, and(4)Run New Tubing. General Well info: MPSP: 1,828 psig(using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Combined Kuparuk A,B&C-Sands—2,433 psig/6,052' TVD (7.8 ppg EMW)measured 11/27/2014. Wellhead type/pressure rating: FMC KRU Gen II Retrofit,7 1/16"5M Top x 11"3M Bottom Nabors 7ES BOP Configuration: Annular/VBR /Blind Rams/Mud Cross/VBR(or 7") MIT results: MIT-IA—Pass(4/14/2015) MIT-T—Pass(5/13/2015) MIT-OA—Failed(7/20/2009);Passing SCLD(10/12/2013) Well Type: Miscible Gas/Water Injector Estimated Start Date: June 14,2015 Production Engineer: David Lagerlef/David Haakinson Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly@conocophillips.com) Proposed Procedure: Pre-Rig Setup: 1. RU DSL. Cut tubing at 6,961' MD. RDMO DSL. Set BPV. RWO Procedure: 1. MIRU. Pull BPV. Circulate killweight fluid. Install BPV. ND Tree. 2. Install blanking plug. NU BOPE and test to 3,000 psig. Pull the blanking plug. Pull the BPV. 3. BOLDS. Pull completion tubing. 4. RU E-line. Locate TOC, caliper the damaged casing, and set an IBP/RBP 50' above the upper packer and 500' below the TOC in the surface casing. Cut the casing above the TOC. Confirm circulation. RDMO E- line. 5. RIH and circulate sand on top of plug. POOH. Circulate through casing cut to cleanup Arctic Pack. Conduct 30 minute NFT. ND BOPE. 6. Remove tubing head. Cut excess casing growth, re-land the casing in slips, and NU BOPE. (Cannot test BOPE until the 7"casing is pulled due to failing MIT-DA). 7. POOH with casing. Shell test BOPE to 3,000 psig. 8. RIH and remove any surface casing restrictions to the production casing stub with string milling assemblies. 9. RIH and dress off the production casing stub. TOOH. RIH and drift the casing assembly. TOOH. 10. RIH and engage casing assembly onto the casing stub. Land the casing in slips. PT the casing. 11. Cement behind the production casing to surface. PT the cement plug. NFT. a. 5 bbl fresh water b. XX bbls ARCTICSET* 1 (calculated annular volume + 15 bbls excess; PressureNet added as needed based on surface casing damage found or created) c. Displace w/2 bbl ARCTICSET* 1 d. 5 bbls fresh water followed by XX bbls of seawater as displacement fluid 12. ND BOPE. Cut excess casing. Install packoff. NU new tubing head and BOPE. Shell test the BOPE to 3,000 psig. 13. RIH and mill cement plug. TOOH. PT the casing. RIH and dry mill remaining debris. TOOH. 14. RIH and cleanout sand. TOOH. RIH and release IBP/RBP. TOOH. RIH and release next IBP/RBP. 15. RIH and fish tubing stub. TOOH. RIH and retrieve packer and upper selective completion. TOOH. 16. RIH and fish remaining tubing patch equipment from lower selective completion. TOOH. 17. RIH and cleanout to the lower packer. POOH. 18. RIH and land new upper selective completion and completion tubing. Space out and circulate corrosion inhibitor. Set the packer. PT the IA. 19. Shear the PBR. Space out the pipe. Circulate corrosion inhibitor.Land the hanger and RILDS. 20. PT the tubing. PT the IA. Shear the SOV. NFT. 21. Install BPV. PT BPV. ND BOPE. 22. NU the tree. Pull BPV. Install tree test plug. PT tree and packoffs. 23. Freeze protect. Set BPV. 24. RDMO. Post-Rig Wells Work: 1. Pull BPV. 2. RU Slickline: a. Pull ball and rod. b. Pull SOV and install DV. c. Pull RHC plug. ConocoPhillips Well: 1 Y-07 2015 RWO PROPOSED COMPLETION API: 500292095000 1 7 L PTD: 183-068 "�/ ct v�.C� Wellhead: RetroFitted FMC Gen II Tree: 3 1/8"5M .4_ HES 7"Cementing Valve Conductor: 16"62.5#H-40 Welded to 78'RKB 611'111' Fes,►/ F— Baker 7"Overshot Casing Patch Surface Casing: ,er 9 5/8"40.0#J-55 BTC to 2,249'RKB �,+�tirj //���� Production Casing: " 7"26.0#K-55 BTC from TOC to 8,180'RKB 7"26.0#L-80 TC-Il to TOC(SC) Production Tubing: 3-1/2"9.3#J-55 BTC AB-Mod ' 4—CAMCO 1-1/2"MMG GLM Perforations: MD Zone 7,091'-7,218' C 1-3 0.--11 4—20'Baker PBR w/80-40 GBH-22 LTSA 10 7,247-7,262' B C. 4—20'Baker FHL Retrievable Packer 7,395'-7,402' A 5 4—CAMCO 1-1/2"MMG GLM 7,415'-7,456' A 4 4— CAMCO 1-1/2"MMG GLM 7,476-7,496' A 3 SS 4— Baker CMU Sliding Sleeve w/2.813"'BX'Profile Directional: =I Joy;is I= 4— 3 1/2"Blast Joints(7) Max Incline: 53.9° = Blast I Joints I= 4—3 1/2"Blast Joints(2) Max Dogleg: 15.3°/tcoFT 4—Crossover,2 7/8"x 3 1/2" M„C I— Baker'DB'Packer w/SBE Last Tagged Fill: 7,415'SLM WV Baker 2 7/8"LTSA Total Depth: 8,210'RKB D .4—CAMCO 2.25"ID'D'Nipple SOS 4—2 7/8"Shear-out Sub Updated by: J.Coberly 5/27/2015 ;:;:2ZZ;;_ `C' KUP INJ 1Y-07 Conor Philhip5 Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status net(°) MD(ftKB) Act Btm(ftKB) r„",,,41,,;,,1„ 500292095000 KUPARUK RIVER UNIT INJ 53.93 7,400.00 8,210.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 19-07,12/1020146:55:03 PM SSSV:LOCKED OUT Last WO: 1/9/1988 35.011 5/15/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,414.0 11/27/2014 Rev Reason:GLV C/O lehallf 12/10/2014 iLt Casing Strings +I. i` Casing CONDUCTOR Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WWt/Len(I...Grade Top Thread _ _ 16 15.062 30.0 78.0 78.0 6250 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread HANGER.298 r 0'5 L SURFACE 95/8 8.835 29.5 2,249.4 2,206.2 40.00 J-55 BTC '�, r�, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 30.1 8,179.5 6,651.3 26.00 K-55 BTC ..• ... , urn Tubing Strings Tubing DescriptionMa...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lbr t) Grade Top Connection TUBING 3.5x2.875" 1 String 31/21 2.9921 29.81 7,336.61 6,078.1 9.301 J-55 11PCBTCABMOD • 30.0-78.04-s ,, Completion Details CONDUCTOR;30,0-7e.o Nominal ID Top(ORB) Top(ND)(ftKB) Top Inc)(°) Item Des Com (in) p® 29.8 29.8 0.01 HANGER FMC TUBING HANGER 3.500 SAFETY VLV;1,803.3 1,803.3 1,796.7 18.14 SAFETY VLV CAMCO TRDP-1A SSSV(LOCKED OUT 10/20/2009) 2.812 411 • 6,977.5 5,849.0 46.40 SBR CAMCO OEJ SBR 2.813 • 6,999.1 5,863.9 46.40 PACKER CAMCO HRP-1SP PACKER 2.859 7,076.4 5,916.0 48.81 BLAST RINGS BLAST RINGS(5) 3.500 • 7,236.5 6,017.6 52.07 BLAST JT BLAST JOINT(1) 3.500 • SURFACE;29.5-2,249.44---41 ., 7,273.5 6,040.2 52.64 NIPPLE AVA'BPL'NIPPLE PATCHED OVER 2.750 7,286.4 6,048.0 52.84 XO-Reducing CROSSOVER 3.5x2.875(ID 2.441",6.4#,J-55,EUE8rd 2.875 7,290.0 6,050.2 52.90 SEAL ASSY LOCATOR/SEAL ASSEMBLY 2.875 GAS LIFT;6,939.6 ;111 7,300.3 6,056.4 53.05 PACKER BAKER'DB'PACKER WITH Sbr 3.250 7,324.2 6,070.7 53.26 NIPPLE CAMCO'D'NIPPLE NO GO 2250 II SBR;6,977.5 7,335.9 6,077.7 53.37 SOS SHEAR OUT SUB-ELMD TTL @ 7330'during(PROF on 2.441 • 10/7/2002 PACKER:6.999, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ORB) (°) Des Com Run Date ID(in) ' INJECTION;7,038.5 7,229.0 6,013.0 51.95 PATCH SET BAKER 35 KB STADDLE PATCH ASSEMBLY I, 11/42006 1.595 THE LOWER SECTION:35 KB SNAP LATCH PROFILE(2.31"G FM)SPACER PIPE,&AVA • SEAL UNIT(45.66'LONG)SET INTO THE D NIPPLE @ 7324'RKB.UPPER SECTION:35 KB UPPER STRADDLE PACKER(2.31"G FIN) • IPERF;7,091.0-7218.0- _ SPACER PIPE,&35 KB SNAP LATCH COLLET(NO ' PINS IN SNAP LATCH)31.92 LONG STUNG INTO THE LOWER ASSEMBLY @ 7261'SLM.TOP @ • 7246.6'rkb ,•7.614.0 6,247.9 50.18 FISH 5"Vann Gun 484.57'Long c 1983 0.000 Perforations&Slots Shot Dens IPERF;7,242.0-7,262.0- Top(TVD) Btm(TVD) )shotslf _ - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com • 7,091.0 7,218.0 5,925.6 6,006.2 C-3,C-2,C-1, 6/8/1983 12.0 IPERF 5"Geo-Vann;120 deg. UNIT B,1Y- Ph PATCH;7,229.0 07 NIPPLE;7,273.5 7,242.0 7,262.0 6,021.0 6,033.2 UNIT B,IY- 6/8/1983 12.0 IPERF 5"Geo-Vann;120 deg. 07 Ph 7,395.0 7,402.0 6,112.7 6,116.9 A-5,1Y-07 6/8/1983 12.0 IPERF 5"Geo-Vann;120 deg. Ph 7,415.0 7,456.0 6,124.6 6,149.2 A-0,IY-07 6/8/1983 12.0 IPERF 5"Geo-Vann;120 deg. SEAL ASSY;7,290.0 Ph PACKER;7300.3 7,478.0 7,496.0 6,162.6 6,173.7 A-3,1Y-07 6/8/1983 12.0 (PERF 5"Geo-Vann;120 deg. • - Ph Mandrel Inserts St all on Top(TVD) Valve Latch Pod Size TRO Run r`i Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com NIPPLE;7,324.2 1 6,939.6 5,8225 CAMCO 'MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 1/10/1988 830 a 2 7,038.5 5,890.8 MERLA TMPD 1 INJ OPEN 0.000 12/9/2014 8:00 Notes:General&Safety SOS:7,3359 . End Date Annotation 6/13/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 12/15/2010 NOTE:RECOVERED PIECES OF SEVERELY ERODED CV@7039RKB 10/31/2013 NOTE:RECOVERED SEVERELY ERODED CV@7039RKB J IPERF;7.395.0.7,102.0- r IPERF;7,415.S-7,456.0---, 1 IPERF;7,478.0-7,496.0- FISH;7,614.0 PRODUCTION;30.1-5179.5-a kt3- °Col 2- ,k`6 WELL LOG TRANSMITTAL DATA LOGGED (D/2/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 5, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 H'( 1 201 AOG C RE: Plug Setting Record: 1Y-07 Run Date: 4/28/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22368-00 SCANNED JUN 1 2 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ✓ctv / ,/ age Project Well History File~er Page 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: -' : ~. Logs of various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: E~EVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Scanning Preparation ~ x30=~flO + = TOTALPAGES qD BY: Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ' frO PA.,C.~ COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES .Y: Stage 2 IF NO IN STAGE '~, PAGE(S} DISCREPANCIES WERE FOUND: YES BY: BEVERLY BREN VINCE~ MARIA LOWELL (SCANNING IS COMPLETE AT THiS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (ind~vidu~l pa,.'..~e [Spec~! attentto* ] ~car ni~.:~ completed) NO NO IIIIIIIIIIIIIIIIII RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ General Notes or Comments about this file: Quality Checked • MEMORANDUM TO: Jim Regg P.I. Supervisor ~~ 7 ~~ ~ (~`~ FROM: Lou Grimaldi Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 30, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPAII.LIPS ALASKA INC 1 Y-07 KUPARLJK RI V iJNIT 1 Y-07 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv ._,J'~ Comm Well Name: KUPARUK RIV UNIT 1Y-07 Insp Num: mitLG090703141953 Rel Insp Num: API Well Number: 50-029-20950-00-00 permit Number: 183-068-0 / Inspector Name: Lou Grimaldi Inspection Date: 7/3/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Y-07 Type Inj. W TVD ssa~ ; IA 300 200o ts9o ~s9a P.T.D lsso6ao TypeTest SPT Test psi zooo pp iao iao tao ~ao _ Interval 4YRTST P~F' P ~ Tubing 1400 1400 1390 1390 - NOtes' 2•~ bbl's pumped, good four yeaz test M-ir~~ +~+ P~~sw-.~ +~ps, 4 13~~~ ({ ~ ~ ~' 1 ~ ..-;T 's'i v ly. .~, w~n { ._ Thursday, July 30, 2009 Page 1 of 1 • ConocoP hi~lips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 ,~~~~~~ ~~ ~ ~ $ ZQ~$ -~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • REC~~VE® AUG 2 5 ZOQ8 Alastca pit & Gas Cons. COR'}, ~,=',;SlOn Anchor~~a ~~s3-o~8 _~_, Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle ~ ~ Z ~~C~ ~ ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date Well 2H-05 185-168 2H-17 200-019 2K-27 201-169 2M-03 191-141 1 B-14 194-030 1B-18 194-061 16-19 194-064 1 B-20 203-115 1 B-101 203-133 1B-102 203-122 1 Y-05 183-087 1Y-07 183-068 1 Y-17 193-068 1 Y-22 193-070 1Y-26a 188-116 1 Y-30 188-090 1 E-112 204-091 1E-119 204-031 1 E-121 1 E-123 204-246 204-074 Initial top of cement Vol. of cement um ed Final top of cement Cement top date ft bbls ft SF N/A SF N/A 6" N/A 6" N/A 10" N/A 10" N!A 16" N/A 16" N/A SF N!A SF N/A SF N/A 21" N/A 3" N!A 4" N/A 6" N/A 6" N/A SF N/A SF N/A SF N/A SF N/A 14" N/A 14" N/A 6" 5" N/A N/A 9" N/A SF N/A 21" N/A 3" N/A 4" N/A 6" N/A 6" N/A SF N/A SF N/A SF N/A SF N/A 14" N/A 14" N/A 6" N/A 8/17/2008 Corrosion inhibitor Corrosion inhibitor/ sealant dat al 5.10 8/2/2007 1.27 8/2/2007 8.92 8/2/2007 2.13 8/2/2007 1.70 8/13/2008 8.07 8/13/2008 5.10 8/13/2008 5.95 8/13/2008 1.00 8/17/2008 1.00 8/17/2008 1.27 8/13/2008 1.27 8/13/2008 1.27 8/13/2008 2.12 8/13/2008 3.83 8/13/2008 3.83 8/13/2008 5.95 8/17/2008 4.67 8/17/2008 1.00 8/17/2008 1.00 8/17/2008 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~`~- ~1~ MAY ~. ~ 200 Log Description NO. 4678 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 04/30!08 3K-102 NA PRODUCTION PROFILE 04!08/08 1 1 1 E-04 11996622 LDL ~ "'t D - ~( 04/16/08 1 1 2U-13 11996617 PRODUCTION PROFILE - at( 04/10/08 1 1 2W-17 11996618 SFRT - 04/12/08 1 1 2L-330 11970662 PERF/SBHP _ ~ 04/19/08 1 1 3F-18 11970666 LDL - G' 04/23/08 1 1 iD-130 11964595 LDL _C ~- 04/23/08 1 1 1Y-07 11964596 INJECTION PROFILE -~ / 'a 04/24/08 1 1 2T-217A 11970667 INJECTION PROFILE ..p ! 6~0 (`j 04/24/08 1 1 iF-05 11964597 INJECTION PROFILE j 69 "- 04/25/08 1 1 3K-102 12021157 MEM PROD PROFILE j 04/26/08 1 1 1 L-09 11970669 PRODUCTION PROFILE t.( 04/26/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • l . . WELL LOG TRANSMITTAL RECEIVED '~\/Ir' (J q '.'.'. (I[.ll' " I,'J '.' ., (. ) ProActive Diagnostic Services, Inc. ~ Qn & Gas Gons. Commission Anchorage To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1) 1 BL / EDE Disk 2) 3) 4) 5) 6) 7) Signed: ~-~ 1 Y - 07 13-Aug-06 Caliper Report 5(;ANNED AUG ;) 02005 Date : 1r/00, ( f) h Print Name: ~ \ Á P ~ r~ [". (¡t {¡ .(¿ Itl PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAG~@MEMORYLOG.COM Us~ 1~3 -00"6 WEBSITE: WWW.MEMORYLOG.COM 0:\00 ]OSANC-2006\Z _ W ordlDistribution\TransmittaL Sheels\Tl1II1smit _ Origina1.doc ~ ¡'Vo "63 I I I I I I I I I I I I I I I I I I I ~:r c, t'Í5'3 -0<0'5 1t/'-/0'ð:3 . RECEIVED Memory Multi-Finger Caliper AUG 2 9 2006 Log Results Summary ~askaOlI & Gas Cons. CommiI8ion Anchorage Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: ConocoPhillips Alaska, Inc. August 13, 2006 6596 1 3.5" 9,3 lb. J-55 Tubing 2,875" 6.5 lb. J-55 Tubing Well: 1Y-07 Field: Kuparuk State: Alaska API No.: 50-029-20950-00 Top Log IntvI1,: Surface Bot. Log Intvl1,: 7,286 Ft. (MO) Top Log Intvl1.: 7,286 Ft. (MD) Bot. Log Intvl1.: 7,327 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the bottom of 2.875" Tubing @ 7,327' (Driller's Depth). This log was run to assess the condition of the 3.5" and 2.875" tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing is in good condition with respect to corrosive damage, with the exceptions of 30% and 26% penetrations in joints 182 (5,680') and 149 (4,655'). The damage appears mainly in the form of isolated pitting. No significant areas of cross-sectional wall loss are recorded throughout the 3.5" tubing logged. The caliper recordings indicate a moderate bend in the upper body of joint 7 (-220'), with a recorded minimum I.D. of 2.83". Corrosive damage is recorded below the ports in the A V A Nipple Assembly (7,274]. A 3-D log plot of the recordings for the Nipple assembly is included in this report. The caliper recordings indicate the 2.875" tubing is in good condition with respect to corrosive damage. No significant wall penetrations, areas of cross-sectional wall loss, or I. D. restrictions are recorded throughout the 2.875" tubing interval logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Isolated Pitting ( 30%) ( 26%) Jt. Jt. 182 @ 149 @ 5,680 Ft. (MD) 4,655 Ft. (MD) No other significant wall penetrations (> 17%) are recorded throughout the 3.5" tubing logged. 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the 3.5" tubing logged. 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: Moderate Bend Minimum 1.0. = 2.83" Jt. 7 @ 220' Ft. (MD) No other significant I.D. restrictions are recorded throughout the 3.5" tubing logged. PmActíve Diagnostic Services! Inc / P.O. Sox 1369, Stafford! TX 77497 Phone: or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS(Q)memorylog.com Prudhoe Sav Field Office Phone: 659-2307 Fax: 659-2314 I I I I I I I I I I I I I I I I I I I . . 2.875" Tubing- MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 11%) are recorded throughout the 2.875" tubing logged. 2.875" Tubing - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 2%) are recorded throughout the 2.875" tubing logged. 2.875" Tubing - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the 2.875" tubing logged. I Field Engineer: N. Kesseru Analyst: M. Tahtouh Witness: T Senden I ProÞ,ctiveDiagnost¡c Sen/¡ces; Inc Phone: (281) or (888) 565-9085 Fax: Prudhoe Fiê.id Office Phone: 1369; 77497 565-1369 E-maíJ: PDS@memorylog,com 659-2307 Fa>c 659-231.4 I I I Well: Field: Company: Country: I Tubing: Nom.OD 3.5 ins I 1Y-07 Kuparuk ConocoPhillips Alaska, Inc. USA Weight 9.3 f Grade & Thread -55 I penetration body Penetration and Metal loss ('Yo wall) metal loss body I 250 200 150 100 50 0 o to 1% I I 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% pene. loss o o I 20 Damage Configuration ( body ) I I 10 I o isolated generdl line ring hole / poss pitting corrosion corrosion corrosion ible hole I I o I I I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 2.992 ins August 13, 2006 MFC 24 No. 99628 1.69 24 M. T ahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins lower len. 1.2 ins Damage Profile (% wall) penetration body o 1 metal loss body 50 100 GlM 1 Bottom of Survey = 231.5 Analysis Overview page 2 I I I I I I I Pup Jt. 231.2 I I I AVA Nipple Assembly w/lsolation Sleeve Corrosion below the Ports. I I I I I Pup Ji. 231.4 I I I I 1 1274 7215 7276 u n 3 Inc. 1Y-07 Date' 13,2006 Detail of Across the A VA at .....~~1>~....jJ, {)¡ ~ 6 ß&OO Min ID (:laoon II:!) I PDS REPORT JOINT TABULATION SHEET I I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: lY-07 Kuparuk ConocoPhillips Alaska, Ine. USA August 13, 2006 I Joint Jt. Depth Pen Pen. Pen ¡Vîetal Min. Damage Profile No. (Ft.) Body 1.0. Comments (%w all) (Ins) (Ins.) (Ins.) 0 50 100 1 15 0.01 2.90 1.1 46 0.02 2.92 II 1.2 56 0.03 2.88 Slight Slio Mash uoner bodv. II 2 64 0.01 2.91 3 95 0 0.01 2 2 2.88 4 126 0 0.01 f 4 2.93 5 157 0 0.03 1D 3 2.94 6 188 0 0.02 2.92 7 218 n 0.03 2 2.83 Moderate Bend unner bodv. 8 250 n 0.02 2.92 9 280 n 0.03 2.93 10 309 () 0.01 2.93 11 338 0 0.03 12 î 2.95 12 370 0 0.01 , 4- 2.92 13 402 0 0.01 , 4- 2.91 14 433 0 0.01 , 2 2.93 15 463 n 0.01 f 4- 2.91 16 495 n 0.03 11 :¡ 2.95 17 526 0 0.02 9 ¡ 2.95 18 557 0 o~tuj 2.92 19 588 0 0.01} 2.89 20 617 0 0.0 2.93 21 646 0 0.0 2.92 22 678 ) 0.0 2.94 23 708 ! 0.01 2.92 24 740 ) 0.01 2.92 25 771 ) 0.01 2.92 26 801 0 0.02 6 4 2.91 27 833 0 0.01 2.93 28 865 0 0.01 2.93 29 896 n 0.01 2.91 30 926 n 0.02 2.95 31 957 n 0.03 ) 2.92 32 989 ( 0.02 9 2.92 33 1020 ( 0.01 4- ) 2.94 34 1052 0 0.01 5 ¡ 2.94 35 1083 () 0.02 ( 2.96 36 1115 0 0.01 I 2.93 37 1145 n 0.01 ¡ 2.94 38 1176 I 2.93 39 1207 ( I 0.02 2.95 40 1239 ( 0.01 2.96 41 1270 ( 0.03 1 2.92 Shallow nittirw. 42 1301 () 0.01 4 2.92 43 1330 () 0.03 ! 1 2.95 44 1360 () 0.02 q 2.92 45 1389 () 0.03 III 2.94 46 1420 () 0.01 I 5 ) 2.92 47 1451 0 0.03 I 10 2 2.92 48 1482 0 0.ü1 I 4 2 2.91 I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 1Y-07 Kuparuk ConocoPhillips Alaska, Inc. USA August 13, 2006 I I I Joint Jt. Depth F'en, Pen. Pen, Meidl Min. Damage Pro file No. (Ft.) pset Body I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 49 1513 0.02 2.91 50 1543 0.02 2.94 51 1575 0.03 2.94 Shallow nittinQ. 52 1606 0.03 2.93 Shallow nittinQ. Sliqht Slin Mash lower bod". 53 1638 0 0.02 () 2 2.91 54 1670 0 0.01 5 2.93 55 1700 0 0.02 q 2.93 56 1731 0 0.04 2.94 Shallow nittinp'. ~ 57 1763 {I 0.01 2.91 57.1 1794 {I 0 ( 2.81 SSSV TRDP-1 A 58 1805 0 0.02 2.92 59 1837 0 0.03 2.92 Shallow nittir]Q:. 60 0 0.03 12 2 2.94 Shallow nittinQ. 61 1899 0 0.01 2.94 62 1930 0 0.02 2.87 63 1961 0 0.02 2.91 64 1992 {I 0.02 2.87 65 2022 () 0.02 2.87 Lt Denosits. 66 2054 () 0.02 2.88 67 2084 0 0.02 7 ì 2.92 68 2116 0 0.01 4 ì 2.92 69 2148 0.02 fì 2.91 70 2179 0.03 I 2.90 71 2210 0.04 I' 2.88 Shallow nittinq. I 72 2240 0.02 2.90 Lt. Denosits. 73 2272 0.02 2 2.89 74 2303 0.02 ì 2.90 75 2334 0 0.02 2.92 76 2365 U 0.02 2.91 77 2396 0 0.02 ( 2.92 78 2426 () 0.01 2.91 79 2456 ) 0.02 2.92 80 2486 I 0.02 2.91 81 2517 0.02 2.90 82 2548 0.02 7 2.90 83 2579 0 0.01 6 2.90 84 2611 0 0.01 ;:fti 85 2642 0 0.02 86 2673 0 0.02 2.92 87 2705 0 0.01 2.91 88 2735 0 0.01 2.91 89 2767 0 0.01 {) 2 2.93 90 2798 0 0.01 "' 2.92 91 2830 0 0.01 "' 2.93 92 2861 0.02 2.95 93 2891 0.03 2.93 94 2922 0.03 2.93 95 2954 0.02 8 7 2.92 96 2984 0.03 13 2 2.93 Shallow oittinq. 97 3015 0 0.02 () J 2.94 I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1Y-07 Kuparuk ConocoPhiilips Alaska, Inc. USA August 13, 2006 I I I Joint Jt. Depth 'Ce" ~ Pen. VIf·tal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (Ins) ) (Ins.) 0 50 100 98 3046 2.93 ~ 99 3076 2.94 '" 100 3107 0.01 2.93 w 101 3139 0.02 2.89 ~ 102 3168 0 0.02 6 2.81 103 3200 :> 0.02 2.88 Slight SliD Mash lower body. 104 3231 0 0.03 10 2 2.91 105 3262 0.04 2.91 Shallow oitting. ~ 106 3294 0.02 2.91 107 3326 0.02 2.93 108 3357 0.03 ] 2.92 109 3387 0.02 2.92 110 3417 Q 0.02 9 4 2.90 111 3449 0 0.03 ] 2.94 112 3479 0 0.02 2.94 113 3511 0 0.02 2.94 114 3542 0 0.02 !.92 I: Sh"low olltioo. 115 3573 0 0.02 116 3605 0 0.02 117 3635 0 0.04 17 3 iii! 118 3667 0 0.01 5 2 2.90 119 3696 0.ü3 12 2.94 120 3727 0.01 2.90 121 3758 0.02 2.93 122 3790 0.02 2.90 Lt. Denosi ts. 123 3821 0.03 ] 2.90 124 3852 0.02 2.87 125 3883 0 0.02 2.93 126 3915 Q 0.01 t 2.91 127 3946 0 0.01 2.87 Lt. Deposi ts. 128 3979 0 0.02 2.92 129 4010 0.02 2.87 130 4040 0.02 2.91 131 4071 0.02 8 2.91 132 4102 0.01 ') 2.89 133 4133 0 0.02 8 3 2.89 134 4165 ( 0.01 2.92 135 4196 0.02 2.91 136 4228 0.02 2.89 137 4259 ( 0.02 2.89 138 4290 ( 0.01 2.89 U. DeDosi ts. 139 4320 0 0.01 2 2.91 140 4352 0 0.01 2.89 141 4383 0 0.02 2.94 142 4415 0 0.02 t 2.92 143 4447 0 0.02 ( 2.88 144 4478 0 0.02 ( 2.86 145 4510 0 0.02 7 2 2.94 146 4542 0 0.02 9 3 2.91 Slight SliD Mash UDDer body. 147 4573 () 0.02 9 2 2.90 I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I PDS REPORT JOINT TABULATION SH I I I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: lY-07 Kuparuk ConocoPhillips Alaska, Inc. USA August 13, 2006 I I I I Joint Jt. Depth Pen Pen. Pen i'vli,tid Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 148 4604 Ii 0.02 ( 149 4635 :J Wf Ii 2.90 Isolated nitting. Lt. Denosits. 150 4666 2.91 151 4698 ! 0.01 2.90 ~o 0.02 2.92 1 4761 0.02 2.90 1 12 0.01 4 2.91 155 4824 0.04 15 2.91 Shallow nittino. 156 4855 0 001 s 2.91 157 4885 0 0.02 q 2.87 158 4916 0 0.03 2.91 159 4946 0 0.01 2.92 160 4976 Ii 0.02 ì 2.89 161 5007 0 0.02 j 2.90 162 5038 0 0.03 W t±tlD 163 5070 0 0.02 164 5100 Ii 0.01 2.89 165 5130 Ii 0.02 2.88 166 5160 Ii 0.01 2.86 167 5190 Ii 0.02 ('; t 2.90 168 5221 0 0.02 (, t 2.89 169 5252 0 0.02 9 J 2.91 170 5283 0 0.03 W 2.90 171 5315 0 0.02 B 2.91 172 5345 ! 0.03 1 2.88 173 5375 ( 0.02 2.89 174 5405 0.02 2.89 175 5437 ! 0.01 1 2.89 176 5468 ! 0.01 ( ;; 2.92 177 5500 0 0.02 5 2.88 178 5530 0 0.02 ¡ 2.89 179 5559 0 0.02 2.90 I HiO 5590 Ii 0.ü1 2.90 181 5621 0 0.02 2.88 11.. 182 5653 0 0.07 '·in ( 2.88 Isolated nitting. 183 5684 0 0.02 ) 2.89 184 5715 0 0.02 9 2.89 185 5746 0 0.02 2.91 186 5777 0 0.02 2.90 187 5808 ! 0.04 S 2.89 Shallow nitting. 188 5838 I 0.02 2.92 189 5869 I 0.01 2.89 190 5900 ! 0.02 4 2.88 191 5931 0 0.02 ß 4 2.90 192 5962 0 0.01 2.92 193 5994 0 0.03 0 2.90 194 6025 0 0.02 2.89 195 6056 () 0.01 2.90 196 6088 Ii 0.02 2.89 197 6118 0 0.02 6 ;; 2.90 I I I I I I I I I Body Metal Loss Body Page 4 I I I I PDS REPORT JOINT TABULATION SH I I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf j-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: lY-07 Kuparuk ConocoPhiiJips Alaska, Inc. USA August 13, 2006 I I I I I I joint jt. Depth PC'! Pen. PerL I :Vletal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (In;;,) (Ins.) (Ins.) 0 50 100 198 6149 0 0.02 a 2.91 199 6181 0 0.02 2.90 200 6213 I) 0.04 'ì 2.88 Shallow nittinQ. 201 6244 0.02 2.92 202 6275 0.02 2.89 203 6307 0.03 :; 2.91 204 6338 0.02 I 2.92 205 6370 0.02 m 2.91 206 6401 0 0.01 2.88 207 6432 0 0.02 2.91 208 6464 I) 0.02 2.89 ?Oq 6495 I) 0.02 ') 2.88 210 6526 I) 0.02 I 2.90 211 6557 I) 0.02 (, 2.88 212 6589 0 0.02 11 I 2.90 m (} 0.02 4 2.88 21 6651 0 0,02 2.89 21 6682 0 0.02 2.91 2 I) 0.02 2.91 217 6746=tl 0.02 2.91 218 6776 0.02 2.88 219 6807 0.03 1'1 (, 2.89 Shallow nittin\!. 220 6839 0 0.02 9 2.89 221 6870 I 0 0.03 10 2.87 222 6902 0 0.04 !'\ 2.85 Shallow nittinº. 222.1 6933 0 0 \ N/A GLM ILatch @ 9:00\ 223 6945 0 0.04 I 2.89 Shallow nittinQ. U. Denosits. 11II1 223.1 6974 0 0 \ N/A Packer Assemblv 224 7007 0 0.04 I 2.83 Shallow nittin\!. 11II1 224.1 7037 0 0 0 01 N/A Iniection MandrellLatch @ 8:30\ 225 7047 I) 0.02 9 2.87 226 7076 0 0.02 a 2.91 Blast t. 227 7107 0 0.01 2.90 Blast t. 228 7135 0 0.01 2.86 Blast t. ~ 7164 0 0.01 ;i 2.87 Blast t. 7194 0 0.02 9 I 2.87 Blast t. 230.1 7223 0 m 11 ') 2.91 PUP 230.2 7234 0 9 7 2.93 PUP 230.3 7237 0 10 2.93 PUP Blast It. 231 7245 0 .03 2.94 Blast It. 231.1 7267 I) 0.03 2.96 PUP 231.2 7272 0 0.02 2.93 PUP 231.3 7274 () 0 ! 2.75 A V A Ninnle. Corrosion below the norts. 231.4 7276 () 0.03 10 ') 2.94 PUP 231.5 7286 0 0 () () N/A CROSS OVER I I I I I I I I I Body Metal Loss Body Page 5 ------ Well: Field: Company: Country: Tubin : 1Y·07 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f J·55 - ---.... .. .. PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: August 13, 2006 MFC 24 No, 99628 1.69 24 M. Tahtouh Cross Section for Joint 182 at depth 5679.874 ft Tool speed = 49 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 92 % Tool deviation = 40 0 Finger 21 Penetration = 0,075 ins Isolated Pitting 0,08 ins = 30% Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. .. ------ ------- - -.... .. .. PDS Report Cross Sections Well: Field: Company: Country: Tubin : 1Y·07 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f ·55 Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: August 13, 2006 MFC 24 No, 99628 1.69 24 tV\. Tahtouh Cross Section for Joint 149 at depth 4654.51 7 ft Tool speed = 51 NominallD = 2,992 Nominal OD = 3.500 Remaining wall area = 98 % Tool deviation = 46 0 Finger 3 Penetration = 0.065 ins Isolated Pitting 0,07 ins 26% Penetration HIGH SIDE UP Cross Sections page 2 I I I Well: Field: Company: Country: 1Y·07 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 2.875 ins Weight 6.5 f Grade & Thread ·55 I Penetration ami Metal loss (% wall) I penetration body metal loss body 10 I I 0 o to 1 10 to 20 to 40 to to over 1% 10% 20% 40% 85% 85% pene. 0 0 loss 0 0 I I I Damage Configuration ( body ) 10 I I o I isolated pitting general line ring hole / pass corrosion corrosion corrosion ible hole I o I I DS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: August 13,2006 MFC 24 No, 99628 1.69 24 M. T ahtouh Nom.ID 2.441 ins Nom. Upset 2.875 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) penetration body o o Bottom of Survey = 0.3 Analysis Overview page 2 I I metal loss body 50 100 I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I Joint Jt. Depth No. (Ft.) .1 7286 .2 7290 .3 7300 .4 7304 .5 7314 .6 7316 .7 7327 I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION EET 2.875 in 6.5 ppf J-55 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: PUP Locator Sub PACKER PUP DNi Ie PUP END OF LOG Page 1 lY-07 Kuparuk ConocoPhillíps Alaska, Inc. USA August 13, 2006 Comments Damage Profile (%wall) o 50 100 Body Metal Loss Body I KRU 1Y -07 I I 1"(,,0'1 API: 500292095000 Well Type: INJ Angle (1ìJ TS: 49 deg (1ìJ 7092 ,. SSSV Type: TRDP Orig Completion: 5/15/1983 Anole ® TO: 43 dea ® 8210 Annular Fluid: LastW/O: 1/9/1988 Rev Reason: Pull Sieve, Set SSSV Paekoff Assv ( 1803-1804, Reference Loa: Ref Loa Date: Last Update: 3/1312006 00:3.500) Last T ao: 7445 TO: 8210 ftKB ~S' Max Hole Anole: 54 deo ® 7400 escn tlon Ize Top ~ Bottom TVD Wt Thread CONDUCTOR 16.000 0 78 62,50 H-40 Gas Lift SUR. CASING 9.625 0 2203 40.00 I J·55 , ndrellDummy PROD CASING 7.000 0 8180 6635 26.00 I K·55 Valve 1 (6940-6941, IUDI!'!!\::! 00:5.750) Size I Too I Bottom I TVD I Wt I Grade I Thread ~72~6 7286 6031 9,30 J·55 I BTC AB·MOD 7327 6055 6.50 J·55 I EUE 8RD SBR Jim (6977·6978, It Interval TVD Zone Smtus Ft Date TVDe Comment 00:3.500) 7091·7218 5909 . 5989 C·3,C·2,C·1, 127 12 6/8/1983 IPERF 5" Geo·Vann; 120 deg, Ph B 7242 - 7262 6004·6016 UNITB 20 12 6/8/1983 IPERF 5" Geo·Vann; 120 dea. Ph 7395 . 7402 6096 - 6100 A·5 7 12 618/1983 IPERF 5" Geo·Venn; 120 dee. Ph 7415·7456 6108·6133 A-4 41 12 6/8/1983 IPERF 5" Goo·Vann; 120 deo, Ph PKR 7478·7496 6146·6157 A·3 18 12 618/1983 IPERF 5" 120 deg. Ph (6999-7000, Gas 00:6.156) St MD I TVD IMan Mfr Man Type I V Mfr I V Type I V OD I latch I TRO I Date I Vlv Run Cmnt ~ManTypel DMY 1.5 RK 0 1/1011988 Injection V Mfr I V Type I V 00 I latch I Port I TRO I Date I Vlv , ndrellDummy Run Cmnt Valve 2 - I DMY I 1,0 I BK I 1.000 0 9/13/1990 Closed (7038-7039, < 00:5.313) DeDth TVD Tvpe Descriotion ID -.- 1803 1795 SSSV Cameo TRDP-1A 2.812 TUBING (0-7286, - 6977 5832 SBR Cameo OEJ 2,813 00:3.500, - 6999 5847 PKR Cameo HRp·1SP 2.859 10:2.992) - 7258 6014 PACKOFF K3, EXT.PIPE 116112", XO, ISO SLEEVE, OAL 177", SET PACK OFF ON K·3; .;JVV Perf ~ ASSY SLlPSTOP ®7259 ON TOP OF PACKER· set 2111/2006 (7242·7262) 7273 6023 NIP AVA BPL PORTED NIPPLE 2.750 7290 6033 SEAL Baker SEAL ASSEMBLY 3.000 7291 6034 PKR Baker 'DB' wI Seal Bore Ex!. 3.250 PACKOFF 7315 6048 NIP Cameo '0' Nioole NO GO 2.250 ASSY 7326 6055 SOS Cameo 2,441 (7258-7273, ~TTl 2.441 00:2.875) / NIP Depth DescriDtion I Comment (7273-7274, 7614 5" Vann Gun 1484,57' Lona 00:4:453) Dam Note SEAL 7/31/1998 BPI au lied was badlv eroded. (7290-7291, 00:2.875) NIP (7315-7316, 00:2.875) TUBING (7286-7327, 00:2,875, 10:2:441 ) SOS (7326-7327, 00:2.875) Perf - r-- (7395-7402) - f--- - - f--- - r-- == Perf - (7415-7456) == Perf = F== - 1--' (7478-7496) -. i--- .-- r-- - f--- - f--- 5" Vann Gun (7614-8099, 00:5.000) I I I I I I I I I I I I I I I I Sc~luIIIbepgep NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,.~ ~~\'l\.~E~; ~~~j t. .. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1/-;(:::\.. _A/ ~ U I ~ t v '-_ 0x:J 0 Field: Kuparuk Well Job# Log Description Date BL Color CD '"'0 J,....)' ,J 1 E-1 92 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-1i)5L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1 F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04106 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1 D-10'1 N/A INJECTION PROFILE 06/27/06 1 2Z-1J 11249930 LDL 07/11/06 1 1 D-1 06 N/A INJECTION PROFILE 06/26/06 1 2M-21 . 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e STATE OF ALASKA ~ OIL AND GAS CC)NSERVATION COMMI,.%~i~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate / Pull tubing Alter casing Repair well Othe J 5. Type of Well: 6. Datum elevation (DF or KB) <"1 %1 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development Exploratory Stratigraphic Service Location of well at surface 571' FNL, 1851' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1339' FSL, 1687' FWL, Sec. 1, T11N, R9E, UM At effective depth 671' FSL, 1493' FWL, Sec. 1, T11N, R9E, UM At total depth 598' FSL, 1472' FWL, Sec. 1, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8210 6656 feet feet RKB 96 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-07 9. Permit number/approval number 83-'86 ~' ~¢, 10. APl number '~ ' ' 5o-0;~9-20950 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8 0 9 9 true vertical 6575 feet feet Junk (measured) Vann Gun 485' long, top @ 7614' Casing Length Structural Conductor 7 8' Surface 2 21 4' Intermediate Production 81 4 7' Liner Perforation depth: measured 7091 '-7218', true vertical 5910'-5989', Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth 16" 251 SX AS II 78' 78' 9 5/8" 900 AS III & 2248' 2203' 25O SX AS I 7" 940 SX AS I & 81 78' 6635' 103 SX AS I 7242'-7262', 7395'-7402', 6004'-6017', 6095'-6099', 7415'-7450', 6107'-6128', 7478'-7496' 6144'-6156' 3.5", 9.3#, J-55 @ 7286', 2.875, 6.5#, J-55 @ 7286'-7327' Packers and SSSV (type and measured depth) PKR: Camco HRP-1SP @ 6999' & Baker DE, @ 7291'; SSSV: Camco TRDP-1AF, I~.C~_1.8~3_' _ _ 13. Stimulation or cement squeeze summary 14. KELI:IVI:U Converted well from water injection to MWAG injection on 11/25/92. Intervals treated (measured) N/A JUN 2 5 1993 Treatment description including volumes used and final pressure Alaska 011 & bas bU(l$. ~,u,~rnissi0 N/A Reoresentative Daily Averaae Production or Iniection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation -0 1 0 8 0 0 -0- 1450 3200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Suspended Service MWAG In!ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P AGE 1 ,. ¢,~v: WELU REPORT FOR DRILLSiTE !Y F'iq,';}DUCTT. ON t~JELL :-:~TP~'TUS ~AS LIFT STATUS S/'~ IMPACT ....................... C N C 7" 10" OAS INJ AH H M' 0 ~ c' "¥ T' Cut~: CSG METER VOI_S L I R I D ..... ~.: , , ~ :A~INe MSCF' E8 ~ N E - . . - ...... !gZ i16 i!2 ~.A 50 I200 700 80' 0 1~7 O 0000 (] 0 .... o i ~ ~; uO0 74 'o-iai9 0 0000 0 0 ~'. .... ~o,~ 1200 90 0 2135 0 0000 0 0 ........ 0000 O' i9i lO0 ~, ~ s¢~ 900 700 6~ 0 0 0 0000 0 0 i76-'i76 ~'7 .5 ~.0' {50 -6'00- ...... &O ............ 0--;3&'7 0 0000 '0 0 !~2 lla i~4 ,<n-_,..~ .¢~"',~, 1!00- - ~00 70 0 1343 0 0000 0 0 18:5 176 ¢_!6 ~..'l, 65 ' !360 "eOb ....... 74 ....... o' '946 0 "0000 0 0 0 0 0 75 68 950 150 0 0 0 0 2400 74 1783 4~su, 0 0 0 0 0000 ,~=.-~ ~76~ ;.*-:~,~:-~.~ 78 8,~, ~ ...... I000 0 0 .............................. ? "!' 3'7 t !' -;':', ?; i ~. l:' :? :' .... 0 ..... 1'0'. 3i8 0000 0 . 432 O. 000 0000 0 O- 2. 796 0000 ~ 0 3733 0 000 OOC, O C, .. 'O 0 0 000 2400 26 0 0 4 861 0000 0 ~::::7.::.,,' 0 d, 0 ~ ~' 0,.'3 500 ':; 0 '0 'bOO ",400 = '~ ': -'~' '-' '40 0 ' '4 5 49 0 ,~ ...... ~ 219~ :~5;2 iOO 930 ' 0 '0 000 0000 ;:!!q~) :.:', ..... :,7~ 'OC; -3qs,-', .SOn 0 7679 0 OOC, ,.qO{~,? c'~ 1783 r'QT-¢:.h C.: RECEIVED k&o '1 _Y'- 2 k-&o _ ................................ l~ ~O ARCO Alaska, Inc. Date: September 7, 1988 RETURN TO: Transmittal #: 7285 ARCO Alaska,/nc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3F-13 3K-18 3B-13 '3Q-15 3N-08A ~ 3H-14 1E-12 ~ 3K-14 '31-03 1Y-06 1Y-07 Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report KuParuk Well Pressure Report Kuparuk Well Pressure Report Please acknowledge receipt and return 8 - 2 7- 8 8 Casing 8 - 2 7 - 8 8 Tubing 8 - 2 6 - 8 8 Casing 8 - 2 7- 8 8 Casing 8 - 2 6 - 8 8 Casing 8 - 2 6 - 8 8 Casing 8 - 2 6 - 8 8 Casing 8 - 2 6 - 8 8 Casing 8 - 2 6 - 8 8 Casing 8 - 2 6 - 8 8 Both Sands 8 - 2 6 - 8 8 Sand 'A' Receipt Acknowledged: D&M State of Alaska , Anchorage Chevron Unocal Mobil SAPC ALASKA O~'L AND GAS CONSERVATION CO,v~MISSION WI=LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well \ OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ - · WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-68 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20950 . 4. Location of well at surface 9. Unit or Lease Name 571' FNL, 1851' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1399' FSL, 1687' FWL, Sec. 1, TllN, R9E, UM 1Y-7 At Total Depth 11. Field and Pool 598' FSL, 1472' FWL, Sec. 1, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.}16.Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 96'I ADL 25646 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/05/83 05/13/83 06/08/83*[ N/A feet MSL[ 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8210'MD, 6656'TVD 8099'MD, 6575'TVD YES IX NO []I 1803 feet MD 1350' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal, CBL/CCL/GR/VDL, Gyro, CET 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 78' 24" 251 sx AS II 9-5/8" 40.0# J-55 Surf 2249' 12-1/4" 900 sx AS Ill & 250 s AS I 7" 26.0# K-55 Surf 8180' 8-1/2" 940 sx Class G & 103 ;x AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf 3-1/2" 7327' 6999' & 7291' 7091 '-7218'MD 5910'-5989'TVD 7242 ' -7262 'MD 6004 ' -6017 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7395'-7402'MD 6095'-6099'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7415'-7450'MD 6107 '-6128 'TVD 7340'-7342' 250 sx Class G 7478'-7496'MD 6144'-6156'TVD 7062'-7064' 100 sx Class G See Sundry notice ~ated 9/23/85. for fracture data. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.} t Date of Test Hours Tested PRODUCTION FOR O1L-BBL GAS-MCF WATER-BBL cHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ 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 "~' J'~L:, '']' - ,:-:';' .Al~:~,,a 0il & Gas · Note: Drilled RR 5/15/83. Squeezed, perforated well & tubing run 6/8/83. Workover~performed 7/8/85 & 1/9/88. Fractured we]] 9/10/85. Converted to water injector 10/26/85. WC~/Sc~ :DAN I Form 10-407 Submit in duplicat ac_v 7-1-RO CONTINUED ON REVERSE SIDE 29. 30. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 5907' 5984' 6088' 6207' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, 7090' 7210' 7382' 7577' GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-~zO~_~, "~'. ~,L~-'~ Title Associate Engineer ___ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 ,." ' STATE OF ALASKA ' ALA;- . OIL AND GAS CONSERVATION CON, oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Iq, Stimulate ~ Plugging i-i Perforate iq Pull tubing Alter Casing ~ Other Ix 1//ORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 96' Feet 3. Address 6. Unit or.PLoperty name P.O. Box 100360, Anchorage, AK 99510-0360 ~uparuK ~lver Unit 4. Location of well at surface 571' FNL, 1851' FWL, Sec. 1, T11N, RgE, UM At top of productive interval 1399' FSL, 1687' FWL, Sec. 1, T11N, RgE, UM At effective depth 671' FSL, 1493' FWL, Sec. 1, T11N, RgE, UM At total depth 598' FSL~ 1472' FWL~ Sec. 1~ T11N~ R9E~ UM 11. Present well condition summary Total depth: measured 8210'MD true vertical 6656'TVD feet feet 7. Well number 1Y-7 8. Approval number 7-945 9. APl number 50-- 029-20950 10. Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8099'MD true vertical 6575 'TVD feet feet Junk (measured) Vann Gun 484.57' long, top ~ 7614' Casing Length Size Conductor 78 ' 16" Surface 2214 ' 9-5/8" Producti on 8147 ' 7" Cemented Measured depth 251 sx AS II 78'MD 900 sx AS III & 2249'MD 250 sx AS I 940 sx Class G & 8180'MD 103 sx AS I ~ue Vertical depth 78'TVD 2203'TVD 6635'TVD Perforation depth: measured 7091 ' -7218 ', 7242 ' -7262 ' true vertical 5910'-5989', 6004'-6017' Tubing (size, grade and measured depth) ~-1/2", J-55, tbg w/tail 0 7327' Packers and SSSV (type and measured depth) HRP-1-SP pkr 0 6999', DB pkr ~ 7291' , 7395'-7402', 7415'-7450', 7478'-7496' , 6095'-6099', 6107'-6128', 6144'-6156' , & TRDP-1A SSSV @ 1803' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure ~. .... ~,~ Oil & G~s Cons. C0mmissi0~ Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well History) Daily Report of Well Operations ~1 Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW03/44 Date /-~[.~ Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are slarled. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field ARCO Alaska, Inc. ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25646 Title WORKO~BR KUPARUK RIVER UNIT Auth. or W.O. no. AK2840 IStatL 1Y-7 JWell no. API: 50-029-20950 Operator ~co Spudded or W.O. begun ~Date ACCEPT I 01/07/88 Date and depth as of 8:00 a.m. Ol/O8/88 ( TD= 8210 P~: 8099 sUPV:DL ? ' ol/o9/88 ( TD: 8210 PB: 8099 SUPV:DL Complete record for each day reported NORDIC 1 ARCO W.I. IHour I 56.0000 IPrior status if a W.O. 2200 NU 5000 PSI TBG HEAD MW:10.0 NaC1/BR MOVE RIG F/ 1Y-8 TO 1Y-7. ACCEPT RIG AT 2200 HRS 1/7/88. PULL BPV. DISPLACE WELL W/ 10.0 PPG BRINE. SET BPV. ND THEE. NU BOPE AND TEST SAME. PULL 2 STANDS TBG. HAND TBG OFF W/ HALLIBURTION STORM PKR. TEST PKR TO 500 PSI. ND BOPE AND LAND HEAD. DAILY:S23,833 CUM:$23,833 ETD:S23,933 EFC:$186,900 RIH WITH 3-1/2" TBG MW:10.0 NaCl/BR NO TUBING HEAD & TESTED TO 3000 PSI. NO BOPE & TESTED. RETRIEVED STORM PKR. POH & LD SAME. POH WITH 3-1/2" COMPLETION EQUIPMENT, CHANGED OUT COUPLINGS TO AB-MOD. SERVICED RIG. CONTINUED POH WITH 3-1/2" TUBING, GLM'S & OEJ. CHANGE OUT COUPLINGS TO AB-MOD. PULLED WEAR BUSHING. RIH WITH REDRESSED OEJ, i GLM WITH CU, & 3-1/2" TUBING. DAILY:S34,849 CUM:$58,68~ ETD:S58,682 EFC:$187,000 The above is correct Signature ~V' J Date For form preparation and di~ltlji'ibution, see Procedures Manual, Sel~t~on 10 Dril n~, Pages 86 and 87. JTitle Associate Engineer ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code I County or Parish ARCO Alaska, Inc. I NORTH SLOPE AK Field ILease or Unit KUPARUK RIVER UNIT ITitle ADL: 25646 Auth. or W.O. no. I AK2840 J WORKOVER District Stale 1Y-7 J Well no. API: 50-029-20950 OperatorARCO JA.R.Co. W.,.56. 0000 ~bandonment ~ost ~otal number of wells (active or inactive) on thiSjcenter prior of this to plugging well and Spudded or W.O. begUnAcCEPT JDate 01/07/88 /~°ur 2200 ['[RSIPriOr status if a W'O' Date and depth as of 8:00 a.m. Old TD Complete record for each day reported NORDIC 1 01/10/88 ( TD: 8210 PB: 8099 SUPV:DL RELEASED RIG MW: 0.0 DIESEL FINISHED RIH WITH 3-1/2" COMPLETION ASSY (TAIL @ 7327', SSSV @ 1803', PKRS @ 6999' & 7291'). SPACED WELL OUT. TESTED CONTROL LINE TO 5000 PSI. LANDED TUBING. TESTED TUBING TO 2500 PSI. TESTED ANNULUS TO 2500 PSI. TESTED SSSV TO 1500 PSI. SET BPV. ND BOPE. NU TREE & TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. TESTED CU TO 1000 PSI. SET BPV. SECURED WELL & RELEASED RIG @ 1800 HRS, 1/9/88. DAILY:S87,543 CUM:$146,225 ETD:S146,225 EFC:$187,000 INew TD I PB Depth Date IKind of rig Type completion (single, dual, etc.) IOfficial reservo r name(s) Released rig Classifications (oil, gas, etc.) Producing method Potential test data Well no. Date Reservoir Producing Inte[val Oil or gas Test time Production Oil on test !Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature v I Title For form preparation andjl~istribution, see Procedures Manual, ~E~ction 10 Dr ling, Pages 86 and 87~. Associate Engineer STATE OF ALASKA -- Abandon ~ Suspend [] Operation Shutdown I-i Re-enter suspended well ~ Alter casinrk~ 1. Type of Request: Time extension ~ Change approved program ~J Plugging [] Stimulate [] Pull tubing ~,,Amend order [] Perforate _~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 571' FNL, 1851' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1399' FSL, 1687' FWL, Sec. 1, T11N, RgE, UM At effective depth 671' FSL, 1493' FWL, Sec. 1, T11N, RgE, UM At total depth 598' FSL, 1472' FWL, Sec. 1, T11N~ RgE~ UM 11. Present well condition summary Total depth: measured 821 0 ' M D feet true vertical 6656 ' TVD feet 5. Datum elevation (DF or KB) RKB 96 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 1Y-7 8. Permit number 83 -6R 9. APl number 50-- 029-20950 10. Pool Kuparuk River Oil Plugs (measured) None Pool feet Effective depth: measured 8099 'HD feet true vertical feet 6575 ' TVD Casing Length Size Conductor 78 ' Surface 2214' Production 8147' Junk(measured) Vann Gun 484.57' long, top (~ 7614' Cemented Measured depth True Vertical depth 16" 251 sx AS II 78'MD 78'TVD 9-5/8" 900 sx AS III & 2249'MD 2203'TVD 250 sx AS I 7" 940 sx Class G & 8180'MD 6635'TVD 103 sx AS I Perforation depth: measured 7091 '-7218', 7242'-7262', 7395'-7402' true vertical 5910'-5989', 6004'-6017', 6095'-6099' Tubing (size, grade and measured depth) 3-1/2", J-55 @ 7327' Packers and SSSV (type and measured depth) Camco HRP-1-SP ~ 6999', Baker DB @ 7291' , 7415'-7450' , 6107'-6128' , 7478'-7496' , 6144'-6156' , Camco TRDP @ 1798' D ~".,-, ]- · i -,,,o,,,-, Oil & Gas Oozes. c0mmis x,;~,-.~ Anch0rag0 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation January 5, 1988 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 Signed ~~ ~ Title Associ01;¢ Engineer Commission Use Only (JWR) SA3/32 'Conditions of apprOval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Date '~'~'~'~ ~-~--- !'}:'~.' --~r~y ~.~st Approved Copy 0RIGI~L SIGNED BY Returned ~ LONNIE C. SMITH / ~om~si~ner the commission Dete Form 10-403 Rev 12-1-85 Submit in triplicate KRU WELL 1Y-7 3-1/2" COUPLING AND WELLHEAD CHANGEOUT PRELIMINARY PROCEDURE 1) RU slickline. Set plug in "D" nipple. 2) Pull dummy from bottom GLM. RD slickline. 3) MIRU workover rig. 4) Circulate kill weight brine down tubing taking returns up annulus. 5) ND tree. NU and test BOPE. 6) Sting SBR off of packer. POH 2 stands. 7) Make up storm packer and GIH one stand. Set storm packer. from same and test to 500 psi. POH. Release 8) ND BOPE. Change out tubing head to 5000 psi equipment. NU BOPE and test. 9) GIH and latch storm packer. POH with same. ~. _ 10) Continue POH while changing out couplings to AB-Mod. ._ - 11) Rerun completion with redressed SBR, 1-~-'~-~M-and SSSV. 12) ND BOPE. NU and test tree. 13) Displace well to diesel. 14) Release rig. 15) RU slickline. Pull plug from "D" nipple. 16) TOTP. Workover fluid: NaC1/NaBr BHP = 3340 psi @ 6037'TVD/7300'MD Anticipated start date: 1/5/88 SA3/32a 12/8/87 ANNULAR PREVENTER 6 PIPE RAHS 4 BLIND RAI'IS 5 TUBIN6 HEAD 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-:3000 PSI STARTING HEAD 11 "-3000 PSI X 7-1/16"-5000 PSi TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY T[$T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 10. 11. 12. 13. I4. 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4, TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. 5, INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI, 6, OPEN ANNULAR PREVENTER AND CLOSE PiPE RAMS. 7. INCREASE PRESSURE TO :3000 PSI AND HOLD FOR 10 MINUTES. 8. 'CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSi TO TEST VALVES, TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSi UPSTREAM OF VALVE AND WITH ZERO PSi DOWNSTREAM, BLEED SYSTEM TO ZERO PSI. 9. OPEN PiPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO :3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES AP.E SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO :3000 PSI. TEST KELLY COCKS AND iNSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SENO TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST-ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. dG JULY 28, 1986 ATTACtlMENT 1 PACE 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF NUMBER NUMBER INITIAL 50-029 INJECTION " "~E-01A-~' 2046401 '"~'~1E-04 '-""~20478 05/08/83 04/17/83 '"""~1E-16'~ 20777 02/11/83 '"~1E-27 "'"'/ 20837 02/11/83 ~"~1C-06,-"'""20890 07/28/84 1R-08~''''- 21333 08/29/85 1Y-01 ~ 20933 10/15/85 1Y-02'""- 20941 03/30/85 ~1Y-07,/' 20950 11/01/85 '"'"1Y-08''''/' 20944 03/30/85 ""'Z2B-O6J 21078 11/07/85 ~2D-07j 21080 07/12/86 '"'~2B-10j 21084 11/09/86 DATE OF DATA TYPE REASON FOR PROFILE/ PROFILE/ PROFILE/ SURVEY SURVEY SURVEY 05/31/87 SPINNER REINITIATED INJECTION 06/03/87 SPINNER REINITIATEB INJECTION 06/01/87 SPINNER REINITIATED INJECTION 06/02/87 SPINNER REINITIATEB INJECTION 06/23/87 SPINNER FOL~OWUP 06/11/87 SPINNER FOLLOWUP 06/09/87 SPINNER FOLLOWUP 06/21/87 SPINNER FOLLOWUP 03/16/87 SPINNER FOLLOWUP 06/10/87 SPINNER FOLLOWUP 06/14/87 SPINNER FOLLOWUP 06/17/87 SPINNER FOLLOWUP 06/15/87 SPINNER FOLLOWUP WELL COMPLETION A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C S A&C S A&C S A&C S ZONES TAKING WATER A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C I NJ ECT I ON BWPD RECEIVED Alaska Oil & Gas Cons. Commission Anchorage .al~-'m'nCO Alaska, Inc !-~~~:~-'-~"" Post Office .. x 100360 '~'~_~:~ Anchorage, Alaska 99510-0360 January 26.?87 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk Water Injection Wells for the fourth quarter of 1986. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have any questions concerning the information reported, please contact me at (907) 263-4386. Since. (~. ~. Roberts, Jr. Operations Engineer JWR/SPT: -pg- 0052 Attachments . . -.~.~ ~ ~ Alastm Oil & Gas Cons. Commission ~ Anchorage .:-, ARCO Alaska, Inc. is a Subsidiary of AllenlicRichfieldCompeny '.:..:.-' .-.-~ ATTACHMENT 1 KUPARtlK RIVER FIELD CONSERVATION ORDER 198 RULE ii - INJECTIVITY PROFILES FOURTll QUARTER 1986 SUBMITTAL WELL APl NUMBER NUHDER 50-029 20706 20711 20713 21234 21210 21307 2095O 21281 21055 DATE OF DATE OF DATA TYPE REASON FOR INITIAL PROFILE/ PROFILE/ PROFILE/ INJECTION SURVEY SURVEY SURVEY 02/22/83 03/01/83 03/01/83 11/16/85 lO/28/85 10/28/85 11/01/85. 11/11/86 11/27/86 12/86 12/17/86 12/26/86 11/22/86 11/23/86 11/211/86 11125186 12/86 12/86 SURVEY SP NNER SP NNER SP NNER SP NNER SP NNER SP NNER SURVEY SURVEY WELL COMPLETION FOLLOWUP ARC SS FOLLOWUP ARC SS FOLLOWUP ARC SS NITIAL ARC SS NITIAL ARC SS NITIAL ARC SS NITIAL ARC SS NITIAL ARC SS NITIAL ARC SS ZONES TAKING WATER INJECTION BWPO A 1347 ARC ARC ARC ARC ARC ARC A 4000 A 974 : ..... : - Anchorage, Amska 99510-0360 -_. - - TelePhone 907 276 1215 _ - .. : _' - · · ':-- -'--~ ._ ".. September 2, 1986 .-.-::--:.:--- ' -. .- Mr. C. V. Chatterton -.. -- Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive _. Anchorage, Alaska 99501 - _ Subject: Kuparuk River Field _ Production Surveys Dear Mr. Chatterton' In compliance-with Rule 9 of Conservation Order Number 173, Kuparuk River Field Rules, we are hereby submitting production survey informa- tion for the second quarter of 1986. Production survey information consists of production logs and production tests as identified in Attachment 1. Production logs (spinners) identified in this attachment will be sent under separate cover. Note that several initial spinners not previously submitted to the State are being submitted at this time. ;~ y~u have any ~u~stions rnnr~rnino the ~nformation r~oorfed please contact me at (907) 263-4935. Sincerely, SenSor Operations £n§ineer ~, , ~ ~ VLF-pg:O074 ~ A'~CO~ Alaska. ;mr... ig a .~ub=;,~;a,,v Of Atiant~cRichf~e!dCo~,.;arty ARCO Alaska, .?'~ Post Of, ~,._. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Cas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- on the Wel I Action Date Performed 1F-4 1F-5 1F-8 1G-3 1G-4 - 1L-3 1L-5 1Q-8 1Q-12 1Q-14 1R-3 1R-10 1Y-7 1Y-10 1Y-15 1Y-13 2B-6 2B-8 2B-11 2B-12 2C-2 2C-4 2C-5 2C-7 2D-4 2D-5 2F-3 2F-4 2F-15 2F-16 2D-1 0 2D-16 Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers on on on on on on on on on on on on on on on 10/24/85 10/24/85 -10/24/85 10/25/85 10/25/85 10/24/85 10/24/85 10/25/85 10/25/85 10/25/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 1115185 11/5/85 1115185 11/5/85 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 11/2/85 11/2/85 11/2/85 11/2/85 11/6/85 11/6/85 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION GOMMISSION 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. 571' FNL, 1851 ' FWL, T11N, ReE, UM 5. Elevation in feet (indicate KB, DF, etc.) 96' (RKB) 12. SEC. 1 · 7. Permit No. 83-68 8. APl Number 5o-029-20950 9. Unit or Lease Name KtJPARUK RIVER tJNIT 10. Well Number 1Y-7 11. Field and Pool KUPARUK R!VER FIELD I 6. Lease Designation and Serial No. KUPARUK R I VER O I L ADL 25646, ALK 2577 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 X[] 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 October 26, 1985 Kuparuk well 1Y-7 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both the "A" and "C" sands. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~- ,~~ (~/¢,.~¢.--~-¢--- Title _K U_ P ~A .R U .K .... The space below for Commission use UFbI'O~ I I UNb COO~,E) i NA]OFt Da,;~ 1 / 1 5 / 8 5 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 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Y-7 Dear Mr. Chatterton: Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU4/L187 Enclosure If RECEIVED OOT 1 1 985' Alaska Oil & Gas Cons. Comrnissio~ AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA L _ AND GAS CONSERVATION CO. .vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 83-68 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20950 4. Location of well at surface 9. Unit or Lease Name 571' FNL, 1851' FWL, Sec.l, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1399' FSL, 1687' FWL, Sec.l, T11N, RgE, UM 1Y-7 At Total Depth 11. Field and Pool 598' FSL, 1472' FWL, Sec.1, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 96' RKBI ADL 25646, ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/05/83 05/13/83 06/08/83*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set J 21. Thickness of Permafrost 8210'MD,6656'TVD 8099'MD,6575'TVD YES [~X NO [] 1798 feet MD 1350' (Approx) 32. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal, CBL/CCL/GR/VDL, Gyro~ CRT 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 78' 24" 251 ~x A~; II 9-5/8" 40.0# J-55 Surf 2249' 12-1/4" 900 ax AS III & 250 sx A~ I 7" 26.0# K-55 Surf 8180' 8-1/2" 940 sx Class C & 103 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ., interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7091' - 7218' 3-1/2" 7327' 6999' & 7291' 7242' - 7262' 7395' - 7402' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7415' - 7450' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7478' - 7496' 7340' - 7342' 250 sx Clas,~ 7062' - 7ORb,' 100 .~x £1a.~.~ fl, 27. N/A PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR iOI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED=k 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 RECEIVED 0C'T1 Alaska Oil & Gas Cons. Cu.~rnissi0n Anchorage Form 10-407 -b NOTE: Well was recompleted 7/8/85. TEMP2/WC28 Submit in duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand 1. LIST OF ATTACHMENTS Well Hi story GEOLOGIC MARKERs MEAS. DEPTH TRUE VERT. DEPTH 5907' 5984' 6088' 6207' 30. FORMATION TEsTs 7090' 7210' 7382' 7577' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~ ~~ Title Associate Engineer Date /~ -/-OP~' 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, (:;as Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 ARCO 011 and Gas Company Well History - Initial Report - Daily Prepare and submit the "lltltill R,~N,"I" on the flat Wedneldly ertl, · well il spudded or workover operetlonl ere Itarlld. Daily work prior to spudding Ihould be Kmmarized on the form giving inclusive dltll only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 503673 WWS t/1 - - lCounty, p~nl~ o,r borough North Slope Borough Ladle or Unit ADL 25646 Title Recompletion Istlte Alaska Fill no. 1¥- 7 tV/O AP1 50-029-20950 Operator ARCO Alaska, Inc. Spudded or W.O. begun ID-,, 7/2/85 I ARCO W.I. IH°ur '~'~''~-~ hrs. [Pr,orst.tu. if.W.O. Workover Date and depth aa of 8:00 a.m. 7/02/85 7/03/85 7/04/85 thru 7/05/85 7/06/85 thru 7/08/85 Complete record for each day reported The above iS correct Signature '1 '~ XX ,'~ / Date For form preparation and dis~'ributioO, 2.~ W S. CONGDUr~ see Procedures Manual, Section 10,~ "'"" · ''' Drilling, Pages 86 and 87. 7" @8180' Attempting to bleed Tbg Accept rig @ '~rs, 7-2-85. 7" @ 8180' Wt. 8.8, PV 7, YP 20, PH 9.0, WL --, Sol -- Bled tbg prss. RU WL, pull GLM dummy @ 6928'. ND tree, NU BOPE & sst. Pull tbg. Spear SBR. Attmp to bleed off tbg. press. 56.24% Pmp kill fluid, POOH w/tbg. 7" @ 8180' Wt. 8.8, PV 10, YP 10, PH 8.5, WL --, Sol -- POOH w/3½" tbg. RIH to fish pkr. Tag pkr @ 6978', POH w/pkr & tail pipe assy. RIH w/R-3 pkr. Tst csg to 3000 psi. RIH w/bit & scrprs. Tag fill @ 7308', cln out to 7434'. 7" @ 8180' 7608' WLM PBTD, RIH w/slickln to pull std'g vlv Crude oil w/diesel cap Wsh & rm fill f/7434'-7583'. RU WL, RIH w/GR & Junk bskt. RIH w/pkr & tailpipe assy, set @ 7291'. RU & rn 3½" compl string. Drop ball, set pkr. Tst tbg;'est communication to ann. RU WL, RIH w/std'g vlv, set in "D" nipple @ 731~ Pressure up on tbg to 2000 psi & communicate w/ann. RIH to pull 48/64" orifice vlv @ 6934'. POH w/orifice vlv. RIH w/dummy vlv & set in @ 6934'. Tst tbg to 2000 psi; OK. RIH, pull dummy & repl w/orifice vlv. PU to shear SBR, pkr pulled loose. Relnd pkr & set. Sheared SBR. Set BPV. ND BOPE, NU &tst tree. Displ well to crude. Tst SSSV. RU WL. TIH to pull std'g vlv. (Re total of 219 jts, 3½", 9.3#, J-55 BTC IPC & 3 Jts, 3½", 9.3#, J-55 EUE 8RD IPC tbg w/SSSV @ 1798', retry pkr @ 6999', perm pkr @ 7291', "D" Nipple @ 7315'.) q-'q- ~,~ ~ ~ 'L q ' RECEIVED OC"F 1985 rcc'J Alaska Oil & Gas Cons. Cmi.mssion Title ' '"m~mm~'~J ~'4~1~ 7/25/85 Dct[[~S Supec~enden~ AR3B-459--1-D Number all daily well hllto,y forml con~cutlvely es they are prepared for each well. iPag~ no. ARCO O~1 and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Repor~1' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Fieel Report" should be submitted also when operations are suspended for an iedefimte or appreciable lenglh of time. On workovers when an oUicial test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for repotting the entire operation if space is evadable. District ~County or Parish I Alaska Field Lease or Unit Kuparuk River Auth. of W.O. no. J Title I AFE 503673- ~- WWS North Slope Borough ADL 25646 Recompletion API 50-092-20950 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun [ Date Workover [ 7/2/85 Complete record for each day reported 7/09/85 IAccounting cost center code Slate Alaska Well no. IY-7 W/O Date and depth as of 8:00 a.m I olal number of wells (active or ~nactive) on this est center prior to pluggmg and bandonment of this well our ,- = .~ -- IPrior status f a W.O. I 7" @ 8180' 7608' WLM PBTD, RR Crude oil w/diesel cap Could not pull std'g vlv. Set BPV. RR @ 0800 hfs, 7/8/85. Old TO Released rig 0800 hrs. Classifications (oil, gas. etc.) 0±l New TD [PB Depth 7608' WLM PBTD Date IKind of rig 7/8/85 Rotary Type comlMetion (stogie clual, etc.) Single Producing method Official reservoir namefsi Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct ~ .-- ~ 7/25/85 Drilling Superintendent For form preparati .... d distr,buti ...... ~ W.S. CONGDOi-: see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number ell daily well history forms consecufively aa they are prepared for each we . iPage no. DI~I~o, O! AllentlcRIchflefdCompa~lf ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the following wells: 1Y-7 DS 11-5 DS 11-6 DS 6-9 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L147 Enclosures RECEIVED OCT o Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLX[~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchoraqe, AK 99510 4. Location of Well Surface: 571' FNL, 1851' FWL, Sec.1, T11N, RgE, UH 7. Permit No. 8. APl Number 50- 029-20950 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-7 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 96' I ADL 25646 ALK 2577 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made (Submit in Duplicate) [] Altering Casing [] Abandonment [] 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, ipcluding estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). Accepted rig ~ 0330 hfs, 7/2/85. Killed well. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled 3-1/2" tubing. Retrieved pkr. Tstd csg to 3000 psi - ok. RIH & set pkr @ 7291'WLM. Ran 3-1/2" completion assy w/tail ~ 7327', pkrs ~ 7291' & 6999', & SSSV ~ 1798' . Set BPV. ND BOPE. NU tree & tstd to 3000 psi - ok. Set BPV. Secured well & released rig ~ 0800 hfs, 7/8/85. RECEIVED oc'Fo 985 Alaska Oii& Gas Cons, Cor,'ffnJssion Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below f~;~ Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 GRU11/SN05 Rev. 7-1430 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~-'- Post Office ~. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 23, 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: Well Action Date Performed ,. 1Y-1 Fracture 9/10/85 1Y-7 Fracture 9/10/85 3C-5 Fracture 9/12/85 3C-7 Fracture 9/12/85 3C-8 Fracture 9/12/85 If you have any questions, please call me at 263-4212. T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) on the Alaska 0it & Gas Cons, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-68 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20950 4. Location of Well SURFACE LOCATION: 571' FNL, 1851' FWL, SEC. 1, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 96 ' (RKB) 6. Lease Designation and Serial No. ADL 25646, ALK 2577 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Y-7 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. 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). On September 10, 1985, the "A" sands of Kuparuk well 1Y-7 were hydraulically fractured and propped to improve production. The treatment consisted of 214 BBLS of gelled diesel as pad and carrying fluid and 2,570 LBS of 100 mesh and 12,792 LBS of 12/40 sand as proppant. The flush consisted of 65 BBLS of gelled diesel. Prior to pumping, equipment and lines were tested to 7,000 psi. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~ ~ Title KUPARUK 9 / 2 3 / 8 5 _Date The space below for Commission use OP~]~-~_LO~ COORD1NATOR~ ~ . ~. Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10403 ~)~,, ~ lOr~ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate . ARCO Alaska, Inc. Post Office ~...x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. 'Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first 'stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions .are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc.: J.F. Beall TMD:ps:013 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ---.. ALASKA LAND GAS CONSERVATION C '~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER I--I 2. Name of Operator ARCO Alaska, Inc. -3. Address P.O. Box 100360, Anchorage, Alaska 4. Location of Well N/A 99510 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 1 1. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. N/A see attached 12. 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 Ca'sing [] Perforations D Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair.Well [] Change Plans [~ Repairs Made [] Other Pull Tubing - [] Other Y~ 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). Pursuant to form 10-403, it is proposed that the attached list of JA/~roducing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern' will occur approximately 12/15/85. Injection will be into the A and C sands. SEP 2 0 19B5 Gas ConS. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed :::~, /~ ~,~.4--~t,,-~---~ Title Kuparuk Operations Coordinator Da,e 9/18/85 The space below for Commission use ~(.~./.~ ~'~ ~, .... ~;':'-' Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 ^pproved Copy By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Permit API ~ Lease & Serial # Convert Date 1E- 6 -26 80- 78 82-166 029-20493 029-20840 25651 469 10/15/85 10/15/85 iF- 2 - 4 - 5 - 8 81-2 1 1 1 11 72 32 62 029-20881 20846 20807 20836 25652 l! 2578 10 10 10 10 115/ 1151 1151 1151 85 85 85 85 1G- 2 - 3 - 4 - 5 82-1 1 1 83- 38 49 61 20 029-20813 20824 20835 20908 25640 2571 10 10 10 10 115/ 1151 1151 1151 85 85 85 85 IL- 1 - 3 - 5 - 7 -16 84-1 1 1 1 1 73 58 23 45 81 029-21196 21182 21155 21171 21202 25659 2585 !! 12/15/ 10/15/ 10/15/ 12/15/ 10/15/ 85 85 85 85 85 iQ- 1 -- 2' - 7 - 8 -11 -12 -13 -14 IR- 3 - 8 -10 -13 84-2 2 2 2 1 1 85- 85-1 1 31 32 18 09 99 93 44 45 77 73 96 50 029-21247 21248 21234 21225 21216 21210 21306 21307 029-21406 21333 21351 21385 25634 II II II 2567 !! !! !! 2568 !! !! 10 12 12 10 12 10 12 10 10 10 10 10 /15/ 1151 1151 1151 1151 1151 1151 1151 115/ 1151 1151 1151 85 85 85 85 85 85 85 85 85 85 85 85 1Y- 1 - 7 -10 -13 83- 50 68 51 15 029-20933 20950 20934 20903 25641 25646 !! 25548 2572 2577 2662 12 12 12 12 /15/85 /15/85 /15/85 /15/85 2B- 5 - 6 - 7 - 8 - 9 -10 -11 -12 84- 4 22 24 28 27 29 35 38 029-21067 21078 21080 21079 21082 21084 21089 21092 25656 25655 !! l! 2582 2581 12/15/85 10/15/85 12/15/85 10/15/85 12/15/85 12/15/85 10/15/85 10/15/85 2C- 1 - 2 - 3 - 4 - 5 83- 83 93 89 94 99 029-20962 20972 20968 20973 20978 25654 !! 2580 !! !! !! RECEi 12/15/85 10/15/85 12/15/85 10/15/85 MARK: 009 SE? 2 o BBS c!as~:~ Oil & Gas (";,r:r~s. 6ommissioh ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 17, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1Y-7 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1Y-7 to a selective single completion. Since we expect to start this work on June 27, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~rea Drilling Engineer JBK/JWR/tw SN/L046 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED J U N 1 8 1985 Alaska Oil & Gas Cons. Commission Anchara~e .... STATE OF ALASKA ~--- ALASKA ~ _AND GAS CONSERVATION CL ~IlSSION 'SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WE L L~] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-68 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20950 4. Location of Well Surface; 571' FNL, 1851' FWL, Sec.l, T11N, RgE, UH 5. Elevation in feet (indicate KB, DF, etc.) RKB 96' 12. I 6. Lease Designation and Serial No. ADL 25646 ALK 2577 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-7 11. Field and Pool Kuparuk River Field Kuparuk River Oil 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 (Clear!y state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1Y-7 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationall.y tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. RECEIVED Estimated Start: June 27, 1985 J u N 985 Work ~] Alaska Oil & Oas Cons. C0mmissJ0n 14. I hereby ge~d, fy that the foregoing is true and correct to the best of m~ kno~v~c~e~ Signed //~'~'~.~J~j~_~*~ Title Approved by IRIIilA[ lltlll ApproveO Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 (JWR) SN/070 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. -, ..-.:-':c.'-,~_ 9;:7 =:77 5637 Return To: · . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ,~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. P~.U _SUR~S/?RESSU~E ANALYSZS ~lA-2 5/11,12/84 Torque Turn (Pressure & Temp Surveys) .................... .~_f[A--6-__ 7/06/84 Camco ~/ /lB-11/ 7/10,12/84 ..... -zlA-10 5/10/84 /lC-1 12/17/83 /1C-6 8/04/84 /!G,10- 12/2!/83 - /1G-11 12/23/83 ~~ 5/21/84 ~-~-j? 5/i3,i4/84 /1G=3~ 6/26/84 .~.~1G:_8~2~ 5/18/83 ~!_~j3:.:'7/o7/84 /1H-4 12/27/83-. ~tY-5 12/14/83 ~lY-7 12/15/83 /~1 7/03/84 ~,~/1 4/lO/O4 C~o Otis Otis Otis Camco Camco Otis Camco Static Torque Turn (Pressure & Temp Surveys) Camco Static HP Static Canmo Camo Camco Camco Camco' Otis Otis Otis Otis Otis Camoo Receipd~ac~nowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D & /4 W.¥. Pasher C.R. Smith G. Phillips Dr illing Geology Phillips Oil Sohio Mobil J.J. Rathmell Union R & D Well Files NSK Operations , -_ [.':C.r.c .~ 77 5r~37 Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: · . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~99~- 5128/84 2C-1 11/09/83 · · 2C-2 11/09/83 2C-6 11/08/83 2~r2 11/o8/83 (2C-~:~ 4/18/83 ~~') 4/24/83 tlC.r41:: 4/22/83 ~~:- 4/30/83 ~=3 4/28/84 "(~.~,~37 4129/84 ~'~-3) 5/04/84 VZ-5 5/06/84 2X-5 8/12/84 s/08/84 3C-6 5719/84 3C-6 5/17/84 ._ Otis Lynes -Lynes Lynes Lynes Camlco Camco Camco Otis Camco Camco Dresser PBU Flow Survey (Gradient). Otis Static Gradient Otis .. DrESser Dresser Mini Drawdown & Buildup Survey /cat Receipt Acknowledged: B. Adams · F.G. Baker P. Baxter BPJ~ Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Union Well Piles x, / KUPAr~K Bkt31NEER I FIG TRA~ i T FAL #_~~) TO: William VanAlen ~: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following: PLEASE NOTE- BL- BLUELINE, S- SEPIA, F- F! LM, T- ATRq' SHELBY J. P. O. BOX 100360 ANE}E~CGE, AK. 99510 KIJPAFEJ~< ~ 1 NEER! hiS TO: William Vard~.! en FREi4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the foliowincj- '~PLEASE ~RN RECEi PT TO. ARCD ALASKA, lINC:. A]-I-N: · SHELJ3Y J. MATI-HE3.~,S - ATOI 1115-B P. O. BOX 100360 AtxCHE~vN:3E, AK. 99510 TEST SUMMARY TEST DATA . ARCO REP: TEST TYPE: WELL: TEST DATE: ? · WELL TYPE: .Old _ ~. New ~ Pzoducer Injector PERFORATIONS: ?o ?__Z PERF TYPE: qco. ~J~.n.n....,z-" )Z...;D~ ,, LOGGING TOOLS RUN: ~. ' u~...s INTERVALS: -' ! . . · TEST SUMMARY HAODR WELL EVENT HISTORY DATE START END EVENT ! _?oo I~ CUMULATIVE PRODUCTION (IN3ECTION): TOTAL PRODUCTION (IN3ECTION) TIME: TIME SINCE LAST HA3OR SHuT IN: DAYS KUPA~3K ~GINEERI I~ FRQ'~'I: D.W. Bose/Shelby J. I,,~3tthews Transmitted herewith are the followin~j- PLEASE NOTE- BI' - BLUELINE, S - SEPIA, ,. /z/J~IPT ACXNO,'./LEDSED: // PLEASE P,_FTU~N RECZE 1 PT TO: /~qO3 ALASKA, INC. ATTN: S~uI-EIJ~Y J. ~/ATiT-IB,,;~ - ATOI 111 5-B P. O. P_DX 100360 A~~E, ~(, 99510 KUPAF~,% EKC i NEER ! 'I'R~N.~",.-~I TTAL #~ TO: Wi l liam \/anAlen ~,4: D.W. Bose/Shelby J. ~tthews Transmitted herewith are the following- PLEASE NOTE~~F-F! IA4, T- TAPE, FC- ~PY 1 PT ACKO,,CX',/I _ _R')C;IED: ~/~E RETUP~ RECEIPT TO: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 13, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Y-7 Well Completion Report Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for 1Y-7. If you have any questions, please call Jo Ann Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/jG3L70-sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA~..,L AND GAS CONSERVATION Ct, .MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILX~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-68 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20950 4. Location of well at surface 571' FNL, 1851' FWL, Sec. 1, T11N, RgE, UM -t'[~ATION~' 9. Unit or Lease Name VEi~iFIED Kuparuk River Unit At Top Producing Interval ~ujr~.?-~-~ i 10. Well Number 1399' FSL, 1687' FWL, Sec. 1, TllN, R9E, UM 1Y-7 At Total Depth____BS'Ii~"--'~'~-- _,t 11. Field and Pool 598' FSL, 1472' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 96' RKBIADL 25646 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 05/05/83 05/13/83 06/08/83I N/A feet MS LJ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8210'MD,6656'TVD 8099'MD,6575'TVD YES~] NO [] 1850 feet MD] 1350' (Approx) 22. Type Electric or Other Logs Run DI L/SFL/SP/GR/FDC/CNL/Cal, CBL/CCL/GR/VDL, Gyro, CET 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 78' 24" 251 sx AS II 9-5/8" 40.0# J-55 Surf 2249' 12-1/4" 900 sx AS Ill & 250 sx A5 I 7" 26.0# K-55 Surf 8180' 8-1/2" 940 sx Class G & 103 sx fSI 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) 7091 ' -7218 ' 3-1/2" 7013 ' 6984 ' 7242' -7262' 7~395'-7402' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7415'-7450' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7478'-7496' ' 7340'-7342' '.50 sx Class G 7062'-7064' 00 sx Class G 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-OIL RATIO TEST PERIOD ~_. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS TRUE VERT. DEPTH 5907' 5984' 6088' 6207' 30. MEAS. DEPTH 7090' 7210' 7382' 7577' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Completion Summary, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 1Y-7 DRILLING HISTORY NU 20" Hydril & diverter & tstd same. Spudded well @ 1200 hrs, 05/05/83. Drld 12-1/4" hole to 2277'. Circ & condition hole. Pump pill. Ran 57 jts 9-5/8" 40#/ft, J-55, BTC csg w/shoe @ 2249'. Cmtd 9-5/8" csg w/900 sx Arctic Set III & 250 sx Arctic Set I. ND 20" Hydril & diverter. Instld 7" casing spool & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 7730'. Ran DIL/SFL/SP/GR/FDC/CNL/Cal logs f/2249'-7718'. Cont. drlg 8-1/2" hole to 8210' TD as of 05/13/83. Circ btms up. Ran 208 jts 7" 26#/ft K-55 BTC csg w/shoe @ 8180'. Cmtd 7" csg w/940 sx Class "G" cmt. Bumped plug to 1800 psi - ok. Performed top job on 9-5/8" x 16" annulus while displ 7" cmt. Pumped 103 sx Arctic Set I. Displ well w/NaC1/NaBr in csg w/top 360' of 7" csg to diesel. NU FMC tbg head & tst to 3000 psi - ok. Secured well & released rig 0930 hrs, 05/15/83. HILL/DH20 06/13/83 1Y-7 COMPLETION SUMMARY ND adapter flange 'and master valve. RU Gearhart. Ran CBL/CCL/GR/VDL f/8099'-2018'. Ran Gyro. RD Gearhart. NU adapter flange and master valve. Accepted rig @ 1300 hours, 06/02/83. Ran CET - poor bonding. NU BOPE & tstd - ok. RIH & perf'd f/7340'-7342' w/4 spf. Set cmt retainer @ 7285'. Stung into retainer; squeezed 250 sx Class G cmt. RIH & perf'd 7062'-7064' w/4 spf. Set retainer @ 7028'. Stung into retainer; pumped & squeezed 100 sx Class G cmt. TIH & tagged cmt @ 7010'. Drld cmt, retainer @ 7028', & cmt @ perfs (7062'-7064'). Tstd csg to 1500 psi - ok. TIH & tagged cmt @ 7220'. Drld cmt, retainer @ 7285' & cmt @ perfs (7340'-7342') to 7420' (below perfs). Tstd csg to 1500 psi - ok. Ran 3-1/2" completion assy w/tail @ 7013', pkr @ 6984', & SSSV @ 1850'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Set pkr. Dropped bar & perf'd the following intervals: 7091'- 7218' 7242'- 7262' 7395'- 7402' 7415'- 7450' 7478'- 7496' Flowed to clean up well. Dropped ball & released guns (top Vann Gun fish @ 7614'). Closed SSSV. Set BPV. Secured well & released rig @ 1800 hrs, 06/08/83. GRU3:CS7 PAD 1Y, WELL NO: 7 ':'IGMA-GYRO dOB NO: AO,..,,:,.",ZO149 "~ KI..IF'AF,~I_II-:.'. F I ELD, I".IORTH '.31_OF'E, ALA'.31<A ':'..., I' .C';iVlA'ZGYRO~-~--'O=B2 IO'-'MD;' .... SLIRVEYO RS': ...... F'EFFERI< ORN 7' M'It::EER:.; ........ D RUN: ..... 2 8'=M'A¥=83 S I GM A-G Y RI]I NO: 411, P ROB E NO: 067 VERT I CAL:'""SEC'TI'ON'"CALCLILA~I N PI._A I] I RECT I ON: .'-;il ~J ~J~G. ,J:34 M I N,, W I ~t Wt tps ocK J A Pti'I'ROL.AN~! C;(}MPANY ........................................................................................................ REC:ORD""OF '" SURVEY RADILIS OF CURVATURE METHOD ARCO ALA:SKA., INE:, PAD--I'¥'; ...... WEEIZ--NO':'--7 ........... S~I"GMi~-=CCERO KUF:'ARUK FIELD-, NORTH SLOPE, ALASKA C:OMPUTAT I ON .......... 3=-t,.i,tE .................. EC4~=.E 11: 16: 57 28-JI_IN-87.~ PAGE hl~.' ' '1 ............ TRVE- .......... MEASURED DRIFT DRIFT C:OURSE'VERTICAL VERTICAL SUBSEA R E C: T A N G U L A R C: L 0 S U R E DOGLEG' DEPTH ANGLE DIREC:TION LENGTH DEPTH .SECTION TVD C: 0 0 R D I N A T E S DISTANC:EE DIREC:TION SEVERIT; FEET ................... D ...... M ............... E~ ......... M ............ PE'E'~'-~PEET ..... FEET 'FEE-]~ --~EET FEE~ {4- ..... ~- ..... DG-/-~-(.leF" 0. 0 0 0 0 0. O. 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[; ....... 2--'55--E 2200. 25 22 S 13:32 W t 00. 2158,/=,3 222.81 2062.63 22:'-;. 83 S 0.3/_, W 223.8:3 S 0 6 W O, 6/=. 2300. 26 58 S 12 28 W 100· 2248,37 2/=,6.54 2152.37 26/=,·80 S 10,2.9 W 2/=,7.00 S 2 12 W 1.8,7 2400, 28 ........ 4 S '10 41- ' W ......... 1'00-.- ....... 2337';05 312;-'50 .......224t';-0.' ._=-, ...... .'3_ 1"-2-,'¢77-'-S .... --t'.~-:--5~"-W ......... ~.--4't~:-69 ..... S ..... 3--'.-~5-W · ,'~ 2500. 28 55 S 8' 58 W 100. 2424.93 3/-.,0· 0.9 2328.93 :2:59.0.9 S 27 · 72 W 3/=,0 · 16 S 4. 25 W I. 18 ' 2/-..00, .... 28-43"-'S ..... 8 31'-' W ...... 100; ........ 25-t'2;-54 .........408;~"23 ~4'!t--675'4-----41"~6-;-~5-.'3-'~5'~ 05-W ----408;-~Z5 ~._=: ...... 4--56-W .... O; 2? 2700 · 2.9 28 S ¢~ 10 W 1¢~(I. 25.9.9 .91 4,..~/=, 7.9 '-'-~ '-' -=, 21 W · -' ._ 0._-, .91 454 81 S 42 53 W 4 ~/-, 79 '=' .' -- -- · . . I · -- -- I ..I ~ -- · 2:B00. :31 28 'S 5 42 W 100. 2/=,86.0'F~ 507.47 25.90.0.9 505. ¢)8 S 4.9. 10 W 507.47 S 5:3:q W 2.6/=, . ...... 2.':?~00; ....... 33' '-1-6-S .... 4 2 W ....... 100; ........ 2770:-55 ...... 561--; 00 ...... 26'74;-55 .... 558'; 43"- S------5._~: :'64' "'W ....... 56-1700 ......... S ....... 5-'29- W -~'02 ARCO ALA'..:;KA, INC. COMF'UTATION PAGE r',ll:i) ' ' 2 F:'AD 1Y; WEL, E'"'NFi: 7 :E:IF~MA F~YRO IF{B NO: AO.=,'~:3Z01"4~ - " - '=_ .... ;] - ' ....... ._,. .... 'l I'ME DATE ...................... : '.~ ...... KUF'ARUK F I ELD, NORTH SLOPE, ALASI<A 1 i: 16:._P1'7 '.:'R-,]I,_ ...... IN-R::: .................................................................................................................................... : ................. TRUE MEASLIRED DRIFT DRIFT (::OURSE VERTICAL VERTICAL SUBSEA R E: E: T A N G U L A R i-: L 0 '.'.-'; U R E DOGL. EG' DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT'., FEET B ........ M D M FEET ..................... FEET :300 A. :36 '"" 100 '-' ~'.'5-,'-' '-"" _ 56.:, 2 :E: W . .,.' ,=,._ ." . ..:,._', 61R,_. 46 275/--',.. · :33 615 .8Z',. '.'5 .,56 .75 W 61 ,~'-, 4.'7 '..:; ._.'--; 16 W :'::. ,_,':":'._, 31 A 0"'-" ............ 40 ........... 1 33'"'W ................... I'00'2 ............. 2'.-'T.~30 ','55 ........... '~_;80' ;"'E;"I ........ 2834'75'5 .............. z.-;78';;" I'" I-"'".:'D, ............... 58¥7 ~; :--:200. 42 11 S 0 21 W 100. 3005.84 7.45.20 27~0:-.~.84 743.')1 S 5:-.?.87 W 746.31 S .4 36 W 2.2:3 3300. .44 30 '.':; 0 20 E 100. 3078,55 814,53 2S~82.55 812.55 S 5S~.88 W 81.4.75 '.E; 4 13 W 2,36 3400~ 45 ......... 7' S ........... 0 8 E I00;; ............. 3I'47¥48 ...........88~.4~.-~55 .... 30537'.4~8 ....... 883'-:'03-$ ...... 5~';"5,~B"~'~'N :'::S(')~) 4.5 1 o c. (") 15 E 10A 321¢~ ~.~3 ¢~=.=, ~ '75 ~, r]c:? W '~' == ~'= S ~' 34. W . ...... - · . . . ~ ~, ~. 26 31 -?._c:. ~ ~, ~ ._ 4.01 '.E; ='~ · ._ ,_ ~..,._, . o 3700. 45 21 o~, 0 54 E 100. 3360.57 10~6.. ,65 :3264.57 1096.21. S 57.83 W 1097.74 '.E; 3 1 W 0.21'" 3800. 4.5 ...... ~") S i 'B E 1 O0 :34:30 81 1167 '-'~6 3:334.81 1167 . .~,~':'"' S 56. =~'._,.., W 11~,~.-'- 75 '.S '~'~ 46 W O. 1'~. 3 ~; 00% ............ 45'-38'-S ............. 1 ..... '~'~.., ................. E I 0~..) ......., .c,=,O0 ............... 8~ 1 ~ ~'~, I~ ~,40~ ....... 8c? I ~'.~...-~ .... ........ 70 ~, .... =.:,~ ~._,= ................... W I ~c~.:. ~ ............... ~ .:.' ................... z. ~,~'~' ..... W 0";'30 · -. ~z.~ [ .~,~. . .........,~. ~._, S '2 20 W O. 51 4lnn ~5 ......... ~,-,"~ · ~ (~ ~, ' .. if~ , ~i~ . "'~'. ~ · 42 O0 45 ~' S 0 r~ ~' ' ..... ~ E 11~ 371~.~7 14~._~ .:,816.~7 ~14._,1.._,~.S ~:~ 50 W 14~2 41 2 0 W O. 13 4;,,',,',_ ... 4s 0 -- .... E: u .... _ ='., z A ~-'FROLANE COMF~NY 4500 43 57 S 1 5 E 10C) <'<'"= 84 1[ M~' 8 ~, ~., c; t., ....... ~,. = .... =,. 1 382'~. o4 16 :.~. 16 ._ 46.35 W 16 :,~ c,O .., . 4600 43 "4~5- S ...... 1 3'E .......... IO0"; ............ 37~7';'73 ......... I727~;66 ...... 3'[~0'I;-'~ ......~ 7._ I. 4.~ .:, 4._,. O~'"'N ............ I"'7:-z2';-~4 .......... ~ "I'"-2?~'"W ...... O;'"i':B 47n¢~... 43 15~ ~'=; ~. 47 E ~00. 4070.45 1795,08 3974,45 ~800.~c}_. S 4:2:,~4 N 1Rr~o_...84 ._,':' 1 24 N 0.~=._~, 4800 42 59 S ~ ._.~ E 100. 414:3 4:3 1864 O1 4047.43 1:36:B.66 '.S 1 19 W . . . . ~ c ..... :, 0 '51 .... ~'~-T0~-4:2'~-~87 .... l"~31~-4E~-~O;-~"?~6¥'D3-'"~'"~~-~-84~-W-~'t~36;~/8 ....... ~E: ......... i ...... I'4'-W .... ..~ 5000. 41 47 S 0 42 E 100. 42'P1.00 1~'~8.15 41~5.00 2003.63 S 40.'Y~4 W 2004.05 S 1 10 W 0.7 5100' 4 I' 28 ~ ...... 0 34'-'E .......... 100;~'436~;7D .... 2064~'20 ..... 426~;-7D---2070'-,- 06--S ..... -40';-1'~7~"W .... ~0~0;--45 S t ........ 7-' W -~ 0~c~9 · -~' · - ~. . '- ._. 1 4 W 0.57 5200. 40 54 :S 0 37 E 100. 4441.00 212~.Eo 4345 O0 ~13._ 73 S. 3S~ 50 W 2136.zS~ ':' 5:~:00. 40 42 <'~, 0 31 E 1 O0. 4516.4.9 21 ~4.67 4420.6S] ~,?r}_._ 1 .2$~. <'._. ~<:8 . :E:4 W 2201 .63 S i 1 W 0 .21 5400 40 '12 ~ .... 5scJJ'J. ~:.~_. 36 c.._, 0 13 W 100. 466~]. 48 2323.06 4573. ~ 2330.33 S .:,,:,. 33 W 2330.54 S 0 57 W 0.68 57('~'~. .... 38 14 S 1 25 W 10('~. =,_,~._..~'m O0 ~44_," P. ~::~ _ 472~z. O0 2456. J'~5 ...... c.~, 40.33 W 24sF,. F:'~ S ('~ 56 W O. :~:0 ~:BAA :2:7 == ~ .... '5 ~ · -,., 1 43 W 100. 4903.72 ':'MA'~ 'pO 4:B07.72 2517.70 .: 42 0::: W ~._1._ {'~5 '.S 0 57 W ....... -- ~-~-~''--~ ' ~ - ...... A ..... ~--~ W ARCO ALA::~KA~ INC. 'F'AD"IY'~ ....... WEI=t=-NO: ......? ......... KUF°ARUK FIELD~ NLRTH-.-,LJFE~ ALASKA F'A G E N f'l ,~ 3 TRUE ....... HEA'.31_IRED DRIFT' DRIFT C:OLIR'.3E VERTICAL VERTICAL SUBSEA R E C: 'r n N O LI L A R E: L 0 S i_1 R E DOGLEG DEP'I'H ~NGI_E DTREC:T!ON LENGTH DEPTH SECT!ON TVD C 0 0 R Fi [ N ~ T E S'DTST~NCE D[REC]'ION SEVERI"I'', ........... FEE T ....................... D .......... M ........................ D ......... M ................ FEET- .............. FEET .............. F'E'E:~ ........... =FEE T F.E E T FEE-T E~ ...... M ..... DG..~-C-)O F:' 6 C)(') C) :3 !5 2 C) ¢' '-'/' ""- "'-' · :, 3 15 gl 1C)C)5(')/-.4.9c, (:.)2 4 ~6. o.o._-, 26.:"~/_,. :=:9 '" :3 ....... · .'- :,..' ~ · o 47 . 1 W 2/=,:37:31 :S 1 1 W 1:37 ...... 6100'; .............. 5;4"'"'~'7'-8 .......... 5 ..... t.'9-W ............. t'00'; .......... 5~'4-6;;":~2 -2686,'~'4' /=,2OK) .'33 45 '.':; 7 ~ N 100 ~'-='",¢ '"" ~ '~ .... 'C '=,~A,=,, 4:3 ':' ~ .... '"'~C' 9" - C.:, 1 12 ":' . . . ._, ~ .. ./ . .-' 0 2742.04..., 1 ._ (~. S 1 I'Fy W 0 45 6,:300 .-,.-, .... , o~ 2797 1 · :,.:, ~.:, S 7 W 100 .~,31"..'..,~c)~ ,.,o ,~c~/. . ~-) .,?Fl(')4 .... 28 c-~, 64 54 W .,:. .......... , .......... t- 4 (') (5 -, ............ ~ 5 ............... :~ .......... g .........q-"W ................. t Fl (3 ........................ 5 .F-~ ¢) 5' .;. t'6 .............. >28' .~'."3'-5 S ............ .'~ -".2 ,=).c).;_~,.~ .... -';'86 F,)-;., ("-) t"~--F;---72.-;.-5 ~.--.-. W .......... ':, e, At"+:. ,o -2 .......... g ......... t ........ 2, ~.,--.. ~ q "' 1,56)(] 37 12 c. .... 9 3:7 W 10C) .=i,47~._ '::8 ..""¢~.. 12 4 /=,6. 0 ()", F:8'-"50"" ~:3'-1 (")' '27--gl ................ 1'() C')= ................ 5554";' 66 ........... 2 .~Y'8 ;-'8/:, ........... 5'458';'66'--2978 ;'-9 't:- S ..... ~) 75-~.' W ...... -298(~)'~D5 ............. S .............. t'"'-"4':7-W ......... -t..'~ ."'7:2 .........'" ..,..,.:,._,. 34 3041 89 '.-, 105 08 W '"z,('.) 4'='._, 70 ¢' 1 .=; 9 W 9:32 670() 41 1 s 11 ,1.1H 100 5/:,31 o4 3037 74 ':'='-'= -' /=.8(1)(). 42 "' '.~ ._,7(.)o :58 .q ..... ._',4 . 11 49 W lC) C). ':' ' = '-104.0(l) 56(1) 9 ':cO 3107,14 S 11'--' 6'7 W :31'"' 4(.".) 'S ':) (.)~. . 11 W 1 ::;/' ii , 7C) 0C) 47 3 S 1E: 5 W 1(:) .... . 5 .?,' ' .1 ~, .... " 149.21 W ._~.J :=: 2 .=,o'-"~' W '2.11 71 ¢)(:): ....~"F/'. ....... '- "=: '~' "" ":, ...... ~ ....... z .~,~ ..... W 1C~I 5914. ' ., ., ':~" ,., ,.-c,..~ ......... ,- ............ 7200. D ! :30 .--, 1 ~ 5 N ~-'.~ ='_~ '~ ~" - ~-'- '- ' ~" .... "' F '- "" P..., S :3 5 N 2 04 ~" '- 1 (~! '='" 77.._, .. .=:..-~14,i7~1 .:,~ 1. ,_ y /:"-': FY.3, ).~ .:, I~" 74' N :'~:3'P7, ""'- , 7.--:oo_. , ~:'~_ _ 3._, ~-' ~ 2 .:,'-'~,. ~ ! o~1~6o.:,8", ?6'",:,~IiI.~l~~l~~l~~:,~_,' ..... ....... '--,^ ..... - ........ .--- ........ · _ .=, ._ ,.- .=, N ! 00~~~35 .98 II A PETROI.ANE COMPANY '. 7500. ~ 1 ':":':': S 15 3 N 100. ' ~ ~- ~'' ~.,. o-,...:. 75 3631 6.4 6062 75 S:675 6,7 c. 81 # i~ # . d.. i '.' -- . -- -- # ._m i -- · 7600 .~(') "' 4'~"_. .,. ":~:" - .... 1 .~, :'~ 1 ...... W ........... i'0(~} ........... . ,'!,.~'~',.._ '1. =.. .'s (5 ..... .......... F-:~'tq,:R.--.?,~, _. .......... /-,-l.'~:'5-.':Nt~)_ .,.._. ..... ..... F.:?fl,(9,.-. :Z~'"-.'::_ ........ -25:R-,'-~5-. ........... N ....... ~'(:) .c,'-,;'- "7' R ..... ~'~ ....... 4 ........... O'-W .... ()', ":"'='...., " '-" ~"'~' 4 14 W :3.,:.0'-"' 7700. 46, ~7._, ¢' 16 1° N,., 100, 6287. :32 ~782_ . .41 6,191 . ,3:Z 377:3,, 14 '.E: 278, ¢,'~.... N ._-, 7,:,.:,. 44 ¢'.~, '78C)0 ................ 44 57 .~ 1/=, °1 W lC)C). /-,3.~6 84 3o._,.3.01 /=,26C).84 :3:B42.0':.,' S '="P':' .::1 W '-"-' ~ '- .:, ,: .... _-': '7:=: S 4 27 W 2, C)O 7S.,'00 :: ................... ~'"'-"" ......_'3-,7 ................. -,~,------- -~ ...... ~ .,-, ......... 4o I ._ .:, 16 ' W --100. 64.,. .... 6._, o ~..' ! ,~2 6,:_~.:,... 6~ .:, ::'0o, 80 .=., ...,1 .-: . ~6 W .:, ...,:. 1. ~"1 .:, 4--40"W .... ! ..... ) 7'P50 42 44 S 16 32 W 50 6,46,5.20 :3'254.80 .6369.20 3941 48:3 :::',":~.89 W 3955 1:3 '.S 4 46 W 1 (.,.:, F'ROJEC:TED TO F'BTD _ ,=,,,. 'M ...... 1'4 S~-.- 6~74 .... ~ ...... .~i .......... ':' ~ .... 0~'''°'- .. F'RO._IECTED TEl TD :321C). 42 44 '._:; 16, :32 W 111. 6,656.14 4128.03 6560.14 4110.6.4 S .,7Y.14 W 4128 08 S 5 16, W (:) O0 FINAL CLO:3LIRE - DIRECTION:._.c. ._,: DEGS 16 MINS 11 :SEC:$ W DISTANCE 41.-,_ 08 FEET ............... ARCO --'AE~SKA's'---1NC :' ......... PAD 1Y~ WELL NO: 7 '.-';IOMA-GYRO JOB NO: AO583Z014Sx KUPARLIK FIELD., NORTH SLOPE~ ALASKA ~"OM'A~C~'RO's~8~i 0 ~ M£i~ ~E;LtRVE~'OF~, .--PEF~'ERf~¢tRN~M~tL~~tA~E~Rt~N~'~8~A~8'~3 SIGMA-GYRO NO: 411, PROBE NO: 067 ARCO ALASKA, IN¢:. COMPUTATION PAGE N~'_-I.' F:'AD 1¥, WEEE NO.' 7 '-'.:.IGMA-GYRO"' ' .................................... ~.ICIB NC.I' ........ AO,...~l-°'~ZOI49 TIME DATE ..... KUF'AF:(UK F I ELD, NORTH SLOPE, ALASKA 11: 17: 54 .-,o~,=,_,_,,_, ikl,,_,.,._,o.-~ ................ HAR~:,ER TRIJE ~:,121B._,Ei0i CODE - MEASURED VERTICAL MD-TVD VERTICAL R E C: T A N G U L A R C: L 0 S U R E VERTICAL NAME DEPTH DEPTH DIFF DEPTH C: 0 0 R D I N A T E S DISTANCE DIRECTION THICKNE'.:;'.=: FEET :~FEET FEET ........................... FEET FEE'f FEE'P ............................. D ............. M ._ ... .34 W :3:314.47 R ~' t'-' . . .=,'~ 11 .... .4 :-4_ 2:10.3'? .q 164. 2 I W TOP UF'PER .=,AN[ ..~ 70~¢¢~. O0 57¢07..:,,.-,""'" 1182.6 .. ,.. .'4" .. ._ E{ A.:.E ~'' "'" ............. r ~, ~,~: ~,"~ "c~Ktr~'c. ....... , _~.-z-:.,Tri--rrn .................... ......... .=ic~'p,'~'-'-z'T'-T~. '~'r-:-- 3, .... ,~_~. ................................ ........ .=i,',?, f:-:?-:~? ~ .... 3'Z;O0':"?'~;--~ ........... I",o, z[--~'3"'"'W'''''', ............ 2: 40.M' -?'/-', ........ .':-; .......... ~-: ........... ¢' r' ._._~ 1 5 t ,-.3 25:34 4. S* ~' 214 68 W 3541 00 .~ W TOF' LOWER .:,AN£.:, 7382.00 6087.5" 2'~4, . ...,~'""-'..-,.~ , ~' , _. . ._-, · , S ._ 2'.~ " ' ' 3 56 W BASE L. OWER SANDS 7577· O0 6207.07 ,~"/':/.:, :,;. ':.~. 6111 ,07 3683,50 c.._, ~:5~,. 62 W :::/',":/2_ _. ,22 c. Whipst¢ ( k' A PETROLANE COMPANY --- ? , , , . ~ , ~ * . . ; . ' " ' ........ ' ' ' ' : " i .... ~i ' ' , ' i : ~ ': ~ ~ ;' ' :~ ' i ~ ; ~ il~ ;iii ~!! ~ ,! ; ' ~ i . [ ~ , ~ ; ~ ~ : ; : ~ I , · I : I : '. ~'~; ~: ~ : ~ ; ; ;' :'':l. ~; ~ ;~J~;~ ; : ~ 'I ; : : ~ ' ~ : ~ : ; ~ ; ~ : i i~ ~l : f~ ~,~ :De~ 711M [ ~ ~ '. ~ ~ : ': ~ ' . , . ~ - : ~ · ~ ~ ~ I : -- --. : . , . . . : , . . ~ L : ~~ -~~~~~~%~ .. . · . , , : , ~ I · ~ . ~~~~ l~ I , , %% ~ . : : · ~ : : ~ : : · ! I ~ - :, l.:, ~ l::, ~ I :% ~~~-~%~~~~~~ ~ . , · , . ' ..... I , . [ ; i , ~ ~ , i ~ ~ [ ~ i ~ * ~--~. - · . ~--~% - , . . .... ~~~ : :-. %% T ~ e ~ ~ : ; , : ~ . ~ ; , , [ ~ : : ~ ~ [ ; , : . . , . . __ - , . . . : · , , : ,: ~~~-~~~~~~~, , , ~: ' ' ' ' ' . ~~~~ --~~ ~ ~ [ [ ~ ~ i i I ; ~ ~ L ' ' ' ~ ~ ' : .-- ~. .¢ · :: .... ~, 2. :- ~: ::~' '~ ? -- '?~' ~ '? --~ :~:~ ::' i '': : : R '~-' ~ : ~'.'.:' ~~ ~~T' I , . - ~ : i . i i : m : : : : i : : - - ~ · : ~ . ' : - ~ · ' ' ~ .-- . I __~~ .:: _~~~ w ~ ....... : ., Suggested form to be inserted in each "Active" well folder to check for timely' Compliance with our regulations. ' operator,'Wel~ Name and Reports and Materials to be received by: Required Date Received Remarks C°mpletion Report Yes. , 7 - . _.,. ~-- , .Core Chips . Registered Survey Plat ... Inclination Survey Directional Survey , ! Drill Stem Test Reports -. ! kqJPARUK ENC ! NEERI hE; TO: William VanAlen Transmitted herewith are the followincj' FF43~4: D.W. Bose/Shelby J. Matthews WELL AR(~ ALASKA, I 1',,~. Ua~¢n' g., ATrN- SHELBY J I~ATTI-iEI,.~S - ATOI 111 5-4~0ho?s. Coz ,,.. '" P. O. BOX 100360 AkK]-E)P, AIGE, AK. 99510 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 24, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton' Enclosed are subsequent sundry reports for the following wells' 1A-4 1Y-6 1Y-7 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, District Drilling Engineer PAV/GRU3L54'sm Enclosures 'UN 2 Oi~ & Gas Cons. 6ommissiol~ Anchoxa~e STATE OF ALASKA ~" ALASKA ,~L AND GAS CONSERVATION Cb,VIMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER [] 1. DRILLING WELL[] 2. Name of Operator ARCO Alaska~ Inc, COMPLETED WELL 3. Address P, 0, Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 571' FNL, 1851' FWL, Sec. 1, T11N, R9E, UN 5. Elevationinfeet(indicate KB, DF, etc.) 96' RKB 6. Lease Designation and Serial No. ADL 25646 ALK 2577 12. 7. Permit No. 83-68 8. APl Number 50-- 029-20950 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NoTIcE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stim u lation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) Altering Casing [] Abandonment [] Other 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). ND adapter flange & master valve. RU Gearhart. Ran CBL/CCL/GR/VDL f/8099'-2018'. Ran Gyro. RD Gearhart. NU adapter flange & master valve. Accepted rig @ 1300 hrs, 06/02/83. Ran CET - poor bonding. NU BOPE & tstd - ok. RIH & perf'd f/7340'-7342' w/4 spf. Set cmt retainer ~ 7285'. Stung into retainer; squeezed 250 sx Class G cmt. RIH & perf'd 7062'-7064' w/4 spf. Set retainer ~ 7028'. Stung into retainer; pumped & squeezed 100 sx Class G cmt. TIH & tagged cmt @ 7010'. Drld cmt, retainer @ 7028', & cmt ~ perfs (7062'-7064'). Tstd csg to 1500 psi - ok. TIH & tagged cmt ~ 7220'. Drld cmt, retainer ~ 7285' & cmt @ perfs (7340'-7342') to 7420' (below perfs). Tstd csg to 1500 psi- ok. Ran 3-1/2" completion assy w/tail ~ 7013', pkr ~ 6984', & SSSV ~ 1850'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Set pkr. Dropped bar & perf'd the following intervals: 7091'-7218' 7242'-7262' 7395'-7402' 7415'-7450' 7478'-7496' JUN 2 9 '!983 Alaska 0it & Gas Cuns. Commission Anch0ra§e Flowed to clean up well, Dropped ball & released guns (top Vann Gun fish @ 7614'). Closed SSSV. Secured well & released rig @ 1800 hrs, 06/08/83, 14. I hereby cert~y that the foregoing is true and correct to the best of my knowledge. //~~ ~.~ Area Drilling Engineer Signed Tide The spac w ission use Conditio~[s of Approval, if any: Set BPV. Date By Order of Approved by COMMISSIONER the Commission Date ___ _ Form 10-403 GRU3/SN31 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In¢ Post Office BOx 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1983 Mr. C V. Chatterton Commissioner State of Alaska Alaska Oil & Gas COnservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells' * West Sak SWPT #1 * Ciri Wolf Lake 1A-4 1Y-4 1Y-5 1Y-6 1Y-7 1Y-8 1E-14 2Z-1 2Z-2 2Z-3 2Z-6 2Z-7 2Z-8 * Due to the confidential material contained in these reports, please handle and file in a confidential manner. Thank you. Sincerely, P. A. VanDusen District Drill ing Engineer PAV/SH7'sm Attachments JUN 2 o,,~ , Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA " - - ALASKf-' AND GAS CONSERVATION C~ /IlSSION MONTHLY REPORT UF DRILLING AND WOI KOVER OPERATIONS · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-68 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20950 4. Location of Well at surface 571 ' FNL, 1851' FWL, Sec. 1, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) PAD 67' , 96' RKB 6. Lease Designation and Serial No. ADL 25646 ALK 2577 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Y-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. May ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1200 hfs, 05/05/83. Drld 12-1/4" hole to 2277'. Circ & cond hole. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7730' . Ran open hole logs. Cont drlg 8-1/2" hole to 8210' TD. Ran, Cmtd, & tstd 7" csg. Displ top 360' of well w/diesel. Secured well & released rig @ 0930 hrs, 05/15/83. SEE DRILLING HISTORY 13. Casing or liner 9-5/8", 40 Arctic Set 7" 26 0#/ run and quantities of cement, results of pressure tests .0#/ft, J-55, BTC csg w/shoe @ 2249'. Cmtd w/900 sx Arctic Set III I cmt. ft, K-55, BTC csg w/shoe ~ 8180'. Cmtd w/940 sx Class "G" cmt. & 250 sx SEE DRILLING HISTORY 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/FDC/CNL/Cal f/2249'-7718' . 6. DST data, perforating data, shows of H2S, miscellaneous data N/A JUN '~ J.-.~ L~ ,J Alaska Oii ,:::. Gas [;~r~. ,'. · · u Orllll'llS~lurl ~ -' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Area Dri ] 1 ing Engi neet DATE ' NOTE--Repo, r~ on ~his f,C'rm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas,~or~servation C' -ommission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 H I LL/MR26 Submit in duplicate t-~ _.. --~ ~ ~,~ 1Y-7 DRILLING HISTORY NU 20" Hydril & diverter & tstd same. Spudded well @ 1200 hrs, 05/05/83. Drld 12-1/4" hole to 2277'. Circ & condition hole. Pump pill. Ran 57 jts 9-5/8" 40#/ft, J-55, BTC csg w/shoe @ 2249'. Cmtd 9-5/8" csg w/900 sx Arctic Set III & 250 sx Arctic Set I. ND 20" Hydril & diverter. Instld 7" casing spool & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 7730'. Ran DIL/SFL/SP/GR/FDC/CNL/Cal logs f/2249'-7718'. Cont. drlg 8-1/2" hole to 8210' TD as of 05/13/83. Circ btms up. Ran 208 jts 7" 26#/ft K-55 BTC csg w/shoe @ 8180'. Cmtd 7" csg w/940 sx Class "G" cmt. Bumped plug to 1800 psi - ok. Performed top job on 9-5/8" x 16" annulus while displ 7" cmt. Pumped 103 sx Arctic Set I. Displ well w/NaC1/NaBr in csg w/top 360' of 7" csg to diesel. NU FMC tbg head & tst to 3000 psi - ok. Secured well & released rig 0930 hrs, 05/15/83. HILL/DH20 06/13/83 KUPARUK RIVER UNIT SEQUENCE DF EVENTS WELL: /) ~ '" -7 OPERAI'ION: TlR[ EVENT .. O~l~ I:ZU WI~£LtlqE UklIT 09~0 i000 PlC~r=o OPE~4E.b .SWA& VALVE. I O&O 5F_..T" TOOLS ~--¢ 72_75 tAD P~i5 I I ~ 0 -iai5 5~ w F=.Lt..... 'R..O 5H, P 5H'-F UPDEE 7_79t PS/ J 57 ~ ~ LOW&R. ~5~) PSI_ 1.5 ?7 ¢ KUPARUK ENGINEERING TRANSMITTAL ~ ~'~ TO' W'illiam V-a-n Alen Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, FROM' D.W. Bose/Shelby J. Matthews WELL NAME' __ F - FILM~ PC - PHOTOCOPY i.~ACKNOWLEDGED: - · ARCO AL:ASKA, A'TTN' SHELBY J. MATTHEWS - AFA,/W~[a Oil& Gas Con~. Commission P.O. BOX 360 Anchorage ANCHORAGEs AK. 99510 ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 9, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Y-7 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on May 16, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ewin Area Drilling Engineer JBK/JG'sm Enclosures ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-68 3. Address p.O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface' 571' FNL, 1851' FWL, Sec. 1, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 96' RKB 12. I 6 . Lease Designation and Serial No. ADL 25646 ALK 2577 8. APl Number 50-029-20950 9. Unit or Lease Name I(uparuk Ri vet 1 In i t 10. Well Number IY-7 11. Field and Pool Kuparuk River Field Kuparuk River Oil 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 I-~ 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). Ar-tco Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1 :The procedure will be as follows' 4) 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported_ on subsequent reports. The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuliwith'in-the permhfrost' interval. A 5000 psi WP wireline lubricator will be used and tested on ail wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start' May 16, 1983 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tme.Area Drilling Engineer Approved by. COMMISSIONER ~,.proved Copy Returned By Order of the Commission Date ........ Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANOUM State of Alaska TO: THRU: I~n~ie C. Smith C om mi s s ioner FROM: ! ¢'_~_~~ Bobby Foster ?e'tro le'um Ins pec"c.o :r ALASKA/~~D 6AS CO~SERVATIO~ COMMI SS ION ~. V .[ ~r~on ~'-'~' DATE: chai ~r~a~~ / . Ma~' 9, 19 82 TELEPHONE NO: SUBJECT: Witness BOPE Test On ARCO's 1Y-7 Sec. 1, TI iN, R9E U~4 Permit #83-6 $ Saturday,..May._ 7, 1983: I traveled this date to Prudhoe Bay '~n~ 'witnessed the DOPE test on ARCO's 1Y-7 in the Kuparuk field. The test began at 3:00 p.m. and was concluded at 4:30 p.m. and w~s concluded at 4:30 p.m. As the attached DOPE test report shows there were no failures. In summ~ry, I witnessed the DOPE test on ARCO's 1Y-7. 02-00IA(Rev. 10/79) STATE OF ALASKA ALASKA OI~~- GAS CONSERVATION CfP~4/SSION B.Q.F.E. Inspection Repo~ Operator_ Well_ Location. Sec Dril linq' Contractor~Rig Location, General_~~~. Well Sign_ - ceneral Housekeeping ~eserve p~t . Rig BOPE Stack 1. Annular Preventer Blind Rams / I Choke Line Valves H.C.R. Valve / Kill Line Valves /~- Che~ Valve ./ Test Pressure 1 oo ~o0~ - ACCUMULATOR SYSTEM Full Charge Pressure ~/~2 Pressure After Closure psig psig min~ sec. rain ~ sec. Pump incr. clos. pres' 200 psig -- Full Charge Pressure Attained: 'Controls: Master ~ memote~~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly . / Test Pressure Lower Kelly /- ~ll ~pe / Test Pressure Test Pressure Inside BOP j Test Pressur~~o Choke Manifold '~/C? ~ Test Pressur .~~.~ No. Valves ' ~ N°. flanges ~'~'~ AdjuStable Chokes / Hydrauically operated choke / _ ~ , Test Time' / /~ hrs .days and Test Results: Failures~ Repair or Replacement of failed equipment to be made within_ Inspector/Ccmmiss, ion office notified. Remarks: L~ ~ / Distribution ,- orig. - AO&QCC cc - Operator cc - Supervisor Inspe -- April 29, 1983 ~. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk River Unit IY-7 ARCO Alaska, Inc. Pe~it No. 83-68 Sur. Loc. 571'~<L, 1851'F~, Sec. 1, ~1- ~ RgE ~ Bt~ole Loc. 1518'~L, I121'FSL, Sec. 1, TIi~, R9E, U~.~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the. above referenced ~..~el]. if coring is conducted, a one cubic inch chip from each foot of recovered core is required. 'Samples of well cuttings and a wuc] log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). if svailab]e, a tape containing the digitized log information shall be subr~:itted on all logs for copying except experimental logs, velocity surveys and dipmeter s~.~rveys. ,:~mn~'~' ~ r~vers~ in Alaska and their drainage, systems. W, ave.. been 'classified as .intportant for the sp~%zning or miKration of anadro~ous~o~.~o'~ Operations in these areas are ~uo ct to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Ad[aini~trative Code). Prior to co~pmencing operations you ~,~ be contacted by the Habitat Coor(~inator's Office, Department of Fish an~ Ga~-~e. Pollution '-~: ~, .... ~ ~.tate is prohibited by u~ an~_,~aters o~ the e Chapter 3, ArtiCle 7 and the reguiatiop, s°promulgated' thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal !~ater Pollution Control Act, as amen~ed. Prior to co~encing operations you may be contacted by a r~presentative of the D~part~ent of Environmental Conservation. To aid us in scheduling field work, please notify thi.~'~ office 24 hours prior to com~encing installation of the blo~out Mr. Jeffrey B. Kewin Kuparuk River Unit 1Y-7 -2- April 29, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, Where a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the eVent of suspension or abandonment, please give this office ~adequate advance notification so that we may have a witness present. Very~tru!y you!_s, C V Chatterton ' By ORDER OF TH~ CO~SS~ON Chai~n of Alaska Oil and Gas Conservation Co~ission Enc i o sure cc: Department of Fish & Game, Habitat Section w/o encI. DePartment of Environmental Conservation w/o encl. be ARCO Alaska, Inc. Post Office B~ ~60 Anchorage, Alaska 99510 Telephone 907 277 5637 April 18, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1Y-7 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1Y-7, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on May 2, 1983, your prompt approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, dBr/d~2k59:llm Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ALASKA L,,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [J~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~]X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 571' FNL, 1851' FWL, Sec. 1, T11N, RgE, UN At top of proposed producing interval /I~R 0ii ~ t~-'~;~ ,,~. u;,,,u,qlSSl~ ,! ~-. ~-.".., :.~flm Target @ 5995~ TVD; 1520' FWL~ 1320~ FSL, Sec. 1, T11N~ RgE, UM-' At total depth 1518' FWL, 1121' FSL, Sec. 1, T11N, RgE, UH 5. Elevation in feet (indicate KB, DF etc.) RKB 96', PAD 67' 6. Lease designation and serial no. ADL 25646 ALK 2577 9. Unit or lease name :~ Kuparuk River Unit 10. Well number 1Y-7 11. Field and pool Kuparuk River F~eld Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 32 mi. NW of Deadhorse miles 3429' FEL @ surface feet I1Y-8 well 60~ (~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease I 18. Approximate spud date 8194' MD, 6701' TVD feet 2560 I 05/02/83 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 267F, psig@~80OF Surface KICK OFF POINT1500 feet. MAXIMUM HOLE ANGLE 42 oI (see 20 AAC 25.035 (c) (2) 30?_3 psig@ 5932 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT i SIZE ,Hole Casing 4" 16" i 2.-1/4,, 10-~/4,, 2-1/4" 9-5/8" 8-1/2" 7" Weight 65# 45.5# 40.0# HF-ERW 26# K-55 22. Describe proposed program: ;ASING AND LINER Grade Coupling H-40 PEB K-55 BTC J-55/ BTC BTC Length MD TOP TVD 80' 29' I 29' I 41 ' 29' I 29' 2147' 8166' 70' ~ 70' I 28' 28' MD BOTTOM TVD 109' Ii 109' 70'I 70' 2217' I 2200' I 8194' Ii 6701 ' (include stage data) ±200 cf 750sxAS I11 & 250sxAS I 377 sx Class "G" neat 318 sx Class "G"extended ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8194' MD, (6701' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 ps~ for annular). Expected maximum surface pressure will be 2676 psig. Pressure calculations are based on latest reservoir pressure data. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 1Y-8 will be 60' away from 1Y-7 @ the surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~ 2272' MD, approximately 500' MD 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space be fo~:::om~'sion use' Samples required []YES ~NO Permit number APPROVEDBY / Form 10~01 GRU2/PD22 Mud log required I--JYES J~NO Area Drillin9 Engineer above top of West Sak Sands. DATE /~ CONDITIONS OF APPROVAL I Directional Survey required ~_ES []NO v~l date IAPl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE April 29, 1983 Submit in triplicate Bas Cons, bt}remission ~urface Oiverter System. I. 16" - 2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi double ,studded adapter. ¢. 20" 2000 psi drilling spool w/lO" side outl ets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automat'ically upon closure of annular preventer. 6. 20" 2000 psi annul ar 'preventer. · 7. 20i'm' bell nipple. Maintenance & Operation. 1. Upon initial installation close annular preventer and verify that ball valves have opened properlyo 2. Close annular preventer and blow air through diverter lines 'every 12 hours. 3. Close annular preventer in the event, that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do no._....=~t shut in well under an), circumstances~. __ 16" Conductor 2, 2 ]983 ~ . ~i~ka Oil ~,. ads L;ons. LJOrft~lliSSiO~ Anchnra(;;ie ANNULAR PREVENTER m BLIND RAMS _1 L PIPE RAMS 7 m ,) PIPE ARMS , ,q HD D D%GRAM .-'1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11' o 3000 psi x 13-5/8" - 5000 psi spacer spool ¢o 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" o 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams '9. 13-5/8" - 5000 ps~ annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WI~( 1S00 PSI DOWNSTREJa~4 OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE, 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. .CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETPaRCT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO PSI AND HOLE FOR IO MINUTES. BLEED TO 6. OPEN ANNULAR. PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO¢~3-ooO~/JPSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE ~ AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE P~AMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPEP. ATE BOPE DAILY. APR 2 ANNULAR PR£VENTER -11 BLIND tL&MS 't ( ) L PIPE ARMS 9 , PIPE ARMS HD 3 CSG D IAGRAI4 ~2 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-i/16" - 3000 psi tubing head 4. 7-!/16" - 3000 psi x 11" - 3000 psi double studded adapter 5. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 7. 13~5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 9. 13-5/8" - 5000 psi pipe rams 10. 13-5/8" o 5000 psi blind rams 11. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUIO. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIM)T IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAO. 3. CLOSE ANNULAR PREVENTER AND..CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. S. MINUTEs.INCREASE PRESSUREBLEED TO zETCRtl~'~ PSI AND HOLE FOR 10 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. · 7. INCREASE PRESSURE TO PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTBvl TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. I%RKE SURE MANIFOLD AND LINES ARE FULL OF ARCTICI DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KDOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE T~-~Tr-Q~Er'AI ~F. jE~q~C) FUNC- TIONALLY OPERATEK ~., I~). FIEV r l.y DAILY. APt:, 7, 2 I983 APR J983 35 LOCATED IN PROTRACTED .~F..~!,'TWP. IIN~,RGE. 9 E.tUM!A.? M...ER!DIAN. RESERVE'PIT !'°'O! ..,.....,.. .... I I '-_I' ' RESERVE PiT _o RESERVE, PIT ..... ,.. .. .~ a~'' .' PHASE II .~... .- ,., ' I. Y~5975115. Xa 5514602~ LAT. 70° LONO. 149° 44~.818' 211 '~L~ 1792'FWL ~. Y=597511 5.50 X= 531520.06 L~T. 70° ~0'35.0296" LO ~G. 149044' ~9.070' 211 FN L,,1852' FWL 3. Y' 597~115.~4 X~ 551580.12 ~ ~ 70° [0~0. 211' FNL~ 191~'FWL i .., ~ §97§1111.44 X= Ii:5164'0.4 § LAT. 70° 20' $5.0P. 60" LON O. 149°4~~ 35.5152' 2 I1' FNL~ 1973' FWL Y= 5 974755.49 X. 5:3 164~,43 · LAT. 70020 :~1.4857 LONG, 149 o 44' ,35.597 571' FNL~1971 FWL 7. Y~ 59747§§.§1 X' 531 52_C)1.21 LAT. 70°20 LONG. 149°4~' :59.110" { '571' FNL,1851' FWL Y- 5974755.48 · "8. Y. §97475B.4~ X. 5:51580.41 : X, .531460.§~ LAT. 70° 20~ ~1.4881" .' LAT. ?O°20'Sl. 4951' LONG. 149°44~ ~7. :551" 571' FNL~ 1911~ FWL D.S. A SURVEY I 12 LONG. 149° 44 '40.854" 570' FNL,1791'FWL VICINITY MAP 5 cole': I"=lmi. NOTES' · 1.. ALL Y 1~ X COORDINATES ARE ALASKa, STATE PLANE~ZONE 4. ~. DISTANCES' TO SECTION LINES ARE GEODETIC. 3. SEE REF.. DWG. 2?--9138, SH1; 7Y-12-~OOI,REV. 7A. 4. DRILL SITE AND Y 8~ X COORDIt!,~,TE$ ARE BASED ON MONUI.'.~NTS I'Y EAST AND' I'Y MIDDLE BY LHD ASSOCIATES. Ii, EL. BASED ON MON. I'Y MIDDLE BY [.,~tD ASSOC. SURVEYOR'S. CERTIFICATE- I HEREBY CERTIFY THAT I AM PROPE_.RLY REGISTERED AND LICENSED TO PRACTICE LAHD SURV.---YINB IN ,THE STATE OF ALASKA, AND THAT THIS PLAT'REPF~"-'SENI~ A ~IURVEY MADE UNDER MY DIRECT SUPERVISION~ ANDTH~T. ALL DETAILS ARE CORRECT AS OF' MARCH I, 198:5. 4.1~' -- .~.,~lllll.. , I - ' ' '~ '" .',RCO'-,~loska. Inc. L-Kupc'ru ' [;roJec, North Slope Drllllnl~ AS DULLY LOCATIONS " PI-:A~E I _ ~ _ ,,.,,,, .., ,,. I drawn by · J.O.' I dv~'g, no.9.05 "~5.12d 28 CHECK LIST FOR 'NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc 8) (3) Admin ~./~L,~. (9z thru (4) Casg ,~J~./~ ~-~/-~3 (12 thru 20) (5) BOPE ~.~.,~. (21 thru 24) 9, 10. 11. Company Lease & Well No. YES NO 1. Is the'permit fee attached ................................. 2. Is well to be located in a defined pool .' ............... '' ' '' ' 3. Is well located proper distance from property line ....... 4. Is well located proper distance from other wells ....... 5. Is sufficient undedicated acreage available in this pool . . 6. Is well to be deviated and is Well bore plat included .. . 0 ,~ 7. Is operator the 0nly affected party. ........... ........ 8. Can permit be apProved before ten-day wait .............. Does operator have a bond in force .................................. ..~.. Is a conservation order needed . Is administrative approval needed 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. I's conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... Wil Wil Wil Is Is Is 1 cement cover all known productive horizons ..................... 1 surface casing protect fresh water zones ....................... 1 all casing give adequate safety in collapse, tension and burst.. this wei1 to be kicked off from an existing wellbore ............. ~7 old wellbore abandonment procedure included on 10-403 ............ adequate well bore separation proposed ....................... ,... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~z DoCs BOPE have sufficient pressure rating - Test to ~OO psig .. ,~ Does the choke manifold comply w/API R?-53 (Feb.78) .................. Additional requirements ............................................. REMARKS Additional Remarks: z Geology: Engineering: WVA~ JKT__~ HJH ,/ reV: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. .o I C CAE E,, ,'3 0 o, 000 C,; 0 000 <:., o 0 01 d O04 0(~ R 002 OO4 002 009 006 O65 O65 O65 065 065 O65 O65 ft65 ( '~ ,' ['~ F .4.. i,,..~ i~11111 il ii:~ l! [:] .~ ( . I ',.~ ('i (; P (] :R r.4 q ~..' SP SF 9 P f.'.i b DF~PT SP R :H ~) ~", SP GR I o 1,, # '? 6~; 0. - > 7. 7.490. 2, 5F.. 7 5 ('1 ()0 u '3750 ('l r; 0 ,') '7 (.) () 0, -2 !5. 't 2 1. ('? 2.7227 4.2~g.~_ 2. 959~: l,f;D 54.7a52 4,. 2 ~:~ 9 ! 7h5;', fl,l', (t r ~ 0 ,. ) C i, I., [ 0352 5, ~:9 l 4 :I [,[) 3. 3535 2.70.12 0 , 017 6 ~.2383 .3, () .$ 8 a - '..). ()059 5.1.641 2.8945 0.1 03 o 9. 3750 77.3 4 O.02ac; 7500 ! 0.21 0 9 O. 064c? 9.6 0 94, 5.5 9 3 k~ lO, 12... 0 9 I,'¢ 4, 4, 8. 0. u356 !. 0,093 g !, ,,ri 37 5 ,0 2 6 4, '2, I 4 2 a ,,, '4 g 9,2 ,,5. 0 0 L..r4 n ,111il ,,,, ., ., J { DEF'T ;,3afl · ,~,"- l"', l:, S~'I '" : .,,,.' 111.. {557 ~- l!' 1, r,, 1 7 q 7~} SiP -3~.0000 CR 120, r~O00 ~z p[4i -099 250c~ GR 1. ~f'~. 5''~ '". -9oq,2500 B'~ -q99.250,) DF:P~c t~,l C'(}. "~"~i' t.:, ,',~,i":' [ I1 3.71()9 '] t~' 3.0547 4, 375 b~: PH: 1' - 9 qq 2 ..... 5:0 (') D t_;,.: P 'F' 8 P . , - 99:~.~, 2500 t:q C i':~' t.:i...: :-:~ 99; 25: O 0 C N'L: :" 999,2500 ,.. ....... '.,A.. . ~:... ~ .... .. ., ...... .., . 2500 l': - a,:>,~;~. 250 ~ ~'~(:,I,',~ ~ -oq9.25(')(~ F("".N'I -4i.'~.' 250(> Iii. n C a i. [ I "'., C'AL[ I L l) D h: F-}- 1 ( .... l, '[ D ['~ H ,I..' C A L I I 'r., .ri') I t, 1') C, A L f 3,1152 - 9 99.2500 10.0844. 3.0 A "~ -999,2500 3,0 P40 -999,250(.: 11,5781 3.5113 -909,2500 11,0781 3,1504 -q99.2.5~)0 .11.1641 l, 99o2 -999,2500 9 , 7 3 '% 4 3047 2500 .B4 .~7 3.0 ~( 7 q ' . 97i:J;6 2 7500 -qqq,2500 11,414~ '999,25t 0 9,75.q0 , 2.29 t 0 - '..) 99.250 Ci (' i..-,r'~ [1 Ii i ail ,i:.] ii_,. [:-] I ~P :~ [,.:i [3 -999. 250~, 2.2,65F, ,,, 999.2509 1) k H ~ ~ ,.. o q 0.25 (" ~.,,' 2.996! -gtJg. 250n 3.2.!, ?,'9 Ir,D -999.2500 ['~F ~{tl -99o,.2500 ..'?,..5469 -999,2500 --a99. :2.,. -999.!~500 -?gq, 25f')r} -,~99. 2500 2, .2.246 q99 ~ b 'ii 9.' 25 0,..' 9., 613 ? '1 f,D ,- q 99.2, 500 l) R H 0 .- ':' 9 g. 25 o .q C t~ [. I '99,9 , 2500 3. ? 3 6 '~ .1.. 2,2793 - 999.25 *:'~ 0 10. d. 06,3 3.07B1 -9q9.25n0 l 0 . 4844, 3,23~'3 -999,2500 I0 4Q . . 22 2,6172 -999. 2500 tO.. 3438 2.1.719 -999.25o0 10,7Q!.3 2,257~'~ - (~ 99,25 ':) 0 .1:1.5156 2,42'1.9 -99g, '~500 10. 516 2 5352 -99 q: 2500 10.42 q7 2.72~7 - 9 99,2 500 9.5234 3, .... 21.5 .~..~{'e99, 2500 10. 3672 3.3848 - 999.25 t:l 0 69,93'15 -~'99. 2500 R~iRA 77 . 0 F, 25 !: ,'::' F' l' -999 250P' - q a 9.250 (.. k .v F:.' -,.5~. 5(:,?5 iD E', P T 42 n 0 S P - 57 RF!C.a -999 G':~ a o'~ ~ t,." % ,,.,t, * ~:,; ,', ('! 1", ~. ,. R H r', 'F. - '4 ':: q, 2 fi 0 0 -, o ,4 ti) . 25 I),;)C/, [.. ,- q 9, 9 . 250 ,., 3.0254 :TLr: -ag9.250r) CALl -qg9. 250{) -999.25nr; 3. :164'~ .TLD -<399.2,500 [.~[i. Ht; -999,25C)0 C 4I'., i · ,, 9 q 9,25 f'l C, 3.263'1 9,2500 ,-.909 . 25()(, 9.25 C) 0 3, P 75 l) I [., 13 · "999,250f: CALZ ,,-q 99 25 (') f'~ D R H 0 ... ,250:~ (.iAL I - 9,9. 9,2 5 o o ] 0 , '/575 3. l~755 -999.25o(> 9.7(-.;,56 4,3711 -999,2500 1. 0,65 G 3 3.30 a 7 -q9g. 25(')(> 11,4375 3,5].17 '999,25~)0 :t 3.3 ~'. 2 ~.'; 4,1875 -c~99,2509 12,50 n 0 3.54, 49 -g99,2500 12.6406 500 554'7 3,3396 '999,2500 i3,1562 4.1602 -~99,25n0 13.~,4~ 4,5391 - .':) 9 .., , 250 0 I 2. 6797 4.8750 ; P t:C F" r GR SP GR DE P 7 SP G R D t'i P sE Sp 7 O. 5 C', 0 0 !',,,' ';4: t~. 1 6.6 7 9 ? 1' .I.., ~! 6 1 . ~:.,. 72 .r; () ~,( F' M I - G R 0 {)O. 0 F C N !,, 44,23 a 3 494,750n 4,246.i 39.257,q 5c I . 4,0 '4 6 ".* 7,9,15~ 560,0000 3.8,909 4.12P, 9 4:7. 4609 432. 4 . 24:6 6,8164 42. 6270 470,000t) 6. I 4, 8 ~.~ 41.21.09 436. Ou¢),.~ 4. 2266 7,507 fq a. :.:135 7. '¢~ .!9.. · 5 (.) 0 I 3.5 2 34, 4 ~, '4590 ,/'* .2t :I t< CA t,.! 9 R ~ U IbP .1 i., P, l [, D [)R CAr, I b, D U k" i'f () CAL, I I ,L L RL .,:) {) R .[.t",.:] 0. O039 1 3. 0703 5.0703 1. 3. 8,7266 -0.00!0 12.4141 4..91.,()2 '7,6875 0,0 J, b 6 14,4453 6.a98,4 o~oo83 17,~75 468 [~ 0 0 4 9 ,14.22~46 2422 , 75 :12,94,53 -0,0034 I0.5547 13,9 297 - 0.0044 I 1.89a4 1~,5234 15,3125 L-r, an,,,,;,..~[.: { 59, 1 'I P.92. 7.35~44 1 ~95. OttO0 62, O625 I 1. 3594. 45.507~ 4 ,'+ 9 , ,h :~ '[t !: 4.0547 11.0703 6.9 ,:i 1 '* 40.0234 2000, 293,5000 · 4 .S391 CA,[,I ii L, f) l[L fT~ C ;~ L :Il 13.57 0 3 0,0 049 12,0703 ! 3. 3750 o. 007 12,2500 7.02.!1 -0,0C, 59 16,53k3 25.79 f'; 9 -0.4424 8.9082
