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186-142
._..............._ p-rD 6 $ G - 14Z.. Loepp, Victoria T (DOA) From: Hunt, Jennifer L(DOA) Sent: Monday,June 22, 2015 8:50 AM To: Sharon.K.Allsup-Drake@conocophillips.com Cc: Loepp, Victoria T(DOA) Subject: 2T-03( PTD 186-142) Change Status from Suspended to Abandoned Follow Up Flag: Follow up Flag Status: Flagged SCANNED JUL 2 12015 Good Moring Sharon, I have updated the status of this well to P&A. Please let me know if you have any further questions. Thank you -Jenni Hunt Alaska Oil and Gas Conservation Commission I Statistical Technician II I 907.793.1241 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 Jenni Hunt at (907) 793-1241 or jennifer.hunt@alaska.gov. 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial produ(~tion scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA D Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type Poor Quality Originals: Other: ~.~.~O. NOTES: TOTAL PAG ES.' ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL n DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES:~v/'-~ (at the time of scanning) SCANNED BY.' BEVERLY E~REN VIN~ARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: PAG ES: Quality Checked (done) RevlNOTScanned.wlxl RECEIVED STATE OF ALASKA MAY 10 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDAOACC la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑✓ 1b.Well Class: 20AAC 25.105 20AAC 25.110 • Development ❑✓ Exploratory ❑ GINJ El WINJ ❑ WAG ❑ WDSPL❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test CI 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 27,2013/ 186-142/313-110 ‘ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 September 5, 1986 50-103-20073-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 377'FSL,556'FWL,Sec. 1,T11N, R8E, UM September 11, 1986 2T-03 • Top of Productive Horizon: 8.KB(ft above MSL): 117'RKB 15.Field/Pool(s): 1194'FNL, 1390'FEL,Sec.2,T11N, R8E, UM GL(ft above MSL): 77'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): • 978'FNL, 1512'FEL,Sec.2,T11N, R8E,UM 7426'MD/5712'TVD Kuparuk Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498945 y- 5970357 Zone-4 7897'MD/6067'TVD• ADL 25569 TPI: x-496997 y- 5974066 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-496875 y- 5974282 Zone-4 1714'MD/1697'ND 2667 18.Directional Survey: Yes ❑ No❑✓ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 2360'MD/2224'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD CCL not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 32' 115' 32' 115' 24" 234 sx CS II 9.625" 36# J-55 32' 3174' 32' 2787' 12.25" 800 sx AS III,350 sx Class G 7" 26# J-55 30' 7893' 30' 6064' 8.5" 640 sx Class G,300 sx AS I 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/IVO) 3.5" 7458' 7306'MD/5625'ND,and 7413'MD/5702'N[ perfs plugged off , 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7426'cement plug 29 bbls 17 ppg Class G Satalip APR 2 8 2014, 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes u No ✓ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 RBDMS MAY 10 2O13\20%CONTINUEDOREVERSE 17F'e / �/Subm Tal only T / 29. GEOLOGIC MARKERS(List all formations and ma..._.s encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 2360' 2224' needed,and submit detailed test information per 20 AAC 25.071. N/A Formation at total depth: 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265-1102 Email: James.Ohlingeracop.com 5/1//y Printed Name Lamar Gantt Title: CTU Engineering Supervisor Signature 40,4,1_,N i ,� Phone 263-4021 Date - --/I'//3 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 2T-03 Pre Rig Well Work Summary • DATE SUMMARY 3/12/2013 (PRE-CTD) : POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, TORQUED T LDS TO 450 LBS. 3/13/2013 PULLED ISO SLEEVE @ 1714' RKB; TAGGED w/SIMULATED GYRO DRIFT @ 7863' SLM ( EST. 261' OF RAT HOLE ); MEASURED BHP (2746 psi ) @ 7530' RKB; DRIFT W/ DMY WHIPSTOCK TO 7500' SLM; SET 2.81"XX PLUG &AVA CATCHER @ 7359' RKB' PULLED GLV's @ 6707', 5854' RKB, SET DV @ 6707' RKB. IN PROGRESS. 3/14/2013 PULLED OV&GLV's @ 7221', 4662', 2734' RKB, SET DV's @ 5854', 4662', 2734' RKB, CIRC OUT W/ INHIBITED SEA WATER AND DIESEL FP ( PUMP 275 BBL CIRC OUT). LRS & DHD TO CMIT; IN PROGRESS. 3/14/2013 (PRE CTD) : CMIT TXIA PASSED TO 2550 PSI, MV, SSV, SV PASSED DDT. MV, SSV, SV PASSED PT, UNABLE TO PREFORM SSSV DDT DUE TO HYDRALIC PUMP ISSUES. 3/15/2013 (PRE-CTD): SSSV-DDT(PASSED)WITH A GAIN OF 0.5 PSI IN 30 MIN. 3/15/2013 ASSIST DHD PERFORM A PASSING SSSV CLOSURE TEST. IN PROGRESS. 3/16/2013 SET DV @ 7221' RKB; MITT( PASSED ); PULLED CATCHER & 2.81"XX PLUG @ 7448' RKB. 3/22/2013 PERFORATE INTERVAL 7451'-7456' USING 2" HSC 6 SPF 60 DEGREE PHASING, CORRELATE TO TUBING DETAIL RECORD 17 DEC 2011, READY FOR COIL. 3/27/2013 Lay in 29 bbls 17 ppg, class"G"cement from 7,860-ft corrected depth. Squeeze—3 bbls to perfs. Clean out tubing to est. TOC at 7,440-ft MD. POOH jetting across all jewelry. Freeze protect. Trap 900 psi on tubing for over balance. Ready for Slickline in 72 hrs. 3/29/2013 BRUSHED & FLUSHED SSSV @ 1713' RKB; FUNCTION TESTED, GOOD. TESTED TBG 1500 PSI, GOOD. TAGGED TOC @ 7389' SLM/7417' RKB; WORKED BAILER TO 7394' SLM/7422' RKB. READY FOR E-LINE. 3/30/2013 LOG GYRODATA GYRO FROM SURFACE TO 7390'WITH GAMMA CCL, REPEAT LOG TO SURFACE. JOB COMPLETE ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: 2T-03 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 4/3/2013 6:00:00 AM Rig Release: 4/23/2013 3:00:00 PM Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 04/01/2013 24 hr Summary RDMO for 2T-03 12:00 00:00 12.00 MIRU MOVE MOB P Move rig to 21-03 04/02/2013 Move to 2T-03.Well pad prep work had to be redone,grade pad and install tree valves.Spot rig modules. 00:00 03:00 3.00 MIRU MOVE MOB P Rig modules and shop on 2T location 03:00 21:00 18.00 MIRU MOVE MOB T Well pad grade had to be redone and tree not prepared for rig up(tree valves not installed). 21:00 00:00 3.00 MIRU MOVE MOB P Pad prepped sufficiently to spot rig. Spot rig modules for 21-03.. 04/03/2013 Continue to troubleshoot BOPE test equipment failures, replaced R1 valve on MP line, BOPE test in progress. 00:00 10:00 10.00 MIRU MOVE MOB P RU Putz,berm up around cellar, RU interconnect,steam, landings, load pits. Spot tiger tank and RU hardline to rig from tiger tank. NU BOP stack. **Accept rig at 0600 hrs** 10:00 20:00 10.00 MIRU WHDBO BOPE P Perform initial BOPE test 250/4700 psi; annular 2500 psi.AOGCC John Crisp onsite to witness test. Troubleshoot tree valve issues.Valve crew and FMC called out several times to service tree valves,finally able to get shell test against master valve. Made crew change @ 18:00. Troubleshoot air in test pump system, also found R1 valve on MP line to be leaking, replaced valve and got good test. 20:00 00:00 4.00 MIRU WHDBO BOPE P Still leaking off slowly,shut surface safety valve while waiting on FMC crew to set 2-way check in BPV profile. BOP test in progress. 04/04/2013 Continue troubleshooting BOPE failures, pull BPV and run TWC, perform initial BOP test,witnessed by AOGCC John Crisp. Replace MP Lines, upper blinds,C-10, R-7 valves.Test both swabs, R-1, R-7, C-10, and BL2 valves, all tested good. 00:00 02:00 2.00 0 0 MIRU WHDBO BOPE T Waiting on FMC crew from Prudhoe 02:00 05:30 3.50 0 0 MIRU WHDBO BOPE T PJSM. PU FMC lubricator,pull BPV, lay down BPV, PU two way check, set same, lay down FMC lubricator, test two way check 250/4700 psi. 05:30 13:00 7.50 0 0 MIRU WHDBO BOPE T End of initial BOPE Test. BOPE test witnessed by AOGCC(John Crisp) Page 1 of 18 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 13:00 13:30 0.50 0 0 MIRU WHDBO BOPE T Rig down test equipment, R/D test pump and freeze protect 13:30 20:45 7.25 0 0 MIRU WHDBO BOPE T PJSM to replace MP line, Upper blind shears,and C-10 valve and R-7 valve, blow down stack and surface lines, replace failures. 20:45 00:00 3.25 0 0 MIRU WHDBO BOPE T PJSM. Fluid pack BOP equipment, test swab valves, R-1, upper blind shear,C-10, R-2, R-7 and BL2 valves, all tested good. BOPE test complete. **Nabors charged for 24 hrs of downtime** 04/05/2013 PT inner reel lines, pull TWC, LD FMC lubricator. Load coil with SW.MU BHA#1 pilot hole assembly. RIH and tag TOC @ 7,426,swap hole over to milling fluid, mill WS pilot hole from 7,426'to 7,580'. 00:00 01:30 1.50 0 0 MIRU WHDBO CIRC P Reverse circulate with water, PT inner reel lines. 01:30 03:30 2.00 0 0 MIRU WHDBO MPSP P PU FMC lubricator, pull TWC, LD FMC equipment. Service and test PDL's. PJSM. 03:30 03:30 0.01 0 0 SLOT WELLPF SFTY P 03:30 04:29 0.99 0 0 PROD1 WHPST SFTY P Pre-spud 04:29 06:23 1.90 0 62 PROD1 WHPST PULD P PJSM. Load coil with seawater, MU checks. PU/MU BHA#1 Hook coil to tool and surface test. 06:23 08:47 2.40 62 7,430 PROD1 WHPST TRIP P RIH, EDC Closed, pumping seawater returns to TT 08:47 09:53 1.10 7,430 7,380 PROD1 WHPST CIRC P Tag TOC, PUH open EDC and circulate hole to Bio Water, PUW=37K Official TOC corrected from K1 is 7426 Post tie in 09:53 12:41 2.80 7,380 7,444 PROD1 WHPST MILL P Bio around, Close EDC, RIH to mill (Counter change 14'), ROP=30FPH, Stalled multiple times @ 7452.5 to 7452.9 call this the X nipple @ 7448 12:41 13:23 0.70 7,444 7,465 PROD1 WHPST MILL P Through X nipple and milling ahead @ 25 FPH, @ 7457.6 ROP dropped to 17.8 FPH 13:23 15:59 2.60 7,465 7,480 PROD1 WHPST MILL P 7465.2'Stall twice as working through, Stalled again 15:59 16:05 0.10 7,480 7,439 PROD1 WHPST WPRT P 7480',Wipe up hole to log K1 16:05 16:11 0.10 7,439 7,448 PROD1 WHPST DLOG P Log K1 for-18'correction 16:11 16:17 0.10 7,448 7,462 PROD1 WHPST WPRT P RBIH to mill, 1.46 BPM @ 2890PS1 FS, ROP=20 FPH 16:17 18:17 2.00 7,480 7,500 PROD1 WHPST MILL P Continue milling 1.46 BPM @ 2,892 psi FS, ROP=20 FPH 18:17 18:32 0.25 7,500 7,500 PROD1 WHPST WPRT P 100 ft wiper trip, saw motor work @ 7,467'both up/dn 18:32 19:32 1.00 7,500 7,520 PROD1 WHPST MILL P Milling 1.43 bpm @ 2,892 psi FS, ROP=20 FPH 19:32 19:56 0.40 7,520 7,520 PROD1 WHPST WPRT P Wiper to 7,400', motor work @ same depth 7,467' Page 2 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:56 22:56 3.00 7,520 7,560 PROD1 WHPST MILL P Milling 1.44 bpm @ 2,804 psi, ROP= 20 FPH. Several stalls, pick-ups, slow going through perfs, PUW= 37K. 22:56 23:26 0.50 7,560 7,560 PROD1 WHPST WPRT P Wiper trip, PUW=37K 23:26 23:59 0.55 7,560 7,580 PROD1 WHPST MILL P Milling 1.44 bpm @ 2,804 psi FS, ROP=20 FPH 04/06/2013 Made several back reaming trips on low side @ 1 fpm from 7,400;to 7,580',till no improvement in dry drift. POOH. LD BHA#1,jet BOP stack. RU HES S/L, RIH w/memory caliper to tag up @ 7,558', log up hole @ 50 fpm to 6,870', OOH w/caliper, LD caliper, RIH w/WS dummy drift to 7,431',work drift to 7,455'. POOH. RDMO S/L. MU BHA#2,TIH w/Dummy WS to 7,580'with no problems,TON. Flow check, LD BHA#2. 00:00 00:45 0.75 7,580 7,400 PROD1 WHPST WPRT P PUH to dry drift,dry drift 1K WOB @ 7,467'. 00:45 04:00 3.25 7,400 7,482 PROD1 WHPST REAM P Make several back reaming trips on low side @ 1 fpm.Till no improvement on dry drift run.WOB of 0.5K @ 7,467'. 04:00 04:45 0.75 7,100 7,580 PROD1 WHPST DLOG P PUH.Make CCL logging pass to 7,580' 04:45 06:51 2.10 7,580 62 PROD1 WHPST TRIP P POOH 06:51 07:51 1.00 62 0 PROD1 WHPST PULD P At surface, Flow check well, PJSM lay down BHA on dead well, Blow down and lay down BHA. Mill at 2.79 No Go 07:51 08:27 0.60 0 0 PROD1 RPEQP1CIRC P P/U Nozzle and jet BOP stack 08:27 11:27 3.00 0 0 PROD1 RPEQP1PULD P PJSM, Rig up slickline 11:27 13:15 1.80 0 7,558 PROD1 RPEQPI SLKL P RIH with memory MIT @ 150 FPM, Tag up @ 7558 SLM @ 12:24,Wait for fingers to open up Log uphole @ 50 FPM to 6870 SLM,Trip out of hole @ 100FPM 13:15 14:15 1.00 7,558 0 PROD1 RPEQP1SLKL P At surface, PJSM lay down Memory MIT, M/U Dummy whipstock 14:15 15:00 0.75 0 0 PROD1 RPEQP1SLKL P At surface with S/L, Lay down memory tool, P/U DW 15:00 16:15 1.25 0 7,457 PROD1 RPEQP1SLKL P Set down @ 7431,work to 7455, Work harder and get to 7457,Trip out 16:15 16:51 0.60 7,457 0 PROD1 RPEQP1SLKL P Trip out with Dummy Whipstock 16:51 18:45 1.90 0 0 PROD1 RPEQP1SLKL P At surface, R/D slickline 18:45 19:39 0.90 0 0 PROD1 RPEQP1 PULD P PJSM. PU BHA#2,Test MWD, Stab on WH,check pack-offs,tag _ stripper,set depth,close EDC. 19:39 21:48 2.15 0 7,580 PROD1 RPEQP1TRIP P Trip in hole,dummy drift.Tie-in GR -7 correction,Tag @ 7,580'. No problems encountered. 21:48 23:42 1.90 7,580 0 PROD1 RPEQP1 TRIP P POOH w/BHA,open EDC,continue OOH. 23:42 00:00 0.30 0 0 PROD1 RPEQP1 PULD P Flow check, PJSM, LD BHA#2. Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/07/2013 24 hr Summary LD dummy whipstock, PU BHA#3, RIH w/Baker whipstock with openhole anchor,set TOW @ 7,550'10 deg LOHS, POOH and LD BHA#3. PU BHA#4, RIH w/BHA#4 milling window assembly,tag WS @ 7,550', start milling casing window,exit casing 7,556',drill rathole to 7,571', ream window,good drift, POOH and LD BHA#4. PU BHA#5, RIH w/build section assembly, in progress. 00:00 00:42 0.70 0 0 PROD1 RPEQP1PULD P LD Dummy WS, MU BHA#3 Baker Whipstock 00:42 03:36 2.90 0 7,560 PROD1 RPEQP1TRIP P TIH w/Baker Whipstock,tie-in GR- 8'correction, continue in hole, PUW=39K,close EDC, PU to 30K, pressure up to 2,850 psi to set anchor, release from WS,TOW @ 7,550' 10 deg LOHS. 03:36 05:36 2.00 7,560 0 PROD1 RPEQP1TRIP P POOH with BHA#3 05:36 06:48 1.20 0 73 PROD1 RPEQP1PULD P At surface, Flo check well. Lay down BHA#3 Whipstock setting tools, M/U BHA#4 window milling BHA W .6°mtor,2.80 dimond window mill and 2.79 string reamer 06:48 08:24 1.60 73 7,425 PROD1 WHPST TRIP P RIH with BHA#4 08:24 08:36 0.20 7,425 7,452 PROD1 WHPST DLOG P Log K1 marker for-6'correction 08:36 08:42 0.10 7,452 7,531 PROD1 WHPST TRIP P trip in to 7531 08:42 09:24 0.70 7,531 7,531 PROD1 WHPST CIRC P Swap well to 9.5 PPG used flo pro, close EDC 09:24 09:42 0.30 7,531 7,550 PROD1 WHPST TRIP P Trip in hole to mill window,Tag up @ 7550, PUW=40K 09:42 14:42 5.00 7,550 7,555 PROD1 WHPST MILL P 7550 start milling window, 1.37 BPM @ 3816 PSI FS 14:42 17:12 2.50 7,555 7,560 PROD1 WHPST MILL P 7555.2 DHWOB dropped from 1530 lbs to 500 lbs,Continue milling schedule,auto milling as per procedure,exit casing,see Baker milling report 17:12 19:42 2.50 7,560 7,571 PROD1 WHPST MILL P Start milling rathole, 1.37 bpm @ 3,908 psi FS, DHWOB=2.5K, drill to 7,571'. Ream window three times, dry drift window,good drift, PUW=37K,open EDC. 19:42 21:42 2.00 7,571 0 PROD1 WHPST TRIP P POOH BHA#4,close EDC @ 200', flow check, PJSM,on surface. 21:42 22:21 0.65 0 0 PROD1 WHPST PULD P LD BHA#4 22:21 23:00 0.65 0 0 PROD1 DRILL PULD P PU BHA#5 23:00 00:00 1.00 0 4,226 PROD1 DRILL TRIP P RIH w/build section assembly 04/08/2013 RIH w/BHA#5 to 7,571',drill build/turn section to 7,965',pumped to/hi 5 barrel sweeps,chase sweep OOH and LD BHA. PU BHA#6 with rib steer motor, RIH to 7,965',drill A lateral section from 7,965'to 8,204', drilling in progress. 00:00 01:00 1.00 4,226 7,571 PROD1 DRILL TRIP P Continue in hole with BHA#5,tie-in GR-7'correction, PUW=29K, RIH to 7,571'. Page 4 of 18 CONN DC7 U) co i _ \ H NA ^ N ---I t ('D - O N lG 2. 0, N cn CO W = O � � (�) D I Jo D `, \, � (� (..., cnN N v CTIOD : _.4 O. p CO NO N J = 1 J N N O N i O p ' Cp.) 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H - CI. 4, p i - ' ' N CO Cha ra KUP 2T-03A • Conoco'Phi lips = Well Attributes Max Angle&MD TD Alaska.In( Wellbore API/UWI Field Name Well Status Incl(1) MD(ftKB) Act Bun(ftKB) catomAvlhps 501032007301 KUPARUK RIVER UNIT PROD 10,983.0 Comment H2S(ppm) Dab Annotation End Date KB-Ord(ft) Rig Release Dab SSSV:TRDP 25 1/17/2010 Last WO: 12/172011 40.00 9/14/1986 Well ConhB.-2T-03A 5/10/2013 7'40:26 AM Schematic-Actual Annotation Depth(MB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:GLV C/O osborl 5/10/2013 HANGER,28r Casing Strings e. Casing Description String 0... String ID.,.Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 32.0 115.0 62.50 H-40 WELDED Casing Daseriptlon String 0... String ID...Top(ftKB) Set Depth(f...'Set Depth(TVD)...String WL..String...String Top Thrd / SURFACE 95/8 8.921 32.3 3,174.3 36.00 J-55 BTC Casing Description String 0... String ID...Top(RMB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd PRODUCTION 7 6.276 30.1 2,058.0 26.00 L-80 TC-II CIE BACK CONDUCTOR, 111 Casing Description String 0... String ID...Top(MB) Set Depth(f...Sal Depth(TVD)...String Wt...String...String Top Thrd II 92-115 PRODUCTION 7 6.276 2,058.0 7,570.0 26.00 J-55 BTC Post S/T SAFETY VL 1,711V, i. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd WINDOW A 7 6.176 7,550.0 7,555.0 _ Casing Description String 0... String 10...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd LINERA 23/8 1.992 7,679.7 10,983.0 4.70 L-80 ST-L Liner Details Top Depth V i (TVD) Top Incl Nomi... Top(ftKB) (MD) (°) Item Description. Comment ID(In) PRODUCTION 7,679.7 BILLET LINER TOP BILLET 1.000 TIE BACK, -, k 9,473.5 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 30.2,059 Tubing Strings GAS LIFT, Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 2.735 TUBING WO 3 1/2 2.992 28.3 7,458.3 9.30 L-80 EUE8RDMOD Completion Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) MB)__ (°I Item Description Comment ID 8n) SURFACE, , es 28.3 HANGER TUBING HANGER w/3.66'PUP 2.992 32.3,174 1,713.9 SAFETY VLV SCSSSV,TRMAXX-CMT-SR-5,w/2.813"X PROFILE 2.813 7,275.2 LOCATOR BAKER 80-40 LOCATOR w/7.58'OF STICK UP 3.000 GAS LIFT, 4,693 7,283.8 PBR BAKER POLISHED BORE RECEPTACLE 3.000 7,306.9 PACKER BAKER FHL RETRIEVABLE PACKER 2.920 7,358.5 NIPPLE HES X NIPPLE 2.813 GAS LIFT, 7,406.8 LOCATOR BAKER 80-40 LOCATOR w/5.44'OF STICK UP 4.000 5,854 7,413.0 PACKER BAKER F-1 PRODUCTION PACKER,PLUS B GUIDE 4.000 7,415.5 SBE BAKER SEAL BORE EXTENSION 3.000 7,447.9 NIPPLE HES X NIPPLE 2.813 GAS LIF. 6.70T7_ 7,457.6 WLEG BAKER WIRELINE ENTRY GUIDE w/SHEAR OUT SUB 2.950 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl GAS'LIFT, Top(ftKB) (1K8) (°) Description Comment Run Date ID(In) 7,358.5 PLUG 2.81"XX PLUG SET IN NIPPLE 4/30/2013 0.000 7,458.0 PILOT HOLE 2.80"pilot hole through cement plug 4/5/2013 7,550.0 WHIPSTOCK Whipstock for 2T-03A window exit 4/7/2013 -_ LOCATOR, -_ _ 7,OR, 275 PBR,7,284 Perforations&Slots Shot PACKER,7,307 Top(WD) Bon(TVD) Dens is Top(MB)Bum(ftKB) (KKB) (KKB) Zona Dote fah_ Type Comment _ • 7,689.0 9,473.0 A-2,A-3,A-2, 4/15/2013 32.0 SLOTS Slotted pipe-0.125"x2.5"@ 4 A-3,2T-03A circumferential adjacent rows,3" NIPPLE,7,358 la centers staggered 18 deg,3' PLUG.7,359" non-slotted ends B 9,474.0 10,982.0 A-3,2T-03A 4/15/2013 32.0 SLOTS Slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3" i♦ centers staggered 18 deg,3' non-slotted ends LOCATOR, 7,007 Notes:General&Safety PACKER,7,413 End Date Annotation __ SBE,7,410 / 4/29/2013 NOTE:SIDETRACK,LATERALS AL1,AL2(off main wellbore) NIPPLE,7,448 WLEG,7,458 PILOT HOLE, 7,458 WINDOW A, 7,550-7,555 WHIPSTOCK, 7.550 PRODUCTION Mandrel Details 2,038-7,570 Top Depth Top Port (WD) Incl OD Valve Latch Sloe TRO Run N...Top,734.) (ftKB) PI Make Model (in) Sent TSP. TSP. (in) (Wi) Run Date Com... SLOTS, 1 2,734.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,224.05/5/2013 7,592.9,449 _ SLOTS, 2 4,662.6 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,216.0 5/5/2013 7,889.9,473 ) _ - _ _ _ - LINER AL2 - 3 5,854.1 CAMCOMMG 1 1/2 GAS LIFT GLV RK 0.188 1,205.0 5/42013 (o8 main oexbar.). ` ' 4 6,707.0 .CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,193.05/42013 7,431-9,449 _ 5 7,221.4 CAMCO MMG 1 12 GAS LIFT OV RK 0.250 0.0 5/4/2013 1 SLOTS, 9,474-10.082 r 4 LINER A 7,880-10,983 TD(2T-03A), 10,983 `, ° 1 KUP 2T-03AL1 e ConocoPhilli •wr Well Attributes Max Angle&MD TD Ala •tom Wallboro API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) ska. t,.,M,»+,nhp. 501032007360 KUPARUK RIVER UNIT PROD 101.43 7,820.51 9,450.0 Comment H2S(ppm) Data Annotation End Date KB-Ord(ft) Rig Rallies.Data ••- Well Cenfq:-2T-03AL1,5/10/2013 7'41:58 AM SSSV:TRDP 25 1/17/2010 Last WO: 12/17/2011 40.00 9/14/1986 — Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:GLV C/O osborl 5/10/2013 Casing Strings HANGER,28 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER AL1 2 3/8 1.992 8,013.8 9,444.0 4.70 L-80 ST-L • p Liner Details Top Depth (TVD) Top incl Nonni... Top(ftKB) (1KB) (CI Item Description Comment ID(In) MI 8,013.8 5,800.4 96.55 BILLET OPEN HOLE ANCHORED BILLET 1.000 CONDU32TOR, I Perforations&Slots Shot OF Top(TVD) BBn(TVD) Dens SAFETY VLV, Top(ftKB)Bbn(ftKB) (ftKB) (ftKB) Zone Date (oh— Type Comment 1.714 - 8,035.0 9,443.0 5,798.0 5,793.2 A-3,2T-03AL1 4/18/2013 32.0 SLOTS Slotted pipe-0.125"x2.5"@4 • circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends Notes:General&Safety End Date Annotation ` I 4/29/2013 NOTE:SIDETRACK,LATERALS AL1,AL2(off main wellbore) PRODUCTION 4 6.TIE BACK, 30-2,058 MS GAS LIFT, 2,735 I SURFACE. ,. ik 32-3.174 ■ GAS LIFT, _. 4,883 a a • GAS LIFT, 5,854 a- I B B GAS LIFT, _. 8,707 a a a GAS LIFT, _. 7,221 a a a LOCATOR, 7,275 PBR,7284 -. { PACKER,7,307 - 1111111.-I I NIPPLE,7,358 PLUG,7.359 LOCATOR, -__--- 7,407 -- PACKER,7,413 SBE,7,418 NIPPLE,7,4481 l WLEG,7,458 �'� PILOT HOLE, 7,458 WINDOW A, 7I555 WHIPSTOCK, 7,550Mandrel Details PRODUCTION - Depthp Post Sit Top To Port 2.038-7,570 L\ 5... (TVD) Inel OD Valve Latch Size TRO Run 8,835&,44SLOTS3 N...Top(NKR) ) C) MModel (in) Sen n) (p Type Type (Isi) Run Dab Corn... LINER ALI, I J^\ I (ftKBMal. model 2,734.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,224.0 5/5/2013 TO(2T--03 LIj 2 4,662.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,216.0 5/5/2013 9,450 LINER A, -_.. 3 5,854.1 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,205.0 5/4/2013 7,880-10,083 4 6,707.0 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,193.0 5/4/2013 n 5 7,221.4 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 5/4/2013 1 1 it .-, air. KUP 2T-03AL2 ConocoPhillipsWell Attributes Max Angle&MD TD Alaska.I� Wellbore API/UWI Field Name Well Status Incl I°) MD(ftKB) Act Bun(ftKB) n,,..»1,n II, 501032007361 KUPARUK RIVER UNIT PROD 101.43 7,820.51 _ 9,450.0 Comment H2S(ppm) Dab Annotation End Dab KB-Ord(ft) Rig Release Oct. °°• Well Con59:-2T-03Al2,5/10/2013 7:43:08 AM SSSV:TRDP 25 1/17/2010 Last WO: 12/17/2011 40.00 9/14/1986 Schematic-Actual Annotation Depth(ftKB) End Dab Annotation Last Mod...End Dab Last Tag: Rev Reason:GLV C/O osborl 5/10/2013 Casing Strings HANGER,28 - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String... String Top Thrd PLINER AL2 2 3/8 1.992 7,431.3 9,446.0 4.70 L-80 ST-L (off main wellbore) Liner Details Top Depth (TVD) Top Incl Noml... Top INKS) (ftKB) (°) Ibm Deseriptlon Comment ID(in) CONDUCTOR, 7,431.3 5,715.9 42.55 DEPLOY SHORTY DEPLOYMENT SLEEVE 2.250 32-115 Perforations&Slots Shot SAFETY VLv, 1.714 Top(TVD) Bun(TVD) Dens Top(MB)Ban(ftKB) (NKS) (fIKB) Zona Dab Oh-- Typa Comment 7,592.0 9,446.0 5,831.0 A-3,A-2,A-3, 4/22/2013 32.0 SLOTS Slotted pipe-0.125'x2.5"@ 4 A-2,A-3, circumferential adjacent rows,3" 2T-03AL2 centers staggered 18 deg,3' non-slotted ends % / Notes:General&Safety End Date Annotation PRODUCTION 4/29/2013 NOTE:SIDETRACK,LATERALS AL1,AL2(off main wellbore) TIE BACK, -4 k 30-2,058 GAS LIFT, 2.735 SURFACE, A 32-3.174 GAS LIFT, Ai 4.663 GAS LIFT, Ac 5.854 I .... GAS LIFT, _ } 6,707 1� GAS LIFT, F 7,221 LOCATOR, 7,275 PBR,7,284 PACKER.7,307 ilhi, NIPPLE,7,358 7 PLUG,7,350 LOCATOR, _A l 7,407 PACKER,7.413 SBE,7,418 - // !. L NIPPLE,7,448 - Mandrel Details WLEG,7,458 : Top Depth Top Port PILOT HOLE, (TVD) Inel OD Valve Latch Sic. TRO Run WINDOW A.'\ • N...Top(ftKB) (ftKB) (°) Make Model (in) Seta TM» Type (in) (Pail Run Oct. Com... 7,555-7555 1 2,734.6 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,224.0 5/5/2013 WHIPSTOCK, i 2 4,662.6 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,216.0 5/5/2013 PRODUCTION Poetsrt, I 3 5,854.1 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,205.0 5/4/2013 2,038-7,570 SLOTS, 4 6,707.0 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,193.0 5/4/2013 7.592-9.446 LINER AL2 5 7,221.4 CAMCO MMG 1 12 GAS LIFT OV RK 0.250 0.0 5/4/2013 (o6 mein wellbore), 7,431-0,446 TD(2T-03AL2), 0,450 LINER A, --I 7,880-10,083 -_ I- 1I -L OF 77.1 THE STATE Alaska Oil and Gas - OJ 1 1 L A S ��� Conservation Commission = ,... :. GOVERNOR SEAN PARNELL *h , 333 West Seventh Avenue �, Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 MAR 2 ° M James Ohlinger S1N QE CTD Engineer Q— ConocoPhillips Alaska, Inc. 1 14- P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -03 Sundry Number: 313-110 Dear Mr. Ohlinger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy P. oerster Chair DATED this I d y of March, 2013. Encl. STATE OF ALASKA • AI•CA OIL AND GAS CONSERVATION COMM�ION Ili h A APPLICATION FOR SUNDRY APPROVALS Ir 20 AAC 25.280 1. Type of Request: Abandon l Plug for Redrill ]r • Perforate New Pool r Repair w ell I Change Approved Program E Suspend r Plug Perforations R • Perforate i— Pull Tubing E Time Extension j"""' Operational Shutdow n I Re -enter Susp. Well j'""" Stimulate I— Alter casing imm Other: 3 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillipsAlaska, Inc. Development [. Exploratory E 186 - 142 - 3. Address: Stratigraphic i — Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20073 - 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 E No F+ 2T -03 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25569' 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): • 7897 6067 none none Casing Length Size MD TVD Burst Collapse --_ CONDUCTOR 83 16 115' 115' SURFACE 3142' 9.625 3174' 2787' RFC IIVE,D PRODUCTION 7863' 7 7893' 6064' D-TS t"'71()19 3 l !I,At n 1 1:3 A.0(3 CC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7520 - 7561,7592 -7607 5782 - 5813,5836 -5846 3.5 L - 7458 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL RETRIEVABLE PACKER • MD= 7307 TVD= 5625 PACKER - BAKER F -1 PRODUCTION PACKER , PLUS B GUIDE - MD= 7413 TVD= 5702 SSSV - CAMCO TRMAXX- CMT -SR -5 • MD =1714 TVD =1697 12. Attachments: Description Summary of Proposal • I - � 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch F Exploratory r Stratigraphic ( Development [ • Service E 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/4/2013 OiI Gas r WDSPL V Suspended 1I .ti 16. Verbal Approval: Date: VVINJ r GINJ 1 WAG I- Abandoned E Commission Representative: GSTOR E SPLUG F 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 -1102 Email: James. J .Ohlinuer(cD.conocophillips.com Printed Name Ja es Ohlinq Title: CTD Engineer Signature f ^at..s &s.e.-•-.". Phone: 265 -1102 Date 3/ _V Commission Use Only Sundry Number: ✓ ✓ ✓ ✓✓ ������ � Conditions of approval: Notify Commission so that a representative may witness ✓✓ Plug Integrity F BOP Test i� Mechanical Integrity Test i — Location Clearance E s a P e ii. /T l {zr ' t /plc `c.N..�� Other: ,iG 70 A p s d.., S di •4- L LJ •. a c t •, * Z. 5 as / ®s 4 Ai"...,..4.1 (-- f'I f f" /+ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / ABO ac MAR 2 • X 013 G7LJIV'�7 MAR -•� A ) j ' APPROVED BY Approved by: ' ? -a / T -7 COMMISSIONER THE COMMISSION Date: 3 - 14 / Approved application is valid tor 12 months trom the date of approval. O 1/I- /✓ " Submit Form and Attachments in Duplicate '' P . • KRU 2T -03 CTD Summary for Perforating & Plugging Sundry (10 -403) Summary of Operations: Well 2T -03 is a Kuparuk A- sand /C -sand development (producer) well equipped with 3'/2" tubing and 7" production casing. A rig work -over (RWO) was performed for subsidence in December 2011. Operations cemented off the existing perfs prior to work over. Pulled and replaced upper the 2000' of 7" casing and cemented same. Then ran a 3 -1/2" straddle packer completion and re- perfed the A &C sand after the RWO to regain production. Three proposed A -sand CTD laterals will increase reservoir exposure in the fault block. Prior to drilling, the existing A & C -sand perfs in 2T -03 will be plugged with cement to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAq 25.112(c)(1) to plug the A & C -sand perfs in this manner. _ - i tu o a-c r _ The 3 -1/2" tubing in the tubing tail will be perforated (7450' -7455' RKB) to allow cement to go above the tubing tail and reduce the risk of contaminated cement at the tubing tail. After plugging off the existing A &C -sand perfs with cement, a pilot hole will be drilled through the cement to 7,600' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2T- 03A sidetrack wilLexit the 7" casing at 7,550' MD and will target the A3 sand south of the existing well with a 3,350' lateral. The hole will be completed with a 2-%" slotted liner to the TD of 11,100' MD with an aluminum billet at 7,750' MD. The 2T -03AL1 lateral will kick off from the aluminum billet at 7,750' MD and will target the A3 sand north of the existing well with a 1700' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9,450' MD with an aluminum billet at 7,670' MD. The 2T -03AL2 will kick off from the aluminum billet at 7,670' MD and will target the A2 sand north of the existing well with a 1705' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9,375' MD with the final liner top located inside the 3 tubing at 7,453' MD. CTD Drill and Complete 2T -03 Laterals: April 2013 Pre -CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs — T & IC. 3. RU Slickline. a. Pull ISO sleeve from the SSSV b. Drift and tag PBTD c. Drift w/ Dummy whipstock d. Obtain static bottom hole pressure, (SBHP) e. CMIT & MITT 4. RU Eline: Perforate tubing tail at 7450' -7455' RKB (5' of perfs) 5. RU coil: Place cement in the 7" casing, squeeze off A &C sand existing perfs. 6. RU Slickline. Tag top of cement and pressure test. RD Slickline. 7. Prep site for Nabors CDR2 -AC, including setting BPV aim C Vim, i ite 1 ^-ell r) f r2x/frci y /e3 7 dr, /!r rye well _ G°s q Tr - (C4) Cfq/ 5 , 4 vk' r'✓1��d '49 [eCo ut -y Page 1 of 2 ton, r4,3 p /70G l t /c6/ 3/1/2013 • • Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 2T -03A Sidetrack (A3 sand, south) ( a. Drill 2.80" high -side pilot hole through cement to 7,600' MD b. Drift pilot hole with whipstock dummy c. Set whipstock at 7,550' MD with high -side orientation. d. Mill 2.80" window at 7,550' MD. e. Drill 2.70" x 3" bi- center lateral to TD of 11,100' MD f. Run 2%" slotted liner with an aluminum billet from TD up to 7,750' MD 3. 2T -03AL1 Lateral (A3 sand, north) v a. Kick off of the aluminum billet at 7,750' MD b. Drill 2.70" x 3" bi- center lateral to TD of 9,450 MD Run 2%" slotted liner with an aluminum billet from TD up to 7,670' MD 4. 2T -03AL2 Lateral (A2 sand, north) a. Kick off of the aluminum billet at 7,670' MD b. Drill 2.70" x 3" bi- center lateral to TD of 9,375' MD c. Run 2%" slotted liner from TD up to 7,453' MD, inside the 3Y2" tubing tail 5. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to production Page 2 of 2 3/1/2013 044 KUP • 2T -03 a Conoc Phillipps s Well Attributes Max Angle & MD TD Wellbore APIIUWI Field Name Well Status Inc! ( °) MD (RKB) Act Btm (RKB) Alaska Inc. 501032007300 KUPARUK RIVER UNIT PROD 50.37 4,200.00 7,897.0 ' Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date Well connc - zr� an s not z z 5a s3 Pm SSSV: TRDP 25 • 1/17/2010 Last WO: 12/17/2011 40.00 9/14/1986 Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,836.0 4/30/2012 Rev Reason: GLV C/O ninam 8/18/2012 Casing Strings HANGER, 29 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 320 115.0 115.0 62.50 H - 40 WELDED H PROD Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 32.3 3,174.3 2,787.3 36.00 J BTC / Casing Description String 0... String ID ... Top (RKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd s UCTION 7 6.276 30.1 7,892.8 6,063.7 26.00 J-55 BTC 2/ Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd c ortoucroR. PRODUCTION 7 6.276 30.1 2,058.0 1,992.3 26.00 L -80 TC -II • 3z - :a / TIE BACK SAFETY VLV, Tubing Strings 1,7:4 ;s Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TV D) ... String Wt... String ... String Top Thrd ISO SLE l � �� I TUBING WO 31/ I 2.992 I 28.3 7,458.3 I 5,735.8 9.30 I L -80 EUE8RDMOD Completion Details I Top Depth • (ND) Top Mel Nomi... I Top (RKB) (RKB) ( °) Item Description Comment ID (in) 28.3 28.3 -0.02 HANGER TUBING HANGER w/ 3.66' PUP 2.992 V 1,713.9 1,697.5 22.75 SAFETY VLV SCSSSV, TRMAXX- CMTSR -5, w/2.813" X PROFILE 2.813 7275.2 5,602.6 44.34 LOCATOR BAKER 80-40 LOCATOR w/ 7.58' OF STICK UP 3.000 PRODUCTION 7283.8 5,608.7 44.24 PBR BAKER POLISHED BORE RECEPTACLE 3 TIE BACK . 30 7,306.9 5,625.2 43.97 PACKER BAKER FHL RETRIEVABLE PACKER 2.920 7,358.5 5,662.7 43.37 NIPPLE CAMCO X NIPPLE 2.813 GAS LIFT, 4 2,735 C. 7,406.8 5,697.6 42.07 LOCATOR BAKER 80-40 LOCATOR w/ 5.44' OF STICK UP 4.000 rLL II� 7,413.0 5,702.2 42.05 PACKER BAKER F -1 PRODUCTION PACKER , PLUS B GUIDE 4.000 7,415.5 5,704.1 42.05 SBE BAKER SEAL BORE EXTENSION 3.000 I 7,447.9 5,728.0 41.96 NIPPLE CAMCO X NIPPLE 2.813 7,457.6 5,735.2 41.93 WLEG BAKER WIRELINE ENTRY GUIDE w /SHEAR OUT SUB 2.950 SURFACE, 32 -3,174 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) r Top Depth (ND) Top Intl GAS LIFT. Top (RKB) (RK0) ( °) Description Comment Run Date ID (In) 4,663 1,714 1,697.5 22.75 ISO SLEEVE TR -MAXX ISOLATION SLEEVE, OAL =80" 7/27/2012 2.310 IM Perforations & Slots Shot GAS LIFT, Top (ND) Btm (ND) Dena 5,954 Top m( KB) BtRKB) (RKB) (RKB) Zone Date Oft- Type Comment - 7,520 7,536 5,782.4 5,794.1 C-4, A -3, 2T-03 7/18/1993 6.0 APERF 2 1/8" EnerJet; ( + / -) 45 deg. Phasing - 7,531 7,561 5,790.5 5,812.5 A -3, 2T -03 12/11/2011 6.0 IPERF 31/2" Millennium HMX. 60 Deg Phasing GAS LIFT, .. 7,536 7,561 5,794.1 5,812.5 A -3, 2T -03 10/17/1986 4.0 IPERF 4" HyperJet II _ ___; 6,707 , �, , , 7,592 7,607 5,835.5 5,846.2 A -2, 2T -03 12/11/2011 6.0 IPERF 3 1/2" Millennium HMX. 60 Deg OM Phasing 7,602 7,604 5,842.4 5,843.9 A -2, 2T -03 10/17/1986 4.0 IPERF 4" HyperJet II MI GAS LIFT, - MI LOCATOR, 7,275 PBR, 7,284 PACKER, 7,307 Ill IIII NIPPLE, 7,35a - LOCATOR, ,4 1 PACKER, 7,413 3 SBE. 7,416 NIPPLE, 7,448 ( 3 WLEG, 7,458 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run APERF, Stn Top (RKB) (RKB) I Make Model (!n) Sery Type Type (!n) (psi) Run Date Corn... 7,520 - 7,538 1 2,734.6 2,483.5 46.79 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,274.0 12/27/2011 IPERF, 7'331 -7'391 , 2 4,662.6 3,794.0 46.57 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,265.0 12/27/2011 PERF 7'538 - 7'581 3 5,854.1 4,608.7 45.78 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,253.0 12/27/2011 IPERF, 4 6,707.0 5,1992 44.70 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,240.0 12/27/2011 7,592 - 7,807 IPERF, 5 7,221.4 5,564.7 44.97 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 7/27/2012 7,802.7,804 PRODUCTION, 2,039 -7,893 TD, 7,897 2T -03 Proposed CTD Sidetrack 3 -1/2" TRMAXX- CMT -SR -5 SSSV @ 1714' MD TR -MAXX ISO Sleeve is installed 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 16" 62# H - 40 shoe @ 115' MD 3 -1/2" Camco MMG gas lift mandrels @ 2735' MD 4663' MD 5854' MD 6707' MD 7221' MD 9 - 5/8" 36# J - 55 shoe @ 3174' MD Baker 3 -1/2" PBR @ 7284' MD (3" ID) • Baker FHL Packer @ 7307' MD (3.0" ID) 3 -1/2" Camco X Nipple @ 7358' MD (2.813" min ID) Baker F -1 Packer @ 7413' MD (4.0" ID) ( Baker 3 -1/2" SBE @ 7416' MD (3" ID) 3 -1/2" Camco X Nipple @ 7448' MD (2.813" min ID) _ : n 3 -1/2" WLEG @ 7458' MD ,r 2T -03A wp03 A3 south - . ",.:%. TD @ 11,100' MD Billet @ 7750' MD r:,,° 2T -03AL1 wp03 A3 north • TD @9450'MD 1 Billet @ 7670' MD C4 /A3 perfs 7520' - 7561' MD - ti 2 A2 -sand perfs _ 7592' - 7604' MD �� 2T -03AL2 wp01 A2 north 7" 26# J-55 shoe 7893' MD TD @ 9375' MD @ Liner top — 7448' RKB • • 2. . �_.` WELL LOG TRANSMITTAL RECEIVED ''' JAN 20 2012 PRoAcIivE DiAgNostiC SERVICES,INC. n AOGCC To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 SCANNED F° r 1) Caliper Report 29-Nov-11 21-03 1 Report / CD 50-103-20073-00 2) / Signed : V `'7) 1 _e" C-(' Date : t Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGE(lDMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Archives\Distribution\TransmittalSheets\ConocoPlullips_Transmrit.docx 1 - • �v1 ACEIVED I JAN 2 0 2012 Memory Multi-Finger Caliper SCC Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 2T-03 P Y P Log Date: November 29,2011 Field: Kuparuk I Log No. : 10193 State: Alaska Run No.: 1 API No.: 50-103-20073-00 Pipet Desc.: 9.625" 36 lb. J-55 Top Log Intvll.: Surface Pipet Use: Surface Casing Bot. Log Intvll.: 2,046 Ft.(MD) IInspection Type : Subsidence Inspection COMMENTS : IThis caliper data is correlated to the Halliburton Radial Cement Bond Log dated 25-November-2011. This log was run to assess the condition of the 9.625"surface casing to identify areas of buckling or ID I restriction due to subsidence. The caliper recordings indicate slight to moderate buckling from surface to IT —570' and—700'to—1,470', with severe buckling recorded from—380'to—405' and—890'to—900'. Obstructions are recorded in the area of severe buckling at 400'and an area of buckling at 334', restricting the I.D.to 7.51" and 7.61" respectively. A 3-D log plot overlay of the centered and off-center caliper I recordings across the 9.625"surface casing logged and a graph illustrating minimum recorded diameters on a joint-by-joint basis are included in this report. The caliper recordings indicate heavy deposits which temporarily impaired the caliper fingers from—1,500'to I 2,046' (end of log). As a result,the minimum recorded diameters throughout this interval are likely to be smaller than the actual diameters inside the surface casing logged. The caliper recordings indicate the 9.625"surface casing logged appears to be in good to poor condition with I respect to corrosive and mechanical damage. Wall penetrations ranging from 21%to 44%wall thickness are recorded throughout an area of apparent wear from the kick-off point at— 1,480'to—1,900'. No other significant wall penetrations or areas of cross-sectional wall loss are recorded throughout the surface casing U logged. The presence of heavy deposits from—1,500'to 2,046'(end of log)may mask additional damage to the inside of the surface casing. MAXIMUM RECORDED WALL PENETRATIONS: I Apparent Wear ( 44%) Jt. 44 © 1,791 Ft. (MD) Apparent Wear ( 40%) Jt. 38 @ 1,534 Ft. (MD) Apparent Wear ( 40%) Jt. 42 @ 1,697 Ft. (MD) I Apparent Wear ( 38%) ( 37%) Jt. 46 @ 1,843 Ft. (MD) Apparent Wear Jt. 45 @ 1,798 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: INo significant areas of cross-sectional wall loss(>9%)are recorded throughout the surface casing logged. MAXIMUM RECORDED ID RESTRICTIONS: IObstruction in Area of Severe Buckling Minimum I.D. =7.51" Jt. 9 @ 400 Ft. (MD) Obstruction in Area of Buckling Minimum I.D. =7.61" Jt. 8 @ 334 Ft. (MD) Heavy Deposits with Temporary Finger Impairment Jts. 37-49 —1,500 to 2,046 Ft. (MD) INo other significant I.D. restrictions are recorded throughout the surface casing logged. IField Engineer: E Gustin Analyst: C. Waldrop Witness: C. Kennedy ProActive Diagnostic Services, Inc. ( P.C. Box 1369, Stafford,TX 77497 Phone: (281) or(888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907) 659-2314 I . , 0 • I PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-03 Date : November 29, 2011 IDescription : Overlay of Centered and Off-Center Caliper Recordings Across Buckled 9.625"Casing. Maximum Diameter Depth 3-D Log(Off-Center) Image Map(Off-Center) 3-D Log(Centered) Image Map(Centered) I 7.625 inches Minimum Diameter 9.625 lft:700ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° I 7.625 inches 9.625 I 7.625 Nominal I.D. inches 9.625 Ammi.•MINIIIIIM..... I ill MIAMI „ 50 illiM 111 . . I100 I 1 MGM. .....„. I 1 200 . I250 ... 413111101h I . 300 I • • 4.'.. ....- i AR I 350 , millit." : I . • a --- 400 I # i 401 Ic 450 _ I I . I • • , r t I i I 500 I : 550 - - . . ; I , 1 lit 600 I I ___, 1 -- : : . 650 I 700 I 1 750 ---4P I 1 800 I 1 , I 850 I .11 .), 900 9 , ...„. — ... ,• •—.. n... ."Ktiff. ...,1 ) I /) 950 gill I I 1000 - - I 2k ..- I I . _ _ • 0 1050 IEEE WHERE 1 ' ■■■■'i1■■■ �, " ■■■■r �■■■ 1 ■■■■■hi■■ e ■■■■■ER 1100 ■■■■■Y MENU MBE= ■MUNE MEMME ■■■■MO?■■■ ■■■■■!EMEM 1150 ■■1111■■n 1111MEM S■' 1111■11■s■1111 ■■■■■■■RE , II ■■■■■■Ara■ ■■■■■raimm 1200 ■■■■■EMMEN! I 1111■■ 1■■■ 1111 ■■ a1■■. ......[WEEN1250 I ■■■■■EA'■■■ ■■■■■W■■■ ■■■i ■■ . I ■ ■■ VE 1300 ■■■■■■EVA■■ ,' I ■■■■■■:WER =MN Elf 1350 IIIIIMIPY/ sem, , ■11■■: � I ■11■iM■ = NEMER■IME MEMEERINI I Emir1400 ■■■■ ■■ ■■■■■i ■ 111 ■■■■■■AM 1450 1111■■■■a,■ 1111 =SEM MIME ■■■■■■VIME ■■■■■1VI■■ ■■■■■� �U■ 1500 1111■■=AUBE 1111■r■■i■■ ■■■■■ri■■ ; I =MEN MOAN P.Cri%ill■ni■■ 1550 ■■a•■OME■ ■■11PI.�AIP' 1600 I . I , • • IN I momr..._............zimmi - Millirrill 1650 .4. Iii '• I -Vill i - i-- ..:....._... i _ 1700 1 7 WI 11i, I Li rm'ils, W-._nO111111. 1750 ROO I •--- .....71111111111Nall Mg ill21111111 ---""=—.—.....5—— • 1800 I -- MI SU ____=ammimmodllill 641lit --, .- am ME :r I ----=---r'-iillIllIl iRgn rimmommomm.•_:Amp.mm •vv., ___ INEMOIMIMW-1741,111.1111.11 r 'OW" ..mm•IMMIill.11.11110 rtiEll - I _ ••••1 dim __Wiz- -111111111111 1900 MINMEtt I - tizTraratimm _ - 1116i11111,11111111111 __.z—mm111111111 ---1 Ella" - I N 1950 -Fitm -.mil ist, -B El mi 1 . ..„..iii, ' 2000--a i _____. • , , r_ sill==./11 I ---. ima- rum inumbiiito .,.. Nominal I.D. 1 7.625 inches 9.625 Minimum Diameter I-- 7.625 inches 9.625 1 .._ L_a_ximum Diameter Depth 3-D Log(Off-Center) Image Map(Off-Center) 3-0 Log(Centered) Image Map(Centered) 7.625 inches 9.625 1 ft.Mft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° I I I I I ' . • • I Il -- .--,, Minimum Diameter Profile Well: 2T-03 Survey Date: November 29,2011 I Field: Kuparuk Tool: UW MFC XR 40 No.217958 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 8.921 inches 1 Mipimum Measured Diameters(In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 I 0.1 z I 4 10. I. 12 ' 14 16. Il I 18, . a 20 i ' N III! 2: S 28 II 30, . I 32' , 34 ' 36 ��=. 38 -, 44: Temporary Finger Impairment I 46 M 48 I50- I. — I I I . S • Correlation of Recorded Damage to Borehole Profile Pipe 1 9.62 5 in (52.8'-2031.3') Well: 2T-03 Field: Kuparuk I Company: Country: ConocoPhillips Alaska,Inc USA Survey Date: November 29, 2011 I I ■ Approx.Tool Deviation ■ Approx.Borehole Profile I 1 io 58 I 1 6 255 1 12 490 1 18 727 `v 24 965 "- ' z I s c Q CS o p 30 1201 36 1438 I 1 4211111 1 1676 I48 1914 51 2031 I0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) IBottom of Survey=51 I I I • • IPDS Report Overview I Body Region Analysis Well: 2T-03 Survey Date: November 29,2011 Field: Kuparuk Tool Type: UW MFC XR 40 No.217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J-55 Analyst: C.Waldrop Tubing: Nom.OD Weight Grade&Thread Nom.ID Nom.Upset Upper len. Lower len. I 9.625 ins 36 ppf J-55 8.921 ins 9.625 ins 6.0 ins 6.0 ins IPenetration(%wall) Damage Profile(%wall) 450 mu 0 Penetration body Metal loss body 0 50 100 1 0 ME 30 II 20 • 10 a -_ 10 0 ; NMI 1 Oto 20 to 40 to over 20% 40% 85% 85% MIM. MI Number ofjoints analysed(total=52) • 1 40 9 3 020 • 1 Damage Configuration (body) no 20 30 • I 15 ----- m • mi sis 10 S I .-- 40 • Isolated General Lie Other Hole/ Pitting Corrasion Corrasion Damage Pos.Hole No EN um 50 - I Number of joints damaged(total= 12) 0 0 0 12 0 Bottom of Survey=51 I I 1 S • PDS REPORT JOINT TABULATION SHEET I Pipe: 9.625 in 36.0 ppf J-55 Well: 2T-03 Body Wall: 0.352 in Field: Kuparuk I Upset Wall: 0.352 in Company: Country: ConocoPhillips Alaska,Inc Nominal LD.: 8.921 in LISA Survey Date: November 29,2011 IJoint Jt.Depth I'en. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 53 0 0.04 13 1 8.87 Pup 1 58 0 0.04 10 5 8.88 Slight Buckling. 2 98 0 0.04 10 2 8.86 _ Slight Buckling. 3 138 0 0.03 9 1 8.85 Buckling. I 4 176 0.04 0.05 14 8.81 Slight Buckling. 5 216 0.04 0.05 14 t 8.86 Slight Buckling. 6 255 0.07 0.06 16 7 8.81 Slight Buckling. 7 295 0.06 0.06 , 16 4 8.83 _ Slight Buckling. I 8 334 0 0.05 14 7 7.61 Obstruction. Buckling. 9 373 0.04 0.05 13 6 7.50 Obstruction. Severe Buckling.Full Finger Extens 10 411 0 0.04 13 4 8.86 Slight Buckling. 11 451 0.05 0.04 11 9 8.85 Slight Buckling. 12 490 0 0.05 14 8 8.83 Slight Buckling. I 13 529 0 0.04 13 2 8.82 14 569 0 0.04 13 2 8.84 15 609 0 0.04 11 4 8.83 16 648 0.04 0.04 11 4 8.81 I 17 688 0.07 0.05 14 0 8.76 Slight Buckling. 18 727 0.09 0.05 14 0 8.75 Slight Oval Due to Mild Buckling. • 19 767 0 0.04 13 3 8.83 20 806 0.04 0.04 13 5 8.80 Slight Buckling. I 21 846 0.14 0.04 13 3 8.76 Slight Oval Due to Mild Buckling. 22 886 0.12 0.06 16 5 8.45 Severe Buckling. 23 925 0.10 0.04 13 7 8.79 Slight Buckling. 24 965 0.06 0.05 14 5 8.79 Slight Buckling. 25 1004 0.06 0.04 13 7 8.79 Slight Buckling. ' 26 1043 0.05 0.04 11 8 8.77 Slight Buckling. 27 1083 0 0.04 12 2 8.79 Slight Buckling 28 1123 0.06 0.04 13 , 5 8.79 Slight Buckling. 29 1162 0.10 0.04 13 4 8.76 Slight Oval Due to Mild Buckling. I 30 1201 0.09 0.05 14 5 8.74 Slight Oval Due to Mild Buckling. 31 1241 0.07 0.05 14 5 8.84 Slight Buckling. 32 1280 0.07 0.04 13 7 8.81 , Slight Buckling. 33 1320 0.05 0.04 13 1 8.82 Slight Buckling. I 34 1359 0 0.06 16 4 8.81 Slight Buckling. 35 1398 0 0.06 16 8.70 Slight Oval Due to Mild Buckling. 36 1438 0 0.04 13 4 8.80 Slight Buckling. 37 , 1477 0.06 0.09 26 , 9 8.38 App Wear. Hvy Deposits.Temp Finger Impairrn .1 I 38 151 7 0.08 0.14 40 5 , 7.92 App Wear. Hvy Deposits.Temp Finger Impairm 39 1557 0.11 0.11 31 5 7.67 App Wear. Hw Deposits.Temp Finger Impairm 40 1596 0.09 0.10 28 3 6.35 App Wear. Hw Deposits.Temp Finger Impairm 41 1636 0 0.09 24 3 . 6.79 App Wear. Hvy Deposits.Temp Finger Impairm 42 1676 0.07 0.14 40 5 6.90 App Wear. Hw Deposits.Temp Finger Impairm I 43 1715 0.04 0.12 34 4 6.74 App Wear. Hw Deposits.Temp Finger Impairm 44 1755 0.06 0.16 44 8 6.73 App Wear. Hw Deposits.Temp Finger Impairm 45 1795 0.11 0.13 37 _ 5 6.99 App Wear. Hw Deposits.Temp Finger Impairm 46 1835 0.04 0.14 38 3 6.18 App Wear. Hw Deposits.Temp Finger Impairm I 47 1874 0 0.07 21 4 , 7.22 , App Wear. Hw Deposits.Temp Finger Impairm 48 1914 t) 0.06 16 3 6.42 Heavy Deposits.Temp.Finger Impairment. 49 1954 t) 0.07 18 2 5.56 Heavy Deposits.Temp.Finger Impairment. II Penetration Body Metal Loss Body Page 1 ' • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 36.0 ppf J-55 Well: 2T-03 Body Wall: 0.352 in Field: Kuparuk ' Upset Wall: 0.352 in Company: Country: ConocoPhillips Alaska,Inc Nominal I.D.: 8.921 in USA Survey Date: November 29, 2011 iJoint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 50 1996 0.09 0.11 30 1 5.88 App Wear. Hvv Deposits.Temp Finger Impair 51 2031 0.07 0.07 18 4 7.13 Heavy Deposits.Temp.Finger Impairment. IPenetrBody Metal Loss ation Body I 1 I 1 I Page 2 I 0 • I li-73S„ P PDS Report Cross Sections •I Well: 2T-03 Survey Date: November 29,2011 Field: Kuparuk Tool Type: UW MFC XR 40 No.217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J-55 Analyst: C.Waldrop I ICross Section for Joint 44 at depth 1791.220 ft Tool speed=52 I Nominal ID=8.921 Nominal OD=9.625 ite------- -Remaining wall arca=93% Tool deviation=23° I I I ' Finger=23 Penetration=0.155 ins Apparent Wear 0.16 ins=44%Wall Penetration HIGH SIDE=UP I I I I I • • I I:PS PDS Report Cross Sections I Well: 21-03 Survey Date: November 29,2011 Field: Kuparuk Tool Type: UW MFC XR 40 No.217958 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J-55 Analyst: C.Waldrop 1 ICross Section for Joint 38 at depth 1533.700 ft Tool speed=50 1 Nominal ID=8.921 ---"......0.„„0.................,„Nominal OD=9.625 Remaining wall arca=95% Tool deviation=12° '' \\ 1 / 1 111 I I 1 1 1 1 1 Finger=24 Penetration=0.141 ins Apparent Wear 0.14 ins=40%Wall Penetration HIGH SIDE=UP 1 I I I I I . • • I 1ti 5 p PDS Report Cross Sections I ,,. Well: 2T-03 Survey Date: November 29,2011 Field: Kuparuk Tool Type: UW MFC XR 40 No.217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J-55 Analyst: C.Waldrop I ICross Section for Joint 9 at depth 399.910 ft Tool speed= 50 I Nominal ID=8.921 Nominal OD=9.625 Remaining wall area= 100% Tool deviation=0° I (I. I 1 I IMinimum I.D.=7.505 ins Obstruction in Area of Severe Buckling Min. I.D.=7.51 ins HIGH SIDE=UP 1 I I I I I . . • ' PDS Report Cross Sections s I Well: 2T-03 Survey Date: November 29,2011 Field: Kuparuk Tool Type: UW MFC XR 40 No.217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J-55 Analyst: C.Waldrop I ICross Section for Joint 8 at depth 334.360 ft Tool speed=51 I Nominal ID=8.921 Nominal OD=9.625 Remaining wall arca= 100% Tool deviation=0° I I I I I I 111 Minimum I.D.=7.610 ins Obstruction in Area of Buckling Minimum I.D.= 7.61 ins HIGH SIDE=UP I ani • PHILLIPS Alaska Inc. KRU 2T-03 I A Subsidiary or PHILLIPS PETROLEUM COMPANY 7 I ° 2T-03 SSSV API:1501032007300 Well Type:I PROD Angle @ TS: 42 deg @ 7519 SSSV Type: TRDP Orig 9/14/1986 Angle @ TD: 40 deg @ 7897 (1795-1796, Lo Completion: OD:2.875) 1. 1 Annular Fluid: Last W/O: Rev Reason: COIL comment by Imo Reference Log: Ref Log Date: Last Update: 8/29/2002 Gas ti Last Tag: 7532 TD: 7897 ftKB ILii q Last Tag Date: 8/27/2002 Max Hole Angle: 50 deg @ 4200 Mandrel/Valy€ r- Casing String-ALL STRINGS 1(2840-2841, Description Size Top Bottom TVD Wt Grade Thread 01:4.750) y SUR.CASING 9.625 0 3174 2787 36.00 J-55 PROD.CASING 7.000 0 7892 6063 26.00 J-55 I Gas Lift 1 CONDUCTOR 16.000 0 115 115 62.50 H-40 LandrelNalve I ® � Tubing String-TUBING 2(4935-4936, rr r Size Top Bottom TVD Wt Grade Thread 01:4.750) I 2.875 0 7460 5737 6.50 J-55 EUE 8RD AB-MOD Perforations Summary ' Gas Lift Interval TVD 20-7536 5782-5794 CZ- 3 Status Ft SPF Date Type Comment 75 16 6 7/18/1993 APERF 2 1/8"EnerJet;(+/-)45 deg. ‘AandrelNalve 12K1 Phasing 3(59725973, r 7536-7561 5794-5812 A-3 25 4 10/17/1984 (PERF 4"HyperJet II ' 01:4.750) j 7602-7604 5843-5844 A-2 2 4 10/17/1984 IPERF 4"HyperJet II 8 Gas Lift MandrelsNalves St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date VIv . Mfr Type Run Cmnt I 1 2840 2556 Camco KBMG GLV 1.0 BK 0.125 1236 6/3/1998 I 2 4935 3981 Camco KBMG GLV 1.0 BK 0.188 1319 6/3/1998 3 5972 4691 Camco KBMG GLV 1.0 BK 0.250 1419 6/3/1998 4 6322 4933 Camco KBMG DMY 1.0 BK 0.000 0 5/25/1998 5 6703 5196 Camco KBMG OV 1.0 BK2 0.250 0 6/3/1998 Gas Lift -'--t: 6 7052 5444 Camco KBMG DMY 1.0 BK 0.000 0 5/25/1998 I y5(670/Valve L,j 7 7377 5676 MMH 2 7/8 X1.5 DMY 1.5 RK 0.000 0 6/3/1998 5(67035704, ' Other(plugs,equip.,etc.)-JEWELRY OD:4.750) Depth TVD Type Description ID 1795 1771 SSSV Camco TRDP-1A-SSA 2.312 7418 5706 PBR Brown 2.500 I 7435 5719 PKR Brown'HB-1' 2.500 � ) 7449 5729 NIP Camco'D'Nipple NO GO.Set 2.25"CA-2 5/25/98;pulled 5/27/98 2.250 r 7459 5736 SOS Brown 2.441 7460 5737 TTL 2.441 I General Notes Date Note 8/27/2002 CORKSCREWED TUBING @ 1450'TO 7460' I NOCOIL III PBR • (7418-7419, IOD:2.875) . PKR I (7435-7436, 01:6.151) I NIP (74497NIP OD:2.875) I TUBING (0-7460. 9. 00:2.875, 0:2.441) I Perf (7520-7536) - --- II Perf (7602-7604) STATE OF ALASKA ALASKA• AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell 17 Rug Perforations r Stimulate r Other r Alter Casing Pull Tubing J Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well -- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1" Exploratory r _ - 186 -142 3. Address: 6. API Number: "'" Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 •. 50 - 103 - 20073 - 00" 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 . " 2T -03 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7897 feet Plugs (measured) None true vertical 6067 feet Junk (measured) None Effective Depth measured 7809 feet Packer (measured) 7307, 7413 true vertical 5999 feet (true vertucal) 5625, 5702 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 115 115 SURFACE 3142 9.625 3174 2787 PRODUCTION 7863 7 7893 6064 r.. ..., ' M / ' rl , r.x,Nt; t SAN 1 9 2012 Perforation depth: Measured depth: 7526- 7561', 7592' -7607' f .�_, r g , t ^omftl True Vertical Depth: 5782'- 5813', 5836-5846' B Qt1 €" nchorage Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7458 MD, 5735 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL RETRIEVABLE PACKER @ 7307 MD and 5625 TVD PACKER - BAKER F -1 PRODUCTION PACKER , PLUS B GUIDE @ 7413 MD and 5702 TVD SSSV - CAMCO TR- MAXX- CMT -SR -5 @ 1714 MD and 1698 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 151 423 253 -- 231 Subsequent to operation shut - in 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Iz' • Service r Stratigraphic f 15. Well Status after work: - Oil F, Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP rr SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -305 Contact Brett Packer @ 265 -6845 Printed Name J. Brett Packer Title Wells Engineer Signature ";i5%A1 -'-P-1 Phone: 265 -6845 Date / /,z /r .z. RBDMS 11 3 2012 pi-"‘. Form 10 -404 Revised 10/2010 74 /77 / 2 Submit Original Only /47/Z KUP 2T -03 • ConocoPhillips 014 Well Attributes ax Angle & MD TD Alaska. Inc' Wellbore API /UWI Field Name Well Status !nei (°) MD (ftKB) Act Btm (ftKB) 501032007300 KUPARUK RIVER UNIT PROD 50.37 4,200.00 7,897.0 " "` Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••• SSSV: TRDP 40 1/17/2010 Last WO: 40.00 9/14/1986 Well Omen -2T -0312/30/2011 9:39 19 AM _. .. .. Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,801.0 12/28/2011 Rev Reason: WORKOVER, GLV C /O, SET SLEEVE ninam 12/29/2011 ( I Casing Strings HANGER, 28 Casing Description String 0... String ID ... Top (61613) Set Depth (1,.. Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 32.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (7.. Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.765 32.3 3,174.3 2,787.3 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 Casing Description String 0 ... String ID ... Top 30.1 B S et De h (6... Set Depth V ... Sting Wt... stun J String BTC String 9 P( 1 P( Pt (D N) 9 String ... e P Thrd TIE BACK 7 6.276 30.1 2,058.0 1,992.3 26.00 L - 80 TC - II CONDUCTOR, 32-115 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd SAFETY a j TUBING 1 3 1/2 i 2.992 I 28.3 I 7,458.3 I 5,735.8 I 9.30 I L - 80 I EUE8RDMOD SLEEVE, 1,714 I Completion Details LIU Top Depth (ND) Top Inc! Nomi... Top (ftKB) (RKB) ( °) Item Description Comment ID (in) 28.3 28.3 -0.02 HANGER TUBING HANGER w/ 3.66' PUP 3.500 1,713.9 1,697.5 22.75 SAFETY VLV SCSSSV, TRMAXX- CMT -SR -5, w/2.813" X PROFILE 2.813 7,2752 5,602.6 44.34 LOCATOR BAKER 80-40 LOCATOR w/ 7.58 OF STICK UP 2.992 7,283.8 5,608.7 44.24 PBR BAKER POLISHED BORE RECEPTICLE 3.000 TIE BACK. 11 IL 7,306.9 5,625.2 43.97 PACKER BAKER FHL RETRIEVABLE PACKER 2.920 30 - 2,058 7,358.5 5,662.7 43.37 NIPPLE CAMCO X NIPPLE 2.813 GAS LIFT. 7,406.8 5,697.6 42.07 LOCATOR BAKER 80-40 LOCATOR w/ 544' OF STICK UP 2.992 2,735 7,413.0 5,702.2 42.05 PACKER BAKER F -1 PRODUCTION PACKER , PLUS B GUIDE 4.000 IIII 7,415.5 5,704.1 42.05 SBE BAKER SEAL BORE EXTENSION 3.000 7,447.9 5,728.0 41.96 NIPPLE CAMCO XNIPPLE 2.813 7,457.6 5,735.2 41.93 WLEG BAKER SHEAR OUT SUB 2.950 SURFACE. 1 l Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) 32 -3,174 Top Depth r _ - -- 7 (ND) Top Inc! Top (ftKB) (RKB) (°) Description Comment Run Date ID (in) GAS LIFT, 1,714 1,697.5 22.75 SLEEVE TR - MAXX ISOLATION SLEEVE, OAL =80" 12/28/2011 2.310 4.663 ill MIlk Perforations & Slots Shot B Top (ND) Btm (ND) Dens Top (ftKB) Btm (ftKB) (RKB) (1114B) Zone Date (sp... Type Comment GAS L FT. - _ . 7 7,536 5,782.4 5794.1 C A - 3, 2T - 03 - 7/18/1993 6.0 APERF 2 1/8" EnerJet; ( + / - ) 45 deg. Phasing 5,854 7,531 7,561 5,790.5 5,812.5 A -3, 2T -03 12/11/2011 6.0 IPERF 3 1/2" Millennium HMX. 60 Deg '��' Phasing 7,536 7,561 5,794.1 5,812.5 A -3, 2T -03 10/17/1986 4.0 IPERF 4" HyperJet 11 GAS 1 - 7,592 7,607 5,8355 5,8462 A -2, 2T -03 12/11/2011 6.0 IPERF 3 1/2" Millennium HMX. 60 Deg 7 Phasing 7,602 7,604 5,842.4 5,843.9 A -2, 2T -03 10/17/1986 4.0 IPERF 4" HyperJet 11 GAS LIFT, 7,221 S LOCATOR, 7,275 PBR. 7,284 PACKER, 7,307 l NIPPLE, 7,358 _ l LOCATOR. 1 7,407 PACKER. 7,413 SBE, 7,416 NIPPLE, 7,448 f.: WLEG, 7,458 V J 4 Mandrel Details Top Depth Top Port (ND) Inel OD Valve Latch Size TRO Run APERF, Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (!n) (psi) Run Date Com... 7620 - 7636 1 2,734,6 2,483.5 46.79 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,274.0 12/27/2011 PERF, 7.531 2 4,662.6 3,794.0 46.57 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,265.0 12/27/2011 IPERF, 7,536 3 5,854.1 4,608.7 45.78 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,253.0 12/27/2011 IPERF, 4 6,707.0 5,199.2 44.70 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,240.0 12/27/2011 760 - 7 60 4 5 7,221.4 5,564.7 44.97 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 12/27/2011 7,602-7,604 a PRODUCTION, 2,038 -7,893 TD, 7,897 ! i ConocoPhillaps Time Log & Summary Nlellvrew Web Reporting Report Well Name: 2T - 03 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/21/2011 2:30:00 AM Rig Release: 12/18/2011 12:00:00 AM Time Logs Date From TO Dur S. Depth E. Depth Phase Code Subcode T Comment 11/20/2011 24 hr Summary Mob Rig to 2T -Pad 23:00 00:00 1.00 MIRU MOVE MOB P Mobilize Rig and support equipment from 2A -Pad to 2T -Pad 11/21/2011 MIRU at 2T -03 Well Slot. Fill Pits w/9.6 lb/gal Brine. Hook -up and test Lines. Pull BPV. Circulate Brine. Monitor Well. Install BPV and Blanking Plug. ND Tree. NU BOP E. Perform Initial BOPE Test. 00:00 01:30 1.50 MIRU MOVE MOB P Continue to move Rig and support equipment to 2T -Pad. Spot needed 1 equipment behind Wellhead. 01:30 02:30 1.00 COMPZ MOVE RURD P PJSM. Pull Rig over 2T -03 Well Slot (Pad Operator on Location to observe). Accept Rig at 02:30 hrs, 11- 21 -11. 02:30 07:00 4.50 COMPZ MOVE RURD P Spot and Level rig , waiting for vac trucks to deliver ordered kill fluid. 07:00 09:30 2.50 COMPZ WHDBO MPSP P PU and MU Lubricator, Pull BPV. Lay down Lubricator. Obtain pressures - 500 psi SITP, 0 psi SIIAP and 40 psi SIOAP. 1st load of 9.6 ppg KWF on location at 8 AM Off load into rig pits. Continue to wait on next load of 290 bbls. 09:30 10:30 1.00 COMPZ MOVE RURD P RU circulating lines from tree to rig. 10:30 15:15 4.75 COMPZ MOVE RURD P Fill kill lines to Kill tank with diesel. Hook up OA to kill line. 2nd Load of 290 bbls of 9.6 ppg KWF arrived on location. Load in pits. 15:15 15:30 0.25 COMPZ MOVE PRTS P Pressure test lines at 250 / 3,500 psi. 15:30 15:45 0.25 COMPZ WELCTL SFTY P Held PJSM with rig crew on killing well. Page 1 of 28 • • Time Logs Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 15:45 20:00 4.25 COMPZ WELCTL CIRC P Establish reverse circulation rate at 1 bpm at 370 psi, 1.5 bpm at 1,180 psi while circulating had a pressure drop to 650 psi . Shut down pumps and come back on line to see if upper valves were opening at 1.5 bpm at 390 psi. Increase rate to 2 bpm at 840 psi, tank strap showed to be getting 1 to 1 returns. Pump Hole volume (240 bbls +). Attempt to circulate the "long way" to verify that the Orfice Valve was or was not washed out. Unable to circulate the long way, Resume reverse circulating at 2.0 bpm /885 psi. Returns after 300 total barrels pumped = 9.5 lb/gal heavy. End Well Kill. Blown down lines. Monitor Well. 20:00 20:45 0.75 COMPZ WHDBO PLUG P Install BPV. 20:45 22:30 1.75 COMPZ WHDBO NUND P PJSM. Nipple down Production Tree. Inspect Tubing Hanger threads. Install Test Dart. Pressure up on SSSV Control Line and block in. 22:30 00:00 1.50 COMPZ WHDBO NUND P PJSM. Nipple up BOP Stack (2 7/8" x 5" VBPR installed in both top and bottom Gates). 11/22/2011 Complete NU BOPE. Perform Initial BOPE Test. Pull and LD 2 7/8" Tbg, or pull Tbg in tension and set Slips. _ RU S -Line and drift for possible E -Line Tbg cut. 00:00 05:00 5.00 0 0 COMPZ WHDBO NUND P Complete Nipple -Up BOP Stack. Fill Stack. Function test BOPs. Call -out AOGCC Inspector. (Begin to load Pipe shed with 3 1/2" Drill Pipe). Rig up test equipment. 05:00 15:15 10.25 0 0 COMPZ WHDBO PRTS P Perfnrm initial BOPE Test per ConocoPhillips / AOGCC n requirements at 250/3,500 psi. ®/� ° Record pressure test on Chart. J i�1 / lJ 111 Perform Koomey draw down test. The test was witnessed by AOGCC Field Inspector, J. Crisp. Top Drive was found frozen during testing operation and the Lower VPR's was a failed / Passed during the Initial BOP test. 15:15 17:15 2.00 0 0 COMPZ WHDBO RGRP T Number 10 Valve on the Choke Manifold failed during the pressure test. Rebuild and Re -Test. Good test. 17:15 18:45 1.50 0 0 COMPZ WHDBO PLUG P Cameron Service Rep pulled Test Dart and Back Pressure Valve. Lay down same. Page 2 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 20:30 1.75 0 0 COMPZ WHDBOTHGR PJSM. Pick -up 3 1/2" Landing Pup Joints. Make -up to Top Drive for weight control (35K). BOLDS. Hanger came off seat and observed an 8K weight loss on weight indicator. Work Tubing up to 80% several times (10 cycles) in an attempt to pull free from the PBR No -Joy. Total Tubing stretch at 80% =7' 1 ". (Call out S -Line to lock -out the SSSV and to drift Tubing for an E -Line cut). Set Slips with Tubing in tension. Prep for S -Line operations. 20:30 00:00 3.50 0 0 COMPZ RPCOM RURD S -Line arrived. Spot Unit. 11/23/2011 RU S -Line. Lock open the TRSSSV. Drift Tbg. RD S -Line. RU E -Line. Rattle Tbg with String Shot. 00:00 01:30 1.50 0 0 COMPZ RPCOM RURD P PJSM. Rig up S -Line equipment. Make -up Tool String to drift the 2 7/8" Tubing down to the TRSSSV. 01:30 07:15 5.75 0 1,936 COMPZ FISH SLKL P RIH with a 2.340" Drift. Got down to the top of the TRSSSV at 1,822 -ft slmd. with no problems. POOH. RIH with a Brush below the 2.340" Drift to verify that the Flapper in the TRSSSV is still open and the "brush" the TRSSSV profile. Confirmed that the Flapper is still open. Clean -up the Shifting Tool profile. POOH. RIH with a Catcher Sub (there is only one setting tool for this size /type of TRSSSV on the Slope) Set Catcher Sub at 1,936 -ft with no problems. POOH. RIH with the TRSSSV Lock -out Tool. Leave in profile. POOH. RIH with a 2.13" Blind Box. Set down on the Lock -out Tool. Work Spang Jars to shift Lock -out Sleeve . Lock -out Tool fell through the TRSSSV down to the Catcher Sub. POOH. 07:15 08:45 1.50 0 1,934 COMPZ RPEQP1SLKL P Crew Change Out. RIH w/2.5" RB with prong Z5. Fished out lock out tool at 1934' slmd, Latch,POOH with Z5. RIH with TRSSSV Lock -out tool, set down and Work to Shift Lock -out sleeve open. TRSSSV appeared to be Locked Out. POOH and Lay Down Same. 08:45 10:00 1.25 0 1,936 COMPZ RPEQP1 SLKL P RIH w/ 2.5" GR to Catch at 1936' slmd. latch and POOH w/ Catch and Lay down same. 10:00 12:30 2.50 0 7,215 COMPZ RPEQP1SLKL P RIH w/ 5' stem,2.14" Cent (78" OAL) sat down at 6,370' slmd, work past, continue down and tagged at 7,215' slmd, unable to work passed. POOH and lay down same. Page 3 of 28 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 14:00 1.50 0 7,221 COMPZ RPEQP1SLKL P RIH w/ 5' stem, 1.98" Cent. Tagged at 7,221' slmd. POOH and lay down same. 14:00 17:30 3.50 0 6,750 COMPZ RPEQP1SLKL P MU and RIH w /2.23" OD catcher and tagged at 6,750' slmd. Unable to work passed. POOH and RDMO Slick -line. Dispatch E -Line Crew & Equipment. 17:30 19:30 2.00 0 0 COMPZ RPEQPI ELNE P E -Line arrive on Location. Spot Unit. 19:30 22:30 3.00 0 0 COMPZ RPEQP1ELNE T PJSM. Rig up E -Line equipment. While rigging up noticed a "kink" in the E -Line. Cut line and re -head. Make up tool string. Pressure test lubricator at 500 psi. Good. 22:30 00:00 1.50 0 COMPZ RPEQP1 ELNE P Run in with CCL and a 5 -ft x 240 grain String Shot. 11/24/2011 Log String Shot into place and shoot. POOH. RIH with Nalco RCT to cut the 2 7/8" Tbg. Cut Tbg at 7100'. POOH. RD. Circulate Well. Single down 2 7/8" Tbg from cut depth. PU BHA #3. Single in on 3 1/2" Drill Pipe. 00:00 07:00 7.00 0 0 COMPZ RPEQP1 ELNE P Continue to run in with CCL and String Shot. Set down at 7,176 -ft (pick -up depth). Tie into the GLM at 7,052 -ft. Drop back down. Log String Shot into place at 7,128' - 7,133'. Shoot. Good. POOH. Make up the 1.688" RCT. RIH. Set down at 7,115 -ft (pick -up depth). Attempted 4 time to get down to were the String Shot had rattled the Tubing. No -Joy. Tie into the GLM at 7,052 -ft. Drop back down and position the RCT at 7,100 -ft elmd. Set Anchor. Good. Fire Cutter. Good indication on surface that Tubing cut. POOH. 07:00 09:00 2.00 0 0 COMPZ RPCOM CIRC P Rig back E -line. Install 3 1/2" Landing Joint. MU to TD and PUH slowly and confirmed that the TBG was clearly cut. RDMO E -Line equipment and Tools. Circulate 9.6 ppg brine around 1 -1/2 times to surface until clean at 5 bpm, 1050 psi. Had dirty diesel mixed with the brine during the first 140 bbls. Shut down and monitor well. 09:00 09:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM with Rig Crew,SLB and Cameron. Discuss Hazard for Pulling tubing and control line and laying down tubing. 09:30 12:30 3.00 7,100 5,310 COMPZ RPCOM TRIP P Pull Tubing Hanger to Rig Floor, Up Wt 80k. Remove and Lay down Hanger, secure control line to spooler. TOOH sideways with 2 7/8" Tubing while spooling up control line. Page 4 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:15 0.75 5,310 5,310 COMPZ RPCOM PULD P Reached the SSSV and end of control line. Joint #9,11 & 45 showed sign of being corkscrew. Recoved 33 SS Bands. Unload spooler and control line from Rig floor. 13:15 20:00 6.75 5,310 0 COMPZ RPCOM TRIP P Continue to TOOH with 2 7/8" Tubing sideways. Recovered Tubing Hanger, 2 ea 2 7/8" Pup Joints, 223 ea Joints of 2 7/8" Tubing, TRDP (SSSV), 6 ea GLMs, RCT cut 2 7/8" Stub (9.60 -ft.). Control Line complete and 33 SS Bands were also recovered. The 1.688" RCT cut was perfect. 20:00 21:00 1.00 0 70 COMPZ RPCOM FISH P PJSM. Install Wear Bushing. Make -up BHA #1, 6 1/8" Mill /Casinq Scraper. Single in on 3 1/2" Drill Pipe to 48 -ft. Work to 70 -ft. POOH and inspect Mill. As expected, found two shallow gouged spots on the side of the Mill caused by damaged 7" Casing. 21:00 23:30 2.50 0 390 COMPZ RPCOM FISH P Make -up BHA #2, 4 3/4" Bull Nose /Casing Scraper. Single in on 3 1/2" Drill Pipe to 110 -ft. Drop through. Continue down to 360 -ft. Push to 370 -ft. with 1 - 3K. Work from 370' - 390' with pushing up to 10K and occasional rotation up to 3K torque. Stopped further progress at i 390 -ft. Pull back through buckled area with "bobbles and pipe chatter". c tJ Continue to pull back to surface standing 3 1/2" Drill Pipe in Derrick. 23:30 00:00 0.50 0 0 COMPZ RPCOM FISH P Make -up BHA #3, 4 3/4" Bull Nose on 3 1/2" Drill Pipe. (Largest OD is the Tool Joints on the Drill Pipe at 5.00 "). 11/25/2011 Single in a 4 3/4" Bull Nose on 3 1/2" DP to get through the damaged 7" Csg section. Continue down to the top of the 2 7/8" Cut -off Stump. Rev Circ. TOOH. RU E -Line. Record CBL. Pick TOC. Run String Shot to rattle 7" back -off Collar. RD E -Line. Page 5 of 28 • Time Logs Date From To Dui S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 0 7,078 COMPZ RPCOM FISH P Single in with BHA #3 and 3 1/2" Drill Pipe from the Derrick. Had to continue to "push" through the damage 7" Casing section down to —525 -ft where the Drill Pipe weight was enough to continue in with no push weight from the Top Drive. Stop at 1,000 -ft and record a torque weight check at 1500- ft/lbs. Continue in. Make Torque checks at 2,000 -ft = 1,500 ft/lbs, and at 3,000 -ft = 2,500 ft/lbs. Continue to single in with 3 1/2" Drill Pipe down to 7,078 -ft (top of the 2 7/8" Tubing Stump is at 7,100 -ft). Top of fish is a tad sticky. 4K over pull off bottom. Normal string weight 162K up weight, 77K down weight. 04:30 07:00 2.50 7,070 7,070 COMPZ RPCOM CIRC P Reverse Circulate Well x 1 1/2 volumes. 07:00 11:15 4.25 7,070 0 COMPZ RPCOM TRIP P TOOH standing back drill pipe. Lay down drift assembly. 11:15 11:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazard for removing riser and installing shooting flange. E -line Crew on location. 11:30 12:45 1.25 0 0 COMPZ RPCOM NUND P Nipple Down Riser and Nipple Up Shooting FLange. 12:45 13:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM with E -Line Crew & Rig Crew. Discuss Hazard for Rigging up and Loading E -Line Equipment and Tools. 13:00 14:30 1.50 0 0 COMPZ RPCOM ELOG P MIRU E -Line Unit and Load Equipment to Rig Floor. 14:30 21:00 6.50 0 0 COMPZ RPCOM ELOG P RIH with CAST -M RCBL,Equipment on E -Line. Record a Cement Bond Log from 7,060 -ft back to surface at 60- ft/min. Top of Cement picked at 2,150 -ft. Lay down CBL tools. Make -up a 240 grains x 5 -ft String Shot. RIH. Record tie -in pass. Position the middle of the String Shot across the 7" Casing Collar at 2,078 -ft. Fire. Good. POOH. Rig down and release E -Line. 21:00 22:30 1.50 0 0 COMPZ RPCOM NUND PJSM. Nipple down Shooting Flange. Nipple up Riser. 22:30 00:00 1.50 0 886 COMPZ RPCOM TRIP P PJSM. Pick -up Baker Inflatable Retrievable Bridge Plug. Trip in hole on 3 1/2" Drill Plpe. Gently work Packer through the damage 7" Casing section. Continue RIH. 11/26/2011 Continue to trip in with Inflatable Bridge Plug. Set and test same. Dump —50 -ft of 20/40 mesh sand on top of IBP. ND BOP. RU Hydratight Equip. Control 7" Casing growth. ND Tubing Spool and pull 7" Pack -off. Spear Casin•. 00:00 01:00 1.00 886 2,660 COMPZ RPCOM TRIP P Continue to trip in with the IBP on 3 1/2" Drill Pipe. Up Weight = 84K. Down weight = 59K. Page 6 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 2,660 2,667 COMPZ RPCOM PACK P Position the center element of the IBP at 2,667.25-ft. (Note: Top of Fishing Neck is at 2,659.66 -ft, ` Bottom of the IBP is a t 2,6670.77 -ft). Pressure up to 500 psi to close the Inflation Valve. Good. Bring pump pressure up to 700 psi and hold for 15 minutes to begin the setting procedure. Increase pressure to 1,100 psi x 15 minutes. Set 1K down. Increase pressure to 1,600 psi x 15 minutes. Set 1K down again. Increase pressure to 2,100 psi ( Hydraulic Running Tool shear release pressure). Bumped pressure up to 2,330 psi. Hydraulic Running Tool released from the IBP. 02:30 03:15 0.75 2,667 2,657 COMPZ RPCOM PRTS P Pull up Hole 10 -ft. Hydraulic RunningTool free from the IBP. Pressure test IBP at 3,000 psi x 15 minutes. Good test. Recorded the setting sequence and the final pressure test on a chart. 03:15 05:00 1.75 2,657 0 COMPZ RPCOM TRIP P Trip out standing back the 3 1/2" Drill Pipe in the Derrick. Lay down Hydraulic Running Tool. 05:00 06:00 1.00 0 2,515 COMPZ RPCOM TRIP P Trip back in with 3 1/2" Drill Pipe with a Bull Plug on the end. (Bull Plug ID = 2.500 "). Up Wt =84k / Dn Wt =57k. 06:00 09:00 3.00 2,515 2,515 COMPZ RPCOM OTHR P RU Circulating Hose. Dump 1050# of Sand on top of IBP set at 2659.66 -ft. Let Sand Settle. RIH and Tag top of sand at 2,606 -ft. RD Circulating Equipment. 09:00 09:15 0.25 2,515 2,606 COMPZ RPCOM SLKL P PJSM. Discuss hazard for TOOH. 09:15 10:30 1.25 2,606 0 COMPZ RPCOM TRIP P TOOH standing back Drill Pipe. 10:30 10:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazard for Nipping Down BOPE. 10:45 14:30 3.75 0 0 COMPZ RPCOM NUND P Bleed Down OA. Nipple Down Riser. Nipple Down BOPE. 14:30 14:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for 7" Casing Growth. 14:45 22:30 7.75 0 0 COMPZ RPCOM NUND P Install Hydratight System. Control 7" r/ Casing growth. Total Hydratight Control Growth = 36 inches. Total Hydratight Cycles = 139. Strarting Pressure = 15,000 psi. Ending Pressure = 1,000 psi. Rig down Hydratight equipment. Nipple down Tubing Spool. Pull 7" PAck -Off. Page 7 of 28 I - • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 30 COMPZ RPCOM FISH P PJSM. Make -up BHA #6, ITCO Casing Spear. Plant Spear in the 7" Casing. Pull Casing to neutral weight, 90K. (Total Hydratight growth plus pick -up to neutral weight = 41 inches). Over pull 7" Casing to 137K (includes Top Drive weight). Set Slips. 11/27/2011 N11 RfP Stark MU Baker MS Cutter. Cut 7" Csq. Spot Hot Sea Water. TOOH w /MS Cutter. Install 7" Plpe Rams. Spear Csg. Circulate out Arctic Pack. Lift BOP Stack. Pull Slips. NU BOP Stack. Single down 7" Csg to Cut Stub. 00:00 00:15 0.25 30 0 COMPZ RPCOM FISH P Release ITCO Spear. POOH and lay down same. 00:15 01:00 0.75 0 0 COMPZ RPCOM FISH P Rig up Wachs Cutter and cut -off excess Casing growth. Rig down Wachs Cutter. 01:00 07:00 6.00 0 0 COMPZ RPCOM NUND P PJSM. Nipple up Adaptor Flange, Cement Cross, and the BOP Stack. (Load 7" Casing in Pipe Shed). 07:00 07:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Making Up BHA. 07:15 08:00 0.75 0 4 COMPZ RPCOM PULD P Load Tools to Rig Floor. MU BHA. 5 1/2" MSC w/ 2 1/4" Knives. 08:00 10:00 2.00 4 2,033 COMPZ RPCOM TRIP P TIH with MSC. Perform Torque Check at 570 -ft and 970 -ft,1 K Torque at Both Depth. Continue In Hole with MSC. 10:00 12:00 2.00 2,033 2,100 COMPZ RPCOM OTHR P Stop and Correct Drill pipe Depth to 2,033 -ft. Locate Casing Collars with MSC at 54 SPM at 250 psi and Correlate to Cement Bond Log. Collars should be at 2036 -ft and 2078 -ft, found collars at 2058 -ft and 2099 -ft. PUH and lay down one joint to locate collar above that should be at 1995 -ft on the cement bond log, located that collar at 2016 -ft. Call Town Engineer and discuss the depth found with MSC compare to the Log. RIH and Locate CSG collars at 2016',2058',and 2099 ft. Locate collar at 2058 ft again, PUH to 2038 ft and park to make 7" Casing cut. 12:00 12:30 0.50 2,038 2,038 COMPZ RPCOM CPBO P PJSM. Discuss hazard of cutting casing and taking returns to tanks. Set Parameters, Up Wt 65k / Dn Wt 65K, 60 RPM, 1100 Free Torque. Start Cutting at 4 BPM, 580 psi at 60 RPM, 2K Torque, Increase Pump Rate to 5 BPM, 660 psi, 60 RPM, 2k Torque. Seen Psi fall from 660 psi to 330 psi after 62 bbls pumped, good indication that Casing is cut. 12:30 13:15 0.75 2,038 2,038 COMPZ RPCOM CIRC P Circulate 80 bbls of Hot Seawater into 7" Casing at 4.5 bpm, 280 psi and let soak. Page 8of28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 14:45 1.50 2,038 0 COMPZ RPCOM TRIP P PJSM. Blow down top drive. TOOH standing back drill pipe and L/D MSC Assembly 14:45 15:45 1.00 0 0 COMPZ RPCOM EQRP P PJSM. Drain Stack and change lower rams to 7" solid body rams and function test. 15:45 16:45 1.00 0 0 COMPZ RPCOM PULL P PJSM. MU Spear Assembly. Spear 7" Casing. PUH to 200K. 16:45 00:00 7.25 0 0 COMPZ RPCOM CIRC P Establish Circulation and Pup down 7" Casino taking returns from the OA to the open top tank to displace artic pack with hot diesel and follow with more hot seawater. Continue to pump until returns are clean. Pump Rate at 2 bpm, 160 psi on the casing and 60 psi on the 9 5/8" OA. Pump 290 bbls of warm diesel and allow to soak. Due to very thick Arctic Pack in the returns tank it took a long time to suck out enough fluid in the taks to make room to recover the Diesel Soak with hot Sea Water. 11/28/2011 Circ out Diesel with Hot Sea Water. Lift Stack and pull Csg Slips. Set Stack back down and NU. Single down 7" Casing or "work through" the damaged 9 5/8" Casing section. 00:00 04:30 4.50 0 0 COMPZ RPCOM CIRC T Continue to make room in returns tank to displace the Diesel Soak (Vac Truck doing the best it can). Bring Rig Pump on at 4.0 bpm /320 psi. After 20 bbls pumped, no returns. Shut down and investigate. Found Maniford at the Returns Tank plugged with Formation Sand. Clean out Manifold. Also found Hard Line Hose that had sand in it and a broken nipple (no spill). Call -out for replacement hose. 04:30 06:30 2.00 0 0 COMPZ RPCOM CIRC P Resume an attempt to circulate. Plugged off line again with Sand. Re -route returns to the Cutting Bin. Continue to flush the "Diesel Soak" with Hot Sea Water at 4.0 bpm /60 psi. 06:30 08:30 2.00 0 0 COMPZ RPCOM CIRC P Swap well over to 9.6 ppg brine. Circulate 164 bbls at 4 bpm, ICP =130 psi, FCP= 180 psi. 08:30 09:30 1.00 0 0 COMPZ RPCOM NUND P PJSM. ND BOPE and Retrieve Slips from 7" Casing. Had to cycle casing to remove slips. 09:30 11:00 1.50 0 0 COMPZ RPCOM NUND P Slips are now out. PJSM. NU BOPE. Fill stack with fluid and perform static leak test. Page 9 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 2,038 2,000 COMPZ RPCOM PULL P Crew Change. PJSM.Start Cycling Casing while pumping at 4 bpm, 60 psi. Made 8 cycle while pulling 50k to 225k worked weight to 245k,250, and casing pulled free at 275k. Up Weight after casing pull free was 110k 11:30 12:15 0.75 2,000 2,000 COMPZ RPCOM PULD P RU Casing Equipment. Remove 1st joint of casing and lay down 7" CSG spear. 12:15 17:00 4.75 2,000 0 COMPZ RPCOM PULL P POOH, laying down 7" casing. 17:00 17:45 0.75 0 0 COMPZ RPCOM PULD P Un -Load Casing from Pipe Shed. R/D Casing Handling Equipment. Recover 11 total centtralizer. Every joint from surface except the last two, were corksrewed and bent, no sign of scale or corrosion. Joint number 10 from surface had damage to the casing collar. 0 0 COMPZ RPCOM MPSP P Set Test Plug. CIO lower pipe ram's back to 2 7/8" x 5" VBR's. 17:45 22:00 4.25 0 0 COMPZ RPCOM BOPE P Test Lower Pipe Rams and body breaks at 250/3000 psi. Record test on chart. Rig down test equipment and pull test plug. 22:00 00:00 2.00 0 315 COMPZ RPCOM TRIP P Make up HA #9, 9 5/8" Casing Scraper Assembly. Trip in to 318 -ft. Tagged 9 5/8" damage Casing. Tried several more times, always tagging at the same spot. Pull one Stand. Pick -up 1 single joint of Drill Pipe. 11/29/2011 Circulate Hot SW from 318 -ft to clean -up remaining Arctic Pack. Chase with 9.6 Brine. TOOH with 9 5/8" Csg Scraper. Perform Weekly BOPE Test. RU E -Line. Record Gyro and Caliper Logs in the 9 5/8" Csg. Rig Repair crack in wall of Pit #4 /Pill Pit. 00:00 02:30 2.50 315 315 COMPZ RPCOM CIRC P Circulate with hot Sea Water from 315 -ft to clean out remaining Arctic Pack from the top of the Well. Circulate at 2.0 bpm /70 psi and at 4.0 bpm/70 psi. Total volume pumped 75 bbls. Swap top of well back over to 9.6 lb/gal Brine. 02:30 03:30 1.00 315 0 COMPZ RPCOM TRIP P Trip out with BHA #9. Lay down same. Pick -up the Swizzle Stick and wash out the BOP Stack at 8.0 bpm. 03:30 11:30 8.00 0 0 COMPZ WELCTL BOPE P PJSM. Set Test Plug. Rig up test equipment. Test BOPE per / ConocoPhillips / AOGCC requirements at 250/3,000 psi. Perform Koomey draw down test. Record pressure tests on Chart. The State's right to witness the test was waived by AOGCC Field Inspector, L. Grimaldi. Page 10 of28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 17:00 5.50 0 2,045 COMPZ EVALWE ELNE P Held PJSM on RU Gyro and PDS tools. Discussed well control scenario's. RU e line and RIH to 2,045 -ft and log out of the hole to surface. RD E line. 17:00 18:00 1.00 0 0 COMPZ RPCOM OTHR P Install wear ring and bring 7" CSG pup jts to rig floor for Dummy run. 18:00 19:00 1.00 0 0 COMPZ RPCOM PULD P PJSM- running of String Mill assembly's, PU MU BHA #10- Bull Nose, DC, XO, 8 3/8" String Mill, Flex Joint, 8 1/2" String Mill. Lay down equipment for Rig Repair of Pill Pit Wall. 19:00 00:00 5.00 0 0 COMPZ RIGMNT RGRP T Rig Repair crack in wall of Pit #4 /Pill Pit. 11/30/2011 Rig Repair crack in wall of Pit #4 /Pill Pit. Work damaged 9 5/8" Csg sections with String Mills. Dummy Drift for 'ES' Cementer. 00:00 05:00 5.00 0 0 COMPZ RIGMNT RGRP T Rig Repair crack in wall of Pit #4 /Pill Pit. 05:00 10:00 5.00 0 319 COMPZ RPCOM TRIP P PJSM- running of String Mill assembly's, PU MU BHA #10- Bull Nose, DC, XO, 8 3/8" String Mill, Flex Joint, 8 1/2" String Mill, XO, Bumper Sub, Oil Jars, 4 3/4" DC's to 319 -ft bull nose depth 10:00 14:30 4.50 319 2,037 COMPZ RPCOM MILL P RIH with BHA #10 tagged up at 313 -ft mill depth. Gather parameters 50k up and dn, 60 rpm with 1,000 ft/Ibs free torque, circulating at 4 bpm at 80 psi with 5k WOM with 2,000 ft/lb of torque. Milled thru tight spots from 313 to 314 -ft and 375 to 378 -ft mill depth fell thru and RIH to 2,000 -ft mill depth. Change hole over to 140° sea water and ream from 1,437 to 2,000 -ft mill depth. Pump sweep from surface to surface with bull nose at 2,037 -ft. 14:30 15:45 1.25 2,037 0 COMPZ RPCOM TRIP P POOH and Lay down milling assy. 15:45 17:00 1.25 0 0 COMPZ RPCOM OTHR P RU CSG equipment to MU Skirted screw in assy, 7" Pup jt, ES Cementer, and 7" Pup jt. 17:00 18:30 1.50 0 241 COMPZ RPCOM PULD P MU Skirted screw in assy, 7" Pup jt, ES Cementer, and 7" Pup jt. Cross over to 3 1/2 IF and Continue to RIH w/ BHA assy to 241 -ft. 18:30 20:00 1.50 241 377 COMPZ RPCOM TRIP P RIH with BHA #11, sat down and unable to work past 377 -ft with 10k WOB, POOH and lay down Drift assembly. 20:00 21:00 1.00 0 306 COMPZ RPCOM PULD P PJSM- running of String Mill assembly's, PU MU BHA #12- Bull Nose, 6 1/8" stabilizer, 4 3/4" DC, XO, 8 3/8" String Mill, 8 1/2" String Mill, XO, Oil Jars, 4 3/4" DC's to 306 -ft bull nose depth Page 11 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 306 983 COMPZ RPCOM MILL P RIH with BHA #12 and tag at 378 -ft mill depth, Set parameters 50k up and dn, 40 rpm with 1,000 ft/Ibs free torque, circulating at 4 bpm at 60 psi with 5k WOM with 2,200 ft/lb of torque. Milled thru tight spots from 378 to 383 -ft, reciprocate thru area several times, 5k to slide thru, BDTD and continue RIH to 983 -ft. 12/01/2011 Continue work damaged 9 5/8" Csg sections with String Mills. Dummy Drift for 'ES' Cementer. Back off 7" Csg stub. Spear and Recover 7" Csg stub. Change out Lower Rams to 7" and Test. Change Over Floors to run Csg. ✓ 00:00 01:45 1.75 983 2,044 COMPZ RPCOM CIRC P Continue to RIH from 983 -ft to 2,044 -ft mule shoe depth. no problem getting in top of 7" stub. Pump sweep from surface to surface with bull nose at 2,044 -ft. Change hole over to 9.6 brine. 01:45 04:00 2.25 2,044 0 COMPZ RPCOM TRIP P POOH and Lay down milling assy. 04:00 04:30 0.50 0 234 COMPZ RPCOM PULD P MU Skirted screw in assy, 7" Pup jt, ES Cementer, and 7" Pup jt. Cross over to 3 1/2 IF and Continue to RIH w/ BHA assy to 234 -ft. 04:30 06:30 2.00 234 2,037 COMPZ RPCOM TRIP P RIH with BHA #13, 10k dn wt to slide thru tight area 373 to 383 -ft, continue RIH with BHA to 2,037 -ft, Circulate Bottoms Up at 4 bpm at 160 psi. 06:30 07:30 1.00 2,037 0 COMPZ RPCOM TRIP P POOH and Lay down drift assy. 07:30 08:00 0.50 0 0 COMPZ RPCOM OTHR P Jetted BOP Stack to clean ram cavaties. 08:00 09:30 1.50 0 314 COMPZ RPCOM PULD P PU and MU BHA #14 Back off tool to 314 -ft 09:30 11:30 2.00 314 2,352 COMPZ RPCOM TRIP P Trip in hole with BHA #14 from 314 -ft to 2,352 -ft filling DP every 5 stands with fresh water and spaced out slips straddling 7" CSG cplg to be backed off. 11:30 12:30 1.00 2,352 2,352 COMPZ RPCOM OTHR P Set slips on BO Tool and Pressure up to 1,350 psi for inital break and continue to cycle tool for a total of 8 cycles at 670 to 920 psi, backing off CSG 3 1/4 rds. Released BO Tool. 12:30 13:30 1.00 2,352 2,352 COMPZ RPCOM CIRC P Drop ball and rod, shear out POS at 2,400 psi and reverse circulate fresh water out of DP. 13:30 15:00 1.50 2,352 0 COMPZ RPCOM TRIP P POOH with BO Tool and lay down same. 15:00 16:00 1.00 0 2,050 COMPZ RPCOM PULD P PU and MU BHA # 15 to 16 -ft and RIH to 2,050 -ft and Engage spear. Continue to Back out CSG stub 2,058 -ft and PU 1 -ft. 16:00 17:00 1.00 2,057 2,057 COMPZ RPCOM CIRC P Circulate 2 Bottoms up at 5 bpm at 190 psi. 17:00 18:30 1.50 2,057 0 COMPZ RPCOM TRIP P POOH with Fish from 2,057 -ft, Clean and lay down Spear. Stub has pin looking down. Page 12 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 0 0 COMPZ RPCOM PULD P Clean and clear floors. Bring in Cmt. Head and Centralizers. 19:30 20:00 0.50 0 0 COMPZ RPCOM OTHR P PJSM- Setting test plugs. Pull Wear Ring. Set Test Plug. 20:00 21:30 1.50 0 0 COMPZ RPCOM BOPE P PJSM. Change out Lower Rams to 7 ". 21:30 23:30 2.00 0 0 COMPZ RPCOM BOPE P PJSM. RU test equipment. Pressure test Lower 7" Rams 250/3000, leak in head pin on high pressure test, repair and retest 250/3000, chart test. RD test equipment 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR P Change over floors to run 7" Csg. 12/02/2011 Run New 7" TC -II Csg, 'ES' cementer and screw into top of 7" Csg. Pressure Test 7" Csg. Cement 7" x 9 5/8" annulus to surface. ND BOPE. Set Csg. in Slips in Tension. Cut 7" Csg. Install Pack Off. NU New Tbg. Head. 00:00 00:30 0.50 0 0 COMPZ RPCOM OTHR P Continue to change over floors to run 7" Csg. 00:30 04:00 3.50 0 2,045 COMPZ RPCOM RNCS P PU Triple- Connection Screw -in -sub (Set Up Pin Down), 10 -ft pup, HES 'ES' Cementer (6 pins set to shear at 3300 psi), 10 -ft Cross over Joint and Single in on 7 ", 26#, TC -II Csg with one straight blade centralizer per joint. lost weight at 375 -ft, Rotate 1/4 turn and slide thru slowly on its own, continue RIH to 2,045 -ft. Up wt 88k, Dn wt 80k 04:00 05:30 1.50 2,045 2,058 COMPZ RPCOM RNCS P MU 14.78 -ft pup jt and XO to Top Drive, RIH slowly rotating and pumping 4 bpm at 60 psi, engage and screw into stub at 2,058 -ft, torque to 10k, BDTD, RU testing equipment. RD Csg. equipment 05:30 06:00 0.50 2,058 2,058 COMPZ RPCOM PRTS P Pressure test 7" Csg 2000 psi, bring up to 2500 psi, chart test. RD test equipment. 06:00 10:30 4.50 2,058 2,058 COMPZ RPCOM NUND P PJSM- Rigging up cement equipment. RU Cement Head with Closing plug loaded. SLB Cement equipment. Held PJSM with all contractors involved in CMTjob. Page 13 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 14:30 4.00 2,045 2,045 COMPZ CEMEN "CMNT P Pressure test Rig pump lines at 4,000 psi. Open cementer at 3,274 psi and break circulation with rig pump. Switch over to SLB and pump 10 bbls ahead and flush lines. PT SLB at 2,500 psi. Circulate 100 bbls of 110° F Sea water to warm up 9.625 x 7" annulus. Mix and Pump and pump 15 bbls of 15.7 ppg AS -1 Slurry followed by 76 bbls of 15.7 ppg AS -1 Slurry w/ 1.5 Ib. / bbl Cemnet, Followed by 9 bbls of 15.7 ppg AS -1 Slurry, drop release closing plug and follow with 1 bbl of 15.7 ppg AS -1 Slurry, 10 bbls of Fresh water, followed by 71 bbls of 110° F Sea water, Seen 15.7 PPG slurry at 35 bbls of SW away and closed OA valves in and squeezed away at 850 psi up to 950 psi for last 36 bbls of SW at 2 bpm. Bumped plug, seen 1,230 psi pressure spike while shifting ES Cementer closed and pressure up to 2,600 psi. Let sit for 5 minutes and Bleed back .75 bbls. RD Cementers and clean up through OA valve, rinsing BOP stack. 14:30 00:00 9.50 32 32 COMPZ WHDBO NUND P ND and Lift BOPE. Top of cement 40" from Csg head flange. Install 7" x 10.75" Emergency slips at 50k OSW of 88k. Cut CSG stub with Wachs cutter and remove stub and pup. ND Cement Cross, flow back riser and rack back BOPE. Install new casing packoff. NU new McEvoy Gen 4 tubing head. 12/03/2011 NU New Tbg. Head. Test Csg Packoff. NU BOPE. Test Tbg Head Lower Break. Set Test Plug and test BOPE 250/3500. Drill out Cement and ES cementer closing plug. P/T 7" Csg 3000 psi. Run Junk Mill to Top of Sand. 00:00 01:00 1.00 32 32 COMPZ WHDBO NUND P Continue NU of new McEvoy Gen 4 tubing head. 01:00 01:30 0.50 32 32 COMPZ WHDBO BOPE P RU testing equipment, pump plastic packing, test Csg packoff 3000 psi, held 15min. RD testing equipment. 01:30 05:30 4.00 32 32 COMPZ WHDBO NUND P NU BOPE. Rebuild and install VBR's in lower cavity. 05:30 09:30 4.00 32 32 COMPZ WHDBO BOPE T Pressure test break below Tbg head against cement plug 3000 psi, chart same. Set test lu in Tbg Hanger. 9 9 er. 9 Test BOPE 250/3500. VBR's failed - change out Ram packers and re install. Test at 250/3,500 psi with 2 7/8 and 3 1/2 Testjts. 09:30 11:30 2.00 0 1,900 COMPZ RPCOM PULD P PU and MU 6 1/8 Bit assy and RIH to 1,900 -ft and tag up. Page 14 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 16:00 4.50 1,900 2,618 COMPZ RPCOM DRLG P Gather parameters: 71K up wt, 71k dn wt, 71k ROT wt at 80 rpm's with 1,600 ft/lbs free torque, circulating at 5 bpm @ 260 psi. Begin drlg out cmt at 4 to 5k WOB w/ 1,800 ft/Ibs. torque from 1,900 -ft to wiper plug at 2,044 -ft. drill out wiper plug at 2,046 -ft and chase to 2,150 -ft and set down work free and continue to 2,618 -ft. 16:00 17:00 1.00 2,600 2,600 COMPZ RPCOM PRTS P RU and PT 7" CSG at 3,000 psi 17:00 19:30 2.50 2,600 0 COMPZ RPCOM TRIP P POOH and lay down Drlg BHA and clean boot baskets. 1 gal Alum, chunks of cement, magnet had small amout of metal Shavings. Wash BOPE with swizzle stick and magnet. 19:30 22:30 3.00 0 2,620 COMPZ RPCOM MILL P PJSM- Discussed hazards with MU and RIH of Mill Assembly. MU Junk Mill, Csg Scraper, Boot Baskets, Magnet, Bumper Sub, Oil Jar, Pump- out -Sub, DC's and RIH on DP to 2,550 -ft and CBU. Tag dn at 2,581 -ft, 84k up/ 77k dn, 80k rot, 1800 ft/lb torque, 40 rpm, rotate dn to top of sand at 2,619 -ft, dry mill with 2 -3k torque, Spud dn several times and continue dry mill w/ 5k wob, start milling after 30 min, mill dn to 2,620 -ft. 22:30 00:00 1.50 2,620 626 COMPZ RPCOM TRIP P Pull 1 std wet, drop Ball Bar and open Pump- out -Sub at 2100 psi, POOH with Milling BHA. 12/04/2011 Run RCJB and Circulate well clean. Standby for Weather, Field Wide Phase 3 declared. 00:00 01:00 1.00 626 0 COMPZ RPCOM TRIP P POOH and lay down Milling BHA, ✓ clean out boot baskets. 01:00 03:15 2.25 0 2,632 COMPZ RPCOM CIRC P MU RCJB, B000t Baskets, Magnet, Bumper Sub, Oil Jar, Pump- out -Sub, DC's and RIH on DP to 2,550 -ft, 77k up /70k dn, 75k rot, 20 rpm, 1600 ft/lb torque. Drop 7/8 ball pumping 4 bpm at 290 psi, seat ball 4 bpm at 490 psi, rotate and wash dn 2,622 to 2,632 -ft, CBU. 03:15 05:30 2.25 2,632 0 COMPZ RPCOM TRIP P POOH with RCJB BHA, Clean out RCJB and boot baskets, some metal, cement in basket, ready tools to rerun. 05:30 06:30 1.00 0 2,556 COMPZ RPCOM CIRC P RIH with RCJB BHA, Boot Baskets, Magnet, Bumper Sub, Oil Jar, Pump- out -Sub, DC's on DP to 2,556 -ft, Page 15 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 23:30 17.00 2,556 2,556 COMPZ RPCOM OTHR T Phase 3 conditions declared field wide, standby for high winds and drifting snow. Off High Line at 1100 hrs. Phase 2 on Spine road declared at 18:00, Phase 3 on all drill sites. road cleared to 4 corners, confer with CPF -2 Drill Site Lead, Roads and Pads, Prep for going back to work. 23:30 00:00 0.50 2,556 2,556 COMPZ RPCOM SFTY P PJSM- Discuss hazards with being shut down and going back to work after major blow. 12/05/2011 Run RCJB and Circulate well clean. Circulate out Sand. Change hole over to 9.6 ppg. Pull RBP. Engage and Jar on Fish. 00:00 01:30 1.50 2,556 2,648 COMPZ RPCOM CIRC P RCJB BHA, Boot Baskets, Magnet, Bumper Sub, Oil Jar, Pump- out -Sub, DC's on DP at 2,556 -ft, tag sand at 2,632 -ft, 77k up/ 70k dn, 75k rot, 20 rpm, 1600 ft/lb torque, pump 5 bpm at 700 psi, wash and rotate dn to 2,648 -ft, CBU, PU 1 std and BDTD. 01:30 03:30 2.00 2,556 0 COMPZ RPCOM TRIP P POOH with RCJB BHA, RCJB and boot baskets empty, Lay down BHA #19. 03:30 05:30 2.00 0 2,640 COMPZ RPCOM PULD P PJSM. MU Thru Tbg Wash Over Retrieving Head Assembly and RIH on DP to 2,640 -ft, pump 4 bpm at 230 psi, wash dn to 2,658 -ft, 05:30 06:30 1.00 2,640 2,640 COMPZ RPCOM OTHR T Shut down for Phase 3 weather until cleared 06:30 08:30 2.00 2,640 2,072 COMPZ RPCOM CIRC P Pump 40 bbl sweep, change well over to 9.6 ppg brine. Engage IBP and release same. Let equalize 08:30 09:30 1.00 2,072 0 COMPZ RPCOM TRIP P POOH and lay down same 09:30 09:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM on slip and cut of drill line 09:45 12:30 2.75 0 0 COMPZ RPCOM SLPC P Slip and cut 84 -ft of 1 1/8" Drill line and service draw works 12:30 14:00 1.50 0 310 COMPZ RPCOM PULD P PU and MU BHA #21 (5 3/4" OS) and RIH to 310 -ft 14:00 16:30 2.50 310 7,121 COMPZ RPCOM TRIP P RIH w/ BHA #21 to 7,121 -ft. pump 5 bpm at 700 psi, 115k up/ 93k dn, 105k rot, 15 rpm, 3700 torque, rotate over Tbg and engage fish at 7,123 -ft, cont. CBU. 16:30 00:00 7.50 7,121 7,111 COMPZ RPCOM JAR P Bleed off jars at 200k 45k OSW. Straight pulled to 220k. Begin jarring at 200k and straight pull to 220k for 115 cycles moving fish up hole 10 -ft. 12/06/2011 Pull remainder of old 2 7/8" Tbg completion. Lay Down BHA #21. Attempt lay down fish. Wait on pressure relief tool. 00:00 07:00 7.00 7,111 7,106 COMPZ RPCOM JAR P Continue jarring at 200k and straight pull to 220k for 125 cycles and moved fish up 5 -ft. 07:00 08:00 1.00 7,106 7,106 COMPZ RPCOM OTHR P Perform Inspection on Derrick after Jarring. Page 16 of 28 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 7,106 7,056 COMPZ RPCOM JAR P Continue jarring at 210k Up Wt and straight pull to 225k for a total of 70 cycles. Able to move Packer Up Hole. Lay down working joint, Blow down top drive. Still seeing heavy drag up hole at 160k, but able to move fish up hole. 12:00 19:30 7.50 7,056 0 COMPZ RPCOM TRIP P Continue To TOOH standing back drill pipe while watching hole fill. 150K up 19:30 20:30 1.00 0 0 COMPZ RPCOM PULD P Lay Down 5 3/4" Overshot. Change over floors to single out 2 7/8" completion. 20:30 21:30 1.00 0 0 COMPZ RPCOM PULL P Start laying down w/2 7/8" tubing filled w/wet cement. Found trapped pressure in tubing, screwed in TIW Valve. 21:30 00:00 2.50 0 0 COMPZ RPCOM OWFF T Monitor well. Clean and clear floors. Complete 3 1/2" completion tally. Waiting on a hot tap to release trapped tubing pressure. State notified, 24 hr extension granted by State Rep. John Crisp at 22:40 for weekly BOPE test. 12/07/2011 Pull remainder of old 2 7/8" tbg completion. Preform weekly BOPE test. Clean Out to top of PBR. 00:00 04:30 4.50 0 297 COMPZ RPCOM OWFF T Waiting on a hot tap to release trapped tubing pressure. State notified, 24 hr extension granted by State Rep. John Crisp at 22:40 for weekly BOPE test. 04:30 09:00 4.50 297 0 COMPZ RPCOM STRP T Hot Tap equipment on location. PJSM. Discuss hazard for releasing tapped psi from 2 7/8" tbg. RU hot tap equipment, tap 2 7/8" tbg and release psi from each joint and UD same. Tubing had trapped psi and was plugged with cement. 09:00 10:00 1.00 0 0 COMPZ RPCOM CIRC P Change out floor equipment. MU swizzle stick and clean BOP stack at 8 bpm. 10:00 10:30 0.50 0 0 COMPZ RPCOM SEQP P Drain Stack. Install Test Plug and load test joint to rig floor. Rig up testing equipment. 10:30 16:30 6.00 0 0 COMPZ RPCOM BOPE P PJSM. Start Weekly BOP test. John Crisp with AOGCC waived witness to test. 16:30 17:30 1.00 0 0 COMPZ RPCOM PULD P Finish Weekly BOP test. R/D Testing Equipment. Load Tools for Next BHA to Rig Floor. 17:30 23:00 5.50 0 7,242 COMPZ RPCOM PULD P PJSM- MU 6 1/8" Mill Tooth Bit, dual boot baskets, bumper sub, oil jar, pump- out -sub, DC's and RIH on DP. Tag at 7,242 -ft, 160k up /93k dn. 23:00 00:00 1.00 7,242 7,429 COMPZ RPCOM MILL P Obtain parameters, 160k up /93k dn, 115k rot, 5200 ft/lb torque, pumping 5 bpm at 930 psi, rotate dn at 40 rpm to 7,429 -ft. Page 17 of 28 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/08/2011 24 hr Summary Continue Clean Out to top of PBR. Circulate Bottoms Up. Wash Over, Engage and Pull Packer Assembly. MU Mill Tooth Bit Assembly. 00:00 00:30 0.50 7,429 7,445 COMPZ RPCOM MILL P Continue rotate down at 40 rpm, 5 bpm at 930 psi and Tag at 7,445 -ft, top of PBR. 00:30 01:30 1.00 7,445 7,366 COMPZ RPCOM CIRC P Circulate Bottoms Up 7 bpm at 1710 psi ICP, reciprocate while pumping 1 1/2 times volume, FCP 1750 psi. PU 1 std, BDTD. 01:30 05:30 4.00 7,366 0 COMPZ RPCOM TRIP P POOH with Mill Tooth Bit Assembly standing back DP and DC's. Lay Down BHA #22. 05:30 10:30 5.00 0 7,382 COMPZ RPCOM PULD P PJSM- PU 6 1/8" OD Flush ID drag Tooth Shoe, Extension, 5 3/4" Overshot with 4 3/4" Spiral Grapple, top sub, bumper sub, oil jar, pump- out -sub, 9- DC's, accelerator and RIH on DP. 10:30 12:00 1.50 7,382 7,418 COMPZ RPCOM FISH P Set depth to stand 73 at 7382.5', up wt 158k, down wt 93k. Set parameters: Pump rate 3 bpm, 63 spm, 320 psi, continued in hole and set down at 7444.1' rotating at 6 rpm, 5 -5.6 k torque, continue in hole. Wash over pbr to 7458'. PUH and confirm overshot is latched onto PBR. Statrt jarring to shear packer. 12:00 12:45 0.75 7,418 7,300 COMPZ RPCOM TRIP P After 14 jar licks, seen good indication that packer is sheared. Seeing over pulls while TOOH, up wt =175k to 200k. Continue OOH to check for packer assembly, while watching hole fill. Hole not taking the correct amount of fluid. Stop and Monitor well. Seeing a trace of gas breaking out of the fluid. 12:45 14:30 1.75 7,300 7,300 COMPZ RPCOM CIRC T Stop and CBU at 1.5 times well bore volume. Had gas breaking of fluid while circulating at 8 bpm, 2000 psi, continue to circulate until returns where clean and free of gas. Monitor well. 14:30 20:00 5.50 7,300 322 COMPZ RPCOM TRIP P Blow down top drive, continue ooh and monitor well for proper hole fill. 20:00 23:00 3.00 322 0 COMPZ RPCOM PULD P Lay down BHA #23, recovered complete PKR / Tail pipe fish, all elements and slips accounted for. Load out fish and Baker equipment. Post jarring inspection. 23:00 00:00 1.00 0 295 COMPZ RPCOM PULD P PJSM- PU MU Mill Tooth Bit, bit sub, bumper sub, oil jar, pump- out -sub, DC's (BHA #24) 12/09/2011 Drill out cement to PBTD. Run Csg Scraper. Page 18 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 295 7,477 COMPZ RPCOM TRIP P RIH with Mill Tooth Bit, bit sub, bumper sub, oil jar, pump- out -sub, DC's on DP, start looking for TOC at 7,345 -ft, Tag at 7,477 -ft, PUH. 03:00 13:30 10.50 7,477 7,889 COMPZ RPCOM MILL P Obtain parameters, 157k up /95k dn, 117k rot, 6000 ft/lb torque, pumping 7 bpm, 148 spm at 1700 psi, rotate down at 80 rpm from 7,460 -ft, 4 -5k wob, drill down to 7,520 -ft, pick pump rate to 8 bpm at 2000 psi, continue Drilling down to 7,889.0 where PBTD was called. 13:30 15:30 2.00 7,889 7,850 COMPZ RPCOM CIRC P CBU with a 40 bbl High -Vis Sweep, continue until returns are clean at shaker. Pump rate 8 bpm, 2150 psi. Up Wt =157K, Dn Wt= 95K. Lay down working joint. Blow down Top drive. Monitor Well. 15:30 17:00 1.50 7,850 7,850 COMPZ RPCOM PULD P Crane On location to Load empty ESP spooler. Hold PJSM with Crane Operator and Rig Crew. 17:00 21:00 4.00 7,850 0 COMPZ RPCOM TRIP P PJSM. TOOH standing back DP. Lay down BHA #24. 21:00 00:00 3.00 0 5,527 COMPZ RPCOM PULD P PJSM- MU Mule Shoe, 7" Csg Scraper, bit sub, bumper sub, oil jar, DC's and RIH on DP 12/10/2011 Continue Running Csg Scraper to PBTD. Reverse Circulate well clean. Single out 80 joints 3 1/2 Drill Pipe. Preform Lock out/Tag out for Slip -n -Cut. Top Drive failed to Re -Start. Trouble Shoot and Repair Top Drive and Draw Works Problems. 00:00 03:00 3.00 5,527 7,889 COMPZ RPCOM REAM P Continue RIH with 7" Csg Scraper assembly to 7,365 -ft, set parameters 1 bpm at 60 psi, 30 rpm and reciprocate to 7,455 -ft several times, BDTD and continue RIH, Tag at 7,889 -ft, Up Wt =175k, Dn Wt= 90k. PU 2 -ft. 03:00 06:00 3.00 7,887 7,880 COMPZ RPCOM CIRC P Reverse Circ with a 40 bbl High -Vis Sweep, Pump rate 6 bpm, 1430 psi. Observe frac sand, cement and formation solids in samples over shaker, continue until returns are clean at shaker. Lay down working joint. Blow down Top drive. 06:00 08:30 2.50 7,880 7,880 COMPZ RPCOM OWFF P Monitor Well. Seeing flow at surface from Drill Pipe and no gain at trip tank. Shut in drill pipe and obtain SIDPP. Had 20 psi on Drill Pipe. Check Weight on Brine. Order out another load of Brine. Brine deliver was 9.5 ppg, add salt and weight to 9.6 ppg heavy. 08:30 10:00 1.50 7,880 7,880 COMPZ RPCOM CIRC P Circulate 9.6 ppg heavy (brine) around at 5 bpm, 835 psi. Rig down pumping equipment, open up TIW valve and monitor for gains or loses to trip tank and surface. Page 19 of 28 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:15 0.25 7,880 7,880 COMPZ RPCOM SFTY P PJSM. Discuss hazard for TOOH and Laying down drill pipe. 10:15 13:30 3.25 7,880 5,456 COMPZ RPCOM TRIP P TOOH, single out 78 joints. Stop At 5,456 -ft and Slip -N -Cut drilling line. 13:30 14:30 1.00 5,456 5,456 COMPZ RPCOM SLPC T Shut down top drive, lock out / tag out equipment to slip and cut drilling line. Was unable to re -start top drive. Trouble Shoot Top Drive Problem. 14:30 22:30 8.00 5,456 5,456 COMPZ RPCOM RGRP T Continue to Trouble Shoot Top Drive Problem. 22:30 00:00 1.50 5,456 5,456 COMPZ RPCOM RGRP T Top Drive problem fixed, Draw Works not responding, Trouble Shoot and Repair Draw Works Problem. 12/11/2011 Continue Slip -n -Cut Drilling Line. TOOH with BHA #25. NU Shooting Flange. RU E -line. Perforate 7,592 to 7,607 -ft (A2) and 7,531 to 7,561 -ft (A3) MU Baker FB-1 Production Packer /SBE/Tail Pipe Assembly. 00:00 00:15 0.25 5,456 5,456 COMPZ RPCOM SFTY P PJSM- Hazards preforming Slip -n -Cut activities. 00:15 01:45 1.50 5,456 5,456 COMPZ RPCOM SLPC P Continue on with Slip -n -Cut of Drilling Line. 01:45 05:00 3.25 5,456 306 COMPZ RPCOM TRIP P Continue OOH laying down 2 joints and standing back 52 stands of Drill Pipe for next job. monitor well. 05:00 06:30 1.50 306 0 COMPZ RPCOM PULD P Lay down BHA #25 and kick out Baker equipment. 06:30 06:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discussed hazards of removeing riser and rigging up shooting flange. 06:45 08:45 2.00 0 0 COMPZ RPCOM NUND P Nipple down riser and nipple up shooting flange. 08:45 09:00 0.25 0 0 COMPZ RPCOM SFTY P Hold PJSM with HES E -Line Crew & Rig Crew. Discuss hazard for rigging up equipment and perf guns. 09:00 12:30 3.50 0 0 COMPZ RPCOM PULD P R/U E -Line Lubricator,Pump -N -Sub, BOPE, with grease head. Load and R/U Perf Guns and Firing Head. 12:30 14:30 2.00 0 0 COMPZ RPCOM PERF P On Well with pert guns and firing head. PT lubricator against closed blinds rams to 1000 psi. Open blinds and RIH with perf guns. Tie in with GR/CCL logging tools to an old CBL, correlated and fired perf guns at 7,592 - 7,607 ELMD. 14:30 15:45 1.25 0 0 COMPZ RPCOM PERF P POOH with E -Line. PJSM, Lay down first Gun and confirmed that shots had fired. 15:45 16:30 0.75 0 0 COMPZ RPCOM PULD P Load and MU second perf gun. 16:30 17:30 1.00 0 0 COMPZ RPCOM ELOG P On Well with second set of pert guns. PT lubricator, RIH and Tie in with GR /CCL. Correlated and fired perf guns at 7,546 - 7,561 -ft ELMD. 17:30 18:45 1.25 0 0 COMPZ RPCOM PERF P POOH with E -Line. PJSM, Lay down second Gun and confirmed that shots had fired. 18:45 19:45 1.00 0 0 COMPZ RPCOM PULD P Load and MU third perf gun. Page 20 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:45 1.00 0 0 COMPZ RPCOM ELOG P On Well with third set of perf guns. PT lubricator, RIH and Tie in with GR/CCL. Correlated and fired perf guns at 7,531 - 7,546 -ft ELMD. 20:45 22:00 1.25 0 0 COMPZ RPCOM PERF P POOH with E -Line. PJSM, Lay down third Gun and confirmed that shots had fired. 22:00 23:15 1.25 0 0 COMPZ RPCOM PULD P Rig Down E -line lubricator equipment. E -fine Re -head. MU Baker F1 Premenant Packer, SBE, Tail Pipe Assembly. 23:15 23:30 0.25 0 0 COMPZ RPCOM SFTY P Hold PJSM with HES E -Line Crew & Rig Crew. Discuss hazard for rigging up equipment and DPU on Packer Assembly. 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD P Rig Up E -line Packoff equipment, preforrm checks on 3.625" DPU. 12/12/2011 Set Baker FB -1 Production Packer /SBE/Tail Pipe Assembly. RD E -line. ND Shooting Flange. NU Riser. Run 3 1/2 Gas Lift Completion. Sting into SBE. Space out 7 -ft off bottom. MU Tubing Hanger and Pups. Load well with corrosion inhibited 9.6 ppg brine. Land Tubing Hanger and RILDS. 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD P Rig Up E -line Packoff equipment, preforrm checks on 3.625" DPU. Set Packer Assembly in riser and connect Halliburton 3.625" DPH w/ GR and CCL. 01:00 02:45 1.75 0 0 COMPZ RPCOM ELOG P RIH with 7" Baker FB -1 Production Packer, SBE, Tail Pipe Assembly on DPU /GR/CCL, Tie in with GR /CCL logging tools, check for line creep. 02:45 03:00 0.25 0 0 COMPZ RPCOM PACK P Set Top of Packer/Tailpipe Assembly at 7,412.8 -ft ELMD, let DPU stroke fully. 03:00 04:00 1.00 0 0 COMPZ RPCOM TRIP P POOH w/ E -line setting tool and lay down same. 04:00 07:30 3.50 0 0 COMPZ RPCOM NUND P PJSM- RDMO and kick out E -line equipment. ND Shooting Flange. Bring in SSSV Control line and spooler. Clean and clear floors. 07:30 07:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discussed hazards with running completion, review procedures and running order for 3 1/2 gas lift completion. 07:45 13:30 5.75 0 5,638 COMPZ RPCOM RCST P Run New 3 1/2" Completion. 13:30 14:15 0.75 5,638 5,638 COMPZ RPCOM PULD P Stop and MU SCSSSV, TRMAXX- CMT -SR -5 w/ 2.813" X Profile. RU Control Line. Apply 5000 psi and hold while TIH. Page 21 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 18:45 4.50 5,638 7,413 COMPZ RPCOM RCST P Continue in hole with 3 1/2" Completion to Joint # 234 and correct depth to 7,406 -ft at 1700 hrs. 108k up wt/ 73k dn wt. PU Joint # 235 and engage top of packer assy and seal bore extension with seal assembly locator. Set down at 7,413 -ft ( top of packer assembly). Made several attempt to engage into seal assembly with charge pump, no luck. Continue to try and engage with seal assembly. 18:45 20:00 1.25 7,434 7,434 COMPZ RPCOM RCST P Fully located and no -go out at 7,434 -ft, pressure up tubing to 500 psi with 5k dn wt, monitor casing, no returns. Pull up to string weight plus 7 -ft, pipe marked, POOH with 3 joints, calculate and verify Space Out with Baker Rep. MU Space Out Pups to completion and band. 20:00 20:30 0.50 7,434 7,393 COMPZ RPCOM HOSO P MU head pin and pressure test equipment to Landing Joint MU Landing Joint to 7" x 3 1/2" McEvoy Tubing Hanger, pup joint and first full joint to completion, band while RIH to 7,393- ft.bleed down control line and feed thru tubing hanger securing with swage lock fittings, open SSSV. 20:30 21:45 1.25 7,393 7,393 COMPZ RPCOM CIRC P Circulate well 184 bbls 9.6 ppg inhibited brine chased with 68 bbls 9.6 brine, 4 bpm at 250 psi. monitor well. 21:45 22:00 0.25 7,393 7,393 COMPZ RPCOM SFTY P PJSM- Discussed hazards with / landing tubing hanger and pressure testing, review procedures. 22:00 23:30 1.50 7,393 7,413 COMPZ RPCOM THGR P Locate top of packer assembly at 7,413 -ft, Made several attempt to engage into seal assembly with charge pump, no luck. Continue to try and engage with seal assembly. 23:30 00:00 0.50 7,413 7,427 COMPZ RPCOM THGR P Land tubing hanger, RILDS, RU pressure test equipment in cellar. 63 ea. SS bands used. 12/13/2011 Pressure Test Tubing and Casing. Shear SOV in GLM #5. Close SSSV and test from below. IA will not pass a PT. RU Sline. Pull SOV and set Dummy Valve. Continue with IA "leak hunt" testing, 00:00 01:00 1.00 7,427 7,427 COMPZ RPCOM RURD P RU pressure test equipment in cellar. 01:00 02:30 1.50 7,427 7,427 COMPZ RPCOM PRTS P Pressure Test Tubing 2500 psi for 15 min, IA= 0 psi, no returns, bleed tubing to 2000 psi, Pressure IA to 3500 psi for 30 minute test, Tbg= 2550 psi, 15 minutes IA= 3450 psi, Tbg= 2550 psi, 30 minutes IA= 3425 psi, Tbg= 2550 psi, tests charted. Bleed Tbg and IA to 0 psi. Page 22 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:30 1.00 7,427 7,427 COMPZ RPCOM PRTS P Ramp up IA to 2300 psi before SOV sheared. Monitor well, Close SSSV, pressure IA to 1000 psi to test SSSV from below, bleeds off, small return from Tbg. Trouble Shoot SSSV, Tbg Hanger leaking, bleed IA and Tbg to 0 psi, tighten down LDS. SSSV test not holding, leak slowed down. 03:30 08:30 5.00 7,427 7,427 COMPZ RPCOM THGR P Drain stack of fluid to inspect top of hanger, Pull tubing hanger and inspect and clean. Re -set and re -test pumping into IA with SSSV open. Pressure to 500 psi, linear leak, pressure 2000 psi, slow linear leakoff. No fluid coming into the stack. Shut in tubing and IA, pressures up to 80 psi. Bleed back and Tubing and IA slowly pressures back up to 80 psi. 08:30 11:30 3.00 7,427 7,427 COMPZ RPCOM SLKL T Call out HES SL to set TTP in X nipple. 11:30 14:30 3.00 7,427 7,427 COMPZ RPCOM SLKL T MI HES SL, PJSM, Continue RU. PT Lubricator to 2500psi, ok. 14:30 20:30 6.00 7,427 7,427 COMPZ RPCOM SLKL T RIH with 125 wire, 11' x 1.875" Stem, KJ, LSS. Unable to locate lower X profile. SL measured tag depth referenced to original RKB -7438'. POOH and note increased tension 1000 #. X lock filled with muck and what appeared to be carbolite. RD TS and Rig up to pull SOV in GLM #5. Pull SOV from Station #5. RIH with a Dummy Valve and set in same Station. Pull Tool String back inside Lubricator. S -Line stand -by for pressure testing the Completion. Page 23 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:30 2.00 7,427 7,427 COMPZ RPCOM PRTS T Resume pressure testing the Completion. Pressure test the IA at 1,500 psi. Observe a 750 psi loss in 10 minutes. Bleed IA to "0" psi. Pressure up on the tubing side to 1,500 pst x 5 minutes. Good test. Re- pressure up on the IA to 1,500 psi. Tubing pressure slightly increased to 1,700 psi as expected. However, the IA pressure continues to bled off at the same rate as before. Possible conclusions are that the Packer is leaking, a possible Casing problem, or the Tubing Hanger is leaking. Fill the BOP Stack. Pressure up on the IA at 1,500 psi and observe for fluid movement. Bring pressure up to 3,000 psi. No fluid movement observed by- passing the Tubing Hanger. Problem remain "down -hole. Discuss findings and a plan forward with Anchorage Engineer. 22:30 00:00 1.50 7,427 7,427 COMPZ RPCOM SLKL T Resume S -Line operations. RIH. Pull Dummy Valve from Station #5. Pull out with tool String and dummy Valve. 12/14/2011 RD S -Line. Bring fluid in Pits up to weight. Circulate and condition Well. Perform Weekly BOPE Test. 00:00 01:00 1.00 7,427 7,427 COMPZ RPCOM SLKL T Rig down S -Line equipment and release Unit. 01:00 03:30 2.50 7,427 7,427 COMPZ RPCOM CIRC T Take on a load of 8.6 lb/gal Brine in Pits. Order out 11.8 lb/gal Brine to mix with the fluid in the Pits to bring the weight up to 9.6 lb/gal. Move Drill Pipe that is standing in the Derrick to one side so as to make room to stand back the completion tubing. Load an additional 80 Joints of Drill Pipe in the Pipe Shed. 03:30 04:30 1.00 7,427 7,427 COMPZ RPCOM CIRC T Build fluid in Pits to 9.6 lb/gal. 04:30 07:00 2.50 7,427 7,427 COMPZ RPCOM CIRC T PJSM, Circulate corrosion inhibited brine from IA to kill tank at 3 BPM holding 150 psi on the choke. ICP 330 psi, FCP 370 psi. 07:00 10:00 3.00 7,427 7,427 COMPZ RPCOM CIRC T Blow down hardline and roll the hole to 9.6+ ppg through open pock GLM #5 through gas buster at 2 BPM. ICP 280 psi, FCP 260 PSI. Page 24 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:45 2.75 7,427 7,427 COMPZ RPCOM OWFF T Shut well in and monitor. Pressure up to 80 psi after 30 minute. Confer with town and weight up to 10.3 ppg. While weighing up, testing choke manifold and squeeze manifold valves and charting. Close choke valves 2, 5, and 6. Test first valves in line on the sqeeze manifold with hose open from IA. No flow from hose and charted test to 3500 psi. Open choke valves 2, 5, 6 and shut 3, 7, and 8 and repeat charted test 3500 psi. Both tests near flat line and appear to be compressing some air in system. Mud weighted up to 10.3 and prepare for circ out. 12:45 15:15 2.50 7,427 7,427 COMPZ RPCOM CIRC T Start Circ 10.3 ppg brine holding 50 psi on choke. 15:15 17:00 1.75 7,427 7,427 COMPZ RPCOM OWFF T Monitor well for no flow. 17:00 18:00 1.00 7,427 7,427 COMPZ RPCOM OPNW T Discuss Plan forward and schedulled Weekly BOPE Test with Anchorage Engineer. Begin to weight up Pit to 10.4 lb/gal Brine. 18:00 20:30 2.50 7,427 7,368 COMPZ RPCOM THGR T PJSM. Observe no -flow from Well. BOLDS. Pull Tubing Hanger to Floor. Disconnect SSSV control Line. Lay down Tubing Hanger. Lay down 1 Joint of 3 1/2" Tubing. Lay down 3 ea 3 1/2" Pup Joints. Pick -up and make -up Tubing Hanger. Cap and secure SSSV Control Line. Install BPV and Blanking Plug in the tubing Hanger. Land Tubing Hanger. RILDS. 20:30 21:30 1.00 7,368 7,368 COMPZ WELCTL BOPE T PJSM. Rig up test equipment. 21:30 00:00 2.50 7,368 7,368 COMPZ WELCTL BOPE T PJSM. Begin weekly BOPE Test per ConocoPhilli P s /AOGCC P requirements at 250/3,500 psi. 12/15/2011 Complete Weekly BOPE Test. Condition Well with 10.4 lb/gal Brine. Trip out With 3 1/2" GL Completion. Trip in with Test Packer to diagnose Casing /Packer leak. 00:00 03:30 3.50 7,368 7,368 COMPZ WELCTL BOPE T Continue testing the BOPE per ConocoPhillips / AOGCC requirements at 250/3,500 psi. Perform Koomey drawdown test. All pressure tests recorded on chart. The States right to witness the test was waived by AOGCC field Inspector M. Herrera. Rig down test equipment. 03:30 05:30 2.00 7,368 7,368 COMPZ RPCOM CIRC T PJSM. Suck down BOP Stack. Pull BPV and Dart. Make -up Landing Joint. RU Circ Hose, BOLDS, Pull Hanger up 3' at 98k #. 05:30 07:00 1.50 7,368 7,368 COMPZ RPCOM CIRC T Circ 10.4 ppg brine down tubing at 3 bpm. ICP 170 psi, FCP 170 psi, 259 bbls. Page 25 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 07:30 0.50 7,368 7,368 COMPZ RPCOM OWFF T Monitor Well, Takes 0.4 bbls in 10 minutes. 07:30 09:30 2.00 7,368 1,820 COMPZ RPCOM TRIP T PJSM, POOH with rt-1/2" Completion. 09:30 13:00 3.50 1,820 0 COMPZ RPCOM TRIP T OOH with SSSV, Continue POOH. Well taking approx 1.0 barrel fluid per hour over displacement. 13:00 13:30 0.50 0 0 COMPZ RPCOM PULD T PU BHA Tools, RU Rig floor to run DP 13:30 14:00 0.50 0 0 COMPZ RPCOM PULD T Set Wear Ring 14:00 14:45 0.75 0 0 COMPZ RPCOM PULD T PJSM, PU and MU BHA #26 - Model "I" Retrievamatic Packer with two joints of 2- 1/16" CS Hydrill stinger. 14:45 16:15 1.50 0 2,350 COMPZ RPCOM TRIP T RIH with BHA #26 16:15 17:00 0.75 2,350 3,070 COMPZ RPCOM TRIP T Kick while Drilling Drill, Continue RIH to 3070' to test. 17:00 20:00 3.00 3,070 3,070 COMPZ RPCOM PRTS T Set Test Packer at 3,070'. Rig up test equipment. Pressure up on the Drill Pipe to 1,500 psi. Test the Casing /Packer below the Test Packer. Lost 50 psi in 15 minutes. Bleed pressure to "0" psi. Pressure up on the 3 1/2" Drill Pipe x the 7" Annulus to 3,000 psi and test the Casing from the top of the Test Packer back to surface. Lost 50 psi in 15 minutes. Bleed pressure down to "0" psi. Both tests recorded on chart. Rig down test equipment. 20:00 00:00 4.00 3,070 7,426 COMPZ RPCOM TRIP T Release the Test Packer. Continue to trip in with 3 1/2" Drill Pipe from the Derrick. Continue to trip in with single 3 1/2" Drill Pipe from the Pipe Shed. Depth at Midnight = 7,426 -ft. Up Weight = 129K. down Weight = 94K 12/16/2011 Finish TIH. Set Test Pkr. Test Csg from 7,353 -ft back to Surface at 3,000 psi. Good. Release Test Pkr. Clean out inside PBR and Rev Circ Hi -Vis Sweep to surface. TIH with 3 1/2" DP. PU and RIH with 3 1/2" GL Stacker - Packer Completion. 00:00 01:30 1.50 7,426 7,353 COMPZ RPCOM TRIP T Enter the top of the Baker FB -1 Packer at 7,406 -fr dpmd, with no problems. Pick back up and set the Test Packer with the center element at 7,353 -ft. 01:30 02:30 1.00 7,353 7,353 COMPZ RPCOM PRTS T PJSM. Rig up test equipment. Pressure up down the Drill Pipe to 1,500 psi to test the FB -1 Packer. Pressure slowely declined with a loss of 200 psi in 15 minutes. Bleed pressure down to "0" psi. Pressure up on the 3 1/2" Drill Pipe x 7" Annulus to 3,000 psi x 15 minutes to test the Casing back to surface. Good test. Recorded both test on Chart. Bleed pressure to "0" psi. Page 26 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:30 2.00 7,353 7,400 COMPZ RPCOM CIRC T Release the Test Packer. Ease back down hole. Bring Rig Pump on Line at 1.5 bpm /130 psi Washed insid of the PBR to the Baker Shear -Out Sub at 7,450 -ft dpmd. Saw very little fill, if any. Wash back out of the PBR. Park Mule Shoe at 7,400 -ft. Reverse Circulate at 3.0 bpm. Start a 20 bbl Hi -Vis Sweep and Reverse Circulate back to surface at 4.0 bpm /530 psi. Recovered some Sand, but not a great amount or any heavy slugs. End Reverse Circulating. 04:30 12:00 7.50 7,450 0 COMPZ RPCOM TRIP T Ease back down and dry tag the Shear Out Sub at 7,450 -ft. Start to single down the extra 3 1/2" Drill Pipe to the Pipe shed. Up wt 109k# and down wt 95k #. Stack back 52 stands of 3 -1/2" Drill Pipe. 12:00 12:30 0.50 0 0 COMPZ RPCOM PULD T On surface, LD BHA #26, Remove Wear Ring. 12:30 14:00 1.50 0 0 COMPZ RPCOM PULD T RU Floor to run 3 -1/2" Completion. 14:00 23:30 9.50 0 7,413 COMPZ RPCOM RCST T PJSM, Discuss running order, RIH with 3 -1/2" GL Completion as designed. Make -up SSSV. Install Control Line and pressure test at 6,500 psi x 15 minutes. Good. Continue to run in with the 3 1/2" Tubing and install a SS Band on each Joint. 23:30 00:00 0.50 7,413 7,412 COMPZ RPCOM PACK T Up Weight = 100K. Down Weight = 75K. Make -up Landing Joint. Bring Charge Pump on line at 70 psi. Enter the Baker F -1 Packer at at 7,413 -ft. Pressure increased to 90 psi when Seal Assembly (with no Seal Rings) started to enter the Seal Bore Extension. Pressure gradually increased to 140 psi. Bleed pressure. Continue in to "No -Go ". Pick -up to String Weight + 1 -ft and mark Tubing. 12/17/2011 Set FHL Pkr. Shear PBR. Space -out. MU Tbg Hanger. Tie in SSSV Control Line. Circ Corrosion Inhibited Brine. Land Completion. RILDS. PT Tbg. PT Csg. Shear open the SOV. PT SSSV. Set BPV /Dart. ND BOP Stack. NU Tree. Freeze Protect. Test Tree. Set BPV. Release Rig. RDMO. 00:00 01:00 1.00 7,412 7,412 COMPZ RPCOM CIRC T PJSM. Pump 15 bbls Of Corrosion Inhibited 10.4 lb/gal Brine dow the Tubing. Chase with a Tubing volume of 10.4 lb/gal Brine and spot the CIB on the back -side. Page 27 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 03:00 2.00 7,311 7,300 COMPZ RPCOM PACK T Enter the Sea Bore Extension and No -Go. Pick back up to the 1 -ft mark. Drop the FHL Packer Setting Ball /Rod. Weight 15 minutes. Pressure up on the Tubing to 2,500 psi and set the FHL Packer. Hold pressure x 5 minutes. Pull up to 110 K (10K overstring weight) and shear the Seal Assembly from the Packer. Pick -up 7 -ft and mark the Tubing. Lay down 15.30 -ft of Jt #233, Jt #232, and Jt #231. Pick -up a total of 14.60 -ft of 3 1/2" Pup Jts. Pick Jt #231 back up. Make -up Tubing Hanger Assembly. Tie in SSSV Control Line. Pump open SSSV. 03:00 04:00 1.00 7,300 7,300 COMPZ RPCOM CIRC T Circulate Corrosion Inhibited 10.4 lb/gal Brine at 4.0 bpm /280 psi. Total volume circulated = 250 bbls. 04:00 06:30 2.50 7,300 7,306 COMPZ RPCOM THGR T Land Tubing Hanger, Up 95K, dwn 75k. RILDS, RU Test Eq, PT Tubing 2500 psi for 15 min, OK. PT 7" casing and packer 3500 psi for 30 min, OK. Shear out SOV at 2580 psi and test IA and SSSV at 1000 psi for 10 min, OK. 06:30 07:00 0.50 0 0 COMPZ RPCOM NUND P Set BPV. 07:00 12:00 5.00 0 0 COMPZ RPCOM NUND P PJSM, ND BOP and Inspect and Clean Out. ( * *AOGCC State Rep Chuck Scheve waived witness of initial BOP test on 2T -220 at 10:22 AM on 12/17/2011**) 12:00 16:15 4.25 0 0 COMPZ RPCOM NUND P NU 3 -1/8 ", 5MTree, Pad operator Mike Grahm verified allignment. PT Tree and Packoffs to 5000 psi. OK. Pull BPV and pressure up SSSV to 5000psi 16:15 20:00 3.75 0 0 COMPZ RPCOM FRZP P RU LRS and pump 145 BBLS Diesel down IA ret up tubing. U -tube FP into tubing. LRS RDMO. 20:00 22:00 2.00 0 0 COMPZ RPCOM RURD P Set BPV. Dress out Tree. Secure Cellar. Disconnect Lines to Kill Tank. Cleaning Pits. 22:00 23:30 1.50 0 0 COMPZ RPCOM RURD T Wait on Vac Truck to return to Location to finish Sucking out Rig Pits (100 bbls of 10.4 lb/gal Brine left in Pits. Unable to move Rig with that much wweight in Pits. Unable to get a second Vac Truck) 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Vac Truck arrive on Location. Empty Rig Pits. Release Rig at 24:00 hrs Page 28 of 28 2T -03 Post Rig Well Work DATE SUMMARY 12/26/11 PULLED 1.5" SOV FROM 7221' AND CIRCULATED 255 BBL'S DOWN AR UP IA. SET 1.5" DV @ 7221' RKB; MIT IA TO 3500 psi ( Passed ) PULLED BALL AND ROD FROM PLUG @ 7358' RKB. SHEARED BAKER SOS @ 7458' RKB. IN PROGRESS. 12/27/11 PULLED DV'S AND INSTALLED GLV'S @ 2734', 4662', 5854', 6707', AND OV © 7221' RKB ( DRAW DOWN TEST GOOD) . IN PROGRESS. 12/28/11 PULLED 2.81" RHC PLUG BODY FROM 7458' RKB.TAGGED 7801' SLM WITH 2.5" BAILER EST 250' RATHOLE. MEASURED BHP @ 7530' RKB ( 3047 psi max) . SET TR -MAXX ISO SLEEVE @ 1713' RKB. COMPLETE • 2'3 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 12, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 scANNED APR 0 $ 2013 RE: Packer Setting Record / Perforating Record: 2T -03 Run Date: 12/11/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -03 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20073 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: `-0/11 Signed: 4/14. 1 • tic -142 04 V2, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 30, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log / RCT -String Shot / Shotrod: 2T -03 Run Date: 11/25/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -03 Data in LAS format, Digital Log Image files 1 CD Rom 50- 103 - 20073 -00 SCANNED APR 0 8 Z°13 Cement Bond Log 1 Color Log 50 -103- 20073 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Signed: Y Date: � � (� �� � ) � �j► Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, December 07, 2011 11:26 AM To: 'Packer, J.Bret Cc: Gober, Howard; DOA AOGCC Prudhoe Bay Subject: RE: 2T -03 (PTD#186-142) ( ) Brett, The right call was made to delay the BOP test temporarily until you could get of the well safely. Good luck with the rest of the well workover. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Packer, J.Brett [ mailto: J. Brett.Packer @conocophillips.com] Sent: Wednesday, December 07, 2011 11:22 AM To: Schwartz, Guy L (DOA) Cc: Gober, Howard Subject: 2T -03 (PTD #186 -142) 1 Guy, This email is just to document our conversation yesterday regarding the 24 -hr extension on our weekly BOP test granted by John Crisp and to provide you with a status update. Background Info: This is a subsidence well that was planned to be worked over. Prior to the RWO, this well had a known surface casing leak, there was TxIA communication, and we were unable to drift the tubing to set a plug, therefore, with only one un- testable barrier left, the safest plan of action was to bullhead cement down the tubing and plug the perforations until the workover could be done. Following the cement job (and subsequent cement squeezes), the well passed a CMIT TxIA indicating we had competent 7" casing. Deepest tag depth (Top of cement): 7,221' MD Tubing was cut at: 7,100' MD Packer at: 7,435' MD Extenuating Circumstances: 24 -hr notice was given on 12/5/11 for our weekly BOP test due on 12/6/11. The morning of 12/6/11, we were on bottom, latched onto our tubing stub at 7,100' MD and trying to jar the seal assembly from the PBR. We got it moving up hole, although with significant drag, so we assumed that we were pulling the packer, tailpipe, and everything, which wouldn't have been a bad thing because we were planning on going back and pulling the packer anyways. They continued to slowly pull out of the hole, trying not to swab the well. This took longer than expected, and when they got down to the actual 2 -7/8" tubing, we found some contaminated cement in the tubing and discovered trapped pressure while breaking the connections. We installed the TIW valve and decided that the safest thing to do would be to hot -tap the remaining joints of tubing to relieve any additional possible trapped pressure. As a result, we were not going to be able to get out of the hole and start a BOP test before the midnight deadline. The rig supervisor spoke with John Crisp around -10:00 pm on 12/6/11 informing him of the situation, and Mr. Crisp granted them a 24 -hour extension. Current Status: 12/7/2011 Page 2 of 2 • We hot - tapped the remaining joints and pulled the rest of the pipe out of the hole this morning, and found out we were mistaken because we didn't have the packer and tailpipe assembly as originally thought, only the seal assembly. This morning, we are currently performing our weekly BOP test, and the next step will be to fish the PBR /packer /tailpipe assembly. If you have any additional questions, don't hesitate to call. 9. Brett Wacker Bing aZ We1E WWorlgverEngineer Work" (907) 265 -6845 Cell# (907) 230 -8377 12/7/2011 • Page 1 of 3 Regg, James B (DOA) From: Regg, James B (DOA) 1420 Z Sent: Friday, December 02, 2011 2:43 PM 14. / Z'Z'' It p.m �j l 4 ZG To: McMains, Stephen E (DOA) l Cc: Brooks, Phoebe L (DOA) Subject: FW: KRU 2T -03 PTD 1861420, Sundry approval 311 -305 Attachments: KRU 2T -03 history page.pdf re: Well History for KRU 2T -03; PTD 1861420; see attached Well History reports what Sundry 311 -305 shows - 3500psi (rams /valves) and 2500psi (Annular) BOP test pressures; 3500psi test pressure only applies after casing is cut and new tubing head is installed; prior to that work being completed, BOPE test should be 3000psi; see email string below A copy of this email will be placed in the well file to note amendment to Sundry Approval 311 -305; please adjust Well History. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Regg, James B (DOA) Sent: Friday, December 02, 2011 10:16 AM To: 'Packer, J.Brett' Cc: Nordic 3 Company Man; Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: KRU 2T -03 PTD 1861420, Sundry approval 311 -305 Brett - Thank you for the explanation. For this sundry, we will make the notation in the well file correcting the approved sundry and our Inspection database regarding the proper test pressure being 3000psi. It is the operator's responsibility to make sure the permit reads correctly as per the conditiions of approval, and if they disagree, seek clarification from the Commission (preferably before operations commence). Compliance should never be assumed based on previous activities, and the Commission may not catch subtle intent in work procedures. In reviewing the BOPE test report, I check the info against the approved permit and search for any subsequent correspondence that may have corrected the approved permit. I can't speak for Guy, but from my perspective this could simply be avoided with a clear statement in your application regarding test pressures at each stage of operation (e.g, "BOPE test pressures for Steps # through ## are xxx psi "). This will head off these types of time - consuming inquiries (and future questions that might arise later as others review our well files). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Packer, J.Brett [mailto:J.Brett.Packer @conocophillips.com] Sent: Friday, December 02, 2011 8:41 AM To: Regg, James B (DOA) 12/2/2011 P- oo�2of3 -� Cc: Nordic 3 Company Man Subject: RE: KRU 2T-03 PTD 1861420, Sundry approval 311-305 Jim, Attached is a copy of the Sundry Application that was submitted. This workover procedure is the same procedure we have been using on alt of these subsidence vveUs� At this point duhnQthe vvorkover.vve have two bonierain the weU: an inflatable bridge plug set in the 7" casing at 2667' MD and tested to 3000 psi, and Kill Weight Fluid to surface. As is the case with all these subsidence workovers, once we remove the tubing head to relieve the compressive forces from the 7" casing, we nipple the BOP stack up the the 11''3.UOO psi casing head so that we can cut & pull the 7"casing. Many of these subsidence weUs, such as this one, have a shallow surface casing |eak, so with adequate barriers be|ow, the BOP stack is essentially only acting as a diverter if needs be (Step #9 of the Sundry Procedure); and we have basically been considering it a diverter until the BOP stack is nippled back up to the new tubing head and can be tested as perAOGCC guidelines (Steps#19& #20 ofthe Sundry Procedure). This issue has been discussed with Guy Schwartz here in town on past subsidence welts. The BOP test in question is the weekly BOP test done on 11/29/11. We dont include the weekly BOP tests in our procedures because we can't predict exactly where we'll be in the workover operations when the weekly BOP test is due. A|so, there is no discrepancy in the weekly BOP test rules for workovers regarding whether the BOP stack is functioning only as a diverter or an actual blowout preventer, it only states that a BOP test must be done every 7 days on workover operations. |t� ' us1aohappenawevvereinthemidd|eofthie7^oomingworkandnipp|eduptothecasingheadvvhenwe were due for our our weekly test, Due to the maximum 3,000 psi rating of the casing head, we cannot comply with the 3500 psi BOP test pressure stated in the approved Sundry without significant risk and possible injury to our personnel. | apologize for not informing you of this detail ahead of time, 1. BmmBu4r OriU6muZWeirs WorkpverEngi*eer .~ (907)265-6845 Cerr# (907)230-077 _ _ . . _ _ . _ From: Nordic 3 Company Man Sent: Thursday, December 01, 2011 10:34 AM To: Packer, J.Brett Cc: Nordic 3 Toolpusher; Nordic 3 Tour Pusher Subject: FW: KRU 2T-03 PTD 1861420, Sundry approval 311'305 Brett, Here you go Randy Dolcater - Rory Ober Cell 907-943-1096 Office 659-7446 - -'- - From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, December 01, 2011 9:53 AM To: Nordic 3 Company Man Subject: [EXTERNALlRE: KRU 27-03 PTD 1861420, Sundry approval 311-305 Send me a copy of approval Jim Regg AOGCC l2/7/20]} - • • Page 3 of 3 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Nordic 3 Company Man [mailto:n1433 @conocophillips.com] Sent: Wednesday, November 30, 2011 7:07 PM To: Regg, James B (DOA) ( ) Cc: Packer, J.Brett; Nordic 3 Toolpusher; Nordic 3 Tour Pusher Subject: KRU 2T -03 PTD 1861420, Sundry approval 311 -305 Jim, We were nippled up to an 11" 3,000 PSI CSG head after 7" was cut prior to removal of the 7 "CSG. This was submitted by Brett Packer for approval and approved. Randy Dolcater - Rory Ober Cell 907 - 943 -1096 Office 659 -7446 From: Regg, James B (DOA) [mailto:jim.regg©alaska.gov] Sent: Wednesday, November 30, 2011 4:55 PM To: Nordic 3 Toolpusher Cc: Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: Sent from NSK0277 KRU 2T -03 PTD 1861420 Thank you; Sundry approval 311 -305 requires rams and valves to be tested to 3500psi. Do you have some other approval from the Commission allowing a lower test pressure? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Nordic 3 Toolpusher [ mailto :n1434 @conocophillips.com] Sent: Wednesday, November 30, 2011 4:47 PM To: Regg, James B (DOA) Subject: FW: Sent from NSK0277 12/2/2011 • V [Z1! IN 0 1 Master Well Data Company 1134200 ICONOCOPHILLIPS ALASKA INC Well Name IKCPARLK RIV UNIT 2T -03 Permit to Drill 11861420 API Well No. 50 -103- 20073 -00 -00 v Location )Sec: 1, T1IN, R8E, PM L Field IKUPARt'K RIVER Curr Stat Fa' Date Effective 'Sundry Appri Form Submitted: ' Code I Type Work: 1 Comments 10/4/2011 311 -305 Application for Sundry ICSGA Intent: Repair / Replace Casing 3500 psi BOP Test & 2500 psi Annular test (min). 10/4/2011 311 -305 Application for Sundry IPTBG Intent: Repair / Replace Tubing 3500 psi BOP Test & 2500 psi Annular test (min). 10/4/2011 311 -305 Application for Sundry IREPW Intent: Repair Well 3500 psi BOP Test & 2500 psi Annular test (min). 9/10/2011 Report of Sundry Well 0 RSWIN Report: Suspended Well Inspection 5 8/7/2011 311 -024 Report of Sundry Well 0 RSUSP Report: Suspend 2/3/2011 311 -024 Application for Sundry IPLUG Intent: Plug Perforations 10/17/1986 DTCMP Dt Well Completed • 10/17/1986 Other Report (see comm RFRAC Report: Well Fractured From well history file 9/5/1986, 'DTSPD Dt Well Spudded 7/24/1986 DTAPV Dt Well Permit Approved 7/24/1986 PERI Dt Well Permit Issued 1111 • • Page 1 of 1 Regg, James B (DOA) From: Nordic 3 Toolpusher [n1434 @conocophillips.com] )4(ett Za Sent: Wednesday, November 30, 2011 4:47 PM ) (4u) To: Regg, James B (DOA) ucq. I CH t� Subject: FW: Sent from NSK0277 Attachments: scan.pdf gqe5 c oLd 4fi pPeSStt re_ kA w' SUwcni 3 I I -3& Wto l )01/4 e-lc 4'S 11/30/2011 - • Page 1 ')f 1 Regg, James B (DOA) From: Regg, James B (DOA) `� '0)1 P' b �r4w Sent: Wednesday, November 30, 2011 4:09 PM To: Nordic 3 Toolpusher; DOA AOGCC Prudhoe Bay; Nordic 3 Company Man; Brooks, Phoebe L (DOA); Wedir, Ben (Nordic-Calista) Subject: RE: Nordic 3 11 -29 -11 (Corrected) Please scan and send copies of test charts; thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Nordic 3 Toolpusher [mailto:n1434 @conocophillips.com] Sent: Wednesday, November 30, 2011 9:04 AM To: DOA AOGCC Prudhoe Bay; Nordic 3 Company Man; Regg, James B (DOA); Brooks, Phoebe L (DOA); Wedin, Ben (Nordic - Calista) Subject: Nordic 3 11 -29 -11 (Corrected) Made change from witnessed by Lou Grimaldi to waived by Lou Grimaldi. Brian Pederson / Andy Anderson Nordic Rig 3 907 - 659 -7438 11/30/2011 9 • STATE OF ALASKA tt OIL AND GAS CONSERVATION COMMISSION � `��� BOPE Test Report Submit to: jim.regga.alaska.aov doa. aogcc. prudhoe. bavAalaska. qov phoebe. brooks(caalaska. qov Contractor: Nordic Rig No.: 3 DATE: 11/29/11 Rig Rep.: Pederson / Sipes Rig Phone: 659 -7438 Rig Fax: 659 -7566 Operator: CPAI Op. Phone: 659 -7446 Op. Fax: 659 -7566 T n YS Rep.: Rowell / Hinkel E -Mail n1433@conocophillips.com c, We Name: KRU 2T -03 PTD # 1861420 Operation: Drlg: Workover: X Explor.: Test: Initial: Weekly: X Bi- Weekly / Test Pressure: Rams: 250/3000 Annular: 250/3000 Valves: 250/3000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 1 P BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11 P Pit Level Indicators P P #1 Rams 1 2 7 /8x5VBR P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 2 7 /8x5VBR P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 0 NA HCR Valves 2 3 1/8" P Kill Line Valves 2 3 1/8" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time /Pressure Test Result System Pressure 3050 P CHOKE MANIFOLD: Pressure After Closure 1800 P Quantity Test Result 200 psi Attained 18 P No. Valves 12 P Full Pressure Attained 102 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @2000 CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 8.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Supervisor at: jim.regq @alaska.gov Remarks: FSV Misc P = 3W EUE FOSV. * **NOTE - Sundry 311 -305 requires 3500psi pipe ram test (J. Regg; 11/30/11) 24 HOUR NOTICE GIVEN YES X NO Waived By Lou Grimaldi Date 11/28/11 Time 07:00 Witness Test start 03:30 Finish 11:30 Form 10 -424 (Revised 01/2011) 2011- 1129_BOP_Nordic3_KRU 2T- 03.xls • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/10/11 Inspector: Bob Noble Operator: CPA Well Name: KRU 2T -03 Oper. Rep: Martin Walters PTD No.: 186 -142 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 08/07/11 Date AOGCC Notified: 09/09/11 ' Sundry No.: 311 -024 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 600 Photos Taken? Yes IA 0 OA 20 ' Condition of Wellhead: The wellhead looked to be in good operating condition. The tree was leaning back slightly. The flowline was attached but blinded. The A/L line K been removed but with still in the wellhouse. The A/L line had 1400 psi left on it. Condition of Surrounding Surface The pad looked to have qood clean gravel, There was a wellhouse on the well. The cellar box was dry. Location: The location was verified with the use of a plot plan. Follow Up Actions None Needed: ss94Yg Attachments: Photos (2) REVIEWED BY: Well Schematic Insp. Supry S,Z t KRU 2T pad layout Comm PLB 08/2010 2011- 0910_Suspend_KRU_2T- 03_bn.xls Suspended Well Inspection - KRU 2T -03 PTD 1861420 Photos by AOGCC Inspector B. Noble 9/10/2011 1 ,. ,„._ .,... • . . ';'-',...= - -Ac. ,.,.. ,...J IF o to N . ,„,,,, .,....„ , $ 4 414MININALidit k4' „,,,,t.. , _ _ - 4„: 4 114, •k . c /i i lif ,r Pi -....t 0 ; 414 \ ".** '''' r - , .,...,, '' sm.- ... . . —., — , .„ ..... .. _ A.- , - •- ^ -00 00 .f rrrNrrr ! / - a rrir d r rrrrrrrrwr . iirrrrn : ; * , � '' - 4 ' • f --;- -- it -. l /r /r /N /i� ..- �►1 T. 0 4 b _ lrfr,410, / I !!! !/!! / �!! 'MUM ". Sa m"" ;..N:. _ t . rrtrrrrrr��r�r rrii ririarrnIoI ;y" ///rrlrlr / /� /! ' ' , � . nrrnnn° I �1�' ' " 111111► kw i it :,,,,.,:,,,:' 'A `�% � 11�1 tllkt�i ti A � III'1!1'1� ►1 ��t1► �►�►' `►�'' ► .' • • 1 KUP 2T -03 ConoCOrIliI ips a,d,1, 1�+4ttr) w ,u �i , . _A91 ra , Wellbors APIIVNB Field Name eB Status In tl( Msq ') MD MKS) A et Bart MAD) e,,, „ „sr,. 5010320073£0 KUPA RIVER UNIT PROD 50.37 4,200.00 7,897.0 Comment H2S (ppm) OA. Annotation End Date Krd (R) ' Rig Release Date : SSSV:TRDP 40 1/17/1010 Last WO: ,...� - - - --- - _ - � 811 40.00 9/14/1986 yd+c... - Annotation Depth (Mal End Oat. Annotation last FSod._ End Oat* Last Tag TOC 7,4300 1/26/2011 Rev Reasoro RESOUEF 10 CMT plug Imosbor 32742011 • ii a .a 'tut it 1 F � i y t`” '1 1 , 1 -,' a �hlh is § ( (�i "6 Casing 04/stringers 5 rig 0.. S tring 1D.. Top ittiB) - IDepth It. Set pth(IVO)... String Ott -. String_ String Top Thtd I RANDER.2e CONDUCTOR 16 15.062 320 115. 115.0. 62- H-40 WELDED _- Casing Descriptor String O_. String ID ... Top(RKB) Set Depth h (f — Set Depth (TVD) ... String Wt.. String. String Top Trill SURFACE 95'8 8.765 32.3 3,174.3 2,787.3 36.00 3 BTC Casing Description _ String 0 Sv g I ... Top (nKe) get De plh (T.. Set Dopih (TV0) . _ String L4T... 50:1 String Tep Thrd PRODUCTION ' 7 6 301 7 6, 063.7 2 6 . 00 BT Tub)nR Strtigs:. `C. � 41 Tubing Description Sing 0... Sir[ng ID... + Set D epth Sat Depth(TVD)... Se rig 3 String.. St Top Thrd TUBING 2 7/8 1 2441 t 1 7.459.7 5,736.8 6550 J-55 EUEOI4AB1 /OD 1 1 - :, aCompiot)on Details Top Depth CO.YOUCTOR. (NO) T Incl Rani.. 7z - „ 5 rep feel (•) Item Des <,Iption 07 Comme 40 941 28.3 283 0,02 HANGER C)W TUBINGIIAN 2.875 1794,8 1,770.$ - - 27,75 SAFETY VLV CAMCO ' F ' 0P- A,SSA 1 a 7,417.8 5,705.8 42 ■ - PBR BROWN MI 2-500 SAF111 r.rs V.47 6 E —_. - -- G. 7,434.5 5.718.1 4200 PACKER BROWN HS-1 2800 7,449.0 5,728.8 41.96 NIPPLE CAMCO D NIPPLE 2.250 mm 7,458.8 5,7363 _ SOS BR ..1 SNFAR OUT SUB, ELMD TTL 7A during PERE on 2.441 oos ti1T. /16/93 2.040 _ Other In Hole`_ N irel)ne retriova plugs, valves, pumps, fish, etc.) 1. Top Depth I IND) Top I n c ToP (ttKe) (ft") Q) Dssu[pd M on Comment Run Date 10 (In) 7,435.0 5,718.5 42.00 CMT SOZ RE- SQUEEZE CEMENT: PUMPED10 15-8 ppg'G' 3'27/2011 0.000 CEMENT; TOC r 7435' Perforations & Slots . suRFacE. 5hot 029,174 Top(TVD) DWI (VD) Dena Top CRAB) Btm(RKS) IRKS) (RIO) Zone Data ph.. Type Comment 045 LIFT. 7,520.0 7,536.0 5,782.4 5,791.1 C A.3, 2T-03 7/1811993 6.0 APERF 2 1/8' EnerJet; ( +1.) 45 deg. Phasing 4 7,5380 7,561.0 5,794,1 5,8125 A - 27-03 10)17/1986 4.0 IPERF 4' Hype/Jet!! 7,602.0 7,6010 5,842,4 5 843.9 A -2, 2T 10/17/1986 4 0 IPERF 4' Hypeclet II GASUTT. „._. Notes: General & Safety 5972 End Date Annotation 8272002 NOTE: CORKSCREWED TUBING © 1450' TO 7460 •"NO COIL "• 549x2009 NOTE: CORKSCREWED TUBING a 362 ELMO GASXi 1 1/29)'2010 ' NOTE: VIEW SCHEMATIC W(Alaska Scheonatic9.0 439 GAS OF .]Q3 III ii ill LI: I 6 A451177. '.. 7,052 CAS UFT. Tan f a4.1477 1 I .. K5 PACR.7,435 Plarar n 6,941* 7,440— '-- -___ ,,. : J 1 5007,159 G1 T $02, 7.405 `c. F M t PII' p 1 1 Tit 1' i AeER”, a t Do, os a � i bS "kill ` -$ , � 1 .. b 1 7.570.7.536 " Top Depth Top Port IPERF, ) 1041 r � � L auri S ) T (p1)) 7,535 -7,54, 840 T0 . RKB i 1 Pt sari Type ( 1 (Psi) Con, 2,839.6 ® 46.73 CAMCO KBMG EN GAS LIFT ( # 8 I 0 . 1 2 5 1236.0 63/1998 4,935.4 3, 981.0 M CAMCO ." GAS LIFT WM BK agaggaliZigall IPERF, © � ®m 7.5024504 ° 3 5.972 4 45.84 CAMCO KB MG a , 1,419.0 6G/1998 ns 5M4.CM p10 441 4 6,37 1111Miggiiiial KIM 11111 1 t tai a s DMY I 5 6.70 4 .. s :010 LTC T °250 1/ * 1 8 7,051.9 5,443.8 44.79 CAMCO KBMO 1 GAS LIFT D4(Y BK 0.000 00 625/1998 7 7,3772 5,678.3 43,15 1,6 2 778*0.5 1 1/2 GAS LIFT DM RK 0.000 0.0 6/3/1998 7 PRODU0T10N. Ob•1a8r� TD. 7,691 r r.............. r= " NOTE —......, , .4 t-:.:-:-:-:-:°:•:-:-:-:- I NO SNOW IS TO BE PLACED IN ,--- , i ---N I ANY RESERVE PIT OR LINED PIT. / '; r amgo tatasi k, pRoi 1 I RESERVE PIT r . p G .1 j ICO [ PIPELINES i L I........ 1 PIT)TE 1 0 n. I ... i I MR V.' — p -a-) ... crum • 1 1 I L...„,......„--11-- • 05% 1, ,7 [ , i - 1M , .. 1 1 1 II III . i ; 1 / 15' El.f.:1 01.57,i14,5 4 191 ,,,,,,,,,„,, ' I Ming; 1' I 1% 9 r, 1 4 ; 2 23iii 26 28 30 32,i Ff'„ F. 2 .- n" IQ ix.1 „ _,,,..t., ,,, ,„.,...„, ..., 3, k,„ 4., 000 4 • 8 *..tt,!>. ,;•• •,..”. •••:, A Y, 22 OA 27 29 31 CSk ..4. r, 37 20 18 38 "1774;1,' cu t".4 CZ .1 TO S2 , --75"--- , 25%25 1 25 1 25 1 --75*-- 1 20 1 -40*- 1 2,5 1 -15.0" --50 te I G SPACES .. \ .1 ,,,,cEsi 12_spAcEs 12 01Imas 0 25 1 .....6r1s. , ....., .,, 0 QS 0 15 12:f2sEs I 2 I t .. tk„. if,/ 0 " : , 4 MSC ei 1 ri rig 'YAM r il l r . 4 ffa 1 r ed : 119; tl redd &let e r I , ; . ! •, L --. El 11 '1/ \‘,..././././ ../.„ , ./.-- 1• , L , •k 1 LEGEND 1 : FEATURE LOCATION !, . EXISTING PRODUCER r k C A U TI ON LEGEND A EXISTING INJECTOR THIS DRILL SITE IS a CONVERTED FROM I. t, /74 - CLEAN SNOW DUMP AREA ALL EQUIPMENT. 21 RESCUE EQUIPMENT CONSIDERED TO BE PRODUCER TO INJECTOR * SODA LOCATIONS Z ABANDONED CONDUCTOR ? • - ENVIRONMENTAL AREA-NO SNOW DUMPING, AN H AREA I - POWERLINE-WATCH CLEARANCEII„ r"-F] DESIGNATED SAFE AREA (PRIMARY) A EXISTING CONDUCTOR KODIAK II, BLOWERS MAY HIT LINES WITH DISCHARGE. M. DESIGNATED SAFE AREA (SECONDARY) 0 PARTIAL TREE I ' ; " - KODIAK BLOWERS MAY DISCHARGE OVER - '0'" EVACUATION ROUTES DEPENDING ON WIND I. PIPELINES. , WIN p xxmot - NO SNOW DUMPING AREA r DSOCK BARRICADE/ESCAPE ROUTE MIi 1 AREA: 2T MODULE:XXXX UNIT: D2 1, A LOUNSBURY, INC FIRE EXTINGUISHER ; I APPROVAL: I I .; ::: ; ": V„' ' ,„ ' ': ° t I t 5 115/01/02 Add Well 39, Rev Per X02013ACS !ART III ,, DATE: 11/26/99 c FILE'LK622011 l 4 5 30 01 Add Wells Mote Title Bk Rev Per K01039ACS ROt, ' DRAWING NO. SHEET: REV: , :v r.mtir; • .7;7 .7. i • irlwi DATE REVISIONS ea ctiK witer. • • S [1:ff' nInSEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM ISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 J. Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 9510 - Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -03 Sundry Number: 311 -305 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • i Daniel T. Seamount, Jr. Chair DATED this 7 day of October, 2011. Encl. • • RECEIVED Conoco Phillips SEP 3 0 2011 Alaska P.O. BOX 100360 Alaska Oil & Cons. Commission ANCHORAGE, ALASKA 99510 -0360 A Gas nchorage September 29, 2011 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7` Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T -03 (PTD 186 -142). 2T -03 was originally completed in September of 1986. The well is a single gas lift completion producing from the Kuparuk A & C sand intervals. This well is located in an area where surface subsidence has become an issue. Since 1997, this well has measured a total surface subsidence of 50 ", which has caused severely corkscrewed tubing. / The well failed an MIT -OA on 3/27/09 and diagnostic casing tests indicate a leak in the 9 %" surface casing at 348' MD. The well passed a TIFL on 9/27/10, but at the end of November 2010 while in the process of doing an OA No Flow Test, the IA was bled down, and over the course of the next couple months, the IA pressure slowly built up to a maximum of 625 psi— indicating TxIA communication or a packer leak. Due to the corkscrewed tubing, we are unable to drift to set a plug, therefore, with only one un- testable barrier remaining, it was determined the safest plan of action would be to cement the perforations and isolate the reservoir until a workover could be completed. The perforations were cemented on 1/26/11, and re- squeezed on 3/27/11 and 7/18/11. Following the 3` cement squeeze, the tubing passed an MIT to 2500 psi, although recently, we have been unable to get successful drawdown tests on the tubing and IA. C M rr r .4 The SBHP has been determined using the SI wellhead pressures and a static diesel column to surface. The SBHP is calculated to be 2,660 psi at a mid -perf depth of 5,813' TVD, and the MASP is 2,079 psi using a 0.1 psi /ft gradient. Plans are to test the BOP's to 3500 psi, which is at least 1000 psi above the MASP to comply with the ConocoPhillips Well Control Policy. The objective of this workover is to pull the existing tubing, cut & pull the damaged portion of the 7" casing, re- install new 7" casing, and circulate cement into the7" x 9 5 /8" annulus; which will ultimately plug the leak in the 9 casing and provide a more structurally sound wellbore to combat any future surface subsidence. New 3 ' /2" tubing will be run to accommodate possible future CTD opportunities. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely ? J. Brett Packer Wells Engineer CPAI Drilling and Wells II + m.o... v So ., s er L.1,0 STATE OF ALASKA p-" „ , - x 4- fl S E P 3 0 2011 ALASKA•. AND GAS CONSERVATION COMMISSI ' APPLICATION FOR SUNDRY APPROVA S Alaska Oil & Gas Cons. Commission 20 AAC 25.280 h.,,r.h;1r a n 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well J Change Approved Program r Suspend r Plug Perforations ” Perforate r Pull Tubing l✓ Time Extension r Operational Shutdown r Re -enter Susp. Well '"" Stimulate r Alter casing p" Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r" ., Exploratory r 186 -142 3. Address: Stratigraphic r Service (" 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50- 103 - 20073 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No rti 2T -03 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25569 • 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): 7897 6067 7809' 5999' Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 115' 115' SURFACE 3142 9.625 3174' 2787' PRODUCTION 7863 7 7893' 6064' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7520'- 7561', 7602' -7604' 5782'- 5813', 5842' -5844' 2.875 J - 7459 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN HB -1 MD= 7435 TVD= 5718 SSSV - CAMCO TRDP -IA -SSA MD =1795 TVD =1771 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/21/2011 Oil Gas r" WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR F SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265 -6845 Printed Name J. Brett Packer Title: Wells Engineer �-7 Signature , 7 / P hone: 265 -6845 Date / //f Commission Use Only Sundry Number3i (.3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test V Mechanical Integrity Test r Location Clearance r iti 35 fis:, 3Df / Other: *ZS00 fis Ann J+�s� s,._._„ Subsequent Form Required: APPROVED BY /W./ Approved by: �� COMMISSIONER THE COMMISSION Date: Form 10 -4+ `o -4/_// SS Duplicate l �; ��M�.,� w � p .' � 'j o • KUP • 2T -03 -)i-c,l --- (... C___ Lt. r re4,04 ) Con o W Attributes Max Angle & MD TD � Inc I Wellbore APVU WI Field N e Well Status Incl (°) IMD (RKB) Act Btm (RKB) Ux,ocai•alNpt 501032007300 KUPARUK RIVER UNIT PROD 50.37 4,200.00 7,897.0 Comment (ppm) Date Annotation End Date KB (R) Rig Release Date Well Cons5 203 559Q01 sys .gryt - ,_ SSSV- TR 40 1/17/2010 Last WO_ 4000 9/14/1986 __. _ - .... _ eic M fation Depth (RKB) End Date Annotation Last Mod - T EM Dab Last Tag: TOC I 7,430 0 1 . 1/26/2011 Rev Reason' RE- SQUEEZE CMT Plug imosbor 3/2712011 (;ac Strings Casing Description ' String 0... Siring ID ... Top (ttKB) Set Depth (L.. Set Depth (WD) .. String Wt... String ... String Top Thrd HANGER. za CONDUCTOR 15 32.0 115.0 W _. H WELDED Casing Desenptbn String 0... String g ID ._ Top (fI01103) Sat Depth (P... Set Depth pth (T (T VD) .. String g YH Siring _. String Top Thrd SURFACE 95/8 8.765 32.3 3,174.3 2,787.3 36.00 J - 55 BTC i Casing Description String 0... String ID ._ Top (tIKB) Sat Depth (f... Sat Depth (TVD) ... String Wt_. Siring ... String Top Thrd { PRODUCTION 7 6.151 30.1 7,8928 6,063.7 26.00 J-55 BTC { Tubing Strings Tubing Description String 0 ,String ID... Top (f1KB) Set Depth (f... S Depth (WD) 'String W0t._'. String ...'String Top Thrd I 27/8 2.441 I 283 I et 7,459.7 5,736.8 6. 50 1 J55 EUE8rdABMOD BE _ Completion Details Top Depthl CONDUCTOR,_, . (WD) 1 Top Intl Nomi... 32 -115 .' Top K5(B) (B) (°) hem Description Comment ID(in) 28.3 28.3 -0.02 HANGER CIW TUBING HANGER - - -- 2.875 LE Ai; 1.794.8 1,770.9 27.75 SAFETY VLV CAMCO TRDP-1A-SSA 2.312 I. 7,417.8 5,705.8 42.04 PBR BROWN PBR 2.500 SAFETY VLV, 1,795 7,434.5 5,718.1 42.00 PACKER BROWN HB -1 2.800 It 7,449.0 5,728.8 41.96 NIPPLE CAMCO D NIPPLE 2.250 7,458.8 S. /36.2 41.93 SOS BROWN SHEAR OUT SUB. ELMD TTL 7493' during PERF on 2.441 GAS LIFT, - - 07/18/93 2,840 ?% ' Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth 7 (TVD) Top Ind li - Top (RKB) MKB) CI Description Comment Run Date ID (in) 7,435.0 5,718.5 42.00 CMT SOZ RE-SQUEEZE CEMENT; PUMPED70 BBLS 15 -8 ppg 'G' 3/27/2011 0.000 CEMENT; TOC 7435 Perforations & Slots SURFACE.-__ -.. Shot 32 -3,176 Top (TVD) trim (TVD) Dens • T.. MKS 134n RKB) OMB) (RKB) Zone Date Oh-. T1. - - -._ Comment GAS LIFT 7,520.0 7,536.0 5,782.4 5,794.1 C4, A-3, 2T -03 7/18/1993 6.0 APERF 2 1/8" EnerJet (t / -) 45 deg. Phasing i 4 ' 9 7,536.0 7,561.0 5,794.1 5,812.5 A -3, 2T -03 10/17/1986 4.0 IPERF 4" HyperJet II 7,602.0 7,604 -0 5.842A 5,843.9 A -2, 2T -03 110/17/1986 4 0 i tPERF 4" HyperJet II Gas urn, _. ' No1c & Safety - ____. _... 5.972 b Annotation End Da 8/27/2002 NOTE: CORKSCREWED TUBING @ 1450' TO 7460' ' "'NO COIL "' 529!2009 NOTE: CORKSCREWED TUBING @ 362 ELMD GAS LIFT. _ 6.322 11/29/2010 NOTE: VIEW SCHEMATIC w /Alaska Schlxnatic9.0 GAS LIFT, 6,703 I GAS LIFT, 7,052 GAS LIFT, __.. 7,377 . PACKER, 7,035 NIPPLE, 7,449 II p f ei-7"S G Grrt e- 1 SOS, 7,459 - -- - € CMT S02, 7,435 "--- APERF._ __ Mandrel Details Top Depth Top Port IPERF (TVD) Inel OD Valve Latch Size TRO Run 7,536 -7,561 Sin Top (MKS) (RKB) (°) flake hide (In) Sery TYpe Type lie) (psi) Run Dot Can... 1 2,839.6 2,555.5 46.73 CAMCO KBMG 1 GAS LIFT GLV BK 0.125 1,236.0 6/3/1998 2 4,935.4 3,981.0 46.83 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,319.0 6/3/1988 IPERF, 3 5,972.1 4,690.9 45.64 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,419.0 6/3/1998 ],BM4,6W �-- CSGRBG CMT PLUG. 7,430 4 6,322.2 4,933.2 46.47 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/25/1998 5 6,703.4 5,196.7 44.69 CAMCO KBMG 1 GAS UFT OV BK2 0.250 0.0 6/3/1998 6 7,051.9 5,443.8 44.79 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/25/1998 'f 1 7 7,377.2 5,676.3 43.15 MMH 27/8x1.5 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/3/1998 PRODUCTION, 30-7,893 TD, 7,897 - - - -- . • • 2T -03 Expense Rig Workover (PTD #: 186 -142) Current Status This well is currently shut -in awaiting a workover. This well is located in an area where surface subsidence has become an issue. Since 1997, this well has measured a total surface subsidence of 50 ", which has caused severely corkscrewed tubing. The first indications of corkscrewed tubing were observed as early as August 2002 when Slickline indicated heavy pick up weights while drifting the tubing, but was still able to drift to bottom at that time. The following day, an FCO was aborted with coiled tubing because the pick up weights were too severe. In April 2009, the tubing was drifted to a max depth of 3500' w/ a 1.75" swedge using a 1.5" toolstring with knuckle joints every 3 feet. A month later, a 1.80" gyro survey (37.3' OAL) stacked out at 362' MD. The well failed an MIT -OA on 3/27/09 and diagnostic casing tests indicate a leak in the 9 3/4" surface casing at 348' MD. A workover was planned to proactively repair the 7" casing due to subsidence, therefore the well remained on production to allow for de- pressuring, although gas lift was discontinued in June 2010 as per subsidence waiver requirements. The well passed a TIFL on 9/27/10, but at the end of November 2010 while in the process of doing an OA -NFT, the IA was bled down, and over the course of the next couple months, the IA pressure slowly built up to a maximum of 625 psi — indicating TxIA communication or a packer leak. , Due to the corkscrewed tubing, we are unable to drift to set a plug, and also unable to pull the orifice valve and set a dummy to get a test on the 7" production casing, therefore, with only one un- testable barrier remaining, it was determined the safest plan of action would be to bullhead cement from surface to plug the perforations and isolate the reservoir until a workover could be completed. The Kuparuk A &C sand perforations were cemented on 1/26/11, and re- squeezed on 3/27/11 and 7/18/11. The estimated top of cement in the tubing is at 7,327' MD. Following the 3` cement squeeze, the tubing passed an MIT to 2500 psi, although recently, we have been unable to get a successful drawdown test on the tubing. Event History 3/27/09 MIT -OA— Failed, SCLD found OA leak at 348' MD. 4/19/09 TIFL— Passed, T- POT — Passed, T- PPPOT— Passed, IC- PPPOT— Passed 4/30/09 Gauge tbg w/ 2.20" to 3000 ft, 1.75" to 3500 ft w/ 1.5" toolstring and knuckle joints every 3 feet. 5/1/09 All Drillsite 2T injectors SI due to subsidence. 5/28/09 Attempted Gyro survey, RIH w/ 37.3' x 1.80" OD gyro tools, stacked out at 362.5' ELM. 6/21/10 T- POT — Passed, T- PPPOT— Passed 9/27/10 TIFL— Passed 12/16/10 OA- NFT— Passed, IC -PPPOT —Failed 1/26/11 Well was SI, Bullheaded 8 bbls 15.8 ppg "G" cement to perfs. 1/30/11 MIT -Tbg – Failed 2/20/11 CMIT TxIA — Failed 3/27/11 Squeezed 10 bbls 15. "G" cement to erfs. 3/31/11 C IT TxIA — Failed 5/24/11 IA -DDT —F ailed 5/27/11 MIT -IA (CMIT TxIA) — Failed (OV in GLM #5) 7/17/11 Attempted dye test. Pumped 320 bbls diesel down tbg taking returns out the IA, only got 240 bbls returns. No dye to surface. 7/18/11 Squeezed 10 bbls 15.8 ppg "G" cement w/ 3 lb/bbl CemNet to perfs, T.O.C. estimated at 7,327' MD. 8/7/11 MIT -Tbg— Passed to 2500 psi, T-DDT--Failed, IA- DDT — Failed 9/3/11 Tbg- DDT — Failed RWO Scope of Work • Pull the corkscrewed tubing. • Cut & pull the subsidence damaged 7" casing. ✓ • Re -run new 7" casing and cement the 7" x 9 3/4" annulus. • Pull the packer. • Drill out cement in the 7" casing. • Install new 3 'h" single completion. • • General Well info Well Type: Producer Wellhead: Cameron Gen IV, 11" 3K btm x 7- 1/16" 5K top flange SBHP/MASP: 2,660 psi / 2,079 psi (Based upon current SI pressure of 625 psi and a diesel gradient to the mid - perf depth of 5,813' TVD. All supporting injectors have been SI. MIT Results: MIT -OA— failed on 3/27/09, MIT -Tbg —Passed on 8/7/11, OA NFT— passed on 12/16/10, T- DDT— failed on 9/3/11 BOP Configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams Est. Start Date: Oct. 21, 2011 Prod. Engineer: Mike Balog / Evan Reilly RWO Engineer: Brett Packer (265 -6845 / j. brett.packer @conocophillips.com) Pre -Rig Work 1. Verify circulation between tbg & IA. 2. Dummy drift for split shot and tag top of cement in tubing. a. If able to drift for split shot and if circulation rate determined prior is not adequate, run a split shot and split the collar above the PBR. 3. Circulate well full of 9.6 ppg corrosion inhibited brine. 4. CMIT TxIA to 2500 psi, DDT on both tubing & IA. . 5. PT tubing and casing packoffs, FT LDS's. • 6. Set BPV. 199V Proposed RWO Procedure It 5 k- 1. MIRU Nordic 3. 2. Pull BPV, verify well is dead. If not, reverse circulate 9.6 ppg brine. Verify well is dead. Set BPV, ND tree, NU 11" 5K BOP. Pressure test BOP including annular to 250/3500 psi. 3. Pull blanking plug and BPV. Attempt to pull tubing from PBR. a. If unable to pull free, set tubing in the slips. b. RU Slickline, drift tubing for E -line RCT cutter. RD Slickline c. RU E -line, RIH and cut the tubing in the middle of first full joint above the PBR. i. If unable to drift for E -line cutter, perform a blind backoff. ✓ 4. POOH laying down tubing. 5. Run 7" scraper assembly to top of tubing stub. Circulate well clean. 6. RU E -Line. Run casing evaluation logs including CBL in the 7" casing. Based on cement top, determine depth of 7" collar to back -off following casing cut. RIH and fire string shot across that collar. RD E -Line. 7. Set RBP below top of cement. Pressure test to 2500 psi and drawdown test to Q psi. D m pan s d on top RBP. — oK 74135 nab 8. ND BOP stack, ND tubing head. Spear 7" csg and pull in tension and re -land in slips. Cut off 7" casing growth. Tack weld slips to casing. 9. NU 11" 5M BOP on casing head. (Cannot test break due to leak in the surface casing, BOP stack will be considered a diverter, there are 2 barriers in the well at this point.) 10. Cut 7" casing above TOC. Circulate Arctic Pack from the 9 5 /8" x 7" annulus with w/ heated diesel followed by heated seawater. 11. Spear 7" casing and POOH sideways. • — Proposed RWO Procedure Continued 12. Run 9 %" casing scraper to top of 7" stub. Circulate clean. • 13. RU E -Line. Run casing evaluation logs in the 9 %" casing. RD E -Line. 14. Run back off tool and back off casing stub. ' 15. Run tandem string mills to gauge the 9 5 /s" csg for the ES cementer. 16. Spear and recover backed off 7" casing stub. 17. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing. • 18. Open ES cementer and pump cement into 9 -5/8" x 7" annulus to surface. Close cementer. 19. WOC. ND BOP, pull casing in tension and land in slips. Cut 7" casing, install packoff. NU new tubing head. 20. NU 11" 5M BOP and test break to 3500 psi. 21. Drill out cement. Pressure test casing to 3500 psi. Continue down until tag up on top of sand, dry drill to break up debris. Circulate well clean. 22. RIH with wash shoe, boot baskets, magnets, etc. and circulate out sand on top of RBP. 23. RIH w/ RBP retrieving tool on work string. Release RBP and POOH. a. RIH w/ overshot and pull tubing stub from PBR if necessary. 24. RIH w/ overshot for PBR, latch onto PBR and attempt to pull Brown HB -1 packer free. a. If packer will not pull free, set the drillpipe in the slips. b. RU E -line, RIH and cut the tubing at 7,445' RKB (middle of the pup joint below the packer). RD E -line. 25. POOH standing back drillpipe, lay down packer. a. If tubing was cut below the packer, MU milling assembly, RIH and mill over remaining tubing tail. b. RIH w/ 2'/8" overshot and retrieve tubing tail. 26. RIH and drillout cement to 7800' RKB. Circulate well clean. 27. RIH with new 3 %z" single completion to 7460' RKB. Reverse circulate corrosion inhibited fluid down the IA, drop ball & rod and set the packer. PT IA to 3500 psi. Shear the PBR. 28. Space out and land the hanger. RILDS. 29. Pressure test tubing to 3000 psi, PT IA to 3500 psi, shear the SOV. 30. Set 2 -way check. ND BOP. NU tree and pressure test. 31. Pull 2 -way check. Freeze protect well. Set BPV. 32. RDMO Nordic 3. Post - Ric Work request: 1. RU Slickline: Pull ball & rod. Pull SOV and replace w/ DV. Pull RHC plug. 2. Perforate Kuparuk A & C sands. C - plr" 3. RU Slickline: Run new GLD. 4. Return well to production. 5. Re -frac Kuparuk A & C sands (if necessary). ✓ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 10, 2011CC^N` SEP 1 4 ?t''' Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission ta Q11 & Gas (`'ells• 333 West 7 Avenue, Suite 100 itiSC1?!3i Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -03 (PTD 186 -142) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2T- 03 (PTD 186 -142). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List � t 2 8 t U - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, je/e/ w Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Re air well Rug Perforations Stimulate Ot her Suspended Well r p 9 r r Inspection Aker Casing r Rill Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r • 186 -142 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 ' 50- 103 - 20073 -00 — QQ 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025569 2T -03 9. Field /Pool(s): r Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7897 feet Plugs (measured) None true vertical 6067 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 7435 true vertical 0 feet (true vertucal) 5718 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 115 115 SURFACE 3142 9 -5/8 3174 2787 PRODUCTION 7863 7 7893 6064 Perforation depth: Measured depth: 7520 7536, 7536-7561, 7602-7604 True Vertical Depth: 5782 -5794, 5794 -5812, 5842 -5844 E 1 CooliSilai S Co�9* Tubing (size, grade, MD, and TVD) 2.875, J -55, 7460 MD, 5737 TVD �����$` SO o PA Packers & SSSV (type, MD, and TVD) PACKER - BROWN HB -1 @ 7435 MD and 5718 TVD SSSV - CAMCO TRDP -1A @ 1795 MD and 1771 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 15. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP F SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact MJ Loveland /Martin Walters Printed Name Martin Walters ��//�� Title: Well Integrity Project Supervisor Signature W cr94,e Phone: 907-659 -7043 Date: 09 -10-11 eleOMS SEP 14 S•l3•'( �/ Form 10 -404 Revised 10/2010 Submit Original Only Y • • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk River Unit 2T -03 Field /Pool: Kuparuk River /Kuparuk River Pool Permit # (PTD): 186 -142 Sundry 311 -024 API Number: 50103200730000 Operator: ConocoPhillips Date Suspended: 8/7/2011 Surface Location: Section: 377' FSL, 556' FWL, Sec 1 Twsp: T11 N Range: R8E UM Nearest active pad or road: KRU DS2T Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good. Gravel Pad Location cleanup needed: No Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: Rain water on pad Discoloration, Sheens on pad, pits or water: No sheen Samples taken: No Access road condition: Good Photographs taken (# and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Good. Cycled SSV, SV, MV, IA valve, and OA valve. SSSV & MV open and tree leaning back slightly Cellar description, condition, fluids: 6X6 wooden cellar. Dry Rat Hole: No Wellhouse or protective barriers: Wellhouse with fiberglass floor Well identification sign: Stenciled on wellhead and wellhouse Tubing Pressure (or casing if no tubing): 600 psi. Flowline attached but blinded Annulus pressures: IA = 0 psi, OA = 20 psi. AL line disconnected but in house Wellhead Photos taken (# and description): 2 of wellhead and cellar Work Required: Address 1400 psi on disconnected AL line /,-�� Operator Rep (name and signature): Martin Walters jil� r Xi/(ht et AOGCC Inspector: Bob Noble Other Observers: Mouser /Bybee /Greenwood Inspection Date: 9/10/2011 AOGCC Notice Date: 9/1/2011 Time of arrival: Time of Departure: Site access method: Highway vehicle • KUP • 2T -03 Conoc d Well Attributes Max Angle & MD TD Alaska. Inv W ellbore APWWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (ftKB) ,�, 501032007300 KUPARUK RIVER UNIT PROD 50.37 4,200.00 7,897.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP 40 1/17/2010 Last WO: 40.00 9/14/1986 Well Coned -2 328no11 AM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: TOC 7,430.0 1/26/2011 Rev Reason: RE- SQUEEZE CMT Plug Imosbor 3/27/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 28 CONDUCTOR 16 15.062 32.0 115.0 115.0 62.50 H WELDED i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 32.3 3,174.3 2,787.3 36.00 J - 55 BTC 1 1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 30.1 7,892.8 6,063.7 26.00 J -55 BTC Tubing Strings ' Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd III TUBING 27/8 2.441 28.3 7,459.7 5,736.8 6.50 J -55 EUE8rdABMOD �Iw:z .r .; Completion Details Top Depth CONDUCTOR, (ND) Top Inc! Nom'... 32 -115 Top (ftKB) (ftKB) (C) Item Description Comment ID (in) 28.3 28.3 -0.02 HANGER CIW TUBING HANGER 2.875 mac I 1,794.8 1,770.9 27.75 SAFETY VLV CAMCO TRDP-1A-SSA 2.312 7,417.8 5,705.8 42.04 PBR BROWN PBR 2.500 SAFETY 1.7995 ° 7,434.5 5,718.1 42.00 PACKER BROWN HE-1 2.800 ir 7,449.0 5,728.8 41.96 NIPPLE CAMCO D NIPPLE 2.250 7,458.8 5,736.2 41.93 SOS BROWN SHEAR OUT SUB. ELMD TTL @ 7493' during PERF on 2.441 GAS LIFT, 07/18/93 2.040 _ i Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc] Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 7,435.0 5,718.5 42.00 CMT SQZ RE- SQUEEZE CEMENT; PUMPED10 BBLS 15-8 ppg 'G' 3/27/2011 0.000 Perforations & Slots CEMENT; TOC @ - 7435' SURFACE, • Shot 32 -3,174 Top (TVD) Btm (TVD) Dens �� Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh .. Type Comment GAS LIFT, I -4 7,520.0 7,536.0 5,782.4 5,794.1 C-4, A -3, 2T -03 7/18/1993 6.0 APERF 2 1/8" EnerJet; ( + / -) 45 deg. Phasing 4,935 7,536.0 7,561.0 5,794.1 5,812.5 A -3, 2T-03 10/17/1986 4.0 IPERF 4" HyperJet II L 7,602.0' 7,604.0 5,842.4 5,843.9 A -2, 2T-03 10/17/1986 4.0 IPERF 4" HyperJet II GAS LIFT, ., Notes: General & Safety 5,972 End Date Annotation GAS LIFT, 8/27/2002 NOTE CORKSCREWED TUBING @ 1450' TO 7460' "'NO COIL *** 5/29/2009 NOTE: CORKSCREWED TUBING @ 362 ELMD 11/29/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 6,322 t GAS LIFT, ! 6,703 LIFT, IE Ill 1 4 GAS LIFT. 7,052 GAS LIFT, 7,377 I PBR, 7.418 PACKER, 7,435 ./-- I NIPPLE. 7,449 II '. I SOS, 7,459 n. CMT SQZ, 7.435 APERF, Mandrel Details 7520 -7,536 Top Depth Top Port IPERF, (TVD) Inc! OD Valve Latch Size TRO Run 7,536 -7,561 Stn Top (ftKB) (ftKB) (°) Make Model (in) Seen Type Type (in) (psi) Run Date Com... 1 2,839.6 2,555.5 46.73 CAMCO KBMG 1 GAS LIFT GLV BK 0.125 1,236.0 6/3/1998 2 4,935.4 3,981.0 46.83 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,319.0 6/3/1988 IPERF, 7,602 3 5,972.1 4,690.9 45.64 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,419.0 6/3/1998 CSG MT PLUG. CMT G C 4 6,322.2 4,933.2 46.47 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 525/1998 5 6,703.4 5,196.7 44.69 CAMCO KBMG 1 GAS LIFT OV BK2 0.250 0.0 6/3/1998 I 6 7,051.9 5,443.8 44.79 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/25/1998 7 7,377.2 5,676.3 43.15 MMH 27/8x1.5 1 12 GAS LIFT DMY RK 0.000 0.0 6/3/1998 PRODUCTION, 30-7,893N Ik TD, 7,897 POWERLINES ,.. AMP , ME NOTE ICI t .......... 'I • NO SNOW IS TO BE PLACED IN I ANY RESERVE PIT OR LINED PIT. (---/— -....\\ BLS 1 p6� 2a RIR RESERVE PIT P � r[are' (i N k PIPELINES \ PIT rO eaw * p a0 ���i HM I° � rn 1 0 OZ. I— n. � ® 191' 1515 1 231- 7 6 5 4 3 2 23 4 a„ NN N N® I I S ow ,- .)n oO 0 AAA 91) ®a oic,.a 3 , a J d ® ( GI Ge( 0 Y m ' ' 37 20 18 3 38 M 22 27 29 31 N N / �yI 1 11 I T O DS2A 1 -75'— $5' L25' -48' 5 1 , 150'— '- 45' 62.5 -13 5 25� e I ,: SPACES] L is I! s6 s 1 2 nE s I1 L3 W, S I2I IS 00 5 8 15d 40r 1 FEATURE LOCATION LEGEND CAUTION EXISTING PRODUCER LEGEND - EXISTING INJECTOR // / - CLEAN SNOW DUMP AREA, ALL EQUIPMENT. I2 RESCUE EQUIPMENT CONSIDERED TO BE THIS DRILL SITE IS 0 CONVERTED T TOR • * SCBA LOCATIONS C4f.4.7. - ENVIRONMENTAL AREA -NO SNOW DUMPING. AN H AREA I ABANDONED CONDUCTOR 1 I DESIGNATED SAFE AREA (PRIMARY) )S( EXISTING CONDUCTOR - ow/01 - POWERLINE -WATCH CLEARANCE!!, KODIAK BLOWERS MAY HIT LINES WITH DISCHARGE. 12 I DESIGNATED SAFE AREA (SECONDARY) IR PARTIAL TREE ' OP'VA�yj,. - KODIAK BLOWERS MAY DISCHARGE OVER (] EVACUATION ROUTES DEPENDING ON WIND PIPELINES. I WINDSOCK r.•:•:•:•:1 - NO SNOW DUMPING AREA. ® BARRICADE /ESCAPE ROUTE ra AREA: 2T MODULE:XXXX UNIT: D2 A LOUNSBURY, INC ::•:: i R , FIRE EXTINGUISHER APPROVAL: DS2T FACILITY EXPANSION h 5 5/01/02 Add Well 39, Rev Per K02013ACS MRT SCT DATE 11/26/9 CARD FILE:L It622011 FEATURE LOCATION 4 5/30/01 Add Wells, Update Title Blk, Rev Per K01039ACS ROL MRT DRAWING NO. SHEET: REV: NO COST DATE REVISIONS BY CHK ENGR PROJ CEA —D2TX -3323 001 5 • 0 • `'' -- 2T -03 (PTD# 186 -142) -- © ConocoPhillips Alaska, Inc. " This photo is copyrighted by .y ` ` ConocoPhillips Alaska, Inc. and cannot be released or . . „ published without express written consent of , ConocoPhillips Alaska . t. b , - * - 4. 1 C 0 w { II t; ;{ p i 4 6 - 'r r 7 • . ., t ' --, - ,- _ e ,,, r.- f - tur ' b 4. '" �A" ` " 1**r,r t' . - *1 y t �( !1'M. w , fi x; = • �" g I � A.,. . Y s� '?o Aar.., r 4 Li tel -..- 4 41E9 ,—t i , '" � sl1 111 1i y /l/liflit/ < t l/'/ /lam / /,�/1il r fi � t e,rw� * ' r , 1l/ /I /v I/III! /.111111111,,1lltivl1 /111 ■ * 111/ ty11111I111 ��' .11111 ■ ■� 1 l i \ 1 t w - \ `mil ' ti ' 1/U /l/N /!!!/ > 1�ll l/11i1111111/1U1 //1111 1 . ,, luffininsiiimaluivill _A.., -..,.� - ^ --w _ - -. � - �_wa� , 4 • - 1- © 2 T ConocoPh 03 (PTD# illips 86 Ala ska, Inc. This is copyrighted b ConocoPhiphoto y llips Alaska, . / c bd published and annot without e release express or Inc written consent of :. P. ''''t , _ cPiips o h AI s Con o II a ka ` / , ', .. 51. <1C-7 . ' - '''' 4. f - " �- ' �, ,,,,, ...., A.4 - -...--- , , :..-_,,.-.. , i '''s - --,,,,;* , ' - ,,.f4...-:, 4 , w .. ,,,,,;„,-, . .; : , - ' -.-:.-..,." . ... . ''.,,. 4 '' ''' -....,,....4.:,„ .4e.,.- ,,,-.4t4..--, -7, * w. y 7 * t. fir , J n a jr S < • t .,,„......i... _ .,,,..„..,,A0....;,,, --- r'''' '' ' - ' ' 0 ' 4 - ...,-; f ..-.1.1, jra., l'.. 1 - .., . .., •'e t `� i r f -- . # 4., / 1 ' - ' . - *47 4 .1‘. ‘.. ,' �'� # "ms 0 '''''' • t ,>. e / � s, A ' l ' � . d 4 + i' '!-, ' .;,,,,,,, .. - . , i .,..* die ,..• • : . 4#1 /** 4 " 44,4"..-/e/ , - e* ' ' ' ' .„, irS* /14 f / ,gF ^y ., t r ry +f i 7 "- • a + • } u ° Abe": t • • ConocoPhillips AUG 2 3 2011 Alaska P.O. BOX 100360 Alaska Oil & Gas COnL. Commission ANCHORAGE, ALASKA 99510 -0360 Anchorage August 21, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 AAWCO AUG 2 ti Commissioner Dan Seamount: Enclosed please find a 10 -404 Report of Sundry Operations post perforation cementing procedure on 2T -03 (PTD 186 -142, Sundry 311 -024). Please call Martin Walters or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, 7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosure STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMISIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perforations J Stimulate r Other r Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 - 142 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 20073 - 00`° 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 ALK 2667 2T -03 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7893 feet Plugs (measured) 7435' & 7350' cmt true vertical 6063 feet Junk (measured) None Effective Depth measured 7776 feet Packer (measured) 7435 true vertical 5946 feet (true vertucal) 5719 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 115 115' SURFACE (QC) 3142 12 3174 2787' PRODUCTION 7863 7 7893 6063' RECEIVED Perforation depth: Measured depth: 7520 -7536, 7536 -7561, 7602 -7604 cemented i\UC7 2 3 23W True Vertical Depth: 5782 -5794, 5794 -5812, 5842 -5844 cemented n & Gas cow GQINTh$� R 0 p (4,„"cY Pa Oil 8 Tubing (size, grade, MD, and ND) 2.875, J -55, 7460 MD, 5737 ND << Packers & SSSV (type, MD, and ND) PACKER - BROWN 'HB -1' @ 7435 MD and 5719 ND TRDP - CAMCO TRDP -IA -SSA @ 1795 MD and 1771 ND 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NA 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 Subsequent to operation 0 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -024 Contact MJ Loveland /Martin Walters Printed Name MJ L veland7 -` Title Well Integrity Supervisor Signature '' 7. - � Phone: 659 -7043 Date t �/ 7 010 )z / / Form 10 -404 Revised 1 00'10 MS AUG 2 3 Z0 Submit Original Only • 2T -03 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/26/11 SQUEEZE 8 BBL OF 15.8 PPG "G" CEMENT. DISPLACE TOC - 7430', FREEZE PROTECT WITH 12 BBL OF DIESEL. INITIAL TWO = 450/200/10 FINAL T /I /O = 0/200/10 01/30/11 MITT- (failed) ; Initial T /I /O= 400/220/40; Shot T FL @ 972ft. IA FL @ 6703ft. #5 OV. Pumped 11.5bbls. of diesel with no pressure increase T /I /O= 350/220/40; Let sit for 20min. shot T FL @ 300ft. T /I /O= 290/220/40 03/27/11 PUMPED (BULLHEADED) 10 BBL OF 15.8 PPG "G" CEMENT DOWN THE TUBING. DISPLACED CEMENT WITH WIPER BALL, 1 BBL BIO, 30 BBL FRESH WATER AND 12 BBL DIESEL FREEZE PROTECT. TOP OF CEMENT -7435'. REQUIRES STATE WITNESS TAG AND PRESS TEST. 03/31/11 CMIT- failed; Initial T /I /0= 640/675/60; T & IA FL @ SF. Started to pressure up T with diesel after pumping 4.5bbls. of diesel pressure seemed to stabilize at about 1545psi. shut down pump T /I /O= 1330/1350/60; Let sit for 15min. T /I /O= 800/800/60; final T /I /O= 800/800/60 07/18/11 Cement re- squeeze. Pumped 10 bbl of 15.8 "G" cement with 3 lbs/bbl Cemnet. Displace cement with wiper ball, 0.5 bbl Biozan, 12 bbl of diesel. Initial squeeze pressure 2000 psi @ 1.0 bpm, final squeeze pressure 2900 psi @ 0.7 bpm. TOC - 7350'. 08/07/11 MIT -T (Passed), ,T -DDT, IA -DDT, T /I /O= (si)600/600/10. Flowline is blinded and GL is disconnected. Pressured up T with 0.15 bbl of diesel. Initial T /I /O= (si)2500/600/10. 15 min T /I /O= (si)2440/600/10. 30 min T/I/O= (si)2420/600/10. Bled T to 0 psi. (18 min).T /I /0 =(si)0 /200/0. Bled IA to 0 psi. (25 min).T /I/0= (si)0/0/0. 30 min T /I /O = (si)100/0/0. 60 min T /I /O = (si)150/10/0. Final T /I /O = (si)150/10/0. Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2011 8:33 AM To: 'Herrmann, Daniel D' Subject: RE: 2T -03 Change of Scope after failed CMIT (PTD 186 -142) Dan, sundry issued to plug perforations Sundry # intended scope of the su ( ry The work you outline below is still part of the t p ry P 9 P 311 -024) . The steps below are prudent and are approved. You are not required to notify the inspectors for a witnessed pressure test ( step 3 in your procedure) as this work is only to plug perfs and not abandon the well. The intent as I unde rstand is to isolate the p erfs in order to facilitate a RWO. The perforations will then be re- opened once the tubing is replaced. Please report all wellwork associated with this work scope on a 10-404 as indicated on the sundry. Regards, Guy Schwartz Senior Petroleum Engineer 1∎01 h ki AOGCC 793 -1226 (office) 444 -3433 (cell) From: Herrmann, Daniel D [mailto:JD.Herrmann @conocophillips.com] Sent: Friday, March 04, 2011 3 :36 PM To: Schwartz, Guy L (DOA) Subject: 2T -03 Change of Scope after failed CMIT Guy, Perry said that he spoke with you on 2T -03's failed CMIT after we pumped cement to secure the perforations and asked if I would send you an email about our plan forward. The plan forward is we are going to try and re- squeeze the cement job with the same amount of cement at 8 bbls but pump 2 nerf balls before and 1 after the slug of cement to try and help with keeping the cement uncontaminated. I have attached the plan for re- squeeze and the wellbore schematic. Please let me know if you have any questions. Dan Herrmann Wells Engineer! ConocoPhillips Alaska Inc. ATO 1586 Office: (907)263 -4619 Cell: (713)703 -5282 fd.herrmann@conocophillips.com 3/9/2011 • • Well 2T -03 _ Proposed Re- Squeeze Well Suspension ?rip / '/9 'fL" 2T -03 is being evaluated for slot recovery. Currently it has subsidence related buckling and the last drift was unable to get past -350'. The well needs to be secured by pumping cement across the formation to isolate the productive zones due to the inability to test multiple barriers. Proposed Well Suspension Procedure: Procedure Cementing Unit 1. Mix 8 bbls of 15.8 ppg Class G cement slurry, 2. Pump 2 nerf balls followed by the 8 bbls of 15.8 Class G cement slurry, followed by a nerf ball and displaced w/ .5 bbl of Biozan, 30 bbls freshwater & 12 bbls diesel freeze protect. During pumping hold and monitor pressure on the IA to ensure that the cement is not being pumped into the IA instead of to the perforations. Estimated TOC - 7435' RKB Slickline 3. Contact AOGCC for State witnessed Pressure test & cement plug tag. - Note: Due to buckling in the tubing, a drift & tag is highly unlikely to tag the TOC. 4. After minimum of 24 hours pressure test cement plug to 2000 psi then bleed tubing to 0 psi. Record pressures. Drift & tag to TOC @ approx. 7435' RKB. • • 71Alf [U LAMA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Perry Klein Well Integrity Supervisor ConocoPhillips Alaska, Inc. (9 6 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -03 Sundry Number: 311 -024 SkiANI Dear Mr. Klein: NEDFEB 0 4 2 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �, or Daniel T. Seamount, Jr. Chair DATED this ✓ day of February, 2011. Encl. "� w"i • STATE OF ALASKA \ \ k' `;,, ALASKA. AND GAS CONSERVATION COMMISSIO ,�' � APPLICATION FOR SUNDRY APPROVALS IAA" 2 X01 20 AAC 25.280 ` 1. Type of Request Abandon 17 Plug for Redrill ❑ Perforate New Pool 17 Repair w ell ❑ ; ?� g ± sh l edi �i9i€rrnr° ❑ • s! ion 1011 Suspend ❑ Plug Ferforations pi , Perforate r Pull Tubing r YO lrr i tq nsion r Operational Shutdown ❑ Re -enter Susp. Well r Stimulate 11 Alter casing r Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development � r Explorator r 186 -142 , 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20073 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number where ownership or landownership changes: Spacing Exception Required? Yes ❑ No C 2T -03 . 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25569 'ALK 2667 Kuparuk River Field / Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7893 6063,. . • 7776' . 5946' Casing Length ' Size 1 " ' ° MD ND Burst Collapse -',' CONDUCTOR 83 16 115' 115' SURFACE (QC) 3142 12 3174' 2787' PRODUCTION 7863 7 7893' 6063' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7520 - 7536, 7536 - 7561, 7602 - 7604 5782 - 5794, 5794 - 5812, 5842 - 5844 2.875 J - 55 7460 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BROWN 'HB -1' MD= 7435 ND= 5719 TRDP - CAMCO TRDP -IA -SSA MD= 1795 ND= 1771 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/25/2011 Oil r Gas r WDSPL 17 Suspended r 16. Verbal Approval: Date: / GINJ r WAG r Abandoned r Pp /•�1'� - / WINJ ❑ Commission Representative: Ci 5J #z GSTOR ❑ SPLUG 17. I hereby certify that the foregoing is true and corr to the b t of my knowledge. Contact: Perry Klein Printed Name erry Klein Title: Well Integrity Supervisor — Signature Phone: 659 - 7043 Date 1/22/201 Commission Use Only Sundry Number. 3‘\...03(4 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity [YBOP Test ❑ Mechanical Integrity Test r Location Clearance r Other. Subsequent Form Required: D _ tD e.( APPROVED BY ' F / 3/ I Approv N COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 1/2010 7 /- ., Z_ ORI G I 1 V A L y Submit in Duplicate • • ConocoPhillips RECErv :� Alaska O P.O. BOX 100360 2 8 / ,i ANCHORAGE, ALASKA 99510 -0360 't s m Abs. 1Q Jan 25th, 2011 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a 10 -403 sundry request to plug the perforations of 2T -03 PTD (186 -142). ✓ Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ® KUP 2T -03 Co 1ocoPhillips Os l Attributes fax Angle & MO TD B) AL I• l : W.Ilbore API/UWI Field Name Well Status I ncl (•) MD (RK Act 8tm (808) ConocoPhillips 501032007300 KUPARUK RIVER UNIT PRODUCING 50.37 4,200.00 7,897.0 - `' Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date • Wen conn9. - 2T - 03 529000932005 PM SSSV: TRPD 60 1/11/2009 40.00 9/14/1986 Schematic - Actual Annotation Depth (RK8) End Date Annotation • Last Mod By End Date Last Tag: 7,532.0 8/272002 Rev Reason: ADD NOTE triplwj 529/2009 Casing Strings - - - -- - ----- . - ----- ---- - - - -- a - - - -- String 00 String ID I Set Depth Set Depth (TVD) String Wt String Casing Description (In) (In) Top (RKB) IRKS) (848) (I6./R) Grade String Top Thrd CONDUCTOR 16 15.062 40.0 115.0 115.0 62.50 1-1-40 at I �SURFACE 958 8.765 0.0 3,174.0 0.0 7,892.0 2,787.1 38.00 J-55 PRODUCTION 7 6.151 6,063.1 26.00 J-55 CONDUCTOR, 115 Tubing Strings String OD String ID Sat Depth Set Depth (TVD) String Wt String _ Tubing Description (In) (In) Top (RKB) (MB/ (RKB) (11m/ft) Grade String Top Thrd - TUBING 2 7/8 2.441 0.0 7,460.0 5,737.0 6.50 J - 55 EUE 8RD SAFETY VLV• 0 A8 - MOD 1,795 Other In Hole (All Jewelry: Tubinf Run & Retrievable, Fish, etc.) Top Depth (TVD) Top Inc] Top MKS) (81(8) (") Description Comment Run Date ID (In) GAS LIFT, - 1,795 1,771.1 27.78 SAFETY VLV Camco TROP -1A -SSA 10/17/1988 2.312 2,846 _ -- 2,840 2,555.7 48.73 GAS LIFT CAMCOMBMG /1/GLVBK/.125/1236/ Comment: STA 1 6 /3/1998 2.371 4,935 3,980.7 46.83 GAS LIFT CAMCOMBMG /1 /GLVBK/.188/1319 /Comment: STA2 6/3/1998 2.371 SURFACE, 5,972 4,690.8 45.84 GAS LIFT CAMCOMBMG/1IGLVBK/.25/1419/ Comment: STA 3 6/3/1998 2.371 3,174 6,322 4,933.1 46.47 GAS LIFT CAMCO/KBMG /1IDMY /BKI // Comment: STA 4 5/25/1998 2.371 6,703 5,196.4 44.69 GAS LIFT CAMCOMBMG/1/OVBK2 /.25/ /Comment: STA5 6/3/1998 2.371 GAS LIFT. 7,052 5,443.9 44.79 GAS LIFT CAMCOMBMG /1/DMY /B0/ Comment: STAB 5/25/1998 2.371 4,935 g.. 7,377 5,676.1 43.15 GAS LIFT MMH/2 7/8 X 1.5 /1.5IDMY /RK/ // Comment: STA 7 6/3/1998 2.347 I 7,418 5,705.9 42.04 PBR Brown 10/77/7988 2.500 7,435 5,718.5 42.00 PACKER Brown 'M &1' 10/17/1986 2.500 GAS LIFT. 7,449 5,728.9 41.96 NIPPLE Camco 'D' Nipple NO GO. Set 2.25" CA-2 5/25/98; pulled 10/17/1986 2.250 5972 ? 5/27/98 7,459 5,736.3 41.93 SOS Brown 10/17/1986 2.441 7,460 5,737.0 41.93 TTL ELMD TTL @ 7493' during PERF on 07/18/93 10/17/1986 2.441 & GAS LIFT Perforations Slots 6. 322 Shot Top (TVD) Btm (TVD) Den. Top (RIM) etrn (RKB) (8103) (RK8) inns Date (eh -• Type Comment 7,520 7,536 5,782.4 5,794.1 C-4, A -3, 2T -03 7/16/1993 6.0 APERF 2 1/8" EnerJet; (.1-) 45 deg. Phasing 7,536 7,561 5,794.1 5,812.5 A -3, 2T -03 GAS car, 10/17/1986 4.0 IPERF 4" HyperJet II 5.703 7 ,00 2 7,604 5,842.4 5,843.9 A -2, 2T -03 10/17/1986 4.0 IPERF 4" HyperJel 11 No te s : Gen eral &Safety End Date Annotation 8/27/2002 NOTE: CORKSCREWED TUBING @ 1450' TO 7460' """NO COIL'"' GAS LIFT, f 5/29/2009 NOTE: CORKSCREWED TUBING @ 362 ELMD 7 052 l .4 f ____. GAS LIFT 7 _7_ PACKER. 1.435 NIPPLE. 7.449 - - 1 SOS. 7.459 - TTL, 7,460 ■ APERF, 7,520 -7.538 IPERF, 7,538 -7,581 IPERF, - _ - 7.502 -7,504 PRODUCTION, 7592 \ ID. 7,891 • • • Well 2T-03 Proposed Well Suspension 2T -03 is being evaluated for slot recovery. Currently it has subsidence related buckling and the last drift was unable to get past -350'. The well needs to be secured by pumping cement across the formation to isolate the productive zones due to the inability to test multiple barriers. Proposed Well Suspension Procedure: Procedure Cementing Unit 1. Mix 8 bbls of 15.8 ppg Class G cement slurry, 2. Pump 8 bbls of 15.8 Class G cement slurry, followed by a nerf ball and displaced w/ 1 bbl of Biozan, 29.5 bbls freshwater & 12 bbls diesel freeze protect. During pumping hold and monitor pressure on the IA to ensure that the cement is not being pumped into the IA instead of to the perforations. Estimated TOC - 7435' RKB Note: Do not exceed a fracture gradient of .65 psi /ft during the cement job. Slickline 3. Contact AOGCC for State witnessed Pressure test & cement plug tag. - Note: Due to buckling in the tubing, a drift & tag is highly unlikely to tag the TOC. 4. After minimum of 24 hours pressure test cement plug to 2000 psi then bleed tubing to 0 psi. Record pressures. Drift & tag to TOC © approx. 7435' RKB. Page 1 of% 3 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, February 02, 2011 1:41 PM To: 'NSK Well Integrity Proj' Cc: Glessner, Dana; Herrmann, Daniel D Subject: RE: Update 2T -08 (PTD 186 -109) 2T-03 (PTD 186 -142) Perry, Thanks for the update... as you mentioned until you have the well loaded up on both IA and tubing side will be hard to tell if you were successful. If 1 understand correctly you have not tried CMIT's on the two wells ? ? ?? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Wednesday, February 02, 2011 12:21 PM To: Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; Glessner, Dana; Herrmann, Daniel D Subject: Update 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Guy, We pumped both plugs with operational success however are not able to get passing MITTS at this time. 2T -03 has a fairly large leak that might allow us to reattempt the plug. 2T -08 is leaking on the order of 1 gallon per minute at 1000 psi and might prove difficult to retreat. We are in the process of evaluating our options developing our plan forward. I suspect we will attempt to load the backside of the well to better understand our current leak path /s and rates before deciding on a clear path forward. Let myself or MJ know if you have any questions Perry Klein Well Integrity Projects, 907 -659 -7043 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, January 24, 2011 2:33 PM To: NSK Well Integrity Proj Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Perry, We have discussed the wells internally and agree that they should stay as "pluaperfs" for the time being. Based on how the rig workover goes they well status may change to suspended or P &A . Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 2/2/2011 Page 2 of 4 1 444 -3433 (cell) From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Monday, January 24, 2011 1:50 PM To: Schwartz, Guy L (DOA) Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Guy, I've discussed the plan forward for both wells once a cement plug has been placed across the perforations to isolable the reservoir. At this time we plan to attempt a work over similar to past subsidence wells where the tubing is pulled and replaced. The production casing will be pulled and replaced to some point below the suspected damage. Communication will then be reestablished to the reservoir via the original mother bore through some combination but not limited to milling, under reaming , perforating, and fracturing. At this point it looks as if plug perfs is the appropriate check box on the 10 -403 sundry request. On your response I will mail the hard copies to your office. Sincerely, Perry Klein Well Integrity Projects 907 - 659 -7043 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, January 24, 2011 9:45 AM To: NSK Well Integrity Proj Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Perry, v � 4 I talked to Commissioner Foerster this morning regarding 2T -03 and 2T -08. You have verbal approval to plug perforations as outlined in the sundry applications. As we discussed if your intentions are to workover the wells and not sidetrack/P &A we can stay with the "plug perforations" request vs "suspended" . It will still require a witnessed PT and possible tag of TOC. Can you send brief email response on the proposed workover options... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Sunday, January 23, 2011 9:43 AM To: Schwartz, Guy L (DOA) Subject: RE: 2T -08 10 -403 sundry request to plug open perfs with cement Guy, 2/2/2011 Page 3 of 4 • • Thanks for your help. Yes they are very similar in regards to the condition and suspected damage mode. I'm assuming these wells will be worked over and brought back on line, not suspended as was done with the injectors. Thanks for the quick action. I'll touch base with you Monday. Perry From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Sunday, January 23, 2011 9:29 AM To: NSK Well Integrity Proj Subject: Re: 2T -08 10 -403 sundry request to plug open perfs with cement Perry, I reviewed the procedures. They are similar to the other 2T wells we have suspended. We should be able to fast track these two sundries based on the risk potential. I will discuss with Commissioners first thing Monday morning. Regards, Guy Sent from my iPhone On Jan 22, 2011, at 8:33 PM, "NSK Well Integrity Proj" <N1878 @conocophillips.com> wrote: Guy, Please find enclosed an outlined procedure and 10-403 request to plug the perforations of gas lifted producer, 2T -08, PTD 186 -109. The hard copies will be mailed promptly. As discussed earlier via phone on 1 -21 -11 the well has a shallow surface casing leak at approximately 330' and buckled tubing that will not drift for a plug past 250' feet. Recently the well has show signs of tubing by inner annulus communication prompting the need for it to be secured. We would like to pump cement Tuesday morning 1- 25 -11. In the past your office has requested us to attempt to tag the cement top post treatment. While I have left that step in our procedure I would ask that the tag not be a requirement in this well. The state of the buckled tubing is such that we risk a stuck or lost tool string when attempting to drift the well which may further complicate future well work. Thank you for your consideration. Please call or e-mail if you have any questions. A well bore schematic has been attached for your convenience. Sincerely, Perry Klein Well Integrity Projects 907 -659 -7043 2/2/2011 Page 1 of 3 Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Monday, January 24, 2011 1:50 PM To: Schwartz, Guy L (DOA) Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Guy, I've discussed the plan forward for both wells once a cement plug has been placed across the perforations to isolable the reservoir. At this time we plan to attempt a work over similar to past subsidence wells where the tubing is pulled and replaced. The production casing will be pulled and replaced to some point below the suspected damage. Communication will then be reestablished to the reservoir via the original mother bore through some combination but not limited to milling, under reaming , perforating, and fracturing. At this point it looks as if plug perfs is the appropriate check box on the 10 -403 sundry request. , rte On your response I will mail the hard copies to your office. /• 2 4 { - l/ Sincerely, Perry Klein Well Integrity Projects AirinaroU FEB 01 20)1 907 - 659 -7043 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, January 24, 2011 9:45 AM To: NSK Well Integrity Proj Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Perry, I talked to Commissioner Foerster this morning regarding 2T -03 and 2T -08. You have verbal approval to plug perforations as outlined in the sundry applications. As we discussed if your intentions are to workover the wells and not sidetrack/P &A we can stay with the "plug perforations" request vs "suspended" . It will still require a witnessed PT and possible tag of TOC. Can you send brief email response on the proposed workover options... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Sunday, January 23, 2011 9:43 AM To: Schwartz, Guy L (DOA) Subject: RE: 2T -08 10 -403 sundry request to plug open perfs with cement 1/24/2011 • Page 2 of 3 • Guy, Thanks for your help. Yes they are very similar in regards to the condition and suspected damage mode. I'm assuming these wells will be worked over and brought back on line, not suspended as was done with the injectors. Thanks for the quick action. I'll touch base with you Monday. Perry From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Sunday, January 23, 2011 9:29 AM To: NSK Well Integrity Proj Subject: Re: 2T -08 10 -403 sundry request to plug open perfs with cement Perry, I reviewed the procedures. They are similar to the other 2T wells we have suspended. We should be able to fast track these two sundries based on the risk potential. I will discuss with Commissioners first thing Monday morning. Regards, Guy Sent from my iPhone On Jan 22, 2011, at 8:33 PM, "NSK Well Integrity Proj" <N 1878 @conocophillips.com> wrote: Guy, Please find enclosed an outlined procedure and 10-403 request to plug the perforations of gas lifted producer, 2T -08, PTD 186 -109. The hard copies will be mailed promptly. As discussed earlier via phone on 1 -21 -11 the well has a shallow surface casing leak at approximately 330' and buckled tubing that will not drift for a plug past 250' feet. Recently the well has show signs of tubing by inner annulus communication prompting the need for it to be secured. We would like to um cement Tuesday morning 1- 25 -11. p p Y 9 In the past your office has requested us to attempt to tag the cement top post treatment. While I have left that step in our procedure I would ask that the tag not be a requirement in this well. The state of the buckled tubing is such that we risk a stuck or lost tool string when attempting to drift the well which may further complicate future well work. Thank you for your consideration. Please call or e-mail if you have any questions. A well bore schematic has been attached for your convenience. Sincerely, Perry Klein 1/24/2011 • Page 3 of 3 Well Integrity Projects 907 - 659 -7043 <2T -08 10 -403 sundry request 1- 22- 11.pdf5 <2T-08.pdf <2T -08 Sundry Procedure.doc> 1/24/2011 MICROFILMED 9/~ 1/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing Alter casing Repair well Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 117' RKE 3. Address: Exploratory ~ 7. Unit or Property: P,O. ~Box 100360 Stratagrapic Anchorage, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface: 8. Well number: 377' FSL, 556' FWL, Sec 1, T11N, R8E, UM 2T-03 At top of productive interval: 9. Permit number/approval number: 1194' FNL, 1390' FEL, Sec 2, T12N, R8E, UM 86-142 At effective depth: 10. APl number: 1028' FNL, 1485' FEL, Sec 2, T12N, RSE, UM 50-103-20073-00 At total depth: 11. Field/Pool: 978' FNL, 1512' FEL, Sec 2, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7897 feet Plugs (measured) None true vertical 6067 feet Effective Deptl measured 7809 feet Junk (measured) None true vertical 6000 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 234 Sx CS II 115' 115' Surface 3146' 9-5/8" 800 Sx AS III & 3174' 2787' 350 Sx Class G Production 7865' 7" 640 Sx Class G & 7893' 6064' 300 Sx AS I Liner Perforation Depth measured 7520'-7561';7602'-7604' true vertical 5782'-5812';5843'-5844' ,, Tubing (size, grade, and measured depth) F.,; ,;~..: ~.' 2.875", 6.5 Ib/ft, J-55 @ 7460' Packers and SSSV (type and measured depth) Packer: Brown HB-1 @ 7435'; SSSV: Camco TRDP-1A-SSA @ 1795' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 5/29/98. In7f~0,a_l~strs~,ated (measured) 0 RiG IN A L Treatment description including volumes used and final pressure Pumped 241,990 lbs of 16/20, & 12/18 ceramic proppant into formation, fp was 6123 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 515 393 396 1234 298 Subsequent to operation 963 952 646 1143 296 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __ZX Oil X Gas Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~(~. ~ Title'. Production Engineering Supervisor Date ~)/Z-~/I~~ . ..... ~1 IDf~41T IIXI I'"~1 IDI If'ATE' Form 10-404 RE ARCO Alaska, Inc. -'¼UPARUK RIVER UNIT ~, ~LL SERVICE REPORT 2T-03(4-1)) WELL JOB SCOPE JOB NUMBER 2T-03 FRAC, FRAC SUPPORT 0523981826.6 UNIT NUMBER DATE 05/29/98 DAY 3 FIELD ESTIMATE DAILY WORK 'A' SAND FRAC. OPERATION COMPLETE ISUCCESSFUL IKEYPERSON ~ Yes O No ~_~ Yes O No DS-YOAKUM AFC# ICC# I DAILY COST AOCUM COST KD2303 230 DS28TL $146,550 $156,883 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA ITTLSize 769 PSII 2321 PSII 220 PSI 500 PSI 0 PSI 280 PSl l 0.000 " SUPERVISOR SMITH Signed Min ID [ Depth 0.000" 0 FT DAILY SUMMARY PUMPED 'A' SAND RE-FRAC TREATMENT. 241,990# IN THE FORMATION, 684# LEFT IN WELLBORE. TIME LOG ENTRY 07:30 SAFETY MEETING 08:14 PRESSURE TEST TREATING LINE TO 9400#. 08:35 START BREAKDOWN STAGE, 77 BBLS 25 BPM 50# DEL XL GW TBG=8123 CSG=3478 08:41 START 1 PPA 16/20 SCOUR STAGE, 50 BBLS 15 BPM 50# DEL XL GW TBG=6761 CSG=3456 08:43 START CONDITION STAGE, 50 BBLS 15 BPM 50# DEL XL GW TBG=7303 CSG=3307 08:46 START 2 PPA 16/20 SCOUR STAGE, 50 BBLS 15 BPM 50# DEL XL GW TBG=5348 CSG=3302 08:50 START FLUSH STAGE, 50 BBLS 15 BPM 50# DEL XL GW TBG=6001 CSG=3302 08:53 START FLUSH W/STRAIGHT SW, 87 BBLS 15 BPM TBG=6633 CSG=3330 08:59 SHUTDOWN ISIP=1840 10:07 START DISPLACE STAGE, 52 BBLS 5 BPM 50# DEL XL GW TBG=3539 CSG=3178 10:15 START DATA-FRAC, 48 BBLS 15 BPM 50# DEL XL GW TBG=5708 CSG=3323 10:19 START FLUSH, 57 BBLS SW 15 BPM TBG=6409 CSG=3242 10:23 SHUTDOWN ISIP=2019 11:23 START PAD, 52 BBLS 5 BPM 50# DEL XL GW TBG=2138 CSG=3122 11:32 START 2ND PAD, 298 BBLS 15 BPM 50# DEL XL GW TBG=5470 CSG=3329 11:51 START 2 PPA 16/20 STAGE, 100 BBLS 15 BPM 50# DEL XL GW TBG=5045 CSG=3449 12:00 START 6 PPA 12/18 STAGE, 800 BBLS 15 BPM 50# DEL XL GW (400 BBLS 50# & 400 BBLS 40#) TBG=5763 CSG=3467 12:54 START 10 PPA 12/18 STAGE, 200 BBLS 15 BPM 40# DEL XL GW TBG=3987 CSG=3452 13:07 START 12 PPA 12/18 STAGE, PUMPED 38 BBLS 40# DEL XL GW TBG=5502 CSG=3479 13:11 STARTED FLUSH 12 BBLS 40# DEL XL GW & 30 BBLS DIESEL TBG=5699 CSG=3421 13:16 SHUTDOWN JOB COMPLETE. SECURE WELL, RD FRAC EQUIPMENT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $200.00 $200.00 APC $10,000.00 $10,000.00 DIESEL $0.00 $714.00 DOWELL $134,750.12 $134,750.12 HALLIBURTON $0.00 $7,099.00 LITTLE RED $1,600.00 $4,120.00 TOTAL FIELD ESTIMATE $146,550.12 $156,883.12 1. Type of Request: 2. Name of Operator STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION COMMI~I~ REPORT OF SUNDRY WELL OPERATIONS Operation ShutdoWn__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 377' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1194' FSL, 1390' FWL, Sec. 2, T11N, R8E, UM At effective depth 1028' FSU 1484' FWL, Sec. 2, T11N, R8E, UM At total depth 978' FSL, 1512' FWL, Sec. 2, T11N, R8E, UM Present well condition summary Total Depth: measured true vertical 7897' 6066' Effective depth: measured 7809' true vertical 5999' Length Size 8O' 16" 31 42' 9 5/8" 7863' 7" 12. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet feet feet feet $. Datum elevation (DF or KB) 117' RKB. 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-03 9. Permit numl;)er/approval number 86-142 ??' ?-~-? I10, APl number 5o-103-20073 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) NONE Junk (measured) NONE Cemented 234 S~ AS I 800 Sx AS III & 350 ~'x Class G 650 S~ Class G & 300 Sx AS I - Other feet True ve~ical depth 115' 2787' 6063' , ~... 328 measured 7536'-7561', 7602'-7604'~ true vertical 5793'-5812', 5843'-5844' Mcasured depth 115' 3174' Tubing (size, grade, and measured depth) 2 7/8" J-55 6.5#/FT , EUE, ABMOD, IPC Tail @ 7460' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA, 1735', Packer: Brown HB-1, 7435' 7.893' 13. Stimulation or cement squeeze summary Hydraulically fractured the A and C Sands with gelled water and 16/20 Carbolite. Intervals treated (measured) 7518'-7688' RKB Treatment description including volumes used and final pressure Pumped 1,315 Bbls of ~lelled water and 100,220 Lbs of 16/20 Carbolite. Final WHTP = 5300 psis. '14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Prior to well operation 416 288 13 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1351 1262 0 - Casing Pressure 1000 100 16. Status of well classification as: Water Injector__ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~,~.f~./~ -.~~/4'~/~'/'~'-~2 Title SenoirOperationsEn~ineer Form 1¢0-404 I~v 05/17-/89 Service SUBMIT1N DLi'PLICATE ARCO Alaska, In,_ Subsidiary of Atlanlic Richfield Company WELL PBDT CONTRACTOR REMARKS I FIELD- DISTRICT- STATE Ko?/l P~ /( OPERATION AT REPORT TIME WELL SERVICE REPORT IDAYS DATE / j ~'-/v //Io /SiP I~ l -- I~Y~ ( ~ 133o C bLAA6E C~OE j~ .- poqp~' / ,~ $o 1~$ ~p TlP m t' K /rA r~ r~ I ¢' ~ PWI . ~O # l0 ox'. lbs 'A e 5~I ~411Y ' I~ E' F'R A c TaI~ ED s'A~ _b !.~ [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots 0 R ALASKA OIL AND GAS C, ONSERVATION C, OMIv.,SSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing_ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 377' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1194' FSL, 1390' FWL, Sec. 2, T11N, R8E, UM At effective depth 1028' FSL, 1484' FWL, Sec. 2, T11N, R8E, UM At total depth 978' FSL, 1512' FWL, Sec. 2, T11N~ R8E, UM 12. Present well condition summary Total Depth: measured 7 8 9 7' true vertical 6066' feet Plugs (measured) feet ~ 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2T-03 f~. ~-, ,L ,~ 9. Permit number 86-142 10. APl number 5o-103-20073 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7809' feet Junk (measured) 5 9 9 9' feet ~ Casing Length Size Structural Conductor 8 0' 1 6" Surface 31 4 2' 9 5/8" Production Liner Perforation depth: 7863' 7" Cemented Measured depth True vertical depth 234 Sx AS I I 15' I 15' 800 Sx AS III & 3174' 2787' 350 Sx Class G 650 Sx Class G 7893' 6063' 300 Sx AS I measured 7536'-7561' 4 SPF 7602'-7604' 4 SPF true vertical 5793'-5812', 5843'-5844' TVD Tubing (size, grade, and measured depth 2 7/8" J-55 w! tbg tail @ 7460' Packers and SSSV (type and measured depth) Brown HB-1 @ 7435', Camco TRDP-1A-SSA @ 1735' 90 degree phasing 90 degree phasing RECEIVED laska Oil & Gas Co,s. ComnC im- line, rage 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ Fracture stimulate A and C Sands with 1100 BBLS gelled water and 98000 LBS Carbo-lite. 14. Estimated date for commencing operation 15. Status of well classification as: August 7. 1989 Oil X Gas __ Suspended m 16. If proposal was verbally approved ~ 47/- -~ ~ Name of approver .~/~L ,' ~/,~t_ Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~"'~ ¢~ /~ .~-'/~-~-~&/'c'-~'~Title Sr. Operatoins Encjineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test m Subsequent form require 10- '/~)f Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C. SM!TH Commissioner IApproval No. .Approved Copy Returned .. Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Messrs chambers ant, June 27, 1989 Page 3 rdan Kuparuk Well 2T-03 'A' Sand Re-Fracture Procedure Charge Code' K80488 1. Obtain a 24 hour well test. 2. MIRU Slickline unit. RIH with gauge ring. Tag fill. . RIH with Standing Valve and set in Camco 'D' nipple @ 7449'. Pull DV from 1-1/2"mandrel @7377 Install full open CV. Displace annulus with 208 bbls of 9.8 ppg brine. This volume should leave a pad of 15 bbls (500') of diesel in the annulus. Pull CV. Run DV. Pressure test tubing to 4500 psi. RIH and pull SV. 4. RDMO Slickline. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. ** WELL SHOULD BE CLOSED IN A MINIMUM OF THREE DAYS BEFORE THE REFRAC JOB IS PUMPED.** 5. MIRU fracture equipment. . . . Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Lite for fines due to excessive handling. Obtain a sample of the Carbo-Lite and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. Install "Tree Saver" with maximum mandrel I.D. (NOTE: The tree saver will probably need to be set in the 3-1/2" tubing hanger above the 3-1/2" x 2-7/8" x-over collar.) Pressure up the 7" x 2-7/8" annulus to 1500-2000 psi. Pump pre-pad allowing annulus pressure to increase to a maximum of 2000-psi.. Immediately prior to pumping the pad, increase the annulus pressure to 3000 psi, provided the SIWHP is a least 1000 psi. Allow annulus pressure to increase to a maximum of 3500 psi by the end of the pad. Maintain this pessure (3500 PSI) on the annulus throughout the remainder of the job. Pump fracture treatment per the attached schedule. Recommended maximum surface treating pressure is 6500 psi. Record the 5, 10, and 15 minute pressures following the ISIP. Bleed annulus pressure down to a maximum of 2000 psi, before SIWHP declines below 1000 psi. Expected wellhead treating pressure: WHTPE = 4450 psig Fracture Gradient = 0.70 psi/ft Tubing Friction = 320 psi/1000 ft (5849' TVD) (7460' MD) @20 BPM Engineering.If initial pump in pressure exceeds 6000 psi, shut down job and~o~f~ ~i~ ED Oil & Gas Cons, Messrs chambers aha June 27, 1989 Page 4 rdan 8. Rig down frac equipment. Follow attached flowback schedule. 9. After well has completed flowback, obtain 24 hour well test. The annulus can be displaced with diesel when the next slickline operation takes place on this well. No workover fluids are required. No BOP's are required. The estimated bottomhole pressure is 2000 psi. RECEIVED ~laska 0il & Gas Co~s, uommi~io~, Anchorage KUPARUK WELL 2T-03 'A' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6~28~89 ST, aGE FLUID DESCRIPTION CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT BBLS BPM PPG DESCRIPTION LBS DIRTY VOLUME HIT PERFS STG/CUM BBLS I GW PRE-PAD 200.0 20 2 GWPAD 640.0 3 GW wi2 PPG 36.8 4 GW wi4 PPG 46.7 5 G W w/6 PPG 67.2 6 GW w/8 PPG 70.2 7 GW w/lO PPG 62.4 8 GW w/12 PPG 39.2 I 0 SUCK DIESEL FLUSH 46.0 +SV SHUT DOWN 20 20 20 20 20 20 20 20 0 ~ - 0 FOR ISIP 0 16/20 M CARBO-LITE 0 2 16/20 M CARBO-LITE 3087 4 16/20 M CARBO-LITE 7854 6 16/20 M CARBO-LITE 16935 8 16/20 M CARBO-LITE 23591 1 0 16/20 M CARBO-LITE 26225 1 2 16/20 M CARBO-LITE 19770 0 -- 0 200/ 200 50 640~ 840 250 40/ 880 890 551 935 93O 851 1020 985 951 1115 1070 901 1205 1165 60/ 1265 1255 46/ 1311 1315 TOTAL GELLED WATER - 1 1 16.4 BBLS TOTAL DIESEL = 46.2 BBLS TOTAL SLICK DIESEL = 46.0 BBLS +SV 16/20 M CARBO-LITE = Stages 1 through 8 are Gelled Water. Stages 1 &2 are Gelled Water with 40 Ibs/l(XX) gal silica flour and enough breaker for a 6 hour break. Stages 3 through 8 are Gelled Water with 6 hour breaker and without silica flour. Stages I through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 9 should include a volume adjuslment for surface equipment between the wellhead and densitometer. This job is intentionally underflushed by 2 bbl. The Mender tub should be bypassed at flush. All fluids should be maintained above 100° F on the surface. 97462 LBS DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data .., ? / t / / WALTER d. HICKEL, GOVERNOR P.O. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in TI IN R7E Umiat Meridian could be offered for lease. The unleased, land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, IJ~,t. mes E. Eason 'Director cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 1991 Alaska 0ii .& Gas Cons. Commission Anchorage CiS_~ ::f,r,r:~.o ,m mc,,'c:ed paper DEIYkI~T~IENT OF NATUI~AL I~ESOUI~CES D~ws~or~ OF O~L ANg GAS August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 STEVE COWPER, P.O. BOX 7034 ANCHORAGE, ALASK~ Dear Mr. Wood: In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 16, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, ~ ames E. Eason i rector . cc' C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR ARCO Alaska, Inc. Date: July 21, 1989 Transmittal #: 7521 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmilted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 J - 0 2 Kuparuk Fluid Level Report 7- 1 1 - 8 9 Casing 3 J - 0 2 KuParuk Fluid Level Report 7- 1 7 - 8 9 Casing 2T- 03 Kuparuk .Well Pressure Re.port 7- 1 3 - 8 9 Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION; BP Chevron Unocal Mobil D&M State of Alaska ..... K~uparuk Well Pressure Rep~ Pressure Measurement Device: ~:: : 1:3 HP' I~ AMERADA I--1 LYNES : :. :':: :::: :::::: ::::::::::::: ;::: r-l:Other:: ' i :i-::!mrament ,dentlflr. atlon No.: I-1 Torque; TUrn ::: Calibration Date: : : .: ~:..: ~:, . - : ;:: ,;:, :7-: ~;:,.:,:,,:~. -: ' '.:::.:d~ ¥..' . ;:C:::: :::.::Type of T~t: .~ Static ~ PBU Sand: . , Final -' -: Datum Time : . :::. WL 1: ~D- I TVD- 'Upper ~ Loweri .. ' . :~hxlmum ~O~'d:Tempe~tU--:~. ~. Operation./Englneering-2;2 -, //~ ~' Repre~entative ~ STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION ---/J~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of Well Classification of Service Well OIL [iX GAS [] SUSPENDED [] ABANDONED [] SERVICE []. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-142 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20073 t. ~,, .,_~ u 9. Unit or Lease Name 4. Location of well at surface !, h' ~ ~'~ ~ - ~ ~l'?~' 377' FSL, 556' FWL, Sec. 1, T11N, R8E, UM :; ~ ~,'~'~'~ ~'- ~ ~ ~ ~ ~ ~ ;'j ~ ~ ~ ~' ~ ~. 1~' J~ Kuparuk River Unit At Top Producing Interval ............... ~- ~r~...? ~- ~ ~r 10. Well Number 1194' FNL, 1390' FEL, Sec. 2, T11N, R8E, UH ", '~,''' ,-,~". , ; i ;' .- ,~ ~ 2T-3 1 At Total Depth ii ~ ',~ i', ,~: ~ !~ ~:~ ,., .~:~ :¢ .. ;~.~ ~, 11. Field and Pool 978' FNL, 1512' FEL, Sec. 2, T11N, R8E, UM I~ ~;'-~ ~ ........... Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 117' ADL 25569 ALK 2667 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/05/86 09/11/86 12/23/86* N/A feet MS L 1 I 7897'MD 6066'TVD 7809'MD 5999'TVD YES ~] NO [] 1795' feet MD 1550' (Approx) . 22. Type Electric or Other Logs Run DIL/SP/SFL,FDC/CNL, Cal, GR, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 234 sx CS II 9-5/8" 36.0# J-55 Surf 3174' 12-1/4" 800 sx AS Ill & 350 sx Cla~s 7" 26.0# J-55 Surf 7893' 8-1/2" 640 sx Class G & 300 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) 2 -7/8" 7460 ' 7435 ' 7536 ' -7561 ' MD 7602'-7604'MD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 5793'-5812'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5843 '-5844 'TVD See attached Adder:lure, dated 1-1.3-87: for Fracture Perforated w/4 spf, 90° phasing 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE m~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None FEB 0 2 *Note: Drilled RR 9/14/86. Well perforated & tubing run 10/17/86. Form 10-407 WC2: 03: DAi;IT~-~- Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE £,,~f 29. ,,. '; 30. ~ '., . .....' GEOLOGIC MARKERS FORMATION TESTS · . : . NAME Include interval tested, pressure data, all fluids recovered and gravity, ~, i.. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ..~ ~.. Top Kuparuk C 7518' 5780' N/A Base Kuparuk C 7533' 5791' Top Kuparuk A 7533' 5791' Base Kuparuk A 7688' 5907' ;-~' · · . 31. LIST OF ATTACHMENTS Addendum (dated 1-13-87) 32. I hereby certify that the foregoing is true and correct to the Best of my knowledge Signed ~..~ Title Date ., INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item'21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). -. Item 23' Attac..hed supplemental records for this well should show the details of any multiple stage cement- lng and the 10cat'ionof. l~he cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- je~tion,~ Gas I.nJection., Shut-in, Other-explain. .- ~ Item 28: If no Cores taken, indicate "none". ADDENDUM 9/13/86 12/23/86 2T-3 Arctic Pak w/300 sx AS I, followed by 60 bbls Arctic Pak; tst OK. Frac'd Kuparuk "A" sand perfs 7536'-7561' & 7602'-7604' in 10 stages per 12/17/86 procedure using Musol, Diesel, 20/40 mesh sand and 100 mesh sand. Press'd ann to 2610 psi w/diesel. Tst lns to 8000 psi; OK. Production Pmp'd: Stage 1: 30 bbls diesel w/5% Musol, 3000 psi, 2 BPM Stage 2: 44 bbls diesel @ 3000 psi, 2 BPM Drilling Pmp'd: Stage 3: 75 bbls gelled diesel @ 20 BPM, 5100 psi avg Stage 4: 50 bbls gelled diesel pad @ 20 BPM, 6400 psi Stage 5: 20 bbls gelled diesel w/1 ppg, 100 mesh sand @ 20 BPM, 6300 psi Stage 6: 117 bbls gelled diesel spacer, 4710 psi, 20 BPM Stage 7: 36 bbls gelled diesel w/3 ppg 20/40 mesh sand, 4800 psi, 20 BPM Stage 8: 46.5 bbls gelled diesel w/6 ppg 20/40 mesh sand @ 6600 - 7000 psi, 15 - 20 BPM Stage 9: 24 bbls gelled diesel w/8 ppg 20/40 mesh sand @ 6800 - 6200 psi, 17 - 20 BPM Stage 10: 42+ bbls gelled~diesel flush @ 18 bbls - 20 bbls, 6200 psi (underflush by 3+ bbls) ' Date ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE December 31, 1986 TRANSMITTAL #5864 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Final Prints: (1 blueline copy unless otherwise specified) 2T-5 "'~'. 5" DIL-SFL-GR 9-3-86 3014-7670 ~5" FDC Raw 9-3-86 3014-7645 ~'2" DIL-SFL-GR 9-3-86 3014-7670 ''~2" FDC Raw 9-3-86 3014-7645 ~'5" FDC Porosity 9-3-86 3014-7645 ~2" FDC Porosity 9-3-86 3014-7645 ~Cyberlook 9-3-86 3014-7635 2T-3 2T-2 ~5" DIL-SFL-GR 9-12-86 3178-7889 x'52" FDC Raw 9-12-86 3178-7863 '-~2" FDC Porosity 9-12-86 3178-7863 '~2" DIL-SFL-GR 9-12-86 3178-7889 "5" FDC Raw 9-12-86 3178-7863 ~5" FDC Porosity 9-12-86 3178-7863 ~Cyberlook 9-12-86 7350-7850 X~Cyberlook 9-26-86 8300-8670 ~2" DIL-SFL 9-26-86 3561-8778 ~2" FDC Raw 9-26-86 3898-8752 2" FDC Porosity 9-26-86 3898-8752 ~5" FDC Raw 9-26-86 3898-8752 ~5" FDC Porosity 9-26-86 3898-8752 ~5" DIL-SFL 9-26-86 3561-8778 Receipt Acknowledged: DISTIBUTION: NSK Drilling Vault (film) Rathmell D&M L. Johnston (vendor package)~. ARCO Alaaka. Inc. is · Subsidiary of AllanticRichfieldComplny ARCO Alaska, Inc. Extension Exploration ~TRANSMITTAL TO: Bill V _ ADDRESS: , 3001 Po[cup!ne FROM: Crai ~ _ ~ DA TE: _~%~~~~~_________ Transmitted herewith are the following: Well Oats //- 9-12-86 Ir~ .Tape Open Hole 3160.0 4100. Kuparuk 2T-6(K-lO sand~) <~/2~/~... 3J~d~- ~/~ ~-21-86 Lis Tape Open Hole 387~ - ~210 Kuparuk 2T-8(K-lO sands) ~-22-86 Lis Tape Open Hole 29~8.5 - ~000.0 Return receipt to: CONFIDENTIAL ARCO Alaska, Inc.~/ Extenstion Exploration ATTN: Lucille Johnston P. O. Box 100360 Anchorage, Alaska 99510 A NO - ~Tq g RECEIVED Processed By: L. dohn~r Alaska Oil & Gas Cons. Commission Anchora:qe October 22, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60071 Well: 2T-3 Field: Kuparuk, Alaska Operator: E. Sellers Survey Date: October 12, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note that a magnetic tape of the survey will be sent to Standard AK Prod. Co., Exxon, and Arco as per request of Jo Ann Gruber. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures Oil & Gas Cons. NL Sperry. Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 A N Ii;:: H O R A G E A L. A S K A ARF':O AL.A.::,k.A, 'i'Nc~ .......................................................... DATE ElF SURVEY OCTOBER 12~ 1986 '-'" ~ q - '-'°' ..... - '"' "C I" · .'I-._ L~:L']MPU]"AT~ON DATE BUoo 13YRCi~.:L. JP]_. SURVEY KLIPARLIK OCTOBEER 14: 1 9:'_-'16 dOB NLIMBER I~ilC]~lBO'"'~,~iOl(~i~:tS;!::iI i!:[:!:'!i:' ii.fl:: ............... AL..ASI<A I<ELL..Y DI...ISHINC~ ELEV. = 117.0()F:""I'. ........ ..................................................................................... 0 F:'E; R A T 0 R- E. S E L. L E R S VE'.'I:~I' ~ (Z:AL SEC:TI ON I.'.'. Al....I] ..................................... ~~ ~-.,k~ .~..~ ........ ~s ................... '.. K)~): )~.~!~:[ :?::~:~ ::&~;: :!: ~(4:~ :!. DE".'F:'TH ........ i]Ejl¢"I];JLI .... DEPTH [)El'.Si M I N [)EOIR EEi;.'.-7:; DEL-ii/]. ()() I',IOR'TH / S(]L.ITH E-'AF;'T / WE;F:T SECT I r/.'lN ............................. 10 C) 200 :300 4()0 5()0 6 (") C) 700 800 900 10,:]) () ]. 1 ()() 1200 1400 1500 m'"'l: · Z'-Z' 16 (') 1700 ~ .. 17._,0 1800 1900 ..... 2000 '210 0 22 (:) 0 2:300 24()0 25 (Z) 0 ;'.-:.' 6 C) 0 :2 '700 (). 1 O0. 200. 300. 4()0 ,, 500. ('D() '-"-' O0 0 5 ,'-',.--,, N I :E:. ._"::':).. W (]), 10 O, 0'7 N O. 0:3 E O. o,.., O0 l'::"-:' O0 0 7 S 79:7::0 W () 1=i 0 1'-' · . . .............. c, N 0 09 W 0 16 oo ....... 2e,::'-.': :'66 ..................... i":) ........ 7 ......... :i;.'i '--'i":~: - :~.::~ w ' ' 6":':['!:i'! ......................... iS-;'iS-f-" A ...................... ~'.5'] :'Si:Y-~- ........................ '/'i_ ....... ,, :-(7: 0() .'.'ii:8:3. ()0 C) 8 E', 77. :39 E 0.20 0. 12 '..:.'i; 0. 1:3 W -(). ()4 1 C) 5;' 9. :26.': :l 1 ':78. ,68 .l 494.42 1 54:2' 84 1590. '7 1/_-, ;.'-': 4. 1775 47 , ,4. F,"-, . .,.= .... o.47 1 :::61.8/_-. 1744.86 ' 1'i:',45., %!4' ....... i-'.?,~'f:~flT'~"-~-- ...... 34 ?-':4 N 16.80 W 2 (3' 26.6'.-::' 15:'(_')9.6'.::.;' :36 2.'i: 0 N 16.3'? W 21 C'5. :2,'7 19:.-33. :37 :39 .':5 :/ N 18.8("D W 2 :t S,::,. '5 ~ ..... ~i:"ig!~,:'5~ ..... ~? .... ~-i ............ N' ':['~;': 60 w -';, 9 El'.-:' 6'? '-' "" = /_-, 9 5'2 . _. ....... ,'1..: ..... 44 N 20 :--,::) W :';..::::::'i?o. 'P,:':: ":?::~:7:.::.','.":~':"i, ...... ;.f,i;:; ...... !5!~-,; ..... Fi 'i-'i;;Te.o w 245'.-:). 5 L:.: 5':' 342. 5 :::': 46 47 hi 1. 9. 19 W ,:':.:. CDC). (") C) 48:3 ,, 0 (':) (:) 1 :.5: Iq 56. :59 E O. 1 '7 C). 0:3 :i:-'; o. :L '? E .... (]) . 1:1. .... 0 09 '799,'.:)9 ,/_-,Fq2,'....-~9 C) 4(;.) N 56 ='(' . , . . .... ,.) 1,4 (') 64 C) Od.-, N 0 03 W 0 77 ::: .... 99 .9.._'::' 7 F.: 2 .9. 2 :.5:.::'"' o =' N 5. 6 . :30 W z'-'. '75 ~.'>. 8 :.5: N 3.00 W 3 .9. 1 o.::;.o ................................. x-.'7 ...... nn?..:. ~/.7 .................... '2i. ....... ?5< ....... N""'!:~;,'...] hC'i w ........... -i' L'¥7 ............................................................................ 6. 9 ::::2 -':. c, '": ..... ~: ......... ::::.'--: N 54 lC) 1,4 1 0(") 11 71 N 16. 10 W 17 '""-' ...... . .. . .. . ~ . ,, ,'", / ... ]. ('D',::: :1. , 6. :::::._ ,..,/-!:--,_ C). N ..."::'::'~.., 5 (3 W .,..9 · (')...... '21 '''-~. . 15]... N 2:3. ::: 1 1,.,I ~:: c,. 04 ..... i 186. ?6' ...... i/E: ' '!;j:~i ..... N ::-':2', :~:O~ ~ ............... %"0'i ................ ~i6-':"iS?::'"'Ki 1":' '-. . "' N . =7.-; 45 9 51 N :31,.'?,c) W 1.24 4:3 69 N 40.zZ W ,_7 4C) · "q - '~' "> 'q ""'-' ' '-D '~' '-"-"~ " 1._77.4.~. 1-_, 1._ N .,-..". 1; W o.o; 6t.~... Y N .-,0..'., W 7/,oo .................................................................................................................................................. _-' ......................................... 1 4.7.,,:..] 8 4 15 5:/-., N :2:7::./-, ('D I,,,I =' 5; ":, .... 7:2.' 1 '= N '= = '7:3 W ::::':~ 81 14. 73.7:---: 1 '7 '2:'-'.: N 17. 0 W 5. 18 85.4 "74- ....~ 61:3": '7-4- ........... 2~4 ....... 5;?7 ........ ~'-'£i_=-:-Y~i{~-~ ................. 6:"(~i~ ................. ~ i~'7,-5 · .o 4 N I6.'?~9 W 6.72 15~. 15 N 7..°. 06 W 177.66 q':' '-"-' . . 227 · _.~_ ~:.:, N 18.10 W 4.40 207 20 N 94 ~.~. W 15 :P. :2:(.") 1.7:_:: 2.89 2:. 24 1 · 96 0.77 O. 50 · .~,p;o :--:5: N 11(-) '=' = W 281 41 :315.42 N ]. 5:7. 12: W :.5::38. :}.': 1 :374.20 N 145. :3:2 W . :395>. O:L'-: ................................................................................................................................ 43/_",. 49 N 167.52: W 4/-_,4.26 501·50 N 191.2(]) W 5:32.81 /-,,'_:: /_-,4 N '--'16 44 W 6:3.'.!:.. :::: 7 N 241.6. 705.44 N 265.':;'A W '748.09 · ~ARCO'- AL AsKA ~ 21'-3 KUF:'A R UI< I NC. ::E; F'" E R R V."'-:ii!; U N W E L I .... S I.J R V E V I N (';~ C 0 M F:' A N Y F::' A F:i Iii.:. DATE OF SURVEY OCTOBER I":,~, 19'~6 COMPLITATION DATE BO:SS GYROSCOPIC 'SURVEY OCTOBER 14: 1':';'-'"":. oo ,_lOB NUMBER ..... K~!?!.-:Y BU;.-:,';H.! NC! ..F!.::g~,. ......... ~ ........ !..!.5../]..,..(;!(! .1F'T?~ 0. F' E R A 1" O. R - E. ":;:- E ..... L L E R"-'.:, ..................................................................................................................... V E R T I C A i .... :!ii; IE C 'T' I ('3 N C A I.... C I..I L A T E j[I A L. Fi hi ('-'i [;.'.: L. 0 :.::; I_11:-~ E TRUE SUB-SEA COLIRSE COLIRSE DOG-LEG TOTAL MEASURE[.~ VERT I CAL. VERT I L. AL E;EVER I TY D E F' T H D E.'. F' T' H ][.:l E G / 10 DEF'TH INCLINATION DIRECTION I) E:. (3 M I hi D E G R E E S 2 F..: ()0 252 :iii:. 0:3 24-1' 1 '2' ('!i :5.: 4.6 4'!;:.' N 18. :39 W (2}. 58 2,.:.~00 ......... -::,:.'.i',-.w...'""6s: .... 5!4 f~;i~"/"-:;:,,-, .......................................... 46 5'5. ................................................................. N 22. ~ 0 W z-. 7 .l o4.:,'~ '-' 66 N '- =' '"' --- . 7,:> N :3 () 00 :266 E. 79 .d..., 4,:::. 79 46 4 N 21 · ':: 9 W 0.66 909. ' "" ':'100 ";'7':'Ffi. :36 261:3.36 4..=; 4/', N 20 .69 W (2) ._,~-'-:Y 976 8::: N ................................. 314.61 W -"-'-' ~ .~-~:. 17 :341, :39 W 964. (2)4 ..:, :, 7, 19 W 10:35 :':-:8 3:2 C.) 0 ;fi:g 0,:1.. 94 :3:30 () 28'74.46 :;ii', 4 C) 0 2 '!? 4 ,-1- ,, 52 35 C.)O :"4 () 1. 5.2' 9 :3600 :3086. ,14 ::::700 ':' 1 =~b 5-2:3 :380 0 .89 :39 00 5.:291. 1. 7 4. 00 {':) :7::35 ::}.','. '79 41'i5i5' :_::4'-:'=; "=;':' 4-2 0 0 :34 90.4:2 430(:) :3554, :7..'5 ................. 44-0 0 :361 ',!::~. 81 45 O0 36. E: 4.51 4600 :3 '7.'.'51.29 4700 :3819. :32 4 :':: (-) 0 "-' '-' '-2 -'. _. .:,,: .... / :_.::7 49(')(") :3956.3:--: 5000 4-0:;::: 4.7 :/ · ='; .... 1 (')C) 4-092. ,..,':' ,..,':' 52:0(') 4160. 78 '6~ibi) 42'2e :'4E: ' 5400 4296, 02 · : .-,(), ) 4:36 :z:. 44 P;,'.:, c)c) 4431 ' !:i', 4' 57 00 4500.4-2 26 :ii!:'7 ,, 94. 46 :7: N 20. 6, () W 2757.4. 6 45 ,'.'51 N 2c). ~ 9 W 2',iii: 2 '7 ,,.'.!":, 5',._: ......... 4 f::; 12 hi ';::' (3.50 W 2::3'.:.> E:. 2 9 4 4 41 N ':.!: 0. 19 W 2'F, 69.44 44 :35 N 17. :39 W 0.2'i? 1044.04 hi :392. !52 W 1106.65 0.21 1111.2'?) hi 417.::i:'7 W 11'7'7.96 (). 66 1:1 '7 :iii:. 09 Iq 44:2:. '.:)8 W 1248,, '7,'.':, 0. ?;../-,_ 12:44 .3 :L:: N .467 . ...=; ._F, W 1 .z,"" 18.82 1·77 1:310.82 N 490.19 W 1388.20 ::::::(')::: .5 :::_ 4 ::: 48 N 1 ._,. = fi_ (-). W 4 . :::_ 9. 1670 .~,._-, ~-'-' N 5./.,_.,.,.7., 74 W 174 (').. 26 _. :Z.~ I',l1 ,, ~:., (") W :_-{ 5(') 174:3.09 N ._,,:,._,, 72 W 1815. 16 :~ 4 ::l 7 "" r r= 1- ,:, - - ...._, ._,.) 1,., N 21. :50 gl 1 46 1':'15· 16 N 612 74 W :}.': 5(':, :[. 81 49 17 N 25. I (') W .... ' rfi ' '7. f:; l 48 5:4 N '26,. :.--.:0 W -'" .- CC,- . :36:34. '2'.:.;" 4'7 :37 N' -.'::.,9,50 g ':":';.z, -'7-'1: .4'_) .,::.. -::.:;.z, ..::':; ............... 4 6 o 71 ,:,';7 ........................ N 7.-;...:, .z':4-. '~__'~E,_, (j, ............ w :':: 77 ("). E: 7 46 47 N 3:2', 60 W 3839.33 46, 48 N 32.69 W ....... !~: !~3 i5 ?":':z'i ............... 4 i~,' ..... i~;:~i ............. iq'"-::~: ~..'-: :-?.-f,:6-i~ ' :3975. F:8 4'7 9 N :32.89 W 404:3. '78 4'7 18 N :3:2. :::9 W 4179.0'2. 47 o._~'-"-' N o..'-"-'. 89 W 4246,. 44 47 c,'-"-:7 N 32.80 W 4:7:14. :2/:4 4/-, ;~8 N :':::4.. !50 W 4 :_::83 ,, 42: 4. 5 48 hi :36. 10 gl .:)':: 1 '""-"::' ".:' 9 Iq 64".;.' 9"::' W 1967 6, 4 .' .... I::l I::l .,.I I ,~ . · · .~., I . 47 1955:3.08 hi 67 El, 90 g 2042, 98 '.22 2(:) 18..68 N '710. 9'....-/ W 2117. :}.':8 ':'- 40 --,-g · ...(.),~ 1 49 N O. 16 :.--"142, 86 N _ , '"'>"~,-) (') (2)7 ~.zl. 4 · 24 N 0. 11 2 ':.':' /', F; . 6,(-) N O..'.27 2:327.07 hi 0.14- 2:788.71 N 748·71 W 2190.54 787.88 W 2263.09 827.21 W 2:335.72 8 E, 6.6,:3 W ';34 (")8, 4.1 '? 06. :37 W 2481.2';:' 94. 6.2!5 W :2554.41. O. 28 2450.40 N 98/:,. 39 W 2627.7(2) .~..~ ~._I2 21 N lC)26.60 W 2701 1 :::': ':~ :::::' :::" :~:'~; - ":, ~ 7 Zt · '":".=; _ · _ 0:": 1 ~ ~. .... .-._ N 106/-,, 66, W 2774 /-.'.-7, .... ! ,,.52 26,:35. :3 U N 11 (2)'7, :33 W :2:34'7. '71 1.."5;2: 2694. :'::6 N 114'3:'. 10 W 291 ..:7:, :38 · ARCO ALASKA; :.':-r-3 I< LIF:'A F;:I...iI< :ii!; F::' E R R Y -'.-'_':; LI Iq W E I.... I .... :.'.::; IJ R V E Y I N C:i C O M F:'A N Y · ANC:HORACq:i: AL. AS1.:::A iNC. ' COMF'UTATION DATE OCTOBEF;: 14, 1986 F:'AGE :3 DATE OF' SURVEY OCTOBER 12,, 1'5'o6 BUo._, OYRu:=;L:JPIC SLIRVE¥ ,J 0 B N t.J FI B E R A K- B O- 600i~i':t;.;i:::'.:i't,:::i;.,i;/::: ;(i.::,:.'::,:: . K EL. 1... Y BI..ISH I N(.:i E L E V. =: ~. 'i '7l 0 0 F'"r. ..................................................... 0 F' I.:.": R A T 0 R-" E. (:; E I.._ L E IR S ...................................................... I"RUE ..e ........ _',,-L.::: ........ 7'?_ .......................... 7.'_E2_L .... ...... ] ..... ----...:._1 ..... I"IEA::;I IREB VERT I C:AL VERT I C~L I NC:L_ I NA'f' Z ON Ii ]' REC T I ON .:,EVER I T Y REL. q AN oLILAR C, UURD I N~ T ES;: ':' "'.". ::.:';?. ::'.i? ':?MERT [ CAl.. I]EF'TH F~E F:'I"H I)EF'TH DE"G M 1' N I]EGREEFi; I]ELS / J. ()0 IqORTFI/SCIU-rH EAST/WEST SE:CT I ON 6000 470'P, 86 6100 47'7'.:.':.', :32 ,:.!:, 2 () O 4',3,'/. 8,, 4. :2 (':, 3 0 () 4 ? ]. ';7. ::i!~ 5 ,, · ..... 4' ......I # ,. /% .... 60 ("~ ._,'= 12 :'::. '7 '? 6700 D ~ '.-:~:3.6? 4/-,A2 '""-' 4A .1:2: .. - . ..'),,:2 4'7 :i!', :[ ~';![!:if .................... ;:!i?.-i: !:i!!i' ........ ¢,.i' ?.:,, :::_::0 t4 480 () '"'' . .: ..... 4-6 :;2:9 N :37, ]. () W 4',F:6'.:). 21 46 2'7 N :;ii','7 ,, :30 14 4.'.:.'~:38. 'i:i'2' 2~ ~;:;_. ...... ..,::' F,... ....... hi:37 ./-", ()'14 5006.7'F~ 46 :'::0 N :7::7.80 N 5076.69 44 4-7 Iq 40. ('~ 14 c). :L 5 C) ,, 25 C), 15 0,25 0. i 7 :3 () 41.04. N 1. 405. 'PS W :':::34. 5.81 :7:: (:)'P 8. '79 N 144'?. '7'!.:~ W :341 '7. :34 '- ~ N 14'.~) 3 91 W .:,4,:,,:,. """" ,:: 1 ... 6, 40 '-' '"'''-' :':.::2,-.: 1:3.84 N 1 - = '"~: " .--, 6.:, 0.54 :326 W ,, 4 · 6, :300 5:2,<.., 4,6'7 /_,,:.? (-) (..1 c::..-., .--, ,":. /., :[ ....... I.Z .'.._ . 7000 54 C) 6 ,, 4:3 7 i 00 5477. '29 7.20 (') . 5 ._ 4 ,:,. .,:. '"' ... '-' 7:300 561 ?. 61 740 C) ~ F,'::/":.,. '20 75 C) (") 5'7,S/.:, ,, ]. 0 76 C) 0 584 C.). '78 770 O' 5916. :--/' 7800 5'F~'P 2. :36 7,':-:':.-/7 /-, 0 6 6 . 18 .:, 14.'7, ,"!:,'7 44 4,S N '41. () W 52 4. 4 , ... :l :-':!',. 61 51 Iq 4 :[. W ....~::;.,";' ...... ::::'::~., 4-:;ii: 44 ...,'::',-:,'"' N 41 . 1 '::).. W ._,.:,6(.). 9;5 44 .... 4~i ...... iq.. '41 ,'~.'.~ 'W 54:31.22 44 50 N 41.6C.) W 5502.6, l 44 :3 N :'::'P. 80 W C). 7 C.) :3 :':: 2:3. C)'."; ..... N 1/-, 28.9 .":: .... IAI :'-':/- 99 . .,::"-' ~".J C). 0 :--: :2:::.:'76.24 N 16, 7.5. 16, W :.376, 7.8 ./:, 0. 1 'i.'"~ :7:: 429.44 hi :l '721. !5.;'7 W :2::3:7:: 6. !=;6 O. 39 .:,4,:,.::. 3:7:: N 1768. '.-,9 W '::9c).=, 13 0 ' ''"' ':~ '= ''"' =' OC) N 1 .... (.),:, o 1 '= 1:3 W .-,,:~'7.'-, , . .:,; , .;, 5~:, ._ .j .:~ ,_~ I 4?/ '-'='-"-' 07 N 1 '-' c . ,:,.., o,:, .o6 .). 7'..-;' W 4041. ,:,'-'c_) ............... --'/ 6,:2 564'.-7~ ]. (") 4.1 4'.-.-/ hi :3:1. :}.':0 W :2 77 :::/-, 9 ::: '.:)'.-.-/ Iq]. '.? :..:.: 9 ~ 2 W 41 / .:,. II:.- .'".~. ..... · .. · -- -- # .- .. . ..... · .: 7.,.- .:,. '78 41 :"::::: N :31 1 (") W (') :31 :2:7 P;.=;', 8:3 N 197:3. 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'.F_'; U I":~ ~ I!: Y T I".1G F: r'_' I',"ll::' :'."-~ N Y I'" (:.': (3 El:' 4 DATE OF SURVEY uL:TuBER 12, 1.. ..... C.:OMF'LITATION DATE iD i:.".: Ti.-_l B E F,' 14 1 o,-':,- , .:-o,.:, ,JOB NUMBER AK-BL'I-C, OOT.~.!,~':~: ~,~: .... KE!:.,L~Y E:: L! !-:i.H .! I',!!~....~.L.E~.., ......... :..-'. ........ !..!.Z..,,.. (?9..F.!:'T,, ............................... 0F::' !~ R A T 0 F::,: -.-L-T..:, .. '.i,.:': F,.,,L !;,:.,E!.;.!~,i.,-3,,;, I F~ JE ~,LIB.-~,EA ................................ ~!'i!._-.!....T.A...L_. ...................................................................................................... ;'?. ?:??,i~!i!ili!? ?.? P'I I!i.:. (:l'.i:; LII::;: E:.': i'i VIZF:;~'I" I I:'.:F'--/I._ VE:I'RT I [~FAI .... F:;,: E: C: 'l' (..l lq l:S l...I t... ¢-.11::;: I'":1.".)1::1t:~ I211 N (.:/"l'E G.; M D.--'I'VD VEEI'R'I" l I.-'.:~.! ................................................. DEF'TH f) E: F:' T' Ft DF.F'T'H NORTH / SCH_H"H E::F/'.S'T'/WE.'. S;T D I F:FEI:;tE:NC:E COI::;:F;:EC:T I FiN 4 C:, 0 (.".1 5 0 0 () 6000 7 C~ 0 0 7 Er.:.? '7 .. 2 ./:,,'.':, 5.7'.:z :37:!5 (.:.:. 7'i:? 4024.71 470? ~ ,'.:-::6 5406,. 4:2,' /::,06,6,., 18 "I"HE: C:AI....C:I_II_~'T' ]J ON F:'F;..'CH::EDUF;tE:'..:.i; F4f-~E: DA:.:;Ei:D ON 'T'HE." L.IS;E: OF 'T' FI F;.: E E: I)IMENFi;IL-iNAi... RF~KIII..I:L-:; [')F: C:I...IRVF~"I"I_IF~E:': ME"T'HCq:). :iii;F::'IEF:;,'RY-..::::;I...II',I WI:':.:.LI_. :[:.;L.IF?VEi:YING COMI::'ANY A N C H r'.l R A G E: A L. A :.:_; K A ARco ALASI':i:A., ']:Nc:., .,:: '1 -..:, C:OIdPUTAT l' ON DATE KUPARLIK ¢IRTF~BER 14 1 A L. A S K A .............. PAGE....,'::' DATE OF ._~JRVEY OCTOBER 12, I'.~86 ,_lOB NUMBER K E L L Y [-.'{1_1 b-.; H I I',1~:~ E L E V 0 R'I.:.: R A'l'Ol::~--I:-:. 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()0 17 3 4 :1. 717, 00 1 ::34 7 1817, O0 :_:i[F'E-".F:'<RY-.:.-:i:L. IN WEL. L Sa..IRVEY I NG CF~MF'ANY A N C.: ~'j ':_.'! F:~__A. gi.[~_.. [~. L.__A_2:-.'~ ~_2::_A_ .......... hR'CO nE'A'SkA,'" NC:. :2l'-:3 KI IPARUK .... :-. ..................... . ............. · A I.... (~ :.:,'.'~ K A F'AGE I.'.:OMF'UI"ATION DATE ................................................. OC:]i.OBER 14., 19L~/:, DATE OF SURVEY OCTOBER I~, 1986 ,JOB NUMBER AK,BO~,O0.7.,1.....;.: ...... KE:I_L.Y BU'..'f.:H I Iq(,~...[..-..-,!...:..E...;.V....,. ......... ~ ........ .I_I....Z..,,..(.).!~!....F:"T',, OEE. RA I"OF(-..E, I NFE:R~:O~'~.ED V~LLIE.::, FUR EVEN It)(:) FEET i_IF .~!_IB-.=,E~ DEF1H :. ::.,:: : . . ...: .............................................................. - ._...` ,. ......... _ ................................................................... .. I"1E-_' ~ :i..:;l...ll::~ [E .i:.J.'l VEF'~ T I CAI .... VERT I F:AL. F;:IEC.: TAN(3 L.II..P,R L' 0 L- I:-~D I N .F.~'I"E ?:; MD- I"VD VERT I DE F"F H D E!: F:' T H ......... 'Ei'E: F~'iYH N 0 I-'.;: T'H/'..3 F.) LI'T' Fl E A'._:;'I" / WEE S;T I_') I . '-' ~,_-,. 1-_, . '-'"') 241. 19 N 1C) 4 9:':: W . 19 6 5 1917 0 0 1 ,:,(.)(.. C) O .... 4,:, 7 0 '=' ' "" ' 20:.:.:7 2017. O0 1900. O0 308. ,":38 hi 1.~""=._.,, 11 14 70 . '.". ~...":' '--' 1....=,, ,:..":' 1 .1. 7.00 .'2000 . C) 0 ~.'q,=,"" ,.,'-". 48 N 148.9. 9. W '?. ::::...~.'.-' 1 27 .24. :2:'7 :.2:-'2:' 2 51 292 '.:.:' :2:61 :30'7 :.2: 271 :_::2: .1. 7 ::;ii:.:/: 1 '7 ,. O0 :': 5:4:, c.) :25', 17. ;':) () :3.5C):.]3: :.:.::(55) ]. 7. O0 :]i64:.2: ....:31 ~ ? 2 ]. 0 0 ,, 0 0 4 6:3.4:3 N .1. 7 ::3. '?.=; W .1. :32. ::: :2 :34.61 ........... 7 ..... 1 :.5.': 4 2. :36 7 ,:'~,,:':, '..--':'::: F~,O (') 0 6/-, 2 '74 Iq 4 ~":; /-, 9' 2 .= ',:":'. 9':.:-' [.,,I ':.? 5: 0. :3 '7 · " ........ " ...... " .... 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() 0 1 ]. !5:2. 1 :.3 I',J q. :3:3. :2'7 N 44. :3.9 4 4:3.5 (: "::'9(') (') 0 0 12 4.5.'; ':)2' N 4 6 ::3 ]. :':: H z ,-',,=' 4 .............. 4,: ....... ] 41.. 47 40, o ..... ,z, 4 14 .J ." ,: .... :300C). O0 1 :'340.2:3 N 4,F,:s:. '-' ='"'F '29 '-":' :2:100.00 1444.65 N 521.84 14 o7~.73 46.44 :37:::9 :.3217. (")0 :'39 :'3:3 :.2: :3.1. 7.0 0 40 :-37 ' :.'3417" 00 4 2 4 1 "-":: ]. '7 0 C) ..2, ...I u .. ~ 4:3 9-7 :3 61 '7.0 0 4S4,? · ,.-: ,=,. '7:3 W 6:21.21 4,_. 4 :.2: ..56.(). 22 W /::,7 (), 0 ]. 4 :.:.:, ::::0 .5 9 ~!:. 51 W '72 4.6',3 ]54.6 7 /5,45!:. (")4 W 76:<:). 22 ...,'-:=._,..q4_ 692.59 W 8:32.02 51.80 ',:.!: F'E F:.t R ¥-S I.J N 14 E L L. S LI R V E ¥ 1' N G C 0 H F:'~ I',1Y A N C H O R Ai3 E A L A S K A 21'--3 COMPI.JTn'I"I ON DATE KLIPARUK OCTOBER 14~ 19F::6 F'~GE 7 D~TE OF SURVEY OCTOBER 12., 1986 dOD NUMBER .~.K-BO"~6,0O:~,1,1:.i!::iil;'.i;::,:::',,. ................... I<E L I.... Y BIJS H I N(3 ELI-- V, = 117. (') 0 F "1', 0 F' E R A ]" F~R-- E. S E L. L. E:' R :_.:; MISASI._iF:;~EF.i I)E:F:'TF.I 46 96 4842:1 49;::;::~ 5 '>' I~~ .'"1 i'", -'- ....I ..-:. ,::.", I'~ ..... zl'..:, 1 ~ ,-.- .~ ,.~ · _, ..., / ;:. 5:E:66 6C.) .,1. 61 !54 62'P'.:.;' .A444 6590 67:32 68¥3 7C) 1 4 '71 7 :~ a ,.~,' ' V F";F:~'I-I CAI .... VERT '[ CAL. F:;,'EC ]'A NGLII.... AR C.:(](]R D I iqA'T'ES ND-TVD VERT T CAl... DEF:'TH DEF'I"H IqCIF;~ T'H / S OLI'T'H EAST/WEST If I FF'ERENCE: fi OR F:.t E[C:'I" I ON 4 2 ]. 7. C) C) 4:31 '7.0 () 44'i'7, OP 4 6 'l 7.0() 4 717.0'0 4 :'2:1 '7.0 C) 4'? ]. '7. C)() ~1~' ." · .., 017. C)(") 5117. C)O 52:17. C.)0 5:317. C) 0 I::." ! ....... I-17. ()0 5517. C) 0 5617. O0 :::04.59 W 9'25. !54 45.92 '::' 6:2 22 . ..... W 971 '71 46.17 ':..;' ".:.: C). 5,r) W 1018, 4. :3 46.77 ':).. ",;', ':;'.., !:~ ..... :':: 14 106 ,,'.'::,. (") 1 ,..1. 7 . ....._,':'i'.':, 0:3'.:.:'. ()6 14 ].-I 14.0'....':/ 48. ()7 o.~,:~:"/i.i~:' u ............ i'1 .~j.'5:"i:i'~ ..................................... 47' : ............................................................................ '::',6 159.15 W 1206.78 44.73 :21'9 '=/ .. ..... ,:, W 1249 ""'-' · ,:,..:, 4:3.0.=;, 52 () o. C) (':) :'3 :]-: 62 ,, 26 N ]./-, ..../-, :::. C) :2_' W 1 ..., = ._,='-'c,. 75 4 C). '.-.'./0 5:30 C). C) C) ::ii: 4:3'7. :7:8 N 1 '7'28.5:L:: W 15'P 7. '.94 4-1. I '? 5400 ,, 0 C) :3.511. 7'.--..' N 1 '7'P 4.52 W 16:38. 'P 8 41. C) 4 = ='")'" 00 .:, ~,:,,t_ 14 N 1 ''"' '= ''" ':":',' _ . ,:,._, .".~ 18 W 1679.37 40 ...,; ._1 ._ I..I __I I · SF:'E:.IRRY-.fi~LIIxl WEI...I.... SURVEYING COMF'AIqY ANCI..~ORAGE AL.A'.:;KA ARCO 2T-.'":3 COMF:'UTATION DATE ALASKA DATE OF .:,URVEY OCTOBER 12~ PAGE 8 1986 M E A S I...I I:-~ Ii.:.': L] D E F' T F.I 74. :3 3 7568 7 '700 7 8:3 2 7' :3 9 '7 ]'NI"E;B .Eli VAI_UES FOR EVEN 1,0o FEET i-.iF Si..IB-SEA DEPTH :?~:?,ilil;iJ'~ii!i',i;S?:'~i?lil!! ;~!i~iii , "i"R!:::!E ..... SLIB-:SEA .............................. "[; 0 ].'_~..[. ........................................................................................................ ?i:;:;:i!.?::i;: :'~ VERT I C:AI .... VERT I CAI .... I::;~EC: l"Al'q(:iilJ L.. AR C '.] ')RD INA l'lS.::i'_:; M 13-." 'I"VD VERT I CAI .... ...... DEF']"H ......... I~!.E!Z"?H . . NORTFI/SOUT'H EAfi:'I"/WEST DII..:'FFERENCE CC~f;~RE:C:TION ................................... · ~:'; ....... ::: 17 ,, 0 () 5 7 () O. 0 0 :3 7 3 7.8 3 N 19 6, :5:. 0 9 W 1'7._, =' .... 1. ]~ L:: :3 4.4 9 591 .-? .- o" o~ ............. ~.:.-_'.. :: _":, o o ....... o7...---_o ..................... .- -'-"7_'. .'. '_"_'___. 5 :.'.. . . . '~"_'o 1 .>..:, .................... .1. hi .,:.:'::. o:_..:o ...... 6. ?.:: .1. .......................................... W ! 7 o::'~'::L..._-, - '_'...'2L."-' ,--, .................................. :"'"_..'_':~.:, ,:.. Z ._, ........................................................ 6 0 :l 7 ,, () () 5'? () O. 0 () :}.': 8:5:8 ,, :l 4 hi ':ii: 0.4 7.7 4 W i. 815. :.}.':'7 :31. :3 9 6 (')4!:,6..1. 8 5'i74'i~). 1 :iii: :3 'P :;..'.-: 4 ,, 'i74 N2C)/:: '7.8() W :[ 8:30.82 1 5.44 THE c:nLC:UL. ATI ON F'ROCEI)LIRES t li:;'E 'A"i~'I'I;,IE'AR ..... i'N'T'ERpr]I n'r'l ON BE!"I':glEEN .................................................................................................................................... THE: NEAREST :20 FOOl" MI] (F:ROM RA[I II..I'.i{; CIE CI..IRVATI.JRE) F'OINTS C") C,.') ~.. . .. 71% i C',O ...... !::.'; F:' E: IR R Y -. E; LI N HE:I...L :F.i;I...IFi:VEi:Y I I',IG F.:OFIF::'ANY F'D~GE '.? %~-., ..- ... ARC:O AI_',~.SS.;Kn ~ ' ]: NC: ~ DATE OF '-~ I'~ ._LRVEY 2T.-:3 CI:]MF'LITA'TI ON DAI'E : i'!:iUF'~IR!J!:'il OCTOBER 14, 1986 JOB NUMBER AL..F.~Sk:'F.~ KELLY..BUSH I Iq,3.. EL:E.V....... ............ =. ........ .1....!..? ... . O !?. FT. OF'E-'RATOR-E:. '.--.:EL.L. ERS 75.'.5:3 5790.69 75:1-':3 5790.69 '76 :.-7!::.:3 ~5907. 1. 2 ' 7700 FS'il) :1. 6,, :2 !!5 7 E: 05? !5999. :.:i: :l 7897 60/_".6 ~ 18 5.673.69 3717.79 N 1950.96 W BASE I.:::LIF:'ARLiI-::: C: · '56.7:3.69 :3717.79 N 1951("). 9./:, W TEIF' I.:::LIPARLII-::.' A · 5790, 1. 2: 7:805:.;. 91 N 2002,, 9 ]. W B~q:.'.-'J:E: I-:::I...IF:'F~F;:LII.::; ('.'.'~ !.579 9, 2-:!5 :3:.'.:.': :£ 2, '7!5 N :200 6.6:3 !/,I S I..IR VIEE Y DI.:.'iJF' T I.--! f::' ~-i ~'"~ --' , :, ':', <. ,, .'"..il 1:'"iI,51 '? 4, L:i: 2 N ::..i: 0 40. 4 :'~i: !/'J F' L I_.ll]'j B A C:I'::i '1" [I ............................................................................................................................................ 594'.-'..'),'1'8 i..3;i:;!~i;i[':"94' N 2067,:30 W I'OTAL DEF'TH ]DRIL_I._EF:~ · .-., FRA f I GRAPH I C SUMMARY .... [~IV__ELL_I " .... USING ~.IL [EI-TH~:,~ '-' " .... ANELSF'ERRY oLIN '"I~,LRVE~- DATA · ~ : ..................................................................................... ]~] ]] ];, ]~.~ T'] 2' ;2 ................................... Ti .................................................................... ,~ .-- --. 2' ]~.--- 7'~ ]~, ]" ]'7 7;,'T :]:. T] 7~: ~ 2' ]7 7.'~ ~2 2' 2'.~.],],2,2,~],];.].].];_]~,]'~ ~- '2.~,-" '~; -- ...................................... ............................. NARKER ............................ MEASURE[) DEP'I"H ........................... T'VB ................. :: .......... THI~Z~i-:::NES:;~: B~TI"J REF. TO WEI_LI~~ -I"OF' I-::]...II:::'ARI...II.::: C 7518 57'7'J) ..... ,,~: . ,~-,~.-,,.-.., ,.. 370?. 24N 1745. '7~3W ................................ BASE KI...II::'ARLII< C 7._,.:,.:, ~::;7c~(') 6'::) 56'73./-,'T~ :3717 77N l'?F() ........................................... TOP KUI:::'AF~LII< A 7 ....... :,..::, 5'7'70.6'? 5673.6'? 3717.7'?N 1950. BASE KLIP~RUK A _T A '::' c'.., ,_, ,..., 5o(")7... . :[2 ~r~79("). ..... 1~ ,:,_,Ex_,. 91N. ~..- ~,. P L U. G B A C K T I) 7809 5 '? 99.21 '='..., "":, c,'-' ~:"". 21 :3874 . ,~'- ~:'-' N 2040.48 W TOT A~..... [fEE P TH [!1~:.]: L:[: ~ R ..... '78'~ 7{ .................................................................. ~?::~.6 ~ .~..!? ............ ':'.2 ..:[ :~.~... ~: '.F'. ............................................................................... .~.:. ~E~Z 4~ .... 1) FROM LINEAR Et'XTRAF'OLATION BEiI__OW I) EEPEL:;T STATION. 2 ) F:i]MFq~.Ii~ER' F'ROI3RAM ...... .................................................................................................... DATA CALCi_ILATION AND IN'[ERPCIL. ATION BY RADIUS OF I_._IRVATLIRE DATE OF SIJRVEY OCTOBER 12~ 1'78,'_'-, COMPI_ITAT I ON [lATE KELLY BUSHING ELEV.= 117.00 FT. - .::,: ?' ~?~?:.: · ]. ............................................................................. 5CqLE ;- 1 INCH TO !O00. CO ~UPqRUK 8CTOBEq ~2. 3. CC ¢°m oo _ . 5CRLE :- 1 iNCH TO 1500.00 / 1500.0 2T-~ q8c8 qLRSKq. 'NC. OCT8BE~ [2. LgsE .. -~. 7897 I - STATE OF ALASKA --- ALASK/ .L AND GAS CONSERVATION COMMI, ON REPORT OF SUNDRY WELL OPERATIONS __ 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~- Perforate ~ Pull tubing _ Alter Casing C Other ~ Comp3_ete 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska~ Inc RKB 117' Feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 7. Well number 377' FSL, 556' FWL, Sec. 1, T11N, R8E, UM ?T-'~ At top of productive interval 8. Approval number 1194' FNL, 1390' FEL, Sec. 2, T11N, R8E, UM 451 At effective depth 9. APl number 1028' FNL, 1484' FEL, Sec. 2, T11N, R8E, UM 50-- 103-20073 At total depth 10. Pool 978' FNL, 1512' FEL, Sec. 2, T11N, R8E, UH Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 7897 'MD feet Plugs (measured) None true vertical feet 6066'TVD Effective depth: measured feet Junk (measured) true vertical 7809 'MD feet None 5999 ' TVD Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 234 sx CS II 115'MD 115'TVD Surface 3142' 9-5/8" 800 sx AS Ill & 3174'MD 2787'TVD 350 sx Class G Production 7863' 7" 650 sx C1 ass G & 7893 'MD 6063'TVD 300 sx AS I Perforation depth: measured _ 7536 ' - 7561 'MD 7602' - 7604 'ND true vertical 5793' - 5812'TVD ~ E C E IV E D 5843' - 5844'TVD Tubing (size, grade and measured depth) ~';u 8 1986 2-7/8", J-55, tbg w/tail ~ 7460' Packers and SSSV (type and measured depth) Alaska 0il & 6as Cons. Commission HB-1 pkr ~ 7435' & TRDP-1A-SSA SSSV ~ 1795' Anchora.qe 12. Stimulation 0r cement squeeze summaryN/ C 0 ~'"I ~'~ !.;' ~ ~-~'i' ,~r ~'~ ~'i~ ¢,.¢ f' ~~L Interv~s treated (measured) ~i,~', l-~a~:~ '~'~ Treatment description including volumes used and final pressure '~ 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History, w/Addendum, dated 9/23/86) Daily Report of Well Operations _~ Copies of Logs and Surveys Run ~ hereby certify that the foregoing is true and correct to the best of my knowledge ~ j([~ - CT~--- .,~ 15. I Signed ~~~ Title Associa,e.Eng,neer. , Date Submit in Duplicate Form 10-404 Rev. 12-1-85(¢ (UAM) bWU/'I'I~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish I Alaska Field ILease or Unit 1 Kuparuk River Auth. or W.O. no. ~Title I AFE AK0707 Nordic 1 cost center code Alaska North Slope Borough ADL 25569 Completion IWell no. 2T-3 API 50-103-20073 Operator I A.R.Co. W.I. ARCO Alaska, Inc. J 56.24% Spudded or W.O. begun Date Complete 10/16/86 Date and depth Complete record for each day reported as of 8:00 a.m. lO/17/86 lO/18/86 Iotal number of wells (active or inactive) on this i DSt center prior to plugging and ~ bandonment of this well I our I Prlor status If a W.O. I 1530 hrs. 7" @ 7893' 7809' FC, Rn 2-7/8" compl 11.2 ppg brine Accept ri~ @ 1530 hrs, 10/16/86. ND tree. NU & tst BOPE. Schl, perf 7602'-7604' & 7536'-7561' w/4 SPF, RD Schl. GIH w/2-7/8" compl. RU 7" @ 7893' 7809' FC, RR Diesel Rn 233 its, 2-7/8", 6.5#, J-55 EUE 8RD AB Mod tbg w/SSSV @ 1795', HB-1 pkr @ 7435', TT @ 7460'. Tst ann to 2500 psi, tst SSSV; OK. ND BOPE, NU & tst tree. Displ well to diesel. Set BPV. RR @ 1230 hrs, 10/17/86. CONFIDENTIAL. Old TO J New TD IPBDepth Jl I Released rig Date J Kind of rig I 1230 hrs. 10/17/86 Type completion (single, dual, etc.) Single Classifications (oil, gas, etc.) Oil Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Gas Cons. Commiss[on Anchorage 7809' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected _ The above is correct ! For form prsparation and Oistribution, sse Procedures Manual, Seotion tO, Drilling. Psges 80 and 87. Date ITitle Drilling Supervisor ADDENDUM WELL: 9/13/86 2T-3 Arctic Pak w./300 sx AS I, followed by 60 bbls Arctic Pak; tst OK. Drilling Supervisor Date ARCO Alaska, Inc. Post Office BOX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records .Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 DATE' 11-7-86 Transmittal #5819 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-2 CBL 10-12-86 7000-8786 Run 1 2T-3 CBL 10-12-86 3135-7780 Run 1 2T-5 CBL 10-11-86 3842-7548 Run 1 2T-6 CBL .10-13-86 3400-8007 Run 1 2T-8 CBL 10-10-86 5100-7475 Run 1 2T-9 CBL 10-10-86 2900-6174 Run i Receipt Acknowledged' Distribution' E Naska 011 & Gas Anchorage BPAE(1 bl) Unoci Mobil(1 bl+l se .Drilling(1 bl) bl+ ) Chevron(1 bl+l se) NSK(1 bl) l bl+l se) ~~ L. Johnston(1 bl+l se) Vault(1 film) ARCO Alaska, /nc. *'~' Post Office Box 100360 Anchorage. Alaska 99510.0360 Telephone 907 276 1215 P,E TURj~ TO: ARCO A~SKA~ INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items return one Signed copy of this transmittal. Schl: ' 2T-2 2T-3 DATE 10-08-86 TRANSMITTAL # 5 789 Open Hole Lis Tape plus listing: 09-26-86 09-12-86 Run #1 Run #1 Please acknowledge receipt and One COpy of each Receipt Acknowledged: D. ~etherell.~Schl Pkgs. Date: ARCO Alelka. Inc. is · Subsidiary o1' Allar~licRtchfieldComp·ny STATE OF ALASKA ALASKA ~,~L AND GAS CONSERVATION COMMIS...,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown ~ Re-enter suspended well -- Alter casing -- Time extension ~ Change approved program ~ 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 377' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1386' FNL, 1285' FEL, Sec. 2, T11N, R8E, UM (Approx.) At t~l, d~th ' .... , 1436' FEL, Sec. 2, T11N, R8E, UH (Approx.) 5. Datum elevation (DF or KB) 117' RKB 6. Unit or Property name Ku.o~ruk River Unil; 7. Well number 2T-3 8. Permit number 86-142 9. APl number 50-- 103-20073 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective dePth: measured true vertical Casing Conductor Surface 7897 'MD feet 6077 ' TVD feet 7809 'MD 6011 'TVD feet feet Production Length Size 80' 16" 3142 ' 9-5/8" 7863 ' 7" Plugs (measured) None Junk (measured) None Cemented 234 sx CS II 800 sx AS III & 350 sx Class G 650 sx Class G & 300 sx AS I Measured depth 115 'MD 31 74 'MD 7893 'MD True Vertical depth 115'TVD 2802'TVD 6074'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 0 9 i986 Alaska 0il & 6as 0ohs. Com,,m[ssio~ 12.Attachments Well Hi story 13. Estimated date for commencing operation~~i~ih~if 14. If proposal was verbally approved Name of approver J~ ~'i ~ ~ ~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~t~ ~ ¢'~¢LLL~ Title Associate Engineer Commission Use Only (DAM) SA/122 Approved by Description summary of proposal ~ Detailed operations program ~ BOP sketch Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test .m Location clearanceI ¢: ~._. ,L ;. ~ j_;'. i~ ~"~ ~* Commissioner Date the commission Date//~ Submit in triplicate Form 10-403 Rev 12d-85 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 started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Kuparuk River County. parish or borough North Slope Borough Lease or Unit ADL 25569 Tte Drill Field IState Alaska no. 2T-3 Auth. or W.O. no. AFE AK0707 Rowan 34 API 50-103-20073 Operator ARCO W.I. ARCO Alaska, Inc. Spudded or W.O, begun IDtte IHour Pr or status if a W.O. Spudded I 9/5/86 I 1300 hrs. Date and depth as of 8:00 a.m. The above is correct 9/06/86 thru 9/08/86 9/09/86 9/10/86 9/11/86 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Complete record for each day reported 56.24% 9-5/8" @ 3174' 3330', (3280'), Drlg Wt. 9.7, PV 12, YP 11, PH 9.0, WL 8.4, Sol 10.3 Accept rig @ 0930 hrs, 9/5/86. NU diverter sys. Spud well @ 1300 hrs, 9/5/86. Drl to 801', DD & surv 12¼" hole to 3185', s--~ort ~p] c-~-~rc', TOH. RU & rn 79 its, 9-5/8", J-55, 36# BTC csg w/FC @ 3092', FS @ 3174'. Cmt w/800 sx AS III & 350 sx Cl "G" w/2% S-1 & .2% D-46. N~ diverter, NU & tst BOPE. RIH, tag cmt @ 3072', DO cmt & flt equipment + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 3330'. 836', .4°, N4.4W, 836' TVD, .28 VS, .31N, .01W 1575', 15.1°, N25.6W, 1568 TVD, 86.60 VS, 74N, 46W 1857', 28.4°, N18W, 1830.05 TVD, 186.87 VS, 171N, 75W 2359', 43.3°, N19.5W, 2233 TVD, 481 VS, 453N, 172W 2958', 46.5°, N22.7W, 2652 TVD, 905 VS, 855N, 319W 3130', 45.8°, N21.3W, 2771 TVD, 1029' VS, 970N, 366W 9-5/8" @ 3174' 4587', (1257'), Drlg Wt. 10.3+, PV 25, YP 25, PH 9.5, WL 5.4, Sol 13 Drl 8½" hole f/3330'-3612', circ, mud cut f/9.7 - 8.1. Drl to 3706', circ, mud cut to 8.1. Raise mud wt to 9.9, drl to 3769', packed off. Circ, raise mud wt to 10.2, drl to 3830', packed off. Circ, mud cut to 9.2. Drl to 4587'. 3546', 44.6°, N21.9W, 3064 TVD, 1322 VS, 1244, 475 4229', 50.7°, N17.5W, 3523 TVD, 1813 VS, 1733, 598 4512', 49°, N24.1W, 3705 TVD, 2028 VS, 1934, 678 9-5/8" @ 3174' 7050', (2463'), Drlg Wt. 10.5, PV 25, YP 27, PH 9.0, WL 4.6, Sol 15 Drl to 6143', circ gas cut mud 10.3+-9.6 ppg. Drl to 7050' (raise mud wt to 10.5 ppg @ 6143'). 4701', 46.8°, N30.5W, 3832 TVD, 2168 VS, 2059N, 742W 5351', 47.6©, N3OW, 4274 TVD, 2644 VS, 2470N, 984W 6317', 46.8°, N34.3W, 4938 TVD, 3342 VS, 3059N, 1365W 6779', 45°, N37.7W, 5259 TVD, 3671 VS, 3327N, 1560W 9-5/8" @ 3174' 7787', ([737'), Drlg Cons. &. C--.~s Wt. 11 PV 21, YP 18 PH 8.5 WL 5.2 Sol 19 fil~S,,i~0'~l-- Drl & surV to 7269' POOH to 9-5/8" shoe, rn LOT to 12.0 ppg , , fin POH. Chg B~L~, RIH, drl to 7787' 7194', 44.8°, N39.6W, 5553 TVD, 3958 VS, 3556N, 1743T~,~FI~F~iT~A/ .~CO 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 indefnite or appreciable length of time. On workovers when an official test is not required upon completion, repod completion and representative tes[ Jata in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish State Alaska North Slope Borough Field Kuparuk River Auth. or W.O. no. AFE AK0707 (-ease or Unit Title ADL 25569 Drill Alaska IWell no. 2T-3 Rowan 34 Operator A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun IDate I Spudded Date and depth as of 8:00 a.m. Complete record for each day reported Old TD Released rig 9/12/86 9/13/86 thru 9/15/86 API 50-103-20073 W.I. [Total number of wells (active or inactive) on this Jcost center prior to plugging and J 56.24% Jabandonment of this well I JHour J Prior status if a W.O. 9/5/86 ! 1300 hrs. I 0400 hrs. Classifications (oil, gas, etc.) O±l Producing method 9-5/8" @ 3174' 7897', (110'), C&C Wt. 11.4, PV 24, YP 14, PH 8.5, WL 5.6, Sol 19 Drl 8~" hole to 7897', CBU, 10 std short trip, CBU, raise mud wt f/Il - 11.4 ppg, POOH. RU Schl, rn DIL/SP/SFL/CAL f/7895'-3178', FDC/CNL f/7985'-7300' & GR f/7895'-1000' Schl. RIH to 7897', C&C. 7877', 39°, N24.5W, 6062 TVD, 4413 VS, 3942N, 1985W 7" @ 7893' 7897' TD, 7809' PBTD (0'), RR 11.2 ppg Brine CBU, POOH, LD DP, spot 65 bbls LCM pill @ 9-5/8" shoe, fin POOH & LD DP. RU & rn 193 jts, 7", 26#, J-55 BTC csg to 7893'. Cmt csg w/500 sx 50/50 Healy Fly C1 "G" w/4% D-20, 2% D-46 & .5% D-65, followed by 150 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/299 bbls 11.2 ppg brine using rig pmps, bump plug. ND BOPE. Make final cut; well started flowing on 9-5/8" x 7" ann. Re-set BOPE. Arctic Pak w/300 sx AS I & 60 bbls Arctic Pak. WOC. ND BOPE, NU tbg spool, adapter & 3".vtv.. '~ RR @ 0400 hrs, 9/14/86. ~giii'¥ ~ 7809' TD 7809' PBTD JDate Kind of rig 9/14/86 Rotary Type completion (single, dual, etc.) Single J Official reservoir name(s) J Kuparuk Sands Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedu[es Manual, Section 10, Drilling, Pages 86 and 87. ARCO ALASKA, INCo Development GeoSc| ence TRANSH I TTAL- _ ADDRESS: ..,~/9 6 / ~,~'z~z~, i~,' ~-~P. % . Transmitted herewith are the fol~owing:. ~/~-//~z~S ~/ ,~-/2- Fl. DATE RECEIPT ACKNOWLEDGI~NT: Return receipt to: AR~O Alaska~ In ~1B~Oil & gas Cons. ~ommission Ex~en~t~on Expl/~~on/ ATTN' Lua~Ile fJohnsCo~ ANO-8~E. ~. o~ Box ~oo~,o / _ ~.: :';: .. :: .' : - ~: -..~ .VlEMORA 'DUM Sta* , of Alaska ALAS~ O~ A,l~q) GAS CONSERVATION CO~VR'~SSION TO: C.V. Chat~t¢~7~__~- DATE' September 10, 1986 FI LE NO.: D. EWS. 48 THRU: FROM: Lonnie C. Smith Commissioner Edgar W. Sipple, Jr. Petroleum Inspector TELEPHONE NO.: SUBJECT: BOP Test ARCO Kuparuk 2T-3 Permit No. 86-142 Kuparuk River Field Saturday, SeRtember 6, i986~ I traveled this date from Conoco ,~lilne Point, s~.~dt Of~a~{Juher report, to ARCO Kuparuk 2T-3, Rowan Rig 34, to witness a BOP test. The drilling contractor was on a short trip to run casing. Sunday, September 7, 1986: The BOP test commenced at 6:00 p.m. and COn~clUded-at 8:00' p.m. There was one failure. See Remark section on the report. I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the BOP test on ARCO 2T-3, Rowan Rig 34. Attachment ALASKA 0IL & GAS CONSERVATION COMMISSION B.O'.P.E. Inspection Report Operator. ~/~ ~u J r-t Location: Sec / TI/~ R~.M Drillin~ Contractor ~O ~7~J Ri Location, General ~ ~ Well Sign~____~ General ~Housekeeping. ~P f~- Rig Visual Audio Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack A~u~ ~ Pr~.event er Blind Rams 0&, Choke Line Valves H/C.R. Valve O~ K~I ~n~ Valves ~ Check Valve Weii ~2-?~ ~ 'Representative Test Pressure '30o,o ~0o O Test Results: Failures Permit ¢ ~/~Casing Set t.( Representative ACCUMULATOR -SYSTEM Full Charge Pressure ~'~'--psig ~? '~.,~"'' Pressure After Closure /~O psis I ~OO .Pump incr. clos. pres. 200 psig '/ min ¢'0 sec. Full Charme Pressure~Attained: ~ min~sec. N2 ~/¢~i 2%~0 ~., ~¢ 2~Zopsig Controls: Master '~¢ ~(~A ~r(k (..~) Remote */~ Blinds'switch cover Kelly and Floor Safety Valves Upper Kelly ~?~ ¢~est Pressure ~ ~O o Lower Kelly ~'Test Pressure ~00 Ball Type ~~est Pressure Inside BOP ~--'~Test Pressure ~ooo Choke Manifold 4~. Test Pressure ~oo Valves /¢ - No. flanges ~ Adjustable Chokes Hydrauically operated choke ~ ~ Test Time ~ ,hrs. ¢0 Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Remarks: ~ ~w~ '" . ,4 .~ ..': r ~- ,.~..¢r-,,-~,.~:,- · ~ ;,,,., ,. ....... , ~ .... ,~. :.... I ~. , $','.rXP ~ /~ ., y'~.... '" Distribution Inspector orig. - AO&GCC cc - Operator cc - Supervisor July 24, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kupa~ak River Unit 2T-3 ARCO Alaska, Inc. Permit No. 86-142 Sur. Loc. 377:FSL, 556'FWL, Sec. 1, TllN, RSE, U~4. Btmhole Loc. 1129'F~.~, 1420'FEL, Sec. 2, TllN, R8E, b~:~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~?nere a diverter system is required, Dlease~ also not~v_~ 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. ~'ry ~tr~lv.~o~urs, / C. V. Chatter~ton Chai~an o f Alaska Oil and Gas Conservation Co~.ission BY O~P~ER OF THE CO~,fISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section Department of Environmental Conservation w/o Mr. Doug L. Lowery STATE OF ALASKA ALASKA ¢~L AND GAS CONSERVATION CC...~VllSSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill .,'2]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry © Deepen []1 Service rs,, Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet ~uparuk River Field 3. Address 6. Property Designation Kuparuk River 0il Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 377'FSL, 556'FWL, Sec.1, T11N, R8E, UM Kuparuk River Unit ~tatewide At top of productive interval 8. Well nu ,mber Number 1386'FNL, 1285'FEL, Sec.2~ T11N, R8E, UN 2T-3 ~8088-26-27 At total depth 9. Approximate spud date Amount 1129'FNL, 1420'FEL, Sec.2, T11N, R8E, UM 08/10/86 ~500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(mD~ndTVD) property line 7742 'MD 129' ~ TD feet 2T-2 25'~ surface feet 2560 (6063'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depthlO00 feet Maximum hole angle45 o Maximum surface I 664 psig At total depth CVD) 3325 psig 18. Casing program Setting Depth size Specifications ~ Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" R? .~ N-~O W~l H R~' ~, ~, 11~, 11~, ~?n0 cf 12-1/4"9-5/8" ~6.0¢ J-SS BTC 3115' ~5' ~B' ~IRO' ?Rll ' 7~0 HF-ERW ~45 Ex Class Ob]end 8-1/2" 7" 26.0¢ J-55 BTC 7708' 34' 34' 7742' 6063' 200 sx Class G(minimum HF-ERW T0C 50(' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate'~-' ~~ '._~ ~ ~~[~'~ '~:~''~~~~~! ~'.~,~-,~¢~t, Perforation depth: measured ~ ~ aa ~ ~ ............ true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ DiverterSketch~ Drilling program Drilling fluid program ~ Timevs depth plot ~ Refraction analysis C Seabed report ~ 20AAC25,050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ S ~.~ Regional Drilling Engineer Signed ' ' ~ ~~~ Title Date Commission Use Only ( LWK } PD/PD299 APl number ~ Approval date I See cover letter Permit Number ~'~ / ~ ~ 50-- / ¢ :~- % o c:-7 3~ 0 7 / 2 4 / 8 6I for other requirements Conditions of approval Samples required ~ Yes ~No Mud Icg required B Yes ~ No Hydrogen sulfide measures ~ Yes U No Directional survey required ~ Yes ~ No Required wor~~~~3M; ~ SM; ~ 10M; ~ lSM Other: by or0or of Approved by ~ ~ ( t~~~~ Commiss,oner the corem,ss,on Date Form 10-401 Rev. 12-1-85 Su 'iplicate KuP~RUK RIVER UN'I T 20" DI VERTER SCHEM~T I C DE SC R I PT I ON · 1. 16" CONDUCTOR. 2. TFNKO STARTER HERD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLING SPOOL N/lO" OUTLETS. 7. 10" HCR BALL VALVES H/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DONNNIND DIVERSION. 8, 20" 2000 PSI ANNULAR PREVENTER. %%% ARCO ALASKA., INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC25.035 (b) MAI NTENANCE & OPERAT I0N UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLON RIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOMNNIND DIVERSION. DO NOT SHUT IN NELL UNDER /~NY C I RCUM~T/~NCES,. 0084002 7 6 I 5 4 3 1 L 2 I 1. 16' - 2COO PSI TAh~C~) STARTING ~F_AD 2. 11' - 3,000 PSI CASING ~r_AD 3. I1' - 3~C)0 PSI X 1~-5/8" - 5CO0 PSI E~AQg~ SPOCL 4. 13-5/8" - 5000 PSI PIPE 5. 13--5/8" - 5CO0 PSI DRILLIh~ KILl. LI~F_S 6. 13--5/8' - E030 PSI DC~ RAM W/PIPE RA~ CN TOP, '/. 13-5/8" - 5000 PSI AN~ ACCLMJLATOR CAPACITY TEST I. C2ECX AJ~D FILL AC~TCR RESE~OIR TO'F~ LEVEL WI~ ~~IC ~UID. 2. ~ ~T A~T~ ~~ IS $~ ~I I~ ~I ~T~ ~ ~ ~~T~. 3. ~~ TI~, ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~T~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~INI~ 13-5/8" BOP STACK TEST 1. FILL BOP STAQ< A.I',I) ~ MANIFOLD WITH ARCTIC DIESEL. 2. O-ECX THAT ALL LOCX DONN ~ IN ~E]_~ AR~ ~Y RETRAC'TED. SE. AT TEST F~,_L)G iN ~E:Li_I-E.AD WITH RL~Ih~ ,J'T A~ RL~N IN LC~ LIh~ YALVES A~CE~ TO E~ STACX. ALL Cr~ VALVES ANO C~ S~ BE C~. 4. P~'~~ UP TO 250 PSI A~ NK]LD FDR I0 MIN. IN- ~ F~.~ TO 3C~ PSI A~ H<I_D FCR I0 MIN. BLEE_O F'RE~ TO 0 PSI. 5. C~,~ A~ PRE'V~hffER ANO ~.,NUAL KILL AJ~ C~E LINE VALVES. ~,_(]S,E TCP PIPE P~ A~ h~ VALVES C~ KILL A~D C~K]KE LINES. 6. TEST TO 250 PSi AJ~ 3(X)O PSI AS IN STEP 4. 7. CCtNTIhJJE TESTING ALL VALVES, LIt~ES, AhO C~S WITH A 250 PSI LOC/ AJ~ 3000 PSI HIG-L TEST AS IN STE~ 4. DO t~DT F:~~ TEST ,~ C¢4C!<E THAT iS .NgT. A .FU_L O_OS].NQ POSITIVE SEAL (~ CZ~LY F~ICIN TEST C~S %~AT DO NOi FELLY CLOSE. 8. C~ TOP PIPE RA~ Ah~ CLOSE BOT'TO~ PIPE RANIS. TEST BOTTCI~ PIPE RAMS TO 250 PSI AhD 3000 PSI. 9. CPEN.BOTTC~ PIPE RA~, ~C3< CLrT RUNNING JT AhO .i0. CLOSE BLIhD RA~ AhO TEST TO 2.50 PSI AhD 3000 PSI. II. CPEN BLIN:) RAW AhO RETRIEVE TEST PLUG. ~ SURE MANIFOLD AkD LINES ARE F'LE.L CF NO~-F~EEZING- FLUID. SET ALL VALVES IN DRILLING POSITICI% . TEST STA~IPE VALVES, KELLY, KF1 LY CCCXS, DRILL PIPE SAFETY VALVE, AJ~D INSIDE BOP TO 250 PSI 3000 PSI. 13. RECC~ TEST IhFC~TION ON BLC~ ~ TEST FC~a~, Sim, AND SEND TO DRILLING ~]Sm. 14. PERFO:~ C~ETE BC~ TEST AFTER NIF~ING LP AJ~D ~EKL¥ THEREAF-r~ FL~t .~q~J2-~L~ ~CP~'TE BOoS DAIL; ;'; ' . i..'" GENERAL DRILLING PROCEDUk~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKERS DE6ASSER HUD CLEANER STIR ~ STIR _ STIR LWK4 / ih TYPICAL HUD SYSTEH SCHEHATIC DRILLING FLUID PROGRAM Spud to. 9-5/8" Surface Casing Density 9.6-9.8 PV 15-30 Drill out to WeiRht Up 8.7-9.2 5-15 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. Lw 5 / ih - -ARCO -ALASKA.- IN ..... .: .. --PAD 2T. WELL NO=-3"PR.OPOSED--"'- ......... ; .................... ~ ................ : .... KUPARUK-FIELD, NORTH_._:_:: ~_L- - - 'F,--__S~OPE'--: AL ASKA ' - ;~===~'-~:~==~'~ _._---_ -_;L_-: ...... --AST. H-N' ]:-NC.:.';:- ;'- - ' '---- ' - ~ . . ~ ~--~ - . ---~-'--~ ? ............................. . ........ _ _ - ................... ~ ............ :- ~ ..... _- -' ~ ..... ~ ........ i ....... '~ ...... i ....... , ........ . !. _ : ....... , .......... . - _ ~ ___ . . !._ : -.-~- - '"- - lOgO:. __I~IP-:_,r_u.n" '.,.,.,=_, ,.,,.,,,---,-,~.,-~-,.....,..-,..,-.... nnn - 'r.n- innnnc'p__._n_i ............ ;' .............. · ; . .... ~ ........ 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'r..'t.~. ,.. ,...,., ,, i.,, , ...... .... ...... ...... f..-,..!t ......... , .... :'"""? ~:T---~ .... ' ~". ~--im---,-'~'m, ,--i ...... --',-'"'"-""t,'--~ i "f-,'F-l"~ .... .---..:--:.-,.--.,i.-,,--? ..... .-,---:- ....... ---'?-'-, ~-'"'~. ...... i,~:~i .... ~ * ~-r'"l''--'-''~'-, : '~-"- '~' ~-+"--~-'i-* .'~. . ........ ~ .~l'. ' I* ~ .... ,.i't"' .... ...... 1] .~ .... '. l,t 1]~, ~ '' f' ' .... '" ..... ' 'IT ........ '~ .................................... ..... ~t t il t~ !i ...... ............. !.- I .~t". t .... ''. i' I, ,. ,,.. , t . .' ........... t I ' ................ !. ' ' t ! ,'" , I i ,'I' I. ; ', ~ ! : i I T · ~, I : i i ' i I : ~ I ' t ' I ,i'~ ~'oo., i . i, ,~'o0~ . '~' '. :. ~ ~, ~0o, .' . , .sod':':',.. ',:,oo ' :. ,I/"o'o, . ;~ ~0o', . ~ i'.,'go"o'.':~ ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2T Pad (Wells 2 - 17) Dear Mr. Chatterton. Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. If Si ncerely, Gruber Associate Engineer JG/tw GRU13/L44 Enclosure RECEIVED - · - ARCO Alaska. Inc. is ~ C'ubsidiary o! AHantiCRiCh~ieldCompany ' ' ~ I 6 LOCATED IN PROTRACTED LOCATED IN PROTRACTED SEC, I~ TIIN.R8E~ U.M. SEC. I ~ TIIN~RGE~ Z - Y = 5,970,382.43 LAT. 70~[9'49.[~87'' [0 - Y = 5,970,[32.65 LAT. 70~[9'46.67]9" X = 498,944.93 LONG.[50°00'30.807'' X = 498,945.Z7 LONG.[50~00'30.796" ~2' FSL, 556' F~L 08 = 77' PAD = 8[.5 [52'FSL, 556' F~L O5 = 76.0 PAD = 8[.7 3 - Y = 5,970,357.42 ~T. 70~[9'48.88~8'' [[ = Y = 5,970,i07.7[ LAT. 70°[9'46.4267'' ~ = 498,944.9[ LONG.[50°00"30.808'' X = 498,945.[0 LON6.[50°00'30.80[" 377' FSL, 556' F~L 06 = 77' PAD = 8]..5 ].27' FSL, 556' F~L 0G = 75.9 PAD = 4 - Y = 5,970,332.46 LAT. 70~[9'~.6372'' [Z - Y = 5,970,08Z.58 ~T. 700[9'46.[794" I ~ , X = 498,944.84 LONG. [50=00' 30.809" .~ X = 498,944.98 LONG. [50°00 30.804" 352" FSL, 556' ~L OG = 77' PAD = 81.6 co 102' FSL 556' FWL OG = 75.7 PAD = 81.7 ~O ~ '' 5 - Y = 5,970,307.5Z LAT. 70°[9'~.3919'' '~ [3 - Y = 5,970,057.59 LAT. 70°[9'45.9336" X = 498,944.9[ LONG.[50°00'30.808'' ~ ~ X = 498,945.08 LONG.[50°00'30.80['' 3~7' FSL, 556' FWL OG = 77' PAD = 81.6 ~0 ~ 77' FSL, 556' FWL OG = 75.5 PAD = 81.6 ' 6 - Y : 5,970,282.50 LAT 70°19'~.1459'' ~ ~ ' ' CO (~ c)14 - Y : 5,970,032.60 LAT. 70°19 45.6879" X = 498,944.95 LONG.150°O0'30.806" ~ ~ ~ ~ X : 498,944.91 LDNG.150°O0'30.806" 302' FSL, 556' FWL OG = 77' PAD : 81.7 ~ ~ ~ ~S 52' FSL, 556' FWL OG : 75.3 PAD : 81.7 7 - Y = 5,970,257.54 LAT. 70019'47.9003'' ~ 0 ~ ~ 15 -'Y-= 5,970,007.69 ~T. 70019'45.4428" X = 498,944.95 LONG. 150°00' 30.806'' ~ ~ ~ X 498,944.93 LONG. 150~00' 30.806'' 277' FSL, 556' FWL OG = 77' PAD : 81.6 ~ 27' FSL, 556' FWL OG = 75.2 PAD = 81.6 8 - Y = 5,970,232.63 LAT. 70019'47.6553" ~ 16 - Y = 5,969,982.85 LAT. 70°19'45.1985" X : 498,944.96 LONG. 150~00' 30.806" ~ ~ ~ X = 498,944.88 LONG. 150000, 30.807" 252' FSL, 556' FWL OG : 76.9 PAD : 81.6 ~ 2' FSL, 556' FWL OG = 75.1 PAD = 81.7 9 Y : 5,970.207.62 LAT. 70°19'47 4093" c) LOCATED IN PROTRACTED X = 498,945.01 LONG. 150000' 30.804" ~ SEC.[~, TI I N~ RGE~ U.M. 227' FSL, 556' FWL OG = 76.3 PAD = 81.6 17 - Y : 5,969,957.72 LAT. 70°!9'44.9514'' X = 498,944.94 LONG. 150000, 30.805" j 23' FNL, c~'~W~ OG~ =,,~5.0~/~,PAD :~ 81.6 ~ m · , ~ ,,-~ ~ ~,. ~.~ ,~ .... L ~ NOTES ~'.~.,?'~; ~;~ ~ :~' ;.,. ;: '~:~ :, I. ALL COORDINATES ARE A.S.R~ZONE4. ~ ..... '.-~ .... . q . 2. SECTION LINE DISTANCES ARE TRUE. ]~'~ ~]~; ~.~ ~. :~ .~:] ;; ~ ~ 3. HORIZ; POSITIONS BASED ON TEME MON~ 2T-EAST, 2T-WEST ~ ~~D~EE ;:P~ ~D~A~SOC. 4. VERT. POSITIONS BASED ON TBM's 2T-6 ~ NI9+75, EI1+52 PER F.R.B. A ASSOC. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-3140 rev.~. ICER~FICATE OF SU RVEYO~; i dEREBY CERTiFy THAT I AM PROPERLY ~ ~ ~_ REGISTERED AND LICENSED TO PRACTICE LAND ~~ =~. : ~ SURVEYING )N THE STATE OF ~LASK~ ~D THAT ~.~ ur . .. · ''' D~TE 18 JAN 86 ~ ~ ~ ~ ~. Siegel ~.~w. w. DRILL SITE ZT CONDUCTOR ?,c ......... ~ECKED SH ~ ~ ~L ~O. OYl~ FIELD ~K F.R.B. e5~I AS- BUILT LOCATIONS 'L~",~'-ZZ-F~- BSSDG, .... ,11 ,,,,,,,,, llDWG. No. NSK 86-6 Arctic Boulevard, Suite 201, Anchorage, Alaska 99503 IlSCAI_E N.T.S. JiJOa ~o. (3) Admin · ;':'1"1"6" (-2 Is well to be lOcated in a defined POOl ' ' ~ · ee eeleeeee~ee.~e®eeeeeeeee ®ce ) 3. Is well located proper distance from property line .................. '(FT_.... ' 7- u,-f49. ('9 thru 13),_ 10. '(10'and 13) / - 12. 13. (14 't~ 22) (5) BOPE (6) OTHER (6) Add: 4 Is well located proper distance from other wells · e~e®e ~ eee e e e e · · · e · · · 5. Is Sufficient undedicated acreage available in this pool . ........... 6. Is well to be deviated and is wellbore plat included ................ 7 Is operator the only.affected party 8. Can permit be approved before fifteen-day wait ........ ' .............. 14. 15. 16. 17. 18. 19. 20. 21. 22. Does Operator have a bond in force ....... ........................... ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is .the lease nurber appropriate ..................................... /f. . - Does the well have a unique name and number ......................... ~ · , Is conductor string provided .., ..................................... Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... · Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required ....................................... Is the drilling fluid program schematic and list 'of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~Od)O psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallcrw gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. ~o___9~: Eng~negring JAL~c~ rev: 07/18/86 6. 011 POOL CLASS STATUS AREA UNIT NO. o ON/OFF SttORE Additional Remarks: ,I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX: .. No special'effort has been made to chronologically organize this category of information. bVP OlO,H02 VERIFICATION blS?lNG PAGE; $* REEb HEADER ** SERVICE NAMg i~PI~ DATE 186/09/27 ORIGIN ~ REEb NAN,£ 1149467 COM~ENTS .BIBRA~¥ TAPE SERVICE NAME IEDIT ~i !86/09/27 ~EvtNUATION , OUSTAPE CO~ME'NT$ lblBRARY TAP~ BNG?H I 1024 rlbE ** INFO'RMATZiON RECORDS MNli:M CON'~E:N?S .... T"', *' ' ~..,~ O0 0 004 o:oo 000 O0~ 0'0 00~002, PRE!, E 000 000 OOl, 065 ********************************************************************************************** ************************************************************************************ ONPANY · ARCO AHAEKA XNC ELb w~T-~ ~OU#T¥ s gu TH SLOP~ BOROUGH STATE s A~ASKA DATE bOGG~DI S~P 8 ~DP £NSX~Y a 1[,4 LBIG RM' = 3,580 9 64 DF. v~sc"oSxTY = 40,0 s RMF ~:~,,.o o 64 r , bVP O~O,H02 VERIFICATION LISTING SCHLUMBERGER LOGS INCbUDED k~ITH THIS MAGNETIC TAP£: CONPENSA?ED.NEUTRON ~,OG CFDN) DATA AVAILABb~t 4]00' TO 3178' '~NTRY',B[~OCKS TYP£. 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