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184-128
Image Project Well History File Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Ma ps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: . ;ch ' Logs of various kinds [] Other BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /S/ Scanning Preparation ~-~ x 30 = BY: BEVERLY BREN VINCENT SHERY~ LOWELL. Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: + ~ = TOTALPAGES ~3 BY: OUNT MATCHES NUMBER IN.SCANNING PREPARATION: YES X BREN VINCENT SHERYL MARIA LOWELL NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: * ~ NO (SCANNING ~ C~PLE~ AT ~IS ~1~ UN~ SPEC~ A~ENTION IS REQUIRED ON ~ IND~UAL PAGE ~S~ ~ ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10125102Rev3NOTScanned.wpd • RECEIVED STATE OF ALASKA FEB 10 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLE ION REPOy-T Abtalaft la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned Suspended, lb.Well Class: 20AAC 25.105 V11 20 C 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG I WDSPL ❑ Other ❑ No.ofCompletions:T' /)9' Service 2 StratigraphicTest III 2.Operator Name: 12.Permit to Drill Number: 5.Date Comp.,Susp., ConocoPhillips Alaska, Inc. or Aband.: December 8,2013 184-128/313-479 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 September 18, 1984 50-029-21159-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 303'FNL,272'FWL,Sec.5,T1ON,R9E,UM September 23, 1984 • 2G-12 - Top of Productive Horizon: 8.KB(ft above MSL): 140'RKB 15.Field/Pool(s): 1354'FSL, 1254'FWL,Sec.5,T1ON,R9E,UM GL(ft above MSL): 36'AMSL Kuparuk River Field - Total Depth: 9.Plug Back Depth(MD+TVD): 1012'FSL, 1373'FWL,Sec.5,T1ON, R9E, UM 7508'MD/6066'TVD Kupuruk River Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-508970 y- 5943285 Zone-4 8167'MD/6613'TVD ADL 25667 • TPI: x-509969 y- 5939664 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-510090 y- 5939322 Zone-4 1795'MD/1791'TVD 2588 18.Directional Survey: Yes ❑ Na❑✓ 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) 2898'MD/2734'TVD 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 none not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 116' 36' 116' 24" 202 sx CS II 9.625" 36# J-55 36' 2884' 36' _ 2730' 12.25" 800 sx PFE,250 sx PFC 7" 26# J-55 34' 8054' 34' 8517' 8.5" 330 sx Class G,250s sx PFC 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/TVD) 3.5" 7514' 7485'MD/6047'TVD perforations cemented off 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. it(1115 Was hydraulic fracturing used during completion? Yes❑ No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED DINED APR 2 8 Z014 7508'TOC _40 bbls 17 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) t.-__, _... .... plugged 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 0 No Q Sidewall Cores Acquired? Yes ❑ No Q 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 1 RBr �iv MAR 21 20 i Form 10-407 Revised 10/2012i/`, r / w -CONTINUED ON REVERSE -NZ 112,1)l`1 Submit original only 7, 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 2898' 2734' needed,and submit detailed test information per 20 AAC 25.071. Top Upper Sand 7494' 6046' Base Upper Sand 7500' 6051' Top Lower Sand 7565' 6105' Base Lower Sand 7718' 6232' N/A Formation at total depth: Kuparuk A , 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.J.Ohlinger a,conocophillips.com Printed Name Lamar Gantt , Title: CTD Supervisor � .. ` ( Signature , ;`t(k1ti A r7` J,jj ,tiW Phone 263-4021 Date 401/74 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 • 0 2 O in 2 w o o "6 1- 2 w 0 m ^Q y o� '- `off o� own2, c•L2 0xc ry as-,m �3a0 w 1 1 ^O o- 0 11 11 Q¢ m 11 11 1 1 w.m II 11 11 0 1-m 11 11 I I « • II I1 1 1 o0 .0 1 I 1 1 I I 1 1 J i t 11 It 1 1 «L .~i m 1 1 1 1 I I I 11 11 II I I II It II 1 I 11II I 1 c- 1j II 1 11 II 1 I I 1I II I I O 11 II II •0 m 1I II II N 4) N 0 1 II II II n _ ^2 ;I 11. II �\ Ea N 11 11 1. N CO v n 11 1 1 @�)\O • CI N V-O `�\ 1I CO CO o N N ` \\ 1 1 Cpl H \\ 1 I -O N V pto �_ o \\ I1 • a0 N I--- C 10 w II 1 CO Ill 0 �\�` C I I I CO � � V V CE ���`` ^�w m 11 11 1 I J ILI 2 d' N E- V a am II 11 11 m U 0 .� I1 '11 11 ll a 11 11 OU - d OU(V 11 11 /I * E N i E C 0 11 11 1 N M CO r= Ip -0 _ 11 1 m O) U M LL o .3- 0 ,I 1 1 (V (V 'CA '-)Y. (V GV o I I I i 11 1 r r N CO r r I I 1 M M M m m M CO o a l'8@,7, \ 1I /, I � ti‘1 II II !1 I/ o. _i "6 U 4/1 co N 1 1111 1 L V NI Op "?0 co V r- N 10- in" ^ t 0. N IM O- in(V G n - CO N o m Q. -0 1 C411 1 =r a p @ N Y co* _0 ID N nCO Nv N Q I io c o ao" r 02 -_J • 2G-1? PRE AND POST RIG WELL WORK PRE RIG WELL WORK DATE SUMMARY 10/27/2013 Tagged Asphaltines @ 7414 SLM; Displaced Tbg w/hot Diesel &Tag Fill @ 7609'SLM (Est. 17' Fill); Drift w/Baker Dmy Whipstock down to 7637' RKB (Confirmed Whipstock Setting Depth of 7580' RKB W/Engr. Ready for E-Line. 10/28/2013 (PRE-CTD) : INSTALLED RE-ENERGIZER JEWELRY, RE-ENERGIZE IC PO'S, POT-IC PASSED, PPPOT-IC FAILED. 10/30/2013 PERFORM BOTTOM HOLE PRESSURE SURVEY WITH A 30 MINUTE STOP AT 7600: 3197PSI/112F, AND 15 MINUTE GRADIENT CHECK AT 7480: 3158PSI/126F. PERFORATED 7505-7507 WITH A 2"2'6SPF, 60 PHASE, 6.7GM BH MILL HMX HSC. 11/5/2013 RIH TO TAG D-NIPPLE AT 7502' RKB, FLAG PIPE, MILL NIPPLE TO 2.80", DRY DRIFT NIPPLE, F/P TBG TO 3000'CTMD, JOB IN PROGRESS. 11/6/2013 RIH TO FLAG, CORRECT DEPTH TO 7502.4' RKB, TAG TD AT 7918' RKB, LAY IN 25 BBLS OF 17 PPG CLASS G CEMENT WHIILE MAINTAINING 1:1 RETURNS, HELD 2000 PSI SQUEEZE PRESSURE FOR 30 MINUTES, CONTAMINATE CEMENT TO 7500' RKB, CHASE CONTAMINATED CEMENT OOH @ 70%, F/P TBG TO 3000' RKB, TRAP 1500 WHP AT SURFACE, READY FOR S/L TAG AFTER 72 HRS, JOB IN PROGRESS 11/12/2013 TAG CEMENT @ 7634'SLM (EST. 54' BELOW TOP PERF). READY FOR CTU. 11/21/2013 RIH TO TAG TOP OF CEMENT TAG AT 7617',PICK UP 5 FT STOP PAINT FLAG 7612, LAY IN 15 BBLS OF 17 PPG CLASS G CEMENT WHILE MAINTAINING 1:1 RETURNS, HELD 1300 PSI SQUEEZE PRESSURE FOR 30 MINUTES, CONTAMINATE CEMENT TO 7495' , CHASE CONTAMINATED CEMENT OOH @ 70%, F/P TBG TO 3000' RKB, TRAP 1500 WHP AT SURFACE, READY FOR S/L TAG AFTER 72 HRS 11/25/2013 DRIFT AND TAG TOP OF CEMENT (HELD 1700 PSI THROUGHOUT JOB)@ 7508' RKB (D-NIPPLE @ 7502' RKB). READY FOR DHD. 11/26/2013 (PRE-CTD): TREE TEST TO 5000 PSI. (PASSED) 11/27/2013 (PRE-RWO): BLEED TUBING DOWN TO 500 PSI. (COMPLETE). POST RIG WELL WORK 1/19/2014 DRIFT TBG W/2.62"MAGNET TO TAG LINER TOP @ 7506' RKB; MEASURE BHP (3552 psi) @ 7500' RKB. JOB COMPLETE. ConocoPhiIIi s Time Log & Summary P Wellview Web Reporting Report Well Name: 2G-12 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 12/4/2013 11:00:00 PM Rig Release: 1/9/2014 8:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/04/2013 24 hr Summary Mob rig from 2G-17 to 2G-12. Rig up equip&nipple up BOPE.Accept rig at 2300. 11:00 18:00 7.00 0 0 MIRU MOVE MOB P Move rig from 2G-17 18:00 23:00 5.00 0 0 MIRU MOVE MOB P Ru equip. Nipple up BOPE 23:00 00:00 1.00 0 0 MIRU WHDBO NUND P Continue rigging up.Accept rig @ 2300. 12/05/2013 Troubleshoot BOPE test, Had to pull BPV&set two wat check.Testing BOPE in progress. 00:00 02:30 2.50 0 0 MIRU WHDBO NUND P Continue rig up/prep for BOPE test. Test waived by Lou Grimaldi. 02:30 03:30 1.00 0 0 MIRU WHDBO BOPE P Attempt shell test. Get stack to 4500 psi but bleeds down rapidly. Troubleshoot. Continue rigging up to BOPE test. 03:30 04:30 1.00 0 0 MIRU WHDBO BOPE T Call valve crew,service tree. Call FMC to get 2-way check coming. 04:30 07:00 2.50 0 0 MIRU WHDBO BOPE T Still trying to get a shell test/not holding/toubleshooting. 07:00 10:30 3.50 0 0 MIRU WHDBO BOPE T FMC on location. R/U/pull BPV and set TWC.Trouble spacing out with extentions. 10:30 20:30 10.00 0 0 MIRU WHDBO BOPE P Continue with BOPE test 20:30 00:00 3.50 0 0 MIRU WHDBO BOPE T BOPE stack test complete. Displace coil with 30 bbls od water. Start testing inner reel valve. unable to get a flat line on low or high test. troubleshoot. Line up to pump full coil volume to get out any air. ****3.5hrs Billable rig repair 12/06/2013 Finished BOPE test(waived by Lou Grimaldi) Pulled TWC from tree. Tagged TOC @ 7507'. Milling cement pilot hole from 7507'to 7538'. 00:00 01:00 1.00 0 0 MIRU WHDBO BOPE T Continue BOPE test,displace air out of coil to re-test inner reel valve. Found Pac off to be leaking, Choke B to be washed out and C13 valve washed out. ****1 hr Billable rig repair. 01:00 02:00 1.00 0 0 MIRU WHDBO BOPE P Test Tiger tank line. 02:00 03:00 1.00 0 0 MIRU WHDBO BOPE P Test PDL's. 03:00 05:00 2.00 0 0 MIRU WHDBO BOPE T Change out C13, rebuild choke B, and replace pac off. ****2 hrs Billable rig repair Page 1 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:00 1.00 0 0 MIRU WHDBO BOPE T Test inner reel valve and pack off. """" 1 hr billable rig repair 06:00 08:00 2.00 0 0 MIRU WHDBO BOPE P Conduct PJSM, R/U, P/T and Pull TWC. 08:00 09:30 1.50 0 0 PROD1 WHPST CTOP P Test E-line and install BHI checks 09:30 10:00 0.50 0 0 PROD1 WHPST SFTY P Pre-Spud with crew 10:00 10:30 0.50 0 0 PROD1 WHPST SFTY P Conduct PJSM for deploying milling BHA 10:30 13:30 3.00 0 62 PROD1 WHPST PULD P Deploy BHA#1 milling BHA with D331. 13:30 16:30 3.00 62 7,310 PROD1 WHPST TRIP P RIH 16:30 17:00 0.50 7,310 7,358 PROD1 WHPST DLOG P Tie into the HRZ correction of-6ft. 17:00 17:15 0.25 7,358 7,450 PROD1 WHPST TRIP P Continue IH 17:15 19:00 1.75 7,450 7,450 PROD1 WHPST DISP P Swap hole to 8.6ppg Power-Pro. 19:00 19:30 0.50 7,450 7,504 PROD1 WHPST MILL P 8.6 mud all around. Shut down pumps, close EDC. 1900 on WHP w/ pumps off&choke closed. RIH,tag TOC @ 7503'. Pick up clean,22 k. RBIH, 1.36 bpm, 3898 psi FS.start milling cement @ 20 deg right. stall @ 7504'pick up clean. 19:30 21:15 1.75 7,504 7,525 PROD1 WHPST MILL P ©7503', looked a little soft on top but 2.16 WOB @ 7505' 16 ROP. Mill down to 7525. 21:15 22:00 0.75 7,525 7,525 PROD1 WHPST DLOG P Pull up to 7300' . Log W/CCL to 7525' . Looks like a+4'correction. TOC @-7507. 22:00 00:00 2.00 7,525 7,538 PROD1 WHPST MILL P Continue milling cement pilot hole @ 1.31 BPM @ 4132 PSI, 2.77 WOB, 15 ROP. Start opening ckoke to reduce pump pressures, @ 7530'. start seeing crude cut over the shakers, divert to tiger. BHP was measured @ 3197 psi. Bring WHP to 600 psi. BHI sencer showing 3752 psi. Bring returns back inside, looks good. 12/07/2013 Finished milling cement pilot hole to 7630'. Rigged up E-line, caliper cement pilot hole. Data sent to town for process. Pumped slack management. 00:00 05:48 5.80 7,538 7,630 PROD1 WHPST MILL P Continue milling @ 7538'. 1.48 BPM @ 3617 psi,WHP 580, 3747 BHP. Conduct pre-spud with the crew in the dog house. 05:48 06:12 0.40 7,630 7,300 PROD1 WHPST TRIP P 7630'TD Cement pilot hole. PUH to perform CCL. 06:12 06:27 0.25 7,300 7,600 PROD1 WHPST DLOG P 7300' Log CCL down to 7600'. 06:27 08:27 2.00 7,600 62 PROD1 WHPST TRIP P 7600' PUW 26k, Open EDC, POOH 08:27 08:57 0.50 62 62 PROD1 WHPST SFTY P Surface-Conduct PJSM wing crew to undeploy milling BHA#1 Page 2 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:57 10:57 2.00 62 0 PROD1 WHPST PULD P Undelploy and L/D milliing BHA#1 **Mill gauged 2.79od no-go 10:57 11:27 0.50 0 0 PROD1 WHPST SFTY P Conduct PSJM w/HES E-Line 11:27 14:42 3.25 0 0 PROD1 WHPST DLOG P R/U HES E-Line 14:42 16:27 1.75 0 7,630 PROD1 WHPST DLOG P RIH w/caliper, Tie in,and log from 7630'up to 7300' 16:27 17:27 1.00 7,630 0 PROD1 WHPST DLOG P POOH w/caliper 17:27 17:42 0.25 0 0 PROD1 WHPST SFTY P Conduct PJSM w/HES a-line to R/D equipment. 17:42 20:00 2.30 0 0 PROD1 WHPST DLOG P R/D HES eline 20:00 00:00 4.00 0 0 PROD1 RPEQP1 CTOP P Conduct prejob. Perform slack management. Cut off CTC, install external CTC. reverse circulate. Cut 52'of coil. Re-head E-line&test. Install CTC&pull test. Test CT to 4000 psi, good. 12/08/2013 Drifted pilot hole with dummy whip stock from 7507'to 7630'. Set Whip stock @ 7580,20 LOHS. RIH W/ window milling BHA. 00:00 01:00 1.00 0 0 PROD1 RPEQP1 SLPC P Pump forward full rate, full coil volume of 50 bbls 01:00 03:30 2.50 0 71 PROD1 RPEQP1 PULD P Conduct pre-job. MU&PD BHA#2, dummy whip stock drift. 03:30 05:00 1.50 71 7,312 PROD1 RPEQP1TRIP P RIH with BHA#2, EDC open 05:00 05:15 0.25 7,312 7,366 PROD1 RPEQP1DLOG P 7312'Tie into the formation correction of-2'. 05:15 05:45 0.50 7,366 7,630 PROD1 RPEQP1TRIP P RIH, drift cement pilot hole down to bottom. 05:45 07:30 1.75 7,630 71 PROD1 RPEQP1TRIP P POOH 07:30 07:48 0.30 71 71 PROD1 RPEQP1SFTY P Conduct PJSM w/rig crew for undeploying drift BHA#2 07:48 09:18 1.50 71 0 PROD1 RPEQP1PULD P Undeploy drift BHA#2 09:18 09:48 0.50 0 0 PROD1 RPEQP1CTOP P M/U INJH w/nozzle and jet stack. 09:48 10:06 0.30 0 0 PROD1 RPEQP1SFTY P Conduct PJSM to P/U, M/U and _deploy WS setting BHA#3 10:06 12:06 2.00 0 71 PROD1 RPEQP1 PULD P Deploy WS setting BHA#3 12:06 14:06 2.00 71 7,315 PROD1 RPEQP1TRIP P RIH w/WS setting BHA#3 14:06 14:36 0.50 7,315 7,395 PROD1 RPEQP1 DLOG P 7300'Tie into formation correction of -5.5' 14:36 15:51 1.25 7,395 7,591 PROD1 RPEQP1 TRIP P Continue in hole to setting depth, Orient to 20 LOHS. Pressure up to shear to 4700psi WHP 1450. Tool didn't shear. Bleed WHP down to 800psi and set WS @ 7580' 15:51 16:30 0.65 7,591 7,480 PROD1 RPEQP1 DISP P PUH, displace well to 9.6ppg ***Static pressure BHI AP 3964psi BHI WHP 1200psi 16:30 18:30 2.00 7,480 71 PROD1 RPEQP1TRIP P POOH Page 3 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 21:30 3.00 71 0 PROD1 RPEQP1PULD P Conduct pre-job. PUD Whip stock BHA. Lay down the same. Pick up& stab on first PDL. 21:30 23:00 1.50 0 73 PROD1 WHPST PULD P Pre-Job. PD window milling BHA. 23:00 00:00 1.00 73 5,402 PROD1 WHPST TRIP P RIW W/window milling BHA. 12/09/2013 Milled window at 7580,20 LOHS,to 7602. RIH W/build BHA. 00:00 01:30 1.50 5,402 7,512 PROD1 WHPST TRIP P Continue RIH W/window milling BHA. Tie in for a-5 correction.stack out 7512. 01:30 02:00 0.50 7,512 7,581 PROD1 WHPST TRIP P Pick up,try again no good.try different toll faces, no good. Pick rate up to 1.3 BPM, ease into 7512, pass by. Pull up&redrift at min rate, no problem. RIH to TOW @ 7581' 02:00 10:00 8.00 7,581 7,587 PROD1 WHPST MILL P Begin milling per-program, 10:00 12:00 2.00 7,587 7,588 PROD1 WHPST MILL P 7586.5'early exit, 1'below midway point. 1.42bpm at 3900psi.WHP 171, BHP 3834, IA 325, OA 29 12:00 12:45 0.75 7,588 7,589 PROD1 WHPST MILL P 7588.2'bottom of tray start 2fph. 12:45 14:27 1.70 7,589 7,602 PROD1 WHPST MILL P 7589.3'start milling rat hole. 14:27 15:45 1.30 7,602 7,602 PROD1 WHPST MILL P 7602'TD rate hole. Back ream window area @ 60fph. PUW 25k 15:45 18:00 2.25 7,602 73 PROD1 WHPST TRIP P 7602'Open EDC, POOH following manage pressure schedule, PUW 25k 18:00 18:30 0.50 73 73 PROD1 WHPST SFTY P Chnge out. Conduct pre-job for PUD. 18:30 21:00 2.50 73 0 PROD1 WHPST PULD P PUD window milling BHA.#4 21:00 22:30 1.50 0 62 PROD1 DRILL PULD P Conduct Pre-job. PD build BHA#5 with 2.2°+AKO motor and Bi Center bit 22:30 00:00 1.50 62 7,602 PROD1 DRILL TRIP P RIH W/build BHA. Tie in for-5. 12/10/2013 Drilled ahead in A lateral from 7602 to 8260. 00:00 02:45 2.75 7,602 7,731 PROD1 DRILL DRVE P Drill build , 1.31 BPM, 3861 PSI, BHP=3804, 02:45 03:06 0.35 7,731 7,731 PROD1 DRILL WPRT P Wiper, 26k off BTM.Wipe up to 7600'. RBIH 03:06 05:42 2.60 7,731 7,810 PROD1 DRILL DRLG P Drill ahead 130 BPM @ 3600 psi, 3814 BHP. 05:42 08:00 2.30 7,810 60 PROD1 DRILL TRIP P 7810 Call end of build, POOH for Lateral BHA, PUW=27K,Avg DLS=38° 08:00 09:30 1.50 60 0 PROD1 DRILL PULD P At surface, PJSM, PUD BHA#5 Build BHA with 2.2°AKO motor and Bi Center bit 09:30 11:30 2.00 0 72 PROD1 DRILL PULD P PJSM, PD BHA#6, .6°AKO motor and Hyc Bi Center, Make up to Coil and surface test. 11:30 13:00 1.50 72 7,270 PROD1 DRILL TRIP P Trip in well, EDC open 13:00 13:18 0.30 7,270 7,301 PROD1 DRILL DLOG P Log GR tie in for-6'correction, Close EDC, PUW=24K Page 4 of 27 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 13:18 13:36 0.30 7,301 7,610 PROD1 DRILL TRIP P Trip in hole 13:36 13:42 0.10 7,610 7,630 PROD1 DRILL DLOG P Log RA marker @ 7588'. TOWS=7581.5 13:42 13:54 0.20 7,630 7,810 PROD1 DRILL TRIP P Continue trip in to drill 13:54 16:00 2.10 7,810 7,960 PROD1 DRILL DRLG P 7810', Drill Ahead, 1.36 BPM @4086 PSI FS, BHP=3950 16:00 17:06 1.10 7,960 7,960 PROD1 DRILL WPRT P 7960',Wiper trip to EOB @ 7810, MAD Pass up to 7605 PUW=27.5 17:06 20:00 2.90 7,960 8,110 PROD1 DRILL DRLG P 7960', Drill Ahead, 1.38 BPM @ 3850 PSI FS, BHP=3810 20:00 21:00 1.00 8,110 8,110 PROD1 DRILL WPRT P Wiper up to 7615'. RBIH 21:00 23:45 2.75 8,110 8,260 PROD1 DRILL DRLG P 8110, Drill Ahead, 1.38 BPM @ 3860 PSI FS, BHP=3810 23:45 00:00 0.25 8,260 7,928 PROD1 DRILL WPRT P Wiper 27k off BTM, 12/11/2013 Current position identified, decision from town to POOH for plug back assembly. Had 7-8 hrs of down time for reel tension issues, issues resolved. POOH, PUD BHA#6, PD BHA#7, RIH w/anchored billet assembly, set billet @ 7,650'. POOH BHA#7 and PUD BHA. PD BHA#8, RIH w/build section BHA to 7,255'. 00:00 00:15 0.25 7,928 7,620 PROD1 DRILL WPRT P Continue wiper. 00:15 02:30 2.25 7,620 328 PROD1 DRILL TRIP T Get call from town. Current position idenified, POOH for plug back operations. 02:30 11:00 8.50 328 328 PROD1 DRILL TRIP T Having reel tension issues. Park at 328'. Make calls to Electrician& mechanic. EDC open,continue to circulate to maintain managed pressure. Start NAD NPT 11:00 11:24 0.40 328 64 PROD1 DRILL TRIP T Reel repairs complete, End NAD NPT 7.5Hrs,trip out for billet 11:24 12:54 1.50 64 0 PROD1 STK PULD T At surface, PJSM, PUD BHA#6 12:54 14:00 1.10 0 73 PROD1 STK PULD T PJSM, PD BHA#7 Aluminum Billet and open hole anchor, Make up to coil and surface test 14:00 16:00 2.00 73 7,275 PROD1 STK TRIP T Trip in hole, EDC open 16:00 16:18 0.30 7,275 7,322 PROD1 STK DLOG T Log tie in for-3'correction 16:18 16:36 0.30 7,322 7,662 PROD1 STK TRIP T Continue in well, stop at 7450 and shut EDC, PUW=25.5 16:36 16:42 0.10 7,662 7,661 PROD1 STK WPST T At set depth TF=350°, (10L), Pumps on see tool shift at 4500PS1, Set down 3K, Looks good,Top of billet=7650 16:42 18:30 1.80 7,661 76 PROD1 STK TRIP T Trip out after setting anchored billet 18:30 21:00 2.50 76 76 PROD1 STK PULD T PUD BHA#7, LD BHA, service injector, reel, and shaker. 21:00 22:30 1.50 76 76 PROD1 STK PULD T PU BHA#8, 2.4 degree AKO motor, PD BHA. 22:30 00:00 1.50 76 7,255 PROD1 STK TRIP T TIH w/BHA for KO/build section 12/12/2013 Continue in hole with KO/build section BHA to 7,650'.Time mill off billet to 7,658', drill build section to TD @ 7,745',TOOH for lateral BHA. PUD BHA#8, PD BHA#9, TIH w/BHA to 7,745'. Drill ahead A lateral to 8,190', drilling in progress. Page 5 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:57 0.95 7,255 7,650 PROD1 STK TRIP T Continue in hole with KO/build section BHA,tie-in to GR-7' correction,close EDC,dry tag billet @ 7,650'. 00:57 03:45 2.80 7,650 7,658 PROD1 STK KOST T Start time drilling as per well plan 1,2,3 fph for 1', 10 fph for 5',and 20 fph for 2'. 03:45 06:45 3.00 7,658 7,745 PROD1 DRILL DRLG T Drill ahead build section: 1.34 BPM @ 3,850 psi, BHP=3,815 psi, CTW=10.75K, DHWOB=.64K, ROP=45 06:45 08:51 2.10 7,745 55 PROD1 DRILL TRIP T 7745, Call end of build,trip out, PUW=26K,Avg DLS=-51° 08:51 10:15 1.40 55 0 PROD1 DRILL PULD T At surface, PJSM, PUD BHA#8 10:15 10:33 0.30 0 0 PROD1 DRILL BOPE T Perform Bi Weekly BOPE Function test 10:33 12:03 1.50 0 72 PROD1 DRILL PULD T PJSM, PD BHA#9 Lateral section BHA with .6+°AKO motor and re run HYC bit, Make up to coil track and surface test 12:03 13:33 1.50 72 7,280 PROD1 DRILL TRIP T Trip in well, EDC open 13:33 13:51 0.30 7,280 7,312 PROD1 DRILL DLOG T Log tie in for-7'correction, close EDC, PUW=26K 13:51 14:27 0.60 7,312 7,745 PROD1 DRILL TRIP T RIH to 7560 get static pressure, start @ 710 PSI WHP 3802PS1 Annular, 10 minute WHP=809, BHP=3885 -12.2PPG EMW, RIH to drill 14:27 17:33 3.10 7,745 7,890 PROD1 DRILL DRLG T 7745', Drill Ahead, 1.38 BPM @ 3980PSI FS, BHP=3845 PSI 17:33 18:03 0.50 7,890 7,890 PROD1 DRILL WPRT T Wiper trip to window, PUW=32K, MAD pass for data, RBIH. 18:03 20:18 2.25 7,890 8,040 PROD1 DRILL DRLG T 7,890', Drill Ahead, 1.35 BPM @ 3940PSI FS, BHP=3875 PSI, ROP=60 20:18 21:06 0.80 8,040 8,040 PROD1 DRILL WPRT T Wiper trip#2, PUW=29K, RBIH. 21:06 23:18 2.20 8,040 8,190 PROD1 DRILL DRLG T 8,040', Drill Ahead, 1.35 BPM @ 3860PS1 FS, BHP=3880 PSI, ROP=50 23:18 00:00 0.70 8,190 8,190 PROD1 DRILL WPRT T Wiper trip#3, PUW=27K,tie-in to GR for+2.5'correction, pressure calibration @ window, pump rate 1.35 bpm @ 3975,WH psi 150, annular psi 3927, 810 psi on choke. RBIH. 12/13/2013 Drill ahead A lateral from 8,190'to 9,050',with 150'wiper trips, new mud system @ 8,875',drilling in progress. 00:00 00:15 0.25 8,190 8,190 PROD1 DRILL WPRT T Continue in hole after wiper trip. 00:15 03:30 3.25 8,190 8,340 PROD1 DRILL DRLG P 8,190', Drill Ahead, 1.36 BPM @ 3950PSI FS, BHP=3875 PSI, CTW=10K, ROP=50, BHA wiper @ 8,253', pumped 5/5 sweeps. 03:30 04:15 0.75 8,340 8,340 PROD1 DRILL WPRT P Wiper trip to window Page 6 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 05:45 1.50 8,340 8,490 PROD1 DRILL DRLG P 8,340', Drill Ahead, 1.36 BPM @ 4050PSI FS, BHP=3878 PSI, CTW=9.5K, ROP=80. 05:45 06:33 0.80 8,490 8,490 PROD1 DRILL WPRT P Wiper trip to 7650', PUW=27K, 06:33 07:57 1.40 8,490 8,640 PROD1 DRILL DRLG P 8490', Drill ahead, 1.4 BPM @ 4060 PSI FS, BHP=3905 07:57 09:45 1.80 8,640 8,640 PROD1 DRILL WPRT P Wiper trip to window with tie in for +1.5'correction, PUW=27.5K 09:45 10:57 1.20 8,640 8,790 PROD1 DRILL DRLG P 8640', Drill, 1.32 BPM @ 3920 PSI FS, BHP=3980 10:57 13:15 2.30 8,790 8,790 PROD1 DRILL WPRT P Wiper trip to window, PUW=28.5K, Make two pressure pumping survey passes at 1.33 BPM, 203 PSI WHP to obtain 3840 PSI BHP, Tie in for +.5', Pump bottoms up observe for formation fluid, RBIH to drill 13:15 20:51 7.60 8,790 8,940 PROD1 DRILL DRLG P 8790',drill, 1.34 BPM @ 3940 PSI FS, BHP=3985, Perform Mud swap, New mud at bit 8875'. Build inclination to avoid ankerite, ROP=less than 10 for several hours, short wiper @ 8,905'. Broke free from ankerite @ 8,930'. 20:51 22:06 1.25 8,940 8,940 PROD1 DRILL WPRT P Wiper trip to 7,760' 22:06 00:00 1.90 8,940 9,050 PROD1 DRILL DRLG P 8940',drill, 1.33 BPM @ 3980 PSI FS, BHP=3990, CTW=8.2K, DHWOB=1.8K, ROP=60 12/14/2013 Drilling ahead from 9,050'to 9,835'with 150'wiper trips,drilling A lateral in progress. 00:00 00:54 0.90 9,050 9,090 PROD1 DRILL DRLG P 9,050", Drill, 1.33 BPM @ 3980 PSI FS, BHP=3990, CTW=6.2K, DHWOB=1.8K, ROP=50 00:54 02:03 1.15 9,090 9,090 PROD1 DRILL WPRT P Wiper to 7,885', PUW=25K, RBIH. 02:03 04:24 2.35 9,090 9,240 PROD1 DRILL DRLG P 9,090", Drill, 1.33 BPM @ 3977 PSI FS, BHP=3995, CTW=7.4K, DHWOB=1.9K, ROP=40 04:24 06:24 2.00 9,240 9,240 PROD1 DRILL WPRT P Wiper trip to window with tie in for +2.5'correction, PUW=24K 06:24 09:54 3.50 9,240 9,390 PROD1 DRILL DRLG P 9240 Drill, 1.32 BPM @ 3880 PSI FS, BHP=3990 09:54 10:48 0.90 9,390 9,390 PROD1 DRILL WPRT P Wiper to 8540, PUW=24K 10:48 13:30 2.70 9,390 9,540 PROD1 DRILL DRLG P 9390', Drill, 1.31 BPM @3845 PSI FS, BHP=4012, RIW=9.5K, WHP=120 13:30 14:24 0.90 9,540 9,540 PROD1 DRILL WPRT P 9540',Wiper to 8690, PUW=25K 14:24 16:24 2.00 9,540 9,690 PROD1 DRILL DRLG P 9540', Drill, 1.3 BPM @ 3760 PSI FS, BHP=4030 16:24 19:09 2.75 9,690 9,690 PROD1 DRILL WPRT P Wiper trip to window with tie in, PUW=25K,tie-in for+2'correction, RBIH. Page 7 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:09 00:00 4.85 9,690 9,835 PROD1 DRILL DRLG P 9690', Drill, 1.34 BPM @3950 PSI FS, BHP=4050, RIW=5K, WHP=150. BHA wiper @ 9,750', PUW=24K, negative CTW below 9,780', made couple of short BHA trip, pumped 5/5 sweeps. 12/15/2013 Drilling ahead from 9,835'to 10,390'with 150'wiper trips,drilling A lateral in progress. 00:00 00:15 0.25 9,835 9,840 PROD1 DRILL DRLG P 9,835', Drill, 1.34 BPM @3950 PSI FS, BHP=4050, RIW=5K, WHP=150.Continue with negative weight till wiper trip. 00:15 01:30 1.25 9,840 9,840 PROD1 DRILL WPRT P Wiper trip to 8,640', PUW=25K, RBIH. 01:30 05:12 3.70 9,840 9,990 PROD1 DRILL DRLG P 9,840', Drill, 1.32 BPM @4090 PSI FS, BHP=4055, RIW=2K, WHP=145, DHWOB=1.5K, ROP=60 05:12 06:30 1.30 9,990 9,990 PROD1 DRILL WPRT P Wiper trip, PUW=26K, RBIH. 06:30 08:30 2.00 9,990 10,090 PROD1 DRILL DRLG P 9990', Drill, 1.3 BPM @ 3940 PSi FS, BHP=4070, RIW=-5K 08:30 08:54 0.40 10,090 10,090 PROD1 DRILL WPRT P BHA Wiper, low surface weight, weight transfer, PUW=25K 08:54 10:42 1.80 10,090 10,096 PROD1 DRILL DRLG P 10090', Drill, 1.3 BPM @ 3945 PSI FS, BHP=4010, RIW=-6K 10:42 13:30 2.80 10,096 10,096 PROD1 DRILL WPRT P Wiper to window with tie in for+.5' correction, Pump 5 X 5 sweeps, PUW=25K 13:30 15:42 2.20 10,096 10,170 PROD1 DRILL DRLG P 10096', Drill, 1.3 BPM @ 3930 PSI FS, BHP=4040, Stall at 10,100 then had two at 10097 with fluid losses. Broke through, ROP=65 Into better zone. Fluid loss @.1 BPM 15:42 17:36 1.90 10,170 10,240 PROD1 DRILL DRLG P Stall at 10,170', losing fluid .2 to.4 BPM, ROP 40-60 FPH. Continue drilling ahead. 17:36 19:36 2.00 10,240 10,240 PROD1 DRILL WPRT P Wiper trip to 8,750', PUW=24K, RBIH. 19:36 23:30 3.90 10,240 10,390 PROD1 DRILL DRLG P 10240', Drill, 1.32 BPM @ 3950 PSI FS, BHP=4070, RIW=-2K, ROP=40, still losing fluid @.3 BPM. 23:30 00:00 0.50 10,390 10,390 PROD1 DRILL DRLG P Wiper trip, PUW=26K, RBIH. 12/16/2013 Drilling ahead from 10,390'to 10,857'with 150'wiper trips, drilling ahead to TD @ 10,900'. 00:00 01:15 1.25 10,390 10,390 PROD1 DRILL WPRT P RBIH after wiper trip. 01:15 04:21 3.10 10,390 10,540 PROD1 DRILL DRLG P 10390', Drill, 1.3 BPM @ 4095 PSI FS, BHP=4073, RIW=-2K, ROP=30, still losing fluid @.3 BPM. 04:21 05:51 1.50 10,540 7,605 PROD1 DRILL WPRT P Wiper trip for tie-in, PUW=26.5K 05:51 07:51 2.00 7,605 10,540 PROD1 DRILL WPRT P RBIH after wiper trip. 07:51 11:36 3.75 10,540 10,690 PROD1 DRILL DRLG P 10540', Drill, 1.3 bpm @ 4160 psi -1-2k down weight, ECD 13.03 ppg. WOB 1.62 k, ROP-55. 11:36 13:06 1.50 10,690 7,615 PROD1 DRILL WPRT P Wiper trip to window, PUW=25 k 13:06 14:48 1.70 7,615 10,690 PROD1 DRILL WPRT P RBIH after wiper trip Page 8 of 27 Time Logs 1 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/16/2013 24 hr Summary Drilling ahead from 10,390'to 10,857'with 150'wiper trips, drilling ahead to TD @ 10,900'. 14:48 16:48 2.00 10,690 10,748 PROD1 DRILL DRLG P 10690', Drill, 1.3 bpm @ 4160 psi 3.3k down weight, ECD 13.03 ppg. WOB 1.62 k, ROP—32. 10746', Drill, 1.3 bpm @ 4250 psi 5.0k down weight, ECD 13.07 ppg. WOB 1.37 k, ROP—50. 16:48 17:30 0.70 10,748 10,756 PROD1 DRILL WPRT P Wiper trip 200', PUW=30 K, Hard to get going stacking, Low ROP with poor transfer 17:30 21:42 4.20 10,756 10,840 PROD1 DRILL DRLG P 10757', Drill, 1.3 bpm @ 4100 psi 3.3k down weight, ECD 13.03 ppg. In ankorite Low ROP<10FPH, confirmed in sample, Broke out @ 10785, ROP—60FPH 21:42 23:30 1.80 10,840 10,840 PROD1 DRILL WPRT P 10840',Wiper to 9400'with sweeps, PUW=25K, Clean trip up, Had to reduce pump rate to.75 BPM while RIH 23:30 00:00 0.50 10,840 10,857 PROD1 DRILL DRLG P 10840', Drill Ahead, 1.3 BPM @ 3920 PSI FS, RIW=.7K, BHP=4111 PSI 12/17/2013 Drill ahead to called TD @ 10,883'. Lay in 12.4 ppg beaded completion fluids to window, slightly viscosified completion fluids to surface. MU 2,087'of"A"lateral liner, RIH with same. 00:00 00:54 0.90 10,857 10,880 PROD1 DRILL DRLG P 10857', Drill Ahead to TD, 1.3 BPM @ 3920 PSI FS, RIW=.7K, BHP=4111 PSI.Temporarily differentially stuck @ 10,880', several attempts to pull free to 50K were unsuccessful, able to circulate. Shut down pump, let well stabilize for 10 mins, coil pulled free, called TD @ 10,880'. 00:54 05:09 4.25 10,880 66 PROD1 DRILL WPRT P Pump 10 bbl to/hi vis sweeps, chase sweep to swab, minimal solids when sweeps reached surface, no issues during wiper trip. 05:09 09:36 4.45 66 10,883 PROD1 DRILL TRIP P RBIH for tie-in,tie-in to GR for-8' correction,corrected TD,close EDC. Continue in hole, confirm TD @ 10,883'. 09:36 13:12 3.60 10,883 0 PROD1 DRILL CIRC P POOH laying in completion fluids 12.4 Formate. Paint EOP flags @ 8,600'and 5,400'. 13:12 13:48 0.60 0 0 PROD1 DRILL OWFF P At Surface, monitor,30 minute monitor for flow, hold pre job safety meeting for laying down BHA. 13:48 14:30 0.70 0 0 PROD1 DRILL PULD P Lay down drilling BHA#9, Bit,one side cutter badly chipped,three top pilot cutters chipped/worn badly on one side graded 2,2. Pump approx 1 bbl to fill hole. Continue to monitor and fill as needed. Page 9 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 20:30 6.00 0 2,087 COMPZ CASING PUTB P PJSM, Pick up and run liner,2 3/8" no-ported bull nose, 26 joints 2 3/8" slotted,XO, 11 joints 2 3/8"solid liner,XO, 29 joints 2 3/8"slotted. 20:30 21:48 1.30 2,087 2,131 COMPZ CASING PULD P PJSM, MU Liner running BHA#10, inspect and changed out checks, Note: 14 bbls of 12.4 ppg KWF lost to formation while PU of liner and BHA. 21:48 23:18 1.50 2,131 7,531 COMPZ CASING RUNL P RIH with 2,087'of 2G-12A lateral liner ass'y pumping minimum rate,60 fpm, IA 294, OA 0, CTW 9.1k.Tie into flag with-10'correction, PUW 29k. 23:18 23:48 0.50 7,531 7,531 COMPZ CASING SFTY P Safety Stand Up, discussion of resent incidents and near misses and how they relate to our operations,what we can do to continue safe operations into next year. 23:48 00:00 0.20 7,531 7,850 COMPZ CASING RUNL P Continue RIH with"A"lateral liner ass'y. 12/18/2013 Attempt to set 2,087'"A"lateral liner ass'y,work down from 9,433, unable to pass 9,703'ctmd. POOH with liner ass'y, laid down same. MU-RIH with Clean out ass'y. Safety Stand Up with town representative. Clean out open hole to 10,877'.Wiper trip to swab. 00:00 00:42 0.70 7,850 9,433 COMPZCASING RUNL P 7,850', Continue RIH with"A"lateral liner ass'y. IA 295, OA 0. 00:42 02:06 1.40 9,433 9,703 COMPZ CASING RUNL T 9,433', Sat down, PUW 40k to pull free,work liner to 9,703', unable to pass, clean PUW 37k, confer with town engineer. 02:06 04:45 2.65 9,703 2,131 COMPZ CASING TRIP T 9,703', POOH, PUW37k, 04:45 05:15 0.50 2,131 2,131 COMPZ CASING OWFF T 2,131', Monitor well for flow, hold pre job safety meeting for laying down BHA. Note: 13 bbls of 12.4 ppg KWF lost to formation while RIH (6)and POOH (7) 05:15 07:27 2.20 2,131 2,087 COMPZ CASING PULD T 2,131', Lay down liner running BHA #10. 07:27 07:57 0.50 2,087 2,087 COMPZ CASING SFTY T Safety Stand Down to cover recent rash of incidents @ NSOD. 07:57 10:27 2.50 2,087 0 COMPZ CASING PULD T PJSM w/oncoming crew. 2,087', lay down"A"lateral liner. Laying down solid liner @ 10:00. Lay down remaining liner assembly. 10:27 12:42 2.25 0 0 COMPZ CASING PULD T PU/MU BHA#11 clean-out assembly parabolic mill, 0.6 ATO motor. 12:42 14:57 2.25 0 7,485 COMPZ CASING TRIP T TIH w/BHA#11 clean-out assembly, close EDC,tie-in to GR for-7.5' correction, continue in hole. 14:57 16:30 1.55 7,485 7,485 COMPZ CASING CIRC T Circulate out completion fluid from window. Page 10 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 19:00 2.50 7,485 7,485 COMPZ CASING SFTY T Decision made to stay in cased hole and circulate well for upcoming safety stand down. Safety Stand down with Mike Wheatall, crew changeout. 19:00 21:15 2.25 7,485 10,877 COMPZ CASING WPRT T 7,485', RIH with clean out ass'y, stack out at 7,670',20'below billet, PU and up rate to.8 bpm, RBIH, sat down but fell thru at 7,670', short wiper thru area, RBIH thru tight spot no problem, continue RIH take weight at 9,824', PU and pass thru easily, no problems to 10,877'ctmd, small amount shale across shackers. 21:15 00:00 2.75 10,877 8,270 COMPZ CASING WPRT T 10,877', Pump hi/lo sweeps,wiper trip to swab. Note: lost 70 bbls 12.4 ppg midnight to midnight. 12/19/2013 Lay in completion fluid from TD to surface. Ran lower"A"lateral liner to TD at 10,833'. 00:00 02:51 2.85 8,270 62 COMPZ CASINGWPRT T 8,270', Pump 10 bbl to/hi vis sweeps, chase sweep to swab, minimal solids when sweeps reached surface, no issues during wiper trip, jog performed at 500'. Note: lost 70 bbls 12.4 ppg midnight to midnight. 02:51 07:06 4.25 62 10,881 COMPZ CASING TRIP T 62'-RBIH for tie-in,tie-in to GR for -6.5'correction, close EDC, continue in hole, confirm TD @ 10,881'. 07:06 10:15 3.15 10,881 0 COMPZ CASING CIRC T 10,881'-POOH laying in beaded liner running pill into tbg, 12.4 formate to surface. Paint EOP flags @ 9,200' and 5,900'. 10:15 11:00 0.75 0 0 COMPZ CASING OWFF T At surface,check well for flow, PJSM. 11:00 12:30 1.50 0 0 COMPZ CASING PULD T Break off injector, lay down BHA #11,prep rig floor for liner. 12:30 16:00 3.50 0 0 COMPZ CASING PUTB T PJSM. PU/MU Lower Liner assembly bull nose, 26 jts slotted, 11 jts solid, 13 slotted, D. Sleeve, MU BHA#12. 16:00 21:45 5.75 0 10,883 COMPZ CASING RUNL T TIH w/lower liner assembly,tie-in to EOP flag for-6.5'correction,take weight at 9,850', PUW 28k,work to 10,110'until progress stalled, PUW 32k, stack weight and bring on pump down coil 1 bpm for 1/2 bbl, PU 40k to free and RBIH,work liner to 10,883' using same pump/PU method, PUW 32k, pump off liner, PUW 23k at 10,883'. Page 11 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 10,883 4,510 COMPZ CASING TRIP P 10,883'-POOH,tie-in confirms 10,833'TD, Paint EOP flags @ 8,600'and 6,900'. Note: lost 12 bbls 12.4 ppg midnight to midnight. 12/20/2013 Ran Upper"A"lateral liner to 9,307',set anchor billet,swap hole over to 9.6 ppg Flo-Pro drilling fluid. Perform Bi-weekly BOP test. 00:00 01:06 1.10 4,510 44 COMPZ CASING TRIP P 4,510'-Continue POOH. Note: lost 12 bbls 12.4 ppg midnight to midnight. 01:06 01:51 0.75 44 44 COMPZ CASING OWFF P At surface, check well for flow, PJSM. 01:51 03:00 1.15 44 0 COMPZ CASING PULD P Break off injector, lay down BHA #12, prep rig floor for liner. 03:00 05:30 2.50 0 578 COMPZ CASING PUTB P PJSM. PU/MU Upper Liner assembly ported bull nose, 16 jts slotted, Anchor Billet, MU BHA#13. 05:30 09:00 3.50 578 9,307 COMPZ CASING RUNL P 578'-TIH w/Upper liner assembly, EDC closed, pumping down back side,tie-in to EOP flag for neg 5 ft correction. Tag billet @ 9304'up WT 29k lbs, Set anchored billet 10 deg ROHS, release from liner at 3500 psi PUW dropped to 26k. 09:00 12:00 3.00 9,307 55 1COMPZ CASING RUNL P POOH from 8787'circulation depth while displacing the well to 9.9 flow pro. 12:00 12:30 0.50 55 55 COMPZ CASING SFTY P At surface,730 psi whp. crew change, PJSM 12:30 15:00 2.50 55 0 COMPZ CASING PULD P Pressure undeploy and laydown BHA #13, 15:00 16:30 1.50 0 0 PROD2 STK SEQP P PJSM, FMC on location,set 2 way check prior to BOP test. 16:30 19:30 3.00 0 0 PROD2 STK DISP P Pull checks and instal JTSW nozzle, displace coiled tubing to water, flush stack,grease stack and misc. surface valves. 19:30 00:00 4.50 0 0 PROD2 STK BOPE P Perform bi-weekly BOPE test, 250/4,000 psi, annular 2,500 psi. Test waived by Jeff Turkington (AOGCC) Note: lost 25 bbls 12.4 ppg midnight to midnight. 12/21/2013 Complete Bi-weekly BOP test. Cut 4,400'coil. Pull TWC. Perform slack management. Install coil connector and re-head. 00:00 07:00 7.00 0 0 PROD2 STK BOPE P Complete bi-weekly BOPE test, 250/4,000 psi,annular 2,500 psi. Test waived by Jeff Turkington (AOGCC) Note: lost 25 bbls 12.4 ppg midnight to midnight. Page 12 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:30 1.50 0 0 PROD2 STK SEQP P PJSM-LD BOP test equipment, prep to cut, blow down coil, pipe/slack management. 08:30 17:00 8.50 0 0 PROD2 STK CTOP P PJSM-to cut 4,400'of 2"coil, @ 11:00 hrs cut 1000' @ 13:30 hrs cut 3000' —3 bucket loads per 1000' 17:00 18:00 1.00 0 0 PROD2 STK BOPE P PJSM, Pull 2 way check. 18:00 21:00 3.00 0 0 PROD2 STK CIRC P Perform slack management, load coil with water, reverse circ 10 bbl at 2 bpm. 21:00 22:00 1.00 0 0 PROD2 STK CTOP P PJSM-Prep to cut, cut additional 100'coil,e-line found at 36', RD equipment. 22:001 00:00 2.00 0 0 PROD2 STK CTOP P PJSM-Install coil connect, pull test 35k, re-head 12/22/2013 MU AL2 drilling BHA#14. Kick off billet at 8,784'.Drill ahead AL2 lateral to 9,230'. 00:00 01:45 1.75 0 0 PROD2 STK CTOP P Continue re-head, P/T 4,000 psi, good. load coil with 9.6 ppg drilling fluid. 01:45 05:15 3.50 0 72 PROD2 STK PULD P PJSM-MU AL2 lateral drilling BHA #14, pressure deploy same. Gas at surface when well opened, WHP=850 psi. 05:15 09:30 4.25 72 8,770 PROD2 STK TRIP P 72'-RIH with AL2 drilling BHA,gas in returns, start taking returns to tiger tank, tie-in to GR for-3.5'correction, close EDC, PUW=25K.TIH. 09:30 10:15 0.75 8,770 8,770 PROD2 STK CIRC P Decide to circulate hole to new mud system due to gas cut returns, circulate hole. 10:15 11:15 1.00 8,770 8,786 PROD2 STK TRIP T TIH to billet, dry tag billet @ 8,786', make BHA wiper trip due to weight transfer issues. 11:15 12:15 1.00 8,786 8,786 PROD2 STK KOST T Make several attempts to start time milling off billet, still having weight transfer issues. 12:15 13:30 1.25 8,786 8,786 PROD2 STK WPRT T Wiper trip to window, PUW=23K, RBIH. 13:30 15:00 1.50 8,784 8,784 PROD2 STK KOST P Tag billet, multiple stalls,@ 8784.3'. Up Wt 28k down Wt 10k. Attempt to time drill© 1 fph, stall once, Started milling,WOB 0.55, 1.37 bpm, 3551 psi, ECD 12.51, IA/OA=313/0 psi 15:00 15:42 0.70 8,784 8,785 PROD2 STK KOST P Mill ahead at 1 fph for 1 ft 15:42 16:12 0.50 8,785 8,786 PROD2 STK KOST P Mill ahead at 2 fph for 1 ft 16:12 18:00 1.80 8,785 8,895 PROD2 STK KOST P Mill ahead at 3 fph for 1', Increase ROP to 15 fph for 7".WOB 0.75, 1.37 bpm, 3457 psi, ECD 12.51. Increase ROP,drill 45',clean hole, dry drift good. 18:00 18:30 0.50 8,895 8,930 PROD2 DRILL DRLG P Drilling ahead,AL2 lateral, 8895', 1.38 bpm @ 3691 psi, ROP 103 fph, WOB 0.82 k, RIHwt 8.6k. Page 13of27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:06 0.60 8,930 8,000 PROD2 DRILL WPRT P Wiper trip, PUW=29k, 19:06 19:48 0.70 8,000 8,930 PROD2 DRILL WPRT P Wiper trip, RIHW= 11.2K, 19:48 21:00 1.20 8,930 9,080 PROD2 DRILL DRLG P Drilling,8930', 1.37 bpm, @ 3637 psi, BHP 3997, RIW=9.3k, DHWOB =0.80, ROP 110 fph 21:00 21:24 0.40 9,080 8,230 PROD2 DRILL WPRT P 9,080'-Wiper trip, PUW=26k, Increase rate to 1.52 ppm,@ 3767 psi, 21:24 21:48 0.40 8,230 9,080 PROD2 DRILL WPRT P 8,230'-Wiper trip, RIHW=9.7k, 21:48 23:00 1.20 9,080 9,230 PROD2 DRILL DRLG P Drilling, 9088', 1.44 bpm, @ 3873 psi, BHP 4021, RIW=7.4k, DHWOB =0.99, ROP 120 fph 23:00 00:00 1.00 9,230 7,800 PROD2 DRILL WPRT P 9,230'-Wiper trip to window, PUW=28k, Note: lost 12 bbls 9.6 ppg midnight to midnight. 12/23/2013 Drilling ahead from 9,230'to 10,131'with 150'wiper trips and sweeps, drilling AL2 lateral in progress. 00:00 00:15 0.25 7,800 7,680 PROD2 DRILL WPRT P 7,800'-Continue wiper trip to window, PUW=25k,calibrate choke. Note: lost 12 bbls 9.6 ppg midnight to midnight. 00:15 00:30 0.25 7,680 7,610 PROD2 DRILL ELOG P Tie in to RA, +2.5'correction. 00:30 01:24 0.90 7,610 9,230 PROD2 DRILL WPRT P 7,610'-Wiper trip, RBIH, RIHW= 11.4k, 01:24 03:54 2.50 9,230 9,380 PROD2 DRILL DRLG P 9,230'BOBD, 1.45 bpm @ 3834 psi, BHP 4018, RIW=7.4k, DHWOB= 1.24, ROP 100 fph. 03:54 04:36 0.70 9,380 8,350 PROD2 DRILL WPRT P 9,380'-Wiper trip, PUW=28k, IA 328, OA 13. 04:36 05:12 0.60 8,350 9,380 PROD2 DRILL WPRT P 8,350'-Wiper trip, RBIH, RIHW= 10.7k 05:12 07:12 2.00 9,380 9,530 PROD2 DRILL DRLG P 9,380' BOBD, 1.45 bpm @ 3775 psi, BHP 4019, RIW=6.8k, DHWOB= 1.21, ROP 80 fph. 07:12 08:42 1.50 9,530 9,530 PROD2 DRILL WPRT P Wiper trip, PUW=27K, RBIH. 08:42 10:39 1.95 9,530 9,680 PROD2 DRILL DRLG P 9,530' BOBD, 1.45 bpm @ 3930 psi, BHP 4070, RIW=5.8k, DHWOB= 1.55, ROP 85 fph. 10:39 12:48 2.15 9,680 9,680 PROD2 DRILL WPRT P Wiper trip for tie-in correction of+.5', PUW=27.5K, RBIH. 12:48 14:00 1.20 9,680 9,830 PROD2 DRILL DRLG P 9,680'BOBD, 1.44 bpm @ 3980 psi, BHP 4055, RIW=2.5K, DHWOB= 1.45, ROP 110 fph. 14:00 15:30 1.50 9,830 9,830 PROD2 DRILL WPRT P Wiper trip, PUW=27.5K, RBIH. 15:30 17:09 1.65 9,830 9,980 PROD2 DRILL DRLG P 9,830'BOBD, 1.44 bpm @ 3980 psi, BHP 4055, RIW=2.5K, DHWOB= 1.45, ROP 110 fph. 17:09 18:33 1.40 9,980 9,980 PROD2 DRILL WPRT P Wiper trip, PUW=27K, RBIH. Page 14 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:33 20:27 1.90 9,980 10,130 PROD2 DRILL DRLG P 9,980'BOBD, 1.44 bpm @ 3968 psi, BHP 4062, RIW=6.0K, DHWOB= 1.15, ROP 48 fph. ROP increasd to 91 fph, @ 10016'. @ 10129', RIHW =2.36, DHWOB= 1.11, ROP=65, BHP=4092. 20:27 22:03 1.60 10,130 7,600 PROD2 DRILL WPRT P Wiper trip, PUW=27.5K, RA tag correction plus 3' 22:03 23:45 1.70 7,600 10,130 PROD2 DRILL WPRT P RBIH, 23:45 00:00 0.25 10,130 10,161 PROD2 DRILL DRLG P 10131' BOBD, 1.41 bpm @ 3810 psi, BHP 4114, RIW=8.2K, DHWOB= 0.08, ROP 100 fph. Note: lost 50 bbls 9.6 ppg midnight to midnight. 12/24/2013 Drilling ahead from 10131'to 11030'with 150'wiper trips and sweeps, Drilling ahead 00:00 01:48 1.80 10,161 10,280 PROD2 DRILL DRLG P 10,181'-1.41 bpm @ 3841 psi, BHP 4133, RIW=6.89K, DHWOB=0.75, ROP 100 fph. Note: lost 50 bbls 9.6 ppg midnight _to midnight. 01:48 03:06 1.30 10,280 10,280 PROD2 DRILL WPRT P 10,280'-Wiper trip to 9,270', PUW=30K, RBIH 03:06 05:39 2.55 10,280 10,430 PROD2 DRILL DRLG P 10,280'-BOBD, 1.41 bpm @ 3802 psi, BHP 4110, RIW=6.7K, DHWOB =0.7, ROP 90 fph. 05:39 07:15 1.60 10,430 10,430 PROD2 DRILL WPRT P 10,430'-Wiper trip to 9,230', PUW=29K, RBIH, IA 334, OA 16. 07:15 09:24 2.15 10,430 10,580 PROD2 DRILL DRLG P 10,430'-BOBD, 1.42 bpm @ 3837 psi, BHP 4097, RIW=4.7K, DHWOB = 1.15, ROP 100 fph. 09:24 10:54 1.50 10,580 7,650 PROD2 DRILL WPRT P 10,580'-Wiper trip for tie-in at window, PUW=29K, pump 5x5 sweep 10:54 11:03 0.15 7,640 7,605 PROD2 DRILL ELOG P Tie in to RA with+2.5'correction. 11:03 12:39 1.60 7,605 10,580 PROD2 DRILL WPRT P 7,605'-Wiper trip BIH, RIHW= 10.5k, Mud system#3 drilled 1,796', .7% D.S., start pumping mud system#4, IA 333, OA 18 12:39 13:54 1.25 10,580 10,730 PROD2 DRILL DRLG P 10,580'-BOBD, 1.42 bpm @ 3954 psi, BHP 4092, RIW=4.7K, DHWOB =.90, ROP 140 fph. _Note: New mud at bit at 10,600'. 13:54 15:09 1.25 10,730 10,730 PROD2 DRILL WPRT P 10,730'-Wiper trip to 9,530', PUW=30K, RBIH, IA 323, OA 0. 15:09 16:15 1.10 10,730 10,880 PROD2 DRILL DRLG P 10,730'-BOBD, 1.45 bpm @ 3850 psi, BHP 4070, RIW= 1.7K, DHWOB = 1.18, ROP 145 fph. 16:15 17:51 1.60 10,880 10,880 PROD2 DRILL WPRT P 10,880'-Wiper trip to 9,380', PUW=30K, RBIH, IA 323, OA 0. 17:51 20:21 2.50 10,880 11,030 PROD2 DRILL DRLG P 10,880'-BOBD 1.45bpm at 3850 psi, BHP 4040, RIW 1.8k, DHWOB 1.18, ROP 140fph Page 15 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:21 22:21 2.00 11,030 7,606 PROD2 DRILL WPRT P 11,030'-Wiper trip for tie-in at window 22:21 22:36 0.25 7,606 7,629 PROD2 DRILL DLOG P 7606'Tie into the RA marker correction of+3'. 22:36 00:00 1.40 7,629 10,587 PROD2 DRILL WPRT P 7629'Wiper back in hole. RIW 10k 12/25/2013 Drilling ahead from 11030'to 11160'. Performed wiper to the swab valves. RBIH to confirm TD. 11160', Lay in 12.4ppg completion fluid with beads up to 5200', and without bead to surface. 00:00 00:24 0.40 10,587 11,030 PROD2 DRILL WPRT P 10587'Continue wiper trip back inhole from window. 00:24 02:54 2.50 11,030 11,160 PROD2 DRILL DRLG P 11030' BOBD 1.41bpm at 3564psi, RIW 8k, BHP 4152,WHP 195, IA 332, OA 8 02:54 07:06 4.20 11,160 70 PROD2 DRILL WPRT P 11160'TD well. PUW 27k,start swab wiper, perform jog at 500' 07:06 09:00 1.90 70 7,260 PROD2 DRILL TRIP P 70'RBIH,Tie in correction+12'. 09:00 10:00 1.00 7,260 7,260 PROD2 DRILL EQRP T 7,260'Troubleshoot, replace counter, troubleshoot MWD cable. 10:00 12:18 2.30 7,260 11,157 PROD2 DRILL TRIP P 7,260' RIH,Tie in at RA marker +19.5', continue RIH, appears polymers breaking out of mud after entering open hole,tagged corrected at TD 11,157'. 12:18 13:18 1.00 11,157 9,725 PROD2 DRILL WPRT T 11,157'Wiper trip for bottoms up as per town, no change in returns after bottoms up, call back from town, carry on as per plan. 13:18 14:15 0.95 9,725 11,157 PROD2 DRILL WPRT T 9,725' RBIH to TD. 14:15 18:45 4.50 11,157 70 PROD2 DRILL CIRC P 11,157' Lay in 12.4 ppg beaded liner running pill and unbeaded 12.4 completion fluid to surface, paint EOP flags at 9,700'and 6,200' 18:45 19:15 0.50 70 70 PROD2 DRILL PULD P 70'On surface, monitor well for flow. 19:15 20:15 1.00 70 0 PROD2 DRILL PULD P Conduct PJSM, L/D drilling BHA 20:15 20:45 0.50 0 0 COMPZ CASING PUTB P Conduct PJSM, prep rig floor for running completion. 20:45 00:00 3.25 0 798 COMPZ CASING PUTB P Start making up AL2 liner completion w/41 jts of slotted liner. 12/26/2013 M/U, Run AL2 liner completion.TOL 9875'. M/U, BHA#16, and kick off of billet to drill AL2-01. 00:00 00:45 0.75 798 1,324 COMPZ CASING PUTB P Continue M/U AL2 completion. 00:45 01:15 0.50 1,324 1,324 COMPZ CASING PUTB P 1324' R/D tubing equipment, replace Pac-off. 01:15 02:45 1.50 1,324 7,524 COMPZ CASING RUNL P 1324' RIH w/BHA#15, 41 jts of slotted liner, liner top billet. 02:45 03:45 1.00 7,524 8,855 COMPZ CASING RUNL P 7524'Correct to EOP flag at 6200'- 9'. PUW 31.5k, Continue in hole. 03:45 04:00 0.25 8,855 8,940 COMPZ CASING RUNL P 8855'Tie into the RA marker correction of+ 12.5. 04:00 04:30 0.50 8,940 10,499 COMPZ CASING RUNL P 8940'Continue RIHTB 04:30 05:15 0.75 10,499 11,160 COMPZ CASING RUNL P 10499'PUW 35k, Bring pump up to 1.5bpm work pipe down pass hard spot. Page 16 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 05:30 0.25 11,160 11,160 COMPZ CASING RUNL P 11160'set down 3k, bring up pump and release from liner.TOL 9879.4'. 05:30 07:51 2.35 11,160 70 COMPZ CASING RUNL P POOH 07:51 08:21 0.50 70 70 COMPZ CASING OWFF P 70'Monitor well for flow, PJSM for LD 08:21 09:03 0.70 70 0 COMPZ CASING PULD P Lay down liner running BHA#15 09:03 09:33 0.50 0 0 PROD3 STK BOPE P Function test BOPE 09:33 11:21 1.80 0 72 PROD3 STK PULD P PJSM-MU AL2-01 drilling BHA#16 11:21 14:27 3.10 72 9,850 PROD3 STK TRIP P 72'RIH with AL2-01 drilling BHA#16, correction at GR+.5'. 14:27 16:27 2.00 9,850 9,874 PROD3 STK CIRC P 9,850'Circulate out 12.4 ppg completion fluid to 9.6 ppg drilling fluid, RBIH and tag top of billet at 8,874', PU 26k. 16:27 21:57 5.50 9,874 9,905 PROD3 STK KOST P 8,872.96' Kick off billet following time milling schedule 1,2,3,10&20 fph 21:57 22:12 0.25 9,905 9,905 PROD3 STK KOST P 9905' Drift window area, clean 22:12 00:00 1.80 9,905 9,978 PROD3 DRILL DRLG P 9905'drill ahead 1.45bpm 3679psi, BHP 4129,WHP 248, IA 326, OA 0 12/27/2013 Finished POOH,displaced well to 9.6ppg drilling fluid, Kick off of billet at 9873'. Drilled ahead to 10780'. 00:00 01:30 1.50 9,978 10,030 PROD3 DRILL DRLG P 9978'OBD 1.45bpm at 3675psi. BHP 4135,WHP 251, IA 326, OA 0,WOB 1.7k, ROP 45fph. 01:30 02:30 1.00 10,030 8,900 PROD3 DRILL WPRT P 10030'Wiper up hole PUW 25k 02:30 03:00 0.50 8,900 10,030 PROD3 DRILL WPRT P 8900'Wiper back in hole RIW 10k 03:00 04:54 1.90 10,030 10,180 PROD3 DRILL DRLG P 10030' BOBD 1.41 bpm at 3680psi, BHP 4161,WHP 247, IA 327, OA 0, WOB 1.5k, ROP 120fph 04:54 05:39 0.75 10,180 9,000 PROD3 DRILL WPRT P 10180'Wiper up hole. PUW 25k 05:39 06:18 0.65 9,000 10,180 PROD3 DRILL WPRT P 9,000'Wiper back in hole RIW 10k 06:18 07:42 1.40 10,180 10,330 PROD3 DRILL DRLG P 10180' BOBD 1.41 bpm at 3849 psi, BHP 4110,WHP 227, IA 328, OA 0, CW 5.57k,WOB 1.46k, ROP 120 fph 07:42 09:06 1.40 10,330 7,610 PROD3 DRILL WPRT P 10,330'-Wiper trip for tie-in at window 09:06 09:33 0.45 7,610 7,624 PROD3 DRILL DLOG P 7,610' Did not see RA, RBIH to 7,590'and tie into the RA marker correction of+15'. 09:33 10:48 1.25 7,624 10,337 PROD3 DRILL WPRT P 7,624'Wiper back in hole. RIW 10k 10:48 13:39 2.85 10,337 10,480 PROD3 DRILL DRLG P 10,337' BOBD 1.42 bpm at 3952 psi, BHP 4140,WHP 232, IA 333, OA 4, CW 2.23k,WOB 1.87k, ROP 100 fph 13:39 14:51 1.20 10,480 9,075 PROD3 DRILL WPRT P 10,480'Wiper up hole PUW 27k 14:51 15:36 0.75 9,075 10,480 PROD3 DRILL WPRT P 9,075'Wiper back in hole RIW 10k 15:36 18:06 2.50 10,480 10,630 PROD3 DRILL DRLG P 10480' BOBD 1.42 bpm at 3971 psi, BHP 4138,WHP 202, IA 335, OA 12, CW 3.63k,WOB 1.52k, ROP 90 fph Page 17 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:06 19:06 1.00 10,630 8,900 PROD3 DRILL WPRT P 10630'Wiper up hole. PUW 27k 19:06 20:06 1.00 8,900 10,630 PROD3 DRILL WPRT P 8900'Wiper back in hole. RIW 7k 20:06 22:36 2.50 10,630 10,780 PROD3 DRILL DRLG P 10630'BOBD 1.44bpm at 3705psi, BHP 4143,WHP 170, IA 340, OA 23, CTW 3k,WOB 1.5k, ROP 80fph. 22:36 00:00 1.40 10,780 8,462 PROD3 DRILL WPRT P 10780'Wiper up hole PUW 25k 12/28/2013 TD'd AL2-01 laterat at 11225'. Started wiper to the swap valves chasing sweep. 00:00 00:30 0.50 8,462 7,610 PROD3 DRILL WPRT P 8462', Continue wiper up hole. 00:30 00:45 0.25 7,610 7,618 PROD3 DRILL DLOG P 7610'tie into the RA correction of+ 15.5' 00:45 02:21 1.60 7,618 10,780 PROD3 DRILL WPRT P 7618'Wiper back in hole. RIW 9k 02:21 02:36 0.25 10,780 10,800 PROD3 DRILL DRLG P 10780', BOBD 1.41bpm at 3700psi, BHP 4143,WHP 210, IA 340, OA 27 02:36 05:06 2.50 10,800 10,800 PROD3 DRILL DRLG P 10800', New Mud at the bit. Continue drilling ahead. 05:06 05:42 0.60 10,800 10,930 PROD3 DRILL WPRT P 10930',Wiper up hole PUW 26k 05:42 06:12 0.50 9,950 10,930 PROD3 DRILL WPRT P 9950'Wiper back in hole. RIW 9k 06:12 09:12 3.00 10,930 11,080 PROD3 DRILL DRLG P 10930' BOBD 1.41bpm at 3935 psi, BHP 4193,WHP 280, IA 336, OA 9. 09:12 10:06 0.90 11,080 9,950 PROD3 DRILL WPRT P 11080' Wiper up hole PUW 26k 10:06 10:42 0.60 9,950 11,080 PROD3 DRILL WPRT P 9950' Wiper back in hole. RIW 7k 10:42 14:36 3.90 11,080 11,220 PROD3 DRILL DRLG P 11,080' BOBD 1.39 bpm at 3885 psi, BHP 4177,WHP 302, CW-4.5k, DHWOB 1.47k, ROP 30 fph, IA 338, OA 14. 14:36 19:36 5.00 11,220 72 PROD3 DRILL WPRT P 11,220' Called TD, pump 10/10 to/hi sweep,Wiper up hole to swabs, PUW 28k, choke plugging off RBIH to clear choke. 19:36 19:51 0.25 72 72 PROD3 DRILL CTOP P 72'Tag up and zero counters. Clean INJH 19:51 21:21 1.50 72 7,260 PROD3 DRILL WPRT P RIH 21:21 21:36 0.25 7,260 7,306 PROD3 DRILL DLOG P 7260',Tie into the K1 correction of+ 1.5' 21:36 00:00 2.40 7,306 11,225 PROD3 DRILL WPRT P Continue wiper in hole. Tag bottom at 11225' 12/29/2013 Performed wiper to the swab valves. RBIH, confirm TD, layed in completion fluid with beads, M/U slotted liner RIH,tagged up on billet with GS.Confir with town,decide to POOH to pick up 16 aditional jts of liner. 00:00 03:45 3.75 11,225 72 PROD3 DRILL TRIP P POOH laying in 12.4ppg completion fluid w/alpine beads up to 5200'and without beads to surface. 03:45 04:15 0.50 72 72 PROD3 DRILL OWFF P Surface, no-flow check well. Conduct PJSM/L/D drilling BHA. 04:15 06:00 1.75 72 0 PROD3 DRILL PULD P L/D drilling BHA#16 06:00 07:00 1.00 0 0 COMPZ CASING SFTY P PJSM-Running liner,prep floors for running liner. 07:00 08:30 1.50 0 873 COMPZ CASING PUTS P MU Bull nose, 28 jts 2 3/8"slotted liner, shorty deployment sleeve. Kick while running liner drill. Page 18 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:48 1.30 873 917 COMPZ CASING PULD P 873'MU Liner running BHA#17 09:48 13:24 3.60 917 10,754 COMPZ CASING RUNL P 917'RIH with BHA#17 and AL2-01 lower liner ass'y, IA 305, OA 0.-11 correction at flag, +12 correction at RA tie-in, continue RIH. 13:24 14:54 1.50 10,754 10,754 COMPZ CASING RUNL P 10,754'Sat down, Deployment sleeve and GS at 9,881'middle of AL2 billet, PU attempt to pass, PU 8k overpull, sat back down and bring on pump.3 bpm, PU clean 32k 100', several more attempts to pass same 10,754'unsuccessful, confer with town engineer. 14:54 18:00 3.10 10,754 917 COMPZ CASING RUNL T 10,754' POOH, Paint EOP flag at 6,100'. 18:00 19:00 1.00 917 917 COMPZ CASING OWFF T 917' On surface, monitor well for flow. Conduct PJSM 19:00 20:00 1.00 917 873 COMPZ CASING PUTB T 917' Lay down BHA#17. 20:00 21:15 1.25 873 1,376 COMPZ CASING PUTB T 873' PU/MU 16jts of 2 3/8"slotted liner to existing 28 jts(44 jts total) 21:15 21:33 0.30 1,376 1,376 COMPZ CASING SFTY T Kick while tripping drill with crew. P/U, and M/U safety joint onto liner lower down in slips. Mentoring new floorhand. UD safety joint. """"TT-Time 4.30min 21:33 22:03 0.50 1,376 1,376 COMPZ CASING PUTB T M/U BHI tools to liner. Strip INJH down onto liner. Test Tools. 22:03 00:00 1.95 1,376 COMPZ CASING RUNL T RIH w/BHA#18, and 44 jts of slotted liner. 12/30/2013 Finish POOH with liner assy, RIH, set lower AL2-01 liner at 11,225'. POOH, RIH, set upper AL2-01 liner at 9,848'with top of OH anchored billet at 9,770', POOH, RIH with KO/drilling BHA#20. 00:00 00:15 0.25 7,433 7,526 COMPZ CASING RUNL T Continue RIH w/AL2-01 liner assy. 00:15 00:30 0.25 7,526 7,521 COMPZ CASING RUNL T Correct to EOP flag 6100', Minus 5.38' PUW 30k. 00:30 01:00 0.50 7,521 8,945 COMPZ CASING RUNL T Continue in hole with AL2-01 liner assy. 01:00 01:15 0.25 8,945 8,976 COMPZ CASING RUNL T 8945'Tie into the RA marker correction of+9.5'. 01:15 02:00 0.75 8,976 10,788 COMPZ CASING RUNL T Continue RIH with AL2-01 liner assy. 02:00 03:00 1.00 10,788 10,788 COMPZ CASING RUNL T Stacking weight, P/U,work pipe at 50 fpm. Still stacking weight. Losing hole. Confer with town. 03:00 04:30 1.50 10,788 11,225 COMPZ CASING RUNL P 10625' RIH at 70 fpm, pumping 0.8bpm,to bottom 11225'. PUW 34. RBIHTB set down, bring pump up to 1.2bpm and release from liner. PUW 25k. 04:30 05:45 1.25 11,225 7,575 COMPZ CASING RUNL P Remove liner length from BHA. POOH 05:45 06:00 0.25 7,575 7,596 COMPZ CASING RUNL P 7575'Tie into the RA marker correction of+6' 06:00 07:45 1.75 7,596 44 COMPZ CASING RUNL P 7,596' POOH, paint EOP flag at 7,300'. Page 19 of 27" Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 07:45 08:15 0.50 44 44 COMPZ CASING OWFF P 44' Monitor well for flow. PJSM-LD BHA 08:15 09:30 1.25 44 0 COMPZ CASING PULD P Lay down BHA#18, PJSM-running liner, prep floors for liner run. 09:30 10:06 0.60 0 78 COMPZ CASING PUTB P MU Bull nose, 2 3/8"x 3.82"pup jt, 2 jts 2 3/8"slotted liner, OH anchored billet. 10:06 11:24 1.30 78 140 COMPZ CASING PULD P 74' MU liner running BHA#19. 11:24 16:00 4.60 140 9,848 COMPZ CASING RUNL P 140' RIH with liner running BHA#19, EDC open puming minimum,-1.5 correction at flag tie-in,close EDC, +1.5 correction at RA marker tie-in, continue RIH. 16:00 16:15 0.25 9,848 9,770 COMPZ CASING RUNL P 9,848' Sat down lightly 1.2k, PU to neautral, bring on pump, setting tool sheared at 3000 psi, set upper AL2-01 liner at 0° HS, PUW 28k, remove liner length from BHA. 16:15 20:00 3.75 9,770 78 COMPZ CASING RUNL P 9,770' POOH, Flow check at 7,397', no flow,continue POOH. 20:00 20:30 0.50 78 78 COMPZ CASING OWFF P 78' On surface, monitor well for flow 20:30 21:30 1.00 78 0 COMPZ CASING PULD P Lay down BHA#19, service injector head. 21:30 22:39 1.15 0 72 PROD4 STK PULD P PJSM-MU kick off/drilling BHA #20. 22:39 00:00 1.35 72 5,102 PROD4 STK TRIP P 72' RIH with KO/Drilling BHA#20, AKO 0.4+, IA 299, OA 0 12/31/2013 Kick off Anchored billet @ 9768 30R, Drill to 10160 midnight 00:00 00:45 0.75 5,102 7,630 PROD4 STK TRIP P Continue RIH w/kick off BHA. 00:45 01:00 0.25 7,630 7,668 PROD4 STK DLOG P Tie into the RA Marker correction of + 1.5'. 01:00 01:45 0.75 7,668 9,750 PROD4 STK TRIP P Continue RIH 01:45 03:45 2.00 9,750 9,750 PROD4 STK DISP P Displace well to drilling fluid. 03:45 04:03 0.30 9,750 9,768 PROD4 STK TRIP P RIH, and dry tag top of billet @ 9768', PUW 26k 04:03 10:33 6.50 9,768 9,771 PROD4 STK KOST P 9766.5' Bring pump up to 1.40bpm at 3697psi, BHP 4104,WHP 228, IA 305, OA 0 10:33 13:48 3.25 9,771 9,810 PROD4 STK KOST P Trouble getting off of billet. PUH and pump a high vis pill down to assist in weight transfer. 13:48 14:03 0.25 9,810 9,750 PROD4 STK KOST P 9810' PUH, drift billet area, looks clean. PUW 25k 14:03 14:18 0.25 9,750 9,810 PROD4 STK KOST P 9750' RBIH RIW 11k 14:18 16:18 2.00 9,810 9,920 PROD4 DRILL DRLG P 9810' Drill ahead in the AL2-02. 1.45bpm at 3650psi. BHP 4105, WHP 179, IA 323, OA 0. 16:18 16:48 0.50 9,920 8,830 PROD4 DRILL WPRT P 9920',Wiper up hole PUW 27.5k 16:48 18:18 1.50 8,830 9,920 PROD4 DRILL WPRT P 8830',Wiper back in hole. RIW 11k 18:18 21:06 2.80 9,920 10,070 PROD4 DRILL DRLG P 9920, Drill, 1.41 BPM @ 3630 PSI FS, BHP=4090, RIW=9K Page 20 of 27 • . Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:06 22:24 1.30 10,070 10,070 PROD4 DRILL WPRT P Wiper to 9000', PUW=27K, clean trip out and in, No Billet in sight 22:24 00:00 1.60 10,070 10,160 PROD4 DRILL DRLG P 10070', Drill, 1.4 BPM @ 3640 PSI FS, BHP=4110, Midnight depth 10160 01/01/2014 Drill 10160 to 10820 00:00 01:30 1.50 10,160 10,220 PROD4 DRILL DRLG P 10160', Drill, 1.4 BPM @ 3640 PSI FS, BHP=4110 01:30 04:30 3.00 10,220 10,220 PROD4 DRILL WPRT P Wiper to window with 5 X 5 sweeps and tie in for+12'correction, PUW=27K 04:30 07:00 2.50 10,220 10,370 PROD4 DRILL DRLG P 10220', Drill, 1.4 BPM @ 3630 PSI FS, BHP=4102 07:00 08:00 1.00 10,370 9,170 PROD4 DRILL WPRT P 10370'Wiper up hole. PUW 28.5k 08:00 08:30 0.50 9,170 10,370 PROD4 DRILL WPRT P 9170'Wiper back in hole RIW 8.3k 08:30 11:00 2.50 10,370 10,520 PROD4 DRILL DRLG P 10370' BOBD 1.41bpm at 3635psi. BHP 4121,WHP 187, IA 339, OA 32 """"Crossed fault at 10431' lost 0.3bpm returns temporily slowily coming back. 11:00 11:45 0.75 10,520 9,000 PROD4 DRILL WPRT P 10520',Wiper up hole. PUW 26 11:45 12:30 0.75 9,000 10,520 PROD4 DRILL WPRT P 9000',Wiper back in hole. RIW 8k 12:30 15:30 3.00 10,520 10,670 PROD4 DRILL DRLG P 10520', BOBD 1.44bpm at 3650psi, BHP 4138,WHP 176, IA 342, OA 40 15:30 17:00 1.50 10,670 7,610 PROD4 DRILL WPRT P 10670',Wiper up hole. PUW 28k 17:00 17:15 0.25 7,610 7,631 PROD4 DRILL DLOG P 7610',Tie into the RA marker correction of+ 13.5' 17:15 19:09 1.90 7,631 10,675 PROD4 DRILL WPRT P 7631',Wiper back in hole. RIW 12k, tagged up on billet @ 7650 with 5k, 40L TF, PUH run in at higher speed clean pass through 19:09 22:51 3.70 10,675 10,820 PROD4 DRILL DRLG P 10675 Drill, 1.4 BPM @ 3740 PSI FS, RIW=4.5K, DHWOB=1.5K, BHP=7137 22:51 00:00 1.15 10,820 10,379 PROD4 DRILL WPRT P Wiper to 8830, PUW=27K 31/02/2014 Drill 101820 to 11185', Stand by for phase three weather-7 hrs 00:00 00:18 0.30 10,379 10,820 PROD4 DRILL WPRT P Continue wiper to 8830, Stacking on way in hole 10,700'area 00:18 01:30 1.20 10,820 10,872 PROD4 DRILL DRLG P 10820', drill ahead, 1.4 BPM @ 3880 PSi FS, BHP=4160 01:30 05:18 3.80 10,872 10,970 PROD4 DRILL DRLG P 10872 couple of stalls, hard to get going drilling,stacking, BHA wipers, PUW=35K, Cut into HRZ @ 10872 still in at 10970'wiper 05:18 06:06 0.80 10,970 9,800 PROD4 DRILL WPRT P 10970',Wiper up hole. PUW 26k 06:06 06:51 0.75 9,800 10,970 PROD4 DRILL WPRT P 9800',Wiper back in hole. RIW 7k 06:51 08:06 1.25 10,970 11,014 PROD4 DRILL DRLG P 10970' BOBD, 1.42bpm at 3700psi.BHP 4196,WHP 77, IA 344, OA 58 Page 21 of 27 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:06 09:36 1.50 11,014 7,392 PROD4 DRILL TRIP T ****Phase 3, pull up into casing to standby 09:36 16:36 7.00 7,392 7,392 PROD4 DRILL CIRC T Open EDC, circulate while slowly recepricating in casing. 16:36 16:51 0.25 7,392 7,610 PROD4 DRILL TRIP T 7154', Field went to Phasel, RBIH to tie in depth 16:51 17:03 0.20 7,610 7,630 PROD4 DRILL DLOG T Tie into the RA correction of+ 17'. 17:03 18:39 1.60 7,630 11,019 PROD4 DRILL WPRT T Continue RIH 18:39 20:27 1.80 11,019 11,070 PROD4 DRILL DRLG P 11019',drill, 1.4 BPM @ 3940 PSI FS, BHP=4279 20:27 00:00 3.55 11,070 11,185 PROD4 DRILL DRLG P 11070', Stacking, no motor work, BHA Wiper with good shove on bottom, Drilling ahead, midnight depth 10185 01/03/2014 TD AL2-02 Lat @ 11,200, Swab Wiper, Run AL2-02 lower liner section to TD, 00:00 00:30 0.50 11,185 11,200 PROD4 DRILL DRLG P Drill to TD @ 11,200', Start Lo-Hi sweeps 00:30 02:36 2.10 11,200 7,600 PROD4 DRILL WPRT P Call TD at plan depth of 11200', Sweeps out chase to swab, PUW=31K 02:36 02:48 0.20 7,600 7,628 PROD4 DRILL DLOG P Log tie in for counter data, +11' correction,continue to swab 02:48 04:48 2.00 7,628 72 PROD4 DRILL WPRT P Continue to swab,Open EDC 04:48 06:48 2.00 72 7,600 PROD4 DRILL WPRT P Tag up, reset depths to BHA length, continue wiper to bottom 06:48 07:03 0.25 7,600 7,625 PROD4 DRILL DLOG P 7600',Tie into the RA, +2.5'. 07:03 09:03 2.00 7,625 11,200 PROD4 DRILL WPRT P 7625', Continue RIH to verify TD. 09:03 09:21 0.30 11,200 11,200 PROD4 DRILL TRIP P Verified TD 11200', PUW 25.5k 09:21 12:51 3.50 11,200 72 PROD4 DRILL TRIP P POOH, Laying in 12.4ppg liner running pill with alpine beads up to 6200' 12:51 13:21 0.50 72 72 PROD4 DRILL SFTY P Surface, monitor well for flow, Conduct PJSM 13:21 14:21 1.00 72 0 PROD4 DRILL PULD P L/D BHA#20 Drilling tools 14:21 14:51 0.50 0 0 COMPZ CASING SFTY P Prep to M/U AL2-02 liner assy. Conduct PJSM 14:51 19:27 4.60 0 1,492 COMPZ CASING PUTB P Start M/U AL2-02 lower liner with non ported bullnose,46 Jts slotted liner, and shorty deployment sleeve, M/U coiltrack BHA. M/U to coil and surface test 19:27 20:57 1.50 1,492 7,404 COMPZ CASING TRIP P RIH with liner 20:57 21:03 0.10 7,404 7,386 COMPZ CASING DLOG P 7404 at flag, correct to 7392.34 for -12.28, PUW=30K 21:03 21:33 0.50 7,386 8,690 COMPZ CASING TRIP P Continue in with liner, RIW=13.9K 21:33 21:45 0.20 8,690 8,739 COMPZ CASING DLOG P Log HRZ for tie in for+13' 21:45 22:33 0.80 8,739 10,648 COMPZ CASING TRIP P RIH with liner Page 22 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:33 00:00 1.45 10,648 11,200 COMPZ CASING TRIP P Set down @ 10648,work pipe, loosing ground on P/U's.start pumping down coil .7 BPM. BHP went from 3950 static to—4100 PSI pumping. Liner went smoothly to bottom 40-50 FPM. Pump off and and trip out. Lost 9 bbls on trip in from surface 31/0-4/2014 Complete AL2-02 Liner 10,200'to 7880, Start BOPE Test.Witness waived by Jeff Jones AOGCC 00:00 03:06 3.10 11,200 49 COMPZ CASING TRIP P Trip out of well after setting AL2-02 lower liner section at 11,200', Paint EOP flags @ 7700 and 5600 03:06 04:06 1.00 49 0 COMPZ CASING PULD P On Surface, Start flow check, PJSM lay down BHA on dead well, Lost 16 BBI 12.4 completion fluid surface to surface 04:06 07:36 3.50 0 1,158 COMPZ CASING PUTB P PJSM, M/U BHA#22, Ported bullnose, 10'pup, 59 JTS 2 3/8" slotted liner, liner top billet, 5:45 joint 25 BOP drill, M/U safety joint and deploy, 3 Minutes 07:36 07:51 0.25 1,158 1,852 COMPZ CASING SFTY P ****Joint 38, Kick while tripping drill. 2min 42sec Continue making up completion 07:51 10:51 3.00 1,852 7,515 COMPZ CASING RUNL P RIH,AL2-02,w/upper liner section 59 jts of slotted liner and liner top billet. 10:51 11:06 0.25 7,515 7,515 COMPZ CASING DLOG P Correct to the EOP flag at 5600' correction of-4'. PUW 28.5' 11:06 12:15 1.15 7,515 9,751 COMPZ CASING RUNL P Continue in hole to bottom. 12:15 13:45 1.50 9,751 7,570 COMPZ CASING RUNL P 9751',Tag up on bottom. PUW 33k, pump 1.3bpm at 3600psi. PUW 26k, remove liner BHA from counter,and pull up into casing to displace well to 9.6ppg drilling fluid. 13:45 16:15 2.50 7,570 53 COMPZ CASING RUNL P POOH 16:15 18:00 1.75 53 0 COMPZ CASING PULD P Conduct PJSM, Updeploy Liner running BHA#22 18:00 18:30 0.50 0 0 PROD5 DRILL CTOP P Crew change,valve checklist 18:30 20:45 2.25 0 0 PROD5 DRILL OTHR P PJSM, R/U tools and lubricator and set 2 way check, rig down and load out lubricator. Grease crew serviced tree 20:45 22:30 1.75 0 0 PROD5 DRILL CIRC P Remove check valves in UQC and install nozzle,stab injector on well and circ coil to fresh water 22:30 00:00 1.50 0 0 PROD5 DRILL BOPE P Start full BOPE test,Witness waived by Jeff Jones AOGCC 31/05/2014 Completed BOPE test, RIH with BHA#23, Dry tag billet @ 7878 00:00 08:30 8.50 0 0 PROD5 DRILL BOPE P Continue full BOPE test.Witness waived by Jeff Jones,AOGCC Page 23 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:30 2.00 0 0 PRODS DRILL BOPE P Continue BOP test 10:30 11:30 1.00 0 0 PROD5 DRILL BOPE T Call FMC, Delayed due to Nabors 7es possession of lubricator, FMC crew change out. Replace R1, R2, C9. Retest R1 - pass, R2-pass, C9-fail. **** 1 hr Nabors Downtime 11:30 12:30 1.00 PROD5 DRILL BOPE T Regrease wellhead Tango#1 valve and retest--Fail 12:30 13:00 0.50 0 0 PROD5 DRILL SFTY T Discuss Human Energy Incidents power point sent from ConocoPhillips HSE,Wells Supt. 13:00 14:30 1.50 0 0 PROD5 DRILL BOPE P PJSM with FMC, Load lubricator and equipment, P/T lubricator and pull 2way check. 14:30 15:30 1.00 0 0 PROD5 DRILL BOPE T Test C9 valve-pass, Install new spring on INJH counter. **** 1 hrs Nabors Downtime 15:30 18:00 2.50 0 0 PRODS STK PULD P PJSM w/rig crew for stabbing INJH to swap coil to drilling mud and install BHI checks. 18:00 19:30 1.50 0 0 PRODS STK PULD P Crew change, PJSM, Continue to deploy BHA#23,AL3 Lateral section with.6°motor and RB Hughes Bi Center 19:30 19:42 0.20 0 0 PROD5 STK SFTY P During deployment ops BHA set in deployment rams bled off PDL to shaker and initiated LEL alarm. Shut choke in and assessed situation. Sensor got wet with mud during bleed off. Secondary monitor showed levels below LEL threshold. Lined up to TT for bleed offs of PDL, Cont pressure deploy 19:42 20:18 0.60 0 72 PROD5 STK PULD P Continue Pressure deploy, Make up coil to BHA and surface test, Strip on tag up and set counters 20:18 23:06 2.80 72 7,270 PROD5 STK TRIP P Trip in with EDC open 23:06 23:18 0.20 7,270 7,307 PROD5 STK DLOG P Tie into HRZ for zero foot correction 23:18 00:00 0.70 7,307 7,879 PROD5 STK TRIP P RIH to 7475, Shut EDC, continue in, clean pass through window, Dry tag billet at 7879, PUH and bring on pumps 01/06/2014 Drill off LTB @ 7979, Drill ahead to 8749, Lost 37 BBIs/24 Hrs 00:00 01:00 1.00 7,879 7,879 PROD5 STK KOST P Pumps on @ 1.35 BPM @ 3800 PSI FS, BHP=3957,stall on first attemp then tag up with motor work and DHWOB @ 7878 Mill @ 1 FPH 01:00 01:30 0.50 7,879 7,880 PROD5 STK KOST P Mill @ 2 FPH, 1.34 BPM @ 3800 PSI FS, BHP=3960 01:30 02:00 0.50 7,880 7,881 PRODS STK KOST P Mill @ 3 FPH, 1.34 BPH @ 3833 PSI FS, BHP=3949 Page 24 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 I 03:42 1.70 7,881 7,930 PROD5 DRILL DRLG P Drill @ 10 fph to 7886 then drill ahead, 1.34 BPM @ 3950 PSI FS, BHP=3950, Sent new 9.6 PPG Flo Pro @ 7909,At bit @ 7923 03:42 03:54 0.20 7,930 7,930 PRODS DRILL WPRT P 7930',Wiper past billet, PUW=24K, Looks good past billet 03:54 07:24 3.50 7,930 8,080 PRODS DRILL DRLG P 7930 Drill, 1.35 BPM @ 3850 PSI FS, BHP=3991,WHP=86 07:24 07:54 0.50 8,080 7,685 PROD5 DRILL WPRT P 8080'Wiper up hole PUW 27k 07:54 08:24 0.50 7,685 8,080 PROD5 DRILL WPRT P 7685',Wiper back in hole RIW 12k 08:24 10:42 2.30 8,080 8,230 PRODS DRILL DRLG P 8080', BOBD 1.32bpm at 4024psi. BHP 4008,WHP 82, IA 309, OA 0 10:42 11:12 0.50 8,230 7,685 PRODS DRILL WPRT P 8230',Wiper up hole. PUW 26k 11:12 11:42 0.50 7,685 8,230 PRODS DRILL WPRT P 7685',Wiper back in hole. RIW 12k 11:42 15:12 3.50 8,230 8,380 PROD5 DRILL DRLG P 8230', BOBD 1.31bpm 3800psi. BHP 4010, IA 323, OA 4 15:12 15:54 0.70 8,380 7,603 PRODS DRILL WPRT P 8380',Wiper up hole PUW 27k 15:54 16:09 0.25 7,603 7,618 PRODS DRILL DLOG P 7603',tie into the RA marker correction of+5'. 16:09 16:36 0.45 7,618 8,380 PRODS DRILL WPRT P 7618', Continue wiper in hole. RIW 11k 16:36 19:06 2.50 8,380 8,530 PROD5 DRILL DRLG P 8380', BOBD 1.43bpm at 3800psi, BHP 4034,WHP 116, IA 324, OA 4 19:06 19:42 0.60 8,530 7,700 PRODS DRILL WPRT P 8530',wiper up hole. PUW 27 19:42 20:12 0.50 7,700 8,530 PRODS DRILL WPRT P 7700',wiper back in hole RIW 11k 20:12 22:12 2.00 8,530 8,680 PRODS DRILL DRLG P 8530', BOBD 1.43bpm at 3796psi, BHP 4032,WHP 153, IA 329, OA 13 22:12 22:42 0.50 8,680 7,750 PRODS DRILL WPRT P 8680',Wiper up hole PUW 26k 22:42 23:12 0.50 7,750 8,680 PRODS DRILL WPRT P 7750',Wiper back in hole. RIW 10k 23:12 00:00 0.80 8,680 8,749 PRODS DRILL DRLG P 8680', BOBD 1.40bpm at 3650psi. BHP 4010,WHP 149, IA 334, OA 22 01/07/2014 TD @ 9130, Swab Wiper, Lay in completion fluid, P/U liner RIH 00:00 01:00 1.00 8,749 8,830 PRODS DRILL DRLG P Drilling, 1.4 BPM @ 3630 PSI FSm BHP=4047 01:00 02:30 1.50 8,830 8,830 PRODS DRILL WPRT P Wiper to window with sweeps and tie in, Sweeps brought out addtional cuttings. Correct+5'@ RA marker, Clean trip up and down 02:30 04:30 2.00 8,830 8,980 PRODS DRILL DRLG P 8830' Drill Ahead, 1.5 BPM @ 3650 PSI FS, BHP=4045 04:30 05:30 1.00 8,980 8,980 PRODS DRILL WPRT P Wiper trip to 7900, PUW=25K, Clean trip 05:30 07:45 2.25 8,980 9,130 PRODS DRILL DRLG P 8980', Drill Ahead, 1.5 BPM @ 3564 PSI FS, BHP=4037, 9130 Call TD, Pump Sweeps 07:45 10:45 3.00 9,130 57 PRODS DRILL WPRT P Sweeps coming out,Call TD @ 9130 CTMD. start swab wiper, PUW=26.5K, Open EDC @7495, See overpulls at 7900 and 7878 Page 25 of 27 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 10:45 13:45 3.00 57 9,130 PROD5 DRILL TRIP P Tag up, reset depths to BHA length, RBIH to verify depth,tag bottom @ 9130'CTMD. 13:45 17:00 3.25 9,130 71 PROD5 DRILL TRIP P POOH while laying in 12.4 ppg kill weight liner running pill with beads and lubricants, See same slight overpulls at 7900 and 7878. Flag pipe at 7473'and 5872'. 17:00 18:30 1.50 71 71 PROD5 DRILL SFTY P At Surface, Monitor well for flow,shut in choke, Crew change out while conducting safety stand down with Wells Superintendent and Wells Manager. PJSM to lay down BHA #23. 18:30 19:06 0.60 71 0 PRODS DRILL PULD P Lay down BHA#23,drilling tools. 19:06 19:54 0.80 0 0 COMPZ CASING SFTY P Prep to make up AL3 liner assembly. Conduct PJSM. 19:54 23:30 3.60 0 1,668 COMPZ CASING PUTB P Fill hole W 2 bbls brine. Start making up AL3 liner with non ported bullnose,40 joints of slotted liner, 11 joints of solid, a pup and a deployment sleeve with a polished seal bore. Make up to coiltrack and coil, Surface test tool 23:30 00:00 0.50 1,667 2,985 COMPZ CASING TRIP P Trip in EDC shut, Midnight depth 2985 01/08/2014 TIH w/AL3 liner assembly, release from liner @ 9,130'. TOOH, circulating well to seawater, diesel from 2,900'. PUD BHA#24, Set BPV. Blow down coil and surface lines, remove inner reel lines, start reel swap. 00:00 01:18 1.30 2,985 7,475 COMPZ CASING TRIP P Trip in with AL3 Liner 01:18 01:24 0.10 7,475 7,467 COMPZ CASING DLOG P Correct at flag for-7.5, PUW=36K 01:24 02:12 0.80 7,467 9,130 COMPZ CASING TRIP P Continue trip in, pass second EOP flag @ 9064.08, Tag at 9129', PUW=35K, Set back down and release from liner, PUW=25K, Reset depth to 7476.44. Top of Seal Bore assembly 7506'. 02:12 03:42 1.50 9,130 9,130 DEMOB WELLPF DISP P Pump 15 BBI hi vis spacer followed by Seawater 03:42 05:48 2.10 9,130 27 DEMOB WELLPF FRZP P Trip out displacing to seawater, PUW=23K, Goto diesel @ 5580',tag up 05:48 06:42 0.90 9,130 27 DEMOB WELLPF SFTY P PJSM 06:42 08:18 1.60 9,130 27 DEMOB WELLPF PULD P Pressure undeploy BHA#24, liner running tools. 08:18 08:30 0.20 27 0 DEMOB WHDBO SFTY P PJSM 08:30 10:00 1.50 0 0 DEMOB WHDBO NUND P Set type H BPV 10:00 10:12 0.20 0 0 DEMOB WHDBO SFTY P PJSM 10:12 11:00 0.80 0 0 DEMOB WHDBO DMOB P Power wash Injector and jet stack. 11:00 11:12 0.20 0 0 DEMOB WHDBO SFTY P SLB PJSM Page 26 of 27 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode -T Comment 11:12 12:24 1.20 0 0 DEMOB WHDBO DMOB P Rig up SLB, difficulty starting deck motor, Deck motor started,warming up, attempt to cool down fluid end& developed hydraulic leak in power pack hose. Rigged down disabled pump, dispatched replacement from Deadhorse. 12:24 13:36 1.20 0 0 DEMOB WHDBO DMOB T Rig up SLB, difficulty starting deck motor, Deck motor started,warming up,attempt to cool down fluid end& developed hydraulic leak in power pack hose. Rigged down disabled pump,dispatched replacement from Deadhorse. Continue to move forward with prep of rig for reel swap. 13:36 13:48 0.20 0 0 DEMOB WHDBO SFTY T PJSM N2 unit delayed by 7es rig move. 13:48 18:00 4.20 0 0 DEMOB WHDBO DMOB P Flush rig iron and stack with corrosion inhibition pill. N2 unit on pad, rigging up, cool down, PT-3500 psi,blow down reel and remaining iron w 15 k scf N2, bleed lines to zero. 18:00 00:00 6.00 0 0 DEMOB WHDBO DMOB P Remove inner reel lines, unstab coil, start reel swap. 01/09/2014 Continue with reel swap 00:00 20:00 20.00 0 0 DEMOB WHDBO DMOB P Continue with reel swap Rig Release @ 8pm Page 27 of 27 �TrpJ i2c • • Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Tuesday, October 15, 2013 3:35 PM To: jason.burke @conocophillips.com Cc: Bettis, Patricia K(DOA); Hunt,Jennifer L(DOA) Subject: 2G-12 (PTD 184-128, Sundry 313-479) Attachments: 2G-12 10-403.pdf Jason, We have changed the well class before and after the proposed work to be consistent with our well database. Since 2G- 12 was changed to producer status for flowback greater than 30 days,the well is currently classified as a producer. Since this well is a plug-for-redrill,the well status after proposed work is"suspended". Attached please find a modified Sundry application (313-479)with changes highlighted in yellow. Please make the changes on your sundry copy. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonr alaska.gov SCANNED NOV ?D13 1 • •oF 774, ��\\I s, THE STATE Alaska Oil and Gas 1 o 1 ASKA Conservation Commission Witt GOVERNOR SEAN PARNELL 71 333 West Seventh Avenue rh: off; Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 Jason Burke CTD Engineer a� ConocoPhillips Alaska, Inc. f Y P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2G-12 Sundry Number: 313-479 Dear Mr. Voss: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this" day of September, 2013. Encl. RECEIVED STATE OF ALASKA �� • AL IS6I OIL AND GAS CONSERVATION COMMON 1 �`�L, SEP 0 6 2013 APPLICATION FOR SUNDRY APPROVALSG�•I( 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill Perforate New Pool fl Repair w ell r Change Approved Program r Suspend fl Rug Ferforations P Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate [ Alter casing fl Other: r 2.Operator Name: 4.Current Well Class: °" 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development N(v\'L=fcploratory 184-128 • 3.Address: Stratigraphic r\\, Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 \D 1 50-029-21159-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F.7 2G-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25667• 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): 8167• 6622 - 7971' - 6446' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116' 116' SURFACE 2848 9.625 2884' 2730' PRODUCTION 8019 7 8053' 8517' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7582'-7600',7615'-7654' 6120'-6135',6148'-6180' 3.5 J-55 7514.7 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER MD=7485 TVD=6047 SSSV-BAKER FVL SSSV MD=1782 TVD=1779- / 12.Attachments: Description Summary of Proposal • 13. Well Class after proposed work: r Vi 7firl i3 Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: V'IFIt"II5)6, ,/ 9/20/2013 Oil r Gas r WDSPL E Suspended ry 16.Verbal Approval: Date: WINJ GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG f. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Burke @ 265-6097 Email: Jason.Burke@conocophillips.com Printed Name Ja on Bur Title: CTD Engineer Signature Phone:265-6097 Date 0,-5—.7:6/2 Commission Use Only Sundry Number: 313. �C/ Conditions of approval: Notify Commission so that a representative may witness V� 1 E-f' Plug Integrity n BOP Test /Mechanical Integrity Test r Location Clearance fl RBDMS OCT 1 0 2� Other: 1X C /7,) z 6- Ii 4O 1.7C2/�� 5 ' � a.t-) xei 1 7 C z' appiy, yr-d 71c ;2l-' 4-4G 7_-5', 11 7- L/-) (/ ) fv P l'1 A- I.II-1r pce-3 s cict4 7rd, Spacing Exception Required? Yes 0 No Subsequent Form Required: /0 „- 4/)-- — A APPROVED BY 9 Approved by: r COMMISSIONER THE COMMISSION Date: /`///---3 Appr•vecIapplication is valid tor 12 months trom the date of approval. Form 10-403(Revised 10/2012) Submit Form and Attachments in Duplicate �\l\1 tJRIGINAL 0, • • RECEIVED SEP 0 6 2013 Conoco Phillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 4, 2013 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to plug the A sand perforations in 2G-12 well. This operation will allow us to prepare the well for drilling operations to commence later this year. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A sand perfs in this manner. The objective of this plugging operation is to plug back the A sand, and provide a medium to drill a pilot hole and set a whip-stock for the future CTD operation. Drilling permits with quarter-mile review will be requested at a later date. This well will be ultimately classified as WINJ. Attached to this application are the following documents that explain the proposed job operations. — Sundry summary — Sundry application form for 2G-12 — Current wellbore schematic — Proposed wellbore schematic — Proposed CTD schematic If you have any questions or require additional information please contact me at my office 907-265-6097. Sincerel , -s• :urke ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 2G-12 CTD Summary for Perforating & Plugging Sundry (10-403) Summary of Operations: Well 2G-12 is a Kuparuk A-sand injector well equipped with 31/2"tubing and 7"production casing. Fg proposed A-sand CTD laterals will increase reservoir exposure in the fault block. Prior to drilling,the existing A sand perfs in 2G-12 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 AAC 25.112(c)(1)to plug the A sand perfs in this manner. The 3-1/2"tubing in the tubing tail will be perforated(7505'-7507' 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 sand perfs with cement, a pilot hole will be drilled through the cement to 7,630' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2G- 12A sidetrack will exit the 7"casing at 7,580' MD and will target the A4 sand south of the existing well with a 3,220' lateral. The hole will be completed with a 2-%" slotted liner to the TD of 10,800' MD with an aluminum billet at 9,800' MD. The 2G-12AL1 lateral will kick off from the aluminum billet at 9,800' MD and will target the A5 sand south of the existing well with a 1000' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,800' MD with an aluminum billet at 9,200' MD. The 2G-12AL2 will kick off from the aluminum billet at 9,200' MD and will target the A4 sand in the eastern fault block of the existing well with a 1,900' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,100' MD with an aluminum billet at 7,840' MD. The 2G-12AL3 will kick off from the aluminum billet at 7,840' MD and will target the A4 on the east side of the fault block and climb into the AS sand, drilling in the eastern fault block with a 3,260' MD lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,100' MD ran back into the tubing tail to 7,500' MD. CTD Drill and Complete 2G-12 Laterals: October 2013 -1 Coo C40/'• iO" e j:Fr Pre-CTD Work A 117517 2- 1(, j' p 5 / 1. RU Slickline. a. Drift and tag PBTD b. Obtain static bottom hole pressure,(SBHP) 2. RU Eline:Perforate tubing tail at 7505'-7507' RKB (2' of perfs) 3. RU coil:Mill out Camco `D' nipple out at 7,502' MD Place cement in the 7"casing, squeeze off A sand existing perfs. 4. RU Slickline. Tag top of cement and pressure test. RD Slick-line. 5. Prep site for Nabors CDR2-AC,including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2G-12A Sidetrack(A4 sand,south) Page 1 of 2 9/5/2013 • • a. Drill 2.80"high-side pilot hole through cement to 7,630' MD Y C' b. Drift pilot hole with whipstock dummy ! c. Set whip-stock at 7,580' MD with high-side orientation. d. Mill 2.80"window at 7,580' MD. e. Drill 2.70"x 3"bi-center lateral to TD of 10,800' MD f. Run 2%"slotted liner with an aluminum billet from TD up to 9,800' MD 3. 2G-12AL1 Lateral(A5 sand,south) a. Kick off of the aluminum billet at 9,800' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,800' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 9,200' MD 4. 2G-12AL2 Lateral(A4 sand,south) a. Kick off of the aluminum billet at 9,200' MD b. Drill 2.70"x 3"bi-center lateral to TD of 11,100' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 7,840' MD 5. 2G-12AL3 Lateral(A5 sand,south) a. Kick off of the aluminum billet at 7,840' MD b. Drill 2.70"x 3"bi-center lateral to TD of 11,100' MD c. Run 2%"slotted liner from TD up to 7,500' MD, inside the 3'h"tubing tail 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Pre-produce before returning to injection. Page 2 of 2 9/5/2013 . r KUP 2G-12 • • u Conoco 1M1P5 / ' Well Attributes Max Angle&M_D TD /'1Ii151ta,WIC. (".i i" Wellbore API/DWI Field Name Well Status Incl(") MD(ftKB) Act Btm(ftKB) CbncoRVlaps 500292115900 KUPARUK RIVER UNIT INJ 48.45 3,000.00 8,167.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Wall Confg:-2G-12,7/11/2012609:21 AM SSSV:LOCKED OUT Last WO: 2/11/1987 40.98 9/24/1984 Schematic-Actual Annotation Depth(ROB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,933.0 6/11/2011 Rev Reason:WELL REVIEW osborl 7/11/2012 Casing Strings "" Casing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(ND)...String Wt...String... String Top Thrd 1 r CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H-40 WELDED HANGER,32 Casing Description String 0... String ID...Top(BOB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd t ' SURFACE 95/8 8.921 36.0 2,884.2 2,729.5 36.00 L-80 BTC 10.75"x9.625" Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String Wt...String... String Top Thrd I ' PRODUCTION 7 6.276 34.4 8,053.2 6,5171 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 31/2 2.992 32.0 7,514.7 6,064.3 9.30 J-55 EUE8rdABM OD Completion Details Top Depth (TVD) Top Incl Nomi... II Top(ftKB) (RKB) (1 Rem Description Comment ID(in) 32.0 32.0 0.10 HANGER McEVOY TUBING HANGER 3.500 1igy'. 1,781.6 1,778.7 13.11 SAFETY VLV BAKER FVL SSSV(LOCKED OUT 1/3/1989) 2.810 7,471.5 6,028.4 34.31 PBR BAKER PBR w/SEAL ASSEMBLY 2.810 7,485.3 6,039.8 34.24 PACKER BAKER FHL PACKER 3.000 7,502.4 6,054.1 34.12 NIPPLE CAMCO'D'NIPPLE 2.750 7,513.9 6,063.6) 34.07 SOS BAKER SHEAR OUT SUB 2.992 CONDUCTOR, 36116 - Perforations&Slots " , Shot i Top(TVD) Bloc(TVD) Dens it Top(SOB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 7,582.0 7,600.0 6,120.0 6,134.9 A-5,2G-12 11/1/1984 4.0 IPERF 4"Schlum.Casing 7,615.0 7,654.0 6,147.5 6,179.9 A-4,2G-12 11/1/1984 4.0 IPERF 4"Schlum.Casing SAFETY VLV, 1,782 i' Notes:General&Safety Milt End Date Annotation 6/12/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE , l 10.75"x9.625", 36-2,884 illik GAS LIFT, ' 7,429 PBR,7,471 PACKER,7,485 NIPPLE,7,502 f.... SOS,7,514 isilak IPERF, 7,582-7,600 inn I 1 — — Mandrel Details IPERF, Top Depth Top r Pon 7,615.7,654 (ND) Inc! OD Valve Latch Size TRO Run Stn Top(RKB) (MB) (•) Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 7,428.8 5,993.3 34.52 OTIS LBX 1 1/2 GAS LIFT DMY RO-5 0.000' 0.0 2/19/1987 PRODUCTION, TD,8,67\ • A ■ 2G-12 Proposed Plugging 3-1/2"Baker FVL SSSV @ 1781'MD(locked out) 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 16"62#H-40 shoe @ 116'MD 10-3/4"by 9-5/8"36# L-80 shoe @ 2884' 3-1/2"Camco MMG gas lift mandrel @ 7429' MD • Baker 3-1/2"PBR @ 7471 MD(2.81"ID) Baker FHL packer @ 7485'MD(3.0"ID) 3-1/2"Camco D landing nipple @ 7502'MD(2.75"min ID, No-Go) 3-1/2"tubing tail @ 7514'MD -: -mom ) V jo Ile/LC A-sand perfs 7582'-7600'MD • 7615-7654'MD IN 1 `r5tk 76 3o 7"26#J-55 shoe @ 8053'MD 2G-12 Proposed CTD Sidetrack 3-1/2"Baker FVL SSSV @ 1781'MD(locked out) 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 16"62#H-40 — shoe @ 116'MD 10-3/4"by 9-5/8"36# L-80 shoe @ 2884' 3-1/2"Camco MMG gas lift mandrel @ 7429' MD • Baker 3-1/2"PBR @ 7471 MD(2.81"ID) Baker FHL packer @ 7485'MD(3.0"ID) 3-1/2"Camco D landing nipple @ 7502'MD(2.75"min ID, No-Go) 3-1/2"tubing tail @ 7514'MD KOP @ 7580'MD AS East of fault AL3 wp02 11100 Ft TD A-sand perfs `. ILat#4 I (3260 ft) 7582'-7600'MD • 7615-7654'MD \\\���� � ------------------------------------------- A4 East of fault AL2 wp03 11100 ft TD(1900 ft) /i ILat#3 Billet @ 7840'MD ` . I A5 West of fault ILat#2 I AL1 wp04 [Fault 2 I ` \10800 ft TD(1000 ft) Billet @ 9200'MD ILat#1 A4 West of fault A wp06 10800 ft TD(3220 ft) 7"26#J-55 shoe @ Billet @ 9800'MD 8053'MD • • • Ferguson, Victoria L (DOA) From: Burke,Jason <Jason.Burke @conocophillips.com> Sent: Tuesday, September 10, 2013 12:49 PM To: Ferguson,Victoria L(DOA) Cc: Venhaus, Dan E Subject: RE:2G-12 (PTD 184-128, Sundry 313-479) Oops, sorry. The well head is McEvoy Gen I, 5000 psi Ippr- ConocchilIips Jason Burke CID Engineer- Greater LCuparuk Area 700 Cj St#1950 .anchorage,AX 99501 (0):(9o7)-265-6o97 (JO(907)-231-4568 Jason.Burke @conocophillips.com From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson©alaska.gov] Sent:Tuesday, September 10, 2013 12:14 PM To: Burke, Jason Subject: [EXTERNAL]RE: 2G-12 (PTD 184-128, Sundry 313-479) No, I was looking for the current wellhead, FMC Gen x and pressure rating of flanges. From: Burke, Jason [mailto:Jason.Burke@conocophillips.com] Sent: Tuesday, September 10, 2013 12:11 PM To: Ferguson, Victoria L(DOA) Cc: Venhaus, Dan E Subject: RE: 2G-12 (PTD 184-128, Sundry 313-479) Victoria The MPSP from 8/5/13 (BHP= 3583 psi, 6148'TVD, .1 psi/ft gradient) is 2968 psi As for the current WHP,this well is an injector that is currently on flow back(trying to reduce pressures), are you looking for a current flowing pressure, an anticipated injection pressure or a static pressure? Thanks ConocchiIIips Jason Burke CTD Engineer- Greater 9Cuparuk.area 700 G St#1950 .anchorage, AX 99501 (0): (9o7)-265-6097 1 • (M):(9o7)-231-4568 Jason.Burke@conocophillips.com From: Ferguson,Victoria L(DOA) [mailto:victoria.ferguson @alaska.gov] Sent:Tuesday, September 10, 2013 10:31 AM To: Burke,Jason Subject: [EXTERNAL]2G-12 (PTD 184-128, Sundry 313-479) Jason, What is the MPSP and the current wellhead? Thank, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 vi ri .f r n alask ov cto a e guso a q 2 RECEIVED STATE OF ALASKA 0 MAY 0 2 2013 ALA.OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS QGC 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other WINJ to PROD Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension Change Approved Program rOperat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: V 4.Well Class Before Work: 5.Permit to Drill Number: '' ConocoPhillips Alaska, Inc. Development fl Exploratory r 184-128 3.Address: 6.API Number: ,/Stratigraphic r Service 50-029-21159-00 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): ,/ 8.Well Name and Number: ✓ ADL 25667 ALK 2588 2G-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8167 feet Plugs(measured) None true vertical 6622 feet Junk(measured) None Effective Depth measured 7971 feet Packer(measured) 7485,7502 true vertical 6446 feet (true vertical) 6047,6062 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 116 116 0 0 SURFACE 10.75' 2848 12 2884 2729 0 0 PRODUCTION 8019 12 8053 6517 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7582-7600, 7615-7654 _. O,-' 2, True Vertical Depth: 6120-6135,6147-6180 SCANNED }��� � ��� /0 1 3 Tubing(size,grade,MD,and ND) 3.5,J-55,7514 MD,6071 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 7485 MD and 6047 ND NIPPLE-CAMCO'D'NIPPLE @ 7502 MD and 6062ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A 1086 895 2681 Subsequent to operation 15 150 1662 250 150 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service jl, Stratigraphic r 16.Well Status after work: Oil P Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-126 Contact Paul Provencio Email PauI.A.Provencioe.conocoohillips.com Printed Name Paul A.Provencio Title Engineering Technician Signat Phone:263-4683 Date s r(izo 1 d''''-'-- ,PC-L—CA-- Form 10-404 Revised 12/2012 RBDMS MAY - 2 2013 (0 /, Submit Original Only • • ' 2G-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/02/13IWeII brought on production to reduce resevoir pressure for upcoming drilling. I I I I I I I I I i I I I KUP •. 2G-12 ConocoPhillips Well Attributes Max Angle&MD TD Alaska Inc, 'u` ,, Wel!bore APVUWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) (mxrA,,Wiv."? 500292115900 KUPARUK RIVER UNIT PROD 48.58 2,925.00 8,167.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date Well Gonna:-2G-12 4/11/2013 1 33 09 PM SSSV:LOCKED OUT Last WO: 2/11/1987 40.98 9/24/1984 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,909.0 4/4/2013 Rev Reason:TAG haggea 4/11/2013 Casing Strings ta, Casing Description 'String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 1 CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H-40 WELDED HANGER,32 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE 95/8 8.921 36.0 2,884.2 2,725.1 36.00 L-80 BTC a 10.75'x9.625" _ -_. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd I PRODUCTION 1 7 6.276 34.4 8,053.2 6,524.6 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 TUBING 31/2 2.992 32.0 7,514.7 6,071.8 9.30 J-55 EUE8rdABMOD - Completion Details . Top Depth .._ (TVD) Top Inel Nomi... Top(ftKB) (MKB) (1 Item Description Comment ID(In) 32.0 32.0 -6.80 HANGER McEVOY TUBING HANGER 3.500 1,781.6 1,778.3 13.60 SAFETY VLV BAKER FVL SSSV(LOCKED OUT 1/3/1989) 2.810 7,471.5 6,035.8 34.05 PBR BAKER PBR w/SEAL ASSEMBLY 2.810 7,485.3 6,047.3 34.11 PACKER BAKER FHL PACKER 3.000 7,502.4 6,061.6 34.12 NIPPLE CAMCO'D'NIPPLE 2.750 - / ' 7,513.9 6,071.2 34.07 SOS BAKER SHEAR OUT SUB 2.992 I CONDUCTOR, 36++6 € Perforations&Slots --Shot t Top(TVD) Btm(TVD) Dens II Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date Oh— Type Comment 7,582.0 7,600.0 6,127.5 6,142.4 A-5,2G-12 11/1/1984 4.0 IPERF 4"Schlum.Casing 7,615.0 7,654.0 6,154.9 6,187.5 A-4,2G-12 11/1/1984 4.0 IPERF 4"Schlum.Casing SAFETY VLV, 1.782 Notes:General&Safety alli1;. End Date Annotation 6/12/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE . 10.75'x9.625•, 362,884 GAS LIFT, 7,429 PBR,7,471 -- PACKER,7,485 --- NIPPLE,7,502 11.1 SOS,7,514 IPERF, 7,582-7,600 = Mandrel Details Top Depth Top Port . 7,6157,854 IPERF, 4__._ S (TVD) Inc' OD Valve Latch Size TRO Run r i _ T_ N...Top(ftKB) MOP (1 Make Model (In) Sem TYPe Type lie) (psi) Run Date Com... 1 7,428.8 6,000.6 34.12 OTIS LBX 1 12 GAS LIFT DMY RO-5 0.000 0.0 2/19/1987 10:00 ,, I PRODUCTION, 34.8,053 TD,8,167 • • • OFT j , THE STATE Alaska Oil and Gas ALASKA Conservation Commission rh GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ALAS � Anchorage, Alaska 90 279.3433 OR 2.t 3 Fax: 907.276.7542 some) Darrell R. Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. O` P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2G -12 Sundry Number: 313 -126 Dear Mr. Humphrey: 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 Ay Chair DATED this of March, 2013. Encl. STATE OF ALASKA • ` . ' - AL�4 OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRYAPPRO ALS t\ 20 AAC 25.280 1. Type of Request: Abandon . ❑ Rug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Change Approved Rogram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Rill Tubing ❑ Time Extension ❑ Operational Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ After casing ❑ Other: WINJ to PROD 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development in Exploratory ❑ 184 -128 - 3. Address: Stratigraphic 0 Service Pl 6. API Number. • P. O. Box 100360, Anchorage, Alaska 99510 50 -029- 21159-00 • 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spicing in this pool? Will planned perforations require spacing exception? Yes ❑ No IN 2G - - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25667 ALK 2588 Kuparuk River Field / Kuparuk River 011 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): 8167 6622 7971' 6446' None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116' 116' SURFACE 2848 10.75 X 9.625 2884' 2729' ' RECEIVED D PRODUCTION 8019 7 8053' 6517'1 � r illy MAR . � ACC S Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7582 -7600, 7615 -7654 6120 -6135, 6147 -6180 3.5 J - 7514 Packers and SSSV Type: - Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER • MD= 7485 TVD= 6047 NIPPLE - CAMCO 'D' NIPPLE • MD= 7502 TVD= 6062 SSSV = NONE 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 10 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/15/2013 Oil � Gas ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Darrell Humphrey Email: N1139 a,conocoehillies.com Printed Name Darrell R. Humphr v Title: NSK Production Engineering Specialist Signature ! J Phone: 659 -7535 Date 3. // . J Commission Use Only Sundry Number: 3(3_, Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical IntegrityTest ❑ Location Clearance ❑ , Other: RBDMS MAR 15 Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: /6(7 / v 4 APPROVED BY / / Approved by: ' y COMMISSIONER THE COMMISSION Date:, - 1 ( J$ p rov pp (Canon is Yaw tor Tz montns from the sate of approval. ____ p1q �►( s 1 12) V L Submit Form and Attachments in Duplicate L dp • 2G -12 • , DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 2G -12 from Water Injection service to Oil Production service for longer than 30 days. We wish to flow back this well for longer than 30 days for reservoir pressure reduction purposes in conjunction CTD drilling activities for 2G -11, 2G -12 and 2K -26. We plan to drill CTD laterals in these 3 wells and then return 2G -12 to water injection. The 16" Conductor was cemented with 202sx CS II (116' and / 116' tvd). The 9 -5/8" Surface casing (2884' and / 2729' tvd) was cemented with 800sx Permafrost E and 250sx Permafrost C. The 7" Production casing (8053' and / 6517' tvd) was cemented with 250sx Permafrost C and 330sx Class G. 11/17/12 (PRE -CTD) MITOA (Passed) @ 1800 psi, PT MV, SSV, AND SV to 4500 psi (Passed). Initial T/I/0 _ - 2200/800/50/4, OA FL @ 130' (600 fps). Rig up tri-plex to OA, pressure OA up to 1800 p si with 3.5 bbls of diesel for 25 min. Initial T/I/0 = 2200/850/1800/4. 15 Min reading: 2200/850/1725/4. 30 Min reading: 2200/850/1690/4. Pressure OA up to 1800 psi. Initial T/I/0 = 2200/850/1800/4. 15 Min reading: 2200/850/1780/4. 30 Min reading: 2200/850/1760/4. Pressure OA up to 1800 psi. Initial T/I/0 = 2200/850/1800/4. 15 Min reading: 2200/850/1780/4. 30 Min reading: 2200/850/1780/4. ti • • • RECEIVED 1'� Pv1 A R 12 2U13 Robert Christensen/Darrell Humphrey AOGCCAOG Production Engineering Specialists. . Kuparuk Unit , NSK -69 PO Box 196105 Anchorage, AK 99519 -6105 ConocoPhi i I ps g Phone: (907) 659 -7535 Fax: 659 -7314 March 11, 2013 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 2G -12 from Water Injection Service to Oil Production Service. We wish to flow back this well for longer than 30 days for reservoir pressure reduction purposes in conjunction CTD drilling activities for 2G -11, 2G -12 and 2K -26. We plan to drill CTD laterals in these 3 wells and then return 2G -12 to water injection. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 2G -12 (PTD 184 -128). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, Darrell R. Humphrey "t"- Attachments Sundry application Well schematic y • �,, KUP • 2G -12 COnOCOPIiIIIIps f "� Well Attributes Max Angle & MD TD Alaska Inc. Wellbore API /UWI Field Name Well Status Inc! r) MD (ftKB) Act Btm (ftKB) 1 500292115900 KUPARUK RIVER UNIT INJ 48.45 3,000.00 8,167.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: LOCKED OUT Last WO: 2/11/1987 40.98 9/24/1984 Well Confia: - 2G-12, 10/11/2012 11.41.54 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,920.0 10/9/2012 Rev Reason: TAG ninam 10/11/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • 1 ` r CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H WELDED HANGER, 32 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f,.. Set Depth (TVD) ... String Wt... String ... String Top Thrd ' SURFACE 10.75 "x9.625" 95/8 8.921 36.0 2,884.2 2,729.5 36.00 L-80 BTC ,.... F Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 PRODUCTION 7 6.276 34.4 8,053.2 6,517.1 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 TUBING 31/2 2.992 32.0 7,514.7 6,064.3 9.30 J -55 EUE8rdABMOD Completion Details Top Depth (TVD) Top Inc! NOnri,,. Top (ftKB) (MB) ( °) Item Description Comment ID (In) 32.0 32.0 0.10 HANGER McEVOY TUBING HANGER 3.500 2.810 2.810 3.000 1,781.6 1,778.7 13.11 SAFETY VLV BAKER FVL SSSV (LOCKED OUT 1/3/1989). 7,471.5 6,028.4 34.31 PBR BAKER PBR w /SEAL ASSEMBLY 7,485.3 6,039.8 34.24 PACKER 7502.4 6,054.1 BAKER FHL PACKER 4.1 34.12 NIP CAMCO'D' NIPPLE 2.750 7,513.9 6,063.6 34.07 SOS BAKER SHEAR OUT SUB Shot 2.992 36-116 Perforations & CONDUCTOR, s T o p (TVD) Btm (TVD) Dena Top (ftKB) Btm (ftKB) (ftKB) (SKIS) Zone Date (eh.- Type Comment 7,582 7,600 6,120.0 6,134.9 A -5, 2G -12 11/1/1984 4.0 IPERF 4" Schlum. Casing 7,615 7,654 6,147.5 6,179.9 A-4, 2G -12 11/1/1984 4.0 IPERF 4" Schlum. Casing SAFETY VLV, 762 Notes: General & Safety End Date Annotation 6/12/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 SURFACE J l 10.75'99.825•. 38 -2,884 i' GAS LIFT, 7,429 PBR. 7A71 { J L PACKER, 7,485 NIPPLE. 7.502 SOS, 7,514 PER 7,582 Mandrel Details IPERF, Top Depth Top Port 7,615 -7,654 (TVD) loci OD Valve Latch Size TRO Run Stn Top (ftKB) (SKIS) ( °) Make Model (In) Sery Type Type (In) (psi) Run Date Com... 1 7,428.8 5,993.3 34.52 OTIS LBX 1 1/2 GAS LIFT DMY RO 0.000 0.0 2/19/1987 PRODUCTION, TD, 8,063 . ' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 07,2012 TO: Jim Regg P.I.Supervisor � Q (('Z/(-L SUBJECT: Mechanical Integrity Tests tl 1 CONOCOPHILLIPS ALASKA INC 2G-12 FROM: John Crisp KUPARUK RIV UNIT 2G-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry --- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2G-12 API Well Number 50-029-21159-00-00 Inspector Name: John Crisp Permit Number: 184-128-0 Inspection Date: 5/1/2012 Insp Num: mitJCr120503091120 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2G-12 ' 1Type Inj W TVD 6039 - { IA 1 1200 I 3300 - 3220 3200 PTD 1841280 ' Type Test SPT Test psi 1509 OATH-1 400 430 430 440 1 — — Interval 4YRTST P/F ' P - �Tubing 2575 i 2625 2575 2575 �+ Notes: 3.9 bbls pumped for test. • SCANNED MAR 1 3 2014 • Monday,May 07,2012 Page 1 of 1 MEMORANDUM • To~ Jim Regg 1~_ P.I. Supervisor 11~F' `7~/ ~j~L~G FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 07, 2008 SUBJECT: Ntechanical Integrity Tests CONOCOPHILLIPS AL.ASK.4 INC ~G_i? KUPARL'K RIV U?vZT 2G-12 Src: Inspector Reviewed By: P.I. Suprv ~~~Y Comm Well Name• KUPARUK RN UNIT 2G-t2 API Well Number: ~0-029-21 t59-00-00 Inspector Name: John Crisp Insp Num: mitJCr080~04094424 Permit Number: t84-128-0 - Inspection Date: 5%2;2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - - - -- / - - -- ~. _ Well I 2G-'z iType Inj. j W ~ TVD ' 6040 ~, IA ioso z9so ~ i 2860 I zs4o ~-~ ~ - P.T. ta4lzao T eTest; SPT ~, Test si ~ i,io ~ - _ ~ _ --_L yp p QA _ 200 ~ 240 ~ X40 240 Interval 4YRTST p~F P ~ Tubing z6oo z6oo 2600 2600 i Notes' ~-6 bbl's pumped for test Wednesday, May 07, 2008 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Consen'alion Commission TO: Jim Regg ~h. ..(1' 7 (I (;- tC4 P.I. Super\'isor I?j ( DATE: Wednesday. June 30, 2004 SUBJECT: Mechamcallmegm)' Tests CONOCOPHJLLlPS AlASIoV\ fNC 2G-l:? FROM: John Crisp Petroleum Inspector KUPARUK RIV UNIT 2G-I:? Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Supn :þ-::'- Comm Well Name: KUPARUK RIV UNIT 2G-12 Insp Num: mltJCrO-10628 1916-15 Rellnsp Num: API Well Number: 50-029-21159-00-00 Permit Number: 18-1-128-0 Inspector Name: John Crisp Inspection Date: 6/27/200-1 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2G-12 Type Inj. 5 TVD 6613 IA 1700 30..\0 3030 3030 P.T. I 18.H280 TypeTest SPT Test psi 1510 OA 100 350 350 350 Inten'al ..\YRTST PIF P Tubing 2..\00 2..\00 2..\00 1..\00 Notes: Wednesday. June 30. 200-1 Page 1 of 1 STATE OF ALASKA ALAS~.,,-, OIL AND GAS CONSERVATION COMk..._,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend "; Operation Shutdown i } Re-enter suspended well [-] Alter casing El Time extension Change approved program S! Plugging ~ Stimulate-~ Pull tubing'' Amend order [: Perforate ~. Other 2. Name of Operator ARCO Alaska, !nc~ 3. Address p.O. Box ]00360. Anchorage, Alaska 99510 4. Location of well at surface 303' FNL, 272' FWL, Sec. 5, T10N, T9E, UM At top of productive interval 1354' FSL, 1272' FWL, Sec. 5, TION, R9E, UM At effective depth 1109' FSL, 1339' FWL, Sec. 5, TION, R9E, UM At total depth 1012' FSL, 1374' FWL, Sec. 5, TION, R9E, UM 5. Datum elevation (DF or KB) 127' RKB Unit or Property name Kuparuk River Unit 7. Well number 2G-12 9. '0'29~-~1159 50-- 10. Poo~Kuparuk River Oil Pool 11 · Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8167' 6613' feet Plugs (measured) feet 7971' 6446' feet Junk (measured) feet Casing Length Structural Conductor 116 I Surface 2884' Intermediate 8053' Production Liner Perforation depth: measured true vertical Size Cemented Measured depth 16" 202 Sx C.S. II 116' 9-5/8" 800 Sx Permafrost E 2884' 250 Sx Permafrost C 7" 250 Sx Permafrost C 8053' 330 Sx Class "G" 7582' -7600', 7615' -7654' MD 6119'-6134' 71+7'-6179' TVD Wue Vertical depth 116' 2729' 6516' Tubing (size, grade and measured depth) Alaska Oil & Gas Colin. Corm':i~;sior~ 3 1/2" J-55 @ 7515' Packers and SSSV (type and measured depth) FHL r~ -~/~o~, ~, F'VI Fa 1 Cll R ' ~2.Attachments Description summary of proposal [] Detailed operations program Perforate C _<:;and wii-h ~inglp ~hnJ-..q at 7497' and 7500' MD-RKB. 13. Estimated date for commencing operation BOP sketch 04/27/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to thA best of my knowledge signed . ~,~,.,~.~ Title .,/'[-.¢'~.-. Z" Date "- Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test © Location clearance Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned .~ Commissioner the commission Date feet Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 2G-12 Well 2G-12 is currently utilized for 'A' Sand-only water alternating gas injection. Perforation of the 'C' Sand will allow injection into the 'C' Sand and provide pressure support to the offset 'C' Sand producers. A copy of the proposed program to allow conversion of the subject well is attached. The perforating will be performed with 2-1/8" through-tubing guns. A 5000 psi BOP and lubricator will be employed during all stages of the downhole work. The 'A' Sand pressure is estimated at 3400 psig and the 'C' Sand pressure is estimated at 2700 psig, both from offset wells. Messrs. Lyden and Wade April 18, 1988 Page2 Kuparuk Well 2G-12 Cut Tubing Tail/Perf 'C' Procedure Charge Code: 230DS28GL The tubing tail will be cut below the packer in this well to expose the C Sand for perforating. The 'C' Sand will be perforated with 2 shots only to provide pressure support to offset 'C' Sand producers. A 2-1/8" E-Line through-tubing perforating gun will be used. , If the well is currently on gas injection, convert to water injection. After conversion, inject water at maximum rate for a minimum of one week before pedorating the C Sand. Cut Tubing Tpil; 2. Shut off water injection to the well. 3. MIRU Slickline unit and tag fill. discontinue procedure and contact Operations Engineering. Bottom A Sand perf = 7654' MD-RKB Minimum tag depth= 7704' MD-RKB 4. POOH. RDMO slickline unit. 5. MIRU E-Line unit. Pressure test equipment. If tag is less than 50' below bottom A Sand perf, 6. RIH with CCL/Sinker Bar/2.70"Jet Cutter/Centralizer. packer. Cut the tubing at 7493' MD-RKB, 1' below the base of the packer (22' above the tubing tail). Note: Camco 'D' Nipple, ID=2.75, at 7502' MD-RKB. 7. Confirm the tubing has dropped using CCL. If not, RIH with a second jet cutter and re-shoot the same location. 8. POOH with tubing cutter. 9/23/84 1 0/1 3/84 Tie in to tubing tail. Locate Perforate C Sand: 9. RIH with perforating gun. 10. RIH w/CCL, perf gun, magnetic decentralizer. 1 1. Tie-in to depth using the following logs: Schlumberger DIL/SFL Schlumberger CCL/CBL Messrs. Lyden and Wade April 18, 1988 ~3 12. Perforate the following locations with a single shot using a 2-1/8" strip gun. DIL/SFL CCL/CBL Shot Deoth (MD-RKB) Depth (MD-RKB) I 7497' 7496' 2 7500' 7499' Perforating gun specifications: Any of the following service company guns will be acceptable. However, it should be noted that the Schlumberger Enerjet Gun has performed the best in field use and in perforating studies. Schlumberger 2-1/8" Enerjet Dresser 2-1/8" Silverjet Gearhart 2-1/8" E-Jet II 13. POOH. RD E-Line Unit. 14. Continue water injection at the maximum header pressure or meter limit. The well will not be switched to a gas injection cycle until a 5% HPV water slug has been established in the 'C' Sand. 1. 5,000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5,000 PSI WlRELIN[ RAMS (VARIABLE SIZE) .3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 Id]RELINE BOP EOU]PMENT iii STATE OF ALASKA ALASKA u~L A~D GAS CONSERVATION CO,,~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Water Injector OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-128 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21159 4. Location of well at surface 9. Unit or Lease Name 303' FNL, 272' FWL, Sec. 5, TION, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1354' FSL, 1254' FWL, Sec. 5, T10N, R9E, UM 2G-12 . At Total Depth 11. Field and Pool 1012' FSL, 1373' FWL, Sec. 5, T10N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.} 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 140' ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 09/18/84 09/23/84 11/01/84* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+lA/D) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 8167'MD 6613'TVD 7971 'MD 6446'TVD YESl~] NO[] 1782 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DI L/SFL/GR/SP/FDC/CNL/Cal, BHCS/GR, Gyro(GCT), CBL, Temp. Log 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 116' 24" 202 ~x CS II 9-5/8" 36.0# J-55 Surf 2884' 12-1/4" 800 sx PF E & 250 sx pz C 7" 26.0# J-55 Surf 8053' 8-1/2" 330 ~x Class C & 250 .~ PFC 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) 7582 ' -7600 'MD 3-1/2" 7~;1 $ ' 74B5 ' 7615'-7654'MD w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6119 ' -6134 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6147'-6179'TVD See Addendum.. attached to the W~.ll Cnrnnl¢t'inn· 03/21/85; for Fracture daf. a_ 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24~HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED Al~ska 0ii & Gas Cons. Ap,~hor~ ,, *Note: Drilled RR 09/24/84. Well perforated & tubing run 11/01/84. Workover was performed 02/17/87. ~ted Form 10-407 WC2:28:DANI Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . , 29. ', 30. . GEOLOGIC MARKERS - FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE V. ERT. DEPTH GOR, and time of each phase. Top Upper Sand 7494' 6046' N/A Base Upper Sand 7500' 6051' Top Lower Sand 7565' 6105' Base Lower Sand 7718' 6232' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my. knowledge · . : i Signed ~ ,/.~./,~,,~k_,/ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ~ Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. ~. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA '~'---- ALASt OIL AND GAS CONSERVATION COMB SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging ~ Perforate [] Pull tubing Alter Casing [] Other [~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 127' 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 303' FNL, 272' FWL, Sec. 5, T10N, R9E, UM At top of productive interval 1354' FSL, 1272' FWL, Sec. 5, TION, R9E, UM At effective depth 1109' FSL, 1339' FWL, Sec. 5, TION, R9E, UM At total depth 1012' FSL, 1374' FWL, Sec. 5, TION, R9E, UM 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8167 'MD 6613 ' TVD 7971 'MD 6446 'TVD feet Plugs (measured) feet feet Junk (measured) feet 7. Well number 2G-12 8. Approval number 7-30 9. APl number 50-- 029-21159 10. Pool Kuparuk River 0il Pool None None Casing Length Conductor 116' Surface 2884' Production 8053' Size Cemented Measured depth 16" 202 sx CS II 116'MD 9-5/8" 800 sx PF E & 2884'MD 250 sx PFC 250 sx PFC ~ 8053'HD 7" 330 sx Class G True Vertical depth 116'TVD 2729'TVD 6516 ' TVD Perforation depth: measured true vertical 7582 ' -7600 'MD, 7615 ' -7654 'MD 6119'-6134'TVD, 7147 ' -6179 'TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 7515' Packers and SSSV (type and measured depth) FHL pkr @ 7485' & FVL SSSV ~ 1782' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to Well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 Histor~y) Daily Report of Well Operations ,(~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢ ~'~/~{...,/,~ L,~/~ Title Associate Engi neet Date Form 10-404 Rev. 12-1-85 Submit in Duplicate (DANI) SW02/038 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. I Accounting District I County or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25667 Auth. or W.O. no. ~Title AFE AK1975 I Re completion/Wo rkover Nordic 1 API 50-029-21159 Operator ARCO Alaska, Inc. COSt center code Alaska JWell no. 2G-12 Spudded or W.O. begun JA.R.Co. W.I. 56.24% IDate 2/9/87 Workover Date and depth as of 8:00 a.m. 2/10/87 2/11/87 2/12/87 2/13/87 Complete record for each day reported Iotal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 0915 hrs. 7" @ 8053' 7971' PBTD, Chg tbg spool 12.5 ppg gel mud Accept rig @ 0915 hrs, 2/9/87. Displ well w/12.5 ppg mud. Monitor well; well dead. ND tree, NU & tst BOPE to 3000 psi. RIH w/RTTS, set @ 60!. ND BOPE. Chg out tbg spool. 7" @ 8053' 7971' PBTD, CO couplings Wt. 12.2, PV 28, YP 38, PH 10, gel mud Chg out tbg head & tst. NU BOPE & tst. RIH, retry RTTS. Circ, POOH, chg couplings to 3½" 8RD EUE AB-Mod. 7" @ 8053' 7971' PBTD, Cln mud pits 6.8 ppg diesel RU & rn 235 its, 3½", 9.3# J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1782', FHL pkr @ 7485', TT @ 7515'. Tst tbg & ann to 2500 psi. Tst SSSV to 1000 psi. ND BOPE, NU & tst tree to 250/5000 psi. ~' . Displ well w/diesel. 7" @ 8053' 7971' PBTD, RR 6.8 ppg diesel Fin cln'g pits. RR @ 0930 hrs, 2/12/87. Old TD Released rig New TD Date PB Oeplh K nd of rig 7971' PBTD 0930 hrs. 2/12/87 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production IOil 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 $ig ~~.~~__~~~t~ I D~//.~/F~ JTitle Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. f'-" STATE OF ALASKA '-'-.- ALASK.. OIL AND GAS CONSERVATION COMh. .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspen_d [] Operation Shutdown ~ Re-enter s~yended well m Alter casing ~ Time extension [] Change approved program I~. Plugging © Stimulate C Pull tubing j~-~..Amend order ~ Perforate- Other- 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 127' 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 303' FNL, 272' FWL, Sec. 5, T10N, R9E, UM At top of productive interval 1354' FSL, 1272' FWL, 5cc. 5, T10N, RgE, UM At effective depth 1109' FSL, 1339' FWL, 5cc. 5, T10N, R9E, UM At total depth 1012' FSL, 1374' FWL, 5cc. 5, T10N, RgE~, UM 11. Present well condition summary Total depth: measured true vertical 8167 'MD 661 3 'TVD feet feet 7. Well number 2c-12 8. Permit number 84-128 9. APl number 50-- 029-21159 10. Pool ~(uparuk River Oil Pool Plugs (measured) None Effective depth: measured true vertical Casing Length Conductor 116' Surface 2884' Production 8053' 7971'MD 6446'TVD Size 16" 9-5/8" feet feet Junk (measured) None Cemented Measured depth 202 sx CS II 116'MD 800 sx Permafrost E 2884'MD 250 sx Permafrost C 250 sx Permafrost C 8053'MD 330 sx CI'G' True Vertical depth 116'TVD 2729'TVD 6516'TVD Perforation depth: measured 7582 ' -7600 ', 7615' -7654 ' true vertical 6119 ' -6134 ', 7147 ' -6179 Tubing (size, grade and measured depth) 3-1/2", J-55, @ 7515' Packers and SSSV (type and measured depth) FHL 8 7492' & FVL ~ 1918' 12.Attachments Description summary of proposal~., Detailed operations program - BOP sketch 13. Estimated date for commencing operation February 9, 13R7 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~/ ~ Title Associate Engineer Commission Use Only (JLQ)SA/202 Date Conditions of approval Notify commission so representative may witness ~ Plug integrity Approved by ~:__/ ~(-i;i;:~;~ Form 10-403 Rev 12-1-85 I Approval No. BOP Test ~ Location clearance ¢-~ ~.~.p r ovid C~".:' by order c Commissioner the commission Date/-~-'~ '~ feet Submit in triplicate Kuparuk Workovers Couplin$ & Wellhead Changeout Without Pulling Packer Preliminary Procedure and Cost Breakdown Pre-Rig Arrival Operations 1. Set pOsitive plug in 'D' nipple & test same. Bleed pressure off tubing and annulus. 2. Pull gas lift valve from 1st mandrel above retrievable packer. 3. Circulate kill weight fluid. Test wellbore to 1000 psi. Rig Operations 1. Move in, rig up workover rig. 2. ND tree. NU BOPS & test same. 3. pull tubing free from packer. POH 2 stands. 4. PU storm packer &mU same into tbg string. 5. GIH 1 stand. Set storm packer. Rel f/same & test to 500 psi. POH. 6. ND BOPS.Chanseout wellhead to 5000 psi equipment. NU BOPS. 7. GIH & latch storm packer. POH with same. 8. Fin POH with tubing. LD GLMs & changeout couplings to AB MOD while POH. 9. Re-run completion assembly with reconditioned AB MOD GLMs. 10. ND BOPS. NU tree. 11. Displace well to diesel. 12. Release rig. 13. Move in, rig up slick line unit. 14. Pull plug from 'D' nipple. TOTP~. .... Anticipated Bottom Hole Pressure: 3100 psi Completion Fluid: 10.2 ppg NaC1/NaBr Brine ANNULAR PREVENTER 6 P I PE RAP'IS 4 BLIND RAHS 5 TUBIN6 HEAD 2 , , , , , 10, 1. 16" CONDUCTOR SWA(3ED TO 9-5/8" 2. 11"-:~000 PSI STARTING HEAD I 1. ::3. 11"-:3000 PSI X 7-1/16"-5000 PSI 12. TUBING HEAD 1,3. 4. 7-1/16" - $000 PSI PIPE RAMS ,5. 7-1 / 16" - 5000 PSi BLIND RAMS 14. 6. 7-1/!6" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS, INCREASE PRESSURE TO ;5000 PSI AND HOLD FOR 10 MINUTES, CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTP. EAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI, OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLINO POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO :3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN . AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BORE TEST ONCE A WE'~- '; ': :'~AND~FU~CTIONALLY OPERATE BORE DAILY. ".', . >' . - ., JG dULY 28, 1986 (NORDIC RIG 9-5/8") ARCO Alaska, In Post Office Bo.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatter Alaska Oil and' Ga 3001 Porcupine Dr Anchorage, AK 9 ton, Chairman s Conservation Commission ive 9501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- on the Wel ! Action Date Performed 1 L-1 Convers 1 L-7 Conve rs lQ-2 Convers 1Q-7 Convers 1Q-11 Convers 1Q-1 3 Convers 2B-5 Convers 2B-9 Convers 2C-1 Convers 2C-3 Convers 2C-6 Convers 2C-8 Convers 2D- 2 Conve r s 2D-7 Convers 2D-11 Convers 2D-1 4 Convers 2F-1 Convers 2F-2 Convers 2F-1 3 Convers 2F-1 4 Convers · 2G-3 Convers 2G-3 Convers 2G-5 Convers 2G-7 Convers 2G-1 0 Convers 2.(3-1 2 Conve r s 2G-1 6 Convers 2U-3 Convers 2U-4 Convers 2U-7 Convers 2U-1 6 Convers 2W-2 Convers 2W-4 Convers ion ion ion ion ion ion on on · on o on · on · on · on · on on · on · on on on on on on on on on on on · on · on on · on on · on 11118/85 11/18/85 11/17/85 11/17/85 11117185 11/17/85 11/23/85 11/23/85 11/19/85 11/19/85 11/19/85 11/19/85 11/20/85 11/20/85 11120/85 11/20/85 11121185 11/21/85 11/2~1/85 11/21/85 11/14/85 11/14/85 11/14/85 11/14/85 11/14/85 11114/85 11/14/85 RECEIVED 11/16185 ~ ~.,,, 11 / 1 6 / 85 ,J AN.8 11/16/85 1 1 / 2 2 / 8 5 ARCO Alasks_ r,c. is a Subsidiary of AllanticRichfieldCompany ~-'": STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 8q-128 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21159 4. Location of Well SURFACE LOCATION' 303' FNL, 272' FWL, SEC. 5, T10N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 40' (RKB) 6. Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2G-12 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 14, 1985 Kuparuk well 2G-10 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into "A"sand. the RECEIVE[; Alaska. Oil & Gas Cons, 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~, ///~¢,~-~__ '~,44.c,~,~,~.- Title KI I PAR! JK The space below for Commission use OPERAT IONS COORD I NATOR Date. 1:2 / 1 8 ! 85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, h': '-~" Post Office L._., 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfietd waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per dri!lsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED s EP o O~ t~ G~s Cons. Commissior., Anchora:~e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany - 6 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MAR_K:0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 8O 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 25658 25658 25657 25656 25644 I! 25643 25655 25644 25655 25642 2580 12/15/85 " 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 -2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 " [~/15/85 ¢',ECEIV STATE OF ALASKA ALASKA~'"L AND GAS CONSERVATION CC-'tMISSION SUNDRY NOTICES AND REPORT ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] -2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, ^laska 4. Location of Well 99510 7. Permit No. see attached 8. APl Number so- see attached 9. Unit or Lease Name Kuparuk River Unit N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 6. Lease Designation and Serial No. see attached 10. Well Number see attached 11. Field and Pool Kuparuk River Field Kuparuk River 0ii Pool 12. Check APpropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE.OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [~ Repairs Made [] Other [] Pull Tubing [] Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~,07 for each completion.) 13. Describe Proposed or Completed Operations {Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list o~^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. SEP 2 o 19B5 AlasV, B Oil & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ::~, /~'~,~.',~ ~,~_~,¢~-~-'~--' Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 Approved Copy .R. eturr~cl / By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARco Alaska, Ir. Pos! Office Gox 100360 Anchorage. A]as.ka 99510-0360 Te!ephone 907 276 1215 DATE' 05-2 9-8 5 T1Lz~NSMITTAL NO: 5203 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-11!5B P.O. BOX 100360 ANCHORAGE, AK 99510 pr , C" . A ~.. r, r., TRANSMIT'fED I-!ERE¥~ITi[ 'ARE 'file FOLLOWING ITEMS .~EA~E OWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TFJ~NSMITTAL. S~'.QU~;NCE OF EVENTS .RE~oURE DATA -2A-3 PBU- '~' SAI~D 2A-5 SBIIP --2B-1 PBU ~2B-2 PBU 2B-15 PBU- POST FRAC - 2B-16 PBU 2F-7 PBU- STATE 2-['~-2~'~> PBU- 'n' SAND U- 2G-!2 PBU- 2H-15 ISBHP 2W-13 PBU- 2X-!3 PBU STATE 'A' SAND POST FRAC 'C' SAND 03-16-85 -11-21-84 04-01-85 04-02-85 04-09-85 04-10-85 04-14-85 04-20-85 .......... 04-13-85 04-11-85 '-- 03-23-85 04-10-85 04-21-85 03-30-85 BAKER/ LYNES PRESSURE (ONE COPY OF EACH) la-1 PDU !A-2 PBU la-2 PBU la-5 BUILD-UP la-6 PBU la-6 BUiLD-UP ia-10 BUILD-UP ia-10 BUILD-UP REPORTS 04 -2 04-2 04 -2 04-2 04 -2 04-2 04 -2 04-2 3-85 3-85 3-85 3-85 3-85 3-85 3-85 3-85 SET DEPTH 7187' 7476' 7476' 6957' 8300' 8300' 8415' 8415' OOL NO. 1722 1302 1512 1734 1719 2062 1508 1299 RECEIPT ACKNOWLEDGED: B PAE * 3. CURRIER* ~!IEVROi]* O & M* ~ T T tJ D.~L~I..G L. 0OHNSTON MOBIL * NSK CLERK DISTRIB UT ION: W. PASHER EXXON PHILLIPS OIL* J. RATI-{MELL* D~-~.~a u~, & b~s Cor,s. 3ommission Anchorage STATE OF ALAS SOHIO* UNION* K.TUL"N/VAULq'~ _ ARCO Alaska, in,. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-2 9-$ 5 TRANSMITTAL NO-5199 RETURN TO: ARCO ALASKA, INC.. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-illSB P.O. BOX 100360 A~';CHORAGE, AK 99510 TIU~NSMITTED IlEREWITIi ARE TIlE FOLLOWING ITEMS. PLEASE ACKt;OWLEDGE RECEIPT AND RETURN ONE SIGNED COPY O? TItIS TRANSMITTAL. KUPARUK ~;~ELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 2A-7 04-23-85 2F-6 03-21-85 2G-8 03-21-85 2G-12 03-23-85 2H-13 04-26-85 2]~-14 04-28-85 2H-15 04-29-85 2U-1 04-11-85 2U-2 04-11-85 2U-3 04-11-85 2U-4 04 -11-85 2U-5 05-02-85 2U-6 05 -03-85 2U-7 05-04-85 2U-8 05-04-85 2U-13 03-09-85 2U-!4 03'21-85 2U-15 0~-_ 0-85 2U-!6 03-15-85 2V-2 03-23-85 2V-SA 03-17-85 2V-SA 01-24-85 2W-4 0~ ~-13-85 2X-1 04-14-85 --' X-3 04-13-85 2X-13 03-30-85 STATIC-'C' SAND STATIC-'A' & 'C' SAND STATIC-PBU-'A' SAND PBU-'A' SAND STATIC-PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND PBU-'A' SAND PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND ST~.~¥C-'A' SAND STATIC-'A' SAND S TAT iC STATIC-'A'&'C' SAND STATIC-'A'&'C' SAND STATIC-'A'&'C' SAND c TATiC ' C ' ,~ - SAND STATIC-'C' SAND STATIC-'A'&'C' SAND S ,r~ '~', m T,,-, I I '~ ~-~,- A SAND S~ r~ ,A~IC-'A'&'C' SAND.~ STATIC-'A' &'C' SAND PBU-'A' SAND ~' ECEIPT ACKN OI~..~._.DC~ D: ;PAE* ~. CURRIER* hm VIION* ) & M* DRILLING L JO,,h~TO.] MOB I L * NSK CLERK DISTRIBUTION: - I"~. PASHER EXXON PHILLIPS OIL* J. RATHMELL* c' m~ m OF - ~-~E AmASKA* SOiliO* UNION* K. TULiii/VAULT ARCO Alaska, inc' ~ Post Office bo...00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 itETURN ]"0' ARCO * "'" Al'TN: RECOF~I)S CI..FFRI,', ATO-i i t SiS . F',[), I)();< i 0(-)360 AK~C,H[ll.',:A(;E, Al< ?<;,:5 t ¢, T i:;; A N,? N I T TIE I) H lie I:;,: E W ]: 'l" H A I:;: [..". '1' I. I Il.:. I::' CI L. I... (] I,,J ]: H [; F;: E: C, E: Z F' l' (t N ];) i:;: E '1" LJ I? t',l 0 i,IIE ,"_.': I C- N lie f) C ()F:' Y l..J ~' F;: / 2 E q UE i',l C ['" I1F:' E V Iii: N ]' S ([) N E C [)I::' Y [)i:: El A C H ) 13 I"1-1 7~ 5' i.~ I"1F' ( H I ..9 C · ~--~t.,1 ].V:[TY) (';'3-'"~¢-~J~5 2. U-' i S; ,.$"I~':I"IF' .( M T ,S'C '"' .... ,,'.. ")V-'') i:;,'lJbI ' C' ,[CANI) (]NI...Y).".{1"11::' ~-.. ,-.'. .. -. ~-- · .... .:.'! V .... 4 T U R N ¢, F: 0 U N I) C- A.?., ::?.kl-.i 7.4. I)IESEI... 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I", .:. .:, t..1F, v E. ir ,.; .. I) t. "r,'" · ., ~ ' .~ -;' r- ' ~' I' I.' *~. *.¢. · · ,.t. I','1 ;,:.. F",'"',.- ;; .... ,,..~ . ~{' f'i' ' ":'i ',' ... 1'1 .~ .... .'. U N I C) i'-I. '.',:- .... ' .... ,/ '¥'~I, ':': ..... '' ~, "," I\, .,.· i ........... '' ': i ARCO. Alaska, lnc.~'"'---.. Post Office. 00360 Anc.horage, Alaska 99510-0360 Telephone 907 276 1215 Ok'E 03 .... 16 ---8'.:- ,.,; .... 17...,-;~ :..... I..., .. :- · 0 3' .... '2 ?-" ..':~ Y . Z.. ::. ('," ~ '" :: .... ::, ._:' -, "~ ' ."'~ 0S ....2 ,' ;':,_,' · .-.."' '~ *:.'. -.. . ~--. ..... ,.% A ,-, .~. ~-~,..- ... ... ~ ... ~..L ..;' "' -. ¢,.3-t 6---.::.~"'~_,, ',::,:,-"~ ,' .... o..;- (.,. ~_. ", ~ · ..' .-A...-' '" · ', .:- ,..J OA .... 74 ........ 03-25-'85 03- i ,-;.:.:.: m :~,_ . . ~.- .... "~ _.. ,..~ I~'. C',~ .... ~ ,' ,_; 03-i ,..,....~, ',::-:':,- 2 z_ ,~,' ~.., - ._-) _... ~ S-- --i o_,::, ~ C:,:)- ? ? '"'~ ...... ~- ~.....~ 03-2:::: .... ,.", 7-. ,-, r; r~ r_- ~- -- '- .c'. '-' 'F-.: i I F.:. T, I I i J l , ~.,I B !--i F' · ! I '"' !:', I"~ ,7 I i.":'~ 1'..'r r':_. PF,'I:EP ,r':oR FF;:AC ,..~OB P .'T. ]' LI I.","Z N G F" C! I:;..' I:-: F;: A C " ~ BH 2'TA'T'!C · ,r.:,.T....,, I.J ' £OUt-?CE WATER WA,TH ,.q'~ ~"~ GI..V ' . F..'l i' ~ . ...~',.GI-.V"£ F'~'I:... IF:' F !':',' H P 'F' B U "" .... OPEN 'C'gAND/,?'i'ATIC BHF'(!NITIAI_) F', T, ~UB I NG/F:'RE-'-FRAC ~ - "'-IT, - · ~r', F'REP FOR C' .... ',,o. ,, . · . ~:-t~t ..... ,-,, ¥,~T.T,.C BI" r' ,~:TAT!C BHP:;'C'SAN!) ONLY F'F:EF' r.-'OR F.'RAC I::,! II ! T)"..; ~ "" "'""~ ~' .. .::,--;.,;:N ?~1'Ir''' t ~_. I,. I ...... , F' i'-.-,' I J ~, T:., I I .~.., ,:?. F' i --"',! ?'-.~ E F: ,? L; F.,' V E "( c.; I L,* .., ... ARCO Alaska, !nc. is a Subsidiary ol AtlanlicRichlieldCompany ARCO Alask&, Ir, '' Post Office box 360 Anc_horage, Alaska 99510 Telephone 907 277 5637 ' ,, ,-.,l...r..,,~ k A, I C'. r:-'l T T i'~: F;,'kZ. C; 0 R D,? C L ,:r F:' .. . ,.. A '1" () .-- J i'-i .:> ]E ' . ,, ,:'~ H fl; I"I 0 F;,'A L; E, A I< 9'7':: i ;'~ · ..... · . . l" F:~-'; ?-!,.Ti i I l" l'"ii: D H Ii..'. r:: IY W ! l" H A i-i: IE l" I' IE I::~Ii-'CI.-7. II::'T AND F::F:.TLII-'¢N ONE ;?I,.(.~NI.ZD ... ¢., ,.,.- If (;.! I..I [!:i',i C E 0 !'T Iii: V E N I',.V "' " · i- [..IJ,S !...0C;- 2 C ..- 4 r.; --~'.:: ,:,',.., ,~ ,..:' F' 0 ,~'l' F' r:~. F;.: F C;. ~'.':i ,?. E N. 'F F.: Y 'T' [!: ?i F:' / ~.' F:' I N 0 .':'- ''~ o- - ~-~ ~.~ I:;; l.J H. :$ i · ~,, ~,'.- ~,.' '" "L'., ;'("--.--'I~"o'" ' " '" ' ..... ,~. :: "' ., ,:: - .,'-.; ?'"' ,:q, ~'~ RE I='I!:'.RF:'' C ' ?:FAN..r,, C'. C'I.../'"'-'" ' .. I" ,::. I',, F- ~ "* "~ "~.... q ~.N ". -' ~'. ..... ':: .... R I I i"~ '"' ''~ ,,, ~ 'Il' a',, ,,..~ .~ . · ' ~.' ..... I / r,',....'f?'::..,~: ~ ~ .... ,:: . G ~..,,x.,~ I!r.. N :i" i'::. Y · :~ f::, ..~ ~ . . ..... TEHF:'; :' ~' " · ,.:. I-- I H O 2'- i ? .... "; ~' "'"' ' ;::,_.;. 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('j fl :,,: i ARCO Alaska, Inc Post Office Bo^ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2G-12 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/L49 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA _ AN D GAS CONSERVATION CC. ivllSSION WELL COMPLETION OR'RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-128 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21159 4. Location of well at surface 9. Unit or Lease Name 303' FNL, 272' FWL, Sec.5, TION, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1354' FSL, 1254' FWL, Sec.5, T10N, RgE, UM 2G-12 At Total Depth 11. Field and Pool 1012' FSL, 1373' FWL, Sec.5, T10N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKB ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 09/18/84 09/23/84 11/01/84 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'l-VD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 8167'MD,6613'TVD 7971'MD,6446'TVD YES I-X NO I--I 1918 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/$P/FDC/CNL/Cal, BHCS/GR, G:y ro (GCT), CBL, Temp. Log 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 116' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2884' 12-i/4" 800 sx Permafrost E & !50 sx Permafrost C 7" 26.0# J-55 Surf 8053' 8-1/2" 330 sx Class G & 250 s Permafrost C 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) 7615'.- 7654' 3-1/2" 7515' 7492' 7582' - 7600' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATERoBBL OIL GRAVITY-APl (corr) Press. ,24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE !..,.~ ,,,-.,~ .-~ ~:....~.,.~.,. ~.: ,......~, .. .... ;~_:_ ,_'-; ...' .:.~ ,[,.i'~,' ?:F;-'.!'~'-' Form 10-407 GRU5/WC17 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :'- .'~. .- :? :;~. .:. -~: ~ : :., _ ~... ;~ ~ ~ : ~' . .- .-~.~ .. ~ ;' _ .... . . .:. .... -:' GEOLOGIC MARKERS ' -.-" : -. :.-'.: _ -! '.. ~'.-.f:':'i~, ~,'" ' - · ~ ..... FORMAT. ION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR0 and time of each phase. Top Upper Sand 7494' 6046' N/A Base Upper Sand 7500' 6051' Top Lower Sand -7565' 6105' Base Lower Sa0d 7718' 6232' ,: · . 31. LIST OF ATTACHMENTS : -Addendum 32. I hereby certify that the (oregoing'is true and correct to the best of my knowledge Signed &/Q~ ~J~ Title Associate Engineer Date INSTRUCTIONS General' .This form is designed for submitting a complete and correct well completion report and log on ali types of lands and leases in Alaska. Item 1' classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection,.Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ADDENDUM WELL: 9/25/84 10/16/84 1/27/85 2/08/85 2/11/85 2/12/85 2G-12 AFE: 902225 Arctic Pak w/250 sx PF "C", followed by 56.5 bbls Arctic Pak. Rn gage ring/JB/CBL f/7950'-5730'; lost tl dnhole. RIH w/OS, latch fsh @ 7971', POOH w/fsh. Rn GCT gyro f/ 7920'-surf. Rn pre-frac breakdn tsts in 4 stages w/total of 160 bbls gelled diesel. Prep gelled diesel f/frac. Repair suction pmp. Frac well in 7 stages w/total .of 370 bbls of gelled diesel & 1,029# 100 mesh & 16,000# 20/40 mesh. Rn Temp log f/7750'-7450'. Drilling fSuperintendent ARCO Alaska, In¢ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 25, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-12 Dear Mr. Chatterton' Enclosed is an addendum to the 2G-12 Well History to include with the Well Completion Report dated 02/13/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw' GRU4/L191 Enclosure RECEIVED AJaska 0il & GaS Coils. C0mm/ssJ0rl · -, ~ch0rage xc' 2G-12 Well File ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc Post Office ~,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2G-12 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2G-12 Well History covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L144 Enclosures RECEIVED Alaska Oil & Gas ;Sons. Corr~rnission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA --. ALASKA .L,.~ AND GAS CONSERVATION CO. ~ISSION · 4ELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] . . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-128 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-21159 4. Location of well at surface 9. Unit or Lease Name 303' FNL, 272' FWL, Sec.5, TION, RgE, UM ~ .... ! Kuparuk River Unit At Top Producing Interval i V~..~,. ~L) 10. Well Number 1354' FSL, 710' FEL, $ec.6' TION, RgE, UM iSur~. ~---~1 2G-12 AtTotal'Depth 13'73 Pf'~l"'t$~c,.~- ~'~' [B.H.--~ -j ll. Field and Pool 1012' FSL, ,82~' FFL, Scc~6, T10N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 140' RKBJ ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 09/18/84 09/23/84 11/01/84 N/A feet MSLI 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set ] 21. Thickness of Permafrost 8167'MD,6613'TVD 7971 'MD,6446'TVD YES [~ NO [] 1918 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP/FDC/CNL/Ca] ~ BHCS/GR~ Gyro ((:;CT) 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 116' 2M' ?(~? .~x £nld .~t- I1 9-5/8" 36.0# J-55 Surf 2884' 12-1/4" _ _ 7" 26.0# J-55 Surf 8053' 8-1/2" 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) 7615' - 7654' 3-1/2" 7~15' 7492' 7582' - 7600' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' : DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCr wATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCr WATER-BBL OIL GRAVITY-APl (corr) Press. '24-HOUR 'RATE 28. CORE DATA Brief description of lithology~ porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Anch0r~,,.ge Form 10-407 GRU2/WC27 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · , . . 29. 30.; -.; : · , · .~- ~. ~ , , ~.. _ ~ ,: - ., . , . . ~-.. '..: ':... :': i .? GEo'~oG-ici. MARKER~ 7~.:.7.'- .: i:'~':: -:,. ! ';.' ..... -.;-.: ;..~ i '-.. ~ORk/iATiON-T-ESys:-.-:. , · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7494' .6046' N/A Base Upper Sand 7500' 6051' Top Lower Sand 7565' 6105' Base Lower Sand 7718' 6232' .. 31. LIST OF ATTACHMENTS W~,ll ~-nry, ~.y .... op~ Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~1 ~)qJ)(-J ..~U.~ Tit,e Associate Engi neet 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 (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ADDENDUM WELL: 2G-12 AFE: 902225 10/16/84 7971' PBTD Rn gage ring/JB/CBL f/7950'-5730'; lost tl dnhole. RIH w/OS, latch fsh @ 7971', POOH w/fsh. Rn GCT gyro f/ 7920'-surf. Questionable cmt bond. RECEIVED '~as~ Oil & Gas Cons. 6ommJssiorl --.. .... Anchorage ~: -~-- ~:!~:3 :_?:: ? ._u~. ~wm~ l~..j.: ,~:~!~omng .nome De~~.form giving InMulive dates only. District/:: :: ~n~y, pi,~,i;, or bc.-ough ': ::Alaska -' ::' "~:~:?::~':'":': North Slope Borough Field -: i ILeaM or Unit Kuparuk River / ADL #25667 / Aut~. or W.O. no. ITlfle AFE 902225 / Drill, Complete & Perforate Doyon #9 AP1 50-029-21159 Well History - Initial Report- Dally Istate Alaska 2G-12 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 9/18/84 9119184 9/20/84 9/21/84 IDate IHour 9/18/84 0600 Hrs. Complete record for each day reported 16" @ 116' Accept ri~ @ 0200 hrs, 9/18/84. ARCO W.I. 56.24% Prior statu~ If a W.O. 16" @ 116' 2445', (2350'), Drlg Wt. 9.5· PV 22, YP 30, PH 8.5, WL 12.8, Sol 9 Spud well @ 0600 hrs, 9/18/84. Drl & surv 12¼" hole to 2445'. 1451', Assumed vertical 1735', 11.7°, S38.2E, 1733.32 TVD, 26.80 VS, 22.75S, 17.90E 2313', 26.9.0, S16.1E, 2276.90 TVD, 218.16 VS, 200.83S, 91.11E 9-5/8" @ 2884' 2915', (470'), NU BOPE Wt. 9.6, PV 17, YP 26, PH 8.8, WL 12.6, Sol 10 Drl 12¼" hole to 2915', short trip, circ, POH. RU & rn 71 its, 9-5/~" & 1 jt 10-3/4" w/FS @ 2884', FC @ 2801'. Cmt w/250 sx C1 "~'~@ 15.6 ppg. Displ using rig pmps, bump plug. CIP @ 2300 hrs, 9/19/84. ND 20", NU BOPE. 2565', 35.1°, S16.1E, 2492.97 TVD, 347.95 VS, 325.53S, 127.10E 2873', 47.9°, S15.1E, 2723.59 TVD, 552.03 VS, 522.10S, 181.98E 9-5/8" @ 2884' 4620', (1705'), Drlg Wt. 8.9, PV 11, YP 8, PH 10.8, WL 9.8, Sol 4 Tat BOPE to 3000 psi; OK. TIH w/8½" BHA to 2801', tst csg to 1500 psi. DO FC cmt, FS + 10' new formation to 2925'. Conduct formation tst to 12.5 EMW. Drl & surv 8½" hole to 4620'. 3191' 3713' 4333' · 46.3", S14.1E, 2940.06 TVD, 784.91 VS, 747.53S, 240.70E ,. 46.7°, S14.7E, 3299.38 TVD, 1163.44 VS, 1114.28S, 334.87E · 46.4°, S17.4E, 3725.77 TVD, 1613.51 VS, 1546.84S, 459.31E E Alaska Oil &.Gas Con& The above ia coreco[ j~ Signature ,/J . . I] IDate I'rifle 9/26/84 Drilling Superintendent RCO 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 dat~ 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 I Kuparuk River Auth. or W.O. no. ~Title I AFE 902225 Doyon #9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 9/22/84 thru 9/24/84 9/25/84 IA.R.Co. W.I. Date Complete record for each day reported Accounting cost center code State North Slope Borough Alaska ADL #25667 Drill, Complete & Perforate IWell no. 2G-12 AP1 50-029-21159 rrotal number of wells (active or inactive) on this Icost center prior to plugging and 56,24% Jabandonment of this well I IHour I Prior status if a W,O. ~9/18/84 J 0600 Hrs. I 9-5/8" @ 2884' 8167', (3547'), RIH w/7" csg Wt. 10.2, PV 16, YP 7, PH 9.5, WL 6.0, Sol 11 Drl & surv 8½" hole to 8167', short trip to 3700', circ, POOH. RU Schl, log DIL/SFL/GR/SP/FDC/CNL/CAL f/8151' WLM. Att to log BHCS/GR, unable to wrk thru 4317', log cancelled, POOH, RD Schl. RU & begin rn'g 202 jts, 7", 26# csg. 4966', 45.2°, S19E, 4167.08 TVD, 2066.98 VS, 1977.94S, 01.05E 5693', 43.7°, S14.8E, 4686.74 TVD, 2575.29 VS, 2466.71S, 740.63E 6591', 41.7°, S17.5E, 5346.43 TVD, 3184.56 VS, 3051.94S, 910.10E 8167', 31-3/4°, S21-1/2E, 6609.21TVD, 4125.75 VS, 3940.81S, 1224.87E 7" @ 8054' 7971', (0'), RR 10.2+ NaC1/NaBr Rn 202 jts w/mkr jr, 7", 26#, J-55 BTC csg w/FC @ 7971', FS @ 8053', mkr @ 7616'. Cmt w/330 sx C1 "G" w/l% CFR-2, 5% KC1, .3% Halad. Displ w/10.2+ NaCl/NaBr, bump plug. CIP @ 1145 hrs, 9/24/84. ND BOPE, instl lower tree adapter. RR @ 1500 hrs, 9/24/84. Arctic Pak w/ 250 sx PF "C", followed by 56.5 bbls Arctic Pak. Old TD Released rig 1500 Hrs. Classifications (oil, gas, etc.) Oil . . . Produc!ng method Flowing New TD Date I PB Depth 8167' (9/23/84) 7971' I Kind of rig 9/24/84 Rotaryl J Type completion (single, dual, etc.) I Official rese~oir name(s) J Kupurak Sands Well no. Date Reservoir I Producing Interval Oil or gas Test time Production /~f~l]f~t'o~m Oil on test Gas per day -.c~ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected t For form preparation and distribution, see Procedures Manual, Section 10, ........... Drilling Superintendent $ UB.$ URFA CE DIRECTIONAL SURVEY ~-~ UIDANCE ~'~ ONTINUOUS r~OOL Company ATLANTIC RICHFIELD COMPANY Well Name Field/Location 2G-12 (303' FNL~ 272' FWL~ S5~ TION, R9E~ U~) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 69693 Lo::ed By: BEUTLER/I,JEST Date NOV-26-84 Computed By: STEVENS qCT ~I, lqEC'I'It,,~NAI, SURVEY CHST[JNI-]~ LIST A I, A S ~, A I~cjq'~lr;~j~ flj,' (..f'l!.~l-~i~'F/~q.'iLf;[,i 'I'L.jI'Ii, t.,('~CAI ]()N; ?Ar"L, Fr.,'rLAb- avora(.le~] VF'H3 I.C,~I, Sr;('I ll.~'l: ?iIqN'IZ,. P. iSI , PH(i, JECTI::9 1,5 PEG 59 MIN EAST C' I I ,'.~ T J. ~ l~ E.; R ?c;-I 2 J< LJ P h R U K C fl ;4 P U T A T 1 f) N A~CO A L/~.SK A, 2C,- 12 TNC. i) A =.t'Fi; DEP'I'I4 T R U E VERTICAL · ~ DEB'! tt i,N'j'F~PtII,A'rEI', VA.[,UF5 1"'0~ I:'..,VEN 100 F'EEI' UF 0. ¢)U 1. O0. O0 200, OO gOO.nO 400.00 5()0, O0 600, O0 700,00 800, O0 oOO,O0 1 Ob . U0 299,9g 499,9~ 099.9~ 799.97 1000, 0 u 110o.00 1200,00 1]00.o0 1400. o(') 1500. no 1600. nO 1700.00 18OO,OU lO00,00 999 , 97 10q9,,)6 11q9.95 1,299,94 1309.'~3 I 0'9~, 75 -140,00 0 0 I'.~ U 0 E 0,00 0,00 -,10,0<) (,)18 $ %1 33 W 0,!9 1, lO bo,g9 0 36 S 62 16 W 0,29 0,35 15(}.q9 0 36 S, 75 24 W 0,37 0,14 2hq,q9 0 23 o~ 6b 3 ~ 0,52 0,3] qbg,gB 0 32 ~ 70 4q W 0,51 0,15 459,08 0 27 S 61 24 W 0,55 0,04 5hq.qB 0 20 ~ 70 57 W 0.71 0,36 650, q'l 0 21 S 4j 28 ~ O., fl7 t),gq 759,07 (.)4 ~,~~t~ 42 ~ ~,03 0,43 200O, OO 21 00. 22U0. 2300.00 2400.00 2500. O0 2600. ou 270n oO 28UO~OO 2900. ou 198~, 08 21'lj. 2263 . 89 2351 2437.27 2597 , o4 2571. qSq,~t~ u 5] $ 70 56 F 2,1.1 U, 15 1159,94 ~25O,03 U 54 S 60 50 ~' 4.93 O, 10 1359.ql 1. .]0 S 5,J 27 F', 6. 3'1 1.30 145o.73 b 40 S 47 5 F: 11.08 5.47 tqbfl.75 9 57 S 39 4 F 23.40 't.b7 .1656.~5 13 49 ~ 32 4n f:: q2.fl~ 3.75 175P.q3 lo 52 F 25 lO F. 68.85 2,95 .~000, Ou 3100.Ot~ 3700.00 3 ]0o, Or} 3400.00 3600. (~ ('J. ,~ 7 O O. 0 U .~RUO. OU 3900.0~¢ IH4H,()H 1.'4 10 ,q 19 ] E 9q.'~l 3,13 1o41.72 21 43 S 17 ~2 E 134,47 2,48 2n.J.3,HO 24 17 S lt) .~fi F 173,45 2,b 2123.Hv 2h t)q $ lb b4 F 2i6.82 2.29 2711,q0 ?~ bi S lb 13 E 204.78 3,.3q 2797,'2/ 32 56 S 14 43 E 316.~2 3,20 23'19.43 '~t) 33 S s4 5 P: 373.2'/ 3.09 2457,6,~ 40 32 S 13 39 F 435,fil 4,2q 2%Jl.O9 4,i ,i6, S 1 ~ 7 F 503.27 4,20 259q.5~i a~ 17 $ 12 ~7 ~'~ 576.03 2732,70 2gul .46 4n ] S !2 51 E 797.40 0.91 2H'/! .73 .Cb 4r' $ 13 0 E BOq.Or U.2B 2'),i 1 .05 301 (). '7 ~ 45 31qq.n'/ 40 .~3 $ 13 2n F' 1156.41 O,lO 3217,77 3'2~6.45 4,) 36 f; 13 4q F .t3Ul ,63 t).bl I'}ATK UF SURVEY: 15-0CT-84 KELbY BOSI!ING F6EVATIUN{ 140,00 EN'G I N F'I~.:R I ~EUTLER/WEST MEAfiIIRF:p L)FPTIi RKCTANGI,JL, AR COORDINATES NORTh/SOUTH EAST/WEST F" E E T F g F: T HOHIg, DEPARTIIRE DIST, AZIMUTH F~ET DEC, MIN O.O0 N 0,00 0.2! S 0,05 0,58 S 0,98 0,9? S 1,86 1,32 S 2.72 1.5'2 S 3,44 1,81 S 4.34 2, I I S 4,80 2,46 S 5,45 2,0.8 S 5,58 0,00 N 0 0 E 0,21 5 13 44 W 1,14 S 59 20 W 2,07 S 63 40 W 3,02 8 64 12 ~ 3.76 8 66 15 w 4,7'1 $ 67 21 W 5,25 S 66 14 ~ 5,98 8 65 41 W 6,10 S 04 23 W 2,09 S ~,79 3,14 $ 3,2fl 3,05 S 2,00 4,21 S U,81 b,uO S 0,44 0.04 S 2.05 9.'7J S 0,24 19,U8 S !5,5~ 30.04 S 27,~'3 60,03 S 40.46 5,50 S 60 44 W 4,54 fi 46 1.9 W 4.16 S 28 44 m 4,35 S 10 43 W b.02 8 5 2 E 6.3B 5 lB 43 g 11.56 S 32 39 g 25.26 $ 38 5 g 4o,Ul 5 37 13 E 72,39 S 33 58 E 88,05 $ 51.52 1.21,9] S 62.06 159,1q S 7~,13 20U,84 S 80.25 240,56 S q8,95 295,04 S 112,42 35Z,U] S 12~,58 412,49 S 14.1,5t 47~,47 $ 157.23 549,52 $ 17],44 102,54 $ 30 9 E t37.09 8 27 11 E 175,60 S 24 5~ E 218,57 $ 23 14 E 265.~8 ~ 21. 51E 317,42 S 20 44 E 374,u9 6 19 46 E ~3b,OO S lB 5b g 503.04 $ 1~ li E 570,24 b 17 31 E 622,83 S lP9,55 095.18 S Z05,~2 76b. OO S 221,79 ~35.82 S 23'7.8P 905,55 S 254,06 975,3a S 270,~g 1. U4b,,l'l S 280,90 1ilbo92 $ J03,'11 1257,27 S 33'1.80 o51.06 $ 16 5~ E 725,01 fi 16 29 E 70'1.~7 fi 16 ~ E 569,01. 5 15 53 E 940.52 ~ ~5 40 E 10~2,13 8 15 ~9 E 1084,12 S 15 20 E 115~.b2 $ 15 13 5 1229.15 S 15 '1E ~301.~1 5 15 2 ~ FT ARC{'I AbA,%FA, 26-12 [)ATE; ]q-h!UV-H4. .IN'i*<t,.PUI.A'rED %iA[.,UF:!, ~Otx ~,Vk:ht !00 F'~.:~.'.T CgURSF. V D.R'I' ICAL bEVIATIO!~ A 7.1. ~. UTti :.~ F. CT I 0~ D [!'. ti tq I N i J }? (~ N~ 1 h F E E T 4000.0 ~100,O0 4300, 4400, O0 4500.0L) 4600. 470O. O0 4800. 4000. O0 '1'~ U E ,q U ~'~ - S E A V i<R T I c'h l., 4~ 45 $ 1, 30 E 1447.16 46 35 S l,~ 52 E 151q.84 4a 28 S 1b 38 F 1665,00 45 27 S ~b 59 F 1737,48 45 13 S 10 9 f 1809,89 45 56 S !,) 17 F 1881,90 45 37 S 15 22 F 1953,57 4',) 20 S !0 25 E 2024.R7 5000, O0 5100,00 5 200,0 () 5300,00 5400,00 5500.00 5600, Oo 5700,00 5800, O0 5000.00 3496.07 '3563.bR 3423,56 3t, 32,24 1492,74 3'/01.01 35t>1 ,01 3769, b 1 3~2q, ~ 1 3~3~. 10 3698.70 390"1, U7 3767.67 3977.05 J~ 37. O5 4046. '/"~ 3qo6.70 411t~,91, o000 O1 O0 0200 6300 6400 050O 6600 6700 68O0 0900 ,00 . O0 .0~.) n 0 o O0 0 , . O0 . 411!'7.38 ~n47, 'lb 425~,07 '~11~, n"/ 4.~2~, 93 41 ~8, q3 44.00,16 42~o, lt, 4471 ,~fl 4331 4543,b(. 44t)3.6~ 4015, oq ,475,69 40~7,57 4547 4760.3 ] 4620,33 4832,96 4692,9t~ 43 IR ,5 1.3 42 E 2790.98 43 21 R 14 1 W 28~9.60 43 5 $ 14 26 [< 2{128.00 42 42 S 14 3fi ~7 2995.09 42 2g S 1,I 39 E 3063,60 42 If) S 14 36 F 3131.01 41 bl S ~4 32 E 319'1,9t~ al 34 S ~4 q8 F' 32b4.40 .~0 57 S lb 11 F 3330,39 t9 54 $ lb 51 E 3~95.32 4.905,04 5051.Z5 'tqll ,25 5124.55 4q~4.55 519~.17 505~.1'1 5272.07 5132,07 5346.33 5206. ~3 5421 .UO 54°0.17 5356. 1 5572.22 j43~,22 'lOOO,Ou 5~49.39 7100.o0 5727.o'1 bSu7.6'/ 7200,00 58no,,.)~ '1300, f~O 5~R'1,26 57~7.25 7400.00 596~.5{ 5828.53 7500.00 6050.~1 7700.00 621';.i9 7800.00 6300.9~ ol 7qO(~,O0 63gb,~4 t~245,4'1 PAGE DATE LiE SURVEY: 15-0CT-~4 KELLY BOSHI~,~G FLEVATIUN: ENGIN~ihR: BEUTbEN/~E~T LJF 5~EA~I.IRFiL) DEPT[i r~EG/1 oO HEC'I'ANGIJbAR Cr)ORHIt~A'fE$ HORIZ. ~'~ OI~TH/St:lO Ttt E, AST/WEST DIST, FEET FEET FIlET 0.44 1.i27,79 S 355,44 E 1.374,54 u,26 139t1,35 S 373,55 E 144'1,]9 0.30 1.46~.bq $ 3ql,96 E 1520.09 t),38 153~.82 S 410,'10 F 1592.~9 U.34 100~.80 S 429,95 E 1665,26 0.30 107~,55 S 449,57 F 1'137,74 0.56 1748.il S 469 77 0.i7 181'/,25 S 489~90 E 1882,~3 0.,J2 188o,04 S 510,05 E 1953,79 0,73 1.954,44 $ 530,16 E 2025,07 0,23 0.17 0,20 2,78 0,55 0,21. 0,37 O, 75 0 , 82 O. 26 0,31 0.50 0.25 o.44 0,41 0.58 1,13 I. 31 2022,q6 S 550 30 F 2095 99 2090,2'1 S 570~48 E 2166~72 2157,90 S 590,5q E 2237'25 2225,29 S 610,22 E 2307,44 2292,99 S 626,bl E 237'1,06 2360,88 S 042.12 E 2q46,~4 2428,49 S t~57 55 E'. 2515,96 2495,89 S 573~33 E 2585,12 2562,94 S 589,28 E 2654,0~ 25~9,'~5 S 705,45 E 27~2,72 2~90.a7 S 721.78 E 2791.40 2763,15 S '13~.19 E 2860,05 2879,47 S 755,04 E 2928,48 7895,32 S 772,11 E 2990.50 2960,~0 S 789,23 E 3064,18 3025,98 $ ~06 25 E 3131.55 3090.80 S ~23~08 E 3198,52 3155,16 S 839,92 E 3265 04 ]2~8.~6 S ~55,96 E 3330:98 3281,44 S ~74.28 E 3395,9! 1.61 3342.bl S ~02.04 E 3459.b0 0,?0 3402,08 S 91. t).03 E 3521,09 0.'13 3460,18 $ 928.30 F 3582.53 0.~5 3510,9! $ 940.63 E: 3542.08 1,47 3572.~7 S 964,~0 E 3700.26 1.07 3526.22 $ 982,08 E 375'1.01 U,b3 3t)79.09 S 1000,32 E 3~12,ob 0.42 3'131.35 S 101~,25 E 3867,79 0.56 3'182,90 $ 1035,15 F 3922,24 1.30 3~33.36 S 1053.99 E 3975.52 140,00 FT DEPARTURE AZIMUTH DEG MIN S 14 59 E S 14 57 E S 14 56 E $ 14 50 E $ 14 57 E S 14 59 E S 15 5 g S 15 '1 g S 15 10 g $ 15 13 E 8 15 15 E $ 15 18 E S 15 20 g ;5 15 17 g S 15 12 E S 15 9 E S 15 bE S 15 3 E 815 0 E $ 14 59 E S 14 57 E S 14 55 g S 14 55 E S 14 55 g 6 14 55 E S 14 54 E S 14 54 E $ 14 54 E S 14 55 E S 14 56 E S 14 58 g S 15 1 g S 15 3 E ~ 15 b g S 15 9 g $ 15 12 E ~ 15 15 E S 15 19 E S 15 22 k 2G-,. 1 2 ~.:A,51.~kl.;[.) VF'RTIiCAI., VER'I'ICAI., [)EV!A.'I'zr';~,~ Db, P'rH k) .F,[:'Tit Ob]P'l,' H DF]G 1~ 1 N i.,)I;.~G Irt I N VI:,R'£~CAJ, DtjGI.,E~, RI~;CTANGUL, Ak CO(JPDINA'i'E$ HORlg, DEPARTURE ~ECTIf]N Sh:VERITX ~O~TH/~OLJTH b,;AST/WES'[ DIS'I'. A~IMUTH FEk:T DE(;/IO0 FEET FEET FEET DEG NIN ~OO0.Ou 6470.b7 b'.330, %'1 ?)1 40 ~3100,00 6655,O8 o4,15,6~ 31 40 8167,0() 6612, 10 0472.70 3.1. 40 S 19 37 F ~027.78 S 19 37 F: 4()~0,1h S I',.~ 37 ~:, 4115.2ff (), U 0 0.0 0 O, UO 3~2.u0 S 10'71.63 F 4027,97 fi 15 25 E 3932 25 S 1Ufl9,27 t< 4080 33 fi 15 28 E 396b:3~ S 11Ol,O9 E 4115:42 $ 15 31 E KIIPA~IIK NORTi-I 5I.,UPE, CI'~MPIjTATICII~, IJA~I'E~ lq-Nt.)V-,R~ .i N'I.'F A P L{I...ATLD UAl, lJF,,..~ ?'f)}< t,..iVE:N 100o ~,F..ET fl[-' ~I{ASURED DEPT VERTICAL I.)i,)Gb[<G RFCTANGUbAR C[]t'SRDINA',i~E,5 t'tOHI[, DEPARTURE bECTif']i~ SEVERiT2 NO~TH/SClUTH EAST/WEST DIST. AZI~U'I'H FF'ET DEG/1 O0 FEET' FEET FEET DEG O, O0 0,0¢) - 140, ~,~t) 0 0 .lO00, O0 999.97 gbO.9') 0 50 2000,00 !Yt~, OR 1848,0~ 19 10 3000,00 2805.50 2605.59 48 27 4000. O0 ]495.07 3 '~55.07 46 42 5000.00 41~7.38 40.~7,']~ 45 7 O00O,O0 49Ob,b4 4705,64 4J 18 7000,00 5649, ~JR 5509, 3~ 39 7 8000.0() ~4'10.57 b'.~ 30,5'1 31 40 8169,00 6612.70 b47~,70 Il 40 0. 00 O.b5 3.13 1, ,06 0, ,i 4 '0,23 0,31 1.61 U, 0 () O. O0 O,uO ~ 0,00 E O,UO N 0 0 E 2.b9 $ 4,79 W 5,50 S 60 44 W 88 ~5 S 51.52 E 102,54 $ 30 9 g 022 8] S 189.65 F b51,06 $ 16 56 E 1'32'1 79 S 35b,44 g 1.374,54 S 14 59 E 2022 46 S 550,30 E 2095.99 $ 15 13 E 2096 ~7 $ 721,78 E 2791,40 $ 14 59 E 3342.bl $ 892 04 fi: ]459 bO f; 14 5b E 3tt82.~0 $ 1071:03 E 4027:97 $ 15 25 E ]965,1J8 $ 1101'09 F. 4115.42 S 15 ]! E C f!M P ti T A'¥ 1 f"~'.: i)ATF; ARCO ALA,~KA, 2C,-12 KIJPARI!K NlnkTH b[.,tJPE., A b A 5 F A V F, RTI CAI, D F F' T ~i S I~ R - S 1:.: a C r':~ u P 5 F Vb.:P'l'IC~15 DF;VlATIr~i'~ hZlt~tJTn [') t,< P ',[' H D [;J/,]~ N I 1'~ I.) [< G I', [ bi 1.40,aU 240.01 340.0 l 440.02 540,,02 640o02 740.03 ~40,03 940.03 1040,n4 1140,09 1240,0o 1340,07 1440,00 1540, I 1. 1640,56 174~,01 9AU. (l,~ 4 {j . ()0 240, 340. 440, UO 540, O0 '140. 84U, 1949,33 2055.25 2163.07 2273.27 2386,31 2503.2~ 262~.7~. 2766.~ 2000.69 3051,65 3197. R:.~ 3341 .?1 3484.53 362n. 3774.11 3919.73 4004.5o 4211 4356.7~J 4501 ?.94U 3140.90 3240. On 344o. un 364u.O(; '3 74 ~}. u() 3~4U, v h R '1' I C A t.. $KC7' I r)i4 t-'F:ET PAG'~ '5 PATE L)F SL.,~VK~: 15-t)CT-~4 KLI.,L¥ BUSHI'NG EbEVATIUNJ 140,00 FT kiNdl'tqFl~;P: DEUTbER/wEST 0 . 00 n,02 0,22 0.37 0,54 0,50 0,64 0.73 0 ,q9 1.06 1.50 2,40 3,31 4.29 5,4.0 7,4b 15.21 30.73 5 3,7 !:) 83.4 ~s 118.32 158.50 2u4,82 757,51 38P.71 413,42 516.55 68q,42 J 2 bl F: 795.95 1 3 3 ? 89R, 4b 1 3 I 1 W lOOl 13 23 F li04.HO !3 2R E 1210.21 1.3 54 F 1115.97 1~ 25 F 1427.0b 14 b4 ~ 152R.t)4 15 2t F' 1633.59 lb SO ~: l'138.nb I') t,./C 1., E G l') E (; / 1 {) 0 HFC'I"ANGUL, AR Cr~L)RDTNATE.S HORI' t~f:)RTtt/;.3[ILJTtt EAST/WEST DIST, F E F T F ~ E 'f F E E T O,t) O 0.57 0.55 O,~l O. 54 O. 26 L). {)g t) , 3 2 U.22 O,.q7 O,U2 S O.Ul F: 0.02 0,33 S 0.35 W 0,45 0'77 S 1,32 W 1,b3 1,06 S 2.27 W 2,50 1,41 S 2,98 W 3,29 1,o2 S 3,82 W 4,1'4 1,96 S 4,55 W 4,95 2.21 $ 5,07 W 5,53 2.~3 S 5.57 W b,16 0,()¢ U,j1 U,13 U,Oq 0.34 4.21. q,20 o,TR 3.93 2.0'7 S 5,46 W 6,07 2,83 $ 4,20 W 5,06 3,34 $ 2.73 W 4,31 3,~9 S 1,54 W 4,18 4.b6 $ 0,33 W 4,57 5.3] S 1,01 E 5,42 O.SR S 3,0q E 7,54 13,0'1 S 9,b2 K 1.6,23 2o.11 S 2t.),~4 E 33,16 40.34 S 33.56 E 57,21 3.58 1,99 2,28 3.05 3,19 4,25 3,91 1,bO 1,83 73,54 S 40.24 F 86,91 100,57 $ 57,04 F 121,16 144,94 S 69,~3 F 160,B8 1H9,24 S H2.94 E 206,07 240.05 S 97.17 F 25B.95 20B.54 S 1,12.~7 F 319,16 36'1.07 S 130,34 E 389,52 449.38 S 150.39 ~ 473,88 550,02 $ 173.bh E 57b,76 b6U,44 S 19~,0~ E b89,48 0,27 0,16 0.41 t),15 0.47 0,27 0.35 0.46 0.28 704.b2 S 271.45 F 795.95 h64,55 S 244.b3 F B98,47 964,55 S 26'1,85 E 1001,05 106b,~8 S 291,70 F 1104,88 1168,2~ $ 31~.25 F ~210,34 1271,1b $ 341.23 K 131o.16 1374.05 S 36'1.2P F: 1422,29 14'/b.o~ $ 3q4,07 E !5~,30 lb78.b4 S 421.b4 F 1633.65 1679.~6 S qSU.05 E 1739,11 DEPARTURE AZIMUTH DEG MiN N 0 0 5 $ 23 11 E 846 39 w $ 59 52 w 865 1 ~ S 64 38 w 867 3 w S 66 38 w S 66 24 w S b4 45 w 856 1 w S 39 15 w S 21 33 w $ 4 9 w S 10 41 E ~ 24 lO E $ 36 21E 838 3 E S 35 54 15 532 DE S 28 24 g S 25 43 E S 23 39 E 522 2 E 6 20 42 E S 19 32 E S 18 30 E S 17 30 E S 16 41 E 516 9 E 5 15 47 g S 15 31 E S 15 18 g 515 U E 515 1E 5 14 57 E S 14 5b E $ 14 57 E S 14 59 E INC. A L A,jI< g J.N'i'F]~PULAThP VA[,UF~ t~'[]~ ',1] R tJ F Eli,SURF[) VFI{!rlCAI, DEPT}'! I) F. PTH VIfR'I'ICAL, OEVIATiON AZi~OTtt r)i£1:>'l'H DE{,; ~]['N L.~Fi'G NI.N 4646.6z~ 4790. 3~ 4040. UO 4932.R0 414u.00 5074.47 424u,UO 5215.59 4340,00 5355,49 4~4u.00 5494.gl 4540.00 5633.72 404u,00 5772.01 474U.00 5g09.69 qB4u,O0 6047 24 ,1940, 61164159 5040.90 02 5140,00 b321 '6'1 5240,00 5456, 6591. ~t) 5340, O0 672~,3b o857.~2 55'10.00 695'7.8~ 7115 6,t 5'14u,00 724 I: ,.:,80o.nO 4,t 23 S 13 47 ~7 4quo. Ou 43 7 S 14 24 .E bc}uo,oo ¢2 3g S 14 37 F blO0,O0 42 21 S 14 3R F, 52()(),0{) 41 54 S 1,t 32 F 5]00,00 41 20 E; 14 b2 E 540o,00 .~u 26 S 'lb 29 F 55o0,1')0 t9 15 S lo 25 E b6oO,{)o 37 bP S 17 15 E ~7uO, 01.) 30 4'2 $ 1 / b5 [' OAT~:: lq-NdV-84 PAGE 6 hA'I!E OF SURVEY: 15-0CT-84 KELLY PUSHING FbEVATION: 140,00 FT WNGIt~EER: ~EUTLER/wE6T E,V[']N 100 FEF_'I' iJF' SUB-SEA DEPTH V I:,R 1' I C t~ L.Dt)(;bFiG 8ECTi(.)N Se:VERITY ~ F [~.T PEr;/100 HECTANGUhAR Cf)tJ[~[)I NATE6 J~r]RTH/6OUTI,~ EA6T/wES'I' F'EET FEET D I S T, FEET Z, DEPARTURE AZIMUTH DEG MIN IR4t,51 0,24 1780.40 S 479,15 E 1.84],75 1.946.64 U,50 1879,39 S 508,10 E 194~,86 2048,1'1 0,35 1.970,'"1~ S 536,75 E 2048,36 2148,51 0,25 2072,9~ S 565,3~ Fi 214~,59 224~.O8 0,40 216U,q2 S 593,71. E 2248,23 2345.8S 1,64 2262,7t S ~19,55 E 2346,04 24,t2.89 0.41 235'1.43 S 041.33 E 2443,1'1 253q,02 0.23 2451,25 S o62,91 E 2539 30 2634.43 U,65 ~544,22 S ~84,'19 E 2~34:77 2728.q9 u,31 2v..]u,22 S 707,02 E 2729,38 ,S 15 3 E 8 15 11 E 6 15 15 g S 15 18 g $ 15 '1 ~ 8 15 3 E 5 15 0 E 2[{23,]0 0.36 2g17.4B 0,36 3010,24 U.2~ 3101.88 0,49 3192.28 O.bl 32~1.25 1.00 3451,25 1.18 3530,7o O.b8 3606.82 1.15 222"1,95 $ 729,4~ E 2~23,80 2U19.28 S 752,41 E 2917,96 2909.10 $ 7'15 '11 Fi 3010,75 2997,'/9 $ "/gB[sq f: 3102,41 3085,31 $ ~21,05 E 3192,84 3171,59 S 84'4,22 fl 3281,83 3255,24 S ~6~,93 E 3368 70 3335,15 S 589,~7 E 3451:83 34~1,27 S 912,~8 F 3531,30 3~83,~0 S 935,~6 E 3607.31 $ 14 5ti t.] $ 14 5b E ,5 14 55 E $ 14 55 E $ 14 54 E $ 14 54 E $ 14 54 E $ 14 56 E $ 14 58 E ~ 15 2 E 36'19.56 O. '17 374(). 27 U, 80 3816.41 0,54 38~2.40 0.57 3946.a~ 1,20 40UR, qo O. Un ,tO 10,53 O. oo ,il 15,2~ 0,00 3553.02 S 958.q4 E 368U.02 3619,2] S 980.37 E 3749,06 3u82,98 S ~uOl,o4 F 3810,75 3'14b,46 S lu23,13 F' 3uR2.o9 3~0V.52 $ 104~.bO Fi 3947.22 386!) 04 S 1065,29 [: 4009,16 3923.14 $ lO~6,(,P E 4070,~g 3965,38 S 1101,09 E 4115.42 315 5 E 515 9 E 15 15 12 E $ 15 16 E $ 15 2u E 5 15 24 E $ 15 28 E 15 15 31 i A RCI'I ALAL%KA, 2C-12 KI1pARIlt~ TOP TOTAi..~ [)FPTH SURFACE bOCATION AT Ol~lG.Ihl: 303' FNIj, 272' FWb, S~".C 5. TI. ON RglS~, DM TVI') kECTANGIIbAi4 COORDIi~ATE,5 $ U [4-S[',:A NORTH/$UIITH EAST/WES"I' 74t),l. t~() o045.8b %9Ob. B5 3623,01 750(), (;o f~ObO,~l 5910,61 3626 22 7 b~b. (.)0 ~104.7 ~ 5964.73 .3660:65 7'11~,00 b232,75 6092.25 3740,67 7971.00 ~445.89 6305,8q 380~,46 8167.0~ 0612.7t) 6472.70 3065.38 981 62 5 982 68 g 994 14 g 1021 47 E lOb6 51 5 110! 09 g ARCO 2G-12 KItPARIIA NinRTi.1 Sl,t][:.)t<, AI, At, KA m A R KFI-< N F,A 5 U R I~.!', .'g t,.. !,, () b: F DATE bF' SURVEY: 15-UCT-U4 K~I,I.,¥ BUSinING EbF;~/.ATIUN: t~:NGThEkR: t~EUTbF,~/~EST 140,00 FT SURFACE bUCATION AT [}~'(]"k;][l'~= t(JT]Jw ["'~lll, iI 2'12" [,'WU, SEC TVD RECTAN(;IIbAR COORDINATES $ [ 1F. - S t!: A NUR'I'H/SOIJTH EAST/WEST 7494.00 o(')45, ab 5905,85 3623,01 750u.0() O050.R1 5910,61 3626,72 7565.0o 0104.'73 5964.73 3660,65 7'11 ~.0n 6232,25 6092'25 3740,67 797i,0~ 6445. ,R9 6305,89 3868,46 8167,00 6612,70 6472,70 3965,38 981 62 g 982 68 g 994 14 E 51 £ 1101 09 g FINAT, Whl,b I,[)CAT!LI'~ ~,'1" '.IF': 'I' F' U P $ U )') - .% E A M F' A g U F' Ir.j; D V Fl i< q' I C A i, V ~:'. [)'1' 1 C A D ~. P T n D [!'. P T H l') [< P T H 816'1, O0 o61 ?. 7u ~ 472, '1 () ,} " F I,',; F ',1' I F., (,, 1~ I 1,5 31 ~' SCHLUP1BEROER ARCO ALASKA, INC. 20-~2 KUPARUK NORTH SLOPE, ALASKA OCTOBER iS, 1984 TVN PLOT FROH OCT DATA JOB REFERENCE 69695 WELL' 2G-12 SURFACE LOCATION' 303' FNL, 272' SCALE : 1/I000 IN/FT FWL, S5, TION, R9E, UM HORIZONTAL PROJECTION -1000 -2000 -3000 -4000 -5000 -6000 .:':':":' t' :"': :.:"i'~':':": ...... !'":":' :'"::"I'":: ....... 7','": ...... ................ ~ ........... ~ ........................... ; .............................................................................................. 20.I6 .................... ........... ~' ...... : · l ' ', ' . ~ . ~ ' :..._...~. ~..._...~'- ' ~ · ---; SOUTH -7000 -6000 NEST -SO00 -4000 -3000 -2000 - 1000 0 t 000 2000 ERST NW WELL' 2G-12 SURFACE LOCATION' 303' FNL, 272' FWL, S5, TION, R9E, UM VERTICAL PROJECTION -4000 - ooo -2ooo -,ooo o o ,ooo 2000 ooo 4000 · ' ]. - ........................ & , ........... ~ ............... ~ ................. ; .................. : .................... ~ ......... + ............. ' ............... 7 ....................................... ] ] .................. ......... : ........... ~ ............... ~ ................ , ................................ + ....................... ~ ........... ~...f~.ih~. .................... ~ .............. , .... '~ '; ...... ; .... ; ....;' ;'; ...... ;"; ;"';'":';;'~";';';';;;'";;.;.;;;;;~;'7; ........ ;;'t;;-'; ;;;]'7-"; ;;TT ...... ; ....... ; .......... ~ ...... ............... i .................. L..~ ......... Z;....; .2....;..;i ................... ; .............. ' ............................ ' ......... ; .... ; ................ ~ ............ ; ............ ~ ........... ; .......... ;;;;;;;;';;; '; .... :::::::::::::::::::::::::::::: -- * ..... ; ....... '---- ; ...... ;.-.:-i ........ ; .... . . . ; ; .......... l . ;~ . . ....................... ; .................. ~ ................. ,~ ................................... ; ............ , ....... ; .......................... ,.._.._.... , ' ..... ; ..... , .............. ; . . . ....... : ......................................... ~ ............................................................................. ; ...... , ; ........... ' ......~ .... ]~l ]'] ........ : ............ ' ......... : ........... : ' ~ ....... .............................. , ..... ; .... ~ ; . ....... ~ .... ~ ....... . . : ........ ~ .....~ ........................ ~ .................. , .................. ~...:...: ......... : ............. ;;;;Z.L]; ::::::::::2::::::::::: ::::::::::::::: ::: ::: ~ .... * ......................... ~: ......................... ! ' ' ' ................. II f .................... ~ ........................... ~ .............................................................. ; .... ........................................ + ......................... ....................................................................................................... Z . . · ....... ; ......... '. .......... , . - : . .-~ ......... : .... ; ..... , - , ' ............1R~BB ..................................... f ......... PROJECTION ON vERTICAL PLANE OF AZIMUTH 164 $CPLED IN VERTICAL OEPTH$ HORIZ SCALE : 1/looo IN/FT Suggested form to be fnsertcd in each "Active" we~ ro.ta~r cu u,u~z, ~-~' for ti~ly c~/i~ce ~ {~" ~L~u~atio~. '_ ..... ~ . ,~ a ~ ~ ~ ~ .-t~ ~te Required ._Date Received .Remarks . . Cc~pletion Re~ort Yes '? · _- ..... .... Well tlistory Yes / ,~-~, ' "~____~;~/~.~ · ~ ....... ~ e/3-/~' ~' ,, , · % · .. , · ...... ~re mips " ~/~~. ~ ..... -- ~ .: ,, , , . · .-.= . . Core ~scrip~on ~ ~"' :~-" . ~ , ..... / ' / ' ~ ,, . , , Drill St~ Tese ne~s ~:~./~j_.. ., ~ , .... , : . . ....... , ,~,las! ::':..~. TO AT . SUBJECT IDATE : Fc/~c~rv ,-~, P,.~-'z~- . :.~:. :i klcrc o.r-c i:!'."'!i ~j'~bzici'v'c- i::..?.~ ~c/nf earl i\L~..L I V EL/ F E B 2 0 1985 Alaska Oil & Gas Cons. Commission ~® 4S 469 POLY PAK (S0 Sets) 4P 469 SEND PARTS I AND 3 WITH CARBON INTACT. - PART 3 WILL BE RETURNED WITH REPLY. ,~nchorage /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M Date': DISTRIBUTION .. Drilling W. Pasher State of AK .. Geology '- G. Phillips Sohio Mobil Phillips 0il Union NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. it a subsidiary of AtlanticRichtieldComoany ARCO Alaska, Il ' Post Office Box 360 Anchorage, Ala.~ka 99510 Telephone 907 277 5637 RETURN TO: Date:l/29/85 Transmittal No: 5009 PAGE 1 of 2 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS Schlumberger :~!k/3C~.~/. 2"/5" FDC-CNL/GR "Poro" 9/30/84 Run 1 / " 2"/5" " "Raw" 9/30/84 " 7300 - 7889 7300 - 7889 " 2"-~5" DIL-SFL/GR 9/30/84 " 2847 - 6914 " CPL Cyberlook 9/30/84 " 7300 - 7874 ~ 1L-_16 2"/5" FD~-CNL/GR '.'P. oro" 2"/5" " "Raw" 2" / 5" D IL_-.SFL / GR CPL Cyberl°ok 10/17/84 Run 1 7100 - 7780 10/17f84 " 7100 - 7780 10/17/84 . " 4012- 7820 10/17/84 " 7100- 7780 1L-8 2"/5" FD~-CN~L/GR "Poro" 9/04/84 Run 1 2392 - 7742 " 2"/5" " "Raw" 9/04/84' " 2392 - 7742 " 2"/5" DIL-SFL/GR 9/04/84 " 2392 - 7782 " CPL Cyberlook 9/04/84 " 7100 - 7742 ./cat Receipt Acknowledged: DISTRIBUTION B. Currier Drilling W, Pasher State of AK ~ BPAE G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files _ . ARCO Alaska Post Of 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: Date: 1129/85 Transmittal No: 5009 PAGE .2 Of 2 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. o znu3- 2"/5, "Poro" ,9/20/84 1 ' 2"/5" " "Raw" 9/20/84 " 2"/5" DIL-SFL 9/20/84 " " CPL Cyberlook 9/19/84 " ,~ .....~i: 2"/5" Density Neutron/GR "Poro" 9/2~3/84 " " 2" "' " "Raw" 9/23/84 ~ " 5" " " "Raw'.' 9/23/84 " .2"/5" DIL, SFL/GR 9/23/84 " CPL' Cyberlook 9/23/84 3600 - 8452 3600 - 8452 2074 - 8452 3600 - 8150 Run 1 7290 - 8125 " 7290 - 8125 " 2884 -'81~5 " 2884 - 8148 " 7450 - 7750 /cat Receipt Acknowledged: B. Currier Drilling BPAE Geology" Chevron Mobil D & M NSK Ops. DISTRIBUTION W. Pasher State of AK G. Phillips Sohio Phillips Oil Union J. Rathmell Well Files ARCO Alaska. Inc, il a aubaldlery of AllantlcRIchfieldComl~afty ARCO Alaska, In~r~.~_. Post Offi~ '360 Anchorage, A-~Ska 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RETURN TO: ARCO ALASKA, INC. : ATTN: Records Clerk AT0-1115B P.0. Box 100360 T/~ran~Chorage, AK 99510 itted herewith-are the followiu§ items. Please acknowledge receipt and return one signed copy of this transmittal. CBL' s/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/84 ,, ,, ,, ,, ,! ,, ,, ,1 ,, 1, ,, ,, ,! ,, I! ,! ,, 1, 1, II !I I, I1 II oO I! I! II 11 II I' I1 II II II ti It II II ,t 11 II II Runl "GCT" 10/07/84 " "GCT" 10/07/84 " "OCT/JB / SA" 9 / 31/84 " "OCT/JB/Ring 9/17/84 " "GA/JB/GCT" 9/19/84 " " 9/17/84 " '_' GCT" 7 / 21/84,' " "GCT" 9/21/84 " "GCT/OA/dB" 9114184 " " 9/15/84 " -"GCT/JC" 10/12/84 " " 1o/15/84 " " 10/12/84 " " 10/13/84 " "GCT/JB/GA" 10/22/84 " " 10/22/84 " "JB/GA" 8/19/84 " " 8/20/84 Run 3 9/21/84 Run 1 "OCT/dB" 10/14/84 Run I " lO/14/84 " " 1o/05/84 " "GCT" 10/05/84 " "Perf 4"~ 9/10/84 Run 2 5 z/2"/P?S/dB" 11/05/84 Run 1 Acoustic "VDL/Signature/GR" /cat Receipt Acknowledged: B. Currier ' ? BPAE ~ Chevron DISTRIBUTION · Drilling W. Pasher Geologyi_ /~Z/~ G. Phillips Mobil Phillips Oil 6597 - 8292 ~2B-3/ 7000 - 8460 J'2B-!6/ 4950- 7004 ~2B-13vz 5750 - 8408 -2B-14 5700 - 7970 ~2B-!5 5348 - 6824 -2B-2 7250 - 9182 ~2B-4 5055 - 6487 --2B-l/ 6200 - 7866 f2D-5w/ 6800 - 8954 --2D-6 5054 - 6650 -2D~7/' 5597 - 8084 --'2D-'8-/ 5650 - 7951 --2G-9~ 5840 - 8524 -.gG-11~ 4940 - 6765 ~2G-10/ 5730 - 7950 --2G-12~ 5790 - 7814 - 2G-13/ 5989 - 8624 --2G-14/ 8650 - 9334 ~iF-6~/ 8650 - 9562 5692 - 6742 ~lY-5~ 5150 - 7252 ..-'-iL-i/ 4500 - 6550 ~lL-2w// 6800 - 7518 -1L-4 7000 - 8210 7961 - 8941 --2V-8A 6100 - 6992 ~'1E-24 : ~ - ~ ~ . ~ % ', ~ ~,% . · ," ., · '. ¢,: . .~, ,~ Sohio Union D & M NSK Ops. J. Rathmell Well Files' ARCO Alaska, Post Off' x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 11/07/84 Transmittal No: 4~38 RETLTRN TO: .. ARCO ALASKA, INC. _ ATTN:.- Records Clerk :llSB Box 100360 c hOrage, AK 99510 ' ~Transmitted herewith are the follOwing items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES/Schlumberger /~69612 1L-1 10/08/84 Run 1 ~/69613 1L-2 10/01/84 Run 2 f/69591 2B-13 10/03/84 Run 1 /~/69596 2G-12 9/23/84 f/69594 2G-14 10/08/84 " ,~.~69595 2D-3 10/08/84 " #69623 2D-2 10/16/84 " 3188 - 6643.5 2795 - 7105. /cat Receipt Acknowledged: B. Currier Drilling BPAE Geology Chevron Mobil D & M NSK Ops. Date: DISTRIBUTION W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files ,. ~l~,~ ~: ~la~ka Iflc. ,~ a sub$1d~;:ll'y O! AllanhcRich:,p;cCompen) ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly Reports Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells' 2G-9 1L-8 2D-6 2B-16 2G-10 1L-4 2D-5 2B-15 2G-11 1L-3 2D-4 2B-14 2G-12 1L-2 2B-13 2G-13 Sincerely, Area Drilling Engineer JBK/SH/tw, HILL/01 Enclosures RECEIVED NOV 0 5 l~i~ Alas:~,a 0t~ & Gas Cons. C0mmlssl0rt Anchorage &R~J Al:~k~ Ine i_~ ,m R~;hsld|ar¥ ef AtlanticRIchfieldComDany .~--~ STATE OF ALASKA ~ "--~ -. " ALASK._ .)IL AND GAS CONSERVATION ~, .vlMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~( Workover operation [] 2. Name of operator 7. Permit No· ARCO Alaska, Inc. 84-128 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21159 4. Location of Well at surface 303' FNL, 272' FWL, Sec.5, TION, R9E, UM 5. Elevationinfeet(indicate KB, DF, etc.) 140' RKB, Pad 104' 6. Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2(3-12 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of September , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0600 hrs, 9/18/84. Drld 12-1/4" hole to 2915'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8167'TD as of 9/23/84. Ran logs. Ran, cmtd & tstd 7" csg. Secured well and released rig @ 1550 hr$, 9/24/84. Performed Arctic Pack w/250 sxs PF "C" + 56.5 bbls Arctic Pack. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8", 36#, J-55, HF-ERW + Ijt 10-3/4", 45.5#, K-55 BTC csg w/shoe ~ 2884'. Cmtd w/250 sxs Class "G". 7" 26#, J-55, BTC csg w/shoe ~ 8053' Cmtd w/330 sxs Class "G" 14. Coring resume and brief description N/A 15. Logs run and depth where run D IL/SFL/GR/SP/FDC/CNL/Cal f/8151 ' - 2884' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A DEr'Ell, Il'Pt I\L'~,.L I V LI,./ NOV o 5 1.9 Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. / NOTE--Repo~on ~forn~ls re~uire~ f~r each calendar month, reg~'~d;~ss-o'f't~l~'s';~tu~'~i'(~;::)-e;~tions, and must be filed~in duplicate with the Alaska Oil and Gas'Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10~,04 ~lll /MD~ Submit in duplicate MEM'ORANDUM TO: THRU: Sta e of Alaska FROM: ALASKA/~,,IL AND GAS CONSERVATION COmmISSION C. V e3:ton DATE: Sep~ 26, 1984 Cha i~f~n~---j ~.~-~/' /¢i/ !// FILE NO: D 51 70 ~ /~_.~6 - . Lonnie C. Smith / ' Co.is S io~er ~TELEPHONE NO: Edgar W.Sipple, jr.~~~UBJECT: Wit~ess BOPE Test Petrole~ Inspector~ ~CO' s Kupa~k 2G-12 Sec. 5, T10N,R9E,~I, Pe~it No. 84-128, Doyon Rig 9. Wednesday, September 19,. 1984_: I traveled this date from ARCO's DS 15-8, Pru~e- BAy~ SubjeCt of another report, to ARCO's Kuparuk 2G-12, Doyon Rig 9, to witness a BOPE test. The drilling contractor was in the process of drilling the hole. ~Ynursday, September 20, 1984: The BOPE test commenced at 8:00 am ~n'd Was-ConCluded at. 9:20 am' There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 2G-12, Doyon Rig 9. Attachment 02-00IA(Rev. 10179) . O&G ~4 5/$4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator . /~rC~ Well :~ '~ Location: Sec /~ T/t~ R~&tM Drillin~ Contractor Location, General ~ Well Sign~)~ General Housekeeping. ~k Rig Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack ~lar r~event er Pipe/.~ams Blin~ Rams Choke Line Valves H;C.R. ~lve Kill Line Valves Check Valve Test Pressure ~.Test Results: Failures Representative /(~ Permit # ~'~/// ~.q Casing Set @ ~~ ft. 3¢:O Ri~ #~¢ Representative /,° ~/IID ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psi~ Full Charge Pressure Attained: ~ min~.~ sec. N~ ~ ~00 , ~/0o. glo o/ j /'>': 'g ..... Controls: Master ~ ~_ Remote ~/~ Blinds switch cover psig / ~ ~ minS~sec. Kelly and Floor Safet~ Valves Upper Kelly~~ Test Pressure Lower Kelly ~"~Test Pressure Ball Type'''~ ~K. Test Pressure Inside BOP~"-O~ Test Pressure Choke Manifold ;3 Test Pressure No. flanges~' % Adjustable Chokes ~--/?4z,~ Hydrauically operated choke Test Time , ~'~ hrs. ~ Repair or Replacement of failed equipment to be made within f%7//~ days and Inspector/ Commission office notified. Remarks,__ !A-~ ¢,,¢~Y ~.~,~;'" Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector~ July 31, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2G-12 ARCO Alaska, Inc. Permit No. 84-128 Sur. Loc. 303'FNL, 272'~, Sec. 5, T10M, R9E, UM. Btmhole Loc. tll0'FSL, 1380'FWL, Sec. 5, T10N, R9E, UM. Dear ~ir. Kew-in Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 t~C 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these 8reas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Artic!e~7 and the regulations promulgated thereunder (Title 1~, Alaska Administratiye Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. K~win Kuparuk River Unit 2G-12 -2- July 31, 1984 equipment so that a representative of.the Commission may be present to witness testing of the equipment before the surface Casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance' notification so that we may have a witness present. Verj~truly ~purs, ~ ~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION be EnclosUre cc: Department of Fish & Game, Habitat Section w/o encl. DePartment of EnVironmental Conservation w/o encl. ARCO Alaska, Inc. ?"'- Post Office B i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 18, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2G-12 Dear Mr. Chatterton' Enclosed are- An application for Permit to Drill Kuparuk 2G-12, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on August 11, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kewi~ Area Drilling Engineer JBK/JG/tw GRU8/L59 Attachments RECEIVED J U L 2 5 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~. ALASKA UIL AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL FXlX REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE MULTIPLE ZONE [] 9. Unit or lease name Kuparuk River Unit 10. Well number 26-12 2. Name of operator ARCO Alaska, Inc. 3. Address P, 0. Box 100:360, Anchorage, Alaska 99510 4. Location of well at surface 303' FNL, 272' FWL, Sec.5, T10N, R9E, UM At top of proposed producing interval 1397' FSL, 1297' FWL, Sec. 5, T10N, R9E, UM At total depth 1110' FSL, 1:380' FWL, Sec, 5, T10N, RgE, UH 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 140', PAD 104' I ADL 25667 ALK 2588 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles · 303 feet 17. Number of acres in lease feet 2501 20. Anticipated pressures 2770 MAXIMUM HOLE ANGLE 44° (see 20AAC25.035 (c) (2) 3180 16. Proposed depth (MD & TVD) 7926' MD, 6380' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1435 feet. 21 I15. Distance to nearest drilling or completed 6-11 well60' ~ surface feet 18. Approximate spud date 08/11184 psig@___80° F Surface psig@ 6236 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD Z~,~ 16" 62.5# H-40 Wel¢ 80 36' I 36' 116i 116' 12-1/4" 9-5/8" 36.0# J-55 HF-,ERW BTC 2864 35' I 35' 2899! 2760' I / i I 8-1/2" 7" 26.0# J~55 HF'ERW BTC 7893 33' II 33' 7926'1 6380' I I QUANTITY OF CEMENT (include stage data) + 200 cf 760 sx Permafrost E & 370 sx Permafrost C 280 sx Class G 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7926' MD (6380' TVD), Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole, The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2770 psi, Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects, Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2G-12 will be 60' away from 2G-11 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the workover rig using 3-½", 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~- _ . _ t~¢'&,~ TITLE The space b~elo~ for(~ommiss~e / CONDITIONS OF APPROVAL Samples required Mud log required I Directional Survey required I APl number [~]YES MO E]YES I ~[-~FES i--INO I 50- t~ Permit number Approval date I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY Form 10401 ,COMMISSIONER DATE July 31, 1984 by order of the Commission Submit in triplicate Permit to Dril 1 2G-12 9.2#/ft, J-55, BTC tubing. Selected intervals will be perforated and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED J U L 2 5 198~, Abska Oil & Gas Cons. commission Anchorag~ I 1 ~-~ ~ - : '-'Hft~tz d ; -: ' '; . . : - , , , · , . . , , , , ,, _ I , , , i · ,. ~ ...... I i' ~ , ' ~- ! -- ~ .....t ~ ~ :. ~ooo- ~-.. ~.-.. ~o°o- ~- ~ooo- ~. ~ooo ~ , ~ ~nn' ' ' ~ ~ ..... i .... . ~ I i~.. ~ .......... ~ i ~ i .... ..... ~~ ~ , ..... .......... .............. ~ -: ~ ~ }: ._~ .... ~ ~ * ~ ....... , ....... .... · I _~ i i ~ , ~ ~. ; ~ , - - ..... - i ......... ' ........ ':~ ............... ........... ~'' ...... .... ,~ _: ~: ~ L~ ~ }_::-~:: :._: :::~ :::::::::::::::::::::: h_:.: ,. ...... I .~ ~~ . ~ , ~:=~-, , ,~ , : :'~~,"~ ' ,. , .,.,., , ~ ....... ~ ~', 1-5DEG '59-~H[NE' - ~ ~ ....... 5 198 ......... , ._ , ....... UL ..... I ,, I ..~ i ...... - f__-. ~ .. ~, ...... ,~ j._ ....... ............... .. ":- . ..... ' .... t.~t " )il & A.~o~~~ co.~. t~,~,~,J ...... ~ ,- - ............ i ..... Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lO" side outlets. 5. lC" ball valves, hydraulically actuated, w/lC" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. 3 Maintenance & O~eration 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and clo~e ball valve to upwind diverter line. Do not shut in well under any circumstance~. . . · o 16" Conductor RECEIVED Cborage' Con?mission I ' ANNUI.~ 9 BLIND ' ~,~ 4 I-ZD DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - S000 psi drilling spool w/choke end kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCOMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC F1. UID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND FtANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHE/~D. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND ¥'ALVE$ UPS~ OF C['-tOI<]~S. DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR i0 B. ~~'PP, ESSbRE 1)31/FNST~ OF CHO~ ISOLATION VAL.IFES~. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3O00 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN 80T'rOM SET OF PIPE P, AMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P,/~24S AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY CDCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. I6. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPEI:UkTE BOPE DAILY. RECEIVED JUL 2 5 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc.' Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2G Pad Wel 1 s 5-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L26 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ 49~h G CON O AS lmgl 3' .... '"~+' .5 .6 .? · DS 2(3 $2 Ti 1~ ~ TIO~ I HEREBY CERTIFY THAT I AM P£OPERLT REGISTERED AND LICENSED TO PRACTICE LAND ~-URVETING I1~ THE STATE OF- ALASKA AND THAT THIS PLAT UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARI/ A 527S- $ 3% [.OC~TEV ltl Sec'non SZ.rt 5. 2- 5~929.92 236 ~L 6, Y-5944 t ~5,21 X- )08929,90 8, Y-5944015.09 X- 50&929.94 235 ~L 427 ~L LOCA~ IM SE~{O~ 5.T1 9. Y-~94)465.24 ~T- 70-15-24.321~ X- 50&969.91 ~N~149-55-39.024 273 ~L 123 ~ {g. Y-5941405.10 ~T- 70-15-23.7297 2- 5089~.75 LON~i49-55-)9,0~{ 272 ~L {83 ~ il, Y-594~3~5.24 ~T- 70-{5-23.I4~ ~- 508969,92 LON~i49-55-39.02~ 272 ~L 243 ~l 12. Y-59~285.17 ~T- 70- {5-22.5500 , 2- )0S9~.8~ LON~ 149-55-~9,052 272 ~L 3O3 ~ ~T~D IR SECTIO~ 6.TION,RgE,U.~ t). Y-5~32~5.1~ ~T- 70-~5-22,55~2 X- )0860~.92 ~N~149-55-qg,504 88 ~ 3O3 ~L 14. Y-)9(33qS.15 ~T- 70-15-23,1441 88 ~ 243 ~ I5. Y-594~405,25 ~T- 70-15-23.~353 X- 50~609,~5 ~N~I~55-49Ag9 tAT- 70- { 5-31.5000 tONG= 149-55-40.1 $2 60? FSL I..~T. 70-15-30.9115 LONG-. 149- 55-40. ! 6) 547 FSL LAT- 70-15-30,3204 IONG- 149-55-'t0.164 487 FSL LAT- 70-15-29.729~ LONG- 149-55-40-16~ . ,., 88 FEL 183 FNL S7FEL 123 ~ { ARCO nc. ~ ~~.' ~up.ruk Proj~t North Slope DriltJ: L D.$ 2,0 CONDUCTORS 5' 16 AS- BUILT iii - ___ .-- ~set,' 6. Z.04 {,c,~,'None ,, .... (1) Fee (2) Loc , , CHECK LIST FOR NEW WELL'. PERMiTs :,!:. ~ .... .,~'. ,.' APPROVE DAT . ¢-thru 8) '(8) (3) Admin_ 0 ~ ')" (~, th, ru 11) nd 11) (4) Casg '('12 thru 20) Company (21 thru 24) Lease & Well No. , YES NO (6) Add: 1. Is the permit fee attached .......................................... ~-~, · 2. Is well to be-located in a defined pool .......................... 17~-x~ 3. Is well located proper distance from property line iiiii[iiiiiiiiiii[~ 4. Is well located properdistance from other wells .. 5. Is sufficient undedicated acreage available in this __ 6. Is well to be deviated and is well bore plat included ............ ~ 7. Is operator the only affected party ..' ................... i .... i'i 8. Can permit be approved before ten-day wait .. . i . ~ __ . 10. 11. 12. 13. 14. 15. 16. '17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have. a bond in force ............................... Is a conservation order needed ..... Is administrative appzoval needed Is conductor string provided ................................. Is enough cement used to circulate ;~ c;;~ugtor and surface' . . Will cement tie in surface and intermediate or production string's ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ............... '' <~z Will all casing give adequate safety in collapse, ten;i;~ and Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... · Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ..... .. Does BOPE have sufficient pressure rating - Test to ..~/~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional r~quirements ............................................. Additional Remarks: Geology: Enginj~er ing: Hwr. _ LCS 2Z EW WVA ~ JKT ~_Q~JH ~x~ ,. rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~t~, ~ O ~ ~ ,'1 ~ o I1t ~ ° o ~ ~-~O 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. 'LIS 'T V~RIF'ICAT,ION LISTIN~ VERIFICATION LISTING PAGE ~* RiEEL HEADER ~ERVICE NAME : ;ED I'T )ATE :~BS/OZ/ )RIGIN : ~EEL NAME :304916 :ONTIN,L~ATIDN ~ ~REVI~US REEL ~OMM~NTS :Lt~RAR~ TAPE k, 'TAPE HEADER ,¢ SERVICE NAME :EOIT )ATE :BS/OZ./ 3 ]RiGIN ?APE NAM~ : iONTINUATION # ~R:EVIO~S TAP~ : :OMM~.NTS :L.I,aRAR'.~ TAPE ~* FILE HEADER ~-m :ILE NAME :EDIT .001 ~ERV'ICE NAME : /ERS ION # : }ATE: ~AXIMUM LENGTH : :ILE TYPiE : ~REV.IDUS FILE : INFORMATION 4NEM CONTENTS 'N : ARCO ALASKA INC. iN : KUPARUK ZG-12 :N : KUPARUK ~ANG: 'gE ~ECT: 5 ;O~N: NORTH SLOPE ;TAT: ALASKA ~NEM CONTENTS ~RES: E COMMENTS ~NIT TYPE CATE SIZE gOOE 000 000 016 0~5 000 000 014 055 000 000 005 065 000 000 002 065 000 000 004 065 000 000 002 055 000 000 012 055 CO0 000 006 065 UNiT TYPE CATE SIZE CODE OOO 000 001 055 .VP 01O..HOZ VERIFICATION LISTING PASE 2 ,: SCHLUMBERGER : ALASKA ~I¥1SION COMPUTING CENTER gOMPANY = ARCO ALASKA INC WELL = ZG-.12 FIELD = KU:PARUK ~OU'N'TY = N.SLOPE STATE = ALASK SECTION = 5 TOWNSHIP : ION RANGE : 9E TAPE DENSITY = 800 8PI ,DATE L:DGGED 23 SEP 8.~ BOTTOM .L~G [NTERYAL = 81~8 FT,,, TOP LOG INTERVAL = ZB,~ PT. C A S [ N 'G- L 3 G G E R BIT SIZE '= 8.500 IN. TYPE .VP 010oH02 VERIFIgA'TION LISTING PA'gE ,3 DENS I ? Y VISCOSITY PM FLUID LOSS RM 13 ME'AS. TEMP. RMF ~ MEAS. T,EMP. RMC ~ MEAS. TEMP. RM ,3 LOP: T rltAgS TE AD GR.P,gR IS THE G:R ON 'TH,E FDC/CNL ,PJ2R'OSITY BL:UEL,INE GR.RAW IS 'THE G'R ON THE DOC/CNg RAW DATA ~LUEL.IN~ .FOR ,SOME REASON (UNKNOWN TO ME) THE FIELD ENGINEER P,'jT TH'E GR FROM THE MAIN I:I;LE 2'N JUST THE RAW DATA BLUELiNE, AND THE GR ON THE PB~ROSITY ~LU'ELIN~ IS FROM THE REPEAT FILE. .ALL GR"S ON TH,E LISTINGS NOW MATCH THE ~LUE,LINES--SORRY FOR ALL ~, D~T~ ,FORMAiT RE£3RD :. NT RY BLACKS TYPE SIZE REPR CODE ENTRY' 2 1 6~ O 8 ,~ 7 3 ~ 0 9 ¢ 65 .lin O 1 6~ 0 ) A T U M S,P e.C I F I C A T I O N '~'L O;C ~ S ~N~M SER¥IgE SERVICE UNIT API API API API FILE SIZE SPL R~PR ID ORDER ~ LOG TYPE CLASS MOO .NO. CDDE PRDC ESS -¥P 010oMOZ VERIFICATION LISTING PAGE )EPT FT O0 DO0 O0 0 SFLU DIL OHMM O0 Z20 01 0 ~LO DI~ ~HMM O0 120 ~,6 0 [LM OIL OHMM O0 120 4.~ 0 ~P DIL MV O0 010 01 0 ~'R DIL GAPI O0 310 O1 0 iR RAW GAP~ O0 310 01 0 ;R POR GA,PI O0 310 O1 0 ]ALI FDN IN O0 180 O1 0 ~H28 FDN G~C3 O0 350 g2 0 )RHO FON G/',C3 O0 ~56 01 O ~RAT FON O0 4.ZO Ol 0 ~NRA FDN O0 000 O0 0 ~PHI FON PU O0 890 O0 0 qCNL FDN CPS O0 330 31 0 :CNL FON CPS O0 330 30 0 )EPT ~P '-ALI ~NRA )EPT ;P ;ALI ~NRA ),E PT ~P ;ALI ~NRA )EPT ;P 'ALi ~NRA )EPT ~P 3ALI 2NRA )EPT ~P :ALI JNRA ]EPT i~LI ATA ** 8148.0000 SFLU -12. 9687 GR -999°2500 RHO8 -999.2500 NPHI 8100o0000 SFLU -38,8½37 GR 9,~0~3 RHOB 0..0000 NPHI 8000,000:0 SFLU -4.9.8437 GR 9.179'7 RHOB 0.,0000 NPHI 7900.0000 SFLU 10,04.69 GR 9,1719 RHOB 0o0000 NPHi 7800.0000 SFLU -27.0938 GR 9.2813 RHOB 0.0000 NPHI 7700,0000 SFLU -Z,31~5 GR 8,8'gB4 RHOB 0,.0000 NPm£ 7500.0000 SFLU 26.2656 GR 8.6906 RHOB 0.0000 NPHI 2-8965 iLO 87.3750 SR -999.2500 DRHO -999.2500 NCNL 2.0977 113.5625 GR 42.2852 NCNL 2.4.766 ILD 104.3750 GR 39.~043 NCNL 2.7246 104..6B75 ~R 2.64.53 DR~O 39.a531 NCNL 1.7031 [Lg 109.3125 GR 2.~199 DR~O 46.1426 NCNL ,~.. 7734, ILg 98.6375 GR 2.~629 DR,~D 3,5.1305 NCNL 7..~659 91.0625 SR 2o~082 DRHO 32.9590 NCNL 58. O000000'O00000O 08 00000000000000 6 '~ 00'0 00 O 0000000'0 68 O000000000000O 68 000 O 00000~;000';9 ~ 000 O.O00OO00~O0 :6,8 '000 00,000.00'0 00'O 68 OOO00OO0000OOO 58 O00,OOOO000~O000 6.8 O00000000000.OO 68 00000000000000 ~8 00~-0000000'0000 68 O0000000000OO0 68 000 O.O000'O0000O b, 8 0 O' 0.0000 0'00.0 00 0 68 O00OO000000000 2.55'86 87.~750 GR --999.2500 NRA'T '-999.Z500 FCNL 1,9072 ILM I13o56Z5 GR 0,0615 NRAT 0o0000 FCNL 2oZ148 ILM 104.3750 GR 0.1260 NRAT, 0.0000 FCNL 2..3223 ILM 0.0556 NRA'T O.O000 FCNL 109.3125 ~R 0o0571 NRAT 0.0000 FCNL 3.5781 ILM 98.~375 GR O.O9~Z NRAT 0.0000 FCNL 5.9219 91o06Z~ GR 0.0306 NRAT O.OOOO FCNL -999°2500 -999.ZS.00 -899. 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Z500 RHOB ~NRA -~99.2500 NPHI ]EPT 6~00.0000 SFLU SP -8@.2500 ;ALI @.507~ RHOB RNRA -999.2500 NP~i 2EPT 6500.0000 5FLU SP -90.9375 GR gALI 9..Z734 RHOB RNRA -~99.Z500 NPHI 3EPT 6500.0000 SFLU SP -83.6250 GR CALl 9.0625 RHOB 1~.1~8~ iLO 63.~500 GR 30.6152 NCNL 2.500,0 ILO 108.2~00 GR 44. 8730 NCNL 8.1875 I.LO Z22..5000 GR 43.1152 NCNL 5.2813 Z9.5. 0000 -999. ZS, 00 -999°250.0 NCNL 4. 5547 ILO 150.~750 GR - gg 9.25:00 DRHC · -999.,7500 NC,NL 9.250'0 I'LD 103.7500 GR -999.2500 ORHO -999.250.0 NCNL 4.4531 iL0 L21.3125 GR -999.2500 ,DR~D -999.Z50,0 NCNL G.~Z97 ILO 1~8.6250 SR -gg9.zSO0 ORHO -999.2500 NCNL ~o6133 113.2500 -999.Z500 3RHO -999.Z500 NCNL ~ot758 iLO 89.~875 GR -999.Z500 DRHO -999.Z500 NCNL 7.57~Z IL3 73.5000 GR -999.2500 ORHO 8-5016 ILM 63,.7:500 GR 0.0205 NRAT 0.0000 FCNL IO.B.ZSO0 GR 0,.0t37 NRAT 0.0000 FC,NL ~..7070 2.22.~:00:0 GR 0.015I NRAT 0°0000 FCN, L 2.8613 I'L~ 296.0000 GR -999. 2500 NRA;']' '-'999. 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OOOO SFLU -5i.8750 GR -999.Z500 RHOB -999.2500 NPHI 5&00.0000 SFLU -45.6250 GR -999.2500 RHgB -999.2500 NPHI 5500.0020 SFLU -~.7813 JR -999.2500 RHOB -999.2500 NPHi 5%00.0000 SFLU -41.5313 &R -99t,.Z500 NCNL 3. Z305 -999,.Z500 DRNO -999.2500 NCNL 2.4727 I,LD 99,..~375 GR -999.2500 D.RHO '-999,o,Z500 NCNL %-5¢69 ILO t24.5625 GE -999.2500 DR~O -999.2500 NCNL 3.3730 iLO 144.7500 GR -999.2500 gRflO -999.2500. NCNL 3.7285 .[,LD 15'7.500,0 GR -999.2:500 O.R~O -999.2500 NCNL 1.7607 ILD 171.8750 GR -999. Z500 DRNO '-999..2500 NCNL ~..)3,07 ILB 1.03.8125 &R -99'9.250,0 DRHO -99'9.2500 NCNL ~.6992 ILD 166.8750 GR -999.2500 2R~O -999.2500 N'CNL 3.%199 ILD 140.1250 GR -'999.2500 DRHO -'999.2500 NCNL 3.0098 iL2 87.7500 SR -999.2500 DRHO -999.2500 NCNL 2.11~3 ILD 90.6250 GR -999. 104.. - 9 '99. -'999. --999° -999. -999. -999. -999. -999. 3~. -999. -999. --999. J -999. -999. -999. 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Z500 5R -999.2500 NR&T -999.2500 FCNL 4..21~8 -9'99oZ500 GR -99'9. Z500 NRAT -999.2500 FCNL ~.5117 ILM -'999oZ500 GR -999.2500 NRAT -999.Z500 PCNL 5.7695 -~99.2500 GR -99~.Z5.00 NRAT -999.Z500 FCNL 5.8008 ILM -~99. Z500 SR -99~..Z500 NRAT -999.2500 FCNL -999.Z500 -999.2500 -999.Z'59'0 -999.2500 3..3~96 -99~.2500 -.999..Z50~ 3 1,191 -999. 250.0 -999. 2500 -9'9~=.Z500 --999.2500 3.,5859 -999.250.0 -'999..2500 -~99.25'00 -999.Z500 -999.2500 -999.2;50 4.3594 -999.2500 -999.2500 5.7969 -999.Z500 -999.2500 -999.Z500 -999.Z500 -999.Z500 .VP OIOoHOZ VERIFICATiDN LISTING PA~E 9 )EPT 3ZO0oO000 SFLU SP -65.6250 GR :ALI '-999. ZSOO RHgB JNRA -999.2500 NPHI )EPT 3[00.0000 SFLU ~P -64.0'625 GR :ALZ -999.2500 RHOB ~N,RA -999°2500 NPHI ) E P T 300 0.0000 S :F L U ;P -71.2.500 GR :,ALZ -999.2:500 RHO5 ~NRA -999. Z500 NPHI )EPT 2900,.000'0 SFLU ;P -77,.587~ .GR :ALI -999.2500 R'HO~ ~NRA -9:99. 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