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190-142
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ?~)-/¢~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items- Pages: [] Grayscale, halftones, pi.ctums, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. n Other, No/Type OVERSIZED Logs'of vadous kinds . Other Complete COMMENTS: Scanned by: Dianna Vincent Nathan Lowell _ TO RE-SCAN Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended Q lb. Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5 Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: December 9, 2011 190 - 142 / 311 - 355 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 23, 1990 50 103 - 20147 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2538' FNL, 220' FEL, Sec. 23, T12N, R8E, UM October 28, 1990 3G - 22 Top of Productive Horizon: 8. KB (ft above MSL): 90' RKB 15. Field /Pool(s): 1079' FNL, 480' FEL, Sec. 27, T12N, R8E, UM GL (ft above MSL): 54' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1296' FNL, 744' FEL, Sec. 27, T12N, R8E, UM 9625' MD / 6002' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498160 y 5988561 Zone 4 9782' MD / 6085' TVD ADL 25549 TPI: x - 492622 y - 5984743 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 492358 y 5984526 Zone 4 SSSV @ 1907' MD / 1784' TVD 2663 18. Directional Survey: Yes ❑ No Q 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) 1600' MD / 1539' 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 GR / CCL 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' 115' 36' 115' 24" 216 sx AS I 9.625" 36# J -55 36' 4042' 36' 2947' 12.25" 950 sx AS III, 550 sx Class G 7" 26# J -55 36' 9764' 36' 6076' 8.5" 200 sx Class G 4.5" 12.6# L -80 9150' 9611' 5734' 5994' 6.125" 21 bbls 15.8 cement 24. Open to production or injection? Yes ❑ No 0 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" 9177' 9126' MD / 5720' TVD none 0 ' NED 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. O 0 2017 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ii s.a iii Anctisrav 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable shut - in 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. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No is 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 RBDMS JAN 0 6 2012 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE /J Submit original only (4,-. 28. GEOLOGIC MARKERS (List all formations and markers ntered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes EI 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 1600 1539 needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: none 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik elsor @ 263 - 4693 Printed Name er H. Gober Title: Wells Enaineerinq Supervisor Signature #.%_,41_4.-. Phone 263 - 4220 Date 1 /6/12- - 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 la: 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 12/2009 KUP 3G -22 Conoc hillips a 1'-„" , * . Well Attributes ax Angle & MD TD Wel!bore API /UWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) Alaska. Inc. 501032014700 KUPARUK RIVER UNIT PROD 61.02 3,500.00 9,782.0 Cortocraps ' Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date SSSV: TRDP 110 11/3/2010 Last WO: 12/8/2011 37.11 10/30/1990 Well Confie: - 3G -22, 1/0/2 AM - - Schemt 23011 k - Actual 611:2 Annotation Depth (RKB) String 0,,. Entl St Date ng ID ,.. Annotation Top (RKB) Last Mod ... End Date Last Tag: SLM 9,472.0 11/ Rev Reason: WORKOVER ninam 12/30/2011 i Casing Strings [ Casing Descripti Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd HANGER, 24 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.58 H WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 35.0 4,042.2 2,947.1 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 0.0 9,764.0 6,075.9 26.00 J - 55 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SCAB LINER 4 1/2 4.000 9,126.3 9,611.0 5,994.1 11.60 L -80 BTC -Mod Liner Details Top Depth CONDUCTOR, 1 (ND) Top Inel Noml... 36-115 T (ftKB) (RKB) ( °) Item Description Comment ID (in) 9,126.3 5,719.8 54.53 PACKER BAKER C2 @ ZXP LINER TOP PACKER 4.470 SAFETY VLV. jI 9,146.4 5,731.4 54.59 HANGER BAKER HYDRAULIC FLEXLOCK HANGER 4.470 1.607 1. a'='' . ' 9,156.2 5,737.1 54.61 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 23.9 9,177.0 5,749.2 9.30 L -80 EUE8rdABMOD GAS LIFT, Completion Details 31 s0 Top Depth . n (ND) Top Inc! Nomi... Top (ftKB) (RKB) (°) Kern Description Comment ID (In) p 23.9 23.9 -0.03 HANGER TUBING HANGER & PUP 3.500 1,906.7 1,783.9 45.41 SAFETY VLV CAMCO TRMAZZ- CMT -5-SR SAFETY VALVE 2.812 9,093.2 5,700.6 54.44 NIPPLE CAMCO X NIPPLE 2.813 SURFACE, • L 9,140.4 5,727.9 54.57 SEAL ASSY SEAL ASSEMBLY FOR BOT 80-40 SEAL BORE EXTENSION HALF 2.990 35 MULE SHOE 4 _1 Other In Hole eNireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, _ Top Depth 5,445 (TVD) Top Inc! Top (RKB) (RKB) ( °) Description Comment Run Date ID (in) 9,561 5,967.3 57.66 FISH 1.5" OV Dropped valve into rathole while attempting to set a 10/17/1999 0.000 GLM at GLM #6 on 10/17/98 9,643 6,011.2 57.66 FISH 1" GLV Found Empty Pocket @ GLM #4; Fell to Rathole 10/11/1996 0.000 GAS LIFT. r 7133 Perforations & Slots Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (RKB) (RKB) (RKB) Zone Date (68... Type Comment 9,376 9,426 5,863.8 5,891.5 C-4, A -3, 3G-22 6/10/1991 4.0 APERF 180 deg. phasing; 2 1/2' Titan GAS LIFT, e3 T, 9,426 9,462 5,891.5 5,912.3 A -2, 3G-22 1/4/1991 4.0 IPERF 180 deg. phasing; HLS 4 1/2" Csg Gun Notes: General & Safety End Date Annotation 11/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 9,033 II NIPPLE. 9,093 -- lit t 1� �i Y SEAL ASSY, r 1 9,140 It I I APERF, 9,376 -9,426 IPERF, 9,426 -9,462 Mandrel Details Top Depth Top Port (TVD) Ind OD Valve Latch Size TRO Run Stn Top (RKB( (RKB) ( °) Make Model (in) Sery , Type (in) (psi) Run Date Com... Flsrl.9ss1 1 3,160.1 2,495.3 59.20 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/8/2011 4 2 5,445.4 3,686.0 58.11 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/8/2011 3 7,133.2 4,581.0 58.07 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/8/2011 I I , 4 8,328.2 5,254.2 54.24 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/8/2011 /i 5 9,032.8 5,665.3 54.28 CAMCO MMG 1 1/2 GAS LIFT SOV REK 0.000 0.0 12/8/2011 SCAB LINER. i} 9,126 -9,611 pq FISH, 9,643 1.1 PRODUCTION. iL 0-9,764 TD, 9,762 3G -22 Pre Rig Well Work Summary DATE SUMMARY i 7/29/11 RAN TEL,2.12 "CENT., 1 3/4" SAME BAILER, GOT STUCK @ 7266' SLM, likE FREE, ALL TOOLS RECOVERED, IN PROGRESS. 7/30/11 TAG 9464' SLM, BRUSHED TBG & FLUSHED TBG TO TTL, CLEAN READY FOR CALIPER. 7/31/11 RAN 24 -ARM CALIPER WITH EXTENDED REACH FINGERS, TAG PBTD AT 9510'. MADE SEVERAL ATTEMPTS TO LOG 7" CASING FROM 9510'. CALIPER FINGERS APPEARED TO FOULING WITH DEBRIS. HAD TO CYCLE CALIPER FINGERS OPEN /CLOSED TO CLEAR. LOG CALIPER FROM 9462' TO SURFACE. DATA SENT TO PDS FOR PROCESSING. 8/4/11 MEASURED SBHP @ 9419' RKB. COMPLETE. 8/16/11 TEST BOPS 8/17/11 ATTEMPTED TO PULL FRAC SLEEVE AT 1767 CTMD, SEVERAL JAR LICKS AT MAX PULL, NO MOVEMENT. RIGGED UP SCALE BLASTER, JETTED 7" FROM 9300 CTMD TO 9500 CTMD WITH SEVERAL PASSES, RTNS GOOD ALL DAY, ALSO JETTED FRAC SLEEVE AT 1767. WELL IS SHUT IN AND FREEZE PROTECTED. JOB COMPLETE 8/19/11 LOG 24 ARM CALIPER FROM TAG DEPTH OF 9514' TO 9147'. RAW CALIPER DATA LOOKED USABLE, COMPARED TO PREVIOUS ATTEMPT ON 7/31/11. HES ANCHORAGE TO PROCESS FINAL LOG. AND REPORT. 11/20/11 (PR) T POT- PASSED; TPPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; FUNCTION TEST LDS- FUNCTIONAL 11/20/11 REPLACED 1" GLV'S WITH 1" DV'S @ 2806' RKB AND 6420' RKB.IN PROGRESS 11/21/11 PULLED 1.5" OV FROM 9199' RKB.MECHANICAL PROBLEMS ON TRANSPORT CREATING DELAY IN JOB.BULLHEAD 260 BBL'S DOWN IA TO FORMATION ATTEMPT TO SET 1.5" DV © 9199' RKB.IN PROGRESS 11/22/11 SET 1.5" LIGHT DMY @ 9199' B .MITIA 3000# PASSED.TAGGED 9472' SLM EST 40' RATHOLE.PULLED 1.5" LIGHT DMY @ 9199' RKB.30 MIN SBHPS @ 9419' RKB= 3386 psi WITH GRADIENT • ConocoPhillips Time Log & Summary Wenview Web Reporting Report Well Name: 3G - 22 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 11/26/2011 4:30:00 PM Rig Release: 12/10/2011 4:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/25/2011 24 hr Summary Rig was released f/ 3H -34 to move 10 miles to 3G -22 @ 1200 hrs 11/25/2011. The camp arrived @ 1300 hrs. The truck shop arrived @ 16:30 hrs. A convoy of the pumps, motors, and boiler complex's arrived @ 2030 hrs. Peak went back and loaded two pipe shed pieces and the pits. PJSM, then moved rig sub off the hole. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P The camp arrived on location © 1300 hrs. The truck shop was close behind @ 16:30 hrs. Rigging down and moving off of 3H Pad. Move the rock washer away from the rig. A convoy of the pumps, motors, and boiler complex's arrived @ 2030 hrs. Peak went back and loaded two pipe shed pieces and the pits. PJSM, then moved rig sub off the hole. Note: Rig was released f/ 3H -34 to move to 3G -22 (10 mile move) @ 1200 hrs 11/25/2011. 11/26/2011 Bring sub base, pipe sheds, pits to 3G from 3H. Set matting boards over 3G, set sub base over well, set modules in place around the rig. Connect all lines from each module. Prepare to take on mud, load 4" drill pipe in pipe shed. Rig accepted © 16:30 Hrs 11/26/2011. 400 bbls of 12.2 ppg mud in the pits, rigging up to 434 bbl flow back tank. 00:00 02:30 2.50 0 0 MIRU MOVE MOB P Move Rig Sub off Well 3G -22, maneuver on pad, attatch tow bar, line up to leave pad. 02:30 05:30 3.00 0 0 MIRU MOVE MOB P Move pipe sheds, pits, and sub base to 3G from 3H pad. Begin to set up on well 3G -22. 05:30 06:30 1.00 0 0 MIRU MOVE MOB P Set matting boards on rig 'foot print pattern' around the well head. 06:30 09:00 2.50 0 0 MIRU MOVE MOB P Set sub base over well 3G -22. Center up. 09:00 10:00 1.00 0 0 MIRU MOVE RURD P Set matting boards for pipe shed, set both pipe shed module. 10:00 12:00 2.00 0 0 MIRU MOVE RURD P Set matting boards for pits, pumps, and motor complexes. 12:00 12:45 0.75 0 0 MIRU MOVE RURD P Set matting boards for boiler room complex. Set complex in place. 12:45 16:00 3.25 0 0 MIRU MOVE RURD P Rig up steam, air, water, glycol lines, lower stairs and landings, prepare rig for acceptance. 16:00 16:30 0.50 0 0 MIRU MOVE RURD P Finalize rig acceptance form with Company Man. Rg accepted 16:30 hours 11/26/2011. 16:30 17:30 1.00 0 0 COMPZ RPCOM RURD P Load 12.2 PPG KWF into pits. Load 4" DP in pipe shed. Prepare rig for upcoming work over operations. Set Site Control shack Page 1 of 16 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 20:30 3.00 0 0 COMPZ RPCOM RURD P Load more 12.2 ppg KWM into pits (Total of 400 bbls in the pits at crew change). Trucks going back to MI mud plant in Deadhorse f/ two more loads. Loading 4" drill pipe in the pipe shed. 20:30 00:00 3.50 0 0 COMPZ RPCOM RURD P Loading pipe shed w/ 4" drill pipe. Sim Ops: Trouble shoot and thaw steam lines on the rig. Work to get tioga on the pipe shed working. Toolhouse roustabouts setting 434 bbl flow back tank, hooking up 2" hardline from choke house to tank. 11/27/2011 Set up 434 barrel double wall tiger tank, choke house, hardline in w/ 2 ". Kill the well w/ 12.2 ppg mud. 1,/ Circulate out gas cut mud. 00:00 03:30 3.50 0 0 COMPZ WELCTL KLWL P Rig up high pressure lines in cellar, install double IA valve, 1500 PSI on IA, SIMOPS: Pressure up rig water lines. Take on 12.2 PPG mud into pits. 03:30 05:00 1.50 0 0 COMPZ WELCTL KLWL P Test mud pumps, and all lines to 3500 PSI. No leaks. Rig up scaffolding in cellar around tree. Test outside flow back lines to 1000 PSI. No leaks. 05:00 08:00 3.00 0 0 COMPZ WELCTL MPSP P Rig up lubricator, pull CIW 3 type 'H' BPV. Rig down lubricator. ( Called FMC Rep. Deadhorse, on question on actuated valve showing a 2" length of piston sticking out of the end. Kuparuk valve shop advised that 1 -1/2" to 2" is the open position on the old Axelson actuator. 08:00 08:30 0.50 0 0 COMPZ WELCTL KLWL P PJSM, Rig up in cellar to pump down the tubing and take returns into the choke house, and then the flow back tank. 08:30 11:30 3.00 0 0 COMPZ WELCTL KLWL P Bleed off gas from the annulus. Break circulation w/ 12.3 PPG KWF @ 1 BPM. Tubing ICP =1650 PSI / IA ICP =1500 PSI, stage up to 2 BPM. After 400 stokes, TBG =1000 PSI / IA =1525 PSI, staged up to 3 BPM. At 80 bbls pumped- KWF @ GLM #6 (9199' MD). TBG =500 PSI / IA =1550 PSI. Maintain 500 psi plus w/ KWF at the GLM. Pump 380 barrels total. Shut in and monitor well. TBG =0 / IA =125 PSI. 11:30 12:00 0.50 0 0 COMPZ WELCTL RURD P Blow down outside hard lines to the choke house and the 434 tiger tank. Page 2 of 16 S • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 0 0 COMPZ WELCTL CIRC P Bullhead 15 BBLS of 12.2 PPG mud down the tubing @ 2BPM. 700 PSI. Increase to 950 PSI. Shut in well monitor pressures. TBG =480 PSI / IA =75 PSI. Bleed off pressure. Shut back in. Monitored pressure. TBG =50 PSI / IA =40 PSI. 12:30 13:15 0.75 0 0 COMPZ WELCTL CIRC P Decided to line up to pits 1,2,3, and 6 so the degasser can be utilized. Load 200 more barrels of 12.2 mud into pits from truck. 13:15 15:00 1.75 0 0 COMPZ WELCTL CIRC P Pump down tubing @ 3 BPM. 700 PSI. Pumped surface to surface. 3250 strokes. Mud weight still out of balance. 12.2 PPG in. 11.9 PPG out. 15:00 16:45 1.75 0 0 COMPZ WELCTL CIRC P Continue to circulate to condition the mud, adding barite to weight up the light spots, and running the degasser. 16:45 17:45 1.00 0 0 COMPZ WELCTL OWFF P Observe well for flow. Well static. Rig down hoses. Rig up to dry rod in CIW'HP' BPV. 17:45 18:00 0.25 0 0 COMPZ WELCTL MPSP P Set BPV. CIW 3" type 'HP' BPV. Line up to pump down IA. Test BPV from underneath. Bull head 3.8 BBLS down IA @ 780 PSI, 3.5 BPM. BPV showed no leaks. Shut down. Bleed back pressure on IA. 18:00 20:00 2.00 0 0 COMPZ WHDBO NUND P Nipple down production tree. All threads looked good. Tubing hanger threads looked good. 20:00 21:30 1.50 0 0 COMPZ WHDBO NUND P Nipple up adapter spool and spacer spool. SIMOPS: R/D out side hard line, empty tiger tank. ( Hauled off 360 BBLS.) 21:30 22:15 0.75 0 0 COMPZ WHDBO NUND P Remove 13 5/8" x 11' adapter spool from bottom of BOP stack and place on BOP rack. 22:15 00:00 1.75 0 0 COMPZ WHDBO NUND P Nipple up Hydril 13 5/8" BOP stack. 11/28/2011 Nipple up and test BOPE. Pull blanking dart and BPV. Attempt to pull SBE from the PBR. Unable to pull free. 6/ Work pipe/ circulate and call out Halliburton E line. PJSM, RU HES e-line. 00:00 03:45 3.75 0 0 COMPZ WHDBO NUND P PJSM. Continue to Nipple up BOPE, SIMOPS: change out save sub on top drive, cut 3" off of riser. 03:45 05:30 1.75 0 0 COMPZ WHDBO BOPE P Rig up test equipment. Install 4" test joint with 3'/2' EUE XO, per Cameron rep. flood stack and choke manifold with water. Page 3 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 10:30 5.00 0 0 COMPZ WHDBO BOPE P Test BOPE 250 PSI low, 4100 PSI high, 250 PSI low, 3500 PSI high on annular. Pick up 4" test joint. Test #1 - Top pipe rams 3W X 6" VBR's. Choke valves 1,12,13,14 & manual Q,y� kill valve. Test #2 - upper IBOP,HCR ��IIJJ�� kill, choke valves 9,11.Test #3 Lower IBOP, choke valve 5,8,10. Test #4 Dart valve choke valves 4,6,7. Test #5 Floor valve, choke valve 2, Test #6 HCR choke valve, demco kill line valve. Test #7 Manual choke valve, HCR kill. Test #8 Annular preventer. Test #9 Lower pipe rams, 2 7/8" x 5 ". Accumulator test system pressure = 3000 PSI after closed = 1850 PSI, 200 PSI attained in 40 secs. Full pressure attained 178 seconds. 5 nitrogen bottle average = 1900 PSI Test #10 blind rams choke valve 3. 10:30 12:00 1.50 0 0 COMPZ WHDBO BOPE P Rig down 4" test joint. Rig up 3W test joint with 3 %" EUE XO per Cameron rep. Rig up test equipment. Test #11 annular test, 250 PSI low. Pressure up to 2000 PSI, saw an inch of movement. Bled off pressure. Pull test joint. inspect threads. attempt to make up test joint. Note: Grease fitting on choke valve #6 failed. Replaced fitting, failed again, regreased, passed. AOGCC Chuck Scheve witness entire test. 12:00 12:30 0.50 0 0 COMPZ WHDBO BOPE P Crew change PJSM. Set test joint 3%2' 12:30 13:30 1.00 0 0 COMPZ WHDBO BOPE P Test with 3 %" test joint. Upper and lower VBR's. 250 PSI low, 4100 PSI high. Annular test 250 PSI low, 3500 PSI high. 13:30 14:00 0.50 0 0 COMPZ WHDBO BOPE P Rig down test equipment. 14:00 14:30 0.50 0 0 COMPZ WHDBO BOPE P Blow down kill line and choke lines, suck out water from stack to enable the Cameron hand to see his profile. 14:30 14:45 0.25 0 0 COMPZ RPCOM MPSP P Pull blanking plug on dry rod, check for gas, no gas. Pull BPV. 14:45 16:00 1.25 0 0 COMPZ RPCOM NUND P Monitor well on trip tank, pick up casing equipment from beaver slide, rig up casing equipment. Hole static. 16:00 16:30 0.50 0 0 COMPZ RPCOM PULD P Make up landing joint out of 3 pups, 1 -8', 2 -10'. 16:30 17:00 0.50 0 0 COMPZ RPCOM PUTB P Make up landing joint to hanger. Make up 8 turns. Screw into top drive. Back out lock down screws. Page 4 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 21:30 4.50 0 0 COMPZ RPCOM CIRC P Attempt to pull free. Max pull 149K. 114k = 80% of tubing tension rating. 35k = Doyon 141 topdrive and block weight. The tubing hanger pulled out with 15k over, and 7.5' feet of stretch was seen at max pull. Staged pumps up to 3 BPM. 550 PSI. Circulate while working pipe. Notified Halliburton E line. Continued to circulate and work string until Hal. rigged up. 21:30 22:00 0.50 0 0 COMPZ RPCOM PULD P Picking up Halliburton e-line tools from the beaver slide to the floor. Stage tools in the pipe shed. 22:00 22:30 0.50 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on rigging up HES f/ cutting 3 -1/2" tubing. 22:30 22:45 0.25 0 0 COMPZ RPCOM RURD P Shut down pumps. Set 3 -1/2" tubing string in the slips w/ 140k on the weight indicator. Remove the top 10' pup of the lalnding joint. Blow down the top drive. Break out the 3 -1/2" EUE x 4" XT39 crossover. 22:45 00:00 1.25 0 0 COMPZ RPCOM RURD P Rig up HES- MU lubricator and BOPS. 11/29/2011 Rig up Schlumberger E -line crew with Lubricator. Make up 1.75" cutter assembly. WLIH to locate & cut tbg at 9225' WLM. WLOH. Utilize pumping to free tool @ 1807'. Observed sand at surface when circulating. Pulled free and hung up in lubricator. Dissasemble BOP's, clamp & cut line. Remove BOP's & lubricator. Pull & lay down cutter assembly. Observed good fire. RD E -line. Make up valves. Circulate to weight up to 12.5 PPG. FCP = 780 PSI - 4 BPM. Monitor well - static. POOH lay down 3 1/2" tbg. 00:00 04:30 4.50 COMPZ RPCOM ELNE P Held PJSM with crew & E -line Reps. Rig down E -line BOPE. Make up floor safety valve with XO's drifted to 2.25 ". Make up E -line BOPE, and lubricator. Hange sheaves. Make up electromechanical cutter assembly. 04:30 04:45 0.25 COMPZ RPCOM PRTS P Fill lubricator and test same to 500 / 3000 PSI. 04:45 08:00 3.25 COMPZ RPCOM ELNE P WLIH with cutter assembly. Take weight at 7390' WLM. Pump down tbg string, to free tool and pump down to set on depth at 9225'. Verify depths, and fire tool to cut tbg. 08:00 08:30 0.50 COMPZ RPCOM ELNE P WLOH to 1807' WLM. String pulled tight. 08:30 12:45 4.25 COMPZ RPCOM ELNE T Break circulation at 1 BPM - 400 PSI. Stage pumps to 5.5 BPM - 1350 PSI. Work wireline assembly, observing sand at surface. Continue work wireline until free, increasing pump to 6 BPM - 1525 PSI. SHut down pumps. Pull assembly to surface at 15', observing tool string hung up in lubricator. Page 5 of 16 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 16:00 3.25 COMPZ RPCOM ELNE T Dissasemble lubricator. Break connection on BOPE. Observed tool string centralizer hung up in Lubricator. Install cable clamp. Cut wireline, pull and lay down lubricator. 16:00 18:00 2.00 COMPZ RPCOM ELNE P Pull and lay down BOPE, hydraulic lines and grease head. Pull and lay down tool string assembly. Inspect cutter to obsery good fire. Rig down sheaves. 18:00 21:30 3.50 COMPZ RPCOM CIRC P Make up valves and hoses. Circulate well increasing mud weight to 12.5 PPG. FCP = 780 PSI - 4 BPM. Rig up tbg pulling equipment, power tongs, and control line spooler. 21:30 21:45 0.25 COMPZ RPCOM OWFF P Monitor well - static. Held PJSM iwth crew, casing hand, and Camco rep. 21:45 22:15 0.50 COMPZ RPCOM PULL P Pull, breakout & lay down 3 1/2" tbg pups, and hanger. UP WT = 92K. 22:15 23:15 1.00 COMPZ RPCOM PULL P Pull & lay down 10 ints. Spool control line. Pulling wet. Pump dry job. Install pressure gauge and put 5000 PSI on control line. 23:15 00:00 0.75 COMPZ RPCOM PULL P Continue POH, breakout & lay down 3 1/2" tbg. Crew Change 11/30/2011 Continue POOH, breakout & lay down 3 1/2" tbg. Control line parted and dumped 5000 PSI. Would not hold pressure. Continue POOH. Recovered 28 SS bands. POOH lay down a total of 300 jnts.Install wear bushing. MU BHA #1, TIH picking up 4" DP from shed. 00:00 02:15 2.25 COMPZ RPCOM PULL P Continue POOH, breakout & lay down 3 1/2" tbg. Spool control line. Recovered a total of 28 stainless steel control line clamps. Observed Isolation sleeve hung up in pin end of joint above SSSV. Observed proper displacement. 02:15 12:30 10.25 COMPZ RPCOM PULL P Continue POOH lay down 3 1/2" tbg. Recoverd a total of 300 jnts of tbg. 6 GLM's,a nd SSSV. Cut joint looked good - 8.52'. 12:30 15:30 3.00 COMPZ RPCOM PULD P Clean & clear rig floor area. Send out all GLM's. remove tubinh from pipe shed. Send out power equipment. Load spiral DC's in shed. Strap same. 15:30 16:00 0.50 COMPZ RPCOM PULD P Install wear bushing. RILDS. 16:00 16:15 0.25 COMPZ FISH SFTY P Held PJSM with crew & BOT rep. Discuss sasfety & hazard recognition issues. Discuss procedure to make up fishing BHA #1. 16:15 18:00 1.75 225 COMPZ FISH PULD P Make up fishing BHA #1. Total length = 225.04'. Page 6 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 225 5,829 COMPZ FISH TRIP P Make up remainng BHA with drill collars. Continue trip in hole picking up 4" drill pipe frorm shed to 5824'. Observed proper displacement. Crew Change 12/01/2011 Continue TIH picking up 4" DP from shed to tag top of tbg stump at 9202' DPM. Engage fish & pull seal assembly free. CBU. Verify 12.5 PPG mud all around. POOH at slow speed due to swabbing issues. Rack back DC's. Breakout & lay down Overshot & seal assembly, cut jnt. Make up BHA #2, TIH. Slip & cut Drilling line. Service rig. Continue TIH to 5384'. 00:00 03:00 3.00 5,829 8,648 COMPZ FISH TRIP P Continue trip in hole with BHA #1, picking up 4" drill pipe from shed to 8648'. 03:00 04:00 1.00 8,648 8,648 COMPZ FISH TRIP P Rack back 10 stands making room for remaining DP in shed. 04:00 06:00 2.00 8,648 9,154 COMPZ FISH TRIP P Continue TIH with DP singles from shed to 9154'. 06:00 06:30 0.50 9,154 9,202 COMPZ FISH FISH P Break circualtion, obtain parameters. UP WT = 143K, SO WT = 77K, ROT WT = 105K. Pumps at 3 BPM - 800 PSI. Wash down to tag tbg stump at 9202'. DPM. Engage fish. Pull to verify catch at 175K. Work string to fire jars with 200K pulled, observing fish came free. Pull to observe seals pull free of packer. Retag to verify fish catch. 06:30 07:30 1.00 9,202 9,202 COMPZ FISH CIRC P Continue circulate bottoms up with pumps at 6 BPM - 1700 PSI. No gas on bottoms up. Verify 12.5 PPG mud all around. 07:30 07:45 0.25 9,202 9,100 COMPZ FISH OWFF P Monitor well - static. Rack back one stand. Blow down Top drive & lines. 07:45 12:00 4.25 9,100 6,803 COMPZ FISH TRIP P POOH with BHA #1 & Fish to 6803'. Observed swabbing issues, slowing pulling rate to accomodate. Observed proper displacement. Crew Change 12:00 17:00 5.00 6,803 225 COMPZ FISH TRIP P Continue POOH with BHA #1 & Fish to BHA. Observed swabbing issues, slowing pulling rate to accomodate. Observed proper displacement. 17:00 18:30 1.50 225 0 COMPZ RPCOM PULD P Rack back DC's. Breakout & lay down overshot assembly, and fish. recovered seal assembly - 12.80', and cut jnt - 22.15'. Estimated top of PBR @ 9227'. 18:30 18:45 0.25 0 0 COMPZ RPCOM PULD P Clean & clear rig floor. Send tools out. 18:45 19:45 1.00 0 312 COMPZ WELLPF PULD P Make up BHA #2, packer retrieving tool. BHA length = 218.83'. Run one more stand. Stab a safety valve. 19:45 20:00 0.25 312 312 COMPZ WELLPF SFTY P Held PJSM with crew. Discuss sasfety & hazard recognition issues. Discuss procedure to slip & cut drilling line. 20:00 21:15 1.25 312 312 COMPZ WELLPF SLPC P Slip & cut 74' of drilliing line. Servie rig, Top drive & blocks. Page 7 of 16 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 00:00 2.75 312 5,384 COMPZ WELLPF TRIP P Trip in hole with BHA #2 to 5384' DPM. Observed proper displacement. Crew Change 12/02/2011 Continue trip in hole with BHA #2. Tag top of packer at 9227' DPM. Obtain paramteres. Engage fish top, work string with staright pulls to 215K. Rotate string to put 9 RH turns in and release packer ? ?. Slack off to re- engage PKR pull to 215K fire jars, free movement. Retag same depth, with no overpull. Repeat tag. CBU POOH. Did not recover fish. Inspect snap latch - shear screws sheared. MU BHA #3 with Itco Spear - 3.947" Grapple. TIH to 8210'. 00:00 02:15 2.25 5,384 9,150 COMPZ WELLPF TRIP P Continue trip in hole with BHA #2 to 9150'. Observed proper displacement. 02:15 02:45 0.50 9,150 9,227 COMPZ WELLPF FISH P Obtain parameters. Tag packer at 9227' DPM. UP WT - 155K, SO WT - 80K, ROT WT - 98K. Pumps at 6 BPM - 1500 PSI. Engage fish, pull to verify catch. Work string, open jars, pull to 215K. Repeat. No release. In neutral position work string with RH turns for a total of 9 turns, Observed release ? ?. Pull to observe no overpull. Retag, and engage fish once again. Pull to 215K, jars fired and free movement obtained. Repeat tag up, at same depth. Observed pressure increase when set down. Work string free movement. 02:45 04:00 1.25 9,227 9,227 COMPZ WELLPF CIRC P Circulate bottoms up, observing fluid losses with initial rates of 6 BPM. Slow pumps to 4 BPM. Initial losses at 30 BPH, slowing to 5 BPH while pumping. 04:00 04:30 0.50 9,227 9,125 COMPZ WELLPF OWFF P Monitor well - Static, pull one stand, swabbing. 04:30 12:00 7.50 9,125 4,915 COMPZ WELLPFTRIP P POOH with BHA #2, pumping each stand as swabbing issues would not allow staright pull. Fluid loss 16.5 BBLS. Crew Change 12:00 15:15 3.25 4,915 1,150 COMPZ WELLPF TRIP P Continue POOH pumping each stand out to 1150' at 2.5 BPM - 250 PSI. Observed hole with fluid dropping when stand pulled. 15:15 18:45 3.50 1,150 0 COMPZ WELLPFTRIP P Blow down top drive & lines. POOH on elevators to BHA. Rack back DC's and pull to snap latch. Observed shear pins sheared, and no fish recovered. Breakout & lay down snap latch assembly. Observed proper displacement. 18:45 20:00 1.25 0 223 COMPZ WELLPF PULD PJSM. Make up BHA #3 with Itco Spear assembly and 3.947" Grapple. 20:00 00:00 4.00 223 8,210 COMPZ WELLPF TRIP P Trip in hole with BHA #3 to 8210'. Observed proper displacement. Crew change Page 8 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/03/2011 24 hr summary Continue TIH with BHA #3. Obtain parameters. Tag & engage fish. verify catch. Pull and jar on packer until pulled free. Observed 25K drag. CBU with gas cut mud at surface. Circulate until 12.5 PPG all around. Monitor well. Observed flow with mud weight balanced. Weight up system in stages to 12.9 PPG. Monitor 1 / well - static. Pump out of hole with fish to 1351'observing drag of 25 -90K. 00:00 00:30 0.50 8,210 9,227 COMPZ WELLPF TRIP P Continue trip in hole with BHA #3. Obtain parameters, UP WT - 150K, SO WT - 80K Pumps at 4 BPM - 1500 PSI. 00:30 02:00 1.50 9,227 9,227 COMPZ WELLPF FISH P Tag & engage fish at 9227 DPM. Pull to verify catch. Continue pull and jar on packer until free movement obtained, after firing jars repeatedly at 250K, and straight pull to 300K. Pull PKR up hole to approximately 15', observing 25 -30K drag. Take weight when attempting to go down. 02:00 05:00 3.00 9,227 9,227 COMPZ WELLPF CIRC P Circulate bottoms up at 4 BPM - 1300 PSI. Observed fluid loss increase to 30 BPH at 5 BPM. Observed gas cut mud on surface when bottoms up, continuing to circulate until well balanced at 12.5 PPG. Circulate a total of 8200 strokes. 05:00 05:30 0.50 9,227 9,227 COMPZ WELLPF OWFF P Monitor well. Observe well flowing, with pit gain 4 BBLS in 30 minutes. 05:30 11:00 5.50 9,227 9,227 COMPZ WELLPF CIRC P Decision to increase mud weight to 12.7 PPG. Circulate at 4 BPM - 1300 PSI to increase mud weight.. Monitor well - flowing. Increase mud weight to 12.9 PPG. Observed 24 BPH losses while pumping. Well balanced at 12.9 PPG. Monitor well. Static. 11:00 12:00 1.00 9,227 9,059 COMPZ WELLPF TRIP P Pump out of hole with fish, observing hanging up and drag from 25 -90K. Recock and fire jars numerous times when PKR hanging up. Total fluid losses for tour - 242 BBLS. Crew • Change 12:00 00:00 12.00 9,059 1,351 COMPZ WELLPF TRIP P Continue pump out of hole with fish, observing hanging up and drag from 25 -90K. Recock and fire jars numerous times when PKR hanging up. Fluid losses slowing and tapered off to 2.2 BPH while pumping out of hole. Total fluid losses for tour - 27 BBLS. Crew Change 12/04/2011 Continue pump out of hole with fish. Pull and la down HB PKR assembl with tail.' • - Make up Clean out assembly with Reverse circulating basket. TIH to 1826'. Phase 3 weather. Rig on standby for 8.75 HRS until phase 2 announced. Monitor well. Continue TIH from 1826' - to tag at 9378'. Drop ball and allow to seat on reverse basket. Wash down circulating up to 6 BPM. Observed fluid losses at 100 BPH, slow pumps in stages down to 3.5 BPM. Mix & pup LCM pills. Losses slowed to 60 BPH. Continue wash & work through casing anomaly at 9278' until upper mill through bad spot. Wash down to 9393'. Mix mud. Fluid loss for the day = 277 BBLS. Page 9 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 1,351 225 COMPZ WELLPF TRIP P Continue pump out of hole with fish to the BHA, observing hanging up and drag. Fluid losses 2.2 BPH while pumping out of hole. 01:00 01:15 0.25 225 225 COMPZ WELLPF OWFF P Monitor well. Static. Held PJSM discussing procedure to breakout & lay down fish. 01:15 02:30 1.25 225 0 COMPZ WELLPF PULD P Rack back DC's. Pull, breakout & lay down Fish. Fish = HB PKR & tailpipe assembly - 52.36' 02:30 03:30 1.00 0 0 COMPZ WELLPF PULD P Clean & clear rig floor. Send tools out. Perform Post Jarring Derrick Inspection 03:30 06:00 2.50 0 240 COMPZ WELLPF PULD P Make up BOT cleanout assembly with Reverse circulating basket assembly, and 6.125" Head. 06:00 07:00 1.00 240 1,826 COMPZ WELLPF TRIP P Trip in hole with BHA #4 to 1826'. Cleanout assembly. Observed proper displacement. 07:00 12:00 5.00 1,826 1,826 COMPZ WELLFF OWFF T Security announce Phase 3 Weatehr conditions. Rig on stanby, and emergency services could not travel to location if needed. Perform Rig maintenance. Monitor well. Static. Crew Change 12:00 15:45 3.75 1,826 1,826 COMPZ WELLPF OWFF T Rig on standby. Rig continued to perform maintenance. Phase 2 weather conditions announced. 15:45 20:15 4.50 1,826 9,352 COMPZ WELLPF TRIP P Continue trip in hole with BHA #4 to 9352'. Obtain parameters. UP WT = 155K, SO WT = 80K. ROT WT = 105K. Pumps at 3 BPM - 900 PSI. 6 BPM - 1800 PSI. 20:15 21:00 0.75 9,352 9,352 COMPZ WELLPF FCO P Tag up at 9378' DPM. Drop 7/8" Ball as per BOT rep. Allow to fall and pump @ 3 BPM to observe seated in reverse basket assembly. 6 BPM - 2250 PSI. 21:00 00:00 3.00 9,352 9,393 COMPZ WELLPF FCO P Wash down to tag and rotate drill string to work through casing anomaly at 9378'. Continue wash down and work to 9393', observing better downward movement. At 6 BPM fluid losses at 100 BPH. Slow pumps to 3.5 BPM with losses at 60 BPH. Mix & pump LCM pills. Mix mud to keep volume. Total fluid loss for the day = 277 BBLS. 12/05/2011 Continue wash & work from 9393' to 9625', with pumps at 3.5 BPM - 900 PSI. Fluid losses 60 BPH. Continue mix & pump 30 BBL LCM pills. Monitor well. establish well breathing, with returns slowing. Pump out of hole,. Observed 25K overpull at 9395'. Troubleshoot & repair boiler issue. Continue Pump out of hole with proper displacement to 3920'. Pull on elevators from 3920' to BHA. Breakout & lay down BHA. Observed reverse basket assembly packed off with iron debris and sand. Rig up test equipment, begin testing BOP's. Witness of test waived by AOGCC rep John Crisp. Total loss for the day = 280 BBLS. Page 10 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:15 6.25 9,393 9,625 COMPZ WELLPF FCO P Continue wash & work string down from 9393' - 9625'. Pumps at 3.5 BPM - 1075 PSI. Fluid losses steady at 60 BPH. Mix & pump 30 BBL LCM pills, and mix mud to 12.9 PPG for volume. 06:15 08:15 2.00 9,625 9,625 COMPZ WELLPF OWFF P Monitor well. Observe flow, and establish breathing issues. Flow slowing, wuth a total of 10 BBLS gained in 2 HRS, until dead. 08:15 12:00 3.75 9,625 7,934 COMPZ WELLPF TRIP P Pump out of hole with assembly from 9625' - 7934'. Pump at 1 BPM - 350 PSI. Observed 25K overpull at 9395'. Work through area, and monitor well. Continue pump out of hole. Total fluid lost in tour = 271 BBLS. Crew Change 12:00 17:45 5.75 7,934 3,920 COMPZ WELLPF TRIP P Continue pump out of hole from 7934' - 3920'. 17:45 18:30 0.75 3,920 3,920 COMPZ WELLPF RGRP T Observe well. Boilers down, blow down rig, and troubleshoot. Repair electrical connection. Load lines, and verify boiler operation OK. 18:30 21:45 3.25 3,920 225 COMPZ WELLPF TRIP P Continue pump out of hole from 3920' - BHA. Monitor well. 21:45 23:15 1.50 225 0 COMPZ WELLPF PULD P Breakout & lay down BHA. Inspect reverse basket assembly. basket packed off iwth iron debris, and sand. Clean & clear rig floor. 23:15 00:00 0.75 0 0 COMPZ WHDBO BOPE P RU, test BOP's, to 250 / 4000 PSI. Witness of test waived by AOGCC rep John Crisp. Total loss for the tour = 8.5 BBLS. Crew Change 12/06/2011 Continue test BOP's. Test choke manifold and valves. Test BOP stack & rams. Test manual, and HCR valves.Test all rig floor safety valves. All test to 250 / 4000 PSI. Test annular to 250 / 3500 PSI. All test recorded on chart. Perform Koomey test. Intial 200 PSI gained in 34 sec. Full 3000 PSI gained in 147 secs. Observed 5 nitrogen bottle with avg psi of 1950. Witness of test waived by AOGCC rep John Crisp. Make up 4 1/2" Scab Liner assembly with BOT Flexlock hanger & ZXP Liner top packer. RIH to locate shoe at 9612'. Break circulation, staging pump to 4 BPM - 950 PSI. CBU x 2, staging HES E -line crew. Held PJSM. 00:00 08:00 8.00 0 0 COMPZ WHDBO BOPE P Continue test BOP's. Test Choke manifold and valves. Test BOP stack rams. Test Manual, and HCR valves. t() Test all rig floor safety valves. All test l to 250 / 4000 PSI. Test annular to 250 / 3500 PSI. All test recorded on 1r' chart. Perform Koomey test. Intial 200 PSI gained in 34 sec. Full 3000 PSI gained in 147 secs. Observed 5 nitrogen bottle with avg psi of 1950. Witness of test waived by AOGCC rep John Crisp. 08:00 08:45 0.75 0 0 COMPZ WHDBO BOPE P Rig down test equipment. Blow down lines and choke manifold. Line up choke. Page 11 of 16 • a Time Logs , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 10:15 1.50 0 0 PROD1 CASING RURD P Pull tools to rig floor. Rig up casing running equipment, power tongs. Ensure wear bushing will fit over running tool, and packer assembly. RIH, set WB. RILDS. 10:15 10:30 0.25 0 0 PROD1 CASING SFTY P Held PJSM with crew, Casing rep and BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to make up and run 4 1/2" Scab liner assembly. 10:30 12:45 2.25 0 0 PROD1 CASING RNCS P Make up 4 12/" shoe track, baker -loc connections, and fill same. Check floats. Continue make up 4 1/2" jnts as per detail. Pick up Baker SBE with Flexlock hanger, and ZXP packer assembly. Make up running tool assmy and XO. Rig up and circulate through assembly at 2.5 BPM - 75 PSI. 12:45 20:45 8.00 0 9,613 PROD1 CASING TRIP P Trip in hole with liner. Obtain T &D parameters every 10 stands. Observed proper displacement. Locate shoe joint at 9613' DPM. UP WT = 142K, SO WT = 77K. 20:45 23:15 2.50 9,613 9,613 PROD1 CASING CIRC P Rig up and break circulation staging pumps to 4.5 BPM - 950 PSI. Maintain less than 1000 PSI as per BOT rep. MUD WT = 12.9 PPG In /Out 23:15 00:00 0.75 9,613 9,613 PROD1 CASING ELOG P Held PJSM with HES E -line reps. Discuss rigging up. Pull tools to rig floor. Continue circulate at 4 BPM. Observed fluid losses at 20 -30 BPH. Crew Change 12/07/2011 Continue rig up HES E -line crew with BOP, Lubricator, and pump in sub. Monitor well. WLIH for correlation / log on Scab Liner. WLOH. RD E -line. SPOT Schlumberger Cementers. RU. Pump 21 BBL scab liner cement ✓ job. Displace with 12.9 PPG LSND. Set Liner Hanger & packer. Top of ZXP packer = 9126'. WOC 5 HRS. Perform Liner lap test 250 / 2500 PSI - 30 Minutes. Perform NFT - 30 Minutes. Displace well with 8.5 seawater. Perform NFT - 30 minutes. Begin POOH, lay down 4" DP. 00:00 00:15 0.25 9,613 9,613 PROD1 CASING SFTY P Held PJSM with new crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up, and run GR/CCL 00:15 02:15 2.00 9,613 9,613 PROD1 CASING RURD P Position shoe at 9613'. Pumps off. Rig up HES E -line crew with Lubricator & BOP's. Make up pump in sub. Monitor well. Breathing back 1 BBL in and hour. Flow slowing to stop. Pressure test Lubricator to 500 PSI. 02:15 04:00 1.75 9,613 9,613 PROD1 CASING ELOG P WLIH with GR /CCL assembly. Loacte & correlate to HES CBL - 1990. Discuss log with Engineer, and confirmed string on depth as planned. 04:00 05:00 1.00 9,613 9,613 PROD1 CASING ELOG P WLOH with GR /CCL. Observed well - static. Page 12 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:30 1.50 9,613 9,613 PROD1 CASING RURD P Rig down HES E -line crew with Lubricator, & BOP's. Clean & clear rig floor area. 06:30 07:45 1.25 9,613 9,611 PROD1 CEMEN RURD P Spot Schlumberger cementers. Pull tools to floor. Make up cement head & lines. Position shoe on depth at 9611' 07:45 10:00 2.25 9,611 9,611 PROD1 CEMEN "CIRC P Circulate & condition mud, while SLB crews rigged up. Held PJSM with crew & SLB. Pumps at 3 BPM - 800 PSI. No losses. 10:00 10:45 0.75 9,611 9,611 PROD1 CEMEN" CMNT P Turn over to SLB. Pump 5 BBLS Water. Pressure test lines to 3500 PSI. Continue pump 10 BBLS 13.5 ,-/ Mud Push, 21 BBLS of 15.8 PPG (/�" cement, and 10 BBLS water. 10:45 11:15 0.50 9,611 9,611 PROD1 CEMEN DISP P Turn over to Rig. Displace cement 11 " w with 12.9 PPG mud at 3 BPM - 800 (4• PSI. Observed latch up at 860 strokes, and bump plug at 900 Strokes. Cement in place at 1110 HRS. 11:15 12:00 0.75 9,611 9,611 PROD1 CEMEN" RUNL P Pressure to 3000 PSI. Set down 40K to set hanger. Bleed off, check floats. Pressure to 1000 PSI. Pull to 30K over, slack off to 70K. Rotatae 12 RH turns to release from hanger assembly. Pull to observe pressure decrease. Circulate at 4 BPM - 1000 PSI. Continue pick up 10'. Rotate drill string 15 RPM's. Slack off to set ZXP packer with 45K down weight. Stop rotation. Pull up 15'. Crew Change 12:00 12:45 0.75 9,611 9,611 PROD1 CEMEN" CIRC P Circulate bottoms up x 2 with pumps at 6 BPM - 1950 PSI. Reciprocated drill string in 15' increments. Estimated 4 -5 BBLS cement returns. 12:45 13:15 0.50 9,611 9,100 PROD1 CEMEN" RURD P Pull 15'. Breakout & lay down 1 single. Blow down lines. Breakout & lay dwon cement swivel. Install floor valve. 13:15 17:15 4.00 9,100 9,100 PROD1 CEMEN - WOC P Wait on cement as planned for 500 PSI compressive strength. Clean pits. Servie rig. Secure well, repair beaver slide door. Make up lines. 17:15 18:30 1.25 9,100 9,100 PROD1 CEMEN P Break circulation. Close rams. Perform Liner top pressure test @ 250 / 2500 PSI. Held pressure 30 minutes, record on chart. Bleed pressure. Open rams, rig down cement line. 18:30 19:00 0.50 9,100 9,100 PROD1 CEMEN" OWFF P Perform NFT - 30 minutes. No Flow. Held PJSM with crew & drivers. Discuss safety & hazard recognition issues. Discuss procedure to displace well. Page 13 of 16 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 22:15 3.25 9,100 9,100 PROD1 CEMEN' CIRC P Displace well with 8.5 PPG seawater. Pumps at 6 BPM - 1600 PSI. Stage pumps to 8 BPM - 2000 SPI. Reciprocate string 90'. Total fluid pumped - 700 BBLS. Blow down Top drive & lines. 22:15 22:45 0.50 9,100 9,100 PROD1 CEMEN' OWFF P Perform NFT - 30 minutes. No Flow. Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to breakout & lay down 4" DP.. 22:45 00:00 1.25 9,100 8,585 COMPZ RPEQPITRIP P POOH, breakout & lay dow 4" drill pipe. Pull to 8585'. Observed proper displacement. UP WT - 150K, SO WT - 82K. Crew Change 12/08/2011 Continue POOH breakout & lay down 4" drill pipe. Prep for 3 1/2" Completion run. Slip & Cut Drilling line. Service rig. Make up BOT 3 1/2" seal assembly, and trip in hole with 3 1/2" completion string as per detail to 8455'. Make up SSSV and control line. Test to 6000 PSI. 00:00 03:00 3.00 8,585 4,790 COMPZ RPEQPITRIP P POOH, breakout & lay down 4" DP. Prep for 3 1/2" completion run. 03:00 03:45 0.75 4,790 4,790 COMPZ RPEQP1 SVRG P Service rig, & Top Drive. 03:45 07:30 3.75 4,790 0 COMPZ RPEQP1 TRIP P Continue POOH, breakout & lay down 4" drill pipe. 07:30 08:00 0.50 0 0 COMPZ RPEQP1 PULD P Inspect, breakout & lay down running tool. 08:00 09:00 1.00 0 0 COMPZ RPEQP1 TRIP P Trip in hole with remaining DP from the derick. POOH, lay down same. / 09:00 09:30 0.50 0 0 COMPZ RPCOM RURD P BOLDS, pull wear bushing. ✓ 09:30 09:45 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew. Discuss sasfety & hazard recognition issues. Discuss procedure to Slip & cut drilling line. 09:45 11:30 1.75 0 0 COMPZ RPCOM SLPC P Slip & Cut 71' of drilling line. Service & inpect drawworks brake linkage. Inspect TD. 11:30 12:00 0.50 0 0 COMPZ RPCOM RURD P Pull tools to rig floor. Rig up power tongs to run completion string. Crew Change 12:00 12:45 0.75 0 0 COMPZ RPCOM RURD P Continue rig up power equipment to run completion string. 12:45 13:00 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew & BOT rep. Discuss sasfety & hazard recognition issues. Discuss procedure to run 3 1/2" completion string. Confirm running order, and check tubing. 13:00 20:00 7.00 0 7,100 COMPZ RPCOM RCST P Make up seal assembly. Continue pick up 3 1/2" tubing, and GLM's as per detail. 20:00 22:00 2.00 7,100 7,100 COMPZ RPCOM RCST P Make SSSV, and attach control line after pumping to purge line. Observed trouble obtaining a test on the line at the conection. Cut line twice, Re- connect and test line to 6000 PSI. - 15 minutes. Page 14 of 16 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 7,100 8,455 COMPZ RPCOM RCST P Continue RIH with 3 1/2" completiopn string to joint # 270, 8455'. Crew Change 12/09/2011 Continue RIH with 3 1/2" Completion string, SSSV & C.L. Space out, install space out pups. Make up Tbg hanger with CL. Pressure test to 6000 PSI. Pump 30 BBLS of corrosion inhibitor, chase with 8.5 seawater to allow 5 BBLS in tbg. Land tbg hanger. RILDS. Pressure down tubing to 2500 PSI - 30 Minutes. Test annulus to 2500 PSI - 30 Minutes. Bleed pressure allowing SOV valve to shear. ND BOP's. Open Ram doors, clean I out cement. NU Tree & test to 5000 PSI. Displace well with 316 BBLS of freeze protect diesel. Install BPV. Secre well, tree & cellar. 00:00 01:00 1.00 8,455 9,100 COMPZ RPCOM RCST P Continue run 3 1/2" Completion string. 01:00 01:30 0.50 9,100 9,167 COMPZ RPCOM RCST P Sting into ZXP top, continue slack off to No -go out in seal bore. Mark pipe, and pull 3 joints. 01:30 03:30 2.00 9,167 9,167 COMPZ RPCOM RCST P Install space out pups. (10.13' & 6.15'), and single under hanger. Make up tubing hanger & pup. Make up control line, and pressure test same to 6000 PSI - 15 minutes. 03:30 04:15 0.75 9,167 9,167 COMPZ RPCOM CRIH P Pump 30 BBLS of corrosion inhibiotr. Chase with 74.5 BBLS of seawater to allow 5 BBLS inhibitor in the tubing string. Pumps at 3.5 BPM - 350 PSI. 04:15 05:00 0.75 9,167 COMPZ RPCOM THGR P Drain Stack. Land tubing hanger. Observed landed with seals too high. 05:00 07:15 2.25 COMPZ RPCOM HOSO P Rig up power tongs. Pull tbg to first single. Install 10' spaceout pups for proper space out. Make up control line with splice. Re -test line to 6000 PSI. Attach to joint & hanger. Total of 69 SS bands run. RIH land tbg. RILDS. 07:15 08:00 0.75 COMPZ RPCOM PRTS P Rig up line. Pressure down tbg to 2500 PSI - 30 Minutes. Record on chart. 08:00 09:00 1.00 COMPZ RPCOM PRTS P Bleed tbg to 1600 PSI. Pressure down annulus to 2500 PSI - 30 minutes. Record on chart. Bleed pressures to 0 PSI. pressure down annulus to 2300 PSI to observe SOV shear, and communication to tbg. Bleed all pressures. 09:00 10:00 1.00 COMPZ WHDBO MPSP P Blow down all lines. Back out & lay down landing joint. Install BPV. Cut control line, rig down spooling unit. 10:00 12:00 2.00 COMPZ WHDBO NUND P Held PJSM. Function annular and rams while fluching same. Open doors and clean out green cement. Clean out ram cavities. Crew Change 12:00 15:00 3.00 COMPZ WHDBO NUND P Continue clean out rams, & BOP's. 15:00 16:30 1.50 COMPZ WHDBO NUND P Nipple down double studded adapter flange, and BOP stack. 16:30 17:45 1.25 COMPZ WHDBO NUND P Nipple up tree adpter flange, and tree. Verify tree orientation with Pad operator. Page 15 of 16 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 19:00 1.25 COMPZ WHDBO PRTS P Rig up, and pressure test void on hanger to 5000 PSI - 5 minutes. Test SSSV line to 5000 PSI. RD Lines. 19:00 20:45 1.75 COMPZ WHDBO PRTS P Rig up and test tree to 5000 PSI. Record on chart. Rig down lines. SIMOPS: Rig up Little Red Services. 20:45 21:15 0.50 COMPZ RPCOM SFTY P Held PJSM with crew, Mud Man & Little Red Services reps. Discuss safety & hazard recognition issues. Discuss procedure to displace well with freeze protect diesel. 21:15 23:30 2.25 COMPZ RPCOM FRZP P Test lines to 2200 PSI. With LRS, Displace well with 316 BBLS of 60 Deg diesel at 2.5 BPM - 1250 PSI. Observe well - static. 23:30 00:00 0.50 COMPZ WHDBO MPSP P Install BPV as per Cameron rep. Secure well, tree valves & cellar. Crew Change 12/10/2011 Well Secure. Clean pits. Suck out cellar. Prep rig for move. Rig released at 0400 HRS. Prep & move rig with Peak, to 1 E pad. 00:00 04:00 4.00 DEMOB MOVE DMOB P Well secure. Clean pits, Rockwasher. Suck out cellar box. TBG Pressure = 0 PSI. Annulus Pressure = 0 PSI. Blow down all lines, and disconnect all interconnect lines. Rig Released @ 0400 HRS. Page 16 of 16 • • C---S. WELL LOG TRANSMITTAL I' PROAcrivE DIAgNOSIIiC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 :juk.s AUG cb 1 20ia RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. RECEIVED Attn: Robert A. Richey 130 West International Airport Road AUG - 2011 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 ON & Gas Cons. Commissicm Anchorage 1 . ' • - _: 30-Jul-11 2X-17 1 Report / CD 50- 029 - 22616 -00 2) Caliper Report 31- Jul -11 3G-22 1 Report / CD - 50 -103- 20147 -00 1 '� ?() g Signed : O Date : as t` LS Print Name: 1`4�w.. �- Oklr-y ��- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E -MAIL : PDSANCHORAGE(MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \ConocoPlullips_Transmit.docx 1 - 1 )- 1 • • 1 Multi- Finger Caliper i� Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 3G -22 Log Date: July 31, 2011 Field: Kuparuk I Log No. : 10259146 ZX70 State: Alaska Run No.: 1 API No.: 50- 103 - 20147 -00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE MOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 9,300 Ft. (MD) 1 Inspection Type : Pre -CTD Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is correlated to the Tubing Detail Record dated January 05, 1991. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage prior 1 to CTD operations. The caliper recordings indicate the 3.5" tubing appears to be in good to fair condition, with a maximum recorded wall penetration of 23% in joint 166 (5,118'). Recorded damage appears as isolated pitting. No I significant areas of cross - sectional wall loss or I.D. restrictions are recorded. Although no significant I.D. restrictions are recorded, the caliper recordings indicate light scale -like deposits throughout the majority of the 3.5" tubing. 1 This summary report is an interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: I Isolated Pitting ( 23%) Jt. Jt. 166 @ 5,118 Ft. (MD) Isolated Pitting ( 21%) 157 @ 4,830 Ft. (MD) I No other significant wall penetrations (> 19 %) are recorded. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: I No significant areas of cross - sectional wall loss (> 9 %) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: I No significant I.D. restrictions are recorded. Mandrel Orientation I 3G-22 Joint No. Tool ConocoPhillips Deviation Alaska, Inc. Kuparuk July 31, 2011 Mandrel No. Latch Orientation 90.1 55 1 5:30 172.1 60 2 9:30 I 209.1 59 3 11:30 245.1 56 4 1:00 278.1 56 5 1:30 1 299.2 54 6 10:00 I Field Engineer: Galligan & Regnier Analyst: C. Waldrop Witness: J. Condio Active Diagnostic Se; c. / P.._ X369, Staffor;_. .'497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS(umemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I 1 i ( ' — 1H ;--- 1 • • Correlation of Recorded Damage to Borehole Profile 1 ■ Pipe 1 3.5 in. (71.6' - 9300.3') Well: 3G -22 Field: Kuparuk I Company: ConocoPhillips Alaska, Inc 1 Country: USA Survey Date: July 31, 2011 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 75 1 25 _ 799 1 50 1558 .......2 75 - 1111111 2351 I GLM 1 -� 100 pr 311 5 I 125 P 3848 150 1 4610 _ a 1 GLM 2 2 — — 175 E 5382 U_ C Z 200 6137 Y I GLM 3 0 Q 225 689 7 1 GLM 4 250 7667 — GLM 5 8429 1 GLM 6 300 9215 300.6 9300 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 1 I Bottom of Survey = 300.6 1 1 • 1 PDS Report Overview IPS Body Region Analysis I Well: 3G -22 Survey Date: July 31, 2011 Field: Kuparuk Tool Type: UW MFC XR 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf J -55 EUE MOD Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 in. 9.3 ppf J -55 EUE MOD 2.992 in. 3.5 in. 6.0 in. 6.0 in. 1 Penetration(% wall) Damage Profile (% wall) I 400---- Penetration body Metal loss body 0 50 100 0 1 300 --- 200 1--- 100 --- 50 _ -_ 0 I 0 to 20% 20 to 40 to over 40% 85% 85% GLM 1 98 Number of joints analysed (total = 307) I 305 2 0 0 148, I Damage Configuration ( body ) 300 GLM 2 I 250 200 GLM 3 198 = _ 150 1 100 _ -_ 50 GLM 4 2484 0 I Isolated General Line Other Hole / —" Pitting Corrosion Corrosion Damage Pos. Hole GLM 5 . Number of joints damaged (total = 250) GLM 6 I 250 0 0 0 0 Bottom of Survey = 300.6 1 1 1 1 • III PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf J -55 EUE MOD Well: 3G-22 Body Wall: 0.254 in. Field: Kupanik Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in. Country: USA Survey Date: July 31, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 72 0 0.01 5 0 2.96 Pu p 3 1 75 0 0.03 12 2.92 Shallow Pitting. U. Deposits. ■ 2 105 0 0.03 11 3 2.90 Lt. Deposits. ■ 3 135 0 0.03 12 4 2.92 Shallow Pitting. Lt. Deposits. ■ 4 166 0 0.03 11 4 2.92 Lt. Deposits. ■ I 5 196 0 0.03 12 4 2.92 Shallow Pitting. Lt. Deposits. ■ 6 227 0 0.03 11 3 2.90 Lt. Deposits. ■ 7 257 0 0.03 11 3 2.92 Lt. Deposits. 8 288 0 0.02 7 1 2.91 Lt. Deposits. I 9 10 318 0 0.03 12 3 2.93 Shallow Pitting. Lt. Deposits. ■ 349 0 0.03 11 2 2.92 Lt. Deposits. ■ 11 379 0 0.03 12 2 2.91 Shallow Pitting. Lt. Deposits. ■ 12 407 0 0.03 11 2 2.89 Lt. Deposits. ■ I 13 438 0 0.03 10 2 2.92 Lt. Deposits. ■ 14 467 0 0.04 14 4 2.92 Shallow Pitting. Lt. Deposits. ■ 15 498 O 0.04 16 4 2.92 Shallow Line of Pits. Lt. Deposits. • 16 526 0 0.03 11 3 2.92 Lt. Deposits. • 17 556 0 0.03 11 1 2.92 I.t. Deposits. ■ I 18 586 0 0.03 11 3 2.92 Lt. Deposits. ■ 19 617 O 0.03 10 2 2.91 Lt. Deposits. ■ 20 647 0 0.03 12 4 2.93 Shallow Pitting. Lt. Deposits. ■ 21 676 0 0.03 12 4 2.90 Shallow Pitting. Lt. Deposits. ■ I 22 23 707 0 0.04 16 7 2.92 Shallow Line of Pits. Lt. Deposits. r 738 0 0.03 12 5 2.91 Shallow Pitting. Lt. Deposits. ■ 24 769 0 0.03 12 3 2.91 Shallow Pitting. Lt. Deposits. ■ 25 799 0 0.03 12 5 2.93 Shallow Pitting. Lt. Deposits. ■ I 26 829 0 0.03 12 3 2.93 Shallow Pitting. Lt. Deposits. ■ 27 858 0 0.04 17 6 2.92 Shallow Line of Pits. Lt. Deposits. ■ 28 888 0 0.03 11 5 2.93 ■ 29 918 0 0.03 11 3 2.89 , Lt. Deposits. • I 30 949 0 0.04 14 5 2.93 Shallow Line of Pits. Lt. Deposits. ■ 31 979 O 0.03 11 2 2.91 Lt. Deposits. Ni 32 1010 O 0.04 16 7 2.92 Shallow Pitting. Lt. Deposits. 1 33 1040 0 0.03 11 3 2.89 Lt. Deposits. ■ 34 1070 0 0.03 12 4 2.92 Shallow Pitting.. Lt. Deposits. • I 35 1101 0 0.03 12 2 2.90 Shallow Line of Pits. Lt. Deposits. ■ 36 1131 0 0.03 12 3 2.92 Shallow Pitting. Lt. Deposits. ■ 37 1161 0 0.03 11 4 2.92 Lt. Deposits. ■ 38 1 191 0 0.04 16 5 2.91 Shallow Line of Pits. Lt. Deposits. ■ I 39 1222 0 0.03 12 4 2.94 Shallow Pitting. • 40 1253 0 0.03 11 4 2.93 ■ 41 1283 0 0.03 11 3 2.94 ■ 42 1314 0 0.03 12 4 2.93 Shallow Pitting. Lt. Deposits. ■ I 43 1344 0 0.03 11 3 2.91 Lt. Deposits. NI 1375 0 0.03 12 4 2.91 Shallow Pitting. Lt. Deposits. ■ 45 1405 0 0.03 11 4 2.91 Lt. Deposits. ■ 46 1436 0 0.03 12 4 2.90 Shallow Pitting. Lt. Deposits. ■ 47 1466 0 0.04 14 4 2.90 Shallow Pitting. Lt. Deposits. ■ I 48 1497 0 0.03 11 4 2.91 Lt. Deposits. ■ 49 1527 0 0.03 12 5 2.91 Shallow Line of Pits. Lt. Deposits. Body 1 Metal Loss Penetration Bo Body Page 1 1 1 1 . • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf J -55 EUE MOD Well: 3G-22 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in. Country: USA Survey Date: July 31, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 50 1558 0 0.03 11 2 2.91 Lt. Deposits. • 51 1588 0 0.04 14 4 2.92 Shallow Pitting. Lt. Deposits. • ■ 52 1619 0 0.03 11 3 2.88 Lt. Deposits. • 53 1649 0 0.03 11 4 2.90 Lt. Deposits. ■ 54 1680 0 0.03 1 1 3 2.92 Lt. Deposits. ■ I 55 1710 0 0.03 11 2 2.89 Lt. Deposits. • 56 1741 0 0.04 14 4 2.91 Shallow Line of Pits. Lt. Deposits. ■ 57 1772 0 0.04 14 4 2.90 Shallow Line of Pits. Lt. Deposits. 58 1802 0 0.02 9 1 2.88 Lt. Deposits. I 58.1 1819 0 0 0 0 2.27 Frac Sleeve 14'2" OAL 58.2 1833 0.03 0.04 16 8 2.99 Pup Shallow Pitting. 58.3 1842 0 0 0 0 2.81 Otis 'FMX' Series SSV 58.4 1851 0 0.02 9 3 2.96 Pu p I 59 1860 0 0.04 16 5 2.91 Shallow Pitting. Lt. Deposits. ■ 60 1891 0 0.04 14 6 2.91 Shallow Line of Pits. Lt. Deposits. ■ 61 1921 0 0.04 17 6 2.87 Shallow Line of Pits. Lt. Deposits. ■ 62 1952 0.03 0.03 12 5 2.91 Shallow Pitting. Lt. Deposits. • I 63 1983 0 0.04 16 6 2.91 Shallow Line of Pits. Lt. Deposits. • 64 2013 0 0.04 16 7 2.96 Shallow Pitting i 65 2044 0 0.05 19 7 2.90 Shallow Line of Pits. Lt. Deposits. 1 66 2075 0 0.03 11 2 2.93 Lt. Deposits. • 67 2105 0 0.04 16 5 2.92 Shallow Line of Pits. Lt. Deposits. • I 68 2136 0.03 0.04 14 7 2.93 Shallow Pitting. Lt. Deposits. i 69 2166 0 0.04 14 4 2.87 Shallow Pitting. Lt. Deposits. ■ 70 2197 0 0.04 18 6 2.92 Shallow Pitting. Lt. Deposits. 1 71 2228 0.04 0.04 16 6 2.92 Shallow Line of Pits. Lt. Deposits. • I 72 2258 0 0.05 19 9 2.92 Shallow Pitting. Lt. Deposits. i 73 2289 0 0.04 14 6 2.92 Shallow Line of Pits. Lt. Deposits. • ■ 74 2320 0 0.04 14 5 2.86 Shallow Line of Pits. Lt. Deposits. 75 2351 0 0.02 9 1 2.90 Lt. Deposits. I 76 2381 0 0.04 16 7 2.90 Shallow Pitting. Lt. Deposits. i 77 2412 0.04 0.04 17 6 2.96 Shallow Pitting. 1 78 2442 0 0.04 18 7 2.91 Shallow Pitting. Lt. Deposits. 1 79 2473 0.03 0.04 17 6 2.96 Shallow Line of Pits. • I 80 2503 0 0.04 16 4 2.89 Shallow Line of Pits. Lt. Deposits. 81 2534 0 0.02 9 0 2.89 Lt. Deposits. 82 2565 0 0.04 14 4 2.91 Shallow Pitting. Lt. Deposits. • 83 2595 0 0.04 14 5 2.93 Shallow Line of Pits. Lt. Deposits. • 84 2626 0 0.03 12 5 2.87 Shallow Pitting. Lt. Deposits. ■ I 85 2657 0 0.04 17 8 2.93 Shallow Pitting. Lt. Deposits. i 86 2687 0 0.04 17 6 2.90 Shallow Pitting. Lt. Deposits. • 1 87 2717 0 0.04 17 7 2.96 Shallow Pitting. 88 2747 0.03 0.04 14 6 2.92 Shallow Line of Pits. Lt. Deposits. ■ I 89 2778 0.03 0.04 17 6 2.91 Shallow Pitting. Lt. Deposits. 90 2808 0.03 0.04 14 6 2.91 Shallow Pitting. Lt. Deposits. 90.1 2838 0 0 0 0 2.92 GLM 1 (Latch @ 5:30) i 91 2846 0.04 0.04 14 6 2.96 Shallow Pitting. 1 92 2873 0 0.05 19 8 2.91 Shallow Pitting. Lt. Deposits. 1 I 93 2904 0.04 0.04 17 5 2.91 Shallow Pitting. Lt. Deposits. • 94 2934 0.03 0.04 16 7 2.91 Shallow Pitting. Lt. Deposits. 'Penetration Body I Metal Loss Body Page 2 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf J -55 EUE MOD Well: 3G -22 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc Nominal I.D.: 2.992 in. Country: USA Survey Date: July 31, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 95 2964 0.03 0.04 16 5 2.94 Shallow Pitting. • 96 2994 0.03 0.04 16 6 2.90 Shallow Pitting. Lt. Deposits. ■ 97 3025 0.04 0.04 16 6 2.96 Shallow Pitting • 98 3054 0 0.04 17 8 2.92 Shallow Pitting. Lt. Deposits. r 99 3084 0.04 0.04 18 7 2.96 Shallow Pitting. 1 I 100 3115 0.04 0.04 17 7 2.94 Shallow Pitting. 101 3144 0.04 0.05 19 9 2.96 Shallow Pitting. i 102 3174 0.04 0.04 16 7 2.94 Shallow Pitting. r 103 3202 0 0.04 17 6 2.91 Shallow Pitting. Lt. Deposits. 1 I 104 3231 0.04 0.04 18 6 2.91 Shallow Line of Pits. Lt. Deposits. ■ 105 3261 0 0.04 18 6 2.90 Shallow Pitting. Lt. Deposits. ■ 106 3291 0.05 0.04 17 8 2.96 Shallow Pitting. 1 107 3321 0.03 0.04 16 6 2.93 Shallow Pitting. ■ I 108 3350 0.04 0.04 14 5 2.92 Shallow Pitting. Lt. Deposits. • 109 3381 0.03 0.04 17 6 2.94 Shallow Pitting. ■ 110 3410 0 0.04 14 6 2.95 Shallow Line of Pits. • 111 3439 0.04 0.05 19 6 2.93 Shallow Pitting. • 112 3468 0 0.04 18 7 2.91 Shallow Pitting. I. t. Deposits. r I 113 3497 0.04 0.04 16 6 2.91 Shallow Pitting. Lt. Deposits. ■ 114 3526 0 0.04 16 6 2.94 Shallow Pitting. ■ 115 3555 0.0:3 0.04 14 4 2.94 Shallow Pitting. ■ 116 3584 0 0.04 16 5 2.92 Shallow Pitting. Lt. Deposits. ■ I 117 3612 . 0 0.05 19 7 2.89 Shallow Pitting. Lt. Deposits. r 118 3643 0 0.05 19 6 2.92 Shallow Pitting. Lt. Deposits. ■ 119 3673 0.04 0.04 16 7 2.90 Shallow Pitting. Lt. Deposits. 1 120 3700 0 0.04 16 6 2.91 Shallow Pitting. Lt. Deposits. ■ 1 121 3729 0 0.04 16 6 2.92 Shallow Pitting. Lt. Deposits. ■ 122 3756 0.03 0.04 17 6 2.89 Shallow Pitting. Lt. Deposits. 123 3787 0.04 0.04 17 6 2.95 Shallow Pitting. ■ 124 3818 0.04 0.05 19 8 2.96 Shallow Pitting. r I 125 3848 0.03 0.04 17 7 2.91 Shallow Pitting. Lt. Deposits. ■ 126 3878 0.04 0.04 16 5 2.91 Shallow Pitting. Lt. Deposits. • 127 3908 0.03 0.04 17 7 2.94 Shallow Pitting. r 128 3939 0.04 0.04 16 5 2.95 Shallow Line of Pits. • 129 3970 0.03 0.04 16 5 2.91 Shallow Pitting. Lt. Deposits. ■ I 130 4001 0.05 0.04 16 6 2.94 Shallow Line of Pits. ■ 131 4030 0 0.04 16 7 2.90 Shallow Pitting. Lt. Deposits. a 132 4062 0.03 0.04 16 6 2.96 Shallow Pitting. 1 133 4092 0 0.04 16 6 2.94 Shallow Line of Pits. • I 134 4123 0 0.04 16 6 2.91 Shallow Pitting. Lt. Deposits. • 135 4152 0.04 0.04 17 6 2.96 Shallow Pitting. ■ 136 4183 0 0.04 18 7 2.92 Shallow Pitting. Lt. Deposits. ■ 137 4213 0 0.04 17 4 2.92 Shallow Pitting. Lt. Deposits. ■ I 138 4243 0.03 0.04 14 5 2.90 Shallow Line of Pits. Lt. Deposits. • 139 4275 0.03 0.04 18 7 2.96 Shallow Pitting. 140 4304 0.04 0.04 16 6 2.95 Shallow Pitting. 1 141 4335 0 0.04 16 6 2.90 Shallow Pitting. Lt. Deposits. ■ 142 4365 0 0.05 19 6 2.91 Shallow Pitting. Lt. Deposits. ■ I 143 4396 0.03 0.04 16 6 2.95 Shallow Pitting. ■ 144 4426 0 0.04 14 5 2.92 Shallow Line of Pits. Lt. Deposits. Penetration Body I 4' Metal Loss Body Page 3 1 1 1 • . PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf J -55 EUE MOD Well: 3G -22 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc Nominal I.D.: 2.992 in. Country: USA Survey Date: July 31, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 145 4457 (1 0.04 18 6 2.96 Shallow Pitting. ■ 146 4488 0.04 0.04 16 6 2.95 Shallow Line of Pits. 147 4518 0.04 0.04 16 6 2.94 Shallow Pitting. ■ 148 4550 0.04 0.05 19 7 2.96 Shallow Pitting. r 149 4579 0 0.04 14 4 2.88 Shallow Line of Pits. Lt. Deposits. ■ I 150 4610 0.03 0.04 16 5 2.94 Shallow Pitting. ■ 151 4640 0 0.04 14 4 2.90 Shallow Pitting. Lt. Deposits. ■ 152 4672 0 0.03 12 4 2.88 Shallow Line of Pits. Lt. Deposits. ■ 153 4703 0.03 0.04 14 4 2.95 Shallow Line of Pits. ■ I 154 4732 0 0.04 16 6 2.90 Shallow Line of Pits. Lt. Deposits. ■ 155 4764 0.03 0.04 14 5 2.95 Shallow Pitting. ■ 156 4794 0 0.05 19 7 2.94 Shallow Pitting. r 157 4824 0.03 0.05 21 7 2.95 Isolated Pitting. r I 158 4855 0 0.04 16 , 5 2.95 Shallow Line of Pits. ■ 159 4885 0 0.04 14 4 2.89 Shallow Pitting. Lt. Deposits. ■ 160 4917 0 0.04 18 6 2.92 Shallow Pitting. Lt. Deposits. ■ 161 4947 0 0.04 14 4 2.89 Shallow Line of Pits. Lt. Deposits. • 162 4977 0.03 0.04 18 6 2.94 Shallow Pitting. ■ I 163 5008 0 0.04 16 6 2.92 Shallow Line of Pits. Lt. Deposits. ■ 164 5040 0.04 0.04 18 7 2.92 Shallow Pitting. Lt. Deposits. II 165 5070 0.04 0.03 12 3 2.91 Shallow Pitting. Lt. Deposits. • 166 5100 0.04 0.06 23 7 2.90 Isolated Pitting. Lt. Deposits. r I 167 5131 0.03 0.04 17 7 2.92 Shallow Pitting. Lt. Deposits. 168 5162 0 0.04 14 5 2.89 Shallow Pitting. Lt. Deposits. ■ 169 5192 0 0.05 19 8 2.95 Shallow Pitting. 1 170 5222 0 0.05 19 5 2.90 Shallow Pitting. Lt. Deposits. ■ I 171 5253 , 0 0.04 16 6 2.89 Shallow Pitting. Lt. Deposits. ■ 172 5283 0.04 0.04 18 7 2.90 Shallow Pitting. Lt. Deposits. 172.1 5314 0 0 0 0 2.91 GLM 2 (Latch @ 9:30) i 173 5322 0.03 0.04 14 4 2.93 Shallow Line of Pits. ■ I 174 5351 0 0.05 19 7 2.91 Shallow Pitting. Lt. Deposits. r 175 5382 0.03 0.04 17 7 2.90 Shallow Pitting. Lt. Deposits. 176 5413 0 0.04 18 6 2.91 Shallow Pitting. Lt. Deposits. ■ 177 5443 0 0.04 18 7 2.90 Shallow Pitting. Lt. Deposits. r 178 5474 0 0.03 12 4 2.90 Shallow Pitting. Lt. Deposits. • I 179 5505 0.04 0.04 17 6 2.92 Shallow Pitting. Lt. Deposits. ■ 180 5535 0 0.04 16 6 2.92 Shallow Pitting. Lt. Deposits. ■ 181 5566 0.04 0.04 17 7 2.92 Shallow Pitting. Lt. Deposits. ■ 182 5596 0.03 0.04 14 2 2.93 Shallow Pitting. Lt. Deposits. ■ I 183 5626 0.03 0.04 16 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ 184 5655 0 0.04 16 5 2.92 Shallow Pitting. Lt. Deposits. ■ 185 5684 0 0.04 17 6 2.92 Shallow Line of Pits. Lt. Deposits. ■ 186 5713 0 0.04 14 5 2.90 Shallow Line of Pits. Lt. Deposits. ■ I 187 5743 0 0.04 16 5 2.92 Shallow Line of Pits. Lt. Deposits. ■ 188 5773 0 0.05 19 8 2.89 Shallow Pitting. Lt. Deposits. 189 5805 0 0.04 17 4 2.87 Shallow Line of Pits. Lt. Deposits. ■ 190 5835 0 0.04 16 4 2.91 Shallow Line of Pits. Lt. Deposits. • 191 5865 0 0.04 16 4 2.88 Shallow Pitting. Lt. Deposits. • I 192 5896 0 0.04 14 4 2.88 Shallow Line of Pits. Lt. Deposits. • 193 5926 0.03 0.03 12 4 2.90 Shallow Line of Pits. Lt. Deposits. I Penetration Body I Metal Loss Body Page 4 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf J -55 EUE MOD Well: 3G-22 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc Nominal I.D.: 2.992 in. Country: USA Survey Date: July 31, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 194 5956 0.03 0.04 17 5 2.92 Shallow Pitting. Lt. Deposits. ■ 195 5986 0 0.04 17 4 2.91 Shallow Pitting. Lt. Deposits. ■ 196 6016 0 0.03 11 2 2.92 Lt. Deposits. 197 6045 0 0.04 14 4 2.88 Shallow Line of Pits. Lt. Deposits. • 198 6077 0 0.04 17 4 2.88 Shallow Pitting. Lt. Deposits. ■ I 199 6107 0 0.04 14 3 2.90 Shallow Line of Pits. Lt. Deposits. • 200 6137 0 0.04 18 4 2.89 Shallow Pitting. Lt. Deposits. ■ 201 6168 0 0.04 16 3 2.92 Shallow Pitting. Lt. Deposits. • 202 6196 0 0.04 16 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ I 203 6226 0 0.04 14 4 2.88 Shallow Line of Pits. Lt. Deposits. ■ 204 6257 0 0.04 16 6 2.88 Shallow Pitting. Lt. Deposits. ■ 205 6287 0 0.04 16 3 2.92 Shallow Line of Pits. Lt. Deposits. ■ 206 6317 0.03 0.04 16 6 2.90 Shallow Line of Pits. Lt. Deposits. ■ I 207 6349 0 0.04 14 4 2.90 Shallow Line of Pits. Lt. Deposits. • 208 6379 0.04 0.05 19 7 2.91 Shallow Pitting. Lt. Deposits. i 209 6408 0 0.03 11 2 2.91 Lt. Deposits. 209.1 6436 0 0 0 0 2.84 GLM 3 (Latch @ 11:30) I 210 6445 0 0.04 16 3 2.88 Shallow Pitting. Lt. Deposits. ■ I 211 6474 0 0.04 16 6 2.90 Shallow Pitting. Lt. Deposits. • 212 6504 0 0.03 11 3 2.88 Lt. Deposits. ■ 213 6535 0 0.05 19 6 2.88 Shallow Pitting. Lt. Deposits. • 214 6566 0 0.03 12 2 2.88 Shallow Pitting. Lt. Deposits. ■ I 215 6595 0.04 0.04 14 5 2.89 Shallow Line of Pits. Lt. Deposits. ■ 216 6627 0 0.03 11 2 2.88 Lt. Deposits. ■ 217 6658 0.04 0.05 19 8 2.94 Shallow Pitting. 1 218 6687 0.06 0.03 12 3 2.88 Shallow Line of Pits. Lt. Deposits. ■ I 219 6717 0 0.03 12 3 2.88 Shallow Line of Pits. Lt. Deposits. • 220 6747 0 0.03 10 2 2.89 Lt. Deposits. ■ 221 6777 0 0.04 16 5 2.88 Shallow Pitting. Lt. Deposits. ■ 222 6808 0 0.04 14 4 2.90 Shallow Pitting. Lt. Deposits. • I 223 6837 0.03 0.04 14 4 2.87 Shallow Line of Pits. Lt. Deposits. • 224 6867 0 0.03 12 3 2.91 Shallow Pitting. Lt. Deposits. • 225 6897 , 0 0.05 19 6 2.89 Shallow Pitting. Lt. Deposits. ■ 226 6928 0 0.04 14 4 2.91 Shallow Line of Pits. Lt. Deposits. • 227 6956 0 0.04 14 2 2.90 Shallow Pitting. Lt. Deposits. ■ I 228 6987 0 0.04 16 4 2.87 Shallow Pitting. Lt. Deposits. • 229 7018 0 0.03 12 3 2.88 Shallow Line of Pits. Lt. Deposits. ■ 230 7049 0.04 0.04 16 4 2.92 Shallow Pitting. Lt. Deposits. • 231 7079 0 0.03 11 3 2.88 Lt. Deposits. • I 232 7109 0 0.04 16 4 2.89 Shallow Line of Pits. Lt. Deposits. • 233 7140 0 0.03 11 .3 2.90 Lt. Deposits. ■ 234 7171 0 0.04 14 4 2.92 Shallow Line of Pits. Lt. Deposits. • 235 7201 0 0.04 14 2 2.90 Shallow Pitting. Lt. Deposits. • 1 236 7232 0.04 0.03 12 3 2.92 Shallow Line of Pits. Lt. Deposits. • 237 7263 0.04 0.04 16 3 2.88 Shallow Line of Pits. Lt. Deposits. • 238 7293 0 0.04 16 2 2.92 Shallow Line of Pits. Lt. Deposits. • 239 7324 0 0.04 16 5 2.90 Shallow Pitting. Lt. Deposits. • 240 7355 0 0.04 16 5 2.90 Shallow Line of Pits. Lt. Deposits. ■ I 241 7385 0.04 0.03 12 4 2.88 Shallow Pitting. Lt. Deposits. • 242 7415 0 0.04 16 6 2.92 Shallow Line of Pits. Lt. Deposits. I Penetration Body I Metal Loss Body I Page s 1 11 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf J -55 EUE MOD Well: 3G -22 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc I Nominal I.D.: 2.992 in. Country: USA Survey Date: July 31, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 243 7445 0 0.04 14 3 2.87 Shallow Line of Pits. Lt. Deposits. ■ 244 7477 0 0.04 16 4 2.87 Shallow Line of Pits. Lt. Deposits. • ■ 245 7508 0 0.04 16 5 2.91 Shallow Line of Pits. Lt. Deposits. 245.1 7539 0 0 0 0 2.81 GLM 4 (Latch @ 1:00) 246 7546 0 0.03 11 1 2.89 Lt. Deposits. ■ I 247 7575 0 0.04 14 4 2.90 Shallow Line of Pits. Lt. Deposits. Ni 248 7605 0 0.03 12 2 2.84 Shallow Pitting. Lt. Deposits. 249 7635 0 0.03 12 2 2.86 Shallow Pitting. Lt. Deposits. 250 7667 0 0.04 16 , 4 2.88 Shallow Line of Pits. Lt. Deposits. • I 251 7697 0 0.03 12 2.88 Shallow Pitting. Lt. Deposits. 252 7727 0 0.04 14 3 2.88 Shallow Line of Pits. Lt. Deposits. ■ 253 7759 0 0.05 19 5 2.90 Shallow Pitting. Lt. Deposits. ■ 254 7789 0 0.04 16 5 2.93 Shallow Pitting. Lt. Deposits. ■ I 255 7819 0 0.05 19 7 2.88 Shallow Pitting. Lt. Deposits. i 256 7849 0 0.05 19 4 2.89 Shallow Pitting. Lt. Deposits. ■ 257 7879 0.03 0.04 17 4 2.90 Shallow Pitting. Lt. Deposits. ■ 258 7909 0 0.03 11 1 2.90 Lt. Deposits. 259 7941 0 0.04 16 3 2.87 Shallow Line of Pits. I. t. Deposits. ■ I 260 7972 0 0.03 11 2 2.88 Lt. Deposits. 261 8002 0 0.04 16 5 2.88 Shallow Line of Pits. Lt. Deposits. ■ 262 8032 0 0.03 12 4 2.92 Shallow Pitting. Lt. Deposits. ■ 263 8063 0 0.04 18 5 2.92 Shallow Pitting. Lt. Deposits. ■ I 264 8094 0 0.03 12 2 2.88 Shallow Pitting. Lt. Deposits. 265 8125 0.04 0.03 12 2 2.88 Shallow Line of Pits. Lt. Deposits. 266 8155 0 0.04 18 1 2.91 Shallow Line of Pits. Lt. Deposits. 267 8185 0 0.03 12 2 2.88 Shallow Pitting. Lt. Deposits. I 268 8215 0.04 0.04 18 6 2.93 Shallow Pitting. Lt. Deposits. ■ 269 8247 0 0.04 14 3 2.91 Shallow Line of Pits. Lt. Deposits. 270 8276 0 0.04 16 2 2.88 Shallow Line of Pits. Lt. Deposits. 271 8308 0 0.04 14 3 2.90 Shallow Pitting. Lt. Deposits. • I 272 8338 0 0.03 11 2 2.92 Lt. Deposits. 273 8367 0 0.03 12 2 2.87 Shallow Pitting. Lt. Deposits. 274 8397 0 0.04 16 3 2.90 Shallow Line of Pits. Lt. Deposits. 275 8429 0 0.02 7 1 2.88 Lt. Deposits. 276 8460 0 0.04 18 3 2.92 Shallow Pitting. Lt. Deposits. ■ I 277 8489 0 0.03 11 1 2.91 Lt. Deposits. 278 8518 0 0.04 16 3 2.89 Shallow Line of Pits. Lt. Deposits. 278.1 8548 0 0 0 0 2.85 GLM 5 (Latch @ 1:30) 279 8556 0 0.04 14 4 2.91 Shallow Line of Pits. Lt. Deposits. ■ I 280 8583 0 0.03 12 2 2.89 Shallow Line of Pits. Lt. Deposits. 281 8614 0 0.03 12 2 2.88 Shallow Line of Pits. Lt. Deposits. 282 8644 0 0.03 12 2 2.92 Shallow Pitting. Lt. Deposits. 283 8674 0 0.03 11 2 2.89 Lt. Deposits. I 284 8704 0 0.03 12 3 2.88 Shallow Pitting. Lt. Deposits. 285 8735 0 0.04 14 3 2.88 Shallow Line of Pits. Lt. Deposits. 286 8765 0 0.03 11 1 2.88 Lt. Deposits. NI 287 8798 0.0:1 0.04 14 4 2.88 Shallow Pitting. 1.1 Deposits. • 288 8828 0 0.04 14 4 2.88 Shallow Pitting. Lt. Deposits. • I 289 8857 0 0.03 11 2 2.89 Lt. Deposits. 290 8886 0 0.04 14 2 2.88 Shallow Line of Pits. Lt. Deposits. Penetrati Body I Metal Loss on Body Page 6 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf J -55 EUE MOD Well: 3G -22 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in_ Company: ConocoPhillips Alaska, Inc Nominal ID.: 2.992 in. Country: USA Survey Date: July 31, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss LD• Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 291 8918 0 03 0.04 14 3 2.90 Shallow Line of Pits. Lt. Deposits. C 292 8949 0 0.04 14 2 2.91 Shallow Line of Pits. Lt. Deposits. 293 8979 0 0.04 16 1 2.89 Shallow Line of Pits. Lt. Deposits. No 294 9009 0 0.04 18 5 2.87 Shallow Pitting. Lt. Deposits. r 295 9040 0 0.03 11 2 2.91 Lt. Deposits. I 296 9070 0 0.04 14 4 2.91 Shallow Line of Pits. Lt. Deposits. 297 9100 0 0.04 16 4 2.92 Shallow Pitting. Lt. Deposits. 298 9131 0 0.02 7 1 2.88 Lt. Deposits. 299 9161 0 0.02 9 0 2.84 Lt. Deposits. • I 299.1 9192 0 0.00 2 0 2.86 Pup Lt. Deposits. 299.2 9200 1) 0 0 0 2.85 GLM 6 (Latch @ 10:00) 299.3 9209 0 0.03 10 0 2.75 Pup Deposits. • 300 9215 0 0.02 9 0 2.83 Lt. Deposits. • I 300.1 9247 0 0 0 0 2.80 Baker 10' PBR 300.2 9260 0 0 0 0 2.76 Baker 'HB' Retrievable Packer 300.3 9268 0 0 0 0 2.85 Pup Lt. Deposits. 300.4 9282 0 0 0 0 2.66 Camco DN Nipple 300.5 9284 0 0.02 7 0 2.89 Pup Lt. Deposits. 1 I 300.6 9300 0 0 0 0 2.87 3.5" Tubing Tail _ I Penetration Body Metal Loss Body 1 1 1 1 1 1 1 1 Page 7 1 1 1 • • 1 PDS Report Cross Sections I s Well: 3G -22 Survey Date: July 31, 2011 Field: Kuparuk Tool Type: UW MFC XR 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 in. 9.3 ppf J -55 FLEE MOD Analyst: C. Waldrop 1 1 Cross Section for Joint 166 at depth 5118.140 ft Tool speed = 54 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 93% — — Tool deviation = 58° /...--- \ 1 1 I/ \ 1 i \ 1 -- 1 N �� \ . 1 I Finger = 13 Penetration = 0.058 in. Isolated Pitting 0.06 ins = 23% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 3G -22 Kuparuk Survey Date: July 31, 2011 Field: Tool Type: UW MFC XR 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 in. 9.3 ppf J -55 EUE MOD Analyst: C. Waldrop 1 I Cross Section for Joint 157 at depth 4829.700 ft Tool speed = 55 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 93% i- 1 """N` Tool deviation = 58° I • 1 1 i ___- , 1 I \ 1 I Finger = 18 Penetration = 0.053 in. Isolated Pitting 0.05 ins = 21% Wall Penetration HIGH SIDE = UP 1 1 1 I 1 , I A , KUP 3G -22 COt10Co'tii!ip5 Attributes Angle &MD TD Alaska. IK; � We APIIVWI Fiala No Well Status proMnj Type Intl ( ") MD (ro(B) Act Btm (rote) cnrwmkdigs 501032014700 KUPARUK RIVER UNIT PRODUCING 61.02 3 500 9,782 ' Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date well coafi9. - 3G -zz 3(7 /3009 rsn - os 70 SSSV: TRDP 95 1/12009 Last WO: 37.11 10/30/1990 Schematic - Actual Annotation Depth )8 B) End Date Ann otation (Last Mod By End Date Last Tag CTM 9,600 3/5/2009 Rev Reason: UPDATE FISH RECORD � triplwj 3/72009 Casing Strings - -. - String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (In) (m) Top HUM) (DKB) (IIKB) (Ibsm) Grade string Top Thrd CONDUCTOR 16 15062 37 115 115.0 62.58 +40 I SURFACE 95/8 8.765 0 4,042 2,947.1 36.001 -55 " " PRODUCTION 7 6.151 0 9,764 6,075.9 26.001 -55 CONDUCTOR I i 115 Tubing Strings ' String OD string ID Set Depth Set Depth )TVD) String Wt String SAFETY VLV. : Tubing Description (in) (In) Top (ro(e) MKB) /RIM) (IbsIR) Grade String Top ' Thrtl i eel\ p TUBING 3 12 2.992 0 9,299 5,820 9.30 - 55 UE MOD SLEEVE -C. \ " I ' 1.807 Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth (TVD) Top Intl Top (1IKB) (KB) 1') Description Gemmed Run Date D (ti) I ASLI 1,807 1,709.7 41.57 SAFETY VLV Otis'FMX' Series 10 1/5/1991 2.813 RT, z 826 p 1,807 1,709.7 41.57 SLEEVE-C FRAC SLEEVE' FISH "(14'2" OAL) last Attempt 6 /62007 7 2/1996 2.310 2,806 2,300.4 48.93 GAS LIFT McMURRAY/FMHO /1 /GLVBK/.156 /1280 /Comment:STA 1 3/16/2007 2.867 I 5,293 3,605.4 57.99 GAS LIFT McMURRAY/FMHO /1/DMYBK/ // Comment: STA 2 3/16/2007 2.867 SURFACE. 4.092 6,420 4,201.8 57.89 GAS LIFT McMURRAY/ FMHO /1 /GLVBK/.156/1285/Canment:STA 3 3/162007 2.867 7,527 4,7900 55.90 GAS LIFT MCMURRAY/FMHO /1/DMY/BK/// Content: STA 4 3/16/2007 2.867 8,543 5,379.3 54.30 GAS LIFT McMURRAY /FMHO /1/DMYBK/ / /Canxnent STA 5 1/52005 2.867 GAS LIFT, 9,199 5,761-9 5473 GAS LIFT MACCO/SPM- 2/1.5 /OV/RK/.25/ /Canment: STA6 3/152007 2.867 9,246 5,788.8 54.49 PBR Baker 10' stroke 1/5/1991 3.000 I 9,260 5,797.0 54.57 PACKER Beker'HB' Retr. d 1/5/1991 2.850 r r� 9,281 5,809.2 54.68 NIPPLE Camco' Nipple NO GO 7/5/1991 2.750 7,6;',1 err ,�i 9,298 5,819.0 54.77 SOS Baker 1/5/1991 2.992 s nzo lJ 9,299 5,819.6 54.77 TTL 1/5/1991 2.992 c 9,561 5,967.3 57.66 FISH 1.5" OV Dropped valve into rathole while attempting to set a 10/17/1999 0.000 t GAS urr GLM at GLM #6 on 10/17188 7 sn 1 1 . 9,643 6,011.2 57.66 FISH 1" GLV Found Empty Pocket @ GLM #4; Fell to Rathde 10/11/1996 0.000 Perforations &Slots 51.01 Top (TVD) Btrn (TVD) Dens Top (WOB) Wm OM (MB) OMB) zone Date (s ..• Type comment GAS LIFT, 9.376 9,426 5,863.8 5,891.5 C-4, A-3, 3G-22 3/10/1991 4.0 APERF 180 deg. phasing; 2 12" Titan 8 543 9.426 9,462 5,891.5 5,912.3 A-2, 3G-22 1/4/1991 4.0 PERF 180 deg. phasing; HLS 4 12" Csg Sun CASUFT 9,199 II i PBR. 9 PACKER.9260 A" I I NIPPLE 9 281 SOS, 9,298 TTL. 9.299 ` AEERF. 9.376-9426 7. IPERF. 9,4259,462 � FISH, 9,561 is', i FISH. 9.643 i 1 PRODUCTION. 9,760 TD, 8,782 1 Conoco~illips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seaniount: ~~'~~ APR Q 5'2010 -~~aska qi~ &GasCc~s.Co~n~~~on ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, t'op of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/31/10 3A_ 3B_ 3C_ 3G_ 3H_ 31.31.3M_ 3A R 3R POrf's ell Name PI # TD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date -~ - -•~ Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 50029214310000 1852050 Surface Na 26" n/a 4.25 3/29/2010 3A-04 50029214330000 1852070 SF Na 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3/29/2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3/29/2010 3B-10 50029213660000 1851140 6'6" n/a 6'6" n/a 25.5 3/28/2010 3C-11 50029213570000 1851020 SF n/a 25" n/a 4.25 3/27/2010 3G-08 50103201280000 1900650 SF 0.65 27" 3/2/10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/28/2010 3G-22 50103201470000 1901420 SF Na 22" Na 4.25 3/28/2010 3H-01 50103200840000 1871100 SF Na 21" n/a 4.25 3/28/2010 3H-03 50103200850000. 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-14B 50103200920200 2050210 SF n/a 23" n/a 3.4 3/29/2010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3/29/2010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3/29/2010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/28/2010 3J-15 50029214970000 1852890 SF n/a 22" n/a 3.4 3/28/2010 3M-05 50029217060000 1870250 SF n/a 21" Na 3.4 3/29/2010 3M-07 50029217080000 1870270 SF nia 22" n/a 4.25 3/29/2010 30-09 50029218250000 1880610 SF n/a 23" n/a 4.25 3/27/2010 30-16A 50029217960100 1880430 SF Na 22" Na 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF Na 17" n/a 3.25 3/27/2010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" Na 5.52 3/27/2010 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M E E L E W A T E R IA L U N D ER TH IS M ARK ER STATE OF ALASKA AI_~SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 220' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1220' FNL, 700' FEL, Sec. 27, T12N, R8E, UM At effective depth 1366' FSL, 913' FEL, Sec. 27, T12N, RSE, UM At total depth 1417' FNL, 986' FEL, Sec. 27, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6. Datum elevation (DF or KB) RKB 90 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-22 9. Permit number/approval number 90-142 10. APl number 50-103-20147-00 11. Field/Pool Kuparuk River Field/Oil Pool 9782 feet Plugs (measured) None 61 03 feet 9678 feet Junk (measured) None 6030 feet ORIGINAL Casing Length Structural Conductor 8 0' Surface 4 0 0 7' Intermediate Production 9729' Liner Perforation depth: measured 9376'-9462' true vertical 5863'-5912' Size Cemented Measured depth True vertical depth 1 6" 216 Sx AS I 1 15' 1 15' 9-5/8" 950 Sx AS III & 4042' 2941' 550 Sx Class G 7" 200 Sx Class G 91 4 0' 6 0 9 3' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 9299' Packers and SSSV (type and measured depth) PKR: Baker HB @ 9260'; SSSV: Otis FMX @ 1807' RECEIVED .MAR 2 0 19,3 13. Stimulation or cement squeeze summary Alaska011 &Gas Cons. Commission Fracture stimulate well on 6/10/96 Intervals treated (measured) Anchorage 9376'-9462' Treatment description including volumes used and final pressure Pumped 88.1 Mlbs of 20/40 and12/18 ceramic proppant into formation, fp was 6800 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 4 4 5 6 9 0 210 971 173 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 2063 1319 369 975 149 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/J~¢¢/'.-~~1~ Title Wells Superintendent Form ,1~-~'0~ ~{e~ E6:~/88 ( Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,4~. WELL SERVICE REPORT '~' K1 (3G-22(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-22 FRAC,' FRAC SUPPORT 0607962122.11 DATE DAILY WORK UNIT NUMBER 06/10/96 'A' SAND REFRAC , DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I {~) Yes ~ NoI (~) Yes (~ No DS-GALLEGOS PEI~R~E .,~ ESTIMATE KM1318 230DS36GL $1 1 2,035 $118,607 r Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann ~ Initial Outer Ann nn 1 135 PSI 0 PSI 250 PSI 500 P. SII 0 PSII 450 PSI DALLY SUMMARY I REFRAC'D 'A' SAND - SCREENED OUT EARLY W/88,069 LBS PROPPANT BEHIND PIPE AND 24,491 LBS LEFT IN WELLBORE @ 10 I PPA. USED 8,187 LBS 20/40 AND 88,069 LBS 12/18 PROPPANT. TIME LOG ENTRY ' 06:30 MIRU DOWELL PUMPING EQUIP & APC SUPPORT EQUIP. QC FLUIDS. 08:30 HOLD PRE-JOB SAFETY MEETING, PRIME UP PUMPING EQUIPMENT, PRESSURE TEST LINES AND EQUIP TO .8,500 PSI. PRESSURE 7" ANNULUS TO 3,000 PSI 09:15 START PUMPING CONDITIONING STAGE. 09:30 FINISH CONDITIONING STAGE, S/D. FFP = 4,065 PSI, ISIP = 2,120 PSI. CONDUCT PULSE TESTING. 10:20 FINISH PULSE TESTING, FSIP = 1,035 PSI. START PUMPING DATAFRAC. 10:45 FINISH DATAFRAC, S/D. FFP = 3,6.30 PSI, ISIP = 1,900 PSI. MONITOR PRESSURES. 11:40 FINISH MONITORING POST-DATAFRAC PRESSURES, FSIP = 925 PSI. START PUMPING PAD. 12:25 FINISH PUMPING PAD, START 20/40 PROPPANT @ 2 PPA. 12:30 , SWITCH TO 12/18 PROPPANT @ 2 PPA, RAMP UP TO 10 PPA, THEN PLATEAU @ 10 PPA. 13:05 13:10 16:00 SCREEN-OUT, S/D W/TBG PRESSURE @ 6,800 PSI. 88,069 LBS OF PROPPANT BEHIND PIPE AND 24,491 LBS LEFT IN WELLBORE @ 10 PPA FROM SURFACE TO PERFS. CLEAR PUMPS AND LINES, RDMO DOWELL AND APO. .WELL SECURED AND EVERYBODY OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $51o.oo . .APO . $4,473.00 $7,088.00 ARCO $1,860.00 $1,860.00 DOWELL $105,702.00 $105,702.00 HALLI BURTON $0.00 $3,447.00 TOTAL FIELD ESTIMATE $1 12,035.00 $1 18,607.00 ALAbKA OIL AND GAS CONSERVATION COMMIbo~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed' Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 2538' FNL, 220' FEL, Sec. 23, T12N, At top of productive interval 1220' FNL, 700' FEL, Sec. 27, T12N, At effective depth 1366' FSL, 913' FEL, Sec. 27, T12N, At total depth 1417' FNL, 986' FEL, Sec. 27, T12N, R8E, UM R8E, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured 9782' true vertical 61 03' feet feet Plugs (measured) Plugging Perforate _ Other 6, Datum elevation (DF or KB) 90' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-22 9. Permit number/approval number 90-142 10. APl number ,~Q-103-20147 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9678' true vertical 6030' feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Prod uction Liner Perforation depth: Length Size 80' 16" 4007' 9 5/8" 9729' 7" measured 9376'-9462' true vertical 5863'-5912' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, EUE, ABMOD, IPC, 9299' Packers and SSSV (type and measured depth) SSSV: Cemented 216 Sx AS I 950 Sx AS III & 550 Sx Class G 200 Sx Class G Otis FMX, 1807', Packer: Baker HB, 9260' Measured depth 115' 4042' 9764' True vertical depth 115' 2941 ' 6093' 13. Stimulation or cement squeeze summary ,-.¢,,,,:i,-': ' Hydraulic Fracture Treatment .,.:... Intervals treated (measured) ' 9376' - 9462' Treatment description including volumes used and final pressure Gelled water fracture: 1952 bbls water and 72M# of ceramic proppant. WHTP=5350 14. Represeotatiye Daily Average PrgCuctign or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure Tubing Prior to well operation Subsecluent to operation -0- "0 -0- 500 115 990'-// ~49; 34 500 175 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned Form 10-404 Rev 09/12/90 * Refer to attachment describing testing method. Date SUBMIT IN DUPLICATE TEL N0:9076597739 ~384 PS1 FRAC/$TIMULATION SUMMARY WELL NO' 36'~- AFE: AK H?- DATE: Procedure Date' (~-[[-~[ Begin Frac: Service Co. l~:~3 ~z...~ c~ (~/~d g r--Z~ Zone: Annulus Press' ~~ Te~t Lines To: STAGE VOL FLU I D PROP RATE PRESSURE ISIP: . .{ mm~ ~ [ , 1 5 Min: Avg Press: psi Fluid to Recover: (c~ ~%_ Sand In Zone: ~__, ~ ~ ~-- Sand In Csg: .. 1~, ~'~'"~' ! Job Complete' ADC: TA lm4b !'31A, A / 1 fl/I Rig Supe'rvisor ~ 67 · WELL 3G-22 WELL TESTING METHOD Well 3G-22 was hydraulically fractured on 6/13/91. The well was tested to tanks via temporary piping on 7/3/91 for 12 hours at an average backpressure of 175 psi. A total of 512 bbls of fluid was produced from the well during the 12 hour test period. The water cut of the fluid was determined to be 3.5%. The daily rate based on this volume was calculated to be 1024 BFPD (+990 BOPD). The gas rate of 495 MSCFPD was estimated using a gas oil ratio (GOR) of 500 SCF/STB, which is the average GOR of the Drill Site 3G wells currently producing. The well could not be tested through the production facilities at Drill Site 3G because the well is not currently piped up to the facilities. STATE OF ALASKA AL~,~KA OIL AND GAS CONSERVATION CC, WELL COMPLETION OR RECOMPLETION REPORT I Status of Well Classification of Service Well OIL E~] GAS [~] SUSPENDED r-~ ABAN~O E~] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-142 3 Address 8 APl Numbe¢ P.O. Box 100360,.Anchorage, AK 99510-0360 50-103-201..47 4 Location of well at surface j ................... 9 Unit or Lease Name 2538' FNL, 220' FEL, SEC 25, T12N, RSE, UM i ; ..... f: KUPARUK RIVER~ -)/~'~';~i~ i ...... --, -~ ~, 10 Well Number At Top Producing Interval ' 1079' FNL, 480'-FEL, SEC 27, T12N, R8E, UM ] ~ER]F~Ei> ~ ~ur- 3G-22 ~'~ 1296' FNL, 744' FEL, SEC 27, T12N, RSE, UM .!?': ........ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation end Serial No. KUPARUK RIVER OIL POOL RKB 90', PAD 54' GL[ ADL 25549 & ALK 2663 12 Date Spudded10/23/90. 13 Da. te T.D. Reached10/28/90. 14 Date Comp. , Susp. or Abarx:l.1/05/91. I15 water Depth' if °"sh°reNA feet MSL 116 NO' Of cOmpletiOns1 17 Total Depth (MD+'l'VD) 18 Plug Back Dep~ (MD+TVD) ;19 DirectionalSurvey 20 Dep~whereSSSVset 121 Thickness of permafrost 9782' MD, 6085' TVD 9678' MD, 5972' 'I'VD YES xL~.J No L~ 1807, feet MDI 1600' APPROX 22 Type Electric or O~er Logs Run EWR/C N/SFD/DGR/C ET/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD , SE'FrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24' 216 SX ASI 9-5/8" 36# J-55 SURF 4042' 12-1/4' 950 SX ASlII~ 550 SX CLASS G 7" 26~ J-55 SURF 9764' 8-1/2' 200 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD} PACKER SET (MD) 3-1/2' 9299' 9260' 9426'-9462' W/4-1/2' CSG GUN @ 4SPF MD 589Z-5912' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE A'I-rACHED ADDENDUM 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO ! TEST PERIOD ,e- Flow Tubing Casing Pressure CALCULATED OIL-BBI_ GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA ~'~ief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. '-:,: o:. .... , Form 10-407 Submit in duplicate Rev. 7-1-80 ~EDON REVERSE SIDE N,NVE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9374' 5882' NA ~UPARUK C BO'FI'OM 9392' 5873' <UPARUK A TOP 9392, 5873' <UPARUK A BOTTOM 9588' 5971' 31. LIST OF ATTACHMENTS ' GYRO I='¢~¢~-. ~ ~'4 ~.t~ ~4;~4~,,.1 .... 3;'. I hereby certify~that the foregoing is true and(~rrect to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod 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 ADDENDUM WELL: 5/26/91 3G-22 Frac KRU "A" sand peals from 9426'-9462' @ 4spf in 5 stages as follows: Stage 1. Stage 2 Stage 3 Stage 4 Stage 5 *Screened out w/2ppg @ Perfs Pmp 110 bbl YF 240 XL G/W @ 25 bpm 0300-6240psi Prnp 90 bbl YF 240 Non -XL G/W @ 25 bpm 6240-5420 psi ISIP: 1569 Frac Grad: .70 Ped F~:1085 Pmp 1000 bbl YF 240 XL G/W @ 25 bpm 5560-6250-5450 psi Prop 130 bbl YF 240 XL GW W/2ppg 16/20 Carb~ 25 bpm 5450-5250 psi Pmp 12 bbl YF 240 XL GW w/4ppg 16/20 Carb~ 25 bpm 5250-8600 psi 8600psi Average Pressure: Fluid to recover: Sand in zone: Sand in casing: 800 bbls 5230 #16/29 Carbolite 8640# D~nte~ ARCO ALASKA INC. DAILY OPERATIONS WELL: 3G-22 PAGE: 1 BOROUGH: FIELD: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: NORTH SLOPE KUPARUK RIVER FIELD KUPARUK RIVER UNIT ADL 25549 ALK 2663 50-103-20147 90-142 AK5342 55.252072 ACCEPT: 10/23/90 02:30 SPUD: 10/23/90 06:00 RELEASE: 10/30/90 06:00 OPERATION: DRILL RIG: DOYON 14 10/23/90 (1) TD: 115' ( 115) SUPV:JMM 10/24/90 (2) TD: 3295' (3180) SUPV:JMM 10/25/90 -(3) TD: 4100' ( 805) SUPV:JMM 10/26/90 (4) TD: 5804' (1704) SUPV:JMM 10/27/90 (5) TD: 8311' (2507) SUPV:JMM DOYON 14 TEST DIVERTER SYSTEM MW: 0.0 VIS: 0 ACCEPT RIG ON 3G-22 @ 02:30 ON 23-OCT-90, NU DIVERTER SYSTEM MU SPUD MUD, PU & MU BHA BIT #1, ORIENT, FUNCTION TEST DIVERTER DAILY:S24,149 CUM:$24,149 ETD:S24,149 EFC:$1,800,000 NAVIDRLG 12.25 HOLE 9-5/8"@ 4081' MW: 9.1 VIS: 64 SPUD @ 0600 HRS @ 115' DRILL TO 413'. ORIENT N NAVIDRILL TO 533'. PENETRATIN RATE LOW, NAVIDRILL WEAK POOH N CHANGE OUT NAVIDRILL MTR, ORIENT, RIH. DRILL 12-1/4" HOLE TO 3295'_ DAILY:S85,492 CUM:$109,641 ETD:S109,641 EFC:$1,800,000 MU 9-5/8" STARTING HEAD 9-5/8"@ 4081' MW: 0.0 VIS: 0 DRILL FROM 3295 TO 4083. MAKE WIPER TRIP, DRILL FROM 4083' TO 4100'. POOH, RAN 98 JTS OF 9-5/8", J-55, 36#, BTC CASING TO 4081'. PUMP 80 BBLS H20, 328 BBLS ASIII (950 SX) 12.1 PPG LEAD CEMENT, 113 BBLS (950 SX) CLASS G 15.8 PPG TAIL CEMENT. DISPLACE WITH 305 BBLS H20, BUMP PLUG @ 2500 PSI, FLOATS OK, CIP @ 0400 HRS. RD DIVERTER, MU 9-5/8" STARTING HEAD. DAILY:S212,029 CUM:$321,670 ETD:S321,670 EFC:$1,800,000 TURBODRLG 8-1/2" HOLE 9-5/8"@ 4081' MW: 9.6 VIS: 39 NU BOPE, TEST ALL SURF EQUIP TO 500 & 3000 PSI, INSTALL WEAR BUSHING, PU & MU BHA & ORIENT, INSTALL SOURCES IN RLL TOOL, RIH, DRILL OUT F/C & 10' OF NEW FORMATION, PERFORM EMW, 12.2 PPG EMW, TURBODRLG 8-1/2" F/4110-5804 DAILY:S83,522 CUM:$405,192 ETD:S405,192 EFC:$1,800,000 DRLG @ 8311' 9-5/8"@ 4081' MW:10.4 VIS: 40 DRILL FROM 8~11' TO 8406' REPLACE SWIVEL PACKING. DRILL , FROM 8406' TO 9343' TD. POOH, EMW TO 10.9 PPG PASSED. CONT POOH. UMLOAD RLL LOG, CHANGE TO DAILY:S57,647 CUM:$462,839 ETD:S462,839 EFC:$1,800,000 ARCO ALASKA INC. DAILY OPERATIONS WELL: 3G-22 OPERATION: DRILL RIG: DOYON 14 PAGE: 2 10/28/90 (6) TD: 9343'(1032) SUPV:JMM 10/29/90 ( 7) TD: 9782' ( 439) SUPV:JMM 10/30/90 (8) TD: 9782'( SUPV:JMM o) REAMING 8-1/2" HOLE 9-5/8"@ 4081' MW:10.4 VIS: 40 DRILL FROM 8311' TO 9343' POOH, PERFORM LOT TO 10.9 PPG EMW, PASSED. POOH AND CHANGE TO ROTARY BHA. RIH AND REAM FROM 9265' TO 9343'. DAILY:S63,050 CUM:$525,889 ETD:S525,889 EFC:$1,800,000 COND HOLE TO RUN 7" 9-5/8"@ 4081' MW:10.4 VIS: 39 DRILL FROM 9343' TO 9782' TD. POOH AND UNLOAD RLL LOGS. RIH FOR WIPER TRIP. REAM TIGHT BOTTOM HOLE SECTION. DAILY:S68,956 CUM:$594,845 ETD:S594,845 EFC:$1,800,00 RIG DOWN, PREP TO MOVE 7"@ 4081' MW:10.4 VIS: 39 CIRC ON BOTTOM, SPOT 25 BBL DIESEL PILL ACROSS KINGAK SHALE. POOH LD DP. RUN 228 JTS OF 7" 26#, J-55 CASING TO 9764. (123 JTS OF BTC AND 105 JTS OF AB MOD). RU DOWELL, CEMENT WITH: 10 BBL ARCO PRE-WASH, 35 BBL ARCO SPACER, 39 BBL (200 SX) CLASS G CEMENT 15.8 PPG, 370 BBL OF 10.4 PPG BRINE. BUMP PLUG TO 3500 PSI, FLOATS HELD, CIP @ 03:00 HRS, 30-OCT. FULL RETURNS THRUOUT JOB, RECIP PIPE DURING JOB. RD DOWELL SET 7" CASING SLIPS, NU TREE, TEST TREE TO 3000 PSI, OK. WILL BE MOVING TO 3G-4. , DAILY:S180,929 CUM:$775,774 ETD:S775,774 EFC:$1,800,000 SIGNATURE: DATE: ARCO ALASKA INC. DAILY OPERATIONS WELL: 3G-22 PAGE: 1 BOROUGH: FIELD: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: NORTH SLOPE KUPARUK RIVER FIELD KUPARUK RIVER UNIT ADL 25549 ALK 2663 50-103-20147 90-142 AK5342 55.252072 ACCEPT: 01/04/91 18:30 SPUD: RELEASE: 01/05/91 23:00 OPERATION: COMPLETION RIG: NORDIC 1 01/05/91 ( 9) TD: 9782 PB: 9678 SUPV:DB/LA 01/06/91 (10) TD: 9782 PB: 9678 SUPV:DB/LA NORDIC 1 RD HALLIBURTON 7"@ 4081' MW:10.4 NaC1/Br MOVE F/3G-21 TO 3G-22, ACCEPT RIG @ 18:30 1/4/91, ND MASTER VALVE & NU BOPE & TEST, WITNESSED WAIVED BY HAROLD HAWKINS, RU HLS, RIH & PERF 9426'-9462' IN TWO RUNS, RD HALLIBURTON DAILY:S27,745 CUM:$803,519 ETD:S803,519 EFC:$1,800,000 RIG RELEASED 7"@ 4081' MW:10.4 NaCl/Br RD HLS, STRAP JWLRY, RUN 3-1/2" 9.39 J-55 COMP, SET PKR @ 9260' PRESS TBG & ANN TO 1000 PSI, HOLD 10 MIN, BLEED OFF, , BOLDS, HOLD 2000 PSI ON TBG, PU & SHEAR PBR @ 92K# (27K# OVERPULL), BLEED OFF TBG, RELAND HGR, RILDS, TST SSSV @ 1807' W/1000 PSI DIFFERENTIAL FOR 10 MIN, BLEED OFF, ND BOPE NU TREE & TST, REV CIRC 12 BBLS DIESEL CAP INTO ANNULUS, INJECT 4 BBLS DIESEL CAP INTO TBG, PT=200 PSI, PC=0 PSI, PA=500 PSI, SECURE WELL RELEASE RIG @ 23:00 1/5/91 MOVE TO 3G-13 DAILY:S193,005 CUM:$996,524 ETD:S996,524 EFC:$1,800,000 SIGNATURE: DRI LLI~NG PERINTE~T DATE: / / D~RECT I ONAL SURVEY FOR A. RCO ALASKa- INCORPOR:~'TED KUP/,.p~'dK R i VER UN I T, x,.~ELL I4U!qBER 3G- '2'Z NORTH SLOPE BORoUG~' ~LASKA' 06 DECEMBER ~990 DATK : ;i CI OFILMED GREAT LAND DIRECTIONAL DRILLING, Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-22 Section at: S,55.48,W Surveyor..: ROB SHOUP S MEAS C DEPTH 7 100 7 200 7 300 7 400 7 500 INCLN ANGLE 0.08 0.22 0.16 0.23 3.33 7 600 6.46 7 700 7.49 7 800 8.84 7 900 11.35 7 1000 16.77 7 1100 20.61 7 1200 24.24 7 1300 24.44 7 1400 25.82 7 1500 27.43 7 1600 30.34 7 1700 32.95 7 1800 39.00 7 1900 45.15 7 2000 49.00 7 2100 51.02 ~Survey Codes: (KRU3G22G Bl.17) VERTICAL-DEPTHS BKB SUB-SEA 100.0 10.0 200.0- 110.0 300.0 210.0 400.0 310.0 499.9 409.9 599.6 509.6 698.8 608.8 797.8 707.8 896.2 806.2 993.2 903.2 1087.9 997.9 1180.3 1090.3 1271.5 1181.5 1362.0 1272.0 1451.4 1361.4 1538.9 1448.9 1624.1 1534.1 1704.9 1614.9 1779.1 1689.1 1847.2 1757.2 1911.5 1821.5 7/GYRO INC. for Gyrodata Services, RECORD OF SURVEY Inc. Computation...: Survey Date...: RKB Elevation.: Job Number .... : API Number..'..: 12/04/90 RADIUS OF CURVATURE 11/19/90 90.00 ft AKl190G256 50-103-20147 SECTION DISTNCE DIRECTION BEARING -0.0 N 28.72 W -0.1 N 22.58 W -0.1 N 21.11W -0.0 N 80.92 W 2.8 S 49.79 W 11.3 S 49.08 W 23.4 S 51.08 W 37.5 S 51.76 W 55.1 S 55.89 W 79.3 S 57.03 W 111.4 S 54.99 W 149.5 S 54.76 W 190.7 S 55.59 W 233.2 S 55.33 W 278.0 S 54.73 W 326.3 S 53.30 W 378.7 S 54.19 W 437.4 S 53.41 W 504.4 S 53.41 W 577.5 S 54.02 W 654.1 .S 54.64 W RELATIVE-COORDINATES FROM-WELL-HEAD 0.1 N 0.0 W 0.3 N 0.1 W 0.6 N 0.3 W 0.8 N 0.5 W 0.0 N 3.4 W 5.5. S 9.9 W 13.3 S 19.2 W 22.2 S 30.3 W 32.5 S 44.5 W 46.0 S 64.7 W 63.9 S 91.3 W 85.8 S 122.5 W 109.3 S 156.3 W 133.4 S 191.3 W 159.1 S 228.0 W 187.5 S 267.1 W 218.5 S 309.4 W 253.2 S 356.8 W 293.1 S 410.5 W 336.4 S 469.5 W 381.1 S 531.8 W CLOSURE DL DISTNCE BEARING /100 0.1 N 28.72 W 0.08 0.3 N 23.87 W 0.14 0.7 N 22.86 W 0.06 1.0 N 32.04 W 0.07 3.4 N 89.88 W 3.10 11.3 S 60.74 W 3.13 23.4 S 55.23 W 1.03 37.6 S 53.79 W 1.35 55.1 S 53.80 W 2.52 79.4 S 54.61 W 5.42 111.4 S 55.02 W 3.85 149.5 S 54.98 W 3.63 190.7 S 55.02 W 0.25 233.2 S 55.10 W 1.38 278.0 S 55.09 W 1.62 326.3 S 54.93 W 2.93 378.8 S 54.77 W 2.62 437.5 S 54.64 W 6.06 504.4 S 54.47 W 6.15 577.6 S 54.38 W 3.87 654.2 S 54.37 W 2.05 KRU 3G-22 S MEAS INCLN C DEPTH ANGLE 7 2200 54.82 7 2300 54.80 7 2400 56.94 7 2500 55.59 7 2600 58.42 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 1971.8 1881.8 733.9 2029.4 1939.4 815.6 2085.5 1995.5 898.4 2141.0 2051.0 981.5 2195.5 2105.5 1065.4 7 2700 57.41 2248.6 2158.6 7 2800 54.79 2304.4 2214.4 7 2900 54.71 2362.1- 2272.1 7 3000 60.86 2415.4 2325.4 7 3100 60.04 2464.7 2374.7 1150.0 1232.9 1314.5 1398.9 1485.7 RECORD OF SURVEY DIRECTION BEARING S 55.50 W S 56.38 W S 56.82 W S 55.85 W S 57.54 W S 57.72 W S 58.31 W S 58.98 W S 58.98 W S 59.46 W 7 3200 58.64 2515.7 2425.7 1571.4 S 60.41 W 7 3300 57.78 2568.4 2478.4 1656.1 S 61.43 W 7 3400 58.20 2621.4 2531.4 1740.6 S 59.10 W 7 3500 61.02 2672.0 2582.0 1826.7 S 56.94 W 7 3600 60.66 2720.7 2630.7 1914.0 S 57.98 W 7 3700 59.88 2770.3 2680.3 2000.7 S 58.94 W 7 3800 59.31 2820.9 2730.9 2086.8 S 59.52 W 7 3900 58.66 2872.4 2782.4 2172.2 S 60.67 W 7 4000 57.96 2924.9 2834.9 2256.9 S 61.50 W 7 4100 57.48 2978.3 2888.3 2341.0 S 61.46 W 2425.0 2509.3 2594.0 2679.0 2764.3 7 4200 57.95 3031.8 2941.8 7 4300 58.27 3084.6 2994.6 7 4400 58.54 3137.0 3047.0 7 4500 58.93 3188.9 3098.9 7 4600 58.92 3240.5 3150.5 7 4700 59.22 3291.9 3201.9 2849.6 S 61.97 W S 62.09 W S 61.38 W S 61.38 W S 61.08 W S 61.22 W RELATIVE-COORDINATES FROM-WELL-HEAD s w 472.6 S 664.9 W 518.1 S 734.0 W 564.2 S 803.2 W 610.3 S 873.3 W Page 2 CLOSURE DISTNCE BEARING 12/04/90 DL /lOO 734.0 S 54.45 W 3.84 815.7 S 54.60 W 0.59 898.4 S 54.78 W 2.16 981.6 S 54.91 W 1.5C 1065.4 S 55.05 W 3.08 655.6 S 944.8 W 1150.0 S 55.24 W 699.6 S 1015.2 W 1232.9 S 55.43 W 742.1 S 1085.0 W 1314.5 S 55.63 W 785.7 S 1157.4 W 1398.9 S 55.83 W 830.2 S 1232.2 W 1485.8 S 56.03 W 873.3 S 1306.6 W 1571.6 S 56.24 W 914.6. S 1380.9 W 1656.3 S 56.48 W 956.6 S 1454.5 W 1740.9 S 56.67 W 1002.3 S 1527.7 W 1827.1 S 56.73 W 1049.3 S 1601.3 W 1914.5 S 56.76 W 1094.7 S 1675.3 W 2001.3 S 56.84 W 1138.8 S 1749.4 W 2087.4 S 56.94 W 1181.6 S 1823.7 W 2173.0 S 57.06 W 1222.7 S 1898.2 W 2257.9 S 57.21 W 1263.1 S 1972.5 W 2342.2 S 57.37 W 1303.1 S 2046.9 W 2426.5 S 57.52 W 1342.9 S 2121.9 W 2511.2 S 57.67 W 1383.3 S 2196.9 W 2596.1 S 57.80 W 1424.2 S 2272.0 W 2681.5 S 57.92 W 1465.4 S 2347.0 W 2767.0 S 58.02 W 1.02 2.65 0.45 6.15 0.90 1506.8 S 2422.2 W 1.56 1.13 1.73 3.27 0.87 1.06 0.71 1.06 0.92 0.48 0.60 0.33 0.58 0.39 0.22 2852.6 S 58.11 W 0.32 ~Survey Codes: 7/GYRO KRU 3G-22 S MEAS INCLN C DEPTH ANGLE 7 4800 58.85 7 4900 57.61 7 5000 57.66 7 5100 57.83 7 5200 58.00 7 5300 58.00 7 5400 58.13 7 5500 58.13 7 5600 58.16 7 5700 58.14 7 5800 58.09 7 5900 58.04 7 6000 58.10 7 6100 58.29 7 6200 58.01 7 6300 57.83 7 6400 57.64 7 6500 57.80 7 6600 57.69 7 6700 57.90 7 6800 57.98 7 6900 57.89 7 7000 57.84 7 7100 58.04 7 7200 58.12 7 7300 58.63 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING 3343.3 3253.3 2935.0 3396.0 3306.0 3019.7 3449.5 3359.5 3103.9 3502.9 3412.9 3188.2 3556.0 3466.0 3272.7 3609.0 3519.0 3357.3 3661.9 3571.9 3441.9 3714.7' 3624.7 3526.6 3767.5 3677.5 3611.3 3820.2 3730.2 3696.1 3873.1 3783.1 3780.9 3926.0 3836.0 3865.5 3978.9 3888.9 3950.2 4031.6 3941.6 4035.0 4084.3 3994.3 4119.8 4137.4 4047.4 4204.4 4190.8 4100.8 4288.9 4244.2 4154.2 4373.3 4297.6 4207.6 4457.8 4350.9 4260.9 4542.4 4404.0 4314.0 4627.2 4457.1 4367.1 4711.9 4510.3 4420.3 4796.6 4563.3 4473.3 4881.3 4616.2 4526.2 4966.0 S 60.45 W S 59.87 W S 60.08 W S 59.84 W S 60.12 W RELATIVE-COORDINATES FROM-WELL-HEAD 1548.6 S 2497.1 W 1590.9 S 2570.8 W 1633.2 S 2643.9 W 1675.5 S 2717.1 W 1717.9 S 2790.5 W Page 3 CLOSURE DISTNCE BEARING 2938.3 S 58.19 W 3023.2 S 58.25 W 3107.7 S 58.30 W 3192.2 S 58.34 W 3276.9 S 58.38 W S 59.85 W 1760.3 S 2863.9 W 3361.7 S 58.42 W S 59.98 W 1802.9 S 2937.4 W 3446.5 S 58.46 W S 59.01 W 1846.0 S 3010.5 W 3531.4 S 58.48 W S 59.47 W 1889.4 S 3083.5 W 3616.4 S 58.50 W S 58.51 W 1933.2 S 3156.3 W 3701.3 S 58.51 W 1976.9 S 3229.1 W 3786.2 S 58.53 W 2020.0 S 3302.2 W 3871.1 S 58.55 W 2063.3 S 3375.2 W 3955.9 S 58.56 W 2106.8 S 3448.2 W 4040.9 S 58.58 W 2150.6 S 3521.0 W 4125.8 S 58.58 W S 59.59 W S 59.29 W S 59.29 W S 59.22 W S 58.76 W S 58.16 W S 58.00 W S 58.01 W S 57.99 W S 54.75 W 2194.9 S 3593.2 W 4210.6 $ 58.58 W 2239.6 S 3665.0 W 4295.1 S 58.57 W 2284.4 S 3736.7 W 4379.7 S 58.56 W 2329.2 S 3808.4 W 4464.2 S 58.55 W 2376.0 S 3878.9 W 4548.8 S 58.51 W S 54.64 W 2425.0 S 3948.0 W S 54.18 W 2474.3 S 4017.0 W S 54.72 W 2523.6 S 4085.9 W S 54.20 W 2572.8 S 4154.8 W S 49.70 W 2625.1 S 4221.6 W 12/04/90 2680.8 S 4286.0 W 4668.6 4578.6 5050.6 S 48.59 W 4633.3 S 58.44 W 4717.9 S 58.37 W 4802.4 S 58.30 W 4886.9 S 58.23 W 4971.3 S 58.13 W 5055.4 S 57.97 W DL /1oo 0.67 1.31 0.16 0.24 0.26 0.19 0.16 0.70 0.33 0.69 0.78 0.22 0.06 0.20 0.43 0.47 0.22 0.16 0.11 2.33 0.11 0.34 0.39 0.42 3.25 0.96 'Survey Codes: 7/GYRO KRU 3G-22 S MEAS INCLN C DEPTH ANGLE 7 7400 58.51 7 7500 56.26 7 7600 54.91 7 7700 55.10 7 7800 55.38 VERTICAL-DEPTHS SECTION BKB SUB-SEA DISTNCE 4720.8 4630.8 5135.4 4774.7 4684.7 5218.8 4831.2 4741.2 5300.2 4888.5 4798.5 5380.8 4945.6 4855.6 5461.6 7 7900 55.68 5002.2 4912.2 5542.7 7 8000 53.35 5060.2 4970.2 5623.1 7 8100 53.76 5119.6' 5029.6 5702.8 7 8200 53.91 5178.6 5088.6 5782.8 7 8300 53.97 5237.5 5147.5 5862.8 7 8400 54.41 5296.0 5206.0 5943.1 7 8500 54.64 5354.0 5264.0 6023.5 7 8600 53.84 5412.5 5322.5 6103.7 7 8700 53.97 5471.4 5381.4 6183.7 7 8800 54.45 5529.9 5439.9 6264.2 RECORD OF SURVEY DIRECTION BEARING S 49.02 S 46.75 S 45.24 S 45.27 S 44.99 S 44.88 W S 48.15 W S 47.54 W S 47.53 W S 47.14 W S 47.09 W S 46.41 W S 47.02 W S 47.27 W S 50.36 W 7 8900 54.44 5588.0 5498.0 6345.3 $ 50.18 W 7 9000 54.41 5646.2 5556.2 6426.3 S 50.27 W 7 9100 54.46 5704.3 5614.3 6507.2 S 49.61 W 7 9200 54.73 5762.3 5672.3 6588.3 S 49.53 W 7 9300 54.78 5820.0 5730.0 6669.5 S 49.27 W 7 9400 55.31 5877.3 5787.3 6751.0 S 50.07 W 7 9500 56.29 5933.5 5843.5 6833.4 $ 50.27 W 7 9600 57.66 5988.0 5898.0 6916.9 S 50.70 W X 9782 57.66 6085.4 5995.4 7070.2 S 50.70 W RELATIVE-COORDINATES FROM-WELL-HEAD 2737.0 S 4350.2 W 2793.5 S 4412.7 W 2850.8 S 4472.1W 2908.5 S 4530.2 W 2966.5 S 4588.5 W 3024.8 S 4646.7 W 3080.8 S 4705.8 W 3134.8 S 4765.4 W 3189.3 S 4824.9 W 3244.1 S 4884.4 W 3299.3 S 4943.8 W 3355.1 S 5003.1W 3410.7 S 5062.2 W 3465.7 S 5121.4 W 3519.1 S 5182.5 W 3571.1 S 5245.0 W 3623.2 S 5307.6 W 3675.5 S 5369.8 W 3728.4 S 5431.9 W 3781.5 S 5493.9 W 3834.6 S 5556.3 W 3887.5 S 5619.9 W 3940.9 S 5684.5 W 4038.3 S 5803.5 W Page 4 12/04/90 CLOSURE DL DISTNCE BEARING /100 5139.7 S 57.82 W 0.33 5222.6 S 57.66 W 2.74 5303.4 S 57.48 W 1.69 5383.5 S 57.30 W 0.17 5463.9 S 57.12 W 0.34 5544.5 S 56.94 W 0.31 5624.6 S 56.79 W 3.14 5704.0 S 56.66 W 0.57 5783.8 S 56.53 W 0.15 5863.6 S 56.41 W 0.26 5943.6 S 56.28 W 0.44 6024.0 S 56.15 W 0.51 6104.0 S 56.03 W 0.89 6183.9 S 55.91 W 0.21 6264.4 S 55.82 W 2.10 6345.3 S 55.75 W 0.12 6426.3 S 55.68 W 0.07 6507.2 S 55.61 W 0.44 6588.3 S 55.53 W 0.28 6669.5 S 55.46 W 0.18 6751.1 S 55;39 W 0.76 6833..4 S 55.33 W 0.99 6917.0 S 55.27 W 1.40 7070.3 S 55.17 W 0.00 ~Survey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-22 SUBSEA DEPTH 0 100 200 300 40O 500 600 7O0 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2OO0 2100 2200 2300 2400 MEAS DEPTH 90 190 290 390 490 590 691 792 894 997 1102 1211 1320 1431 1544 1660 1781 1915 2066 2232 2408 2590 2775 2950 3150 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 5 12/04/90 INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 0.07 90 0 0 N 28.72 W 0.05 N 0.03 W 0.21 190 0 0 N 23.19 W 0.27 N 0.12 W 0.17 290 0 0 N 21.26 W 0.58 N 0.25 W 0.22 390 0 0 N 74.94 W 0.80 N 0.47 W 3.02 490 0 0 S 54.70 W 0.25 N 2.94 W 6.16 590 0 0 S 49.15 W 4.85 S 9.09 W 7.40 690 1 1 S 50.90 W 12.61 S 18.31 W 8.73 790 2 1 S 51.71 W 21.44 S 29.36 W 11.19 890 4 2 S 55.63 W 31.83 S 43.43 W 16.59 990 7 3 S 56.99 W 45.42 S 63.89 W 20.69 1090 12 6 $ 54.98 W 64.31 S 91.90 W 24.26 1190 21 8 S 54.85 W 88.31 S 126.01 W 24.72 1290 30 10 S 55.54 W 114.14 S 163.28 W 26.32 1390 41 11 S 55.14 W 141.23 S 202.52 W 28.70 1490 54 13 S 54.10 W 171.09 S 244.73 W 31.90 1590 70 16 S 53.83 W 205.79 S 291.87 W 37.85 1690 91 21 S 53.56 W 246.13 S 347.22 W 45,75 1790 125 35 S 53.50 W 299.68 S 419.40 W 50.33 1890 176 51 S 54.43 W 365.89 S 510.42 W 54.81 1990 242 66 S 55.78 W 441.37 S 618.52 W 56.83 2090 318 77 S 56.74 W 521.89 S 739.75 W 58.12 2190 400 81 S 57.36 W 605.48 S 865.80 W 55.45 2290 485 85 S 58.16 W 688.72 S 997.70 W 57.80 2390 560 75 S 58.98 W 763.60 S 1120.78 W 59.34 2490 660 100 S 59.94 W 852.01 S 1269.56 W 2500 3341 57.95 2590 751 91 S 60.48 W 931.29 S 1411.02 W KRU 3G-22 DATA INTERPOLATED FOR 100 FT Page SUBSEA INTERVAL 6 12/04/90 SUBSEA DEPTH 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 MEAS DEPTH 3537 3739 3934 4122 4310 INCLN TVD MD-TVD VERT ANGLE BKB DIFF CRRT 60.89 2690 847 96 59.66 2790 949 102 58.42 2890 1044 95 57.58 2990 1132 88 58.30 3090 1220 89 4502 58.93 3190 1312 4696 59.21 3290 1406 4889 57.75 3390 1499 5076 57.79 3490 1586 5264 58.00 3590 1674 545 564 583 602 621 639 658 677 696 715 734 752 770 787 805 3 58.13 3690 1763 3 58.15 3790 1853 2 58.07 3890 1942 1 58.14 3990 2031 1 57.99 4090 2121 8 57.64 4190 2208 6 57.71 4290 2296 4 57.96 4390 2384 2 57.86 4490 2472 0 58.08 4590 2560 1 58.58 4690 2651 7 55.89 4790 2737 3. 55.11 4890 2813 8 55.62 4990 2888 0 53.56 5090 2960 DIRECTION BEARING S 57.33 W S 59.17 W S 60.95 W S 61.57 W S 62.02 W 92 S 61.37 W 94 S 61.21 W 92 S 59.94 W 87 S 59.90 W 88 S 59.95 W 89 S 59.46 W 89 S 59.06 W 89 S 59.49 W 89 S 59.28 W 90 S 58.70 W RELATIVE COORDINATES FROM WELL HEAD 1019.94 S 1554.98 W 1112.11 S 1704.35 W 1195.57 S 1848.81 W 1271.79 S 1988.57 W 1347.05 S 2129.65 W 1425.11 S 2273.60 W 1505.30 S 2419.39 W 1586.17 S 2562.60 W 1665.24 S 2699.42 W 1745.08 S 2837.61 W 1825.66 S 2976.39 W 1907.95 S 3114.68 W 1990.63 S 3252.57 W 2072.50 S 3390.59 W 2155.26 S 3528.79 W 88 S 58.00 W 2238.90 S 3663.92 W 87 S 57.99 W 2322.83 S 3798.25 W 88 S 54.67 W 2412.11 S 3929.83 W 88 S 54.51 W 2504.92 S 4059.58 W 88 S 51.93 W 2598.55 S 4189.00 W 91 S 48.77 W 86 S 46.34 W 75 S 45.26 W 76 S 44.90 W 72 S 47.84 W 2703.95 S 4312.32 W 2809.19 S 4429.25 W 2909.96 S 4531.71 W 3012.22 S 4634.13 W 3107.74 S 4735.63 W 5100 8219 53.92 5190 3029 69 S 47.45 W 3199.89 S 4836.46 W KRU 3G-22 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 12/04/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5200 8390 54.36 5290 5300 8562 54.15 5390 5400 8732 54.12 5490 5500 8903 54.44 5590 5600 9075 54.45 5690 5700 9248 54.75 5790 5800 9422 55.53 5890 5900 9604 57.66 5990 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 3100 70 S 47.10 W 3293.61 S 4937.68 W 3172 72 S 46.79 W 3'389.62 S 5039.62 W 3242 70 S 48.25 W 3482.96 S 5140.44 W 3313 72 S 50.18 W 3572.90 S 5247.18 W 3385 72 S 49.77 W 3662.51 S 5354.50 W 3458 73 S 49.41W 3753.84 S 5461.65 W 3532 74 S 50.11 W 3846.39 S 5570.49 W 3614 81 S 50.70 W 3942.88 S 5686.99 W KRU 3G-22 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DE~TH INTERVAL 12/04/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 16.77 993 903 79 S 57.03 W 46 2000 49.00 1847 1757 578 S 54.02 W 336 3000 60.86 2415 2325 1399 S 58.98 W 786 4000 57.96 2925 2835 2257 S 61.50 W 1223 5000 57.66 3450 3360 3104 S 60.08 W 1633 65 W 79 S 54.61 W 5.4 470 W 578 S 54.38 W 3.9 1157 W 1399 S 55.83 W 6.1 1898 W 2258 S 57.21 W 0.9 2644 W 3108 S 58.30 W 0.2 6000 58.10 3979 3889 3950 S 59.29 W 2063 7000 57.84 4510 4420 4797 S 54.72 W 2524 8000 53.35 5060 4970 5623 S 48.15 W 3081'S 9000 54.41 5646 5556 6426 S 50.27 W 3623 3375 W 3956 S 58.56 W 0.1 4086 W 4802 S 58.30 W 0.4 4706 W 5625 S 56.79 W 3.1 5308 W 6426 S 55.68 W 0.1 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 12/04/90 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-22 Section at: S,55.48,W Surveyor..' ROB SHOUP Computation...: RADIUS OF CURVATURE Survey Date...' 11/19/90 RKB Elevation.: 90.00 ft Job Number .... : AKl190G256 AP1 Number .... : 50-103-20147 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 220 WEL S23 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" CASING PROJECTED TD MEAS INCLN DEPTH ANGLE 0 0.00 4042 57.76 9374 55.17 9392 55.27 9392 55.27 9568 57.22 9764 57.66 9782 57.66 VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 -90 2947 2857 5862 5772 5873 5783 5873 5783 0 N 0.00E ON 0E 2292 S 61.48 W 1240 S 1929 W 6730 S 49.86 W 3821 S 5540 W 6745 S 50.01 W 3830 S 5551 W 6745 S 50.01 W 3830 S 5551 W 5971 5881 6076 5986 6085 5995 6890 S 50.56 W 7055 S 50.70 W 7070 S 50.70 W 3924 S 5664 W 4029 S 5792 W 4038 S 5804 W <KB>O 650 t300 1950 2600 325O 3900 4550 5200 585O 6500 7i50 7800 8450 9t00 650 VERTICAL SECTION VIEW ARCO ALASKA, INC. KRU 3G-22 , Section at: S 55.4B W TVD Scale.' 1 inch = 1300 feet Dep Scale.' t ~nch = 1300 feet ~ Drawn ' 12/04/90 i ~arker Identification MD TVB SECTN AJKB 0 0 0 A -- B] 9-518' CASING 4042 2947 2292 C] TOP KUPARUK C 9374 5862 6730 DJ BASE KUPARUK C 9392 5B73 6745 ~ TOP KUPARUK A 9392 5873 6745 ~ 7' CASING 9764 6076 7055 I ~] PROJECT~ TD 9782 6085 7070 I I I I i ....... .... INCLN 0.00 57.76 55. i7 55.27 55.27 57.22 57.66 57.66 0 650 i300 t950 2600 3250 3900 4550 5200 5850 6500 Section Departure Marker Identification MO N/S E/H A] KB 0 0 N 0 E 8) PROJECTED TO 9782 4038 S 5804 H PLaN V IEN ARCO ALASKA, INC. KRU 36-22 CLOSURE ..... : 7070 ft S 55.i7 N DEOLZNATION.: 0.00 E SCALE ....... : 1 inch = 1100 feet DRANN ....... : 12/04/90 rr' Z C~ V 55O 0 55O 1100 t650 22OO 2750 33O0 385O 4400 495O 55OO 6050 6600 7t50 6050 5500 4950 4400 3850 3300 2750 2~00 t650 ltO0 550 0 550 <- NEST · EAST -> AOGCC GEOLOGICAL MATEDJALS ]NYENTORY LiST PEnMiT # /9 o -/y-.~ WELL NAME /~/~ ~ COMPLETION DA~ / t ~ /. ~/ CO. CONTACT ~C~ check Off or lis~ data ~lSI it is received:Iisi received date for 407. if nol re.]~ired list as NR . , . i ! . , 9) ~o} 11} ~ 4] II ~5] , ! lllll j I ARCO Alaska, Inc. Date: February 4, 1991 Transmittal #: 8000 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G- 0 .9~.~ Pulse Echo Cement Evaluation Log 3G-24~, Pulse Echo Cement Evaluation Log 3 G-04~_ _,..,~-. Pulse Echo Cement Evaluation Log 3 G-15-~,~ Pulse Echo Cement Evaluation Log 3 G - 22,X?,/~' Pulse Echo Cement Evaluation Log 3G- 21/";,~ '- Pulse Echo Cement Evaluation Log 3 G- 04;~ Acoustic Cement Bond Log 3 G- 22~ Acoustic Cement Bond Log 1 L- 2 2',~ Squeeze Record Receipt Acknowledge- 10- 11- 11- 11- 11- 11- 11- 11- 1-2 State of AlaSka -~. Drilling : 3-90 5229-9682 15-90 6698-9704 1 6-90 4900-7939 14-90 4500-7815 18-90 6600-9595 23-90 8466-11;513 16-90 4892-7962 18-90 6600-9616 0-91 9200-9800 Date: NSK (-EiVED FEB ,~ 199! Alaska Oil & Gas Cons. Commission Anchorage TO: THRU: MEMORAhOUM State of Alaska ALAS~t OIL A~D GAS CONSERVATION COI.~4ISSION Lonnie C. Smi --~-~i DATE: January 18, 1991 Conm~i s s ioner FILE NO: JT.HH. !189!.5 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection AAI KRU 3G-,=2 Kuparuk Rv. Field FROM: Harold R. Hawkins Petroleum inspector Saturday Januar__Z 5, 1991: i inspected Nordic Rig /,~1 at AAI KRU 3G-22. I wen ~om ~ ~ ce~=~ to rig {loor and checked location and found no infractions except the blowdown lines were still not changed out and were still ~ ~' . ~o~_ AP1 I talked to Don Breeden, the AAI representative and he told me all lines and unibolts were on location but welders ~-=shed up mainly on ~ne targets. ~,~ve riot ~'~ ~ ~ ~ordzc Rig No. i is up on requirements except the in s ~umm-ary: The TM -' blowaown lines wh~c~ is being worked on now. 02-00lA (Rev. 6/89) 20/11/~WIEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _.X_ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development Exploratory Stratigraphic Service 4. Location of well at surface 2538' FNL, 220' FEL, SEC 23,T12N,R8E,UM At top of productive interval 1220' Fnl, 700' FEL, Sec. 27, T12N, R8E, UM At effective depth NA At total depth 1417"FNL, 986' FEL, Sec. 27, T12N, R8E, UM (approx) (approx) 12. Present well condition summary Total Depth: measured 9782' feet (approx) true vertical 6103' feet Effective depth: measured NA feet (approx) true vertical NA feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 9O' 7. Unit or Property name Kuparuk River Unit 8. Well Number 3G-22 9. Permit number 90-142 10. APl number ,50-103-20147 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 4007' 9 5/8" Intermediate Production 9729' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented 216 SX AS I 950 Sx ASII I& 550Sx Class G 200Sx class G Measured depth True vertical depth 1 1 5' 11 5'approx. 4042' 2941'(approx) 9764' 6093' (approx) RECEIVED DEC - 1990 Alas 0ii & Gas Cons, 6Qmmissior~ Anchorage 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation January, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:, Oil ~[ Gas _ Suspended _ Service 17. I hereby cerlt, ify that the foregoing is true and correct to the best of my knowledge. Signed c~'~x'~' ~~~'~ FoRTitle COMMISSIoNArea DrillingusE ONLyEngineer Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Commissioner Form 10-403 Rev 06/15/88 OI~iCINAL S16NED ~¥ LONNIE C. SM~T~4 Approved Copy Returned lApp_reval No:..-... / Date SUBMIT IN ~tRIPLICATE I~..P~am ~.~d. submit-~~~:_O~, the first Wednesday after a well Is .pu~ or w~r o~10~ .~ ~. :~ D~ wo~_~~:~~ ~ the fo~ giving I~lu~ dat~ only. Field : ~' ~::~3 :~' : IL .... Unit ~~ R[~ ~[S~; I ~ 25549 A~ 2663 Auth. or W.O. no. ITitte ~5342 J DRILLING ARt Ji[.~-dGa$':~~::::~::' ' ' Well Hi,to~y- Initial Report- Dally IState AK IWell no. 3G-22 Operator ]ARCO W.I. ARCO ] 55. 02521 Spudded or W.O. begunsPUD rDate 10/24/90 IHOur 06:00 IPrlOrstatusifaw'O' Date and depth as of 8:00 a.m. 10/23/90 (-1) TD: 115' ( 115) SUPV: GNH 10/24/90 (2) TD: 3295'( 3180 SUPV:JMN 10/25/90 (3) TD: 4100'( 805) SU~V:JNM 10/26/90 (4) TD: 5804'( 1704)11 SUPV:,.TNN ~ 10/27/90 (5) TD: 8311'( 2507 SUPV:JMM 10/28/90 (6) TD: 9343'(1032) SUPV:JMH TD: 9782'( 439) SUPV: JMN - 4 i990 Cons. Commi~i~. For fo~ pre~amtlo~ ~lstHbuflon, s~ Procedures M~u~ ~ 10, DHIIIng, Pag~ ~ and 87. Complete record for each day reported DOYON 14 TEST DIVERTER S~STEM MW: 0.0 VIS: 0 ACCEPT RIG ON 3G-22 @ 02:30 ON 23-0CT-90, NU DIVERTER SYSTEM MU SPUD MUD, PU & MU BHA BIT %1, ORIENT, FUNCTION TEST DIVERTER DAILY:S24,149 CUM:$24,149 ETD:S24,149 EFC:$1,800,000 NAVIDRLG 12.25 HOLE 9-5/8"6 4081' MW: 9.1 VIS: 64 SPUD @ 0600 HRS @ 115' DRILL TO 413'. ORIENT N NAVIDRILL TO 533'. PENETRATIN RATE LOW, NAVIDRILL WEAK POOH N CHANGE OUT NAVIDRILL MTR, ORIENT, RIH. DRILL 12-1/4" HOLE TO 3295'. DAILY:S85,492 CUM:$109,641 ETD:S109,641 EFC:$1,800,000 MU 9-5/8" STARTING HEAD 9-5/8"6 4081' MW: 0.0 VIS: 0 DRILL FROM 3295 TO 4083. MAKE WIPER TRIP, DRILL FROM 4083' TO 4100' POOH, RAN 98 JTS OF 9-5/8", J-55, 36%, BTC CASING TO 4081' PUMP 80 BBLS H20, 328 BBLS ASIII (950 SX) 12.1 PPG LEAD CEMENT, 113 BBLS (950 SX) CLASS G 15.8 PPG TAIL CEMENT. DISPLACE WITH 305 BBLS H20, BUMP PLUG @ 2500 PSI, FLOATS OK, CIP @ 0400 HRS. RD DIVERTER, MU 9-5/8" STARTING HEAD. DAILY:S212,029 CUM:$321,670 ETD:S321,670 EFC:$1,800,000 ~i8-1/2" HOLE 9-5/8"@ 4081' MW: 9.6 VIS: 39 ~~_ T ALL SURF EQUIP TO 500 & 3000 PSI, INSTALL WEAR ~~~~U~'& MU BHA & ORIENT, INSTALL SOURCES IN RLL TOOL, ~:OUT F/C & 10' OF NEW FORMATION, PERFORM EJv~, 12.2 ~~DP.~G 8-1/2" F/4110-sa04 '~~'$22 CUN:$405,192 E~D:$405,192 EFC:$1,800,000 DRLG @ 8311'. 9-5/8"@ 4081' MW:10.4 VIS: 40 DR.T~L FROM 8311' TO 8406', RgPZd~CE SWI1/gL PACKING. DRILL FRON 8406' TO 9343' I~D. POOH, gMW TO 10.9 PPG PASSED. CONT POOH. UN/~AD RLL LOG, CIU~GE TO DAI~:$57,647 CUN:$462,839 ETD:S462,839 RFC:S1,800,000 RE, A~NG 8-1/2" HOLE 9-5/8"~ 4081' MW:10.4 VIS: 40 DR.TLL FRGH 8311' TO 9343'. POOH, PERFORM LO? TO [0.9 PPG ENW, PASSE, D. POOH AND CHANGB TO ROTARY BHA. RI~ A.ND REAM FRQM 9265' TO 9343'. DAILY:S63,050 CUN:$525,889 ETD:S525,889 EEC:S[,800,000 COND HOLE TO RON 7" 9-5/8"8 4081' MW:10.4 VIS: 39 DRILL FROM 9343' TO 9?82' ID. POOH AND UNLORD R~L L(X]S. RIH FOR ~IPBR TRIP. AP, AN TIGHT BOTTOH ROLE SECTION. DAILY:S68,956 Ct.~:$594,845 ElD:S594,845 ~FC:$1,800,000 AR3B.-459-1-D INumberall dally' well hlltory forms consecutively no. u they are prepared for each wall. '1Page I AR~../O. and Gas Company Daily Well History-Final Report Instructions: Prepare a~'.~et!...v_~{~e:flrst Wed.ne.sd. ay after allowable has been assigned or well Is Plugged, Abandoned, or Sold. an indefinite or appreciable length of time. On workovers when an official test is not "Final Reporl" should IMW.' ........ . ..al~..S~mpenoea rgr requ red upon completloi~?~'~ ~. . iltal[t~~ test data ~n blocks provided. The "Final Reporl" form may be used for reporting the entire I District "_:?;-~-~-'-? !:: County or Parish ISlate ARCO ALASKA INC. NORTH SLOPE I AK I~we. no. Field Lease or Unit KUPARUK RIVER FIELD I ADL 25549 ALK 2663 ~3G-22 Aulh. or W.O. no. ITM AK5342 I DRILLING Operator A.R.Co. W.I. ARCO Date 55. 2521 Spudded or W.O. begun SPUD 10/24/90 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 10/30/90 ( TD: 9782'( SUPV:JMM Old TD Iotal number of wells (active or inactive) on this~ cst center prior to plugging and I bandonment of this well our IPrlor status if e W,O. I 06:00 RIG DOWN, PREP TO MOVE 7"@ 4081' MW:10.4 VIS: 39 CIRC ON BOTTOM, SPOT 25 BBL DIESEL PILL ACROSS KINGAK SHALE. POOH LD DP. RUN 228 JTS OF 7" 26#, J-55 CASING TO 9764. (123 JTS OF BTC AND 105 JTS OF AB MOD). RU DOWELL, CEMENT WITH: 10 BBL ARCO PRE-WASH, 35 BBL ARCO SPACER, 39 BBL (200 SX) CLASS G CEMENT 15.8 PPG, 370 BBL OF 10.4 PPG BRINE. BUMP PLUG TO 3500 PSI, FLOATS HELD, CIP @ 03:00 HRS, 30-OCT. FULL RETURNS THRUOUT JOB, RECIP PIPE DURING JOB. RD DOWELL SET 7" CASING SLIPS, NU TREE, TEST TREE TO 3000 PSI, OK. WILL BE MOVING TO 3G-4. RR 10/30/90 @ 06:00 DAILY:S180,929 CUM:$775,774 ETD:S775,774 EFC:$1,800,000 i'--' & Gas Cons. Commission Anchorage New TO IPB Depth Kind of rig Released rig Date Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective da~e corrected The above is correct For form preparation ~;istribu-ti%n, · ~/ k.~ J see Procedures Manu%~ Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well. Olvl~lo~ of ARCO Alaska, Inc. Date: November 15, 1990 Transmittal #: 7941 RETURN TOi ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G- 02 Dual Gamma Ray Compensated 1 0 - 21 - 90 3085- 6659 Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic 1 0-21 -90 Wave Resistivity Formation Exposure Time Dual Gamma Ray Compensated 1 0 - 2 9 - 90 Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic 1 0 - 2 9 - 9 0 Wave Resistivity Formation Exposure Time 3G-02 3085-6659 3G-22 4100-9782 3G-22 4100-9782 Receipt Acknowledged: ~~...'~~~~t Date' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) N()V 'I ,"ji '1~0 Alaska 0il & 6~s Cons. Commission Anchorage ARCO Alaska, Inc. Date: November, 1990 Transmittal #: 7942 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-22 3G-02 LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return 11. . 0 Receipt Acknowledged: Date: .......... DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED NOV ~ ~ 19.90 Alaska 0il & 61as Cons. Commission Anchorage October 22, 1990 Telecopy: (907)276-7542 A. Wayne McBride Area Drilling Engineer ARCO Alaska, Inc. P. O o Box !00360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-22 BJlCO 'Alaska, Inc. Permit No. 90-142 Sur. Loc. 2538' FNL, Btmhole Loc. !417'F~, 220'FEL, Sec. 23, T12N, RSE, UM.._. 986'FE7_~, Sec. 27, T12N, RgE, U~.. Dear ~r. McBride: Enclosed is the approved application for permit to drill the above referenced well. ~The permit to drill does not exempt you from obtaining additional permits required by !a~..~ from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting dete_~minations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely~ ~ Lonnie C. ~--Smith Commissioner Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory~ Stratigraphic Test _. Development Oil X Re-Entry _ Deepen --I Service _ Development Gas w Single Zone X Mulliple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and P°ol ARCO Alaska, Inc. RKB 90', Pad 53' GL feet Kuparuk River Field 3. Address 8. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora(:je, AK 99510-0360 ADL 25549 ALK 2663 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 220' FEL, Sec. 23, T12N, R8E, UM K~Jparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1220' FNL, 700' FEL, Sec. 27, T12N, R8E, UM 3G-22 #U630610 At total depth 9. Approximate spud date Amount 1417' FNL, 986' FEL, Sec 27, T12N, R8E, UM 27-OCT-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-23 10015' MD 986'@ TD feet 25' at surface feet 2560 6206'TVD feel 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400' feet Maximum hole anc,~le 57° Maximum surface 1750 pslg At totaldepth (TVD) 6206' @ 3450 psi 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD 'I'VD IVD TVD linclude sla~e dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +_200 Cu.Ft. 12.25 9.625 36.0# J-55 BTC 4013 35' 35' 4048' 2954 1785 Cu. Ft. AS III & HF-ER~I 590 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MO[ 4602' 35' 35' 4637' 3275' 205 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 5378' 4637' 3275' 10015' 6206' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Cu. R. ~ ~,,; Surface Cu. Ft. ~ '~¥. ~-~. ~,~ ~' , ..... Intermediate Production Pedoration depth: measured·~'.'.'~ i''' ~'''~._~,~,~_ .0il & ~;~.~r .... .~ L)ll~r true verlical 20. Altachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch ;X Drilling program ;X Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report ~20 AAC 25.050 requirements X_ 21. I hereby certi~ that the foregoing is true and correct to the best of my knowledge Signe~~J~ ~ ,~ ,Title Area Drillinc~ Engineer Date ~ ~/' [ ~.z/~mmission Use Only Permit Nu~'ber I APl number '~'" - I Approval date J See cover loiter for ?~ -/~-.-'_~ so-/~ ~- ~.~/5~ ? '1 0 / 22 / 90 other recluirements Conditions ol approval Samples required ~Ye s ~ N o Mud log required~ Ye s N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ,~Yes ~ No Required working pressure for DOPE ~2M' ~ 3M/~ .... ~ 5M' ~ 1 0M' ~ 1 5 M Other; ~'~'?- ~~ ~!"? by order of Approved by i ~/~'~--~,-,.,~-~ ~ ~,~~'% Commissioner the commission Date ~/c3 Form 10-401 Rev. 7-24-89 Submit in triplicate Pad 3G, 14al I No, 22 P,,oposad Kupa~uk FIeld. No~th Slope. Ala,k, ~:~~7 0 . RKB ELEVATiON~ 90' 1000 2000 3000_ 4000_ 5000_ 6000~ ?000 KOP TVD=400 TMD=400 DEP~O g BUILD 3 DEO -- ~-- I$ PER I00 FT 21 27 B/ PERHAFROST TVD=lSgO THD=1685 DEP-416 T/ UGNU SNDS TVD=1740 THD=1885 DEP-54g Si EOC TVD-2001 THD=2299 DEP=86g T/ W SAK SNDS TVD-2400 TMD=3031 DEP=1482 B/ g SAK SNDS TVD=2830 THD=3820 DEP-2144 g 5/8' CSG PT TVD-2954 THD=4048 DEP=2335 K-lO TVD-30?7 THD-4273 DEP-2524 K-$ TVD-4170 THD=62?9 DEP=4206 AVERAGE ANGLE 56 DEG 59 MI N TARGET - T/ C ZONE TVD-'5980 THD=9601 DEP-6ggl T/ A ZONE TVD=59go THD=g61g DEP=?O06 B/ KUP SND$ TVD=6097 THD-9815 DEP-?I?I TD~'-L-OG--PTt' TVt:~'6206 THD-lO015 DEP-7339 _ i I I ..... I ..... I ........ ~ 3000 4000 ..... sooo_-. ~ooo __ z~l~ -"~ooo -- --- VERTICAL SECTION -'--= ..... _ 1000! 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ ARCO ALASKA. Ine. Pad ~SG. :Well Hoe 22 Propoeed Kuperuk :Field. North Slope. Ala.ka 7'000 6000 5000 4000 ,~ , ~,,,h ,I, I I S 55 DEG 29 I"IIN W 69=91' (TO TARGET) WEST-EAST 3000 I 2000 1 000 0 1 000 I I.,,,,, I I SURFACE LOCATION~ 2538'.F#L. 220' FEL SEC. 23. T I2N, R8E SOUTH 3962 gEST $?60 TARGET LOCATION ~ 1220' FNL. TOO' FEL SEC. 27. T I2N. R8E TD LOCATION~ 1417' FNL. 986' FEL SEC. 27. TI2N. R8E 00~ Og! OOl O~ 001 Ogl Og ~ O0 ~ Og 0 Og O0 ____ O~ l O0 J~~__~ ._1_ I , I ' /////// 00~ / ~ 006 ff0 006 // oo, 002 R 002 / O0 / 0011 00£ 0011 00£ 00~ ./ 00£ 00£."00£ oo~ 0 OI 00l O~ O~ 00l OOJ Ogg 00! GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 3GPAD ' · ,, 3. . . f . . . 10. 11, 12. 13. 14. 15. 16. 17. 18. 19. 20. 21, Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan, Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. _ . _ Drill Out cement and 10' of new hole. Perform leak off test. Drill-8;1/_2" hole to logging point according to directional ~plan. Run. op.en_hol ~e_ evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel _ . . Shut' in and secure well, Clean location and release rig ............. ........ Fractu_re stimulate~weiL _ - - Reperfora _..~tio~;perfs~_;_ 7~;:-~ '--- _ ...... ' -- --. -- DRILLING FLUID PROGRAM (3G-22) Spud to 9-5/8" surface casina Density 8.6-10.0 PV 15-35 YP 15-35 Viscosity 50-100' Initial Gel 5-15 10 Minute Gel 1 5-4 0 APl Filtrate 1 0-1 2 pH 9-10 % Solids .... 10. +Ir.. Drill out to weioht UD 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7 Weight up 10.7 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System~ Triple Tandem Shale Shaker (2) Mud Cleaners Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1750 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-22 will be 3G-23. As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge--from--that point. Excess non-h_azardous~-~luids--devetoped-from well operations-and-those fluids necessa.-~~-~~.tl3e, fluid level in reserve pits will be pumped down the surface/~uction.?casinglannulUs. The annulus will be left with a non.freezing fluiddur~ng any extencied~s~-down in- pumping operations. The annulus will-bes_eal~with-t75-Sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. 7 I I I I I 13 5/8" 5000 BOP STACK ^(~C.,UMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 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 THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(XX) PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 6. TEST TO 250 PSI AND 3(X)0 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TESTANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'FI'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3(XX) PSI. 12. TEST KELLY COCKSAND INSIDE BOP TO 3(X)0 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16"- 2(X)0 PS! 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 PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 i~UPARUK RIVER UN~, 20" DIVERTER SCHEMATIC 6 4 3 ' OW - 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/ $. O00RMNAT£$ SHOWN AN£ A.$.IP ZQN~ ~ N~O 8?, VICINITY M~P i"~ ~ Mt. I0 FW, L, 0.0. PAD R4§' 48,? 84,0 PPO' 40,4 $4.0 195' 40. P 84.0 140' 47. p 83.4 8' 47.3 ~.t. O.~. 40' 47.1 PO' 46,9 53./ 95' 46,0 83.0 I PO' 46,~ 145' 4~.5 I PO' 46.4 5P.9 SUt~V~¥OR'S CKN?IFI · I HffRff~Y PERT/FY THAT ! AM NffOlSP~OffO AND LICeNSeD AND ~AT ?fils PLAT ~PPRffS~N~ M&D~ ~ M~ ~ UN~ MY OI~T [ ~ T~T ALL DigNifieS AND ~T~ILS AR~ ~~P AS OF ARCO ALASWA, IN¢, OWO. NO. ' NSDW. $$00, CEA .03GX.650700 oo.~o.'4 NO..'NSK $.$07d8 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE F e e pC, /oX hr (2) Loc (8) '(9 thru 13)" 10. z/q.~. ~rf, /o-~-~o 1~. (10 and 13), 12. 13. (4) Casg ~/,~,~,{, h -~- 9o (14 thru 22) (5) BOPE (23 thru 28) Company Is the permit fee attached .......................................... Lease & Well No. YES NO 2. Is well to' be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. /~ 4. Is well located proper distance from other wells .................... ~__ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ , . 7. Is operator the only affected party ................................. z~_ 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~,_ Is a conservation order needed ...................................... /~ Is administrative approval needed ................................... ~ ,, Is the lease number appropriate ..................................... ~,_ .. Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to~_~ psig .. Does the choke manifold comply w/A_PI RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. /vip (29 thru 31) (6) Add: Geolo ~y: DWJ ~ Eng ~ineering: LCS ~ BEW.-' rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT oN/OFF POOL CLASS STATUS AREA NO. SHORE ,, ,,. Additional Remarks: Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX, No special 'effort has been made to chronologically organize this category of information. -; · ,, (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/11/01 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: FEWD DATE: 90/11/01 ORIGIN OF DATA: 3G22 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** Anchorage ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G22.MWD SERVICE NAME: FEWD VERSION #: V3.26 DATE: 90/11/01 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-22// API: 50-103-20147// DATE: 29-0CT-90 LOCATION: 2538' FNL & 220' FEL, SEC. 23, TWP. 12N, RANGE 8E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA.// RIG: DOYON 14// CO. REP.: McCAULEY// COMMENTS: NEUTRON AND DENSITY ARE CALIPER CORRECTED. NO TOOL WEAR COMPENSATION REQUIRED. SLIDE INTERVALS ARE SEMI-QUANITATIVE. LOGS MADE AT ROPs GREATER THAN 180 FT/HR HAVE LESS THAN ONE DATA POINT PER FOOT. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 CAL MWD INCH 0 0 0 0 1 4 0 1 68 NFO MWD CTS 0 0 0 0 1 4 0 1 68 NFl MWD CTS 0 0 0 0 1 4 0 1 68 NN0 MWD CTS 0 0 0 0 1 4 0 1 68 NN1 MWD CTS 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 DDE MWD 0 0 0 0 1 4 0 1 68 GRC MWD API 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 NPSC MWD P.U. 0 0 0 0 1 4 0 1 68 RHOB MWD G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 ROP CAL NFO NFl NN0 NN1 FXE DDE GRC EWR NPSC RHOB MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD FT/H INCH CTS CTS CTS CTS HOUR API OHMM P.U. G/C3 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION DEPT FXE 3900.000 -999.250 4000.000 -999.250 4100.000 .767 4200.000 .394 4300.000 .481 4400.000 .615 4500.000 .671 4600.000 .503 4700.000 .625 4800.000 .579 4900.000 .560 5000.000 .652 5100.000 .445 5200.000 .545 5300.000 .573 5400.000 .845 5500.000 .510 5600.000 .968 5700.000 .592 5800.000 .762 ROP DDE -999.250 -999.250 -999.250 .653 403.372 .943 481.421 1.042 260.859 1.111 258.750 1.235 48.000 1.471 183.983 1.538 249. 141 2.214 199.716 .799 345.490 .952 187.822 .833 350.893 .813 328.125 .670 338.459 1.563 148.641 1.724 286.659 1.333 347.397 1.482 210.345 1.282 185.482 1.039 ( every CAL GRC 100 FT) NFO EWR -999.250 -999.250 -999.250 -999.250 8.591 48.594 404.000 17.890 10.191 70.882 489.000 6.548 8.730 97.798 580.333 4.934 8.599 84.761 561.667 4.719 8.641 74.949 583.000 5.838 8.558 68.017 532.333 14.038 8.704 77.406 532.333 6.904 8.769 92.875 588.333 6.309 8.668 92.092 539.000 4.146 8.607 97.376 535.000 3.818 8.871 76.691 499.000 3.779 8.649 92.075 527.000 4.658 8.538 95.322 572.714 3.379 8.622 123.036 615.000 3.848 8.829 79.026 537.667 3.452 8.567 80.679 623.000 4.231 8.682 91.246 674.200 3.885 8.633 94.380 543.000 3.340 8.720 75.225 564.333 3.160 NFl NPSC -999.250 -1049.212 412.000 53.645 511.000 47.949 559.000 37.975 532.333 40.381 559.000 37.814 501.000 41.624 567.000 38.666 540.333 36.964 547.000 39.277 567.000 40.521 501.667 43.462 543.000 38.983 594.428 37.522 583.000 35.821 508.333 39.217 631.000 31.701 645.400 30.204 583.000 35.532 545.667 35.164 NN0 RHOB -999.250 -999.250 2384.000 3.082 2360.000 2.078 2616.000 2.377 2546.667 2.253 2680.000 2.259 2498.667 2.266 2594.667 2.229 2728.000 2.230 2576.000 2.299 2440.000 2.286 2461.333 2.266 2568.000 2.259 2611.428 2.341 2696.000 2.346 2626.667 2.227 2904.000 2.471 2836.800 2.389 2712.000 2.321 2749.333 2.305 NN1 -999.250 2320.000 2232.000 2589.333 2509.333 2600.000 2562.667 2642.667 2600.000 2608.000 2616.000 2520.000 2696.000 2574.857 2536.000 2658. 667 2776.000 2923.200 2728.000 2856.000 5900.000 .449 6000.000 .538 6100.000 .764 6200.000 1.289 6300.000 .851 6400.000 .588 6500.000 1.062 6600.000 .773 6700.000 .636 6800.000 .601 6900.000 .674 7000.000 .626 7100.000 3.667 7200.000 .609 7300.000 .495 7400.000 1.171 7500.000 1.136 7600.000 .585 7700.000 .704 7800.000 .744 7900.000 .986 800O.000 .630 8100.000 .732 230.713 1.852 273.842 1.333 311.865 1. 176 234.338 1.493 156.226 5.556 210.937 1.439 198.633 1.075 294.907 1.235 202.930 .980 236.959 1.887 222.725 -999.250 236.536 1.399 213.965 1.343 214.063 1.316 233.724 1.471 201.953 3.846 110.369 1.493 148.500 1.389 253.125 1.505 181.222 1.746 228.516 1.818 123.249 1.754 235.986 2.381 8.907 105.134 8.732 108.412 8.732 78.876 8.815 80.665 8.899 74.973 8.699 132.780 8.647 107.537 8.736 107.646 9.042 114.065 8.692 124.636 9.005 140.140 8.658 164.570 8.828 129.793 9.144 116.846 8.872 119.786 8.643 99.162 8.597 94.519 8.986 113.331 8.551 92.870 8.851 94.529 8.819 95.791 8.665 96.976 8.913 93.262 596 3 615 3 615 3 649 4 607 3 671 5 567 2 591 2 625 2 615 2 615 2 703 5 615 4 607 4 607 4 575 4 612 4 619 4 569 4 615 4 599 4 623 4 671 4 .333 .114 .0O0 .991 .000 .699 .667 .002 .000 .508 .000 .131 .O00 .314 .0OO .439 .667 .749 .000 .928 .000 .346 .00O .009 .0O0 .728 .00O .726 .O0O .917 .000 .111 .333 .061 .000 .070 .667 .009 .000 .105 .O0O .413 .000 .544 .000 .580 591 37 671 34 599 32 641 29 635 30 655 34 575 37 548 37 572 36 636 35 615 35 695 35 595 38 591 38 551 38 639 34 620 34 619 34 588 35 612 33 631 33 603 33 639 30 .00O .031 .000 .062 .000 .434 .667 .045 .000 .664 .000 .735 .000 .952 .333 .574 .333 .094 .333 .717 .00O .304 .0OO .347 .000 .875 .000 .276 .000 .475 .000 .509 .333 .348 .000 .219 .333 .018 .333 .149 .000 .481 .000 .267 .O00 .720 2669.333 2.313 2712.000 2.201 2808.000 2.320 3053.333 2.443 2880.000 2.414 2648.000 2.360 2648.000 2.289 2669.333 2.536 2637.333 2.478 2605.333 2.360 2664.000 2.363 2488.000 2.447 2480.000 2.319 2573.333 2.511 2504.000 2.431 2680. 000 2.364 2728.000 2.325 2672.000 2.476 2738.667 2.362 2776.000 2.531 2792.000 2.404 2808.000 2.407 2888.000 2.558 2552.000 2696. 000 2840.000 2946.667 2976.000 2600.000 2568.000 2589.333 2637.333 2600.000 2568.000 2536.000 2488.000 2488.000 2600.000 2632.000 2696.000 2760.000 2754.667 2781.333 2744.000 2752.000 2776.000 8200.000 .622 205.469 8.786 571.000 579.000 2616.000 1.299 108.408 4.611 36.649 2.465 8300.000 .771 222.518 8.442 639.000 559.000 2760.000 1.449 116.240 4.706 34.968 2.380 8400.000 2.250 138.281 8.600 601.667 596.333 2664.000 1.588 116.297 4.178 35.928 2.318 8500.000 1.324 162.330 8.865 567.000 575.000 2584.000 4.762 133.202 3.986 38.917 2.291 8600.000 .747 214.453 8.700 663.000 643.000 2848.000 4.762 82.826 5.992 30.021 2.421 8700.000 1.020 140.084 8.770 625.000 599.000 2744.000 1.667 88.799 4.728 33.833 2.380 8800.000 .596 216.935 9.038 593.667 564.333 2530.667 1.351 129.486 4.236 39.281 2.504 8900.000 1.040 182.285 8.799 711.000 735.000 2568.000 2.703 205.641 3.287 34.071 2.330 9000.000 .694 209.961 8.667 679.000 719.000 2552.000 1.852 180.881 4.815 34.663 2.330 9100.000 .618 165.874 8.686 520.000 535.000 2360.000 3.226 96.986 3.015 44.941 2.362 9200.000 .840 182.285 8.858 503.000 511.000 2472.000 1.408 123.045 3.734 42.981 2.444 9300.000 14.502 158.509 9.862 465.000 489.000 2376.000 14.286 88.901 2.963 35.552 2.490 9400.000 1.545 49.002 8.719 655.000 663.000 3160.000 8.333 49.827 25.054 29.120 2.380 9500.000 1.655 28.868 8.825 535.000 551.000 2520.000 5.882 81.289 5.189 38.599 2.389 9600.000 1.938 38.483 8.839 527.000 551.000 2552.000 7.692 91.234 4.726 40.161 2.423 9700.000 2.024 34.413 8.756 591.000 551.000 2664.000 11.111 94.966 3.798 38.632 2.395 9800.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 627 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: 3G22.MWD SERVICE NAME: FEWD VERSION #: V3.26 DATE: 90/11/01 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 -999.250 -1049.212 3900.00 TO -999.250 -999.250 9850.00 FT 2712.000 2632.000 2648.000 2552.000 2968.000 2772.000 2493.333 2552.000 2648.000 2360.000 2520.000 2344.000 2968.000 2600.000 2536.000 2552.000 -999.250 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: FEWD DATE: 90/11/01 ORIGIN OF DATA: 3G22 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/11/01 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********
