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198-253
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. / ~0¢'/~-'¢ ~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages:/Z_~ ~-~" Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned b~ildred Daretha Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Isl r STATE OF ALASKA ALA OIL AND GAS CONSERVATION COASION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell ' Plug Perforations r Perforate r Other r Alter Casing r••" Rill Tubing r• Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory f " 198 - 253 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 _ 50 103 - 20283 00'00 7. Property Designatigp (Lease Number): 8. Well Name and Number: ADL 25569 2T - 220 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): —• none Kuparuk River Field / Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 5752 feet Plugs (measured) none true vertical 3509 feet Junk (measured) None Effective Depth measured 5527 feet Packer (measured) 2540, 4852' true vertical 3355 feet (true vertucal) 1947, 2974 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 112 112 SURFACE 4953 9.625 4990 3045 GRAVEL PACK 677 4 5529 3356 RECEIVED LINER JUL 2 4 2012 Perforation depth: Measured depth: 4961 - 5517' AOGCC True Vertical Depth: 3030' - 3348' Tubing (size, grade, MD, and TVD) 4.5, L - 80, 4588 MD, 2840 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER TWIN SEAL ESP PACKER @ 2540 MD and 1947 TVD PACKER - BAKER MODEL SC -1 GRAVEL PACK PACKER @ 4852 MD and 2974 TVD SSSV - CAMCO DS NIPPLE @ 512 MD and 511 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - in Subsequent to operation shut - in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development )W Service r Stratigraphic r 16. Well Status after work: .. Oil P' Gas r WDSPL t Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r" SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Erik Nelson @ 263 -4693 Printed Name Erik Nelson Title Sr. Wells Engineer Signature /' Phone: 263 -4693 Date ..- Z V;( 0 ReDMS JUL 25 2012 AK yt Form 10-404 Revised 11/2011 l ' N,, \ 1 • �� 11,--- Submit Original Only KUP • 2T -220 Conoc 0-4 Well Attributes Max Angle & MD TD a Wellbore APIAWI Field Name Well Status Ind(*) MD (ftKB) Act Btm (ftKB) 501032028300 TABASCO PROD 66.55 2,958.69 5,7520 "°" Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••• WeilCOntiq' - 2T - 220, 723I20127:14:35AM SSSV: NIPPLE 50 6/18/2009 Last WO: 7/6/2012 36.81 1/18/1999 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: ELMD 4,699.0 11/8/2008 Rev Reason: WELL REVIEW osborl 7/23/2012 HANGER 28 - ---I, Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String .. String Top Thrd CONDUCTOR 16 15.062 38.0 112.0 112.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 37.0 4,990.0 3,044.5 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 6 5,529.0 5,752.0 3,509.4 CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (6... Set Depth (TVD) ... String Wt... String ... String Top Thrd 38 -112 GRAVEL PACK 4.63 4.000 4,851.7 5,529.0 3,356.1 11.60 L -80 SealLock LINER Liner Details NIPPLE, 512 Top Depth (TVD) TopIncl Nomi... Top (ftKB) (ftKB) 1 ° ) Item Description Comment ID (In) 4,851.7 2,973.6 59.35 PACKER BAKER MODEL SC -1 GRAVEL PACK PACKER 4.750 4,861.6 2,978.6 59.39 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 4.875 4,863.8 2,979.7 59.40 SBE BAKER SEAL BORE 4.750 1 1 Q 4,885.1 2,990.5 59.50 KOIV BAKER MODEL 'B' KOIV (2) 3.437 4,961.4 3,029.5 58.87 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 5,517.2 3,348.5 50.21 0 -RING BAKER 0 -RING SUB 2.375 5,518.3 3,349.2 50.18 VALVE BAKER FLAPPER VALVE (2) 2.875 ESP MANDREL, :IC ,. Tubing Strings 2.419 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... Sting ... String Top Thrd ESP TUBING WO 4 1/2 3.958 28.4 4,588.1 2,839.7 12.60 L -80 IBTM Completion Details Top Depth (TVD) Top Inc. Nomi... PACKER, 2,540 Top (ftKB) (ftKB) ( Item Description Comment ID (in) 28.4 28.4 -0.58 HANGER FMC MODEL120 -11' x 4.5" ESP HANER 3.958 lir 512.0 510.9 9.39 NIPPLE CAMCO DB NIPPLE 3.812 IIII 2,540.3 1,947.3 63.65 PACKER BAKER TWIN SEAL ESP PACKER 3.970 ill 2,692.9 2015.5 63.32 NIPPLE CAMCO DB NIPPLE, PN - 100101390 3.750 MANDREL. Mt 4,507.5 2,798.7 59.65 GAUGE WELL LIFT DISCHARGE GAUGE UNIT 3.985 2537 4,515.0 2,802.5 59.60 X0 Reducing CROSSOVER 4.5 x 3.5, 9.3#, L -80, EUE8RD 3.500 4,524.7 2,807.4 59.53 DISCHARGE CENTRILIFT DISCHARGE HEAD 513 SERIES 3.985 WE 4,525.2 2,807.7 59.53 PUMP CENTRILIFT 56 STAGE P62 -538 PMSXD 056 P62 FER 12 CRC PUMP 4,544.1 2817.3 59.40 INTAKE CENTRILIFT AR DESIGN PUMP INTAKE NIPPLE, 2.693 OE 4,5452 2,817.8 59.39 SEALS CENTRILIFT TANDEM SEAL SECTION 4,559.0 2,824.1 57.91 MOTOR CENTRILIFT 562 MSP 336/2650/78 16R ESP MOTOR 4,584.3 2,837.7 58.34 GAUGE WELL LIFT MGU ilig 4,586.1 2,838.6 58.37 Centralizer MOTOR CENTRALIZER GAUGE.4,507 loweleer Perforations &Slots _ i l l Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (MB) (ftKB) (ftKB) Zone Date Oh- Type Comment It 4,961.4 5,517.0 3,029.5 3,348.3 TABASCO, 7/8/1999 99.0 SLOTS OPEN HOLE GRAVEL PACK TE1, 2T -220 SCREENS DISCHARGE, 4,525 � Notes: General & Safety PUMP, 4,525 . ,yq End Date Annotation INTAKE. 4,544 6/9/2004 NOTE: ESP WORKOVER SEALS, 4,545 ,. 3/29/2009 NOTE: ESP WORKOVER 4/17/2009 NOTE: View Schematic w/ Alaska Schematic9.0 MOTOR, 4,559 6/14/2012 NOTE: LEAK FOUND IN TREE w/ HES LDL GAUGE, 4,584 Centralizer. 1 4,586 w. ii , Mandrel Details Top Depth Top Port (TVD) Inc. OD Valve Latch S.ze TRO Run Stn Top (NKB) (ftKB) 11 Make Model (.n) Sery Type Type (.n) (psi) Run Date Corn... 1 2,419.4 1,891.8 63.46 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 7/6/2012 2 2,637.2 1,990.5 63.36 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 7/6/2012 SURFACE, 37- 4,990'' SLOTS, 4,9615,517 4. MEM GRAVEL PACK LINER, 4,852 -5,529 OPEN HOLE, 5,529 -5,752 TD (2T -220). 5.752 2T -220 Pre -Rig Well Work Summary DATE ' SUMMARY 2/5/12 PULLED CATCHER SUB & OA " DBP PLUG FROM DB NIPPLE @ 2893' KB. MEASURED BHP @ 2890' RKB: 894 PSI. COMPLETE. 3/30/12 T -POT (PASSED), P -PPPOT (PASSED), BLEED IA DOWN FOR IA DD TEST (FAILED) 4/1/12 SET 3.75" DBP PLUG IN DB NIPPLE © 2893' RKB. POSITIVE AND NEGATIVE TESTS PASSED. COMPLETE. 4/2/12 IA DRAWDOWN TEST FAILED 4/5/12 AC EVAL 4/10/12 PULLED 3.75 DBP PLUG @ 2893' RKB, SET 3.75 DBP PLUG @ 2893' RKB & TESTED (PASS) JOB COMPLETE 4/11/12 PRESSURE UP IA TO 1000 PSI AND MONITOR FOR 2 HRS. 4/13/12 TROUBLE SHOOT WELL FOR LEAKS, MIT -IA TO 1000 PSI FAILED (LLR = -0.42 gpm) T. & IA DDT FAILED 5/25/12 SET CATCHER @ 2860' SLM. PULLED DV FROM 2556' RKB, LEFT POCKET OPEN. PULLED CATCHER. PULLED P PLUG ON 3.75" DB LOCK FROM 2893' RKB. COMPLETE. 6/8/12 SPOT UP EQUIPMENT, ASSIST PULLING BPV, IN PROGRESS. 6/12/12 SET 1 "DV @ 2556' RKB, CONFIRMED VALVE SET WITH CHECK SET TOOL. READY FOR E -LINE. COMPLETE. 6/14/12 PERFORMED LEAK DETECT LOG FROM A DEPTH OF 2800' TO SURFACE. LRS ESTABLISHED A RATE OF 0.15 BPM AT 1000 PSI DOWN THE TUBING. * ** DISCOVERED THAT LRS WAS RIGGED INCORRECTLY TO THE TUBING SIDE OF THE HORIZONTAL WELLHEAD AND WAS PUMPING DOWN THE TUBING TO FORMATION * * *. WILL RETURN WITH ELINE TO PERFORM LEAK DETECT WHILE PUMPING DOWN IA. 6/15/12 (AC EVAL) T POT- PASSED; TPPPOT- PASSED; TORQUED LDS; CALLED FOR VR TO BE PULLED FROM IA CASING VALVE. 6/16/12 PERFORMED LEAK DETECT LOG FROM 2800' TO SURFACE LOOKING FOR A LEAK IN THE IA. RESULTS WERE INCONCLUSIVE. TEMPERATURE ANOMALY WAS OBSERVED IN THE PACKER AREA. 2 TEMPERATURE BASELINE AND FLOWING PASSES WERE PERFORMED. 6/17/12 PULLED DV @ 2556' RKB. COMPLETE. • • ©noc ©Phifiips Time Log & Summary WelMew Web Reporting Report Well Name: 2T - 220 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/28/2012 1:00:00 AM Rig Release: 7/7/2012 9:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/28/2012 24 hr Summary MIRU Nordic Rig 3. Pull BPV and Circulate Well to 8.9 ppg KWF. 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Move Nordic Rig 3 from 2T -209 to 2T -220 01:00 03:30 2.50 , 0 0 MIRU MOVE RURD P Spot cuttings box, hook up hardline, spot auxiliary equipment and Load pits w/ Filtered 8.9 ppg 3 % KCL Brine. 03:30 04:30 1.00 0 0 COMPZ WHDBO MPSP P PJSM, Lubricate out BPV and lay down lubricator. 04:30 05:30 1.00 0 0 COMPZ WELCTL OTHR P RU circulating hoses, while blending Filtered 8.9 ppg 3% KCL in pits. 05:30 06:00 0.50 0 0 COMPZ WELCTL PRTS P Load kill line to kill tank and pressure test same at 250 / 3,500 psi. 06:00 08:30 2.50 0 0 COMPZ RPCOM KLWL P Held PJSM with crew on killing well. Open up well and obtain 230 psi IA, 230 psi TBG. Reverse Circulate 200 bbls of filtered 8.9 ppg 3% KCL brine at 2 bpm at 60 psi ICP, FCP at 140 psi. 8.9 ppg in and 8.9 ppg out with 200 bbls recovered. 08:30 11:00 2.50 0 0 COMPZ RPCOM OWFF P Monitor well - 20 psi on TBG / Top pits with filtered 8.9 ppg 3% KCL brine while monitoring well. 11:00 16:30 5.50 0 0 COMPZ RPCOM KLWL P Reverse Circulate at .25 bpm at 180 psi ICP returning gas at 210 psi Full open choke, seen 600 psi on pump side and 500 psi max on choke pressure. Unloaded and increase pump rate to 2 bpm till clean fluid at choke. Close in IA, Bullhead at 210 bbls at 2 bpm at 1,300 psi - SWI - 640 psi IA; 500 psi TBG 16:30 20:30 4.00 0 0 COMPZ RPCOM OWFF P Monitor Well, after 4 Hours, Ann Press 130 psi, Tbg 40 psi. 20:30 23:30 3.00 0 0 COMPZ RPCOM CIRC P PJSM, Circulate 287 bbl Down Tbg, Up IA at 2 bpm. ICP 60 psi, FCP 100 psi. 23:30 00:00 0.50 0 0 COMPZ RPCOM OWFF P Shut in Well and Monitor- Pressure up to 20 psi on Tbg and 15 psi on Annulus in first Minutes. Load Pits continue to Monitor. Pressure Slowly Dropping, Diesel slight Flow from IA. 06/29/2012 Weight up to 9.0 ppg KWF and Re- Circulate, SL Set Rua in DB Nipple and Pull and Reset DVs in GLMs after Circ Out Page 1 of 11 • • Time Logs Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 COMPZ RPCOM OWFF P Continue to Monitor Well and Load Pits w/ 8.9 ppg KWF. Diesel Slight Flow from IA and 0 Flow from Tbg. 02:00 03:00 1.00 0 0 COMPZ RPCOM CIRC P Circulate 103 bbls of 8.9 ppg KWF Down Tbg with Ret Up IA at 2 bpm. Returns Clean Up after 10 bbls. 03:00 05:30 2.50 0 0 COMPZ RPCOM OWFF P Monitor Well, Static- Notify FMC Wellhead Hand, Load Pits, Load Lubricator, Blow Down Hardline 05:30 06:00 0.50 0 0 COMPZ RPCOM MPSP P Prepare to Set BPV and Well not passing No Flow Test 06:00 09:30 3.50 0 0 COMPZ RPCOM OWFF P Monitor Well and Pressures Up to 20 psi on IA/Tbg, wait on SL 09:30 12:00 2.50 0 0 COMPZ RPCOM SLKL P PJSM, Spot and RU SL Unit, PT Lubricator to 500 psi, OK 12:00 13:00 1.00 0 0 COMPZ RPCOM SLKL P RIW w/ 3.80 GR to 2864' SLM, POOH 13:00 15:00 2.00 0 0 COMPZ RPCOM CIRC P PJSM, Circ 150 bbls of 9.0 ppg Brine down IA up Tbg @ 2 bpm, Bullhead 72 bbls 15:00 17:00 2.00 0 0 COMPZ RPCOM SLKL P RIH w/ 3.75 Plug in DB Nipple at 2864' SLM, Set Catcher on Plug, Set DV in upper GLMat 2556' 17:00 22:00 5.00 0 0 COMPZ RPCOM SLKL P PJSM w/ SL, Make two attempts to Pull DV from GLM at 2837', unsucessful. 22:00 23:30 1.50 0 0 COMPZ RPCOM PRTS P Pressure up Tbg and Shear out SOV at 1700 psi 23:30 00:00 0.50 0 0 COMPZ RPCOM SLKL P RIH with SL and pull SOV from 2837' 06/30/2012 Finish Well Kill, Install BPV, Nipple Down Tree, Nipple up BOPE and Test 250 / 3500 psi. Pull BPV/ Blanking Plug, UnLand Hanger and Shear Packer, RU SL to Plu from DB Nipple 00:00 02:00' 2.00 0 0 COMPZ RPCOM CIRC P Bullhead 147 bbls of 9.0 ppg Brine down Tbg through GLM #2 at 2 bpm. ICP 530 psi, FCP 1000 psi. 02:00 03:00 1.00 0 0 COMPZ RPCOM SLKL P Set Dummy Valve in GLM at 2837' 03:00 04:30 1.50 0 0 COMPZ RPCOM PRTS P PJSM, PT Tbg- Slow Linear Leakoff. 04:30 05:30 1.00 0 0 COMPZ RPCOM SLKL P Rig Down Slick Line 05:30 06:00 0.50 0 0 COMPZ RPCOM PRTS P Perforn No Flow Test for 30 minutes on Tbg. No Flow Observed 06:00 06:30 0.50 0 0 COMPZ WHDBO MPSP P PJSM, Dry rod and Set BPV 06:30 08:00 1.50 0 0 COMPZ WHDBO NUND P PJSM, ND FMC Horizontal Unihead, Install Blanking plug. 08:00 10:30 2.50 0 0 COMPZ WHDBO NUND P PJSM, NU Nordic 11" 5M Class III stack, Install riser 10:30 16:00 5.50 0 0 COMPZ WHDBO BOPE P RU test equipment - Shell test - work air from system and observe for leaks. Test BOP w/ 4 1/2 Test joint at 250 / 3,500 psi. RD Test equipment. 24 hr notice was given at 16:45 hrs on 6 -27 -12 and Right to witness was waived by Lou Grimaldi at 06:20 hrs on 6- 30 -12. Page 2 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:00 2.00 0 0 COMPZ RPCOM MPSP P PJSM, Pull Blanking p!'11. Prepare to MU Landing Joint 18:00 19:30 1.50 0 0 COMPZ RPCOM PACK P PJSM, MU Landing Joint, Back Out Lock Down Screws, Pull Hanger, Shear out of Packer at 215k #, Reland Hanger and RILDS, Monitor IA- Slowly comes up to 20 psi. 19:30 23:00 3.50 0 0 COMPZ RPCOM SLKL P PJSM, Start Rig Up Slickline, Changeout Long Nose Landing Joint (3.25" ID) to Short Nose Landing Joint w /out Side Port Isolation Sleeve (3.81" ID), PT SL Lub 1500 psi, RIH w/ 4 -1/2 GS to 2885' SLM and Recovered Catcher Sub 23:00 23:30 0.50 0 0 COMPZ RPCOM SLKL P PT Lubricator 1500 psi, SL Revover Prong at 2888' SLM 23:30 00:00 0.50 0 0 COMPZ RPCOM SLKL P PT Lubricator 1500 psi, SL RIH With Plug Retrieval Tool 07/01/2012 SL Retreive Plug from DB Nipple, Circulate 509 bbls 9.0 ppq KWF BU, Tally out of Hole with ESP Completion to 3850' 00:00 01:00 1.00 0 0 COMPZ RPCOM SLKL P SL POOH with Plug from DB Nipple. 01:00 02:00 1.00 0 0 COMPZ RPCOM SLKL P Changeout Landing Joint to Long Nose Landing Joint w/ Side Posrt !so Sleeve (3.25" ID) , RD SL 02:00 06:00 4.00 0 0 COMPZ RPCOM CIRC P PJSM, Circulate 360 bbls of 9.0 ppg Brine down Tbg taking Returns up IA to kill tank. ICP 1 bpm @ 120 psi, 2 bpm 340 psi, 3 bpm @ 1200 psi. At 360 bbls pumped, shut down to strap Tiger Tank, recovered 16 bbls back 06:00 09:00 3.00 0 0 COMPZ RPCOM CIRC P Held PJSM. RU hoses to reverse circulate and mix 30 bbl 2.5 ppb 9.0 sweep. Reverse circulate 3.5 bbls of sweep and pressure up to 1,450 psi with in 75 stks. Shut down and bleed off - call out FMC to BOLDS. 09:00 10:00 1.00 0 4,785 COMPZ RPCOM OTHR P Held PJSM, RU to pull hanger, BOLDS and pull hanger 4 -ft above hanger bowl at 110k up wt. Leave hanger off seat. 10:00 12:15 2.25 4,785 4,785 COMPZ RPCOM CIRC P Held PJSM, Circulate 75 bbls of 9.0 ppg Filtered Brine at 1.5 bpm at 240 psi taking returns to kill tank. Recovered 85 bbls - One for one returns. Load pits and empty kill tank in preparation for circulating 1 1/2 Hole volume of 420 bbls. Page 3 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 17:00 4.75 4,785 4,785 COMPZ RPCOM CIRC P Held PJSM, Pump 26.5 bbls of remaining sweep and chase with 345 bbls of Filtered 9.0 ppg brine at 1.5 bpm at 240 psi w/ returning at 40 psi thru full open choke. Recovered 340 bbls in kill tank. Continue to circulate 72 bbls at 1.5 bpm at 200 psi taking sweep to cuttings box and returns thru Gas buster to cuttings box. final returns were 9.0 ppg w/ 28 visc. 17:00 18:00 1.00 4,785 4,785 COMPZ RPCOM OWFF P Monitor well for flow on trip tank, RD Top drive and FOSV 18:00 21:30 3.50 4,785 4,755 COMPZ RPCOM PULL P PJSM, Prepare for Decompletion. Bring Hanger to Floor, Up 150 -100k# and 60k# Down. Meg Cable- Good. Lay Down Hanger and Landing Joint. 21:30 00:00 2.50 4,755 3,580 COMPZ RPCOM PULL P POOH with Completion, Weight swings steady out Up 98k #, but still occasional Overpulls 50k# -10k# over Up Weight. At 3580', Up Weight 80k #. 07/02/2012 Finish Tallying out of Hole with ESP Completion, Lat down Packer and inspect, RIH with new Completion String 00:00 03:30 3.50 3,580 2,104 COMPZ RPCOM PULL P Continue POOH 3580', Up 80k# with ESP. At Packer, 65k# up. Find Packer Feed Thru Penetrator O -Rings Cut. Videos and Pictures in Anc Rig Folder. 03:30 05:00 1.50 2,104 1,890 COMPZ RPCOM PULL P Continue POOH from 2104', Up wt at 1890' 63k# up. 05:00 05:30 0.50 1,890 1,890 COMPZ RPCOM OTHR P Strap Decompletion and Prepare to Run Completion. 05:30 07:00 1.50 1,890 2,022 COMPZ RPCOM TRIP P PJSM, RIH w/ Completion from 1,890 -ft to 2022 -ft 07:00 12:00 5.00 2,022 2,047 COMPZ RPCOM OTHR P Meg cable - good and Make lower packer splice, (cable cut was 2 -ft to short), Pull 1st joint below packer and replace w/ 10 -ft pup joint. Continue to make packer splice. Meg cable. 12:00 17:00 5.00 2,047 4,666 COMPZ RPCOM TRIP P RIH w/ 1 stand and install 2nd GLM Assy. Continue to RIH 21 stands of 4 1/2" 12.6 #, L -80 IBT -M TBG from derrick to 4,144 -ft, PU 1 jt and install 3.812" "DB" Nipple assy. Continue to RIH w/ 5 stands of 4 1/2" 12.6#, L -80 IBT -M TBG from derrick to 4,666 -ft. Page 4 of 11 • • Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 17:00 21:00 4.00 4,666 4,666 COMPZ RPCOM OTHR P PU and MU FMC TC -BH- EMS- EC -HT, 11" X 4 1/2" MOD API BTBG bottom x 5.000- 4SAM2 -2G RH Acme Top w/ CIW "H" bpvt. Compression Pack off bottom. 5,000 SBMS prep. (Manufacturer PN: P125725 -0001) TBG hanger. Check BIW ESP Penetrator (Manufacturer PN: C85A5104) - (HO: 82605) Check BIW Heat Trace Penetrator port (Manufacturer PN: EMH1609 -4) - (HO: 82550), Check BIW I -Wire Penetrator (Manufacturer PN: EWC1828 -2P) - (HO: 82533) Make Final splice 21:00 00:00 3.00 4,666 4,666 COMPZ RPCOM OTHR T Attempt to Attach Lower Pig Tail below Hanger and find Incorrect Pig Tail Connection. Had to Resplice. 07/03/2012 Land Hanger, Attempt to Set Packer, Pressure Test Fail, Troubleshoot Failed Test with SL 00:00 00:30 0.50 4,666 4,666 COMPZ RPCOM OTHR T Continued...Attempt to Attach Lower Pig Tail below Hanger and find Incorrect Pig Tail Connection. Had to Resplice. 00:30 01:00 0.50 4,666 4,666 COMPZ RPCOM HOSO P Land Hanger, Run In Lock Down Screws, Test Packoffs 5000 psi, OK 01:00 02:15 1.25 4,666 4,666 COMPZ RPCOM SFTY P Prepare to Pump Diesel Down Tbg, PJSM with LRS, PT Lines 1500 psi, OK 02:15 04:00 1.75 4,666 4,666 COMPZ RPCOM CIRC P Start Bullheading Diesel Down Tbg at 1 bpm, Pressure builds from 400 psi to 680 psi after 30 bbls away. Crack IA taking Returns to Kill Tank and continue pumping Down Tbg up IA 1 bpm - 380 psi. Pump Total of 70 bbls 04:00 04:30 0.50 4,666 4,666 COMPZ RPCOM OTHR P Shut Down LRS, Bleed Back Pressure, Blow Down Kill Line 04:30 09:00 4.50 4,666 4,666 COMPZ RPCOM SLKL P PJSM, RU Slick Line and PT lubricator at 1,500 psi. RIH w/ 3.735" OD Guage Ring to 2,801 -ft slm and set down at 3.562" Camco "DB" Nipple. POOH. RIH w/ 3.562" Plug and set @ 2,803 -ft slm, POOH. RIH w/ Prong and set @ 2,803 -ft slm. POOH. Negative test plug for flow for 15 minutes. 09:00 12:30 3.50 4,666 4,666 COMPZ RPCOM PRTS P RU and PT lines to 3,500 psi w/ LRS. Pump 29 bbls CI 9.0 ppg at 1.5 bpm at 500 psi (ICP) and 2 bpm at 1,100 psi (FCP). Follow with 140 bbls of gelled Diesel at 2 bpm at 800 psi (ICP) and 1.7 bpm at 1,350 psi (FCP). TBG pressure rose to 900 psi during the FP operation, bleed back to zero psi prior to finishing pumping operation. Page 5 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 15:00 2.50 4,666 4,666 COMPZ RPCOM PACK P Pressure up to 3,000 psi and bleed IA pressure back to 20 psi - flowing, (Recovered 20 bbls of diesel in kill tank) Shut in IA. TBG bled back to 2,500 psi, bring pressure back up to 3,100 psi on TBG w/ same results, increase TBG pressure up to 3,500 psi - seen indications of pin shears at 2,250 psi +/- on 6,000 psi gauge on top of TBG. TBG pressure fell form 3,500 psi to 2,300 psi and IA pressure climbed to 250 psi in 5 minutes - bleed off pressure and reroute pump lines in order to eliminate surface squeeze manifold. Open up well and obtain pressures after being SI for 60 minutes - Zero TBG psi and 250 IA Psi. Attempt to pressure up TBG to 2,500 psi - TBG still bleeds off and IA remained at 250 psi. Bleed TBG to 1,290 psi and Attempt to pressure up on the IA - pumping at .5 bpm at 340 psi for 1 bbl - shut down and bleed back to 260 psi slowly. Bleed pressure of TBG to Zero and monitor for IA by TBG communication - none seen. Suspend operations and call Town Engineer. 15:00 21:30 6.50 4,666 4,666 COMPZ RPCOM SLKL T PJSM w/ HES. RIH w/ Dogless "GS" to 2,803 -ft and spank down to verify prong is in place. Pressure up to 1,000 psi, lost 100 psi in 5 minutes while POOH. RIH w/ 4 1/2" D and D Hole finder to 2,800 -ft. Set Holefinder at 2796' SLM- PT Tbg 950 psi- Fail. Set Holefinder at 2690' SLM- PT Tbg 950 psi- Fail. Set Holefinder at 2590' SLM- PT Tbg 950 psi- Pass, Pressure up to 1350 psi, Pass. POOH with Hole Finder and Redress. Page 6 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 4,666 4,666 COMPZ RPCOM SLKL T RIH with Hole Finder to attempt to narrow down leak area. Set Holefinder at 2690' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2670' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2660' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2655' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2648.5' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2645' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2640' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2618' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2585' SLM- PT Tbg 1000 psi- Fail. Set Holefinder at 2560' SLM- PT Tbg 1000 psi- Fail 07/04/2012 Troubleshoot failed Pressure Test of Completion, Circulate around 9.0 ppg KWF, Prepare to pull and rerun Complertion. 00:00 01:00 1.00 4,666 4,666 COMPZ RPCOM SLKL T POOH with Slickline D &D Hole Finder. Redress and Reconfigure Toolstring with Centalizers and Rollers. 01:00 13:30 12.50 4,666 4,666 COMPZ RPCOM SLKL T RIH with Run 3 of the D &D Hole Finder. Set Hole finder at 2685' SLM- PT Tbg 1000 psi- Fail. Set Hole finder at 2669' SLM- PT Tbg 1000 psi- Fail. Set Hole finder at 2659' SLM- PT Tbg 1000 psi- Fail. Set Hole finder at 2654' SLM- PT Tbg 1000 psi- Fail. Set Hole finder at 2648.5' SLM- PT Tbg 1000 psi- Fail. Set Hole finder at 2644' SLM- PT Tbg 1000 psi- Fail. Set Hole finder at 2615' SLM- PT Tbg 1000 psi- Fail. Set Hole finder at 2580' SLM- PT Tbg 1000 psi- Pass. Pull out of Hole. RIH w/ 3" Gauge ring and pull prong from 3.562" "DB" "P" plug at 2,801 -ft SLM. ( had 500 psi on TBG and dropped to 240 psi) POOH, inspect prong -good. RIH w/ new prong and install at 2,801 -ft. PT at 1,000 psi, had a 600 psi drop in 10 minutes. POOH. RIH w/ 3.78" OD Catcher sub and located packer mandrel - oops, POOH and RIH w/ 3.71" OD and drop off at 2,796 -ft. SLM. POOH and RIH w/ KO tool and pull DV from station #2 at 2,754 -ft SLM w/ 500 psi on TBG and 175 psi on IA. Pull DV and seen equalization between IA and TBG. POOH. Hang back Slick line. Page 7 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 16:00 2.50 4,666 4,666 COMPZ RPCOM CIRC T PJSM, Circulate 63 bbls of 9.0 ppg filtered Brine at 2 bpm at 50 psi thru open pocket at 2,749 -ft. Recover 65 bbls at kill tank. 1 to 1 returns. Continue to circulate at 2 bpm at 60 psi for 135 bbls and recovered 139 for 135 bbls pumped. 16:00 21:00 5.00 4,666 4,666 COMPZ RPCOM SLKL T RU slick line and RIH w/ KO tool and set DV in Station #2 at 2,754 -ft SLM - Pressure TBG to 1,000 psi and Shear off DV. POOH and change over to "GS" and RIH to 2,796 -ft. Engage and POOH w/ 3.71" OD catcher sub. Change over and RIH and engage prong, POOH w/ Prong and seen no PSI differential change. RIH and recover DB "P" Plug. RD Slick line and release unit. 21:00 00:00 3.00 4,666 4,666 COMPZ RPCOM CIRC T PJSM, Check Fluid Paths, Blow Down Hardline, Pump 35 bbls 2 ppb Hi -Vis Sweep down Tbg returns up IA. Circulate 9.0 ppb Brine at 3 bpm down Tbg, Returns up IA to Kill Tank. ICP = 680 psi 07/05/2012 Finish Circulating around 9.0 ppg KWF, Pull Baker ElecPak ESP Completion, and Prepare to Run Baker Twin Seal ESP Packer Completion 00:00 01:00 1.00 4,666 4,666 COMPZ RPCOM CIRC T Continue Circulating 9.0 ppg Brine KWF at 3 bpm Down Tubing up IA to Kill Tank. At 400 bbls pumped, returns to Pits. FCP - 306 psi. Total 500 bbls pumped. 01:00 03:30 2.50 4,666 4,666 COMPZ RPCOM OWFF T Monitor Well, PJSM, Rig Down Hoses, Tie in Kill and Choke to BOP 03:30 05:00 1.50 4,666 4,666 COMPZ RPCOM PRTS T MU Landing Joint. Test Kill and Choke Lines 250 / 3500 psi. Chart and Rig Down and blow down Hardline 05:00 05:30 0.50 4,694 4,666 COMPZ RPCOM PULL T PJSM, BOLDS, Pull Hanger, Overplus and Shear Release Packer at 167k# and 96k# Up Weight, Pull Hanger to Floor. 05:30 08:00 2.50 4,666 4,572 COMPZ RPCOM OTHR T Meg ESP Cable, OK. - Pull hanger and lay down, Pull 1 stand to 4,572 -ft and string ESP cable over sheave. 08:00 13:30 5.50 4,572 2,025 COMPZ RPCOM TRIP T POOH to ElcPak Packer to 2,685 -ft, cut ESP Cable below penetrator and lay down same. Plugged bottom of packer and attempted fill with rig water - unable to fill fluid coming from under setting sleeve. PIR - Employee was struck in back and shoulder area during the task of removing pig tail from penetrator - sent to see medic, received aleve and returned to work. Page 8 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 21:30 8.00 2,025 2,025 COMPZ RPCOM OWFF T Monitor well on trip tank, discuss plan forward with town engineers and wait for completion equipment to arrive. 21:30 22:30 1.00 2,025 2,025 COMPZ RPCOM PULL T PJSM, POOH from 2025' and LD Tbg and GLM to 1900', RIH and PU Tbg and GLM to 2024'. Up wt 65k #, Down 60k# 22:30 23:30 1.00 2,025 2,025 COMPZ RPCOM OTHR T Continue Waiting on Packer 23:30 00:00 0.50 2,025 2,025 COMPZ RPCOM PULD T Load Packer, Suck out Stack, Pick Up Packer and Make Up Safety Joint. 07/06/2012 ReRun ESP Completion, Circluate Completion Fluids, Set DB Plug with SL, PrePare to ReSet Packer 00:00 04:00 4.00 2,025 2,025 COMPZ RPCOM OTHR T Perform FT Packer Splice and Test Cable. 04:00 10:00 6.00 2,025 4,553 COMPZ RPCOM TRIP T Continue to RIH w/ ESP completion from 2,025 -ft to 4,553 -ft, MU hanger to Landing jt w/ iso sleeve and MU to TBG string. 10:00 13:00 3.00 4,553 4,553 COMPZ RPCOM OTHR T Make Final splice and Connect to penetrator, Change out packing element on TBG hanger 13:00 14:00 1.00 4,553 28 COMPZ RPCOM HOSO T PJSM, Drain BOP Stack and Land Hanger w/ 8" centralizer at 4,585 -ft, with pump intake at 4,541 -ft, 3.562" "DB" Nipple at 2,690 -ft, KBMG Station #2 at 2,634 -ft, Baker Twin seal packer at 2,546 -ft, KBMG Station #1 at 2,419 -ft, and 3.812" "DB" Nipple at 512 -ft, with FMC Tabasco Sands 11" 5k Horizontal TBG Hanger at 28 -ft. RILDS. 14:00 15:30 1.50 28 28 COMPZ RPCOM PRTS T PJSM, RU Little Red Services to Production wing and PT hanger voids at 250 / 5,000 psi. good test 15:30 17:30 2.00 28 28 COMPZ RPCOM RURD T PJSM, Pull !so landing joint and install short neck landing joint. Install TIW Valve, 4 1/2 EUE Head pin, PIS. RU Slick line and LRS for freeze protecting well. PT pump lines at 3,500 psi. 17:30 18:30 1.00 28 28 COMPZ RPCOM FRZP T Pump 70 bbls of diesel down TBG at 1.7 bpm at 700 psi. tacking returns to kill tank thru full open choke. 18:30 22:00 3.50 28 28 COMPZ RPCOM SLKL T RU slick line and PT lubricator at 1,500 psi. RIH w/ 3.780" Gauge ring and drift run to 2694' SLM. RU and RIH with 3.562 DB Plug and set in Nipple at 2696' SLM, RIH and set Prong in Plug. PT Tbg at 400 psi. Monitor- lose 10 psi in 10 minutes - good test. Perform No Flow Test - Pass. Stand Back Slickline. Page 9of11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 28 28 COMPZ RPCOM CIRC T PJSM with LRS, PT lines to 3500 psi- OK. Bullhead 25 bbls Corrosion Inhibited Brine down IA at 1 bpm 280 psi, 2 bpm 500 psi ICP, 600 psi FCP. Start Bullheading Gelled Diesel down IA at 1 bpm, 500 psi ICP. 115 bbls away at 00:00. 07/07/2012 Set Baker Twin Seal FT Packer and Test, ND Bops and NU Tree 00:00 03:00 3.00 28 28 COMPZ RPCOM CIRC T Continue Pumping Gelled Diesel Down IA at 1 bpm 700 psi at 75 bbls, drop rate down to 0.75 bpm at 650 psi. Slowly pressures up to 700. Dropped rate down to 0.5 bpm at 680 psi. Run out of Gelled Diesel at 115 bbls away, swap to Diesel and pump 25 bbls. RD LRS. 03:00 08:30 5.50 28 28 COMPZ RPCOM PACK T Rig Up Hoses to Set Pump Down Tbg and Set Packer. Pressure up Tbg slowly at —1 stk/min to 2500 psi. Noted pressure bobble around 1200 psi, and continue pressuring up Tbg to 2500 psi. IA remaining constant —300 psi. Shut in and monitor Pressure on Chart, Pressure dropping off from Tbg at approx 250 psi per 5 min. Bleed Tbg down to 1000 psi and still dropping pressure linearlly at same rate. Slowly pressure IA to 1100 psi and chart. Holding Pressure. Holding 1100 psi on IA, pressure up Tbg to 3500 psi. IA holding and Tbg dropping still at —250 psi per 5 minutes. ? ?? Perform 30 minute IA test. Dropped 60 psi in 15 minute and 30 psi in second with last 5 minutes flat. -- PASS ?? Troubleshoot Tbg Leakoff. Install [so sleeve landing joint w/ "Y" and PT TBG at 3,500 psi - lost 150 psi in 40 minutes. IA pressure maintained 1,475 psi. RD TBG test equipment. 08:30 11:30 3.00 28 28 COMPZ RPCOM OTHR P Start Centrilift decompression as per chart, RD Slick line and Install BPV while conducting decompression. Note: found sensor and used for testing TBG was set aside and the heat caused hose to pressure up on the blue pin needle on chart during decompression. 11:30 14:30 3.00 28 28 COMPZ RPCOM NUND P PJSM, ND BOP and Dutch riser. 14:30 15:00 0.50 28 28 COMPZ RPCOM OTHR P Check ESP conductivity after Bop removal and Tree installation. 15:00 17:00 2.00 28 28 COMPZ RPCOM NUND P NU Adapter and Tree, PT void at 250 / 5,000 psi 17:00 17:30 0.50 28 28 COMPZ RPCOM MPSP P Remove BPV and install TWC Page 10 of 11 I • » ^ ` • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 28 28 COMPZ RPCOM PRTS P Pressure test tree at 250 / 5,000 psi 28 28 COMPZ RPCOM MPSP P Pull TWC and Install BPV 17:30 21:00 3.50 28 28 COMPZ MOVE RURD P Split DP in derrick, Pull off of 2T -220, clean cellar and release Nordic 3 @ 2100 hrs on 7/7/12 Page 11 of 11 STATE OF ALASKA • ALASKII. AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r' Repair w ell ri Plug Perforations f Stimulate r Other "®" Alter Casing p- Pull Tubing Jd Parf orate New Pool r Waiver r Time Extension `"`" Change Approved Program r' Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1" Exploratory i- 198 - 253 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 - 20283 - 00 ' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 • 2T - 220 9. Field /Pool(s): Kuparuk River Field / Tabasco Oil Pool 10. Present Well Condition Summary: Total Depth measured 5752 feet Plugs (measured) none true vertical 3509 feet Junk (measured) none Effective Depth measured 5527 feet Packer (measured) 4852 true vertical 3355 feet (true vertucal) 2974 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 112 112 SURFACE _ 4953 9.625 4990 3045 OPEN HOLE W/ 4 5752 3509' LINER SCREENS s D FEB 2 2 6112, RECEIVED Perforation depth: Measured depth: 4961' - 5517' FEB 0 7 2092 True Vertical Depth: 3030' - 3348' I I\laska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, MD, and ND) 4.5, L -80, 4784 MD, 2909 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER MODEL SC -1 GRAVEL PACK PACKER @ 4852 MD and 2974 TVD NO SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development I✓ , Service r Stratigraphic r 15. Well Status after work: . Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ "`° SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -378 Contact Eh _ elso _ • 263 -4693 Printed Name - i Nel • / Title Wells Engineer Signature \ Phone: 263 -4693 Date ��, 7/Z.._ RBDMS FEB 0 7 2012. 2 ,�- tto Form 10-404 Revised 10/2010 — I Submit Original Only 2T -220 Pre Rig Work DATE SUMMARY 12/9/11 EXERCISED CMU @ 4634' RKB PUT SLEEVE OPEN. PUMPED 5 BBL DS OWN IA. COMPLETE. ,*° KUP 2T - 220 ConocoPhillips ° `. 1 $ ! ! oreApI/UWI ribu ax Angle & MD TD Ala$Ka, I I P.1 Field Name Well Status Intl (°) MD (ftKB) Act Btm (ftKB) CarncoFTitkps 501032028300 TABASCO PROD 66.55 2,958.69 5,752.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE 50 6/18/2009 Last WO: 3/9/2009 36.81 1/18/1999 Well Confiq'. - 2T- 220, 1/24/2012 3 ".01:05 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: ELMD 4,699.0 11/8/2008 Rev Reason: WORKOVER ninam 1/24/2012 (; __ -" - " " " -_ Casing Strings HANGER, 28 {� + Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 112.0 112.0 62.58 H - 40 WELDED 111111111. _ - _.r Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I SURFACE 95/8 8.697 37.0 4,990.0 3,044.5 40.00 L BTC Casing Descr String 0... Strin ID ... T op ( 8KB ) Set Depth (t... S e t D ep th (TVD) ... String Wt... String ... String To Thrd `;. Gravel Pack Open 4.63 4 .000 4,851.7 5,752.0 3,509.4 11.60 L 80 SealLockr Hole w/ Liner CONDUCTOR, .? Screens 38 -112 ii.... Liner Details Top Depth (TVD) Top Inc! Nomi... NIPPLE, 543 Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 4,851.7 2,973.6 59.35 PACKER BAKER MODEL SC-1 GRAVEL PACK PACKER 4.750 II 4,861.6 2,978.6 59.39 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 4.875 4,863.8 2,979.7 59.40 SBE BAKER SEAL BORE 4.750 4,885.1 2,990.5 59.50 KOIV BAKER MODEL 'B' KOIV 3.437 4,961.4 3,029.5 58.87 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 / 5,5172 3,348.5 50.21 0-RING BAKER 0-RING SUB 2.375 5,518.3 3,349.2 50.18 VALVE BAKER FLAPPER VALVE (2) 2.875 GAS 21 ,556 5529.0 3,356.1 49.89 OPEN HOLE - Tubing Strings `` Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd la TUBING 4 1/2 3.958 28.4 4,790.5 2,942.5 12.60 L IBTM Completion Details PACKER, 2,684 Top Depth -- - ,TVD) Top Inc! Noml... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 28.4 28.4 -0.58 HANGER FMC MODEL 120- 11' x 45 ESP HANGER 3.958 iv 543.2 541.7 10.08 NIPPLE CAMCO DB NIPPLE 3.812 MI 2,684.2 2,011.6 6328 PACKER BAKER 51A6 TWIN SEAL PACKER BODY 3.970 GAS LIFT, 2,893.2 2,105.6 63.18 NIPPLE CAMCO DB NIPPLE 3.750 2,837 4,709.9 2,901.9 59.96 GAUGE WELL LIFT DGU 3.958 _..... 4,727.1 2,910.5 59.88 DISCHARGE CENTRILIFT DISCHARGE HEAD 513 SERIES 2.995 4,727.6 2,910.7 59.87 PUMP CENTRILIFT 56 STAGE P62 -538 PMSXD 056 P62 FER 12 CRC PUMP NE 4,746.6 2,920.3 59.77 INTAKE CENTRILIFT AR DESIGN PUMP INTAKE NIPPLE, 2.893 4,747.6 2,920.8 59.77 SEAL CENTRILIFT TANDEM SEAL SECTION ar 4,761.4 2,927.8 59.70 MOTOR CENTRILIFT 562 MSP 336/2650/78 16R ESP MOTOR 4,786.7 2,940.5 59.56 GAUGE WELL LIFT MGU 4,788.6 2,941.5 59.56 Centralizer MOTOR CENTRALIZER GAUGE,4,710 61==kti Perforations & Slots Shot I II I P Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh... Type Comment al 4,961 5,517 3,029.5 3,348.3 TABASCO, 7/8/1999 99.0 IPERF OPEN HOLE GRAVEL PACK I I TE_1, 2T -220 DISCHARGE,: Notes: General & Safety 4,727 �� End Date Annotation PUMP, 4,728 I. 4/17/2009 NOTE: View Schematic w/ Alaska Schematic9.0 INTAKE, 4,747 e,. SEAL, 4,746 MOTOR, 4,781 Me W GAUGE. 4,787 < Centralizer, I 4,789 t_s 111 P. . 1 1 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (poll Run Date Cont... 1 2,556.4 1,954.4 63.60 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 1/2/2012 2 2,837.0 2,080.1 62.78 CAMCO KBMG 1 GAS LIFT SOV BK -5 0.000, 0.0 1/2/2012 SURFACE, r i 37 -4,990 - I -5517 4.88IPERE. - IIIIK I�� Gravel Pack Open Hole w/ Liner Screens, _ 4.852-5,752 TD(2T -220). 5,752 • • . Conoc Phillips Time Log & Summary We /!view Web Reporting Report Well Name: 2T - 220 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/18/2011 1:00:00 AM Rig Release: 1/4/2012 10:00:00 AM Time Logs Date From To Dur S. Depth- E. Depth Phase Code Subcode T Comment 12/18/2011 24 hr Summary MIRU. Kill Well. Nipple Down ESP Tree. 00:00 01:00 1.00 MIRU MOVE MOB P Mobilize Rig from 2T -03 to 2T -220 Well Slot. 01:00 06:30 5.50 MIRU MOVE RURD P Spot and level Nordic Rig 3 over Well. Berm up. Move in spot and berm up support equipment. Rig Accepted at 01:00 hrs 12/18/2011. 06:30 10:15 3.75 COMPZ WHDBO MPSP P MU Lubricator and Pull BPV. FMC encounters problems pulling valve due to lack of in -line master valve. Unable to get valve above swab to shut. Two foot 7" Otis Lubricator extension borrowed from CDR2 and continue to pull BPV. 10:15 16:45 6.50 COMPZ WHDBO KLWL P Initial Pressure T /I /O = 50/ 200/ 150 psi. Line up and pump 150 degree filtered 8.6 ppg seawater w/ 3% KCL taking returns to tiger tank. Pumping 4 bpm at 760 PSI down IA. Pressure increases on IA to 1200 psi, tubing pressure drops to 0 psi. Pump 316 bbls down IA. Total returns 143 bbls to tiger tank. Swap over and bullhead 72 bbls down the tubing with IA shut in. Open up IA and continue circulating diesel down tubing up IA to tiger tank at 4 bpm at 200 psi. After 180 bbls away, get seawater returns. 16:45 19:00 2.25 COMPZ WHDBO KLWL P Shut in Well. Tubing pressure = 0 psi. Casing = 10 psi. Monitor Well. . Vac Truck empty Kill Tank. Well continues a slight flow from the IA. Still have a some diesel in the flow returns, too. 19:00 22:00 3.00 COMPZ WHDBO KLWL P Bring Rig Pump on line at 3.0 bpm/700 psi. Increase rate to 5.0 bpm/1,225 psi. Circulated 275 bbls (IA Volume +). Shut in Well to monitor. Once again the Tubing is dead, but still have a slight flow up the IA. Comingle the IA into the Tubing and let Well balance out. Flow check Well. Well now on a slight vacuum. 22:00 22:30 0.50 COMPZ WHDBO MPSP P PJSM. Install BPV. Page 1 of 18 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 COMPZ WHDBO NUND P PJSM. Nipple down ESP Tree. Inspect Tubing Hanger threads. Install Blanking Plug. 12/19/2011 Perform initial BOPE test. Pull Tubing Hanger. Circ Well. Rig up to handle the ESP Completion. POOH with the 4 1/2" ESP Completion. 00:00 02:30 2.50 COMPZ WHDBO NUND P Nipple up BOP Stack. 02:30 05:00 2.50 COMPZ WHDBO PRTS P Perform the initial ROPE test per ConocoPhillips / AOGCC requirements at 250/2,500 psi. The State's right to witness the test was waived by AOGCC Field Inspector, .A1" C. Scheve. Complete testing Choke Manifold Valves, Top Drive Valves, and Floor Valve. However unable test the BOP Stack and HCR Valves due to rapid pressure fall -off (both low pressure and high pressure attempts) Suspect that the BPV /Blankingi Pluq is not holdinci. Pull and trouble shoot BPV /Blanking Plug. 05:00 07:00 2.00 COMPZ WHDBO MPSP T FMC Service pull BPV /Blanking Plug and inspect. Change -out o -ring on BPV and re -set. Tests good. 07:00 11:30 4.50 COMPZ WHDBO PRTS P Continue to test BOP Stack and HCR Valves at 250/2500psi. Tests Charted. Perform Koomey draw down test. 11:30 12:00 0.50 COMPZ RPCOM PULD P PU and MU Landing Joint and BOLDS. 12:00 12:30 0.50 COMPZ RPCOM PULL P Pull Hanger up 3'. Pulls free at 102k# and drops back to 98k #. 12:30 15:45 3.25 COMPZ RPCOM CIRC P PJSM. Circulate 330 bbls down tubing up IA. Clean 8.6 ppb SW returns. Monitor Pressure for 30 minutes while have PJSM for pulling Completion. Well on vac losing 3.5 bph. 15:45 22:45 7.00 4,784 62 COMPZ RPCOM PULL P Start pulling 4 1/2" ESP /GL Completion. Recovered 48 Stds, 2 ea GLMs, 1 ea Sliding Sleeve Assembly (IN THE CLOSED POSITION), Baker Guardian Gauge Assembly (with Patch across on the inside) NOTE: 1/4" NPT BLANKING 1. PLUG WAS MISSING FROM SIDE V OF GAUGE ASSY, and 4 single joints of Tubing. Total Joints = 148. Tubing looks good. No pitting on any of the joints. All pin ends, good. 22:45 00:00 1.25 62 62 COMPZ RPCOM PULD P Break -out ESP Assembly sections and lay down same. 12/20/2011 LD ESP Sections. MU BHA #1. RIH and perform clean -out down to the SC -1GP Pkr. Page 2 of 18 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 62 0 COMPZ RPCOM PULD P Continue to inspect, break -out and lay down ESP Assembly sections. ESP findings: Pump locked -up. Seal Section and the Gas Separator, OK. Motor also checked, OK. Recovered 79 Cannon Clamps, 2 ea Flat Guards, 2 ea Pump Protectolizers, 1 ea Motor Protector, 14 ea SS BANDS (Note: 4 ea SS Bands left in the Hole). 02:30 04:30 2.00 0 0 COMPZ WELLPF RURD P Clear and clean Floor. Install Wear Bushing. Rig -up to handle 3 1/2" Drill Pipe. 04:30 09:00 4.50 0 258 COMPZ WELLPF PULD P PJSM. Load Baker Fishing Tools in Pipe Shed. Make -up BHA #1, Mule Shoe and 9 5/8" Casing Scraper. 09:00 12:00 3.00 258 4,084 COMPZ WELLPF TRIP P Trip in with BHA #1 and 3 1/2" Drill Pipe from the Derrick. Up Weight = 95K. Down Weight = 65K. Started taking weight at 4,084 -ft dpmd. 12:00 14:30 2.50 4,084 4,708 COMPZ WELLPF CIRC P Wash at 3.0 bpm /190 psi and work down to 4,481 -ft. Had to pull 55K over to free. Reverse Circulate at 5.0 bpm /450 psi down to 4,505 -ft. and clean up Well. Rernvarprl Fnrmatinn Sand. Fluid loss = 6 - 8 bph. Wash • down to 4,708 -ft. 14:30 15:30 1.00 4,708 4,708 COMPZ WELLPFCIRC P Reverse circulate at 5.0 bpm /510 psi. Returns = Formation Sand and some pieces of gravel. 15:30 17:00 1.50 4,708 4,708 COMPZ WELLPF CIRC P Pull up hole to 4,405 -ft. Wash back down to 4,708 -ft. Dicsuss Plan Forward with anchorage Engineer. 17:00 00:00 7.00 4,708 4,705 COMPZ WELLPF CIRC P Vis up Fluid System to 60 Vis. Reverse Circulate from 4,705 -ft. Fluid loss remains at 6 - 8 bph. Returns = some silt and some sand with occasional section of clean returns. Prep to POOH. 12/21/2011 Trip to change BHA. Continue with Wellbore Clean -out. to the Packer at 4,851 -ft. POOH. 00:00 01:45 1.75 4,705 258 COMPZ WELLPF TRIP P Trip out with BHA #1, standing back 3 1/2" Drill Plpe in the Derrick. 01:45 03:15 1.50 0 205 COMPZ WELLPF PULD P Lay down BHA #1. Clean String Magnets. Make -up BHA #2, 8 1/2" Cone Bit. 03:15 04:30 1.25 205 4,708 COMPZ WELLPF TRIP P Trip in with BHA #2 with 3 1/2" Drill Plpe from the Derrick. Up Weight = 95K. Down Weight = 68K. RPMs = 60. RTW = 80K. Torque = 3,800 ft/lbs. Tag fill at 4,708 -ft dpmd. Page 3 of 18 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 08:30 4.00 4,708 4,812 COMPZ WELLPF CIRC P Wash at 4.0 bpm /360 psi and rotate the first couple of feet. Then able to wash with no rotation. Continue on down to 4,751 -ft (end of Stand in the Top Drive). Switch to Reverse Circulate to clean -up Wellbore. Continue to C/O to 4,842 -ft. Reverse Circ. Attempt to CIO and Had Top Drive problems. POOH to 4,812 -ft. 08:30 13:00 4.50 4,812 4,812 COMPZ RIGMNT RGRP T Check out and repair Top plate and rotary seal 13:00 13:30 0.50 4,812 4,842 COMPZ WELLPF FCO P Finish clean out to 4,842 -ft 13:30 18:00 4.50 4,842 0 COMPZ WELLPF TRIP P POOH with BHA #2. Lay down same. 18:00 19:30 1.50 0 4,832 COMPZ WELLPFTHGR P Make -up BHA #3, 2 7/8" Mule Shoe and 9 5/8" Casing Scraper. Trip in with 3 1/2" Drill Pipe from the Derrick. Up Weight = 98K. Down Weight = 68K. 19:30 20:00 0.50 4,832 4,842 COMPZ WELLPF CIRC P Bring Pump on line at 3.0 bpm /270 psi. Tagged up at 4,842 -ft. AttamptMd to enter the top of the SC -1 Gravel Pack Packer. Continue several time to "clock" the Mule Shoe. Also changed pump rate. Unable to make and progress (possible junk from lost ESP Bands and a piece of Flat guard from a previous RWO preventing progress). 20:00 21:00 1.00 4,842 4,839 COMPZ WELLPF CIRC P Reverse Circulate Drill Pipe volume x 3 at 3.0 bpm /280 psi. Returns were some silt and fine sand. 21:00 00:00 3.00 4,839 0 COMPZ WELLPF TRIP P Trip out with BHA #3 standing the 3 1/2" Drill Pipe back in the Derrick. Lay down BHA. Clear and clean the Floor. 12/22/2011 RIH with Test Packer. Test Csg. Discuss results with Anchorage Engineer. POOH w/ Test Pkr. Found SS bands in element. RIH w/ RCJB and c/o to 4,849 -ft. 00:00 02:30 2.50 0 4,800 COMPZ WELLPF TRIP P PJSM. Pick -up Baker 9 5/8 Retrievamatic Packer Trip in on 3 1/2" Drill Plpe from the Derrick to 4,800 -ft Up Weight = 92K. Down Weight = 65K. Set Packer with 8K down weight. Page 4 of18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 05:30 3.00 4,800 4,745 COMPZ WELLPF PRTS P Attempt to test the 9 5/8" Casing at 2,500 psi. However, the Packer communicated into the Drill Pipe due to not enough "set down" weight. Re- calculate how much down weight can be set on the Packer for a 2,500 psi test and still maintain the 80% 'VA" Burst safety margin. Set 12K down. Walk pressure up to 1,850 psi where is appears we are still in communications somewhere. Move Packer down hole 5 -ft and try again. Same results. Discussed with Anchorage Engineer if a 1,500 psi casing test would be acceptable so we would have enough set down weight to pack -off the Packer Element. Pressure up on the 9 5/8" Csg to 1,500 psi. Observe a slow stea• • - - - e in pressure. Lost 200 psi in 25 minutes. pressure. Move Packer up -ho to . 4,745 -ft. Pressure up to 1,600 psi x 30 minutes. Test recorded on a Chart. "Rock solid ". 05:30 13:30 8.00 4,745 0 COMPZ WELLPF TRIP P Release Packer. Trip out with 3 1/2" a Degi -'•e found sipage in the - body on the blind rams, investigate and make decision to continue to POOH) with Baker Retrievable Packer. Lay down Packer. (Recovered numerous pieces of SS bands - equaling 1 band in the Elements and slips segments on the Test packer) Function Blind rams and multiple times and had no sipage thru weep hole. 13:30 17:30 4.00 0 0 COMPZ WELLPF OTHR P Call out 8 1/2" RCJB and wait for equipment to arrive. 17:30 18:30 1.00 0 254 COMPZ WELLPF PULD P MU and MU BHA #5 8.5 RCJB assy to 254 -ft 18:30 20:00 1.50 254 4,800 COMPZ WELLPF TRIP P Trip in with BHA #5 on 3 1/2" Drill Pipe from the Derrick. Stop for scheduled Drilling Line maintenance. 20:00 21:30 1.50 4,800 4,800 COMPZ WELLPF RGRP P PJSM. Cut and Slip (90 -ft) of Drilling Line. Inspect Draw Works. Adjust brakes. Check Crown -O- Matic. Page 5 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:00 0.50 4,800 4,849 COMPZ WELLPF FISH P Resume Operations. Drop the 11/16" Ball. Up Weight = 100K. Down Weight = 70K. RTW = 82K. Free Spin Torque = 2,950 ft/lbs. Bring Pump on line at 2.0 bpm /350 psi. Increase rate to 8.0 bpm /960 psi. Saw Ball go on seat at 1,100 psi. Wash down slowly and tag up at 4,837 -ft. Washed down to 4,840 -ft with little problem. At 4,840 -ft work to wash and rotate RCJB with 2 - 6K WOB and with increased torque between 3,500 - 4,000 ft/Ibs down to 4,842,5 -ft. At 4,842.5 -ft the torque .r fell off as fell as the WOD. End rotation. continue washing down to %1 4,849.6 -ft. (took weight again), the �� top of the SC -1 Gravel Packer. Remain on top of Packer (no rotation) and increased the pump rate to 10.0 bpm /1,460 psi. for a couple minutes. Fluid loss during the Clean -out = 35 bbls. 22:00 00:00 2.00 4,849 4,848 COMPZ WELLPF CIRC P Reduce Pump rate to 3.0 bom /280 psi. Circulate bottoms up. 12/23/2011 TOOH w /RCJB. Empty recovered ESP Bands. TIH w/9 5/8" RBP. Set at 4,835 -ft and test Csg. Swap Fluids. Spot Sand on top of RBP. RU E -Line. Log Well. RD E -Line. 00:00 02:00 2.00 4,848 254 COMPZ WELLPF TRIP P PJSM. Trip out with 3 1/2" Drill Pipe standing back in the Derrick. Normal hole fill on the trip out. 02:00 03:00 1.00 254 0 COMPZ WELLPF PULD P Lay down RCJB. Recovered much Junk: Several mangled pieces of Flat Guard, Several pieces of SS Bands, The Control Rod from the Inflatable Bridge Plug , several / mystery pieces, most likely from the ✓ IBP. Gravel, and one Rock -1.5" x 1" in size. Empty out the Boot Basket and recovered -1 gallon of Pea Gravel. 03:00 05:00 2.00 0 4,800 COMPZ WELLPF TRIP P Clean Floor. Make up the 2 ea Boot Baskets and the 8.5" RCJB again. Trip in with BHA #6 (same configuration as BHA #5) 3 1/2" Drill Pipe from the Derrick. 05:00 05:30 0.50 4,800 4,850 COMPZ WELLPF FISH P Bring Pump on line at 8.0 bpm/1,211 psi. Washed RCJB down with no rotation to 4,849.6 -ft with no bobbles. Hole is clean down to the assumed top of the SC -1 Gravel Pack Packer. Increased Pump rate up to 10.0 bpm/1,665 psi for a few minutes. Lost a total of 39 bbls. 05:30 08:30 3.00 4,850 254 COMPZ WELLPF TRIP P Trip out with 3 1/2" Drill Pipe to BHA #6. Page 6 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:30 1.00 254 0 COMPZ WELLPF PULD P POOH BHA #6 and clean magnets, boot baskets and RCJB. Recovered small particles and pcs of Flat guard 09:30 10:30 1.00 0 0 COMPZ WELLPF OTHR P Clean and Clear rig floor 10:30 11:00 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM on Picking up and making up Baker G Plug 11:00 14:00 3.00 0 4,835 COMPZ WELLPFTRIP P PU and MU and RIH w/ 9 5/8 Baker G Plug to 4,835 -ft 14:00 16:00 2.00 4,835 4,805 COMPZ WELLPF PACK P Set Baker G Plug at 4,835 -ft Bottom of plug, 4,828 -ft Center of element, 4,822 -ft Top of equalizer. PT at 1,500 psi. Release off and PU to 4,805-ft. 16:00 17:30 1.50 4,805 4,805 COMPZ WELLPF CIRC P Reverse circulate Non - Viscousified Fluid into well bore displacing visc KWF from well. 17:30 20:30 3.00 4,805 4,800 COMPZ WELLPF CIRC P Rig to dump Sand. Spot 500 lb of 20/40 Mesh Sand on top of the 9 5/8" Retrievable Bridge Plug. Displace the 3 1/2" Drill Plpe with 8.9 lb/gal Brine at a slow pump rate. Wait on Sand to settle. Tag the top of Sand at 4,818 -ft. 20:30 22:00 1.50 4,800 0 COMPZ WELLPFTRIP P Trip out with the RBP Running Tool. Stand back the 3 1/2" Drill Pipe in the Derrick. Clean Floor. 22:00 00:00 2.00 0 0 COMPZ WELLPF ELOG P PJSM. Rig up E -Line equipment. Plck up Halliburton's FASTCAST Logging Tool. Run in down to 1,800 -ft. Unable to get any deeper due to several bad "Dog Legs in the 9 5/8" Casing. 12/24/2011 Record FASTCAST and Gyro Logs. RD E -Line equipment. TIH and wash Sand from top of RBP. Release and pull RBP. Pick -up next BHA. TIH. Clean out Screen Assembly. 00:00 02:00 2.00 0 0 COMPZ WELLPF ELOG T Reconfigure the Centralizers and relax tension of the Centralizer Arms. RIH. Got through the 1,800 -ft area. However now stopping at 2,042 -ft (5.9 Deg DL and 62 deg hole angle). Attempted several times to pass through at different line speeds. No -Joy. Order out Knuckle Joints. Decide to Log the top 2,000 -ft while waiting for the Knuckle Joints and the Gyro /40 -arm Caliper folks to show up. 02:00 13:00 11.00 0 0 COMPZ WELLPF ELOG P Record data in the top 2,000 -ft of the 9 5/8" Casing with the FASTCAST Tool at 15 ft/min. Set back FASTCAST Tools. Pick -up Gyro w /memory GR and the 40 Arm Multi- Finger Caliper Tool. Run in with Logging Tools. Unable to get past 2,075 -ft. POOH and set E line aside. Page 7 of 18 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 13:30 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM on RIH w/ CSG scraper to 4,500 -ft. 13:30 16:00 2.50 0 4,500 COMPZ WELLPF TRIP P PU and MU CSG scraper and RIH to 4,500-ft. 16:00 18:00 2.00 4,500 4,500 COMPZ WELLPF CIRC P Reverse circulate 1 Hole volume at 8.0 bpm /1,220 psi. 18:00 19:30 1.50 4,500 0 COMPZ WELLPF TRIP P POOH from 4,503 -ft. Up Weight = 90K. Lay down BHA #8, 9 5/8" Casing Scraper. 19:30 22:45 3.25 0 0 COMPZ WELLPF ELOG P PJSM. Rig up E -Line equipment. Pick up Halliburton's FASTCAST Logging Tool. Run in at 70 ft/min to 2,090 -ft where Tool String set down. Pull up to 1,900 -ft. Tried 10 more times at 150- ft/min. Set down at: 2,100', 2115', 2126', 2130', 2050', 2050', 2106, 2111', 2105', 2112'. Abort any further attempts. Pull out. Lay down FASTCAST Tool String (no marks on head of Tool). Rig down E -Line and release. 22:45 00:00 1.25 0 4,820 COMPZ WELLPF TRIP P Pick -up BHA #9, Baker RBP Running Tool. Trip in with 3 1/2" Drill _ Pipe from the Derrick. 12/25/2011 Release E -Line. RIH and Swap Well over to Vis 8.6 lb/gal Brine. Wash Sand. Release and POOH w /RBP. Test BOPE. Problems. Set RBP. Set Test Plug. BOP repairs. 00:00 02:30 2.50 4,820 4,820 COMPZ WELLPF CIRC P Reverse circulate and swap Well bore over to viscosified (55 vis) 8.6 lb/gal Brine at 4.0 bpm /380 psi. 02:30 04:15 1.75 4,820 4,825 COMPZ WELLPF CIRC P Fluff the Sand on top of the Retrievable Bridqe Plug. Latch and release RBP. Crculate bottoms -up. 04:15 06:30 2.25 4,825 0 COMPZ WELLPF TRIP P Blow down top Drive. Trip out with 3 1/2" Drill Pipe standing back in the Derrick. Lay down RPB and Running Tool. 06:30 12:00 5.50 0 0 COMPZ WHDBO BOPE T Held PJSM, Pull wear ring and Install Test plug. PU 2 7/8 Test jt and RIH to below LPR's. Test Pipe rams at 250/3,500 psi. Pull up and test )279/ Annular at 250 / 2,500 psi. Annular tested good at 250 and failed at 1,500 psi. Made multiple attempts to test Annular - un successful. Lay 7 down Test jt. Pull Test plug. 12:00 13:30 1.50 0 2,008 COMPZ WHDBO TRIP T PU and RIH w/ Baker "G" Plug to 2,008 - ft. 13:30 14:30 1.00 2,000 2,000 COMPZ WHDBO PACK T Set RBP and PT at 1,000 psi - good test. 14:30 15:30 1.00 1,910 1,910 COMPZ WHDBOOTHR T POOH w/ 1 stand DP. MU 3 1/2 IF \ i / FOSV, X -O, Test plug and land test plug in preparation for BOP Repair and weekly BOP Test. 15:30 18:30 3.00 1,910 1,910 COMPZ WHDBO RGRP T Change out the Bonnet Seal on the Blind Rams. 3 hrs Non revenue 18:30 00:00 5.50 1,910 1,910 COMPZ WHDBOOTHR T Change out Packing Element on the Annular. Page 8 of 18 Time Logs 40 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/26/2011 24 hr summary Complete BOP repairs. Perform weekly BOPE test. Pull Test Plug and RBP. MU and RIH with BHA #10 and CO the Screen Assembly. TOOH. LD BHA 10. 00:00 01:30 1.50 1,910 1,910 COMPZ WHDBO PRTS P Rig up test equipment. Shell test BOP Stack at 250/3,500 psi. Good. Called (and paged) the AOGCC Field Inspector, B. Noble at 01:30 hrs to notify him that we were starting the Test as per his instruction received earlier. 01:30 08:30 7.00 1,910 1,910 COMPZ WHDBO PRTS P Perform weekly BOPE Test per ConocoPhil lips / AOGCC requirements at 250/3,500 psi. Tested the Annular at 250/2,500 psi. Perform Koomey draw down test. All pressure test recorded on a chart. AOGCC Field Inspector, B. Noble witnessed the test. Pull test plug 08:30 09:30 1.00 1,910 2,008 COMPZ WELLPF PACK P RIH and release RBP. 09:30 10:30 1.00 2,008 2,008 COMPZ WELLPF CIRC P CBU at 5 bpm at 150 psi 10:30 12:00 1.50 2,008 0 COMPZ WELLPF TRIP P POOH and lay down Baker "G" RBP 12:00 15:00 3.00 0 715 COMPZ WELLPF PULD P PU and RIH with hyd 511 clean out string to 715 -ft 15:00 16:00 1.00 715 4,849 COMPZ WELLPF TRIP P RIH w/ C/O BHA # 12 on 3 1/2 13.30# S -135 DP to 4,849 -ft ( SC -1 Liner Top ). 16:00 00:00 8.00 4,849 4,860 COMPZ WELLPF FCO P Wash into 4" Screened Liner at 4,849 -ft and clean out 5,020 -ft with some difficulty due to junk/trash. Mule Shoe plugged -off. Attempt to Reverse Circulate at 3.0 bpm and at 6.0 bpm. No returns. Go back the long way and clear Mule Shoe. Continue in make progress with difficulty. However, continue to push junk/trash ahead. Also getting junk beside Clean -out Tubing. Continue to work free down to 5,170 -ft. Progress all but stopped. Fluid loss 16 bbls /hr. Pull up to 4,860 -ft, into the 4.750" ID Liner section. Circulate an attempt to bring up any trash. 12/27/2011 Continue to Clean -out the Screen Assembly. 00:00 00:30 0.50 4,860 4,860 COMPZ WELLPF CIRC P Circulate bottoms up at 9.0 bpm /810 psi. No fluid loss at present ( ?). Pumped 335 bbls. Returns -3/4 gal Sand, some Pea Gravel, and a few broken pieces of ESP Bands /Flat guard recovered. Page 9 of 18 Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 00:30 02:00 1.50 4,860 5,330 COMPZ WELLPF FCO P Continue back down to 5,170 -ft with little problem. Started to push Junk/Trash again. However with not the problems as before. Bring Pump on at 3.0 bpm /300 psi. Continue making hole. Lost returns at 5,228 -ft. Well went on a vacuum. Continue making hole but now with some problems. Pumping at minimum rate to keep Top Drive from freezing. Stopped making hole at 5,330 -ft. However, now starting to see signs of the slick (no Tool Joints) clean -out string trying to become differentially stuck when trying to pull up hole. Abort any further attempt to clean -out deeper. 02:00 03:00 1.00 5,330 5,330 COMPZ WELLPF TRIP P End 8.6 lb/gal Vis Brine and start Filtered 8.6 lb/gal Brine. Begin to pull out of the Screen Assembly pumping down the Drill Pipe while tripping up to the SC -1 Gravel Pack Packer. 03:00 07:30 4.50 5,330 5,110 COMPZ WELLPF CIRC P Pump 50 bbls of Filtered 8.6 lb/gal Brine down the Drill Pipe. Returns to surface. Continue pumping an additional 40 bbls with only 50 %returns. Start tripping out with BHA #12. Double displacing the Drill Pipe Volume down the backside with Filtered 8.6 lb/gal Brine. Standing back the 3 1/2" Drill Pipe in the Derrick, 100k up /60k dn to 3,860 -ft, RBIH on DP and dry tag @ 5,130 -ft, PUH to 4,828 -ft, RBIH and dry tag at 5,110 -ft 07:30 12:00 4.50 5,110 4,828 COMPZ WELLPFCIRC P Reverse circulate 3 bpm at 1260 psi, 85 % losses, POOH to 4,840 -ft, monitor trip tank, no losses, RBIH ✓ and tag 5,235 -ft, 100k up/ 62k dn, pumping dn DP 3 bpm at 280 psi, POOH to 4,828 -ft, monitor trip tank, 60 bph losses. 12:00 14:00 2.00 4,828 766 COMPZ WELLPF TRIP P Start tripping out with BHA #12. Double displacing the Drill Pipe Volume down the backside with Filtered 8.6 lb/gal Brine. Standing back the 3 1/2" Drill Pipe in the Derrick. 14:00 15:15 1.25 766 0 COMPZ WELLPF PULD P Change over floors, single out 2 7/8" Hydrill, LD clean out BHA #12, clean and clear floors 15:15 16:15 1.00 0 101 COMPZ WELLPF PULD P PJSM- Running Shifting Tool. PU MU BHA #13, Mule Shoe, Shifting Tool, 1 jt 2 7/8" tbg, XO's, Boot Basket, 9 5/8" Csg Scraper, Bit Sub, Bumper Sub, Oil Jar, Dual String Magnets. Page 10 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 18:00 1.75 101 4,875 COMPZ WELLPF OTHR P RIH with BHA #13 on DP, slide thru to open SSD at 4,864 -ft to 4,875 -ft PUH 92k up/ 67k dn to Close SSD, 10k over pull thru SSD to 4,838 -ft, RBIH and open SSD, PUH thru SSD to Close with no overpull. 18:00 21:00 3.00 4,875 101 COMPZ WELLPF TRIP P Start tripping out with BHA #13, 92k up/ 62k dn. Double displacing the Drill Pipe Volume down the backside with Filtered 8.61b /gal Brine. Standing back the 3 1/2" Drill Pipe in the Derrick 21:00 23:00 2.00 101 0 COMPZ WELLPF PULD P Break Down BHA #13, off load tools. Bring in Baker completion equipment. 23:00 00:00 1.00 0 0 COMPZ WELLPF OWFF P Monitor well while changeing over floors to run completion. 3 bph losses. 12/28/2011 Run 4 1/2" TC -ESP with Feedthru Packer completion. MU and Land Tbg Hanger. RILDS and Test Hanger Packoffs. 00:00 00:45 0.75 0 28 COMPZ RPCOM OTHR P Pull Wear Ring. 00:45 01:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discussed handling and running of ESP completion, guard and channel placement, splicing of cable. 01:00 07:00 6.00 0 86 COMPZ RPCOM PULD P PU MU, service TC -ESP motor, seal assembly, pull cable over sheave, connect gauge and install 2 flat guards. 07:00 10:30 3.50 86 2,098 COMPZ RPCOM TRIP P RIH w/ ESP components from 86 -ft. to 2,098 -ft with 4 1/2", 12.6#, L -80 IBTM TBG. PU Baker Twin Seal Packer and prep for splice. Conducting MEG checks every 1,000 -ft ran. Unable to locate X -O for penetrator. 10:30 12:00 1.50 2,098 2,098 COMPZ RPCOM OTHR T Unable to locate X -O for penetrator. Found X -O in job box. 12:00 16:00 4.00 2,098 2,098 COMPZ RPCOM OTHR P Make ESP splice for feed thru Packer and test continuity of ESP Cable 16:00 19:30 3.50 2,098 4,762 COMPZ RPCOM TRIP P Continue to RIH w/ 4 1/2 ", 12.6 #, L -80 IBTM TBG from 2,098 -ft to 4,762 -ft. PU Landing jt and MU to TBG Hanger. Conducting MEG checks every 1,000 -ft ran. 19:30 22:15 2.75 4,762 4,762 COMPZ RPCOM OTHR P Make Final splice, MU to Tbg hanger and test continuity. all good. Installed with Completion - 3ea. Flat guards 3ea. Protectolizers 76ea. 2 -ft x 4 1/2" Cross coupling Clamps Page 11 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 4,790 4,790 COMPZ RPCOM THGR P Land Tbg hanger. 103k up wt / 65k down wt. RILDS. Pressure Test Hanger Packoffs 5000 psi. Pull Landing Joint and Isolation Sleeve, re -run Landing Joint 12/29/2011 Test Hanger Packoffs. RU Slickline. Set plug . Displace IA to Diesel. Set Packer. Pressure test IA. Depressure IA per schedule. Pull DV. Freeze Protect Tbg. Set SOV. RD Slickline. Install BPV. ND BOPE. Remove upper and lower VBR's for double gate swap. Make cable checks, 2 legs shorted out, confer with town engineer. NU Tree. 00:00 01:00 1.00 4,790 4,790 COMPZ RPCOM THGR P Pressure Test Hanger Packoffs 5000 psi. Pull Landing Joint and Isolation Sleeve, re -run Landing Joint with FOSV. 01:00 01:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discussed hazards associated with Slickline rig up. RU Slickline equipment. 01:15 02:30 1.25 0 0 COMPZ RPCOM SLKL P RU Slickline equipment. P/T lubricator 2500 psi. 02:30 03:15 0.75 0 0 COMPZ RPCOM SLKL P RIH with 3.78" gauge ring to tag DB nipple at 2,892 -ft SLM- POOH and change out tools. 03:15 04:15 1.00 0 0 COMPZ RPCOM SLKL P RIH with 3.75" Cat Standing Valve (3.78" OD No -Go) on 4.5" GS, set SV at 2,892 -ft POOH, change out tools, pressure test lubricator to 3500 psi. 04:15 05:45 1.50 0 0 COMPZ RPCOM CIRC P Bull head 145 bbls diesel down IA, 2.5 bpm at 1150 psi, shut down IA pressure at 900 psi, monitor IA 20 min, IA at 360 psi. 05:45 15:00 9.25 0 2,893 COMPZ RPCOM PACK P Start setting sequence for Baker 51A6 Twin Seal Packer, pressure up Tbg to 2500 psi for 5 min. Bleed Tbg to 1000 psi. pressure up IA to 1500 psi and chart. pressure up Tbg slowly to 3500 psi while maintaining 1500 psi on IA, hold Tbg pressure 5 min to complete packer setting sequence. bleed Tbg to 0 psi holding 1500 psi on IA, Chart 30 minute IA test. While conducting Centrilift depressurization schedule the following slick line work was conducted; Pulling of the dummy valve from GLM #1 @ 2,837 -ft was pulled. 30 bbls of diesel was bullhead down TBG at 1 bpm @ 60 psi ICP and 980 psi FCP. 2,000 psi TBG to CSG SOV was installed. Catcher sub was retrieved from on top of 3.75" Standing Valve installed in 3.75 " 'DB' Nipple at 2,893 -ft. Pull standing valve and install 3.75 DBP, PT at 1, 000 psi. RD slick line. 15:00 15:30 0.50 0 0 COMPZ RPCOM MPSP P Set BPV with dry rod. Page 12 of 18 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 21:30 6.00 0 0 COMPZ WHDBO NUND P PJSM- ND BOPE breaking all 11" stack breaks to swap out 11" 5m Shaffer for 11" 5m Double BOP's. Remove upper and lower VBR's. Set back on stump. 21:30 00:00 2.50 0 0 COMPZ WHDBO DHEQ T Make checks on ESP cables, 2 legs shorted out, no readings on Simpson gauge, 4 volts on Megger , hook up with computer with no readings transmiited from downhole equipment, confer with town engineer on plan forward. calls made to confer we have back up equipment. start NU of tree. 12/30/2011 ND Tree. Install blanking plug. NU BOPE and test. Pull blanking plug and BPV. RU Slickline. Pull Upper DV. Load well with 8.6 ppg filtered brine. Dummy off upper and lower GLM's. RIH to Pull DBP plug. 00:00 07:00 7.00 0 0 COMPZ WHDBO NUND T ND tree, Install blanking plug, NU BOPE, Install upper and lower VBR's. 07:00 11:30 4.50 0 0 COMPZ WHDBO BOPE T AOGCC notified, Witness of test waived by Jeff Jones. Conduct BOP test at 250 / 2,500 psi on annular and 250 / 3,500 psi on BOP Rams. Test rams and annular w/ 4 1/2 Test it. 11:30 12:00 0.50 0 0 COMPZ WHDBO MPSP T Pull Blanking plug and BPV. 12:00 15:00 3.00 0 2,893 COMPZ RPCOM SLKL T Held PJSM with Rig crew and HES Slick line crew on RU and pulling of valves. RU lubricator, PT @ 1,000 psi - good test. RIH and set catcher on DBP plug at 2,893 -ft.. POOH and RIH to 2,556 -ft and pull dummy valve. POOH. 15:00 19:30 4.50 0 0 COMPZ RPCOM CIRC T RU to reverse circulate - (Found IA valve was froze up, Thaw out valve and well head with steam blanket.) Reverse circulate back to rig pits to confirm. Blow air through kill line to verify open. PT kill line to tank at 250 / 3,500 psi. Reverse circulate 190 bbls of 3% KCL - Sea water at 1.5 bpm @ 60 psi through open pocket. 19:30 00:00 4.50 0 2,893 COMPZ RPCOM SLKL T RIH with KOT and set dummy valve in open GLM @2,556 -ft. POOH and redress tool. RIH with KOT and pull SOV from GLM @ 2,837 -ft. POOH, drop SOV and PU dummy valve. RIH and set DV at 2,837 -ft. POOH and change tools to fish catcher, RIH with GR pulling tool and POOH with catcher sub, RIH with 2" RS pulling tool and POOH with prong. RIH with PRS to pull 3.75" DBP plug from 2,893-ft. Page 13 of 18 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/31/2011 24 hr Summary POOH with DBP plug. RD Slickline. Pull TC -ESP completion to flowthru packer. cable found pulled from top of packer, cable checks good below packer. Hotshot packer to Baker shop. Monitor well. Swap cable spools. 00:00 01:45 1.75 2,893 0 COMPZ RPCOM SLKL T POOH with 3.75" DBP plug from 2,893 -ft. RDMO Slickline. 01:45 02:00 0.25 0 0 COMPZ RPCOM SFTY T PJSM- discussed hazards with shearing flowthru packer and pulling of ESP completion. 02:00 03:00 1.00 0 0 COMPZ RPCOM PULD T Pull landing joint, set blanking sleeve, set landing joint, install FOSV and hook up to top drive. 03:00 05:00 2.00 0 0 COMPZ RPCOM THGR T Pick up to 150k, 5k over estimated shear weight of packer. work several times with no success, work pick weight to 200k before packer sheared, let elements relax 10 minutes, PUH 110k up wt. 10 -ft and caught weight, drop down and let elements relax, pull tubing hanger to floor 103k up wt, penetrator slightly loose, scrape mark dow outside of connection, no resistance found at connection, cut cable 2 -ft below splice, no resistance on all three legs, short down hole. confer with town engineer. 05:00 11:30 6.50 0 4,727 COMPZ RPCOM CIRC T Circulate 504 bbls of 3% KCL - Sea water at max 3 bpm or 600 psi through ESP pump as per Baker Reps. 11:30 12:00 0.50 0 0 COMPZ RPCOM PULD T Lay down TBG Hanger and Blow down Top drive. 12:00 13:00 1.00 0 0 COMPZ RPCOM OTHR T Shuffle 3 1/2 DP in derrick in case needed after pull of ESP Completion 13:00 17:00 4.00 0 4,760 COMPZ RPCOM TRIP T PJSM, Pull off bottom from 4,760 -ft. Pull 15 -ft and haung up to 125k, sit down to 50k then pull free at 140k, Lay down first joint, Continue to POOH w/ completion 17:00 17:30 0.50 4,760 2,090 COMPZ RPCOM PULD T On surface with Twin Seal Packer, off load and send to Prudhoe. MEG wire, all good, cut cable and clamp at top or second full joint below packer, set in slips. 45 ea. 4 1/2" Cannon cross clamps recovered. 17:30 21:30 4.00 2,090 2,090 COMPZ RPCOM OWFF T Monitor well on trip tank.clean and clear floors, preform rig maintenance checks. Page 14 of 18 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 2,090 2,092 COMPZ RPCOM OTHR T PJSM- loading hazards of cable spool to rig. MIRU crane, Off load used cable spool, load new cable spool, inspect and find new cable spool damaged, centrilift rep assures original spool has enough wire, remove new spool and load original cable spool. RDMO crane, assemble spooler guard rails. bring in packer and clamps. 01/01/2012 Swap cable spools. Lost DGU communication. Pull TC -ESP completion, Tech Wire worn in two at bottom of motor. MU and install 8.0" centralizer to bottom of MGU Change out and service seal sections. MU new MLE and connect to motor. 00:00 00:30 0.50 2,092 2,092 COMPZ RPCOM OTHR T Continue rigging up spooler guards. Call from Centrilift Rep, he double checked and found not enough wire left on original spool as per his records. 00:30 01:30 1.00 2,092 2,092 COMPZ RPCOM OTHR T PJSM- loading and unloading cable spools„ MIRU crane, swap out original spool for new spool as per Centrilift recomendation. RDMO crane. 01:30 05:30 4.00 2,092 2,032 COMPZ RPCOM PULL T Install spooler guards, cut approximatly 400 -ft bad cable on new spool, MEG cable, good. PU and drop 2 joints 4 1/2" tbg, MU packer, no discharge pressure or temp signal from DGU. confer with town engineer 05:30 09:00 3.50 2,032 2,032 COMPZ RPCOM OTHR T Call for crane to swap spools to pull completion to ESP equipment. 09:00 12:00 3.00 2,032 89 COMPZ RPCOM TRIP T POOH from 2,032 -ft to 89 -ft with ESP completion 12:00 14:00 2.00 89 0 COMPZ RPCOM PULD T Continue to Pull ESP components to surface - Found Itec wire to parted at bottom of motor due to wearing on CSG wall while RIH. Centralizer was 5.85" OD and motor is 5.65" OD. Call Baker Machine and had a 8" OD centralizer built to maintain standoff for Itec wire running along 5.85" OD motor. 14:00 15:30 1.50 0 28 COMPZ RPCOM OTHR T RIH and Lay down tandem seal units. PU replacement Tandem seal section and MU same. Preparing to service when crane arrived. monitor well on trip tank. 15:30 17:00 1.50 28 28 COMPZ RPCOM OTHR T Swap out ESP Cable spool. 17:00 23:00 6.00 28 28 COMPZ RPCOM OTHR T Continue with service of tandam seal section, MU MLE to cable. Phase to Phase and Phase to Ground good. Losses to well average 7 bph. 23:00 23:15 0.25 28 28 COMPZ RPCOM SFTY T PJSM- discussed hazards of running ESP equipment. Page 15 of 18 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 28 28 COMPZ RPCOM PULD T PU MGU / motor / seal section / ESP / DGU to floor, lay down 5.85" bottom centralizer and MU 8.0" centralizer to bottom of MGU, MU Tech Wire to MGU, MLE to motor. 01/02/2012 Install TC -ESP with Flowthru Packer completion, make final splice and test. Land tubing hanger, test seals. Pull ISO sleeve and set TWC. ND BOPE. 00:00 02:00 2.00 28 78 COMPZ RPCOM PULD T Continue working up ESP seal sections installing 2 flat guards / 3 protectolizers, connect Tech Wire to DGU, test cable and ESP equipment, 02:00 05:30 3.50 78 2,098 COMPZ RPCOM RCST T Continue RIH with ESP completion to Baker Flowthru Packer as per original run order, MEG wire every 1,000 -ft and at packer prior to making up splice, record all readings. 05:30 08:30 3.00 2,098 2,098 COMPZ RPCOM OTHR T MU feed thru splice at Twin Seal Packer 08:30 12:00 3.50 2,098 4,760 COMPZ RPCOM RCST T Continue to RIH w/ ESP completion from 2,098 -ft to 4760 -ft. 12:00 13:00 1.00 4,760 4,760 COMPZ RPCOM OTHR T PU landing jt and make up to FMC TBG Hanger. PU and MU to TBG String. 13:00 16:00 3.00 4,760 4,760 COMPZ RPCOM OTHR T Make final splice in ESP cable 16:00 17:00 1.00 4,760 4,790 COMPZ RPCOM THGR T Land FMC TBG hanger, RILDS, Set TWC. 17:00 23:00 6.00 4,790 4,790 COMPZ RPCOM THGR T RU test equipment and begin TBG hanger seals test. unable to get test with TWC against closed blind rams, open rams and set short landing joint, RU test equipment, no joy with test, pull short landing joint and set long landing joint with intigrated isolation sleeve. rig up direct to wing V valve in cellar and test hanger seals to 5000 psi, solid 15 minutes, charted. 23:00 00:00 1.00 0 0 COMPZ WELCTL NUND T PJSM- ND BOPE breaking all 11" stack breaks to swap out 11" 5m Shaffer for 11" 5m Double BOP's. Remove upper and lower VBR's. 01/03/2012 Continue ND BOPE. NU tree and test. Test ESP connections. Pull TWC. RU Slickline. Set plug and catcher. Pull lower DV. Load IA / TBG with diesel. Set DV. 00:00 05:00 5.00 0 0 COMPZ WELCTL NUND T Continue ND BOPE breaking all 11" stack breaks to swap out 11" 5m Shaffer for 11" 5m Double BOP's. Remove upper and lower VBR's. Set back on stump. 05:00 05:30 0.50 0 0 COMPZ WELCTL OTHR T Make ESP cable integrity check. 05:30 07:30 2.00 0 0 COMPZ WELCTL NUND T NU Tree. Page 16 of 18 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode. T Comment 07:30 12:00 4.50 0 0 COMPZ RPCOM PRTS T Pressure test TBG head adapter and Tree 250/5000. Had Problems with test plug and had a leaking connection. Was able to obtain test on chart. Meg ESP Cable, tested good. Pull two way check valve and Set TIW for SLickline operation. 12:00 13:30 1.50 0 0 COMPZ RPCOM SLKL T PJSM- Hazards with rigging up Slickline. RU Slickline, pressure test equipment. 13:30 15:30 2.00 0 2,893 COMPZ RPCOM SLKL T RIH with DBP Plug and set at 2,893 -ft. POOH with S /L. R/U Prong and RIH and set Prong in Plug at 2,893 -ft. Test Prong and Plug to 500 psi. 15:30 16:00 0.50 0 0 COMPZ RPCOM SLKL T NU and RIH with Catcher Sub. Set Catcher above Prong and POOH. 16:00 17:00 1.00 0 0 COMPZ RPCOM SLKL T MU and RIH with kick over tool. Locate and Pull dummy valve from lower GLM at 2,837 -ft. POOH and R/B Slick -line. 17:00 20:00 3.00 0 0 COMPZ RPCOM CIRC T R/U and Pump Freeze Protect well at 2.5 bpm, 700 psi ICP, pump 210 bbls diesel around 2.5 bpm at 800 psi FCP. monitor well, T =100 psi, IA = 100 psi. 20:00 20:15 0.25 0 0 COMPZ RPCOM SFTY T PJSM with LRS, HES and Barker Reps- communication and high pressure pumping. 20:15 00:00 3.75 0 0 COMPZ RPCOM SLKL T RIH with KOT and 1" dummy valve to set at 2,837 -ft, sat dow in upper GLM at 2,556 -ft, POOH and redress tool, RBIH with same to 2,837 -ft, made several attempts to keep valve latched into profile, no success, POOH w/ dummy valve, redress tool with new valve, RBIH with same set 1" dummy valve at 2,837 -ft, POOH. 01/04/2012 Set Packer per program. MIT -IA. Bleed IA down per Centrilift schedule. Make final ESP cable integrity tests. Set SOV. RD Slickline. Set BPV. RDMO Nordic Rig 3. 00:00 02:00 2.00 0 0 COMPZ RPCOM PACK T Pressure test equipment 4000 psi. Start setting sequence for Baker 51A6 Twin Seal Packer, pressure up tbg to 2700 psi for 5 min. Bleed tbg to 1000 psi. attempt to pressure up IA, will not pressure up past 850 psi, bleed IA to 100 psi, pressure tbg up to 3000 psi for 5 min, bleed tbg to 1000 psi, IA will not pressure up past 850 psi at .8 bpm, bled IA to 100 psi, pressure up tbg to 3600 psi and hold 5 min bleed tbg to 500 psi, pressure IA to 1550 psi at 2 bpm, holding, pressure tbg to 3600 psi for 5 min, bleed tbg to 0 psi, IA at 1500 psi. Meg ESP cable all good. Page 17 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:00 1.00 0 0 COMPZ RPCOM PRTS T Chart 30 minute MIT -IA, lost 100 psi in 15 min, bump back to 1550 psi, good, 03:00 06:00 3.00 0 0 COMPZ RPCOM PRTS T While conducting Centrilift depressurization schedule the following slick line work was conducted; Pulling of the dummy valve from lower GLM @ 2,837 -ft. 2,000 psi (tbg to csg shear) SOV was set at 2,837 -ft. 06:00 07:00 1.00 0 0 COMPZ RPCOM SLKL T RD Slickline and Un -load tools and equipment from Rig floor. 07:00 08:00 1.00 0 0 COMPZ RPCOM MPSP T Installed CIW 4" Type 'H" BPV. Made final check of ESP Cable, Tested Good. 08:00 10:00 2.00 0 0 COMPZ MOVE DMOB T Clean Cellar area and Tree. RDMO Nordic #3. RIG RELEASED AT 10:00 A.M. Page 18 of 18 • ( ZT -zzo Regg, James B (DOA) Prt irfe Z53v From: Schwartz, Guy L (DOA) Sent: Wednesday, December 21, 2011 10:51 AM To: Nelson, Erik Q Cc: Gober, Howard; Regg, James B (DOA) Subject: RE: 2T -220 (PTD #198 -253) BOPE test issue... Erik, Thanks for the explanation. I also appreciate your relaying the conditions of sundry operations to the other folks at ConocoPhillips. This was an unusual situation but we can still use it as a learning tool. As for the Commission, getting the operator a hard copy or scan of the sundry (once signed) sooner would also help relieve this problem. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Nelson, Erik Q [ mailto: Erik.NelsonOconocophillips.com] Sent: Tuesday, December 20, 2011 8:01 PM To: Schwartz, Guy L (DOA) Cc: Gober, Howard Subject: 2T -220 (PTD #198 -253) BOPE test issue... Guy, As we discussed on the phone earlier this afternoon we had a number of issues that led to our testing of the BOPE to 250/2500 psi instead of the 250/3500 psi specified in the Sundry Approval #311 -378. In this workover there is a possibility that we will have to install a second casing string. In an attempt to avoid a late night phone call to you seeking authorization to proceed I submitted an Application for Sundry Approval due to this possibility. After we spoke about what was submitted I thought we would just pick up and go on under the Sundry if we needed to install the second casing string. After asking for and receiving a verbal authorization to proceed we went ahead with the workover as if we were not operating under a Sundry. Due to holiday related absences at AOGCC the Sundry Approval did not get to me until today so there was no way I would have known to test the BOPE to 250/3500 psi. Moving forward I have communicated to my Supervisor and fellow Wells En• ineers that AOGCC re•ards an operation operating under a Sundry to be under that Sund rom start to finish and not when we •et to the •art of the operation which requires a Sundry. Thank you for your assistance in resolving this matter. Have a great Holiday Season. )6. Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 1 • • Regg, James B (DOA) From: Nordic 3 Toolpusher [n1434 @conocophillips.com] Sent: Tuesday, December 20, 2011 12:32 PM To: Regg, James B (DOA) Cc: Nordic 3 Company Man Subject: RE: Nordic 3 12 -19 -11 Jim, I have let the town engineer know and forwarded this e-mail to him and will get back to you when I have more 9 9 answers. We tested to the pressures indicated in the well plan. Thanks, Brian From: Regg, James B (DOA) [mailto:jim.reqg©alaska.gov] Sent: Tuesday, December 20, 2011 11:05 AM To: Nordic 3 Toolpusher Cc: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: [EXTERNAL]RE: Nordic 3 12 -19 -11 Re: BOPE test pressure So, is 2500psi test pressure a typo or is this well another one of those subsidence workovers (like KRU 2T -03) that have a pressure restriction, thus the reason for not testing to pressure required on Sundry approval? Refer to attached ( "Due to the maximum 3,000 psi rating of the casing head, we cannot comply with the 3500 psi BOP test pressure stated in the approved Sundry without significant risk and possible injury to our personnel. ") You need to make note in the remarks justifying lower BOPE test pressure than required by regulations; issue needs to be clearly addressed in Sundry application as noted in attached email so it can be properly documented in our approval. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Nordic 3 Toolpusher [ mailto :n1434Caconocophillips.com] Sent: Monday, December 19, 2011 7:15 PM To: DOA AOGCC Prudhoe Bay; Nordic 3 Company Man; Regg, James B (DOA); Brooks, Phoebe L (DOA); Wedin, Ben (Nordic - Calista) Subject: Nordic 3 12 -19 -11 Brian Pederson / Andy Anderson Nordic Rig 3 907 - 659 -7438 1 • • KAA. Zr- Z zo P iqs - Zs3 Regg, James B (DOA) From: Regg, James B (DOA) ( Z�zc �t Sent: Tuesday, December 20, 2011 11:05 AM To: Nordic 3 Toolpusher Cc: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: Nordic 3 12 -19 -11 Attachments: RE: KRU 2T -03 PTD 1861420, Sundry approval 311 -305 Re: BOPE test pressure So, is 2500psi test pressure a typo or is this well another one of those subsidence workovers (like KRU 2T -03) that have a pressure restriction, thus the reason for not testing to pressure required on Sundry approval? Refer to attached ( "Due to the maximum 3,000 psi rating of the casing head, we cannot comply with the 3500 psi BOP test pressure stated in the approved Sundry without significant risk and possible injury to our personnel. ") You need to make note in the remarks justifying lower BOPE test pressure than required by regulations; issue needs to be clearly addressed in Sundry application as noted in attached email so it can be properly documented in our approval. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Nordic 3 Toolpusher [ mailto :n1434 Sent: Monday, December 19, 2011 7:15 PM To: DOA AOGCC Prudhoe Bay; Nordic 3 Company Man; Regg, James B (DOA); Brooks, Phoebe L (DOA); Wedin, Ben (Nordic - Calista) Subject: Nordic 3 12 -19 -11 Brian Pederson / Andy Anderson Nordic Rig 3 907 - 659 -7438 II 1 le • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.reggCaialaska.gov doa. aogcc. prud hoe. bav(c'D.alaska. gov phoebe.brooksC alaska.aov Contractor: Nordic Rig No.: 3 DATE: 12/19/11 Rig Rep.: Pederson / Brown Rig Phone: 659 -7438 Rig Fax: 659 -7566 Operator: CPAI Op. Phone: 659 -7446 Op. Fax: 659 -7566 Rep.: Boehme / Hinkel E -Mail n1433 @conocophillips.com Well Name: 2T -220 PTD # 1982530 i,,nAnd 3 II_ 37g Operation: Drlg: Workover: X Explor.: / 7t1/ S Test: Initial: X Weekly: Bi- Weekly Test Pressure: Rams: 250/2500 Annular: 250/2500 Valves: 250/2500 3S - MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result s 3 ` yz, ,, Location Gen.: P Well Sign P Upper Kelly 1 P Q. Housekeeping: P Drl. Rig P Lower Kelly 1 P U PTD On Location P Hazard Sec. P Ball Type 1 P ` e Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 1 P J )34: BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm / ? /,,,i Stripper 0 NA Trip Tank P P Annular Preventer 1 11 P Pit Level Indicators P P #1 Rams 1 2 7 /8x5VBR P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 2 7 /8x5VBR P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 0 NA HCR Valves 2 3 1/8" P Kill Line Valves 2 3 1/8" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time /Pressure Test Result System Pressure 3050 P CHOKE MANIFOLD: Pressure After Closure 1900 P Quantity Test Result 200 psi Attained 18 P No. Valves 12 P Full Pressure Attained 99 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @2000 CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 6.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Supervisor at: jim.regq alaska.gov Remarks: FSV Misc P = 4W EUE FOSV. Test was shut down after testing choke to troubleshoot and repair FMC blanking plug 0-Ring failure, Test was resumed succesfully. 24 HOUR NOTICE GIVEN YES X NO Waived By Chuck Scheve Date 12/16/11 Time 19:07 Witness Test start 21:30 Finish 03:30 Form 10 -424 (Revised 01/2011) Nordic 3 12 -19 -11 • • I'M /AA 3 ' SEAN PARNELL, GOVERNOR 1 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Nelson Wells Engineer S,3 ConocoPhillips Alaska, Inc. $ r� P.O. Box 100360 l Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, 2T -220 Sundry Number: 31k -31$ , Dear Mr. Nelson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. /1<-, Chair DATED this )�° day of December, 2011. Encl. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Eivprit 1 :(, ?11) 08 December 2011 Alaska Ancnorage �i� Cons. Commission Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T -220 (PTD 198 -253). Well 2T -220 was drilled in 1999 and completed as a single completion in the Tabasco formation. The well was completed with an open -hole gravel pack and placed on artificial lift with an electrical submersible pump (ESP). Recently, ConocoPhillips Alaska initiated a policy requiring two barriers from any energized fluid (i.e. reservoir fluids, power fluids, lift gas, etc.). Consequently, we must retrofit all of our packerless single casing ESP wells at West Sake and Tabasco with a 2 barrier. This can be done by either installing a packer or an inner casing string. The primary objective of this workover is to install an ESP with a feed -thru packer, which, along with a competent production casing string, will satisfy our barrier requirements. This, in and of itself, does not require Sundry Approval; but, if the production casing is found to be compromised, our backup plan is to install an inner 7" casing string then an ESP with a feed -thru packer, which does require Sundry Approval, hence the reason for this pre - emptive Application for Sundry Approval. If you have any questions or require any further information, please contact me at 263 -4693. Regards, Erik Q. Nelson Wells Engineer CPAI Drilling and Well , • ki , N(, `\ ��� ALASKA OIL ANA S ON COMMISSION • RECEIVED OL, , ) . i APPLICATION FOR SUNDRY APPROVALS 20 A25.280 P r 4I k a g ppro c7 eh 1$3100 1. Type of Request: Abandon Aug for Redrill Perforate Peoraa te New w � Pool Repair well �; Suspend r Rug Perforations IT Perforate F. Pull Tubing r Operational Shutdown r Re -enter Susp. Well IT Stimulate r Alter casing PI 'Other: it 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F)) . Exploratory r 198 -253 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20283 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No p 2T -220 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25569 • Kuparuk River Field / Tabasco Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5752 _ 3509 • 5527' 3355' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 112' 112' SURFACE 4953 9.625 4990' 3045' RAVEL PACK OPEN HOLE 4850' 4" 4887' 2991' W/ LINER SCREENS 865 4" 5752' 3509' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4961' -5517' 3030' -3348' 4.5 L -80 4784 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SC -1 GRAVEL PACK PACKER MD= 4852 TVD= 2974 NO SSSV 12. Attachments: Description Summary of Proposal Fli 13. Well Class after proposed work: r Detailed Operations Program r BOP Sketch r Exploratory Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/11/2011 Oil Pii - Gas r WDSPL ri Suspended r 16. Verbal Approval: Date: 12• T • (( WINJ r GINJ r WAG rI Abandoned IT Commission Representative: c5 Sc-ltuwwr -FZ GSTOR E, SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson @ 263 -4693 Printed Name Erik Nelson Title: Wells Engineer Signature Phone: 263 -4693 Da L I Commission Use Only 2t Sundry Number:3( ('31 g Conditions of approval: Notify Commission so that a representative may witness vvv Plug Integrity r BOP Test hs. Mechanical Integrity Test Location Clearance E Other: "� psG , / / Subsequent Form Required: /6 - • 0 ill , APPROVED BY / Z I 14 , Approved by: OMMISSIONER THE COMMISSION Date: S DEC 19 ` :- N 1L � ` Form 10 -403 Revised 20�i 1 R I fl VI Lftwo ( ` 9 ubm it in Duplt A ii • • 2T -220 Expense Rig Workover PTD #: 198 -253 Current Status The ESP currently in well 2T -220 has not functioned since installation and the well has been freeze protected and is shut -in. Scope of Work Pull 4 -W ESP completion. Scrape, inspect, and pressure test 9 -5/8" csg. M0 ,! 'Option #1 - If the 9 -5/8" csg passes pressure test then we'll run a new 4 -'/" ESP completion with a feed - #1.1c, -(a/thru k_ ,� Option #2 - In the event the 9 -5/8" csg does not pass the pressure test we will tie -in a 7" csg string to the top of the 4" Gravel Pack Screens and bring it to surface. Then we'll run a new 3 - %" ESP completion back in with a feed -thru pkr. General Well info MASP: 1092 psi Reservoir pressure /TVD: 1411 psi / 3188' TVD Using SBHP measured on 10 July 2009 of 1276 psi at 4650' MD (2872' TVD and 1233 psi gradient stop at 4454' MD (2772' TVD) Wellhead type /pressure rating: FMC Horizontal Unihead / 11" 5M BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe TIFL / MIT -IA / MIT -OA: NA due to packerless ESP completion Well Type: Producer Estimated Start Date: 11 December 2011 Production Engineer: Thomas Nenahlo RWO Engineer: Erik Q. Nelson Work: 263 — 4693 • Cell: 903 — 7407 ,Q, r E -Mail: Erik.Nelson @conocophillips.com Q % /\ .1- �s7" Proposed Procedure from failure of pressure test on 9 -5/8" csg: 1. TIH w/ Baker anchor assembly and 4 -1/2" PBR w/ 15' stroke. 2. Latch into Baker SC -1 pkr, shear PBR, TOOH sideways w/ polish bore and rep to run 7" csg.,. 3. ND BOPE, ND tbg head, U new 7" csg head, NU BOPE. (3�� -e 5j 1 ' / ppe. @, 4. Test break to 250/ psi. 351O p> 1 .Zob A.4•0 5. RU 7" csg handling eqpt and TIH w/ 7" csg. 6. Stab into PBR, space out, and land 7" csg on slips. i7. ND BOPE, set IC POs, PT POs, NU new 3 -1/2" tbg head, NU BOPE, and test breaks. ,8. MU and TIH w/ ESP on 3 -1/2" tbg w/ Baker 3 -1/2" x 7" feed -thru pkr. �9. MU tbg hgr, make final splice of ESP cable to penetrators. Circulate gelled diesel or IPF down the IA to 3000' MD. Land hanger. RILDS. Pull landing joint. - RU Slickline: RIH to set WRP below bottom mandrel. Set catcher sub on top. A Install two -way check. ND BOPE. Test ESP cable integrity. 12. NU and test tree to 250/5000 psi. Pull two -way check. 13. Pressure up on tubing to set the packer. PT tubing to 2500 psi. Bleed tubing down to 1500 psi, PT annulus to 2500 psi. Bleed IA to zero, bleed tbg to zero, quickly ramp up IA pressure to shear the SOV. 14. Set BPV and RDMO Nordic #3. Proposed Procedure continued on next page: • • Post -Riq Work: 1. Pull BPV 2. RU Slickline 3. Pull SOV from upper mandrel & replace w/ DV 4. Pull DV from bottom mandrel and replace w/ SOV 5. Pull catcher sub 6. PuII WRP 7. Install TTC -ESP, packoff, and slipstop. 8. Handover to Ops • • COI1oCOPhilll Tabasco Well: 2T -220 2011 RWO OPTION #2 COMPLETION API: 50- 103- 20283 -00 Conductor: PTD: 198 - 253 ` DS 16 ", 62.5 #, H -40 to 112' Wellhead: FMC Horiz X -mas Tree: 4- 1/16 ", 5K psi Production Casing: Lift Threads: 5" RH Acme 9 -5/8 ", 40 #, L -80 to 4990' BPV: 4" CIW Type 'H' Proposed 3 -1/2" Completion Liner / GP Screens • Tubing = 3 -1/2 ", 9.3 #, L -80, 8rd EUE / 4 ", 11.6 #, L -80 BTCM -SCC • 2.313" DS- nipple at 500' • 3 -1/2" KBG2 -9 GLM • Baker 3 -1/2" x 7" feed -thru packer • 3 -1/2" KBG2 -9 GLM • Baker Centrilift TC -ESP 4 3 -1/2 ", 9.3 #, L -80, 8rd EUE Proposed 7" Csq String • Casing = 7 ", 26 #, L -80, BTCM • 80 -47 Seal Assembly 15' SBE • 4 -1/2" PBR 1- 3 -1/2" x 7" Baker feed -thru pkr @ -4600 ft RKB • Baker EBH -2 anchor assembly r I 1 Baker WELLLIFT Motor Gauge Unit c � a N W 4 7 ", 26 #, L -80, BTCM V - V ' V 4 -1/2" PBR @ 4856' RKB g g 1- Baker SC -1 Pkr @ 4856' RKB 4 4" Baker Weld GP Screens @ 4856 - 5517' RKB EI _ _ Last Updated: 8- Dec -11 Updated by: EQN t .UP • 2T -220 i p 1 ,. Ct�t t i Well Attributes Max Angle MD TD `"' `' . t we 501032028300 IField Name TABASCO _ JPRO Status In 66 55 IMO ( 2 K 9 69 Act 5 7 52 0 __ [_szmaYfvl' - " C nt H2S (ppm) Date An n lotion End Date KB - Grd (ft) Ri g Release DMe ".' SSSV. NONE 50 6/18/2009 Last WO: 3/9/2009 36 81 ' 1118/1999 _ _ 61c C of g 2T-2at11 345.57 PM --- - - - SSchematic ematic Actual Annotation Depth (ftKB) End Date Annotat iLast Mod ... End Date Last Tag_ ELMD 4,699 0 11/8/2008 Rev Reason' FORMAT UPDATE 1 Imosbor 1 4/4/2011 Casin. Stnn.s HANGER. 28 Casing Descdption String 0... String ID .. Top (ftKB) Set Depth (f Set Depth (TVD) . String Wt... Str g String Top ThM CONDUCTOR 16 _ 15.062 38.0 1120 112.0 62.58 H - 40 WELDED ' Casing Description String O.. Sting ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd ' SURFACE 9518 8.697 37.0 4,990.0 3,044.5 40.00 L - 80 BTC I Casing Deuription String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thnl „a„ 1 Gravel Pack Open 4.63 4.000 4,851.7 5,752.0 3,509.4 11.60 L -80 SealLock Hole w/ Liner Screens CONDUCTOR, Liner Details 38-112 L .i:' Top Depth ' (ND) Top Inel N mi... Top (9KB) 'ftKB) 11 Kern Desert lion Comment ID (in) ( a 4,851.7 2,973.6 59.35 PACKER BAKER MODEL SC - 1 GRAVEL PACK PACKER 4.750 5 h 4,861.6 2,978.6 59 39 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 4.875 IIMIIIIS, 4,863.8 2,979.7 59.40, SBE BAKER SEAL BORE ✓ 4.750 4,885.1 2,990.5 59 50 KOIV BAKER MODEL 'B' KOIV 3.437 ESP ' - _. - - - - -- 5 = 4 3 5 8 87 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 MANDREL. ... _.._ -_.. _. a... 3,000 � �� 5,517.2 3,348.5 50 21 0-RING BAKER O-RING SUB 2.375 5,518.3 3,349.2 50 -18 VALVE BAKER FLAPPER VALVE (2) 2.875 ';,, 1 5,529.0 3,356.1 49 89 OPEN HOLE ` Tubing Strings Tubing Description 'Str n 0.. ,String ID Top (ftKB) Set Depth (i Set Depth (ND) ... String Wt... String String Top Thrd ESP VI_ ESP TUBING I 4 3958 284 I 4,7840 I 2,9392 I 12.60 L-80 j _ . _ IBT MANDREL,- 4,576 ' Completion Details Top Depth (ND) Top Inc) Nom)... Top (ftKB) .. (ftKB) el Rem Des tion _ -_..._ Comment __- ID (in) 28 4 28.4 -0.58 HANGER FMC Tubing Hanger w/ 4.5" Pup 4.500 4,634.4 2,863.6 59.20 SLEEVE -C Baker 3.813" CMU Sliding Sleeve (closed) 3.813 SLEEVEC,___ _ 4,680.0 2, 887.0 60.12 GAUGE Baker Guardian Gauge with pups 3.965 4,631 4,723.3 2,908.6 59.90 XO - Reducing X -over 3.5" 8RD Pin x 4.5" IBT Box 3.500 4,724.0 2,908.9 59.89 ESP PUMP 538 Series pump w/ 5.47' gas separator section - 0.000 t; i I 4,743.0 2,918.4 59.79 ESP Intakes Gas Separator and Intake 0.000 4,748.4 2,921.2 59.76 SEAL 513 Series Tandem Seal Section 0.000 2 .__. 4,762.2 2,928 2 59.69 ESP MOTOR 562 Series Motor, 228 HP KMHG 2305Vl60A 0.000 PATCH,4,678 ---- -- ._ 5 4,781 -9, 2,938.1 5959 Centralizer Centralizer 3.500 s Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top Inc! Top (10(B) (ftKB) (1 Description Comment Run Date ID (in) 4,677.8 2,886.0 60.13 PATCH HES OWEN PERMANENT PATCH FOR LEAK IDENTIFIED 10/24/2009 3.375 @ 4780' ON LDL - ,,y 4,724 / ' � Perforations s ESP PUMP, $Slots 2 _ ., hot ESP Intakes, 4,743 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh• Type Comment SEAL, 4,748 4,961.4 5,517.0 3,029.5 3,348.3 TABASCO, 7/8/1999 99.0 IPERF OPEN HOLE GRAVEL PACK TE 1, 2T-220 ESP MOTOR, ____ ________ .... 4,762 Notes: General & Safety C2nlreb&ef, End d Data Annotation 4n7 4,782 4/17/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 3/17/2010 NOTE: LEAK @ 4689' @ BOTTOM OF PERMANENT PATCH 1 s Mant�rel Detains _ r * Top Depth Top Port - _ (TVD) Ind OD Valve Latch Si.. TRO Run Stn To• • B (8K6) (1 Make Model (in) Sere Type Type )in) (psi) Run Date Com... SURFACE, 1 3,000.1 2,150.0 66.30 Camco KBMG 1 ESP DMY BK - 5 0.000 0.0 3/28/2009 374,990' --- IPERF, - - 4,576.4 2,833.4 58.21 Camco KBMG 1 ESP DMY BK - 5 0.000 0.0 3/28/2009 4,961 -5,517 © ___ - -.- N Gravel Pads Open Hole w/ Liner Screens, °° 4,852 -5,752 TD (2T-220), - .. 5,752 . Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, December 09, 2011 1:26 PM To: 'Nelson, Erik Q' Subject: RE: Request for Verbal Approval on Application for Sundry Approval for 2T -220 (PTD #198 - 253)... Eric, You have verbal approval to proceed with the workover on 2T -220 as proposed. As per our conversation a step needs to be added that places a mechanical barrier in the 9 5/8" before removing the BOP and changing the wellhead configuration. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Nelson, Erik Q [ mailto: Erik.Nelson @conocophillips.com] Sent: Friday, December 09, 2011 10:46 AM To: Schwartz, Guy L (DOA) Subject: Request for Verbal Approval on Application for Sundry Approval for 2T -220 (PTD #198 - 253)... Guy, I'm writing to confirm our phone conversation about my request for verbal approval on my Application for Sundry Approval for 2T -220 (PTD #198 -253). Thank you for your consideration of my request. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #1590 700 G. Street Anchorage, AK 99501 Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 12/9/2011 :~ ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 r1'l', ~: w ~~~D Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~` ~' [ulJ ~~lt~~i~ i~ ~"' ~` `~ wag ~~~ ~~ttissio ~-~~~~v~rag~ q~-2~3 a-7- a-2o Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 July 21St. The corrosion inhibitor/sealant was pumped July 30th, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 2R_ 2K_ 2T POrf Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ff bbls ft al 2B-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n!a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30!2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7!21!2010 5.1 7/31/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2T-220 Run Date: 5/4/2010 May 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-220 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20283-00 ,~ ,~ z~~~ ,~~ _~ J' PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 / ~ ~ ~ aS3 Office: 907-273-3527 ~ `jC°~~~ Fax: 907-273-3535 rafael.b ~n Date: h7AY a ~ 2010 Signed: a i~~ ~ , WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: .Leak Detection Log: 2T-220 Run Date: 4/4/2010 Apri19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-220 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20283-00 ~y t„, m ~7 ; ,.~. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com ~~~~a~~ i 9 ~a u_ Date: ~T~~ ~ ~ ~ r. Signed: t f . WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2T-220 Run Date: 3/17/2010 March 19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-220 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20283-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A CUPY ur iH~ TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto q~ i ors, Date: MAR ~ ~ 2010 ,3 ~' ~5 l~ ~~( ~~ Signed: . A ~~a r~~ • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 1.00 Anchorage, Alaska 99501 RE: Patch Setting Record: 2T-220 Run Date: 10/25/2009 December 1, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-220 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20283-00 4' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-27 -3 5 , . ~ ,~ rafael.barre . ~ ~~t~n~ct~m` `~ ~~C ~ ~ X009 Date: ~~~s~'~i4-~ ~~~~ C;t~~e~. Uc ~~°n!~~i:~r; ~~chnr~ f~ Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Downhole Video: 2T-220 Run Date: 9/3/2009 The teclulical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 November 13, 2009 2T-220 Digital Video File 50-103-20283-00 ~~~~~~~ ~J~, i~ ~ ~~ 2 Q 1 CD Rom PLEASE ACKI~TOWLEDGE RECEIPT BY SIGNIIvTG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com Date: ,~~-a~3 ~ -~~~~ /~'~ ~. ~, ~' r ~` Signed: ~ • ~ WELL LOG TRANSNIITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2T-220 Run Date: 8/19/2009 September 9, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-220 15igital Data in LAS format, Dig'ital Log Image file 1 CD Rom 50-103-20283-00 ; ~~;,i~': .. ~..r.~v„ . ~~d~.~nH,+" _ „. .. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton VVireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-353~ rafael.barreto@halliburton. com ~ ~ ~ ~~~ ~'~'~~~ Date: ;`I; ~; ~ , ~~ `'. !1 j ' ~~ S igned: ~ S ' ,% ~' • • VV~~L ~Qi.~ TF'~I N~SM/TT~I L Ie~ PrtoAclive Dinqniosric SErtviar, Inic. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) E59-5102 RE : Cased Hole/Open Hole/Mechanicel Logs and/orTubing Inspection(Caliper/ MT~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the foqowing : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West lnternational Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8952 1) Caliper Report 21 Aug-09 2T,220 1 Report / EDE 50-103-20283-00 2) ~ .~"~'~~•F=± 9 i~ r~ ,4 ~~%~~ . : ~ ~.~ , ~ ~;i~s ~~ ~-~ ~ ~ ~ ~ ~ ,~ , Signed : - Date : AUG 2~ 20~~ Print Name: ~#as~a ~i4 ~ ~as Con~. Gorr~~i~sion Anch~ara~~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAOE, AK 99518 PMONE: (907)245-8951 FAX: (907)245-88852 E-NU-a: pdsanchoraae~memorvba.com WEBSITE: WWW.memorvloa.com c:~~,~~ ~e s~~o~oesx~~T~roa_c~.ao« '" !' r~ u Memory MultirFinger Catiper ~og Re~uits Sumt~r~ar~} Company: ConocoPhillips Alaska, lnc. Well: 2T-220 Log Date; August 21, 2009 Field: Tobasco Log No. : 6772 State: Alaska Run No.: 2 API No.: 50-103-20283-00 Pipe1 Desc.: 4.5" 12.6 Ib. L-80 IBT Top Log Intvll.: Surface Pipe1 Use: ESP Tubing Bot. Log Intvl1.: 4,706 Ft. (MD) fnspection Type : Corrosive & Mechanical Damage tnspection COMMENTS : This ca-iper data is tied into the Sliding S/eeve ~ 4,634' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage in the vicinity of a suspected tubing leak beiween 4,677' and 4,707'. The caliper recordings indicate the 4.5" tubing logged is in good condition, with no sig~ificant wall penetrations, areas of cxoss-sectional wall loss, or I.D. restrictions recorded. A 3-D log plot of the caliper recordings across the suspected tubing leak is included in this report. The caliper recordings indicate buckling at 4,481'. This is the second time a PDS caliper has been run in this well and the first time this 4.5" tubing has been logged. MAXIMUM REGORDED WALL PENETRATIONS: No significant wall penetrations (> 10%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 2%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. ~ ~~~~" ~;} ~c~~ ~c.~"~` ~~ r~ l,i i ~ ~~ .~ Field Engineer. N. Kesseru Analyst: C. Waldrop Witness: C. Fitzpatrick FroActive Diagnostic Services, Inc. / P.O. Bax 1369, Stafford, TX 77497 Phone: (281} or (88S) 565-9055 Fax: {ZS1) 565-1369 E-mail: PQS~amemarylog.corn Prudhoe Eay Field Office Phone: (907} F59-2307 Fax: {9d7) 659-2314 ~~ Z~ ~ ~5~~ ~ ~`~ ~ • • PDS Multifinger Caliper 3D Log Plot " S, ' Company : ConocoPhillips Alaska, Inc. Field : Tobasco Well : 2T-220 Date : August 21, 2009 Description : Detail of Caliper Recordings Across Suspected Tubing Leak (4,677' - 4,707). Correlatio• Recorded Dama e to Borehole Profile g ~ Pipe 1 4.5 in (16.9' - 4692.1') Well: Field: Company: Country: Survey Date: 2T-220 Tobasco ConocoPhillips Alaska, Inc USA August 21, 2009 ^ Approx. Tool Deviacion . Approx. Borehole Profile GLM 1 GLM 2 148 0 50 Damage Profi~e (°/a wall) / Tool Deviation (degrees) 20 303 615 927 1239 1553 1863 2178 ~ ~ 2489 LL c ~ 2801 Q v ~ 3136 3449 3 762 4069 4380 4692 100 Bottom of Survey = 148 • • PDS Report Overview 5.,,. Body Region Analysis Well: 2T-220 Survey Date: August 21, 2009 Feld: To6asco Too) Type: UW MFC 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Wei~t Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 ppf L-80 IBT 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body wp metal loss body 200 150 --- 100 - i~ - 50 ~ 0 ro 1 ro 10 to 1% 10°/a 20% 20 to 40 to over 40% 85% 85% Number of'oints anal se d total = 155 pene loss . 20 135 0 153 2 0 0 0 0 0 0 0 Damage Configuration ( body ) 10 0 isolated general line ring hole / poss pitting cortosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body ~ metal loss body 0 50 100 GLM 1 GLM 2 Bottom of Survey = 148 Analysis Overview page 2 PDS R~ORT JOINT TABULATION S~ Pipe: 4.5 in 12.6 ppf L-80 IBT Well: 2T-220 Body Wall: 0.271 in Field: Tobasco Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: August 21, 2009 Joint No. Jt. Depth (Ft) PE~n. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss %~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 17 0 0.01 3 1 3.93 PUP 1 20 0 0.01 2 1 3.94 2 51 t) 0.00 1 1 3.92 3 82 0 0.01 5 1 3.93 4 114 0 0.01 3 1 3.93 5 145 0 0.01 2 1 3.93 6 177 U 0.01 3 1 3.94 7 208 0 0.01 3 1 3.93 8 240 0 0.01 3 1 3.93 9 272 0 0.01 2 1 3.89 10 303 t) OA2 8 1 3.92 _ 11 334 0 0.01 3 1 3.94 12 365 0 0.01 2 1 3.94 13 397 (1 0.01 4 1 3.93 14 428 (1 0.00 1 1 3.93 15 460 0 0.01 3 1 3.92 16 491 0 0.01 3 1 3.93 17 523 0 0.01 4 1 3.93 18 554 0 0.01 4 1 3.90 19 586 ll 0.01 4 1 3.92 20 615 0 0.01 3 1 3.93 21 646 0 0.01 3 1 3.93 22 677 t) 0.01 3 1 3.92 23 709 0 0.01 3 1 3.93 24 741 0 0.01 3 1 3.93 25 772 0 0.01 2 1 3.91 26 804 0 0.01 3 1 3.93 27 835 0 0.01 3 1 3.94 28 864 0 0.01 3 1 3.93 29 895 l1 0.01 3 1 3.94 30 927 0 0.01 3 1 3.93 31 959 t) 0.01 3 1 3.94 32 990 l) 0.01 3 1 3.94 33 1022 0 0.01 3 1 3.92 34 1053 (1 0.01 3 1 3.92 35 1084 O 0.01 4 1 3.94 36 1116 U 0.01 4 1 3.93 37 1147 0 0.01 3 1 3.94 38 1177 0 0.01 4 1 3.93 39 1209 0 0.01 2 1 3.93 40 1239 0 0.01 3 1 3.92 41 12 71 t) 0.01 3 1 3.89 42 1303 U 0.01 3 1 3.88 43 1334 0 0.01 4 1 3.94 44 1365 0 0.01 3 1 3.94 45 1396 0 0.01 4 1 3.93 46 1428 0 0.01 4 1 3.94 47 1459 0 0.01 3 1 3.91 48 1490 0 0.01 3 1 3.93 49 1522 0 0.01 3 1 3.90 Penetra6on Body Metal Loss Body Page 1 PDS R~ORT JOINT TABULATION S~ Pipe: 4.5 in 12.6 ppf L-80 IBT Well: 2T-220 Body Wall: 0.271 in Field: Tobasco Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Norninal I.D.: 3.958 in Country: USA Survey Date: August 21, 2009 Joint No. Jt. Depth (Ft) Pc~n. UF~,c~t (Ins.) Pen. Body {Ins.) Pen. % Metal Loss % Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1553 0 0.03 10 1 3.89 51 1582 O 0.01 3 1 3.93 52 1613 0 0.01 3 1 3.93 53 1643 0 0.01 2 1 3.94 54 1674 l) 0.01 3 1 3.89 55 1706 l) 0.02 G 1 3.94 56 1737 l~ 0.01 2 1 3.93 57 1769 0 0.02 8 1 3.89 58 1800 0 0.00 1 1 3.89 59 1832 0 0.00 1 1 3.93 60 1863 0 0.01 2 1 3.93 61 1894 t~ 0.01 3 1 3.93 62 1926 O 0.01 Z 1 3.92 63 1957 0 ~.01 4 2 3.91 64 1988 0 0.03 10 1 3.93 65 2020 0 0.00 1 1 3.93 66 2051 0 0.02 9 1 3.93 67 2083 0 0.01 3 1 3.92 68 2114 ll 0.00 1 1 3.91 69 2146 0 0.02 8 1 3.91 70 2178 0 0.01 3 1 3.88 71 2208 U 0.00 1 1 3.92 72 2239 0 0.01 2 1 3.93 73 2271 U 0.00 1 1 3.93 74 2303 0 0.00 1 1 3.92 75 2333 0 0.00 1 2 3.93 76 2364 tl 0.01 2 1 3.92 77 2396 t1 0.02 t3 1 3.87 78 2426 t) 0.00 1 1 3.88 79 2457 O 0.02 9 1 3.88 80 2489 0 0.01 4 1 3.92 81 2521 0 0.01 2 1 3.90 82 2551 0 0.01 2 1 3.93 83 2583 O 0.02 8 1 3.90 84 2613 0 0.01 3 1 3.90 85 2644 O 0.00 1 1 3.89 86 2676 0 0.01 2 1 3.93 87 2707 l) 0.01 4 I 3.89 88 2738 0 0.01 2 1 3.92 89 2770 U 0.02 8 1 3.93 90 2801 0 0.00 1 1 .92 91 2831 t) 0.01 3 1 3.89 92 2861 l) OA2 9 1 3.91 93 2892 0 0.00 1 1 3.91 94 2923 0 0.01 2 1 3.93 95 2955 0 0.02 8 1 3.91 95.1 2986 t) 0.03 10 1 3.90 PUP 95.2 2996 0 0 0 0 N A GLM 1 Latch ~ 11:00 953 3003 0 0.03 10 1 3.89 PUP 96 3013 ll 0.03 10 1 3.93 Nenetration Body Metal Loss Body Page 2 PDS R~ORT JOINT TABULATION S~ Pipe: 4.5 in 12.6 ppf L-80 IBT Well: 2T-220 Body Wall: 0.271 in Field: Tobasco Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: August 21, 2009 Joint No. Jt. Depth (FL) I'c~n. UF~se~t (Ins.) Pen. Body (Ins.) Pen. % Metal loss °i~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3045 0 0.01 "3 1 3.92 98 3073 0 0.00 1 1 3.93 99 3105 0 0.00 1 1 3.88 100 3136 0 0.00 1 1 3.92 101 3168 0 0.01 3 1 3.93 102 3199 0 0.01 5 1 3.87 103 3230 l1 0.01 2 1 3.92 104 3262 0 0.01 3 1 3.91 105 3293 0 0.01 5 0 3.90 106 3324 0 0.01 3 1 3.92 107 3356 0 0.01 3 1 3.89 108 3387 0 0.01 3 1 3.92 109 3418 l) 0.01 2 1 3.92 110 3449 0 0.02 8 1 3.92 111 3481 0 0.01 4 1 3.92 112 3512 0 0.01 4 1 3.93 113 3543 ll 0.01 3 1 3.91 114 3574 0 0.01 3 1 3.91 115 3606 ~ 0.02 8 1 3.93 116 3636 0 0.00 1 1 3.92 117 3668 0 0.01 3 1 3.91 118 3699 0 0.02 9 1 3.89 119 3730 0 0.03 10 1 3.91 120 3762 0 0.01 3 1 3.91 121 3793 0 0.01 3 1 3.90 122 3824 0 0.01 3 1 3.91 123 3855 0 0.01 4 1 3.91 124 3887 0 0.01 2 1 3.89 125 3918 0 0.01 3 1 3.90 126 3949 0 0.01 3 1 3.90 127 3979 0 0.02 8 1 3.88 128 4007 0 0.02 8 1 3.91 129 4038 ll 0.01 3 1 3.87 130 4069 0 0.01 2 1 3.92 131 4100 0 0.01 4 1 3.91 132 4131 (~ 0.00 1 1 3.92 133 4162 ll 0.01 4 1 3.91 134 4194 U 0.01 3 1 3.92 135 4225 tl 0.01 3 1 3.92 136 4255 U 0.01 3 1 3.88 137 4287 l) 0.01 3 1 3.91 138 4318 U 0.01 4 1 3.91 139 4349 U 0.02 8 1 3.92 140 4380 0 0.02 6 1 3.90 141 4411 l) 0.01 4 1 3.88 142 4442 l) 0.00 1 1 3.90 143 4473 l1 0.02 £3 1 3.90 144 4505 i) 0.02 8 1 3.85 145 4535 0 0.02 7 1 3.90 145.1 4566 p 0.02 B 1 3.89 PUP _ Penetration Body Metal Loss Body Page 3 PDS R~ORT JOINT TABULATION S~ Pipe: 4.5 in 12.6 ppf L-80 IBT Well: 2T-220 Body Wall: 0.271 in Field: Tobasco Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: August 21, 2009 Joint No. )t. Deptfi (Ft.) Pc~n. UF~sct (Ins.) Pen. Body (Ins.) Pen. % Metal Loss %~ Min. I.D. Qns.) Comments Damage Profile (%wall) 0 50 100 145.2 4576 (1 0 0 U N A GLM 2 Latch @ 9:30 1453 4583 (1 0.02 9 1 3.89 PUP 146 4592 U 0.01 4 1 3.86 146.1 4624 (1 0.02 8 1 3.89 PUP 146.2 4634 0 0 0 l1 3.81 Baker CMU Slidin Sleeve Closed 146.3 4639 0 0.02 6 1 3.89 PUP 147 4648 0 0.02 8 1 3.91 147.1 4680 O 0 0 0 3.97 Baker Guardian Gau e with Pu s 148 4692 0 0.01 2 1 3.90 _ Penetration Body Metal Loss Body Page 4 - ConocOPhlliips :~L~~,h,i In:~ HPflGER, 28 KUP 2T-220 11 Attribut es An le 8 MD TD bore APW WI 501032028300 RNA Name TABASCO W dl SteWS PROD AoNM (l ~(M~) 66.55 2,958.69 Aa ~(~) 5,752.0 omnnt ',SSV. NONE 1125 (ppntl 220 Dah Amofatlon BM DYe 1/172009 Lact WO: 3l9l200 ItB-Grtl U9 9 36.81 Rlg RNease D~ 1118/1999 matanon asi Tag: EIMD ~ DePw (h~) ~ 4,699.0 9ia Dae 1182008 Mwlauon Rev Reason: ESP WORKOVER Bia Date M77/2009 _ :as Strl as§~9 Des~r~lfan 'ONDUCTOR asln9Descrlptlm ~URFACE s fl O 16 S1tYi90 95/8 _ SI'M~91D ... uP 1 ~~ n... et DqN~ ( 15.062 0.0 112.0 112-0 _ SnMD_.ITUP111141 I~,99.DOYI~ 3,044.,5~ 8.697 37.0 ._ 81~In9 Wt.. SMn9... 62.58 Hd0 I~40900 .I~~9_.I 91rM9 Top d WELDED a~m9 ~ma _. _ 2a.a ca~nnaM ~ laeve (dosec DuDs ESP AIPNIXt0., 3.000 ESP MPNDft0.. 1,576 Zone I Dete GAUGE, A 680 ESP Ir1el 4. ESF MOiOR, 4.762 GMrdar. ~ ~82 I~.ITm,~dl ~, I~' I,~e I~~ I~ i~, I"~ I~ I M~ I'~a~ I~~. I~~I ~aFA~E. Page 1 of 1 ~ Maunder, Tharrtas E (DQA) F~om: ~nnis, J J {,l.J.Ennis@conc~cflphiAips.com] Sent: Monday, July tl~, 2009 9:38 AM To: Maunder, Thomas E (QOA) Cc: Allsup-Qrake, Sharor~ K ~ubj~ct: RE: 2T-220 (198-253) Attachmen#s: 2T-220 iNel! work summary for Maunder 7=6-Q9.xls G4od morning Tom, ~ The weil work summary Shar€~n provided (one en~ry on 5i51€}9; inciudes tfise ''normai" pt~si rig actsvicies ~~a€ occurred. This well gave us some trouble ge##ing POP'd due to plugging below #he E5P in#ake, most likely in screens, preventing fluid snfilow. i've added same ofi these evenis to #he at~ached summary. Since things we~e dragging out, we decided to get the 404 submitted without waiting unti! POP occurred as usual. The well did finadiy ciear its throat on S115 anti was pump"tng -7fl00 bfpd prior to Si fior or~going CPF2 ini~t separator work. Please let me know if any other questions or cancerns. Jim Enr~fs % f enni~~corrocvphillip~.com ~~/~~VvY~JYY 1 ~`~ fst~~~~~a•z2~~ ~c~ i;~4~ a d, 4~ L. V y a ~~yw~ #d ii~~~~w% t1 ~ i. ~` ~ ?"~ ~ From: Maunder, Thomas E {pOA) [mailtc3:~om.maunder@alaska.gov] Sent; Su~d~y, July Q5, 20Q4 11:51 AM To: Ennis, a J ~ubj~t: zT-2zQ (1~8-253~ Jim, I ar~n reviewin~ tne 404 recently submitted fQe tMe workover ccanducted in late Mar~h Qn this well. Could you provide th~ pre- and pc~st~ rig w~rk summary? Emai1 is fine. Thanks in advance. Tom Maunder, PE AQ~UCG 7/5/2~09 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Well ^~ ~ Plug Perforations ~ Stimulate ^ Other ~ Alter Casing ^ Pull Tubing ^~ . Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drili Number: ConoCOPhillips Alaska, InC. Development ~• Exploratory ^ 198-253 /• 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20283-00 ' 7. KB Elevation (ft): 9. Weli Name and Number: RKB 31' • 2T-220 • 8. Property Designation: 10. Field/Pooi(s): ADL 25569 " Kuparuk River Fieid / Tabasco Oil Pool ` 11. Present Well Condition Summary: Total Depth measured 5752' • feet true vertical 3509' Y feet Plugs (measured) Effective Depth measured 5527' feet Junk (measured) true vertical 3355' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 81' 16" 112' 112' SURFACE 4959' 9-5/8" 4990' 3045' LINER 31' 4" 4887' 2992' LINER 630' 4" 5517' 3348' PerForation depth: Measured depth: open hole gravel pack 4961'-5517' ~ E~ ~ I VE D true vertical depth: 3029'-3348~ JUN ~ 0 2009 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4784' MD ~~aska ~ii Sc Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI - - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0' Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO ' Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Ennis @ 265- 1544 Printed Nam ~~f1f11S Title Wells Engineer /' q 6~ ~~ ~ Signature Phone: 265-1544 Date Pre ar n All u-Drake 263-4612 ~ G -~ ' ~*~.(~ y- c'~ Form 10-40 evised 04/2006 ~~~~~ ~~_ ,r ~~r ~', ZQ(~~ Submit Original Only ,~~~~~/~ ConocoPhillips :~~,.,h:;. ~~~~ '- KUP H2S(ppm) 'Date Annotation EntlDate >NE 220 I 1/V2009 Last W0~ 3/9 IDept~(kK6) IEndData IMnotation ~ ELMD 4,699.0 11/8/2008 Rev Reason: ESP WORKOVER 2T-220 rd (ft) Rig Release D: 36 81 1/18/1999 - -.. I End Date 4/172009 BTC HANGER.28 ESP MANDREL.- ~- 3,000 ESP MANOREL,- a.ne SLEEVE-C, _ 4,636 GAUGE, 4.680 -- ESP PUMP, 4.724 ESP Nt~ces, 6.743 SEAl.4.168 ESPMOTOR. SURiACE. .. 3]-9.990-. . . ~ . IPERG. 4.961-5.517 - - IMER -_ ~ 4.856~5.51]-- - TD (2T-420), S,152 i Description String 0... ~String ID ... Top (NKB) Se~ Dapth (t... Set Depth (ND) ... IString Wt... iString .., i5tring Top l 9 TUBING ~ 4 1/? I 1 QSR ~R 4 4 7R4 fl ~ 9iQ ~ I 1~ fi(1 i I-RO i IRT Com letion Det ails Top Depth (ND) Top Incl Top (itKB) (ftKB) I (°) Nem Dezcription Comme~ ID (in) 28.4 28 4I -0.58 HANGER FMC Tubing Hanger w/ 4.5" Pup 4.500 4,634.4 2,863.6 59.20 SLEEVE-C Baker 3.813" CMU Sliding Sleeve (closed) 3.873 4,680.0 2,887.0 60.12 GAUGE Baker Guardian Gauge with pups 3.965 4,723.3 2,9088 1 59.90 XO - Reducing X-over 3.5" 8RD Pin x 4.5" IBT Box 3.500 4,724-0 2,908.9 ~ 59.89~ ESP PUMP ~538 Senes pump w/ 5.47' gas sepa2ror section 0.000 4,743.0 2,918A~~ 59J9 I ESP Intakes Gas Separetor and Intake l 0.000 _ 4,748.4 2,9212I 59J6 i _ SEAL ~513 Series Tandem Seal Section 0.000 -_ ' 4,7622~' 2,g2g21, 59.69I __"."__"--__ ESP MOTOR ~562 Sedes Motor, 228 HP KMHG 2305Vt60A ~. I 0-000 4,787.9i 2,938.7~~,~ 59.59; Centralizer Centralizer I 3.500 ~ITubingDescription String~O ... StringlD... Top(HKB) SetDapih~f... SetDepth(ND)... StringWt.. String._ String TOpThrd GR~ AVEL PACK 4 I 4,856A 5,517.0 3,3483 , CompleUon Det ails Top Depth ~i ND l ) To I^~~ P P` , ftK8) ITo ftK6 ( .... .. . ... (°) Item D ription l . Commant ID.(inl. . 4.856.0 2.975J , 59.37IGRAVEL ~OPEN HOLE GRAVEL PACK 3/11/1999 Perforations $ . . . . . .. . - - "- -_- PACK I .. .. - l -----. __ _. Stots - Shot Top (TVD) Btm (TVD) I Dans Top (ftKB) Btrn (ftK8) (ftKe) (ftK6) Zone Date (zh~~~ Type CommeM 4,961. 5,517 ~ 3 029.3 3,348.3 TABASCO, 7/8/1999 I 99.0 IPERF OPEN HOLE GRAVEL PACK ''~ ~ I TE_1.2T-220 , ~ Notes: General & Safet Entl Date AnnoGtion 4/17/2009 ,NOTE:VIEWSCHEMATICwIAlaskaSchematic9.0 i - ... ..__ .__ . .__.___ . .__.__.__,.. .. .... .... .. . . ___~ Mandrel Details -- _ _--- - Top Depth Top Port ' I I -- ~ TR I St Run Dat _ TO deI ~ D P ~V e 1 Comm... _ __ , O.O 3,000g1 2,150.0 66.30 Camco 7 ESP DMY !KBMG BK-S O 000 ~ 2 4,576.4 2,83 34 5821 Camco IKBMG ~ 1 ESP DMY BK-S 0.000 __0.0 3/28/2009 ~ . • • 2T-220 Pre & Post Rig Well Work Summary 6/15/09 Blew well dry with lift gas both IA and tubing string. Blew down the gas pressure still trapped in the well. At about 146 Psi SBHP the plug popped and the well came on. SBHP went from 146 Psi to 1076 Psi in about 12 minutes. Started up the pump and tried to draw down the FBHP but could only get 30 Psi of draw down with the pump running 60 Hz. Decided to let pump run ovemight at 60 Hz. 6/14/09 Joey continued science project was able to blow tubing dry and U tube lift gas. 5/15/09 Tried another start up with Centrilift. Ran the pump for about one hour and fifteen minutes. Pulled the SBHP down to Shut ~ down pressure. Turns out someone did not bleed the IA to zero and it was gas packed and the IA bypass check valve did not have a flapper in it. Shut down unit. Will pump 290 Bbls of diesel down the IA and try for a restart. If we still pull the BHP down to nothing then there are still inflow issues with the well. 5/10/09 Set up a dp across the plug by jumpering LG to the backside. Pushed the IA diesel around. Bled backside to zero. Started the pump. 5/5/09 RIH W/ 3.60" GAUGE TO XO @ 4723' RKB. TEST TBG W/ 4.5" D&D HOLEFINDER SET @ 4663' SLM. P/T TBG TO 700 PSI IA DID NOT TRACK. JOB COMPLETE. 4/27/09 Started new ESP, pump started heating up and had to shut back down. 4/26/09 Pumped some methanol and diesel thru flowlne and ROV's planning on going for a start tomorrow. 4/22/09 Completed well commissioning check list. 4/18/09 Instrument techs repaired wetthead instrumentation problem. 4/15/09 Trouble shoot wiring cable problem. 4/11/09 2bbls down the flowline, 1 bbl down the backside, pressured up both tubing and backside. Able to get 5 bbls down the flowline and confirmed it was open. 4/10/09 Instrumentation work complete 4/8/09 Floor kit and wellhouse installed. Need CPF2 E&I/Centrilift to reintall HT and instrumentation and power. Putled BPV. 12/11/08 PRE-RWO, T-POT (PASSED), T-PPPOT (FAILED), NEEDS REMOVED TO FUNCTION TEST LDS'S n \ I C~ ConocoPhillips Time Log & Summary LNeltview Web ReAOrUng ~~ ~O ~ ' _.~.. ~, ~ „~~' -~`~ ~~~ .~ .'~'~^ # ~~ ~w,~~/~ ~~~ .,a'.J~~.~~'a;~',s"E-~ .~~~` ;'~ ,,`~,~~ ~'~~'~,~ c~' \ ?°~~. S. ~.`.1 I>-~ Well Name: 2T-220 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/26/2009 4:30:00 AM Rig Release: 3/29/2009 1:00:00 PM , ~~ ~ ~~ .. _.. .. ~ ~ , ~ , ;~ ~ , ; ~~ .. ? ~ ` ~~~:; ~ . ~~~,.,.~ . ~~ - ~, '~ . : .~..~ ~ ~ ~'~ ~~ - . ~~,r . ~ ~ . .<. . ..e ~... .~~x- - ~ ~~ .~. ~.,...._ ~ . .. . .r .a x ~ ~ ~=~=.~,. „ ; ,~r: ~ ~ ~ ~ay,;~ s E._ ~i ~3 , ~ ~ a ~" v" ~ k S ' ~ ~ ~ ~ _ ~?~ F 3.. , 6 f _ : ~ . ; ' IdS ; ~. „ ~. ~ I [ f , 1.. 3/25/2009 2a hr Summarv • Moved rig from 3H Pad to CPF2 spine road. 08:00 17:00 9.00 0 0 MIRU MOVE TRNS P Nordic Rig 3 released from 3H-28A on 3/25/08 @ 08:00 am. Movin ri to 2T-220. 17:00 19:00 2.00 0 0 MIRU MOVE OTHR P Pull rig off road at 1Q Pad. Stand by with crews for CPAI field wide crew chan e. 19:00 00:00 5.00 0 0 MIRU MOVE TRNS P Moving rig to 2T-220. 3/26/2009 Moved rig to 2T Pad, spotted rig over well 2T-220, RU kill tank and hard line, loaded pits with filtered seawater, ulled BPV, flushed IA and tb with hot seawater, sef BPV, ND tree, NU BOP. 00:00 03:30 3.50 0 0 MIRU MOVE TRNS P Cont moving rig from 1Y to 2T Pad. 03:30 04:30 1.00 0 0 COMPZ RPCOM PSIT P Spot rig onto 2T-220. Berm up rig and spot aux equipment. Acce ted Nordic Ri 3 onto 2T-220 on 3/26/2 9 04:30 am. 04:30 09:00 4.50 0 0 COMPZ RPCOM RURD P Load lubricator to pull BPV. load piYs , with filtered seawater, RU hardline to kill tank. Pull BPV, tubing press = 300 si, IA ress = 200 si. 09:00 13:00 4.00 0 0 COMPZ RPCOM CIRC P PJSM. Test hardline 250/2500 psi. Bleed down tubing and IA. Pump down tubing taking returns to IA. Pumped 370 bbl of filtered SW @ 5 bpm / 2200 psi., 350 bbl of returns to tank. Well loaded with SW, shut in ressures T/IA = 0/0. 13:00 15:00 2.00 0 0 COMPZ RPCOM CIRC P Pumped 290 bbl of hot SW down the IA taking retums up the tubing and back to the pits to wash tubing prior to pulling, full retums. Shut in ressures T/IA = 0/0. Monitor w I. 15:00 17:30 2.50 0 0 COMPZ RPCOM RURD P Crane on location. PJSM, load ESP s ooler onto ri floor. 17:30 19:00 1.50 0 0 COMPZ RPCOM NUND P ND tree and install blanking piug. 19:00 00:00 5.00 0 0 COMPZ RPCOM NUND P NU 13 5/8" BOP. 3/27l2009 RU and tested all BOPE at 250/2,500 psi, pulled blanking plug and BPV, MU landing jnt, BOLD's, unseat hanger, CBU, RU ESP spooler and sheave, POOH LD 4 1/2" ESP completion, CO ESP spools, offloaded tec-wire spooler, loaded new pump equipment and clamps, POOH LD ESP pump assembly, cleaned rig floor and cleared i eshed, finished rack and tall of new 4 1/2" tb . Page 1 0# 3 ' ~ • ~„~ ~ ~~ 0.".-r~`~. ~~ ~ w ,~ , ,:h ~ 1 "- '~ .~~ e e, ,,F~in" ~ ~.2a~Y~~.~,~.'~& .. ~~t'~`' : ~ s4 ~/' . .."~ :_. ~~c~r:~ . ~ ~~~ .~ . . ~ ~ ~~.'~._.,. _`~-~~'. `\?"~ 2 ~~. ~ 3~t: './ ^ ~ . ~:.~ , ~ ~ a Pha~,~ ~ ~.\. m~~%i,}~2~' i . ~G~tl~~ . ;~ ~ fi,3'.."~y ~~~~ocl~i~ ' ~ ~.. ~~ i~ .. \ "X° {~ % ~ ~ ~Y . L ~ : ... `" .;:1 /~u:rF..e~~ k` ,~=' .u.~^'. ~.1~'~'~. r "._ ~,'z .~ - ~ // ~ ~ ~~~~~ar~rrn~~ .~, ~~~~~: , ~ ,~. _ . .%;. 00:00 03:00 3.00 0 0 COMPZ WELCTL BOPE P RU and test all BOPE at 250/2,500 psi, witness of test waived by AOGCC Rep Jeff Jones on 3/26/09 at 17:00 hrs, RD test e ui ment. 03:00 04:30 1.50 0 0 COMPZ RPCOM OTHR P Pull blankin lu and BPV, install landin 'nt, RU circ hose, BOLD's. 04:30 07:30 3.00 4,786 4,756 COMPZ RPCOM CIRC P Unseat han er and oull to riq floor u~ weight 80K. CBU @ 5 bpm/1900 si. Han ESP and teo-wire sheaves. 07:30 19:00 11.50 4,756 0 COMPZ RPCOM PULL P P(~(~H with 4,5" ESP com le~, tion. LD and KO old tubing. Load and tally new tubin , drift 3.833". 19:00 21:00 2.00 0 0 COMPZ RPCOM OTHR P CO ESP spools with crane, off-load tec-wire spooler, load new pump assembl , load clam boxes. 21:00 22:00 1.00 0 0 COMPZ RPCOM PULD P LD ESP pump assembly. Missing 10 - SS bands and 5 flt cable uards. 22:00 00:00 2.00 0 0 COMPZ RPCOM OTHR P Clean and clear rig fllor and pipeshed, finish rack and tally of new 4 1/2" tb and 'ewel . 3/28/2009 PU and assemble new ESP pump, PU RIH with new 4 1/2" ESP completion assembly testing ESP cable eve 1,000', MU han er, drained stack, landed han er, RILD's, set 2 wa check, ND BOP, NU tree. 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR P Load clamps and jewelry. 01:00 03:30 2.50 0 92 COMPZ RPCOM RCST P PU and MU ESP um assembly checking rotation of each componant, fill units with oil, MU X-O and full 'nt. 03:30 07:30 4.00 92 104 COMPZ RPCOM OTHR P MU gardian gauge assembly and s lice tec-wire. 07:30 16:30 9.00 104 4,755 COMPZ RPCOM RCST P PU and RIH with 4 1/2" IBT com letion, 16:30 20:30 4.00 4,755 4,784 COMPZ RPCOM HOSO P PU and MU tubing han er. Make splices on ESP cable and TEC wire. Drain stack, land hanger, up weight 83K, down weight 63K, RILDS. LD landing joint. Check E$P cable and TEC wire. 20:30 21:00 0.50 4,784 4,784 COMPZ RPCOM OTHR P Set BPV. 21:00 23:00 2.00 4,784 4,784 COMPZ RPCOM NUND P ND 13 5/8" BOP. 23:00 00:00 1.00 4,784 4,784 COMPZ RPCOM NUND P NU tree. 3/29/2009 Test tree and void at 250/5,000 psi, RU and freeze protect well with 275 bbls diesel, allow well to u-tube, set BPV, dress tree, blow down circ lines, clean pits, RDMO, clean well site, move rig to 2E Pad. Nordic 3 ri release on 03/29/09 13:00. 00:00 01:00 1.00 0 0 COMPZ RPCOM NUND P Cont NU tree. 01:00 02:30 1.50 0 0 COMPZ RPCOM SEQP P RU and test tree and void at ,000 si, ood tests. 02:30 05:00 2.50 0 0 COMPZ RPCOM FRZP P Spot LRS unit and diesel tanker, PJSM, RU LRS lines and test same at 250/2,500 psi, pump 275 bbls diesel down IA at 3 bpm - 850 psi, through the gas separator/pump intake takin returns u the tb . Page 2 uf 3 From: NSK Problem Well Supv [mailto:n1617@conocophillips.rnm] Sent: Monday, December 15, 2008 9:33 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Problem Well Supv; CPl=2 Prod Engrs Subject: 2T-220 (PTD# 198-253) Report Of Failed ESP JimlTom, Tabasco packerless tubing conveyed ESP producer 2T-220 (PTD# 198-253) encountered trouble returning to production following the CPF2 plant turnaround in late June 2008. The pump failed to surface fluids and ovefieated after a few running hours. Extensive diagnostics on the well were inconclusive, but a caliper log indicated severely corroded tubing. The well is tentatively scheduled to undergo a rig workover in the first quarter of 2009 and will remain shut in until that time. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7724 Cell 907-943-1720 Pager 907-659-7000 #909 ~3'~~ ..~ _ ALL LAG }~~; TR~1~~11~/~'T:4L -- - --~~~ ProActive Diagnostic Services, Inc. .. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~ ~ r ~, ~ ~ ~ c, ~ ~~"v 130 West International Airport Road +~.,~~*h~*~,~,~ , v Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 J Caliper Report 2J Signed Print Name: 07-Nov-08 50-103-20283-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.88952 E-MAIL: ~d~a~rl~a~~m~faCc~l~arl:~ol~~3og.res:a WEBSITE:',y,N~,y.Y"a.aY930Y'#3c1e 2T-220 1 Report / EDE t9 ~-a53 ~ r X155 C:\Documerts and Settings\Owner\Desktop\Tiansmit_COnow.docx C ii i~ • ~ Memory Multi-Finger Caliper Lag Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-220 Log Date: November 7, 2008 Field: Kuparuk Log No.: 8722 State: Alaska Run No.: 1 API No.: 50-103-20283-00 Pipet Desc.: 4.5" 12.6 Ib. L-80 BTC-MOD Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvll.: 4,636 Ft. (MD) Pipet Desc.: 3.5" 9.3 Ib. L-80 8rd EUE-M Top Log Intvl1.: 4,636 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl1.: 4,704 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This log is tied into the Cross-over @ 4,636' (Driller's Depth). This log was run to assess the condition of the 4.5" and 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing is in good to poor condition, with a maximum recorded wall penetration of 74% in joint 123 {3,899'). Recorded damage appears as scattered pitting near the surface and broadens into general corrosion a5 depth increases. More severe, intermittent lines of corrosion and bands of circumferencial corrosion are also recorded within the interval of general corrosion. Maximum cross-sectional wall loss of 20% is recorded in seven joints between 2,050' and 3,712'. Cross-sectional metal loss from 15% to 20°~ is recorded throughout the deviated interval of the 4.5" tubing. No significant I.D. restrictions are recorded. Slight buckling is recorded from --180' to 1,200'. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with a 51% wall penetration recorded in joint 2 (4,673'). Cross-sectional wail loss of 17% is recorded in joint 1 (4,641'). No sign cant I.D. restrictions are recorded throughout the 3.5" tubing logged. 4.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS Corrosion (74%) Jt. 123 @ 3,899 Ft. (MD) Corrosion (62%) Jt. 134 @ 4,226 Ft. (MD) Corrosion (60%) Jt. 44 @ 1,388 Ft. (MD) Corrosion (58%) Jt. 39 @ 1,205 Ft. (MD) Corrosion (54%) Jt. 111 @ 3,503 Ft. (MD) 4.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Corrosion (20%) Jt. 95 @ 3,012 Ft. (MD) Corrosion (20°~) Jt. 81 @ 2,538 Ft. (MD) Corrosion { 20%) Jt. 117 ~ 3,684 Ft. (MD) Corrosion (20%) Jt. 72 ~ 2,239 Ft. (MD) Corrosion (20%) Jt. 82 @ 2,553 Ft. (MD) 4.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS :~~~,~~~~ ~;~',f ~ ~ >?~~~ No significant i.D. restrictions are recorded. ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (88$) 565-9085 Fax: (281) 565-1369 E-mail: PDSramemorylog.com Prudhoe Bay Field Office Phone; (407} 659-2307 Fax: (907) 559-2314 Igo-a~3 # r~-1SS ~ • 3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS : Isolated Pitting (51%) Jt. 2 @ 4,673 Ft. (MD) Corrosion (33°~) Jt. 1 @ 4,641 Ft. (MD) Shallow Corrosion (19°~) Jt. 3 @ 4,703 Ft. (MD) 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Corrosion (17%) Jt. 1 @ 4,641 Ft. (MD) No other significant areas of cross-sectional wall loss (> 12%) are recorded throughout the interval logged. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the interval logged. Field Engineer: K. Miller Analyst: HY. Yang Witness: C. Fitzpatrick ProRctive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281j 565-1369 E-mail PDS@memorylog.com Prudhoe Bay Field Office Phone: (907j 659-2307 Fax: (907) 659-2314 ' • ' Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 4.5 in (16.5' - 4636.0') Well: 2T-220 Pipe 2 3.5 in (4636.0' - 4701.4') Field: Kuparuk ' Cornpany: Country: ConocoPhillips Alaska, Inc. USA Survey Date: November 7, 2008 A pprox. Tool De viatjon ^ A pprox. Borehol e Profil e 21 611 1234 1862 D 2490 ~ ESPM .~ L Q a, 3142 3776 ESPM 442 8 4638 3 4701 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 3 1 20 40 60 v ~~ ` ~ 80 E Z c ~O 100 120 140 1 1 2 • • PDS Report Overview ~~ ~,. Body Region Analysis Well: 2T-220 Survey Date: November 7, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Rngers: 24 Analyst: _ __ HY. Yan Tubing: Nom.OD Weight Crade & Thread Nom.ID Norn. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 BTC-MOD 3.958 ins 4.5 ins 6.0 ins 0.0 ins Penetration and Metal Loss (% wall) o penetration body ;~,r; metal loss body 100 80 60 40 20 ~• 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 153 gene. 0 3 16 87 47 0 loss 15 61 77 0 0 0 Damage Configuration (body ) 150 100 50 0 isolated general fine ring hole / puss pitting corcosion corrosion corrosion ible hole Number of ~oints dama ed total = 150 22 121 7 0 0 Damage Profile (% wall) ~ penetration body ~ metal loss body 0 50 100 0 50 ESPM 1 98 ESPM 2 145 Bottom of Survey = 145.5 Analysis Overview page 2 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 BTC-MOD Well: 2T-220 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: November 7, 2008 Joint No. Jt. Depth (Ft.) I'c•n. Ulxc•t (Ins.) Pen. Body (Ins.) I'c•n. °~, ~1c•t,il I~~ss "4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 17 O 0.01 4 ~) 3.91 PUP 1 21 O 0. 4 1;i 1 3.92 Scattere itti 52 it 0.03 I 1 I 3.91 Scattered ittin . 3 83 U 0.02 £3 U 3. 1 4 115 t? 0.04 ! (, I 3.93 Scattered ittin . 5 146 O 0.10 iii ' 3.93 Scattered ittin . 6 177 U 0.06 ~'2 I 3.89 Scan red ittin . Sli ht bucklin . 7 208 ~? 0.05 I ti I 3.92 Scattered ittin . 8 240 U 0.05 I ~~ I 3.91 Scattered ittin . 9 271 l) 0.06 2~1 1 3.91 Scattered ittin . 10 300 (1 0.09 31 -1 3.92 Scattered ittin . Sli ht bucklin . 11 331 O 0.08 Z£3 3.91 Scattered ittin . 12 363 U 0.03 13 I 3.91 S ttered ittin . 13 395 U.l~- 0.0 1 ~~ 3.92 Scattered ittin . 14 426 ~~ 0.03 13 I 3.89 Scattered ittin . 15 458 ! ~ 0.07 28 ~ 3.92 orrosi n. Sli ht bucklin . 16 487 U 0.08 ~' £i _' 3.91 Corrosion. 17 519 U 0.06 24 1 3.91 Scattered ittin . 18 548 t~.l~o 0.07 25 _' 3.8 Scattered ittin . 19 580 U 0.07 ~'6 ~ 3.92 Scattered ittin . 20 611 +~ 0.05 17 I 3.90 Scattered ittin . Sli ht bucklin . 21 643 i ~ 0.06 24 S 3.91 Corrosion. 22 674 U 0.10 36 t, 3.92 Line corrosion. 23 705 U.US 0.06 23 i 3.92 Scattered ittin . 24 734 U 0.05 I cj 3.90 Shallow corrosi n. 25 766 l) 0.05 1U _' 3.92 Scattered ittin . Sli ht buckli 26 797 U.t); 0.10 38 4 3.91 Corrosion. 27 828 ~).(~i, 0.11 4O 7 3.92 Line corrosion. 28 860 t?.1:~ 0.10 3G i 3.92 Corrosion. 29 891 a 0.08 1t3 3.86 Corrosion. 30 921 U.t)(> 0.08 tU ~ 3.90 Scattered ittin . Sli ht bucklin . 31 953 (1 0.05 1£3 1 3.88 Scattered ittin . 32 984 U 0.11 -11 ~ 3.92 Corrosion. 33 1015 U 0.09 4 -t 3.91 Line corrosion. 34 1047 c) 0.08 > 1 4 3.90 Corrosion. 35 1078 U 0.05 ZU 3.91 Scattered ittin . Sli ht bucklin . 6 1109 a 0.11 -1c) tt 3.91 Line corrosion. 37 1140 ~ ~ 0.12 -1;! - 3.91 Corrosion. 38 1171 t) 0.08 29 is 3.88 Corrosion. 39 1202 O.U6 0.16 5£3 1 3.88 Corrosion. 40 1234 0 0.09 , ; ~ 3.89 Corrosion. 41 1265 U 0.12 44 - 3.90 Corrosion. - 42 1296 U 0.05 17 3 3.91 Shallow corrosion. 43 1327 U 0.06 ZZ -1 3.86 Corrosion. 44 1358 U.U6 0.16 t,t) ~) 3.91 Corrosion. 45 1389 O.US 0.07 ~5 d 3.88 Corrosion. 46 1421 l).(15 0.10 3b G 3.88 Corrosion. 47 1452 a 0.07 26 (; 3.92 Corrosion. 48 1484 a 0.08 2~) I i 1 3.92 Corrosion. 49 1516 ti 0.07 ~'£3 ~> 3.90 Corrosion. Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 BTC-MOD Well: 2T-220 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: November 7, 2008 Joint No. Jt. Depth (Ft.) I'~•n. l lt~x~t (lnc.) Pen. Body (Ins.) Pc~n. °4, 'vtet,~l I o5s "~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1546 U 0.10 ,8 £i 3.87 Line wrrosion. 51 1578 (1.u5 0.08 iU £3 3.90 Corrosion. 52 1609 (t.U(~ 0.12 -1(i 5 3.91 Corrosion. 53 1641 U.~u~ 0.10 S£S I 3.91 Corrosio . 54 1673 t t.t u, 0.07 ' (, I (~ 3.91 Corrosion. 55 1705 U.(u, 0.12 -1; I~1 3.88 Corrosion. 56 1736 tl.tl`> 0.11 41 I±~ 3.88 Corrosion. 57 1767 (1 .12 :}, (, 3.88 Corrosion. 58 1798 (1.(17 0.08 3t) b 3.89 Line Corr si n. 59 1830 t1.U' 0.08 3U 1(~ 3.91 Corrosion. 60 1862 (LU(, 0.08 ?~) 14 .95 Corrosion. 61 1894 (1.U£3 0.12 ~5 I (> 3.93 Co rosion. 62 1924 tl.u(~ 0.08 Z£9 I ; 3.94 Corrosion. 63 1956 u.tlts 0.12 ~l-1 17 3.93 Corrosion. 64 1986 u.t15 0.09 34 I-1 3.92 Corrosion. 65 2018 tt.U£i 0.12 44 I,- 3.87 Corrosion. 66 2049 t 1. I t l 0.12 4. ~ ~' ~ 1 3.93 Corrosion. 67 2081 U. I I 0.11 -1Z I £~ 3.93 Corrosion. 68 2112 t 1. I Ll 0.13 49 I £t 3.94 Corrosion. 69 2143 tl.u(, 0.08 3t1 I(~ 3.90 Corrosion. 70 2175 I1.(1£i 0.11 d1 I ~ 3.93 Corrosion. 71 2207 u.U(~ 0.08 > I t 5 3.90 Corrosi n. 72 2238 O.U<) 0.12 X33 'u 3.92 Corrosion. 73 2269 0.11£t 0.10 ;(> 15 3.92 Corrosion. 74 2300 U 0.07 l 5 I <# 3.95 C r lion. 75 2332 (1.11' 0.15 54 I £i 3.91 Corrosion. 76 2363 O.UB 0.11 42 17 3.88 Corrosion. 77 2395 ll.l)7 0.13 46 l ; 3.91 Corrosion. 78 2426 U.U£3 0.13 47 I') 3.93 Corrosion. 79 2458 (1.t15 0.07 _'-1 IU 3.91 Corrosion. 80 2490 t l 0.08 ~' ~) 14 3.93 C rrosi n. 81 2521 U.Uv 0.13 -17 'tl 3.94 Corrosion. 82 2552 tl.ll 0.13 4£9 ~'U 3.93 Corrosion. 83 2583 U. I t) 0.12 4b 17 3.92 Corrosion. 83.1 2614 u.U7 0.09 ~t4 15 3.96 PUP Corrosion. 83.2 2622 U 0 U O N A ESPM 1 Latch ~ 4:30 83.3 2629 i).It) 0.09 ,3 Ztl 3.97 PUP Corrosion. 84 2637 u.U£~ 0.13 47 I £t 3.91 Corrosion. 85 2669 (1. I ? 0.13 X1£3 I ~~ 3.93 Corrosion. - 86 2700 tl.tu, 0.08 '8 I ; 3.92 Corrosion. 87 2732 tl.U7 0.10 36 I(, 3.94 orrosion. - 88 2764 tl.tl£3 0.12 ~15 I'1 3.91 Corrosion. - 89 2795 U. I 1 0.13 4t3 I; 3.93 Cor osion. 90 2826 11.15 0.14 5(1 1 ~~ 3.96 Corrosion. - 91 2857 tl.(l~) 0.12 ~t(~ 17 3.9 orrosion. 92 2889 n (u, 0.09 ~_' I ~ 3.92 Corrosion. - 93 2920 tl.tt7 0.10 ;£I I ~ 3.92 Corrosion. 94 2952 tl (1- 0.08 ; I l i. 3.93 Corrosion. 95 2984 ~' I -t 0.1 ~£9 ~'U 3.92 Corrosion. - 96 3015 ~' ~ ~" 0.12 46 I £i 3.92 Corrosion. _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 BTC-MOD Well: 2T-220 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: November 7, 2008 Joint No. Jt. Depth (Ft.) I'wr. Ut~~et 11rn.) Pen. Body (Ins.) Pen. °i~ ~1c~1,il I ris5 ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3047 U.U6 0.10 iE~ I _s 3.93 Corrosion. 9 3078 tt.(t,- 0.08 3U I' 3.89 Corrosion. 99 3110 tt 0.08 3O 15 3.88 Corrosion. 100 3142 O. l U 0.12 44 I ~ 3.83 Corrosion. 101 3174 U. l t) 0.13 4F3 I tS .93 Corrosion. 102 3205 O.(15 0.08 ~!t3 I t, 3.95 Corrosion. 103 3236 t).U7 0.11 41 I ~ 3.91 Corrosion. - 104 3 69 t).Ub 0.10 i6 1 b 3.92 Corrosion. 105 3300 tt.t)o 0.08 29 16 3.95 Corrosion. 106 3332 U.O5 0.08 31 13 3.93 Corrosion. 107 364 0.117 0.09 X34 I i 391 Corrosion. 108 3395 U 0.06 ~~' ~? 3.92 Corrosion. 109 3427 U.1 1 0.12 45 Its 3.93 Corrosion. 110 3458 O 0.06 14 ~l 3.92 Corrosion. 111 3490 O.O9 0.15 54 17 3.89 Corrosion. 112 3522 U 0.07 ? 7 ~) 3.89 Corrosion. 113 3554 O.U6 0.07 17 14 3.93 Corrosion. 114 3585 t) 0.06 _'< <) 3.92 Corrosion. - - 115 3617 U.U6 0.07 ?7 1.1 3 93 Corrosion. 116 3649 u.U~t 0.09 sit I 3.93 Corrosion. - 117 3680 u. I t t 0.13 4F~ 't) 3.91 Corrosion. - 1 18 3712 a 0.06 ~' 1 t; 3.92 Lin corrosion. 119 3744 U.US 0.05 I r) t~ 3.92 Shallow corrosion. 120 3776 U.II 0.14 5u L5 3.89 Corrosion. 121 38 7 U 0.06 ~?2 I u 3.9 C rr si n. 122 3838 it.U7 0.07 '-3 Itt 3.90 Corrosion. 123 3870 u.U7 0.20 74 I t~ 3.91 Corrosion. 124 3900 t1.t)6 0.08 29 1 i 3.93 Corrosion. 125 3932 I1 0.05 19 E3 3 92 Shallow c rrosion. 126 3964 (t 0.06 ~:; I I 3.92 Corrosion. 127 3996 11 0.06 1=1 ~t 3.92 Corrosion. 128 4028 (.1.U5 0.07 ~'S Ili 3.90 Corrosion. 129 4060 U.l)~) 0.14 52 I (> 3.91 Corrosion. 130 4090 t).tt~t 0.14 i2 1l~ 3.91 Corrosion. 131 4121 t).iJ7 0.07 ~'7 14 3.92 Corrosion. 132 4152 U 0.06 ? t I t I 3.92 Corrosion. 133 4184 u.tt7 0.10 ~i I; 3.88 Corrosion. 134 4216 tl. I I 0.17 (~! 1 '> 3.88 Corrosion. 135 4247 t) 0.06 Z 1 3.92 Corrosion. 135.1 4279 tl.UtS 0.09 >Z I rs 3.97 PUP Corrosion. 135.2 4285 t) 0 tt tt N A FPM 2 Latch ~ 7:00 135.3 4293 U. 1 tt 0.10 (~ I ~) 3.95 PUP Corrosion. 136 4301 U.tt~1 0.14 53 15 3.87 Corrosion. 137 4332 tt.l l 0.10 37 I i 3.91 Corrosion. 138 4364 l) 0.07 ~6 ti 3.90 Corrosion. 139 4396 t t 0.06 1? ~~ 3.91 Corrosion. 140 4428 lt.tt7 0.09 al IE, 3.89 Corrosion. 141 4460 tt.tu~ 0.08 31 I-! 3.91 Corrosion. 142 4490 tt.tt7 0.13 17 I-1 3.89 Corrosion. 143 4521 U. I ,- 0.14 ~t) I (, 3.91 Corrosion. _ Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 BTC-MOD Well: 2T-220 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: November 7, 2008 Joint No. Jt. Depth (Ft) Nevi. Utnc~t (Ins.} Pen. Body (Ins.) Ne~n. °~, ~h~~,il Ins. ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 144 4551 tt.ut~ 0.11 ~I I') 3.90 Corrosion. 145 4583 l1.Ui 0.10 ;7 I t~ 3.90 orrosion. 145.1 4615 t).O7 0.08 ~~! I t, 3.96 PUP Corrosion. 145.2 4622 ~) 0 ~) t~ 3.81 Baker CMU Sleeve 145.3 4625 l).U(~ 0.09 34 I ~ 3.91 PUN Corrosion. 145.4 4634 l1 0.02 6 ~) 3.88 PUP 145.5 4636 U 0 0 U 3.50 Cross-over Penetration Body Metal Loss Body Page 4 PDS Report Cross Sections ~-~ _ ~S ,~ Wefl: 2T-220 Survey Date: November 7, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: Z4 Tubin 4.5 ins 12.6 f L-80 BTC-MOD Anal st: HY. Yan Cross Section for Joint 123 at depth 3898.71 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 96 Tool deviation = 74 ° Finger 1 Penetration = 0.2 ins Corrosion 0.2 ins. = 74% Wall Penetration HIGH 51DE = UP lr ~I u Cross Sections page 1 PDS Report Cross Sections ~ _ ~~ ,,. Well: 2T-220 Survey Date: November 7, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers; 24 Tubin 4.5 ins 12.6 f L-80 BTC-MOD Anal st: HY. Yan Cross Section for Joint 134 at depth 4225.73 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 91 °h Tool deviation = 63 ° Finger 3 Penetration = 0.167 ins Corrosion 0.17 ins. = 62°I° Wall Penetration HIGH SIDE = UP n Cross Sections page 2 ~ ~ ~ ~ ~ ~ s ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~~ ~S . Well: 2T-220 Survey Date: November 7, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 4.5 ins 12.6 f L-80_BTC-MOD Analyst: HY. Yang Cross Section for Joint 95 at depth 3012.08 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 81 Tool deviation = 67 ° Finger 3 Penetration = 0.11 1 ins Corrosion 20% Crosssectional Wall Loss HIGH SIDE = UP • Cross Sections page 3 `S PDS Report Cross Sections Well: 2T-220 Survey Date: November 7, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc, Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 4.5 ins 12.6 ppf L-80 BTC-MOD Analyst: HY. Yang Cross Section for Joint 81 at depth 2537.8 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 81 °~ Tool deviation = 72 ° Finger 1 Penetration = 0.066 ins Corrosion 20% Crosssectional Wall Loss HIGH SIDE = UP • Cross Sections page 4 • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 8rd EUE-M Well: 2T--220 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 7, 2008 Joint No. Jt Depth (Ft.) I'c•n. UI»E°~ (Ins.) Pen. Body (Ins.) I'c~n. % Mc~t,~l Loss °i<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 4636 ~) 0 11 t~ N A Crossover 1 4638 U.~~t~ 0.08 ;', I 2.89 Corrosion. - 2 4670 +~ 0.13 5 I I ! 2.88 Isolated ittin . 3 4701 t? 0.05 I ~~ 2.91 Shallow corrosion. _ Penetration Body Metal Loss Body Page 1 ~ ~ ~ ~ w ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~~ `~ PDS Report Cross Sections Well: 2T-220 Survey Date: November 7, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 8rd EUE-M Anal st: HY. Yan Cross Section for Joint 2 at depth 4672.67 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 88 Tool deviation = 64 ° Finger 20 Penetration = 0.13 ins Isolated Pitting 0.13 ins. = 51 % Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ! i ~ ~ ~ ~ ~ ~ ~ ~ ~S PDS Report Cross Sections Well: 2T-220 Survey Date: November 7, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 8rd EUE•M Anal st: HY. Yan Cross Section for Joint 1 at depth 4640.57 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 85 Tool deviation = 87 ° Finger 3 Penetration = 0.084 ins Corrosion 0.08 ins. = 33% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 ~~ ~S PDS Report Cross Sections Well: 2T-220 Survey Date: November 7, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 8rd EUE-M Anal st: HY. Yan Cross Section for Joint 1 at depth 4640.49 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 84 Tool deviation = 49 ° Finger 17 Penetration = 0.067 ins Corrosion 17% Cross-sectional Wall Loss HIGH SIDE = UP • • Cross Sections page 3 ~ ~ KUP ~ 2T-220 ConocoPhillips '!' wex Attributes 1j.1i._' ,I WNIDOre AIallOWl Rla tl Name Well status Prodlrljwet line fir) IYD m KB) m1ma1Q 1R.. 507032028300 TABASCO PROD 66.55 2.958.69 5,752.0 -.-.__ _. - .•. Commefa H281Ppn1 Date Amotatlon tlDate KB ~ Rig Release Dale e 1z zi o7 PM - SSSV: NONE 220 7/112008 Last WO: 6!6/2004 36.81 1/18/1999 Arawtallon Last Tag: 1 1,870.0 10/122008 Rev Reason: SLM TAG FILL Fs0 ate 10/13/2008 Casio Sbin s ~ ~ Cashlg Daeotptlon smog MI a M) T PmW sec oepm Pmgl sel 1 P~ rslg tM PbsAq tr ade 8tthg T Rao .II CON UC OR 1 6 15.06 2 0.0 112.0 112.0 62.58 H10 WELDED SURFACE 951 8 8.69 0.0 4,990.0 3,044.5 40.00 L-80 BTM-MOD LINER 4 3.47 6 4,856.0 5,517.0 3,348.3 11.60 L-80 Saeens IbWGER. ze Tubi Stri l~B Deswiptlon arYg OD Pnl atln8 11n1 Top PIKm Set Deem (RKd) set Depth (rvDl PIKE) Str-'q wt pCSllq Strtr t7atl 10 e stMg Tap Mal ALL 412 3.958 0.0 4,636.0 2,864.4 12.60 L-80 BTC-MOD CONWClOR ALL 3 1/2 2.992 4,636.0 4,712.0 2,902.9 9.30 L-80 EUE-M , n2 GRAVEL PACK 4 4.856.0 5.517.0 3.348.3 Other In Hok A ll Jewel :Tub' Run & Retrievable Fish etc. Top Ir'DI Top ESR r Top PtKel IgKel tad rl Defapllan Camme! Rul Date D PM MgNDl7EL. ~~ ~ 26.0 28.0 -0.58 HANG FMC TBG HANGER 6820D4 3 95R _ 2,628.0 1,9864 63.39 ESP MANDREL SWSIKBG-2!1/DMVBKbI/l Cortanent: STA1 6/6I20D4 3.938 4,288.0 2,691.6 62.26 FSP SWSIKBGy1/DMYBK3l//CanareM: STA2 61612004 3.93R ~ MANDREL ew MlWDREL 4,623.0 2,857.8 59.01 SLEEVE BAKER CMU W/3.81 CAMCO PROFILE 6/612004 3.870 , a.zee 4,636.0 2.864.4 59.23 XO 6/6/2004 3.500 4,702.0 2,897.9 60.01 GAUGE BAKER CENTURY GAUGE, BANDED TO SIDE OF PIPE 6162004 3.500 ' 4,7120 2.902.9 59. DISCHARGE CENTRILIFT DISCHARGE GAUGE 6/62004 4.713.0 2.903.4 59.95 PUMP CENTRILIFT ESP PUM, 89 STAGE GC 100 6!62004 4,736.0 2,974.9 59.83 INTAKE CENTRILIFf INTAKE 8162004 stEEVE. a,sz3 I I 4,737.0 2,915.4 69.82 5EAL CENTRILIFT TANDEM SEAL SECTION 6/62004 4,751.0 2.922. 5.75 MOTOR CENTRILIFT ES MOTOR 418HP2610198A 6/62004 4,785.0 2,939.7 59.57 NIP CENTRILIFT NIPPLE set 6/62004 6/62004 4,786.0 2.9402 59.57 Centralizer CENTRILIFT CENTRALIZER set 6/6/2004 6/6!2004 l Perfora tions XO, 4 636 ~~ i ~~ Top (TVD) t7hn (TVD) Dens T MKS Don P~1 PIKe) PtKel Zone Otle (~~- Cd nnellt i 4,961.0 5,517.0 3,029.3 3,348.3 7/&1999 99.0 IPERF OPEN HOLE VEL PACK GgllGE.4102 DISCNAFtGE. 4,]12 rt q PUMR, 4,]13 y INTPHE, 4,738 ~°i y' SEg1, 4,73] Q k MOTOR,1151 I L ~ T 1 NIP. d, ]85 Ceneel¢w, 4 /3s SURFgCE, 4,880 IPERF, 4,961-5.51] - ~ LINER, 5,51 T '- ~ TD 12T-220), 5 152 y ConocoPhiIIi ps June 29, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 rllll I~ Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 Subject: Report of Sundry Well Operations for 2T-220 (APD # 198-253) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 2T -220. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, f1 ~ ;J/~~ M. Mooner Wells Group Team Leader CPAI Drilling and Wells MM/skad OR\G\NAL RIEC' 'E~~VE' '. oP""" ~ .:, JUN 3 0 2004 t\~aska Oil 8;[ Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28' 8. Property Designation: ADL 25569, ALK 2667 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE gravel pack screen assembly Perforation depth: ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell D Pull Tubing D Operat. ShutdownD Stimulate 0 Other D Waiver D Time Extension D Re-enter Suspended Well 0 5. Permit to Drill Number: 198-253 / 6. API Number: 50-103-20283-00 Plug Perforations D Perforate New Pool 0 Perforate D 4. Current Well Status: Development - 0 Stratigraphic D Exploratory D Service D 9. Well Name and Number: 2T-220 10. Field/Pool(s): Kuparuk River Field / Tabasco Oil Pool measured 5752' feet true vertical 3509' feet measured 5165' feet true vertical 3139' feet Length Size MD 112' 16" 112' 4879' 9-5/8" 4990' 661' 4" 5517' Plugs (measured) Junk (measured) TVD Burst Collapse 112' 3047' 3348' Measured depth: 4961'-5517' E'~""' E r\/F" lw"", tJ "w,,,,~ . i:: JUN 3 02004 open hole gravel pack true vertical depth: 3029'-3348' .\~¡ ~sk~~ Oil g~ Tubing (size, grade, and measured depth) 4-1/2" /3-1/2" , L-80, 5517' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) n/a '.DMSBFL JUM 3 u 1""~ 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl SI SI 52 3891 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A it C.O. Exempt: Oil-Bbl SI 662 CasinQ Pressure Tubinq Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Contact Printed Name Signature 256 WDSPLD Mike Mooney @ 265-4374 Mike Mooney )/ J( mMrAj Title Phone T earn Leader ~ ' JO ¿¡ Wells G rou P Date <;?:2 q <~"'k' 263-4612 b aran AI/suo Preoared v ORIG\NAL Submit Original Only Form 10-404 Revised 04/2004 ~' ConocoPhillips Alaska Operations Summary Report Legal Well Narne: 2T -220 Common Well Narne: 2T-220 Event Name: WORKOVER/RECOMP Contractor Narne: Doyon Drilling Inc Rig Narne: Doyon 19 Date From - To Hours Code Sub Phase Code 5/22/2004 10:30 - 14:30 4.00 MOVE RURD MOVE 14:30 - 17:00 2.50 MOVE MOVE MOVE 17:00 - 20:00 3.00 MOVE RURD RIGUP 20:00 - 21 :00 1.00 WELLSR NUND WRKOVR 21 :00 - 00:00 3.00 WELLSR RURD WRKOVR 5/23/2004 00:00 - 04:00 4.00 WELCTL BOPE DECOMP 04:00 - 08:00 4.00 WELCTL BOPE DECOMP 08:00 - 10:00 2.00 WELLSR RURD DECOMP 10:00 - 11 :00 1.00 WELLSR NUND DECOMP 11 :00 - 12:00 1.00 WELLSR NUND DECOMP 12:00 - 14:00 2.00 WELLSR SFTY DECOMP 14:00 - 14:30 0.50 CMPL TN PULD DECOMP 14:30 - 15:00 0.50 CMPL TN CIRC DECOMP 15:00 - 17:30 2.50 CMPLTN CIRC DECOMP 17:30 - 18:00 0.50 CMPL TN OBSV DECOMP 18:00 - 21 :00 3.00 CMPL TN RURD DECOMP 21 :00 - 22:00 1.00 CMPL TN PULD DECOMP 22:00 - 00:00 2.00 CMPL TN PULD DECOMP 5/24/2004 00:00 - 12:00 12.00 CMPL TN PULD DECOMP 12:00 - 13:00 13:00 - 16:00 1.00 CMPL TN OTHR DECOMP 3.00 CMPL TN PULD DECOMP 16:00 - 16:15 0.25 CMPLTN CIRC DECOMP Page 1 of 9 Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Spud Date: 1/1/1999 End: Group: Description of Operations Prepare rig for move from 2T-202. Move and spot rig on 2T -220. Rig up on location. Nabors install berms as AES shorthanded. Accept rig at 20:00 hrs. ND tree, install blanking plug. NU BOPE. Cont NU BOPE. Near miss: Test pump started without opening discharge valve, resulting in valve parted. Relief valve should have opened, but didn't open at set pressure. Root cause not yet determined. Filled pit with 250 bbl seawater and commenced heating it to 160F. RU hardline from annulus valve to open top tank. PT to 500 psi. Pressure test BOPE to 250/3,500 psi. AOGCC rep Jeff Jones waived witnessing test. Relocate ESP spooler. Prepare pad for ESP spooler. Move snow and gravel mounds. Prep to move spooler. Pull BPV w/FMC. 0# SIWHP. 0# SICP. Install mouse hole with super sucker. Change out ESP spool, and spot same. Change out landing joint, coupling on the previous has issues. Tear down power swivel from 2T-202 and prep for 2T-220. Will be utilizing Kelly for 2T -220. Continue prep of Kelly. Begin taking off dirty returns from open top tank. Pressure test floor valve and all appropriate iron. BOLDS. Tool box safety meet. Rig up circulation system to reverse in hot fluid wash. Pull hanger up 4' for hot wash circulation. Break out at 100K, ie. 40 klbs overpull. Begin reverse circulation. At 180 BBLS away 220# IA press, 20# DP press. 150 DEG pump temp. 60 DEG return temp. 370 BBLS away @ 3.5 BPM 170 DEG pump temp. 120 Deg return temp. Shut dwn pumps and monitor well. Static. Blow dwn lines to tanks and prep to POOH. RU sheaves and surface equipment to pull tubing with ESP cable and heat trace. Pull hanger to surface w/5-1 0 klbs overpull first 10', then only minor or no overpull. Disconnect ESP cable and Heat trace cable from hanger and LD hanger. Pull completion & LD same. Condition of tubing very good. No overpull. 9 jnts pulled at report time, 135 + ESP assy left. Cont pull & LD completion. 60 jnts at 06:00,100 at 12:00. Visible exterior corrosion from joint #84, ie. end of the heat trace. At 08:00 pad operator issued a hot work permit for GBR to comence fabrication of Hydril flow line system. Lay down Rachem spooler. NOTE: Lost one band to this point. Continue to pull completion from well. Clean up rig floor after removing Rachem spooler. Still signs of corrosion and pitting. Circulate bottoms due to gas shows in fluid. Shut down hot work permit to GBR until gas is circulated to tanks. Joint 135 excessive corrosion on ESP cable and wadded up around primary armor. Printed: 6/28/2004 1 :52:08 PM ( ConocoPhillips Alaska Operations Summary Report Legal Well Narne: Common Well Name: Event Name: Contractor Name: Rig Narne: 2T -220 2T-220 WORKOVER/RECOMP Doyon Drilling Inc Doyon 19 Date Frorn - To Hours Code îoUJe Phase 5/24/2004 16:15 - 20:00 3.75 CMPL TN PULD DECOMP 20:00 - 00:00 4.00 CMPL TN PULD DECOMP 5/25/2004 00:00 - 03:00 3.00 CMPL TN OTHR DECOMP 03:00 - 04:00 1.00 RIGMNT RURD DECOMP 04:00 - 08:00 4.00 CMPL TN OTHR WRKOVR 08:00 - 09:30 1.50 CMPLTN OTHR WRKOVR 09:30 - 10:30 1.00 RIGMNT RURD WRKOVR 10:30 - 11 :00 0.50 RIGMNT RGRP WRKOVR 11 :00 - 12:30 1.50 WELCTL BOPE WRKOVR 12:30 - 14:30 2.00 WELCTL BOPE WRKOVR 14:30 - 16:00 1.50 WELCTL OTHR WRKOVR 16:00 - 21 :00 5.00 FISH PULD WRKOVR 21 :00 - 00:00 3.00 FISH TRIP WRKOVR 5/26/2004 00:00 - 03:00 3.00 FISH TRIP WRKOVR 03:00 - 06:00 3.00 FISH RURD WRKOVR 06:00 - 07:00 1.00 FISH FISH WRKOVR 07:00 - 08:00 1.00 FISH FISH WRKOVR 08:00 - 10:00 2.00 FISH MILL WRKOVR 10:00 - 11 :00 1.00 FISH MILL WRKOVR 11 :00 - 13:30 2.50 FISH OTHR WRKOVR 13:30 - 15:00 1.50 FISH MILL WRKOVR 15:00 - 19:00 4.00 FISH OTHR WRKOVR Page 2 of 9 Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Spud Date: 1/1/1999 End: Group: Description of Operations Continue to POOH to ESP. One band lost. - 80 jnts of tubing in rerun condition. Break down V-tool, I-tube and ESP assy. I-tube severely corroded with multiple holes through pipe body. Large amount of scale. Found upper tandem motor grounded. ESP housings severely corroded with pittings. Last 350' of ESP cable had -10% of I-wire armour missing. All bands (-60) and 9 cable guards on I-tube / ESP missing. Clean up rig floor, cellar and pipe shed after pulling completion. Change from 4.5" to 3.5" rams. Start MU kelly. Begin welding on rig for flow line for rotating head to transfer tank. Hot work permit issued by pad operator. Additional clean-up required after pulling completion, target 0 issues. Finish assembling kelly and install rat hole. Set back kelly. Repair swivel lock. T est kelly and both kelly valves to 250/3500 psi. Begin to pick up BHA for reverse junk basket run. Test 3.5" rams to 250/3,500 psi. Witness waived by AOGCC, Jeff Jones. Set wear bushing. (1.6' long, 10.75" ID, 9" ID) Note: have to back out tubing hanger alignment pin on horizontal wellheads before running testplug and wear bushing. Pick up handling equipment and make up BOT fishing assy #1. 8 1/8" RCJB w/ball installed - boot basket- 2x/o - bumper jar - oil jar - 6 x 4 3/4" DC - pump out sub (1 13/16" ball seat) - x/o= 225.58'. RIH with fishing assy #1 PU 3.5" PH-6 (12.95# - P110) work string. Drift pipe to 2". 2,500' at midnight. Cont RIH with fishing assy #1 drifting all pipe. Tag up at 4681'. PU kelly, MU & PT mudhose. Fill oil. Tag weight readings. Wash & ream from 4,681' to 4,690'. Crew spotted flow line leak and subsequently spilled - 7 gal of sea water onto the pad and - 7 gal into secondary containment. Called all parties for initial contact. Sent out 2 hour notice. Rotate and wash over scale and fill. 4 BPM - 830 psi. 45K dwn wt. 52K up wt. no losses. Continue to wash up fill and bands. Prep to pump 4 ppb hi-vis pill. Power failure. Unable to to re-set ESD system (rig-saver) after accidental shut down. Go to manual override. Second gel pill to shakers. Having to slow the pumps down for them to keep up. Up WT = 52K DWN WT = 45K, 4 BPM -775 psi. Appears that gel sweep is reacting to fluid properties in hole. Gel is turning to rubber. Having problems with suction on pump. The 30 bbl ,4 ppb hi-vis sweeps that were pumped and circulated into the system partially blocked suction screens. Dispose of 200 BBLS circulation fluid, while taking on 150 BBLS of clean sea water. Printed: 6/28/2004 1 :52: 08 PM ~t ConocoPhillips Alaska Operations Summary Report Legal Well Narne: Common Well Name: Event Narne: Contractor Narne: Rig Narne: 2T-220 2T-220 WORKOVER/RECOMP Doyon Drilling Inc Doyon 19 Date Frorn - To Hours Code ~ouJe Phase 5/26/2004 15:00 - 19:00 4.00 FISH OTHR WRKOVR 19:00 - 19:30 0.50 FISH MILL WRKOVR 19:30 - 22:00 2.50 FISH CIRC WRKOVR 22:00 - 00:00 2.00 FISH TRIP WRKOVR 5/27/2004 00:00 - 01 :30 1.50 FISH TRIP WRKOVR 01 :30 - 03:00 1.50 FISH TRIP WRKOVR 03:00 - 04:30 1.50 FISH TRIP WRKOVR 04:30 - 06:00 1.50 FISH TRIP WRKOVR 06:00 - 10:30 4.50 FISH TRIP WRKOVR 10:30 - 11 :30 1.00 FISH MILL WRKOVR 11 :30 - 12:30 12:30 - 14:30 14:30 - 18:00 18:00 - 21 :00 1.00 FISH 2.00 FISH 3.50 FISH 3.00 FISH MILL WRKOVR CIRC WRKOVR TRIP WRKOVR TRIP WRKOVR 21 :00 - 22:30 1.50 FISH TRIP WRKOVR 22:30 - 00:00 1.50 FISH TRIP WRKOVR 5/28/2004 00:00 - 03:00 3.00 FISH TRIP WRKOVR 03:00 - 04:00 1.00 WELLSR DEQT WRKOVR 04:00 - 05:00 1.00 FISH FISH WRKOVR 05:00 - 07:30 2.50 FISH FISH WRKOVR 07:30 - 09:30 2.00 FISH CIRC WRKOVR 09:30 - 10:30 1.00 FISH CIRC WRKOVR 10:30 - 11 :00 0.50 FISH TRIP WRKOVR 11 :00 - 16:00 5.00 FISH TRIP WRKOVR 16:00 - 17:00 1.00 FISH OTHR WRKOVR 17:00 - 18:00 1.00 FISH TRIP WRKOVR Page 3 of 9 Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Spud Date: 1/1/1999 End: Group: Description of Operations Open up pump valves, but found no problem. There is a general problem with the low & high pressure pump arrangement resulting in partial or complete loss of suction, even with neat seawater. Wash & ream f/4770' t/4781' (kelly down). Discontinue milling for evaluating junk recovery with still sufficient distance to TOL for best recovery with wash pipe. RB kelly, back flow in pipe. Pump dry job. POOH with fishing assy #1. Cont POOH with fishing assy #1 to BHA. Pull BHA & break out RCJB. Recovered: -4 guards, 10 bands, 15 gal iron sulfide. Note 1: Carbon bands severly corroded. Note 2: Catcher in RCJS 100% intact. Rerun RCJB, fishing assy #2. Run BHA. RIH with DP. Service rig. Continue to RIH to 4,750'. PU kelly & break circulation. Wash and ream from 4,750' to 4,826'. 45 DW WT. 57 UP WT. RPM: 40 - 3K ftlbs. 4.5 bpm - 760 psi. Seawater. No sweeps. Little resistance, max 2 klbs WOB.. Dry mill 10' to 4,836'. Circ BU POOH to BHA Pull BHA. Break down RCJB. Recovered 4-6 Ibs broken up steel bands and cable guards along with 10 gal iron sulfide. RCJB catcher undamaged. LD RCJB MU fishing assy #3. 8 3/16" rat-trap junk basket mill - 2 x X/O bushings - 1 jnt 8 1/8" wash pipe - boot basket / drive sub - xo - bumper sub/jar - oil jar - 6 x 4 3/4" DC - pump out sub - xo: 246.91'. RIH with fishing assy #3. Cont RIH with fishing assy #3,81/8" wash pipe. Slow trip due to backflow. PT 9 5/8" casing to 1 ,500 psi / 30 min, chart. PU kelly Problems in getting proper suction on mudpump. Checked seats, strainers, liners, etc, but found no debris or other reason for starving pump. Picked up Kelly and lined up to reverse. Begin reverse out of sand and left over bands. 3 BPM @ 230# IA pressure. 20# DPP. Re-affirm that tag is 4,848' RKB and prepare to POOH. Blow dwn Kelly and prepare to POOH. Install bales and elevators. Lay down one single and rack back doubles. Pick up long tongs and prepare to tear down Baker string. 3 bands collected. Clean rig floor and lay down handling equip. Pick up new handeling tools and begin to make up BHA for IBP retrieval. Printed: 6/28/2004 1 :52:08 PM ConocoPhillips Alaska Operations Summary Report Legal Well Narne: 2T-220 Cornmon Well Narne: 2T-220 Event Narne: WORKOVER/RECOMP Contractor Narne: Doyon Drilling Inc Rig Narne: Doyon 19 Date Frorn - To Hours Code Sub Phase Code 5/28/2004 18:00 - 21 :30 3.50 FISH TRIP WRKOVR 21 :30 - 22:00 0.50 FISH SFTY WRKOVR 22:00 - 00:00 2.00 FISH TRIP WRKOVR 5/29/2004 00:00 - 03:00 3.00 FISH TRIP WRKOVR 03:00 - 04:00 1.00 FISH TRIP WRKOVR 04:00 - 10:00 6.00 FISH TRIP WRKOVR 10:00 - 11 :00 1.00 FISH TRIP WRKOVR 11 :00 - 12:00 1.00 FISH TRIP WRKOVR 12:00 - 14:00 2.00 FISH TRIP WRKOVR 14:00 - 16:00 2.00 FISH TRIP WRKOVR 16:00 - 21 :00 5.00 FISH TRIP WRKOVR 21 :00 - 21 :30 0.50 FISH OTHR WRKOVR 21 :30 - 22:30 1.00 FISH CIRC WRKOVR 22:30 - 23:30 1.00 FISH WASH WRKOVR 23:30 - 00:00 0.50 FISH CIRC WRKOVR 5/30/2004 00:00 - 02:00 2.00 FISH CIRC WRKOVR 02:00 - 02:30 0.50 FISH CIRC WRKOVR 02:30 - 03:30 1.00 FISH FISH WRKOVR 03:30 - 06:00 2.50 FISH TRIP WRKOVR 06:00 - 10:00 4.00 FISH TRIP WRKOVR 10:00 - 14:30 4.50 FISH TRIP WRKOVR 14:30 - 22:00 7.50 WELCTL BOPE WRKOVR Page 4 of 9 Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Spud Date: 1/1/1999 End: Group: Description of Operations MU BHA: IBP retrieving - 15 jnts 2 3/" Hydril 511 - 3 x x/O - 2 x boot baskets- bumper jar - oil jar - 6 x 4 3/4" DC - pump out sub - xo = 719.22' Safety & info meeting with new crew on rig floor. Rih with IBP retrieving tool on 3.5" PH-6 DP. Cont RIH with IBP retrieving assy. Break circulation 60' from bottom. Tag TOL at 4856'. Attempt reverse circ, no go. Attempt to unplug string by pumping down tubing, max 4,000 psi, no go. Drop shear-ou probe and attempt to open circ sub. No go. PJSM - POOH tripping wet. Attention on potential spill. Lay down drill collars. Prep to lay down 511 work pipe. No fill at this time. Lay down drill collars and jars, bumper sub. Pick up 2 3/8" handeling gear. Prep to pull 2 3/8" out for BHA inspection. At this time no solids. OOH. solids in the last 8' of tubing. Fishing tool plugged off with sand and scale. All tools washed from pulling wet. Prepare BHA to RBIH. RIH with IBP retrieving tool, run #2. Utilize same fish string. RIH with retrieving assy on 3.5" PH-6 DP to 4745'. Remove elevator and bails, PU kelly. Break circ and pump hi-vis sweep due to backflow from solids in annulus. 4.6 BPM-420 psi. Wash down from 4745' to 4890', ie. 10 ft above IBP. Stod up 2' above liner top, had to rotate string to break through. 10 RPM- 2200 ftlbs free rotating torque, max 2400 ftlbs. Rotating wt 45 klbs. Commence pump 30 bbl 3 ppb FloVis pill and displace hole to filtered seawater taking returns back to open top tank. Up wt: 55 klbs, Dw wt: 35 klbs. 4.6 BPM - 570 bbl. Reciprocate string. Cont displacing hole to filtered seawater. Pumped 2 x hole volumes with 30 bbl hi-vis ahead. 4.6 BPM - 570 psi. Wash down slowly with kelly and engage IBP at 4900'. Set down 4 klbs, got good pressure indications of catch. Pull up and release packer with 15 klbs overpull. Allow packer to relax, fluid level dropped out of sight. Shot FL: 210' after 15 min. Circ down DP at 1 BPM - 900 psi. Attempt to pull up - stuck at 4890'. Line up on annulus to flush by packer at 5 BPM, hole filled up. Switch to DP - pipe plugged. Work and jar on IBP increasing overpull. Came free with 45 klbs overpull dragging 20 klbs overpull to top of liner. Shoot fluid level: 5 min -100',15 min 115', 30 min - 132', 65 min - 187', 115 min - 78'. LD 3 jnts DP. Attempt to shear circ sub- no go. PJSM with crew, POOH, wet trip. Shoot fluid level to confirm top of liquid. Shot # 7 after 215 min -126'. Continue to POOH. Found IBP parted in mandrel leaving packing element, 7' 1" mandrel and bottom sub in hole. Pull wear bushing & perform weekly BOPE test 250/3,500 psi. Set wear bushing. Printed: 6/28/2004 1 :52:08 PM Legal Well Name: Cornmon Well Narne: Event Narne: Contractor Name: Rig Name: 5/30/2004 5/31/2004 6/1/2004 ~, { ConocoPhillips Alaska Operations Summary Report 2T -220 2T -220 WORKOVER/RECOMP Doyon Drilling Inc Doyon 19 Date Frorn - To Hours Code ¿>~dbe Phase 14:30 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 04:30 04:30 - 08:00 08:00 - 08:45 08:45 - 11 :00 11 :00 - 11 :30 11 :30 - 12:30 12:30 - 18:00 18:00 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 03:00 03:00 - 03:30 03:30 - 06:00 06:00 - 06:30 06:30 - 08:30 08:30 - 09:00 7.50 WELCTL BOPE WRKOVR 2.00 WAlTON EQIP WRKOVR 1.00 WELCTL BOPE WRKOVR 3.50 FISH TRIP WRKOVR 3.50 FISH 0.75 FISH 2.25 FISH 0.50 FISH 1.00 FISH 5.50 FISH 6.00 FISH 0.50 FISH 0.50 FISH 2.00 FISH 0.50 FISH 2.50 FISH TRIP WRKOVR TRIP WRKOVR FISH WRKOVR FISH WRKOVR FISH WRKOVR TRIP WRKOVR TRIP WRKOVR TRIP WRKOVR FISH WRKOVR FISH WRKOVR TRIP WRKOVR TRIP WRKOVR 0.50 RIGMNT RSRV WRKOVR 2.00 FISH TRIP WRKOVR 0.50 FISH PULD WRKOVR Page 5 of 9 Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Spud Date: 1/1/1999 End: Group: Description of Operations Lower kelly cock leak - new underway. AOGCC Chuck Shievy waived test. Sevice and clean rig while WO tools from BOT, Dead Horse. 21/8" weight bar, 3 1/8" up/dw jar & xo. Tools arrive at 00:00 hrs. Test new lower kelly cock 250 /3,500 psi. MU BHA: 2 1/8" bull nose - 2 1/8" weight bar - xo - up/dw jar - circ sub - 2 x xo- 15 jnts 2 3/8" Hyd 511 - 2 x xo - bumper jar - oil jar- 6 x 4 3/4" DC - xo: 686.62' Cont RIH on 3 1/2" PH-6 work string. Break circulation. 1.5 BPM @ 90# DPP. UP wt = 57K. DWN = 37K. Tag IBP @ 4.890', (10' above set depth). Spudded IBP down hole in 2' increments using the bumper sub to 5,013'. Check up wt every 15'. 2-5 BPM, 300-1300 psi, 0-50% returns. Dwwt = 35K up wt = 54K. Stand up at 5,013' with no further progress. Max down weight 10 klbs, max spud dw wt 5 klbs. Standby for more water. Water truck on location. Was ordered 06:30 hrs. Made several attempts to push IBP down without success. POOH. Fill 5 bbl every ten jts. Found 2 3/8" STL connection beveled. BO weight bar - caught 8" of packer element on bar. MU IBP fishing assy #1. 3.187" wash pipe (8.7') - circ sub - hyd disconnect - U/D jar - 2x X/O - 15 jnts 2 3/8" 511 Hydril - 2x X/O - 4 3/4" bumper jar & oil jar - 6 x 434" DC - X/O = 692.37'. RI H to 4,811', 45' above liner top. Take pressure and torque readings. 18 RPM - 2,100 ftlbs. 2 BPM/11 0 PSI - 3/300 - 4/510 - 5/840 Fluid level shot at 21' at 21 :00. Hole full after pumping 25 bbl. Cont RIH. Had to rotate through liner top. Stand up at 4961', top of perfs. PU kelly. (Did not remove bails) Wash & push down to 5,048' (ORKB) 2 bpm - 160 psi. 30-50% returns. Hole stay full on connections. Had indications of catching IBP: 5 klbs overpull & lost returns, then regained circ and no further overpull. Made several attempts to spud and work down on IBP, max torque 3,000 ftlbs, 1,000 above free rotating torque. Did not rotate on plug, but work torque into it with 5-10 klbs down weight. Upwt: 60 klbs, DW wt: 40 klbs. RB kelly. POOH. Had 3-10 klbs pulling out of liner. Max 20 klbs. Fluid level dropped OOS. Grease blocks, crown, D.W., inspect brakes. POOH wI 3-1/2" pipe. Rack back collars, lay down jars. Fluid level 302'. LID 15 jts 2-3/8" pipe. Break wash-over pipe down, clear barrel of Printed: 6/28/2004 1 :52:08 PM ConocoPhillips Alaska Operations Summary Report Page 6 of 9 Legal Well Name: Common Well Narne: Event Narne: Contractor Name: Rig Name: 2T-220 2T -220 WORKOVER/RECOMP Doyon Drilling Inc Doyon 19 Spud Date: 1/1/1999 End: Group: Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Frorn - To Hours Code îo~be Phase Date Description of Operations 6/1/2004 0.50 FISH 1.00 FISH 5.50 FISH 08:30 - 09:00 09:00 - 10:00 10:00 - 15:30 PULD WRKOVR band material. PULD WRKOVR Clean rig floor and remove 2-3/8" handling equipment. TRIP WRKOVR Rerun wash-over pipe,hyd disconnect - circ sub, PU16-3-1/8" DC, drift in door - jars - 6 x 4-3/4" DC. Rig up power tongs and air slips. RIH w/ 3-1/2" pipe f/derrick. TRIP WRKOVR Tagged top of liner. Work thru with tongs. R/U Kelly and established circulation. CIRC WRKOVR Wash down and tag up at 5,048', previous clean-out depth. FISH WRKOVR Spud, work, wash & ream IBP f/5,048' - t/5,096' ORKB. No further progress. Upwt 62 klbs, Dwwt: 42 klbs, Rot wt 50 klbs Free rotating torque: 3,000 ftlbs /20 RPM. 1 BPM: 60 psi off bttm, 170 on fish. Rotated on IBP: WOB 2-4, Torque 4,000 ftlbs Max dw wt rotating: 10 klbs. Max push wt 30 klbs. Max torque 4,500 ftlbs. Partial returns, little or no drag in liner. TRIP WRKOVR RB kelly. TRIP WRKOVR LD 4 pup jnts & POOH. TRIP WRKOVR Cont POOH with wash pipe run #2. Recovered 1.5 Ibs junk; ribs, rubber and completion band trapped in wash pipe. TRIP WRKOVR MU new 3 1/8" wash pipe assy #3 & RIH with same assy without hyd. disconnect and circ sub. Fluid level @ 0800 hrs = 225'. FISH WRKOVR Tagged up at liner top, worked thru with tongs. R/U Kelly. Pumped down to fish at 5096' ORKB. WASH WRKOVR Up wt 58K Dwn wt 37K Pumping at 1 BPM w/90 psi. Worked over fish press increased to 130 psi. Shut off pump, worked over fish rotating only. P/U and dragging 10K over string wt. Kicked pump on, press went up to 360 psi. dropped back to 130 psi. No drag. Work back over fish w/o pumping, rotating only. Pulled up dragging again w/extra 40k over string wt. drag fell off at 4998'. Fluid level dropped out of site. Lowered back down 60' without touching anything. TRIP WRKOVR R/B Kelly and POOH. Recovered 1-2 Ibs ribs and rubber, no completion bands. TRIP WRKOVR MU new 33/16" wash pipe w/2x cut-lip guide and 5 ea dragon teeth starting 3' above burn shoe. RIH with wash pipe assy #4. WASH WRKOVR Take parameter readings. Wash and work down on fish. Had to rotate last 11'. Had 20 klbs overpull increase twice, but lost after pulling back 1 a'. Circ 0.2-1.0 BPM, had partial returns. Rotate. push and spud to 5,098', no further progress. RPM: 40, 3,000-5,500 ftlbs. 1 BPM - 60 psi prior to milling and 170 psi when finished. WOB: 0 - 10 klbs, max down weight: 25 klbs TRIP WRKOVR RB kelly and POOH with washpipe #4. TRIP WRKOVR Cleaned out washpipe. Found bunrt shoe to beveled and distorted. Recovered more IBP ribs and one band. PULD WRKOVR M/U new shoe on BHA and RIH with washpipe run #5. TRIP WRKOVR Worked thru top of liner. Ran on down and tagged fish at 5096'. MILL WRKOVR Milled on fish pumping 1 BPM w/110 psi. Not milling down seems to be 15:30 - 16:00 0.50 FISH 16:00 - 18:00 18:00 - 22:00 2.00 FISH 4.00 FISH 22:00 - 22:30 0.50 FISH 22:30 - 00:00 1.50 FISH 6/2/2004 00:00 - 03:00 3.00 FISH 03:00 - 10:00 7.00 FISH 10:00 - 12:00 2.00 FISH 12:00 - 13:30 1.50 FISH 13:30 - 18:30 5.00 FISH 18:30 - 00:00 5.50 FISH 6/3/2004 00:00 - 02:00 2.00 FISH 4.00 FISH 0.50 FISH 02:00 - 06:00 06:00 - 06:30 1.50 FISH 4.00 FISH 1.50 FISH 06:30 - 08:00 08:00 - 12:00 12:00 - 13:30 Printed: 6/28/2004 1 :52:08 PM Legal Well Narne: Common Well Narne: Event Narne: Contractor Name: Rig Narne: 6/3/2004 6/4/2004 6/5/2004 .( ( ConocoPhillips Alaska Operations Summary Report 2T-220 2T -220 WORKOVER/RECOMP Doyon Drilling Inc Doyon 19 Date Frorn - To Hours Code ~~Je Phase 12:00 - 13:30 13:30 - 16:30 16:30 - 21 :00 21 :00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 02:30 02:30 - 04:30 04:30 - 08:30 08:30 - 09:00 09:00 - 12:30 12:30 - 16:30 16:30 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 07:00 07:00 - 10:00 10:00 - 15:00 15:00 - 16:30 1.50 FISH 3.00 FISH MILL WRKOVR JAR WRKOVR 4.50 FISH JAR WRKOVR 1.00 FISH TRIP WRKOVR 1.00 RIGMNT RSRV WRKOVR 1.00 FISH CIRC WRKOVR 2.50 FISH 2.00 FISH TRIP WRKOVR TRIP WRKOVR 4.00 FISH TRIP WRKOVR 0.50 FISH TRIP WRKOVR 3.50 FISH WASH WRKOVR 4.00 FISH JAR WRKOVR 7.50 FISH JAR WRKOVR 2.00 FISH TRIP WRKOVR 0.50 RIGMNT OTHR WRKOVR 4.50 FISH TRIP WRKOVR 3.00 RIGMNT RSRV WRKOVR 5.00 FISH TRIP WRKOVR 1.50 FISH CIRC WRKOVR Page 7 of 9 Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Spud Date: 1/1/1999 End: Group: Description of Operations just spinning. While rotating added more weight and begin to push fish down hole to 5135' ORKB. Lost pump press and lost circulation. Attempted to pull, stuck at 5125'. Possible to rotate but not go up or down, then torqueing up and stalling. Work and jar on string for 3 hrs, max 150 klbs, work up 10'. Hole full when pumping on annulus, fluid level drop when pumping down string, no returns. Remove suction valve on pump and run 4 BPM to shake. string. Lost 5 klbs o/pull. Work string with max 190 klbs - (250 klbs MD wt). Jar with 65 klbs o/pull. Start moving w/160-190 klbs overpull to 5093', came free. RB kelly & pull back to liner top at 4,856'. Had 10 klbs drag to 5,083', no more overpull. Inspect rig after fishing operation. Fill hole 60 bbl down annulus. Washed 30' above liner and into liner to remove any debris caught above top of liner. Closed ann preventer and bullheaded 40 bbl, 4.5 bpm - 360 psi. Was able to reverse circulate down to 1 bpm. POOH with wash pipe #4, run #5 to BHA. Cont POOH. Found lower IBP assy lodged in washpipe. Clean out recovery from washpipe. LD 31/8" Up/Dw jars. MU redressed 3 3/16" washpipe - circ sub - hydraulic disconnect - 16 x 31/8" DC - xo - new 43/4" jars - 6 x 43/4" DC - xo RIH with washpipe run #6. Tagged top of liner, worked thru and ran on down and tagged top of fish @ 5127' While rotating, push fish down hole. Fish would catch occasionally and torque up, mill off and continue down hole. Pushed fish to 5191 ORKB. Started torquing up. Work pipe back to 5,088', no further progress. Limited pulling capacity due to slip type elevator used on 3.5" PH-6 string. Work & jar on string up at 5,088'. Install DP elevator as slip type elevator is limited on pulling and jarring. Take out suction valve on pump to vibrate string. Work to max 265 klbs pull, 210 klbs overpull, made 2-3 feet over several hours. Mix 140 bbl 2% Lubetex and 2lbs/bbl Flovis. Attempt to bullhead lube-pill down annulus, plugged off. Spot 40 bbl pill down pipe. No returns. Apply 265 klbs pull on string and close bag. Bullhead with 0.25 bpm @ 800 psi, slowly increasing rate maintaining pressure. After 20 min and 0.75 bpm (tot 8 bbl pumped) string came free. Pressure dropped and rate brought up to 2 bpm - 300 psi. PIPE FREE. Displace 80 bbllube-pill down annulus to slick up build section. Well on vacuum. - was plugged before. LD pup with circ head. Change to slip type elevator. Pull back to liner top, no drag. Inspect rig after jarring operation. POOH with washpipe assy #6. No recovery. Slip and cut drill line. Service rig. MU flat bottom junk mill on BHA and RIH for clean out run. Stopped 40' above liner top (4806'). RU circulating head. Displaced 80 bbllube-pill down tubing closed Printed: 6/28/2004 1 :52:08 PM I( ( GonocoPhillips Alaska Operations Summary Report Legal Well Narne: Cornmon Well Narne: Event Narne: Contractor Narne: Rig Name: Date 6/5/2004 6/6/2004 2T -220 2T-220 WORKOVER/RECOMP Doyon Drilling Inc Doyon 19 Frorn - To Hours Code Sub Phase Code 15:00 - 16:30 1.50 FISH CIRC WRKOVR 16:30 - 17:30 1.00 FISH TRIP WRKOVR 17:30 - 00:00 6.50 FISH PULL WRKOVR 00:00 - 03:30 3.50 FISH PULL WRKOVR 03:30 - 04:30 1.00 MOVE POSN WRKOVR 04:30 - 06:30 2.00 CMPL TN OTHR WRKOVR 06:30 - 09:00 2.50 WELCTL BOPE WRKOVR 09:00 - 12:00 3.00 CMPL TN RUNT WRKOVR 12:00 - 12:30 0.50 CMPL TN SFTY WRKOVR 12:30 - 13:30 1.00 CMPL TN OTHR WRKOVR 13:30 - 16:30 3.00 CMPL TN RUNT WRKOVR 16:30 - 19:30 3.00 CMPLTN RUNT WRKOVR 19:30 - 21 :30 2.00 CMPL TN RUNT WRKOVR 21 :30 - 00:00 2.50 CMPL TN RUNT WRKOVR 6/7/2004 00:00 - 07:30 7.50 CMPL TN RUNT WRKOVR 07:30 - 11 :30 4.00 CMPL TN RUNT WRKOVR 11 :30 - 12:30 1.00 CMPL TN RUNT WRKOVR 12:30 - 16:30 4.00 CMPL TN RUNT WRKOVR 6/8/2004 16:30 - 17:30 1.00 CMPLTN SOHO WRKOVR 17:30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 04:30 5.50 CMPL TN NUND 1.00 CMPL TN RURD 0.50 CMPL TN RURD 1.00 CMPL TN RURD 3.00 CMPL TN RURD WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 04:30 - 06:00 1.50 CMPL TN RURD WRKOVR 06:00 - 11 :30 5.50 MOVE OTHR WRKOVR 11 :30 - 13:00 1.50 MOVE OTHR WRKOVR 13:00 - 16:00 16:00 - 20:30 3.00 MOVE OTHR WRKOVR 4.50 WELCTL BOPE WRKOVR Page 8 of 9 Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Spud Date: 1/1/1999 End: Group: Description of Operations Annular and bullhead to slick up liner. LD pup with circ. head. Worked thru top of liner and continued down and tagged fish at 5165' ORKB. Unable to push further. POOH with workstring laying down all DP. PU kelly & make service breaks. RB kelly. Pull & lay down DC & BHA. PJSM. Jack mast back and level and align rig on well. Pull wear bushing, and install test plug. Change rams f/3-1/2" to 4-1/2". Test 4-1/2" rams 250 low 3500 high. Weekly BOP test extened 24 hrs by John Crisp w/AOGCC. R/U to run ESP completion. PJSM on running tubing and ESP completion. N/D ESP Cable Sheave and realign over hole. P/U motor, centralizer, motor and pump. Pick upseal section and assemble same to motor section. Service the seal section checking and recording info. of entire assembly. Feed motor lead extension cable through sheave to floor. Install ESP assy. MU 3.5" tbg, install Guardian 2 gauge. Run completion as per plan. 11 jnts 4.5" tubing run at report time, 134 left to run. Cont run ESP completion (13 jnts/hr)Testing cable every 1000' Change out spool and splice ESP cable at 650'. Test conductivity OK. Continue RIH w/ ESP completion (4.5" tbg. ESP cable, controlline,& GLM. Made final splice to ESP cable. Connect I-wire and ESP cable to penetrators and run thru Hanger. Test conductivity OK. Run 2 jnts 3.5" tbg, 145 jnts 4.5" tbg, 1 CMU and 2 GLMs. Install ESP and I-wire with 77 clamps, 3 protectolizers, 5 flat guards, 15 flat bands. Up Wt = 52 K Dwn = 46 K Blks = 10 K Landed hanger, RILDS. Install TWC. RD BOPE. NU tree adapter. Cont NU tree. Attempt to pressure test flange, SBMS leak. Change damaged O-ring on SBMS & re-install tree adapter. Pressure test adapter to 250/5,000 psi. Install and orient tree, test same t0250/5,OOO psi. Centrilift Rep. did not have pigtail to test, had to run back KOC. Released rig. Scoped down derrick and laid down. Preped rig for rig move. Test ESP cable, good. Clean out equipment from cellar. Test DH gauge, no response. Trouble shoot without success. DH gauge failed, possibly in penetrator. Made decision to rig back up and pull hanger to floor and diagnos. Time from Rig Release to decision to rig back up (0400 hrs to 0630 hrs) belongs to CPA N/D tree, retest DH Press-Temp Guage, no response, showing OPEN. Move pipe shed away from Carrier. Move Carrier back 4" to recenter rig over well. Repair turnbuckle on jacking system of rig. Releveled rig. (Repair Time 1.5 hrs.) PJSM on raising derrick. Raised derrick and rig up to pull hanger. N/U BOPE, change out pipe rams to 4-1/2" and test 250/3500 psi. Printed: 6/28/2004 1:52:08 PM { ~: Page 9 of 9 ConocoPhillips Alaska Operations Summary Report Legal Well Narne: 2T-220 Common Well Narne: 2T-220 Event Narne: WORKOVER/RECOMP Contractor Narne: Doyon Drilling Inc Rig Narne: Doyon 19 Date Frorn - To Hours Sub Phase Code Code 6/8/2004 16:00 - 20:30 4.50 WELCTL BOPE WRKOVR 20:30 - 00:00 3.50 WELCTL BOPE WRKOVR 6/9/2004 00:00 - 00:30 0.50 WELCTL NUND WRKOVR 00:30 - 01 :00 0.50 WELCTL NUND WRKOVR 01 :00 - 02:00 1.00 WELCTL EaRP WRKOVR 02:00 - 03:00 1.00 WELCTL NUND WRKOVR 03:00 - 04:30 1.50 WELCTL NUND WRKOVR 04:30 - 06:00 1.50 WELCTL NUND WRKOVR 06:00 - 08:00 2.00 WELCTL NUND WRKOVR 08:00 - 09:00 1.00 WELCTL NUND WRKOVR Start: 5/22/2004 Rig Release: 1/18/1999 Rig Nurnber: Spud Date: 1/1/1999 End: Group: Description of Operations Witnessing waived by John Crisp (AOGCC). Pulled BPV and installed 2 way check. Tested BOPE and removed the 2 way check. Well is still on a slight vacum. Removed 2-way check and backed out the LDS. Pulled Hanger to the floor with no problems. 52k Up weight. Found I-wire internal wire inside of the connector to be broken. Repaired I-wire and retested. Tested good. Downhole gauge is reading 860 psi and 64 degrees. Also re-checked ESP cable and it checked out OK. Re-Ianded the hanger 46k down weight. Lined up on alignment pin and seated completely. RILDS. Installed 2-way check Removed BOPE from the wellhead and re-checked I-wire, checked out OK still showing 860 psi and 64 degrees. Changed pipe rams back from 4-1/2" to 3-1/2". Continued Nippling down the BOPE. NU adapter & tree. Tested 250/3500 psi. Pull two-way check and install BPV. Release Rig @ 0900 hrs.Centrilift made final conductivity check of ESP cable & I-wire. Confirmed balanced conductivity for ESP. I-wire tested good Downhole guage reading 850 psi and 64 degrees. Prepare for Rig move. Printed: 6/28/2004 1:52:08 PM ConocoPhillips Alaska, Inc. 2T-220 TUBING (0-4636. 00:4.500. 10:3.958) ::>ROOUCTION (0-4990. 00:9.625, Gas Lift mdrel/Oummy Valve 2 (4288-4289, 00:5.984) SLEEVE (4623-4624, 00:5.000) TUBING (4636-4712, 00:3.500, 10:2.992) XO (4636-4637. 00:4.500) GAUGE (4702-4703, 00:4.500) OISCHARGE (4712-4713, 00:5.130) PUMP (4713-4736, 00:5.130) INTAKE (4736-4737, 00:5.130) SEAL (4737-4751, 00:5.130) MOTOR (4751-4785, 00:5.130) NIP (4785-4786. 00:3.000) Perf (4961-5517) GRAVEL PACK (4856-5517, 00:4.000, 10:0.000) LINER (4887-5517. 00:4.000, Wt:11.60) Ii t1 API: 501032028300 SSSV Type: None Well Type: PROD Orig 1/18/1999 Completion: Last W/O: 6/6/2004 Ref Log Date: TD: 5752 ftKB Max Hole Angle: 67 deg @ 2959 Size 16.000 9.625 4.000 4.000 Top 0 0 4856 4887 Bottom 112 4990 4887 5517 KRU 2T-22 0 Angle @ TS: deg (à) Angle @ TD: 43 deg @ 5752 Rev Reason: WORKOVER Last Update: 6/10/2004 TVD 112 3045 2991 3348 Wt 62.58 40.00 32.00 11.60 Grade Thread H-40 WELDED L-80 BTM-MOD L-80 Seal-Lock L -80 Screens Thread BTC-MOD 8rdEUE-M Thread Zone I Status ] Ft I SPF I Date I Type ] Comment 556 99 7/8/1999 (PERF ~:¿~ HOLE GRAVEL Annular Fluid: Reference Loç¡: 28'RKB Last Tag: 5165 Last Tag Date: 6/5/2004 Casing String - ALL Description CONDUCTOR SURF ACE/PRODUCTION LINER LINER Tubing String - ALL Size I Top I Bottom 4.500 0 4636 3.500 4636 4712 Tubing String - GRAVEL PACK Size I Top I Bottom 4.000 4856 5517 Perforations Summary Interval I TVD I 4961 - 5517 3029 - 3348 Gas Lift. MandrelsNalves St MD TVD Man Mfr 1 2628 1986 SWS KBG-2 2 4288 2692 SWS KBG-2 Other (plugs, eQuip., etc.) - JEWELRY Depth TVD Type Description 28 28 HANGER FMC TBG HANGER set 6/6/2004 4623 2858 SLEEVE BAKER CMU W/3.81 CAMCO PROFILE set 6/6/04 4636 2864 XO 4702 2898 GAUGE BAKER CENTURY GAUGE, BANDED TO SIDE OF PIPE set 6/6/2004 4712 2903 JISCHARGE CENTRILlFT DISCHARGE GAUGE set 6/6/2004 4713 2903 PUMP CENTRILlFT ESP PUM, 89 STAGE GC 100 set 6/6/2004 4736 2915 INTAKE CENTRILlFT INTAKE 4737 2915 SEAL CENTRILlFT TANDEM SEAL SECTION set 6/6/2004 4751 2923 MOTOR CENTRILlFT ESP MOTOR 418HP/2610/98A set 6/6/2004 4785 2940 NIP CENTRILlFT NIPPLE set 6/6/2004 4786 2940 Centralizer CENTRILlFT CENTRALIZER set 6/6/2004 General Notes Date I Note 6/10/2004 TREE: FMC MODEL 120 4-1/165K TREE CAP CONNECTION: 7" OTIS TVD 2864 2903 TVD 3348 I Wt 12.60 9.30 I Wt 0.00 I Grade I L-80 L-80 I Grade I Man Type V Mfr V Type V OD Latch Port TRO Date Run BK-5 0.000 0 6/6/2004 BK-5 0.000 0 6/6/2004 DMY DMY 1.0 1.0 Vlv Cmnt ID 3.958 3.810 3.500 3.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 198-253-0 KUPARUK RIV U TABS 2T-220 50- 103-20283-00 PHILLIPS ALASKA1NC Roll #1: Start: Stop Roll #2: Start Stop MD 0_5..752 TVD 03509 Completion Date: ~ Completed Status: 1-OIL Current: T Name Interval D 9200~'''~' 1 SPERRY MPT/GR/EWR4 L DGR/EWR4-MD FINAL 1062-5752 L DGR/EWR4-TVD ~"/WtFINAL 1023-3510 _ DSSI~~''' L MUD / L PEX-3DD/CN ~ PEX-HALS ~' L PEX-MCFL L PROD-PSP//' FINAL 4905-5505 L RELABELED DS~~/'' BL(C) 4910-5700 L SSTVD l/"-" R SRVY RPTL/ R SRVY RPT~ R SRVY RPT ~ T 9028 b,..-~ 1 FINAL 4988-5670 FINAL 4990-5747 F1NAL 4988-5682 FINAL 4988-5695 FINAL 4988-5695 FINAL 4988-5695 SPERRY 852.88-4995. SPERRY 0-4771. PB1 SPERRY 0-5752. SCHLUM PEX-DSI/HALS/PDC Sent Received T/C/D · OH 5/27/99 5/27/99 OH 6/1/99 6/3/99 OH 6/1/99 6/3/99 OH 3/17/99 3/18/99 OH 2 3/23/99 3/26/99 OH 3/17/99 3/18/99 OH 3/17/99 3/18/99 OH 3/17/99 3/18/99 CH 5 3/24/00 4/10/00 OH 2 3/17/99 3/18/99 OH 3/17/99 3/18/99 OH 2/23/99 2/24/99 OH 2/23/99 2/24/99 OH 3/15/99 3/16/99 OH 3/17/99 3/18/99 Wednesday, March 28, 2001 Page 1 of 1 3~24~00 Schlumberger NO. 121313 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2T-220 PROD PROFILE/DEFT 000312 I 1 ,,, Alaska Oil & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson(/~J~ DATE: March 1, 1999 Chairman THRU: Blair Wondzell, P. I. Supervisor :~[~-l~ FROM: Lawrence M Wad~z'/~z''~ SUBJECT: Petroleum Inspector FILE NO: .ab2gcagfDOC BOP Test Nordic 3 KRU 2T-220 PTD 98-253 March 1,1999: ! traveled to Kuparuk to witness a BOP test on Nordic 3 which was completing a Tabasco well on 2T pad. While trying to do a full body pressure test on the BOP test we found a flange leak under the hydril. That was fixed and then the test plug started leaking. It was pulled and the another rubber seal installed on the test plug. It still leaked. We dumped two sacks of barite on top of the test plug and it quit leaking. Then the popoff on the test pump started leaking. We continued testing using the mud pumps while the popoff valve was taken apart. There was a small pebble under the seat in the popoff valve. It was cleaned out and the pump worked as it should. From then on the test went smooth. SUMMARY: Witnessed a BOP test on Nordic 3, 0 failures, 6 hours. Attachments: cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nordic Operator: ARCO Well Name: 2T-220 Casing Size: g 5/8 Set ~_. Test: Initial X Weekly Rig No. 3 PTD # Rep.: Rig Rep.: 4,987 Location: Sec. Other 98-253 DATE: Rig Ph.# Dearl Gladden 3/1/9g Shane McGheehan I T. 11N R. 8E Meridian Umiat Test MISC. INSPECTIONS: Location Gen.' ok Housekeeping: ok (Gen) PTD On Location X Standing Order Posted X Well Sign X Drl. Rig X Hazard Sec. X ' FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F I 250/3,000 P I 250/3,000 P I P 250/3,000 I 250/3,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 250/3,000 P 250/3,000 P 250/3,000 P 250/3,000 P 250/3,000 P 250/3,000 P 250/3,000 P 250/3,000 MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X · H2S Gas Detector X X , CHOKE MANIFOLD: No. Valves 12 No. Flanges 36 Manual Chokes Hydraulic Chokes Test Pressure 250/3,000 250/3,000 Functioned Functioned P/F ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2350-2400 2,900 I 2,000 . minutes 15 sec. minutes 27 sec. X Remote: X 2400-2450 Psig. Number of Failures: I ~' ,Test Time: 6.0 Hours. Number of valves tested '/9 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-O21L (P, ev.12/94) ab2gcagf, xls ARCO Alaska, Inc. AAI Drilling Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Ddlling Manager Janua~ 8,1999 Mr. Blair Wondzell, PE Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: 2T-220 Sidetrack Dear Mr. Wondzell: As per our conversation of 1/7/99, this letter is to notify you of the upcoming sidetrack of the surface hole on well 2T-220 in the Kuparuk River Unit (KRU). This sidetrack was required after losing drilling BHA in the hole at 1904'. Approximately 3.5 days were spent unsuccessfully attempting to retrieve the fish. Current plans call for laying a balanced cement plug above the fish, kicking off of the plug using a steerable motor assembly, and drilling to surface casing TD as outlined in the original approved permit to drill (permit # 98-253). No changes from the original permit are planned in regards to surface casing point or well target. Attached are a plug setting procedure and wellbore schematic, If you have any questions or require further information, please contact Tom Brockway, Operations Drilling Engineer at (907) 263-4135 or Tom McKay, Shallow Sands Drilling Team leader at at (907) 265- 6890. Thomas A, Brockway ,~,-'~ Operations Drilling En~lrneer ARCO Alaaka~ Ino, la a Subeidiary of AtlanticRIch~eldCompeny ARCO Alaska, Inc. Plug Procedure for Sidetrack Kuparuk River Field-Producer Tabasco Well. 2T-220 1. RIH with 5" DP with a 300' 3-112" stinger to +/-1610 (top of fish at 1612' MD). 2. Circulate and condition hole until mud properties re[urn to the ranges specified in the 2T-220 well plan and Tabasco Master Well Plan. 3, La)/250' balanced cement plug from 1610' MD to +/- 1360' MD. 4. POQH to +/- 1100' MD. Circulate out excess, cement and contaminated mud. Wait +/- 2 hfs for plug to set up, Ease slowly back into hole and tag top of plug, Circulate and condition for second plug, §. Lay 250' balanced cement plug from +/- 1360' MD to +1- 1110' MD. 6. POOH to +/- 600' MD, Circulate out excess cement and contaminated mud, 7, Finish POOH and stand back 5" DP 8. PU kickoff BHA, RIH, tag cement, and dress plug to +/- 1130'. · Note: a minimum of 8-10 hours of WOC time will be required before dressing the plug in order for the cement to obtain sufficient compressive strength. · Rattle pipe before running back in hole to help minimize the possibility of cement falling into the MWD and motor. Run drill pipe screens if available, 9, Kick off as per revised Inteq directional plan. Time drill as necessary to get off of plug, · Pre-treat mud system as necessary to help minimize cement contamination effects. 10. Drill to TD, case and cement as per 2T-220 well plan and Tabasco Master Well Plan, Operations Dr-~lling Engine~ Drilling Team Date Date 2T-220 Plug & Sidetrack TAB, 01/07/99, v2 ARCO FIIo Calculations Charl jShaet number o, 0 ~ q772 ~ ARCO Alaska, Inc. - ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 28, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-220 (Permit No. 98-253/399-111) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the Report of Sundry Well Operations to cover any changes made to the completion during the recent workover operations on Tabasco well 2T-220. If there are any questions, please call 263-4603. Sincerely, Paul Mazzolini Drilling Team Leader AAI Drilling PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X Change-Out ESP 2. Name of Operator: !5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X 28' RKE 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagraphic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 792' FSL, 556' FWL, Sec. 1, T11 N, R8E, UN 2T-220 At top of productive interval: 9. Permit number/approval number: 1078' FNL, 826' FWU SEC 1, T11 N, R8E, UN 98-253 / 399-111 At effective depth: 10. APl number: 50-103-20283 At total depth: 11. Field/Pool: 517' FNL, 953' FWL, SEC 1, T11 N, R8E, UN Kuparuk River Field/Tabasco Oil Pool 12. Present well condition summary Total Depth: measured 5752 feet Plugs (measured) true vertical 3509 feet Effective Deptt measured 5529 feet Junk (measured) true vertical 3339 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 16" 9 cu yds High Early 112' 112' Surface 4959' 9.625" 447 sx AS III U 950 sx Class G 4990' 3047' 60 sx AS I Production Liner 665' 4" gravel pack screen assembly 5517' 3348' Perforation Depth measured 4961'-5517' MD OPEN HOLE GRAVEL PACK true vertical 3032'-3348' TVD OPEN HOLE GRAVEL PACK / I L Tubing (size, grade, and measured depth) 4.5" x 3.5", 12.6# / 9.3#, L-80 @ 4575'/4675', Y-block w/2-7/8", 6.5#, L-80 @ 4792' Packers and SSSV (type and measured depth) ~' ~ ~ ~ ~ / ~_~ .~. 4852' GP packer, No SSSV 13. Stimulation or cement squeeze summary (measured~ N/A ~,~,f~. ~.~, ~.~_ ,~. Intervals treated Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signed '~~~~ Title: Drilling Team LeaOer Date Paul Mcl'z2'olin[ Prepared by Sharon AIIsup-Drake Form 10-404 Rev 06/15/88 SUBMIT IN DUPLIC~ Date: 8/6/99 ARCO ALASKA INC. WELL SUMPLARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2T-220WOE RIG:NORDIC 3 WELL_ID: 999391 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: TABASCO BLOCK: SPUD:07/02/99 START COMP:06/30/99 FINAL: WI: 0% SECURITY:0 API NIIMBER: 50-103-20283-00 06/30/99 (C1) TD: 5545' PB: 5545' 07/01/99 (C2) TD: 5545' PB: 5545' 07/02/99 (C3) TD: 5545' PB: 5545' 07/03/99 (C4) TD: 5545' PB: 5545' 07/04/99 (C5) TD: 5545' PB: 5545' 07/05/99 (C6) TD: 5545' PB: 5545' MOVING RIG TO 2T-22099(RI MW: 0.0 SUPV:D. GLADDEN / T. BRASSFIELD Rig moving to 2T-220. UPCOMING OPERATIONS:CONT' MOVE TO 2T-220 - MIRU PREPARING TO KILL WELL MW: 0.0 SW SUPV:D. GLADDEN / T. BRASSFIELD Move rig from 3A pad to 2T-220. Accept rig ~ 1930 hrs. 7/1/99. UPCOMING OPERATIONS:PULL COMPLETION KILLING WELL MW: 8.5 SW SUPV:D. GLADDEN / T. BRASSFIELD RU kill manifold. PJSM. Mix LCM pill for well kill. Pump LCM pill. UPCOMING OPERATIONS:N/D TREE - N/U BOPS - TEST BOPE'S POOH WITH ESP COMPLETION MW: 8.5 SW SUPV:D. GLADDEN / T. BRASSFIELD Pump LCM pill.Pump FSW into casing. Test BOPE's to 300/3000 psi. Pull tubing hanger to floor. UPCOMING OPERATIONS:CHANGE OUT ESP ASSEMBLY AND RIH RIH WITH GLOBE BASKET TO MW: 8.5 SW SUPV:D. GLADDEN / T. BRASSFIELD Bullhead 10 bbls down tubing at 50 psi, no pressure increase. Pump 17 bbls LCM pill and displace with 68 bbls FSW. Monitor well, no losses. PJSM. POH with ESP completion. RIH w/slickline w/GR/junk basket. UPCOMING OPERATIONS:RIH WITH ESP COMPLETION FISHING-26 BANDS AND 2 FL MW: 8.5 SW SUPV:D. GLADDEN / T. BRASSFIELD Make run with GR/JB to top of gravel pack packer at 4845' RIH with fishing tool assembly on 3.5" & 4.5" tubing. Tag top of packer at 4851'. POOH. RIH with braided line unit making several runs to recover downhole junk. UPCOMING OPERATIONS:RUN ESP COMPLETION Date: 8/6/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/06/99 (C7) TD: 5545' PB: 5545' 07/07/99 (C8) TD: 5545' PB: 5545' 07/08/99 (C9) TD: 5545' PB: 5545' RUNNING IN HOLE WITH TUBI MW: 8.5 SW SUPV:D. WESTER / S. GOLDBERG Continue making braided line runs with varying success. Running three prong grab or magnet. Safety meeting. Running in hole slowly with Centrilift tandem motor assembly. Attempted to work through without success. Found ice in clamps. Run back in hole and tag up. Begin to circulate to warm the well. Able to proceed in hole. UPCOMING OPERATIONS:CONTINUE RIINNING IN HOLE. LAND TUBING AND FREEZE PROTECT WELL EQUALIZING FREEZE PROTECT MW: 8.5 SW SUPV:D. WESTER / S. GOLDBERG Continue circulating to warm well. Run ESP assembly. Had BEAR safety assessment. N/D BOPs. UPCOMING OPERATIONS:PULL BPV AND RDMO CENTERING RIG OVER 1G-17 MW: 0.0 SUPV:D. WESTER / S. GOLDBERG N/D BOPE. N/U tree and test to 5000 psi. Freeze protect well. RDMO. Release rig ~ 1100 hrs. 7/8/99. UPCOMING OPERATIONS:N/U DIVERTER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 11Typ; Of i~qu~i Abandon _ Suspend _ Operational shutdown __ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other X Change approved program _ Pull tubing _ Variance _ Perforate _ Change-out ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 31 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 792' FSL, 556' FWL, Sec. 1, T11 N, R8E, UM 2T-220 At top of productive interval 9. Permit number / approval number 1078' FNL, 826' FWL, SEC 1, T11 N, R8E, UM 98-253 At effective depth 10. APl number 50-103-20283 At total depth 11. Field / Pool 517' FNL, 953' FWL, SEC 1, T11N, RSE, UM Kuparuk River Field/Tabasco Oil Po( 12. Present well condition summer Total depth: measured 5752 feet Plugs (measured) true vertical 3509 feet Effective depth: measured 5527 feet Junk (measured) true vertical 3355 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 81' 16" 9 cu yds High Early 112' 112' Surface 4959' 9.625" 447 sx AS III L, 950 sx Class G 4990' 3047' 60 sx AS I Production 31' 4" gravel pack screen 4887' 2995' Liner 630' 4" gravel pack screen 5517' 3348' ?,ECEi¥ED Perforation depth: measured 4961 '-5517' MD true vertical 3032'-3348' TVD ,¢~as~(a 0ii & GaS Cor~8, C0mBissiory-,~ Tubing (size, grade, and measured depth 4.5" x3.5",12.6#/9.3#,1-80 @ 4575'/4677'/~i'lc"Ora{JO U~/~//~/~L Packers & SSSV (type & measured depth) 45S2' GP packer, No SSSV 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch ___X 14. Estimated date for commencing operation 15. Status of well classification as: June 28, 1999 16. If proposal was verbally approved Oil __X Gas__ Suspended __ Name of approver Date approved Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Questions? Call Tom Brockway 265-4135 Signed '*~")~~O/~~'~ Title: Drilling Team Leader Date Paul Mazzolini Prepared b~' Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test __¢/ Location clearance --I Mechanical Integrity Test__ Subsequent form required lo- ORIGINAL SIGNED BY / Approved by order of the Commission Robcrt N. Chr!stenson ........... Commissioner_ ..... Date_____~_ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE TABASCO 2T-220 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. Confirm that plug has been removed from I-tube landing nipple. 2. Set BPV in tubing and install VR plug in annulus valve. 3. Remove flow lines, well house and scaffolding as required. 4. Detach all power and instrumentation lines from wellhead penetrators and spool back. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. (expected kill wt = 7.4 PPg) 2. Circulate well with sea water and pump LCM pill. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE to 3000 psi. Record results. Test casing to 3000 psi. Record results. 4. Pull BPV. Screw in landing joint. POOH w/4-1/2" tubing and ESP Y-block completion. Stand back tubing in derrick. Spool up cable and heat trace for re-use. 5. Lay down failed ESP. Pick up ESP motor, seal assembly, Y-block, and 2-7/8" tubing I-tube on 4-1/2" 12.6# L-80 BTCM production tubing as per schematic. 6. RIH with ESP motor assembly with power cable and data gathering information wire attached to tubing as per schematic. 7. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 8. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. 9. Make surface electrical connections as required. 10. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 11. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to production. Lower Limit: 4.9 days Expected Case: 6.5 days Upper Limit: 8.1 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running new completion 2T-220 WO TAB, 06/23/99, vl -'Proposed Tabasco 2T-220 (C) Producer Workover Completion 16" Conductor @ 80' Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (2015' MD / 1724' TVD) 4-1/2" Nova Clamps AII Depths RKB Nordic Rig 3~ 3-1/2" Nova Clamps ESP power cable splice above Y-block B. 3-1/2" x 20' 9.3# L-80 EUE8RD Pup joint A. Centrifilt Series 562 ESP assembly w/power cable, 5.62" OD Super-Bands to top of Y-block +/- 3' intervals 9-5/8" Surface Casing 40.0# L-80 BTCM (4990' MD / 3047' TVD) Open Hole Gravel Pack (5517' MD / 3348' TVD) i N. FMC Tabasco Producer horizontal wellhead/hanger system w/125 amp penetrators M. Heat Trace, Raychem, 3000' L. 4-1/2" 12.6# L-80 BTCM tubing to surface K. XO sub, L-80 4-1/2" BTCM box x 3-1/2" BTCM Special Clearance pin J. 3 jts, 3-1/2" 9.3# L-80 BTCM tubing 3.865" Special Clearance couplings I. Baker 'Sentry' gauge, 3-1/2", w/I-wire, Clamp-on style H. 3-1/2" x 4' Landing pup, 9.3#, L-80, BTCM 3.865" Special Clearance couplings G. 3-1/2" Trico Y-Block w/couplings, 3-1/2" EUE8RD pin on motor leg, 2-7/8" EUE8RD pin on I-tube leg, 3-1/2" BTCM Special Clearance box on uphole end F. 2-7/8" Trico 'X' landing nipple w/2.312" profile, EUE8RD box x Hydrill 511pin E. 3-11/16" x 2' L-80 'Swivel Sub', 2.875" ID Hydrill 511 D. 3 jts, 2-7/8" 6.5# L-80 Hydrill 511 flush jt tubing ((drift)*0.184" planned clearance as per Centrilift (ESP OD) - (I tube OD) = 8.679" - 5.62" - 2.875~,~J C. 2-7/8" Wireline Entry Guide, Hydrill 511 Baker SC-1 Gravel Pack packer, 8.44" OD, 4.75" ID (4852' MD / 2977' TVD) Baker Model 'B' KOIV, 5" OD, 2.88" ID (4885' MD / 2994' TVD) 2 jts, Baker 4" blank tubing 11.6#, Hunting Seal Lock threads 4" OD, 3.428" ID Baker 4" Gravel Pack screen, Hunting Seal Lock 20 gauge (0.02") screen, 4.63" OD, 3.428" ID (4961' MD / 3032' TVD) to (5517' MD / 3357' TVD) TAB, 6/23/99, vl 11" 56. psi BOP Stack-- No, ic Rig 3 Kuparuk River Unit Tabasco Operations - Producer Wells ¼ J Kill Line L Choke Line 4 ~ 1 Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic 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 the 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 stack and manifold with water. 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, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v. 1 0 F:! I I--I-- I N CS S ~ ICt ~/I I" ~c: To: State of Alaska Alaska Oil and Gas Conservation COmm. Atm.: Loft Taylor 3001 Porcupine Dn Anchorage, Alaska 99501 June 1, 1999 RE: MWD Formation Evaluation Logs 2T-220, AK-MM-90055 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2T-220: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20283-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20283-00 t Bkteline 1 Folded Sepia 1 Blueline JUN 1999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company .: C] F! I I_/I IM CS S E FI~JI i-- i~ S ~rELL LOG TRANSMITFAL To: State of Alaslqa May 27, .1999 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2T-220, AK-MM-90055 1 LDWG formatted Disc with verification listing. API#: 50-103-20283-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATFACHEDCOPY OF THE TRANSMITFAL LETTER TO THE A'ITENTION OF: Sperry-Sun Drilling Service Atto: Yurt Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date'.o,!Zy ?_ 7 !999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ~ STATE OF ALASKA "----~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas [] Suspended [] Abandoned [] Service [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 98-253 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20283 4. Location of well at surface . ............ ~ 9. Unit or Lease Name 792' FSL, 556' FWL, Sec. 1, T11 N, R8E, UM Kuparuk River Unit At Top Producing Interval _~./~.j~_~=; 10. Well Number 1078' FNL, 826' FWL, SEC 1, TllN, R8E, UM ~ 2%220 At Total Depth ~'. _;]~._~i~} 517' FNL, 953' FWL, SEC 1, T11N, R8E, UM .... . , . ..,,.. .... ~---~** ..~ 11. Field and Pool .... - Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 31 feetI ADL 25569 ALK 2667 Tabasco Oil Pool (proposed) 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions January 1, 1999 March 4, 1999 March 13, 1999I N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSVset 21. Thickness of Permafrost 5752' MD/3509'TVD 5527' MD/3355'TVD YES [] No []I N/A feetMD 1640' (approx) 22. Type Electric or Other Logs Run GR/Res/Density, HALS/Den/CNL/GR/MCFL, Dipole Sonic 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 28' 112' 24" 9 cu yds High Early 9.625" 40# L-80 28' 4990' 12.25" 447 sx AS III L, 95O sx Class G, 6O sx AS I 4" 32# L-80 4856' 4887' 8.5" gravel pack screen 4" 11.6# L-80 4887' 5517' 8.5" gravel pack screen 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) 4.5"x 3.5" 4575'/4677' 4852' GP packer 4961'-5517' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. gravel pack DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 8, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO ! 4/11/1999 11.0 Test Period > 586 64 83 1761 159 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY - APl (corr) Press. 355 psi 0 24-Hour Rate > 1190 189 176 0 28. CORE DATA _ Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. . * This 10-407 is submitted as directed per the 10-401 form approved (Permit ¢98-253) 0 R I GI NA L Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. Top Tabasco Base Tabasco NAME -.. GEOLOGIC MARKERS MEAS. DEPTH 5019' 5641' TRUE VERT. DEPTH 3060' 3431' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOFI, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I hereby certify lhat the following is true and correct to the best of my knowledge. Signed Paul Mazzo~ Title Drilling Team Leader Date '~"/2 ~,/~,~ INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 4/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2T-220 WELL_ID: AK9717 TYPE: AFC: AK9717 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:01/01/99 START COMP:03/06/99 RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20283-00 12/31/98 (D1) TD: 117'(117) SUPV: 01/01/99 (D2) TD: 442' (325) SUPV:DONALD LUTRICK 01/02/99 (D3) TD: 2200' (1758) SUPV:DONALD LUTRICK 01/03/99 (D4) TD: 4061' (1861) SUPV:DONALD LUTRICK 01/04/99 (D5) TD: 4772' (711) SUPV:DONALD LUTRICK MW: 0.0 VISC: MIX SPUD MUD 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig from 2T-215 to 2T-220. DRLG MW: 8.8 VISC: 220 PV/YP: 38/42 APIWL: 7.8 Make repairs to pipe shoot. RU diverter and test. Drilling from 117' to 442' MW: 9.5 VISC: 165 PV/YP: 34/38 DRILLING APIWL: 7.0 Drilling from 442' to 2200' Wash and ream from 910' to 990' MW: 9.5 VISC: 170 PV/YP: 35/40 DRLG AT 4350' APIWL: 6.4 Ream dog legs from 1530' to 1620' Take check shots at 1566' and 1598' Ream from 1620' to 1700' Ream to 1717' Starting taking weight. Slow pump. Work through bridge to 1789' Check shot. Lost 4 deg angle. Tie into survey pt at 1695' Drilling from 1789' to 4061' MW: 9.5 VISC: 120 PV/YP: 26/43 JAR ON FISH APIWL: 6.6 Control drill for logs from 4061' to 4772' Battery in MWD failed. POH wet. Hole swabbing at 1800' Ream to 1904' Packed off. Attempt to work pipe. Pipe backed off due to back lash in torque. Attempt to screw into pipe with no success. POH. Check all breaks. Pipe backed off 12 its into HWDP. Date: 4/14/99 01/05/99 (D6) TD: 4772'( 0) SUPV:FRED HERBERT 01/06/99 (D7) TD: 4772'( 0) SUPV:FRED HERBERT 01/07/99 (D8) TD: 4772'( 0) SUPV:FRED HERBERT 01/08/99 (D9) TD: 0'( 0) SUPV:FRED HERBERT 01/09/99 (D10) TD: 1080' (1080) SUPV:FRED HERBERT 01/10/99 (Dll) TD: 3200' (2120) SUPV:FRED HERBERT 01/11/99 (D12) TD: 4548'(1348) SUPV:FRED HERBERT ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT MW: 9.6 VISC: 110 PV/YP: 24/34 APIWL: 6.2 RIH W/ FISHING ASSY. #2 RIH with fishing assembly. Tag TOF @ 1104'. Engage fish & jar on fish with no success. Attempt to break 1st tool joint above rotary table to rig up SWS & side entry sub- would not break. Torque pipe w/rotary & fire shot. Did not break. MW: 9.6 VISC: 160 PV/YP: 23/49 APIWL: 6.5 POOH W/ FISHING ASSY. g4 RIH w/fishing assembly #2. Attempt to screw in to fish. POOH. RIH w/fishing assembly #3, wash down to TOF. Attempt to screw into fish w/no success. POH. RIH w/fishing assy #4. MW: 9.6 VISC: 66 PV/YP: 18/20 APIWL: 2.0 CIRC & COND FOR CEMENT JOB RIH w/fishing assembly #4, space out for fishing and install jar block on top drive. Attempt to screw into fish. Wash out around top of fish. POOH. P/U assy #5. Snapped pin on XO in top of acc. jars. RIH. Wash thru bridge @ 900' Space out and install jarring block. Attempt to catch fish w/wall hook. POOH. MW: 9.4 VISC: 48 PV/YP: 14/15 APIWL: 9.2 P/U DRILL PIPE Pump cement. Circ out contaminated mud. Wash down to 1478' and tag cement @ 1478'. Pump more cement. MW: 9.5 VISC: 135 PV/YP: 30/37 APIWL: 4.2 DRILLING AHEAD @ 1532' Dress cement plug from 951' to 960', circ out contaminated mud. Drill cement from 960' to 1062' Sidetracked off of plug to the low side while polishing it off. Drilling 12.25" hole from 1062' to 1080' MW: 9.5 VISC: 185 PV/YP: 27/60 APIWL: 6.2 RIH AFTER SHORT TRIP TO 900' Drilling 12.25" hole f/1080' to 3200' MW: 9.5 VISC: 190 PV/YP: 24/53 APIWL: 6.4 CIRC, FAX LOGS TO GEOLOGIST, DEPTH 4925' Drilling 12.25" hole from 3200' to 3200' Pump slug. POOH to 951', tight @ 2608', swabbing slightly. Drilling 12.25" hole from 3245' to 4548' Control drill from 4103' Date: 4/14/99 01/12/99 (D13) TD: 4994'(446) SUPV:FRED HERBERT 01/13/99 (D14) TD: 4994'( 0) SUPV:FRED HERBERT 01/14/99 (D15) TD: 4994'( 0) SUPV:FRED HERBERT 01/15/99 (D16) TD: 4994'( 0) SUPV:TOMMY THOMPSON 01/16/99 (D17) TD: 4994' ( 0) SUPV:TOMMY THOMPSON 01/17/99 (D18) TD: 4994'( 0) SUPV:TOMMY THOMPSON 01/18/99 (D19) TD: 4994' ( 0) SUPV:TOMMY THOMPSON ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 MW: 9.5 VISC: 210 PV/YP: 31/44 POOH W/ HOLE OPENER APIWL: 6.5 Drilling 12.25" hole from 4548' to 4994' POOH, tight 4334' Backream from 4350' to 4100' POOH tight and swabbing slightly f/2677' to 1100'. RIH w/hole opener. Bridge @ 4862' Wash & ream thru bridge. MW: 9.7 VISC: 49 PV/YP: 18/16 RIG DOWN CASING EQUIPMENT APIWL: 7.0 Wash to bottom from 4862' to 4994' Pump pill. Run 9-5/8" casing. MW: 9.7 VISC: 46 PV/YP: 17/16 WOC. WASH SURFACE EQUIPMENT APIWL: 7.0 Pump cement. Pressure up to open stage tool. Pumping by plug w/2700 psi. Bleed off pressure & try again, still pumping by plug. Drop opening cone. wait 30 minutes for cone to fall. Pressure up still pumping past plug. Cone not on seat. Attempt one more time w/no success. Rig down casing equipment. Lay down landing joint ( threads bad). RIH w/stinger and push opening cone to seat. POH w/stinger. Attempt to make up in hanger w/no success. Lay down landing joint. Threads galled. MW: 9.7 VISC: 60 PV/YP: 22/15 TIH SET PKR & PRESSURE TEST STAGE TOOL APIWL: 7.0 Circ and condition for cement job. Pump cement. Check for flowback. TIH pushing closing plug to stage tool. MW: 9.6 VISC: 38 PV/YP: 15/ 9 APIWL: 9.0 CIRC & COND FOR 3000 PSI CASING TEST @ TOP OF INSERT BAFFLE TOH, remove float, TIH. Set storm packer, pressure test. ND diverter and NU BOPE and pressure test to 250/2000 psi. Retrieve storm packer. Drill out DVT. TOH LDDP MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Complete drill out of stage tool. Pressure test BOPE to 250/2000 psi. Tag cement @ 4834' Drill out cement to baffle. Perform FIT to 16 ppg EMW. Set bridge plug @ 4819' MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED FROM 2T-220 @ 1800 HRS APIWL: 0.0 Freeze protect well w/diesel. N/D BOPE. N/U tree and test to 5000 psi. Rig released @ 1800 hrs. 1/18/99. Date: 4/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 02/28/99 (D20) MW: 9.7 VISC: 55 PV/YP: 10/16 APIWL: 0.0 TD: 0' ( 0) FINISH TESTING BOPS SUPV:DEARL W. GLADDEN Move rig and spot over 2T-220. Accept rig ~ 1000 hrs. 1/28/99. N/D tree. N/U BOP and test. 03/01/99 (D21) MW: 9.7 VISC: 48 PV/YP: 10/14 APIWL: 12.6 TD: 0' ( 0) Drilling out 9-5/8" SUPV:DEARL W. GLADDEN Trouble w/test plug, will not seal, change seals. Test BOP to 250/3000 psi. Clean out mud cement from 4814' to 4816' 03/02/99 (D22) MW: 9.7 VISC: 48 PV/YP: 12/22 APIWL: 5.4 TD: 5134' (5134) DRILLING @ 5340' ANGLE DROPING AND TURNING RIGHT. CIRCULATIN SUPV:DONALD L. WESTER Continue to clean out cement from 9-5/8" from 4815' to 4984'. Clean out open hole to 4994' Drill 8.5" hole from 4994' to 5014' - 20' new hole. LOT test formation to break down 5014', EMW 13.4 ppg. Drill from 5014' to 5134' 03/03/99 (D23) MW: 9.7 VISC: 46 PV/YP: 13/22 APIWL: 5.0 TD: 5675'( 541) CONTIUNE DRILLING 8.5" HOLE @ 5740' ANGLE CONTINUE TO DROP SUPV:DONALD L. WESTER Continue drilling 8.5" hole from 5134' to 5339' Angle dropping unable to hold angle up. Circulate gas cut mud. Drilling 8.5" hole from 5339' to 5550' Permit depth. Call State for approval of up to 300' past permit to 5850' Verbal approval from AOGCC per Blair Wondzell. Continue drilling 8.5" hole from 5550' to 5675' 03/04/99 (D24) MW: 9.7 VISC: 48 PV/YP: 12/24 APIWL: 3.5 TD: 5752'( 77) CHANGE PIPE RAMS TO 3.5" SUPV:DONALD L. WESTER Continue drilling 8.5" hole from 5675' to 5751' RIH w/logging tools. UPCOMING OPERATIONS:RIH W/ 3.5" MULE SHOE & CASING SCRAPER ASSY 2400' & 4900' 03/05/99 (D25) MW: 9.7 VISC: 47 PV/YP: 10/20 APIWL: 4.0 TD: 5708'( 0) PUMPED 40 BBL LCM PILL. PULL TO SHOE. CIRC CUT MUD WEIGHT F/ SUPV:DONALD L. WESTER Continue running Schlumberger e-logs. Pump 5650# sand. Rig displaced to bottom. Pull back into 9-5/8" casing shoe @ 4990' Let sand settle to bottom to cover from 5708' up to 5580' PBTD. RIH to 5708' no returns. Tagged fill no sand. Pull back to 5771' break circulation pipe not plugged. Circulate long way. UPCOMING OPERATIONS:LAY #2 5600 LB SAND PLUG TO COVER F/ 5708' TO 5585' 128' Date: 4/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 REMEDIAL AND COMPLETION OPERATIONS WELL:2T-220 RIG:NORDIC 3 WELL_ID: AK9717 TYPE: AFC: AK9717 AFC EST/UL:$ 909M/ 1000M STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:01/01/99 START COMP:03/06/99 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20283-00 03/06/99 (C26) TD: 5752' PB: 5708' 03/07/99 (C27 TD: 5752' PB: 5669' 03/08/99 TD: 5752' PB: 5537' C28 03/09/99 TD: 5752' PB: 5529' C29 03/10/99 TD: 5752' PB: 5529' C30) POOH P/U 8.5" OPEN PACKER MW: 0.0 SUPV:DONALD L. WESTER Pump calcium carbonate pill and spot across open hole from 5571' to 4990' Circulate and cut mud weight from 9.7 to 9.5 ppg. Pump sand plug %2. Tag sand @ 5704'. Cut mud weight to 9.4 ppg. Pump sand plug ~3. Displace sand to end of DP. Tag @ 5669' UPCOMING OPERATIONS:RUN OPEN HOLE PACKER SET @ 5580' +- CIRCULATE & ROTATE F/ 9-5 MW: 0.0 SUPV:DONALD L. WESTER RIH slowly w/Baker ECP packer on 3.5" DP to 5115'. Try to circulate and work past 5115'. No go. UPCOMING OPERATIONS:C/O HOLE COMPLETE CHANGE OVER TO C MW: 0.0 SUPV:DONALD L. WESTER Rotate down through open hole. Saw ledges @ 5125' to 5135' Continue to circulate rotate and reciprocate from 5390'-5483'. Fine formation sand coming over shakers. Pump and spot Zan-Vis pill in open hole. UPCOMING OPERATIONS:PUMP THE 25 BBLS CAUSTIC AHEAD OF HOG WASH. PICKLE DRILL PIPE. POOH RUN BAKER SCREENS. P/U BAKER GRAVEL PACK ASS MW: 0.0 SUPV:DEARL W. GLADDEN Pump and displace caustic wash. Pump NaC1 and surfactant. Pump acid pickle fluid. UPCOMING OPERATIONS:TIH W/BAKER GRAVEL PACK ASSY - TAG BTTM W/ASSY & COND. COMPLETION FLUID -SPOT FROMIC ACID PILL ACROSS OPEN HOLE TOH W/ BAKER PACKER SETTI MW: 0.0 SUPV:DEARL W. GLADDEN RUN AND SET GRAVEL PACK ASSEMBLY, SET PACKER AND PERFORM GRAVEL PACK, REVERSE CIRCULATE UPCOMING OPERATIONS:P/U 144 JTS 4 1/2" TBG AND TIH - TOH & STANDBACK TBG IN DERRICK- P/U & TIHW/ "Y" BLOCK ASSY & ESP PUMP Date: 4/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 6 03/11/99 (C31) TD: 5752' PB: 5529' 03/12/99 (C32) TD: 5752' PB: 5529' 03/13/99 (C33) TD: 5752' PB: 5529' 03/14/99 (C34) TD: 5752' PB: 5529' P/U 4 1/2 TBG. - STANDBAC MW: 0.0 SUPV:DEARL W. GLADDEN Pull tail pipe above upper flapper in gravel pack assy ~ 4885', check fluid loss. Pump Flo Vis pill. Monitor fluid loss. Pump Flo Vis pill #2 and #3. Pump calcium carbonate. Monitor fluid loss. UPCOMING OPERATIONS:STANDBACK 4 1/2 TBG - RUN COMPLETION SRING 4 1/2" TBG W/ ESP RUNNING ESP COMPLETION ST MW: 0.0 SUPV:DEARL W. GLADDEN POOH WITH BAKER GRAVEL PACK TOOLS, CHANGE RAMS TO 4.5", TEST BOPE RAMS AND DOORS, RIH PICKING UP 4.5" TUBING, POOH STANDING BACK TUBING IN DERRICK, PICK UP ESP PUMP AND MOTOR. UPCOMING OPERATIONS:FINISH RUNNING COMPLETION STRING - SPACE OUT FOR CABLE CONN. - MAKE CONN. TO PENETRATORS - LAND HANGER TEST TREE MW: 9.4 KCL SUPV:DEARL W. GLADDEN PU ESP, Y BLOCK AND COMPLETION ASSEMBLY, RIH SLOW WITH ESP CABLE, HEAT TRACE. SPACE OUT AND MAKE UP TUBING HANGER AND PENETRATORS. UPCOMING OPERATIONS:FINISH TREE TEST - FREEZE PROTECT - SET BPV - MOVE OFF WELL TO 2T-215 RIG RELEASED OFF 2T-220 @ MW: 0.0 AIR SUPV:DEARL W. GLADDEN SPLICE AND LAND ESP CABLES AND HEAT TRACE IN TUBING HANGER, LAND TUBING, NIPPLE DOWN BOPE, NIPPLE UP TREE, AND TEST SAME, FREEZE PROTECT WELL, AND RELEASE RIG TO MOVE. UPCOMING OPERATIONS:MOVE RIG TO 2T-215 -N/U BOP - TEST BOPS Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2T, Slot 2T-220 2T-220 Job No. AKMM90055, Surveyed: 4 March, 1999 SURVEY REPORT 15 March, 1999 ORIGINAL RECEIVED 1999 AImJm O~ & Gas Cons. Commimion Andlorage Your Reft AP1-501032028300 Surface Coordinates: 5970772.57 N, 498944.90 E (70° 19' 52.9661" N, 150° 00' 30.8095" W) Kelly Bushing: 110.92ft above Mean Sea Level o R, I L L~ I N I~ s I~ R V I cc I~, E~ Survey Ref: svy8389 Sperry-Sun Drilling Services Survey Report for 2T-220 Your Ref: API-501032028300 Job No. AKMM90055, Surveyed: 4 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Global Coordinates Northings Eastings Northlngs Eastings (ft) (ft) (ft) (ft) Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°llOOfl) Vertical Section (ft). Comment 2T-220 PB1 0.o0 0.000 0.000 -110.92 0.00 11o.51 0.000 0.000 -0.41 110.51 186.03 0.530 204.960 75.11 186.03 248.53 0.910 271.770 137.60 248.52 277.80 1.620 294.870 166.87 277.79 340.92 3.290 304.660 229.93 340.85 369.94 3.960 305.530 258.89 369.81 400.49 4.790 305.070 289.35 400.27 430.09 5.840 305.260 318.82 429.74 459.52 7.110 305.300 348.06 458.98 489.90 8.490 304.670 378.16 489.08 520.10 9.570 306.800 407.99 518.91 549.26 10.21o 308.240 436.71 547.63 579.20 10.870 311.630 466.15 577.07 609.07 11.570 315.630 495.45 606.37 637.72 12.590 317.400 523.46 634.38 668.65 14.280 319.390 553.55 664.47 698.45 16.220 319.590 582.30 693.22 726.93 17.360 321.490 609.56 720.48 757.97 17.600 323.870 639.17 750.09 787.49 18.150 326.160 667.26 778.18 816.03 19.300 328.620 694.29 805.21 846.39 20.800 331.310 722.81 833.73 0.00 N 0.00 E 5970772.57 N 498944.90 E 0.00 N 0.00 E 5970772.57 N 498944.90 E 0.32 $ 0.15W 5970772.25 N 498944.75 E 0.56 S 0.77W 5970772.01N 498944.13 E 0.38 S 1.37W 5970772.19 N 498943.53 E 1.02 N 3.67W 5970773.59 N 498941.23 E 2.08 N 5.17W 5970774.65 N 498939.73 E 3.43 N 7.08W 5970776.00 N 498937.82 E 5.00 N 9.32W 5970777.58 N 498935.58 E 6.92 N 12.03W 5970779.49 N 498932.88 E 9.28 N 15.40W 5970781.86 N 498929.50 E 12.06 N 19.25W 5970784.63 N 498925.65 E 15.11 N 23.22W 5970787.68 N 498921.68 E 18.63 N 27.41W 5970791.20 N 498917.49 E 22.64 N 31.61W 5970795.21N 498913.29 E 26.99 N 35.74W 5970799.57 N 498909.17 E 32.37 N 40.50W 5970804.94 N 498904.40 E 38.33 N 45.59W 5970810.90 N 498899.31 E 44.68 N 50.82W 5970817.26 N 498894.09 E 52.09 N 56.47W 5970824.67 N 498888.44E 59.52 N 61.66W 5970832.10 N 498883.25 E 67.24 N 66.59W 5970839.82 N 498878.32 E 76.25 N 71.79W 5970848.83 N 498873.12 E 0.000 0.702 1.366 2.940 2.718 2.316 2.719 3.548 4.315 4.551 3.743 2.353 3.024 3.503 3.787 5.664 6.512 4.442 2.429 3.023 4.887 5.799 0.00 0.00 -0.33 -0.64 -0.53 0.61 1.49 2.62 3.94 5.55 7.52 9.85 12.44 15.47 19.00 22.87 27.68 33.04 38.78 45.52 52.32 59.45 67.83 Continued.,. 15 March, 1999 - 11:45 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-220 Your Ref: API-501032028300 Job No. AKMM90055, Surveyed: 4 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°/100ft) Vertical Section (ft) Comment 2T-220 D- 19 852.88 20.814 331.639 728.88 839.80 905.14 20.950 334.270 777.71 888.63 996.49 20.590 333.840 863.12 974.04 1026.94 20.260 334.040 891.66 1002.58 1057.07 20.810 337.540 919.87 1030.79 1086.20 21.500 337.480 947.04 1057.96 1118.00 22.250 339.320 976.55 1087.47 1149.54 22.920 341.160 1005.67 1116.59 1181.11 23.520 342.150 1034.68 1145.60 1212.86 25.160 343.480 1063.61 1174.53 1244.69 27.270 344.350 1092.17 1203.09 1279.33 29.600 344.790 1122.63 1233.55 1308.77 31.070 345.700 1148.03 1258.95 1340.55 32.650 346.350 1175.03 1285.95 1370.68 33.910 347.190 1200.21 1311.13 1403.57 35.890 348.240 1227.19 1338.11 1435.34 37.250 349.090 1252.70 1363.62 1464.87 38.940 349.650 1275.94 1386.86 1497.68 40.370 350.720 1301.20 1412.12 1529.48 41.580 351.150 1325.21 1436.13 1560.12 43.720 352.510 1347.74 1458.66 1592.36 45.840 353.300 1370.63 1481.55 1624.03 47.840 354.040 1392.29 1503.21 1655.89 50.390 355.320 1413.14 1524.06 1687.33 52.850 356.960 1432.66 1543.58 78.28 N 72.89W 5970850.86 N 498872.02 E 94.86 N 81.36W 5970867.44 N 498863.55 E 123.99 N 95.53W 5970896.58 N 498849.39 E 133.54 N 100.20W 5970906.12 N 498844.72 E 143.18 N 104.53W 5970915.76 N 498840.39 E 152.89 N 108.55W 5970925.47 N 498836.37 E 163.91N 112.91W 5970936.49 N 498832.02 E 175.30 N 117.00W 5970947.89 N 498827.93 E 187.12 N 120.92W 5970959.71N 498824.01E 199.62 N 124.78W 5970972.21N 498820.15 E 213.13 N 128.67W 5970985.72 N 498816.26 E 229.03 N 133.05W 5971001.62 N 498811.88 E 243.41 N 136.84W 5971016.00 N 498808.10 E 259.69 N 140.89W 5971032.28 N 498804.05 E 275.78 N 144.67W 5971048.37 N 498800.27 E 294.17 N 148.67W 5971066.76 N 498796.27 E 312.73 N 152.39W 5971085.32 N 498792.56 E 330.63 N 155.75W 5971103.22 N 498789.20 E 351.26 N 159.31W 5971123.86 N 498785.64 E 371.85 N 162.60W 5971144.45 N 498782.36 E 392.40 N 165.54W 5971164.99 N 498779.41E 414.94 N 168.34W 5971187.53 N 498776.62 E 437.90 N 170.89W 5971210.49 N 498774.07 E 461.88 N 173.12W 5971234.47 N 498771.85 E 486.46 N 174.77W 5971259.06 N 498770.20 E 1.813 1.813 0.428 1.108 4.464 2.370 3.195 3.087 2.267 5.446 6.738 6.753 5.231 5.087 4.453 6.291 4.568 5.841 4.830 3.907 7.604 6.798 6.541 8.560 8.828 69.72 85.27 112.65 121.62 130.72 139.92 150.39 161.26 172.57 184.57 197.57 212.88 226.75 242.48 258.06 275.89 293.92 311.34 331.45 351.55 371.65 393.73 416.27 439.86 464.11 Tie-on Survey Continued... 15 March, 1999 - 11:45 - 3- DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-220 Your Ref: API-501032028300 Job No. AKMM90055, Surveyed: 4 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1719.03 53.410 357.280 1451.68 1562.60 1750.10 53.970 358.130 1470.08 1581.00 1782.58 55.280 358.900 1488.88 1599.80 1814.59 56.450 359.640 1506.85 1617.77 1846.16 57.320 0.800 1524.09 1635.01 1878.29 58.530 1.740 1541.16 1652.08 1910.31 59.370 2.570 1557.67 1668.59 1941.00 59.810 3.460 1573.21 1684.13 1973.61 60.100 4.280 1589.53 1700.45 2005.40 60.850 4.690 1605.20 1716.12 2035.93 62.030 6.250 1619.80 1730.72 2069.04 63.760 6.950 1634.88 1745.80 2100.75 64.960 7.870 1648.60 1759.52 2131.74 66.120 8.880 1661.43 1772.35 2196.18 65.740 9.580 1687.72 1798.64 2259.57 66.210 9.840 1713.53 1824.45 2322.90 65.970 9.850 1739.19 1850.11 2386.84 63.780 10.480 1766.34 1877.26 2450.29 63.070 10.930 1794.73 1905.65 2513.22 62.270 11.370 1823.62 1934.54 2577.60 63.540 11.330 1852.94 1963.86 2640.83 63.350 11.020 1881.21 1992.13 2702.04 63.370 11.630 1908.65 2019.57 2767.68 63.700 11.850 1937.91 2048.83 2831.29 62.740 12.680 1966.57 2077.49 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 511.79 N 176.04W 5971284.39 N 498768.93 E 536.81 N 177.04W 5971309.40 N 498767.93 E 563.28 N 177.73W 5971335.88 N 498767.25 E 589.77 N 178.07W 5971362.37 N 498766.92 E 616.21 N 177.96W 5971388.81 N 498767.02 E 643.43 N 177.36W 5971416.03 N 498767.63 E 670.84 N 176.32W 5971443.44 N 498768.67 E 697.28 N 174.93W 5971469.87 N 498770.07 E 725.44 N 173.03W 5971498.03 N 498771.98 E 753.02 N 170.86W 5971525.61 N 498774.14 E 779.71 N 168.31W 5971552.30 N 498776.70 E 808.98 N 164.92W 5971581.58 N 498780.10 E 837.33 N 161.23W 5971609.92 N 498783.79 E 865.24 N 157.12W 5971637.83 N 498787.90 E 923.31 N 147.68W 5971695.90 N 498797.35 E 980.38 N 137.92W 5971752.97 N 498807.12 E 1037.42 N 128.02W 5971810.01 N 498817.03 E 1094.40 N 117.80W 5971866.99 N 498827.25 E 1150.16 N 107.26W 5971922.75 N 498837.80 E 1205.01 N 96.45W 5971977.59 N 498848.61 E 1261.20 N 85.18W 5972033.78 N 498859.90 E 1316.69 N 74.21W 5972089.27 N 498870.87 E 1370.34 N 63.47W 5972142.91 N 498881.62 E 1427.87 N 51.51W 5972200.45 N 498893.59 E 1483.36 N 39.45W 5972255.93 N 498905.66 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°/lOOff) (fi) Comment 1.942 489.14 2.848 513.89 4.472 540.13 4.126 566.42 4.131 592.71 4.509 619.83 3.437 647.18 2.883 673.61 2.351 701.81 2.613 729.45 5.923 756.26 5.554 785.74 4.600 814.32 4.776 842.51 1.154 901.27 0.831 959.07 0.379 1016.86 3.539 1074.62 1.286 1131.20 1.415 1186.91 1.973 1244.01 0.532 1300.36 0.891 1354.87 0.585 1413.37 1.906 1469.86 Continued... 15 March, 1999 - 11:45 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-220 Your Ref: AP1-$01032028300 Job No. AKMM9005$, Surveyed: 4 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2894.56 63.190 12.770 1995.32 2106.24 2958.70 66.550 11.990 2022.56 2133.48 3022.12 66.170 12.510 2047.99 2158.91 3085.37 65.750 12.700 2073.76 2184.68 3148.37 65.300 13.210 2099.86 2210.78 3211.50 66.080 11.960 2125.85 2236.77 3271.59 66.020 11.570 2150.24 2261.16 3338.62 65.930 11.870 2177.53 2288.45 3402.06 65.800 12.000 2203.47 2314.39 3463.60 64.990 12.380 2229.09 2340.01 3529.40 64.650 12.840 2257.09 2368.01 3592.42 64.470 12.760 2284.16 2395.08 3653.50 64.620 12.000 2310.41 2421.33 3719.55 65.060 9.620 2338.50 2449.42 3783.28 66.100 6.820 2364.85 2475.77 3843.33 65.830 7.560 2389.31 2500.23 3910.63 65.270 8.090 2417.16 2528.08 3969.88 65.690 6.580 2441.75 2552.67 4037.08 65.440 6.170 2469.55 2580.47 4100.29 64.720 5.850 2496.18 2607.10 4163.90 63.570 6.170 2523.92 2634.84 4216.73 62.750 6.960 2547.78 2658.70 4290.85 62.240 6.050 2582.01 2692.93 4354.37 61.310 5.360 2612.05 2722.97 4417.26 60.420 5.460 2642.67 2753.59 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1538.33 N 27.04W 5972310.90 N 498918.08 E 1595.04 N 14.60W 5972367.61 N 498930.53 E 1651.82 N 2.27W 5972424.39 N 498942.86 E 1708.19 N 10.34 E 5972480.76 N 498955.48 E 1764.07 N 23.19 E 5972536.63 N 498968.34 E 1820.22 N 35.72 E 5972592.78 N 498980.88 E 1873.98 N 46.92 E 5972646.54 N 498992.08 E 1933.93 N 59.36 E 5972706.49 N 499004.53 E 1990.57 N 71.33 E 5972763.13 N 499016.51 E 2045.26 N 83.14 E 5972817.82 N 499028.33 E 2103.37 N 96.14 E 5972875.92 N 499041.34 E 2158.86 N 108.75 E 5972931.42 N 499053.96 E 2212.73 N 120.58 E 5972985.28 N 499065.79 E 2271.45 N 131.78 E 5973044.00 N 499077.00 E 2328.87 N 140.07 E 5973101.42 N 499085.30 E 2383.28 N 146.94 E 5973155.83 N 499092.17 E 2443.98 N 155.28 E 5973216.53 N 499100.52 E 2497.44 N 162.16 E 5973269.99 N 499107.41 E 2558.24 N 168.95 E 5973330.79 N 499114.21 E 2615.25 N 174.95 E 5973387.80 N 499120.22 E 2672.18 N 180.95 E 5973444.73 N 499126.22 E 2719.01N 186.34 E 5973491.55 N 499131.62 E 2784.33 N 193.78 E 5973556.87 N 499139.08 E 2840.02 N 199.35 E 5973612.56 N 499144.65 E 2894.70 N 204.53 E 5973667.24 N 499149.84 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°ll00ff) (ft) Comment 0.722 1525.87 5.353 1583.61 0.961 1641.40 0.718 1698.82 1.026 1755.78 2.187 1812.97 0.601 1867.64 0.430 1928.60 0.277 1986.22 1.431 2041.88 0.817 2101.07 0.308 2157.62 1.150 2212.47 3.329 2272.07 4.320 2330.06 1.212 2384.89 1.098 2446.14 2.425 2500.03 0.669 2561.22 1.228 2618.54 1.864 2675.78 2.047 2722.92 1.288 2788.66 1.749 2844.62 1.422 2899.54 Continued... 15 March, 1999 - 11:46 - 5- DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-220 Your Ref: AP1-$01032028500 Job No, AKMM90055, Surveyed: 4 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 4481.60 59.820 4545.52 59.390 4607.46 58.740 4670.55 59.820 4733.89 59.840 4793.39 59.530 4858.71 59.380 4921,78 59.670 4929.29 59.260 2T-220 5040.77 513o.91 5218.25 5313.98 5411.89 5506.89 5602.22 5692.95 5729.o3 5752.oo 57.890 56.070 55.470 54.12o 52.700 50.490 47.890 44.750 43.460 43.46o Azim. 6.160 6.440 6.720 6.640 6.490 7.350 7.o2o 7.250 7.090 8.500 10.65o 12.99o 12.63o 12.7oo 13.29o 14.9oo 15.83o 16.o3o 16.o3o Sub-Sea Depth (ft) 2674.72 2707.06 2738.90 2771.13 2802.96 2833.00 2866.19 2898.18 2902.00 2960.12 3009.24 3058.38 3113.56 3171.93 3230.94 3293.24 3355.89 3381.80 3398.47 Vertical Depth (ft) 2785.64 2817.98 2849.82 2882.05 2913.88 2943.92 2977.11 3009.10 3012.92 3071.04 3120.16 3169.30 3224.48 3282.85 3341.86 3404.16 3466.81 3492.72 3509.39 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2950,20 N 210.17 E 5973722.74 N 499155.49 E 3005.01N 216.22 E 5973777.54 N 499161.55 E 3057.78 N 222.31 E 5973830.32 N 499167.64 E 3111.65 N 228.62 E 5973884.19 N 499173.96 E 3166.05 N 234.88 E 5973938.59 N 499180.23 E 3217.04 N 241.07 E 5973989.58 N 499186.42 E 3272.86 N 248.11E 5974045.39 N 499193.47 E 3326.79 N 254.86 E 5974099.33 N 499200.23 E 3333.21N 255.66 E 5974105.74 N 499201.03 E 3427.45 N 268.56 E 5974199.99 N 499213.94 E 3501.97 N 281.11 E 5974274.50 N 499226.51 E 3572.65 N 295.90 E 5974345.18 N 499241.30 E 3648.92 N 313.24 E 5974421.44 N 499258.66 E 3725.62 N 330.48 E 5974498.14 N 499275.90 E 3798.15 N 347.21 E 5974570.67 N 499292.65 E 3868.13 N 364.76 E 5974640.65 N 499310.21 E 3931.39 N 382.13 E 5974703.91 N 499327.58 E 3955.54 N 389.02 E 5974728.06 N 499334.48 E 3970.73 N 393.39 E 5974743.24 N 499338.84 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°/100fi) Vertical Section (ft) Comment 1.326 0.772 1.119 1.715 0.207 1.352 0.492 0.557 5.760 2955.33 3OLO.46 3o63.59 3117.83 3172.59 3223.95 3280.20 3334.55 3341.o2 Tie-On Survey 1.636 2.842 2.319 1.443 1.451 2.377 3.012 3.539 3.596 0.000 3436.11 3511.56 3583.44 3661.16 3739.30 3813.24 3884.73 3949.53 3974.29 3989.87 Projected Survey Continued... 15 March, 1999 - 11:46 - 6 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-220 Your Ref: AP1-$01032028300 Job No. AKMM90055, Surveyed: 4 March, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2T All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.963° (15-Mar-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 6.360° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5752.00ft., The Bottom Hole Displacement is 3990.17ft., in the Direction of 5.658° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 852.88 839.80 78.28 N 72.89 W Tie-on Survey 4929.29 3012.92 3333.21 N 255.66 E Tie-On Survey 5752.00 3509.39 3970.73 N 393.39 E Projected Survey 15 March, 1999 - 11:46 - 7- DrlllQuest Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2T, Slot 2T-220 2T-220 Job No. AKMM900$8, Surveyed: 12 January, 1999 SUR VE Y REPORT 18 February, 1999 ORIGINAL Your Ref: API-501032028300 KBE-80.40 Surface Coordinates: 5970772.57 N, 498944.90 E (XOo 19' 52.9661" IV, 150° ~j~r~r~.~Ljr.1 oo, ~o.~o~, w) Survey Ref.. $vy8247 Sperry-Sun Drilling Services Survey Report for 2T-220 Your Ref: AP1-$01032028300 Job No, AKMM900$8, Surveyed: 12 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 852.88 20.800 331.310 759.82 911.63 20.950 334.270 814.72 1002.98 20.590 333.840 900.13 1033.43 20.260 334.040 928.66 1063.56 20.810 337.540 956.88 1092.69 21.500 337.480 984.05 1124.49 22.250 339.320 1013.56 1156.03 22.920 341.160 1042.68 1187.60 23.520 342.150 1071.69 1219.35 25.160 343.480 1100.62 1251.18 27.270 344.350 1129.17 1285.82 29.600 344.790 1159.63 1315.26 31.070 345.700 1185.04 1347.04 32.650 346.350 1212.03 1377.17 33.910 347.190 1237.22 1410.06 35.890 348.240 1264.19 1441.83 37.250 349.090 1289.71 1471.36 38.940 349.650 1312.95 1504.17 40.370 350.720 1338.21 1535.97 41.580 351.150 1362.22 1566.61 43.720 352.510 1384.75 1598.85 45.840 353.300 1407.64 1630.52 47.840 354.040 1429.30 1662.38 50.390 355.320 1450.15 1693.82 52.850 356.960 1469.67 Vertical Depth (ft) 840.22 895.12 980.53 1009.06 1037.28 1064.45 1093.96 1123.08 1152.09 1181.02 1209.57 1240.03 1265.44 1292.43 1317.62 1344.59 1370.11 1393.35 1418.61 1442.62 1465.15 1488.04 1509.70 1530.55 1550.07 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 76.25 N 71.79W 5970848.83 N 498873.12 E 94.86 N 81.36W 5970867.44 N 498863.56 E 123.99 N 95.53W 5970896.58 N 498849.39 E 133.54 N 100.20W 5970906.12 N 498844.72 E 143.18 N 104.53W 5970915.76 N 498840.39 E 152.89 N 108.55W 5970925.47 N 498836.37 E 163.90 N 112.91W 5970936.49 N 498832.02 E 175.30 N 117.00W 5970947.89 N 498827.93 E 187.12 N 120.91W 5970959.71N 498824.01 E 199.62 N 124.78W 5970972.21N 498820.15 E 213.13 N 128.67W 5970985.72 N 498816.26 E 229.03 N 133.05W 5971001.62 N 498811.88 E 243.41 N 136.84W 5971016.00 N 498808.10 E 259.69 N 140.89W 5971032.28 N 498804.05 E 275.78 N 144.67W 5971048.37 N 498800.27 E 294.17 N 148.67W 5971066.76 N 498796.27 E 312.73 N 152.39W 5971085.32 N 498792.56 E 330.63 N 155.74W 5971103.22 N 498789.20 E 351.26 N 159.31W 5971123.85 N 498785.64 E 371.85 N 162.59W 5971144.45 N 498782.36 E 392.40 N 165.54W 5971164.99 N 498779.42 E 414.94 N 168.34W 5971187.53 N 498776.62 E 437.89 N 170.89W 5971210.49 N 498774.08 E 461.88 N 173.11W 5971234.47 N 498771.85 E 486.46 N 174.77W 5971259.06 N 498770.20 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°/100fi) Vertical Section (ft) Comment 1.813 0.428 1.108 4.464 2.37o 3.195 3.087 2.267 5.446 6.738 6.753 5.231 5.087 4.453 6.291 4.568 5.841 4.830 3.907 7.604 6.798 6.541 8.560 8.828 70.48 88.30 116.25 125.41 134.68 144.o5 154.7o 165.75 177.23 189.39 202.56 218.08 232.12 248.04 263.79 281.81 300.03 317.62 337.92 358.20 378.45 400.70 423.40 447.14 471.52 Tie-on Survey Continued... 18 February, 1999 - 9:08 - 2 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-220 'Your Ref: API-501032028300 Job No, AKMM90058, Surveyed: 12 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1725,52 53,410 357.280 1488.69 1569.09 1756,59 53,970 358.130 1507.09 1587.49 1789.07 55.280 358.900 1525.89 1606.29 1821.08 56.450 359.640 1543.85 1624.25 1852,65 57,320 0.800 1561.10 1641.50 1884.78 58.530 1.740 1578.16 1658.56 1916.80 59,370 2.570 1594.68 1675.08 1947.49 59,810 3.460 1610.21 1690.61 1980.10 60.100 4.280 1626.54 1706.94 2011.89 60,850 4.690 1642.21 1722.61 2042,42 62,030 6.250 1656.80 1737.20 2075.53 63,760 6.950 1671.89 1752.29 2107,24 64,960 7.870 1685.61 1766.01 2138.23 66,120 8.880 1698.44 1778.84 2202.67 65.740 9.580 1724.72 1805.12 2266.06 66.210 9.840 1750.53 1830.93 2329.39 65.970 9.850 1776.20 1856.60 2393,33 63,780 10.480 1803.35 1883.75 2456.78 63,070 10.930 1831.73 1912.13 2519,71 62.270 11.370 1860.62 1941.02 2584.09 63.540 11.330 1889.95 1970.35 2647.32 63.350 11.020 1918.21 1998.61 2708.53 63.370 11.630 1945.66 2026.06 2774.17 63,700 11.850 1974.91' 2055.31 2837.78 62.740 12.680 2003.57 2083.97 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 511.79 N 176.04W 536.81 N 177.04W 563.28 N 177.73W 589.77 N 178.06W 616.21 N 177.96W 643.43 N 177.36W 670.84 N 176.32W 697.27 N 174.93W 725.44 N 173.03W 753.01N 170.86W 779.71 N 168.30W 808.98 N 164.92W 837.33 N 161.23W 865.24 N 157.12W 923.31N 147.68W 980.38 N 137.92W 1037.42 N 128.02W 1094.40 N 117.80W 1150.16 N 107.26W 1205.01N 96.45W 1261.20 N 85.17W 1316.69 N 74.21W 1370.34 N 63.47W 1427.87 N 51.51W 1483,36 N 39.45W 5971284.39 N 498768.93 E 5971309.40 N 498767.93 E 5971335.88 N 498767.25 E 5971362.37 N 498766.92 E 5971388.81 N 498767.03 E 5971416.03 N 498767.63 E 5971443.44 N 498768.67 E 5971469.87 N 498770.07 E 5971498.03 N 498771.98 E 5971525.61 N 498774.14 E 5971552.30 N 498776.71E 5971581.58 N 498780.10 E 5971609.92 N 498783.79 E 5971637.83 N 498787.90 E 5971695.90 N 498797.35 E 5971752.97 N 498807.12 E 5971810.01 N 498817.03 E 5971866.99 N 498827.25 E 5971922.74 N 498837.80 E 5971977.59 N 498848.62 E 5972033.78 N 498859.90 E 5972089.27 N 498870.87 E 5972142.91 N 498881.62 E 5972200.44 N 498893.59 E 5972255.93 N 498905.66 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°/lOOft) (ft) Comment 1.942 496.68 2.848 521.54 4.472 547.88 4.126 574.27 4.131 600.64 4.509 627.82 3.437 655.23 2.883 681.69 2.351 709.92 2.613 737.58 5.923 764.39 5.554 793.84 4.600 822.39 4.776 850.53 1.154 909.16 0.831 966.81 0.379 1024.45 3.539 1082.04 1.286 1138.45 1.415 1193.97 1.973 1250.87 0.532 1307.03 0.891 1361.35 0.585 1419.63 1.906 1475.89 Continued... 18 February, 1999 - 9:08 - 3 - DrillQuest jsenoIIH~7 - g, - 80:6 - 666~ '/u;n~qa:l 9~ '"penulJuoo 99' 1.06~ ~i~' I. 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Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4488.09 59.820 6.160 2711.73 2792.13 2950.20 N 210.18 E 5973722.74 N 499155.49 E 4552.01 59.390 6.440 2744.07 2824.47 3005.00 N 216.23 E 5973777.54 N 499161.55 E 4613.95 58.740 6.720 2775.91 2856.31 3057.78 N 222.31 E 5973830.32 N 499167.64 E 4677.04 59.820 6.640 2808.14 2888.54 3111.65 N 228.62 E 5973884.19 N 499173.96 E 4740.38 59.840 6.490 2839.97 2920.37 3166.05 N 234.88 E 5973938.59 N 499180.23 E 4799.88 59.530 7.350 2870.00 2950.40 3217.04 N 241.07 E 5973989.58 N 499186.42 E 4865.20 59.380 7.020 2903.20 2983.60 3272.85 N 248.11 E 5974045.39 N 499193.47 E 4928.27 59.670 7.250 2935.19 3015.59 3326.79 N 254.86 E 5974099.32 N 499200.23 E 4935.78 59.260 7.090 2939.00 3019.40 3333.21 N 255.67 E 5974105.74 N 499201.03 E 4995.00 59.260 7.090 2969.27 3049.67 3383.72 N 261.95 E 5974156.25 N 499207.32 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.984° (16-Feb-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 4.427° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4995.00ft., The Bottom Hole Displacement is 3393.84ft., in the Direction of 4.427° (True). Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°/100fi) Vertical Section (ft) Comment 1.326 0.772 1.119 1.715 0.207 1.352 0.492 0.557 5.760 0.000 2957.62 3o12.73 3065.82 3120.Ol 3174.74 3226.05 3282.24 3336.54 3343.00 3393.84 Projected Survey Continued... 18 February, 1999 - 9:08 - 5 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-220 Your Ref: AP1-$01032028300 Job No. AKMM900$8, Surveyed: 12 January, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2T Comments Measured Depth (ft) 852.88 4995.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 840.22 76.25 N 71.79 W 3049.67 3383.72 N 261.95 E Comment Tie-on Survey Projected Survey 18 February, 1999 - 9:08 - 6 - DrillQuest Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2T, Slot 2T-220 PB1 2T-220 PB1 Job No. AKMM90055, Surveyed: 1 January, 1999 SURVEY REPORT o G NAL 18 February, 1999 Your Ref: API-501032028370 KBE-80.40 MWD SURVEY INSTRUMENT Surface CooPdinates: 5970772.57 N, 498944.90 E (70° 19' 52.9661" N, 150° 00' 30.8095" W) DRILLINB S E I~V I C~,,E S Survey Ref: svy7221 Sperry-Sun Drilling Services Survey Report for 2T-220 PB1 Your Ref: API-501032028370 Job No. AKMM90055, Surveyed: 1 January, 1999 Prudhoe Bay Unit Measured Depth (ft), Incl. Azim. 0.00 0.000 0.000 117.00 0.000 0.000 192.52 0.530 204.960 255.02 0.910 271.770 284.29 1.620 294.870 347.41 3.290 304.660 376.43 3.960 305.530 406.98 4.790 305.070 436.58 5.840 305.260 466.01 7.110 305.300 496.39 8.490 304.670 526.59 9.570 306,800 555.75 10.210 308,240 585.69 10.870 311.630 615.56 11.570 315.630 644.21 12.590 317.400 675.14 14.280 319.390 704.94 16.220 319.590 733.42 17.360 321.490 764.46 17.600 323.870 793.98 18.150 326.160 822.52 19.300 328.620 852.88 20.800 331.310 882.14 22.380 334,780 913.46 22.710 337,020 Sub-Sea Depth (ft) -80.40 36.60 112.12 174.61 2O3.88 266.94 295.90 326.36 355.83 385.07 415.17 445.00 473,72 503.16 532.46 560.47 590.56 619.31 646.57 676,18 704.27 731.30 759.82 787.03 815.96 Vertical Depth (ft) 0.00 117.00 192.52 255.01 284,28 347.34 376.3O 406.76 436.23 465.47 495.57 525.40 554.12 583.56 612.86 640.87 670.96 699.71 726.97 756.58 784.67 811.70 840.22 867.43 896.36 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0,00 E 5970772.57 N 498944.90 E 0,00 N 0,00 E 5970772,57 N 498944.90 E 0,32 S 0.15 W 5970772.25 N 498944,75 E 0.56 S 0.77 W 5970772.01 N 498944.13 E 0.38 S 1.37 W 5970772.19 N 498943.53 E 1.02 N 3.67 W 5970773.59 N 498941.23 E 2.08 N 5,17 W 5970774.65 N 498939.73 E 3.43 N 7.08 W 5970776,00 N 498937.82 E 5.00 N 9,32 W 5970777.58 N 498935.58 E 6.92 N 12.03 W 5970779.49 N 498932.88 E 9.28 N 15.40 W 5970781.86 N 498929.50 E 12.06 N 19,25 W 5970784.63 N 498925,65 E 15,11 N 23.22 W 5970787.68 N 498921.68 E 18.63 N 27.41 W 5970791.20 N 498917.49 E 22.64 N 31.61 W 5970795.21 N 498913.29 E 26.99 N 35.74 W 5970799.57 N 498909.17 E 32.37 N 40.50 W 5970804.94 N 498904.40 E 38.33 N 45.59 W 5970810.90 N 498899.31 E 44.68 N 50.82 W 5970817.26 N 498894.09 E 52.09 N 56.47 W 5970824.67 N 498888,44 E 59.52 N 61.66 W 5970832.10 N 498883.25 E 67.24 N 66.59 W 5970839.82 N 498878.32 E 76.25 N 71.79 W 5970848,83 N 498873,12 E 85.85 N 76.66 W 5970858.43 N 498868.25 E 96.81 N 81.56 W 5970869.39 N 498863,35 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.000 0.00 0.702 -0.33 1.366 -0,65 2.940 -0.54 2.718 0.58 2.316 1.45 2.719 2.56 3.548 3.86 4.315 5.44 4.551 7.39 3.743 9.69 2.353 12.24 3.024 15.24 3.503 18.72 3.787 22.56 5.664 27.33 6.512 32.64 4.442 38.33 2.429 45.02 3.023 51.78 4.887 58.86 5.799 67.19 6.941 76.14 2.937 86.44 Cont/nued... 18 February, 1999 - 8:49 -2- DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-220 PB1 Your Ref: API-501032028370 Job No. AKMM90055, Surveyed: 1 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 944.35 23.170 338.480 844.40 974.30 23.980 340.700 871.86 1004.29 24.260 343.350 899.23 1034.69 24.060 345.550 926.97 1065.05 23.940 348.090 954.70 1092.63 23.570 349.740 979.94 1125.49 23.780 351.030 1010.04 1157.12 24.370 352.400 1038.92 1187.91 24.900 353.940 1066.91 1220.52 26.410 355.720 1096.30 1252.33 28.290 357.350 1124.55 1283.58 29.950 358.890 1151.85 1315.97 30.740 0.940 1179.81 1347.58 31.860 2.650 1206.82 1379.21 31.830 4.030 1233.69 1411.61 32.860 4.490 1261.06 1443.30 34.040 5.610 1287.50 1474.29 35.060 6.800 1313.02 1507.00 37.580 6.640 1339.38 1537.92 39.590 7.120 1363.54 1569.86 40.740 7.040 1387.95 1601.80 41.820 7.350 1411.95 1633.73 43.830 7.480 1435.37 1664.91 46.540 7.380 1457.35 1730.61 46.970 7.800 1502.36 Vertical Depth (ft) 924.8O 952.26 979.63 1007.37 1035.10 1060.34 1090.44 1119.32 1147.31 1176.70 1204.95 1232.25 1260.21 1287.22 1314.09 1341.46 1367.90 1393.42 1419.78 1443.94 1468.35 1492.35 1515.77 · 1537.75 1582.76 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 107.95 N 86.12W 5970880.53 N 498858.80 E 119.18 N 90.29W 5970891.76 N 498854.63 E 130.83 N 94.07W 5970903.42 N 498850.85 E 142.82 N 97.41W 5970915.40 N 498847.51 E 154.84 N 100.22W 5970927.42 N 498844.70 E 165.74 N 102.36W 5970938.32 N 498842.56 E 178.75 N 104.56W 5970951.33 N 498840.36 E 191.52 N 106.42W 5970964.10 N 498838.51E 204.26 N 107.94W 5970976.84 N 498836.98 E 218.32 N 109.21W 5970990.90 N 498835.72 E 232.90 N 110.09W 5971005.49 N 498834.85 E 248.10 N 110.58W 5971020.69 N 498834.35 E 264.46 N 110.60W 5971037.05 N 498834.34 E 280.88 N 110.08W 5971053.46 N 498834.86 E 297.53 N 109.11W 5971070.12 N 498835.83 E 314.82 N 107.82W 5971087.41 N 498837.12 E 332.22 N 106.28W 5971104.80 N 498838.67 E 349.69 N 104.38W 5971122.28 N 498840.57 E 368.93 N 102.11W 5971141.51N 498842.84 E 388.07 N 99.80W 5971160.66 N 498845.15 E 408.52 N 97.26W 5971181.10 N 498847.69 E 429.42 N 94.62W 5971202.01 N 498850.34 E 450.95 N 91.82W 5971223.53 N 498853.14 E 472.88 N 88.96W 5971245.46 N 498856.00 E 520.31N 82.64W 5971292.90 N 498862.33 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°/100fi) (fi) Comment 2.369 96.96 4.012 107.62 3.729 118.74 3.034 130.24 3.426 141.84 2.758 152.41 1.701 165.07 2.569 177.53 2.704 190.00 5.198 203.81 6.361 218.19 5.828 233.22 4.021 249.46 4.522 265.82 2.304 282.48 3.268 299.79 4.202 317.25 3.946 334.82 7.710 354.20 6.572 373.48 3.604 394.08 3.441 415.15 6.301 436.85 8.694 458.97 0.803 506.82 Continued... 18 February, 1999 - 8:49 - 3 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-220 PB1 Your Ref: API-501032028370 Job No. AKMM90055, Surveyed: 1 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1761.88 46.990 8.310 1523.69 1604.09 1790.29 48.200 8.060 1542.85 1623.25 1821.60 50.920 8.310 1563.16 1643.56 1852.49 53.560 8.100 1582.07 1662.47 1885.96 54.750 8.060 1601.67 1682.07 1917.35 56.330 8.120 1619.43 1699.83 1948.50 58.040 8.080 1636.31 1716.71 1981.64 59.940 8.110 1653.39 1733.79 2012.78 61.750 7.870 1668.56 1748.96 2042.64 63.210 8.590 1682.35 1762.75 2108.01 64.800 8.970 1711.00 1791.40 2171.73 65.030 9.600 1738.02 1818.42 2234.40 64.970 9.730 1764.50 1844.90 2299.02 65.180 9.950 1791.74 1872.14 2362.49 65.490 10.140 1818.22 1898.62 2425.45 65.430 10.970 1844.37 1924.77 2490.11 65.480 10.770 1871.23 1951.63 2553.59 65.850 11.250 1897.39 1977.79 2615.93 65.850 11.520 1922.90 2003.30 2679.91 66.020 10.990 1948.99 2029.39 2743.82 66.390 11.190 1974.77 2055.17 2806.92 66.470 11.970 2000.00 2080.40 2871.14 66.020 12.400 2025.87 2106.27 2934.29 66.320 12.140 2051.39 ' 2131.79 2997.91 65.340 11.860 2077.44 2157.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 542.95 N 79.44W 5971315.53 N 498865.54 E 563.71 N 76.45W 5971336.30 N 498868.53 E 587.30 N 73.06W 5971359.88 N 498871.93 E 611.47 N 69.57W 5971384.05 N 498875.41 E 638.33 N 65.76W 5971410.91N 498879.23 E 663.95 N 62.12W 5971436.53 N 498882.88 E 689.87 N 58.43W 5971462.45 N 498886.57 E 717.99 N 54.43W 5971490.57 N 498890.57 E 744.92 N 50.65W 5971517.50 N 498894.35 E 771.13 N 46.86W 5971543.70 N 498898.15 E 829.19 N 37.89W 5971601.77 N 498907.13 E 886.15 N 28.58W 5971658.72 N 498916.45 E 942.14 N 19.04W 5971714.71 N 498925.99 E 999.88 N 9.03W 5971772.45 N 498936.01E 1056.67 N 1.03 E 5971829.24 N 498946.08 E 1112.97 N 11.52 E 5971885.54 N 498956.58 E 1170.74 N 22.62 E 5971943.30 N 498967.68 E 1227.51 N 33.66 E 5972000.08 N 498978.74 E 1283.28 N 44.89 E 5972055.84 N 498989.97 E 1340.57 N 56.29 E 5972113.13 N 499001.38 E 1397.96 N 67.54 E 5972170.52 N 499012.64 E 1454.61N 79.15 E 5972227.17 N 499024.26 E 1512.07 N 91.56 E 5972284.63 N 499036.67 E 1568.52 N 103.83 E 5972341.07 N 499048.95 E 1625.29 N 115.90 E 5972397.84 N 499061.03 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°/100fi) (fi) Comment 1.194 529.68 4.308 550.65 8.709 574.47 8.563 598.88 3.557 626.01 5.036 651.88 5.491 678.05 5.734 706.45 5.851 733.64 5.337 760.11 2.488 818.83 0.965 876.48 0.211 933.21 0.448 991.73 0.559 1049.32 1.203 1106.47 0.292 1165.14 0.902 1222.83 0.395 1279.53 0.802 1337.77 0.646 1396.09 1.140 1453.72 0.931 1512.24 0.606 1569.75 1.592 1627.55 Continued... 18 February, 1999 - 8:49 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-220 PB1 Your Ref: API-501032028370 Job No. AKMM90055, Surveyed: 1 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 3062.21 65.120 11.900 2104.38 3125.26 64.990 12.370 2130.97 3189.73 65.110 11.610 2158.16 3253.46 65.930 11.990 2184.57 3316.37 64.900 11.880 2210.74 3378.92 64.290 11.920 2237.58 3442.16 64.230 12.340 2265.04 3506.09 64.990 12.940 2292.45 3568.60 64.300 11.960 2319.22 3632.76 64.520 12.920 2346.94 3695.97 63.720 11.720 2374.53 3758.83 63.750 11.550 2402.34 3822.65 64.000 12.210 2430.45 3884.90 64.050 12.570 2457.71 3948.18 64.240 12.220 2485.31 4010.46 63.920 11.370 2512.53 4076.51 63.840 10.440 2541.61 4139.30 63.290 9.380 2569.56 4203.62 62.390 8.480 2598.92 4266.77 62.190 8.200 2628.29 4330.70 62.010 7.250 2658.20 4394.47 61.090 5.880 2688.58 4457.88 60.770 5.150 2719.39 4520.72 60.310 4.710 2750.30 4585.34 59.890 3.750 2782.51 Vertical Depth (ft) 2184.78 2211.37 2238.56 2264.97 2291.14 2317.98 2345.44 2372.85 2399.62 2427.34 2454.93 2482.74 2510.85 2538.11 2565.71 2592.93 2622.01 2649.96 2679.32 2708.69 2738.60 2768.98 2799.79 . 2830.70 2862.91 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1682.42 N 127.92 E 5972454.97 N 499073.06 E 1738.31 N 139,94 E 5972510.86 N 499085.08 E 1795.49 N 152.08 E 5972568.04 N 499097.23 E 1852.27 N 163.94 E 5972624.81N 499109.10 E 1908.23 N 175.77 E 5972680.78 N 499120.94 E 1963.52 N 187.42 E 5972736.06 N 499132.60 E 2019.21 N 199.39 E 5972791.76 N 499144.58 E 2075.57 N 212.03 E 5972848.11 N 499157.23 E 2130.73 N 224.21 E 5972903.27 N 499169.41 E 2187.23 N 236.68 E 5972959.77 N 499181.89 E 2242.79 N 248.81 E 5973015.33 N 499194.03 E 2298.00 N 260.18 E 5973070.54 N 499205.41E 2354.08 N 271.98 E 5973126.61N 499217.21E 2408.73 N 283.99 E 5973181,26 N 499229.23 E 2464.35 N 296.21 E 5973236.88 N 499241.46 E 2519.18 N 307.66 E 5973291.71 N 499252.91 E 2577.42 N 318.88 E 5973349.94 N 499264.14 E 2632.80 N 328.56 E 5973405.33 N 499273.83 E 2689.33 N 337.44E 5973461.86 N 499282.72 E 2744.65 N 345.55 E 5973517.17 N 499290.84 E 2800.64 N 353.15 E 5973573.16 N 499298.44E 2856.33 N 359.56 E 5973628.85 N 499304.86 E 2911.50 N 364.89 E 5973684.02 N 499310.19 E 2966.01N 369.59 E 5973738.53 N 499314.91E 3021.88 N 373.72 E 5973794.39 N 499319.05 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.347 1685.71 0.707 1742.63 1.085 1800.85 1.396 1858.63 1.645 1915.61 0.977 1971.89 0.606 2028.61 1.460 2086.06 1.796 2142.28 1.392 2199.86 2.126 2256.47 0.247 2312.64 1.008 2369.72 0.526 2425.41 0.581 2482.09 1.331 2537.89 1.270 2597.05 1.747 2653.19 1.873 2710.38 0.504 2766.26 1.343 2822.75 2.377 2878.82 1.126 2934.23 0.953 2988.91 1.443 3044.87 Continued.., 18February, 1999-8:49 -5- DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-220 PB1 Your Ref: API-501032028370 Job No. AKMM90055, Surveyed: 1 January, 1999 Prudhoe Bay Unit Measured Depth (ft) 4645.47 4771.00 Sub-Sea Vertical Incl. Azim. Depth Depth (ft) (ft) 60.130 2.180 2812.57 2892.97 60.130 2.180 2875.09 2955.49 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~) (~) (~) (~) , 3073.88 N 376.41 E 5973846.40 N 499321.75 E 3182.66 N 380.55 E 5973955.17 N 499325.90 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section Comment (°/100fi) (ft) 2.296 3096.83 0.0o0 3205.33 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 6.819° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4771.00ft., The Bottom Hole Displacement is 3205.33ft., in the Direction of 6.819° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 4771.00 2955.49 3182.66 N 380.55 E Projected Survey 18 February, 1999 - 8:49 - 6 - DrillQuest 3/17/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12442 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL Sepia LIS Color Tape Print 2T-220 .~ c~ O'~' 99125 DSI,PE×,HALS (PDC) 990304 1 2T-220 99125 PEX-HALS 990304 1 1 2T-220 9912§ PEX-MCFL 990304 1 1 2T-220 99125 PEX-3 DET DEN CNL 990304 1 1 2T-220 99125 SSTVD 990304 1 1 2T-220 99125 DSI 990304 1 1 2T-220 99126 RELABELED DSI 990304 1 2T-201 99128 USIT 981223 I SIGNE Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: 1999 Naska ~ & Gas Cons. Co~~ And~or~e 15-Mar-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 WELL COMPLETED WITH NORDIC 3 NEW KBE Re: Distribution of Survey Data for Well 2T-220 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 5,752.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 23-Feb-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-220 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey' Window / Kickoff Survey: Projected Survey: 852.88' MD 'MD 4,995.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 I~ I I__1__1 rM r~- SI~ FIUI I-- I= S 23-Feb-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-220 PB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 4,771.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 21.1998 To~n Mckay Drilling Team Leader ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kupamk River Unit 2T-220 ARCO Alaska. Inc. Permit No: 98-253 SurLoc: 792'FSL. 556'FWL, SEC01. TIlN. R08E, UM Btmhoic Loc. 596'FNL. 955'FWL, SEC 01, T11N. R08E, UM Dear Mr. McKay: Enclosed is lite approved application for permit to drill thc above referenced xvcll. Annular disposal has not been requested as part of file Permit to Drill application for Kuparuk River Unit Well No. 2T-220. Please note that any disposal of fluids generated from this drilling operation which are pumped down thc surface/production casing annulus of a well approved for annular disposal on Drill Site 2T must comply with thc requirements and limitations of 20 AAC 25.080. Approval of fids permit to drill docs not authorize disposal of drilling waste in a volume greater than 35.000 barrels tlu-ough rile annular space of a single well or to nsc that well for disposal purposes for a period longer titan one year. Thc permit to drill docs not exempt you from obtaining additional permits rcqnircd bv law from other governmental agencies, and docs not authorize conducting drilling operations until all olhcr required permitting determinations arc made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24, hours) must be given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting fl~e Commission Comnlissioner~~ ~ ~ BY ORDER OF THE MISSION dlf/Enclosurcs cc; Dcpanmcnt of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conscrx'ation w/o cncl. STATE OF ALASKA ALA$¥Ga, OIL AND GAS CONSERVATION COMrva~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI ' Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 88' feet Kuparuk River Field 3. Address 6. Property Designation Tabasco Oil Pool P. ©. Box 100360, Anchorage, AK 99510-0360 ADL 25569, ALK 2667 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 792' FSU 556' FWL, Sec. 1, T11N, RaE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1053' FNL, 939' FWL, Sec. 1, T11N, RaE, UM 2T-220 #U-630610 At total depth 9. Approximate spud date Amount 596' FNL, 955' FWL, Sec. 1, T11N, RaE, UM 12/20/98 $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 2T-210 5555' MD 939' @ Target feet 125' @ 80' feet 2560 3353' TVD feet 16. To be completed for deviated well s 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 63.64° Maximum surface 2048 psig At total depth (TVD) 2411 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 82' 28' 28' 110' 110' +200 CI- 12.25" 9.625" 40# L-80 BTC 4959' 28' 28' 4987' 3069' 568 Sx Arcticset III & 933 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vedical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vedical 20. Attachments Filing fee X Property plat ~' BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E Refraction analysis [~ Seabed report r-' 20AAC 25.050 requirements X 21. I hereby certify that the foregoing is trpe and correct tolthe best of my knowledge , . ,, , ~ Signed / ~ ~'V - {'/~ Title Drilling Team Leader Date ; Commission Use Only ',27~ Approvaldate I.~,~/ C;)C_~ See cover letter tor I APl number ~ired -'E ~Yes other Permit Number~. (~;~'-- 2, .~"._~ . 50-//4:~ ..~ ,2.. ~'..~' I Mud'o~re"~ I requirements Conditions of approval Samples required [--J Yes 2~ No ,~ No Hydrogen sulfidemeasures F Yes J~' No Directional surveyrequired ~ Yes J'-' No Required working pressure for BOPE E~ 2M [~ OE 5M E 10M E 15M Other: I.)~ by order of Approved by L0avi('J ~ Ink~,~,_ Commissioner the commission ..... -. ~ ~0 0.~,,~ ,,, gl ihmif in lrinliP...~t~. 10-401 Rev. 7-24-89 'O, RiG'IN -L. Drill, Case and Completion Plan for Tabasco 2T-220 (C) Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon Rig 19. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/4987') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, POOH. 5. Run and cement 9-5/8" 40.0# L-80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 6. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. 7. Pick up 8-1/2" bit and BHA. Trip in and drill out stage collar. Clean out to top of float collar. 8. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 9. Freeze protect well. Install BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. 10. Secure well. Release rig. 11. Move in / rig up Nordic Rig 3. Nipple up BOPE and test to 3000 psi. Test casing to 3000 psi. Record results. 12. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 13. Drill 8-1/2" hole to well total depth (+/- 5555') according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 14. Run open hole wireline logs as needed. 15. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 16. Pump caustic wash. Pump pickle job. Circulate brine. 17. Pump acid pill across formation. Reverse out with brine. POOH 18. Run in hole with 4" Gravel Pack screen assembly. Set gravel pack packer. 19. Pressure test lines. Pump gravel pack sand and pack screens. 20. Reverse out excess sand. Circulate well to non-freezing, clean completion brine. POOH 21. Pick up Centrilift ESP motor, seal assembly, Y-block, and 2-7/8" tubing I-tube on 4-1/2" 12.6# L-80 BTCM production tubing. 22. Run in well with ESP motor assembly with power cable and data gathering information wire attached to tubing. 23. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 24. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. 2T-220 (C) Page 1 TAB, 12/10/98, v2 25. Make sudace electrical connections as required. 26. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 27. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to production. 2T-220 (C) Page 2 TAB, 12/10/98, v2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well Tabasco 2T-220 (C) Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Doyon Rig 19 Spud to 9-5/8" surface casing 8.5-9.6 16-26 25-50 150-250* 10-20 10-30 8-15 8-10 4-6% Nordic Rig 3 Drill out to TD 10.2 4-7 15-30 60-120 2-4 4-8 8-15 8.0-8.5 4-7% Drilling Fluid System' Doyon Rig 19 Triple Derrick Shale Shakers Centrifuge, Mud Cleaner Desander, Degasser Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner Nordic Rig 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual/Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using an expected surface casing leak-off of 14.1 ppg EMW (0.73 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2240 psi. The leak off EMW was chosen based on an open hole FIT on 2T-202 taken to 14.1 ppg at 2829' TVD (0.73 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3303 ft)(0.73 - 0.11) = 2048 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1500 psi (0.50 psi/ft). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3089'. Well Proximity Risks: The nearest existing well to 2T-220 is 2%210. As designed, the minimum distance between the two wells would be 125.0' at 80' MD. Drillinq Area Risks: Risks in the 2T-220 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 2T drilling results, 10.1 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 9-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-220 4-1/2" x 9-5/8" tubing annulus will be filled with kill weight brine and diesel after setting the 4-1/2" production tubing string and prior to the drilling rig moving off of the well. Tabasco Producer 2T-220 (C) ..... ' Producer Completion 16" Conductor @ 80' Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/- 1981' MD / 1696' TVD) 4-1/2" Nova Clamps AII Depths RKB Nordic 3~ 3-1/2" Nova Clamps ESP power cable splice above Y-block B. 1 jt, 3-1/2" 9.3# L-80 EUE8RD tubing A. Centrifilt Series 562 ESP assembly w/power cable, 5.62" OD Super-Bands to top of Y-block +/- 3' intervals 9-5/8" Surface Casing 40.0# L-80 BTCM (+/- 4987' MD / 3069' TVD) Well TD - Open Hole Gravel Pack (+/- 5495' MD / 3323' TVD) i N. FMC Tabasco Producer horizontal wellhead/hanger system w/125 amp penetrators M. Heat Trace, Raychem, 3000' L. 4-1/2" 12.6# L-80 BTCM tubing to surface K. XO sub, L-80 4-1/2" BTCM box x 3-1/2" BTCM Special Clearance pin J. 3 jts, 3-1/2" 9.3# L-80 BTCM tubing 3.865" Special Clearance couplings I. Baker 'Sentry' gauge, 3-1/2", w/l-wire, Clamp-on style H. 3-1/2" x 4' Landing pup, 9.3#, L-80, BTCM 3.865" Special Clearance couplings G. 3-1/2" Trico Y-Block w/couplings, 3-1/2" EUE8RD pin on motor leg, 2-7/8" EUE8RD pin on I-tube leg, 3-1/2" BTCM Special Clearance box on uphole end F. 2-7/8" Trico 'X' landing nipple w/2.312" profile, EUE8RD box x Hydrill 511pin E. 3-11/16" x 2' L-80 'Swivel Sub', 2.875" ID Hydrill 511 D. 3 jts, 2-7/8" 6.5# L-80 Hydrill 511 flush jt tubing (drift)*~ 0.184" planned clearance as per Centrilift (ESP OD) - (I tube OD) = 8.679" - 5.62" - 2.875"/ C. 2-7/8" Wireline Entry Guide, Hydrill 511 Gravel Pack Assembly (run on drillpipe) -- Baker SC-1 Gravel Pack packer, 9-5/8" -- 4 jts, Baker 4" blank tubing, Hunting Seal Lock threads -- Baker ceramic flapper valve -- Baker 4" Gravel Pack screen, Hunting Seal Lock 20 gauge (0.02") screen 12-20 US mesh gravel pack sand TAB, 12/09/98, vl I v w ".~" For: BROCKWAY Oot~ plotted: 7-Oec-g8 Plot Re~r~nce ~s ~O Ve~ ~ ~[no~ om In f~t ~fe~nce ~o[ ~22~ ARCO Alaska, In ............ Structure : Pad 2T W®[[ : 220 Field : Kuparuk River Unit Location ; North Slope, Alaska[ TD LOCATION: 596' FNL, 955' F-WL SEC. 1, T11N, R8E 6.36 AZIMUTH 3457' (TO TARGET) ***Plane of Proposal*** East (feet) -> 5oo o 500 600 I I I I I I I 95/8 Casing ' End Angle Drop 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 RKB ELEVATION: 116' TARGET LOCATION: 1055' FNL, 939' FWL SEC. 1, T11N, RSE TARGET TVD=3089 TMD=5027 DEP=3457 NORTH 3435 EAST 383 KOP TVD=250 TVD=2§O DEP=O 4.00 8.00 12.59BEGIN TURN TO TARGET 7VD=548 TMD=550 DEP=15 14.55 17.19 20.28 23.63 DLS: 4.00 deg per 100 ft 27.15 50.78 34.49 38.25 42.04 45.8749.71B/ PERMAFROST 'r'VD=1496 TMD=1640 DEP=482 53.58 _, 57.451/ UCNU SNDS TVD=1643 TMD=1879 DEP=670 EOC TVD=1733 TMD=2059 DEP=826 MAXIMUM ANGLE 63.64 DEG K-13 WD=2070 TMD=2819 DEP=1505 T/ W SAK SNDS TVD=2206 TMD=3126 DEP=1778 BECIN TURN TO TARGET TVD=2615 TMD=4048 DEP=2601 B/ W SAK SNDS TVD=2656 TMD=4158 DEP=2682 Top Wes{ Sak Sand? / EOC ~iiln iii ato Target SURFACE LOCATION: I 7~2' FSI_, 556' FWL SEC. 1, T11N, RSE 63.29 62.01 END ANGLE DROP TVD=2894 TMD=4657 DEP=3120 DLS: 1.50 deg per 100 ft 60.79 TARGET ANGLE 60 DEG 9 5/8" CSG PT TVD=3069 TMD=4987 DEP=3422 TARGET - TOP TABASCO TVD=3089 TMD=5027 B/ TABASCO WD=3303 TMD=5455 DEP=3826 TD - CSG PT TVD=3353 TMD=5555 DEP=39t3 I I I I I I 0 250 500 750 i i i i i i i i i i , i i i i ii l 1000 1250 1500 1750 2000 2250 2500 2750 3000 Vertical Section (feet) -> Azimufh 0.36 wi~h reference 0.00 N, 0.00 E from slo~ #220 i i i i I I I 3250 3500 3750 4000 4200 3900 5600 5500 3000 2700 24oo A I Z 2100 0 1800 ~ --i- 1500 ~.~ 1200 90O 600 300 300 320 30O 280 260 240 22O 200 180 A 160 I 140 120 80 60 40 20 20 4O ARCO Alaska, Inc. ........... -~truoture : Pad 2T Well : 220 Field : Kuparuk River Unit Loaaflon : Nor'th Slope, Alaska 900 1850 1800 ~f 1 750 4 1700 I 1650 ~ 1600 ~1550 400~ 1500 I1~1450 4O0 <- West (feet) 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 I~ I I I I I I ~ ~¢~~1 I I I I I I I I I I I I I I I I I I I I I ¢ t 320 ~ \ lO~ I // 1- 92150 / 2 I ~ 18o¢ \ I / 1050 ~ 2050 ~ I 800 / 2~0 [ 2000 /1000 ~ 175 1200 / ¢240 ~ 1750 ~ 220 ~ 1150 ,', ooo 700~ ~ lO ~ ~ ~ ] 1 700 ~ 180 /900 / ~105 165~ 950 ~ ' ~ / / / ~~00~ / / /~50 ~ ~ 650 / // /1 ~oo 145£ '~ o....1 fl00 550 ~00 i i i i i 60 4-0 20 200 180 160 14-0 120 1 O0 BO <- West (feet) 120 ,..-,, \ / / \ \\ ? 800 / / ~_,_ \ 1600 ! /750 /1050 100 v \ / ? ? / / , 1550t 850 750 / / 1400 80 \\85~ ! / 1000 / \ / /%0 / / \ 155( ~700 / / / eo 1500~, ii /~j ~1350 ~ 75( 1800 / 50 / ~5o ~5o/ / 40 / / ~ 500 ~ ~1~50' ~50 150C / ~00 75~/ ,OO~oo/ / ~ 7~0~00 / / 20 150 ~ %~50 // ~50 ~1250 / ~o~ ~o~ / oo, OO o ~oo¢o~ / / ~oo ~o z ~ ~o ~ ~o~, ~ ~oo. / ,o 150 ~ 300 650 70~ / 4o 6o o 2o 4o 6o 8o 1 oo 960 920 88O 84O 800 760 720 680 64-0 600 560 52O 480 44( 400 360 320 280 24O ARCO Alaska, Inc. Structure : Pad 2T Well : 220 :c;~3 q :-~i~ Field: Kuparuk RTver Unit ~o~[on : North ~op~ Alaska East (feet) -> 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 320 I I I I I I I I I I I I I I I I I I I I I tI ~ / 2300/// 920 ~ iI 2500 ~ 2200 iI ~~/ 880 ~2200 // 84O ,, ' I/ / // /~oo ¢800 / // / /// 7~0 2~0, ~[ 2~00 Il ///~200 ~20 / 2000 [~3000 2800 ~ 2700 ~ 2600 1906 2500 1700 ~ 2400 2300 2200 ~ 21oo O0 ~2000 2100 180C I / fl oo I I I I I I I I ~ 1500 I I I I Z200 I J 1400 I I I 1 1300 1200 2000 1900 1800 / / 2400 / 1300~ / 320 / / / / / / / / / / / 16 / / / / ~lOO / / / / / / / ~1900 / /1200 / t / / / / / / t / / / / / / 1100 /! ! 1100 / / / lOO9 / / / / / 1 / / / / / / / i i i i i i 280 240 200 160 120 80 40 0 40 80 120 160 200 24-0 280 320 East (feet) -> 680 ~4-o I Z o 560 --,}. 520 48O 440 4OO 36O 320 280 240 4400 4200 4000 3800 3600 3400 3200 $000 2800 2600 2400 2200 2O00 1800 1600 1400 1200 1000 800 600 ARCO Alaska, Inc. Slnuoture: Pad 21 Well : 220 F~eld : Kuparuk R~ver Un~f Lo,allan: North Slope, Alalka Eost (feet) -> 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 I I I I I I I I I I I I I I I I I I I / I I I I~ I I I I I ~ I 4700 /2700 // ! / 45OO 4500 2700 4300 41 00 29O0 270C 5900 3700 5700 3500 3300 3101 00 3300 3504 2900 ~100 3300 I ~900 O0I ~2700 3100 330~ 370( I I 310~, 1 29o~ 270~ / / / I 2500~ I / / / / 5300 Mgoe I / 230~ / / / 270C / / I ~oo I I / / I 900 I / / 300 / / / / / 25oo / / 2300 / 2300/ / 350~ / / / / / / 2100 / / / 270£ // / 41 // 3500 / # 2100 / / 300 / / / / ? /~900 / / / / / ~500 / / / / / / / / /2300 / /3300 ?oo'°° ~5002~ i 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 Eost (feet) -> 4400 4200 4000 3800 3600 3400 3200 3000 280o A I 2600 2400 2200 2000 18O0 1600 1400 1200 1000 800 600 ARCO Alaska, Inc. Pad 2T 220 slot #220 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 220 Vets. #2 Our ref : prop3088 License : Date printed : 7-Dec-98 Date created : 28-Jul-98 Last revised : 7-Dec-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 19 45.172,w150 0 47.034 Slot location is nT0 19 52.961,w150 0 30.800 Slot Grid coordinates are N 5970772.056, E 498945.220 Slot local coordinates are 792.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath MSS <4046-4427'>,,202,Pad 2T PMSS <0-5924'>,,32,Pad 2T PMSS <4850 - 5918'>,,32A,Pad 2T PMSS <5497-13787'>,,32B,Pad 2T PMSS <0-4749'>,,30,Pad 2T PMSS <4627 - 10686'>,,30A, Pad 2T PMSS <12144-13360'>,,3SA, Pad 2T PGMS <0-6370'>,,9 PGMS <0-6975'>,,7 PGMS <0-8208'>,,6 PGMS <0-7670'>,,5 PGMS <0-8160'>,,4 PGMS <0-8445'>,,17 PGMS <0-7868'>,,13 PGMS <0-6789'>,,11 PMSS <3115 - 3645'>, .Pad 2T .Pad 2T .Pad 2T .Pad 2T .Pad 2T Pad 2T Pad 2T Pad 2T 12,Pad 2T PGMS <0-6725'>,,12B,Pad 2T PMSS <4757-6800'>,,12A, Pad 2T PMSS <1287-1725'>,,2,Pad 2T PGMS <0-8890'>,,2A, Pad 2T PMSS <0-10570'>,,29,Pad 2T PMSS <380 - 11400'>,,31,Pad 2T PGMS <O-8250'>,,10,Pad 2T PGMS <O-7650'>,,8,Pad 2T PMSS <5917-7957'>,,16A, Pad 2T PGMS <0-8947'>,,16B,Pad 2T PMSS <1604-3625'>,,16,Pad 2T PGMS <O-7625'>,,15,Pad 2T Closest approach with 3-D Minimum Distance Last revised Distance 26-Aug-98 345.0 24-Feb-98 225.0 24-Feb-98 225.0 24-Feb-98 225.0 16-Jul-98 252.6 16-Jul-98 252.6 23-Jan-98 727.0 23-Jan-98 564.9 23-Jan-98 515.0 23-Jan-98 488.5 23-Jan-98 464.3 23-Jan-98 439.6 23-Ja~-98 814.9 23-Jan-98 715.0 23-Jan-98 664.9 23-Jan-98 689.2 23-Jan-98 689.2 23-Jan-98 689.2 26-Aug-98 390.0 26-Aug-98 390.0 23-Jan-98 270.0 23-Jan-98 234.8 23-Jan-98 640.0 23-Jan-98 540.0 23-Jan-98 790.0 23-Jan-98 790.0 23-Jan-98 790.0 23-Jan-98 765.0 method M.D. 100.0 0.0 0.0 0.0 310.0 310.0 100.0 180.0 0.0 290.0 260.0 260.0 160.0 0.0 250.0 270.0 270.0 270.0 0.0 0.0 100.0 380.0 100.0 0.0 0.0 0.0 0.0 0.0 Diverging from M.D. 980.0 0.0 0.0 0.0 310.0 310.0 100.0 180.0 0.0 290.0 260.0 260.0 160.0 0.0 250.0 270.0 270.0 270.0 250.0 250.0 100.0 380.0 100.0 0.0 0.0 0.0 0.0 0.0 PGMS <0-8262'>,,1%,Pa6 PMSS <650 - 11080'>,,37,, .. 2T PMSS <921-10235'>,,20,Pad 2T PMSS <0-12821'>,,21,Pad 2T PMSS <0 - 9210'>,,26,Pad 2T PMSS <741-15471'>,,36,Pad 2T PMSS <918 - 10193'>,,22,Pad 2T PMSS <O-4175~>,,201,Pad 2T PMSS <O-9298'>,,27,Pad 2T PGMS <0-7897'>,,3,Pad 2T PMSS <893 - 12977~),,23,Pad 2T PMSS <469-10632~>,,18,Pad 2T PMSS <O-9845'>,,19,Pad 2T PMSS <0-5340'>,,210,Pad 2T PMSS <0-???>,,207,Pad 2T PMSS <918' - 10890'>,,28,~ad 2T 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 26-Aug-98 23-Jan-98 26-Aug-98 25-Aug-98 21-Oct-98 23-Jan-98 4-Dec-98 7-Dec-98 23-Jan-98 739.0 888.4 860.0 874.9 315.0 777.0 375.0 552.5 299.8 414.9 360.0 827.8 844.8 125.0 158.5 285.0 260.0 320.0.~.. 100.0 200.0 250.0 100 0 100 0 100 0 260 0 250 0 100 0 290.0 260.0 80.0 330.0 240.0 260.0 320.0 1632.0 200.0 250.0 100.0 100.0 100.0 260.0 250.0 100.0 290.0 260.0 80.0 330.0 5554.8 16" Div ...... ter Schematic -- DoY( : Rig 19 Kuparuk River Unit Tabasco Operations 21 1/4' 2000 pSI, liSP IR'DEE BOP/DM~ql~ STUDDED TOP/F1.ANGr~ BO1TOId 1" C/W PLUG · I i 16' 150 PS] HYDR. OPERATED KNIFE GATE VAt.V[ 16' F~'G'D VENT UNE SURFACE DIVERTER CONFIGURATION · .. 13-5/8" 5~ ~)0 psi BOP Stack -- D~,on Rig 19 Kuparuk River Unit Tabasco Operations - Producer WelIs 3' 0 1/4' 1' 10 1/~' 1' 10 1/a' ' CHOKE UNE 1/13' ~ PSI HCR VALV~ / = ~/8' 5000 ~ =~ w.v~ STACK WELLHF..,U3 13 5/5". 5000 PS1 HyDRIL ANNUI.~R BOP, STUDDED TOP/~.ANGED BOTI'OM -------------SINGLE 13 -~/8", 5000 PSI, 10' MPt. OPERATORS, HYDRIL PIPE RAM F"LANGE: BOTTOM/~"TUDDED TOP sING'L[ 13 5/8". 5000 PSi, 14" MPL OPERATORS, BUND SHEAR RAM 3 1/8" 5000 PS~ HCR VALVE .. 2" mLL'UNE 3 ~/a' sooo ~ ~AT~ V~LV~ F*LANGE BO*I'rOM/STUDDED TOP SINGLE 13 S/IS'..9000 PSi. 10' UPL OPERATORS HYDRIL PiPE RAM FLANCE/F'L~GE ADAFTER SPOOL HUB x FLANGE BOP STACK ELEVATION 11" 5(' O psi BOP Stack-- No ...... tic Rig 3 Kuparuk River Unit Tabasco Operations- Producer Wells Kill Line ri Choke Line 11I Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic 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 the 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 stack and manifold with water. 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, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v.1 PE SD# K98075ACS 2 1 11 112 DRILL SITE 2-T o 220 25.0' ,~~ 218 37.5' 21,5 62.5 210 o 209 o 208 62.5'--~_ 207 ~ 3~ ~ 30 ® ~0~ ~ 3 ~ ? ~ 8 ~0~ · I0 · ii · 12 · 13 38~ 14 · 1,5 36~ 16 · I? · 18 · 19 · 20 · 21 · 37 VICINITY MAP ~" = 2 M~L~S SEE SHEET 2 FOR NOTES AND LOCATION INFORMATION (NO SCALE) LEGEND NEW CONDUCTOR LOCATIONS EXISTING CONDUCTORS ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CADD FILE NO. J I DRA~N¢ NO: LK622012 9//16/98 LOUNSBURY &: ASSOCIATEs, INC. AREA: 2T MODULE: XX DRILL SITE 2-T WELL CONDUCTORS 207-210,215,218 &: 220 AS-BUILT LOCATION ISHEET: IREV: CEA-D2TX-6220D12 oo~ o. 2 UNIT: D2 ~EVI OATE I BY I CK I APP I . DESCRIPTION ~ BY I CK lAPPI D£SCRIPllON 9/16/98 MRT JU PER .... 8 ~ KgBO75Acs .~_~ NOTES " .,-r- ' 1, BASIS OF LOCATION AND ELEVATION ARE DRILLSITE 2-T MONUMENTS PER LHD &: ASSOCIATES. coo o,, , s zo, ,. ALL DISTANCES ARE TRUE. · 5. ELEVATIONS SHOWN ARE B.P.M.S.L. 4. WELLS ARE LOCATED WITHIN PROTRACTED SECTION 1.~,"L~/'' ~.,f./,',',',-~~____~~ T. 11 N,, R, 8 E.. UMIAT MERIDIAN, ALASKA. 5. DATE OF SURVEY: 9/13/98, FIELD BK. L98-71 pg. 14-2.3. 6, DRILL SITE 2-T GRID NORTH IS ROTATED 179' 59' 40" WEST FROM A.S.P. ZONE 4 GRID NORTH. 7, SEE REFERENCE DRAWINGS: CEA-D2TX-866, FOR CONDUCTOR 2-17 LOCATIONS, CEA-D2TX-6220D7 FOR CONDUCTOR 18-23, VICINITY MAP ,--2 ~L~S 26-,32, .36-38 &: TABASCO LOCATIONS, AND CEA-D2TX-6220D9 FOR CONDUCTOR 202. LOCATED IN SECTION 1, T 11 N, R '8 E. U.M. SEC. SEC. · WELL LINE LINE O.G. PAD NO. Y X LATITUDE LONGITUDE O/S O/S ELEV. ELEV. F.S.L. F.W.L. 207 I 5,970,610.10 498,945.02 70'19'51..368" 150'00'.:30.805" 6,30' 556' 75.2' 80.4' i 208 5,970,622.69 498,944.87 70'19'51.492" 150.00'30.810" 642' 556' 75,2' 80.4' ; , · 209 5,970,635.10 i 498,944.90 70'19'51.614" 150.00'30.809" 655' 556' 74.9' 80.4' 210 5,970,647.69 498,944.73 70'19'51.7.38" 150'00'30.814" (~67' 556' 74.7' 80.4' 215 5,970,709.72 498,944.99 70'19'52.348" 150'00'30. 807" 729' 556' '74.2' 80.4' I , I 218 5,970,747.74 498,944.97 70-19'52.722" 150'00'30.807" 768' I 556' 74.1' 80.4' i 220 5,970,772.57 498,944.90 70'19'52.966"i 150'00'30.810" 792' 556' 74.1' 80.4' _.~c OF z~/ ~e_ SURVEYOR'S CERTIFICA'ITZ ~. ~\ ~. ......... ;,,._v~41 ~,-~'-° j~ '*..~?v, I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND __~ ~;t ~ ~ ',,,Z~ ~. LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF _ ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ~ ..... ; ..... , ~~~ ~,~ o,~~~,o~~ ~ o~.~ o~,.~ ~ ~o~ %%?....~/~ ~/,~ ....." ~_~ · ~;~ 2'~/-4.~...~.-'' ~ LOUNSBURY AREA: 2T MODULE: XX UNIT: 02 ~' DRILL SITE 2-m ARCO Alaska, Inc. WELL CONDUCTORS 207-210,215,218 & 220 Subsidiery of Atlentic Richfield Compeny AS-BUILT LOCATION LK622012 9/16//98 CEA-D2TX-6220D12 002 OF 2 1 SEC. SEC. · WELL LINE LINE O.G. PAD NO. Y X LATITUDE LONGITUDE O/S O/S ELEV. ELEV. F.S.L. F.W.L. 207 5,970,610.10 498,945.02 70'19'51.368" 150'00';30.805" 6;30' 556' 75.2' 80.4' 208 5,970,622.69 498,944.87 70-19'51.492" 150'00'30.810" 642' 556' 75.2' 80.4' 209 5,970,635.10 498,944.90 70'-19'51.614" 150'00'30.809" 655' 556' ' 74.9' 80.4' 210 5,970,647.69 498,944.7,3 70'19'51.7,38" 150'00'.30.814" ~67' 556' 74.7' 80.4' 215 5,970,709.72 498,944.99 70-19' 52. 348" 150'00'30. 807" 729' 556' 74.2' 80.4' 218 5,970,747.74 498,944.97 70-19'52.722" 150'00'30.807" 768' 556' 74.1' 80.4' 220 5,970,772.57 498,944.90 70-19'52.966" 150'00'30.810" 792' 556' 74.1' 80.4' ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor December 9, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill Tabasco 2T-220 Tabasco Producer, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designed as a producer using an open hole gravel pack completion technique for sand control purposes. The surface hole will be drilled and cased using Doyon Rig 19. After this rig moves off the well, Nordic Rig 3 will move onto location to drill out the production interval and run the completion. Completion plans call for running a 4-1/2" production tubing string with an ESP and Y-block assembly, 2-7/8" I-tube, and heat trace. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Tabasco sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Tabasco sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 2T-220, such as shallow gas. 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program is attached. 9) Aisc note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. Please note that the anticipated spud date for this well is December 20, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Sincere3.y-~,... .-.~, Thomas A. Brockway Operations Drilling Engine' Attachments: CC: Tabasco 2%220 Well File Tom McKay ATO-1060 Jack Walker ATO-1200 Lewis Ledlow ATO-1063 ARCO Alaska, I /kAl PAYABLES P.O. Box 102776 Anchorage, AK 995 10-2776 PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION 3001 PORCUPINE DRIVE IMI EXACTLY *******': The First National Bank of Chicago-0710 Chicago, Illinois Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 2050867,7,7~ ,' ~O SORF= ~/~,' ,:OR :~qOh ;~F= 2"- CHECK NUMBER 721 NOVEMBER 19, 1998 73-426 839 0997579 ***: VOID AFTER 90 DAYS *** . DOLLARS AND O0 CENTS' ,~*********** 100.00 ~ oqq ? S ? WELL PERMIT CHECKLIST _WELL NAME ~,~. gl/', ..~"T'- 2_::5> (23 PROGRAM: exp [] dev~redrll [] serv n we,bore segll ann. disposal para req,I ~;',?,,~'~ UNIT// /,///~::~ C:~ ON/OFF SHORE ~,,L,J .~ COMPANY ./~_ '/~. ("...~,,'~-'~ FIELD & POOL ...... ...~.___~_O_~._(~___ INIT CLASS ,~_~ 1. Permit fee attached ....................... 2. [_ease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well Iocaled proper distance from drilling unit boundary 6. Well Iocaled proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued wilhout administrative approval ...... 13. Can permit be approved before 15-day wait ........... ADMINISTRATION 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl' vol adequale to circulate on conductor & surf csg ..... 17. CM I- vol adequate to tie-in long string to surf csg ........ 18. CMI will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequale ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ (~)O("-') psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ N N N N N N (2~9N ENGINEERING 28. Work will occur without operation shutdown ........... (~Y(~ N~ ......... 29. Is presence of H2S gas probable. ' s zones ....... ..... .................... .............. ........................................................ 32. Seismic analysis o[ shallow ~as :,ones. ' ................. 33. Seabed condition su~ey (i[off-shore) ............. Y ~ 34. CoCtad.na~e/phon~ ~or weeklg pro,mss reports lexp~oraro~ ontyj GEOLOGY D,b'rE/ ANNULAR DISPOSAL 35. h proper cementing records, this plan Witwill contain waste in a s~itable receiving zoO."" ..... (A) (B) will not contaminate frest'~'ater; or caus~illing waste... to surface; ~ (C) will nol impair mechanical ~Jsed for disposal; (r)) will not damage pro~orrnation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N .... Y N Y N ......................................................... Y N COMMISSION: DWJ~___,,~_ ~ RNC . Y_../,/'Z/'[ co , Comments/Instructions: APPR [)ATE .............................................. GEOI_O~ ..... ~NGI~EI~RING: JDH ~ M chel~hsl ~;v (]5/29/9B rill C \[H';ofh( ~!\wl)~l'Ji;'.'i\¢t~ru ~; I\, I~ '~ I Il' I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_ file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue May 25 13:57:17 1999 Reel Header Service name ............. LISTPE Date ..................... 99/05/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/05/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER TABASCO MWD/MAD LOGS WELL NAME: API NUMBER: OPER3~TOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPEP~ATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: R3~NGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-90055 G.TOBIAS F. HERBERT 2 T - 220 gJa,~ka 0il & uas ~ns. ~0mmissi0n 501032028300 ,~Orage ARCO ~AS~ INC. SPERRY-S~ DRILLING SERVICES 25 -~Y- 99 MWD RUN 3 AK-MM-90055 M. HALL D. GLADDEN 1 llN 08E 792 556 110.90 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 110.90 80.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 24.000 16.000 110.0 12.250 9.625 4990.0 8.500 5752.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 DRILLED 2T-220 PB1 AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA P_AY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PH_ASE-4 (EWR4) . THIS PORTION OF THE HOLE WAS DRILLED BY RIG DOYON 19 WITH KBE OF 117.41' AMSL. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THIS PORTION OF THE WELL WAS DRILLED BY RIG NORDIC 3 WITH KBE OF 110.92' AMSL. 5. MWD RUN 2 DATA WAS CORRECTED UPWARD 6.5' AND MERGED WITH MWD RUN 3 DATA. THE MERGED DATA ARE SHIFTED TO THE PDC REFERENCE LOG- THE GAMMA RAY FROM THE PEX SLB OF 03/04/99. 6. MWD RUNS l&2 REPRESENTS WELL 2T-220 WITH API#: 50-103-20283-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5752'MD, 3045'TVD. SROP = SMOOTHED RATE OF PENETPJITION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 1056 0 FET 1056 5 RPD 1056 5 RPM 1056 5 RPS 1056 5 RPX 1056 5 ROP 1058 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 1056.0 4910.0 4911.5 4933 0 4962 0 4973 5 4978 0 4982 0 4986 0 4988 0 4991 5 4995 5 4999 5 5004 5 5016 5 5021 0 5024 0 5043 5 5049 0 5056 5 5089 0 5106 5 5116 0 5145 5 5150 5 5175 0 5194 5 5209 0 5214 0 5215 5 5339 0 5388 5 5394 5 5407 5 5413 5 5416 0 GR 1055 5 4909 5 4910 5 4931 0 4961 5 4973 0 4977 5 4981 5 4985 5 4987 5 4991 0 4995 5 4999 0 5004 5 5017 0 5021 5 5025 0 5044 0 5050 0 5056 0 5090 5 5109 0 5116 5 5144 5 5152 0 5175 0 5194 5 5209 0 5214 0 5215 5 5339 5 5388 0 5394 0 5406 0 5414 0 5416 5 STOP DEPTH 5741 0 4951 0 4951 0 4951 0 4951 0 4951 0 5750 0 EQUIVALENT UNSHIFTED DEPTH -- 5422 0 5426 0 5427 5 5446 0 5464 0 5467 0 5472 0 5480 0 5496 0 5504 0 5518 5 5520 5 5525 5 5534 0 5543 5 5547 0 5575 0 5601 5 5628 5 5632 0 5640 0 5646 5 5660 5 5741 0 5750 0 $ 5422 5 5425 5 5428 0 5446 5 5465 5 5468 5 5473 0 5481 0 5497 0 5505 0 5519 5 5523 0 5528 0 5537 0 5546 5 5549 0 5576 0 5602 5 5631 0 5635 5 5643 0 5647 5 5662 5 5743 0 5752 0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 1062.0 4990.0 MWD 3 4990.0 5752.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Min Max Mean DEPT 1056 5750 3403 ROP 0 2339.65 215.388 GR 18.6576 155.613 82.4223 RPX 2.642 83.2014 13.9238 RPS 3.4585 160.82 19.783 RPM 3.5667 2000 32.7662 RPD 3.8901 2000 52.2408 FET 0.0522 6.7114 0.552908 Nsam 9389 9385 9339 7790 7790 7790 7790 7790 First Reading 1056 1058 1056 1056.5 1056.5 1056.5 1056.5 1056.5 Last Reading 5750 5750 5741 4951 4951 4951 4951 4951 First Reading For Entire File .......... 1056 Last Reading For Entire File ........... 5750 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 1055.5 FET 1056.0 RPD 1056.0 RPM 1056.0 RPS 1056.0 RPX 1056.0 STOP DEPTH 4940 5 4950 0 4950 0 4950 0 4950 0 4950 0 ROP 1057.5 LOG HE~DER DAT~ DATE LOGGED: SOFTWAR~ SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMI/M ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA tLAY EWR4 $ 4988.5 ELECTROMAG. RESIS. 4 BOREHOLE AAID CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 12 - JAN- 99 INSITE 3.2 U3/3.2 U3 5.46 MEMORY 4995.0 1062.0 4995.0 20.3 66.5 TOOL NUMBER Pl158CRG8 Pl158CRG8 12 . 250 12.3 SPUD 9.50 165.0 9.5 350 7.6 3.000 2.430 1. 940 2.800 32.5 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 1055.5 4988.5 3022 7867 1055.5 ROP 4.8309 2339.65 217.639 7863 1057.5 GR 18.6576 155.613 82.619 7771 1055.5 RPX 2.642 83.2014 13.9247 7789 1056 RPS 3.4585 160.82 19.7845 7789 1056 RPM 3.5667 2000 32.7694 7789 1056 RPD 3.8901 2000 52.2464 7789 1056 FET 0.0522 6.7114 0.552915 7789 1056 Last Reading 4988.5 4988.5 4940.5 4950 4950 4950 4950 4950 First Reading For Entire File .......... 1055.5 Last Reading For Entire File ........... 4988.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4958.0 ROP 4989.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5743.0 5752.0 04-MAR-99 INSITE 3.2 U3/3.2 U3 5.46 MEMORY 5752.0 4990.0 5752.0 43.5 57.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER P1251CG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BARADRIL -N 9.70 44.0 8.4 4.2 .000 .000 .000 .000 26.7 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 4958 5752 5355 1589 4958 GR 42.96 144.27 81.5067 1571 4958 ROP 0 1920 203.214 1527 4989 Last Reading 5752 5743 5752 First Reading For Entire File .......... 4958 Last Reading For Entire File ........... 5752 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/05/25 Origin ................... STS Tape Name ................ UNKI~OWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Reel Trailer Service name ............. LISTPE Date ..................... 99/05/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2T-220 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 50-103-20283-00 REFERENCE NO : 99125 LIS Tape Verif~'tion Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:0~~ / PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/12 ORIGIN : FLIC REEL NAME : 99125 CONTINUATION # : PREVIOUS REEL : CO~ff4ENT : ARCO ALASKA, 2T-220, KUPARUK, API #50-103-20283-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/12 ORIGIN : FLIC TAPE NAME : 99125 CONTINUATION # : 1 PREVIOUS TAPE : CON~4ENT : ARCO ALASKA, 2T-220, KUPARUK, API #50-103-20283-00 TAPE HEADER KUPARUK RIVER OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN 1 99125 D KIRKBY WESTER SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 2T-220 501032028300 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 12-MAR-99 RUN 2 RUN 3 .......... 1 llN 8E 792 556 110.92 110.92 80.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 4990.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:0~~ J 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED OPEN HOLE PEX, HALS, AND DSI DATA AQUIRED ON ARCO ALASKA'S 2T-220 WELL. THE MAIN PASS IS THE PDC. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged DEPTH INCREMENT: O . 5000 FILE SURk4ARY LDWG TOOL CODE .............. DAS CNT SDN DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 5704.0 4908.0 5668.0 4908.0 5680.0 4990.0 5694.0 4990.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE .............. DAS DAS REMARKS: ___i ......EQUIVALENT UNSHIFTEDDEPTH .......... BCS CNT SDN DLL BCS RUN NO. PASS NO. MERGE TOP MERGE BASE 1 1 4904.0 5626.0 1 2 5626.0 5670.0 THIS FILE CONTAINS THE EDITED DATA. THE CURVES ARE CLIPPED AT FIRST AND LAST VALID READINGS. THE DAS RUNS ARE SPLICED AT THE DEPTHS SHOWN ABOVE. THE DAS CURVES ARE RELABELED. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09~ PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 GR DAS GAPI 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 SP DAS MV 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DAS LB 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DAS LB 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 MRES DAS OH~4M 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDAS DEGF 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 DEV DAS DEG 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 TNPH CNT PU-S 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN OPk4M 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09'~ PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) MINVSDN 0H~94 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 ~fNOR SDN OH~4~ 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 LLS DLL 0ItM~I6037522 O0 000 O0 0 1 1 1 4 68 0000000000 LLD DLL OHlCiM6037522 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS 6037522 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 5704.000 GR.DAS -999.250 SP.DAS -999.250 TENS.DAS 5145.000 TEND.DAS 1677.057 MRES.DAS -999.250 MTEM. DAS -999.250 DEV. DAS -999.250 CNTC. CNT -999.250 CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999.250 CRAT. CNT -999.250 NRAT. CNT -999.250 NPHI.CNT -999.250 TNPH. CNT -999.250 CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN -999.250 MSFL.SDN -999.250 MINV. SDN -999.250 MNOR.SDN -999.250 LLS.DLL -999.250 LLD.DLL -999.250 DT.DAS -999.250 DTSH. DAS -999.250 SCRA.DAS -999.250 DEPT. 4904.000 GR.DAS -999.250 SP.DAS -999.250 TENS.DAS -999 TEND.DAS -999.250 ~4~ES.DAS -999.250 MTEM. DAS -999.250 DEV. DAS -999 CNTC. CNT -999.250 CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999 CRAT. CNT -999.250 NRAT. CNT -999.250 NPHI.CNT -999.250 TNPH. CNT -999 CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN -999 MSFL.SDN -999.250 MINV. SDN -999.250 ~4NOR.SDN -999.250 LLS.DLL -999 LLD.DLL -999.250 DT.DAS 115.301 DTSH. DAS 222.555 SCRA.DAS -999 250 250 250 250 250 250 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE · 99/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verifi~a'tion Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:0~~j PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O. 1667 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH PEX 5724.5 HALS 5724.5 DSI 5724.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH .......... 4904.5 4904.5 4904.5 04-MAR-99 8Cl-205 1400 04-MAR-99 5752.0 5705.0 4908.0 5704.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GA~fi~A RAY DSI DIPOLE SONIC CNT COMPENSATED NUETRON DAS DENSITY HALS HIGH RES LATEROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): TOOL NUMBER ........... HGR DSST-B HCNT HRDD HALS-B 8.500 4990.0 LIS Tape Verifi~tion Listing Schlumberger Alaska Computing Center 12-MA~-1999 15:09 PAGE: LOGGERS CASING DEPTH (FT) : '4988.0 BOREHOLE CONDITIONS MUD TYPE: BARADRIL-N MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 47.0 MUD PH: 8.5 FLUID LOSS (C3): 3.6 MAXIMUM RECORDED TEMPERATURE (DEGF): 76.0 RESISTIVITY (OH~ff) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): O. 094 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 077 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 111 MUD CAKE AT (BHT) : 67.0 67.0 67.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MA TRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.5 REd. ARKS: Primary depth control using magnetic marks. Note depth reference is Nordic III's DF (elev = 110.92) Surface hole drilled by Doyon 19. Long tool string correction applied to HALS (ARIP_LTS) Speed correction is turned off due to high deviation in we Bridged at 5705' and logged up from there. Two tool turners ran on CNT for density/nuetron orientatio TVD log referenced to mean sea level. THIS FILE CONTAINS THE RAW DATA FOR THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 164 4 66 1 5 66 6 73 7 65 8 68 0.166 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09'~-j PAGE: TYPE REPR CODE VALUE .............................. 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ND?4B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DSI LB 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 SP PEX MV 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC PEX CPS 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC PEX CPS 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 TNRA PEX 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 GR DSI GAPI 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RTNR PEX 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT PEX CPS 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RCNT PEX CPS 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 DEVI DSI DEG 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HTEN DSI LB 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 MRES DSI OHY~4 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 MTEMDSI DEGF 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI PEX PU 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH PEX PU 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 NPOR PEX PU 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HCAL DSI IN 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 LLD HALS OH~E4 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 LLS HALS OH~4~ 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HRLD PEX OH~E46037522 O0 000 O0 0 2 1 1 4 68 0000000000 HRLS PEX OPE~4 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HDRA PEX G/C3 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 PEFZ PEX 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RHOZ PEX G/C3 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 Pk4IN PEX OH~4~ 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HMNO PEX OHNE4 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RXOZ PEX 0H~24 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RX08 PEX OH~ff46037522 O0 000 O0 0 2 1 1 4 68 0000000000 HCNT PEX CPS 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HCFT PEX CPS 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HGR PEX GAPI 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RHFT PEX CPS 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RHNT PEX CPS 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 DPHZ PEX PU 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HTNP PEX PU 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 HNPO PEX PU 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verifi~ation Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09''~ ~' PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DTCO DSI US/F 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 DTSM DSI US/F 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 PR DSI 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 RSHC DSI 6037522 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5724.492 TENS.DSI 1841.000 SP. PEX 0.000 CNTC. PEX CFTC. PEX 289.992 TNRA.PEX 6.787 GR.DSI 122.532 RTNR.PEX RCFT. PEX 284.615 RCNT.PEX 1860.879 DEVI.DSI -999.250 HTEN. DSI MRES.DSI 7.864 MTEM. DSI 73.694 NPHI.PEX 105.247 TNPH. PEX NPOR.PEX 220.160 HCAL.DSI 7.073 LLD.HALS 173.415 LLS.HALS HRLD.PEX 1784.879 HRLS.PEX 2936.455 HDRA.PEX -999.250 PEFZ.PEX RHOZ.PEX -999.250 ~IN. PEX 0.105 H~INO. PEX 0.138 RXOZ.PEX RXO8.PEX 0.491 HCNT. PEX 1914.541 HCFT. PEX 289.992 HGR.PEX RHFT. PEX 284.615 RHIVT. PEX 1860.879 DPHZ.PEX 60721.211 HTNP. PEX HNPO. PEX 220.160 DTCO.DSI -999.250 DTSM. DSI -999.250 PR.DSI RSHC.DSI -999.250 DEPT. CFTC. PEX RCFT. PEX MRES.DSI NPOR.PEX HRLD.PEX RHOZ.PEX RXO8.PEX RHFT. PEX HNPO. PEX RSHC.DSI 4904 658 249 179 239 250 7 864 51 727 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS.DSI 4108.875 SP. PEX 83.625 CNTC. PEX TNRA.PEX 4.204 GR.DSI 62.409 RTNR.PEX RCNT. PEX 1023.141 DEVI.DSI 59.387 HTEN. DSI MTE~.DSI 70.301 NPHI.PEX 55.585 TNPH. PEX HCAL.DSI -999.250 LLD.HALS -999.250 LLS.HALS HRLS.PEX -999.250 HiDRA.PEX -999.250 PEFZ.PEX HMIN. PEX -999.250 H~!NO.PEX -999.250 RXOZ.PEX HCNT. PEX -999.250 HCFT. PEX -999.250 HGR.PEX RHNT. PEX -999.250 DPHZ.PEX -999.250 HTNP. PEX DTCO.DSI -999.250 DTSM. DSI -999.250 PR.DSI 1914 7 113 223 25455 -999 0 122 223 -999 1041. 4. 1474. 51. -999. -999. -999. -999. -999. -999. 541 023 043 587 691 250 490 532 587 250 736 449 521 932 250 250 250 250 250 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION · O01CO1 DATE : 99/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION ~ O01CO1 DATE : 99/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW DSI PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 2 0.1667 RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~94ARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... DSI 5716.5 5482.0 $ LOG HEADER DATA DATE LOGGED: 04-MAR-99 SOFTWARE VERSION: 8Cl-205 TIME CIRCULATION ENDED: 1400 04-MAR-99 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 5752.0 TD LOGGER (FT) : 5705.0 TOP LOG INTERVAL (FT) : 4908.0 BOTTOM LOG INTERVAL (FT) : 5704. 0 LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER .................................... GR GA~ff~A RAY HGR DSI DIPOLE SONIC DSST-B CNT COMPENSATED NUETRON HCNT DAS DENSITY HRDD HALS HIGH RES LATEROLOG HALS-B $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 4990.0 4988.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09~j PAGE: 10 BOREHOLE CONDITIONS MUD TYPE: BARADRIL-N MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) : 47.0 MUD PH: 8.5 FLUID LOSS (C3): 3.6 MAXIMUM RECORDED TEMPERATURE (DEGF) : 76.0 RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.094 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 077 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 0.111 MUD CAKE AT (BHT): 67.0 67.0 67.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THE~ SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: Primary depth control using magnetic marks. Note depth reference is Nordic III's DF (elev = 110.92) Surface hole drilled by Doyon 19. Long tool string correction applied to HALS (ARIP_LTS) Speed correction is turned off due to high deviation in we Bridged at 5705' and logged up from there. Two tool turners ran on CNT for density/nuetron orientatio TVD log referenced to mean sea level. THIS FILE CONTAINS THE RAW DATA FOR THE DSI PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 108 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 9 LIS Tape Verifi~-aVtion Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09~ PAGE: 11 TYPE REPR CODE VALUE .............................. 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DSI LB 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 GR DSI GAPI 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR PEX 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT PEX CPS 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI DSI DEG 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 HTEN DSI LB 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 ~IRESDSI OH~4~ 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMDSI DEGF 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 HCNT PEX CPS 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 HCFT PEX CPS 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 HGR PEX GAPI 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 RHFT PEX CPS 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 RHNT PEX CPS 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 HTNP PEX PU 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 HNPO PEX PU 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 DTCO DSI US/F 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 DTSM DSI US/F 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 PR DSI 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 RSHC DSI 6037522 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. TNRA.PEX RCNT. PEX MTEM. DSI HCNT. PEX RHNT. PEX DTSM. DSI 5716. 509 -25 403 14 928 73 317 -18 260 14 928 238 875 TENS.DSI 950. 000 CNTC. PEX -18.260 CFTC. PEX GR.DSI 102.110 RTNR.PEX -26.288 RCFT. PEX DEVI.DSI -999. 250 HTEN. DSI 241. 951 I~ES.DSI NPHI.PEX -26.000 TNPH. PEX -999.250 NPOR.PEX HCFT. PEX 4.353 HGR.PEX 102.110 RHFT. PEX HTNP. PEX -999. 250 HNPO. PEX -999. 250 DTCO. DSI PR.DSI 0.365 RSHC.DSI 2.171 4. 353 29. 862 16. 085 -999. 250 29. 862 110. 052 LIS Tape Verifi~c~tion Listing Schlumberger Alaska Computing Center 12-MA~-1999 15:09'~ PAGE: 12 DEPT. TNRA.PEX RCNT. PEX MTEM. DSI HCNT. PEX RHNT. PEX DTSM. DSI 5482.009 -4 407 35 389 73 366 -999 250 -999 250 -999 250 TENS. D S I GR. DSI DEVI . DS I NPHI. PEX HCFT. PEX HTNP. PEX PR. DSI 3782.000 CNTC. PEX 65.354 RTNR.PEX 50.807 HTEN. DSI -9.537 TNPH. PEX -999.250 HGR.PEX -999.250 HNPO.PEX -999.250 RSHC.DSI -2.634 CFTC. PEX 0.610 RCFT. PEX 1129.616 MRES.DSI -999.250 NPOR.PEX -999.250 RHFT. PEX -999.250 DTCO.DSI -999.250 2 028 24 961 15 048 -999 250 -999 250 -999 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 99/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NTJMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: 0.1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... PEX 5731.5 HALS 5731.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH .......... 4906.0 4906.0 04 -MAR-99 8Cl -205 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09~-~ PAGE: 13 TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 1400 04-MAR-99 5752.0 5705.0 4908.0 5704.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY DSI DIPOLE SONIC CNT COMPENSATED NUETRON DAS DENSITY HALS HIGH RES LATEROLOG $ TOOL NUMBER ........... HGR DSST-B HCNT HRDD HALS - B BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 4990.0 4988.0 BOREHOLE CONDITIONS MUD TYPE: BARADRIL-N MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) '. 47.0 MUD PH: 8.5 FLUID LOSS (C3): 3.6 MAXIMUM RECORDED TEMPERATURE (DEGF) : 76.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) : O. 094 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 077 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 111 MUD CAKE AT (BHT): 67.0 67.0 67.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN) : TOOL STANDOFF (IN): 1.5 REMARKS: Primary depth control using magnetic marks. Note depth reference is Nordic III's DF (elev = 110.92) Surface hole drilled by Doyon 19. Long tool string correction applied to HALS (ARIP_LTS) Speed correction is turned off due to high deviation in we Bridged at 5705' and logged up from there. Two tool turners ran on CNTfor density/nuetron orientatio TVD log referenced to mean sea level. THIS FILE CONTAINS THE RAW REPEAT DATA. LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09'--~"' PAGE: 14 $ LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 148 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 TENS DSI LB 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 SP PEX MV 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC PEX CPS 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC PEX CPS 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA PEX 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 GR DSI GAPI 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 RTNR PEX 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT PEX CPS 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT PEX CPS 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 DEVI DSI DEG 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 HTEN DSI LB 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 MRES DSI 0H~I~6037522 O0 000 O0 0 4 1 1 4 68 0000000000 MTEMDSI DEGF 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI PEX PU 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH PEX PU 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 NPOR PEX PU 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 HCALDSI IN 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 LLD HALS OH~lq 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verifi~tion Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:09~ PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) LLS HALS 0I~4~ 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 HRLD PEX OHIZ~46037522 O0 000 O0 0 4 1 1 4 68 0000000000 HRLS PEX OH~ff46037522 O0 000 O0 0 4 1 1 4 68 0000000000 HDRA PEX G/C3 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 PEFZ PEX 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 RHOZ PEX G/C3 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 H~4IN PEX OIt~ff4 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 HNINO PEX OH~ff46037522 O0 000 O0 0 4 1 1 4 68 0000000000 RXOZ PEX OH~k4 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 RX08 PEX OH~ff46037522 O0 000 O0 0 4 1 1 4 68 0000000000 HCNT PEX CPS 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 HCFT PEX CPS 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 HGR PEX GAPI 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 RHFT PEX CPS 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 RHNT PEX CPS 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 DPHZ PEX PU 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 HTNP PEX PU 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 HNPO PEX PU 6037522 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 5731.509 TENS.DSI 1638.000 SP.PEX -40.000 CNTC. PEX CFTC. PEX 441.967 TNRA.PEX 3.292 GR.DSI 142.954 RTNR.PEX RCFT. PEX 420.158 RCNT. PEX 1380.332 DEVI.DSI -999.250 HTEN. DSI MRES.DSI 7.864 MTEM. DSI 73.718 NPHI.PEX 41.768 TNPH. PEX NPOR.PEX 36.825 HCAL.DSI 6.607 LLD.HALS 60000.000 LLS.HALS HRLD. PEX 45000.000 HRLS.PEX 53700.000 HDRA.PEX -999.250 PEFZ.PEX RHOZ.PEX -999.250 H~4IN. PEX 0.098 HdwAVO.PEX 0.128 RXOZ. PEX RXO8.PEX 0.403 HCNT. PEX 1411.384 HCFT. PEX 441.967 HGR.PEX RHFT. PEX 420.158 RHNT. PEX 1380.332 DPHZ.PEX 60721.211 HTNP. PEX HNPO. PEX 36.825 DEPT. 4906.175 TENS.DSI 4236.996 SP. PEX 14.563 CNTC. PEX CFTC. PEX 268.386 TNRA.PEX 3.744 GR.DSI 65.695 RTNR.PEX RCFT. PEX 253.281 RCNT. PEX 1005.836 DEVI.DSI 59.339 HTEN. DSI MRES.DSI 7.864 MTEM.DSI 70.690 NPHI.PEX 47.303 TNPH. PEX NPOR.PEX 44.085 HCAL.DSI -999.250 LLD.HALS -999.250 LLS.HALS HRLD. PEX -999.250 HRLS. PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX RHOZ.PEX -999.250 IE4IN. PEX -999.250 I~viNO.PEX -999.250 RXOZ.PEX RXO8.PEX -999.250 HCNT. PEX -999.250 HCFT. PEX -999.250 HGR.PEX RHFT. PEX -999.250 RHNT. PEX -999.250 DPHZ.PEX -999.250 HTNP. PEX HNPO.PEX -999.250 1411.384 3.406 34.665 37.864 60000.000 -999.250 0.401 142.954 37.864 1029.357 4.334 1496.996 44.207 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verif~i~tion Listing Schlumberger Alaska Computing Center 12-MAR-1999 15:0~~ PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT . 004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 99/03/12 ORIGIN : FLIC TAPE NAME : 99125 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : ARCO ALASKA, 2T-220, KUPARUK, API #50-103-20283-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/12 ORIGIN · FLIC REEL NAME : 99125 CONTINUATION # : PREVIOUS REEL : COf~MENT : ARCO ALASKA, 2T-220, KUPARUK, API #50-103-20283-00
