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Home My WebLink About205-197Pull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations Alter CasingOther StimulatePerforateInstall WhipstockPerformed: Coiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift ExploratoryDevelopment 6. API Number:ServiceStratigraphic 8. Well Name and Number:7. Property Designation (Lease Number): 10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071): 11. Present Well Condition Summary: measuredTotal Depth 7525'feet None feet feetNonefeet3102'true vertical measuredEffective Depth 4496'feet 4532', 5583'feet feet2699', 3003'feet2688'true vertical Measured depthPerforation depth True Vertical depth 2744' TVD4667' MDL-804-1/2"Tubing (size, grade, measured and true vertical depth) 4532' MDPackers and SSSV (type, measured and true vertical depth) 5583' MD N/A 2699' TVD 3003' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/ATreatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 15. Well Class after work: StratigraphicServiceExploratory DevelopmentDaily Report of Well Operations WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run SPLUGSUSPGINJGSTORElectronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: Authorized Name and Contact Name:Digital Signature with Date: Contact Email: Contact Phone:Authorized Title: N/A Sr Res Eng:Sr Pet Geo:Sr Pet Eng: WINJ WAG 77 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Viking ESP Packer Packer: Baker SC-1R Liner Top Packer SSSV: None Adam Becia adam.c.becia@conocophillips.com (907) 265-6007Production Engineer 5654-5737', 5991-6033', 6035-6657', 6704-6746', 6748-7371', 7373-7415' 3017-3035', 3090-3094', 3095-3115', 3116-3116', 3116-3109', 3109-3107' measured true vertical Packer Representative Daily Average Production or Injection Data Tubing PressureCasing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 547 Gas-Mcf MD 240 Size 108' 9833361909 256455 6376 296 measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-197 50-103-20520-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025548, ADL0025569 Kuparuk River Field/ Tabasco Oil Pool KRU 2T-203 Plugs measuredJunk Length Production Liner 6018' 1901' Casing 3097' 4-1/2" 6046' 3104'7484' 1579' 108'Conductor Surface Intermediate 16" 10-3/4" 77' 1546'1610' CollapseBurst Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022 Operations shutdown Change Approved Progra Other: Convert ESP to GL 13b. Pools active after work: Tabasco Oil Pool DTTMSTART JOBTYP SUMMARYOPS 8/20/2023 SUPPORT OTHER OPERATIONS SET 3.77''CATCHER W/BELL G.2''RS(OAL59'')@4536'RKB,REPLACED ST #1@2193'RKB W/1'' DMY VLV/BK LATCH,REPLACED ST#2 @4464'RKB W/1''SOV(2000#TBG SHEAR)BK LATCH, LRS PERFORM 1000PSI MIT-T(PASS).IN PROGRESS 8/21/2023 SUPPORT OTHER OPERATIONS PULLED BALL & ROD FROM 4536'RKB,PULLED 3.81'' RHC PLUG BODY @4545'RKB,MEASURED BHP @4607'RKB,SET SUMMIT ESP SF5800 PUMP @4625'RKB. IN PROGRESS ***SBHP 1210 PSI *** 8/22/2023 SUPPORT OTHER OPERATIONS SET 4.5'' PACKOFF (OAL 61'') @ 4562'SLM / 4588 'RKB, SET 4.5'' TUBING STOP (OAL 21'') @ 4558' SLM / 4584' RKB Complete. 9/14/2023 REPAIR WELL SHAKE OFF 3.77'' CATCHER (OAL 38'') @ 2940' RKB. IN PROGRESS 9/15/2023 REPAIR WELL PULLED 1'' SOV FROM ST#2 @ 4464' RKB, DISPLACED TBG W/DIESEL, SET 1'' OV (5/16''PORT) BK LATCH IN ST#2 @ 4464' RKB, PULLED 3.77'' CATCHER @ 4585' RKB, PULLED TBG STOP @ 4585' RKB, ATTEMPTED TO PULL PACKOFF. JOB IN PROGRESS 9/16/2023 REPAIR WELL PULLED PACKOFF @ 4579' RKB, PULLED ESP PUMP TO DB NIPPLE @ 4546' RKB. JOB IN PROGRESS 9/17/2023 REPAIR WELL PULLED SUMMIT ESP PUMP FROM DB NIPPLE @ 4546' RKB, OBTAINED PASSING 1500 PSI PRESSURE TEST . JOB COMPLETE 2T-203 Convert to GL Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: 4,496.0 2T-203 9/4/2007 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull SOV & ESP equipment, set OV - GL conversion 2T-203 9/17/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: ZONES NOT LOADED INTO WELLVIEW 12/9/2010 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.79 30.8 1,609.8 1,546.2 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 28.2 6,046.1 3,096.9 29.70 L-80 BTCM LINER 4 1/2 3.96 5,582.6 7,484.0 3,103.7 12.60 13 CR VAM Tubing Strings: Top (ftKB) 25.3 Set Dept 4,667.0 Set Dept 2,743.6 OD Nom Max 10.85 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Thread HYD563 ID Nom Min (in) 2.06 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,191.3 1,940.8 62.01 Mandrel GAS LIFT 6.403 4 1/2" x 1" KBMG, GLM Camco KBMG 3.865 4,399.8 2,657.4 71.66 Sensor - Discharge Gauge 6.039 4 1/2" 12.6 ppf OPSIS Dual Sensor, Hyd 563 BxP HES OPSIS 3.913 4,464.1 2,677.7 71.58 Mandrel GAS LIFT 6.350 4 1/2" x 1" KBMG, GLM Camco KBMG 3.865 4,531.6 2,699.3 71.07 PACKER 6.875 7 5/8" x 4 1/2" Viking ESP Packer, 5K PSI W.P. Viking 12ESP 3.898 4,545.8 2,703.9 70.96 Nipple - DB 5.210 4 1/2" x 3.813" DB-6' Nipple Camco DB-6 3.813 4,553.5 2,706.4 70.91 Sensor - Discharge Gauge 5.620 4 1/2" Vigilant Discharge Pressure Tubing Sub Summit Vigilant Sensor 3.958 4,615.1 2,726.6 70.89 Annular Connection Port (ACP) 5.380 TCC Perforated Intake Summit TCC Perforat ed Intake 3.958 4,625.8 2,730.1 70.89 Seal - Protector 5.250 Upper 513 Series Tandem Seal Section Summit 513 Series 3.630 4,643.7 2,735.9 70.90 Motor 5.620 562 Sieries Motor, KMS2, 180HP/2290V/48A Summit 562 Motor, 180 HP 3.630 4,664.0 2,742.6 70.81 Motor - Adapter 4.560 Adapter, Gauge to 562 Motor Summit Adapter 2.060 4,664.3 2,742.7 70.81 Sensor - Discharge Gauge 3.750 Vigilant, Sensor, High Temp, 150C w/ Discharge Pressure 5000 psi Summit Vigilant Sensor 2.560 4,666.2 2,743.3 70.80 Centralizer 6.000 Centralizer, 2 3/8", EUE, 7" Casing, 6" OD Summit Centraliz er Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,191.3 1,940.8 62.01 1 DMY BK 1 8/21/2023 SLB KBMG 4,464.1 2,677.7 71.58 2 GAS LIFT OV BK 1 9/15/2023 SLB KBMG 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,582.6 3,003.3 78.45 PACKER 6.690 BAKER SC-1R Liner Top Packer BAKER SC-1R 76A4-40 4.000 5,586.8 3,004.2 78.57 MILLOUT 5.500 MILLOUT EXTENSION 3.958 5,592.4 3,005.2 78.72 XO THREAD 6.050 3.958 5,603.6 3,007.4 78.88 KOIV TOOL 5.000 3.500 5,606.1 3,007.9 78.85 KOIV 5.000 3.500 7,475.9 3,104.1 93.08 Flapper VLV 1 5.520 3.000 7,477.3 3,104.0 93.08 Flapper VLV 2 5.520 3.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,654.0 5,737.0 3,017.4 3,034.6 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 5,991.0 6,033.0 3,086.9 3,094.5 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,035.0 6,657.0 3,094.9 3,114.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,704.0 6,746.0 3,115.7 3,116.4 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,748.0 7,371.0 3,116.4 3,108.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 7,373.0 7,415.0 3,108.6 3,107.0 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores DEVIATED, 2T-203, 10/2/2023 6:06:08 PM Vertical schematic (actual) LINER; 5,582.6-7,484.0 SLOTS; 7,373.0-7,415.0 SLOTS; 6,748.0-7,371.0 SLOTS; 6,704.0-6,746.0 SLOTS; 6,035.0-6,657.0 PRODUCTION; 28.2-6,046.1 SLOTS; 5,991.0-6,033.0 SLOTS; 5,654.0-5,737.0 Motor; 4,643.7 Seal - Protector; 4,625.8 Annular Connection Port (ACP); 4,615.0 Nipple - DB; 4,545.8 PACKER; 4,531.6 Mandrel GAS LIFT; 4,464.1 Sensor - Discharge Gauge; 4,399.8 Mandrel GAS LIFT; 2,191.3 SURFACE; 30.8-1,609.8 CONDUCTOR; 31.0-108.0 Tubing hanger; 25.3 KUP PROD KB-Grd (ft) 33.99 RR Date 2/25/2006 Other Elev 2T-203 ... TD Act Btm (ftKB) 7,525.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032052000 Wellbore Status PROD Max Angle & MD Incl (°) 93.24 MD (ftKB) 7,282.91 WELLNAME WELLBORE Annotation Last WO: End Date 8/11/2023 H2S (ppm) 53 Date 12/9/2022 Comment SSSV: NONE 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7525'feet None feet true vertical 3102' feet None feet Effective Depth measured 7484'feet 4532', 5583'feet true vertical 3104' feet 2699', 3003'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4667' 2744' Packers and SSSV (type, measured and true vertical depth)4532' 5583' 2699' 3003' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Tabasco Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 323-299 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Viking ESP Packer: Baker SC-1R SSSV: None Adam Klem Adam Klem@conocophillips.com (907) 263-4529Staff RWO/CTD Engineer 5654-5737', 5991-6033', 6035-6657', 6704'-6746', 6748-7371', 7373-7415' 3017-3035', 3087-3095', 3095-3115', 3116-3116', 3116-3109', 3109-3107' 4-1/2"1901' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) *Has not popped yet Gas-Mcf MDSize 108' Shut In measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-197 50-103-20520-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025569, ADL0025548 Kuparuk River Field/ Tabasco Oil Pool KRU 2T-203 Plugs Junk measured Length Production Liner 6018' Casing 3097'6046' 7484' 3104' 1579' 108'Conductor Surface 16" 10-3/4" 77' 1610' 1546' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Page 1/8 2T-203 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/1/2023 12:00 8/2/2023 00:00 12.00 MIRU, MOVE MOB P Pickup berm. Move high line trailer. Back rig off 2K-07. Stage in middle of pad. Pickup rig mats and clean up area. Begin Nordic 3 rig move from 2K-Pad to 2H-Pad. Rig fell through on 2H-Pad. 2 Hours getting rig un-stuck. Staged Rig on 2H-Pad to swap out mud cross on BOP stack while rig mats are shuffle from 2K-Pad to 3A-Pad. 8/2/2023 00:00 8/2/2023 16:00 16.00 MIRU, MOVE MOB P Shuffle Rig Mats from 2K-Pad to 2A-Pad 8/2/2023 16:00 8/2/2023 19:00 3.00 MIRU, MOVE MOB P Move Rig from 2H-Pad to 2A-Pad. 8/2/2023 19:00 8/3/2023 00:00 5.00 MIRU, MOVE MOB P Shuffle Rig Mats from 2H-Pad to 2A- Pad to 2T-Pad. Move Rig Office from 2K-Pad to 2T-Pad. 8/3/2023 00:00 8/3/2023 12:00 12.00 MIRU, MOVE MOB P Pickup mats from 2H to 4-corners. Shuffle rig mats from 2A to 2T Pad. Nordic crew set cellar pit liner, T-Mats around cellar, and rig mats in front of well. Setup office comms. 8/3/2023 12:00 8/4/2023 00:00 12.00 MIRU, MOVE MOB P Continue to lay mats from 2A to 2T. 8/4/2023 00:00 8/4/2023 04:00 4.00 MIRU, MOVE MOB P Continue to lay mats from 2A to 2T. 8/4/2023 04:00 8/4/2023 05:30 1.50 MIRU, MOVE MOB P Moving Rig from 2A-Pad to 2T-Pad 8/4/2023 05:30 8/4/2023 12:30 7.00 MIRU, MOVE RURD P Finish laying rig mats. Spot in and level rig over the well. RU circ manifold hoses, choke and kill lines to tree for well kill. Berm in cellar. Unload and stage HES TEC Wire spoolers. 8/4/2023 12:30 8/4/2023 20:00 7.50 MIRU, MOVE RURD P Level pad for cuttings tank. Spot cuttings tank. Stage 400 bbl upright tank for filtered brine storage. Load upright w/ first load of 290 bbl 9.8# filtered brine. Gather initial pressures: T/IA/OA = 240 / 240 / 100 psi. Unload and stage GBR Powertongs. Lay pit liner, spot open top tank, berm in. Spot Tiger Tank. RU hardline. Spot Highline Trailer. NES Vac Truck onsite to load 290 bbls brine from upright. LRS onsite to heat up first load of 9.8# brine to 140 deg F. 8/4/2023 20:00 8/4/2023 21:30 1.50 MIRU, WELCTL COND P Rig accept @ 20:00 hrs. Load 50 bbls to Pits to mix Deep Clean Pill. 8/4/2023 21:30 8/4/2023 22:00 0.50 MIRU, WELCTL PRTS P PT Surface lines to tanks manifold. 8/4/2023 22:00 8/5/2023 00:00 2.00 MIRU, WELCTL COND P LRS heating 2nd load of filtered 9.8# brine to 140 deg F. 8/5/2023 00:00 8/5/2023 00:45 0.75 MIRU, WELCTL COND P LRS completed heating fluid. 8/5/2023 00:45 8/5/2023 01:00 0.25 MIRU, WELCTL SFTY P PJSM for circulating Hot Diesel. 8/5/2023 01:00 8/5/2023 01:30 0.50 MIRU, WELCTL RURD P MIRU LRS to Well. 8/5/2023 01:30 8/5/2023 02:00 0.50 MIRU, WELCTL KLWL P Online with LRS pumping Hot Diesel down TBG taking returns up the IA at 1.5 BPM, 350 PSI on TBG, 130 on the choke manifold. Pumped 50 bbls total. 8/5/2023 02:00 8/5/2023 02:15 0.25 MIRU, WELCTL RURD P RDMO LRS. Rig: NORDIC 3 RIG RELEASE DATE 8/11/2023 Page 2/8 2T-203 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/5/2023 02:15 8/5/2023 03:30 1.25 MIRU, WELCTL KLWL P Chase Hot Diesel with 55 bbls of Deep Clean pill 3 bpm, 175 psi. Switch over to 180* degree 9.8 PPG Brine at 4 bpm, 200 psi, Tubing pressure went to 10 psi after 350 bbls total pumped, 0 PSI on the choke.. Continue pumping at 4.5 BPM. 8/5/2023 03:30 8/5/2023 04:15 0.75 MIRU, WELCTL OWFF P Total Pumped. 290 bbls of 180* degree 9.8 PPG Brine, 50 bbls of 180* degree diesel, 55 bbls of Deep Clean Pill. Pumped a total 375 bbls down the TBG and 265 bbls returned to tanks. Well on a vac. No flow, No pressure. Feed IA with 10 bbls of 9.8 PPG Brine every 30 mins. 8/5/2023 04:15 8/5/2023 05:30 1.25 MIRU, WELCTL RURD P RD Circulating Iron to the Tubing. 8/5/2023 05:30 8/5/2023 06:00 0.50 MIRU, WELCTL MPSP P Install Type 'H' BPV and PT Same. Attempt rolling test from below to 1,000 psi. Pumped 30 bbls 9.8# brine. Achieved 45 psi. 8/5/2023 06:00 8/5/2023 06:30 0.50 MIRU, WHDBOP OWFF P Perform 30 minute NFT to verify. 8/5/2023 06:30 8/5/2023 14:30 8.00 MIRU, WHDBOP NUND P ND and Hang Tree in cellar. Call out HES to disconnect and cap DH gauge wellhead connection. ND Tubing Head Adapter. Inspect hanger neck threads. Good condition. Install HP BPV test dart. Attempt to NU BOP stack. HES TEC wire cap too tall. Bent TEC wire cap on bottom BOP flange. Replaced SwageLock fitting with shorter cap. NU BOP's. Fix hydaulic leak in BOP crane hyd. hose. Highline onsite to rig up power to office and rig. Crane on location. Load HES Tec Wire Hydraulic Spooler for pull. Load Baker ESP Cable spooler and empty spool. Very tight fit through ceiling hatch. Cont. to pump 10 bbls of 9.8# brine down IA every 30 minutes. 8/5/2023 14:30 8/5/2023 21:00 6.50 MIRU, WHDBOP RURD P RU Choke and Kill lines. Install Riser. RU HYD Hoses. Function Test BOP Rams and Chokes. 8/5/2023 21:00 8/6/2023 00:00 3.00 MIRU, WHDBOP BOPE P Fill Stack. Perform Initial BOP shell test 250/2500. Rig: NORDIC 3 RIG RELEASE DATE 8/11/2023 Page 3/8 2T-203 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/6/2023 00:00 8/6/2023 04:15 4.25 MIRU, WHDBOP BOPE P Completed Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular w/ 3 ½ TJ, tested UVBR's w/ 3 ½ TJ LVBR's w/3 1/2", tested UVPRs and LVPR'S w/ 4.5" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 4 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2000 PSI and demonstrate bleed off. Conduct Accumulator Draw Down Test. Initial pressure=3050 PSI, after closure=1625 PSI, 200 PSI attained =19 sec, full recovery attained =125 sec. UVBR's= 4 sec, Annular= 15 sec. Simulated blinds= 5 sec. Simulated LPR's= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Kam StJohn. Had Failed / Pass on Choke HCR Valve. 8/6/2023 04:15 8/6/2023 04:30 0.25 MIRU, WHDBOP BOPE T HCR choke failed initial test. Greased and functioned. Passed retest. 8/6/2023 04:30 8/6/2023 05:30 1.00 COMPZN, RPCOMP RURD P Rig down Testing Equipment. L/D Test Joints.Drain BOP Stack. 8/6/2023 05:30 8/6/2023 06:30 1.00 COMPZN, RPCOMP MPSP P Pull Test Plug and Type 'H' BPV. 8/6/2023 06:30 8/6/2023 09:00 2.50 COMPZN, RPCOMP PULL P Load and MU ESP Cable Sheave. Pick up Landing Joint and MU same to Hanger. Set 10K down and BOLDS. Unseat Hanger @ 115K. Pull hanger to rig floor @ 90K. 4,650.0 4,620.0 8/6/2023 09:00 8/6/2023 09:30 0.50 COMPZN, RPCOMP CIRC P Pump 75 bbls of 9.7# filtered brine down Tubing lined up to take returns to active system. Cont. to pump 10 bbls of 9.7# filtered brine down IA every 30 minutes. Briefly established returns (<10 bbls to cuttings tank) then fluid level dropped. 4,620.0 4,620.0 8/6/2023 09:30 8/6/2023 10:00 0.50 COMPZN, RPCOMP OWFF P OWFF. Blow down Top Drive. Remove 1st clamp below hanger. Cut TEC Wire and ESP cable. Function test TEC Wire spooler and ESP cable spooler. 4,620.0 4,620.0 8/6/2023 10:00 8/6/2023 13:45 3.75 COMPZN, RPCOMP PULL P Pull ESP cable over sheave and attach to ESP cable spooler. Start POOH laying down 4.5" ESP completion from 4,620'. 4,620.0 3,616.0 8/6/2023 13:45 8/6/2023 14:15 0.50 COMPZN, RPCOMP CIRC P Pump 71 bbl Tubing volume of fluid to maintain fluid column and mitigate gas migration. Unable to establish returns. 3,616.0 3,616.0 8/6/2023 14:15 8/6/2023 19:00 4.75 COMPZN, RPCOMP PULL P Cont. to pull 4 1/2" ESP completions from 3,616' to 211'. Pumping 150% hole fill plus 10 bbls every 30 minutes to maintain fluid column. 3,616.0 211.0 8/6/2023 19:00 8/6/2023 20:00 1.00 COMPZN, RPCOMP PULD P L/D ESP Gauge and ESP Components. Recovered 111 Cannon Clamps, 2 Bands, 8 Half Clamp and 1 Motor Clamp. 211.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/11/2023 Page 4/8 2T-203 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/6/2023 20:00 8/6/2023 21:00 1.00 COMPZN, RPCOMP CLEN P Secure Cable to Spooler. Secure Tec- Wire to Spooler. Clean & Clear Rig Floor. 0.0 0.0 8/6/2023 21:00 8/6/2023 22:15 1.25 COMPZN, RPCOMP PULD P Change out Handling Equipment. Load YellowJacket tool in pipe shed. 0.0 0.0 8/6/2023 22:15 8/7/2023 00:00 1.75 COMPZN, RPCOMP BHAH P PU / MU BHA #1. 6-3/4" Mill Bit, Boot Baskets X2, 6-3/4" String Mill, String Magnet and Oil Jars. 0.0 54.0 8/7/2023 00:00 8/7/2023 08:00 8.00 COMPZN, RPCOMP TRIP P Single in BHA #1 (7 5/8" casing cleanout) on 3 1/2" Drill Pipe. PUW = 101K. SOW = 49K. Set 10K @ 5,533'. Attempt to wash down to liner top packer @ 5,582' @ 3 BPM. Repeat hard tag @ 5,533'. Crane on location. Pick old ESP cable reel off rig floor. Set HES TEC wire air spooler, GBR Power Tongs, and new ESP cable on rig floor. 54.0 5,533.0 8/7/2023 08:00 8/7/2023 10:30 2.50 COMPZN, RPCOMP CIRC P Circulate 9.7# brine STS. Good returns. Measure 9.7# returns density. Acting like we've plugged up at the liner top. Crane on location. Pick old ESP cable reel off rig floor. Set HES TEC wire air spooler, GBR Power Tongs, and new ESP cable on rig floor. 5,533.0 5,520.0 8/7/2023 10:30 8/7/2023 11:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes. 5,520.0 5,520.0 8/7/2023 11:00 8/7/2023 13:15 2.25 COMPZN, RPCOMP WASH P TIH to tag @ 5,533'. Bring pumps online at 6 BPM and attempt to wash through debris. Make multiple attempts to wash through w/o rotation. Unsuccessful. TIH and lightly tag top of fill @ 6 BPM (1,327 psi) and 30 RPM. Free Torque = 4.5K. Set 2K down and began pushing debris, washing down. Moved to 5,534' and went on losses. No returns. Lowered pump rate to 3 BPM. Stopped rotating. Cont. wash down to 5,551'. Set down 7K. PUH to 5,547'. Obtain parameters. 30 RPM. 3 BPM @ 200 psi. 4K Torque. PUW = 100K. SOW = 65K. TIH and work debris down to 5,576'. Set down 5K. Repeat tag and set down w/o rotation. Attempt to wash further without success. Original Tally shows liner top @ 5,582'. 5,520.0 5,576.0 8/7/2023 13:15 8/7/2023 14:30 1.25 COMPZN, RPCOMP TRIP P TOOH to 4,501'. 5,576.0 4,501.0 8/7/2023 14:30 8/7/2023 15:30 1.00 COMPZN, RPCOMP REAM P Obtain Parameters. Work String Mill across packer set interval from 4,501' - 4,591. 35 RPM. 6 BPM @ 1,100 psi. 4,501.0 4,595.0 8/7/2023 15:30 8/7/2023 16:00 0.50 COMPZN, RPCOMP SVRG P Rig Service. Top Drive compensator hose failed. Repair and Reroute 4,595.0 4,595.0 8/7/2023 16:00 8/7/2023 16:45 0.75 COMPZN, RPCOMP REAM P Cont. to work string mills across packer set interval from 4,595' - 4,415'. 35 RPM. 6 BPM @ 1,100 psi. 4,595.0 4,415.0 8/7/2023 16:45 8/7/2023 17:45 1.00 COMPZN, RPCOMP CIRC P Circulate BU. 4,415.0 4,415.0 8/7/2023 17:45 8/7/2023 20:00 2.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #1 (7 5/8" casing cleanout) from 4,550' to 54'. 4,415.0 54.0 8/7/2023 20:00 8/7/2023 21:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #1. Rcovered 2 gallons of Paraffin & Scale from lower boot and Metal in the Upper boot basket. 54.0 0.0 8/7/2023 21:00 8/7/2023 21:30 0.50 COMPZN, RPCOMP BHAH P Load and M/U BHA #2 (4 1/2" Liner Top Cleanout). 0.0 88.0 Rig: NORDIC 3 RIG RELEASE DATE 8/11/2023 Page 5/8 2T-203 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/7/2023 21:30 8/8/2023 00:00 2.50 COMPZN, RPCOMP TRIP P TIH w/ BHA #2 88.0 5,553.0 8/8/2023 00:00 8/8/2023 00:15 0.25 COMPZN, RPCOMP TRIP P TIH to Tag Depth at 5576'. 5,553.0 5,576.0 8/8/2023 00:15 8/8/2023 01:15 1.00 COMPZN, RPCOMP CIRC P Tagged Obstruction @ 5576 Cleanout 10 into Liner Top Packer to 5586. Washed across Liner top x3. PUH to 5565 and shut annular. Pump at 1 bpm, 60 psi, pumped @ 2 bpm, 140 psi. pumped at 385 psi. Well on vac. 5,576.0 5,586.0 8/8/2023 01:15 8/8/2023 04:00 2.75 COMPZN, RPCOMP TRIP P Blow down Top Drive. TOOH w/ BHA #2 (7 5/8" casing cleanout) from 5,586' to 88'. 5,586.0 88.0 8/8/2023 04:00 8/8/2023 05:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #2. Clean & Inspect Boot Baskets. Boot Baskets were clean. 88.0 0.0 8/8/2023 05:00 8/8/2023 05:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #3. Test Packer. 0.0 15.0 8/8/2023 05:30 8/8/2023 08:45 3.25 COMPZN, RPCOMP TRIP P TIH w/BHA #3 15.0 4,549.0 8/8/2023 08:45 8/8/2023 11:45 3.00 COMPZN, RPCOMP PRTS P Set Test Packer @ 4,540' mid element. PT to 2,500 psi. Charted. Initial test failed. Likely due to air in system and wellbore (previously on a vac). Bumped pressure back up. Extended test. Double blocked at Kill, Mud Manifold, and Choke Manifold. Passed. Initial 2,700 psi. 15 min = 2,660 psi 30 min = 2640 psi. 4,549.0 4,549.0 8/8/2023 11:45 8/8/2023 12:15 0.50 COMPZN, RPCOMP TRIP P TIH to 5,479' to run last stands in derrick. 4,549.0 5,479.0 8/8/2023 12:15 8/8/2023 18:15 6.00 COMPZN, RPCOMP TRIP P Top Drive maintenance. Lower Grabber not functioning. Rotate and continue to TOOH. TOOH laying down 3 1/2" DP from 5,479' to surface. 5,479.0 15.0 8/8/2023 18:15 8/8/2023 19:15 1.00 COMPZN, RPCOMP BHAH P L/D BHA #3 (Test Packer) 15.0 0.0 8/8/2023 19:15 8/8/2023 23:45 4.50 COMPZN, RPCOMP PULD P Clear and Clean rig floor. Load completions equipment to pipe shed and rig floor. Load Lower ESP section. Centralizer, Sensor, Motor, Seal Sections, TCC Perforated intake to pipe shed. Load Tec-Wire. RU Handling Equipment. RU Eckel for 4-1/2" TBG. RU Torque Turn Equipment. 0.0 0.0 8/8/2023 23:45 8/9/2023 00:00 0.25 COMPZN, RPCOMP PUTB P PU/MU Lower ESP section. Centralizer, Sensor, Motor, Seal Sections, TCC Perforated intake. Feed new ESP cable through sheave and install in derrick. Install cable and secure. Install discharge gauge unit sub. Splice new ESP cable to Lead Cable on motor. 0.0 105.0 8/9/2023 00:00 8/9/2023 03:45 3.75 COMPZN, RPCOMP PUTB P Continue to Splice new ESP cable to Lead Cable on motor, Vigilant Temp, PSI Sensor, Tandem Seal Section, TCC Perforated Intake. Fill Section of Motor with Mineral Oil while lowering in hole. 105.0 105.0 8/9/2023 03:45 8/9/2023 10:15 6.50 COMPZN, RPCOMP PUTB P MU Vigilant Discharge PSI Sub, Adapter Sub, DB Nipple, Viking ESP Packer. Make ESP Splice through ESP Packer. 105.0 105.0 8/9/2023 10:15 8/9/2023 11:45 1.50 COMPZN, RPCOMP PUTB P TIH w/ 4.5", 12.6#, L-80 Hyd 563 ESP completions T/ 253'. 105.0 253.0 Rig: NORDIC 3 RIG RELEASE DATE 8/11/2023 Page 6/8 2T-203 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/9/2023 11:45 8/9/2023 13:30 1.75 COMPZN, RPCOMP PUTB P Noticed drag w/ TIH before picking up HES OPSIS gauge. TOOH to investigate. Feel dragging coming out of hole. See clamps and couplings with drag marks on both sides. Inspect Viking Packer for drag marks. Noticed drag marks on both packer body and ESP splice clamp above packer. Equivalent OD from Packer to Clamps measure to 6.9375". Drift of 7 5/8" 29.6# is 6.75". Reconfigure ESP splice clamp. Replace with 2 each stainless steel super bands.above and below packer. 253.0 105.0 8/9/2023 13:30 8/10/2023 00:00 10.50 COMPZN, RPCOMP PUTB P TIH w/ 4.5", 12.6#, L-80 Hyd 563 ESP completion F/ 105' T/ 4001', SOW=54K. 4 1/2" Hyd 563 torque turned T/ 3800 Ft/Lbs. Best O Life AG dope used. Summit noticed slight damage to ESP cable sheath. Inspect. Confirm electrical connection still good. Perform armor repair @ 185. PU/MU HES OPSIS DHG and TEC Wire. PT gauge wire @ 276' T/ 10000 PSI for 10 Mn. Good PSI gauge #1=15.18, Temp 61.38*. PSI gauge #2=15.64. Temp=61.62*. Cont. TIH w/ 4.5" Hyd 563 ESP Completions, installing cross collar clamp on every connection. Checking ESP cable every 1000'. @ 4001' Check sensor. Meg insulation test and OHMS readings - all within specs. Check gauge wire integrity every 1000'. PSI gauge #1=1045.93. Temp 63.80*. PSI gauge #2=1046.27. Temp 63.69*. 105.0 4,001.0 8/10/2023 00:00 8/10/2023 02:00 2.00 COMPZN, RPCOMP PUTB P Cont RIH w/ 4 1/2" ESP completion. Make up space out pumps. Make up last full joint of Hyd 563. Make up XO pup to hanger T/ 4633' PUW=107K, SOW=54K. Total of 118 cross collar clamps. 1 Upper GLM clamp. 1 Lower GLM clamp. 2 Mid joint dule channel clamps. 6 Mid joint single channel clamps. 4 Motor clamps. 4 Seal clamps. 4 stainless steel supper bands (2 below tubing hanger, 2 at Viking packer that replaced Splice clamp) 4,001.0 4,633.0 8/10/2023 02:00 8/10/2023 02:30 0.50 COMPZN, RPCOMP PULD P Pick up landing joint. Make up to hanger. Make up hanger to string. Torque hanger to align locking pin with wellhead alignment pin profile. 4,633.0 4,633.0 8/10/2023 02:30 8/10/2023 07:45 5.25 COMPZN, RPCOMP RURD P Terminate ESP cable and Opsis gauge Tec wire through hanger. Install dummy penetrator. Finish pumping 80 Bbls CI brine down chased w/ 50 Bbls 9.7 PPG brine. Allowing formation to drink fluid. Check ESP cable. Check sensor. Meg insulation test and OHMS readings - all within specs. Good test. Check TEC wire signal and comms. Good. 4,633.0 4,633.0 Rig: NORDIC 3 RIG RELEASE DATE 8/11/2023 Page 7/8 2T-203 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/10/2023 07:45 8/10/2023 09:45 2.00 COMPZN, RPCOMP PULD P TIH and Land Tubing Hanger. Check cable and TEC wire electrical integrity, On 1st attempt did not fully engage. PU 6". Troubleshoot. Rotate approx. 2 deg to the right to align w/ side outlet. Fully aligned but still would not fully seat. Approx. 1.5" off seat. Screw in Top Drive. Set 5K down and seals slid in. RILDS. HES TEC Wire: Gauge 1: 1,150 psi and 64.3 deg F. Gauge 2: 1,151 psi and 64.3 deg F. Summit ESP Readings: Intake Temp = 66.9 deg F. Intake Press = 1,011 psi. Motor Temp = 65.7 deg F, Discharge Press = 1,011 psi. Phase to Phase OHMS = 5.6. Phase to Ground GOHMS = 2.15. 4,633.0 4,666.0 8/10/2023 09:45 8/10/2023 11:00 1.25 COMPZN, RPCOMP RURD P Unscrew Top Drive from Landing Joint. Drop Ball and Rod. Clean and clear rig floor. GBR made up head pin to top of landing joint using Power Tongs. R/U PT manifold to Tubing and IA with isolation valves (used pictures). Flood lines and prepare to set Viking packer. 4,666.0 4,666.0 8/10/2023 11:00 8/10/2023 11:30 0.50 COMPZN, RPCOMP PACK P Set Viking Packer. Sheared @ 1,700 psi. Held 4,000 psi for 5 minutes to fully set. Bleed off and prep for Tubing and IA pressure tests. 4,666.0 4,666.0 8/10/2023 11:30 8/10/2023 13:30 2.00 COMPZN, RPCOMP PRTS P PT Tubing to 3,000 psi. Hold for 30 minutes. Chart. Initial = 3100 psi. 15 min = 3050 psi. 30 min = 3035 psi. Pass. Bleed Tubing to 1,500 psi and block in. PT IA to 2,500 psi w/ 1,500 psi on Tubing. Hold for 30 minutes. Chart. Initial = 2620 psi, 15 min = 2560 psi, 30 min = 2550 psi. Dump Tubing pressure. SOV did not shear. Bump IA up to 2,700 psi. SOV sheared. Bleed off Tubing and IA. 4,666.0 4,666.0 8/10/2023 13:30 8/10/2023 15:00 1.50 COMPZN, RPCOMP RURD P Back out Landing Joint. Drain Stack. Clean and Clear Rig Floor. 4,666.0 0.0 8/10/2023 15:00 8/10/2023 16:30 1.50 COMPZN, RPCOMP MPSP P Set 'HP' BPV. Test BPV to 1,000 psi from below through sheared SOV. First attempt BPV leaked by. Drain Stack. Pull, redress, reset, and retest. Good Test. Bleed off. Blowdown lines. R/D. Swapped from 2T Highline power to Rig Generators @ 15:00 0.0 0.0 8/10/2023 16:30 8/10/2023 17:00 0.50 COMPZN, WHDBOP OWFF P OWFF for 30 minutes. 0.0 0.0 8/10/2023 17:00 8/10/2023 20:00 3.00 COMPZN, WHDBOP NUND P ND BOPs. Perform ESP cable final integrity test. Summit ESP Readings: Intake Temp = 67 deg F. Intake Press = 984 psi. Motor Temp = 67.4 deg F, Discharge Press = 983 psi. Phase to Phase OHMS = 5.0. Phase to Ground GOHMS = 2.22. 0.0 0.0 8/10/2023 20:00 8/10/2023 22:00 2.00 COMPZN, WHDBOP NUND P NU new Tubing Head Adapter. Install Test Dart. 0.0 0.0 8/10/2023 22:00 8/10/2023 22:30 0.50 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 15 Min - Good test 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/11/2023 Page 8/8 2T-203 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/10/2023 22:30 8/11/2023 00:00 1.50 COMPZN, WHDBOP NUND P Terminate Opsis gauge I-wire through addaptor spool. Final HES TEC Wire: Gauge 1: 1343 psi and 65.8 deg F. Gauge 2: 1344 psi and 65.8 deg F. N/U tree. 0.0 0.0 8/11/2023 00:00 8/11/2023 00:30 0.50 COMPZN, WHDBOP RURD P R/U circ manifold & LRS. 0.0 0.0 8/11/2023 00:30 8/11/2023 01:00 0.50 COMPZN, WHDBOP PRTS P LRS PT tree T/ 5000 PSI for 5 Min. 0.0 0.0 8/11/2023 01:00 8/11/2023 01:30 0.50 COMPZN, WHDBOP MPSP P Pull tree test dart & HP BPV. 0.0 0.0 8/11/2023 01:30 8/11/2023 03:15 1.75 COMPZN, WHDBOP FRZP P LRS pump 83 Bbls diesel down IA @ 2 BPM, ICP=200 psi. FCP= 1300 psi. U- tube well for 1 Hr. 0.0 0.0 8/11/2023 03:15 8/11/2023 04:00 0.75 COMPZN, WHDBOP RURD P Secure tree and cellar. Final Pressures = T/I/O = 90 / 90 / 50 psi. 0.0 0.0 8/11/2023 04:00 8/11/2023 05:00 1.00 DEMOB, MOVE DMOB P Move auxillary equipment away from rig. Rig Release @ 05:00 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/11/2023 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: 4,496.0 2T-203 9/4/2007 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig Set ESP equipment 2T-203 8/22/2023 SCOLEM Notes: General & Safety Annotation End Date Last Mod By NOTE: ZONES NOT LOADED INTO WELLVIEW 12/9/2010 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.79 30.8 1,609.8 1,546.2 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 28.2 6,046.1 3,096.9 29.70 L-80 BTCM LINER 4 1/2 3.96 5,582.6 7,484.0 3,103.7 12.60 13 CR VAM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.3 Set Depth 4,667.0 Set Depth 2,743.6 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,191.3 1,940.8 62.01 Mandrel GAS LIFT 6.403 4 1/2" x 1" KBMG, GLM Camco KBMG 3.865 4,399.8 2,657.4 71.66 Sensor - Discharge Gauge 6.039 4 1/2" 12.6 ppf OPSIS Dual Sensor, Hyd 563 BxP HES OPSIS 3.913 4,464.1 2,677.7 71.58 Mandrel GAS LIFT 6.350 4 1/2" x 1" KBMG, GLM Camco KBMG 3.865 4,531.6 2,699.3 71.07 PACKER 6.875 7 5/8" x 4 1/2" Viking ESP Packer, 5K PSI W.P. Viking 12ESP 3.898 4,545.8 2,703.9 70.96 Nipple - DB 5.210 4 1/2" x 3.813" DB-6' Nipple Camco DB-6 3.813 4,553.5 2,706.4 70.91 Sensor - Discharge Gauge 5.620 4 1/2" Vigilant Discharge Pressure Tubing Sub Summit Vigilant Sensor 3.958 4,615.1 2,726.6 70.89 Annular Connection Port (ACP) 5.380 TCC Perforated Intake Summit TCC Perforat ed Intake 3.958 4,625.8 2,730.1 70.89 Seal - Protector 5.250 Upper 513 Series Tandem Seal Section Summit 513 Series 3.630 4,643.7 2,735.9 70.90 Motor 5.620 562 Sieries Motor, KMS2, 180HP/2290V/48A Summit 562 Motor, 180 HP 3.630 4,664.0 2,742.6 70.81 Motor - Adapter 4.560 Adapter, Gauge to 562 Motor Summit Adapter 2.060 4,664.3 2,742.7 70.81 Sensor - Discharge Gauge 3.750 Vigilant, Sensor, High Temp, 150C w/ Discharge Pressure 5000 psi Summit Vigilant Sensor 2.560 4,666.2 2,743.3 70.80 Centralizer 6.000 Centralizer, 2 3/8", EUE, 7" Casing, 6" OD Summit Centraliz er Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,577.1 2,714.1 70.88 SLIP STOP Tubing stop (21" OAL)D&D 8/22/2023 4,578.9 2,714.7 70.88 PACKOFF D&D packoff w/ ball check (61" OAL) D&D 8/22/2023 4,584.0 2,716.4 70.88 ESP Set 3.80 SUMMIT ESP 41' OAL SUMMIT SF5800 8/21/2023 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,191.3 1,940.8 62.01 1 DMY BK 1 8/21/2023 SLB KBMG 4,464.1 2,677.7 71.58 2 SOV BK 1 8/21/2023 2000# TBG SLB KBMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,582.6 3,003.3 78.45 PACKER 6.690 BAKER SC-1R Liner Top Packer BAKER SC-1R 76A4-40 4.000 5,586.8 3,004.2 78.57 MILLOUT 5.500 MILLOUT EXTENSION 3.958 5,592.4 3,005.2 78.72 XO THREAD 6.050 3.958 5,603.6 3,007.4 78.88 KOIV TOOL 5.000 3.500 5,606.1 3,007.9 78.85 KOIV 5.000 3.500 7,475.9 3,104.1 93.08 Flapper VLV 1 5.520 3.000 7,477.3 3,104.0 93.08 Flapper VLV 2 5.520 3.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,654.0 5,737.0 3,017.4 3,034.6 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 5,991.0 6,033.0 3,086.9 3,094.5 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores DEVIATED, 2T-203, 8/29/2023 1:14:05 PM Vertical schematic (actual) LINER; 5,582.6-7,484.0 SLOTS; 7,373.0-7,415.0 SLOTS; 6,748.0-7,371.0 SLOTS; 6,704.0-6,746.0 SLOTS; 6,035.0-6,657.0 PRODUCTION; 28.2-6,046.1 SLOTS; 5,991.0-6,033.0 SLOTS; 5,654.0-5,737.0 Motor; 4,643.7 Seal - Protector; 4,625.8 Annular Connection Port (ACP); 4,615.0 ESP; 4,584.0 PACKOFF; 4,578.9 SLIP STOP; 4,577.1 Nipple - DB; 4,545.8 PACKER; 4,531.6 Mandrel GAS LIFT; 4,464.1 Sensor - Discharge Gauge; 4,399.8 Mandrel GAS LIFT; 2,191.3 SURFACE; 30.8-1,609.8 CONDUCTOR; 31.0-108.0 Tubing hanger; 25.3 KUP PROD KB-Grd (ft) 33.99 RR Date 2/25/2006 Other Elev 2T-203 ... TD Act Btm (ftKB) 7,525.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032052000 Wellbore Status PROD Max Angle & MD Incl (°) 93.24 MD (ftKB) 7,282.91 WELLNAME WELLBORE Annotation Last WO: End Date 8/11/2023 H2S (ppm) 53 Date 12/9/2022 Comment SSSV: NONE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,035.0 6,657.0 3,094.9 3,114.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,704.0 6,746.0 3,115.7 3,116.4 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,748.0 7,371.0 3,116.4 3,108.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 7,373.0 7,415.0 3,108.6 3,107.0 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores DEVIATED, 2T-203, 8/29/2023 1:14:08 PM Vertical schematic (actual) LINER; 5,582.6-7,484.0 SLOTS; 7,373.0-7,415.0 SLOTS; 6,748.0-7,371.0 SLOTS; 6,704.0-6,746.0 SLOTS; 6,035.0-6,657.0 PRODUCTION; 28.2-6,046.1 SLOTS; 5,991.0-6,033.0 SLOTS; 5,654.0-5,737.0 Motor; 4,643.7 Seal - Protector; 4,625.8 Annular Connection Port (ACP); 4,615.0 ESP; 4,584.0 PACKOFF; 4,578.9 SLIP STOP; 4,577.1 Nipple - DB; 4,545.8 PACKER; 4,531.6 Mandrel GAS LIFT; 4,464.1 Sensor - Discharge Gauge; 4,399.8 Mandrel GAS LIFT; 2,191.3 SURFACE; 30.8-1,609.8 CONDUCTOR; 31.0-108.0 Tubing hanger; 25.3 KUP PROD 2T-203 ... WELLNAME WELLBORE 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7525'None Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Adam Klem adam.klem@conocophillips.com (907) 263-4529 RWO/CTD Engineer Tubing Grade:Tubing MD (ft): Packer: 5583'MD/3003'TVD SSSV: None Perforation Depth TVD (ft):Tubing Size: L-80 4651' 7/1/2023 Packer: Baker SC-1R SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025569, ADL0025548 205-197 P.O. Box 100360, Anchorage, AK 99510 50-103-20520-00-00 ConocoPhillips Alaska, Inc. KRU 2T-203 Tabasco Oil PoolTabasco Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 3102'7484'3104'1088 None MD 108' 1546' 108' 1610' 3097'6046' 16" 10-3/4" 77' 1579' Perforation Depth MD (ft): 5654-5737' 5991-6033' 6035-6657' 6704-6746' 6748-7371' 7373-7415' 6018' 4-1/2" 3017-3035' 3087-3095' 3095-3115' 3116-3116' 3116-3109' 3109-3107' 7484'1901' 4-1/2" 3104' 7-5/8" P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:13 am, May 23, 2023 323-299 Adam Klem Digitally signed by Adam Klem Date: 2023.05.22 14:39:59 -08'00' DSR-5/23/23 X BOP test to 2500 psig Annular preventer test to 2500 psig VTL 6/22/2023 MDG 6/9/2023 X 10-404 GCW 06/22/2023 06/23/23Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.23 08:59:12 -08'00' RBDMS JSB 062723 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 22, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 2T-203 (PTD# 205-197). 2T-203 is a producer drilled in 2005 completed with 4.5" tubing and 7 5/8" casing. It currently is completed with an ESP and it appears the ESP cable failed. A rotary workover is required to pull the tubing and ESP and replace the ESP. A production packer will be added to isolate the majority of the ESP cable from production fluids. If you have any questions or require any further information, please contact me at 907-263-4529 2T-203 RWO Procedure Tabasco Producer PTD #205-197 Page 1 of 1 Remaining Pre-Rig Work 1. Prep well for rig. Rig Work 1. MIRU Nordic 3 on 2T-208. 2. Circulate in KW brine (est 10.5ppg KW brine) 3. Shut the well in and perform no flow test for 30 min to verify KW. 4. Set BPV, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. 5. Pull BPV, MU landing joint and BOLDS. 6. Pull 4-1/2” tubing laying down tubing and ESP 7. MU new ESP and 4 ½” completion 8. Once on depth, space out and MU tubing hanger 9. Circulate in corrosion inhibited fluid into the IA 10. Land the tubing hanger, RILDS and pull the landing joint 11. Drop ball and rod. Pressure up to set packer 12. PT tubing to 3000psi for 30 minutes. Chart. 13. PT IA to 2500psi for 30 minutes. Chart. 14. Shear SOV 15. Install BPV and PT from below 16. ND BOPE. NU tree. 17. Pull BPV, freeze protect well 18. RDMO. Post-Rig Work 19. Handoff to operations to put back on production General Well info: Wellhead type/pressure rating: FMC Tabsaco Gen 2, 5M psi top flange Production Engineer: Natalie Dye Reservoir Development Engineer: Sayeed Abbas Estimated Start Date: 7/1/23 Workover Engineer: Adam Klem (263-4529/ adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 4.5”completion and replace the ESP and add production packer BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram MIT results: x SCLD: passed 4/30/23 x IC POT & PPPOT: passed 4/29/23 x TBG POT &PPPOT: failed 4/29/23 MPSP: 1,088 psi using 0.1 psi/ft gradient Static BHP: 1,360 psi / 2723’ TVD measured on 5/3/23 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:4,496.0 2T-203 9/4/2007 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled ESP equip. 2T-203 3/21/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic 10.0 1/8/2018 jennalt NOTE: ZONES NOT LOADED INTO WELLVIEW 12/9/2010osborl NOTE: View Schematic w/ Alaska Schematic9.012/9/2010 ninam General Notes: Last 3 entries Com Date Last Mod By Crude/water below 2363' RKB 12/16/2018 spilch Freeze protected with diesel from surface to 2363' MD (36 bbls).12/12/2018 spilch Pressure tests I can't get to display in the right field: Gas MITIA passed to 1000 psi 1/22/18; T- POT, T-PPPOT, IC-POT, IC-PPPOT passed 10/7/18; SCLD passed 10/9/18. 10/9/2018 spilch Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/49.7930.81,609.8 1,546.2 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 28.2 6,046.1 3,096.9 29.70 L-80 BTCM LINER 4 1/2 3.96 5,582.6 7,484.0 3,103.7 12.60 13 CR VAM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.3 Set Depth … 4,650.8 Set Depth… 2,738.3 String Ma… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXPM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.3 25.3 0.00 HANGER 10.850 Tubing Hanger, FMC, TC-BH-EMS- EC-HT, 11" x 4-1/2", 5" RH Acme Top x 4-1/2" TXP Bottom, CIW 4" H BPVG FMC TC-BH- EMS-EC -HT 3.958 3,372.8 2,341.1 72.01 GAS LIFT 6.437 GLM, Camco, KBMG, 4-/2" x 1" with SOV T >IA 2kpsi, SN: 19860-05 CAMCO KBMG3.860 4,483.6 2,683.9 71.43 GAUGE 4.500 ROC Gauge Tubing (ROC-150 S/N ROC-005922) HES TXP 3.860 4,495.8 2,687.7 71.34 GAUGE 4.500 ROC Gauge Annulus (ROC-150 S/N ROC-005912) HES TXP 3.958 4,552.7 2,706.2 70.91 ESP 4.500 Motor Shroud Assembly #1 - GVSS Acess TXP 3.958 4,583.0 2,716.1 70.88 ESP Motors 5.000 Motor Shroud Assembly #2 - ALP Acess TXP 3.958 4,614.6 2,726.4 70.89 ESP 4.500 Motor Shroud Assembly #3 - No GO & B-Profile Acess TXP 3.958 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,372.8 2,341.1 72.01 1 GAS LIFT SOV BK 1 0.0 3/7/2019 STS 2000# Schlumb erger Camco KBMG 0.000 3,372.8 2,341.1 72.01 1 GAS LIFT BK 1 Schlumb erger Camco KBMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,582.6 3,003.3 78.45 PACKER 6.690 BAKER SC-1R Liner Top Packer BAKER SC-1R 76A4-40 4.000 5,586.8 3,004.2 78.57 MILLOUT 5.500 MILLOUT EXTENSION 3.958 5,592.4 3,005.2 78.72 XO THREAD 6.050 3.958 5,603.6 3,007.4 78.88 KOIV TOOL 5.000 3.500 5,606.1 3,007.9 78.85 KOIV 5.000 3.500 7,475.9 3,104.1 93.08 Flapper VLV 1 5.520 3.000 7,477.3 3,104.0 93.08 Flapper VLV 2 5.520 3.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,654.0 5,737.0 3,017.4 3,034.6 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 5,991.0 6,033.0 3,086.9 3,094.5 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,035.0 6,657.0 3,094.9 3,114.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,704.0 6,746.0 3,115.7 3,116.4 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,748.0 7,371.0 3,116.4 3,108.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 7,373.0 7,415.0 3,108.6 3,107.0 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores DEVIATED, 2T-203, 3/21/2023 9:31:52 AM Vertical schematic (actual) LINER; 5,582.6-7,484.0 SHOE; 7,482.6-7,484.0 Flapper VLV 2; 7,477.3-7,478.8 Flapper VLV 1; 7,475.9-7,477.4 SEAL; 7,457.3-7,461.1 SEAL; 7,416.7-7,420.5 SLOTS; 7,373.0-7,415.0 SEAL; 7,370.7-7,373.5 SLOTS; 6,748.0-7,371.0 SEAL; 6,745.7-6,748.5 SLOTS; 6,704.0-6,746.0 SEAL; 6,701.5-6,704.2 SEAL; 6,657.4-6,660.2 SLOTS; 6,035.0-6,657.0 PRODUCTION; 28.2-6,046.1 FLOAT SHOE; 6,044.6-6,046.1 SEAL; 6,032.6-6,035.3 SLOTS; 5,991.0-6,033.0 SEAL; 5,988.3-5,991.1 FLOAT COLLAR; 5,959.0- 5,960.4 SEAL; 5,944.1-5,946.8 SLOTS; 5,654.0-5,737.0 SEAL; 5,650.9-5,653.7 KOIV; 5,606.1-5,607.9 KOIV TOOL; 5,603.6-5,606.1 SEAL; 5,593.1-5,595.9 MILLOUT; 5,586.8-5,592.4 PACKER; 5,582.6-5,586.8 ESP Motors; 4,583.0 GAUGE; 4,495.8 GAUGE; 4,483.6 GAS LIFT; 3,372.8 SURFACE; 30.8-1,609.8 FLOAT SHOE; 1,608.0-1,609.8 FLOAT COLLAR; 1,526.9- 1,528.4 CONDUCTOR; 31.0-108.0 HANGER; 30.8-34.9 HANGER; 28.2-32.7 HANGER; 25.3 KUP PROD KB-Grd (ft) 33.99 RR Date 2/25/2006 Other Elev… 2T-203 ... TD Act Btm (ftKB) 7,525.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032052000 Wellbore Status PROD Max Angle & MD Incl (°) 93.24 MD (ftKB) 7,282.91 WELLNAME WELLBORE Annotation Last WO: End Date 12/17/2018 H2S (ppm) 100 Date 11/22/2015 Comment SSSV: NONE 2T-203 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108 108 16 15.06 62.5 H-40 0 0 Surface 1609 1546 10.75 9.95 45.5 L-80 BTC BTC Production 6046 3097 7.625 6.87 29.7 L-80 BTCM BTCM Liner 7484 3103 4.5 3.96 12.6 L-80 VAM VAM Tubing 4650 2738 4.5 3.96 12.6 L-80 TXP TXP PROPOSED COMPLETION 4-1/2" 12.6# L-80 Hyd563 Tubing to surface 4-1/2" GLMs @ TBD HES Tbg/IA sensing DHG Viking Feedthrough packer 3.813" X Nipple Summit Pump and Motor Motor Centralizer REMAINING COMPLETION LEFT IN HOLE Linertop Packer and Perfs with Screens from 5582' RKB to 77484' RKB (3.25" ID) Surface Casing Production Liner w/ slots Conductor Perfs for Tabasco ESP Production Casing DHG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVE'® rA" 25 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 11 Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program Plug for Redrill ❑ erforate Naw Pool ❑ Repair Well ❑+ Re-enter Susp Well ❑ Other. ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development El Stratigraphic❑ Exploratory ❑ Service ❑ 205-197 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20520-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: Al 25569, ADL 25548 KRU 2T-203 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kul River Field / Tabasco Oil Pool i t. Present Well Condition Summary: Total Depth measured 7,525 feet Plugs measured None feet true vertical 3,102 feet Junk measured None feet Effective Depth measured 7,484 feet Packer measured 5,583 feet true vertical 3,104 feet true vertical 3,003 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 16 108' MD 108' TVD SURFACE 1,579 feet 10 3/4 " 1,610' MD 1546' TVD PRODUCTION 6,018 feet 7 5/8 6,046' MD 3097' TVD LINER 1,901 feet 4 1/2 " 7,484' MD 3104' TVD Perforation depth: Measured depth: 5654-5737, 5991-6033, 6035-6657, 6704-6746, 6748-7371, 7373-7415 feet True vertical depth: 3017-3035, 3087-3094, 3095-3115, 3116-3116, 3116-3109, 3109-3107 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 4,651' MD 2,738' TVD Packers and SSSV (type, measured and We vertical depth) PACKER= BAKER SC -1R LINER TOP PACKER 5,583' MD 3,003' TVD SSSV =NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN NIA NIA WA N/A Subsequent to operation: 280 32 3551 210 240 14. Attachments (required per 20 MC 25.070, 25.071, 8 25,283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318.514 Authorized Name: Ron Phillips Contact Name: Ron Phillips Authorized Title: Sr. Wells Engineer Contact Email: Ron.L.Phillips@cop.com Authorized Si nature: Date: Contact Phone: (907) 265-6312 Form 10404 Revised 4/2017 VTL 215-119 14f �C/jam RBDMS�,) FEB 0 1 2019 Submit Original Only DL KUP PROD WELLNAME 2T-203 WELLBORE 2T-203 C�or11IIlins #'�I Well Attributes Max Angle & MD TD Field Name We11Mre FWVW1 W¢Bboee slaWi ncll,) MDIXKB) ;p Bl:: ' AfaBIIB, IrIC, rAflGFCr1 m,moncnnnn _.__. DEVN1E.-Zr-AS,IRI/$p181239RpM Last Tag ......... ... ,........ ....... uereuw Ve,OUIzawM[IatEM) AnnIXatpn NMh(BKB) End Dao I wellbpe Iaat Motl By ................................................................ HANGER: ]S9kLoneruetalls CONDUCTOR: 910.1fB.0 GAs uFr; 9.9rze ONUGE, 4.42s owcE:4.42e SLVSTOP; 4,52 .1 pccss5) ono SeOKDFF; e ESP: 4.usa ESPumn;4stt.] AWEss ESP MTOR 4,W3 ESP Mm.a 4seaa ESPMm.a: 4614e ELOTs, sass Os.>azo_ .Lms: ssel oa,oaa o- PRODUCTION. 2.2E,Oei.1 SLOr6:6,0360-9,8SO. SLOTS, 670403,7x3.0- Sears 674eD7.214- SLOTS: 7.3MO7.4150- St atl i Notes: 12/9/2010 UNER:55926T1Ba.o Last Tag; 4495.0 9/41200] 2T OJ 5. Conversion Last Rev Reason AnnWetion End Dep WNlbnre Last Moda, eason: Rebace650V 111)12019 2T-203 zembaq ng Strings Deae,ipGon OD pn) 10 (in) Toppla) Se1DepthmKIS gel Depth lND)....hLen(L..GMe Top TMead UCTOR 16 15M 310 108.0 108.0 62.50 Rio WELDED Desadpfion OO pn) ID pn) roplKKO) SM papth IBKB) Se10epN jIVD)... Wtl1m g... G20e TopTareq CE 1014 9,19 30.8 1,609.8 1,5462 4550 LA0 BTC Mttgp110n ODI&) ID(Inl Top mKB) Stl REpums.) Yt Depth llV01... WYLen 11... Grate Tap iM1reW UCTION )SIB 68] 282 6,046.1 3,096.9 29)0 LA0 BTCM Deulplion pp (int ID DnI Top(RKB) SN Depth mus) SNDOA (NO).., WtlLen a... Grade Top TXrW 4112 3.96 5,582.6 ),484.0 3,103] 1260 13 CR VAM DetailsNomlwllD mKB) Top(Np)mKB) TopinCl l°) Ikm Use Oom (IN 5,5626 3,003.3 )8.45 PACKER BAKER SC -1 R Liner Top Packer 4.T0 5,586.8 30042 78.57 MILLOUT MILLOUT EXTENSION 3.58 5,531 3,0054 78,758EAL Sealbore W/4 5" Vam Top SealboreA 3250 -71M 5,6036 3,0070 70-7TOOL 3500 5,606.1 36079 78.85 KOIV 3500 5,650.9 3,0163 7842 SEAL Sealbore 60/4.5" Vann Top SealboreB 3.250 5,944.1 3,078.1 7889 SEAL Sealbore WAS' Vam Top SealboreC 3,250 5,988.3 3,086.4 7938 SEAL Sealbore w/46' Vam Top SealbomD 3250 6,032.6 3,0945 79.49 SEAL Sealbore 60/45" Vam Top SealbomE 32W 6,657.4 3,114) 8859 SEAL Sealbore w/4.S Vam Top Sealborel' 3,250 6,7014 3,115.7 88.88 SEAL Sealbore R14,T Vam Top SealboREG 3250 6,7457 3,116.4 89.49 SEAL Sealbore W145'Vam Top SealboreH 325) 7,3]04 3,108) 9198 SEAL Sealbore w/4. 'Vam Top Sealbore) 3250 ],418.] 3,107. 92.40 SEAL Sealbore wl4.6' Vam Top Sealbore) 3,250 7,4573 3,105.1 92.93 SEAL Sealbore W4S- Vend Top SealboreK 3,250 7475.9 7,104.1 93.08 MFW777 3.000 7,4773 3,104.0 93.08 Flapper VLV2 3.000 Tubing Strings Tubinq Oe... i lion Sinnq Ma.,. ID(n) Top lnKa) Set DepN 110. SN De re"WII...en"I'm Grade Top Cannechon TOBING-RW02018 4112 3.9fi 25.3 4,650.6 2,738.3 12.60 L$0 T%PM Completion Dafalls TWI VD) Top Incl Rommel TOPmKB) mNB) rl Ham o a Com IO IM) 25.3 25.3 0.110 HANGER Tubing anger,FM , T - M E -H ' x 4-il ", 5" Rm 3.95 Acme Top x 4-02' T%P BOBom, CIW 4' H BPVG 4,483.8 2,68391 7143 IGAUGE ROC Gauge Tubing (R -150 SM RO - 922) 3.8 8495.8 2,687.7 71.M IGAUGE ROC Gauge Annulus (ROC -1 50 SIN RU"05912) 77.9 4,552,1 2,7706 .2 ].1 ESP Minors Motor Shroud Assembly #1-GVSS 3.958 4,5830 2,716.1 7. ESP MObIs Motor Shroud Assembly #2 -ALP 3.958 4,614.6 2,77264 7.89 I ESP hi Motorhrould Assembly#3-No G06 B-Profle 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, Fish, etc.) Too afths)Ubj rn"Q-1m Topincl IRKS) 19 ox con aur Dap ID (in) 4,520.1 1 2,695.5 )1.16 SLIPSTOP 412'SLIP STOP 12124GOI 8 85216 I ,696.0 j 71.15 A SS) D.. .0"A CAD RACKOA BEMBL 1-271=1 RACKOFF FROM TOP TO EO DEVICE) 442' 'AL 8 4,526.3 2,6976 71.11 ESP 3.80" BAKER ESP 41.15' CAL i 8 4,567.3 I 2,)10.9 770. J JAUUILDS E6 AIJULSSUtSPMOTOR (LOWER MATING UNIT 10 1 MOTOR TO PLUG ARM=38.11)4633'OAL 8 Perforations & Slots Toshiba) BtmI ) Top ITVD) (EKS) BlnnVD) Me) LmxMZone Dam Shot Dena (thorned Typ Co. 5.W0 5,7370 3,017.4 3,034.6 2/1&2006 99.0 SLOTS Ipma#ng Exc Dame ureenlsealbOres 5,9916 7030 3,086.9 3.094.5 01WO06 99.0 SLOTS Altemating Exc12K oarse screen(sealbores ,0350 6,6520 3,094.9 3,114] 0162(,06 990 SLOTS Iprnafng Excl2K oarse .peen/sealbores 8]040 67460 3,115.] 3,1164 1WI)06 90.0 SLOTS Afterna1mg Exc12KCoarbe smeendsealbores 6]48.0 7,371.0 3,116.4 3,1083 01 2006 .0 SLOTS Alternating Exc2K Coarse xreen/sealbores 7,37 0 ],415. 3,108.6 3,10)0 01 006 SLOTS Iematlng ExGl oarse SCreerlsea0o25 Marginal inerts N TopmKB) Top ITVDI I'l Mab MWeI ODIin) 9ery Valw-h Type Type PoRSce (int TRO Run Iiog Run Wp Com 3,372. 2,341.1 CAMCO KBMG 1 1 GAS LIFT SOV BK 1 0.000 0,011711712018 2000 It General & Safety End Dale I Annotation NOTE: View Schematic m/ Alaska Schemahc9O Caws; hillip5 h'1 .(TC. KUP PROD WELLNAME 2T-203 WELLBORE 2T-203 DEW,TED-a-=.. IMMS IISSSS PM Notes: Genenl3$if Ly vwea sclenmcl+�bal) Ena D. An'whtgn ......._.__.................................................._._.............__.. 121D12DiD NOTBZONES NOT LOADED INTO WELLVIEW 11812018 NOTE: View 5an.nnait wl AWSM SChS.A3 100 WWGER; 3.3� CONDUCTOR: 31 D10.0 SURFACE: 3.61.5XS� DAA LIFT; 3.3]28 SAUSE; 4,`03.6 WUOE 4.405 SUPSTOF; 4$301 (ACCESS) 06D PACMDFe: 0,5218 ESQ; A5 3S ESP Mo1we; 4,Sa7 ACCESS ESP MOTOR, 4,55]3 ESP Mokn: 4,500 ESP Mynv', 4,5148 SLOTS. 5,04, 65]3] 0� MOTS: 51010&03.0� PRCOUCTION: n SS,G 1l .U.S: SONS .08,.7 SLOTS; B,]W OB.]48.0� MOTS: S744O],37IO� SLOTS: TOSS. 7,41ED� LINER; SW 7.480.0 s r,e Operations Summary (with Timelog Depths) 2T-203 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time End Time our (hr) Phase OpCode Actrvily Code Time P -T-% Operation Start Depth (ftKB) End Depth (flKB) 12/17/2018 12/17/2018 2.00 MIRU MOVE MOB P Release Rig F/ 3H-78 U 2T-203 14:00 16:00 12/17/2018 12/18/2018 8,00 MIRU -90V -E MOB P Moving to 2T-203 Move Pits and Shop 16:00 00:00 U 2T-203 12/78/2018 12/18/2018 12.00 MIRU MOVE MOB P Continue Mobilizing rig from 3H-18 to 00:00 12:00 2T-203, pits and warehouse on location by 18:00hrs 12118/2018 12/19/2018 12.00 MIRU MOVE MOB P Continue Mobilizing -Fig 3H-18 to 12:00 00:00 2T-203, rig central system on location by 23:59 furs to begin spotting in. 12/19/2018 12/19/2018 12.00 MIRU MOVE MOB P Finish prepping pad around 2T-203 00:00 12:00 well head, back in and spot rig over well center and verify center over well. Back in and button up pits to rig and begin rigging up all auxiliary equipment. Change out Bridal Line and pin. 12/19/2018 72/20/2018 12.00 WI -RU MOVE RURD P PJSM, raise derrick and pin in place, 12:00 00:00 derrick in the air by 13:00hrs. Continue rigging up rig Floor, pits, and pumping lines/valves. Rig Accepted at 00:00 hrs on 12-20-2018. 12/20/2018 12/20/2018 6.00 SURPRD WELLPR KLWL P Install secondary annulus valve on 00:00 06:00 tree R/U pulled BPV with lubricator w/ 450 psi on tubing Hook up to Bleed tank 12/20/2018 12/20/2018 12.00 SURPRD WELLPR KLWL P Start Beetling off tubing gas to bleed 06:00 18:00 tank bleed f/ 800 psi t/ 150 psi Annulus and tubing Start pumping down tubing @ 3 bbls min w/ 8.5 S/W 250 psi take returns through choke to bleed lank and pump 280 bbls LRS pump 140 bbl 150 deg desel chase w/ 250 Clean filter s/w @ 160deg Shut down Monitor well 72/20/2018 12/21/2018 -6 00 SURPRD WELLPR KLWL P Continue Monitor well w/ 125 psi order 18:00 00:00 295 bbls 9.3 Brine and Pump 213 bbls 9.3 BBLs Brine @ 4 bbls min w/ 145 shut down Monitor well w/ 50 psi on ann Could not bleed off order 580 bbls 9.6# brine 12/21/2018 12/21/2018 14.50 WI -RU WELCTL KLWL P PJSM, Start pumping 9.6 filtered Brine 00:00 14:30 @ 2 bbls min w/80 psi Total pumped 285 bbls Clean returns 9.6 brine shut down monitor well 1 hr with no Flow R/D lines and Flow back tank . 72/21/2018 12/21/2078 1.00 MIRU WHDBOP MPSP P Set FMC BPV 14:304:30 15:30 72/21/2018 72/21/2018 -7 50 MIRU WHDBOP NUND P N/D tree, N/U BOP stack and R/U to 15:30 23:00 test BOPE 72/21/2018 12/22/2018 1.00 MIRU WELLPR BOPE P Start testing BOPEwith AOGCC Guy 23:00 0000 Cook State inspector 250/2500 psi 12/22/2018 12/22/2018 10.00 MIRU WELLPR BOPE - Continue pressure testing BOPE with 00:00 1000 AOGCC Guy Cook State inspector, 250/2500 psi, complete 5 out of 11 pressure tests, valve #11 on choke manifold leaking by and test chart recorder having issues with keeping pressure constant. Page 1/5 ReportPrinted: 1/21/2019 Operations Summary (with Timelog Depths) 2T-203 Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTime End Time our (hr) Phase Op Cotle Apivity Cotle Time P -T -X Operation Stan Depth (ttKB) End Depth (flKB) 12/22/2018 12/22/2018 2.00 MIRU WELLPR RGRP T Break down choke manifold valve #11 10:00 12:00 and replace seals and service, change out 3 transducers on lest pump while troubleshooting test chart, replace test chart and insert new chart into the system, re -pressure test pump, tested good. 12/22/2018 12/22/2018 6.00 MIRU WELLPR BOPE P Continue pressure testing BOPE with 12:00 18:00 advisement from AOGCC Guy Cook State inspector, begin pressure testing with new chart recorder test sequence #1 thru #11, 250/2500 psi, all tested good. 12/22/2018 12/22/2018 1.00 MIRU WELLPR RURD P R/D test equipment and Pulled Test 18:00 19:00 plug and BPV and lay out same, clear and clean rig floor 12/22/2018 12/23/2018 5.00 COMPZN RPCOMP TURD P PJSM, R/U ESP Equipment,hook up 19:00 0000 ESP cable Sheave in derrick. r/u Weatherford power tongs Equipment 12/23/2018 12/23/2018 8.00 COMPZN RPCOMP PULL P M/U FMC Landing Joint to hanger 4,607.0 4,560.0 00:00 08:00 BOLDS and Pull hanger to floor and UD same, ConocoPhillips Generator assisting Summit ESP breaker issues for running spooler, troubleshoot generator. 12/23/2018 12/23/2018 0.50 COMPZN RPCOMP SVRG P PJSM, rig service while 4,560.0 4,560.0 08:00 08:30 troubleshooting generator for Summit ESP. 12/23/2018 12/23/2018 5.50 COMPZN RPCOMP EQRP T Change out ConocoPhillips Generator 4,560.0 4,560.0 08:30 14:00 for Summit ESP spooler, test equipment, equipment tested good with new generator. Old generator breaker system failed. 12/23/2018 12/24/2018 10.00 COMPZN RPCOMP PULL P Continue POOH with 4-1/2" TXP 4,560.0 100.0 14:00 00:00 tubing and ESP cable, spooling ESP cable on Summit spooler and taking off clamps each joint, inspecting and drifting each joint. 12/24/2018 12/24/2018 2.00 COMPZN RPCOMP PULL P Lay down ESP pump and motor, 100.0 0.0 00:00 0200 pumps shaft sheared off, recover centralizer and rig down spooler, clear and clean rig floor. 12/24/2018 12/24/2018 6.50 COMPZN RPCOMP KURD P R/U New ESP ASSY, Equipment and 0.0 0.0 02:00 08:30 c/o ESP cable spool w/ Summit, 12/24/2018 12/24/2018 0.50 COMPZN RPCOMP SFTY P PJSM, RIH with ESP cable and TEC 0.0 0.0 08:30 09:00 line and making up ESP and gauges BHA. 12/24/2018 12/24/2018 5.00 COMPZN RPCOMP PUTB P P/U Access ESP motor shroud and 0.0 1,000.0 09:00 14:00 install ESP cable at ACP and test ESP cable, tested good. RIH installing clamps every connection, P/U and M/U HES ROC gauges and install TEC line and pressure test connection to 5150 psi for 10 minutes, good test. Continue RIH with ESP and TEC line installing clamps each connection to 1,000' and test ESP cable, ground fault detected. Page 2I5 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 2T-203 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur(m) Phase Op Corte Activity Corte Time P -T -X Operation Start Depth (flKB) End Depth(%KB) 12/24/2018 12/25/2018 10.00 COMPZN RPCOMP PULL T POOH laying out clamps and 1,000.0 0.0 14:00 00:00 inspecting ESP cable, no signs of wear and damage, lay out TEC cable and HES ROC gauge assembly and pull up and disconnect ESP line from ACP and test ESP cable and c/o bad continunity and esp connection port on motor shroud assy 12/25/2018 12/25/2018 3.00 COMPZN RPCOMP PUTB T Continue RIH w/ ROC Gauge and 0.0 212.0 00:00 0300 Hook up and test to 5800 psi for 10 minutes, good test. All good and Make a Splice w/ ESP cable Test good Continue RIH w/ 4-1/2" Tubing from 212'. 12/25/2018 12/25/2018 3.50 COMPZN RPCOMP PUTB P Continue RIH w/4 -1/2"12.6#L-80 212.0 1,321.0 03:00 06:30 TXPM MOD Tubing make up to 7,000 ft/lb with torque turn, running ESP cable and ROC TEC installing Cannon Clamps every joint from 212' to 1,250' and install GLM SOV and make up last 4-1/2" tubing single to 1,321'. 12/25/2018 12/25/2018 10.00 COMPZN RPCOMP SLKL P PJSM, R/U Slick Line and P/U 10' x 1,321.0 1,321.0 06:30 16:30 3.83" drift and RIH to No -Go stop at 1,274' and POOH and lay out drift to pipe shed. M/U ESP motor and install oil in housing and RIH on Slick Line Access ESP assembly #1 with air weight of 1,3601bs to 1,100' cable head depth and set ESP motor, check electrical reading on ESP cable, all good test. Shear out and POOH with Slick Line and M/U Access ESP assembly #2 and RIH with air weight 1,190 Its and set pump, test connections all good. Shear out and POOH with Slick Line and M/U Access ESP assembly #3 and RIH and set tubing pack off, attempt to pressure test pack off, RIH and jar down on pack off with Slick Line and POOH and pressure test tubing pack off to 1,000 psi for 10 minutes, good test. M/U tubing stop assembly and RIH on Slick Line and set. POOH with Slick Line and rig down slick line sheaves and tools and set off to side of rig floor. 12/25/2018 12/25/2018 1.00 COMPZN RPCOMP RURD P PJSM, rig down slick line and clear 1,321.0 1,321.0 16:30 1730 and clean rig floor. PJSM, rig Weatherford back up for running 4- 1/2" completions string with ESP and TEC lines clamping every joint. 12/25/2018 12/26/2018 6.50 COMPZN RPCOMP PUTB P Continue RIH w/ 4-1/2" 12.6# L-80 1,321.0 4,000.0 17:30 0000 TXPM MOD Tubing make up to 7,000 ft/lb with torque turn, running ESP cable and ROC TEC installing Cannon Clamps every joint from 1,321' to 2,420' and test connections, good test. Continue RIH w/ 4-1/2" 12.6# L-80 TXPM MOD Tubing make up to 7,000 ft/Ib with torque turn, running ESP cable and ROC TEC installing Cannon Clamps every joint from 2,420' to 4,000' and test connections, good test. Page 315 ReportPrinted: 1/21/2019 Operations Summary (with Timelog Depths) 2T-203 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Depth Stan Time End Time Dur (ho Phase Op Code Acdvlty Code Time P -T -X Operation (WB) EM Depth (WB) 12/26/2018 12/26/2018 2.00 COMPZN RPCOMP PUTB P Continue RIH w/ 4-1/2" 12.6# L-80 4,000.0 4,577.0 00:00 02:00 TXPM MOD Tubing make up to 7,000 fl/lb with torque turn, running ESP cable and ROC TEC installing Cannon Clamps every joint from 4000 to 4577' and test connections, good test. 12/26/2018 12/26/2018 5.00 COMPZN RPCOMP SLKL P R/U and RIH w/ Slick line gauge run 4,577.0 45,774.0 02:00 07:00 w/ 3.84 drift T/ 4,445' with no issues going in the hole (had drift floating through spot at 3,097'to 3,136' and 3,378' to 3,445' and seen slight drag coming back through spot of 100 lbs over string weight, 71' hole inclination, worked up and back down through spots with no issues). POOH to surface and rig down slick line. 12/26/2018 12/26/2018 0.50 COMPZN RPCOMP PUTB P Continue RIH w/ 4-1/2" 12.6# L-80 4,577.0 4,644.0 07:00 07:30 TXPM MOD Tubing make up to 7,000 fUlb with torque tum, running ESP cable and ROC TEC installing Cannon Clamps everyjoint from 4,577' to 4,620'. 12/26/2018 12/26/2018 0.50 COMPZN RPCOMP THGR P Make up Hanger and orientate to well 4,644.0 4,644.6- 07:30 08:00 head with space out to land out with mule shoe at 4,644.85'. 12/26/2018 12/26/2018 4.00 COMPZN RPCOMP THGR P Terminate ESP and TEC into hanger 4,644.0 4,644.0 08:00 12:00 penetrations and test connections and lines, all tested good. 12/26/2018 12/26/2018 1.00 COMPZN RPCOMP THGR P Slack off with hanger and string 4,644.0 4,644.0 12:00 13:00 utilizing ESP pig -tail and TEC line rolled up on floor to 24.85' RKB depth and land hanger in head profile and verify with FMC rep. Run in locking dogs and verify proper torque. 12/26/2018 12/26/2018 3.50 COMPZN RPCOMP RURD P PJSM, R/D Weatherford TRS, RID 4,644.0 4,644.0 13:00 16:30 Summit ESP cable and sheave, RID Halliburton TEC cable spooler and sheave. Clear and clean rig floor. 12/26/2018 12/26/2018 0.50 COMPZN RPCOMP OWFF P Pump down tubing, shear out the 4,644.0 4,644.0 16:30 17:00 shear out valve with 2,000 psi and verify good flow to IA, shut down and allow tubing to U -Tube back up IA and flow check well for 30 minutes, well Flow on Back side and tubing was not dropping. 12/26/2018 12/27/2018 7.00 COMPZN RPCOMP OWFF T Shut in well and Monitor O psi for 30 4,644.0 4,644.0 17:00 00:00 mins w/ 9.4 brine Pump down tubing 175 bbls @ 3 bbls taking returns out to flow back tank recovered 60 bbls Shut down and monitor well IA would not stop flowing. tubing Static.Shut in well and monitor well w/ no pres build up and order 290 bbls filtered 9.6 brine 12/27/2018 12/27/2018 2.00 COMPZN RPCOMP KLWL T Continue Shut down and monitor well 00:00 02:00 IA would not stop flowing tubing Static Shut in well and monitor well w/ no pres build up and order 290 bbls filtered 9.6 brine 12/27/2018 12/27/2018 1.50 COMPZN RPCOMP KLWL T Start pumping 9.6 filtered brine @ 2 02:00 03:30 bbls min w/ no returns pumped Tot 186 BELS of 9.6 Brine. RID lines and set H -P BPV. Well on Vacuum Page 4/5 Report Printed: 112112019 Operations Summary (with Timelog Depths) 2T-203 WMIZ�11,, 01 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Depth Start Time End Time Dur inn Phase op Code Activity Code Time P-T-x operation (flKB) End Depth(ftKB) 12/27/2018 12/27/2018 0.50 COMPZN WHDBOP OWFF T Shut down and monitor well 30 min 0330 0400 All good No flow 12/27/2018 12/27/2018 0.50 COMPZN WHDBOP MPSP P R/D lines and set H-P BPV Well on 04:00 04:30 Vacuum 12/27/2018 12/27/2018 8.00 COMPZN RPCOMP NUND P N/D BOP and N/U FMC Tree 04:30 12:30 12/27/2018 12/27/2018 2.50 COMPZN WHDBOP PRTS P RU LRS test tree to 250/5000 PSI for 12:30 15:00 1 15 Min each. 12/27/2018 12/27/2018 2.00 COMPZN WHDBOP MPSP P Pull tree test plug. RU lubricator test 15:00 1700 to1000 PSI. Pull BPV. RD lubricator 12/27/2018 12/27/2018 2.00 COMPZN WHDBOP CRIH P LRS reverse circulate100 Bbls 9.6 17:00 1900 filtered brine with 1% CRW 132 corrosion inhibitor at 2BPM, 650 PSI. 12/27/2018 12/27/2018 1.00 COMPZN WHDBOP FRZP P LRS freeze protect with 97 Bbls of 19:00 2000 diesel at 2BPM, 750 PSI. Allow well to U-Tube. RD LRS. 12/27/2018 12/27/2018 2.00 COMPZN WHDBOP MPSP P RU lubricator, test to 1000 PSI. Set 2000 2200 1 1 1 1 IHP BPV. RD lubricator. 12/27/2018 12/28/2018 2.00 DEMOB MOVE RURD P Install tree cap. RD circulating 2200 0000 1 I equipment. RD secondary annulus valve. RIG RELEASED at 0:00 Page 5/5 Report Printed: 1/21/2019 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Tabasco Oil Pool Tabasco Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7525' 3102' 7484' 3104'937 None None Casing Collapse Conductor Surface Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU 2T-203 5654-5737' 5991-6033' 6035-6657' 6704-6746' 6748-7371' 7373-7415' 6018' 4-1/2" 3017-3035' 3087-3095' 3095-3115' 3116-3116' 3116-3109' 3109-3107' 6/25/2024 7484'1901' 4-1/2" 3104' Viking ESP Baker SC-1R 1579' 6046' Perforation Depth MD (ft): 108' 1610' 3097'7-5/8" 16" 10-3/4" 77' Burst 4667' MD 108' 1546' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025569, ADL0025548 205-197 P.O. Box 100360, Anchorage, AK 99510 50-103-20520-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 4532'MD/2699'TVD 5583'MD/3003'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field Adam Klem adam.klem@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:09 pm, Apr 30, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@conocophillips.com, C=US Reason: Location: Date: 2024.04.30 14:13:14-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem SFD 5/1/2024 DSR-4/30/24 X 10-404 BOP test to 2500 psig Annular preventer test to 2500 psig VTL 5/8/2024 X ESP CO JLC 5/8/2024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 15, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 2T-203 (PTD# 205-197). 2T-203 is a producer drilled in 2005 completed with 4.5" tubing and 7 5/8" casing. It was worked over in 2023 to replace a failed ESP cable, and right after the workover it appears the ESP failed.. A rotary workover is required to pull the tubing and ESP and replace the ESP. If you have any questions or require any further information, please contact me at 907-263-4529 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem @conocophillips.com, C=US Reason: Location: Date: 2024.04.30 14:12:49-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 2T-203 RWO Procedure Tabasco Producer PTD #205-197 Page 1 of 2 Remaining Pre-Rig Work 1. Install DV in all GLM, 2. Set plug and catcher in nipple at 4546 MD 3. MITT and MITIA to 2500psi each for 30 min 4. Pull the DV leaving the GLM at 4464MD open for circ 5. Pull plug and catcher 6. Prep well for rig. Rig Work 1. MIRU Nordic 3 on 2T-203. 2. Circulate in KW brine (est 8.8ppg KW brine) 3. Shut the well in and perform no flow test for 30 min to verify KW. 4. Set BPV, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. 5. Pull BPV, MU landing joint and BOLDS. 6. Pull 4-1/2 tubing laying down tubing, packer and ESP a. Packer is a simple pull to release so should pull free 7. MU new ESP and 4 ½ completion 8. Once on depth, space out and MU tubing hanger 9. Circulate in corrosion inhibited fluid into the IA 10. Land the tubing hanger, RILDS and pull the landing joint 11. Drop ball and rod. Pressure up to set packer 12. PT tubing to 3000psi for 30 minutes. Chart. 13. PT IA to 2500psi for 30 minutes. Chart. 14. Shear SOV 15. Install BPV and PT from below 16. ND BOPE. NU tree. 17. Pull BPV, freeze protect well 18. RDMO. Post-Rig Work 19. Handoff to operations to put back on production General Well info: Wellhead type/pressure rating: FMC Tabasco Gen 2, 5M psi top flange Production Engineer: Natalie Dye Reservoir Development Engineer: Mandy Pogany Estimated Start Date: 6/25/24 Workover Engineer: Adam Klem (263-4529/ adam.klem@conocophillips.com) Current Operations: This well is currently producing on gas lift Well Type: Producer Scope of Work: Pull the existing 4.5completion and replace the ESP and production packer BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram MIT results: MITT and MITIA planned pre rig 2T-203 RWO Procedure Tabasco Producer PTD #205-197 Page 2 of 2 IC POT & PPPOT: passed 4/29/23 TBG POT &PPPOT: failed 4/29/23 MPSP: 937 psi using 0.1 psi/ft gradient Static BHP: 1,210 psi / 2723 TVD measured on 8/21/23 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: 4,496.0 2T-203 9/4/2007 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull SOV & ESP equipment, set OV - GL conversion 2T-203 9/17/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: ZONES NOT LOADED INTO WELLVIEW 12/9/2010 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.79 30.8 1,609.8 1,546.2 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 28.2 6,046.1 3,096.9 29.70 L-80 BTCM LINER 4 1/2 3.96 5,582.6 7,484.0 3,103.7 12.60 13 CR VAM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.3 Set Depth 4,667.0 Set Depth 2,743.6 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,191.3 1,940.8 62.01 Mandrel GAS LIFT 6.403 4 1/2" x 1" KBMG, GLM Camco KBMG 3.865 4,399.8 2,657.4 71.66 Sensor - Discharge Gauge 6.039 4 1/2" 12.6 ppf OPSIS Dual Sensor, Hyd 563 BxP HES OPSIS 3.913 4,464.1 2,677.7 71.58 Mandrel GAS LIFT 6.350 4 1/2" x 1" KBMG, GLM Camco KBMG 3.865 4,531.6 2,699.3 71.07 PACKER 6.875 7 5/8" x 4 1/2" Viking ESP Packer, 5K PSI W.P. Viking 12ESP 3.898 4,545.8 2,703.9 70.96 Nipple - DB 5.210 4 1/2" x 3.813" DB-6' Nipple Camco DB-6 3.813 4,553.5 2,706.4 70.91 Sensor - Discharge Gauge 5.620 4 1/2" Vigilant Discharge Pressure Tubing Sub Summit Vigilant Sensor 3.958 4,615.1 2,726.6 70.89 Annular Connection Port (ACP) 5.380 TCC Perforated Intake Summit TCC Perforat ed Intake 3.958 4,625.8 2,730.1 70.89 Seal - Protector 5.250 Upper 513 Series Tandem Seal Section Summit 513 Series 3.630 4,643.7 2,735.9 70.90 Motor 5.620 562 Sieries Motor, KMS2, 180HP/2290V/48A Summit 562 Motor, 180 HP 3.630 4,664.0 2,742.6 70.81 Motor - Adapter 4.560 Adapter, Gauge to 562 Motor Summit Adapter 2.060 4,664.3 2,742.7 70.81 Sensor - Discharge Gauge 3.750 Vigilant, Sensor, High Temp, 150C w/ Discharge Pressure 5000 psi Summit Vigilant Sensor 2.560 4,666.2 2,743.3 70.80 Centralizer 6.000 Centralizer, 2 3/8", EUE, 7" Casing, 6" OD Summit Centraliz er Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,191.3 1,940.8 62.01 1 DMY BK 1 8/21/2023 SLB KBMG 4,464.1 2,677.7 71.58 2 GAS LIFT OV BK 1 9/15/2023 SLB KBMG 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,582.6 3,003.3 78.45 PACKER 6.690 BAKER SC-1R Liner Top Packer BAKER SC-1R 76A4-40 4.000 5,586.8 3,004.2 78.57 MILLOUT 5.500 MILLOUT EXTENSION 3.958 5,592.4 3,005.2 78.72 XO THREAD 6.050 3.958 5,603.6 3,007.4 78.88 KOIV TOOL 5.000 3.500 5,606.1 3,007.9 78.85 KOIV 5.000 3.500 7,475.9 3,104.1 93.08 Flapper VLV 1 5.520 3.000 7,477.3 3,104.0 93.08 Flapper VLV 2 5.520 3.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,654.0 5,737.0 3,017.4 3,034.6 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 5,991.0 6,033.0 3,086.9 3,094.5 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,035.0 6,657.0 3,094.9 3,114.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,704.0 6,746.0 3,115.7 3,116.4 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,748.0 7,371.0 3,116.4 3,108.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 7,373.0 7,415.0 3,108.6 3,107.0 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores DEVIATED, 2T-203, 9/18/2023 5:42:09 AM Vertical schematic (actual) LINER; 5,582.6-7,484.0 SLOTS; 7,373.0-7,415.0 SLOTS; 6,748.0-7,371.0 SLOTS; 6,704.0-6,746.0 SLOTS; 6,035.0-6,657.0 PRODUCTION; 28.2-6,046.1 SLOTS; 5,991.0-6,033.0 SLOTS; 5,654.0-5,737.0 Motor; 4,643.7 Seal - Protector; 4,625.8 Annular Connection Port (ACP); 4,615.0 Nipple - DB; 4,545.8 PACKER; 4,531.6 Mandrel GAS LIFT; 4,464.1 Sensor - Discharge Gauge; 4,399.8 Mandrel GAS LIFT; 2,191.3 SURFACE; 30.8-1,609.8 CONDUCTOR; 31.0-108.0 Tubing hanger; 25.3 KUP PROD KB-Grd (ft) 33.99 RR Date 2/25/2006 Other Elev 2T-203 ... TD Act Btm (ftKB) 7,525.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032052000 Wellbore Status PROD Max Angle & MD Incl (°) 93.24 MD (ftKB) 7,282.91 WELLNAME WELLBORE Annotation Last WO: End Date 8/11/2023 H2S (ppm) 53 Date 12/9/2022 Comment SSSV: NONE 2T-203 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108 108 16 15.06 62.5 H-40 0 0 Surface 1609 1546 10.75 9.95 45.5 L-80 BTC BTC Production 6046 3097 7.625 6.87 29.7 L-80 BTCM BTCM Liner 7484 3103 4.5 3.96 12.6 L-80 VAM VAM Tubing 4650 2738 4.5 3.96 12.6 L-80 TXP TXP PROPOSED COMPLETION 4-1/2" 12.6# L-80 Hyd563 Tubing to surface 4-1/2" GLMs @ TBD HES Tbg/IA sensing DHG Viking Feedthrough packer 3.813" X Nipple Summit Pump and Motor Motor Centralizer REMAINING COMPLETION LEFT IN HOLE Linertop Packer and Perfs with Screens from 5582' RKB to 77484' RKB (3.25" ID) Surface Casing Production Liner w/ slots Conductor Perfs for Tabasco ESP Production Casing DHG n • RECEIVED STATE OF ALASKA ALOKA OIL AND GAS CONSERVATION COMMISSION FEB 2 0 REPORT OF SUNDRY WELL OPERATIONS 2018 1.Operations Abandon l Rug Perforations r Fracture Stimulate J- Pull Tubing r 'i. O w n r Performed: Suspend fl Perforate r Other Stimulate fl Alter J— Change Approve ram r Rug for Redrill fl Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Convert to Gaslift IV 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1707 Explorator l 205-197 3.Address: Service 6.API Number: Stratigraphic P. O. Box 100360, Anchorage, Alaska 99510 50-103-20520-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25569/25548 KRU 2T-203 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Tabasco Oil Pool 11.Present Well Condition Summary: Total Depth measured 7525 feet Plugs(measured) None true vertical 3102 feet Junk(measured) None Effective Depth measured 7484 feet Packer(measured) 0 true vertical 3104 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 108' 108' SURFACE 1579' 10 3/4 1610' 1546' PRODUCTION 6018' 7 5/8 6046' 3097' LINER 1901' 41/2 7484' 3116' Perforation depth: Measured depth: Slots: 5654-5737; 5991-7415 M' R ; True Vertical Depth: 3017-3035; 3087-3107~ Tubing(size,grade,MD,and ND) 4 1/2 ,L-80,4560 MD,2709 TVD Packers&SSSV(type,MD,and ND) Packer=BAKER SC-1R Liner Top Packer, Packer MD=5583;TVD=3003 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 NA NA Subsequent to operation 518 82 2901 936 261 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Fi Exploratory J-' Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run J! 16.Well Status after work: Oil J;r''... Gas fl WDSPL J Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ E SUSP r SPLUG 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: 318-023 Contact Adam Childs Email: adam.q.childs(cr�conocophillips.com Printed Name Adamc)z.....___Childs Title: Staff Petroleum Engineer Signature Phone:263-4690 Date 2/19/2018 VTt 3/I //8 A We REOMS FFr , 2018 Form 10-404 Revised 5/2015 Submit Original Only • 2T-203 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/01/18 2T-203 brought onto production with lift gas while waiting on RWO to replace ESP motor a • KUP D 2T-203 y' Conoco Phillips- ips Well Attribl Max Angle&MD TD :a Wellbore API/UWI Field Name Wellbore Status ncl(1 MD(ftKB) Act Btm(ftKB) Alas/',-n,.11ry; 4. 501032052000 TABASCO PROD 9324 7,282.91 7,525.0 C .P.vphdl+ Comment H2S(ppm) Date Annotation End Date 'KB-Grd(ft) Rig Release Date ... SSSV:NONE 100 11/22/2015 Last WO: 12/7/2007 33.99 2/25/2006 DEVIATED-21-203,2/19/2018 1133:48 AM Last Tag "...Vertical schem000(actue✓)....... Annotation Depth(ftKB) End Date Last Mod By Last Tag: 4,496.0 9/4/2007 WV5.3 Conversion Hanger;25.2-4 •I Last Rev Reason Annotation End Date Last Mod By Rev Reason:GLV C/O-(pump and motor need to be troubleshot) 1/30/2018 pproven Casing Strings ' I. {I�I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 108.0 108.0 62.50 H-40 WELDED u y Casing Description 00(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(L..Grade Top Thread SURFACE 103/4 9.794 30.8 1,609.8 1,546.2 45.50 L-80 BTC Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 5/8 6.875 28.2 6,046.1 3,096.9 29.70 L-80 BTCM 111 t Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread -^..-h CONDUCTOR;31.0-108.0' LINER 41/2 3.958 5,582.6 7,484.0 3,103.7 12.6013 CR VAM Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inel(°) Item Des Corn (in) SURFACE;30.8-1,609.8- 5,582.6 3,003.3 78.45 PACKER BAKER SC-1R Liner Top Packer 4.000 5,586.8 3,004.2 78.57 MILLOUT MILLOUT EXTENSION 3.958 5,593.1 ' 3,005.4 78.75 SEAL Sealbore w/4.5"Vam Top SealboreA 3.250 ESP MANDREL 2,909.3 - 5,603.6 3,007.4 78.88 KOIV TOOL 3.500 5,606.1 3,007.9 78.85 KOIV 3.500 -: 5,650.9 3,016.7 78.42 SEAL Sealbore w/4.5"Vam Top SealboreB 3.250 • • 5,944.1 3,078.1 78.89 SEAL Sealbore w/4.5"Vam Top SealboreC 3.250 ESP MANDREL 4,426.3 5,988.3 3,086.4 79.38 SEAL Sealbore w/4.5'Vam Top SealboreD 3250 6,032.6 3,094.5 79.49 SEAL Sealbore w/4.5"Vam Top SealboreE 3250 6,657.4 3,114.7 88.59 SEAL 'Sealbore w/4.5"Vam Top SealboreF 3.250 Discharge Gauge,4,491.23 6,701.4' 3,115.7 88.88 SEAL Sealbore w/4.5"Vam Top SealboreG 3.250 6,745.7° 3,116.4 89.49 SEAL Sealbore w/4.5"Vam Top SealboreH 3.250 7,370.7 3,108.7 91.98 SEAL Sealbore w/4.5"Vam Top Sealborel 3250 ,,,. 7,416.7 3,107.0 92.40 SEAL Sealbore w/4.5"yam Top SealboreJ 3.250 ESP Intake;4,561.9 - 7,457.3 3,105.1° 92.93 SEAL Sealbore w/4.5"Vam Top SealboreK 3.250 Upper Tandem Seel Section; RIMIN 4,572.4' 7,475.9 3,104.1 93.08 Flapper VLV 1 3.000 Lower Tandem Seel Section; 4,579a _1. AMM, 7,477.3 3,104.0 93.08 Flapper VLV 2 - 3.000 0i ESP Motors;4,588.2 4 ® Tubing Strings MotorGauge'4,805.7 s_ Tubing Description !String Ma...1ID(in) !Top(ftKB) Set Depth(ft..Set Depth(TVD)( 1Wt(lb/ft) Grade 'Top Connection Motor Centralizer;4,607.5 ( ) Tubing-RW02017 4112 3.958 25.31 4,609.5 2,7247 12.60L-80 TXPM Completion Details Top(ND) Top Incl Nominal i Top(ftKB) (ftKB) (') Item Des Com ID(in) 25.3 25.3 0.00 Hanger Tubing Hanger,FMC,TC-BH-EMS-EC-HT,11"x 4-1/2",5"RH 3.958 Acme Top x 4-1/2"TXP Bottom,CIW 4"H BPVG = 4,491.2 2,686.3 71.38 Discharge WeIILift Discharge Gauge Unit,Centrilift 3.958 Gauge 4,561.9 2,709.1 70.87 ESP Intake TTC Drilled Crossover,Centrilift 4,572.4 2,712.6 70.87 Upper Tandem Upper Tandem Seal Section,Centrilift Seal Section 4,579.3 2,714.9 70.88 Lower Tandem Lower Tandem Seal Section,Centrilift Seal Section VW SLOTS;5,854.05,737.0-- i 4,586.2 2,717.1 70.88 ESP Motors ESP Motor,Centrilift,300HP/3620V/51A 4,605.7 2,723.5 70.88 Motor Gauge WeIILift E Motor Gauge Unit,Centrilift 4,607.6 2,724.1 70.89 Motor Centralizer Motor Centralizer,Centrilift Perforations&Slots Shot Dots Top(ND) Btm(ND) (shots/ft SLOTS;5,991.0-6,033.0-, !Ai Top(ftKB) Btm(ftKB) (ftKB) (0KB) Zone Date ) Type Com 5,654.0 5,737.0 3,017.4 3,034.6 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores I ., I 5,991.0 6,033.0 3,086.9 3,094.5 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores '�';; I 6,035.0 6,657.0 3,094.9 3,114.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse PRODUCTION;28.2-6,046.1-._. screen/sealbores SLOTS;6,035.0-6,657.0--. 72, 6,704.0 6,746.0 3,115.7 3,116.4 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores 6,748.0 7,371.0 3,116.4 3,108.7' 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores SLOTS;6,704.05,748.0 7,373.0 7,415.0 3,108.6 3,107.0 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse amisscreen/sealbores Mandrel Inserts atit SLOTS;"810-7137" . ,748.07,371.0 8 on Top(ND) Valve Latch Port Size TRO Run ,„..4, N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type _ (in) (psi) Run Dale Corn 1 2,909.3 2,198.3 Camco KBMG 1 ESP GLV BK 0.188 1,509.0 1/24/2018 2. 2 4,426.3 2,665.7 Camco KBMG 1 ESP OV BK 0.250 0.0 1/24/2018 SLOTS;7,373.0-7,415.0 Notes:General&Safety End Date Annotation 12/9/2010 NOTE:ZONES NOT LOADED INTO WELLVIEW 12/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 LINER;5,5826-7,484.0 L OF T • • 0.)",%'\1vj��s THE STATE Alaska Oil and Gas -- M O LAsKA Conservation Commission f;>= 333 West Seventh Avenue fie GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 9,0; ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Adam Childs Staff Petroleum Engineer iCANNE�? t w th 6 'u h ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2T-203 Permit to Drill Number: 205-197 Sundry Number: 318-023 Dear Mr. Childs: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 611 (YN, Hollis S. French Chair DATED this�day of January, 2018. REM; - 2018 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 1 8 2018 APPLICATION FOR SUNDRY APPROVALS 0—' iis` (/o '' s# G 20 AAC 25.280 C C 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to Gaslift n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory ❑ Development 2 • 205-197 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20520-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA f Will planned perforations require a spacing exception? Yes ❑ No 10 KRU 2T-203 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569/25548 ' Kuparuk River Field/Tabasco Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7525 3102 ' 7484 . 3104 ' None None Casing' Length Size MD TVD Burst Collapse Structural Conductor 77' 16 108' 108' Surface 1579' 10 3/4 1610' 1546' Intermediate Production 6018' 7 5/8 6046' 3097' Liner 1901' 4 1/2 7484' 3116' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:5654-5737;5991-7415 ' 3017-3035;3087-3107 4 1/2 L-80 4650 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV=None, Packer=BAKER SC-1R Liner Top Packer SSSV=None, Packer MD=5583,Packer TVD=3003 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/1/2018 Commencing Operations: OIL ❑ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Adam Childs Contact Name: Adam Childs Authorized Title: Staff Petrol_um Eno ineer Contact Email: adam. .childs conocophillips.com i Contact Phone: 907-263-4690 Authorized Signature: w�� Date: l/1$/I g COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: — 6/1,� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ROOMS r - 1 2rt..18 Spacing Exception Required? Yes ❑ No i Subsequent Form Required: le -40 Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: I 31=, I I 42 A5 VZ5//" A(//111i4 V / Submit Form and Form 10-403 Revised 4/2017 Approved application I i1QctLt sNr 1ALate of approval. Attachments in Duplicate • 2T-203 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. is seeking approval to convert the artificial lift method from Electric Submersible Pump (ESP)to gaslifted production in Tabasco well 2T-203 as the ESP motor recently failed, halting production. Converting the artificial lift method to gaslift will restore production until such time as a rig workover can be executed. This well was successfully placed on gas lift in 2017 (sundry#316-638)while awaiting a rig workover to replace and upsize the tubing conveyed ESP. The upsized ESP was set at 4562' MD and placed on production from 7/26/17 to 12/27/17 when an ESP motor failure occurred. The 4.5"tubing is equipped with 1"side-pocket gaslift mandrels at 2743' &4427' RKB. These mandrels are currently dummied off. Prior to the 2017 RWO, a gas MIT of the inner annulus was performed to 1000 psi 12/9 - 12/10/16. IA and OA fluid levels remained unchanged after an overnight monitoring period. Cumulative pressure drop for the test period was 19 psi, with 16 psi occurring in the first 15 mins. An unloading valve will be installed in the mandrel at 2743' RKB, and an orifice valve will be installed in the mandrel at 4427', through which lift gas will enter the tubing. KUP PROD • 2T-203 .p-� ConocoPhdIips Ø Well Attributes Max Angle&MD TD Alaska.Inc, Wellbore APIAIWI Plaid Name Wellbore Status (•) MD(hKB (ft ) Act Btm KB) 0,..,,,,d,""0,..,,,,d,"" 501032052000 TABASCO PROD 1nct 93.24 7,282.91 7,525.0 ' --- Conlmerlt 8125(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Data DEVIATED-2T-203,82820174'3529 PM SSSV:NONE 100 11/22/2015 Last WO: 12/7/2007 33.99 2/25/2006 Vertical sMenNBc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 4,496.0 9/42007 Rev Reason:PULL/REPLACE PACKOFF 8 pproven 8/22017 • SLIPSTOP,GLV C/O Hanger;25.2- itti:t.ik i Casing Strings Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread 1 SURFACE 103/4 9.794 30.8 1.609.8 1,546.2 45.50 L-80 BIC ,m MI4W56,.,81111/, ua,.,.,,nu. ,-,.,,:,.:,.I� I up.,Casing Description OD(In) 10(In) Top(ftKB) Set Depth(5103) Set Depth(TVD)...WULen(I...Grade Top Thread I PRODUCTION 75/8 6.875 28.2 6,046.1 3,096.9 29.70 L-80 BTCM • Casing Description OD(In) 11)(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread LINER 41/2 3.958 5,582.6 7,484.0 3,103.7 12.6013 CR VAM Liner Details M1CONOUCTOR:31.0-108.0- Nominal ID Top(ftKB) Top(TVD)(ftKB) Top incl(1 hem Des Com (In) 5,582.6 3,003.3 78.45 PACKER BAKER SC-1R Liner Top Packer 4.000 5,586.8 3,004.2 78.57 MILLOUT MiLLOUT EXTENSION 3.958 SURFACE:30.8-1609.5- 5,593.1 3,005.4 78.75 SEAL Sealborew/4.5"Vam Top SealboreA 3.250 5,603.6 3,007.4 78.88 KOIV TOOL 3.500 5,606.1 3,007.9 78.85 KOIV 3.500 ESP MANDREL;2,909.3 5,650.9 3,016.7 78.42 SEAL -Sealbore w/4.5"Vam Top SealboreB 3.250 5,944.1 3,078.1 78.89 SEAL Sealbore w/4.5"Vam Top SealboreC ' 3.250 --- 5,988.3 3,086.4 79.38 SEAL Sealbore w/4.5"Vam Top SealboreD 3.250 ESP MANDREL;4.426.3 6,032.6 3.094.5 79.49 SEAL Sealbore w/4.5"Vam Top SealboreE 3.250 6,657.4 3,114.7 88.59 SEAL Sealbore w14.5"Vam Top SealboreF 3.250 6,701.4 3,115.7 88.88 SEAL Sealbore w/4.5"Vam Top SealboreG 3.250 it.. 6,745.7 3,116.4 89.49 SEAL Sealbore w14.5"yam Top SealboreH 3.250 Discharge Gauge.44912 . . "- - 7,370.7 3.108.7 91,98 SEAL Sealbore w14.5"Vam Top Sealborel 3.250 • 7,416.7 3,107.0 92.40 SEAL Sealbore w/4.5"yam Top SealboreJ 3.250 SLIPSTOP;4,501.0 - I 7,457.3 3,105.1 92.93 SEAL Sealbore w/4.5"Vam Top SealboreK 3.250 PACKOFF:4,503.0 7,475.9 3,104.1 93.06 Flapper VLV 1 3.000 7,477.3 3.104.0 93.08 Flapper VLV 2 3.000 Tubing Strings ESP Make;4,561.9, 4"7-- Tubing Description String Ma...ID(In) Top(HIKE) Set Depth(ft..,Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection Upper Tandem Seal Section; 4,572.41 Tubing-RWO 2017 41/2 3.958 25.3 4,609.5 2,724.7 12.60 L-80 TXPM Lower Tandem seal Section:4.57.7 - 9Completion Details ESP Motors.4,586,2Nominal ID _ Motor Gauge'4605.7 ".7_, Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) Mo Motortor Gauge.d 607.5 ' 25.3 25.3 0.00 Hanger Tubing Hanger,FMC,TC.BH-EMS-EC-HT,11"x4-12", 3.958 5"RH Acme Top x 4-1/T TXP Bottom,CIW 4"H BPVG 4,491.2 2,686.3 71.38 Discharge We11Litt Discharge Gauge Unit.Centrllllt 3.958 O Gauge •= 4,561.9 2,709.1 70.87 ESP Intake TTC Drilled Crossover,Centrilift j 4,572.4 2,712.6 70.87 Upper Upper Tandem Seal Section,Centrilift Tandem Seal Section 1111 . 4,579.3 2,714.9 70.88 Lower Lower Tandem Seal Section,Centrilift Tandem Seal Section 4,586.2 2,717.1 70.88 ESP Motors ESP Motor,Centrilift,300HP/3620V/51A SLOTS;5,854.0-5.737.0-� ' 4,605.7 2,723.5 70.88 Motor Gauge We11Llth t E Motor Gauge Untt,Centrlli a>it 4,607.6 2,724.1 70.89 Motor Motor Centralizer.Centrilift ICentralizer Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) U Top(ftKB) (ftKTop(TVDB) (")) Top Incl pee Com Run Data ID(in) 4,501.0 2,689.4 71.30 SLIPSTOP 4 1/T SLIP STOP 8/21/2017 4,503.0 2,690.0 71.29 PACKOFF 4-12"GS(114"BRASS)8 D8D PACKOFF w/EG 8/21/2017 SLOTS,6991.0-6,033.0- DEVICE 8 CHECK(OAL=57-,38.5'TO EO. DEVICE) Perforations&Slots t shot Dens Top(TVD) elm(TVD) (shout PRODUCTION;28.2-6,046.1 , :_: Top(kK8) atm(ftKB) (ftKB) (ftKB) Zone Dale II Type Com SLOTS;6.035.0-6657.0-. 5,654.0 5,737,0 3,017.4 3,034.6 2/16/2006 99.0 SLOTS Alternating Excl2K • 111r - i Coarse screen/sealbores el 5,991.0 6,033.0 3,086.9 3,094.5 2/16/2006 99.0 SLOTS Alternating EvcI2K _ Coarse screen/sealbores SLOTS:6.704.0-8.746.0. 6,035.0 6.657.0 3,094.9 3,114.7 2/1612006 99.0 SLOTS Alternating Excl2K Coarse screen/seatbores stors:s T4s x73710 6,7040 6,746.0 3,115.7 3,116.4 2/16/2006 99.0 SLOTS Alternating Excl2K - b Coarse screen/sea(bores 411r r•. 6.748.0 7.371.0 3,116.4 3,108.7 2/16/2006 99.0 SLOTS Alternating Excl2K Coarse screen/sealbores SLOTS,7.373.0-7415.0 lir7,373.0 7,415.0 3,108.6 3,107.0 2/16/2006 99.0 SLOTS Alternating Excl2K izini Coarse screen/sealbores IP 1111 LINER;5,582.6-7404.0 KUP PROD • 2T-203 ConocoPhillips O , Alaska,Inc. ronacd4vPipe DEVIATED-21-203,8/28/2017 4:3530 PM Vertical schematic(actual) Hanger.25.2- Mandrel Inserts r St lttt en R Toff(TVD) Valve e Port 9lze TRO Run Top MKS) (ftNBJ Make Mede) OD(In) Sere Typ Type Type (In) (psi) Run Dale Com 1 2,909.3 2,198.3 Camco KBMG 1 ESP GLV BK 0.188 1,486.0 1/26/2017 Debris 2- 4,426.3 2,665.7 Camco KBMG 1 ESP SOV BK 0.000 0.0 7/25/2017 2000 lb TBG Shear -, vCONDUCTOR:31.o 108.0 i Notes:General&Safety End Dale Annotation 12/6/2010 NOTE:ZONES NOT LOADED INTO WELLVIEW SURFACE,30.8.1,6098- 12/9/2010 NOTE:View Schematic wl Alaska Schematic9.0 ESP MANDREL;2.9093 ESP MANDREL.9,426.3 Discharge 00690;4.491.2 SLIPSTOP;4,5070 j PAC 60FF,4,503 I 03.0 ESP Intake;4,561.9• , IPS Upper Tandem Seal Section; 4.572 41 Lower Tandem Seal Seclon; 4,579.3 ESP Motors:4586.2 Motor Gauye:4,805.7 Motor Centralzer,4.607.5 , i4j • 1 , SLOTS;5654.0-57370 I SLOTS;5,991.0-6,0330- PRODUCT VON;382-8.057.1 - SLOTS;8035.0-8.6570-� SLOTS,6.704.0-6.748 0 SLOTS'.6.7/8.0-7,371 0 IR yac SLOTS;7,373.0-7,415:0 LINER;5.582.6-7.484 0 • S Loepp, Victoria T (DOA) From: Childs,Adam G <Adam.G.Childs@conocophillips.com> Sent: Thursday,January 25, 2018 8:25 AM To: Loepp,Victoria T(DOA) Subject: ConocoPhillips 2T-203 10-403 Application Good Morning Victoria, Last week we submitted a 10-403 application to convert the 2T-203 from ESP to Gas Lift. I just wanted to provide one update to this application and offer my assistance if there are any questions on it. The Description Summary of Proposal section from the application submitted made reference to the MITIA that was performed in Dec 2016.The update to this is that we performed another successful gas MITIA this week. On 1/22 at 14:45 we tested the well to 1000 psi.Through 1/24 at 08:15(41.5 hrs)the well had only lost 10 psi. The scope of our proposal is similar to what we did last year when we submitted and received approval on Sundry#316- 638.We will look to work up a rig workover to fix the well while returning it to production temporarily on gas lift. Please let me know if there are any questions on the application. Thank you, Adam Childs Staff Reservoir Engineer ConocoPhillips Alaska 907-263-4690 1 2 o5-kon • • 2-y5)4./ TRAI LL LOG SMITTAL RECEIVED PROACTIVE DIACINosTic SERVICES, INC. AUG 7 8 2017 AOGCC To: AOGCC Makana Bender DATA LOGGED 333 West 7th Avenue ta K.BENDER Suite 100 Anchorage, Alaska 99501 (907)793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C.Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED ,` E;:E7 () 6 21-111' 1) Caliper Report 16-Aug-17 2T-203 1 Report /CD 50-103-20520-00 2) 049.4.12.0.01.44si) Signed : '✓-.4 Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM MAchives\MasterTemplateFiles\TemplatesDistribution\TransmittalSheets\ConocoPhil l ips_Transmit.docx 2-1;5- 1/401 7 • RECEIVED • 2.654 { illi . AUG 2 8 2017 Memory Multi-Finger Caliper Lot 0 AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-203 Log Date: August 16, 2017 Field: Kuparuk Log No.: 14271 State: Alaska Run No.: 1 API No. 50-103-20520-00 Pipe Description: 4.5 inch 12.6 lb. L-80 Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 4,491 Ft. (MD) Inspection Type : Restriction Inspection COMMENTS : This caliper data is tied into the top of ESP Mandrel 2 at 4,426.3 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to I.D. restrictions, particularly around the two ESP Mandrels. The caliper recordings indicate possible I.D. restrictions at the bottom of both ESP Mandrels, restricting the I.D.to 3.76 inches at 2,916 feet and 3.80 inches at 4,432 feet. The 3.80 inch O.D. pump will likely encounter a tight spot at these two locations. 3-D log plots of the caliper recordings across each ESP Mandrel as well as a graph illustrating the minimum recorded diameters on a joint-by-joint basis are included in this report. The caliper recordings indicate the 4.5 inch tubing logged appears to be in good condition with respect to internal corrosive and mechanical damage, with no significant wall penetrations or areas of cross-sectional wall loss recorded. MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 14%)are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : Desariptlon Mum tum Recordeed'Diametero;rir ,r Possible Restriction in ESP Mandrel 1 3.76 inches 70.2 2,916 Ft. (MD) Possible Restriction in ESP Mandrel 2 3.80 inches 106.2 4,432 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt C. Waldrop S. Ferguson Field Engineers; At-lair/sirs) VVitrlebs,r,': ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • cr.-PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-203 Date : August 16, 2017 Description : Detail of Caliper Recordings Across ESP Mandrel 1. Nominal I.D. Depth 3-D Log Image Map 3.5 inches 4.5 lft:60ft 170° 0° 90° 180° 270° 0° Maximum I.D. 3.5 inches 4.5 Minimum I.D. I 3.5inches 4.5 I wa.a A 2900 — 2905 -. -- 2910 0 2915 i':f,i, . .;,,,,,„,:. / - .,..__ I . :::,:::;:,,, :',,: „ „,„:. - 1-:i 2920 Possible I.D. - Restriction of 3.76" n,�;: at the Bottom of 2925 ESP Mandrel 1 • e , _ s PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-203 Date : August 16, 2017 Description : Detail of Caliper Recordings Across ESP Mandrel 2. Nominal I.D. Depth 3-D Log Image Map • IIIIIIIIIIIIIIIIIIIIIMIE------1 -1--_-- 3.5 inches 4.5 lft 60ft 0° 0° 90° 180 270° 0° Maximum I.D. 3.5 inches 4.5 Minimum I.D. I I 3.5 inches 4.5 --.7-7 J ---_---- --._.----- ---.. -,- .--.--- ---.77- 4415 L---- 4420 -- =...._. __– 1 4425 _ --z--- , = ,. , 1 . 4430 ,., rz .. t r OININ 1 ,,..1 _ 4435 --L. ---,:=----- 1 _,- - - Possible I.D. Restriction of 3.80" 4440 - - — at the Bottom of ._ _-- , ESP Mandrel 2 -- - _ I. ..,k •A ILC • • Ca. Minimum Diameter Profile Well: 2T-203 Survey Date: August 16,2017 Field: Kuparuk Tool Type: UW MFC 40 No.217958 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 3.958 inches Minimum Measured Diameters(in.) 2.75 3 3.25 3.5 3.75 0.17 - — - - - 12 2-] 76 7.] 281 12 498 17 702 22 898 27 1,094 32- 1,294 37 1 1,495 I 1 42, 1,700 1,906 la 47' i I 52- 2,114 C Z 57 j 2,322 C "5O 62 2,530 y C 67 2,736 70.2 2,909 74 3,052 I I I 79 ! 3,258 84 3,464 89 I 3,672 94 3,879 99 4,084 104 4,292 106.3 4,433 • • PDS Report Cross Sections Well: 2T-203 Survey Date: August 16,2017 Field: Kuparuk Tool Type: UW MFC 40 No.217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 Analyst: C.Waldrop Cross Section for Joint 70.2 at depth 2,915.663 Tool speed= 51 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area= 66% Tool deviation= 72° 1i 1 11* 111 . 14111114 Minimum I.D.=3.757 in. Possible Restriction at the bottom of ESP Mandrel 1 Minimum I.D.=3.76 in. HIGH SIDE=UP • • Ca PDS Report Cross Sections Well: 2T-203 Survey Date: August 16,2017 Field: Kuparuk Tool Type: UW MFC 40 No.217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 Analyst: C.Waldrop Cross Section for Joint 106.2 at depth 4,432.483 Tool speed= 52 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area= 68% Tool deviation=70° 7 1 441,11///////littliiiiiitoor \ A \ 1 allilimi I ‘IIIa i 5N 111Fitaiiir - . , ik. Minimum I.D.=3.800 in. Possible Restriction at the bottom of ESP Mandrel 2 Minimum I.D.=3.80 in. HIGH SIDE=UP • • Correlation of Recorded Damage to Borehole Profile • Pipe 1 4.5 in (12.3'-4,491.5') Well: 2T-203 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: August 16,2017 . Approx.Tool Deviation ■ Approx.Borehole Profile 1 15 10 417 20 : 820 30 'a 1,213 a 40 1,617 L � t 50 2,031 u_ Z t c 60 2,447 'o p 70 2,858 80 1 3,300 90 3,713 100 4,126 107.2 4,490 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=107.2 • • _ PDS Report Joint Tabulation Sheet ELI 0 Well: 2T-203 Survey Date: August 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 Tubing 3.958 in. 0.271 in. 12 ft. 4,491 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 12 0 0,02 8 2 3.94 . Pun 1 15 0 0.04 13 2 3.93 1.1 55 0 0.01 5 1 3.93 . Pun 7 1.2 63 0 0.01 5 1 3.93 Pup 1 1.3 71 0 0.02 6 1 3.93 Pun 2 76 0 0.03 11 3 3.93 3 117 0 0.03 11 2 3.94 a 4 158 0 0.03 11 2 3.94 • 5 199 0 0.03 9 3 3.93 ■ 6 240 0 0.03 10 2 3.94 ■ 7 281 0 0.03 10 1 3,94 is 8 321 0 0.02 8 1 3.94 • 9 363 0 0.04 14 2 3.94 NI 10 417 0 0.02 9 2 3.92 • 11 460 0 0.02 9 1 3.94 u 12 498 0 0.02 8 3 3.94 C 13 541 0 0.02 7 1 3.94 14 580 0 0.02 8 2 3.92 C 15 621 0 0.02 6 2 3.94 16 660 0 0.02 6 1 3,94 • 17 702 0 0.02 6 2 3.94 18 742 0 0.03 9 2 3.93 • 19 781 0 0.04 13 3 3.93 C 20 820 0 0.03 10 1 3.92 21 859 0 0.03 11 1 3.94 III 22 898 0 0.02 7 1 3.95 • 23 939 0 0.02 8 2 3.95 V 24 979 0 0.02 8 2 3.94 • 25 1017 0 0.02 7 2 3.95 • 26 1056 0 0.02 7 1 3.94 s 27 1094 0 0.03 10 2 3.94 • 28 1133 0 0.02 6 2 3.94 29 1174 0 0.03 10 2 3.93 • 30 1213 0 0.02 8 1 3.95 • 31 1252 0 0.02 6 1 3.94 1 32 1294 0 0.03 11 1 3.92 im 33 1335 0 0.02 6 1 3.93 II 34 1376 0 0.02 9 1 3.93 • 35 1415 0 0.03 11 2 3.93 ■ 36 1455 0 0.02 8 2 3.94 C 37 1495 0 0.02 7 1 3.93 38 1537 0 0,04 13 5 3.93 r 39 1576 0 0.02 7 1 3.93 40 1617 0 0.02 7 2 3.94 C 41 1659 0 0.02 6 1 3.95 42 1700 0 0.02 8 2 3.94 • 43 1742 0 0.02 7 1 3.92 • 44 1783 0 0,02 9 1 3.94 • 45 1825 0 0.02 9 1 3,93 • 46 1866 0 0.02 8 1 3.93 • IPenetration Body Metal Loss Body Page 1 0 • 11111 PDS Report Joint Tabulation Sheet Well: 2T-203 Survey Date: August 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf 1-80 Tubing 3.958 in. 0.271 in. 12 ft. 4,491 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 47 1906 0 0.02 7 3 3.93 48 1948 0 0.02 7 1 3.94 49 1990 0 0.02 7 1 3.94 0 50 2031 0 0.02 7 1 3.92 51 2073 0 0.02 6 1 3.94 52 2114 0 0.02 6 1 3.95 i 53 2156 0 0.02 8 1 3.92 • 54 2197 0 0.03 12 4 3.92 55 2239 0 0.02 7 3 3.92 56 2281 0 0.03 10 2 3.94 57 2322 0 0.03 10 2 3.94 I 58 2363 0 0.02 8 1 3.93 0 59 2405 0 0.03 10 3 3.94 r 60 2447 0 0.02 7 1 3.93 I 61 2488 0 0.03 10 2 3.92 62 2530 0 0.02 8 1 3.94 63 2571 0 0.02 7 2 3.93 0 64 2613 0 0.03 12 3 3.93 r 65 2654 0 0.02 9 2 3.94 66 2695 0 0.03 10 2 3.93 c 67 2736 0 0.02 6 1 3.92 . I' 68 2778 0 0.03 10 2 3.94 U 69 2820 0 0.02 8 1 3.94 • 70 2858 0 0.02 7 2 3.94 o 70,1 2899 0 0.03 9 1 3.90 Pup 0 70.2 2909 0 0 0 0 3.76 ESP MANDREL 1 (LATCH @ 4:30) 70.3 2917 0 0,02 7 3 3.92 Pup 71 2927 0 0.03 10 1 3.92 72 2968 0 0.02 6 1 3.93 i 73 3010 0 0.02 7 1 3.94 • 74 3052 0 0.03 10 2 3.93 • 75 3093 0 0.02 8 2 3.93 • 76 3134 0 0.04 13 2 3.93 III 77 3176 0 0.02 8 1 3.94 • 78 3217 0 0.04 13 1 3.94 in 79 3258 0 0.02 7 1 3.94 • 80 3300 0 0,02 8 1 3.94 • 81 3341 0 0.02 8 1 3.94 • 82 3381 0 0.03 9 2 3.93 r 83 3422 0 0.02 8 2 3.92 • 84 3464 0 0.02 6 1 3.94 • 85 3506 0 0.02 8 1 3.94 • 86 3547 0 0.02 7 3 3.93 ii 87 3589 0 0.03 9 1 3.93 r 88 3630 0 0.02 8 1 3.92 • 89 3672 0 0.03 11 2 3.92 r 90 3 713 0 0.03 12 1 3.94 IN 91 3755 . 0 0.02 7 1 3.94 i 92 3796 0 0.03 10 1 3.93 • 93 3838 0 0.02 7 2 3.92 Is IPenetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet Well: 2T-203 Survey Date: August 16, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf 1-80 Tubing 3.958 in. 0.271 in. 12 ft. 4,491 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 94 3879 0 0.03 10 2 3.93 t 95 3921 0 0.03 . 11 4 3.94 96 3962 0 0.02 8 1 3.92 97 4003 0 0.03 9 2 3.94 98 4043 0 0.02 7 2 3.93 . 99 4084 0 0.02 9 2 3.93 100 4126 0 0.02 7 2 3.91 101 4167 0 0.02 7 2 3.93 102 4208 0 0.02 6 1 3.95 MM 103 4250 0 0.02 7 3 3.94 11 104 4292 0 0.03 10 2 3.93 105 4333 0 0.03 9 1 3.93 106 4375 0 0.03 11 2 3.93 106.1 4416 0 0.04 14 2 3.90 Pup 106.2 4426 0 0 0 0 3.80 ESP MANDREL 2(LATCH a, 7:00) 106.3 4433 0 0.02 6 1 3.91 Pup 107 4443 0 0.04 13 2 3.93 107.1 4485 0 0.03 9 2 3.92 Pup • 107.2 4490 0 0 0 0 3.86 WELL LIFT DISCHARGE GAUGE Penetration Body Metal Loss Body Page 3 • 0 KUP PROD 2T-203 `- a Conoco i hillip�s Well Attributes Max Angle&MD TD Aia ",,, &Mauro ARAI eq Awe erre WOWS.Status ma 11 MO MINN Act Mrs IRKS) a,a„.,„„;n,y.y. 222252:2: "IAEA SCC PR.10 5324 7 282 61 15252 ... Commelt 921;:T: - 2:13c1at,o1 6na Date 1(6-GM{Y5 615 amen cats :f',A716042.:49'.'7 SSC:S♦... :,...P ti'iL'- 5 ___. 7. _ai:'W 2.,.__.7 33.99 c<5. V.efr sc-:-a.c- nna. •. 44pin -I na•.• 95.51.... us II Cl:. :ao-ma _as:Tac_. 4. _ S.‘.1.2:7 Re,Rea.- -...,-R-=.A..CE RAC,IC 4 R 3. 82,2: 7 "'•:-:': /// tas)ng Strings Ca•Irp C6acSptlls 00 iM1 a]ion' cy4RKS) Sat Cacti:!MKS; 88 Desats 4Ta0!-._Vrt.litt It...Gas. Tee nteaa ZI-ONDUCTOR 16 '5::52 3..'9 ..i 108.1 62.50 9440 WE.DED casing Deetatpticn Os(41 14M) op 4ttC6i Sat Oeptn OW 131 WINOS(raO1, en P...08 49 Toy Tnr096 �� JP ACE 903:4 5.754 30.8 .5 ..545.2 45.50 L30 ETC E. beeoptmae 00 PM c0 PM up 01881 Set cepte MRK B1 081 Oren; M.. WtAen4..Gad. Top Teresa PRODUCTION 758 S.875 2E2 5.:46.' ...0959 29.70,.-o: 3TC'! Casing Onro'Ipt.n 00444 ID Nel opOMB I Sat Cap44RK61 Seto. e4'rVj.. ens..Gads Tep Th•aS LINER 41.2 3.5.3E 5,5822.5 74&4.2 3 102 7 2_: _CR PAM Liner Details •45.-45-4.-COCSAC MS 11841.1.4 y..^...� w:T,aa C 7.532.5 ,.45. t--- :. _ -._ :C�aC%N 4.;02 5.566.8 3.034.2 55.57 __-- _-.-E. 3.956 walaapt a4,M.as- 5.553'. 3,:5.4 78.75 :c-._ 3.250 5.6013.5 3,:07.4 75.8E "Z.:_ 3.500 5.606.' 3.007 6 75.35 3.500 SSP INSSIORIL:S}012-.--111173.650.5 2,9 7- 79.42 SEA_ _ :.£_ 3.250 5,944.1 2.078.'.I 7589 SEAL. . 2,...::,5 3.250 3,9583 3 0394 753E SEAL _ .-: a_ 3.250 serww.s 44.1 8' c 5.032.6 3,294.5 79.49 SEAL ::£_::.._: .: _..._5:-10 3.290 6.5574 3.!'4.7 58.59 SEAL -:_..:.. -.:-_s, 3.250 5.7''14 3.1'57 02.88 SEAL __a._a..---..::55.52 3.250 8.749.7 59,49 SEAL __a__a.. .:_.a.. 3.250 �.... 5333.. ,.. :-,..z.::-,...- 2}a . .. _.acnaee aw0e.4 a4 7.375:.7 ?.'Di.7 3?.9$ SEAL 3£a::'i - s---.__,._= 3.250 7416.7 3'37,; 92.40'SEAL -' .a--::i;£;rs. 3.2X' aw1v.4.o+c 7.457.3 3t;5.t _4.53 SEAL Se .„7...........:: i _:::a:::. 3.256 MOMS: -0 I 7.475.5 3,734.9 91 03 Flapper VLV' 3.033 7.417.3 3.104.0 53.08 Rapper VLP2 3.030 Tubing strings .0...s.o .sa-£' Tualn6:::::,. $te9Iq Mm,.I611M7 :00:;::::: IS.,captnIt'..get OfyOIlT94...W1Y 1 Gale jug Can:I•egpl .foss.* ser ea a:Fi -.t...^; R ,7 I 4"7.221. 3.958 5:31 4.3 51 2,724.71 .2.5.01,.-80 1TX".! ''""ornemOaa'acre.: ComDetails 4.003 ESP aa..4-.n3 Nan9114 e1 Nrslega:SANT _ : TuLl„2,s::72.,:::::::::..,,, ttKsi T:C'-^.;s.:: IMF.stor....Mc SAWS 25.3 _._ __:-..:c = 3.99$ 4.49'.2 2.685.2 ___-_ :: 3.958 v£_ 4.551.9 2.709.' 72.87 ESP Inst£ TT: :'09s' ®'. 4572.4 2.712! 7787 J✓ee'-atte-1 Sea J__ __T,Zee Se-'a-C£•- -. 111 4.179.3 2.744.5 7:32 ..:..,...- ..c'.vE'Ta'.ar.Saa.Ec:,CE,_..-- 4,585.2 _7' ._s ESPMetors Ev= _._ _.. - 4,505.7 :.25.7 7:'33 Motor Gsupa „__.c _._-3a.;£.-:C_- . -0.637.6 57 swre.f,..4,, .0 i 724 70.85 Meter _-:-a :.C__-.. I .a► Centralizer •,_._.r-- s. :. Other In Hole(Wlreline retrievable plugs,valves,pumps,fish,etc.) 2:2 57.01 5:f 44 T-.5 ltt481 ttC91cot 1::n Ort• 1034) 4..391.0 2.65:.4 7t533 SUP'^-'OP 41,2"SUPSTOe ".29.23'7 4.503.: 2.692.3 7'29r33.22 2 083 PACK#P W.^KOBE{94'CA>.3E'T 7 7.2:.23.7 '.035.ZEROED 0 GS)(NO CHECK VA-VE; SLOTS:SIM..1.en.-- I - Perforations&Slots an0t I : 0'te 5c.1,2 Bt'sIT.OI (.nota? L 5 Top OMB) BttntrtKE, '^49: 1#501 CC'S 04Le 5 Type I air 5,654.0 3.737 3.017.4 3.034.6 21161006 99.0 81.01'S Axe'-£: . __ x. rRpWCT41l Zt...e1.1, ili_ + SUMS.0.41.tl1.�-. .fa._-___ a - 5.991.0 6.030.: 2:.569 3.:34.5 2116'2006 99.0 SLOTS E. Cease III 6.835.0 6.65': sea _."4.7 2'16'2096 99.0 SLOTS A7,'-.:';:-72::':E:-,1-: '__: ._. *018:1.70404,1464 6.704.0 6.749 2 _. 2116/2006 99.0 SLOTS = _.. Ccs-=:. _ Sea::'_- *oa.1.14e0q,ar,i - 6.748.0 7,37'.: 54 3.•39.7 211612006 99.0 SLOTS Ate"= ::: 3,4-3,,-.-. Sea::.5 : ow 7.373.0 7.4'5: _ __.6 2'07.0 Z'5072'5 994 SLOTS A!e..i.._o.._... sea _0 Ma Mandrel Inserts Mil st ss cat Top WAD) VMae Lean Pant Mn Tl0 Run -. 4 Top(rt4B) 15906) MS. MOON 00441 SMV Type Type IMI 4084 Run Dere Gem 8:81168'''' 8 Canso KBM)G 1 ESP GLV BK 0.188 1.486.0 1/26,2013 2 4,428.3 2.683.7 Cameo 69443 1.ESP OV BK 0.250 0.0 1;2522017 49ik fA7FT.4N0 STATE OF ALASKA • ALA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate EPull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Convert to Gaslift r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pro Explorator r 205-197 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 r 50-103-20520-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25569/25548 KRU 2T-203 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Tabasco Oil Pool 11.Present Well Condition Summary: Total Depth measured 7525 feet Plugs(measured) None true vertical 3102 feet Junk(measured) None Effective Depth measured 7484 feet Packer(measured) 0 true vertical 3104 feet (true vertical) 0 Casing Length Size MD ND Burst Collapse CONDUCTOR 77' 16 108' 108' SURFACE 1579' 10 3/4 1610' 1546' PRODUCTION 6018' 7 5/8 6046' 3097' LINER 1901' 41/2 7484' 3116' RECEIVED Perforation depth: Measured depth: Slots: 5654-5737; 5991-7415 FEB 0 6 2017 True Vertical Depth: 3017-3035; 3087-3107 A GCC Tubing(size,grade,MD,and TVD) 4 1/2 ,L-80,4560 MD,2709 TVD Packers&SSSV(type,MD,and TVD) Packer= Baker SC-1R Liner Top Packer, MD=5583, TVD=3003 12.Stimulation or cement squeeze summary: Intervals treated(measured): % NNlED APR 1 8 2017, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 NA NA Subsequent to operation 165 86 3171 1288 250 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r, Exploratory r Development p.. Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil p Gas r WDSPL r GSTOR r WINJ WAG GINJ SUSP SPLUG Printed and Bectronic Fracture Stimulation Data r r r r r r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 316 -638 Contact Vanessa Angel Email: vanessa.m.angel(a conocophillips.com Printed NameVanessa Angel Title: Senior Petroleum Engineer Signature t , — /�, Q Phone:265-1018 Date 2/2/2017 u G 'ti,��/,//� VTi- 3/28 / l L 37287 Form 10-404 Revised 5/2015 RBDMS 1,t/ FEB - 7 2017 Submit Original Only • • 2T-203 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/28/17 2T-203 brought onto production with lift gas while waiting on RWO to replace ESP motor. KUP P D 2T-203 ConofoPhillips Well Attribute Max Angle 0 TD Alc),kc I11i. Wellbore API/UWI Field Name Wellbore Status ncl('I MD(ftKB) Act Btm(ftKB) CarloaaPhgbps 501032052000 TABASCO PROD 93.24 7,282.91 7,525.0 L .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-2T-203,2/6/20179'.38'.49 AM SSSV:NONE 100 11/22/2015 Last WO: 12/7/2007 33.99 2/25/2006 Mer9n(sphematic.(aoaag Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 4,496.0 9/4/2007 Rev Reason:GLV C/O pproven 1/27/2016 HANGER;24.1-_ 1 9;Ear1Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 108.0 108.0 62.50 H-40 WELDED , . li .„ it CsausRinFgADcesEcription OD(iino)3/4 ID 008.784 Top(ftKB3)0 8 Set Depth(iftK6B0)9.8 Set Depth CiI15/4D)6...2.Wt/Le4n5(51.0..GLr8adoe TBoTpcThread Casing Description 111 ri iii PRODUCTION OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... VVULen(I...Grade Top Thread Casing Description OD(in) ID(in) Top(ftKB) Set Depth(fIKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thr.d LINER 4 1/2 3 958 5.582 6 1 3,10360 13 CR VAM 1111, :: Ill Liner Details -^-^CONDUCTOR;31.0-108.0• Nominal ID Top(ftKB) Top )(ftKB) Top Inc!(.) Item Des Com (in) I • 114.000 .. .. 5,586.8 3,004.2 78.57 MILLOUT MILLOUT EXTENSION 3.958 SURFACE;30.8.1,609.8 5,593.1 3,005.4 78.75 SEAL Sealbore w/4.5"Vam Top SealboreA 3.250 5,603.6 3,007.4 • •• 3.500 • 5,606.1 3,007.9 78.85 KOIV3.500 5,650.9 3,016.7 78.42 SEAL Sealbore w/4.5"Vam Top SealboreB 1250 GAS LIFT;2743.4 5,944.1 3,078.13.250 5,988.3 3,086.4 -• 1250 6,032.6 3,094.5 6,657.4 1 6,701.4 3,115.7 88.88 SEAL Sealbore w/4.5"Vam Top SealboreG 3250 GAS UFT;4,4274 6,745.7 3,116.4 89.49 SEAL Sealbore w/4.5"Vam Top SealboreH 3.250 7,370.7 3,108.7 91.98 SEAL Sealbore w/4.5"Vam Top Sealborel 3.250 7,416.7 3,107.0 92.40 SEAL Sealbore w/4.5"Vain Top SealboreJ 3.250 DSCHARCE.4,4,'1 7,457.3 3,105.1 92.93 SEAL Sealbore w/4.5"Vam Top SealboreK 3.250 7,475.9 3,104.1 93.08 Flapper VLV 1 3.000 7,477.3 3,104.0 93.08 Flapper VLV 2 3.000 INTAKE,4,5572 Tubing Strings Tubing Description String Ma...ID(in) Top(kK0)2411 4Set Depth(k.. Set Depth(ND)(. 2,7252.. bfk)12.60GradeL-80 TIBT op ConnectionMod SEAL;4,567.6 ESP TUBING I 41/21 3.9581 1Wt(I1 I SEAL;4,574.7 �• =. Completion Details MOTOR 4,581.6 Nominal ID SENSOR 4,8089 1 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) CENTRALIZER 4,608.8 ' 24.1 24.1 0.00 HANGER FMC HORIZONTAL ESP TUBING HANGER 3.958 4,477.7 2,682.0 71.48 DISCHARGE WELL LIFT DISCHARGE SUB-Hydro-tested Sub& 3.958 Gauge 065 4,557.2 2,707.6 70.88 INTAKE TTCESP PERFORATED CROSSOVER INTAKE 4,567.8 2,711.1 70.87 SEAL UPPER TANDUM SEAL SECTION 4,574.7 2,713.4 70.88 SEAL LOWER TANDUM SEAL SECTION 4,581.6 4,606.9 2,715.6 70.88 MOTOR ESP MOTOR 2,723.9 70.89 SENSOR WELL LIFT GAUGE PRESSURE SENSOR 4,6088 . 2,724.5 70.89 CENTRALIZE '1/4"SS line attached 1.995 R Perforations&Slots SLOTS;5,654.08,737.0--• _ Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com - 5,654.0 5,737.0 3,017.4 3,034.6 2/16/2006 99.0 SLOTS Alternating ExcI2000 Coarse screen/ sealbores 1 5,991.0 6,033.0 3,086.9 3,094.5 2/16/2006 99.0 SLOTS Alternating ExcI2000 Coarse screen/ sealbores SLOTS,5,991.06,033.0-. 6,035.0 6.657.0 3,094.9 3,114.7 2/16/2006 99.0 SLOTS Alternating ExcI2000 ■ Coarse screen/ sealbores 1ii, 1 6.704.0 6,746.0 3,115.7 3,116.4 2/16/2006 99.0 SLOTS Alternating ExcI2000 ICoarse screen/ ".;moi sealbores ` PRODUCTION;28.2-8,046.1 � *�_ SLOTS;6,035.06,657.0 1 7,371 1 I: 116 99.0 SLOTS Alternating Excl2000 Coarse screen/ e... sealbores `1- 11 2/16/2006 99.0 SLOTS Alternating Excl2000 _ Coarse screen/ sealbores SLOTS;6,704.08,746.0 ill, Mandrel Inserts i on Top(TVD) Valve Latch Port Si. TRO Run SLOTS;6,748.0-7,371.0 "' N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com .. • 0.18811/25/2017 • OV BK 0.250 0.01/25/2017 i SLOTS;7,373.0-7,415.0 7-7 Notes:General&Safety . 11111 MI End Date Annotation - 12/9/2010 NOTE:ZONES NOT LOADED INTO WELLVIEW 12/9/2010 • 1 LINER,5,5826-7464.0 • • 2T-203 DTTMST,JOBTYP SUMMARYOPS 1/25/17 GLV CIO SET CATCHER @ 4582' RKB. MEASURED BHP @ 4557' RKB(1294 PSI) (RATE) PULLED SOV AND SET OV @ 4427' RKB. PULLED DV @ 2743' RKB. IN PROGRESS. 1/26/17 GLV C/O SET GLV @ 2743' RKB. BRUSH & FLUSHED TBG TO 4500' SLM. (RATE) INCONCLUSIVE TEST OF GLVD w/HOLEFINDER. PULLED CATCHER @ 4544' SLM. JOB COMPLETE. 1/27/17 PUMPING PUMP 15 BBLS OF METHANOL DOWN THE IA TRACKING ONLY JOB COMPLETE 1/28/17 Brought onto oproduction with lift gas while waiting on RWO to replace ESP motor. • • yofTg s„, THE STATE Alaska Oil and Gas of Conservation Commission LAsKA 333 West Seventh Avenue *h, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov David Neville 6 r '" Senior Petroleum Engineer O* ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2T-203 Permit to Drill Number: 205-197 Sundry Number: 316-638 Dear Mr.Neville: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this )e day of January, 2017. RBDMS LA ./ JAIJ 1. 6 2017 • • RECEIVED STATE OF ALASKA DEC 2 2 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION j S i jJ g 1 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon Plug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r-- Plug Plug for Redrill r Perforate New r Re-enter Susp Well r Alter Casing r Other: Convert to Gaslift Pi' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r, 205-197 • 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage, Alaska 99510 50-103-20520-00 ' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No J" KRU 2T-203 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569/25548 * Kuparuk River Field/Tabasco Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: , MPSP(psi): Plugs(MD): Junk(MD): 7525 3102 7'�R� 3 IOL( /45 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 108' 108' SURFACE 1579' 10 3/4 1610' 1546' PRODUCTION 6018' _ 7 5/8 6046' 3097' LINER 1901' 4 1/2 7484' 3116' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:5654-5737;5991-7415 • 3017-3035;3087-3107 4 1/2 L-80 4560 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=NONE SSSV=NONE Packer=BAKER SC-1R Liner Top Packer « Packer MD=5583;TVD=3003 12.Attachments: Proposal r WellBore r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r . Service r 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 01/06/17 OIL (.7 . WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG IT GSTOR r SPLUG r Commission Representative: GINJ r Op r Abandoned r- 17. 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: David Neville Printed Name David Neville Phone:265-6220 Email: david.i.neville(a conocophillips.cc Title: Senior Petroleum Engineer Signature Aff„..0, / / Date: `272 1 7(6 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓`� — L . Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMS . L. JAN 2 6 2017 Post Initial Injection MIT Req'd? Yes r No Spacing Exception Required? Yes r No r✓ Subsequent Form Required: l D 4.c aL APPROVED BY Approved by: g% 201_4„..74----' COMMISSIONER THE COMMISSION Date: 1 — IS -"7 11i4;c U � i VT-1- 1` f /1 Submit Form and Form 10-403 Revised 11/2015 4,i4 p I nn lad for 12 months from the date of approval. Attachments in Duplicate S • 2T-203 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. is seeking approval to convert the artificial lift method from Electric Submersible Pump (ESP)to gaslifted production in Tabasco well 2T-203 as the ESP motor recently failed, halting production. Converting the artificial lift method to gaslift will restore produciton until such time as a rig workover can be executed. The well was originally completed as a packerless producer, with a through tubing conveyed ESP set at 4557' MD. The 4.5" tubing is equipped with 1"side-pocket gaslift mandrels at 2743' &4427' RKB. These mandrels are currently dummied off. The through tubing ESP was removed during diagnostic wellwork. A gas MIT of the inner annulus was performed to 1000 psi 12/9 - 12/10/16. IA and OA fluid levels remained unchanged after an overnight monitoring period. Cumulative pressure drop for the test period was 19—psi, with 16 psi occurring in the first 15 mins. An unloading valve will be installed in the mandrel at 2743' RKB, and an orifice valve will be installed in the mandrel at 4427', through which lift gas will enter the tubing. ow KUP P D 2T-203 ConOCOPhi 1p5 Ai✓i', Well Attribute Max Angle AP TD � ` .rWellbore API/LAMAPI/LAMField Name Wellbore Status ncl(•) MD(ftKB) Act Btm(ftKB) CorwmYhilh fUaska.Inc. pst 501032052000 TABASCO PROD 93.24 7,282.91 7,525.0 -_ ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-2T-203,12/21/2016238:35 PM SSSV:NONE 100 11/22/2015 Last WO: 12/7/2007 33.99 2/25/2006 Vertical cameo(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 4,496.0 9/4/2007 Rev Reason 4104•ULLED SLIP-STOP, pproven 11/10/2016 PACKOFF 8 •PUMP HANGER;24.1-.II( I 1 Casing Strings Y _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .� CONDUCTOR 16 15.062 31.0 108.0 108.0 62.50 H-40 WELDED t 3 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread , ! d wp,SURFACE 103/4 9.794 30.8 1,609.8 1,546.2 45.50 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 75/8 6.875 28.2 6,046.1 3,096.9 29.70 L-80 BTCM 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread y LINER 4 1/2 3.958 5,582.6 7,484.0 3,103.7 12.60 13 CR VAM r. Liner Details Nominal ID �ti CONDUCTOR;31.0.708.0- '?; A TopftKB To TVD ftKB TopIncl(°) Item Des Com ( ) P( 1( 1 (in) 5,582.6 3,003.3 78.45 PACKER BAKER SC-1R Liner Top Packer / 4.000 5,586.8 3,0042 78.57 MILLOUT MILLOUT EXTENSION 3.958 SURFACE;30.8-1,609.8-- , ' 5,593.1 3,005.4 78.75 SEAL Sealbore w/4.5"Vam Top SealboreA 3.250 5,603.6 3,007.4 78.88 KOIV TOOL 3.500 5,606.1 3,007.9 78.85 KOIV 3.500 _ 5,650.9 3,016.7 78.42 SEAL Sealbore w/4.5"Vam Top SealboreB 3.250 GAS UFT;2,743.4 a 5,944.1 3,078.1 78.89 SEAL Sealbore w/4.5"Vam Top SealboreC 3.250 5,988.3 3,086.4 79.38 SEAL Sealbore w/4.5"Vam Top SealboreD 3.250 6,032.6 3,094.5 79.49 SEAL Sealbore w/4.5"Vam Top SealboreE 3.250 6,657.4 3,114.7 88.59 SEAL Sealbore w/4.5"Vam Top SealboreF 3.250 6,701.4 3,115.7 88.88 SEAL Sealbore w/4.5"Vam Top SealboreG 3.250 GAS LIFT;4,427.4 ,gn 6,745.7 3,116.4 89.49 SEAL Sealbore w/4.5"Vam Top SealboreH 3.250 7,370.7 3,108.7 91.98 SEAL Sealbore w/4.5"Vam Top Sealborel 3.250 7,416.7 3,107.0 92.40 SEAL Sealbore w14.5"Vam Top SealboreJ 3.250 DISCHARGE;4,477.7 _7 G_ 7,457.3 3,105.1 92.93 SEAL Sealbore w/4.5"Vam Top SealboreK 3.250 7,475.9 3,104.1 93.08 Flapper VLV 1 3.000 7,477.3 3,104.0 93.08 Flapper VLV 2 3.000 Tubing Strings INTAKE;4,557.2 II-III SEAL;4,567.6 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt OWN) Grade Top Connection - ESP TUBING 41/2 3.958 24.1 4,610.8 2,7252 12.60 L-80 IBT Mod SEAL;4,5747 + Completion Details MOTOR;4,581.6 SENSOR;4,606.9 1 Nominal ID 1 Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) CENTRALIZER;4,608.6 24.1 24.1 0.00 HANGER FMC HORIZONTAL ESP TUBING HANGER 3.958 4,477.7 2,682.0 71.48 DISCHARGE WELL LIFT DISCHARGE SUB-Hydro-tested Sub 8 3.958 Gauge iM 4,5572 2,707.6 70.88 INTAKE TTCESP PERFORATED CROSSOVER INTAKE • IIIII 4,567.8 2,711.1 70.87 SEAL UPPER TANDUM SEAL SECTION = 4,574.7 2,713.4 70.88 SEAL LOWER TANDUM SEAL SECTION 4,581.6 2,715.6 70.88 MOTOR ESP MOTOR rb, 4,606.9 2,723.9 70.89 SENSOR WELL LIFT GAUGE PRESSURE SENSOR I 4,608.8 2,724.5 70.89 CENTRALIZE 1/4"SS line attached 1.995 R Perforations&Slots SLOTS;5,654.0-5,737.0 Shot - Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 5,654.0 5,737.0 3,017.4 3,034.6 2/16/2006 99.0 SLOTS Alternating ExcI2000 Coarse screen/ MI sealbores 5,991.0 6,033.0 3,086.9 3,094.5 2/162006 99.0 SLOTS Alternating Exc(2000 Coarse screen/ _ - - sealbores SLOTS;5,991.0-6,033.0^ 6,035.0 6,657.0 3,094.9 3,114.7 2/16/2006 99.0 SLOTS Alternating Exc(2000 ■ = Coarse screen/ ' = sealbores 6,704.0 6,746.0 3,115.7 3,116.4 2/16/2006 99.0 SLOTS Alternating Exc)2000 ' Coarse screen/ sealbores PRODUCTION;26.2-6,046.1`� SLOTS;6,035.0-6,657.0_ T 6,748.0 7,371.0 3,116.4 3,108.7 2/16/2006 99.0 SLOTS Alternating Exc12000 Coarse screen/ _ sealbores 1.1 7,373.0 7,415.0 3,108.6 3,107.0 2/16/2006 99.0 SLOTS Alternating ExcI2000 Coarse screen/ sealbores SLOTS;6,704.0-6,746.0 ex Mandrel Inserts St s ati a. on Top(TVD) Valve Latch Port Size TRO Run SLOTS;6,740.0-7,371.0 -a- Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,743.4 2,145.5 CAMCO KBG-2- 1 GAS LIFT DMY BK-5 0.000 0.0 12/26/2007 1R 2 4,427.4 2,666.1 'CAMCO KBG-2- 1 GAS LIFT SOV BK-5 0.000 2,000.0 12/27/2007 s 1R SLOTS;7.373.0-7,4150 -, ..-- Notes:General&Safety MI End Date Annotation 12/9/2010 NOTE:ZONES NOT LOADED INTO WELLVIEW ID 12/9/2010 NOTE:View Schematic wl Alaska Schematic9.0 IIIII LINER;5,562.6-7,464.0 • • 'Bettis, Patricia K (DOA) From: Neville, David J <David.J.Neville@conocophillips.com> Sent: Tuesday, December 27, 2016 8:00 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2T-203 (PTD 205-197) Greetings Patricia, Thank you for reviewing this application. The additional information should include an effective depth of 7484' MD, 3104'TVD. Please let me know if any further information is required. Regards, David Neville Tarn Base Petroleum Engineer (907) 265-6220 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday, December 22, 2016 10:42 AM To: Neville, David J <David.J.Neville@conocophillips.com> Subject: [EXTERNAL]KRU 2T-203 (PTD 205-197) Good morning David, What is the current effective depth, both MD and TVD,for KRU 2T-203? This information was left off of the Form 10- 403, Box 11. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • 'Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Thursday, December 22, 2016 10:42 AM To: 'david j.neville@conocophillips.com' Subject: KRU 2T-203 (PTD 205-197) Good morning David, What is the current effective depth, both MD and TVD, for KRU 2T-203? This information was left off of the Form 10- 403, Box 11. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • ConocoPhillips ~~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~+CE~~JED ~~~ 2 2~l~ f~#sk~ Q~ & Gas Cep. Commissiar Anch~ra~aP a°aT,l2~.03 Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRLI). 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 corrosion inhibitor/sealant was pumped July 11th, 12th, 13th 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, 1 Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16/10 2r_ sN Pn~ 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 ft bbts ft al 2T 22 50103202240000 1950860 8" Na 8" n/a 3.8 7/12/2010 2T 23 50103202160000 1950320 8" n/a 8" n/a 2.1 7/12/2010 2T-27A 50103202170100 2090900 7" n/a 7" n/a 1.7 7/12/2010 2T-32 50103202180000 1950490 36" n/a 36" n/a 11.9 7/12/2010 2T 37 50103202270000 1951010 22" n/a 22" n/a 2.5 7/11/2010 2T-38A 50103202290100 1972050 8" n/a 8" Na 1.7 7/11/2010 2T-203 50103205200000 2051970 22" Na 22" Na 5.1 7!13/2010 2T-208 50103205180000 2051870 13" n/a 15" n/a 2.5 7/13/2010 2T-210 50103202730000 1982030 18" Na 18" n/a 5.1 7/12/2010 2T-217A 50103203340100 2000740 8" Na 8" n/a 1.7 7/12/2010 3H-13A 50103200890100 1961970 SF n/a 22" n/a 3.8 7/11/2010 as ~ DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2051970 Well Name/No. KUPARUK RIV U TABS 2T-203 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20520-00-00 MD 7525 TVD 3101 Completion Date 2/25/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Direction al Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Port ion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc D rectional Survey t 14035 ~S Verification 30 7520 Open O en 4/17/2006 8/22/2006 p fD C Li 14035 I d ti /R i ti it 1575 7461 p O 8/22/200 GR F T RO s uc on es v y n s pen 6 , E , P, NPHI, RHOB, Res ~g Induction/Resistivity 25 Col 682 7520 Open 3/24/2008 MD ROP, DGR, EWR, Induction/Resistivity 25 Col 674 3101 Open 3/24/2008 CTN, ALD 15-Feb-2006 TVD DGR, EWR, CTN, ~ ALD 15-Feb-2006 ,r' ED C 16051 5ee Notes 0 0 Open 3/24/2008 MD and TVD logs in EMF, PDF, and CGM graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y N~ Daily History Receive / N J d? l Chips Received? ~T'1~~ Formation Tops ( ~,, (J,/ N Analysis Received? Comments: i DATA SUBMITTAL COMPLIANCE REPORT 511 212 0 0 8 Permit to Drill 2051970 Well Name/No. KUPARUK RIV U TABS 2T-203 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20520-00-00 MD 7525 TVD 3101 Completion Date 2/25/2006 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: __ __ _ _._ __ ___ __ _ _ _ /~{ • Date: _ ! ~___-' L~-1 _~C}~~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2T-203 March 11, 2008 AK-MW-4163248 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2T-203 2" x 5" MD TC Logs: 1 Color Log 50-103-20520-00 2" x 5" TVD TC Logs: 1 Color Log 50-103-20520-00 Digital Log Images 1 CD Rom 50-103-20520-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. An~l~r~ge=~~as~~ 99~5~18 Date: ~~ ~ ~ ~ +., ~ i Signed: ~ c9d5""-~q ~- ~ l (oL~ ~ ~ ~ Ric Ea STATE OF ALASKA JAN ~ 299 ;,~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT~° ~~'~ $ ~~$'~01~~• ~°"~'""'q" ._-~---- 1. Operations Pertormed: Abandon ^ Repair Well 0 Plug Perforations ^ Stimulate ^ ter ^ Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillipS Alaska, InC. Development ~ "Exploratory ^ 205-197 / " 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20520-00 ` 7. KB Elevation (ft): 9. Well Name and Number: RKB 30' - 2T-203 ~ 8. Property Designation: 10. Field/Pool(s): ADL 25569 &25548 Kuparuk River Field /Tabasco Oil Pool ^ 11. Present Well Condition Summary: Total Depth measured 7525' feet true vertical 3102' feet Plugs (measured) Effective Depth measured 4496' feet Junk (measured) true vertical 2688' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURFACE 1579' 10-3/4" 1609' 1546' PRODUCTION 6007' 7-5/8" 6046' 3097' LINER W/SCREE 1902' 4-1/2" 7484' 3104' Perforation depth: Measured depth: 5654'-5737', 5991'-6033', 6035'-6657', 6704'-6746 ', 6748'-7371', 7373'-7415' true vertical depth: 3018'-3035', 3087'-3095', 3095'-3115', 3116'-3116 ', 3116'-3109', 3109'-3107' Tubing (size, grade, and measured depth) 4-1 /2" , L-80, 4557' MD. Packers &SSSV (type & measured depth) SC-1 R liner top pkr @ 5582' 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 300 ~ 52 1100 -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 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 NiA if C.O. Exempt: none Contact Jim E 's @ 265-1544 Printed Name iS ~ Title Wells Group Engineer Signature Phone Date I '~) 0 Pre b S n Il u Drak 263-4612 ~~ /L2. vS Form 10-404 Revis d 04/2004 ~~ ~~~ `r~~l ~ ~" ~~Ojl ~~1~~ Submit Original Only • Tlme Log Summary Well Name: 2T-203 Job Tvoe~ Recomoletion Start End ~ Sub ` Date From To ~ .....__ 12/4/07 18:00 0.00 112~~07 0:00 8:00 12/5/07 8:00 9:00 Dur 6 8 ~ De th' De th Phase P __~._ ._.._._. 7520 7520 MIRU_ , 7520 7520 MIRU 7520 ~ 7520 MIRU Code 1 MOVE MOVE MOVE , Code ..... MOB_ MOB PSIT~ Time Activit ; _ _ ._ .._~__. P Movinq rip f/ 2L-330. well t_ 0 2T~ad._ ~ P Mov~ ~r~ tcLeo, 2T,,~,ad for workover. ea~~ ~P~ :PJSM, Move rig over well 2T-203. Spot & € level rig. Nordic 3 Rig accepted this date @ __ _ ~ i ___ ~,,~ . Q~Q(~hl~ ...A.._~ 112/5/07. 9:00 12:00 3 12/5/07' 12:00 18:00 __.._..~.._ _ 12/5/07 18:00 20:00 ~ 3 __ 6 1 [ 2 ~ 7520 ~ 7520 MIRU ~ _. 7520 7520 I MIRU ,,- ___ 7520 ~ 7520 MIRU ~ MOVE .._ _ ! MOVE _ RPCOM RURD RURD I 1 SF Q P ,Berm cellar, drop tarps and run Comm fine to _ riq.__ 1 P PJSM, RU and spot rockwasher, mud lab and~~ tanks. Wa~hin mud its.,, ~~._... __..._.~ ~~.P 'RU Lubricator & Pull BPV, Well on vacuum. E ~ 12/5/071 20:00 23:00 3 7520 7520 MIRU I. P RPCOM CIRC i ~-.--~ ~ P PJSM, RU Little Red Hot Oil, p-test lines t/ 1 i ~ P ( .2000 psi, pump 50 bbls hot brine down tbg, j } 200 bbls hot brine down IA to flush oil. 12/5/07€ 23 00 0:00 1 7520 7520 3 MIRU RPCOMj SFEQ ~ P Set BPV, blow down kill manifold. RD kill 12/6/07 0:00 9:00 9 i °' 7520 7520 ~ M~~ P 1 PCOM~ _ NUND ~ marnfold, _ t P PJSM, Finish nipple down tree, install ___ f 12/6/07 9:00 11:30 ' 2.5 w__~ 7520 7520 a MIRU P RPCOM RURD ; ;blanking plug. Install and nipple up 11" BOP. _.. P Load spoolers and empty spools on floor w/ 1 ' ~ 1 ~...__ ~ _.m..a ~~. ° _ ~.w P__ m. _ .crane. _.~W _~ ._ 1 2/6/07 ' ~._ 12/6/0 11:30 12:30 _ _ 712:30 16:00 1 ., ~ 3.5 , 7520 7520 MIRU ~, _ .~. 7520 7520 MIRU RPCOM NUND 1 P ~ a~. WELCT, BOPE~ P Finish nipple up of BOPE and prepare t/ test. _ _ 1 ~~P ~ Test BOPE @ 250 / 2500 psi. Had (1) failure ....' _~... ..._..._ L __- _ w/ clamp. Repair_an~ r t~ est, OI<. _ 12/6/07 16:00 ~ 17:00 1 _ 7520 7520 ;MIRU RPCOM; ... RURD ; ~_ P P]SM and hang sheaves for spooling ESP ' - _. .w__.-_, ...~___._. _... ..__ P _. .~ ~ cable & Capillarv_tube~,~ ~_,.~,__ __ 12/6/07' 17:00 17:30 0.5 7520 7520 MIRU RPCOMj OTHR £ P Back out tbg hanger lock-down screws. _~~®m .~. i _ a - ~ I t ..~ _ _,., ~ 12/6/07` 17:30 19:00 1.5 =7520 7520 MIRU .m RPCOM CIRC ~ . . P .Pump 52 bbls filtered brine down tbg. _ 12/6/07 19:00 20:30 , .. € 1.5 i M.__,~ ~a € 7520 7520 ' ~.. _~.€ MIRU P ..__. __ ~ RPCOM PULD _ m _m,~_ P PJSM, unseat tbg hngr, Pull to 100kibs to 1 P unseat, PU wt 90 klbs. Pull to floor, ~ ~ € 'disconnect penetrators and capillary tbg. ~ 1 f 12/6/07 20:30 22:00 1 6%071 22:00 0:00 1.5 2 € 7520 7520 7520 7520 __ _ IRU ~MIRU „~ ~ -- 1 RPCOM PULD ~ P RPCOM TRIP Test ESP cable to validate penetrator _ w. inta~rity_..S.tI~I..dP+~d~.Skldll~t € P L/D (2) pup jts, PU 60ft, pull cable and ~ capilarry tbg thru sheaves, start on spoolers. P TOH w/ 4 1/2" IBT tbg & ESP. Remove canon .~._~,.,.` .~...~_... ,,__... _ €, _._tiw__. ~a. ~,~..~ _~.u.-~. P _ ..~ ~ . _clam,w~nd ~~Q.QI cable w~~.h,~...,.~.zw..,m. 112/7/07 0:00 , 4:00 ' 4 _ . _ 7520 7520 =MIRU ; RPCOM TRIP P ? P POOH w/ ESP w/ spooling cable and capillary t tube. ,12/7/07 4:00 6:00 ~..~.r~~. ~ 2 .. 7520 7520 MIRU I ~ ; ~,.~.~~ __,~~~..._~ RPCOMI PULD P ~ ~~_.~. P Continue POOH, breaking out ESP assembly and laying out. Testing indicated motor short ~ ~2CI~G„~P~d~'f,~U and. D .~..~~.,~ 12/7/07 6:00 9:00 3 ( 7520 7520 I MIRU ~ RPCOM~ PULD ? P Test and remove old ESP equipment off rig. 2/7/07 9:00 50:00 ~ 1 _.__....._ .__..........a ( 7520 7520 ~ MIRU 1 - ..__?_._.. ___,.._ RPCOM PULD _~_._ ....~.._,.__,....__.__~._....... _..._.__ _...v...,~.... .. P C/O ESP cable spool w/ crane. 12/7/07 10:00 12:00 .._._ ~ 2 € MIRU 1 7520 7520 _ ~.~ P RPCOM OTHR 1 _ __ _ ..~...~ .._ . _ __ P Test New Cable and ESP Cable. _ . ~.~ 12/7/07.. 12:00 15:00 ~ 3 ~ 1 a ., _ 7520 7520 ;MIRU ~ P _ 1 RPCOM PULD ? 2 _ _ ~. ,,,,..~~ .~ P 'PJSM, assemble pum & set in intake Housii g 12/7/07' 15:00 1 0 2 7520. 7520 MIRU =RPCOM PULD P RU Halliburton slicklline to set pump & set 1 P same in intake houseing. Re-Pin disconnect 12/7/07 17:00 17:30 _.__.... OS ` ~. ~ 7520 7520 _ _ ~_~~_ MIRU ~ _ _ ~~. RPCOM, DHEQ P , _~, ~ _ and t...~~k~~f~.,~~~.-~._~. ~.~... m~ P UR to p-test packoff, test packoff t/ 1000 psi & hold f 15 mtnw_•_ r- __L_...... ~w.w _ _. _ __.._,~......._._....._.... 12/7/07 17:30 18.30 1 7520 7520 ' MIRU RPCOM PULD P Set slip stop w/ Halliburton slickliln e, RD .. _..,_ ~.. _._ ._. __ ~ ? ~ ._ slickline. .~_.~..... ~...__._~._..__ ... .. . .__._.. ___ 12/7/07 18 30 20:00 .__ 1 5 _._...._ .~... 7520 7520 ' _ MIRU .~. _ RPCOM ___._ OTHR .~.... . _..._.___._~..._ __ P Fill Centrilift motor w/ oil & assemle to seal ®amm_~ ~ ~~ 1 __.~.~~~ ...~.~ _.MP..._.. ~..~. ®~ ~s~~,~1.,a.~~v1~4~1~ _.~....~~._ _~_:~.. Tlme Log Summary ;_ ;12/7/07 _..~. 20:00 0:00 ~ ~.__ 4 ___...._.._ 7520 ._~~ ._._~. 7520 MIRU RPCOM _..~ DHEQ .__~ P ..~._.__ .............~_.__~.___.__...~__.~___--a Connect motor lead t/ motor. Test connection' € i ~ P ~ & cable, insure comm, Install cable guards, ( ~ E ~ ~ ,„.~._ .~..m...,~, . ~.~.», ~ ~~. ! ~ ._ ~ ~ .,~,m ~ ;splice 1/4& 3/8" capillary tubing, RIH w/ ESP, terminate discharge sub capillary );inn mm ,~ ........ _.n 12/8/07, 12/8/07; 0:00 2:30 2:30 4:30 ( 2.5 2 7520 7520 7520 MIRU 7520 MIRU RPCOM RPCOM TRIP TRIP ~ P T ,RIH w/ ESP, meg cable, OK. ' .Down 2 hrs. Spooler locked up, diagnose lock € i P ~ up of spooler air motor. Disassemble and ~....._._.._ _ ~ ..M...._ ._ ~ .._..~_ .. _. _ . ~~.. ~.. reoai~, .... __.___.._.._._._.._~.._._.,._..__. 12/8/07 4:30 9:00 ~ .~._._... 4.5 ~...._.__ ~ .__. 7520 7520 MIRU ~.._ ~.._...~. RPCOM P TRIP ~ P ~ Continue RIH w/ ESP on 4 1/2" IBT tbg w/ stops to Meg test cable at 1000 ft intervals. Pll.~~.,~4U_.tbsl.,~icac..~n(/..l~.ndis~Ia.it... 12/8/07[ 9:00 9:30 0.5 7520 7520 MIRU RPCOM RURD , P .Install penetrators in hanger. ~ P ~ . ~ . 12/8/07] . 9:30 __..... _.._. 13:00 ! 3.5 _ ~ 7520 .. _.._.._._. _ 7520 MIRU ~ RPCOM= ....~..._._ ~.~_ RURD P ___ ~.,... _..-.,,.._ , .__.._____- ..._.~_ w Splice connectors on ESP cable & Meg same, € : P__ : OK. .~. _._~ 12/8/07 _ 13:00 13:30 0.5 7520 7520 MIRU ~RPCOM __ __ _ P_ RURD ~ P Terminate infection line, install check valve iZel~„w hanger a 12/8/07 13:30 14:30 ! 1 7520 1 7520 MIRU RPCOM HOSO ~ P Land hanger, RILDS, PU 90 klbs, SO 58 klbs i 12/8/07 12{8/07 14:30 { 17:30 ~ 17:30 ' 3 ~ 18:00 0.5 ~ 7520 € 7520 ( : P ~ ( 7520 ~ MIRU ~RPCOM NUND P 7520 MIRU RPCOM NUND T ~ w/ ESP set at 4611 ft. Bock out landing jt, ND BOP. Damaged cap tbg / penetrator connection, 12/8/07 18:00 20:00 2 i _ ( 7520 , _ P „__~ 7520 3 MIRU RPCOM€ __ _ NUND P re air, enetrator. _P_~_.P_. ~.._..~.. _-, 'NU Tree. a.. 12/8/07.. _ ~ 20:00 _~_, ~ _ _ ._. 21:00 ; 1 ? .. _~.- _. 7520 ~ _ ~m~ P 7520 ~ MIRU RPCOM __ ~~ DHEQ ~ P 1 ._....._..~ _ _. ~..._ -Test tree t/ 5000 psi f/ 15 min, OK. Pull 2- € I P _ wav_check~~ _~ _m~®e 12/8/07 21:00 23:30 2.5 7520 7520 ;MIRU €RPCOM FRZP i P RU pump to purge Chem inj line, pump 8 gal P av-hyd oil, unable to pump open lower check `• i ? valve, pressure to 4900 psi, abort operation. [ ~ _ ~RU displace 50 bbls, 8.5 ppg brine, RU Little 1 ~ 'Red, ptest lines and displace freeze protect ~ diesel, pump 35 bbls tbg, 65 bbls in IA, max I € ' ~ ' .:pressure 400 w/ on tbg. At end of pump ~ ~ ~ i operation, well on vacuum. 12/8/07 23:30 0:00 0.5 7520 7520~MIRU RPCOM OTHR P Perform last QC on ESP equipment, OK. Set ~ ~ i L ~ _ W W ~ _ I I ~ ~ ~ i._ _ _ ._ __. ~ P I ~ ~ ._. - ~ ___~_ i BPV. Rig released at 0000 hrs, 9-Dec-2007. ' ___._._ __.___....___._ ... _..._.~...... _._..__._ _.... . ~ • I: ~ KRU 2T-203 ConcscoRhillpi~ Alaska., Inc. ~2'T-2D3 -- ___-- API: 501 032 0 52 000 Well T e: PROD An le a7 TS: de a7 SSSV Type: NONE Orig 2/25/2006 Angle @ TD: 93 deg @ 7525 Coin letion: Annular Fluid: Last W/O: 12/7/2007 Rev Reason: ESP WORKOVER Reference Lo : 30' RKB Ref Lo Date: Last U ate: 12/10/2007 `.. - Last Ta : 449G SLM TD: 7520 ftK6 Last Tag Date: 9/4/2007 Max Hole Angle: 93 deg I~ 72£;'i Casin Strin -ALL STRINGS ~_ Descri ion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 108 108 62.50 H-40 WELD SURFACE 10.750 0 1609 1546 45.50 L-80 BTC PRODUCTION 7.625 0 - 6046 _..__. 3097 29.70 _ L-80 _..... BTr MOD PUMP CaSlrl g ~Stl'tC1g - 'J~ REEN L~ NER (4517-4580, OD:3.800) ; ~ . . .. . Description - - - - - Size Top Bottom__ _ _ TVD Wt Grade Thread ~,,, ~ LINER w/SCREENS 4.500 5582 7-184 _',104 12.60 13 CR VAM _ _ . Tubing String - 7llBING ~ _ Size Top Bottom TVD Wt Gr ade Thread 500 0 1 . 4557 2708 1260 L- 80 IBTP,~ S CC SEAL (a5sa4sa2, _ . . Perforations Summary _ OD:5.130) MOTOR (45824607, OD:5.620) ~ Pressure Sub --- -~ (46074609, oD:a.soo> PUP _. _.._.. (55825651, OD:4.500) xo (55925593, c« ' ~ -" OD:6.050) i , interval I w tone status rt srr mate I commem 5654 - 5737 3018 - 3035 83 99 2/16/2006 Screens Alternating Exc12000 Coarse screeN sealbores 5991- 6033 3087 - 3095 42 99 2/16/2006 Screens Alternating Exc12000 Coarse screeN sealbores 6035 - 6657 3095 - 3115 622 99 2/16/2006 Screens Alternating Exc12000 Coarse screeN sealbores 6704 - 6746 3116 - 3116 42 99 2/16/2006 Screens Alternating Exc12000 Coarse screeN sealbores 6748 - 7371 3116 - 3109 623 99 2/16/2006 Screens Altemating Exc12000 Coarse screeN sealbores 7373 - 7415 3109 - 3107 42 99 2/16/2006 Screens Altemating Exc12000 t:nArSP. C(:rP.P.r/ SP.AIt]ArP.S Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V MFr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2743 2145 CAMCO KBG-2-1R DMY 1.0 BK-5 0.000 0 12/26/200 2 4427 2666 CAMCO KBG-2-1R OPEN 1 0 BK-5 0.000 0 11/26/200 Other (plugs, eguip., etc. -COMPLETION Post Workover ~ I IlnMti I T\/Il I Vine I - _ Iln~nriMinn - 1 Ill 1 4476 2681 Pressure CENTRILIFT WELL LIFT DISCHARGE PRESSURE SUB 0.000 Sub 4517 2695 PUMP CENTRILIFT TTC/EPMTAR 1" FC 2700161 STAGE PUMP 0.000 4556 2707 Pump CENTRILIFT TTCESP PERFORATED CROSSOVER INTAKE 0.000 Intake 4568 2711 SEAL CENTRILIFT UPPER/LOWER TANDEM SEAL SECTIONS GSB3D6 FER 0.000 HL SB/SB PFSA 4582 2716 MOTOR CENTRILIFT MOTOR 304 HP KMHG 2290/81 0.000 4607 2724 Pressure CENTRILIFT WELL LIFT PRESSURE SUB 0.000 Sub I 46Uy I Other ( Z/"Lh I C:P.ntrallZPr I CaN I KILIr I MU I UK_CtN I KALILtK I _lu s e ui ) - _ p g q p., etc. LINER DETAIL U.000 I - Perf _ De th TVD T e _ Descn ion ID (5991-6033) 5582 3003 PACKER SG1 R 76A4-40 LINER TOP PACKER 4.000 I 5582 3003 PUP 3.958 5592 3005 XO 3.958 5593 3005 SEAL 3.25" SEALBORE w/4.5" SLHT SEALBORE 'A' 3.250 5651 3017 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE'B' 3.250 Pert (so35~s57) 5944 3078 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE'C' 3.250 5988 3086 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE'D' 3.250 Perf (6704.6746) Perf (6748-7371) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1~~~ ~, ~ 2 5 2007 ..r t-~ REPORT OF SUNDRY WELL OPERATIONS ~ fit ~ ~s C~ns~ Ctxnmission 1. Operations Performed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Other .rflt88 Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 205-197 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20520-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 30' 2T-203 " 8. Property Designation: 10. Field/Pool(s): ADL 25569, 25548 Kuparuk River Field /Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 7525' feet true vertical 3102' ~ feet Plugs (measured) Effective Depth measured 3710' feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURFACE 1579' 10-3/4" 1609' 1546' PRODUCTION 6007' 7-5/8" 6046' 3097' LINER W/SCREE 1902' 4-1/2" 7484' 3104' Perforation depth: Measured depth: 5654'-5737', 5991'-6033', 6035'-6657', 6704'-6746', 6748'-7371', 7373'-7415' true vertical depth: 3018'-3035', 3087'-3095', 3095'-3115', 3116'-3116', 3116'-3109', 3109'-3107' Tubing (size, grade, and measured depth) 4-1/2" / 3-1/2" , L-80, 5576' / 5590' MD. Packers &SSSV (type & measured depth) SC-~ R liner packer @ 5582 no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) 5560'-7415' Treatment descriptions including volumes used and final pressure: 107 bbls 10% HCI 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1090 231 101 -- 288 Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil 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 NIA, if C.O. Exempt: contact Jim nnis @ 265- 1544 Printed Nam is Title Wells Group Engineer +~ Signature Phone Date ~ aj~ ~ l Pre aced b aron All u -Drak 263-4612 Form 10-404 evised 04/2004 ~ ~ ~ ~ i ~ ~ ] 1~ S~Orjgina Only L !~/~ O, ~c~nt~cQPhillps A12tsk~, Inc" ... _ 2T-203 _ TUBING ~ API: 501032052000 Well T e: PROD (a557s, OD:4.500, ID:3.958) TUBING (5576-5590 KRU 2T-203 I e,,,,m n Tc• I ~o~ n I SSSV Type: NONE Orig Completion: 2/25/2006 Angle @ TD: 93 deg @ 7525 Annular Fluid: Last W/O: Rev Reason: WORKOVER Reference L 30' RKB Ref Lo Date: Last U date: 1/2/2007 Last Ta : 3710 TD: 7520 ftK6 OD:3.500, Last Tag Date: 6/18/2006 _. Max Hole Angle: 93 deg Ca) 7283 ID:2ss2) Casing String -ALL STRINGS PUP - Descri tion Size To Bottom TVD Wt Grade Thread (5582-5651 PRODUCTION 7.625 0 6046 3097 29.70 L-80 BTCM , OD:4.500) CONDUCTOR 16.000 0 108 108 62.50 H-40 WELD SURFACE 10.750 0 1609 1546 45.50 L-80 BTC Casing String -SCREEN LINER',, _ XO Description i Size Top Bottom TVD Wt Grade Thread (5592-5593, LINER w1SCREENS d 500 55H2 ~ 718•i 37©-l ~ 12.6[1 ~ l3 GR ~ YAM f oDa.oSO) ~~,~ _ _ _ ~ Tubin String -TUBING Size To Bottom TVD Wt Grade Thread 4.500 0 5576 3002 12.60 L-80 IBTM SCC 3.500 5576 5590 3005 9.30 L-80 8rdEUE P rfe orations Summary _ __ Interval TVD Zone Status Ft SPF Date T e Comment 5654 - 5737 3018 - 3035 83 99 2/16/2006 Screens Alternating Exc12000 Coarse screen/ sealbores 5991 - 6033 3087 - 3095 42 99 2/16/2006 Screens Alternating Exc12000 Coarse screen/ sealbores 6035 - 6657 3095 - 3115 622 99 2/16/2006 Screens Alternating Exc12000 Coarse screen/ sealbores 6704 - 6746 3116 - 3116 42 99 2/16/2006 Screens Alternating Exc12000 Coarse screen/ sealbores 6748 - 7371 3116 - 3109 623 99 2/16/2006 Screens Alternating Exc12000 Coarse screen/ sealbores 7373 - 7415 3109 - 3107 42 99 2/16/2006 Screens Alternating Exc12000 Coarse screen/ sealhores Other (plugs, equip., etc.) -COMPLETION Post Workover Depth I TVD I Tvne I Description I ID Perf (5991-6033) Perf (6035-6657) Perf (6704-6746) ~ 5585 13004 I SEAL I BAKER SEAL ASSEMBLY w/LOCATOR _ _ _ I 3.000 I - - Other lu s, equip., etc.j_-LINER DETAIL . ._.._ IlnnMh ~ TVII i Tvnn i flnarrinfinn i 117 i 5582 3003 PACKER SC-1R LINER TOP PACKER 4.000 5582 3003 PUP 3.958 5592 3005 XO 3.958 5593 3005 SEAL 3.25" SEALBORE w/4.5" SLHT SEALBORE'A' 3.250 5651 3017 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE 'B' 3.250 5944 3078 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE 'C' 3.250 5988 3086 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE'D' 3.250 6033 3095 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE 'E' 3.250 6657 3115 SEAL 3.25" SEALBORE w/4.5" VAM SEALBORE'F' 3.250 6701 3116 SEAL 3.25" SEALBORE w/4.5" VAM SEALBORE'G' 3.250 6746 3116 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE 'H' 3.250 7371 3109 SEAL 3.25" SEALBORE w/4.5" VAM TOP SEALBORE 'I' 3.250 /483 I 311)4 I SHUN 14" GI'V St I SHUE I 4.U1_IU I General Notes Perf (6748-7371) r~ ~onocoPhillips Time Log Summary tMelNiaw Web Reporting Well Name: 2T-203 Job Type: RECOMPLETION Time Logs Oate _ _ From '''To Dur S._De~th E,_Depth__Phase Code __ Subcode T COM 12/11/2006 18:00 20:00 2.00 DEMOB MOVE DMOB P Finish rigging down. Pull off 1D-121, clean well and location. 20:00 00:00 4.00 DEMOB MOVE MOB P Move rig from 1D-121 to 2T-203. 12/12/2006 00:00 06:30 6.50 DEMOB MOVE MOB P Continue rig move from 1 D-Pad to 2B-Pad. Stand by at 26-Pad for CPF-2 crew than a for 30 mins. 06:30 09:30 3.00 DEMOB MOVE MOB P Move rig from 2B-Pad to 2T-Pad. 09:30 12:00 2.50 COMPZ MOVE OTHR P Grade and level pad for rig. Set pit liner and "T' mats. 12:00 16:00 4.00 COMPZ MOVE RURD P PJSM. Spot rig over 2T-203 and level up. Rig up containment. Accept rig @ 16:00 on 12/12/06. 16:00 00:00 8.00 COMPZ RPCOh RURD P Remove scaffolding from 2T-31, spot cuttings box, Rig up lines to kill well. Spot flow back tanks in containment, make up hard line to rig. Service mud manifold and choke manifold valves. Ri u lubricator to ull BPV. 12/13/2006 00:00 03:00 3.00 COMPZ RPCOh RURD P Pull BPV with lubricator. Continue ri in tanks and lines for well kill. 03:00 05:00 2.00 COMPZ WELCT CIRC P Circulate 290 bbls of 110 degree filtered seawater down IA taking returns up tubing to flow back tanks, started @ 5 BPM rate, had to reduce rate to 2 BPM with 100 bbls away, pump pressure 1500 psi. Pump remaining 190 bbls seawater @ 2.5 BPM @ 950 psi, unable to get seawater all the way around, diesel / seawater contaminate returns at end of circ. Shut down and monitor pressures, starting pressure tbg 30 psi IA 0 si. 05:00 09:00 4.00 COMPZ WELCT WOEO NP Stand by /filter addtnl filtered seawater. 09:00 09:30 0.50 COMPZ WELCT OWFF P Bleed tbg press, 30 psi to 0 psi ! 10 min. Observe well. Wellbore static tbg and annulus. 09:30 10:30 1.00 COMPZ WELCT NUND P PJSM, install BPV, ND tree. 10:30 16:00 5.50 COMPZ WELCT NUND P PJSM, NU BOPE, all components. 16:00 18:00 2.00 COMPZ WELCT OTHR P PJSM, change to 4 1/2 rams. _~~ ~ ~~ ~ _ Pa~~ 1 ~~ r~ Time Logs Date From To Dur S. Depth E, De th Phase Code Subcode T COM _ _ 12!13/2006 18:00 22:00 4.00 COMPZ WELCT ROPE P PJSM, RU /test BOPE. Function and PT BOP rams, annular, and choke manifold to 250/2500 psi. BOP test witness b AOGCC Lou Grinaldi . 22:00 00:00 2.00 COMPZ RPCOR RURD P Pull blanking plug and BPV. Make up landing joint. Load 35 joints of 4.5" tubin in i e shed and stra . 12/14/2006 00:00 01:30 1.50 COMPZ RPCOh PULD P Pull hanger to rig floor, hanger pull free at 100K, string weight 100K. Inspect hanger, measure penetrators, and take pictures. No indications why hanger was difficult to land on last workover. Lay down landing joint and han er. 01:30 02:30 1.00 COMPZ RPCOA CIRC P Circulate bottoms up @ 2.5 BPM @ 1500 si. 02:30 09:30. 7.00 COMPZ RPCOh PULD P POOH w/ 4.5" ESP completion, standing back tubing in derrick, spooling up ESP power cable and -wire. 09:30 13:30 4.00 COMPZ RPCOR PULD P Flow check, losses approx 4.5 BPH on TOH. La do ESP ass ,clear floor. 13:30 14:30 1.00 COMPZ RPCO4 PULD P MU Baker seal assy, flow check, RIH same. 14:30 20:30 6.00 0 5,430 COMPZ RPCOA TRIP P Follow seal assy with 4 1/2 tbg in sgls (37 jts), begin RIH 4 1/2 tbg from mast. Ta fill 5410'MD. 20:30 00:00 3.50 5,430 5,591 COMPZ RPCOA CIRC P Reverse circulate bottoms up @ 5 BPM @ 110 psi, had to reduce rate to 3 BPM do to filtration unit plugging off, very small amount of calcium carbonate and possibly old mud in returns. Continue circulating while running in hole, tag fill @ 5440'MD, continue circulating while working pipe, work through area, pipe moving freely. Continue in hole with seal assembly on 4.5" tubing, tag top packer with seal assembly @ 5585'MD, locate no-go @ 5591'MD. Up/Down weight 103K and 53K, calculate space-out, pull out of packer assembly. Pump sweep around @ 5 BPM @ 130 psi, no solids in sweep, circulate hole clean. 12/15/2006 00:00 01:00 1.00 5,584 COMPZ RPCOA CIRC P Finish circulating hole clean. 01:00 05:00 4.00 COMPZ RPCOA HOSO P Make up landing joint and hanger, sting in PBR, calculate space out. Make up space-out pups. Re-land HGR /sting in PBR, verify space-out. Tubing 9000# in compression. Sting out of packer assembly /HGR out wellhead for freeze protect. Difficulty orientin mule shoe / h r to land. 1~~gQ 2 of 3 s n i Time Logs Date From To Dur S. bepth_ E D e th Phase -Code Subcode T COM __ 12/15/2006 05:00 06:30 1.50 COMPZ RPCOR FRZP P Pump 150 bbls diesel down IA for freeze protect, let diesel U tube to tubin side. 06:30 07:30 1.00 COMPZ RPCOh HOSO P Drain BOP, re-land HGR with 9500# compression on PKR. Run in LDS, confirm HGR dn. 07:30 08:30 1.00 COMPZ WELC7 OTHR P PJSM, test 4 1/2 X 7 5/8 ann to 1500 psi / 30 min. Test successful, no re-tests. Set BPV. 08:30 12:00 3.50 COMPZ RPCOh NUND P PJSM, ND BOPE. 12:00 13:30 1.50 COMPZ RPCOh NUND P PJSM, install prod tree. Pull BPV, set TWC. 13:30 15:30 2.00 COMPZ WELCT OTHR P Test tree 5000 psi / 15 min. Test successful. 15:30 16:30 1.00 COMPZ MOVE RURD P PJSM, Complete clean pits while RD rig, prepare move to 2T-208. Release rig Nordic #3, this date, 1630 hrs. Sus end o erations. 12/23/2006 06:00 07:00 1.00 MIRU MOVE MOB P PJSM, commence move out Nordic rig #3, 1 C-17 to 2T-203. ~__ ~'~tt~ of 3 ~ono-c Phillips Time Log Summary tNe/Niew 1Neb ReAORtng __._..~ Well Name: 2T-203 Job Type: RECOMPLETION Time Logs --- - _ -- - Date Frortz To Dur S. De th E. De th Pha ~e Code Subcode T COM ---__- 12/23/2006 06:00 18:00 12.00 MIRU MOVE MOB P Move rig and camp from 1C pad to 2T ad 12/24/2006 00:00 01:00 1.00 MIRU MOVE PSIT P Spot rig over well. 01:00 06:30 5.50 MIRU MOVE RURD P Accept rig at 0100 hrs. Continue to spot kill tank, misc equipment. Make plumbing /elect connections. Make read for well work. 06:30 07:30 1.00 COMPZ WELCT OTHR P PJSM, Observe press. on tbg /ann. Bleed 75 psi on ann to 0 psi in 5 min. Ann. static, tb on vacuum. 07:30 08:30 1.00 COMPZ WELCT NUND P PJSM, ND prod tree, visual inspect same. 08:30 10:00 1.50 COMPZ WELCT OTHR P RU rock washer, plumb lines while wait on blanking plug, due to incorrect lu arrivin to ri . 10:00 14:00 4.00 COMPZ WELCT NUND P PJSM, set blanking plug. NU BOPE. 14:00 15:00 1.00 COMPZ WELCT OTHR P PJSM, change to 4 1/2 rams. 15:00 21:00 6.00 COMPZ WELCT BOPE P Test BOPE. Test Rams to 250/2500 psi. Test Annular Preventer to 250/2500 si. 21:00 23:00 2.00 COMPZ RPCOh OTHR P PJSM. Pull blanking plug. Pull BPV. MU landin 'oint. 23:00 00:00 1.00 COMPZ RPCOh OTHR P Unland tubing hanger. Hanger pulled free at 115K up wt. Lay down tubing han er 12/25/2006 00:00 01:30 1.50 COMPZ RPCOR CIRC P Pump 146 bbls of 2 micron filtered SW down IA, well on vac, did not get any returns. Pump 85 bbls 2 micron filtered SW down tubing, did not get an returns. 01:30 05:30 4.00 5,582 0 COMPZ RPCOR PULD P PJSM. POOH laying down first 31 joints, standing back next 49 stands. Well still on Vac, replace tubing displacement + 20 bbls/hour with 2 micron filtered SW. 05:30 07:30 2.00 0 0 COMPZ RPCOh OTHR P Strap tbg, /record dimensions ESP / all related equip. RU floor, prepare for ESP com letion. 07:30 08:30 1.00 0 0 COMPZ RPCOh PULD P PJSM, MU TCC, XO, intake, RIH same. 08:30 12:00 3.50 0 0 COMPZ RPCOh PULD P PJSM, RU slickline, set pump, test 500 si. Rack TCC to mast. 12:00 13:00 1.00 0 0 COMPZ RPCOA SLKL P RD slickline, clear floor excess equip. ~~ Time Logs _ Date From To Dur S. De th E De th Phase Code Subcode T COM - _ - - - 12/25/2006 13:00 19:00 6.00 0 0 COMPZ RPCOh RCST P PU ESP motor assy /seal sections, purge with oil. RU cable /control line sheaves. Connect sensor lines, motor leads, band all lines /leads. Cont MU remainin ESP a ui . 19:00 20:00 1.00 0 130 COMPZ RPCOh RCST P MU connections to pressure sub and ensure data is bein transmitted. 20:00 00:00 4.00 130 2,000 COMPZ RPCOh RCST P Continue to RIH with 4.5" tubing. Clamp each collar with cannon clamps above GLM, then clamp every other collar. Perform electrical inspections/tests on the ESP power cable eve 1000'. 12/26/2006 00:00 04:00 4.00 2,000 4,613 COMPZ RPCOR RCST P Continue to RIH with 4.5" ESP Com letion 04:00 05:30 1.50 COMPZ RPCOA RCST P MU tubing hanger. 05:30 07:30 2.00 COMPZ RPCOh WOEQ NP Wait on Penetrators from Centrilift for tubin han er. 07:30 10:30 3.00 COMPZ RPCOh SFEQ P Splice ESP cable to penetrator on han er. 10:30 12:30 2.00 COMPZ RPCOti SFEQ NP ESP cable splice is too short. Need to breakout full joint below hanger and MU 2 pups to make ESP cable plug into enetrator. 12:30 14:30 2.00 COMPZ RPCOh HOSO P Land tubing hanger 14:30 16:30 2.00 COMPZ RPCOh FRZP P Pump 150 bbls diesel down tubing for freeze rotection. 16:30 22:30 6.00 COMPZ RPCOh NUND P Set TWC and ND BOPE 22:30 23:30 1.00 COMPZ RPCOh SFEQ P Check ESP cable/motor for electrical integrity. DID NOT Pass. Cable tested Grounded. Will have to NU BOPE and pull hanger to floor and ins ect cable. 23:30 00:00 0.50 COMPZ RPCOh NUND T Begin to NU BOPE 12/27/2006 00:00 03:00 3.00 COMPZ WELCT NUND T NU BOPE 03:00 04:00 1.00 COMPZ WELCT BOPE T Fill stack and body test BOPS to 250/3000 si 04:00 06:00 2.00 COMPZ WELCT OTHR T Continue to round up lubricator and extensions to pull TWC. Off load excess tools. Monitor IA. Pull TWC. 06:00 06:30 0.50 COMPZ RPCOh RURD T MU Landing joint. BOLDS. 06:30 10:00 3.50 COMPZ RPCOR PULD T PJSM. MU valve on landing joint. Pull hanger to floor. Found ESP cable pinched thru armor about 1' below penetrator in area of pigtail splice to penetrator, probably caught on secondary packoff on 7-5/8" casing hanger. Cut off below bad spot and tested cable, OK. MU new pigtail and re-splice, new splice is about 8' below han er. Re-test cable, OK. e ~~ _ ~_.... ___ __ Pa~~ 2 ~f 3 ~__..~ _ i Time Logs _ _____ Date From To Dur S__D_e~ E. Depth Phase Gode Subcode T_ COM____ _ ~_ 12/27/2006 10:00 11:00 1.00 COMPZ RPCOR RCST T MU ESP cable to penetrator. Re-dress seals on tubin han er. 11:00 12:00 1.00 COMPZ RPCOR RCST T PJSM. Land tubing hanger. 115K# PU, 60K# SO, 39K# Block. Wt. RILDS. LDLJ. Set TWC. 12:00 14:30 2.50 COMPZ RPCOh NUND T PJSM. ND BOPE. 14:30 15:00 0.50 COMPZ RPCOti DHEO T Test ESP power cable, OK 15:00 16:30 1.50 COMPZ RPCOA NUND P MU FMC 11" 5 Ksi X 4-1/16" 5 Ksi Adapter and Tree. Test hanger void to 5000 psi, OK. Test tree to 5000 psi, OK. 16:30 17:00 0.50 COMPZ RPCOh DHEQ P RU valve service truck hose to 3/8" capillary tube. Pump hydraulic fluid into line and hold 1500 psi to verify integrity, OK. Continue pressuring up, bottom check opened at 2400 psi, OK. Bleed off and secure chemical in'ection line. 17:00 18:00 1.00 COMPZ RPCOh FRZP P Little Red pump 78 Bbls of diesel for freeze protection into IA. IA on vacuum after shutting down. RD lines and secure well. Release Rig @ 1800 hrs _ - - ~ ~~g~ 3 ~t 3 • 2t-203 Well Events Summary DATE Summary 12/20/06 RIH WITH JSN, JETTED THROUGH FILL AT 5560', WELL WENT ON A VAC, JETTED SCREENS TO TAG AT 7484' (TD). RAN SCHLUMBERGER SCALE BLASTER TOOL TO 7480', PUMPED 107 BBLS ACID ACROSS SCREENS FROM 5560' TO 7415'. JETTED ACROSS SCREENS WITH SSW, TWO PASSES, 200 BBLS. BULL HEADED 500 BBLS SSW. FP WELL WITH 50 BBLS DIESEL. RE: 2T-203 (205-197) ESP failure -Gas lift test request Subject: RE: 2T-203 (2Q5-197) ESP failure -Gas lift test request From: NSK Problem Well Supu <n1617~cr~,conocophillips.com> Date: Sat, 04 Nov 2006 12: X6:12 -0900 Ta: Thomas Maunder <tonl n~aunder(u;,admin.state.ak.us% Tom, To follow-up an the approval for a temporary gas lift test of packerless ESP well 2T-203, operations decided against trying the gas lift test. It has remained SI waiting on the RWO which is scheduled for this winter. Thanks, Marie McConnell Problem Well Supervisor (907) 659-7224 n 1617@conocophillips. com From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, September 06, 2006 12:43 PM To: NSK Problem Well Supv Subject: Re: 2T-203 (205-197) ESP failure -Gas lift test request Hi MJ, Your plan sounds appropriate. Keep us informed. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 9/6/2006 10:44 AM: Tom, Approval to temporarily gas lift 2T-203 (205-197) for less than 30 days is requested for RWO diagnostic planning. A RWO is planned to repair the well. However, as production performance before pump failure was considerably less than expected, a production test on gas lift is needed to evaluate if the ESP should be replaced or a gas lift completion should be installed. It is expected that the test on gas lift will be completed within ~7 days, but might be extended a few days depending on how the test progresses. CPAI will notify AOGCC when gas lift production has started and again when the test has been completed. Let me know if you have any questions or require anymore details about the proposed gas lift test. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 1 of 2 11/6/2006 8:26 AM RE: 2T-203 (205-197) ESP failure -Gas lift test request -----Original Message----- ', From: NSK Problem Well Supv Sent: Sunday, August 06, 2006 2:56 PM To: Thomas Maunder' ', Cc: NSK Problem Well Supv ', Subject: 2T-203 (205-197) ESP failure Tom, The ESP on 2T-203 (205-197) went down on a phase motor failure and will require a work over to pull and replace the pump. Currently the well is SI. At the present time ConocoPhillips does not intend to pursue a variance to lift the well with gaslift. If plans change the 10-403 approval will be requested at a later date. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 2 of 2 11/6/2006 8:26 AM WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2T-203, August 2, 2006 AK-MW-4163248 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20520-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: -_~ Signed: ~EC~IVED AUG 2 2 2006 ~b S - ~ 9 ~- CN! & Gas Cons. Commission ~ ;/Y035~ Anchorage ZT-203 (205-197) ESP failure • • Subject:2T-2O3 (205-197) ESP failure From: NSk Problem Well Supv <n1617(cr`conoeophiTlips.com= Date: Sun, 06 .\u~ 2t~06 1-1:~i5:55 -0800 'fo: "hhomas Maunder °~tonl maundcr(iadmin.state.al:.us> LC: NSK ProbleiZl Well Supv <n1617(i?conocophillips.com% Tom, The ESP on 2T-203 (205-197) went down on a phase motor failure and will require a work over to pull and replace the pump. Currently the well is SI. At the present time ConocoPhillips does not intend to pursue a variance to lift the well with gastift. If plans change the 10-403 approval will be requested at a later date. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 1 of 1 8/7/2006 12:08 PM • ConocoPhillips April 13, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2T-203 Dear Commissioner: • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2T-203. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~~~'~ :l 9 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ :~~ o~s~ vommissiol WELL COMPLETION OR RECOMPLETION REPORT AND LO~t~i~~~~~ 1a. Well Status: Oil Q Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: February 25, 2006 12. Permit to Drill Number: 205-197 / • 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 24, 2006 13. API Number: 50-103-20520-00 4a. Location of Well (Governmental Section): Surface: 580' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 7. Date TD Reached: February 13, 2006 ~ 14. Well Name and Number: 2T-203 At Top Productive Horizon: 646' FNL, 139' FEL, Sec. 2, T11 N, R8E, UM 8. KB Elevation (ft): 30' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 228' FSL, 1095' FWL, Sec. 36, T12N, R8E, UM 9. Plug Back Depth (MD + TVD): 7484' MD / 3103' TVD Tabasco Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498945 y- 5970560 Zone- 4 10. Total Depth (MD + TVD): - 7525' MD / 3101' TVD 16. Properly Designation: ADL 25569 & 25548 TPI: x- 498248 y- 5974614 Zone- 4 Total Depth: x- 499481 - 5975488 - Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 2667!2662 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1556' MD 21. Logs Run: GR/Res, Dens/Neu ~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 152# X-65 30' 107' 30' 107' 24" 150 sx ASI 10.75" 45.5# L-80 30' 1610' 30' 1545' 13.5" 39o sx ASLite, 340 sx AS I 7-5/8" 29.7# L-80 30' 6046' 30' 3099' 9-7/8" 450 sx DeepCRETE 4.5" 12.6# 13Cr 5582' 7484' 3003' 3103' 6.75" screens 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET screens from: 4.5" 4630' 5582' 5654'-5737' MD 5991'-6033' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6035'-6657' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6704'-6746' MD n/a 6748'-7371' MD 7373'-7415' MD 26. PRODUCTION TEST Date First Production April 9, 2006 Method of Operation (Flowing, gas lift, etc.) ESP oil producer Date of Test 4!10/2006 Hours Tested 10 hours Production for Test Period --> OIL-BBL 173 GAS-MCF 13 WATER-BBL 69 CHOKE SIZE 176 Bean GAS-OIL RA7lo 104 Flow Tubing press. 310 ps Casing Pressure not available Calculated 2a-Hour Rate -> OIL-BBL 400 GAS-MCF 41 WATER-BBL 164 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Z~zs ,. NONE ~~. ~A~ G~ ~ 2006 ~ b . ,,n~~wt~ .... ~. Form 10-407 Revised 12/2003 ~ ('1 (~ I ~ ~~ ! ~ ~ CONTINUED ON REVERSE ~~ ~ r 2s. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. It no tests were conducted, state "None". 2T-203 Tabasco 6009' 3090' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 263-6481 Printed N~ R hom s Title: Greater Kuoaruk Area Drillino Team Leader y~f 3l0 G Signature 2•G~G~ 3 rJ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Contractor Name: n1433@ppco.com Rig Name: Nordic 3 Date From - To ,Hours Code Code' Phase _-- - -- 1/21l2006 15:00 - 21:30 I 6.501 MOVE I, DMOB MOVE 1/22/2006 21:30 - 00:00 I 00:00 - 03:45 2.50 3.75 MOVE MOVE 03:45 - 04:15 0.50 MOVE 04:15 - 07:00 i 2.75 MOVE i 07:00 - 09:00 ' ~ 2.00 ~'1 MOVE 09:00 - 10:00 1.00 WELCTL 10:00 - 12:00 2.00 ii MOVE 12:00 - 19:00 I, 7.0011, RIGMNT I 1 19:00 - 00:00 i 5.00 I RIGMNT 1 /23/2006 100:00 - 09:30 109:30 - 12:00 1,12:00 - 00:00 1 /24/2006 100:00 - 07:30 '~ 07:30 - 09:30 109:30 - 11:00 ,11:00 - 15:00 9.50'', 2.50' 12.00:: WAIT( 7.50 WAIT( 2.001 WELC 1.501, DRILL 4.00'' WELC MOVE I MOVE MOVE MOVE POSN MOVE RURD '~, MOVE RURD RIGUP I NUND 'RIGUP RURD ,RIGUP RSRV RIGUP I RSRV 'RIGUP WOW 'RIGUP WOW !:RIGUP WOW 'RIGUP WOW RIGUP NUND 1 RIGUP OTHR !RIGUP NUND 1 RIGUP 15:00 - 15:30 '' 0.5011 WELCTL' BOPE ~'1 RIGUP 15:30 - 16:30 '', 1.00; DRILL I OTHR RIGUP I 16:30 - 17:00 ', 0.50 DRILL SFTY ~ RIGUP '.17:00 - 18:30 '~, 1.50'.- DRILL li OTHR RIGUP ; 118:30 - 19:45 '1 1.25' DRILL ; ', RIRD RIGUP ;19:45 - 21:15 I 1.50; DRILL ', PULD I SURFAC '; 21:15 - 21:30 ' ; 0.251 DRILL ' OTHR SURFAC '121:30 - 22:00 ', 0.50' DRILL I CIRC SURFAC 22:00 - 00:00 11 2.00!; DRILL I ~ DRLG ;I SURFAC i Start: 1 /21 /2005 Rig Release: 2/25/2006 Rig Number: 3 Page 1 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Description of Operations Prep cellar for rig move, blow dwn heaters and water lines, RD rock washer box, hang off diverter stack. 'i1 Call DSO to location, back rig off welt, move rig mats from 208 to 203. Fin spotting rig mats and aligned rig with well 2T-203. ~!~ Moved rig and spotted over well Leveled rig and bermed around cellar, set in blow down tank, (ACCEPTED RIG @ 07:00 hrs 1/22/2006, Blowing snow, temp. -33 with ~'; -66 wind chill and wind at 29 mph ~~ Set in service company shacks and hooked up same, changed out liners on mud pumps to 5 1/2", PHASE 2 called field wide Warmed up starting head and set on starting head and diverter, found conductor and landing ring to be approx 12" low not allowing 16" diverter line to go thru window in cellar, compared to 2T-208 and 2T-203 it is lower. ~, Cont to rig up, took on water to rig, changed out saver sub on top drive to 5", prep'd cellar for welder Inspect Top Drive grabber box assembly, C/O washpipe/swivel packing, ~~ Load 290 bbls Spud Mud, attempt to spot rock washer tank, adjacent I well house needs moved, crane on stndby till weather conditions permit ',moving well house. ~ Slip and cut drill line, load 10 3/4" casing, strap and drift to 9.875", C/O ~' gearbox oil on Top Drive, remove starting head from conductor, prep 'and began rewelding conductor extension, RD Eckle tubing tongs, RU !.pipe spinner. Field still in phase 2 condition. Cont to be in Phase 2 weather cond., fin. loading pipe shed with 10 3/4" csg, fin welding on ext to 16" conductor, set in cuttings tank for ',centrifuge and bermed same 'Set on 21 1/4" 2M diverter and NU 1st section of 16" diverter line, Phase 3 was called at 10:15 hrs ', Finish strapping 10 3/4" csg, clean and organize rig, service loader 'while waiting on phase 3 weather. Cont to service and clean around rig while waiting on Phase 3 weather, Phase 3 lifted in field, access road to 2T phase 2, called out crane Began to NU riser and bell nipple, with crane removed 2T-30 wellhouse !Removed centrilift ESP spools from rig floor and loaded GBR's 10 3/4" csg equipment '~I Fin NU riser and MU hydraulic lines to diverter valves and hooked up ',turnbuckles, fin MU 16" diverter line. '; Function tested diverter and performed koomey test, NOTE: John ';Spaulding waived witnessing of test ', Strapped DP in derrick and HWDP and jars in pipe shed Held pre-spud meeting with rig crew and service company personnel Went thru rig prior to spud with crew going off tour and pressure tested ',mud pumps and ck ok, held pre-spud meeting with crew that had 'arrived late onto the slope then held crew change ';Held PJSM then RU Sperry Sun's surface read out gyro MU 13 1/2" RR bit on 8" motor with 1.83 deg bend and tagged up on ice in conductor at 36' Flooded conductor with water and pressure tested mudline and I standpipe to 2,000 psi checking lines for leaks and ck ok. Cleaned out ice in conductor from 36' to 10T, circ down at 300 gpm at ' 175 psi ~'; Spudded well and drilled 13 1/2" hole from 10T to 163' MD/163' TVD Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Contractor Name: n1433@ppco.com Rig Name: Nordic 3 Date From - To Hours ' Code Sub Code 1/24/2006 ':22:00-00:00 1/25/2006 '00:00-09:00 09:00 - 10:30 10:30 - 13:15 1/26/2006 13:15 - 13:45 -13:45 - 15:30 15:30 - 16:15 16:15 - 19:30 19:30 - 21:00 '; 21:00 - 22:00 22:00 - 00:00 00:00 - 06:00 06:00 - 10:00 2.00 DRILL DRLG ~ 9.00 DRILL DRLG i i 1.50, DRILL i ~~,SURV 2.75' DRILL I DRLG 'i 0.50', DRILL '~CIRC 1.75, DRILL ,TRIP 0.75' DRILL IOTHR 3.25' DRILL ',TRIP 1.50! DRILL i I,DRLG 1.00! RIGMNTI,RGRP 2.00' DRILL ',DRLG 6.00', DRILL 'DRLG 4.001 DRILL 'SURV 1,10:00 - 23:00 I~ 13.00 I ', 23:00 - 00:00 I 1.00 1 /27/2006 ', 00:00 - 01:15 ~I ' 1.25 , I ,01:15-01:30 ~ 0.25 , 01:30 - 02:30 ii 1.00 DRILL ,,DRLG DRILL CIRC DRILL 'CIRC DRILL 'OBSV DRILL WIPR Page 2 of 15 Spud Date: 1/19/2006 Start: 1/21/2005 End: 2/25/2006 Rig Release: 2/25/2006 Group: Rig Number: 3 Phase Description of Operations SURFAC (56') ART 1.1 hrs SURFAC Drilled 13 1/2" hole per directional plan from 163' to 583' MD/57T ND (420') ADT 6.47 hrs, AST 5.47 hrs, ART .95 hrs, 10-20K wob, 50-60 ;rpm's, 140 spm, 420 gpm at 450 psi. Took Gyro surveys every ', connection due to close approach's, saw good build with lower pump ~, rate and got ahead of plan SURFAC '~, Backreamed hole and ran 3 gyro's attempting to drop angle with no '.change SURFAC ', Drilled 13 1/2" hole from 583' to 679' MD/ 641' ND, (96') ART .78 hrs, ',AST .6 hrs, 10-20K wob, 50-60 rpm's, 167 spm, 500 gpm, off btm ,pressure 460 psi, on btm, 550 psi, off btm torque 800 ft-Ibs, on btm ', 2,200 ft-Ibs, rot wt 45K, up wt 45K, do wt 45K, ran gyro survey and with 'increase in pump rate and 30' slide and 60' of rotation saw 1.78 deg ',drop in angle to put well back on line SURFAC ',Circ btms up at 679', circ at 420 gpm at 500 psi SURFAC '.Monitored well-static, blew down top drive and POOH with BHA #1. Rig 'went on Hi-Line power @ 1415 hrs. SURFAC 'Change bend on mud motor from 1.83 deg. to 2.12 deg. SURFAC !Held PJSM. PU & MU MWD tools and non-mag flex drill collars, BHA ~~#2. RIH to 679'. SURFAC ,'Drill from 679' to 705' MD. SURFAC '', POOH 1 stand. Blow down top drive. Replace wash pipe in top drive. RBIH. SURFAC I Continue drilling 13-1/2" hole from 705' to 78T MD/780' ND as per '~ directional plan. ADT 2.48 hrs, AST 1.58 hrs, ART 0.90 hrs. 10-12 K# ', WOB, 50 RPM, 154 SPM, 460 gpm, 1000 psi, on btm torque 2200 ft-Ib, ~ off btm torque 1200 ft-Ib, rot. wt. 60K, up wt. 60K, do wt. 55K. Ran one ~ Gyro, checked OK with MW D. SURFAC 'I Directionally drilled 13 1/2" hole from 78T to 1,078' MD/ 1,058' ND 291'), ART 1.58 hrs, AST 2.69 hrs, 10-20K wob, 50 rpm's, 160 spm, ~i475 gpm, off btm pressure 1,050 psi, on btm 1,150 psi, off btm torque II 1,600 ft-Ibs, on btm 3,000 ft-Ibs, rot wt 68K, up wt 68K, do wt 68K, ran ~I gyro surveys ea. corm SURFAC III Ran gyro surveys due to magnetic interference and close approach to 2T-210 well, at current AZ well would cross hard line, discussed with (town, determined the 2T-210 well was a shut in inj since 1/01and had 11650 psi tbg press, 1700 IA press and 100 psi OA press, bled OA ;pressure down to -0-and was ok'd to drill ahead surveying 30' intervals. SURFAC ~ Directionally drilled 13 1/2" hose 1,078' to 1620' MD/ 1554' ND (542'), ART 1.17 hrs, AST 7.33 hrs, 15-20K wob, 50 rpm's, 194 spm, 578 gpm, off btm pressure 1500 psi, on btm 1600 psi, off btm torque 3500 ft-Ibs, on btm 5500 ft-Ibs, rot wt 73K, up wt 77K, do wt 70K, released gyro at 1,143', ran a total of 18 gyro surveys on surface hole and took a total of i~ 6 hrs, ave 20 min per run SURFAC Pumped 30 Bbl, weighted hi-vis sweep at 11.3 ppg, had no increase in cuttings back from sweep, circ at 194 SPM, 578 GPM, 1500 psi. Circ hole MW in and out at 9.5 ppg. SURFAC Fin circ hole clean after pumping sweep, circ 3X btms up and was clean at the shakers, circ at 194 SPM, 578 GPM, 1500 psi. Circ hole MW in and out at 9.5 ppg. SURFAC Monitored well-static, blew down top drive SURFAC Wiped hole by POOH wet from 1,620' to 610' on elevators with no problems Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Page 3 of 15 Legal Well Name: 2T-203 Common Well Name: 2T-203 Spud Date: 1/19/2006 Event Name: ROT -DRILLING Start: 1/21/2005 End: 2/25/2006 Contractor Name: n1433@ppco.com Rig Release: 2!25/2006 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code '~, Cade ~'i Phase Description of Operations __ 1 /27/2006 ', 02:30 - 03:30 '~ li 03:30 - 04:00 i 04:00 - 06:00 ~~ 06:00 - 06:15 111 06:15 - 07:30 107:30 - 10:30 11! 10:30-11:30', 11:30 - 13:30 13:30 - 13:45 13:45 - 18:00 1 11 i it '118:00 - 20:15 120:15-21:00 L 21:00 - 22:30 1 '.22:30 - 00:00 '1 1 /28/2006 100:00 - 00:15 'I 11 1~ .00:15 - 01:00 'I 01:00 - 02:45 02:45 - 07:00 1.00', DRILL ' WIPR ''SURFAC 0.501, DRILL ;REAM ~ SURFAC 2.00' DRILL CIRC SURFAC i 0.251 DRILL ~~ ' OBSV SURFAC 1.2511 DRILL TRIP ',SURFAC I 3.0011, DRILL ' PULD I SURFAC 1.00', CASE ' OTHR I, SURFAC CASE 2.001, 'RURD ~ SURFAC , 0.25 ~~, CASE ', SFTY I SURFAC 4.2511 CASE I RUNC SURFAC 2.25'' CEMENTCIRC SURFAC 0.7511 CEMEN7~1 RURD I SURFAC 1.501 CEMENTCIRC (SURFAC 1.50 0.25 0.75 PUMP SURFAC CEMEN~PUMP'SURFAC CEMENI~DISP !SURFAC 1.75 CEMEN~RURD SURFAC 4.25 WELCT NUND SURFAC RIH from 610' to 1,458' Precautionary washed and reamed from 1,458' to btm at 1,620' with no problems ~ Pumped weighted hi vis sweep and circ hole clean, saw no increase in ~~~ cuttings from sweep, circ a total 3X btms up and was clean at the shakers, circ at 194 spm, 578 gpm, 1,500 psi and 60 rpm's, MW in and out at 9.6 ppg Monitored well-static, blew down top drive ', POOH wet on elevators from 1,620 to 160', stood back HWDP and jars, POOH to NMFDC's with no problems POOH LD 3- NMFDC's to MWD, downloaded MWD and fin LD BHA #2 1' and cleared rig floor Made dummy run with 10 3/4" landing jt and hanger RU GBR's 10 3/4" csg equip. with Franks fill up tool I Held PJSM with rig crew and casing crew on running order and potential hazards M/U 10 3/4" shoe tract RIH to 125' with Jts #1 through #3 thread locking same and circ and check floats, Cont RIH with 10 3/4" csg to1,575' with no problems and good pipe displacement, st wt up 105K, do wt 70K, MU hanger and landed csg with float shoe at 1,609.76' MD/ 1,545' TVD and float collar at 1,527, no problems RIH, Ran a total of 40 jts (1,572') of 45.5#, L-80, BTC csg, total csg, float equip and hanger, 1,578.94', ran 16 bow spring centralizers and 3 stop rings per well plan (Jts #1 to 15 jts & Jt #39). ', Circ hole thru fill up tool and began cond mud for cementing, staged 'pump rate up to 6 bpm at 250 psi, st wt up 95K, do wt 70K, reciprocating pipe with full returns I, RD Franks fill up tool and RU Dowell cement head 'Fin circ and conditioning mud for cementing, conditioned mud from 9.8 II ppg, 98 vis, PV 40 and YP of 59 to a mud out of 9.7 ppg, 61 vis, 21 PV 'and 16 YP, circ at 6 bpm at 300 psi, st wt up 100K do wt 73K and held PJSM with Dowell, ASRC vac truck drivers, MI mud eng. and rig crew on cementing operations while circ. 11 Dowell pump 5 Bbl water ahead, pressure test lines to 3500 psi. Pump 50 Bbl CW100 flush, 8.3 ppg, 5 BPM avg, 160 psi. Pump 40.6 Bbl of ',10.8 ppg Mudpush at an ave 4 BPM, 100 psi. Drop bottom plug. Mix & ', pump 310 Bbl (390 sx) of 10.7 ppg Arcticset Lite lead cement, ave 5.6 ',BPM, 120 psi. Finish lead & start mixing 15.7 ppg Arcticset tail slurry at midnight. Reciprocating casing 5' to 6', 105 K# up weight, 75 K# down I, weight. (Note: Bumped plug @ 0045 hrs 1/28/06, approx. 70 Bbls cmt 1 returns to surface.) Cont to cement 10 3/4" csg, Mixed & pumped 56 Bbls (340 sx) of 15.7 ppg, .93 yield Arcticset I tail cement, ave 5.1 BPM, 225 psi. shut downand dropped top plug. Dowell chased plug with 20 Bbl water, 5.7 BPM, 90 psi. Switch to rig :.pump and displace with mud, 5.9 BPM, 350 psi -slowed to 3.6 BPM last 12 Bbl. Bumped plug at 126 Bbl mud to 1000 psi. Checked floats, ,floats held. CIP @ 00:45 hrs. Reciprocated casing 5'-6' until cement returned to surface, 105K# up wt, 75 K# down wt, landed on fluted ', hanger. Had 70 Bbls of 10.7 ppg lead cement returns to surface. Full ', returns throughout. RD cmt head, landing jt and csg equip., flushed out diverter 1 ND 21 1/4" Diverter and 16" diverter line Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report 2T-203 2T-203 ROT -DRILLING n1433@ppco.com Nordic 3 Date From - To 1/28/2006 I~, 07:00 - 08:00 108:00 - 10:30 10:30 - 11:15 11:15 - 11:30 11:30 - 17:00 17:00 - 22:45 Hours ' Code I Code Phase 1.00 DRILL OTHR 'SURFAC 2.50' WELCTL NUND 'SURFAC 0.75' WELCTL NUND !SURFAC 0.25', WELCTL OTHR !SURFAC 5.50 ~, WELCTL NUND SURFAC 5.75' WELCTL BOPE SURFAC 22:45 - 23:30 0.751 DRILL I OTHR j SURFAC I, 23:30 - 00:00 i 0.501 DRILL II OTHR 'SURFAC t 1/29/2006 'i 00:00 - 06:30 6.5011 DRILL OTHR ,SURFAC I 06:30 - 07:00 0.50'1 DRILL ii RIRD '~ SURFAC 07:00 - 14:30 !, 7.50 DRILL I PULD i SURFAC 14:30 - 16:00 ', ~ 1.50 RIGMNT, RSRV I, SURFAC I 16:00 - 22:00 ', 6.00 DRILL PULD ~, SURFAC 22:00 - 00:00 ' 2.00 1 /30/2006 00:00 - 01:30 ' 1.50 01:30 - 02:00 02:00 - 03:00 03:00 - 04:30 ' 04:30 - 06:15 06:15 - 09:00 09:00 - 09:45 :09:45 - 11:00 '.11:00 - 00:00 1 /31 /2006 ' 00:00 - 13:00 13:00 - 14:00 14:00 - 16:00 DRILL 'PULD DRILL PULD SURFAC SURFAC 0.50' DRILL 1 OTHR ~, SURFAC 1 DRILL 1.00 TRIP SURFAC 1.501 DRILL ~ CIRC SURFAC 1.751 CASE DEQT SURFAC i 2.751 CEMEN7DSHO (SURFAC 0.75', DRILL i I CIRC 1.25 ~I DRILL ,LOT 13.00' DRILL 'DRLG 13.00! DRILL ,DRLG 1.00'' DRILL 'CIRC SURFAC SURFAC INTRMI I NTRM 1 INTRM1 2.00 DRILL I WIPR ~ INTRM1 Start: 1 /21 /2005 Rig Release: 2/25/2006 Rig Number: 3 Page 4 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Description of Operations Unloaded 8" Sperry Sun tools and 10 3/4" csg from pipe shed Oriented and NU FMC 11" x 5M Unihead Tabasco horizontal csg and tbg head Set on 11"BOP stack I Tested seals to 1,000 psi for 10 min 8 ck ok NU 11" BOP stack, riser and flowline, changed out top set of rams over from 4" to 5" DP I~ RU ~ tested BOPE, tested rams including 7 5/8" rams, valves and ~, manifold to 250 psi low and 3,000 psi high including annular, tested ', koomey, beginning pressure 2800 down to 1,800 psi, 200 psi in 17 sec. and full recovery in 1 min 23 sec. psi. NOTE: Chuck Scheve with AOGCC witnessed test i Install wear bushing. ', Load 5"drill pipe into pipe shed. Fin. loading 141 jts of 5" DP into pipe shed and strapped same RU floor and handling tools, held PJSM PU, torqued up and stood back 47 stand of 5" DP Service top drive, drawworks, & blocks. Remove water from pipe shed. Held PJSM, Load 7-5/8" casing into pipe shed, strap same. Approx. ',100 jts, 4 rows in. Will bring in remainder, 50 jts, while drilling. !, Held PJSM, Began to MU 9 7/8" BHA #3, MU bit & Sperry-Sun tools. !~ Fin MU 9 7/8" BHA #3 RIH to 263', uploaded MWD, PU & RIH with 3- 6 1/2" NMFDC's and 1 std of 5" HWDP, shallow tested MWD and blew ',down top drive. Installed wear bushing I, RIH with BHA #3 with HWDP, jars and 5" DP from 263' to 1,480'. ',Circ hole evening MW in and out at 9.0 ppg, circ at 390 gpm at 800 psi RU and tested 10 3/4" csg to 3,000 psi for 30 min and charted same ~, Drilled out cmt plugs, float collar at 1,527, shoe track, float shoe at ',1,609', cleaned out to 1,620' then drilled 20' of new hole to 1,640' MD/1 ,570' TVD, drilled out at 30 rpm's, 5-10K wob, 160 spm, 475 gpm ~'i at 1,100 psi, rot wt 70K, up wt 75K, do wt 65K. ,Circ btms up then displaced out 9.0 ppg spud mud with 8.8 ppg 're-conditioned LSND mud, circ at 160 spm, 475 gpm at 960 psi, blew ~, down top drive RU and performed LOT to 11.8 ppg EMW, 240 psi with 8.8 ppg MW ~', and 1,545 TVD Directionally drilled 9 7/8" hole from 1,640' to 2780' MD/2159' TVD (1140'), ART 2.21 hrs, AST 6.08 hrs, ADT 8.29 hrs, 5K to 10K wob, 80 rpm's, 162 spur's, 483 gpm, on btm press 1180 psi, off btm press 1100 psi,off blur torque 4200 ft-Ibs, on blur torque 4600 ft-Ibs, rot wt 70K, up wt 82K, do wt 60K, with 9.0 ppg MW ECD ave 9.9 ppg, prior to drilling ahead, with 9.0 ppg MW and 80 rpm's, est clean hole ECD's, at 477 gpm clean hole was 9.5 ppg and at 558 gpm clean hole was 9.51 ppg. Continue directional drilling 9-7/8" hole from 2780' to 3742' MD (962'), 2452' TVD. 4.89 ART, 4.19 AST, 9.08 ADT. 5K-10K WOB, 80 RPM, 162 SPM, 483 GPM, 1250 psi-1320 psi on blur, 1140 psi- 1240 psi off blur, 4650 ft-Ib on blur Torque, 4500 ft-Ib off blur Torque, 70K Rot Wt, 87K Up Wt, 62K Dn Wt, 9.0 ppg MW, 9.7 ppg to 10.0 ppg ECD. Pump hi-visc weighted sweep and circulate bottoms up, reciprocate pipe and rotate to clean hole. Stand back 1 stand. Circulate bottoms up, reciprocate and rotate pipe with 2nd stand to clean hole. ,Short trip into 10-3/4" casing shoe. Tight spots at 2665', 2245', & 2050'. Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Page 5 of 15 Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Spud Date: 1/19/2006 Event Name: ROT -DRILLING Start: 1/21/2005 End: 2/25/2006 Contractor Name: n1433@ppco.com Rig Release: 2/25/2006 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To 'Hours ; Code Code Phase ', Description of Operations 1/31/2006 14:00 - 16:00 !, 2.00 DRILL I WIPR ~I INTRM1 ' Hole started swabbing at 2000'. MU top drive, circulate and ream ' '~ stands out until inside shoe. 16:00 - 16:30 ; 0.50;, DRILL CIRC ' INTRM1 ~, Circulate bottoms up, reciprocate & rotate pipe to clean out clay buildup ' ' i inside casing. Break out & blow down top drive. 16:30 - 17:00 'I 0.50.. RIGMNT' RSRV INTRMI 'i Service top drive, drawworks, & blocks. , 17:00 - 20:00 ' 3.00 l DRILL WIPR INTRMI RIH. Work thru tight spot at 1825'. Wash & ream thru tight spots from , i 2000' to 2835'. RIH, precautionary work stands to bottom. ', 20:00 - 00:00 ' 4.001 DRILL ', DRLG INTRM1 Continue directioonal drilling from 3742' to 4006' MD (264'), 2534' TVD. i ', 1.42 ART, 0.52 AST, 1.94 ADT. 5K-10K WOB, 80 RPM, 162 SPM, 483 li ', I ~ GPM, 1350 psi on btm, 1220 psi off btm, 5920 ft-Ib on btm Torque, ~, ~~ !, I 5500 ft-Ib off btm Torque, 70K Rot Wt, 90K Up Wt, 59K Dn Wt, 9.0 ppg MW, 9.8 ppg TO 10.0 ppg ECD. 2!1/2006 00:00 - 20:30 ~ 20.501 DRILL DRLG INTRM1 ', Continue directionally drilling from 4006' to 5385' MD (1379'), 2955' ', ' TVD. 8.81 ART, 4.87 AST, 13.68 ADT. 5K-10K WOB, 80 RPM, 170 i SPM, 507 GPM, 1550 psi on btm , 1450 psi off btm, 8300 on btm II I '~ Torque, 7600 off btm Torque, 79K Rot Wt, 102K Up Wt, 69K Dn Wt, ' ', ~I 9.1 ppg MW, 10.0 to 10.3 ppg ECD. Pumped weighted hi-visc sweeps ~, ', ' ', at 4100', 4600', & 5370'. Slow Pump rates @ 4311' MD, 2629' TVD: ', ,Pump #1 & Pump #2, 180 psi @ 30 SPM, 250 psi @ 45 SPM - SPR @ 4975' MD, 2839' TVD: Pump #1, 190 psi @ 30 SPM, 250 psi @ 45 ', ', ~ SPM, Pump #2, 180 psi @30 SPM, 250 psi @ 45 SPM. 20:30 - 21:30 I 1.00', RIGMNT! RGRP '~ INTRMI DPlrop Drive saver sub washed out. PU 30' 8~ stand back stand. Blow '~ : down top drive. Change out saver sub. Circulate slow thru head pin ' while changing saver sub. ' ' ' ' :21:30 - 00:00 2.50 DRILL ,DRLG ,INTRMI TVD. Continue directionally drilling from 5385 MD (200 ), 3003 to 5585 I ', i I 0.42 ART, 1.20 AST, 1.62 ADT. 5K-10K WOB, 80 RPM, 174 SPM, ~, ~I I li 519 GPM, 1640 psi on btm , 1560 psi off btm, 8500 on btm Torque, I, I ~ 7900 off btm Torque, 79K Rot Wt, 108K Up Wt, 69K Dn Wt, 9.1 ppg ', I I MW, 10.1 to 10.2 ppg ECD. Slow Pump Rates @ 5542' MD,2998' ~ ' ~ ~ 2/2/2006 ~~, 00:00 - 08:00 8.00 DRILL DRLG INTRMI TVD: Pumps #1 & #2: 220 psi @30 SPM, 310 psi @ 45 SPM. 'Continue directionally drilling from 5585' MD to 6062' MD, (47T), 3099' I I ~', TVD. 2.06 ART, 3.19 AST, 5.25 ADT. 5K-10K WOB, 80 RPM, 170 I ~' SPM, 507 GPM, 1650 psi on btm , 1510 psi off btm, 8500 on btm j i II !Torque, 9500 off btm Torque, 82K Rot Wt, 135K Up Wt, 60K Dn Wt, i ~ i ' 9.1 ppg MW, 10.0 to 10.2 ppg ECD. Slow Pump Rates @ 6028' ~i ' ~I ', ', MD,3099' TVD: Pumps #1 & #2: 200 psi @30 SPM, 250 psi @ 45 SPM. ~~ 08:00 - 09:30 ' 1.50', DRILL ',CIRC ' INTRM1 Pump hi-vis sweep and circulate around to clean hole. 167 SPM, 498 'GPM, 1450 psi. ', 09:30 - 10:00 ' 0.50' DRILL ' OBSV INTRM1 ', Blow down top drive. Monitor well, static. 10:00 - 15:00 5.00 ,DRILL REAM ', INTRM1 'i POOH for short trip. Backream out from 5920' to 4500'. 80 RPM, ', L !,Circulate @ 160 SPM, 477 GPM, 1450 psi. :15:00 - 15:30 0.501 DRILL ,WIPR ', INTRM1 I Pull 2 stands on elevators, OK. Blow down top drive. Continue POOH ', ' ~ ~~ for wiper trip of new hole to 3677. 1.001 RIGMNT', RSRV INTRM1 ,15:30 - 16:30 ~I I Service top drive, blocks, & drawworks. Change out grabber dies. , ' '~ 1 '~ Circulate thru headpin while servicing rig. ',16:30 - 18:00 ' 1.501 DRILL WIPR ii INTRMI ' ' RIH from 3677 to bottom at 6062'. Break circulation & tag bottom. LD ' , I !~ 1 jt DP. it 18:00 - 20:30 ~I 2.50 DRILL CIRC , INTRMI I Break circulation & establish good circulation rate. Pump weighted, ii !~ ', hi-vis sweep, & circulate around. Circulate 3 bottoms up to clean hole, ~ ~, ', ', 160 SPM, 477 GPM, 1450 psi. Rotate & reciprocate pipe while ~ ', l 'circulating. it 20:30 - 00:00 ', 3.501 DRILL i TRIP INTRM1 POOH on elevators from 6062' to 2929'. Maximum overpull 20K to Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Opera#ions Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Start: 1/21/2005 Contractor Name: n1433@ppco.com Rig Release: 2/25/2006 Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours !Code !Code' Phase 2/2/2006 2/3/2006 20:30 - 00:00 ~ 3.50 00:00 - 02:30 ~ 2.50 02:30 - 03:30 '' 03:30 - 04:00 04:00 - 04:30 ' ~ 04:30 - 06:30 106:30 - 07:00 ', !~ 07:00 - 08:00 '~, 08:00 - 09:00 II 09:00 - 10:00 '10:00-13:00 '! 113:00 - 14:00 ';14:00-18:001 DRILL '!TRIP INTRM1 DRILL 'TRIP 'INTRM1 1.00 DRILL 'PULD 0.50' DRILL 'TRIP 0.501 DRILL PULD 2.00 ~, DRILL OTHR 0.50', RIGMNT! RSRV 1.00'' DRILL !, PULD 1.00 i DRILL 'RIRD 1.00' DRILL ~, RIRD ~ 3.00 CASE ' RURD 1.00 I RIGMNT!I OTHR 4.00 CASE I RUNC ''.18:00 - 18:30 II 0.50'i CASE ', 18:30 - 21:00 i, 2.50', CASE ', 21:00 - 21:30 !! 0.50'! CASE 21:30 - 00:00 it 2.50 CASE 2/4/2006 00:00 - 01:00 ' 1.00 CASE 01:00 - 02:30: 1.50 ! CASE ~! 02:30 - 03:30 ! 1.00 ! CASE CIRC RUNC CIRC INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRMI I NTRM 1 INTRMI INTRM1 I NTRM 1 I NTRM 1 INTRM1 I NTRM 1 RUNC ' INTRM1 ',RUNC 'CIRC RURD INTRM1 INTRMI INTRM1 INTRM1 03:30 - 06:00 ' 2.501 CEMENT CIRC 06:00 - 07:45 2/5/2006 ~~,! 07:45 - 08:30 08:30 - 09:30 109:30 - 10:30 ',10:30-13:00 13:00 - 14:30 14:30 - 15:30 15:30 - 16:00 16:00 - 21:30 21:30 - 22:00 22:00 - 00:00 00:00 - 05:00 05:00 - 05:30 1.75 CEMENT PUMP ~ INTRM1 I !I ii ! I 0.75' CEMEN i DISP i, INTRM1 i i I 1.0011 CEMENl~RURD INTRM1 1.00 CASE IOTHR INTRM1 2.50 DRILL ! ! I LOT I ,INTRMI ' 1.50 it DRILL 'RIRD i INTRM1 1.00' DRILL '.RIRD INTRMI 0.50' DRILL PULD INTRM1 5.50 DRILL ,PULD I INTRM1 0.50 DRILL I RIRD INTRM1 2.00', RIGMNT RSRV INTRM1 5.00 ~i DRILL I PULD ~, INTRM1 0.501 DRILL OTHR ',INTRMI Page 6 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Description of Operations 25K. (Continue POOH @ 2400 hrs) Continue POOH from 2929' to 439'. Little to no overpull pulling into casing shoe. Pull wear bushing. Continue POOH to 16T. LD 3 non-mag Flex DC. Download MWD. Service rig. LD BHA. 'Clean rig floor & remove tools. 'Change out bails. RU to run 7-5/8" casing. Attempt to blow down kill line, no go, frozen. Will thaw same. PJSM. MU 7-5/8" shoe joints, RIH, check floats, OK. Run 7-5/8", 29.7#, L-80, BTCM casing to 1570', just above surface casing shoe. ',Circulate casing volume to thin mud and assure floats are cleat 'Continue running 7-5/8" casing to 3500'. Break circulation slowly and reciprocate casing. Bring rate up to 6 BPM !i and circulate bottoms up to thin mud and condition hole. Continue to RIH with 7-5/8" casing to 5920'. 139 joints in hole, 2 joints left to run. Finish running 7-5/8", 29.70#, L80, BTCM Intermediate Casing. MU FMC hanger and landing joint. Ran 141 joints plus a 20' pup joint. Circulate with Frank's fill up tool and reciprocate casing to condition II mud and hole for cementing. 155K Up Wt, 55K Dn Wt, 6 BPM, 400 psi, i LD fill up tool. Load plugs & MU cementing head and lines. Blow down ~,i top drive and circ lines. Resume circulating and recoprocating pipe to thin and condition mud 'and hole for cementing. 170K Up Wt, 55K Dn Wt, 6 BPM, 400 psi to !, 350 psi. Circulated approx. 3 bottoms up. PJSM. Dowell pump 10 Bbls CW-100, tst lines to 3500 psi, pump 20 !, Bbls more CW-100. Mix & pump 10.5 ppg Mud Push II spacer, pumped only 20 Bbls (50 Bbls planned) due to problems getting dry MP II from bulk tank. Drop bottom plug. Mix & pump 169 Bbls of 12.5 ppg DeepCRETE cement, 5.9 BPM, 210 psi. Drop top plug and chase with 20 Bbls water. Switch to rig pump, ',displace with mud at 6 BPM, 100 psi to 600 psi. Bumped plugs at 'calculated displacement. Bumped up to 1250 psi. Bled off & checked ,floats, OK. Reciprocated casing throughout, 185K Up Wt, 45K Dn Wt. RD cement head and casing elevators. LD landing joint. ~' Set FMC pack-off. RILDS. Test pack-off to 5000 psi, 10 min, OK. I RU & perform leak off test down 10-3/4" X 9-5/8" annulus, 12.1 ppg !! EMW. Flush annulus by injecting 65 Bbls water, 2 BPM, 380 psi. Switch to Hot Oil unit and inject 110 Bbls of diesel for freeze protection, ;final pressure 1000 psi at 2 BPM. i Remove casing tools and equipment from rig floor and pipe shed. II Change bails. RU floor to LD 5" DP. Install wear bushing. I! RIH 1 stand at a time & LD 5" DP, 61 STANDS TOTAL. Remove all unnecessary handling tools from rig. PJSM. Slip & cut drilling line. ;RIH 1 stand 5" DP at a time & LDDP. 61 stands DP, 6 stands HWDP. ', PU washing tool & clean out BOP stack @ 6 BPM, 30 psi, 30 RPM. Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 2/5/2006 2/6/2006 2T-203 2T-203 ROT -DRILLING n1433@ppco.com Nordic 3 From - To 'Hours ' Code !, Sub Phase 05:30 - 06:00 !, 0.50 06:00 - 12:00 !~, 6.00 12:00 - 16:00 ',16:00-16:30 ',..,16:30 - 18:00 !,.18:00 - 22:30 ', 22:30 - 00:00 00:00 - 04:30 ! 04:30 - 07:00 107:00 - 07:30 07:30 - 09:00 09:00 - 11:00 111:00 - 11:30 111:30 - 13:30 13:30 - 14:00 1,14:00-14:30 ! 14:30 - 20:00 20:00 - 21:00 !, 21:00 - 22:00 22:00 - 22:30 22:30 - 23:45 ~~ 23:45 - 00:00 , 2/7/2006 1100:00 - 01:00 ~ 01:00 - 02:00 !I 02:00 - 03:30 03:30 - 05:30 ! 05:30 - 06:30 ~' 06:30 - 12:00 12:00 - 00:00 4.00 0.50 1.50 4.50 Code DRILL ~' PULD !! INTRM1 WELCTL!I EORP I INTRM1 WELCTL! BOPE i INTRM1 WELCTL BOPE INTRM1 DRILL ' RIRD I INTRM1 DRILL I PULD I INTRM1 1.501 DRILL 4.501, DRILL 2.501 DRILL 0.50; DRILL 1.501... DRILL 2.00, DRILL 0.501 DRILL 2.00', DRILL 0.50', DRILL 0.50! DRILL 5.50' DRILL 1.00!. CASE 1.00'. CASE 0.50 DRILL 1.25' DRILL 0.25 i, DRILL 1.00', DRILL 1.00'', DRILL 1.50' DRILL 2.00', DRILL 1.00;' DRILL 5.50'' DRILL 12.00!.. DRILL OTHR PULD PULD PULD PULD OTHR PULD TRIP PULD OTHR TRIP CIRC INTRMI INTRM1 INTRM1 I NTRM 1 INTRM1 I NTRM 1 INTRMI INTRM1 I NTRM 1 INTRM1 I NTRM 1 I NTRM 1 DEOT INTRM1 OTHR INTRMI DRLG ~IINTRM1 DRLG (PROD ', DRLG 'CIRC IOTHR 'OTHR FIT DRLG 'DRLG PROD PROD PROD PROD PROD PROD PROD 2/8/2006 00:00 - 11:30 '. 11.50111 DRILL 1 DRLG PROD 11:30 - 12:00 ; 0.50 I DRILL '~, OBSV !,PROD 12:00 - 16:45 4.75 DRILL TRIP !PROD 16:45 - 18:30 !, 1.75 DRILL OTHR 1, PROD 18:30 - 19:00 I 0.50 DRILL PULD !~ PROD 19:00 - 22:15 ! 3.251 DRILL PULD I PROD Start: 1 /21 /2005 Rig Release: 2/25/2006 Rig Number: 3 Page 7 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Description of Operations -- - _ -- __ _____ ~ Pull wear bushing. Drain BOP stack. Set test plug. Change pipe rams from 5" to 4". Clean & inspect all cavities. Remove 7-5/8" rams. Change Pump #1 to !4-1/2" liners, replace seats & valves. Rack & tally 243 joints of 4" DP in pipe shed. Test BOPE to 250 psi & 3000 psi, Accumulator drawdown test, OK. Witnessing of test waived by Lou Grimaldi, AOGCC Field Inspector. 1i Change Pump #2 to 4-1/2" liners, replace seats & valves. Finish ;loading & strapping 4" DP. !.Pull test plug. Set wewar bushing. RD tongs for 5" & RU tongs for 4". Prep floor to PU i;< stand back 4" ' DP. PU 4" DP, spin up & stand back 14 stands. Installed "Super Sliders" on each joint (42). 'Load 5" DC & 4" HWDP into pipe shed. Strap same. PJSM. PU 4" HWDP & 5" DC, MU Super Sliders. Stand back. 1 PU 30 jts DP, stand back & MU Super Sliders. 'Rack & tally 3 jts HWDP, arrange BHA in pipe shed to PU. ~ PU mud motor, 6-3/4" bit, & MWD tools. Upload MWD, shallow test, blow down top drive. PU non-mag flex DCs. Hold PJSM. Load RA sources in MWD tools. 1~ RIH PU 4" DP. Install super sliders as needed. !~, PU & MU Agitator & Shock tool. ' Fill pipe, pulse test MWD, blow down top drive. I Continue RIH to 5919'. 1 Circulate & condition mud for casing test, 4.5 BPM, 970 psi, 103K# Up Wt, 35K# Dn Wt. Test 7-5/8" casing to 3500 psi. Held pressure for 30 minutes, no loss. ! RD test equipment. Blow down choke & kill lines. ;Tag plugs @ 5953'. Drill out plugs, float collar, cement, and float shoe ~I at 6046'. Clean out rat hole to 6062' MD. Drill new 6-3/4" hole to 6069' MD, & drilling ahead. 103K# Up Wt, 35K# Dn Wt, 57 K# Rot Wt. 7600 ft-Ib Torque on btm, 5675 ft-Ib Torque off btm. 95 SPM, 188 gpm, 1430 psi. Drill 20' of new hole to 6082' MD, 3103' TVD. CBU 100 spm, 1,300 psi. 1 Displace well to 8.9 ppg Flo-Pro at 100 spm, 1,300 psi. Clean shakers, surface lines and pits for Flo-Pro. Circ and cond mud and obtain clean hole ECD, perform dynamic FIT. Directionally drill 6 3/4" production hole from 6,082' to 6,305'. Cont directional drilling 6 3/4" hole from 6,305' to 6,668' MD/ 3,119' ~~ TVD, AST 8.16 hrs, ART 1.72 hrs, ADT 9.88 hrs, torque on bolt 6,310 ~ ft/Ibs, torque off bolt 5,940 ft/Ibs, up wt 85K, dwn wt 50K, rot wt 63K, 1 ECD's at 10.6 Cont directional drilling 6 3/4" hole from 6,668' to 6,762' MD/ 3,116' ~~ TVD (94'), up wt 130K, dwn wt 27K, rot wt 65K, torque on bott 6,800 '' ft/Ibs, torque off bolt 6,600 ft/Ibs, ART 4.14 hrs, AST 6.14 hrs, ADT !.10.28 hrs, 107 spm at 1,700 psi, 210 gpm's. ROP reduced to near zero. ~ Blow dwn Top Drive and monitor well ! POOH from 6,762' to 108'. i PJSM, remove nuke sources and dwn load MWD. UD 6 3/4" bit and motor. Check corrosion ring, retrieve float from MWD pin end, C/O seal Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Contractor Name: n1433@ppco.com Rig Name: Nordic 3 Date From - To ', Hours ' Code '~ Sub '1 Phase 'Code, 2/8/2006 !~ 19:00 - 22:15 I 3.251 DRILL PULD PROD 22:15 - 00:00 1 1.75 !, DRILL OTHR PROD 2/9/2006 j 00:00 - 01:30 ' 1.50 ~ DRILL ;.01:30 - 02:00 j 0.50'1 DRILL 02:00 - 03:00 ! 1.00 DRILL ! 03:00 - 05:00 ', 2.00 i DRILL ! 05:00 - 12:00 ''i II 1 7.00 DRILL II , 12:00 - 21:30 I 9.50 ~, DRILL 21:30 - 22:45 1.251, DRILL 22:45 - 00:00 1.25'.: DRILL '1 2!10/2006 !, 00:00 - 00:30 '~, I 00:30 - 01:00 !~ 01:00 - 05:00 ~, i 05:00 - 05:30 ', 05:30 - 07:30 '! ! 07:30 - 08:00 08:00 - 09:30 09:30 - 10:30 10:30 - 14:15 ', ',14:15 - 14:30 14:30 - 16:15 16:15 - 16:45 16:45 - 17:15 17:15 - 17:45 17:45 - 19:45 19:45 - 20:00 TRIP PROD OTHRIPROD TRIP PROD REAM PROD DRLG PROD it DRLG !,PROD CIRC PROD DRLG PROD 0.50 i DRILL ,DRLG 0.50 DRILL ',CIRC 4.00' DRILL OBSV 0.50'x, DRILL ;CIRC 2.00!, DRILL ',OBSV 0.50!1 DRILL DRLG 1.501 DRILL 'OBSV 1.001 DRILL 3.751 DRILL 0.251 DRILL 1.751'~~ DRILL 0.501, DRILL 0.50', DRILL 0.50 ~ DRILL CIRC PROD PROD PROD PROD PROD PROD PROD PROD OBSV PROD CIRC ', PROD OBSV 'PROD CIRC 'PROD OBSV ', PROD CIRC 'PROD 2.00 DRILL OBSV ' PROD 0.25' DRILL CIRC I PROD Start: 1 /21 /2005 Rig Release: 2/25/2006 Rig Number: 3 Page 8 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Description of Operations li rubbers on float, P/U and M/U new 6 3/4" PDC bit and mud motor. Up-load MWD, perform shallow test on MWD, PJSM and load nuke sources, blow dwn Top Drive. ~I RIH with BHA #5 to 3,550'. II R/U and fill pipe, service Top Drive. i Cont RIH with BHA #5 and took weight at 6,307. Kelly up and wash/ream from 6,307' to 6,764', up wt 120K, dwn wt 55K, 1~ rot wt 60K, torque at 6,400 fUlbs, 100 spm with 1,460 psi, 60 rpm. Cont directinal drilling 6 3/4" hole from 6,764' MD to 7,088' MD/ 3,116' TVD (324'), up wt 130K, dwn wt 30K, rot wt 70K, 65 rpm, torque on btm '; 7,300 fUlbs, torque off btm 7,300 fUlbs, 100 spm at 1,450 psi, 200 gpm, mud wt 8.9+ FLo-Pro with 59 vis, ECD at 10.6, 56.35 hrs on jars, ART ',1.38 hrs, AST 4.37 hrs, ADT 5.75 hrs. Cont directional drilling from 7,088' MD to 7,480' MD/ 3,103' TVD (392') and had sudden fluid loss (60 bph). PU off btm and reduced pump rate to 2 bpm while rot and recip, mixed ', 40 bbl SafeCarb LCM pill (.5 ppb Flo-Vis Plus, 5 ppb SafeCarb 2Q, 20 ppg SafeCarb 250), pumped pill at 100 spm, 1,400 psi and got full 'returns. Cont directional drilling from 7,480' MD to 7,516' MD/ 3,101' TVD (36'), ', up wt 155K, dwn wt 30K, rot wt 80K, 65 rpm, torque on btm 9,190 ft/Ibs, !torque off btm, 7,480 ftllbs, 100 spm at 1,550 psi, 200 gpm, mud wt 1, 8.9+ Flo-Pro with 58 vis, ECD at 10.9, 63.32 hrs on jars, ART 2.23 hrs, AST 4.74 hrs, ADT 6.97 hrs. ~I Cont directional drilling 6 3/4" hole from 7,516' MD to 7,518' MD/ 3,101' ~'~ ND and lost all returns. 1 Pump and spot 40 bbl SafeCarb pill from 6,299' to 7,518', 100 spm, 1,450 psi with little or no returns. ~I Monitor fluid loss on trip tank while waiting on mud delivery. Static loss II at 12.5 bph. !Pump and spot 40 bbl SafeCarb pill from 6,299' to 7,518', 100 spm, 1,450 psi with little or no returns. ~', Monitor fluid loss on trip tank. Static loss at 10 bph. Drill (rotate) from 7,518' to 7,520' with significant fluid loss. Monitor fluid loss on trip tank and mix 100 bbl SafeCarb pill. Static loss it at 6 bph. ~~ Pump and spot 100 bbl SafeCarb pill at 85 spm, 1,350 psi with little or 1 no returns. 'Monitor fluid loss on trip tank. Static loss at 14.5 bph. Circ 444 stks at 85 spm, 1,180 psi and move pill up hole, with little or no returns. ',Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss at 8.5 bph. ':Circ 400 stks (20 bbls) at 85 spm, 1,180 psi with little or no returns. Field in phase 2 weather cond. Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss at 2 bph. Pump and spot 35 bbl SafeCarb pill at 85 spm, 1,140 psi with little or no `returns. ', Blow dwn Top Drive and cont monitor fluid loss on trip tank. Static loss 1 at 5.5 bph. Circ 400 stks (20 bbls) at 85 spm, 1,110 psi, to move pill up into 7 5/8" casing shoe, with little or no returns. Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Contractor Name: n1433@ppco.com Rig Name: Nordic 3 Date From - To Hours ! Code 'Sub Code _ 2/10/2006 l 20:00 - 22:45 - ------ ~, 2 75 , DRILL OBSV 22:45 - 23:15 !, ~I 0.5011 DRILL !CIRC 2/11 /2006 23:15 - 00:00 0.75 ~1 DRILL I OBSV 00:00 - 01:00 01:00 - 01:15 01:15 - 03:15 03:15 - 03:45 03:45 - 05:45 05:45 - 06:00 1.00 0.25 2.00 0.50 2.00 0.25 DRILL DRILL DRILL DRILL DRILL DRILL DRILL OBSV CIRC 06:00 - 09:30 ', 3.50 ', 09:30 - 10:30 ; 1.00'x, DRILL '10:30-11:00'. 11:00 - 12:15 12:15 - 17:45 17:45 - 18:30 18:30 - 22:30 ', 22:30 - 22:45 ! 22:45 - 23:45 1.23:45 - 00:00 0.50'',- DRILL 1.25'1 DRILL Start: 1 /21 /2005 Rig Release: 2/25/2006 Rig Number: 3 Page 9 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Phase ! Description of Operations PROD ~i, Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss ~! at 8 bph. PROD ~!, Pump and spot 35 bbl SafeCarb 500 pill at 85 spm, 1,140 psi. (45 ppb !~ safecarb 500, 3 ppb safecarb 250, 21 ppb safecarb 40, .5 ppb FloVis and whole mud) !, PROD ~~ Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss !~ ' at 1 bph, up wt 165K, dwn wt 35K, rot wt 80K, off btm torque 7,400 ', ' ft/Ibs, hrs on jars 63.98. Total fluid lost at 23:59 hrs = 895 bbls for last ', 24 hrs. PROD Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss at 1 bph. PROD Circ 400 stks (20 bbls) at 85 spm, 1,110 psi, to move pill up into 7 5/8" 'casing shoe, with little or no returns. OBSV '...PROD ', Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss ' at 7 bph. CIRC '' PROD 'Pump and spot 35 bbl SafeCarb 500 pill at 85 spm, 1,140 psi with little OBSV CIRC TRIP CIRC TRIP CIRC 5.50' DRILL OBSV 0.75' DRILL 'CIRC ', ', or no returns. !1 PROD '! Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss I at 1 bph. ~', PROD I Circ 400 stks (20 bbls) at 85 spm, 1,110 psi, to move pill up into 7 5/8" casing shoe, with little or no returns. ~ PROD I, POOH 30 studs, wet on elevators from 7,510' to 4,691'. First 5 studs ', !,tight and had no hole fill. Hole fill within .5 bbl after 20 studs. Up wt 170 - 200K, dwn wt 25 - 30K. III PROD Break circ and attempt to recover returns. Staged pump as follows: 1 11 bpm w/ no returns, 2 bpm w/ no returns, 4.7 bpm w/ 12 pct returns, 198 gpm. PROD RIH to shoe from 4,691' to 6,046', up wt 105K, dwn wt 38K. PROD Mix, pump and spot 70 bbl SafeCarb 500 pill at 100 spm, 1,450 psi with little or no returns. PROD Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss ~ at 7 bph. 1 PROD I Mix, pump and spot 70 bbl SafeCarb 1000 pill at 85 spm, 1,140 psi with little or no returns. 4.00 ~! DRILL ' OBSV PROD ,Blow dwn Top Drive and cunt monitor fluid loss on trip tank. Static loss I at 3 bph. 0.25' DRILL TRIP PROD ', POOH 5 studs to 5,547, up wt 105K, dwn wt 40K, rot wt 62K. 1.00'. DRILL 'CIRC Il PROD !Mix, pump and spot 50 bbl SafeCarb 1000 pill at 85 spm, 1,140 psi with ! ~, little or no returns. 0.25 !, DRILL OBSV I PROD ~I Blow dwn Top Drive and cunt monitor fluid loss on trip tank. No static ! ',loss. Fluid lost at 23:59 hrs = 590 bbls, total lost 1,485 bbls. 0.50'', DRILL ' OBSV ~~, PROD ! Cont monitor fluid loss on trip tank, with no static loss. 4.00! DRILL (TRIP I PROD 'POOH from 5,547. 0.50', DRILL ~, OTHR 'PROD !, PJSM, dwn load nuke sources. 1.501 DRILL ', OTHR !PROD .Down load MWD. 2.00 DRILL ' PULD PROD LD BHA #5. 1.50 DRILL I TRIP PROD PU BHA #6 (clean out assem) and RIH to 3,039'. 1.001 DRILL ~, CIRC ,PROD CBU at 50 spm, 2.3 bpm, 170 psi, 6% return on flowline, loosing 1 bpm, 1 ' ' stage pump up to 70 spm 3.3 bpm, 200 psi, 17% returns at flow line, loosing 7 bpm. Lost 25 bbls during this circ. 1.501 DRILL TRIP PROD RIH from 3,039' to 5,511', up wt 95K, dwn wt 38K. 1.00 1 DRILL CIRC ', PROD !, Break circ stage pump to 70 spm, 3.3 bpm at 320 psi, loosing 2.2 bpm, ! ', 7% returns at flow line. ': 2/12/2006 00:00-00:30 00:30 - 04:30 04:30 - 05:00 ~I 05:00 - 06:30 106:30 - 08:30 108:30 - 10:00 10:00 - 11:00 11:00 - 12:30 12:30 - 13:30 Printed: 4/11/2006 2:45:58 PM ConocoPhiilips Alaska 0.50'',. DRILL 1.25! DRILL 0.75! DRILL 6.00 I DRILL Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Contractor Name: n1433@ppco.com Rig Name: Nordic 3 Date From - To 'Hours 'I Code Sub .Code 2/12/2006 ~ 13:30 - 15:30 2.00 ~''~ DRILL ~I OBSV '15:30-16:00 ',16:00-17:15', :17:15 - 18:00 '18:00-00:00 2/13/2006 ' 00:00 - 00:30 00:30 - 02:00 i II 02:00 - 02:30 I, ~!~ 02:30 - 03:00 03:00 - 11:00 11:00 - 11:30 11:30 - 15:30 X15:30-17:30 ~~ 17:30 - 19:30 I 119:30 - 20:00 20:00 - 23:30 0.50 1.50 0.50 0.50 8.00 0.50 4.00 2.00 2.00 DRILL DRILL Start: 1 /21 /2005 Rig Release: 2/25/2006 Rig Number: 3 Phase Page 10 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Description of Operations PROD Blow dwn Top Drive and monitor fluid loss on trip tank, mix SafeCarb ', 1000 LCM pill, (87 ppb SafeCarb 1000, 15 ppb SafeCarb 500, 3 ppb !SafeCarb 250, 45 ppb S200, 4 ppb DuoFlo). I~ TRIP I PROD ', Cont RIH from 5,511' to 6,045' (7 5/8" shoe depth). ',CIRC PROD 'Pump and spot 35 bbl SafeCarb 1000 pill at 3 bpm, 240 psi. ',TRIP PROD !Blow dwn Top Drive and POOH from 6,045' to 5,597. ', OBSV ;PROD ', Blow dwn Top Drive and cunt monitor fluid loss on trip tank. No static ', loss. Fluid lost at 23:59 hrs = 47 bbls, total lost 1,532 bbls. OBSV j PROD ~ Cont monitor fluid loss on trip tank, loosing 3.5 bph. CIRC I, PROD CBU, staging pump from 1 1/2 to 2 1/2 bpm, return mud temp 34 deg, DRILL ' OBSV DRILL TRIP DRILL j REAM DRILL I DRLH DRILL CIRC DRILL I CIRC DRILL (TRIP 0.50 DRILL ~ CIRC 3.50' DRILL ! OTHR 23:30 - 00:00 ' 0.50' DRILL TRIP 2/14/2006 (00:00 - 01:15 01:15 - 02:00 02:00 - 03:30 03:30 - 04:00 04:00 - 09:30 09:30 - 09:45 09:45 - 17:00 17:00 - 19:00 19:00 - 00:00 2/15/2006 ',.00:00 - 00:15 ...00:15 - 01:45 01:45 - 02:45 02:45 - 10:00 I, ~I ~I 10:00 - 10:30 I~ 1.25 0.75 1.50 0.50 5.50 0.25 7.25 2.00 5.00 Operations Summary Report ~ 270 to 330 psi, lost 75 bbls during circ. PROD Blow dwn Top Drive and monitor well. PROD Cont RIH from 5,597' to 6,269' on elevators, dwn wt 20-25K. PROD Kelly up and wash/ream dwn to 7,520', staged pump to 70 spm, 560 psi, 82 rpm, 20% return flow rate, mud wt out 9.1 ppg. PROD Drill ahead from 7,520' MD to 7,525 MD/ 3,104' TVD. Iii PROD Rot and recip at 1 bpm, and mix 130 bbls SafeCarb LCM pill. Loosing 1 ~', bpm during circ. !PROD ~ Pump and spot SafeCarb pill at 2 bpm, 340 psi. PROD 'Blow dwn Top Drive and POOH from 7,525' to 5,987, rotating from 7,495' up to 6,380' with no pump. PROD ' Circ at 3 bpm with little or no returns. PROD ',Clean trip tank, off load FloPro mud, flush surface equipment, off load ', magnets, scrapers, brushes, fill trip tank with 9.1 filtered brine. Cont fill '~ tank farm with 9.1 brine at 3.5 - 6.4 NTU's. 'i PROD ', Cont POOH from 5,987 to 4,595' with BHA #6 while cleaning pits. ~ ',Total fluid lost 2,044 bbls. DRILL TRIP j PROD; Cont POOH from 4,995' to 3,500' with BHA #6 while cleaning pits i Began filling hole with 9.1 ppg brine. DRILL ', OBSV PROD t Monitor well on trip tank while off loading magnets, scrapers and ~ ~ brushes. ave 15 BPH losses DRILL ! TRIP PROD Cont POOH from 3,500' to BHA. DRILL I PULD !i PROD LD BHA #6. CMPLTNI OTHR I CMPLTN RD handling equipment, c/o bails, RU Doyon compensator equipment, I ' off load Sperry tools, RU to run screens. ' SFTY ..CMPLTN CMPLTN , Held PJSM with Baker Rep, Doyon casing and rig crew on running of 4 1/2" chrome screens CMPLTNI SCRN CMPLTN ~', PU and RIH with 4.5" chrome screens per well plan to 1,875'. Ran 30 'chrome screens and 8 blank jts CMPLTNI RURD ',CMPLTN ! RD compensator equipment, RU 2 7/8" handling equipment. CMPLTNI RUNT CMPLTN PU and RIH with 2 7/8" inner string, up wt 58K, dwn wt 55K. Fluid lost in ~' , 'last 24 hrs = 540 bbls, Total fluid lost 2,584 bbls. (ave 22.5 BPH last 24 0.25 CMPLTN':. SCRN I CMPLTN hrs) ', MU Baker SC-1 R packer assembly with KOIV valve and RIH from ',1,875' to 1,912', st wt up 58K, do wt 55K 1.50 (CMPLTNI RURD CMPLTN ' RD liner and inner string handling tools and RU for 4" DP 1.00 ~ CMPLTN OTHR CMPLTN !RIH with screens with 1 std of 4" DP from 1,912' to 2,000', est circ at 2 I bpm at 80 psi, rotated screens at 20 rpm's at 1,100 ft-Ibs torgue, st wt ~ 7.251 CMPLTN SCRN ;~ CMPLTN up 62K, do wt 55K RIH with 4 1/2" chrome screen assembly from 2,000' to 5,900', to just '~ ~, above 7 5/8" csg shoe at 6,046', had to work DP and screens down due 1 to hole drag, hole losses ave 70 BPH of 9.1 ppg brine 0.50 ', CMPLTNI OTHR ,CMPLTN '~ Filled pipe at 5,900', circ at 2 bpm at 80 psi, rotated screens at 28 Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Start: 1/21/2005 Contractor Name: n1433@ppco.com Rig Release: 2/25/2006 Rig Name: Nordic 3 Rig Number: 3 Date From - To 'Hours ! Code !Code Phase 2/15/2006 10:00 - 10:30 .10:30 - 12:45 i 12:45-15:00'.. ' 15:00 - 18:00 I, 118:00 - 19:30 II li IIII ~, I ~! 19:30 - 00:00 I 2/16/2006 !i 00:00 - 00:30 !' ~I I'! 00:30 - 03:30 i~ Ili 03:30 - 03:45 II ', 03:45 - 05:30 'I ' 05:30 - 06:00 'I 06:00 - 07:30 ' 07:30 - 08:00 0.50 CMPLTN OTHR CMPLTN 2.25 CMPLTNI SCRN !,I CMPLTN iI it 2.251 CMPLTN SCRN CMPLTN 3.00 CMPLTNI OTHR I CMPLTN ,. 1.50 'I CMPLTN.' CIRC I CMPLTN 4.50 CMPLTNI SCRN CMPLTN 0.50 CMPLTN SCRN 3.00', CMPLTNI CIRC I 0.251 CMPLTNI OBSV 1.75 ! CMPLTNI PCKR 0.50 CMPLTNI DEOT i 1.50' CMPLTNI' RURD 0.50' CMPLTNI CIRC 08:00 - 12:30 ~~, ! 4.50 ~ 12:30 - 13:30 ~!, 1.00 13:30 - 14:30 '', 1.00 14:30 - 18:30 I 4.00 CMPLTNI OBSV ~~ CMPLTN OBSV CMPLTN% CIRC I CMPLTN OBSV CMPLTN CMPLTN I CMPLTN !I CMPLTN CMPLTN 'CMPLTN 'CMPLTN CMPLTN CMPLTN !I CMPLTN CMPLTN Page 11 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Description of Operations !I RPM's with 6,800 ft-Ibs torque, st wt up 148K, do wt 59K ' RIH with screens from 5,900', had to work thru tight spot between i 6,150' to 6,220', string plugged temporarily then came unplugged and I was able to cont RIH circ stand down at 1 bpm when screens stopped again at 6,520' !Was able to work screens up hole from 6,520' to 6,440', stood back 1 !std, still was not able to go down 'Monitored well while building hi vis sweep in mud pits, while static hole ave 20 bph losses, slowly worked pipe out of hole from 6,440' to 6,400' ', Pumped 100 bbl, 49 vis, 19 YP, 8.9 ppg hi vis brine pill with flo-vis and ;followed with viscosified brine at 6,400', staged pump rate up to 3 bpm II at 300 psi and had 85-90% returns, increased to 4 bpm at 460 psi and !, ave 70% returns, slowed rate back to 3 bpm at 300 psi, with sweep back at surface early, had no increase in cuttings IlAfter circ sweep around at 6,400' attempted to either POOH or RIH with screens and DP with no success, tried with pump on or off and I would not go, est. rotation at 16 rpm's at 8,800 ft-Ibs of torque and was able to work screens down, appears to be friction holding screens, after i starting rotation at 13-18 rpm's would work pipe down +/- 3' then lock in torque and cont RIH with DP and screens, would pump at 7 spm., 14 gpm at 140 psi with full returns, RIH to 7,297, up wt 150K, dwn wt 40K, rot wt 80K, had to work through tight spot at 7,011'. Fluid lost in last 24 hrs = 1,116 bbls, Total fluid lost 3,700 bbls. ', Cont RIH with 4 1/2" chrome screen assembly from 7,297 to 7,484', !! circ at 7 spm, 110 psi, 6-10 rpm to break screens free, then washing 'down with no rotation. Circ btms up at 7,484', staged pump up to 3 bpm, 320 psi, pumped 571 bbls 8.6 brine and had 350 bbls back in returns, 8.9+ brine wt out II with good amount Calcium Carb at btms up, circ till 8.6 brine in and out Monitored well on trip tank, RU circ lines and chart to set SC-1 R j Packer, losses ave 69 bph. Dropped 1 7/16" ball and pumped ball down at 1 bpm and seat, set II SC-1 R Packer as per BOT at 5,582'.sheared out at 2,950 psi ~!, RU and tested packer & 7 5/8" annulus to 3,000 psi for 15 min on chart. ! Test OK. RU Dowell and pump in sub, Held PJSM on pumping MudSoly Pressure tested lines to 3,500 psi, then Pulled up to 1st circ position at 7,454' and pumped 86 bbls 9.3 ppg MudSOLV, ave 7 bpm, 1,300 psi .with .7 bpm returns, with 72 bbls away slowed pump rate to 5 bpm at 710 psi. Increased pump rate to 7 bpm, 1,310 psi for the 69 bbl 8.6 ppg ',brine displacement. Set down 6' to the "safe position" at 7,460', down wt 30-35K. ! Monitor well in "safe position" and allow MudSOLV to soak, PJSM on 112nd pill. i! Pull up to 5,986' "upper safe position" and monitor well on trip tank, average loss at 180 bph. i MU circ head, pull up to "upper circ position" at 6,040' and start 2nd !Ii MudSOLV pill at 3 bpm, 150 psi, at 50 bbls away increased pump rate Ito 3.5 bpm 220 psi with no returns. Pumped 83 bbls of 9.3 ppg ', MudSoly pill followed with 50 bbls 8.5 brine at 4 bpm at 330 psi, pulled '! up to "upper safe position" at 5,986'. ', Monitored well allowing MudSOLV to soak, well-static, prep pipe shed ! to LD DP Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Page 12 of 15 Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Spud Date: 1/19/2006 Event Name: ROT -DRILLING Start: 1/21/2005 End: 2/25/2006 Contractor Name: n1433@ppco.com Rig Release: 2/25/2006 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To 'Hours Code 'Sub ,Phase Description of Operations 2/16/2006 18:30 - 19:15 19:15 - 19:30 ' 19:30 - 00:00 ' 2/17/2006 100:00 - 01:00 'I 01:00 - 01:30 01:30 - 04:00 04:00 - 04:45 04:45 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 10:15 10:15 - 11:30 1 11:30 - 13:30 !i 13:30 - 20:30 I 20:30 - 21:00 ', ~~ 21:00 - 22:00 it 22:00 - 23:30 23:30 - 00:00 2/18/2006 ', 00:00 - 01:15 101:15 - 02:00 02:00 - 05:00 105:00 - 05:30 105:30 - 07:30 07:30 - 07:45 it 07:45 - 11:30 ~1 111:30-13:00 13:00 - 20:00 120:00 - 20:45 120:45 - 23:00 23:00 - 00:00 Code 0.75' CMPLTN'!.OTHR 'CMPLTN 1 RIH from 5,986' to 6,046' and LD head pin, monitored losses and ave was 180 bph, POOH to 5,672' and allowed fluid level to drop in annulus 870' (25 bbls)(8 min) per AOGCC approval, cunt to pull inner string up ' !I through KOIV at 5,600'. 0.25'x, CMPLTN OBSV ,CMPLTN Monitor well for fluid loss. KOIV holding, no static loss. 4.50', CMPLTN!, PULD ',CMPLTN POOH from 5,600' LD DC's, HWDP and DP, removing "Super Sliders", ', I~ Ito 2,424'. Fluid lost in last 24 hrs = 1,165 bbls, Total fluid lost 4,865 1.00 !, CMPLTNI' PULD I CMPLTN bbls. ;POOH LD 4" DP from 2,424' to packer running tool and 2 7/8" inner 0.5011 CMPLTNI PULD CMPLTN ,string at 1,886' !, RU and LD packer running tool 2.501 CMPLTN PULD CMPLTN ~ 'POOH from 1,875' LD 2 7/8" 511 Hydril wash string 0.75'1 CMPLTN RURD CMPLTN ', RD 2 7/8" handling tools and unloaded 2 7/8" tbg from pipe shed 2.251, CMPLTN TRIP CMPLTN ', RIH with 4" DP to 2,418', removed supper slidders while RIH 1.00 CMPLTN PULD CMPLTN POOH from 2,415' to 745' LD 54 jts of 4" DP, unloaded pipe shed 0.501; CMPLTN TRIP CMPLTN 'RIH from 745' with 14 stds DP from derrick to 2,975' 1.751 CMPLTN PULD 1 CMPLTN 'POOH from 2,975' LD remaining DP and 14 stds of Hybrid push pipe 1 I with HWDP and DC's " ' ' " 1.25 CMPLTN OTHR II CMPLTN s from pipe shed and RU to run 4 1/2 DP, HWDP and DC Unloaded 4 1 tbg 2.00 ~~, RIGMNT RSRV ~, CMPLTN ',Slip and cut 55' of drilling line and checked crown o-matic 7.00' CMPLTN PULD j CMPLTN I PU and RIH with 4 1/2", 12.6#, L-80 IBTM tbg to 4,342'. 0.50', CMPLTN RURD ;CMPLTN ~!, C/O handling equipment, RU to run Dp from derrick. 1.00', CMPLTN TRIP ~ CMPLTN ~~ Cont RIH from 4,342' with 12 stnds DP from derrick to 5,475', removed ~~ Super Sliders while RIH. 1.50''.. CMPLTNI CIRC ',CMPLTN 1, RU and pump 225 bbls 8.6 brine with 1 % corrosion inhibitor at 5,475', I~ staging pump rate up from 1 bpm to 4 bpm at 120 psi. 0.50 CMPLTN RURD CMPLTN II RD circ lines, prep to POOH LD 4" DP. 1.25 CMPLTNI PULD CMPLTN 1, POOH from 5,475' to 4,342' LD 36 jts of 4" XT-39 DP 0.75 CMPLTNI RURD ;CMPLTN '~, Changed out handling tools from 4" DP to 4 1!2" tbg, unloaded 4" DP II and super sliders from pipe shed. 3.00 ,CMPLTN. TRIP CMPLTN I POOH from 4,342' LD 3 jts of 4 1/2" tbg, then POOH standing back 46 stds for ESP completion 0.50 ~ CMPLTN PULD CMPLTN ' ~ Pulled wear bushing 2.00' CMPLTNI. RURD ,CMPLTN ~ RU to run ESP completion, hung scheave and strung ESP cable, RU Centrilift's equip. 0.251 CMPLTN', SFTY ~ CMPLTN I Held PJSM with Centrilift rep and rig crew on running of 4 1/2" ESP ', completion 3.751, CMPLTNI RUNT I CMPLTN ~ 11 PU MU motor, intake and pump with discharge head and RIH to 75', !~ , 1 ~ Install ESP power cable on pump assembly, Meger test ESP cable (test '~, ~ ~ I ok) and installed Cannon Clamps 1.50 1 CMPLTN RUNT CMPLTN MU 3 1/2" pup jt and XO to 4 1/2" tbg RIH to 85' then installed Guardian I ~ Gauge, spliced TEC wire and tested same. ' 7.00 CMPLTN] RUNT CMPLTN , RIH with ESP completion on 4 1/2" tbg to 4,589', RIH with 143 jts & 2 'I ' pup jts (4,439') of 4 1/2", 12.6 ppf, L-80 IBTM tbg with CMU sliding 11 '1 sleeve, (closed) with 2-GLM's both with 1"with dummy valves, Total ', I I :tubing and completion equip. RIH 4,588.63'. Used 76- 6.75" Cannon 1 'clamps, 4-5.875" Protectolizer clamps, 2-5.625" Flat guards and 4-Flat stainless steel bands., ave tbg MU was 3,500 ft-Ibs 0.751, CMPLTN OTHR CMPLTN MU 11" x 4.5" Horizontal Hanger. 2.25. CMPLTN OTHR I CMPLTN Install penetrators and splice/connect ESP cable. I 1.00 !CMPLTN SOHO ~~ CMPLTN ~, Attempt to land hanger 3 times. Hanger not landing landing out, landing I ', 2" short, trouble shooting problem, st wt up 90K, do wt 38K, checked Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2T-203 2T-203 ROT -DRILLING n1433@ppco.com Nordic 3 Date From - To ', Hours ' Code Sub ''Code 2/18/2006 23:00 - 00:00 1.00 CMPLTN'' SOHO 2/19/2006 ', 00:00 - 01:00 , 1.00 CMPLTN',, RUNT I I VIII 01:00 - 03:00 II 2.00 CMPLTNI RUNT 103:00 - 10:30 I I I 7.50 ~i, CMPLTNII OTHR ~I 10:30 - 12:00 ! 1.50 112:00 - 22:00 ' 10.00 22:00 - 00:00 ' 2.00 2/20/2006 ' 00:00 - 01:30 I 1.50 101:30 - 07:00 I 5.50 07:00 - 09:30 09:30 - 11:30 11:30 - 12:00 12:00 - 13:00 13:00 - 16:30 16:30 - 17:00 17:00 - 20:00 2.50 2.00 0.50 1.00 3.50 CMPLTNI. RURD CMPLTN' TRIP CMPLTNI PULD CMPLTNI PULD WELCTIJ BOPE CMPLTNI, OTHR i CMPLTNI OTHR CMPLTNI PULD CMPLTNII PULD CMPLTN', TRIP 0.50 CMPLTNI. CIRC 3.00 CMPLTN! CIRC Page 13 of 15 Spud Date: 1/19/2006 Start: 1/21/2005 End: 2/25/2006 Rig Release: 2/25/2006 Group: Rig Number: 3 Phase ' Description of Operations CMPLTN I continuity on ESP & I-wire and ck'd ok CMPLTN ', Cont to attempt to land hanger, on 4th try still landed 2" short of being 'fully landed in the hanger, PU to hanger and checked I-wire & ESP continuity and ck ok, st wt up 90K, do wt 38k CMPLTN 'Pulled TWC and RIH for 5th try when tbg stopped 10' above hanger, PU hanger to rotary table to 4,620 and had 30K add up wt 120K, 're-checked ESP continuity and ck ok and I-wire did not test. CMPLTN ', Pulled tbg hanger to above rotary table, pulled 140K over when I-wire II broke off from penetrator, installed BPV and began to work pipe, '~ worked st wt up to 225K and down to 25K with no movement, II discussed options with town. Clamped ESP cable 6' below hanger for I, future use as pigtail then cut off wire and removed penetrators on I hanger, broke out hanger off of full jt and LD same with landing jt. MU 4 1/2" IBTM coupling with XO's back to 4" XT-39 DP. Cont to work tbg up to 225K and down to 25K with no movement, rotated tbg at 1/4 I increments while working pipe and after 1 1/4 turns saw no change, filled stack and est circ down the tbg at 3/4 bpm at 70 psi and after pumping 2-3 bbls of 8.6 ppg brine and after working string wt up to 200K, tbg began to move up hole, after pulling 30' jt to table, st wt up was down to the original up wt of 90K when attempting to land hanger. CMPLTN LD top jt of 3 1/2" tbg and RU scheaves to POOH with ESP completion CMPLTN Began to POOH with 4 1/2" completion, would pull up approx 20' and would have 180K up wt drag, then would est circ and tbg would pull free, POOH pumping from 4,587' to 4,480' LD 2-pup jts and 2-single jts li PU while RIH with completion. Cont to POOH and up wt was at 83K and was able to begin standing back tbg in stds. After pulling 1 std and li a double had approx 20' of I-wire balled up at surface, (would put that approx 260' from surface), cont to POOH with ESP comp spooling up it ESP & I-wire, recovered all 76 clamps, 4 Pro gaurds, 2 Flat gaurds, li and 9 steel bands, ESP cable and I wire. CMPLTN ', Removed Gaurdian Gauge, electrical test of pump OK, could not rotate I pump manually, intake port full of Calcium Carb, Monel Coating 'damage on motor section, LD pump assembly. CMPLTN '', Fin LD ESP pump assembly and cleared rig floor. CMPLTN ' PJSM, RU and test BOPE, tested rams, valves and manifold to 250 psi low and 3,000 high. Note Chuck Scheve W / AOGCC waived witnessing of test. Accumulator system before 2,800 psi, after functioning rams '.1,900 psi, 23 seconds to 200 psi, 1 min 25 sec back to full pressure CMPLTN 'Removed ESP pump equipment from pipe shed and loaded 30 jts of 4" I DP into pipe shed and strapped same. CMPLTN MU FMC tbg hanger onto new full jt of 4 1/2" tbg then made dummy run Iwith same and checked ok, LD same. CMPLTN I, Installed wear bushing. CMPLTN ', MU clean out BHA with 2 7/8" x 14' mule shoe, XO's and 7 5/8" csg ~ scraper RIH to 22'. CMPLTN '~ RIH with clean out assembly from 22', PU 14 jts of 4 1/2" tbg and cont Ito RIH with tbg out of derrick, RIH and set 20K wt down at 4,480', st wt III up 67K, do wt 40K, changed over handling tools to 4" DP. CMPLTN II Est circ and washed down thru spot at 4,480' to 4,510', cont to RIH and I sat down at 4,540' circ and washed down to 4,570'. CMPLTN Circ hole clean at 4,570', pumped hi vis sweep and circ hole staging pump rate to 6 bpm at 130 psi, had a large amount of calcium carbonate back at btms up, cont to circ hole clean while using a crane Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Start: 1/21/2005 Contractor Name: n1433@ppco.com Rig Release: 2/25/2006 Rig Name: Nordic 3 Rig Number: 3 Date From - To 'Hours Code 'Sub Phase wue - 2/20/2006 17:00 - 20:00 3.00 CMPLTNI CIRC CMPLTN 20:00 - 21:30 i 1.50 CMPLTNI CIRC I CMPLTN 21:30 - 23:00 I, 1.50 CMPLTNI, CIRC CMPLTN 23:00 - 00:00 1.00 i CMPLTNI CIRC li CMPLTN 1 2/21/2006 00:00 - 01:30 ' 1.50 CMPLTN! CIRC I CMPLTN 01:30 - 02:00 ', 0.5011 CMPLTN:, CIRC ~I CMPLTN i 02:00 - 04:00 ', 2.00 I CMPLTN' CIRC ',CMPLTN 04:00 - 05:15 ', ', 1.2511 CMPLTNI. CIRC 1 ,'CMPLTN 05:15 - 05:30 0.251 CMPLTN OBSV CMPLTN 05:30 - 06:30 ', 1.00 ~ CMPLTN', PULD ',,CMPLTN 06:30 - 07:15 0.751 CMPLTN! RURD ';CMPLTN III 07:15 - 09:15 ' 1 2.00'1 CMPLTN TRIP ', CMPLTN 09:15 - 00:00 ', 14.751 WAITON! WOW CMPLTN 2/22/2006 00:00 - 20:00 ', 20.00 I WAITON' WOW ;CMPLTN 20:00 - 22:30 ~! 2.5011 CMPLTN-.TRIP '!,CMPLTN 22:30 - 23:30 1.001~i CMPLTN, PULD 'CMPLTN 23:30 - 00:00 0.501 CMPLTN!. PULD 'CMPLTN 2/23/2006 ~ 00:00 - 09:00 ' 9.00 ICI CMPLTN; OTHR .;CMPLTN 09:00 - 10:30 ' 1.501 CMPLTN', PULD 'CMPLTN 10:30 - 20:30 10.00 lil RIGMNT RGRP CMPLTN 20:30 - 21:00 ! '~ 0.501 CMPLTN, SFTY ; CMPLTN 21:00 - 00:00 ' 3.00 CMPLTN', PULD ',CMPLTN 2/24/2006 1 00:00 - 03:00 ', 3.00 I CMPLTNI, PULD ',CMPLTN 03:00 - 12:00 I 9.00' CMPLTNI RUNT CMPLTN Page 14 of 15 Spud Date: 1/19/2006 End: 2/25!2006 Group: Description of Operations to change out ESP spools and loaded 9 add. jts of 4" DP into pipe shed :and strapped same. 8.6 ppg brine in and out, st wt up 70K, do wt 40K. ' Cont to wash down at 2 bpm from 4,570' to 5,108', up wt 90K, dwn wt 35K. String stacking out, with pumps on at 2 bpm at 80 psi allowed string to go down Circ btms up at 5,108', stage pump rate up to 6 bpm at 120 psi, pump 'high vis sweep and at btms up had very little calcium carb. Cont RIH from 5,108' to 5,552' string stacking out and cont to wash 'down at 2 bpm at 80 psi , st wt up 90K, down wt 35K. (Top of SC-1 R ', Pkr @ 5,582'), prep to circ sweep above top of packer '~ Pumped Hi-Vis Sweep and circ at 4 bpm at 100 psi, at btms up had 'very little calcium carbonate back from sweep, recip up wt 90K, dwn wt 1138K. ~ Ease dwn through top of packer (5,582') with charge pump, 60 psi, to 15,598' twice, POOH to 5,577, up wt 100K. RU and reverse circ Hi-Vis Sweep, followed with clean brine (17.8 NTU), 3 bpm 130 psi, very little calcium carb at shakers, up wt 95K, dwn wt 35K with no pump. Pump 20 bbl Hi-Vis Sweep followed by clean brine (17.8 NTU) with '~ Corrosion Inhibitor, staged pump rate up to 6 pm at 200 psi, very litte 1, calcium carb at shakers from sweep. III Monitored well-static POOH from 5,557' LD 36 jts of 4" DP, POOH to 4,440', st wt up 75K, do wt 35K i RD 4" DP spinners & RU 4 1/2" tbg handling tools !1 POOH from 4,440' to 2,590', POOH standing back 20 stds of 4 1/2" tbg when Phase 3 weather condition was called field wide ii Operations suspended due to phase 3 weather, picked up around rig and monitoring well while waiting on weather, well-static Operations suspended due to Phase 3 weather, picked up around rig, '1 monitored well-static Cont to POOH standing back 23 stds of 4 1/2" tbg from 2,590' to 455' 1, POOH from 455' LD 14 jts of 4 1/2 jts of tbg, 7 5/8" casing scraper and 2 7/8" mule shoe Pulled wear bushing ', RU to pull 7 5/8" pack-off, checked pressure on 7 5/8" x 10 3 /4" ,Annulus and had 120 psi, RU bleed tank and blew down to 60 psi, opened to cuttings tank with 2" hose and bled down, recovered approx 175 bbls diesel I Retreived 7 5/8" pack-off, MU modified pack-off for ESP lower penetrator then RIH, oriented and set pack-off, RILDS, tested seals to 15,000 psi for 10 min & ck ok Removed low drum clutch and chain, inspected drawworks and re-installed same. Note: Rig went off hi-line power at 1430 hrs. Will ~!, attempt to repair Drawworks after running 4 1!2" completion and during rig move. 11 PJSM with Centrilift and rig crew on re-running ESP completion. PU, MU, & service ESP assembly. MU power cable to motor & check same. RIH to 55'. Fin MU ESP assmebly with Gaurdian Gauge RIH from 55' to 70', installed I-wire to Gauge and checked continuity on both the I-wire and ESP cable and checked ok. i, RIH with ESP completion on 4 1/2" tbg to 4,573', RIH with 143 jts & 2 v Printed: 4/11/2006 2:45:58 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-203 Common Well Name: 2T-203 Event Name: ROT -DRILLING Start: 1/21/2005 Contractor Name: n1433@ppco.com Rig Release: 2/25/2006 Rig Name: Nordic 3 Rig Number: 3 Date From - To 'Hours !Code Code', Phase __- _ RUNT 11 CMPLTN 2/24/2006 11 03:00 - 12:00 9.00 CMPLTN'~I III II I 12:00 - 16:30 4.50'', CMPLTN RUNT CMPLTN ~~ I' I II 16:30 - 18:00 I 1.50 ~I,I CMPLTNI RUNT CMPLTN I ~ I I I I I ~~ 18:00 - 00:00 II 6.00 WELCTL NUND '-CMPLTN 2/25/2006 00:00 - 04:00 ! 4.00 "' WELCTLI NUND I CMPLTN i II ', 04:00 - 05:00 ! 1.00 CMPLTNI, RURD CMPLTN 05:00 - 07:30 ' 2.50 CMPLTN' FRZP CMPLTN it I I ' 'I 07:30 - 08:30 I, 1.00', CMPLTN FRZP I CMPLTN I ' III 08:30 - 10:00 ~', 1.50 I CMPLTNIi OTHR ~ CMPLTN 10:00 - 11:00 1.00 WELCTL EORP 'i CMPLTN 11:00 - 12:00 1.0011 CMPLTNI OTHR 'I CMPLTN i I~ Page 15 of 15 Spud Date: 1/19/2006 End: 2/25/2006 Group: Description of Operations II pup jts (4,439') of 4 1/2", 12.6 ppf, L-80 IBTM tbg with CMU sliding sleeve, (closed) with 2-GLM's both with 1"with dummy valves, Total tubing and completion equip. RIH 4,573.3'. Used 77- 6.75" Cannon clamps, 4-5.875" Protectolizer clamps, 5-5.625" Flat guards and 76-1 1/4" Flat stainless steel bands., ave tbg MU was 3,500 ft-Ibs, st wt up 86K, do 36K MU FMC Uni-Head/ Horizontal tbg head with TWC and RIH to 4,600', installed penetrators to tbg head, cut ESP and TEC wires and spliced wires to penetrators, checked continuity and ck'd ok. II RIH with FMC tbg hanger and landed 4 1/2" completion at 4,630', RILDS landed ESP completion string with the ESP motor at 4,602', I pump intake at 4,587, ESP pump at 4,571', CMU sliding sleeve (closed) with 3.813" DB profile at 4,482', KBG-2-1 R 4 1/2" x 1"GLM I~ #1 with dummy valve at 4,430' and KBG -2-1 R 4 1 /2" x 1" GLM #2 with dummy valve set at 2,738', st wt up 86K, do wt 36K, blk wt 20K, RU and 'tested lower hanger seals to 250 psi low and 3,000 psi high and ck ok LD landing jt, ND BOPE & set stack on stump. Test continuity on penetrators, OK. Began to NU FMC tree. NOTE: Meg tested 2T-208, ESP tested 1.5G and Gauge showed 879 psi at 61 deg. ' Fin NU FMC 11" x 5M Unihead/Horizontal tree. Checked ESP 'continuity and ck ok, Tested void and. tree to 5,000 psi each for 10 min and ck ok, Final guardian guage readings were 819 psi at 59 degrees ',with 1.8 OHMS and 2 GIG, pulled TWC. RU circ manifold to freeze protect well ', Held PJSM and RU little red, attempted to pump down 4 1/2" x 7 5/8" 'annulus and pressured up to 700 psi and would not circ up tbg, RU on 1, tbg and was able to pump down tbg with returns out IA, freeze protected well with 75 bbls diesel, ave 1.3 bpm at 750 psi. Put tbg and annulus in communication to u-tube. I, Pump an additional 75 bbls diesel down 10 3/4" x 7 5/8" annulus to 11 replace diesel bled off to change out 7 5/8" pack-off, ave 2 bpm at 900 I psi, final pressure after shutting down 400 psi I RU crane and unloaded Centrilifts ESP spool's from rig floor then loaded 9 5/8" csg equip RU & installed BPV and secured well. Fin cleaning out mud pits, trip tank and cellar area. RELEASED RIG @ 12:00 Hrs 2/25/06 Printed: 4/11/2006 2:45:58 PM Halliburton Company Global Report Company: ConocoPhillipsAlaska Inc. Uate: 4/11/20D6 Time: 16:35:00 Page: t Field: Kuparuk River Unit Co-ordinate(NE) Refe rence: Well: 2T-203, True North Site: Kuparuk 2T Pad Vertical {TVD) Reference: 2T-203: 110.7 Well: 2T-203 Sectioir (VS) Referenc e: Well (O.OON,O.ODE,55.OOAzi) Wellpath: - 2T-203 __ Survey Calculation I1l ethod: Minimum Curvature Db: Oracle ___ Survey: Start Date: Company: Toot: Engineer: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre i Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 2T Pad Site Position: Northing: 5970382.43 ft Latitude: 70 19 49.129 N From: Map Fasting: 498944.93 ft Longitude: 150 0 30.807 W Position Uncertainty: 0.00 ft North Reference: True Ground Leve-: 0.00 ft Grid Convergence- -0.01 deg ~ _ _ Well: 2T-203 Slot Name: i Well Position: +N/-S 177.82 ft Northing: 5970560.23 ft Latitude: 70 19 50.878 N +E/-W -0.35 ft Easting : 498944.61 ft „ Longitude: 150 0 30.817 W Position Uncertainty: 0.00 ft - Wellpath: 2T-203 Drilled From: Well Ref. Point ~, I, 501032052000 Tie-on Depth: 30.52 ft 'I Current Datum: 2T-203: Height 110.72 ft Above System Da tum: Mean Sea Level Magnetic Data: 1/13/2006 Declination: 23.99 deg ', Field Strength: 57547 nT Mag Dip Angle: 80.76 deg ~i Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.52 0.00 0.00 55.00 Survey Program for Definitive Wellpath Date: 8/2/2005 Validated: N o Version: 3 Actual From To Survey ft ft Toolcode Tool Name - ', 106.91 720.00 2T-203 gyro(1 07-720) (106. 91-7 CB-GYRO-SS Camera based gyro single shot ' ', 795.47 933.13 2T-203 (795-933) (795.47-933.1 MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC ', 999.00 1094.00 2T-203 gyro(999-1094) (999.00- CB-GYRO-SS Camera based gyro single shot j 1189.12 7469.13 2T-203 (1189. 12-7469.13) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC Survey ', MD Incl Azim TVD Sys TVD N/S E/1V MapN MapE Toot ~~ ft deg deg ft ft ft ft ft ft 30.52 0.00 0.00 30.52 -80.20 0.00 0.00 5970560.23 498944.61 TIE LINE ~I 106.91 0.45 50.52 106.91 -3.81 0.19 0.23 5970560.42 498944.84 CB-GYRO-SS 171.00 0.58 323.74 171.00 60.28 0.61 0.23 5970560.84 498944.84 CB-GYRO-SS ', 257.00 3.90 319.13 256.92 146.20 3.18 -1.94 5970563.41 498942.67 CB-GYRO-SS 348.00 8.73 312.39 347.34 236.62 10.18 -9.07 5970570.41 498935.54 CB-GYRO-SS 440.00 11.66 308.57 437.88 327.16 20.68 -21.50 5970580.91 498923.12 CB-GYRO-SS 530.00 13.33 308.76 525.75 415.03 32.85 -36.70 5970593.08 498907.92 CB-GYRO-SS 597.00 11.52 310.89 591.17 480.45 42.06 -47.78 5970602.30 498896.84 CB-GYRO-SS 629.00 11.33 305.18 622.54 511.82 45.97 -52.76 5970606.20 498891.86 CB-GYRO-SS 720.00 11.85 320.04 711.71 600.99 58.28 -66.07 5970618.51 498878.55 CB-GYRO-SS 795.47 12.37 335.69 785.52 674.80 71.59 -74.38 5970631.82 498870.25 MWD+IFR-AK-CAZ-SC 841.15 13.98 343.84 830.00 719.28 81.35 -77.93 5970641.58 498866.70 MWD+IFR-AK-CAZ-SC 933.13 15.26 348.96 919.00 808.28 103.91 -83.34 5970664.14 498861.29 MWD+IFR-AK-CAZ-SC 999.00 16.74 336.42 982.33 871.61 121.11 -88.80 5970681.34 498855.84 CB-GYRO-SS 1033.00 17.08 336.14 1014.86 904.14 130.17 -92.78 5970690.40 498851.86 CB-GYRO-SS 1065.00 16.33 334.53 1045.51 934.79 138.53 -96.61 5970698.76 498848.03 CB-GYRO-SS Halliburton Company Global Report Company: ConocoPhillips Alaska Inc. Date: 4/11/2006 Time: 16 :35:OD Page: 2 Field: Ku paruk River Unit Co-ordinate(NE) Reference: Well: 2T-203, True North Site: Ku paruk 2T Pad Vertical (TVD) Refe rence: 2T-203: 110.7 Well: 2T -203 Section (VS) Referen ce: Well ( O.OON,O. OOE, 55.OOAzi) Wellpath: 2T -203 Su rvey Calcula tion Method: Minimum Curvature Db: Oracle Sur~ev ', Ill incl Azim TVD Sys TV D N/S E/W Map\ MapE Tool ft deg deg ft ft ft ft ft ft 1094.00 16. 00 334. 90 1073. 37 962. 65 145 .83 -100 .06 5970706 -- .06 ___ 498844 .58 __ __ CB-GYRO-SS 1189.12 15. 95 341. 00 1164. 82 1054. 10 170 .06 -109 .88 5970730 .29 498834 .77 MWD+IFR-AK-CAZ-SC 1216.61 17. 48 341. 86 1191. 15 1080. 43 177 .55 -112 .39 5970737 .78 498832 .25 MWD+IFR-AK-CAZ-SC 1311.78 20. 55 337. 94 1281. 12 1170. 40 206 .62 -123 .12 5970766 .85 498821 .53 MWD+IFR-AK-CAZ-SC 1405.19 24. 50 337. 59 1367. 39 1256. 67 239 .74 -136 .67 5970799 .96 498807 .99 MWD+IFR-AK-CAZ-SC I~ 1500.33 27. 61 338. 02 1452. 85 1342. 13 278 .43 -152 .44 5970838 .65 498792 .22 MWD+IFR-AK-CAZ-SC I 1569.21 33. 28 337. 93 1512. 20 1401. 48 310 .77 -165 .53 5970870 .99 498779 .14 MWD+IFR-AK-CAZ-SC 1627.89 32. 67 338. 78 1561. 43 1450. 71 340 .45 -177 .31 5970900 .67 498767 .37 MWD+IFR-AK-CAZ-SC 1720.03 35. 76 335. 70 1637. 62 1526. 90 388 .19 -197 .40 5970948 .41 498747 .29 MWD+IFR-AK-CAZ-SC 1783.14 39. 93 333. 84 1687. 45 1576. 73 423. 19 -213. 92 5970983. 41 498730 .77 MWD+IFR-AK-CAZ-SC it 1814.48 42. 21 332. 77 1711. 08 1600. 36 441. 58 -223. 18 5971001. 80 498721 .52 MWD+IFR-AK-CAZ-SC 1902.54 46. 62 331. 54 1773. 96 1663. 24 496 .05 -251. 98 5971056. 26 498692 .73 MWD+IFR-AK-CAZ-SC 1974.96 51. 80 329. 43 1821. 26 1710. 54 543 .72 -279. 01 5971103. 94 498665 .70 MWD+IFR-AK-CAZ-SC ~ 2003.16 53. 59 330. 21 1838. 35 1727. 63 563 .11 -290. 28 5971123. 33 498654 .43 MWD+IFR-AK-CAZ-SC 2047.91 53. 57 329. 13 1864. 92 1754. 20 594 .19 -308. 47 5971154. 41 498636 .26 MWD+IFR-AK-CAZ-SC 2097.83 57. 08 328. 36 1893. 31 1782. 59 629 .28 -329. 77 5971189. 49 498614 .96 MWD+IFR-AK-CAZ-SC 2142.44 59. 26 327. 18 1916. 84 1806. 12 661 .34 -349. 99 5971221. 55 498594 .75 MWD+IFR-AK-CAZ-SC 2192.47 62. 08 326. 91 1941. 35 1830. 63 697 .93 -373. 71 5971258. 14 498571 .03 MWD+IFR-AK-CAZ-SC 2235.45 62. 64 327. 28 1961. 28 1850. 56 729 .90 -394. 40 5971290. 11 498550 .36 MWD+IFR-AK-CAZ-SC 'I 2287.21 65. 16 326. 97 1984. 05 1873. 33 768 .93 -419. 62 5971329. 14 498525 .14 MWD+IFR-AK-CAZ-SC 2335.38 67. 35 327. 05 2003. 45 1892. 73 805 .91 -443 .63 5971366. 12 498501 .14 MWD+IFR-AK-CAZ-SC 2382.26 68. 94 329. 88 2020. 90 1910. 18 842 .99 -466. 38 5971403. 20 498478 .40 MWD+IFR-AK-CAZ-SC ', 2431.45 69. 13 333. 48 2038. 51 1927. 79 883 .42 -488. 16 5971443. 63 498456 .62 MWD+IFR-AK-CAZ-SC 2476.55 70. 33 336. 90 2054. 14 1943. 42 921 .82 -505. 91 5971482. 03 498438 .88 MWD+IFR-AK-CAZ-SC ': 2518.60 70. 31 339. 55 2068. 30 1957. 58 958 .58 -520. 60 5971518. 79 498424 .20 MWD+IFR-AK-CAZ-SC 2570.26 71. 44 343. 65 2085. 23 1974. 51 1004 .89 -535. 99 5971565. 09 498408 .81 MWD+IFR-AK-CAZ-SC ' 2664.70 68. 72 344. 18 2117. 40 2006. 68 1090 .19 -560. 59 5971650. 39 498384 .23 MWD+IFR-AK-CAZ-SC 2711.37 68. 80 343. 63 2134. 31 2023. 59 1131 .98 -572. 65 5971692. 18 498372 .17 MWD+IFR-AK-CAZ-SC '' 2759.33 71. 03 342. 39 2150. 78 2040. 06 1175 .06 -585. 82 5971735. 25 498359 .02 MWD+IFR-AK-CAZ-SC I 2854.83 72. 01 342. 56 2181. 05 2070. 33 1261 .43 -613 .09 5971821. 62 498331 .76 MWD+IFR-AK-CAZ-SC 2948.81 70. 49 342. 55 2211. 26 2100. 54 1346 .32 -639 .77 5971906. 51 498305 .09 MWD+IFR-AK-CAZ-SC 3043.26 70. 30 343. 61 2242. 95 2132. 23 1431 .45 -665 .66 5971991. 63 498279 .21 MWD+IFR-AK-CAZ-SC '; 3137.22 74. 41 343. 78 2271. 43 2160. 71 1517 .37 -690 .79 5972077. 54 498254 .10 MWD+IFR-AK-CAZ-SC 3232.42 72. 73 343. 91 2298. 35 2187. 63 1605 .07 -716 .20 5972165. 24 498228 .71 MWD+IFR-AK-CAZ-SC ', 3326.59 72. 00 343. 84 2326. 88 2216. 16 1691. 28 -741. 13 5972251. 45 498203 .80 MWD+IFR-AK-CAZ-SC 3419.96 72. 02 343. 71 2355. 72 2245. 00 1776. 55 -765. 94 5972336. 71 498179 .00 MWD+IFR-AK-CAZ-SC ~ 3512.60 73. 90 343. 73 2382. 87 2272. 15 1861. 57 -790. 77 5972421. 72 498154 .18 MWD+IFR-AK-CAZ-SC 3608.94 70. 96 342. 77 2411. 95 2301. 23 1949. 51 -817. 23 5972509. 66 498127 .74 MWD+IFR-AK-CAZ-SC i ' 3703.16 72. 62 343. 55 2441. 39 2330. 67 2035. 17 -843. 15 5972595. 31 498101 .83 MWD+IFR-AK-CAZ-SC ', 3799.77 72. 12 342. 96 2470. 65 2359. 93 2123. 34 -869. 68 5972683. 48 498075 .32 I MWD+IFR-AK-CAZ-SC I ', 3894.70 72. 05 343. 17 2499. 85 2389. 13 2209. 75 -895. 99 5972769. 88 498049 .02 MWD+IFR-AK-CAZ-SC '~ j 3989.17 72. 04 342. 04 2528. 97 2418. 25 2295. 50 -922. 86 5972855. 63 498022 .17 MWD+IFR-AK-CAZ-SC j 4082.61 71. 45 342. 16 2558. 24 2447. 52 2379. 95 -950. 13 5972940. 07 497994 .91 MWD+IFR-AK-CAZ-SC I '~ 4177.61 71. 70 341. 84 2588. 27 2477. 55 2465. 66 -977. 98 5973025. 78 497967 .07 I MWD+IFR-AK-CAZ-SC 4272.98 72. 12 341. 51 2617. 88 2507. 16 2551. 72 -1006. 49 5973111. 84 497938 .58 MWD+IFR-AK-CAZ-SC ', 4366.53 71. 70 343. 60 2646. 93 2536. 21 2636. 55 -1033. 14 5973196. 66 497911 .94 MWD+IFR-AK-CAZ-SC ~!, 4462.94 71. 59 344. 73 2677. 29 2566. 57 2724. 58 -1058. 11 5973284. 69 497886 .99 MWD+IFR-AK-CAZ-SC !, '~i 4558.21 70. 87 345. 37 2707. 95 2597. 23 2811. 73 -1081. 38 5973371. 83 497863 .73 MWD+IFR-AK-CAZ-SC j j 4653.27 70. 90 346. 21 2739. 08 2628. 36 2898. 80 -1103. 43 5973458. 90 497841 .70 MWD+IFR-AK-CAZ-SC '~~ ~I 4748.77 70. 13 348. 82 2770. 94 2660. 22 2986. 69 -1122. 90 5973546. 78 497822 .24 MWD+IFR-AK-CAZ-SC 4843.95 72. 09 353. 51 2801. 77 2691. 05 3075. 64 -1136. 70 5973635. 73 497808 .45 MWD+IFR-AK-CAZ-SC 4935.06 72. 66 357. 99 2829. 37 2718. 65 3162. 21 -1143. 13 5973722. 29 497802 .04 MWD+IFR-AK-CAZ-SC I 5032.96 73. 91 2. 56 2857. 54 2746. 82 3255. 94 -1142. 67 5973816. 01 497802 .51 MWD+IFR-AK-CAZ-SC Halliburton Company • Global Report Company: ConocoPhillipsAlaska Inc. Date: 4/11/2006 Time: 16:35:00 Page: 3 Field: Kuparuk River Unit Co-ordinate(NF.) Reference: Well: 2T-203, True North Site: Kuparuk 2T Pad Vertical (T~'D) Reference: 2T-203: 110.7 ~', Well: 2T-203 Section (VS) Reference: Well (O.OON,O.OOE,55.OOAzi) W'ellpath: 2T-203 Survey Calculation Method: Minimum Curvature Db:Oracle Surcc~ ~7D Licl Azim TVD Sys TVD N/5 E/y'V ft deg deg ft ft ft ft __ _ __ _ 5128.49 73. 57 7.41 2884. 30 2773.58 3347 .28 -1134 .71 ', 5223.20 73. 89 12.16 2910. 85 2800.13 3436 .84 -1119. 26 '~ 5315.63 74. 35 18.06 2936. 16 2825.44 3522 .62 -1096. 09 5410.89 74. 01 22.92 2962. 14 2851.42 3608 .45 -1064. 02 ~~~ 5504.28 76. 23 27.65 2986. 14 2875.42 3690 .02 -1025. 47 I~ 5599.24 78. 92 33.09 3006. 58 2895.86 3769 .98 -978. 58 I 5693.89 78. 00 38.95 3025. 53 2914.81 3844 .95 -924. 08 5787.73 77. 36 44.19 3045. 57 2934.85 3913 .52 -863. 28 5882.77 78. 07 49.77 3065. 80 2955.08 3976 .84 -795. 41 5977.58 79. 34 53.47 3084. 38 2973.66 4034 .55 -722. 54 'i 6023.42 79. 53 52.82 3092. 78 2982.06 4061 .58 -686. 48 6075.84 79. 28 55.40 3102. 42 2991.70 4091 .78 -644. 74 6169.88 84. 78 57.99 3115. 46 3004.74 4142 .89 -566. 93 6265.59 91. 15 59.11 3118. 86 3008.14 4192 .76 -485. 38 6358.46 92. 43 55.92 3115. 96 3005.24 4242. 61 -407. 09 6449.57 91. 89 53.59 3112. 52 3001.80 4295. 15 -332. 74 6541.01 88. 87 50.51 3111. 92 3001.20 4351. 36 -260. 65 ', 6635.32 88. 44 50.09 3114. 13 3003.41 4411. 59 -188. 11 ', 6727.50 89. 06 50.98 3116. 14 3005.42 4470. 17 -116. 96 6820.37 91. 24 53.06 3115. 90 3005.18 4527 .31 -43. 77 6910.01 88. 70 53.74 3115. 94 3005.22 4580 .75 28. 19 1(apN V[apE 'Cool ft ft 5973907.33 497810.49 MWD+IFR-AK-CAZ-SC 5973996.88 497825.95 MWD+IFR-AK-CAZ-SC 5974082.66 497849.13 MWD+IFR-AK-CAZ-SC 5974168.47 497881.20 MWD+IFR-AK-CAZ-SC 5974250.02 497919.77 MWD+IFR-AK-CAZ-SC 5974329.97 497966.65 MWD+IFR-AK-CA2-SC 5974404.93 498021.16 MWD+IFR-AK-CAZ-SC 5974473.48 498081.97 MWD+IFR-AK-CAZ-SC 5974536.79 498149.84 MWD+IFR-AK-CAZ-SC 5974594.48 498222.71 MWD+IFR-AK-CAZ-SC .5974621.50 498258.77 MWD+IFR-AK-CAZ-SC 5974651.70 498300.51 MWD+IFR-AK-CAZ-SC 5974702.78 498378.32 MWD+IFR-AK-CAZ-SC 5974752.64 498459.87 MWD+IFR-AK-CAZ-SC 5974802.47 498538.16 MWD+IFR-AK-CAZ-SC 5974854.99 498612.51 MWD+IFR-AK-CAZ-SC 5974911.20 498684.60 MWD+IFR-AK-CAZ-SC 5974971.41 498757.14 MWD+IFR-AK-CAZ-SC 5975029.96 498828.29 MWD+IFR-AK-CAZ-SC 5975087.09 498901.48 MWD+IFR-AK-CAZ-SC 5975140.52 498973.44 MWD+IFR-AK-CAZ-SC 7006.21 89.71 55.01 3117.28 3006.56 4636.78 106.37 5975196.53 499051.63 MWD+IFR-AK-CAZ-SC 7098.88 91.65 57.54 3116.18 3005.46 4688.22 183.43 5975247.95 499128.68 MWD+IFR-AK-CAZ-SC 7189.96 89.73 57.70 3115.08 3004.36 4736.99 260.34 5975296.71 499205.59 MWD+IFR-AK-CAZ-SC j 7282.90 93.24 55.75 3112.67 3001.95 4787.95 338.00 5975347.66 499283.25 MWD+IFR-AK-CAZ-SC 7377.03 91.89 53.79 3108.46 2997.74 4842.19 414.81 5975401.88 499360.06 MWD+IFR-AK-CAZ-SC '! 7469.13 93.08 55.17 3104.47 2993.75 4895.65 489.70 5975455.32 499434.95 MWD+IFR-AK-CAZ-SC 7525.00 93.08 55.17 3101.47. 2990.75 4927.52 535.49 5975487.18 - 499480.74 - PROJECTED to TD r~ ~~ 11-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2T-203 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 30.52' MD Window /Kickoff Survey: 7,469.13' MD (if applicable) Projected Survey: 7,520.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~09~C~~~'~~ i • D 0 ~ d b FRANK H. MURKOWSK/, GOVERNOR ~~ O~ ~ ~ 333 W. 7'" AVENUE, SUITE 100 CO1~T5ERQATI011T CO1rII~IIS5I011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 February 14, 2006 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Waiver Request--20 AAC 25.033 (e)(3) ConocoPhillips Alaska, Inc. KRU 2T-203 PTD: 205-197 Dear Mr. Thomas: Your request for a waiver to 20 AAC 25.033 (e)(3) [...the wellbore must be kept full of drilling fluid at all times;] is hereby GRANTED. ConocoPhillips Alaska, Inc. ("CPAI") applied for a waiver to 20 AAC 25.033 (e)(3) by letter dated January 25, 2006 for completion operations on KRU well 2T- 203. The waiver was requested due to high volume fluid losses experienced while recently completing KRU well 2T-208 [205-187]. Similar losses are likely in 2T-203 since the target Tabasco reservoir has high permeability while the reservoir pressure is relatively low. CPAI had employed a frangible valve [Knock-Out Isolation Valve - KOIV] in the downhole completion equipment to mitigate fluid losses, however the KOIV did not function correctly. CPAI believes that the hydrostatic head above the KOIV and the fluid velocity through it when it was actuated caused the flapper to shatter. For 2T-203, CPAI has determined the hydrostatic balance depth below surface based on the reservoir pressure and completion fluid weight. Prior to actuating the KOIV, CPAI will assess the fluid loss rate and based on that assessment stop filling the well for the time necessary to allow the fluid level to drop toward the balance depth. When the determined time has elapsed, CPAI then intends to actuate the KOIV and attempt to fill the wellbore. If it is not possible to fill the hole, CPAI intends to again assess the fluid loss and proceed with completion activities while filling the hole with up to 60 bbls/hour. Randy Thomas • February 14, 2006 Page 2 of 2 20 AAC 25.033 (j) gives the Commission discretion to waive the requirements of sections (c) - (g) of the regulation if the drilling fluid program or system meets the design criteria of section (b). If the KOIV is still intact, it should be possible to fill the hole and operations will continue normally. In the event that the KOIV fails, continuing to fill the weiibore will result in a fluid column weight in excess of the reservoir pressure. Accordingly, the Commission concludes that CPAI's plan will meet the intent of 20 AAC 25.033 (b) (1) (A) . In order to implement the plan, sufficient fluid volume must be available as required by 20 AAC 25.033 (b)(2). DONE at Anchorage, Alaska and dated Fe~u~ 14, 2006. Gas Co~rservation Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission Oil and Gas Conservation Commission • • ------- Original Message -------- Subject:RE: 2T-203 Waiver Request Date:Mon, 13 Feb 2006 17:20:42 -0900 From:Hayden, Philip <Philip.Hayden@conocophillips.com> To:Thomas Maunder <tom maunder@admin.state.ak.us> CC:Thomas, Randy L <Randy.L.Thomas@conocophillips.com> Tom, 1. With expected reservoir pressures (4.9 - 6.3 ppg MWE) and fluid weights (8.7 - 9.1 ppg) we would expect the fluid level to drop anywhere from 870 to 1500' MD. 2. The flapper of the KOIV is rated to 1500 psi. 3. If the KOIV should not function after closing we would first establish the loss rate. If the loss rate is less than approximately 60 bph (what we feel comfortable with) we would maintain the fluid level at surface by simply keeping up with the fluid loss. If, on the other hand, the loss rate exceeds this "comfortable" number we would allow the fluid level to drop but continue to pump into the hole at a rate of at least 60 bph. In this way we would always maintain a positive hydrostatic acting on the reservoir. In addition, before closing the KOIV we would establish the loss rate and calculate how long it would take to empty 870' of casing annulus at that rate. We would stop filling the hole for that calculated period of time allowing the level to fall less than the 870'. This is a conservative calculation as we would assume that the loss rate would decrease as the hydrostatic falls. After attempting to close the KOIV we would establish whether it had closed or not. If successful we would maintain the fluid level at surface. If unsuccessful we would proceed as in (3) above. If there is any more information you would like please let me know Regards Philip -----Original Message----- From: Thomas Maunder [mailto:tom maunderC~admin.state.ak.us] Sent: Monday, February 06, 2006 3:25 PM To: Hayden, Philip Subject: Re: 2T-203 Waiver Request Philip, I have returned to your waiver request on this well and have a couple more questions. 1. Do you have a feeling how far the fluid level might drop? I have done some calculations based on the contrast in the formation pressure and your planned fluid density, but I need your assessment. 2. What sort of differential pressure can the KOIV withstand? 3. Have you all internally reached a decision on how operations might proceed if "softly/slowly" closing the KOIV doesn't work? I think that the determination in 3 will be the key to needing a waiver or not. Look forward to your reply. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 1/27/2006 10:54 AM: 1 oft 2/14/2006 8:31 AM • • >Tom, >1. We spudded the well late on the 24th January. We plan on picking up >the screens in approximately 3 weeks time, --17th February. >2. On 2T-208 we feel that the high flow rate (loss rate} forced the >flapper of the valve (a ceramic material designed to be ruptured later >in the program) to slam shut thus breaking it. >3. You are correct. Our idea is to reduce the loss rate by letting the >fluid level fall. With the lower loss rate we would hope to be able to >let the KOIV flapper close more slowly, without rupturing it. >4. If the KOIV shuts successfully we would expect our loss rate to >diminish to practically zero. In this scenario we would fill the hole, >with the level at surface, so as to be able to monitor the fluid level >for eventual losses/flow. >If the valve failed to close or was ruptured when closing we have yet >to decide internally whether (a) we would elect to pump a LCM pill and >then re-establish the fluid level at surface or (b) operate without the >fluid level at surface. >I hope I have helped to clarify the waiver request. If you have any >further queries please let me know. >Regards >Philip >-----Original Message----- >From: Thomas Maunder [mailto:tom maunderc~admin.state.ak.us] >Sent: Friday, January 27, 2006 10:00 AM >To: Hayden, Philip >Subject: 2T-203 Waiver Request >Philip, >We have received your request and I am examining it. A couple of >questions... >1. When will you be on the well and when do you anticipate running the >screens? >2. You previously related to me that it is felt that when the KOIV >closed on the prior well, the high flow rate at that time possibly >ruptured it, is this correct? >3. I need a little clarification on your plan. You plan to run the >screen and place the acid which will likely result in the high losses. >Do you plan to let the fluid level drop thereby reducing the losses >sufficiently that when the KOIV closed that any loss rate is not >sufficient to rupture the valve? >4. If this is successful, do you plan to fill the hole above the KOIV >or just let the fluid level remain "where it is"? Your statement in >the last paragraph about pumping fluid but not sufficient to fill the > hole is not clear. >Thanks in advance for your responses, >Tom Maunder, PE >AOGCC 2 of 2 2/14/2006 831 AM -~ . RECEIVED ConocoPh i I I i ps JAN 2 7 2006 Conoco/Phillips, Inc.. A~BSt(8 Oit & G8S Co(IS. Gormiiasion Post Office Box 100360 AnChore~@ Anchorage, Alaska 99510 January 25, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333. West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: 2T-203. Permit to Drill # 205-197, API # 50-103-20520-00 Dear Commissioner: With reference to section 25.033, part Q) of the regulations ConocoPhillips Alaska, Inc. hereby applies for a waiver from part (e) (3)-of the same section for completion operations on-Tabasco well 2T-203. --•-~- ~-- After running 4 %2" screens into the production hole, setting the liner hanger packer and spotting an acid flush across the screens, as per the procedure on file with the commission, ConocoPhillips would like to plan to let the fluid level in the well fall below the rotary table. After spotting the acid flush we expect to induce heavy losses (`OOs bbl/hour) due to the removal of the filter cake. In order to control these expected losses we are planning to run a Knock Out Isolation Valve (KOIV) below the liner hanger packer. The flapper in this valve falls into place as we pull through it with our screen wash string when starting to trip out of the hole. However, in order to maximize the chances of this KOIV functioning correctly we would like to reduce the forces acting on it as it closes. To do this we would like to reduce the flow velocity through the valve when closing, hence letting the fluid level in the well fall below the rotary table. If the KOIV closes successfully then ConocoPhillips would resume drilling standard practices and maintain the well full of fluid. Please note that at no time do we intend the well to be in an under balance condition -during the period of operation under this requested waiver fluid will be constantly pumped down the well but not at a rate to keep the level at surface. Reservoir pressure in this area is forecast to be approximately 6.3 ppg equivalent or less while our fluid density will not fall below 8.7 ppg. If you have any questions or require further information, please contact Phillip Hayden at (907) 265-6481. Sincerely, -.-.~_ _ Randy Thomas l Kuparuk Drilling Superintendent 2T-203 Waiver Request * • • Subject: 2T-203 Waiver Request From: Thomas Maunder ~ ~-tom maundcrr~admin.state.ak.us=~~ Date: l~ri, ~7 .Iai~ ?006 10:~~0:?~ -000 "I'o: Philip Hayden ~~~=philip.hayden@conocophillips.coill.:. Philip, we have received your request and I am examining it. A couple of questions... 1. When will you be on the well and when do you. anticipate running the screens? 2. You previously related to me that it is felt that when the KOIV closed on the prior well, the high flow rate at that time possibly ruptured it, is this correct? 3. I need a little clarification on your plan. You plan to run the screen and place the acid which will likely result in the high losses. Do you plan to let the fluid level drop thereby reducing the losses sufficiently that when the KOIV closed that any loss rate is not sufficient to rupture the valve? 4. If this is successful, do you plan to fill the hole above the KOIV or just let the fluid level remain "where it is"? Your statement in the last paragraph about pumping fluid but not sufficient to fill the hole is not clear. Thanks in advance for your responses, Tom Maunder, PE AOGCC ~l~t~ ~r y'` ~~~~L~ -~ o a~~ ~e~~~~ ~~ ~ ~C ~ S ~ ~~ ~ .~ L` ~ ~ ~~ ~c~ ~ ~f~~ ~ ZF p~C.3.~V~ `~C~--~ o. t ~ ~s~~~ ~~ .~ a ~ ~~-~~~ ~ ~~ 4 of~ 1/27/2006 10:01 AM • • -- ~tcpr~ ~„~ ~o ~~~~\~~ ~ t losses S ~~ ~~~ `s~c~~ ` ct~ ~©Q t~ aS ~~~~~-~~ o~~- ~~ ~~ ~~~e ~~ ~ ~ ~ ~~ c7~4` Y.O \~ y ~~ ~' \ l `^ 111 N~~ h~ ~ r. ~ ~ C' ~ L~r ~ 1-~. ~- ~--~: ~... ~~ y ~.~ ~ U c~ wv.'~ v ~. ~_ ~- s ~ ~~~ tip:\~ ~ ~ ~~ ~ ~. ,, ~~ ~~.~ c~.~~vc .~ 1r~c~ 1 ~~; ~ ~ RE: 2T-203 Waiver Request •, Subject: RC: 2T-?tl_~ Waiver Request From: "Havcien. Pl~ili~i" Philip.Hayden~a:a~nocop~illips.com> Date: Fri, ~7 Jan ?O06 10:54:47 -0900 To: Thomas ~9aunder ~~~-tom ~i~auntie-r(ci`acjmin.statc.~+k.us== Tom, 1. we spudded the well late on the 24th January. We plan on picking up the screens in approximately 3 weeks time, -17th February. 2. On 2T-208 we feel that the high flow rate (loss rate) forced the flapper of the valve (a ceramic material designed to be ruptured later in the program) to slam shut thus breaking it. 3. You are correct. Our idea is to reduce the loss rate by letting the fluid level fall. With the lower loss rate we would hope to be able to let the KOIV flapper close more slowly, without rupturing it. 4. If the KOIV shuts successfully we would expect our loss rate to diminish to practically zero. In this scenario we would fill the hole, with the level at surface, so as to be able to monitor the fluid level for eventual losses/flow. If the valve failed to close or was ruptured when closing we have yet to decide internally whether (a) we would elect to pump a LCM pill and then re-establish the fluid level at surface or (b) operate without the fluid level at surface. --, r I hope I have helped to clarify the waiver request. If you have any further queries please let me know. Regards Philip -----Original Message----- From: Thomas Maunder [mailt~e:*:::om rla~znder~.~?adrin.stat=e.ak.t.s Sent: Friday, January 27, 2006 10:00 AM To: Hayden, Philip Subject: 2T-203 Waiver Request Philip, We have received your request and I am examining it. A couple of questions... 1. When will you be on the well and when do you anticipate running the screens? 2. You previously related to me that it is felt that when the KOIV closed on the prior well, the high flow rate at that time possibly ruptured it, is this correct? 3. I need a little clarification on your plan. You plan to run the screen and place .the acid which will likely result in the high losses. Do you plan to let the fluid level drop thereby reducing the losses sufficiently that when the KOIV closed that any loss rate is not sufficient to rupture the valve? 4. If this is successful, do you plan to fill the hole above the KOIV or just let the fluid level remain "where it is"? Your statement in the last paragraph about pumping fluid but not sufficient to fill the hole is not clear. Thanks in advance for your responses, Tom Maunder, PE AOGCC ] of 1 1/27/2006 l T:09 AM Re: 2T-203 • Subject: Re: 2T-~U3 From: i~hun~a~ iti~launder <lom inaundcr~~ad~nin.state.ak.us=~ Date::~~lon, 1? Dcc ?UO5 09:41:19.-O9ti~~ To: "Ilav~icn, Phili~~" ~~Philip.Ha}~dcr~ru!c~~nocophillihs.con~-> Thanks Philip. My question is answered. Hayden, Philip wrote, On 12/12/2005 9:35 AM: Tom, Although it hasn't been definitively decided yet I am thinking we will go with the same arrangement as on 2T-208 - 5" DP in the surface & 9 7/8" hole and 4" DP in the production interval. The arrangement of the BOP would also be the same as on 2T-208 - Annular 5" or 4" Rams depending on DP in use Blinds Variables 2 7/8" - 5" 7 5/8" Rams The use of the variables here should also cover the running of the tubing. Please let me know if this has answered your query. Regards Philip -----Original Message----- From: Thomas Maunder [mailto:tom maunder~admin..state.ak.us] Sent: Monday, December 12, 2005 9:21 AM To: Hayden, Philip Subject: 2T-203 Philip, I am reviewing 2T-203. set of rams will be 4" the way?? Are variably need to change the top Tom Maunder, PE AOGCC On the stack arrangement, it is indicated that the top Is it because there is no pilot hole that 4" is used all =-s not an option, since as I understand the rig will still rams to 4-1/2" to run the tubing? 1 of 1 12/12!2005 9:41 AM Re: Packer setting depth 2T-208 & 203 Subjeet:l':cPackei-settin~~ depth 2T-208 & 203 'r-'~t ~~~---~~r`-~ From: '(~h~~ma; 1Vlaund~;r ~ atom maundercr admin.statc.alc.ils? Date: 1t"cd, ~~, Dcc 200 O~:~1>:-#h -090(1 To: "Havdtn. Philip" ~-Philip.Ha~~d~n!~'conocophillips.e,om~:> Philip, There is no specification regarding the packer depth on a production well. What likely applies is "good oilfield practice" and based on your comment, you are setting the packer where you are because of the requirements of the equipment you are using. Good luck with the operations. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 12/6/2005 3:19 PM: Tom, I just wanted to confirm that you are aware and approve that the packer with which we will be hanging off our production screens will be positioned approximately 500' inside the 7 5/8" casing. This is due to the space out required for circulating with the screens in place. Please let me know if you were not aware or if this presents a problem for the commission. Regards Philip 1 of 1 ~`~ ~~ ~.c~ 1/12/2006 8:03 AM ~~~ ~~ 3 ~ qq ~ ~3 ~ ~ d ~ ~ ~!"~~ ~ ~ ~ ~ ~ i ) , j I a ~~ ~ ! 1 ~X ~ ~A ~ ~ _ ) ~ j ~ 'mod ai j+ "~ ~i ~'± lr ~ ~'r1 ~ fa~ '~.~~ ~ E~ L~ _ ~a„~+' ;,,J , .xd 'x~a ~..~ `,mil ~J ~ ;a.~ °. ALASSA OIL A1QD GAS COI~TSFR~A~`IO1~T COril-'IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: KRU Tabasco 2T-203 • FRANK H. MURKOWSKl, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ConocoPhillips Alaska, Inc. Permit No: 205-197 Surface Location: 4700' FNL, 4724' FEL, Sec. 1, T11N, R8E Bottomhole Location: 4503' FNL, 3498' FEL, Sec. 36, T12N, R8E Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this I day of month, 2005 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Chairman ~~~ ~~~~ V STATE OFALASKA ~',~! 1~ /~ - G ~ ~~~ ~ ~ ~~~~J ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~Ips1tR ~'rl ~~~~ ~~~~• CurrxrliSS101i 20 AAC 25.005 ~I1C~iDfBQ@ 1a. Type of Work: Drill^J Redrill Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ~ Multiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone Q 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 2T-203 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 8518' TVD: 3105' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 4700' FNL, 4724' FEL, Sec.1, T11N, R8E ~ 7. Property Designation: i ADL 25569/25548 Tabasco Oil Pool Top of Productive Horizon: 602' FNL, 188' FEL, Sec.2, T11N, R8E 8. Land Use Permit: ALK 2667/2662 13. Approximate Spud Date: 1/10/2006 ' Total Depth: 4503' FNL, 3498' FEL, Sec.36, T12N, R8E ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 15652' at top Res.' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498944.61 y- 5970560.2 Zone- 4 10. KB Elevation (Height above GL): 30 feet 15. Distance to Nearest Well within Pool: 2T-10 , 726' ~ 16. Deviated wells: Kickoff depth: 2gQ ~ ft. Maximum Hole Angle: g2° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1027 psig ~ Surface: 685 prig ~ 18. Casing Program ecificatio S Setting Depth Quantity of Cement Size p ns Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 152 X-65 Welded 77 0 0 107 107 Driven to 7T. Cmt from 35',.4/2000 13 1/2" 10 3/4" 45.5 L-80 BTCM 1710 0 0 1710 1553 ' 390 sx ASLite, 340 sx AS1 9 7/8" 7 5/8" 29.7 L-80 BTCM 6162 0 0 6162 ~ 3094 440 sx DeepCRETE 6 3/4" 4 1/2" 12.6 13Cr VAM Top 2758 5760 3062 8518 3105 ~ NA -Screens 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling ProgramQ Time v. Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Philip Hayden @ 265-6481 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature 1 Phone ~-~5 6~ ~o Date i Z ~2~0~ '-'•""~~ Pre ared b Sharon Allsu -D k Commission Use Only Permit to Driller !` ~ Number: G~.~.7 ' l~ ~ API Number: 50- f U 3 " ,2~ ~~d ~~~ Permit Ap oval O Date: ~ See cover letter for other requirements Conditions of approval Sa pies required Yes ^ No ~ Mud log required Yes ^ No y rogen sulfidLe measures Yes ~ No ^ Directional survey required Yes ~ No ^ Other: '3 © S ~ Q ~"LS~ APPROVED BY ,~ - / ~j~^ Approved b : THE COMMISSION Date: (J (~.~ ~-" ~ a~~~~~At~ Form 10-401 Revised 06/2004 ~ Submit in Duplicate ConocoPhillips Conoco/Phillips, Inc. Post Office Box 100360 Anchorage, Alaska 99510 December 2, 2005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333. West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill Surface Location: Top Productive Horizon: Bottom Hole Location: Dear Commissioner: • ~ECE~~lED o~c o ~ ~~o~ Alaxk~ Oil ~ ins ConSe ~Ott1ff11SSIQt) Anchorage 2T-203 4700' FNL, 4724' FEL, Sec. 1, T11N, R8E, UM 602' FNL, 188' FEL, Sec. 2, T11 N, R8E, UM 4503' FNL, 3498' FEL, Sec. 36, T12N, R8E, UM ConocoPhillips Alaska, Inc. hereby applies fora "Permit to Drill" for the producer well 2T-203. The well will be drilled and completed using Nordic Calista Rig #3. The planned spud date for 2T-203 is January 10 2006 although ConocoPhillips is considering moving this well ahead of 2T-208 which would bring the spud date forward to December 17 2005. The following logs are to be run on this well: GR/Res/Density/Neutron and possibly Lateralog if it is available. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be hauled for - treatmentand injection in an approved Prudhoe or GKA disposal well. The following people are the designated contacts for reporting responsibilities. to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25,070) 263-4612 B) Geologic Data and Logs Pat Perfetta, Geologist (20AAC 25.071) 263-4411 If you have any questions or require further information, please contact Phillip Hayden at (907) 265-6481. Sincerely, - < 1 --~. Randy Thomas Kuparuk Drilling Superintendent • Permit It -Tabasco Well #2T-203 Horizontal Application for Permit to Drill Document ~ation for Permit to Drill, Well 2T-203 Revision No.O Saved: 1-Dec-05 Mpxirriia~ Well Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(~) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9)-~-~ ............................................................................................... 5 10 . Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11 . Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ..........................................................................:..................... 5 12 . Evidence of Bonding ..........................,..................................................... ....... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program ..................................................................................... 5 ORIGINAL °~°°" • /~ition for Permit to Drill, Well 2T-203 Revision No.O Saved: 1-Dec-05 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ......................................................................................:......... 6 15. Attachments ............................................................................................................. 7 Attachment 1 Directional Plans - 2T--203 (16 pages) ............................................................................ 7 Attachment 2 Drilling Hazards Summary (2 page) ................................................................................ 7 Attachment 3 Cement Loads and CemCADE Summary (2 pages) ...................................................... 7 Attachment 4 Well Schematic (1 page) ................................................................................................. 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each we/1 must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a wel/ with mu/tiple well branches, each branch must similarly be identi/ed by a unique name and API number by adding a suffix to the name designated for the wel/ by the operator and to the number assigned to the well by the CQmmiSSton. The well for which this application is submitted will be designated as 2T-203. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied 6y each of the following items, except for an t"rein already on file with the commission and identified in the application; (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (S) the coordinates of the proposed location of the we/l at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration, (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4700' FNL 4724' FEL, Sec 1 T11N R8E UM ~ NGSCoordinates ~ RKBE/evation 110.2 AMSL Northings: 5970560.23 Eastings: 498944.61 ' Pad E/evation 80.2 AMSL Location at Top of Productive Interval Tabasco 602 FNL, 188' FEL, Section 2, T11N, R8E, UM NGS Coordinates Measured De th, RKB.• 6113 Northings: 5974657.36 Eastings: 498199.10 Tota/ ~ertica/ De th, RKB: 3092 Tota/ vertical De th, SS.• 2982 Location at Total De th 4503 FNL 3498' FEL Section 36 T12N, R8E, UM NGS Coordinates Measured De th, RKB: 8518 North/ngs: 5976037 Eastings: 500168 Tota/ t/ertica/ De th, RKB; 3105 Tota/ t/ertica/ De th, 'SS.• 2995 and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) Ifa we// is to be intentionally deviated, the application far a Permit to I)rt"/l (Form 10-401) must (1) inc/ude a plat, drawn to a suitab/e scale, showing the path of the proposed we//bore, incfuding atl adjacent wel/bores within 200 feet of any portion of the proposed we/I; Please see Attachment 1: Directional Plan for the well bore to be completed (2T-203). and Page 2 of 7 ~. /~ation for Permit to Drill, Well 2T-203 Revision No.O Saved: 1-Dec-05 (2) for al/ wells within 200 feet of the proposed welibore (A) list the names of the operators of those we/!s, to the extent that those names are known or disco~erabfe in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the on/y affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to tJri// must be accompanied by each of the fallowing items, except for an item a/ready on fr/e with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPEJ as required by 20 AAC25, 035, 20 AAC25.03b, or 20 AAC 25.037, as app/icable; The BOPE will consist of an 11" x 5M BOP stack and 21 ~/a" 2M Diverter with 16" line. Please see information on the Nordic Calista Rig #3 blowout prevention equipment placed on file with the Commission. ConocoPhillips plans to arrange the BOPs as follows: Annular 4" Pipe Rams Blinds 7 5/8" Casing Rams 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to brill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application. (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maxirtaum potentia/surface pressure based on a methane gradient; The expected reservoir pressures in the Tabasco sands in the 2T-203 area vary from 0.25 to 0.33 psi/ft, i or 4.9 to 6.3 ppg EMW (equivalent mud weight). The .pressure data was estimated using information from downhole gauges in the field. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the deepest penetration of the Tabasco formation is 685 psi, calculated as follows: MPSP = (3111 ft)(0.33 - 0.11 psi/ft) = 685 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia! causes of ho% problams such as abnarma/ly gea pressured strata, lost eireu/titian zones, and zones that have a propensity for differentia! sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/icatian for a Permit to Urif/ must be accompanied by each of the following items, except far an item already on Fle with the commission and identified in the app/ication: (s) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); All Formation Integrity Tests (FIT) will be performed in accordance with the LOT /FIT procedure that ConocoPhillips Alaska has on file with the Commission. An FIT will be performed after setting the 10 3/a" surface casing. A Dynamic" FIT will be performed after drilling out the 7 5/8" casing. This dynamic test Page 3 of 7 ~tion for Permit to Drill, Well 2T-203 Revision No.O Saved: 1-Dec-05 will consist of circulating at the highest expected pump rate with the drill-out fluid in the hole while monitoring the well for losses. After this test the fluid will be swapped over to the reservoir drill in fluid. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dril/ must be accompanied by each of the fallowing items, except far an item already an file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a descriptian of any slotted Inver, pre- perforated liner, ar screen to be insta/led; Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD (RKB) MD/TVD (RKB) OD in in Ib/ft Grade Connection ft ft ft Cement Pro ram 16 24 152 X-65 Welded 77 0 / 0 107 / 107 Driven to 77'. Cemented from 35' with 150 sx ASI. 10 3/a 13 ~/z 45.5 L-80 BTC, AB 1710 0 / 0 1710/1553 Cement to Modified Surface with 390 sx ASLite Lead, 340 sx ASI Tail 7 5/8 9 7/8 29.7 L-80 BTC, AB 6162 0 / 0 6162/3094 440 sks Modified DeepCRETE 4 '/z 6 3/4 12.6 13CR VAM Top 2758 5760 / 3062 8518 / 3105 NA /Screens & blank i e See also Attachment 3: Cement Loads and CemCADE Summary. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applr`catian for a Permit to ®rr`ll must be accompanied by each of the fof/awing items, except for an r"tem a/ready on file +-vith the commissioon and identified in the application: (7) a diagram and descriptian of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21 ~/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 2T-203. Please see diagrams of the Nordic Calista Rig #3 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (8) a dril/ing fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Surface Drilling will be done with a bentonite based mud system, the intermediate hole with an LSND type mud system and the production hole with MI's Flo-Pro mud system. Drilling will be done having the following approximate properties over the listed intervals: S ud to Base of Permafrost Intermediate Ho% Section Production Interval Initial Value Final Value Density (ppg) g,5 10.0 8.9 - 9.2 9.1 - 9.3 Funnel Viscosity seconds +150 +65 40-50 Plastic Viscosity c 8_12 Yield Point cP 30-50 15-30 24-30 26-30 ORIGINAL Page 4 of 7 /~ation for Permit to Drill, Well 2T-203 Revision No.O Saved: 1-Dec-05 pH 8.5-9 8.5-9 8.5-9 9-9.5 API Filtrate(cc) g 5.5-8 4-6 4-6 Chlorides (mg/q <500 <500 <500 35000 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nordic Calista Rig #3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dri/I must be accompanied by each of the fo/lover"ng items, except for an item a/ready on fi/e with the commission and identified in the app/ication; (9) for an exploratory or stratigraphic test we/l, a tabulation setting aut the depths of predicted abnormal/y geo pressured strata as required by 20 AAC25.033(>7; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on fr/e with the commission and identified in the app/ication; (10) for an exploratory ar stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to t7ri/l must be accompanied by each of the fol%wing items, except far an item a/ready an file with the Commlesion and identified in the app/ication; (ZZ) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed conditians as required by 20 AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to ©ril! must be accompanied by each of the following items, except for an item a/ready on file with the commission and identfied in the application; (12) evidence showing that the requirements of20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on .file with the Commission. 13. Proposed Drilling Program. Requirements of 20 AAC 25.005 (c)(13) An app/ication for a Permit to Drill must be accompanied by each of the fo1/owing items, except for an item a/ready on file with the commission and identified in the application; The proposed drilling program is listed below. Please refer as well to Attachment 4, Well Schematic. 1. Move In /Rig Up Nordic Calista Rig #3. 2. Provide 24 hour notice to AOGCC inspectors to witness diverter test and pending spud of well. Nipple up and function test the Diverter System. Prepare spud mud. 3. Spud and directionally drill surface hole to (1710' MD / 1553' TVD (below base of the permafrost) as per the directional plan. Run MWD tool as required for directional monitoring. 4. Condition mud & hole for running casing. POOH. 5. Run & cement 10 3/a" casing to surface. Displace cement with mud. Perform top job if required. ORIGINAL ~_~~ • ~tion for Permit to Drill, Well 2T-203 Revision No.O Saved: 1-Dec-05 6. Remove diverter system and install wellhead & test. Install & test 11" x 5,000 psi BOP's and test to 3000 psi. (Note that this test pressure is less than the working pressure of the BOP). Notify AOGCC 24 his before test. 7. Prepare LSND mud system for intermediate hole section. 8. PU 9 7/8" PDC bit & drilling assembly with MWD/LWD (GR/RES). RIH, clean out casing to top of float equipment. Pressure test casing to 2500 psi and record results. 9. Drill out float equipment and 20 ft of new hole. Perform LOT or FIT recording results. 10. Directionally drill intermediate hole to 6162 ft MD / 3094 ft TVD. ' 11. Condition mud & hole for running casing. POOH. 12. Run & cement 7 5/8" casing. 13. PU 6 3/a" PDC bit, motor, MWD/LWD (GR/RES/DENS/NEU & LAT if available) and remaining BHA components. RIH to top of float equipment. 14. Pressure test casing string to 3500 psi and record results. 15. Drill out float equipment and clean the rat hole. 16. Swap out LSND mud with Flo-Pro mud system. 17. Drill Horizontal production hole to 8518' MD / 3105' TVD. ' 18. Condition mud & hole as required for running completion screens. Displace to brine. 19. POOH and LD excess drillpipe. 20. RIH with clean out assembly. Pump wash pills as necessary. Condition brine. POOH. 21. RIH with 4 ~/z" screens, 2 7/8" inner string and liner hanger on drillpipe. 22. Set hanger and packer. Spot Wellzyme /Acid Flush across screen / wellbore annular space. POOH w/ DP and inner string. 23. Run ESP pump and GLM's on 4 ~/z" tubing. Land tubing. 24. ND BOPS/NU Tree, freeze protect, RD, Release rig. 14. Discussion of Mud and. Cuttings Disposal and Annular Disposal. Requirements of 20 AAC 25.005 (c)(14) An app/ication for a Permit to Dri/! must be accompan/ed 6y each of the fo/%wing items, except for an item already on f/e with the commission and identified in the application: (i4) a genera/ description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator inter7ds to request authorization under ZO AAC 25.080 for an annu/ar disposa/operation G~ the we/!.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class ~ II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage there and eventual processing for injection down an approved disposal well. Page 6 of 7 ~? R I ~11~~L tion for Permit to Drill, Well 2T-203 Revision No.O Saved: 1-Dec-05 At the end of drilling operations, an application may be submitted to permit 2T-203 for annular disposal of fluids occurring as a result of future drilling operations on 2T pad 15. Attachments Attachment 1 Directional Plans - 2T--203 (16 pages) Attachment 2 Drilling Hazards Summary (2 page) Attachment 3 Cement Loads and CemCADE Summary (2 pages) Attachment 4 Well Schematic (1 page) ORIGINAL °"'~' • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2T Pad Plan: 2T-203 Plan 2T-203 Plan: 2T-203wp05 Proposal Report 14 November, 2005 HALL~~I.~RTt~N Sperm Qri~ling S-er~rces ORIGINAL ` ~Vnd~d~~"'p~ Calwlatlon Method: Mlnlmum Curvature Error System: ISCWSA Seen MNfgd: Trev. Cylkider North Error Surface: Elllp[I ~~on~° Warnk Mefiad: Rules Based Project: Kuparuk River Unit rn~~1" Y M1Ll g GWdarlc Datum: NAD 7927 (NADCON CONUS) Site: Ku aruk 2T Pad p Magnetk Model: BGGM2005 Plan 2T-203 Well: Plan 2T-203 HAL.L.IBURTON """`'-e`'n1 8020 RKB. Planned RKB ,: ', ._. .... Sperry Drilling Services ~.,rthing~ASP Y: :87056023 ~s,a,~yASRx: ~aaw.6, Plan: 2T-203wp05 _ 0 SHL@4700ftFNL&4724ftFEL-Sect-T11N-R08E ' KOP :Build @ 3°I100ft , 290ft MD, 290ft ND ' 600 ~ Continue Build @ 4°/100ft , 957ft MD, 943ft ND O O 12 10 3/4" ~ -131/2" Hole ~ 00 Q 10 3l4" CSG @ 1710ft MD,1553ft ND ~ d / ~ ~ Sail @ 52.5°Inc & 315°Azi : 1770ft MD,1590ft ND Per mafrost R V 1800 Top Ugnu C Continue Dir @ 4°/100ft,1970ft MD,1712ft ND ~ m 3 Sail @ 68.84°Inc 8t 345.84°Azi : 2751ft MD, 2100ft ND L Top West Sak D Continue Dir @ 4°/100ft, 4481ft MD, 2725ft ND 7 5/8"Csg - 9 7/8" Hole 7 5/8" CSG @ 6162ft MD, 3094ft ND; 571 ft FNL & 1498 FEL -Sect - 711 N - R08E Base West Sak Target (Heel); 6247' MD, 3095' ND Target (T2); 7389' MD, 3107' ND 41/2" Csg - 6 314" Hole i ~ Target (T1); 6789' MD, 3110' ND Target (T3); 7890' MD, 3089' ND 2T-203wp05 Tabasco Target (Toe); 8518' MD, 3105' ND, 4503' FNL 8~ 3498' FEL; Sec36-T12N-R08E .. -600 0 600 1200 1800 2400 3000 3600 4200 Vertical Section at 55.00° (600 ft/in) ~,. GaruHtlm Metlwd: Mlninum Curvature ~~ '~ ~ E^°s,~,^ '~"'S" srenMplnd. rre~. u°m Pro ect: Ku aruk River Unit 1 P ~~Sr d~~Q' f ~ w °,~,E',~i~; Site: Kuparuk 2T Pad ,n;~i~,}sz MM«~ JCON`~' Well: plan 2T-203 Wellbore: plan 2T-203 HALLIE3URTOIV - - - - '° ` "` ` V 1F,i~~g ASP Y J&e 2 Plan: 2T-203wp05 Sperry Drilling Services Eastl^ansax asasas.a, C i ~ ~ ; °' ~. f '-' X50 ---_____._._ . __ 0 z i e +~'' ' '~00 __ _________ i 950 _ _ _ ' _ __ _._ e i i -3800 __~_._.____ ..__._.....41/2" Csg - 63/4" Hole _ _ ..__, _. Target (Tce); 8518' MD, 3105' ND, 4503' FNL & 3498' FEL; Sec36-T12N-R08E i Target (T3); 7890' MD, 3089' ND Target (T2); 7389' MD, 3107 ND Target (T1); 6789' MD, 3110' ND i~ Target (Heel); 6247' MD, 3095' ND 7518" CSG @ 61628 MD, 30948 ND; 571 ft FNL 81498 FEL -Sect - T11 N - 808E ~ 7518" Csg - 9 7/8" Hole !. Continue Dir @ 4°/100ft, 4481ft MD, 2725ft ND Sail @68.84°Inc 8345.84°Aa : 2751ft MD, 21008 ND ._ __ __. -- Continue Dir @ 4°/1008,19708 MD,1712ft ND i Sail @ 52.5°Inc 8 315°Azi :177bR MD,1590ft ND I 0314" CSG @ 17108 MD,1553R ND _ __ __..-~-- ___.___- _..__._h. -- ____---_ __-.- i 103/4" Csg -131/2" Hole ,~ Continue Build @ 4°/100ft , 957ft MD, 943ft ND OP :Build @ 3°/1008 , 2908 MD, 2908 ND _SHL@4700RFNL84724RFEL-Sect-T11N-R08E _ -2850 -1900 -950 0 950 1900 2850 083 0 West(-1/East(+1 (950 ft/inl Canoed hillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: Plan: 2T-203 Wellbore: Plan 2T-203 Design: 2T-203wp05 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBtJRTON Sperry Drilling Se~ces Well Plan: 2T-203 Planned RKB @ 11020ft (Nordic 3 (80.3+30)) Planned RKB @ 110.20ft (Nordic 3 (80.3+30)) True ~ Minimum Curvature ' Project Kuparuk River Unit, North Slope Alaska; United States Map System: US State Plane 1927 (6cact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well PIan:2T-203 Well Position +N/S 0.00 ft Northing: 5,870,560.23 ft ~ Latitude: 70° 19' 50.878" N +E!-W 0.00 ft Easting: 49$,944.$1 ft ~ Longitude: 150° 00' 30.817" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 80.20ft __ _ __ Wellbore Plan 2T-203 I Magnetics Model Name Sample Date Declination Dip Angte Field Strength BGGM2005 12/31/2005 24.00 80.76 57.545 j _ _ ---- Design 2T-203wp05 Audit Notes: Version: 1 Phase: PLAN Tie On Depth: 30.00 Vertical Section: Depth From (TVD) +NlS +FJ-W Direction II (ft) (ft) (ft) (°) L~ 30.00 0.00 0.00 55.00 _-1 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +FJ-W Rate Rate Rate TFO (ft) (°) (°) (ftj (ft} (ft) (°/100ft) (°1f00ftj (°1100ftJ (°} 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0,00 290.00 0.00 0.00 290.00 0.00 0.00 0.00 0.00 0.00 0.00 956.67 20.00 315.00 943.21 81.44 -81.44 3.00 3.00 0.00 315.00 1,769.66 52.52 315.00 1,590.00 416.91 -416.91 4.00 4.00 0.00 0.00 1,969.66 52.52 315.00 1,711.70 529.13 -529.13 0.00 0.00 0.00 0.00 2,750.54 68.84 345.84 2,099.84 1,115.89 -845.18 4.00 2.09 3.95 67.21 4,481.41 68.84 345.84 2,724.50 2,681.05 -1,240.10 0.00 0.00 0.00 0.00 6,247.18 89.75 55.11 3,095.20 4,179.10 -639.26 4.00 1.18 3.92 82.47 6,293.56 88.36 55.13 3,095.97 4,205.61 -601.22 3.00 -3.00 0.04 179.22 6,789.78 88.36 55.13 3,110.20 4,489.19 -194.26 0.00 0.00 0.00 0.00 6,858.00 90.40 55.11 3,110.94 4,528.20 -138.30 3.00 3.00 -0.03 -0.63 7,389.62 90.40 55.11 3,107.20 4,832.30 297.74 0.00 0.00 0.00 0.00 7,448.27 92.16 55.16 3,105.89 4,865.81 345.85 3.00 3.00 0.09 1.77 7,890.72 92.16 55.16 3,089.20 5,118.38 708.74 0.00 0.00 0.00 0.00 8,026.16 88.10 55.05 3,088.89 5,195.85 819.81 3.00 -3.00 -0.08 -178.38 8,518.04 88.10 55.05 3,105.20 5,477.49 1,222.74 0.00 0.00 0.00 O.QO 11/f 4/2005 3:38t38PM Page 2 of 7 COMPASS 2003.11 Build 50 ConocoPhllips Alaska Database: EDM 2003.11 Single UserDb Company: Conoco Phillips Alaska (Kuparuk) Project: Kuparuk River Unit Ske: Kuparuk 2T Pad Well: Plan: 2T-203 Wellbore: Plan 2T-203 Design: 2T-203wp05 Planned Survey 2T-203wp05 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBURTGN Sperry Drilling SeMc~s Well Plan: 2T-203 Planned RKB @ 11 Q20ft (Nordic 3 (80.3+30)} Planned RKB @ 110.20ft (Nordic 3 (80.3+30)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +NIS +E!-W Northing Easting DLSEV Vert Section (ft) (~) (°1 (ft) (ft) (ft) (ft) eft) (ft) (°/100ft} (ft) 30.00 0.00 0.00 30.00 -80.20 0.00 0.00 5,970,560.23 498,944.61 0.00 0.00 SHL @ 4700ft PNL & 4724ft FEL -Sec 1 - T71N - R08E 100.D0 0.00 0.00 100.00 -10.20 0.00 0.00 5,970,560.23 498,944.61 0.00 0.00 200.00 0.00 0.00 200.00 89.80 0.00 0.00 5,970,560.23 498,944.61 0.00 0.00 290.00 0.00 0.00 290.00 179.80 0.00 0.00 5,970,560.23 498,944.61 0.00 0.00 KOP : Build ~ 3°/1008 , 290ft MD, 2908 TVD 3D0.00 0.30 315.00 300.00 189.80 0.02 -0.02 5,970,560.25 498,944.59 3.00 0.00 400.00 3.30 315.00 399.94 289.74 2.24 -2.24 5,970,562.47 498,942.37 3.00 -0.55 500.00 6.30 315.00 499.58 389.38 8.16 -8.16 5,970,568.39 498,936.46 3.OD -2.00 600.00 9.30 315.00 598.64 488.44 17.75 -17.75 5,970,577.98 498,926.86 3.00 -4.36 700.00 12.30 315.00 696.86 586.66 31.00 -31.00 5,970,591.23 498,913.62 3.00 -7.61 800.00 15.30 315.00 793.96 683.76 47.86 -47.86 5,970,608.10 498,896.76 3.00 -11.75 900.00 18.30 315.00 889.68 779.48 68.30 -68.30 5,970,628.53 498,876.33 3.00 -16.77 956.67 20.00 315.00 943.21 833.01 81.44 -81.44 5,970,641.68 498,863.19 3.00 -20.00 Continue Build ~ 4°/100ft , 957ft MD, 943ft TVD 1,000.00 21.73 315.00 983.70 873.50 92.36 -92.36 5,970,652.59 498,852.27 4.00 -22.68 1,100.00 25.73 315.00 1,075.22 965.02 120.81 -120.81 5,970,681.05 498,823.83 4.00 -29.67 1,200.00 29.73 315.00 1,163.72 1,053.52 153.71 -153.71 5,970,713.95 498,790.94 4.00 -37.75 1,300.00 33.73 315.00 1,248.75 1,138.55 190.89 -190.89 5,970,751.13 498,753.76 4.00 -46.88 1,400.00 37.73 315.00 1,329.91 1,219.71 232.18 -232.18 5,970,792.42 498,712.48 4.00 -57.02 1,500.00 41.73 315.00 1,406.80 1,296.60 277.37 -277.37 5,970,837.61 498,667.30 4.00 -68.12 1,556.49 43.99 315.00 1,448.20 1,338.00 304:54 -304.54 5,970,864.78 498,640.14 4.00 -74.79 Permafrost 1,600.00 45.73 315.00 1,479.04 1,368.84 326.24 -326.24 5,970,886.49 498,618.44 4.00 -80.12 1,700.00 49.73 315.00 1;546.28 1,436.08 378.56 -378.56 5,970,938.81 498,566.14 4.00 -92.97 1,710.00 50.13 315.00 1,552.72 1,442.52 383.97 -383.97 5,970,944.22 498,560.73 4.00 -94.29 10 3/4" CSG @ f 710ft MD, 1553ft TVD -10 314" Csg - 1 3 112" Hole 1,769.66 52.52 315.00 1,590.00 1,479.80 416.91 -416.91 5,970,977.15 498,527.80 4.00 -102.38 Sail @ 52.5°Inc & 315°Azi : 1774ft MD, 1590ft TVD 1,800.00 52.52 315.00 1,608.46 1,498.26 433.93 -433.93 5,970,994.18 498,510.78 0.00 -106:56 1,870.24 52.52 315.00 1,651.20 1,541.00 473.35 -473.35 5,971,033.59 498,471.38 0.00 -116.24 Top Ugnu C 1,900.00 52.52 315.00 1,669.31 1,559.11 490.04 -490.04 5,971,050.29 498,454.68 0.00 -120.34 1,969.66 52.52 315.00 1,711.70 1,601.50 529.13 -529.13 5,971,089.39 498,415.60 0.00 -129.94 Continue Dir ~ 4°/700ft, 1970ft MD, 1712ft TVD 2,000.00 53.00 316.40 1,730.06 1,619.86 546.42 -546.00 5,971,106.67 498,398.74 4.00 -133.84 2,100.00 54.69 320.89 1,789.07 1,678.87 607.02 -599.29 5,971,167.27 498,345.46 4.00 -142.74 2,200.00 56.54 325.19 1,845.57 1,735.37 672.96 -648.86 5,971,233.21 498,295.91 4.00 -145.52 2,300.00 58.53 329.31 1,899.27 1,789.07 743.90 -694.46 5,971,304.15 498,250.33 4.00 -142.18 2,400.00 60.64 333.24 1,949.91 1,839.71 819.51 -735.86 5,971,379.77 498,208.94 4.00 -132.73 2,500.00 62.87 337.01 1,997.24 1,887.04 899.42 -772.87 5,971,459.67 498,171.94 4.00 -117.21 2,600.00 65.19 340.64 2,041.04 1,930.84 983.24 -805.31 5,971,543.49 498,139.52 4.00 -95.71 2,700.00 67.60 344.12 2,081.09 1,970.89 1,070.56 -833.02 5,971,630.80 498,111.83 4.00 -68.32 2,750.54 68.84 345.84 2,099.84 1,989.64 1,115.89 -845.18 5,971,676.13 498,099.68 4.00 -52.28 Sail @68.84° Inc &345.84°Azi : 2751ft MD, 2100ft TVD 2,800.00 68.84 345.84 2,117.69 2,007.49 1,160.61 -856.46 5,971,720.85 498,088.40 0.00 -35.87 fi/f4/2005 3:38i38PM Page 3 of 7 COMPASS 2003.1 f Build 50 ~~~G1~AC. `-' Sperry Drilling Services o P C ~lli HALLIBURT~N on co ps h Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 2T-203 Company: ConocoPhillips Alaska (Kuparuk] TVD Reference: Planned RKB @ 11Q20ft (Nordic 3 (80.3+30)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 110.20ft (Nordic 3 (80.3+30)) Site: Kuparuk 2T Pad North Reference: True Well: Plan: 2T-203 Survey Calculation Method: Minimum Curvature Wellbore: Plan 2T-203 Design: 2T-203wp05 ' Planned Survey 2T-203wp05 Map Map MD Inclination Azimuth TVD SSTVD +N/S +E/-W Northing Easting DLSEV Vert Section '~ (ft) {°) (°) (fti (ft) (ftJ (ft) (ft1 lft) (°/100ft) {fti 2,900.00 68.84 345.84 2,153.78 2,043.58 1,251.04 -879.28 5,971,811.27 498,065.60 0.00 -2.70 3,000.00 68.84 345.84 2,189.87 2,079.67 1,341.46 -902.09 5,971,901.69 498,042.80 0.00 30.48 3,100.00 68.84 345.84 2,225.96 2,115.76 1,431.89 -924.91 5,971,992.11 498,019.99 0.00 63.66 3,125.60 68.84 345.84 2,235.20 2,125.00 1,455.04 -930.75 5,972,015.26 498,014.16 0.00 72.15 Top West Sak D 3,200.00 68.84 345.84 2,262.05 2,151.85 1,522.32 -947.73 5,972,082.53 497,997.19 0.00 96.83 3,300.00 68.84 345.84 2,298.14 2,187.94 1,612.74 -970.54 5,972,172.95 497,974.39 0.00 130.01 3,400.00 68.84 345.84 2,334.23 2,224.03 1,703.17 -993.36 5,972,263.37 497,951.59 0.00 163.18 3,500.00 68.84 345.84 2,370.32 2,260.12 1,793.60 -1,016.18 5,972,353.79 497,928.79 0.00 196.36 3,600.00 68.84 345.84 2,406.41 2,296.21 1,884.02 -1,038.99 5,972,444.21 497,905.98 0.00 229.54 3,700.Q0 68.84 345.84 2,442.50 2,332.30 1,974.45 -1,061.81 5,972,534.63 497,883.18 0.00 262.71 3,800.00 68.84 345.84 2,478:59 2,368.39 2,064.88 -1,084.63 5,972,625.05 497,860.38 0.00 295.89 I 3,900.00 68.84 345.84 2,514.68 2,404.48 2,155.30 -1,107.44 5,972,715.47 497,837.58 0.00 329.07 4,000.00 68.84 345.84 2,550.77 2,440:57 2,245.73 -1,130.26 5,972,805.89 497,814.78 0.00 362.24 4,100.00 68.84 345.84 2,586.85 2,476.65 2,336.16 -1,153.08 5,972,896.31 497,791.98 0.00 395.42 4,200.00 68.84 345.84 2,622.94 2;512.74 2,426.58 -1,175.89 5,972,986.73 497,769.17 0.00 428.59 4,300.00 68.84 345.84 2,659.03 2,548.83 2,517.01 -1,198.71 5,973,077.16 497,746.37 0.00 461.77 4,400.00 68.84 345.84 2,695.12 2,584.92 2,607.44 -1,221.53 5,973,167.58 497,723.57 0.00 494.95 4,481.41 68.84 345.84 2,724.50 2,614.30 2,681.05 -1,240.10 5,973,241.18 497,705.01 0.00 521.95 Continue Dir @ A°l100ft, 4481ft MD, 2725ft TVD 4,500.00 68.94 346.63 2,731.20 2,621.00 2,697.90 -1,244.23 5,973,258.03 497,700.88 4.00 528.24 4,539.17 69.17 348.29 2,745.20 2,635.00 2,733.60 -1,252.17 5,973,293.73 497,692.95 4.00 542.21 Base West Sak 4,600.00 69.54 350.86 2,766.65 2,656.45 2,789.58 -1,262.47 5,973,349.71 497,682.66 4.00 565.88 4,700.00 70.24 355.05 2,801.05 2,690.85 2,882.75 -1,273.98 5,973,442.87 497,671.17 4.00 609.90 4,800.00 71.03 359.21 2,834.22 2,724.02 2,976.95 -1,278.69 5,973,537.06 497,666.47 4.00 660.07 4,900.00 71.92 3.32 2,866.01 2,755.81 3,071.72 -1,276.58 5,973,631.82 497,668.59 4.00 716.15 5,000.00 72.89 7.39 2,896.25 2,786.05 3,166.60 -1,267.68 5,973,726.69 497,677.51 4.00 777.87 5,100.Q0 73.94 11.42 2,924.80 2,814.60 3,261.12 -1,252.01 5,973,821.20 497,693.19 4.00 844.92 5,200.00 75.07 15.40 2,951:53 2,841.33 3,354.83 -1,229.65 5,973,914.90 497,715.55 4.00 916.98 5,300.00 76.26 19:34 2,976.29 2,866.09 3,447.28 -1,200.72 5,974,007.33 497,744.50 4.00 993.70 5,400.00 77.52 23.24 2,998.98 2,888.78 3,538.00 -1,165.35 5,974,098.04 497,779.87 4.00 1,074.71 5,500.00 78.83 27.10 3,019.48 2,909.28 3,626.56 -1,123.72 5,974,186.58 497,821.51 4.00 1,159.61 5,600.00 80.19 30.93 3,037.68 2,927.48 3,712:52 -1,076.03 5,974,272.53 497,869.21 4.00 1,247.98 5,700.00 81.60 34.72 3,053.51 2,943.31 3,795.48 -1,022.51 5,974,355.47 497,922.73 4.00 1,339.40 5,800.00 83.04 38.49 3,066.88 2,956.68 3,875.01 -963.43 5,974,434.99 497,981.82 4.00 1,433.42 5,828.20 83.45 39:55 3,070.20 2,960.00 3,896.77 -945.80 5,974,456.74 497,999.46 4.00 1,460.34 2T-203wp01 T1 {E flank well) 5,900.00 84.51 42.23 3,077.73 2,967.53 3,950.74 -899.06 5,974,510.71 498,046.19 4.00 1,529.59 5,988.62 85.83 45.53 3,08520 2,975.00 4,014.38 -837.86 5,974,574.33 498,107.40 4.00 1,616.22 2T-203 T2 {wp02) 6,000.00 86.00 45.95 3,086.01 2,975.81 4,022.30 -829.73 5,974,582.25 498,115.53 3.99 1,627.42 6,069.00 87.04 48.52 3,090.20 2,980.00 4,069.06 -779.17 5,974,628.99 498,166.09 4.00 1,695.65 27-203wp01 Weel (E flank well) 6,100.00 87.51 49.66 3,091.67 2,981.47 4,089.34 -755.77 5,974,649.27 498,189.49 4.00 1,726.46 6,112.58 87.70 50.13 3,092.20 2,982.00 4,097.43 -746.16 5,974,657.36 498,199.10 4.01 1,738.97 Tabasco 11/i4/2005 338i38PM Page 4 of 7 COMPASS 2003.11 Build 50 ORIGINAL ConoCOPhillips Alaska Sperry Drilling Services Planning Report -Geographic Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: Plan: 2T-203 Wellbore: Plan 2T-203 Design: 2T-203wp05 ', Planned Survey 2T-203wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBtJRTON Sperry Drilling Services Well Plan: 2T-203 Planned RKB @ 11020ft (Nordic 3 (50.3+30)) Planned RKB @ 11020ft (Nordic 3 (80.3+30)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/S +EI-W Northing Easting DLSEV Vert Section {ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/t00ft1 (ft} 6,162.00 88.45 51.96 3,093.86 2,983.66 4,128.49 -707.75 5,974,688.40 498,237.51 4.00 1,788.25 7 5/8" CSCa @ 8182ft MD, 3094ft TVD; 571ft FNL & 149ft FEL -Sect - T11N - R08E - 7 5/8" Csg - 9 7/8" Hoie 6,200.00 89.03 53.37 3,094.70 2,984.50 4,151.53 -677.54 5,974,711.44 498,267.72 4.00 1,826.21 6,247.18 89.75 55.11 3,095.20 2,985.00 4,179.10 -639.26 5,974,739.00 498,306.00 4.00 1,873.38 Target (Heel }; 8247 MD, 3095' TVD - 2T -203wp05 Heel - 27-203 Heel (wp04) 6,293.56 88.36 55.13 3,095.97 2,985.77 4,205.61 -601.22 5,974,765.51 498,344.04 3.00 1,919.75 6,300.00 88.36 55.13 3,096.15 2,985.95 4,209.29 -595.94 5,974,769.19 498,349.32 0.00 1,926.19 6,400.00 88.36 55.13 3,099.02 2,988.82 4,266.44 -513.93 5,974,826.32 498,431.33 0.00 2,026.15 6,441.13 88.36 55.13 3,100.20 2,990.00 4,289.95 -480.19 5,974,849.82 498,465.07 0.00 2,067.26 2T-203wp01 Heel - 2T-203wp01 Toe (E flank well) 6,500.00 88.36 55.13 3,101.89 2,991.69 4,323.59 -431.92 5,974,883.45 498,513.35 0.00 2,126.10 6,600.00 88.36 55.13 3,104.76 2,994.56 4,380.74 -349.90 5,974,940.58 498,595.36 0.00 2,226.06 6,615.46 88.36 55.13 3,105.20 2,995.00 4,389:57 -337.23 5,974,949.41 498,608.03 0.00 2,241.51 2T-203 T3 (wp02) - 2T-203 Toe (wp03) 6,700.00 88.36 55.13 3,107.62 2,997.42 4,437.88 -267.89 5,974,997.71 498,677.37 0.00 2,326.02 6,789.78 88.36 55.13 3,110.20 3,000.00 4,489.19 -19426 5,975,049.00 498,751.00 0.00 2,415.77 Target (T1); 8789' MD, 311 0' TVD - 2T-203wp05 T7 - 2T-203 T1 (wp02) 6,800.00 88.66 55.13 3,110.47 3,000.27 4,495.03 -185.88 5,975,054.84 498,759.38 2.99 2,425.98 6,858.00 90.40 55.11 3,110.94 3,000.74 4,528.20 -138.30 5,975,088.00 498,806.96 3.00 2,483.98 6,900.00 90.40 55.11 3,110.64 3,000.44 4,552.22 -103.86 5,975,112.01 498,841.41 0.00 2,525.97 7,000.00 90.40 55.11 3,109.94 2,999.74 4,609.43 -21.83 5,975,169.20 498,923.43 0.00 2,625.97 7,100.00 90.40 55.11 3,109.24 2,999.04 4,666.63 60.19 5,975,226.38 499,005.45 0.00 2,725.97 7,200.00 90.40 55.11 3,108.53 2,998.33 4,723.83 142.21 5,975,283.57 499,087.47 0.00 2,825.97 7,300.00 90.40 55.11 3,107.83 2,997.63 4,781.03 224.23 5,975,340.75 499,169.49 0.00 2,925.96 7,389.62 90.40 55.11 3,107.20 2,997.00 4,832.30 297.74 5,975,392.00 499,243.00 0.00 3,015.58 Target (T2}; 7389' MD, 3107 TVD - 2T-203wp05 T2 7,400.00 90.71 55.12 3,107.10 2,996.90 4,838.23 306.25 5,975,397.93 499,251.51 2.99 3,025.96 7,44827 92.16 55.16 3,105.89 2,995.69 4,865.81 345.85 5,975,425.51 499,291.11 3.00 3,074.21 7,500.00 92.16 55.16 3,103.94 2,993.74 4,895.34 388.27 5,975,455.03 499,333.53 0.00 3,125.91 7,600.00 92.16 55.16 3,100.16 2,989.96 4,952.42 470.29 5,975,512.09 499,415.55 0.00 3,225.84 7,700.00 92.16 55.16 3,096.39 2,986.19 5,009.51 552.31 5,975,569.16 499,497.57 0.00 3,325.76 7,800.00 92.16 55.16 3,092.62 2,982.42 5,066.59 634.33 5,975,626.23 499,579.59 0.00 3,425.69 7,890.72 92.16 55.16 3,089.20 2,979.00 5,118.38 708.74 5,975,678.00 499,654.00 0.00 3,516.35 Target (T3); 78$0' MD, 3089' TVD - 2T-203wp05 T3 7,900.00 91.88 55.15 3,088.87 2,978.67 5,123.68 716.35 5,975,683.30 499,661.61 2.99 3,525.62 8,000.00 88.89 55.07 3,088.20 2,978.00 5,180.87 798.37 5,975,740.47 499,743.63 3.00 3,625.61 8,026.16 88.10 55.05 3,088.89 2,978.69 5,195.85 819.81 5,975,755.44 499,765.06 3.00 3,651.76 8,100.00 88.10 55.05 3,091.34 2,981.14 5,238.13 880.29 5,975,797.71 499,825.55 0.00 3,725.56 8,200.00 88.10 55.05 3,094.65 2,984.45 5,295.38 962.21 5,975,854.95 499,907.47 0.00 3,825.50 8,300.00 88.10 55.05 3,097.97 2,987.77 5,352.64 1,044.13 5,975,912.19 499,989.39 0.00 3,925.45 8,400.00 88.10 55.05 3,101.29 2,991.09 5,409.90 1,126.04 5,975,969.43 500,071.30 0.00 4,025.39 8,500.00 88.10 55.05 3,104.60 2,994.40 5,467.16 1,207.96 5,976,026.67 500,153.22 0.00 4,125.34 8,518.04 88.10 55.05 3,105.20 2,995.00 5,477.49 1,222.74 5,976,037.00 500,168.00 0.00 4,143.37 Target (Toe}; 6518' MD, 31 05' TVD, 4503' FNL $ 3498' FEL; Sec36-T12N-R08E - 4 1 !2" Csg - 8 3f4 " Hole - 2T-203wp05 Tce i 11/14/2005 3:38:38PM Page 5 of 7 COMPASS 2003.11 Build 50 ORIGINAL ~ Sperry Drilling Services Con P ~li HALLIBUR TON oco ho ps Planning Report - Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 2T-203 Company: ConocoPhillips Al aska (Kuparuk) TVD Reference: Planned RKB @ 110. 20ft (Nordic 3 (80.3+30)) Project: Kupanik River Un it MD Reference: Planned RKB @ 110. 20ft (Nordic 3 (80.3+30)) Site: Kuparuk 2T Pad North Reference: True Well: Plan: 2T-203 Survey Calculation Method: Minimum Curvature Wellbore: Plan 2T-203 Design: 2T-203wp05 __ Geologic Targets Plan 2T-203 TVD Target Name +N/-S +E(-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,107.20 2T-203wpO5T2 4,832.30 297.74 5,975,392.00 499,243.00 - Point 3,095.20 2T-203 Hee! (wp04) 4,179.10 -639.26 5,974,739.00 498,306.00 - Point 3,089.20 2T-203wp05 T3 5,118.38 708.74 5,975,678.00 499,654.00 - Point 3,070.20 2T-203wp01 T1 (E flank well) 2,199.01 169.10 5,972,759.00 499,114.00 - Point 3,095.20 2T-203wp05 Heel 4,179.10 -639.26 5,974,739.00 498,306.00 - Point 3,110.20 2T-203 T1 (wp02) 4,844.30 315.74 5,975,404.00 499,261.00 - Point 3,105.20 2T-203wp05Tce 5,477.49 1,222.74 5,976,037.00 500,168.00 - Point 3,100.20 2T-203wp01 Tce (E flank well) 3,119.21 923.04 5,973,679.00 499,868.00 - Point 3,105.20 2T-203 T3(wp02) 5,489.52 1,409.76 5,976,049.00 500,355.00 - Point 3,090.20 2T-203wp01 Heel (E flank well) 1,302.90 -6.79 5,971,863.00 498,938.00 - Point ', 3,105.20 2T-203 Toe (wp03) 5,477.49 1,222.74 5,976,037.00 500;168.00 - Point 3,115.20 2T-203 Heel (wp02) 4,443.18 -264.26 5,975,003.00 498,681.00 - Point !~ 3,100.20 2T-203wp01 Heel 4,629.19 -307.29 5,975,189.00 498,638.00 - Point 3,110.20 2T-203wp05 T1 4,489.19 -194.26 5,975,049.00 498,751.00 - Point 3,125.20 2T-203 Toe (wp02) 5,854.62 1,905.76 5,976,414.00 500,851.00 - Point 3,150.20 2T-203wp01 Tce 6,089.63 1,782.71 5,976,649.00 500,728.00 - Point 3,085.20 2T-203 T2 (wp02) 5,184.41 871.75 5,975,744.00 499,817.00 - Point 11/f4/2005 3:38;38PM Page 6 of 7 COMPASS 2003.11 Build 50 r ~-' ' Sperry Drilling Services CQI'1t3CU ~ if~~1p5 Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2T Pad North Reference: Well: Plan: 2T-203 Survey Calculation Method: Wellbore: Plan 2T-203 Design: 2T-203wp05 Prognosed Casi ng Points HALLlBURTON Sperry Drilling Services Well Plan: 2T-203 Planned RKB @ 110.20ft (Nordic 3 (80.3+30)) Planned RKB @ 110.20ft (Nordic 3 (80.3+30)) True Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter eft) eft) ~~) ~") 1,710.00 1,552.72 103/4 13-1@ 6,162.00 3,093.86 7-5/8 9-7/8 8,518.03 3,105.20 4-1/2 63/4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +Nl-E +El-W l~) (°l (°) jftj (ft? (ftj Name 1,556.49 43.99 315.00 1,448.20 304.54 -304.54 Permafrost 1,870.24 52.52 315.00 1,651.20 473.35 -473.35 Top Ugnu C 3,125.60 68.84 345.84 2,235.20 1,455.04 -930.75 Top West Sak D 4,539.17 69.17 348.29 2,745.20 2,733.60 -1,252.17 Base West Sak 6,112.58 87.70 50.13 3,092.20 4,097.43 -746.16 Tabasco 11/14/2005 3:3838PM ORIGINAL COMPASS 2003.11 Build 50 • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2T Pad Plan 2T-203 Plan 2T-203 2T-203wp05 Anticollision Report 08 November, 2005 r-~,~,~~.~~ut~TC~nr Sherry [~ri!ling Services ORIGINAL C ~/~TrMy,ry yy!'1 ~L[ ~I Interp I t M th d: MD Interval 5051etlons Cal I t Melhad M Curv ~v , ~ Y./1 RV' 1 ~ ~ !!! 3 Dep1hR SI ~F m 3000 To 8518.04 E rMod 1 ISCWSA Maximum Range: 1048.BOd18058363 5 ~.~: "~ ~~~Ierl .~:Z',iN:(1 ', Error Surface Elhpbcal Conic ', Reference Wall: Plan: 2T-203wp05 Warning Method: Rulea Barad HALLIBURTON srle.eFVaoc12n31 Sperry Drilling Services Uate: 20U5-11-087OU: W:W lelitlated~. 1'es Version: I9eyth From Iteplhlo Sun'w/1'lur ld ,_w ,,, ~„~:;, 3U 00 120U.W 21 201apUS CO GYRO-SS w«.. a.,27.zoa v>,~i wet- W4i6ae. Ren }T 1U3 .. uva-n, ~mu.s. From Cslmr T~ MO - .e ~. - ... . ~. v.,.. ., a<mn-c .. um~a> -sr7o az ~~. -_. .n eE-+9~ic. n .r.sD SB~B.Sp!'~-.... ....- Critical Issues: C 0 z Tracelihlg Cylinder Azhnuth (TFO+Alq I`I vs Centre to Centre Separation 14U fl/hll Tras~elling Cylinder Arfmuth (FFOi.A7.l) I`I s's Centre W Cenree Separation IS Ninl SE("IIO\ DETAII Sec HD lac .id TlT1 fr/S eFJ-R' Dl.eg TFsae 3'Sec Taig¢t 1 30.00 0.00 0.00 30.00 0.00 0.00 0.0o g.oo o.oo z 290.00 0.00 0.00 z9o.oo o.oo o.oo o.o0 0.00 0.00 3 956,67 20.00 315.00 913.21 B1.N -61.11 3.00 315.00 -20.00 d 1769.66 52.52 i15.00 1590.00 Ii6.91 -di6.91 1.00 0.00 -102.ig 5 1969.66 52.52 115.00 1711.70 529.13 -$29,13 0.00 0.00 -IZ9.91 6 2750.54 68.81 315.8{ 2099.61 1115.89 -815.18 1.00 67.21 -52.28 N81.01 66.8d 311.81 272x50 2681.05 -]260.10 0.00 0.00 521.95 8 6217.18 89.]5 55.72 3095.20 d179.10 -bJ9.M 6.00 82.17 187338 2i-203 Hed (wp011 9 6293.56 88.16 55.]1 3095.97 620<.bl -601.22 3.00 179.22 1919.75 20 6]89.78 88.16 55.13 3110.20 6189.19 -191.E6 0.00 0.00 2115,77 2i-303 TI fwp01) II 6858.00 90.40 55.11 {1{0.91 1528.20 -136.30 1.00 -0.63 2183.98 12 7389.62 90.60 55,11 1107.20 {832 t0 397.71 0.00 0.00 301158 2T-203 T11npOQ 13 7146.27 92.Ifi 55.16 3105.89 6663.81 315.65 J.00 1.77 3071.21 11 7890.72 92.16 55.16 1069.20 3126 38 708.71 0.00 0.00 351635 2T-203 T3 ( pOQ IS 8026.16 88.10 55.05 ,1088.89 5195,83 819.8] 1,00 -17838 3651 'l6 26 8518.01 88.10 15,05 1105,20 5177,{9 1222.74 0.00 0.00 /11337 2T-203 ioe Iwp0/) 11 /8/2005 11:35 AM • ~, i ConoCOPhiHips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 2T Pad She Error: 0 OOft Reference Well: Plan 2T-203 Well Error: 0 OOft Reference Wellbore Plan 2T-203 Reference Design: 2T-203wp05 Sperry Drilling Services Anticoliision RepDlt Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Ca~ulation Method: Output errors are at Database: Offset TVD Reference: HALf_IBtJRTON Sperry Drilling Services Well Plan 2T-203 Planned RKB (o> 11020ft (Nordic 3 (80 3+30j) Planned RKB ~ 11Q20ft (Nordic 3 (80.3+30J) True Minimum Curvature 1-00 sigma EDM 2003.11 Single User Db Offset Datum 2eferance 2T-203wp05 =filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval 25.OOft Error Model: ISCWSA )epth Range: UnlimRed Scan Method: Trav. Cylinder North 2esuks Limited by: Maximum center-center distance of 1,048.SOft Error Surface: Elliptical Conic Naming Levels evaluated aE: 0.00 Sigma Survey Tool Program Date 11/8/2005 ~~~ From To '~, (ft) (ft) Survey (Wellbore) Tool Name Description 30.00 1,200.00 2T-203wp05 (Plan 27-203) CB-GYRO-SS Camera based gyro single shot 1,200.00 8,518.04 2T-203wp05 (Plan 2T-203) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation blaming Site Name Depth Depth Distance (ft) from Plan Offset WeII - Wellbore -Design (ftj (ft) (ft) (ft) Kuparuk 2T Pad 2T-02 - 2T-02 - 2T-02 784.37 825.00 184.78 16.42 168.71 Pass -Major Risk 2T-03 - 2T-03 - 2T-03 339.47 350.00 203.24 7.36 195.88 Pass -Major Risk 2T-04 - 2T-04 - 2T-04 362.06 375.00 228.08 9.60 218.48 Pass -Major Risk 2T-06 - 2T-06 - 2T-06 406.05 425.00 276.91 8.33 268.58 Pass -Major Risk 2T-202 - 2T-202 - 2T-202 1,404.73 1,475.00 85.35 43.90 43.02 Pass -Major Risk 2T-204 - 2T-204 - 2T-204 145.39 150.00 12.46 2.85 9.61 Pass -Major Risk 2T-207 - 2T-207 - 2T-207 629.53 625.00 54.93 13.12 42.68 Pass -Major Risk 2T-209 - 2T-209 - 2T-209 848.87 850.00 41.71 15.03 27.17 Pass -Major Risk 2T-210 - 2T-210 - 2T-210 1,126.17 1,125.00 46.16 24.50 21.74 Pass -Major Risk 2T-215 - 2T-215 - 2T-215 815.78 800.00 128.22 14.97 113.35 Pass -Major Risk 2T-217 - 2T-217 - 2T-217 7,988.07 6,500.00 149.58 24.53 127.65 Pass -Minor 1/200 2T-217 - 2T-217A - 2T-217A 195.44 200.00 175.51 3.77 171.74 Pass -Major Risk 2T-218 - 2T-218 - 2T-218 1,133.66 1,100.00 120.33 25.16 97.23 Pass -Major Risk 2T-22 - 2T-22 - 2T-22 311.88 325.00 163.18 5.57 157.61 Pass -Major Risk 2T-220 - 2T-220 - 2T-220 681.02 650.00 215.86 13.44 202.78 Pass -Major Risk 2T-220 - 2T-220PB1 - 2T-220P61 673.91 650.00 215.69 13.27 202.76 Pass -Major Risk 2T-23 - 2T-23 - 2T-23 307.25 300.00 148.24 5.49 142.75 Pass -Major Risk 2T-26 - 2T-26 - 2T-26 336.41 350.00 102.57 6.00 96.57 Pass -Major Risk 2T-27 - 2T-27 - 2T-27 360.87 375.00 87.84 6.42 81.42 Pass -Major Risk 2T-28 - 2T-28 - 2T-28 361.24 375.00 73.33 6.58 66.76 Pass -Major Risk 2T-29 - 2T-29 - 2T-29 312.71 325.00 58.20 5.59 52.62 Pass -Major Risk 2T-30 - 2T-30 - 2T-30 435.82 450.00 40.58 7.87 32.75 Pass -Major Risk 2T-31 - 2T-31 - 2T-31 337.14 350.00 25.35 6.43 18.93 Pass -Major Risk 2T-32 - 2T-32 - 2T-32 313.08 325.00 13.20 5.59 7.62 Pass -Major Risk Plan: 2T-208 -Plan: 2T-208 - 2T-208wp04 760.50 750.00 60.84 16.70 44.38 Pass -Major Risk Plan: 2T-208 -Plan: 2T-208P61 - 2T-208P61 wp03 750.27 750.00 60.60 16.48 44.36 Pass -Major Risk Plan: 2T-40 -Plan 2T-40 - 2T-40 (wp04) 1,661.67 1,825.00 265.30 40.87 224.64 Pass -Major Risk Plan: 2T-40 -Plan 2T-40 Sidetrack Scenarios - 2T-40 1,661.67 1,825.00 265.30 4D.87 224.64 Pass -Major Risk Prelim: 2T-Tabasco Horz (6-7) - Owen's Plan - Owen's f 5,154.46 7,457.80 428.18 215.78 217.25 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/812005 11:26:44AM Page 2 of 2 COMPASS 2003.118ui1d 50 ORIGINAL •n: 2T-203wp05 (Plan 2T-203/Plan 2T-20~ 'Mr ~ar-~-caPh~lf~~s R~!~isk3 HALLIBURTON Sperry Drilling Services Ukulatlon Metlnd: Minimum CUVaWra Enar Sysbni: scwsA Scan McOwd: T2v. Cjlintler NOM Em>rsuta~e: ELI cony WaMn9 Method' Rilm Besod Gmdatlc DeWm: NA01927 tTWDGON CONl19) Magnotlc Model. BGGMIllClS Ground Level: 80.20 RKB: Planned RKB ~ 110.20k (Nordic 3 (80.3+30)) Northing/ABP V: 5970580.23 EastlnglASP X: 498944.61 VVB_LBORE TARGEr DETALS (MAP CCI0RDN4TES) Project: Kuparuk River Unit Nr,n,e TvD +ws +E/.W Northing EasOng shape Site: Kuparuk 2T Pad Weil: Plan 2T-203 Wellbore: PIan2T-203 ~T 203wp05 T3 ''<T~203wp05 Heel J?-203wp05 Haei Circle 2T-203wpO5Prodlnt -T~203wpO5Toe 308920 309520 309520 309520 310520 529620 4356.92 4356,92 4356.92 5655.31 70&40 639.61 639.61 639.61 1222A0 5975678.00 5974739.00 5974739.00 5974739.00 5976037.00 409654.00 496806.00 498,906.00 498306.00 500168.00 Point Point Circle (Radius: 1320.00) ~ Rscfangle(2271. Pok1t ;'T-203wp05 Toe Circle 310520 565531 1222A0 5576037.00 500168.00 Circle (Radius: 1320.00) Plan: 2T-203wp05 zr-zo3wpo5T2 <~'-203wp05 T1 310720 311020 soio.ti 4667A7 297.40 -194.61 ~7s3sz.oo 5975049.00 as9243.0o 498751.00 Poem Poht .oa sae wl. low wla r.s~a ble atrz C_ w O O 117 t O Z 7 O fn ODeralw: Conaco9XIIXpS Alaska lEYDOlUk) GX~COrtacXOn: -0.01 Jab NO: XN/A 11tlQ Xupaluk Xivei UnX MapneMa Ca<InaXOrc 29.00 AiE NO: MN/A WaE 2i-10]wp05 OID' B0.)d A91NO' tlN/A A)a XN/A DaNX9 Der 100 't Eydlam (IVD)RdX.Xnce: e~.niea'.e.e- f SaReaeLOCaOOn Original VS Plane: 55.00 ruenlweX PIan II~20] 998944.41 VIEW V$ PIOne: 55.00 RKX NeIpXf 11030 X O tJ l Z UMISYIIXm: A916avea: !95 section rysl XX9emnae: Slpl ~----- I Plan View ~p W ~ N N ph ~ aL0 ~ N ~ O O O N ---t~-~--~--~--- ~ --t~--~- 5977000 2T-217A I I I I I I I II I I pT- wp05 I ' ----~--_-~____+____~.___- -. i-_____~ i ---_. ~.i,-.__..I 5976000 I I I I I I I I' 1 ----~-----T- - _- - _ ~__ z zzo --- ----~-----~------ s97sc^,e I I I I I ~ I I I I I ' I 2T-210 1 I -----L----L--- --1- --- ~----- ~----J------~i - s97cocc I I II I I I I I I I I I I I I I __-__j__-.__1.---- - - - ---_-__ ~- 5973000 I I - I--___ ~ ___ I ____I I I I I I ~t I I I I I I __-__ I + - __~__-__~_____~_____+__-__~.-}5972000 ~__-__~____ I I I 1 I I I I I I I I I I I I I I I I I -----~--~--~ -------- - --•--~--•--~-----~-----~-- s97iooo 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 I I I -... ...__._-.._..~___. _..__..ti,.._.e.-~a..~.-. a.~ '.~.- 5970000 z z 0 z ~--------~ I I Section View; i _~~.2T-203wpO5Plan -~-2i-210 -~-2T-217A 21zzo ~ ~rfrrr~nJEr.ri l ___________________________________J d 0) D O t N 0) >_ T East I+I / Wesf I-J 2000 Q~ vJ N h N N N N h N N h h .p .p ~p ^ M M M ^ N M M M a `~M, e~, `= `" vertical Secfia~ along "View v~ Plane" v ~ ~ ~ Combo Preview Page 1 of 1 (TOOlboxl.xls) 11/82005 2:13 PM Y: 59)0560.1] 'I • • 2T-203 ~rillinQ Haz (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13 1/2" Surface Hole / 10 3/4" Casino Interval Hazard. Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar & pad continuously during interval. Gas Hydrates Moderate Minimum mud weight of 9.6 ppg. If observed - control drill, reduce pump rates, reduce drilling fluid tem eratures, addition. of Drilltreat. Running Sands and Gravels Moderate Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Stuck surface casing Low Clean the hole before running casing, pump high densit hi h viscosit sweeps, wi er trip s Stuck pipe Low Keep hole clean, use high density high viscosity sweeps, keep pipe moving/rotating with pumps on whenever ossible Hole swabbing on trips Moderate Circulate hole clean prior to trip, proper hole filling use of trip sheets , pumpin out of hole as needed 9 7/8" Intermediate/Pilot Hole / 7 5/8" Casing Interval Hazard Risk Level Miti ation Strate Hydrogen Sulphide gas Moderate ~ H2S drills, detection systems, standard well control H2S radices Running Sands and Gravels Low Maintain planned mud parameters, Increase mud wei ht, use wei hted swee s. Gas Hydrates Low ~ Control drill, reduced pump rates, reduced drilling fluid tem eratures additions of Driltreat. Insufficient or undetermined Moderate Importance of LOT communicated to all parties, all LOT parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an acce table FIT is obtained. Stuck Pipe High Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever possible. Monitor mud arameters for tou h, thin filter cake Abnormal Pressure Low ~ BOP training and drills, material on location for increased mud wei ht. Barite sa Hi h Good drillin practices as documented in well Ian Lost circulation Moderate Keep hole clean -use PWD to monitor hole cleaning. If losses occur -reduce pump rates and mud rheolo ,use LCM High ECD /Tight hole on Moderate Condition mud & clean hole prior to trips. Monitor trips/ Swabbing ECDs with PWD tool and in particular while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets). Utilise wiper trips as hole conditions dictate. Closely monitor drillpipe running & tripping speeds. V ~ ~ 2T-203 Drilling Hazards Summary. doc U 6 3/4" Production Hole / 4 1/2" Liner Interval Hazard Risk Level Miti ation Strate Hydrogen Sulphide gas Moderate ~ HZS drills, detection systems, standard well control HZS ' ractices Abnormal Reservoir Pressure Low ~ BOP training and drills, material on location for increased mud wei ht. Differential sticking High Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever possible. Monitor mud arameters for tou h, thin filter cake. Lost circulation Moderate Keep hole clean -use PWD to monitor hole cleaning. If losses occur -reduce pump rates and mud rheolo ,use LCM Barite sa Hi h Good drillin ractices as documented in well plan High ECD /Tight hole on Moderate Condition mud & clean hole prior to trips. Monitor trips/ Swabbing ECDs with PWD tool and in particular while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets). Utilise wiper trips as hole conditions dictate. Closely monitor drill i e runnin & tri in seeds. 2T--203 Drilling Hazards Summary.doc Rig: Nordic 3 Location: Tabasco Client: ConocoPhillips Alaska, Inc. Revision Date: 11/11/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface I t ;i r =<~ro Previous Csg. < 16", 152# casing at 107' MD < Top of Tail at 1,410' MD < Base of Permafrost at 1,556' MD (1,448' TVD) < 10 3/4", 45.5# casing in 13 1/2" OH TD at 1,710' MD (1,553' TVD) Mark of Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface ~eliminary Job Design based on limited input data. For estimate purposes only Schlamaerger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 40% excess below the permafrost. The top of the tail slurry is designed to be at 1,410' MD. Lead Slurry Minimum pump time: 180 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.6381 ft3/ft x (110') x 1.00 (no excess) = 70.2 ft3 0.3637 ft3/ft x (1410' - 110') x 3.50 (250% excess) = 1654.8 ft3. 70.2 ft3 + 1654.8 ft3+ = 1725.0 ft3 1725.0 ft3 / 4.45 ft3/sk = 387.6 sks Round up to 390 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 130 min. (pump time plus 90 min.) ARCTICSET I @ 15.7 ppg - 0.93 ft3/sk 0.3637 ft3/ft x (1556' - 1410') x 3.50 (250% excess) = 185.9ft3 0.3637 ft3/ft x (1710' - 1556') x 1.40 (40% excess) = 78.4 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 185.9 ft3 + 78.4 ft3 + 43.2 ft3 = 307.5ft3 307.5 ft3/ 0.93 ft3/sk = 330.7 sks Round up to 340 sks BHST = 33°F, Estimated BHCT = 57°F. (BHST calculated using a gradient of 2.6°F/100 ft. .below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time /bbll (mint CW100 5.0 10.0 2.0 2.0 Pause 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Pause 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 ASL 6.0 307.3 51.2 86.2 AS 1 5.0 54.8 11.0 97.2 Pause 0.0 0.0 5.0 102.2 Water 5.0 20.0 4.0 106.2 Pause 0.0 0.0 5.0 111.2 Mud 7.0 127.8 .18.3 129.5 Mud 3.0 9.0 3.0 132.5 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint throughout tail slurry column ORIGINAL Rig: Nordic 3 Location: Tabasco Client: ConocoPhillips Alaska, Inc. Revision Date: 11/9/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin 13@slb.com 8 I i Previous Csg. < 10 3/4", 45.5# casing at 1,710' MD < Top of Tail at 2,625' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 6,162' MD (3,094' TVD) CemCADE Preliminary Job Design 7.625" Intermediate Casing reliminary Job Design based on limited input data. For estimate purposes onP, Schl~mpeng~r Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above the top of the West Sak - (3537' MD annular length). Tail Slurrv Minimum thickening time: 210 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 3537 x 1.25 (25% excess) = 949.7 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 949.7 ft3 + 20.6 ft3 = 970.3 ft3 970.3 ft3/ 2.25 ft3/sk = 431.2 sks Round up to 440 sks BHST = 73°F, Estimated BHCT = 65°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) /bbll (min) (mint CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 20.0 4.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 MP II 5.0 50.0 10.0 31.0 DeepCRETE 6.0 172.7 28.8 59.8 Drop top plug 0.0 0.0 5.0 104.8 Water 5.0 20.0 4.0 108.8 Switch to rig pump 0.0 0.0 5.0 113.8 Mud 6.0 250.3 41.7 155.5 Slow & bump plug 3.0 9.0 3.0 158.5 MUD REMOVAL Recommended Mud Properties: 9.2 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend minimum 1 Tandem Rise centralizer per joint across zones of interest for proper cement placement. ORIGINAL 2T-203 ~rizontal Proposed Completion Schematic ConocoPhillips Description Size TOL Btm TVD Wt Grade Conn. Conductor 16 0 107 107 152# X-65 Surface 10 3/4 0 1710 1553 45.5# L-80 BTCM Intermediate 7 5/8 0 6162 3094 29.7# L-80 BTCM Production 4 1/2 5760 8518 3105 12.6# CR13 VAM Top Tubing 41/2 0 +/-5700 12.6# L-80 IBTM (2) Camco 4 1/2" X 1" KBMG Side Pocket Mandrels set at: TVD Approx MD 2400 3600 2800 4700 (max depth <70 deg) Baker 4'/" CMD Sliding Sleeve with 3.81" Camco profile Centrilift ESP @ +/-5760' MD, 3062' TVD Baker SC-1 R Liner Top PKR @ +/-5862' MD, 3074' TVD 7 5/8" shoe @ 6162' MD 3094' TVD TD @ 8518' MD / 3105' TVD OR161NAI_ ~a,p: • • __ SHARON K. ALLSUP-DRAKE ~ 120 CONOCOPHILLIPS ATO 1530 700 G ST. IL ~ )BY~'~'' ANCHORAGE AK 9y9/~15.01 y DATE G~-'`~J 62-i4'/3>> f PAY TO THE S~rl ~~~ ~ F-~ ~~CC ~ /W, ~V ' ORDER OP - 1` (1~ //N~ , ~ a C /~~°'tfi3LTAF15"'~J D.. ~,~~ E,. Chase Manhatlan Bank USA, N.A. ~r. ~~~~~ 200 White Clay Center Dr., Newark, DE 19)11 Valid Up To 5000 Dollars MEMO --- - -~~-1 -- - ~ --, -%~~~_ _~ x:03 1 i00 L44~: 2 184? 19079 2?6il' L 1 20 r ,: ~, 0 ~I TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TR.ANS~IITTAL LETTER WELL NAME ~~ 2~~ ~~ PTD# 2C~ ~- CHECK WHAT i ADD-ONS ~ "CLUE" APPLIES ~ (OPTIONS) MULTI The permit is for a new wellbore segment of ;LATERAL 'existing well , Permit No, API No. ~ (If API number Production should continue to be reported as 'last two (2) digits a function of the original API number stated are between 60-69) above. I PILOT HOLE In accordance with 20 AAC 25.005(f), all ~ (per i records, data and logs acquired for the pilot hole must be clearly differentiated in both !name (name on permit plus PH) ~ and API number (50 i ~ ~ 70/80) from records, data and logs acquired 1 for well (name on permit). I i SPACING j The permit is approved subject to full ~I i EXCEPTION compliance with 20 AAC 25.05. Approval to !perforate and groduce/infect is contingent upon issuance of a conservation order 'approving a spacing exception. (Company Name) assumes 'the liability of any protest to the spacing exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the 0' ~ SAMPLE ~ Commission must be in no greater than 3 st f ro sample intervals from below the perma j j or from where samples are first caught and ~, '~ i 10' sample intervals through target zones. Rev: 04/01/05 C\jodyltransmittaf_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, TABASCO OIL - 490160 _ ~ Well Name: KUPARUK RIV U TABS 2T-203 Program DEV Well bore seg ^ PTD#:2051970 Company CONOCOPHILLIPS ALASKA INC Initial ClassfType DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached - - - Yes - - - - - 2 Lease number zppropriate_ -------------------- Yes - --------- - _ - - . -Surface location and-tap of productive interval_ in ADL 25569;_TO in ADL 25548._ - - _ _ - 3 Uniquewell_nameandnumb_er ------------ -- - - -- -_ Yes- ,.... - -- -- -- -- -------- --- -------- 4 Well locatedin.a-defnedpool___-__- -__----- --------- ------------Yes- -_--._KUPARUKRIVER,_TABASCOOIL-49016Qgovernedby_GO435A,,-____-------_--__--__ 5 Well located proper distance from drilling unit_boundary- _ - _ _ - - - - - - Yes - - - - . -This proposed well_cgnf4rms to Conservation Order No. 435A Rule 3, which_specifies 10-acre spacing.- _ _ - - - - 6 Well located proper distance-from other wells_ _ _ Yes _ Conforms to_Conseruation Order No. 435A_ Rule 3,_which specifies 10-ac_re spacing_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficient acreage available in_drilling unit_ _ - - - - - - Yes Conservation Order No. 435A specifies no well may opened tothe-po41 closer than 300 feet to an - - - . - - - - - - 8 If_deviated, is wellbore plat_included _ . -------- Yes ------- - _ _ - .external boundary where ownership changes. - _ - - . - - - --------------------------- 9 Operator only affected party _ _ _ Yes _ _ - - - 10 Operator has appropriate_bondfnforce__.~_______ __ __ _ ___ ___ _ _Yes_ ...-_ _ _~ ______ __ ___ _~________ __ ____-____ --------------------- 11 Permit_c_anbeissuedwithouiconservationorder________________ __________-Yes_ ____________-_ - - - - - Appr Date 12 -Permit_can be issued without administr-alive-approval _ Yes - _ - - - - ------------------------------------------------------ SFD 12/8/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by Injection Order # (put1O# in_comments)-(For- NA_ , 15 All wellswithfn114_mileareaofreyiewidentified(Fo[servicewellonly)___ ____________ NA.. _.._.____--_,__________--_____________--__-____-____---_---_---_-------.-, 16 Pre-produced injector: duration of pre--p[oduction Less than_ 3 mgnths_(For service well only) - - NA- - ----------------------------------------------- ACMP-Finding of Consistency_has been issued_forthis project- , _ _ _ - - _ _ NA_ - - _ , _ _ _ _ _ - _ _ . _ --------------------------------------------------- Engineering 18 Conductor sting-provided_____________________________ ____________Yes- -- ---- 19 Su_rfacecasing-p-rQtectsallknpwnUSDWs-______----.------ -_-_-_---_-NA__ -__Allaquifersexempted, 40 CFR-147.1Q2_(b)(3)------------------------------------------ 20 CMT_vol_adeguate_to circulate-on conductor_& surf_csg _ - - - -Yes _ _ _ - _ ------------------------------------------------------------- 21 CMT_vofadeguate_totie-inlongstringtasu_rfcsg_________ ______ ____________ No__ _____Allhydrocarbon_zonesin8-1l2"hole will be coyered.____----____----------__--_---__--__ 22 CMT.will coverall know_n_productiye horizons- _ _ _ - _ - - _ - , No_ _ _ _ _ - - _ Screened liner completion planned- - - - - - - - - - - - - ----------------------------------- 23 Casing designs adequate for C,T,B&_permafrost-------------- ------ Yes- ------------------------.----------..--------------------------,--------- 24 Adequate tankage-or reserve pit - - - - - - - - - - - - - - - - - Yes - _ _ - _ - _ Rig is_equipped with steel-pits. _ No reserve_pitplarined, All waste to approved disposal_wells._ 25 If a_re-drill, has-a_ 10-403 for abandonment been approved - - - - - - - - - - - - - _ - _ _ . - _ NA_ - _ _ _ _ _ _ _ _ _ _ _ -------------------------------------------------------------- 26 Adequate wellbore separationproposed_ ___ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes , .. _ ... Proximity analysis performed, Traveling cylinder path calculated: Gyros possible, _ _ _ _ _ _ _ _ _ , _ _ - ... _ . _ 27 If_diverterrequfred,doesitmeetregulations___________________ ____________Yes- ____._--____ ____-__--__--_ Appr Date 28 Dulling fluid_ program schematic & equip list adequate_ - - - - - - - - - - - - - - Yes Maximum expected formation pressure 6,3_EMW._ Mud weight planned, 9.1- 9.3 ppg in zone._ - - TEM 12!12!2005 ` 29 BOPEs,-do they meet regulation_-__-------------------- ----- ------Yes_ __--_-- -_----_-__-__------_.---___---_-_--___--__.-_---__-_-,__--_---_ ~Q ~ 30 B_OPE_press rating appropriate; test to-(put prig fn comments)- - - - - - - - - - - - - - - - - - - - Yes _ - _ _ _ _ _ MASP calculated at 685_psi. 3000 psi BOP test_planned. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ /r/,~'/~ 31 Choke-manifold complies wIAPI_ RP-53 (May 84)_ _ _ - - . Yes _ _ _ - . _ - _ - _ - . - _ 32 Work will occur without operation shutdown_ - - _ _ - _ _ Yes - _ - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presen4e-of H2S gas_probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ - - - _ _ N2S has been_ reported in offset wells, Mud should_preclude H2S qn rig. -Rig has senso[s-and alarms, - _ _ _ _ _ _ 34 MechanicalconditfonofwellswithinAORVerified(For_seruicewellonly)-- ------------NA__ .-__--__--_-_______________---__--__-__ Geology 35 Permitcan be issued wlo hydrogen.sulfidemeasvres _ No- _ . - _ - -Offset wells 2T-217A and -220 measured-75 & 220_ppm H2S during 2004- - - - - - - - - - - - - - - - - - - - - - - - 36 Data-presented on_ potential overpressure zones- - - - - - - - - - - - - - - - - - - - Yes Reservoir is depleted; est. pressure is 4.3 t_o 6,3_ppg EMW. Prod int. will be d[illed with 9.1 - 9.3 ppq mud. Appr Date 37 Seismic analysis_ of shallow gas-zones. - _ - - _ NA_ _ - - _ - - -Moderate potential for hydrates; mitigation measures_discuss in Drilling Hazards_Summary-- SFD 12!8/2005 38 Seabed condition survey-(if off-shore) _ . - . - - - - _ NA_ - - - - - - - - - - - - _ ---------- 39 Contact name/phone for weekly_progtess reports [exploratory only] - . - _ _ - - _ NA_ Geologic Engineering Publi Commissioner: Date: Commissioner: Date Co er Date pTS' ~Z~J~~S ~~ /Z /3 ~~ lZ-~~3--0~'' • • 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 io chronologically organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Aug O1 09:30:33 2006 Reel Header Service name .............LISTPE Date .....................06/08/01 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/08/01 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Tabasco MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS • Scientific Technical Services Scientific Technical Services 2T-203 501032052000 ConocoPhillips Alaska Inc. Sperry Drilling Services Ol-AUG-06 MWD RUN 2 MWD RUN 3 MWD RUN 4 W-0004163248 W-0004163248 W-0004163248 J. BOBBITT E. QUAM J. BOBBITT P. WILSON D. HEIM D. HIEM SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING 1 11N 8E 580 556 110.72 80.20 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 1610.0 7.625 6046.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4 ALSO INCLUDED COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND AT-BIT INCLINATION (ABI). RESISTIVITY DATA FOR RUNS 3,4 WERE CORRECTED FOR BOREHOLE AND SALINITY EFFECTS. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 7/25/06, FROM P. PERFETTA (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 2T-203 WITH API#:50-103-20520-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7520'MD/3101'TVD. SROP = SMOOTHED RATE OF PENETRATION 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 (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" BIT MUD WEIGHT: 9.0-9.1 PPG MUD SALINITY: 20000 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header ~ • Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/01 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 STOP DEPTH GR 1575.5 7461.5 RPD 1590.0 7469.0 RPS 1590.0 7469.0 FET 1590.0 7469.0 RPM 1590.0 7469.0 RPX 1590.0 7469.0 ROP 1620.5 7520.0 NPHI 6020.0 7433.5 NCNT 6020.0 7433.5 RHOB 6020.0 7449.0 PEF 6020.0 7449.0 DRHO 6020.0 7449.0 FCNT 6020.0 7433.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 1575.5 6062.0 MWD 3 6062.0 6762.0 MWD 4 6762.0 7520.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FCNT MWD NCNT MWD RHOB MWD DRHO MWD RPD MWD Units Size Nsam Rep FT 4 1 68 CNTS 4 1 68 CNTS 4 1 68 G/CM 4 1 68 G/CM 4 1 68 OHMM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 ~ • RPM MWD OHMM 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 1575.5 7520 4547.75 11890 1575.5 7520 FONT MWD CNTS 94.96 885.62 461.338 2828 6020 7433.5 NCNT MWD CNTS 12574.9 32747.7 23880.6 2828 6020 7433.5 RHOB MWD G/CM 1.079 2.705 2.22547 2859 6020 7449 DRHO MWD G/CM -0.774 0.518 0.101077 2859 6020 7449 RPD MWD OHMM 0.18 2000 238.878 11759 1590 7469 RPM MWD OHMM 0.34 2000 85.9347 11759 1590 7469 RPS MWD OHMM 0.6 2000 62.8094 11759 1590 7469 RPX MWD OHMM 0.522 2000 24.8168 11759 1590 7469 FET MWD HOUR 0.3 119.38 2.6759 11759 1590 7469 GR MWD API 16.76 133.19 72.2962 11773 1575.5 7461.5 PEF MWD BARN -0.11 10.04 1.47715 2859 6020 7449 ROP MWD FT/H 0.16 745.41 124.253 11800 1620.5 7520 NPHI MWD PU-S 12.71 58.68 24.0027 2828 6020 7433.5 First Reading For Entire File..........1575.5 Last Reading For Entire File...........7520 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/01 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.......06/08/01 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 1575.5 RPX 1590.0 RPM 1590.0 header data for each bit run in separate files. 2 .5000 STOP DEPTH 6018.0 6010.5 6010.5 • • RPD 1590.0 6010.5 RPS 1590.0 6010.5 FET 1590.0 6010.5 ROF 1620.5 6062.0 LO G HEADER DATA DATE LOGGED: 02-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6062.0 TOP LOG INTERVAL (FT) 1620.0 BOTTOM LOG INTERVAL (FT): 6062.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 32.7 MAXIMUM ANGLE: 79.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97054 EWR4 ELECTROMAG. RESIS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 1610.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 63.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.000 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.640 84.2 MUD FILTRATE AT MT: 1.800 68.0 MUD CAKE AT MT: 2.100 68.0 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 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 ~ • RPD MWD020 OHMM 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1575.5 6062 3818.75 8974 1575.5 6062 RPD MWD020 OHMM 1.43 2000 21.7379 . 8842 1590 6010.5 RPM MWD020 OHMM 0.42 1745.13 15.3042 8842 1590 6010.5 RPS MWD020 OHMM 0.89 109.15 14.4705 8842 1590 6010.5 RPX MWD020 OHMM 1.91 88.48 12.924 8842 1590 6010.5 FET MWD020 HOUR 0.3 85.11 1.42171 8842 1590 6010.5 GR MWD020 API 16.76 133.19 82.0425 8886 1575.5 6018 ROP MWD020 FT/H 2.24 599.52 129.263 8884 1620.5 6062 First Reading For Entire File..........1575.5 Last Reading For Entire File...........6062 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/01 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.......06/08/01 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 STOP DEPTH FET 6011.0 6716.5 RPX 6011.0 6716.5 RPS 6011.0 6716.5 RPD 6011.0 6716.5 RPM 6011.0 6716.5 GR 6018.5 6709.5 PEF 6020.0 6696.5 NPHI 6020.0 6681.5 DRHO 6020.0 6696.5 RHOB 6020.0 6696.5 0 NCNT 6020. 6681.5 FCNT 6020.0 6681.5 ROP 6062.5 6762.0 LO G HEADER DATA DATE LOGGED: 08-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6762.0 TOP LOG INTERVAL (FT) 6062.0 BOTTOM LOG INTERVAL (FT) 6762.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.3 MAXIMUM ANGLE: 91.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 59475 ALD Azimuth. Litho-Den 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6046.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S) 59.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3) 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 75.2 MUD FILTRATE AT MT: .210 69.0 MUD CAKE AT MT: .000 69.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel ~ DEPT FT 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6011 6762 6386.5 1503 6011 6762 FONT MWD030 CNTS 94.96 8 85.62 441.742 1324 6020 6681.5 NCNT MWD030 CNTS 12574.9 30 107.9 23215.7 1324 6020 6681.5 RHOB MWD030 G/CM 1.079 2.705 2.23252 1354 6020 6696.5 DRHO MWD030 G/CM -0.774 0.518 0.0829461 1354 6020 6696.5 RPD MWD030 OHMM 0.18 2000 1338 1412 6011 6716.5 RPM MWD030 OHMM 0.34 2000 393.628 1412 6011 6716.5 RPS MWD030 OHMM 0.6 2000 276.704 1412 6011 6716.5 RPX MWD030 OHMM 0.522 2000 78.9202 1412 6011 6716.5 FET MWD030 HOUR 0.36 1 19.38 10.5215 1412 6011 6716.5 GR MWD030 API 27.04 59.45 42.2722 1383 6018.5 6709.5 PEF MWD030 BARN 0.38 10.04 1.73352 1354 6020 6696.5 ROP MWD030 FT/H 0.16 7 45.41 96.0682 1400 6062.5 6762 NPHI MWD030 PU-S 12.71 58.68 24.6224 1324 6020 6681.5 First Reading For Entire File..........6011 Last Reading For Entire File...........6762 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header .Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/01 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 s ~ FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 6682.0 7433.5 NCNT 6682.0 7433.5 FONT 6682.0 7433.5 RHOB 6697.0 7449.0 DRHO 6697.0 7449.0 PEF 6697.0 7449.0 GR 6710.0 7462.0 RPD 6717.0 7469.0 RPX 6717.0 7469.0 FET 6717.0 7469.0 RPM 6717.0 7469.0 RPS 6717.0 7469.0 ROP 6762.5 7520.0 LO G HEADER DATA DATE LOGGED: 10-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7520.0 TOP LOG INTERVAL (FT) 6762.0 BOTTOM LOG INTERVAL (FT) 7520.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 93.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 CTN COMP THERMAL NEUTRON 18446744073 70955 EWR4 Electromag Resis. 4 59475 ALD Azimuth. Litho-Den 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6046.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 60.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 17000 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .190 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .170 76.7 MUD FILTRATE AT MT: .200 69.0 MUD CAKE AT MT: .160 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Red 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 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 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6682 7520 7101 1677 6682 7520 FCNT MWD040 CNTS 223.58 7 50.88 478.589 1504 6682 7433.5 NCNT MWD040 CNTS 15535.4 32 747.7 24465.9 1504 6682 7433.5 RHOB MWD040 G/CM 1.461 2.638 2.21913 1505 6697 7449 DRHO MWD040 G/CM -0.063 0.505 0.117389 1505 6697 7449 RPD MWD040 OHMM 80.34 2000 483.393 1505 6717 7469 RPM MWD040 OHMM 42.75 2000 212.215 1505 6717 7469 RPS MWD040 OHMM 18.41 2000 146.127 1505 6717 7469 RPX MWD040 OHMM 8.887 38 9.567 43.9278 1505 6717 7469 FET MWD040 HOUR 0.31 23.58 2.68361 1505 6717 7469 GR MWD040 API 29.09 59.33 42.3243 1505 6710 7462 PEF MWD040 BARN -0.11 3.38 1.24649 1505 6697 7449 ROP MWD040 FT/H 2.55 2 38.55 120.927 1516 6762.5 7520 NPHI MWD040 PU-S 18.84 31.69 23.4572 1504 6682 7433.5 First Reading For Entire File..........6682 Last Reading For Entire File...........7520 File Trailer Service name. ..........STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/01 Origin ................. Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/08/01 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF Writing Library. • Scientific Technical Services Scientific Technical Services End Of LIS File