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Home My WebLink About203-0091. 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: Pull/Replace Sel Comp 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 10165'feet 7501'feet true vertical 6119' feet 8105'feet Effective Depth measured 7501'feet 7758', 7982'feet true vertical 5709'feet 5873', 6018'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 7275' 5564' Packers and SSSV (type, measured and true vertical depth)7758' 7982' 5873' 6018' 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: 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: 323-653 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: CAMCO HRP-1-SP Packer: Baker FB-1 Dusty Ward dusty.ward@conocophillips.com (907) 265-6531Staff RWO/CTD Engineer 7939-7958', 8409-10164' (Squeezed 7721-10165') 5990-6002', 6101-6119' (Squeezed 5849-6025') 2172' 2-3/8" 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) Gas-Mcf MDSize 110' Well Shut-In measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-009 50-029-21151-01-00 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: ADL0025655, ADL0025656 Kuparuk River Field/ Kuparuk Oil Pool - Suspended KRU 2B-03A Plugs Junk measured Length Production 8363' Casing 6280'8395' 10165' 6119' 3127' 110'Conductor Surface Production 16" 9-5/8" 75' 3161' 2751' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov None. This 10-404 covers work through whipstock set in the old 2B-03A. The 10-407 submitted with this will cover the new 2B-03B. By Samantha Coldiron at 3:34 pm, Mar 06, 2024 DSR-3/6/24 RBDMS JSB 031324 Page 1/8 2B-03 Report Printed: 3/5/2024 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) 1/28/2024 00:00 1/28/2024 06:00 6.00 RURD P Perform rig down checklists, prep location for move, prep loads for transport to 2B pad, Cold weather prevent some work being down outside by crews 0.0 0.0 1/28/2024 06:00 1/29/2024 00:00 18.00 WAIT T Waiting on ambient temperature to increase to start rig move. 0.0 0.0 1/29/2024 00:00 1/29/2024 06:00 6.00 MIRU, MOVE WAIT T Waiting on ambient temperature to increase to start rig move. 0.0 0.0 1/29/2024 06:00 1/29/2024 15:00 9.00 MIRU, MOVE MOB P Prep and move camp, shop and supporting buildings 0.0 0.0 1/29/2024 15:00 1/29/2024 18:00 3.00 MIRU, MOVE MOB P Mob rig from 2M pad to 4 corners 0.0 0.0 1/29/2024 18:00 1/30/2024 00:00 6.00 MIRU, MOVE RGRP T Drive motor on moving system fail // Perform repairs in road 0.0 0.0 1/30/2024 00:00 1/30/2024 02:00 2.00 MIRU, MOVE MOB P Repairs complete mob rig to 4 corners, allow traffic by, continue to move to 2B 0.0 0.0 1/30/2024 02:00 1/30/2024 12:00 10.00 MIRU, MOVE RURD P Rig on pad. prep for backing over 2B- 03. Spot over well back in pits raise derrick continue working pre acceptance checklist. spot in kill tanks and cutting tanks. 0.0 0.0 1/30/2024 12:00 1/30/2024 15:00 3.00 MIRU, WELCTL RURD P Pre acceptance checklist completed. Tool house still RU kill tanks and hardline to rig. Mix 30 BBL deep clean pill. 0.0 0.0 1/30/2024 15:00 1/30/2024 17:30 2.50 MIRU, WELCTL CIRC P Reverse circulate well out to 8.5# seawater. 3BPM 750PSI 0.0 0.0 1/30/2024 17:30 1/30/2024 18:00 0.50 MIRU, WELCTL OWFF P Observe well for flow 0.0 0.0 1/30/2024 18:00 1/30/2024 20:30 2.50 MIRU, WELCTL SLKL P R/U Slickline 0.0 0.0 1/30/2024 20:30 1/30/2024 20:45 0.25 MIRU, WELCTL SLKL P P/T Lubricator 1,500 psi 0.0 0.0 1/30/2024 20:45 1/30/2024 21:00 0.25 MIRU, WELCTL MPSP P M/U IBP 0.0 0.0 1/30/2024 21:00 1/30/2024 21:15 0.25 MIRU, WELCTL MPSP P P/T connection Sim-ops start loading DrillPipe 0.0 0.0 1/30/2024 21:15 1/30/2024 21:45 0.50 MIRU, WELCTL MPSP P Set IBP COE @ 51' from Rig Floor Test/Chart 1,000 psi from below 10 min 0.0 0.0 1/30/2024 21:45 1/30/2024 22:30 0.75 MIRU, WELCTL SLKL P R/D Slickline 0.0 0.0 1/30/2024 22:30 1/31/2024 00:00 1.50 MIRU, WELCTL NUND P Check SSSV void, bleed crude/gas to bucket, Nipple down tree/adaptor 0.0 0.0 1/31/2024 00:00 1/31/2024 00:45 0.75 MIRU, WELCTL NUND P Secure tree in corner of cellar, N/U BOPE Inspect tubing hanger threads, function 3-1/2" EUE 8rd XO, 11 turns Function LDS in 2-5/16", out 2-15/16" 0.0 0.0 1/31/2024 00:45 1/31/2024 03:30 2.75 MIRU, WELCTL NUND P Install 7"x13-5/8" DSA, N/U 13-5/8" BOPE Continue sim-ops processing/loading DP 0.0 0.0 1/31/2024 03:30 1/31/2024 18:00 14.50 MIRU, WHDBOP SVRG P Perform between well maintenance, brake all door bolts, UPR, blinds, LPR, clean and inspect, take photos, brake top flange bolts, swap out 13-5/8" annular element, (preventative maint.) Continue to process DP 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/10/2024 Page 2/8 2B-03 Report Printed: 3/5/2024 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) 1/31/2024 18:00 1/31/2024 20:00 2.00 MIRU, WHDBOP OTHR P RU to test BOP's MU XO's to test joints. flood stack with fresh water perform shell test. Load pipe shed W/264 joints of XT-39 0.0 0.0 1/31/2024 20:00 2/1/2024 00:00 4.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3,500 PSI for 5 Min each, test #1 Blind Rams, CMV 1,2,3, & 16, 2" Rig Floor Kill, IBOP, Outer Test SPool Valve. Test #2 Blind Rams, CMV, 4,5,& 6, HCR Kill, Inner Test Spool Valve, Manual IBOP, Test #3 Blind Rams, CMV, 7,8, & 9, Manual Kill, and XT-39 Dart Valve, Test #4 Super and Manual Bean Choke (1,500 psi), Test #5 Lower Pipe Rams, XT-39 TIW, Test #6, Upper Pipe Rams, CMV 10 & 11, Test #7 Upper Pipe Rams, 12, 13, & 15, 3.5" FOSV, Test #8 CMV 14, Test #9 HCR Choke, Test #10 Manual Choke, Test #11, Lower Pipe Rams, Test #12 Annular, Perform accumulator test. Initial pressure=2950 PSI, after closure=1550 PSI, 200 PSI attained =20 sec, full recovery attained = 108 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Sullivan, Sean T. 0.0 0.0 2/1/2024 00:00 2/1/2024 03:00 3.00 MIRU, WHDBOP BOPE P Continue testing BOPE, Test #7 Upper Pipe Rams, 12, 13, & 15, 3.5" FOSV, Test #8 CMV 14, Test #9 HCR Choke, Test #10 Manual Choke, Test #11, Lower Pipe Rams, Test #12 Annular, Perform accumulator test. Initial pressure=2900 PSI, after closure=1575 PSI, 200 PSI attained =11 sec, full recovery attained = 121 sec. UVBR's= 5 sec, Annular= 22 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2045 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Sullivan, Sean T. (( Total Test time 7.5 hrs )) 0.0 0.0 2/1/2024 03:00 2/1/2024 03:30 0.50 SLOT, RPCOMP OTHR P R/D Testing equipment, clean up RF. 0.0 0.0 2/1/2024 03:30 2/1/2024 04:00 0.50 SLOT, RPCOMP SVRG P Service Rig Top drive 0.0 0.0 2/1/2024 04:00 2/1/2024 07:00 3.00 SLOT, RPCOMP SLKL P Start RU Dutch riser. Tool siezed at LDS unable to function L/D Dutch riser (Dutch Riser not required for operations./ DDT on Cement plug passed 30 minute no flow W/8.5 seawtaer in well and BOP's tested to 3500 PSI.) R/U HES Slickline Equalized RBP and pulled plug RD HES Slick- line . 0.0 0.0 2/1/2024 07:00 2/1/2024 08:00 1.00 SLOT, RPCOMP RURD P RU floor to pull completion. 0.0 0.0 2/1/2024 08:00 2/1/2024 08:30 0.50 SLOT, RPCOMP PULL P MU landing joint to hanger MU X-O's to lading joint BOLDS. 0.0 0.0 2/1/2024 08:30 2/1/2024 09:30 1.00 SLOT, RPCOMP PULL P Pull hanger and pup joints to floor. PUW=102K weight broke back to 85K. 7,259.0 7,229.0 Rig: NABORS 7ES RIG RELEASE DATE 2/10/2024 Page 3/8 2B-03 Report Printed: 3/5/2024 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) 2/1/2024 09:30 2/1/2024 10:30 1.00 SLOT, RPCOMP CIRC P Circulate and condition well 8.5# seawater SxS at 100 SPM 660 PSI. 7,229.0 7,229.0 2/1/2024 10:30 2/1/2024 10:45 0.25 SLOT, RPCOMP OWFF P OWFF for 15 minutes no flow. RD circulating eq. blow down top drive. 7,229.0 7,229.0 2/1/2024 10:45 2/1/2024 18:00 7.25 SLOT, RPCOMP PULL P Pull 3.5# EUE 8rd tubing PUW=86K F/7229' T/Surface *** Note: 3-1/2" EUE Cut joint 19.92' 7,229.0 0.0 2/1/2024 18:00 2/1/2024 20:00 2.00 SLOT, WHPST OTHR P Load out remaining pulled tubing out of pipe shed, inspect cut joint, clean rig floor, load milling assembly components into shed, get measurments. Rig up RF for milling operations. 0.0 0.0 2/1/2024 20:00 2/1/2024 20:30 0.50 SLOT, WHPST SFTY P Pre-spud/PJSM with crews. 0.0 0.0 2/1/2024 20:30 2/1/2024 23:00 2.50 SLOT, WHPST BHAH P M/U Milling BHA - 5-3/4" Cut Lip Shoe, 3.1/2" inner dress off mill, Wash Pipe Extension, Wash Over Boot Basket, 3- 1/2" Flex Joint, Upper String Mill, XO (3- 1/2" IF x XT39) HWDP x 1, Oil Jars, String Magnets x 2, and XT39 Pup Joint. *** Note: Swallow 5.28", Mill 4.37" Shear pins 1.1" *** Note: Install Wear Ring 0.0 108.8 2/1/2024 23:00 2/2/2024 00:00 1.00 SLOT, WHPST TRIP P TIH with Milling/Drift BHA #1 108.8 587.0 2/2/2024 00:00 2/2/2024 00:30 0.50 SLOT, WHPST SVRG P Rig Service - Top Drive and Iron Roughnecks 587.0 587.0 2/2/2024 00:30 2/2/2024 08:00 7.50 SLOT, WHPST TRIP P Continue RIH on singles from pipe shed with drift/milling BHA #2, drifting DP on v -door Swap out dies on hand slips RIH F/587' T/7281' PUW=140K SOW=97K 587.0 7,241.0 2/2/2024 08:00 2/2/2024 12:00 4.00 SLOT, WHPST MILL P Establish Milling parameters Rot=30 RPM Tq=6000 PR=3BPM Rot Wt=115K Tag top of tubing stump at 7259' ORKB 7253' 7ES RKB. Mill F7259' T/7268.2' ORKB (F/7253' T/7262.2' 7ES RKB) 7,241.0 7,259.0 2/2/2024 12:00 2/2/2024 13:00 1.00 SLOT, WHPST CIRC P Circulate high vis 25 BBL sweep 3.5 BPM. Sweep at bit Increase rate to 5 BPM sweeep the hole clean. Circulate the sweep out of the well. 7,259.0 7,259.0 2/2/2024 13:00 2/2/2024 13:15 0.25 SLOT, WHPST OWFF P OWFF for 15 minutes 0 flow 7,259.0 7,259.0 2/2/2024 13:15 2/2/2024 16:00 2.75 SLOT, WHPST TRIP P TOOH with milling BHA #1 F/7268.2' ORKB (7262.2' 7ES RKB) T/7150' polish casing from 7150 to 7050'. Continue TOOH F/7050' T/587 7,259.0 587.0 2/2/2024 16:00 2/2/2024 16:30 0.50 SLOT, WHPST BHAH P Rack BHA and inspect mill. Empty boot basket. 587.0 0.0 2/2/2024 16:30 2/2/2024 17:00 0.50 SLOT, WHPST BHAH P MU BHA 0.0 587.0 2/2/2024 17:00 2/2/2024 19:45 2.75 SLOT, WHPST TRIP P TIH F/587' T/7,267' PUW=140k, SOW=95k 587.0 7,267.0 Rig: NABORS 7ES RIG RELEASE DATE 2/10/2024 Page 4/8 2B-03 Report Printed: 3/5/2024 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) 2/2/2024 19:45 2/3/2024 00:00 4.25 SLOT, WHPST MILL P Establish Milling parameters Pump rate 68 spm/4 bpm/575 psi Rot=60 RPM Tq=6500 PR=4BPM Rot Wt=111K ROP slowed down, assuming on collar. Lower pump rate 50 spm/3 bpm/305 psi Tag top of tubing stump at 7,262' ORKB 7272' 7ES RKB. Mill F7267' T/7277' 7ES RKB 7,267.0 7,277.0 2/3/2024 00:00 2/3/2024 01:00 1.00 SLOT, WHPST CIRC P Pump 20 bbl high vis sweep @ 3 bpm, circulate around the corner, followed by 10 bbl spacer, PUH 6', launch final 20 bbl high vis sweep, increase pump rate to 6 bpm 7,277.0 7,270.0 2/3/2024 01:00 2/3/2024 01:30 0.50 SLOT, WHPST SVRG P TOOH F/7,270' T/7,249', Rig Service - Top Drive 7,270.0 7,249.0 2/3/2024 01:30 2/3/2024 04:15 2.75 SLOT, WHPST TRIP P TOOH F/7,249' T/Surface 7,249.0 112.0 2/3/2024 04:15 2/3/2024 05:00 0.75 SLOT, WHPST BHAH P L/D Milling BHA #3, inspect, gauge mills 112.0 0.0 2/3/2024 05:00 2/3/2024 07:45 2.75 SLOT, WHPST BHAH P Organize and verify WS BHA in pipe shed. PJSM for PU BHA. Pulling up to attach the WS wear rig pulled out of wellhead. 0.0 0.0 2/3/2024 07:45 2/3/2024 11:45 4.00 SLOT, WHPST RURD T Attempted to reset wear ring. unable to engage wear ring with LDS. Called Vault rep to address issue. removed seal from test plug to verify test plug wasn't preventing wear ring from making full engagement in tubing head. 5' to wellhead. Correct measurement from floor to ULDS was verified attempted to reset the wear ring. unable to engage ULDS in wear ring. wait on well head rep to deliver alternate wear ring. Well head rep brought new wear ring and no running tool. returned to wear house for running tool. 0.0 0.0 2/3/2024 11:45 2/3/2024 14:15 2.50 SLOT, WHPST BHAH P MU BHA and whipstock 0.0 569.6 2/3/2024 14:15 2/3/2024 15:15 1.00 SLOT, WHPST TRIP P TIH F/569.6 T/1228' 569.6 1,228.0 2/3/2024 15:15 2/3/2024 16:45 1.50 SLOT, WHPST CIRC P Attempt a shallow function test. pressuring up to 2100 PSI unable to circulate apparent blockage in BHA pressure falling off slowly continue to work pressure up to 2200 PSI and allow to drop off. Blow down top drive. 1,228.0 1,228.0 2/3/2024 16:45 2/3/2024 18:00 1.25 SLOT, WHPST TRIP T Blockage in the BHA unable to establish shallow test on treletrack. TOOH F/1228 T/569 1,228.0 569.0 2/3/2024 18:00 2/3/2024 19:30 1.50 SLOT, WHPST BHAH T Brake down BHA until we could find blockage. Screen Sub seems to be fully open. brake out screen sub for inspection. brake floats out, found metal pieces on top of floats, Seems MWD is plugged off. 569.0 72.8 2/3/2024 19:30 2/3/2024 21:00 1.50 SLOT, WHPST BHAH T Load backup MWD tool into pipeshed, start warming it up, sim-ops pull remaining BHA from hole 72,84' and inspect mill. 72.8 0.0 2/3/2024 21:00 2/3/2024 22:45 1.75 SLOT, WHPST BHAH T M/U Gen II WS setting/Milling BHA w/4 new pins and 37k Shear screw (Batch #103687763) 0.0 570.0 Rig: NABORS 7ES RIG RELEASE DATE 2/10/2024 Page 5/8 2B-03 Report Printed: 3/5/2024 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) 2/3/2024 22:45 2/4/2024 00:00 1.25 SLOT, WHPST TRIP T Shallow hole test of Teletrac tools @ 652'/80 gpm 570.0 652.0 2/4/2024 00:00 2/4/2024 01:00 1.00 SLOT, WHPST DHEQ P 652', continue testing tools,150 gpm/3.6 bpm 200 gpm/4.75 bpm 652.0 652.0 2/4/2024 01:00 2/4/2024 05:30 4.50 SLOT, WHPST TRIP P Continue TIH on stands at reduced speed 45 fpm TIH F/652' T/72 PUW=135K SOW=105K 652.0 7,245.0 2/4/2024 05:30 2/4/2024 07:00 1.50 SLOT, WHPST WPST P Orient WS to 315.25* set WS at 7275 ORKB (7269' 7ES) 7,245.0 7,269.0 2/4/2024 07:00 2/4/2024 09:00 2.00 SLOT, WHPST CIRC P Circulate the well over to 11.6# WBM 47 vis 9.4 BPM at 2500PSI. Condition well. transfer 11.6# WBM to all pits. 7,269.0 7,269.0 2/4/2024 09:00 2/4/2024 09:30 0.50 SLOT, WHPST RURD P Blow down top drive and circulating lines. 7,269.0 7,269.0 2/4/2024 09:30 2/4/2024 11:30 2.00 SLOT, WHPST SLPC P Slip and cut drilling line 7,269.0 7,269.0 2/4/2024 11:30 2/4/2024 12:00 0.50 SLOT, WHPST SFTY P Hold pre-spud safety meeting 7,269.0 7,269.0 2/4/2024 12:00 2/4/2024 22:00 10.00 SLOT, WHPST MILL P Reestablish milling parameters PUW=135K SOW=105K Roll pumps 4 BPM 800 PSI Rot=70 RPM TQ=4900 Rot wt=110 PUW 120K 80 RPM=5300 Ft LBS 90 RPM=5500 Ft Lbs Tag at 7249.7' Start milling at 75 RPM 5- 7K Tq. WOB 3-5K Mill through casing T/7311' ORKB 7305' (7ES RKB) 7,269.0 7,305.0 2/4/2024 22:00 2/4/2024 22:45 0.75 SLOT, WHPST REAM P Ream casing exit pumping 5 bpm/200 spm/1,231 psi, Recep through casing exit x 2, cease rotating, lower pump rate 1/4 bpm/17 spm/390 psi, drift casing exit (clean). 7,305.0 7,305.0 2/4/2024 22:45 2/5/2024 00:00 1.25 SLOT, WHPST DISP P Displace well to new 11.6 ppg drilling fluid 7,305.0 7,305.0 2/5/2024 00:00 2/5/2024 00:15 0.25 SLOT, WHPST DISP P Continue displacing well with new 11.6 ppg drilling fluid 7,305.0 7,230.0 2/5/2024 00:15 2/5/2024 00:45 0.50 SLOT, WHPST OWFF P Shut down pump observe well for flow 7,230.0 7,230.0 2/5/2024 00:45 2/5/2024 01:15 0.50 SLOT, WHPST CIRC P Line up and pump dry job, 13.6 ppg 15 bbl. Monitor well for flow 7,230.0 7,230.0 2/5/2024 01:15 2/5/2024 04:30 3.25 SLOT, WHPST TRIP P TOOH F/7230' PUW=135K T/551' PUW=45K 7,230.0 551.0 2/5/2024 04:30 2/5/2024 07:00 2.50 SLOT, WHPST BHAH P LD BHA. #3 Window mill BHA F/551' To surface 551.0 0.0 2/5/2024 07:00 2/5/2024 07:30 0.50 PROD1, DRILL SVRG P Service top drive. 0.0 0.0 2/5/2024 07:30 2/5/2024 09:30 2.00 PROD1, DRILL BHAH P MU drilling BHA F/0 T/337' Verify tool face 0.0 337.0 2/5/2024 09:30 2/5/2024 10:00 0.50 PROD1, DRILL TRIP P TIH F/337' T/1150' Perform shallow surface test on MWD 337.0 1,150.0 2/5/2024 10:00 2/5/2024 11:00 1.00 PROD1, DRILL CIRC P Condition well w/11.6# Circ at 2 BPM at 650PSI 1,150.0 1,150.0 2/5/2024 11:00 2/5/2024 15:00 4.00 PROD1, DRILL TRIP P Continue TIH F/1150' T/4000' condition well. Continue to TIH 7243' Orient TF Establish Pump rates and ECD's 250 GPM= 1234 PSI in DP ECD=13.0 1,150.0 7,243.0 Rig: NABORS 7ES RIG RELEASE DATE 2/10/2024 Page 6/8 2B-03 Report Printed: 3/5/2024 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) 2/5/2024 15:00 2/6/2024 00:00 9.00 PROD1, DRILL DDRL P Slide F/7,303' T/7,355' Increase PR to 300 GPM ECD=13.2PPG Drill F/7355' 40 RPM 6K Tq. 300 GPM T/7,564' 7,243.0 7,564.0 2/6/2024 00:00 2/6/2024 01:00 1.00 PROD1, DRILL DDRL P Driling Ahead, PR to 300 GPM ECD=13.3PPG Drill F/7,564' RPM 6K Tq. 300 GPM T/7,612' *** Note: Average ROP 84 fph 7,564.0 7,612.0 2/6/2024 01:00 2/6/2024 02:30 1.50 PROD1, DRILL DDRL P 7,612' , Pump #1 shut down, increase pump #2 to rate 256 gpm/1,944 psi RBIH, Drill ahead 7,612' PUW=125 k, SOW=93 k *** Note: Average ROP 77 fph 7,612.0 7,660.0 2/6/2024 02:30 2/6/2024 06:00 3.50 PROD1, DRILL DDRL P Slide F/7,660' T/7,674', P/U stand, Pump 250 gpm/6 bpm/2,053 psi, Rotate F/7,674' T/7,759' Rot=50, TQ=6,100k 7,660.0 7,759.0 2/6/2024 06:00 2/6/2024 12:00 6.00 PROD1, DRILL DDRL P Continue rotating F/7,759'' T/8,042', pump 272 gpm/6.5 bpm/2,677 psi, Rot=50 rpm, TQ=7,400 k 7,759.0 8,042.0 2/6/2024 12:00 2/6/2024 18:00 6.00 PROD1, DRILL DDRL P Continue rotating F/8,042'' T/8350', pump 281 gpm/6.7 bpm/2,441 psi, Rot=60 rpm, TQ=7,200 k PUW=135 k pumps on, pumps off 150 k, SOW= 97 k Average ROP=113 fph 8,042.0 8,350.0 2/6/2024 18:00 2/6/2024 19:00 1.00 COMPZN, CASING CIRC P Circ 20 bbl Hi Vis sweep, chase with 2x BUS, total pumped 455 bbls, 6 bpm at 2200 psi, reciprocate 20 RPM, TQ 5.8K, 118 PUW, 108K SOW 8,350.0 8,350.0 2/6/2024 19:00 2/6/2024 19:30 0.50 COMPZN, CASING OWFF P Flow check well-slight flow that is slowing down. 8,350.0 8,350.0 2/6/2024 19:30 2/6/2024 22:30 3.00 COMPZN, CASING TRIP P Trip out of the hole, 140K UWT, Swabbing, Pump out at 125 gpm, 1000 psi, tight spot at 7945' rotate through at 20 rpm, pulled tight again at 7910'. UWT 155K, attempt to run back in hole and will not go down, No returns, rotate 30 rpm, work stuck pipe and increase pump rate to 6 BPM at 2300 psi. Got pipe to move and returns slowly came back. 8,350.0 7,943.0 2/6/2024 22:30 2/7/2024 00:00 1.50 COMPZN, CASING WASH P Wash down from 7943' to 8228', 3 BPM at 1000 psi, Wash and ream down from 8228 to 8323'. 7,943.0 8,323.0 2/7/2024 00:00 2/7/2024 02:00 2.00 COMPZN, CASING TRIP P Wash down from 7943' to 8228', 3 BPM at 1000 psi, Wash and ream down from 8228 to 8323'. 8,323.0 8,350.0 2/7/2024 02:00 2/7/2024 03:00 1.00 COMPZN, CASING TRIP P TOOH F/8,350' T/7,808', work through, continue TOOH F/7,808' T/7,230' 8,350.0 7,246.0 2/7/2024 03:00 2/7/2024 07:00 4.00 COMPZN, CASING CIRC P Above Window, circulate sweep around 7,246.0 7,246.0 2/7/2024 07:00 2/7/2024 11:00 4.00 COMPZN, CASING TRIP P TOOH F/7,246' T/338' 7,246.0 338.0 2/7/2024 11:00 2/7/2024 14:30 3.50 COMPZN, CASING BHAH P L/D Drilling BHA *** Note: Bit Grade 1-7-CT-S-N-X-MT- TD 338.0 0.0 2/7/2024 14:30 2/7/2024 15:45 1.25 COMPZN, CASING OTHR P Clean RF for liner operations 0.0 0.0 2/7/2024 15:45 2/7/2024 16:00 0.25 COMPZN, CASING PUTB P PJSM with rig crew and GBR 0.0 0.0 2/7/2024 16:00 2/7/2024 17:00 1.00 COMPZN, CASING PUTB P RU GBR to run 3.5" Hyd563 tubing 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/10/2024 Page 7/8 2B-03 Report Printed: 3/5/2024 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) 2/7/2024 17:00 2/7/2024 18:00 1.00 COMPZN, CASING BHAH P P/U 3.5" L-80, 9.3#, HYD 563 Liner BHA. Baker lock shoe track. 0.0 0.0 2/7/2024 18:00 2/7/2024 18:30 0.50 COMPZN, CASING SVRG P Service top drive 0.0 0.0 2/7/2024 18:30 2/7/2024 23:30 5.00 COMPZN, CASING PUTB P Run 3.5" HYD 563 to 1131', 35K SOW. PU x nipple, seal bore extension and baker ZXP LTP. PU HWDP and circulate through float shoe. 3 BPM at 200 PSI. 0.0 1,575.0 2/7/2024 23:30 2/8/2024 00:00 0.50 COMPZN, CASING RUNL P Trip in hole with liner on drill pipe stands from derrick . 45K SOW at 1575 and 50K SOW at 2334' 1,575.0 2,334.0 2/8/2024 00:00 2/8/2024 06:00 6.00 COMPZN, CASING TRIP P Trip in hole with liner on drill pipe stands from derrick . 50K SOW at 2334' 2,334.0 7,260.0 2/8/2024 06:00 2/8/2024 07:00 1.00 COMPZN, CASING CIRC P Condition hole @ 3 bpm, gas in returns, 7,260.0 7,260.0 2/8/2024 07:00 2/8/2024 08:30 1.50 COMPZN, CASING TRIP P TIH with 3.5" Liner 7,260.0 8,307.0 2/8/2024 08:30 2/8/2024 09:30 1.00 COMPZN, CEMENT TRIP P Space out, Cement Head, brake circulation, 4 bpm/95 spm/760 psi wash down towards bottom. 8,307.0 8,344.2 2/8/2024 09:30 2/8/2024 12:00 2.50 COMPZN, CEMENT CIRC P Circulate to Condition hole, 11.6 ppg in and out. 8,344.2 8,344.2 2/8/2024 12:00 2/8/2024 12:30 0.50 COMPZN, CEMENT CMNT P PJSM with HES, Nabors, MI SWACO for cement job 8,344.2 8,344.2 2/8/2024 12:30 2/8/2024 15:00 2.50 COMPZN, CEMENT CMNT P Pressure test cement lines flood and P/T surface lines from cementer to cement head 4,000 psi, (Good Test), primary cement job, start job as per cementing procedure, recep pipe throughout job set on depth 8,340', cement going down pipe, bump plug @ 1018 stks, hold 2,000 psi for 5 mins, bleed pressure floats are holding. pressure up against plug 3,800 psi, slack off and work pipe to confirm set, pressure up to 2,600 psi to release from running tool. Rotate 25 rpm, set down 40 k, closed annular. 8,344.2 7,130.0 2/8/2024 15:00 2/8/2024 16:00 1.00 COMPZN, CEMENT RURD P BD top drive and cement line, LD cement head. 7,130.0 7,130.0 2/8/2024 16:00 2/8/2024 16:30 0.50 COMPZN, CEMENT CIRC P Circulate out cement from 6836' at 8 BPM/1450 psi 7,130.0 7,130.0 2/8/2024 16:30 2/8/2024 17:30 1.00 COMPZN, CEMENT PRTS P P/T & chart packer 1,750 psi for 10 mins 11.6 ppg LSND in hole, Good Test, P/U and realese RS seal assembly. 7,130.0 7,130.0 2/8/2024 17:30 2/8/2024 18:30 1.00 COMPZN, CEMENT BHAH P Flush mud maifold and kill line with black water pill. BD kill line and mud manifold. 7,130.0 7,130.0 2/8/2024 18:30 2/8/2024 19:30 1.00 COMPZN, CEMENT OWFF P Flow check well and load completion equipment into pipeshed 7,130.0 7,130.0 2/8/2024 19:30 2/9/2024 00:00 4.50 COMPZN, CEMENT PULD P Pump 15 BBL dry job and start POOH and LD DP. At 7085' PUW = 130K 7,130.0 1,380.0 2/9/2024 00:00 2/9/2024 06:00 6.00 COMPZN, CEMENT PULD P POOH and LD DP. RIH with stood back drill pipe and LD drill pipe. 1,380.0 0.0 2/9/2024 06:00 2/9/2024 08:00 2.00 COMPZN, CEMENT PUTB P Clean RF and set up for completion ops. Confirm pipe and jewerly in shed Correct pipe tally 0.0 0.0 2/9/2024 08:00 2/9/2024 20:30 12.50 COMPZN, RPCOMP PUTB P P/U 3.5" L-80 563, 3.5" L-80 TN110SS 563, and 3.5" EUE 8rd tubing. Stab seal assembly into SBR and bottom out at 7200'. PU 2' and space out. Pull out of the seals. 0.0 7,200.0 Rig: NABORS 7ES RIG RELEASE DATE 2/10/2024 Page 8/8 2B-03 Report Printed: 3/5/2024 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) 2/9/2024 20:30 2/9/2024 22:30 2.00 COMPZN, RPCOMP DISP P Circulate well to CI seawater 3.5 BPM taking LSND mud returns to cuttings box. 0.0 0.0 2/9/2024 22:30 2/9/2024 23:00 0.50 COMPZN, RPCOMP THGR P Pump out the stack. Land tubing hanger & RILDS. 0.0 0.0 2/9/2024 23:00 2/10/2024 00:00 1.00 COMPZN, RPCOMP PRTS P PT TBG to 3500 psi for 30 min and chart. Trap 1750 on the tubing and PT the IA to 2500 psi for 30 minutes and chart. Drop the pressure on the tubing and shear the SOV. Turn on the pumps to verify SOV sheared. 0.0 0.0 2/10/2024 00:00 2/10/2024 01:00 1.00 COMPZN, RPCOMP OWFF P Open well for flow test. Blow down cement hose and rig down landing joint. 0.0 0.0 2/10/2024 01:00 2/10/2024 02:00 1.00 COMPZN, WHDBOP MPSP P Set BPV and PT down IA to 1000 psi for 10 minutes. Blow down 2nd kill line. Jet the stack and BD kill and choke lines. 0.0 0.0 2/10/2024 02:00 2/10/2024 06:00 4.00 COMPZN, WHDBOP NUND P Remove riser, remove turn buckles. break bolts on DSA and kill line. Rack back the stack and remove DSA. NU the tree. Test tree 250/5,000 psi 0.0 0.0 2/10/2024 06:00 2/10/2024 06:30 0.50 COMPZN, WHDBOP FRZP P PJSM, R/U LRS to well, P/T lines 3,500 psi, circulate 80 bbl of deisel freeze protect, 0.0 0.0 2/10/2024 06:30 2/10/2024 08:00 1.50 COMPZN, WHDBOP FRZP P R/U jumper tubing x IA and Allow well to U-tube R/D LRS 0.0 0.0 2/10/2024 08:00 2/10/2024 12:00 4.00 COMPZN, WHDBOP RURD P Pull RF mats and rotary bushings, super sucker and clean under rotary bushing. Working on Rig Move and Derrick Down checklist. *** Rig release at 12:00 noon 0.0 0.0 2/10/2024 12:00 2/10/2024 18:00 6.00 DEMOB, MOVE MOB P Trucks on location moving Electrician shack, Tool shack ect...Set rig tongs on floor and Bridle up blocks. Set top drive in stump and BD steam and water lines. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/10/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC) 7,501.0 2B-03A 11/20/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut tubing for RWO 2B-03A 11/26/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Well SIDETRACKED 3/17/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER 2 3/8 1.92 7,993.4 10,165.0 4.43 L-80 STL Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 7,275.0 Set Depth … 8,006.6 String Max No… 3 1/2 Set Depth …Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 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) 7,701.6 5,836.7 50.12 GAS LIFT 5.390 CAMCO KBUG 2.920 7,739.8 5,861.2 50.02 SBR 5.000 CAMCO OEJ-10 SBR 2.973 7,757.6 5,872.7 49.98 PACKER 5.867 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 7,797.6 5,898.4 49.89 PRODUCTION 5.390 CAMCO KBUG 2.920 7,865.7 5,942.4 49.66 PRODUCTION 5.390 CAMCO KBUG 2.920 7,904.0 5,967.2 49.56 BLAST RINGS 4.500 BLAST RINGS (2) 2.992 7,971.5 6,010.9 49.80 PRODUCTION 5.390 CAMCO KBUG 2.920 7,982.0 6,017.7 49.84 PACKER 5.875 BAKER FB-1 PACKER 4.000 7,984.5 6,019.3 49.85 SBE 5.000 BAKER SEAL BORE EXTENSION 3.000 7,999.8 6,029.1 49.90 NIPPLE 4.500 CAMCO D NIPPLE NO GO 2.750 8,005.8 SOS 4.570 CAMCO PE-500 SHEAR OUT SUB 2.992 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) 7,256.6 5,552.5 50.12 WHIPSTOCK Set WSS on tubing at 7275' ORKB top at 7256.63. Bottom of the slide at 7269.93 Baker G-2 H1501 50006 2/4/2024 0.000 7,271.1 5,561.8 50.13 ANCHOR LATCH Integral WS anchor set on tubing at 7275' ORKB. 3.94' OAL Baker H1505 40035 2/4/2024 0.000 7,662.0 5,811.3 50.22 TUBING PUNCH 3' OF TUBING PUNCH FROM 7662' TO 7665' RKB, 4 SPF, 0 DEGREE PHASE, 12 SHOTS TOTAL 10/30/2023 2.992 7,720.0 5,848.5 50.07 CEMENT RETAINER 3-1/2" QUADCO SVCR CEMENT RETAINER 11/3/2023 0.000 8,105.0 OBSTRUCTI ON Ran DV Camera to Observe Obstruction at 8105 1/25/2018 0.000 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) 7,993.4 6,025.0 49.88 SLEEVE 2.700 BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 8,318.1 O-RING 2.375 O-RING SUB 1.920 8,351.5 CMT DIVERTER 2.375 PORTED CEMENT DIVERTER 1.920 8,354.3 BAFFLE 2.375 SOLID BAFFLE SUB 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,939.0 7,958.0 5,989.9 6,002.2 C-4, 2B-03A 8/2/1984 12.0 IPERF 5.5" csg gun, 120 deg pH 8,409.0 10,164.0 A-4, 2B-03A 3/17/2003 99.0 IPERF SLOTTED LINER Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,993.4 10,165.0 6,025.0 Squeeze – Formation Squeeze 11/3/2023 7,721.0 7,993.4 5,849.1 6,025.0 Squeeze – Formation Squeeze PUMPED 21 BBLS OF 15.8 PPG CLASS G CEMENT FOR RESERVOIR ABANDONMENT 11/3/2023 2B-03A, 3/5/2024 11:39:59 AM Vertical schematic (actual) LINER; 7,993.4-10,165.0 IPERF; 8,409.0-10,164.0 Liner - Lower completion work over 2024; 7,141.0-8,350.0 PRODUCTION; 32.0-8,395.2 OBSTRUCTION; 8,105.0 WINDOW; 8,068.0-8,074.0 Squeeze – Formation Squeeze; 7,993.4 ftKB PACKER; 7,982.0 PRODUCTION; 7,971.5 IPERF; 7,939.0-7,958.0 PRODUCTION; 7,865.7 PRODUCTION; 7,797.6 PACKER; 7,757.6 Production String 1 Cement; 7,141.0 ftKB Squeeze – Formation Squeeze; 7,721.0 ftKB CEMENT RETAINER; 7,720.0 GAS LIFT; 7,701.6 TUBING PUNCH; 7,662.0 ANCHOR LATCH; 7,271.1 WHIPSTOCK; 7,256.6 Seal Assembly; 7,153.8 Mandrel – GAS LIFT; 6,515.2 Mandrel – GAS LIFT; 3,195.3 SURFACE; 34.1-3,161.3 CONDUCTOR; 35.0-110.0 Hanger; 32.0 KUP PROD KB-Grd (ft) 28.00 RR Date 8/15/1984 Other Elev… 2B-03A ... TD Act Btm (ftKB) 10,165.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115101 Wellbore Status PROD Max Angle & MD Incl (°) 50.90 MD (ftKB) 7,500.00 WELLNAME WELLBORE2B-03B Annotation Last WO: End DateH2S (ppm) 90 Date 12/3/2016 Comment SSSV: LOCKED OUT TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC - SCHLUMBERGER 1 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 198-011/ T38554 179-059/ T38555 179-112/ T38556 183-020/ T38557 186-002/ T38558 201-083/ T38559 193-133/ T38560 203-009/ T38561 184-022/ T38562 183-095/ T38563 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 10:47:17 -09'00' 203-009/ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Morales, Tony To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Cc:White, Bradley; NSK RWO CM; Cozby, Kelly; Hobbs, Greg S; Turcotte, Matthew Subject:7ES Nabors KRU 2B-03 BOPE Test 2/1/24 Date:Thursday, February 1, 2024 3:27:57 PM Attachments:Nabors 7ES 2-1-24.xlsx Tony Morales 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 805 797-6720 tony.morales@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. .58%$ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:7ES DATE: 2/1/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22030090 Sundry #323-653 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3043 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T90 P Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)2900 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1550 P Check Valve 0NA200 psi Attained (sec)11 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)121 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge: 1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 5 @ 2045 P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 22 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/29/24 18:00 Waived By Test Start Date/Time:1/31/2024 20:00 (date) (time)Witness Test Finish Date/Time:2/1/2024 3:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Nabors Test BOPE with 3.5'' & 4" test joints 250/3500. Annular tested on 3.5" test jnt. 250/3500. Alarms tested. Tony Morales/Matt Turcotte ConocoPhillips Mark Adams/Scott Kiser KRU 2B-03A Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022) 2024-0201_BOP_Nabors7ES_KRU_2B-03A 9 9 9 999 9 9 9 9 9 -5HJJ 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" H-40 110' 9-5/8" J-55 2751' 7" J-55 6101' 2-3/8" L-80 6119' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 21 bbls 15.8 ppg Class G 7501-7720'Balanced plug, 5 bbls 15.8 ppg Class G in IA, 3 bbls in Tubing Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 7721-7993' Tubing 7993-10165' Liner SUSPENDED 7939-7958' MD and 5990-6002' TVD (cemented) Slotted Liner: 8409-10164' MD and 6101-6119' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 26# 10165' 32' 6025' 62.5# 36# 110' 32' 8395' SIZE DEPTH SET (MD) 7758' MD/5873' TVD PACKER SET (MD/TVD) 24" 12-1/4" CASING WT. PER FT.GRADE 3/12/2003 CEMENTING RECORD 5950161 1450' MD/ 1437' TVD SETTING DEPTH TVD 5948806 TOP HOLE SIZE AMOUNT PULLED 507453 506162 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A Kuparuk River Field/ Kupaurk River Oil Pool ADL025655, ADL025656 1881' MD/ 1820' TVD (locked out) BOTTOM 50-029-21151-01-00 KRU 2B-03A689' FSL, 246' FEL, Sec. 19, T11N, R9E, UM 58' FNL, 2511' FEL, Sec. 31, T11N, R9E, UM 81-172 3/10/2003 10165' MD/ 6119' TVD 7501' MD/ 5709' TVD 126' P.O. Box 100360, Anchorage, AK 99510-0360 508398 5954836 3984' FNL , 1213' FEL, Sec. 30, T11N, R9E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 11/20/2023 203-009/ 323-546/ 323-310 233 sx Cold Set II 34'800 sx Cold Set III, 500 sx Cold Set II 4.43# 35' 7993' 3161'34' 35' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 25 sx Class G3" TUBING RECORD 350 sx Class G, 250 sx Cold Set I8-1/2" 7982' MD/6018' TVD 8008'3-1/2" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 8:16 am, Dec 15, 2023 Suspended 11/20/2023 JSB RBDMS JSB 010223 xG DSR-1/29/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1450' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A Suspend TPI (Top of Producing Interval). Authorized Name and Formation Name at TD:N/A Suspended Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. 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. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@conocophillips.com , C=US Reason: I am the author of this document Location: Date: 2023.12.14 15:57:23-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC) 7,501.0 2B-03A 11/20/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut tubing for RWO 2B-03A 11/26/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Well SIDETRACKED 3/17/2003 triplwj 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 35.0 110.0 110.0 55.00 H-90 WELDED SURFACE 9 5/8 8.92 34.1 3,161.3 2,751.2 36.00 J-55 BUTT PRODUCTION 7 6.28 32.0 8,395.2 6,100.8 26.00 J-55 BTC WINDOW 6 5.00 8,068.0 8,074.0 6,076.4 LINER 2 3/8 1.92 7,993.4 10,165.0 4.43 L-80 STL Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.0 Set Depth … 8,006.6 Set Depth … 6,033.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 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) 32.0 32.0 0.04 HANGER 8.000 MCEVOY GRAY TUBING HANGER 3.500 1,881.5 1,820.5 33.66 SAFETY VLV 5.937 OTIS FMX SAFETY VALVE (LOCKED OUT 5/29/1990) 2.813 2,014.4 1,928.3 37.98 GAS LIFT 5.390 CAMCO KBUG 2.920 4,135.4 3,418.8 43.86 GAS LIFT 5.390 CAMCO KBUG 2.920 5,742.1 4,548.4 47.52 GAS LIFT 5.390 CAMCO KBUG 2.920 6,962.6 5,363.1 49.95 GAS LIFT 5.390 CAMCO KBUG 2.920 7,701.6 5,836.7 50.12 GAS LIFT 5.390 CAMCO KBUG 2.920 7,739.8 5,861.2 50.02 SBR 5.000 CAMCO OEJ-10 SBR 2.973 7,757.6 5,872.7 49.98 PACKER 5.867 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 7,797.6 5,898.4 49.89 PRODUCTION 5.390 CAMCO KBUG 2.920 7,865.7 5,942.4 49.66 PRODUCTION 5.390 CAMCO KBUG 2.920 7,904.0 5,967.2 49.56 BLAST RINGS 4.500 BLAST RINGS (2) 2.992 7,971.5 6,010.9 49.80 PRODUCTION 5.390 CAMCO KBUG 2.920 7,982.0 6,017.7 49.84 PACKER 5.875 BAKER FB-1 PACKER 4.000 7,984.5 6,019.3 49.85 SBE 5.000 BAKER SEAL BORE EXTENSION 3.000 7,999.8 6,029.1 49.90 NIPPLE 4.500 CAMCO D NIPPLE NO GO 2.750 8,005.8 6,033.0 49.93 SOS 4.570 CAMCO PE-500 SHEAR OUT SUB 2.992 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) 7,259.0 5,554.1 50.12 CUT Cut tubing with WellTech Mechanical cutter. 3.55" blade extension. Tubing in compression when cut. Correlated with 1984 tubing tally per program. 11/26/2023 2.990 7,662.0 5,811.3 50.22 TUBING PUNCH 3' OF TUBING PUNCH FROM 7662' TO 7665' RKB, 4 SPF, 0 DEGREE PHASE, 12 SHOTS TOTAL 10/30/2023 2.992 7,720.0 5,848.5 50.07 CEMENT RETAINER 3-1/2" QUADCO SVCR CEMENT RETAINER 11/3/2023 0.000 8,105.0 6,089.7 69.90 OBSTRUCTI ON Ran DV Camera to Observe Obstruction at 8105 1/25/2018 0.000 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) 2,014.4 1,928.3 37.98 1 GAS LIFT DMY BK 1 0.0 11/22/2023 0.000 4,135.4 3,418.8 43.86 2 GAS LIFT DMY BK 1 0.0 11/22/2023 0.000 5,742.1 4,548.4 47.52 3 GAS LIFT DMY BK 1 0.0 11/22/2023 0.000 6,962.6 5,363.1 49.95 4 GAS LIFT OPEN 1 0.0 11/22/2023 1.000 7,701.6 5,836.7 50.12 5 GAS LIFT DMY BK 1 0.0 4/12/2012 0.000 7,797.6 5,898.4 49.89 6 PROD DMY BK 1 0.0 1/31/2018 0.000 7,865.7 5,942.4 49.66 7 PROD DMY BK 1 0.0 1/31/2018 0.000 7,971.5 6,010.9 49.80 8 PROD DMY BK 1 0.0 5/25/1995 0.000 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) 7,993.4 6,025.0 49.88 SLEEVE 2.700 BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 8,318.1 6,106.1 96.07 O-RING 2.375 O-RING SUB 1.920 8,351.5 6,102.8 94.52 CMT DIVERTER 2.375 PORTED CEMENT DIVERTER 1.920 8,354.3 6,102.6 94.28 BAFFLE 2.375 SOLID BAFFLE SUB 1.920 2B-03A, 12/14/2023 10:54:26 AM Vertical schematic (actual) LINER; 7,993.4-10,165.0 IPERF; 8,409.0-10,164.0 PRODUCTION; 32.0-8,395.2 OBSTRUCTION; 8,105.0 WINDOW; 8,068.0-8,074.0 Squeeze – Formation Squeeze; 7,993.4 ftKB PACKER; 7,982.0 PRODUCTION; 7,971.5 IPERF; 7,939.0-7,958.0 PRODUCTION; 7,865.7 PRODUCTION; 7,797.6 PACKER; 7,757.6 Squeeze – Formation Squeeze; 7,721.0 ftKB CEMENT RETAINER; 7,720.0 GAS LIFT; 7,701.6 TUBING PUNCH; 7,662.0 Cement Plug; 7,501.0 ftKB CUT; 7,259.0 GAS LIFT; 6,962.6 GAS LIFT; 5,742.1 GAS LIFT; 4,135.4 SURFACE; 34.1-3,161.3 GAS LIFT; 2,014.4 SAFETY VLV; 1,881.5 CONDUCTOR; 35.0-110.0 KUP PROD KB-Grd (ft) 38.11 RR Date 8/15/1984 Other Elev… 2B-03A ... TD Act Btm (ftKB) 10,165.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115101 Wellbore Status PROD Max Angle & MD Incl (°) 96.12 MD (ftKB) 8,299.11 WELLNAME WELLBORE2B-03A Annotation Last WO: End DateH2S (ppm) 90 Date 12/3/2016 Comment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,939.0 7,958.0 5,989.9 6,002.2 C-4, 2B-03A 8/2/1984 12.0 IPERF 5.5" csg gun, 120 deg pH 8,409.0 10,164.0 6,100.6 6,119.0 A-4, 2B-03A 3/17/2003 99.0 IPERF SLOTTED LINER Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,993.4 10,165.0 6,025.0 Squeeze – Formation Squeeze 11/3/2023 7,721.0 7,993.4 5,849.1 6,025.0 Squeeze – Formation Squeeze PUMPED 21 BBLS OF 15.8 PPG CLASS G CEMENT FOR RESERVOIR ABANDONMENT 11/3/2023 7,501.0 7,720.0 5,708.9 5,848.5 Cement Plug Balanced Plug 8 bbls of 15.8 ppg Class G Cement. 5 bbls in IA, 3 bbls in tubing 11/4/2023 2B-03A, 12/14/2023 10:54:27 AM Vertical schematic (actual) LINER; 7,993.4-10,165.0 IPERF; 8,409.0-10,164.0 PRODUCTION; 32.0-8,395.2 OBSTRUCTION; 8,105.0 WINDOW; 8,068.0-8,074.0 Squeeze – Formation Squeeze; 7,993.4 ftKB PACKER; 7,982.0 PRODUCTION; 7,971.5 IPERF; 7,939.0-7,958.0 PRODUCTION; 7,865.7 PRODUCTION; 7,797.6 PACKER; 7,757.6 Squeeze – Formation Squeeze; 7,721.0 ftKB CEMENT RETAINER; 7,720.0 GAS LIFT; 7,701.6 TUBING PUNCH; 7,662.0 Cement Plug; 7,501.0 ftKB CUT; 7,259.0 GAS LIFT; 6,962.6 GAS LIFT; 5,742.1 GAS LIFT; 4,135.4 SURFACE; 34.1-3,161.3 GAS LIFT; 2,014.4 SAFETY VLV; 1,881.5 CONDUCTOR; 35.0-110.0 KUP PROD 2B-03A ... WELLNAME WELLBORE2B-03A DTTMSTART JOBTYP SUMMARYOPS 7/5/2023 SUPPORT OTHER OPERATIONS RUN HOLE FINDER, FAIL @ ~7662' RKB. PASSING TEST @ 7602' RKB. ESTABLISH LLR .42 BPM @ 2500 PSI. CONDUCT INJECTIVITY TEST 2 BPM @ 2050 PSI, E-LINE UP NEXT AFTER SUNDRY APPROVAL, INPROGRESS 7/23/2023 SUPPORT OTHER OPERATIONS (PRE RWO) FT LDS/GN (COMPLETE), T POT (PASS) T PPPOT (PASS), IC POT (PASS), IC PPPOT (PASS), MITOA (PASS) @ 1800 PSI 8/2/2023 SUPPORT OTHER OPERATIONS RIH W 2.78" DRIFT TO NIPPLE AT 7999.8' PAINT A FLAG AT 7900' EOP, SET CEMENT RETAINER AT 7900' RKB, WHP-CIRC AND IA PRESSURES ALL TRACKING, DISCUSS WITH TOWN ENGINEER AND DECISION MADE TO MILL OUT RETAINER AND RESET ABOVE TBG LEAK. SLOW MILLING **** JOB IN PROGRESS **** 8/4/2023 SUPPORT OTHER OPERATIONS SLOW MILLING MADE IT TO 7964' CTMD POOH, F/P TBG TO 3000' CTMD, JOB SUSPENDED UNTIL CEMENTERS ARE AVAILABLE, JOB IN PROGRESS. 8/30/2023 SUPPORT OTHER OPERATIONS SET 3-1/2" D&D HOLE FINDER @ 7766' RKB, OBTAINED PASSING CMIT TO 2500 PSI. SET HOLE FINDER @ 7678' RKB, OBTAINED TBG TEST 2100 PSI / IA 1450 PSI, LDFN, JOB IN PROGRESS. 8/31/2023 SUPPORT OTHER OPERATIONS OBTAINED PASSING TBG TEST @ 7704' RKB W/ D&D HOLE FINDER. READY FOR PLAN FORWARD. LEAK IN TBG BETWEEN 7704' RKB 7766' RKB. 9/27/2023 SUPPORT OTHER OPERATIONS DRIFTED TUBING W/ 5' 2.5'' DRIFT TO 7957' SLM, IN PROGRESS 9/28/2023 SUPPORT OTHER OPERATIONS ATTEMTED TO SET HF @ 7969' RKB, PRE SET HF @ 6968' RKB. CALLED OFF JOB FOR RIG JOB, IN PROGRESS. 10/1/2023 SUPPORT OTHER OPERATIONS ATTEMPT TO FIND LEAK POINT IN THE C SANDS WITH HOLEFINDER. UNABLE TO GET TEST IN THE C SAND STRADDLE. MADE MULTIPLE SETS BELOW UPPER PACKER STARTING @ 7960' SLM (SEE LOG FOR DETAILS) ALL FAILED, THE LAST FAILING C SAND SET @ 7775' RKB (UPPER PACKER @ 7757' RKB) PLAN FORWARD NEEDED FOR CEMENT JOB. 10/30/2023 SUPPORT OTHER OPERATIONS SHOT 3FT OF HOLES IN 3-1/2" TUBING FROM 7662' TO 7665'' RKB (4 SPF, 12 HOLES TOTAL), CCL TO TOP SHOT = 5.6', CCL STOP = 7656.4', CORRELATE TO GLM @ 7701.6' FROM TUBING TALLY DATED 9/28/1984. PULLED A CCL LOG FROM 7800' TO SURFACE. JOB IS READY FOR CT (PUMPING OF FLUID UP NEXT) 2B-03 Suspend Summary of Operations 11/2/2023 SUPPORT OTHER OPERATIONS MIRU FOR CORRELATION LOG. RIH WITH GR/CCL/CEMENT RETAINER DRIFT. LOG FROM 7800' CTMD TO 6700' CTMD. GOOD DATA. RIG DOWN. JOB IN PROGRESS. 11/3/2023 SUPPORT OTHER OPERATIONS MIRU TO SET CEMENT RETAINER AND PUMP CEMENT PLUG. SET CEMENT RETAINER AT 7720' RKB. PUMPED 21 BBLS OF 15.8 PPG CLASS G CEMENT INTO RETAINER FOR RESERVOIR ABANDONMENT. POOH. LDFN. JOB IN PROGRESS. 11/3/2023 SUPPORT OTHER OPERATIONS CIRC-OUT WELL PUMPED 330 BBLS 9.8 BRINE DOWN TBG TAKING RETURNS UP IA TO PRODUCTION JOB COMPLETE 11/4/2023 SUPPORT OTHER OPERATIONS RU TO PUMP BALANCED CEMENT PLUG. PUMPED 8 BBLS OF 15.8 PPG CLASS G CEMENT. 5 BBLS IN IA AND 3 BBLS IN TUBING. RDMO. SLICKLINE TO FREEZE PROTECT WITHIN 24 HOURS. 11/5/2023 SUPPORT OTHER OPERATIONS PULL GLV @ 2014' RKB. (POCKET LEFT OPEN) LRS CIRC'D IN 115 BBLS OF DIESEL FREEZE PROTECT. READY FOR SW TOC IN 48 HOURS. 11/20/2023 SUPPORT OTHER OPERATIONS TAG TOC @ 7501' RKB, CONDUCT PASSING CMIT TO 1600 PSI (AOGCC WITNESSED BOB NOBLE)... JOB IN PROGRESS 11/23/2023 SUPPORT OTHER OPERATIONS DEPLOY CATCHER, SET DMY IN STA #1 @ 2014' RKB, PULL CATCHER.... SUCCESFUL DRIFT FOR E-LINE CUTTER. READY FOR DHD 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: Plugs (MD): Junk (MD): 10165'8105' 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 Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Wells Engineer Tubing MD (ft): Packer: 7758'MD/5873'TVD Packer: 7982'MD/6018'TVD SSSV: 1886'MD/1821'TVD Perforation Depth TVD (ft): Tubing Size: 8007' 10/21/2023 Packer: CAMCO HRP-1-SP PACKER: BAKER FB-1 SSSV: OTIS FMX STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025655, ADL0025656 203-009 P.O. Box 100360, Anchorage, AK 99510 50-029-21151-01-00 ConocoPhillips Alaska, Inc. KRU 2B-03A None/SuspendedKuparuk Oil PoolKuparuk River Field N/A Length Size Proposed Pools: Burst PRESENT WELL CONDITION SUMMARY 6119' 8100' 6088' None MD 110' 3161' 8395' 16" 9-5/8" 75' 3127' Perforation Depth MD (ft): 7939-7958' 8409-10164' (Slotted Liner) 8363' 2-3/8" 5990-6002' 6101-6119' (Slotted Liner) 10165'2172' 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov MPSP (psi): 3043 TVD 110' 2751' 6280' 6119' Tubing Grade: J-55 By Grace Christianson at 8:51 am, Dec 08, 2023 323-653 BOP test to 3500 psig Annular preventer test to 2500 psig 10-404 X X VTL 12/08/2023 A.Dewhurst 08DEC23 12/8/2023 DSR-12/8/23 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.12.08 14:24:11 -09'00'12/08/23 RBDMS JSB 121223 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty K Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2B-03A (PTD# 203-009). Well 2B-03A was a CTD lateral drilled from the original 2B-03 well in March, 2003. The original well was drilled and completed in 1984. The well remained a gas lifted producer for the Kuparuk A-sands after CTD in 2003. The well had rock production issues before CTD, and then enjoyed a season of less rock production. In 2017 however, additiona rock and sand production was noticed. Cleanouts of the lateral were attempted, but ultimate access the lateral was lost and flow diminished. The well was SI in August, 2019. In 2022, the well became a candidate for a rig workover and sidetrack to get back to A-sands. If you have any questions or require any further information, please contact me at +1503-476-2519. After a suspension of 2B-03A on a previously approved form sundry (323-310), the tubing will be pulled, whipstock set. A permit to drill will be submitted seperatly to drill a short slant well to reacquire the Kuparuk A-sand. A cemented liner will be landed and lastly a 3 1/2" gas lifted upper completion will be installed. 2B-03A RWO Procedure Kuparuk Producer Sidetrack Setup PTD #203-009 Page 1 of 2 Remaining Pre-Rig Work 1. Finish suspend of well. (Separate sundry 323-310) 2. Dummy off GLMs. 3. Perform tubing cut at ~7260’ RKB. a. Punch tubing above tubing cut as needed. Rig Work MIRU 1. MIRU Nabors 7ES on 2B-03A. (No BPV will be installed for MIRU due to internal risk assessment on N7ES.) 2. Circulate well over to seawater. 3. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 4. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing, Grow PC, Set whipstock 5. Pull BPV, MU landing joint and BOLDS. 6. Pull 3-1/2” tubing down to pre-rig cut. a. Grow and stretch of 7” production casing if experience any drift issues: set plug/ storm packer near surface, pressure test plug. ND to casing head and let grow, pull 7” casing and re-land slips and PO, nipple up new tubing spool and BOP’s, test flange break and IC packoffs. b. Continue to lay down tubing. 7. Set Whipstock at 7250’ TOWS oriented high side. Subsequent work to mill window and drill the 2M-24A sidetrack is covered in the Permit to Drill that will be submitted in parallel. General Well info: Wellhead type/pressure rating: Vetco Gray Gen III, 7-1/16” 5K top flange. Production Engineer: Natalie Dye Reservoir Development Engineer: Mandy Pogany Estimated Start Date: 10/21/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently shut in, with original Kuparuk suspended. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre rig cut, perform grow and stretch of 7” production casing if necessary, set whipstock in preparation to drill 2B-03B lateral BOP configuration: Annular / Pipe Rams / Blind Rams /Flow Cross/ Pipe Ram 2B-03A RWO Procedure Kuparuk Producer Sidetrack Setup PTD #203-009 Page 2 of 2 Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A (Tubing will be cut before pulling tubing with rig.) CMIT-T x IA Planned in Plug for Redrill/Suspend sundry referenced above. MIT-OA PASSED – 7/23/2023 IC POT &PPPOT PASSED – 7/23/2023 TBG POT &PPPOT PASSED – 7/23/2023 MPSP: 3043 psi using 0.1 psi/ft gradient Static BHP: 3645 psi / 6024’ TVD measured on 07/22/2023 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 35.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 55.00 Grade H-90 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 34.1 Set Depth (ftKB) 3,161.3 Set Depth (TVD) … 2,751.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 32.0 Set Depth (ftKB) 8,395.2 Set Depth (TVD) … 6,100.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description WINDOW OD (in) 6 ID (in) 5.000 Top (ftKB) 8,068.0 Set Depth (ftKB) 8,074.0 Set Depth (TVD) … 6,076.4 Wt/Len (l… Grade Top Thread Casing Description SLOTTED LINER OD (in) 2 3/8 ID (in) 1.920 Top (ftKB) 7,993.4 Set Depth (ftKB) 10,165.0 Set Depth (TVD) … Wt/Len (l… 4.43 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,993.4 6,025.0 49.88 SLEEVE BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 8,318.1 6,106.1 96.07 O-RING O-RING SUB 1.920 8,351.5 6,102.8 94.52 CMT DIVERTER PORTED CEMENT DIVERTER 1.920 8,354.3 6,102.6 94.28 BAFFLE SOLID BAFFLE SUB 1.920 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 32.0 Set Depth (ft… 8,006.6 Set Depth (TVD) (… 6,033.5 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.0 32.0 0.04 HANGER MCEVOY GRAY TUBING HANGER 3.500 1,881.5 1,820.5 33.66 SAFETY VLV OTIS FMX SAFETY VALVE (LOCKED OUT 5/29/1990) 2.813 7,739.8 5,861.2 50.02 SBR CAMCO OEJ-10 SBR 2.973 7,757.6 5,872.7 49.98 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 7,904.0 5,967.2 49.56 BLAST RINGS BLAST RINGS (2) 2.992 7,982.0 6,017.7 49.84 PACKER BAKER FB-1 PACKER 4.000 7,984.5 6,019.3 49.85 SBE BAKER SEAL BORE EXTENSION 3.000 7,999.8 6,029.1 49.90 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,005.8 6,033.0 49.93 SOS CAMCO PE-500 SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,105.0 6,089.7 69.90 OBSTRUCTION Ran DV Camera to Observe Obstruction at 8105 1/25/2018 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/ft )Type Com 7,939.0 7,958.0 5,989.9 6,002.2 C-4, 2B-03A 8/2/1984 12.0 IPERF 5.5" csg gun, 120 deg pH 8,409.0 10,164.0 6,100.6 6,119.0 A-4, 2B-03A 3/17/2003 99.0 IPERF SLOTTED LINER Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,014.4 1,928.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,265.0 4/12/2012 2 4,135.4 3,418.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,266.0 4/12/2012 3 5,742.1 4,548.4 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,300.0 4/12/2012 4 6,962.6 5,363.1 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 2/1/2018 5 7,701.6 5,836.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/12/2012 6 7,797.6 5,898.4 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 1/31/2018 7 7,865.7 5,942.4 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 1/31/2018 8 7,971.5 6,010.9 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 5/25/1995 Notes: General & Safety End Date Annotation 3/17/2003 NOTE: Well SIDETRACKED 11/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0 12/29/2015 NOTE: TAGGED ICE PLUG @1,733' SLM(removed 12/29/2015) Comment SSSV: LOCKED OUT 2B-03A, 2/2/2018 5:20:53 PM Vertical schematic (actual) SLOTTED LINER; 7,993.4- 10,165.0 IPERF; 8,409.0-10,164.0 PRODUCTION; 32.0-8,395.2 OBSTRUCTION; 8,105.0 WINDOW; 8,068.0-8,074.0 SOS; 8,005.8 NIPPLE; 7,999.8 SBE; 7,984.5 PACKER; 7,982.0 PRODUCTION; 7,971.5 IPERF; 7,939.0-7,958.0 PRODUCTION; 7,865.7 PRODUCTION; 7,797.6 PACKER; 7,757.6 SBR; 7,739.8 GAS LIFT; 7,701.6 GAS LIFT; 6,962.6 GAS LIFT; 5,742.1 GAS LIFT; 4,135.4 SURFACE; 34.1-3,161.3 GAS LIFT; 2,014.4 SAFETY VLV; 1,881.5 CONDUCTOR; 35.0-110.0 HANGER; 32.0 Last Tag Annotation Last Tag: RKB Depth (ftKB) 8,100.0 End Date 1/21/2018 Last Mod By pproven Last Rev Reason Annotation Rev Reason: H2S, TAG, OBSTRUCTION @8,105', GLV C/O-REPLACED HFCV's W/ DV's. (C- SANDS CLOSED) End Date 2/2/2018 Last Mod By pproven KUP PROD KB-Grd (ft) 38.11 Rig Release Date 8/15/1984 Annotation Last WO: End Date 2B-03A H2S (ppm) 90 Date 12/3/2016... TD Act Btm (ftKB) 10,165.0 Well Attributes Wellbore API/UWI 500292115101 Field Name KUPARUK RIVER UNIT Wellbore Status PROD Max Angle & MD Incl (°) 96.12 MD (ftKB) 8,299.11 2B-03B Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Conductor 110 110 16 15.06 55 H90 Surface 3161 2751 9.625 8.921 36 J55 Production 8395 6101 7 6.276 26 J55 Liner 8350 6257 3.5 2.992 9.3 L80 Tubing 7200 5516 3.5 2.992 9.3 L80 PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L80/TN110 EUEM Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco MMG gas lift mandrels @ TBD PROPOSED CEMENTED 3.5" LINER 5.0" x 7.0" Liner Top Packer @ xxxx' RKB (4" ID) SBE 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3.5" Cemented Liner Across A-sand Interval 3-1/2" Landing Collar 3-1/2" Float Collar 3-1/2" Float Shoe REMAINING COMPLETION LEFT IN HOLE 3.5" x 7.0" Packer (7758' RKB) GLM Blast Rings GLM 3.5" x 7.0" Packer (7982' RKB) 2-3/8" CTD Liner Top (7993' RKB) 2.75" D-Nipple (8000' RKB) Camco SOS @ 8006' RKB Surface Casing Production Casing Conductor A-sand perfs C-sand Perfs 7758' RKB TOWS ~ 7250' RKB 7982' RKB TOW: 8066.5', TD ~ 8350' RKB C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-11-02_21172_2B-03A_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21172 KRU 2B-03A 50-029-21151-01 Coil Flag 02-Nov-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 203-009 T38125 11/21/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 11:26:22 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 19 Township: 11N Range: 9E Meridian: UM Drilling Rig: n/a Rig Elevation: n/a Total Depth: 10165 ft MD Lease No.: ADL 025655 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3161 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8395 Feet Csg Cut@ Feet Liner: 2 3/8" O.D. Shoe@ 10165 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8007 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Retainer 7720 ft 7501 ft 9.9 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1650 1620 1600 1600 IA 1650 1640 1610 1610 OA 600 600 600 600 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Plugback for redrill. A wireline tag was performed and top of cement was found to be 7501 ft MD. Bailer came back with looked, smelled, and felt to be contaminated cement. It was very thick with lots of small fine hard pieces. Passing CMIT TxIA. November 20, 2023 Bob Noble Well Bore Plug & Abandonment KRU 2B-03A ConocoPhillips Alaska PTD 203-009, Sundry 323-546 none Test Data: P Casing Removal: Brent Rogers Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-1120_Plug_Verification_KRU_2B-03A_bn 9 9 8PLDW 999 9 9 9 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 gp contaminated cement. James B. Regg Digitally signed by James B. Regg Date: 2023.12.03 18:05:12 -09'00' 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: ___________________ 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): 10165'None Casing Collapse Structural Conductor Surface Intermediate 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 Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718 Senior Well Interventions Engineer Tubing Grade: Tubing MD (ft): 7758' MD and 5873' TVD 7982' MD and 6018' TVD 1881' MD and 1820' TVD Perforation Depth TVD (ft): Tubing Size: J-55 8007' 10/15/2023 Packer: Camco HRP-1-SP Rtvbl Packer Packer: Baker FB-1 Packer SSSV: Otis FMX Sfty Vlv (locked out) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025656 203-009 P.O. Box 100360, Anchorage, AK 99510 50-029-21151-01-00 ConocoPhillips Alaska, Inc. KRU 2B-03A N/A plugged for redrill Kuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6119' 8100' 6088' None MD 110' 2751' 110' 3161' 6101'8395' 16" 9-5/8" 75' 3127' Perforation Depth MD (ft): 7939-7958' Slotted Liner: 8387-10165' 8363' 2-3/8" 5990-6002' Slotted liner: -6119' 10165'2172' 3-1/2" 6119' 7" 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 9:00 am, Oct 05, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.10.04 10:46:13-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 323-546 SFD 10/5/2023 X Obsolete Form SFD SFD ADL 025655, Plug for Redrill VTL 10/20/2023 SFD SFD DSR-10/5/23 10-407X JLC 10/20/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.20 11:41:56 -08'00'10/20/23 RBDMS JSB 102323 Date: 10-3-23 Date of Work: 10-15-23 Subject: 2B-03A Reservoir Abandonment Prepared by: Katherine O’Connor (214) 684-7400 Well History 2B-03A is a gas li0ed producer that has minor TxIA communica4on. It has been mostly shut in since 2018 due to rock produc4on. Fill cleanouts were a8empted to get the well back online, but not successful overall. This well will be sidetracked and redrilled. The objec4ve of this program is to abandon the reservoir in prepara4on for the sidetrack, which is scheduled for mid November2023. During the ini4al job, the retainer was set ~7900’ KB and there was reservoir x selec4ve IA x coil tubing backside x IA communica4on, either due to unknown leaks in the selec4ve or a failed retainer. Slickline did some diagnos4cs and discovered that the upper packer (at 7757’ KB) is likely not leaking, and the selec4ve has con=rmed leaks. The path forward for this well will be to pump a reservoir plug through a retainer, and then lay in a balanced plug into the tubing and IA. Notes: Failed TIFL Aug 2022 Last tag 2/10/23 7993’ RKB Inclina4on Max: 92 deg @ 8299’ RKB (<50 degrees in tubing) Min ID: 2.813” TRSV @ 1881’ RKB Last SBHP 02/10/23 || 3542 psi || 7993’ RKB Planned KOP for sidetrack ~7250’ RKB Tubing leak at 7662’ KB Calculaons Procedure: Eline 1. RIH with tubing puncher and punch ~3’ of holes at ±7662’ KB. Fullbore 1. Within 24 hours of coil rigging up, Iuid pack tubing and IA with ~ 330 bbl corrosion inhibited brine (do not want Iuid to swap before cemen4ng). (275 bbl volume x 1.2) Coil String Top Bottom Size ID bbls/ft volume ft/bbl notes 3.5" tubing 0 8006 3.5" 9.3# 2.992" 0.0087 69.6 115.0 3.5" x 7" annulus (IA) 0 7757 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 204.9 37.9 calc'd from packer 2-3/8" liner 8006 10165 2-3/8" 4.43# 1.920" 0.0036 7.7 279.2 total liner (slotted + solid) 2-3/8" (only) slotted liner 8387 10165 2-3/8" slotted 1.920" 0.0036 6.4 279.2 slotted liner 1. RU coil and cement unit 2. Set retainer at ±7710’ KB 3. The total cement needed is 29 bbls (±21 below retainer and ±8 for balanced plug) for planned TOC at 7500’ RKB. Recalculate cement volumes as necessary depending on retainer depth. 4. Pump the following cement schedule for the reservoir job: a. ±10 bbl diesel to establish injec4vity b. ±10 bbl freshwater spacer c. ±21 bbls 15.8ppg Class G cement 5. A0er 21 bbls pumped, uns4ng from retainer and circulate out any remaining cement 6. CMIT-TxIA to 1000 psi to ensure retainer is closed 7. Open the IA and establish 1-to-1 returns pumping down the coil and taking returns from the IA with the wellhead shut-in. As soon as the Iow path is con=rmed, begin pumping the following cement schedule for the balanced plug cement job: a. ±10 bbl freshwater spacer b. ±8 bbls 15.8ppg Class G cement c. 2 bbl freshwater spacer d. Coil displacement 8. With 5 bbls of cement pumped into the IA, shut in IA and lay remaining 3 bbls of cement into the tubing. 3 bbls of cement should =ll the tubing from the retainer to ~7,365’. 9. Begin pumping a contam pill and clean out the tubing down to a TOC of 7500’ KB . POOH a8emp4ng to circulate 1-to-1 returns down the coil and out the wellhead. Once all cement is in place, try not to pressure up either the wellhead or the IA to avoid pushing cement in or out of the IA. Leave tubing and IA pressures equal at all 4mes if possible. 10. RDMO Slickline & Fullbore 1. WOC for minimum 24 hours. No4fy AOGCC inspector of cement 4ming and plug tag at least 24 hours in advance. 2. RU Slickline and PT equipment as required 3. RIH to tag TOC (AOGCC witness) @ approx. 7500’ RKB, record results 4. CMIT-TxIA to 1500 psi (AOGCC witness), record results TOC 7500’ RKB Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer KRU 2B-03A 203-009 323-546 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: ___________________ 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): 10165'None Casing Collapse Structural Conductor Surface Intermediate 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 7939-7958' Slotted Liner: 8387-10165' 8363' 2-3/8" 5990-6002' Slotted liner: -6119' 10165'2172' 3-1/2" 6119' 7" 16" 9-5/8" 75' 3127' Perforation Depth MD (ft): MD 110' 2751' 110' 3161' 6101'8395' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6119' 8100' 6088' None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025656 203-009 P.O. Box 100360, Anchorage, AK 99510 50-029-21151-01-00 ConocoPhillips Alaska, Inc. KRU 2B-03A N/A plugged for redrill Kuparuk River Oil Pool Kuparuk River Field N/A Tubing Grade: Tubing MD (ft): 7758' Md and 5873' TVD 7982' MD and 6018' TVD 1881' MD and 1820' TVD Perforation Depth TVD (ft): Tubing Size: J-55 8007' 6/19/2023 Packer: Camco HRP-1-SP Rtvbl Packer Packer: Baker FB-1 Packer SSSV: Otis FMX Sfty Vlv (locked out) 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718 Senior Well Interventions Engineer 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 3:31 pm, May 25, 2023 323-310 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.05.25 14:57:57-08'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor Plug for Redrill SFD 10-407 SFD 6/8/2023 X Suspension expires 12/31/2023 DSR-5/26/23 X SFDADL0025655, VTL 6/26/2023BWH 6/26/23 06/26/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.26 14:47:08 -08'00' RBDMS JSB 062723 Date: 5-22-23 Date of Work: 6-19-23 Subject: 2B-03A Reservoir Abandonment Prepared by: Katherine O’Connor (214) 684-7400 Well History 2B-03A is a gas liŌed producer that has minor TxIA communicaƟon. It has been mostly shut in since 2018 due to rock producƟon. Fill cleanouts were aƩempted to get the well back online, but not successful overall. This well will be sidetracked and redrilled. The objecƟve of this program is to abandon the reservoir in preparaƟon for the sidetrack, which is scheduled for 15 August 2023. Notes: x Failed TIFL Aug 2022 x Last tag 2/10/23 7993’ RKB x InclinaƟon Max: 92 deg @ 8299’ RKB (<50 degrees in tubing) x Min ID: 2.813” TRSV @ 1881’ RKB x Last SBHP 02/10/23 || 3542 psi || 7993’ RKB x Planned KOP for sidetrack ~7250’ RKB CalculaƟons Procedure: Eline 1. Set fullbore retainer ±7900’ RKB Pumping 1. RU Halliburton cementers 2. The total cement pumped is 12.5 bbls (8 below retainer and 3.5 above retainer) for planned TOC at 7500’ RKB. Recalculate cement volumes as necessary depending on retainer depth. 3. Pump the following cement schedule: a. ±10 bbl diesel to establish injecƟvity b. ±10 bbl freshwater spacer c. ±9 bbls 15.8ppg Class G cement d. AŌer 7.5 bbls pumped, drop dart to shut retainer e. ±3.5 bbls cement f. Drop 5” foam ball g. ±48 bbls water h. ±18 bbls diesel for freeze protect String Top Bottom Size ID bbls/ft volume ft/bbl notes 3.5" tubing 0 8006 3.5" 9.3# 2.992" 0.0087 69.6 115.0 3.5" x 7" annulus (IA) 0 7757 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 204.9 37.9 calc'd from packer 2-3/8" liner 8006 10165 2-3/8" 4.43# 1.920" 0.0036 7.7 279.2 total liner (slotted + solid) 2-3/8" (only) slotted liner 8387 10165 2-3/8" slotted 1.920" 0.0036 6.4 279.2 slotted liner abandon the reservoir in preparaƟon for the sidetrack, 4. RDMO Slickline & Fullbore 1. WOC for minimum 24 hours. NoƟfy AOGCC inspector of cement Ɵming and plug tag at least 24 hours in advance. 2. RU Slickline and PT equipment as required 3. RIH to tag TOC (AOGCC witness) @ approx. 7500’ RKB, record results 4. CMIT-TxIA to 2500 psi (AOGCC witness), record results Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,100.0 2B-03A 1/21/2018 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: H2S, TAG, OBSTRUCTION @8,105', GLV C/O-REPLACED HFCV's W/ DV's. (C-SANDS CLOSED) 2B-03A 2/2/2018 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: TAGGED ICE PLUG @1,733' SLM(removed 12/29/2015) 12/29/2015 pproven NOTE: View Schematic w/ Alaska Schematic9.0 11/18/2010 ninam NOTE: Well SIDETRACKED 3/17/2003 triplwj 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 35.0 110.0 110.0 55.00 H-90 WELDED SURFACE 9 5/8 8.92 34.1 3,161.3 2,751.2 36.00 J-55 BUTT PRODUCTION 7 6.28 32.0 8,395.2 6,100.8 26.00 J-55 BTC WINDOW 6 5.00 8,068.0 8,074.0 6,076.4 LINER 2 3/8 1.92 7,993.4 10,165.0 4.43 L-80 STL Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.0 Set Depth … 8,006.6 Set Depth … 6,033.5 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 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) 32.0 32.0 0.04 HANGER 8.000 MCEVOY GRAY TUBING HANGER 3.500 1,881.5 1,820.5 33.66 SAFETY VLV 5.937 OTIS FMX SAFETY VALVE (LOCKED OUT 5/29/1990) 2.813 2,014.4 1,928.3 37.98 GAS LIFT 5.390 CAMCO KBUG 2.920 4,135.4 3,418.8 43.86 GAS LIFT 5.390 CAMCO KBUG 2.920 5,742.1 4,548.4 47.52 GAS LIFT 5.390 CAMCO KBUG 2.920 6,962.6 5,363.1 49.95 GAS LIFT 5.390 CAMCO KBUG 2.920 7,701.6 5,836.7 50.12 GAS LIFT 5.390 CAMCO KBUG 2.920 7,739.8 5,861.2 50.02 SBR 5.000 CAMCO OEJ-10 SBR 2.973 7,757.6 5,872.7 49.98 PACKER 5.867 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 7,904.0 5,967.2 49.56 BLAST RINGS 4.500 BLAST RINGS (2) 2.992 7,982.0 6,017.7 49.84 PACKER 5.875 BAKER FB-1 PACKER 4.000 7,984.5 6,019.3 49.85 SBE 5.000 BAKER SEAL BORE EXTENSION 3.000 7,999.8 6,029.1 49.90 NIPPLE 4.500 CAMCO D NIPPLE NO GO 2.750 8,005.8 6,033.0 49.93 SOS 4.570 CAMCO PE-500 SHEAR OUT SUB 2.992 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) 8,105.0 6,089.7 69.90 OBSTRUCTI ON Ran DV Camera to Observe Obstruction at 8105 1/25/2018 0.000 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) 2,014.4 1,928.3 37.98 1 GAS LIFT GLV BK 1 1,265.0 4/12/2012 0.156 4,135.4 3,418.8 43.86 2 GAS LIFT GLV BK 1 1,266.0 4/12/2012 0.156 5,742.1 4,548.4 47.52 3 GAS LIFT GLV BK 1 1,300.0 4/12/2012 0.156 6,962.6 5,363.1 49.95 4 GAS LIFT OV BK 1 0.0 2/1/2018 0.188 7,701.6 5,836.7 50.12 5 GAS LIFT DMY BK 1 0.0 4/12/2012 0.000 7,797.6 5,898.4 49.89 6 PROD DMY BK 1 0.0 1/31/2018 0.000 7,865.7 5,942.4 49.66 7 PROD DMY BK 1 0.0 1/31/2018 0.000 7,971.5 6,010.9 49.80 8 PROD DMY BK 1 0.0 5/25/1995 0.000 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) 7,993.4 6,025.0 49.88 SLEEVE 2.700 BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 8,318.1 6,106.1 96.07 O-RING 2.375 O-RING SUB 1.920 8,351.5 6,102.8 94.52 CMT DIVERTER 2.375 PORTED CEMENT DIVERTER 1.920 8,354.3 6,102.6 94.28 BAFFLE 2.375 SOLID BAFFLE SUB 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,939.0 7,958.0 5,989.9 6,002.2 C-4, 2B-03A 8/2/1984 12.0 IPERF 5.5" csg gun, 120 deg pH 8,409.0 10,164.0 6,100.6 6,119.0 A-4, 2B-03A 3/17/2003 99.0 IPERF SLOTTED LINER 2B-03A, 5/25/2023 1:54:28 PM Vertical schematic (actual) LINER; 7,993.4-10,165.0 IPERF; 8,409.0-10,164.0 PRODUCTION; 32.0-8,395.2 OBSTRUCTION; 8,105.0 WINDOW; 8,068.0-8,074.0 PACKER; 7,982.0 PRODUCTION; 7,971.5 IPERF; 7,939.0-7,958.0 PRODUCTION; 7,865.7 PRODUCTION; 7,797.6 PACKER; 7,757.6 GAS LIFT; 7,701.6 GAS LIFT; 6,962.6 GAS LIFT; 5,742.1 GAS LIFT; 4,135.4 SURFACE; 34.1-3,161.3 GAS LIFT; 2,014.4 SAFETY VLV; 1,881.5 CONDUCTOR; 35.0-110.0 KUP PROD KB-Grd (ft) 38.11 RR Date 8/15/1984 Other Elev… 2B-03A ... TD Act Btm (ftKB) 10,165.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115101 Wellbore Status PROD Max Angle & MD Incl (°) 96.12 MD (ftKB) 8,299.11 WELLNAME WELLBORE2B-03A Annotation Last WO: End DateH2S (ppm) 90 Date 12/3/2016 Comment SSSV: LOCKED OUT TOC 7500’ RKB ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ;;( 03 - Vex:¡ Well History File Identifier D Two-sided 11I11111I1111111111 Organizing (done) ~scan Needed I~ ~ R~CAN \Ø' Color Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner o Diskettes, No. D Other, No/Type: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: NOTES: Scanning Preparation I x 30 = ,-~D D Other:: ' .' Date: ~ ()$' 151 VI1-iJ , , 1- Date: c/ a g / OS 151 yV1 0 + 13 = ~pTAL J?AGES 4-3 (Count does not ¡no ude cover sheet) JAAf Date: L- a. <? OS/sl Y VI - I BY: Helen ~(Maria ) Project Proofing BY: Hel~" Mari~ BY: Helen Maria Production Scanning Stage 1 Page Count from Scanned File: L- Lf (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VY~S Heier( Maria~_ NO Stage 1 If NO in stage 1, page(s) discrepancies were found: Date: if ~ OS Isl YES NO VVlP BY: BY: Helen Maria Date: 151 1II1I11 I III I I Date: 151 Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • ~~ J ~~~'` ~~ I~ Well Job # ~~ ~„ ~ ~~~ r; ~~ 20~~ Log Description ,',~~~„ NO. 4861. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 09/05/08 1J-127 12096529 INJECTION PROFILE ~ ~ ~- 08/14/08 1 1 1 R-11 12096530 PRODUCTION PROFILE 08/15/08 1 1 iJ-118 12066541 MEM INJECTION PROFILE 08/17/06 1 1 1J-122 12066542 MEM INJECTION PROFILE / 08/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE (p 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE 4f - r (Q 08/19/08 1 1 1J-105 12066543 MEM INJECTION PROFILE '}- I(p 08/19/08 1 1 2E-12 11996653 SBHP SURVEY ~ 08/21/08 1 1 iJ-156 12080419 INJECTION PROFILE ( 08/21/08 1 1 1A-26 12080420 SBHP SURVEY G)Q -/ 5 08/22/08 1 1 1A-23 12080421 SBHP SURVEY ~ ` 08/22/08 1 1 2D-05 12080422 INJ PROF/LDL ~ - ~(p 08/23/08 1 1 1H-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 2B-03A 11996656 PRODUCTION PROFILE f 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY app- l(p / 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE / ~- ~ sQ 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE '~-~ O' G/5' 08/30/08 1 1 2E-13 12080431 SBHP SURVEY G- - ~G 08/31/08 1 1 2E-14 12080432 SBHP SURVEY L(•- 08/31/08 1 1 1 B-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 iH-18 11996666 INJECTION PROFILE c/ 09/03/08 1 1 F-10 11996660 PLUG SETTING RECORD 08/28/08 1 1 1 G-05 11996665 PACKER SETTING RECORD 09/02/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. `, ConocoPhiilips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 14, 2008 Mr. Tom Maunder `~ ~j~„' • ` ~ f --~ ~~--~ `"~`~ ~ . ~ ~. . ~, ~: . ~~W.- Alaska Oil & Gas Commission G 333 West 7th Avenue, Suite 100 3. Q ~ 1 Anchorage, AK 99501 ~~NE®MAY ~ p 20p~ ~ti Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled•with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with. the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped April 3 2008 and the corrosion inhibitor/sealant was pumped on April 20th and 30th of 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, __.. Perry Kle ConocoPhillips Well Integrity Projects Supervisor 4'wv.-' ,' ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 5/14/2008 Well Name 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 bbls ft al 26-01 184-115 25' 5" 3.25 23" ~ 4/3/2008 1.7 .4/20/2008 2B-02 184-122 30' 5" 0.5. 20" 413/2008 4.3 4/20/2008 26-03A .203-009 4' 0.5 33" 4/3/2008 10.2. 4/20/2008 2B-04 184-120 30' ~ 4 28" 4/3/2008. 6.4 4/20/2008 2B-06 184-022 26' 5 19" 4/3/2008 8.5 4/20/2008 2B-09 184-027 74' .10.5 32" 4/3/2008 11.1 4/20!2008 2B-10 184-029' 74' ~ 10.5 33" 4/3/2008 17 4/20/2008 2B-11 184-035 50' ~ 7.5 29" 4/3!2008 6 4/20/2008 2B-12 184-038 6' 1 29" 4/3/2008 6 4/20/2008 2H-01 184-077 SF n/a SF n/a 2.5 4/30/2008 2H-02 184-073 SF n/a SF n/a 2 4/30/2008 2H-03 184-070 SF n/a SF n/a 4 4/30/2008 2H-04 184-055 SF n1a SF n/a 2 4/30/2008 2H-08 185-171 2' 6" n/a 2' 6" n/a 25 4/30/2008 2H-10 185-260 SF n/a SF n/a 2 4/30/2008 2H-14 185-261 SF n/a SF n/a 2.5 4/30/2008 2H-12 185-262 SF n/a SF n/a 2.5 4/30/2008 2H-13 184-096 2" n!a 2" n/a 2 4/30/2008 2H-14 184-095 SF n/a SF n/a 2 4/30/2008 • -~,. =~-- MICROFILMED 03/0112048 DO NOT PLACE _y=-_. r ~'' -`'~~ ,- ~.. ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_InsertstMicrofilm_Marker. doc 10/31/05 Schlumbepgep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 SC;;ANNED NOV 2 S 200S AUn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk -- Well Job# Log Description Date BL Color CD 1R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1 D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 - 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N·09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 -' 2C·04 11022934 INJECTION PROFILE 10/14/05 1 ~M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A·01 A 11072922 INJECTION PROFILE 10/26/05 1 1 R·1 0 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1 E-170 11015750 USIT 10/19/05 1 1J-154 11022931 USIT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 SIGNED: 7L1- rJU DATE: / f ~, tJ ~ ().~ )- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thankyou. ~ 03 .-. tðo(J~ /7 M-p 2.~ 0 '7-- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030090 Well Name/No. KUPARUK RIV UNIT 2B-03A Operator CONOCOPHILLlPS ALASKA INC Spd (i) ~ÀW 1,. API No. 50-029-21151-01-00 MD 10165.-" TVD 6119./ Completion Date 3/17/2003 / Completion Status 1-01l ---- ----- REQUIRED INFORMATION Mud log Yes Samples No DATA INFORMATION Types Electric or Other Logs Run: Induction Memory, MWD. GR Well log Information: log/ Electr Data Digital Dataset Type Med/Frmt Number Name log Log Run Scale Media No ~------ i ~ 0 Asc c.:W38 LIS Verification ¡ Ftþt~ 12038 I nd uction/Resistivity 4flÐ 0 Asc ¿)'2038 LIS Verification ; RPt M- Directional Survey ~~ C Tf ~454 Gamma Ray C Pdf 2454 Gamma Ray ~~ Gamma Ray ~~ Gamma Ray L__~____ 25 Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent Current Status 1-01l UIC N Directional surve(Ye0 (data taken from logs Portion of Master Well Data Maint) Interval OHI Start Stop CH Received Comments A Directional Survey log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/4/2003. A Mud log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/4/2003. 7960 10175 Open 4/21/2003 Sonic, eel, GR - 4 reports on disk. 7450 10171 Open 4/21/2003 Sonic, CCl, GR 7450 10171 Open 4/21/2003 Sonic, CCl, GR - 4 reports on disk. 8067 10165 5/15/2003 7989 10165 Open 3/16/2004 Gamma Ray - MWD --- 7989 10165 Open 3/16/2004 Gamma Ray - MWD 7989 10165 Open 3/16/2004 Gamma Ray - MWD 7989 10165 Open 3/16/2004 Gamma Ray - MWD Sample Set Number Comments Permit to Drill 2030090 MD 10165 TVD 6119 ADDITIONAL INFORMATION Well Cored? Y @J Chips Received? ~ Analysis Received? - Y I t~ .-~---------- ------------ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Well Name/No. KUPARUK RIV UNIT 2B-03A Operator CONOCOPHILLlPS ALASKA INC Completion Date 3/17/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? GIN >~/N Formation Tops ~ Date: API No. 50-029-21151-01-00 UIC N ~ / r'~ M'vrj- "-' ) Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 2B-03A Contains the following: 1 LDWG Compact Disc ) d l\ 5 L\ (Includes Graphic Image files) 1 LDWG lister summary ) (9êJ3 -COer r&l. BAKER HUGHES Anchorage GEOScience Center 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional TVD Log LAC Job#: 444503 Sent By: Glen Horel Received B~0)\,'Á ~~<SQ1~"l:YV\.. Date: Mar 3, 2004 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 R~'bm~ RECEIVED 1':1.~ !l 'I 6 ~O' A I .r " . .... Vl.J. .t~a3~a 011 & Gas Cons. Commisston fJi:thor~e V'~ íl/y. .' '-//' ..' 1··t:::~~:;:;:_:;~:~·;~;:~:;;~:::i-1 :·······_········..·~·;¡¡:~.:i,:,:,~_.·.·... ..... "'1 ;:-~ ,~.: '~: ~, ~:J. ·,·····,···_-~··,···,········í;¡i~;ï·;;:;;--_··,·_·_··~·'-'~"'- f,;,-::·~·,·,·,·,·,!·:,·..,..,,,,,·,~1· .,..."...~,...,.~~;\:~ >".: t·" .... ~ . "1I1":":l"~ ...1A..."PC *fI ... :i;·;;"':;'¡'~'''·' ·ï;"~.. .....'.....",...., ...........'....... ........,. :::=~~ ~or1":;IiI'~ II'""\ !'0=~·-~~;f~i:~'~~~';'·~,~;~:·~~·~,··'·~~- :_~)'l~( _ ,NiMW'Þ, '"_, :>/j" ..~ _. '(UIo¡,:. ~,.' 1"0-"' ,."....,,~\ h ..........._................'_.,..~...._~~...~...'.-...__.,...,- ',"'".."~":~li,'.I\\I1iIIi.I'\'''""''~. ~~.~:'~,. j r" ::",.:," ~ ~~t~t~~,::~r' . ..._,-,.,.."......._. ) ., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator ConocoPhillips 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 689' NSL, 249' WEL, SEC. 19, T11 N, R09E, UM At top of productive interval 3984' SNL, 1213' WEL, SEC. 30, T11 N, R09E, UM At total depth 58' SNL, 2515' WEL, SEC. 31, T11N, R09E, UM X = 506157, Y = 5948807 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oil Pool RKB = 126' ADL 025656 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/10/2003 3/12/2003 3/17/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10165 6119 FT1!01'65 . :'6119 FT ImYes 0 No 22. Type Electric or Other Logs Run Induction Memory, MWD, GR Classification of Service Well 7. Permit Number 203-009 8. API Number 50-029-21151-01 9. Unit or Lease Name X = 508396, Y = 5954836 Kuparuk River Unit X = 507453, Y = 5950161 10. Well Number 2B-03A 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost 1889' MD 1450' (Approx.) -r/4.,J~~ aD&:-; "h?O 6072.' 'lV'þ ~ 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTI4 HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 110' 24" ,233 sx Cold Set II 9-5/8" 36# J-55 Surface 3161' 12-1/4" 800 sx Cold Set III, 500 sx Cold Set II 7" 26# J-55 Surface 8067' 8-1/2" 350 sx Class 'G', 250 sx Cold Set I 2-3/8" 4.43# L-80 79931 10165' 3" 25 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-3/8" Slotted Section MD TVD 8409'-10164' 6101'-6119' 25. SIZE 3-1/2",9.3#, J-55 TUBING RECORD DEPTH SET (MD) 8008' PACKER SET (MD) 7766' & 7985' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 22 Bbls of Diesel \" ·:·.~:ir::"ftl 1..3_f_·{1~~ ._...~;ifi:_.-~ ~ t.,... , ,_~",I'-"*_rl"__~~I,~ 27. Date First Production March 23, 2003 Date of Test Hours Tested 3/29/2003 15 PRODUCTION FOR TEST PERIOD OIL-BBL 566 OIL-BBL GAs-McF 1481 GAs-McF WATER-BBL 1132 WATER-BBL CHOKE SIZE GAS-OIL RATIO 176 962 OIL GRAVITY-API (CORR) Flow Tubing Casing Pressure CALCULATED Press. 180 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core c~E eEl VE D No core samples were taken. RBDMS BfL G~ M"~ 7 1003 O~'G1NAL MAY 0 1 2003 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate ) ) 29. ,I- ,[ \ 11"( ¡;"I I Geologìc Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth - - Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. t<alubik 7715' 5845' Kuparuk D & C 7936' 59881 Kuparuk B 7958' 6002' Kuparuk A 8054' 6064' Miluveach 8501' 6103' "1"'\' ,¡tI, "I' ''0. ~ ) _ Summary of Daily Drilling Reports, Surveys RECE'VED MAY 0 1 2003 A\aska au & Gas Cons. Commission Anchorage 31. List of Attachments: , " 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble . ~ ~ q. fit ~ Hie Technical Assistant Date Ot¡ ~ 30-03 28-03A 203-009 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Dan Kara, 564-5667 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1; Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, ìr'ìection for in-situ combustion. IrEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. IrEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. (~EM 27: Method of Operation; Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. , II) .' r ORIGINAL Form 10-407 Rev. 07-01-80 ') ') BP EXPLORA TrON Operations Summary Report Page 1 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2B-03 2B-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/3/2003 03:00 - 07:00 4.00 MOB P PRE Continue to prep rig for move to KRU. 07:00 - 08:00 1.00 MOB P PRE Hold PJSM with Security, Tool Service, and rig crews to discuss moving procedures. Exchange phone numbers etc. Complete F pad location inspection. 08:00 - 00:00 16.00 MOB P PRE Begin rig move. 3/4/2003 00:00 - 05:00 5.00 MOB P PRE Continue move to location. 05:00 - 10:00 5.00 MOB P PRE Arrive location. COntinue location prep, moving snow, laying pit liner, install tree scaffolding. Move rig over well. Accept rig at 1000 hrs on 3-4-03. 10:00 - 11 :30 1.50 RIGU P PRE Prep to NU BOPS. 11:30 -17:00 5.50 BOPSUR P PRE Remove tree cap. NU BOPS. Open all ram doors and check seals. Replace 2-3/8" combi's. Replace seals in HeR valve. 17:00 - 19:30 2.50 RIGU P PRE Install e-line reel on rig. Install lubricator above BOPs. Secure BOP stack in cellar with 4 chains. 19:30 - 00:00 4.50 BOPSUR P PRE Test BOP equipment. Witness waived by J. Crisp, AOGCC. HCR. No failures. 3/5/2003 00:00 - 01 :00 1.00 BOPSUR P PRE COmplete BOP test. Load pits with 350 bbls 9.2 formate mud. 01 :00 - 03:00 2.00 RIGU P PRE Pull coil to injector and stab same. Change pack offs in injector. 03:00 - 04:30 1.50 RIGU P PRE Reverse circulate coil for slack management. Complete hard line rig up to drilling choke manifold. 04:30 - 07:00 2.50 RIGU P PRE Install e-line coil connector. Test same. Change out slickline on pressure deploy winch. 07:00 - 08:30 1.50 RIGU P PRE Hold pre spud meeting in ops cab with rig team. Review drilling choke procedures and pressure deployment procedures. 08:30 - 11 :00 2.50 RIGU P PRE MU 4-1/16" pressure deployment lubricator. 11 :00 - 13:00 2.00 BOPSURP PRE Pull BPV. Found 100 psi on well. 13:00 - 15:00 2.00 RIGU P PRE Complete RU of lubricator. String slick line. MU slickline tools. Hook up pack off pump & line. Latch lubricator with side door elevators. Big improvement over hanging lubricator off of tugger. 15:00 - 15:45 0.75 STWHIP P WEXIT Hold extensive PJSM prior to beginning practice pressure deployment. Review procedure in detail with crews. 15:45 - 17:00 1.25 STWHIP P WEXIT Practice deploying milling BHA 17:00 - 18:00 1.00 STWHIP P WEXIT Pressure test BHA lubricator to 1500 psi. Drilling choke manifold leaking. Bleed pressure and tighten up same. 18:00 - 19:00 1.00 STWHIP P WEXIT Hold pre spud meeting in ops cab with night crew. Discuss well plan and choke & pressure deployment procedures. 19:00 - 19:45 0.75 STWHIP P WEXIT Pad operator Pump open surface safety valve. 19:45 - 20:00 0.25 STWHIP P WEXIT Pressure test lubricator and drilling choke to 3000 psi. 20:00 - 21 :45 1.75 STWHIP P WEXIT Practice pressure deployment. Step by step recording changes to draft procedure. NO GO plate prevented lubricator from making up. Unsting injector remove NO GO Plate and sting back onto well. 21:45 - 23:15 1.50 STWHIP P WEXIT RIH to 7,560'. 23:15 - 00:00 0.75 STWHIP P WEXIT Tie in log. 3/6/2003 00:00 - 00:15 0.25 STWHIP P WEXIT Tie in -22' correction using SWS CBL from 9/19/84. 00:15 - 01 :00 0.75 STWHIP P WEXIT RIH tag at 7,990'. Attempt to drill. Onlly 50 psi differential across BHA. Still have some "U": tube effect displacing brine to 9.2 ppg bio. Cycle EDC. Seen pressure differential increase to 300 psi but still in process of changing well over to 9.2 Bio. Printed: 3/24/2003 9:16:38 AM ) ) BP EXPLORATION Operations Summary Report Page 20f 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2B-03 2B-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/6/2003 00:15 - 01 :00 0.75 STWHIP P WEXIT Unable to get any motor work.Up wt 22K, On wt 7K FS= 2750 psi. 01:00 - 02:15 1.25 STWHIP N DFAL WEXIT POH 02: 15 - 06:00 3.75 STWHIP N WEXIT Change out EDC."O" ring was visable in the ports. BHI will have the shop tear it down. Stab on injector. Surface test failed no communications. Unstab injector. Repair failed connection in reel house. 06:00 - 08:30 2.50 STWHIP N DFAL WEXIT RIH with pilot mill assembly. 08:30 - 09:00 0.50 STWHIP N DFAL WEXIT Log tie in with GR after correcting -16 from EOP flag. -1 ' correction after tie in. 09:00 - 14:00 5.00 STWHIP P WEXIT Tag up at 7989'. Mill ahead. 3900 psi fs @ 1.61 bpm. Very slow milling. 0 nipple supposed to be at 8000' ELM. Lots of stalls. Metal and other solids in returns. Mill to 8000.1' Not sure what we just milled up. Orienter has failed. Will need to pull it before drilling pilot hole. 14:00 - 16:30 2.50 STWHIP P WEXIT Continue milling. Appear to be on 0 nipple (according to e-line jewelry depth & mwd tie in). Through nipple at 8001.5'. 16:30 - 17:45 1.25 STWHIP P WEXIT Continue to mill ahead at 10 fph to 8008'. 17:45 - 19:00 1.25 STWHIP N DFAL WEXIT POOH for orienter failure. 19:00 - 19:45 0.75 STWHIP N DFAL WEXIT PJSM for pressure undeployment 19:45 - 20:30 0.75 STWHIP N DFAL WEXIT Undeployment drill 20:30 - 21 :30 1.00 STWHIP N DFAL WEXIT Change out failed orienter. 21 :30 - 22:45 1.25 STWHIP N DFAL WEXIT RIH to 7,376' 22:45 - 23:00 0.25 STWHIP N DFAL WEXIT Correct to flag -17'. RI H to 7,530'. 23:00 - 23:25 0.42 STWHIP N DFAL WEXIT Tie in -1 correction after correcting to flag. 23:25 - 00:00 0.58 STWHIP N DFAL WEXIT RIH tag at 8015'. PU to downream thru tailpipe. 3/7/2003 00:00 - 00:30 0.50 STWHIP P WEXIT Ream tail pipe twice. Orienter not turning. Communication with orienter ok. Have correct orientation for ramp decide to begin cement ramp. RIH tag TO at 8,015'. 00:30 - 03:00 2.50 STWHIP P WEXIT Drill at 1.5 / 1.5 bpm at 3,670 psi. FS = 3,500 psi. DH annular pressure = 3,511 psi, DH tubing pressure 4,500 psi WOB 1-1.5K ROP 5-10. TF 165. Drill to 8,028. Unable to orient. 03:00 - 04:30 1.50 STWHIP N DFAL WEXIT POH for failed orientor. POH to 500'. Monitor well. OK. POH to surface. 04:30 - 05:00 0.50 STWHIP N DFAL WEXIT Change out orienter. 05:00 - 07:00 2.00 STWHIP N DFAL WEXIT RIH with pilot mill assembly. Shallow test MWD. Continue in hole. 07:00 - 07: 15 0.25 STWHIP N DFAL WEXIT Log grtie in. -18' correction to EOP flag. Log gr. Add l' correction. 07:15 -11:00 3.75 STWHIP P WEXIT Begin milling ahead. Unable to hold tool face due to reactive torque. MWD indicates entire BHA above orienter is turning due to reactive torque. Back ream from 8,029 to 8,000'. Make several oriented passes to try and open hole. Still unable to hold 210 deg TF. 11:00-12:15 1.25 STWHIP N DPRB WEXIT POOH to PU PDC bit and reduce motor angle. 12:15 - 13:45 1.50 STWHIP N DPRB WEXIT Practice presure undeploy with day crew. Pull test slickline winch and calibrate with strain guage. 1,400 psi creates 1,450# of pull. 13:45 - 14:00 0.25 STWHIP N DPRB WEXIT Wait on Weatherford hand to adjust motor from 1.75 deg to 0.5 deg. 14:00 - 16:45 2.75 RIGU P WEXIT NU 2-1/16" valves below btm set of rams on BOPs. These will allow access to well head to monitor WHP during pressure deployment operations. Test same to 300/3,500 psi. Printed: 3/24/2003 9:16:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) Page 3 of1 0 BP EXPLORATION Operations Summary Report 28-03 28-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 From - To Hours Task Code NPT Phase Description of Operations 3/7/2003 16:45 - 18:00 18:00 - 19:15 19:15 -19:30 19:30 - 20:00 20:00 - 22:00 22:00 - 22: 15 22:15 - 23:25 3/8/2003 23:25 - 00:00 00:00 - 01 :00 01 :00 - 01:45 01 :45 - 03:00 03:00 - 03:20 03:20 - 03:30 03:30 - 06:00 1.25 STWHIP N 1.25 STWHIP N 0.25 STWHIP N 0.50 STWHIP N 2.00 STWHIP P 0.25 STWHIP N 1.17 STWHIP N 0.58 STWHIP N 1.00 STWHIP N 0.75 STWHIP N 1.25 STWHIP N 0.33 STWHIP N 0.17 STWHIP N 2.50 STWHIP P Practice pressure deploy BHA. (0.5 mtr with 3.0 bi-center bit.) RIH to flag. Correct to flag -25.2'. Tie-in +2' correction. Soft wear upgrade to CTDS2 system required for additional BOP wellhead pressure transducer. RIH and tag at 8,029'. Attempt to drill. Unable to get any motor work. Getting good weight transfer 5-6 k WOB stacking max at surface -15K. Run into bottom 50 fpm unable to stall. POH POH. Change out failed Weatherford Motor for Baker Extreme. Output shaft sheared. RIH to flag @ 7,556'. Correct to flag -22.7'. Tie-in correction +7'. RIH tag at 8,028'. Drill at 1.52/1.54 bpm. with 3,600 psi ,3560 psi FS WOB .5k DH annular pressure 3588 psi, DH coil; pressure 3825 psi. WOB .3K. Numerous stalls having trouble establishing a new pattern . Drill ahead on cement. 3200 psi@ 1.5 bpm. Able to drill at 10-12 fph and maintain 210TF. Mill cement to 8059'. Log GR tie in . Add 2' correction. Pilot hole TD at 8061' POOH for 1.75 deg mtr & 2.8" parabolic speed mill. At surface. Get off well. MU 2.8" speed mill in 1.75 deg Weatherford mtr. Get on well. Test MWD. 3 chipped guage cutters, otherwise good condition. RIH with BHA #7 (1.75 mtr w/2.8 speed mill) Log gr tie in. Correct to EOP flag -15'. Correct to gr log +3'. Tag up in pilot hole at 8034'. Try several tool faces. Finally orient to 210L and ream through to 8041'. Continue in hole and tag at 8058'. 3200 psi@1.5 bpm. 300 dpsi. Mill ahead to 8065.3' at 30R. TF changed & motor work increased. Appear to have contacted csg wall. Log gr tie in. Add +3' correction to gr log. RIH to re-confirm TD. TD at 8068'. Cement ramp 8,062' - 8,068'. POOH for window mill. Change out mill and motor for BHA #8 one step window mill. Hi build motor and mill with brass ridge set gage passed thru BOP and Tree No Problem. Should have a reasonable chance on pressure deploy and undeploying. That will saving killing the well to change BHA's. WEXIT RIH to tie-in circulating at .35 bpm 1,280 psi. Set down one time at 1970'. RIH to 2662. MWD short identified. DFAL WEXIT POH short in MWD. DFAL WEXIT Check mill. (ridge set guage GONE) LD MWD. Change out lower quick connect. Unable to RIH with bha setting down 37' below table. Unable to rotate thru. POH. Make Plastic ridge set guage out of thread protector and Epoxy on to mill. RIH had to rotate but fell thru. Good Job by crew thinking out of the box. DFAL WEXIT RIH to 1,860' set down. Begin circulating at .6 bpm at 1700 psi. DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT WEXIT DPRB WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT WEXIT 06:00 - 10:30 4.50 STWHIP P WEXIT 10:30 - 10:45 0.25 STWHIP P WEXIT 10:45 - 12:15 1.50 STWHIP P WEXIT 12:15 - 12:45 0.50 STWHIP P WEXIT 12:45 - 14:15 1.50 STWHIP P WEXIT 14:15 - 14:30 0.25 STWHIP P WEXIT 14:30 - 15:30 1.00 STWHIP P WEXIT 15:30 - 16:45 1.25 STWHIP P WEXIT 16:45 -17:15 0.50 STWHIP P WEXIT 17:15 - 17:30 0.25 STWHIP P WEXIT 17:30 - 19:00 1.50 STWHIP P WEXIT 19:00 - 19:20 0.33 STWHIP P WEXIT 19:20 - 20:00 20:00 - 20:40 20:40 - 22: 15 22:15 - 23:00 0.67 STWHIP P 0.67 STWHIP N 1.58 STWHIP N 0.75 STWHIP N Printed: 3/24/2003 9:16:38 AM ') ) BP EXPLORATION Operations Summary.Report Page 4 of1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 28-03 28-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 Date From;.. To Hours Task Code NPT Phase Description of Operations 3/8/2003 22: 15 - 23:00 0.75 STWHIP N DFAL WEXIT RIH to 2600'. 23:00 - 00:00 1.00 STWHIP P WEXIT Continue to RIH correction to flag -16.5'. 3/9/2003 00:00 - 00:20 0.33 STWHIP P WEXIT Tie-in log +3' Correction. 00:20 - 06:00 5.67 STWHIP P WEXIT RIH tag up at 8,066.5'. Begiin time milling sequence. Mill at 1.56/ 1.56 bpm @ 3,600 psi. WOB .1 K,DH annular pressure 3,500 psi, DH coil pressure 4,200 psi. TF 30R. Mill to 8069.0' 06:00 - 09: 15 3.25 STWHIP P WEXIT Continue time milling sequence as per well plan. 3800 psi @ 1.52 bpm (on btm). TF: 15-30R. 2.0 - 3.0k# DH WOB. 3518 PSI ann press (11.37 ppg eqmw) 09:15 - 10:15 1.00 STWHIP P WEXIT Through window. Drill 9' rate hole below window. TOW: 8066.5', BOW: 8074'. Ream up & down through window at 30R. 10:15-11:00 0.75 STWHIP P WEXIT Pull into csg. Check for flow for 10 minutes. Slight Flow. Shut in driling choke. Monitor WHP. Increased 30 psi in 15 minutes, to 2983 psi. 11 : 00 - 11: 15 0.25 STWHIP P WEXIT Log gr tie in at 7550'. No correction. 11:15 -13:00 1.75 STWHIP P WEXIT POOH. Maintain WHP using drilling choke as per pressure schedule assuming 11.2 ppg formation pressure. 13:00-14:00 1.00 STWHIP P WEXIT At surface. Shut in well with 750 psi WHP. Pressure un-deploy. Went fairly smoothly for 1 st time under pressure. 14:00 - 15:30 1.50 STWHIP P WEXIT MU 1.75 deg wthrfd mtr with 2.77 bald crayola. Pressure deploy. Some trouble getting mill past 32' mark (pups below tbg hanger). Get on well. WHP: 675 psi. Equates to 11.38 ppg formation pressure (11.2 was predicted) Order out 250 bbls 11.8 ppg formate KWF. 15:30 - 15:45 0.25 STWHIP P WEXIT RIH. MWD shorted out. 15:45 - 16:00 0.25 STWHIP P WEXIT POOH to surface. Suspect lower quick connect. Will only have to get off well, but not un-deploy. 16:00 - 16:45 0.75 STWHIP P WEXIT At surface. Close rams & strip up off BHA with injector. Trouble shoot & repair short in upper quick connect. Get on well. Equalize to WHP. Open 2-3/8" slips. 16:45 - 19:15 2.50 STWHIP P WEXIT RIH with crayola mill assembly. Set down at 8,070' PU went to bottom 8,084'. 19:15-22:00 2.75 STWHIP P WEXIT Ream up @ 30 R 10' hour. Shut down pump. RIH 8074 no problems. Orient 75R. Ream up. Orient 45L Ream up. RIH dry tag 45L.NO Problem. PU to 7,949'. Open ECD. 22:00 - 22:50 0.83 STWHIP P WEXIT Circulate 5.4 bbl hi vis sweep followed by 9.2ppg Formate Flo Pro. 22:50 - 00:00 1.17 STWHIP P WEXIT POH 1.5 bpm at 100 fpm. following the choke schedule. 3/10/2003 00:00 - 00:15 0.25 STWHIP P WEXIT POH. 00: 15 - 02:00 1.75 STWHIP P WEXIT Pressure Undeploy BHA.Documenting changes to draft procedure step by step. 02:00 - 02:40 0.67 STWHIP P WEXIT Change out BHA. 02:40 - 04:30 1.83 DRILL P PROD1 Pressure deploy. Unable to get bha to fall thru top of well head. Worked wire. Bleed off pressure and unstab lubricator. Rotated bicenetred bit to orient off center side of bit to low side of motor build. Redeploy took a few attempt to work it through. 04:30 - 06:15 1.75 DRILL P PROD1 RIH with build assembly. 06:15 - 06:30 0.25 DRILL P PROD1 Log GR tie in. Add 6' correction. 06:30-07:15 0.75 DRILL P PROD1 RIH. Unable to get through window (?). Tagging up at 8078'. Work pipe & pump. No go. 07:15 - 07:30 0.25 DRILL P PROD1 Pull up hole. Re-Iog gr tie in. Add 6" correction. Indicates bit was tagging btm of open hole, not window. Printed: 3/24/2003 9: 16: 38 AM ) ') BP EXPLORATION Operations Summary Report Page 5 of1 0 Legal Well Name: 2B-03 Common Well Name: 2 B-03A Spud Date: 3/3/2003 Event Name: REENTER+COMPLETE Start: 3/3/2003 End: 3/17/2003 Contractor Name: NORDIC CALISTA Rig Release: 3/17/2003 Rig Name: NORDIC 2 Rig Number: 2 From - To Hours Task . Code NPT Phase Description of Operations 3/10/2003 07:30 - 13:00 5.50 DRILL P PROD1 Drill build section. 3550 psi @1.58 bpm. 300 dpsi. 1.58 in/1.6 out. WOB: 0.25 to 1 K # ROP: 30-40 FPH. TF: 30R. Going slow to establish smooth build & turn. Drill to 8275'. End of build. Got 35 deg d-Iegs out of 2.6 deg mtr & Hycalog bi-center. Projected 95 deg inc & 218 deg azm at bit (5988' TVD) This is a used formate mud system. Weight transfer excellent, so far. 13:00 - 13:30 0.50 DRILL P PROD1 Short trip to window. Hole smooth. 13:30 - 15:15 1.75 DRILL P PROD1 POOH for 1.1 deg mtr for build. Follow TOH pressure schedule. Losing some fluid to formation. Reduce circ rate until 1: 1 returns. 15:15 - 16:00 0.75 DRILL P PROD1 At surface. Pressure undeploy BHA. 16:00 - 17:00 1.00 DRILL P PROD1 MU 1.1 deg Baker extreme mtr with Hughs PDC bi-center. Pressure deploy BHA. Test MWD. Power fluctuation problems with MWD. 17:00 - 18:30 1.50 DRILL N DFAL PROD1 Un-deploy BHA. Trouble shoot MWD. 18:30 - 20:15 1.75 DRILL N DFAL PROD1 Replaced the lower quick connect, Double ball valves 1 power communication sub. Deploy BHA under pressure. Capturing revistion to draft procedure for pressure deployment. 20:15 - 21:30 1.25 DRILL P PROD1 RIH while circulating on choke in accordance with pumping schedule. 21 :30 - 21 :50 0.33 DRILL P PROD1 Correct to flag. Log in and correct +8'. 21 :50 - 22:00 0.17 DRILL P PROD1 RIH and tag at 8,277'. 22:00 - 23:30 1.50 DRILL P PROD1 1.56/1.58 bpm 3720 psi FS = 3,550 psi, .3K WOB, ROP 150. DH annular pressure 3,680 psi and DH coil pressure 4,170 psi. Drill to 8,450'. 23:30 - 00:00 0.50 DRILL P PROD1 Wiper to window. 3/11/2003 00:00 - 00: 15 0.25 DRILL P PROD1 Wiper to window. 00:15 - 02:45 2.50 DRILL P PROD1 Directionally drill from 8,450' with 1.52/1.55 BPM at 3,700 psi. 3,550 psi FS, 3K WOB, 140 ROP. DH annular pressure 3,700 psi, DH tubing pressure 4,220 psi, ECD 11.96. Drill to 8,700'. 02:45 - 03:20 0.58 DRILL P PROD1 Wiper to window. Smooth all the way. 03:20 - 05:00 1.67 DRILL P PROD1 Directionally drill from 8,700' with 1.53/1.74 BPM at 3,700 psi. 3,550 psi FS, 2.5K WOB, 122 ROP. DH annular pressure 3,720 psi, DH tubing pressure 4,220 psi, ECD 11.96. Drill to 8,900'. 05:00 - 06:00 1.00 DRILL P PROD1 Wiper to window. Hole smooth. 06:00 - 09:00 3.00 DRILL P PROD1 Drill ahead. 3500 psi@ 1.5 bpm. 100 dpsi on mtr. 1.5 in/1.5 out. WOB: 1.9K#. ROP: 80-120 FPH. Ann Prs: 3700 psi, ECD:12.0 ppg. Drill to 9100' 09:00 - 10:15 1.25 DRILL P PROD1 Short trip to window. Hole smooth. 10:15 - 15:18 5.05 DRILL P PROD1 Directionally drilling at 1.5 bpm @ 3800 psi. FS = 3560 psi. WOB 2.5k, ROP 27, DH Annular pressure 3,736, DH DP pressure 4,322' psi. Drill to 9,222'. 15:18 - 16:20 1.03 DRILL P PROD1 Wiper to window. Hole in good shape. 16:20 - 19:35 3.25 DRILL P PROD1 Directionally drill at 1.5 bpm @ 3,880 psi. FS = 3,700 psi. WOB 4 k, ROP 27-133, DH Annular pressure 3,739, DH DP pressure 4,422' psi. Drill to 9,420'. 19:35 - 20:45 1.17 DRILL P PROD1 Wiper to window. Hole smooth. 20:45 - 22:30 1.75 DRILL P PROD1 Directionally drill at 1.5 .1.5 bpm @ 3,878 psi FS= 3,700 psi. WOB 2-3K, ROP 60. DH Annular pressure 3,833 psi. DH DP pressure 4,374' psi. ECD 12.49. Drill to 9553. Begin mud swap. 22:30 - 23:30 1.00 DRILL P PROD1 Continue to directionally drill. Post mud swap values Printed: 3/24/2003 9:16:38 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') BP EXPLORATION Operations Summary Report 2 B-03 2 B-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 3/11/2003 22:30 - 23:30 ~ To Hours Task Code NPT Phase PROD1 3/12/2003 23:30 - 00:00 00:00 - 00:30 00:30 - 02:50 02:50 - 04:30 04:30 - 06:30 06:30 - 08: 15 08:15 - 09:10 09:10-11:10 11 : 1 0 - 11: 35 11:35-12:15 12:15-13:30 13:30 - 14:15 14:15 -15:00 15:00 - 17:20 3/13/2003 17:20 - 19:00 19:00 - 20:30 20:30 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 - 07:30 07:30 - 12:00 12:00 - 13:45 13:45 - 14:00 14:00 -15:30 1.00 DRILL P 0.50 DRILL P 0.50 DRILL P 2.33 DRILL P 1.67 DRILL P 2.00 DRILL P 1.75 DRILL P 0.92 DRILL P 2.00 DRILL P 0.42 DRILL P 0.67 DRILL P 1.25 DRILL P 0.75 DRILL P 0.75 DRILL P 2.33 DRILL P 1.67 DRILL P 1.50 DRILL P 3.50 BOPSUR P 3.50 BOPSURP 2.50 EVAL P 1.50 EVAL P 4.50 EVAL P 1.75 EVAL P 0.25 EVAL P 1.50 EVAL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 Description of Operations are:1.5/1.550 @ 3,750psi, FS =3500, WOB 3k ,ROP 180. DH annular pressure 3,688, DH DP pressure 4032, ECD 11.9 ppg. Drill to 9,630'. Wiper to window. 9,630 Wiper trip to window. Clean trip hole in good shape. Directionally dríll1.49 11.5 bpm @ 3,750 psi, FS =3500, WOB 3k ,ROP 60-120. DH annular pressure 3,750, DH DP pressure 4327, ECD 12.0 ppg. Drill to 9834. Wiper to window. Directionally drill 1.49 1 1.53 bpm @ 3,650 psi, FS =3550, WOB 2-3k,ROP 100. DH annular pressure 3,750, DH DP pressure 4275, ECD 12.0 ppg. Drill to 10030. Wiper to window. Directionally drill from 10030. Inc =88deg 1.5/1.5 bpm @ 3620psi. WOB=1.5-2Klbf, ROP= 70-90 FPH. DH Annular press 3820psi. DH DP press 4310psi, ECD 12.3 ppg. Drill to 10060. Drill from 10060, intersected bottom of A4, attempt to start climbing. Stacking, weight transfer worsening. WOB 750-2300Ibf. ROP slowing to 10-20FPH. Send Lubetex pill DH. Break through hard spot. ROP picked up to 100fph. Drill to 10160'md. Short trip 50' Directionally drill from 10160'md. 1.51 11.57bpm 3400psi, 91deg INC. WOB= 500-6001bf Stacking. DH annular 3750, DH DP press 4070psi, ECD=12.1. Attempt to drill, not making any progress, stacking. Poor weight transfer. Call town and decide to call TO at 10160'md. POH, Condition hole. Shut down pumps prior to window. Trap 800psi at surface while shut down. Tie-in. Power down ops cab, work on Schlumberger surface computers. Condition hole. RIH and tag td. Corrected TO 10165'md. POH at 25fpm, 1.5bpm. Shut down pumps while passing thru window, choking back well. POH following choke schedule. Pressure undeploy BHA. Test BOP. AOGCC Chuck Shieve waived witnessing the test. Continue pressure testing BOP. AOGCC Chuck Shieve waived witnessing test. PJSM. MU and Pressure deploy Memory restivity tool. RIH, pumping at 1.5bpm following press curves. 1.55bpm, circ press 3300psi. Log from 7500' down at 40fpm, 1.5bpm in 9.2ppg K Formate flo-pro. Tag TO. Allow 8.5ppg pill to get 3bbl above circ sub. Log up at 35fpm to 7500' laying in 8.5ppg pill. Log back down to TO at 46fpm without circulating. Circulate out 8.5ppg and POH following choke schedule. PJSM prior to pressure undeploying memory resistivity tool. Review procedure and checklist. Pressure undeploy memory Res tool. LD tool. MU and Test BHI driling assembly on Catwalk. Printed: 3/24/2003 9:16:38 AM ') ') BP EXPLORATION Operations Summary Report Page 7 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 28-03 28-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 Date From -To Hours Task Code NPT Phase Description of Operations 3/13/2003 15:30 - 16:45 1.25 EVAL P PROD1 Wait for results of memory Resistivity tool. Make sure we have good data prior to pressure Re-deploying cleanout assembly. 16:45 - 18:00 1.25 EVAL P PROD1 Pressure deploy cleanout assembly BHA #15. 18:00 - 22:15 4.25 EVAL P PROD1 RIH with BHA #15, following choke schedule. RIH 4k at surface. No motorwork but seeing negative weight as high as -6000 at @ 10,000' md. running out of push. Tag TD at 10,188 uncorrected. Correction has been averaging around -20'. Look like bottom. Pressure information 9.2 flo pro at 8000 MD 5900 TVD. Theoriticalliner top 8,000MD. An Friction Sur Choke DH annular pres BPM ECD 0 760psi 3600 psi 0 11.7 360 400 3644 .3 11.9 385 375 3649 .5 11.97 560 200 3614 1.0 11.84 738 22 3556 1.5 11.65 POH to 8,300. 22:15 - 23:00 0.75 EVAL P PROD1 RIH circulating @ 1.5 and 4200 psi into coil 16 bbl Hi vis kill wt pill follower by Kill weight brine. Reduce circulation rate to 1.36bpm @ 3677psi. With higher weight brine in coil seeing higher negatives weights. pill turning corner at 9950'. rate at .8 BPM, EDC 11.5 With 5 bbl of pill out at 10036' Shut down and continue to bottom. 23:00 - 00:00 1.00 EVAL P PROD1 POH circulating .3 bpm laying pill. Displace with kill weight 11.66 ppg per Micro Motion Meter. 660 psi choke pressure 11.66 EDC at 8800 md . Brine sample weight checked at 11.8+ ppg.@ 66 degrees.POH to 8000'. With Kill weight turning the corner. Sur Choke DH annular pressure BPM ECD 740 3580 0 11.8 300 3580 1.04 11.81 0 3610 1.5 11.88 3/14/2003 00:00 - 00:50 0.83 EVAL P PROD1 Surface Choke DH annular pressure o 3726 BPM .5 ECD 12.06 00:50 - 02:00 1.17 EVAL P 02:00 - 02:30 0.50 EVAL P 02:30 - 03:00 0.50 EVAL P 03:00 - 04:00 1.00 CASE P 04:00 - 12:00 8.00 CASE P PROD1 With 11.3+ back to surface, had to POH running close on volume of KWF left in the CT. We should have a good chance to displace the kill weight out from the top of the liner 8,000' if we start pumping at low rate .5 bpm. POH filling metal displacement. Displacing kill weight with 9.2 mud. At 4000' seeing just a trace of returns. 11.5+ ppg. Monitor well no flow. Total 3 bblloss during kill operation. Return fluid last weighed 11.6+ LD BHA #15 Freeze protect coil with diesel. Swap 2" eline reel for regular 2" CT. Unstab CT, stand back injector, suck CT back to reel. Injector maintenance. Drop PROD1 PROD1 COMP COMP Printed: 3/24/2003 9:16:38 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 28-03 28-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 Date From- To Hours Task Code NPT Phase Description of Operations 3/14/2003 04:00 - 12:00 8.00 CASE P COMP Eline reel onto lowboy trailer, PU new reel, intstall grapple connector and prep to thread CT over pipe shed to injector. Simops: PU 2-3/8" Slotted / Solid liner. Drift every connection on 2-3/8" with 1.85" drift on tugger, 1.90" drift will not pass. PU 1" CS Hydril (perform kick while tripping drill). 12:00 - 13:00 1.00 CASE P COMP Continue PU 1" Hydril work string. Fill annulus between 2-3/8" liner and 1", pump down 1" to insure stinger is stabbed into seal assembly. Good test. 13:00 - 15:30 2.50 CASE P COMP PU & position injector. Pull CT over pipe shed and stab injector. Install dart catcher. Displace methanol in CT reel. Install weld on eTC. Pull and Press test eTC. 15:30 -16:15 0.75 CASE P COMP Pump CT dart. CT Vol = 40bbls 16:15 - 16:35 0.33 CASE P COMP Position injector, Stab CT to liner running tool. 16:35 - 21 :30 4.92 CASE P COMP RIH with 2-3/8" solid/slotted liner. Take KWF to clean Pit #5. Work liner down circulating in mud for a little more lubricity. Increasing well head pressure via choke to offset reduction ofkill weight hydrostatic. Extensive stacking while running in hole but pickups are clean. Progress is slow pipe moving only a few feet per cycle. Worked liner to 10,172' ctm. Have 9.2 ppg back to surface by the time worked to bottom. 21 :30 - 23:00 1.50 CASE P COMP PU to ball drop position. Drop 5/8" phenolic ball and circulate at 1.8 bpm thru open choke. At 34.7 bbl displacement ( theoritical40.0 bbls) with 4400 psi sheared ball seat. PU 18,000 versis 29,000 off liner. RU Cementers. First time RU for Kuparuk DS cementers and for APC support. 23:00 - 23:30 0.50 CEMT P COMP PSJM for cementing. 23:30 - 00:00 0.50 CEMT P COMP Mix cement. 3/15/2003 00:00 - 01 :30 1.50 CEMT P COMP Charge lines and PT DS lines to 5,000 psi. Mix cement and pump 5 bbl 9.2 Brine ,5 bbllaytex cement, while circulating thru choke as required. Shut down holding 550psi on well. Suck back lines to inner reel valve. Had to blow Air assist to clearing lines. Rezero because of having to blow down to help clear line. Load dart and kick out with 1000psi. Pump 1.5 bbl.(mistake should have been .2bbl) Check to make sure dart has been kicked out. NO Didn't launch. Found dart back against the cap. Must have voided volume between inner an outer reel valves which allowed pressure in reel to push back dart. Retry and launch dart with 1000 psi pumped .2 bbl. Dart launched. Will have to displace on volume to avoid overdisplacement by 1.5 bbl. Stop displacement at 40 bbls ( theoritical volume to bump) and pull out of liner. 01 :30 - 02:00 0.50 CEMT P COMP PU above liner top holding 800 +- psi on well head. Circulate @ 2,150 psi .5 bpm to shear dart and clear .33 bbl cement volume from the 1" CS Hydril. Dart sheared at 41.5 bbls. This confirms micro motion volume. Pull to 7000' filling metal displacement while holding 800 psi. 02:00 - 07:30 5.50 CEMT P COMP Wait on cement while holding 800 psi on wellhead. 07:30 - 08:45 1.25 CEMT P COMP Swap well to KWF 11.8ppg, parked at 7000'md (5261'TVD). Start pumping at 1.5bpm with Opsi on wellhead. Monitor returns. Reducing pump rate as needed after KWF exits the stinger. 08:45 - 10:00 1.25 CEMT P COMP POH replacing coil voidage. 10:00 - 10:15 0.25 CEMT P COMP SAFETY meeting and Flow check Printed: 3/24/2003 9:16:38 AM ) ) BP EXPLORATION Operations Sum maryRéport Page 9 of1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2B-03 2B-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/15/2003 10:15 - 12:30 2.25 CLEAN P COMP LD 5 stands CS Hydril, liner running tool. PU Cleanout assembly, 1.875" HC mill, 1-11/16" motor, 72joints of CSHydril. 12:30 - 14:00 1.50 CLEAN P COMP RIH with clean out assembly, BHA #16. 14:00 - 14:30 0.50 CLEAN P COMP Pressure test liner lap to 2000psi. Close backside, double block HCR and Kill, pressure up to 840psi pumping at 1 bpm, unable to pressure up past this. Shut down pumping, slow bleedoff from 840 to 500 over 5min. Check surface lines, look good, try again. Slowly press up to 970psi and shut down, slow bleed off. 14:30 - 16:30 2.00 CLEAN P COMP Swap KWF for 9.2ppg Bio system. Parked at 7050'md, 0.5/0.5bpm, 0 WHP. 16:30 - 18:00 1.50 CLEAN P COMP RIH, pumping 0.75bpm liner top looks clean. See motor work at 8094 work past, 8102 see more cement, bring rate up to .95bpm (Freespin =3050) work past. RIH at 3fpm. Motor work at: 8154 slow to 1-2fpm, getting consistent 150psi motor work.Cleanout to 8286. 18:00 - 21 :30 3.50 CLEAN P COMP Attempting to mill thru hard/ tight spot at 8,286' CTM (Aluminum "0" ring sub at 8318 tally depth) Holding 150 psi on choke at .9 bpm. Seen oil & gas in returns. Increased choke to hold back 200 psi. A lot of stalls ultimately succeeded by parking above sub and feathering in with 25-50 psi motor work. Couldn't tell we were making progress other than we were not stalling. Got through. 21 :30 - 22:40 1.17 CLEAN P COMP RIH to 8,318 stackout with no motor work. This is the correct distance from the "O"ring sub to be the float plate. Confirming that 8,286' was the "0" ring sub. PU wash GLM at 6,969 and 7,708 while starting 9.2 Formate into hole. Slight gain in returns increased the surface pressure on choke to 250 psi. Oil shows in returns. RIH to baffle plate 22:40 - 00:00 1.33 CLEAN P COMP Mill float & baffle plate @1 bpm and with 50 psi motor work. 3/16/2003 00:00 - 06:00 6.00 CLEAN P COMP Continue milling on float/baffle plate at 8,318' CTM. 06:00 - 09:00 3.00 CLEAN P COMP PU, RBIH multiple times. Try to stall motor, unable to stall motor. Continue milling 1 bpm /1 bpm, 3120psi circulating press. Holding 300psi on the choke. 9.3ppg density on MM. Patience. See some motor work and a few stalls, break through. 09:00 - 11 :30 2.50 CLEAN P COMP RIH at 0.3ft/min. 3050 Freespin. Maintain 300psi on wellhead pumping at 1 bpm. Motor work: 8319, 8320. Likely the Baffle plate. Work through, brief motor work at 8355. 11 :30 - 12:30 1.00 CLEAN P COMP Continue RIH to 10137'. Tag TD. Clean to bottom. 12:30 - 13:00 0.50 CLEAN P COMP POH laying in new viscosified 9.8ppg K Formate Brine in slotted lIiner section. 13:00 - 14:00 1.00 CLEAN P COMP POH from liner top laying in 9.8ppg KWF (un-viscosified). 14:00 - 14:30 0.50 CLEAN P COMP Park at 200'. SAFETY meeting on pulling CS Hydril and cleanout BHA. Monitor well. 14:30 - 16:00 1.50 CLEAN P COMP Stand back 36 stands CS Hydril, LD one single, LD MHA, motor and mill. 16:00 - 17:30 1.50 CLEAN P COMP RIH with nozzle and stinger to circulate out KWF with 5% KCI and Diesel Freeze Protect 17:30 - 18:30 1.00 CLEAN P COMP Park at liner top and circulate out KWF with 5% KCI at 0.65/0.65bpmfollowing pressure schedule, final WHP is 1200psi. Printed: 3/24/2003 9:16:38 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 28-03 28-03A REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/3/2003 Rig Release: 3/17/2003 Rig Number: 2 Spud Date: 3/3/2003 End: 3/17/2003 From - To Hours Task Code NPT Phase Description of Operations 3/16/2003 CaMP POST POST 18:30 - 20:00 1.50 CLEAN P 20:00 - 22:30 0.00 RIGO P 22:30 - 00:00 1.50 RIGO P 00:00 - 03:00 3.00 RIGO P POH. Freeze protect well with 22 bbls diesel. LO BHA. Blow down coil with N2 and tail back CT to reel. Clean pits. RO rig floor. Install new air compressor. Wait on grease crew. Continue cleaning pits, RO M-I, Inteq, NO BOP. Release Rig at 03:00. 3/17/2003 POST Printed: 3/24/2003 9:16:38 AM Well: Field: API: Permit: Date ) ) 2B-03A Kuparuk River Unit 50-029-21151-01 203-009 Accept: Spud: Release: Rig: 03/04/03 03/10/03 03/17/03 Nordic #2 . _ _. ~ .__ _. L_ . - . -,.. ~~~~.,~-~.~. .~ - . POST RIG WORK 03/20/03 DRIFTED TBG TO -81321 RKB. LINER APPEARS CLEAR. SET CATCHER @ 7993' RKB. UNABLE TO PULL VALVE @ 77081 RKB. 03/21/03 INSTALLED OV @ 77081 RKB & GLV @ 69691 RKB. 03/22/03 COMPLETED GAS LIFT INSTALLATION. 04/16/03 PUMP 10 BBLS SW W/30 GALS OF WAW-5206 OF PRE-FLUSH: PUMP 24 BBLS SW W/130 GALS OF SCW-4004 OF TREATMENT. 04/28/03 OBTAINED BHP @ 80001 RKB. Company: Field: Site: Well: .WeUpath: Phlllips·Alasks¡)nc. KupárukRiver Unit· .. KRU2B Þad 28-03 . 2B~03A ') ) BP Baker Hughes INTEQ Survey Report R.. IS ...'......~._......._..._...... INTRQ Date: . 4/30/2003. Time: 13:52:04 Co-ordinate(NElªefërelJce: Well:. 2B~03. True North Vertical (TVD) Jiefërënce: .28-03 RKB126:Ö Šëction (V~) ReferenceiWell (O;OON ,O.00E,200.00Azi) Survey Calcul~tionl\1ethod: MinimurrrCürvature Db: Sybase Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: KRU 2B Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: 2B-03 Well Position: +N/-S +E/-W Position Uncertainty: 5954835.32 ft 508397.80 ft Map Zone: Coordinate System: Geomagnetic Model: Latitude: Longitude: North Reference: Grid Convergence: Slot Name: 0.00 ft Northing: 5954835.32 ft Latitude: 0.00 ft Easting: 508397.80 ft Longitude: 0.00 ft Wellpath: 28-03A 500292115101 Current Datum: 2B-03 RKB Magnetic Data: 1/9/2003 Field Strength: 57474 nT Vertical Section: Depth From (TVD) ft 0.00 Survey Program for Definitive Wellpath Date: 4/9/2003 Validated: Yes Actual From To Survey ft ft 200.00 8067.00 Gyro (0) 8067.00 10165.00 MWD Annotation MD ft 8067.00 10165.00 TVD ft 6072.25 6119.02 KOP TD Survey: MWD Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Survey MD ft ~ 8067.00 8083.00 8115.55 8145.46 8175.77 loci deg 50.27 63.28 73.07 77.63 74.17 8211.09 8240.12 8299.13 8333.80 8367.73 87.15 94.11 96.12 96.03 93.13 8401 .20 8435.22 90.52 89.45 Azim deg 187.01 194.76 201.00 212.00 201.00 TVD ft 6072.25 . 6081.00 6093.10 6100.68 6108.09 197.83 205.40 232.16 238.17 241.85 6113.81 6113.49 6108.13 6104.46 6101.75 243.27 250.21 6100.68 6100.69 Height 126.00 ft SSTVD ft 5946.25 5955.00 5967.10 5974.68 5982.09 5987.81 5987.49 5982.13 5978.46 5975.75 5974.68 5974.69 +N/-S ft 0.00 N/S ft -4683.71 -4696.80 -4725.49 -4751.32 -4777.57 -4810.37 -4837.32 -4882.73 -4902.41 -4919.31 -4934.73 -4948.15 Alaska, Zone 4 Well Centre BGGM2002 70 17 16.163 N 149 55 55.300 W True 0.06 deg 70 17 16.163 N 149 55 55.300 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Version: 4 Toolcode BOSS-GYRO MWD Start Date: Engineer: Tied-to: E/W ft -947.66 -950.25 -959.56 -972.47 -985.58 -997.13 -1007.80 -1044.26 -1072.54 -1101.83 -1131.51 -1162.75 28-03 8067.00 ft Mean Sea Level 25.31 deg 80.67 deg Direction deg 200.00 Tool Name Sperry-Sun BOSS gyro multishot MWD - Standard 3/12/2003 From: Definitive Path MapN ft 5950151.02 5950137.93 5950109.24 5950083.39 5950057.13 MapE ft 507455.46 507452.89 507443.61 507430.73 507417.65 5950024.32 5949997.36 5949951.92 5949932.20 5949915.27 507406.15 507395.50 507359.10 507330.84 507301.58 5949899.83 5949886.37 507271.91 507240.69 VS ft 4725.37 4738.55 4768.69 4797.38 4826.54 4861.31 4890.28 4945.42 4973.59 4999.49 5024.13 5047.43 DLS deg/100ft 0.00 90.77 34.93 38.70 36.99 37.80 35.41 45.29 17.24 13.78 8.88 20.64 ) ') II.. BP s Baker Hughes INTEQ Survey Report ·.,,·................~......._...._........'..M'...._...~ IN'TEQ Company: PhillipsAlaska;lnc; Date: 4/30/2003 Time: .. 13:52:04 . Page: >2 Field: Kuparû~ River Uhit Co-ordinate(NE) Referençe: . Well: 2B-03,TrÜeNorth Site: KRU 26 Pad VertÏc~(TVD) Rëfereöcë: ~B-03RI<B ·126,0 Well : 2B~03 Sec6oö(VS) Reference: VVell(O .ØO N ,O;OOE ,2()0~ OOAzi) Wellpath: · 2B-03A SurveyCålcul~tjon Method: MihimumCUrvatute ·Db: $ybase Survey MD Incl Azhü ·TVD SSTVD N/S E/W MapN MapE VS DLS ft· dëg dëg ft. ft ft ft ft ft ft deg/100ft 8470.29 86.87 253.82 6101.82 5975.82 -4958.97 -1196.08 5949875.51 507207.38 5068.99 12.65 8501.81 89.23 254.81 6102.89 5976.89 -4967.49 -1226.41 5949866.96 507177.06 5087.37 8.12 8538.18 91.53 263.12 6102.65 5976.65 -4974.44 -1262.07 5949859.97 507141.41 5106.10 23.71 8571.81 90.37 267.44 6102.09 5976.09 -4977.21 -1295.57 5949857.16 507107.92 5120.16 13.30 8602.67 90.12 272.13 6101.96 5975.96 -4977.33 -1326.42 5949857.01 507077.07 5130.82 15.22 8635.86 88.41 268.88 6102.39 5976.39 -4977.03 -1359.60 5949857.27 507043.89 5141.89 11.06 8667.75 88.41 264.20 6103.27 5977 .27 -4978.96 -1391.41 5949855.31 507012.09 5154.58 14.67 8700.85 88.37 258.48 6104.20 5978.20 -4983.94 -1424.11 5949850.30 506979.40 5170.44 17.27 8732.95 89.88 254.93 6104.69 5978.69 -4991.32 -1455.34 5949842.88 506948.18 5188.06 12.02 8770.45 91.93 249.30 6104.10 5978.10 -5002.82 -1491.01 5949831.33 506912.53 5211.07 15.98 8805.39 91.50 244.22 6103.05 5977.05 -5016.60 -1523.09 5949817.52 506880.47 5234.99 14.58 8842.65 90.46 238.21 6102.42 5976.42 -5034.53 -1555.72 5949799.56 506847.86 5263.00 16.37 8872.09 89.11 231.12 6102.53 5976.53 -5051.55 -1579.72 5949782.52 506823.88 5287.20 24.51 8902.08 89.14 226.48 6102.98 5976.98 -5071.29 -1602.28 5949762.75 506801.34 5313.47 15.47 8935.06 90.74 219.47 6103.02 5977.02 -5095.41 -1624.75 5949738.61 506778.91 5343.81 21.80 8965.21 90.89 214.25 6102.59 5976.59 -5119.52 -1642.82 5949714.48 506760.86 5372.65 17.32 9003.50 87.61 206.66 6103.09 5977.09 -5152.49 -1662.21 5949681.49 506741.51 5410.27 21.59 9036.34 90.44 198.63 6103.65 5977.65 -5182.77 -1674.84 5949651.20 506728.91 5443.04 25.92 9067.64 93.41 198.93 6102.60 5976.60 -5212.38 -1684.91 5949621.58 506718.88 5474.31 9.54 9102.62 93.56 207.66 6100.47 5974.47 -5244.42 -1698.71 5949589.53 506705.12 5509.14 24.91 9133.62 93.62 210.38 6098.53 5972.53 -5271.47 -1713.72 5949562.46 506690.14 5539.69 8.76 9165.82 90.80 209.31 6097.29 5971.29 -5299.38 -1729.73 5949534.54 506674.17 5571.39 9.37 9218.47 89.11 223.34 6097.33 5971.33 -5341.69 -1760.84 5949492.20 506643.11 5621.79 26.84 9260.27 88.28 233.34 6098.28 5972.28 -5369.43 -1792.02 5949464.42 506611.96 5658.52 24.00 9292.24 86.91 237.73 6099.62 5973.62 -5387.51 -1818.34 5949446.33 506585.66 5684.51 14.37 9328.46 89.17 239.28 6100.86 5974.86 -5406.41 -1849.21 5949427.38 506554.82 5712.83 7.56 9365.55 88.68 242.03 6101.56 5975.56 -5424.59 -1881.53 5949409.18 506522.52 5740.96 7.53 9397.63 89.20 237.69 6102.15 5976.15 -5440.69 -1909.26 5949393.05 506494.81 5765.58 13.62 9435.11 87.02 235.71 6103.39 5977.39 -5461.25 -1940.57 5949372.45 506463.53 5795.61 7.86 9472.81 90.06 241.42 6104.35 5978.35 -5480.90 -1972.71 5949352.77 506431 .41 5825.06 17.15 9505.82 89.51 246.54 6104.47 5978.47 -5495.37 -2002.36 5949338.27 506401.78 5848.81 15.60 9545.54 87.08 246.38 6105.66 5979.66 -5511.23 -2038.76 5949322.37 506365.40 5876.15 6.13 9576.89 87.42 240.65 6107.16 5981.16 -5525.19 -2066.77 5949308.38 506337.41 5898.85 18.29 9610.45 88.65 236.80 6108.31 5982.31 -5542.59 -2095.43 5949290.94 506308.77 5925.02 12.04 9651.79 88.71 232.75 6109.27 5983.27 -5566.43 -2129.19 5949267.07 506275.04 5958.96 9.80 9685.17 87.67 223.84 6110.32 5984.32 -5588.60 -2154.07 5949244.88 506250.19 5988.30 26.86 9722.27 89.36 221.99 6111.28 5985.28 -5615.76 -2179.32 5949217.69 506224.97 6022.46 6.75 9757.40 87.36 213.83 6112.29 5986.29 -5643.44 -2200.88 5949189.99 506203.45 6055.84 23.91 9790.45 86.50 212.76 6114.06 5988.06 -5671.03 -2218.99 5949162.39 506185.36 6087.96 4.15 9835.66 89.39 208.68 6115.68 5989.68 -5709.85 -2242.07 5949123.54 506162.34 6132.34 11.05 9871.21 87.18 203.45 6116.75 5990.75 -5741.76 -2257.67 5949091.61 506146.76 6167.66 15.96 9904.47 89.11 194.43 6117.83 5991.83 -5773.17 -2268.45 5949060.20 506136.02 6200.86 27.72 9944.35 89.75 188.53 6118.22 5992.22 -5812.23 -2276.38 5949021.13 506128.14 6240.28 14.88 9992.16 88.01 181.64 6119.16 5993.16 -5859.82 -2280.62 5948973.55 506123.95 6286.44 14.86 10030.11 88.22 172.42 6120.41 5994.41 -5897.65 -2278.66 5948935.72 506125.96 6321.33 24.29 10060.00 88.37 169.52 6121.30 5995.30 -5927.16 -2273.97 5948906.22 506130.68 6347.45 9.71 10090.70 92.79 163.60 6120.99 5994.99 -5956.99 -2266.84 5948876.39 506137.84 6373.05 24.06 10123.05 91.04 159.04 6119.91 5993.91 -5987.61 -2256.48 5948845.79 506148.23 6398.28 15.09 10134.03 91.23 161.25 6119.69 5993.69 -5997.94 -2252.76 5948835.47 506151.97 6406.71 20.20 10165.00 91.23 161.25 6119.02 5993.02 -6027.26 -2242.80 5948806.16 506161.95 6430.85 0.00 Phillips Alaska, Inc. WELLPATH DETAILS 2B.o3A 500292115101 Parent Wellpath: 2B-03 Tie on MD: 8067.00 Rig: Nordic 2 Ref. Datum: 2B.o3 RKB 126.00tt V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 200.00· 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E~ Reference: Well Centre: 2B-03. True North Vertical (NO Reference: System: Mean Sea Level Section (VS Reference: Slot - (O.OON.O.OOE) Measured Depth Reference: 2B-03 RKB 126.00 Calculation Method: Minimum Curvature ANNOTATIONS lVD MD Annotation 5946.25 8067.00 KOP 5993.02 10165.00 TO 5300 5350 5400 5450 'ë5500 ~ 5550 U') ;S600 .. 2"->650 Q _5700 œ U :e5750 .: CÞ .¡ > 5800 CÞ 25850 ~ 5900 5950 6000 6050 Conocð'Phillips / >-...... i · ; / ¡Ji<- ~ /;1 .-. ~ ?J .. ~ ~ ........-<...'y ,ø;,.. LEGEND 28-03.28-03A.Plan 0'1.1 2B-03 (28-03) 2B-03A T ^M ^ it 8a~er Hughes :~~~~t~i~~~i2~qcçm Wellpath: (2B-03/2B-03A) Azimuths to True North Magnetic North: 25.31· Stre~~~~~~~il~~ Dip Angle: 80.67· Date: 1/9/2003 Model: BGGM2oo2 Created By: Brij Polnis Date: 413012003 Cr;î:~act JnfortnaliorL INTEQ -4500--] ... .. .... . .... .. ..... .... ......... ....... .>' .. '. . .. -460<>-::1 · , , . · , . . . , , -470o-=j · . · .. ~J@ ..... ..'..... · ...... · =1 . .' ..... ...... ... .. ... .. .' -4800-:=; "," .. · · /; · · .." ... ...... .. .. , .. .... '" · · -4900": . ., . ..' · y .. .. , · ... . ." .. .... ...... .... ... ...,.. ..'.; ..' .... ....... I :'-5000-= .. · '.' . .. ---:::::=---" ~ . ~. ~ =.. , . ............ .........................,. , .'. .... . . . ". , 18-03 l2B-03\'" ... ........ ;¡ ~A"" ... .. . · /J ' . .... '. . ê t -"nvv . ...... . , .... . .. ... .' ." .......... _I ê t ,. ..,.... .. ...... ...... .. ..,. .. .... '.. _n~~ .. ..... ." ... , ....... J ...;. .... · .' , .;.,-....'vv ...; , .~ , . · . ........ · . · · . . · . ~-"ùvv · . .' , . // , ..... · , .$ '.' . .... .. , · . · . ~ A "n. , . .. .. . .' ... .. .., .}(;/ .... ... .. · . · , ........vv .. . . · . · .. .... · ~ . ccnf'L · .' '-:f: -........vv ~9 '. . . .. · . · :/ · · . · · . ~ -"'vvv · · }#"" ' . · . . · , .' . , , · . · · . · · f¡ ·.....vv II . ... , · · · · . · · " . , .; , · -....uvv ...... . .. · . .. .. · · · · . -"''''vv . . ..,.... ..' · · · · ... . . '.' . ... ,'" \ nTI , '. '," '., ... , -uvvv .... ,. no, ^' "' ~.'.. ~~ · , · · ".~" . . . . ".w..., . · · · .' · · .' v.vv .. ... · .. , · .' , · , , . . · . , , , -ULVV ",L ~<~ M ,~ nL~'M ,_':" ,_::-nM M n nn n.'n~ nl~^ n. ,~'n.Ln 'Ar ,~' .'~~~ : ,~ M:IM T' !' i ~o doo j I' '_~~' : ' , ;-- uv . :200 -ùLVV -ù ""-,~ .v 'v .V NV .VV .~ Vertical Section at 200.00° [50ft/in] ~/30/2003 1:&1 PM ids ~ I'· w...1L LOG TRANSMITTAL , f)u3-CO¡ ) )roActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 5'(') -. O(!Z} 9 (~ 11 S ì C~ì \ RE: Distribution - Final Print(s) 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR Co.f;0M FILM BLUE LINE 2b-03a 3-1 503 Open Hole 1 1 ~ Res. Eva!. CH 1 1 Mech. CH Caliper Survey (;Q . 2 Coloy/ r "', // I "' "--.-......' Signed: """'- - """' ~\ì\.~'v'""\~ '-C 0 ~. ç".y\ Date: Print Name: PRoAcTivE DiAGNOSTic SERvicES, INC., } 10 K STREET SUiTE 200, ANClioRAGE, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.memorylog.com r~ECEIVED APíi 2 1 2003 \ "\.;z ~b\\\ ~ ÞJaska Q¡-I & Gas Cons. Commission Anchorage '\1 I~: @c-;J®~[ æ) ~." ¡f\~.. ~b ~ ~.t FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer ConocoPhillips Alaska Inc. PO Box 196612 Anchorage AK 99519 Re: Kuparuk River Unit 2B-03A ConocoPhillips Alaska Inc. Permit No: 203-009 Surface Location: 689' NSL, 249' WEL, Sec. 19, TI1N, R09E, UM Bottomhole Location: 108' SNL, 2550' WEL, Sec. 31, TIIN, R09E, UMJ Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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 con1ply 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 North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~¡;Ø-~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 'it:!- day of February, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section (IJ(-A+ z-/ '3103 . STATE OF ALASKA \ ALASKA C.) AND GAS CONSERVATION COMMk...JON PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill II Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil ORe-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 6~ 5. Datum Elevation (DF or KB) 10. Field and Pool / Phillips Alaska IlIc: ~¡J#i¿'¿ì,o.s ,4L/:J5IC{) ~ RKB = 126' Kuparuk River Oil Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025656 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 689' NSL, 249' WEL, SEC. 19, T11 N, R09E, UM Kuparuk River Unit At top of productive interval 8. Well Number 3895' SNL, 1200' WEL, SEC. 30, T11 N, R09E, UM 2B-03A / Number U-630610 At total depth 9. Approximate spud daty 108' SNL, 2550' WEL, SEC. 31, T11 N, R09E, UM 02115/03 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well / 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025587, 2444' MD No Close Approach 2560 10200' MD / 5976' TVDss 16. To be completed for deviated wells 0 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} Kick Off Depth 8067' MD Maximum Hole Angle 95 Maximum surface 2990 psig, At total depth (TVD) 6107'/3599 psig 18. Casin~ Program Specifications Setting Depth $Ize Top Bo\tom Quantity of Cement Hole Casina WeiQht Grade Couplina Lenath MD TVD MD TVD (include staae data) 3" 2-3/8" 4.6# L-80 ST-L 2200' 8000' 5903' 10200' 5976' 59 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 8430 feet Plugs (measured) true vertical 6303 feet Effective depth: measured 8313 feet Junk (measured) true vertical 6228 feet Casing Length Size Cemented RECEIV'EI) ,IAN ~¡ J :200~) .Alaska Oil & Gas Cons. Gommissìm! An$.hDrf.1Qe TVD Structural Conductor Surface Intermediate Production Liner 110' 3161' 16" 9-5/8" 233 sx Coldset II 800 sx CS III, 500 sx CS II 110' 3161' 110' 2751' 8395' 7" 350 sx Class 'G', 250 sx CS I 8395' 6280' Perforation depth: measured 7938' - 7958' (C Sand); 8071' - 8081' and 8098' - 8142' (A Sand) true vertical 5989' - 6002'; 6074' - 6081', 6092 - 6120' 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer NameINumber: Dan Kara, 564-5667 21. ~~;::y C:a~i~:a,!~, .t., h.., e, for.e,, g.~."; ., IS, e and coITect to"..,th,e., .', b,., ~,..,.;,:eO.:, ~'.'..; D.k.. n.ri~,.,I~,n~,Eg,n"e,¡.gineer . , " .'. ' ""C~ISSJQn Use,O"~:,, Permit Number API Number Approval ~a~ See cover letter Zc:;.3 - oð 9" 50-029-21151-01 a L/ I~ forotherreQuirements Conditions of Approval: Samples Required 0 Yes B No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required 1i1 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T~+- ~oPE fc, Š$"DO f~ ¡ . ORIGiNAl SIGNED BY ML.œ Prepared By NameINumber: Terrie Hubble, 564-4628 Date 1/13/03 Approved By Form 10-401 Rev. 12-01-85 Commissioner by order of the commission Dated] y lo~ tUb~it In Triplicate K.J 2B-03A Sidetrack - Coiled TUbìo.) Drilling Summary of Operations: Coiled tubing drilling will sidetrack KRU 2B-03 using the dynamically overbalanced coiled tubing drilling / (DOCTD) technique (see description below). This horizontal sidetrack will target Kuparuk A sand reserves for production. 2B-03A will be a producing well. Prior to CTD arrival, service coil will abandon the existing perforations in 2B-03 (sundry form 10-403 ,/ submitted). CTD Drill and Complete 2B-03~ro2ram: Planned for Februarv 15. 2003 1) Mill cement ramp,/wfud through 7" liner at 8067' md and mill 10' of openhole. 2) Drill 2.7" x 3" ¢ent$Y ole horizontal sidetrack 2B-03A from window to -10200' TD targeting Kuparuk A sa~val. /. 3) Complete with 2 3/8" solid/cemented liner from TD to -8000' (-10 inside tubing tail). NOTE: 'Bonsai' completion to be considered pending reservoir saturations. 4) Perforate selected intervals. 5) Post CTD rig - Run GL V s. Bring on production. Mud Program: · Steps 1: 9}'Pp~KCL/NaCl biozan brine · Steps 2-r.:?fipg Potassium Formate based Flo-Pro Disposal: · No annular injection on this well. · Class II liquids to KR U 1 R Pad Class II disposal well · Class II drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: /' 01'" " · Base case 2 3/8",4.6#, L-80, STL solid liner from 8000' - 10200', 12 b s of 15.8 ppg Class G cement. NOTE: If no loss circulation occurs, and low water saturations e óuntered, a 2-3/8" Bonsai completion may be ran (combination cemented/slotted liner) Well Control: · BOP diagram is attached. /' · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for 2B-03A. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · A post drilling, memory resistivity log will run in openhole. Hazards · Sidetrack may encounter minor losses through existing fracture. Lost circulation risk is low. Reservoir. ./ pressure is 11.3 ppg. Well 2B-03 produces H2S at 95 ppm. Highest H2S on 2B pad is 400 ppm. 2B pad is a H2S pad. All H2S monitoring equipment will be operational. D. Kara 564-5667 office, 240-8047 cell 1/3 K~.IIJ 2B-03A Sidetrack - Coiled TUbi..) Drilling Reservoir Pressure tp".~..--..., · Res. pressure was measured on 1/07/03 at 3599 psi @ 5980'ss (6107' TVD(11.3 pg). Max. surface pressure with gas (0.1 psi/ft) to surface is 2990 psi. As done in the past at KRU by CTD, dynamically overbalanced coiled tubing drilling (DOCTD) techniques " will be employed to address high reservoir pressure. Plans are to use 9.2 ppg drilling fluid in combination / with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. / Using this technique with an underbalanced mud weight requires deployment of the BRA under trapped /. wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. At least two times hole volume of kill weight fluid will be on location as a contingency. Once drilling is complete, the production liner will be deployed into the wellbore after killing the well with ./';-., kill weight fluid. Measured reservoir pressure: 3599 psi at 5980' ss, 6107' TY'fJ';""i).3 ppg EMW. Expected annular friction losses while circulating (ECD)~i Planned mud density: 9.2 ppg equates to 2925 psi hydrostatic bottom hole pressure.(::::,,:,:-) While circulating 9.2 ppg fluid, bottom hole circulating pressure is estimated to b~Si, or 125 psi over- v'~ balanced to the reservoir. /; ~." When circulation is stopped, a minimum O~i surface pressure will be applied to balance the reservoir. Operating parameters will be adjusted based on real-time bottom hole pressure measurements while drilling. D. Kara 564-5667 office, 240-8047 cell 2/3 K. .J 2B-03A Sidetrack - Coiled TUbì..) Drilling Kuparuk 2B-03A Potential Drilling Hazards POST ON RIG 1. Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S - Well2B-03 produces H2S at 95 ppm. Highest H2S on 2B pad is 400 ppm. 2B pad is a H2S pad. / All H2S monitoring equipment will be operational. H2S procedures must be followed according to the AK Safety Handbook and Shared Services Drilling H2S SOP. All personnel must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in H2S in the pit area, although KRU CTD sidetracks have not seen this in the past. The Pit watcher should always carry a calibrated personal H2S monitor. 3. Reservoir pressure - Reservoir. pressure was measured at 3599 psi @ 5980' ss, 6101' TVD (11.3 ppg). Max. surface pressure with gas (0.1 psi/ft) to surface is 2990 psi. Reservoir frac gradient is -0.7 psi/ft or 13.5 EMW, 4260 psi. 4. The Dynamically Overbalanced Coiled Tubing Drilling (DOCTD) technique will be used. Drilling will / be done with a less than kill-weight fluid (9.2 ppg Flo-Pro). While drilling and circulating at 1.5 BPM, hydrostatic head from the 9.2 ppg mud (2925 psi), plus 800 psi of annular friction, plus 0 psi choked backpressure held on the return side will provide a 3725 psi BHP and overbalance the reservoir by -125 psi. However, when circulation is shut down, the reservoir could be underbalanced by -675psi. Maintain . at least 675 psi WHP when not circulating to prevent reservoir in-flux and to maintain formation stability /' by keeping static BHP close to circulating BHP seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole PWD sub. Increases ~ill occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return-line flow rate and pit volume continuously. If a pit gain has been identified (underbalance event occurred), divert those returns to an outside tank. 5. No gas saturated intervals are expected. However, always be prepared for the potential for gas influx. Ensure all PVT equipment is fully operational and monitor return-line flow rate and pit volume continuously. 6. Lost circulation is not expected. Some early losses may occur into the existing frac wing. These losses should diminish quickly. No faults are expected to be encountered along the wellbore trajectory. Lost circulation is considered low risk. If lost circulation occurs plan to control it with adjustments to the DOCTD parameters. Lower circulation rate (1 BPM minimum) would be utilized prior to LCM treatments. However, as a contingency ensure that LCM material is on location so that a pill could be mixed quickly if required. Pump only Liquid Casing or OM Seal fine through a slimhole drilling BHA. Do not pump MI Seal through a drilling BHA due to plugging potential. D. Kara 564-5667 office, 240-8047 cell 3/3 I ConocoPbillip8 Alaeka. Inc. -- SSSV (1889-1890, 00:3.500) --Iii I::!! "--:1:),1':; ..-1 _~'r,'- -'þ'::"~' ,i,ll!i' ,11111"'1. ",,·,:'III,I, 'WOOIII:II!:] ,~,',"::,'I" ..-JI1lilll!11 ~ :JIlli:il,.. '~ --,~ SSR (7758-7759, 00:3.500) ~iIUIIII~I' ,1,1 ¡11111 '11:lilll;ill PKR (7766-7767, 00:6.151) ... "'11'1i""~ __1111::II:!:,~~ -.JII11Iil!:' -'-=-, ,,',::"1 "~IIII::I!: .... _i~I¡:t·_ PKR (7984-7985, 00:6.151) ..--. SSE :'X~~:;'L:; (7989-7990, 00:3.500) /. NIP U (8001-8002, 00:3.500) ~ -L Perf (~142) 1" OMY - (8182-8183, 00:2.000) ) 28-03 API: 500292115100 SSSV Type: LOCKED OUT Annular Fluid: Reference Log: LastTag: 8153 FCO Last Tag Date: 12/17/2002 Casing String· ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Tubing String· TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 7939 - 7958' 5990 - 6002 Zone C-4 8098-8142 6092-6120 A-4 Stimulations & Treatments Interval Date Type 0-0 4/27/1989 Scale Inhibitor 0-0 12/30/1995 Scale Inhibitor Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 2021 1933 Cameo KBUG 2 4142 3424 Cameo KBUG 3 5748 4552 Cameo KBUG 4 6969 5367 Cameo KBUG 5 7708 5841 Cameo KBUG Production MandrelsNalves St MD TVD Man Man Mfr Type 6 7804 5903 Cameo KBUG 7 7872 5947 Cameo KBUG 8 7978 6015 Cameo KBUG Other l3lugs, equip., etc.;' . JEWELRY Depth TVD Type 1889 1827 SSSV 7758 5873 SBR 7766 5878 PKR 7984 6019 PKR 7989 6022 SBE 8001 6030 NIP 8007 6034 SOS 8008 6034 TTL Fish· FISH Depth I 8182 1" DMY General Notes Date I Note 4/27/2001 Tag rocks & FRAC sand ') KRU 28-03 Well Type: PROD Orig 8/15/1984 Completion: Last W/O: Ref Log Date: TD: 8430 ftKB Max Hole Angle: 51 deg @ 7500 Angle @ TS: 50 deg @ 7936 Angle @ TD: 51 deg @ 8430 Rev Reason: FCO by ImO Last Update: 12/19/2002 Bottom 8008 Top Bottom TVD Wt Grade Thread 0 110 110 55.00 H-90 0 3161 2751 36.00 J-55 0 8430 8430 26.00 J-55 TVD Wt Grade Thread 6034 9.30 J-55 8RD EUE Status Ft SPF Date Type Comment 19 12 8/29/1984 IPERF 120 deg. phasin'g; 5 1/2" Csg Gun 44 8 8/29/1994 IPERF 90 deg. phasing; 4" Csg Gun VMfr Comment Pumped 20 bbl DSL w/1 drum 8660, &70 bbl SW w/5 Pumped 10 bbls SW w/ 30 Gal SS-5206, &20 Bbls SW w I V Type V OD Latch Port TRO Date Run 1/6/2000 1/6/2000 1/6/2000 7/6/1998 7/7/1998 Vlv Cmnt V Mfr GLV 1.0 BK 0.188 1342 GLV 1.0 BK 0.250 1444 OV 1.0 BK 0.250 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 V Type VOD Latch Port TRO DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 Description ID 2.813 2.973 2.867 4.000 3.000 2.750 2.992 2.992 Date Vlv Run Cmnt 6/28/1998 Closed 5/25/1996 Closed 5/25/1996 Closed Otis 'FMX' (Locked Out) Cameo 'OEJ-10' Cameo 'HRP-1-SP' Baker 'FB- l' Baker Cameo 'D' Nipple Cameo 'PE-500' Description I Comment Empty Pocket: Dropped to Rathole ~ ~ 1" Shoe @ 8430' DTK 1/02103 1" Liner & Perfs I P&A'd with 17.0 ppg Cement 2-3/8" STL 4.6# Liner Cemented & Perforated ....... ".> ..¿, ~- .\ ..,,/ o @ 10200' :~ FCO to 8100' 3" Open hole Mill Window in 7" Casing &' ~ 17 ppg P&A Cement Top at Tubing Tail I I ."./ -..- , _________ Top of 2-3/8" Liner @ 8000' (proposed) TOC at liner top. B B 3-1/2" X 7" Camco HRP-1SP Packer @ 7766' ~ j ~ B B 3-1/2" x 7" Baker FB-1 Packer @ 7984' 3-1/2",9.3#, J-55 Production Tubing to Surface J . 9-5/8" J-55 Casing Shoe @ 2751' J Otis 'FMX' SSSV 1889' L.J+ KRU 2B-03A PRvÞOSED CTD HORIZONTI..2 SIDETRACK Perfs 8071'·8081' 8098'-8142' Tubing ¿ 8008' ) ") 8 .ii. ,- iiš;:¡:Ë(i BP Baker Hughes INTEQ Planning Report Company: Field: Site: Well: Well path: Phillips Alaska,lnc. Kuparuk River Unit KRU·28 Pad 28-03 Plan#1. t 28-03A _ .._.~_,.,..._,_,~.~_"_..__.~.__,..,,__..___ '_'_'_'~"""_'''_'''_M'·___'_''''M'''___'''''''__M_''''''_.. ___._...____._...__~___"_.n,...__._._.M._~n. ......._.__ ._..,_. __,.. .__._ ....._M.".'.,._ ,_._..,_..".~_" ...._....,.,_.._ ._,__.,,,.,_,. "_'._....' _.."._. .." ......". _._. ~ Date: . 119/2003 .. . rime:.13,:J7:29 Page: Co-ordinate(NE),.Reference: Wen:28~03 True North Vertical{TVJ»Refer~l!ce: System:Mean S~a L~~el Seetion(VS)Reference: .. ..... Well' (0.00N,O.00E,200.00Azi) :~:~:.:.~~.::'.:.-.::~~:.::'::c::~:':::::::::::~~:::.::::~::~:::::;:~~:%~r=~:~~;~~~:J~~:~~~~;:.:.~::=:~~2~~~:~::3~.~~~·~~:~·:::..::::c::::.:: :~~}.:.c~X~~:~;:· .--.....-. ~ '..,.,__" _ ...._.....M_..._'...'._ ..... .".. ._,...,.. _'M". '''._.. Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 . ..... ~~.... 'H'" ...,,~_.._ ..._..._.,,_ .._._......"....~."._. ". ·...M...... .."·M.._"·.....·, _,.. .._ Site: KRU 2B Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: I)osition Uncertainty: 0.00 ft Ground Level: 0.00 ft 5954835.32 ft 508397.80 ft Latitude: Longitude: North Reference: Grid Convergence: "" ..". - ........ ...-..... . . '''M.. ~"__...,."...,,.. ... .,,_.... Well: 2B-03 Slot Name: Well Position: +N/-S +E/-W Position Uncertainty: 0.00 ft Northing: 5954835.32 ft Latitude: 0.00 ft Easting : 508397.80 ft Longitude: 0.00 ft 70 17 16.163 N 149 55 55.300 W True 0.06 deg 70 17 16.163 N 149 55 55.300 W Wellpath: Plan#1.1 2B-03A 500292115101 Current Datum: 28-03 RKB Magnetic Data: 1/9/2003 Field Strength: 57474 nT Vertical Section: Depth From (TVD) ft 0.00 Height 126.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 _......._._.._.MM_......__.._..~......_...,._ Targets . ._. ."...~..'":" '..__ "'..."."....,,~ ~ h:_...~~._ '._._':_~'M" . "... _'_rM_.. _~__..._~," ,_.__..~. ,.._.:....,~"~._~,." . .___" _.' "'~ ._.~....." w ~~...._ """:... 'M "'''M'''_''.' _.._ ..,.__.., ,_ __ ,..~':_.... Name lVI.P. ..... .. Northing TVD 01... 28-03 8000.00 ft Mean Sea Level 25.31 deg 80.67 deg Direction 200.00 . .__.__.._,._".......M~_... n_'M'U'_" ...... l\1I1.P Easting ··~-=:=:·L~tit~d¡··~~~······- ·.··~L=~i~rigit~d~·~=>1 Deg . Min See Deg Min Sec _,,___...._.__...........__ __,..M. .' __..,._.._....__..._.., ~M~ ".._, ....._.._._"..___..._,_......._.. ... ...". .~""..~.~"" M""_'__'__ ... "...__.._...__._n_~_.___..._..__._.. _.__..M Annotation MD TVD ft ft 8000.00 5903.25 TIP 8067.00 5946.24 KOP 8081.00 5954.74 3 8199.03 5990.00 4 8215.96 5989.26 5 8352.10 5977 .32 6 8477.84 5970.98 7 8677.82 5968.32 8 I 8752.86 5967.53 9 9194.51 5963.79 10 9302.84 5962.94 11 I 9511.45 5963.66 12 : 10200.00 5975.99 TO . __. __..,... ..___ _M..~'h__.....__...__ __,,_,._. .·_...__.M..~_...,,_____...M.~.___ _. '..M...._M__M..'M.' '":",.M"_"_'_"__"'M_..'.'_'" "'_'_'_""_'_'_'M_..__ ...,,_.._..........__..~ ..,.~ . "_ ...,_...~.. ._..._ .....~. ," ~".....M_' 'M, _'" ~....~~.~.,,~...-"" .. ".........".~.....,.._.,..~'.._._..;..._.~ '~''''.'..,. ~,_~ ._,,-_,,.,,~.,,_,_.~,, '"M'_"' __...__~ ...____~..._~·._._._R._.' '__"R"_" - .. _.___0.._..- --- ----..----..--.---.-...---..-.-------.-------..- .---..--- -- ---~'_.'------ -.- - --.. -....-..-... .-- Plan: Plan #1.1 Similar to Owen's Version #1 Principal: Yes Date Composed: Version: Tied-to: Plan Section Information 1/9/2003 2 From: Definitive Path -., .-- - ..- ..-.-..-..- -.-. ~..--.. ...-...- -.--.-. -..-.,-.-.- -.--.-.--,----.- ---.------.,-- ._,--- .---. --..- .- - ---.---- -...-- MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10OO deg/100ft deg/10OO deg . ~-". -.- -..----.. ..,... --- -.----.----..-.- --'"-_._..~" -..~ --.----. -~_.. _._-_.._._----_._-,-_.__._------_.~._.._,.._--~ --... -- .._,- .. -".-.- .-....,. , 8000.00 49.90 187.13 5903.25 -4632.72 -941.34 0.00 0.00 0.00 0.00 8067.00 50.27 187.01 5946.24 -4683.71 -947.66 0.57 0.55 -0.18 345.99 8081.00 55.03 190.73 5954.74 -4694.70 -949.39 40.00 33.98 26.56 33.00 8199.03 90.00 211.25 5990.00 -4796.83 -990.69 33.78 29.63 17.39 33.15 .-.-.- ----. .---.-..--.- -.---.-.....----- --- _._.__.....__._---~.. -.--.----- ) BP ) B..I .AIma Baker Hughes INTEQ Planning Report ....s IN"rEQ . '" "".'.. n.."'...._"'_._.__~_'_..._,_._~,...._.. .__..'~.~~___.., .~.~. ,"._.,.. ,_.. H"'~"'~"'~.'_H"'____'__"""~.'_'_"'_"'_":-'___""__".'._.:.......__.."..... .__""_'~___'_...""H_'_._'.., ,_, Company: Phillips Alaska, Inc. Date: 1/9/2003 Time: 13:17:29 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) . Refere.nce: Well:2B:'03, True North Site: KRU 2B Pad Vertical (TVl» Reference: System: Mean Sèa Level Well: 2B-03 Section (VS) Reference: Weill (0.00N,0.00E,200.00Azi) Wellpath: Plan#1.1. 2B-03A __ ___.___,:."~.~~~r__~~I~_~~~~_i~n..~!!~~~~_"~.._~.¡_~~.T~~.g~~~~ur.e.. ..__........I>.~~. ._. ~Y.?~~~ . ~ ".. -., - '.'., ' ....-". -' . ."~ _"....__ _,._~~,...w:"._.._,_."..., ~'.'''_'''''''_ ~.:.._.._ Plan Section Information ... ' . ."..____, ...,"..__ .,...,. "'~_.'"~..~_~..~'".._.___..... _.___,.",.._....__.,~,~..,~'._.__."~.__.._,~_.__._~___~..r-_."____"_____._·-:-_·~~M~~_'__:_'.--..--.-~..--..~._:_....- .,.':-'~,... ~~ ,...""-~-..-..,-- .._.. ...___._._". .,._......_..n___'. '..' ""'._ MD Incl Azim TVD +Nl-S +E/-W DLS Build . Turri TFO Target ft deg deg ft ft ft d~gl1 000.· degltQOftcjeg/1 OOft deg . -'.'~'-"'-- .... ."... ,.....,_.__".'.., .~.w"... ~., ..,_,_._.,... .,.. ..... "..,.... ..,_.. ._m'__..~". ....".__".._'...._,~, ._._.._..... .__~,.... .~,",.""".'..~.._ ..... ~~.._ _..., .~_'".._~.,........ . 8215.96 95.00 214.10 5989.26 -4811.05 -999.81 34.00 29.55 16.84 29.61 8352.10 95.00 230.50 5977.32 -4911.02 -1090.77 12.00 0.00 12.05 89.28 8477.84 90.75 245.00 5970.98 -4977.81 -1196.69 12.00 -3.38 11.53 105.90 8677.82 90.75 269.00 5968.32 -5022.46 -1390.11 12.00 0.00 12.00 89.84 8752.86 90.45 260.00 5967.53 -5029.65 -1464.72 12.00 -0.40 -11.99 268.14 9194.51 90.45 207.00 5963.79 -5283.08 -1807.21 12.00 0.00 -12.00 270.22 I 9302.84 90.45 220.00 5962.94 -5373.22 -1866.87 12.00 0.00 12.00 89.95 I 9511 .45 89.16 245.00 5963.66 -5499.20 -2031.05 12.00 -0.62 11.98 92.95 10200.00 89.16 162.00 5975.99 -6076.76 -2282.18 12.05 0.00 -12.05 269.26 Survey .,.,..........,.....,... .. n.,,_._,. '_'."_""M ...,._..._....._ ,.. .....,_._,. . .~.'".... ..._"._,_¥..... ._. ~..,. _....?~ .__.__.. ~,_ _.__ ... "_"'_"'M ... .~, . ' _.".~_., .,.'~.... . u. "~,,..__....' -~ .. . ... ..... ,,. .".....~.... .. MD Incl Azim SSTVD NIS E/W MapN Map,E VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg '.......,......... ....."....,.,,'. ." '".." ,,~,.'.'~' ... .... _....·_·,.w·_."'_···,..~·~ _..._..._"".. ... .. .'...._."M ".._ _ "........._.__..__,_.........~.._ "........_...._~_.'_~......._.."_'_h.._".. .._._.,",,",.....'....~...._"...'_,M'..'''M._... ".... .".....".".. ....'. .,,-" ."....-,. .. .. .....' .,,,...,,,. ".,~.,"..'.'... ,.-" 8000.00 49.90 187.13 5903.25 -4632.72 -941.34 5950202.02 507461.73 4675.29 0.00 0.00 TIP 8025.00 50.04 187.09 5919.33 -4651.71 -943.71 5950183.02 507459.38 4693.94 0.57 345.99 MWD 8050.00 50.18 187.04 5935.37 -4670.75 -946.06 5950163.99 507457.05 4712.64 0.57 346.02 MWD 8067.00 50.27 187.01 5946.24 -4683.71 -947.66 5950151.02 507455.46 4725.37 0.57 346.05 KOP 8075.00 52.97 189.19 5951.21 -4689.92 -948.55 5950144.81 507454.58 4731.51 40.00 33.00 MWD 8081.00 55.03 190.73 5954.74 -4694.70 -949.39 5950140.03 507453.75 4736.29 40.00 31.64 3 8100.00 60.47 194.76 5964.88 -4710.36 -952.95 5950124.37 507450.21 4752.22 33.78 33.15 MWD 8125.00 67.79 199.44 5975.78 -4731.83 -959.58 5950102.90 507443.60 4774.66 33.78 30.99 MWD 8150.00 75.23 203.66 5983.71 -4753.85 -968.30 5950080.86 507434.91 4798.34 33.78 28.94 MWD 8175.00 82.75 207.59 5988.48 -4775.95 -978.91 5950058.75 507424.32 4822.74 33.78 27.60 MWD 8199.03 90.00 211.25 5990.00 -4796.82 -990.69 5950037.87 507412.57 4846.37 33.78 26.85 4 8200.00 90.29 211.41 5990.00 -4797.65 -991.19 5950037.04 507412.07 4847.32 34.00 29.60 MWD 8215.96 95.00 214.10 5989.26 -4811.05 -999.81 5950023.64 507403.46 4862.86 34.00 29.61 5 8225.00 95.01 215.19 5988.47 -4818.46 -1004.93 5950016.22 507398.35 4871.58 12.00 89.28 MWD 8250.00 95.04 218.20 5986.28 -4838.43 -1019.81 5949996.24 507383.49 4895.43 12.00 89.38 MWD 8275.00 95.05 221.21 5984.08 -4857.59 -1035.72 5949977.07 507367.61 4918.87 12.00 89.64 MWD 8300.00 95.05 224.22 5981.88 -4875.88 -1052.61 5949958.75 507350.74 4941.84 12.00 89.90 MWD 8325.00 95.03 227.24 5979.69 -4893.26 -1070.44 5949941.35 507332.93 4964.27 12.00 90.17 MWD 8350.00 95.00 230.25 5977.50 -4909.68 -1089.16 5949924.91 507314.23 4986.11 12.00 90.43 MWD 8352.10 95.00 230.50 5977.32 -4911.02 -1090.77 5949923.58 507312.62 4987.91 12.00 90.70 6 8375.00 94.24 233.15 5975.47 -4925.12 -1108.71 5949909.45 507294.70 5007.30 12.00 105.90 MWD 8400.00 93.40 236.04 5973.80 -4939.57 -1129.04 5949894.98 507274.39 5027.84 12.00 106.12 MWD 8425.00 92.56 238.92 5972.50 -4952.99 -1150.09 5949881.54 507253.35 5047.65 12.00 106.31 MWD 8450.00 91.70 241 .80 5971.57 -4965.35 -1171.80 5949869.16 507231.66 5066.68 12.00 1 06.46 MWD 8475.00 90.85 244.67 5971.02 -4976.60 -1194.12 5949857.88 507209.36 5084.89 12.00 106.57 MWD 8477.84 90.75 245.00 5970.98 -4977.81 -1196.69 5949856.67 507206.79 5086.90 12.00 106.63 7 8500.00 90.76 247.66 5970.68 -4986.70 -1216.98 5949847.76 507186.51 5102.20 12.00 89.84 MWD 8525.00 90.76 250.66 5970.35 -4995.60 -1240.34 5949838.84 507163.16 5118.55 12.00 89.88 MWD 8550.00 90.77 253.66 5970.02 -5003.25 -1264.13 5949831.16 507139.38 5133.88 12.00 89.92 MWD 8575.00 90.77 256.66 5969.69 -5009.66 -1288.29 5949824.73 507115.23 5148.16 12.00 89.96 MWD 8600.00 90.77 259.66 5969.35 -5014.79 -1312.76 5949819.57 507090.78 5161.35 12.00 90.00 MWD 8625.00 90.76 262.66 5969.02 -5018.63 -1337.45 5949815.70 507066.08 5173.40 12.00 90.04 MWD 8650.00 90.76 265.66 5968.69 -5021.17 -1362.32 5949813.13 507041.22 5184.30 12.00 90.08 MWD 8675.00 90.75 268.66 5968.36 -5022.41 -1387.28 5949811.87 507016.26 5194.00 12.00 90.12 MWD 8677.82 90.75 269.00 5968.32 -5022.46 -1390.11 5949811.81 507013.44 5195.02 12.00 90.15 8 8700.00 90.66 266.34 5968.05 -5023.37 -1412.26 5949810.88 506991.29 5203.44 12.00 268.14 MWD 8725.00 90.56 263.34 5967.78 -5025.61 -1437.16 5949808.61 506966.40 5214.07 12.00 268.11 MWD 8750.00 90.46 260.34 5967.55 -5029.16 -1461.90 5949805.03 506941.66 5225.86 12.00 268.08 MWD 8752.86 90.45 260.00 5967.53 -5029.65 -1464.72 5949804.54 506938.84 5227.29 12.00 268.05 9 8775.00 90.46 257.34 5967.36 -5034.00 -1486.42 5949800.17 506917 .15 5238.80 12.00 270.22 MWD 8800.00 90.47 254.34 5967.15 -5040.11 -1510.66 5949794.03 506892.92 5252.83 12.00 270.20 MWD ) BP ) &..1 -..a.. Baker Hughes INTEQ Planning Report IN'I'EQ '''.._........_ .... _"_...._._.....__..._,."..__..~,...~...._ u" ._..__..~,....~_..,___.." _.~"~"'..~"....._"_.."........~__..~ .._"..__..,___._.~.__""_.,._"...,,.._._ .._,_..__~_"..,___._".._. ...". '~m_.'_..."_ .0_,. "' _.'.'".. __ .....,_,...." "·n....."._. ....m.· ............1 Company: Phillips Alaska, Inc. Date: .1/9/2003 Time: 13:1.7:29 Page: 3 Field: Kuparuk River Unit Cq"Ordillate(NErReference: W~II: 28~03,TrlJe North Site: KRU 28 Pad Vertical (TV]»Reference: System: . Mean Sea Level Well: 28-03 S~tion(VS)Referenç~: ..... Well(0.00N,O.00E,200.00Azi) Wellpath: Plan#1.1 28-03A __...._~~~~r.~~I~_~l~~~~!!_~~!~~..c~~_._.._._._~!~i~_~~.~~~~tu.~e._........ ...... ..~.~.:..~y-base .- __._ ....~_._ ...____ _.___,__._.'__ .."_._.·.·.._....·_'.m_·,.·...··.,,._ _..... Survey ... ''''''-0''''''-'-,,,''-''''''-'-- .".... ,-_,_._ .".........__._.. .."..."_.~,_,,.. .~-:-_~_......""__..._......_..__..._'_ _._ __~'____'.__'_"'..'__".~~___'_"'_' _...._"____._,.__... __.~_~_..._ __.. ..__.....__.'.__,_._. ..___" .......__,_.. ...__ n'" _ _", ._. . _....._ _,n._.....",,_.,,__.·,...· .".._....._ ...._ _"p""__' .".,~."._,." . MD Incl Azlm SSTVD N/S EIW M.apN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg .. '''' -... ... . .... ".. .......... .... ,.".."-.......,,~.,,. "_.,,.~. .._,.,_...... .~',,,,_.~ _.._.._.-...~.. ..,...,""._~........._... ".' .~._"...,.>._..""-" ,-.... -...-........,,- 8825.00 90.48 251.34 5966.95 -5047.48 -1534.54 5949786.63 506869.05 5267.93 12.00 270.18 MWD 8850.00 90.49 248.34 5966.74 -5056.10 -1558.01 5949777.99 506845.59 5284.05 12.00 270.15 MWD 8875.00 90.49 245.34 5966.52 -5065.93 -1580.99 5949768.14 506822.62 5301.15 12.00 270.13 MWD 8900.00 90.50 242.34 5966.31 -5076.95 -1603.43 5949757.09 506800.20 5319.17 12.00 270.10 MWD 8925.00 90.50 239.34 5966.09 -5089.12 -1625.26 5949744.89 506778.39 5338.08 12.00 270.08 MWD 8950.00 90.50 236.34 5965.87 -5102.43 -1646.42 5949731.57 506757.25 5357.82 12.00 270.05 MWD 8975.00 90.50 233.34 5965.65 -5116.82 -1666.85 5949717.15 506736.83 5378.34 12.00 270.02 MWD 9000.00 90.50 230.34 5965.43 -5132.27 -1686.51 5949701.69 506717.19 5399.57 12.00 270.00 MWD 9025.00 90.50 227.34 5965.21 -5148.72 -1705.33 5949685.22 506698.39 5421.47 12.00 269.97 MWD 9050.00 90.50 224.34 5965.00 -5166.13 -1723.26 5949667.79 506680.48 5443.96 12.00 269.95 MWD 9075.00 90.49 221.34 5964.78 -5184.46 -1740.26 5949649.44 506663.51 5467.00 12.00 269.92 MWD 9100.00 90.49 218.34 5964.57 -5203.65 -1756.27 5949630.23 506647.51 5490.51 12.00 269.89 MWD 9125.00 90.48 215.34 5964.36 -5223.65 -1771.26 5949610.21 506632.55 5514.44 12.00 269.87 MWD 9150.00 90.47 212.34 5964.15 -5244.42 -1785.18 5949589.44 506618.65 5538.71 12.00 269.84 MWD 9175.00 90.46 209.34 5963.95 -5265.88 -1798.00 5949567.96 506605.86 5563.26 12.00 269.82 MWD 9194.51 90.45 207.00 5963.79 -5283.08 -1807.21 5949550.75 506596.67 5582.57 12.00 269.79 10 9200.00 90.45 207.66 5963.75 -5287.95 -1809.73 5949545.88 506594.16 5588.01 12.00 89.95 MWD 9225.00 90.45 210.66 5963.55 -5309.78 -1821.91 5949524.04 506582.01 5612.69 12.00 89.95 MWD 9250.00 90.45 213.66 5963.36 -5330.94 -1835.21 5949502.87 506568.73 5637.13 12.00 89.98 MWD 9275.00 90.45 216.66 5963.16 -5351.38 -1849.60 5949482.41 506554.36 5661.25 12.00 90.00 MWD 9300.00 90.45 219.66 5962.96 -5371.03 -1865.05 5949462.74 506538.94 5685.00 12.00 90.02 MWD 9302.84 90.45 220.00 5962.94 -5373.22 -1866.87 5949460.56 506537.12 5687.68 12.00 90.05 11 9325.00 90.31 222.66 5962.79 -5389.85 -1881.50 5949443.91 506522.51 5708.32 12.00 92.95 MWD 9350.00 90.16 225.65 5962.69 -5407.79 -1898.91 5949425.96 506505.12 5731.12 12.00 92.97 MWD 9375.00 90.00 228.65 5962.65 -5424.79 -1917.24 5949408.94 506486.81 5753.37 12.00 92.98 MWD 9400.00 89.84 231.64 5962.69 -5440.81 -1936.43 5949392.90 506467.64 5774.98 12.00 92.98 MWD 9425.00 89.69 234.64 5962.79 -5455.80 -1956.43 5949377.88 506447.66 5795.91 12.00 92.98 MWD 9450.00 89.53 237.64 5962.96 -5469.73 -1977.18 5949363.93 506426.92 5816.10 12.00 92.97 MWD 9475.00 89.38 240.63 5963.20 -5482.55 -1998.64 5949351.09 506405.48 5835.49 12.00 92.95 MWD 9500.00 89.23 243.63 5963.50 -5494.24 -2020.74 5949339.38 506383.40 5854.03 12.00 92.92 MWD 9511.45 89.16 245.00 5963.66 -5499.20 -2031.05 5949334.40 506373.09 5862.22 12.00 92.88 12 9525.00 89.14 243.37 5963.86 -5505.10 -2043.25 5949328.49 506360.90 5871.93 12.05 269.26 MWD 9550.00 89.10 240.35 5964.24 -5516.89 -2065.29 5949316.68 506338.88 5890.55 12.05 269.28 MWD 9575.00 89.07 237.34 5964.64 -5529.82 -2086.68 5949303.73 506317.51 5910.02 12.05 269.33 MWD 9600.00 89.04 234.33 5965.06 -5543.86 -2107.36 5949289.67 506296.84 5930.28 12.05 269.38 MWD 9625.00 89.01 231.31 5965.48 -5558.96 -2127.27 5949274.54 506276.95 5951.28 12.05 269.43 MWD 9650.00 88.98 228.30 5965.92 -5575.09 -2146.36 5949258.39 506257.88 5972.97 12.05 269.48 MWD 9675.00 88.96 225.29 5966.37 -5592.20 -2164.58 5949241.26 506239.68 5995.28 12.05 269.53 MWD 9700.00 88.94 222.27 5966.83 -5610.25 -2181.87 5949223.20 506222.41 6018.15 12.05 269.58 MWD 9725.00 88.92 219.26 5967.30 -5629.17 -2198.19 5949204.26 506206.12 6041.52 12.05 269.64 MWD 9750.00 88.91 216.25 5967.77 -5648.94 -2213.49 5949184.48 506190.84 6065.32 12.05 269.70 MWD 9775.00 88.89 213.23 5968.25 -5669.47 -2227.73 5949163.93 506176.62 6089.49 12.05 269.75 MWD 9800.00 88.89 210.22 5968.74 -5690.73 -2240.88 5949142.66 506163.50 6113.96 12.05 269.81 MWD 9825.00 88.88 207.20 5969.22 -5712.65 -2252.88 5949120.73 506151.52 6138.67 12.05 269.87 MWD 9850.00 88.88 204.19 5969.71 -5735.17 -2263.72 5949098.20 506140.71 6163.54 12.05 269.93 MWD 9875.00 88.88 201.18 5970.20 -5758.23 -2273.36 5949075.13 506131.10 6188.50 12.05 269.99 MWD 9900.00 88.88 198.16 5970.69 -5781.77 -2281.77 5949051.59 506122.72 6213.49 12.05 270.05 MWD 9925.00 88.89 195.15 5971.18 -5805.71 -2288.93 5949027.64 506115.58 6238.44 12.05 270.10 MWD 9950.00 88.90 192.14 5971 .66 -5830.00 -2294.83 5949003.35 506109.71 6263.28 12.05 270.16 MWD 9975.00 88.91 189.12 5972.13 -5854.56 -2299.44 5948978.78 506105.13 6287.94 12.05 270.22 MWD 10000.00 88.93 186.11 5972.61 -5879.33 -2302.75 5948954.01 506101.85 6312.35 12.05 270.28 MWD 10025.00 88.95 183.09 5973.07 -5904.25 -2304.75 5948929.09 506099.87 6336.45 12.05 270.34 MWD 10050.00 88.97 180.08 5973.52 -5929.23 -2305.45 5948904.11 506099.21 6360.16 12.05 270.39 MWD Company: Phillips Alaska, Inc. Field: Kuparuk River Unit Site: KRU 28 Pad Well: 28-03 Well path: Plan#1.1 28-03A Survey MD ft 10075.00 10100.00 10125.00 10150.00 10175.00 10200.00 . -- .....", ..'". ..". ." ~.. Incl deg 89.00 89.02 89.05 89.09 89.12 89.16 Azim deg 177.07 174.05 171.04 168.03 165.01 162.00 ) ) --.... ....... ..N''fRQ BP Baker Hughes INTEQ Planning Report .. .... .", ._... _h"." ..,..._.._u,....o.., ~n.~,._.._.., ._~.,'_.._.__~.~, ,__ __. .,._.'.,._..__....__.~...' ....__,._""__._~....~_""...._.~._". ,_.._,.._,_.._..~...." .._...~._....___ _. ",~_~, ._., ."._h"_ ,~...~ "._.. ."~ ~,._..,,_ .,.._ ."." .._....... _,._.." .. . , M"_ ._.... _.... ~_.., ,..w_.._'_.,._,"." .._-"..__._ Date: 1/9/2003 Time: 13:17:29 Page: 4 Co,.()rdinate(NE) Reference: Well: .28-03, True North Vertical (TV») Reference: System:. Mean Sea Level Sedion(VS)Reference:. Well (Q.00N,0.00E,200.00Azi) .._......_...~~~~~:.£~~_~I.~~~_~_~!.!!!.~~:...:-'-,.~~~!T.~T..~~~ature . .. .... J?~:. Sybase .. ...._,..... ~_'·_._"_"n ....'.. _.,...~._ __,.._.__.~"...~, ".__o..._~~,_._.~. "...~____..,.._." ...._..."...___..." ,_.._.. .__..~~ ,__... _.~__.........._,_,_~...__'" _...... ~ .,0'" ~~_"",.~,."..__._.".._., .,_, '". ".~. SSTVD N/S E/W MapN DLS TFO Tool ft ft ft ft deg/100ft deg 5973.97 -5954.21 -2304.82 5948879.13 6383.43 12.05 270.45 MWD 5974.40 -5979.13 -2302.89 5948854.22 506101.82 6406.18 12.05 270.50 MWD 5974.82 -6003.91 -2299.65 5948829.44 506105.09 6428.36 12.05 270.55 MWD 5975.22 -6028.49 -2295.11 5948804.87 506109.66 6449.90 12.05 270.60 MWD 5975.61 -6052.80 -2289.28 5948780.57 506115.51 6470.75 12.05 270.65 MWD 5975.99 -6076.76 -2282.18 5948756.62 506122.63 6490.84 12.05 270.70 TD (2B-03IPtan#1.1 2B-03A) Date: 1/9/2003 Plan: Plan # Created By: Brii Polnis Azimuths to True North Magnetic North: 25.31° Direct: (907) 250-0132 Hughes IrJ.¡:~~il:(~g¿)ii~f'~~6com Contac- Magnetic Field Strength: 57474nT Dip Angle: 80.67° Date: 1/9/2003 Model: BGGM2002 T ^M t-' e- LEGEND 26-03 (2B·03) Plan# 1.1 26-03A Plan #1.1 (PKliups~! ~ ...- m·· . BAKUt I . , ,., HUGIIU; - I ::: ... .~. o¡¡ lNTEQ I ,- .~_~ 1._~~~_ Inc. Phillips Alaska, WELLPATH DnAlLS "aftll.! 21-oJA 500282115101 211-03 aooo.oo Bake Paront YHllpaUt: ne on MD: lUg: Ref. Datum: 2.-o3...KB 126.0Oft v.-= ~!; ~~~ :=~D 200.00' 0.00 0.00 0.00 ----- REFERENCE INFORMATION -4600-- co~~c::r~~(t~5¡ ~:::;:~~: ~~:e~:n~~~~~;'L:~e~ Nort Mea~~~idö~~f~ ~:::;:~~: ~if.~3 WK~N.O·~~)OO Calculation Method: Minimum Curvature .--- -4800- 5000- - C æ o -5200--- o _ N - - + i" -5400 ~ 1:: o ~ "':'" -5600-- - -- .c ., ~ o en -5800-- T.~t uc:nOH DETAfU, a.c lItO hlc Ad TVD +HI-S +E;·W DL.. Trace VSec ~ :=:gg =:~ U~:~~ :r4l~: ==:~~ ~;::: ~ 34~:= ~~t~ 3 aoIt.oo n.D3 '10.73 0S4.7. ........70 .a..S ~.oo 33.00 ....,34.28 . 8'H.03 10.00 2U.2S H.o.oo ..c798..83 .etO." 33.78 33.15 4a4I.3ð I 12t5." 05.00 2'..,0 HII.2I .....tt.oS ..".I, S4..00 21.81 4682.81 e 1352.10 '1.00 230.50 1871_32 ....11'OZ ·1080." 12..00 8..Z1 .017.81 7 .477.... eo.75 245.00 H70." -41177.&' -11M..8 12.00 105.80 50.45.10 . .877..2 10.71 268.00 HðI.32 -5022M -1310.11 12.00 ...&4 51"..0'2 o 1752.68 tOA5 zeo.oo He7.53 -6020'" -1464.72 12..00 Hl.14 5227.2iJ 10 .1.....11 80M 207.00 1MJ.78 .uaJ.o. -1107.21 '2..00 270.22 SSl2.57 11 8302:.&4 10.45 220.00 He2..M -sJ73.2Z -1HeA7 12.00 ....5 5817.N 12 11111.45 '..1' 241.00 1813.. ·Mn.20 ·2031.0S 12.00 112.S5 1182.22 13 10200.00 ".15 182..00 H7I'" -eon.71 ·22.2.11 12..05 210.28 M80..8A T AA:GET ŒT Al.S T\.~ +K'-S *EJ-W """ ANNOTATIONS TVD MD Annotation 5803.2S SOOO.OO TIP 5841.24 SH7.oo KO' 1854.74 SOII1.00 3 1"0.00 111".03 4 58118.21 112 II." I 1877.32 11352.10 1 InO.8S 8477.14 7 18118.32 8877..2 S 1"7.53 117S2.e1 8 5"3.78 11114.11 10 5"2.14 8S02.&4 11 1"3.ee 8511.41 12 5878.11I 10200.00 TO 5400 5500 -6200 - -- -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -BOO West(- )/East( +) [200ft/in] ~~~ I 2ß..03A! -200 -400 -' __ ___TIJ__. -~-~ Plan#1.1 2B-03A V1D' '~1 -6Q0(} ~5· 4· ~TlP . ~K.O... P. .. < .3 - c: æ 5600 o o ~ - ~ 5700 a. G) Q 'i 5800 U :e G) > G) 5900 i! t- 6000 6100 6200 6300 6400 6500 -----tl9/2003-· --1 : 17 PM 5900 5300 5400 5500 5600 5700 5800 Vertical Section at 200.00° [100ft/in] 5200 5100 ~~]_(~ª=<>1l 5000 4900 4800 4700 6000 6100 Page 1 I ...,.. Base FlanQe ~ . ~ ~ ··t·····..·....·..···j·AJ-~ . ",' o I ssv I ~ L·································;·I I:C:·:¡:¡:·:·:·:¡:¡:·:¡:Wi?':. ~a AI IOJT D()J ~ Master Valve ~ ~ \ ~ I I r 2 ~!,'I!3" ':',)ml\~ It: :': : . J I r Ü T LM.'............ ~I,¡"¿·: c~;;;bi"'l I __ u._-,--- . . . ~. '.' ";'....T ":-- I '. ..~....... . I ^ ..... "I t- . . ¡ I +- '.: .':'. .:~~~.:::~ :.... ··:x ::~~.. -- I . ..... . I "" .. ,,' ~ --..--.. ... ~© r . I ~k>wT... ~ ~1__~_f'1"",L;n.___ J 1--+ ~ Tree Size ~ Swab Valve ~ ¡...... ·Oh..··..···k··......···U..··· ... " "" " ::::::: :.:-: :·:0:-: :'e::::::::ne '''' , '" , . " " ....,', ....,...,..,',',','.',',..'..,',,',., . . , . . . . . . . . . . . , . , . , , . . , ~ /. I ~ ./ I 11t1[ L-J Â I: "", t _ 5000 11::;.1 R·.., ~ . .'\'':;'.. I J :: ::2 :~:.ë.0.mbí.:· :::: ., .... . ., ... 0...... . .... . . .. ..; ,;,;,;J.QJ.,;', . .:.:' I. ' . j I M~: 9~~~f (iJ ': I 7 1/16" 5000 psi RX-46 11/4 Turn L T Valve ~ ~ all I .. I I.... 17 1116" 5000 pSI, RX-46 ~ / I ; ·\'t.!~~~~~r7.:) i:·:.:~f,.df.II·Ag:~itjl~1::··:··:·:I· 171:16 5000 psi BOP"s. 10=7.06 /' Lubricator 10:::: 6:375" with 5" OUs Unions I I, OJID~~ r . . . Rig Floor ~ KB Elevation ~:~":: :..:'.?:'):::':~;::::I ) BOP-Tree ) T l'lll¡r : ~ 1ª!!:·~Øqþ:j#f:.}J:>: Weill I Rev: 07/10/02 C\jody\templates ;, ") TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing well Permit No, API No. Production ·should continue to be reported as a function 'of the ,original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all 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 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce 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. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. DATE CHECK NO. P054978 P054978 11/18/02 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET H 11/18/02 INV# CKll1402S PERMIT TO DRIL~ FEE RECEIVED ~ß-D3A- .JA.N 1 ,,) 2003 Alaska Oil & Gas Con s. Commission A!1chonqe "- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ TO THE ORDER OF 18 ~"" 2001 NQTVALlDAFTER 120 DAYS" "~" BP EXPLORATION, (ALASKAtNG· PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGI;, AK99519-6612 PAY ~~;.:::.~~.:.::.:.:: ::::~~ :'.:":':':::~:~~:j'/:,.;;\~~~\~:~.::~~:\\ ~::·1 f..·........Jj~ ~:'~. ...'·1-··..'"· ...... ..... f:}::/!;;~·\r.~{f;~~i:hi:~;~:~;!~~~;Çl·ti 1110 5 l. c¡ 7 a III B: 0 l. ~ 20 3 a g 5 I: 0 ~ 2 7 a c¡ bill _---,.___ _~n_______ -_ --- Lair. WELL PERMIT CHECKLIST COMPANY fll. I)J /!.5 ilK. WELL NAME /( /¿¡ 26' - 6 3A PROGRAM: Exp _ Dev L Redrll ~ Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL INIT CLASS tJe.v /"'d.~/ GEOL AREA íj , 6 UNIT# ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . r? N 2. Lease number appropriate. . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. W ell located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . \ '!. N 12. Permit can be issued without administrative approval.. . . . . \::/) N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_ ~X "I/o>. 4. (Service Well Only) 14. All wells w/in y.. mile area of review identified. . . . . . . . .. ~ ~ ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N 16. Surface casing protects all known USDWs. . . . . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. . . . --N- N/A- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . AN, 19. CMT will cover all known productive horizons. . . . . . . . . . Gy¿ N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . ~ N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . NeT D ú( 22. If a re-drill, has a 10-403 fo.r abandonment been approved. . . / N llll./: I" ~ . 23. Adequate wellbore separation proposed.. . . . . . " . . . . ,N 24. If diverter required, does it meet regulations. . , . . . . . . . ~N N/A- I / 25, Drilling fluid program schematic & equip list adequate. . . . . N q, 2- P PC¡ --r I {. Š P po, ck.4 túGlt-wr BX.@."ý pet-I fÄ.4,(C~ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N V - I 27. BOPE press rating appropriate; testto 3Çoo psig. N 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N 29. Work will occur without operation shutdown. . . . . . . . . . . "'Z') N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . ~, N 31. Mechanical condition of wells within AOR verified. . . . . . . . '--¥--N-N/Æ- V@ ß~·A' APPR DATE &L~ APPR DATE ~ ~310~ (Service Well Only) GEOLOGY APPR DATE 11'(; f1~? 'tExploratory Only) 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... ..I' ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING ule ENGINEER RP~ TEM JDH JBR /' MJW SFD_ WGA Rev: 10/15/02 COMMISSIONER: Comments/lns\~uc~ionS: / COT . lIJ'J J'.1 -- ¡f r~ k~~ vVc-1/ DTSð¿J,)JJO J t:.r A-.kt - C íu A~y cI~"'~/'t:.. MLBo2/e>Y/¿J.3 ~~~I..v;t 1.oY'/~.mi/ ~ G:.èM)d be t.I~"'r $,rA..)I'.f}c.&..-.1. -:- R'p¿ G:\geology\perm its\checklist.doc ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sìm,plify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) **** REEL HEADER **** MWD 04/03/04 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/03/04 444503 01 2.375" CTK *** LIS COMMENT RECORD *** ) Remark File Version 1.000 Extract File: ldwg.las ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 8000.5000: STOP.FT 10165.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N IlN RANG. 09E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 126 DMF KB EKB .F 126 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL OS2 . PRESSTEQ I -Remarks 1. 20: NO: ~~~~~ ~. œ -009 CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska Inc. 2B-03A Kuparuk River Unit 70 deg 17' 16.163" N 149 deg 55' 55.300" W North Slope Alaska Baker Hughes INTEQ 2.375 CoilTrak 12-Mar-03 500292115101 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Other Services Line 1 RECEIVED \,,1.' fJ 1 6 ~no I~ ;¡-;~ . :....~ ..~ .Alas~s on & Gas Con$. Commiækm f~f¡~hQfage Data record type is: 0 * FORMAT RECORD (TYPE# 64) 0.0 0.0 GRAX ROPS GR ROP GR ROP ---------------------------------------------------- ODEP *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control) .Per ConocoPhillips instructions, the MWD Gamma Ray is PDC for this borehole *** LIS COMMENT RECORD *** mwd 5.xtf 150- ConocoPhillips Alaska Inc. 2B-03A Kuparuk River Unit North Slope Alaska WDFN LCC CN WN FN COUN STAT ---------------------------------- *** INFORMATION TABLE: CONS MNEM VALU 1024 MWD .001 **** FILE HEADER **** 14 bytes 132 bytes Minimum record length: Maximum record length: 61 records... Tape Subfile: 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) The well 2B-03A was kicked-off from original well 2B-03 at 8067' MD (5946' SSTVD) and was drilled to TD at 10165' MD (5993' SSTVD) on Run 13. (5). Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE surface system. (6) Tools ran in the string included CCL, Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and an Orienting Sub with a near bit inclination sensor. (7) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips instructions, the MWD Gamma Ray is PDC for this borehole. (8) The interval from 10136' MD (5994' SSTVD) to 10165' MD (5993' SSTVD) was not logged due to sensor bit offset at TD. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet ) ) ) ) Datum Frame Size is: 12 bytes Logging direction is down (value= 255) optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 52 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8000.500000 10165.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 61 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 ConocoPhillips Alaska In 2B-03A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. ) ) *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAX MWD ROPS MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 104 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8000.000000 10164.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 113 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/03/04 444503 01 **** REEL TRAILER **** MWD 04/03/04 , ) BHI 01 Tape Subfile: 4 2 records. . . Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 8000.5000 61.9200 -999.2500 8001.0000 62.5854 -999.2500 8100.0000 138.4700 26.7871 8200.0000 92.9100 47.2862 8300.0000 67.4700 144.5800 8400.0000 67.8933 130.1150 8500.0000 74.7300 126.5075 8600.0000 77.5850 140.9100 8700.0000 66.7589 134.6825 8800.0000 68.0100 127.6475 8900.0000 75.6200 115.9800 9000.0000 83.0200 35.9075 9100.0000 87.9400 132.4750 9200.0000 88.0700 53.5400 9300.0000 52.2200 101. 7225 9400.0000 62.7980 91. 4850 9500.0000 72.5600 127.8200 9600.0000 106.2100 59.8625 9700.0000 110.7950 103.4050 9800.0000 84.0150 68.5850 9900.0000 81. 4667 116.1825 10000.0000 73.8900 101.2700 10100.0000 109.5150 89.4950 10165.0000 -999.2500 -999.2500 Tape File Start Depth 8000.500000 Tape File End Depth 10165.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 8000.0000 -999.2500 -999.2500 8000.2500 54.8200 -999.2500 8100.0000 138.4700 26.7871 8200.0000 92.9100 47.2862 8300.0000 67.4700 144.5800 8400.0000 67.8933 130.1150 8500.0000 74.7300 126.5075 8600.0000 77.5850 140.9100 8700.0000 66.7589 134.6825 8800.0000 68.0100 127.6475 8900.0000 75.6200 115.9800 9000.0000 83.0200 35.9075 9100.0000 87.9400 132.4750 9200.0000 88.0700 53.5400 9300.0000 52.2200 101.7225 ,,,ft ) ) 9400.0000 62.7980 91. 4850 9500.0000 72.5600 127.8200 9600.0000 106.2100 59.8625 9700.0000 110.7950 103.4050 9800.0000 84.0150 68.5850 9900.0000 81.4667 116.1825 10000.0000 73.8900 101.2700 10100.0000 109.5150 89.4950 10164.7500 -999.2500 -999.2500 Tape File Start Depth 8000.000000 Tape File End Depth 10164.750000 Tape File Level Spacing 0.250000 Tape File Depth Units feet Tape Subfile 4 is type: LIS