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Home My WebLink About198-1901. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11197'feet None feet true vertical 5373' feet None feet Effective Depth measured 10781'feet 10303'feet true vertical 5155'feet 4889'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)2-3/8" 3-1/2" L-80 L-80 10221' 10462' 4848' 4974' Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Tarn Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Packer: Tri Piont Retrivable 10303'MD/4889'TVD SSSV: None 325-184 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 Leslie Manning leslie.manning@conocophillips.com (907) 263-3731Staff RWO Engineer 10774-10804' 5152-5168' 10400'4-1/2" 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) N/A Gas-Mcf MDSize 108' Well Shut-In measured TVD 5-1/2" x 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-190 50-103-20270-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0380054 Kuparuk River Field/ Tarn Oil Pool KRU 2N-315 Plugs Junk measured Length Production Liner 11153' Casing 5363'11179' 10424'4953' 3776' 108'Conductor Surface 16" 7-5/8" 78' 3805'2317' Burst Collapse Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:40 pm, Jun 06, 2025 DSR-6/18/25JJL 6/13/25 RBDMS JSB 061325 Page 1/8 2N-315 Report Printed: 6/2/2025 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) 4/26/2025 00:00 4/26/2025 03:00 3.00 MIRU, MOVE OTHR P Complete BWM. Install 2 3/8" fixed in LPR. 0.0 0.0 4/26/2025 03:00 4/26/2025 12:30 9.50 MIRU, MOVE MOB P Mob sub F/ 2S T/ 2N 0.0 0.0 4/26/2025 12:30 4/26/2025 15:30 3.00 MIRU, MOVE MOB P Lay down double mats. Lay down herculite. Hang tree in cellar. Stage wellhead equipment behind well. 0.0 0.0 4/26/2025 15:30 4/26/2025 16:30 1.00 MIRU, MOVE MOB P Spot sub over 2N-315. Set down. Verify center & level. 0.0 0.0 4/26/2025 16:30 4/26/2025 19:00 2.50 MIRU, MOVE RURD P Berm in cellar. R/U auxillary equipment. Take initial RKB's.. Complete acceptance checklist. Rig accepted @ 19:00 Hrs. 0.0 0.0 4/26/2025 19:00 4/26/2025 23:30 4.50 MIRU, WELCTL RURD P Take on seawater to pits. Build 35 Bbls heated deep clean pill. R/U circ equipment in cellar. Take initial pressures T/IA/OA = 600/620/0. Call out grease crew to service tree. R/U hard line. 0.0 0.0 4/26/2025 23:30 4/27/2025 00:00 0.50 MIRU, WELCTL SFTY P PJSM w/ rig crew on well kiill. 0.0 0.0 4/27/2025 00:00 4/27/2025 00:30 0.50 MIRU, WELCTL PRTS P PT circ manifold & kill tank hard line T/ 3000 PSI. 0.0 0.0 4/27/2025 00:30 4/27/2025 04:00 3.50 MIRU, WELCTL KLWL P Bleed free gas off TBG & IA. Kill well down TBG w/ 32 Bbls heated deep clean pill, followed by 421 Bbls seawater @ 3 BPM. 8.6 PPG back to surface. 0.0 0.0 4/27/2025 04:00 4/27/2025 04:30 0.50 MIRU, WELCTL OWFF P OWFF. B/D Hardline to tanks. TBG dead. IA spitting fluid. 0.0 0.0 4/27/2025 04:30 4/27/2025 04:45 0.25 MIRU, WELCTL KLWL P Pump additional 60 Bbls down TBG taking returns T/ pits through MGS @ 3 BPM, 570 PSI. 0.0 0.0 4/27/2025 04:45 4/27/2025 05:15 0.50 MIRU, WELCTL OWFF P OWFF. TBG dead. IA spitting fluid. 0.0 0.0 4/27/2025 05:15 4/27/2025 05:30 0.25 MIRU, WELCTL KLWL P Pump additional 50 Bbls down TBG taking returns T/ pits through MGS @ 3 BPM, 570 PSI. 0.0 0.0 4/27/2025 05:30 4/27/2025 08:30 3.00 MIRU, WELCTL OWFF P OWFF, IA sputtering Tubing filling 5 gal bucket / 10 minutes. Slowing down. Next 5 gal bucket full in 17 min. IA lightly sputtering. Monitor. Next 5 gal bucket @ 23 min. IA static. Tubing went static 0.0 0.0 4/27/2025 08:30 4/27/2025 10:00 1.50 MIRU, WELCTL MPSP P Set BPV. Rolling test to 1000 PSI 0.0 0.0 4/27/2025 10:00 4/27/2025 12:00 2.00 MIRU, WHDBOP NUND P PJSM, ND Tree, Function test LDS, 9 Turns on hanger threads, Install test dart On High Line 10:30 0.0 0.0 4/27/2025 12:00 4/27/2025 14:30 2.50 MIRU, WHDBOP NUND P PJSM, NU BOPE, Measure RKB's center stack, Install riser. Hook up trip tank lines 0.0 0.0 4/27/2025 14:30 4/27/2025 16:30 2.00 MIRU, WHDBOP RUNL P R/U testing equipment, Purge lines. Grease BOPE. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2025 Page 2/8 2N-315 Report Printed: 6/2/2025 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) 4/27/2025 16:30 4/28/2025 00:00 7.50 MIRU, WHDBOP BOPE P Initial BOPE test. Test BOPE to 250/3000 PSI for 5 Min each, Tested UVBR's w/ 2 7/8" & 4 1/2" test joins. Test LPR w/ 2 3/8" test joint. Test annular w/ 2 3/8" & 4 1/2" test joint. Test blinds rams.Choke valves #1 to #13, upper and lower top drive well control valves. Test 2 7/8" Pac HT FOSV & IBOP. Test 3 1/2" & 4 1/2" EUE & 3 1/2" IF FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 2950 PSI, after closure = 1650 PSI, 200 PSI attained = 22 sec, full recovery attained = 120 sec. UVBR's = 5 sec, LVBR’s = 5 sec. Annular = 19 sec. Simulated blinds = 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2000 PSI. Witness waived by AOGCC rep Brian Bixby. 0.0 0.0 4/28/2025 00:00 4/28/2025 01:45 1.75 MIRU, WHDBOP BOPE P Complete initial BOPE test. 0.0 0.0 4/28/2025 01:45 4/28/2025 02:00 0.25 MIRU, WHDBOP BOPE T CMV #8 failed initial test. Rebuilt CMV #8. Passed retest. 0.0 0.0 4/28/2025 02:00 4/28/2025 03:00 1.00 MIRU, WHDBOP RURD P B/D, R/D testing equipment. 0.0 0.0 4/28/2025 03:00 4/28/2025 03:30 0.50 MIRU, WHDBOP MPSP P Pull dart & BPV. 0.0 0.0 4/28/2025 03:30 4/28/2025 03:45 0.25 COMPZN, RPCOMP RURD P M/U landing joint. K/U. Set 10K down. BOLDS. 0.0 0.0 4/28/2025 03:45 4/28/2025 04:00 0.25 COMPZN, RPCOMP PULL P Pull hanger T/ RF. Hanger off seat @ 70K. Pipe free @ 160K. PUW=95K. 10,420.0 10,385.0 4/28/2025 04:00 4/28/2025 05:15 1.25 COMPZN, RPCOMP CIRC P Circ STS+ @ 3 BPM, 440 PSI. Over boarding contaminated fluid. 10,385.0 10,385.0 4/28/2025 05:15 4/28/2025 06:00 0.75 COMPZN, RPCOMP OWFF P OWFF. L;/D hanger & landing joint. B/D TD. 10,385.0 10,385.0 4/28/2025 06:00 4/28/2025 16:00 10.00 COMPZN, RPCOMP PULL P Pull 3 1/2 Completion from pre rig cut @ 10385 , PUW=55K 10,385.0 105.0 4/28/2025 16:00 4/28/2025 16:30 0.50 COMPZN, RPCOMP CIRC P Circulate diesel fluid out of tubing, 2 BPM @ 62 PSI 105.0 105.0 4/28/2025 16:30 4/28/2025 17:00 0.50 COMPZN, RPCOMP OWFF P OWFF. Goog 105.0 0.0 4/28/2025 17:00 4/28/2025 17:30 0.50 COMPZN, RPCOMP PULL P Continue out of well. Recovered 325 Jts 3 1/2 1nd 1 cut joint 15.03 0.0 0.0 4/28/2025 17:30 4/28/2025 19:30 2.00 COMPZN, RPCOMP CLEN P Crew change out. Clear RF & pipe shed. B/D TD. 0.0 0.0 4/28/2025 19:30 4/28/2025 20:30 1.00 COMPZN, RPCOMP RURD P Install wear bushing. 0.0 0.0 4/28/2025 20:30 4/28/2025 21:30 1.00 COMPZN, RPCOMP SVRG P Service rig. Work on TBG tongs. 0.0 0.0 4/28/2025 21:30 4/28/2025 22:30 1.00 COMPZN, RPCOMP CLEN P Clean RF. 0.0 0.0 4/28/2025 22:30 4/28/2025 23:30 1.00 COMPZN, RPCOMP PULD P P/U 2 7/8" Pac HT DP T/ 191'. 0.0 191.0 4/28/2025 23:30 4/29/2025 00:00 0.50 COMPZN, RPCOMP CIRC P Circ contamintated fluid off top of holw. @ 3 BPM, 88 PSI. Over boarding contaminated diesel fluid. 180.0 180.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2025 Page 3/8 2N-315 Report Printed: 6/2/2025 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) 4/29/2025 00:00 4/29/2025 00:30 0.50 COMPZN, RPCOMP CIRC P Circ contamintated fluid off top of holw. @ 3 BPM, 88 PSI. Over boarding contaminated diesel fluid. 191.0 191.0 4/29/2025 00:30 4/29/2025 01:00 0.50 COMPZN, RPCOMP OWFF P OWFF. B/D circ hose. 191.0 191.0 4/29/2025 01:00 4/29/2025 01:30 0.50 COMPZN, RPCOMP TRIP P Rack back 2 stands 2 7/8" Pac HT DP. 191.0 0.0 4/29/2025 01:30 4/29/2025 04:30 3.00 COMPZN, RPCOMP RURD P Process 83 joints 2 7/8" Pac DP. 3 1/8" DC/s. Load BHA. 0.0 0.0 4/29/2025 04:30 4/29/2025 06:00 1.50 COMPZN, RPCOMP BHAH T M/U BHA #1 Spear, jars DC's T/ 180'' M/U joint #1 Pac DP T/ 210'. 0.0 210.0 4/29/2025 06:00 4/29/2025 06:45 0.75 COMPZN, RPCOMP CIRC T Attempt to circ. Pressure up. 210.0 210.0 4/29/2025 06:45 4/29/2025 07:30 0.75 COMPZN, RPCOMP BHAH T TOOH w/ BHA #1 to find obstruction. Spear plugged with trash. 210.0 0.0 4/29/2025 07:30 4/29/2025 08:00 0.50 COMPZN, RPCOMP BHAH T M/U BHA #1 Spear, jars DC's T/ 180'' M/U joint #1 Pac DP T/ 210'. 0.0 210.0 4/29/2025 08:00 4/29/2025 08:30 0.50 COMPZN, RPCOMP CIRC T Circ STS @ 2 BPM, 790 PSI. 210.0 210.0 4/29/2025 08:30 4/29/2025 09:30 1.00 COMPZN, RPCOMP PULD T P/U 2 /8" Pac DP T/ 1203'. PUW=44K. SOW=44K. 210.0 1,203.0 4/29/2025 09:30 4/29/2025 10:00 0.50 COMPZN, RPCOMP CIRC T Circ STS @ 2 BPM, 955 PSI. 1,203.0 1,203.0 4/29/2025 10:00 4/29/2025 11:00 1.00 COMPZN, RPCOMP PULD T P/U 2 /8" Pac DP F/ 1203' T/ 2116'. PUW=50K. SOW=46K. 1,203.0 2,116.0 4/29/2025 11:00 4/29/2025 12:30 1.50 COMPZN, RPCOMP CIRC T Circ BU @ .5 BPM, 2220 PSI. 2,116.0 2,116.0 4/29/2025 12:30 4/29/2025 13:15 0.75 COMPZN, RPCOMP PULD T P/U 2 /8" Pac DP F/ 2116' T/ 2715'. PUW=55K. SOW=47K. 2,116.0 2,715.0 4/29/2025 13:15 4/29/2025 15:00 1.75 COMPZN, RPCOMP CIRC T Circ @ .5 BPM, 2220 PSI. Drop activation ball to open circ sub. Ball on seat 3600 PSI, fell T/ 2300 PSI. Circ 1 BPM, 3500 PSI. Decison made to change out BHA T/ overshot. 2,715.0 2,715.0 4/29/2025 15:00 4/29/2025 17:00 2.00 COMPZN, RPCOMP TRIP T TOOH racking back 2 7/8" DP F/ 2715' T/ 171'. PUW=55K. 2,715.0 0.0 4/29/2025 17:00 4/29/2025 17:30 0.50 COMPZN, RPCOMP SVRG T Service rig 0.0 0.0 4/29/2025 17:30 4/29/2025 19:30 2.00 COMPZN, RPCOMP WAIT T Wait for overshot 0.0 0.0 4/29/2025 19:30 4/29/2025 20:30 1.00 COMPZN, RPCOMP BHAH T Pick up BHA # 2 4.6" overshot 0.0 175.0 4/29/2025 20:30 4/29/2025 22:30 2.00 COMPZN, RPCOMP CIRC T Circulate due to drill string out of balance, unable to get flow to stop out of drill pipe, annulus not gaining 175.0 175.0 4/29/2025 22:30 4/30/2025 00:00 1.50 COMPZN, RPCOMP WAIT T Process 136jts 2-7/8 Pac pipe while waiting for flapper sub 175.0 175.0 4/30/2025 00:00 4/30/2025 01:30 1.50 COMPZN, RPCOMP WAIT T Process 136jts 2-7/8 Pac pipe while waiting for flapper sub 175.0 175.0 4/30/2025 01:30 4/30/2025 02:30 1.00 COMPZN, RPCOMP BHAH T Make up BHA# 2 w/ float sub 175.0 177.0 4/30/2025 02:30 4/30/2025 03:45 1.25 COMPZN, RPCOMP TRIP T Trip in hole with BHA# 2 on stands 2- 7/8" Pac pipe 177.0 1,110.0 4/30/2025 03:45 4/30/2025 04:15 0.50 COMPZN, RPCOMP CIRC T Circ STS @ 2 BPM, 479 PSI. 1,110.0 1,110.0 4/30/2025 04:15 4/30/2025 05:15 1.00 COMPZN, RPCOMP TRIP T TIH F/ 1110' T/ 2063', PUW=50K, SOW=44K 1,110.0 2,063.0 4/30/2025 05:15 4/30/2025 06:15 1.00 COMPZN, RPCOMP CIRC T Circ STS @ 2 BPM, 525 PSI. Crew change out. 2,063.0 2,063.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2025 Page 4/8 2N-315 Report Printed: 6/2/2025 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) 4/30/2025 06:15 4/30/2025 07:15 1.00 COMPZN, RPCOMP TRIP T TIH F/ 2063' T/ 2711', PUW 54K, SOW 45K 2,063.0 2,711.0 4/30/2025 07:15 4/30/2025 09:00 1.75 COMPZN, RPCOMP PULD T P/U 2 7/8" Pac DP F/ 2711 T/ 4501', PUW=74K, SOW=45K 2,711.0 4,501.0 4/30/2025 09:00 4/30/2025 09:45 0.75 COMPZN, RPCOMP CIRC T Circ BU @ 3 BPM, xx1400 PSI. 4,501.0 4,501.0 4/30/2025 09:45 4/30/2025 11:30 1.75 COMPZN, RPCOMP PULD T PUDP F/ 4501' T/ 6768'. 4,501.0 6,768.0 4/30/2025 11:30 4/30/2025 12:30 1.00 COMPZN, RPCOMP CIRC T Circ BU @ 3 BPM, 1750 PSI. 6,768.0 6,768.0 4/30/2025 12:30 4/30/2025 16:00 3.50 COMPZN, RPCOMP PULD T XO P/U 2 7/8" HT Pac DP F/ 6768' T/ 10250', PUW=135K, SOW=50K. 6,768.0 10,250.0 4/30/2025 16:00 4/30/2025 19:00 3.00 COMPZN, RPCOMP SLPC T Slip & cut 66' drill line. Lube up system w/ 776. Begin circ lube seawater around. 10,250.0 10,250.0 4/30/2025 19:00 4/30/2025 20:00 1.00 COMPZN, RPCOMP TRIP T TIH T/ 10342' // Up wt 130K Dn Wt 49 K Rot 5000 ft/lbs 10,250.0 10,342.0 4/30/2025 20:00 4/30/2025 21:15 1.25 COMPZN, RPCOMP CIRC T Circulate in lubes 2% lube 776, Pump 2 bpm @ 2900 psi // Check torque while rotating 3800 ft/lbs Up Wt 106K Dn wt 60K 10,342.0 10,342.0 4/30/2025 21:15 4/30/2025 21:45 0.50 COMPZN, RPCOMP OWFF T Flow check well no flow 10,342.0 10,342.0 4/30/2025 21:45 5/1/2025 00:00 2.25 COMPZN, RPCOMP TRIP T Trip out of hole for clean out assembly 10,342.0 8,800.0 5/1/2025 00:00 5/1/2025 06:45 6.75 COMPZN, RPCOMP TRIP T Trip out of hole for clean out assembly F/ 8800' T/ 175" 8,800.0 175.0 5/1/2025 06:45 5/1/2025 08:30 1.75 COMPZN, RPCOMP BHAH T L/D BHA #2. 175.0 0.0 5/1/2025 08:30 5/1/2025 10:00 1.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. Mobilize tools for BHA #3. 0.0 0.0 5/1/2025 10:00 5/1/2025 11:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #3 clean out run T/ 201'. 0.0 201.0 5/1/2025 11:00 5/1/2025 21:30 10.50 COMPZN, RPCOMP TRIP P TIH F/ 201' T/ 10385'. Filling pipe every 2500'. 201.0 10,385.0 5/1/2025 21:30 5/1/2025 22:30 1.00 COMPZN, RPCOMP WASH P Wash over stump pump 53 spm @ 1760 psi // Free Rot 35 rpm @ 2700 ft/lbs Wash down over stump top at 10421' 45 psi pump pressure increase , NG @ 10427 100 psi pump pressure increase Pick up T/ 10,416', unable to wash over second time, attempt to rotate over unable to pass 10421' 10,385.0 10,427.0 5/1/2025 22:30 5/2/2025 00:00 1.50 COMPZN, RPCOMP BKRM P Back ream packer set depths up to 10182' 10,427.0 10,182.0 5/2/2025 00:00 5/2/2025 06:30 6.50 COMPZN, RPCOMP TRIP P Trip out of hole racking stands in derrick 10,182.0 201.0 5/2/2025 06:30 5/2/2025 07:45 1.25 COMPZN, RPCOMP BHAH P L/D BHA #3, cut lip on wash pipe shoe, folded over. 201.0 0.0 5/2/2025 07:45 5/2/2025 09:00 1.25 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 5/2/2025 09:00 5/2/2025 09:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #4 test packer T/ 44'. 0.0 44.0 5/2/2025 09:30 5/2/2025 16:30 7.00 COMPZN, RPCOMP TRIP P TIH F/ 44' T/ 12210', PUW-=95K, SOW=63K. 44.0 10,218.0 5/2/2025 16:30 5/2/2025 18:30 2.00 COMPZN, RPCOMP CIRC P Circ BU @ 2 BPM, 700 PSI. 10,218.0 10,218.0 5/2/2025 18:30 5/2/2025 19:30 1.00 COMPZN, RPCOMP PRTS P Set test packer 10204' COE , Test casing to top of RBP @ 10467' 2000 psi 10 min good test 10,218.0 10,218.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2025 Page 5/8 2N-315 Report Printed: 6/2/2025 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) 5/2/2025 19:30 5/2/2025 20:00 0.50 COMPZN, RPCOMP OWFF P OWFF while prepping for laying down drill pipe 10,218.0 10,218.0 5/2/2025 20:00 5/3/2025 00:00 4.00 COMPZN, RPCOMP PULD P Pull out of hole laying down drill pipe 10,218.0 6,700.0 5/3/2025 00:00 5/3/2025 04:00 4.00 COMPZN, RPCOMP PULD P Pull out of hole laying down drill pipe 6,700.0 20.0 5/3/2025 04:00 5/3/2025 05:00 1.00 COMPZN, RPCOMP BHAH P Lay down packer 20.0 0.0 5/3/2025 05:00 5/3/2025 07:00 2.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor 0.0 0.0 5/3/2025 07:00 5/3/2025 07:45 0.75 COMPZN, RPCOMP RURD P Load completion equipment in pipe shed. Verify joint count & jewelry running order. 0.0 0.0 5/3/2025 07:45 5/3/2025 08:45 1.00 COMPZN, RPCOMP RURD P R/U GBR Torque Turn equipment. Dump test tongs. 0.0 0.0 5/3/2025 08:45 5/3/2025 09:00 0.25 COMPZN, RPCOMP SFTY P PJSM w/ Baker & GBR on running 4 1/2" tie back string. 0.0 0.0 5/3/2025 09:00 5/3/2025 15:00 6.00 COMPZN, RPCOMP PUTB P Run PBOS, 1.875 X Nipple 5 1/2" s 3 1/2" packer, KBG GLM, 80-40 PBR. Run 4 1/2", 11.6#, L-80, Hyd 513 liner T/ 3278'. PUW=66K, SOW=47K. 2 3/8" EUE torque T/ 1600 Ft/Lbs. 4 1/2" Hyd 513 torque turn T/ 3400 Ft/Lbs. 0.0 3,278.0 5/3/2025 15:00 5/3/2025 16:00 1.00 COMPZN, RPCOMP CIRC P Circ STB @ 3 BPM, 960 PSI. 3,278.0 3,278.0 5/3/2025 16:00 5/4/2025 00:00 8.00 COMPZN, RPCOMP PUTB P Run 4 1/2" liner F/ 3278' T/ 8200 3,278.0 8,200.0 5/4/2025 00:00 5/4/2025 02:45 2.75 COMPZN, RPCOMP PUTB P Run 4 1/2" liner F/ 8200' T/ 9643 8,200.0 9,643.0 5/4/2025 02:45 5/4/2025 06:00 3.25 COMPZN, RPCOMP CIRC P Circulate STS @ 1.7 bpm @ 1363 psi Crew change out. 9,643.0 9,643.0 5/4/2025 06:00 5/4/2025 07:00 1.00 COMPZN, RPCOMP PUTB P Run 4 1/2" liner F/ 9643' T/ 10400'. PUW=100K. SOW=65K. 9,643.0 10,400.0 5/4/2025 07:00 5/4/2025 09:30 2.50 COMPZN, RPCOMP PUTB P Wash in @ 1 BPM, 970 PSI. Taking weight @ 10420', Saw shear @ 10423' w/ 65K down. Took weight again @ 10426' w/ 10K down. PSI increase T/ 1500. Kill pump., P/U of stub. Confirm weight & PSI @ 10426', 2x. 10,400.0 10,426.0 5/4/2025 09:30 5/4/2025 11:30 2.00 COMPZN, RPCOMP CRIH P P/U T/ 10418'. Pump 50 Bbls CI seawater followed by 114 Bbls slick seawater @ 1.5 BPM, 1300 PSI. RIH T/ 10424', set slips. B/D TD. 10,426.0 10,424.0 5/4/2025 11:30 5/4/2025 12:00 0.50 COMPZN, RPCOMP SFTY P PJSM w/ HES & rig crew on R/U & slick line. 10,424.0 10,424.0 5/4/2025 12:00 5/4/2025 12:45 0.75 COMPZN, RPCOMP RURD P R/U slick line. 10,424.0 10,424.0 5/4/2025 12:45 5/4/2025 14:00 1.25 COMPZN, RPCOMP SLKL P Run 1.80" cent, 1.25" x 5' stem, 1.85" gauge ring T/ 10428' Slick Line Depth. POOH. 10,424.0 10,424.0 5/4/2025 14:00 5/4/2025 15:30 1.50 COMPZN, RPCOMP SLKL P Change tool sting RIH w/ 1.80" cent, 1.25" x 5' stem, 1.85" cent T/ 10291' Slick Line Depth. POOH. Inspect tool string. 10,424.0 10,424.0 5/4/2025 15:30 5/4/2025 17:00 1.50 COMPZN, RPCOMP SLKL P Run 2 3/8" X-line w/ 1.74" OD. Had to work through tight spot @ 10291'. Located X @ 10386'. Located top of hex @ 10475' (All SL Depths) 10,424.0 10,424.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2025 Page 6/8 2N-315 Report Printed: 6/2/2025 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) 5/4/2025 17:00 5/5/2025 00:00 7.00 COMPZN, RPCOMP SLKL P Wait on slick line tools from wireline shop, Run 1.87" drift to X-nipple confirm drift, good run, RIH W/ 1.80" CENT, 5' x 1.25" STEM, 1.84" SWAGE &BULL NOSE, TOOLS FALL FREE & TAGGED HEX PLUG@ 10,478' SLM (10,465' RKB), POOH, CHANGE TOOLS.RIH W/ 2 3/8" X-LINE & 1.875" XX PLUG (OAL 23"),BOBBLED THRU X NIP, COME BACK UP TO SHIFTX-LINE, SAT DOWN @ 10,370' SLM (10,355' RKB), TAPPACKING THRU & START SETTING LOCK, SAWDOUBLE BOBBLE, GOOD PULL TEST, SHEAR OFF &POOH. 10,424.0 10,424.0 5/5/2025 00:00 5/5/2025 00:30 0.50 COMPZN, RPCOMP RURD P Rig up circ lines to set packer and pressure test 10,424.0 10,424.0 5/5/2025 00:30 5/5/2025 00:45 0.25 COMPZN, RPCOMP PACK P Pump to 3700 psi w/ rig pumps 46 total strokes ( 2.7 bbls ) , swap to test pump continue to 4400 psi, 10,424.0 10,424.0 5/5/2025 00:45 5/5/2025 01:30 0.75 COMPZN, RPCOMP PRTS P PT tubing 3000 psi 30 min good test 10,424.0 10,424.0 5/5/2025 01:30 5/5/2025 02:00 0.50 COMPZN, RPCOMP RURD P Rig up slick line to retrieve xx plug 10,424.0 10,424.0 5/5/2025 02:00 5/5/2025 03:15 1.25 COMPZN, RPCOMP SLKL P Retrieve XX plug from x-nipple 10,424.0 10,424.0 5/5/2025 03:15 5/5/2025 03:45 0.50 COMPZN, RPCOMP RURD P Rig down slick line 10,424.0 10,424.0 5/5/2025 03:45 5/5/2025 04:45 1.00 COMPZN, RPCOMP PRTS P RIg up test equipment, PT packer 2000 psi 30 min good test rig down test equipment 10,424.0 10,424.0 5/5/2025 04:45 5/5/2025 05:15 0.50 COMPZN, RPCOMP SVRG P Service TD and blocks 10,424.0 10,424.0 5/5/2025 05:15 5/5/2025 07:30 2.25 COMPZN, RPCOMP BHAH P M/U BHA #5 4 1/2" RBP. T/ 80'. Crew change out. 10,424.0 10,424.0 5/5/2025 07:30 5/5/2025 08:00 0.50 COMPZN, RPCOMP RURD P Fill pipe. Flood lines. R/U circ equipment. P/U T/ set depth 69.04'. 10,424.0 10,424.0 5/5/2025 08:00 5/5/2025 08:15 0.25 COMPZN, RPCOMP MPSP P Pressure up w/ test pump. Set & shear off RBP T/ 3000 PSI. COE @ 67.19', Top @ 61.58' 10,424.0 10,424.0 5/5/2025 08:15 5/5/2025 08:30 0.25 COMPZN, RPCOMP TRIP P Set down 3K on RBP, confirm set. L/D DP top joint of DP T/ 45' 10,424.0 10,424.0 5/5/2025 08:30 5/5/2025 09:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Change out fitting on power tongs cylinder. 10,424.0 10,424.0 5/5/2025 09:00 5/5/2025 09:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #5. 10,424.0 10,424.0 5/5/2025 09:30 5/5/2025 09:45 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. 10,424.0 10,424.0 5/5/2025 09:45 5/5/2025 10:00 0.25 COMPZN, RPCOMP PRTS P PT RBP/ 1000 PSI for 10 Min. 10,424.0 10,424.0 5/5/2025 10:00 5/5/2025 10:30 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 10,424.0 10,424.0 5/5/2025 10:30 5/5/2025 13:00 2.50 COMPZN, RPCOMP NUND P Split BOP stack, lift. Set 11 x 4 1/2" emergency slips w/ 70K down. Cut 4 1/2" joint w/ WHACKS saw. Pull cut joint. Rack back BOP stack. 10,424.0 0.0 5/5/2025 13:00 5/5/2025 15:15 2.25 COMPZN, RPCOMP NUND P N/U new 7 1/16" x 11" TBG Head. Install test plug. 0.0 0.0 5/5/2025 15:15 5/5/2025 15:30 0.25 COMPZN, RPCOMP PRTS P PT pack off T/ 5000 PSI for 10 Min. 0.0 0.0 5/5/2025 15:30 5/5/2025 18:00 2.50 COMPZN, RPCOMP NUND P Move 2nd IA valve up to new head. N/U BOP. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2025 Page 7/8 2N-315 Report Printed: 6/2/2025 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) 5/5/2025 18:00 5/5/2025 19:00 1.00 COMPZN, RPCOMP RURD P R/U testing equipment. Fill stack w/ fresh water. Crew change out. 0.0 0.0 5/5/2025 19:00 5/5/2025 19:30 0.50 COMPZN, RPCOMP PRTS P PT stack break T/ 250/3000 PSI. Weekly BOPE function test. 0.0 0.0 5/5/2025 19:30 5/5/2025 20:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 5/5/2025 20:00 5/5/2025 20:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #6. RBP retrievail head. 0.0 10.0 5/5/2025 20:30 5/5/2025 21:00 0.50 COMPZN, RPCOMP MPSP P Release RBP @ 67'. 10.0 67.0 5/5/2025 21:00 5/5/2025 22:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #6 & RBP. 67.0 0.0 5/5/2025 22:00 5/5/2025 22:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed 0.0 0.0 5/5/2025 22:30 5/5/2025 23:00 0.50 COMPZN, RPCOMP RURD P R/U GBR TBG equipment. Verify joint count and jewelry running order. 0.0 0.0 5/5/2025 23:00 5/5/2025 23:15 0.25 COMPZN, RPCOMP SFTY P PJSM w/ GBR, Baker & rig crew on running 2 3/8" completion. 0.0 0.0 5/5/2025 23:15 5/6/2025 00:00 0.75 COMPZN, RPCOMP PUTB P Pick up and run 2-3/8" EUE completion per approved tally 0.0 200.0 5/6/2025 00:00 5/6/2025 11:00 11.00 COMPZN, RPCOMP PUTB P Pick up and run 2-3/8" EUE completion per approved tally T/ 10200' 200.0 10,200.0 5/6/2025 11:00 5/6/2025 13:00 2.00 COMPZN, RPCOMP HOSO P Kelly up to Jt 324, pump 1 bpm @ 108 psi , locate SBE @ 10211' , 200 psi increase, NG @ 10,222', calculate space out for landing 10,200.0 10,222.0 5/6/2025 13:00 5/6/2025 14:00 1.00 COMPZN, RPCOMP CIRC P Circulate in 127 bbls CI 10,222.0 10,220.0 5/6/2025 14:00 5/6/2025 15:00 1.00 COMPZN, RPCOMP HOSO P Land hanger RILDS 10,220.0 10,220.0 5/6/2025 15:00 5/6/2025 16:00 1.00 COMPZN, RPCOMP RURD P Rig up PT equipment 10,220.0 10,220.0 5/6/2025 16:00 5/6/2025 17:00 1.00 COMPZN, RPCOMP PRTS P PT TxIA 2000 psi / unable to get passing test on tubing, communication to IA 10,220.0 10,220.0 5/6/2025 17:00 5/6/2025 18:00 1.00 COMPZN, RPCOMP RURD P Rig down test equipment for slick line ops 10,220.0 10,220.0 5/6/2025 18:00 5/6/2025 19:30 1.50 COMPZN, RPCOMP WAIT T Wait for slick line to run dummy valve 10,220.0 10,220.0 5/6/2025 19:30 5/6/2025 20:30 1.00 COMPZN, RPCOMP SLKL T Spot and R/U Slick line unit 10,220.0 5/6/2025 20:30 5/6/2025 23:00 2.50 COMPZN, RPCOMP SLKL T RIH w/ Catcher and set @10150' SLM /POOH 10,220.0 10,220.0 5/6/2025 23:00 5/7/2025 00:00 1.00 COMPZN, RPCOMP SLKL T RIH and Pull SOV @ 10123' W/ SLM 10,220.0 10,220.0 5/7/2025 00:00 5/7/2025 00:30 0.50 COMPZN, WHDBOP SLKL T POOH /L/D SOV 10,220.0 10,220.0 5/7/2025 00:30 5/7/2025 03:00 2.50 COMPZN, WHDBOP SLKL T RIH/ Dummy valve and set @ 10123 SLM POOH 10,200.0 10,200.0 5/7/2025 03:00 5/7/2025 04:30 1.50 COMPZN, WHDBOP PRTS P Test Tubing t/2000 psi All Good 30 mins bleed down to 1500 psi and terst B.S 2500 PSI f/ 30 mins 10,200.0 10,200.0 5/7/2025 04:30 5/7/2025 07:30 3.00 COMPZN, WHDBOP SLKL P RIH to pull dummy valve and catcher from completion 10,200.0 10,200.0 5/7/2025 07:30 5/7/2025 08:15 0.75 COMPZN, WHDBOP SLKL P Rig down slick line unit 0.0 0.0 5/7/2025 08:15 5/7/2025 09:00 0.75 COMPZN, WHDBOP CLEN P Jet Stack 0.0 0.0 5/7/2025 09:00 5/7/2025 10:00 1.00 COMPZN, WHDBOP MPSP P Set BPV and test 1000psi 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2025 Page 8/8 2N-315 Report Printed: 6/2/2025 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) 5/7/2025 10:00 5/7/2025 12:00 2.00 COMPZN, WHDBOP NUND P Nipple down BOPs 0.0 0.0 5/7/2025 12:00 5/7/2025 14:00 2.00 COMPZN, WHDBOP NUND P Nipple up production tree, PT void 5000 psi 0.0 0.0 5/7/2025 14:00 5/7/2025 14:30 0.50 COMPZN, WHDBOP RURD P Rig up LRS to freeze protect 0.0 0.0 5/7/2025 14:30 5/7/2025 16:30 2.00 COMPZN, WHDBOP FRZP P Freeze protect OA w/ 8 bbls diesel, FP IAxT w/ 25 bbls LEPD 0.0 0.0 5/7/2025 16:30 5/7/2025 20:30 4.00 DEMOB, MOVE RURD P Misc rig down from well pull off well prep for transport 0.0 0.0 5/7/2025 20:30 5/8/2025 00:00 3.50 DEMOB, MOVE MOB P Mob rig 2X Rig released 00:00 on 5/8/25 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/8/2025 Page 1/1 2N-315 Report Printed: 6/6/2025 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 148.80 Well Status PROD Legal WellName 2N-315 API / UWI 5010320270 Field Name TARN PARTICIPATING AREA Start Date 3/9/2025 09:00 End Date Secondary Job Type BARRIER TESTING Objective Final Job Status IN PROGRESS Primary Wellbore Affected 2N-315 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number ACQUIRE DATA 2N-315 RWO - Wells 2N-315 Capitalize 10449006 UNIT/RIG: AES WELL INTEGRITY DHD Rig Accept Date 5/11/2025 Rig Release Date 5/11/2025 Rig Supervisor MILLER, MATT,DHD Field Supervisor Title DHD Field Supervisor Company CPAI Phone W… 659-7098 Mobile N/A Pager 993 Job scope, work string information, or noted if job is performed during drilling operations Comment Daily Operations Report Start Date 5/11/2025 06:00 Report End Date 5/11/2025 14:00 Status at Reporting Time 05/12/2025 Time Log Hrs (hr) 8.00 ZX Code ZX08 Ann-Comm Evaluation / Leak Detection this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary (MISC) CDDT T X IA TO 0 PSI (PASS) ) TEST IA COMPANION FLANGE & VR PLUG TO 5K (PASS) General Remarks Initial T/I/O/OO = SI 13/31/404/243 Final T/I/O/OO = SI 0/1/404/243 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager SHEETS, ROBERT,DHD Tech DHD Tech AES 659-7098 N/A N/A BORGE, CHRIS,DHD Tech DHD Tech AES 659-7098 509-336-9161 N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 06:00 07:00 1.00 1.00 NE TRAV P Travel from KOC to 2N-315 2N-315 07:00 07:30 0.50 1.50 NE RURD P MIRU 2N-315 07:30 12:30 5.00 6.50 NE DHD P (MISC) CDDT T X IA TO 0 PSI (PASS) ) TEST IA COMPANION FLANGE & VR PLUG TO 5K (PASS) Initial T/I/O/OO = SI 13/31/404/243, T FL @ NS, IA FL @ SF Stung into companion alemite with 0 psi, pressured up to 5000 psi. monitor for 30 min, 15 min = 5000 psi 30 min = 5000 psi, bled void between VR plug and companion flange to 0 psi U- tube T x IA for 30 min T/I/O/OO = 17/20/404/243 Bled T X IA for 30 min simultaneously to T/I/O/OO = vac/2/404/243 (fluid) Held T & IA on open bleeds for 2 hrs. Starting T/I/O/OO = 0/0/404/243 15 min T/I/O/OO = 0/1/404/243 (+1) 30 min T/I/O/OO = 0/1/404/243 (0) Final T/I/O/OO = SI 0/1/404/243 2N-315 12:30 13:00 0.50 7.00 NE RURD P RDMO 2N-315 13:00 14:00 1.00 8.00 NE TRAV P Travel from 2N-315 to 2L-310 2N-315 Job: ACQUIRE DATA Report Date: 5/11/2025 Rig: AES WELL INTEGRITY DHD *filters for Intervention jobs only Page 1/1 2N-315 Report Printed: 6/6/2025 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 148.80 Well Status PROD Legal WellName 2N-315 API / UWI 5010320270 Field Name TARN PARTICIPATING AREA Start Date 3/9/2025 09:00 End Date Secondary Job Type BARRIER TESTING Objective Final Job Status IN PROGRESS Primary Wellbore Affected 2N-315 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number ACQUIRE DATA 2N-315 RWO - Wells 2N-315 Capitalize 10449006 UNIT/RIG: HES SLICK LINE 765 Rig Accept Date 5/12/2025 Rig Release Date 5/12/2025 Rig Supervisor FERGUSON, SID,Wells Supervisor Title Wells Supervisor Company CPAI Phone W… 659-7223 Mobile 943-1065 Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment START TKT 09:00 END TKT 19:00 Daily Operations Report Start Date 5/12/2025 05:30 Report End Date 5/12/2025 21:00 Status at Reporting Time 05/16/2025 Time Log Hrs (hr) 15.50 ZX Code ZX50 Slickline / DSL Misc. (or Multiple Operations this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary SET 1.875'' XX PLUG IN X NIPPLE 10,355' RKB, SET 1.82'' x 68'' CATCHER ON XX PLUG 10, 354' RKB, INSTALLED 1'' .25'' PORT BTM LATCH OV ST # 1 10,104' RKB, PERFORMED PASSING 3000 PSI MITT, PULLED 1.82'' CATCHER 10,354' RKB.. IN PROGRESS General Remarks T/I/O/OO INITIAL= 0/10/350/250 FINAL=500/175/350/250 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager CONNOR, DAVE,Slickline Operator Slickline Operator HES N/A 907-317-8156 N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 05:30 08:00 2.50 2.50 SW TRAV P HAL MEETING, MEET W/ CWG, TRAV TO WL SHOP, PU TOOLS FOR JOB & EQUIPMENT STAGED AT WL SHOP, CONTACT DSO, TRAV TO 2N-315 2N-315 08:00 09:00 1.00 3.50 SW RURD P ARRIVE, INSPECT AREA, SPOT IN EQUIPMENT, TGSM, RU, .125'' WIRE & 1.25'' RLLR ( WHEELS 1.42'' ) TS = RS 6' 5' , KJ 6', KJ 6', 5', LSS ( 36' ) INSTALL FUSIBLE CAP, LOGGED W/ DSO 2N-315 09:00 12:30 3.50 7.00 SW SLKL P ****START TKT 09:00****PT W/ LRS 3000 PSI, RIH W/ 1.75'' X-LINE RT / 1.875'' XX PLUG 120 FPM, SD 10,346' SLM / 10,356' RKB, WORKED PLUG INTO 1.875'' X NIPPLE, SET PLUG, 1200 # OVERPULL, SHEARED OFF PLUG, POOH, OOH W/O PLUG 2N-315 12:30 14:30 2.00 9.00 SW SLKL P PT W/ LRS 3000 PSI, RIH W/ 2'' GS & 1.82'' x 68'' JUNK CATCHER, SD 10,354' RKB / 10, 344' SLM, SET CATCHER, POOH, OOH W/O CATCHER 2N-315 14:30 17:00 2.50 11.50 SW SLKL P PT W/ LRS 3000 PSI, RIH W/ 2 3/8'' DANIELS KOT / RT, 1'' 1/4'' PORT BTM LATCH OV, LOCATE / SD ST # 1 10,998' SLM / 10,104' RKB, WORKED VLV IN POCKET , SET VLV, SEEN TRAV, GOOD 2000 PSI TUBING TEST, SHEAR OFF , POOH.. OOH W/O VLV 2N-315 17:00 19:00 2.00 13.50 SW SLKL P INSTALL 4.5'' TEST CAP ON PCE, PERFORM 3000 PSI MITT W/ PASSING RESULTS, RIH W/ QC, 2'' GR, SD / LATCH 1.82'' JUNK CATCHER 10,344' SLM, POOH.. OOH W/ CATCHER PRE=950/200/400/250 INTITIAL=3050/275/400/250 15 MIN=3025/275/400/250 30 MIN=3015/275/400/250 2N-315 19:00 20:00 1.00 14.50 SW RURD P ****END TKT 19:00**** SECURE WELL, REMOVE FUSIBLE CAP, DSPCE, CUTT 200' WIRE LDFN, RE-PACK STUFFING BOX, PJSM, CONTACT DSO 2N-315 20:00 21:00 1.00 15.50 SW TRAV P TRAV TO OFFICE, SYNC CPU, TIWF 2N-315 FLUIDS - for CT include "BHA no" + "String Name" into Purpose field Fluid Fluid Sub Type To (bbl) Note DIESEL 1.0 PT / MITT Job: ACQUIRE DATA Report Date: 5/12/2025 Rig: HES SLICK LINE 765 *filters for Intervention jobs only Page 1/1 2N-315 Report Printed: 6/6/2025 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 148.80 Well Status PROD Legal WellName 2N-315 API / UWI 5010320270 Field Name TARN PARTICIPATING AREA Start Date 3/9/2025 09:00 End Date Secondary Job Type BARRIER TESTING Objective Final Job Status IN PROGRESS Primary Wellbore Affected 2N-315 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number ACQUIRE DATA 2N-315 RWO - Wells 2N-315 Capitalize 10449006 UNIT/RIG: HES SLICK LINE 765 Rig Accept Date 5/13/2025 Rig Release Date 5/13/2025 Rig Supervisor FERGUSON, SID,Wells Supervisor Title Wells Supervisor Company CPAI Phone W… 659-7223 Mobile 943-1065 Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment START TKT 08:00 END TKT 19:00 Daily Operations Report Start Date 5/13/2025 05:30 Report End Date 5/13/2025 20:30 Status at Reporting Time 05/14/2025 Time Log Hrs (hr) 15.00 ZX Code ZX50 Slickline / DSL Misc. (or Multiple Operations this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary EQUALIZED & PULLED 1.875'' XX PLUG 10,356' RKB. BAILED DEBRIS OFF OF 1.80'' HEX PLUG 10,466' RKB, IN PROGRESS. General Remarks T/I/O/OO INITIAL= 200/175/250/250 FINAL=150/150/250/250 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager CONNOR, DAVE,Slickline Operator Slickline Operator HES N/A 907-317-8156 N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 05:30 06:30 1.00 1.00 SW TRAV P HAL MEETING, CONFER W/ CWG, AQUIRE WELL FILE, CONTACT DSO, TRAV TO 2N-315 2N-315 06:30 07:30 1.00 2.00 SW RURD P ARRIVE, INSPECT AREA, TGSM, MUPCE, RU .125'' WIRE & 1.25'' RLLR ( 1.42'' WHEELS ) TS= RS 5' 6', KJ 5' 5' , KJ 5', OJS,LSS ( 39') 2N-315 07:30 10:30 3.00 5.00 SW WAIT P ***START TKT 08:00****WAIT ON SCAFFOLDING TO BE SIGNED OFF 2N-315 10:30 12:00 1.50 6.50 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ EQ PRONG ASSY, SD / 10,346' SLM, JD x1 , EQUILIZED PLUG, POOH.. OOH W/ TOOLS 2N-315 12:00 14:00 2.00 8.50 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ 2'' GR, SD / LATCH 1.875'' XX PLUG 10,356' RKB / 10, 346' RKB, POOH.. OOH W/ XX PLUG 2N-315 14:00 16:00 2.00 10.50 SW SLKL P PT W/ LRS 2500 PSI, RIH W/, 10' 1.75 IN. P-BAILER MSBB, SD 10,451' SLM / 10,461' RKB, WORKED BAILER 10 MIN , POOH, OOH W/ BAILER OF SMOO, MORE LIQUID THAN SOLIDS 2N-315 16:00 17:30 1.50 12.00 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ QC,1.5'' GS, SD 10,451' SLM / 10,461' RKB, ATTEMPT TO LATCH 1.80'' HEX PLU, POOH.. OOH W/ SHEARED GS 2N-315 17:30 19:00 1.50 13.50 SW SLKL P PT W/ LRS 2500 PSI, RIH W/, 10' 1.75 IN. P-BAILER MSBB, SD 10,451' SLM / 10,461' RKB, WORKED BAILER 15 MIN.. POOH..OOH W/ BAILER BTM OF FILL 2N-315 19:00 19:30 0.50 14.00 SW RURD P ****END TKT 19:00**** SECURE WELL, REMOVE FUSIBLE CAP, DSPCE, LDFN, CONTACT DSO 2N-315 19:30 20:30 1.00 15.00 SW TRAV P TRAV TO OFFICE, SYNC CPU, TIWF 2N-315 FLUIDS - for CT include "BHA no" + "String Name" into Purpose field Fluid Fluid Sub Type To (bbl) Note DIESEL PT Job: ACQUIRE DATA Report Date: 5/13/2025 Rig: HES SLICK LINE 765 *filters for Intervention jobs only Page 1/1 2N-315 Report Printed: 6/6/2025 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 148.80 Well Status PROD Legal WellName 2N-315 API / UWI 5010320270 Field Name TARN PARTICIPATING AREA Start Date 3/9/2025 09:00 End Date Secondary Job Type BARRIER TESTING Objective Final Job Status IN PROGRESS Primary Wellbore Affected 2N-315 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number ACQUIRE DATA 2N-315 RWO - Wells 2N-315 Capitalize 10449006 UNIT/RIG: HES SLICK LINE 765 Rig Accept Date 5/14/2025 Rig Release Date 5/14/2025 Rig Supervisor FERGUSON, SID,Wells Supervisor Title Wells Supervisor Company CPAI Phone W… 659-7223 Mobile 943-1065 Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment START TKT 08:00 END TKT 19:00 Daily Operations Report Start Date 5/14/2025 05:30 Report End Date 5/14/2025 21:30 Status at Reporting Time 05/15/2025 Time Log Hrs (hr) 16.00 ZX Code ZX50 Slickline / DSL Misc. (or Multiple Operations this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary BAILED DEBRIS OFF OF 1.80" HEX PLUG 10,466' RKB. ATTEMPT TO PULL HEX PLUG, NO SUCCESS...IN PROGRESS General Remarks T/I/O/OO INITIAL= 150/125/250/250 FINAL= 100/100/225/250 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager CONNOR, DAVE,Slickline Operator Slickline Operator HES N/A 907-317-8156 N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 05:30 06:30 1.00 1.00 SW TRAV P HAL MEETING, CONFER W/ CWG, AQUIRE WELL FILE, STOP BY WL SHOP TO PU TOOLS , CONTACT DSO, TRAV TO 2N-315 2N-315 06:30 07:30 1.00 2.00 SW RURD P ARRIVE, INSPECT AREA, TGSM, MUPCE, RU .125'' WIRE & 1.25'' RLLR ( 1.42'' WHEELS ) TS= RS 5' 6', KJ 5' 5' , OJS,LSS ( 33') 2N-315 07:30 09:00 1.50 3.50 SW WAIT P ***START TKT 08:00****WAIT ON SCAFFOLDING TO BE SIGNED OFF 2N-315 09:00 11:30 2.50 6.00 SW SLKL P PT W/ LRS 2500 PSI, RIH W/, 10' 1.75 IN. P-BAILER MSBB, SD 10,451' SLM / 10,461' RKB, WORKED BAILER 15 MIN.. POOH..OOH W/ BAILER BTM OF FILL 2N-315 11:30 13:30 2.00 8.00 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ QC, KJ ,5' 1.25'' RLLR ,BOW SPRING CENT,1.82'' LIB ( 103'' ) SD 10, 451' SLM / 10,466' RKB, JD x 2, POOH.. OOH W/ LIB, GOOD FISHING NECK IMPRESSION OFF HEX PLUG 2N-315 13:30 15:30 2.00 10.00 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ QC,BOW SPRING CENT, 1.5'' GS ( 39'') @ 120' FPM, SD IN GLM #2 @ 10,279' RKB, GENTLY TRY TO WORK TOOLS THROUGH, UNSUCCESSFUL, POOH, OOH W/ TOOLS 2N-315 15:30 18:00 2.50 12.50 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ QC,KJ, 5' X 1.25" RLLR, BOW SPRING CENT,1.5'' GS (OAL 107") @ 120' FPM, SD 10,453' SLM / 10,466' RKB, ATTEMPT TO LATCH, UNABLE, POOH, OOH W/ TOOLS 2N-315 18:00 20:00 2.00 14.50 SW SLKL P PT W/ LRS 2500 PSI, RIH W/ QC, KJ,1.85" CENT, 5' X 1.25" RLLR, BOW SPRING CENT, 1.5" GS (OAL 114") @ 120' FPM, SD 10,453' SLM / 10,466' RKB, ATTEMPT TO LATCH, UNABLE, POOH, OOH W/ TOOLS 2N-315 20:00 20:30 0.50 15.00 SW RURD P ****END TKT 20:00**** SECURE WELL, REMOVE FUSIBLE CAP, DSPCE, LDFN, CONTACT DSO 2N-315 20:30 21:30 1.00 16.00 SW TRAV P TRAV TO OFFICE, SYNC CPU, TIWF 2N-315 FLUIDS - for CT include "BHA no" + "String Name" into Purpose field Fluid Fluid Sub Type To (bbl) Note DIESEL PT Job: ACQUIRE DATA Report Date: 5/14/2025 Rig: HES SLICK LINE 765 *filters for Intervention jobs only Page 1/1 2N-315 Report Printed: 6/6/2025 WSR Historical - QC JOB Well Type Development Orig KB/RT (ft) 148.80 Well Status PROD Legal WellName 2N-315 API / UWI 5010320270 Field Name TARN PARTICIPATING AREA Start Date 3/9/2025 09:00 End Date Secondary Job Type BARRIER TESTING Objective Final Job Status IN PROGRESS Primary Wellbore Affected 2N-315 NETWORK Job Type Project Desc Common WellName Cost Type Network/Order Number ACQUIRE DATA 2N-315 RWO - Wells 2N-315 Capitalize 10449006 UNIT/RIG: HES SLICK LINE 765 Rig Accept Date 5/15/2025 Rig Release Date 5/15/2025 Rig Supervisor FERGUSON, SID,Wells Supervisor Title Wells Supervisor Company CPAI Phone W… 659-7223 Mobile 943-1065 Pager N/A Job scope, work string information, or noted if job is performed during drilling operations Comment Daily Operations Report Start Date 5/15/2025 05:30 Report End Date 5/15/2025 21:00 Status at Reporting Time 05/16/2025 Time Log Hrs (hr) 15.50 ZX Code ZX50 Slickline / DSL Misc. (or Multiple Operations this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary EQUALIZED & PULLED 1.80" HEX PLUGS @ 10,466' RKB & 10,486' RKB, JOB COMPLETE. General Remarks T/I/O/OO INITIAL= 100/100/375/250 FINAL= 950/150/350/275 weather related data when and if weather has affect on job Weather Wind T (°F) CONTRACTOR Supervisor Title Company Phone Work Mobile Pager CONNOR, DAVE,Slickline Operator Slickline Operator HES N/A 907-317-8156 N/A TIME LOG - enter a Vendor if trouble time occurs during operation Start Time End Time Dur (hr) Cum Dur (hr) Major Equip Activity Code Time P-T-X Operation Vendor (NPT) Wellbore 05:30 06:30 1.00 1.00 SW TRAV P HAL MEETING, CONFER W/ CWG, AQUIRE WELL FILE, STOP BY WL SHOP TO PU TOOLS , CONTACT DSO, TRAV TO 2N-315 2N-315 06:30 07:30 1.00 2.00 SW RURD P ARRIVE, INSPECT AREA, TGSM, RE PACK STUFFING BOX, MU PCE, RU .125'' WIRE & 1.25'' RLLR ( 1.42'' WHEELS ) TS= RS 5' , 3' , KJ 5' , 5' , OJS , LSS ( 30') INSTALL FUSIBLE, LOGGED W/ DSO 2N-315 07:30 10:30 3.00 5.00 SW SLKL P *** START TKT 08:00 *** PT W/ T-BIRD 2500 PSI, RIH W/ QC. 10' X 1.75" P- BAILER MS BB (OAL 150") SD 10,453' SLM / 10466' RKB WORK BAILER 15 MIN, POOH, OOH W/ TOOLS, (BOTTOM FULL OF SHMOO) 2N-315 10:30 14:30 4.00 9.00 SW SLKL P PT W/ T-BIRD 2500 PSI, RIH W/ QC, 2" GR, 1.84" BAIT SUB, BOW SPRING CENT, 3' X 1.25" RLLR STEM, BOW SPRING CENT, 1.5" GS (OAL 125") TOOLS FALL SLOWLY 20-100' FPM, SD 10453' SLM / 10,466' RKB, JOGGLED AROUND, LATCHED UP, HIT OJ LICK, SEE PRESSURE CHANGE, CONTINUE JARRING, COME FREE, SEE WEIGHT INCREASE, HANG UP 10,380' SLM, WAIT 30 MIN FOR ELEMENT TO RELAX, POOH, OOH W/ HEX PLUG 2N-315 14:30 15:30 1.00 10.00 SW SLKL P PT W/ T-BIRD 2500 PSI, RIH W/ QC, 2" GR, 1.84" BAIT SUB, BOW SPRING CENT, 3' X 1.25" RLLR STEM, BOW SPRING CENT, 1.5" GS (OAL 125") TOOLS FALL SLOWLY 20-50' FPM, STALL OUT 1800' SLM, POOH, OOH W/ TOOLS, ADD 8' LUBE SECTION, ADD 5' RLLR TS = RS 5' , 3' , KJ 5' , 5' , 5', OJS , LSS (OAL 35') 2N-315 15:30 19:00 3.50 13.50 SW SLKL P PT W/ T-BIRD 2500 PSI, RIH W/ QC, 2" GR, 1.84" BAIT SUB, BOW SPRING CENT, 3' X 1.25" RLLR STEM, BOW SPRING CENT, 1.5" GS (OAL 125") TOOLS FALL SLOWLY, SD 10,472' SLM / 10,486' RKB, 2 x 1100 # OJ LICKS, PLUG CAME FREE, WAIT 30 MIN FOR ELEMENT TO RELAX, POOH, OOH W/ HEX PLUG 2N-315 19:00 20:00 1.00 14.50 SW RURD P ****END TKT 19:00**** SECURE WELL, REMOVE FUSIBLE CAP, DSPCE, INSPECT AREA, CONTACT DSO, RDMO 2N-315 20:00 21:00 1.00 15.50 SW TRAV P STAGE EQUIPMENT AT W/L SHOP, TRAVEL TO OFFICE, SYNC CPU, TIWF 2N-315 FLUIDS - for CT include "BHA no" + "String Name" into Purpose field Fluid Fluid Sub Type To (bbl) Note DIESEL PT Job: ACQUIRE DATA Report Date: 5/15/2025 Rig: HES SLICK LINE 765 *filters for Intervention jobs only Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 10,799.0 2N-315 4/6/2025 raineg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set OV, pulled 1.80" HEX plugs. 2N-315 5/15/2025 fergusp 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 Insulated 16 15.06 30.0 108.0 108.0 62.58 H-40 WELDED SURFACE 7 5/8 6.87 29.3 3,805.0 2,316.6 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 10467' 5 1/2 4.95 26.0 11,178.5 5,363.4 15.50 L-80 LTCM Tie-Back String 4 1/2 4.00 23.8 10,424.0 4,953.1 11.60 L-80 Hyd 513 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 10,221.0 String Max No… 2 3/8 Set Depth … 4,847.6 Tubing Description Tubing – Production Wt (lb/ft) 4.70 Grade L-80 Top Connection EUE-M ID (in) 2.00 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) 21.5 21.5 0.00 Hanger 6.980 2 3/8" Completion Gen 4 Tubing Hanger ( Top Threads 2-3/8" IBT ) FMC Gev 4 1.910 10,104.4 4,790.6 61.54 Mandrel – GAS LIFT 3.750 2 3/8" x 1 KBG GLM, DMY w/ bottom latch SOV Pinned 2000 psi (SN#24269-08) SLB KBG 1.995 10,199.1 4,836.7 60.27 Locator 3.080 Baker locator Baker Locator 1.990 10,199.9 4,837.1 60.26 Seal Assembly 2.670 Baker 40-26 Seal Assembly (Located 2' off NG) Baker 40-26 Seal Assembl y 1.940 Top (ftKB) 10,420.0 Set Depth … 10,461.9 String Max No… 4 Set Depth … 4,973.6 Tubing Description Tubing – Completion Lower Wt (lb/ft) Grade Top Connection 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) 10,437.2 4,960.2 57.33 NIPPLE 4.520 CAMCO 2.75" NIPPLE 2.750 10,444.1 4,963.9 57.27 SEAL ASSY 4.000 BAKER LOCATOR/ 80-40 CASING SEAL ASSEMBLY w/15' EFFECTIVE SEAL STROKE 2.985 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) 23.7 23.7 0.00 EMERGENCY SLIPS C-29 Emergency Slips w/ pack off 5/5/2025 4.500 10,279.6 4,877.2 59.26 **ADD-A- COMP** 2 3/1" x 1" KBG, GLM, DMY w/ bottom latch. SLB KBG 24269 -07 5/5/2025 1.995 10,303.0 4,889.2 58.92 **ADD-A- COMP** 5 1/2" x 3 1/2" Tri Point Hydrotrieve Retrievable Packer Tripoint Hydrotre ve 5/5/2025 2.880 10,355.3 4,916.5 58.15 **ADD-A- COMP** 2 3/8" x 1.875" X Nipple HES X Nipple 44320 44-07 5/5/2025 1.875 10,420.0 4,950.9 57.50 CUT WELLTEC MECHANICAL TUBING CUT. TATTLE-TAIL INDICATED 3.62" OF BLADE EXTENTION 4/15/2025 2.992 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) 10,104.4 4,790.6 61.54 1 GAS LIFT OV BTM 3 3/4 0.0 5/12/2025 slb KBG 0.250 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) 10,201.7 4,837.9 60.24 XO Reducing 4.540 4 1/2" Hyd 513 Box x 3.406 ACME Pin XO 2.770 10,222.3 4,848.2 59.99 XO Enlarging 4.500 3.306 ACME Box x 4 1/2" Hyd 513 Pin, XO 2.770 10,279.6 4,877.2 59.26 Mandrel – GAS LIFT 3.750 2 3/8" x 1 KBG GLM, DMY w/ bottom latch (SN#24269-07) SLB KBG 1.995 10,303.1 4,889.2 58.92 Packer 4.950 5 1/2" x 3 1/2" Tri Piont Retrivable Packer Tri Point Hydratrieve Packer 2.880 10,355.3 4,916.5 58.15 Nipple - X 3.045 2 3/8" x 1.875" X Nipple (SN#4432044-07) HES X-Nipple 1.875 10,417.2 4,949.5 57.53 Overshot 4.500 4 1/2" x 3 1/2" Poor Boy Overshot, (2' From Fully Located) 3.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,774.0 10,794.0 5,151.5 5,162.6 S-7, 2N-315 10/12/1998 4.0 IPERF 2.5" HC/BH, 180 deg ph, 170 deg orient/10 deg CCWF/ high side 10,794.0 10,804.0 5,162.6 5,168.1 S-7, 2N-315 10/11/1998 4.0 IPERF 2.5" HC/BH, 180 deg ph, 170 deg orient/10 deg CCWF/ high side 2N-315, 6/2/2025 10:00:18 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10467'; 26.0-11,178.5 IPERF; 10,794.0-10,804.0 FRAC; 10,774.0 IPERF; 10,774.0-10,794.0 Tie-Back String; 23.8-10,424.0 CUT; 10,420.0 **ADD-A-COMP**; 10,355.3 **ADD-A-COMP**; 10,303.0 **ADD-A-COMP**; 10,279.6 Seal Assembly; 10,199.9 Mandrel – GAS LIFT; 10,104.4 SURFACE; 29.3-3,805.0 CONDUCTOR Insulated; 30.0- 108.0 EMERGENCY SLIPS; 23.7 Hanger; 21.5 KUP PROD KB-Grd (ft) 35.09 RR Date 9/30/1998 Other Elev… 2N-315 ... TD Act Btm (ftKB) 11,197.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032027000 Wellbore Status PROD Max Angle & MD Incl (°) 69.76 MD (ftKB) 5,932.64 WELLNAME WELLBORE2N-315 Annotation Last WO: End DateH2S (ppm) 60 Date 11/23/2015 Comment SSSV: NIPPLE Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 10,774.0 10,804.0 1 FRAC 10/14/1998 0.0 0.00 0.00 2N-315, 6/2/2025 10:00:19 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10467'; 26.0-11,178.5 IPERF; 10,794.0-10,804.0 FRAC; 10,774.0 IPERF; 10,774.0-10,794.0 Tie-Back String; 23.8-10,424.0 CUT; 10,420.0 **ADD-A-COMP**; 10,355.3 **ADD-A-COMP**; 10,303.0 **ADD-A-COMP**; 10,279.6 Seal Assembly; 10,199.9 Mandrel – GAS LIFT; 10,104.4 SURFACE; 29.3-3,805.0 CONDUCTOR Insulated; 30.0- 108.0 EMERGENCY SLIPS; 23.7 Hanger; 21.5 KUP PROD 2N-315 ... WELLNAME WELLBORE2N-315 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:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]KRU 2N-315 PTD 198-190 Date:Friday, April 25, 2025 11:41:06 AM Attachments:image002.png image003.png From: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Sent: Wednesday, April 16, 2025 3:35 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: RE: [EXTERNAL]KRU 2N-315 PTD 198-190 Jack, Yes, let proceed with this new plan. Thanks for working with us. Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, April 16, 2025 1:55 PM To: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Cc: Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: RE: [EXTERNAL]KRU 2N-315 PTD 198-190 Brian – This is a better design. I would change the conditions of approval as follows: Old language: Additional monitoring per the attached single barrier risk assessed mitigations table MITT shall include a plug set below 10,444' to test full single barrier envelop Proposed new language: Additional monitoring per the attached single barrier risk assessed mitigations table MITT shall include a plug set in the 2-3/8” X-nipple below the packer. Note: These conditions of approval may change to be in-line with the outcome of the 3M-19 request for reconsideration and docket OTH-25-016 (Specifically impacts the test frequency in row 2 of the attached CPAI risk mitigations table). Let me know how you wish to proceed. Jack From: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Sent: Wednesday, April 16, 2025 10:06 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: FW: [EXTERNAL]KRU 2N-315 PTD 198-190 Jack, Appreciate the call this morning. Per our conversation this is what I was planning as a contingency and ability to eliminate the every 2 year MIT with a HEX plug below 10,444’MD. High level overview: Pull existing completion OOH. RIH with test packer and set below 10182’ MD and test below against the HEX plug to 2000 psi to prove casing integrity. POOH RIH with new 4.5’’ liner and packer completion and set packer below 10,182 MD. Drop ball and rod and set packer. RU SL pull ball and rod and test packer from below against the HEX plug to 2000 psi to verify packer integrity. ( Could elect to do this POST RIG and a back up option if packer does not test we would cement through the GLM to achieve passing MIT and possibly cement to surface at that time. ) Run new 2-3/8’’ tubing and sting in to seals as planned. Please let me know your thoughts and if you need me to clarify anything. Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Thursday, April 10, 2025 10:44 AM To: Manning, Leslie <Leslie.Manning@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com> Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: FW: [EXTERNAL]KRU 2N-315 From: Gluyas, Gavin R (OGC) <gavin.gluyas@alaska.gov> Sent: Thursday, April 10, 2025 10:43 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: [EXTERNAL]KRU 2N-315 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. ORIGINATED TRANSMITTAL DATE: 4/21/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5400 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5400 2N-315 50103202700000 Tubing Cut Record 15-Apr-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 198-190 T40327 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:25:27 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Tarn Oil Pool Tarn Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11197' 5373' 10781' 5155' 2458 10437' None Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: (907) 263-3731 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field Leslie Manning leslie.manning@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380054 198-190 P.O. Box 100360, Anchorage, AK 99510 50-103-20270-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 10462' MD 108' 2317' 108' 3805' 5363'5-1/2" 16" 7-5/8" 78' Packer: None SSSV: None 3776' 11179' Perforation Depth MD (ft): KRU 2N-315 10774-10804' 11153' 5152-5168' 4/23/2025 3-1/2" m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:16 am, Apr 01, 2025 325-184 DSR=4/2/25 2554 psi X *AOGCC Witnessed BOP test to 3000 psi and annular test to minimum of 2500 psi. *Additional monitoring per the attached single barrier risk assessed mitigations table. *MITT shall include a plug set below 10,444' to test full single barrier envelop SFD 4/10/2025JJL 4/7/25 10-404 *&: 4/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.10 10:30:58 -08'00' RBDMS JSB 041025 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 28, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Leslie Manning Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2N-315 (PTD# 198-190). Well 2N-315 is a producer drilled in 1998 and completed with 3.5" tubing/gas lift completion. Tubing leaks have been identified between 4648' - 4670' RKB, between 4869' - 4900' RKB and at 6610' RKB, and 6802' RKB. Production casing leaks have been identified at 6610' RKB and 6830' RKB. Therefore, a RWO is needed to restor the well to production. The RWO plan is to pull the tubing, isolate the 5.5" casing with a 4.5" tieback liner, then run 2.375" tubing/gas lift completion. If you have any questions or require any further information, please contact me at +1-512-755-6782. 2N-315 RWO Procedure Tarn Gas Lifted Producer PTD #198-190 Page 1 of 2 Remaining Pre-Rig Work 1. Pull plug from nipple at 10,437’ MD 2. Obtain updated SBHP 3. Pull OV from Station #2 @ 10,383’ MD; leave open pocket for deep circ point 4. Re-secure with expandable plug @ ~10,500’ RKB 5. Cut tubing @ ~10,420’ RKB 6. Prep well for rig ~48 to 96 hours before rig arrival; confirm no gas in OA, IA, or Tubing Rig Work MIRU 1. MIRU Nordic 3 on 1R-35 2. Circulate 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 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing Section 5. Pull BPV, MU landing joint and BOLDS 6. Pull 3-1/2” tubing down to pre-rig cut (~10,420’ RKB) 7. PU drillpipe and fish seal assembly from 10,444’ RKB Run new 4-1/2” Tie-back 8. PU and RIH w/ 4-1/2” x 2-3/8” tie-back liner and seal assembly 9. Once on depth, stab into seals, space out as needed 10. Pick up and circulate in corrosion inhibited fluid and freeze protect the new OA (4-1/2” x 5-1/2” annulus 11. Stab back into seals 12. Set plug as needed for barrier 13. ND BOP, Land 4-1/2” tie-back, NU tubing head for 2-3/8” tubing, NU BOPs, Test flange breaks 14. Pressure test 4-1/2” casing to 2500 psi for 30 minutes and chart Install new 2-3/8” Tubing 15. MU and RIH w/ 2-3/8” completion with seal assembly and GLM 16. Once on depth, stab into seals and space out as needed 17. Pick up and circulate in corrosion inhibited fluid and freeze protect the new IA (2-3/8” x 4-1/2” annulus) 18. Stab back into seals, Land hanger, RILDS 19. Pressure test tubing to 3000 psi for 30 minutes on chart, PT packoffs 20. Pressure test inner annulus to 2500 psi for 30 minutes on chart ND BOP, NU Tree 21. Install BPV 22. ND BOPE, NU tree, PT tree 23. Pull BPV, freeze protect well if needed, and set BPV if necessary 24. RDMO Post-Rig Work 25. Install GLD 26. Pull Expandable Plug 27. Handover to Operations 2N-315 RWO Procedure Tarn Gas Lifted Producer PTD #198-190 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen 5 5k Production Engineer: Mandy Pogany Estimated Start Date: 4/23/2025 Workover Engineer: Leslie Manning (907.263.3731 / leslie.manning@conocophillips.com) Current Operations: This well is currently shut in Well Type: Producer Scope of Work: Pull existing 3-1/2” completion, install new 4-1/2” tie-back liner, and new 2-3/8” tubing/gas lift completion BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram MIT results: Tbg: Known TxIA Leak IA: Known Production Casing Leak OA: Open Shoe IC POT & PPPOT: passed 3/9/25 TBG POT & PPPOT: passed 3/9/25 MPSP: 2458 psi using 0.1 psi/ft gradient Static BHP: 2978 psi / 5200’ TVD measured on 7/4/20 SBHPS was obtained on 4/7/2025 for 2N-315; SBHP = 3074 psi @ 5200’ TVD; MPSP = 2554 psi. As a result, we plan to BOP Test to 250/3000 psi. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 23' of Fill) 10,781.0 2N-315 7/4/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Eline Caliper & LDL 2N-315 5/5/2022 claytg 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 Insulated 16 15.06 30.0 108.0 108.0 62.58 H-40 WELDED SURFACE 7 5/8 6.87 29.3 3,805.0 2,316.6 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 10467' 5 1/2 4.95 26.0 11,178.5 5,363.4 15.50 L-80 LTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 24.8 Set Depth … 10,461.9 String Max No… 3 1/2 Set Depth … 4,973.6 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rd 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) 24.8 24.8 0.00 HANGER 8.100 FMC GEN V TUBING HANGER 3.500 479.1 478.6 7.64 NIPPLE 4.520 CAMCO DS NIPPLE 2.875 6,874.9 3,494.3 66.84 GAS LIFT 4.725 MANDREL CAMCO KBG-2-9 2.920 10,331.6 4,904.0 58.50 SLEEVE 4.000 BAKER CMU SLIDING SLEEVE w/CAMCO 2.813" PROFILE 2.813 10,383.4 4,931.4 57.86 GAS LIFT 4.725 MANDREL CAMCO KBG-2-9 2.900 10,437.2 4,960.2 57.33 NIPPLE 4.520 CAMCO 2.75" NIPPLE 2.750 10,444.1 4,963.9 57.27 SEAL ASSY 4.000 BAKER LOCATOR/ 80-40 CASING SEAL ASSEMBLY w/15' EFFECTIVE SEAL STROKE 2.985 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,648.0 2,659.7 65.80 LEAK - TUBING MULTIPLE TUBING LEAKS OBSERVED BETWEEN 4648' - 4670' RKB 5/5/2022 2.992 4,869.0 2,745.6 68.11 LEAK - TUBING MULTIPLE TUBING LEAKS OBSERVED BETWEEN 4869' - 4900' RKB 5/5/2022 2.992 6,610.0 3,389.0 67.77 CASING LEAK CASING LEAK NEAR 6610' IDENTIFIED WITH WATERFLOW 10/4/2020 5.000 6,610.0 3,389.0 67.77 LEAK - TUBING TUBING LEAK IDENTIFIED @ 6610' RKB 5/5/2022 2.992 6,802.0 3,465.2 66.10 LEAK - TUBING TUBING LEAK IDENTIFIED @ 6802' RKB 5/5/2022 2.992 6,830.0 3,476.5 66.38 CASING LEAK CASING LEAK NEAR 6830' IDENTIFIED WITH WATERFLOW 10/4/2020 5.000 10,437.0 4,960.1 57.33 2.75" CA-2 Plug 2.75" CA-2 Plug (33" OAL) 7/7/2020 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) 6,874.9 3,494.3 66.84 1 Gas Lift DMY INT 1 0.0 10/23/1998 0.000 10,383.4 4,931.4 57.86 2 Gas Lift OV BTM 1 0.0 7/6/2020 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,774.0 10,794.0 5,151.5 5,162.6 S-7, 2N-315 10/12/1998 4.0 IPERF 2.5" HC/BH, 180 deg ph, 170 deg orient/10 deg CCWF/ high side 10,794.0 10,804.0 5,162.6 5,168.1 S-7, 2N-315 10/11/1998 4.0 IPERF 2.5" HC/BH, 180 deg ph, 170 deg orient/10 deg CCWF/ high side Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 10,774.0 10,804.0 1 FRAC 10/14/1998 0.0 0.00 0.00 2N-315, 3/28/2025 1:46:16 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10467'; 26.0-11,178.5 IPERF; 10,794.0-10,804.0 FRAC; 10,774.0 IPERF; 10,774.0-10,794.0 2.75" CA-2 Plug; 10,437.0 GAS LIFT; 10,383.4 GAS LIFT; 6,874.9 CASING LEAK; 6,830.0 LEAK - TUBING; 6,802.0 CASING LEAK; 6,610.0 LEAK - TUBING; 6,610.0 LEAK - TUBING; 4,869.0 LEAK - TUBING; 4,648.0 SURFACE; 29.3-3,805.0 NIPPLE; 479.1 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 35.09 RR Date 9/30/1998 Other Elev… 2N-315 ... TD Act Btm (ftKB) 11,197.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032027000 Wellbore Status PROD Max Angle & MD Incl (°) 69.76 MD (ftKB) 5,932.64 WELLNAME WELLBORE2N-315 Annotation Last WO: End DateH2S (ppm) 60 Date 11/23/2015 Comment SSSV: NIPPLE COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 108 108 16 15.062 62.58 H-40 WELDED Surface 3805 2316.6 7.625 6.875 29.7 L-80 BTCM Production 11178.5 5363.4 5.5 4.95 15.5 L-80 LTCM New Liner 10444 4964 4.5 4 11.6 L-80 HYD513 New Tubing ~10219 4847 2.375 1.995 4.7 L-80 EUE 2N-315 Proposed RWO Completion PROPOSED COMPLETION Liner Set on Slips; FMC 4-1/2" 11.6# L-80 HYD513 XO to 2-3/8" Seal Bore 2-3/8" Seal Bore XO to 3-1/2" 9.3# L-80 EUE 3-1/2" 9.3# L-80 EUE XO to 2-3/8" VAM ST-L 2-3/8" x 1" KBG GLM 2-3/8" 4.7# L-80 EUE 2-3/8" x 1.875" X Nipple 2-3/8" 4.7# L-80 EUE XO to 3-1/2" 9.3# L-80 EUE 4" OD Baker 80-40 Seal Assembly Tubing (Gas Lift Completion) FMC Hanger 2-3/8" 4.7# L-80 EUE-8RD 2-3/8"x 1" KBG GLM Baker GBH22 40-26 Seal Assembly w/ locator 7-5/8" Surface Casing 16" Conductor TARN perfs 10774'-10804' RKB Casing Leaks 6610' & 6,830' RKB (non located casing leak suspected above this) PC Calc TOC 10,182' MD 4-1/2" 11.6# L-80 HYD513 Production Liner 2-3/8" 4.7# L-80 EUE-Mod Tubing 5-1/2" x 3-1/2" Production Casing 10,781' RKB Fill (Last tag 7/4/2020) CSR 10,444' RKB SC cement surface to 3,850' From:Manning, Leslie To:Lau, Jack J (OGC); Loepp, Victoria T (OGC) Cc:Taylor, Jenna; Glasheen, Brian; Hobbs, Greg S; Livingston, Erica J; Coberly, Jonathan Subject:RE: [EXTERNAL]RE: KRU 2N-315 10-403 (198-190) Date:Thursday, April 3, 2025 9:07:22 AM Attachments:image001.png Jack – Thank you for your prompt review of this request! A risk assessment was performed and 2N-315 will require an internal waiver to operate as a gas lifted producer. Below is a table noting the additional monitoring required under the internal waiver. Please reach out with any additional questions. Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, April 2, 2025 11:42 AM To: Manning, Leslie <Leslie.Manning@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2N-315 10-403 (198-190) Hi Leslie, This well appears very similar to the 1R-35 single barrier repair (uncemented tie-back with PC leaks and open shoe), for which CPAI performed a risk assessment and submitted the attached monitoring plan (single barrier mitigations table). Was a similar risk assessment performed? If so, what are the mitigations? Jack From: Manning, Leslie <Leslie.Manning@conocophillips.com> Sent: Tuesday, April 1, 2025 10:26 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2N-315 10-403 Jack / Victoria – I will be OOO 4/10 -4/22; the 2N-315 RWO is scheduled to start ~4/23. If you complete your review of this Sundry request later than 4/9, please cc Brian Glasheen so that he can answer any questions you may have. Thank you! Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Tuesday, April 1, 2025 10:23 AM Condition of Approval requires adherence to the table below. MITT requires plug set below 10,444' to test full single barrier envelop. - JJL 4/7/25 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. To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2N-315 10-403 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, This application has been received for processing. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Friday, March 28, 2025 3:19 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: KRU 2N-315 10-403 Hello – See attached 10-403 or KRU 2N-315. Please let me know if you need additional information. Thank you Jenna C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-05_21069_KRU_2N-315_LeakDetectionSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21069 KRU 2N-315 50-103-20270-00 Leak Detection Survey 05-May-22 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 FTP ______________________________ ______________________________________ 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:198-190 T36555 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.06 15:56:22 -08'00' Originated:Delivered to:15-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 26-Oct-20 0 1 2 1B-102 50-029-23167-00 906749775 Kuparuk River Multi Finger Caliper Field & Processed 7-Oct-20 0 1 3 1D-05 50-029-20417-00 906744243 Kuparuk River Packer Setting Record Field- Final 1-Oct-20 0 1 4 1R-17 50-029-22212-00 906744935 Kuparuk River Packer Setting Record Field- Final 5-Oct-20 0 1 5 2B-07 50-029-21080-00 906716400 Kuparuk River Multi Finger Caliper Field & Processed 2-Oct-20 0 1 6 2B-07 50-029-21080-00 906716400 Kuparuk River Leak Detect Log with ACX Processed 1-Oct-20 0 1 7 2H-11 50-029-20052-00 906792896 Kuparuk River Plug Setting Record Field- Final 31-Oct-20 0 1 8 2N-315 50-103-20270-00 906731635 Tarn Participating Area Leak Detect Log with TMD3D Field & Processed 28-Sep-20 0 1 9 2P-451 50-103-20402-00 906771682 Meltwater Perforation Record Field- Final 19-Oct-20 0 1 10 2T-38A 50-103-20229-01 906748612 Kuparuk River Plug Setting Record Field- Final 17-Oct-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/16/2020 12/16/2020 Abby Bell PTD: 1981900 E-Set: 34414 . i ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 SCANNED MAR 3 1 2015 March 25, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission I (�, I g 333 West 7th Avenue, Suite 100 4 r V s Anchorage, AK 99501 �N Commissioner Cathy Foerster: 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 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 attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, 'y .771,� MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 3-22-2015 2N&2T PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-315 50103202700000 1981900 6" N/A 13" N/A 4 3/22/2015 2N-339 50103202610000 1981000 8" N/A 25" N/A 8.5 3/22/2015 2T-06 50103200680000 1861070 3' 0.30 25" 8/13/2014 8.5 3/22/2015 From: NSK Problem Well Supv [n1617@conocophiliips.com] Sent: Monday, May 11, 2009 11:06 AM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: NSK Problem Well Supv Subject: 2N-315 (PTD 198-190) Report of failed TIFL Attachments: 2N-315 schematic.pdf; 2N-315 90 day TIO plot.jpg Tom, ~ Kuparuk gas lifted producer 2N-315 (PTD 198-190) failed a diagnostic TIFL on 05/10/09. The TIO prior to the test was 250/700/300. A leaking GLV is suspected. Slickline wili troubleshoot the GLV's and repair if possible. Attached is a schematic and a 90 day TIO plot. ,i Please let me know if you have any questions. w ~~ r, Brent Rogers/Martin Walters Problem Wells Supenrisor ~~~~~~~~°` ~~t'~' ~~~~ ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 «2N-315 schematic.pdf» «2N-315 90 day TIO plot.jpg» 8/7/2009 KRU 2N-315 PTD 198-190 5/ 11 /2009 TIO Pressures T/I/O Plot - 2N-315 ............................ , , 900 .................................. ........................................ ................. 800 ........................................................................................... 700 ....................................................................................... 600 ............ ......... ....... ................ . ................. a 500 ............... .. . ................... ................ 400 --_ ..__. .. .. .... .. .. . ........ .... 300 .................................................................................... ............. 200 ................................................................................................. 100 ................................................................................................. 0 11-Feb-09 24-Feb-09 09-Mar-09 22-Mar-09 04-Apr-09 Date 17-Apr-09 30-Apr-09 200 ~ 150 a E a~ 10~ ~ Y O s t~ 50 0 ~ ~~~~ ~ ~ KUP 2N 315 ' r e ~~ M - T [y /yp~y`~~/~ ,. 1!1~f{lV~w{~ ~~~~ii ` _ r= 4 i' ~ i~ ~~ ~~ :- i~Pd c ~, li ~3 ,~~r ` 4, Y p ~.y .n~ l~_4lYJ ..~~-. ~ ' Y .; ~~ p~ Wellbore API/UWI Fleld Name Well Status Pfodllnj Type Ind (°) MD (ttKB) ACt BtT (ttKB) ~~~. 501032027000 TARN PARTICIPATING AREA PROD 69.76 5,932.64 11 197.0 ~-~- ~~ -- ---- ~ CommeM HYS (ppm) Date Annotatlon End Date KB~rd (R) Rig Release ~ate . ~" SSSV: NIPPLE 30 7/1/2008 Last W0: 35.09 9/30I1998 s;. _ _ , - z~ AnnMatlon Depth (ttKB) Entl Date M nMffilon End Date Last Tag: SLM 10,802.0 1 2/28/2008 Rev Reason: TAG 12/292008 ~.- ~ *.si q N~ ~ ~ ~~r~~ i 7„~, .° ~!u t C i ~ ;,~ I - A 9 ~ ' a~i -,r. , - u fl ;.~4~iia ~;;i.- ~a - ~ .. . . . . . . . . . . . . ... ... . _ Casinp Deaaiption String 0... t Stdng ID ... _ Top (RKB) _ ... , _ Set Depth (f... Set Depth (ND) ... . Strinp Wt... Stdng ... ~. _; m„ Stdng 7op Thrd CONDUCTOR 16 15.062 0.0 108.0 108.0 62.58 H-40 WELDED Insulated Casinp Deacription String 0... String ID ... 7op (ttKB) Set Depth ~f... Sat Depth ('fVD) ... String Wt... String ... String Top 7hrtl SURFACE 7 5/8 6.750 0.0 3,805.0 2,316.3 40.00 L-80 BTC Casing Deacription String 0... String ID ... 7op (tdCB~ Set Depth (f... Sat Dapth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 5.000 0.0 10,467.3 4,976.3 15.50 L-80 LTCM ~~ ,~,,....o Casing Deacription Stdng 0... Stdng ID ... Top (ttKB) Set Depth (f... Sat Dapth (ND) ... String W4.. String ... String Top Thrd PRODUCTION 3 1/2 2 992 10 467 3 11 178 5 5 363 4 9 30 L 80 EUE 8RD ~`~~ ~ ~ 'Fa __ ,~ .°~ , k z:.o, ~1~t1~~~ - i;~~~'~~^~_~ ~~~~ ~~E'~~ ~~+,~' ~,r, ~ ~ -- _ _ ~~ _ n 7ubing Dascripdon String 0... String ID ... Top (ffKB) Sat Depth (L.. Set Depth (TVD) ... Shtng Wt... Strinp ... Stdng Top Thrd HANGER,25 m TUBING 31/2 2.992 1.0 10,467.9 4,973.3 9.30 L-80 EUEBrd s..., ~ ~~ ~;~ ~3~i I~#f~ ' ~ ~ i(~ 1~ .~ ~ i ~' `~i~ r r ~r , ~~ ~ ,~ ~ „~ _ ~~ ' ~ ~ a ~~ ~_ ~ ii -,~ .. ~ °" 'i .r..~m-~~~ ,5~r ~ -~ Top Depth (ND) Top Ind ~:+ ~~. ~, - iop (ttHB) (RKB) ~°) Item Dascriptlon ~ CommeM ID (in) _ ~ 24.8 24.8 -0.23 HANGER FMC GEN V TUBING HANGER 3.500 i: 479.1 478.5 7.64 NIPPLE CAMCO DS NIPP~E 2.813 coNOUCioa 10,331.6 4,904.1 58.36 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO 2.813" PROFILE 2.813 i"°°i't`b,aioe ~ ~ 10,4372 4,9602 57.33 NIPPLE CAMC02.75"NIPPLE 2J50 .'. i~ 10,444.1 4,963.9 57.27 SEAL ASSY BAKER 80-0.0 CASING SEAL ASSEMBLY 2.985 ~ i I~' ~ ii'N i m 6$ 6 ,~. ~ 'S,,r ., u ~ '= ~°~ ~ t ` ~ = ' ` '~' ~ ~ ~~i a r t ~,r,~ ~~:. , , ~ = P.1=r~~ r` ~ 1 er;s. '~'w . ,< . . ~_ ' ~ , . - A~~,~s~ . ~' 1 NIPPlE,479 Shot Top (ND) etm (ND~ Dena - Top (RKB) Btm (ftKB~ (RKB) ~RHB) Zone Date (sh••• 7ype CommeM ~~~~.f6s 70,774.0 10,794.0 5,151.4 5,162.6 10/1Z7998 4.0 IPERF 2.5" HCBH, 180 deg ph, 170 deg suaFnce, orienVlO tleg CCWF/ high side °a•e°5 10,794.0 10,804.0 5,162.6 5,168.1 10/11/1998 4.0 IPERF 2.5" HCBH, 180 deg ph, 170 deg ~., orienUlO deg CCWF/ high side Min Top Maz Btm Top Depth Depth Dapth Depth (ND) (ND) (ftK8) (ftKB~ (ftKB) (ftKB~ SLEEVE, 10,332 GAS LIFf, 10,383 NIPPLE, 10,437 SEALASSV. 10.449 PRODUCTION, 0.10,467 IPERF, 10,77410,794 FRAC. 70.774 IPERF, 10.794-10.804 w/Alaska Make I Motlel I I~/ I Sarv I TYPe I TYPe I(~^) PRODUCTION, 10.467-11.178 TD. 11.791 s ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~~~C~ N4`~ ~ ~ 20D? a '~~- Iq Enclosed please find a (revised 10/3/07)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 a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, .~1 ~~~ on Arend ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/28/2007 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 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16!2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16!2007 2N-313 198-091 5' 0.75 18" 9/9!2007 2N-335 198-204 20" na 20" na 13 9116/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16!2007 2N-303 200-169 5" n!a 5" n/a 1 9/27/2007 2N-304 201-130 10" n!a 10" n/a 4.5 9!27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n!a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9!27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" nla 5" n/a 1 9/27/2007 2N-318 200-100 10" nla 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 • `~~'~ Dear Mr. Maunder: 'REC~c ocr ~VFC) A/$~k~ Di~~ ~~ ~ 2 ?D07 Anehn age C~mfssi Op ~$J\~~ 1 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRtl). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ~~ M.T. vel d ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Tap-off Report of Sundry Operations (10-404) Date Kuparuk Field 8/28/2007 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 2L-1103 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9!2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21 ` 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n!a 1 9/27/2007 2N-304 201-130 10" n!a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n!a 12" n!a 7.5 9!27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" nla 1 9/27/2007 2N-309 199-021 9" n!a 9" n/a 2 9/27/2007 2N-311 208-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 5" n/a 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9!27/2007 2N-317 19&143 5" nIa 5" n/a 1 9!27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27!2007 2N-319 198-197 5" n/a 5" n!a 9.5 9/27/2007 Well COmpliance Report File on Left side of folder 198-190-0 KUPARUK RIV U TARN Roll #1: Start: Stop Roll #2: MD 11197 TVD 05373 Completion Date: 2N-315 50- 103-20270-00 PHILLIPS ALASKA[NC Start Stop 9/30/98 Completed Status: 1-OIL Current: Name D 8805 L DGR/CNP/SLD-MD L DGR/CNP/SLD-TVD L DGR/EWR4-MD L DGR/EWR4-TVD R SRVY CALC. Daily Well Ops __ --- ___ Was the well cored? yes no Comments: 2 FINAL FINAL FINAL FINAL Interval Sent Received T/C/D · . SPERRY MPT/GR/EWR4/CNP/SLD OH 12/23/98 12/23/98 3815-11197 OH 12/30/98 12/30/98 2331-5373 OH 12/30/98 12/30/98 3815-11197 OH 12/30/98 12/30/98 2331-5373 OH 12/30/98 12/30/98 BHI 9227.22-2190.71 OH 10/30/98 11/2/98 Are Dry Ditch Samples Required? yes n~ And Received? yes no Analysis Description Received? yes no Sample Set # Wednesday, November 08, 2000 Page 1 of 1 ARCO Alaska, Inc. - ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999 Dear Ms. Mahan: · ;'~'~ 2 8 2000 Anchorage Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 1999, as well as total volumes injected into annuli for ~vhich injection' authorization expired during the fourth quarter of 1999. Annular Injection during the fourth quarter of 1999: h(1) h(2) I h(3) Total for [ Previous I New Well Name Volume Volume Volume Quarter [ Total [ Total CD1-37 15214 100 0 15314 I 17273 32587 CD1-39 27391 . 100 0 27491 i 4017 31508 1D-12 27089 100 0 27189 ] 5702 32891 CDI-16 28925 [ 100 0 29025 [ 0 i 29025 l CDl132 7449 ' 100 0 7549,0[7549 CD1-03 285 i 100 0 385i 0 385 CD 1-42 287 100 0 387 [ CDI-40 20 [ 0 0 20 I 32649 ] 387 32669 CD1-45 274 100 0 374 i 0 i 374 CD1-36 293 100 0 393 [ 0 393 CD1-35 217 100 0 317 I 0 317 CD1-23 20 0 0 20 ~ 17085 ] 17105 CDi-13 89 100 0 189 0 ! 189 CD1-01 20 0 0 20 5201 [ 5221 Total Volumes into Annuli for which bzjection Authorization Expired during the fourth quarter Total Well Name Total h(1) Volume Total h(2) Volume Total h(3) Volume Volume Injected 25426 Status of Annulus 2N-315 25326 100 0 I Open, Freeze Protected 2L-329A 33971 100 0 34071 Open. Freeze Protected 2L-325 20280 100 0 20380 Open, Freeze Protected ' 2L-313 12433 100 ! 0 12533 i Open, Freeze Protected Ms. Wendy Mahan AOGCC Fourth Quarter 1999 Annular Injection Report Page Two Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snod~ass Morrison and Winfree Sharon Allsup-Drake Well Files 0 F! I I--I--I I~ G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and CJas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-315, December 30, 1998 AK-MM-803 84 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-315: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20270-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20270-00 2" x 5" MD Neutron & Density Logs: 50-103-20270-00 2" x 5" TVD Neutron & Density Logs: 50-103-20270-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELl, LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-315, December 23, 1998 AK-MM-80384 1 LDWG formatted Disc with verification listing. API#: 50-103-20270-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPY OF THE TRANSMH'rAL LETTER TO THE ATYE~ON OF: Sperry-SM Ddlling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alas.ka~,grg~. 18 . . Si STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Alter casing __ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate _ Pull tubing__ Variance_ Perforate_ Other X Annular Iniection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X_ Exploratory __ Stratigraphic __ Service 41' FNL, 675' FEL, Sec. 3, T9N, R7E, UM At top of productive interval At effective depth At total depth 2263' FSL, 97' FWL, Sec. 27, T10N, R7E, UM 2619' FNL, 100' FEL, Sec.28, T10N, R7E, UM 6. Datum elevation (DF or KB) 28' RKB 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 2N-315 9. Permit number 98-190 10. APl number 50-103-20270 - 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 11197' feet (approx) true vertical 5373' feet Effective depth: measured 11081' (approx) true vertical 5315' Casing Length Size Structural Conductor 80' 16" Surface 3777' 7.625" Intermediate Production 10418' 5.5" x Liner 732' 3.5" Plugs (measured) feet Junk (measured) feet None Cemented Measured depth True vertical depth 9 Cu Yds High Early 108' 108' 296 sx ASlll LW & 3805' 2316' 247 sx Class G & 60 sx ASI 220 sx Class G 10446' 4965' 11178' 5363' Perforation depth: measured 10774'- 10804' true vertical 5151'-5168' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 10462' Packers and SSSV (type and measured depth) Baker CSR @ 10446', No SSSV RECEIVED Alaska Oil & 8as Cons. Commissio~ Anchorage 13. Attachments Description summary of proposal __ Detailed operation program __ BOP sketch Contact Paul Mazzolini at 265-4603 with any questions. LOT test, surface cement details and casing detail sheets X 14. Estimated date for commencing operation November 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved , Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY 15. Status of well classification as: Gas __ Suspended__ Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance Mechanical Integrity Test _ Subsequent'form require 10- /~l~¢.~-~42~ Approved by the order of the Commission IApproval Commissioner Date //~~~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Cementing Details Well Name: 2N-315 Report Date: 09/23198 Report Number: 5 Riq Name: DOYON 141 AFC No.: AK9517 Field: TARN I i Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: LC Depth: I % washout: 7-5/8" 9-7/8" n/aI 3805' 3674 Centralizers State type used, intervals covered and spacing Comments: 38 Gemeco bow spring, placement on casing detail. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.2 24 23 20 19 Gels before: Gels after:. Total Volume Circulated: 5/13 5/12 1200 bbls Wash 0 Type: Volume: Weight: Comments: Spacer 0 Type: Volume: Weight: Comments: ARCO 30/30 10.5 / 10.5 1st stage/2nd stage Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: AS III LW 70 99 / 197I 10.5 4.42 1st stage~2nd stage Additives: Comments: G 70I I 1247 / 60 15.8 / 15.7 1.15 / 0.93 1st stage G/2nd stage AS1 Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 7.5 ! 8.5 7,5 / 7 90 I st stage/2nd stage Reciprocation length: Reciprocation speed: Sir. Wt. Down: 20 10 fpm 60 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 168.6 / 73.7 169 ! 73.3 Calculated top of cement: CP: Bumped plug: Floats held: Surface thru stage collar @ 1606'. Date:9-23-98 yes yes Time:0003 hrs. Remarks:lst stage: pumped 5 bbls of fresh water, 30 bbls of 10.5 ppg Arco spacer, 78 bbls of lead and 50 bbls of tail cement. Displaced with 30 bbls of fresh water, 52 bbls of mud, 30 bbls of 10.5 ppg Dowell spacer and 57 bbl$ of mud. Bumped plug, floats held, ClP @ 1913 hrs. Opened stage collar with 2600 psi, circulated out 10 bbls of cement above stage collar, full returns throughout. 2nd stage: Pumped 5 bbls of fresh water, 30 bbls of 10.5 ppg Arco spacer, 155 bbls of lead and 10 bbls of tail cement. Displaced with 30 bbls of fresh water and 43.3 bbls of mud. Closed stage collar with 800 psi, increased pressure to 2000 psi for 5 min. Bled off casing, no flowback. Had 85 bbls of 10.5 ppg cement returns to surface, ClP @ 0003hrs. Cement Company: Rig Contractor: I Approved By: DS DOYON I D.BURLEY ARCO Alaska, Inc. Casing Detail 7-$/8" Surface Casing WELL: TARN 2N-315 DATE: 9122198 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RT to LR = 29.00 7 5/8" Landing Joint 34' OA. 29..00- . .. FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.15 29.00 52-87 7 5/8", 29.7#, L-80 BTC-MOD 1532.44 31.15- Jt #101 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 42.10 1563.~59 Gemeco 7 5/8" Stage Collar (BAKERLOK) 2.77 1605.69 ,..Jt. #100 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 41.92 1608.46 its. 3-51 7 5/8",29.7#, L-80' E~tFC-MOD (~shutoff baffle on top of jt #3, BAKERLO 2066.05 1650.38 Gemeco Float Collar 1.32 ' 3716.43 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 85.42 3717.75 Gemeco Float Shoe 1.50 3803.17 3804:67 Insert baffle (~ 3674'. 38 Gemeco Bow Spring CENTRALIZERS Run centralizers over stop collars on Jts. 1, 2, 100, & 101. Run centralizers over collars on Jts 3-13, 16, 19, 22, 25, 28, 31, 34, 37, 40, 43, 46, 49, 55, 58, 61, 64, 67, 70, 73, 76, 79, 82, 85. . . , . Remarks: String Weights with Blocks: 90K# Up,60K~ Dn,12k# Blocks. Ran 89 joints of casing. Drifted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: D.P. BURLEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 2N-315 D.P. BURLEY 7 518", 29.7 ppf, L-80, BTC Date: 9/24/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 3,091' TVD 830 psi LOT = (0.052 x 3,091') Fluid Pumped = 3,805' TMD EMW = 2,316' TVD Leak-off Press. + MW 0.052 x TVD + 9.1 ppg EMW = 14.3 ppg Pump output = 0.1000 bps UJ TIME LINE 2,300 psi ~. .] ..... 1~i ...... 1./, .4 ...'.' 2,000 psi r ~, w.~.~ ~...~ ~,..fl, ~ ~ .......... , ......... , ............ I .............................. l,g00 psi : .......... 1,800 psi .......J 1,7oo ,,, ............ ;' 1,500 psi 1,400 psi ~ .................................................................... 1,300 psi ......... 1,100 psi i [ 1,0o0ps~ ~ ....... e LEAK-OFF TEST ............... ......... t ................ [7' ~ CASING TEST .......... ~-' ooo p.I - .... -~ ..... ................. LOT SHUT IN TIME ............... 0oo p~ ........... r .... ~- ............. --~-- CASING TEST SHUT IN TIME .............. 7oo psi ...... ].. ......... if [ ....................... ~ .. TIME LINE 400 psi .... ~ ..... ~1~ ' ............... ......... ~"-~'".::' "; ............ 300 psi ......... - ........................................ -, ~'/ ,= ....................................................................... I'"]"1'T1 ....... _ ........................... 2~ 7 ";~ ..................... ~li~i ....... ~oo.,, ~r ............................................... r'-l'-l'T'l ....... i .............. 0 p~l ;o 2 4 $ $ 10 12 14 15 18 20 ;22 24 2B 28 30 32 M 38 38 40 4:2 44 48 48 50 52 ~4 5~ $8 80 82 84 86 88 70 72 74 78 78 80 82 84 88 80 90 STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ~. .i . 0 stks 0 psi ........................ -~-~i~- ........ -t-~--~i .... '- .................. ; .... -as;ii~- ........ i-)-6-i;;i---i . 6 stks 190 pst ........................ -~-~i~- ......... ~-6--~i---i ........................ ¥6-;i~-~- ........ ~'6'~;r-'i ~ ....................... ¥ff;;i~-~- ........ ~¥6--~;i---i ................... I' .................. ~ .............. ~---'{ . : 14stks : 640ps~ ........................ f~-;i~'~' ........ ~-6'~;;i'"i r .................. r .... fa-;ii~-~'---~ .... i~-6"r;;r"',, I- .................. I- .................. ~ .................. , : 19stks : 600 psi ; ...... ~ 20stks I 490psi ~ [ ....................... ~'~';ik'~' ....... i .................. i'"'~-6';;i~'~' ......... ~'6'~;r"i .................. ~ .................. 1 .................. , , 35stks : 450 psi .' .................. : j j 40stks j 450 psi r ...................... 'a-~'~tk'~' .... '"'z~-6"~r"i ................... ~ .................. 4 .......... ~ ....... ~ ..................................... ~ .................. , CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ! j ................... i ..... .... ..... ..... r ........................ .... .... ..... r ........................ .... ..... : 3 stks : 330 psi r ........................ z-~'t'~; .... T--"az~-'~-~i ..... j ........................ i--~-t-~;; .... T-'"~"~';i .... [ ........................ i--~'t'~i; .... T-'-'t~i-'~-~i .... t .................................... -I- ............. ; .... : 7 stks : 880 psi ,. .................. d .................. ..~ .................. : 8 stks ; 1,030 psi [ .................. i ..... §"-~-t'~ .... ~ .................. ~ .................. ~- .................. [ .................. .,' .... !.o.~.~ ?_...i_!,..~.°_.°_._p.?L_i ; 11stks j 1,450psi [ ....................... ¥~"~t'~;'"T"¥;~'~'~;¥'" ~ .................. ~ .................. -I- .................. [ ........ : ......... : .... ! .4_ ~.t.k_ .~.. .. .,' ..!:9.o_.o_ R .~L..; i 15stks ! 2,030Esi } ..................................... ,-~ IS.UT IN TIME' S.UT IN ..ESSUi~E [ 0.0 rain : 2~030 Esi --q'-~---------' ...... ~========'"~- ' ' ' [ 1 0 min : -"J,§~ ps[ ,--~ ,.~ ................................... SHUT IN TIME SHUT IN PRESSURE [.....3...C)....m.i~ ..... "~'.[~'~ .... I 440 ~si I I 4 0 rain .... ~; ............ -.~.~--~---4 - -~r =.-=--~-- -r ---~ ~ .... ;'; ........... 4' 1.0 minj 4uu ps[ 4 : 5.0 min : ':~;~"~T~ ....... ; .... ~i~-o--~i"-: i .... ~':6'~'i'ri"-'t ,--,,,,,,-'","--'", .... ~..,.~..........~... - i. - - -~..~,~,,~..~ - -- .t .................. ..I 40min : : 370 psi : 5.0 min [ ,,. 370 psi .,' ['~:~'~i~"'"i ...... [ .... ~'~'i;~i'"; '-y76'~i;',[ ...... i .... ~-~'~;i'"] - - ~,...--~--~-- - f - -"~,~,~.~-"~'~'~ - - ' 1 .................. 8.0min : : 360 psi : ,-"--,-.'- ...... ~' ...... ~'"4 .............. -""~ 9.0 min ' .: 360 psi 10.0 min ' '_....j .... .3..6.0.._p..s.i.._.~ . 2,010 psi ; : 2,.o~.o__P_?L..; ; 2,010 psi ~ ;"-~:~'~'~'--'~"-"--"'-----T'-~;~'~'"; }----;; .......... ..t - - ----.,..,..,~.-.-.- - -.-t- .................. I 80min : : 2,000 psi : ..... ;'; ........... -I .... 'f' .............. -.--'1 9.0rain : : 2,000ps~ : i"~'~'6'~'rn-'i ................. T"~;~'~'~-~"'i [ '-]--- '~'(b-6' ~'~, "; ..... ,r":f,'~J'~'i~,¥-; 25.0m,n ~ : 1,970 ps, : 30.0 min i 1,970 ~...s.i..j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-315 Supervisor: D.P. BURLEY Date: 9/23/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 2,331' TVD 840 psi LOT = (0.052 x 2,331') Fluid Pumped - 7 5/8", 29.7 ppf, L-80, BTC 3,805' TMD 2,316' TVD EMW = Leak-off Press. + MW 0.052 x TVD + 9.1 ppg EMW = 16.0 ppg Pump output = 0.1000 bps 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 400 300 200 100 0 *'"'"""~'-" ,~L~.i~.,~L.:~i,..i..i.+.+.~-.-~--.~-.-,.+.~...~ ~..~..~...~.7-~..~ -- - -- ---~-- TIME LINE psi psi ~ . -- psi psi psi 0 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk st~ stk stk stk stk stk stk stk stk stk slk stk stk stk stk stk stk stk st~ stk stk stk stk stk STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE 0 stks 0 psi ......................... ~-~- .......... ~-0-i~ ..... ........................ -~-~' ......... ¥~'~'i;a .... ........................ -~-~i~' ......... i'f6'i;~'~ .... ...................... '~';t~;' ......... ~i-~-i~;~ .... ........................ A~.t~?_ ......... _~__4.o___p__~.[ .... , 6 stks 450 psi ........................ j_~_t~?_ ......... .s__s_o__~?!_ ,,, ........................ ~.~_t_k.?. ......... .t~.o._~.s.[._.] ........................ ~_~_~.~_ ......... _Z_~.°...e.~.L...= 10 stks 840 psi ' ! ! ,L a J ...................................... '. .................. : ...................................... ~ .................. ..I' CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .................. ~ .................. .~ .................. : 0 stks 0 psi 1 stks 90 psi ......................... ~--a~;- ......... ~¥~-~a---~ ......................... ~--;t-~;- ......... ~-6-~a---',, ........................ -~--;t~; ......... ~-~--~a---i · ....................... '~-'~i-~- ......... ~f~-i;;F--i ' 6 stks 725 psi 7 stks 880 psi .................. .[ .................. j .................. ......................... _s_~_t_k_?_ ........ ?..3.9.._p~!._~ 9 stks 1,150 psi ........................ !.O.~.t.k.?. ....... ?:.3..0_9..P_~!..i 11 stks 1,450 psi ........................ i-~-~t~- ....... i;-~--~'a'-i ........................ i-~-~;i[~- ....... ........................ i~-~[~- ....... i;'~i~"~'~i--] I I ? ..................................... ~ .................. -I SHUT IN TIME SHUT IN PRESSURE 1.0 min 2,030 psi [ .... 2.-o-m-i-,~ ........................... SHUT IN TIME ..... 0"."0'~'i~ ....................... i .... §~,'0' ~;'i .... ..... ~-.-~-~T~ ....................... i .... ~-Y~-i:;a'---i ......................................2.0 min ] .... ~-'~'~-~'['"'!,' 3.0 min : : 800 psi 4.0 m~n : : 790 psi ............ -. ...... ~ .................. ~ .............. :...~ ..... .5:.o_.??. .... .= .................. j .... 7__~_9_p_~.:._.] ..... .~:.o...m..i.,. .... [ .................. j .... !.~.o._.e?.L_j 7.0min : i 760 psi 9.0 min : i 750 psi SHUT IN PRESSURE .......................................... 3.0 min [ .... ~-.-o'~'i'~ ........................... : 6.0min 2,010 psi : 7.0rain : : 2,010psi : }. ............ .- ..... ~, .................. .I ............... =_.. 8.0 mm ~ .................. 4 .................. ~ ................... [ .... _9...O...m..i.n_ .... j .................. j____2_,_O_.O._O...p.s.!..:, .... !9:.o._m_9....j .................. ,,'__..z:_o.99...p~!..j .... !_5:.°__~]?.._.,: .................. L_?.,~P...p~!.. ,.' .... 2_9:.°__7%i .................. ~___~..,~9___p~!__j 25.0min : i 1,970 psi : NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. - ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-315 (Permit No. 98-190) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tarn 2N-315. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS [] SUSPENDED E~] ABANDONED~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-190 3 Address 8 APl Number P.O. Box 100360, Anchora~]e, AK 99510-0360 50-103-20270 4 Location of well at surface ? . ...... 9 Unit or Lease Name At Top Producing Interval 10 Well Number 2263' FSL, 97' FWL, Sec. 27, T10N, R7E, UM ' .'i-..", ,':';.:~ { 2N-315 AtTo tel Depth . ~~. 11 Field and Pool 2619' FNL, 100' FEL, Sec. 28, T10N, RTE, UM Kuparuk River Field 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 121'I ADL 380054 ALK 4602 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 20-Sep-98 27-Sep-98 30-Sep-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost I 11197' MD & 5373' TVD 11081' MD & 5315' TVD YES N NO U NA feet MD 1050 APPROX 22 Type Electric or Other Logs Run GR/Res, GPJCCL, Density/Neutron 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 108' 24" 9 cu. yds High Early 7.625" 29.7# L-80 SURF. 3805' 9.875" 296 sx ASIIILW, 247 sx Class G, 60 sx ASI 5.5" x 15.5# L-80 SURF. 10446' 6.75" 220 sx Class G 3.5" 9.3# L-80 10446' 11178' 6.75" (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10462' 10446' (CSR) 10774'-10804' MD 5151'~5168' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10774'-10804' 214200# of 12/18 and 20/40 carbolite ,',r',,,-,,,, , tJl"( It'll lkl/.4 ! Date First Production Method of Operation (Flowing, gas lift, etc.) lO,~9,98 Gas u., Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBI CHOKE SIZE I GAS-OIL RATIO Anchorane 10/21/98 9.00 TEST PERIOI: 1338 937 0 176 700 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BB[ OIL GRAVITY-APl (corr) Press. 357 0 24-HOUR RATE: 3381 2366 0 37° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A ED ommission Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Total pump volumes for this event: Category 1. 120 Category 2. 100 Category 3. 0 Total: 220 Top Reservoir (T3) 10670' 5092' Base Reservoir (-r2) 10919' 5231' Total to Date: 220 Annulus left open - freeze protected with diesel. 31. LIST OF AI-rACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 10/19/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-315 WELL_ID: AK9517 TYPE: AFC: AK9517 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:09/20/98 START COMP: RIG:RIG ~ 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20270-00 09/19/98 (D1) TD: 108'(108) SUPV:D.BURLEY 09/20/98 (D2) TD: 910' ( 802 SUPV:D.BURLEY 09/21/98 (D3) TD: 3616'(2706 SUPV:D.BURLEY 09/22/98 (D4) TD: 3815' ( 199 SUPV:D.BURLEY 09/23/98 (D5) TD: 3835' ( 20) SUPV:D.BURLEY 09/24/98 (D6) TD: 5795'(1960) SUPV:D.BURLEY MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG 90% MOVED TO 2N-315 Moving rig to 2N-315. MW: 10.0 VISC: 95 PV/YP: 35/28 APIWL: 7.2 DRILLING 9-7/8" HOLE FROM 1520' RIG ON HIGHLINE POWER 24 Move rig to well 2N-315. NU diverter system. Accept rig 0 0700 hrs. Test diverter. Clean out conductor to 106' Drill 9-7/8" hole from 108' to 910' MW: 10.2 VISC: 64 PV/YP: 29/22 APIWL: 5.5 POH TO RUN 7-5/8" CASING. RIG ON HIGHLINE Drill from 910' to 2201', max gas encountered below permafrost. Drill from 2201' to 3616' MW: 10.2 VISC: 53 PV/YP: 24/21 APIWL: 4.8 TESTING BOPE. RIG ON HIGHLINE POWER Drill from 3616' to 3815'. Run 7-5/8" casing. Pump first and second stage cement. ND diverter system. MW: 9.1 VISC: 43 PV/YP: 13/13 APIWL: 10.0 DRILLING 6-3/4" PRODUCTION HOLE FROM 4400'. RIG ON HI NU BOPE and test to 250/3500 psi. Clean out cement to 1605', drill out stage collar. Clean out cement to 3668' Clean out float equipment and cement and drill 20' of new hole to 3835' Perform FIT, EMW of 16.0 ppg. MW: 9.2 VISC: 48 PV/YP: 13/13 APIWL: 5.6 DRILLING 6-3/4" HOLE FROM 6175' RIG ON HIGHLIN Safety stand-down meeting. Drill from 3835' to 5795' Attempted to repair leaking union on standpipe. Perform LOT, EMW 14.2 ppg. Date: 10/19/98 09/25/98 (D7) TD: 8005'(2210) SUPV:D.BURLEY 09/26/98 (DS) TD: 9655'(1650) SUPV:D.BURLEY 09/27/98 (D9) TD:ll197' (1542) SUPV:D.BURLEY 09/28/98 (D10) TD:ll197'( 0) SUPV:D.BURLEY 09/29/98 (Dll) TD:ll197'( 0) SUPV:G.R. WHITLOCK 09/30/98 (D12) TD:ll197'( 0) SUPV:G.R. WHITLOCK ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT MW: 9.3 VISC: 49 PV/YP: 11/19 APIWL: 5.2 DRILLING 6-3/4" HOLE FROM 8085' Drill from 5795' to 8005' Encountered mild losses. Pulled slowly to 5620', swabbing. Circ and condition mud. MW: 9.2 VISC: 47 PV/YP: 11/16 APIWL: 5.0 DRILLING 6-3/4" HOLE FROM 10320' RIG Staged back in hole, CBU ~ 6467', 7220' and 8006'. Maintained full returns throughout, no other problems. Drill from 8006' to 9655' MW: 9.8 VISC: 46 PV/YP: 11/15 APIWL: 4.0 CONDITIONING MUD ~ 11197' (TD) . Drill from 9655' to 10719' Encountered 10 bph losses after increasing mud wt. to 9.8 ppg, well breathing during connections. Drill from 10719' to 11197' (TD) . Pump low/high vis sweeps and circ hole clean. Begin wiper trip to shoe. MW: 9.8 VISC: 45 PV/YP: 11/16 APIWL: 4.9 RUNNING 5-1/2" X 3-1/2" PRODUCTION CASING CURRENT DEPTH 7168 Completed wiper trip to shoe. Pump low/high vis sweeps and circ hole clean. Run 3.5"x5.5" casing. MW: 9.8 VISC: 42 PV/YP: 12/12 APIWL: 4.6 LANDING TUBING Run 5.5" casing. Pump cement. Run 3.5" tubing. MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Run 3.5" tubing. Freeze protect well. N/D BOPE. NU master valve and test to 5000 psi. Release rig @ 1000 hrs. 9/30/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(2N-315(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-315 PERFORATE, PERF SUPPORT 1009980508.2 DATE DAILY WORK UNIT NUMBER 10/10/98 PERFORATE 3-1/2" TUBING DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 NOI NO SWS-DECKERT SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE K85117 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 500 PSI 350 PSI 500 PSI 350 PSII 0 PSII 0 PSI DAILY SUMMARY RAN PERF ASSEMBLY, 2-1/2" HC/BH/4 SPF/180 DG PHASING/2 SPF 170 DEG F/HIGH SIDE/2 SPF 10 DEG FROM HIGH SIDE. ATTEMPT TO PUMP TOOLS DOWN BUT UNABLE TO GET PAST 2300' PUMPING 2 BPM W/2300 PSI ON TUBING TAKING RETURNS OUT ANNULAS TROUGH SLEEVE AT 10,383' RKB. POH RD. WILL CONTINUE WITH CHANGED SET UP OF TOOLS. IN PROGRESS.[Perf] TIME 08:30 10:00 LOG ENTRY MIRU. SWS (DECKERT AND CREW) TGSM, ICY CONDITIONS. MU PERF ASSEMBLY 2-1/2" HC LOADED 10'/BH / 4SPF/180 DEG PHASING/2 SPF 170 DEG FROM HIGH SIDE/2 SPF 10 DEG FROM HIGH SIDE. (GUN/SAFE/ MPD/GUN GR/WT/HEAD) TL 27'. RIGGED UP HOT OIL TO TUBING AND JUMPER LINE TO ADJACENT FLOWLINE.FROM ANNULAS. PT LUB TO 3000 PSI. RIH. 12:30 TOOL STOPPED AT 1650' RKB PUMPED TOOL DOWN AT 2 BPM 2300 PSI AND WAS UNABLE TO GET PAST 2300' @ 68 DEG IINCLINATION. WORKED TOOL WITH NO SUCCESS. 14:00 POH TO CHANGE TOOLS BUT PARTS NOT AVAILABLE. RD. WILL RETRY WITH NEW ASSEMBLY IN MORNING.PUMPED DIESEL DOWN TUBING AND ANNULAS TO FREEZE PROTECT TO 2000' VERT. LEAVE WELL SHUT IN. NOTIFIED DSO. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~. WELL SERVICE REPORT '~" K1(2N-315(W4-6)) WELL JOB SCOPE JOB NUJVlBER " 2N-315 PERFORATE, PERF SUPPORT 1009980508.2 DATE DAILY WORK UNIT NUMBER 10/11/98 RUN GAMMA-RAY TIE IN AND PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES SWS-DECKERT SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE K85117 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY IRAN GAMMA-RAY,CCL TOOLS TAGGED DOWN AT 10,832' AND TIE IN W/SPERRY SUN MWD LOG. RAN PERF GUN ASSEMBLY TIE IN AND PERFORATE 3-1/2" TUBING FROM 10,804' TO 10,794' RKB (10').[Perf] TIME 08:00 09:00 LOG ENTRY 18:00 MIRU SWS (DECKERT AND CREW). TGSM, USE CAUTION TAPE AROUND WIRELINE. MU ASSEMBLY ROLLER/CCL/GR/WT/ROLLER/WT/HEAD) TL=23'. RIGGED UP PUMPER AND PT TO 3000 PSI. RIH SLOWLY. TAGGED DOWN AT 10,832' RKB. LOGGED UP ABOVE JEWLRY , TIE IN WITH SPERRY SUN MWD LOG DATED 9/28/98. POH. AT 4000' LUBRICATOR STARTED DRIPPING. BLEED DOWN SYSTEM AND STOP LEAK. CONT POH. 13:00 AT SURFACE RD. LAID DOWN LUBRICATOR AND CHANGED OUT GREASE HEAD PACKING ELEMENT. 14:00 PICKED UP LUBRICATOR, MU #1 PERF ASSEMBLY 2-1/2" HC, BH,4 SPF, 180 DEG PHASING, 2 SPF 170 DEG FROM HIGH SIDE, 2 SPF 10 DEG FROM HIGH SIDE. (ROLLER/10' GUN/ROLLER/CCL/WT/ROLLER/WT/HEAD) TL= 33.6'. TEST LUB TO 3000 PSI. 14:45 RIH.TAGGED DOWN AND TIE IN WITH GR/CCL LOG RAN ON 10/10/98. ADD 200 PSI TO TUBING AND PERFORATE 3-1/2" TUBING OVERBALANCED F/10,804' TO 10,794' (10'). LOG UP PAST JEWELRY AND POH. AT SURFACE RD. LEAVE WELL SHUT IN. NOTIFIED DSO. WORK IN PROGRESS. ARCO Alaska. Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ,, Kl(2N-315(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-315 PERFORATE, PERF SUPPORT 1009980508.2 DATE DAILY WORK UNIT NUMBER 10/12/98 PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES SWS-DECKERT SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE K85117 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 100 PSI 100 PSI 100 PSI 100 PSI 0 PSII 0 PSI DAILY SUMMARY IRAN PERF ASSEMBLY 20'/2-1/2" HC/BH/4 SPF/180 DEG PHASED/ORIENT 2 SPF 170 DEG FROM HIGH SIDE/2 SPF 10 DEG FROM HIGH SIDE. PERFORATED FROM 10,794' TO 10,774' RKB (20').[Perf] TIME LOG ENTRY 08:00 MIRU SWS (DECKERT,CREW AND LRS) TGSM. RIGGING UP AND WORKING AROUND OTHER EQUIPMENT. MU PERF ASSEMBLY 2-1/2" HC/BH/4SPF/180 DEG PHIASNG/ORIENT 2 SPF 170 DEG FROM HIGH SIDE/2 SPF 10 DEG FROM HIGH SIDE. (ROLLER/WT/ROLLER/20' GUN/ROLLER/CCL/SWIVEL/HEAD) TL=40.5'. 09:30 RIG UP LRS, PT LUB TO 3000 PSI. RIH SLOWLY. TIE IN WITH CCL GR/LOG DATED 10/10/98. WITH 200 PSI WHP PERFORATED 3-1/2" TUBING OVER BALANCED FROM 10,794' TO 10,774' RKB (20'). GOOD SURFACE INDICATIONS. LOG UP AND POH. 12:30 AT SURFACE RD. ALL SHOTS FIRED. SHUT IN WELL. NOTIFIED DSO. SL TO FOLLOW UP. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(2N-315(W4-6)) WELL JOB SCOPE JOB NUMBER ' " 2N-315 FRAC, FRAC SUPPORT 1009981523.5 DATE DAILY WORK UNIT NUMBER 10/14/98 FRAC A SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-YOKUM KRALICK FIELD AFC# CC# Signed ESTIMATE K85117 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 0 PSI 2000 PSI 0 PSI 500 PSI 0 PSII 0 PSI DAILY SUMMARY I I I FLUSHED WELL TO COMPLETION-1358# SAND IN PIPE (APPROX. 290' OF FILL)W/212,842# IN FORMATION [Frac-Refrac] I COMPLETED 334 BBL BRACKET FRAC AND FRAC'D A SAND W/214,200# OF 12/18 AND 20/40 CARBOLITE TOTAL PUMPED - TIME LOG ENTRY 08:00 MIRU DS AND LRS 12:30 TGSM - CONGESTED PAD 13:00 P/T HARD LINE AND EQUIP TO 9000 PSI - LEAK - BLEED OFF AND HAMMER UP - P/T GOOD TO 9000 PSI 14:00 PUMP BREAKDOWN AND SHUT DOWN 14:27 PUMP SCOUR STAGE W/1 PPA 20/40 CARBOLITE AND STEP DOWN - 855 ISlP - PUMP PULSES 15:50 DATA FRAC YF-150D 100 BBLS - STEP DOWN AND SHUT DOWN - 911 ISlP 18:30 ADJUST PAD AND PERFORM BRACKET FRAC W/GLASS BALLS AND 20/40 MESH SAND - 334 TOTAL BBLS 19:15 SHUT DOWN FOR JOB REDESIGN - ORDERED MORE WATER AND FUEL 21:00 START PAD - 400 BBLS 50# GEL 15 BPM 22:00 CONTINUE THROUGH PROGRAM AS REDESIGNED AND FLUSH WELL W/DIESEL 02:00 RDMO DS AND LITTLE RED - PUMPED 214,200# 12/18 AND 20/40 CARBOLITE W/#212,842 IN FORMATION AND #1352 IN PIPE - 7043 PSI MAX PRESS DURING BREAKDOWN STAGE SURVEY CALCULATION AND FIELD WORKSHEET ~ .lob No..0_~:S_!__-__0_08__94__- Sidetrack No.______ Page 1 of 5 m;t~.[4:14: Company ARCO ALASKA INC. Rig Conlraclor & No. DOYON - 141 Field TARN DEVEI.OPMENT FIEI,D Well Name & No.TARN I)RIIA~SITE 2N/315 Survey Section Name SPERRY SUN Bill Rep. WELL DATA Target TVD F(~) Target Coord. N/S__ Slot Coord. N/S -39.83 Grid Correction 0.000 Depths Measured From:RKB~ MSL[-] SS[-_] Target Description__ Target Coord. E/W Slot Coord. E/W -675.38 Magn. Declination 26.820 Calculation Method MINIMUM CURVATUF Target Direction (DD) Build\Walk\I)L pdtq0ft~)~ 30m~ 10m[~ Vcrt. Sec. Azim. 329.55 Magn. to Map Corr. 26.820 Map North to: OTHER SURVEY DATA __ Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction I.ength TVI) Section N(+) / S(-) E(+) / W(- I)L Build (+) Right (+) Comment Type (FT)__ __(D__DO- (DD) ~ __(.I_!_'-I_')____ __~(IrF_)_ ~)___ _(Per 100 Fll'3)rop (-) Left (-) MWD 108.00 0.00 0.00 108.00 0.00 0.00 0.00 TIE IN POINT \ 20-SEP-98 MWD 162.63 0.15 252.95 54.63 162.63 0.02 -0.02 -0.07 0.27 0.27 8" MIC SET @ 1.4 AKO 20-SEP-98 MWD 252.11 0.48 285.88 89.48 252.11 0.31 0.05 -0.54 0.41 0.37 START SLIDING AT 238' 20-SEP-98. MWD 341.00 2.28 306.74 88.89 340.97 2.21 1.21 -2.32 2.07 2.02 ALL SLIDE 20-SEP-98 MWD 430.88 5.60 311.29 89.88 430.62 8.03 5.17 -7.05 3.71 3.69 5.06 , 20-SEP-98 MWD 522.12 9.45 314.58 91.24 521.06 19.50 13.37 -15.73 4.24 4.22 3.61 ,, 20-SEP-98 MWD 611.49 12.90 317.07 89.37 608.73 36.33 25.83 -27.75 3.90 3.86 2.79 75' SLIDE 20-SEP-98 MWD 706.12 17.01 317.05 94.63 700.13 60.17 43.70 -44.39 4.34 4.34 -0.02 75' " 20-SEP-98 MWD 800.37 20.30 313.73 94.25 789.42 89.36 65.10 -65.60 3.67 3.49 -3.52 75' " -- 21-SEP-98 MWD 885.92 23.63 311.8l 85.55 868.75 119.98 86.79 -89.11 3.98 3.89 -2.24 60' " 21-SEP-98 MWD 976.42 27.34 311.23 90.50 950.43 157.00 112.59 -118.27 4.11 4.10 -0.64 60' " 21-SEP-98 MWD 1066.36 32.36 310.55 89.94 1028.41 199.39 141.87 -152.11 5.59 5.58 -0.76 75' " 21-SEP-98 MWD 1157.11 35.99 313.32 90.75 1103.48 247.97 175.97 -189.98 4.35 4.00 3.05 75' " . 21-SEP-98 MWD 1248.16 39.62 315.56 91.05 1175.41 301.85 215.06 -229.78 4.26 3.99 2.46 60 .... 21-SEP-98 MWD 1342.47 43.11 319.51. 94.31 1246.20 362.79 261.06 -271.78 4.62 3.70 4.19 75' " 21-SEP-98 MWD 1437.45 47.03 323.70 94.98 1313.28 429.36 313.78 -313.45 5.17 4.13 4.41 75' " 21-SEP-98 MWD 1531.52 50.70 328.47 94.07 1375.17 500.03 372.58 -352.89 5.46 3.90 5.07 75' " 21-SEP-98 MWD 1624.67 54.77 328.62 93.15 1431.56 574.14 435.81 -391.56 4.37 4.37 0.16 61' " 21-SEP-98 MWD 1717.60 59.54 329.45 92.93 1481.95 652.19 502.75 -431.71 5.19 5.13 0.89 61' " . 21-SEP-98 MWD 1811.02 63.97 330.14 93.42 1526.15 734.46 573.86 -473.09 4.79 4.74 0.74 61' " 21-SEP-98 MWD 1905.75 66.93 330.90 94,73 1565.50 820.60 648.86 -515.49 3.21 3.12 0.80 61' " 21-SEP-98 MWD 1999.85 67.29 330.48 94.10 1602.11 907.28 724.45 -557.92 0.56 0.38 -0.45 21-SEP-98 MWD 2093.51 67.66 330.11 93.66 1637.98 993.78 799.60 -600.79 0.54 0.40 -0.40 21-SEP-98 MWD 2190.71 68.31 330.31 97.20 1674.42 1083.89 877.80 -645.56 0.70 0.67 0.21 i ~~t,]~r~,,~:]~ SURVEYCALCULAT]ON AND FIELD WORKSHEET JobNo, 045i_00894 S~detl. ackNo.__ Page 2 or 5 ]tl[~]j:~__: Company ARCO ALASKA INC. Rig Conlractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2N/315 Survey Section Name SPERRY SUN BtlI Rep._ WELL DATA Target TVD ~) Targc~ Coord. N/S Slot Coord. N/S -39.83 Grid Correction 0.000 Depths Measured From:RK~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -675.38 Magn. Declination 26.820 Calculation Method MINIMUM CURVATU1 Target Direction (DD) Build~WalkSI)L pdfi0ft~ 30m~ 10m~ Vert. Sec. Azim. 329.55 Magn. to Map Corr. 26.820 Map North to:OTHER SURVEY DATA __ Survey Survey Incl. Hole Course Vertical ............................. Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Dircclion Length TVD Section N(*) / S(-) E(+) / W(- I)l. Build (+) Right (+) Comment Type (~ ~DD) (I)D) ~ (g~ (_[(T) _~ (~l~__ _(Per 100 F~rop (-) Left (-) 21-SEP-98 MWD 2285.82 68.60 332.19 95.11 1709.35 1172.31 955.36 -688.11 1.86 0.30 1.98 21-SEP-98 MWD 2379.17 67.03 331.90 93.35 1744.60 1258.67 1031.71 -728.63 1.71 -1.68 -0.31 31' " 180TF 21-SEP-98 MWD 2472.35 66.79 331.26 93.18 1781.14 1344.33 1107.09 -769.42 0.68 -0.26 -0.69 ................................ 21-SEP-98 MWD 2567.52 66.56 331.74 95.17 1818.82 1431.67 1183.89 -811.12 0.52 -0.24 0.50 21-SEP-98 MWD 2660.56 66.42 331.04 93.04 1855.94 1516.94 1258.79 -851.98 0.71 -0.15 -0.75 21-SEP-98 MWD 2754.42 66.50 331.53 93.86 1893.43 1602.95 1334.26 -893.32 0.49 0.09 0.52 .............. 21-SEP-98 MWD 2850.84 66.44 331.81 96.42 1931.92 1691.29 1412.07 -935.27 0.27 -0.06 0.29 .............................................................. 21-SEP-98 MWD 2944.37 66.31 330.61 93.53 1969.40 1776.94 1487.17 -976.54 1.18 -0.14 -1.28 21-SEP-98 MWD 3038.44 66.43 331.80 94.07 2007.11 1863.09 1562.70 -1018.05 1.17 0.13 1.27 ............................................. 21-SEP-98 MWD 3132.88 66.14 330.27 94.44 2045.09 1949.52 1638.34 -1059.92 1.51 -0.31 -1.62 21-SEP-98 MWD 3226.75 66.10 331.41 93.87 2083.10 2035.33 171.3.30 -1101.74 1.11 -0.04 1.21 21.-SEP-9~ MWD 3321.65 66.68 330.60 94.90 2121.10 2122.26 1789.35 -1143.89 0.99 0.61 -0.85 ..... 21-SEP-9[ MWD 3415.43 66.21 330.98 93.78 2158.58 2208.20 1864.39 -1185.84 0.62 -0.50 0.41 ,. .................................................. (i, 21-SEP-9[ MWD 3507.56 66.09 331.31 92.13 2195.83 2292.43 1938.19 -1226.51 0.35 -0.13 0.36 .-. 22-SEP-9[ MWD 3599.96 66.31 331.69 92.40 2233.12 2376.93 2012.48 - 1266.85 0.45 0.24 0.41 22-SEP-9~ MWD 3695.50 65.88 331.14 95.54 2271.84 2464.22 2089.18 - 1308.64 0.69 -0.45 -0.58 22-SEP-9[ MWD 3741.32 65.70 331.91 45.82 2290.63 2505.99 2125.92 - 1328.56 1.58 -0.39 1.68 24-SEP-9~ MWD 3866.17 66.69 330.26 124.85 2341.02 2620.17 2225.89 -1383.80 1.45 0.79 -1.32 24-SEP-9~ MWD 3959.68 67.94 330.96 93.51 2377.08 2706.43 2301.07 -1426.13 1.50 1.34 0.75 24-SEP-9~ MWD 4055.07 68.89 331.22 95.39 2412.18 2795.10 2378.71 -1469.01 1.03 1.00 0.27 24-SEP-98 MWD 4145.45 68.19 331.17 90.38 2445.24 2879.18 2452.42 -1509.54 0.78 -0.77 -0.06 30'--LS 24-SEP-9~ MWD 4241.27 64.63 330.81 95.82 2483.58 2966.95 2529.20 -1552.12 3.73 -3.72 -0.38 30'--LS 24-SEP-9~ MWD 4331.02 63.76 330.74 89.75 2522.65 3047.73 2599.72 -1591.57 0.97 -0.97 -0.08 24-SEP-9~ MWD 4427.42 64.16 331.88 96.40 2564.97 3134.30 2675.70 -1633.15 1.14 0.41 1.18 lie '", SURVEY CALCULATION AND FIELD WORKSHEET I ~ Joh No. 0451-00894 Sidetrack No.__ Page 3 of 5 Company ARCO ALASKA INC. Rig Contractor & No. DOYON- 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRII,LSITE 2N/315 Survey Scction Name SPERRY SUN BHI Rep. WELL DATA Target TVD _ F(_F~)__ Target Coord. N/S Slot Coord. N/S -39.83 Grid Correction 0.000 Depths Measured From:RKB~ MSL[~ SS~ Target Description__ Target Coord. V,/W Slot Coord. F,/W -675.38 Magn. Declination 26.820 Calculation Method MINIMUM CURVATUI Target Direction (DD) Build\Walk\l)I, pdfi0ft[~ 30m~_-] 10m~ Vcrt. Sec. Azim. 329.55 Magn. to Map Corr. 26.820 Map North to: OTItER SURVEY DATA Survey Survey Incl. Hole Course Vertical ............. Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Len th ']'VD Section N(-4/tv~q(-) E(+) / W(- Dl, Build (+) Right (+) Comment _ Type (FT) (DD) (DD) ('?I[)_ __(F_~)~ ....,~_ (I_~ _(Per 100 F~rop (-) Left (-)__ 24-SEP-98 MWD 4522.05 64.08 331.04 94.63 2606.28 3219.39 2750.49 -1673.82 0.80 -0.08 -0.89 , -- __ 24-SEP-98 MWD 4616.22 65.31 327.45 94.17 2646.54 3304.50 2823.63 -1717.36 3.69 1.31 -3.81 30'--45L -- 24-SEP-98 MWD 4709.32 66.74 328.24 93.10 2684.37 3389.53 2895.64 -1762.63 1.72 1.54 0.85 24-SEP-98 MWD 4802.49 67.59 327.43 93.17 2720.53 3475.36 2968.33 - 1808.34 1.21 0.91 -0.87 24-SEP-98 MWD 4896.64 68.32 326.40 94.15 2755.86 3562.53 3041.45 -1855.98 1.28 0.78 -1.09 24-SEP-98 MWD 4990.49 68.98 326.44 93.85 2790.03 3649.81 3114.27 -1904.33 0.70 0.70 0.04 24-SEP-98 MWD 5084.79 69.71 326.63 94.30 2823.29 3737.92 3187.88 - 1952.98 0.80 0.77 0.20 24-SEP-98 MWD 5182.36 68.33 327.27 97.57 2858.23 3828.93 3264.23 -2002.67 1.54 -1.41 0.66 30'--140R __ 24-SEP-98 MWD 5277.73 68.12 327.86 95.37 2893.61 3917.44 3338.98 -2050.17 0.62 -0.22 0.62 __ 24-SEP-98 MWD 5373.57 68.96 329.25 95.84 2928.67 4006.62 3415.08 -2096.69 1.61 0.88 1.45 24-SEP-98 MWD 5465.05 69.40 327.94 91.48 2961.19 4092.11. 3488.05 -2141.25 1.42 0.48 -1.43 -- 24-SEP-98 MWD 5558.48 65.98 326.98 93.43 2996.65 4178.48 3560.91 -2187.73 3.78 -3.66 -1.03 20'--90R 24-SEP-98 MWD 5653.98 66.64 329.51 95.50 3035.03 4265.90 3635.27 -2233.74 2.52 0.69 2.65 25-SEP-98 MWD 5744.24 67.62 330.12 90.26 3070.11 4349.06 3707.16 -2275.56 1.25 1.09 0.68 -- 25-SEP-98 MWD 5838.21 68.61 329.72 93.97 3105.13 4436.25 3782.61 -2319.26 1.13 1.05 -0.43 25-SEP-98 MWD 5932.66 69.76 330.20 94.45 3138.69 4524.53 3859.04 -2363.46 1.31 1.22 0.51 -- 25-SEP-98 MWD 6117.88 67.70 330.99 185.22 3205.88 4697.10 4009.39 -2448.20 1.18 -1.11 0.43 30'--160R 25-SEP-98 MWD 6213.13 68.44 331.56 95.25 3241.46 4785.41 4086.87 -2490.67 0.95 0.78 0.60 25-SEP-98 MWD 6402.50 68.55 333.38 189.37 3310.88 4961.36 4243.10 -2572.10 0.90 0.06 0.96 30'--160R 25-SEP-98 MWD 6497.67 67.47 334.61 95.17 3346.52 5049.34 4322.41 -2610.79 1.65 -1.13 1.29 --. 25-SEP-98 MWD 6592.75 68.02 333.47 95.08 3382.53 5137.07 4401.53 -2649.31 1.25 0.58 -1.20 25-SEP-98 MWD 6686.52 66.68 333.93 93.77 3418.64 5223.37 4479.10 -2687.65 1.50 -1.43 0.49 30'--160L __ -- 25-SEP-98 MWD 6780.95 65.88 332.02 94.43 3456.63 5309.67 4556.11 -2726.93 2.04 -0.85 -2.02 25-SEP-98 MWD 6874.72 66.84 331.88 93.77 3494.23 5395.49 4631.92 -2767.32 1.03 1.02 -0.15 r SURVEY CALCULATION AND FIELD WORKSHEET ~ .lob No. ?~5__1_-~0__0._89_~4_ Sidetrack No.~ Page 4 of 5 ~,Ll[~-_l:~.~ Company ARCO ALASKA INC. Rig Conlraclor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD · Well Name & No.TARN I)RILLSITE 2N/315 Survey Section Name SPERRY SUN BHI Rep. WELL DATA Target TVD _(.F_T).~~ Target Coord. N/S Slot Coord. N/S -39.83 .____ Grid Correction 0.000 Depths Measured From:RKB~ MSI~ SS~ Target Description___ Target Coord. E/W Slot Coord. I?./W -675.38 Magn. Declination 26.820 Calculation MethodMINIMUM CURVATUI Target Direction..._ (DD) Build\Walk\DL pdt")0ft~ 30m[~ lOmL_~ Vcrl. Sec. Azim. 329.55 Magn. to Map Corr. 26.820 Map North to:OTItER SURVEY DATA --_ Survey Survey Incl. Hole 'Fotal Coordinate Build Rate Walk Rate Course Vcr! ica 1 Date Tool D(~_?~_ Angle Direction m~(~ TVD Section $(4-) / S(-) E(+) / W(~; Df, Build (+) Right (+) Comment Type __ __ D(Q_~)._. _(_D_D)_ ...... _(_F_T_)_ ........................ .(_F_~') ....... _(E__T) '_i _(Per 100, F~rop (-) Left (-) _ 25-SEP-98 MWD 6968.55 67.41 332.05 93.83 3530.70 .5481.87 4708.23 -2807.96 0.63 0.61 0.18 , 25-SEP-9~ MWD 7065.40 68.62 333.02 96.85 3566.96 5571.55 4787.91 -2849.37 1.56 1.25 1.00 25-SEP-98 MWD 7156.48 67.21 333.36 91.08 3601.20 5655.77 4863.24 -2887.44 1.59 -1.55 0.37 30'--140L -- 25-SEP-98 MWD 7250.65 67.04 331.66 94.17 3637.81 5742.42 4940.20 -2927.49 1.67 -0.18 -1.81 ____ 25-SEP-98 MWD 7344.11 66.63 329.96 93.46 3674.58 5828.32 5015.21 -2969.39 1.73 -0.44 -1.82 25-SEP-98 MWD 7438.36 67.54 329.11 94.25 3711.27 5915.13 5090.03 -3013.40 1.27 0.97 -0.90 _ 25-SEP-98 MWD 7532.97 66.22 329.06 94.61 3748.42 6002.13 5164.68 -3058.11 1.40 -1.40 -0.05 30'--180 -- 25-SEP-98 MWD 7628.10 65.55 328.73 95.13 3787.29 6088.95 5239.03 -3102.96 0.77 -0.70 -0.35 25-SEP-98 MWD 7721.98 65.66 329.67 93.88 3826.07 6174.45 5312.46 -3146.74 0.92 0.12 1.00 -- __ 25-SEP-98 MWD 7818.35 65.63 329.62 96.37 3865.81 6262.24 5388.22 -3191.11 0.06 -0.03 -0.05 25-SEP-98 MWD 7914.58 65.57 329.25 96.23 3905.56 6349.88 5463.68 -3235.67 0.36 -0.06 -0.38 26-SEP-98 MWD 8007.00 65.45 328.83 92.42 3943.87 6433.98 5535.80 -3278.94 0.43 -0.13 -0.45 26-SEP-98 MWD 8097.76 65.40 329.11 90.76 3981.62 6516.51 5606.53 -3321.48 0.29 -0.06 0.31 , 26-SEP-98 MWD 8183.29 66.29 329.39 85.53 4016.62 6594.55 5673.60 -3361.39 1.08 1.04 0.33 .... 26-SEP-98 MWD 8286.49 67.46 330.32 103.20 4057.15 6689.46 5755.67 -3409.04 1.40 1.13 0.90 -- -- 26-SEP-98 MWD 8381.34 68.53 330.69 94.85 4092.69 6777.38 5832.21 -3452.34 1.18 1.13 0.39 -- 26-SEP-98 MWD 8473.43 67.33 327.97 92.09 4127.29 6862.71 5905.61 -3495.86 3.03 -1.30 -2.95 30'--160L 26-SEP-9[ MWD 8567.57 67.07 326.99 94.14 4163.78 6949.44 5978.79 -3542.51 1.00 -0.28 -1.04 26-SEP-9t~ MWD 8662.76 68.00 326.91 95.19 4200.15 7037.31 6052.52 -3590.48 0.98 0.98 -0.08 26-SEP-9~ MWD: 8760.30 68.00 328.22 97.54 4236.69 7127.69 6128.85 -3638.99 1.25 0.00 1.34 26-SEP-9[ MWDI 8848.88 67.74 328.25 88.58 4270.06 7209.73 6198.61 -3682.19 0.30 -0.29 0.03 30'--150R 26-SEP-9~ MWD 8943.07 67.21 329.28 94.19 4306.14 7296.72 6273.00 -3727.30 1.16 -0.56 1.09 , -- 26-SEP-9~ MWD! 9037.97 67.09 329.42 94.90 4342.99 7384.17 6348.23 -3771.88 0.19 -0.13 0.15 26-SEP-9t~ MWD 9137.71 66.24 328.05 99.74 4382.50 7475.74 6426.52 -3819.41 1.52 -0.85 -1.37 30'--160R ! SURVEY CALCULATION AND FIELD WORKSHEET i ~ Job No. 0451-00894 Sidetrack No.__ Page 5 of 5_ 1;t~,_]ll:are:~ Company ARCO ALASKA INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2N/315 Survey Scction Name SPERRY SUN BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -39.83 __ Grid Correction 0.000 Depths Measured From: RKI~ MSL~] SS[~ Target Description Target Coord. E/W Slot Coord. E/W -675.38 Magn. Declination 26.820 Calculation MethodMINIMUM CURVATU! Target Direction (DD) Build\Walk\DL pdtq0ft[~ 30m~ 10m[~ Vert. Sec. Azim. 329.55 Magn. to Map Corr. 26.820 Map North to:OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate_ Build Rate Walk Rate Date Tool Depth Angle Direction Le(ni~glt,¢ TVD Section N(~T/~S(-) E(+)F/T~W(- DL Build (+) Right (+) Comment Type (FT) (DD)_ (DD),_~_~___ __(FT)_,:_z_, x--~ (Per 10t31F~IB)rop (-) Left (-) 26-SEP-9~ MWD 9227.22 66.98 331.29 89.51 4418.04 7557.88 6497.42 -3860.88 3.42 0.83 3.62 ...' 26-SEP-9[ MWD 9322.73 67.87 330.08 95.51 4454.71 7646.05 6574.31 -3904.06 1.50 0.93 -1.27 26-SEP-9~ MWD 9417.83 66.84 330.34 95.10 4491.33 7733.82 6650.48 -3947.67 1.11 -1.08 0.27 30'--180 26-SEP-9~ MWD 9511.30 63.79 330.19 93.47 4530.36 7818.73 6724.22 -3989.79 3.27 -3.26 -0.16 30'--180 -- 26-SEP-98 MWDi 9606.22 62.57 329.23 94.92 4573.18 7903.43 6797.36 -4032.51 1.57 -1.29 -1.01 26-SEP-9fi MWD 9700.26 63.88 330.48 94.04 4615.55 7987.38 6869.96 -4074.66 1.83 1.39 1.33 27-SEP-98 MWD 9793.94 64.65 329.80 93.68 4656.23 8071.77 6943.15 -4116.68 1.05 0.82 -0.73 -- 27-SEP-98 MWD 9888.52 65.83 331.42 94.58 4695.84 8157.63 7017.98 -4158.82 1.99 1.25 1.71 27-SEP-98 MWD 9982.63 64.71 331.26 94.11 4735.21 8243.07 7092.98 -4199.82 1.20 -1.19 -0.17 30'--160R 27-SEP-98 MWD 10077.33 61.91 328.12 94.70 4777.75 8327.65 7166.02 -4242.48 4.19 -2.96 -3.32 20'--180 27-SEP-98 MWD 10172.80 60.59 330.46 95.47 4823.67 8411.34 7237.97 -4285.23 2.56 -1.38 2.45 15'--150R 27-SEP-98 MWD 10265.06 59.48 330.62 92.26 4869.75 8491.26 7307.56 -4324.54 1.21 -1.20 0.17 20'--150R 27-SEP-98 MWD 10358.49 58.10 330.33 93.43 4918.16 8571.15 7377.09 -4363.92 1.50 -1.48 -0.31 20'--150R .. 27-SEP-98 MWD 10451.83 57.19 334.30 93.34 4968.13 8649.88 7446.88 -4400.55 3.72 -0.97 4.25 20'--150R 27-SEP-98 MWD 10545.68 55.06 332.22 93.85 5020.44 8727.63 7516.47 -4435.59 2.92 -2.27 -2.22 30'--180 27-SEP-98 MWD 10638.65 54.27 333.79 92.97 5074.21 8803.33 7584.04 -4470.02 1.62 -0.85 1.69 27-SEP-98 MWD 10826.04 56.83 333.21 187.39 5180.21 8957.48 7722.31 -4538.97 1.39 1.37 -0.31 27-SEP-98 MWD 10920.45 57.62 335.34 94.41 52}tl.32 9036.58 7793.82 -4573.42 2.07 0.84 2.26 -- 27-SEP-98 MWD 11014.40 58.91 334.52 93.95 5280.74 9116.13 7866.19 -4607.28 1.56 1.37 -0.87 27-SEP-98 MWD 11108.48 60.06 333.31 94.08 5328.51 9196.94 7938.98 -4642.92 1.65 1.22 -1.29 27-SEP~98 MWD 11197.00 60.06 333.31 88~52 5372.69 9273.48 8007.51 -4677.37 0.00 0.00 0.00 PROJ@TD -- TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 18. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Kuparuk Rivcr Unit 2N-315 ARCO Alaska. Inc. Permit No: 98-190 Sur Loc: 41'FNL, 675'FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 2580'FSL. 37'FEL. Sec. 28, T10N, R7E, UM Dear Mr. Mazzolini: Enclosed is thc approved application for permit to drill thc above referenced well. Approval of annular disposal of drilling wastes is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 to ensure the requirements of 20 AAC 25.080 are met prior to initiating disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2N must comply with thc requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to usc that well for disposal purposes for a period longer than one year. Thc permit to drill docs not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Con]mission to witness a test of BOPE installed prior to drilling new hole. Notice max, be given bv contactin~g t~ p~cum field inspector on thc North Slope pager at 659-3607. David W. Johnston Chairman '~,._~ BY ORDER OF THE COMMISSION dlffEnclosures CC: Department of Fish & Game. Habitat Section ,~v/o cncl. Dcpamncnt of Environmental Conservation w/o cncl. STATE OF ALASKA ALASC,~¢OIL AND GAS CONSERVATION COMMIssiON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll [~ lb Type of Well Exploratory [~ Stratigraphic Test [~ Development Oil X Re-Entry [-- Deepen E~ Service E Development Gas ~-' SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380054, ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 41' FNL, 675' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2329' FSL, 107' FWL, Sec. 27, T10N, RTE, UM 2N-315 #U'630610 At total depth 9. Approximate spud date Amount 2580' FSL, 37' FEL, Sec. 28, T10N, R7E, UM 9/19/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2N-317 11074' MD 37' @ TD feet 28.7' @ 450' feet 2560 5321' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 67° Maximum su~fac~ 1357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' _+200 CF 9.875" 7.625" 29.7# L-80 BTC MOD 3785' 28' 28' 3813' 2300' 1.110 Sx Arcticset III L & 240 Sx Class G 2. 260 sx ASIIIL & 60 sx ASI 6.75" 5.5" 15.5# L-80 LTC-M 10385' 28' 28' 10413' 4941' 210 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 661' 10413' 4941' 11074' 5321' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~:'~ ~ ~* ~ !~''~'/ ~ ~'~'~.'~ ~ Surface .~ ,¢~ ~.~ '- Intermediate Production Perforation depth: measured -.~ ~ ~ ~ ~ ~ true vertical ~'~ ~"'~'~ 0ii & GaS CO,RS. 20. Attachments Filingfee X Property plat ['%.. BOPSketch X DiverterSketch X '~'l"uh~hOgpr°gram X Ddlling fluid program X Time vs depth plot [~ Refraction analysis ~ Seabed report E~r 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~'~O..x~ ,/I~C,/VZ.e--~--~--~ Title Tarn Drilling Team Leader Date ~/1,5'/~ ~:~ _ ~ Commission Use Only Permit Number I APl number I Approval date ~'t .._/9 /~ I Soo cover letter for ~ .?..¢'"../' ? 4;2:~. 50- /O a -- ~ O *~------------------------------~- 7~) '~ other requirements L;onoitlonso, approval Samples required E Yes ~: No Mud log required E~ Yes [~ No Hydrogen sulfidemeasures E Yes ~ No...-~ Directional surveyrequired ~. Yes B No Required working pressure for BOPE [~ 2M ~3M')E 5M E~ 1OM B 15M Other: byorderof ¢ /~ ,~ Approved by ~,-i,-~;~,,~ c,;,.,,~,~,~ ~_,, Commissioner the commission Date Form 10-401 Rev. 7-24-89 David W. Johnston Submit in triplicate STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMMI~dlON PERMIT TO DRILL 20 AAC 25.005 ~a. TypeofWork Drill X Reddll r-~ lb TypeofWell Exploratory E] StratigraphicTest ~ Development Oil X Re-Entry E] Deepen r~, Service E] Development Gas E] Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380054, ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 41' FNL, 675' FEL, Sec. 3, TDN, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2329' FSL, 107' FWL, Sec. 27, T10N, R7E, UM 2N-315 #U;630610 At total depth 9. Approximate spud date Amount 2580' FSL, 37' FEL, Sec. 28, T10N, R7E, UM 9/19/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2N-317 11074' MD 37' @ TD feet 28.7' @ 450' feet 2560 5321'-I-VD feet 36. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 67° Maximum surface 1357 psig At total depth ('I'VD) 2300 psig 18. Casing program Setting Depth size Specifications Top BOttom Quantity of cement Hole Casing Weight Grade Couplin~l Length MD TVD MD TVD {include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOC 3785' 28' 28' 3813' 2300' 1.110 Sx Arcticset III L & 240 Sx Class G 2. 260 sx ASIIIL & 60 sx ASI 6.75" 5.5" 15.5# L-80 LTC-M 10385' 28' 28' 10413' 4941' 210sxClass G 6.75" 3.5" 9.3# L-80 8rd DUE 661' 10413' 4941' 11074' 5321' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured dep.,th. ,~ .... .T.m{j V~e_r~Ta~,~epth Structural Conductor Surface Intermediate Production ~: i- Liner Perforation depth: measured DUPLI I ATE 0o,s. true vertical Anchorage 20. Attachments Filing fee X Property plat BI BOP Sketch X DiverterSketch X Ddlling program X Drilling fluid program X Time vs depth plot r-] Refraction analysis [~ Seabed report r-] 20 AAc 25.050 requirements X 21. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed "~,J~ ,~~~CommissionTitleuse Only Tam Drilling Team Leader Date Permit Number IAPInumber IApprovaldate ¢.../¢ ~;l¢ [ See cover letter for ~;~- x'~ ,~'<::~ 50- //0~' -- ~- 0 2-. '~ ¢__.) ~' other requirements Conditions of approval Samples required E~ Yes ~ No Mud log required r-] Yes ~, No Hydrogen sulfiderneasures [--1 Yes 1~ No Directional surveyrequired ,~ Yes [--i No Required working pressure for BOPE F~ 2M [-"~ME~ 5M E~ 1OM [~ 15M Other. Original Signed By byorderof ~.~/'~) Approved by ~ ~ ..... Commissioner the commission Date · , Form 10-401 Rev. 7-24-89 0a¥1d W. d0hnst0n Submit in triplicate ARCO Alaska, Inc. '- ' Post Office Box 100360 Anchorage, Alaska 99510-0360 September 15, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-315 Surface Location: 41' FNL 675' FEL Sec 3 TgN R7E, UM Target Location: 2329' FSL, 107' FWL Sec. 27, T10N, R7E, UM Bottom Hole Location: 2580' FSL, 37' FEL Sec, 28, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-315, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drilisite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(¢). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: ARCO Alaska, Inc. ia a Subsidiary of AflanticRichfieJdCompany David W. Johnst(~ Application for Permit to Drill Page 2 KRU 2N-315 1) Completion Report (20 AAC 25.070) 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments Sharon Allsup-Drake, Drilling Technologist 263-4612 265-6967 cc: KRU 2N-315 Well File ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 315 1. Move in and rig up Doyon 141. 2. Install divertersystem. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 315 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 +_10% 2-6 4-8 4-6 through Tam 9.0-10 <11% Drillinq Fluid System: ITriple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N-315 is 2N-317. The wells are 28.7' from each other at a depth of 450'. Drillinq Area Risks: The primary risk in the 2N 315 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' 'I-VD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. {Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 315 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2N 315 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi ARCO Alaska, Inc. This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 51/2'' 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31/2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AA(3 25.080 (h). ~ jon,e For: T Brassfield O~te p~otted : 14-Sep-98 Plot Reference i~ ,}16 Version Coordinates ore in feet reference 600 600 ('- 1800 --i-- 2400 0 '~ 3000 (D 3600 I ~2oo 4800 5400 60O0 ]ARCO Inc. [Structure : Tarn Drill Site 2N I : 315 Field .' Torn Development Field Location : North Slope, Alaska TD LOCATION: 2580' FSL, 37' FEL SEC. 28, TI ON, R7E TARGET LOCATION: 2529' FSL, 107' FWL SEC. 27, TI ON, R7E <- West (feet) 4800 4200 3600 3000 24430 1800 1200 600 0 600 [ I I I I I ~ ~ I ! I I I I [ [ I I I 8400 .aTO - Casing Pt ,..-,=~.'k~-~T2 - Base Bermuda ' ~.:a ~-,iTARGE-T _ Mid Bermuda T4k._~T5 - Top Bermuda End Angle Drop'~ ~ :ceberg Interval -- Begin Angle Drop TARGET 31/0=5118 TM0=10721 0EP=8873 C40 C50 NORTH 7649 WEST 4497 C80 7 5/8 Casing Pt 329.55 AZIMUTH 88?3' (TO TARGET) ***PLANE OF PROPOSAL*** 78O0 7200 6600 6000 5400 4800 4200 3600 3000 2400 RKB ELEVATION: 149' 1800 1.50KOP ]¥0=250 TMD=250 DEP=O Bose West Sak 7'50 DLS: 3.00 deg per 100 ft 1200 13.50 BEGIN 5 DEG BUILD TVD=744 TMD=750 OEP=64 20.00 OLS: 5.00 dog per 100 ff. 52 40 BEGIN TURN TO TARGET TV0=1021 TMD=1050 DEP=177 '42 11 B/ P. ERMAFROST TVD= 1199 TMD=I 269 DEP=301 EOC 600 '51.92 T/ WEST SAK SNOS TVD=1243 TMD=1328 DEP=341 66.70 EOC TV0=1513 TMD=IBO5 0EP=729 ?~ ~ -o~ ~'_oh o ~ B/ W SAK SNDS TVD=1990 TMD=3022 OEP=lB49 ~ ~' ~e ~o ~ 7 5/8" CSG PT TVD=2300 TMD=3815 DEP=2577 ~o~-~, ;,,,,b '~.~5, C80 TMD=2477 TMD=4254 DEP=2992 '~" ~<b" 600 ............... · ~ ~ '~ [SURFACE LOC"~ATION: ] MAXIM U IV! ALN ~L~ ~ ~ I 40' FNL, 675' FEL 6 6.9 3 D E G ~ I sec. ~, T~N, R7E. BEGIN ANGLE DROP TVD=4652 TMD=9816 OEP=8100 ........ ULt. /_.UU oeg per 100 ft 65.26 59.26 TARGET ANGLE T2 - B/ BERMUDA WD=5181 TMD=10831 0EP=8963 ~ C~5 TVD=5208 TMD=1087¢ DEP=S999 v 5 5D EG TD TVD=5321 TMD=II0?4 DEP=9163 i i i i i i i i ! i i i i i i I i i i i i i i i i i i i i i i i i i 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 Vertical Section (feet) -> Azimuth 329.55 with reference 0.00 N, 0.00 E from slot #315 Structure : Tarn Drill Site 2N I 315 lField : Tarn Development Field Location : North Slope, Alaska 160 I ,,~--. 140 120 0 lOO Z <- West (feet) ,, ,,,, 300 '.,, 1600 ,; · 1200 "", ~o ,,,,,,,, .,,,,, 240 \ 2~o "5,,, '"'", , 200 ", '~ 1200 1200 ,, '{ 1400 ; 18O '"\ \ "-,, 2200 1000 '\,,, -. ,oo ',,, "--.. ',, ',,, '.. \\ '.. ~ ooo ,,,, ", ,, ". '~ ~ 000 .' ~ 000 ... . ,,, / '. '.. '"'. '~ 1200 '%.. \\ '"'~o~ '" ~, ; ' 80 '"' ""' ~ ; 800 \',,,\, ", ; .~) ~ 800 800d ,- ~ '"< 800 -' 60 '; 1000 ", ; ',,,,,, / ,200/ ,~ { 000 ~ ',,, ,' ," '-.~oo 003 ~oo ',,,,,,,, \ / .,. .., "° ~~.. ' '"::::'"' 'Oo' e.Oo %° '~ /eoo ,"' ..qo ~.~-,.,,. ~oo "',, ~oo \ ~oo ,,, %0- 2o F3>.. ~ "',, 800 x,,, -,.,,, 1600 ".. 4oo~9'"-.. o .%0o ~.,..,. ~ ~ 2'~'~°° ~ e _ ~ 4od'.,.'+~ ...e ~ ~'oo 20 ~ ",.~oo ~ '"~'~o. ~o"°~e I I I I I I I I I I I [ I I I I I I I I I I I I I I I I I I I I 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 120 140 <- West (feet) 320 300 280 26O 240 220 200 180 160 0 120 100 80 60 ICreo~ed by ie-e, For: T Brassfield] Dote plaited : 14--Sep-§R Caard;nate~ are ;n (eat reference ~at I AR -O Alaska, Inc. .............. Structure : Tarn Drill SUe 2N Well : 315 IField : Torn Development Field Location : North Slope, Alaska <- West (feet) 680 640 600 560 520 4.80 4-40 4.00 360 320 280 2¢0 200 160 120 80 40 920 880 840 800 76O 72O 680 640 600 560. 520 · 480 '"',. 440 400 360 320 i t '; 1600 ', · 2200 ",~ 3000 ',. 2800 2000 ~ scab,,.... -..,. %~ %%% '"" 1400 160~.. 1200 280 1400 16OO 240 ~'*''""'--...~ 2000 200 1600 "'-~.. 2200 · 2000 '\ 1400 · ~ 1400 ""\,,,,\ '\ '"-,~ 2600 \\, · %'%.% \ \ "'"' 240~-. 1200 ". 1200 '-... 12OO 920 880 840 800 760 720 68O 64O 680 640 600 560 520 4~0 440 ~400 West;36° (feet)32° 280 24-0 200 160 12(~ 80 600 '~ - 60O 5~o 520 4-80 160 200 240 '"'",, 320 1600 '~ 280 380 400 I.rCreated by j0~es For: T BrassfieldI Date plotted : 14-qep-g8 Coordinates are in feet reference slat ~15. ~e Ve~ical Oepth~~ RKB (Oaya~ 141)] I~ I Structure: Tarn Drill Site 2N Well : ield : Tarn Development Field Location : North Slope, Alaska West (feet) 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 ,4-00 200 0 , , , , 3400'~ \,, ~; 4400 ',,,,\, , 4000 ;' 4400 '~ 3600 4200 '\,, \, :: '; 3400 "',,, ,,,, 32oo',~ "x,,,,,, 3800 ~,, ~ 4000 ", 4200 ~. 3400 :~00 " \, " ',,, '~ 5000 \\ \ ',,,, ,~6oo '\, ~ :~2oo 36oo 3ooo'., \, ; '., \ 4800 ", 4000 ', · ",, ', 3200 3400 '\,\,, 3400 '\"~ 4600 \\ 3200 28oo'~ ,,, '~ 3o0o ~ 380o '\\\\, 5200 ';\X4400 '~,, .\. \ '\\ 3ooo~i '~ 4200 ,\ "\"' \' " i~ 5600 2600'~ 3000 ',,, 4~00 \',\,,,,, ",.\, ~000 ~,,, 2800 "'-,.. ,,,, '\ ",,, 2600[~, '"., 4000 \ 2800 \ " · ~3~oo \, \i ~4oo ... ., \, \, '". 24o~'. \,,, ",' '- \,,,,,, '\\ -,,.. 3800 ':3600, \,, 2600 "- ,,\,,,,\, 2600 ", 2200 " \ '. ',, · 26o0 2~0'a.. 3'6o0 3400'~ \, 2°00 - 220~'. '\.. ' .. '.,\. 2400320d;;, "\ 2600 "-..... 3400 ,,\, '" "~ 2400 ,800 -.. ....,. \ \. ~6o'~.. 3~oo "., ~2oo \~ooo'\, soo '"-... 3000 '".,, '" 28oct., · \ ,40o ~ ~2oo ".. .~ ", " '~. 2600 ~ 240i . ~% ,,,\,,,, 2000 ,\\ ',. ~200 "~"'"' ~_ ". " 2800 \\ ~ooo ---'.'.'.'."--._._~poo ~22oo '"'.. 2~oo ~o~ 2~o-._ ' ...... 3400 ' ' "\ '"' 26~o---j;Z'LZ.....?oo ~ ~ ~oo "\ 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 <- Wesf (feel) 3000 2800 2600 240O 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 Z 0 - 2600 .-h 2400 -.,,. 22O0 2OOO 1800 1600 1400 1200 1000 800 ITCreated by ja.e~ For: T Brassfield] Oote plotted : 14-Sop-g8 Coordinates ore in feet ref~ce slat ~315. ~e Ve~ical Oepth,~ RK8 (Ooyon 141)./ 7600 7400 720O 7OOO 6800 6600 64O0 6200 A I 6000 5800 5600 5400 5200 5000 4800 4600 4400 IARCO Alaska, Inc. Sfruc[ure : Tarn Drill Site 2N Well : 315 Field : Tarn Developrnenf Ir[eld Location : North Slope, Alaska <- West (feet) : [ ~ I L I I I ! I I · 4600 4400 4200 4000 3800 3600 3400 ,3200 ,:3000 2800 2600 2400 2200 2000 1800 1600 I f I I I I t I ~/~ I I I I I I I I I I I I '\ 5000 'X ,, 4~oo \ 4600 '", '"'""k 5400 \',,,,, 5200 "5 5000 '""- 4800 ",,,,\ 4600 \ 3600 '~,\,., 4400 5400 "~ \ 4800 ~ 4800 \ \ ~ 4400 '\ \ · ~ 4200 4000 \ \ % 3800 · \ \ 36ao 4200 '\ '\ 4400 '~ "'",,,,,,, 4200 "~, 4000 4000 ~,. 3200 '% 3800 ',,,, 3800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 <- West (feet) 7600 7400 72O0 7000 6800 660O 6400 6200 6000 I 5800 5600 5400 5200 5OO0 '~800 4600 440O 4200 4000 3800 Z ARCO Alaska, Inc. Tarn Drill Site 2N 315 slot #315 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE Bake~ Mu~hes INTEQ REPORT Your ref : 315 Version #5 Our ref = prop3126 License : Date printed : 14-Sep-98 Date created : 1-Sep-98 Last revised = 13-Sep-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n?0 10 13.563,w150 18 52.338 Slot Grid coordinates are N 5911966.928, E 460917.806 Slot local coordinates are 39.83 S 675.38 W Projection type: alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Object wellpath PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <O-9134'>,,313,Tarn Drill Site 2N · PMSS <O-?431'>,,345,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <O-8239~>,,339,Tarn Drill SiCe 2N PMSS <O-9690~>,,329,Tarn Drill Site 2N PMSS <O-9631'>,,343,Tarn Drill Site 2N PMSS <O-10655~>,,337,Tarn Drill Site 2N PMSS <7090-10245'~,,337A,Tarn Drill Site 2N PMSS <O-11225~>,,331,Tarn Drill Site 2N PMSS <O-11526'>,,321,Tarn Drill Site 2N PMSS ¢5286-10028~>,,321A,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 14-Aug-98 28.7 450.0 450.0 4-Aug-98 29.3 350.0 350.0 21-Jul-98 439.1 675.0 675.0 15-Jul-98 389.4 450.0 450.0 23-Jul-98 120.2 0.0 0.0 1-Ju~-98 354.4 500.0 500.0 28-May-98 198.5 675.0 675.0 28-May-98 416.9 425.0 425.0 18-Jun-98 32~.8 450.0 450.0 29-Jul-98 327.8 450.0 450.0 10-Sep-98 240.0 200.0 200.0 25-Aug-98 90.3 100.0 1125.0 31-Aug-98 90.3 100.0 8360.0 ARCO Alaska, Inc. Diverter Schematic Doyon 141 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline I I I 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator DSA 13-5/8" 5,000 psi x 11" 3,000 psi W P 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE _ __ ~/hydraulic actuator ~ CHOKE LINE 13-5/8" 5,000 psi WP L_~'~~ DRILLING SPOOL w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. -~.- Post Office Box 100360 Anchorage, Alaska 99510-0360 September 15, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-315 Surface Location: 41' FNL 67'5' FEI_ Sec 3 TgN R?E, MM Target Location: 2329' FSI_, 107' FWI_ Sec. 27, T10N, RTE, UM Bottom Hole Location: 2580' FSL, 37" FEL Sec. 28, T10N, FITE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-315, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johnstu-¢~ Application for Permit to Drill Page 2 KRU 2N-315 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-315 Well File -'~ ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 315 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. , Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(0). o Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. .... ARCO Alaska, Inc. '--~ DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 315 Drillincl Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-1 O.2 ppg 15-35 25-50 70-120' Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 _+10% 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Degasser *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: ARCO Alaska, Inc. The nearest well to 2N-315 is 2N-317. The wells are 28,7' from each other at a depth of 450'. Drilling Area Risks: The primary risk in the 2N 315 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9,6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 315 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2N 315 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi ARCO Alaska, Inc. --- This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 51/2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3½" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). Creoted by jones For: T Brassfield[ Oote plotted : 14--Sep--98 Pict Reference is 315 Version ~5, Ccord;notee ore in fee{ reference True Ve~cel Depths~ ARCO Alaska, ~DC. Structure : Tarn Drill Site 2N Well ; 515 Field : Torn Development Field Location : North Slope, Alaska <- West (feet) 4800 4200 .3600 .3000 2400 1800 1200 600 0 600 I f ~ I[ ~ ? I f ~I I I ~~ t I ~~ 8400 TO LOCATION · : -TO - Comng Pt I 2580' FSL, 37' FELI C55~.~.1~2 - Bose Bermudo - 7800 SEC. 28, TION, R7E T4~k~'~RGETk~T - Mid Bermudo I I .3 - Top Bermudo End Angle Drop~ 7200 ~ Iceberg Inte~ol % Begin Angle Drop TARG~ LOCATION: ~' ~s~, ,o~' ~w~ ~ ~oo I SEC. 27I TI ON, RTEI - TARGET WO=5~ 18 TMB=10721 ~ 6000 OEP=8875 NORTH 7649 ~C40 WEST 4497 ~ F5400 329.55 AZIMUTH~ 8873' (TO TARGET) ~ ~oo 3000 600 2400 7 5/8 Cosing Pt ~ RKB ELEVATION: 149' ~ 1800 0 ~ 1 50KOP WD=250 TMD=250 OEP= Bo~ ~s~ ~n~ 0 Bose West SoK Sonds ~ 750 DES: 3.00 deg per 100 ft ~ ~ 1200 ~ 52 40 BEGI~ TURN TO TARG~ WD=1021 TMD=lO5~EP=177 % I ~ '42 11 B/ PERMAFROST ~D=1199 TMB=1269 DEP=301 % EOC P 800 1200 ~ '51 92 T/ WEST SAK SNDS WD=124~MD=1328 DEP=541 ~ ! ~ ' 66.70 EOC WD=lS13 TMO=1805 DEP~29 __~s~ ~ moo ~ . ~o*. ~s, ~o~ ~e % F o ~ a/ w SAK SNDS WO=lggo TM0=3022 DEP=184g 6~e°_'~o _¢ I ~ ~os ~' ~ r 5/8" CSO PT WO=2300 TM0=5813 OEP=2577 6a'o ¢ L 'TM0=2477 TM0=4264 DEP=2992 ~ ' ~o~ MAXIMUM ANGLE e~'~* ~[~o. ~. ~o~,~o~:~s. 66.93 DEG ~ I sec. 3. T9N, R7E 3600 C40 ~D=3936 TMD=7988 BEP=6418 4200 2 00 do~ per ~5.26 4800 59.26 IAKUbi AINUL~ TX - e/ BERMUDA ~0=5~81 TMD=~085~ UaP=aa6a C35 ~0=5206 TMD=1087¢ DEP=8999 54oo 5 5 D E G TD ~=5321 TMD=l1074 DEP=9163 6000 i i i i i i i i i i i i I t i i i i i i i i i I I I I t I ; ~ I I 600 0 600 1200 1800 2400 5000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 Verficol Section (feet) -> Azimuth 329.55 with reference 0.00 N, 0.00 E from slot ~515 Created by io.eaFor: T Bras.afield ~ote plotted : t4-Sep-g8 Plot Reference ~.~ 315 V~r~on ~5. I Coordinotcs or~ ~n feet r~f~rence slot ~315. IA_lq'CO Alaska, Inc. Structure : Tarn Drill Site 2N Wall : 515 Field : Tarn Development Field Location : North Slope, Alaska <- West (feet) 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 120 140 320 ' '(~ ' ' ' ' ' ' '~' ' ' ' ' ~,,, ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' 8~' 320 300 ~ ",,,, l eOO ",; i 300 280 '"' '\ i 280 260 ] 260 24O i 240 220 i 220 ~ ",, ~ 200 1200200 ~°°' k ~ ", 1~oo ", 180 i 180 0 ".,,,,.,.,~,: 000~ ",, "~1000 :1000 r ~'~ ""', '"', ~ '"~ ~ 200 ~.oo 80 1200~,.:::,.,,.. k '" '" ,,~ · ~,,.:,,,,~,,,.,. v°° ,, ',, ,,,' ~o ~o ~ _ \ '"woo \ ',.,ooo .,,,~oo ~o,o,/' ;,"' .~.1~o? \ %. \ , , ;' 1:oo/ '~-~.~ \ '.~.. . ",, ',,, 4o '.., ,0005 '%,. \ ,, ',, ;;,,,' ...',.ooo~ o \ a..'::.... ,:,oo o -~oo % '"',. /_ e "%. o _ % 4oo",.'*~ ,. 6~ -¢' °o % -...,,oo -- "e "-~ '¥"...., h~ e ~'°° 160 14-0 120 --i.- L 0 1 O0 Z 2o 6O I I I I I I I I I t I I I I I I t I I I I I , I t I i I I 4O 6O 160 140 120 1(30 80 60 40 20 0 2(3 40 60 80 100 120 140 <- West (feet) C~e~teO W io~es For: T BrassfieldI Oot8 plotted : PIO~ Reference ts ..~15 Version ~5. Co,rd;nates are ~n feet reference slot ~15. True Ve~cal Depth~~ RKB (Oa~on 141~. AR OO Alaska, Inc. Location : North Slope, Alaska <- West (feet) 680 64-0 600 560 520 480 4-40 400 360 320 280 24-0 200 160 120 80 40 I I I ~I ~ I ~ ~ I I I ~ I I ~ I ~_~ I I I I ~-J~ I I I I ~ 1 , i ~ i 920 920 8¢0880 ""',,,,,,,,,,,,,,, '", '", . \\'""'"\"",,,,,,,, 2200 ""',\,\\ \'"' /[840 880 800 '"'"',.,,,o ,,,,,,\,\,,,,,,, . ,,,,,,;\,,,,,, [ ~oo 560 520 ........ 480 ,,,,.,,. 400 \'\, 1 "-....,. %- ",,,,, \ ,,,, ooo,,, 400 4-0O 320 ~ 320 280 "~ -280 240 -~ - 240 / 200 -~ ...... ' ......... '",. ~ 200 "'-., ........ ' ...... ~ 406'% ".. 680 64(3 60a 560 520 480 440 400 360 320 280 240 20a 160 12(~-k 80 ~0 <- Wesf (feot) Z 4400 4200 4000 3800 3600 3400 3200 3000 I ,~. 2~00 ',-i-- ~ 2600 '" 0 2400 z ARCO Alaska, Inc. ' f~f~' ' ' ' ' i 4600 4400 ~4200 f4000 ~ 3800 3600 ? 3400 Structure : Torn DHll SHe 2N Well : 315 Field : Torn Development Field Location : North Slope, Alaska rCreoted by jones For: T Brassfield Dote plotted : 14-sep-98 Plot Reference ;e .t15 Version j~5. Coord;notes ore in feet reference spot ~1,]15. J True Verticoi Oepths~ere reference RKB (Doyon 141). <- West (feet) 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 4600 II II ~ I I I f II I I I '"'",, O0 '", 4400 ~ 3600 o ~ "~ 3200'"k,,xx, ~ 4200~ 3400,, 'x % 3600 " '" 3200 ' ',, %, ~ ~oo;'~ ~ ", ~ X~ooo ~ 4800 ,, ",~ ~ 3~oo i,, i, ~, ;200 ,, ',~ 3000"' , %~ 4200 % 4200 '"X ~ ',,4000 ~,2800 J~ i ... =~oo~ '-... ,ooo .,.. ~oo ,,;~oo ~ '..".'. 2400'~,,., ,% , %, 5800 ~600 ',~ 2600 ... ,, , "- '" 2600 x,k, 280o~ I '- '. k , h=~oo 28~ 3600 '"',, -~ · , ;4oo'~ k ?,~ -,, k X ~ k 2ooo 2000 220~ , ,, ,, ",,, 2400 ',, , " ~4oo 52o~ 2600 '-..,. ,,,,,,,, k , 1800 " , '~ 2400 ~ 1800 -.. 5200 '"%. 2200 '~?000~ 1600 ~ ~ 200~A ' 5 1 60O 800 '"-. ~000 280Ut ,... ,,,. ,, '~ i%- ,, ~ "-. 2600 '" ' 600 k,,,,,,, ~2ooo, Fl 180 2400 ", "¢2~ J h 80o ! 3200 3000 2800 2600 2400 220~ 2000 1800 1600 1400 1200 1000 800 600 400 200 0 <- West (feet) Created by jones FOI': T Brassfield Dote plotted : 14-Sep-g8 .~lot Reference is 315 Ve~ion ~5. Coordinotes ore in feet reference slot ~315. True Ve~icol Depths ore reference RKB (Oo~on 7600 7400 72O0 70O0 6800 6600 6400 6200 6000 5800 C- 5600 0 Z 5400 5200 50aa 4800 4600 4400 4200 4OOO 3800 ARCO Alaska, Inc. JStructure : Tarn Drill Site 2N Well : 315 JField : Tarn Development Field Location : North Slope, Alaska <- West (feet) 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 5000",, ', 4800 '~ ', · 4600'; 4400 % 4800 \, \ \ '~, 4600 -\ · · ~ 4400 \, 4200 '~, \ ~ ¢200 '"',,, 5400 '\ \ \ '", 5200 5000 '~ 4000 4800 \" \ 3800 ~ \ \ 4600 \ 3800 · 3600"'~ 4400 "~ 3600 4200 ,,, k,,,, 4000 3200".,,,,, 3800 · 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 <- Wesf (feel) 76OO 7400 7200 7000 680O 6600 6400 6200 A 6ooo I 5800 - 5600 540O 5200 5000 4800 4600 4400 4200 4000 3800 ARCO Alaska, Inc. Tarn Drill Site 2N 315 slot #315 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Bake~ Hughes INTEQ Your ref : 315 Version #5 Our ref : prop3126 License : Date printed : 14-Sep-98 Date created : 1-Sep-98 Last revised : 13-Sepo98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is nT0 10 13.563,w150 18 52.338 Slot Grid coordinates are N 5911966.928, E 460917.806 Slot local coordinates are 39.83 S 675.38 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-8500 PMSS <0-9134 · PMSS <0-7431 PMSS <0-12339 PMSS <0-9553 PMSS <0-8239 PMSS <0-9690 PMSS <0-9631 >,,317,Tarn Drill Site 2N >,,313,Tarn Drill Site 2N >,,345,Tarn Drill Site 2N >,,341,Tarn Drill Site 2N >,,323,Tarn Drill Site 2N >,,339,Tarn Drill Site 2N >,,329,Tarn Drill Site 2N >,,343,Tarn Drill Site 2N PMSS <O-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'~,,337A,Tarn Drill Site 2N PMSS <O-11225'>,,331,Tarn Drill Site 2N PMSS <0-11526'>,,321,Tarn Drill Site 2N PMSS <5286-10028'>,,32IA,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 14-Aug-98 28.7 450 4-Aug-98 29.3 350 21-Jul-98 439.1 675 15-Jul-98 389.4 450 23-Jul-98 120.2 0 1-Jun-98 354.4 500 28-May-98 198.5 675 28-May-98 416.9 425 18-Jttn-98 327.8 450 29-Jul-98 327.8 450 10-Sep-98 240.0 200 25-Aug-98 90.3 100 31-Aug-98 90.3 100 .0 450.0 0 350.0 0 675.0 0 450.0 0 0.0 0 500.0 0 675.0 0 425.0 0 450.0 0 450.0 0 200.0 0 1125.0 0 8360.0 ARCO Alaska, Inc. Diverter Schematic Doyon 141 Flowline 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS / 1 I I 3" 5,000 psi WP OCT MANUAL GATE V KILL LINE L 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / 1 / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE _ __ ~(/hydraulic actuator 13-5/8" 5,000 psi WP L__~ ~ DRILLING SPOOL w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams WELL PERMIT CHECKLIST COMPANY /~__,¢5~__,~j __ INIT CLASS ,,~_. /'-~,~/' ADMINISTRATION ..R DATE. WELL NAME/'~/' ~ -,~,/",~ PROGRAM: exp [] dev~)~' redrll [] serv [] wellbore seg II ann. disposal para req AREA o~"~d"j [JNIT# //_//' ~ ~_) ON/OFF SHORE __C3~. ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie4n long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. GEOL N N N N N N N N N N N N N 21. If a re-drill, has a 10~403 for abandonment been approved. GEOLOGY Ft i)A'rg ,. 7////¢¢ ANNULAR DISPOSAL 35. APPR [;)ATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ..... (B) will not contaminate freshwater; or cause drilling waste. to surface; (C) will not irnpair mechanical integrity of the well used for di (r)) will not damage producing formation or impair recovery f~ pool; and (E,) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. G__EOIA)G.Y: ENGINEERING: UIC/Annular COMMI,~ · ~ 13 " __ JDH~ RNC co ~ 22. Adequate wellbore separation proposed ............. (~ N 23. If diveder required, does it meet regulations . . .. ....... ~ ~N 24. Drilling fluid program schematic & equip list adequate ..... ~)N 25 BOPEs, do they meet regulation ................ ~ I N 26, BOPE press rating appropriate; test to ~O~(5 psig. t~IN ...................................................................................................................................................................... 27, Choke manifold complies w/APl RP-53 (May 84) ........ ~(,~N 28, Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y 3Q Permit can be issued WIG hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ..... ' ........ 33. Seabed condition survey (if off-shore) ............. / Y N 34. Contact na~e/phon~ ~or weekly progress reports ....... Y N...__.~ , ,, . [explorato~ only] ...................... M:cheldist u:;v 0,5/29/98 o..,, ~,-,: .... ~ T,~: ..... ,, ~," ~'~,v.- Please note that any disposal of fluids generated from this ~illing operation which are pumped d~ the surhce/production casing annulus of a well approved for annular disposal on Drill Site ~ must comply with the requirements ~d limitations of 20 ~C 25.080. Approval of this pemit to &ill does not authorize disposal of &illing waste in a volume greater th~ 35,000 b~els t~ough the a~ular space of a single well or for a period longer than one year. 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundaly .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15*day wait ........... Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Dec 21 10:39:53 1998 Reel Header Service name ............. LISTPE Date ..................... 98/12/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/12/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-80384 K. FERGUSON D. BURLY 2N-315 501032027000 SPERRY-SUN DRILLING SERVICES 21-DEC-98 3 9N 07E 41 675 148.80 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 3804.0 6.750 11197.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMFLA P-AY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATE THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 4. THE MD SECTION 10670'MD, 5092'TVD TO ll197'MD, 5373'TVD WAS CONTROL-DRILLED AT 100'/HR FOR NUCLEAR LOG QUALITY. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL FROM D. SCHWARTZ FOR D. HASTINGS OF ARCO ALASKA, INC. ON 10/22/98. THIS DATA IS CONSIDERED PDC. 6. MWD RUN 2 REPRESENTS WELL 2N-315 WITH API#: 50-103-20270-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF ll197'MD, 5373'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (BEST BIN). SC02 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 9.1 TO 9.9 PPG MUD SALINITY: 350-500 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY; 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START PEF 3752 GR 3761 FET 3768 RPD 3768 RPM 3768 RPS 3768 RPX 3768 DRHO 3775 RHOB 3775 FCNT 3812 NCNT 3812 NPHI 3812 ROP 3855 $ BASELINE CURVE FOR SHIFTS: .5000 DEPTH 5 5 5 5 5 5 5 .0 .0 .0 .0 .0 .0 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: all bit runs merged. STOP DEPTH 11090.5 11103.5 11110.5 11110.5 11110.5 11110.5 11110.5 11090.5 11090.5 11075.0 11075.0 11075.0 11197.0 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 3815.0 11197.0 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD API 4 1 ROP MWD FT/H 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 FET MWD HOUR 4 1 NPHI MWD P.U. 4 1 NCNT MWD CNTS 4 1 FCNT MWD CNTS 4 1 RHOB MWD G/CC 4 1 DRHO MWD G/CC 4 1 PEF MWD BA3~N 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Min Max Mean DEPT 3752.5 11197 7474.75 GR 22.7683 227.467 116.962 ROP 0.06 1541.18 252.438 RPX 0.05 53.01 4.68703 RPS 1.31 47.98 4.83103 RPM 0.87 2000 14.8757 RPD 0.1 2000 6.26598 FET 0.35 48.7 1.38364 NPHI 8.91 55.09 38.859 NCNT 18384 43969 24870.6 FCNT 150.21 1171.11 228.32 RHOB 0.8 4.56 2.34005 DRHO -1.56 2.2 0.115513 PEF 0.08 12.52 2.20977 First Last Nsam Reading Reading 14890 3752.5 11197 14685 3761.5 11103.5 14685 3855 11197 14685 3768.5 11110.5 14685 3768.5 11110.5 14685 3768.5 11110.5 14685 3768.5 11110.5 14685 3768.5 11110.5 14505 3812 11075 14527 3812 11075 14505 3812 11075 14606 3775 11090.5 14606 3775 11090.5 14677 3752.5 11090.5 First Reading For Entire File .......... 3752.5 Last Reading For Entire File ........... 11197 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMNLARY VENDOR TOOL CODE START DEPTH PEF GR FET RPD RPM RPS RPX RHOB DRHO FCNT NCNT NPHI ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 3652 5 3761 5 3768 5 3768 5 3768 5 3768 5 3768 5 3775.0 3775.0 3812.0 3812.0 3812.0 3855.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11090.5 11003.5 11110.5 11110.5 11110.5 11110.5 11110.5 11090.5 11090.5 11075.0 11075.0 11075.0 11197.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA R3~Y EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA 27-SEP-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.87 MEMORY 11197.0 3815.0 11197.0 54.3 69.4 TOOL NUMBER P1087GRM4 P1087GRM4 P1087GRM4 P1087GRM4 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL FLATRIX: NDATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.750 6.8 LSND 9.80 46.0 10.0 550 4.0 2.900 1.780 3.600 4.000 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 46.1 Name Min Max Mean Nsam DEPT 3752.5 11197 7474.75 14890 ROP 0.06 1541.18 252.438 14685 GR 22.7683 227.467 116.962 14685 RPX 0.05 53.01 4.68703 14685 RPS 1.31 47.98 4.83103 14685 RPM 0.87 2000 14.8757 14685 RPD 0.1 2000 6.26598 14685 FET 0.35 48.7 1.38364 14685 NPHI 8.91 55.09 38.859 14505 FCNT 150.21 1171.11 228.32 14505 NCNT 18384 43969 24870.6 14527 RHOB 0.8 4.56 2.34005 14606 DRHO -1.56 2.2 0.115513 14606 PEF 0.08 12.52 2.20977 14677 First Reading 3752.5 3855 3761.5 3768.5 3768.5 3768.5 3768.5 3768.5 3812 3812 3812 3775 3775 3752.5 Last Reading 11197 11197 11103 5 11110 5 11110 5 11110 5 11110 5 11110 5 11075 11075 11075 11090.5 11090.5 11090.5 First Reading For Entire File .......... 3752.5 Last Reading For Entire File ........... 11197 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/12/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/12/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File