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210-113
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9380'feet 7093', 7123'feet true vertical 6093' feet 7188', 7221'feet Effective Depth measured 7045'feet N/A feet true vertical 5757'feet N/A feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 3-1/2" L-80 L-80 6975' 7268' 5702' 5933' 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:Kuparuk 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: Contact Name: Contact Email: Contact Phone: 3821'3305' Burst Collapse Production Liner 7747' Casing 6113'7786' 9380'6093' 3782' 121'Conductor Surface 16" 7-5/8" 81' measured TVD 5-1/2" x 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 187-067 50-029-22691-01-00 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: ADL0025631, ADL0025632 Kuparuk River Field/ Kuparuk Oil Pool KRU 3A-17A Plugs Junk measured Length 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 121' Well Shut-In 325-142 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: None SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049 Authorized Name and Digital Signature with Date: Authorized Title: RWO/CTD Engineer 8019-9379' 6100-6093' 1370'2-3/8" 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 2:07 pm, Jun 02, 2025 DSR-6/3/25JJL 6/30/25 210-113 JSB RBDMS JSB 061825 Page 1/21 3A-17 Report Printed: 5/30/2025 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) 4/8/2025 00:00 4/8/2025 01:00 1.00 MIRU, MOVE MOB P Pull mats off of 3M load, and send to 3A. Pick up and secure location. 0.0 0.0 4/8/2025 01:00 4/8/2025 04:30 3.50 MIRU, MOVE MOB P Drive sub, and pits from 3M to 3A. 0.0 0.0 4/8/2025 04:30 4/8/2025 06:00 1.50 MIRU, MOVE MOB P Hang tree in cellar, lay herculite around well. place well head equipment behind 3A-17. Remove jeep from the pits. 0.0 0.0 4/8/2025 06:00 4/8/2025 07:30 1.50 MIRU, MOVE MOB P Spot sub over 3A-17. Set rig mats and shim sub. Spot pit mod into sub base, set mats and shim pits. 0.0 0.0 4/8/2025 07:30 4/8/2025 08:30 1.00 MIRU, MOVE MOB P Raise derrick and pin to A-legs. Raise cattle chute and pin in place. 0.0 0.0 4/8/2025 08:30 4/8/2025 10:30 2.00 MIRU, MOVE MOB P Hook blocks onto top drive and rig down bridal lines. M/U stand pipe to mud manifold. 0.0 0.0 4/8/2025 10:30 4/8/2025 12:00 1.50 MIRU, MOVE MOB P Rig crew complete rig acceptance checklist. 0.0 0.0 4/8/2025 12:00 4/8/2025 14:00 2.00 MIRU, MOVE KLWL P Rig accept at 12:00. Take on fluids to the pits. Initial pressures T/IA/OA 500/100/100 0.0 0.0 4/8/2025 14:00 4/8/2025 16:00 2.00 MIRU, WELCTL KLWL P PJSM. Line up on tubing and bleed free gas. Shut in tubing, line up on IA and bleed free gas. Pump 290 BBLs sea water @ 4 BBL min, ICP: 2000 PSI, FCP 1700 PSI. 0.0 0.0 4/8/2025 16:00 4/8/2025 17:00 1.00 MIRU, WELCTL OWFF P Shut in well blow down lines from cellar to tiger tank. OWFF in the cellar: Pencil width flow, would not stop. 0.0 0.0 4/8/2025 17:00 4/8/2025 18:30 1.50 MIRU, WELCTL COND P Consult town for mud weight moving forward. Cut weight in the pits F/ 12.0 PPG to 11.4 PPG. 0.0 0.0 4/8/2025 18:30 4/8/2025 20:00 1.50 MIRU, WELCTL CIRC P Circulate in 11.4 PPG NaCl NaBr. @ 4 BBL/ min @ 420 PSI ICP, 995 PSI FCP. 0 losses 0 gains while pumping. 0.0 0.0 4/8/2025 20:00 4/8/2025 21:00 1.00 MIRU, WELCTL OWFF P Observe flow stop out to tiger tank. Blow down lines. OWFF in the cellar 30 min: Static. 0.0 0.0 4/8/2025 21:00 4/8/2025 21:30 0.50 MIRU, WHDBOP MPSP T FMC attempt to set CIW BPV. Would not set. Pull back to rig floor, inspect clean, and attempt to set BPV 2nd time. FMC rep checked paper work. 0.0 0.0 4/8/2025 21:30 4/8/2025 22:30 1.00 MIRU, WHDBOP WAIT T FMC Rep go to KIC valve shop to get correct ISA BPV. 0.0 0.0 4/8/2025 22:30 4/9/2025 00:00 1.50 MIRU, WHDBOP MPSP P FMC set ISA BPV. Perform 1000 psi rolling test to BPV for 10 min. Good test. 0.0 0.0 4/9/2025 00:00 4/9/2025 01:00 1.00 MIRU, WHDBOP NUND P Inspect hanger threads and install blanking sub. 0.0 0.0 4/9/2025 01:00 4/9/2025 03:30 2.50 MIRU, WHDBOP NUND P Install DSA and TQ flanges to spec. Obtain RKBS. Install riser & turnbuckles. 0.0 0.0 4/9/2025 03:30 4/9/2025 05:30 2.00 MIRU, WHDBOP RURD P M/U 3.5", and 2 7/8" Test joints. R/U test lines, and equipment, fill stack, and purge lines. 0.0 0.0 4/9/2025 05:30 4/9/2025 06:00 0.50 MIRU, WHDBOP BOPE P Shell test BOP's 250 low, 3500 PSI high. 0.0 0.0 4/9/2025 06:00 4/9/2025 08:00 2.00 MIRU, WHDBOP WAIT P Wait on AOGCC Rep to arrive. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 2/21 3A-17 Report Printed: 5/30/2025 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) 4/9/2025 08:00 4/9/2025 16:30 8.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular to 3500PSI on 2-7/8" and 3-1/2" test joint, UVBR's, LVBR's w/2-7/8" and 3-1/2" test joint. Test #1) Blind Rams, CMV 1-2-3-16, RIg Floor Kill, Outer Test Spool Valve, IBOP. Test #2) Blind Rams, CMV 4-5-6, HCR Kill, Inner Test Spool Valve, Manual IBOP (Open CMV 2, Inner Test Spool Valve, Rig Floor Kill, Upper IBOP). PU 3.5" Donut Test Joint w/HT-38 TIW Test #3) LPR, HT-38 TIW, Test #4) Annular (3,500 psi), CMV 7-8- 9, Manual Kill, Test #5) Hydraulic Super Choke and Manual Adjustable Choke (1,500 PSI Test). Test #6) UPR, CMV 10-11 PU 2-7/8" Donut Test Joint w/3.5" EUE FOSV, Test #7) Annular (3.500 psi), CMV 12-13 -15, 2-7/8" Pac TIW, 3.5" FOSV. Test #8) UPR, CMV 14,2-7/8" Pac Dart Test #9) HCR Choke. Test #10) Manual Choke. Hydraulic accumulator test. Initial pressure=3050 PSI, after closure=1700 PSI, 200 PSI attained =11 sec, Full recovery attained = 117 sec. UVBR's= 6 sec, Annular= 25 sec. Simulated blinds= 6 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2130 PSI. Test gas detectors, PVT and flow show. Test Witnessed by AOGCC rep Guy Cook 0.0 0.0 4/9/2025 16:30 4/9/2025 17:00 0.50 MIRU, WHDBOP BOPE P R/D test equipment blow down lines. 0.0 0.0 4/9/2025 17:00 4/9/2025 18:00 1.00 COMPZN, RPCOMP MPSP P Pull BPV as per FMC rep. 0.0 0.0 4/9/2025 18:00 4/9/2025 22:00 4.00 COMPZN, RPCOMP RURD P RU to pull 3.5" completion. MU landing joint to tubing hanger. BOLDS. Unseat hanger. UWT 80K/DWT 65K. CIRC BU at 2BPM / 380 psi. OWFF 10 min. LD landing joint/hanger. CU BU 2BPM / 270 psi. OWFF 10 min. 6,740.0 6,682.0 4/9/2025 22:00 4/9/2025 23:00 1.00 COMPZN, RPCOMP OWFF P Open well for flow and monitor for 30 min. No flow. 6,682.0 6,682.0 4/9/2025 23:00 4/9/2025 23:30 0.50 COMPZN, RPCOMP PULL P POOH F/6682' T/6140' UWT 85K/DWT 65K. 6,682.0 6,140.0 4/9/2025 23:30 4/10/2025 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig, grease tongs. 6,140.0 6,140.0 4/10/2025 00:00 4/10/2025 05:30 5.50 COMPZN, RPCOMP PULL P POOH F/6140' Laying down 9.3# EUE tubing. 206 joints, 4 GLMS, 1 X Nipple, and on2 2.72' cut joint recovered from the well. PUWT 85K SOWT 65K. 6,140.0 0.0 4/10/2025 05:30 4/10/2025 06:00 0.50 COMPZN, WELLPR OTHR P Install wear bushing. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 3/21 3A-17 Report Printed: 5/30/2025 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) 4/10/2025 06:00 4/10/2025 07:00 1.00 COMPZN, WELLPR OTHR P Set up racking area, and secure tubing racked back in the derrick. Mobilize BHA components to the rig floor. 0.0 0.0 4/10/2025 07:00 4/10/2025 08:00 1.00 COMPZN, WELLPR BHAH P P/U Fishing BHA F/ surface to 214'. 0.0 214.0 4/10/2025 08:00 4/10/2025 14:00 6.00 COMPZN, WELLPR PULD P RIH F/ 214' to 6653' picking up singles of 2 7/8" HT Pac DP. PUWT: 100 K SOWT: 68 K 214.0 6,653.0 4/10/2025 14:00 4/10/2025 15:00 1.00 COMPZN, WELLPR CIRC P CBU @ 2.5 BBL/ Min @ 2000 PSI 6,653.0 6,653.0 4/10/2025 15:00 4/10/2025 18:00 3.00 COMPZN, WELLPR JAR P P/U 3 more joints of 2 7/8" Drill pipe. Wash down and tag top of fish @ 6729'. Cont to slack off to 6731' and fully swallow fish. Pull 20K over and allow jars to bleed. Cock jars and fire pulling up to 227 K Straight pulling F/ 234K to 275K, Total hits 111. 6,653.0 6,731.0 4/10/2025 18:00 4/10/2025 18:30 0.50 COMPZN, WELLPR JAR P Perform a post jarring inspection. 6,731.0 6,731.0 4/10/2025 18:30 4/10/2025 23:30 5.00 COMPZN, WELLPR JAR P Jarring per Baker Rep. UWT 100K/DWT 60K/ROT WT 80K. Set off jars at 193K and straight pull 270K. Pulled about 4.5' of seals out of seal bore. 6,731.0 6,726.5 4/10/2025 23:30 4/11/2025 00:00 0.50 COMPZN, WELLPR SVRG P Grease rig floor equipment. 6,726.5 6,726.5 4/11/2025 00:00 4/11/2025 00:30 0.50 COMPZN, WELLPR JAR P Perform derrick inspection. 6,726.5 6,726.5 4/11/2025 00:30 4/11/2025 02:30 2.00 COMPZN, WELLPR JAR P Jarring per Baker Rep. UWT 100K/DWT 60K/ROT WT 80K. Set off jars at 193K and straight pull 296K. 401 total jar licks and jars are starting to fail and no progress made in 2 hours. 6,726.5 6,726.5 4/11/2025 02:30 4/11/2025 03:00 0.50 COMPZN, WELLPR JAR P Release off fish. 6,726.5 6,690.0 4/11/2025 03:00 4/11/2025 04:00 1.00 COMPZN, WELLPR CIRC P Circulate a bottoms up. Open well for flow. 6,690.0 6,690.0 4/11/2025 04:00 4/11/2025 08:00 4.00 COMPZN, WELLPR TRIP P POOH F/ 6690' to 212' 6,690.0 212.0 4/11/2025 08:00 4/11/2025 09:30 1.50 COMPZN, WELLPR BHAH P L/D BHA #1 (Fishing BHA) F/ 212 to surface. 212.0 0.0 4/11/2025 09:30 4/11/2025 10:00 0.50 COMPZN, WELLPR SVRG P Service, and inspect rig floor equipment and top drive. 0.0 0.0 4/11/2025 10:00 4/11/2025 11:00 1.00 COMPZN, WELLPR SFTY P Rig crew inspect crown cluster, and derrick for post jaring opperations. while waiting on equipment to arrive from dead horse. 0.0 0.0 4/11/2025 11:00 4/11/2025 12:00 1.00 COMPZN, WELLPR WAIT P Rig crew continue w/ maintenance tasks and house keeping through out the rig while waiting for new set of 3 1/8" Jars. 0.0 0.0 4/11/2025 12:00 4/11/2025 13:30 1.50 COMPZN, WELLPR BHAH P P/U BHA # 2 (Fishing BHA w/ longer catch overshot, and new jars) F/ surface to 216'. 0.0 216.0 4/11/2025 13:30 4/11/2025 16:00 2.50 COMPZN, WELLPR TRIP P TIH F/ 216' to 6720' PUWT: 100K SOWT: 68K 216.0 6,720.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 4/21 3A-17 Report Printed: 5/30/2025 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) 4/11/2025 16:00 4/11/2025 17:00 1.00 COMPZN, WELLPR CIRC P Lube up the system to 1%, SxS at BPM/2100 psi 6,720.0 6,720.0 4/11/2025 17:00 4/11/2025 22:30 5.50 COMPZN, WELLPR JAR P Engage overshot at 6728', bleed jars at 140K stage up 193K straight pull to 296K. 6,720.0 6,728.0 4/11/2025 22:30 4/11/2025 23:00 0.50 COMPZN, WELLPR JAR P Perform derrick inspection. 6,728.0 6,728.0 4/11/2025 23:00 4/11/2025 23:30 0.50 COMPZN, WELLPR JAR P As per BOT rep set jars off at 193K, and straight pull to 296K. Total licks 293. 6,728.0 6,728.0 4/11/2025 23:30 4/12/2025 00:00 0.50 COMPZN, WELLPR SVRG P Grease the crow, DW and TBG tongs. 6,728.0 6,728.0 4/12/2025 00:00 4/12/2025 00:30 0.50 COMPZN, WELLPR JAR P Release F/fish as per BOT rep 6,728.0 6,650.0 4/12/2025 00:30 4/12/2025 01:30 1.00 COMPZN, WELLPR CIRC P Circulate a BU 2BPM at 1100 PSI. OWFF for 10 minutes: Static. 6,650.0 6,650.0 4/12/2025 01:30 4/12/2025 05:30 4.00 COMPZN, WELLPR TRIP P POOH F/ 6650' to 216' standing back DP in derrick. 6,650.0 216.0 4/12/2025 05:30 4/12/2025 06:30 1.00 COMPZN, WELLPR BHAH P L/D BHA F/ 216' to surface. 216.0 0.0 4/12/2025 06:30 4/12/2025 07:00 0.50 COMPZN, WELLPR CLEN P Clean and clear rig floor. R/U Handling equipment for running in w/ 3.5" EUE work string. 0.0 0.0 4/12/2025 07:00 4/12/2025 07:30 0.50 COMPZN, WELLPR BHAH P M/U gutted over shot to bottom of first joint of tubing. 0.0 0.0 4/12/2025 07:30 4/12/2025 13:30 6.00 COMPZN, WELLPR PULD P RIH P/U 3.5" 9.3# EUE work string F/ surface to 6711'. 0.0 6,711.0 4/12/2025 13:30 4/12/2025 14:30 1.00 COMPZN, WELLPR ELNE P Space out string and R/U YJOS E-line. YJOS E-line M/U Tool string and surface test. 6,711.0 6,729.0 4/12/2025 14:30 4/12/2025 17:00 2.50 COMPZN, WELLPR ELNE P YJOS RIH W/ 2" RCT, centralizers wt bars, and CCL F/ Surface to 6800'. CCL able to locate collars on down stroke, but unable to locate collars on up stroke. POOH. 6,729.0 6,729.0 4/12/2025 17:00 4/12/2025 20:00 3.00 COMPZN, WELLPR ELNE P YJOS E-line RIH F/surface T/ 6929.7' (ORKB). Anchors would not open. Called Town and decided to cut at 6910.7' (ORKB) without anchors engaged. POOH and RD E-line. 6,729.0 6,729.0 4/12/2025 20:00 4/12/2025 23:30 3.50 COMPZN, WELLPR ELNE P TOOH with 3-1/2" EUE L-80 work string F/6729 to surface. LD BHA #3. UWT 81K/ SOW 66K 6,729.0 0.0 4/12/2025 23:30 4/13/2025 00:00 0.50 COMPZN, WELLPR SVRG P Grease rig floor equipment. 0.0 0.0 4/13/2025 00:00 4/13/2025 02:00 2.00 COMPZN, WELLPR BHAH P PU Fishing BHA #4 0.0 214.0 4/13/2025 02:00 4/13/2025 06:00 4.00 COMPZN, WELLPR TRIP P RIH with fishing BHA on 2-7/8" DP. Trip in hole F/214 T/ 6711. PUWT: 100K SOWT: 68K 214.0 6,711.0 4/13/2025 06:00 4/13/2025 07:00 1.00 COMPZN, WELLPR FISH P P/U one joint M/U X/O F/ 2 7/8" HT PAC to HT 38 to string, and Kelly up with the top drive. Start pumps @ 1.5 BBL/Min @ 440 PSI and obtain initial parameters. Slack off w/ Pumps on observe pressure go F/ 440 PSI to 1100 PSI while swallowing the stump. @ 6729.2' Set down 10K. P/U and warm up jars stage up to jarring @ 195K HKLD and straight pulling to 275 HKLD after the jars fired. After 4 hits weight fell off indicating fish is free or grapple slipped off. 6,711.0 6,729.2 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 5/21 3A-17 Report Printed: 5/30/2025 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) 4/13/2025 07:00 4/13/2025 08:00 1.00 COMPZN, WELLPR CIRC P Circulate around high vis sweep @ 2.5 BBL/Min @ 1680 PSI. Rig crew perform derrick inspection while circulating. 12.7- 13.0 PPG fluid back to surface at bottoms up. 6,729.2 6,717.0 4/13/2025 08:00 4/13/2025 08:30 0.50 COMPZN, WELLPR OWFF P L/D working joint, and blow down top drive. OWFF: Static. 6,717.0 6,717.0 4/13/2025 08:30 4/13/2025 11:00 2.50 COMPZN, WELLPR TRIP P POOH F/ 6717' to 214'. 6,717.0 214.0 4/13/2025 11:00 4/13/2025 12:00 1.00 COMPZN, WELLPR BHAH P POOH racking back drill collars, and L/D BHA. No fish. Broken/ missing grapple and overshot bowl slightly distorted. 214.0 0.0 4/13/2025 12:00 4/13/2025 12:30 0.50 COMPZN, WELLPR CLEN P Clean and clear rig floor. Consult town for plan forward. 0.0 0.0 4/13/2025 12:30 4/13/2025 16:30 4.00 COMPZN, WELLPR TRIP P M/U gutted over shot to the bottom of 3.5" tubing, and RIH F/ Surface to 6727' UWT 81K/SOW 66K 0.0 6,727.0 4/13/2025 16:30 4/13/2025 18:30 2.00 COMPZN, WELLPR CIRC P CBU x2 @ 3 BPM @ 700 PSI. 6,727.0 6,727.0 4/13/2025 18:30 4/13/2025 19:00 0.50 COMPZN, WELLPR SVRG P Grease the crown, topdrive, blocks,Blakjack and draworks. 6,727.0 6,727.0 4/13/2025 19:00 4/14/2025 00:00 5.00 COMPZN, WELLPR WAIT P Wait on Welltech with cutter. Rig crew perform maintenance 6,727.0 6,727.0 4/14/2025 00:00 4/14/2025 01:00 1.00 COMPZN, WELLPR WAIT P Wait on Welltech with cutter. 6,727.0 6,727.0 4/14/2025 01:00 4/14/2025 02:30 1.50 COMPZN, WELLPR SLPC P Slip and cut drill line. 6,727.0 6,727.0 4/14/2025 02:30 4/14/2025 03:30 1.00 COMPZN, WELLPR WAIT P Wait on Welltech with cutter. Rig crew work on maintenance and house keeping through out the rig. Monitor well on the trip tank. 6,727.0 6,727.0 4/14/2025 03:30 4/14/2025 04:30 1.00 COMPZN, WELLPR ELNE P RU YJOS E-line, and Well tec. 6,727.0 6,729.0 4/14/2025 04:30 4/14/2025 05:00 0.50 COMPZN, WELLPR ELNE P P/U Well Tec cutter and M/U to tool string. 6,729.0 6,729.0 4/14/2025 05:00 4/14/2025 06:00 1.00 COMPZN, WELLPR ELNE P YJOS RIH w/ Well Tec cutter F/ Surface to 6920'. Locate GLM, and make several passes to correlate collars on CCL. 6,729.0 6,729.0 4/14/2025 06:00 4/14/2025 06:30 0.50 COMPZN, WELLPR ELNE P Place cutter @ 6907' (5' Bellow nearest collar). Set anchors on Well tec cutter. Make cut. String in compression observe full cutter extension on read out in unit. Retract cutters, and extend while rotating until stall 9 times per Well Tec proceedure to verify cut. 6,729.0 6,729.0 4/14/2025 06:30 4/14/2025 07:30 1.00 COMPZN, WELLPR ELNE P YJOS E-line POOH w/ Well Tec cutter F/ 6907' to surface. 6,729.0 6,729.0 4/14/2025 07:30 4/14/2025 08:00 0.50 COMPZN, WELLPR ELNE P Inspect Well Tec cutter on surface. Good wear observed on all 3 cutters, no indications of damage on anchors. Extension indicator measured 6.3 (minimum 5.57). L/D Tools. 6,729.0 6,729.0 4/14/2025 08:00 4/14/2025 08:30 0.50 COMPZN, WELLPR ELNE P R/D YJOS equipment on the rig floor. 6,729.0 6,729.0 4/14/2025 08:30 4/14/2025 11:00 2.50 COMPZN, WELLPR TRIP P POOH racking back 3.5" tubing F/ 6729' to surface. B/O L/D overshot on bottom of tubing. 6,729.0 0.0 4/14/2025 11:00 4/14/2025 13:00 2.00 COMPZN, WELLPR BHAH P P/U BHA # 6, Fishing BHA F/ Surface to 211' 0.0 211.0 4/14/2025 13:00 4/14/2025 13:30 0.50 COMPZN, WELLPR SVRG P Grease Draw works, Power tongs, Top Drive and all handling equipment. 211.0 211.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 6/21 3A-17 Report Printed: 5/30/2025 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) 4/14/2025 13:30 4/14/2025 17:00 3.50 COMPZN, WELLPR TRIP P TIH w/ 2 7/8" HT Pac drill pipe F/ 211' to 6714'. PUW 98K/SOW 69K 211.0 6,714.0 4/14/2025 17:00 4/14/2025 18:00 1.00 COMPZN, WELLPR FISH P Wash down F/ 6714' to 6726' (top of stump). PU to 125K jars bled off. PUW to 200K and Fish pulled free. 6,714.0 6,726.0 4/14/2025 18:00 4/14/2025 19:00 1.00 COMPZN, WELLPR CIRC P Circ 54 SPM at 2350 PSI. SxS 2744 strokes. Sent 37 bbls out to cuttings tank. 6,726.0 6,653.0 4/14/2025 19:00 4/14/2025 23:00 4.00 COMPZN, WELLPR TRIP P TOOH F/6653' T/211' UWT 90K 6,653.0 211.0 4/14/2025 23:00 4/14/2025 23:30 0.50 COMPZN, WELLPR BHAH P LD Fishing BHA #6 FD 194.98' Fish from top to bottom (Pre- rig cut 12.4', GLM#2 6.87', pup 14.98', 5 JTs 14 through 10 = 156.38' & Welltec cut jt 4.35') 211.0 0.0 4/14/2025 23:30 4/15/2025 00:00 0.50 COMPZN, WELLPR SVRG P Grease floor equipment. 0.0 0.0 4/15/2025 00:00 4/15/2025 03:00 3.00 COMPZN, WELLPR BHAH P MU fishing BHA #7 F/ Surface to 211' 0.0 211.0 4/15/2025 03:00 4/15/2025 07:30 4.50 COMPZN, WELLPR TRIP P TIH with BHA #7 on 2-7/8" DP from derrick. F/211' T/ 6900' PUWT: 98 K SOWT: 68 K 211.0 6,900.0 4/15/2025 07:30 4/15/2025 08:00 0.50 COMPZN, WELLPR FISH P Obtain paramters. Wash down to top of fish @ 1 BBL/Min @ 240 PSI. Tag top of fish @ 6919'. Set down 10K, No increase in SPP. P/U and verify string is free. Set down 10K start rotary @ 10 RPM 2100 Ft/Lbs. Observe weight fall off, cut rotary, and continue to slack off to 6920.3' (1.3' swallow on over shot). Observe pressure spike to 820 PSI. Stop pumps. Set down 10K P/U to 125K to verify overshot bit. Start jaring staging up F/ 150K HKLD, to 175K HKLD straight pulling after jars fired F/ 200 to 275K HKLD. After 16 hits jars quit firing. PUWT: 98 K SOWT: 68K ROTWT: 82 K 6,900.0 6,920.3 4/15/2025 08:00 4/15/2025 08:30 0.50 COMPZN, WELLPR FISH P Release off of fish rotating 5-10 RPM @ 2.1 - 3.5K TQ. Bump down on top of fish and rotate off. 6,920.3 6,915.0 4/15/2025 08:30 4/15/2025 09:30 1.00 COMPZN, WELLPR CIRC P CBU 2X @ 3 BBL/Min 2,450 PSI 6,915.0 6,915.0 4/15/2025 09:30 4/15/2025 10:00 0.50 COMPZN, WELLPR OWFF P Blow down top drive. OWFF 10 min: static. 6,915.0 6,915.0 4/15/2025 10:00 4/15/2025 12:30 2.50 COMPZN, WELLPR TRIP P POOH F/ 6915' to 211'. 6,915.0 211.0 4/15/2025 12:30 4/15/2025 14:00 1.50 COMPZN, WELLPR BHAH P L/D BHA F/ 211' to surface. 211.0 211.0 4/15/2025 14:00 4/15/2025 14:30 0.50 COMPZN, WELLPR SVRG P Service rig floor euqipment. Install new HDI gauge at driller's console. 0.0 0.0 4/15/2025 14:30 4/15/2025 16:30 2.00 COMPZN, WELLPR BHAH P LD BHA F/214.9' T/0' MU New BHA T/215.19' 214.9 215.2 4/15/2025 16:30 4/15/2025 21:00 4.50 COMPZN, WELLPR TRIP P TIH F/215/19' T/6920' PUW=100K SOW= 70K 215.2 6,920.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 7/21 3A-17 Report Printed: 5/30/2025 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) 4/15/2025 21:00 4/15/2025 21:15 0.25 COMPZN, WELLPR FISH P Establish fishing parameters. ROT at 17 RPM ROT WT=81K Free TQ=2.3K PR=1 bpm @ 350PSI off 920PSI on Engage TOF at 6920.6' Set down 10K down. Start jarring on fish 150K up fire straight pull to 270K Hit 12 jar ;licks no movement. Jars stopped firing. Work overshot off top of fish. 6,920.0 6,905.0 4/15/2025 21:15 4/15/2025 22:00 0.75 COMPZN, WELLPR CIRC P Circulate BUS. 3 BPM at 2200 PSI 6,905.0 6,905.0 4/15/2025 22:00 4/15/2025 22:30 0.50 COMPZN, WELLPR OWFF P OWFF crude swapped to top of hole. No flow. 6,905.0 6,905.0 4/15/2025 22:30 4/16/2025 00:00 1.50 COMPZN, WELLPR TRIP P TOOH F/6905' T/4814 PUWT=98K SOW=70K 6,905.0 4,814.0 4/16/2025 00:00 4/16/2025 02:00 2.00 COMPZN, WELLPR TRIP P TOOH W/Fishing BHA F/48914' PUW=98K SOW=70K. 4,814.0 215.2 4/16/2025 02:00 4/16/2025 05:00 3.00 COMPZN, WELLPR BHAH P LD BHA and remove jars from BHA. Replace BS, jars and OS. 215.2 225.1 4/16/2025 05:00 4/16/2025 09:00 4.00 COMPZN, WELLPR TRIP P TIH W/reconfigured BHA. F/225.08' T/6911' PUW=XXK SOW=XXK 225.1 6,911.0 4/16/2025 09:00 4/16/2025 10:00 1.00 COMPZN, WELLPR FISH P P/U working joint and make up to string. Obtain parameters. PUWT: 99K SOWT: 70K ROTWT: 82K @ 15 RPM @ 15 RPM 2.2K TQ. SPP: 310 PSI @ 1 BBL/ min. Wash down to top of stump and set down 10K @ 6920.7'. P/U to 125K and fire jars. Straight pull to 200K. Weight fell off, w/ no extra wt. Slack off and attempt to re-engage fish 3 times. P/U and start rotating to the left @ 10 RPM @ 1.5-1.9 K TQ and attempt to re- engage fish (LH Catch grapple in OS). No sucess. 6,911.0 6,920.0 4/16/2025 10:00 4/16/2025 10:30 0.50 COMPZN, WELLPR CIRC P CBU @ 3 BBL/ MIn @ 2300 PSI 6,920.0 6,920.0 4/16/2025 10:30 4/16/2025 13:30 3.00 COMPZN, WELLPR TRIP P POOH F/ 6920' to 211' 6,920.0 6,920.0 4/16/2025 13:30 4/16/2025 16:00 2.50 COMPZN, WELLPR BHAH P POOH W/ BHA F/ 211' to Surface. Grapple and part of control missing F/ over shot. Change out overshot. Run back in hole w/ BHA to 211'. 211.0 211.0 4/16/2025 16:00 4/16/2025 16:30 0.50 COMPZN, WELLPR SVRG P Rig service. Service derrick camera system. 211.0 211.0 4/16/2025 16:30 4/16/2025 19:30 3.00 COMPZN, WELLPR TRIP P RIH F/ 211' to 6920' PUWT: 100K SOWT: 70K 211.0 6,920.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 8/21 3A-17 Report Printed: 5/30/2025 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) 4/16/2025 19:30 4/16/2025 23:30 4.00 COMPZN, WELLPR FISH P Establish Fishing parameters Rot=16 RPM at 2300 Free tq. 81K Rot Wt PR=1 BPM 370 PSI Engage TOF at 6923.14' 10K down. 680 PSI on fish Start jarring 200K straight pull to 250K Hit 184 licks lost 10K PUW=90K Able to move drill pipe freely. RIH tag at 6922.14' 1' short of orginal tag depth. PUH to 6915' 6,920.0 6,920.0 4/16/2025 23:30 4/17/2025 00:00 0.50 COMPZN, WELLPR CIRC T Circulate BUS 3 BPM at 1600 PSI 6,915.0 6,915.0 4/17/2025 00:00 4/17/2025 00:30 0.50 COMPZN, WELLPR OWFF T OWFF for 30 minutes. 6,915.0 6,915.0 4/17/2025 00:30 4/17/2025 02:00 1.50 COMPZN, WELLPR TRIP T TOOH F/6915' T/5500' Turn around TIH to TOF attempted to screw back into fish 6,915.0 6,915.0 4/17/2025 02:00 4/17/2025 02:45 0.75 COMPZN, WELLPR FISH T Attempted to screw into fish unable to make up to fish. 6,915.0 6,915.0 4/17/2025 02:45 4/17/2025 03:15 0.50 COMPZN, WELLPR RURD T Blow down top drive 6,915.0 6,915.0 4/17/2025 03:15 4/17/2025 06:00 2.75 COMPZN, WELLPR TRIP T TOOH F/ TOF T surface PUW=90K SOW=70K 6,915.0 0.0 4/17/2025 06:00 4/17/2025 07:30 1.50 COMPZN, WELLPR BHAH T Accelerator parted at lower barrel. 5.97' of accerator recovered. 5.97' left along w/ 6 DC, jars, bumper sub, X/O's, and overshot. P/U Spear BHA F/ Surface to 74'. 0.0 74.7 4/17/2025 07:30 4/17/2025 11:30 4.00 COMPZN, WELLPR TRIP T RIH F/ 74' to 6688'. PUWT: 89K SOWT: 68 K 74.7 6,688.0 4/17/2025 11:30 4/17/2025 12:00 0.50 COMPZN, WELLPR FISH T Obtain parameters. Slack off to top of fish, set down 10K @ 6708'. P/U no overpull. Attempt 3 times, same result. P/U and put 3 left hand turns into string, and attempt to engage fish. No over pull, attempt 4 times, same result. Stab into fish, and circulate @ BPM @ PSI. Apply 3 left hand turns and attempt to catch fish 6,688.0 6,708.0 4/17/2025 12:00 4/17/2025 13:00 1.00 COMPZN, WELLPR CIRC T ccirculate at 1.5 BPM at 1630 PSI 2029 STK's 6,708.0 4/17/2025 13:00 4/17/2025 13:30 0.50 COMPZN, WELLPR OWFF T OWFF for 30 minutes 4/17/2025 13:30 4/17/2025 14:00 0.50 COMPZN, WELLPR SVRG T Service TD and power tongs 4/17/2025 14:00 4/17/2025 14:30 0.50 COMPZN, WELLPR TRIP T TOOH F/6671' T/5164' PUW=93K SOW=68K 4/17/2025 14:30 4/17/2025 15:30 1.00 COMPZN, WELLPR CIRC T Circulate 1.5BPM at 1500 PSI 1519 Total stks 4/17/2025 15:30 4/17/2025 17:30 2.00 COMPZN, WELLPR TRIP T TOOH F/5164' T/74.68' PUW=80K SOW=65K 4/17/2025 17:30 4/17/2025 18:00 0.50 COMPZN, WELLPR BHAH T LD BHA 4/17/2025 18:00 4/17/2025 20:30 2.50 COMPZN, WELLPR BHAH T MU Milling dress off BHA. T/97.6 0.0 97.6 4/17/2025 20:30 4/17/2025 22:00 1.50 COMPZN, WELLPR TRIP T TIH F/97.6' T/2577' 97.6 2,577.0 4/17/2025 22:00 4/18/2025 00:00 2.00 COMPZN, WELLPR CIRC T Circulate 1.5 BPM at 280 PSI. Wait on pahse 3 weather to lift. 2,577.0 2,577.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 9/21 3A-17 Report Printed: 5/30/2025 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) 4/18/2025 00:00 4/19/2025 00:00 24.00 COMPZN, WELLPR CIRC T Circulate 1.5 BPM at 280 PSI. Wait on phase 3 weather to lift. 2,577.0 2,577.0 4/19/2025 00:00 4/19/2025 04:30 4.50 COMPZN, WELLPR WAIT T Circulate 1.5 BPM at 280 PSI. Wait on phase 3 weather to lift. 2,577.0 2,577.0 4/19/2025 04:30 4/19/2025 06:30 2.00 COMPZN, WELLPR SFTY T TOOH F/2577' T/97' 2,577.0 97.0 4/19/2025 06:30 4/19/2025 08:00 1.50 COMPZN, WELLPR BHAH T LD milling BHA. MU modified accelerator W/BS. 97.0 17.0 4/19/2025 08:00 4/19/2025 10:30 2.50 COMPZN, WELLPR TRIP T RIH F/ 17' to 6660'. 17.0 6,960.0 4/19/2025 10:30 4/19/2025 12:00 1.50 COMPZN, WELLPR FISH T Obtain parameters, and screw into accelerator w/ BHA. P/U to 100K and verify over pull. attempt to release overshot @ 6925. Bump down on fish until able to free rotate. Rotate to the right 2.3-2.7K TQ and release overshot. 6,960.0 6,703.0 4/19/2025 12:00 4/19/2025 12:30 0.50 COMPZN, WELLPR SFTY T Rig crew perform Derrick inspection 6,703.0 6,703.0 4/19/2025 12:30 4/19/2025 13:30 1.00 COMPZN, WELLPR CIRC T CBU @ 1.5 BBL/Min @ 600 PSI. 6,703.0 6,703.0 4/19/2025 13:30 4/19/2025 14:00 0.50 COMPZN, WELLPR OWFF T OWFF: Static, blow down top drive. 6,703.0 6,703.0 4/19/2025 14:00 4/19/2025 15:00 1.00 COMPZN, WELLPR TRIP T POOH F/ 6703' to 4000'. PUWT: 75K SOWT: 50K 6,703.0 4,000.0 4/19/2025 15:00 4/19/2025 15:30 0.50 COMPZN, WELLPR SVRG T Rig service. Service power tongs. 4,000.0 4,000.0 4/19/2025 15:30 4/19/2025 17:00 1.50 COMPZN, WELLPR TRIP T Cont. POOH F/ 4000' to BHA 4,000.0 216.0 4/19/2025 17:00 4/19/2025 18:00 1.00 COMPZN, WELLPR BHAH T LD BHA, 216.0 0.0 4/19/2025 18:00 4/19/2025 18:30 0.50 COMPZN, WELLPR RURD T RD from running DP RU to run tubing 4/19/2025 18:30 4/19/2025 19:00 0.50 COMPZN, WELLPR BHAH T MU over shot BHA on tubing. 5.0 5.0 4/19/2025 19:00 4/20/2025 00:00 5.00 COMPZN, WELLPR TRIP T TIH W/3-1/2" tubing F/5' T/6730' 5.0 6,730.0 4/20/2025 00:00 4/20/2025 01:00 1.00 COMPZN, WELLPR PULD T Continue in hole F/6850' T/6920' Set gutted overshot on top of 3-1/2" tubing string. 6,850.0 6,920.0 4/20/2025 01:00 4/20/2025 01:30 0.50 COMPZN, WELLPR RURD T RU Full open safety valve and side port entry sub on top of 3-1/2" work string. 6,920.0 6,920.0 4/20/2025 01:30 4/20/2025 03:30 2.00 COMPZN, WELLPR SLKL T Continue moving e-line unit out of way spot in Slickline and RU. 6,920.0 6,920.0 4/20/2025 03:30 4/20/2025 12:00 8.50 COMPZN, WELLPR SLKL T RIH W/2" bailer and 30' TS to 6982' Bailer full of sand and small rubber piece. Bailer make multiple runs to 6992'. P/U Flat bottom magnet and RIH. Unable to get past top of 3.5" tubing @ 6920'. POOH P/U 2.5" X magnets and RIH to 6992' get small pieces of grapple out of the hole. 6,920.0 6,920.0 4/20/2025 12:00 4/20/2025 17:00 5.00 COMPZN, WELLPR SLKL T P/U 2.5" Pump bailer and RIH and make it to 6996'. Bring back large amounts of grapple back to surface. 6,920.0 6,920.0 4/20/2025 17:00 4/20/2025 20:00 3.00 COMPZN, WELLPR SLKL T RIH W/2.71" GR unable to pass top of tubing stump. RIH W/2.65" sample bailer to 6919'. 6,920.0 6,920.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 10/21 3A-17 Report Printed: 5/30/2025 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) 4/20/2025 20:00 4/20/2025 20:30 0.50 COMPZN, WELLPR PULD T Set 3.5" work string down on top of tubing stump at 6920'. 6,920.0 6,920.0 4/20/2025 20:30 4/20/2025 23:30 3.00 COMPZN, WELLPR SLKL T RIH W/2.65" bailer to 6940' RIH W/2.70 Swedge to 6919' 6,920.0 4/20/2025 23:30 4/21/2025 00:00 0.50 COMPZN, WELLPR SVRG T Service crown. 4/21/2025 00:00 4/21/2025 01:00 1.00 COMPZN, WELLPR SLKL T Slickline Searching for 2.71" swedge. Mix 40 BBL 1% saf-lube pill 6,920.0 6,920.0 4/21/2025 01:00 4/21/2025 01:30 0.50 COMPZN, WELLPR CIRC T Spot pill at tubing stump reduce friction for swedging. ICP3BPM at 1200 PSI FCP=3BPM 1000 PSI Blow down TD and surface lines. 6,920.0 6,920.0 4/21/2025 01:30 4/21/2025 03:15 1.75 COMPZN, WELLPR SLKL T Attempt to pass 2.71" swedge through tubing stump at 6919'. detained 3 times unable to pass. RD Slick line 6,920.0 6,920.0 4/21/2025 03:15 4/21/2025 05:00 1.75 COMPZN, WELLPR CIRC T Well out of balance after spotting pill Circulate BUS at 5 BPM 1100 PSI Blow down TD and surface lines 6,920.0 6,920.0 4/21/2025 05:00 4/21/2025 08:30 3.50 COMPZN, WELLPR TRIP T TOOH W/3.5" WS F/6920' T/ 600' . Town gave direction to RIH back to bottom. PUWT= 85 K SOW= 65 K 6,920.0 600.0 4/21/2025 08:30 4/21/2025 11:00 2.50 COMPZN, WELLPR TRIP T RIH W/ 3.5" 9.3# EUE work string F/ 600' to 6920'. Swallow tubing stump w/ overshot. 600.0 6,923.0 4/21/2025 11:00 4/21/2025 12:00 1.00 COMPZN, WELLPR ELNE T R/U AK E-line 6,923.0 6,923.0 4/21/2025 12:00 4/21/2025 14:00 2.00 COMPZN, WELLPR ELNE T AK E-line RIH w/ 1" Shot rod and fire string shot @ 6985'. 6,923.0 6,923.0 4/21/2025 14:00 4/21/2025 18:15 4.25 COMPZN, WELLPR ELNE T AK E-line RIH w/ 2" RCT to 6986'. Make cut w/ RCT. Good indications of RCT firing. POOH. R/D AK E-line. 6,923.0 6,923.0 4/21/2025 18:15 4/21/2025 22:00 3.75 COMPZN, WELLPR TRIP T TOOH racking back 3.5" tubing work string F/6923' to surface. 6,923.0 0.0 4/21/2025 22:00 4/21/2025 22:30 0.50 COMPZN, WELLPR SVRG T Service Rig 0.0 0.0 4/21/2025 22:30 4/21/2025 22:45 0.25 COMPZN, WELLPR SFTY T PJSM to MU BHA and TIH 0.0 0.0 4/21/2025 22:45 4/21/2025 23:00 0.25 COMPZN, WELLPR RURD T RU to run DP 0.0 0.0 4/21/2025 23:00 4/22/2025 00:00 1.00 COMPZN, WELLPR BHAH T PU BHA 17A Fishing BHA. 0.0 21.4 4/22/2025 00:00 4/22/2025 01:30 1.50 COMPZN, WELLPR BHAH T PU BHA 17A Fishing BHA. 21.4 227.9 4/22/2025 01:30 4/22/2025 06:00 4.50 COMPZN, WELLPR TRIP T TIH F/227.9' T/6919' PUW= 98K SOW=70K 227.9 -6,920.0 4/22/2025 06:00 4/22/2025 06:30 0.50 COMPZN, WELLPR FISH T Establish Fishing parameters PR=1.5BPM 400 PSI off Rotate at 15 RPM 2000 FT/LBS Fr Tq. ROT WT=97K PR=1.5BPM at Set down 10K Pump pressure 450 PSI PUWT=98K -6,920.0 6,920.0 4/22/2025 06:30 4/22/2025 08:00 1.50 COMPZN, WELLPR CIRC T Build High Vis. sweep Circulate Sweep SxS. 3BPM 1800 PSI 6,920.0 6,920.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 11/21 3A-17 Report Printed: 5/30/2025 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) 4/22/2025 08:00 4/22/2025 11:45 3.75 COMPZN, WELLPR TRIP T TOOH F/6920' to see if we recovered fish. PUW=100K SOW=70K Overpulled 10K at 6880' weight fell off immediately. Continued to TOOH. PUW=98K 6,920.0 227.9 4/22/2025 11:45 4/22/2025 13:00 1.25 COMPZN, WELLPR BHAH T LD BHA and fish. Fish OAL=65.34' 227.9 5.4 4/22/2025 13:00 4/22/2025 16:30 3.50 COMPZN, WELLPR TRIP T MU overshot BHA #16, PUW=86k, SOW=67k Engage fish F/6,984.34' T/6,989' 5.4 6,989.0 4/22/2025 16:30 4/23/2025 00:00 7.50 COMPZN, WELLPR SLKL T RU HES Slickline Make multiple runs W/2.5" bailer work down to 6992' W/2.5" pump bailer. Recovered grapple pieces and miscellaneous swarf form the tubing. Still recovering fill at midnight. 6,989.0 6,989.0 4/23/2025 00:00 4/23/2025 06:00 6.00 COMPZN, WELLPR SLKL T RU HES Slickline Make multiple runs W/2.5" bailer work down to 6992' W/2.5" pump bailer. Recovered grapple pieces and miscellaneous swarf form the tubing. Continue to bail untill no metal in fill and nominal sand in bailer. MU 2.71" drift to 6992' MU RBP drift to 6992' MU 3" GR RIH to 6992' Latched TTS pulling tool Sheared GS in 10 hits. 6,989.0 6,989.0 4/23/2025 06:00 4/23/2025 10:30 4.50 COMPZN, WELLPR SLKL T Continue POOH, redress GR RBIH, latch up @ 6,988' to TTS pulling tool, sheared GR 7 hits. POOH 6,989.0 6,989.0 4/23/2025 10:30 4/23/2025 15:30 5.00 COMPZN, WELLPR SLKL T MU dogless GS, RIH latch into TTS pulling tool, 6,988', confirmed we could shear GS to release. POOH, MU loaded GS, Continue jarring on fish x 4, unable to move fish. Shear off POOH, RD Slickline. 6,989.0 6,989.0 4/23/2025 15:30 4/23/2025 16:00 0.50 COMPZN, WELLPR CIRC T Pump BUS 3.5 BPM 760 PSI. 6,989.0 6,989.0 4/23/2025 16:00 4/23/2025 16:30 0.50 COMPZN, WELLPR OWFF T OWFF for 30 minutes 6,989.0 6,989.0 4/23/2025 16:30 4/23/2025 18:00 1.50 COMPZN, WELLPR TRIP T TOOH F/6989' T/2845' PUW=48K 6,989.0 2,845.0 4/23/2025 18:00 4/23/2025 19:00 1.00 COMPZN, WELLPR CIRC T Trip tank found W/11.2# feeding hole Circulated SXS 5BPM 650 PSI OWFF for 15 minutes. 2,845.0 2,845.0 4/23/2025 19:00 4/23/2025 20:45 1.75 COMPZN, WELLPR TRIP T TOOH F/2845 T/5.4' LD overshot 2,845.0 0.0 4/23/2025 20:45 4/23/2025 22:30 1.75 COMPZN, WELLPR RURD T RD from tripping pipe get RU to test BOP's load test joints in pipe shed pre mark donut joints MU X-O's to safety valves. align valves for testing Pull wear ring, drain stack and set test plug. Fill stack with fresh water for BOP test. Flood lines purge system. 0.0 0.0 4/23/2025 22:30 4/23/2025 23:00 0.50 COMPZN, WELLPR SVRG T Service rig. 0.0 0.0 4/23/2025 23:00 4/24/2025 00:00 1.00 COMPZN, WELLPR BOPE T Start shell test, IBOP failed CMV#2 failed on shell test. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 12/21 3A-17 Report Printed: 5/30/2025 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) 4/24/2025 00:00 4/24/2025 10:00 10.00 COMPZN, WELLPR BOPE T Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 2-7/8" and 3-1/2" test joint, UVBR's, LVBR's w/2-7/8" and 3-1/2" test joints. 1. Blind Rams, CMV 1-3-4 -5-6-16, Rig Floor Kill, Outer Test Spool Valve, Manual IBOP, Blind Rams, CMV 7,8,9, HCR Kill, Inner Test Spool Valve, LPR, 3-1/2” FOSV, 2-7/8” HT PAC TIW, Annular, Manual Kill, 2-7/8” HT PAC Dart, Hydraulic Super Choke & Manual Adjustable Choke (1,500 psi Test), UPR, CMV 10-11, LPR, HT-38 TIW, Annular, CMV 12-13-15, UPR, CMV 14, HCR Choke, Manual Choke, IBOP, CMV 2, (Fail/Pass CMV #2 & IBOP) Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3,050 PSI, after closure=1500 PSI, 200 PSI attained =16 sec, full recovery attained = 132 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2150 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Kam St John. 0.0 0.0 4/24/2025 10:00 4/24/2025 10:30 0.50 COMPZN, WELLPR RURD T RD Testing Equipment and blow down test pump. 0.0 0.0 4/24/2025 10:30 4/24/2025 13:00 2.50 COMPZN, WELLPR BHAH T MU BHA 4-3/4" wash pipe. 0.0 247.0 4/24/2025 13:00 4/24/2025 16:00 3.00 COMPZN, WELLPR TRIP T TIH w/wash pipe BHA #18 PUW= 100K SOW= 70K 247.0 6,985.0 4/24/2025 16:00 4/24/2025 18:30 2.50 COMPZN, WELLPR MILL T Establish milling parameters at 6970' 20 RPM 2500 Ft/Lbs free Tq. 40 RPM 2500 Free Tq. 34 SPM 960 PSI RT WT=84K Wash over tubing down to 7010' (7ES RKB) 6,985.0 7,010.0 4/24/2025 18:30 4/24/2025 19:15 0.75 COMPZN, WELLPR CIRC T Circulate BUS. 3.5 BPM 7,000.0 7,000.0 4/24/2025 19:15 4/24/2025 22:45 3.50 COMPZN, WELLPR TRIP T TOOH F/7000' T/247.2 7,000.0 247.2 4/24/2025 22:45 4/25/2025 00:00 1.25 COMPZN, WELLPR BHAH T LD BHA sand recovered in boot baskets. 247.2 0.0 4/25/2025 00:00 4/25/2025 01:00 1.00 COMPZN, WELLPR BHAH P LD BHA recovered 25.59' of tubing in wash pipe and RBP. Unable to recover RBP from tubing. 0.0 0.0 4/25/2025 01:00 4/25/2025 02:00 1.00 COMPZN, WELLPR BHAH P MU milling BHA. new shoe 3.5" ID 36.72" swallow. 24.0 247.2 4/25/2025 02:00 4/25/2025 06:00 4.00 COMPZN, WELLPR TRIP P TIH W/BHA F/247.2 T/7,008' 247.2 7,042.0 4/25/2025 06:00 4/25/2025 08:00 2.00 COMPZN, WELLPR WASH P Obtain Pump Parameters. PUW=98k, SOW=70k Wash down Top of fish F/7,008' RPM=50, 35 spm/980 psi, 1,500 ft/lbs PUW=100k, SOW=70k ROTW=85k Ratty torque 1,500-3,500 ft/lbs Increase pump rate. 57 SPM/2,600 psi T/7,040', 20K WOB, continue burning over collar T/7,042' Torque 1,500 - 3,500 ft/lbs. 7,042.0 7,042.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 13/21 3A-17 Report Printed: 5/30/2025 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) 4/25/2025 08:00 4/25/2025 08:30 0.50 COMPZN, WELLPR WASH P Perform dry run T/6,933' T/7,042', Clean drift. 7,042.0 7,042.0 4/25/2025 08:30 4/25/2025 11:00 2.50 COMPZN, WELLPR TRIP P TOOH, F/6,933' T/Surface PUW=95k, SOW=75k. 7,042.0 247.0 4/25/2025 11:00 4/25/2025 12:00 1.00 COMPZN, WELLPR BHAH P LD BHA 247.0 0.0 4/25/2025 12:00 4/25/2025 13:00 1.00 COMPZN, WELLPR BHAH P MU Fishing BHA #19 0.0 227.0 4/25/2025 13:00 4/25/2025 13:30 0.50 COMPZN, WELLPR SVRG P Service handling equipment, Greased DW and TD. 227.0 227.0 4/25/2025 13:30 4/25/2025 16:30 3.00 COMPZN, WELLPR TRIP P TIH w/DP F/BHA T/6980' PUW=95K SOW=76K 227.0 6,972.0 4/25/2025 16:30 4/25/2025 17:30 1.00 COMPZN, WELLPR FISH P Obtain fishing parameters PUW=95k, SOW=76K ROT WT=83K 1 BPM=260 PSI, 15 RPM Tq.=1700 Ft/lBS. Tagged up at 7008' set down 10K latched fish PU T/125K bleed jars work up to 150K fired jars 15 times Release from fish. 6,972.0 6,972.0 4/25/2025 17:30 4/25/2025 18:00 0.50 COMPZN, WELLPR CIRC P Circ BUS 2BPM 1000 PSI 6,972.0 6,972.0 4/25/2025 18:00 4/25/2025 18:30 0.50 COMPZN, WELLPR OWFF P OWFF for 30 minutes blow down top drive and surface lines. 6,972.0 6,972.0 4/25/2025 18:30 4/25/2025 22:15 3.75 COMPZN, WELLPR TRIP P TOOH F/6972' T/227' PUW=95K 6,972.0 227.0 4/25/2025 22:15 4/26/2025 00:00 1.75 COMPZN, WELLPR BHAH P LD fishing BHA, MU washover BHA 227.0 247.0 4/26/2025 00:00 4/26/2025 01:00 1.00 COMPZN, WELLPR BHAH P MU wash pipe BHA to 227.0 247.0 4/26/2025 01:00 4/26/2025 04:30 3.50 COMPZN, WELLPR TRIP P TIH F/247 T/7038' PUW=95K SOW=75K 247.0 7,038.0 4/26/2025 04:30 4/26/2025 07:00 2.50 COMPZN, WELLPR MILL P PU to 7003' Establish milling parameters 1.5 BPM=650 PSI 2BPM=835PSI ROT 60 RPM Free Tq. 1380 Ft./Lbs Rot Wt=85K off Continue burning over collar F/7,038' T/7,044.8', 7,.046' w/12k down 7,038.0 7,046.0 4/26/2025 07:00 4/26/2025 08:00 1.00 COMPZN, WELLPR SLPC P LD working single and rack back 1 stand 7,046.0 6,981.0 4/26/2025 08:00 4/26/2025 09:30 1.50 COMPZN, WELLPR SLPC P Slip and cut drilling line. Pump 20 bbl high-vis sweep. 6,981.0 6,981.0 4/26/2025 09:30 4/26/2025 12:00 2.50 COMPZN, WELLPR TRIP P TOOH with wash pipe F/6,981' T/BHA 6,981.0 247.0 4/26/2025 12:00 4/26/2025 12:30 0.50 COMPZN, WELLPR BHAH P LD and inspect BHA 3.5" ID, 3 chips on face on shoe. 247.0 0.0 4/26/2025 12:30 4/26/2025 13:15 0.75 COMPZN, WELLPR BHAH P MU BHA XO (2-7/8 HT-PAC x 2-3/8" REG), XO (2 -3/8" REG x 2-3/8" IF), 3-3/4" Accelerator, XO (2-3/8" IF x 2-3/8" REG), 3-1/8" DC x 6, XO (2-3/8" REG x 2-3/8" IF), 3-3/4" Oil Jar, 3-3/4" LBS, XO (2-3/8" IF x 2-3/8" REG), XO (2-3/8" REG x 2-3/8" IF), POS (3,500 psi Shear), XO (2-3/8" IF x 2-3/8" IF), Overshot top sub, 4-11/16" Upper Extension, 4-11/16" Overshot bowl, 3.5" NOM catch, 4-11/16" Cut Lip Guide. 0.0 226.0 4/26/2025 13:15 4/26/2025 15:45 2.50 COMPZN, WELLPR TRIP P TIH w/overshot BHA #21 226.0 7,008.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 14/21 3A-17 Report Printed: 5/30/2025 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 15:45 4/26/2025 16:15 0.50 COMPZN, WELLPR FISH P Bring pump online, 1.0 bpm/100 psi. swallow fish pump pressure increased 385 psi, set down 5k, PUH pump pressure steady, assuming we have fish, increase pump rate, shear POS 3,500 psi, 7,008.0 7,013.0 4/26/2025 16:15 4/26/2025 17:00 0.75 COMPZN, WELLPR CIRC P Circulate BU 7,013.0 7,008.0 4/26/2025 17:00 4/26/2025 21:00 4.00 COMPZN, WELLPR TRIP P TOOH F/7008' T/226' PUW=95K 7,008.0 226.0 4/26/2025 21:00 4/26/2025 22:30 1.50 COMPZN, WELLPR BHAH P LD BHA and fish. Tubing joint measured ' OAL=31.72'. Swell at bottom of joint measured 3.7" OD at cut. Tubing measured 3.6" OD 226.0 0.0 4/26/2025 22:30 4/26/2025 23:15 0.75 COMPZN, WELLPR BHAH P MU Milling BHA. 0.0 257.5 4/26/2025 23:15 4/27/2025 00:00 0.75 COMPZN, WELLPR TRIP P TIH F/257.47' T/1700' 257.5 1,700.0 4/27/2025 00:00 4/27/2025 02:00 2.00 COMPZN, WELLPR TRIP P Continue TIH F/1700' T/6976' PUW=98K SOW=75K 1,700.0 6,976.0 4/27/2025 02:00 4/27/2025 05:00 3.00 COMPZN, WELLPR MILL P Establish milling parameters PR=2 BPM at 920 PSI Rot 450 RPM Free Tq= 1300 Ft/Lbs Rot WT= 84K Wash down from 7045' to collar at Mill down to 7,072' 2-3K WOB work up to 10K WOB Torque on fish=1.8-1.9K Ft/Lbs. PR=2 BPM 930 PSI. 6,976.0 7,072.0 4/27/2025 05:00 4/27/2025 05:30 0.50 COMPZN, WELLPR MILL P Continue burning down to NO-GO @ 7,175' 7,072.0 7,075.0 4/27/2025 05:30 4/27/2025 06:00 0.50 COMPZN, WELLPR WASH P Drift collar area F/7,075' T/6,943'; CLean 7,075.0 6,943.0 4/27/2025 06:00 4/27/2025 06:30 0.50 COMPZN, WELLPR CIRC P Circulate high-vis sweep 6,943.0 6,943.0 4/27/2025 06:30 4/27/2025 09:00 2.50 COMPZN, WELLPR TRIP P TOOH F/6,943' T/BHA 6,943.0 257.5 4/27/2025 09:00 4/27/2025 10:00 1.00 COMPZN, WELLPR BHAH P Rack back collars, LD and inspect BHA #22 Burn Shoe, heavy wear, (3.55"ID) Send BS for redress. 257.5 0.0 4/27/2025 10:00 4/27/2025 11:00 1.00 COMPZN, WELLPR BHAH P MU overshot fishing BHA 0.0 226.0 4/27/2025 11:00 4/27/2025 13:00 2.00 COMPZN, WELLPR TRIP P TIH w/overshot BHA #23 7,035', PUW=93k, SOW=75k 226.0 7,035.0 4/27/2025 13:00 4/27/2025 13:30 0.50 COMPZN, WELLPR FISH P Wash down F/7,035' T/7,044.5' Attempt to swallow fish, bring rotary on RPM=20, Torq=1,300 ft/lbs RBIH, not seeing stumb any more, assuming we are over fish. 7,035.0 7,045.0 4/27/2025 13:30 4/27/2025 14:00 0.50 COMPZN, WELLPR CIRC P Circulate BU 7,045.0 7,045.0 4/27/2025 14:00 4/27/2025 16:45 2.75 COMPZN, WELLPR TRIP P TOOH w/2 stands, (check well for flow), w/BHA F/7,038' T/BHA 7,045.0 226.0 4/27/2025 16:45 4/27/2025 18:00 1.25 COMPZN, WELLPR BHAH P LD BHA and fish. Cut joint measured 30.7' OAL cut swelled to 3.56" OD at bottom. 226.0 0.0 4/27/2025 18:00 4/27/2025 19:00 1.00 COMPZN, WELLPR BHAH P PU wash over BHA. T/226' 0.0 226.0 4/27/2025 19:00 4/27/2025 22:00 3.00 COMPZN, WELLPR TRIP P TIH W/BHA F/226' T/7103' PUW=95K SOW=70K 226.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 15/21 3A-17 Report Printed: 5/30/2025 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 22:00 4/28/2025 00:00 2.00 COMPZN, WELLPR MILL P Establish milling parameters PR=2 BPM 866 PSI Rot= 40 RPM 1.8 Free Tq. 60 RPM 1.9K free Tq. RROT WT 84K Washed down F/7073' T/7101' Milled down to 7104' worked up to 18K WOB PR=2BPM pressure increased to 1600PSI Stopped making hole. 4/28/2025 00:00 4/28/2025 03:30 3.50 COMPZN, WELLPR MILL P Establish milling parameters PR=2 BPM 866 PSI Rot= 40 RPM 1.8 Free Tq. 60 RPM 1.9K free Tq. RROT WT 84K Washed down F/7073' T/7101' Milled down to 7104' worked up to 18K WOB PR=2BPM pressure increased to 1600PSI Stopped making hole. 7,101.0 71,004.0 4/28/2025 03:30 4/28/2025 04:00 0.50 COMPZN, WELLPR OWFF P Shut down pumps and observed well for flow no flow. 7,101.0 7,101.0 4/28/2025 04:00 4/28/2025 07:00 3.00 COMPZN, WELLPR TRIP P TOOH F/7104 T/227 PUW=98K 7,101.0 257.0 4/28/2025 07:00 4/28/2025 08:30 1.50 COMPZN, WELLPR BHAH P Rack back collars, LD BHA 3.5" tubing inside wash pipe 257.0 0.0 4/28/2025 08:30 4/28/2025 09:00 0.50 COMPZN, WELLPR BHAH P MU washover/burn shoe BHA 0.0 226.0 4/28/2025 09:00 4/28/2025 12:00 3.00 COMPZN, WELLPR TRIP P TIH w/BHA #25 PUW=93k, SOW=74k Swallow over stub at 7,103' 226.0 7,103.0 4/28/2025 12:00 4/28/2025 18:30 6.50 COMPZN, WELLPR MILL P Establish milling parameters PR=2 BPM 866 PSI Rot= 30 RPM 1.2 Free Tq. 40 RPM 1.9K free Tq. RROT WT 84K Washed down F/7,003' T/7,133' Milled down to 7,135'' worked up to 10K WOB PR=1.5 BPM pressure increased to 1200 PSI 7,103.0 7,105.0 4/28/2025 18:30 4/28/2025 19:30 1.00 COMPZN, WELLPR CIRC P Pump 20 bbl hi-vis sweep 3 BPM @ 1800 psi, circulate out at 4 BPM @ 3250 ps OWFF, Static 7,105.0 7,003.0 4/28/2025 19:30 4/28/2025 22:30 3.00 COMPZN, WELLPR TRIP P TOOH to inspect BHA F/7135' T/227 PUW = 94K @ 7,105 PUW = 36K @ 257' 7,003.0 227.0 4/28/2025 22:30 4/28/2025 23:30 1.00 COMPZN, WELLPR BHAH P Lay down milling BHA #25, washover assembly Burn over mill missing 2 teeth Clean and clear rig floor 227.0 0.0 4/28/2025 23:30 4/29/2025 00:00 0.50 COMPZN, WELLPR SVRG P Service rig, grease power tongs 0.0 0.0 4/29/2025 00:00 4/29/2025 01:00 1.00 COMPZN, WELLPR BHAH P Pick up fishing BHA #26, overshot assembly 226', PUW 36K 0.0 226.0 4/29/2025 01:00 4/29/2025 04:00 3.00 COMPZN, WELLPR TRIP P TIH with overshot BHA #26 226.0 7,103.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 16/21 3A-17 Report Printed: 5/30/2025 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 04:00 4/29/2025 05:00 1.00 COMPZN, WELLPR FISH P Establish milling parameters 1.5 bpm/517 psi Rot=15 RPM, ROTQ=1,500 ft/lbs 500 psi pump increase Swallow down to 7,105' 7,103.0 7,105.0 4/29/2025 05:00 4/29/2025 08:00 3.00 COMPZN, WELLPR TRIP P TOOH to inspect BHA F/7105' T/227' PUW = 94K @ 7,105' PUW = 36K @ 257' 7,105.0 227.0 4/29/2025 08:00 4/29/2025 09:00 1.00 COMPZN, WELLPR BHAH P LD BHA #26 w/o fish 2 gouges on bottom of shoe, upload pictures Break out, clean boot baskets 227.0 0.0 4/29/2025 09:00 4/29/2025 09:30 0.50 COMPZN, WELLPR BHAH P MU, milling assembly BHA #27 with new crown style shoe. 0.0 257.0 4/29/2025 09:30 4/29/2025 12:00 2.50 COMPZN, WELLPR TRIP P TIH F/suface T/7101' PUW=93k, SOW=75k 257.0 7,101.0 4/29/2025 12:00 4/29/2025 17:00 5.00 COMPZN, WELLPR MILL P Continue washing down F/7,106' T/7,130' Establish milling parameters 3.0 bpm/1,875 psi 5K WOB max, 50 RPM Rot=50 RPM, ROTQ=1,500 ft/lbs 200 psi pump increase when swolling the stub. Mill F/7130' T/7137' 7,106.0 7,137.0 4/29/2025 17:00 4/29/2025 17:30 0.50 COMPZN, WELLPR CIRC P Circulate and condition at 67 spm at 2800 psi, Flow check well. No flow. 7,137.0 7,137.0 4/29/2025 17:30 4/29/2025 21:00 3.50 COMPZN, WELLPR TRIP P TOOH F/7137' T/257'. 7,137.0 257.0 4/29/2025 21:00 4/29/2025 22:30 1.50 COMPZN, WELLPR BHAH P LD wash over BHA #27 with 30.95' tubing joint inside. 257.0 0.0 4/29/2025 22:30 4/29/2025 23:00 0.50 COMPZN, WELLPR SVRG P Service top drive and crown. Clean and grease tongs. 0.0 0.0 4/29/2025 23:00 4/30/2025 00:00 1.00 COMPZN, WELLPR BHAH P PU BHA #28 to overshot the 50' of 1.75" coil tubing. 0.0 229.0 4/30/2025 00:00 4/30/2025 03:00 3.00 COMPZN, WELLPR TRIP P TIH F/229' T/7105' PUW=95k, SOW=75k 229.0 7,105.0 4/30/2025 03:00 4/30/2025 04:30 1.50 COMPZN, WELLPR FISH P Obtain parameters RPM=20, ROTW=85k, ROTQ=1,800 ft/lbs, Pumping 2.0 bpm/950 psi Wash down T/7,102', set down 3k PUH and ROT=20 rpm Wash down T/7,107', set down 10k, observe 630 psi pressure spike. Shut down pump and ROT - PU T/125k and bleed jars, work 2 times, Pull to 150k then 170k, weight dropped off, attempt to latch onton fish 6 times with minimal overpull, then dropped off, OWFF static 7,105.0 7,107.0 4/30/2025 04:30 4/30/2025 05:00 0.50 COMPZN, WELLPR OWFF P Check well for flow, static 7,107.0 7,107.0 4/30/2025 05:00 4/30/2025 08:00 3.00 COMPZN, WELLPR TRIP P TOOH, overshot BHA w/1.75" grapple 7,107.0 229.0 4/30/2025 08:00 4/30/2025 10:00 2.00 COMPZN, WELLPR BHAH P LD BHA and fish OAL=7.52' of 1.75" coil recovered Break bowl apart and release coil from grapple 229.0 0.0 4/30/2025 10:00 4/30/2025 11:00 1.00 COMPZN, WELLPR BHAH T Confer with town for plan forward MU overshot BHA with wash pipe. BHA #29 0.0 229.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 17/21 3A-17 Report Printed: 5/30/2025 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 11:00 4/30/2025 14:00 3.00 COMPZN, WELLPR TRIP T TIH w/overshot wash pipe BHA #29 PUW=95, SOW=75k 229.0 7,101.0 4/30/2025 14:00 4/30/2025 16:00 2.00 COMPZN, WELLPR FISH T KU, wash down over top of 1.75" coiled tubing ROT=20 rpm, ROTQ=3,000 ft/lbs F/7,101', T/7,134' PUW=127k, weight bobbles T/7,101' TBIH dry F/7,100' T/7,134', PUH PUW=95-125k Still dragging weight, continue pulling F/7,134 7,101.0 7,134.0 4/30/2025 16:00 4/30/2025 16:30 0.50 COMPZN, WELLPR OWFF T Continue PUH, F/7,134' T/6,945' Check well for flow 7,134.0 6,945.0 4/30/2025 16:30 4/30/2025 19:30 3.00 COMPZN, WELLPR TRIP T TOOH F/6945' T/261' PUW 94K/ SOW 75K 6,945.0 261.0 4/30/2025 19:30 4/30/2025 20:30 1.00 COMPZN, WELLPR BHAH T LD BHA #29 coil overshot 1.75" grapple. NO Fish! 261.0 0.0 4/30/2025 20:30 4/30/2025 21:30 1.00 COMPZN, WELLPR BHAH P PU BHA #30 Coil overshot 1.66" grapple 0.0 261.0 4/30/2025 21:30 4/30/2025 23:30 2.00 COMPZN, WELLPR TRIP P TIH F/261' T/7045' PUW 95K/ SOW 75K 261.0 7,045.0 4/30/2025 23:30 5/1/2025 00:00 0.50 COMPZN, WELLPR SVRG P Grease blocks, crown and tongs. 7,045.0 7,045.0 5/1/2025 00:00 5/1/2025 04:30 4.50 COMPZN, WELLPR FISH P Work 1.66" coil grapple down over coil tubing to 3-1/2" tubing stub at 7133.5'. Obtain parameters RPM=20, ROTW=85k, ROTQ=2000 ft/lbs, Pumping 2.0 bpm/900 psi Wash down T/7,133', set down 3k PUH and ROT=20 rpm Shut down pump and ROT - PU T/125k and bleed jars, work several times, Pull to 150k then weight dropped off, attempt to latch on to fish several times with minimal overpull, then dropped off, 7,045.0 7,133.5 5/1/2025 04:30 5/1/2025 05:00 0.50 COMPZN, WELLPR OWFF P Check well for flow, Static 7,133.5 7,133.5 5/1/2025 05:00 5/1/2025 08:00 3.00 COMPZN, WELLPR TRIP P TOOH 7,133.5 261.0 5/1/2025 08:00 5/1/2025 08:30 0.50 COMPZN, WELLPR BHAH P At surface, LD BHA #30, recovered fish OAL=1.9' of 1.75" coiled tubing w/metal debris stuck in grapple. Clear and clean overshot. 261.0 0.0 5/1/2025 08:30 5/1/2025 09:00 0.50 COMPZN, WELLPR BHAH P MU washover assembly with 4-3/4" Cut Lip burn shoe. 0.0 289.0 5/1/2025 09:00 5/1/2025 11:30 2.50 COMPZN, WELLPR TRIP P TIH, F/surface T/7,133' PUW=94, SOW=75k 289.0 7,133.0 5/1/2025 11:30 5/1/2025 12:00 0.50 COMPZN, WELLPR SVRG P Service rig 7,133.0 7,133.0 5/1/2025 12:00 5/1/2025 19:00 7.00 COMPZN, WELLPR MILL P KBU Establish milling parameters 2.25 bpm/987 psi Rot=32 RPM, ROTQ=1,900 ft/lbs Wash over stub at 7,133', continue IH hole. Stall @ 7,142', PUH, regain rotating Continue to wash down F/7,142' T/7,165' Ream area F/7,165' T/7,160' Continue to wash down F/7,160' T/7176' 7,133.0 7,176.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 18/21 3A-17 Report Printed: 5/30/2025 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) 5/1/2025 19:00 5/1/2025 19:45 0.75 COMPZN, WELLPR CIRC P Pump 25 BBL hi-vis sweep 3 BPM at 1800 psi Chase at 4 BPM at 2500 psi Reciprocate pipe 15 RPM F/7170' T/7125' once sweep is on backside. 7,176.0 7,165.0 5/1/2025 19:45 5/1/2025 20:00 0.25 COMPZN, WELLPR OWFF P Flow check well. No flow. 7,165.0 7,165.0 5/1/2025 20:00 5/1/2025 23:00 3.00 COMPZN, WELLPR TRIP P TOOH F/7165' PUW 95K T/289' PUW 37K 7,165.0 289.0 5/1/2025 23:00 5/2/2025 00:00 1.00 COMPZN, WELLPR BHAH P LD BHA #31 Wash over assembly. Clean Boot Baskets. Remove shoe and LD lower wash pipe. 289.0 0.0 5/2/2025 00:00 5/2/2025 01:00 1.00 COMPZN, WELLPR BHAH P PU BHA #32 overshot assembly for 3- 1/2" tubing. 0.0 258.0 5/2/2025 01:00 5/2/2025 03:30 2.50 COMPZN, WELLPR TRIP P TIH F/258' T/7070' 258.0 7,070.0 5/2/2025 03:30 5/2/2025 05:00 1.50 COMPZN, WELLPR SLPC P Cut 102' of drill line and slip on new line. TQ deadman. Grease and inspect brake linkage- calibrate blocks. 7,070.0 7,070.0 5/2/2025 05:00 5/2/2025 05:30 0.50 COMPZN, WELLPR TRIP P Continue IH F/7,070' T/7,105' 7,070.0 7,106.0 5/2/2025 05:30 5/2/2025 06:30 1.00 COMPZN, WELLPR FISH P Obtain parameters 1.5 bpm/460 psi, PUW=95k, SOW=75k RWT=84k, RPM=20, ROTQ=1,900 ft/lbs SOW T/7,134' w/10k down PUW T/115k, hold for 5 min bleed jars RBIH to swallow another 1' SOW T/7,137' w/15k down PUH F/7,134' T/7,124', weight fell off T/95k 7,105.0 7,137.0 5/2/2025 06:30 5/2/2025 07:00 0.50 COMPZN, WELLPR OWFF P Check well for flow 7,137.0 7,137.0 5/2/2025 07:00 5/2/2025 10:30 3.50 COMPZN, WELLPR TRIP P TOOH, F/7,137' T/BHA 7,137.0 258.0 5/2/2025 10:30 5/2/2025 11:30 1.00 COMPZN, WELLPR BHAH P Stand back collars in derrick LD BHA and fish, OAL=31.75' NO COIL recovered. 258.0 0.0 5/2/2025 11:30 5/2/2025 12:30 1.00 COMPZN, WELLPR BHAH T MU fishing BHA w/4-3/4" cut lip quide shoe, 2 joints of 4-1/2" wash pipe and 6 3-1/8" Drill collars. 0.0 290.0 5/2/2025 12:30 5/2/2025 15:30 3.00 COMPZN, WELLPR TRIP T TIH w/BHA #33 290.0 7,165.0 5/2/2025 15:30 5/2/2025 20:00 4.50 COMPZN, WELLPR FISH T Tag TOF @ 7,165' PUW=95k, SOW=75k Set back down, swallow fish T/7,171' Bring pump online, Pressuring up to 2,500 psi with little bleed off. Open bleeder and dump pressure. Warm up jars, straight pull T/115k. Jarring at 125K up to 160 K. Straight pull 150k to 215K. Derrick inspection every 25 licks. Circulation stabished after 52 jar licks. Pump BU at 2BPM 1350 psi. Retrun to jarring 160K and 215K straight pulls. Pulled free at 200K after 74 jar hits. 7,165.0 7,165.0 5/2/2025 20:00 5/2/2025 21:00 1.00 COMPZN, WELLPR CIRC T Circulate BU at 2 BPM/ 780 psi. Perform post jarring inspection while circulating. 7,165.0 7,165.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 19/21 3A-17 Report Printed: 5/30/2025 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 21:00 5/2/2025 22:30 1.50 COMPZN, WELLPR OWFF T Flow check well. No flow. Install TIW, line up to pump through kill line, close upper pipe rams and pump down back side. At 1 BPM pressured up to 630 PSI then flat lines with all fluids pumping away. Flow check well again. No flow 7,165.0 7,165.0 5/2/2025 22:30 5/3/2025 00:00 1.50 COMPZN, WELLPR TRIP T TOOH F/7165' PUW 95K T/3658' PUW 60K 7,165.0 3,658.0 5/3/2025 00:00 5/3/2025 01:30 1.50 COMPZN, WELLPR TRIP T TOOH F/3658' PUW 60K 3,658.0 289.0 5/3/2025 01:30 5/3/2025 03:30 2.00 COMPZN, WELLPR BHAH T LD BHA #33 3-1/2" tubing grapple. No Fish. 289.0 0.0 5/3/2025 03:30 5/3/2025 04:00 0.50 COMPZN, WELLPR SVRG P Grease power tongs and draw works. 0.0 0.0 5/3/2025 04:00 5/3/2025 05:00 1.00 COMPZN, WELLPR BHAH P MU wash pipe BHA to swallow coil tubing and fishing grapple to latch onto coil BHA. 0.0 289.0 5/3/2025 05:00 5/3/2025 07:30 2.50 COMPZN, WELLPR TRIP P TIH, with fishing BHA #34 289.0 7,130.0 5/3/2025 07:30 5/3/2025 09:30 2.00 COMPZN, WELLPR CIRC P Circulate to fill pipe, PUW=94k, SOW=75K Engaged fish 7,155'-7,165', jarring 115k- 125k, straight pull 125-150k let soak, then lost weight TBIH, set down again at 7,165'. PUH clean to previous top of fish 7,112', Circulated BU, OWFF, static TOOH. 7,130.0 7,130.0 5/3/2025 09:30 5/3/2025 13:30 4.00 COMPZN, WELLPR TRIP P TOOH, with BHA #34, racking back DP 7,130.0 289.0 5/3/2025 13:30 5/3/2025 15:30 2.00 COMPZN, WELLPR BHAH P LD Drill collars, LD BHA #34, CT fish recovered Move over and work out of mouse hole breaking down fish. Total 1.75" CT and CT BHA length 61.24'. 289.0 0.0 5/3/2025 15:30 5/3/2025 16:00 0.50 COMPZN, WELLPR SVRG P Grease all handling equipment, drawworks and top drive. 0.0 0.0 5/3/2025 16:00 5/3/2025 16:30 0.50 COMPZN, WELLPR BHAH P MU test packer BHA #35 0.0 5/3/2025 16:30 5/3/2025 18:30 2.00 COMPZN, WELLPR TRIP P TIH F/37.93' T/1860' PUW 48K TIH at 90 FPM max 34.0 1,860.0 5/3/2025 18:30 5/3/2025 19:00 0.50 COMPZN, WELLPR MPSP P Set test packer at 1885' COE PT to 2500 psi for 5 min. Good test. Release packer. 1,860.0 1,860.0 5/3/2025 19:00 5/3/2025 22:00 3.00 COMPZN, WELLPR TRIP P TIH F/1860' T/7100' TIH at 90 FPM max. PUW 92K/ SOW 74K 1,860.0 7,100.0 5/3/2025 22:00 5/4/2025 00:00 2.00 COMPZN, WELLPR MPSP P Testing 5.5" production casing: 7102' COE pumped1BPM away at 700 psi. 6098' COE PT 2500 psi for 5 min good test. 6570' COE pumped1BPM away at 700 psi. 7,100.0 6,570.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 20/21 3A-17 Report Printed: 5/30/2025 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 00:00 5/4/2025 02:00 2.00 COMPZN, WELLPR MPSP P Testing 5.5" production casing: 6478' COE pumped1BPM away at 700 psi. 6383' COE pumped1BPM away at 700 psi. 6290' COE PT 2500 psi for 5 min good test. 6354' COE PT 2500 psi for 30 minutes, charted good test. Narrowed leak down to 29'- Good test above 6354' and failed test above 6383'. 6,478.0 6,383.0 5/4/2025 02:00 5/4/2025 05:00 3.00 COMPZN, WELLPR TRIP P TOOH F/6350' PUW 82K T/38' 6,383.0 38.0 5/4/2025 05:00 5/4/2025 06:00 1.00 COMPZN, WELLPR BHAH P LD test packer BHA 38.0 0.0 5/4/2025 06:00 5/4/2025 07:30 1.50 COMPZN, WELLPR BHAH T MU Fishing BHA with 1-7/8" grapple 0.0 269.0 5/4/2025 07:30 5/4/2025 10:00 2.50 COMPZN, WELLPR TRIP T TIH w/Fishing BHA 269.0 7,159.0 5/4/2025 10:00 5/4/2025 12:00 2.00 COMPZN, WELLPR FISH T KBU, PUW=94k SOW=75 Obtain parameters ROT=21 RPM, Free TQ=1,970 ft/lbs Pumping 3 bpm/525 psi TIH slowly, set down 5k @ 7,165' Work pipe, no indication of latch up. Confer with town team 7,159.0 7,165.0 5/4/2025 12:00 5/4/2025 13:00 1.00 COMPZN, WELLPR OWFF T Check well for flow Strap all old 3.5" Tubing in derrirck 7,165.0 7,165.0 5/4/2025 13:00 5/4/2025 19:30 6.50 COMPZN, WELLPR TRIP T TOOH sideways w/2-7/8" HTPAC DP F/7165' PUW 94K T/226' 7,165.0 226.0 5/4/2025 19:30 5/4/2025 21:00 1.50 COMPZN, WELLPR BHAH T LD BHA #36 Slickline overshot, jars and collars. No fish! 226.0 0.0 5/4/2025 21:00 5/4/2025 21:30 0.50 COMPZN, WELLPR SVRG P Grease Handling equipment, Grease draw works and top drive. 0.0 0.0 5/4/2025 21:30 5/4/2025 22:00 0.50 COMPZN, WELLPR CLEN P Clean up rig floor and RU for RIH with 3.5" killstring. Remove wear bushing. 0.0 0.0 5/4/2025 22:00 5/4/2025 23:30 1.50 COMPZN, WELLPR TRIP P RIH with 14 stands of new 3-1/2" EUEM tubing. POOH and LD 3-1/2" tubing to pipe shed. 0.0 1,316.0 5/4/2025 23:30 5/5/2025 00:00 0.50 COMPZN, WELLPR PULD P POOH and LD 3-1/2" tubing to pipe shed. 1,316.0 900.0 5/5/2025 00:00 5/5/2025 01:00 1.00 COMPZN, WELLPR PULD P Continue POOH and LD new 3-1/2" tubing to pipe shed. 900.0 0.0 5/5/2025 01:00 5/5/2025 08:30 7.50 COMPZN, RPCOMP PUTB P Started finding holes in old tubing. Called town decided to RIH and LD the 14 stands of old tubing. Then only run new tubing. 0.0 1,360.0 5/5/2025 08:30 5/5/2025 09:00 0.50 COMPZN, RPCOMP PUTB P MU Landing Joint Hanger, PUW=80k, SOW=70k Land 3.5" 9.3# L-80, EUE 8RD, new and used tubing. 1,360.0 0.0 5/5/2025 09:00 5/5/2025 09:45 0.75 COMPZN, WHDBOP PUTB P RILDS, test hanger void 0.0 0.0 5/5/2025 09:45 5/5/2025 10:15 0.50 COMPZN, WHDBOP PUTB P Jet BOP stack 0.0 0.0 5/5/2025 10:15 5/5/2025 11:15 1.00 COMPZN, WHDBOP MPSP P Set BPV in IS-A profile with test dart. Test from below with a rolling test 1,050 psi/10 mins 0.0 0.0 5/5/2025 11:15 5/5/2025 14:15 3.00 COMPZN, WHDBOP RURD P Rig crew R/D turnbuckles, pull flow nipple, and perfrom between wells maintenance on BOPs. 0.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 21/21 3A-17 Report Printed: 5/30/2025 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 14:15 5/5/2025 15:45 1.50 COMPZN, WHDBOP NUND P ND BOP's NU Tree and adaptor flange. Hook up and test adaptor flange 3,000 psi / 15 mins 0.0 0.0 5/5/2025 15:45 5/5/2025 16:45 1.00 COMPZN, WHDBOP FRZP P Spot in and RU LRS to IA in celler. 0.0 0.0 5/5/2025 16:45 5/5/2025 17:45 1.00 COMPZN, WHDBOP PRTS P Test tree to 5000 PSI 0.0 0.0 5/5/2025 17:45 5/5/2025 18:15 0.50 COMPZN, WHDBOP MPSP P Pull BPV 0.0 0.0 5/5/2025 18:15 5/5/2025 20:15 2.00 DEMOB, MOVE PRTS P Freeze protect tubing and IA to 2500' with 60 BBL's diesel. U-tube T/IA. Final pressures T/IA/OA=100/100/90 psi. Rig release at 20:00. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 5/5/2025 Page 1/1 3A-17 Report Printed: 6/2/2025 Well Progress Summary Report Job Type: DATA ACQUISITIONALASKA Network/Order Number:10460458 Job Category:WELL INTERVENTION Primary Wellbore Affected:3A-17 Contractor:AES Contractor:HES Contractor:HES Contractor:SLB Contractor:PW Contractor:PW Contractor:HES Contractor:PW Contractor:PW Contractor:PW Contractor:PW Contractor:PW Last 24hr Summary:RUN 1: SET THROUGH TUBING NEO UMBRELLA PLUG AT 7130' IN 5.5" CASING. RUN 2: DUMP BAIL 2 GAL OF CERAMIC BRIDGING BEADS ONTO PLUG RUN 3: DUMP BAIL 5 GAL OF 17 PPG CEMENT ON TOP OF BEADS/PLUG CEMENT DUMPED AT 18:30, AFTER 18 HRS PLUG WILL BE READY FOR ANOTHER 5 GAL OF CEMENT ***JOB IN PROGRESS*** Report Start Date:5/27/2025 05:30 Report End Date:5/27/2025 21:30 Time Log End Time Start Time Dur (hr)Operation 07:00 05:30 1.50 MEET W/ WSL, TRAVEL TO LOCATION. 10:00 07:00 3.00 SPOT EQUIPMENT, RIG UP AND CHECK TOOLS. MAKE UP NEO PLUG. PT 12:30 10:00 2.50 SWAB OPEN, RIH W/ HEAD, 2 X WEIGHT, CCL, NEO RELEASE TOOL, NEO PLUG, CENTRALIZER. OAL = 30', OAW = 200 LBS, MAX TOOL OD = 2.125" SET NEO PLUG BASKET AT 7130.0', CCL OFFSET = 9.5', CCL STOP DEPTH = 7120.5'. POOH. 14:30 12:30 2.00 SWAB CLOSED, MAKE UP BAILER FOR BRIDGING BEADS RUN. 16:00 14:30 1.50 SWAB OPEN, RIH W/ HEAD,CCL, 2.5" X 30' BAILER. OAL = 34', OAW = 100 LBS, MAX TOOL OD = 2.5" STOP 5' ABOVE TOP OF PLUG AND DUMP 2 GALLONS OF BRIDGING BEAD. POOH. 17:30 16:00 1.50 SWAB CLOSED, RIG UP CEMENT RUN 19:15 17:30 1.75 SWAB OPEN, RIH W/ HEAD, CCL, 2.5" X 30' BAILER. OAL = 34', OAW = 200 LBS, MAX TOOL OD = 2.5". STOP 1' ABOVE TOP OF PLUG AND DUMP 5 GALLONS OF CEMENT. POOH. 20:45 19:15 1.50 SWAB CLOSED, LAY DOWN RISER AND RIG DOWN FOR NIGHT. CLEAN UP CEMENT BAILS. 21:30 20:45 0.75 TRAVEL TO F-WING TO SYNC. Secondary Job Type: G Page 1/1 3A-17 Report Printed: 6/2/2025 Well Progress Summary Report Job Type: DATA ACQUISITIONALASKA Network/Order Number:10460458 Job Category:WELL INTERVENTION Primary Wellbore Affected:3A-17 Contractor:AES Contractor:HES Contractor:HES Contractor:SLB Contractor:PW Contractor:PW Contractor:HES Contractor:PW Contractor:PW Contractor:PW Contractor:PW Contractor:PW Last 24hr Summary:***JOB CONTINUED FROM 5/27/25*** ARRIVE AT LOCATION AND NOTIFIED TO RIG DOWN AND ASSIST RIG. ***JOB IN PROGRESS*** Report Start Date:5/28/2025 07:00 Report End Date:5/28/2025 13:00 Time Log End Time Start Time Dur (hr)Operation 08:00 07:00 1.00 MEET W/ WSL, TRAVEL TO LOCATION 10:00 08:00 2.00 ARRIVE AT LOCATION AND NOTIFIED OF POSSIBLE RIG JOB, STANDBY FOR RIG TO COMPLETE CASING PACKER TEST TO SEE IF WE HAVE TO LEAVE AND ASSIST RIG. 12:00 10:00 2.00 NOTIFIED TO ASSIST RIG AND RIG DOWN. 13:00 12:00 1.00 TRAVEL TO RIG. Secondary Job Type: G Page 1/1 3A-17 Report Printed: 6/2/2025 Well Progress Summary Report Job Type: DATA ACQUISITIONALASKA Network/Order Number:10460458 Job Category:WELL INTERVENTION Primary Wellbore Affected:3A-17 Contractor:AES Contractor:HES Contractor:HES Contractor:SLB Contractor:PW Contractor:PW Contractor:HES Contractor:PW Contractor:PW Contractor:PW Contractor:PW Contractor:PW Last 24hr Summary:***JOB CONTINUED FROM 5/28/25*** DUMP BAIL 5 GAL OF 17 PPG CEMENT ON TOP OF PLUG. PLUG SHOULD BE COVERED IN CEMENT. PLUG NEEDS 10 HOURS FOR CEMENT TO CURE BEFORE ADDITIONAL RUNS OF CEMENT CAN BE MADE. ***JOB IN PROGRESS*** Report Start Date:5/29/2025 12:00 Report End Date:5/29/2025 21:00 Time Log End Time Start Time Dur (hr)Operation 13:00 12:00 1.00 MEET W/ WSL, TRAVEL TO LOCATION. 16:00 13:00 3.00 SPOT EQUIPMENT, STRING LINE AND BUILD WEAKPOINT, RIG UP AND CHECK TOOLS. PT. 17:00 16:00 1.00 UNSTAB FROM QTS, HOT CHECK AND ARM BAILER. MIX CEMENT AND PUMP INTO BAILER. 18:30 17:00 1.50 SWAB OPEN, RIH W/ HEAD, CCL, 2.5" X 30' BAILER. OAL = 34' , OAW = 200 LBS, MAX TOOL OD = 2.5". STOP 2' ABOVE TOP OF PLUG AND DUMP 5 GAL OF 17 PPG CEMENT. POOH 20:30 18:30 2.00 SWAB CLOSED, RIG DOWN, CLEAN BAILER. 21:00 20:30 0.50 TRAVEL TO F-WING TO SYNC. Secondary Job Type: G Page 1/1 3A-17 Report Printed: 6/2/2025 Well Progress Summary Report Job Type: DATA ACQUISITIONALASKA Network/Order Number:10460458 Job Category:WELL INTERVENTION Primary Wellbore Affected:3A-17 Contractor:AES Contractor:HES Contractor:HES Contractor:SLB Contractor:PW Contractor:PW Contractor:HES Contractor:PW Contractor:PW Contractor:PW Contractor:PW Contractor:PW Last 24hr Summary:***JOB CONTNUED FROM 05/29/2025*** RUN 5: DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7113' RUN 6: DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7108' RUN 7: DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7103' RUN 8: DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7098' ***JOB IN PROGRESS*** Report Start Date:5/30/2025 05:30 Report End Date:5/30/2025 19:30 Time Log End Time Start Time Dur (hr)Operation 07:00 05:30 1.50 MEET W/ WSL, TRAVEL TO LOCATION. 08:30 07:00 1.50 RIG UP, CHECK TOOL. PT. 09:30 08:30 1.00 UNSTAB FROM QTS, ARM BAILER AND MIX CEMENT. 10:30 09:30 1.00 SWAB OPEN, RIH W/ HEAD, CCL, 2.5" X 30' BAILER. OAL = 34' OAW = 200 LBS, MAX TOOL OD = 2.5". DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7113'. POOH. 11:45 10:30 1.25 SWAB CLOSED, UNSTAB FROM QTS, ARM BAILER AND MIX CEMENT 13:00 11:45 1.25 SWAB OPEN, RIH W/ HEAD, CCL, 2.5" X 30' BAILER. OAL = 34' OAW = 200 LBS, MAX TOOL OD = 2.5". DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7108'. POOH. 14:00 13:00 1.00 SWAB CLOSED, UNSTAB FROM QTS, ARM BAILER AND MIX CEMENT. 15:00 14:00 1.00 SWAB OPEN, RIH W/ HEAD, CCL, 2.5" X 30' BAILER. OAL = 34' OAW = 200 LBS, MAX TOOL OD = 2.5". DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7103'. POOH. 16:00 15:00 1.00 SWAB CLOSED, UNSTAB FROM QTS, ARM BAILER AND MIX CEMENT. 17:15 16:00 1.25 SWAB OPEN, RIH W/ HEAD, CCL, 2.5" X 30' BAILER. OAL = 34' OAW = 200 LBS, MAX TOOL OD = 2.5". DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7098'. POOH. 18:45 17:15 1.50 SWAB CLOSED, RIG DOWN FOR NIGHT AND CLEAN BAILERS. 19:30 18:45 0.75 TRAVEL TO F-WING TO SYNC. Secondary Job Type: G Page 1/1 3A-17 Report Printed: 6/2/2025 Well Progress Summary Report Job Type: DATA ACQUISITIONALASKA Network/Order Number:10460458 Job Category:WELL INTERVENTION Primary Wellbore Affected:3A-17 Contractor:AES Contractor:HES Contractor:HES Contractor:SLB Contractor:PW Contractor:PW Contractor:HES Contractor:PW Contractor:PW Contractor:PW Contractor:PW Contractor:PW Last 24hr Summary:***JOB CONTINUED FROM 05/30/2025*** RUN 9: DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7093' CEMENT NEEDS TO CURE MINIMUM 24 HOURS AFTER LAST BAILER RUN BEFORE PRESSURE TEST. JOB COMPLETE Report Start Date:5/31/2025 05:30 Report End Date:5/31/2025 14:00 Time Log End Time Start Time Dur (hr)Operation 06:30 05:30 1.00 MEET W/ WSL, TRAVEL TO LOCATION. 07:30 06:30 1.00 RIG UP AND CHECK TOOLS. PT 08:30 07:30 1.00 UNSTAB AT QTS, ARM BAILER AND MIX CEMENT. 10:00 08:30 1.50 SWAB OPEN, RIH W/ HEAD, CCL, 2.5" X 30' BAILER. OAL = 34', OAW = 200 LBS, MAX TOOL OD = 2.5". DUMP 5 GAL OF 17 PPG NEO CEMENT ON TOP OF PLUG. EST TOC @ 7093'. POOH. 12:00 10:00 2.00 SWAB CLOSED, RIG DOWN. 14:00 12:00 2.00 MOVE EQUIPMENT TO 3B-12, TRAVEL TO F-WING TO SYNC. Secondary Job Type: G Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,045.0 3A-17A 2/25/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 3A-17A 3/27/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: FISHING NECK GLM @ 5254' MAY BE STRIPPED 8/22/2010 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 121.0 121.0 62.50 H-40 WELDED SURFACE 7 5/8 6.87 39.0 3,821.3 3,305.5 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @7254' 5 1/2 4.95 38.7 7,785.7 6,112.8 15.50 L-80 LTC-MOD LINER A (off AL1) 2 3/8 2.00 8,010.2 9,380.0 4.60 L-80 STL Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 6,974.7 String Max No… 3 1/2 Set Depth … 5,701.6 Tubing Description Tubing – Kill String Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 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) 36.8 36.8 0.12 Hanger 7.000 FMC Gen 4 tubing hanger 3-1/2" EUE TxB X 7" FMC TC-1A- EN 2.900 6,960.6 5,690.5 38.18 Wireline Guide 4.500 3-1/2" 9.3# L-80 EUE 8rd WLEG 3.000 Top (ftKB) 7,178.9 Set Depth … 7,268.0 String Max No… 3 1/2 Set Depth … 5,932.5 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,193.6 5,873.9 38.10 GAS LIFT 4.750 BST ATX 2.900 7,247.2 5,916.1 38.05 NIPPLE 4.500 CAMCO D Nipple NO GO CAMCO D 2.750 7,254.2 5,921.6 38.04 SEAL ASSY 4.500 BAKER GBH-22 SEAL ASSY w/LOCATOR w/ 10' SEALS w/1' SPACE OUT PUP BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,123.3 5,818.5 37.90 PLUG NEO UMBRELLA PLUG, BASKET AT 7130' RKB, BOTTOM OF PLUG AT 7132.6' RKB, TOP OF PLUG AT 7123.3', PLUG OD 1.69", OAL 111", WITH 2 GALS OF CERAMIC BEADS DUMPED ON PLUG BASKET 5/27/2025 0.000 7,188.0 5,869.5 38.13 Slickline Toolstring Fish w/ 3" GS 1.875" TS=5', KJ, 5', 3', OJ, KJSS (29' OAL) w/ 3” GS (brass) 2’ OAL 1/20/2020 0.000 7,219.0 5,893.9 38.01 2.72 Baited JDC 2.72” Bait Sub (2.31 Catch), XO (1.375 FN), and 2.5” Shearable JDC brass (1.375 FN) 1/20/2020 0.000 7,221.0 5,895.5 38.01 Slickline Toolstring Fish w/ 3" RS 1.875" TS=5', KJ, 5', OJ, KJLSS (27' OAL) W/ 3" RS (SPLIT SKIRT) 2’ OAL 1/17/2020 0.000 7,247.2 5,916.1 38.05 2.75 CA-2 Plug 2.75 CA-2 Plug Body (Prong was Pulled) 1/16/2020 0.000 7,396.0 6,032.9 38.48 WHIPSTOCK (AL2) 3.5" MONOBORE BAKER WHIPSTOCK, Orient 20.6 deg., high side looking downhole 10/2/2010 7,412.0 6,045.5 38.51 WHIPSTOCK 3.5" MONOBORE BAKER WHIPSTOCK, Orient 20.6 deg., high side looking downhole 8/31/2010 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) 8,010.2 6,100.2 89.95 BILLET 2.625 LINER TOP ALUMINUM BILLET - COMINGLES WITH AL2 PB1 BILLET (SEE MULTI-LAT DRAWING) 1.995 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,019.0 9,379.0 6,100.1 6,093.4 A-3, A-4, A-2, A- 1, 3A-17A 9/26/2010 32.0 SLOTS Slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,093.0 7,128.0 5,794.7 5,822.2 Cement Plug DUMP BAIL 17 PPG CEMENT ONTOP OF NEO UMBRELLA PLUG (35 GALS) 5/27/2025 3A-17A, 5/30/2025 10:19:46 AM Vertical schematic (actual) LINER A (off AL1); 8,010.2- 9,380.0 SLOTS; 8,019.0-9,379.0 PRODUCTION 5.5"x3.5" @7254'; 38.7-7,785.7 SLOTS; 7,488.0-8,396.0 WHIPSTOCK; 7,412.0 WHIPSTOCK (AL2); 7,396.0 2.75 CA-2 Plug; 7,247.2 Slickline Toolstring Fish w/ 3" RS; 7,221.0 2.72 Baited JDC; 7,219.0 Slickline Toolstring Fish w/ 3" GS; 7,188.0 GAS LIFT; 7,193.6 PLUG; 7,123.3 Cement Plug; 7,093.0 ftKB SURFACE; 39.0-3,821.3 CONDUCTOR; 40.0-121.0 Hanger; 36.9 KUP PROD KB-Grd (ft) 41.00 RR Date 9/2/1996 Other Elev… 3A-17A ... TD Act Btm (ftKB) 9,380.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292269101 Wellbore Status PROD Max Angle & MD Incl (°) 97.04 MD (ftKB) 7,740.32 WELLNAME WELLBORE3A-17A Annotation Last WO: End DateH2S (ppm) 600 Date 8/3/2017 Comment SSSV: NIPPLE STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3A-17A JBR 05/14/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 2 7/8" and 5" test joints used for testing. All looked good. A few issues with failed test equipment were the only issues. Test Results TEST DATA Rig Rep:T. Morales/R. LanghamOperator:ConocoPhillips Alaska, Inc.Operator Rep:R. Phillips/S. Burson Rig Owner/Rig No.:Nabors 7ES PTD#:2101130 DATE:4/9/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopGDC250408152706 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8 MASP: 3463 Sundry No: 325-142 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 3 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5" VB P #2 Rams 1 Blinds P #3 Rams 1 2 7/8"x5" VB P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 2 2 1/16" 5000 P System Pressure P3050 Pressure After Closure P1700 200 PSI Attained P11 Full Pressure Attained P117 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2130 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P25 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 99 9 9 9999 9 9 ORIGINATED TRANSMITTAL DATE: 6/10/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5470 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 5470 3A-17A 50029226910100 Plug Setting Record 27-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@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 210-113 T40539 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.11 08:05:09 -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 ORIGINATED TRANSMITTAL DATE: 5/8/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5408 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 5408 3A-17A 50029226910100 Tubing Cut Record 16-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 210-113 T40391 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 13:09:13 -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 ORIGINATED TRANSMITTAL DATE: 4/21/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5366 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 5366 3A-17A 50029226910100 Tubing Cut Record 27-Mar-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Lorna.C.Collins@conocophillips.com 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 210-113 T40321 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:13:12 -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: Pull/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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9380'7088', 7188', 7221' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other 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 4/12/2025 9380'1370' 3-1/2" Packer: Baker GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 3782' 8019-9379' Slotted Pipe 7747' 2-3/8" 6100-6093' Slotted Pipe 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 121' 3821' 6113'7786' 16" 7-5/8" 81' 7272' MD MD 121' 3305' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025631, ADL0025632 210-113 P.O. Box 100360, Anchorage, AK 99510 50-029-22691-01-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7258' MD and 5925' TVD N/A Cy Eller Subsequent Form Required: Suspension Expiration Date: 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: Cy.Eller@conocophillips.com (907) 265-6049 RWO Engineer KRU 3A-17A 6093' 6784' 5551' 3463 6784', 7250' N/A 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 1:34 pm, Mar 13, 2025 325-142 DSR-3/24/25SFD 4/2/2025JJL 3/21/25 10-404 X AOGCC Witnessed BOP and Annular Test to 3500 psi. If contingent packer is run, ensure packer is set at a depth below the calculated production casing TOC *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.02 15:30:25 -08'00'04/02/25 RBDMS JSB 040325 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3A-17A (PTD# 210-113). Well 3A-17 was drilled and completed in September of 1996 by Parker 245 as a Kuparuk A sand producer. The well was brought online, then in 1999 the Kuparuk C sands were perforated. In 2010, Nabors CDR2 drilled 5 CTD laterals into the Kuparuk A sands. A tubing leak was identified in 2016, and a tubing patch was set from 6,103’ - 6,125’ RKB. In 2018 the well failed a TIFL and the tubing patch was pulled. A plug was set at 7,251’ RKB but failed a DDT after being set. Attempts to remove the plug resulted in multiple coil and slickline fish being left in the tubing. The well requires a workover to pull and replace the tubing. To bring 3A-17A back online, we request approval to proceed with a rig workover to pull and replace the tubing. The 3-1/2” tubing will be pulled from a pre-rig cut above the fish in the tubing, then the tubing section from the pre-rig cut to the seal assembly will be fished. A cleanout and test packer run are planned to confirm the production casing integrity. A new 3-1/2” gas lift completion will be installed. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 3A-17A Kuparuk Producer Pull and Replace Tubing RWO PTD: 210-113 Page 1 of 2 PPre-Rig Work Completed 1. T-POT/PPPOT – Passed 3/3/2025 2. IC-POT/PPPOT – Passed 3/3/2025 3. Function Test LDS – OK 3/3/2025 4. SCLD – Passed 3/3/2025 Pre-Rig Work Remaining 1. Pull all GLV’s and install DV’s leaving the lowest GLM open for a circulation point. 2. Cut tubing at ~6,769’ RKB. Rig Work MIRU 1. MIRU Nabors 7ES on 3A-17A. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater. Record shut-in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier as needed, ND tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve 3-1/2” Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” completion down to the pre-rig cut at ~6,769’ RKB. 6. MU fishing BHA, PU drillpipe and RIH to ~6,769’ RKB. Engage tubing stub and jar tubing section free from sealbore at 7,254’ RKB. a. Close BOPs and condition fluid as needed once seal assembly pulls free. b. Repeat fishing attempts and wash over tubing as needed until tubing section from pre- rig cut to seal assembly is removed. Cleanout Run and Test Packer Run 7. PU DP and RIH with casing scraper to drift and cleanout down to sealbore. 8. MU test packer and test seal assembly to confirm casing integrity to the sealbore. 9. POOH laying down DP. Install 3-1/2” Gas Lift Completion 10. MU new 3-1/2” completion with seal assembly, nipple profile, and GLMs. RIH to sealbore at 7,254’ RKB. a. If test packer and test seal assembly can not confirm sealbore or casing integrity in step 8, a 3-1/2” x 5-1/2” stacked packer will be installed. 11. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 12. Stab seals into sealbore and land tubing hanger, RILDS, drop ball/rod if needed. 13. Pressure test tubing to 3,000 PSI. 14. Pressure test IA to 2,500 PSI. If contingent packer is run, ensure packer is set at a depth within cemented portion of the 5 1/2" production casing. - JJL 3A-17A Kuparuk Producer Pull and Replace Tubing RWO PTD: 210-113 Page 2 of 2 ND BOP, NU Tree 15. Shear out SOV with pressure differential. 16. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 17. Pull BPV and freeze protect well. 18. RDMO. PPost-Rig Work 1. Pull DVs and SOV. Install GLD. 2. Pull ball/rod. General Well Information: Estimated Start Date: 4/12/2025 Current Operations: Shut-In Well Type: Producer Wellhead Type: FMC Gen IV. 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Offset Static BHP: 3,332 psi / 6,013’ TVD measured on 3/7/2025 in offset injector 3A-07 3A-17A Static BHP: 4,020 psi / 5,570’ TVD measured on 8/1/2020 MPSP: 3,463 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion from a pre-rig cut at ~ 6,769’ RKB. Fish tubing section from pre-rig cut to sealbore at 7,254’ RKB. Perform casing cleanout and test packer/test seal run. Install new 3-1/2” gas lift completion. Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Production Engineer: Marina Krysinski Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 7,045.0 3A-17A 2/25/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set TTS pulling tool in RBP 3A-17A 9/18/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: FISHING NECK GLM @ 5254' MAY BE STRIPPED 8/22/2010 lmosbor Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 40.0 121.0 121.062.50 H-40 WELDED SURFACE 7 5/86.8739.03,821.3 3,305.5 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @7254' 5 1/2 4.95 38.7 7,785.7 6,112.8 15.50 L-80 LTC-MOD LINER A (off AL1)2 3/8 2.00 8,010.2 9,380.0 4.60 L-80 STL Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.9 Set Depth … 7,272.1 String Max No… 3 1/2 Set Depth … 5,935.8 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD MOD 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) 36.936.90.12 HANGER 8.000 FMC GEN IV HANGER FMCGEN IV 3.500 507.7 507.7 0.71 NIPPLE 4.530 CAMCO DS Landing Nipple NO GO CAMCO DS2.812 2,961.62,654.5 39.42GAS LIFT 4.750 BSTATX 2.900 4,235.5 3,625.8 40.48GAS LIFT 4.750 BSTATX 2.900 5,254.5 4,398.2 40.82 GAS LIFT 4.750 BST ATX 2.900 6,114.3 5,034.5 40.39 GAS LIFT 4.750 BST ATX 2.900 6,752.6 5,526.5 37.64 GAS LIFT 4.750 BST ATX 2.900 7,197.8 5,877.2 38.07 GAS LIFT 4.750 BST ATX 2.900 7,251.3 5,919.4 38.05NIPPLE 4.500 CAMCO D Nipple NO GO CAMCO D 2.750 7,258.4 5,924.938.02 SEAL ASSY4.500BAKER GBH-22 SEAL ASSY w/LOCATOR w/ 10' SEALS w/1' SPACE OUT PUP BAKER 3.000 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) 4,235.0 3,625.4 40.49 LEAK LEAK @ GLM @ 4235' RKB. 10/15/2010 6,113.0 5,033.6 40.39 LEAK LEAK AT 6113' 5/14/2018 2.992 6,313.0 5,185.8 39.89 LEAK LEAK AT 6313' 5/14/2018 2.992 6,354.0 5,217.239.98 LEAK LEAK AT 6354' 5/14/2018 2.992 6,782.0 5,549.837.37 OTHER Set TTS pulling tool into RBP. (2.31" G F/N 19" OAL) 9/18/2024 0.000 6,784.0 5,551.4 37.36 PLUG 2.72" P2P RBP. w/ EQ Valve and 2' Debris Extension. OAL 7.4' CPP3 5262 8/2/20200.000 6,788.0 5,554.6 37.35 VALVE EQ Valve CPEQ 35033 8/2/20200.000 7,088.0 5,790.7 38.18 CT Toolstring Fish w/ 50' of 1.75' OD Coil BHA = CTC(2.12" X 0.29'), DFCV(2.12" X 1.7'), TTS ACCELERATOR(2.12" X 3.71'), WT BAR(2.12" X 4.91'), TTS BI-DI JARS(2.12" X 6.09'), DISCONNECT(2.12" X 1.57'), FLOW RELEASE JDC (2.17" X 1.9') TOTAL OAL = 20.17' 50' OF 1.75" OD COIL TUBING (WT = 0.109") 3/17/2020 0.000 7,110.0 5,808.0 37.96 LEAK LEAK BETWEEN 7110' & 7147' RKB 1/21/2019 7,188.0 5,869.5 38.13 Slickline Toolstring Fish w/ 3" GS 1.875" TS=5', KJ, 5', 3', OJ, KJSS (29' OAL) w/ 3” GS (brass) 2’ OAL 1/20/20200.000 7,219.0 5,893.9 38.01 2.72 Baited JDC 2.72” Bait Sub (2.31 Catch), XO (1.375 FN), and 2.5” Shearable JDC brass (1.375 FN) 1/20/20200.000 7,221.0 5,895.5 38.01 Slickline Toolstring Fish w/ 3" RS 1.875" TS=5', KJ, 5', OJ, KJLSS (27' OAL) W/ 3" RS (SPLIT SKIRT) 2’ OAL 1/17/2020 0.000 7,250.0 5,918.338.06 2.75 CA-2 Plug 2.75 CA-2 Plug Body (Prong was Pulled) 1/16/2020 0.000 7,396.06,032.938.48 WHIPSTOCK (AL2) 3.5" MONOBORE BAKER WHIPSTOCK, Orient 20.6 deg., high side looking downhole 10/2/2010 7,412.0 6,045.5 38.51 WHIPSTOCK 3.5" MONOBORE BAKER WHIPSTOCK, Orient 20.6 deg., high side looking downhole 8/31/2010 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,961.6 2,654.5 39.42 1 GAS LIFT GLV T-1 1 1,306.0 9/8/2016 0.156 4,235.5 3,625.8 40.48 2 GAS LIFT OVT-1 1 0.0 4/28/20180.188 3A-17A, 3/11/2025 9:15:58 AM Vertical schematic (actual) LINER A (off AL1); 8,010.2- 9,380.0 Shoe; 9,378.6-9,380.0 SLOTS; 8,019.0-9,379.0 BILLET; 8,010.2-8,019.2 PRODUCTION 5.5"x3.5" @7254'; 38.7-7,785.7 FLOAT SHOE; 7,784.7-7,785.7 FLOAT COLLAR; 7,721.2- 7,721.9 SLOTS; 7,488.0-8,396.0 WHIPSTOCK; 7,412.0 WHIPSTOCK (AL2); 7,396.0 SEAL ASSY; 7,258.4 XO PBR 5.5x3.5; 7,258.1- 7,270.4 NIPPLE; 7,251.3 2.75 CA-2 Plug; 7,250.0 Slickline Toolstring Fish w/ 3" RS; 7,221.0 2.72 Baited JDC; 7,219.0 Slickline Toolstring Fish w/ 3" GS; 7,188.0 GAS LIFT; 7,197.8 CT Toolstring Fish w/ 50' of 1.75' OD Coil; 7,088.0 VALVE; 6,788.0 PLUG; 6,784.0 OTHER; 6,782.0 GAS LIFT; 6,752.7 LEAK; 6,354.0 LEAK; 6,313.0 GAS LIFT; 6,114.3 LEAK; 6,113.0 GAS LIFT; 5,254.5 GAS LIFT; 4,235.5 SURFACE; 39.0-3,821.3 FLOAT SHOE; 3,819.8-3,821.3 FLOAT COLLAR; 3,733.3- 3,734.6 GAS LIFT; 2,961.6 NIPPLE; 507.7 CONDUCTOR; 40.0-121.0 HANGER; 39.0-40.5 HANGER; 36.9 KUP PROD KB-Grd (ft) 41.00 RR Date 9/2/1996 Other Elev… 3A-17A ... TD Act Btm (ftKB) 9,380.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292269101 Wellbore Status PROD Max Angle & MD Incl (°) 97.04 MD (ftKB) 7,740.32 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 600 Date 8/3/2017 Comment SSSV: NIPPLE 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) 5,254.5 4,398.2 40.82 3 GAS LIFT GLV T-1 1 1,335.0 11/30/1996 Note 0.156 6,114.3 5,034.5 40.39 4 GAS LIFT OPEN 1 7/29/2016 6,752.6 5,526.5 37.64 5 GAS LIFT DMY T-1 1 0.05/16/20160.000 7,197.8 5,877.2 38.07 6 GAS LIFT DMY T-1 1 0.0 2/4/2007 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,010.26,100.289.95BILLET 2.625LINER TOP ALUMINUM BILLET - COMINGLES WITH AL2 PB1 BILLET (SEE MULTI-LAT DRAWING) 1.995 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 8,019.09,379.06,100.16,093.4 A-3, A-4, A-2, A- 1, 3A-17A 9/26/2010 32.0 SLOTS Slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 3A-17A, 3/11/2025 9:16:01 AM Vertical schematic (actual) LINER A (off AL1); 8,010.2- 9,380.0 Shoe; 9,378.6-9,380.0 SLOTS; 8,019.0-9,379.0 BILLET; 8,010.2-8,019.2 PRODUCTION 5.5"x3.5" @7254'; 38.7-7,785.7 FLOAT SHOE; 7,784.7-7,785.7 FLOAT COLLAR; 7,721.2- 7,721.9 SLOTS; 7,488.0-8,396.0 WHIPSTOCK; 7,412.0 WHIPSTOCK (AL2); 7,396.0 SEAL ASSY; 7,258.4 XO PBR 5.5x3.5; 7,258.1- 7,270.4 NIPPLE; 7,251.3 2.75 CA-2 Plug; 7,250.0 Slickline Toolstring Fish w/ 3" RS; 7,221.0 2.72 Baited JDC; 7,219.0 Slickline Toolstring Fish w/ 3" GS; 7,188.0 GAS LIFT; 7,197.8 CT Toolstring Fish w/ 50' of 1.75' OD Coil; 7,088.0 VALVE; 6,788.0 PLUG; 6,784.0 OTHER; 6,782.0 GAS LIFT; 6,752.7 LEAK; 6,354.0 LEAK; 6,313.0 GAS LIFT; 6,114.3 LEAK; 6,113.0 GAS LIFT; 5,254.5 GAS LIFT; 4,235.5 SURFACE; 39.0-3,821.3 FLOAT SHOE; 3,819.8-3,821.3 FLOAT COLLAR; 3,733.3- 3,734.6 GAS LIFT; 2,961.6 NIPPLE; 507.7 CONDUCTOR; 40.0-121.0 HANGER; 39.0-40.5 HANGER; 36.9 KUP PROD 3A-17A ... WELLNAME WELLBORE 3A-17A Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15.06 62.5 H40 Welded Welded Surface 3821 3306 7.625 6.87 29.7 L80 BTCM BTCM Production 5.5" x 3.5"7786 6113 5.5 4.95 15.5 L80 LTCM LTCM Liner(s)7382 6022 2.375 2 4.6 L80 STL STL Tubing 7272 5936 3.5 2.992 9.3 L80 EUEM EUEM PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" x 1" gas lift mandrels @ TBD 3-1/2" x 2.813" X landing nipple at (2.813" min ID) 3-1/2" Locator Seal Assembly (7258' MD) REMAINING COMPLETION LEFT IN HOLE Baker 4" x 5" PBR/XO @ 7243' RKB 3.5" Cemented liner A-Sand CTD Laterals: 2-3/8" Slotted Liners Surface Casing 3,821' RKB Conductor A-sand CTD Slotted Liner Laterals C-sand Perfs 7347' - 7370' MD B-sand Perfs 7380' - 7390' MD Baker PBR/XO @ 7254' RKB PC TOC: 7,267' MD from 10/29/1996 CBL SC TOC: Surface from 8/27/1996 Cement Detail Calculated TOC from 6/30/1996 Cement Detail: 5,271' RKB CTD KOP @ 7395' MD Production Casing 7,785' RKB 3A-17A Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15.06 62.5 H40 Welded Welded Surface 3821 3306 7.625 6.87 29.7 L80 BTCM BTCM Production 5.5" x 3.5"7786 6113 5.5 4.95 15.5 L80 LTCM LTCM Liner(s)7382 6022 2.375 2 4.6 L80 STL STL Tubing 7272 5936 3.5 2.992 9.3 L80 EUEM EUEM (If sealbore or PC integrity are compromised) PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-2-9 gas lift mandrels @ TBD 3-1/2" PBR and Seal Assembly 3-1/2" Anchor Seal Assembly 3-1/2" x 5-1/2" Packer 3-1/2" x 2.813" X landing nipple at (2.813" min ID) 3-1/2" Stripped Seals (7258' MD) REMAINING COMPLETION LEFT IN HOLE Baker 4" x 5" PBR/XO @ 7243' RKB 3.5" Cemented liner Surface Casing 3,821' RKB Conductor A-sand CTD Slotted Liner Laterals C-sand Perfs 7347' - 7370' MD B-sand Perfs 7380' - 7390' MD CTD KOP @ 7395' MD Baker PBR/XO @ 7254' RKB Production Casing 7,785' RKB PC TOC: 7,267' MD from 10/29/1996 CBL SC TOC: Surface from 8/27/1996 Cement Detail Calculated TOC from 6/30/1996 Cement Detail: 5,271' RKB III STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate nPull Tubing fl Operations shutdown r Performed: Suspend 1— Perforate r Other Stimulate Casing 9 r Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well 17 Re-enter Susp WellrOther: 5-c (t----- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: p(4fr 11 ConocoPhillips Alaska, Inc. Development Fr, Exploratory r 210-113-0 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22691-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025631/ADL0025632 KRU 3A-17A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9380 feet Plugs(measured) N/A true vertical 6093 feet Junk(measured) N/A Effective Depth measured 7381 feet Packer(measured) 6103, 6125, 7258 true vertical 6021 feet (true vertical) 5026, 6043, 5925 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121' SURFACE 3782 7.625 3821 3306' PRODUCTION 7747 5.5 7786 6113' RECEIVED Perforation depth: Measured depth: Slotted liner 8019'-9379' AUG 2 2 2016 True Vertical Depth: 6100'-6093' ACGCG Tubing(size,grade,MD,and TVD) 3.5, L-80, 7258 MD,5925 TVD Packers&SSSV(type,MD,and TVD) PATCH-UPPER PATCH ASSY; 3.5" PIIP PACKER, SPACER PIPE&LATC,H.ASS'Y @ 6103' RKB (OAL =22')@ 6103 MD and 5026 TVD PATCH-STATEWIDE 3 1/2" PARAGON II PACKER(SER#CPP35062) @ 6125 MD and 5043 TVD SEAL ASSY-BAKER GBH-22 SEAL ASSY @ 7258 MD and 5925 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: � scikti Ji',: is J. Z-U 0 1, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r'" Exploratory rr Development ' Service r Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil P Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data f GSTOR r WINJ r WAG r GINJ 1 SUSP E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Dusty Freeborn/Jan Byrne Email: N1617(C�conocophillips.com Printed Name Dusty Freeborn Title: Well Integrity Supervisor Signature Phone:907-659-7126 Date:8/18/16 UT1- A A Form 10-404 Revised 5/2015 /` 31 d U." RBDMS i-c. AUG 2 5 2016 Submit Original Only • • 111. ConocoPhillips RECEIVED �� P.O. BOX 100360 AUG 2 2 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC 18th day of August 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Ms. Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3A-17A PTD 210-113 for a tubing patch set over gas lift mandrel #4. Please call Jan Byrne or myself if you have any questions. Cheers Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 • 3A-17A • DESCRIPTION OF WORK COMPLETED SUMMARY A B 1 2 3 Date Event Summary 4 5 10/13/15 Scale inhibition job pumped and suspected TxIA communication 6 7 12/16/15 S-line work suspected leak between 6109'-6145' 8 9 01/15/16 Leak detect log identified tubing leak at station#4. (6114') 10 06/03/16 CTU performed scale blast to attempt to clean up GLM#4 and clear tubing for potential 11 patch. 12 13 07/08/16 Leak still remains at station#4, verified with 2nd leak detect log. 14 15 08/09/16 Set lower 3.5" PII packer at 6125'. 16 08/13/16 CMIT-TxIA passed. Set snap latch, spacer pipe and 3.5" upper PII packer at 6103'. MIT- 17 T passed. 18 19 08/17/16 TIFL confirmed integrity of tubing patch. 20 21 22 23 24 25 26 27 KUP PROD • 3A-17A ConocoPhillips ��'`ii J Well Attributes Max Angle&MD TD r Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cmoeo Alaska,Inc. 500292269101 KUPARUK RIVER UNIT PROD 97.04 7,740.32 9,380.0 Pre.„. --- Comment 42S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-17A.8/17/2016 5'00:11 PM SSSV:NIPPLE 200 12/27/2014 Last WO: 41.00 9/2/1996 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,045.0 2/25/2016 Rev Reason:SET PATCH pproven 8/17/2016 HANGER 36.9 a74 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ti t.. CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED ill ,!I Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt./Len(I...Grade Top Thread M eu.SURFACE 7 5/8 6.875 39.0 3,821.3 3,305.5 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Leng...Grade Top Thread PRODUCTION 51/2 4.950 38.7 7,785.7 6,112.8 15.50 L-80 LTC-MOD CONDUCTOR;40.0-121.0 5.5"x3.5"@7254' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;507.7 _ LINERA(off AL1) 23/8 1.995 8,010.2 9,380.0 4.60 L-80 STL Liner Details Nominal ID Top(ftKB) Top(TAD)(ftKB) Top Incl(°) Item Des Com (in) 8,010.2 6,100.2 89.95 BILLET LINER TOP ALUMINUM BILLET-COMINGLES 1.995 GAS LIFT;2,061.6 WITH AL2 PB1 BILLET(SEE MULTI-LAT DRAWING) Tubing Strings + Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft..iSot Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 3 1/2 2.992 36.9 7,272.1 5,935.8 9.30 L-80 EUE 8RD MOD Completion Details Nominal ID SURFACE;39.0-3.821.3- .- Top(RKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 36.9 36.9 0.12 HANGER FMC GEN IV HANGER 3.500 507.7 507.7 0.71 NIPPLE 'CAMCO DS Landing Nipple NO GO 2.812 GAS LIFT;4,235.5 <!I 7,251.3 5,919.4' 38.05 NIPPLE CAMCO D Nipple NO GO 2.750 'I 7,258.4 5,924.9' 38.02"SEAL ASSY 'BAKER GBH-22 SEAL ASSY w/LOCATOR w/10'SEALS 3.000 w/1'SPACE OUT PUP Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;5,254.5CI Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 6,103.0 5,026.0 40.34 PATCH UPPER PATCH ASSY;3.5"PIIP PACKER(SN: 8/13/2016 1.600 CPP35050)SPACER PIPE&LATCH ASS'Y(SN: CPAL35043)@ 6103'RKB(OAL=22') 6,125.0 5,042.7 40.44 PATCH STATEWIDE 3 1/2"PARAGON II PACKER(SER# 8/9/2016 1.600 CPP35062) PATCH;6,103.0 II 7,396.0 6,032.9 38.48 WHIPSTOCK 3.5"MONOBORE BAKER WHIPSTOCK,Orient 20.6 10/2/2010 GAS LIFT;6,114.3 < (AL2) deg.,high side looking downhole ill 7,412.0 6,045.5 38.51 WHIPSTOCK 3.5"MONOBORE BAKER WHIPSTOCK,Orient 20.6 8/31/2010 deg.,high side looking downhole PATCH;6,125.0 Perforations&Slots Shot Dens Top(TVD) Ban(TVD) (shotalt GAS LIFT,6,752.7 III:I Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date t) Type Com 8,019.0 9,379.0 6,100.1 6,093.4'A-3,A-4,A-2, 9/26/2010 32.0 SLOTS Slotted pipe- A-1,3A-17A 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends GAS LIFT;7,197.8 Mandrel Inserts St ' all on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) _ Make Model OD(in) Sery Type Type (In) _ (psi) Run Date Com 1 2,961.6' 2,654.5 BST ATX 1'GAS LIFT GLV 'T-1 0.156 1,321.0 10/15/2010 NIPPLE;7,251.3 FFF 2 4,235.5 3,625.8 BST ATX 1 GAS LIFT GLV T-1 0.188 1,346.0 10/15/2010 lI 3 5,254.5 4,398.2 BST ATX 1 GAS LIFT GLV T-1 0.156 1,335.0 11/30/1996 Note SEAL ASSY;7,258.4 ti 4 6,114.3 5,034.5 BST ATX 1'GAS LIFT 'OPEN 7/29/2016 ' 5 6,752.6 5,526.5 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 5/16/2016 ' 6 7,197.8 5,877.2 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 2/4/2007 I Notes:General&Safety WHIPSTOCK(AL2);7,396.0 End Date Annotation 8/22/2010 NOTE:FISHING NECK GLM @ 5254'MAY BE STRIPPED 10/12/2010 NOTE:WELL SIDETRACKED,3A-17A,AL1(off main wellbore),AL2,AL2-01(off mainwellbore) WHIPSTOCK;7,412.0 SLOTS;7,488D-8,396.0 PRODUCTION 5.5-43.5' @7254';38.7-7,785.7 i a a SLOTS;8,019.0-9,379.0 111 II III LINER (off AL1);0,010.2- 9,380.0 V) ;1°r.,_ S Ilo __.-r C or r 4 lV 6co > 7 u u > Q p LL X r0 a _cV W O Q rofl N ��• W[D o cl 6, C _c C pp >- �px pv an u . 0 > ro a E C o Qc o ° 7-3 .Q O O Q o ° -0 > C Q Ln 0 -', tD CO 0 0 CO m 0 CO t O a, E CO C7 y V) 1 p 7 m 0) 0) to tr ) ° c W 1 0 0 0 Q Q Q E -a f° a a Z.. 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U E Pte ° W F F 888 '63 F F- W a) �..{ C7 0 0 0 0 0 C7 co w 0 0 0 0 0 0 0 rn a c Q o 0 0 0 0 U CO - �D 0 0 0 0 0 0 0 0 E - Cr N c0 a0 O NN r 0 coC et a) N o0 r co M- M M 4.4 Q — o ao 0 v etCO N O N 0 N N 4' N• . N ENNNNNNN re. Q.. () T O) M O O) T E E - O - N N O N 0r• O O N N O N -, - — Q1 O O C O d O O O O O (0 O CO u 0 Cr) Cr) N 1() V) U) U) � CO O co wt▪ � O. d 0u O an u C U E a, 06 a � QB ii N = ro z N e , - ± :i 6 '1222 •rn ..= C Q N ,.y M �,.) M M M E E z °I, O O F- a a r f- • PTD2/o-//3 • Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday,August 02,2016 9:21 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: KRU 3A-17 (PTD#210-113-0) Report of IA SCP Attachments: 3A-17 90 day 110 plot jpg;3A-17A.pdf Follow Up Flag: Follow up Flag Status: Flagged S Victoria, KRU producer 3A-17 (PTD#210-113-0)was suspected to have TxIA communication while pumping a scale inhibitor treatment. The well was secured so the IA pressure did not exceed the 2000 psi DNE. Due to the recent wellwork in progress to repair the TxIA communication,the IA pressure recently reached 2200 psi. The production casing is 5%", 15.5 Ib, 1-80 casing with a burst rating of 7000 psi. Slickline is actively working on the well in attempts to repair the leak. If the leak cannot be repaired the well will be secured again with a plug downhole and the pressures bled back down while re-evaluating a new plan forward. Please let me know if you have any questions or disagree with this plan. I have attached a schematic and 90 day TIO plot. Regards, Rachel Kautz Well Integrity Engineer,ConocoPhillips Alaska,Inc. Temp.Slope Phone:907-659-7126 1 ii • KUP PROD • 3A-17A virConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. I Wellbore APIIOWl Field Name Wellbore Status nd(°) MD(REB) Act Bim(ft(B) cmoc.;,M.,c 500292269101 KUPARUK RIVER UNIT PROD _ 97.04 7,740.32 9,380.0 , ... .� Continent H2S(ppm) Date Annotation End Date KB-GM(ft) Rig Release Date 3A-17A,5(18/2016 4;51:49 PM SSSV:NIPPLE 200 12/27/2014 Last WO: 41.00 9/2/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,045.0 2/25/2016 Rev Reason:GLV C/O.PULL CATCHER's,SLIP pproven 5/18/2016 -STOP,K-3 PACKOFF HANGER;36.9 ITS Casing Strings •_Ii Casing Description 00(in) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVD)...Wt0.en(1...Grade Top Thread ke 1) CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED J" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(1...Grade Top Thread ,,, . ,„„„„,,,„„,„„,„„ ,,SURFACE 7 5/8 6.875 39.0 3,821.3 3,305.5 29.70 L-80 BTC-MOD IIIICasing Description OD(m) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVD)...Wt/-en(I...Grade Top Thread r PRODUCTION 51/2 4.950 38.7 7,785.7 6,112.8 15.50 L-80 LTC-MOD 5.55,3.5"@7254' CONDUCTOR:40.0.121.0 Casing Description 00(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)...WtiLeen(I...Grade 'Top Thread LINER A(off AL1) 2 3/8 1.995 8,010.2 9,380.0 4.60 L-80 STL NIPPLE;5077Eil Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Com (in) 8,010.2 6,100.2 89.95 BILLET LINER TOP ALUMINUM BILLET-COMINGLES 1.995 GAS LIFT;2,961.6 WITH AL2 PB)BILLET(SEE MULTI-LAT DRAWING) Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(IVO)(...Wt(Ib81) Grade Top Connection TUBING 3 1/2 2.992 36.9 7,272.1 5,935.8 9.30 L-80 EUE 8RD MOD Completion Details Nominal ID Top(ftKB) Top(TOD)(ftKB) Top Incl 1°) Item Des Com (in) SURFACE;390-3.821.3-•I I) 36.9 36.9 0.12 HANGER FMC GEN IV HANGER 3.500 507.7 507.7 0.71 NIPPLE CAMCO DS Landing Nipple NO GO 2.812 7,251.3 5,919.4 38.05 NIPPLE CAMCO 0 Nipple NO GO 2.750 GAS LIFT;4,235.5 <Y 7,258.4 5,924.9 38.02 SEAL ASSY BAKER GBH-22 SEAL ASSY w/LOCATOR w/10'SEALS 3.000 w/1'SPACE OUT PUP Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top MKS)_ (ftKB) (°) Des Corn Run Date ID(In) GAS LIFT;5,254.5 - 7,396.0 6,032.9 38.48 WHIPSTOCK 3.5"MONOBORE BAKER WHIPSTOCK,Orient 20.6 10/2/2010 (AL2) deg.,high side looking downhole 7,412.0 6,045.5 38.51 WHIPSTOCK 3.5"MONOBORE BAKER WHIPSTOCK,Orient 20.6 8/31/2010 deg.,high side looking downhole Perforations&Slots GAS LIFT;6,114.3 Shot Dens Top(TVD) 080(TVD) (shote/f Top(MB) atm(ftKB) (ftKB) MKS) Zone Data t) Type Com 8,019.0 9,379.0 6,100.1 6,093.4 A-3,A-4,A-2, 9/26/2010 32.0 SLOTS Slotted pipe- A-1,3A-17A 0.125"x2.5"@ 4 circumferential adjacent GAS LIFT;6,752.7 rows,3"centers staggered 18 deg,3'non -slotted ends Mandrel Inserts St all on Top(TVD) Valve Latch Port Sire TRO Run GAS LIFT;7,197.8 N Top OMB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,961.6 2,654.5 BST ATX 1 GAS LIFT GLV T-1 0.156 1,321.0 10/15/2010 2 4,235.5 3,625.8 BST ATX 1 GAS LIFT GLV T-1 0.188 1,346.0 10/15/2010 3 5,254.5 4,398.2 BST ATX 1'GAS LIFT GLV T-1 0.156 1,335.0 11/30/1996 Note NIPPLE;7,251_3 4 6,114.3 5,034.5 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 1/192016 EXT PKG li�il 5 6,752.6 5,526.5 FBST ATX 1 GAS LIFT DMY T-1 0.000 0.0 5/16/2016 I�'1 6 7,197.8 5,877.2 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 2/4/2007 SEAL ASSY;7,258.4 i Notes:General&Safety fi End Dale Annotation 8/22/2010 NOTE:FISHING NECK GLM @ 5254'MAY BE STRIPPED I 10/12/2010 NOTE:WELL SIDETRACKED,3A-17A,AL1(off main wellbore),AL2,AL2-01(off mainwellbore) WHIPSTOCK(AL2);7,396.0 WHIPSTOCK;7,412.0 SLOTS;7,488.0-8,398.0 II PRODUCTION 5.5'4.8" 07254'38.7-7,785.7 SLOTS;8,019.0-9,379.0 LINER A(off AL1);8,0102- 9,3800 • tn ° • . r 0 cc �, �.3o i _ CDoZ 1mu v O_ , s N o) O .0 t C _" r r r r r r r r Co on ' F >- I o (0 Y Cl, o w 1111 Q N 4 O O 6 ,,/ H p ro c ro > Q Q t' ' p —I co cc co COc_o cc o O cu E s m �. _ _ 7 r 7 7 10 14 vi y C C_ ro N Z N co co O N W C C Q > w > Q a o 10 E ° y CC v a, - > = -Ero D 0000000 p '-' v _c _c c w J J J J J J J J @ u >a W W W W W W W W pMc r`o 0 .-- F- LL LL U.. LL LL LL U.. LL vi N E -O ,4 O Q J J J J J J J J ,-, O C O N Og ,Cr) O Z Z Z Z Z Z Z Z v CO -O �. LL LL LL LL LL LL LL LL W t = Cu • E 6 y > Y O 1+ w O G E °) v O Z C, a N -0 P. ti 0 C o _0 c v `, G -. a CD > > Co G O Yr 2 ~ c CO 0 a) �O u Q a) t u > U Lc , pm aaJ0 a Y .0 oo JJ @ •yore J C.) m a v v a v CO a a g E. O a� a ercc d o > ze c� h4 CO W a N W o C7 p o cm.t oodSd ii at G a O lo !g it z \ i.) r y x ro w O > LU y 03 "Z to ' . V C~. J J J _J O J J J Q A �a 03 C., 2 � 333 E S 3 , e Z "1aa 2 " W ?,..p.12„9111# r1/ p Z a: o > > v Q W > > > > W Ce > W m 44) 01 tiln, 2 W R 2 W W W W w z Y Y Y Y Et Y > E CI W W W W Y Y W r w_ Q Q Q Q > > Q J a) u tL D > > > •Q Q > > N N0 1,f�a� Y Y Y Y ? ? Y 0 �, + Zvi x n 0.p K W N C) '- N 0 C) O) Cov al =�0 CI o 111 r r o 0 0 0 50 O ° 000000 0 ro 0 0 0 0 0 0 0 0 it N 0v U O p p 6 p LL 6 E ZEISS ot 03 03> 00 >- ).. 2 ›.. 0 5 � ,r•4 w p p U O p O p 0 v c as sl0$ X C ra r,• p o O O r 0 �^n lD 0 • 0 0 0 0 0 O 0 ru, a' `41' t0 a, O to W to c to E N N r N N r N O O v, C C IN N N N N N N N N u N. O O) O) O) O) O M M 0 _c N NN NN N 0 0 i Oi O O O O O O r 4) �`r,' O O O O O O O O 'L _• 00 C +' O CO K r•i :� O. U C 01 E a > v Qp. c c E Cl- 1 = aul n a� � QQ > m N m d Q N M C,) CI N N U E Z N Y C C) c a • 4111 2.C9%0G WELL LOG TRANSMITTAL#903057461 To: Alaska Oil and Gas Conservation Comm. February 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED I,� Anchorage, Alaska 99501 DATA LOGGED /2M/2o1( FEB 1 0 2016 M.K.BENDER AOGCC RE: Leak Detect Log: 3A-17A Run Date: 1/15/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3A-17A Digital Data in LAS format,Digital Log file 1 CD Rom 50-029-22691-01 Leak Detect Log (Field print) 1 Color Log 50-029-22691-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari ` CANN t "• ' s 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/224 ILc.øt o c 0 Cu O .0 U V" cr) 73 CO 3 d CO Z 0 rnm rn Cl �I c a s ✓ o °? E �-° c a iA ° co c a a c m o �� 2 2 Z o U � =Ii 0 0 > Ind _o m o 0 0 °- a° 0 0 0 0 4 J U y V N N N 2 Q p o CC N N N U J Z E ' '' c 'I 2 c c c C C c a) d Cu c o• = a a. 0) a Cl) a " E"' J N o U 0 0 0 O O O �o co Ce a ! 0 a 0 0 0 0 0 0 O N Cu ° ao ao 0o ao ao ao a! d Z Z 0 N 0) 0) 0) 0) Cr) 0) Q y£ W a I , tI � h. h. U) U) U) co z Ce O 2 N N O a ; �. U (/) t- N- N- n n v W Z 0 J > 0 U o �, Z c m a ■ Q « c Z W Z I- to O C a) = 7) O J a Cu (a 2 to- Om 1 O CO c ZI c1) ° J o 0 0 U U U 5 N ° 2 y 0 Q t a) t,A O _00 E O. I N (NI in is U � co U) I Q cx ) O O II 0 ! M II z N i i ! Z c 11 CO W• o t C I h Y t Q Q N Q Y °- 1( l a) Q ZI cn .. ' I Z o W aTi > > > '> Q 3 U ! a Z Z to y y .N .N 'co, . N Cu = 0 CO - cc cc cc x C C C C C • 0 I = Cu d a) o _ _ 0 Z I5 O c c c c '._ m o p Z p y y i o j E o M O J r y d NI- w I m III O ~ Q L E W Z N H a' I T I z N Q, O Q '.°� d Q N Q C R a+ a a) LL cs. > OLL E E 0 E E ? a • 0 ? w rnLL Q co z a �. ? m o M C I ! L9 1 \ o U• o Q a Of+� a o �. O O O d O ?o t c 0 o 0 re a o 3 J G t— W d J J J Q > 0 Q 0 1 0 ConocoIV Phillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 7:1' 7�I_) March 9, 2012 Commissioner Dan Seamount t 1 ,? y lg11J .a.,rl;' n 26JiJ Alaska Oil&Gas Commission 1 i''-.ii. f-iq° ' 333 West 7th Avenue, Suite 100 _._ — Anchorage,AK 99501 a1O - X13 Commissioner Dan Seamount: 3 A — 17 , Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells were 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 cement was pumped in the fall of 2011. The corrosion inhibitor/sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name,top of cement depth prior to filling,and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerel , /1l/Jc......_#.,..,,-- ----- MJX/ oveland 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 1 Date 3-09-2012 3A,3G,3H,3K PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3A-17A 50029226910100 2101130 3'6" NA 13" NA 5.95 2/14/2012 3G-20 50103201410000 1901230 SF NA 24" NA 3.83 2/14/2012 31417 50103200810000 1870990 19" NA 19" NA 3H-21 50103200940000 1880080 8" NA 15" NA 4.25 2/14/2012 3H-23A 50103202040100 1961860 6" NA 12" NA 6.38 2/14/2012 3K-102 50029233780000 2071650 SF NA 16" NA 6.8 2/14/2012 I 1 STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMIS, N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other Cconductor Alter Casing r Pull Tubing r Fbrforate New Pool Waiver Extension r r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 210-113 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r " 50-029-22691-01 `- 00 7.Property Designation(Lease Number): °� I 8.Well Name and Number: ADL0025632 © (3J 12` • 3A-17A 9.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9380 feet Plugs(measured) None true vertical 6093 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 7258 true vertical 0 feet (true vertucal) 5925 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 1640 630 SURFACE 3782 10 3821 3305 4790 6890 PRODUCTION 7747 5.5 7782 6113 6290 7740 Perforation depth: Measured depth: Slots 7382-9431 RECE I\/ED True Vertical Depth: Slots 6093-6119 DEC 2 8 2011 Tubing(size,grade,MD,and ND) 3.5",9.3 PPF, L-80, 7272 MD, 5936 ND A�Zt=k,Oil&Gas Cons.Commission AnOleiallt Packers&SSSV(type,MD,and ND) PACKER=SEAL ASSY-BAKER GBH-22 SEAL ASSY @ 7258 MD and 5925 ND SSSV=CAMCO"DS" NIPPLE @ 508 MD and 508 ND 11.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA _ NA Subsequent to operation NA _ NA NA NA NA 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r . Service r Stratigraphic r 15.Well Status after work: . Oil r Gas r VIDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 311-356 Contact MJ Loveland/Martin Walters Printed Name Martin Walters Title Well Integrity Project Supervisor Signature Phone: 659-7043 Date: 12/24/11 RBDMS DEC 2 82011 /. g /2....,Form 10-404 Revised 10/2010 Submit Original Only lov ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 24, 2010 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 3A-17A, PTD 210-113, Sundry 311-356, gas lift oil, conductor extension. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor Name of Recipient Page 2 of 2 12/25/11 3A-17A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/23/11 Prep&weld 12"conductor extension with 16"62# .375 pipe. • f'f t G i {M. 4 • I y *F; I. k S�It p} S,•1 t i toy+nr' , ' i w „,,.,,,..,i, ,,. P i :III3"!S F � 5 ,,, , n fj i 4: A Yx+� k.. s r ,.A a t' 5 �, i ' { , ^Yi"y t 1 tUf r f" itt I. t NAB- d a 6)1TAT i /A, S EA PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 a t Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-17A Sundry Number: 311-356 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A Daniel T. :eamount, Jr. Chair DATED this hp day of November, 2011. Encl. -TATE OF ALASKA Its •r RECEIVED ALA. OIL AN. AS CONSERVATION COMMIS_ J VA ` APPLICATION FOR SUNDRY APPROVALS_ NOV 15 201 20 AAC 25.280 PP��,,!! (� (���� 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well 1 Ia6kaChNr RP ���'� � Sibs Suspend r Rug Rerforations r Perforate r Rill Tubing r A liCrffiNifyiension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: conductor extention r • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 210-113-0 • 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-22691-01 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No � 3A-17A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025632 . Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9380 • 6093 • _Casing Length Size MD ND Burst Collapse CONDUCTOR 81 16 121' 121' SURFACE 3782 10 3821' _ 3305' PRODUCTION 7747 5.5 _ 7782' 6113' LINER A 1370 2.625 9380' 6093' - Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots 8019-9379 slots 6100-6093 3.5 L-80 7258 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) SEAL ASSY-BAKER GBH-22 SEAL ASSY W/LOCATOR W/10'SE MD=7258 ND=5925 Nipple MD=508' 12.Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/25/2011 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my kno dge. Contact: MJ Loveland/Martin Walters Printed Name MJ Lovelan Title: Well Integrity Project Supervisor / Signature L� l Phone:6 5�-7p y3 Date //%$`// Commission Use Only Sundry Number 3I I -35( Conditions of approval: Notify Commission so that a representative may witness �J Plug Integrity r BOP Test Dr Mechanical Integrity Test r Location Clearance r Other: F)12-e, d e 4-GC. a��.0-1■ Gre 4J•r Subsequent Form Required: (0— 4-/c.‘( do 4,/ APPROVED BY Approved by L -, COMMISSIONER THE COMMISSION Date: ////6/C i\ •n�e tl•lG 4 i�. Form 10-403 - ��C�1f1�1��� 1 7 Mtg., Submit in Duplicate t ,t C IGI �IAL 4106, ConocoPhillips Alaska,Inc. Kuparuk Well 3A-17A (PTD 210-113-0) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 13, 2011 This application for Sundry approval for Kuparuk well 3A-17A is to extend the conductor to original height so as to prevent any further corrosion to SC. This well is Kuparuk gas lifted oil well and is currently on line. At some point during normal operations the conductor subsided about 12" inches. With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor. 2. Examine SC below where landing ring was for any corrosion damage. 3. Install anti-corrosion coating on SC as specified by CPAI Corrosion Engineer. 4. Extend the conductor to braiden head and fill the void with cement and top off with sealant. 5. File 10-404 with the AOGCC post repair. L� p NSK Problem Well Supervisor 05/07/05 Company ConocoPhillips, Alaska, Inc. BAI HI Well Name 3A-17A Date 11/22/2010 MITE() )nocoPhillips Alaska Greater Kuparuk Area*** Data Distributil ... . .. .. ... .. . ... RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Har d, o v Christine Mahnken 1 Graphic image file I Disk*, 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP ..__.._. 1 Hardcori.' Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk* David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 ; arcco r,�; `'r Glenn Fredrick 1 Graphic image file 1 ;s;,�* P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS ai rdon, Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas I D sk ! 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS DS Engineer / Rig Foreman TOTAL Hardcopy Prints 4 Graphic Image File 4 Electronic Data 5 1 (//0q11b 10 - 1 (3 a04-130 Page 1 of 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q • Exploratory ❑ GINJ ❑ WINJ El WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: October 11,2010 210-113/' 3.Address: 6.Date Spudded: tt (�..to 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 Septembe3,20 0 ' 50-029-22691-01 ` 4a.Location of Well(Governmental Section): 7.Date TD Reached: , 14.Well Name and Number: Surface: 663'FSL,785'FEL,Sec.7,T12N,R9E, UM . September 25,2010 3A-17A • Top of Productive Horizon: 8. KB(ft above MSL): 82'RKB 15.Field/Pool(s): 1892'FNL,2772'FEL,Sec. 17,T12N, R9E, UM GL(ft above MSL): 40'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2547'FNL,3335'FEL,Sec. 17,T12N, R9E, UM ' 7362'MD/6006'TVD Kuparuk River Oil Pool . 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: . Surface: x-507663 - y- 5997044• Zone-4 • 9380'MD/6093'TVD - ADL 25631,25632 TPI: x-510967 y- 5994494 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-510407 y- 5993839 Zone-4 nipple @ 508'MD/508'TVD 2564,2565 18.Directional Survey: Yes 0 No 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1465'MD/1445'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.07t): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7414'MD/6047'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 121' Surf. 121' 24" 212 sx AS I 7.625" 29.7# L-80 Surf. 3821' Surf. 3306' 9.875" 1020 sx AS III,340 sx Class G 5.5"x 3.5" 15.5#/9.3# L-80 Surf. 7782' Surf. 6334' 6.75" 190 sx Class G 2.375" 4.6# L-80 8010' 9380' 6100' 6093' 3" slotted liner 24.Open to production or injection? Yes 0 No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 7272' none 8019'-9379'MD 6098'-6093'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ++rri-L - VA ` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I li t 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) October 17,2010 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/19/2010 12 hours Test Period--> 984 338 963 24 Bean 421 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 179 psi 269 24-Hour Rate-> 1805 760 1893 23.5 deg. 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water ( (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. If _ E M I ED NONE NOV 0 8 2010 RBDMS Nov 0 5 .20115 a R a Say Cons.Cc ;,sror� AnplIrspnii Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only % / 76 el a it) "0/iof%2 6 28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1465' 1445' needed,and submit detailed test information per 20 AAC 25.071. A-2 sand 8460' 6112' Bottom A-2 sand 9360' 6092' N/A Formation at total depth: Kuparuk A sand 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,definitive directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill ng @ 263-4093 11106//a Printed Na Ca a Title: Alaska Wells Manager ` !, Signature Phone 265-6306 Date zr) v Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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String...,String Top Thrd b HANGER,37 r F CONDUCTOR 16 15.062 40.0 121.0 62.50 11-40 WELDED t A P Coning Daserip6ion String 0... String ID...Top(ftKB) Set Depth(T...Sat Depth(WD)._String WL..String..-String Top Thrd I I SURFACE 7 5/8 6.059 39.0 3,821.3 29.70 L-80 BTC-MOO Casing Deuriplton String 0... String ID..Top(ftKB) SM Depth(f...Set Depth(ND)...String WL..String...String Top Thrd �, PRODUCTION 5 1/2 4.950 35.0 7,782.0 15.50 L-80 LTC-MOD 5.5"x3.5"CONDUCTOR, Casing Description String 0... String ID Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 1 40508 LINER A 23/8 1.995 8,010.2 9,380.0 4.60 L-80 STL t NIPPLE.508- Liner Details — If Top Depth (TIED) Top Incl Morel- liTepP(gl_ (ftKB) (') Rem Desaipton Comment ID(in) GAS LIFT, 8,010.2 BILLET LINER TOP ALUMINUM BILLET-COMINGLES WITH AL2 P61 BILLET 1.995 2,962 (SEE MULTI-LAT DRAWING) Tubing Strings Tubing Description String 0 1St ring ID To ftKB Set Depth f...Set Depth(TVD) "String Wt... 'String Top Thrd i 9 PI ) P ( P ( ) 'String-- 9 P TUBING 3 112 1.992 36 9 7272.1 9 30 L-80 �EUE 8RD MOD Completion Details Top Depth i SURFACE, (TVD) Top Inc! 39-3,821 Top(ftKB)1 (ftKB) (1 Item Description Comment ID(in) V 36.9 I(ANGER FMC GEN IV HANGER 3.500 GAS LIFT, 507.7 NIPPLE CAMCO DS Landing Nipple NO GO Mi 4,236 7,251.3 NIPPLE CAMCO D Nipple NO GO 2.750 i I li,, 7,258.4 SEAL ASSY BAKER GBH-22 SEAL ASSY w/LOCATOR w/10'SEALS w/SPACE OUT 3.000 PUP GAS LIFT, 111E::: Other In Hole reline retrievable plugs,valves,pumps,fish,etc.)5,254 Top D) OW) Top Ind IC; 'rep(KKB) ("KB) (1 Deeaiption Comment Run Date' 7,396.0 WHIPSTOCK 3.5"MONOBORE BAKER WHIPSTOCK,Orient 20.6 deg., 10/2/2010 ■ j_ (AL2) high side looking downhole , GAS LIFT, ___.. . 7,412.0 WHIPSTOCK 3.5"MONOBORE BAKER WHIPSTOCK,Orient 20.6 deg., 8/31/2010 6,114 (high side looking downhole Perforations&Slots Shot Top(TVD) Bim(TVD) Dens GAS LIFT,_ net" T.. 6N(B Ben ftKKK (kKB) (ftKB) Zone Dane (eh... Comment 6,753 _ _ -__— 8,019.0 9,379.0 A-3,A-4,A-2, 9/26/2010 32.0 SLOT Slotted pipe-0.125"z2.5"@ 4 A-1,3A-17A circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends GASi;F98 --- L.. "7„i' Notes:General&Safety End Date Annotation 8/22/2010 NOTE.FISHING NECK GLM @ 5254'MAY BE STRIPPED 10/12/2010 NOTE:WELL SIDE TRACKED,3A-17A,AL1,AL1,AL2,AL2-01 NPPLE,7,251 I ('.. I .. I SEAL ASSY, a j 7,258 X I WHIPSTOCK (AL2),7,396 SLOT. 7,388.7,420 WHIPSTOCK, 7,412 PRODUCTION 5.5"03.5", 35-7,782 SLOT. 7488-6,396 Mandrel Details Ii SLOT. Top Depth Top Port _ T--- 7,497-9,249 (TVD) Ind OD Valve Latch Sine TRO Rune SLOT, Stn Top (ftKB) (°I Make Model (in) Sere TY Pe Type (in) (psi) Run Date Com... 8,019-9,379 LINERAL2-01, 1 2,961.6] BST ATX 1 GAS LIF I DMY T-1 0.000 0.0 8/20/2010 7,381-9.250 LINER& 2 4,235.5 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 9/14/1996 8,0109,380 TO(3A-17A), y 3 5,254.5 BST ATX 1 GAS LIFT GLV T-1 0.156 1,335.011/30/1996 Note 9,380 LINER AL1, 4 6,114.3 BST ATX 1 GAS LIFT DMY T-1 0.000 0.09/14/1996 7,410-9,430 5 6,752.7 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 8/22/2010 6 7,197.8 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 2/4/2007 ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 3A-17 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 9/21/2010 12:00:00 AM Rig Release: 10/11/2010 9:00:00 PM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09/21/2010 24 hr Summary Accepted rig 00:00-hrs,21-Sep. Completed BOPE testing. (State test waived by Bob Noble.) Pumped cable slack and cut 1600'CT pipe management. Conducted pre-spud meeting and proceeded CTC/re-head operations. 00:00 13:30 13.50 0 0 MIRU WHDBO BOPE P ***Rig Accept**** Bop testing 4000 g psi high 250 low.State test waived by Bob Noble. I L1 13:30 15:00 1.50 0 0 MIRU WHDBO PRTS P Check all valve alignment and pump slack MNGT back into reel before cutting 1600'of pipe. 15:00 17:00 2.00 0 0 MIRU WHDBO PRTS P Clean up rig floor and prep for pulling BPV. 17:00 18:00 1.00 0 0 MIRU WHDBO PRTS P Rig down FMC&set up to cut 1600' CT pipe. 18:00 21:00 3.00 0 0 SURPRI WELLPF CTOP P Cut 1604'of CT for pipe management. (Found cable end 36' up pipe from slack management.) 21:00 22:00 1.00 0 0 SURPRI WELLPF SFTY P Pre-spud meeting in conference room with call-in to CTD Engineer Jill Long. PJSM with crew. 22:00 00:00 2.00 0 0 SURPRI WELLPF CTOP P Stab pipe;service gooseneck(adjust rollers). Call out BOT as CTC/re-head initiated. 09/22/2010 Milled 2.74"window 7414-7418'through 3.5"liner into formation,depth 7428'. Performed two backream passes and dry-tagged 7428',swapping hole to 9.8-ppg Flo-Pro mud. Pressure undeployed window milling assembly and pressure deployed under ream BHA with 2-1/8"straight workover motor. 00:00 02:30 2.50 0 SURPRI WELLPF CTOP P Make up CTC and pull/pressure test 36K#/4000-psi. Head-up. 02:30 03:30 1.00 SURPRI WELLPF CTOP P PT PDL 2500-psi and TT line 1000-psi. 03:30 04:00 0.50 SURPRI WELLPF CTOP P Make up nozzle and stab on well to check for pressure: 0-psi. Stab off well. 04:00 05:30 1.50 73 PROD1 WHPST PULD P Make up milling BHA.. 05:30 07:30 2.00 73 7,200 PROD1 WHPST TRIP P RIH window milling BHA EDC open. IA 65/OA 390.taking returns to tiger tank. Inspect injector&pipe while RIH.Tie in+2 07:30 08:30 1.00 7,200 7,388 PROD1 WHPST MILL P Light tag @ 7368'-P/U 29K, bring pump rate up to 1.5 bpm, Smooth down to 7388', P/U weight 32K.,§tart milling ampnt 73RR'IA R7/[lA _ 456. Swap to milling fluid. Cement in returns. 08:30 10:30 2.00 7,388 7,414 PROD1 WHPST MILL P Mill through cement to TOWS @ 7414'. P/U and wiper through cement area.Start milling window. Page 1 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10:30 13:00 2.50 7,414 7,417 PROD1 WHPST MILL P Start milling window-1.50 bpm, 2900 psi, BHP 3250,WOB 2.1K, ROP 1 fph,CT weight 8.5K. Light metal shavings @ 7415' 13:00 15:00 2.00 7,417 7,418 PROD1 WHPST MILL P Start holding MPD 400 psi on WH. Pf 1.45 bpm,3300psi, BHP 3662, ROP 1 fph,WOB 1.3K, Ct weight 8K. _ Good metal returns. 15:00 17:30 2.50 7,418 7,428 PROD1 WHPST MILL P Exit out window,Continue milling ahead @ 1 fph. Increase to 2 fph @ 7419', 8%formation in returns. Increase to 3-5 fph. 0 17:30 18:00 0.50 7,428 7,428 PROD1 WHPST MILL P Backreami ng passes&dry-tag was clean. New 9.8 mud around. 18:00 20:00 2.00 7,428 ✓ 0 PROD1 WHPST TRIP P POOH. ✓ ,7 20:00 22:15 2.25 0 0 PROD1 WHPST PULD P Pressure undeploy window milling BHA and make up under reamer. Guage go/no-go diamond window mill,2.73",and string mill,2.74". Pressure deploy under ream BHA with 0.6-deg AKO motor. Experience chain traction issue attempting to strip injector head down pipe to insert upper riser into lower riser. Skate traction system not bleeding off pressure. Bleed pressure and continue. 22:15 00:00 1.75 0 0 PROD1 WHPST PULD P Discuss toolstring configuration with CTD Engineers prior to RIH and decide to run 2-1/8"straight workover motor to mitigate any additional risks introduced to under ream process by AKO motor. Pressure undeploy under ream BHA reconfigure tool and proceed with pressure deploy under ream BHA with 2-1/8"straight workover motor. 09/23/2010 Under reamed cement 7385-7408'. Pressure undeployed under ream BHA and pressure deployed build drilling BHA. Drilled build to 7720-ft with 9.8-ppg Flo-Pro. Performed wiper trip#1 up through window with gamma tie-in(+2')and logged RA marker on whipstock:TOWS 7415'; RA marker 7421'; and BOW 7422'. Observed clean passes through window. 00:00 01:00 1.00 0 0 PROD1 WHPST PULD T Mechanic dispatched to fix leak at B-4 lower choke HCR valve during motor swap process. Also discover some superficial marks on pipe during pressure deploy that may be symptomatic of continued chain tension issue where system will not dump pressure to release skate tension. Mechanic fixed hydraulic issue on B-4 HCR. Page 2 of 20 S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 0 0 PROD1 WHPST PULD T During pressure test PDL step, observe leak at B-4 HCR valve flange. Tighten and re-PT PDL. Continue pressure deploy under ream BHA. Again observe Hyd. leak at B-4 HCR valve. Replace Hyd actuator seals in the B-4. Track 2-hrs NPT from B-4 valve during pressure deploy step process(02:00-04:00). 02:00 05:00 3.00 0 64 PROD1 WHPST PULD P Pressure deploy.Troubleshoot injector stripping problems. 05:00 08:00 3.00 64 7,385 PROD1 WHPST TRIP P RIH.tie in with-3.5'correction. Close EDC.Weight check 18.5K RIH to 7385' 08:00 08:30 0.50 7,385 7,408 PROD1 WHPST REAM P Start pumping in stages-.4 bpm, .8bpm, up to 1.2 bpm.circ. 3500psi, BHP 3800,differential 700 psi. Start cleaning cement.WOB.4,CT weight 5K. RIH 4fpm. Ream down-up- down-up from 7388'-7408'. 08:30 09:00 0.50 7,408 7,385 PROD1 WHPST CIRC P Stop pumping. Diff. pressure would not bleed down below 100 psi for EDC. had to cycle pumps&move pipe to get a good balance point.. EDC open. Good returns, POOH slowly to check blade retaction.- Clean through first restriction. 09:00 11:30 2.50 7,385 67 PROD1 WHPST TRIP P POOH slow through restictions. Injector fan blower siezed while POOH.Speed 50 fpm,due to overide alarms. 11:30 13:00 1.50 67 0 PROD1 WHPST PULD P Undeploy BHA-Underreamer blades intact. 13:00 14:00 1.00 0 0 PROD1 DRILL OTHR P Pre-spud meeting and Injector service. 14:00 15:30 1.50 0 62 PROD1 DRILL PULD P P/U 2.2 AKO build BHA&deploy 15:30 17:15 1.75 62 7,190 PROD1 DRILL TRIP P RIH 17:15 17:45 0.50 7,190 7,428 PROD1 DRILL SRVY P Perform gamma tie-in(7190-7227'); correction of minus 8'. Close EDC and RIH. 17:45 20:15 2.50 7,428 7,570 PROD1 DRILL DRLG P Drill build 57-FPH, 1-2k#WOB, pumping 1.3-BPM 9.8#Flo-pro, 3300-psi CTP,29-psi WHP. 20:15 20:30 0.25 7,570 7,190 PROD1 DRILL WPRT P Wiper trip up to 7190'. PUW 20k#off bottom. 20:30 20:45 0.25 7,190 7,500 PROD1 DRILL DLOG P Tie-in gamma;correction+2'. RIH through window. Log RA marker at 7421'. Tie into RA marker-correct Window depths:TOW 7415'-RA marker 7421'BOW 7422'. 20:45 21:00 0.25 7,720 PROD1 DRILL WPRT P RIH. 21:00 23:45 2.75 7,570 7,720 PROD1 DRILL DRLG P Drill build 55-FPH, 1-2k#WOB, pumping 1.3-BPM 9.8#Flo-pro, 3300-psi CTP,29-psi WHP. 23:45 00:00 0.25 7,720 7,720 PROD1 DRILL WPRT P Begin wiper trip#2 up to 7435'. PUW 23k#off bottom. Page 3 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09/24/2010 24 hr Summary Drilled A-lateral 7720'to 8,467 with no recordable losses to formation. 00:00 00:15 0.25 7,720 7,720 PROD1 DRILL WPRT P Continue wiper trip#2 up to 7435'. RIH. 00:15 01:15 1.00 7,720 7,780 PROD1 DRILL DRLG P Drill build 60-FPH,2-3k#WOB, pumping 1.3-BPM 9.8#Flo-pro, 3550-psi CTP,27-psi WHP. 01:15 03:30 2.25 7,780 42 PROD1 DRILL TRIP P POOH. PUW 21k#. Stop at 7383' to open EDC. POOH. 03:30 06:00 2.50 42 0 PROD1 DRILL PULD P Pressure undeploy BHA#4,build BHA. 06:00 07:30 1.50 0 72 PROD1 DRILL PULD P Pressure deploy BHA#5, lateral BHA. 07:30 10:00 2.50 72 7,780 PROD1 DRILL TRIP P RIH following MPD,-7ft correction. Smooth through window. 10:00 11:30 1.50 7,780 7,930 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3300 psi, BHP 3900, ECD 12.2, ROP 60, WOB 2K, Ct weight 5K.Cutting looking normal over shakers.A-3 sand in formation. 11:30 13:00 1.50 7,930 7,930 PROD1 DRILL WPRT P Wiper trip with MAD pass. P/U weight 20K 13:00 15:00 2.00 7,930 8,080 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3700 psi, BHP 3900, ECD 12.4, ROP 80, WOB 1.4K,Ct weight 5K. No losses. 15:00 16:00 1.00 8,080 8,080 PROD1 DRILL WPRT P Wiper trip-P/U weight 19K. Returns are about the same. 16:00 18:00 2.00 8,080 8,230 PROD1 DRILL DRLG P Drill ahead-1.40 bpm,3700 psi, BHP 3900, ECD 12.5, ROP 70 WOB,2k, Ct weight 4K. 18:00 18:15 0.25 8,230 7,450 PROD1 DRILL WPRT P Wiper trip-P/U weight 22K 18:15 18:45 0.50 7,450 7,051 PROD1 DRILL WPRT P Pull up through window into casing pumping min-rate(0.3-bpm). Smooth through window. Pick up pump rate again to 1.4-bpm at cement top to just below D-nipple. Pump min-rate through D-nipple and bring rate up to 1.4-bpm once through. Stop 200-ft above D-nipple. 18:45 19:00 0.25 7,051 7,388 PROD1 DRILL WPRT P Pump min-rate down through D-nipple and increase rate again to 1.4-bpm until TOC. 19:00 19:15 0.25 7,388 7,435 PROD1 DRILL DLOG P Come offline down through window logging gamma and RA marker(+3' correction). 19:15 19:30 0.25 7,435 8,230 PROD1 DRILL WPRT P RIH pumping 1.4-bpm. 19:30 21:30 2.00 8,230 8,380 PROD1 DRILL DRLG P Drill ahead averaging 75-FPH, pumping 1.42 bpm 9.8#Flo-Pro at 3900 psi. BHP 3950, ECD 12.6. WOB 2k#; CT weight 3k#. 21:30 22:15 0.75 8,380 7,455 PROD1 DRILL WPRT P Wiper trip. PUW21k#. 22:15 23:00 0.75 7,455 8,380 PROD1 DRILL WPRT P RIH. Page 4 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 8,380 8,467 PROD1 DRILL DRLG P Drill ahead averaging 75-FPH, pumping 1.42 bpm 9.8#Flo-Pro at 3800 psi. BHP 3957, ECD 12.7. WOB 2k#; CT weight 4k#. 09/25/2010 Drilled A-lateral to TD at 9380.0';no recordable mud losses to formation. Pumped 10-bbl each low-and high-vis sweeps and began final wiper pass. 00:00 01:30 1.50 8,467 8,530 PROD1 DRILL DRLG P Continue drill ahead at 75-FPH, pumping 1.42 bpm 9.8#Flo-Pro at 3800 psi. BHP 3957, ECD 12.7. WOB 2k#; CT weight 4k#. ROP dropped off to 3-40-fph around 8460'. Discussing geological location with geologist and town for possible sidetrack. Pump 5-bbl low-vis and 5-bbl high-vis to time pills out bit at wiper trip. 01:30 02:30 1.00 8,530 7,450 PROD1 DRILL WPRT P Wiper trip. PUW 22k#. 02:30 03:15 0.75 7,450 8,530 PROD1 DRILL WPRT P RIH. 03:15 05:15 2.00 8,530 8,680 PROD1 DRILL DRLG P Drill ahead at 75-FPH, pumping 1.42 bpm 9.8#Flo-Pro at 3800 psi. BHP 3957, ECD 12.7. WOB 2k#; CT weight 4k#. ROP dropped off to 3-40-fph around 8460'. (Mud update 04:00: LSRV 31,000; DS 0.6%;with 1172'on system.) 05:15 07:00 1.75 8,680 8,680 PROD1 DRILL WPRT P Wiper trip 20K P/U-tie in'0" correction 07:00 09:00 2.00 8,680 8,830 PROD1 DRILL DRLG P Drilling ahead-1.4 bpm,4000, BHP 4100, ECD 13.2, ROP 60,WOB 2K, CT weight 1K. prepare for mud swap. 1372'on system. New mud @ bit 8800'-1.44 bpm, 3600, BHP 3850, ECD 12.4, ROP 90,CT weight 5K 09:00 10:30 1.50 8,830 8,830 PROD1 DRILL WPRT P Wiper trip-P/U weight 19K. 10:30 12:30 2.00 8,830 8,980 PROD1 DRILL DRLG P Drilling ahead-1.43 bpm, 3500, BHP 3900, ECD12.4, ROP 90,WOB 1.4, CT 2K. 12:30 14:15 1.75 8,980 8,980 PROD1 DRILL WPRT P Wiper trip-18K P/U. 14:15 15:45 1.50 8,980 9,130 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3600, BHP 4000, ECD 12.8, ROP 95,WOB 1.6K, CT 2K. 15:45 18:00 2.25 9,130 9,130 PROD1 DRILL WPRT P Wiper trip#3 with RA tie-in. (+1.5' correction). 18K 18:00 19:15 1.25 9,130 9,280 ,PROD1 DRILL DRLG P Drill ahead averaging 120-FPH, pumping 1.42 bpm 9.8#Flo-Pro at 3900-psi. BHP 4050-psi. ECD 12.9. WOB 1.6k#; CT weight 0.2k#. 19:15 20:30 1.25 9,280 7,448 PROD1 DRILL WPRT P Wiper trip to 7448'. PUW 21k#. 20:30 21:30 1.00 7,448 9,280 PROD1 DRILL WPRT P RIH. Page 5 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:30 22:30 1.00 9,280 9,380 PROD1 DRILL DRLG P Drill ahead at 78-FPH,pumping 1.45 bpm 9.8#Flo-Pro at 3800-psi. BHP 4040-psi. ECD 12.9. WOB 1.7k#; CT weight 0.2k#. (Informed KOP established at 8010'). ***Tr)93Roy*** 22:30 00:00 1.50 9,380 7,440 PROD1 DRILL CIRC P Wiper trip to 7440'pumping 10-bbl/10-bbl Hi-lo viscous pills. �J PUW 21k#. Stop at 7440'and rih to 1P('11' tie-in. 09/26/2010 Completed final wiper pass from TD and re-logged the RA marker tie-in with a 0.0'correction. Tagged TD again at 9380'. Pulled OOH laying in 12.0-ppg K-Formate liner-running pill containing 1-2 ppb Alpine beads. Pulled up through window,then POOH circulating in 12.0-ppg K-Formate completion fluid(minus Alpine beads)to surface. Flagged CT for EOP with liner shoe on bottom(7900'), and for EOP for liner shoe above window(5900'). Picked up liner assembly with aluminum liner-top billet and RIH,setting down repeatedly at 8785'. POOH and reconfigured liner running tools for second liner run attempt without knuckle joint in toolstring. RIH liner assembly. 00:00 00:15 0.25 7,440 7,560 PROD1 DRILL DLOG P Continue wiper RIH from 7440'to 7560'logging gamma and RA marker to tie in. (0.0'correction.) 00:15 01:15 1.00 7,560 9,830 PROD1 DRILL WPRT P RIH and time out swap to liner running pill(12.0-ppg K-Formate with 1-2 ppb Alpine beads)to have 1-2-bbl liner running pill above bit at TD tag. Tag TD at 9380'. 01:15 02:15 1.00 9,830 7,380 PROD1 DRILL DISP P POOH laying in liner running pill 0.4-bpm,40-fpm to window. Paint flag on CT at 7971.8'where liner shoe will be on bottom during liner run. 02:15 04:15 2.00 7,380 68 PROD1 DRILL DISP P Pull up through window-all smooth. Completion fluid(12.0-ppg K-Formate minus Alpine beads)at bit. Call out BOT for aluminum liner top billet. POOH circulating well completion fluid. 04:15 04:45 0.50 68 0 PROD1 DRILL PULD P At surface. Monitor well for flow. (Conducted pre-spud meeting with new crew.) 04:45 08:45 4.00 0 0 PROD1 DRILL RGRP P Move off well laying down drilling BHA. Installed bales on top drive. Crew change-test Top drive&HMI links with over-rides&safety trips. Re-set weight calibrations on Injector. 08:45 09:45 1.00 0 0 COMPZ CASING RURD P Prep rig flor for liner running tools. & safety meeting. 09:45 12:45 3.00 0 1,414 COMPZ CASING PUTB P Start P/U liner assembly,total 42 joints. BOP drill-2 min.25 secs. 12:45 13:15 0.50 1,414 1,490 COMPZ CASING TRIP P Start to RIH pumping.3 bpm through GS.DPS having problems. POOH from 80 ft.- 13:15 14:15 1.00 1,490 1,414 COMPZ CASING PULD T Swap out new DPS Page 6 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 15:30 1.25 1,414 7,200 COMPZ CASING TRIP P RIH pumping . 3 bpm.Two guide plates sheered off backside of Injector cart.-Driller slowing down for flag and the injector weight spiked by 10K. (surface weight)when the plates bolts sheared off. 15:30 17:00 1.50 7,200 7,200 COMPZ CASING CTOP T Troubleshooting-Injector centered over well, RIH with less reel tension to watch the difference. POOH 200 ft pipe looked good, RIH-no problems. 30K P/U. 17:00 17:45 0.75 7,200 8,785 COMPZ CASING TRIP P RIH-flag-5.4'correction. RIH tagged up @ 8789'-TOB @ 7412'-Could be stuck in window with Billet.Work pipe with Max. P/U of 35K.Worked it 5 times.Stop&pump.4 bpm to try and move billet. Start Moving up hole 35K surface weight&-10K on BHA. 17:45 21:00 3.25 8,785 1,415 COMPZ CASING TRIP T P/U 300ft for hand-over-RIH one more time to see if anything changed. RIH and tagged same spot 5 times at slower speeds, no luck tagging same spot @ 8788'POOH to inspect Al. Billet. 21:00 23:00 2.00 1,415 1,415 COMPZ CASING PULD T At surface. PJSM to make down liner running tools. Stand back running tools to inspect. Small amount of drill cuttings and metal shavings at FVS union,but no major materials packed off around tools. Nor any marks or scratches on the running tools or billet to indicate hang up in window. Did, however, consider the likelihood of harsh shoulder at knuckle joint hanging up at window. Discussed with CTD Engineer to re-run liner assembly minus the knuckle joint,and also changing the FVS to one without a C-plate slot. PJSM for change of scope. Reconfigured BHA and made up to liner string for second liner run. 23:00 00:00 1.00 1,415 4,386 COMPZ CASING RUNL T RIH. 09/27/2010 Ran the A-lateral liner with aluminum liner top billet;TOB 8008'. Layed down liner running tools and picked up AL1-lateral drilling BHA with 1.1-deg AKO. Kicked off liner top billet at 8008',40-deg right of high side. Drilled ahead AL1-lateral to 8507'. 00:00 00:30 0.50 4,386 7,319 COMPZ CASING RUNL T Continue RIH liner assembly BHA, minus the knuckle joint, and changing the FVS to one without a C-plate slot. Stop at flag(7319.3') and correct to 7313.68'. Continue _ RIH. 00:30 00:45 0.25 7,313 7,428 COMPZ CASING RUNL T Continue to RIH liner assembly. 00:45 01:30 0.75 7,428 9,382 COMPZ CASING RUNL T RIH into open hole. Page 7 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:30 01:45 0.25 9,382 9,382 COMPZ CASING RUNL P Tag TD. Perform weight check. RIH to bottom. Release liner. 01:45 02:15 0.50 9,382 7,175 COMPZ CASING RUNL P PUH for logging run-tie-in. Stop at 8545'. Change EOP depth to 7175.13'. 02:15 02:30 0.25 7,175 7,209 COMPZ CASING RUNL P RIH logging to tie-in gamma. (-2' correction.) Makes sense with 9381.5 versus 9380'TD. ***Estimated Top of Liner is 8010".*** 02:30 04:00 1.50 7,209 37 COMPZ CASING RUNL P POOH circulating completion fluid (12-ppg K-Formate). 04:00 04:30 0.50 37 37 COMPZ CASING RUNL P Tag up. Monitor well for flow/no-flow. PJSM for lay-down liner running tools and pick-up drilling BHA. Prep to PU/LD tools. 04:30 05:00 0.50 37 0 COMPZ CASING PULD P Lay down liner running BHA 05:00 06:00 1.00 0 71 PROD2 STK PULD P Pick up drilling BHA.with 1.1 AKO and re-run Bicenter. 06:00 09:30 3.50 71 8,008 PROD2 STK TRIP P RIH-tie in-8ft,Sit @ 7380 and circulate out KWF.Good 1:1 returns during entire process.Close EDC& RIH. D ta• TOB • 8008'. - 9:30 12:30 3.00 8,008 :,i 0 PROD2 STK KOST P P/U weight 28K,bring pumps online @ 40 right.Start milling 8007.5'Al., returns to surface @ 8008'.Milled as per procedure,with no stalls. Q Increase drilling ROP @ 8017'to eb +� 8030'.27K P/U clean drift through billet. 12:30 15:30 3.00 8,030 8,160 PROD2 DRILL DRLG P Drilling ahead-1.43 bpm,3600, BHP 3930, ECD 12.5, ROP 60,WOB 2.4K,Ct weight 8K. 15:30 16:30 1.00 8,160 8,160 PROD2 DRILL WPRT P P/U weight 29K -billet looked clean. 16:30 18:45 2.25 8,160 8,310 PROD2 DRILL DRLG P Drilling ahead-1.4 bpm,3950, ECD 12.6, ROP 66,WOB 2.3,Ct weight 10K. 18:45 20:00 1.25 8,310 8,310 PROD2 DRILL WPRT P Wiper trip. PUW 28k#. Pulled up to 7447'. Set down through 8168'. Pulled back up through 8168'and RBIH. Smooth second time through. 20:00 21:45 1.75 8,310 8,460 PROD2 DRILL DRLG P Drilling ahead-1.4 bpm,3950, ECD 12.8, ROP 85,WOB 1.8,Ct weight 10K. 21:45 23:30 1.75 8,460 8,460 PROD2 DRILL WPRT P Wiper trip with tie-in. PUW 28k#. PUH to 7437'. RIH logging the RA marker(7437-7458')and determine (+1')correction. RIH and set down 8171'. Pulled up and run in slow past 8171'with slight bobble. Pulled back up through to clean up area and RBIH. Slight bobble down through again. 23:30 00:00 0.50 8,460 8,507 PROD2 DRILL DRLG P Drilling ahead-1.4 bpm,3950, ECD 12.8, ROP 94,WOB 1.8,Ct weight 10K. 09/28/2010 Drilled AL-1 Lateral to 8853.Stuck on wiper trip @ 8484.Work free. POOH for FCO BHA Page 8 of 20 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 01:15 1.25 8,507 8,600 PROD2 DRILL DRLG P Continue drilling ahead-1.4 bpm, 3950, ECD 12.8, ROP 74,WOB 1.8, Ct weight 10K. 01:15 02:45 1.50 8,600 8,600 PROD2 DRILL WPRT P Wiper trip. PUW 28k#. Pulled up to 7450'. Set down through 8172'. Pulled back up to 8125'and RBIH, this time smooth down through. Added drum of clay guard to mud system. 02:45 04:30 1.75 8,600 8,760 PROD2 DRILL DRLG P Continue drilling ahead-1.4 bpm, 3950, ECD 12.8, ROP 91,WOB 1.6, Ct weight 10K. (Performed fire drill on rig 03:30. 100%correct responses, rig and third-party personnel.) 04:30 06:30 2.00 8,760 8,760 PROD2 DRILL WPRT P Wiper trip. PUW 28k#. Pulled up to 7445'. No set downs,slow pump rate to 1 bpm near troubled area. 06:30 07:00 0.50 8,760 8,853 PROD2 DRILL DRLG P Drilling ahead-Start pumping new mud.Shaker bolt sheared off 'f r- bracket.Wiper trip 60ft early. 07:00 08:00 1.00 8,853 7,400 PROD2 DRILL WPRT T POOH-Wiper trip for shaker problems,taking old mud returns to Tiger tank. New mud @ surface, bypass shakers&take into Shaker pit.TF drag from 8150'-8138'2K overpull. 08:00 09:00 1.00 7,400 5,000 PROD2 DRILL WPRT P Pull up through window.trap pressure&open EDC.Wipe up the cased hole. Shaker back operational. Noticed more cutting rolling over shaker while doing wiper in cased hole-current depth 5000'. 09:00 10:00 1.00 5,000 2,200 PROD2 DRILL WPRT P Continue wiping up to 2200',cutting cleaned up around 2800'. 10:00 10:30 0.50 2,200 2,400 PROD2 DRILL CIRC P 2200' slug of shale cutting came across shaker&plugged off choke. Flush chokes,circulate&cleaned up remaining shale-RIH. 10:30 12:00 1.50 2,400 8,495 PROD2 DRILL TRIP P RIH-Tie in @ window with-2 ft correction.-continue RIH,tagged up hard @ 8595' 12:00 14:00 2.00 8,495 8,495 PROD2 DRILL CIRC T Stacked @ fault section. Pump pressure increased to 4800.Torqued into it. Differential 2000 psi.Worked the string 7 tiems,circ. 3300,diff 1500.Try to roll tool. Bit stuck. Depths WOB 7K=8495/WOB- 17K 8484' Cycle pipe up/down 8 times,pump rate.5 bpm, pressure 3300 psi. Page 9 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 8,495 8,495 PROD2 DRILL CIRC T Attempted trapping pressure on CT and pumping down backside to 4000 psi BHP.Attempted to pull.Able to rotate HOT. Max. pull-62K surface/-17K WOB Max.push-11K Surface/+8K WOB No luck. 15:00 15:15 0.25 8,495 8,483 PROD2 DRILL CIRC T Pump back down threw CT- increase pump rate to 1 bpm,Circ. 4500psi-BHP Bore 6300 psi, Pulled 60K into and as we relaxed to RIH is popped free. Total of 56 cycles-CT life&cycles in a good spot 50 bbls loss to formation during process 15:15 16:15 1.00 8,480 7,400 PROD2 DRILL TRIP T POOH to inspect BHA following MPD-all coms working to BHA. Starting getting oily returns when POOH 7500'-Returns to TT.Get above window and Circ.out oily returns. 7 bbls. 16:15 18:15 2.00 7,400 0 PROD2 DRILL TRIP T POOH pumping through EDC. 18:15 21:27 3.20 0 0 PROD2 DRILL PULD T At Surface, PJSM, Pressure un deploy BHA#9 Blow down and break down. Bit had minor chipping on teeth and two plugged ports. No other p apparent damage to BHA 6C�1 21:27 21:45 0.30 0 0 PROD2 DRILL BOPE P Bi Weekly BOPE Function test 21:45 23:45 2.00 0 62 PROD2 DRILL PULD T PJSM, Deploy BHA#10, Surface test tool Open EDC 23:45 00:00 0.25 62 200 PROD2 DRILL TRIP T Trip in well following MP Schedule 09/29/2010 Ran Fill Clean out to 8050. Run PB1 Liner to 8046 TOL Billet Cad 7840 P/U Drill By BHA, Dry Tag Billet @ 7838.Trough and time drill by 00:00 01:45 1.75 200 7,190 PROD2 DRILL TRIP T Continue in well 01:45 01:57 0.20 7,190 7,225 PROD2 DRILL DLOG T Log Tie in for a-8.5. Shut EDC 01:57 03:21 1.40 7,225 8,050 PROD2 DRILL TRIP T Clean run through window,Clean trip past billit Get down to 8050, Pump Lo Hi Sweeps,Chase up hole 03:21 03:33 0.20 8,050 7,430 PROD2 DRILL DLOG T 7430, Log RA Marker on Whipstock +3'correction 03:33 04:03 0.50 7,430 7,440 PROD2 DRILL TRIP T RIH to lay in beaded liner running pill 04:03 06:03 2.00 7,440 62 PROD2 DRILL TRIP T 8050 POOH laying in Beaded pill followed by KWF 12.0 PPG PUW=30k Paint EOP Flags @ 7700'(Orange) &7100'(red) Page 10 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:03 07:33 1.50 62 0 PROD2 DRILL PULD T Flow-check-lay down BHA @ surface. 07:33 08:33 1.00 0 0 PROD2 STK PULD T prepare rig floor for liner&safety meeting 08:33 10:33 2.00 0 268 PROD2 STK WPST T Pressure test CT connector to 4K- good. P/U 6 joints of liner,Anchor billet&Coiltrac. 10:33 12:33 2.00 268 8,046 PROD2 STK WPST T RIH with EDC open pumping . 3bpm. -6.4'correction. P/U weight 28K, Close EDC. RIH 12:33 13:03 0.50 8,046 7,840 PROD2 STK WPST T Orient 175 R-bring pumps online. WOB-1.3K, pump up to 3400 psi, good set,WOB 6K. P/U weight 29K. TOB=7840' 13:03 16:03 3.00 7,840 62 PROD2 STK TRIP T POOH laying in KWF.Ct @ surface -flo-check. 16:03 17:03 1.00 62 0 PROD2 STK PULD T Lay down BHA#11 17:03 17:33 0.50 0 72 PROD2 STK PULD T P/U BHA#12 1.1 degree motor (47) Bi-Center bit 17:33 19:15 1.70 72 7,210 PROD2 STK TRIP T RIH 19:15 19:21 0.10 7,210 7,402 PROD2 STK DLOG T Tie In-9'correction 19:21 21:51 2.50 7,402 7,402 PROD2 STK CIRC T Pump 20 BBI pill,circ out KWF 21:51 22:03 0.20 7,402 7,838 PROD2 STK TRIP T 9.8 Drilling fluid around, RIH to trough /time mill off billet 22:03 23:03 1.00 7,838 7,837 PROD2 STK KOST T 7838', Dry tag TOB,start troughing up hole 150L 1 FPM 1, PUW=29K 1.4 BPM @ 3178 BHP=3890 23:03 00:00 0.95 7,837 7,838 PROD2 STK KOST T 7837.6 Saw WOB start time drilling 1.4 BPM @ 3170 BHP=3797 09/30/2010 Time drill by Billet @ 7838, Drill towards planned TD @-9400' 00:00 01:06 1.10 7,838 7,841 PROD2 STK KOST T Time Milling(cont) 01:06 01:30 0.40 7,841 7,845 PROD2 DRILL DRLG T 7841 Start drilling ahead @ 10 FPH 1.41 BPM @ 3069 BHP=3793 01:30 01:45 0.25 7,845 7,848 PROD2 DRILL DRLG T 7845, Drill ahead 20 FPH 01:45 01:57 0.20 7,848 7,860 PROD2 DRILL DRLG T 7848 Drilling ahead @ 44 FPH 01:57 02:07 0.18 7,860 7,860 PROD2 DRILL WPRT T 7860 Mini wiper to check side track area Looks clean 02:07 03:31 1.40 7,860 7,990 PROD2 DRILL DRLG T 7860', Drill ahead 1.45 BPM @ 3252 FS, 150L TF BHP=3892 03:31 04:16 0.75 7,990 7,990 PROD2 DRILL WPRT T 7990 Wiper to window PUW=28k 04:16 06:29 2.23 7,990 8,290 PROD2 DRILL DRLG T 7990' Drill Ahead 1.44 BPM @ 3195PSi FS BHP=3880 ROP=120 FPH 06:29 06:44 0.25 8,140 8,140 PROD2 DRILL WPRT T 8140'Wiper up to 7450 Wt28k Page 11 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:44 07:44 1.00 8,140 8,290 PROD2 DRILL DRLG T 8140'Drill Ahead 1.43 BPM @ 3377 PSI BHP=3744 ROP 120'FPH 07:44 08:29 0.75 8,290 8,290 PROD2 DRILL WPRT T 8290'Wiper up to 7440' WT off BTM 28k Tie in pass from 7445 to 7460' +1 08:29 10:14 1.75 8,290 8,440 PROD2 DRILL DRLG T 8290' Drill Ahead 1.4 BPM @ 3450 PSI BHP=4300 PSI ROP 120'FPH 10:14 11:14 1.00 8,440 8,440 PROD2 DRILL WPRT T 8440'Wiper up to 7453' 11:14 13:14 2.00 8,440 8,590 PROD2 DRILL DRLG T 8440'Drilling ahead 1.45 BPM @ 3600 PSI BHP=4528 PSI ROP 120 FPH 13:14 14:29 1.25 8,590 8,590 PROD2 DRILL WPRT T 8590'wiper up to 7438' 14:29 15:59 1.50 8,590 8,740 PROD2 DRILL DRLG T 8590'Drill Ahead 1.4 BPM @ 3850 PSI BHP 4742 PSI ROP 120 FPH 15:59 17:29 1.50 8,740 8,740 PROD2 DRILL WPRT T 5 bbls Low/5 bbls high pill at bit 8740'wiper up to 7442' Log down for tie in(-1/2') 17:29 18:59 1.50 8,740 8,890 PROD2 DRILL DRLG T Drilling Ahead 1.44 BPM @ 3559 PSI FS BHP=3977 18:59 20:44 1.75 8,890 8,890 PROD2 DRILL WPRT P 8890'Wiper to window PUW=29K 20:44 22:13 1.49 8,890 9,040 PROD2 DRILL DRLG P 8890', Drill Ahead 1.41 BPM @ 3320 PSI FS BHP=3981 22:13 23:58 1.75 9,040 8,520 PROD2 DRILL WPRT P Wiper to window, PUW=28K Midnight Depth 8520 10/01/2010 TD well @ 9432,Wiper trip to surface, RBIH,tie in for-4.5 correction,Tag @ 9432. POOH laying in Liner running pill/KWF, Pick up lower liner section 00:00 00:18 0.30 8,520 9,040 PROD2 DRILL WPRT P 8050 Continue wiper trip 00:18 01:54 1.60 9,040 9,190 PROD2 DRILL DRLG P 9040 Drill Ahead Pump Lo Hi Sweep 1.40 BPM @ 3301 FS _BHP=3981, ECD=12.8 01:54 03:12 1.30 9,190 7,445 PROD2 DRILL WPRT P Wiper trip to window with tie in PUW=28K 03:12 03:18 0.10 7,445 7,460 PROD2 DRILL DLOG P Log RA Marker-.5'correction 03:18 04:18 1.00 7,460 9,190 PROD2 DRILL WPRT P Head back to bottom 04:18 06:15 1.96 9,190 9,340 PROD2 DRILL DCSG P 9190, Drill Ahead 1.42BPM @ 3450 FS RIW=8K BHP=3990 ROP=100 FPH 06:15 08:45 2.50 9,340 9,340 PROD2 DRILL WPRT P 9340' Wiper trip up to 7455' 29k pu wt off btm. RIH back to BTM. 08:45 09:45 1.00 9,340 9,432 PROD2 DRILL DRLG P 9340' Drill Ahead 1.41 BPM @ 3600 PSI FS BHP=4658 09:45 14:00 4.25 9,432 100 PROD2 DRILL WPRT P Gamma not looking good.Get call from town to stop drilling.TD @ 9432'Pump 5 bbs Lo/10 HI Vis sweep pill.Wiper up to surface. Page 12 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:00 15:30 1.50 100 7,200 PROD2 DRILL TRIP P RBIH 15:30 15:45 0.25 7,200 7,300 PROD2 DRILL DLOG P Log for Tie in -4.5'. 15:45 17:00 1.25 7,300 9,432 PROD2 DRILL TRIP P RBIH,close EDC @ 7402' Tag TD @ 9432 17:00 17:30 0.50 9,432 9,432 PROD2 DRILL CIRC P Circulating Beaded liner pill down coil 17:30 20:18 2.80 9,432 71 PROD2 DRILL TRIP P Trip out of well laying in beaded liner running pill/KWF Paint EOP flags @ 7200,6200 EOP 20:18 21:48 1.50 71 0 PROD2 DRILL PULD P Lay down BHA#12. Blow down and break down. Prep to run liner 21:48 22:15 0.45 0 0 COMPZ CASING PUTB P PJSM, P/U AU lower section of liner Indexing guide shoe, 32 joints slotted liner Shorty deployment sleeve Perform safety joint drill 22:15 23:06 0.85 0 0 COMPZ CASING SFTY T Hand Injured on rig/transport to medic/Stand down 23:06 23:59 0.89 0 0 COMPZ CASING SFTY T Stand down 10/02/2010 Run AU Liner in two sections BOL 9430'TOL a7411. RIH with Upper Whipstock 00:00 05:00 5.00 0 0 COMPZ CASING SFTY T Suspend ops for injury investigation 05:00 08:00 3.00 0 0 COMPZ CASING PUTB P PJSM-P/U liner. 08:00 10:30 2.50 0 9,432 COMPZ CASING RUNL P RIH W/liner run#1.Get pu wt of 30k. Rih down AL1 lat, smooth all the way to tag up 9432'. Pump off liner w/no problem-POOH 10:30 11:30 1.00 9,432 9,432 COMPZ CASING DLOG P Stop @ 8210'. Re-set bit depth to 7175'. Log down to RA marker, TOWS @ 7413'. PUH,paint flag. 11:30 13:15 1.75 9,432 0 COMPZ CASING TRIP P POOH to Surface. 13:15 17:00 3.75 0 0 COMPZ CASING PULD P OOH. Conduct Un-deploy safety meeting.Stab off well, LD BHA. Load up AU Liner#2 17:00 18:24 1.40 0 7,238 COMPZ CASING RUNL P RIH W/AL1 Liner Run#2 18:24 19:18 0.90 7,238 7,229 COMPZ CASING RUNL P Stop and correct to flag,-8.3' PUW=29k 19:18 19:33 0.25 8,396 7,247 COMPZ CASING RUNL P 8396',Tag up, Pump off liner, 1.3 BPM @ 39K PUW=26K TOL=7410 Remove Liner tenth from counters PUH to 7170 and tie in 19:33 19:39 0.10 7,247 7,198 COMPZ CASING DLOG P 7170,Tie in,-.5'correction calling TOL 7410 19:39 21:24 1.75 7,198 65 COMPZ CASING TRIP P Continue out of well 21:24 21:39 0.25 65 65 COMPZ CASING SFTY P PJSM/Flo test well 21:39 22:33 0.90 65 0 COMPZ CASING PULD P Lay down BHA#14 Liner running tool 22:33 23:51 1.30 0 70 PROD3 RPEQP1PULD P P/U BHA 15 Upper whipstock Surface test tool,tag up and set depth Open EDC Page 13 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:51 00:00 0.15 70 70 PROD3 RPEQP1TRIP P RIH with whipstock 10/03/2010 Set Upper whipstock @ 7395', Mill Window 7396.7 to 7402, POOH for full BOPE Test 00:00 01:48 1.80 70 7,205 PROD3 RPEQP1TRIP P Running in with whipstock 01:48 02:00 0.20 7,205 7,226 PROD3 RPEQP1 DLOG P Log Gamma tie in,-8'correction, Shut down pump close EDC, PUW=29k, (j S 02:00 02:30 0.50 7,226 7,403 PROD3 RPEQP1WPST P 7403.7',Orient to high side,TOW _7'395 _ 1j Pumps on,Tool shifted @ 3700 PSI, Set down 2K POOH 02:30 04:15 1.75 7,403 63 PROD3 RPEQPITRIP P Trip out of well 04:15 05:00 0.75 63 0 PROD3 WHPST PULD P PJSM/Flo check well. Pull BHA #15 from well Whipstock setting tools 05:00 06:30 1.50 0 0 PROD3 WHPST PULD P P/U BHA#16 Window milling BHA .6 degree motor,2.74 Mill and string reamer 06:30 09:30 3.00 0 7,380 PROD3 WHPST TRIP P RIH W/Window milling BHA stop @ 7380' 09:30 11:30 2.00 7,380 7,380 PROD3 WHPST DISP P Arrive @ 7380'.open EDC Pump 20 bbls viscosified spacer,displace w/ drilling fluid&recover KWF.Shut EDC 11:30 16:45 5.25 7,380 7,402 PROD3 WHPST MILL P RIH,dry tag whip stock @ 7397' PUH to 7288' 27k pu wt. Pump on line 1.41 BPM @ 3600 PSI FS. RIH pinch point @ 7396.77 stall out motor. Pick off,start time drilling. A 16:45 20:30 3.75 7,402 7,412 PROD3 WHPST MILL P 7402,Call BOW,start milling 1 formation down to 7412 per fr procedure 20:30 22:00 1.50 7,412 7,412 PROD3 WHPST MILL P Ream window 22:00 00:00 2.00 7,412 200 PROD3 WHPST TRIP P Dry pass through window looks good Trip out following MP Schedule PUW=28K 10/04/2010 Complete BOPE test,Witnessed by Chuck S.AOGCC 00:00 00:21 0.35 200 0 PROD3 WHPST TRIP P Continue out of well with window milling BHA 00:21 02:00 1.65 0 0 PROD3 WHPST PULD P PJSM, PUD BHA#15 02:00 03:00 1.00 0 0 PROD3 WHPST CTOP P PJSM Unload PDL 03:00 03:45 0.75 0 0 PROD3 DRILL CTOP P Service tree and valves 03:45 04:00 0.25 0 0 PROD3 DRILL SFTY P PJSM for BOPE Test 6OP 04:00 16:00 12.00 0 0 PROD3 DRILL BOPE P Perform BOPE Test. Have to change (xJ� out B-4. Re-tested good. 16:00 17:15 1.25 0 0 PROD3 DRILL BOPE P R/U to test Inner reel valve, remove checks from UQC,Stab on Injector 17:15 17:45 0.50 0 0 PROD3 DRILL PULD P Prep,pick up Build section BHA. reinstall checks in UQC Page 14 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:45 18:00 0.25 0 0 PROD3 DRILL SFTY P Post BOPE test, Pre-job. Normal up &BHA pick up. Crew change,Valve alignment checklist 18:00 18:45 0.75 0 0 PROD3 DRILL CIRC P Circulate coil back to drilling fluid Un stab injector 18:45 22:15 3.50 0 0 PROD3 DRILL PULD P PJSM, Load PDL with BHA#17. Pressure deploy 2.0 Degree motor and Bi-Center Bit. Surface test tool 22:15 23:51 1.60 62 7,205 PROD3 DRILL TRIP P RIH 23:51 00:00 0.15 7,205 7,215 PROD3 DRILL DLOG P Tie in 10/05/2010 Drilled build and turn for AL2 lateral. Tripped during build to reduce AKO in order to stay on plan/in ploygon. 00:00 00:06 0.10 7,215 7,223 PROD3 DRILL DLOG P Tie in for a-8'correction, Close EDC 00:06 00:27 0.35 7,223 7,412 PROD3 DRILL TRIP P Continue in well to drill Swap to new Mud 00:27 01:33 1.10 7,412 7,461 PROD3 DRILL DRLG P Clean pass through window, Dry Tag @7412 PUH, PUW=28K 1.4 BPM@ 3300 PSI FS, BHP=3899 01:33 02:03 0.50 7,461 7,202 PROD3 DRILL WPRT P Wiper trip to tie in RA.Getting to much DLS Est-40 degrees 02:03 02:09 0.10 7,202 7,218 PROD3 DRILL DLOG P Log Gamma tie in 0 correction RIH to log RA Log RA @ 7401.3 02:09 03:09 1.00 7,218 7,238 PROD3 DRILL CIRC P Recip up hole while formulating directional plan 03:09 05:00 1.85 7,238 0 PROD3 DRILL TRIP P POOH for AKO Change 05:00 05:15 0.25 0 0 PROD3 DRILL SFTY P Hold PJSM for Pressure un-deploy 05:15 08:45 3.50 0 0 PROD3 DRILL PULD P Start to un-deploy.Shift change during. Lay down BHA and adjust AKO from 2 to 1.6. Pressure deploy. 08:45 10:15 1.50 0 7,200 PROD3 DRILL TRIP P RIH w/Build BHA#18 10:15 10:30 0.25 7,200 7,223 PROD3 DRILL DLOG P Tie in for a-9'correction,Close EDC PUW=27K 10:30 10:36 0.10 7,223 7,461 PROD3 DRILL TRIP P RIH,Clean pass through window 10:36 12:51 2.25 7,461 7,615 PROD3 DRILL DRLG P 7461', Drill Ahead 1.4 BPM @ 3500 PSI FS BHP=3838 12:51 13:06 0.25 7,615 7,765 PROD3 DRILL WPRT P Wiper to window 28K 13:06 14:42 1.60 7,765 7,765 PROD3 DRILL DRLG P 7765', Drill Ahead 1.4 BPM @ 3500 FS BHP=3933 14:42 15:12 0.50 7,765 7,765 PROD3 DRILL WPRT P Wiper to window PUW=28K 15:12 16:27 1.25 7,765 7,915 PROD3 DRILL DRLG P 7765 Drill Ahead 1.4 BPM @ 3461 PSI FS BHP=3971 Page 15 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:27 16:54 0.45 7,915 7,415 PROD3 DRILL WPRT P Wiper trip to window with tie in PUW=29 16:54 17:06 0.20 7,415 7,433 PROD3 DRILL DLOG P Tie in with zero correction 17:06 17:36 0.50 7,433 7,915 PROD3 DRILL WPRT P Continue with wiper 17:36 19:06 1.50 7,915 8,065 PROD3 DRILL DRLG P Continue drilling ahead 19:06 20:54 1.80 8,065 0 PROD3 DRILL TRIP P Finished drilling build section. POOH for BHA,opened EDC at the window. 20:54 21:06 0.20 0 0 PROD3 DRILL SFTY P PJSM for undeploy 21:06 00:00 2.90 0 0 PROD3 DRILL PULD P Undeploy/deploy BHA 10/06/2010 Drilled AL2 lateral from 8065'to 8835' 00:00 02:00 2.00 0 0 PROD3 DRILL PULD P Continue with Deployment of lateral drilling BHA 02:00 03:54 1.90 0 7,205 PROD3 DRILL TRIP P RIH 03:54 04:06 0.20 7,205 7,228 PROD3 DRILL DLOG P Tie in,-8'correction,close EDC,27K PUW 04:06 04:24 0.30 7,228 8,065 PROD3 DRILL TRIP P Continue RIH, 15 K RIW 04:24 06:24 2.00 8,065 8,215 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM, 3300 CTP, 3900 BHP with wide open choke, 27K PUW, 15K RIW 06:24 08:24 2.00 8,215 8,215 PROD3 DRILL WPRT P Wiper to window with Madd pass 8076 to 7416 PUW=28K 08:24 10:18 1.90 8,215 8,365 PROD3 DRILL DRLG P 8215', Drill Ahead 1.4 BPM @ 3623 PSI FS 11.7K Slackoff, BHP=3959 10:18 11:33 1.25 8,365 8,365 PROD3 DRILL WPRT P Wiper to window, PUW=28K 11:33 12:57 1.40 8,365 8,515 PROD3 DRILL DRLG P 8365 Drill Ahead 1.4 BPM @ 3631 PSI FS BHP=3972 12:57 13:42 0.75 8,515 7,420 PROD3 DRILL WPRT P Wiper to window with tie in PUW=26K 13:42 13:48 0.10 7,420 7,445 PROD3 DRILL DLOG P Tie in to RA Marker, No Correction 13:48 14:33 0.75 7,445 8,515 PROD3 DRILL WPRT P Continue wiper to bottom 14:33 16:24 1.85 8,515 8,665 PROD3 DRILL DRLG P 8515', Drill ahead 1.4 BPM @ 3511 PSI FS BHP=4020 16:24 17:24 1.00 8,665 7,300 PROD3 DRILL WPRT P Wiper to window PUW=30K 17:24 19:24 2.00 7,300 7,300 PROD3 DRILL SFTY P Safety meeting with Wheatall. Pull into cased hole and circulate 19:24 20:24 1.00 7,300 8,665 PROD3 DRILL WPRT P Wiper to bottom, 16K RIW 20:24 22:06 1.70 8,665 8,815 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3450 CTP,4000 BHP w/wide open choke 22:06 23:36 1.50 8,815 8,815 PROD3 DRILL WPRT P Wiper to window,29K PUW. Clean trip., DS @ .6% 23:36 00:00 0.40 8,815 8,835 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3400 CTP, 4050 BHP 10/07/2010 Drilled to TD at 9200', Layed in KWF and PU liner string Page 16 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 01:48 1.80 8,835 8,951 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3400 CTP,4050 BHP 01:48 02:48 1.00 8,951 7,420 PROD3 DRILL WPRT P Wiper to window. Had trouble getting good weight transfer and then 5K over pulls.29K PUW 02:48 03:00 0.20 7,435 8,951 PROD3 DRILL DLOG P Tie-in,-1.5' 03:00 03:42 0.70 8,951 8,951 PROD3 DRILL WPRT P Wiper back in hole,start new mud down coil for mud swap 03:42 05:06 1.40 8,951 9,110 PROD3 DRILL DRLG P Drilling ahead with new mud, 1.4 BPM, 3300 CTP,4030 BHP 05:06 07:06 2.00 9,110 9,110 PROD3 DRILL WPRT P Wiper trip,29 K PUW 07:06 07:54 0.80 9,110 9,200 PROD3 DRILL DRLG P 9110', Drill Ahead 1.38 BPM @ 3250 FS BHP=3881, ROP=114 07:54 11:30 3.60 9,200 66 PROD3 DRILL WPRT P Call TD. Pump LoHi sweeps,trip to swab valve TO AL2. 11:30 13:06 1.60 66 7,200 PROD3 DRILL WPRT P Bump Stripper,Set BHA depth 77.57 Run back in well 13:06 13:18 0.20 7,200 7,230 PROD3 DRILL DLOG P Gamma tie in for-8 13:18 14:24 1.10 7,230 9,200 PROD3 DRILL WPRT P Continue in well,Swap to beaded pill @ 8500' Tag TD @ 9200,3 BBIs to beads 14:24 17:06 2.70 9,200 0 PROD3 DRILL TRIP P Trip out laying in beaded liner pill/ KWF Following pressure Schedule Paint EOP flags 6000&7800 17:06 17:24 0.30 0 0 PROD3 DRILL SFTY P Monitor well, PJSM forLay down BHA 17:24 18:30 1.10 0 0 PROD3 DRILL PULD P Lay down Drilling BHA 18:30 19:12 0.70 0 0 COMPZ CASING PUTB P RU floor for liner operations 19:12 19:24 0.20 0 0 COMPZ CASING SFTY P PJSM 19:24 22:24 3.00 0 1,271 COMPZ CASING PUTB P PU 38 joints liner. BOP drill at joint #18,Well secured at 2:40. 22:24 23:48 1.40 1,271 7,271 COMPZ CASING RUNL P RIH 23:48 00:00 0.20 7,271 7,300 COMPZ CASING RUNL P Correct to EOP flag,-3'. 31K PUW, 17K RIW(-2.8 WOB) 10/08/2010 Set anchored billet at 7760'. PU drilling assembly,swap well to flopro and mill off billet,drill ahead to end of turn at 8070'. 00:00 00:42 0.70 7,300 9,204 COMPZ CASING RUNL P Continue to RIH with liner 00:42 01:06 0.40 9,204 7,400 COMPZ CASING RUNL P Tag TD at 9203.65',online with pump at 1.3 BPM,4400 CTP. Release liner and POOH pumping down backside 01:06 01:18 0.20 7,400 7,420 COMPZ CASING DLOG P Log RA,-5'correction. Deployment sleeve is at 7971.5' 01:18 02:54 1.60 7,420 0 COMPZ CASING RUNL P POOH pumping down CT. Paint EOP flag at 7100' 02:54 03:12 0.30 0 0 COMPZ CASING SFTY P PJSM while monitoring well for no-flow 03:12 05:12 2.00 0 273 COMPZ CASING PUTB P Lay down BHA. PU guide shoe,6 Joints slotted liner,5.85'pup and anchored billet. MU Inteq BHA Page 17 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:12 07:12 2.00 273 7,381 COMPZ CASING RUNL P RIH 07:12 07:30 0.30 7,381 7,971 COMPZ CASING RUNL P Correct to EOP Flag for-8',Close EDC 07:30 07:42 0.20 7,971 7,199 COMPZ CASING RUNL P Set down @ 7971, Pull up hole,Set back down 7969 Pumps on,see tool shift @ 4K Set down 1.5K on anchor, POOH 07:42 07:57 0.25 7,199 7,220 COMPZ CASING DLOG P Log gamma for a+.75 foot correction BOL=7971,TOL=7760 07:57 09:42 1.75 7,220 59 COMPZ CASING RUNL P Trip out 09:42 10:30 0.80 59 0 COMPZ CASING PULD P PJSM, Flow check well, Lay down BHA#21 10:30 11:30 1.00 0 62 PROD4 STK PULD P P/U BHA#22, 1.7 Degree motor, Bi Center Surface test tool 11:30 13:15 1.75 62 7,200 PROD4 STK TRIP P Trip in well 13:15 13:21 0.10 7,200 7,215 PROD4 STK DLOG P Tie in for a-7'correction 13:21 13:27 0.10 7,215 7,380 PROD4 STK TRIP P RIH to 7380. 13:27 15:12 1.75 7,380 7,380 PROD4 STK CIRC P stop at 7380, Pump spacer, Roll well to flo pro recovering KWF Shut EDC 15:12 15:30 0.30 7,380 7,760 PROD4 STK TRIP P Trip in to kick off billet 15:30 18:42 3.20 7,760 7,770 PROD4 STK KOST P Dry tag billet at 7760,Start sidetracking per recommended practice/procedure 18:42 21:24 2.70 7,770 7,910 PROD4 DRILL DRLG P Continue drilling ahead. Drift billet, clean. Drill some more, 1.4 BPM, AL;t•Q 3300 CTP, 3800 BHP 21:24 22:24 1.00 7,910 7,910 PROD4 DRILL WPRT P Wiper to window,Tie-in due to BHI computer reboot.Zero correction. 22:24 23:54 1.50 7,910 8,070 PROD4 DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 3840 BHP 23:54 00:00 0.10 8,070 PROD4 DRILL TRIP P POOH for AKO adjust 10/09/2010 Drilled AL2-01 lateral 00:00 02:24 2.40 7,800 0 PROD4 DRILL TRIP P Continue POOH for BHA,to PU resistivity tool and lower AKO 02:24 02:36 0.20 0 0 PROD4 DRILL SFTY P PJSM for undeployment 02:36 04:48 2.20 0 0 PROD4 DRILL PULD P Undeploy BHA. PU resistivity and adjust AKO to 1.0. Deploy BHA 04:48 06:48 2.00 0 0 PROD4 DRILL PULD P Deploy BHA#23,Surface test tool All good Tag up,set counters,Open EDC 06:48 08:12 1.40 0 7,205 PROD4 DRILL TRIP P RIH 08:12 08:24 0.20 7,205 7,222 PROD4 DRILL DLOG P Log Tie in for a-10'correction Close EDC 08:24 08:48 0.40 7,222 8,070 PROD4 DRILL TRIP P Trip in to drill, Clean pass through window and past billet 08:48 10:00 1.20 8,070 8,220 PROD4 DRILL DRLG P 8070 Drill Ahead. 1,4 BPM @ 3353 PSI FS BHP=3932 10:00 11:48 1.80 8,220 8,220 PROD4 DRILL WPRT P 8220,Wiper to window with MAD Pass, PUW=29K Page 18 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:48 13:12 1.40 8,220 8,370 PROD4 DRILL DRLG P 8220, Drill ahead, 1.4 BPM @3315 PSI FS, BHP=3964 13:12 14:12 1.00 8,370 8,370 PROD4 DRILL WPRT P 8370,Wiper to window, PUW=30K 14:12 15:12 1.00 8,370 8,520 PROD4 DRILL DRLG P 8370' Drill ahead 1.4 BPM @ 3340 PSI FS 15:12 16:42 1.50 8,520 8,520 PROD4 DRILL WPRT P 8520',Wipe to window with tie in, PUW=28K No Correction on tie in 16:42 18:24 1.70 8,520 8,670 PROD4 DRILL DRLG P 8520', Drill ahead 1.42 BPM @3350 PSI FS BHP=4041 18:24 19:54 1.50 8,670 8,670 PROD4 DRILL WPRT P Wiper to window,29K PUW. Clean trip 19:54 21:12 1.30 8,670 8,820 PROD4 DRILL DRLG P Continue drilling ahead, 11K RIW, 1.4 BPM,3400 CTP,4000 BHP 21:12 22:48 1.60 8,820 8,820 PROD4 DRILL WPRT P Wiper trip to window,28K PUW 22:48 00:00 1.20 8,820 8,957 PROD4 DRILL DRLG P Continue drilling ahead, 11K RIW, 1.4 BPM ,3400 CTP,4050 BHP 10/10/2010 Drilled AL2-01 lateral to TD at 9250'. Condition hole and pump KWF. Run liner. 00:00 00:18 0.30 8,957 8,970 PROD4 DRILL DRLG P Continue drilling ahead, 11K RIW, 1.4 BPM,3455 CTP,4090 BHP 00:18 01:12 0.90 8,970 7,420 PROD4 DRILL WPRT P Wiper to window 01:12 01:24 0.20 7,420 7,440 PROD4 DRILL DLOG P Tie in,zero correction 01:24 02:00 0.60 7,440 8,970 PROD4 DRILL WPRT P Wiper in hole, 15K RIW at window 02:00 03:42 1.70 8,970 9,120 PROD4 DRILL DRLG P Drilling ahead, 11K RIW, 1.4 BPM, 3500 CTP,4100 CTP 03:42 05:48 2.10 9,120 9,120 PROD4 DRILL WPRT P Wiper to window, 28K PUW 05:48 07:12 1.40 9,120 9,250 PROD4 DRILL DRLG P Drill Ahead 1.4 BPM @ 3470 PSI FS BHP=4105 RIW=7K P,i2 Call TD 9250 , 417 07:12 07:42 0.50 9,250 9,250 PROD4 DRILL CIRC P Start LoHi Sweeps 07:42 11:42 4.00 9,250 72 PROD4 DRILL WPRT P Sweeps coming out,Chase to swab No heavy cuttings observed 11:42 13:27 1.75 72 7,215 PROD4 DRILL WPRT P Reset depth at surface, RBIH 13:27 13:33 0.10 7,215 7,225 PROD4 DRILL DLOG P Tie in for a-10'correction 13:33 14:33 1.00 7,225 9,250 PROD4 DRILL WPRT P 9250,Tag TD, 14:33 17:12 2.65 9,250 0 PROD4 DRILL TRIP P Trip out of well laying in Beaded liner pill/KWF. paint flags at 7250'and 5400'EOP 17:12 18:00 0.80 0 0 PROD4 DRILL PULD P Lay down drilling BHA 18:00 19:00 1.00 0 0 "COMPZ CASING PUTB P RU floor for liner operations 19:00 19:18 0.30 0 0 COMPZ CASING SFTY P PJSM for liner operations 19:18 23:18 4.00 0 1,912 COMPZ CASING PUTB P PU liner string,Safety Joint Drill at joint#33, <4 min. 23:18 00:00 0.70 1,912 4,000 COMPZ CASING RUNL P RIH with liner 10/11/2010 Run liner, recover KWF, FP well, RDMO Page 19 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 4,000 9,250 COMPZ CASING RUNL P Continue RIH with liner. Correct at flag at 5400 EOP,-8.3'. Weight check 30K PUW, 16.5K RIW with -5.5 WOB. 02:00 02:30 0.50 9,250 7,370 COMPZ CASING RUNL P Tag At 9250'. Pump at 1.2 BPM, 4300 CTP and PUH, released from liner. 02:30 03:30 1.00 7,370 7,370 COMPZ CASING DISP P Circulate KWF from hole 03:30 06:15 2.75 7,370 0 COMPZ CASING RUNL P POOH, Lay in diesel FP from 2500' to surface 06:15 08:15 2.00 0 0 COMPZ CASING PULD P PJSM, Undeploy BHA#24 Linner run 08:15 10:00 1.75 0 0 DEMOB WHDBO NUND P PJSM, P/U FMC Lubricator and equipment to set BPV 10:00 10:45 0.75 0 0 DEMOB WHDBO NUND P PJSM,Stab back on well, Flush stack and rig not previously flushed 10:45 12:15 1.50 0 0 DEMOB WHDBO NUND P Blow down coil,stack,and rig. Bleed off and unstab injector 12:15 13:15 1.00 0 0 DEMOB WHDBO SFTY P Finger injury on rig floor,sent IP to medic,made notifications.Safety meeting with crew 13:15 19:15 6.00 0 0 DEMOB WHDBO DMOB P Continue with RD,still emptying pits. ND BOP 19:15 21:00 1.75 0 DEMOB WHDBO DMOB P Rig released at 21:00 Page 20 of 20 3A-17 Well Work Summary DATE SUMMARY 10/12110 RAN MAGNET& BRUSH TO TOP OF LINER @ 7395' RKB. MEASURED BHP @ 7395' RKB: 3409 PSI. SET CATCHER @ 7251' RKB. IN PROGRESS. 10/13/10 PULLED DV @ 6752' RKB. ATTEMPTED SET OV @ SAME. IN PROGRESS. 10/14/10 PULLED DV @ 6114' RKB. ATTEMPTED SET GLV @ SAME. SET 1/4" OV @ 6752' RKB. IN PROGRESS. 10/15/10 PULLED DVs @ 4235' &2961' RKB. SET GLVs @ 6114', 4235' &2961' RKB. WITH HOLEFINDER IDENTIFIED POSSIBLE LEAK @ GLM @ 4235' RKB. RAN LIB TO CHECK GLM, UNABLE TO SD. PULLED EMPTY CATCHER @ 7251' RKB. IN PROGRESS. 10/16/10 BLED IA f/620 TO 80 PSI, TBG HOLDING @ 825 PSI. OBSERVE 15 MIN, GOOD. PULLED CATCHER. COMPLETE. Page 1 of 2 Schwartz, Guy L (DOA) From: Long, Jill W[Jill.W.Long @conocophillips.com] Sent: Wednesday, September 29, 2010 12:04 PM To: Schwartz, Guy L(DOA) Subject: RE: 3A-17AL1 PB1-Plugback Notification I'T9 fo - 113 Thank you Guy. Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, September 29, 2010 11:39 AM To: Long, Jill W Subject: RE: 3A-17AL1 PB1- Plugback Notification Jill, Apologize for not getting back sooner. As we discussed on the phone just name the lateral as you listed above and assign a API number with the-70 suffix. The data for the lateral can be added to the final 407 report for the well. Send me the update well sketch when you have it completed. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Long,Jill W [mailto:JilI.W.Long @conocophillips.com] Sent: Tuesday, September 28, 2010 9:02 PM To: Schwartz, Guy L (DOA) Subject: 3A-17AL1 PB1- Plugback Notification Guy- The purpose of this email is to notify you that we have elected to plugback our first attempt at drilling the 3A-17A lateral (PTD#210-114)due to geologic issues. The kick off from the billet was successful but while drilling ahead to acquire the targeted A3 sands, a shale section was encountered in additional to a major fault. Drilling continued for a short distance beyond the fault however, while running back in the hole after completing a standard wiper trip, the BHA became temporarily bit stuck near the fault. The BHA released but, considering the future challenges associated with drilling ahead through the shale and fault, the team has chosen to plugback what has been drilled and try a second attempt at 9/29/2010 Page 2 of 2 drilling the 3A-17AL1. The new directional plan is currently being worked and will be ready tomorrow. If you would like to see the plan I can provide it to you when it is ready. I will plan to call you in the morning to discuss over the phone. I am currently on the slope so if you need to reach me before then please call my cell phone or call the rig phone (907-659-3990). Thank you, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 9/29/2010 M iii- N 1 .0 _ o a 2 u) 0 O Ib io el a Zr. d m cn m m _ II II a a, .a. T O 0 J _ w 0 c 1I I a° m Cl o E. a � I �1 I i✓ <o J 1 \\ I ci N. a \\\ `- u) ° v \....`,r4\ m MN � 1147 N V N V II \ Ct \O M « O G D \ Cr c 0) N E N cu \... 11\I1 'm v m m o st w v :c a) 'o ao n n °° m o n I1 o U) m` °a w E N /1 tLU m o U I co i+ –a //, o O o a 0 m in o v / O O , _ U• J O O m co E 0 m../,,, ` d II .L j/// U• of m U C, QI-ca If N N N N a) II r r r co 11 (') M l`') f') m /1 i a // // ImA // .i ® // a // II 0 //// N f 1 1 An fi L I —\��V j!1 A lyj .r- .O .. / III A N W \ O I- - N a vir 0 CI 13 a°U I o iC N '�n �n2 U a N @ co 8'o •° U■2 QO n v(/) Y u o N N � O = r N V N V \ o roCO � co a co 0 II a. ` / O �/7i J I Q N I o 3 II t N o o I 0 I t co co co I N-- Q O I !0°) J () I N Q Q 1.12 n J CO Y J n Q O O « O t0 I b A J O C Q� a co Q F J N II N J O II a 1-m Cr) ConocoPhillips Ira- Conoco Phillips Travelling Cylinder Report 277o 2/47-1153 BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-17 Project: Kuparuk River Unit ND Reference: 3A-17©82.00ft(Rowan 245) Reference Site: Kuparuk 3A Pad MD Reference: 3A-17©82.00ft(Rowan 245) Site Error: 0.00ft North Reference: True Reference Well: 3A-17 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-17A Database: EDM Alaska Prod v16 Reference Design: 3A-17A_wp09 Offset ND Reference: Offset Datum Reference 3A-17A_wp09 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,297.80 to 9,150.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,110.84ft Error Surface: Elliptical Conic Survey Tool Program Date 9/1/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 50.00 7,297.80 3A-17 Gyro(3A-17) GYD-CT-CMS Gyrodata cont.casing m/s 7,297.80 9,150.00 3A-17A_wp09(3A-17A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,821.00 3,305.24 7 5/8" 7-5/8 9-7/8 9,150.00 6,114.13 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3A Pad 3A-01 -3A-01 -3A-01 Out of range 3A-02-3A-02-3A-02 Out of range 3A-03-3A-03-3A-03 Out of range 3A-03-3A-03A-3A-03A Out of range 3A-03-3A-03B-3A-03B Out of range 3A-03-3A-03B-3A-03B wp04 Out of range 3A-04-3A-04-3A-04 Out of range 3A-05-3A-05-3A-05 7,710.00 7,500.00 848.34 192.65 658.61 Pass-Major Risk 3A-06-3A-06-3A-06 Out of range 3A-07-3A-07-3A-07 8,725.00 7,325.00 1,045.73 175.95 872.99 Pass-Major Risk 3A-08-3A-08-3A-08 Out of range 3A-12-3A-12-3A-12 Out of range 3A-16-3A-16-3A-16 Out of range 3A-17-3A-17-3A-17 7,300.00 7,300.00 0.00 0.39 -0.41 FAIL-No Errors 3A-17-3A-17AL1-3A-17AL1_wp03 7,724.88 7,725.00 1.50 0.89 0.66 Pass-Major Risk 3A-17-3A-17AL2-3A-17AL2_wp05 7,375.00 7,375.00 0.00 0.23 -0.25 FAIL-No Errors 3A-17-3A-17AL2-01 -3A-17AL2-01_wp02 7,375.00 7,375.00 0.00 0.23 -0.25 FAIL-No Errors 3A-18-3A-18-3A-18 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/1/2010 4:10:02PM Page 2 of 11 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips Travelling Cylinder Report BAKER L{ HUGHES / 2/0 -/ Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-17 Project: Kuparuk River Unit TVD Reference: 3A-17 @ 82.00ft(Rowan 245) Reference Site: Kuparuk 3A Pad MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site Error: 0.00ft North Reference: True Reference Well: 3A-17 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-17AL1 Database: EDM Alaska Prod v16 Reference Design: 3A-17AL1_wp03 Offset TVD Reference: Offset Datum Reference 3A-17AL1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refere Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,700.00 to 9,200.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,115.84ft Error Surface: Elliptical Conic Survey Tool Program Date 9/1/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 50.00 7,297.80 3A-17 Gyro(3A-17) GYD-CT-CMS Gyrodata cont.casing m/s 7,297.80 7,700.00 3A-17A_wp09(3A-17A) MWD MWD-Standard 7,700.00 9,200.00 3A-17AL1_wp03(3A-17AL1) MWD MWD-Standard 3,821.00 3,305.24 7 5/8" 7-5/8 9-7/8 9,200.00 6,081.73 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3A Pad 3A-01 -3A-01 -3A-01 Out of range 3A-02-3A-02-3A-02 Out of range 3A-03-3A-03-3A-03 Out of range 3A-03-3A-03A-3A-03A Out of range 3A-03-3A-03B-3A-03B Out of range 3A-03-3A-03B-3A-03B wp04 Out of range 3A-04-3A-04-3A-04 Out of range 3A-05-3A-05-3A-05 7,742.73 7,500.00 847.22 194.47 655.06 Pass-Major Risk 3A-06-3A-06-3A-06 Out of range 3A-07-3A-07-3A-07 8,800.00 7,325.00 1,111.84 176.31 938.25 Pass-Major Risk 3A-08-3A-08-3A-08 Out of range 3A-09-3A-09-3A-09 Out of range 3A-10-3A-10-3A-10 Out of range 3A-11 -3A-11-3A-11 Out of range 3A-12-3A-12-3A-12 Out of range 3A-13-3A-13-3A-13 Out of range 3A-14-3A-14-3A-14 Out of range 3A-15-3A-15-3A-15 Out of range 3A-16-3A-16-3A-16 Out of range 3A-17-3A-17-3A-17 Out of range 3A-17-3A-17A-3A-17A_wp09 7,700.00 7,700.00 0.00 0.22 -0.22 FAIL-No Errors 3A-17-3A-17AL2-3A-17AL2_wp05 Out of range 3A-17-3A-17AL2-01 -3A-17AL2-01 wp02 Out of range 3A-18-3A-18-3A-18 Out of range 3A-18-Prelim:3A-18ALT-3A-18ALTwp01 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/1/2010 4:18:50PM Page 2 of 7 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips Travelling Cylinder Report BAKER FD at 0. - l i.i HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-17 Project: Kuparuk River Unit TVD Reference: 3A-17 @ 82.00ft(Rowan 245) Reference Site: Kuparuk 3A Pad MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site Error: 0.00ft North Reference: True Reference Well: 3A-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-17AL2 Database: EDM Alaska Prod v16 Reference Design: 3A-17AL2_wp05 Offset TVD Reference: Offset Datum Reference 3A-l7AL2_wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer€ Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,297.80 to 9,250.006 Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,120.84ft Error Surface: Elliptical Conic Survey Tool Program Date 9/1/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description � 50.00 7,297.80 3A-17 Gyro(3A-17) GYD-CT-CMS Gyrodata cont.casing m/s 7,297.80 9,250.00 3A-17AL2_wp05(3A-17AL2) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter P P (ft) (ft) Name (•') C) 3,821.00 3,305.24 7 5/8" 7-5/8 9-7/8 , 9,250.00 6,167.61 2 3/8" 2-3/8 3 I Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3A Pad 3A 01 3A 01 3A 01 Out of range 3A 02 3A 02 3A 02 Out of range 3A-03-3A-03-3A-03 Out of range 3A-03-3A-03A-3A-03A Out of range 3A-03-3A-03B-3A-03B Out of range 3A-03-3A-03B-3A-03B wp04 Out of range 3A-04-3A-04-3A-04 Out of range 3A-05-3A-05-3A-05 7,820.00 7,525.00 753.79 175.56 579.10 Pass-Major Risk 3A-07-3A-07-3A-07 9,125.00 7,000.00 1,111.23 228.16 883.70 Pass-Major Risk 3A-12-3A-12-3A-12 Out of range 3A-17-3A-17-3A-17 7,300.00 7,300.00 0.00 0.39 -0.42 FAIL-No Errors 3A-17-3A-17A-3A-17A wp09 7,375.00 7,375.00 0.00 0.23 -0.25 FAIL-No Errors 3A-17-3A-17AL1 -3A-17AL1_wp03 7,375.00 7,375.00 0.00 0.23 -0.25 FAIL-No Errors 3A-17-3A-17AL2-01 -3A-17AL2-01_wp02 7,600.00 7,600.00 0.00 0.22 -0.22 FAIL-No Errors 3A-18-3A-18-3A-18 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/1/2010 4.2705PM Page 2 of 13 COMPASS 2003.16 Build 69 ConocoPhillips II/1 ConocoPhillips Travelling Cylinder Report Z(° --//6 Pry HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-17 Project: Kuparuk River Unit TVD Reference: 3A-17 @ 82.00ft(Rowan 245) Reference Site: Kuparuk 3A Pad MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site Error: 0.00ft North Reference: True Reference Well: 3A-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-17AL2-01 Database: EDM Alaska Prod v16 Reference Design: 3A-17AL2-01_wp02 Offset TVD Reference: Offset Datum Reference 3A-17AL2-01_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,600.00 to 9,300.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,125.84ft Error Surface: Elliptical Conic Survey Tool Program Date 9/1/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 50.00 7,297.80 3A-17 Gyro(3A-17) GYD-CT-CMS Gyrodata cont.casing m/s 7,297.80 7,600.00 3A-17AL2_wp05(3A-17AL2) MWD MWD-Standard 7,600.00 9,300.00 3A-17AL2-01_wp02(3A-17AL2-01) MWD MWD-Standard 3,821.00 3,305.24 7 5/8" 7-5/8 9-7/8 I 9,300.00 6,143.27 2 3/8 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3A Pad 3A-01 -3A-01 -3A-01 Out of range 3A-05-3A-05-3A-05 7,885.58 7,550.00 694.29 176.10 519.14 Pass-Major Risk 3A-12-3A-12-3A-12 Out of range 3A-16-3A-16-3A-16 Out of range 3A-17-3A-17-3A-17 7,600.00 7,675.00 129.30 60.33 102.06 Pass-Major Risk 3A-17-3A-17A-3A-17A_wp09 8,611.34 7,000.00 568.00 86.36 500.09 Pass-Major Risk 3A-17-3A-17AL1 -3A-17AL1_wp03 8,611.34 7,000.00 568.00 86.36 500.09 Pass-Major Risk 3A-17-3A-17AL2-3A-17AL2_wp05 7,600.00 7,600.00 0.00 0.22 -0.22 FAIL-No Errors 3A-18-3A-18-3A-18 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/1/2010 4:42:18PM Page 2 of 10 COMPASS 2003.16 Build 69 SlfATTE 0 AllASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-17A ConocoPhillips Alaska, Inc. Permit No: 210-113 Surface Location: 663' FSL, 785' FEL, SEC. 7, T12N, R9E, UM Bottomhole Location: 3014' FSL, 3208' FEL, SEC. 17, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair S DATED this/ day of August, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ED STATE OF ALASKA N _j , 2 0 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska y&Gm CM.Commission ";'Cf 20 AAC 25.005 la.Type of Work: . lb.Proposed Well Class: Development-Oil A •Service-Winj ❑ Single Zone 0 • lc.Specify if well is proposed for: Drill ❑ Re-drill 5 Stratigraphic Test❑ Development-Gas❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: 5 Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 • 3A-17A • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9150' • TVD: 6032' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:663'FSL,785 FEL,Sec.7,T12N,R9E,UM • ADL 25631,25632 ' Kuparuk River Oil Pool , Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: Top of Kuparuk:4219.95 FSL,2653.2'FEL,Sec.17,T12N,R9E,UM 2564,2565 9/1/2010 ' Total Depth: 9.Acres in Property: 14.Distance to TD:3014'FSL,3208'FEL,Sec.17,T12N,R9E,UM 2560 Nearest Property: 22650' . 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 82 feet • 15.Distance to Nearest Well Open Surface:x- 507663 • y- 5997044• Zone- 4 GL Elevation above MSL: 41 feet • to Same Pool: 3A-07,1200' 16.Deviated wells: Kickoff depth: 7412' ft. 17.Maximum Anticipated Pressure n psig(see 20 AAC 25.035) Maximum Hole Angle: 96° deg. Downhole:4560 psig ; • PO' Surface:3957 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks ' Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 3" 2.375" 4.7# L-80 ST-L 1450 7700 6038 9150 6032 slotted liner , ISX- 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Et gin• Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft) Effective Depth ND(ft): Junk(measured) 7785' 6336' 7717' 6283' Casing Length Size Cement Volume MD TVD Conductor/Structural 81' 16" 212 sx AS I 121' 121' Surface 3782' 7.625" 1020 sx AS III,340 sx CI G 3821' 3306' Intermediate Production 7747' 5.5"x 3.5" 190 sx Class G 7782' 6334' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7347'-7370',7380'-7390',7474'-7504' 5995-6013',6020'-6028',6094-6117' 1 20.Attachments: Property Plat❑ BOP Sketch in Drilling Program in Time v.Depth Plot❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report❑ Drilling Fluid Program In 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 67(.1)11131i°�g1(gl VO Printed Name V. Cawvey / �'1 Title Alaska Wells Manager Signature J c��G"41 'FO(- 1 Old L)ru ve4 Phon 265-6306 Date et cl 1 ll j to 1 1 Commission Use Only Permit to Drill 7 / API Number: Permit Approval See cover letter Number: 4�L.. /1'3 50-f; -- 2249/`G)I-661 Date: 13 I )C for other requirements L- ` Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales: Efl .X f5., 60P 77,5r Samples req'd: Yes 0,No Mud log req'd: Yes ❑ No d Other: w (%1r) H2S measures: Yes [. No ❑ Directional svy req'd: Yes lif No ❑ A 2504. (5i, A 1 l APPROVED BY THE COMMISSION r/ 3, /e DATE: / COMMISSIONER Form 10-401 ( vlsed 7/2009) This permit is valid for 7 months from the date of approval(20 C 25.0050) ub 133 In__ phCate 8'07!0 /tea �'�7,��: Conoco Phillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 18, 2010 Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill 4 lateral sidetracks out of Kuparuk Well 3A-17 using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 3A-17 as early as September 12, 2010. The CTD objective is to drill four lateral sidetracks (3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2-01); targeting the A2 and A3-sands to access reserves away from the parent wellbore, across isolating faults. Two laterals each will be drilled from two separate casingexits in the 3.5" liner. Attached to this application are the following documents: — Permit to Drill Application Forms for 3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2-01 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic — Sundry Application— Plug perforations If you have any questions or require additional information please contact me at 907-263-4093. Sincerel , ,_or ' b(35-Y11-- Jill Lo • Coiled Tubing Drilling Engineer Permit to Drill Summary of Operations KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 Laterals Coiled Tubing Drilling Well History and Objective Well 3A-17 was originally drilled and completed as an A-sand producing, single completion well in September 1996. The A sands were perforated and fracture stimulated in October/November 1996. The well operated as an A-only producer until 1999 when the C and B sands were perforated in June of that year. Production from 3A-17 has historically been lower than expected. The reservoir in the surrounding area is highly faulted and seismic data confirms the current wellbore position is not optimal. The purpose of the CTD project is to drill four CTD sidetracks in the A2 and A3 sands away from the parent• wellbore and across faults that are believed to be isolating. The new reservoir locations should result in improved . sweep efficiency and oil recovery for the pattern. Perforations in the parent wellbore are planned to be plugged prior to CTD rig arrival however the lateral footage drilled in the immediate vicinity of parent well will recover the existing perforations. Operational Outline Pre-Rig Work Remaining 1. Changeout all gas lift valves to dummy valves and caliper the 3.5" liner below the tubing tail. 2. Set a cast iron bridge plug above the A sand perforations(and below the lower CTD kickoff point). 3. Perforate the 3.5" liner across the kickoff point locations 4. Set the lower whipstock at 7412' MD 5. Cement squeeze the B and C sand perforations, cleaning out to the top of the whipstock 6. Prepare wellsite for rig arrival. Rig Work tiro )05.: 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Lower Window a. Mill a 2.74"window exit with high-side orientation off of the whipstock previously cemented in Tk`j _ place at—7412' MD P1-° b. 3A-17A Lateral i. Drill 2.70"x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL1 lateral c. 3A-17AL1 Lateral i. Drill 2.70"x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with a shorty deployment sleeve on top from TD to just inside the window 3. Upper Window a. Set a 3.5" Monobore whipstock at—7395' MD and mill a 2.74"window exit with high-side orientation off of the whipstock set at—7395' MD b. 3A-17AL2 Lateral i. Drill 2.70"x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL2-01 lateral c. 3A-17AL2-01 Lateral i. Drill 2.70"x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with a shorty deployment sleeve on top from TD to inside the 3.5" liner above the window. 4. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Page 1 of 3 8/18/2010 PTD Applications KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 Operational Details Hazards — Shale stability is a potential problem, particularly in the build section when crossing Fault#1. — Drilling into over-pressured zones is a potential hazard in 3A-17. Nearby injecting well 3A-10 has a bottomhole pressure of—4600 psi but is expected to be fault isolated from the planned laterals. Choke pressure will be maintained while drilling, both for maintaining well control and borehole stability. — Well 3A-17 has 130 ppm H2S as measured on 02/16/10. Well 3A-08 is located 16' to the right side and 3A- 09 is 59' to the left side of the 3A-17 surface location. The H2S measured in 3A-08 is 200 ppm (12/18/09) and 3A-09 is 120 ppm (1/2/09). The maximum H2S level on the pad is 260 ppm from well 3A-16 (12/19/09). All H2S monitoring equipment will be operational. Fluids Program — Chloride-based Biozan brine (8.6 ppg)will be used for window milling operations. — Chloride-based Flo-Pro mud (9.8 ppg) for drilling operations. • — Due to the high reservoir pressures, 13.1 ppg Potassium Formate will be used for running completions. Disposal — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. New Completion Details Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 3A-17A 7700' 9150' 6038' 6032' 23/8', 4.7#, L-80, ST-L slotted liner; • aluminum billet on top. . 3 2/8 4.7# L-80 ST-L slotted liner; shorty Y 3A-17AL1 7412' 9200' 5963' 6000' deployment sleeve on top. 3A-17AL2 7600' 9250' 6043' 6085' 23h , 4.7#, L-80, ST-L solid/slotted liner; • aluminum billet on top. • 3A-17AL2-01 7380' 9300' 5939' 6060' 23/", 4.7#, L-80, ST-L slotted liner; shorty • deployment sleeve on top. Existing Casing/Liner Information Weight Top Btm Top Btm Burst Collapse 9 p p p Category OD Grade Connection 9 (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 0 121 0 121 1640 630 Surface 7%" 29.7 L-80 BTC-Mod 0 3821 0 3306 6890 4790 Casing 5 '/2" 15.5 L-80 LTC-Mod 0 7254 0 5922 7000 4990 Liner 3 %" 9.3 L-80 EUE-8rd Mod 7254 7782 5922 6334 10160 10540 Tubing 3 '/2" 9.3 L-80 EUE-8rd Mod 0 7267 0 5932 10160 10540 Directional Planning — See attached directional plans for each of the three laterals. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance Lateral Name Distance 3A-17A 22650' 3A-17AL2 21450' 3A-17AL1 22650' 3A-17AL2-01 21450' Page 2 of 3 8/18/2010 PTD Applications KRU 3A-17A, 3A-1.IML1, 3A-17AL2, 3A-17AL2-01 — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well Lateral Name Distance Well 3A-17A 1200' Toe measured to 3A-07 -3A-17AL2 1200' Toe measured to 3A-07 3A-17AL1 1200' Toe measured to 3A-07 3A-17AL2-01 1200' Toe measured to 3A-07 Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section' Reservoir Pressure — The most recent static BHP survey in well 3A-17 was taken August 12, 2010. The reservoir pressure was measured at 3800 psi at 7426' MD/ 6056' TVD corresponding to 12.1 EMW. This is also the p P 9 ppg highest expected pressure in the targeted fault block. — The highest pressure from any of the surrounding wells that could potentially be anticipated is 4560 psi at / 6628' MD/6065'TVD (in nearby injector 3A-10). �, � ii4• �� o Well Control tiG f — Two well bore volumes (-161 bbl) of KWF will be within a short drive to the rig during drilling operations. In • this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. — BOP diagram is attached for operations with 2" coil tubing. / — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum surface pressure anticipated while sidetracking out of 3A-17 is 3957 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the maximum reservoir pressure from all nearby wells: 4560 psi at 6628' MD/6065' TVD (in nearby injector 3A-10). — The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by using 9.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will • be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. Page 3 of 3 8/18/2010 0 N co 0 ai f o n > > t N o 77 W O Cl 0 W co fV / \` lC0 N .-. N 1A 'QA+ r 0 d ;b N CO C J 01 I 0 W N 6 i p n 43 I A n t _ J _ t0 N a F-J I ¢ m ci N 1 10 0 -v N I N u 11 II CO N e d o p d CCD ? . p co a C C N D. w E m N o 0▪ LLI C 0 m \en 8 W o, 0 C7 N \\ 10 co co N U of m 0 of \\ N fV N N N o i Ki co A "I r... EL le Y ° c �yJly�,1II� ///AI��I{yJ�'I .tl+ ,n''z r4:., 1 ro 0 �. .. . , .. 1 .�,II \\ 111 ; 111 dv* L. t � .. NV W \ o o E ° r O I O U a° N p 0 co C M I r J '2 2 No N O 0 a° d co a° U - _� m oa Ct yc� N0 0 ^'� co N M N O I- m r 2 sr Wes�`` , H° V y X fV (1) o 2 N o O") N- \ 0 = N O U Y 0 \ • fV m d o �© o $ 11 a N /�/ J / Q o I 11 o J 11 Q I r I z o I m h —1 • I. M I I V \ / U O J �J Q 4g2 ��� A N II Cl 'O N- 1_ a°J co l0 r 0 d 1 a1—m CO ConocoPhilhips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3A Pad 3A-17 3A-17A Plan: 3A-17A_wp09 Standard Planning Report 16 August, 2010 rI BAKER HUGHES 'P ConocoPhillips (/"' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17A Design: 3A-17A_wp09 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3A Pad i Site Position: Northing: 5,996,860.05ft Latitude: 70°24'9.520 N From: Map Easting: 507,712.01 ft Longitude: 149°56'14.019 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.06 ° Well 3A-17 Well Position +N/-S 0.00 ft Northing: 5,997,044.46 ft Latitude: 70°24'11.335 N +E/-W 0.00 ft Easting: 507,662.81 ft Longitude: 149°56'15.455 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 40.40ft - Wellbore 3A-17A Magnetics Model Name Sample Date Declination Dip Angle Field Strength C) (0) (nT) BGGM2009 8/11/2010 17.03 79.83 57,388 Design 3A-17A_wp09 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,297.80 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) C) -40.40 0.00 0.00 200.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (0) (ft) (ft) (ft) (°/100ft) (1100ft) (1100ft) (0) Target ' 7,297.80 38.30 112.30 5,873.96 -1,718.31 3,408.20 0.00 0.00 0.00 0.00 . 7,412.00 38.52 112.58 5,963.45 -1,745.39 3,473.78 0.25 0.19 0.25 38.44 7,427.00 39.79 113.30 5,975.08 -1,749.09 3,482.50 9.00 8.47 4.81 20.00 7,507.00 64.34 122.74 6,023.95 -1,779.21 3,537.26 32.00 30.68 11.80 20.00 7,626.49 95.00 146.28 6,045.43 -1,860.89 3,618.64 32.00 25.66 19.70 40.00 7,776.49 95.57 194.49 6,030.74 -2,003.76 3,642.88 32.00 0.38 32.14 87.00 7,886.49 91.69 210.56 6,023.73 -2,104.80 3,600.94 15.00 -3.53 14.61 103.00 8,016.49 91.59 191.06 6,019.97 -2,225.68 3,555.00 15.00 -0.07 -15.01 270.00 8,096.49 91.56 203.06 6,017.77 -2,301.99 3,531.58 15.00 -0.04 15.01 90.00 8,206.49 91.49 219.57 6,014.82 -2,395.61 3,474.63 15.00 -0.06 15.01 90.00 8,276.49 95.04 229.46 6,010.82 -2,445.38 3,425.71 15.00 5.07 14.14 70.00 8,376.49 90.30 243.71 6,006.13 -2,500.21 3,342.55 15.00 -4.74 14.25 108.00 8,476.49 87.72 258.49 6,007.87 -2,532.50 3,248.23 15.00 -2.59 14.78 100.00 8,576.49 87.79 243.48 6,011.81 -2,564.96 3,154.03 15.00 0.08 -15.01 270.00 8,946.49 88.17 187.95 6,025.95 -2,853.56 2,946.57 15.00 0.10 -15.01 269.30 9,150.00 88.43 218.49 6,032.13 ' -3,038.29 2,867.33 15.00 0.12 15.01 90.00 8/16/2010 1.57.05PM Page 2 COMPASS 2003.16 Build 69 ♦-" ConocoPhillips IF/' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17A Design: 3A-17A_wp09 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (e/100ft) (°) (ft) (ft) 7,297.80 38.30 112.30 5,873.96 -1,718.31 3,408.20 449.01 0.00 0.00 5,995,329.82 511,072.43 TIP-3A-17 7,300.00 38.30 112.31 5,875.69 -1,718.83 3,409.47 449.06 0.25 38.44 5,995,329.30 511,073.70 7,400.00 38.50 112.55 5,954.06 -1,742.53 3,466.88 451.70 0.25 38.44 5,995,305.66 511,131.13 7,412.00 38.52 112.58 5,963.45 -1,745.39 3,473.78 452.03 0.25 38.25 5,995,302.80 511,138.03 1 KOP I 7,427.00 39.79 113.30 5,975.08 -1,749.09 3,482.50 452.52 9.00 20.00 5,995,299.12 511,146.76 End 9 deg DLS 7,500.00 62.16 122.12 6,020.80 -1,775.86 3,531.98 460.76 32.00 20.00 5,995,272.40 511,196.26 7,507.00 64.34 122.74 6,023.95 -1,779.21 3,537.26 462.10 32.00 14.33 5,995,269.05 511,201.54 4 7,600.00 88.09 141.35 6,046.14 -1,839.54 3,603.02 496.30 32.00 40.00 5,995,208.80 511,267.35 7,626.49 95.00 146.28 6,045.43 -1,860.89 3,618.64 511.02 32.00 35.43 5,995,187.47 511,282.99 5 7,700.00 95.78 169.89 6,038.42 -1,928.30 3,645.77 565.08 32.00 87.00 5,995,120.10 511,310.191 7,776.49 95.57 194.49 6,030.74 -2,003.76 3,642.88 636.98 32.00 89.25 5,995,044.64 511,307.3811 End 32 deg DLS 7,800.00 94.77 197.94 6,028.62 -2,026.24 3,636.34 660.34 15.00 103.00 5,995,022.15 511,300.861 7,886.49 91.69 210.56 6,023.73 -2,104.80 3,600.94 746.27 15.00 103.31 5,994,943.57 511,265.54 7 7,900.00 91.69 208.54 6,023.33 -2,116.54 3,594.28 759.59 15.00 -90.00 5,994,931.81 511,258.90 8,000.00 91.62 193.53 6,020.43 -2,209.58 3,558.51 859.24 15.00 -90.06 5,994,838.76 511,223.22 8,016.49 91.59 191.06 6,019.97 -2,225.68 3,555.00 875.57 15.00 -90.49 5,994,822.65 511,219.73 8 8,096.49 91.56 203.06 6,017.77 -2,301.99 3,531.58 955.29 15.00 90.00 5,994,746.32 511,196.40 I 9 I 8,100.00 91.56 203.59 6,017.67 -2,305.21 3,530.19 958.80 15.00 90.00 5,994,743.10 511,195.01 8,200.00 91.50 218.59 6,014.99 -2,390.58 3,478.72 1,056.61 15.00 90.01 5,994,657.69 511,143.63 8,206.49 91.49 219.57 6,014.82 -2,395.61 3,474.63 1,062.74 15.00 90.42 5,994,652.65 511,139.55 10 8,276.49 95.04 229.46 6,010.82 -2,445.38 3,425.71 1,126.25 15.00 70.00 5,994,602.84 511,090.69 11 8,300.00 93.95 232.83 6,008.97 -2,460.08 3,407.46 1,146.30 15.00 108.00 5,994,588.12 511,072.45, 8,376.49 90.30 243.71 6,006.13 -2,500.21 3,342.55 1,206.21 15.00 108.26 5,994,547.93 511,007.59' 12 8,400.00 89.69 247.19 6,006.13 -2,509.97 3,321.17 1,222.70 15.00 100.00 5,994,538.14 510,986.221 8,476.49 87.72 258.49 6,007.87 -2,532.50 3,248.23 1,268.81 15.00 100.00 5,994,515.54 510,913.31 13 8,500.00 87.72 254.96 6,008.81 -2,537.89 3,225.37 1,281.70 15.00 -90.00 5,994,510.13 510,890.461 8,576.49 87.79 243.48 6,011.81 -2,564.96 3,154.03 1,331.53 15.00 -89.86 5,994,482.99 510,819.15 14 8,600.00 87.75 239.95 6,012.72 -2,576.09 3,133.34 1,349.07 15.00 90.70 5,994,471.84 510,798.48 8,700.00 87.69 224.94 6,016.72 -2,636.82 3,054.35 1,433.15 15.00 -90.56 5,994,411.04 510,719.56 8,800.00 87.77 209.93 6,020.71 -2,715.93 2,993.79 1,528.20 15.00 -89.96 5,994,331.87 510,659.08 8,900.00 88.01 194.92 6,024.40 -2,808.04 2,955.78 1,627.76 15.00 -89.36 5,994,239.73 510,621.17 8,946.49 88.17 187.95 6,025.95 -2,853.56 2,946.57 1,673.68 15.00 -88.81 5,994,194.21 510,612.01 15 9,000.00 88.19 195.98 6,027.65 -2,905.83 2,935.50 1,726.59 15.00 90.00 5,994,141.93 510,600.99 9,100.00 88.32 210.98 6,030.71 -2,997.25 2,895.79 1,826.08 15.00 89.74 5,994,050.48 510,561.38 9,150.00 88.43 218.49 6,032.13 -3,038.29 2,867.33 1,874.38 15.00 89.29 5,994,009.41 510,532.97 TD at 9150.00 8/16/2010 1.57:05PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips WE- Conoco ips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17A Design: 3A-17A_wp09 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3A-17A t7 0.00 0.00 6,050.00 -3,045.02 2,843.33 5,994,002.66 510,508.98 70°23'41.382 N 149°54'52.179 W -plan misses target center by 30.67ft at 9150.00ft MD(6032.13 TVD,-3038.29 N,2867.33 E) -Circle(radius 1,320.00) 3A-17A t2 0.00 0.00 6,046.00 -1,831.70 3,596.67 5,995,216.63 511,261.00 70°23'53.312 N 149°54'30.098 W -plan hits target center -Point 3A-17A Fault 1 0.00 0.00 0.00 -1,319.88 3,820.22 5,995,728.63 511,484.00 70°23'58.344 N 149°54'23.542 W -plan misses target center by 5901.86ft at 7297.80ft MD(5873.96 TVD,-1718.31 N,3408.20 E) -Polygon Point 1 0.00 -1,319.88 3,820.22 5,995,728.63 511,484.00 Point2 0.00 -2,151.56 3,407.37 5,994,896.61 511,072.05 Point 3 0.00 -2,782.46 3,242.74 5,994,265.60 510,908.08 Point4 0.00 -2,151.56 3,407.37 5,994,896.61 511,072.05 3A-17A,AL1 Fault 2 0.00 0.00 0.00 -2,315.40 3,274.13 5,994,732.65 510,938.99 70°23'48.556 N 149°54'39.552 W -plan misses target center by 5905.75ft at 7297.80ft MD(5873.96 TVD,-1718.31 N,3408.20 E) -Polygon Point 1 0.00 -2,315.40 3,274.13 5,994,732.65 510,938.99 Point 2 0.00 -2,510.91 3,779.99 5,994,537.67 511,445.00 3A-17A t6 0.00 0.00 6,011.00 -2,554.33 3,177.88 5,994,493.65 510,842.99 70°23'46.207 N 149°54'42.375 W -plan hits target center -Point 3A-17A t3 0.00 0.00 6,046.00 -1,847.71 3,608.65 5,995,200.63 511,273.00 70°23'53.154 N 149°54'29.747 W -plan hits target center -Point 3A-17A,AL1 Polygon 0.00 0.00 0.00 -1,764.62 3,531.73 5,995,283.63 511,196.00 70°23'53.972 N 149°54'31.999 W -plan misses target center by 5875.44ft at 7297.80ft MD(5873.96 TVD,-1718.31 N,3408.20 E) -Polygon Point 1 0.00 -1,764.62 3,531.73 5,995,283.63 511,196.00 Point 2 0.00 -1,937.80 3,697.58 5,995,110.64 511,362.01 Point 3 0.00 -2,422.73 3,576.09 5,994,625.64 511,241.03 Point 4 0.00 -2,623.49 3,311.87 5,994,424.63 510,977.04 Point 5 0.00 -2,760.25 3,049.71 5,994,287.61 510,715.05 Point 6 0.00 -3,316.14 2,883.15 5,993,731.61 510,549.07 Point 7 0.00 -3,195.89 2,633.25 5,993,851.59 510,299.08 Point 8 0.00 -2,596.98 2,788.84 5,994,450.60 510,454.04 Point9 0.00 -2,401.54 3,384.09 5,994,646.63 511,049.03 Point 10 0.00 -2,051.67 3,554.45 5,994,996.64 511,219.01 3A-17A t1 0.00 0.00 5,963.00 -1,745.56 3,473.75 5,995,302.64 511,138.00 70°23'54.159 N 149°54'33.697 W -plan hits target center -Circle(radius 1,320.00) 3A-17A t4 0.00 0.00 6,015.00 -2,390.62 3,478.08 5,994,657.64 511,142.99 70°23'47.815 N 149°54'33.579 W -plan hits target center -Point 3A-17A t5 0.00 0.00 6,006.00 -2,510.47 3,320.94 5,994,537.65 510,985.99 70°23'46.637 N 149°54'38.184 W -plan hits target center -Point 8/16/2010 1.57:05PM Page 4 COMPASS 2003.16 Build 69 v-' ConocoPhillips FS- Conoco Phillips Planning Report BAKER Aka HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17A Design: 3A-17A_wp09 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,821.00 3,223.24 7 5/8" 7-5/8 9-7/8 9,150.00 6,032.13 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,297.80 5,873.96 -1,718.31 3,408.20 TIP-3A-17 7,412.00 5,963.45 -1,745.39 3,473.78 KOP 7,427.00 5,975.08 -1,749.09 3,482.50 End 9 deg DLS 7,507.00 6,023.95 -1,779.21 3,537.26 4 7,626.49 6,045.43 -1,860.89 3,618.64 5 7,776.49 6,030.74 -2,003.76 3,642.88 End 32 deg DLS 7,886.49 6,023.73 -2,104.80 3,600.94 7 8,016.49 6,019.97 -2,225.68 3,555.00 8 8,096.49 6,017.77 -2,301.99 3,531.58 9 8,206.49 6,014.82 -2,395.61 3,474.63 10 8,276.49 6,010.82 -2,445.38 3,425.71 11 8,376.49 6,006.13 -2,500.21 3,342.55 12 8,476.49 6,007.87 -2,532.50 3,248.23 13 8,576.49 6,011.81 -2,564.96 3,154.03 14 8,946.49 6,025.95 -2,853.56 2,946.57 15 9,150.00 6,032.13 -3,038.29 2,867.33 TD at 9150.00 I 8/16/2010 1:57:05PM Page 5 COMPASS 2003.16 Build 69 MI W 8 `W� m Y s �' I s = a m T ° • a m , m v n ' o ° . �� m r < m go V 5 F ( • a�Q ' ° a th.AI _ \ % a• 0-6E-631 Q •--- r I 4- -2Z3 "' Millakm.-/- r B ✓• W r m F q P - $ r - — g _ a m r G $ O N P. f- r ;f1 f• a� n r O cc � � -) ►noS m (u! 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Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 f L_ To to o) O O n a) ❑ N C. O N •C. _ E L 0 c 0 Q 0 a 2 a) a) N L - = N• C n D .3 O rn 0 a o- 0 c 0 0 `o c - L L U > L 'o •7 N' a) cn 3 W c E N O Bpi C to 0. r a) 0. 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