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7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-18A Install Tie-back Liner & New Com Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-063 50-029-20767-01-00 14000 Surface Intermediate Scab Liner / Tie-Bac Liner Liner 8680 2475 9773 870 2696 1918 9986 13-3/8" 9-5/8" 7" / 7" 3-1/2" x 3-3/16" 2-3/8" 8701 37 - 2512 35 - 9808 8998 - 9868 / 23 - 9449 - 12145 12085 - 14000 37 - 2512 35 - 8565 7866 - 8618 / 23 - 7869 8252 - 8671 8665 - 8680 none 2670 4760 5410 10530 9986 5380 6870 7240 10160 9997 - 13971 4-1/2" 12.6# 13-CR 21 - 9393 8706 - 8679 Conductor 82 20" 38 - 120 38 - 120 1490 470 4-1/2" HES TNT , 8893 , 7777 No SSSV 8893 7777 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) 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.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028311 , 0028329 21 - 8203 236 0 34478 0 0 0 1154 0 978 0 324-337 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.09.24 08:35:23 - 08'00' Bo York (1248) By Grace Christianson at 9:34 am, Sep 24, 2024 RBDMS JSB 100324 WCB 10-14-2024 DSR-9/27/24 ACTIVITYDATE SUMMARY 6/24/2024 T/I/O = SSV/550/440. Temp = SI. MIT-OA max applied 550 psi, target 500 psi PASSED & PPPOT-T PASSED (Pre RWO). ALP = 2000 psi, SI @ CV. IA FL @ 320' (18 bbls). OA FL @ 80' (5 bbls). PPPOT-T: Stung into test void (20 psi). Bled void to 0 psi. Pressured test void to 5000 psi. Monitored for 30 min. Lost 200 psi in the 1st 15 min & 50 psi in the 2nd 15 min for a total loss of 250 psi in 30 min. Bled void to 0 psi. Bled OAP slowly to 0+ in 2.5 hrs. Used 6.4 bbls of diesel to pressure OAP to 550 psi in 30 min. Monitored for 30 min. OAP lost 38 psi in the 1st 15 min & 11 psi in the 2nd 15 min for a total loss of 49 psi in 30 min. Bled OAP to 0+ psi in 10 min returning 1.1 bbls of diesel. Tags hung. Final WHPs = SSV/550/0+. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:30 6/24/2024 ***WELL S/I ON ARRIVAL*** PULLED P-PRONG FROM PX-PLUG & 9459'MD PULLED PX-PLUG BODY FROM X-NIP @ 9459'MD PERFORMED MAN DOWN DRILL w/WSL DRIFTED TO DEVIATION @ 10042'SLM w/2.50'' S-BAILER ***WELL LEFT S/I ON DEPARTURE*** 6/25/2024 T/I/O= 1326/544/31 LRS Unit 76 Assist E-Line (RWO CAPITAL) Pump 3 BBLS 50/50 followed by 250 BBLS 1% KCL to load the well for E-Line. Pump 3 BBLS 50/50 followed by 38 BBLS Crude for TBG freeze protect. Pumped 13 bbls crude down TBG to pressure up on plug. Bled TBG pressure back to 0 psi. Bled back ~ 1.25 bbls RDMO E-line in control of well upon LRS departure. FWHP's = 0/587/702 6/25/2024 *** WELL SI ON ARRIVAL*** PT TO 200 LOW AND 3000 PSI HIGH. LOG CORRELATED TO LINER SUMMARY DATED10-OCT-2009. RIH. HEAD /2" WB/1.69" WB/2-1/8"CCL/ADAPTOR/MSST/PLUG. MAX OD: 2.50" LENGTH: 22' WEIGHT: 250# CCL TO MID ELEMENT: 9FT. CCL STOP DEPTH: 9977' MID ELEMENT DEPTH: 9986' 13 BBL TO FULL TUBING AFTER PLUG. HOLD AT 1000PSI FOR 10 MINUTES. LOST 64 PSI. THEN STABLED OFF. RIH. HEAD/WELLTECH MECHANICAL CUTTER. WEIGHT: 260# LENGTH: 23' MAX OD: 2.374" HAVE LEAK OUT OF THE GREASE HEAD. POOH AND CLEAN. *** JOB CONTINUED ON 26-JUNE-2024** Daily Report of Well Operations PBU 06-18A Assist E-Line (RW O CAPITAL) Pump 3 BBLS() 50/50 followed by 250 BBLS 1% KCL to load the well for E-Line. Pump 3 BBLS 50/50y followed by 38 BBLS Crude for TBG freeze protect. Pumped 13 bbls crude downy TBG to pressure up on plug. RIH. HEAD /2" WB/1.69" WB/2-1/8"CCL/ADAPTOR/MSST/PLUG. MAX OD: 2.50" LENGTH: 22' WEIGHT: 250# CCL TO MID ELEMENT: 9FT. CCL STOP DEPTH: 9977'MID ELEMENT DEPTH: 9986' 13 BBL TO FULL TUBING AFTER PLUG PULLED P-PRONG FROM PX-PLUG & 9459'MD PULLED PX-PLUG BODY FROM X-NIP @ 9459'MD@ PERFORMED MAN DOWN DRILL w/WSL DRIFTED TO DEVIATION @ 10042'SLM w/2.50'' S-BAILER Daily Report of Well Operations PBU 06-18A 6/26/2024 *** JOB CONTINUED FROM 25-JUNE-2024*** PT TO 250 LOW AND 2500PSI HIGH. RIH. HEAD/WELLTECH MECHANICAL CUTTER. WEIGHT: 260# LENGTH: 23' MAX OD: 2.374" CCL TO CUT: 18.3 FT; CCL STOP DEPTH: 9380.7FT; TUBING CUT AT 9399' CUTTER OPENED TO: 4.6" RDMO AKEL *** JOB COMPLETED *** 6/27/2024 Function and lube LDS for upcoming RWO. All operating as should.. 7/7/2024 T/I/O = 220/510/0. Set 4" ISA BPV, Removed 4' CIW Upper Tree. Installed dryhole tree. Torqued to spec. PT Low (350 psi) Passed PT High (5000 psi). Pull ISA BPV FWP 220/510/0 7/9/2024 T/I/O = 340/564/0. Pumped 25bbls 60/40 down tubing, through cut, up IA to neighboring flowline, to establish good enough rate for upcoming circ out. 5bpm @ 1300psi. FWHP's = 89/723/0 7/10/2024 T/I/O = 490/667/3. ***Circ Out*** Pumped 103bbls surfactant, 303bbls 1%KCl, 737bbls 9.8 brine w/ safelube down tubing, up IA, to 06-19's flowline. Bled well to zero. FWHP's = 0/0/0 7/11/2024 T/I/O = VAC/VAC/18. Temp = SI. Bleed OAP (pre RWO). Wellhouse removed. Dryhole tree & rig scaffold installed. Bled OAP to 0 psi in 30 min (gas). Held open bleed for 3 hrs. Monitored for 30 min. OAP increased 2 psi. Final WHPs = VAC/VAC/2. SV, MV = C. IA, OA = OTG. 04:30 7/11/2024 T/I/0= Vac/Vac/03. Set 4" ISA BPV #549 for RWO 7/22/2024 RWO Decompletion Check void for psi, nipple down THA & dry hole tree together, clean void & ring groove, function each tubing hanger lock down screw one at a time, 3-5/8" clear bowl, make up 5-3/4" LH acme blanking plug to tubing hanger lift threads 9-1/2 LH, there is a nose seal on the blanking plug, as well as an O-ring above the threads which seals on the top shoulder of the tubing hanger neck, the blanking plug sticks up 11-1/2" above the top flange of the tubing head, the tubing hanger lock down screws RKB is 22.85', install new BX-160, stand by for BOP nipple up. 7/22/2024 Nabors CDR 2 - RWO, 7" Tie-Back, Pre-CTD Mobilize Rig from B-30A to 06-18A, 7/21/2024. Arrive DS 6 at 2300. Rig Accepted @ 00:01, 7/22/2024. Complete MIRU Checklists. Remove Tree/THA. Install Blanking Plug in BPV. Test fit threaded XO. Cycle Test LDS. NU 13-5/8" and 7-1/16" BOPs. ***Job Continued to 7-23-2024 *** EL cut tubing @9399' MD. -WCB Pumped 103bbls surfactant, 303bbls 1%KCl, 737bbls 9.8 brine w/ safelube down tubing, up IA, to 06-19's flowline. RIH. HEAD/WELLTECH MECHANICAL CUTTER. WEIGHT: 260# LENGTH: 23' MAX OD: 2.374" CCL TO CUT: 18.3 FT; CCL STOP DEPTH: 9380.7FT; TUBING CUT AT 9399' Mobilize Rig from B-30A to 06-18A, 7/21/2024.g Arrive DS 6 at 2300. Rig Accepted Wellhouse removed.() Dryhole tree & rig scaffold installed. Bled OAP to 0 psi in 30 min (gas). Held openyg bleed for 3 hrs. Monitored for 30 min. OAP increased 2 psi Daily Report of Well Operations PBU 06-18A 7/23/2024 Nabors CDR 2 - RWO, 7" Tie-Back, Pre-CTD Continued from 7/22/2024 Continue to NU 13-5/8" and 7-1/16" BOPs. Install CB74 Riser up through rig floor to QTS. Hook up Koomey Lines. Replace Fittings on hydraulic hoses for McCoy Tongs Rental Power Unit. MU Dart Valve to 2 x TIW valves. Start BOP Testing. ***Job Continued to 7-24-2024 *** 7/24/2024 Nabors CDR 2 - RWO, 7" Tie-Back, Pre-CTD ...Continue WSR from 7/22/2024....Continue to NU 13-5/8" and 7-1/16" BOPs. Install CB74 Riser up through rig floor to QTS. Hook up Koomey Lines. Replace Fittings on hydraulic hoses for McCoy Tongs Rental Power Unit. MU Dart Valve to 2 x TIW valves. Test BOPE, Annular Bag, 2-3/8" x 5" VBR, Blind/Shear, Choke & Kill line valves. (2) FOSV's, Hydraulic and Manual IBOP's 250 psi Low / 3000 psi High. Completed testing, Install flow riser. ...Continue WSR on 7/25/2024... 7/25/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from 7/24/2024... Check IA pressure, pull blanking plug then 4" ISA. MU Landing Jt, BOLDS, Pull 125k- lbs) TBG Hanger to floor no issues. LD landing Jt and TBG hanger. Circulate bottoms up= ~510 bbls plus. Pull 4-1/2" New VamTop completion. Recovering 1- X Nipple, 5 GLM's 219 full joints and cut joint 1.56' in length. Leaving ~40' of cut joint #1 in hole. Total fluid loss during decompletion= 14 bbls Ave 1.167 BPH Clear floor, pipe shed ...Continue WSR on 7/26/2024.... 7/25/2024 M/U blanking plug retrieval tool, RIH, M/U to plug and back out of TBG HGR. Check for pressure and Pull ISA BPV #549. M/U LJ to TBG HGR, BOLDS. Pull TBG HGR to rig floor. 7/26/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from 7/25/2024... NU 7-1/6" coil auxiliary stack, function test and service test flange break to 3500 psi. MU/RIH w/BHA #1 CTC 3.125", Lock-able Swivel, 3.13", XO 3.050", 1 JT 2-3/8" PH^, XO 3.13", DBPV 3.13", G-Force Jar 3.13", TJ Disc (3/4" ball), XO 3.13", XO 2.85", #20 Mod J Setting Tool 3.83", WL Adapter Kit 4.48", 47B2 WLSTRBP 5.930" OAL= 60.13' Drift through 7" Tie-Back LNR several times to get depth correlation. +14¿. Position RBP launch ½" steel ball ...Continue WSR on 7/27/2024... 7/27/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from 7/25/2024... Surge fluid in CT to get ball on seat. Pressure up and set 47B2 WLSTRBP at 9057' top of plug. Release from RBP and tag 10k down. PUH above 7" Tie-Back, pressure test RPB to 500 psi and hold for 5 min (Good) POOH. MU/RIH/BHA #2 Sand dump assembly w/3.03" Nozzle (1.00" hole). Mix and pump 5 bbl, 6 ppa sand slurry with gel lead and tail, Lay in sand slurry from 9020' pumping 1:1 to 8890'. POOH pumping coil displacement. LD sand dump assembly. LD riser and 7-1/16" stack. ...Continue WSR on 7,28/2024... Continue to NU 13-5/8" and 7-1/16" BOPs. Testyg BOPE, Annular Bag, 2-3/8" x 5" VBR, Blind/Shear, Choke & Kill line valves. (2)g FOSV's, Hydraulic and Manual IBOP's 250 psi Low / 3000 psi High Pull TBG HGR to rig floor. Daily Report of Well Operations PBU 06-18A 7/28/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from 7/27/2024... Pull flow box off. . MU/BHA #3 Lock-able Swivel, DBPV's, Logan Fishing Jar, TJ Disc, DCV's, BA Fluted Cent, 3-3/8" Ultra Navi Motor, 7-7/16" Tie Back Polish Mill (7.437") Deploy through 13-5/8" BOP. MU 7-1/16" stack and riser. Trouble shoot rig data acquisition and recording failure (7 hrs rig NPT) Test service break for coil auxiliary stack. RIH/BHA #3 (7.437" Polish Mill) pumping min rate. Dress liner top receptacle at 8,998' per Baker rep. Pump HiVis sweep off bottom and chase to surface. ...Continue WSR on 7/29/2024... 7/29/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from 7/28/2024... Continue POOH, Tag at surface jog down/up 100'. At surface w/BHA #3. Flow Check. Flow Check ND service coil auxiliary stack. Recover BHA #3. Install flow box and riser. Fly in GBR tongs and supporting equipment for running of 7" Csg. Set test plug. Swap VBR's to 7" FR. Test 7" FR 250 psi Low/3000 psi High. Test Annular 250 psi Low/2500 psi High. Pull test plug. Prep floor, run 7" Tieback assembly and 7", 29#, L-80 Csg. ...Continue WSR on 7/30/2024... 7/30/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from 7/28/2024... : Prep Rig floor for running 7' Csg. MU/Run 7" Tie-back assembly: Ported tieback seals , insert orifice float, insert landing collar, 7", 29# L-80 Csg, one 8-1/4" centralizer per every other joint. Preform Kick while tripping drill on both towers. Continue running 7" Csg. Joint #216 Wt Ck 235k-lbs Slowly lower seeing billet seals go into PBR. PU and Space out Csg. Land at 9009' SD 20k-lbs....Continue WSR on 7/31/2024... .. 7/31/2024 Hold PJSM w/ rig crew. Break stack, clean, prep and center CSG. Install 13" x 7" C- 29 slips w/ 50k weight in slips. Mark CSG and cut @ 6 1/2" above FLG face. Bevel and prep stump. Install new BX160. Install new FMC NSBB TBG HD. S/B for rig crew to torque connection. R/U test equipment test secondary seals to 5M for 15 min. Passed. Test witnessed by Co man. Bleed off pressure and turn well over to rig crew. 7/31/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from 7/28/2024... MU Bail Extensions and Top Drive onto top of 7" Csg. Land 7", 29# L-80 Csg, confirm Billet seals are stung in @ 9005' MD. Break circulation and pump bottoms up, RU HES cementers. Pump 255 bbls 15.3 Class G cement. Launch LWP and displace with 9.8 brine. Did not see LWP bump at 1 bbl over calculated volume. Discuss w/ Operations Engineer. Slack off and bury seals. RD HES cementers. Flow check well for 30 min. Set Csg slips, ND stack. Install IC pack-off and new Tbg spool. Test IC pack-off to 5,000 psi. NU stack. ...Continue WSR on 8/1/2024... 8/1/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from 7/31/2024... Continue NU 13-5/8" BOP, Set test plug, install serivce coil auxilly stack. ...Contiue WSR on 8/2/2024.... 8/2/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from8/1/2024/2024... Reconfigure assmebly below CT injector. Found damage to sealing surface on CB 74 QTS. Stack new CB 74 QTS. Service valves and inspect CT pack-off. Start Weekly BOPE testing. Annular Bag 250 psi Low / 2500 psi High. Rams 250 psi Low / 3000 psi High. Annular Bag failed after multiple attempts. Continue testing. Truble shoot Bag ...Continue WSR on 8/3/2024... MU Bail Extensions and Top Drive onto top of 7" Csg. Land 7", 29# L-80 Csg, confirmgg Billet seals are stung in @ 9005' MD. Break circulation and pump bottoms up, RUg@ HES cementers. Pump 255 bbls 15.3 Class G cement. Launch LWP and displace with 9.8 brine. Did not see LWP bump at 1 bbl over calculated volume. Discuss w/ Operations Engineer. Slack off and bury seals. RD HES cementers run 7" Tieback assembly and 7", 29#, L-80 Csg Continueyj g running 7" Csg. Joint #216 Wt Ck 235k-lbs Slowly lower seeing billet seals go intogg PBR. PU and Space out Csg y Dress liner top receptacle( at 8,998' per Baker rep Break stack, clean, prep and center CSG. Install 13" x 7" C-g 29 slips w/ 50k weight in slips. Mark CSG and cut @ 6 1/2" above FLG face. Bevelg@ and prep stump. Install new BX160. Install new FMC NSBB TBG HD. S/B for rigg crew to torque connection. R/U test equipment test secondary seals to 5M for 15 min. Passed. Test witnessed by Co man y Fly in GBR tongs and supporting equipment for running of 7" Csg. Set testyg g gg plug. Swap VBR's to 7" FR. Test 7" FR 250 psi Low/3000 psi High. Test Annular 250gg psi Low/2500 psi High. Daily Report of Well Operations PBU 06-18A 8/3/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from8/2/2024/2024... Trouble shoot annular bag. Ran borescope found Annular bag damaged. ND riser and top cap of 13-5/8" Annular. Install new Annular element. NU top cap of Annular and riser. RU 2-3/8" test joint and BOP test pump. Test Annular 250 psi Low / 2500 psi High. Complete draw down test on Koomey. RD test joint and equipment. RD CT axillary equipment. Pull test plug. RU CT axillary equipment. ...Continue WSR on 8/4/2024... 8/4/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from8/3/2024/2024... Test service break. MU/BHA #4, RIH with Yellowjacket 6" Tri-Cone bit milling assembly. Tag at 8821' ctmd. PUH and establish milling parameters. Work through 9002' and RIH to 9030'. Pump HiVis sweeps. Mill/Wash to 9040' and pump additional HiVis sweep. POOH pumping 4 bpm and chasing sweeps to surface. L/D and inspect milling BHA. MU BHA #5./ RIH w/ Jet Down Nozzle assembly. Correct depth at Yellow flag and tagged hard at 9042'. Attempted to Jet down to RBP using HiVis sweeps with no progression. POOH pumping at 4 bpm chasing sweeps to surface. ....Continue WSR on 8/5/2024... 8/5/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from8/4/2024/2024... RIH w/Convex Mill Assembly Mill F/9016' / T9115¿ ctmd. Unable to mill past 9115'. Pump 10 bbl HiVis pill. POOH / LD milling BHA and inspect. Note wear pattern in center of mill believed to be setting lug on RBP. MU / RIH BHA #7 RBP pulling tool. Tag at 9108' work down to 9111'. Attempt to latch RBP. POOH. MU / RIH BHA #8 Wash Over Shoe. RIH. ...Continue WSR on 8/6/2024... 8/6/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD ...Continue WSR from8/5/2024/2024.. Continue in hole w/BHA #8 Wash Over Shoe Tag at 9117' slowly rotate at 0.1 fpm. Wash down 3' and stalled. Repeated process and stalled at 9120.5'. Pump HiVis sweep and chase OOH. At surface found wash pipe full of cement RIH w/ BHA #9 Dry tag at 9120' work down to 9128' POOH and recover wash pipe full of cement. RIH w/ BHA #10 Tag at 9115' and wash down to 9128' Stalling and making no progression further. Send HiVis sweep down and chase OOH ....Continue WSR on 8/7/2024.... 8/7/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/6/2024... Continue POOH w/BHA #10 LD BHA, wash pipe packed with cement. RIH with BHA #11, YJ Milling Assy., with wash pipe. Mill for ~4 hours. Working down slightly to 9132'. POOH. Wash Pipe again packed with Cement. RIH w/YJ Milling Assy., BHA #12, 6.0625" 6-blade Junk Mill. Start Milling Cement @ 9135'. Mill down to 9260', 25-30 ft/hour ROP. Pump 2 sweeps (10 bbl Powervis). ***Continue WSR to 8/8/2024.*** Start Milling Cement @gy 9135'. Mill down to 9260', 25-30 ft/hour ROP. RIH with Yellowjacket 6" Tri-Cone bit millingjg assembly. Tag at 8821' ctmd. PUH and establish milling parameters. Work throughyg g g 9002' and RIH to 9030'. Pump HiVis sweeps. Mill/Wash to 9040' and pump additional HiVis sweep. POOH pumping 4 bpm and chasing sweeps to surface. L/D andgg inspect milling BHA. MU BHA #5./ RIH w/ Jet Down Nozzle assembly. Correct depthgy at Yellow flag and tagged hard at 9042'. Attempted to Jet down to RBP using HiVisggg g sweeps with no progression. POOH pumping at 4 bpm chasing sweeps to surface. Daily Report of Well Operations PBU 06-18A 8/8/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/7/2024... Milling with YJ Assy., 6.0625" 6-Blade Junk Mill at 9265'. Pumping Sweeps, 10 bbls every 50-60' feet milled. ROP almost stopped at 9290'. Pump 20 bbl HiVis sweep. Paint Yellow EOP Flag at Bit Depth 8986'. EOP = 8924'. ***Job in Progress*** 8/8/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/7/2024... Milling with YJ Assy., 6.0625" 6-Blade Junk Mill at 9265'. Pumping Sweeps, 10 bbls every 50-60' feet milled. ROP almost stopped at 9290'. Pump 20 bbl HiVis sweep. Paint Yellow EOP Flag at Bit Depth 8986'. EOP = 8924'. RBIH with YJ Motor/Wash Pipe BHA# 13. Tag Top of RBP @ 9289'. 4k overpull after setting down. Confirm Set down in same spot 3 times. Pump Sweep. Chase OOH at 60%. Inspect Wash Pipe, Tattle tales all bent back 90 degrees. No cement in wash pipe but slight amound of sand. RIH with YJ RBP Retrieval BHA #14. Stack down 5 times with no indication of latch up to RBP. Pump 5 bbl sweep while stacked down on Fish Neck. ***Job Continued to 8/9/2024*** 8/9/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/8/2024... Make 1 additional attempt to latch up, Jar down again. See 10k overpull. POOH to Inspect BHA. LD Retrieval Tools. We have the fish neck at surface, no Plug though. Assess plan forward for Fishing. Trim 25' of Coil, no E-Line. RIH with BHA #15, YJ Fishing Assembly. Latch on RBP with 2.13" Slick Catch Grapple OS with 5" Baker GS Spear. Minimal overpull observed after first Set down, 1k - 3k #'s. Run back down to slack off on plug again and drift down 50 feet below plug set depth to 9350'. Let Plug elements relax for 1 hour. Pull to surface slowly keeping hole full with ~100 psi Choke back pressure. No additional overpulls observed on trip OOH. ***Job Continued to 8/10/2024*** Assess plan forward for Fishing. Trim 25' of Coil, no E-Line. RIH with BHA #15, YJg Fishing Assembly. Latch on RBP with 2.13" Slick Catch Grapple OS with 5" Bakergy GS Spear. Minimal overpull observed after first Set down, 1k - 3k #'s. Run back down to slack off on plug again and drift down 50 feet below plug set depth to 9350'.gg g Let Plug elements relax for 1 hour. Pull to surface slowly keeping hole full with ~100g psi Choke back pressure. g We have the fish neck at surface, no Plug thoughgg Daily Report of Well Operations PBU 06-18A 8/10/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/9/2024... At surface with Fishing BHA. Flow Check Well 10 minutes. LD Fishing BHA. RBP is Recovered. 2 small chunks of sealing rubber left in hole. Test Casing to 3000 psi. for 30 minutes. Lost 20 psi initial 15 minutes/3 psi second 15 minutes. PASS. R/D and Fly out Tongs and Coil Double Gate BOP off rig. Rig up and install Bell Nipple and Flow Riser to rig floor. Leak Test Air Boots. Install BOP Test Plug and Torque LDS. Test H2S and LEL gas Alarms. Notice to test BOPE given to AOGCC @ 8/9/2024, 0900. Start BOPE Test at 2200. Test to 250/3000 (2500 Annular) per Sundry. Witness Waived by AOGCC Rep Adam Earl. ***Job Continued to 8/11/2024*** 8/11/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/10/2024... Continue Testing BOPE. 250/3000. 2500 Annular, per Sundry. Pull Test Plug. Test Fit Tubing hanger with Landing Joint. Begin PU and Run 4.5", 12.6#, 13Cr, VAMTop Gas-Lifted Completion. ***Job Continued to 8/12/2024*** 8/12/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/11/2024... Continue PU and Run 4.5", 12.6#, 13Cr, VAMTop Gas-Lifted Completion per Approved Tally. Slack off Mule Shoe to Cover Cut Tubing Stump. See Both upper/lower Shear screws. Space-out Completion with Partial joint. Land Hanger/RILDS and Verify torque to 450 ft/lbs. Final Mule Shoe Overshot depth 9406.73' MD. Displace 9.4 ppg brine from Tubing / IA with 1% KCL 8.4 ppg, 120°. 400 bbls Spot 60 bbls of 1% KCL 8.4 ppg with CI from GLM # 3 down to Mule Shoe. Drop Ball and Rod 1.875" (1.375" Fish Neck) ***Job Continued to 8/13/2024*** 8/12/2024 Land 13 x 4-1/2 Tubing hanger stand by for circulate. Set H TWC & test at 3300 psi, stand by for BOP ND. 8/13/2024 BOP is off, clean void, ring groove, & TWC profile, install SBMS, grese hanger neck OD seals & SBMS, make up THA, rig crew torqued up w/ Sweeney, test void 500 psi/5 min., 0 psi loss, test 5000 psi/30 min, lost 200 psi first half, lost 0 psi second half, bleed off test psi., stand by for rig to test tree, pull 4" CIW TWC w/ T-bar, RDMO Land 13 x 4-1/2 Tubing hanger stand by for circulate Continue Testing BOPE. 250/3000. 2500 Annular, per Sundry Continue PU and Run 4.5", 12.6#, 13Cr, VAMTop Gas-Lifted Completion per Approved Tally.y Slack off Mule Shoe to Cover Cut Tubing Stump. See Both upper/lower Shear screws. Space-out Completion with Partial joint.j Land Hanger/RILDS and Verify torque to 450 ft/lbs.gy Final Mule Shoe Overshot depth 9406.73' MD. Displace 9.4 ppg brine from Tubing / IA with 1% KCL 8.4 ppg, 120°. 400 bblsgg g Spot 60 bbls of 1% KCL 8.4 ppg with CI from GLM # 3 down to Mule Shoe. Drop Ball and Rod 1.875" g Begin PU and Run 4.5", 12.6#, 13Cr, VAMTop y gg Gas-Lifted Completion At surface with Fishing BHA. Flow Check Well 10 minutes. LD Fishing BHA. RBP is Recovered. g Notice to test BOPE given to AOGCC @gg@ 8/9/2024, 0900. Start BOPE Test at 2200. Test to 250/3000 (2500 Annular) per Sundry. Witness Waived by AOGCC Rep Adam Earl Daily Report of Well Operations PBU 06-18A 8/13/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/12/2024... Pressure Up Tubing to 3500 psi. Shear/Set 4-1/2" x 7" 13CR HES TNT Packer at 8893'. MIT-T after packer set at 3500 psi. Pressure Loss = 54/16. Pass. MIT-IA. Pressure Loss = 17/2. Pass Shear out Circ Valve at Upper GLM. 2350 Diff. psi. Circulate 10 bbls of KCL through Valve to confirm clear. 2.4 bb/min @ 1270 psi. T-Bar Set TWC. PT to 3300 psi. ND 13-5/8" BOP Stack. Install new BX-160 gasket. NU Tree and Torque THA flange, 4200 ft/lbs. ***Job Continued to 8/14/2024*** 8/14/2024 Nabors CDR2 - RWO 7" Tie-Back. Pre-CTD. Continue WSR from 8/13/2024... PT Hanger Void to 500/5000 psi / 30 minutes. PT Tree to 500/5000 psi / 5 minutes. Pull TWC. RU LRS - Load IA / Tubing w/Diesel FP. 90 bbls. Let FP U-tube for 1 hour. FP to 2500'. Secure Tree. All Valves Shut. Continue RD Checklists. *RIG RELEASED @ 0700* **Job Completed** 8/17/2024 T/I/O/OO = SSV/40/0+/0+. Temp = SI. Strap TOC in OA (post RWO). No well house, S-riser or flow line. Block valves installed on OA and companion SSO's. Strapped OA TOC @ 12' on the 12:00 side, and 19' 6" on the 06:00 side ( ~ .5 bbls). 8/17/2024 T/I/O/OO = ASV/50/VAC/40. Temp = SI. Strap OA TOC (pre CTO). Dryhole tree w/ additional ASV, integral on OA, and rig scaffold installed. Unable to reach TOC w/ string. ASV, SV = C. MV = O. IA, OA = OTG. 00:30 8/18/2024 ***WELL S/I ON ARRIVAL*** RIH w/ KJ, 3.55" BELL GUIDE, 2" JUS, PULL B & R @ 8,927' MD PULL BEK-SOV FROM STA.# 4 @ 3,541' MD SET BK-DGLV IN STA.# 4 @ 3,541' MD LRS- R/U TO IA ***CONTINUE 8/19/24*** 8/18/2024 T/I/O/OO = SSV/60/0/40. Temp = SI. Top off 7" x 9-5/8" annulus w/ cement. Dryhole tree, integral on OA, rig scaffold installed. Mixed and poured FineCem cement into OA until good cement returns out of companion (~21 gal). Pollard Slickline in control of well upon departure. 15:00 8/18/2024 T/I/O= 334/428/0, LRS Unit 72, Assist Slickline with MIT-IA(SIDETARCK), Pumped 0.5 bbls of DSL down IA, *** Job continued to 8-19-24*** Pressure Up Tubing to 3500 psi. Shear/Set 4-1/2" x 7" 13CR HES TNT Packer at 8893'. MIT-T after packer set at 3500 psi. Pressure Loss = 54/16. Pass. MIT-IA. Pressure Loss = 17/2. Pass Shear out Circ Valve at Upper GLM. 2350 Diff. psi. Circulate 10 bbls of KCL through Valve to confirm clear. RIH w/ KJ, 3.55" BELL GUIDE, 2" JUS, PULL B & R @ 8,927' MD PULL BEK-SOV FROM STA.# 4 @ 3,541' MD Daily Report of Well Operations PBU 06-18A 8/19/2024 *** Job continued from 8-18-24*** LRS Unit 72, (SIDETRACK) Assist Slickline, Pumped 1.2 bbls of DSL down IA for MIT-IA. (Total of 2 bbls of DSL down IA), preassured up IA to 2710 Psi with 1.2 bbls of DSL, Lost 42 Psi in 15 min, Lost 11 Psi in 30 Well left in slicklines controll, DSO notified upon departure FWHP= 266/507/1 8/19/2024 ***CONTINUEFROM 8/18/24*** LRS PERFORMED PASSING MIT- IA TO 2,500 PSI (see LRS WSR) PULLED 4-1/2" RHC FROM 8,927' MD RAN 10' X 2-1/4" P.BAILER W/MSFB MULTIPLE RUNS STARTING @ 9,823' SLM RAN 10' X 2-1/2" P.BAILER W/MSFB MADE MULTIPLE RUNS TO 9,959' SLM (10.5 GAL. fine solids) RAN 2.73" GAUGE RING, S/D @ 9,958' SLM ***CONTINUE ON 8/20/24*** 8/20/2024 ***CONTINUE FROM 8/19/24*** BAIL FILL DWN TO 9,978' SLM MADE MULTIPLE RUNS W 2.5" P.BAILER w/MSFB RAN 2.73" G-RING DWN TO 9,978'SLM RAN NORTHERN SOLUTION DUMMY WHIPSTOCK DRIFT, DWN TO 9520'SLM,(S/D 9502'SLM worked to 9520'SLM) RAN KJ, 3' X 1-7/8" STEM, 2' X 1-7/8" STEM, 2.75" G-RING DOWN TO 9,975' SLM RAN 2-1/2" P. BAILER W/MSFB S/D @ 9,975' SLM (VERY LITTLE RECOVERY) RAN KJ, 3-1/2" BLB, 2.75" GAUGE RING S/D @ 9,974' SLM (BRUSH FALLING FREELY) RAN 2-1/2" P. BAILER W/MSFB, S/D @ 9,975' SLM (GOOD METAL MARKS, NO RECOVERY) ***CONTINUE 8/21/24*** 8/21/2024 ***CONTINUE FROM 8/20/24*** ATTEMPTED NORTHERN SOLUTIONS DUMMY WHIPSTOCK UNABLE TO PASS 9520'SLM (S/D 9520'SLM worked to 9,585'SLM /~9591' MD) ***WELL LEFT S/I*** 8/21/2024 PROGRAM REVISION : Coil to mill restrictions & dry tag CIBP. SL drift with WS assembly. 8/22/2024 LRS CTU 2, 2.0" Blue Coil. Job Objective: Mill and Drift for WS. MIRU. BOPs function tested upon installation. Make up and RIH with 2.75" round nose mill and diamond string reamer. Dry tagged CIBP at 9975' E/ 9997' M. PUH to TOL 9450' and begin reciprocating motor/mill with gel sweep. Made several passes 9,450' - 9,550' and run down to 9,970' no issues. Mill/Ream up to TOL @ 10 fpm. Pooh w/BHA. M/U and RIH w/NS 2.74" x 11.82' Dummy Whipstock. Tagged CIBP at 9,975' cmt ,no issues. Made multiple passes w/WS from 9,450' - 9800' no issues. POOH w/BHA.. ***Job in Progress*** 8/23/2024 LRS CTU 2, 2.0" Blue Coil. Job Objective: Mill and Drift for WS. POOH w/BHA. FP tubing w/diesel from 2500' to surface. POOH pumping diesel PD. RDMO LRS CTU #2. ***Job Complete*** PULLED 4-1/2" RHC FROM 8,927' MD LRS PERFORMED PASSING MIT- IA TO 2,500 PSI Daily Report of Well Operations PBU 06-18A 8/23/2024 ***WELL S/I ON ARRIVAL*** RAN 2.74 NORTHERN S, DMYWS DRIFT TO 9918' SLM / 9927' MD RAN 2.79 GRING TO 3-1/2" X 3-3/16" XO @ 9481' MD ( 9472' SLM ) ** 9' CORRECTION ** *** WELL S/I ON DEPARTURE *** 8/27/2024 PROGRAM REVISION : Pre-CTD work is complete. Cancelled Eline setting whipstock since Slickline not able to drift to target depth with high doglegs. Drilling Manager 08/09/24 Monty M Myers 324-461 By Grace Christianson at 11:02 am, Aug 09, 2024 DSR-8/12/24WCB 8-21-2024 SFD 8/9/2024 SFD Variance to 20 AAC 25.112(I). Approved for alternate plug placement with fully cemented liner on upcoming sidetrack. BOPE test to 3500 psi. 12,145' *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.21 15:20:10 -08'00'08/21/24 10-407 RBDMS JSB 083024 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: August 9, 2024 Re: PBU 06-18A Sundry Request Sundry approval is requested to prepare 06-18A for a CTD sidetrack. Proposed plan for 06-18B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, E-line will set a 3-1/4" whipstock, and coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 3-1/4" whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and drill an S-shaped well through Zones 3 and 4 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing perforations via cement squeeze, liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work - (Estimated to start in August 23rd 2024): Pre-Rig Work 1SLDummy WS drift to ~10,000 MD 2ELSet 3-1/4" Monobore packer whipstock at 9,961' MD 0 deg ROHS 3CTMill 2.74” Window with CT unit (if unit is available) 4 Valve Shop Pre-CTD tree work (install sarber spool, PT swab, leak-tight master) 5Valve ShopBleed wellhead pressures down to zero. 6Valve ShopBleed production, flow and GL lines down to zero and blind flange. 7 Operations Remove wellhouse and level pad. Rig Work 1 MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,414 psi). 2 Mill 2.74” Window. (If not done pre-rig) 3 Drill build section: 3.25" OH, ~495' (25 deg DLS planned). 4 Drill production lateral: 3.25" OH, ~1859' (12 deg DLS planned). 5 Run 2-3/8” 13Cr liner 6 Pump primary cement job: 19 bbls, 15.3 ppg Class G, TOC at TOL*. 7 Freeze protect well to a min 2,200' TVD. 8 Close in tree, RDMO. Post-Rig Work 1 Valve Shop Valve & tree work pyppg(pg This completion will completely isolate and abandon the parent Ivishak perfs. 2 Slickline Set LTP* (if necessary). Set live GLVs. 3 Service Coil Post rig perforate (~30’) and RPM. * Approved alternate plug placement per 20 AAC 25.112(i) The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Hole Size: The window and 10’ of formation will be milled/drilled with a 2.74” OD mill. Well Control: BOP diagram is attached. AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: DS-06 is a H2S pad. H2S reading on 06-18A: 5 ppm on 5/21/2022. Max H2S recorded on DS-06: 395 ppm. No expected fault crossings. Low lost circulation risk. Reservoir Pressure: The reservoir pressure is expected to be 3294 psi at 8800’ TVDSS (7.2 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2414 psi. A min EMW of 8.4 ppg for this well will be 561 psi over-balance to the reservoir. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka 907-244-4357 DS-06 is a H2S pad. Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip This RWO PC leak repair was already completed. It is detailed on Sundry 324-337. -WCB 3-1/4" Whipstock - 9961 2-3/8" 13CR HYD511 - 12314 3.70" DPLY Sleeve - 9425 B This RWO PC leak repair was already completed. It is detailed on Sundry 324-337. -WCB Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer SFD 8/9/2024 324-461209-063 PBU 06-18A SFD 8/9/2024 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 06-18A Install Tie-back Liner & New Completion Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-063 50-029-20767-01-00 ADL 0028311 , 0028329 14003 Surface Intermediate Liner Liner Liner 8680 2475 9773 870 2696 1918 13972 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 8679 37 - 2512 35 - 9808 8998 - 9868 9449 - 12145 12085 - 14003 2499 37 - 2512 35 - 8565 7866 - 8618 8252 - 8671 8665 - 8680 none 2670 4760 5410 10530 9459 5380 6870 7240 10160 9997 - 13971 4-1/2" 12.6# 13Cr80 33 - 95148706 - 8679 Conductor 82 20" 38 - 120 38 - 120 1490 470 4-1/2" Baker S-3 Perm No SSSV 9449 8260 Date: Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY 7/1/2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov / By Grace Christianson at 4:01 pm, Jun 07, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.06.07 14:02:29 - 08'00' Eric Dickerman (4002) DSR-6/7/24SFD 6/10/2024MGR11JUN24 2499 * Initial BOPE test to 5000 psi. 13-5/8" BOPE and 7-1/16" BOPE and associated coiled tubing valves to be tested as will be assembled in BOPE stack. Annular to 2500 psi. * Subsequent weekly BOPE tests require 13-5/8" BOPE to be flanged to 7-1/16" BOPE and tested to 3000 psi (Annular to 2500 psi). Coiled tubing valves to be tested weekly. 14,000* SFD 14,000* SFD *Per Well Completion Report of 11/17/09 SFD 10-404 *&:JLC 6/14/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.14 09:45:13 -08'00'06/14/24 RBDMS JSB 061424 RWO 06-18A PTD:2090630 Well Name:06-18A API Number:500292076701 Current Status:Shut-In for PC leak Rig:CDR-2 Estimated Start Date:07/01/24 Estimated Duration:14 days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:2090630 First Call Engineer:Jerry Lau 907-564-5280 907-360-6233 Second Call Engineer:Dave Bjork 907-564-4672 907-440-0331 AFE Number:231-00101 IOR PRE CTD: 675 Current Bottom Hole Pressure:3,300 psi @ 8,800’ TVD 7.4 PPGE | DS06 Average BHP since 2020 Max. Anticipated Surface Pressure:2,499 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2,350 psi (Taken on 8/19/23) Min ID:2.786” ID XO @ 9,481’ MD Max Angle:99 Deg @ 10,095’ Brief Well Summary: 06-18 was drilled in August 1982. It was CTD sidetracked and completed with 2-3/8” slotted liner across the Sag in 2009. Sag perfs reached marginal GOR in early 2023 then Z4 Rich Gas perfs were added, but GOR remained above marginal. While screening the well for a GDWFI CTD ST, a failed CMIT-TxIA and subsequent acoustic LDL identified PC leaks at 4761’ and 8252’ with an overall LLR of 0.5 gpm. Objective: Pull the existing 4-½” 13Cr tubing out of the well. Repair the PC leak by installing a fully cemented 7” tieback. Run new 4-½” 13Cr stacker packer completion. Achieve a passing MIT-IA & MIT-T. Pre RWO work: SL- Set plug in X Nip @ 9459’(Done 10/11/21) Dummy off mandrels (Done 8/20/23) MIT-T to 2,500-psi (Done 8/23/23) Pull 3-1/2” PX Plug from X Nip @ 9459’ DHD – MIT-OA to 500 psi Cycle LDS’s PPPOT-T to 5000 psi EL – Load and Test – Load TBGw/ 1% KCL/SW and crude FP, Set CIBP @ 9,990’, MIT-T to 1000 psi Cut tubing @ 9,399’. 2’ below top collar of 1 st full joint above packer. SL – Pull lower station Circulate well – Lead with soap, place 9.8 ppg brine w/ Safelube in T x IA DHD – Bleed WHP’s to 0 psi Valve Shop Set and test 4-1/16” ISA BPV with blanking plug (209-063) SFD RWO 06-18A PTD:2090630 Proposed RWO Procedure: 1. MIRU CDR #2 Rig. a. Rig up 2” line from the OA valve to the flowback tank. In preparation for the wellhead change out, the OA should be monitored to confirm no-flow / zero pressure and static fluid level for a minimum of three times (3x) the expected time to perform the wellhead work. b. The well is secured with a plug @ 9,990’ c. Well is circulated with 9.8 ppg brine with Safelube. d. Tubing is mechanical cut at 9,399’ e. XO needed for TIW valve to New Vam threads. 2. ND Tree and tubing head adapter. Inspect lift threads. Vague records indicate 5-3/4” LH ACME. Plan for spear if thread type cannot be determined. 3. NU BOPE configured top down: Annular, 2-7/8” x 5” VBRs, Blinds and flow cross, 13-5/8” spacer spool a. Only include spacer spool, if necessary, to keep top of ISA blanking plug beneath flow cross 4. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per CDR #2 BOP test procedure. B. If the BOPE test is the initial rig acceptance test for the stack, then increase the high pressure test to 5000 psi for the shell test. Sebsequent tests will be performed at the standard high pressure of 3000 psi. C. Notify AOGCC 24 hrs in advance of BOP test. D. Confirm test pressures per the Sundry Conditions of approval. E. Test the 2-7/8” x 5” VBR’s with 4-½” and 4” test joints. Test the Annular preventer with a 4” test joint. F. Stump test service coil auxiliary stack to 3000 psi. G. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Pull ISA blanking plug then BPV. No TRSSSV / Control Line(s) / Bands / Clamps 6. Use 9.8 ppg brine with Safelube. Verify hole is staying full and establish loss rate as necessary. Continuously fill across the top. Losses are expected to be minimal – LLR of PC leak was 0.5 gpm with 2500 psi on IA. 7. MU landing joint or spear, BOLDS and pull FMC hanger to the floor. PU weights are expected to be ~105K. Max pull is 273K (80% of the 4-1/2”). a. Pull 4 1/2” tubing to floor, circulate bottoms up. Lay down 4-1/2” 13Cr New VAM tubing string. Number all joints. b. The pipe will not be salvaged. c. Thread protectors are not required. d. Drift completion overshot with cut end. 8. N/U service coil auxiliary stack and service test flange break. 9. Set 7” RBP at ~ 9,030’. Test RBP to 500 psi. Spot ~10ft of 20/40 river sand. 10. RIH w/ Baker polish mill dress-off assembly into the liner top receptacle at 8,998’. 11. N/D service coil auxiliary stack. 12. Set a test plug and swap the VBR’s to 7” fixed rams and test to 3,000-psi with 7” test joint. Pull test plug. 13.Run 7” Tieback assembly: Ported tieback seals, insert orifice float, insert landing collar, 7” 29# L-80 CSG, one 8-1/4” centralizer per every other joint. Lubricate BPV if pressure below. -mgr Include 7-1/16" BOPE and coiled tubing valves. -mgr Stump testing not approved for rig work. - mgr Test pipe slip rams and coil valves with coil tubing equipment. Nipple down service coil BOPE. - mgr RWO 06-18A PTD:2090630 14.Space out with seal stem ports exposed and pump 5bbls FW, 5 bbls mudpush, 255 bbls 15.3 ppg ‘G’, drop LWP and displace with 9.8 ppg brine. Bump plug with 500 psi. bleed off 7” CSG pressure while slacking off to bury the seals. 15. Set casing slips. ND the BOP stack from the tubing spool and install the IC packoff and new tubing spool. Test the IC packoff to 3,500-psi. 16. NU BOP on the new tubing spool. Install a test plug in new tubing hanger profile. Test the spool break to 3,000-psi. Swap the 7” fixed rams to 2-7/8” x 5” VBR’s and test to 3,000-psi. with 4” x 4-1/2” test joints. 17. N/U service coil auxiliary stack and service test flange break. 18. RIH W/ drillout BHA. 6.00” rock bit. Drill up shoe tract. POOH. ID of CSG is 6.125” 19. RIH W/ FCO BHA and clean up any debris. 20. Pull RBP, POOH. Test casing to 3,000-psi. 21. N/D service coil auxiliary stack. 22. Run 4 ½” 13Cr tubing with stacker packer gas lifted completion as detailed on proposed schematic. 23. Land Hanger and reverse in corrosion inhibited 8.5ppg 1%KCl 24. Drop ball and rod and set packer with 3,500psi pump pressure. 25. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes 26. Shear valve in upper GLM. 27. Set TWC 28. Rig down CDR #2. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. 5. Top off OA with cement. Post rig Slickline Work 1. Pull Ball and rod and RHC plug body. Bail down to top of CIBP @ 9,990’ 2. RDMO Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. Proposed BOP Configurations 4. Sundry Revision Change Form Service coil. - mgr Service coil. - mgr 30 minute flow check before breaking stack. - mgr With service coil. - mgr RWO 06-18A PTD:2090630 Wellbore Schematic RWO 06-18A PTD:2090630 Proposed Wellbore Schematic RWO 06-18A PTD:2090630 Proposed RWO BOP Configuration – Coiled Tubing Ops RWO 06-18A PTD:2090630 Proposed RWO BOP Configuration – Standard Ops RWO 06-18A PTD:2090630 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date By Grace Christianson at 8:24 am, Aug 04, 2023 323-440 Drilling Manager 08/03/23 Monty M Myers BOPE test to 3500 psi. Variance to 20 AAC 25.112(i) Alternate plug placement approved with fully cemented production liner in upcoming CT in-zone sidetrack. MGR04AUG23 10-407 SFD 8/9/2023 DSR-8/7/23GCW 08/09/2023JLC 8/9/2023 08/09/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.09 15:43:26 -08'00' RBDMS JSB 081123 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: August 2, 2023 Re: PBU 06-18A Sundry Request Sundry approval is requested to prepare 06-18A for a CTD sidetrack. Proposed plan for 06-18B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, E-line will set a 3-1/4" whipstock, and coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 3-1/4" whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and drill an S- shaped well through Zones 3 and 4 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing perforations via cement squeeze, liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work - (Estimated to start in August 2023): Pre-Rig Work 1SLDummy WS drift to ~10,000 MD, Set Dummy GLVs, MIT-IA to 2500 psi 2ELSet 3-1/4" Monobore packer whipstock at 9,961' MD 0 deg ROHS 3CTMill Window with rig (if unit is available) 4Valve ShopPre-CTD tree work (install sarber spool, PT swab, leak-tight master) 5Valve ShopBleed wellhead pressures down to zero. 6Valve ShopBleed production, flow and GL lines down to zero and blind flange. 7 Opearations Remove wellhouse and level pad. Rig Work 1 MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,414 psi). 2 Mill 2.74” Window. (If not done pre-rig) 3 Drill build section: 3.25" OH, ~495' (25 deg DLS planned). 4 Drill production lateral: 3.25" OH, ~1859' (12 deg DLS planned). 5 Run 2-3/8” 13Cr liner 6 Pump primary cement job: 19 bbls, 15.3 ppg Class G, TOC at TOL*. 7 Freeze protect well to a min 2,200' TVD. 8 Close in tree, RDMO. Post-Rig Work 1 Valve Shop Valve & tree work Sundry 323.-440 PTD 2 Slickline Set LTP* (if necessary). Set live GLVs. 3 Service Coil Post rig perforate (~30’) and RPM. * Approved alternate plug placement per 20 AAC 25.112(i) The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 2.74” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x DS-06 is not an H2S pad. H2S reading on 06-18A: 5 ppm on 5/21/2022. x Max H2S recorded on DS-06: 75 ppm. x No expected fault crossings. x Low lost circulation risk. Reservoir Pressure: x The reservoir pressure is expected to be 3294 psi at 8800’ TVDSS (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2414 psi. x A min EMW of 8.4 ppg for this well will be 561 psi over-balance to the reservoir. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka 907-244-4357 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-18A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-063 50-029-20767-01-00 14000 Surface Intermediate Liner Liner Liner 8680 2475 9773 870 2696 1918 13972 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 8679 37 - 2512 35 - 9808 8998 - 9868 9449 - 12145 12085 - 14003 37 - 2512 35 - 8565 7866 - 8618 8252 - 8671 8665 - 8680 none 2670 4760 5410 10530 none 5380 6870 7240 10160 9997 - 13971 4-1/2" 12.6# 13Cr80 33 - 9514 8706 - 8679 Conductor 82 20" 38 - 120 38 - 120 1490 470 4-1/2" Baker S-3 Perm , 9449 , 8260 No SSSV 9449 8260 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907-564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) 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.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028311 , 0028329 33 - 8308 105 383 9260 36351 22 24 1129 1297 338 915 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Meredith Guhl at 7:44 am, Feb 21, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.17 12:18:56 -09'00' DSR-2/22/23 Sundry Number N/A Perforate WCB 11-24-2023 PBU 06-18A PRUDHOE BAY, PRUDHOE OIL 209-063 RBDMS JSB 022123 ACTIVITYDATE SUMMARY 1/27/2023 ***WELL SHUT IN ON ARRIVAL*** PRESSURE TEST PCE 200#LP-3,000#HP RIH W/ 1 7/16" CHD (1" FN), 2" WEIGHT, 1 11/16" WEIGHT, 1 11/16" GR/CCL, 2" PERF GUN (20' LOADED W/ 6.5 GRAM RAZOR CHARGES) CCL OFFSET=7.5', PERF DEPTH=9,997'-10,017', CCL STOP DEPTH=9,989.5' JOB CONTINUED ON 1/28/2023 1/27/2023 T/I/O= 2250/75/150 TEMP= SI (PERFORATING) Pumped 5 bbls 60/40 followed by 200 bbls crude down Tbg for load. ***Job cont to 01-28-23 WSR*** 1/27/2023 ***WELL FLOWING UPON ARRIVAL*** (perforating) DRIFTED TO DEVIATION W/ 22' x 2" DUMMY GUNS (2.28" max od), 1.75" SAMPLE BAILER @ 10,035' SLM (no sample) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 1/27/2023 Freeze Protect FL. (Assist E-line, perfs) Rig up and PT. Released from job. 1/28/2023 JOB CONTINUED FROM 1/27/2023 CONFIRMED GUNS FIRED WELL & FLOW LINE FREEZE PROTECTED ALL TREE VALVES RETURNED TO NORMAL POSITION (SWAB/SSV/MASTER=C/C/O) ***WELL LEFT SHUT IN*** 1/28/2023 ***Job cont from 01-27-23 WSR*** Pumped 3 bbls 60/40 followed by 130 bbls crude down FL for FP. DSO notified of well status Eline incontrol of well status upon departure. CV's= OTG FWHP's= 0/75/150 Daily Report of Well Operations PBU 06-18A The correct perf depths are shown on the new WBS, below. -WCB RIH W/ 1 7/16" CHD (1" FN), 2" WEIGHT, 1 11/16" WEIGHT, 1 11/16" GR/CCL, 2"() PERF GUN (20' LOADED W/ 6.5 GRAM RAZOR CHARGES) PERF DEPTH=9,997'-10,017', (g) DRIFTED TO DEVIATION W/ 22' x 2" DUMMY GUNS (2.28" max od), 1.75" SAMPLE BAILER @ 10,035' SLM (no sample) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS n 1N t h anlq 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operatio ul CC ❑ Suspend ❑ Perforate Other Stimulate ❑ Alter Casing ❑ Change poroved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well 11 Re-enter Susp Well ❑ Other: Wellwork Platform 0 2. Operator Name: BP Exploration (Alaska), Inc 14, Well Class Before Work 5. Permit to Drill Number 209-063 3. Address: P.O. Box 196612 Anchorage, Development ® Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number. 50-029-20767-01-00 7. Property Designation (Lease Number): ADL 028311 8 028329 8. Well Name and Number: PBU 06-18A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Size: MD: TVD: Burst: Collapse: Total Depth: measured 14000 feet Plugs measured feet Surface true vertical 8680 feet Junk measured feet Effective Depth: measured 13972 feet Packer measured 9459 feet Liner true vertical 8679 feet Packer true vertical 8260 feet Liner 2696 Casing: Length. Size: MD: TVD: Burst: Collapse: Conductor 82 20" 38-120 38-120 1490 470 Surface 2475 13-3/8" 37-2512 37-2512 5380 2670 Intermediate 9773 9-5/8" 35-9808 35-8565 6870 / 8150 4760/5080 Liner 870 7" 8998-9868 7866-8618 7240 / 8160 5410/7020 Liner 2696 3-112" x 33/18" 9449-12145 8252-8671 Liner 1918 2-3/8" 12085 - 14003 8665-8680 Perforation Depth: Measured depth'. 11384 - 13971 feet True vertical depth: 8644-8679 feet Tubing (size, grace, measured and true vertical depth) 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'. 4-1/2" 12.6# 13Cr80 33-9514 33-8308 412' Baker S-3 Penn Packer 9459 8260 no SSSV 10, Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation. 191 9021 17 1788 277 Subsequent to operation: 370 7224 84 781 399 14.Attachments: (e4uked PW 20 MC 25.070,25071,a 26210) 15. Well Class after work: Daily Report of Well Operations E1 Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil m Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-079 Authorized Name: Ryan Thompson Contact Name: Ryan Thompson Authorized Title. Interventions Engineer Contact Email: Ryan.ThompsonAbp.com Authorized Signature: 6� /(/�— Date: 1//'f // I Contact Phone: +1 907 564 4535 Form 10-404 Revised 04/2017 �li -3BDMSL- / JUN 18 7019 Submit Original Only ****WELL S/I UPON ARRIVAL**** (Wellwork platform) DRIFTED W/ 30'x 2" DUMMY PERF GUNS (2.29" rings) , S/D @ 10,009' SLM (No issues, 38* DU -72* Dev) 5/3/2019 ****CONT JOB 5/4/19**** ****CONT. JOB FROM 5/3/19**** (Wellwork platform) RAN SBHPS W/ BP GAUGES PER PROGRAM (Good data) RAN PDS 24 ARM CALIPER LOG FROM 9,500' SLM TO SURFACE (Good data) 5/4/2019 ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** T/1/0=1000/700/400 Temp=Sl (LRS Unit 72 - Load Tubing & IA Pre WellWork Platform) Load IA w/ 5 bbls 60/40 meth and 390 bbls crude. Load Tubing w/ 5 bbls 60/40 meth and 250 bbls crude. MV open. SV, WV, SSV closed. IA/OA OTG. Tag and AFE sign hung, DSO notified of well status upon departure. 5/5/2019 Final T/I/0= 0/0/350. T/I/0= 0/50/250 PRE WELLWORK PLATFORM. Pulled OA Blind & verrified VR plug in OA Comp. Intalled OA Comp blind and torqued to 413 ft lbs. R/D IA Comp blind & R/U VR Lbricator. PT'd VR lubricator low 300psi, Hight 3500 psi. Set 3" VR plug in IA Comp. R/D IA Comp 3" FMC 120 & install tapped blind. Torqued IA Comp tapped blind to 413 ft lbs. R/U CIW lubricator #840 w/ 4" H plug and tool. PT'd Lubricator low 300psi, High 3500psi. Attempted to set 4" H TWC. Could not get plug engagement, (on hold waiting on further instrucctions). PT'd IA & OA Comp. against VR plugs 5/7/2019 Low 300psi, High 3500psi. ***Job In Progress*** Contiued on 5/8/2019. ***Continued from 5/7/2019*** PRE WELLWORK PLATFORM. Broke off CIW lubricator & C/O 4" H plug & tool w/ 4" ISA plug & tool. PT'd lubricator using quick test port to 3500psi. Set 4" ISA # 545 @ 120" bottom of window. R/D CIW lubricator. R/D 4" CIW SV & intalled tree cap assembely on FC. Torqued tree cap x FC to 573 ft lbs. PT'd treecap to 4250psi. R/D SV platform. RDMO ***Job 5/8/2019 Complete*** FWHP=0/50/250 T/I/O=BPV/100/250. Klondike -1 Pulled 4" ISA #545 @ 105". PT tree cap to 500psi for 5min. Passed. 5/20/2019 Job Complete. See log. Final WHP's Vac/100/250. CTU 91WWP 1.75" CT Job Objective: Adperf MIRU. 5/23/2019 ***Job Continued on 5/24/19*** CTU 9/WWP 1.75" CT Job Objective: Adperf Rig up completed. Perform state witnessed BOP test 5/24/2019 ***Job Continued on 5/25/19*** CTU 9/WWP 1.75" CT Job Objective: Adperf Perform state witnessed BOP test. RIH with 2.5" DJN and 2.2" GR/CCL carrier. Bullhead 180bbl of safelube. Tagged 2-3/8" deployment sleeve at 12097CTM. Flag pipe at 11350. POOH. 5/25/2019 ***Job Continued 5/26/19*** CTU 9/WWP 1.75" CT lJ Job Objective: Adperf Continue out of hole with logging carrier. Good to data shows a corrected EOP at flag = 11329.25 and a tag on the deployment sleeve = 12088.3 . Perform D1 drills. MU & RIH with HES 2" x 616' MaxForce gun. Tag & correct depth off and erforate interval 11,384'- 12,000'. POOH. Bullhead well with 250bbl of 1 % KCI. Retrieve/lay down guns. Bullhead 38bbl of 50/50 for freeze protect. Begin rig down from klondike and prep for BOP test. 5/26/2019 ***Job Continued on 5/27/19*** Daily Report of Well Operations 06-18A CTU 9/WWP 1.75" CT Job Objective: Adperf Continue rig down from klondike and prep for BOP test. 5/27/2019 ***Job Complete*** T/1/0=0/0/200. Pre tree replacement, Set 4" FMC ISA BPV #545 @100", BPV LTT (PASSED) PT'd 6/2/2019 Tree cap to 500 psi. PASSED). ***JOB COMPLETE**`. See log for details. Final WHP's BPV/0/200. T/I/O=BPV/100/200. Upper Tree Replacement, Replace 4" CIW Upper Tree with 4" CIW Upper Tree Tag #106. Torqued to API specs. 886 FT/LBS. MV x SSV and WV x Flow line. ***JOB 6/3/2019 INCOMPLETE*** Turned over to night shift. See log for details. Final WHP's BPV/100/200. T/I/O=BPV/0/200 PULL BPV R/U CIW lubricator w/4" ISA pulling tool. PT'd Lubricator Low 300psi, High 3500 psi. Pulled 4" ISA #545 @ 120". R/D CIW lubricator & installed tree cap &PT'd to 500 6/4/2019 psi. ***Job Complete*** FWHP= 100/0/200 T/1/0=0/100/250. Install companion IA. Install 3 1/8" FMC companion IA, PT'd 300 psi. low and 3500 psi high. (PASSED) Pull 3" FMC VR plug. PT'd IA tapped blind flange to 2500 psi. (PASSED). 6/5/2019 ***JOB COMPLETE*** See log for details. Final WHP's 0/100/250. LRS Test Unit 1, Begin on WSR 6/7119. DS6-18, DS6-19 Flow backand test pos add pert. Unit 6/7/2019 move,RU,PT, RDMO Current Barriers: IL SSV,SWAB, OL SSV and SWAB Continue on WSR 6/7/19 LRS Test Unit 1, Continue from WSR 6/8/19. DS6-18, DS6-19 Flow backand test pos add pert. , SB for DSO, Pop and flow. Current Barriers: ILHardline and Vessel, OL SSV and OSDV Continue on 6/9/2019 WSR 6/10/19 TREE= CNV WELLHEAD = FMC ACTUATOR= BAKERb OKB. ELEV = 74' REF ELLV= 74' OF. BEV = 38.99 KOP=_ 2500' Max Angle= 99" @ 10095' Datum MD= NA Datum ND= 88001SS SAFETY NOTES `.` 4-1/2" CHROME TBG & NIPS 06-18A IN ELL ANGLE >70'@10011' 2033' —4-1/2' HES X NP, D = 3.813" GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH P02T DATE / DATE REV BY COMMENTS 08130/82 ORIGINALCOMPLENON 05/28/19 MR/JMD ADPEWS(0526/19) 1 3776 3712 30 MMGM DOME RK 16 10/29/09 13-3/8" CSG, 72#, L-80, D = 12.347" — 2512' 02/19/19 JNIJJMD ADDED REF & BF ELEV 2 6068 5612 39 MMGM SO RK 20 10/29/09 3 7648 6784 41 MMGM DMY RK 0 05/26/99 4 8426 7394 36 MMGM DMY RK 0 02113/06 "5 8916 7797 33 MMGM DMY RK 0 0526/99 -ATTEMPT TO PULL #512M 1/05 - FISHING NECK STRIPPED TOP OF 7" LNR - SCAB — 8998' Minimum ID =1.92" @ 12085' 2318" DEPLOYMENT SLV 3-1/2" LNR, 9.2#, L-80 STL, .0087 bpf, D = 2.992" — 9481' TOPOF 7" LNR — 9497' 4-12" TBG, 12.6#, 13CR-80, .0152 bpf, ID= 3.958" — 9504' 7' SCAB LNR, 26#, L-80, .0383 bpf, ID = 6.276" — 9508' 9-5/8" CSG, 47#, L-80 S00-95, ID = 8.681" — 9808' 4-12' X 7- GEN A WHIPSTOCK (07105/09) — 9860' 7- LNR, 29#, L-80, .0371 bpf, D = 6.184" — 10640- 3-3/16- LNR, 6.2#, L-80 TC11, .0076 bpf, ID = 2.80" — 12145' PERFORATION SUMMARY REF LOG: ??? ANGLE AT TOP FERE: 89" @ 11384' Note: Infer to Production DB for historical perf data '' w -"wo uwmnu 12263 - 13971 SLOT 10/10/09 8998' — 7" TIE BACK SEALS STUNG INTO 7" LNR 9449' —7"X 4-1 /2" BKR S-3 PKR, ID = 3.875- 9449' —3.70" DEPLOYMENT SLV, D=3.00" 9459' — 3-12" HES X NP, D = 2.813 9481' — 3-112"X 3-3/16' XO, D = 2.786" 4-12" HES X NP, Io -3.813 BEHIND CT LNt 9504' 4-12" WLEG, D=3.951 BEHIND CT LNR — ELMD TT NOT LOGGED MILLOUT WINDOW (06-18A) 9868'- 9875' 12085' —2-318" DEPLOYMENT SLV, ID=1.92" 12145' H3-3/16'LN2SH0E TOP OF SLID LNR PBTD — 13971' 2-3/8' LNR, 4.4#, L-80 STL, .0039 bpf, ID =1.992" — 14...,". DATE REV BY COMMENTS DATE REV BY COMMENTS 08130/82 ORIGINALCOMPLENON 05/28/19 MR/JMD ADPEWS(0526/19) 05/26/99 LAST WOIMOVER 1025f09 NORDIC 1 CTD SIDETRACK (06-1 BA) 1028/09 MWJMD DRLGDRAFTCORRECTIONS 11/06/09 BSE/SV GLV CIO (1029/09) 02/19/19 JNIJJMD ADDED REF & BF ELEV PRUDHOE BAY UNIT WELL: 06-18A PERMIT No: F2090630 AR No: 50-029-20767-01-00 T10N. R14E114' FSL & 885' FEL BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Ryan Thompson Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 06-18A Permit to Drill Number: 209-063 Sundry Number: 319-079 Dear Mr. Thompson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogc c.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 2sday of February, 2019. RBDMS5&FEB 2 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 ti ti Form 10-403 Revised 04/2017 ORIGINAL RBDMS�EB z s 2019 ,,�.../// *�8/? Submit Form and Approved application is valid for 12 months from the date of approval. /2��q Attach in Duplicate 1. Type of Request Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations Shutdown D Suspend El Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other WellWork Platform 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ® - 5. Permit to Drill Number 209-063 1 Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ Service ❑ 6. API Number: 50-029-20767-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? B. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 06-18A 9. Property Designation (Lease Number): 10. Field/Pools ADL 028311 6 028329 PRUDHOE BAY. PRUDHOE OIL PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (ps0: Plugs (MD): Junk (MD): 14000 8680 13972 8679 2520 None None Casing Length Size MD TVO Burst Collapse Conductor 82 20" 38-120 38-120 1490 470 Surface 2475 13-3/8" 37-2512 37-2512 5380 2670 Intermediate 9773 9-5/8" 35-9808 35-0 ... ------ I 4760 / 5080 Liner 870 7" 8998-9 68 7866-8518 7240 / 8160 5410 / 7020 Liner 2696 3-1/2" x 3-3/16" 9449-12145 1 8252-8671 Liner 1918 2-3/8" 12085 - 14003 8665-8680 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12145 - 13971 8871 - 6679 4-1/2" 12.6# 1 13Cr80 33-9514 Packers and SSSV Type: 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 9459/8260 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: April 1, 2019 15. Well Status after proposed work: Oil 0- WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative. GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name. Thompson, Ryan be deviated from without prior written approval. Contact Email: RYAN.THOMPSONQbp.enm Authorized Name: Thompson, Ryan Contact Phone: +1 907 564 4535 Authorized Title: Interventions En Authorized Signature: �' Date: Z I I I/ I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: G �\ /a Plug I 1 V l V' Integrity 11E BOP Test R MechanicalIntegrityTest ❑ Location Clearance ❑ n Other: 90P / a i TD -' � Z ZO /"lIS / Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Re wired? Yes ❑ No Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION -fL S Date.> I I ti ti Form 10-403 Revised 04/2017 ORIGINAL RBDMS�EB z s 2019 ,,�.../// *�8/? Submit Form and Approved application is valid for 12 months from the date of approval. /2��q Attach in Duplicate 41, Jyp"44k Sundry Request to Perforate Utilizing The Well Work Platform Well: 06-18A Date: 2/13/19 Engineers: Prachi Vohra: 907-564-4677 Ryan Thompson: 907-564-4535 MASP: 1805 Well Type: Producer Estimated Start date: April 1, 2019 History: 06-18A was CTD sidetracked in October 2009 with 1708' of slotted liner ran as part the completion. Scope of Work: The objective of this intervention is to utilize Service Coil and the Well Work Platform to perforate a proposed additional 750' of perforations above the slotted liner. r Proposed WWP Produre: • MIRU WWP-OPE and support equipment • MIRU CTU • Test BOPE as configured top down (annular, blind shears, 1.75" pipe/slips, mud cross, empty cavity, 1.75" pipe/slips). Test the blind shears and pipe slips to 3500 psi and the annular to 2500 psi using 1.75" coil. ZS/�lxi r C 1�iG� ¢c C- • Perform drift run. • Kill well with 1 % KCL • Perforate the proposed interval below. Safetyjoint with FOSV will be on floor during gun deployment and laydown. 11,300'- 12,050' MD • RDMO WWP and Coil Unit 'T �V G!i � � W Pte`/ (N 0/K �laY�7"r/'�'✓2 V�LFEAD= FMC ACTUATOR= BAKE RC OKB. ELEV_=_74' DONE REF ELEV = 74' BF. ELEV = 38.99' KOP= 2500' Max Angle = 99' @ 10099 Datum MD= NA Dahun TVD= 8800'SS 13-3/8" CSG, 72#, L-80, D =12.347' H 261T TOP OF 7'LNR -SCAB I Minimum ID =1.92" @ 12085' 2-3/8" DEPLOYMENT SLV 13-12' LNR, 9.2#, L-80 STL, .0087 bpf, D = 2.992' -1 9481' TOP OF 7- LNR 9497' 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, D = 3.958' -1 9604' 7" SCAB LNR, 26#, L-80, .0383 bpf, D = 6.276" 9608' 9-5/8' CSG, 47#, L-80 S00-95, D = 8.681" -L_9808 I4-12" X7- GEN 1 WHPSTOCK (07/05/09) JJ 9860' 7' LNR, 29#, L-80, .0371 bpf, D = 6.184' -1 10640' 06-18A SAFELY NOTES"* 4-112" CHROME TBG & NPS'•` WELLANGLE>70' 10011' HES X GAS LFT MANDRELS 1 3776 3712 30 lVMGM DONE RK 16 10/29/09 2 6068 5612 39 MMGM SO RK 20 10/29/09 3 7648 6784 41 MMGM 0M1' RK 0 05/26/99 4 8426 7394 36 MMGM 0MY RK 0 02/13/06 "5 8916 7797 33 MdGM DW RK 0 05/26/99 "ATTEMPT TO POLL #512f11106 - RSNW NECKSTRIPP® 8998' -� 7" TIEBACK SEALS STUNG M0 7" LNR _944�1—I 7' X 4-12" BKR S-3 PKR D = 3.875' 9449' 3.70' DEPLOYMENT SLV, D = 3.00' 9469' 3-1/2' HES X NP, D=2.813 9481' — 3-1Y2- X 3-3/16' XO, D = 2.786" ® L2" FES X PP, D=3.813 IND CT LNR 13-3/16' LNR 6.2#, L-80 TCI, .0076 bpf, D = 2.80" -1 12145' PERFORATION SUMMARY REE LOG: ??? ANGLE AT TOP PERF: 92' @ 12263' Note: %far to Production DB for historical perf data SLTD 1 12263 - 13971 1 SLOT 4-1/2" VW EG, ID = 3.958" BEHIND CT LNR ELMD TT NOT LOGGED MLLOUT WINDOW (OB -18A) 9866 - 9875' 12-3/8' DEPLOYMENT SLV, D =1.92' 12145' 3-3/16" LNR SHOE MILL® OUT TO 2.74" 12263'TOPOFSLTD LNR 13971' BTM SLTD LNR PBTD -1 13971' 12-3/8" LNR 4.4#, L-80 STL, .0039 bpf, D = 1.992'14003' DATE I REV BY I CONVENTS 08/30182 ORIGINAL COMPLETION DATE I REV BY I COMMENTS 11/06/091 BSEISV GLVCO(10/29/09) 06126199 LAST WORKOV Ht 02/19/19 JNJJMO ADDED REF 8 BF ELEI/ 0726109 RRD'PJC SET WFPSTOCK (07/05(09) 0726/09 JVPJC FBA (07/16/09) 1026109 NORdC 1 CTD SIOLTRACK (06-18A) 1028/09 MWJMD ORLG DRAFT CORRECTIONS PRUDHOE BAY LM VVELL: 06-18A PERMITW: 2090630 AR No: 50-029-20767-01-00 SEC 2, TION, R14F;114' FSL &885' FEL BP Exploration (Alaska) Planned Wellbore Configuration Post Perforating ELLV - Rw= Minimum 1) =192" @ 12085' 2318" DEPLOYMENT SLV T 3.95B' FERFOPATDN SLR.I.MARY REFLOG: 77] ANGLEATTOPFERF 92' @" 17263 Nob: Refer ro Rd.Wf M far historical per! axa SIZE SPF R(IERVAL OPNSgz ENE SLID 12263-13971 SLDT 10110109 11300 - 12(150 PORT a NPS '^ 06-18A I WELLANGLE>70°@1Go11• ST MD I WDI DEV I TY FE VLV LATCII PORT DATE 1 3776 3]12 30 MMGAI DONE RK 16 14124109 2 6068 5612 m MGM SO RK 20 10+24109 3 7648 6784 41 MMGM DWY RK 0 1 0&24199 4 8426 7394 36 MMW DPOY RK 0 02113!06 5 891G 7797 33 MMGM PAY RK 0 46126/99 ���c"�� ��/�YLl i�1L/rl/W 11DI�Itt11C41x J11CYYtU HELMINOTLOGGED kLLODT WRADOW (08-1 GA) 98G8-9B]S AtlpertS `\1/ ILN DF arDI DATE FEV BY I COMMENTS I DATE REV BY COMMENTS 08ANB2 048GNAL COMPLERON 1VOG/09 BSE(SV GLVC,O(1029/09) MQN99 LAST WORKOVF 07/Zfi1m FF4)TJC SE WHIPSTOO( IO]A51m) iI W/2Nm JIPJC RSA(m/16109) 1025109 P91C 1 CTD SDETRACK(i618A) 10/20109 WWD DFIGDPAFTNR�7YJN5 Rd1P0E BAY LW WflJ.: OG -IRA FEFUT No: '25090630 API No: 50-029.20767.01-00 SIL 2. Tl OR R14 E 114' FSL 8 685 FEL OP Exploration (Alaska) it• P'atimm f mr Riser r YYe•am lka Anular Birdshev ifnYauY[311l A¢n3te.� VaW r fYiY Ca. F'peStp Cho* Lne c Fi Crf Errpq Cavry Co P�aS n 7x7SP asnee- e rim Cm55 Ssv Master Vaw THA Tub,rg Head Guard Lena DATA SUBMITTAL COMPLIANCE REPORT 8/30/2010 Permit to Drill 2090630 Well Name/No. PRUDHOE BAY UNIT 06-18A Operator BP EXPLORATION (ALASKA INC API No. 50-029-20767-01-00 MD 14000 TVD 8680 Completion Date 11!25/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION _ / Mud Log No Samples No Directional Survey Yes C/ DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, GR, CCL, CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / iyp mearrrmt rvum~er Name ~cmc mGU~a rvo mart atop ~.n rteceiveu ~.unnnenw og Neutron 25 Blu 9360 12027 Case 1/13/2010 MCNL, Lee, TNN, TNF, GR, CCL 12-Oct-2009 C Pds 19204 ~utron 9360 12027 Case 1/13/2010 MCNL, Lee, TNN, TNF, GR, CCL 12-Oct-2009 R LI~S~Verification 9275 13997 Open 1/26/2010 LIS Veri, GR, ROP ED C Lis 19236 Gamma Ray 9275 13997 Open 1/26/2010 LIS Veri, GR, ROP g Gamma Ray 25 Col 9668 14000 Open 1/26/2010 MD GR g Gamma Ray 5 Col 9668 14000 Open 1/26/2010 TVD GR g Gamma Ray 5 Col 9275 13997 Open 1/26/2010 Depth Shift Monitor Plot Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y /~T~ Analysis -aU-Ah Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~' N Formation Tops ~ N a DATA SUBMITTAL COMPLIANCE REPORT 8/30/2010 Permit to Drill 2090630 Well Name/No. PRUDHOE BAY UNIT 06-18A Operator BP EXPLORATION (ALASK/~ INC MD 14000 TVD 8680 Completion Date 11/25/2009 Completion Status 1-OIL Current Status 1-OIL Comments: API No. 50-029-20767-01-00 UIC N Compliance Reviewed By: C~'~_-- Date: ~y /~^, ~~~/ /~ • ~ ~ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 06-18A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - GR Directional TVD Log (to follow) LAC Job#: 2810460 ~ ~~ ,; , .., Sent by: Catri Guidry :~. ,..,_ Date: Ol/~9;~10 -- Received by: Date: - ' '? u PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 -' .~ -_~ BAKER 1RlGMES INTEQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ ~ ~/ ~~ BAKER N VGHES Barer Atlas PRINT DISTRIBUTION LIST CUMYAN Y BP EXPLUKA'I'lUN (ALASKA) INC WELL NAME 06-18A CUUN'IY NUK'1 H SLUYE BUKUUGH STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 1!19/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2810460 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 This Distribution List Completed By Page 1 of 1 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 06 Dear Mr. Maunder, • a,P~-b~o3 o~~l~A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus.. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-06 Date: 12/10/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 06-01 1750490 50029201720000 NA Sealed NA os-o2 1770780 50029202820000 NA Sealed NA 06-03A 1951520 50029201860100 NA Sealed NA 06-04A 2001020 50029201790100 NA Sealed NA 06-05 1780200 50029202980000 NA Sealed NA o6-o6B 2050980 50029202010200 NA Sealed NA 06-07 1780210 50029202990000 NA Sealed NA o6-o8A 1951950 50029203000100 NA Sealed NA O6-os 1790730 50029204000000 NA Sealed NA o6-10A 1981960 50029204020100 NA Sealed NA 06-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 06-13A 2061020 50029204570100 NA Sealed NA 06-14B 2090120 50029204580200 NA Sealed NA 06-15 1800320 50029204590000 NA Sealed NA 06-16 1800330 50029204600000 NA Sealed NA 06-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 9.80 10/4/2009 06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009 06-21 B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 os-22A 1930570 50029208060100 NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009 Os-24A 2000960 50029208220100 NA Sealed NA STATE OF ALASKA ~ ~~~~i /C~ ALASKA OIL AND GAS CONSERVATION COMMISSION V G WELL COMPLETION OR RECOMPLETION REPORT AND L~i~ ~ ~ 1 a. Well Status: ®Oil ^ Gas ^ SPLUG ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.~os zoAAC 2s.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions One 1 b. Well Clas : _ ~+,, ~ ~i ~it~6~IIdF9t ^ Service AO~~~igraphic 2. Operator Name: BP Exploration (Alaska) Inc. Date Com Susp., or Aband.: 10/25/2009 "~ 12. Permit to Drill Number: 209-063 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 10/4/2009 13. API Number: 50-029-20767-01-00 4a. Location of Well (Governmental Section): Surface: ' 7. Date T.D. Reached: 10/23/2009 14. Well Name and Number: PBU 06-18A FSL, 885 FEL, SEC. 02, T10N, R14E, UM 114 Top of Productive Horizon: 3604 FNL, 4156 FWL, SEC. 12, T10N, R14E, UM g. KB (tt above MSL): 74~ GL (ft above MSL): 15. Field !Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3788' FNL, 499' FWL, SEC. 07, T10N, R15E, UM 9. Plug Back Depth (MD+TVD): 13972' 8679' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 686109 y- 5940716 Zone- ASP4 10. Total Depth (MD+TVD): 14000' 8680' 16. Property Designation: ADL 028311 & 028329 TPI: x- 691243 y- 5937125 Zone- ASP4 Total Depth: x- 692870 Y- 5936982 Zone- ASP4 11. SSSV Depth (MD+TVD): None 17. Land Use Permit: f f TVD 18. Directional Survey: ®Yes ^ No Submit electronic and rinted information r 20 AAC 25.050 19. Water depth, if offshore: N/A tt MSL Perma rost ( ): 20. Thickness o 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR, GR, RES, GR / CCL / CNL 22. Re-DrilULateral Top Window MD/TVD: 9868' 8618' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE. ' CEMENTING RECORD PULLED 0" 91.5# H-40 dace 82' Surface 82' 30" 22 5# Poleset 1-/" 7# rf 212' rf 17-1/" xFn P r' 9-5/ " 47# L-so / soass rfa 980 ' Surf 8 6 ' 12-1 /4" 5 x lass ' x Perm fro 'C' 7" 2 -80 7866' 618' -1/2" x Class'G' ~~rz„ x 3-3/16" / 1214 ' 82 7 ' - /4" x - /8" 4.4# L- 12085' 14000' 'r 24. Open to production or injection? ®Yes ^ No 25. TuswG RECORD If Yes, list each interval open (MD+TVD of To & Bottom Perforation Size and Number): SIZE DEPTH .SET MD PACKER SET MD / TVO ; p 2-3/8" Slotted Section 4-1/2", 12.6#, 13Cr80 9504' 9449' / 8252' MD TVD MD TVD 12263' - 13971' 8675' - 8679' 26. ACID, FRACTURE, CEMENT SQUEEZE, fTC. DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED 2200' Freeze Protected w! Diesel 27. PRODUCTION TEST Date First Production: November 4, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowin Date of Test: 11!05/2009 Hours Tested: 6 Production For Test Period OIL-BBL: 202 GAS-MCF: 4,375 WATER-BBL: -0- CHOKE SIZE: 75 GAS-OIL RATIO: 21,718 Flow Tubing Pm~• -0- Casing Press: 1,780 Calculated 24-Hour Rate • OIL-BBL: 807 GAS-MCF: 17,498 WATER-BBL: -0- OIL GRAVITY-API (CORK): Not Available 28. CORE DATA Conventi onal Core(s) Acqu ired? ^Yes ® No Sidewall Core(s) Acquired? ^Yes ®No 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 ~ ~•~- .071. _r None ' j V Fl~tf .,;.-,,~ It1E Form 10-407 Revised 07/2009 CONTINUED ON REVERS ~( Submit O ' final Onl n9 Y 29. GEOLOGIC MARKERS (List all formations and rs encountered): 30. ORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Shublik A 9880' 8628' Shublik B 9905' 8650' None Shublik C 9928' 866T Ivishak Zone 4B 9988' 8702' Ivishak Zone 46 10174' 8705' Shublik A (Base Sag River) 10781' 8644' Shublik A 12195' 8675' Shublik A (Base Sag River) 12250' 8675' Formation at Total Depth (Name): Sag River (From Base) 1250' 8675' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing ' true and correct to the best of my knowledge. `~ I t7~0 Signed: Terrie Hubble Title: Drilling Technologist Date: PBU 06-18A 209-063 Prepared ByNameMumber. Terrie Hubble, 5644628 Well Number Permit No. /Approval No. Drilling Engineer: Sean McLaughlin, 564-4387 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 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, SaR 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 elevation 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 TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: 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. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 07/2009 Submit Original Only BP EXPLORATION Page 1 of 1 s Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date.. From - To Hours ~ TasK Code NPT Phase Description of Operations ' 10/2/2009 22:00 - 00:00 2.00 MOB P PRE MOVE FROM DS-12 TO DS-06. RIG ACCEPTED AT 22:00. MOVE OVER WELL AND SET RIG DOWN, REMOVE HANDRAILS FROM AROUND WELLHEAD PLATFORM. 10/3/2009 00:00 - 02:00 2.00 BOPSU P PRE N/U BOPS. 02:00 - 09:00 7.00 BOPSU P PRE BOP TEST, WITNESS WAIVED BY AOGCC JEFF JONES. FILL PITS WITH 2# BIOZAN WITH 0.6% SAFE LURE WHILE BOP TESTING. 09:00 - 11:30 2.50 BOPSU P PRE CUT OF WELD ON CONNECTOR. INSTALL CONNECTOR AND PULL TEST TO 35K. FLOOD CT. PT CTC AND INNER REEL VALVE. 11:30 - 12:00 0.50 STWHIP P WEXIT HEAD UP CT. 12:00 - 13:30 1.50 STWHIP P WEXIT TROUBLE SHOOT AND REPAIR WET WIRE. JUNCTION BOX IN REEL FOUND TO BE WET. CONTINUE TO HEAD UP BAKER. 13:30 - 14:55 1.42 STWHIP P WEXIT 14:55 - 17:00 2.08 STWHIP P WEXIT RIH to 9440 UP WT 51 K. DN WT 24K 17:00 - 17:35 0.58 STWHIP P WEXIT LOG TIE - IN. CORRECTION = -21' 17:35 - 17:50 0.25 STWHIP P WEXIT RIH TAG AT 9870 17:50 - 00:00 6.17 STWHIP P WEXIT MILL WINDOW. 18:00 9869.42 FT 2509 PSI 19:00 9869.85 FT 2761 PSI 1.49K DWOB 20:00 9870.25 FT 2900 PSI 1.77K 21:00 9870.65 FT 2830 PSI 1.92K METAL ON MAGNETS. 22:00 9871.35 FT 2950 PSI 3.39K 23:00 9871.90 FT 2941~PSI 3.08K 00:00 9872.80 FT 2800 PSI 1.82K 10/4/2009 00:00 - 03:20 3.33 STWHIP P WEXIT CONTINUE MILLING WINDOW. 00:00 9872.80 FT 2800 PSI 1.82K 01:00 9873.45 FT 2740 PSI 1.71 K 02:00 9874.25 FT 2880 PSI 2.57K 03:00 9874.90 FT 2850 PSI 2.28K 03:20 - 04:40 1.33 STWHIP P WEXIT AFTER 9875 FT DWOB DROPS TO 0.50 KLBS, ABOUT 100 PSI MOTOR WORK. 04:00 9875.70 FT 2740 PSI 0.97K 04:40 - 06:40 2.00 STWHIP P WEXIT AFTER 9876.5 FT ESTIMATE STRING REAMER IS 1 FT OUTSIDE WINDOW, START TO INCREASE ROP. 05:00 9877.00 FT 2730 PSI 0.75K 06:00 9882.35 FT 2930 PSI 3.96K SAMPLE IS 15% SAND, 85% METAL. 06:40 - 08:00 1.33 STWHIP P WEXIT DRESS WINDOW. DRY TAG WINDOW OK. 08:00 - 10:00 2.00 STWHIP P WEXIT POH WHILE SWAPPING WELL TO GEO VIS. 10:00 - 12:10 2.17 STWHIP P WEXIT AUGE 3.80 GO 3.79 NOGO. PU 3.4 MOTOR BUILDING ASSY. STAB ONTO WELL. 12:10 - 14:40 2.50 DRILL P LNR1 I T 9325. 14:40 - 16:20 1.67 DRILL P LNR1 LOG TIE-IN CORRECTION = -21 16:20 - 16:30 0.17 DRILL P LNR1 RIH 16:30 - 22:00 5.50 DRILL P LNR1 E TION. TAG AT 9887. 2.5/ 2.5 BPM X3060 PSI, DWOB 4.8K,ECD 9.64, FS 2700 PSI, ROP 10-30 FT/HR. HOLD 20L-20R TF TO BUILD ANGLE. MANY STALLS, SLOW DRILLING. ~6 P' rnntea: iuuzuua za°:zirnn BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/4/2009 16:30 - 22:00 5.50 DRILL P LNR1 DRILL TO 9951 FT. 22:00 - 00:00 2.00 DRILL P LNR1 FIRST GOOD SURVEY OUT THE WINDOW SHOWS BUILD RATE OF 33 DEG/100 VS EXPECTED 40-45 DEG. CONFIRM WITH GEO AND ODE DEEPER LANDING POINT IS OK, CONTINUE DRILLING. 2.45 / 2.49 BPM ~ 2550 FS. ROP AROUND 20 FT/HR WITH 2-4 KLBS DWOB. DRILL TO 9960 FT. 10/5/2009 00:00 - 04:30 4.50 DRILL P LNRi CONTINUE DRILLING BUILD SECTION. HOLD 20R TF TO BUILD ANGLE. 2.58 / 2.57 BPM ~ 2800-3300 PSI. ROP IS 10-30 FT/HR WITH 2-3 KLBS DWOB. AFTER 9994 FT ROP INCREASES, TOP IVESHAK ACCORDING TO GEO. DRILL TO TD OF BUILD SECTION AT 10090 FT. 04:30 - 06:45 2.25 DRILL P LNR1 POOH. 10K OVERPULL AT WINDOW, RIH AND PULL THROUGH WINDOW AGAIN WITH MINIMUM RATE, NOTHING SEEN. CLEAN 7" CASING UP AND DOWN PRIOR TO OPENING EDC. 06:45 - 08:30 1.75 DRILL P LNR1 BHA SWAP 08:30 - 09:50 1.33 DRILL N LNR1 WOO REGARDING POSSIBLE BHA SWAP. WILL GO WITH RIB STEER AS PLANNED. 09:50 - 11:45 1.92 DRILL P LNR1 RIH 9840. UP WT 11:45 - 12:25 0.67 DRILL P LNR1 LOG TIE-IN CORRECTION = -22'. 12:25 - 12:45 0.33 DRILL P LNR1 RIH 12:45 - 14:10 1.42 DRILL P LNR1 DRILL TO 10214. 14:10 - 15:40 1.50 DRILL N SFAL LNRi HYDRAULIC LEAK ON INJECTOR. UPPER CHAIN TRACTION CYCLINDER HARD LINE FAILED. REPAIR AND TEST OK. ATTEMPTED TO MOVE PIPE FAILED AGAIN IDENTICAL POSITION. CYCLINDER MOVING FOR UNKNOWN REASON. WAIT ON PARTS AND MECHANIC. FURTHER INVESTIGATION FOUND THE SKATE TO BE BROKEN. 15:40 - 18:30 2.83 DRILL N SFAL LNR1 WAIT ON MECHANIC AND PLAN FORWARD. REMOVE PIECE OF BROKEN SKATE. POOH SLOWLY. 18:30 - 20:45 2.25 DRILL N SFAL LNR1 PULL THROUGH WINDOW, CONTINUE POOH. CONSULT WITH SLB MECHANICS ABOUT PULLING SPEED, SETTLE ON 80 FT/MIN FOR A SPEED LIMIT. 20:45 - 21:00 0.25 DRILL N SFAL LNR1 SAFETY MEETING. PJSM FOR LAYING DOWN BHA AND TAKING OFF UOC. 21:00 - 21:40 0.67 DRILL N SFAL LNR1 UD BHA #3. FILL WELL AND SHUT IN SWAB. 21:40 - 22:10 0.50 DRILL N SFAL LNR1 LIFT UP INJECTOR, REMOVE UOC AND FLOW SUB. REMOVE CT CONNECTOR. 22:10 - 22:20 0.17 DRILL N SFAL LNRi SAFETY MEETING. PJSM FOR UNSTABBING CT AND WINDING IT BACK ONTO REEL. 22:20 - 23:10 0.83 DRILL N SFAL LNR1 PICK UP INJECTOR, CUT OFF DIMPLED PORTION OF CT. INSTALL INTERNAL GRAPPLE FOR PULLING CT BACK TO REEL. PULL TEST INTERNAL GRAPPLE. ROLL CT OUT OF INJECTOR AND BACK TO REEL, CLAMP Printed: 11/2/2009 2:55:27 PM ~ ~ BP EXPLORATION Page 3 of t6 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task' Code NPT Phase " Description of Operations 10/5/2009 22:20 - 23:10 0.83 DRILL N SFAL LNR1 IT THERE. 23:10 - 23:30 0.33 DRILL N SFAL LNR1 SAFETY MEETING. PJSM FOR TAKING OFF GOOSENECK AND STRIPPER, AND SETTING INJECTOR DOWN ON THE RIG FLOOR. 23:30 - 00:00 0.50 DRILL N SFAL LNR1 M/U CT RISER TO WELL. REMOVE GOOSENECK SUPPORT ARMS. UNPIN AND REMOVE GOOSENECK, TAIL IT INTO THE PIPE SHED. UNHOOK HYDRAULIC HOSES FROM STRIPPER, UNPIN IT AND LIFT INJECTOR OFF STRIPPER. 10/6/2009 00:00 - 01:00 1.00 DRILL N SFAL LNR1 CONTINUE TO UNHOOK HYDRAULIC HOSES FROM STRIPPER AND UNPIN IT. LIFT INJECTOR OUT OF STRIPPER, LIFT STRIPPER OFF WELL AND SET IT ASIDE. SET INJECTOR DOWN SIDEWAYS ON RIG FLOOR, PREP TO REMOVE CHAINS. 01:00 - 01:15 0.25 DRILL N SFAL LNR1 PJSM FOR REMOVING CHAINS AND SKATES FROM INJECTOR. CHECK FLUID LEVEL IN WELL, STAYING STATIC. 01:15 - 03:30 2.25 DRILL N SFAL LNR1 REMOVE CHAINS FROM INJECTOR. UNBOLT TRACTION CYLINDERS. HOOK UP SLING TO SKATES AND WORK THEM OUT THROUGH THE TOP OF THE INJECTOR. 03:30 - 06:00 2.50 DRILL N SFAL LNR1 BOTH SKATES OUT. PREP FOR INSTALLING NEW ONES. LOWER NEW SKATES DOWN INTO INJECTOR, BOLT THEM INTO POSITION. INSTALL TRACTION CYLINDERS. ROLL CHAINS BACK INTO INJECTOR, INSTALL KEEPER PINS AND PEANUTS. PRESSURE UP AND TEST CHAIN TENSION CYLINDERS. 06:00 - 09:15 3.25 DRILL N SFAL LNR1 INSTALL GOOSENECK, INSPECT CHAINS ,INSTALL CHAIN GUARDS. 09:15 - 09:50 0.58 DRILL N SFAL LNR1 PJSM FOR STABBING STRIPPER. INSTALL STRIPPER 09:50 - 10:00 0.17 DRILL N SFAL LNR1 PJSM FOR PULLING CT TO INJECTOR. 10:00 - 12:30 2.50 DRILL N SFAL LNR1 THREAD CABLE THRU INJECTOR AND PULL BACK TO REEL HOUSE. INSTALL GRAPPLE IN CT AND PULL TEST. PULL CT TO INJECTOR. CUT 100' OF CT FOR CR MANAGEMENT 12:30 - 13:45 1.25 DRILL N SFAL LNR1 INSTALL CTC AND PULL TEST 37K. FLOOD COIL AND PRESSURE TEST CTC TO 3600 PSI. 13:45 - 14:45 1.00 DRILL N SFAL LNR1 HEAD UP BAKER. 14:45 - 15:40 0.92 DRILL N SFAL LNR1 MU RIBSTEER DRLG BHA 15:40 - 17:20 1.67 DRILL N SFAL LNR1 RIH TO 9880'. 17:20 - 17:50 0.50 DRILL N SFAL LNR1 LOG TIE-IN CORRECTION = -22' 17:50 - 18:00 0.17 DRILL N SFAL LNR1 RIH TO TD (SET DOWN AT 10000' & 10190') 18:00 - 21:00 3.00 DRILL P LNR1 - 2.65 BPM IN / 2.78 BPM OUT ~ 2700-3200 PSI, FS=2650 PSI 2.OK-3.5K# DHWOB, 10-60 FPH, 96 DEG INC, 90L-100L TF IA=O PSI, OA=75 PSI, ECD=9.8 PPG, PVT=334 BBL DRILL TO 10,285' 21:00 - 00:00 3.00 DRILL P LNRi DRILL SHUBLIK 2.64/2.69 ~ 2800-3000 PSI, FS=2650 PSI 3.OK# DHWOB, 10-20 FPH, 96 DEG INC, 90L TF IA=O, OA=76, ECD=9.8, PVT=328 DRILL TO 10,330' rnnceo: i va~wa c.oa:u rm ~ ~ BP EXPLORATION Page 4 of 16 Operations Summary`Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations.. 10/7/2009 00:00 - 01:00 1.00 DRILL P LNR1 DRILL SHUBLIK FROM 10,330' TO 10,350'. 2.67 BPM IN / 2.72 BPM OUT ~ 3000 PSI, FS=2650 PSI 2.7K# DHWOB, 20-30 FPH, 100E TF, 97 DEG INC IA=114, OA=100, ECD=9.8, PVT=327 01:00 - 01:40 0.67 DRILL P LNR1 WIPER TO WINDOW. WEIGHT BOBBLES AT 10090' & 10180' . WIPER TO TD. SET DOWN AT 10190'. PASS THROUGH WITH PUMPS OFF. CONTINUE WIPER TO TD. 01:40 - 04:00 2.33 DRILL P LNR1 DRILL SHUBLIK FROM 10350' 2.6/2.5 BPM C~ 2750 PSI, FS=2650 PSI 2.5K-3.OK# DHWOB, 20-80 FPH, 100E TF, 97 DEG INC IA=170, OA=105, ECD=9.7, PVT=311 DRILL TO 10390' LOSSES OF 0.8 BPM ~ 10375' AFTER A DRILLING BREAK. LOSSES HEALED TO 0.1 BPM ~ 10386'. 16 BBL LOST FROM 0300 TO 0400. 04:00 - 06:00 2.00 DRILL P LNR1 DRILL 2.7/2.53 BPM 033050 PSI, FS=2650 PSI 3.40K# DHWOB, 50 FPH, 100E TF, 96 DEG INC IA=175, OA=105, ECD=9.7, PVT=309 06:00 - 09:10 3.17 DRILL P LNR1 DRILL 2.67/2.55 BPM ~ 2750-2850 PSI, FS=2650 PSI 2.5K-3.OK# DHWOB, 15 FPH, 100E TF, 96 DEG INC IA=212, OA=105, ECD=9.7, PVT=273 09:10 - 10:00 0.83 DRILL P LNR1 WIPER TO WINDOW MW OVERPULL X10080 10:00 - 12:00 2.00 DRILL P LNR1 DRILL 2.67/2.51 BPM ~ 3330 PSI, FS=2830 PSI 2.2KK# DHWOB, 24 FPH, 100E TF, 97 DEG INC IA=236, OA=105, ECD=9.9, PVT=231. ATTEMP TO DRILL AHEAD fs INCREASE TO 3330 PSI. NO MOTOR WORK. RUBBER IN SCREEN 12:00 - 14:30 2.50 DRILL N LNR1 POH FOR MOTOR FAILURE.JOG THRU 7' OPEN EDC AND POH TO SURFACE AT 3.33 BPM. 14:30 - 15:40 1.17 DRILL N LNR1 SAFETY MEETING, RE: BHA SWAP SWAP RIBSTEER MOTOR & DGS 15:40 - 17:30 1.83 DRILL N LNR1 RIH TO 9880. 17:30 - 17:50 0.33 DRILL N INRi LOG TIE-IN. CORRECTION = -18 17:50 - 18:20 0.50 DRILL N LNRi RIH TAG AT 10,521'. 18:20 - 18:45 0.42 DRILL P LNR1 DRILL SHUBLIK 2.50/2.35 BPM ~ 3000 PSI, FS=2600 PSI 2.OK# DHWOB, 50-70 FPH, 90L TF, 96 DEG INC IA=O, OA=80, ECD=9.9, PVT=162 DRILL TO 10554' SLB DEPTH COUNTER ERROR. ADJUSTED COUNTER. 18:45 - 22:15 3.50 DRILL N RREP LNR1 POWER SUPPLY FAILURE. UNABLE TO RUN POWER PAC & PUMPS. PUH TO ABOVE THE WINDOW & PUMP MINIMUM RATE WHILE TROUBLESHOOT GENERATOR FAULTS. RECTIFIER FAILURE ON GENERATOR #2. REPLACE RECTIFIER AND GEN #2 BACK ONLINE. 22:15 - 22:40 0.42 DRILL N SFAL LNR1 LOG TIE-IN DUE TO SLB COUNTER ERROR. -36' CORRECTION. 22:40 - 23:10 0.50 DRILL N RREP LNR1 RIH. TAG AT 10554' CLEAN PITS AND HOOK TRUCKS UP FOR MUD SWAP. 23:10 - 00:00 0.83 DRILL P LNR1 DRILL SHUBLIK 2.6/2.5 BPM ~ 3050 PSI, FS=2700 PSI ', 3.OK# DHWOB, 35-40 FPH, 50L-80L TF, 97 DEG INC IA=O, OA=75, ECD=10.0, PVT=86 Printed: 11/2/2009 2:55:27 PM ~ ~ BP EXPLORATION Page 5 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To Hours j Task ~ Code ~ NPT Phase Description of Operations 10/7/2009 23:10 - 00:00 0.83 DRILL P LNR1 DRILL TO 10590' 10/8/2009 00:00 - 05:00 5.00 DRILL P LNR1 DRILL SHUBLIK FROM 10,590' 2.44 BPM IN / 2.31 BPM OUT ~ 2800-3000 PSI, FS=2700 PSI 1.4K-3.OK# DHWOB, 20-50 FPH, 100E TF, 95 DEG INC IA=82, OA=82, ECD=10.0, PVT=39 SWAP TO NEW MUD. NEW MUD AT BIT ~ 10,693' DRILL TO 10,700' 05:00 - 06:00 1.00 DRILL P LNR1 WIPER TO 8895'. WIPER TO TD. NO WEIGHT BOBBLES. 06:00 - 08:10 2.17 DRILL P LNR1 2.70 BPM IN / 2.66 BPM OUT ~ 2800-3000 PSI, FS=2700 PSI 3.7K# DHWOB, 50 FPH, 180E TF, 93 DEG INC IA=O, OA=66, ECD=10.0, PVT=287 ~ 10778. DRILLING BREAK. 08:10 - 09:10 1.00 DRILL P LNR1 WIPER TO WINDOW. 09:10 - 10:20 1.17 DRILL P LNR1 2.63 BPM IN / 2.64 BPM OUT ~ 2800-3000 PSI, FS=2350 PSI 2.OK# DHWOB, 150 FPH, 130R TF, 91 DEG INC IA=O, OA=74, ECD=10.0, PVT=280 ~ 10778. 10:20 - 11:15 0.92 DRILL P LNR1 WIPER TO TAILPIPE 2.7 BPM. 11:15 - 11:30 0.25 DRILL P LNR1 LOG TIE - IN CORRECTION = -3' 11:30 - 12:30 1.00 DRILL P LNRi RIH TO 10900 MADD PASS TO TD. 12:30 - 13:30 1.00 DRILL P LNR1 2.63 BPM IN / 2.56 BPM OUT ~ 2800-3000 PSI, FS=2350 PSI 2.30K# DHWOB, 160 FPH, 130R TF, 89 DEG INC IA=99, OA=74, ECD=10.0, PVT=264 13:30 - 14:50 1.33 DRILL P LNR1 WIPER TO WINDOW 14:50 - 16:25 1.58 DRILL P LNR1 2.6 BPM IN / 2.56 BPM OUT C~ 2700 PSI, FS=2350 PSI 2.30K# DHWOB, 100 FPH, 150R TF, 89 DEG INC IA=171, OA=84, ECD=10.0, PVT=256 16:25 - 18:45 2.33 DRILL P LIVR1 WIPER TO TUBING TAIL. 18:45 - 19:30 0.75 DRILL N DFAL LNR1 TAG 11300'. LOST COMMUNICATION WITH RIBSTEER. PUH & TROUBLESHOOT. UNABLE TO ESTABLISH COMMUNICATION. 19:30 - 22:00 2.50 DRILL N DFAL LNR1 POH 22:00 - 23:30 1.50 DRILL N DFAL LNR1 SAFETY MEETING, RE: BHA SWAP L/D RIBSTEER MTR &DGS, BIT GRADED 1,2-BT PU RIBSTEER MTR, DGS, & NEW 3.75" RIBSTEER PDC BIT 23:30 - 00:00 0.50 DRILL N DFAL LNRi RIH RIBSTEER DREG BHA 10/9/2009 00:00 - 01:20 1.33 DRILL N DFAL LNR1 RIH RIBSTEER DREG BHA 01:20 - 01:45 0.42 DRILL N DFAL LNR1 LOG TIE-IN, -19' CORRECTION 01:45 - 02:30 0.75 DRILL N DFAL LNR1 RIH, TAG BOTTOM (~ 11,315' 02:30 - 04:15 1.75 DRILL P LNR1 DRILL SAG RIVER LATERAL CIRCULATED TRIP GAS AND 15 BBL OF MUD TO TIGER TANK. 2.55 BPM IN / 2.52 BPM OUT ~ 2700-2800 PSI, FS=2400 PSI 3.Ok-3.5K# DHWOB, 60-85 FPH, 40R-50R TF, 88 DEG INC IA=26, OA=77, ECD=9.8, PVT=223 DRILL TO 11450' 04:15 - 06:20 2.08 DRILL P LNR1 WIPER TRIP TO WINDOW. MOTOR WORK ~ 10,620' POH. 06:20 - 08:40 2.33 DRILL P LNR1 2.55 BPM IN / 2.52 BPM OUT ~ 2700-2800 PSI, FS=2400 PSI 3.Ok-3.5K# DHWOB, 60-85 FPH, 40R-50R TF, 89 DEG INC IA=413, OA=103, ECD=9.9, PVT=191 SHORT WIPER AT 11512 RATTY 11395 11375 . SET DOWN RIH/ WO PUMP TO GET THRU BRING PUMP BACK ON AT 11500. CONTINUE TO DRILL TO 11595 08:40 - 10:30 1.83 DRILL P LNR1 WIPER TO WINDOW. CLEAN THRU 1 1 300-1 1 400. MIN Printed: 11/2/2009 2:55:27 PM w i BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 .Date From - To Hours Task Code NPT Phase Description of Operations 10/9/2009 08:40 - 10:30 1.83 DRILL P LNRi RATE THU 10:30 - 14:20 3.83 DRILL P LNR1 14:20 - 15:40 1.33 DRILL P LNR1 15:40 - 15:50 0.17 DRILL P LNR1 15:50 - 16:45 0.92 DRILL P LNR1 16:45 - 19:30 2.75 DRILL P LNR1 19:30 - 21:20 1.83 DRILL P LNRi 21:20 - 23:00 1.67 DRILL P LNR1 23:00 - 00:00 1.00 DRILL P LNR1 10/10/2009 00:00 - 01:15 1.25 DRILL P LNR1 01:15 - 02:25 1.17 DRILL P LNR1 02:25 - 03:45 1.33 DRILL P LNR1 03:45 - 04:05 0.33 DRILL P LNR1 04:05 - 05:00 0.92 DRILL P LNR1 05:00 - 08:30 3.50 DRILL P LNR1 08:30 - 08:45 0.25 DRILL P LNR1 08:45 - 09:00 0.25 DRILL P LNR1 09:00 - 09:15 0.25 BOPSU P LNR1 09:15 - 09:45 0.50 CASE P LNR1 09:45 - 10:30 0.75 CASE P LNR1 10:30 - 12:30 2.00 CASE P LNR1 12:30 - 13:00 0.50 CASE P LNR1 13:00 - 18:00 5.00 CASE P LNR1 18:00 - 18:30 I 0.501 CASE I P I I LNR1 18:30 - 19:45 1.25 CASE P LNR1 19:45 - 20:40 0.92 CASE P LNR1 20:40 - 21:00 0.33 CASE P LNR1 21:00 - 00:00 3.00 CASE P LNR1 2.49 BPM IN / 2.39 BPM OUT ~ 2700-2800 PSI, FS=2400 PSI 3.Ok-3.9K# DHWOB, 50 FPH, 40R-50R TF, 88 DEG INC IA=513, OA=95, ECD=9.9, PVT=169 11610 LOST .5 BPM FOR 5 MINUTES. SWAP WELL TO NEW GEO VIS. WIPER TO TAILPIPE RIH TO WINDOW. LOG TIE -IN. CORRECTION = +3 WIPER TO TD. 2.53/2.56 BPM ~ 2550-2600 PSI, FS=2200 PSI 3.4k-3.9K# DHWOB, 50-70 FPH, 90R-40L TF, 88-89 DEG INC IA=230, OA=90, ECD=9.7, PVT=322 70k PU off bottom DRILL TO 11900 WIPER TO WINDOW. DRILL SAG RIVER 2,58/2.59 ~ 2800 PSI, FS=2350 PSI 4K-5K# DHWOB, 70-90 FPH, 70L TF, 90 DEG INC IA=330, OA=100, ECD=9.7, PVT=310 DRILL TO 12,050' WIPER TO WINDOW Continue wiper to window. DRILL SAG RIVER LATERAL FROM 12,050' 2.56 BPM IN / 2.55 BPM OUT ~ 2900 PSI, FS=2350 4.OK-4.5K# DHWOB, 85-90 FPH, 85 DEG INC, 20L IA=260, OA=110, ECD=9.8, PVT=301 TD CALLED ~ 12,150'. WIPER UP THROUGH WINDOW. LOG TIE-IN, +4' CORRECTION WIPER TO TD. TAG TD ~ 12,153'. POH LAYING IN LINER RUNNING PILL IN OPENHOLE PJSM FOR LD BHA LD BHA. FUNCTION TEST BOP REMOVE BAKER HEAD AND CTC. INSTALLCTC PU 1 PH-6. STAB ONTO WELL. PUMP SLACK FROM CT. CIRCULATE AT 3.8 BPM @ 2550 PSI. POP OFF WELL AND CUT 303' WIRE. LD PH-6 SINGLE. LAY OUT RIB STEER COMPONENTS AND PU LINER RUNNING TOOLS. INSTALL BAKER CTC AND PULL TEST TO 35K. PT TO 3500 PSI PJSM FOR PU LINER MU LINER.FLOAT EQUIPMENT AND BAKERLOCK SAME. BAKERLOCK FIRST 4 JOINTS AND DRIFT THE FIRST 10 CONNECTION WITH 2.74 DRIFT. PU 62 JNTS 3-3/16" LINER. CREW CHANGE SAFETY MEETING, RE: PU LINER PU 20 JNTS 3-3/16" LINER & PUP JNTS RU TO RUN 1-1/4" CSH INNER STRING SAFETY MEETING, RE: PU 1-1/4" CSH INNER STRING, LINER RUNNING TOOLS, & PH6. PU 86 JNTS 1-1/4" CSH Printed: 11/2/2009 2:55:27 PM BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 i Date. From - To Hours Task Code NPT Phase "Description of Operations 10/10/2009 21:00 - 00:00 3.00 CASE P LNR1 PRESSURE TEST 3-3/16" LNR X 1-1/4" CSH ANNULUS TO 500 PSI. PU LINER RUNNING TOOLS & 4 JNTS PH6 10/11/2009 00:00 - 01:15 1.25 CASE P LNR1 PU REMAINING LINER BHA. 01:15 - 03:15 2.00 CASE P LNR1 RUN LINER TO TD--DEPLOYMENT SLEEVE, X NIPPLE, 2 PUP JNTS 3-1/2" STL L-80, XO, 1 PUP JNT 3-3/16" TCII L-80, 82 JNTS 3-3/16" 6.2# TCII L-80 LINER W/ TURBOS, O-RING SUB, 2 PUP JNTS 3-3/16" TCII L-80, FLOAT COLLAR, 1 PUP JNT 3-3/16" TCII L-80, & GUIDE SHOE. LINER OAL = 2695.77' 03:15 - 07:00 I 3.751 CASE I N I DFAL I LNR1 07:00 - 10:15 3.25 CASE N DFAL LNR1 10:15 - 13:30 3.25 CASE N DFAL LNR1 13:30 - 16:00 2.50 CASE N DFAL LNR1 16:00 - 17:00 1.00 CASE P LNR1 17:00 - 20:30 3.501 CEMT ~ P 20:30 - 20:50 0.33 CEMT P 20:50 - 22:50 2.00 CEMT P LNR1 LNR1 LNR1 CT UP WEIGHT ABOVE WINDOW = 54K, CT RIH WEIGHT ABOVE WINDOW = 32K TAG TD ~ 12130' UNCORRECTED, EOP FLAG 15' SHALLOW CT PU WEIGHT OFF BOTTOM = 52.5K LAUNCH 5/8" STEEL BALL WITH 500 PSI, BALL HEARD ROLLING CIRCULATE 110 BBL, BALL NOT ON SEAT, CT PU WEIGHT OFF BOTTOM = 43K LAUNCH 2ND 5/8" STEEL BALL WITH 2000 PSI, BALL HEARD ROLLING. NO BALL ON SEAT. BAKER NOTIFIED US THAT THE 3/4 SEAT FOR DISCONNECT NOT INSTALLED CONSEQUENTLY WE ARE CIRCULATING THRU IT'S SHEAR SCREW HOLES. POH POH TO CORRECT BAKER RUNNING TOOL. STANDBACK INJECTOR LD 4 JOINTS OF PH-6 TUBING.LD BAKER RUNNING TOOL MISSING 3/4" SHEAR SEAT. MU LINER RUNNING TOOL 4 JOINTS PH6, STAB INJECTOR RIH WITH LINER 26K DN WT.55k UP WT. TAG AT 12168 UNCORRECTED. PU TO BALL DROP AND LAUNCH WITH 2O00PS1. BALL ROLLING. BALL ON SEAT ~ 46.9 BBLS. PRESSURE TO 4300 HOLD 3800 PSI FOR 3 MINUTES PRESSURE TO 4400 HOLD 4300 FOR PRESSURE TO 4600 HOLD 4550 PRESSURE TO 4800 PSI SHEAR BALL SEAT. PU 47K SWAP WELL TO KCL. 2.0/1.8 BPM AT 2600 PSI 1.2/1.2 BPM ~ 760 PSI SAFETY MEETING, RE: CEMENT JOB BATCH UP CEMENTERS, CEMENT AT DENSITY ~ 21:20 PT CEMENT LINES TO 6000 PSI PUMP 15.8 PPG CLASS G CEMENT WITH ANTIFOAM, DISPERSANT, GASBLOK, & RETARDER. THICKENING TIME--70 BC ~ 3 HR 2 MIN. 0 BBL 2.0/2.0 BPM 2100 PSI 7 BBL 2.0/2.0 BPM 2530 PSI 11.0 BBL 1.7/1.7 BPM 2020 PSI 14.0 BBL 1.7/1.7 BPM 2200 PSI 17.0 BBL 1.7/1.7 BPM 2320 PSI 20.0 BBL 1.7/1.7 BPM 2450 PSI 22.0 BBL 1.7/1.7 BPM 2600 PSI 23.0 BBL 1.6/1.6 BPM 2520 PSI 24.0 BBL 1.6/1.6 BPM 2500 PSI Printed: ivvzoua z:oo:zi Pnn BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours .Task Code NPT Phase Description of Operations 10/11/2009 20:50 - 22:50 2.00 CEMT P LNR1 ZERO IN MM ~ 24.5 BBL CEMENTERS FOLLOW WITH 5 BBL KCL TO CLEAN UP CEMENT LINE CHASE WITH BIOZAN 0 BBL 24.0 BBL 2.1/2.1 BPM 2050 PSI 28.0 BBL 2.2/2.2 BPM 2200 PSI 32.0 BBL 2.1/2.0 BPM 2700 PSI 33.0 BBL 2.1/2.0 BPM 3300 SPI 34.0 BBL DROP TO 1.5 BPM PRESSURE IS INCREASING IN CSH 35.9 BBL 1.5/1.6 2650 PSI 36.0 BBL ZERO OUT MM, CEMENT AT THE SHOE 37.5 BBL 1.4/1.4 BPM 2300 PSI 38.5 BBL 1.4/1.4 BPM 2280 PSI 40.0 BBL 1.4/1.4 BPM 2500 PSI 41.0 BBL 1.4/1.4 BPM 2640 PSI 42.0 BBL 1.4/1.4 BPM 2900 PSI 44.0 BBL 1.5/1.4 BPM 3300 PSI DROP PUMP RATE 45.5 BBL 1.1/1.1 BPM 2200 PSI 46.5 BBL 1.1/1.1 BPM 2000 PSI 48.0 BBL 1.0/1.0 BPM 2040 PSI 50.0 BBL 1.0/1.0 BPM 2220 PSI 51.0 BBL 1.0/1.0 BPM 2350 PSI 53.0 BBL 1.0/1.0 BPM 2580 PSI 55.0 BBL 1.0/1.0 BPM 2830 PSI 57.0 BBL 1.0/1.0 BPM 2980 PSI ~~, 58.0 BBL 1.1/1.0 BPM 2870 PSI ,/ 58.5 BBL SHUT DOWN, OUT MM 22.4 BBL CEMENT IN PLACE ~ 22:30, 1.1 BBL LOSSES LAY IN 1 BBL OF REMAINING CEMENT, PUH & CIRCULATE BIOZAN TO STINGER RIH TO 50' ABOVE O-RING SUB, CONTAMINATE CEMENT PUMPING VOIDAGE PLUS 0.1 BPM 22:50 - 00:00 1.17 CEMT P LNR1 POH PUMPING BIOZAN AT VOIDAGE PLUS 0.1 IN 3-3/16" LNR POH PUMPING BIOZAN AT VOIDAGE PLUS 0.5 IN 4-1/4" TBG 10/12/2009 00:00 - 00:45 0.75 CEMT P LNR1 POH WITH LINER RUNNING TOOLS & INNER STRING 00:45 - 01:00 0.25 CEMT P LNR1 MEETING, RE: UD LRT & S/B 1-1/4" CSH 01:00 - 03:00 2.00 CEMT P LNR1 UD 4 JNTS 2-3/8" PH6 & LINER RUNNING TOOLS, 5/8" BALL RECOVERED S/B 43 STANDS 1-1/4" CSH INNER STRING 03:00 - 04:00 1.00 CEMT P LNR1 CLEANUP RIG FLOOR. SETUP LOGGING TOOL. 04:00 - 04:15 0.25 CEMT P LNR1 SAFETY MEETING, RE: PU C/O LOGGING BHA & NUCLEAR SOURCE 04:15 - 07:00 2.75 EVAL P LNR1 PU MILL, MTR, 2 JNTS 1-1/4" CSH, LOGGING TOOL, 45 STANDS 1-1/4" CSH. MU INJECTOR AND STAB ON TO WELL. 07:00 - 09:00 2.00 EVAL P LNRi RIH TO 9400'. WT CK 40k UP,25K DN. 09:00 - 11:00 2.00 EVAL P LNRi LOG DOWN 30 FT/HR FROM 9400 SET DOWN AT 12039' UNCORRECTED. DRILL STRINGERS TO PBTD. Printed: 11/2/2009 2:55:27 PM BP EXPLORATION Page 9 of 16 Operations Sumrnary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 ~ NPT Phase Description of Operations Date From - To Hours Task Code 10/12/2009 09:00 - 11:00 2.00 EVAL P LNRi CORRECTED PBTD = 12,113' 11:00 - 12:00 1.00 EVAL P LNR1 LOG UP 60 FT/MIN+ 12:00 - 13:00 1.00 EVAL P LNRi POH 13:00 - 15:45 2.75 EVAL P LNR1 SAFETY MEETING, RE: S/B 1-1/4" CSH S/B 45 STANDS 1-1/4" CSH TUBING. 15:45 - 16:00 0.25 EVAL P LNR1 PJSM TO LD BHA AND MEMORY TOOL. 16:00 - 16:30 0.50 EVAL P LNR1 UD LOGGING TOOL & 2 JNTS 1-1/4" CSH 16:30 - 18:00 1.50 EVAL P LNR1 CLEAR RIG FLOOR. JET ST 18:00 - 00:00 6.00 EVAL C LNR1 SAFETY STANDDOWN ADDRESSING CONTROL OF WORK, SIMOPS, PEOPLE WORKING ALONE, AND IDENTIFYING BARRIERS TO MAKING THE OPERATION INJURY FREE. ~ 10/13/2009 00:00 - 00:00 24.00 EVAL C LNR1 SAFETY STANDDOWN ADDRESSING CONTROL OF ~ ~~~ w WORK, SIMOPS, PEOPLE WORKING ALONE, AND IDENTIFYING BARRIERS TO MAKING THE OPERATION INJURY FREE. 10/14/2009 00:00 - 00:00 24.00 EVAL C LNR1 SAFETY STANDDOWN ADDRESSING CONTROL OF WORK, SIMOPS, PEOPLE WORKING ALONE, AND IDENTIFYING BARRIERS TO MAKING THE OPERATION INJURY FREE. 10/15/2009 00:00 - 00:00 24.00 EVAL C LNRi SAFETY STANDDOWN ADDRESSING CONTROL OF WORK, SIMOPS, PEOPLE WORKING ALONE, AND IDENTIFYING BARRIERS TO MAKING THE OPERATION INJURY FREE. 10/16/2009 00:00 - 16:30 16.50 EVAL C LNR1 SAFETY STANDDOWN ADDRESSING CONTROL OF WORK, SIMOPS, PEOPLE WORKING ALONE, AND IDENTIFYING BARRIERS TO MAKING THE OPERATION INJURY FREE. RELEASED BACK TO WORK ~ 16:30 16:30 - 19:00 2.50 EVAL P LNR1 MAKE UP NEW RIG PAD ENTRANCE SIGNS 19:00 - 20:30 1.50 DRILL P LNR1 SAFETY MEETING, RE: BHA CHANGE UD SWIZZLE STICK PU NOZZLE; CHECKS, DISCO, & 1 JNT PH6 20:30 - 22:30 2.00 DRILL P LNR1 RIH TO 3000' CIRCULATING TO ENSURE WELLBORE CLEAR OF ANY ICE BUILDUP. 22:30 - 23:00 0.50 CEMT P LNR1 TEST LINER LAP TO 2000 PSI. TEST FAILED. 23:00 - 23:30 0.50 DRILL P LNR1 SAFETY MEETING, RE: UD BHA UD NOZZLE, CHECKS, DISCO, & 1 JNT PH6. 23:30 - 00:00 0.50 DRILL P LNRi PICKLE THE COILED TUBING REEL. 10/17/2009 00:00 - 00:30 0.50 DRILL P LNR1 PICKLE COIL TUBING REEL 00:30 - 02:00 1.50 DRILL P LNR1 SAFETY MEETING, RE: N2 SLOWDOWN OF REEL SLOWDOWN COILED TUBING WITH N2 02:00 - 04:30 2.50 DRILL P LNR1 SAFETY MEETING, RE: PULL BACK COIL CUT OFF CTC, INSTALL GRAPPLE, PULL COIL BACK, SECURE TO REEL SET INJECTOR ON RIG FLOOR. 04:30 - 06:00 1.50 BOPSU P LNR1 SAFETY MEETING, RE: BOP RAM CHANGE DRAIN STACK, CHANGE BOP RAMS FOR 2" COIL 06:00 - 06:15 0.25 BOPSU P LNR1 SAFETY MEETING AT CREW CHANGE FOR WORKING ON 06:15 - 08:30 2.25 BOPSU P LNR1 FINISH CHANGING RAMS, DRESS AND FILL STACK. 08:30 - 12:35 4.08 BOPSU P LNR1 BEGIN BOPE TEST. LOWER 2" COMBI FAIL LP TEST, C/O LOWER 2" COMBI, REPLACE DOOR SEALS 3 TIMES, Printed: 11/2/2009 2:55:27 PM ~ ~ BP EXPLORATION Page 10 of 16 .Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date. From - To Hours I Task .Code NPT Phase Description of Operations 10/17/2009 08:30 - 12:35 4.08 BOPSU P LNR1 START TESTING BOP BOP TEST WITNESS WAIVED BY LOU GRIMALDI, AOGCC 12:35 - 12:55 0.33 BOPSU P LNR1 SAFETY MEETING OVER SWAPING OUT REEL 12:55 - 14:00 1.08 BOPSU P LNR1 LOWER 2-3/8" REEL, PU 2" REEL 14:00 - 17:00 3.00 BOPSU P LNR1 RESUME BOP TESTING, SERVICED KILL VALVE 17:00 - 20:00 3.00 DRILL P LNR1 CHANGE OUT GRIPPER BLOCKS ON INJECTOR TO 2" 20:00 - 00:00 4.00 DRILL P LNR1 SAFETY MEETING, RE: PULL COIL ACROSS & C/O PACKOFFS. INSTALL GRAPPLE, PULL COIL ACROSS, MU STUFFING BOX TO INJECTOR, C/O PACKOFFS. 10/18/2009 00:00 - 01:00 1.00 DRILL P LNR1 FILL COIL REEL. PUMP SLACK BACK INTO THE REEL 01:00 - 01:45 0.75 DRILL P LNR1 SAFETY MEETING, RE: CUTTING COIL CUT 180' OF CT 01:45 - 04:30 2.75 DRILL P LNR1 PJSM THEN TEST ELINE. FAILED CONTINUITY TEST. TROUBLESHOOT ELINE. ELINE TEST IS GOOD. SAFETY MEETING, RE: MU CTC & BEHEAD MU KENDAL CTC, PULL TEST, BEHEAD ELINE, PRESSURE TEST 04:30 - 06:00 1.50 DRILL P LNR1 SAFETY MEETING, RE: PU BHA PU MILLING ASSY WITH MILL, STRING MILL, MOTOR, HYD JAR, 2 JNTS 2-1/16" CSH, & COILTRAK MHA. 06:00 - 10:00 4.00 DRILL P LNR1 OPEN EDC AND START RIH WITH MILLING ASSY, CIRC ~ 2.0 BPM / 2030 psi, CLOSE EDC ~ 2000' AND RIH 0.34 BPM / 656 PSI j 10:00 - 18:00 8.00 DRILL P LNR1 T; ,G BTM AT CIRC MIN RATE AT 12.130' (UNCORRECTED), PU AND BRING PUMPS UP TO 1.45 BPM (FS 1730), RIH TAG ~ 12,128', STALL, PU, ESTABLISH MILLING PATTERN AND TIME MILL THROUGH O-RING SUB, MILL AHEAD 20', MILL THROUGH FLOATS AT 12,148', MILL AHEAD 9', MILL THROUGH ALUMINUM GUIDE SHOE AND DRILL TO 12,172' BACK REAM THROUGH FLOAT EQUIPTMENT, DRY DRIFT DOWN. 18:00 - 20:00 2.00 DRILL P LNRi IR I ° 20:00 - 22:00 2.00 DRILL P LNRi PUMP HIGH VIS SWEEP & CIRCULATE BOTTOMS UP TWICE. ALL SAMPLES SHOW 100% CEMENT. 22:00 - 22:30 0.50 DRILL P LNR1 RIH, TAG ~ 12,174' MILL 1.6/1.6 BPM ~ 2300 PSI, FS=2030 PSI 0.5K-1.5K DHWOB, 10-30 FPH MILL TO 12179' 22:30 - 00:00 1.50 DRILL P LNRi POH 10/19/2009 00:00 - 02:00 2.00 DRILL P LNR1 POH 02:00 - 03:30 1.50 DRILL P LNRi SAFETY MEETING, RE: C/O BHA L/D COILTRAK MHA, 2 JNTS 2-1/16" CSH, HYD JAR, & MOTOR. MILL GAUGED 2.74" NO GO, 2.73" GO. PU COILTRAK DRLG BHA WITH 1.1 DEG AKO & HYC RAZOR EDGE BC BIT 03:30 - 05:15 1.75 DRILL P PRODi RIH 05:15 - 05:45 0.50 DRILL P PROD1 LOG TIE-IN. -10' CORRECTION. 05:45 - 06:25 0.67 DRILL P PROD1 RIH, WHILE CIRC MUD TO BIT, TAG BTM ~ 12,153', PU, TAG BTM AGAIN AT 12,153' 06:25 - 08:00 1.58 DRILL P PROD1 DRILL AHEAD FROM 12,153' Printetl: 77/2/2009 2:5527I'M ~ ~ BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/19/2009 06:25 - 08:00 1.58 DRILL P PROD1 1.67 / 1.69 BPM, 2985 psi, ECD 10.15 DHWOB 1.13k, ROP 30-50 fph DRILL TO 12,220' 08:00 - 10:00 2.00 DRILL P PROD1 PUH TO 12,130', OPEN EDC, POOH, CLOSE EDC 10:00 - 10:45 0.75 DRILL P PROD1 TAG UP, POP OFF INJECTOR, BREAK OFF AKO MTR (BIT GRADED 1,1,NO,A,X,I,NO,BHA) , LD COILTRACK STRING, MU RIBSTEER MTR TO COILTRACK 10:45 - 11:45 1.00 DRILL P PROD1 BHI CALIBRATION AND RE-PROGRAM COILTRACK STRING 11:45 - 12:15 0.50 DRILL P PROD1 PU BHA #11 W/ COILTRACK, RSM, HCC 2.70 x 3.00 BICENTER BIT, STAB ON INJ 12:15 - 14:25 2.17 DRILL P PROD1 RIH 14:25 - 14:50 0.42 DRILL P PROD1 LOG PIP TAG FOR TIE-IN, -15.5' CORRECTION 14:50 - 15:30 0.67 DRILL P PROD1 RIH TO 12,220' 15:30 - 18:30 3.00 DRILL P PROD1 DRILL AHEAD FROM 12 220' 1.61 / 1.65 BPM, FS 2820 psi 2948-3150 psi, ECD 10.12 DHWOB 3.04k, ROP 5-20 fph DRILL TO 12,280' 18:30 - 22:30 4.00 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.75/1.75 BPM ~ 3200 PSI, FS = 2950 PSI 1.2K-3.OK# DHWOB, 30-60 FPH, 92 DEG INC IA=O, OA=60, ECD=10.2, PVT=313 DRILL TO 12,400' 22:30 - 23:45 1.25 DRILL P PROD1 WIPER TRIP TO 9900'. SLOW PUMPS TO 0.5 BPM FROM 12,100'-12,170' THROUGH THE 3-3/16" SHOE. 23:45 - 00:00 0.25 DRILL P PROD1 LOG TIE-IN, +1' CORRECTION. 10/20/2009 00:00 - 00:45 0.75 DRILL P PROD1 WIPER TO TD 00:45 - 03:30 2.75 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.61 BPM IN / 1.64 BPM OUT ~ 3150 PSI, FS=2800 PSI 1.5K-2.OK# DHWOB, 50-90 FPH ROP, 90 DEG INC IA=70, OA=85, ECD=10.2, PVT=309 DRILL TO 12,550' 03:30 - 05:15 1.75 DRILL P PROD1 WIPER TO 9900'. 05:15 - 06:05 0.83 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.65/1.63 BPM ~ 3300 PSI, FS=2800 PSI 06:05 - 06:50 0.75 DRILL P PROD1 PU FOR BHA WIPER, 8K OVERPULLS OFF BTM, KEEP PUH WITH OVERPULLS OF 3-15K, WIPER INTO 3-3/16" LN R. 06:50 - 08:00 1.17 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.65 BPM IN / 1.66 BPM OUT ~ 3420 PSI, FS=2830 PSI 2.3K# DHWOB, 110 FPH ROP, 91 DEG INC IA=112, OA=90, ECD=10.25, PVT=305 08:00 - 08:50 0.83 DRILL P PROD1 PU AFTER DRILLED OFF, 15K OVERPULL COMING OFF BTM AND CONSTANT OVERPULLS WHILE PUH, STARTS TO PULL CLEAN BUT CANNOT RIH, KEEP PUH WITH STICKING, EVENTUALLY PULLS CLEAN, TURN AROUND AND RIH TO 12,708' 08:50 - 09:45 0.92 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.62 BPM IN / 1.63 BPM OUT ~ 3250 PSI, FS=2810 PSI 2.8-3.1K# DHWOB, 80-140 FPH ROP, 90 DEG INC IA=105, OA=86, ECD=10.2, PVT=299 F'flfltBO: 11/'L/'LUVy 1:~5:L/ F'M ~ ~ BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours ~ Task Code i NPT Phase Description of Operations 10/20/2009 08:50 - 09:45 0.92 DRILL P PROD1 STICKY ON BTM W/ REPEATED OVERPULLS OFF BTM DRILL TO 12,759' 09:45 - 12:00 2.25 DRILL P PROD1 WIPER TO TOL, DROP PUMPS FROM 12,265' TO 12,130' 12:00 - 12:10 0.17 DRILL P PROD1 LOG TIE IN AT 9885', +3.5' CORRECTION 12:10 - 12:50 0.67 DRILL P PROD1 RIH, DROP PUMPS 12,265' TO 12,130', RIH TO 12,759' 12:50 - 16:40 3.83 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.70 BPM IN / 1.71 BPM OUT ~ 3420 PSI, FS=3025 PSI 2.0-2.5K# DHWOB, 80-130 FPH ROP, 90-87 DEG INC IA=122, OA=71, ECD=10.31, PVT=294 STICKY ON BTM W/ REPEATED OVERPULLS OFF BTM DRILL TO 12,921' 16:40 - 17:40 1.00 DRILL P PROD1 WIPER UP TO 3-3/16" TBG TAIL, START MUD SWAP TO NEW GEO-VIS 17:40 - 18:50 1.17 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.55 BPM IN / 1.57 BPM OUT ~ 3240 PSI, FS=2720 PSI 2.5-2.8K# DHWOB, 115 FPH ROP, 87 DEG INC IA=95, OA=68, ECD=10.20, WIPER WHILE SWAPPING MUD 18:50 - 19:45 0.92 DRILL P PROD1 DRILL FROM 12947 E C FOR NOW.. 1.75 / 1.75 BPM ~ 2600-3000 PSI AFTER MUD SWAP. ROP IS 90-100 FT/HR. DRILL TO 12984 FT AND STACKING WT. PICKUP HAVE TO WORK BACK TO BOTTOM, STACKING WT OFF BOTTOM. DRILL TO 13020 FT. 19:45 - 23:25 3.67 DRILL P PROD1 WIPER TRIP FROM 13020 FT BACK TO 9500 FT. PERFORM CCL LOG FROM 9500 FT TO 9300 FT. TIE-IN DEPTH FROM 9875 FT, CORRECT +4 FT. CONTINUE WIPER TRIP TO BOTTOM. 23:25 - 00:00 0.58 DRILL P PROD1 DRILL FROM 13024 FT. CONTINUE HOLDING 89 DEG. 1.58 / 1.57 BPM ~ 2600-3000 PSI. ECD = 9.98 PPG. ROP IS 100-120 FT/HR WITH 2-3 KLBS DWOB. PVT = 319 BBLS. DRILL TO 13090 FT. 10/21/2009 00:00 - 00:15 0.25 DRILL P PROD1 CONTINUE DRILLING TO 13104 FT. NOT GETTING ENOUGH TURN RATE TO STAY IN THE POLYGON. 00:15 - 02:45 2.50 DRILL P PROD1 POOH FOR MOTOR CHANGE. 02:45 - 03:00 0.25 DRILL P PROD1 SAFETY MEETING. PJSM FOR CHANGE OUT BHA. 03:00 - 04:00 1.00 DRILL P PRODi TAG STRIPPER. L/D BHA #11. BIT IS LIKE NEW, WILL RE-RUN. FOUND A BOLT INSIDE THE BIT, FROM THE RSM. 04:00 - 05:15 1.25 DRILL P PROD1 M/U BHA #12 - 2.7 X 3.0 HCC BIT, 1 DEG MOTOR, FLOAT SUB, AGITATOR, 2.37" COILTRAK, TEST ON CATWALK. P/U BHA #12. 05:15 - 07:09 1.90 DRILL P PROD1 TEST TOOL AT SURFACE THEN RIH 07:09 - 07:27 0.30 DRILL P PROD1 LOG TIE-IN AT 9870', -15.5' CORRECTION 07:27 - 08:30 1.05 DRILL P PROD1 CONTINUE RIH, DROP PUMP RATE FROM 12,130' - 12,250' 08:30 - 09:50 1.33 DRILL P PROD1 DRILL SAG RIVER LATERAL TO 13,250 1.75 BPM IN / 1.76 BPM OUT ~ 3670 PSI, FS=3225 PSI 1.5-2.OK# DHWOB, 100-120 FPH ROP, 89-90 DEG INC IA=26, OA=72, ECD=10.21, PVT=314 09:50 - 11:24 1.57 DRILL P PROD1 WIPER TRIP FROM 13,250 UP TO 12,100' 11:24 - 13:00 1.60 DRILL P PROD1 DRILL SAG RIVER LATERAL Printed: 11/2/2009 2:55:27 PM • A BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 `Date From - To Hours Task Code NPT Phase Description of Operations 10/21/2009 11:24 - 13:00 1.60 DRILL P PROD1 1.75 BPM IN / 1.76 BPM OUT ~ 3595 PSI, FS=3350 PSI 1.5-1.9K# DHWOB, 110-140 FPH ROP, 90 DEG INC IA=54, OA=84, ECD=10.24, PVT=306 DRILL TO 13,400' 13:00 - 14:25 1.42 DRILL P PROD1 WIPER TRIP FROM 13,400' UP TO 12,100' 14:25 - 16:20 1.92 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.73 BPM IN / 1.75 BPM OUT ~ 3688 PSI, FS=3345 PSI 1.9-2.3K# DHWOB, 100-140 FPH ROP, 91-88 DEG INC IA=76, OA=88, ECD=10.24, PVT=301 DRILL TO 13,551' 16:20 - 18:00 1.67 DRILL P PROD1 WIPER TRIP FROM 13,551 TO 9,900' 18:00 - 18:30 0.50 DRILL P PROD1 TIE-IN LOG, CORRECT +4.5 FT. 18:30 - 20:00 1.50 DRILL P PROD1 CONTINUE WIPER TRIP TO BOTTOM. 20:00 - 21:30 1.50 DRILL P PROD1 DRILL FROM 13550 FT. HOLD 89 DEG INC FOR NOW. 1.72 / 1.73 BPM ~ 3500-3700 PSI. ECD = 10.29 PPG. INITIAL ROP IS 100 FT/HR WITH 1.86 KLBS DWOB. PVT = 293 BBLS. 8.61 / 8.61 PPG. AFTER 13600 FT GO TO 90 DEG TO GET HIGHER IN THE SAG, AS PER GEO. STARTING TO STACK WT WITH DIFFICULT SLIDING. 21:30 - 00:00 2.501 DRILL N WAIT i PROD1 10/22/2009 100:00 - 10:00 I 10.001 DRILL I N I WAIT I PROD1 10:00 - 10:45 0.751 DRILL N WAIT PROD1 10:45 - 14:00 3.251 DRILL ~ N ~ WAIT ~ PROD1 14:00 - 14:20 i 0.331 DRILL ~ P ~ i PROD1 14:20 - 15:10 0.83 DRILL N SFAL PRODi 15:10 - 15:20 0.17 DRILL P PROD1 15:20 - 15:30 0.17 DRILL P PROD1 15:30 - 16:45 1.25 DRILL P PROD1 CH2 DISPATCH IS NOT SENDING OUT ANY MORE FLUID TRUCKS DUE TO WEATHER IN DEADHORSE, DESPITE BEING STILL IN PHASE 2. SO CAN'T GET ANY NEW MUD OUT OR MINERAL OIL IF NEEDED. DECISION IS MADE TO PULL UP TO 9400 FT AND CIRCULATE. CONTINUE WAIT ON WEATHER. CH2 STILL NOT DISPATCHING TRUCKS. WIND IS 44-60 MPH AT 0400. WAIT ON CONFIRMATION FROM TOWN REGARDING EMERGENCY RESPONSE AVAILABILITY. RIG HAND NOTICES LINE FOR DERRICK CLIMBER HAS COME LOOSE CAUSING THE CLIMBER WEIGHT TO SWING AROUND ABOVE RIG FLOOR. FLAGGED OFF RIG FLOOR AND EVALUATED POTENTIONAL HAZARD IF WEIGHT COMES LOOSE. HAVE PJSM TO SEND 2 HANDS UP ON ROOF TO EVALUATE CAUSE AND RESECURE CLIMBER LINE. RECONNECTED TURNBUCKLE ON THE LINE AND PUT IN PIN TO PREVENT TURNBUCKLE FROM BACKING OUT AGAIN. CONTINUE TO WOW UNTIL FUEL ARRIVES AND WHILE STATUS OF EMERGENCY RESPONSE IS VERIFIED. FUEL & H2O ON LOC AT 01:15. TOWN CONFIRMS OK TO OPERATE. PJSM REGARDING WORKING IN PHZ 2 AND OPERATIONAL PLAN FORWARD. SLB HAND NOTICES DRIP FROM 1502 IN REEL. LOCK OUT REEL, REPAIR. ATTEMPT TO PT HARDLINE, DISCOVER CHICKSAN IS LEAKING NOT THE UNION. RIH TO TIE-IN AT 9850' LOG TIE-IN, -1' CORRECTION RIH TO 13,660', LOW RATE FROM 12,120' TO 12,260' F'flflt@tl: 11/'L'LUUy 1:55:L/ YM BP EXPLORATION Page 14 of 16 Operations Summary. Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/22/2009 16:45 - 18:55 2.17 DRILL P PROD1 DRILL SAG RIVER LATERAL 1.62 BPM IN / 1.63 BPM OUT ~ 3820 PSI, FS=3420 PSI 1.9-2.3K# DHWOB, 90-110 FPH ROP, 92 DEG INC IA=O, OA=55, ECD=10.51, PVT=277 OCCASIONAL WT STACKING WHILE DRILLING. CHECK ON CH2 TRUCK STATUS AT CREW CHANGE, JUST GETTING GOING AGAIN, NO TRUCKS AVAILABLE TO GET LINER FROM STORES. DRILL TO 13,800 FT. 18:55 - 22:25 3.50 DRILL P PROD1 WIPER TRIP TO 9800 FT. CLEAN PASS UP AND DOWN. 22:25 - 00:00 1.58 DRILL P PROD1 DRILL FROM 13800 FT. REDUCE INC TO 89 DEG. 1.64 / 1.65 BPM ~ 3500-3800 PSI. ROP IS 100-120 FT/HR WITH 1-2 KLBS DWOB. FREQUENT WT STACKING AND PICKUPS WHILE DRILLING. 10/23/2009 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUE DRILLING TO 13931 FT. 00:30 - 02:35 2.08 DRILL P PROD1 WIPER TRIP FROM 13,931 FT TO 12,000 FT. CLEAN PASS UP AND DOWN. 02:35 - 04:10 1.58 DRILL P PROD1 DRILL FROM 13,930 FT. CONTINUE HOLDING 89 DEG TO TD. 1.55 / 1.54 BPM ~ 3500-3800 PSI. ROP IS 100-120 FT/HR WITH 1-2 KLBS DWOB. PVT = 250 BBLS, ECD = 10.53 PPG. D I DRILL TO 14.000 FT. CALL TD THERE. 04:10 - 06:30 2.33 DRILL P PROD1 WIPER TRIP TO 9800 FT. 06:30 - 06:40 0.17 DRILL P PROD1 LOG TIE-IN @ 9,895', +1.5' CORRECTION 06:40 - 08:15 1.58 DRILL P PROD1 RIH, TAG TD ~ 14,000.2' 08:15 - 11:15 3.00 DRILL P PROD1 POOH LAYING IN LINER PILL, PJSM FOR LAYING IN LINER PILL 11:15 - 12:15 1.00 DRILL P PROD1 TAG UP, POP OFF, STAND INJECTOR ON LEGS, BREAK OFF BIT, MTR, AGITATOR AND HOT, LD COILTRACK ASSY. 12:15 - 12:30 0.25 CASE C RUNPRD PJSM FOR LOADING LINER AND PREPING RIG FLOOR TO RUN LNR. 12:30 - 15:00 2.50 CASE C RUNPRD PREP RIG FLOOR, LOAD LINER INTO PIPE SHED, STEAM, DRIFT & STRAP LINER. 15:00 - 15:20 0.33 CASE C RUNPRD PJSM FOR RUNNING LINER 15:20 - 18:00 2.67 CASE C RUNPRD MU INDEXING GUIDE SHOE, 1 JT 2-3/8" STL LNR, O-RING SUB, 54 JTS 2-3/8" STL SLOTTED LINER, 6 JTS 2-3/8" STL LNR, DEPLOYMENT SLEEVE, 3" GS PUMP OFF SPEAR, DBPV, 2-3/8" COILTRACK. BHA OAl = 1959.4 FT. 18:00 - 18:40 0.67 CASE C RUNPRD CREW CHANGE. SAFETY MEETING. PJSM FOR MOVING TONGS INTO STABBING BOX AND RUNNING REST OF LINER. REVIEW LINER RUNNING PROCEDURE AND HAZARDS. 18:40 - 21:00 2.33 CASE C RUNPRD SET FARR TONGS IN STABBING BOX AND RUN REMAINING LINER. 21:00 - 21:25 0.42 CASE C RUNPRD MAKE UP INJECTOR TO WELL. SURFACE TEST TOOL. OPEN EDC. 21:25 - 00:00 2.58 CASE C RUNPRD ESTABLISH CIRCULATION 0.35 BPM / 1050 PSI AND RIH. LOG GR TIE-IN AT RA TAG. UP WT IS 32K. Pnntetl: 11/L/ZUUB "L:S~:L/ YM • BP EXPLORATION Page 15 of 16 Operations Summary, Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To i Nours Task Code NPT Phase Description of Operations 10/23/2009 21:25 - 00:00 2.58 CASE C RUNPRD CORRECT -12 FT. CONTINUE RIH. 10/24/2009 00:00 - 00:25 0.42 CASE C RUNPRD CONTINUE RUNNING LINER TO BOTTOM. TAG AT 14003 FT UP WT IS 34K. PICK UP AND TAG 2 MORE TIMES, SAME SPOT. 00:25 - 00:30 0.08 CASE C RUNPRD STACK 3K DOWN AND CLOSE EDC. PUMP 1.43 BPM ~ 3400 PSI AND PICKUP, NEW UP WT IS 29K. AT 0.3 BPM UP WT IS 30K. APPEAR TO HAVE PUMPED OFF LINER. 00:30 - 02:30 2.00 CASE C RUNPRD POOH. 02:30 - 02:45 0.25 CASE C RUNPRD SAFETY MEETING. PJSM FOR L/D COILTRACK BHA AND PUMPING SLACK OUT OF CT. 02:45 - 03:20 0.58 CASE C RUNPRD TAG STRIPPER AND OPEN CT RISER. REMOVE BHI CABLE HEAD AND BOOT CABLE. L/D COILTRAK BHA. 03:20 - 04:00 0.67 CASE N LNR1 M/U 1 JT 2-3/8" PH-6 AND GET ON WELL. PUMP SLACK FORWARD OUT OF CT. BREAK OFF CT RISER AND TRIM 120 FT OF CABLE. 04:00 - 04:30 0.50 BOPSU N LNR1 FUNCTION TEST BOPS 04:30 - 05:00 0.50 CASE N LNR1 INSTALL BTT GRAPPLE CONNECTOR. PULL TEST TO 35K AND PT TO 4000 PSI, GOOD. 05:00 - 05:45 0.75 CASE N LNR1 M/U BHA #14 -LINER TOP PACKER, 3/4" DISCONNECT, 3 JTS OF PH-6. 05:45 - 07:05 1.33 CASE N DPRB LNR1 RIH, PRESSURES UP, CANNOT CIRCULATE, POOH 07:05 - 08:00 0.92 CASE N DPRB LNR1 POOH 08:00 - 08:45 0.75 CASE N DPRB LNR1 POP OFF WELL AND MOVE INJ OVER BUNG HOLE, CIRC AT 0.1 BPM/813 PSI. LD 3 JTS OF PH6, BREAK OFF LTP AND DISCO, FLUSH WITH H2O. RECOVER SEVERAL CEMENT NODULES AND A WELL WORN 5/8" STEEL BALL. 08:45 - 09:45 1.00 CASE N DPRB LNR1 PU 5' STINGER AND NOZZLE, STAB ON WELL AND PUMP HIGH RATE, NO NOTICEABLE DEBRIS ACROSS SHAKERS. 09:45 - 10:15 0.50 CASE N DPRB LNR1 POP OFF WELL, LD NOZZLE ASSY, PU BOT XO, 1 JT PH6, XO, BALL CATCHER, STAB ON WELL 10:15 - 11:15 1.00 CASE N DPRB LNR1 CIRC AT 0.34 BPM/930 PSI, PJSM FOR DROPPING 3/4" BALL, DROP 3/4" STEEL BALL, LAUNCH C~ 600 PSI, CHASE AT 2.8 BPM, HEAR BALL ROLL, STOP HEARING BALL AT 32 BBLS AWAY (REEL VOL 42 BBLS), CONT PUMPING TILL 45 BBLS. 11:15 - 11:30 0.25 CASE N DPRB LNR1 POP OFF WELL, BREAK OFF CATCHER, RECOVER 3/4" BALL 11:30 - 12:35 1.08 CASE N DPRB LNR1 MU LTP SETTING BHA, STAB ON INJECTOR _ 12:35 - 15:12 2.62 CASE N DPRB LNR1 RIH W/ BOT CTC, XO, 3 JTS 2-3/8" PH6, XO, 3/4" DISCO, GH RUNNING TOOL, 4-1/2" KB PACKER, 1 JT 2-7/8" STL LNR, LOCATOR, SEAL ASSY. TOTAL BHA LENGTH = 141.97' CIRC AT 0.11 BPM / 980 PSI 15:12 - 16:05 0.88 CASE N DPRB LNR1 PERFORM WT CHK ~ 9300', 30K SEE SEALS GO IN LINER ~ 9460' (UNCORRECTE41 STACK 5K DOWN ON LTP PT LINER LAP TIME PRESSURE 0 2029 5 1974 10 1941 Printed: 11/2/2009 2:55:27 PM BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: 06-18 Common Well Name: 06-18 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 9/17/2009 End: 10/25/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/25/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/24/2009 15:12 - 16:05 0.88 CASE N DPRB LNR1 15 1919 20 1904 25 1890 30 1879 LOST 150 PSI, PASS 16:05 - 18:35 2.50 CASE N DPRB LNR1 POOH CIRC ACROSS THE TOP. HOLD 200-300 PSI WHP WHILE POOH. 18:35 - 18:50 0.25 CASE N DPRB LNR1 SAFETY MEETING. PJSM FOR UD BHA AND P/U 1.25" CSH. 18:50 - 19:50 1.00 CASE N DPRB LNR1 TAG STRIPPER AND UD 3 JTS OF PH-6 AND LTP RUNNING TOOLS. OFFLOAD BTT TOOLS FROM RIG. 19:50 - 20:10 0.33 RIGD P LNRi PREP RIG FLOOR FOR RUNNING 1.25" CSH. WILL BE RUN IN WELL AND LAID DOWN AS SINGLES. 20:10 - 00:00 3.83 RIGD P LNR1 RUN 45 STDS 1.25" CSH AND LAY DOWN AS SINGLES. 10/25/2009 00:00 - 01:00 1.00 RIGD P LNR1 CONTINUE UD CSH SINGLES. 01:00 - 02:00 1.00 WHSUR P POST PICK UP INJECTOR, CUT OFF CABLE AND RE-BOOT. M/U NOZZLE AND DBPV FOR FREEZE PROTECT. 02:00 - 03:00 1.00 WHSUR P POST RIH. PJSM WITH LRS FOR PUMPING DIESEL WHILE RIH. STOP AT 2200 FT AND FLUSH SURFACE LINES WITH WATER. START DIESEL DOWN CT. 03:00 - 03:30 0.50 WHSUR P POST POOH PUMP DIESEL 1:1. STOP AT 500 FT AND PUMP DIESEL TO SURFACE, THEN POOH NO PUMP. 03:30 - 03:50 0.33 WHSUR P POST TAG STRIPPER. UD FREEZE PROTECT BHA. PJSM THEN VALV CREW GREASE SWAB, SSV, AND MASTER VALVE. 03:50 - 04:10 0.33 WHSUR P POST PJSM THEN SET BPV WITH T-BAR. 04:10 - 06:00 1.83 WHSUR P POST OFFLOAD 1.25" CSH AND EXCESS LINER. PUSH FLUID OUT OF DOWNHOLE END OF CT WITH AIR. RIG UP PUMP TO REMOVE ALL FLUID FROM STACK. BLOW DOWN RIG LINES. 06:00 - 11:00 5.00 WHSUR P POST NIPPLE DOWN BOPE, CLEAN PITS, SECURE RIG FOR RIG MOVE TEST TREE CAP. RELEASE RIG ~ 11:00 10/23/2009. TOTAL TIME 22 DAYS AND 13 HRS Printetl: 11/2/2009 2:55:27 PM • r~~r BAR 1'1'~~ INTE(~ North America -ALASKA - BP Prudhoe Bay PB DS 06 06-18 -Slot 18 06-18A Survey: MWD Survey Report -Geographic 23 October, 2009 by ~.r ' Survey Report -Geographic iNTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference Project: Prudhoe Bay TVD Reference: Site: PB DS 06 MD'Reference: Well: 06-18 North. Reference: Wellbore: 06-18A Survey Calculation Method: Design: 06-18A Database: Well 06-18 -Slot 18 Orig rig on 06-18 @ 74.OOft (Orig rig on 06-18) Orig rig on 06-18 @ 74.OOft (Ortg rig on 06-18) True Minimum Curvature EDM .16 - Anc Prod - WH24P 'roject Prudhoe Bay, North Slope, UNITED STATES Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor .Site PB DS O6, TR-10-14 . Site Position: Northing: 5,941,880.59ft Latitude: 70° 14' 46.529 N ~~ From: Map Easting: 684,674.88ft Longitude: 148° 30' 29.224 W' Position Uncertainty: 0.00 ft Slot Radius: O.000in Grid Convergence: 1.40 ° ;.Well 06-18 API No 500292076700 ~ Well Position +N/-S 0.00 ft Northing: 5,940,715.47 ft Latitude: ~ +E/-W O.OOft Easting: 686,109.25ft Longitude: ~ Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: Wellbore 06-18A API No 500292076701 Magnetics Model Name Sample Date Declitnation a~ Dip Angle (°) BGGM2008 5/14/2009. l . 22.78 80.90 70° 14' 34.725 N li 148° 29' 48.364 W ~i 0.00 ft i Field Strength (nT) 57.711 Design 06-18A i Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) lft1 37.00 r _ - _-- Survey Program Date: 10/23/2009 From To (ft) (ft) Survey (Wellbore) I~ 100.00 9,800.00 1 : Camera based gyro multisho (06-18) ', 9,863.50 14,000.00 MWD (06-18A) +N/S (ftl 0.00 Tie On Depth: 9,800.00 +E/-W Direction fft) (°) 0.00 120.36 Toot Name Description CB-GYRO-MS Camera based gyro multishot MWD MWD -Standard 10232009 1:56:45PM Page 2 COMPASS 2003.16 Build 71 ~ • Ai%~ Survey Report -Geographic by IIVTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 06-18 -Slot 18 Project: Prudhoe Bay TVD Reference::: Orig rig on 06-18 cGil 74.OOft (Orig rig on 06-18) Site: PB DS 06 MD Reference: Orig rig on 06-18 @ 74.OOft (Orig rig on 06-18) Well: 06-18 North Rdferencet True Wellbore: 06-18A Survey-Calculation Method: Minimum Curvature Design: 06-18A Database: EDM .16 - Anc Prod - WH24P ,Survey Measured Depth Inclination Azimuth 9,800.00 TIP 9,863.50 KOP 9,886.71 9,919.75 9,949.75 9,980.91 10,011.07 10,040.99 10,065.17 10,095.45 10,125.03 10,156.15 10,185.01 10,214.63 10,245.91 10,274.57 10,304.63 10,336.07 10,366.57 10,398.71 10,429.71 10,459.69 10,489.63 10,519.98 10,549.70 10,581.10 10,609.80 10,640.54 10,671.66 10,700.96 10,729.96 10,760.08 10,790.28 10,822.00 10,850.32 10,902.70 10,933.36 10,964.18 11,002.92 11,033.10 11,060.64 11,093.08 11,126.82 11,160.52 11,190.26 11,224.60 11,254.98 11,294.36 11,328.94 11,358.98 11,388.94 11,409.06 11,441.52 28.00 124.00 Vertical " - Map Depth +N/-S +Ef-W NortMtng (ft) {ftj (~) (ft) 8,557.98 -2,354.49 3,108.37 5,938,438.59 Map Fasting (ft) Latitude Longitude 689,274.61 70° 14' 11.563 N 148° 28' 18.025 W 28.00 125.27 8,614.05 -2,371.43 3,132.89 5,938,422.26 689,299.55 70° 14' 11.396 N 148° 28' 17.312 W 30.55 125.38 8,634.29 -2,377.99 3,142.15 5,938,415.93 689,308.96 70° 14' 11.331 N 148° 28' 17.043 W 41.66 125.38 8,660.94 -2,389.25 3,158.00 5,938,405.07 689,325.09 70° 14' 11.221 N 148° 28' 16.583 W 51.41 117.20 8,681.57 -2,400.41 3,176.62 5,938,394.36 689,343.97 70° 14' 11.111 N 148° 28' 16.042 W 60.98 113.41 8,698.89 -2,411.42 3,200.01 5,938,383.94 689,367.63 70° 14' 11.002 N 148° 28' 15.362 W 72.10 117.21 8,710.89 -2,423.26 3,224.96 5,938,372.71 689,392.86 70° 14' 10.886 N 148° 28' 14.637 W 83.63 119.33 8,717.17 -2,437.10 3,250.68 5,938,359.51 689,418.91 70° 14' 10.750 N 148° 28' 13.890 W 93.13 120.86 8,717.85 -2,449.21 3,271.56 5,938,347.93 689,440.09 70° 14' 10.630 N 148° 28' 13.283 W 99.19 126.17 8,714.60 -2,465.81 3,296.65 5,938,331.95 689,465.57 70° 14' 10.467 N 148° 28' 12.554 W 96.61 126.74 8,710.53 -2,483.22 3,320.21 5,938,315.13 689,489.55 70° 14' 10.296 N 148° 28' 11.870 W 96.34 126.61 8,707.02 -2,501.69 3,345.01 5,938,297.28 689,514.80 70° 14' 10.114 N 148° 28' 11.149 W 96.24 126.79 8,703.86 -2,518.83 3,368.01 5,938,280.71 689,538.22 70° 14' 9.945 N 148° 28' 10.481 W 96.80 128.47 8,700.50 -2,536.80 3,391.32 5,938,263.33 689,561.96 70° 14' 9.768 N 148° 28' 9.804 W 96.42 128.62 8,696.90 -2,556.16 3,415.62 5,938,244.57 689,586.73 70° 14' 9.578 N 148° 28' 9.098 W 96.18 128.14 8,693.75 -2,573.85 3,437.95 5,938,227.44 689,609.49 70° 14' 9.404 N 148° 28' 8.449 W 95.69 127.94 8,690.64 -2,592.27 3,461.50 5,938,209.61 689,633.48 70° 14' 9.223 N 148° 28' 7.765 W 96.24 127.90 8,687.38 -2,611.49 3,486.16 5,938,191.01 689,658.62 70° 14' 9.033 N 148° 28' 7.048 W 96.24 127.66 8,684.06 -2,630.06 3,510.13 5,938,173.03 689,683.03 70° 14' 8.851 N 148° 28' 6.352 W 96.52 128.20 8,680.49 -2,649.70 3,535.32 5,938,154.03 689,708.70 70° 14' 8.657 N 148° 28' 5.620 W 96.43 127.86 8,676.99 -2,668.67 3,559.58 5,938,135.65 689,733.42 70° 14' 8.471 N 148° 28' 4.915 W 96.52 127.77 8,673.61 -2,686.94 3,583.12 5,938,117.98 689,757.40 70° 14' 8.291 N 148° 28' 4.232 W 96.77 127.66 8,670.15 -2,705.13 3,606.64 5,938,100.37 689,781.36 70° 14' 8.112 N 148° 28' 3.548 W 96.43 127.33 8,666.66 -2,723.48 3,630.56 5,938,082.62 689,805.73 70° 14' 7.931 N 148° 28' 2.853 W 96.49 127.11 8,663.32 -2,741.34 3,654.08 5,938,065.34 689,829.67 70° 14' 7.756 N 148° 28' 2.170 W 96.47 126.97 8,659.77 -2,760.14 3,678.98 5,938,047.17 689,855.03 70° 14' 7.571 N 148° 28' 1.447 W 96.36 126.88 8,656.57 -2,777.27 3,701.78 5,938,030.61 689,878.25 70° 14' 7.402 N 148° 28' 0.784 W 96.46 126.23 8,653.13 -2,795.47 3,726.32 5,938,013.03 689,903.23 70° 14' 7.223 N 148° 28' 0.071 W 94.54 126.07 8,650.15 -2,813.74 3,751.33 5,937,995.38 689,928.68 70° 14' 7.043 N 148° 27' 59.345 W 93.66 126.04 8,648.06 -2,830.94 3,774.96 5,937,978.77 689,952.72 70° 14' 6.874 N 148° 27' 58.658 W 92.95 125.36 8,646.39 -2,847.83 3,798.47 5,937,962.46 689,976.64 70° 14' 6.708 N 148° 27' 57.975 W 93.07 125.92 8,644.80 -2,865.36 3,822.91 5,937,945.54 690,001.51 70° 14' 6.535 N 148° 27' 57.265 W 94.09 125.61 8,642.92 -2,882.98 3,847.37 5,937,928.54 690,026.39 70° 14' 6.362 N 148° 27' 56.555 W 93.32 124.81 8,640.87 -2,901.23 3,873.23 5,937,910.93 690,052.70 70° 14' 6.182 N 148° 27' 55.804 W 93.28 125.69 8,639.24 -2,917.54 3,896.32 5,937,895.19 690,076.18 70° 14' 6.021 N 148° 27' 55.133 W 91.44 126.92 8,637.08 -2,948.53 3,938.50 5,937,865.26 690,119.10 70° 14' 5.716 N 148° 27' 53.908 W 91.32 126.91 8,636.34 -2,966.94 3,963.00 5,937,847.46 690,144.05 70° 14' 5.535 N 148° 27' 53.196 W 90.86 126.74 8,635.76 -2,985.41 3,987.67 5,937,829.61 690,169.17 70° 14' 5.354 N 148° 27' 52.479 W 89.72 126.04 8,635.56 -3,008.39 4,018.85 5,937,807.40 690,200.91 70° 14' 5.127 N 148° 27' 51.573 W 89.14 125.53 8,635.86 -3,026.04 4,043.33 5,937,790.36 690,225.82 70° 14' 4.954 N 148° 27' 50.862 W 89.60 124.76 8,636.16 -3,041.89 4,065.85 5,937,775.07 690,248.72 70° 14' 4.798 N 148° 27' 50.208 W 89.45 124.01 8,636.43 -3,060.21 4,092.62 5,937,757.42 690,275.93 70° 14' 4.617 N 148° 27' 49.430 W 89.66 125.17 8,636.69 -3,079.36 4,120.40 5,937,738.96 690,304.17 70° 14' 4.429 N 148° 27' 48.624 W 87.67 125.39 8,637.48 -3,098.82 4,147.90 5,937,720.19 690,332.14 70° 14' 4.237 N 148° 27' 47.825 W 88.47 125.79 8,638.48 -3,116.12 4,172.07 5,937,703.49 690,356.73 70° 14' 4.067 N 148° 27' 47.123 W 88.49 124.94 8,639.39 -3,135.99 4,200.06 5,937,684.33 690,385.20 70° 14' 3.871 N 148° 27' 46.309 W 88.59 126.63 8,640.17 -3,153.75 4,224.70 5,937,667.18 690,410.27 70° 14' 3.697 N 148° 27' 45.594 W 87.79 126.58 8,641.41 -3,177.22 4,256.29 5,937,644.50 690,442.43 70° 14' 3.466 N 148° 27' 44.676 W 88.00 126.82 8,642.68 -3,197.87 4,284.00 5,937,624.54 690,470.64 70° 14' 3.262 N 148° 27' 43.871 W 88.62 127.75 8,643.57 -3,216.06 4,307.89 5,937,606.95 690,494.97 70° 14' 3.083 N 148° 27' 43.177 W 88.59 128.35 8,644.30 -3,234.52 4,331.48 5,937,589.08 690,519.00 70° 14' 2.902 N 148° 27' 42.492 W 88.65 127.43 8,644.78 -3,246.87 4,347.35 5,937,577.12 690,535.17 70° 14' 2.780 N 148° 27' 42.031 W 88.71 125.78 8,645.53 -3,266.22 4,373.40 5,937,558.42 690,561.69 70° 14' 2.590 N 148° 27' 41.274 W 10!23/2009 1:56:45PM Page 3 COMPASS 2003.16 Build 71 ~~~ ""°'~ Survey Report -Geographic 1NTEQ Company: North America -ALASKA - BP `Local Co-ordinate Reference: .Project: Prudhoe Bay TVD Reference: Site: PB DS 06 MD Reference: We@: 06-18 North Reference: Wellbore: 06-18A Survey Calculation Method: Design: 06-18A Database: Survey Measured Vertical Depth Inclination Azimuth Depth +N/-S (ft) (°) (°) ift) (ft) 11,470.84 11,499.36 11,529.16 11,559.12 11,588.94 11,618.92 11,650.52 11,686.74 11,723.58 11,752.54 11,779.72 11,808.90 11,839.22 11,872.22 11,899.02 11,933.80 11,959.24 11,989.18 12,029.26 12,059.08 12,089.02 12,100.00 2-3/8" 12,119.12 12,147.81 12,147.84 12,179.13 12,210.34 12,240.78 12,267.58 12,299.06 12,329.66 12,359.88 12,389.76 12,420.14 12,450.10 12,479.92 12,510.02 12,540.20 12,570.38 12,600.16 12,630.18 12,660.20 12,697.50 12,734.74 12,769.12 12,805.62 12,835.48 12,870.38 12,899.80 12,930.12 12,960.00 12,990.08 13,021.00 13,050.30 88.62 125.68 8,646.21 -3,283.34 88.56 125.93 8,646.91 -3,300.02 87.54 126.07 8,647.93 -3,317.52 87.48 125.94 8,649.23 -3,335.12 87.64 125.64 8,650.50 -3,352.54 87.98 125.43 8,651.64 -3,369.95 87.67 125.73 8,652.84 -3,388.33 87.67 125.71 8,654.32 -3,409.45 87.48 125.23 8,655.87 -3,430.81 87.57 125.39 8,657.12 -3,447.54 88.13 125.95 8,658.14 -3,463.37 89.17 125.67 8,658.83 -3,480.44 89.51 124.46 8,659.18 -3,497.86 89.51 123.32 8,659.46 -3,516.26 89.48 122.65 8,659.70 -3,530.85 89.72 121.68 8,659.94 -3,549.36 89.17 122.48 8,660.19 -3,562.87 88.34 125.18 8,660.84 -3,579.54 87.39 122.91 8,662.33 -3,601.96 86.99 125.73 8,663.80 -3,618.75 85.66 126.00 8,665.71 -3,636.25 85.27 126.31 8,666.58 -3,642.71 +E1-W (~j 4,397.20 4,420.32 4,444.41 4,468.63 4,492.79 4,517.17 4,542.85 4,572.24 4,602.21 4,625.82 4,647.89 4,671.54 4,696.36 4,723.75 4,746.23 4,775.67 4,797.23 4,822.09 4,855.27 4,879.87 4,904.08 4,912.92 Map Northing (ft) 5,937,541.90 5,937,525.79 5,937,508.89 5,937,491.90 5,937,475.08 5,937,458.27 5,937,440.54 5,937,420.15 5,937,399.54 5,937,383.40 5,937,368.11 5,937,351.64 5,937,334.84 5,937,317.12 5,937,303.09 5,937,285.31 5,937,272.34 5,937,256.29 5,937,234.70 5,937,218.52 5,937,201.62 5,937,195.39 • by Well 06-18 -Slot 18 Orig rig on 06-18 @ 74.OOft (Orig rig on 06-18) Orig rig on 06-18 ~ 74.OOft (Orig rig on 06-18) True Minimum Curvature EDM .16 - Anc Prod - WH24P Map Fasting (ft) 690,585.90 690,609.43 690,633.95 690,658.58 690,683.17 690,707.97 690,734.10 690,763.99 690,794.48 690,818.50 690,840.95 690,865.02 690,890.25 690,918.09 690,940.92 690,970.81 690,992.69 691,017.95 691,051.68 691,076.68 691,101.32 691,110.31 Latitude 70° 14' 2.421 N 70° 14' 2.257 N 70° 14' 2.085 N 70°14'1.911N 70° 14' 1.740 N 70° 14' 1.569 N 70° 14' 1.388 N 70° 14' 1.180 N 70° 14' 0.970 N 70° 14' 0.805 N 70° 14' 0.649 N 70° 14' 0.481 N 70°14'0.310N 70° 14' 0.128 N 70° 13' 59.985 N 70° 13' 59.803 N 70° 13' 59.670 N 70° 13' 59.505 N 70° 13' 59.285 N 70° 13' 59.119 N 70° 13' 58.947 N 70° 13' 58.884 N Longitude 148° 27' 40.583 W 148° 27' 39.911 W 148° 27' 39.212 W 148° 27' 38.508 W 148° 27' 37.806 W 148° 27' 37.098 W 148° 27' 36.352 W 148° 27' 35.499 W 148° 27' 34.628 W 148° 27' 33.942 W 148° 27' 33.301 W 148° 27' 32.614 W 148° 27' 31.893 W 148° 27' 31.098 W 148° 27' 30.445 W 148° 27' 29.590 W 148° 27' 28.964 W 148° 27' 28.241 W 148° 27' 27.278 W 148° 27' 26.563 W 148° 27' 25.860 W 148° 27' 25.603 W 84.59 126.86 8,668.27 -3,654.06 4,928.21 5,937,184.42 691,125.88 70° 13' 58.772 N 148° 27' 25.159 W 84.13 125.00 8,671.09 -3,670.82 4,951.33 5,937,168.24 691,149.40 70° 13' 58.607 N 148° 27' 24.488 W 84.13 124.99 8,671.09 -3,670.83 4,951.35 5,937,168.22 691,149.42 70° 13' 58.607 N 148° 27' 24.487 W 85.39 117.32 8,673.96 -3,686.94 4,978.00 5,937,152.78 691,176.46 70° 13' 58.448 N 148° 27' 23.713 W 88.86 116.71 8,675.52 -3,701.10 5,005.76 5,937,139.31 691,204.56 70° 13' 58.309 N 148° 27' 22.906 W 91.44 116.54 8,675.44 -3,714.74 5,032.97 5,937,126.35 691,232.10 70° 13' 58.174 N 148° 27' 22.116 W 92.36 116.47 8,674.55 -3,726.69 5,056.94 5,937,114.99 691,256.35 70° 13' 58.057 N 148° 27' 21.420 W 91.63 117.04 8,673.46 -3,740.85 5,085.04 5,937,101.53 691,284.79 70° 13' 57.917 N 148° 27' 20.604 W 92.24 116.95 8,672.42 -3,754.74 5,112.29 5,937,088.33 691,312.37 70° 13' 57.781 N 148° 27' 19.812 W 91.84 117.50 8,671.35 -3,768.55 5,139.14 5,937,075.18 691,339.56 70° 13' 57.644 N 148° 27' 19.032 W 90.86 118.33 8,670.64 -3,782.54 5,165.54 5,937,061.85 691,366.29 70° 13' 57.507 N 148° 27' 18.265 W 89.79 118.49 8,670.47 -3,796.99 5,192.26 5,937,048.06 691,393.35 70° 13' 57.364 N 148° 27' 17.489 W 89.39 118.53 8,670.69 -3,811.29 5,218.58 5,937,034.42 691,420.02 70° 13' 57.224 N 148° 27' 16.725 W 89.51 118.50 8,670.97 -3,825.52 5,244.78 5,937,020.83 691,446.57 70° 13' 57.083 N 148° 27' 15.964 W 89.60 117.89 8,671.21 -3,839.75 5,271.31 5,937,007.27 691,473.44 70° 13' 56.943 N 148° 27' 15.193 W 89.75 117.68 8,671.38 -3,853.81 5,298.01 5,936,993.87 691,500.47 70° 13' 56.805 N 148° 27' 14.417 W 90.40 117.18 8,671.34 -3,867.72 5,324.80 5,936,980.63 691,527.59 70° 13' 56.668 N 148° 27' 13.639 W 90.74 116.49 8,671.04 -3,881.16 5,351.37 5,936,967.85 691,554.49 70° 13' 56.536 N 148° 27' 12.868 W 91.20 115.94 8,670.53 -3,894.42 5,378.30 5,936,955.26 691,581.73 70° 13' 56.405 N 148° 27' 12.085 W 91.11 116.16 8,669.93 -3,907.60 5,405.26 5,936,942.75 691,609.01 70° 13' 56.275 N 148° 27' 11.302 W 90.49 116.23 8,669.41 -3,924.06 5,438.73 5,936,927.12 691,642.87 70° 13' 56.113 N 148° 27' 10.330 W 90.25 116.26 8,669.17 -3,940.53 5,472.13 5,936,911.48 691,676.67 70° 13' 55.951 N 148° 27' 9.360 W 90.09 113.99 8,669.07 -3,955.13 5,503.25 5,936,897.66 691,708.14 70° 13' 55.807 N 148° 27' 8.456 W 88.52 114.48 8,669.51 -3,970.11 5,536.53 5,936,883.51 691,741.78 70° 13' 55.659 N 148° 27' 7.489 W 87.29 114.14 8,670.60 -3,982.39 5,563.73 5,936,871.90 691,769.27 70° 13' 55.538 N 148° 27' 6.699 W 86.99 113.76 8,672.34 -3,996.54 5,595.58 5,936,858.54 691,801.46 70° 13' 55.399 N 148° 27' 5.774 W 87.32 112.26 8,673.80 -4,008.03 5,622.63 5,936,847.73 691,828.78 70° 13' 55.286 N 148° 27' 4.988 W 88.06 110.13 8,675.02 -4,018.98 5,650.87 5,936,837.47 691,857.28 70° 13' 55.178 N 148° 27' 4.168 W 88.40 109.29 8,675.95 -4,029.05 5,678.99 5,936,828.10 691,885.64 70° 13' 55.079 N 148° 27' 3.351 W 88.09 108.32 8,676.87 -4,038.74 5,707.45 5,936,819.12 691,914.33 70° 13' 54.983 N 148° 27' 2.524 W 87.91 107.66 8,677.95 -4,048.29 5,736.84 5,936,810.30 691,943.94 70° 13' 54.889 N 148° 27' 1.671 W 87.36 106.84 8,679.16 -4,056.97 5,764.80 5,936,802.31 691,972.10 70° 13' 54.803 N 148° 27' 0.858 W 10!23/2009 1:56:45PM Page 4 COMPASS 2003.16 Build 71 ~~~ °s 1NTEQ Company: :Project: 'Site: Well: Wellbore: Design: • Survey Report -Geographic North America -ALASKA - BP Prudhoe Bay PB DS O6 06-18 06-18A 06-18A Survey ___._. _. - --- Measured Vertical Depth Inclination Azimuth Depth +N/-S (ft) (°) (°) (ft) (~) 13,080.38 87.26 105.98 8,680.57 -4,065.46 13,108.81 87.91 101.29 8,681.77 -4,072.15 13,139.91 89.42 97.59 8,682.49 -4,077.25 13,173.99 89.38 92.42 8,682.85 -4,080.22 13,204.85 89.23 89.77 8,683.22 -4,080.81 13,237.53 89.08 85.67 8,683.70 -4,079.51 13,269.57 89.35 81.70 8,684.14 -4,075.99 13,299.11 90.12 78.78 8,684.28 -4,070.98 13,331.53 91.26 75.13 8,683.89 -4,063.66 13,363.21 91.44 71.77 8,683.14 -4,054.64 13,395.09 91.51 68.50 8,682.32 -4,043.82 13,426.99 89.20 66.08 8,682.13 -4,031.50 13,463.11 88.25 62.05 8,682.93 -4,015.71 13,498.37 88.77 58.31 8,683.85 -3,998.19 13,529.73 89.32 55.12 8,684.37 -3,980.98 13,562.03 90.43 54.33 8,684.44 -3,962.33 13,592.23 92.49 57.16 8,683.67 -3,945.34 13,620.93 92.67 61.49 8,682.38 -3,930.72 13,650.79 92.55 65.28 8,681.02 -3,917.35 13,684.65 93.81 70.26 8,679.14 -3,904.57 13,715.73 92.18 73.87 8,677.51 -3,895.01 13,748.57 91.20 77.62 8,676.54 -3,886.93 13,780.89 90.55 81.34 8,676.05 -3,881.03 13,813.07 88.71 85.06 8,676.26 -3,877.22 13,846.21 88.50 89.96 8,677.07 -3,875.78 13,881.47 89.88 95.29 8,677.56 -3,877.40 13,915.33 89.69 99.83 8,677.69 -3,881.85 13,945.85 88.96 103.78 8,678.05 -3,888.09 13,965.47 88.10 106.39 8,678.55 -3,893.20 14,000.00 88.10 106.39 8,679.70 -3,902.94 TD Locat Co-ordinate Reference: ND Reference:'' MD Reference: North Reference: Survey Calculation Method: Database: .Map +E/_yy; Northing j~) jft) 5,793.62 5,936,794.54 5,821.22 5,936,788.53 5,851.88 5,936,784.19 5,885.82 5,936,782.06 5,916.67 5,936,782.23 5, 949.31 5, 936, 784.33 5,981.15 5,936,788.64 6,010.25 5,936,794.37 6,041.83 5,936,802.46 6,072.18 5,936,812.22 6,102.15 5,936,823.79 6,131.58 5,936,836.82 6,164.04 5,936,853.41 6,194.62 5,936,871.68 6,220.83 5,936,889.53 6,247.20 5,936,908.83 6,272.14 5,936,926.43 6 6,296.80 5,936,941.65 6 6,323.46 5,936,955.67 6 6,354.75 5,936,969.22 6 6,384.27 5,936,979.50 6 6,416.08 5,936,988.37 6 6,447.85 5,936,995.05 6 6,479.79 5,936,999.64 6 6,512.88 5,937,001.90 6 6,548.09 5,937,001.16 6 6,581.64 5,936,997.53 6 6,611.51 5,936,992.03 6 6,630.44 5,936,987.40 6 6,663.55 5,936,978.48 6 • We1106-18 -Slot 18 Orig rig on 06-18 @ 74.OOft (Orig rig on 06-18) Orig rig on 06-18 @ 74.OOft (Orig rig on 06-18) True Minimum Curvature EDM .16 - Anc Prod - WH24P Map Fasting (ff) 692,001.12 692,028.88 692,059.66 692,093.65 692,124.51 692,157.10 692,188.84 692,217.82 692,249.20 692,279.32 692,309.01 692,338.12 692,370.18 692,400.32 692,426.09 692,451.99 92,476.51 92, 500.79 92,527.12 92, 558.07 92,587.35 92,618.95 92,650.56 92,682.40 92,715.44 92,750.67 92,784.33 92,814.34 92,833.39 92,866.73 Latitude 70° 13' 54.720 N 70° 13' 54.654 N 70° 13' 54.603 N 70° 13' 54.574 N 70° 13' 54.568 N 70° 13' 54.580 N 70°13'54.615N 70° 13' 54.664 N 70° 13' 54.735 N 70° 13' 54.824 N 70° 13' 54.930 N 70° 13' 55.051 N 70° 13' 55.206 N 70° 13' 55.378 N 70° 13' 55.547 N 70° 13' 55.730 N 70° 13' 55.897 N 70° 13' 56.041 N 70° 13' 56.172 N 70° 13' 56.298 N 70° 13' 56.391 N 70° 13' 56.471 N 70° 13' 56.528 N 70° 13' 56.566 N 70° 13' 56.579 N 70° 13' 56.563 N 70°13'S6.519N 70° 13' 56.458 N 70° 13' 56.407 N 70° 13' 56.311 N Longitude 148° 27' 0.021 W 148° 26' 59.219 W 148° 26' 58.329 W 148° 26' 57.343 W 148° 26' 56.446 W 148° 26' 55.498 W 148° 26' 54.573 W 148° 26' 53.727 W 148° 26' 52.809 W 148° 26' 51.927 W 148° 26' 51.056 W 148° 26' 50.201 W 148° 26' 49.257 W 148° 26' 48.368 W 148° 26' 47.606 W 148° 26' 46.839 W 148° 26' 46.114 W 148° 26' 45.397 W 148° 26' 44.622 W 148° 26' 43.713 W 148° 26' 42.855 W 148° 26' 41.930 W 148° 26' 41.007 W 148° 26' 40.079 W 148° 26' 39.117 W 148° 26' 38.094 W 148° 26' 37.119 W 148° 26' 36.252 W 148° 26' 35.702 W 148° 26' 34.740 W 10/23!2009 1:56:45PM Page 5 COMPASS 2003.16 Build 71 TREE _ . CM/ WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV =_ 74' BF. ELEV..- KOP = 2500' Max Angle = 99° @ 10095' Datum MD = NA Datum TVD = 8800' SS ~ 06-18A S TES *** 4-1 /2" CHROME TBG & NIPS *** WELL GLE> 70° @ 10011' 2033' -{4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2512' Minimum ID =1.92" @ 12085' 2~/8" DEPLOYMENT SLV TOP OF 7" LNR -SCAB ~~ 8998' ~ 3-1/2" LNR, 9.2#, L-80 STL, .0087 bpf, ID = 2.992" ~-~ 9481' TOP OF 7" LNR ~~ 9497' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3776 3712 30 MMGM DOME RK 16 10/29/09 2 6068 5612 39 MMGM SO RK 20 10/29/09 3 7648 6784 41 MMGM DMY RK 0 05/26/99 4 8426 7394 36 MMGM DMY RK 0 02/13/06 **5 8916 7797 33 MMGM DMY RK 0 05/26/99 '""ATTEMPT TO PULL #5 12/11/05 -FISHING NECK STRIPPED 8998' 7" TIE BACK SEALS STUNG INTO 7" LNR 9441 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 9449' 3.70" DEPLOYMENT SLV, ID = 3.00" 9459' 3-1/2" HES X NIP, ID = 2.813 9481' 3-1/2" X 3-3/16" XO, ID = 2.786" 9482' 4-1/2" HES X NIP, ID=3.813 BEHIND CT LNR 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" ~ 9504' 7" SCAB LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9508' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9808' 4-1/2" X 7" GEN II WHIPSTOCK (07/05/09) 9860' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~~ 10640' 9~ 504' I 4-1/2" WLEG, ID = 3.958" BEHIND CT LNR ELMD TT NOT LOGGED MILLOUT WINDOW (06-18A) 9868' - 9875' 12085' 2-3/8" DEPLOYMENT SLV, ID = 1.92" 12145' 3-3/16" LNR SHOE MILLED OUT TO 2.74" 12263' TOP OF SLTD LNR 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" ~ 12145' ~ 13971' BTM SLTD ~~ ~~ LNR PERFORATION SUMMARY REF LOG: ??? ANGLE AT TOP PERF: 92° @ 12263' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLTD 12263 - 13971 SLOT 10/10/09 ~` ~` ~` ~` ~` ~` ~ ~ PBTD 13971' 2-3/8" LNR, 4.4#, L-80 STL, .0039 bpf, ID = 1.992" --~ 1~ DATE REV BY COMMENTS DATE REV BY COMMENTS 08/30/82 ORIGINAL COMPLETION 11/06/09 BSE/SV GLV GO (10/29/09) 05/26/99 LAST WORKOVER 07/26/09 RRD/PJC SET WHIPSTOCK (07/05/09) 07/26/09 JUPJC P&A (07/16/09) 10/25/09 NORDIC 1 CTD SIDETRACK (06-18A) 10/28/09 MR/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: 06-18A PERMff No: 2090630 API No: 50-029-20767-01-00 SEC 2, T10N, R14E,114' FSL & 885' FEL BP Exploration (Alaska) Alaska Drilling and Wells Saf~tand Down ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs@bp.com] Sent: Thursday, October 15, 2009 4:55 PM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel Subject: RE: Alaska Drilling and Wells Safety Stand Down Tom- Doyon 14 - Z-25 -Operations shut down at 21:00 hours on 10/12/09. Cement Plug in place at 11,032'. Clean-out BHA hung off from floor to 3350' with circulation through the cement line while the shut-down is ongoing. Doyon 16 - O-04A Had just tested BOP's and were preparing to pull tubing when operations were shut down. Two way check installed in tubing and tested. Kill lines blown down. Begin stand down at 22:30 on 10/12/2009. 3©S-C~~3 Nordic 1 - 06-18A Finish logging run of newly run and cemented liner. Clear floor, Jet Stack, begin Stand Dowr at midnight, 10/12/09. Nordic 2 - H-05B Drill to 13,795' MD. Trip for bit. Test BOP's. Begin safety stand-down at 15:45 hours 10/14/09. Fill hole every six hours with a loss rate of 1 barrel per hour. Nabors 4es - Move to MPL-29. Incident occurred at approximately 12:00 hours on 10/10/09. Begin Safety Stand-down at 12:30 p.m. Still rigging up at time of incident. Rig over well, pits full, no wellwork started. Nabors 7es - L-223 7" casing run and cemented. Emergency slips set with pack-off. NU BOP. Test casing spool to tubing spool flange to 5000 psi and FMC pack-off with hand test pump. Change rams from 7" to VBR's, test. Freeze protect OA. Begin Stand Down at 0900 Hours 10/14/09. Nabors 9es - S-218 Currently finishing up running and cementing 7" longstring. Freeze protect OA. Anticipated start of Safety Shut-down- 10:00 hours 10/15/09. Hope that will suffice. Sorry about the delay- the computer has been acting up today- Thanks and don't hesitate to get back with me if you need more information- Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, October 15, 2009 11:15 AM To: Hobbs, Greg S (ANC) Cc: Schultz, Mikel; DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Aubert, Winton G (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: Alaska Drilling and Wells Safety Stand Down Greg, Thanks for the information. Unfortunate that events have prompted this significant response. You indicate that the stand downs began with the wells at a "safe place" which is appropriate. With the wells secure and no 10/20/2009 Alaska Drilling and Wells Saf~tand Down • Page 2 of 2 operations taking place, the need to accomplish BOP tests on the proscribed time interval is not necessary. You are correct that where the test time intervals have been exceeded that the BOP test will need to be accomplished as the first order of business when operations are resumed. For our records, would you please provide a summary of the wells associated with each rig and the wellbore conditions at the time of SD? Keep us informed as operations are resumed. Please call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Thursday, October 15, 2009 11:04 AM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel Subject: Alaska Drilling and Wells Safety Stand Down Tom- To follow up on our phone conversation yesterday, ADW is taking a safety stand down after a high potential incident over the weekend (Saturday) on Nabors 4es. Nabors 4es has been shut down since this event, Nabors 7es went down yesterday, and Nordic 1 and 2 and Doyon 14 and 16 started their stand-downs at a point in between. Nabors 9es is starting its stand-down today. This last incident, and our current safety statistics have created significant concern for ADW management that our current safety culture is not in the place it needs to be. The directive from Steve Robinson is that the stand down be used to address gaps in our safety culture that have allowed 50% of the incidents that have occurred to happen to employees with five years of experience or less. Of these incidents, 40% have occurred with employees working alone. By having every contractor and rig come up with a plan to address these issues, ADW management expects that occurrence of events at the top of the pyramid will be pushed out further into the future. Steve Robinson has asked that plans be presented to him, and they will require his approval. This stand down is unique in that each rig has shut down at a safe point, and there is no planned end time. Start-up on a rig by rig basis is dependent on contractors providing a plan that immediately adresses the above statistics which should defer more significant events. The plan also needs to address longer term changes to embed behaviors that will make a significant change in our current safety culture The reason for this mail is to make you aware that BOP tests could go beyond their timing requirements during the stand down. If this is the case, they will occur as the first operation following ADWE management's approval for a rig to re-start operations. We wanted to make you aware of this potential issue, and appreciate your support, and management wants everyone focuesd on their safety plans, not operations at this time. If you have any questions, feel free to get back with me. Thanks- Greg Hobbs 10/20/2009 ~~ . ~ ~ ~ ~ ~ ALASS-A OIL A11TD ~irA-S COI~TSERQATI011i COMi-IISSIOIQ Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 06-18A Well BP Exploration (Alaska) Inc. Permit No: 209-063 Surface Location: 114' FSL, 885' FEL, Sec. 02, T10N, R14E, UM Bottomhole Location: 3804' FNL, 332' FWL, Sec. 07, TlON, R15E, UM Dear Mr. McMullen: On July 9, 2009 BP Exploration (Alaska) Inc. submitted a revised Application for Permit to Drill (APD) Form 10-401 for the subject well. The reason for the revision was BP's desire to employ a service coil unit (complying with 20 AAC 25.286] to mill the casing exit and drill ~ 10' of new hole rather than the drilling coil unit [complying with 20 AAC 25.033 and 20 AAC 25.036]. Your request is DENIED. 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this?vday of July, 2009 incerely Daniel . Seamount, Jr. Chairman STATE OF ALASKA • ALAS~OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~ JUL d 9 [=:;f~~ Re~1€~ ~ IAA ~Pf~ ~ ~ O~v(w A~t191>t i a rt 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pro~[1~ OfRQ ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 06-18A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13800' TVD 8627'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' 7. Property Designation: ADL 028311 & 0 329 Oil Pool 114 FSL, 885 FEL, SEC. 02, T10N, R14E, UM Top of Productive Horizon: 2285 FWL, SEC. 12, T10N, R14E, UM 2283 FNL 8. Land Use Permit: 13. Approximate Spud Date: July 11, 2009 /August 1, 2009 , Total Depth: 3804' FNL, 332' FWL, SEC. 07, T10N, R15E, UM 9. Acres in Prop 2560 14. Distance to Nearest Property: 20,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-686109 y-5940716 Zone-ASP4 10. KB Ele tion (Heigh bove GL): 74' feet 15. Distance to Nearest Well Within Pool: 1,100' 16. Deviated Wells: Kickoff Depth: 9860 feet Maximum Hole An le: 97 de rees 17. Ma mum Anticipated Pressures in psig (see 20 AAC 25.035) hole: 3302 Surface: 2442 18. Casin Pro ram: - ifi io ns - S in De h - B om n i of m n .f. r sack Hole Casin Wei ht Grade Cou lin Len TVD MD TVD includin sta a data 3-3/4" s-1/2"x3-3/16° g.g1# / 6.2# L-80 STL / TCII 26 472' 98'ss 121 0' 8606'ss 52 sx lass' ' 1 g, PRESE NT WE L CO ITI S M RY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10650 Total Depth P gs (measu ed): 9309 None Effective Depth MD (ft): 10585 Effective Depth TVD (ft): 9252 Junk (measured): None Casing Length, i Cement Volume MD TVD Conductor / Stru 2' 22 Pol s t 2' 82' Surface -3/8" 2432 sx F ndu 400 sx PF 'C' 2512' 2512' Intermediate Pr tin 9- 8" x I 'G' 300 PF' 08' 8 6 ' Liner 1 2' 7" 400 sx CI 'G' 8998' - 10640' 7866' - 9300' Perforation Depth MD ( :10126' - 10210' Perforation Depth TVD (ft): 8846' - 8920' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ®Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name Joh c dl Title Engineering Team Leader Prepared By Name/Number. Si nature _ Phone 564-4711 Date ~ Terrie Hubble, 564-4628 ~" Commission Use Onl Permit To Number: 209-063 API Number: 50-029-20767-01-00 Permit Approval See cover letter for Da e: other re uirem nts Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ^ Samples Req'd: ^ Yes ^ No Mud Log Req'd: ^ Yes ^ No HZS Measures: ^ Yes ^ No Directional Survey Req'd: ^ Yes ^ No Other: APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005 O (~ ~ (~ I ~ n Submit In Duplicate DS06-18A - Coiled Tubing milling To: Tom Maunder Petroleum Engineer ~~ Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: July 8, 2009 Re: Revision to 06-18A Permit to Drill (209-063) This revision changes the window milling operation from rig work to prep work with service coil. Additional documentation is attached that provides an overview of the service coil operation and rig up. A quick turnaround is requested as the window milling operation is scheduled for Saturday July, 11 2009. CTD Drill and Complete DS06-18A: Spud in August 1, 2009 Pre-Rig Operations 1. O MIT-OA - 2000 psi Passed 04/24/2009 DONE 2. O MIT-IA - 3000 psi Passed 12/19/2008 DONE 3. O PPPOT-T, AC-LDS 04/30/2009 DONE 4. O AC-PPPOT-IC 05/08/2009 DONE 5. S Dummy GLVs, (Station #1 and Station #2) 6. S Drift for 4-1/2" X 7" Thru tubing whipstock to 10,000' MD 7. E Set whipstock ~ 9,860'MD. 8. C Test for infectivity through perforations 9. C Squeeze cement past whipstock to abandon existing perforations (33 bbls of 15.8 ppg cement). 10. C Mill 3.8" window at 9860' (supporting documents attached) 11. O PT tree (MV,SV,WV), function LDS 12. W Set BPV 13. O Bleed gas lift and production flowlines down to zero and blind flange 14. O Remove S-Riser, Remove wellhouse, level pad Rig Sidetrack Operations: (Scheduled to begin on August 1, 2009) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV 4. Drill build/turn section with 3.75" bicenter bit, and land well. 5. Drill lateral section to 12,100' MD w/ resistivity log. 6. Run 3-1 /2"x 3-3/16" solid liner w/cementralizers to TD. Place liner top at 9,472' MD. 7. Cement liner from TD to TOL (9,472'MD) with 15.8ppb cement. 8. Lay down 2-3/8" coil tubing reel, PU 2" coil tubing reel. 9. Test liner lap to 2000 psi. 10. Change rams in BOPE. Test BOPE. 11. Drill out 3-3/16" liner shoe. 12. Drill 3" OH to 13,800' MD w/ resistivity. 13. Freeze protect well to 2500' with diesel. 14. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV, Run Live gas lift design 3. RU test separator, flow test well. July 8, 2009 • DS06-18A - Coiled Tubing Grilling Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" and 3" Casing Program: • 3-1/2", 8.81 #, L-80, STL connection solid liner - 9,472'MD - 9,502' MD. • 3-3/16", 6.2#, L-80, TC-II connection solid liner - 9,502'MD - 12,100' MD. • A minimum of 10.8 bbls 15.8 ppg cement will be used for liner cementing. (TOC 9,472'MD) Well Control: • BOP diagrams are attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 97° deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest well within the pool (Sag River) - 12-12A 1100' • Distance to nearest property line - 20,000' South Anticollision Summary • 06-10A - 204' ctr-ctr, Status: Producing • 06-10 - 311' ctr-ctr, Status: Abandoned • 13-10 914' ctr-ctr, Status: Shut in • 01-24 - 1353' ctr-ctr. Status: Shut in injector Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCUCNL log will be run. Hazards • The maximum recorded H2S level on DS 06 is 200 ppm on 06-18(06-01-2008). Drill Site 06 is an H2S pad. • Lost circulation risk is low. No fault crossings are expected. Reservoir Pressure • Res. press. is estimated to be 3,302 psi at 8,600'ss (7.4 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2442 psi. Sean McLaughlin CTD Engineer July 8, 2009 • DS06-18A - Coiled Tubing Drilling = FIIC GBd 3 LH EAD = FMC _ _ CiUATOR= __ BAKERC KB. ~B/= 74' BF. ELEV = KOP= Mex Anyk = 2500' 43 ®880D' Detum MD = 10158' DetwnTVD= N00' SS 139J8' CSG 72A1, L-80, D =12.34T -C Min imu m ID ~ 3.813" ~ 9482' 4-1 /2= HES X NIPPLE ITOPOFTLNR-SCAB I 06-18 1 1 I 1 I 1412• TBG 1 ~ TOP OF 7' LNR H 9497' .0152 bpf, A] = 9.958' 9504' 9.5A' CSG 47i. L-80. D = 8.N7 • H 9808' PERFORATION SUMMARY REF LOO: BHCS ON O7M8182 ANOLEATTOP PERF: 28 ®10150' Notre: Refer bo ProrLction DB fa hiskuieai dela SQE 5PF NTE'RVAL OPnIS DOTE 3-3/8' 4 10090 -10120 S 03H 1A1 3-318' 4 10128 -10148 S 03M 1101 2-7/8' B 10128 -10148 O 0.'U21 A8 3-318' B 10150 -101 BS O 08M 5105 3.3/e• a 10175-1oz1o 0 o1n2W3 3-3/B' B 10164 -10214 S 08A1190 3-318' 4 10234 -10270 S 03M 8180 3-318' 8 10288 -10308 S 02AB188 3-319' 4 103N -10328 S 09117187 T LNR 29i, L-8D, .0371 bpf, D = 8.184' SAFETY NOTEB: "" 4-112" CHROME TB6 "` 141R'HESXNP,AI=9.819' I ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 9778 9712 SO MMGM DOME RK 18 05M21N 2 BON 5812 99 MMOM SO RK 20 05!12!08 9 7648 6784 41 MMQM DMY RK 0 4 8428 7394 9B MMGM DMY RK 0 02/19108 "5 8918 7797 S9 MMGM DRAY RK D -wrrowrr rvru~~zraiaivuo-wrac:rrsrrcerr9 8998' T TE BACK ~ LS STl1~Xi NTO T LNR 9449' T X 4112' BKR S-3 PKR 1l!' HES X NIP, D=9.819 i 9504' H41/Z- TTwNYLR~s ~ ELMD TT NOT LOGGED DOTE REV BY ODfS D*TE REV BY CONNYBJTS ON90162 ORIGINALCOMPLEnON 05130A8 DTM YYELLHEIIDCORRBrTIONS OSrlBIBB LABT WORI9yVBt 04M3107 BSEIRAG GLV C10 08115105 OJBIPJC PERF 05M9107 GDCIfLH VWA/ERSFTYNOTEDELETEO 071291 ORS/TLH FERF CORRBCiIONS D5/28108 S9NSY GLV CAD (0511 ZlDB) 03/22A8 TIP PULLED 02M 05121A6 OJB/P.IC PERFCORRECTION PRUDHOE BAY UNtf VYELL: OB-18 PERMR No: "1820990 A PI No: 54029-20787-00 S~ 2, T10N, R14E, 2727.89' FEL d 2484. BP ~rpioretion {Alee;kea July 8, 2009 • DS06-18A - Coiled Tubing Grilling TREE- FLCGEN3 WELLHB4D- FLIC ACTUATOR- OAKERC _~- EL Bi - T ~' 8F. aBJ- I~ P - 2500' Lit Rage - 13~ 66m' [atlm uD- tnt6s' -Gahm TV O - 8~0' 9S V~-18A SRF~TYNOTES: "xx4112"CHROMETBGx"'~ Proposed CTD Sidetrack 13J.6' CSG, T2iM, LSO, ID- 12317' 2517 ST LID ND DEd TYPE VLV LR1CH PORT 047E 1 2 3776 W68 3712 6612 ~ ~ LILIGLI MLIGLI DO LIE SO RK RK 1 20 O5n2A8 D6112A8 3 76 i8 6x81 i1 LILIGLI DLIY RK D ~ 8126 7391 36 MLIGM OIIY RK D 02113A6 "6 8916 7797 33 LILIGM OLR` RK D ""ATTEMPTTO PULL dS 17111163 -flSHING N~K STRIPPED P ERFO RRTD N SULILYI RY REF LOG: SHCSONO7118r62 RNGLERTTOPP@IF: 28~ 10150' Nol:Rehrb Proulcuo~ DS for 11[brCalpertoam S E SPF NTERVRL Op~rSgz DATE 33,8 1 1m90 -1012a S 03111 Al 33~ 1 10126-10116 S O~11A1 2-7 re 6 10126 -101 W 0 05J21 A6 3Jr8 6 10150 -10166 0 06J15A6 33x8 1 101 T6 -10710 0 O f!?ZA3 3-3.8 6 10181-1 D211 S 0&31 FO 3Jr8 1 1Q231-1 Q270 S 03116A0 33~ 6 1Q286 -1 0306 S 07J06r@8 33x8 1 10306 -10326 S 09/17 x67 EL LID TT NOT LOGGED 3'oplilok 12104100 PRUGHOESRY UNIT W EL L: 06-1&4 P ERLIR No: R P I ND: 50-029-2x767-01 2,T10N, R11E, 272x.6'8' Fa & Zt61 EP Bplorailon (AI91Ma) FNL July 8, 2009 are • DS06-18A - Coiled Tubing Drilling i _~ B BAG 7 1/16" 5000 psi. Blind/Shears cross Mud Cross variable bore pipe 3 1/2"-2 3/8" 2 3/8" combi ram/slips 2 318" combi ram/slips Valve Flow Tee TOTs 7 1/16" 5000psi Mud Cross ~ vis° 5ooopsi TOTs 7 1/16" 5000psi July 8, 2009 • DS06-18A - Coiled Tubing Drilling July 8, 2009 • DS06-18A - Coiled Tubing~illing Service Coil- Mi113.8" window at 9860' and 10' of rathole. The window will be a 41h" x 7" single string exit off of a Baker TTWS. The planned TOWS depth is at 9860' with a high side tray face. Variance request: A variance to the well control equipment requirement of [20 AAC 25.036] is requested for the proposed service coil window milling operation. Instead, the work would be performed in compliance with [20 AAC 25.286], which provides an equally effective means of well control for the scope of work planned. In comparison to other service coil wellwork with open perfs, there is no incremental risk of milling a window in the reservoir that would necessitate adopting more comprehensive control equipment/procedures beyond the requirements of wellwork service operations [20 AAC 25.286]. Service Coil rig uu information R~U~ 0 500 bbl returns tank for fluids handling o Upright tank for fluid supply o KilUChoke Line Combo o lOK- 2" hardline downstream of pump and to choke w/ 1502 hammer unions o Flanged connection between BOPE and Swab Valve 0 2 x 2-1/16" flanged block valves off the pump in sub Blowout Preventer Equipment 4-1/16" Quad lOk o Stripper o Lubricator o Blind/Shear Ram o Blind/Shear Ram o Slip Ram o Pipe Ram o Pump in Sub o Swab Valve BOP Test Frequency Test BOP's per current guidelines (once per week or after any redress or alteration). Pressure Test Procedure • Low PT (300 psi) -Entire System downstream of pump tested against the swab and 2x2 valves on backside of the choke. • High PT (--4000 psi) -Entire System downstream of pump tested against the swab and 2x2 valves on backside of the choke. Service coil milling info - 1 July 8, 2009 • DS06-18A - Coiled Tubing~illing Injector Head Pack-off ~~ Coiled Tubing ~~ Lubricator ~ ~~ - ~ ~~ BlindfShear Rams C~ ~ I~~p 2 " Ki I I Line ~ ut I et ~ ~ _~ Slip Rams -~ ~ ~ ~ Pipe Rams Pump-In Sub w/ 2" cutlet A (5000 psi Working Pressure) ~.,_ Production Tree Swab Value (5000 psi Working Pressure) Coiled Tubing Blowout Preventer. Lubricator, and Injector Head Service coil milling info - 2 July 8, 2009 DS06-18A - Coiled Tubing drilling Injector Head ~. Lubricator _~ (10,000 psi) BOP Stack Well Head -^r. f Production Tubing Coiled Tubing Control Room Pump Room Chiksan + T TTo BOP Stack DownComer-- 1 1To Swab Valve Return Tank (~ ~ Well Return Tank 7 '1'' Reel ~ Flanged Block VLV CTU Pump Tanker Service coil milling info - 3 July 8, 2009 • DS06-18A - Coiled Tubing~illing Service Coil Milling procedure Issues and Potential Hazards • Give BOT 24 hr notice prior to the job. A BOT service hand will be on the unit for the window milling. • Use a 2# Bio or GeoVIS sweeps to help clean the metal shavings out of the well. • Slow patient milling will be the key to a successful window. There is nothing to be gained trying to speed up the window. • Ensure the window is dressed and smooth. Operations 1. RIRU, Test BOPE per SOP. 2. Fill upright tank with 2% KCL milling fluid. 3. Make up the following BHA to mill through the liner: o Hughes Christensen 3.80" diamond window mill (P/N E0378) o Hughes Christensen diamond reamer 3.80"go/3.79"nogo 0 2'/g" Baker X-treme straight motor 0 2-3/8 PH6 pup joint (no weight bars) o Circ sub, Disconnect, DFCV o CTC back to 1.75" CT o Record gage go/nogo on both mill & reamer. o The mills will be made up to the motor at the BOT shop. 2. RIH displacing the well to 2% KCl milling fluid, shut down pump, & lightly tag (1000# WOB) the pinch point dry (planned TOWS @ 9860'). The pinch point on this 4-1/2" x 7" WS is 4.6' from the TOWS. 3. PU 10+', bring pump to full rate (~2.5 bpm), & RIH slowly. Note RIH weight & free spin pressure. Be prepared to tag 1'-2' above dry tag when pumping at full rate. 4. Tag TOWS as indicated by a 250-300 psi increase in pump pressure & flag pipe. If motor stalls, PU & time drill down at 1'/hr. Monitor motor work & limit to a 300 psi increase for the ls` one foot below the TOWS. Monitor & record WOB. 5. Slowly increase motor work after milling 1' using 400 psi as a maximum. Expect ROP less than 1'/hr until mill cuts through the liner wall. Afterwards expect 2-3k# WOB & 1'-3'/hr ROP. o Pump sweeps to ensure the metal is being removed from the hole. In the past there has been an issue with solids settling in the sump and the drilling assembly was not able to pass thru the window. Service coil milling info - 4 July 8, 2009 DS06-18A - Coiled Tubing Qrilling 6. The mill-off could be as much as 8.9' down from TOWS. But, will likely occur ~7' down from the TOWS based on past windows. If mill off does not occur before the theoretical Bottom of the window, control mill at 1'/hr until the mill has reached 9' below TOWS. Mill-off will be indicated by an abrupt decrease in WOB & increased ROP. Record this depth as the bottom of the window. 7. Drill a minimum of 10' in the formation. Sand in the returns is usually a good indication the window exit is successful. If there is any doubt catch a fluid sample and take it to the geologist on either Nordic 1 or 2. Ream up & down from the WS face to 2' below the window bottom several times at 1'/min. 8. Pump a 150k LSRV GeoVIS pill to leave on bottom to prevent any remaining cuttings from falling into the rathole. 9. POOH leaving a 2000' freeze protect cap. Service coil milling info - 5 July 8, 2009 ~, m- _; ; ,~ , t ,~~~ ~ ~~ yyp~ F r~ ~~ ~ a u ~a~ Y k~ ~ 5~ ^. Y r ~ ~ ~ ~ ~ t~ a ~ i ~~ ~ ~ § ~ ¢ ~~ w ~T ALASgiA OIL A1~TD GA5 CO1~T5ER'QATIOl~T CO~'II1II551O1~T John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 06-18A Well BP Exploration (Alaska) Inc. Permit No: 209-063 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Surface Location: 114' FSL, 885' FEL, Sec. 02, T l ON, R 14E, UM Bottomhole Location: 3804' FNL, 332' FWL, Sec. 07, T10N, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerel Dan T. Seamount Chair DATED this ~ day of June, 2009 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~EC~~VE® ~~~''~ ALAS~IL AND GAS CONSERVATION COMMI~N ~ /z¢09 PERMIT TO DRILL ~~ ~~ JUN I d 1009 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. S 1181sCpisdo~ti BatT)mission ^ Coalbed Meth~~ih~G~s Hydrates ^ Shale Gas 99 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 06-18A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13800 TVD 8627 ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' 7. Property Designation: ADL 028311 Oil Pool FSL, 885 FEL, SEC. 02, T10N, R14E, UM 114 Top of Productive Horizon: 2285 FWL, SEC. 12, T10N, R14E, UM 2283 FNL 8. Land Use Permit: 13. Approximate Spud Date: August 1, 2009 , Total Depth: 3804' FNL, 332' FWL, SEC. 07, T10N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 20000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-686109 y-5940716 Zone-ASP4 10. KB Elevation (Height above GL): 74' feet 15. Distance to Nearest Well Within Pool: 1100' 16. Deviated Wells: Kickoff Depth: 9860 feet Maximum Hole An le: 97 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3302 Surface: 2442 1 in Pro m: ifi ns T - ettin D h -Boo uan ' emen c f. r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4_1/g~~ s-~n~~Xa-~~s° 8,81#/ .2# L-80 STL/TCII 262 ' 72 8272 12100 8606ss 52sxCla s'G' ~ g, PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10650 Total Depth TVD (ft): Plugs (measured): 9309 None Effective Depth MD (ft): 10585 Effective Depth TVD (ft): 9252 Junk (measured): None Casing ien th' `Size Cement Voh]me MD TVD Conductor /Structural 2' 2 2 P I 2' Surface 2512' 13-318" 4 2 x F ndu 400 sx PF'C' 2512' 2 12' Intermediate Pr d i n 9-5/8" x l s 'G' x PF ' 9 Liner 1642' 7" 400 sx Class 'G' 8998' - 1 786 ' - 9300' Perforation Depth MD (ft): 10126' - 10210' Perforation Depth TVD (ft): 8846' - 8920' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ®Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fore oing is true and correct. Contact Mel Rixse, 564-5620 Printed Name J ul n Title Engineering Team Leader Prepared By Name/Number Si nat Phone 564-4711 Date ~ C1 Sondra Stewman, 564-x750 Commission Use Onl Permit o Drill Number: 0 063 API Number: 50-029-20767-01-00 Permit Approval See cover letter for e: 7 6 other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: '3S®~ QS~ i'C~~~•~~- ~ ~` Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No ~~C~C7 PSG ~M`t v~ir~J ~, G`~riv~~'- ~>~HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other. APPROVED BY THE COMMISSION Date ~ ,COMMISSIONER Form 10-401 Revised 12f2005 ®~ ~ G ~ N A L S bit I~ pl/ice~/c9qa~e d~~ ~~ 4' DS06-18A - Coiled Tubing Ding To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: June 3, 2009 Re: 06-18A Application for Permit to Drill Request CTD Drill and Complete DS06-18A program: Spud in August 1, 2009 Pre-Rig Operations 1. O MIT-OA - 2000 psi Passed 04/24/2009 DONE 2. O MIT-IA - 3000 psi Passed 12/19/2008 DONE 3. O PPPOT-T, AC-LDS 04/30/2009 DONE 4. O AC-PPPOT-IC 05/08/2009 DONE 5. S Dummy GLVs, (Station #1 and Station #2) 6. S Drift for 4-1/2" X 7" Thru tubing whipstock to 10,000' MD 7. E Set whipstock -- 9,860'MD. 8. C Test for infectivity through perforations 9. C Squeeze cement past whipstock to abandon existing perforations. 10. O MIT-Tubing 3000 psi 11. O PT tree (MV,SV,WV), function LDS 12. O Bleed gas lift and production flowlines down to zero and blind flange 13. O Remove S-Riser, Remove wellhouse, level pad -Complete Rig Sidetrack Operations: (Scheduled to begin on August 1, 2009) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high by 3. Mill 3.80" window at 9,860'. 4. Drill build/turn section with 3.75" bicenter bit, and land well. 5. Drill lateral section to 12,100' MD w/ resistivity log. 6. Run 3-1/2"x 3-3/16" solid liner w/cementralizers to TD. Place liner top at 9,472' MD. 7. Cement liner from TD to TOL (9,472'MD) with 15.8ppb cement. 8. Lay down 2-3/8" coil tubing reel, PU 2" coil tubing reel. 9. Test liner lap to 2000 psi. °"j~ t 10. Change rams in BOPE. Test BOPE. 1 ~` S fie. ~'v`~~~'r'"' 11. Drill out 3-3/16" liner shoe. \ 12. Drill 3" OH to 13,800' MD w/ resistivity. 13. Freeze protect well to 2500' with diesel. 14. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU test separator, flow test well. June 3, 2009 • DS06-18A - Coiled Tubing Ding Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" and 3" Casing Program: • 3-1/2", 8.81 #, L-80, STL connection solid liner - 9,472'MD - 9,502' MD. • 3-3/16", 6.2#, L-80, TC-II connection solid liner - 9,502'MD - 12,100' MD. • A minimum of 10.8 bbls 15.8 ppg cement will be used for liner cementing. (TOC 9,472'MD) Well Control: • BOP diagrams are attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 97° deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest well within the pool (Sag River) - 12-12A 1100' • Distance to nearest property line - 20,000' South Anticollision Summary • 06-10A - 204' ctr-ctr, Status: Producing • 06-10 - 311' ctr-ctr, Status: Abandoned • 13-10 914' ctr-ctr, Status: Shut in • 01-24 - 1353' ctr-ctr. Status: Shut in injector Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCVCNL log will be run. Hazards • The maximum recorded H2S level on DS 06 is 200 ppm on 06-18(06-01-2008). Drill Site 06 is an H2S pad. • Lost circulation risk is low. No fault crossings are expected. Reservoir Pressure • Res. press. is estimated to be 3,302 psi at 8,600'ss (7.4 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2442 psi. ~-~ . G~~ Mel Rixse CTD Engineer June 3, 2009 • DS06-18A - Coiled Tubing D~fling _ D =_ CTWTOR= BAKER KB. aEV = 74' !B REi/ BY REV 8 L ON u our ~ Bs~+a~ c~ coo 06T1 C3J PERF OB/'181D7 H Ai SFTY D9. CdRfE3CT10N13 CiW t JC PRUOFIOE BAY 1~f way: os~a P9tA/T No: "i B2DMo API N0: 50~2Q7ST-00 ~ ~Nrttien (Ahsk~ FIIC C3Bd 3 ii4FETY NOTE: "' 41/2" dIRQME TB6'=' --~ 06-18 - ' June 3, 2009 • DS06-18A - Coiled Tubing ~ing TREE- FLCGEN3 ~~ ~ V~ WELLHB4D- FLC ~ Q SAFETY NOTES:'""412"CHROMETBG •"" RCTURTOR• IRKERC Proposed CTD Sidetrack I~. aEJ- 71' 0 F. EL Bf • ? I~ P - 2Sm' Iu~r A1g! - 13~ 66m' 41x1' MESX NP, ID-3813 Dacun LID- 1o15s' Daum TV D - 88-Q SS 13.316' G9f.,, 72A, 480, ID- 12.317' 2517 Minimum ID = 28" ~i 9473' TOL 3-'1!2" ST LID TVD DEJ TYPE VLV LATCH PDRT DOTE 1 2 37T6 w68 3t 12 51612 30 3l9 LILIGLI IlLCIl DOLT SO RK RK 16 20 06112A8 06112A8 3 7618 6781 11 LILCLI DLN RK 0 4 8126 7391 36 LILIGLI DLIY RK 0 02113,06 "5 8916 7797 33 LILC LI D LfY RK D TK i i cmr i w rv« Ni un iroa - nanin., R6:R i I RIPYCU $~ 3 Cj x EL LID TT NDT LOGG ED ~~ P 9IF0 PRTD N SULILW IM REF LOG: 6 HCS O N 07118x62 RNGLERTTOPPERF: 28~ 10150' Not: Reh rb ProOYCtb~ D! Yor LlrbrCalpe ritlala S SP N RURL p1Agl DR ~ 1m -1012a S 03r11A1 33,6' i 101 26 -101 16 S 03111 Al 2-7.6' 6 10126 -101 W 0 05121 A6 3.3+6' 6 10150-10165 0 OW16A6 3.3+8• 1 101 T6 -10210 0 01122A3 3J~8 6 10181-1021 S 08x31!90 338 1 10231-10270 S 01r16A0 3.7,8 6 1Q286 -1 D306 S 02r-6~88 3.718 1 10306 -10326 S 09117 ~ I 3ope1Y0k 131041:1800 PR UDMD E SRY U NR W B L: 06-18A P 9ILIR ND: R P I N0: 50-0x-?fl767-01 N,RIIEZI27.~'FEL&216116' FNL Ep Etplor>tlon [AIRY Ns) June 3, 2009 • DS06-18A - Coiled Tubing Drilling are i _~ BAG 7 1/16" 5000 psi. bag Blind/Shears cross 2 3/8" combi ram/slips Mud Cross variable bore pipe 3 1l2"-2 3/8" 2 3/8" combi ram/slips Swab Valve Flow Tee TOTs 7 1/ts" 500opsi Mud Cross 7 1/1s" 5000psi TOTs 7 1 / 16" 5000p si June 3, 2009 DS06-18A - Coiled Tubing Drilling are i N _~ BAG m Blind/Shears TOTs m 2" combi ram/slips Mud Cross I I Mud Cross ~~ou 2 318" pipe/slip TOTs 2" pipe/slips Swab Valve Flow Tee June 3, 2009 ~~ ~~ 8~~~ ~~~~ INTEQ North America - Prudhoe Bay PB DS 06 06-18 -Slot 18 Plan 7, 06-18A Plan: Plan #7 ALASKA - BP Baker Hughes INTEQ Planning Report 04 June, 2009 b~ i r~.r INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB DS 06 Well: 06-18 Wellbore: Plan 7, 06-18A Design: Plan #7 Baker Hughes INTEQ Planning Report Well 06-18 -Slot 18 Mean Sea Level 28:18 5/10/1999 23:24 @ 66.59ft (Nabors 7ES) True Minimum Curvature EDM .16 - Anc Prod - WH24P project Prudhoe Bay, North Slope, UNITED STATES Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level oeo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 06, TR-10-14 Site Position: Northing: 5,941,880.59 ft Latitude: 70° 14' 46.529 N From: Map Easting: 684,674.88 ft Longitude: 148° 30' 29.224 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.40 ° Well 06-18 -Slot 18, 06-18 Well Position +NI-S 0.00 ft Northing: 5,940,715.47 ft Latitude: 70° 14' 34.725 N +E/-W 0.00 ft Easting: 686,109.25 ft Longitude: 148° 29' 48.364 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft --- Wellbore Plan 7, 06-18A - , Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2008 5/14/2009 Design .Plan #7 Audit Notes: Version: Vertical Section: 22.78 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 80.90 57,711 Phase: PLAN Tie On Depth: 9,792.59 Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -37.00 0.00 0.00 130.00 6/4/2009 10:34:40AM Page 2 COMPASS 2003.16 Build 70 r;~~r sIN Baker Hughes INTEQ Planning Report bP INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 06-18 -Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 06 MD Reference: 28:18 5/10/1999 23:24 @ 66.59ft (Nabors 7ES) Weli: 06-18 North Reference: True Wellbore: Plan 7, 06-18A Survey Calculation Method: Minimum Curvature Design: Plan #7 Database: EDM .16 - Ahc Prod - WH24P Survey Tool Program Date 6/4/2009 From To (ft) (ft) Su rvey (Wellbore) Tool Name Description 92.59 9,792.59 1 : Camera based gyro multisho (06-18) CB-GYRO-MS Camera based gyro multishot 9,792.59 13,800.01 Plan #7 (Plan 7, 06-18A) MWD MWD -Standard ', Planned Survey I MD Inc Azi TVDSS N/S E/W Northing fft) (°) (°) (ft) (ft} (ft) (ft) 9,792.59 28.00 124.00 8,483.98 -2,354.49 3,108.37 5,938,438.59 TIP 9,800.00 28.00 124.13 8,490.52 -2,356.43 3,111.25 5,938,436.71 9,860.00 28.00 125.20 8,543.50 -2,372.46 3,134.41 5,938,421.27 KOP 9,880.00 29.80 125.20 8,561.01 -2,378.03 3,142.31 5,938,415.89 End of 9 Deg/1 00' DLs 9,900.00 38.80 125.20 8,577.51 -2,384.52 3,151.51 5,938,409.63 ~ 10,000.00 83.80 125.20 8,624.31 -2,433.79 3,221.36 5,938,362.10 ~ 10,027.11 96.00 125.20 8,624.36 -2,449.39 3,243.47 5,938,347.06 End of 45 Deg/100' DLS 10,100.00 96.39 133.99 8,616.48 -2,495.52 3,299.26 5,938,302.31 10,200.00 96.67 146.06 8,605.07 -2,571.51 3,362.96 5,938,227.92 10,227.11 96.70 149.34 8,601.91 -2,594.27 3,377.35 5,938,205.53 5 10,300.00 96.77 140.53 8,593.34 -2,653.46 3,418.89 5,938,147.39 10,400.00 96.62 128.45 8,581.64 -2,722.93 3,489.60 5,938,079.69 10,427.11 96.52 125.18 8,578.54 -2,739.07 3,511.16 5,938,064.09 6 10,482.11 89.92 125.18 8,575.45 -2,770.69 3,556.02 5,938,033.59 End of 12 Deg/100' DLS 10,500.00 89.84 123.93 8,575.48 -2,780.83 3,570.76 5,938,023.81 10,600.00 89.35 116.95 8,576.19 -2,831.46 3,656.92 5,937,975.33 Fasting DLeg V. Sec TFace (ftl (°rlooft) (ft) (°) 689,274.61 0.00 3,894.58 0.00 689,277.54 0.84 3,898.04 90.53 689,301.09 0.84 3,926.09 90.41 689,309.13 9.00 3,935.72 0.00 689,318.48 45.00 3,946.94 0.00 689,389.52 45.00 4,032.11 0.00 689,412.01 45.00 4,059.08 0.00 689,468.91 12.00 4,131.47 87.00+ 689,534.47 12.00 4,229.12 87.95 689,549.41 12.00 4,254.76 89.33 689,592.40 12.00 4,324.63 -89.00 689,664.81 12.00 4,423.46 -90.04 689,686.76 12.00 4,450.35 -91.45 689,732.38 12.00 4,505.03 180.00 689,747.36 7.00 4,522.84 -94.00 689,834.74 7.00 4,621.39 -94.00 6/4/2009 10:34:40AM Page 3 COMPASS 2003.16 Build 70 r~~~ Baker Hughes INTEQ Planni ng Report bP lNTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 06-18 -Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level SFte: PB DS O6 MD Reference: 28:18 5/10/1999 23 :24 @ 66.59ft (Nabors 7ES) Well: 06-18 North Reference: True Welibore: Plan 7, 06-18A Survey Calculation Method: Minimum Curvature Design: Plan #7 Database: EDM .16 - Anc Prod - WH24P Planned Survey ', MD Inc Azi TVDSS N/S E/W Northing Easting DLeg V. Sec TFace lft) (°) (°) (ft) (ft) ln) (ft) (K) (°I100ft) lft) (°) 10,700.00 88.88 109.96 8,577.74 -2,871.23 3,748.59 5,937,937.84 689,927.36 7.00 4,717.18 -93.95 10,732.11 88.73 107.72 8,578.41 -2,881.60 3,778.97 5,937,928.23 689,957.98 7.00 4,747.11 -93.84 8 10,800.00 88.73 112.47 8,579.92 -2,904.91 3,842.69 5,937,906.50 690,022.26 7.00 4,810.91 90.00 10,900.00 88.75 119.47 8,582.12 -2,948.66 3,932.52 5,937,864.98 690,113.13 7.00 4,907.85 89.89 11,000.00 88.79 126.47 8,584.26 -3,003.04 4,016.34 5,937,812.69 690,198.26 7.00 5,007.01 89.74 11,032.11 88.81 128.72 8,584.93 -3,022.63 4,041.77 5,937,793.74 690,224.17 7.00 5,039.08 89.59 9 11,100.00 88.81 123.97 8,586.34 -3,062.84 4,096.43 5,937,754.89 690,279.80 7.00 5,106.80 -90.00 11,200.00 88.84 116.97 8,588.40 -3,113.50 4,182.55 5,937,706.37 690,367.14 7.00 5,205.34 -89.90 11,232.11 88.85 114.72 8,589.05 -3,127.50 4,211.44 5,937,693.09 690,396.36 7.00 5,236.47 -89.76 10 11,300.00 88.85 119.47 8,590.41 -3,158.40 4,271.85 5,937,663.69 690,457.51 7.00 5,302.61 90.00 11,400.00 88.87 126.47 8,592.40 -3,212.78 4,355.67 5,937,611.40 690,542.65 7.00 5,401.78 89.90 11,500.00 88.91 133.47 8,594.35 -3,276.98 4,432.24 5,937,549.12 690,620.78 7.00 5,501.69 89.76 ~ 11,532.11 88.92 135.72 8,594.95 -3,299.52 4,455.10 5,937,527.15 690,644.18 7.00 5,533.69 89.63 11 11,600.00 88.93 130.97 8,596.23 -3,346.10 4,504.45 5,937,481.81 690,694.66 7.00 5,601.44 -90.00 11,700.00 88.95 123.97 8,598.09 -3,406.88 4,583.75 5,937,423.00 690,775.44 7.00 5,701.26 -89.91 11,800.00 88.98 116.97 8,599.90 -3,457.55 4,669.88 5,937,374.48 690,862.78 7.00 5,799.80 -89.78 11,832.11 88.99 114.72 8,600.47 -3,471.54 4,698.77 5,937,361.21 690,892.01 7.00 5,830.93 -89.65 I 12 11,900.00 88.91 119.47 8,601.71 -3,502.45 4,759.18 5,937,331.80 690,953.16 7.00 5,897.07 91.00 12,000.00 88.81 126.47 8,603.69 -3,556.83 4,843.00 5,937,279.51 691,038.30 7.00 5,996.24 90.91 12,032.11 88.78 128.72 8,604.37 -3,576.41 4,868.44 5,937,260.56 691,064.21 7.00 6,028.32 90.77 13 12,100.00 88.79 123.97 8,605.81 -3,616.63 4,923.09 5,937,221.71 691,119.84 7.00 6,096.03 -90.00 3 3/16" 6/4/2009 10:34:40AM Page 4 COMPASS 2003.16 Build 70 ri.r Baker Hughes INTEQ Planni ng Report bP INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 06-18 -Slot 18 Protect: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 06 MD Reference: 28:18 5/10/1999 23:24 @ 66.59ft (Nabors 7ES) Well: 06-18 North Reference: True Wellbore: Plan 7, 06-18A Survey Calculation Method: Minimum Curvature Design: Plan #7 Database: EDM .16 - Anc Prod - WH24P Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting DLeg V. Sec TFace lft) (°) (°1 (ft) (ft) (ft) (ft) lft) (°1100ft) (ft) (°) 12,200.00 88.81 116.97 8,607.91 -3,667.29 5,009.21 5,937,173.20 691,207.17 7.00 6,194.57 -89.90 12,232.11 88.82 114.72 8,608.58 -3,681.28 5,038.11 5,937,159.92 691,236.40 7.00 6,225.69 -89.75+ 14 ~ 12,300.00 88.74 119.47 8,610.03 -3,712.18 5,098.51 5,937,130.52 691,297.55 7.00 6,291.83 91.00 12,400.00 88.64 126.47 8,612.32 -3,766.56 5,182.33 5,937,078.24 691,382.68 7.00 6,390.99 90.90 12,482.11 88.57 132.22 8,614.32 -3,818.58 5,245.79 5,937,027.80 691,447.40 7.00 6,473.04 90.74 ~ 15 12,500.00 88.55 130.97 8,614.76 -3,830.45 5,259.16 5,937,016.26 691,461.06 7.00 6,490.92 -91.00 ~ 12,600.00 88.44 123.97 8,617.39 -3,891.22 5,338.45 5,936,957.47 691,541.82 7.00 6,590.72 -90.97 12,700.00 88.36 116.96 8,620.18 -3,941.87 5,424.56 5,936,908.97 691,629.15 7.00 6,689.24 -90.78 12,782.11 88.31 111.21 8,622.57 -3,975.36 5,499.46 5,936,877.34 691,704.85 7.00 6,768.14 -90.59 End of 7 Deg1100' DLS 12,800.00 88.40 109.07 8,623.09 -3,981.52 5,516.24 5,936,871.60 691,721.78 12.00 6,784.96 -87.60 12,900.00 88.95 97.08 8,625.41 -4,004.09 5,613.45 5,936,851.44 691,819.50 12.00 6,873.93 -87.54 13,000.00 89.54 85.09 8,626.74 -4,005.98 5,713.24 5,936,852.01 691,919.31 12.00 6,951.59 -87.26 13,082.11 90.04 75.25 8,627.04 -3,991.98 5,794.05 5,936,868.00 691,999.74 12.00 7,004.49 -87.10 17 ) 13,100.00 90.04 77.40 8,627.03 -3,987.75 5,811.43 5,936,872.66 692,017.01 12.00 7,015.09 90.00 13,200.00 90.04 89.40 8,626.95 -3,976.27 5,910.58 5,936,886.58 692,115.84 12.00 7,083.67 90.00 13,282.11 90.04 99.25 8,626.90 -3,982.45 5,992.36 5,936,882.42 692,197.74 12.00 7,150.28 90.01 18 13,300.00 90.04 97.10 8,626.89 -3,985.00 6,010.06 5,936,880.31 692,215.50 12.00 7,.165.48 -90.00 13,400.00 90.04 85.10 8,626.82 -3,986.92 6,109.86 5,936,880.85 692,315.31 12.00 7,243.17 -90.00 13,500.00 90.03 73.10 8,626.76 -3,968.05 6,207.88 5,936,902.13 692,412.83 12.00 7,306.13 -90.01 13,552.11 90.03 66.85 8,626.73 -3,950.22 6,256.82 5,936,921.17 692,461.31 12.00 7,332.15 -90.02 19 13,600.00 90.03 72.60 8,626.70 -3,933.63 6,301.72 5,936,938.86 692,505.78 12.00 7,355.89 90.00 13,700.00 90.03 84.60 8 626.65 -3 913.90 6,399.57 5,936,961.00 692,603.11 12.00 7,418.16 90.00 6/4/2009 f0:34:40AM Page 5 COMPASS 2003.16 Build 70 LG~\ Baker Hughes INTEQ Planni ng Report bP INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 06-18 -Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 06 MD Reference: 28:18 5/10/1999 23:24 @ 66.59ft (Nabors 7ES) Well: 06-18 North Reference: True Wellbore: Plan 7, 06-18A Survey Calculation Method: Minimum Curvature Design: Plan #7 Database: EDM .16 - Anc Prod - WH24P Planned Survey ICI MD Inc Azi TVDSS N/S EMI Northing Easting DLeg V. Sec TFace ~ (ft) l°) (°) (ft) (ft) (ft) lft) lft) (°/100ft) (n) (°) 13,800.00 90.03 96.60 8,626.59 -3,914.94 6,499.38 5,936,962.43 692,702.91 12.00 7,495.29 90.01 13,800.01 90.03 96.60 8,626.59 -3,914.94 6,499.39 5,936,962.43 692,702.92 12.00 7,495.30 90.02 f~M2009 10:34:40AM Page 6 COMPASS 2003.16 Build 70 I/ilr ~ Baker Hughes INTEQ Planning Report by lNTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 06-18 -Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 06 MD Reference: 28:18 5/10/1999 23:24 @ 66.59ft (Nabors 7ES) :< Well: 06-18 North Reference: True Wellbore: Plan 7, 06-18A Survey Calculation Method: Minimum Curvature Design: Ptan #7 Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 06-18A Fault 2 0.00 0.00 0.00 -3,555.35 7,030.54 5,937,335.00 693,225.00 70° 13' 59.726 N 148° 26' 24.067 W - plan misses target center by 8650.41ft at 13800.01ft MD (8626.59 TVD , -3914.94 N, 6499. 39 E) - Polygon Point 1 0.00 -3,555.35 7,030.54 5,937,335.00 693,225.00 Point 2 0.00 -3,433.96 7,178.59 5,937,460.00 693,370.00 06-18A Target 2 0.00 0.00 8,600.00 -3,614.23 7,551.28 5,937,289.00 693,747.00 70° 13' 59.142 N 148° 26' 8.937 W - plan misses target center by 1094.35ft at 13800.01ft MD (8626.59 TVD , -3914.94 N, 6499. 39 E) - Point 06-18A Fault 3 0.00 0.00 0.00 -3,587.69 7,124.78 5,937,305.00 693,320.00 70° 13' 59.407 N 148° 26' 21.329 W - plan misses target center by 8655.42ft at 13800.01ft MD (8626.59 TVD , -3914.94 N, 6499. 39 E) - Polygon Point 1 0.00 -3,587.69 7,124.78 5,937,305.00 693,320.00 Point 2 0.00 -3,320.23 7,231.42 5,937,575.00 693,420.00 06-18A Fault 1 0.00 0.00 0.00 -3,771.77 5,464.63 5,937,080.00 691,665.00 70° 13' 57.611 N 148° 27' 9.574 W - plan misses target center by 8616.92ft at 12411.74ft MD (8612.60 TVD , -3773.60 N, 5191. 72 E) - Polygon Point 1 0.00 -3,771.77 5,464.63 5,937,080.00 691,665.00 Point 2 0.00 -3,785.66 6,229.57 5,937,085.00 692,430.00 06-18A Polygon 0.00 0.00 0.00 -2,432.88 3,301.89 5,938,365.00 689,470.00 70° 14' 10.791 N 148° 28' 12.401 W - plan misses target center by 8486.55ft at 9792.59ft MD (8483.98 TVD, -2354.49 N, 3108.37 E) - Polygon Point 1 0.00 -2,432.88 3,301.89 5,938,365.00 689,470.00 Point2 0.00 -3,861.99 5,472.40 5,936,990.00 691,675.00 Point 3 0.00 -3,877.67 6,107.24 5,936,990.00 692,310.00 Point 4 0.00 -3,596.82 7,494.69 5,937,305.00 693,690.00 Point 5 0.00 -3,838.24 7,548.75 5,937,065.00 693,750.00 Point 6 0.00 -4,245.85 5,622.98 5,936,610.00 691,835.00 Point 7 0.00 -2,659.49 3,161.24 5,938,135.00 689,335.00 06-18A Target 1 0.00 0.00 8,600.00 -3,971.75 5,501.70 5,936,881.00 691,707.00 70° 13' 55.643 N 148° 27' 8.501 W - plan misses target center by 22.97ft at 12782.33ft MD ( 8622.58 TVD, -3975.44 N, 5499.66 E) - Point 06-18A Target 3 0.00 0.00 8,600.00 -3,976.23 8,396.65 5,936,948.00 694,601.00 70° 13' 55.573 N 148° 25' 44.383 W - Ian misses tar et center b 1898.44ft at 13800.01ft MD 8626.59 TVD -3914.94 N 6499. 39 E 6/4/2009 10:34:40AM Page 7 COMPASS 2003.16 Build 70 -~ar Baker Hughes INTEQ Planning Report bP INTEQ Company: North America -ALASKA - BP Local Go-ordinate Reference: Well 06-18 -Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level - Site: PB DS 06 MD Reference: 28:18 5/10/1999 23:24 @ 66.59ft (Nabors 7ES) Well: 06-18 North Reference: True Wellbore: Plan 7, 06-18A Survey Calculation Method: Minimum Curvature Design: Plan #7 Database: EDM .16 - Anc Prod - WH24P L_ -Point - - - - °- 12,100.00 8,605.81 3 3/16" 3.188 4.125 Plan Annotations Measured Depth (ft) 9,792.59 9,860.00 9,880.00 10,027.11 10,227.11 10,427.11 10,482.11 10,732.11 11,032.11 11,232.11 11,532.11 11,832.11 12,032.11 12,232.11 12,482.11 12,782.11 13,082.11 13,282.11 13,552.11 13,800.01 Vertical Depth (ft) 8,483.98 8,543.50 8,561.01 8,624.36 8,601.91 8,578.54 8,575.45 8,578.41 8,584.93 8,589.05 8,594.95 8,600.47 8,604.37 8,608.58 8,614.32 8,622.57 8,627.04 8,626.90 8,626.73 8,626.59 Local Coordinates +N/-S +E/-W (ft) (ft) -2,354.49 3,108.37 -2,372.46 3,134.41 -2,378.03 3,142.31 -2,449.39 3,243.47 -2,594.27 3,377.35 -2,739.07 3,511.16 -2,770.69 3,556.02 -2,881.60 3,778.97 -3,022.63 4,041.77 -3,127.50 4,211.44 -3,299.52 4,455.10 -3,471.54 4,698.77 -3,576.41 4,868.44 -3,681.28 5,038.11 -3,818.58 5,245.79 -3,975.36 5,499.46 -3,991.98 5,794.05 -3,982.45 5,992.36 -3,950.22 6,256.82 -3,914.94 6,499.39 Comment TIP KOP End of 9 Deg/100' DLs End of 45 Deg/100' DLS 5 6 End of 12 Deg/100' DLS 8 9 10 11 12 13 14 15 End of 7 Deg/100' DLS 17 18 19 TD at 13800.01 Checked By: Approved By: Date: 6/4/2009 10:34:40AM Page 8 COMPASS 2003.16 Build 70 by Project: Prudhoe Ba , Ai'vnuWe to True Notn M¢ ce4c raom,: zz ]e WELLBORE DETAILS: Plan 7, 06-18A REFERENCE INFORMATION y Slle: PB DS 06 . g Magneac Fetl ~-08A Co-0Ninate (HIE) Reference: We106-18 -Slot 18, True North WBII: 06.18 SlrengW: 5]]10.asn V¢NCaI (TW) Refeence: M¢an 6¢a L¢V¢I Wellbofe: Plan 7, 06-18A Plan: Plan I{7 (06-161PIan 7, 06-18A) Dp Angle. BosO ~~~~~~~ Portent Wellbore: 06-18 Section (VS) Reference: Slot - 18(O.OON, O.OOE) Measured Oepth Reference: 28 18 511011999 23:24 ~ 66.59ft (Nabors 7ES) Tie On MD: 9792.59 CaIGIW1u0 Method. Minimum CunaWre WELL DETAILS: 06-18 Ground Levee. 0.00 +N/-S +E1-W Northing Easfing Latdtutle Longiwce S.el 0.00 0.00 5940715.47 686109.25 70° 14' 34.725 N 148° 29' 48 964 w 18 SECTION DETAILS ANNOTATIONS Sec MD Inc Azi ssND +NI•S +EI-W DLeg TFace VSec Target Annotatbn 1 9792.59 28.00 124.00 8483.98 -2354.49 3108.37 0.00 0.00 3894.58 TIP 2 9860.00 28.00 125.20 8543.50 -2372.46 3134.41 0.84 90.53 3926.09 KOP 3 9880.00 29.80 125.20 6561.01 -2378.03 3142.31 9.00 0.00 3935.72 End of 9 Deg/100' DLs 4 10027.11 96.00 125.20 6624.36 -2449.39 3243.47 45.00 0.00 4059.08 End of 45 Deg/100' DLS 5 10227.11 96.70 149.34 8601.91 •2594.27 3377.35 12.00 87.00 4254.76 5 6 10427.11 96.52 125.18 8578.54 -2739.07 3511.16 12.00 271.00 4450.35 6 7 10482.11 89.92 125.18 8575.45 -2770.69 3556.02 12.00 160.00 4505.03 End of 12 Deg/100' DLS 8 10732.11 88.73 107.72 8576.41 -2881.60 3778.97 7.00 266.00 4747.11 8 9 11032.11 86.81 128.72 8564.93 •3022.63 4041.77 7.00 90.00 5039.08 9 10 11232.11 88.85 114.72 8589.05 -3127.50 4211.44 7.00 270.00 5236.47 10 11 11532.11 88.92 135.72 8594.95 -3299.52 4455.10 7.00 90.00 5533.69 11 12 11832.11 88.99 114.72 8600.47 -3471.54 4698.77 7.00 270.00 5830.93 12 13 12032.11 88.78 128.72 8604.37 -3576.41 4868.44 7.00 91.00 6028.32 13 14 12232.11 88.62 114.72 8608.58 •3681.28 5038.11 7.00 270.00 6225.69 14 15 12482.11 88.57 132.22 8614.32 -3816.58 5245.79 7.00 91.00 6473.04 15 16 12782.11 88.31 111.21 8622.57 -3975.36 5499.46 7.00 269.00 6768.14 End of 7 Deg/100' DLS 17 13082.11 90.04 75.25 8627.04 •3991.98 5794.05 12.00 272.40 7004.49 17 18 13282.11 90.04 99.25 8626.90 -3982.45 5992.36 12.00 90.00 7150.28 18 19 13552.11 90.03 66.85 8626.73 -3950.22 6256.82 12.00 270.00 7332.15 19 20 13800.01 90.03 96.60 8626.59 -3914.94 6499.39 12.00 90.00 7495.30 TD at 13600.01 -120 -ISU -180 -21U -24U C -270 w O -30U 0 -33U .~ -360 O z -3Y0 ~ -42U 0 ~ -45U -axp -510 -540 s a 4'~-. O ,~. J. O, N A U .~ (~ s; 8~ 8: 8' 8. 9 9 9: 9 9~ Mean ; ®IN ~~ BAKER HUGHES 11\ 1 L' l~[ I I T i P K P I ~ r t ~ ~ ' ~ __. @nd oF 9 De -_ IfHY D ___-__ __- ~~ .___. t ~ r ~--~ ~_-Cnd of 45 eg/10~ -~~ d DLS 5- 1 ~ i t +- I t ~ t 9 t 10 3 3/16" 1 t 1 t t 06-1 A Ta et 1 _ __ IEVPI 7, 0 II 13 1 t -+S - ~_ - _ t 1 . _ _ 17 18 T Y at l~ 800.01 I H d of 7 - Deg/1 ' DL I I I 1 r -- - . I _- ___ - - _ f_.__- t-__. .__.-_ ._--. __-_ __.._. -_...._. _ . A 3000 3300 3600 39110 4200 45W 4800 SI00 5400 5700 6000 63U0 6600 69UU 7200 75W 78UU SIUO 84UU West(-)/East(+) (300 ft/in) 0 - I s _ __ ~ - d End oC9 Deg/Ip0' DLg Gte ~ o 12 ' ~ De 1 i 00 ' g ( 3 , 3/16" I ~ 06 18{1 Targe ' ~ t 1 ~~ 5 ~-Kph ~ _ _~ f r ~ t - _ - r '~ _ --_. - _ ~ ~. f --- 06 IS/Pla 7, 06 18A U -_ 1 - _~ _- - ~ - `_ ` T <. 5. i 6 .-~ ~ ---- 8 - 9 0 1 2 _ _. -- - ... _~. -._t -t _ _ at.. . 5 E d of 4 Deg/ 00' D S ~I~ - __, @rrd aC 7 ~ {~_ ~ _ __ __ l 5 . ~`_0 -181 -18 0 - - ; 5 -- _ I - _- - - ___-_ -_-. ----I __ ___. ._ . ..___. -- -- ---.. - -- ---__ _. _.. _. .___ . _. __. -.__._ ... OU ea ---..__.._ . - r ev91 .. _.___. --~- ~-- l • 3750 3YUU 4USU 42W 4350 4500 4650 4800 495U SIUO 525U 5400 SSSU 57UU SSSU 6000 6150 6300 6450 6600 6750 690U 7050 72UU 735U 7500 7650 78W 7YSU 8100 8250 84UU 8550 8700 885U 9W0 9150 9300 9450 Vertical Section at 130.00° (150 ft/in) by Project: Prudhoe Bay , n~muma io rrva Norm Megrretlc Nonn: zz 7e WELLBORE DETAILS: Plan 7, 06-18A REFERENCE INFDRMnnoN Site: PB DS 06 . Mepnatic Fea O6-08A Coordinate (N/E) Reference. Well OG18 - Sbl 18, True NoM Well: 06-18 Slrengln: 9]10 Bsn Venial (TVD) Reference. 28 :18 511011999 23:24 @ 66,59fl (Nabors 7E5) Wellbore: Plan 7, 06.18A Dy Angb' ~~~ Dare: Snarm Parent WellbOre: 06-18 Sectron (VS) Reference Slot- 18(O.OON, O.OOE) Plan: Plan #7 (06-781PIan 7, 06-78A) r4omr e0anlz T MD 7 2 Meawred Deplh Reference: 28:18 511011999 2 3:24@66.59f1 (Na6ors7ES 1 . ie On : 9 .59 9 Cakulalion Method. Minimum Curvature ~ti5 C w O 7O C 0 8 5/10/1999 2: a~ {~~i.r B fA/V^ii LNTEQ 1 -10/ 13-I A O , -1650 ~ -- -BUO _ -I95U ~ q - -06 08/0 -08 n o - I - u - zzs - - r ,, -zaoo ~-- 0 ....~ ! Ory - 2550 ~--- ~ ~ i ~ - 2 U - . `~ ^~ ; r. 071 C ~ N ~I - U 7 zasD _ - o -.a, of-' n -30W _a 315 ~ - - -3300 -~ ~ 3450 - - - \ - _ _ ~ 06- 8/PI n 7, 6-18 -36UU -, - I ~ 5^ i 375 - ~~ - - f b 5 ~ ~ - ~ T $~~ ~ p 40 ~ -3900 ~ ~ ~ 1-07 I-0 A l 0 a -aoso I - q eo -fir .o ~^ 06- OA/ 6-10 ~ \ -4350 r _. _- ~ ~ -asoU -II 1-0 01-0 O1 07/0 -07 PB l 9 -4650 -I L-- ~Q _ -48UU 20~ -sloo T - \ 12-I 112- 9 13 ~; I' 12A szs - ~ -54UU app ' ~~ 5550 _ ,_.... ._. - _. _. _ -.._.- -___ ..----- - 5 ~6 - ~:24 6 6.59Ft(Nabors 7ES) ~ ~ ~ a' 4 00 -5700 • ww auu »w ~y~u pow nrou ~7uv wwu w~uv yaw Mew ~wv wow vr~u nuu x~u ~ruu »>u ~ruu ~o~u ouvu ouu o~w ow~u oow onu owu rwu r_uu raw nuu ro~u rauu i»u ntuu at~u avuu e»u West(-)/East(+) (150 fUin) Pro~ett: Prudhoe Bay ANTI-COLLISION SETTINGS COMMNV orwLS rb,16 Am„~ -AUS w - m _ Sit PB DS 06 _ MOfiT M AM6aICA `` .' ~^ e: Well: 06-18 Interpolation McNOtl: MD, interval: 25.00 A ~~ BAKER P Depth Range From: 9792.59 To 13800.01 GI°YaOOn MMao4 Mxtimum CvMUIa a ~~~/~~~ Results Limited By: Centre Distance: 1577.04 Erm fiy¢iem: I6CWSA , t71YVt1i~ We1111ore: Plan 7, O6.18A Reference: Plan: Plan #7 (06-18IPIan 7, 0618A) ~" ~ Eninu~ca~a "°"" Plan: Plan #7 (06.18/Plan 7, 06-18A) Wam~B NeOn° `W"Bae° 1NTEQ From Cdour To MD +W-S 0.00 WELL DETAILS: 06-18 Ground Level: 0.00 +EI-W Nonhing Easting Latittude Longitude 0.00 5940715.47 686109.25 70° 14' 34.725 N 148° 29' 46.364 W SECTION DETAILS Sec MD Inc Azi TVD +W-S +E/-W DLeg TFace VSec 1 9792.59 28.00 124.00 8550.57 -3354.49 3100.37 0.00 0.00 3894.56 2 9860.00 28.00 125.20 0610.09 -237246 3130.41 0.8d 90.53 392609 3 9880.00 29.80 125.20 6627.60 -2378.03 3112.31 B 00 0.00 3935.72 4 5 10027.17 1022].11 Bfi.00 96.70 125.20 149.34 0690.95 6666.50 -2449.39 -2594.27 3203.47 45.00 0.00 4059.08 3377.35 12.00 6700 4254.76 6 10427.11 Bfi.52 125.16 6645.13 -2739.07 3511.16 12.00 2]1.00 4450.35 10482.11 89.92 125.16 6642.04 -2770.69 3556.02 12.00 180.00 4505.03 8 10732.11 88.73 107.72 6645.00 -2881.60 3776.97 7.00 266.00 4747.11 9 17032.17 88.61 126.72 8651.52 -3022.63 4011.77 7.00 90.00 503908 10 77232.11 88.85 714.72 6655.64 -312].50 4211.44 7.00 270.00 5236.47 11 12 11532.11 11832.11 88.92 88.99 135.72 114.72 6661.54 0667.06 -3299.52 -3471.50 4455.10 7.00 90 00 5533.69 4698.77 7.00 270.00 5830.93 13 72032.11 88.78 128.72 867096 -3576.41 48fi8.4d 7.00 91.00 6028.32 14 12232.11 86.82 711.72 6675 17 -3681 26 5038.11 7.00 270.00 6225 69 15 12482.11 BB.57 732.22 8680.91 -3818.56 5215.79 7 00 91 00 6473 64 16 12782.11 88.31 111.21 6689.16 -3975.36 519946 7.00 263.00 6768.10 17 13082.11 90.04 75.25 6693.63 -3991.98 5784.05 12.00 272.40 7004 49 16 13282.11 90.04 99.25 8693.49 3982./5 5932.36 12.00 90.00 7150.28 19 20 13552.11 73800.01 90.03 90.03 66.85 9660 8693.32 6693.18 -3950.22 3914.94 6256.82 12.00 27000 7332.15 6199.39 12.00 90.00 7495.30 Slot 18 Target SURVEY PROGRAM Date: 2009-06-04700:00:00 Validated: Yas Version: Depth From Deplh To SurveylPlan Tool 92.59 9792.59 1 : Camera Dried gyro multishlf~~7Bljt0-MS 9792.59 13800.01 Plan t{7 (Plan 7, 0618A) MWD LEGEND . O1-0], 01-07, 01-0I VS - 01-0], Ol-0]APBt, Ot-0]APBt V1 01-14,01-24, 01-24 V2 01-24A 01-24A, 01-14AV1 0604, 0604, 06-04 Vl - 06-04, O6-04A, 0604A V70 0604, O6-04A, O6-04A wIM V1 0605, 06-05, 06-05 Vi . 0606, D6-06, 06-06 Vte - Ds-os, o6osA, D6o6A vn - 06-06.06-068,06-068 VB « 0606, 06-068. 06068 wp08 V59 06-06.06-0fiBPB1, 06-06BPB1 V10 °0606, O6-06BPB1, 6068 PB1 WP04 V16 0607, 06-07. 06-07 V1 •'06-08.06-08,06-OB V1 Ofi-0BA O6-OBA O6-0eA V1 06-09. Plen O6-09A, 6-09A wp05 V12 v 0610, 0610, 0610 V1 .~ 0610q O6-tOA, ll6-t0A V3 - 061], 06-17. 06-17 Vlt - 0618, 0618. 06-18 Vfi 06-19,06-19,06-19 V2 0619. 06-19A, 0619A V2 « Ofi-20, Ofi-10, 06-20 V3 +0620. 0610A, 0620A V5 •~ 0620, 06-20A, 06-20A wp05 V40 0621, 06-21, 06-21 V5 • 0621, 0621 A. 0621A V6 0621, 0621A, Plan p2 Vt . 0621, 06-218. 06-218 V3 12-12. 12-12A, 12-12A V6 12-19, 72-19, 12-19 V1 13-10, 1}tOA, 13-t0A Wp 2 Vit c Ran 4] I Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [16 ft/in] Alaska Department of Natura)~sources Land Administration System. Page 1 of~' Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources ~~ Alaska DNR Case Summary File Type: ADL File Number: 28311 ~ Printable Case File Summary See Township, Range, Section and Acreage? New Search L~) Yes (_i No LAS Menu I Case Abstract ~ Case Detail ~ Land Abstract ~, File: ADL 28311 '''~' Search for Status_Plat Updates As of 06/12/2009 Customer-: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acs°es: 2560.000 Date Initiated: 05/28/1965 Office of Pf°imary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O1 ON Rarlge: 014E Section: O1 Section Acres: 640 Search Plats Meridian: U Township: O1 ON Range: 014E Section: 02 Section Acres: 640 Meridian: U Township: OlON Range: 014E Section: 11 Section Acres: 640 Meridian: U Township: 010N Range: 014E Sectiorv: 12 Section Acres: 640 Legal Description OS-28-1965 '~~*SALE NOTICE LEGAL DESCRIPTION*** C14-132 ION 14E UM 1, 2,11,12 2560.00 U- 3- 7 End of Case Summary Last updated on 06/12/2009. http://dnr.alaska.gov/projects/las/Case_Summary.cfin?FileType=ADL&FileNumber=2831... 6/12/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME I ~u O(Q~~~Pr PTD# ~ O ~ 0:63 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~r(,l t~-Flc~ ~, POOL: C. , 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 WALL P~Rfi~I? CI~~`CKLIS~ Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 .:, ___ Well Name: PRU_DHOE BAY UNIT 06-18A ___ ___Program DEV __ __ Well bore seg ^ PTD#:2090630 C . ompany BP EXPLORATION_(ALASKA~ INC __ __. ___ _ Initial ClasslType DEV! PEND _GecArea 890 __ _ _ Unit 11650. __ OnlOff Shore On__ Annular Disposal ^ Administration 1 Permii-fee attached- - _ _ NA 2 Lease number appropriat_e_ - Yes - - Ii3 Uni-que well name and number Yes ~,4 Well located in a defined pool Yes _ '5 Well located proper distance-from-drilling unit. boundary. - Yes _ - _ - 6 Welllocat_edproperdistance.from-othe_rwells Yes ',7 .Sufficient acreage available in-drilling unit. Yes - - 2560 acres. '8 If deviated, is wellbore plat-included _ _ Yes - II9 Operator only affected party- Yes - ~10 Operakor has. appropriate bond in force - Yes $lanket Bond # 6194193. '11 Permit can be issued without conservation order Yes - Appr Date 12 Permit can be issued without administrative approval Yes - 13 Can permit be approved before 15-day wait. Yes ACS 6!12!2009 14 Well located within area and-strata authorized by Injection Order # (put 10# in_comments)-(For- NA_ I15 All wells within 114. mile area of review identified (For service wel_I only) NA 16 Pre-produced injector: duration ofpre-production less than 3 months. (For service well-only) NA ~'i17 Nonconven, gas conforms to AS31,05,030Q,1.A),Q.2.A-D) NA '18 Conductor stnny provided NA- Conductor set_in DS 06-18 (182-099).. Engineering 19 Surface casing protects all-known- USDWs NA- - Surface casing set in DS 06-18. ' 20 CMT. vol-adequate to circulate on conductor & surf-csg NA- Surface casing set in DS 06-18. Ii21 CMTyoI_ adeguateto tie-in long string to surf csg NA Production_casing set in DS 06-1.8. - - - ~~i22 CMT-will coyer all known-productive horizons.. - No - Open hole completion planned in oil-zone. ~i23 .Casing designs adequate for G, T, B & permafrost - Yes ~~24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned._ All waste to approved disposal w_ell(s). '25 If a-re-drill, has a 10-403 for abandonment been approved Yes _ _ _ 309-195 _ _ 26 Adequate wellbore separation proposed Yes Proximity analysis performed, Closest segment. is P&A portion of DS 06-18 and-paths diverge.. '127 If diverter required, does it meet regulations- NA BOP stack already in place, _ - Appr Date I'~28 Drilling fluid-program schematic & equip list adequate. Yes Maximum expected fo[mation_ pressure 7.4 EMW, PI_anned MW 8.6ppg. TEM 611612009 ,29 BOPEs, do ihey meet regulation Yes ('~ 30 BOPE press rating appropriate; test to-(put prig in comments)- Yes MASP calculated at 2442 psi. 3500 psi BOP testplanned, ~ "mss ~ '' ',31 Choke manifold complies wlAPl RP-53 (M_ay 84) Yes ~i32 Work will occur without operation shutdown_ Yes - - I~I33 Is presence of H2S gas. probable. - Yes H2S present at DS 06._ Mud should preclude H2S on-rig.. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (Fo[servce well only) NA- - _- - _ _ --- 35 Permit can be issued w/o hytlr_ogen sulfide measures No- Max. Level H2S on DS 06 is 200ppm on well 06-18 {611/08).- Geology 36 Data presented on potential overpressure zones NA Appr Date 137 Seismic analys_is_of shallow gas zones NA_ _ _ _ _ _ ACS 6!12!2009 X38 Seabed condition survey_(if off_-shore) N_A_ 39 Contact namelphone for weekly-progress reports_ [explora_tory only] - - - - Yes - Mel R_ixse - 56.4-5620... Geologic Engineering Public Commissioner: Date: Com issioner: .Date Commissioner Date • • Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history fife. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. tapescan.txt **** REEL HEADER **** MWD 10/01/18 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/10/23 2810460 O1 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las w version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9275.0000: starting Depth STOP.FT 13997.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 06-18A FLD FIELD: Prudhoe Bay Unit LoC LOCATION: 70 deg 14' 34.725"N 148 deg 29' 48.364"w cNTY. couNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 23 OCt 2009 API API NUMBER: 500292076701 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 02 TOWN.N T10N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 74 DMF DF EKB .F 0 EDF .F 74 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. <2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. Page 1 a~g-o~3 ~~a3~ CJ tapescan.txt (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Cont rol log from Schlumberger GR cNL 12 Oct 2009 per Mikie weeks with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 06-18A through a milled window in a 7 inch liner. Top of window 9868 ft.MD (8544.1 ft.TVDSS) Bottom of window 9873 ft.MD (8548.7 ft.TVD55) RA Tag 9873 ft.Md (8548.8 ft.TVDSS) (9) Tied to 06-18 at 9 880 feet MD (8554.46 feet TVDSS). (10) The interval from 13970 feet to 14000 feet MD (8678.7 ft. to 8680.2 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROPJ~VG -> Rate of Pen etration, feet/hour RACLx -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHZ-Compensated Borehole Corrected (OHMM) RPCLX -> ReSlStivity (PD)(LS)400kHZ-Compensated BOrehOle corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True Vertic al Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9354.08, 9351.93, ! -2.15234 9359.65, 9358.21, ! -1.43457 9362.16, 9362.34, ! 0.179688 9369.33, 9367.9, ! -1.43555 9371.67, 9369.51, ! -2.15332 9373.1, 9370.95, ! -2.15332 9374.18, 9372.56, ! -1.61523 9377.41, 9375.25, ! -2.15332 9381.93, 9379.78, ! -2.15332 9384.26, 9382.29, ! -1.97363 9396.64, 9395.21, ! -1.43555 9401.67, 9399.87, ! -1.79395 9413.15, 9412.43, ! -0.716797 9417.45, 9416.92, ! -0.538086 9429.47, 9428.22, ! -1.25586 9432.52, 9431.45, ! -1.07617 9437.37, 9435.39, ! -1.97363 9441.49, 9439.7, ! -1.79395 9813.53, 9813.17, ! -0.359375 9821.42, 9820.88, ! -0.538086 9825.73, 9824.65, ! -1.07617 9828.06, 9826.44, ! -1.61426 9830.03, 9829.49, ! -0.538086 9833.98, 9834.16, ! 0.178711 9839.54, 9837.21, ! -2.33301 9843.85, 9841.33, ! -2.51172 9846.9, 9846.54, ! -0.359375 9849.95, 9848.51, ! -1.43555 9850.84, 9849.41, ! -1.43457 9853.53, 9852.1, ! -1.43555 9855.51, 9853.71, ! -1.79395 9865.91, 9862.86, ! -3.0498 9868.6, 9866.27, ! -2.33301 9873.93, 9871.96, ! -1.97363 9875.55, 9873.75, ! -1.79395 9879.49, 9877.52, ! -1.97363 9882.19, 9880.39, ! -1.79492 9885.06, 9883.62, ! -1.43555 9890.44, 9889.36, ! -1.07617 9898.87, 9897.61, ! -1.25586 9904.97, 9903.53, ! -1.43555 9913.04, 9912.33, ! -0.717773 9915.73, 9914.48, ! -1.25586 Page 2 9917.89, 9916.63, 9922.91, 9922.19, 9924.52, 9923.63, 9927.04, 9925.96, 9929.77, 9928.33, 9935.15, 9934.97, 9937.84, 9937.48, 9942.86, 9941.79, 9946.27, 9945.55, 9949.95, 9949.59, 9954.07, 9953.35, 9956.05, 9955.15, 9958.2, 9957.3, 9962.5, 9962.15, 9963.94, 9963.4, 9965.55, 9965.55, 9967.53, 9967.53, 9969.86, 9969.86, 9974.17, 9973.63, 9979.91, 9979.55, 9982.23, 9982.59, 9984.21, 9985.82, 9988.15, 9987.43, 9991.92, 9990.84, 9993.89, 9993, 9996.76, 9996.4, 10003.4, 10002.7, 10005.6, 10004.8, 10015.1, 10013.1, 10025.1, 10023.7, 10028.9, 10028.2, 10032.8, 10031.2, 10042.1, 10043, 10045.6, 10044.8, 10057.9, 10056.4, 10064.2, 10063.1, 10072.1, 10071.2, 10078.7, 10075.6, 10082.8, 10080.3, 10102.2, 10099.7, 10109.5, 10107.6, 10111.7, 10110.3, 10120, 10116.8, 10122.9, 10120, 10131.5, 10128.6, 10134, 10131.5, 10140.4, 10137.9, 10143.5, 10142.6, 10150.9, 10152.9, 10156.4, 10157.5, 10189.6, 10186.2, 10199.1, 10196.8, 10203.3, 10201.1, 10206.7, 10204.9, 10211.7, 10210.1, 10218.3, 10215.5, 10220.3, 10217.8, 10223, 10220.5, 10227.5, 10227.1, 10234.7, 10232.9, 10236.8, 10237, 10242.6, 10241.5, 10249.4, 10248.3, 10251.5, 10250.8, 10259.8, 10258.3, 10265.5, 10264.4, 10276.9, 10273.1, 10279.9, 10275.8, 10285.3, 10283.7, 10290, 10288.6, tapescan.txt -1.25586 -0.717773 -0.897461 -1.07617 -1.43555 -0.178711 -0.358398 -1.07617 -0.717773 -0.359375 -0.717773 -0.897461 -0.896484 -0.358398 -0.538086 0 0 0 -0.539062 -0.358398 0.359375 1.61426 -0.717773 -1.07715 -0.896484 -0.359375 -0.717773 -0.716797 -1.97363 -1.43555 -0.717773 -1.61426 0.897461 -0.716797 -1.43555 -1.07617 -0.897461 -3.0498 -2.51172 -2.51172 -1.97363 -1.43457 -3.22852 -2.87109 -2.87109 -2.51172 -2.51172 -0.896484 1.97363 1.07617 -3.4082 -2.33301 -2.15332 -1.79395 -1.61426 -2.87012 -2.51172 -2.51172 -0.359375 -1.79395 0.179688 -1.07617 -1.07617 -0.717773 -1.43555 -1.07617 -3.76758 -4.12695 -1.61426 -1.43457 Page 3 10293.2, 10290.5, 10295.5, 10294.5, 10300.8, 10299.1, 10302.2, 10300.6, 10308.8, 10307.6, 10316, 10313.7, 10319.2, 10319.2, 10327.8, 10325.7, 10333.4, 10332.3, 10337.7, 10337.2, 10345.1, 10344.9, 10346.9, 10346.5, 10349.9, 10350.4, 10356.2, 10355.3, 10358, 10356.4, 10361.2, 10359.6, 10368.1, 10367, 10369.5, 10368.4, 10375.2, 10374.7, 10376.8, 10376.1, 10382.1, 10380.8, 10386, 10384, 10390.5, 10387.6, 10394.3, 10393, 10399.8, 10398.6, 10405.2, 10403.4, 10407.5, 10405.7, 10410.6, 10409.5, 10416.5, 10414.7, 10418.5, 10418.1, 10421.9, 10420.8, 10423.3, 10422.6, 10426.7, 10425.5, 10428.9, 10428.2, 10433.9, 10432.8, 10441.4, 10438.9, 10445.2, 10442.3, 10450.6, 10448.1, 10456.5, 10456.3, 10482.6, 10482, 10484.9, 10484.3, 10486.1, 10486.1, 10491.3, 10491.2, 10502, 10500.2, 10505.1, 10503.4, 10509.5, 10507.2, 10513.7, 10511.3, 10518, 10516.2, 10532.3, 10531.6, 10581.8, 10579.5, 10583.8, 10581.1, 10586.7, 10583.6, 10587.9, 10584.9, 10591.9, 10589, 10594.2, 10591.3, 10595.8, 10593.1, 10597.3, 10595.3, 10600.1, 10597.9, 10602.2, 10599.7, 10605.6, 10604.9, 10610.8, 10608.3, 10614.6, 10613.2, 10624.8, 10621.8, 10629.3, 10626.4, 10632.5, 10630, 10640.1, 10637.7, 10651.2, 10649, 10656.8, 10655.3, 10663.4, 10662.5, 10669.9, 10668.8, tapescan.txt -2.69141 -1.07617 -1.61523 -1.61523 -1.25586 -2.33203 -2.15332 -1.07617 -0.538086 -0.179688 -0.358398 0.538086 -0.897461 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`96LOT `Z'T6LOT `T'S6LOT `T'TLLOT `8'TLLOT `6'L9LOT `T'69LOT 'Z'S9LOT `6'S9LOT 'L'Z9LOT `9'f9LOT `T'ZSLOT `S'£SLOT `L'8bLOT `8'6bLOT `b'TZLOT `Z'£ZLOT `T'6TLOT `b'OZLOT `STLOT `9'9TLOT `b'TTLOT `L'ZTLOT `f'LOLOT `f'60LOT `6'SOLOT 'Z'80LOT `9'ZOLOT `b'bOLOT `9'Z690T `S'£690T `9'0690T `6'T690T `T'8890T `8'8890T `5'b890T `9890T `T'T890T `L'Z890T `b'8L90T `8'0890T ~ ~ tapescan.txt Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 10 bytes 132 bytes 1024 *** INFORMATION TABLE: CONS *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth control log provided by Schlumberger GR CNL-dated 12 oct 2009 per Mikie weeks with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logyin direction is down (value= 255) Optical Loy Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 curves: Name Tool code Samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 113 1 Size Length 4 4 4 4 8 Tape File Start Depth = 9275.000000 Tape File End Depth = 13997.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 122 records... Minimum record length: 54 bytes Page 6 Maximum record length: 4124 bytes tapescan.txt **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS ~** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Lod Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 1 Size Length 4 4 4 4 8 Total Data Records: 225 Tape File start Depth = 9277.000000 Tape File End Depth = 14000.750000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **~* FILE TRAILER **** Tape Subfile: 3 234 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER '~*** Page 7 I. • • MWD 09/10/23 2810460 O1 **** REEL TRAILER **** MWD 10/01/18 BHI O1 tapescan.txt Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS Tape subfile 2 is type: LIS DEPTH GR ROP 9275.0000 -999.2500 -999.2500 9275.5000 95.7900 -999.2500 13997.0000 146.2000 12.9000 Tape File Start Depth = 9275.000000 Tape File End Depth = 13997.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LI5 DEPTH GR ROP 9277.0000 -999.2500 -999.2500 9277.2500 -999.2500 -999.2500 14000.7500 -999.2500 -999.2500 Tape File Start Depth = 9277.000000 Tape File End Depth = 14000.750000 Tape File Level spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LI5 Page 8
