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Home My WebLink About203-0641. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Swap w/ Packer Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,845 feet N/A feet true vertical 7,065 feet N/A feet Effective Depth measured 8,810 feet 3,974 feet true vertical 7,069 feet 3,973 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 6,817' 6,795' Packers & SSSV (type, measured and true vertical depth)Viking Hyd ESP Pckr N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC 777-8520 2. Operator Name Senior Engineer: Senior Res. Engineer: 10,570psi Collapse 2,670psi 4,760psi 7,145' 7,065' 7,020psi 10,530psi Burst 5,380psi 6,870psi 8,160psi 10,160psi 11,160psi 7,660psi 13-3/8" 9-5/8" 7" 3-1/2" 8,520psi 2,483' 6,946' 6,852' Liner 1,226' Length 70' 2,452' 6,942' Surface Production N/A measured 30' 744' N/A Liner Liner Casing Conductor Size 580 MILNE PT UNIT L-01A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 425 Gas-Mcf 1,480 Casing Pressure Tubing Pressure 32 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-072 543 Authorized Signature with date: Authorized Name: Ian Toomey itoomey@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-064 50-029-21068-01-00 Plugs ADL0025509 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 3310 858 Oil-Bbl measured true vertical Packer 3-3/16" 2-7/8" 6,875' 7,619' WINJ WAG 0 Water-Bbl MD 70' 2,483' 6,972' 8,845' TVD 70' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:07 pm, Mar 25, 2021 Chad Helgeson (1517) 2021.03.25 08:27:30 - 08'00' MGR28MAR21 RBDMS HEW 3/25/2021 DSR-4/1/21 SFD 3/26/2021 _____________________________________________________________________________________ Revised By: TDF 3/2/2021 SCHEMATIC Milne Point Unit Well: MPU L-01A Last Completed: 2/28/2021 PTD: 203-064 TD =8,845’(MD) / TD =7,065’ (TVD) 13-3/8” Orig. DF Elev. = 56.0’ / GL Elev.= 17.0’ Nabors 27E 7” 1 6 7 & 8 9, 10 & 11 12 13 19 4 14 18 PBTD =8,810’(MD) / PBTD =7,069’(TVD) 5 9-5/8” Min ID = 2.205” @ 6,684’ 3 2 15 1617 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 72 / L-80 / BTRC 12.347 Surface 70' 0.1481 9-5/8” Surface 47 / L-80 / BTRC 8.681 Surface 2,483’ 0.0732 7” Surface 29 / L-80 / BTRC 6.184 Surface 6,972’ 0.0371 3-1/2" Liner 9.3 / L-80 / STL 2.992 6,845’ 6,875’ N/A 3-3/16” Liner 6.2 / L-80 / TCII 2.800 6,875’ 7,619’ N/A 2-7/8” Liner 6.4 / L-80 / STL 2.441 7,619’ 8,845’ N/A TUBING DETAIL 2-7/8” Tubing 6.5# / L-80 / EUE 8rd 2.441 Surface 6,817’ 0.0058 JEWELRY DETAIL No Depth Item 1 141’ Sta. 3: 2-7/8"x1" GLM Dummy Valve w/ BK latch 2 3,915’ Sta. 2: 2-7/8"x1" GLM Dummy Valve KBBM WDGLV 3 3,974’ Viking Hyd Set ESP Packer W/Dual vent valve 4 4,030’ 2-7/8” X Nipple (2.313” ID) 5 6,602’ Sta. 1: 2-7/8"x1" GLM Dummy Valve KBBM WDGLV 6 6,661’ 2-7/8” HES XN Nip, MIN ID= 2.205” 7 6,713’ Discharge Head: 400 PN/ C63029 2.785X8 EUE 8 6,714’ Zenith Ported Sub: PRESS PORT 400P 9 6,715’ Pump 3: 400PMSXD 134 FLEXER HF H6 FE 10 6,738’ Pump 2: 400PMSXD 134 FLEXER HF H6 FE 11 6,762’ Pump 1: 400PMSXD 134 FLEXER HF H6 FE 12 6,785’ Gas Separator: 400GSV X M FER NO PNT 13 6,788’ Tandem Seal Sections: (2) GSBDB H6 SB/AB PFSA 14 6,801’ Motor: 562XP -150Hp/2,420V/38A 125/2020 06R 15 6,812’ Zenith Sensor: w/6 fin centralizer – Btm @ ±6,817’ 16 6,838.1’ Baker Fluted Head 17 6,838.4’ Baker Tie Back Sleeve 18 6,845’ Baker Deployment Sleeve w/ 4” Profile 19 6,864’ X-Nipple – 3.7” ID 20 8,843’ Baker Tapered Guide Shoe – Btm @ 8,845’ OPEN HOLE / CEMENT DETAIL 13-3/8" Cement to Surface in 17-1/2”” Hole 9-5/8” 1000 sx of CSIII, 750 sx CSIII in 12-1/4” Hole 7” 750 sx Class “G”, 600 sx Class ‘G’ in 8-1/2” Hole Liner 100 sx CSI,147 sx Class ‘G’ WELL INCLINATION DETAIL KOP @ 6,972’ MD Above sidetrack: Max Hole Angle = 16° at 6,500’; Max DSL = 3°/100’ at 6,300’ Sidetrack: Max Hole Angle = 90° - 103°; Max DSL = 40°/100’ GENERAL WELL INFO API: 50-029-21068-01-00 Drilled and Completed by Nabors 27E - 11/3/1984 Drilled and Completed by Nordic 2– 6/14/2003 ESP RWO by Nabors 4ES – 11/13/2005 ESP RWO by Doyon 16 – 5/1/2014 ESP Swap w/ Packer by Doyon 14 - 2/28/2021 WINDOW DETAIL Window in 7” Casing @ 6,972’ to 6,980’ Well Angle @ Window =13 deg. WELLHEAD Tree 2-9/16” – 5M Wellhead 13-5/8” x 11” 5M CIW ‘DGB’ tubing spool w/ 11” x 2-7/8” CIW Tubing Hanger, 2-7/8” EUE 8rd threads top & bottom, 2.5” CIW=H BPV Profile 20 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Type Date Status Kuparuk 7,680 7,840’ 7,139’ 7,108’ 160 3-3/8” /6SPF 6/3/03 Open 8,130’ 8,340’ 7,084’ 7,097’ 210 3-3/8” /6SPF 6/3/03 Open 8,490’ 8,800’ 7,091’ 7,070’ 310 3-3/8” /6SPF 6/3/03 Open Reference Log: Dual Induction – SFL Dated 6/8/1994 Well Name Rig API Number Well Permit Number Start Date End Date MP L-01A Doyon 14 50-029-23011-01-00 214153 2/23/2021 3/1/2021 Hilcorp Alaska, LLC Weekly Operations Summary 2/23/2021 - Tuesday Finish skidding rig floor into moving position, PJSM. Move rig off L-25, around north end of the pad to west side. Hilcorp electrician remove light off L-13 wellhouse. Spot rig on L-01A and shim level. Skid rig floor into drilling position. Begin rigging up. Hook up power to top drive. Hang joint in elevators to ensure rig is centered and level. R/U rig floor steam, water, air and high pressure mud lines. Prepare mud pits for fluid and load w/ 11.1 ppg NaCl/NaBr brine. Spot rock washer and fuel trailer. Lower stairways and install landings. Spot cuttings tank and build containment. R/U 2" hardline and hoses to flow back tank. Install 1502 flange on annulus. Load fresh water into pit #4. Fill lines with fresh water and pressure test. 1502 connection on hardline leaked. Blow down lines, inspect gasket and make back up. Pressure test to 3300 PSI - good. 1150 PSI on tubing and 1450 PSI on annulus. Line up to pump down tubing and take returns out IA. Pump 25 bbls 11.1 ppg viscosified spacer followed by 11.1 ppg NaCl/NaBr. 2 BPM while holding 1700 PSI on the IA for 1st 40 bbls. Increase rate to 4 BPM and hold tubing pressure at 1350-1450 PSI. Observe good 11.1 ppg back to flow back tank and shut down at 298 bbls total pumped. Initial 220 PSI on tubing and IA. Pump additional 20 bbls at 2 BPM, good 11.1 ppg out. Bleed pressure and shut in multiple times with lowest pressures of 60 on tubing and 80 PSI on IA. Pressure began to build to 40 PSI on tubing and 125 on IA,Pump 30 bbls at 4 BPM, 1700 PSI with good 11.1 out. 110 PSI on tubing and 225 PSI on IA and built to 140 on tubing and 225 on IA. Consult completions engineer. Will pump 40 bbls tubing volume then bullhead 20 bbls to fill volume beneath tubing to Kuparuk with 11.1 ppg brine. Pump 40 bbls 11.1 ppg brine at 4 BPM, 1700 PSI while holding 150 PSI back pressure with choke on tubing returns. 37 bbls returns by tank strap. Bullhead 20 bbls at 1 BPM, 490 ICP, 820 FCP. Shut down and monitor while vac truck emptied flow back tank. Tubing 640 PSI, IA 720 PSI initially after bull heading. Tubing 300 PSI, IA 380 PSI after 30 minutes. Tubing 240 PSI, IA 340 PSI after 60 minutes. Tubing 220 PSI, IA 320 PSI after 75 minutes. Bleed off tubing in 1 min intervals f/ 220 PSI to 105 PSI w/ 2 bbls bled back to tank - IA dropped to 200 PSI. Bleed off IA in 1 min intervals f/ 200 PSI to 55 PSI w/ 5 bbls bled back to tank - tubing dropped to 50 PSI but IA built back to 140. Bleed tubing in 1 min intervals f/ 50 PSI to 30 PSI w/ 1/2 bbl bled back to tank - IA built to 160 PSI. Strong steady flow out of tubing to 30 PSI three times. R/U lines to take returns from the IA to the mud pits through the gas buster. 30 PSI with 11.1 brine in hole at deepest Kuparuk 7139' = 0.1 ppg + 0.2 ppg trip margin = 0.3 ppg = 11.4 ppg kill weight. Weight up 69 bbls of brine in pit #4 and load the hopper room with NaBr. Well Name Rig API Number Well Permit Number Start Date End Date MP L-01A Doyon 14 50-029-23011-01-00 214153 2/23/2021 3/1/2021 Hilcorp Alaska, LLC Weekly Operations Summary 2/24/2021 - Wednesday Finish rig up to take returns from the cellar to the choke manifold. Finished weighting up surface pit to 11.4 ppg NaCl/NaBr brine. Fill lines with water and test to 2500 PSI - good. PJSM. Pump 40 bbls 11.4 ppg NaCl/NaBr brine down the tubing taking returns out the IA, 2 BPM, 690 PSI ICP / 480 PSI FCP on tubing, 420 PSI ICP / 390 PSI FCP on IA. Bullhead 20 bbls at 1 BPM, 660 PSI ICP / 750 PSI FCP tubing, 700 PSI ICP / 880 PSI FCP on IA. Monitor for 25 min - Tubing drop from 380 to 250 PSI, IA drop from 565 to 430 PSI. Continue to circulate at 1-2 BPM, 770 PSI ICP / 440 PSI FCP on tubing, 420 PSI ICP / 165 PSI FCP on IA. 11.4 ppg returns at 297 bbls pumped, pump additional 23 bbls excess for 320 bbls pumped with 11.4 ppg returns. Monitor well. Shut in 5 min - 200 PSI tubing, 165 PSI IA. Bleed 3 bbls to pits then shut for 15 min - 100 PSI tubing, 64 PSI IA. Bleed 2 bbls to pits over 10 min then shut for 10 min - 70 PSI tubing, 29 PSI IA. Bleed IA on hour until static. Bleed tubing one hour from 30 PSI to 18 PSI with 1.3 bbls bled back. Pump additional 118 bbls 11.4 ppg brine at 1 BPM 150 PSI increasing to 3 BPM, 800 PSI, slow to 1.8 BPM, 340 PSI because of suspected losses. Bleed 5 bbls off tubing & IA with 2.9 BPH initial flow slowing to 0.7 BPH. Bleed 2.2 bbls back with 1.38 BPH initial flow which almost stopped then picked back up to 4.9 BPH. Shut in and observe 12 PSI on tubing and IA. Prepare to weight up 11.7 ppg with NaBr. Load hopper room and mud man create mix plan. Weight up 100 bbls brine in pit #4. Tubing built to 14 PSI and IA to 40 PSI. PJSM and begin well kill with 11.7 ppg NaCl brine. Pump 40 bbls tubing volume at 1.5 BPM, 250 PSI ICP / 260 PSI FCP. Bullhead 20 bbls at 1 BPM, 320 PSI ICP / 790 PSI FCP. Allow formation to relax after bullheading, monitor pressures. Initial 500 PSI on tubing and 530 on IA reduced to 190 PSI on tubing and 200 PSI on IA in 20 minutes. Continue to mix and pump 11.7 ppg kill weight brine, 1 BPM, 90 PSI ICP / 150 PSI FCP on tubing with 80 PSI ICP / 50 PSI FCP on IA. Good 11.7 ppg out at 298 bbls total pumped. Pump additional 20 bbls with good 11.7 ppg entire extra volume. Shut down, equalize tubing and IA. Observe 4 PSI residual pressure on gauge. Bleed off 0.25 bbl and well went static. Perform 30 minute flow check - static. Blow down and rig down circulating lines. Sim-ops: Grease choke manifold for upcoming BOP test. Install BPV. N/D tree & separate adapter flange from tree. Remove adapter flange from cellar to send to Deadhorse for machining. Install test dart in BPV & pressure test against test dart to 5000 PSI - good. Inspect hanger threads - good. Consulted well head & Centrilift reps: ESP penetrator tool long to test lower pipe rams. Cut 5" of penetrator to provide room for donut test joint. AOGCC notified of upcoming BOP test 15:22 on 22 February 2021. Well Name Rig API Number Well Permit Number Start Date End Date MP L-01A Doyon 14 50-029-23011-01-00 214153 2/23/2021 3/1/2021 Hilcorp Alaska, LLC Weekly Operations Summary 2/26/2021 - Friday Continue POOH racking back stands of 2-7/8" 6.5# EUE L-80 tubing from 5584' to 72’. Replace necessary seal rings and SLM stands in Derrick. 6 joints laid down due to galled threads and damaged pipe while backing out tight connections. 3 BPH losses,Terminate ESP @ MLE. Splice ESP end w/ cable end. All ESP cable spooled to unit. Lay down ESP pump assembly to shed. 113 total cannon clamps recovered. Clear and clean rig floor. R/D Centrilift drain hose. Mobilize new jewelry to pipe shed. Remove used ESP spool from unit and mobilize control line to spooling unit. String control line & ESP cable to rig floor. R/U Centrilift equipment. PJSM. P/U, M/U & service ESP/Motor and seal assy. Connect ESP cable, 100' control line discharge, to motor and gauge assembly. Install 2 bolt on clamps to motor & seal assy connections and 7 pump cannon clamps. RIH with ESP on 2-7/8" 6.5# EUE L-80 tubing t/ 144’. Perform tests on ESP cable. Good test. RIH with ESP on 2-7/8" 6.5# EUE L-80 tubing f/ 144' to 2586'. Torque to 2250 ft/lbs, Install cannon clamp every connection for first 10 jts. Install cannon clamp every other connection from jt #10. Test cable connection every 1000’. Losses @ 1 BPH,ESP cable "cats nested" on spool. Sort and adjust cable to continue running. 2/25/2021 - Thursday Finish removing adapter flange from cellar. N/U BOPs, M/U kill line, energize accumulator, install riser. R/U test equipment, fill BOP stack and lines with fresh water. Perform shell test - choke Oteco flange leaking. Perform 250/2500 PSI shell test - good. Wait on AOGCC inspector to arrive to witness testing. Hang on centrilift sheave, change out driller's side cellar bridge crane wire rope and repair BOP transport pedastal. Test BOPs as per AOGCC, PTD and Hilcorp requirements with AOGCC inspector Guy Cook witnessing. All test performed with fresh water against a test dart installed in BPV. Test held for 5 min each and charted. Annular tested to 250 PSI / 2500 PSI & all other tests to 250 PSI / 4000 PSI. 1) Annular on 2-7/8" test joint, 2) Upper 2-7/8" x 5" VBR on 2- 7/8" test joint, choke valves 12, 13, 14, kill line Demco & 3-1/2" dart valve, 3) Choke valves 9, 11, HCR kill & 3-1/2" FOSV, 4) Choke valves 5, 8, 10, manual kill & upper IBOP, 5) Choke valves 4, 6, 7 & lower IBOP, 6) Choke valve 2, 7) Lower 2-7/8" x 5" VBR on 2-7/8" test joint, 8) Choke valve 3, 9) Choke valve 1, 10) Manual choke B, 11) Hydraulic choke A, 12) HCR choke - Failed, 13) Manual choke valve, 14) Blind rams, PJSM to replace HCR choke. Remove and replace HCR choke valve. Rig up test equipment to re-test HCR choke valve. Close upper 2-7/8" x 5" VBR on 2-7/8" test joint. 15) HCR choke after R&R - Pass. 250 PSI low / 4000 PSI high,Blow down lines and rig down test equipment. Remove test dart and BPV. M/U 2-7/8" EUE landing joint, XO, FOSV, XO and 2-7/8" pup joint. BOLDS, all of them were tight after 7 years since installation, utilized air impact gun. PJSM. P/U and unseat hanger with 86K (40K block weight) and hoist hanger to the rig floor with 83K PU. Cut ESP cable and remove penetrator from the hanger. L/D hanger and landing joint. Remove pup joint and XO from FOSV. Crimp cable pulls on ESP cable, hang ESP elephant trunk and pull rope through. Attempt to mobilize control line spooling unit to the rig floor, too big for beaverslide opening. L/D 10.56' pup joint (bad pin) and joint # 211 (bad box), L/D joints #210 & 209 for even stands and GLM. Rack back stands of 2-7/8" 6.5# EUE L-80 tubing from 6490' to 6239'. Install belly board in derrick. Continue POOH from 6239' to 5584'. Well Name Rig API Number Well Permit Number Start Date End Date MP L-01A Doyon 14 50-029-23011-01-00 214153 2/23/2021 3/1/2021 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. Continue RIH with ESP on 2-7/8" 6.5# EUE L-80 tubing f/ 2586' to 2840'. Torque to 2250 ft/lbs. Install cannon clamp every other connection. 61k P/U, 61k SO,M/U 7” Viking Packer. Make ESP cable and control line splice at packer. Test ESP cable and control lines. Pump through control lines at 3800 psi. Drain Stack for visual confirmation of Packer going through Stack and Well head without hanging up. SimOps: Disassembly control line spool to fit through beaver slide opening, mobilize to rig floor and reassemble. Continue RIH with ESP on 2-7/8" 6.5# EUE L-80 tubing f/ 2840' to 6780'. Torque to 2250 ft/lbs. Install cannon clamp every other connection and above & below GLM bodies. Test cable connection every 1000’. Tubing drifted t/ 2.34”. Losses @ 1 BPH . 85k P/U, 85k SO. Total 28 bbls loss while running completion string. Rig up landing joint with cross overs and FOSV to Hanger. Dress Hanger with new seals and M/U to tubing. Test cable connections. Install penetrator and control lines in Hanger. Splice ESP cable to penetrator and attach umbilical cord. Pump through control lines at 3800 psi. Land tubing with 45k on Hanger. Motor Centralizer at 6817' RILDS. Total 113 cross collar cannon clamps, 7 pump clamps & 2 protectorlizer clamps used, L/D landing joint, cross overs and FOSV. Install BPV. Pull riser, N/D BOPE, hoist stack and set on stump. Install plug in BPV.,N/U adaptor flange and Tree. Centrilift take final readings. 4.4 phase to phase, 780 meg, 4107 pump intake psi, 4090 discharge psi, 161.5° Ti, 165.4° Tm, .0 vib, 120.9 v. 9.9 amps. 2/27/2021 - Saturday Slickline, pull ball and rod, pull DGLV and set DPSOV in sta #3, Pull RHC. LRS freeze protect tubing. 3/2/2021 - Tuesday 2/28/2021 - Sunday Fill gland void with plastic and test to 500/5000 psi for 10 min. R/U & test tree to 250/5000 psi. Good. Pull BPV & Test dart. R/U circ lines to tree. Test to 3000 psi. Good. Line up on 7'' X 2 7/8 and bullhead at 1 bpm. 65 bbl seawater with corrosion inhibiter. with 1% Concor 303. Final circ pressure at 1500 psi. Blow down lines and pumps. Starting pressure at 510 PSI. Pump 56 bbl diesel down IA at 1.2 BPM. Final circ pressure at 2060 psi. Shut in IA. Load Dart in top of Tree with Lubricator extension. Pump in wing valve down tubing 12 bbl diesel. Line up test pump to lubricator and equalize pressure. open swab and drop 1.30 ball and rod. Let Fall on seat for 15 min. Pressure up to 4100 psi down tubing setting packer. Hold for 15 min. Bled to 4000 psi in 15 min. Bleed down to cuttings box. Noted small pin hole in 1502 hose on tubing. Change out hose. Pressure up to 4000 psi with test pump down tubing. Bleed down to cuttings box. Line up and bleed I.A. pressure down f/ 1180 psi t/ 0 psi @ 25 psi/min increments. MITIA, Pump diesel down IA, pressure up to 3150 psi @ 50 psi/min increments with test pump. Hold for 30 charted min and bleed pressure off @ 25 psi/min increments. 1.6 bbls bled back to cuttings tank. SimOps: Rig down service lines to rig floor. Prep to skid rig floor into moving position. Circulate soap pill through surface lines. Secure Tree. Final Wellhead Pressures IA - 0 psi, OA - 0 psi, Tubing - 420 psi. Rig released @ 00:00. 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Annular to 2500 psi. 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KŶĐĞƚŚĞKWƌĂŵĂŶĚĂŶŶƵůĂƌƚĞƐƚƐĂƌĞĐŽŵƉůĞƚĞĚ͕ƚĞƐƚƚŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚĞƐǇƐƚĞŵĨŽůůŽǁŝŶŐƚŚĞ ŶŽƌŵĂůƚĞƐƚƉƌŽĐĞĚƵƌĞ;ĨůŽŽƌǀĂůǀĞƐ͕ŐĂƐĚĞƚĞĐƚŝŽŶ͕ĞƚĐ͘Ϳ Ĩ͘ ZĞĐŽƌĚĂŶĚƌĞƉŽƌƚƚŚŝƐƚĞƐƚǁŝƚŚŶŽƚĞƐŝŶƚŚĞƌĞŵĂƌŬƐĐŽůƵŵŶƚŚĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌͬWsƉƌŽĨŝůĞͬ ƉĞŶĞƚƌĂƚŽƌǁŽƵůĚŶ͛ƚŚŽůĚƉƌĞƐƐƵƌĞĂŶĚƌŽůůŝŶŐƚĞƐƚǁĂƐƉĞƌĨŽƌŵĞĚŽŶKWƋƵŝƉŵĞŶƚĂŶĚůŝƐƚ ŝƚĞŵƐ͕ƉƌĞƐƐƵƌĞƐĂŶĚƌĂƚĞƐ͘ ϭϭ͘ ZhƚŽƉƵůůϮͲϳͬϴ͟^WĐŽŵƉůĞƚŝŽŶ͘ ϭϮ͘ WƵůůƉůƵŐŽĨĨƚŽŽů͕ĐŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞƵŶĚĞƌƚŚĞWs͕ŝĨŶĞĞĚĞĚŬŝůůƚŚĞǁĞůůǁŝƚŚ<t&ĂŶĚƉƵůůƚŚĞWs͘ ϭϯ͘ DhƚŚĞůĂŶĚŝŶŐũŽŝŶƚƚŽƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͕K>^ĂŶĚƵŶƐĞĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ ^ƚƌŝŶŐWhсϴϲ<ĂŶĚ^Kсϴϲ<ǁŚĞŶůĂŶĚĞĚďǇŽǇŽŶϭϲ;ďůŽĐŬǁĞŝŐŚƚсϰϬ<ͿŝŶϭϮ͘ϰƉƉŐďƌŝŶĞ͘ ϭϰ͘ WƵůůƚŚĞŚĂŶŐĞƌƚŽƚŚĞƌŝŐĨůŽŽƌ͘>ĂǇĚŽǁŶƚŚĞůĂŶĚŝŶŐũŽŝŶƚĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ͘ZhƚŽƉƵůů^WŽǀĞƌ ƐŚĞĂǀĞƐƚŽƐƉŽŽůŝŶŐƵŶŝƚƐ͘ Ă͘ /ŶƐƉĞĐƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚŶŽƚĞĂŶǇĐŽƌƌŽƐŝŽŶŽƌĚĂŵĂŐĞ͘ ŽŶƚŝŶŐĞŶĐǇ;/ĨĂƌŽůůŝŶŐƚĞƐƚǁĂƐĐŽŶĚƵĐƚĞĚͿ͗DhŶĞǁŚĂŶŐĞƌŽƌƚĞƐƚƉůƵŐƚŽƚŚĞĐŽŵƉůĞƚŝŽŶƚƵďŝŶŐ͘ ZĞͲůĂŶĚŚĂŶŐĞƌŽƌƚĞƐƚƉůƵŐŝŶƚƵďŝŶŐŚĞĂĚ͘dĞƐƚKWƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞĂŶĚƐƵŶĚƌǇ͘ ϭϱ͘ WKK,ůĂǇŝŶŐĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐƐƉŽŽůŝŶŐ^WĐĂďůĞĂŶĚƌĞŵŽǀŝŶŐĂůůũĞǁĞůƌǇĂƐŝƚƉƌĞƐĞŶƚƐŝƚƐĞůĨ͘ >ĂǇĚŽǁŶ^WĐŽŵƉŽŶĞŶƚƐ͘ ^WŚĂŶŐĞŽƵƚ tĞůů͗DWh>ͲϬϭ ĂƚĞ͗ϮͬϬϭͬϮϭ Ă͘ EŽƚĞĂŶǇĐŽƌƌŽƐŝŽŶ͕ƐĂŶĚ͕ƐĐĂůĞ͕ĚĂŵĂŐĞŽƌŽǀĞƌƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐŽŶƚŚĞƚƵďŝŶŐǁŝƚŚĂƐƐŽĐŝĂƚĞĚ ĚĞƉƚŚƐĂŶĚ^WĐŽŵƉŽŶĞŶƚƐŽŶƚŚĞŵŽƌŶŝŶŐƌĞƉŽƌƚ͘ ƋƵŝƉŵĞŶƚŝƐƉŽƐŝƚŝŽŶ dƵďŝŶŐŚĂŶŐĞƌ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞƚŚĞŶƌĞƵƐĞ͕ƌĞƐƚŽĐŬŽƌũƵŶŬ dƵďŝŶŐΘWƵƉũŽŝŶƚƐ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞƚŚĞŶƌĞƵƐĞ 'ĂƐůŝĨƚDĂŶĚƌĞůƐͬEŝƉƉůĞ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞƚŚĞŶƌĞƵƐĞ ^WĞƋƵŝƉŵĞŶƚͬWŽǁĞƌĂďůĞ ĞŶƚƌŝůŝĨƚƚŽƚĂŬĞƉŽƐƐĞƐƐŝŽŶĨŽƌŝŶƐƉĞĐƚŝŽŶĂŶĚƚĞĂƌĚŽǁŶ WƌŽƚĞĐƚŽƌůŝǌĞƌ;ϱͿ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞƚŚĞŶƌĞƵƐĞ͕ƌĞƐƚŽĐŬ ĂŶŶŽŶĐůĂŵƉƐ;ϭϭϯͿ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞƚŚĞŶƌĞƵƐĞ͕ƌĞƐƚŽĐŬ ϭϲ͘ Z^WƉƵůůŝŶŐĞƋƵŝƉŵĞŶƚ͘ ϭϳ͘ ZhƚŽƌƵŶ^WĐŽŵƉůĞƚŝŽŶ͘ ϭϴ͘ WhĂŶĚDhŶĞǁĂŬĞƌ^WĂƐƐĞŵďůǇ͘^ĞƚďĂƐĞŽĨ^WĂƐƐĞŵďůǇĂƚцϲ͕ϴϬϬ͛D͘ŚĞĐŬĞůĞĐƚƌŝĐĂů ŝŶƚĞŐƌŝƚǇƚĞƐƚĞǀĞƌǇϭ͕ϬϬϬ͛͘/ŶƐƚĂůůĐůĂŵƉƐŽŶƚŚĞĨŝƌƐƚϭϱũŽŝŶƚƐƚŚĞŶĞǀĞƌǇŽƚŚĞƌũŽŝŶƚƚŽƐƵƌĨĂĐĞ͘ Ă͘ DŽƚŽƌĐĞŶƚƌĂůŝǌĞƌ ď͘ DŽƚŽƌŐĂƵŐĞƵŶŝƚ Đ͘ ^WŵŽƚŽƌ Ě͘ >ŽǁĞƌƚĂŶĚĞŵƐĞĂů Ğ͘ hƉƉĞƌƚĂŶĚĞŵƐĞĂů Ĩ͘ 'ĂƐƐĞƉĂƌĂƚŽƌ Ő͘ WƵŵƉηϭ Ś͘ WƵŵƉηϮ ŝ͘ WŽƌƚĞĚĚŝƐĐŚĂƌŐĞŚĞĂĚ ũ͘ ŽůƚŽŶĚŝƐĐŚĂƌŐĞŚĞĂĚǁŝƚŚƉƵƉũŽŝŶƚ͕ϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚďŽǆƵƉ Ŭ͘ ϭũŽŝŶƚ͕ϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ ů͘ EŝƉƉůĞ͕,^Ϯ͘ϯϭϯ͟yE;Ϯ͘ϮϬϱ͟ŶŽͲŐŽͿǁŝƚŚϭϬ͛ŚĂŶĚůŝŶŐƉƵƉƐĂďŽǀĞĂŶĚďĞůŽǁ ŵ͘ yyyũŽŝŶƚƐ͕ϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ŷ͘ EŝƉƉůĞ͕,^Ϯ͘ϯϭϯ͟yǁŝƚŚϭϬ͛ŚĂŶĚůŝŶŐƉƵƉƐĂďŽǀĞĂŶĚďĞůŽǁ͕Z,ƉůƵŐďŽĚǇŝŶƐƚĂůůĞĚ Ž͘ ϭũŽŝŶƚ͕ϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ɖ͘ WĂĐŬĞƌ͕sŝŬŝŶŐ^WƌĞƚƌŝĞǀĂďůĞǁŝƚŚĚƵĂůǀĞŶƚǀĂůǀĞƐ;ƐĞƚƚŝŶŐĚĞƉƚŚсцϰ͕ϬϬϬ͛DͿ ϭϵ͘ WhĂŶĚDhƚŚĞsŝŬŝŶŐƉĂĐŬĞƌ͘sĞƌŝĨǇƚŚĂƚƚŚĞƌĞĂƌĞϰƐĞƚƚŝŶŐƐŚĞĂƌƉŝŶƐĂŶĚϭϴƐŚĞĂƌƚŽƌĞůĞĂƐĞƉŝŶ͘ ϮϬ͘ dĞƌŵŝŶĂƚĞƚŚĞ^WĐĂďůĞĂŶĚDhƚŚĞ^WƉĞŶĞƚƌĂƚŽƌƚŽƚŚĞ^WĐĂďůĞ͘ŶƐƵƌĞƚŚĞϯͬϴ͟EWdĐŽŶƚƌŽůůŝŶĞ ĨĞĞĚƚŚƌƵƉŽƌƚŝƐĚƵŵŵŝĞĚŽĨĨ͘ Ϯϭ͘ DhƚŚĞĐŽŶƚƌŽůůŝŶĞƚŽƚŚĞĚƵĂůǀĞŶƚǀĂůǀĞƐ͘WƌĞƐƐƵƌĞƵƉŽŶƚŚĞĐŽŶƚƌŽůůŝŶĞƚŽϱ͕ϬϬϬƉƐŝĂŶĚŚŽůĚĨŽƌϱ ŵŝŶƵƚĞƐĐŚĞĐŬŝŶŐĨŽƌůĞĂŬƐ;ŶŽƚĞƚŚĞŽƉĞŶŝŶŐƉƌĞƐƐƵƌĞŝŶtĞůůͿ͘ůĞĞĚƚŚĞƉƌĞƐƐƵƌĞƚŽϱϬϬƉƐŝĂŶĚ ůŽĐŬŝƚŝŶƚŽŵĂŝŶƚĂŝŶϱϬϬƉƐŝǁŚŝůĞZ/,͘ ϮϮ͘ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚ^WĐŽŵƉůĞƚŝŽŶ͘ŚĞĐŬĞůĞĐƚƌŝĐĂůŝŶƚĞŐƌŝƚǇƚĞƐƚĞǀĞƌǇϭ͕ϬϬϬ͛͘ Ƌ͘ ϭũŽŝŶƚ͕ϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ ƌ͘ '>D͕ϮͲϳͬϴ͟ǆϭ͕͟sŝŶƐƚĂůůĞĚǁŝƚŚϭϬ͛ŚĂŶĚůŝŶŐƉƵƉƐĂďŽǀĞĂŶĚďĞůŽǁ Ɛ͘ yyyũŽŝŶƚƐ͕ϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ ^WŚĂŶŐĞŽƵƚ tĞůů͗DWh>ͲϬϭ ĂƚĞ͗ϮͬϬϭͬϮϭ ƚ͘ '>D͕ϮͲϳͬϴ͟ǆϭ͕͟sŝŶƐƚĂůůĞĚǁŝƚŚϭϬ͛ŚĂŶĚůŝŶŐƉƵƉƐĂďŽǀĞĂŶĚďĞůŽǁ;ƐĞƚƚŝŶŐĚĞƉƚŚцϭϳϱ͛DͿ Ƶ͘ yyũŽŝŶƚƐ͕ϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ϯϯ͘ WhĂŶĚDhƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐŚĂŶŐĞƌ͘DĂŬĞĨŝŶĂůƐƉůŝĐĞŽĨƚŚĞ^WĐĂďůĞƚŽƚŚĞƉĞŶĞƚƌĂƚŽƌ͕DhƚŚĞ ĐŽŶƚƌŽůůŝŶĞƚŽƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚĚƵŵŵǇŽĨĨĂŶǇĂĚĚŝƚŝŽŶĂůĐŽŶƚƌŽůůŝŶĞƉŽƌƚƐŝĨƉƌĞƐĞŶƚ͘ Ϯϰ͘ WƌĞƐƐƵƌĞƵƉŽŶƚŚĞĐŽŶƚƌŽůůŝŶĞƚŽϱ͕ϬϬϬƉƐŝĂŶĚŚŽůĚĨŽƌϱŵŝŶƵƚĞƐĐŚĞĐŬŝŶŐĨŽƌůĞĂŬƐ;ŶŽƚĞƚŚĞŽƉĞŶŝŶŐ ƉƌĞƐƐƵƌĞŝŶtĞůůͿ͘ůĞĞĚƚŚĞƉƌĞƐƐƵƌĞƚŽϱϬϬƉƐŝĂŶĚůŽĐŬŝƚŝŶƚŽŵĂŝŶƚĂŝŶϱϬϬƉƐŝǁŚŝůĞůĂŶĚŝŶŐƚŚĞ ŚĂŶŐĞƌ͘ Ϯϱ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌǁŝƚŚĞǆƚƌĞŵĞĐĂƵƚŝŽŶƚŽĂǀŽŝĚĚĂŵĂŐŝŶŐƚŚĞ^WĐĂďůĞ͕ƉĞŶĞƚƌĂƚŽƌŽƌĐŽŶƚƌŽůůŝŶĞ͘ Z/>^͘ZĞĐŽƌĚWhĂŶĚ^KǁĞŝŐŚƚƐŽŶƚĂůůǇĂŶĚtĞůů͘ Ϯϲ͘ ƌŽƉƚŚĞďĂůůΘƌŽĚĂŶĚĂůůŽǁƚŝŵĞĨŽƌŝƚƚŽŐƌĂǀŝƚĂƚĞƚŽƚŚĞďĂůůƐĞĂƚ͘ Ϯϳ͘ WƌĞƐƐƵƌĞƵƉŽŶƚŚĞƚƵďŝŶŐƚŽϰ͕ϬϬϬƉƐŝĂŶĚŚŽůĚĨŽƌϭϱŵŝŶƵƚĞƐƚŽƐĞƚƚŚĞƉĂĐŬĞƌ͘ůĞĞĚƚŚĞƚƵďŝŶŐ ƉƌĞƐƐƵƌĞƚŽϬƉƐŝ͘WƌĞƐƐƵƌĞďĂĐŬƵƉƚŽϰ͕ϬϬϬƉƐŝĂŶĚŚŽůĚĨŽƌϱŵŝŶƵƚĞƐƚŚĞŶďůĞĞĚƚŽϬƉƐŝ͘ Ϯϴ͘ ůĞĞĚƚŚĞĐŽŶƚƌŽůůŝŶĞƉƌĞƐƐƵƌĞƚŽϬƉƐŝƚŽĐůŽƐĞƚŚĞǀĞŶƚǀĂůǀĞƐ͘ Ϯϵ͘ ^ůŽǁůǇƉƌĞƐƐƵƌĞƵƉĂƚϱϬƉƐŝͬŵŝŶŽŶƚŚĞ/ƚŽϭ͕ϱϬϬƉƐŝĂŶĚŚŽůĚĨŽƌϯϬŵŝŶƵƚĞƐŽŶĐŚĂƌƚƌĞĐŽƌĚĞƌ͘ Ă͘ dĞƐƚŽĨ^WƉĂĐŬĞƌΛцϰ͕ϬϬϬ͛D͘ ϯϬ͘ ^ůŽǁůǇďůĞĞĚƚŚĞ/ƉƌĞƐƐƵƌĞĂƚϮϱƉƐŝͬŵŝŶƚŽϬƉƐŝ͘ ϯϭ͘ ^ĞƚϮͲϭͬϮ͟,WWs͘ ϯϮ͘ EƚŚĞKWƐƚĂĐŬ͘/ŶƐƚĂůůƚŚĞƉůƵŐŽĨĨƚŽŽů͘ ϯϯ͘ EhƚŚĞƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌĂŶĚϮͲϵͬϭϲ͕͟ϱDƚƌĞĞ͘ ϯϰ͘ WdƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬͬϱ͕ϬϬϬƉƐŝ͘WdƚŚĞƚƌĞĞƚŽϮϱϬͬϱ͕ϬϬϬƉƐŝ͘ ϯϱ͘ WƵůůƉůƵŐŽĨĨƚŽŽůĂŶĚWs͘ ϯϲ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘^ĞĐƵƌĞƚŚĞƚƌĞĞĂŶĚĐĞůůĂƌ͘ ϯϳ͘ ZDK WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϯϴ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶǀŝĂŚĂŶĚŽǀĞƌĨŽƌŵ͘ ϯϵ͘ ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ϰϬ͘ Zh,^ƐůŝĐŬůŝŶĞ͘ ϰϭ͘ WƵůůƚŚĞďĂůůĂŶĚƌŽĚ͘ ϰϮ͘ WƵůůsĨƌŽŵ'>DηϮĂŶĚŝŶƐƚĂůůKs͘ ϰϯ͘ WƵůůZ,ƉůƵŐďŽĚǇ͘ ϰϰ͘ Z,^ƐůŝĐŬůŝŶĞ͘ EŽƚĞ͗&ƌĞĞǌĞƉƌŽƚĞĐƚŝƐƵƉƚŽƚŚĞĚŝƐĐƌĞƚŝŽŶŽĨƚŚĞtĞůůƐ^ƵƉĞƌǀŝƐŽƌͬ&ŽƌĞŵĂŶĚĞƉĞŶĚŝŶŐŽŶƚŝŵŝŶŐĨŽƌƚŚĞ ǁĞůůƚŽďĞWKW͘dƌƵĞĐƌǇƐƚĂůůŝǌĂƚŝŽŶƚĞŵƉĞƌĂƚƵƌĞ;ddͿŽĨϭϭ͘ϭƉƉŐEĂůEĂƌсͲϱ͘ϮΣ& ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚƐĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚƐĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ ϰ͘ ůĂŶŬZtKDK&Žƌŵ 3,000 psi. 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ϴ͕ϭϯϬ͛ ϴ͕ϯϰϬ͛ ϳ͕Ϭϴϰ͛ ϳ͕Ϭϵϳ͛ ϮϭϬ ϯͲϯͬϴͬ͟ϲ^W& ϲͬϯͬϬϯ KƉĞŶ ϴ͕ϰϵϬ͛ ϴ͕ϴϬϬ͛ ϳ͕Ϭϵϭ͛ ϳ͕ϬϳϬ͛ ϯϭϬ ϯͲϯͬϴͬ͟ϲ^W& ϲͬϯͬϬϯ KƉĞŶ ZĞĨĞƌĞŶĐĞ>ŽŐ͗ƵĂů/ŶĚƵĐƚŝŽŶʹ^&>ĂƚĞĚϲͬϴͬϭϵϵϰ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗/dϭͬϮϴͬϮϬϮϭ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh>ͲϬϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϭͬϮϬϭϰ Wd͗ϮϬϯͲϬϲϰ dс ϴ͕ϴϰϱ͛;DͿͬdс ϳ͕Ϭϲϱ͛;dsͿ ϭϯͲϯͬϴ͟ KƌŝŐ͘&ůĞǀ͘сϱϲ͘Ϭ͛ͬ'>ůĞǀ͘сϭϳ͘Ϭ͛EĂďŽƌƐϮϳ ϳ͟ Wdс ϴ͕ϴϭϬ͛;DͿͬWdс ϳ͕Ϭϲϵ͛;dsͿ ϵͲϱͬϴ´ 0LQ,' ´ #¶ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϳϮͬ>ͲϴϬͬdZ ϭϮ͘ϯϰϳ ^ƵƌĨĂĐĞ ϳϬΖ Ϭ͘ϭϰϴϭ ϵͲϱͬϴ͟ ^ƵƌĨĂĐĞ ϰϳͬ>ͲϴϬͬdZ ϴ͘ϲϴϭ ^ƵƌĨĂĐĞ Ϯ͕ϰϴϯ͛ Ϭ͘ϬϳϯϮ ϳ͟ ^ƵƌĨĂĐĞ Ϯϵͬ>ͲϴϬͬdZ ϲ͘ϭϴϰ ^ƵƌĨĂĐĞ ϲ͕ϵϳϮ͛ Ϭ͘Ϭϯϳϭ ϯͲϭͬϮΗ >ŝŶĞƌ ϴ͘ϴϭͬ>ͲϴϬͬ^d> Eͬ ϲ͕ϴϰϱ͛ ϲ͕ϴϳϱ͛ Eͬ ϯͲϯͬϭϲ͟ >ŝŶĞƌ ϲ͘Ϯͬ>ͲϴϬͬd// Eͬ ϲ͕ϴϳϱ͛ ϳ͕ϲϭϵ͛ Eͬ ϮͲϳͬϴ͟ >ŝŶĞƌ ϲ͘ϭϲͬ>ͲϴϬͬ^d> Eͬ ϳ͕ϲϭϵ͛ ϴ͕ϴϰϱ͛ Eͬ dh/E'd/> ϮͲϳͬϴ͟ dƵďŝŶŐ ϲ͘ϱηͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ цϲ͕ϴϬϬ͛Ϭ͘ϬϬϱϴ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϰϯ͛ '>D^dϯ͗ Ϯ цϯ͕ϵϳϱ͛ '>D^dϮ͗ ϯ цϰ͕ϬϬϬ͛ WĂĐŬĞƌ ϰ цϰ͕ϬϰϬ͛ ϮͲϳͬϴ͟yEŝƉƉůĞ;Ϯ͘ϯϭϯ͟/Ϳ ϱ цϲ͕ϲϰϰ͛ '>D^dϭ͗ ϲ цϲ͕ϲϴϰ͛ ϮͲϳͬϴ͟,^yEEŝƉ͕D/E/сϮ͘ϮϬϱ͟ ϳ цϲ͕ϳϮϲ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ ϴ цϲ͕ϳϮϳ͛ WƵŵƉ͗ ϵ цϲ͕ϳϰϵ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ ϭϬ цϲ͕ϳϱϰ͛ dĂŶĚĞŵ^ĞĂů^ĞĐƚŝŽŶƐ͗ ϭϭ цϲ͕ϳϲϴ͛ DŽƚŽƌ͗ ϭϮ цϲ͕ϳϴϰ ^ĞŶƐŽƌ͗ǁͬϲĨŝŶĐĞŶƚƌĂůŝǌĞƌʹƚŵΛцϲ͕ϴϬϬ͛ ϭϯ ϲ͕ϴϯϴ͘ϭ͛ ĂŬĞƌ&ůƵƚĞĚ,ĞĂĚ ϭϰ ϲ͕ϴϯϴ͘ϰ͛ ĂŬĞƌdŝĞĂĐŬ^ůĞĞǀĞ ϭϱ ϲ͕ϴϰϱ͛ ĂŬĞƌĞƉůŽǇŵĞŶƚ^ůĞĞǀĞǁͬϰ͟WƌŽĨŝůĞ ϭϲ ϲ͕ϴϲϰ͛ yͲEŝƉƉůĞʹϯ͘ϳ͟/ ϭϳ ϴ͕ϴϰϯ͛ ĂŬĞƌdĂƉĞƌĞĚ'ƵŝĚĞ^ŚŽĞʹƚŵΛϴ͕ϴϰϱ͛ KWE,K>ͬDEdd/> ϭϯͲϯͬϴΗ ĞŵĞŶƚƚŽ^ƵƌĨĂĐĞŝŶϭϳͲϭͬϮ͟͟,ŽůĞ ϵͲϱͬϴ͟ ϭϬϬϬƐǆŽĨ^///͕ϳϱϬƐǆ^///ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ϳϱϬƐǆůĂƐƐ͞'͕͟ϲϬϬƐǆůĂƐƐ͚'͛ŝŶϴͲϭͬϮ͟,ŽůĞ >ŝŶĞƌ ϭϬϬƐǆ^/͕ϭϰϳƐǆůĂƐƐ͚'͛ t>>/E>/Ed/KE d/> <KWΛϲ͕ϵϳϮ͛D ďŽǀĞƐŝĚĞƚƌĂĐŬ͗DĂǆ,ŽůĞŶŐůĞсϭϲΣĂƚϲ͕ϱϬϬ͖͛DĂǆ^>сϯΣͬϭϬϬ͛Ăƚϲ͕ϯϬϬ͛ ^ŝĚĞƚƌĂĐŬ͗DĂǆ,ŽůĞŶŐůĞсϵϬΣͲϭϬϯΣ͖DĂǆ^>сϰϬΣͬϭϬϬ͛ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϭϬϲϴͲϬϭͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďǇEĂďŽƌƐϮϳͲϭϭͬϯͬϭϵϴϰ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďǇEŽƌĚŝĐϮʹϲͬϭϰͬϮϬϬϯ ^WZtKďǇEĂďŽƌƐϰ^ʹϭϭͬϭϯͬϮϬϬϱ ^WZtKďǇŽǇŽŶϭϲʹϱͬϭͬϮϬϭϰ t/EKtd/> tŝŶĚŽǁŝŶϳ͟ĂƐŝŶŐΛϲ͕ϵϳϮ͛ƚŽϲ͕ϵϴϬ͛ tĞůůŶŐůĞΛtŝŶĚŽǁсϭϯĚĞŐ͘ t>>, dƌĞĞ ϮͲϵͬϭϲ͟ʹϱD tĞůůŚĞĂĚ ϭϯͲϱͬϴ͟ǆϭϭ͟ϱD/t͚'͛ƚƵďŝŶŐƐƉŽŽů ǁͬϭϭ͟ǆϮͲϳͬϴ͟/tdƵďŝŶŐ,ĂŶŐĞƌ͕ϮͲϳͬϴ͟ hϴƌĚƚŚƌĞĂĚƐƚŽƉΘďŽƚƚŽŵ͕Ϯ͘ϱ͟/tс, WsWƌŽĨŝůĞ ϭϳ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d dǇƉĞ ĂƚĞ ^ƚĂƚƵƐ <ƵƉĂƌƵŬ ϳ͕ϲϴϬ ϳ͕ϴϰϬ͛ ϳ͕ϭϯϵ͛ ϳ͕ϭϬϴ͛ ϭϲϬ ϯͲϯͬϴͬ͟ϲ^W& ϲͬϯͬϬϯ KƉĞŶ ϴ͕ϭϯϬ͛ ϴ͕ϯϰϬ͛ ϳ͕Ϭϴϰ͛ ϳ͕Ϭϵϳ͛ ϮϭϬ ϯͲϯͬϴͬ͟ϲ^W& ϲͬϯͬϬϯ KƉĞŶ ϴ͕ϰϵϬ͛ ϴ͕ϴϬϬ͛ ϳ͕Ϭϵϭ͛ ϳ͕ϬϳϬ͛ ϯϭϬ ϯͲϯͬϴͬ͟ϲ^W& ϲͬϯͬϬϯ KƉĞŶ ZĞĨĞƌĞŶĐĞ>ŽŐ͗ƵĂů/ŶĚƵĐƚŝŽŶʹ^&>ĂƚĞĚϲͬϴͬϭϵϵϰ @ 0LOQH3RLQW 'R\RQ ´%236WDFN +LOFRUS$ODVND//&+LOFRUS$ODVND//&Changes to Approved Rig Work Over Sundry Procedure'DWH )HEUXDU\6XEMHFW &KDQJHVWR$SSURYHG6XQGU\3URFHGXUHIRU:HOO038/$6XQGU\$Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHULJZRUNRYHU5:2³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6WHS 3DJH 'DWH 3URFHGXUH&KDQJH+$.3UHSDUHG%\,QLWLDOV+$.$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH $SSURYDO 2SHUDWLRQV0DQDJHU 'DWH 3UHSDUHG 2SHUDWLRQV(QJLQHHU 'DWH Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/15/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-01A (203-064) Multi Finger Caliper Log 10/10/2019 ANALYSIS FIELD DATA Please include current contact information if different from above. Received by the AOGCC 09/16/2020 PTD: 2030640 E-Set:33895 Abby Bell 09/16/2020 d N) O 0 0._,, r N wlnwi .1 M 0 ko..- m OoZ u Q U O N W 6 ( N _s( < co FG >n x @ Q a ..Mb .Amo CD o > . wIl1 00 y F T Y roo a c �° O o -a to -, to T C_ Q 1-` Ym Q IIIJ In M 1n 1n In N ca O v E J �. W 1 T i 1 1 1 r r .0 In in In U yN Ln Q linoN RI 0 l0 to to C6 @ O- 4 in C O a� C C ro Z f-:: N N N N N N h Cn M c C v > QQun E o O T 2' u ,� 0 TT3 f"F{ D 0) co O 000000 000 m ui C zT CL J J J J J J J J J W w W W W W W W W COD c C 0 O LL LL LL LL LL LL LL LL LL 7 N E -O ") 0 Q J J J J J J J J J Q O c co 1. i o ❑ Cn r O z z z z z z z z z CO ,0 0) LL LL LL LL LL LL LL LL LL N -C .- u 4) N ETO u N L O E N E v v O O O• lO 0 0 C O _0 C v C d. N F- > > C L A O ' z J O 0 z Q ac s oo > U .151 /. ua O 0 LL LL H O ,t m U) S.I o. LL — 002x o F a a v _i LL Cl- a 0 C[ whin TS N Q w 0 a 0 0 2 2 z E. O ., cc H 0 2 U r' w o W v ° > W 0 ra � aa � o 0_ 0_ 0 X 0: i� 03 to _ > 0. J O O O J O O J J O 2 �. R M wLi" L./ �' W W W �' W w 3 3 --vilopir •-ftrilA w 2 CO COQCO m m Z < Q W W W Z D W W w W ,* O 0222X < 2 II -10000E0 O wn ❑ v Q W. LL W a a a a s a @ Lt, c W 00 co LO N CV ❑ N N 0 Ian o 10 COCD o L1 Oa MINI O O O O O O N O ..■ I'l / 0 0 0 0 0 0 0 0 0 0 0 ■ii;� 0 0 0 0 0 0 O 0 0 Ol U O, -3 0 0 0 In co No m E O ❑_ 5N co CD 0 N. Q > N 03 v Q W Q ❑ V ❑ U ❑ V V V V QJ to ao N2' E O. p O 0 O O M N 0 O m U LO 0 0 0 0 0 0 0 0 0 O C N N I••• 01 N V h g. �n t' Q 111 CD CO C) N ct 0 7 In 0 A -D N N NN N N N N N N N N �' El .. O) T T 0 0 0 0 0 Of E C p NNNNNN NNNVI Ot 0 0 0 0 0 0 O O O C 00 0 0 0 0 O O O co C In In In 1n In In In In In a N m CID L CO C 'O w LP CL E v o 0')d1 W Y n LU u U r-1 'i a U m M Q' o Q v o N o o Q v c N +' Z M O N r O re L" E n _ .- J Y M RD a u J CL Q N W. LL J Z Q' X J J E Z N -O V c � a_ �1 N C C CD u O_ Jmage J _bject Well History File C~ Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (2 O~ - 0 b?f Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: L t:; / (Count does include 7sheet) Page Count Matches Number in Scanning Preparation: V YES NO Heien~ Date: 8 ð-d- OS" Is! Organizing (done) o Two-sided 11I11111I1111111111 REj«AN ~color Items: o Greyscale Items: DIGITAL DATA v6ïskettes, No·1 D Other, NolType: D Poor Quality Originals: o Other: NOTES: BY: Helen ~ Project Proofing BY: Helen~ Scanning Preparation BY: Helen ~ 1 x 30 = 30 BY: Stage 1 BY: If NO in stage 1 page(s) discrepancies were found: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~escan Needed 1 OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: i Date: c¿ d do. o..s- 151 y11fl 1 - :9 11\1 Date:í5' ~~ ~ 151 + B-ð = T1JTAL PAGES SO j) (Count" not incl Jde cover sheet) V\A Date: 't) ~ OSlsl , '. II VY1iJ YES NO Date: 151 II! 1111111111' /1111 11I1111111111111111 I Date: 151 Quality Checked 1111111111111111111 • r ;' " ~- ~ ;: ~.- . MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc . STATE OF ALASKA A ALAS OIL AND GAS CONSERVATION COMM~N REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: DevelopmentP Stratigraphic 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 56 KB 8. Property Designation: ADLO-025509 11. Present Well Condition Summary: Total Depth feet feet measured true vertical 8845 . 7065 Effective Depth measured 8810 feet true vertical 7069 feet Casing Length Size MD Conductor 83' 13-3/8" 72# L-80 32' - 115' Surface 2452' 9-5/8" 47# L-80 31' - 2483' Production 6983' 7" 29# L-80 30' - 6968' Liner 38' 3-1/2" 9.2# L-80 6838' 6876' Liner 743' 3-3/16" 6.2# L-80 6876' - 7619' Liner 1226' 2-7/8" 6.16# L-80 7619' - 8845' Perforation depth: Measured depth: 7680 - 7840 8130 - 8340 True Vertical depth: 7138.97 -7108.33 7084.01 - 7096.57 Tubing: (size, grade, and measured depth) 2-7/8" 6.5# Packers and SSSV (type and measured depth) no packers o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Stimulate 0 . WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 203-0640 Exploratory Service 9. Well Name and Number: RECEIVED FEB 0 1 2007 sian 6. API Number: 50-029-21068-01-00 . MPL-01A 10. Field/Pool(s): MILNE POINT Field/ KUPARUK RIVER OIL Pool Plugs (measured) Junk (measured) TVD 32' - 115' 31' - 2483' 30' - 6942' 6816' - 6852' 6852' - 7146' 7146' - 7065' 8490 - 8800 7091.39 - 7069.68 L-80 Treatment descriptions including volumes used and final pressure: SCANNEO FEB 0 1 Z007 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 16 468 0 15 463 0 15. Well Class after Droposed work: Exploratory Development p. 16. Well Status after proposed work: Oil P Gas WAG 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 78 78 . x None 16076' Burst 4930 6870 8160 10160 8520 10570 Collapse 2670 3090 7020 10530 7660 11160 28' - 6739' o o o o Tubing pressure 263 263 Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Signature Title Data Engineer RBOMS BH Form 1 0-404 Revised 04/2004 Phone 564-4944 WINJ WDSPL o ;} 2DDí Date 12/29/2006 z.;t;:;¡;> Submit Original Only . . MPL-OIA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/26/2006 Load and transport fluids, standby for flowback tank. Continue job on next day WSR. 12/27/2006 Pump Acid returns down MPB-50. 12/27/2006 ACID WASH Pump 10 bbls crude down tbg to establish injectivity, Pump 10 bbls 12% DAD acid, 3 bbls 60/40 meth (to flush equipment), and 21 bbls crude. FWHP's=200/350/0 FLUIDS PUMPED BBLS 31 CRUDE 10 12% DAD acid 3 60/40 mETH 44 TOTAL STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION SEP 2 2 2006 REPORT OF SUNDRY WELL OPERA TION& Oil & Gas Cons. C.ommission . j(fC 9Jqo~ . RECEIVED 1. Operations Performed: Ancn0[3D8 Abandon 0 Repair WellO PluQ PerforationsD Stimulate Œ] Other Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 203-0640 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-21068-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56.00 MPL-01A 8. Property Designation: 10. Field/Pool(s): ADL-025509 Miline Point Unit / Kuparuk River Oil 11. Present Well Condition Summary: Total Depth measured 8845 feet true vertical 7065.0 feet Plugs (measured) None Effective Depth measured 8810 feet Junk (measured) Fish: Top @ 16076' MD (06/28/2006) true vertical 7069.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 13-3/8" 72# L-80 32 - 115 32.0 - 115.0 4930 2670 SURFACE 2452 9-5/8" 47# L-80 31 · 2483 31.0 - 2483.0 6870 3090 PRODUCTION 6938 7" 29# L-80 30 - 6968 30.0 - 6942.0 8160 7020 LINER 38 3-1/2" 9.2# L-80 6838 · 6876 6816.0 - 6852.0 10160 10530 LINER 743 3-3/16" 6.2# L-80 6876 - 7619 6852.0 - 7146.0 8520 7660 LINER 1226 2-7/8" 6.16# L-80 7619 · 8845 7146.0 - 7065.0 10570 11160 Perforation depth: SCANNED SEP 2 "I20D5 Measured depth: 7680-7840, 8130-8340, 8490-8800 True vertical depth: 7139-7108,7084-7097,7091-7070 Tubing ( size, grade, and measured depth): 2-7/8" 6.5# L-80 @ 28 - 6739 Bottom of Jet Pump @ 6790 Packers & SSSV (type & measured depth): No Packer in well. No SSSV in well. 12. Stimulation or cement squeeze summary: RBDMS 8Ft SIP 2 6 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubing Pressure Prior to well operation: SI 0 0 --- 413 Subsequent to operation: 157 40 0 -- 337 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ! ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilOO GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnonr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature ~~. .~ J!.þ ./ Phone 564-5174 Date 9/19/06 n - Form 10-404 Revised 4/2004 0 R \ G \ N A L . . MPL-01A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/31/2006 T/I/O=900/650/0 *****Continued from previous day WSR***** Finish pumping over flush and tbg displacement for SIT FWHP's=1 050/1 000/0 07130/2006 T/I/O=900/650/0. (SIT) Load IA wI 53 bbls crude. Pump 18.4 bbls VX7377 scale inhibitor down tbg. Pump 449 bbls crude for overflush & tbg displacement. 06/17/2006 CTU #4, FCO I Acid Stirn; MIRU unit. MU and RIH with 2.0" JSN. Tag fill at 6752' ctmd. Jet on pump with XS 1% KCL at 2.0 bpm.Jet 10 bbls 90:10 DAD/15% HCL acid on pump. Pressure tbg to 3000psi - WHP bled down to 215/30 min-soak acid 2 hrs-Attempt to squeeze acid away- WHP to 3000 psi - bleeds down to 1000 psi I 5 min- can inject but tight- all acid away - start pump- producing at -.5 -.7 bpm. 125 bbls produced to clean well up- fluids at PH 6.5 - divert well to production facility - RDMO **** Job Complete **** 06/14/2006 T/I/O= 400/500/0 *****Well flowing on arrival***** (Attempt to pump down tbg ) Pump .4 bbls diesel down tbg pressured up to 3000psi, pressure bled off to 800psi in 7 min. Pumped another .4 bbls with same results. Pumped down tbg several more times getting only minimal amount down hole. Approximate LLR=1.2 GPM. FWHP's=480/500/0 06/14/2006 dump bail acid FL @ -900', DUMP BAIL 1.5 GALS OF 15% HCL ACID ON TOP OF ESP PUMP WI 2"DUMP BAILER ***WELL LEFT SII ON DEPARTURE*** 06/13/2006 *** WELL SII ON ARRIVAL **** DUMP BAIL ACID FL @ -900' PER ECHO METER, DUMP BAIL 1.5 GALS OF 15% HCL ACID ON TOP OF ESP PUMP WI 2"DUMP BAILER 05/21/2006 T/I/O=250/25010 (ESP Trouble) Injection test. Pressured up on tbg with 2 bbls diesel, pumped in 8 bbls more diesel at min. rate. Pressuring up and letting it bleed down. Final WHP=600/25010 05/20/2006 T/I/O=225/225/0 (ESP Trouble) Pumped 5.4 bbls down tbg to pressure up to 3000 psi, held pressure for 5 min., no change, bled pressure off. Final WHP=250/225/0 05/20/2006 RIH WI 27/8" OK-6 & 11' EXT & RUNNING TOOL TO TAG VALVE AT 6565' SLM - TAP VALVE IN POCKET. ***WELL SII ON DEPARTURE*** 05/19/2006 T/I/O=375/35010 (Acid Treatment) Pump 10 bbls crude then 10 bbls acid followed by 29 bbls crude followed by 8 bbls diesel. Let pump soak for 15 min, Pad Op worked pump - forward & reverse. Flush acid with 3 bbls diesel. FWHP=0/20010 05/1912006 ***WELL SII ON ARRIVAL*** esp acid job RIH WI 27/8" OK6 WI 1 1/4" JDC, PULL 1" DMY VALVE @ 6565' SLM - VALVE COATED IN HARD SCALE, LRS PUMPED 7.5% DAD ACID JOB, PROBLEMS SETTING 1" DMY VALVE @ 6565' SLM 05/19/2006 T/l/O=400/40010 Acid Treatment Attempted. Pumped 10.8 bbls crude down tbg when tbg pressured up to 3000 psi. Pumped remaining 60 bbls crude down flowline to production. Final WHP=400/40010 Page 1 . . MPL-01A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 4 50/50 Methanol Water 15.4 Diesel 572 Crude 127 Extra Slick 1 % KCL Water 18.4 VX7377 Scale Inhibitor 10 90: 1 0 DAD / 15% HCL Acid 746.8 TOTAL Page 2 Tree: 29/16" 5M Wellhead: 13 5/8" x 11" 5M CIW 'DGS' tbg spool wI 11" x 27/8" CIW Tubing Hanger, 2 7/8" EUE 8 rd threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 72 ppf, L-80 115' Strc. MPL-01a KOP @ 6000' Max. hole angle = 11 to 15 deg. fl 6300' to TO' Hole angle thru' perfs = 12 deg. max. OLS = 5 de ./100' 8066' 95/8",47 ppf, L-80 STC 2483' 7" 29 ppf, L-80, STC production casing ( drift 10 = 6.059", cap. = 0.0371 bpf) 27/8" 6.5 ppf. L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf) 7" short joint from 6870' to 6850' md 2nd Whip stoek set @ 6968' Perforation Summary Ref loa 'Dual induction. SFL dated 6/08/94 Size SPF Interval (TVD) 2" 4 7,680' -7,840' (160') 7,138' -7108' 2" 4 8,130' - 8,340' (210') 7084' - 7096' 2" 4 8,490' - 8,800' (310') 7,091' - 7,069' Old Bottom hole loeation Stinu..llation Summary 10/30/90 -194.5 M Ibs_ 16 I 20 Carbolite Pertoration SUlTlrT'Iary Ref" Ie>g: DIL I SFL 04/08/84 Interval TVD 706S' - 7128' 7160' - 7180' 7186' - 7214' (7040'-709B') (7129'-7149') (7155'-718:2') T"floal6hoe 7" fjmol<oollac {PHIU) fE,,,,,· 7436' 752' DATE REV BY COMMENTS 04/28/94 JSF 05/08/96 JSF Orilled and Completed by Nabors 27E Recompleted by Nabors 4 ES Sidetrack & Completion Nordic #2 ESP change out by N-4ES 06/15/03 11/12/05 MDO Lee Hulme Orig. KS Elev. = 56.0' (N 27E) Pad GL Elev. = 17' 27/8" x 1" KSMM SPM I 167' Halliburton 7" Oivert valve at 4348' md 27/8" x 1" KSMM SPM 6,578' 2.313" XN Nipple (2.205 no-go 10) 6,718' I Oischarge Head I 6,739' I Centrilift GC1150 ESP, GPMTAR 1:1 I 6,740' I series 513. 159 Stg. Centrilift Tandem Gas separator 513 I 6,757' I series, GRSFTXSARH6 (400 Internals) Centrilift Tandem seal section 513 I 6,762' I series, GSB3DBUT/L TILH6 PFSAFLAS/HSN Centrilift KMH 562 series, I 6,776' I 152 hp motor, 2325 volt / 40 amp Centrilift PumpMate I 6,790' I PumpMate TVD ; 6769' Baker fluted head @ 6,838' Baker tie back sleeve @ 6,838' . 6,845' Baker deplyment slv. w/4' profile @ 6.845' Baker latch collar @ 8,811' Baker float collar @ 8,812' Baker Guide shoe @ 8,845' MILNE POINT UNIT WELL MPL-01a API # :50-029-21068-01 BP EXPLORATION ~ STATE OF ALASKA _ RECEIVED ALASK~L AND GAS CONSERVATION C~ISSION . , REPORT OF SUNDRY WELL OPERATIONS JAN 03 2006 Alaska Oil & Gas Cons, COmmi$SlOn 1. Operations Performed: Cha~ e o Abandon o Suspend o Operation Shutdown o Perforate 1m Other o Alter Casing 1m Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 1m Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To urill Number: BP Exploration (Alaska) Inc. 1m Development o Exploratory 203-064 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21068-01-00 7. KB Elevation (ft): KBE = 56' 9. Well Name and Number: MPL-01A 8. Property Designation: 10. Field 1 Pool(s): ADL 025509 Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 8845 feet true vertical 7065 feet Plugs (measured) None Effective depth: measured 8810 feet Junk (measured) None true vertical 7069 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 130' 13-3/8" 130' 130' 4930 2670 Surface 2483' 9-5/8" 2483' 2483' 6870 4760 Intermediate Production 6968' 7" 6968' 6942' 8160 7020 Liner 2007' 3·112' x 3·3116' x 2·7/8' 6838' - 8845' 6816' - 7065' \5,Çti,!i\~\;\~It;,;¡ ~'.' '¡~.\."'''''''''' Perforation Depth MD (ft): 7680' - 8800' Perforation Depth TVD (ft): 7139' - 7070' Tubing Size (size, grade, and measured depth): 2-7/8",6.5# L-80 6796' Packers and SSSV (type and measured depth): NIA NIA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft .Jj~N dl 4 7006 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 1m Daily Report of Well Operations o Exploratory 1m Development o Service 1m Well Schematic Diagram 16. Well Status after proposed work: 1m Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to tne best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant s"ature~~,;"'~ >--o-'Þ :Ðr--. Phone j ~ Prepared By NamelNumber: 564-4750 Date '~ 1-f:F"\ Sondra Stewman, 564-4750 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only Tree: 2 9/16" 5M Wellhead: 13 518" x 11" 5M CI 'DGB' tbg spool wI 11" x 2 7/8" CIW Tubing Hanger, 2 7/8" EUE 8 rd threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 72 ppf, L-80 115' Btrc. MPL-01a KOP @ 6000' Max. hole angle = 11 to 15 deg. f/ 6300' to TD' Hole angle thru' perfs = 12 deg. max. DLS = 5 de ./100' 8066' BTC 2483' 7" 29 ppf, L-80, BTC production casing (drift ID = 6.059", cap. = 0.0371 bpf) 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf) 7" short joint from 6870' to 6850' md 2nd Whip stock set @ 6968' Perforatic:m Summary Ref loa 'Dual induction - SFL dated 6/08/94 Size SPF Interval (TVD) 2" 4 7,680'-7,840' (160') 7,138'·7108' 2" 4 8,130' - 8,340' (210') 7084' . 7096' 2" 4 8,490' - 8,800' (310') 7,091' - 7,069' Old Bottom hole location Stimulation SUrTlrna.ry 10/30/90 -·194.5 M Ibs_ 16 I 20 Car-bolite Perforation·.Sumrnary Roef Jog:.pIL /.SFL 0410B/84 REV BY COMMENTS 06/15/03 11/12/05 JBF JBF MDO Drilled and Completed by Nabors 27E Recompleted by Nabors 4 ES Sidetrack & Completion Nordic #2 ESP change out by N-4ES Lee Hulme Orig. KB Elev, = 56,0' (N 27E) Pad GL Elev. = 17' 27/8" x 1" KBMM SPM I 167' Halliburton 7" Divert valve at 4348' md 27/8" x 1" KBMM SPM 6,578' 2.313" XN Nipple (2.205 no-go ID) 6,718' I Discharge Head I 6,739' I Centrilift GC1150 ESP, GPMTAR 1:1 I 6,740' I series 513, 159 Stg. Centrilift Tandem Gas separator 513 I 6,757' I series, GRSFTXBARH6 (400 Internals) Centrilift Tandem seal section 513 I 6,762' I series, GSB3DBUTIL TILH6 PFSAFLAS/HSN Centrilift KMH 562 series, I 6,776' I 152 hp motor, 2325 volt I 40 amp Centrilift PumpMate I 6,790' I Pump Mate TVD = 6769' Baker ftuted head @ 6,838' Baker tie back sleeve @ 6,838' - 6,845' Baker deplyment slv. w/4" profile @ 6,845' Baker latch collar@ 8,811' Bakerftoat collar@8,812' Baker Guide shoe @ 8,845' MILNE POINT UNIT WELL MPl...01a API # :50-029-21068-01 BP EXPLORATION BP EXPLORATION Operations Summary Report Page 1 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-01 MPL-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/9/2005 11/13/2005 Spud Date: 5/17/2003 End: 11/13/2005 Date From - To Hours Task Code I NPT . Phase ¡ Description of Operations i , , .._.--._.._.__._--~.._._.- _...________----L-__ 11/10/2005 03:00 - 06:00 0.00 RIGD P PRE PJSM. Scope down & layover derrick. Rig down rig components. 06:00 - 12:00 6.00 MOB P PRE PJSM. Move rig components from MP I pad to MP L pad. 12:00 - 15:00 3.00 RIGU P PRE PJSM. Spot rig components & raise & scope up derrick. Hook up lines. Rig accepted @ 15:00 hrs, 11/10/2005. 15:00 - 16:00 1.00 KILL P DECOMP PJSM. Pick up lubricator & pull BPV. SITP = 1650 psi, SICP = 1620 psi, O/A = 150 psi. 16:00 - 18:00 2.00 KILL P DECOMP PJSM. Circulate heated seawater down tubing @ 4 bpm I 2400 psi, wI 1700 psi back pressure on choke. Circulate (50) bbls, bullhead (10) bbls @ 3 bpm 12650 psi, & continue circulating heated seawater around @ 4 bpm I 2450 psi, holding 1600 - 1700 psi on choke. 18:00 - 18:45 0.75 KILL P DECOMP Circulate heated seawater down tubing at 2 bpm/11 00 psi, w/900 psi back pressure on choke. Circulate 265 bbls to clean sewater returns. Shut well in and monitor well for 45 minutes. Final SITP = 1520 psi. EMW = 12.8 ppg for 75 psi overbalance. Ordered 500 bbls. 12.9 ppg potsssium formate frorn brine plant. 18:45 - 22:00 3.25 KILL P DECOMP Circulate remaining heated sewater to evacuate pits to make room for kill weight fluid. Shut in well and monitor same. SITP post circulation - 1340 psi. 22:00 . 00:00 2.00 KILL P DECOMP Monitor well. SITP at 00:00·1420 psi. 11/11/2005 00:00 - 03:30 3.50 KILL P DECOMP First 230 bbls. kill weight fluid arrived on wellpad. 03:30 - 07:30 4.00 KILL P DECOMP Hole volume = 250 bbls. Wait on remaining kill weight fluid to arrive on wellpad to begin well kill operations. SITp· 1440 psig. lAP - 1460 psig. @ 0500 hrs. 07:30 - 09:00 1.50 KILL P DECOMP PJSM. Line up & circulate 12.9 ppg Potasium Formate brine down tubing @ 4 bprn I 2000 psi, taking returns up itA, thru choke to tiger tank, holding 1450 psi back pressure. After kill weight fluid turnded corner & headed up itA, continue circulating @ 4 bpm I 1800 psi, opening choke as needed to maintain 1800 psi. Pumped total of 280 bbls. 09:00 . 09:30 0.50 KILL P DECOMP PJSM. Monitor well, well is dead. 09:30 - 10:00 0.50 WHSUR P DECOMP PJSM. Set two way check valve & test, OK. 10:00 . 13:30 3.50 WHSUR P DECOMP PJSM. Bleed void & N/D Cameron wellhead. 13:30 - 18:00 4.50 BOPSU P DECOMP PJSM. N/U 135/8" x 5M BOPE. 18:00 - 23:30 5.50 BOPSU P DECOMP PJSM. Service choke valves. Conduct full test on BOPE. Witnessing of test waived by AOGCC rep John Crisp. Testing of BOPE witnessed by Nabors Tool Pusher & BP Company Rep. LP 250 psi, HP 3500 psi. No failures. RID test equip. 23:30 - 00:00 0.50 WHSUR P DECOMP M/U lubricator & pull TWC. UD lubricator. 11/12/2005 00:00 . 01 :00 1.00 WHSUR P DECOMP P/U & M/U landing jt into hanger. BOLDS. Pull hanger to floor wI 58K. Check ESP cable. LID hanger & landing jt. 01 :00 . 02:00 1.00 PULL P DECOMP Circulate bottoms up. Had small amount of gas to surface. Pumped 4112 BPM @ 1400 psi. SID & monitor well. Total losses 13 bbls. 02:00 - 02:30 0.50 PULL P DECOMP Pull ESP cable over sheave & attach to spool. 02:30 - 06:00 3.50 PULL P DECOMP POOH & stand back 2 7/8" ESP completion. 06:00· 06:30 0.50 PULL P DECOMP PJSM. Lubricate & service rig. 06:30 - 08:00 1.50 PULL P DECOMP PJSM. Continue to POOH w/2 7/8" tubing & ESP assembly. 08:00 . 11 :00 3.00 PULL P DECOMP PJSM. UD pump assembly. Recovered 2" BPV from on top of pump assembly. Lower pump assembly shaft twisted off. 11 :00·13:30 2.50 PULL P DECOMP PJSM. Change out spools. Load pump & motor assembly. Printed: 11/14/2005 7:30:27 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/12/2005 MPL-01 MPL-01 WORKOVER Start: 11/9/2005 NABORS ALASKA DRILLING I Rig Release: 11/13/2005 NABORS 4ES Rig Number: From - To I,u~~~~s Task I ~~~e! NP~_¡ _Phase 11 :00 - 13:30 2.50 P DECOMP 13:30 - 15:30 2.00 RUNCMP 15:30 - 23:00 7.50 RUNCMP 23:00 - 23:30 0.50 RUNCMP 23:30 - 00:00 0.50 RUNCMP 11/13/2005 00:00 . 02:00 2.00 RUNCMP 02:00 . 02:30 0.50 RUNCMP 02:30 . 05:00 2.50 BOPSU P RUNCMP 04:00 - 07:00 3.00 WHSUR P RUNCMP 07:00 . 08:00 1.00 WHSUR P RUNCMP 08:00 - 10:30 2.50 WHSUR P RUNCMP 10:30 . 12:00 1.50 WHSUR P RUNCMP Page 2 of 2 Spud Date: 5/17/2003 End: 11/13/2005 Description of Operations ------...- Remove trunk & drain hose. Rig up to run ESP completion. PJSM. Pick up & service pump assembly. Pull ESP over sheave. PJSM. RIH wI ESP assembly on 2 7/8" EUE 8Rd tbg. Check cable for conductivity every 2000'. P/U & M/U hanger. & landing jt. Make final splice on ESP cable. Con't to make final field splice. Plug in & test same. Land completion. P/U Wt = 52K, S/O = 52K RILDS. Set TWC & test to 3500 psi. Installed 2 Flat Guards, 4 Protectolizers, 112 LaSalle Clamps. N/D BOPE. N/U & test X-mas tree to 5000 psi, Ok. PJSM. P/U lubricator, pull two way check valve. Test lines to 3500 psi, OK. PJSM. Circulate seawater to displace out 12.9 ppg brine. Circulate down tubing @ 3 bpm I 1900 psi. After turning corner, take returns thru choke, holding back pressure and keeping pump pressure @ 3 bpm I 1800 psi. Sent approximately (350) bbls of 12.9 ppg brine back to MI mud plant. PJSM. Pick up lubricator, set BPV. Suck water out of tree & replace wI diesel. Secure well. Rig released @ 12 noon, 11/13/2005. Printed: 11/14/2005 7:30:27 AM e e Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Brian Bixby AOGCC Rep: Waived Submitted By: Date: 12/13/2005 Unit/Field/Pad: Alaska Consolidated Team/Milne PointIMPL Separator psi: LPS HPS mm Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI MPL-OIA 2030640 140 100 100 P P OIL Wells: 1 Components: 2 Failures: o Failure Rate: 0.00% MPL-O 1 was recently put back on production. Witnessing was waived by Jeff Jones. Remarks: '. If - ÀJ¡.!\'~ øh_, ~~1l¿;4 -\:ti '~_if~~l:(", ~-¡ ~i Page 1 SVS MPU L 12-13-05 Misc.xls J c..¡ J\f\~ ~~, )- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030640 Well Name/No. MILNE PT UNIT KR L-01A Operator BP EXPLORATION (ALASKA) INC 5. t/L¿ LIJw-~) API!Jo. 50-029-21068-01-00 MD 8845 r ND 7065 /" Completion Date 6/14/2003 -- Completion Status 1-01l Current Status 1-01l UIC N REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes - ------- DATA INFORMATION Types Electric or Other Logs Run: MWD, RES, GR, RWD, CCl Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from logs Portion of Master Well Data Maint) ~--:;""" Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments ---- --: ED C ~ J,..J:> 12151 b.IS Verification ~~ Name Interval Start Stop 6258 8788 1 0/1 0/2003 lDWG edit of 3 pass Memory Gamma Ray 6900 8845 9/16/2003 6900 8845 9/16/2003 5 Blu 6995 8845 Open 4/21/2004 MPR, GR, RWD, DSN 12653 5 Blu 6995 8845 Open 4/21/2004 MPR, GR, RWD, DSN 12653 25 Blu 6975 8845 Open 4/21/2004 GR, RWD, DSN 12653 6967 8845 Open 4/21/2004 GR, RWD, DSN 12653 6967 8845 Open 4/21/2004 GR, RWD, ~~, Sample Set Sent Received Number Comments ED D ~ )(T ! i Rpt I ~ j I ~g b'6g ! Rpt I ! ED C Lis Directional Survey Directional Survey Induction/Resistivity I nd uction/Resistivity Gamma Ray Gamma Ray 12653 Gamma Ray 'flf"'- Well Cores/Samples Information: ADDITIONAL INFORMATION Well Cored? Y @> Chips Received? ~ Daily History Received? (?;/ N ~N Formation Tops Analysis Received? ~ --- --.-" DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030640 Well Name/No. MILNE PT UNIT KR L-01A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21068-01-00 MD 8845 NO 7065 Completion Date 6/14/2003 Completion Status 1-01L Current Status 1-01L UIC N Comments: Compliance Reviewed By: ~ Date: - .-1. ,. 11. -~---== t..-¡ f~ .2..;J-f¡ L - -- -.. ~( f \ ¿;ZCJ~3 - 0 G, \f ])5.f\J t 2/.0 ~ 3 Transmittal Form INTEQ ¡;;:; c 1 w -c:::r 11 c::> > ~ - ~ W N &3 ev' e'- GIS <i i5 œ; -I < '&1. BAKER HUGHES Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: ,. Robin Deason Reference: MPL-OIA Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blue line - GR/Directional Measured Depth Log 1 blueline - MPR Measured Depth Log 1 blueline - MPR True Vertical Depth Log LAC Job#: 487457 Sent By: Glen Horel / / r Receive~p . úI~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Date: Apr )ß}.. 004 Date: ~I Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~.._." _. u___ .~.. _u,u__ .___. '.__._.n., ~~-~~~~:~~-;;---l ~;:-;':;~;J';;:;.:,~--'- ,..'.: .,' , __~ __ I,J,' ., .....' ~~ :~;;,~'~~! ~Loo ...._ _ ....... . .'1 .... ---"" -- .., "............. -......-'" I I =::!~ ==~"':-~ 09/26/03 Sc_lunI~epgep NO. 2976 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Color Date Blueline Prints CD 06/11/03 /"" ~'~i 08/26/03 1/ ,- 09/16/03 1 L/ }~¡~V 04/23/03 ~l~ 02103/03 1/ 01/04/03 MPL-01A ~"1) ~-()(nYI 23433 CH EDIT MGR (PDC) D.S.15-28A~ð!~3-~.j, 23431 MCNL K-07C rq(.... I f5c 10560303 RST -SIGMA C-31 B dr2'~ 23423 CH EDIT MGR (PDC) D.S.15-30A ~...rJf)~ 23422 CH EDITMGR(PDC) 3-25A1N-24 - ) l.{1'J......\ ~ ~ SCMT (REPLACES 3-25A1M-27 PRINTS) ,~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Date Delivered: . , ç-- Received b~\9 LN\ D\ 0 ~'-o'l'f\.. :'-~"<~ - .',-;-,-: -,- ~~~ {'\'.-~ i' STATE OF ALASKA { ALASL,"\ OIL AND GAS CONSERVATION COivl1V11SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: iii Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CASING, LINER AND CEMENTING RECORD II: :¡,I,,:II'Sem~iN:~IIIII¡Qg~':HI'¡I,'I;':"l" 111'1~~III;:II'I"'lli::ttiiæ'!¡I:i'I'II:II¡:!:I:: 1:,I'¡I~~Ö~mø~¡¡'I;:!,:' Surface 130' Surface 2483' Surface 69681 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1970' SNL, 158' EWL, SEC. 08, T13N, R10E, UM Top of Productive Horizon: 2532' SNL, 120' EWL, SEC. 08, T13N, R10E, UM Total Depth: 3017' SNL, 3853' WEL, SEC. 08, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 544759 y- 6031499 Zone- ASP4 TPI: x- 544726 y- 6030936 Zone- ASP4 Total Depth: x- 546037 y- 6030459 Zone- ASP4 18. Directional Survey iii Yes 0 No 21. Logs Run: MWD I RES, GR RWD, CCL 22. 13-3/8" 72# L-80 9-518" 47# L-80 7" 29# L-80 BTRS 9.2# / 6.2# / 6.16# L-80 6838' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 SPF MD TVD MD TVD 7680' - 7840' 8130' - 8340' 8490' - 8800' 7139' - 7108' 7084' - 7097' 7091' -7070' One Other 5. Date Comp., Susp., or Aband. 6/14/2003 / 6. Date Spudded 6/412003 ' 7. Date T.D. Reached 6/9/2003 . 8. Elevation in feet (indicate KB, OF, etc.) KBE = 56' 9. Plug Back Depth (MD+ TVD) 8810 + 7069 Ft 10. Total Depth (MD+TVD) 8845 + 7065 Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1 b. Well Class: iii Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-064 13. API Number 50- 029-21068-01-00 14. Well Number MPL-01A 15. Field and Pool Milne Point Unit / Kuparuk River Sands 16. Lease Designation and Serial No. ADL 025509 17. Land Use Permit: Milne Point Unit 20. Thickness of Permafrost 1800' (Approx.) 'f7' ¡)...:.....t~.. 1>/¡7~" mz:> (PI ~o/''' "'(V.Þ 17-1/2" 12-1/4" 8-112" To Surface 1000 sx CS III, 750 CS II 750 sx Class 'G', 600 sx Class 'G' Downsqueezed: 100 sx CS I 147 sx Class 'G' 8845' 3-3/4" x 4-1/8" ·3-1/2" x 3-3/16" x 2-7/8" SIZE 2-7/8",6.5#, L-80 PACKER SET (MD) DEPTH SET (MD) 6795' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 15 Bbls of MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 24, 2003 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF 7/23/2003 6 TEST PERIOD + 509 229 Flow Tubing Casing Pressure CALCULATED + Oll-Bsl GAs-McF Press. 24-HoUR RATE W A TER-Bsl 188 W A TER-Bsl CHOKE SIZE GAS-all RATIO 451 all GRAVITy-API (CaRR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or w~ter(áttaêh'sepàrate she~t, if necessary). Submit core chips; if none, state "none". I None . , . ,,_.~: L;¿~3:f .,', . ,. .. \-:.IJ..,":':'; 'i,':,:':;' I /~.,,~'~ Form 10-407 Revised 2/2003 OR\G\NAL(}~ CONTINUED ON REVERSE SIDE RBDMS BFL AUG 1 1 1003 "28. GEOLOGIC MARK( 29. (' FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TKC1 7087' 7044' None TKUB 7104' 7054' TKUA 7350' 7120' TKA3 7395' 7125' TKA2 7475' 7137' TKA3 7871' 7102' TKA2 8121' 7083' TKA3 8428' 7093' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr Technical Assistant MPL-01A Well Number Date Lß· O~ -0 ~ Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Mark Johnson, 564-5666 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". ORIGINAL Form 10-407 Revised 2/2003 ( ( BP EXPLORATION Operations Summary Report Page 1 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M P L -01 MPL-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/26/20.0.3 18:0.0 - 00:00 6.00. MOB P PRE Rig move from W Pad to MPL-o.1 location. 5/27/200.3 00:00 - 0.6:00 6.00. MOB P PRE Moving to MPL-o.1 location. At 0600 hrs rig at Milne Camp waiting on crew change. 06:00 - 11 :30 5.50 MOB P PRE Continue to move to location. 11 :30 - 14:30 3.00 MOB P PRE Level out around cellar. Set matting boards. Spot rig. 14:30 - 17:00 2.50 MOB P PRE RU rig Spot auxilary equipment. 17:00 - 19:00 2.00 MOB P PRE Authorization to Proceed Meeting + prespud meeting held at Milne pt base camp. Attended by Milne Ops,Safety,and Enviro. Nortic, Dowell Schlumberger, Mi,Centralift, BP CTD 19:0.0 - 21 :30 2.50. MOB P PRE Continue to RU rig. 21 :30 - 22:00. 0.50. MOB P PRE Pull back pressure valve with lubricator. 22:00 - 0.0:00 2.00 MOB P PRE Test lines and stage vac trucks with Hot seawater. 5/28/200.3 00.:00 - 0.1 :0.0 1.00. MOB P PRE Continue to RU for well kill. Monitor well. Tubing pressure 1100. psi, Annulus pressure 1140 psi. 0.1 :0.0 - 04:00 3.00 KILL P DECOMP Circulate hot Seawater to clean up well. Circulate @ 3bpm with 1330 psi. No losses. 04:0.0. - 08:00 4.00. KILL P DECOMP Pump 40. bbl 10.7 ppb pill and displace with 10.9 brine, Bullhead 25 bbl of pill to the formation at 1.1 bpm (530. psi initial injection pressure and 640 psi final injection pressure). Continue to circulate 10.9ppg brine around with 840. psi at 3 bpm. 50% losses. Reduce rate to 1.5 bpm at 260 psi. Losses decreased significantly. 0.8:0.0 - 09:00. 1.0.0 KILL P DECOMP Monitor well, both tubing and IA on vacuum. OA pressure is zero. Well is dead. 09:0.0 - 12:00 3.00 WHSUR P DECOMP Cameron wellhead specialist on location. PT 7" Casing Packoff. PT to 1 ,Oo.o.psi for 30min. Good test. 12:00 - 12:30 0..50. WHSUR P DECOMP Install two way check prior to removing tree. 12:30 - 13:30 1.0.0 WHSUR P DECOMP ND tree and THA. Inspect 2-7/8" tubing hanger running threads, good condition. 13:30 - 13:45 0.25 BOPSURP DECOMP Hold PJSM to discuss BOP NU procedure. Decide to remove 7-1/16" stack from cellar for clearance to NU 13-5/8". 13:45 -14:30 0.75 BOPSURP DECOMP Remove 7-1/16" BOPs from cellar. Mount on stand. Set off on location. 14:30 - 14:45 0.25 BOPSUR P DECOMP PU 11" tubing head x 13-5/8" XO, position in cellar. 14:45 - 15:00 0.25 BOPSUR P DECOMP PJSM prior to NU 13-5/8" BOP stack. Review procedure, discuss good communication, fall protection and pinch points. 15:00 - 17:45 2.75 BOPSURP DECOMP Install 11 " tubing head x 13-5/8" drilling spool. Variables, mud cross, Double gate and Annular. 17:45 - 18:00 0.25 BOPSUR P DECOMP Tech limits 18:00 - 23:30 5.50 BOPSUR P DECOMP Continue to NU BOP's. NU annular preventer, riser and BOP control liner. 23:30 - 00:00 0.50 RIGU P DECOMP Remove rig sign and lift ESP spooling equipment thru roof of pipe shed. 5/29/200.3 0.0.:0.0 - 02:00 2.00 RIGU P DECOMP Continue to lift ESP spooling equipment to rig floor. Interrupted BOP rig up based on availability of crane. 0.2:0.0 - 07:00. 5.00 BOPSUR P DECOMP Continue to make up riser and BOP control lines. 0.7:0.0 - 13:00 6.00 BOPSUR P DECOMP Begin BOP test. Call out GBR to extend 16" riser between BOPs and rig floor. Troubleshoot leaks in 3" gray-Ioc connections on choke and kill line. Replace Gray- loe fittings. 13:00 - 15:30 2.50 BOPSUR N RREP DECOMP Wait on Gray loe fittings. Replace Gray- foe fittings. 15:30 - 00:00 8.50 BOPSURP DECOMP Continue BOP test with John Spaulding as AOGCC witness. Had to rebuild one HCR. 5/30./2003 00.:0.0 - 02:00 2.00 BOPSURP DECOMP LD test joint. PU mouse hole. Clear floor. Printed: 6/16/2003 2:05:08 PM { (' BP EXPLORATION Operations Summary Report Page 2 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-01 M PL -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/30/2003 02:00 - 03:00 1.00 RIGU P DECOMP Pull CT to rig floor and stab coil. 03:00 - 05:00 2.00 RIGU N WAIT DECOMP RU ESP shieve. Wait on pup to extend 4ES lubricator. 05:00 - 06:30 1.50 RIGU P DECOMP RU lubricator to pull TWC. 06:30 - 07:45 1.25 WHSUR P DECOMP Pull two way check. LD Lubricator. 07:45 - 08:00 0.25 PULL P DECOMP PJSM. Review plan forward for pulling tubing hanger, tubing, ESP cable and ESP. Discuss hazards and risks. 08:00 - 09:00 1.00 PULL P DECOMP PU 2-7/8" landing jt. Back out lock down screws (LDS). Pull tubing hanger. PU wt=50K SO wt=38K 09:00 - 10:00 1.00 PULL P DECOMP Route ESP cable over sheave and onto spooler. Change out Farr tong dies to get proper grip on tbg collars. 10:00 - 20:00 10.00 PULL P DECOMP Pull 3 jts and first GLM. All appear to be in good condition. Fill hole using trip tank. Took about 5 bbls. Once filled, fluid level dropping very slowly. Continue to POOH with 2-7/8" EUE 8 rd completion. ESP cable spooler working well. 20:00 - 21 :30 1.50 PULL P DECOMP LD ESP. ESP NORM'd by Centralift. Pipe inspected by API. 21:30 - 22:15 0.75 PULL P DECOMP Clear floor. Fill hole. Monitor well. Loss 8 bbl to fill. 22:00 - 22:30 0.50 PULL P DECOMP Continue to clear floor. Remove 8 damaged joints. (1 punched,4 bad pins, 2 bad boxes and 1 exterior damage gouge). 22:30 - 23:30 1.00 PULL N DECOMP Airboot on riser leaked while filling well with brine. Clean up 15 gal Brine spill. 14 gal in containment 1 on pad. (IR# 2003-IR-524437 ) 23:30 - 00:00 0.50 PULL P DECOMP RU floor to MU casing scraper for drift run. Scraper has 3-1/2 IF connection. Need to RU Eckley 5-1/2" power tongs to torque it and the subsequent RTTS asssembly. 5/31/2003 00:00 - 03:45 3.75 PULL P DECOMP PU Eckel 5-1/2" power tongs and RU tongs, hydraulic lines. Repair leaks 03:45 - 04:30 0.75 PULL P DECOMP PU drift ( casing scraper) and 3 stands of tubing and RIH. POH to surface. 04:30 - 07:00 2.50 PULL P DECOMP RIH with 14-1/2 stands ( damaged one joint) 2-7/8" tubing RTTS and two stands tubing. Set RTTS. 07:00 - 08:30 1.50 PULL P DECOMP Fill hole between RTTS and blinds. Close blinds. Pressure test 7" RTTS w/ SSC valve. Cameron monitoring the 7" Casing packoff. OA=Opsi, IA=Opsi at start. Pressure slowly to 2000psi, IA tracking WHP, Opsi on 7" packing test port. Increase to 3500psi, Opsi on test port. Good test. Evacuate stack. 08:30 - 08:45 0.25 BOPSUR P DECOMP PJSM on ND 13-5/8" stack 08:45 - 13:15 4.50 BOPSUR P DECOMP Disconnect hydraulics. ND riser, 13-5/8" annular and 13-5/8" upper doublegate. Inspect riser failure: likely stem failure on air boot, plan to replace air boot. 13:15 - 14:00 0.75 BOPSUR N WAIT DECOMP Re-align 7-1/16" doublegates with respect to rest of stack. Wait on 11" x 13-5/8" XO to place above 13-5/8" mudcross. 14:00 - 15:30 1.50 BOPSUR P DECOMP NU XO 11" X 13-5/8" on top of 13-5/8" mudcross. 15:30 - 16:00 0.50 BOPSURP DECOMP PJSM on NU 7-1/16" stack 16:00 - 23:45 7.75 BOPSURP DECOMP NU 7-1/6" BOP Stack (Top down: annular, double gate w/blind shear & 2-3/8" pipe/slip, mud cross, double gate w/ VBR& 2-3/8 combi, 7" full opening MV, XO 7" x 11", XO 11" x 13-5/8", 13-5/8" mud cross, 13-5/8" single gate) 23:45 - 23:55 0.17 BOPSURP DECOMP PJSM for BOP test. 23:55 - 00:00 0.08 BOPSURP DECOMP BOP test. AOGCC John Spalding waived witnessing the BOP test. 6/1/2003 00:00 - 05:00 5.00 BOPSURP DECOMP Continue BOP test. AOGCC John Spalding waived witnessing Printed: 6/16/2003 2:05:08 PM { BP EXPLORATION Operations Summary Report Page 3 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-01 MPL -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/1/2003 00:00 - 05:00 5.00 BOPSUR P DECOMP test. Test good. No failures. E-mail results to AOGCC. 05:00 - 06:15 1.25 BOPSURP DECOMP PJSM before RIH to retrieve RTTS. RIH. Engage packer. Open SSC valve & check for pressure under packer. POH with packer. 06:15 - 06:45 0.50 BOPSUR P DECOMP lD RTTS packer & SSC valve. 06:45 - 07:15 0.50 BOPSUR P DECOMP Tech limits meeting, discuss plan forward. 07:15 - 08:00 0.75 BOPSURP DECOMP Stand back 14 stands of 2-7/8" tubing. Fill hole, took 8bbls to fill the hole. 08:00 - 09:00 1.00 RIGU P WEXIT RU Schlumberger Eline unit. 09:00 - 09:15 0.25 RIGU P WEXIT PJSM on eline ops 09:15 - 09:30 0.25 RIGU P WEXIT Cont RU Schlumberger Eline unit 09:30 - 10:00 0.50 STWHIP P WEXIT PU junkbasket, 6.04" gauge ring, CCl on eline. 10:00 - 13:00 3.00 STWHIP P WEXIT RIH with drift assembly on eline. Sit down at 6800', work past. Drift to 7,060'md. 13:00 - 13:45 0.75 STWHIP P WEXIT lD Drift assembly and PU CIBP (5.687" OD). Found metal band in junk basket and several chunks of rubber. PU setting tools for CIBP, missing XO to CIBP for eline set. 13:45 - 15:30 1.75 STWHIP N WEXIT Wait for Baker to retrieve XO. Review tool requirements for running whipstock with SlB & Baker (again). 15:30 - 16:00 0.50 STWHIP P WEXIT MU Baker CIBP on SlB e-line setting tool with GR/CCL. 16:00 - 18:15 2.25 STWHIP P WEXIT RIH with bridge plug. log in and set at 7035'. 18:15 - 19:30 1.25 STWHIP P WEXIT POH. 19:30 - 19:45 0.25 STWHIP P WEXIT Pressure test BP and casing to 1500 psi. Good Test. 19:45 - 20:45 1.00 STWHIP P WEXIT PU Whip stock. 20:45 - 21 :45 1.00 STWHIP P WEXIT RIH with whipstock. 21 :45 - 22:45 1.00 STWHIP P WEXIT log in correct +3'. make multiple passes at various speeds but at 14 degrees iinclination tool not rotating. Set WS with top at 6990' 30R. 22:45 - 23:30 0.75 STWHIP P WEXIT POH. 23:30 - 00:00 0.50 STWHIP P WEXIT lD whipstock setting tool and RD "E" line. 6/2/2003 00:00 - 00:30 0.50 STWHIP P WEXIT Continue to RD Eline. 00:30 - 01 :30 1.00 STWHIP P WEXIT MU coil connector pull 35k. MU milling BHA. 01 :30 - 01 :45 0.25 STWHIP P WEXIT Circulate to fill coil. 01 :45 - 02:20 0.58 STWHIP P WEXIT MU BHA #1 window milling. Pressure test coil connector to 3500 psi. OK . MU BHA to Coil connector and stab injector on to well. 02:20 - 03:40 1.33 STWHIP P WEXIT RIH. Tag at 6989.9 Correct to pinch point add 4.6'. Corrected tag 6994.5'. 03:40 - 04: 12 0.53 STWHIP P WEXIT Mill with 2.6 BPM at 2630 psi. FS. Up wt 31 K, DN wt 7K, 60 psi MW. WOB 1700. ROP 34 Milling lIike casing is thin. Making progress with little motor work and little WOB. Mill to 7001.1 midway point? 04: 12 - 04:35 0.38 STWHIP P WEXIT Park at 7000.1 Mill to 7002. Set brake mill off almost immediately at 7002.8 motor work 270 psi. Mill to 7002.9. Pick up and retag. 7004.2 Clean pick up. 04:35 - 05:00 0.42 STWHIP P WEXIT Mill 2.6 bpm at 2,950 psi 220 psi MW, WOB 0-2K. At 7003.2 Getting steady motor work. Acts like pinch point. Possible Helical buckling pipe in 7" explaines erratic behavior. 05:00 - 07:30 2.50 STWHIP P WEXIT Mill 2.6 bpm at 2940 psi. FS = 2630 psi. Mill to 7007.2' lose pump #2. Switch to pump #1 on the fly, did not come on line quickly enough. Motor stalls. PU off bottom. 07:30 - 08:45 1.25 STWHIP P WEXIT FS = 2625psi. Ease back down into milling, 0.3fpm. See motor work at 7002', likely top of whipstock. Continue rih to 7007', see Printed: 6/16/2003 2:05:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( (' BP EXPLORATION Operations Summary Report M P L -01 M PL -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 6/2/2003 07:30 - 08:45 From - To Hours Task Code NPT Phase WEXIT 08:45 - 09:30 09:30 - 11 :00 11 :00 - 13:00 13:00 - 13:20 13:20 - 14:45 14:45 - 19:30 19:30 - 20:00 20:00 - 20: 15 20:15 - 20:30 20:30 - 20:45 20:45 - 22:00 22:00 - 22:30 6/3/2003 22:30 - 00:00 00:00 - 01 :15 01:15 - 01:30 01 :30 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 05:45 05:45 - 06:30 06:30 - 07:00 07:00 - 08:40 08:40 - 09:45 09:45 - 11 :00 11 :00 - 12:30 12:30 - 14:45 1.25 S1WHIP P 0.75 S1WHIP P 1.50 S1WHIP P 2.00 S1WHIP N 0.33 S1WHIP N 1.42 S1WHIP N 4.75 S1WHIP N 0.50 S1WHIP N 0.25 S1WHIP N 0.25 S1WHIP N 0.25 S1WHIP N 1.25 S1WHIP N 0.50 S1WHIP N 1.50 S1WHIP N 1.25 S1WHIP N 0.25 S1WHIP N 1.00 S1WHIP N 1.00 S1WHIP N 0.50 S1WHIP N 1.75 S1WHIP N 0.75 S1WHIP N 0.50 S1WHIP N 1.67 S1WHIP N 1.08 S1WHIP N 1.25 S1WHIP N 1.50 S1WHIP N 2.25 S1WHIP N WEXIT WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT Page 4 of 12 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Description of Operations motor work. Mill 2.6bpm, 2820psi. 200psi MW, WOB 0-2.5K Mill to 7008.1 Mill 2.6bpm at 2970psi. See wt back at 7009.5'md, may be off the tray. No addtional motor work as we slack off. Mill to 7013'md, motor stall. PU, pull heavy to 70K near 7006'. RBIH, stall. PU to 70K, stall. Unable to pull free. Continue to work pipe, unable to push/pull free, trying to get the motor working again. 1.3bpm 3360psi, seeing higher pressures at lower pump rate. Looks like we are stuck at the bit, pumping through a stalled motor. Discuss options with town. Continue to circulate at 1.3bpm. Pressure up backside to 1000psi. Slack off, set down, no movement. PU to 65K, no movement. Bleed WHP, PU to 75K while circulating, drop pumps. Still stuck. Drop 7/8" steel ball to disconnect, circulate at 1.6bpm, 3950psi, ball went over the top at 43bbls (12bbls late). Ball on seat at 56.5bbls. Trip pumps at 4400psi, no indication of shearing seat. Run up to 4700psi, nothing, run up to 5,OOOpsi this is Max pressure. No indication of seat shearing. Call out pump truck from cementers in Kuparuk. Wait for pump truck crew. Crew stuck on wrong side of Kuparuk R., the bridge was closed this afternoon. In the mean time spot Eline unit and prep new whipstock. RU cementers. PJSM for pressuring disconnect. Test lines to 8000 psi. Line up to coil and pressure up while holding neutral weight. Disconnect sheared at 2238 psi. RD cementers. POH. LD BHA #1. Fish left in hole Speed mill,string reamer,2-7/8 extreme motor,circ sub, and lower section of HYD disconnect. RU "E" line and Pu whipstock assembly. RIH with whipstock. Log in and set whipstock 5 deg LOHS top of whipstock at 6968'. Lost 300# of PU weight. POH to surface with Eline. LD whipstock running tools and RD wireline. PU window mill BHA. RIH and dry tag at 6974.2' Top of Whipstock 6968'. Pinch point 4' down. PU, bring on pumps to 2.55bpm. RIH at 0.8fpm. See motor work and lose wt at 6979.3' correct -7' to pinch point 6972.4'. FS=2260psi, RIH wt 12.8KLbs, PU wt 29KLbs. Milling 2.54/2.54bpm, 2350-2390psi. PVT= 229bbl (active system: pits 2,3,5) IA=60, OA=Opsi. TK Limits meeting: discuss plan forward, LL'd Milling 6974.0 2600-2650psi,2.55/2.55bpm. Mill to 6975.5 Milling 2360-2600psi, 2.52/2.52bpm. Mill to 6976.3'md Milling 2380psi, 2.52/2.52bpm. Mill to 6977.1 Should be at the halfway point on the tray. Mill to 6977.9 Milling 2500psi, 2.53/2.53bpm. Mill to 6977.8 Send two 5bbl High vis sweep around. Milling 2475psi, 2.53/2.53bpm. Mill to 6980.3 Send 5bbl High Printed: 6/16/2003 2:05:08 PM ,( i ~" BP EXPLORATION Operations Summary Report Page 5 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-01 M PL -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Descri ption . of Operations 6/3/2003 12:30 - 14:45 2.25 STWHIP N DPRB WEXIT vis sweep around. Bottom of the tray should be at 6980.3 (7.9' below the pinch point) 14:45 - 15:30 0.75 STWHIP P WEXIT Milling 2200-2350psi, very little motor work 10-1 OOpsi. 2.5/2.5bpm. ROP picking up, 0.3fpm. Mill to 6986.4'md 15:30 - 15:50 0.33 STWHIP P WEXIT PU, pu wt=32k initially, dropped to 28K. Hung up near 9682' came free. Pu to 6950'md. RBIH, 1.6fpm, RIH wt=12klbs, slight motor work at top of whip 6972'md. See slight motor work at 6981', bottom of window. Tag up at 6986.4'md, right where we left it. Continue drilling formation, 2300-2450psi, 2.5/2.5bpm, 0.5fpm. Send another 5bbl sweep around. Mill to 6990. 15:50 - 16:00 0.17 STWHIP P WEXIT PU clean through window to 6960'. RBIH clean through window. Tag up at 6990, mill to 6990.3 This should be 10' outside window. 16:00 - 18:00 2.00 STWHIP P WEXIT POOH with window milling BHA #2. Formation on shakers. 18:00 - 18:30 0.50 STWHIP P WEXIT Speed mill in gauge. Add string mill to BHA. 18:30 - 20:00 1.50 STWHIP P WEXIT RIH 20:00 - 21 :30 1.50 STWHIP P WEXIT Ream through window. Little motor work on first pass. Two additional passes O.K. Dry tag. O.K. 21 :30 - 22:45 1.25 STWHIP P WEXIT POH to 3089'. 22:45 - 00:00 1.25 STWHIP N WAIT WEXIT Wait on mud to complete mud swap. Due to limited vac truck availability ( River closure) are having to round trip Vac trucks. 6/4/2003 00:00 - 02:00 2.00 STWHIP N WAIT WEXIT Continue waiting on mud delivery. Stored mud (due to bridge outage) has been sitting for days unagitated and has crosslinked to the extent it is in is difficult to move. Will dilute with some of the 10.9 ppg brine. 02:00 - 03:00 1.00 STWHIP N WAIT WEXIT Standby while diluting mud on truck. Cannot blow it off. Have to ship brine from rig, agitate and blow back to rig. 03:00 - 03:30 0.50 STWHIP P WEXIT Continue to POH to surface while changing over to Flo Pro. 03:30 - 04:00 0.50 STWHIP P WEXIT LD milling BHA #3. Mills in gauge. 04:00 - 04:45 0.75 STWHIP P WEXIT Change out coil connector and pull test to 44K. Presure test to 3400 psi. O.K. 04:45 - 05:30 0.75 STWHIP P WEXIT MU 3.0 building assembly. 05:30 - 06:45 1.25 STWHIP P WEXIT RIH 06:45 - 07:35 0.83 STWHIP P WEXIT Tie-in, log down from 6790'. (-5' correction) At 1.8bpm, losing the majority of returns over the shakers, changeout to new screens (175). Drop pumps to prevent losing mud over shakers, mud needs to be heated and sheared. Unable to drill with the current mud system. 07:35 - 10:00 2.42 STWHIP N FLUD WEXIT Park above the window & circulate at 2.5bpm, bypass shakers, steam the pits. Gradual improvement. 10:00 - 10:30 0.50 STWHIP P WEXIT Orient, RIH past window with pumps off. Window looks clean. Takes a couple of stalls/pick-ups to get started drilling. 10:30 - 14:30 4.00 DRILL P PROD1 FS= 3730psi at 2.45bpm. RIH wt. = 12K-13K Drilling 4100-4250psi, FS 2900 psi 2.6/2.6bpm. Very slow, <10 FPH (good MW, but slow diggin). Drill to 7030'md. RA marker seen at 6978' corrected as expected. This puts corrected TOW= 6972, BOW=6980. 14:30 - 18:45 4.25 DRILL P PROD1 Directionally drill at 2.6 / 2.6 bpm at 4000 psi. FS = 3730 psi. Drill to 7048. 18:45 - 19:00 0.25 DRILL P PROD1 Wiper to 6990 19:00 -19:15 0.25 DRILL P PROD1 TF 60L. 19:15 - 22:00 2.75 DRILL P PROD1 Directionally drill 2.6/ 2.6 bpm @ 4080 psi. FS = 3730 psi. Printed: 6/16/2003 2:05:08 PM ( (' BP EXPLORATION Operations Summary Report Page 6 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M P L -01 M PL-O 1 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/4/2003 19:15 - 22:00 2.75 DRILL P PROD1 WOB 6-7K, ROP 9-14. Drill to 7064'. 22:00 - 22:45 0.75 DRILL P PROD1 Orient having trouble getting desired tool face of 90L. 22:45 - 23:45 1.00 DRILL P PROD1 Drill to 7070. 23:45 - 00:00 0.25 DRILL P PROD1 Orient having trouble getting desired tool face. Too much motor bent to orient in open hole. Can get one for one in casing. 6/5/2003 00:00 - 01 :30 1.50 DRILL N DFAL PROD1 POH to dial down motor and change out orienter. 01 :30 - 03:00 1.50 DRILL N DFAL PROD1 Change out bit, motor, orienter. Bit balled and had chipped cutters on nose and bicenter gauge. Motor bearing had a little play in it. 03:00 - 05:00 2.00 DRILL N DFAL PROD1 RIH correct to flag EOP 6700'. Correct -2.4'. RIH and tag at 7068'. 05:00 - 06:45 1.75 DRILL P PROD1 Orient. Tough getting clicks (hole configuration). 06:45 - 10:30 3.75 DRILL P PROD1 Drill FS 3300 psi at 2.6 BPM. Drill to 7091'md. 10:30 - 11 :00 0.50 DRILL P PROD1 Orient highside, getting reactive on bottom and having to PU and orient again. 11 :00 - 14:25 3.42 DRILL P PROD1 Drilling 3800-4000psi, 2.6/2.6bpm. Drilling break at 7094'md. ROP picking up, 30-60fph. Drill to 7196', this is the bottom of the 35deg DLS build section. We are on plan with respect toND and need to catch up to the planned left turn. Stacking. 14:25 - 15:50 1.42 DRILL P PROD1 Orient to 45-50L. Difficult getting back to drilling, orientor is ratcheting around after motor stalls on bottom. 15:50 - 16:45 0.92 DRILL P PROD1 Drilling 3600-3900psi, 2.6/2.6bpm. ROP=50-60fph TF=50L. Drill to 7240'md (7041'ND), Inc= 81deg. 16:45 - 18:00 1.25 DRILL P PROD1 POH pumping at 2.7bpm to change motor bend. PVT=240bbls, OA=60psi. 18:00 - 20:30 2.50 DRILL P PROD1 Changout BHA. Dial down motor to 1.2. PU resistivity tool. 20:30 - 22:00 1.50 DRILL P PROD1 RIH to 6700' EOP flag correct -5'. 22:00 - 23:00 1.00 DRILL P PROD1 Log in to marker correct +4'. 23:00 - 23:45 0.75 DRILL P PROD1 Orient 105L. 23:45 - 00:00 0.25 DRILL P PROD1 Directionally drill 2.55 /2.55 bpm @3700 psi. FS = 3250 psi. 6/6/2003 00:00 - 06:30 6.50 DRILL P PROD1 Continue to directionally drill lateral. 2.51/2.51 @3750 psi. FS = 3250psi. ROP 25. 5-8 K WOB. Slow by steady progess. Drill to 7396'md 06:30 - 07:10 0.67 DRILL P PROD1 Wiper to window. Hole is in good condition. No overpulls. OA= 80psi 07: 10 - 07:45 0.58 DRILL P PROD1 FS=3260psi @ 2.6bpm. RIH wt=1 0,300 Lbs., PU wt=26,000Lbs. Drilling, 2.6/2.6bpm in/out, 3500psi, ROP=25-30fph. Drilling break at 7400' (exiting the bottom of B shale). 80deg inc projected to bit. 07:45 - 08: 15 0.50 DRILL P PROD1 Orient. Getting 20deg clicks vs 36deg design value. Weatherford rep says this orientor can give "partial" clicks ie. 18deg instead of the 36deg as it ratchets around. 08:15-10:10 1.92 DRILL P PROD1 Drilling 3900psi 2.6/2.6bpm. ROP=70-100fph, then slowing. Stacking, make a couple short trips (BHA length). Drill to 7500'md. Geo has identified the top of the A2 on GR. 10:10 - 10:30 0.33 DRILL P PROD1 Wiper to window. See motor work, backreaming at 71 OQ'md (Shale). Orient highside to start climbing, plan to go as deep as 7089'ND. 10:30 -12:30 2.00 DRILL P PROD1 Drill 3700-3900psi, 2.6/2.6bpm. ROP=60-100fph in A2 sand. Drill to 10650'md. 12:30 - 13:00 0.50 DRILL P PROD1 Wiper to window. Two slight overpulls at 7310', 7150'md. 13:00 - 13:45 0.75 DRILL P PROD1 Drill to 7696'md. 101deg projected at the bit. 13:45 - 14:00 0.25 DRILL P PROD1 Orient 90L. Getting one for one, full 36deg clicks. Printed: 6/16/2003 2:05:08 PM ( (' BP EXPLORATION Operations Summary Report Page 7 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PL -01 M PL -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/6/2003 14:00 - 14:40 0.67 DRILL P PROD1 Drill to 7800'md. 14:40 - 15:40 1.00 DRILL P PROD1 Wiper to window. Slight motor work at 71 OO'md. 15:40 - 16:00 0.33 DRILL P PROD1 Orient 90-1 05L. 16:00 - 18:45 2.75 DRILL P PROD1 Drilling, 3600-3900psi, 2.6/2.6bpm. ROP=60-120fph. Drilled to 7944'. 18:45 - 19:20 0.58 DRILL P PROD1 Wiper to window. At 7340 and above over pull, and motor work. Stacked out and motor work back thru 7340 area. 19:20 - 19:30 0.17 DRILL P PROD1 Orient 3 clicks for 3. TF 165L. 19:30 - 20:30 1.00 DRILL P PROD1 Directionally drill 2.6/ 2.6 bpm @ 3600 psi. FS = 3250 psi. ROP 50 - 170 . Drill to 8038'. 20:30 - 20:35 0.08 DRILL P PROD1 Orient 3 clicks for 3. TF 115L. 20:35 - 21 :00 0.42 DRILL P PROD1 Directionally drill 2.7 /2.7 bpm @ 3950 psi FS = 3250 psi. ROP 130. Drill to 8089'. 21:00-22:10 1.17 DRILL P PROD1 Pump 30 bbl high vis pill. Make wiper to window. 5K over pull 7300 -7200'. No motor work. RIH motor work at 7350 took weight at one spot. Much better than previous trip. 22: 10 - 00:00 1.83 DRILL P PROD1 Directionally drill Up wt 26K, dn wt 12K, 2.6/2.6 bpm @ 3800 psi FS = 3400 psi. ROP 25 -140 fph. Drill to 8,194'. 6/7/2003 00:00 - 00:35 0.58 DRILL P PROD1 Orient 2 for 2. TF hi side. Continue to drill lateral section. 2.6/ 2.6 bpm @ 3700 psi. FS = 3250 psi. ROP 125 UP wt 26K, Dn wt 12K, Drill to 8240'. 00:35 - 01 :35 1.00 DRILL P PROD1 Wiper trip to window. Over pull at 7700 20+K. Ratty from 7500 to 7200, . Trip back in smooth. 01 :35 - 01 :45 0.17 DRILL P PROD1 Orient TF 105L. Getting click per click. 01:45 - 04:15 2.50 DRILL P PROD1 Directionally drill 2.6 / 2.6 bpm @ 3650 psi FS = 3400 psi. Up wt 31 K, Dn wt 7K. ROP 50-80. Pump 30 bbl high vis pill to bit prior to wiper trip. Drill to 8390'. 04:15 - 05:30 1.25 DRILL P PROD1 Wiper trip to window. Clean at 7700 this time. Ratty 7300 to 7050 very little motor work. RIH set down at 7326' and 7350. 05:30 - 07:15 1.75 DRILL P PROD1 Directionally drill ROP=100-150fph. Slide is deteriorating off bottom, it is difficult to get drilling after PU. Will swap to new mud after next wiper trip. 07:15 - 07:55 0.67 DRILL P PROD1 Directionally drill to 8540. OA=328psi 07:55 - 09:00 1.08 DRILL P PROD1 Wiper trip to window. 30fpm, 2.6bpm 3300-3550psi. PU wt=28000. Pull heavy at 8250 to 50k no motor work. Smaller overpulls without motor work at 8144,8005,7613,7535,7520, 7490,7410,7350,7261 (ratty throughout 7300-7220). Overpull to 50k at 7207. Overpulls at 7160. Pumps down thru window. Overpull at 6952' (top of whipstock area using correction below and up vs down depth). 09:00 -10:15 1.25 DRILL P PROD1 Log tie-in. Add 10'. 10:15 -12:00 1.75 DRILL P PROD1 RIH, sit down just outside window, then fell through. RIH ratty to 7115'. Tough working past this depth at minimum pump. Stall with pumps. Try orient to drilled TF. Did not get any clicks. Work through tough spot. Continue RIH to bottom. Send new mud downhole. 12:00 - 13:00 1.00 DRILL N FLUD PROD1 Orient. Not getting any clicks. Noticed Mud was 10.1 ppg on MMin. Choke returns to 200psi, continue displacing mud. 13:00 - 16:30 3.50 DRILL N FLUD PROD1 Condition hole while waiting on 12.8 brine to weight up mud. Overpull at 7390, no motorwork. Slow down to 1 Of pm as we POH. See 10K overpull motor work at 7331,7300. RBIH, sit down fall thru 7350', PU and clean this area up. RIH, ratty from 7300-7400'. Printed: 6/16/2003 2:05:08 PM f (' BP EXPLORATION Operations Summary Report Page 8 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-01 MPL-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/7/2003 16:30 - 22:30 6.00 DRILL N FLUD PROD1 RIH to TD. MWD failure, likely lost our MWD battery. Better slide with new mud. Continue working hole -- getting better. Set downs 8434 to 8515. Get mud to 10.9 ppg and 12 ppb KG. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 POH . Ratty 7315 to 7150. Motor work and over pull at 7290'. POH. 6/8/2003 00:00 - 01:40 1.67 DRILL N DFAL PROD1 Continue to POH to surface. 01 :40 - 03:15 1.58 DRILL N DFAL PROD1 LD Orienter and MWD. 03:15 - 03:25 0.17 DRILL P PROD1 PJSM BOP test. 03:25 - 07:00 3.58 BOPSUR P PROD1 Test BOP's 07:00 - 07:30 0.50 DRILL P PROD1 Tech limit meeting, discuss plan forward, LL'd and HSE. 07:30 - 09:30 2.00 DRILL N DFAL PROD1 PU BHA #7: Hycalog DS100 3.75"x4.25" Re-Run (srl# 105421), USMPR, 1.5deg X-treme. New MWD batteries and replace pulser. 09:30 -10:15 0.75 DRILL N DFAL PROD1 PT Reel valve to 3500psi. RIH. Shallow hole test. MWD failed shallow hole test. No pulses. 10:15 -10:30 0.25 DRILL N DFAL PROD1 POH 10:30 - 15:00 4.50 DRILL N DFAL PROD1 Troubleshoot MWD pulser, re-program "flow switch". RIH, without swapping pulser. Shallow hole test a second time, failed test, no pulses. POH. LD tools at surface and changeout pulser. 15:00 - 15:20 0.33 DRILL N DFAL PROD1 RIH, shallow hole test, good test. 15:20 - 16:20 1.00 DRILL N DFAL PROD1 Continue RIH. 16:20 - 17:10 0.83 DRILL N DFAL PROD1 Tie in logging down from 6785'. No correction. Orient to HS above whipstock. 17:00 - 18:00 1.00 DRILL N DFAL PROD1 RIH. RIH wt above window=12500-13000. Set down at 7070' wI motor work (MW). Set down: 7343 with MW, 8315 no MW, Ratty from 8315-8540'md. Cleaner hole than was expected. 18:00 - 18:20 0.33 DRILL P PROD1 Orient to Highside. 18:20 - 19:15 0.92 DRILL P PROD1 Log down last 40' at 60 fph. With new mud and slightly higher weight, Gamma ray higher API. Need new base line info for corrolation. Tag bottom 8556'. 19:15 - 23:00 3.75 DRILL P PROD1 Directionally drill 2.5 I 2.5 bpm 3750 psi. 3600 psi = FS, WOB 1-2K, ROP 45-55. TF high side. Drill to 8665'. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 POH for MWD failure. (Later confirmed as MWD DAS failure) 6/9/2003 00:00 - 00:10 0.17 DRILL N DFAL PROD1 POH to window. Reload MWD software. MWD working. Over pulled at 7900 and 7220. 00: 1 0 - 00:30 0.33 DRILL N DFAL PROD1 RIH to 7690 smooth trip. MWD failed 00:30 - 01 :40 1.17 DRILL N DFAL PROD1 POH. To surface. Hole looking better. 01 :40 - 04:30 2.83 DRILL N DFAL PROD1 Change out failed MWD. 04:30 - 05:40 1.17 DRILL N DFAL PROD1 RIH. BHA#8: Hycalog DS100 3.75 X 4.25" (Rerun2 SN 105421)1.5 deg Extreme and new MWD. 05:40 - 06:15 0.58 DRILL N DFAL PROD1 Tie in. 06:15 - 07:15 1.00 DRILL N DFAL PROD1 RIH. 07:15 - 08:15 1.00 DRILL N DFAL PROD1 Orient to 90R. 08: 15 - 09:45 1.50 DRILL P PROD1 Difficult to start drilling on bottom, sticky. Drilling with negative weight: 3900psi, 2.6/2.6bpm. Struggle to drill after PU off bottom. 09:45 - 10:50 1.08 DRILL P PROD1 Orient. Difficulty getting back on bottom, PU 200' off bottom and pump at 1.7bpm while RIH at 5fpm. 10:50 - 12:50 2.00 DRILL P PROD1 Drilling with negative wt: 3900psi, 2.6/2.6bpm. ROP inconsistent= 20-100fph. Drill to 8827'md 12:50 - 15:50 3.00 DRILL P PROD1 Wiper. Overpull at 8377', 8327', 8247', 8030', 7599', ratty from Printed: 6/16/2003 2:05:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: (' ( Page 9 of 12 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/9/2003 12:50 - 15:50 3.00 DRILL P PROD1 7400-7100'md. RIH, hole in good shape to 8300'. 8300' to bottom is a struggle, negative wt on surface. Slick lubetex pill turning the corner at 8250'md, no noticeable effect on slide. 15:50 - 16:45 0.92 DRILL P PROD1 On bottom at last. Drilling, stick-slip type behavior. Poor weight transfer. Drill to 8845'md. PU, unable to get back to TD after trying for over 30m in. seem to be losing ground. Call TD at 8845'md (7008'NDss). NOTE: The poor slide and inability to get back to bottom is very similar to the drilling conditions we have seen in the past when we had to drill with KCL water during severe lost circulation. 16:45 - 17:40 0.92 DRILL P PROD1 Wiper. Pump 50 bbls very high vis pill (LSRV not measured, but suspect around 200k), focusing on sweeping low spot with bit agitation. Ratty from 7400' up to 7100'. Multiple overpulls without motor work. 17:40 - 18:20 0.67 DRILL P PROD1 Log down from 6780' for final tie-in. Correction +3'. 18:20 - 19:45 1.42 DRILL P PROD1 RIH stackout at 8650, 8753, and 8781 continue to RIH to TD @ 8845'. Much smoother trip to TD this trip down (high vis sweep do something for us?) 19:45 - 20:45 1.00 DRILL P PROD1 Circulate new mud pill (5% lubetex) in open hole. 20:45 - 23:00 2.25 DRILL P PROD1 POH to surface. Flow check OK. 23:00 - 00:00 1.00 DRILL P PROD1 Down load MWD data. LD BHA#8. 6/10/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Continue to LD BHA. Pump dart 57.4 bbl coil displacement. Change out coil connector. Pull and pressure test Baker Coil Connector. Clear floor. RU floor for liner job. 01 :30 - 02:00 0.50 CASE P COMP PJSM for liner running. 02:00 - 05:30 3.50 CASE P COMP PU 2-7/8 X 3-3/16 STL liner. 05:30 - 05:45 0.25 CASE P COMP PU and stab injector 05:45 - 07: 1 0 1.42 CASE P COMP RIH with 3-3/16" x 2-7/8" liner, 5.75" OD fluted C2 sleeve on top. Depth correct at flag, -1. First set down outside window at 7080', drop through. Set down again at 8320'. Set down and PU at 8347',8384'. Ratty past 8800'md. Set down at 8850' MD uncorrected. Repeat tags. This is TD. Confirm full circulation on bottom, 0.6/0.6bpm in/out @ 1350psi. Off bottom PU wt=38K. 07: 10 - 08:30 1.33 CASE P COMP Launch 5/8" steel ball. Pump to seat (54 bbls). Shear at 2800 psi. PU and free from liner at 24k. 08:30 - 11 :45 3.25 CEMT P COMP Displace well to 10.9 ppg formate brine at 2.7 BPM; 2300 psi. 11:45 -12:15 0.50 CEMT P COMP Pre-job meeting with cementers. 12:15 - 13:30 1.25 CEMT N COMP WO dirty truck. 13:30 - 15:30 2.00 CEMT P COMP Mix cement. Pump 5 bbls 3% KCL water spacer. PT lines to 4000 psi. Pump another 5 bbls of 3% KCL spacer. Load 30 bbls class G cement into coil at 2.5 BPM; 2900 psi. Load dart, pump bio water to inner reel valve, pressure to 500 psi. Re-zero MMin. Launch dart. Check -- gone. Displace cement with 50 bbls 10.9 ppg formate brine with 2ppb biozan at 2.5/3300 initial and 2.8/2800 before slowing down for latch-up. (Lost pump #1 at MMin of 32 bbls; swap to pump #2). Lower pump rate to 2.0/1100 at 54 bbls. Latch up with LWP at 57.7 bbls and shear at 3200 psi. Displace LWP to LC at 2.0/1500. At 68 bbls, slow to 1.5/1100. Bump at 70.3 bbls (0.2 bbls before calculated). No cement losses. Pressure to 1800 psi. Bleed to check floats -- no flow. Pressure to 500 psi. Unsting. 15:30 - 17:00 1.50 CEMT P COMP Lay in 10 bbls bio-brine at 1.0 BPM; 54 FPM (50% Printed: 6/16/2003 2:05:08 PM BP EXPLORATION Operations Summary Report M P L -01 M PL -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 ( (' BP EXPLORATION Operations Summary Report Page 10 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M P L -01 M P L -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From -To Hours Task Code NPT Phase Description of Operations 6/1 0/2003 15:30 - 17:00 1.50 CEMT P COMP contamination with cement above us) for 600'. Continue POOH at rate just high enough to keep hole full (0.7/0.1 and 115 FPM). 17:00 - 17:30 0.50 CEMT P COMP UD liner running equipment. 17:30 - 19:00 1.50 CEMT P COMP WOC. Sample at lab but 3 hrs behind CIP time. Hold TL meeting review plan forward and LL. Crew change. Plan is to RIH with nozzle and cleanout TOC and TOL at high flow rate rather than slower flow rates required when using motor. 19:00 - 19:30 0.50 CEMT P COMP P/U nozzle and MHA. 19:30 - 21 :20 1.83 CEMT P COMP RIH at 50'/min w/o pumping to 6000' while waiting for 500 psi compressive strength. 21 :20 - 22:30 1.17 CEMT P COMP Compressive strength at 500 psi and climbing. Continue RIH at normal speeds pumped ahead with 20 bbl biozan pill. Tagged at 6845', top of Baker Deply Sleeve. 22:30 - 00:00 1.50 CEMT P COMP Pump at 4 bpm with bio pill and flush TOL. PUH to 6300' then back down to 6845'. Chase biozan to surface and POH. Circulated 50 bbls contaminate to cuttings tank. 10-12 bbls heavy with cement. Continue TOH. Set back injector. 6/11/2003 00:00 - 00: 15 0.25 CEMT P COMP UD nozzle assembly. 00:15 - 00:35 0.33 EVAL P COMP PJSM review BHA for logging/cleanout run. 00:35 - 03:30 2.92 EVAL P COMP P/U Baker motor and SLB CCUgr carrier and 66 jts 1 1/4" CSH tubing. 03:30 - 04:30 1.00 EVAL P COMP RIH with cleanout assembly 04:30 - 06:00 1.50 EVAL P COMP Start logging CCUgr from 6500'. Log down at 30 FPM. Tag and stall at 8810' (PBTD) uncorrected. Log up at 60 FPM. 06:00 - 07:00 1.00 EVAL P COMP RIH to PBTD and lay in 15 bbl perf pill in liner: 120k LSRV 10.9 ppg formate brine pill (with 10 ppb KG). 07:00 - 08:30 1.50 EVAL P COMP POOH. Did not see any more cement returns on BU. Returns look clean. 08:30 - 10:30 2.00 EVAL P COMP Drop 5/8" ball to open circ sub. Stand back CSH. 10:30 -11:15 0.75 EVAL P COMP LD motor, mill, logging tools. 11: 15 - 11 :45 0.50 CEMT P COMP Pressure test liner lap to 1450 psi bled to 1350 psi while double blocking everything. Bled to 1200 psi in 25 minutes. 11 :45 - 13:00 1.25 EVAL P COMP Download GR/CCL data. Corrected PBTD is 8808'. Fax logs to Anchorage. Discuss bottom perf with asset -- OK to make 8800' the bottom shot. No other changes to perf intervals. 13:00 - 13:30 0.50 PERF P COMP Pre-job meeting: perforating 13:30 - 14:00 0.50 PERF P COMP RU to run guns. 14:00 - 14:30 0.50 CEMT P COMP Re-test hole to 1500 psi. Bled off 250 psi to 1250 psi in 30 minutes. OAP stayed at 0 psi during test. 14:30 - 17:15 2.75 PERF P COMP MU 54 loaded and blank 2" HSD 4spf Power Jet guns 680' net loaded. 17:15 - 19:00 1.75 PERF P COMP MU 33 stands CSH. (bha length = 3190.96') Stab on injector. 19:00 - 20:15 1.25 PERF P COMP RIH. Tagged PBTD at 8808'. 20: 15 - 20:55 0.67 PERF P COMP Load and launch .625" steel ball. Displace with 58 bbls 10.9ppg brine. Ball on seat and moving pipe up. Guns fired at 3300psi with bottom shot at 8800'. Minor mud losses seen. 20:55 - 22:00 1.08 PERF P COMP TOH. Stop at 6800'. Check in/out MM 1.32/1.27 bpm Continue TOH 22:00 - 23:45 1.75 PERF P COMP UD 66 jts of 1 1/4" CSH. 23:45 - 00:00 0.25 PERF P COMP PJSM on laying down perf guns. 6/12/2003 00:00 - 05:00 5.00 PERF P COMP UD 1145' of 2" perf guns. All guns fired. Zones perfed: 8800'·8490', 8340'-8130', 7840'-7680'. Printed: 6/16/2003 2:05:08 PM ( (' BP EXPLORATION Operations Summary Report Page 11 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M P L -01 M PL -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/12/2003 00:00 - 05:00 5.00 PERF P COMP Hole appears to be static. 05:00 - 06:30 1.50 PERF P COMP Clear floor and load out perf guns. 06:30 - 06:45 0.25 RUNCOrvP COMP Safety meeting for blowdown of reel. 06:45 - 07: 15 0.50 RUNCOrvP COMP Check hole again. Took < 1/2 bbl to fill after 3 hours. 07:15 - 08:00 0.75 RUNCOrvP COMP Blow down reel with N2. 08:00 - 08:30 0.50 RUNCOrvP COMP Pre-job meeting: unstab coil. 08:30 - 10:30 2.00 RUNCOrvP COMP Unstab coil and secure at reel 10:30 - 11 :00 0.50 RUNCOrvP COMP PU and RU Eckel tongs. 11:00-11:15 0.25 RUNCOrvP COMP Safety meeting. 11: 15 - 13: 15 2.00 RUNCOrvP COMP MU 15 stands of 2-7/8" EUE (- 900'). MU RTTS packer and SSC. RIH and set packer at 87' below tubing head. 13:15 -13:45 0.50 RUNCOrvP COMP Pressure test plug to 3175 psi. Bled 30 psi in 25 min. 13:45 - 15:30 1.75 RUNCOrvP COMP Blow down stack. ND choke and kill line. ND 7" stack. 15:30 - 00:00 8.50 RUNCOrvP COMP Nipple up 13 5/8" stack. 6/13/2003 00:00 - 00:30 0.50 RUNCOrvP COMP Finish N/U 13 5/8" BOP stack. 00:30 - 00:45 0.25 RUNCOrvP COMP PJSM review testing procedures and hazards. 00:45 - 05:00 4.25 RUNCOrvP COMP Pressure test BOPE to 3500 psi. Witnessing wavied by AOGCC. 05:00 - 05:15 0.25 RUNCOrvP COMP PSJM review pulling procedure for HOWCO RTTS. 05:15 - 06:30 1.25 RUNCOrvP COMP P/U 2 stds 27/8" tbg with TIW valve. Rotate into RTTS, confirm no pressure, pull free. LD packer. Hole is full and static. 06:30 - 08:00 1.50 RUNCOrvP COMP Stand back 15 stands 2-7/8" tubing. 08:00 - 08:30 0.50 RUNCOrvP COMP Crew change and safety meeting. 08:30 - 09:00 0.50 RUNCOrvP COMP Finish standing back 2-7/8" tubing. 09:00 - 10:00 1.00 RUNCOrvP COMP Safety meeting for running ESP completion. 10:00 - 11 :00 1.00 RUNCOrvP COMP RU to run completion. 11 :00 - 14:00 3.00 RUNCOrvP COMP MU pump and cable 14:00 - 14:30 0.50 RUNCOrvP COMP MU and RIH with 2-7/8" 8rd EUE tubing (same tubing pulled from well). Started getting spongy at about 400' in with elevators coming down but not the pipe. By about 750' in, too spongy -- getting nervous. PU and lost a little ground. Confirmed that pipe was filling. 14:30 - 19:00 4.50 RUNCOIVN HMAN COMP POOH, inspecting cable, clamps, etc. Found a "pump protectorizer" clamp used in a "motor protectorizer" application. Stand-off created a larger OD 6.125" than 7" 29# csg drift ID 6.059" 19:00 - 22:00 3.00 RUNCOIVN HMAN COMP Correct protector not on slope. Altered the clamp we have to <5.85" OD but then unable to install "door" over protector. Looking for original clamp from de-completion. Found it. Install and 00 is now 5.9375" slightly larger than we want. Reinstall modified clamp wlo door as per MPU instruction. 22:00 - 00:00 2.00 RUNCOIVN HMAN COMP MU and RIH with 2 7/8" completion string. Check 2 places where cable was pinched on previous TOH - okay. 6/14/2003 00:00 - 10:00 10.00 RUNCOrvP COMP MU remaining tubing and completion equipment -- no further problems with tight clearances. Total of 210 full joints, 2-GLM assemblies wI pups, XN nipple with pups, ESP pump and motor. 114 Laselle clamps (1 on each of the first 10 collars, then every other collar; 2 flat guards, 1 motor protectolizer, 5 pump protectolizers). 10:00 - 12:00 2.00 RUNCOrvP COMP Break circulation -- good. MU hanger, penetrator, landing joint. MU lower connector. Check continuity. 12:00 - 13:00 1.00 RUNCOrvP COMP RIH and land hanger. Printed: 6/16/2003 2:05:08 PM (" ( BP EXPLORATION Operations Summary Report Page 12 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PL -01 M PL -01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/26/2003 Rig Release: 6/14/2003 Rig Number: N2 Spud Date: 5/17/2003 End: 6/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/14/2003 13:00 - 13:30 0.50 RUNCOrvP COMP RI lock down screws. Break-out landing jt.. 13:30 - 15:30 2.00 RUNCOrvP COMP Set TWC. PT from above to 2500 psi -- good. RU on IA and pressure to 250 psi (0.3 BPM)-- no flow up through TWC. 15:30 - 16:30 1.00 RUNCOrvP COMP Clean-up floor; offload brine from pits. 16:30 - 17:00 0.50 RUNCOrvP COMP Pre-job meeting: ND stack. 17:00 - 19:30 2.50 RUNCOrvP COMP ND 13 5/8" 5K stack. Clean mud tanks. 19:30 - 19:40 0.17 RUNCOrvP COMP PJSM NU production tree. 19:40 - 23:15 3.58 RUNCOrvP COMP NU 2 9/16" CIW production tree. Check continuity with Centrilift equipment - ok. PT tree to 5000 psi 23: 15 - 00:00 0.75 RUNCOrvP COMP Pull TWC and set BPV. Rig released at midnight 6-14-2003. 00:00 - 0.00 P POST Printed: 6/16/2003 2:05:08 PM Obp ( f BP Baker Hughes INTEQ Survey Report B.. .... INTEQ Company: BP Amoco Field: Milne Point Site: M Pt L Pad Well: MPL-01 Wellpath: MPL-01A Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 7/1/2003 Time: 16:55:30 Page: Co-ørdinate(NE) Reference: Well: MPL-01, True North Vertical (fVD) Reference: 1 : 01 3120/1984 00:00 56.0 Section (VS) Reference: Well (0.00N,0.00E.113.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: M Pt L Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6029799.28 ft 544529.55 ft Latitude: Longitude: North Reference: Grid Convergence: 70 29 32.230 N 149 38 9.412 W True 0.34 deg Well: MPL-01 Slot Name: 01 MPL-01 Well Position: +N/-S 1698.58 ft Northing: 6031499.10 ft Latitude: 70 29 48.935 N +E/-W 239.73 ft Easting : 544759.08 ft Longitude: 149 38 2.355 W Position Uncertainty: 0.00 ft Wellpath: MPL-01A 500292106801 Current Datum: 1 : 01 3/20/1984 00:00 Magnetic Data: 3/31/2003 Field Strength: 57507 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 MPL-01 6968.00 ft Mean Sea Level 25.50 deg 80.84 deg Direction deg 113.00 Height 56.00 ft Survey Program for Definitive Wellpath Date: 7/1/2003 Validated: Yes Actual From To Survey ft ft 100.00 6900.00 1 : Camera based gyro multisho 6968.00 8845.00 MWD Version: 4 Toolcode Tool Name CB-GYRO-MS MWD Camera based gyro multishot MWD - Standard Annotation 6968.00 6942.06 KOP 8845.00 7064.52 TD Survey: MWD Start Date: 6/9/2003 Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Engineer: Tied-to: From: Definitive Path Survey 6900.00 13.12 215.00 6875.83 6819.83 -252.32 -33.45 6031246.61 544727.16 67.80 0.00 6968.00 13.02 215.80 6942.06 6886.06 -264.85 -42.35 6031234.02 544718.33 64.50 0.30 6997.60 18.00 208.60 6970.58 6914.58 -271.58 -46.50 6031227.28 544714.22 63.31 18.01 7027.30 28.39 201.30 6997.85 6941.85 -282.21 -51.27 6031216.61 544709.51 63.07 36.23 7057.10 39.46 194.00 7022.55 6966.55 -298.06 -56.15 6031200.74 544704.73 64.77 39.53 7092.10 52.38 185.46 7046.87 6990.87 -322.78 -60.18 6031176.00 544700.85 70.72 40.80 7122.30 58.45 185.11 7064.00 7008.00 -347.52 -62.47 6031151.24 544698.71 78.28 20.12 7156.10 65.92 183.70 7079.76 7023.76 -377.31 -64.75 6031121.44 544696.61 87.82 22.41 7186.70 72.07 181.59 7090.73 7034.73 -405.83 -66.06 6031092.92 544695.47 97.76 21.10 7217.70 77.87 178.78 7098.76 7042.76 -435.75 -66.14 6031063.00 544695.57 109.38 20.65 7250.90 80.42 173.51 7105.02 7049.02 -468.27 -63.95 6031030.50 544697.96 124.10 17.38 7280.90 79.89 168.59 7110.15 7054.15 -497.46 -59.35 6031001.34 544702.73 139.74 16.25 ( ( -tIC ObP BP Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 7/1/2003 Time: 16:55:30 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPL-01. True North Site: M Pt L Pad Vertical (fVD) Reference: 1 : 01 3/20/1984 00:0056.0 WeD: MPL-01 Section (VS) Re(erenœ: Well (0.00N,O.00E.113.00Azi) Wellpath: MPL-01A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/1 000 7311.60 81.74 161.91 7115.06 7059.06 -526.75 -51.64 6030972.10 544710.62 158.29 22.31 7339.40 83.32 156.98 7118.67 7062.67 -552.55 -41.96 6030946.37 544720.45 177.27 18.48 7371.10 83.23 150.66 7122.39 7066.39 -580.78 -28.08 6030918.21 544734.50 201.09 19.80 7402.50 82.27 146.79 7126.35 7070.35 -607.40 -11.91 6030891.70 544750.83 226.37 12.60 7435.60 81.91 141.87 7130.91 7074.91 -634.03 7.20 6030865.19 544770.10 254.36 14.76 7486.40 80.77 134.84 7138.57 7082.57 -671.53 40.55 6030827.89 544803.67 299.71 13.86 7530.40 84.55 132.73 7144.19 7088.19 -701.72 72.05 6030797.89 544835.34 340.50 9.82 7587.00 90.44 133.43 7146.66 7090.66 -740.33 113.33 6030759.54 544876.85 393.59 10.48 7636.10 94.75 133.78 7144.44 7088.44 -774.15 148.84 6030725.94 544912.56 439.49 8.81 7687.00 100.37 137.30 7137.75 7081.75 -810.13 184.17 6030690.17 544948.10 486.07 12.99 7727.40 100.81 133.78 7130.32 7074.32 -838.47 211.98 6030662.00 544976.08 522.74 8.63 7758.60 101.16 129.91 7124.37 7068.37 -858.90 234.79 6030641.71 544999.01 551.72 12.23 7806.90 101.51 123.94 7114.87 7058.87 -887.34 272.63 6030613.50 545037.02 597.67 12.14 7835.20 101.34 119.37 7109.26 7053.26 -901.89 296.23 6030599.10 545060.71 625.08 15.84 7862.00 100.99 117.61 7104.07 7048.07 -914.43 319.34 6030586.69 545083.89 651.25 6.57 7903.10 102.66 113.74 7095.65 7039.65 -931.86 355.59 6030569.49 545120.24 691.43 10.07 7937.50 102.48 110.58 7088.16 7032.16 -944.53 386.68 6030557.01 545151.40 724.99 8.98 7987.70 95.63 109.17 7080.26 7024.26 -961.36 433.27 6030540.46 545198.09 774.46 13.92 8026.80 89.82 107.77 7078.40 7022.40 -973.73 470.30 6030528.32 545235.19 813.38 15.28 8056.10 87.54 106.71 7079.08 7023.08 -982.41 498.27 6030519.80 545263.21 842.52 8.58 8087.60 86.40 104.60 7080.74 7024.74 -990.90 528.56 6030511.50 545293.55 873.72 7.61 8115.00 85.61 101.44 7082.65 7026.65 -997.06 555.19 6030505.50 545320.21 900.63 11.86 8150.30 81.83 99.68 7086.51 7030.51 -1003.49 589.67 6030499.28 545354.73 934.89 11.80 8198.60 83.50 94.76 7092.68 7036.68 -1009.50 637.18 6030493.55 545402.27 980.97 10.68 8232.20 87.01 95.81 7095.46 7039.46 -1012.59 670.52 6030490.67 545435.62 1012.86 10.90 8272.20 88.07 91.95 7097.18 7041.18 -1015.29 710.38 6030488.21 545475.49 1050.61 10.00 8302.50 89.56 89.48 7097.81 7041.81 -1015.67 740.67 6030488.01 545505.78 1078.64 9.52 8327.50 93.08 89.13 7097.23 7041.23 -1015.36 765.66 6030488.46 545530.76 1101.53 14.15 8354.30 92.81 86.32 7095.85 7039.85 -1014.30 792.40 6030489.69 545557.49 1125.73 10.52 8386.10 92.11 83.86 7094.49 7038.49 -1011.58 824.05 6030492.60 545589.12 1153.80 8.04 8422.30 92.20 81.40 7093.13 7037.13 -1006.94 859.92 6030497.45 545624.97 1185.01 6.80 8454.80 91.41 79.29 7092.10 7036.10 -1001.49 891.94 6030503.09 545656.95 1212.35 6.93 8503.10 90.70 84.56 7091.21 7035.21 -994.71 939.74 6030510.16 545704.70 1253.70 11.01 8544.20 89.82 88.78 7091.03 7035.03 -992.33 980.76 6030512.79 545745.70 1290.53 10.49 8577.90 93.78 88.78 7089.97 7033.97 -991.61 1014.43 6030513.71 545779.36 1321.24 11.75 8604.20 96.94 91.24 7087.51 7031.51 -991.61 1040.61 6030513.87 545805.54 1345.34 15.20 8644.40 97.03 97.22 7082.62 7026.62 -994.55 1080.38 6030511.17 545845.33 1383.10 14.77 8680.10 94.39 98.27 7079.07 7023.07 -999.34 1115.58 6030506.59 545880.55 1417.37 7.95 8715.20 92.20 103.55 7077.05 7021.05 -1005.97 1149.97 6030500.17 545914.98 1451.62 16.26 8759.40 95.63 108.47 7074.03 7018.03 -1018.13 1192.34 6030488.27 545957.41 1495.37 13.55 8797.10 96.59 110.93 7070.02 7014.02 -1030.76 1227.63 6030475.85 545992.77 1532.79 6.97 8845.00 96.59 110.93 7064.52 7008.52 -1047.76 1272.07 6030459.12 546037.31 1580.34 0.00 ....¡365O C æ6700 - o 121>750 _ J: ~ ~ G B . West(-)/East(+) [100ft/in] Q685O- - "., . .···rKõPl .' ¡.. .. i. I. r---4 ~.._ ! i I ~---r--1 r -r- ==+- ~ i:: ~. ~~=-- ..- '~--=-_L ----i-~~- .T~~)~-!_c=~-k~---i~ cll__-~~r.:--, t- c r ! nl-~+ ::~f~ - ~~t-= > --t-: I _ ;! I J ¡ I ~- --'- -----+------ ~------ - TD r !::~- !-~,-.., -,!~~~-Lr+ ··1~1 ---=~- !~H=-r <!-l-~.~~L~l- 7150 1-1~~t-i +1 +- I ~ ¡ ++++ t' --+--1-~~i-~--~ i t-¡ 1-{j--tJ - ·I,ii'·. ¡__t~..::-=--_-LI.""'_-~_ :..._--_.~_- I'_·.~.·::I·"____'· ._'.-_~ 7200 j-r~vr~C;j;" f,~ I~ ,; ;"I~-L, r~-¡ '" ",1"" ,.T ;; !,;;¡C; q,~~~,;;~;;~;~T;,i " I "! ' ¡,,, i '" I " , ¡ " , I " , i' ;, I" , T':-T;F";~~ -100 -50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 Vertical Section at 113.00° [50ft/in] BP Amoco Parent Wellpath: Tie on MD: Rig: Ref. Datum: V.Section Angle 113.00° WELLPATH DETAILS MPL.()1A 500292106801 MPL.()1 6968.00 Nordic 2 1 : 01 3120/1984 00:00 56.00ft Origin +EJ-W 0.00 Origin +N/-S 0.00 Starting From 1VD 0.00 REFERENCE INFORMATION Co-ordinate (NIE~ Reference: Well Centre: MPL-Q1, True North Vertical (NO Reference: System: Mean Sea Level Section (VS Reference: Slot - 01 (O.OON,O.OOE) Measured Depth Reference: 1: 01 3/20/1984 00:00 56.00 Calculation Method: Minimum Curvature ANNOTATIONS TARGET ŒTNlS TW -tflI-S +EI-W S/'Q¡)e 0_00 -855.86 -38828 poÞjgcn ~.~ :~I'~¡ if(~) 1VD MD Annotation &IP_-01A~1 :i'::millF-" ::~1}; 6886.06 6968.00 KOP 7006.52 8845.00 TO 6500 6550 6600 ...- ~".c..·..œ;¡.·~. -.... bþ h"'rtßQ " LEGEND T æ:f'¡':'JiYmJ Azimuths to True North Magnetic North: 25.50° Magnetic Field Strength: 57507nT Dip Angle: 80.84· Date: 3/31/2003 Model: BGGM2002 ~. .,;:'..,/ 200 300 J I 100 o -100 - c æ -200 g -300 ... ... -400 - + :ë-500 1:: 0-600 ~ ::!: -700 J: '5 -800 o en -900 -1000 -1100 -1200 -1300 -1G Wellpalh: (MPL-01/MPL-01A) Created By: Brij Potnis Date: 71112003 Contact Information' .' Direct: (907) 267-6613 Baker Hughes I~i-~~: (~:})~~~~qcom -I i i i i ¡ ; ì 1 ¡-'j--'T-'''!--~~=~1==-F-- I ' ¡ - -cl--~~ll.:-~~ 1---1- --·-~--h-¡~-~--~-- I I I I ; I I ____~b=~ ! .¡-=-~~=-=- 1 i i -~. ~--+:-=--t~~ I----~~-~-L--~ ! I I j ! I - 1 i I i --.-.-------+------- ! ----==--==----=====-.:..1·---------::...:.::..= I ¡_~~ .·L__~ i l-~: ¡ -->-- ----- ~-- --~~-- I I I I i I I I . --.j _ jun . I· .. I· J. ~. I I MPL-01,MPL-01A Plan ¡-+~- ~-r--:----- J I ì I I ¡ n__ - - ...... . í ~. l==--=== -=--==--....::::: I ~ r::æ::¡ U I ! --~-- .1 I I ~~~-~-+~ Ii! -~ -~--- -~ - - ~-~--- 1111 m-,-rTTllTI--'T'rr-Trn---r¡ r ~4,. i II 1000 1100 1200 1300 1400 1500 1600 1700 7/1/2003 -1:511 PM MPL-OIA requested permit changes 303-118 and 203-064 Subject: MPL-OIA requested pent, chauges 303-118 aud 203-064 ( Date: Thu, 8 May 2003 12:07:53 -0500 From: "Johnson, Mark 0" <JohnsoMO@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> cc: "Hubble, Terrie 1," <HubbleTL@BP.com> Hello Winton, 1) For MPL-01A we would like to change the Sundry approval 303-118 to abandon the existing perforations with a 711 CIBP set at 7030' md rather than pumping cement past the whipstock (original sundry application). The CIBP meets all isolation objectives for the sidetrack and the sidetrack targets the same Kuparuk reservoir. In addition, liner lap cement from the CTD liner job will provide additional isolation. Please see attached modified well schematic. 2) For both the MPL-01A Sundry approval 303-118 and permit to drill approval 203-064 we would like to change the BOP configuration to the 2 attached diagrams. The main change is that practically speaking it· will be better to completely swap out from the 13 5/8" workover stack to the 7 1/16" drilling stack during well operations. This is a change from running a combination 13/7 stack in the sundry and permit to drill. As always, two levels of protection from the reservoir will exist whenever BOP swaps are made. Please let me know if you have any questions or need hard copies of any/all of these attachments. Thx much, MOJ «MP L-01A proposed with CIBP.ZIP» «Nordic 2 wko13 stack - moj 5-8-03.jpg» «MPL-01 Nordic 2 - 7 drilling stack -5-8-03 moj.jpg» \" , ".,' N. ,......... ....... ..'m v v '" 'IV 'IV \.\ ...... . 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','.' ',.., ,', . .'. .,',",' " , , " :.,'" ,'," '.' ",,,' " "," '.', ." c"· .",',' , ",',' ,. " .': '''''''_,'..' d,'" ,', ,'. ..... " ,: ,:. i,', ". ,-.\. .' I O ===:J:::Þ=a 311 slip ram ·11116" . . O.BOP ~ 2 3/8" x 3 1/2" V8R pipe ram I (?9 11".'bblag .ead 7· ....Iope alag m:as~ rU31Je ~1Ioa aþ I \. I ®=0: -~ - -\('>4J. ll.'~," ~ CS-.~.l Tr (,4\, 1: [E ~ r m ~ m@ f1 ~ ¡~) U Uli ! ~ [J Ik'~ Ik @ ~ ~ A / FRANK H. MURKOW5KI, GOVERNOR AT,ASIiA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit :MPL-OIA BP Exploration (Alaska), Inc. Permit No: 203-064 Surface Location: 1970' SNL, 158' EWL, Sec. 08, TI3N, RI0E, UM Bottomhole Location: 3002' SNL, 1477' EWL, Sec.08, TI3N, RI0E, UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required. test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, M~ ' Randy Ruedrich ~ Commissioner BY ORDER OF THE COMMISSION DATED thisll day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section 1 a. Type of work 0 Drill III Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 544759, Y = 6031499 1970' SNL, 158' EWL, SEC. 08, T13N, R10E, UM At top of productive interval x = 544705, Y = 6031217 2251' SNL, 102' EWL, SEC. 08, T13N, R10E, UM At total depth x = 546087, Y = 6030475 3002' SNL, 1477' EWL, SEC. 08, T13N, R10E, UM (' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMI~_jON PERMIT TO DRILL 20 MC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool KBE = 56' Milne Point Unit I Kuparuk 6. Property Designation River Sands ADL 025509 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-01A 9. Approximate spud date 05/04/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8935' MD I 7045' TVDss o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 100 Maximum surface 3150 psig, At total depth (ND) 7000' I 3850 psig Setting Depth Top Bottom Quantity of Cement Lenath MD TVD MD TVD (include staae data) 2107' 6828' 6750' 8935' 7045' 137 sx Class 'G' &r llP 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL 025515,2278' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 6978' MD Maximum Hole Angle 18. Casing ~rogram S 'f'cat'ons Size pecl I I Hole Casing Weiaht Grade CouDlina 3-3/4" x 3-3/16" x 6.2# I L-80 ST-L 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9500 feet 9421 feet 7375 feet 7341 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 130' 2483' 13-3/8" 9-518" To Su rface 1000 sx CS III, 750 sx CS II 130' 2483' 130' 2483' 7523' 7" 750 sx Class 'G', 600 sx Class 'G' Downsqueezëd:~ 1 00 sx CS I 7523' 7486' RECE\VED APR 14 2003 Alaska on &. Gas Coni. CommiøiOn AnmOt1P· Perforation depth: measured 7068' - 7128', 7160' - 7180', 7186' - 7214' true vertical 7040' - 7098', 7130' - 7149', 7155' - 7183' 20. Attachments III Filing Fee 0 Property Plat III BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report III 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that is t u an,dcorrect to the best of my knowledge Signed Mark ~~ Title CT Drilling Engineer ':,"I':!I~I"I'" ,I·, .I~;II'~, Permit Numbe~ / J / API umber 20 ::)-6b'7 50- 029-21068-01 Conditions of Approval: Samples Required 0 Yes ~ No Hydrogen Sulfide Measures 18:1 Yes 0 No Required Working PressUre for BOPE 0 2K Other::SSOa \,>~', ~C)y ~,'S~ Approved By ~ ¿;t5!~~~~::.:-. Form 10-401 Rev. 12-01-85./ ðPPP"1 ~1"e See cover letter t/ l/? ~ 0 l for other requirements Mud Log Require 0 Yes Ii':J No Directional Survey Required IE Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU D3K by order of co~commission . Un"D.11I\L Date 1/17. J;n "~t~n Uli;~ ~i ~: Milne Pòint MPL-01A Sidetrack - Coiled T~tJ.ng Drilling Summary of Operations: The Nordic 2 coiled tubing drilling rig will sidetrack Milne Point MPL-OIA using kill weight drilling mud and/or the dynamically overbalanced coiled tubing drilling (DOCTD) technique (see description below). Flexibility between the two drilling techniques is planned to achieve resistivity L WD objectives (low salinity mud required) and for mud cost optimization. This horizontal sidetrack will target Milne Kuparuk A sand reserves. MPL-OIA will be a producing well. The Nordic 2 rig will pull ESP, P&A well, sidetrack, run and cement liner, perforate, and recomplete with a new ESP. Note that Nordic 2 will be rigging up a workover BOP stack and then a drilling BOP stack (pictures attached) . MPL-Ol Workover and Sidetrack with Nordic 2 ri~ <t 1. Pre-rig - test 7" casing packoff, confirm injection through ESP, set BPV 2. MIRV Nordic 2. Pull BPV, kill well, set TWC. ND tree. NV II" BOPs and test. Pull TWC. 3. Pull 2 7/8" ESP completion. 4. Set 7" storm packer ~ 25' below wellhead. 5. ND 11" annular preventor. NV 7" CTD BOP stack on top of remaining 11" BUPs. Test 7" BOPs against storm packer. Pull storm packer. 6. With 2 3/8"CT - run 6.059" drift and tag TD. 7. With 2 3/8"CT - set 4 YZ" x 7" whipstock at 6978' md. 8. With 2 3/8"CT - P&A Milne Kuparuk perforations by pumping 25 Bbls of 15.8 ppg Class G cement with aggregate. Cleanout and target top of cement at top of whipstock at 6978 'md. 9. WOC. Pressure test wellbore to 1000 psi. P&A complete. If the cement were to fail the pressure test, a second squeeze is not planned since this portion of the wellbore will be isolated by cement during the primary cement job of the new sidetrack liner. Form 10-403 has already been submitted for the P&A portion. 10. Mill 3.8" window off of whipstock. 11. Drill CT sidetrack with 3.75" x 4 118" bicenter bit to TD of8935' md using kill weight drilling mud and/or the dynamically overbalanced coiled tubing drilling (DOCTD) technique. 12. Complete with solid 3 3/16" x 2 7/8" cemented liner. 13. Perforate up to 1000'. 14. Set storm packer. ND 7" BOPs. NU II" annular preventor on remaining 11" BOP stack. Test annular preventor. Pull storm packer. 15. Run 2 7/8" ESP completion and land hanger. Set TWC. 16. ND 11" BOPs, NV THA and tree. Test. Pull TWC. 17. Freeze protect well. Set BPV. RDMO Nordic 2. ~~~ " c:t<<" Mud Program: · Steps 1-10: 10.9 ppg KCL/NaCl/NaBr biozan brine · Steps 11-17: 10.9 ppg PotassiUln Formate based Flo-Pro and/or 8.5 ppg potassium fonnate based Flo-Pro with DOCTD technique. 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. Casing Program: Base case is 3 3/16" x 2 7/8" solid liner from 6828' to TD at 8935' cemented in place with 28 Bbls of 15.8 ppg class G liner cement. Option case is slotted liner completion if no waterflood breakthrough is indicated in L WD resistivity logging. Mark O. Johnson 564-5666 office, 240-8034 cell 1/3 ( . Milne Point MPL-01 A Sidetrack - Coiled T~tJ.ng Drilling Well Control: · Three BOP diagrams are attached. Diagrams are provided for the 11" workover BOP, 11" x 7" work over/sidetrack BOP, and the 11" x 7" work over/sidetrack/pressure deployment (w/s/pd) BOP stacks. Whenever stack changes occur during the MPL-O IA operation, there will be two levels of protection from reservoir pressure and all new BOP equipment and flanges will be pressure tested to pressures listed below. When the II"x 7" w/s/pd stack is in service, the 11" blinds (redundant to 7" blinds) will not be hooked up to an accumulator station (8 stations, 9 rams/HCR). As with all other BOP equipment, the 11" blinds will be function and pressure tested during periodic BOP testing requirements. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer(s) will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for MPL-O IA. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · L WD and LAD resistivity will be run in openhole. Hazards · Sidetrack may encounter minor losses through existing fracture stituulation in parent wellbore, and when crossing fault expected at --8465' md along the directional plan. However, lost circulation risk is low based on historical information. LCM materials will be on location as a contingency. · Reservoir pressure is 10.6 ppg EMW. · H2S at MP L pad is low. MPL-Ol had an H2S level of2 ppm on 3/01101. Highest producing IDS level is from MPL-03 at 18 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure · Res. pressure was measured in January 2003 at 3850 psi @ 7000'ss (10.6 ppg). Max. surface pressure with gas (0.1 psi/ft) to surface is 3150 psi. Dvnamically Overbalance Drillinr As done in the past at KRU by CTD, dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high reservoir pressure. Plans are to use 8.5 ppg drilling fluid in combination with annular friction losses and applied surface pressure to always maintain overbalanced drilling conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BRA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe VBRs and 3" slip rams (see attached w/s/pd BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. At least two times hole volume of kill weight fluid will be on location as a contingency. Once drilling is complete, the production liner will be deployed into the wellbore after killing the well with kill weight fluid. Measured reservoir pressure: 3850 psi at 7000' ss, 10.6 ppg EMW. Expected annular friction losses while circulating (ECD): 250 psi Planned mud density: 8.5 ppg equates to 3094 psi hydrostatic bottom hole pressure. Mark O. Johnson 564-5666 office, 240-8034 cell 2/3 ( ~ Milne Point MPL-01A Sidetrack - Coiled TLIJlng Drilling While circulating 8.5 ppg fluid and holding 650 psi on the drilling choke, the bottom hole circulating pressure is estimated to be 4000 psi, ~ 150 psi over-balanced to the reservoir. When circulation is stopped, a minimum of 900 psi surface pressure will be applied to over-balance the reservoir by -150 psi. Operating parameters will be adjusted based on real-time bottom hole pressure measurements while drilling. Flexibility between using the DOCTD method (8.5 ppg mud + surface pressure) and drilling with kill weight drilling mud (11.9 ppg) is being utilized to obtain the best quality L WD resistivity data (best logged in a low CI- environment) and to optimize fluid costs. This flexibility in drilling technique is one of the main advantages of coiled tubing drilling. Mark O. Johnson 564-5666 office, 240-8034 cell 3/3 d d :z :z æ ~ ~ ¡¡ ..; w CJ o ,:) at I § ~ ...J > â. a. <t ,..: a. w o .... z cr o 0 w w c w ""') w ~ m (J) 0 ,:) <t Z UJ ø w .8- .'. ,\".",. ~~~ ~. 1- -..-. .......~ ~,,~ - ·'I~"\· ...". i! § ø z - t:C III 11.I Z - " Z III MOT ¥/Í¡/o3 , " \" . ". ,"",A-" ( \ ~-- "- '. '8"2.8 / < 0, 0.<; !i/;/J 773.5 -762c'~ /3IS' (!:!.ZS:- U!$J~ /(,2)< /. 'i =::: '¡s'-7 10 "lti - ð,OC) ) 7{¡,20 - 6'78'" - 6'(2- ( 'f,I"Z.S ~ - J '/1 ::. 't 3 x I. ¥:o 6.0 I ~'?- , O.O~7 , l4(J 6178 -b~Zß ::: 'to " L 'I / t I ~'i _ .;¡!} ::::. IOt.~ / ¿ .'1'1 -¿. o . 2- ~~ .so x - 1(.)'-1 :::: Q vt4 t¡:.f 2tO 28'0 \, "'-"~'\ 2~? 3 ,:J~ -~~ Ô' § z (') gJ ::.c: « I ~ o I d z .... w w :r UJ I1f L-Of A ~ ~~4 Ut~ (- MPU L - 01 Tree: 2 9/16" 5M Wellhead: 135/8" x 11" 5M CIW 'DGB' tbg spool wI 11" x 27/8" CIW Tubing Hanger, 2 7/8" EUE 8 rd threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 72 ppf, L-80 115' Btrc. i KOP @ 6000' Max. hole angle = 11 to 15 deg. f/ 6300' to TD' Hole angle thru' perfs = 12 deg. max. DLS = 5 deQ./1 00' @ 8066' 95/8",47 ppf, L-80 Btrc. 2483' Ij 7" 29 ppf, L-80, Btrc. production casing (drift ID = 6.059", cap. = 0.0371 bpf) 27/8· 6.5 ppf, L-80, 8 rd EUE tbg.. (drift ID = 2.347", cap. = 0.00592 bpf) Stimulation Summary 10/30/90 -194.5 M Ibs. 16/20 Carbolite Perforation Summary Ref log: DIL / SFL 04/08/84 Size SPF Interval (TVD) 5" 12 7068' - 7128' (7040'-7098') 5" 12 7160' - 7180' (7129'-7149') 5" 12 7186' - 7214' (7155'-7182') I Mid-perf = 7111 .. Fish - Geo Vann 5" hollow carrier gun DATE REV. BY COMMENTS 04/28/84 JBF 05/08/96 JBF ~ ;~-@ t~~t~t ;:::::~:::~:~:~ ) miP ~..:.:.:o.:'.':- . ...... 1~ frmr :; .:::::::::::::: :~ ,~~~:~~~:i: :: I~~::~::::::: II ;1~I~P :~ , ¡:m1 )1d II ~ Fish .. ~ Drilled and Completed by Nabors 27E Recompleted by Nabors 4 ES r f Orig. KB Elev. = 56.0' (N 27E) Pad GL Elev. = 17' 27/8" x 1" side pocket GLM t Existinq C Halliburton 7" Divert valve at 4348' md I 126' Centrilift GC-1200 ESP, series 513, GP-B, 146Stg. 7" short joint from 6870' to 6850' md 6883'~d Centrilift GS B- T series 513 seal section Centrilift KM E1 562 series, 115 hp motor, 2030 v. /33 amps. Centrilift PH D ] 7" Halliburton Model "N" bridge plug (milled out) 5/6/96 ... 7" float shoe 7" float collar (PBTD) Fill cleaned out to 7375' md 6911' 6928' 6941' I 6951' 7357' tvd 7390' 7436' 7525' MILNE POINT UNIT WELL L-1 API NO: 50-029-21068 BP EXPLORATION (AK) . : 29/16" 5M 11" 5M CIW Tree. . 135/8"x " Wellhead. 11" x 2 7/8 olwl 8 'OGB' tbg spo 27/8" EUE b· Hanger, 2 5" CIW Tu mg b ttom and . and 0 rd threads top . 'H' BPV profile I 115' CIW 80 13 3/8" 72 ppf, l- Btrc. KOP @ 6000' t 15 deg. fl Ie - 11 0 Max. hole ang - 6300' to TO' _ 12 deg. thru' perfs - 6' Hole angle 1100. @! 806 max. OlS = 5 de:!. (' i I l 80 Btrc. 9 5/8", 47 ppf, - I~ 2483' duction casing O Btrc pro f ) " 29 ppf, l-8, . = 0.0371 bp 7 _ 6 059", cap. ( drift 10 - . 8 rd EU E tbg.. 7/8" 6.5 ppf, l-80, = 0.00592 bpf) 2 _ 2 347", cap. ( drift 10 -. Whipstock at 69!8' md in D silt . . Summary Stimulation M Ibs. 16/20 1 0/30/~0 -194.5 Carbollte. Summary Perforation SFL 04/08/84 Reflog: Dill Size SPF Interval 7068'-7128' 7160'-7180' 7186'·7214' (TVD) (7040'-7098') (7129'-7149') (7155'-7182') 5" 5" 5" Mid-perf = 7111 12 12 12 5" hollow carrier ,. Fish - Geo Vann gun MPU L - 01A I · ~f{tt? ......,.-{? .. '?'Wr :::~::::::I: II ~~¡*~iJ9 :~. '·W~· ¡~~~ ~\ I Fish ,. ~ JBF JBF COMMENTS d by Nabors 27E d Complete Drilled an 4 ES d by Nabors Recomplete TD sidetrack Ver. 2 Proposesl C DATE REV. BY 04 I 28 I 84 05 / 08 / 96 ~ MQJ. .1 \ , O' (N 27E) . B Elev. = ~6. Ong.K _ 17' Pad G l Elev. - . ~ t I 126' S'depocke 2 7/8" x 1" GlM ~ e at 4348' 7" Dive rt va Iv Halliburton md 1200 ESP, Centrilift G~P_B, 146Stg. series 513, . B-T series Centrihft GS 513 seal section E 1 562 series, Centrilift KM I 33 2030 v. 115 hp motor, amps. I I I Centrilift PH D -6775' " ' d (150' lap, 4Bbl) d TOC at 6828 m TOl an " b'-center openhole 41/8" x 33/4 ,,'cemented liner 3/16" x 2 7/8 3 8935' md 0000 h 0000 0000 lSl sub at 7620' md Model"N" 7" Halliburto~illed out) 5/6/96 bridge plug ( 7357' tvd .... 7390' 7436' 7525' 7" float shoe 7" float collar (PBTO) ut to 7375' md Fill cleaned 0 NE POINT UNIT MIL W!=~~_~i9_21 068 API NO. EXPLORATION (AK) BP ': ,: I , ,.' I . . --' . ë67°O'::1 ' :: I ~ 6750'{~ :: an :.:: n: I ¡::.J :in,nnI ["~I . .100 -50 0 50 100 150 200 250 300 350 400 450 500 550 6ÓO 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1100 ~ - - - - ,.,,,,. ... . . 1750 800 o-:'j : ''son . . -, . . -~ . - - -- :¡umuuu. .~~u~; m¡ :~,nn,n, ~F\.{)i HydrBufI':frt( /: S :::::J":'IMPL~1(MPL~I):1 .1 J /I\'K: I:J . .t·~\·'..~.HM~^,:! i -aoo¡muum:i . uu<mu Œfœ'< __..,m u< -~" __---; · _900--:..n·IMPL~IAPoIyg,"']lf: ~. ":.. .;.r'-"':"~-~". jMPl-01AT241: . f i -1000--:l·' .'.',j". '-Ln' nnt.t I~ /~ -~'"'V~~: 1 ~ :'~J_""._'_'~~~ ::I .... nn,'" n·.._~X I MÞL.. "- 12 .1 -~. ~ Pt Þ -0 I : ·::!rlm~·"£I .............. . --- .1 'M~:,.~"j ~~M'" :::'umuT u;um u..uuu " . .'. . " . .1600': L-:'··.-··>t;":"-~":'· : : ':"'f":' ::: . ·:···:··t;":'·:"':·'r-:"'-'· "";":" ,;":- :"';"j' , :. ;"';":"f":"r-:";" -7QO -600 -500 -400 -300 -200 -100 0 100 200 300 400 500 600 West(-)/East(+) 6550-':j 6600':j 6650',}" AHNOT~. 'ntII III) ..........1." 111"" .....OD ~ ans.11 ..7LU KOP .HIn .....OD , 7837.U 71aLU . 711ft.OD 711 L 11 ! 7U"-IQ 7....' . 7837.33 7nS.n 7 7~ 7.n.n . 7.....n "71.73 . 7HLD _.73 1D 7OSL17 .UL73 11 7M!A1 '.:s.s.DD TO ..... æ:~~~~tn Jo.P...()1"125 loP .-01.\12" '"P....(t1AU1 lAAC£TOETAILS 1VO ~ *tL.W SlI~ ggs ~~ ~-~ ~.{IOQØ} 1030_00 -9fjC 55 J8!J22 Port 1tI4ðOO -1035 18 1:]2'1 M Potll 101000 -1031 93 18280 Pon. roeooo -11995 126M Port .. .;.":".":-.;.-~. '-~" :." -:-..:..,~ -,' :.: 1000 1 1C)0 12'00 300 1400 500 600 700 800 900 -" O:~ D.DI D." D.DD REFERENCE INFORMATION Co-ordinate ~IE¡ Reference: Wet Centre: MPL"{)1. True North v~:oo (V~ ~:=~ ~~~ ~g~~g~~el Measured Dl!1h Reference: 1: 01 3/2011984 00:00 56.00 Calcutatioo Method: Minimum Curvature st!CTtOtI NT".'" -.c .0 IfMt leal TW .... .......... 1 .no.oo '~1I .,-.00 ..,~ .zsz..u ..D.U 0.00 2 .17LOQ '2.00 211.12 .ns.., -aLa? ..ca..7 CU, :a &n-LDO '4'" 211'.'" n,l5.23 .27G.U -4La8 -.oa 4 11....u...øa ,..." faT.-' -n1.A ·Ra 28.00 Ii 78'"'' to." U.... rHD.aD -nt.lf n.04 '8.1. . 7B&LU 110..00 1J:L01 1074.2D .an." 'U.37 1..oa 7 ''''&1 n.n MA, 7U7..u -"7." JU.1. 12.00 . nn..u n.DD n.4, 1'UO.24 .9OQ.B'I 404.01 '..00 !~ =~ ::* '~a:.:: æ :iæ ,m::! ~i:: 12 ...... U.U ,".... fD48.41 .,ou.A, ,UZ.z1 11:..00 n_ 0.00 ,_ ::00: 17-0.0 0.00 ....00 ~= ::= -- - 07.... ..... 03... ..... il T..... 1oo--} : ')~#=:5 ·--:···r·--··:·:····:·--·c... ~~ v.._ .... t13-DD· BP Amoco WBLPATH DeTAIL. ~ .......,A __, p- ¥hIIpIIt'" - T_... liD. .-.aD RItt _,OIl""'" 11 312111IM_ = =I~ 5I.oDft C· (""::;:~ .:~ tj~:) ,...-.-..~.........r.-..-.·· INTEQ Rill ··"¿IS : 1'1 " ~<.;:.~ LEGEND MPL~1 (MPL~I) ---. PIant3 MPL~1A PI8n 113 T i\ M . ¡.' , I cf) , .' Azimuths to True North Magnetic North: 25.50° Magnetic Field Strength: 57507nT Dip Angle: 80.84· Date: 3/31/2003 Model: BGGM2oo2 Contact Information: Direct: (907) 267~613 E-mail: brij.potnis@inteq.com Hughes INTEQ: (907) 267~600 Plan: Plan #3 (MPL..{)lIPltn#3 MPL..{)1A) Created By: Brij Potris Date: 313112003 Baker ,~ O:(..J~ tJp ..... ( BP ( Baker Hughes INTEQ Planning Report Company: BP Amoco Field: Milne Point Site: M Pt L Pad Well: MPL-01 Wellpath: Plan#3 MPL-01A Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M Pt L Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6029799.28 ft 544529.55 ft lB.. BAKa. HUGIll. .,...................,... l~'lI!>Q Date: 3/31/2003 Time: 15:26:50 Page: Co-ordinate(NE) Reference: Well: MPL-01, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E,113.00Azi) Survey Calculation Method: Minimum Curvature Db: Ora de Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Latitude: Longitude: North Reference: Grid Convergence: 70 29 32.230 N 149 38 9.412 W True 0.34 deg Well: MPl-01 Slot Name: MPl-01 Well Position: +N/-S 1698.58 ft Northing: 6031499.10 ft Latitude: +E/-W 239.73 ft Easting: 544759.08 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan#3 MPL-01A 500292106801 Current Datum: 1 : 01 3/20/1984 00:00 Magnetic Data: 3/31/2003 Field Strength: 57507 nT Vertical Section: Depth From (TVD) ft 0.00 Targets DeScriptið.i Qip. .', pir. MPL-01 A Polygon2.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MPL-01 Hydraulic Fracture -Rectangle (4oox1) MPL-01A T2.3 MPL-01A T2.5 MPL-01A T2.4 MPL-01A T3.1 7030.00 7045.00 7070.00 7080.00 Annotation MD ft 6900.00 6978.00 6998.00 7188.32 7619.16 7685.83 TVD ft 6819.83 6895.81 6915.23 7037.97 7080.00 7074.20 TIP KOP 3 4 5 6 Height 56.00 ft +N/-S ft 0.00 +N/-S ft -855.86 -855.86 -1191.89 -1191.85 -1210.85 -862.81 -802.27 -541.80 -190.80 -301.78 -954.55 -1035.18 -1031.93 -719.95 01 70 29 48.935 N 149 38 2.355 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 MPL-01 6900.00 ft Mean Sea level 25.50 deg 80.84 deg Direction deg 113.00 +E/-W ft -388.28 -388.28 107.75 765.83 1263.77 1429.89 844.19 271.69 -219.26 -69.48 Map Map Northing Easting ft ft 6030641.00 544376.00 6030641.00 544376.00 6030308.00 544874.00 6030312.00 545532.00 6030296.00 546030.00 6030645.00 546194.00 6030702.00 545608.00 6030959.00 545034.00 6031307.00 544541.00 6031196.94 544691.43 <- Latitude -> Deg Min See 70 29 40.518 N 70 29 40.518 N 70 29 37.213 N 70 29 37.213 N 70 29 37.026 N 70 29 40.449 N 70 29 41.045 N 70 29 43.607 N 70 29 47.059 N 70 29 45.967 N 389.22 1321.84 782.80 126.60 6030547.00 545154.00 70 29 39.548 N 6030472.00 546087.00 6030472.00 545548.00 6030780.00 544890.00 70 29 38.754 N 70 29 38.786 N 70 29 41.855 N ~t¡7ß -? ~'i 3 ~ ~ ('is 7/ <..-- Løngitude --> Deg Min See 149 38 13.783 W 149 38 13.783 W 149 37 59.184 W 149 37 39.816 W 149 3725.162 W 149 37 20.271 W 149 37 37.509 W 149 37 54.358 W 149 38 8.809 W 149 38 4.400 W 149 37 50.900 W 149 37 23.452 W 149 37 39.316 W 149 37 58.629 W Ot ( BP ( If&.. BAKa. t.·,);;: )p MUGHfS Baker Hughes INTEQ Planning Report "," '," . '," - . .- .. .~ ',." . . . . . . ¡.~··r f.Q Company: BP Amoco Date: 3131/2003 Time: 15:26:50 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPl-01, True North Site: M Pt l Pad Vertical (TVD) Reference: System: Mean Sea level Well: MPL-01 Section (VS) Reference: Well (0.OON,O.00E,113.00Azi) Wellpath: Plan#3 MPL-01A Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 7895.83 7037.33 7 7978.23 7030.24 8 8178.73 7049.71 9 8438.73 7068.39 10 8608.73 7059.87 11 8935.00 7045.41 TD Plan: Plan #3 Date Composed: 3/31/2003 New landing target Version: 4 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD loci Aziro TVD + N/-S +EI-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/10OO deg/100ft deg 6900.00 13.12 215.00 6819.83 -252.32 -33.45 0.00 0.00 0.00 0.00 6978.00 13.00 215.92 6895.81 -266.67 -43.67 0.31 -0.15 1.18 120.44 6998.00 14.65 212.91 6915.23 -270.62 -46.36 9.00 8.25 -15.04 -25.00 7188.32 80.00 189.72 7037.97 -397.86 -79.02 35.00 34.34 -12.19 -25.00 7619.16 90.00 125.00 7080.00 -771.67 79.04 15.12 2.32 -15.02 274.69 7685.83 100.00 125.00 7074.20 -809.71 133.37 15.00 15.00 0.00 0.00 7895.83 99.89 99.41 7037.33 -887.19 323.19 12.00 -0.05 -12. 19 -88.00 7978.23 90.00 99.41 7030.24 -900.59 404.08 12.00 -12.00 0.00 180.00 8178.73 78.97 120.92 7049.71 -968.55 590.13 12.00 -5.50 10.73 118.00 8438.73 92.93 92.88 7068.39 -1042.49 835.35 12.00 5.37 -10.79 -65.00 8608.73 92.75 72.46 7059.87 -1020.94 1 002.86 12.00 -0.11 -12.01 -90.00 8935.00 92.13 111.64 7045.41 -1032.41 1322.28 12.00 -0.19 12.01 90.00 Survey MD Incl Azim SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft degf100ft deg 6900.00 13.12 215.00 6819.83 -252.32 -33.45 6031246.61 544727.16 67.80 0.00 0.00 TIP 6925.00 13.08 215.29 6844.18 -256.95 -36.71 6031241.96 544 723.92 66.61 0.31 120.44 MWD 6950.00 13.04 215.59 6868.53 -261.55 -39.98 6031237.34 544720.68 65.39 0.31 120.16 MWD 4=:.Q75J1Q 13.00 215.88 4=:.9~UQ -266.13 -43.27 6031232.74 544717.41 64.15 0.31 119.87 MWD C 6978.00) 13.00 215.92 ~ -266.67 -43.67 6031232.19 544717.02 64.00 0.31 119.58 KOP 6998.00 14.65 212.91 6915.23 -270.62 -46.36 6031228.23 544714.35 63.06 9.00 335.00 3 C 7000.00 15.29 211.79 6917.16 -271.06 -46.64 6031227.80 544714.08 62.98 35.00 335.00 MWD 7025.00 23.55 202.91 6940.72 -278.47 -50.33 6031220.36 544710.43 62.48 35.00 336.08 MWD 7050.00 32.06 198.51 6962.82 -289.38 -54.39 6031209.42 544 706.44 63.01 35.00 344.48 MWD 7075.00 40.67 195.82 6982.93 -303.54 -58.72 6031195.24 544702.19 64.55 35.00 348.38 MWD 7100.00 49.31 193.93 7000.60 -320.61 -63.23 6031178.15 544697.78 67.07 35.00 350.56 MWD 7125.00 57.99 192.48 7015.40 -340.20 -67.82 6031158.53 544693.32 70.50 35.00 351.90 MWD 7150.00 66.67 191.29 7027.00 -361.84 -72.36 6031136.86 544688.90 74.77 35.00 352.76 MWD 7158.03 69.46 190.94 7030.00 -369.15 -73.80 6031129.55 544687.51 76.31 35.00 353.32 MPl-01A 7175.00 75.37 190.24 7035.13 -385.05 -76.77 6031113.64 544684.64 79.79 35.00 353.45 MWD ~ 80.00 189.72 7037.97 -397.86 -79.02 6031100.81 544682.46 82.72 35.00 353.66 4 7200. 80.15 187.93 7039.98 -409.23 -80.78 6031089.43 544680.77 85.54 15.12 274.69 MWD 7225.00 80.50 184.11 7044.18 -433.73 -83.37 6031064.92 544678.33 92.73 15.12 275.00 MWD 7229.97 80.57 183.35 7045.00 -438.62 -83.69 6031060.02 544678.04 94.35 15.12 275.64 MPl-01A 7250.00 80.89 180.30 7048.23 -458.38 -84.32 6031040.26 544677.53 101.49 15.12 275.76 MWD 7275.00 81.32 176.50 7052.09 -483.07 -83.63 6031015.59 544678.37 111.77 15.12 276.25 MWD 7300.00 81.79 172.71 7055.76 -507.68 -81.31 6030990.99 544680.84 123.52 15.12 276.84 MWD 7325.00 82.29 168.93 7059.23 -532.12 - n: .36 6030966.58 544684.94 136.71 15.12 277.40 MWD 7350.00 82.83 165.16 7062.46 -556.27 -71.80 6030942.46 544690.64 151.26 15.12 277.92 MWD 7375.00 83.40 161.40 7065.46 -580.04 -64.66 6030918.74 544697.92 167.12 15.12 278.41 MWD 7400.00 84.00 157.64 7068.21 -603.31 -55.97 6030895.52 544706.75 184.22 15.12 278.86 MWD 7425.00 84.62 153.89 7070.69 -625.99 -45.76 6030872.91 544717.10 202.47 15.12 279.28 MWD l~t.· . (' BP ( lBit. ..:. '1 ~ OAK.. -J t.r HUGIIIS ......:.-.:. Baker Hughes INTEQ Planning Report ...............,......,..... ~.~n: I1.Q Company: BPAmoco Date: 3/31/2003 Time: 15:26:50 Page: 3 Field: Milne Point Co-ördinate(NE) Reference: Well: MPL-01, True North Site: M Pt L Pad Vertical (TVD) Reference: System: Mean Sea Level Well: MPL-01 Section (VS) Reference: Well (0.00N,O.00E,113.00Azi) Wellpatb: Plan#3 MPL-01 A Survey Calculation Method: Minimum Curvature Db: Orade .._-- Survey MD loci Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 7450.00 85.26 150.16 7072.89 -647.98 -34.08 6030850.99 544728.91 221.82 15.12 279.65 MWD 7475.00 85.93 146.43 7074.82 -669.18 -20.98 6030829.87 544742.13 242.16 15.12 279.98 MWD 7500.00 86.61 142.70 7076.44 -689.50 -6.52 6030809.64 544 756.72 263.41 15.12 280.26 MWD 7525.00 87.30 138.98 7077.77 -708.86 9.25 6030790.38 544 772.59 285.48 15.12 280.51 MWD 7550.00 88.01 135.27 7078.80 -727.16 26.24 6030772.18 544789.69 308.28 15.12 280.70 MWD 7575.00 88.73 131.55 7079.51 -744.33 44.39 6030755.13 544807.95 331.69 15.12 280.86 MWD 7600.00 89.45 127.84 7fl7R91 -760.29 63.62 6030739.28 544827.27 355.63 15.12 280.96 MWD 7619.16 90.00 125.00 ( 7080.00 => -771.67 79.04 6030728.00 544842.75 374.27 15.12 281.02 5 7625.00 90.88 125.00 7079..96 -775.02 83.82 6030724.68 544847.56 379.98 15.00 0.00 MWD 7650.00 94.63 125.00 7078.76 -789.34 104.27 6030710.48 544868.09 404.40 15.00 0.00 MWD 7675.00 98.38 125.00 7075.93 -803.58 124.61 6030696.36 544888.52 428.69 15.00 0.00 MWD 7685.83 100.00 125.00 7074.20 -809.71 133.37 6030690.28 544897.31 439.15 15.00 0.00 6 7700.00 100.05 123.27 7071.73 -817.54 144.92 6030682.52 544908.91 452.84 12.00 272.00 MWD 7725.00 100.13 120.23 7067.35 -830.49 165.85 6030669.70 544929.91 477.16 12.00 271.70 MWD 7750.00 100.18 117.18 7062.94 -842.31 187.43 6030658.01 544951.56 501.65 12.00 271.17 MWD 7775.00 100.20 114.13 7058.52 -852.96 209.61 6030647.50 544973.80 526.22 12.00 270.63 MWD 7800.00 100.19 111.08 7054.09 -862.42 232.32 6030638.18 544996.56 550.82 12.00 270.09 MWD 7825.00 100.15 108.04 7049.68 -870.66 255.50 6030630.08 545019.79 575.38 12.00 269.55 MWD 7850.00 100.08 104.99 7045.29 -877.65 279.09 6030623.23 545043.43 599.83 12.00 269.01 MWD 7875.00 99.99 101.95 7040.93 -883.39 303.03 6030617.64 545067.40 624.11 12.00 268.48 MWD 7895.83 99.89 99.41 7037.33 -887.19 323.19 6030613.96 545087.58 644.15 12.00 267.95 7 7900.00 99.39 99.41 7036.64 -887.86 327.25 6030613.31 545091.64 648.15 12.00 180.00 MWD 7925.00 96.39 99.41 7033.20 -891.91 351.68 6030609.41 545116.09 672.22 12.00 180.00 MWD 7950.00 93.39 99.41 7031.07 -895.98 376.25 6030605.49 545140.68 696.42 12.00 180.00 MWD 7975.00 90.39 99.41 7030.25 -900.06 400.89 6030601.55 545165.35 720.71 12.00 180.00 MWD 7978.23 90.00 99.41 C 7030.24~ -900.59 404.08 6030601.05 545168.54 723.85 12.00 180.00 8 800U.UO 88.78 101.72 (O~U.47 -904.58 425.48 6030597.18 545189.96 745.10 12.00 118.00 MWD 8025.00 87.37 104.37 7031.31 -910.22 449.82 6030591.69 545214.33 769.71 12.00 117.98 MWD 8050.00 85.97 107.03 7032.76 -916.97 473.84 6030585.09 545238.39 794.46 12.00 117.89 MWD 8075.00 84.58 109.69 7034.82 -924.82 497.49 6030577.39 545262.08 819.29 12.00 117.73 MWD 8100.00 83.20 112.37 7037.48 -933.74 520.69 6030568.61 545285.33 844.13 12.00 117.51 MWD 8125.00 81.84 115.07 7040.74 -943.71 543.38 6030558.77 545308.08 868.92 12.00 117.23 MWD 8150.00 80.49 117 .78 7044.58 -954.70 565.50 6030547.92 545330.26 893.57 12.00 116.88 MWD 8175.00 79.16 120.51 7049.00 -966.68 586.99 6030536.07 545351.82 918.03 12.00 116.46 MWD 8178.73 78.97 120.92 7049.71 -968.55 590.13 6030534.22 545354.98 921.66 12.00 115.98 9 8200.00 80.05 118.58 7053.58 -978.93 608.29 6030523.95 545373.19 942.43 12.00 295.00 MWD 8225.00 81.35 115.84 7057.62 -990.20 630.23 6030512.80 545395.20 967.03 12.00 295.43 MWD 8250.00 82.67 113.11 7061.09 -1000.46 652.76 6030502.69 545417.79 991.78 12.00 295.87 MWD 8275.00 84.01 110.41 7063.99 -1009.66 675.82 6030493.62 545440.90 1016.60 12.00 296.25 MWD 8300.00 85.35 107.72 7066.31 -1017.79 699.34 6030485.64 545464.4 7 1041.43 12.00 296.56 MWD 8325.00 86.71 105.04 7068.04 -1024.82 723.27 6030478.75 545488.44 1066.20 12.00 296.81 MWD 8350.00 88.08 102.36 7069.18 -1030.74 747.53 60304 72.98 545512.73 1090.85 12.00 297.00 MWD 8375.00 89.45 99.69 7069.72 -1035.52 772.06 6030468.35 545537.29 1115.29 12.00 297.12 MWD ~ ~0.8"'7;> 97.02 C7069.ô~) -1039.15 796.79 6030464.87 545562.04 1139.48 12.00 297. 18 MWD 8425.00 92.18 94.35 7069.01 -1041.63 821.66 6030462.54 545586.91 1163.34 12:00 297. 17 MWD 8438.73 92.93 92.88 7068.39 -1042.49 835.35 6030461 .76 545600.61 1176.27 12.00 297. 10 10 8450.00 92.93 91.53 7067.82 -1042.92 846.59 6030461.39 545611.86 1186.80 12.00 270.00 MWD 8475.00 92.93 88.53 7066.54 -1042.94 871.56 6030461.53 545636.82 1209.78 12.00 269.93 MWD 8500.00 92.91 85.52 7065.27 -1041.64 896.49 6030462.98 545661.74 1232.22 12.00 269.78 MWD 8525.00 92.89 82.52 7064.00 -1039.04 921.32 6030465.73 545686.55 1254.06 12.00 269.62 MWD 8550.00 92.85 79.51 7062.75 -1035.14 945.98 6030469.78 545711.18 1275.24 12.00 269.47 MWD 8575.00 92.82 76.51 7061.51 -1029.95 970.40 6030475.11 545735.57 1295.69 12.00 269.32 MWD 8600.00 92.77 73.51 7060.29 -1023.50 994.52 6030481.71 545759.64 1315.37 12.00 269.17 MWD 0 ( BP ( ~i. :~r .,,<. '1'~ BAKa. ~;" , ,':' . t. r... MUGIIIS .......~ Baker Hughes INTEQ Planning Report ..... .................... ¡.~··rf.Q Company: BP Amoco Date: 3/31/2003 Time: 15:26:50 Page: 4 Field: Milne Point Co-ordinate(NE) Reference: Well: MPL-01, True North Site: M Pt L Pad Vertical (TVD) Reference: System: Mean Sea Level Well: M PL -01 Section (VS) Reference: Well (0.00N.0.00E,113.00Azi) Wellpath: Plan#3 MPL-01A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1ooft deg 8608.73 92.75 72.46 7059.87 -1020.94 1002.86 6030484.31 545767.97 1322.05 12.00 269.03 11 8625.00 92.75 74.41 7059.09 -1016.31 1018.43 6030489.04 545783.51 1334.58 12.00 90.00 MWD 8650.00 92.74 77.42 7057.90 -1010.23 1042.65 6030495.26 545807.69 1354.49 12.00 90.09 MWD 8675.00 92.72 80.42 7056.71 -1005.44 1067.15 6030500.21 545832.16 1375.17 12.00 90.24 MWD 8700.00 92.70 83.42 7055.52 -1001.93 1091.87 6030503.86 545856.86 1396.56 12.00 90.38 MWD 8725.00 92.67 86.43 7054.35 -999.72 1116.75 6030506.22 545881.72 1418.59 12.00 90.52 MWD 8750.00 92.63 89.43 7053.19 -998.82 1141'.70 6030507.27 545906.66 1441.21 12.00 90.66 MWD 8775.00 92.58 92.43 7052.06 -999.22 1166.67 6030507.02 545931.63 1464.35 12.00 90.80 MWD 8800.00 92.53 95.43 7050.94 -1000.93 1191.58 6030505.46 545956.55 1487.95 12.00 90.94 MWD 8825.00 92.4 7 98.44 7049.85 -1003.95 1216.37 6030502.59 545981.36 1511.95 12.00 91.07 MWD 8850.00 92.41 101.44 7048.78 -1008.26 1240.97 6030498.43 546005.98 1536.28 12.00 91.20 MWD 8875.00 92.33 104.44 7047.75 -1013.85 1265.31 6030492.98 546030.35 1560.87 12.00 91.33 MWD 8900.00 92.25 107.44 7046.75 -1020.71 1289.33 6030486.27 546054.41 1585.66 12.00 91.46 MWD 89'5 ~ 92.17 110.44 7045.79 -1028.82 1312.96 6030478.30 546078.08 1610.57 12.00 91.58 MWD é8935.0 ~ 92.13 111.64 (7045.41') -1032.41 1322.28 6030474.77"" 546087.42' 1620.56 12.00 91.69 TD ( r \.... 11" annular preventor ~ Choke line . ,...() HCR valve ~0=0~ ~ ~ st=0~ \ ground level MPl-01 II/III/II MOJ 4/9/03 o o 11" tubing head ( Nordic 2 workover BOP stack "' A I ..J , 1-1-. blind ram 11" BOP r-r- . ,. ···..····1 Kill line ~0=0~~~ 11" BOP ~ 2.7/8" x 5 1/2" VBR pipe ram ~ 2 3/811 pipe ram - ---,<::;T- ----,<::;T-- -~-~- , \ - ---,<::;T- - -~- ( 7 1/16" annular preventor "- c::e:t c::e:t I 071/16" OBOP I I /7111~X11" \ c:e1 o Choke line I HCR valve ---tV\- ----tV\-- -~-~- l c:e1 c:e1 o o 7/77"/////ì1 / /ii7viïíï// 2c=0~ \ 11" tubing head MOJ 4/9/03 Nordic i workoverlsidetrack BOP 7" riser to rig floor " RECEIVED APR 1 5 2003 A'aska Oil & Gas Cons. Commission Anchorage ~ Þ== Blind/shear cambi ram þ:= 2 3/811 pipe/slip combi ram 11" BOP ~ blind ram I Kill line ~0=0Ch~~ 11" BOP I ~ 2.7/8" x 5 1/2" VBR pipe ram ~ 2 3/811 pipe ram ~0=0~ \ lOOP Testing Options through 7" lOOP a) Hanger wI TWC (possible ID constraints) --tV\- b) RTTS for casing <7" ~ ~ ~ c) IBP >7" when no hanger solution ( 7" riser to rig floor ( J I Nordic 2 r , workoverlsidetrack 7 1/16" BOP with CoilTrak pressure annulaf preventor deployment capability " .J l ==C:1 071/16" Þ== Blind/sheaf combi fam ~ OBOP Þ 2 3/8" pipe/slip combi ram I r:::q ~ 071/16" () BOP I I /71/1~9X11" \ c::e:1 (), Choke line I HCR valve - --r:::J\ - r<::/T- _~--xY-- c::e:1 c::e:1 o o 7f77 / / / I2ì1 / /ii/ï/íï// _0- 2c ' - - \ 11" tubing head MOJ 4/9/03 Þ== 2 3/811 X 3 1/2" VBR pipe ram Þ 3" slip ram 1---6 blind ram 11" BOP r---r- "·'1 Kill line ~0==®Ch~~ 11" BOP ~ 2.7/8" x 5 1/2" VBR pipe ram ~ 2 3/8" pipe ram ~0=0~ , \ '\OP T,s1j19 Options through 7" "OP a) Hanger w/ TWC (possible ID constraints) --r:::J\- b) RTTS for casing <7" ~ ~ _ c) IBP >7" when no hanger solution . I p055040 DATE INVOICE I CREDIT MEMO 3/12/2003 INV# CK030603M /' DESCRIPTION GROSS PERMIT TO DRILL !y\ pLrD ¡fl , DATE CHECK NO. 3/12/2003 055040 ,.-- VENDOR DISCOUNT NET R·~t:r¡;:l\ Iì=-Di' j( '~~V"fi..-' V ~ J~pP 1LL ~'n0~ !"\. 1\ 1 I ....."':.tv ÞJ5.!i{8 Of¡ & Gas ConS. Cmnrntær.Jn AmmO'!!ge THE AlTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 .'u ANCHQ11AGI:, A~'99519-6612 _ -.-, è~ - ... .-;:-.--;-. .: - - - . - :. - -_ , ."::_:.-.- 0"-.- _.'-____ .__:-__ -_'-_.-. - -.--.._ - ____ ":_.' _ _u_ _ _ ._ _ _ . u . .." -d_ - .","._-__ _." __. . . ..' .... ..' ..' ------- - -.. - _.u.-. "._"." .".___---,._ _ _.__ "__' '._ U_-__-. .- .. ," -. _ -" ", _ __ U._ __ .___ _._ n-- .... ..... -. ,"- .--." - ", - :" ..' .... --,"' - --.-. -.- -.---.- -. _ n .. . _ _ .. nO _ _ _. _'_n .__ -_d .-..-.--. _.__. .-.-- ....__.. _'d.'" ._. .. __..... .. ___ - .__ _n._ d. _ _ -. . - --.- .-. . - - -.-. .:-:: .---.; .,-' :" .......::..-. '-:--.-;. - '",- -:.: ":-, -.,--- --, - -.---- -.. -- ,n, _,,--- _- _-.- ,,_,_. ..._-- _',-,_._ __,"-_.' - _. _n" ., _ _n' . '_- ,-- -'- ,- -.- -, '-', - ',-----', - ."-:', - _ _ _- ' _: _' ':. _:: _ ~.U '_-. "__ __ _,:'__: ÀtÃSKA QIL &G~S CONSERVATION 333 W 7TH A\l~Nt.)E . SUITE'1 OOt...:·,u..:.. ....... ANCHORAG~~AKg9501-3539 PAY: TO THE ORDER OF: NATIONAL CITY BANK Ashland, Ohio - n_,. _.' 'n_ B "p/r;.}].... ..jT.....·.·...:lflI........~. '....'.. ¡flu.r,.. ff''';'' . ...., .." : If; ", . . ,: . .. . ¡..... llW . fliP',""''''''' .....} DATE . 11105 50 ~Olll 1:0 ~ . 2038951: O. 2789 bill 56-389 412 No. P 055040 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT **~~**$1 00.00******* Nq[VALI~t2~::~~~~:~~;;;~);;·:.;~;~~~y·;:/~{~·~ , </:~:~~~ :;t·::;::=::-:s:"":~:~:~:·:~:;, i=:::Æ'¥r~~":\~::\:}¡~:::~¡:~i:{:;< H ~-~, ~"':'--,- i( ;{ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMtTTAL LETTER WELL NAME ¡?J;? L - 01 fì PTD# 7-D :3 --Obt{- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to· be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all· records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number· (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~~Ç.~J:~~~Mtr9~~~.~~I~!,: Company ll~E.XeJ",ºMILQr~L(A1A~Hti.C Well Name: MILti~~J--'.JJ~lLlS.tl._\"-=-LJ1A 'TD#: 2030640 Field & Pool .M1LNEE.O~t.J~..ueARUK.RI.~EB,..::l>25j.o_O Initial ClasslType --11E-V.L1:..01L-GeoArea.8-90 Unit JJ_32.8 On/Off Shore Qo Annular Disposal ¡dministration 1 Pßr:.miUee. ~ttaçh.ed. . . . _ . . . . . . . . . . _ . " _ _ _ _ . _ . . . . . . . . . . _ . _ _ . . . . . . . Yßs _ _ . . _ . . . . . _ .. . . . . _ . . .. . . _ . . . . . . . . . . _ . _ _ . . . . . . . . _ . . . . _ _ . . . . _ . . . . . . . . . . . . . . . . _ 2 _Le~sß nl.JmbE~.r PPPJOPJi;ate. . . . . . . . . . _ . . . . _ . _ . . . . _ . _ . . . _ . _ . . _ . _ _ _ . . . Yes. . . . . . . . . . . . . . . . _ _ _ . . . . . . . . . . . . _ _ . .. . .. . . . . . _ _ . . . _ . . _ . . . . . . _. _ _ . . _ .. _ . . 3 _U.ni.q!,l~ w~I'-n.aIJ1ß .aod IJUJ11b.ß( _ . _ . . . _ . . . _ _ _ _ . . . . . . _ _ . _ _ . _ _ _ _ _ _ _ _ _ . . . Yes. . . _ _ _ _ . . . _ . _ . . _ _ _ _ _ . . . . _ . . . _ . . . . . . . . _ _ . _ . _ . . . . _ _ . . . . _ . . _ _ _ . . . . _ _ . . _ . . _ _ _ . . 4 WeJI JQc~tßd i.n .a. d_efined 'pPol. . . . .. _ . . . _ _ _ . . . . _ _ . . _ . . . . . . . . . . _. . . . . . . Y ßS . _ . . . . . . . _ . . . . . . . . . . . . . . . . . . _ . . . . . .. . . . . . . _ . . . . . . _ _ _ . _ . _ . . . . . . _ . . . _ _ . _ . . . . . . 5 WeJIJo.cated prpper di.$tance. from drilling unitbpul1dar:y. . . . . . . . . . . . . . . . . . _ _ _ . . . Yes. . _ _ _ .. . . . . . . . . . _ . . _ _ _ . . . . . . . . . . . . . . .. .. . . .. . _ _. . _ . . . _ _ . . . . . _ _ . . _ . _ . . _ _ . . . . . . - _ 6 WeJIJo.catßd prpper di.staoce.f(o!11. Qtl)eJ wens. . . . . _ . . . . . . . . . _ _ . . . . _ . . . . . . . . Yß$ . . _ . . . . .. . . . . . . . . . . . .. . . . . . . . . . . _ . . . _ _ _ . _ . . . . . . . . _ . . . . . _ . . _ . . . . . . _ . . . _ . _ . . _ _ . 7 S!Jffiçient pçre~g.ß .ayqilable in .drilJilJg. u.nit. . . . . . . . . . _ . . . . _ . . . . . . . . . . . . . . . . Y ßs . . _ . . . . . . . . . . . . . . _ . . .. . . . . . . . . _ _ . . . _ " . . _ . . . . . . . . . . . . . . . _ _ _ . . . . . . . . . . . . . . . _ . . 8 .If .dßviQted, is. weJlboJ~ pl~tjnc!udect . . . . . _ . . _ . . . . . . . . . . . . _ . _ . . . _ . . . . . _ _ Yes . _ . . . . . . . . . . _ . . _ . . _ .. . _ . . . . . . _ . . . .'. . . . . . . . . . . _ _ . . . _. ........... _ . . . . . . . . . . . 9 .o.perptor Qnly- affected party.. . . . . . .. . . . . . . _ . . . . . . . . . . . . . . . _ _ . . . . . . . . . Yes . _ . . . . . . . . _ . . _ . . . . .. . . .. . . . _ . _ . . . . _ . . . . . . _ . . . _ . _ _ _ . . . . . . . . . . . . . . _ . . . . . . . . . .. . 10 .o.per.ator bas.apprppriate.b_ood iJl JQrce. . . . . _ . . . . _ . _ _ . . . . . . _ . _ _ . . _ . _ _ . _ . . .Yes _ _ . . . _ . _ . . _ . . _ . . . . _ . . . . . . _ _ _ _ . . . . . . . . _ . . . . . . _ . _ . . . . _ _ . . . . . . . . . . _ . . . . _ _ _ . _ . . 11 Per:.mitcpo be i$$u_ed witl)o.ut conservatiOIl Qrçl~r. _ _ _ . _ _ . _ _ _ . _ _ . _ . . _ _ . . . . . . _ . Yes. . _ _ _ . _ . . . _ . . _ . _ _ _ . . . . _ . _ . . . . _ _ . _ _ . _ _ . _ . _ . . . _ . . . _ . _ _ _ . . . . . . . . . _ . . . _ . _ . . . . _ . Apor Date 12 Per:.mitcpo be i$su.ed witl)o.ut Qdmini~tr.ativ.e.apprpvaJ . . . . . . . . _ _ . . _ . _ . _ _ _ . . _ . . . Yes _ . . . _ _ . . . . . . .. . . _ . _ . . _ . . . . . . _ . _ _ _ _ . _ . . .. . _ . . _ . . - - - . . . . . - . . - . - . - . .. . - . . - . . . ) 4/15/2003 13 Can permit be approved before 15-day wait Yes 14 WeJlJo.catßdwith.in.areaQn.d.str~taputhQri~edby.lojectioIJO(der:.~(putlO#in_cpmr:neots).(fQr. NA. _..... _... _................ _ _.. _. _ _ _ _. _....... _..... _ _... _..... _ _... _ _ _ -.... 15 All wells.witþin Jl4.llJite.are.a.of r:.eyiew ideotified (Fpr:. ~ervjce wet! only.) _ _ _ _ . . . . . . _ . . _ _ _NA . . . _ _ _ _ _ . . . . . . . . . . . _ . . _ _ . _ . . . . . _ . . . _ _ _ . . _ _ . _ _ _ _ . . . _ . . . . . . _ _ _ _ _ . _ _ _ _ - . . . . . . . 16 Pre.-proctuçed.iojector~ dl)ratio.n.ofpre-:prodl)ctipnless.thqn.~months.(For_seryjçeweIt Qn!y) _. NA........ _ _... _ _ _..... _ _ _.. _...... _........... _... _.... _ _... _.. _. _ _. _..... _.. 17 .ACMP_Fjn.ding pi CQn$i$teocy.hps b~ell js_su~d.for.tbis prpject. . _ . . . . _ _ . . _ . . . . . . . . NA. . . _ . . . _ . . _ . . . . . _ _ _ _ _ _ . . . . . . . . _ . . _ . . . _ . . . . . _ . _ . _ . . . . . . . _ . . . . . . . . .. _ _ . . . . . . _ . . 18 Gpoduçto( &tr:.ing.prQvided . . . . . . . . . _ _ . . . _ _ _ _ . . . . . . . . _ _ _ _ . _ . . . . . . _ _ . NA . . _ _ . . _ Sid~tr.ack of ~",i$ttng well.. . . . _ . . . _ . . . . . _ . . . . .. . . . _ _ _ _ . . . . . . . . . _ . . _ _ _ . _ . . . . . . . . . 19 .S!Jr:face .ca~in.g_prQtects. all_k[1own. USDWs _ . . . _ _ . _. _ _ . . . _ . _ _ _ _ . _ . .' . . . _ . . NA _ _ _ _ . . . R~dJj of.existing .w.et!.. SED . _ . . . _ _ . . _ . . . . . _ _ . _ . . _ _ _ _ _ . . _ . . . . . . . . . . . . - - . . . . . . . . 20 GMT.vpl.a.dequ.ateJo ci(c!Jl.ßte.on .cond!Jctor..& $u.rf_~g _ . _ . _ . . . . _ _ _ . . . . _ . . . _ . . . NA. _ _ _ . . . _ Sid~tr.ack Qf _e>..<isti.ng well.. . . . . . . _ . . . . . . _ . . _ . . . . _ . _ _ _ . . . _ . . . _ . . . . . . _ _ _ . . _ _ _ . _ . . 21 GMT. vPI. a.dequ.ateJo tie-ill Jo_ng $triog to .surf Ç&g. . _ . . . . _ _ . _ . _ _ . . _ _ _ . _ . . . . _ . . NA. _ . _ . . _ . $id~tr_ack of .e>..<i$ti.ng well. _ Qriginal. PJQd.ucttoo cQs.ìng .npt Gemeoted tnto _s!Jr:fqce .ca~ing, . . _ . . _ . . . . . . _ _ . _ 22 GMT.will Goyer .a!ll<l1owll.Pro.dl,Jctiv~ bOJi?Qn$ _ . . _ . . _ . . . _ _ . . _ _ _ . _ . . .. _ . . _ . . . Yß$ . . . . . _ . L,ilJer planned to. beJl"llIy .cemen.t~d.. . . _ . . . . . . . . . . . _ . . . . . _ _ _ . _ _ _ _ _ . _ . _ . . . _ _ . . . . _ _ _ . . 23 Gpsiog de.sigos. adequate. fpr_ C,.T. B .&. p.erllJafrpst. . _ _ . . _ _ . _ _ . . _ . . . _ _ . . . . . _ . . Yes. _ _ . _ . _ . _ . . . . . . . . . . . . . . _ . . _ . _ . . _ . . . . . .. . . . _ . . . _ _ _ _ _ _ . . . . _ . _ _ . . . _ _ . . _ .. . . _ . . . . 24 Adequate .tC!nJ<Qge.orre.$ery~ pit . . . . _ _ _ . _ . . . . . . . _ . . . . . _ _ . _ . . . . . . _ . _ . . .Yßs _ . . . . _ . Rig& are equjpped with. &tee.1 pits. No r~ser:.ve pit planned. _ All. wa.steJo G&t .. _ . . . _ . . . . . _ . . . _ . . . _ _ . . 25 Jf.a.re-d(ilt /J~s.a.1.0:-4.03 fOJ aba.ndonmellt been aRPJQved _ _ _ _ _ . _ _ _ . _ . _ . . . _ . . . . . .Yes _ _ _ . .. . . 40_3.303-114.reço.m.mend~d.for.a.pprpvaJ,.4l1.5l03.. .. . . . . . . . _ . . . . . . . _ . . . . . . . .. . . _ . . . _ . . . . . . 26 Adequate .w.eUbore. s.eparÇltioll.Propo~ed _ _ _ _ . . . . _ _ _ _ . . . . . _ . _ _ . . . . . _ . _ _ . _ . Y.ß$ _ _ _ _ _ . . ~Q çlQs.e .approacn js.slJesJde.ntifled.. Nearest wellbpr.e j~ tÞe origjn_at we.llbQre.. . _ _ _ . . . . . . . . . . . . _ . . _ _ 27 .If .diver:.teJ Jeq!Jire.d do.es it meet. reguJations. . . _ . _ . . _ . _ . . . . _ . . _ _ . . . . . . _ _ . . . NA. . _ . _ . . . . . _ . . . . . _ . . . . _ . . _ . . . . . . _ . _ _ _ _ _ . . . . . . . . . _ . . _ . .. _ . . . . . . . . . . . . _ . . . . _ _ _ . _ Aopr Date 28 Dril.ling fluid. program sc.hemati.c.&. eq!Jip .Iist.adequate _ . . . . . . . . _ . . . . . . . _ . . . . _ . . Yes. . _. _ _ Measured re.seryQir. pJes.$ure _1l03 .1 0.6 EMW. .F~roposal .ìs.to !Jse. KW mud .or dynamic pverbalance. _ . . . . . . _ . ) 4/16/2003 29 .BOPEs,.dpth.eY.m.eetreguJation... _..... _. _... _. _ _.. _ _.. _. _....... _. yes.... _ _ .3ditferents~tsof.B_QP.s.are.pl~nlledtp.açcom.m.odatethe.operations... _..... _ _... _... _..... _.. 30 .BOPE.pre.ss rating ~pp(op(iat~; te.st tp.(Rut p&ig in .comments). _ . . . _ . . . . _ _ _ _ _ . _ _ . . .Yes. . . _ . . _ MAS~ e~timpted at~15Q psi..PlalJ i$.tQ tesUQ 35.00 psi.. . . . _ . _ . . . _ _ . . . . _ _ . . . _ _ _ . . _ _ . . . . _ . . 31 .C.hoke.llJanifold comp.lies. w/API.RP-53. (May 84). . . . . . . _ . _ . _ . . . . . . _ . . . . _ _ . . . .Yes. _ . . . . . _ . _ _ . . . . . _ _ . _ . . . . _ . . . . . . _ . . . . . . _ . . . . . . . . . . _ . . _ . . _ . . . . . - .. _ . . . . . . . _ . . . 32 WOJk will OGC!Jr:. without .op~ration $/JU.tdoWll. . . . _ _ _ _ . . . . . . . _ . . . . . . . _ . . . . . . . Yes. _ _ . . . . . . _ . _ . . . . _ . . . _ . _ . . . _ . . . . . . . . . _ . . _ _ _ _ . _ _ _ . . . . . . _ . . . _ _ . .. _ . . . . . . _ 33 .Is. pres_eoce. oJ H2S gas. pJQb.able. . . . . . . . _ . . _ _ . . . _ _ _ . . . _ _ _ _ . _ _ . _ . . . . _ . Np _ . . _ . _ _ . Drilling .mud pod drillillg pr.açtices shpuld pr:.eclude_ H2.S. on.tbe. rig, .Rig has moni.ton~ ~ alarms, _ . . . . . . . _ _ 34 Mechantcal.cood.ìtipoptweJlswith.inAORverified.(For.seJ:Vicewellon.ly).. _........... NA.. ." _.... _... _..... _. _" _ _ _ _.... _.. _...... ----- 35 Per:.mit.cpobei$su.edwlo.h.ydrpgen.s.ul.fìdemeasur.es.. _......... _.. _. _ _...... No...... .MPL,-03,35QO~tpth.e.NW,.h.a$mea~ure_d.1.appm_H2$.. MPL-.P1 mea~ure.d.2.ppm.24.mo.nthspgQ.. _.' _... _. 36 .Dpta.pre.sented.on_potentialpverpres.sure?ones. _ _ _. _ _ _ _. _................ Yes. _ _... .Res.p.ressuremea~ure.d.1P..6.ppgEMWi(1Jan.'03.We.llwjl\.be.drilleddynam,ic.aIJY_QverÞalancßdwi.th &.5 ppg.mud, Appr Date 37 .Seismtc.analysjs.oJ shaJlow gas.zone.s. . . . . _ _ . . . _ . . . . _ . _ . . . . . . _ . . . . NA_ . . _ . . . . . . . . . _ _ . . _ . _ . _ . . . . . _ . . . . _ . . . . . . . . . . _ . _ . . . . . . . . . . . . SFD 4/15/2003 38 Seab.ed çQnditipo survey (if off-~hpr.e) . . . . _ _ . . . _ _ . _ . . . . . . . . _ . . . . . . . NA. . _ . _ . . . . . . . . . . _ . . . _ . _ . . . . . . . _ . . . . . . _ _ . . . . . . . . _ . . . _ . . . . . . . . . . . . . . _ . . . 39 .Gontaçtnamelphon.e.for.w.eeklyprogre~s.rep.ort$[expforatory.Qoly). _.. ...... NA.. . _. _ _........ _...... _....... _.. _....,..."., . _ _. _........ Engineering Geology -------,--_.-.--~--- Geologic Commissioner: Date: bD 0+/;7/0 3 Engineering Commissioner: Public Commissioner ~~~ Date Date ~ ~~'\.,,~~ u ) ) Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding infomlation. information of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. ) ) c?<o(3 :]ß¡(j {liP'! /Lfo 5"3 **** REEL HEADER **** RWD 04/04/15 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** RWD 04/04/14 487457 01 RECEIVED ÞPf< 2 1 2004 AfIIaOil&Gas Cons. Commission Anchoraøe 3.125" GAM and 3.125 USR *** LIS COMMENT RECORD *** !! ! ! !! ! ! !! !! !!!! ! !! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: ldwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 6967.0000: STOP.FT 8845.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 8 TOWN.N 13N RANG. 10E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 56 DMF KB EKB .F 56 EDF .F N/A EGL .F 0 CASE.F 6980 OS1 . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. MPL-OIA Milne Point Unit 70 deg 29' 48.935" N, 149 deg 38' 2.355" W North Slope Alaska Baker Hughes INTEQ 3.125" CoilTrak - GR/USMPR 09-Jun-03 500292106801 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 ) ) (2) All depths are Bit Depths unless otherwise noted. (3) All Resistivity and Gamma Ray data is Memory data except for the real time Gamma Ray (GRAX) data presented from 6980' MD(6897' SSTVD) to 7222' MD(7043' SSTVD). (4) Baker Hughes INTEQ Runs 1 & 2 utilized NaviGamma service from 6995' MD (6912' SSTVD) to 7242' MD (7047' SSTVD). (5) Baker Hughes INTEQ Runs 3, 6, & 7 utilized Ultra Slim Multiple Propagation Resistivity (USMPR) from 7242' MD (7047' SSTVD) to 8845' MD (7009' SSTVD). (6) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS on June 11, 2003. (7) The well was tied into the Gamma Ray log from the MPL-01A wellbore at 6782' MD (6705' SSTVD). (8) The sidetrack was drilled from milled window in 7" casing. Top of window: 6972' MD (6890' SSTVD) Bottom of window: 6980' MD (6898' SSTVD) (9) The mud weight was increased from 10.7 ppg to 10.9 ppg with higher potassium mud concentrations. This had the effect of a bulk shift on the Gramma Ray Log which is partially compensated for by utilizing a GR plot scale of 0-200 AAPI. (10) The interval from 8829' MD (7010' SSTVD) to 8845' MD (7009' SSTVD) was not logged due to sensor to bit offset. MNEMONICS: GRAM Gamma Ray APPARENT [RWD], (RWD-API units) GRAX Real Time Gamma Ray APPARENT [MWD], (MWD-API units) ROPS Rate of Penetration, (ft/hour) RPCHM Phase Resistivity, 2 MHz Compensated & Borehole Corrected [RWD], (Ohm-m) RPCLM Phase Resistivity, 400kHz Compensated & Borehole Corrected [RWD], (Ohm-m) RACHM Attenuation Resistivity, 2 MHz Compo & Borehole Corrected [RWD], (Ohm-m) RACLM Attenuation Reistivity, 400 kHz Compo & Borehole Corrected [RWD], (Ohm-m) CURVE SHIFT DATA BASELINE, MEASURED, 7298.75, 7297.7, 7309.33, 7307.23, 7317.74, 7317.74, 7357.46, 7353.68, 7396.83, 7396.62, 7429.3, 7428.24, 7480.98, 7480.98, 7516.02, 7515.6, 7588.44, 7585.92, 7601.26, 7600, 7680.51, 7678.82, 7706.34, 7708.65, 7781.85, 7778.91, 7790.12, 7788.86, 7817.44, 7817.02, 7842.82, 7841.35, 7887.65, 7889.54, 7908.74, 7910.84, 7965.43, 7963.54, 7979.3, 7978.25, 8040.8, 8042.07, 8140.53, 8139.06, 8149.99, 8148.73, 8325.29, 8326.98, 8330.13, 8332.23, 8395.42, 8400.04, 8433.91, 8437.91, 8501.04, 8504.4, 8628.22, 8628.85, 8643.99, 8642.73, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAM Tape Subfile: 1 DISPLACEMENT -1. 05078 -2.10156 o -3.78271 -0.209961 -1.05078 o -0.42041 -2.52197 -1.26123 -1. 68164 2.31201 -2.94238 -1.26123 -0.42041 -1. 47119 1. 8916 2.10205 -1. 89111 -1. 05078 1.26123 -1.47119 -1.26074 1. 68164 2.10156 4.62402 3.99316 3.3623 0.629883 -1.26074 106 records... ) Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** RWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska), Inc. MPL-01A Milne Point North Slope Alaska *** LIS COMMENT RECORD *** !! !!!!! !! !!! !! !! !!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS on June 11, 2003. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0 1 0.0 RPCH RPCH RPCHM01 0.0 RPCL RPCL RPCLM01 0.0 RACH RACH RACHM01 0.0 RACL RACL RACLM01 0.0 ROP ROP ROPS01 0.0 GRAX GRAX GRAX01 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length ) 1 GRAM RWD 68 1 API 4 4 2 RPCH RWD 68 1 OHMM 4 4 3 RPCL RWD 68 1 OHMM 4 4 4 RACH RWD 68 1 OH:M:M 4 4 5 RACL RWD 68 1 OH:M:M 4 4 6 ROP RWD 68 1 F/HR 4 4 7 GRAX RWD 68 1 API 4 4 ------- 28 Total Data Records: 122 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6967.000000 8845.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 136 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** RWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 BP Exploration (Alaska), MPL-OIA Milne Point North Slope Alaska *** LIS CO:M:MENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the unedited raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCH RPCH RPCHM 0.0 RPCL RPCL RPCLM 0.0 RACH RACH RACHM 0.0 RACL RACL RACLM 0.0 ROPS ROPS ROPS 0.0 GRAX GRAX GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM RWD 68 1 API 4 4 2 RPCH RWD 68 1 OHMM 4 4 3 RPCL RWD 68 1 OHMM 4 4 4 RACH RWD 68 1 OHMM 4 4 5 RACL RWD 68 1 OHMM 4 4 6 ROPS RWD 68 1 F/HR 4 4 7 GRAX RWD 68 1 API 4 4 ------- 28 Total Data Records: 243 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6967.000000 8845.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 257 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** RWD 04/04/14 487457 01 **** REEL TRAILER **** RWD 04/04/15 BRI 01 , ."\> Tape Subfile: 4 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes