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197-136
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF VNDRY WELL OPERATIONS MAR 05 HID, Sul 1. Operations Abandon U Plug Perforations LJ Fracture Stimulat Pull Tubing L Operations shutd"dwnLJ Performed: Suspend ❑ '�GP Perforate 11� Other Stimulat❑ Alter Casing'7 ❑ Change Approved Program ❑ Plug for Redrill ❑ :rforate New Pool ❑ Repair We❑✓ Re-enter Susp Well ❑ Other: Install Jet Pump Q 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 197-136 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22790-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025514, ADL0025515 & ADL0025509 MILNE PT UNIT L-20 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): WA MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 19,770 feet Plugs measured 19,601 feet true vertical 7,022 feet Junk measured N/A feet Effective Depth measured 19,601 feet Packer measured 18,547 &18,838 feet true vertical 6,873 feet true vertical 6,045 & 6,248 feet Casing Length Size MD TVD Burst Collapse Structural 74' 20" 112' 112' WA N/A Surface 8,123' 9-5/8" 8,160' 3,546' 5,750psi 3,090psi Production 19,071' 7" 19,104' 6,462' 7,240psi 5,410psi Liner 932' 4-1/2" 19,770' 7,022' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feel Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3 / L-80 / Mod 18,703' 6,149' PHIL & Packers and SSSV (type, measured and true vertical depth) Baker ZXP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 1 0 0 1 0 Subsequent to operation: 0 0 1 1,662 320 1 481 14. Attachments (required Per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory El Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑s Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. umber or N/A if CO. Exem 31 -- So8 Authorized Name: Chad Helgeson Contact Name: Taylor Wellman -?FM/ Authorized Title: Operations Manager Contact Email: twellman ftilcorD.com Authorized Si nature: Date: 3/5/2019 Contact Phone: 777-8449 Form 10-104 Revised 4/2017 RBDMSAa'�MAR 0 6 2019 Submit Original Only K nilmru Al+a:a. LLC Orig.DF Elev.: 49.85/GL Elev.: 16.8' Nabors 22E RKB-THF: 31.18' (Doyon 14) ( i 20'1 35/8' Howco ES Cementer @2,137 SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU L-20 Last Completed: 12/01/18 PTD: 197-136 Tree 3-1/8"-5M Vertical Tree 9-5/8" 2-1/16" 5M Horizontal Tree 7" 11"x 7" 5M FMC Gen 5a w/ 2-7/8" WKM Wellhead Tubing Hanger, w/3" Acme Threads, 2.5"CIW L1.1/H-40/N/A H BPV Profile OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I in 24" Hole 9-5/8" 1,250 sx PF "E", 2,200 sx Class "G" in 12-1/4" Hole 7" 425 sx Class "G" in 8-1/2" Hole 5" 120 sx Class "G" in 6" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor L1.1/H-40/N/A N/A Surface 112' 9-5/8" Surface 40/L-80/BTC 8.835 Surface 8,160' 7" Intermediate 26/L-80/BTC-Mod 6.276 Surface 19,104' 4-1/2" Liner 12.6/L-80/Mod 3.958 18,838' 19,770' TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE 8rd 1 2.992 1 Surface 18,703' 7'Homo ES WELL INCLINATION DETAIL STIMULATION DETAIL Cementer @ 10,447 KOP @ 400' 3/11/1998- Kuparuk A Sand -104 M# 20/40 Carbolite & Max Hole Angle = 70 to 81.5 deg. f/ "3,000'to 35 M# of PropLok coated 16/20 Carbolite behind Pipe. ^'17,600' MD 2 Hole Angle through perforations = 33 deg. JEWELRY DETAIL S � vahe atm tvivse in Ru 4 n Mn ID 2.697' s (2)-7' x 21' Short Joints from " 18,566to 18,610. 7" Tag @� 19 192 7 'a 9 Sands Sands Sards Surds Sands 4.5"a' 411 TD =19,770' (MD) / TD= 7,022'(TVD) PBTD=19,601' (MD) / PBTD = 6,873'(TVD) No Depth Item 1 31' Tubing Hanger 2 18,409' Pressure Gauge; HES ROC 150 3 18,429' TechFlo Jet Pump BHA with Blanking Sleeve 4 18,439' RN Nipple (standing valve set on 12/11/18) (NO -Go 2.697') 5 18,547' 7" x 3-Y:"" PHL packer (Shear release 40,950 lbs) 6 18,569' Autofill sub (Min ID 2.880") 7 18,673' WLEG-Btm@18,703' 8 18,838' Packer: Baker ZXP 7" x 4-1/2" 9 1 18,852' 1 Liner Hanger: HMC Hydraulic 30 1 19,104' 1 Liner Hanger: Baker 7"x5" PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk Cl/B6 19,272 19,286 6,597' 6,608' 14 11/27/18 Open Kuparuk 86 19,297 19,305 6,617' 6,624' 8 11/27/18 Open Kuparuk A3 19,354 19,370 6,664' 6,677' 16 11/27/18 Open Kuparuk A2 19,370' 19,400' 6,677' 6,701' 30 3/19/1998 Oen Kuparuk A2 19,400' 19,414' 6,701' 6,713' 14 11/27/18 Open Kuparuk Al 19,424' 19,451' 6,721' 6,744' 27 11/27/18 Open Kuparuk Al 19,472' 19,477' 6,762' 6,766' 5 11/27/18 Open Perforation Summary: Ref Log-Anadrill LWD 8/2/1997 GENERAL WELL INFO API: 50-029-22790-00-00 Drilled and Cased by Nabors 22E - 8/31/1997 Completed by Nabors 4ES-3/22/1998 RWO by Nabors 4E5 - 7/27/2001 RWO by Nabors 4ES - 6/20/2006 RWO by Nabors 3S-7/24/2006 RWO by Nabors 4ES -11/28/2007 RWO by Nabors 4ES-6/14/2010 RWO by Doyon 16 - 3/26/2011 RWOby Doyon 16-5/19/2013 RWO by Nordic 3-10/08/2015 RWO by Doyon 14 -12/01/2018 Revised By: TDF 3/5/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-20 Doyon 14 50-029-22790-00-00 197-136 11/18/2018 12/11/2018 Daily Operations. 11/14/2018- Wednesday No activity to report. 11/15/2018 - Thursday No activity to report. 11/16/2018 - Friday No activity to report. 11/17/2018 -Saturday No activity to report. 11/18/2018-Sunday No activity to report. 11/19/2018 - Monday Received sundry approval from the AOGCC at 14:30 hours. Hold PJSM on well kill operations. Attempt to blow air through HP lines to kill tank/choke skid. Lines frozen. Stage heater on choke skid. Flood the lines with diesel and PT against a block valve to 3,000psi (good test). Line up the IA to the kill tank (1,680psi). Vent gas from the IA and at 1,060psi got fluid returns. Line to pump down the IA taking returns out the tubing to the kill tank. When the tubing was opened to a closed choke the tubing pressure dropped from 1,200psi to 40psi. Well service came to location, open up the choke and found a small rock and a small chunk of rubber. Put the choke back together and attempt to pressure up but the choke still would not hold. Replaced the choke valve and PT to 1,500psi (good test). Start pumping 115° seawater down the IA taking returns up the tubing to the kill tank at 3 BPM (added 2 drums of DeepClean® to the first 60 bbls). ICP = 1,700psi holding 500psi back pressure and FCP = 1,440psi holding 200psi back pressure. Shut down the pump when the kill tank volume reached 404 bbls. Total pumped = 500 bbls. Blow down all lines to the kill tank. Offload 285 bbls from the kill tank to a vac truck. Resume pumping 115° seawater down the IA taking returns up the tubing to the kill tank at 3 BPM=1,310psi holding 200psi back pressure. Returns starting foaming up. Offload 220 bbls from the kill tank to a vac truck. Resume pumping 115° seawater down the IA taking returns up the tubing to the kill tank at 3 BPM=1,370psi holding 200psi back pressure. Clean seawater to surface. Shut in the well. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-20 Doyon 14 50-029-22790-00-00 197-136 11/18/2018 12/11/2018 Daily Operations. 11/20/2018 -Tuesday Blow down lines and freeze protect same w/ diesel. Offload kill tank to vac truck. Prep pits and load 12.1 ppg brine KWF into pits. Shut in pressures= Tubing 925psi, I/A 925psi. PJSM. Circulate 12.1 ppg KW brine down tubing 3 bpm, 2080psi ICP circulating thru tbg punch @ 18630' with returns up I/A to flow back tank holding 400 to 450 back pressure. FCP 2,240psi. Pumped 287 bbls KWF, 365 bbls seawater returned to FBT. Shut off pump, shut in well. Monitor pressures while emptying FBT with Vac truck. Shut in pressures= tubing Opsi, I/A 500psi. Continue to circulate 12.1 ppg brine down the tubing taking returns out the IA at 3 BPM = 2,880psi with 350psi back pressure slowly opening to a full open choke. Total pumped 800 bbls with a total of 737 bbls returned at the kill tank with 11.5 ppg brine at surface. Shut in the well. Blow down all lines to the kill tank. Suck out the bleed tank. Monitor the well pressures. The tubing was on a vac and had 11psi on the IA. Continue to circulate 12.1 ppg brine down the tubing taking returns out the IA at 3 BPM = 2,670psi with a full open choke. Pumped 144 bbls with 93 bbls returned at the kill tank with 11.9 ppg brine at surface Shut in the well. Blow down all lines to the kill tank. Suck out the bleed tank. Monitor the well pressures. Initially the tubing was on a vac with slight gas from the IA then both went static. Observe the well for flow for 30 minutes. Tubing and IA = Opsi. RD all circulating lines, hard line and circulating equipment on the tree. PJSM. Installed the BPV with dry rod. NO the tree and tubing head adapter. NU the 11" x 7-1/16" DSA and the BOP stack. Torque all the bolts. Install the riser and air up the air boots. Install mouse holes. PU and MU dry rod. Check for pressure under the BPV, no pressure and pull the BPV. Install TWC. Lay down the dry rod. RU BOPE testing equipment. Flood the lines and choke manifold with fresh water. Purge the air from the system. Shell test the BOP stack to 250/4,OOOpsi (passed). Conduct initial BOPE test to 250/4,OOOpsi: Lower pipe rams (2-7/8" x 5" VBR's) with 2-7/8" and 4" testjoints, upper pipe rams (2-7/8" x 5" VBR's) with 2-7/8" and 4" test joints, annular with 2-7/8" and 4" test joints to 250/2,500psi, accumulator drawdown test and test gas alarms. The states right to witness was waived by AOGCC inspector Brian Bixby via email on 11/20/18 at 16:24 hours. Tests: 1. UPR with 2-7/8" test joint, 3" Demco kill, upper IBOP, choke valves 12, 13 & 14 (passed). 2. HCR kill, lower IBOP, choke valves 9 & 11 (passed). Hauled 35 bbls H2O from L -Pad lake for total= 195 bbls. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-20 Doyon 14 50-029-22790-00-00 197-136 11/18/2018 1 12/11/2018 Daily Operations. 11/21/2018- Wednesday Continue initial BOPE test to 250/4'000psi: Lower pipe rams (2-7/8" x 5" VBR's) with 2-7/8" and 4" test joints, upper pipe rams (2-7/8" x 5" VBR's) with 2-7/8" and 4" test joints, annular with 2-7/8" and 4" test joints to 250/2,500psi, perform accumulator drawdown test and test gas alarms. Tests: 3. Manual kill, lower IBOP, 4" XT-39 dart vavle, choke valves 5, 8 & 10 (passed). 4. Choke valves 4, 6 & 7 (passed) . 5. Choke valve 2 (passed). 6. HCR choke (passed). 7. LPR with 2-7/8" test joint (passed). 8. Annular to 2,500psi with 2-7/8" test joint (passed). 9. Blind rams, choke valve 3 (passed). 10. UPR with 4" testjoint, manual choke (passed). 11. LPR with 4" test joint (passed). 12. Annular to 3,000psi with 4" test joint (passed). 13. Hydraulic super choke, manual adjustable choke (passed). Accumulator Test: System pressure = 3,000psi. Pressure after closure=1,700psi. 200psi attained in 46 seconds. Full pressure attained in 200 seconds. Nitrogen Bottles - 6 at 2,090psi. Blow down lines, RD test equipment. RU dry rod, pull TWC as per wellhead rep. Tubing on slight vac. MU landing jt, 4" it DP with FOSV and LH acme thread XO on bottom. M/U Landing jt to hanger, BOLDS. PU 70K to unseat hanger, P/U 150K, pull hanger to rig floor. 31 bbls to fill wellbore. Cut cable, R/U 2 7/8" handling equipment. L/D hanger w/ pup and landing it. Monitor well with trip tank, static loss rate 44 bph, maintain hole fill @ 15-20 bph. Hang ESP sheave in the derrick and attach trunk. RU 2-7/8" handling equipment. String rope over sheave through trunk to the spooling unit. MU crossover to TIW. PJSM. POOH laying down 2-7/8" tubing spooling ESP cable removing cannon clamps from 18,736' to 12262'. Observed cable damage on joint #176 (joint #422 in the tally). Cut ESP cable in spooling unit and MU to an empty spool. Continue to POOH laying down 2-7/8" tubing spooling ESP cable removing cannon clamps from 12,262' to 10,656'. 11/22/2018-Thursday Continue to POOH laying down 2-7/8" EUE tubing spooling ESP cable removing cannon clamps from 10,656' to 5,715'. Maintain 5 bph hole fill, then slow hole fill to 2 bbls every 20 its L/D. Cut ESP cable in spooling unit and MU to an empty spool. Continue to POOH laying down 2-7/8" tubing spooling ESP cable removing cannon clamps from 5715' to 92'. Maintain hole fill to 2 bbls every 20 jts L/D. Lay down ESP components. Recovered 472 cannon clamps and 8 motor clamps. Centrilift noted the seals were blown. Clear the rig floor of Centrilift equipment. RD the sheave and trunk in the derrick. Clean the rig floor of paraffin/oil residue. SimOps: Shoot a fluid level at 500'. Service the top drive. Mobilize and RU 2-7/8" handling equipment. Install 7" wear ring (ID = 6-1/16"). PU and MU mill/motor assembly. RIH with mill/motor assembly on 2-7/8" HT Pac work string to 809'. Change handling equipment to 4". MU crossovers from 2-7/8" HT Pac to 4" HT-38. SimOps: Remove 4" HWDP from the pipe shed. Continue to RIH with mill/motor assembly on 4" HT-38 DP from 809' to 11/23/2018-Friday Continue single in the hole with mill/motor assembly on 4" HT-38 DP from 5,865' to 8,633'(249 its), M/U X0, single in w/ 4" XT-39 DP to 10,988', fill pipe, pump an extra 12 bbls 2 bpm 500psi seeing fluid returns, shut off MP. BD TD. Continue single in the hole with 4" XT-39 DP f/ 10,988' to 18,789' fill pipe every 60 jts ran (PU = 220K and SO = 60K). No displacement returns. Slip and cut 86' of drilling line. Inspect the draw works and calibrate the block height. Continue to RIH on 4" XT-39 DP from 18,789' to 19,072' (PU = 235K and SO = 60K). TIH with 4" DP from the derrick from 19,072' to tag at 19,471' with 5K down. MU the top drive and break circulation. Wash down from 19,471' to hard tag at 19,613' with 5K down at 2 BPM = 770psi. TOOH from 19,613' to 19,246'. Drop 3/4" ball and circulate to seat with 11.9 ppg brine at 2 BPM = 690psi. Circulate the well from 12.1 ppg to 11.9 ppg brine at 3 BPM = 890psi. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-20 Doyon 14 50-029-22790-00-00 197-136 11/18/2018 1 12/11/2018 Daily Operations. 11/24/2018 -Saturday With DP just above perfs at 19,246' continue to displace well from 12.1 ppg to 11.9 ppg brine pumping 2.5 BPM = 690psi. Pumped total 642 bbls with 97 bbl losses. Flow check the well, static loss rate = 7 BPH. Blow down the top drive. TOOH on elevators racking 4" DP back f/ 19,246' to 811', 7-10 bph loss rate over calculated displacement, 77 bbls total. C/O to 2- 7/8" handling equipment, L/D XOs and 25 its 2-7/8" HT Pac work string. L/D cleanout BHA. Maintain 5 BPH hole fill. Continue hole fill at 5 BPH, load out tools, cleanup rig floor, mobilize scraper BHA to floor. PU and MU 3.75" tri cone bit and 4-1/2" casing scraper. RIH with 19 joints of 2-7/8" HT Pac work string to 606'. Change out hydraulic hose on the power tubing tongs. RIH with the remaining 6 joints of 2-7/8" HT Pac work string from 606' to 795'. PU and MU crossovers and 7" casing scraper from 795' to 809'. TIH with dual scraper assembly on 4" DP from 809' to 18,875' (PU = 220K and SO = 55K). Lost 100 bbls during the trip. Slip and cut 60' of drilling line. Service the draw works and calibrate the block height. 11/25/2018 -Sunday TIH with dual scraper assembly on 4" DP from 18,875' to 19,505' setting down 5K, MU top drive, wash down 2 BPM = 375psi, wash thru easily, tag PBTD @ 19,611' with 10K down (PU = 235K and SO = 55K). Note: Worked 7" scraper 4 times across packer set depth area from 18,477' to 18,603'. TOOH from 19,611' to 19,241' just above perfs. CBU 2.5 BPM = 700psi (loss rate =18 BPH). Lower pump rate to 2 BPM = 420psi with 12.6 BPH loss rate. Lost 71 bbls while circulating. Flow check well, 10 BPH static loss rate. Blow down the top drive. TOOH with dual scraper assembly from 19,241' to 809'. Losses = 7-30 BPH over calculated displacement while TOOK Lay down 7" casing scraper, 25 joints of 2-7/8" HT Pac work string, 4-1/2" scraper and tri cone bit. Clean and clear the rig floor. PJSM for PU TCP gun with rig crew and Halliburton representatives. PU and MU TCP guns (84' of guns at 6 SPF). MU crossover, 16 joint of 2-7/8" HT Pac work string, crossovers, 2 joints of 4" XT -39 DP and RA marker sub to 812'. TIH with TCP guns at 60-65 FPM from 812' to 10,048'. No 11/26/2018 - Monday ontinue to TIH with TCP guns on 4" DP at 60-65 FPM from 10,048' to 18,791'. No displacement returns. Submit 24 hr BOP test notification to AOGCC @ 08:29 hrs. Slip and cut 60' of drilling line. Service the draw works and calibrate the block height. Monitor well, fill at 5 BPH. TIH from 18,791' tagging at 19,521', PU to 19,513' L/D single, M/U FOSV. (PU = 225K and SO = 65K). PJSM for E -line. M/U 3-1/2" IF XO on FOSV, RU E -line. Maintain 5 BPH hole fill. Note: Phase 2 weather conditions @ 16:00 hrs. RIH with GR/CCL to 3,000' WLM and pump tools down to 3,480' WLM at 4.3 BPM=1,800psi but unable to get any deeper. POOH. Add additional weight bars and larger pump down cup. RIH with GR/CCL to 3,000' WLM and pump tools down to 3,400' WLM at 4 BPM = 1,600psi but unable to get any deeper. POOH. Remove all weight bars to shorten the BHA. RIH with GR/CCL to 3,000' WLM and pump tools down to 3,400' WLM at 4 BPM=1,600psi but unable to get any deeper. POOH. Add additional pump down cup to the top of the BHA. RIH with GR/CCL to 3,000' WLM and pump tools down to 3,400' WLM at 4 BPM = 1,600psi but unable to get any deeper. POOH. Add roller stem to the top and put both cups on bottom. RIH with GR/CCL to 3,000' WLM, pump tools down to 4,000' WLM at 4 BPM=1,600psi increase pump rate to 5 BPM = 2 400 si and continue to RIH to sit down at 18 762' WLM. Log up for correlation. Send logs to town geologist for evaluation. POOH with E -line. Town geologist compared original open hole log to the correlation for the top of the HRZ. Determined a 18' adjustment is needed. Reviewed log with HES TCP representatives, determined to adjust the DP up 20.5' (18' for correlation correction and 2.5' to place the top shot on depth). RD E -line and offload equipment from the rig floor. Drop 3/4" ball, MU a single and PU to up weight plus 20.5'. Pump ball to seat at 2 BPM = 440psi. Pressure up 1,710psi and the guns fired (good indication on surface). TOOH standing back 4 stands of 4" DP to 19153'. Circulate bottoms up at 3 BPM = 660psi, loosing 15 BPH. Slowed the pumps to 2 BPM = 310psi, loosing 8 BPH. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-20 Doyon 14 50-029-22790-00-00 197-136 11/18/2018 12/11/2018 Daily Operations. 11/27/2018 -Tuesday Continue to circulate a bottoms up at 19,153' pumping 2 BPM, 310psi. Total losses while CBU= 80 bbls. Flow check well, static loss rate @ 6 bph, BD TD, TOOH with perf gun assy L/D 4" DP f/ 19,153't/ 740'. Fill with 1.5 times pipe displacement, 3 bbls every 15 joints. L/D 16 joints of 2-7/8" HT PAC pipe f/ 740't/ 236'. P1SM with Halliburton & rig crew. L/D 2-7/8" per guns f/ 236'. Recovered ball from ball drop sub. All guns fired. 114 bbls calculated displacement for trip out, 173 bbls filled, 59 bbls total losses for trip out. Pull wear bushing and install test plug. Flush BOP stack with stack washing tool prior to testing. R/U stack washer and blow down top drive. Drain BOP stack of 11.9 ppg brine to mud pits. R/U BOP test equipment. Fill BOP stack with water and purge lines. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit NumberStart Date End Date MP L-20 Doyon 14 50-029-22790-00-00 197-136 1 11/18/2018 1 12/11/2018 Daily Operations. 11/28/2018- Wednesday Perform shell test to 250/4,000psi, good. Test BOPE using 4" and 3-1/2" test jts. Test UPR/LPR, BR, upper and lower IBOP, FOSV, dart valve, mud cross and choke manifold valves to 250/4,000psi 5 min ea. Test annular to 250/3,000psi 5 min ea. chart all tests. Perform accumulator drawdown test. Test PVT and gas alarms. No failures. Witness waived by AOGCC inspector Jeff Jones on 11-26-18 @ 10:18, Blow down lines, R/D test equipment. Note: monitor I/A filling at 5 bph. R/D test equipment, pull test plug, blow down kill & choke lines and drain fresh water from stack. Unplanned activity: 7" x 3-1/2" hanger unable to be utilized with TEC cable. Required to change tubing spool to 11" for use of 11" x 3-1/2" FMC hanger w/ continuous penetration for TEC cable. Approval from AOGCC Guy Schwartz to proceed with change to sundry. Mobilize BHA components and perform PJSM. M/U stack washing tool, XO sub, 20 joints 4" HWDP, 10 joints 4" drill pipe, XO sub, Baker storm packer, XO sub then RIH on 3 joints 4" drill pipe. Set packer at 104.8', release running tool and pressure test packer to 250/2,000psi for 5 min. each. Nipple down BOP stack, remove 7-1/16" FMC tubing spool and install 11" FMC tubing spool. Test 7" casing pack -off void to 5,000psi for 10 min. - good test. N/U BOP stack and install risers 11/29/2018 - Thursday Install the test plug, Fill stack, check for leaks, good. R/U test equipment, Test tbg spool x BOP flange to 250/4,000psi 5 min ea, charted, good test. BD lines, R/D test equipment. RIH with running tool and 1 std 4" DP, engage storm packer, close bag and release storm packer, no trapped pressure under packer. Open bag, 18 bbls to fill hole, TOOH L/D 3 its DP, storm packer assy, 10 its 4" DP, 20 jts 4" HWDP and wash tool. Clear and clean rig floor, R/U to run 3-1/2" jet pump completion. Load tools to rig floor. R/U 3-1/2" handling equipment, power tongs, tech wire spool and sheave. Ready FOSV and XO. Maintain 5 bph hole fill. Hold PJSM with all parties involved, M/U WLEG it, 3 jts 3-1/2" EUE tbg, Mirage plug & auto fill w/ pup jts above and below, 7" PHIL retreivable packer (shear release 40,950 ft/lbs) w/ pup above and below, 3 jts tbg, pup it, 2.75" R profile nipple w/ 2.697" no go, pup jt, jet pump sleeve, 2pup jts, gauge mandril, pup jt to 304'. Terminate TEC cable to gauge . Test continuity, pressure test termination seal to 5,000psi. Install clamp on pup above gauge mandrel. P/U and RIH w/ drifted 3- 1/2", 9.3#, L-80, EUE 8rd tubing with TEC cable f/ 304' to 4,900', install clamp over tbg collar on every jt, torque connections to optimum at 3,100 ft/lbs. Test TEC cable every 1,000'. Maintain 5 BPH hole fill. Continue to run drifted 3-1/2", 9.3#, L-80, EUE 8rd tubing with TEC cable f/ 4,900' to 8,403' (270 of 605 joints), install clamp over tbg collar on every jt, torque connections to optimum at 3,100 ft/lbs. Test TEC cable every 1,000'. Maintain 5 BPH hole fill. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-20 Doyon 14 50-029-22790-00-00 197-136 11/18/2018 12/11/2018 Daily Operations. 11/30/2018 - Friday Continue to run drifted 3-1/2", 9.3#, L-80, EUE 8rd tubing with TEC cable f/ 8,403' to 10,339', install clamp over tbg collar on every jt, torque connections to optimum at 3,100 ft/lbs. Test TEC cable every 1000'. Maintain 5 BPH hole fill. Due to major earthquake in Anchorage/Wasilla areas, shut down rig operations, M/U FOSV, monitor well while employees contact their families. Maintain 5 BPH hole fill. Continue to run drifted 3-1/2", 9.3#, L-80, EUE 8rd tubing with TEC cable f/ 10,339' to 18,663", install clamp over tbg collar on every jt, torque connections to optimum at 3,100 ft/lbs. Test TEC cable every 1,000'. Maintain 5 BPH hole fill. 600 cross coupler Cannon clamps installed w/ 2 pins on each. M/U TC -11 box x EUE XO pup joint, C/O elevators, remove XO from FOSV, P/U 4" drill pipe landing joint & M/U XT -39 to TC -II X0. P/U hanger. Blow down choke, kill and hole fill lines. Perform hanger feed thru of TEC cable. Monitor ROC gauge while landing tubing on hanger at 18,703'. 130K PUW, 60K SOW, 20K on hanger. RILS. Flush BOP stack with fresh water. Drain stack. L/D landing joint & install BPV. N/D BOP stack. Feed TEC cable through well head. Install adapter flange. Pressure test adapter flange to 5,000psi. Terminate TEC cable. Sim -ops: clean shakers and mud pits. 12/1/2018 -Saturday N/U tree, Pull BPV, install TWC, fill tree with diesel and test to 250/5,000psi 5 minutes ea. good, Pull TWC. Submit 24 hr diverter test notification for M-03 to AOGCC @ 07:51. R/U LRS, PJSM. Test lines to 250/5,000psi, good. Freeze protect I/A to 2,500', bullhead 70 bbls diesel 2 bpm, caught pressure 6 bbls away, 750psi, gradually slowing to .5 bpm, 790psi at 53 bbls away, FCP= I/A 790psi, Tbg= 213psi. LRS line up to pump down tubing, Pressure up and close auto fill 1,600psi, continue to pressure up seeing packer set @ 1,900psi, pressure to 3,600psi, shut in and test tbg for 30 min, charted, 1 bbl diesel pumped to pressure up. Good test, bleed off pressure. Line up LRS on I/A, pressure up and test I/A to 2,100psi for 30 min, 2 bbis diesel pumped, charted, good. Bleed off to 450psi, Line up LRS on the tbg, pressure tbg to 4,500psi, hold f/ 10 Min, increase to 4,800psi, hold f/ 10 min. Bleed off to 900psi, pressure to 4,800psi for 15 min, bleed off pressure to 900psi, Pressure to 4,900psi and hold f/ 15 min. Bleed off to 900psi, pressure to 4,900psi, hold for 15 min, bleed off to Opsi, Unable to shear mirage plug. RD LRS. Load lubricator to rig floor, R/U and install BPV, R/D lubricator. install tree cap, secure well. Remove bell nipple from BOP stack, skid #2 conveyor into rig move position. Continue cleaning mud pits. Swap from highiine to rig power @ 15:30 / Release from MPU L-20 @ 18:00. 12/2/2018 -Sunday No activity to report. 12/3/2018 - Monday No activity to report. 12/4/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number I Start Date End Date MP L-20 Doyon 14 50-029-22790-00-00 197-136 11/18/2018 12/11/2018 Daily Operations. 12/5/2018- Wednesday MIRU CTU . Perform BOP test, PT CT and PCE High/ Low 200/4,000 psi. RIH with nozzle. Circulate in M/W Freeze protect to 4,000'. 12/6/2018 - Thursday No activity to report. 12/7/2018 - Friday No activity to report. 12/8/2018 -Saturday ****WELL SHUT IN UPON ARRIVAL*** (ELI NE TRACTOR/ GYRO). PT PCE 2501-13-2,0001-1 P. RI W/ ELI NE, WELLTEC TRACTOR, & GYRO (HAD TO START TRACTORING FROM 2,958' TO 10,687'). LOG GYRO SURVEY FROM 10,500' RKB TO SURFACE. LAY DOWN FOR THE NIGHT- LEFT WELL SHUT IN. 12/9/2018 -Sunday PT PCE 250LP-2,000HP. RUN ELINE, TRACTOR STOKER TOOLS, 2" JUC W/ B -PROBE AND BREAKER BAR. LATCHED UP TO ISO SLEEVE AND SEE IA PSI DROP INDICATING KNOCKOUT EQ PLUG SHEARED. PULLED ISO SLEEVE FROM 18,429' MD (ALL PKG RECOVERED) (HAD TO USE STROKER TWICE TO PULL ISO SLEEVE FROM PROFILE). LAID DOWN FOR THE NIGHT- NOTIFIED PAD OP. 12/10/2018 - Monday PT PCE 250 LP - 2,500HP. RAN IN W/ 3-1/2" CAT STANDING VALVE W/ 3" JDC PINNED LIGHTLY AND ATTEMPTED TO SET IN RN NIPPLE AT 18,439' RKB (WELL TECH SAW PIN SHEAR WHEN USING STROKER), BUT POOH W/ STANDING VALVE STILL ATTACHED TO PULLING TOOL BUT ONLY HAD A FRICTION BITE (PIN WAS SHEARED). LAY DOWN FOR THE NIGHT- NOTIFIED PAD OP. 12/11/2018 -Tuesday PT PCE 250 LP-2,500HP. DEPLOYED 2.75" STANDING VALVE FROM SURFACE AND PUSH TO RN NIPPLE 18,439' RKB WITH 2.50" BLINDBOX & WELLTECH TRACTOR. WELL LEFT S/I ON DEPARTURE - NOTIFIED PAD OP. STATE OF ALASKA RECEIVED AIL OIL AND GAS CONSERVATION COMWION REPORT OF SUNDRY WELL OPERATIONS APR 0 6 2013 1.Operations Abandon U Plug Perforations U Fracture StimulateU Pull Tubing U •. oo utdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ "'Cfi•e`•1p�dCre rogram ❑ Plug for Redrill ❑ .rforate New Pool ❑ Repair Well❑ Re-enter Susp Well❑ Other:Tubing Punch Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development El Exploratory ❑ 197-136 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22790-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025514 MILNE PT UNIT L-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 19,770 feet Plugs measured 19,601 feet true vertical 7,022 feet Junk measured N/A feet Effective Depth measured 19,601 feet Packer measured 18,838 feet true vertical 6,873 feet true vertical 6,248 feet Casing Length Size MD TVD Burst Collapse Structural 74' 20" 112' 112' N/A N/A Surface 8,123' 9-5/8" 8,160' 3,546' 5,750psi 3,090psi Production 19,071' 7" 19,104' 6,462' 7,240psi 5,410psi Liner 932' 4-1/2" 19,770' 7,022' 8,430psi 7,500psi 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 18,740' 6,176' Packers and SSSV(type,measured and true vertical depth) Baker ZXP N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A i' r SCANNER " Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 282 42 807 320 217 Subsequent to operation: 0 0 0 1,380 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hilcorp.com Authorized Signature: Date: 4/2/2018 Contact Phone: 777-8333 Form 10-404 Revised 4/2017 RBOMS a.. APR 0 6 2018 Submit Original Only 0 Milne Point Unit II 110 Well: MPU L-20 SCHEMATIC Last Completed: 10/08/15 Hikorp Alaska,LLC PTD: 197-136 TREE&WELLHEAD Orig.DF Elev.:49.85'/GL Elev.:16.8'Nabors 22E Tree 2-9/16"-SM FMC 11"x 7"5M FMC Gen 5a w/2-7/8"WKM 1Wellhead Tubing Hanger,w/3"Acme Threads,2.5"OW 20''` H BPV Profile t 1 OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,250 sx PF"E",2,200 sx Class"G"in 12-1/4"Hole 0', 7" 425 sx Class"G"in 8-1/2"Hole ? t 5" 120 sx Class"G"in 6"Hole 04 Howco ES CASING DETAIL Cementer Size Type Wt/Grade/Conn ID Top Btm fir. 2 0 @ 2132 3/8"SS .1" 20" Conductor 91.1/H-40/N/A N/A 0 112' Cap String i 9-5/8" Surface 40/L-80/Btc. 8.835 0 8,160' 4.1 7" Intermediate 26/L-80/BTC Mod 6.276 0 19,104' as 4-1/2" Liner 12.6/L-80/Mod 3.958 18,838' 19,770' a" TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 18,740Lt ' WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=76 to 79 deg.f/3,500'to TD r` Hole Angle through perforations=33 deg. ILI STIMULATION DETAIL 9-5/8" 7"Howco ES 3/11/1998-Kuparuk A Sand-104 MU 20/40 Carbolite& 0 Cementer @ 35 MU of PropLok coated 16/20 Carbolite behind Pipe. (2)-7"x 21'Short 10,447 Joints fromJEWELRY DETAIL 18,566'to 18,610' No Depth Item 1 105' GLM:Camco 2-7/8"x 1"KBMM w/DSOV PunchU 18,6 ng0' SP @ 8 TOP� 2 2,738' 2-7/8"HES X Nipple-10=2.250" 18,630'to 18,635'MD--► 3 18,657' Discharge Valve:FPDIS 3/24/2018 3 4 18,658' Tandem Pump:Centrilift ESP 134-FLEX 17.5 5 18,705' Intake Gas Separator:GRSFERNAR ca r4 6 18,708' Tandem Seal Section: 7 18,722' Motor:Model MSP1-250,168HP/3,460V/30Amp I i '5 8 18,735' 3/8"External Capillary String 9 18,735' Well Lift MGU Sensor w/6 Fin Centralizer Bottom:18,740' a 6 10 18,838' Packer:Baker ZXP 7"x 4-1/2" 11 18,852' Liner Hanger:HMC Hydraulic .. 7 12 19,104' Liner Hanger:Baker 7"x 5" L PERFORATION DETAIL 11 11 8 i, Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status ", 9 „..141113 Kuparuk A2 19,370' 19,400' 6,677' 6,701' 30 3/19/1998 Open 11 Perforation Summary:Ref Log-Anadrill LWD 8/2/1997 12Li GENERAL WELL INFO 7"tfil & API:50-029-22790-00-00 R4 Tag @ Drilled and Cased by Nabors 22E -8/31/1997 19,197 Completed by Nabors 4ES-3/22/1998 RWO by Nabors 4ES-7/27/2001 RWO by Nabors 4ES-6/20/2006 Kuparuk A2 Sands RWO by Nabors 3S-7/24/2006 RWO by Nabors 4ES-11/28/2007 RWO by Nabors 4ES-6/14/2010 RWO by Doyon 16-3/26/2011 4.5" 4 RWO by Doyon 16-5/19/2013 TD=19,770'(MD)/TD=7,022'(TVD) RWO by Nordic 3-10/08/2015 PBTD=19,601'(MD)/PBTD=6,873'(TVD) Revised By:TDF 4/2/2018 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-20 CTU #4&6 50-029-22790-00-00 197-136 3/21/18 3/24/18 iii Daily Operations , ` Y.` ;�"���.: (! 11,� m...==� I� � ����� 3/21/2018-Wednesday MIRU CTU #4. BOPE Test 250psi low and 3,500psi high. Good test. No failures 3/22/2018-Thursday MIRU SLB CT 4.Troubleshoot micromotion, pump, load cells, back engine. SDFN. 3/23/2018-Friday SLB CTU #6 with 20,615' of 1.75" CT. CV=40.7 bbls. PU injector, 11' of lubricator, and BOPE. Run coil down and MU BHA#1- 1.75" OD roll on connector, 1.69" DFCV, 1.75" MBT, 1.75" MBT,xo, 2.0" OD JSN. OAL= 11.4'. Stab oin well. NU BOPE. Open SSV, install fusible cap. P/T to 250psi low and 3,500psi high. Open well and RIH w/BHA#1 while taking displacement returns to the tank. WHP bled from 880psi to 23psi in 5 minutes on full open choke. Begin circulating slk 1% KCL at 1.5 BPM and jet tubing while RIH. P/U weight= 13k-lbs. @6,700'. P/U weight= 16.5k-lbs @ 8,000' RIH and tag at 8,382'. POH 20'with normal pick up weight.Attempt to RBIH unsuccessful 8,362'. POH 100'with normal P/U. Attempt to RBIH unsuccessful. POH to above 8,000'. Reduce rate to 0.75 bpm and RIH with no issue. Stack out at 9,016'. P/U to 8,500'. RBIH to 9,443'. Stack out at 9,443'. POH to 9,000'. Send 10 bbl gel pill. RBIH and stack out at 9,618'. POH to 9,100'. RBIH to 10,005'and stack out. POH to 9,800'. RBIH and stack out at 10,5074'. POH to 10,300'. RBIH to 11,100' and stack out. POH to 10,800'. Rig up LRS with hot diesel. P/T LRS line to 4,500psi. Good test. Come online with LRS at 1 BPM and RIH. RIH to 13,000'. P/U weight= 24k-lbs. P/U weight=26.5k at 15,000'. P/U weight=30k-lbs at 17,000'.Tag top of ESP at 18,602' ctmd. Paint flag. EC)!at flag is 18,580'. P/U =36k-lbs. Circulate hole clean by pumping 2 times BU volume at 2.5 BPM. 100% returns. Pumping 25 bbls slk 1% KCL/ 10 bbl PowerVis. P/U @ 18,602 is 28k-lbs after cleaning. POH while circulating and jetting 100 degree diesel at 1.5 BPM from 18,602'to 500'. Freeze protect well from 500'with 60/40 McOH while POH to surface.At surface. Close Swab. FP tree. SDFN. WHP climbs to 450psi. SDFN 3/24/2018 Saturday SLB CTU #6 with 20,615' of 1.75" CT. CV=40.7 bbls. PU injector, 11' of lubricator, and BOPE. Run coil down and MU BHA#1- 1.90" OD dimple connector, 1.69" DBCV, 1.69" FAU, 1.69 Knuckle Joint", 2.0" xo,firing head (1/2" ball), 5' of 1.56" 4 spf tubing punch, bow spring. OAL= 11.95'. Distance from Top shot to bottom of bow spring=8.18'.Stab on well. NU BOPE. Open SSV, install fusible cap. P/T to 250psi low and 3,500psi high. Open well and RIH w/BHA#1 while taking displacement returns to the tank.WHP bled from 880psi to150psi in 5 minutes.Tag top of ESP at 18,615' (18,657' corrected). P/U to top shot at 18,630' (corrected) Drop ball and chase by circulating 41 Bbls (CV) Ball hits at 47.2 bbls away. Punch Tubing from 18,630'to 18,635'. See good indications that shots fired. Pump down C x IA annulus and see IA pressure increase. Communication between tubing and IA is confirmed. POH to surface. Freeze protect well from 2,500'with 60/40 McOH while POH to surface. At surface. Close Swab. FP tree. RDMO to L-49.WHP =611psi. 3/25/2018-Sunday No activity to report. 3/26/2018- Monday No activity to report. 3/27/2018-Tuesday No activity to report. STATE OF ALASKA ALI.OIL AND GAS CONSERVATION COMIIIION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ✓ [1 Fill Clean-out Plug for Redrill ❑ arforate New Pool ❑ Repair Well ✓ Re-enter Susp Well El Other: ESP CO ✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 197-136 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22790-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL0025514 MILNE PT UNIT KR L-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): JAN 0 6 2016 N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: AOGCC Total Depth measured 19,770 feet Plugs measured 19,601 feet true vertical 7,022 feet Junk measured N/A feet Effective Depth measured 19,601 feet Packer measured 18,838 feet true vertical 6,873 feet true vertical 6,248 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 8,160' 9-5/8" 8,160' 3,546' 5,750psi 3,090psi Production 19,104' 7" 19,104' 6,462' 7,240psi 5,410psi Liner 932' 4-1/2" 19,770' 7,022' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic %Atilt/ED MAR 0 3 20)6 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 18,740' 6,176' 18,838'MD Packers and SSSV(type,measured and true vertical depth) Baker ZXP Packer N/A 6,248'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 316 96 773 240 221 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ DevelopmentEl Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-573 Contact Stan Porhola Email sporhola(a�hilcorp.com Printed Name Bo York Title Operations Engineer Signature -----4'..-4 n ' -�- m� Phone 777-8345 Date 1/6/2016 n:.� < � 1"4> LRBDMS JAN 0 7 2016 Form 10-404 Revised 5/2015 d X0A6. Submit Original Only 14 • • Milne Point Unit Well: MPU L-20 SCHEMATIC Last Completed: 10/08/15 Ilileorp Alaska,LLC PTD: 197-136 CASING DETAIL Orig.DF Elev.:49.85'/GL Elev.:16.8'Nabors 22E Size Type Wt/Grade/Conn ID Top Btm j y 20" Conductor 91.1/H-40/N/A N/A 0 112' #.; S e 9-5/8" Surface 40/L-80/Btc. 8.835 0 8,160' 2a' s 7" Intermediate 26/L-80/BTC Mod 6.276 0 19,104' 1 „) 4-1/2" Liner 12.6/L-80/Mod 3.958 18,838' 19,770' TUBING DETAIL "" 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 18,740' 07:0 JEWELRY DETAIL Howco ES No Depth Item Cementer 1 105' GLM:Camco 2-7/8"x 1"KBMM w/DSOV (r MI 2 z @ 2,132 2 2,738' 2-7/8"HES X Nipple-ID=2.250" 3/8"SS 3 18,657 Discharge Valve:FPDIS CapStrin: `;' 4 18,658' Tandem Pump:Centrilift ESP 134-FLEX 17.5 ei 5 18,705' Intake Gas Separator:GRSFERNAR um 4, ;, 6 18,708' Tandem Seal Section: ;. 7 18,722' Motor:Model MSP1-250,168HP/3,460V/30Amp tS to it 8 18,735' 3/8"External Capillary String 9 18,735' Well Lift MGU Sensor w/6 Fin Centralizer Bottom:18,740' 10 18,838' Packer:Baker ZXP 7"x 4-1/2" L I� 11 18,852' Liner Hanger:HMC Hydraulic 9* 12 19,104' Liner Hanger:Baker 7"x 5" PERFORATION DETAIL 9-5/8" Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7"Howco ES v Cementer @ Kuparuk A2 19,370' 19,400' 6,677' 6,701' 30 3/19/1998 Open 10,447' Perforation Summary:Ref Log-Anadrill LWD 8/2/1997 (2)-7"x 21'Short Joints from WELL INCLINATION DETAIL 18,566'to 18,610' KOP @ 400' Max Hole Angle=76 to 79 deg.f/3,500'to TD Hole Angle through perforations=33 deg. Mg s OPEN HOLE/CEMENT DETAIL p. rt 41 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,250 sx PF"E",2,200 sx Class"G"in 12-1/4"Hole It, $'.5 7" 425 sx Class"G"in 8-1/2"Hole i* arty it 6 5" 120 sx Class"G"in 6"Hole gel4 a tz,, TREE&WELLHEAD Tree 2-9/16"-5M FMC ' a7 11"x 7"5M FMC Gen 5a w/2-7/8"WKM 1i t4Wellhead Tubing Hanger,w/3"Acme Threads,2.5"CIW i' $ H BPV Profile 3" I I `' 9 ` 10 GENERAL WELL INFO '.11 API:50-029-22790-00-00 id 712 Drilled and Cased by Nabors 22E -8/31/1997 '4v Completed by Nabors 4ES-3/22/1998 7"rtRWO by Nabors 4ES-7/27/2001 R4 Tag @ RWO by Nabors 4ES-6/20/2006 19,912 RWO by Nabors 35-7/24/2006 RWO by Nabors 4ES-11/28/2007 - RWO by Nabors 4ES-6/14/2010 Kuparuk A2 Sands RWO by Doyon 16-3/26/2011 RWO by Doyon 16-5/19/2013 _ RWO by Nordic 3-10/08/2015 4.5"A I STIMULATION DETAIL TD=19,770'(MD)/TD=7,022'(TVD) 3/11/1998-Kuparuk A Sand-104 M#20/40 Carbolite& PBTD=19,601'(MD)/PBTD=6,873'(TVD) 35 MU of PropLok coated 16/20 Carbolite Behind Pipe. Revised By:STP 12/17/2015 • • Hilcorp Alaska, LLC flavor!,Alaska.IAA: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP L-20 50-029-22790-00-00 197-136 9/24/2015 10/8/2015 Daily Operations: 9/23/15-Wednesday No operations to report. 9/24/15-Thursday Finish testing tree on L-45. Move rig to L-20. Spot over well.Accept rig MPU L-20 @ 0800. Berm cellar&cuttings tank. Pull BPV&check pressures.Tubing-550, IA,-500 OA 150. R/U circ lines to kill tank. R/U lines to kill the well. Pressure test to 2,500psi. Bleed gas off tubing F/550 T/80psi. Got fluid back. Bleed off tubing and annulus T/90 psi.Straight fluid. PJSM, start pumping 8.5 ppg heated seawater down the tubing @ 3 bpm 900 psi.Annulus 300 psi. OA climbing from 150 to 500psi during the circulation. Getting straight gassed up oil back. Displace tubing with seawater+10 bbl.Shut down and strap kill tank,SITP 250psi. Pumped 119 bbl got back 107. Bleed off OA f/500psi to 160psi. Note:John Crisp waived witness to BOP test on 9-24-15 @ 13:25 hrs. Start pumping down the tubing with 8.5 ppg seawater @ 3 bpm 930 psi, pump 771 bbls,taking returns out I/A thru choke to kill tank, note 707 bbls returned to kill tank.Stop pumping and shut in well while sucking out kill tank. Bleed off tbg and I/A from 315psi to Opsi, 15 bbls bled back,shut in well and Monitor tbg and I/A pressure,tbg pressure building from Opsi to 220psi, and I/A from Opsi to 235psi in 45 minutes and shut in pressures stabilizing. Note O/A 160psi. Pump another 205bbls down tbg @ 3 bpm 800psi, holding 350psi back pressure with choke taking returns to kill tank, 165 bbls returned,shut down pump,shut in well. Note:total of 976 bbls 8.5 seawater pumped,886 bbls returned,90 bbls losses. Monitor shut in pressures,tbg and I/A pressure building from 100psi to 250psi in 30 min and stabilizing with crane,set ESP spooler on rig floor and set diverter on MPU L-20 and four point same.Weight up 500 bbl pit volume from 8.5 ppg to 9.2 ppg KWF with salt.TBG and I/A remain @ 250 psi,O/A 70psi. Pump 9.2 ppg KWF @ 3 bpm, ICP 870psi down tbg taking returns out I/A holding 350psi back pressure w/choke, note: mostly oil and gas returns to kill tank, 240 bbls pumped started seeing returns cleaning up. 614 bbls pumped,540 bbls to kill tank. divert thru gas buster taking clean returns to pits.Note: O/A gradually climbed from 60psi to 150psi. 725 bbls pumped then fully open choke, FCP 600psi at 3 bpm.9.2 ppg in/8.9 ppg out,continue to circulate 3bpm, 600psi. 784 bbls pumped,shut in well to wt up remaining fluid in pits to 9.2 ppg KWF. 9/25/15- Friday Shut down &monitor well.9.2 in,8.9 out. Bleed off presure from well to 0.Shut in and pressure built to 70psi on the tubing, 140 on the annulus. Monitor for 30 min. Continue pumping @ 3 bpm 9.2 in 8.9 out. Shut down and monitor well. Pressure on the tubing built to 70psi. Bleed down twice and pressure built to 70psi. Bullhead 15 bbl with a final bulhead pressure of 380psi.Started injecting @ 240psi.Shut down and monitor pressure.Tubing @ 140 psi. Bleed down t gg and IA to 0. Pressure built up to 70psi. Decide to weight up to 9.5 ppg. Safety shut down due to incident on th• A : ' Bring all hands to the floor and discuss saftey hazards with hands and report to Milne Point for field meeting w . I (J () personnel. Leave the driller and electrition on the rig. PJSM, build KWF.Weight up pits to 9.5. ppg.Start pumping down 71 tbg @ 5 bpm 1,700psi,thru wide open choke with returns to pits. Pumped 810 bbls, 57 bbls to formation. Bled tbg and I/A to 0 psi, monitor for 60 min,flowing 6.5 bph reducing to no flow on tbg, I/A continues to flow 4 bph diminishing to no flow,well is dead. PJSM, install BPV per wellhead rep. Bleed off hanger void. Blow down circ lines and R/D same, O/A 60psi. PJSM,with I/A open, monitor same. N/D tree,wellhead rep inspect 3" LH Acme hanger threads, 6-1/2 turns, function lockdown screws. N/U adaptor flange and 11"5M BOPE,function components,continue to monitor I/A. PJSM, pull BPV, install TWC per wellhead rep. R/U test equipment. Fill stack and lines with water. Perform shell test to P/4 250/3,500 psi.AOGCC state rep John Crisp waived witness to test on 9/24/15 @ 13:25 hrs.Test BOP components to 11/ 250psi low and 3,500psi high 5 min ea using 2-7/8"test joint,chart record tests. Monitor I/A. Wim" • • C 9/26/15-Saturday 9 Test bops to 3,500psi.Test annular on 2-7/8"test joint. Annular failed on the 2-3/8"joint.Change annular element.Test annular to 3,500psi on 2-7/8" &2-3/8"joint.Good test. RID test equipment. Perform accumulator test. PJSM with centralift,well head rep and rig crew, review well control procedure pulling ESP completion. Pull TWC per wellhead rep. R/U landing joint. Blow down all surface lines. Drain stack. BOLDS. Unseat hanger @ 95K, P/U 10'seeing 140K,work down 2 times 5', Pull hanger to the rig floor @ 125k P/U. Line up trip tank on well,fill stack. Centrilift perform ohm test on ESP cable, 6.5 ohm phase to phase,infinitive phase to ground, remove cable from penetrater, L/D hanger,XOs and landing jt, monitor well with trip tank,4.5 bph loss rate. POOH with 2-7/8"6.5#L-80 EUE ESP completion f/18,780'to 18,621' L/D 2 pup jts, pull 1st stand, R/U ESP cable to spooler, rack 1 std in derrick, L/D GLM with pups.Continue POOH from 18,621'to 13,032" racking 60 stds 2-7/8"tubing in derrick,SLM tbg in derrick. Note:well taking 3 bph while POOH, currently 25.5 bbls over calculated hole fill. M/U FOSV, cut ESP cable,C/O ESP spools. Monitor well with trip tank.Static loss rate continues @ 3 bph.Continue POH from 13,032'to 12,467' 9/27/15-Sunday 4011W , 1,1 4A1'' Continue POH with 2 7/8" 6.5#L-80 EUE ESP completion f/12,467'to 6,875' racking stds 2-7/8"tubing in derrick,SLM same. Note:well taking 3 bph while POH. M/U FOSV,cut ESP cable,C/O ESP spools. Monitor well with trip tank.Static loss reducing to 2 bph.Continue POH from 6,874'to 1,300', hole taking 1.5 bph over calculated hole fill. M/U FOSV,cut ESP cable, C/O ESP spools. Monitor well with trip tank.Static loss reducing to 1.5 bph.Continue POH from 1,300'to pup above XN nipple, L/D XN nipple and 2 pup jts. L/D single.75.9 bbls over calculated displacement on trip out. 198 stands and 2 singles 2-7/8"tbg total tbg. (596 jts)Note:491 cannon clamps removed.Cut ESP cable, 1.1 ohms phase to phase thru splice, 1.0 phase to phase on motor. Pull ESP asst'out of the hole. /ESP assembly per Centrilift from mousehole. Verify oil in pump, Note:small amount of metal shavings found below intake behind protectolizer. Note:4 protectolizers, 3 flat guards and 2 half clamps removed.Static loss rate.75 bph. Load out ESP spool, load spool with new ESP cable onto rig floor with crane. Box up pump and motor assembly. Load out ESP jewelry.Clean rig floor.Work on draworks low drum clutch, investigate overheating,align clutch plates.Continue to monitor well with trip tank.Static loss rate.5 bph. C/O from 2-7/8"to 2-3/8" handling equipment,C/O Power tongs dies,elevators. M/U 2-3/8" mill shoe, 25 jts 2-3/8" PH6,3 XOs,7"casing scraper, bit sub=781.64'. 9/28/15-Monday 'Orr ISI 1 � , (,j Continue to RIH with the 2-3/8" mule shoe& 7"casing scraper on 2-7/8" EUE from the derrick F/781'T/17,060'. Hole taking correct displacment.Continue to RIH with the 2-3/8" mule shoe& 7"casing scraper on 2-7/8" EUE from the derrick F/17,060'T/18,838'4-1/2" LT. Up/102 DN/50 RIH T/19.316'. Rev Circ btm up before going through perfs. 2 bpm @ 200psi pump pressure. No solids @ btms up. Lost 40 bbl while circulating.Gained back 20 bbls after shutting the pumps off. Rev Circ btm up before going through perfs.2 bpm @ 200psi pump pressure. No solids @ btms up. Lost 40 bbl while circulating.Gained back 20 bbls after shutting the pumps off.Wash down F/19,316'T/19,590'. @ 1 bpm through the tubing.Tag 5k. No fill noted.Scraper depth 18,813'. Reverse circ @ 3 bpm 500 psi.two btm up+. No solids observed. No gas observed. Note:52 bbl losses while circulating. Monitor well. Flowing back out of the annulus 6 bph but dropping off. POH slow F/19,590'T/18,560' monitoring annulas,continues to flow but slowing to 4 bph, POH f/18,560'to 15,320' with flow decreasing to.4 bph while POH.Continue POH from 15,320'to 14,470',flowcheck well for 15 min,flowing 1 bph with crude cap. Note:well flowed 28 bbls total POH,Circulate a bottoms up @ 14,470'to clear oil from annulus and check for gas pumping 5 bpm,2,550psi.Gas peaked @ 2,197u,wt in/out 9.4+,dust wt to 9.5 ppg in/out, reducing BGG to 46u. Note: Note 9 bbl loss during circulation. Monitor well for 60 minutes with trip tank, in 20 minutes gained .7 bbl then going static in 30 minutes.Continue POH from 14,470'to 10,692', Hole taking 1 bph over calculated displacement on trip out. • • 9/29/1 TuesdaYa , �� � Continue POOH from 10,692', LD 7"Casing scraper and 2-3/8" PH-6.Clear floor. PU 7"Champ 4 Packer, RIH on 2-7/8" EUE tubing from derrick to 18,800'. P/U 105k,S/O 55k. Note: 13.4 bbl under calculated displacement on trip in. M/U top drive, Circulate bottoms up with packer on depth @ 18,800' pumping 5 bpm, 1,580psi, lost 18 bbls in 45 minutes, reduce pump to 4 bpm, 1,050psi reducing loss rate to 6 bph.9.5 ppg in/out,792u gas @ BU. Reduce rate to 3 bpm,556psi, Note: Lost 30 bbls while circulating.Shut off pump and monitor for 20 minutes,flowing 3 bph.Continue to pump 3 bpm,550 psi, just under 1-1/2 hole volumes total. Note:well flow reducing from 3 bph to 1.5 bph. Bled O/A from 325psi down to 125psi.Set Packer per Haliburton rep to test 7"casing @ 18,805',close upper pipe rams,attempt to pressure up casing, pump 3.8 bbls with pressure not increasing past 250psi, returns out tbg, unseat packer, P/U and set packer @ 18,775', attemp to pressure up, pump 2.3 bbls pressuring up to 220psi, returns out tbg, not enough S/O wt @ 15-20k not including blocks to set packer. Notify town engineer,decision made to POH until S/O wt increases enough to set packer. POH from 18,775'to 17,712' 10 stands,attempt to set packer,close upper pipe ram, pump down kill line 4 bpm pressuring up to 2,000psi attempting to force packer to seat 2 times,see returns out tbg. • • Hilcorp Alaska, LLC t,ite,,rpA,a ka, Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP L-20 50-029-22790-00-00 197-136 9/24/2015 10/8/2015 Daily Operations: 9/30/15-Wednesday Attempt to set packer and test casing @ 17,712', pumping 4 bpm to 2,000psi attempting to force packer to seat 2 times, see returns out tbg.Attempt again @ 17,330'with no success. Load and tally 47 jts 3-1/2" 13.3#DP.TIH picking up 45 jts 3 1/2" DP f/17,330' to 18,778'.Set Champ Pkr as per rep.Attempt to test casing with no test and fluid returns up the DP. TOH standing back 15 stnds 3-1/2" DP from 18,778'to 17,340'. Change over to 2-7/8" handling equipment.TOH standing back an additional 20 stands of 2-7/8"tbg from 17,340'to 15,430'and found a hole in jt#493 from btm.Lay down bad jt and replace.XO to 3-1/2" DP, run 1 stnd DP and set Packer @ 15,550'.Attempt to test casing .Still had leak off up the tubing, but much slower than previous leak off. Change over handling equipment to 3-1/2" DP.TIH from 15,550'with 15 stands DP from Derrick.Continue TIH picking up additional 60 jts 3-1/2" DP that were tallied,to make room for laying down 2-7/8"tubing. POOH standing back 35 stds 3-1/2" DP to 15,462'. M/U FOSV and top drive. Slip and cut 66'drill line. Monitor well with trip tank,static loss rate .2 bph.Change over to 2-7/8" handling equipment. POOH laying down 2-7/8" EUE 8rd tubing from 15,462'to 10,837'. Correct displacement POH. 10/1/15`-Thursday Continue POOH laying down 2-7/8" EUE 8rd tubing from 10,837'to 900'.Stopping to kick out pipe while circulating every 60 jts layed down.At 900' hole not taking fill. Monitor well with slight flow, oil breaking out and rolling @ top of hole. TBIH with 34 stands of 2-7/8"tubing from derrick to 4,110'.Circulate 33 bbls to flow back tank with 8 bbls loss. Bring fluid inside and continue to circulate hole volume @ 3-4 bpm,with 1,220 units max gas @ btm up. Circulate 9.5+in/out. Monitor well,well static after 10 minutes. MU 2-7/8"Safety Jt with FOSV and XO's to 3-1/2" IF. TIH with 35 stands 3-1/2" DP from derrick to 7,493'. Note:4.1 bbls over calculated hole fill. P/U 2-7/8"safety jt with XOs and FOSV, M/U Top Drive, lower safety jt to 7,520',Circulate 3 bpm,450 psi w/good 9.5+ppg in/out,with 1,198u max gas @ Btms up reducing to 140u after 2 circulations. Monitor well for 60 min,flowing 10.5 bph reducing to 4.6 bph in 30 minutes and not slowing any further. Pump 3 bpm,450 psi. Increase wt from 9.5+to 9.6+ppg. Monitor well, no flow, no oil or gas breaking out, slight seepage. L/D safety jt. U tubing out tbg, pump 15 bbl dry job. Blow down top drive,TOH standing back 3-1/2" DP from 7,490'. Losses to formation last 24 hrs=20 bbls.Total losses=487 bbls. 10/2/15- Friday TOH standing back 3 1/2" DP from 7490'to 4100'. Change over to 2 7/8" handling equipment. Continue to POOH standing back 2 7/8"tubing. Lay down and inspect Champ PKR. PKR in good shape.Set aside for rerun. Hole fill took 7 bbls over calculated. Monitor well. Drain stack. Set test plug monitoring IA in cellar.Change out Lower Pipe Rams to 3-1/2". Rig up BOP Test equipment.Test BOP components as per Sundry on both 3 1/2" and 2-7/8" pipe sizes, using water test BOP !� Y components to 250/3,500 psi 5 min ea.,test annular to 250/2,500 psi 5 min ea . Chart all tests. 1 F/P noted on choke G5 valve#3,service and retest ok. Perform accumulator drawdown test.Test Witness Waived by Chuck Scheve with AOGCC on 10-1-2015 @ 14:27 hrs. R/D test equipment, blow down lines. Install 6-1/8" ID wear bushing, RI 4 LDS. M/U 7"Champ packer per rep, Drift and P/U 130 jts 2-7/8" PH6, Note: L/D jt#14 due to damaged tool face.TIH to 4,069'.Service blocks and top drive.Swap to 3-1/2" handling equipment, M/U X0,TIH with 35 stands 3-1/2" DP to 7,539',single in the hole with 3-1/2" DP to 7,724'. Note: 12.2 bbls under calculated displacement. 10/3/15-Saturday • • Continue to single in hole with the Champ PKR on 3-1/2" DP from 7,724'to 18,792'. MU top drive.Circulate bottoms up @ 5 bpm,2,800 psi,with 595 units max gas @ bottoms up.Continue to circulate 9.6+ppg in/out. Lost 54 bbls during z circulation.Set Champ PKR @ 18,795'.Test casing to 2,000 psi and chart for 30 minutes.Test good. Release Champ PKR. , Monitor well for 30 minutes,flowing 8 bph reducing to 4.2 bph in 30 min.TOH laying down 3-1/2" DP from 18,795'to 17,340', monitor well while offloading DP,flow rate reducing to 3.6 bph,continue TOH L/D pipe from 17,340'to 14,470', well continues to flow 3 bph due to wellbore breathing. Note:33 bbls under calculated displacement on trip at this point due to wellbore breathing.Circulate bottoms up pumping 3 bpm,800 psi,gas @ BU 672u with oil breaking out at surface, circulate 1 circulation, increase to 4 bpm, 1,450 psi,continue to circulate out gas. 10/4/15-Sunday i 00.7 °pew Continue to circulate hole volume @ 14,470'.4 bpm with 1,480 psi. Lost 37 bbls on circulation.Continue to TOH laying down 3-1/2" DP from 14,470 to 10,135'. Monitor well. Circulate bottoms up with 380 max gas.Continue to circulate 9.7 ppg in/out. Continue to TOH laying down 3-1/2" DP from 10,135 to top of 2-7/8" PH6 work string @ 4,096',wellbore breathing continues @ 3.5 bph. Change to 2-7/8" handling equipment,TIH with 36 stds of old 2-7/8" EUE tubing from derrick to 7,496'. M/U XO, FOSV and topdrive. Cut and slip 60'drilling line while circulating. Circulate 9.9 ppg well cap around pumping 3 bpm,600 psi until 9.9 ppg in/out. Bottoms up gas 944u.After 1 circulation due to oil and gas breaking out increase pump to 4 bpm, 1000 psi, pump 3 full circulations,gas remains @ 450u,flow check well 10 min, no flow,gas and oil breaking out. Lost 16 bbls circulating. Decision made to stage in the hole 1,000' and circulate 9.9 ppg fluid around. TIH P/U new 2-7/8" EUE tbg in pipe shed from 7,496'to 8,534'.Circulate 9.9 ppg around staging pump up to 6.5 bpm, 2,700 psi,946u max gas @ bottoms up.Circulated STS w/25 bbls lost during circulation.Gas units @ 95 @ end of circulation. Down on Pump and Monitor well @ 06:00. s 1,0/5/15 Monday....'" .,, !iaEi' a.. . ,, -;=t7 AO' Continue to circulate 9.9 ppg STS. Monitor well.Well Static after 15 minute,with 1.5 bbls back to trip tank.TOH from 8540' laying down 2-7/8"tubing and PH-6 work string. Hole taking 1.5 to 2 bbls over calculated on each hole fill. Lay down Halliburton Champ PKR. Rig up ESP running equipment. Make up Pump Assembly test same.Test good. Install flat guards&pump clamps. M/U discharge head w/2-7/8"tbg pup. RIH with ESP Completion per tally, RIH with 11 stds 2- 7/8"6.5#L-80 EUE tbg from Derrick to 1,130'.Continue to RIH with ESP completion picking up singles from pipe shed to 7,187', meg test ESP cable every 2,000'. Note:well taking 3 bph while RIH with ESP. 10/6/1.5-Tuesday Eli ,, i, Continue to RIH with ESP completion picking up singles from pipe shed from 7,187'to 9,360', meg test ESP cable every 2,000'. Note:well taking 3 bph while RIH with ESP.Swap out ESP SPool with Crane.Splice and test cable.Circulated 2 bbls through pump @ 1 bpm 300 psi.Continue to run in hole with ESP from 9,360'to 13,500'. Meg Wire.Continue to run in hole with ESP from 13,500'to 15,500'check ESP cable for continuity and proper resistance value.Continue to run in hole with ESP from 15,500'to 16,465'check ESP cable for continuity and proper resistance value. Drag getting excessive stopped @ 16,683'to pump a lube sweep @ 2bpm @ 2,280 psi. • Hilcorp Alaska, LLC ,,i,,.,,rp Alaska,1.1,C Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP L-20 50-029-22790-00-00 197-136 9/24/2015 10/8/2015 Daily Operations: 10/7/15-Wednesday Continue to pump lube sweep @ 16,683' due to excessive drag. 2bpm @ 2,280psi. Continue run in hole with 2-7/8" ESP completion 16,683'to 17,425', making up singles to Top Drive, pumping down and pressuring tbg up to 1,500 to 2,500psi, to elongate string and obtain movement. Lay down bent jt#556 and replace with jt#600 from tally. Prep for spool swap. Remove spool from floor with crane. Load 3rd spool onto Rig. Make cable splice on 3rd spool. Continue run in hole with 2- 7/8" ESP completion 17,425'to 18,470', making up singles to Top Drive, pumping down and pressuring tbg up to 1,500 to 2,500psi,to elongate string and obtain movement& periodically check ESP cable for continuity and proper resistance value. Losses to formation last 24 hrs= 120 bbls.Total losses= 1,066 bbls. 1450 bbls total to ORT 10/8/15-Thursday Continue run in hole with 2-7/8" ESP completion from 18,470'to 18,736', making up singles to Top Drive, pumping down and pressuring tbg up to 1,500 to 2,500psi,to longate string and obtain movement& periodically check ESP cable for continuity and proper resistance value. MU Tbg Hgr and Landing joint. Make Penetrator Splice.Test cable. Drain Stack, Land Hanger, RILDS, Lay down landing jt, Set BPV. N/D BOP and associated equipment.NU Tree.,pull BP _ hanger void and Tree to 250/5,000psi, pull TWC. Rig up LRS and pump freeze protect. Pump 80 bbls crude down IA and 15 bbls DSL down tubing. Last presure on the IA 200psi &210psi on the Tbg.Continue cleaning pits cutting box. Rig Released from L-20. 10/9/15- Friday No operations to report. 10/10/15-Saturday No operations to report. 10/11/15-Sunday No operations to report. 10/12/15-Monday No operations to report. 10/13/15-Tuesday No operations to report. • OF Tit �w \\I/7 s,, THE STATE Alaska Oil and Gas Fig; 7;, OfAT AKA Conservation Commission - .ftritt2 - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ('�� Main: 907.279.1433 OFALAS � °""��� Fax• 907.276 7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 1400 ` 7 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR L-20 Sundry Number: 315-573 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, sow\.‘00‘ NAr);(„. q-t ( Cathy P. Foerster Chair DATED thisp�q�day of September, 2015 Encl. RBDMSSEP 2 5 2015 R E VED • STATE OF ALASKA .''F? 1 ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 2 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Fill Clean-outs Plug for Redrill❑ Perforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other: ESP CO 0 2.Operator Name: 4.Current Well Class: 5.Permit to Dnll Number. Hilcorp Alaska,LLC v Exploratory ❑ Development Q : 197-136 P 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22790-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.432C Will planned perforations require a spacing exception? Yes ❑ No D / MILNE PT UNIT KR L-20 9 Property Designation(Lease Number): 10.Field/Pool(s): ADL0025514 - MILNE POINT I KUPARUK RIVER OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured). 19,770 • 7,022 • 19,601 ' 6,873 - 19,601' N/A Casing Length Size MD TVD Burst Collapse Structural 112' 20" 112' 112' N/A N/A Surface 8,160' 9-5/8" 8,160' 3,546' 5,750psi 3,090psi Production 19,104' 7" 19,104' 6,462' 7,240psi 5,410psi Liner 932' 4-1/2" 19,770' 7,022' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size. Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6 5#/L-80/EUE 8rd 18,809 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft). Baker ZXP Packer and N/A ' 18,838(MD)/6,248(TVD)and N/A 12 Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development Q r Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/23/2015 Commencing Operations. OIL Q ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola u@.hilcorp.com Printed Name Stan Porhola/ Title Operations Engineer Signature /gyLi-` Phone 777-8412 Date 9/17/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 315-G13 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ l Other: 5 p5 c � S� C "TJ 5���°S 1 Spacing Exception Required? Yes ❑ No rill Subsequent Form Required: /L) Y 01' ��►���,/��J�� Rf APPROVED BY n Approved by:3;""L""V' .. ( C.L ' J l0�i1"MISSIONER THE COMMISSION Date: (_/If ?`-11211/. '-s ?IL`s /94.II is v.,•c-( r-4 /� L/ /' � umd Form and �„Fg 1P O3 Reyised 5/2015 _ _ Ol o�,CGp�rINo alid for 1 months fro the date of approval. achments in Duplicate Well Prognosis Well: MPU L-20 Hikori,Alaska,LL Date:9/17/2015 Well Name: MPU L-20 API Number: 50-029-22790-00 Current Status: SI Oil Well [ESP] Pad: L-Pad Estimated Start Date: September 23rd, 2015 Rig: Nordic#3 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-136 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 3,000 psi @ 7,000' TVD (Last BHP measured 9/17/2015, ESP gauge) Maximum Expected BHP: 3,000 psi @ 7,000' TVD (No new perfs being added) / Max.Allowable Surf Pressure: 360 psi (Based on SBHP taken 9/17/2015 and water cut of 50% (0.385psi/ft)with an added safety factor AtQ (` of 1,000' TVD of oil cap) Brief Well Summary: / "' MPU L-20 was drilled with Nabors 27E as a high-angle departure Kuparuk oil producer. The original completion was ran in March 1998 using Nabors 4ES running an ESP. Replacement ESPs were installed in July 2001 using Nabors 4ES, June 2006 using Nabors 4ES, July 2006 using Nabors 3S, December 2007 using Nabors 4ES,June 2010 using Nabors 4ES, March 2011 using Doyon 16, and May 2013 using Doyon 16. The ESP stopped surfacing fluids on 9/15/2015. Notes Regarding Wellbore Condition • Casing last tested to unknown psi for 30 min down to 18,578' MD on 2/12/1998. • ESP not surfacing fluids as of 9/15/15. Objective: The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. Brief Procedure: WO Rig Procedure: 1. MIRU Norc_lisji3 WO Rig. 2. Circulate well with 8.5 ppg sea water down tubing and fill casing. 3. Set BPV. ND Tree. 4. NU 11" BOPE. Test to 250 psi Low/3,500 psi High, annular to 250 psi Low/2,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test upper pipe rams on 2-7/8"test joint. c. Test lower pipe rams on 2-3/8"test joint. ' 6‘1-- 5.. 5.. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. • Well Prognosis Well: MPU 1-20 Hilcarp Alaska,LL Date:9/17/2015 b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard nrncedure. 6. Bleed any pressure off tubing and casing. Pull BPV. 7. MU landing joint and pull 10k tension over string weight on tubing hanger to confirm ESP free. a. ***Contingency*** If landing joint won't make up to tubing hanger(bad threads). b. MU spear and pull 10k tension over string weight on tubing hanger to confirm tubing cut. 8. POOH. Rack back 2-7/8"tubing and lay down the failed ESP. 3/j' w sk '� 9. MU 2-3/8" muleshoe and pal/2=3/8" and RIH on 2-7/8" tubing to PBTD at+/-19,600' MD. 10. Circulate bottoms up x 2 with 8.5 ppg sea water. 11. POOH. Lay down 2-3/8" muleshoe and 2-3/8"tubing. Rack back 2-7/8"tubing. 12. PU Champ Packer and RIH w/2-7/8"tubing. 13. Set Champ Packer at+/- 18,800' MD.Test casing to 2,000 psi for 30 min. /kir"ki 14. Release Champ Packer. POOH. LD Champ Packer. Lay down 2-7/8"tubing. 15. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. a. Replace old upper GLM with new GLM at+/- 142'. b. Run new 3/8" control line to bottom of pump at+/- 18,807. 16. Set base of ESP at+/-18,807' MD (Pump intake around +/- 18,769' MD). Land tubing hanger. 17. Lay down landing joint. Set BPV. ND BOPE. NU existing 2-9/16" 5,000#tree. Pull BPV. 18. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 19. RD Nordic#3 WO Rig. 20. Replace IA x OA pressure gauge if removed (7" x 9-5/8"). 21. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Milne Point Unit Well: MPU L-20 SCHEMATIC Last Completed: 5/19/13 fiaeor,�Alaska,LLC PTD: 197-136 CASING DETAIL Orig.DF Elev.:49.85'/GL Elev.:16.8'Nabors 22E Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A 0 112' ir La a 9-5/8" Surface 40/L-80/Btc. 8.835 0 8,160' 20 t 7" Intermediate 26/L-80/BTC Mod 6.276 0 19,104' 1 ,:, 4-1/2" Liner 12.6/L-80/Mod 3.958 18,838' 19,770' y ' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 18,809' JEWELRY DETAIL No Depth Item " 01 Howco ES ` c Cementer 1 142' GLM:Camco 2-7/8"x 1"KBMM w/DSOV @ 2132' 2 18,698' 2-7/8"HES XN Nipple-ID=2.250" 1,, 3 18,740' Auto Diverter Valve 4 18,750' Discharge Valve:GPVDIS Ia 5 18,751' Pump:Centrilift ESP 137-P17 SXD ,, 6 18,769' Intake Gas Separator:GRSFTXARH6 , 7 18,774' Tandem Seal Section:GSB3DBUT/LT SB/SB PFSA/FSA CL5 ,, % 8 18,788' Motor:Model MSP1-250,210HP Rerated to 150HP/2,205V/41Amp et 9 18,807' Well Lift MGU Sensor w/6 Fin Centralizer ;I } 10 18,838' Packer:Baker ZXP 7"x 4-1/2" o 'E: 11 18,852' Liner Hanger:HMC Hydraulic t"; 12 19,104' Liner Hanger:Baker 7"x 5" PERFORATION DETAIL gSands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 95/8" 7"Howco ES Kuparuk A2 19,370' 19,400' 6,677, 6,701' 30 3/19/1998 Open 0 Cementer @ Perforation Summary:Ref Log-Anadrill LWD 8/2/1997 10,447' WELL INCLINATION DETAIL (2)-7"x 21'Short Joints from KOP @ 400' 18,566'to 18,610' �,. 2 Max Hole Angle=76 to 79 deg.f/3,500'to TD Hole Angle through perforations=33 deg. 3 OPEN HOLE/CEMENT DETAIL MB 4 20" 250 sx of Arcticset I in 24"Hole 5 9-5/8" 1,250 sx PF"E",2,200 sx Class"G"in 12-1/4"Hole e -44 7 " 425 sx Class"G"in 8-1/2"Hole '?' HI,, `.6 5" 120 sx Class"G"in 6"Hole ,.1 a ;«7 TREE&WELLHEAD ,! Tree 2-9/16"-5M FMC .. ,.., 11"x 7"5M FMC Gen 5a w/2-7/8"WKM ', '';8 Wellhead Tubing Hanger,w/3"Acme Threads,2.5"CIW ,`, H BPV Profile r iU "*. GENERAL WELL INFO 19 ,10 API:50-029-22790-00-00 ?ii Drilled and Cased by Nabors 22E -8/31/1997 1,12 Completed by Nabors 4ES-3/22/1998 , RWO by Nabors 4ES-7/27/2001 7"( RWO by Nabors 4ES-6/20/2006 RA Tag @ RWO by Nabors 35-7/24/2006 19,917-----0.ffl RWO by Nabors 4ES-11/28/2007 RWO by Nabors 4ES-6/14/2010 - RWO by Doyon 16-3/26/2011 Kuparuk A2 Sands RWO by Doyon 16-5/19/2013 STIMULATION DETAIL 3/11/1998-Kuparuk A Sand-104 M#20/40 Carbolite& 4.5"A 4 35 M#of PropLok coated 16/20 Carbolite Behind Pipe. TD=19,770'(MD)/TD=7,022'(TVD) PBTD=19,601'(MD)/PBTD=6,873'(TVD) Revised By:TDF 9/17/2015 Milne Point Unit . li Well: MPU L-20 PROPOSED Last Completed: 5/19/13 flrleorp Alaska,LLCPTD: 197-136 CASING DETAIL Orig.DF Elev.:49.85'/GL Elev.:16.8'Nabors 22E Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A 0 112' I. ,4i 9-5/8" Surface 40/L-80/Btc. 8.835 0 8,160' 20" 4r+ 7" _ Intermediate 26/L-80/BTC Mod 6.276 0 19,104' VI Itilii 1 4-1/2" Liner 12.6/L-80/Mod 3.958 18,838' 19,770' oh ' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 _ 0 ±18,809' P. 3/8" Cap String Stainless Steel N/A 0 ±18,809' r„ JEWELRY DETAIL O. Ho co ES Cementer No Depth Item @2,132' 1 ±142' GLM:Camco 2-7/8"x 1"KBMM w/DSOV ie '$' • 2 ±18,698' 2-7/8"HES XN Nipple-ID=2.250" 3/8 t' 3 ±18,740' Auto Diverter Valve Cap Strin: 4 ±18,750' Discharge Valve:GPVDIS 5 ±18,751' Pump:Centrilift ESP 137-P17 SXD 6 ±18,769' Intake Gas Separator:GRSFTXARH6 7 ±18,774' Tandem Seal Section:GSB3DBUT/LT SB/SB PFSA/FSA CL5 8 ±18,788' Motor:Model MSP1-250,21OHP Rerated to 150HP/2,205V/41Amp tri 9 ±18,807' Well Lift MGU Sensor w/6 Fin Centralizer ,f, "a 10 18,838' Packer:Baker ZXP 7"x 4-1/2" i^ 11 18,852' Liner Hanger:HMC Hydraulic P (" 12 19,104' Liner Hanger:Baker 7"x 5" '1 ‘ PERFORATION DETAIL 35/g 7"Howco ES Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Cementer @ Kuparuk A2 19,370' 19,400' 6,677, 6,701' 30 3/19/1998 Open 10,447' Perforation Summary:Ref Log-Anadrill LWD 8/2/1997 (2)-7"x 21'Short Joints from WELL INCLINATION DETAIL 18,566'to 18,610' - 2 KOP @ 400' 3 Max Hole Angle=76 to 79 deg.f/3,500'to TO it j Hole Angle through perforations=33 deg. 4 OPEN HOLE/CEMENT DETAIL 5 20" 250 sx of Arcticset I in 24"Hole 'I'' 9-5/8" 1,250 sx PF"E",2,200 sx Class"G"in 12-1/4"Hole "6 7" 425 sx Class"G"in 8-1/2"Hole 5" 120 sx Class"G"in 6"Hole SyiiZ 7 TREE&WELLHEAD Tree 2-9/16"-5M FMC 8 11"x 7"5M FMC Gen 5a w/2-7/8"WKM Wellhead Tubing Hanger,w/3"Acme Threads,2.5"CIW H BPV Profile '� 1 0 y 9 GENERAL WELL INFO t rho API:50-029-22790-00-00 "12 Drilled and Cased by Nabors 22E -8/31/1997 rCompletedbyNabors4ES-3/22/19987" RWO by Nabors 4ES-7/27/2001 RATa9 @ RWO by Nabors 4ES-6/20/2006 19,912______141 RWO by Nabors 3S-7/24/2006 RWO by Nabors 4ES-11/28/2007 - RWO by Nabors 4E5-6/14/2010 -..z..-_Kuparuk A2 Sands RWO by Doyon 16-3/26/2011 RWO by Doyon 16-5/19/2013 STIMULATION DETAIL 4.5"I 4 3/11/1998-Kuparuk A Sand-104 M#20/40 Carbolite& 35 M#of PropLok coated 16/20 Carbolite Behind Pipe. TD=19,770'(MD)/TD=7,022'(TVD) PBTD=19,601'(MD)/PBTD=6,873'(TVD) Revised By:TDF 9/17/2015 Milne Point MPU L-20 BOP 09/17/2015 r i O O (tl'(ti1(ffil rill (fll ft fftt Hydril 11"5M ,inittlithitillal r7 Shaffer trLti 27/8"Pipe Rams J ® __ _ 11"5M OD Blinds 1.-;"--r 3 1/8 5M Kill Valves 3 1/8 5M Choke Valves HCRfaillININIP Manual and HCR Manual and IIII II III! III III , 1. .4.1i - - '1F;;til ill' III IRI II1.}il `— [ Hydril il' SM - 2 3/8"Pipe Rams Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: GraYScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] Logs of various kinds Other COMMENTS: Scanned by: E~,~y Mitdred-Dare~owell ID TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell . Date: /si STATE OF ALASKA IRSKA OIL AND GAS CONSERVATION C MISSION ` ` a. '.,• _ ' ' - REPORT OF SUNDRY WELL OPERATIONS ' 1. Operations Performed: A ( / ,4 v. ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ' ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver • ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. • ❑ Exploratory ❑ Stratigraphic 197 - 136 3. Address: • ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22790 - 00 - 00' 7. Property Designation (Lease Number): 8. Well Name and Number: • ADL 025509 & 025514 MPL - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands ' 11. Present well condition summary: Total depth: measured 19770' feet - Plugs:(measured) None feet true vertical 7022' feet Junk: (measured) None feet Effective depth: measured 19601' feet Packer: (measured) None feet true vertical 6873' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 38' - 112' 38' - 112' 1490 470 Surface 8123' 9 -5/8" 37' - 8160' 37' - 3546' 5750 3090 Intermediate Production 19071' 7" 33' - 19104' 33' - 6462' 7240 5410 Liner 932' 4 -1/2" 18838' - 19770' 6248' - 7022' 8430 7500 1,8 201 3 Perforation Depth: Measured Depth: 19370' - 19400' feet JCiA$ 0 RIM True Vertical Depth: 6676' - 6701' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 18809' 6226' Packers and SSSV (type, measured and true vertical depth): None None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 243 43 585 200 212 Subsequent to operation: 406 139 1026 200 223 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: '18:1 Oil ❑ Gas ❑ WDSPL Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Sean McLaughlin, 564 -4387 N/A Email: Sean.McLaughlin @bp.com Printed Name: oe Lastufk Title: Drilling Technologist Signature: 1 A Phone: 564 -4091 Date: (a l 13 Form 10-404 Revise. •' • • 2 l/L P / /4-/ / 3 RBDMS JUN 14 20 * Submit Original,Only • . • °N iA fiCa- AAA -BP lOt Operation Sum eport . Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) Start Date: 5/12/2013 End Date: 5/17/2013 X4- 00XMM: (1,410,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/27/1997 12:00:00AM Rig Release: 5/17/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 30 : 20 3/6/1998 15:00 @37.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/12/2013 00:00 - 00:30 0.50 RIGD P PRE PRE -TOUR MEETING AND SPCC CHECKS - PJSM FOR DERRICK OVER - BRIDLE UP AND LAY DERRICK OVER 00:30 - 03:00 2.50 MOB P PRE PJSM FOR RIG MOVE OFF OF MPF -57A - NOTIFY PAD OPERATOR - DOYON SUPERINTENDANT AND NIGHT TOOLPUSHER & NIGHT WSL ON LOCATION - PULL OFF OF MP F- 57AAND MOVE TO MP L PAD 03:00 - 03:30 0.50 MOB P PRE ARRIVE MPL -PAD - PULL ONTO MPL -PAD - LAY MATS AND PREP TO BACK OVER MPL -20. 03:30 - 05:00 1.50 MOB P PRE - BACK OVER MPL -20 - PJSM - BACK RIG OVER WELL - NOTIFY PAD OPERATOR. - SPOT RIG OVER WELL 05:00 - 07:00 2.00 MOB P PRE PJSM, RAISE DERRICK - BRIDLE DOWN - SPOT RIG COMPONENTS. - RU CELLAR AND RIG FLOOR. * ** ACCEPT RIG AT 0700. * ** 07:00 - 11:00 4.00 MOB P PRE TAKE ON FLUID IN PITS. VAC OUT MELT WATER AROUND TREE SO GAUGE AND BLEED LINE CAN BE PLUMBED INTO OA. RIG UP CIRC OUT SKID. ADD 2X2 PLUG VALVES TO #2 AND #3 FLOWBACK TANKS.T TOTAL OF 3 FLOWBACK TANKS RIGGED UP. 11:00 - 11:30 0.50 WHSUR P DECOMP RIG EVACUATION DRILL - ALL PERSONEL ON LOCATION ACCOUNTED FOR - ALL ARRIVE AT SIGN IN TRAILER BECAUSE BLAST SHACK NOT YET ON LOCATION 11:30 - 13:00 1.50 WHSUR P DECOMP PRESSURE TEST HIGH PRESSURE LINES TO 250 / 3500 PSI, GOOD. CREW CHANGE AND SPCC CHECKS. 13:00 - 15:30 2.50 WHSUR P DECOMP PJSM FOR PULLING BPV. INSTALL BPV LUBRICATOR AND XO FOR 3" WELLHEAD. PRESSURE TEST LUBRICATOR 250 / 3500 PSI, GOOD. PULL BPV. LAY DOWN LUBRICATOR IN PIPE SHED, WILL USE IT LATER. Printed 5/28/2013 11:15:32AM • • • Not'Ameriat *ALAS 2 o ttOn ummairy R . Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) Start Date: 5/12/2013 End Date: 5/17/2013 X4- 00XMM: (1,410,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/27/1997 12:00:00AM Rig Release: 5/17/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 30 : 20 3/6/1998 15:00 ©37.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 21:00 5.50 WHSUR P DECOMP PJSM WITH RIG CREW AND CH2 DRIVERS FOR CIRCULATION WELL KILL. START CIRC KILL AS PER WELL PLAN, BLEED OFF GAS FROM IA. - WSL / TOOL PUSHER VERIFY VALVE ALIGNMENT. - SITP = 1200 PSI, SICP = 1290, SIOA = 200 PSI - BLEED GAS FROM IA F/ 1290 PSI T/ 250 PSI IN 10 MIN. SITP = 1200 PSI - GAS & LIQUID RETURNS. - PUMPED 110 BBLS 10.9 PPG HEATED BRINE AT 3 BPM WITH 1350 PSI DOWN THE TBG THROUGH CHOKE SKID TO FLOW BACK TANKS. - FLUID TO SURFACE AFTER 17 BBLS PUMPED. - ICP = 900 PSI - FCP = 1100 PSI - BULL HEAD ON THE FLY, 20 BBLS KWF DOWN THE TBG AT 3 BPM / 1450 PSI. MONITOR WELL SHUT IN FOR 5 MINUTES. - SITP AFTER 5 MINUTE = 0 PSI - SICP = 950 PSI. PUMP 800 BBLS 10.9 PPG BRINE AT 5 BPM AND 2900 PSI DOWN THE TUIBING 1 THROUGH CHOKE SKID TO FLOW BACK TANKS - HEAVY OIL RETURNS AT TANK & IN RETURN LINE - 10.9# BRINE MEASURED IN RETURN LINE AT 650 BBLS PUMPED DURING 800 BBL CIRCULATION - PUMPS OFF @ 20:15, TBG= 50 PSI, IA = 150 PSI MONITOR FOR 45 MINUTES - TBG STATIC AND IA SHOWING SLIGHT FLOW OF BRINE WHEN NEEDLE VALVE IS OPENED STRAP ON RETURN TANK SHOWS 750 BBLS OUT OF 800 PUMPED IN CIRCULATION PART OF WELL KILL. 21:00 - 22:00 1.00 WHSUR P DECOMP CIRCULATE ADDITIONAL 30 BBLS 10.9 PPG BRINE - PUMPED 30 BBLS 10.9 PPG HEATED BRINE AT 3 BPM WITH 1100 PSI DOWN THE TBG THROUGH CHOKE SKID TO FLOW BACK TANKS. - SHUT DOWN PUMPS AT 21:45, MONITOR WELL - 18 BBLS 10.9 PPG BRINE RETURNED - AFTER 15 MINUTES BOTH TBG AND IA ON A VACUUM. - 185 BBLS KWF LOST TO FORMATION DURING KILL Printed 5/28/2013 11:15:32AM • • 'North America- w ALASKA = BP Pege,3 c 7. • Operation Summary Retort Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) Start Date: 5/12/2013 End Date: 5/17/2013 X4- 00XMM: (1,410,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/27/1997 12:00:00AM Rig Release: 5/17/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 30 : 20 3/6/1998 15:00 @37.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:30 1.50 WHSUR P DECOMP RIG DOWN KILL MANIFOLD - BLOW DOWN LINES - RIG DOWN CIRCULATING LINES & KILL MANIFOLD - R/U SECONDARY KILL LINE 23:30 - 00:00 0.50 WHSUR N WAIT DECOMP WAIT ON WELL SUPPORT - WS EN ROUTE FROM PREVIOUS JOB 24 HR LOSSES = 185 BBLS KWF 5/13/2013 00:00 - 01:30 1.50 WHSUR P DECOMP PRE -TOUR & WEEKLY SAFETY MEETING WITH 'D' CREW SPCC CHECKS PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC - M/U LUBRICATOR & TEST 250 PSI LOW AND 3500 PSI LOW FOR 5 MINS EACH , CHARTED - SET TWC - LAY DOWN LUBRICATOR 01:30 - 02:00 0.50 WHSUR P DECOMP PRESSURE TEST TWC - PERFORM ROLLING TEST BELOW TWC. - PUMP DOWN IA @ 1 -1/2 BPM AND 600 PSI FOR 10 MINS, CHARTED MIN. (22 BBLS KWF PUMPED) - TEST TWC FROM ABOVE 250 PSI LOW & 3500 PSI HIGH FOR 5 MINS EACH , CHARTED. 02:00 - 03:00 1.00 WHSUR P DECOMP PJSM TO DRAIN AND NIPPLE DOWN TREE & N/U BOPE - NIPPLE DOWN FMC ADAPTER FLANGE & 2 9 /16 ",5MTREE - FMC REP CLEAN AND INSPECT 2 -7/8" LEFT HAND ACME HANGER THREADS - CONFIRM 9 TURNS BY HAND 03:00 - 06:00 3.00 WHSUR P DECOMP - N/U 13 -5/8" 5M BOP STACK AND 7 -1/16" x 13 -5/8" ADAPTER FLANGE. - INSTALL TURNBUCKLES AND FLOW NIPPLE. - RE- ENERGIZE ACCUMULATOR SYSTEM. - R/U TEST EQUIPMENT - R/U 2 7/8" AND 4" TEST JOINTS AND FLOOR VALVES AOGCC ,BOB NOBLE, WAIVED STATE'S RIGHT OF WITNESS BOP TEST 06:00 - 13:00 7.00 BOPSUR P DECOMP TEST BOPS TO 250 / 3500 PSI AS PER WELL PLAN. TEST FLOOR VALVES AND CHOKE LINE VALVES. TEST IS WITNESSED BY TOOLPUSHER AND WSL. WHILE TESTING, RIG UP ESP SHEAVE AND TRUNK. INSTALL COMPENSATORS ON TOP DRIVE. 13:00 - 14:30 1.50 WHSUR P DECOMP PJSM FOR PULLING TWC. INSTALL OFFSET LUBRICATOR WITH 2 -7/8" LH ACME PIN ON BOTTOM. DRIFT PIN CONNECTION WITH BPV PRIOR TO MAKING UP TO LUBRICATOR. PRESSURE TEST OFFSET LUBRICATOR 250 / 3500 PSI, GOOD. PULL TWC. Printed 5/28/2013 11:15:32AM • • • AtASKA.BP 4 cd 1 tOttetailOWSUMmittyikeport Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) Start Date: 5/12/2013 End Date: 5/17/2013 X4- 00XMM: (1,410,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/27/1997 12:00:00AM Rig Release: 5/17/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 30 : 20 3/6/1998 15:00 ©37.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 15:30 1.00 WHSUR P DECOMP INSTALL LANDING JT IN HANGER THEN SCREW INTO TOP DRIVE. PJSM FOR PULLING HANGER TO FLOOR. PICK UP TO UNSEAT HANGER. UP WT IS 116K TO START MOVING THEN BREAKS BACK TO 107K. (INCLUDES 40K BLOCK WT) PULL HANGER TO FLOOR, REMOVE FIRST CLAMP AND CUT CABLE AT SECOND CLAMP. RIH TO PLACE CLEAN PIPE ACROSS BOPS. 15:30 - 17:00 1.50 WHSUR P DECOMP CLOSE ANNULAR, CIRCULATE 3 BPM THROUGH MGS AND CHOKE. ABOUT 10 BBLS OF CRUDE RETURNS THEN RETURNS CLEAN UP ENOUGH TO GO BACK TO PITS. SHUT DOWN AND OPEN ANNULAR. LOST 20 BBLS DURING THE CIRCULATION. FLOW CHECK WELL FOR 10 MIN. FLUID IS FALLING IN THE STACK. LAY DOWN HANGER 17:00 - 18:00 1.00 WHSUR N DECOMP WAIT ON 2 -7/8" TUBING SLIPS SLIPS OFF LOCATION WELL IS TAKING 8 BBUHR. TURN ON CONTINUOUS HOLE FILL. 18:00 - 21:00 3.00 PULL P DECOMP SLIPS ON LOCATION POOH WITH 2 -7/8" EUE 8RD TUBING - PULL 2 STANDS - RESTRING ESP CABLE OVER SHEAVE USING DRILL LINE SNAKE ANCHORED TO CABLE. - DOYON SOP FOLLOWED FOR PULLING CABLE OVER SHEAVE - ATTACH ESP TO REEL IN SPOOLING UNIT. 21:00 - 21:30 0.50 PULL P DECOMP KICK WHILE TRIPPING DRILL MR: - USED 5 FT SECTION OF OLD ESP CABLE TO CUT - GOOD REACTION AND STATION PLACEMENT BY CREW 21:30 - 00:00 2.50 PULL P DECOMP POOH WITH 2 -7/8" EUE 8RD TUBING AND ESP ASSEMBLY - POH WITH TUBING & ESP CABLE - F/ 18801' MD. TO THE ESP ASSEMBLY (56 FT) - MAINTAIN -8 BPH HOLE FILL W/ 10.9 PPG BRINE. 24 HR LOSSES = 199 BBLS KWF 5/14/2013 00:00 - 01:30 1.50 PULL P DECOMP PRE -TOUR AND SPCC CHECKS POOH WITH 2 -7/8" EUE 8RD TUBING AND ESP ✓ ASSEMBLY - POH FROM - 12,400' MD - POH WITH TUBING AND ESP CABLE 01:30 - 02:30 1.00 PULL P DECOMP SPOOL CHANGE IN SPOOLING UNIT - MILNE POINT LOADER CALLED - CENTRILIFT CHANGING SPOOLS 02:30 - 06:30 4.00 PULL P DECOMP POOH WITH 2 -7/8" EUE 8RD TUBING AND ESP ASSEMBLY - POH FROM - 11,500' MD - POH WITH TUBING AND ESP CABLE Printed 5/28/2013 11:15:32AM • • • N -jam Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) Start Date: 5/12/2013 End Date: 5/17/2013 X4- 00XMM: (1,410,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/27/1997 12:00:00AM Rig Release: 5/17/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 30 : 20 3/6/1998 15:00 (g37.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 10:30 4.00 PULL N WAIT DECOMP STOP OPERATIONS AT 5800 FT. - DUE TO PHASE II CONDITIONS AND MAIN ROADS BEING DRIFTED IN CALL WAS MADE TO STOP OPERATIONS - STAB SAFETY VALVE ON 2 -7/8" TUBING - CONTINUAL HOLE FILL AT 8 BPH - 340 BBLS KWF ON LOCATION 10:30 - 16:00 5.50 PULL P DECOMP DISCUSS ROAD CONDITION WITH MPU AND KUPARUK ROAD AND PADS. SPINE ROAD AND MPU ACCESS RD HAVE BEEN CLEARED AND THEY INTEND TO CONTINUE WORKING TO KEEP IT OPEN. DISCUSS WITH RWO SUPT, RETURN RIG TO WORK. CONTINUE PULLING 2 -7/8" COMPLETION. 16:00 - 19:00 3.00 PULL P DECOMP PULL LAST STAND OUT. UD JT WITH HOLES PUNCHED IN IT. 10 MIN FLOW CHECK THEN UD REMAINING JT. PULL ESP PUMP TO RIG FLOOR. SLB SLICKLINE PUTS SCREENED ORIFICE IN GLM IN PIPE SHED. - SPOOL UP AND R/D ESP CABLE, R/D ESP TRUNK - CLAMPS RECOVERED = 461 - 2' CANNON, 1 - 1/2 CLAMP, 3 - FLAT GUARDS, 5 - PROTECTOLIZERS 19:00 - 21:00 2.00 PULL P DECOMP CLEAR / CLEAN RIG FLOOR / MOBILIZE TOOLS - REMOVE OLD AND LOAD NEW ESP REEL IN SPOOLING UNIT - REMOVE OLD ESP MOTOR AND PUMP ASSY FROM PIPE SHED - MOBILIZE NEW ESP EQUIPMENT TO RIG FLOOR 21:00 - 23:30 2.50 RUNCOM P RUNCMP PJSM WITH CENTRILIFT REP ON M/U OF MOTOR AND PUMP ASSY - M/U PUMP AND MOTOR ASSY - SERVICE NEW MOTOR AND SEALS 23:30 - 00:00 0.50 RUNCOM P RUNCMP MOBILIZE I -WIRE TO RIG FLOOR - ATTACH I -WIRE TO SENSOR AT BOTTOM OF MOTOR AND TEST SAME - OA= 180PSI - FLUID LOSS = 6 BPH - 24 HOUR FLUID LOSS = 161 BBLS, 10.9 BRINE 5/15/2013 00:00 - 04:00 4.00 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - CONTINUE M/U ESP MOTOR, PUMP AND SENSOR ASSY - SERVICE PUMP AND SEALS - STRING ESP CABLE OVER SHEAVE AND CONNECT TO ESP ASSY - CENTRILIFT REP PERFORM CONDUCTIVITY CHECKS Printed 5/28/2013 11:15:32AM • • _ 6f? Operation: S Aeport Common Well Name: MPL -20 AFE No Event Type: WORKOVER M/ ) X4- OOXMM: 1 � 410 � 000.00 O Start Date: 5/12/2013 End Date: 5/17/2013 ( ) Y Project: Milne Point Site: M Pt L Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/27/1997 12:00:00AM Rig Release: 5/17/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 30 : 20 3/6/1998 15:00 @37.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 06:00 2.00 RUNCOM P RUNCMP RIH WITH 2 7/8" 6.5# EUE 8RD ESP ✓ COMPLETION - RIH FROM ESP ASSY TO 1408' - INSTALL CANNON CLAMPS ON FIRST 375 JOINTS, THEN EVERY OTHER JT. THEREAFTER 06:00 - 12:00 6.00 RUNCOM P RUNCMP CONTINUE RIH WITH 2 7/8" ESP COMPLETION FROM 1408' TO 7852' MD TEST ESP CABLE AND PUMP 5 BBLS DOWN TUBING EVERY 2000 FT. 2000 FT, 1 BPM = 40 PSI. 4000 FT, 1 BPM = 60 PSI. 6000 FT, 1 BPM = 70 PSI. 8000 FT, 1 BPM = 90 PSI. 12:00 - 15:00 3.00 RUNCOM P RUNCMP STOP AT 7852' MD FOR CABLE SPLICE. MAINTAIN CONTINUOUS HOLE FILL AT 5 BPH. 15:00 - 23:00 8.00 RUNCOM P RUNCMP PJSM THEN CONTINUE RIH WITH 2 7/8" ESP COMPLETION FROM 7852' TO 15803' MD PUMP 1 BPM AT 9800 FT IS 110 PSI. - CREW HELD SIMULTANEOUS SPILL DRILL AND FIRE DRILL WHILE RUNNING COMPLETION 23:00 - 00:00 1.00 RUNCOM P RUNCMP REMOVE EMPTY ESP SPOOL FROM SPOOLING UNIT - INSTALL NEW ESP SPOOL - MAKE REEL TO REEL ESP SPLICE AND TEST SAME - OA = 170 PSI - FLUID LOSS = 4 BPH - 24 HOUR FLUID LOSS = 109 BBLS, 10.9 BRINE 5/16/2013 00:00 - 04:00 4.00 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - MAKE REEL TO REEL ESP SPLICE AND TEST SAME 04:00 - 06:00 2.00 RUNCOM P RUNCMP RIH WITH 2 7/8" 6.5# EUE 8RD ESP ✓ COMPLETION - RIH FROM 15803' TO 18505' (AT 6:00) - INSTALL CANNON CLAMPS ON EVERY OTHER JT - CHECK CONDUCTIVITY AND BREAK CIRCULATION, 5 BBL AT .5 BPM EVERY 2000' 06:00 - 08:00 2.00 RUNCOM P RUNCMP CONTINUE RIH WITH 2 7/8" 6.5# EUE 8RD ESP COMPLETION. CIRCULATE FINAL TIME AT 18650 FT, 1 BPM = 160 PSI. 08:00 - 10:00 2.00 RUNCOM P RUNCMP PICKUP FINAL STAND AND GLM. MAKE UP LANDING JT AND TUBING HANGER WITH PUP JT. TERMINATE ESP CABLE WITH A PLUG AND MAKE UP PLUG TO PENETRATOR. TEST ALL CONNECTIONS, GOOD. 10:00 - 10:30 0.50 RUNCOM P RUNCMP RIH SLOWLYAND LAND HANGER. UP WT IS 107K, DOWN WT IS 62K. (INCLUDES 40K BLOCK WEIGHT) FMC RUN IN LOCK DOWN SCREWS. Printed 5/28/2013 11:15:32AM • • North A r n e - ALASKA- BP P 7 of7 Operation mary Report Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) Start Date: 5/12/2013 End Date: 5/17/2013 X4- 00XMM: (1,410,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: DOYON 16 Spud Date/Time: 7/27/1997 12:00:00AM Rig Release: 5/17/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 30 : 20 3/6/1998 15:00 ©37.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 12:00 1.50 RUNCOM P RUNCMP UD LANDING JT. DRY ROD IN TWC. TEST FROM BELOW TO 500 PSI. VISUALLY CONFIRM NO LEAKS PAST TWC. TEST FROM ABOVE AGAINST BLIND RAMS, 250 / 3500 PSI, GOOD. BOTH TESTS CHARTED. 12:00 - 17:00 5.00 BOPSUR P RUNCMP VAC FLUID OUT OF STACK PREP TO REMOVE BOP STACK REMOVE BLIND RAMS AND PIPE SLIP RAMS TO PREP FOR CHANGEOVER TO 3 PREVENTER STACK 17:00 - 18:00 1.00 BOPSUR P RUNCMP PJSM, CUT AND SLIP 82' DRILLING LINE. - CLEAN PITS 18:00 - 20:00 2.00 BOPSUR P RUNCMP PJSM, N/D BOP AND N/U TREE - REMOVE ALL ACCUMULATOR LINES - REMOVE CHOKE AND KILL LINES - N/D BOPE AND STAND BACK ON PEDESTAL 20:00 - 23:00 3.00 WHSUR P WHDTRE N/U FMC ADAPTER AND 2 9/16" CAMERON TREE - CENTRILIFT REP MAKE FINAL CONDUCTIVITY CHECKS ON ESP CABLE - N/U TUBING HEAD ADAPTER AND TREE - FMC REP TEST ADAPTER VOID, 5000 PSI, 30 MINUTES - TEST TREE TO 250 / 5000 PSI, 5 MIN, CHARTED - WSL WITNESSED = GOOD TESTS J - PREP RIG FLOOR TO LAY DERRICK OVER 23:00 - 00:00 1.00 WHSUR P WHDTRE PJSM, M/U WELL SUPPORT LUBRICATOR TO PULL TWC - TEST LUBRICATOR TO 250 / 3500 PSI, 5 MIN CHARTED - OA = 140 PSI - FLUID LOSS = 4 BPH - 24 HOUR FLUID LOSS = 57 BBLS, 10.9 BRINE 5/17/2013 00:00 - 04:00 4.00 WHSUR P WHDTRE PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - PULL TWC - RE -TEST LUBRICATOR, 250 / 3500 PSI, 5 MIN, CHARTED - INSTALL BPV - PERFORM ROLLING TEST FROM BELOW BPV, 500 PSI FOR 10 MIN, CHARTED - CLEAN PITS AND CUTTINGS TANK, PULL CUTTINGS TANK AWAY FROM RIG - PREP RIG FLOOR TO LAY DERRICK OVER - PREP RIG FOR RIG MOVE - RELEASE RIG AT 4:00 Printed 5/28/2013 11:15:32AM ` Tree: 2 9/16" - 5M F MPU L -20 Orig. v. = 49.85' (N22E) Wellhead:11" x 7" 5M Gen 5a _ Orig. G ley. =16.8' w/ 2 7/8" WKM Tubing Hanger , w/ 3" DF To Tbg. Spool = xxx' (N22E) Acme Threads , 2.5" CIW H BPV profile 20" 91.1 PP f H -40 112' Camco 2 -7/8" x 1" 142' KBMM GLM w /DSOV KOP @ 400' Max. hole angle = 76 to 79 deg. f/ 3500' to TD 9 5/8" Howco 'ES' Hole angle thru' perfs = 33 deg O 2123' Cementer 9 5/8 ", 40 ppf, L -80 Btrc. 8160' and / 1 m 7" Howco 'ES' Cementer 10,447' Two 7" x 21' short joints from 18,568' to 18,610' and 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ; 2 7/8" HES "XN" Nipple 18,698' ( drift ID = 2.347 ", cap. = 0.00592 bpf) (2.250" ID) 7 ", 26 ppf, L -80, Btrc. Mod. prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf) Auto Diverter Valve 18,740' 4.5" 12.6 ppf, L -80 Mod ( drift ID = 3.958" , cap = .0152 bpf) Discharge Head: GPVDIS 18,750' Centrilift ESP Intake TVD - 6457' til 137 -P17 SXD 18,751' Intake MD - 18733' 4.5" Liner Top TVD - 6493' _ £ . Intake Gas Separator: 18,769' GRSFTXARH6 4.5" Liner Top MD - ,18838' T andem Seal Section: Mid pert TVD 6697' 1 18,774` Mid -perf MD - 19385' GSB3DBUT /LT SB /SB PFSA /FSA CL5 PBTD TVD - 6'et5' Motor: Model MSP1-250 18 788` PBTD MD - 19600' 210 HP rerated to 150 hp MOM 2205 volt /41 Amp (� Well lift MGU sensor 18,807' Stimulation Summary ® w/6 fin Centralizer 03/11/98 - Kup. A Sand - 104 M# 20/40 Carbolite & 35 M# of PropLok coated 16/2 Carbolite behind pipe C 7 "x 4.5" Baker "ZXP" Pkr. Perforation Summar "HMC" Hydraulic liner hange' 18,838' 1 Ref log: Anadrill LWD 8/2/97 I 18,852' 7 "x5" Baker liner hanger Size SPF Interval (TVD) 1 7" float shoe I 19,104' 1 2 -7/8" 6 19370' -19400 61016' X RA Tag I 19,192' TCP shot .NOTE: Confirmed significant support from Conoco's KRU 30 -07 and 30 -14. These weirs must be SI to stabilize BHP and determine mud wt. A request to CPI Fill Clean out @ 19,600' 6/14/10 needs to be initiated to ensure that the wells are SI _ _ by Nabors 4ES(no fill) > 4 weeks prior to RWO. 4.5" landing collar 19,600' 4 I. 4.5" Float collar 19,684' 4.5" Float shoe 19,770' DATE REV. BY COMMENTS 08/31/97 JBF D and Cased b Nabors 22E 03/22/98 M. Linder Cnmoletion Nabor -ES MILNE POINT UNIT 07/24/01 B. Hasebe RWO Nabors 4ES 06/20/06 R. Handy RWO Nabors 4 -ES WELL L -20 07/24/06 L. Hulme RWO Nabors 3S 11/28/07 REH RWO Nabors 4ES API NO: 50- 029 -22790 6/14/10 REH RWO Nabors 4ES 3/26/11 B. Bixby RWO Dovon 16 05/19/13 B.Kruskie RWO Doyon 16 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 ` Mr. Tom Maunder (� Alaska Oil and Gas Conservation Commission \G 1 0 333 West 7 Avenue r - 1O Anchorage, Alaska 99501 - Subject: Corrosion Inhibitor Treatments of MPL -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPL -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. ....... Sincerely, a4 7 - ------ ,--- Mehreen Vazir BPXA, Well Integrity Coordinator � ■ • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPL -Pad Date: 10 /08/11 1 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPL -01A 2030640 50029210680100 Sealed conductor N/A N/A N/A N/A NA MPL -02A 2091470 50029219980100 Sealed conductor N/A N/A N/A N/A NA MPL -03 1900070 50029219990000 Tanko conductor N/A N/A N/A NIA NA MPL-04 1900380 50029220290000 Sealed conductor N/A N/A N/A N/A NA MPL -05 1900390 50029220300000 Sealed conductor N/A N/A N/A N/A NA MPL -06 1900100 50029220030000 Sealed conductor N/A N/A N/A N/A NA MPL -07 1900370 50029220280000 Sealed conductor N/A N/A N/A N/A NA MPL -08 1901000 50029220740000 Sealed conductor N/A N/A N/A N/A NA MPL -09 1901010 50029220750000 Sealed conductor N/A N/A N/A N/A NA MPL -10 1901020 50029220760000 Sealed conductor N/A N/A N/A N/A NA MPL -11 1930130 50029223360000 Sealed conductor N/A N/A N/A N/A NA MPL -12 1930110 50029223340000 Sealed conductor N/A N/A N/A N/A NA MPL -13 1930120 50029223350000 Sealed conductor N/A N/A N/A N/A NA MPL -14 1940680 50029224790000 Sealed conductor N/A N/A N/A N/A NA MPL -15 1940620 50029224730000 3.3 N/A 3.3 N/A 15.3 8/9/2011 MPL -16A 1990900 50029225660100 23 Needs top job MPL -17 1941690 50029225390000 0.2 N/A 0.2 N/A 5.1 9/1/2011 --' MPL -20 1971360 50029227900000 0.4 N/A 0.4 N/A 3.4 8/10/2011 MPL -21 1951910 50029226290000 1.7 N/A 1.7 N/A 8.5 8/10/2011 MPL -24 1950700 50029225600000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -25 1951800 50029226210000 1.7 N/A 1.7 N/A 15.3 8/10/2011 MPL -28A 1982470 50029228590100 0.3 N/A 0.3 N/A 8.5 10/8/2011 MPL -29 1950090 50029225430000 0.5 N/A 0.5 N/A 3.4 8/7/2011 MPL -32 1970650 50029227580000 0.5 N/A 0.5 N/A 5.1 8/10/2011 MPL -33 1971050 50029227740000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -34 1970800 50029227660000 1.7 N/A 1.7 N/A 8.5 8/9/2011 MPL -35A 2011090 50029227680100 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL-36 1971480 50029227940000 0.1 N/A 0.1 N/A 7.6 9/1/2011 MPL -37A 1980560 50029228640100 6 N/A 6 N/A 47.6 8/13/2011 MPL -39 1971280 50029227860000 1.7 N/A 1.7 N/A 6.8 8/8/2011 MPL -40 1980100 50029228550000 1 N/A 1 N/A 6.8 8/8/2011 MPL-42 1980180 50029228620000 5.3 N/A 5.3 N/A 30.6 8/14/2011 MPL-43 2032240 50029231900000 17.5 Needs top job MPL-45 1981690 50029229130000 10 N/A _ 10 N/A 8.5 8/10/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT�F SUNDRY WELL OPERA NS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ■= Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number. BP Exploration (Alaska) Inc. ® Development ❑ Exploratory `" 197 - 136 3. Address: ❑ Service ❑ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 0 50 - 029 - 22790 - 00 - 00 7. Property Designation: 8. Well Name and Number. ADL 025514 d .. MPL - 9. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 19770' feet Plugs (measured) None feet true vertical 7022' feet Junk (measured) None Effective depth: measured 19601' feet Packer. (measured) None feet true vertical 6873' feet Packer. (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' 1490 470 Surface 8123' 9-5/8" 8160' 3546' 5750 3090 Intermediate Production 19071' 7" 19104' 6462' 7240 5410 Liner 932' 4-1/2" 18838' - 19770' 6248' - 7022' 8430 7500 Perforation Depth: Measured Depth: 19370' - 19400' k.vs True Vertical Depth: 6676' - 6701' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 18806' 6224' Packers and SSSV (type, measured and true vertical depth): None SCE d pl squeeze summary: � 11. Stimulation or cement s q ry� . ,la j`f . Intervals treated (measured): , V u " Treatment description including volumes used and final pressure: Lu �� MS I0fl fkncn 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 425 101 843 260 273 Subsequent to operation: 408 93 880 240 264 13. Attachments: 14. Well Class after work: ❑ Copies of Logs and Surveys run ❑ Exploratory ti Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ 0 Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 N/A Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number Signature �� Phone 564 - 4628 Date °4 / 4° 11( Teme Hubble, 564 -4628 Form 10-404 Revised 10/2010 RBDMS APR 2 2 2011 S ' 2 •f! Submit Original Only /4 • • North America - ALASKA - BP ,' Page of 8 Operation Summary Report Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) I Start Date: 2/18/2011 I End Date: 3/25/2011 X4- 00T93 -E: (1,250,000.00 ) ~ Project: Milne Point Site: M Pt L Pad -r 'I Rig Name /No.: DOYON 16 Spud Date/Time: I Rig Release: 3/25/2011 Rig Contractor: DOYON DRILLING INC. I UWI: Active Datum: 30 : 20 3/6/1998 15:00 @37.20ft (above Mean Sea Level) Date From - To I Hrs 1 Task Code ' NPT I NPT Depth Phase I Description of Operations 3/18/2011 100:00 - 06:00 6.00 MOB I P PRE MOB RIG OFF OF MPC -22A 1 I I -SPOT OUT OF WAY ON C -PAD. -PREP WORK FOR CRANE OPERATIONS 1- BREAKDOWN BOPE MU DOUBLE GATE _ PREVENTER FOR (4) PREVENTER STACK 1 06:00 - 12:00 , 6.00 MOB P PRE INSTALL NEW RAMS IN DOUBLE GATE - BOP STACK UP, ANNULAR, 2 -7/8" BY 5" VBR'S, BLIND SHEARS, SOLID BODY 2 -7/8" PIPE RAMS. I- CONTINUE TO PREP RIG FOR RIG MOVE. 1 ;- 24 HOUR BOP TEST NOTIFICATION TO j 'AOGCC AT 11:30 12:00 - 15:30 3.50 MOB I P PRE PJSM WITH PEAK CRANE CREW AND RIG I CREWS , j 1- -,SET THE BELLY BOARD IN PLACE WITH THE CRANE. - SET GAS BUSTER COVER OVER THE TOP I I ION THE ROOF SECTION OF THE GAS BUSTER. 15:30 - 20:00 4.50 MOB P PRE , ' MOB RIG FROM MPC -22A TO MPL PAD. 4APROX 4 MILES FROM C PAD TO L PAD. __ 1 20:00 - 21 :00 1.00 MOB I P ' PRE I PJSM FOR REMOVING BOOSTER WHEELS ,- INSTALL BOPE ON PEDESTAL. 21:00 - 00:00 3.00 MOB I P PRE PJSM FOR RAISING THE DERRICK. 1 -RAISE AND PIN CATTLE CHUTE. 3/19/2011 00:00 - 06 :00 1 6.00 MOB P PRE MOB RIG OVER MPL -20 AND CENTER OVER , WELL AND NOT TREE. - NOTIFIED PAD OPERATOR OF MOVE OVER WELL. -900 PSI ON THE IA. - DOUBLE MATT THE RIG. LEVEL AND SET RIG 1 DOWN. -BRING OVER TIGER TANK AND CUTTING 1 BOX FROM MPC PAD TO MPL PAD ANDS SPOT. -SET RIG MATTS AND LAY HERCULITE. 1 1 06:00 - 10:30 4.50 l MOB P PRE FINISH PUTTING THE IN PINS THE BELLY BOARD - MAKE UP HARDLINE TO THE TIGER TANK 1 HOOK UP THE CIRCULATION LINES TO THE MANI O F LD IN THE CELLAR. MADE A FOLLOW UP CALL TO AOGCC FOR NOTICE OF INITIAL BOP TESTING. LEFT MESSAGE ON THE PAGER RECIEVED NO CALL BACK. - LEFT A MESSAGE AT 07:30 -- 10 :30 - 11:00 ! 0.50 RIGU P DECOMP PU & MU LUBRICATOR PJSM. - PRESSURE TEST 250 PSI LOW AND 4,000 HIGH Printed 4/20/2011 4:03:47PM art America '- ALASKA BP Pag6 pertti ©n Summary Report • Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) Start Date: 2/18/2011 End Date: 3/25/2011 X4- 00T93 -E: (1,250,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 3/25/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 30 : 20 3/6/1998 15:00 @37.20ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ! (ft) 11:30 - 12:00 0.50 WHSUR P DECOMP RIG EVACUATION DRILL. - HIGH H2S - DRILL WAS CALLED, ALL PERSONNEL MUSTERED TO THE CORRECT LOCATION A HEAD COUNT WAS TAKEN AND ALL j PERSONNEL WERE ACCOUNTED FOR. RWO SUPT ELEVATED THE DRILL TO A LEVEL 1 AT THIS POINT. AAR: IT WAS BROUGHT TO LIGHT THAT WE DID NOT HAVE THE PROPER NOTIFICATION CHARTS IN THE SIGN IN SHACK. ANOTHER GAP WAS WE HAD ONE PERSON IN THE EVACUATION SUPPLIED AIR. WE SHOULD HAVE HAD TWO PEOPLE IN ORDER TO UTILIZE THE BUDDY SYSTEM RIG ACCEPTED AT *** 12:00'"" MADE SECOND FOLLOW UP CALL TO THE AOGCC @ 1150. RECIEVED CALL BACK FROM CHUCK SCHEVE, HE TOLD US THAT HE WAS GOING TO WAIVE RIGHT TO WITNESS. 2.00 -- -- -- - 12:00 - 14:00 WHSUR P DECOMP I LWELL SUPPORT PULLED BPV H. SET BACK THE LUBRICATOR ON THE FLOOR. 14:00 - 21 :00 7.00 WHSUR P DECOMP ! PJSM TESTING LINES AND KILL WELL. -TEST ALL SURFACE LINES TO 3500 PSI. CHASE AND REPAIR LEAKS. -BRING OUT GREASE CREW AND GREASE TREE VALVES. - DISCUSS WITH TOWN ENGINEER AND DECIDED TO PSI TEST LINES TO 4000 PSI. - RETEST LINES TO 4000 PSI. GOOD TEST. HELD AAR FOR SURFACE TESTING OF SURFACE LINES. 21:00 - 22 :00 1.00 WHSUR P DECOMP j BLEED OFF GAS FROM IA THROUGH CHOKE. 1 SHUT IN WHP'S, TBG =840 PSI, IA =920 PSI, 1 0A=0 PSI. -BLEED IA DOWN TO 750 PSI. -BLEED TBG DOWN TO 700 PSI. -SITP BUILT TO 750 PSI 1 22:00 - 00:00 !. 2.00 WHSUR P DECOMP ATTEMPT TO KILL WELL WHEN TOTCO HAD I TO BE REBOOTED AS IT WAS NOT TRACKING PUMP STROKES OR PUMP PSI. -START PI IMPING 115 BBLS OF 10.6 PPG 120 DEGREE (NACL) (NABR) BRINE DOWN THE TBG © 4 BPM WITH 2450 PSI. TOOK 25 BBLS TO CATCH FLUID. -BULL HEAD 42 BBLS OF 10.6 PPG BRINE AT 4 BPM AND 2840 PSI. - OPENED ANNUALAR AND CIRCULATED 600 BBLS THE LONG WAY THROUGH CHOKE AT — — 4 BPM AND 1850 PSI. 3/20/2011 00:00 - 03:00 3.00 I WHSUR P DECOMP - CONTINUE TO CIRCULATE THE LONG WAY THROUGH CHOKE AT 4 BPM AND 1850 PSI. -FCP AT 4 BPM IS 1970 PSI ON TUBING AND 40 PSI ON IA. 03:00 - 03:30 0.50 WHSUR P DECOMP !, MONITOR WELL FOR 30 MIN. 1 -20 PSI ON THE IA , 0 PSI ON THE TBG Printed 4/20/2011 4:03:47PM North America - ALASKA - BP Page 3; of a 1ration S umma Report rY F : Common Well Name: MPL -20 I AFE No Event Type: WORKOVER (WO) I Start Date: 2/18/2011 End Date: 3/25/2011 X4-00T93-E: (1,250,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 3/25/2011 Rig Contractor: DOYON DRILLING INC. 1UWI: Active Datum: 30 : 20 3/6/1998 15:00 @37.20ft (above Mean Sea Level) ( ) ' P (ft) p � Description of O Date From - To Hrs Task Code 1 h _ NPT NPTe Depth Phase Operations —_ -_. — , 03 :30 06:00 2.50 WHSUR i DECOMP CIRCULATE ANOTHER HOLE VOLUME 600 BBLS -PUMP AT 4.3 BPM AND 2750 PSI. 1 - DYNAMIC LOSS RATE OF 35 BPH AT THE (ABOVE PUMP RATE. SHIPPED OUT 100 BBLS OF CRUDE SENT TO MP CFP. 06:00 - 07:30 1 1.50 WHSUR P I DECOMP MONITOR WELL FOR 30 MIN. 1 - BOTH THE TBG AND IA ON A VACUUM. [ t -INITIAL STATIC LOSS RATE OF 10 -12 BPH. - 07:30 - 09:00 1.50 WHSUR P 1 DECOMP PU & MU DSM LUBRICATOR 1 '- PJSM FOR LUBRICATING IN THE 2 -1/2" "H" i STYLE TWC. , l_DSM INSTALLED TWC 09:00 - 12:00 3.00 WHSUR ' P DECOMP PRESSURE TESTING, THE TWC i 1- PERFORMED ROLLING 500 PSI PRESSURE TEST FROM BELOW, MAINTAINING 500 PSI FOR 5 MIN PUMPING @ 2 BPM. - ATTEMPTED 10 MIN 4000 PSI TEST FROM (ABOVE. COULD NOT GET TO TEST TO FLAT LINE. CHECKED ALL THE LINES AND VALVES, ,- CALLED OUT GREASE CREW TO GREASE (THE VALVES. -INSTALLED A SECOND TWC AND RE TESTED. GOT SUCCESSFUL 500 PSI ROLLING TEST FOR 5 MIN AND GOT SUCCESSFUL 4000 PSI 10 MIN TEST FROM ABOVE. i t I- CONTINUOUSLY FILLING HOLE DURING j PRESSURE TESTING OPERATIONS AT 10 I BPH 12:00 - 15:30 3.50 WHSUR ' P DECOMP 11 FINISHED WITH SUCCESSFUL TWC TEST - RD LUBRICATOR AND TEST EQUIPMENT. ! - STATIC LOSS RATE _____ INCREASED TO 22 BPH. I — 1 15:30 - 17:00 1.50 WHSUR P DECOMP NIPPLE DOWN TREE AND ADAPTER FLANGE, SET BACK IN CELLAR - TOOK A MEASUREMENT OF THE PENETRATOR STICK UP ABOVE THE FLANGE- 8.25" I I 7-1/16" X 13 -3/8" DSA _ _ I ' - NU 117:00 21:30 4.50 P I DECOMP NU 13 -5/8" "GK" HYDRILL BOP I BOPSUR STACK CONFIGURATION FROM TOP "GK" ANNULAR, 2 -7/8" BY 5" VBR'S, BLIND SHEARS, MUD CROSS, 2 -7/8" SOLID BODY PIPE RAMS -19:30 Hrs. MAINTAIN CONTINUOUS HOLE FILL WITH A 17 BPH LOSS RATE. -20:15 Hrs. LOSS RATE DROPPED TO 9 BPH. — - 21:30 00 :00 2.50 BOPSUR 50 BOPS PSI OW AND � -- P � DECOMP '� TEST BOPE TO 250 PSI LOW A 4000 PSI i HIGH FOR 5 MIN EACH. I -TEST 2 -7/8" TIW VALVES, DART VALVES. -TEST RAMS W/ 2 -7/8" TEST JTS. -TEST ANNULAR W/ 2 -7/8" TEST JT TO 250 PSI LOW AND 3500 PSI HIGH. 1 - AOGCC, CHUCK SHEVE, WAIVED WITNESS. -ALL TESTS WITNESSED BY BP WSL & DDI 1 TP. 1 I 1-MAINTAIN CONTINUOUS HOLE FILL AT 12 BPH LOSS RATE. Printed 4/20/2011 4:03:47PM North mer L BP ` Page f o aeration Summary Report Common Well Name: MPL -20 I AFE No Event Type: WORKOVER (WO) 1 Start Date: 2/18/2011 End Date: 3/25/2011 , X4- 00T93 -E: (1,250,000.00 ) Project: Milne Point ! Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 3/25/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 30 : 20 3/6/1998 15:00 @37.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth I Phase I Description of Operations (hr) ft O I 3/21/2011 1 00:00 - 06:00 6.00 BOPSUR P DECOMP TEST BOPE TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MIN EACH. -TEST 2 -7/8" TIW VALVES, DART VALVES. 1-TEST RAMS W/ 2 -7/8" TEST JTS. , -TEST ANNULAR W/ 2 -7/8" TEST JT TO 250 PSI LOW AND 3500 PSI HIGH. - KOOMEY TEST: IP OF 2900 PSI, DROP TO I� Q OP 1700 PSI, 200 PSI GAIN IN 21 SECONDS, FINAL GAIN IN 94 SECONDS, 5 BOTTLES AT 2000 PSI, -ALL TEST PASS. - AOGCC, CHUCK SHEVE, WAIVED WITNESS. -ALL TESTS WITNESSED BY BP WS L & DDI TP. -MAINTAIN CONTINUOUS HOLE FILL OF 15 BPH LOSS RATE. 06 :00 - 12:00 6.00 CLEAN N WAIT DECOMP I WAIT ON PBU DRILL SITE MAINTENANCE. 'TRUCK BROKE DOWN. - RIG UP SHEIVE FOR ESP CABLE. - PU/ MU OPSO LOPSO AND 3 -1/2" LH ACME CROSS OVER !- MU LANDING JOINT WITH THE 3 -1/2" LH ACME XO FOR PULLING THE HANGER AND !LAY DOWN IN THE PIPE SHED. 12:00 - 17:00 ' 5.00 CLEAN P j DECOMP MU HYD LUBRICATOR TO TOP OF OPSO LOPSO. - ATTEMPT PRESSURE TEST FOR LUBRICATOR. - TEST FALLING OFF 400 -500 PSI IN 2 -3 MIN ' - 0-RINGS. - BACK OU T OPSO LOPSO FROM PROFILE TO C/O ALL OTIS CONN O- 1 C/0 ACME 0 -RING. - MADE LUBRICATOR BACK UP AND TESTED I AGAIN 1 - 250 PSI LOW AND 4000 PSI HIGH FOR FIVE I CHARTED MIN. GOT GOOD TEST CALLED WELL SUPPORT TO HAVE THE HARD I I LINE TO THE FROM THE RIG TO THE TIGER TANK CHANGED OUT. IT WAS NOTED THAT I THE HARD LINE WAS OUT OF DATE FOR INSPECTION ON THE METAL TAG. 17 00 - 17:30 0.50 CLEAN P DECOMP DRILL SITE MAINT TO PULL TWC. - MADE MANY ATTEMPTS TO PULL TWC. ! - UNSUCCESSFUL AT PULLING TWC. I - DSM BELIEVES THERE TO BE DEBRIS ON TOP OF THE TWC. 17 :30 19:30 2.00 CLEAN I P DECOMP ! BREAK OUT AND STAND BACK THE HYD LUBRICATOR - BREAK OUT THE OPSO LOPSO I I I - CLEAN OUT THE TWC PROFILE 1 - MAKE UP THE OPSO LOPSO AND — _LUBRICATOR AND RE -TEST GOOD. 19:30 - 20:30 1.00 CLEAN P DECOMP ' RIH AND LUBRICATE OUT THE TWC. -VD TWC AND LUBRICATOR. I - TBG AND IA ARE ON A VAC AVG LOSS RATE 10-18 BPH Printed 4/20/2011 4:03:47PM Nortf� Ame - AL - BP page 5 of 8 ration Summary Report Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) , Start Date: 2/18/2011 End Date: 3/25/2011 X4- 00T93 -E: (1,250,000.00 ) Project: Milne Point I Site: M Pt L Pad Rig Name /No.: DOYON 16 ; Spud Date/Time: Rig Release: 3/25/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 30 : 20 3/6/1998 15:00 @37.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ' Phase I Description of Operations (hr) _ (ft) I 20:30 - 21:30 1.00 CLEAN P DECOMP 1 M/U LANDING JOINT W/ TIW VALVE, SCREW INTO HANGER. - FMC REP BOLDS -PULL HANGER OFF SEAT AT 125K IBREAKOVER. -P /U HANGER AT 105K. _ 21:30 - 00:00 2.50 CLEAN P DECOMP !SPACE HANGER BELOW BAG. -- CIRCULATE SURFACE TO SURFACE VOLUME 1 AT 4.5.BPM AND 2890 PSI THROUGH CHOKE. -LOSS RATE WHILE CIRCULATING WAS 30 BPH CIRCULATING IN 5 DRUMS OF SAFE LUBE I TO TREAT THE ENTIRE SYSTEM I 3/22/2011 ; 00:00 - 02:32 i 2.53 CLEAN P DECOMP I L/D HANGED. - DISCONNECT ESP LINE. �- MONITOR WELL. ,- PERFORM FLOW CHECK. HOLE IS ON A VAC. 02:32 06 :00 3.47 CLEAN P DECOMP ' -POQH WITH ESP COMPLETION ON 2 -7/8" 8RD EUE TUBING F/ 18,792' STANDING BACK I IN THE DERRICK. - POOH WITH 120 JNTS. -05:00 AM - STAND 43 OUT OF HOLE LOSS -- _ [RATE OF 9 BPH. - - 06:00 - 12:00 6.00 CLEAN P DECOMP CONTINUE -POOH WITH ESP COMPLETION ON 2 -7/8" 8RD EUE TUBING STANDING BACK 1 IN THE DERRICK. - SPOOLING ESP ON SPOOLER UNIT ON THE ,GROUND. i - POOH WITH 231 JNTS. -ESP CABLE SPLICED AT STAND #114 AND I CABLE REEL IS FULL. I- MAINTAIN CONTINUOUS HOLE FILL USING 1 10.6 -PPG SODIUM BROMIDE DURING TRIP. + ' _ - AVG LOSS RATE IS AT 10-12 BPH 1 - 19:00 7.00 CLEAN P DECOMP CONTINUE POOH WITH ESP COMPLETION ON 2 -7/8" 8RD EUE TUBING. - RECOVERED 596 FULL JNTS OF 2 -7/8" EUE 8RD TUBING, 1 -XN NIPPLE, 1-GLM & A AUTO DIVERTER I - ROCOVERED 461 CANNON CLAMPS - WELL STILL ON A 10-14 BPH LOSS RATE. 19:00 - 20:30 1.50 CLEAN r P DECOMP I R/U LIFTING EQUIPMENT FOR PUMP & MOTOR. - CENTRILIFT BREAK OUT AND LD ESP ASSY IN PIPE SHED. NORM SURVEY FOR ESP ASSEMBLY 1 -BACKGROUND ON MPL PAD= 2 MILT REM -MOTOR=3 I -INTAKE =3 1 - PUMP =3 - T 20:30 21:00 0.50 CLEAN P - DECOMP ',CLEAR & CLEAN RIG FLOOR. Printed 4/20/2011 4:03:47PM ig icrtti America ALASKA- SP Page 6 of a perafiion Summary Report 7 Common Well Name: MPL -20 AFE No Event Type: WORKOVER (WO) Start Date: 2/18/2011 End Date: 3/25/2011 X4- 00T93 -E: (1,250,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 I Spud Date/Time: Rig Release: 3/25/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 30 : 20 3/6/1998 15:00 ©37.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations hr (ft) 21:00 - 22:30 1.50 CLEAN P O DECOMP MOBILIZE VENDORS TOOLS. -COMPLETE WORK ORDERS. -NORM SURVEY FOR ESP ASSEMBLY. RIH WITH ESP COMPLETION ON 2 -7/8" EUE 8RD TUBING. -USE BEST 0 LIFE 2000 THREAD COMPOUND AND MU 8RD CONNECTIONS TO OPTIMUM TORQUE OF 2300 - FTLBS. - INSTALL ONE CANNON CLAMP ON EVERY CONNECTION. I- MAINTAIN CONTINUOUS HOLE FILL. -LOSS RATE = 14 TO 18 -BPH. 22:30 - 23:00 0.50 CLEAN P DECOMP R/D TRUNK & DRAIN HOSE F/ ESP SHEAVE. RESTRING ROPE. 23:00 - 00:00 1.00 RUNCOM P RUNCMP 1'R/U & PU NEW MOTOR PUMP, FILL WITH _ I OIL 3/23/2011 1 00:00 04:00 4.00 RUNCOM] P RUNCMP { -MAKE ELECTRICAL CONNECTION TO ESP 06:00 2.00 RUNCOM ` P RUNCMP ASSEMBLY. 04:00 - 'RIH W/ NEW ESP ASSEMBLY W/ CL -6 MOTOR. ESP MOTOR IS 195 HP DERATED FROM 228 HP. 5.62 "O. D. -RUN IN W/ ESP ASSY ON 2 -7/8 ", L -80, 6.5# EUE 8RD TBG. -OPTIMAL TQ = 2300 FT /LBS. -USE BEST -O -LIFE 2000 THREAD COMPOUND. -RUN CANNON CLAMPS ON THE FIRST 375 JTS, THENEVERY OTHER JT TO SURFACE. I -CHECK CABLE FOR CONDUCTIVITY EVERY 2000'. 1 -CHECK CONDUCTIVITY EVERY CABLE SPLICE. -FILL TBG EVERY 2000' AND PUMP 10 BBLS DOWN TBG. 06:00 - 12:00 6.00 RUNCOM P - RUNCMP CONT: RIH WITH ESP COMPLETION WITH 35 STANDS OF 2 -7/8" EUE 8RD TUBING FROM THE DERRICK - FILLING TUBING AND BREAKING CIRCULATION WITH 10 BBLS - INSTALL ONE CANNON CLAMP ON EVERY CONNECTION. - MAINTAIN CONTINUOUS HOLE FILL. -LOSS RATE = 4 -5 BPH. CENTRILIFT CHECKING CONNECTIVITY 12:00 - 13:00 1.00 RUNCOM P RUNCMP UNABLE TO ESTABLISH CONNECTION - CENTRILIFT TROUBLE SHOOTING THE PROBLEM WITH T HE ESP CONNECTION . 13:00 16:00 3.00 RUNCOM - -- I - �, P RUNCMP ; CONT: RIH WITH ESP COMPLETION WITH 82 STANDS OF 2 -7/8" EUE 8RD TUBING FROM THE DERRICK- ' - - FILLING TUBING AND BREAKING CIRCULATION WITH 10 BBLS - CENTERLIFT TO CHECK CONNECTIVITY HELD KICK WHILE TRIPPING DRILL. DRILLER CALLED THE DRILL THE CREW RESPONDED HELD AAR: AFTER ACTION REVEALED TIW MAKE UP TO BE INCORRECT FOR PICKING UP THE STRING TO CUT THE ESP CABLE. 16:00 - 19:30 3.50 RUNCOM P RUNCMP REEL TO REEL SPLICE FOR ESP CABLE. Printed 4/20/2011 4:03:47PM North America - ALASKA - BP Page 't of 8 :! .. eration Summary Re Common Well Name: MPL -20 IAFE No Event Type: WORKOVER (WO) Start Date: 2/18/2011 1 End Date: 3/25/2011 X4- 00T93 -E: (1,250,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: Rig Release: 3/25/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 30 : 20 3/6/1998 15:00 @37.20ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT 1 NPT Depth j Phase Description of Operations (hr) , .. j 19:30 - 00:00 4.50 RUNCOM P F RUNCMP CONTINUE TO RIH W/ ESP ASSEMBLY ON I 2 -7/8" TBG. -TEST CONDUCTIVITY AND PUMP EVERY 2000'. -PUMP 2 BPM / 320 PSI. _ _ _ 1-HELD KICK WHILE TRIPPING DRILL W/ AAR. 3/24/2011 00:00 - 06:00 6.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ ESP ASSEMBLY ON 1 2-7/8" TBG. -TEST CONDUCTIVITY AND PUMP 10 BBLS 1 EVERY 2000', I- MAINTAINING CONT HOLE FILL DURING , TRIP IN HOLE I- AVG LOSS RATE - 3-4 BPH 06:00 - 08:00 2.00 RUNCOM P 1 RUNCMP 1 REEL TO REEL SPLICE. I I SPLICE OPERATION. PERFORMED BY CENTRILIFT REP. , - CONT HOLE FILL WAS MAINTAINED FOR 1 WELL CONTROL DURING SPLICE OPERATIONS. 08:00 - 12:00 4.00 RUNCOM P RUNCMP I RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION, RUNNING STANDS OUT OF DERRICK. USING BEST 0 LIFE 2000 PIPE DOPE, TORQUING TUBING TO 2300 FT /LBS. ,RIH WITH 198 STANDS, I - MAINTAINING CONT HOLE FILL DURING TRIP IN HOLE AVG LOSS RATE - 3-4 BPH 12:00 - 13:00 1.00 RUNCOM P RUNCMP I PJSM: PICK UP AND MAKE UP TUBING HANGER AND LANDING JOINT WITH TIW ON TOP. I I -MU PENETRATOR IN TBG HANGER SPACE OUT ESP CABLE FOR CENTRILIFT TO DO THEIR LOWER CONNECTION SPLICE 113:00 - 15 :00 2.00 RUNCOM P RUNCMP I CENTRILIFT - MAKE UP LOWER CONNECTOR SPLICE. -MAKE UP PENETRATOR IN HANGER - CONNECT LOWER CONNECTOR AND PENETRATRO -LD ESP CABLE THROUGH THE SHEAVE, LD SHEAVE 1 15:00 16:00 I 1.00 RUNCOM P ■ RUNCMP I I'I LAND TUBING HANGER AND 2 -7/8" ESP I COMPLETION. RUN IN LOCK DOWN SCREWS. -253 JOINTS OF 2 -7/8" TUBING, MU TORQUE = 2,300 FT-LBS. -PU WT = 102K LBS, SO WT = 68K LBS. -461 CANNON CLAMPS, 3 FLAT GUARDS, AND 5 PROTECTOLIZERS 16:00 - 17:00 1.00 RUNCOM P RUNCMP FMC REP INSTALLED TWC - TESTED FROM ABOVE TO 4000 PSI FOR 10 CHARTED MIN, GOOD TEST. - PERFORMED ROLLING TEST FROM BELOW TO ATTAIN 500 PSI FOR FOR 10 CHARTED MIN. 17 :00 - 20:30 3.50 RUNCOM ! P RUNCMP ! PJSM FOR BOPE ND OPERATIONS. -N /D 13 -5/8" HYDRILL BOP AND SET BACK ON STAND -N /D 7 -1/16" X 13 -3/8" DSA. -N /U ADAPTOR FLANGE & TREE. Printed 4/20/2011 4:03:47PM North America - ALASKA -=BPS Page 8 of oration- Summary Report Common Well Name: MPL -20 I AFE No Event Type: WORKOVER (WO) Start Date: 2/18/2011 End Date: 3/25/2011 1X4- 00T93 -E: (1,250,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 3/25/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 30 : 20 3/6/1998 15:00 @37.20ft (above Mean Sea Level) Date From - To Hrs Task Code ' NPT NPT Depth ! Phase 1 Description of Operations (hr) (ft) 20:30 21:00 0.50 RUNCOM - � � P � j RUNCMP � TEST ADAPTOR FLANGE. -TEST TO 5000 PSI F/ 30 CHARTED MINUTES. -OK. 21:00 - 23:00 2.00 RUNCOM P RUNCMP FILL TREE. R/U TO TEST TREE. -TEST TREE TO 5000 PSI F/ 30 CHARTED - MINUTES. -OK. 23:00 - 00:00 1 1.00 RUNCOM P RUNCMP R/U DSM LUBRICATOR & TEST. -TEST TO 250 PSI LOW & 3500 PSI HIGH PRESSURE. -CHART TEST. -OK. -MAKE FINAL ESP CONDUCTIVITY TEST. -FBHP = 3314 PSI. 3/25/2011 00:00 - 06:00 6.00 RIGD P RUNCMP PULL TWC. R/U LRS & TEST LINES TO 3500 PSI. 1- FREEZE PROTECTTBG W/ 15 BBLS CRUDE. 1-R/U & TEST & CHART LUBRICATOR . SET -R/D LUBRICATOR. -TEST & CHART TWC F/ BELOW W/ 5 MINUTE ROLLING TEST. 1 BPM / 500 PSI. I _CONTINUE PUMPING CRUDE DOWN IA TO FREEZE PROTECT. -PUMP A TOTAL OF 65 BBLS DOWN IA. f -R/D LRS. SECURE WELL. I_ PREPARE TO RDMO. * * ** RIG RELEASED AT 06:00 * * * ** Printed 4/20/2011 4:03:47PM Tree: 2 9/16" - 5M FMC M P U L -20 Orig. DF Elev. = 49.85' (N22E) Wellhead:11" x 7" 5M FMC C a - Orig. GL Eleva06.8' w/ 2 7/8" WKM Tubing Hanger , w/ 3" DF To Tbg. Spool = xxx' (N22E) Acme Threads , 2.5" CIW H BPV profile 20" 91.1 ppf, H -40 115' ,] Camco 2 -7/8" x 1" 139' KOP @ 400' sidepocket KBMM GLM Max. hole angle = 76 to 79 deg. f/ 3500' to TD 9 5/8" Howco 'ES' 0 Hole angle thru' perfs = 33 deg 2123 Cementer 9 5/8 ", 40 ppf, L -80 Btrc. 8160' and ' , ® 7" Howco 'ES' Cementer 10,447' Two 7" x 21' short joints from 18,568' to 18,610' and 2 7/8" 6.5 Pp f, L -80, 8 rd EUE tbg.. its 2 7/8" HES "XN" Nipple 18,689` 9 ( drift ID = 2.347", cap. = 0.00592 bpf) (2.250" ID) 7 ", 26 ppf, L -80, Btrc. Mod. prod. casing ( drift ID = 6.151 ", cap. = 0.0383 bpf) 0 0 Auto Diverter Valve 18,732' 4.5" 12.6 ppf, L -80 Mod ( drift ID = 3.958" , cap = .0152 bpf) Discharge Head: GPVDIS 18,745' Centrilift ESP Intake TVD - 6457' 1GRSFTXARH6 19 -P23 SXD 18,746` Intake MD - 18733' 4.5" Liner Top TVD - 6493' _ Intake Gas Separator: 18,763' 4.5" Liner Top MD - ,18838' Mid -perf TVD - 6697' Tandem Seal Section: 18,768` Mid pert MD 19385' GSB3DBUT /LT SB /SB PFSNFSA CL5 PBTD TVD - 6785' Motor: 18,782' PBTD MD - 19600' KMH CL -6 228 hp 2305v/60A 0 D PumpMate XTO 18,801 ` Stimulation Summary w/6 fin Centralizer 03/11/98 - Kup. A Sand - 104 M# 20/40 Carbolite & 35 M# of PropLok coated 16/2C' Carbolite behind pipe 7 "x 4.5" Baker "ZXP" Pkr. I Perforation Summary "HMC" eV. 18 Ref log: Anadrill LWD 8/2/97 HMC" Hydraulic liner hang 18 852 7 "x5" Baker liner hanger Size SPF Interval (TVD) 7" float shoe I 19,104' 2 -7/8" 6 19370' -19400 6677' -6716' X RA Tag ( 19,192' TCP shot NOTE: Confirmed significant support from Conoco's KRU 30 -07 and 30 -14. These well's must be SI to stabilize BHP and determine mud wt. A request to CPI Fill Clean out @ 19,600' 6/14/10 needs to be initiated to ensure that the wells are SI by Nabors 4ES(no fill) > 4 weeks prior to RWO. - — " collar ,6' �� 4.5 Float collar landing 19 4.5" Float shoe 19,770' DATE REV. BY COMMENTS MILNE POINT UNIT 08/31/97 JBI- Dnlled and Cased by Nabors 22E 03/22/98 M. Linder Completion Nabor 4-ES WELL L-20 07/24/01 B. Hasebe RWO Nabors 4ES 06/20/06 R. Handy RWO Nabors 4 -ES API NO: 50- 029 -22790 07/24/06 L. Hulme RWO Nabors 3S 11/28/07 REH RWO Nabors 4ES 6/14/10 REH RWONabors4ES BP EXPLORATION (AK) 3/ ?Q1 R Rixhy RWQ nnvnn 16 ■ STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPOR OF SUNDRY WELL OPERA~NS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: .,Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-136 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22790-00-00 7. Property Designation: ~ 8. Well Name and Number: \ ADL 025514 MPL-20 9. Field /Pool(s): p aruk River Sands Milne Point Unit / Ku 10. Present well condition summary Total depth: measured 19770' feet true vertical 7022' feet Plugs (measured) None Effective depth: measured 19601' feet Junk (measured) None true vertical 6873' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' 1490 470 Surface 8123' 9-5/8" 8160' 3546' 5750 3090 Intermediate Production 19071' 7" 19104' 6462' 7240 5410 Liner g32' 4-1/2" 18838' - 19770' 6248' - 7022' 8430 7500 ' ' Perforation Depth: Measured Depth: 19370 - 19400 True Vertical Depth: 6676' - 6701' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 18792' 6213' Packers and SSSV (type, measured and true vertical depth): 11. Stimulation or cement squeeze summary: Intervals treated (measured): yJ ~ L Q )~ ~ (~ j (~ Treatment description including volumes used and final pressure: AIBSka 01~ ~! .~~8;y, u8,°'ei^„ (;8f11f1'11SSIOtt ~fl~i~f~rn~e 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 445 123 686 260 278 Subsequent to operation: 341 86 646 210 217 13. Attachments: ^ Copies of Logs and Surveys run • Well Class after work: ^ Exploratory ®Development ^ Service n f W ll O ti ® D il R rt pera o s y epo o e a ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mackie Derrick, 564-5891 N/A Printed Name Terrie Hubble Title Drilling Technologist ~Q n Prepared By Name/Number: ~ ~ Signature '~v Phone 564-4628 Date (V Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 RB~MS ~~f n a ~ ,/~~ ~ ~/+ f~ Submit Unginai curry • • MPL-20, Well History (Pre Rig Workover) Date Summary 5/14/2010 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 800/740/250 PSI. RIH WITH 10 FT 1.56" 20ES TUBING PUNCHER RDX (BOTTOM 5' LOADED) WITH WELLTEC 218 XR TRACTOR. LRS PUMPED 224 BBLS FRESH WATER DOWN IA TO WARM TUBING. 5/15/2010 CONTINUE TO RIH WITH 10 FT 1.56" 20ES TUBING PUNCHER RDX (BOTTOM 5' LOADED) WITH WELLTEC 218 XR TRACTOR. PUNCH 2-7/8" TUBING FROM 18444'-18449' WITH 5 FT 1.56" 20ES TUBING PUNCHER RDX. FINAL T/I/0= 700/ 680/ 180 PSI. JOB COMPLETE. 5/20/2010 WELL S/I ON ARRIVAL. R/U SLICKLINE FOR RIG PREP. 5/21/2010 RUN DUAL SPARTEK GAUGES. MADE 3 HOUR STOP C«3 8900' SLM & 15 MINUTE STOP C~ 7600' SLM. RUN PDS CALIPER AS PER PROGRAM. LRS ASSISTED PUMPING TOOLS DOWN HOLE. 5/22/2010 RUN PDS CALIPER AS PER PROGRAM. ,RECOVERED GOOD DATA. PERFORMED MAST TRUCK FIRE DRILL W/CREW & REP. ASSIST SUPPORT TECHS INSTALL BPV. BPV SET. WELL S/I ON DEPARTURE. Page 1 of 1 i North America -ALASKA - BP Page I of ~ Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 5/29/2010 End Date: X4-OOQ9F-E (75,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: _ Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 6/3/2010 _ 03:00 - 07:00 4.00 _ MOB P ~ _ PRE RDMO -MPE-11 -R/D FLOOR, BLOW DOWN WATER AND STEAM -SCOPE DOWN AND LOWER DERRICK -MOVE OFF OF MPE-11 AND MOVE TO MPL- PAD 07:00 - 13:30 6.50 MOB P PRE RIG MOVE FROM MPE-11 TO MPL-20 -PERFORMING RIG MOVE WITH TWO SOWS. -MOVED'CAMP & PITS FIRST -THE SUB & PIPE SHED LAST % -MOVING EQUIPMENT BEHIND WELL __ _ 1 __ _ _ __ 13:30 - 15:00 _ 1.50 RIGU P PRE MIRUAN MPL-20 i -SPOT OVER MPE-06 AT 1330 HRS. -SPOT PITS, TIGER TANK AND PIPE SHED 15:00 - 17:00 2.00 RIGU P PRE RAISED DERRICK -ATTEMTED TO SCOPE -WIND GUSTS @ 35-39 MPH, WITH MAX SLOPING LIMIt @ LESS THAN 35 MPH. **"RIG ACCEPTED AT 17:00*** ~ - 17:00 - 19:00 - 2.00 RIGU -- P PRE WAITING ON WIND SPEEDS TO DROP BEFORE SLOPING DERRICK -RU CIRC LINES FOR WELL KILL ~I -RU LINES TO TIGER TANK. ~ -TEST CIRC LINES TO 3500 PSI -TEST LINES DOWN STREAM OF THE CHOKE TO THE TIGER TANK TO 500 PSI. AFTER CONSULTING WITH FIELD RWO SUPERINTENDANT, THE DECISION WAS MADE TO CONTINUE WITH WELL KILL OPERATIONS WHILE WAITING FOR THE WINDS TO LAY DOWN I ENOUGH TO SCOPE THE DERRICK. _ ~ 19:00 - 23:00 4.00 RIGU P ! PRE TAKING ON SOURCE WATER TO THE PITS ~ GSOURCEWATER -8.3PP { __ ____ 23:00 - 00:00 1.00 RIGU P _ ~ _ PRE _ PJSM FOR PULLING BPV. ~ ~ -RU LUBRICATOR AND PRESSURE TEST TO 500 I PSI, WITH DIESEL -PULL 2-1/2" CAMERON TYPE "H" BPV -TBG PSI- 1100 , I.A. PSI-1000, O.A. PSI-200 Printed 7/8/2010 8:20:37AM i ~ North America -ALASKA - BP Pane 1 of 17 Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-OOQ9F-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 6/4/2010 00:00 - 01:00 1.00 KILLW P DECOMP RU O.A. BLEED LINE -BLEED OA FROM 200 PSI TO 0 01:00 - 06:30 5.50 KILLW P DECOMP SHUT IN WHP'S, TBG=1100 PSI, IA=1000 PSI, OA=O PSI. -BLEED IA DOWN TO 250 PSI. -BLEED TBG DOWN TO 470 PSI. -SITP BUILT TO 600 PSI PUMPED 110 BBLS OF 8.3 PPG SOURCE WATE ~ DOWN THE TBG AT 2-3 BPM / 1210 - 1390 PSI. -SLOWED TO 2 BPM, SHUT IN CHOKE AND BULL ~ HEADED SO BBLS INTO THE FORMATION @ 2 f3PM AT 870-940 PSI. -SHUT DOWN TO TAKE ON FLUID TO THE PITS TO FREE UP A TRUCK AND START SUCKING OUT THE'?IGER TANK. -RESUMED CIRCULATING 560 BBLS DOWN THE TUBING OUT THE ANNULUS TO THE TIGER TANK. i ~ -630 PSI ON TBG AND 950 PSI ON IA WHEN ! i PUMPING RESUMED. ~ -CIRCULATING AT 3 BPM @ 1900 PSI. -SHUT IN AFTER PUMPING A TOTAL OF 850 i BBLS. LOST 201 BBLS TO THE FORMATION INCLUDING THE 50 BBLS THAT WERE BULLHEADED DOWN THE RATHOLE. -SHUT IN TUBING PRESSURE = 720 SHUT IN CASING PRESSURE = 850. -- - -- 06:30 - 07:30 1.00 KILLW P DECOMP MONITOR WELL. SHUT IN TUBING PRESSURE _ 700 SHUT IN CASING PRESSURE = 800. ~ CHARGED THE FORMATION WITH HIGH PUMP ~ PRESSURES DURING WELL KILL. CONSULTED WITH RWO ENGINEER AND RWO FIELD ~ SUPERINTENDANT. DECISION WAS MADE TO CIRULATE ANOTHER WELLBORE VOLUME WITH SOURCE WATER AT A LOWER PUMP RATE, 2 BPM, AND THEN TRY TO DETERMINE WHAT IS NEEDED FOR KWF. Printed 7/8/2010 8:21:22AM North America -ALASKA - BP Page 2 of 1 ~ Operation Summary Report __ Common Well Name: MPL-20 DEAP DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name%No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations i (hr) (ft) 07:30 - 15:30 8.00 KILLW P DECOMP WAITING ON TRUCKS. TRUCKS THAT WERE ON LOCATION WERE TURNED DIRTY TO REDUCE THE FLUIDS IN THE TIGER TANK. CALLED CENTRAL DISPATCH AND THERE ARE VAC ~ TRUCKS AVAILABLE BUT NO DRIVERS. i ~ CH2MHILL IS EXPECTING MORE DRIVERS TO ~ COME IN ON THE NOON FLIGHT AT WHICH TIME i ~ ~ THEY WILL SEND TWO TRUCKS. EMPTIED -200 BBLS OF 10.3 PPG BRINE FROM MPE-11-INTO PIT 2 TO HOLD UNTIL WE KNOW WHAT THE'KWF WILL BE. SENT THAT TRUCK TO START ROUND. TRIPPING' FOR SOURCE WATER FROM MPU WHILE WE WAIT FOR 2 MORE TRUCKS FROM DEADHORSE. RWO FIELD SUPERINTENDANT ON SITE TO DISCUSS`CURRENT WELL CONDITIONS AND UPCOMING WELL. 15:30 - 17:30 2.00 KILLW P , DECOM'P' TAKING ON 8.3 PPG SOURCE WATER TO THE 'PITS ~ -PREP FOR SURF TO SURF CIRCULATION OF SOURCE WATER --- 17:30 - 23:00 5.50' KILLW P DECOMP SECOND SOURCE WATER CIRCULATION -SHUT IN WHP'S, TBG=670 PSI, IA=750 PSI, OA=O PSI. I CIRCULATED 700 BBLS OF 8.3 PPG SOURCE WATER DOWN THE TBG UP THE IA THROUGH THE CHOKE. i -MAX CIRC RATE OF 2 BPM, -TBG ~ PRESSURES=700-1150 , IA PRESSURES= 550-750 -FINAL CIRC PRESSURE ,TBG=1110 PSI , IA=610 PSI --SHUT IN AFTER PUMPING A TOTAL OF 700 BBLS. LOST 54 BBLS TO THE FORMATION 23:00 - 00:00 1.00 KILLW P DECOMP SHUT DOWN AND MONITOR SITP, CHECK FOR FLOW. -NO FLOW, WELL IS 100% 8.3 PPG SOURCE WATER IN AND OUT. -SITP=660 PSI , SICP=660 PSI COMFIRMED WITH RWO ENGINEER ON KWF NEEDED BASED ON SITP, WITH A 75 PSI SAFETY MARGIN. i -10.4 PPG KWF WI -ENGINEER DOUBLE CHECKED THE MASP TO ENSURE ANOTHER RAM WOULD NOT BE NECESSARY FOR THE BOP, MASP=-2870 PSI 6/5/2010 00:00 - 06:00 6.00 KILLW P DECOMP WAITING ON KILL WT FLUIDS FROM PRUDHOE -WEIGHT UP 190 BBLS OF 10.3 PPG BRINE TO 10.4 PPG IN THE PITS. I -MONITOR WELL ~ _ -@ 05:00 TBG= 650 PSI , IA=640 PSI Printed 7/8/2010 8:21:22AM ~1 North America -ALASKA - BP Page 3 of i ~ Operation Summary Report __ Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ ___ 06:00 - 09:30 3.50 KILLW P DECOMP CONTINUE TO WAIT ON KWF FROM PRUDHOE. -THE FIRST OF THREE 290 BBL LOADS OF 10.4 PPG FROM MI ONSITE. -TALKED TO MI IFE COORDINATOR. NABORS ' 7ES WAS AHEAD OF US IN THE ORDER AND THEY HAD TO BUILD VOLUME BEFORE THEY COULD LOAD THE NEXT TWO TRUCKS. -RWO ENGINEER CALLED TO DISCUSS THE KWF. 09:30 10:00 0.50 KILLW _ P DECOMP CALLED RWO FIELD SUPERINTENDANT ABOUT KWFr TBG PRESSURE = 660, CSG PRESSURE _ 650PSf. KWF + 75 PSI OVERBALANCE = 10.42 PPG: AFTER DISCUSSION WE KNOW THAT WE ~ HAVE CHARGED THE FORMATION SOMEWHAT AND BOTH THE $UPERINTENDANT AND WSL FEEL THAT THE 10;4-PPG KWF IS SUFFICIENT AS IT GIVES USA 0.2`PPG TRIP MARGIN. ALL I ~ PREASSURE-READINGS AND CALCULATIONS `WILL BE REVIEWED AGAIN JUST PRIOR TO PUMPING THE KWF TO MAKE SURE THAT °' CONDITIONS HAVE NOT CHANGED. 1 _ 10:00 11:00 _ 1.00. KILLW . P DECOMP .THE FIRST 10.4 PPG TRUCK WAS OFFLOADED INTO THE PITS AND A MUD CHECK REVEALED ~ THAT IT WAS 10.3 PPG. CREWS BEGAN MIXING E NABR TO BRING IT UP TO 10.4 PPG. _ _ 11:00 - 12:00 1.00 KILLW P DECOMP THE SECOND 10.4 PPG TRUCK ARRIVED ON LOCATION. STILL WAITING ON THE THIRD TRUCK TO BEGIN CIRCULATING KWF THROUGH THE - WELL BORE. --- 12:00 - 13:00 1.00 - KILLW P_ DECOMP ALL 450 BBLS IN PITS ARE AT 10.4 PPG. STILL WAITING ON FINAL LOAD OF 10.4 KWF TO BEGIN WELL KILL. 13:00 - 14:30 1.50 KILLW P _ DECOMP SITP = 650 PSI / SICP = 640 PSI. SENT ONE CLEAN VAC TRUCK FORA 47 BBL, 12.0 PPG, SPIKE LOAD FROM MUD PLANT TO BRING 240 BBLS OF 10.1 PPG NACUNABR BRINE UP TO 10.4 PPG FOR ADDITIONAL FLUIDS. Printed 7/8/2010 8:21:22AM ~~ North America -ALASKA - BP Page 4 ct ~ Operation Summary Report --_ -- Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) ~ -_ --- Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 21:00 6.50 KILLW P DECOMP ALL REQUIRED FLUIDS ON LOCATION. - 1100 BBLS OF 10.4 PPG NACUNABR BRINE ON LOCATION. SITP = 640 PSI / SICP = 630 PSI. KWF + 75 PSI OVERBALANCE = 10.4 PPG. WELL KILL OPERATIONS AS FOLLOWS PUMP 110 BBLS OF 10.4 PPG BRINE DOWN TUBING.. ~ TAKING. RETURNS OUT THE IA THROUGH THE CHOKE TO THE TIGER TANK. -1-2 BPM AT 500 T09800 PSI TBG, 210 TO 480 PSI-0N CSG. -BULLHEAD 50 BBLS DOWN THE TBG AT 1-2 BPM AT 600 TO 1120-PSI TBG , S50T0 1200 PSI I ON CSG -PUMP 560-BBLS DOWN TUBING TAKING RETURNS OUT THE LA. THROUGH THE CHOKE TO THE TIGER TANK, 2 i BPM -720 TOTAL BBLS PUMPED CLEAN 10.4 PPG BRINE -TOTAL LOSS DURING CIRCULATION WAS 180 BBLS. 21:00 - 23:30 2.50 KILLW P DECOMP MONITORED WELL -PERFORMED A FLOW CHECK -GAS STILL BREAKING OUT ,GOT BACK 1 BBL IN 40 MIN. -DECIDED TO PUMP AN EXTRA 100 BBLS -15 BBL LOSS DURING 100 BBL CIRC PUMPED 100 BBLS @ 2 BPM. -STOPED PUMPING MONITORED WELL -PERFORMED FLOW CHECK, NO FLOW, AND NO GAS NDIN P I- T= I= 0 0= PSI 23:30 - 00:00 0.50 WHSUR P DECOMP INSTALL 2-1/2" CAMERON TYPE'H' TWC WITH FMC WELLHEAD TECH -TEST FROM ABOVE TO 3,500 PSI FOR 10 CHARTED MINUTES -TEST FROM BELOW TO 500 PSI FOR 10 CHARTED MINUTES BY ROLLING TEST AT 4.5 BPM. _ _ _ 6/6/2010 _ _ 00:00 - 01:00 _ 1.00 _ BOPSUR P _ DECOMP INSTALL 2-1/2" CAMERON TYPE 'H' TWC WITH FMC WELLHEAD TECH -TEST FROM ABOVE TO 3,500 PSI FOR 10 ( CHARTED MINUTES -TEST FROM BELOW TO 500 PSI FOR 10 CHARTED MINUTES BY ROLLING TEST AT 4.5 BPM. Printed 7/8/2010 8:21:22AM r~ North America -ALASKA - BP Page 5 or ~ Operation Summary Report __ Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/1 412 01 0 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 02:00 1.00 i BOPSUR P DECOMP N/D 2-9/16" TREE AND 11"ADAPTOR FLANGE -INSPECT HANGER AND WELLHEAD. -SINGLE BARRIER DISPENSATION IN PLACE FOR MILNE PT ESP SWAP. SINGLE BARRIER =TESTED TWC IN TUBING HANGER. 02:00 - 06:00 4.00 BOPSUR P DECOMP NU 13-5/8" "GK" HYDRILL BOP W/ 2-7/8" BY 5" VBR =NU DSA, CHOKE AND KILL LINES ,& TEST SPOOL -HOOKUP KOOMEY LINES & TURN BUCKLES, I INSTALL FLOW RISER ~ -CONTINUOUS HOLE FILL IN THE LA. @ 9 BPH ESTABLISHED LOSS RATE ~ -MU TEST JOINT 06:00 - 11:00 5.00 BOPSUR P DECOMP . TEST BOPE TO 250 PSI LOW AND 3.500 PSL HIGH. TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE ANO KILL LINE VALVES, FLOOR VALVES, 2-7/8" X 5" VBR'S, ANNULAR PREVENTER. TEST VBR'S AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. i -AOGCC WITNESS OF TEST WAS WAIVED BY BOB NOBLE ON 6/3/2010 . ALL TESTING ~ ' WITNESSED BY NABORS TOOLPUSHER,DRILLER I AND BP WSL. -PERFORM KOOMEY TEST -200 PSI BUILD UP TO 1750 PSI FROM 1550 PSI = 52 SECONDS. -FULL BUILD UP TO 3000 PSI = 207 SECONDS. _ -4 BOTTLES x 2150 PSI. 11:00 - 23:00 12.00 _ BOPSUR _ N HMAN DECOMP WHILE LAYING DOWN THE TEST JOINT IT WAS NOTICED THAT THE TEST I T I CRIMPED. -IT WAS DETERMINED THAT IT HAD BEEN j CLOSED ON BY THE BLIND SHEAR RAMS DURING THE KOOMEY DRAW DOWN TEST. -OPERATIONS WERE SHUT DOWN TO DETERMINE THE CAUSE. -WSL LEADER CONTACTED RWO LEADERSHIP TO INFORM THEM OF THE INCIDENT -ROTARY SUPERINTENDENT RICHARD WATKINS, i BP SAFETY ALLEN GRAFF AND NABORS SAFETY PAUL HOLLEY CAME OUT TO LOCATON TO DO A ROOT CAUSE. -FULL DESCRIPTION OF THE INCIDENT AND THE CORRECTIVE ACTIONS TAKEN WILL BE ~ ENTERED IN A TRACTION REPORT ** CONTINUOUS HOLE FILL WAS MAINTAINED i DURING SHUT DOWN AND INVESTIGATION WITH AN AVG LOSS RATE OF - 7 BPH. ~~ ~k f`o Printed 7/8/2010 8:21:22AM North America -ALASKA - BP Paye 6 of n Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES , Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 23:00 - 00:00 1.00 BOPSUR P DECOMP NABORS WEEKLY SAFETY MEETING DISCUSSIONS WERE: -CURRENT STATUS OF NABORS DRIVEN SAFE WORK PLAN CREATED DURING LAST ADW SAFETY STAND DOWN -DISCUSSED UPCOMING DROPPED OBJECT MANAGMENT SYSTEM _ 6/7!2010 00:00 - 00:30 0.50 BOPSUR P ~ DECOMP .FUNCTION TEST KOOMEY UNIT ~ -USINGNEW FUNCTION TEST PROCEDURES. 00:30 - 02:30 2.00 BOPSUR P DECOMP RU DUTCH RISER SYSTEM. -CROSSOVER/LUBRICATOR -PT LUBRICATOR TO SOO PSI FOR 5 MIN WITH bIESEL -PULL TWC. -TUBINGANDlAARE ON A VAC. AVG LOSS RATE OF'-7-10 BPH i -LDLUBRICATOR AND RD DUTCH SYSTEM. 02:30 - 04:00 1.50 BOPSUR P DECOMP MU LANDING JOINT W/TIW VALVE SCREW INTO HANGER. i -"FMC" BOLDS -PULL TBG HANGER OFF_ SEAT Ca) 83 K -LD HANGER -CUT ESP CABLE, CENTRILIFT PERFORMED MEG CHECK ON CABLE. -MU LANDING JOINT W/TIW VALVE 04:00 - 06:00 2.00 PULL ~ P DECOMP CBU WITH -560 BBLS OF 10.4 PPG BRINE -CIRCULATING AT 3-4 BPM @ 460-1000 PSI -SPOTTING 100 BBL PILL OF SAFE LUBE @ 3,500' 06:00 - 07:00 1.00 PULL P __ __ DECOMP CONTINUE TO CBU WITH -560 BBLS OF 10.4 PPG NACUNABR BRINE CREW CHANGE -ENVIRONMENTAL WALK AROUND, SERVICE ' DRAWWORKS. 07:00 - 09:00 2.00 PULL P DECOMP CONTINUE TO CBU. -PUMPED A TOTAL OF 700 BBLS OF 10.4 PPG. -LOST 54 BBLS TO THE FORMATION. Printed 7/8/2010 8:21:22AM North America -ALASKA - BP Page ~ °' i ~ Operation Summary Report _ _ __ ___ Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) ___ _ 09:00 10:30 1.50 PULL _ P DECOMP MONITOR WELL. -PERFORMED A FLOW CHECK -WELL IS I FLOWING -3 BBL GAIN. DRILLER MADE THE DECISION TO SHUT THE WELL IN. DRILLER INFORMED THE TOOLPUSHER AND WSL OF HIS'DECISION. WSL CALLED THE RWO FIELD SUPERINTENDENT AND LEFT A MESSAGE FOR THE AOGCC. JOHN CRISP WITH AOGCC RETURNED THE CALL AT 10:10 AM. MONITORED WELL FOR-45 MINUTES WHILE PHONE NOTIFICATIONS WERE BEING MADE. A ~ LOW PRESSURE GAUGE WAS ATTACHED TO THECHOKE'MANIFOLD. SITP = 0-1 PSI, SICP = 6-7 PSI. 10:30 - 13:30 3.00 PULL P DECOMP_ CIRCULATING TO CLEAN UP THE WELLBORE. =650.BBLS OF 10.4 PPG BRINE AT 4 BPM AND 1990 PSI. -CIRCULATING THROUGH A WIDE OPEN CHOKE THROUGH THE GAS BUSTER TO THE PITS. DECISION TO CIRCULATE A BOTTOMS UP WAS MADE AFTER DISCUSSION WITH THE RWO ENGINEER AND THE RWO FIELD SUPERINTENDENT. 13:30 - 14:00 _ 0.50 PULL P _ DECOMP SHUT IN AND MONITOR WELL. -OVER 20 MINUTE PERIOD THE SICP BUILT FROM 9 PSI TO 20 PSI. -OVER THE SAME PERIOD OF TIME THE SITP REMAINED AT 0 PSI. -OVER THE NEXT 10 MINUTES THE SICP BUILT TO 21 PSI. -OVER THE SAME PERIOD THE SITP BUILT FROM 0 PSI TO 5 PSI. S~~ 41 ~a~ P~" Printed 7/8/2010 8:21:22AM r~ North America -ALASKA - BP Page a of i ~ Operation Summary Report - _ _ - Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task ~ Code NPT NPT Depth Phase Description of Operations (hr) ~ (ft) 14:00 - 16:30 2.50 PULL P DECOMP AFTER DISCUSSION WITH THE RWO TEAM IN ANCHORAGE THE DECISION WAS MADE TO SHUT IN AND BLEED BACK THE TUBING AND I OBSERVE THE PRESSURES ON THE CASING. SITP = 46 PSI; SICP = 45 PSI OPENED THE TUBING TO THE BLEEDER AND SI OW Y B FD OF THE T1161Nh AFTER 30 MINUTES ~ -THE SICP.DROPPED TO 4 PSI. -7 BBL GAIN WAS TAKEN TO THE PITS. SHUT IN THE TUBING: -SITP = 5 PSI; SICP = 5. OPENED UP'THE TUBING AND THE CASING AND BLED THEM BOTH OFF. -AFTER 5 MINUTES THERE DIDN'T APPEAR TO BE - ~ ANYPRESSURE. -THE WHITEY VALVE ON THE CASING SIDE WAS i OPENED AND THERE WAS NO PRESSURE OR FLOW. -DRILLER AND WSL CHECKED SEVERAL TIMES AND LEFT OPEN. -NO PRESSURE WAS NOTED ON THE CASING SIDE. _~PFNFD THE ANNULAR PREVFNTFR_TO OBSERVE THE WELL. -SMALL "CHAMPAGNE" SIZED GAS BUBBLES WERE OBSERVED. -GAS BUBBLES GREW AND CRUDE BEGAN TO I FLOW. -ANNULAR WAS SHUT. SITP = 5 PSI; SICP = 5 PSI. 16:30 - 00:00 7.50 PULL P DECOMP ORDERED ONE TRUCK W/ 10.6 PPG KILL WEIGHT FLUIDS -ORDERED ONE TRUCK WITH 12.0 PPG NAIBR TO RAISE EXSISTING 10.4 PPG BRINE TO A 10.6 PPG -WAITING FOR KWF TO ARRIVE ON LOCATION ~ -CREWS DOING MAINTENCE. ~ -MONITORING WELL , @ 00:00 TBG=O , IA=O, WELL ON A SLIGHT VAC 6/8/2010 00:00 - 03:00 3.00 PULL P _ DECOMP -WAITING FOR KWF TO ARRIVE ON LOCATION -CREWS DOING MAINTENCE. -MONITORING WELL , @ 03:00 TBG=O , IA=O, WELL ON A SLIGHT VAC Printed 7/8/2010 8:21:22AM North America -ALASKA - BP Page s of 17 Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ _ 03:00 - 04:00 1.00 PULL P DECOMP FINAL TRUCK WITH 10.6 PPG BRINE ARRIVED ON LOCATION. -DOING FINAL FLUID SWAP IN PITS, AND CHECKING WEIGHTS -KWF CIRCULATION PREP -PJSM FOR WELL KILL & WELL CONTROL MEASURES. 04:00 - 06:00 2.00 KILLW P DECOMP .CIRCULATING 10.6 PPG KWF INITIAL PRESSURES, TBG=O , IA=O ,OA=O , WELL ON A SLIGHT VAC -START CIRCULATION @ 2 BPM-560 PSI -BRING CIRC UP TO 3.BPM @ 1100-1170 PSI. =ZERO LOSS RATE @ 3 BPM -BROUGHT CIRC RATE TO 4 BPM @ 1830-1900 PSI _ 06:00 - 09:00 3.00 KILLW P DECOMP CONTINUE CIRCULATING 10.6-PPG KWF AT 4-BPM WITH-1930-PSI. ~ -PUMP 890-BBLS TO GET 10.6-PPG KWF BACK TO SURFACE. -SHUT DOWN AND MONITOR WELL FOR 45-MINUTES. WELL LOSING FLUID. -ESTABLISH STATIC LOSS RATE OF 4-BPH. _ 09:00 - 16:00 7.00 PULL P DECOMP pOH WITH ESP, STANDING BACK 2-7/8" EUE 8RD TBG IN DERRICK. - -BEGIN MIXING 10.6-PPG SODIUM BROMIDE WITH 10.4-PPG SODIUM BROMIDE TO LIMIT LOSSES DUE TO LIMITED SUPPLY OF SODIUM BROMIDE ~ ON THE SLOPE. -MAINTAIN CONTINUOUS HOLE FILL USING 10.5-PPG SODIUM BROMIDE WHILE POH. -STOP EVERY TWO HOURS AND MONITOR ~ WELL /OBTAIN STATIC LOSS RATE. -LOSS RATE = 9=BPH _ ~ 16:00 - 18:00 2.00 PULL P DECOMP CONTINUE TO POH WITH ESP TO STAND #92, ~ STANDING BACK 2-7/8" TBG IN DERRICK. -MAINTAIN CONTIUOUS HOLE FILL USING 10.5-PPG SODIUM BROMIDE. ~ -LOSS RATE = 10-BPH. -TUBING AND ESP CABLE APPEAR IN GOOD CONDITION. -ENCOUNTER LASALLE CLAMPS ON EVERY CONNECTION BEGINNING WITH STAND #72. 18:00 - 18:30 0.50 PULL P DECOMP PERFORM PRE-TOUR CHECKS - 18:30 20:00 - 1.50 PULL P DECOMP -OBTAIN STATIC LOSS RATE OF 6-BPH. CONTINUE TO POH WITH ESP FROM STAND #92 TO STAND #115, STANDING BACK 2-7/8" ~ TUBING IN DERRICK. -ESP CABLE SPLICED AT STAND #114 AND CABLE REEL IS FULL. -LOSS RATE = 6-BPH. -MAINTAIN CONTINUOUS HOLE FILL WITH 10.5-PPG SODIUM BROMIDE. Printed 7/8/2010 8:21:22AM r North America -ALASKA - BP Page 10 of ~ ~ Operation Summary Report ___ --_ Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-OOQ9F-E (625,000.00 ) 1 Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ~ (ft) _ (20:00 - 22:00 2.00 PULL P _ DECOMP ___ CBU AT 5-BPM WITH 1420-PSI. -23-BBL LOSS OVER 307-BBLS OF 10.5-PPG SODIUM BROMIDE PUMPED. -SHUT DOWN AND MONITOR WELL. LOSING FLUID SLOWLY. ' -OBTAIN STATIC LOSS RATE OF 6-BPH. 22:00 - 00:00 _ 2.00 PULL P DECOMP CONTINUE TO POH WITH ESP FROM STAND #115 ' TO #156,. STANDING BACK 2-7/8" TBG IN DERRICK: -MAINTAIN CONTINUOUS HOLE FILL WITH 10.5-PPG SODIUM BROMIDE. 6/9/2010 00:00 - 00:30 0.50 PULL DECOMP MONITOR WELL -STATIC. ~ -OBTAIN STATIC LOSS RATE OF 12-BPH. 00:30 - 03:00 ~ 2.50 PULL DECOMP CONTINUE TO POH WITH ESP FROM STAND #156 TO STAND#194, STANDING BACK 2-7/8" EUE 8RD TBG IN DERRICK. -MAINTAIN CONTINUOUS HOLE FILL USING ~ 10.5-PPG SODIUM BROMIDE. - -LOSS RATE = 10-BPH. --- 03:00 - 03:30 0.50 PULL DECOMP M PIN -NOTE SLIGHT GAS BREAKOUT. -CIRCULATE 3-SURFACE TO SURFACE VOLUMES AT 3-BPM WITH 70-PSI. I -MONITOR WELL. FLUID LEVEL DROPPING AND ___ _ ' ~ LESS GAS BREAKOUT NOTED. 03:30 - 04:30 _ _ _ 1.00 __ _ __ PULL DECOMP _ CONTINUE TO POH WITH ESP FROM STAND #194 ~ TO STAND #197. -TUBING PUNCH IN SECOND JT OF STD #197. -RECOVER 592 FULL JTS OF 2-7/8" EUE 8RD TUBING, 1-XN NIPPLE, 1-GLM. -RECOVERED 481 LASALLE CLAMPS. 04:30 - 06:00 1.50 PULL DECOMP CENTRILIFT BREAK OUT AND LD ESP. 06:00 - 06:30 0.50 PULL DECOMP RIG SERVICE, PERFORM PRE-TOUR CHECKS. 06:30 - 08:30 2.00 PULL DECOMP CLEAN AND CLEAR RIG FLOOR. -REMOVE ESP EQUIPMENT FROM PIPE SHED. ___ _ __ -R/D ESP CABLE TRUNK. 08:30 - 10:00 1.50 BOPSUR _ DECOMP INSTALL TEST PLUG, M/U 2-7/8" TEST JOINT ~ " ' -TEST 13 5/8 ANNULUAR AND HCR s VALVE -WITH 2-7/8" TEST JOINT, 250 PSI / 3,500 PSI -BOTH FOR (5) CHARTED MINUTES. __ ~ __ _ 10:00 - 10:30 ~ 0.50 WHSUR DECOMP -R/D TEST EQUIPMENT, BLOW DOWN LINES. INSTALL 6 1/8" WEAR RING 10:30 - 13:00 2.50 CLEAN DECOMP P/U 2-7/8" MULE SHOE, (35) JOINTS 2-7/8" FOX TBG FROM PIPE SHED Printed 7/8/2010 8:21:22AM North America -ALASKA - BP Page 11 of 17 Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 22:30 9.50 CLEAN _ DECOMP RIH WITH FCO BHA ON 188-STDS (564-JTSt OF 2-7/8" EUE 8RD TUBING FROM DERRICK. -LOSS RATE = 6 TO 8-BPH WHILE RIH. -AT 2100-HRS, HOLD UNANNOUNCED KICK WHILE TRIPPING DRILL. CREW RESPONDED QUICKLY AND SAFELY. THE WELL WAS ' SECURED WITHIN 1-MINUTE OF KICK DETECTION. -HOLD AAR WITH CREW AND DISCUSS CREW MEMBERS IN FILL IN POSITIONS AND ALSO COMMUNICATION USING THE RIG RADIO, I HARMONY.. RADIO AND RIG GAITRONICS SYSTEMS DURING;DRILLS OR EMERGENCIES. -STATIC LOSS RATE OBTAINED DURING AAR = 9-BPH. - _ 22:30 - 23:30 1.00 CLEAN ~ DECOMP OBTAIN,PARAMETERS AT 18,734'. (JUST ABOVE 4-1/2" LINER TOP) ~ - PU WT = 55K.LBS, SO WT = 25K-LBS. -PUMP 40-BBL HI VIS SWEEP AND CHASE WITH 110-BBLS OF 10.6-PPG SODIUM BROMIDE BRINE Y - AT 3-BPM WITH 1270-PSI. - - - 23:30 - 00:00 0.50 CLEAN., - - DECOMP E 1 7 ' T T ENCOUNTERING ANY FIL O R -RECONFIRM TAG OF PBTD OF 19,600' - -- 6/10/2010 ~ 00:00 - 01:00 1.00 CLEAN P DECOMP pOH FROM 19600' TO 18734' -lD SINGLE JT OF 2-7/8" EUE 8RD TBG TO PIPE SHED. ~ -STAND BACK 9-STDS OF 2-7/8" EUE 8RD TBG IN DERRICK. 01:00 - 02:30 1.50 , CLEAN _ DECOMP REVERSE CIRCULATE BOTTOMS UP AT 3-BPM WITH 590-PSI. -INITIAL DYNAMIC LOSS RATE = 60-BPH. -DIRTY FLUID THROUGHOUT CIRCULATION. SWEEP BROUGHT BACK SLIGHT AMOUNT OF SAND/PARTICULATE. -TOTAL LOSS FOR CIRCULATION = 67-BBLS ~ 02:30 - 05:00 2.50 ~ CLEAN DECOMP MONITOR WELL AND NOTE SLIGHT, DIMINISHING FLOW. -FLOW REDUCES FROM 7-BBLS IN 10-MINUTES TO 1/2-BBL IN 10 MINUTES OVER THE FIRST HOUR OF MONITORING. -FLOW REDUCES FROM 1/2-BBL IN 10-MINUTES TO 1/16-BBL IN 10-MINUTES OVER SECOND HOUR OF MONITORING. i -WHEN NO GAIN NOTED IN PITS, OPEN ANNULAR _ AND MONITOR WELL. 05:00 - 05:30 0.50 CLEAN DECOMP POH WITH FCO BHA TO 17804', STANDING BACK 2-7/8" EUE 8RD TUBING IN DERRICK. --1-BBL LOSS FOR EACH 5-STDS PULLED Printed 7/8/2010 8:21:22AM r~ >_ North America -ALASKA - BP Page 12 of 17 Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-OOQ9F-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) __ 05:30 - 11:00 5.50 CLEAN DECOMP DISCUSS SITUATION WITH RWO ENGINEER AND DECIDE TO CBU PRIOR TO POH. -RU TO CIRCULATE. -PUMPED 537 BBLS 10.5 PPG BRINE. -4 BPM / 2050 PSI -NOTED JUST A LITTLE GAS AND BUBBLES. CIRCULATED ADDITIONAL 140 BBLS, TOTAL LOSSES = 30 BBLS DURING CBU -PUMPS OFF AT 10:00 HRS, FLOW STOPPED AT 11:00 HRS WITH 2 BBL GAIN. -DISCUSS SITUATION WITH ANCHORAGE RWO ENGINEER TEAM =AND DECIDE TO INCREASE FLUID WEIGHT TO 10.6+ PPG ~ -SPIKE LOAD`ORDERD 11:00 - 16:00 5.00 _ CLEAN DECOMP WAIT OF KWF FROM MI-MUD PLANT. -MONITER WELL WITH PUMPS OFF, -1 BPH LOSS RATE ---- -_- _ + _ 16:00 - 17:30 1.50 CLEAN DECOMP MIX AND BLEND TO 10.6+ PPG BRINE IN PITS AND ONBOARD THE VAC-TRUCK. 17:30 - 18:00 0.50. ~ CLEAN DECOMP -- - ..PERFORM PRE TOUR CHECKS WHILE CONTINUING TO MIX 10.6-PPG KWF ON VAC TRUCK. __ ___ __ 18:00 - 19:00 1.00 CLEAN ( DECOMP BRING FLUID ON FROM VAC TRUCK. -EQUALIZE AND MIX FLUID IN PITS UNTIL ALL _ _ FLUID ON SURFACE IS AT 10.6-PPG. 19:00 - 19:30 0.50 CLEAN DECOMP HOLD PJSM WITH RIG CREW AND CH2MHILL TRUCK DRIVERS TO DISCUSS UPCOMING PUMPING AND FLUID MIXING OPERATIONS. ~ i -OUTLINE PUMPING SCHEDULE, IDENTIFY ~ ~ OPERATIONS FOR EACH VAC TRUCK, ASSIGN j TWO PEOPLE TO REMAIN IN PITS AT ALL TIMES. -HIGHLIGHT SPILL POTENTIALS AND THAT IT IS ~ ~ THE CREW'S LAST NIGHT OF WORK. _ 19:30 - 21:00 i 1.50 _ _ CLEAN _ DECOMP BEGIN DISPLACING WELL WITH 270-BBLS OF 10.6-PPG SODIUM BROMIDE KWF. -STAGE PUMPS UP TO 4-BPM WITH 1880-PSI. -6-BBLS LOSS THROUGHOUT CIRCULATION. -TAKE RETURNS TO VAC TRUCK THAT ALREADY HAS 20-BBLS OF 12-PPG SPIKE FLUID. -PUMP A TOTAL OF 277-BBLS BEFORE HAVING j TO STOP BLEND MORE 10.6-PPG KWF. Printed 7/8/2010 8:21:22AM North America -ALASKA - BP Page ~s of 1 Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS ~ AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud DatelTime: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date ~ From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ _ 21:00 - 23:30 2.50 CLEAN DECOMP MONITOR WELL WHILE VAC TRUCK BLENDS 10.5-PPG FLUID FROM WELL WITH 12-PPG SPIKE FLUID. -WELL INITIALLY FLOWS SLIGHTLY WITH NO MEASUREABLE GAIN IN PIT VOLUME. -FLUID LEVEL DROPS SLOWLY THOUGHOUT WAITING FOR 10.6-PPG KWF TO CONTINUE. -BRINGNN 290-BBLS OF 10.6-PPG KWF FLUID j i FROM VAC TRUCK. -PIT #2 FLUID WEIGHT = 10.7-PPG AND PIT #3 + FLUID WEIGHT = 10.5-PPG. ROLL PITS UNTIL DENSITY IN BOTH IS 10.6-PPG. 23:30 - 00:00 0.50 CLEAN ~ _ DECOMP RESUME DISPLACING WELL TO 10.6-PPG KWF AT 4-BPM WITH 1950-PSI. -STATIC LOSS RATE DERIVED FROM AMOUNT ~ OF FLUID NEEDED TO GET RETURNS = -2-BPH. -CRUDE AND_MINIMAL GAS RETURNS WHILE CIRCULATING. 6/11/2010 00:00 - 02:00 2.00 CLEAN ° P' DECOMP CONTINUE TO DISPLACE WELL TO 10.6-PPG 1 ' KWF AT 4-BPM WITH 1950-PSI. ' -CRUDE AND SLIGHTLY INCREASING GAS SEEN THROUGHOUT CIRCULATION. -RETURNS STILL WEIGH 10.5-PPG AFTER A TOTAL OF 753-BBLS 10.6-PPG PUMPED (HOLE VOLUME =641-BBLS). 02:00 - 03:00 ~ 1.00 CLEAN DECOMP MONITOR WELL WHILE BRINGING ON 290-BBLS ~ OF 10.6-PPG KWF. -MILD GAS BREAKOUT BUT FLUID LEVEL DROPPING. -MIX ADDITIONAL 100-BBLS OF 10.6-PPG FLUID ON SECOND VAC TRUCK WHILE WAITING FOR ~ FIRST TRUCK TO OFFLOAD. 03:00 - 04:30 1.50 CLEAN DECOMP CONTINUE TO DISPLACE WELL TO 10.6-PPG KWF AT 4-BPM WITH 1950-PSI. -STATIC LOSS RATE CALCULATED AT 3-BPH BASED ON AMOUNT OF FLUID PUMPED TO GET RETURNS. -CRUDE AND DIMINISHED GAS RETURNS WHILE CIRCULATING. -GET 10.6-PPG RETURNS WITH AN ADDITIONAL 134-BBLS PUMPED (887-BBLS TOTAL PUMPED). -CONTINUE TO CIRCULATE WHILE DISCUSSING OPTIONS WITH RWO ENGINEER. DECIDE TO RIH WITH 10-STDS TO JUST ABOVE LINER TOP (MULESHOE AT 18734'). -LOSS RATE _ -15-BPH WHILE CIRCULATING. 04:30 - 05:00 0.50 CLEAN , DECOMP MONITOR WELL. FLUID LEVEL DROPPING SLOWLY WITH SLIGHT GAS BREAKOUT. 05:00 - 06:00 i 1.00 CLEAN DECOMP RIH WITH FCO BHA ON 10-STDS OF 2-7/8" TUBING TO POSITION MULESHOE AT 18734'. Printed 7/8/2010 8:21:22AM r~ North America -ALASKA - BP Page 1a or 1 Operation Summary Report Common Well Name: MPL-20 DEAP DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud DatelTime: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 06:00 - 09:00 3.00 CLEAN DECOMP CBU W/ 10.6 PPG BRINE AT 18,734' MD, 4 BPM / 1950 PSI -LOST 27 BBLS (NO GAS NO OIL) -DISCUSS WITH ANCHORAGE RWO ENGINEER ~ TEAM, ON PLAN FORWARD. DECISION MADE TO PERFORM WEEKLY BOPE TEST (TEST DUE ~ 6/13/2010). _ 09:00 - 11:00 - 2.00 ~ - LEAN C _ DECOMP MONITOR WELL. FLUID LEVEL DROPPING SLOWLY -0905-HRS, iEAVE MSG ON AOGCC PAGER REGARDING PERFORMING WEEKLY BOPE TEST EARLIER THAN ANTICIPATED. JEFF JONES, AOGCC, RETURNED CALL AT 0907-HRS AND WAIVED STATE'S RIGHT TO WITNESS TEST. -10:00 HRS NOTIFIED THAT CONOCO PHILLIPS INJECTION WELL 30-14 IS IN THE PROCESS OF BEING SHUT-IN. -(-2) BPH LOSS RATE _ - - - 11:00 13:30 2.50 -- BOPSUR DECOMP MU WEAR RING RETRIEVING TOOL IN TO THE TBG STRING AND PULL WEAR RING. -RWO ETL ADVISES OF PLAN FORWARD TO DISPLACE WELL TO 11.1-PPG KWF AFTER WEEKLY BOPE TEST IS COMPLETE. 13:30 - 14:00 0.50 BOPSUR _ DECOMP MU AND INSTALL TEST PLUG. - -FILL BOP STACK, LINES AND CHOKE ~ MANIFOLD. 14:00 - 19:00 5.00 BOPSUR DECOMP PERF RM WEEKLY BOPE TEST. -TEST TO 250-PSI LOW AND 3500-PSI HIGH. -TEST 2-7/8" X 5" VBRS AND ANNULAR USING 2-7/8" TEST JT. -HOLD AND CHART EACH TEST FOR 5-MINUTES. -TEST WITNESSED BY NABORS TOOLPUSHER i i RICK BJORHUS AND BP WSL DAVE RHODES. -AOGCC REP JEFF JONES WAIVED STATE'S RIGHT TO WITNESS BOPE TEST. __ 19:00 - 20:00 1.00 BOPSUR DECOMP RD BOPE TEST EQUIPMENT. -INSPECT AND TIGHTEN DUTCH RISER FLANGE ON TOP OF BOP STACK. 20:00 - 21:00 1.00 BOPSUR DECOMP PULL TEST PLUG. ~ -FILL WELL AND CALCULATE LOSS RATE _ 3-BPH. 21:00 - 00:00 3.00 CLEAN DECOMP MONITOR WELL WHILE WAITING FOR SUFFICIENT VOLUME OF 11.1-PPG FLUID TO BE ON LOCATION TO DISPLACE WELL. -LOSS RATE = 4-BPH. -GENERAL PAINTING AND CLEANING WHILE WAITING FOR FLUID. 6/12/2010 00:00 - 03:00 3.00 CLEAN P DECOMP CONTINUE TO WAIT FOR SUFFICIENT VOLUME OF 11.1-PPG KWF ON LOCATION PRIOR TO BEGINNING DISPLACEMENT. I -LOSS RATE = 4-BPH. ~~~ G5 ~f~)l1° Printed 7/8/2010 8:21:22AM North America -ALASKA - BP P2ge 15 of i ~ Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. _ UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ~ Phase Description of Operations (hr) (ft) 03:00 - 07:00 4.00 CLEAN P DECOMP DISPLACE WELL TO 11.1-PPG BRINE. -HOLD PJSM WITH ALL CH2MHILL TRUCK DRIVERS, TRUCK PUSHER AND RIG CREW INVOLVED IN DISPLACEMENT OPERATION. DISCUSS POSITIONS OF PEOPLE, ORDER OF FLUIDS PUMPED, SPILL POTENTIALS AND OUTLINE OF OPERATION. -PUMP TUBING VOLUME STAGING PUMPS UP TO 4-BPM WITH 2080-PSI. ~ -ONCE 11.1-PPG BRINE TURNS THE CORNER, SLOW PUMP TO 3-BPM WITH 1200-PSI. -INITIALLY THICK CRUDE. RETURNS, BUT LESSENED QUICKLY: "CHAMPAGNE".BUBBLES OF GAS INITIALLY WITH SLIGHT INCREASE TOWARDS BOTTOMS UP. -DISPLACED WITH 763 BBLS 11.1 PPG BRINE. LOST -180 BBLS -14.1 PPG SURFACE TO SURFACE, PUMPS OFF AT 07:00 HRS. -- - 07:00 - 08:00 --- 1.00 , ~ CLEAN --_ P DECOMP MONITOR WELL. -21 BPH LOSS RATE -PERFORM DERRICK INSPECTION _ 08:00 - 14:30 i __ 6.50 _ CLEAN ' - P DECOMP POH FROM 18,734' MD W/ BHA #1 -FILL EVERY (5) STANDS -LOST 147 BBLS TO FORMATION. 14:30 - 16:00 1.50 CLEAN P DECOMP UD BHA #1 (30 JTS 2-7/8" FOX, MULE SHOE) 16:00 - 17:00 _ _ 1.00 _ CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. -STATIC LOSS RATE = 20 BPH. 17:00 - 18:00 01 0 RUNCOM P- RUNCMP R/U TO RUN ESP COMPLETION ON 2-7/8" TBG ' FROM DERRICK. _.. _ _ -BRING CANNON CLAMPS TO RIG FLOOR. 18:00 - 18:30 ~ 0.50 RUNCOM P RUNCMP PERFORM DAILY RIG SERVICE ACTIVITIES. _ _ LOSS RATE = 19-BPH. 18:30 - 22:00 3.50 RUNCMM P RUNCMP __ PU, MU, AND SERVICE ESP -BRING ESP CABLE OVER SHEAVE AND CONNECT MLE. -INSTALL 3-FLAT GUARDS, 5-PROTECTROLIZERS AND 1-MID JOINT CLAMP ON ESP. _____ _ ___ -LOSS RATE = 19-BPH. 22:00 - 00:00 2.00 RUNCMM P _ RUNCMP RIH WITH ESP COMPLETION ON 2-7/8" EUE 8RD I ~ ~ TUBING. -USE BEST O LIFE 2000 THREAD COMPOUND i AND MU 8RD CONNECTIONS TO OPTIMUM TORQUE OF 2300-FTLBS. -INSTALL ONE CANNON CLAMP ON EVERY CONNECTION. -MAINTAIN CONTINUOUS HOLE FILL. -LOSS RATE = 14 TO 18-BPH. Printed 7/8/2010 8:21:22AM ~~ r 1 North America -ALASKA - BP Page 16 of 17 Operation Summary Report __ Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2010 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations i (hr) (ft) 6/13/2010 1 00:00 - 06:00 6.00 _ RUNCMM P RUNCMP RIH WITH ESP COMPLETION ON 2-7/8" EUE SRD TUBING. -USE BEST O LIFE THREAD COMPOUND ON ALL CONNECTIONS. -INSTALL ONE CANNON CLAMP ON EVERY CONNECTION. -FLUSH MOTOR WITH 5-BBLS BRINE FOR EVERY 2000' RlH WHILE CHECKING ESP CABLE CONDUCTIVITY. 20-STDS RIH = 3-BPM WITH 180-PSI, 40-STDS RIH = 3-BPM WITH 290-PSI. I -MAINTAIN CONTINUOUS HOLE FILL WHILE RIH. -LOSS RATE _ -11-BPH. RIH TO JOINT #185. 06:00 - 06:30 0.50 RUNCOM _ P RUNCMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 08:30 2.00 RUNCMM P RUNCMP CONTINUE RUN COMPLETION F/JOINT #185 T/ JOINT #245 -FLUSH MOTOR W/ 5 BBLS, 2 BPM / 310 PSI 08:30 - 10:30 2.00 RUNCMM P RUNCMP CENTRILIFT REP PERFORM REEL TO REEL CABLE SPLICE . :FLUSH MOTOR W/ 5 BBLS, 2 BPM / 310 PSI -MAINTAIN CONTINUOUS HOLE FILL. -STATIC LOSS RATE = 12 BPH. _ ___ ~ 10:30 18:00 7.50 i RUNCOM P RUNCMP CONTINUE TO RUN COMPLETION F/JOINT #245 T/ JOINT #480. -MAINTAIN CONTINUOUS HOLE FILL -INSTALL CANNON CLAMP ON EVERY CONNECTION UNTIL JOINT #375, THEN INSTALL CANNON CLAMP ON EVERY OTHER CONNECTION. -LOSS RATE = 14-BPH. ___ 18:00 - 18:30 0.50 RUNCOM P RUNCMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 18:30 - 19:00 0.50 RUNCOM P _ RUNCMP CONTINUE TO RUN COMPLETION F/ JOINT #480 TO JOINT #495. ~ -INSTALL CANNON CLAMP ON EVERY OTHER CONNECTION. -MAINTAIN CONTINUOUS HOLE FILL -LOSS RATE = 14-BPH. _ 19:00 - 22:30 3.50 RUNCMM P RUNCMP CENTRILIFT REP PERFORM REEL TO REEL CABLE SPLICE. I -HOLD WEEKLY SAFETY MEETING WITH TINSLEY CREW. -STATIC LOSS RATE = 12-BPH. 22:30 - 00:00 1.50 RUNCMM P RUNCMP CONTINUE TO RIH WITH ESP COMPLETION FROM JOINT # 495 TO JOINT #585. -INSTALL CANNON CLAMP ON EVERY OTHER CONNECTION. -MAINTAIN CONTINUOUS HOLE FILL. -LOSS RATE = 14-BPH. Printed 7/8/2010 8:21:22AM North America -ALASKA - BP Page ~ ~ or ~ ~ Operation Summary Report Common Well Name: MPL-20 DEAP_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5 /3 012 0 1 0 End Date: 6/14/2010 X4-0009E-E (625,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: 6/14/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 30:20 3/6/1998 15:00 @37.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 6/14/2010 00:00 - 01:00 1.00 RUNCOM P RUNCMP CONTINUE TO RIH WITH COMPLETION FROM JOINT #585 TO JOINT #593. -INSTALL CANNON CLAMP ON EVERY OTHER CONNECTION. -RUN TOTAL OF 484-CANNON CLAMPS, 2-FLAT GUARDS, 5-PROTECTROLIZERS AND 1-MID-JOINT CLAMP. -FLUSH PUMP AT 2-BPM WITH 440-PSI. i -MAINTAIN CONTINUOUS HOLE FILL. -LOSS RATE = 14-BPH. 01:00 - 02:00 1.00 RUNCOM P RUNCMP MU LANDING JOINT TO TUBING HANGER AND ~ THEN MU HANGER TO STRING. 02:00 - 04:00 2.00 RUNCOM P _ RUNCMP CENTRILIFT REP SPLICE FIELD CONNECTOR TO ESP CABLE. ~ -PLUG ESP CABLE INTO PENETRATOR AND ' TEST. __ _ -STATIC LOSS RATE = 11-BPH. 04:00 - 04:30 0.50 RUNCMM P ~ RUNCMP LAND ESP COMPLETION. -PU WT = 68K-LBS, SO WT = 35K-LBS. FMC REP RILDS. -LD LANDING JOINT. _____ 04:30 - 06:00 1.50 RUNCOM __ P RUNCMP FMC REP T-BAR IN TWC. -PERFORM ROLLING TEST BELOW at 1-BPM ~ WITH 300-PSI FOR 10-CHARTED MINUTES. ~ -TEST ABOVE TO 3500-PSI FOR 10-CHARTED MINUTES. ____ 06:00 - 07:30 _ 1.50 _ RUNCMM P RUNCMP N/D BOPE 07:30 - 09:00 1.50 RUNCMM P RUNCMP N/U 2-9/16" PRODUCTION TREE -FMC REP TESTED HANGER VOID TO 5000 PSI F/ - 30 MINUTES. -- _ ----------1 09:00 - 12:00 ' ---- 3.00 WHSUR - P ----- RUNCMP M/U AND TEST LUBRICATOR TO 500 PSI W/ DIESEL -WELL SUPPORT TECH PULLED TWC, AND I INSTALL TYPE 'H' BPV -PERFORM BPV ROLLING TEST FROM BELOW -2 BPM / 500 PSI -SECURE WELL -CLEAN PITS AND TRANSFER FLUID TO i ( STORAGE TANK ON TEXACO PAD. ***RELEASE RIG AT 12:00 HRS. 6/14/2010*** Printed 7/8/2010 8:21:22AM Tree: 2 9/16" - 5M FMC Wellhead:11" x 7" 5M FMC Gen 5a . w/ 2 7/8" WKM Tubing Hanger , w/ 3" Acme Threads , 2.5" CIW H BPV profile 115' ~ 20" 91.1 ppf, H-40 KOP @ 400' Max. hole angle = 76 to 79 deg. f/ 3500' to TD Hole angle thru' perfs = 33 deg 9 5/8", 40 ppf, L-80 Btrc. 8160' and 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. (drift ID = 2.347", cap. = 0.00592 bpf ) 7", 26 ppf, L-80, Btrc. Mod. prod. casing (drift ID = 6.151", cap. = 0.0383 bpf ) 4.5" 12.6 ppf, L-80 Mod (drift ID = 3.958" ,cap = .0152 bpf ) Intake ND - 6457' Intake MD - 18733' 4.5" Liner Top ND - 6493' 4.5" Liner Top MD - ,18838' Mid-pert TVD - 6697' Mid-perf MD - 19385' PBTD TVD - 6785' PBTD MD - 19600' Stimulation Summary 03/11/98 - Kup. A Sand -104 M# 20/40 Carbolite & 35 M# of PropLok coated 11 Carbolite behind pipe Perforation Summary Ref log: Anadrill LWD 8/2/97 Size SPF Interval (ND) 2-7/8" 6 19370'-19400 6677'-6716' TCP shot MPU L-20 Orig. DF Elev~9.85' (N22E) Orig. GL Elev. .8' DF To Tbg. Spool = xxx' (N22E) Camco 2-7/8" x 1" sidepocket KBMM GLM 9 5/8" Howco `ES' Cementer 139' 2123' 7" Howco `ES' Cementer Two 7" x 21' short joints from 18,568' to 18,610' and 2 7/8" HES "XN" Nipple (2.250" ID) Auto Diverter Valve Discharge Head: GPVDIS Centrilift ESP 119-P23 SXD Intake Gas Separator: GRSFTXARH6 Tandem Seal Section: GSB3DBUT/LT SB/SB PFSA/FSA CLS Motor: KMH CL-6 190 hp 2415v/48A Pumpmate XTO w/6 fin Centralizer 10,447' 18,687` 18,729` 18,735` 18,736` 18,753' 18,758` 18,772` 18,788` 7"x 4.5" Baker "ZXP" Pkr. "HMC" Hydraulic liner hang 18,838' 7"x5" Baker liner hanger 18,852' 7" float shoe 19,104' RA Tag 19,192' Fill Clean out @ 19,600` 6/14/10 by Nabors 4ES(no fill) 4.5" landing collar 19,600' 4.5" Float collar 19,684' 4.5" Float shoe 19,770' DATE EV. BY 03/22/98 M. Linder 7 4 asebe 06/20/06 R. Hand 07/24/06 L. Hulme 11/28/07 REH 6/14/10 REH COMMENTS RWO Nabors 4-ES RWO Nabors 4ES RWO Nabors 4ES MILNE POINT UNIT WELL L-20 API NO: 50-029-22790 BP EXPLORATION (AK) MPL-20 plan forward • Page 1 of 2 Schwartz, Guy ~ (DOA) From: Schwartz, Guy L (DOA) "~ Sent: Friday, June 11, 2010 2:08 PM t`~~ To: 'Baca, Hank' Cc: Sarber, Greg J; Engel, Harry R; Rossberg, R Steven ~ cl ~' ~ 3 Subject: RE: MPL-20 plan forward Hank, As per our discussion on the phone you have verbal approval to continue the operation as outlined below. The MASP of the well is above the AOGCC limit of 3000 psi which requires a 4 ram BOP stack. (4ES has a 3 ram stack) However, changing out the BOP's at this point in the well operation would be less safe than continuing the operation. Points of argument include: 1) the BOP will be freshly pressure tested as of today. 2) the well will be completed in about 2 days or less. 3) pulling the rig off immediately and changing BOP stacks would involve setting a shallow depth storm packer .. gas migration to the surface under the packer would be very likely during the delay. Regards, Guy Schwartz . ~ ~. {t; .`.; +f'~1'` Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Friday, June 11, 2010 12:31 PM To: Schwartz, Guy L (DOA) Cc: Sarber, Greg J; Engel, Harry R; Rossberg, R Steven Subject: MPL-20 plan forward Guy, sorry for the delay. Current status: RU for weekly BOP test. -2bph losses with 10.6ppg in the hole. We are on bottom with 2-7/8" tubing and a muleshoe used to wash fill. Mid pert is 6696' TVD. Assuming a 0.1psi/ft gas column, (and that 10.6ppg is EMW for reservoir pressure) MASP is ~3005psi. We cannot install a 4~' preventer without ND and moving the rig out of the way. We feel finishing the well is safer than tripping out, setting a deep barrier, a shallow barrier and moving the rig on and off. Plan forward: Finish weekly BOP test Weight up from 10.6ppg to 11.1 and displace well. Verify loss rate stable POOH with tubing standing back. LD extra cleanout joints. PU ESP on tubing in derrick and RIH 6/11/2010 MPL-20 plan forward • Page 2 of 2 Set TWC ~ test, ND BOP, NU tree, RDMO We will maintain continuous hole fill while performing all of this work and monitor loss rate. The 0.5ppg additional mud weight provides 174 psi overbalance. Conoco just shut-in the Kuparuk injector we suspect caused the ~0.2ppg increase over the last 3 days. Tripping out of the hole and running completion is expected to take ~36 hours. This should give us both twice the amount of time and twice the pressure build up we've seen so far. This allows for time delays while finishing work and delayed response from injector shut-off. Thanks for your prompt attention and please let me know if you have questions. Wank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell 6/11/2010 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS a ,z., „- ,~ {i _~ 1. Operations Performed: ;{ ~~..w ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Welt ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-136 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22790-00-00 ' 7. KB Elevation (ft): 49 85 ~ 9. Well Name and Number: MPL-20 8. Property Designation: 10. Field /Pool(s): ADL 025514 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 19770 ~ feet true vertical 7022 'feet Plugs (measured) N/A Effective depth: measured 19601 feet Junk (measured) N/A true vertical 6873 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' 1490 470 Surface 8123' 9-5/8" 8160' 3546' 5750 3090 Intermediate Production 19071' 7" 19104' 6462' 7240 5410 Liner 932' 4-1/2" 18838' - 19770' 6248' - 7022' 8430 7500 Perforation Depth MD (ft): 19370' - 19400' Perforation Depth TVD (ft): 6676' - 6701' Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 18681' Packers and SSSV (type and measured depth): 7" x 4-112" Baker ZXP packer 18838' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbf Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 920 Subsequent to operation: 801 ~ 584 603 300 258 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ~ ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ~ ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Aras Worthington, 564-4102 NIA Printed Name Sondra Stewman Title Drilling Technologist Si Prepared By Name/Number: la ) 1 g ure Phone 564-4750 Date l , , 0 Sondra Stewman, 564-4750 Form 10-4~vised 04/2006 '` Submit Ori final Onl ~v /~jG-oL Tree: 2 9/16" - 5M F~111~! Wellhead: 11" x 7" 5M FMC Gen 5 w/ 2 7/8" WKM Tubing Hanger , w/ Acme Threads , 2.5" ClW H BPV profile 20" 91.1 ppf, H-40 115' MPU L-20 Orig. D~v. = 49.85' (N22E) Orig. GL lev. = 16.8' DF To Tbg. Spool = xxx' (N22E) KOP @ 400' Max. hole angle = 76 to 79 deg. f/ 3500' to TD Hole angle thru' perfs = 33 deg 9 5/8", 40 ppf, L-80 Btrc. 8160' and 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. (drift ID = 2.347", cap. = 0.00592 bpf ) 7", 26 ppf, L-80, Btrc. Mod. prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 4.5" 12.6 ppf, L-80 Mod (driftlD=3.958",cap=.0152 bpf) Intake TVD - 6457' Intake MD - 18733' 4.5" Liner Top TVD - 6493' 4.5" Liner Top MD - ,18838' Mid-pert TVD - 6697' Mid-perf MD - 19385' PBTD TVD - 6785' PBTD MD - 19600' Stimulation Summary 03/11/98 - Kup. A Sand - 104 M# 20/40 Carbolite & 35 M# of PropLok coated 1 E Carbolite behind pipe Perforation Summary Ref log: Anadrill LWD 8/2/97 Size SPF Interval (TVD) 2-7/8" 6 19370'-19400 6677'-6716' TCP shot Camco 2-718" x 1" 139' sidepocket KBMM GLM 9 5/8" Howco 'ES' 2123' Cementer 7" Howco `ES' Cementer 10,447' Two 7" x 21' short joints from 18,568' to 18,610' and 2 7/8" HES "XN" Nipple 18,564` (2.250" ID) Discharge Head: GPVDIS 18,607` Tandem Pumps 18 608` PMSXD 1:5, 74P31 , Intake Gas Separator: 18,637' GRSFTXARH6/Tandem Tandem Seal Section: 18,642` GS63DBFERHLSSCVSB/SBPFSA Motor: 18,655` KMHG/228 2305vt/60amp Rerate- KMH-A/165 2133vt/46amp Phoenix XT-1-14294 18,675' w/6 fin Centralizer PumpMate TVD 6197` 7"x 4.5" Baker "ZXP" Pkr. "HMC" Hydraulic liner hang 18,838' 7"x5" Baker liner hanger 18,852' 7" float shoe 19,104' RA Tag 19,192' Fill Clean out @ 19,600` 11/28/07 by Nabors 4ES 4.5" landing collar 19,600' 4.5" Float collar 19,684' 4.5" Float shoe 19,770' DATE ~2EV. BY ~ COMMENTS Linder 06/20/06 R. Hand RWO Nabors 4-ES 07/24/06 L. Hulme RWO Nabors 3S 11/28/07 ~ REH ~ RWO Nabors 4ES MILNE POINT UNIT WELL L-20 API NO: 50-029-22790 BP EXPLORATION (AK) • • BP EXPLORATION:` Page 1 of 3 Operations Summary'Report Legal Well Name: MPL-20 Common Well Name: MPL-20 Spud Date: 7/27/1997 Event Name: WORKOVER Start: 11/26/2007 End: 12/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/2/2007 Rig Name: NABORS 4ES Rig Number: Date I from.- To ~ Hours ~ Task f Code l NPT i 11/25/2007 102.30 - 16:00 I 3.501 MOB I P 16:00 - 18:00 2.00 RIGU P 18:00 - 18:30 0.50 RIGU P 18:30 - 21:00 2.50 RIGU P 21:00 - 23:00 2.00 PULL N 23:00 - 23:30 23:30 - 00:00 PULL I P PULL IP 11/26/2007 00:00 - 01:00 1.00 PULL P 01:00 - 02:00 1.00 PULL P 02:00 - 02:30 0.50 PULL P 02:30 - 06:00 3.50 PULL P WAIT 06:00 - 10:00 4.00 KILL P 10:00 - 00:00 14.00 PULL N WAIT 111/27/2007 100:00 - 12:30 I 12.501 KILL I N 12:30 - 14:30 I 2.00 I KILL I P 14:30 - 18:30 4.00 KILL P 18:30 - 19:30 I 1,001 KILL { P WAIT 19:30 - 20:00 I 0.50 PULL I N f WAIT 20:00 - 22:00 2.00 PULL P Phase Description of Operations PRE PJSM. Scope & lay down derrick. Rig down rig components. PRE PJSM. PRE Move Rig & all rig components from MPE-22 to MPL-20. MPE pad operator witnessed moving sub off well. PRE MIRU on MPL-20. Spot sub, pipe shed and pits. PRE Crew change. Walk thru & inspect derrick. PRE Raise & scope up derrick. Install mud lines. & R/U equip. DECOMP Accepted rig @ 21:00 hrs. Wait on trucks to move tiger tank & deliver kill fluids. Hold weekly safety meeting w/ all hands. DECOMP P/U lubricator & test to 500 psi. Pull BPV. LiD lubricator & TWC. DECOMP Take on produced water from MPU plant to kill well. R/U kill lines. DECOMP Con't to take on kill fluid. DECOMP Spot tiger tank & R/U lines. Purge lines w/ steam. DECOMP Hold PJSM & review kill procedure. Assign tasks to personnel. DECOMP Test lines to 3500 psi. Open well: SITP = 840 psi, SICP = 1030 psi. OAP = 80 psi. Bled off SI pressures to 270 psi. Circulate & kill well. Pump 3.5 BPM @ 1350 psi & increased to 1490 psi. CP increased from 410 psi to 510 psi. OAP increased to 200 psi. At 400 bbls, S/D & check tiger tank recovered -230 bbls. Con't to circulate & kill well. Obtained clean returns at 802-Bbls. pumped. S/D pumping and shut-in tubing and IA to monitor well. DECOMP Monitor SITP and SICP. (SITP = 150-psi. SITP trending downward and stabilized at 120-psi after 5 hrs. Mid-pert TVD = 6697'. Fluid weight used to circulate well = 8.4-ppg. Calculated EMW to balance well = 8.73-ppg. EMW to allow a 150-psi overbalance = 9.2-ppg. Agreed with RWO engineer to weight up to 9.1-ppg heavy brine weight. DECOMP Wait on 1000-Bbls. of 9.2-ppg NaCUNaBr kill weight brine to arrive from MI mud plant in Deadhorse due to Doyon 14 rig blocking traffic on MPU Spine Road near MPK pad intersection. Crew currently cleaning rig and performing maintenance. DECOMP Wait on 9:2 ppg brine. Unable to get fluid due to Doyon 14 rig break down on Milne Point road near MPK Pad access. Clean, service & paint rig. Doyon 14 rig re-commenced moving at 0715-hrs. Brine ordered from MI at 0730-hrs. to have trucks lined up behind rig to get by it as soon as it clears MPU Spine Road. DECOMP PJSM. Take on 9.2 ppg fluid. DECOMP SICP prior to pumping was 570 psi, SITP was 120 psi. Bled gas off casing, (small quantity), and SICP was 120 again. PJSM. Bring on pump @ 3 bpm / 1150 psi, holding 200 psi back pressure on choke, taking Fluid returns to tiger tank. Kill well, Pump 4 BPM @ 1710 psi. Pumped total of 850 bbls. S/D & monitor weN. Pressure dropped to 0 psi. After 5 min tubing went on Vacuum. Had 600 bbls returned to surface. DECOMP Leave well open & monitor same. Perform derrick inspection & check PVT alarms. Well dead. DECOMP Wait on FMC (late because of of Doyon #14 camp move) DECOMP P/U TWC & install in tubing hanger. Fill stack & pressure test Printed: 12/412007 8:40:41 AM • BP EXPLORATION Page 2 of 3- Operations Siummary Report Legal Well Name: MPL-20 Common Well Name: MPL-20 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date I From - To I Hotars Task Code I NPT 11/27/2007 20:00 - 22:00 22:00 - 23:00 23:00 - 00:00 11128!2007 00:00 - 01:00 I 01:00 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 09:30 09:30 - 10:30 10:30 - 18:00 18:00 - 18:30 18:30 - 23:30 23:30 - 00:00 11/29/2007 00:00 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 09:30 09:30 - 11:30 11:30 - 15:30 15:30 - 16:00 16:00 - 16:30 16:30 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 23:00 23:00 - 00:00 11/30/2007 00:00 - 06:00 06:00 - 06:30 2.00 PULL P 1.00 WHSUR P 1.00 BOPSU P 1.00 BOPSU P 5.00 BOPSU P 0.50 PULL P 0.50 PULL P 1.00 PULL P 1.50 PULL P 1.00 PULL P 7.50 PULL P 0.50 PULL P 5.00 PULL P 0.50 PULL P 2.00 PULL P 1.00 PULL P 1.50 CLEAN P 5.00 CLEAN P 2.00 CLEAN P 4.00 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 1.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 4.00 CLEAN P 1.00 CLEAN P 6.00 CLEAN P 0.50 CLEAN P Spud Date: 7/27/1997 Start: 11/26/2007 End: 12/2/2007 Rig Release: 12/2/2007 Rig Number: Phase Description. of Operations DECOMP TWC. Had leak in tree cap. Install test cap & test TWC to 3500 psi for 10 min. Pressure test TWC from bottom by pumping in annulus @ 4 BPM. Max. Pressure 1000 psi. Tested for 10 min total. Took 11 bbls to pressure up. Est FL @ --350'. Charted testing operations. Bleed off & R/D test equip. DECOMP Bleed off hanger void. N/D tree & adapter flange. Inspeact threads, Ok. Install 3" L/H Acme X-over w/ 8 112 turns. Remove same. DECOMP N/U DSA & BOPE. DECOMP Con't to N/U BOPE. DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi. HP 3500 psi. Tested rams w/ 2 7/8" test jt. BOP test witnessing waived by Jeff Jones w/ AOGCC. DECOMP Service rig, check crown o matic, PVT system, OK. DECOMP PJSM. Take fluid level shot, fluid level @ 250'. DECOMP PJSM. M/U landing joint, BOLDS. Pull hanger to floor, hanger off seat @ 40K, total up wt max = 105K. DECOMP PJSM. UD hanger, POOH w/ 2 7!8" tubing. DECOMP Safety meeting w/ crew, James Willingham, Dave Cain, Nabors Tool Pusher and BP WSL. DECOMP Continue to POOH w/ 2 7/8" 8 rnd ESP completion. DECOMP Crew change. Check PVT alarms. Inspect derrick. DECOMP Continue to POOH w/ 2 7/8" 8 rnd ESP completion. Recovered 197 stands of 2 7/8" tubing, 507 LaSalle Clamps (2 Bad), 6 Protectolizers, 3 Flat Guards, 10' pup, 8' pup, and GLM assembly. LD 1 joint 2 7/8" tubing (perforated joint below XN nipple). DECOMP LD ESP assembly per Baker Centralift rep. DECOMP LD ESP. Inspection by centralift rep revealed both pumps locked up, intake was gritty, but motor and cable were both OK. DECOMP Clear and clean rig floor. Rig up handling tools for 2 3/8" tubing. DECOMP PU MU 2 3!8" muleshoe, 31 jts 2 3/8", 5.95# N-80 PH tubing, 2 3/8" x 2 7/8" X/O, TL 992.39'. RIH with same. DECOMP TIH w/ 2 7/8" tubing from derrick. DECOMP PJSM. Slip & cut 84' of drilling line. Check crown o matic, OK. DECOMP PJSM. Continue to RIH w/ cleanout assembly on 2 7/8" tubing. 190 stands. (18,827') DECOMP PJSM. M/U headpin & circulate down thru top of liner. Up wt 74K, down wt 18K. Pump @ 3 bpm / 1000 psi. Smooth thru liner top @ 18,838'. DECOMP Continue to RIH. Tag top of fill @ 19,487'. DECOMP Establish cleanout parameters. Up wt 75k Ibs, down wt 18k lbs. RU circulating hose. Wash down from 19,487' to 19,489'. Pump long way DECOMP Service Rig. Check PVT alarms and perform derrick inspection. DECOMP PU joint # 594. Circ down to 19,580'. Reverse circulate btms up 3 bpm @ 830 psi. 60 bph losses. DECOMP PU joint # 595. Circ down to 19,600'. Reverse circ btms up 3 times 3bpm @ 830 psi. Tagged hard @ 19,600'. DECOMP Blow down lines and monitor well for flowback. DECOMP POOH with cleanout assembly. LD first 4 joints of 2 7/8" tubing. Stand remaining 2 718" tubing back in derrick. DECOMP PTSM. Check PVT system, crown o matic, inspect derrick, OK. Printed: 12!4/2007 8:40:41 AM • • BP EXPLORATION' Page 3.of 3 Operations Summary Report Legal Well Name: MPL-20 Common Well Name: MPL-20 Spud Date: 7/27/1997 Event Name: WORKOVER Start: 11/26!2007 End: 12/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12(2/2007 Rig Name: NABORS 4ES Rig Number: Date 11 /30/2007 From - To' Hours I .Task I Code I NPT I Phase I Description of Operations I 06:00 - 06:30 0.50 CLEAN P 06:30 - 10:00 3.50 CLEAN P 10:00 - 11:00 1.00 CLEAN P 11:00 - 12:00 1.00 CLEAN P 12:00 - 16:00 4.00 CLEAN N 16:00 - 18:00 ~ 2.00 18:00 - 18:30 0.50 18:30 - 21:00 I 2.50 21:00 - 00:00 I 3.00 12/1/2007 100:00 - 05:00 I 5.001 RU 05:00 - 06:00 i 1.00 I RU 06:00 - 06:30 I 0.501 RU 06:30 - 15:00 l 8.501 RU 15:00 - 18:00 I 3.00 I RU 18:00 - 18:30 0.50 RU 18:30 - 19:00 l 0.50 19:00 - 22:00 3.00 22:00 - 00:00 I 2.00 12/2/2007 00:00 - 01;00 I 1.001 RUNCOf~j~P 01:00 - 02:30 1.501 WHSUR I P 02:30 - 04:00 1.50 WHSUR P 04:00 - 06:00 2.00 WHSUR P 06:00 - 08:00 2.00 WHSUR P DEGOMP DECOMP PJSM. Continue to POOH w/ 2 7/8" tubing. DECOMP PJSM. L/D 2 3/8" pipe & cleanout assembly. DECOMP Clear /clean rig floor, prep to pick up ESP. WAIT RUNCMP Wait on wind. Wind speed and direction coming from beaver slide side of rig, making it unsafe to run pipe from the derrick. Decision made to wait for wind to subside. RUNCMP PJSM. Pick up, make up, and service ESP assembly. RUNCMP Crew change. Check PVT alarms, crowm o matic, inspect derrick, OK. RUNCMP Pull ESP cable (new #1 solid SS CEBER) over sheave. Plug in cable to ESP, install flat guards and protectolizers, and test cable. RUNCMP RIH with ESP on 2 7!8" 6.5#, L-80, EUE 8 Rd tubing, Check cable conductivity and pump through motor every 2,000'. RUNCMP RIH with ESP on 2 7/8" 6.5#, L-80, EUE 8 Rd tubing. Check cable conductivity and pump through motor every 2,000'. RUNCMP Change Reels. Make reel-to-reel splice. 82 stands in hole (7,830'). RUNCMP PJSM. Service rig, check crown o matic, PVT system, derrick inspection, OK. RUNCMP Continue to RIH with ESP on 2 7/8" 6.5#, L-80, EUE 8 Rd tubing. Check cable conductivity and pump through motor every 2,000' @ 1 1/2 bpm / 1280 psi, pumping a total of 5 bbls each time, 161 stands in the hole. RUNCMP Change Reels. Make reel-to-reel splice. RUNCMP Crew Change. Service rig, check crown o matic, PVT system, derrick inspection, OK. RUNCMP Continue making reel-to-reel splice. RUNCMP Continue to RIH with ESP on 2 718" 6.5#, L-80, EUE 8 Rd tubing. Check cable conductivity and pump through motor every 2,000' @ 1 1/2 bpm / 1280 psi, pumping a total of 5 bbls each time. RUNCMP PU Landing Joint and MU hanger. Install penetrator, attach connection, plug in, and test. RUNCMP Land hanger, RILDS and LD landing joint RUNCMP Set TWC. Test TWC from above to 1,000psi for 10 charted minutes. Attempt to test from below to 1,000psi. Able to test from below to 1,000psi while pumping 2bpm. RD and blow down lines. RUNCMP ND BOPE RUNCMP NU tree. RUNCMP PJSM. Service rig, test tree to 5000 psi, set BPV, test from below @ 1000 psi, OK. Secure well, release rig @ 08:00 hrs. Printed: 12!4(2007 8:40:41 AM . STATE OF ALASKA lit SL!6)è6 ALA OIL AND GAS CONSERVATION COM.,ON REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Convnission RECEIVED AUG 1 4 2006 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 197-136 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22790-00-00 7. KB Elevation (ft): 49.85 9. Well Name and Number: MPL-20 8. Property Designation: 10. Field 1 Pool(s): ADL 025514 Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 19770 feet true vertical 7022 feet Plugs (measured) NIA Effective depth: measured 19601 feet Junk (measured) NIA true vertical 6873 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' 1490 470 Surface 8123' 9-5/8" 8160' 3546' 5750 3090 Intermediate Production 19071 ' 7" 19104' 6462 7240 5410 Liner 932' 4-1/2" 18838' - 19770' 6248' - 7022' 8430 7500 ,SCAf\!~Ë.O (~, I l: ç, Perforation Depth MD (ft): 19370' - 19400' Perforation Depth TVD (ft): 6676' - 6701' 2-7/8",6.5# L-80 18773' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker ZXP packer 18838' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: 0 0 0 200 Subsequent to operation: 1195 346 314 380 301 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 Printed Name Sondra Stewman Title Technical Assistant ,/~v . . _ ~'. Prepared By Name/Number: S!gnatur ~(r>v~e ~~ .-J Phone 564-4750 Date08 - t \ -CC¡:> Sandra Stewman, 564-4750 Form 10-404 Revised 04/2006 ORIGINAl RBDMS BFL AUG 1 6 2006 Submit Original Only . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-20 MPL-20 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 7/17/2006 7/26/2006 N3S Spud Date: 7/27/1997 End: 7/17/2006 12:00 - 00:00 12.00 RIGU P Move Camp from MPF Pad. MIRU Nabors 3S on MPL-20. 7/18/2006 00:00 - 02:00 2.00 RIGU P PRE Conitune to R/U on well. Accept Rig @ 0100 hrs. 02:00 - 04:00 2.00 RIGU P PRE Position Tiger Tank, hammer up hard line, and test. PJSM wI VECO and Rig crew. Pull BPV wI lubricator. T/I/O = 70170/0 psi. 04:00 - 06:00 2.00 KILL P DECOMP Pump 115 Bbls of 9.1 ppg brine down Tubing while taking returns to the Tiger Tank. Close Choke and attempt to bullhead into formation. Reduce rate to 1 BPM, IA to 1500 psi. Shut down. IA pressure holding steady. 06:00 - 10:00 4.00 KILL P DECOMP Open choke and circulate 9.1 #/gal brine down tubing, returns from IA @ 4 BPM, 1450 Tbg pressure, 100 psi on IA. Circulate 700 Bbls get 9.1 #/gal returns. Shut down and Flow Check the Well for 30 minutes. Tbg and IA - 0 psi. Lubricate and set TWC. Test from below to 1500 psi. OK. 10:00 - 23:00 13.00 BOPSU P DECOMP ND tree. NU BOPE. Contact Chuck Scheve wI AOGCC waived State witness of BOPE test @ 18:00. Blow down hard line, and disconnect from Tiger Tank. Move Tiger Tank and hard line to make way for ESP cable spooling unit. Function test BOPE and RU to test same. 23:00 - 00:00 1.00 BOPSU DECOMP Start testing BOPE to 250 psi low I 3500 psi high. 7/19/2006 00:00 - 02:30 2.50 BOPSU DECOMP Continue testing BOPE to 250 psi low test! 3500 psi high test. 02:30 - 04:00 1.50 PULL DECOMP RD BOPE testing equipment. RU Wells Support to pull TWC. Check pressure for trapped pressure and pull TWC. 04:00 - 06:00 2.00 PULL DECOMP RD lubricator and RU for pulling ESP completion. 06:00 - 07:30 1.50 PULL DECOMP PUMU landing joint wI XO to 3" LH Acme thread for top of hanger. MU to hanger. Open IA with 0 psi, break out LDS. Pull hanger to floor wI 82K #'s PU weight. load hole wI 2 Bbls 9.1 #/gal brine. Cut ESP cable, break out and lay down Tbg hanger. POOH and run ESP cable over shieve to spooler. 07:30 - 09:30 2.00 PULL DECOMP Wait on MPU electrician for connecting genset to spooling unit. 09:30 - 10:30 1.00 PULL DECOMP Make electrical modifications to connect genset to spooling unit. Function test. OK 10:30 - 13:30 3.00 PULL DECOMP POH ESP completion, standing back 2 7/8" Tbg in Derrick. Keeping hole full wI 9.1 #/gal brine wI charge pump as POH. ESP cable splice @ 2600'. Change spools on spooling unit. 50 Stands OOH. 13:30 - 23:00 9.50 PULL DECOMP Continue POOH standing back 2 7/8" DP in Derrick to stand number 172. Losses @ -1 Bbl/Hr. 23:00 - 00:00 1.00 PULL DECOMP Start changing out spool on spooling unit. 7/20/2006 00:00 - 02:00 2.00 PULL DECOMP Continue changing out spool. Load new spool on spooler. 02:00 - 06:00 4.00 PULL DECOMP Continue POOH wI ESP completion, standing back 2 7/8" Tbg in Derrick. 250 stands out of 296 OOH. 06:00 - 09:00 3.00 PULL DECOMP 297 Stands of 27/8" Tbg stood back in Derrick. Confirm Tbg punch in 1 st joint above XN nipple. Break out and lay down joint wI XN. 09:00 - 10:00 1.00 PULL DECOMP POH to ESP motor. Pull pot head connector. Motor oil burnt, and motor grounded out. (Motor fried). RBIH and inspect pump. Pump shaft froze up, unable to rotate. Slight traces of carbolite and formation fines in pump. Intake clean and clear. 10:00 - 12:00 2.00 PULL DECOMP BOLD ESP assembly. Recovered 493 LaSalle clamps, 3 Flat guards, and 5 protectolators. Load 2 3/8" DP into pipe shed. Stap and drift wI 1.75" rabbit. 12:00 - 13:00 1.00 PULL DECOMP Clean and Clear rig floor and pipe shed of ESP assembly. PU Printed: 7/31/2006 11 :00:32 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-20 MPL-20 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 7/17/2006 Rig Release: 7/26/2006 Rig Number: N3S Spud Date: 7/27/1997 End: 7/20/2006 12:00 - 13:00 1.00 PULL DECOMP handling tools and prep for running 2 3/8" DP. 13:00 - 15:00 2.00 CLEAN DECOMP PUMU 2 3/8" Muleshoe on 1102' of 2 3/8" 5.95 #/ft DP. BHA OAL - 1107' 15:00 - 20:30 5.50 CLEAN DECOMP RIH wI 2 3/8" MS I DP assembly on 86 stands of 2 7/8" Tbg from Derrick. 20:30 - 00:00 3.50 CLEAN DECOMP Inspect drill line and found to be frayed. Slip and cut out entire worn section (192 feet). 7/21/2006 00:00 - 06:00 6.00 CLEAN DECOMP Continue RIH w/2 3/8" MS I DP on 2 7/8" TBG from derrick. 215 of 296 stands in the hole. 06:00 - 09:00 3.00 CLEAN DECOMP 283 Stds in hole. Mix 30 Bbls Viscous pill. 09:00 - 11 :30 2.50 CLEAN DECOMP Pump 15 Bbls viscous sweep down DP, jet across TOL @ 18838' MD, reciprocating pipe across liner lap jetting @ 4 BPM, 1900 psi Tbg pressure. 150 Bbls pumped, shut down and RIH to 18878' MD. Reverse out bottoms up and recover 1 gal of carbolite. Reverse additonal 50 Bbls. Flow check well. No Flow 11 :30 - 14:00 2.50 CLEAN DECOMP PU Stand # 284 to RIH and tag top of liner @ 18878' MD. PU single joint of Tbg from pipe shed. Rig up head pin, attempt to jet into TOL. Reciprocate pipe varying pump rate to get into liner. Work 2 turns of torque into pipe and repeat. Continue trying to pass into 4 1/2" Liner. 14:00 - 19:00 5.00 CLEAN DECOMP Enter 4 1/2" liner and RIH w/2 78" Tbg from Derrick. Tag fill @ 19350' MD. PU wt of 75K, SO wt of 18K. Unable to Reverse circulate and strip through bag due to lack of string weight and hydraulics on Tbg. Jet down singles of 2 7/8" Tbg, then reverse circulate bottoms up. Jet and reverse 2 singles then lay down same and RIH wI Stand from Derrick. Carbolite returns. 19:00 - 00:00 5.00 CLEAN DECOMP Repeat process of jetting down single, reverse circulate to clean fluid. Continue washing from 19350' to 19476'. Washing down singles at 3.3 BPM wI 1150 PSI. Reverse circulate bottoms up to clean out carbolite at 3.3 BPM wI 800 - 900 PSI. 7/22/2006 00:00 - 06:00 6.00 CLEAN DECOMP Continue FCO, jetting and reverse circulating to bottom from 19476 to 19600' (corrected to TOL) 06:00 - 11 :00 5.00 CLEAN DECOMP FCO to 19641' MD. Correct to tag of TOL and depth of Float Collar - 19600'. Reverse circulate until clean returns. 11 :00 - 16:30 5.50 CLEAN DECOMP Pump 30 Bbls of Duo-Vis pill. Displace wI Brine and weight up from 9.1 #/gal to 9.4 #/gal as circulate sweep surface to surface. Sweep came back clean. Pump 4 BPM @ 1120 psi. SID & monitor well. 10 min. 16:30 - 17:30 1.00 CLEAN DECOMP UD single. RID circulating equip.. Well U-tubing, Lite spots fl weight up. Pump 1 tubing volume. 4 BPM @ 1160 psi. SID & monitor well. Both sides dead. Annulus FL falling slowly. PIU wt = 85K, SIO wt 17K. 17:30 - 18:00 0.50 CLEAN DECOMP POOH & stand back 5 stands. Flow check well. Well dead, FL slowly dropping. 18:00 - 00:00 6.00 CLEAN DECOMP POOH standing back 155 stands of 27/8" TBG in derrick. Well losing fluid @ 5 BPH. 7/23/2006 00:00 - 03:30 3.50 CLEAN DECOMP Continue POOH standing back 2 7/8" TBG in the derrick from stand #155 to 268. Losses continued @ 5 BPH. Stand #268 was noticed to be crushed by tong dies. After further examination, other joints in the derrick were noticed to be damaged. Tong dies were examined and were proper size, but Printed: 7/31/2006 11 :00:32 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-20 MPL-20 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 7/17/2006 Rig Release: 7/26/2006 Rig Number: N3S Spud Date: 7/27/1997 End: 7/23/2006 00:00 - 03:30 3.50 CLEAN DECOMP not wrap around dies. Tong dies were changed out. 03:30 - 06:00 2.50 CLEAN DECOMP Continue POOH w/2 7/8" tubing. Stood back a total of 296 stands. 06:00 - 07:30 1 .50 CLEAN DECOMP R/U handling tools for 2 3/8" MS DP. POOH & UD 34 jts of 2 3/8" MS DP. UD 2 3/8" handling tools. 07:30 - 09:00 1.50 CLEAN DECOMP Change out 41/2" Power Tongs. Clear & clean rig floor. 09:00 - 12:00 3.00 CLEAN DECOMP PJSM. Cut & slip 167' of drilling line. Inspect brakes & drums. Service & lube rig. 12:00 - 14:00 2.00 RUNCMP Use Super sucker & dig & install mousehole. Load, drift & tally 50 jts of 2 7/8" tubing. Unpack & load ESP in pipe shed. 14:00 - 14:30 0.50 RUNCMP Hold PJSM wI all hands. Review running order & procedure. Blow down choke. 14:30 - 17:30 3.00 RUNCMP P/U, M/U & service ESP. Pull e-line over sheave. Plug into ESP & meg e-line connection. 17:30 - 18:30 1.00 RUNCMP RIH wI pup, single jt & "XN" nipple. Con't to RIH wI stands of 2 7/8" tubing. Pump thru tubing & check e-line every 2000'. Pump 1 BPM @ 820 psi. 18:30 - 21:30 RUNCMP Test crown-o-matic at crew change. Low clutch failed after testing. Replaced 4-way air valve on low clutch. 21 :30 - 00:00 RUNCMP RIH wI ESP completion on 2 7/8" TBG from the derrick. Drifting and watching for damage tubing while RIH. Changing out damage TBG as RIH. 7/24/2006 00:00 - 16:00 RUNCMP Continue RIH wI ESP completion on 2 7/8" TBG from Derrick. Pump thru TBG and check e-line per 2000'. Pump 1 BPM @ 820 psi. Drifting all stands to 2.347". Laying down all no drift jts & replacing bad jts as RIH. Tubing M/U torq = 2300 ft-Ibs. Installing 1 La Salle clamp per jt. Held D1 drill. Doing periodic flow checks. Hole taking fluid slowly. Ran 249 jts in hole. UD & Replaced 31 jts which were crimped by tubing tongs. 16:00 - 20:30 4.50 RUNCMP Change out reels & make reel to reel splice @ 7850 ' . Test cable & splice. Pump thur pump @ 1 BPM wI 840 psi. 20:30 - 00:00 3.50 RUNCMP Continue RIH wI ESP completion on 2 7/8" TBG from derrick from stand #124 to 173. Pump thru pump @ 1 BPM with 810 to 870 psi. 7/25/2006 00:00 - 06:00 RUNCMP Continue RIH wI ESP completion on 2 7/8" TBG from the derrick changing out damaged joints of TBG while RIH. Check ESP cable every 2000'. Pump 1 BPM @ 870 psi. Drifting all stands to 2.347". Lay down & change out all jts that wouldn't drift &lor damaged. Tbg MIU torq = 2300 ft-Ibs. Hole taking fluid slowly, approx. 1 BPH. RIH wI total of 505 jts. Laid down 35 jts to date. 06:00 - 10:00 4.00 RUNCO RUNCMP Change out reels & make reel to reel splice @ 15914'. Tubing string stacked out at 15914' RIH. 10:00 - 16:00 6.00 RUNCO RUNCMP Mix and pump 2 x 30 bbl. pills of Steelube. Spotted pill outside of ESP. 16:00 - 00:00 8.00 RUNCO RUNCMP Continue RIH wI ESP completion on 2 7/8" TBG from the derrick changing out damaged joints of TBG while RIH. Check ESP cable every 2000'. Pump 1 BPM @ 870 psi. Drifting all stands to 2.347". Lay down & change out all jts that wouldn't drift &lor damaged. Replaced 36 bad jts. wlcondition "B" tubing. RIH w/595 jts. tubing, 1 x 2-7/8" GLM, 3 x 10' TBG pups, 1 x 8' TBG pup, 1 x 4' TBG pup, 1 x "XN" nipple, ESP BHA and tubing hanger. Tbg M/U torq = 2300 ft-Ibs. Hole Printed: 7/31/2006 11 :00:32 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-20 MPL-20 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 7/17/2006 Rig Release: 7/26/2006 Rig Number: N3S Spud Date: 7/27/1997 End: 01 :00 - 03:30 03:30 - 04:00 0.50 04:00 - 10:00 10:00 - 14:00 14:00 - 16:00 2.00 WHSUR P 16:00 - 00:00 8.00 RIGD P 7/27/2006 00:00 - 06:00 6.00 RIGD P taking fluid @ -1 BPH. Counted tubing jts. on location and found that one too many jts. had been RIH. POH and UD one jt. below GLM to keep GLM depth at -150' per program requirements. RIH w/tubing. PUMU tubing hanger on 3-1/2" DP landing joint and 3" L.H. Acme XO w/TIW valve. RUNCMP Pump 10 bbls. brine through ESP at -1 BPM at 800-900 psi. Check ESP cable for continuity and proper resistance values. Good tests. Make lower penetrator connector splice. RUNCMP Land tubing hanger. RILDS. UD 3-1/2" DP landing joint and XO. Set and test TWC to 2500 psi. RUNCMP N/D BOPE. RUNCMP N/U UD Flange, Adaptor Flange and Tree and test to 5,000-psi. RUNCMP P/U Lubricator and install on Tree, pull TWC and install BPV. Centrilift Technician made final ESP checks--all good. Secure Cellar and release rig at 1600-hours. POST RID rig components. Clean interior of rig and make ready for rig move July 27th. POST RID rig components. Clean interior of rig and make ready for rig move July 27th. Printed: 7/3112006 11 :00:32 AM · . Tree: 2 9/16" - 5M FMA Wellhead: 11" x 7" 5M. Gen 5 wI 2 7/8" WKM Tubing Hanger, wI 3" Acme Threads, 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 I 115' I KOP @ 400' Max. hole angle = 76 to 79 deg. fl 3500' to TD Hole angle thru' perfs = 33 deg 95/8",40 ppf, L-80 Btrc. 8160' md I 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7",26 ppf, L-80, Btrc. Mod. prod. casing (drift ID = 6.151", cap. = 0.0383 bpf) 4.5" 12.6 ppf, L-80 Mod ( drift ID = 3.958" , cap = .0152 bpf ) Intake TVD - 6457' Intake MD - 18733' 4.5" Liner Top TVD - 6493' 4.5" Liner Top MD - ,18838' Mid-perf TVD - 6697' Mid-perf MD - 19385' PBTD TVD - 6785' PBTD MD - 19600' Stimulation Summary 03/11/98 - Kup. A Sand - 104 M# 20/40 Carbolite & 35 M# of PropLok coated 16/2 Carbolite behind pipe Perforation Summary Ref log: Anadrill LWD 8/2/97 Size SPF Interval (TVD) 2-7/8" 6 19370' -19400 6677'-6716' TCP shot MPU L-20 07/24/01 06/20/06 07/24/06 B. Hasebe R. Handy L. Hulme RWO Nabors 4ES RWO Nabors 4-ES RWO Nabors 3S or~g. D_v. = 49.~5' (N22E) Ong. ~v. = 16.8 DF To Tbg. Spool = xxx' (N22E) Camco 2-718" x 1" sidepocket KBMM GLM 9 5/8" Howco 'ES' Cementer 7" Howco 'ES' Cementer Two 1" x 21' short joints from 18,568' to 18.610' md 141' I 12123' I 10,447' I 118,680'1 Discharge Head GPDIS 118,695'1 Tandem Pumps, 74GC2900'118 696' I GPMTAR 1:1 ' 27/8" HES "XN" Nipple Intake Gas Separator GRSFTXAR (400 Internals) Tandem Seal Section GSB3DB UT/L T AB/HSN PFSAlFSA CL5 Motor, 266 HP, 2345 volt, 69 amp, Model KMH PumpMate w/6 fin Centralizer PumpMate TVD 6197' 118,728" 118,733' I 118,746' I 118,769'1 7"x 4.5" Baker "ZXP" Pkr. "HMC" Hydraulic liner hangJ 18,838' 7"x5" Baker liner hanger I 18,852' 7"floatshoe RA Tag 19,104' 19,192' Fill Clean out @ 19,600' 7/24/06 4.5" landing collar 4.5" Float collar 4.5" Float shoe MILNE POINT UNIT WELL L-20 API NO: 50-029-22790 19,600' 19,684' 19,770' BP EXPLORATION (AK) _ STATE OF ALASKA G/jq~ Al~ Oil AND GAS CONSERVATION COM_SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUL 1 4 2006 .Ajaska Oil & Gas Cons. Commission A 1. Operations Performed: o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 197-136 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22790-00-00 7. KB Elevation (ft): 49.85 9. Well Name and Number: MPL-20 8. Property Designation: 10. Field 1 Pool(s): ADL 025514 Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 19770 feet true vertical 7022 feet Plugs (measured) NIA Effective depth: measured 19601 feet Junk (measured) NIA true vertical 6873 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' 1490 470 Surface 8123' 9-5/8" 8160' 3546' 5750 3090 Intermediate Production 19071' 7" 19104' 6462 7240 5410 Liner 932' 4-1/2" 18838' - 19770' 6248' - 7022' 8430 7500 ;;:-(~. .~ :1,'. i ';~ I - " .;;./....., '" , - Perforation Depth MD (ft): 19370' - 19400' Perforation Depth TVD (ft): 6676' - 6701' 2-7/8",6.5# L-80 18795' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-112" Baker ZXP packer 18838' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Recresentative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant /~ - .-/ "';. Prepared By Name/Number: Signature " '( l..i\:::;::, ..:...< Phone 564-4750 DateU1-l3'OC¡ Sandra Stewman, 564-4750 -. ". Form 10-404 Revised 04/2006 o R 1 G 1 N A L ;::}'i::r\ IØJMS 8fL JUL 1 4 2006 Submit Original Only Tree: 29/16" - 5M F~ Wellhead: 11" x 7" 5~ Gen 5 wI 2 7/8" WKM Tubing Hanger, wI 3" Acme Threads, 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 I 115' I KOP @ 400' Max. hole angle == 76 to 79 deg. fl 3500' to TD Hole angle thru' perfs == 33 deg 95/8", 40 ppf, L-80 Btrc. 8160' md I 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7",26 ppf, L-80, Btrc. Mod. prod. casing ( drift ID = 6.151 ", cap. == 0.0383 bpf) 4.5" 12.6 ppf, L-80 Mod (drift ID = 3.958" ,cap = .0152 bpf) Intake TVD - 6457' Intake MD - 18733' 4.5" Liner Top TVD - 6493' 4.5" Liner Top MD - ,18838' Mid-perf TVD - 6697' Mid-perf MD - 19385' PBTD TVD - 6785' PBTD MD - 19600' Stimulation Summary 03/11/98 - Kup. A Sand - 104 M# 20/40 Carbo lite & 35 M# of PropLok coated 16/2 Carbolite behind pipe Perforation Summary Ref log: Anadrill LWD 8/2/97 Size SPF Interval (TVD) 2-7/8" 6 19370'-19400 6677'-6716' TCP shot MPU L-20 Or~g. Daev. = 49.~5' (N22E) Ong. GWev. = 16.8 DF To Tbg. Spool = xxx' (N22E) Cameo 2-7/8" x 1" sidepocket KBMM GLM 139' I 9 5/8" Howco 'ES' Cementer I 2123' 7" Howco 'ES' Cementer 110,447' I 27/8" HES "XN" Nipple 118,680'1 Tandem Pump, 27 and 122 I 'I Stg GC2200's, GPMTAR 1:1 18,723 Tandem Gas Separator 118,749'1 GRSTX ARH6 (513 Series Internals) Tandem Seal Section I 'I Model GSB3 DB L T AB/HSN FSA CL5 18,754 Motor, 266 HP, 2345 volt, 118,768'1 69 amp, Model KMH _ , Phoenix MS1 w/6 fin Centralizer Two 7" x 21' short joints from 18,568' to 18,610' md 118,792'1 7"x 4.5" Baker "ZXP" Pkr. "HMC" Hydraulic liner hangJ 18,838' 7"x5" Baker liner hanger I 18,852' 7"floatshoe 19,104' 19,192' RA Tag Fill Clean out @ 19,600' 6/14/06 4.5" landing collar 4.5" Float collar 4.5" Float shoe 19,600' 19,684' 19,770' DATE REV,BY COMMENTS 08/31/97 JBF Drilled and Cased by Nabors 22E 03/22/98 M. Linder Completion Nabor 4-ES 07/24/01 B. Hasebe RWO Nabors 4ES 06/20/06 R. Handy RWO Nabors 4-ES MILNE POINT UNIT WELL L-20 API NO: 50-029-22790 BP EXPLORATION (AK) .. e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-20 MPL-20 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/11/2006 Rig Release: 6/16/2006 Rig Number: 4ES Spud Date: 7/27/1997 End: 6/16/2006 6/12/2006 06:00 - 06:30 0.50 RIGD P PRE Lower Derrick. Disconnect services and rig-down Modules. 06:30 - 09:00 2.50 MOB P PRE Move to MPL-20 Well Slot. 09:00 - 12:00 3.00 RIGU P PRE Spot sub Base over Well. Spot Pits, Pipe Shed, and Camp. Raise and scope Derrick. 12:00 - 13:00 1.00 KILL P DECOMP Take on 120 deg F. Sea Water in Pits. Spot BUG Tank. Rig-up Lines to Tree and BUG Tank. Prep for Well Kill. Accept Rig at 12:00 hrs. 13:00 - 13:30 0.50 KILL P DECOMP Pick-up Lubricator. Pull BPV. (Tubing on a vacuum). Lay down same. 13:30 - 14:00 0.50 KILL P DECOMP Pressure test lines to 1000/3500 psi. Good. 14:00 - 14:30 0.50 KILL P DECOMP Hold pre-job safety and operations meeting with All. 14:30 - 19:00 4.50 KILL P DECOMP Begin pumping 120 deg Sea Water at 3.0 bpm/1900 psi to circulate out diesel, Oil, and Produced Water. Observed clean retums to surface. Shut down well kill operation. 19:00 - 20:00 1.00 KILL P DECOMP Monitor well. Stable, well on slight vacuum. Set and test TWC. Rig down circulating lines. 20:00 - 21 :00 1.00 WHSUR P DECOMP Bled pressure off hanger void area.N/D tree and adapter flange. Remove from cellar area. 21 :00 - 21 :30 0.50 BOPSU DECOMP NIU BOPE, leave out test spool. 21 :30 - 00:00 2.50 BOPSU DECOMP Change out annular element and piston seal. 6/13/2006 00:00 - 02:30 2.50 BOPSU DECOMP Change annular element and piston seals. 02:30 - 04:00 1.50 BOPSU DECOMP NID BOPE, Install test spool. NIU BOPE. 04:00 - 08:30 4.50 BOPSU DECOMP Preform BOPE test per BP/AOGCC requirements at 250/3500 psi. Good test. The State's right to witness the test was waived by J. Chrisp. 08:30 - 09:30 1.00 BOPSU DECOMP Rig down test equipment. Pick-up Lubricator. Pull TWC (Well on a slight vacuum). Lay down same. 09:30 - 10:30 1.00 PULL P DECOMP Make-up landing joint. Pull tubing hanger to floor with no problems with 100K. Hanger broke free at 112K. Fill hole with 10 bbls. (Static FL = -350'). Circulate oil off the top of the Annulus fluid column. 10:30 - 13:00 2.50 PULL P DECOMP POOH & stand back 2 7/8" tubing. 13:00 - 13:30 0.50 PULL P DECOMP Change out spools. 13:30 - 18:30 5.00 PULL P DECOMP Con't to POOH & stand back 2 7/8" tubing. 116 stands out of hole. 18:30 - 19:30 1.00 PULL P DECOMP Cut ESP cable. Test same. Wrap cable around spool. Change out spools. Connect cable to new spool. 19:30 - 23:30 4.00 PULL P DECOMP Con' t to POOH & stand back 27/8" tubing. recovered 197 stands in derrick & UD 5 jts. 2 jts were bad, 1 wI galled threads & 1 wi holes. 23:30 - 00:00 0.50 PULL P DECOMP Drain & Break down ESP. 6/14/2006 00:00 - 02:30 2.50 PULL P DECOMP Con't to UD & inspect ESP. Top pump was locked up. Twisted shaft in Lower Pump. Very small amount of scale. Seal Ok, Motor Ok. No sand. Load pump into shipping containers. 02:30 - 03:30 1.00 PULL P DECOMP UD elephant hose. Clear & clean rig floor. Install Wear Bushing. 03:30 - 06:00 2.50 PULL P DECOMP RIU handling equip for RTS-6 DP. M/U notched collar on 2 3/8" DP. PIU & RIH wI Notched Collar, 30 jts of 2 318" DP, XO. Total CO/BHA = 971.41' 06:00 - 06:30 0.50 PULL P DECOMP Lube Rig. Inspect Derrick. 06:30 - 07:00 0.50 PULL P DECOMP Finish in with 2 3/8" Tubing from Pipe shed. 07:00 - 13:30 6.50 PULL P DECOMP Continue trip in 2 7/8" Tubing from Derrick. Tagged top of fill at 19,405' (5-ft below Perforations). Printed: 6/20/2006 12:16:41 PM .,. e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-20 MPL-20 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/11/2006 Rig Release: 6/16/2006 Rig Number: 4ES Spud Date: 7/27/1997 End: 6/16/2006 6/14/2006 13:30 - 17:00 3.50 PULL P DECOMP Begin to wash and reverse circulate single joints with no problems. Reverse circulating rate = 5.0 bpm/1600 psi. Losses 1-2 bpm. Returns = Carb-O-Lite. Cleaned out fill from 19405 to 19600'. 17:00 - 20:00 3.00 PULL P DECOMP Mix & reverse 30 bbl Hi-Vis sweep all the way around. Circulated out small amount of Carbolite wI sweep. Pumped 6 BPM @ 1600 psi. Losses were 1.2 BPM. Circulated total 1 01 0 bbls. 20:00 - 21 :30 1.50 PULL P DECOMP Monitor well. RlU Hot Oilers. Pressure test lines. Pumped 5 bbls of diesel. Displaced w/1 00 bbls of seawater from rig pump. SID & monitor well. Well U-tubed slighly then quit. Well static. 21 :30 - 00:00 2.50 PULL P DECOMP Break off circulating head. drain lines. RlU, POOH & stand back 2 7/8" tubing. 80 stands out. 6/15/2006 00:00 - 03:00 3.00 PULL P DECOMP Con't to POOH & standback 27/8" tubing. Pulled total of 198 stands. UD 2 singles. 03:00 - 04:00 1.00 PULL P DECOMP RlU handling tools for 23/8" PH6 DP. POOH & UD 31 jts of 2 3/8" DP. 04:00 - 04:30 0.50 PULL P DECOMP RID DP tools. Pull Wear Bushing. Clear & clean rig floor. RlU to run ESP. 04:30 - 06:00 1.50 RUNCMP P/U, MIU & service ESP. 06:00 - 06:30 RUNCMP Lube & service rig. Perform derrick inspection. 06:30 - 09:00 RUNCMP M/U & service ESP. Splice in plug. Plug in Cable & test same. 09:00 - 13:00 RUNCMP RIH wI ESP on stands of 2 7/8" tubing. Check cable every 20 stands & pump thru pump. 1 BPM @ 950 psi. 13:00 - 16:00 3.00 RUNCMP Change out reels & Make reel to reel splice & test same. 16:00 - 22:00 6.00 RUNCMP Con't to RIH wI ESP. Check cable & pump thru pump every 20 stands. 1 BPM @ 1300 psi. RIH wI 167 stands. 22:00 - 00:00 2.00 RUNCMP Change out reels & make reel to reel splice & test same. 6/16/2006 00:00 - 01 :00 1.00 RUNCMP Finish making reel to reel splice. 01 :00 - 03:00 2.00 RUNCMP Con't to RIH wI ESP on 2 7/8" tubing. Ran total of 198 stands. Checked cable & pumped thru ESP every 20 stands. 1 BPM @ 1300 psi. 03:00 - 03:30 0.50 RUNCO RUNCMP M/U landing jt onto hanger. Install penetrator. 03:30 - 05:30 2.00 RUNCO RUNCMP Make final field splice. Connect to pentrator & test same. 05:30 - 06:30 1.00 RUNCO RUNCMP Land hanger. RILDS. UD landing jt. Set TWC. 06:30 - 08:00 1.50 BOPSU P RUNCMP Nipple down BOP Stack. 08:00 - 09:00 1.00 WHSUB P RUNCMP Nipple-up Production Tree. 09:00 - 10:00 1.00 WHSUB P RUNCMP Pressure test Tree to 5,000 psi. Good test. 10:00 - 11 :00 1.00 WHSUB P RUNCMP Pick-up Lubricator. Pull TWC. Install BPV. Secure Cellar. Release Rig at 11 :00 hrs. Printed: 6/20/2006 12:16:41 PM '~' STATE OF ALASKA ALASKA OIL ~,~D GAS CONSERVATION COMMISSI~. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Pedorate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5, Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 49.85' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3629' NSL, 5164' WEL, SEC. 8, T13N, R10E, UM MPL-20 At top of productive interval 9. Permit Number / Approval No. 197-136 1519' SNL, 2766' WEL, SEC. 23, T13N, R9E, UM 10. APl Number At effective depth 50-029-22790 1614' SNL, 2867' WEL, SEC. 23, T13N, R9E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1665' SNL, 2927' WEL, SEC. 23, T13N, R9E, UM Sands 12. Present well condition summary Total depth: measured 19770 feet Plugs (measured) true vertical 7022 feet Effective depth: measured 19601 feet Junk (measured) true vertical 6873 feet Casing Length Size Cemented M D TVD Structural Conductor 74' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 8123' 9-5/8" 2200 sx 'G', 1250 sx PF 'E' 8160' 3546' Intermediate Production 19071' 7" 425 sx Class 'G' 19104' 6462' Liner 932' 4-1/2" 120 sx Class 'G' 18838' - 19770' 6248' - 7022' RECEIVED Perforation depth: measured 19260 - 19295', 19370'- 19400' true vertical 6587' - 6615', 6676' - 6701' Alaska Oil & Gas Cons. Comrnissior; Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 18763'. Anchorage. Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker ZXP packer at 18838'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Repor~ of Well Operations 17. I hereby cert~oing is true an_.~ correct to the best of my knowledge Title Technical Assistant Date ~' 'Z.. i- 0 / Signed s on~r Sta~m a n~....~"~~ Prepared By Name/Number: Sondra Stewman, 564-4750 · · .. Form 10-404 Rev. 06/15/88 Submit In Duplicate ~ BP EXPLORATION Page 1 of 1 OperatiOns Summary Report Legal Well Name: MPL-20 Common Well Name: MPL-20 Spud Date: 7/27/1997 Event Name: WORKOVER Start: 7/20/2001 End: 7/23/2001 Contractor Name: NABORS Rig Release: 7/23/2001 Rig Name: NABORS 4ES Rig Number: ! Date ::i:~From ' TO I HOUrs ACtivity COde NPT i Phase Description of Operations 7/19/2001 19:00 - 00:00 5.00 RIGU DECOMP MOVED RIG FROM I PAD TO L PAD AND RD. 7/20/2001 00:00 - 04:00 4.00 RIGU P DECOMP FULLY RIGGED UP. ACCEPTED WELL @ 04:00. 04:00 - 07:00 3.00 KILL P DECOMP SPOT AND BERM TIGER TANK. HOOK UP LINES. RU TO KILL WELL. PULL BPV. 07:00 - 09:00 2.00 KILL N DPRB DECOMP RU SWS TO PERF. CIRC. HOLES IN TBG. 09:00 - 09:30 0.50 KILL N DPRB DECOMP PT LINES & LUBRICATOR TO 3000 PSI. 09:30 - 17:00 7.50 KILL N DPRB DECOMP RIH. STARTING PUMPING WHEN TOOLS WERE @ 4000'. TOOLS QUIT FALLING @ 5935'. FINAL RATE 2 BPM @ 2500 PSI. 17:00 - 19:00 2.00 KILL N DPRB DECOMP POOH @ RIGGED SWS DOWN. 19:00 - 19:30 0.50 KILL P DECOMP PT LINES TO 3500 PSI. 19:30 - 00:00 4.50 KILL P DECOMP CIRC. DN. TBG. 2 BPM @ 2500 PSI. 7/21/2001 00:00 - 02:30 2.50 KILL P DECOMP CIRC. WELL DN. TBG. 2 BPM @ 3000 PSI. TOTAL PUMPED 750 BBLS. SEAWATER. 02:30 - 03:00 0.50 KILL P DECOMP MONITORED WELL. DEAD. 03:00 - 04:00 1.00 WHSUR P DECOMP SET @ TEST TWC. ND TREE. 04:00 - 06:00 2.00 BOPSUF',P DECOMP NU DOPE. 06:00 - 07:30 1.50 BOPSUF',P DECOMP BODY TEST DOPE. LP 250 PSI. HP 3500 PSI. TESTED GOOD. WITNESSING WAIVERED BY JOHN CRISP (AOGCC). 07:30 - 08:30 1.00 BOPSUF:P DECOMP PULLED TWC. 08:30 - 09:00 0.50 WHSUR P DECOMP PU LANDING JT. MU TO HANGER. BOLDS. 09:00- 09:30 0.50 WHSUR P DECOMP SERVICE RIG. 09:30 - 10:00 0.50 WHSUR P DECOMP UNLAND HANGER. PULLED 105K. 10:00 - 12:00 2.00 PULL P DECOMP POOH W/ESP. 12:00 - 12:30 0.50 PULL P DECOMP CIO SPOOLING UNITAT 1,154'. 12:30 - 17:30 5.00 PULL P DECOMP POOH WI ESP. 17:30 - 18:30 1.00 PULL P DECOMP CIO SPOOLING UNIT AT 9,870'. 18:30 - 22:30 4.00 PULL P DECOMP POOH W/ESP. 22:30 - 23:30 1.00 PULL P DECOMP CIO SPOOLING UNIT 18,135'. 23:30 - 00:00 0.50 PULL P DECOMP POOH W/ESP. 7/22/2001 00:00 - 01:30 1.50 PULL P DECOMP POOH W/ESP. INSPECT & LAY DN. ESP. 01:30 - 02:30 1.00 PULL P DECOMP CLEAR FLOOR. PREP TO RIH. 02:30 - 08:00 5.50 RUNCOI~ COMP PU, SERVICE & TEST ESP. INSTALLED PUMP DISCHARGE .1_ LINE & TEST. 08:00 - 00:00 16.00 RUNCOI~-' COMP RIH W/ESP & 2 7/8" TBG. 7/23/2001 00:00 - 03:30 3.50 RUNCOI~r~ COMP FINISHED TIH W/ESP & 2 7/8" TBG. TOTAL OF 2 SPLICES MADE WI RIH. SPLICES @ 7,778' & 15,500'. 03:30 - 04:00 0.50 WHSUR P COMP MU LANDING JT. & HANGER. 04:00 - 05:30 1.50 WHSUR P COMP i SPLICE EFT CONN. PLUG IN & TEST. 05:30 - 06:00 0.50 WHSUR P COMP P/U WT. 82K. S/O WT. 30K. LAND HANGER & RILDS. SET & TEST TWC. 06:00 - 10:00 4.00 BOPSUF P COMP ND DOPE. CLEAN PITS. 10:00 - 11:30 1.50 WHSUR P COMP NU TREE. TEST HANGER AND TREE TO 5000PSI. TESTED GOOD. 11:30 - 12:00 0.50 WHSUR P COMP RU LUBRICATOR. PULL TWC. SET BPV. L/D LUBRICATOR. 12:00 - 13:00 1.00 WHSUR P COMP SECURE TREE & CELLAR. RELEASED RIG @ 13:00. I Printed: 7/30/2001 4:00:40 PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE 01 PL E W M ATE IA L U N D ER TH IS M ARK ER C :LORIkMFILM.DOC Well Compliance Report File on Left side of folder '197-13'6~0 ............ MI~NE ?~OiNT UNIT L£20 so- o29'2279o-oo MD 19770 TVD 07022 rC~mpletionDate: .~9/98 Completed Status: 1-OIL BP EXPLORATION Current: T Name Interval Sent Received T/C/D C 9210 ~-9' sCHLuM IMP-CDR ' OH 2 / L CBL FINAL 0-3371 ~ CH 5 L ~P-CDR-MD ~ 8114-19770 OH 2 L ~P-CDR-~D ~ 3600-7022 OH 2 Daily Well O~~ ~) Was the well cored? yes 6/3/99 6/10/99 2/24/98 2/26/98 3/22/98 3/31/98 6/3/99 6/10/99 6/3/99 6/10/99 Are Dry Ditch Samples Required? yes ~ R ee_cei, ivoa? yo~ .~_.~ Analysis Description~ yes no bample Se~ Comments: Tuesday, April 04~ 2000 Page 1 of 1 June 3,1999 GeoQuest Schlumberger GeoQuest 3940 Arctic Boulevard Anchorage, Alaska 99503 (907) 273-1700 (907) 561-8317 (Fax) TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MD CDR/IMPULSE & TVD for well MPL-20. Job # 97418 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 E-TRANS- 5/25/99 3 Bluelines each 1 Film each State of Alaska Alaska Oil & Gas Conservation Ah'n: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 OH CDR 1 B!ueline each 1 Sepia each OXY USATIncT- ......... Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 OH CDR 1 Blueline each 1 Sepia each Sent Certified Mail: P 067 695 554 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, AI~_.~:~%C~6~ ~ Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A'I-rN: She r~~.~~ Received Iqy.~..~, ~ / ./V STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service~ (-:otis ",. [] Oil [] Gas [] Suspended [] Abandoned [] Service 12. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-136 397-198, 398-006 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612--__ ...... 50-029-22790 4. Location of well at surface !.:?i.~,-~,,;..-.t.-..:.:.;..,;; .:¢ ~1~,,¢1~'1~11~. 9. Unit or Lease Name 3629' NSL, 5164' WEL, SEC. 8, T13N, R10E, UM~ _ ~.,.,..~:~ .......... _~ Milne Point Unit At top of productive interval~ ; .~_/¢ '_~ ~Z~.. i~ 10. Well Number 1507' SNL, 2667' WEL, SEC. 23, T13N, R9E, UM : V~;i~.~'.-,'.., MPL-20 At total depth ,.,~¢~.'..'~-~-,~,._~__,....~_. , 11. Field and Pool 1653' SNL, 2828' WEL, SEC. 23, T13N, R9E, UM .... ~ ........... , ...... .,, Milne Point Unit / Kuparuk River 15. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 49.85'I ADL 025514 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 16. No. of Completions 7/27/97I 8/25/97I 3/19/98I N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 19770 7022 FTI 19601 6873 FTI [~Yes []NoI N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, Gyro, LWD, GR/CCL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 37' 8160' 12-1/4" 1250 sx PF 'E', 2200 sx Class 'G' 7" 26# L-80 33' 19104' 8-1/2" 425 sx Class 'G' 4-1/2" 12.6# L-80 18838' 19770' 6" 120 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 18763' MD TVD MD TVD 19370'-19400' 6677'-6701' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 84 bbls diesel 18275'-19145' 100 sx 'G', sqzd to 660 psi 18835' EZSV, with 10 bbls 'G' on top Frac 19370'-19400' 104000# 20/40 & 35000# 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) i . i 'i' ":, L March 27, 1998~ Electric Submersible Pump "'- / ; ''~ ~-~ Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 19138' 6489' Top Kuparuk 'B' 19254' 6583' Top Kuparuk 'A' 19340' 6652' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01~80 Performance Enquiry Report Operator BP Exploration Date 00:33, 05 May 98 Page The analysis is from - 15:00, 02 Aug 97 - to - 16:30, 13 Feb 98 Programs in Result Table: MPL-20 drill and complete Well Type MPL-20 Event MPL-20 Event MPL-20 Event MPL-20 Event Time From Time To Duration DescriDtion E.M.W.(equivalent mud weight) Hole Size MDR 15:00, 02 Aug 97 15:00, 02 Aug 97 0 hr 0 min Obtained leak off 14.0 8-1/2 20:00, 18 Aug 97 20:00, 18 Aug 97 0 hr 0 min Obtained leak off 15.5 6 16:00, 23 Aug 97 16:00, 23 Aug 97 0 hr 0 min Obtained leak off 15.0 6 16:30, 13 Feb 98 16:30, 13 Feb 98 0 hr 0 min Obtained required level of integrity 14.0 6 Facility M Pt L Pad Progress Report Well MPL-20 Rig Nabors AC-¢S'~ Page Date 1 04 May 98 Date/Time 27 Jul 97 28 Jul 97 29 Jul 97 30 Jul 97 31 Jul 97 01 Aug 97 06:00-06:30 06:30-07:30 07:30-14:00 14:00-14:30 14:30-17:00 17:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-21:30 21:30-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-10:00 10:00-10:30 10:30-18:00 18:00-18:30 18:30-22:00 22:00-00:00 00:00-03:30 03:30-06:00 06:00-06:30 06:30-08:30 08:30-13:30 13:30-15:00 15:00-22:30 22:30-00:30 00:30-03:30 03:30-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-11:30 11:30-13:30 13:30-17:30 17:30-18:00 18:00-19:30 19:30-20:00 20:00-21:30 21:30-00:00 Duration 1/2 hr lhr 6-1/2 hr 1/2 hr 2-1/2 hr lhr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2hr 1/2hr 1/2 hr 9-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 8hr lhr 2hr 1/2 hr 3hr 8-1/2 hr 1/2hr 2hr lhr 1/2 hr 1/2 hr 7-1/2 hr 1/2 hr 3-1/2 hr 2hr 3-1/2 hr 2-1/2 hr 1/2hr 2hr 5hr 1-1/2 hr 7-1/2 hr 2hr 3hr 2-1/2 hr 2hr lhr lhr 1-1/2 hr 2hr 4hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr Activity Held safety meeting Serviced High pressure lines Rigged up Divertor Tested Divertor Serviced Divertor Drilled to 112.0 ft Held safety meeting Drilled to 1088.0 ft Held safety meeting Drilled to 2405.0 ft Held safety meeting Pulled out of hole to 1000.0 ft R.I.H. to 2405.0 ft Drilled to 3535.0 ft Circulated at 3535.0 ft Pulled out of hole to 1700.0 ft R.I.H. to 3535.0 ft Held safety meeting Drilled to 5045.0 ft Circulated at 5045.0 ft Pulled out of hole to 0.0 ft Held safety meeting R.I.H. to 5045.0 ft Drilled to 6170.0 ft Held safety meeting Drilled to 6530.0 ft Circulated at 6530.0 ft Pulled out of hole to 5000.0 ft R.I.H. to 6530.0 ft Drilled to 7587.0 ft Held safety meeting Drilled to 8180.0 ft Circulated at 8180.0 ft Pulled out of hole to 1000.0 ft R.I.H. to 8180.0 ft Held safety meeting Circulated at 8180.0 ft Pulled out of hole to 0.0 ft Serviced Casing handling equipment Ran Casing to 8160.0 ft (9-5/8in OD) Circulated at 8160.0 ft Mixed and pumped slurry - 450.000 bbl Circulated at 2122.0 ft Mixed and pumped slurry - 485.000 bbl Serviced BOP stack Serviced Casing handling equipment Rigged down Divertor Installed Casing head Rigged up BOP stack Installed BOP test plug assembly Tested BOP stack Removed BOP test plug assembly Serviced Block line Ran Drillpipe to 0.0 ft (5in OD) Facility Date/Time 02 Aug 97 03 Aug 97 04 Aug 97 05 Aug 97 06 Aug 97 07 Aug 97 M Pt L Pad Progress Report Well MPL-20 Rig Nabors ~q~ Page Date Duration Activity 00:00-02:30 02:30-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-13:00 13:00-17:00 17:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-08:30 08:30-09:00 09:00-18:00 18:00-18:30 18:30-01:30 01:30-02:30 02:30-05:00 05:00-06:00 06:00-06:30 06:30-09:30 09:30-18:00 18:00-18:30 18:30-02:00 02:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-03:00 03:00-03:30 03:30-06:00 06:00-12:30 12:30-13:30 13:30-14:30 14:30-16:30 16:30-17:30 17:30-18:30 18:30-21:00 21:00-22:00 22:00-00:30 2-1/2 hr 2-1/2 hr lhr 1/2 hr 4-1/2 hr lhr 1/2 hr lhr lhr 1/2 hr 3hr 1/2 hr 8-1/2 hr lhr lhr lhr 1/2hr 6-1/2 hr 4hr lhr 1/2 hr 11-1/2 hr 1/2hr 1/2hr lhr 1/2 hr 1/2 hr 9hr 1/2 hr 7hr lhr 2-1/2 hr lhr 1/2 hr 3hr 8-1/2 hr 1/2 hr 7-1/2 hr lhr lhr lhr lhr 21 hr 1/2 hr 2-1/2 hr 6-1/2 hr lhr lhr 2hr lhr lhr 2-1/2 hr lhr 2-1/2 hr Made up BHA no. 3 R.I.H. to 2122.0 ft Drilled installed equipment - Cementing packer Held safety meeting R.I.H. to 8074.0 ft Serviced Top drive Tested Casing Drilled installed equipment - Float shoe Circulated at 8200.0 ft Performed formation integrity test Drilled to 8731.0 ft Held safety meeting Drilled to 10055.0 ft Circulated at 10055.0 ft Pulled out of hole to 8160.0 ft R.I.H. to 10055.0 ft Held safety meeting Conducted electric cable operations Drilled to 10774.0 ft Repaired Main engine Held safety meeting Drilled to 12500.0 ft Held safety meeting Circulated at 12500.0 ft Pulled out of hole to 10050.0 ft Serviced Top drive R.I.H. to 12500.0 ft Drilled to 13905.0 ft Held safety meeting Drilled to 15036.0 ft Circulated at 15036.0 ft Pulled out of hole to 8160.0 ft R.I.H. to 11000.0 ft Held safety meeting R.I.H. to 15036.0 ft Drilled to 16331.0 ft Held safety meeting Drilled to 17036.0 ft Circulated at 17036.0 ft Pulled out of hole to 15000.0 ft R.I.H. to 17368.0 ft Drilled to 17398.0 ft Drilled to 18723.0 ft Circulated at 18723.0 ft Pulled out of hole to 13700.0 ft Pulled out of hole to 500.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 3410.0 ft Serviced Top drive Serviced Block line R.I.H. to 8435.0 ft Took MWD survey at 8435.0 ft R.I.H. to 18723.0 ft 2 04 May 98 Facility M Pt L Pad Progress Report Well MPL-20 Rig Nabors AC-aS:2'7E' Page Date 3 04 May 98 Date/rime 08 Aug 97 09 Aug 97 10 Aug 97 11 Aug 97 12 Aug 97 13 Aug 97 00:30-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-10:30 10:30-12:00 12:00-19:30 19:30-20:30 20:30-23:00 23:00-23:30 23:30-01:00 01:00-06:00 06:00-20:00 20:00-23:00 23:00-01:00 01:00-02:30 02:30-04:00 04:00-05:30 05:30-06:00 06:00-08:30 08:30-11:00 11:00-13:30 13:30-14:30 14:30-05:00 05:00-06:00 06:00-07:00 07:00-09:30 09:30-11:30 11:30-16:00 16:00-16:30 16:30-19:30 19:30-21:00 21:00-22:30 22:30-06:00 06:00-08:00 08:00-09:00 09:00-10:30 10:30-12:00 12:00-13:00 13:00-14:00 14:00-21:00 21:00-21:30 21:30-00:00 00:00-01:00 01:00-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-10:00 10:00-13:30 13:30-14:00 14:00-16:00 Duration 5-1/2 hr 1/2hr 2hr lhr lhr 1-1/2 hr 7-1/2 hr lhr 2-1/2 hr 1/2hr 1-1/2 hr 5hr 14hr 3hr 2hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr lhr 14-1/2 hr lhr lhr 2-1/2 hr 2hr 4-1/2 hr 1/2hr 3hr 1-1/2 hr 1-1/2 hr 7-1/2 hr 2hr lhr 1-1/2 hr 1-1/2 hr lhr lhr 7hr 1/2 hr 2-1/2 hr lhr 2-1/2 hr 1-1/2 hr lhr 1/2hr lhr 2hr 1/2 hr 3-1/2 hr 1/2 hr 2hr Activity Drilled to 19003.0 ft Drilled to 19125.0 ft Circulated at 19125.0 ft Pulled out of hole to 16800.0 ft R.I.H. to 19125.0 ft Circulated at 19125.0 ft Pulled out of hole to 500.0 ft Serviced BOP stack Pulled BHA Retrieved Wear bushing Rigged up Casing handling equipment Ran Casing to 4700.0 ft (7in OD) Ran Casing to 19103.0 ft (7in OD) Circulated at 19103.0 ft Mixed and pumped slurry - 36.000 bbl Circulated at 10446.0 ft Mixed and pumped slurry - 51.000 bbl Serviced Casing handling equipment Serviced Seal assembly Serviced Seal assembly Serviced Top drive Laid out 5in drill pipe from derrick Repaired Top drive Laid out 5in drill pipe from derrick Serviced Block line Serviced Block line Serviced BOP stack Serviced Top drive Tested BOP stack Installed Wear bushing Made up BHA no. 5 Singled in drill pipe to 2335.0 ft Serviced Drillstring handling equipment Singled in drill pipe to 10000.0 ft Singled in drill pipe to 9830.0 ft Repaired Drillstring handling equipment Singled in drill pipe to 10398.0 ft Drilled installed equipment - DV collar Circulated at 10449.0 ft Washed to 10715.0 ft Singled in drill pipe to 18975.0 ft Washed to 19005.0 ft Tested Casing Drilled installed equipment - Landing collar Circulated at 19083.0 ft Drilled installed equipment - Float shoe Circulated at 19145.0 ft Circulated at 19145.0 ft Flow check Circulated at 19145.0 ft Pulled out of hole to 18721.0 ft Circulated at 18721.0 ft R.I.H. to 19145.0 ft Circulated at 19145.0 ft Facility M Pt L Pad Progress Report Well MPL-20 Page 4 Rig Nabors 4E~ .R'7~ Date 04 May 98 Date/Time 14 Aug 97 15 Aug 97 16 Aug 97 17 Aug 97 18 Aug 97 19 Aug 97 20 Aug 97 16:00-16:30 16:30-17:00 17:00-18:00 18:00-22:30 22:30-23:00 23:00-06:00 06:00-08:30 08:30-10:30 10:30-12:30 12:30-13:30 13:30-16:00 16:00-16:30 16:30-00:00 00:00-01:00 01:00-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-07:00 07:00-07:30 07:30-10:30 10:30-17:30 17:30-20:00 20:00-21:30 21:30-23:30 23:30-00:30 00:30-06:00 06:00-13:00 13:00-14:00 14:00-15:00 15:00-18:00 18:00-19:30 19:30-21:30 21:30-23:00 23:00-23:30 23:30-06:00 06:00-08:30 08:30-09:00 09:00-20:30 20:30-00:30 00:30-01:30 01:30-02:30 02:30-06:00 06:00-08:30 08:30-11:00 11:00-13:00 13:00-16:30 16:30-17:30 17:30-18:00 18:00-20:00 20:00-23:30 23:30-06:00 06:00-00:00 00:00-06:00 Duration 1/2hr 1/2 hr lhr 4-1/2 hr 1/2 hr 7hr 2-1/2 hr 2hr 2hr lhr 2-1/2 hr 1/2 hr 7-1/2 hr lhr 3hr 1/2 hr lhr 1/2 hr lhr 1/2 hr 3hr 7hr 2-1/2 hr 1-1/2 hr 2hr lhr 5-1/2 hr 7hr lhr lhr 3hr 1-1/2 hr 2hr 1-1/2 hr 1/2hr 6-1/2 hr 2-1/2 hr 1/2 hr 11-1/2 hr 4hr lhr lhr 3-1/2 hr 2-1/2 hr 2-1/2 hr 2hr 3-1/2 hr lhr 1/2 hr 2hr 3-1/2 hr 6-1/2 hr 18hr 6hr Activity Flow check Pulled out of hole to 18848.0 ft Rigged up Fluid system Mixed and pumped 5.000 bbl of treatment Rigged down Fluid system Pulled out of hole to 3700.0 ft Pulled out of hole to 194.0 ft Pulled BHA Laid out 5in drill pipe from derrick Serviced Top drive Ran Tubing to 594.0 ft (2-7/8in OD) Singled in drill pipe to 563.0 ft Ran Drillpipe in stands to 18842.0 ft Washed to 19145.0 ft Circulated at 19145.0 ft Rigged up Cement unit Mixed and pumped slurry - 20.000 bbl Pulled Drillpipe in stands to 18275.0 ft Displaced slurry - 13.000 bbl Held 630.0 psi pressure on 11.500 bbl squeezed cement Circulated at 18275.0 ft Pulled Drillpipe in stands to 595.0 ft Laid down 595.0 ft of Tubing Made up BHA no. 6 R.I.H. to 3947.0 ft Serviced Top drive R.I.H. to 14600.0 ft R.I.H. to 18641.0 ft Washed to 18990.0 ft Drilled cement to 19145.0 ft Circulated at 19145.0 ft Drilled to 19165.0 ft Worked toolstring at 19165.0 ft Circulated at 19165.0 ft Flow check Pulled out of hole to 3800.0 ft Pulled out of hole to 202.0 ft Pulled BHA R.I.H. to 18420.0 ft Circulated at 18420.0 ft Washed to 18940.0 ft Circulated at 18940.0 ft Washed to 19080.0 ft Washed to 19165.0 ft Circulated at 19165.0 ft Drilled to 19185.0 ft Circulated at 19185.0 ft Serviced Block line Repaired Draw works Performed formation integrity test Circulated at 19077.0 ft Circulated at 19077.0 ft Repaired Top drive Repaired Top drive Progress Report Facility M Pt L Pad Well MPL-20 Page 5 Rig Nabors 4~a$'~7~ Date 04 May 98 Date/Time 06:00-06:30 06:30-12:00 12:00-18:00 18:00-18:30 18:30-02:30 21 Aug 97 02:30-05:00 05:00-06:00 06:00-06:30 06:30-11:30 11:30-15:00 15:00-16:00 16:00-17:00 17:00-19:00 19:00-20:00 20:00-02:00 22 Aug 97 02:00-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-02:30 23 Aug 97 02:30-06:00 06:00-06:30 06:30-08:30 08:30-10:00 10:00-15:00 15:00-16:00 16:00-22:30 22:30-23:30 23:30-06:00 24 Aug 97 06:00-06:30 06:30-12:00 12:00-13:00 13:00-21:00 21:00-22:30 22:30-00:30 25 Aug 97 00:30-03:00 03:00-06:00 06:00-06:30 06:30-15:30 15:30-20:30 20:30-21:00 21:00-06:00 26 Aug 97 06:00-06:30 06:30-09:00 09:00-20:00 20:00-21:00 21:00-22:00 22:00-23:00 23:00-23:30 Duration 1/2 hr 5-1/2 hr 6hr 1/2 hr 8hr 2-1/2 hr lhr 1/2 hr 5hr 3-1/2 hr lhr lhr 2hr lhr 6hr 4hr 1/2 hr 4hr 1/2 hr 5hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 6-1/2 hr 3-1/2 hr 1/2 hr 2hr 1-1/2 hr 5hr lhr 6-1/2 hr lhr 6-1/2 hr 1/2 hr 5-1/2 hr lhr 8hr 1-1/2 hr 2hr 2-1/2 hr 3hr 1/2 hr 9hr 5hr 1/2 hr 9hr 1/2 hr 2-1/2 hr llhr lhr lhr lhr 1/2 hr Activity Held safety meeting Repaired Top drive Circulated at 19185.0 ft Held safety meeting Pulled out of hole to 0.0 ft Ran Drillpipe to 920.0 ft (2-7/8in OD) Ran Drillpipe in stands to 2000.0 ft Held safety meeting Ran Drillpipe to 19185.0 ft (4in OD) Circulated at 19185.0 ft Mixed and pumped slurry - 34.000 bbl Pulled Drillpipe in stands to 18200.0 ft Circulated at 18200.0 ft Held 1200.0 psi pressure on 7.500 bbl squeezed cement Wait on cement Pulled Drillpipe in stands to 8000.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Installed BOP test plug assembly Tested BOP stack Removed BOP test plug assembly Serviced Top drive Held safety meeting Made up BHA no. 8 R.I.H. to 18283.0 ft Drilled cement to 18950.0 ft Held safety meeting Drilled cement to 19080.0 ft Circulated at 19080.0 ft Drilled cement to 19195.0 ft Performed formation integrity test Drilled to 19237.0 ft Circulated at 19237.0 ft Pulled out of hole to 3000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Made up BHA no. 9 R.I.H. to 18232.0 ft Serviced Block line R.I.H. to 19237.0 ft Circulated at 19237.0 ft Drilled to 19266.0 ft Held safety meeting Flow check Circulated at 19260.0 ft Drilled to 19262.0 ft Pulled out of hole to 0.0 ft Held safety meeting Ran Drillpipe to 1189.0 ft (2-7/8in OD) Ran Drillpipe to 19260.0 ft (4in OD) Circulated at 19260.0 ft Mixed and pumped slurry - 35.000 bbl Pulled Drillpipe in stands to 18000.0 ft Held 760.0 psi pressure on 12.000 bbl squeezed cement Facility M Pt L Pad Progress Report Well MPL-20 Page 6 Rig Nabors ~ ~'~--~ Date 04 May 98 Date/Time 27 Aug 97 28 Aug 97 29 Aug 97 30 Aug 97 09 Feb 98 10 Feb 98 11 Feb 98 12 Feb 98 23:30-01:30 01:30-06:00 06:00-06:30 06:30-08:00 08:00-16:30 16:30-18:00 18:00-02:00 02:00-06:00 06:00-06:30 06:30-09:00 09:00-11:00 11:00-12:00 12:00-13:00 13:00-21:30 21:30-22:30 22:30-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-11:30 11:30-14:30 14:30-15:00 15:00-16:30 16:30-17:00 17:00-19:00 19:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-11:00 11:00-14:00 14:00-17:30 17:30-18:00 06:00-08:00 08:00-08:30 08:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-01:00 01:00-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-11:30 11:30-12:00 12:00-15:30 15:30-18:00 18:00-18:30 18:30-19:30 19:30-06:00 06:00-06:30 Duration 2hr 4-1/2 hr 1/2 hr 1-1/2 hr 8-1/2 hr 1-1/2 hr 8hr 4hr 1/2 hr 2-1/2 hr 2hr lhr lhr 8-1/2 hr lhr 7-1/2 hr 1/2 hr 1/2 hr lhr 3-1/2 hr 3hr 1/2 hr 1-1/2 hr 1/2 hr 2hr llhr 1/2 hr 1/2hr lhr 3hr 3hr 3-1/2 hr 1/2hr 2hr 1/2hr 21-1/2 hr 1/2hr 11-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 3hr 1/2hr 5hr 1/2 hr 3-1/2 hr 2-1/2 hr 1/2 hr lhr 10-1/2 hr 1/2 hr Activity Circulated at 18000.0 ft Held 1200.0 psi pressure on 2.500 bbl squeezed cement Held safety meeting Held 1200.0 psi pressure on 2.500 bbl squeezed cement Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 10 R.I.H. to 18000.0 ft Reamed to 18900.0 ft Held safety meeting Drilled cement to 19262.0 ft Circulated at 19262.0 ft Circulated at 19262.0 ft Flow check Pulled out of hole to 0.0 ft Serviced Block line Ran Drillpipe in stands to 17000.0 ft Held safety meeting Ran Drillpipe to 18835.0 ft (4in OD) Set Cement retainer at 18835.0 ft with 0.0 psi Performed formation integrity test Circulated at 18835.0 ft Performed formation integrity test Mixed and pumped slurry - 10.000 bbl Pulled Drillpipe in stands to 18435.0 ft Circulated at 18435.0 ft Laid down 18835.0 ft of Drillpipe Held safety meeting Laid down 1000.0 ft of Drillpipe Removed Bore protector Serviced Top ram Rigged down BOP stack Installed Xmas tree Freeze protect well - 60.000 bbl of Diesel Rigged down Drillfloor / Derrick Held safety meeting Rig moved 75.00 % Held safety meeting Rig moved 100.00 % Held safety meeting Serviced Top drive Removed Xmas tree Installed BOP stack Rigged up Top ram Installed BOP test plug assembly Tested BOP stack Held safety meeting Tested BOP stack Installed Wear bushing Made up BHA no. 1 R.I.H. to 2078.0 ft Held safety meeting Reamed to 2167.0 ft R.I.H. to 11000.0 ft Held safety meeting Progress Report Facility M Pt L Pad Well MPL-20 Rig Nabors ~ ~-'7~'~ Page 7 Date 04 May 98 Date/Time 06:30-15:30 15:30-19:00 19:00-19:30 19:30-21:30 21:30-22:00 22:00-05:30 13 Feb 98 05:30-06:00 06:00-06:30 06:30-16:00 16:00-16:30 16:30-22:30 22:30-06:00 14 Feb 98 06:00-06:30 06:30-07:30 07:30-09:00 09:00-10:00 10:00-19:00 19:00-20:00 20:00-21:00 21:00-22:00 22:00-06:00 15 Feb 98 06:00-06:30 06:30-12:00 12:00-13:00 13:00-13:30 13:30-14:00 14:00-16:30 16:30-19:00 19:00-21:30 21:30-22:00 22:00-02:00 16 Feb 98 02:00-06:00 06:00-06:30 06:30-16:00 16:00-18:00 18:00-18:15 18:15-19:30 19:30-21:00 21:00-21:30 21:30-00:30 17 Feb 98 00:30-01:30 01:30-04:30 04:30-06:00 06:00-06:30 06:30-12:30 12:30-20:30 20:30-23:00 23:00-06:00 18 Feb 98 06:00-06:30 06:30-12:00 12:00-17:00 17:00-18:00 18:00-18:30 18:30-21:30 Duration 9hr 3-1/2 hr 1/2hr 2hr 1/2hr 7-1/2 hr 1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 6hr 7-1/2 hr 1/2 hr lhr 1-1/2 hr lhr 9hr lhr lhr lhr 8hr 1/2 hr 5-1/2 hr lhr 1/2 hr 1/2hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 4hr 4hr 1/2 hr 9-1/2 hr 2hr 1/4 hr 1-1/4 hr 1-1/2 hr 1/2 hr 3hr lhr 3hr 1-1/2 hr 1/2 hr 6hr 8hr 2-1/2 hr 7hr 1/2 hr 5-1/2 hr 5hr lhr 1/2 hr 3hr Activity R.I.H. to 18578.0 ft Repaired Top drive Pulled out of hole to 17350.0 ft R.I.H. to 18578.0 ft Tested Casing Drilled cement to 18835.0 ft Drilled installed equipment - Cement retainer Held safety meeting Drilled installed equipment - Cement retainer Performed formation integrity test Circulated at 19266.0 ft Pulled out of hole to 0.0 ft Held safety meeting Pulled BHA Made up BHA no. 2 Serviced Top drive R.I.H. to 19103.0 ft Serviced Block line Held safety meeting Reamed to 19266.0 ft Drilled to 19365.0 ft Held safety meeting Drilled to 19472.0 fl Circulated at 19472.0 ft Pulled out of hole to 19103.0 ft R.I.H. to 19472.0 ft Circulated at 19472.0 ft Pulled out of hole to 14725.0 ft R.I.H. to 19333.0 ft Washed to 19472.0 ft Circulated at 19472.0 ft Pumped out of hole to 17000.0 ft Held safety meeting Pumped out of hole to 400.0 ft Pulled BHA Held safety meeting Made up BHA no. 3 R.I.H. to 6700.0 ft Circulated at 6750.0 ft R.I.H. to 13000.0 ft Circulated at 13000.0 ft R.I.H. to 19100.0 ft Circulated at 19103.0 ft Held safety meeting Reamed to 19472.0 ft Drilled to 19770.0 ft Circulated at 19770.0 ft Pumped out of hole to 14675.0 ft Held safety meeting Pumped out of hole to 10200.0 ft Pulled out of hole to 0.0 ft Serviced Drillfloor / Derrick Held safety meeting Rigged up sub-surface equipment - Liner hanger Facility Date/Time 19 Feb 98 20 Feb 98 21 Feb 98 M Pt L Pad Progress Report Well MPL-20 Rig NaborsAgEff'2-'7~ Page Date Duration Activity 21:30-22:00 22:00-06:00 06:00-06:15 06:15-10:00 10:00-15:30 15:30-15:45 15:45-17:30 17:30-18:00 18:00-18:15 18:15-20:00 20:00-20:30 20:30-22:30 22:30-23:30 23:30-01:00 01:00-03:00 03:00-06:00 06:00-06:15 06:15-09:00 09:00-15:30 15:30-16:30 16:30-18:00 18:00-18:15 18:15-06:00 06:00-06:15 06:15-09:00 09:00-10:30 10:30-13:30 13:30-16:30 16:30-18:00 18:00-18:15 18:15-20:30 1/2hr 8hr 1/4 hr 3-3/4 hr 5-1/2 hr 1/4 hr 1-3/4 hr 1/2 hr 1/4 hr 1-3/4 hr 1/2 hr 2hr lhr 1-1/2 hr 2hr 3hr 1/4 hr 2-3/4 hr 6-1/2 hr lhr 1-1/2 hr 1/4 hr 11-3/4 hr 1/4 hr 2-3/4 hr 1-1/2 hr 3hr 3hr 1-1/2 hr 1/4 hr 2-1/4 hr Circulated at 1000.0 ft Ran Drillpipe to 14500.0 ft (4in OD) Held safety meeting Ran Drillpipe to 18838.0 ft (4in OD) Circulated at 19770.0 ft Held safety meeting Mixed and pumped slurry - 24.500 bbl Set Liner hanger at 18838.0 ft with 4500.0 psi Held safety meeting Circulated at 19590.0 ft Pulled Drillpipe in stands to 18830.0 ft Reverse circulated at 18830.0 ft Tested Liner Ran Drillpipe in stands to 19590.0 ft Reverse circulated at 18590.0 ft Circulated at 18590.0 ft Held safety meeting Circulated at 18590.0 ft Laid down 5300.0 ft of 4in OD drill pipe Serviced Block line Laid down 6800.0 ft of 4in OD drill pipe Held safety meeting Laid down 19600.0 ft of 4in OD drill pipe Held safety meeting Laid down 730.0 ft of Tubing Rigged down Tubing handling equipment Serviced Pipe ram Rigged down BOP stack Installed Tubing head spool Held safety meeting Installed Xmas tree 8 04 May 98 Facility Date/Time 06 Mar 98 07 Mar 98 08 Mar 98 09 Mar 98 10 Mar 98 11 Mar 98 12 Mar 98 M Pt L Pad Progress Report Well MPL-20 Page 1 Rig Nabors 4ES Date 04 May 98 Duration Activity 15:00-02:00 02:00-02:15 02:15-04:00 04:00-06:00 06:00-08:00 08:00-08:30 08:30-09:00 09:00-12:00 12:00-12:15 12:15-14:00 14:00-20:00 20:00-21:30 21:30-02:30 02:30-03:30 03:30-04:00 04:00-06:00 06:00-06:15 06:15-11:30 11:30-12:15 12:15-12:30 12:30-15:45 15:45-18:30 18:30-19:00 19:00-19:30 19:30-20:15 20:15-20:30 20:30-03:30 03:30-05:00 05:00-06:00 06:00-06:15 06:15-14:00 14:00-21:00 21:00-04:00 04:00-06:00 06:00-06:15 06:15-09:30 09:30-10:15 10:15-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-13:45 13:45-14:30 14:30-15:30 15:30-16:00 16:00-23:30 23:30-01:00 01:00-06:00 06:00-17:00 17:00-21:30 21:30-22:00 22:00-06:00 06:00-20:00 20:00-21:00 llhr 1/4 hr 1-3/4 hr 2hr 2hr 1/2 hr 1/2 hr 3hr 1/4 hr 1-3/4 hr 6hr 1-1/2 hr 5hr lhr 1/2 hr 2hr 1/4 hr 5-1/4 hr 3/4 hr 1/4 hr 3-1/4 hr 2-3/4 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 7hr 1-1/2 hr lhr 1/4 hr 7-3/4 hr 7hr 7hr 2hr 1/4 hr 3-1/4 hr 3/4 hr 1/4 hr 1/2 hr lhr 1/2hr 1-1/4 hr 3/4 hr lhr 1/2 hr 7-1/2 hr 1-1/2 hr 5hr llhr 4-1/2 hr 1/2 hr 8hr 14hr lhr Rig moved 100.00 % Flow check Removed Xmas tree Installed BOP stack Tested All functions Removed Hanger plug Installed Wear bushing Installed Drillstring handling equipment Held safety meeting Made up BHA no. 1 Singled in drill pipe to 5281.0 ft Circulated at 5281.0 ft Singled in drill pipe to 11543.0 ft Serviced Block line Installed Drillstring handling equipment Singled in drill pipe to 13674.0 ft Held safety meeting Singled in drill pipe to 19400.0 ft Rigged up Logging/braided cable equipment Held safety meeting Circulated at 19400.0 ft Conducted electric cable operations Functioned TCP Flow check Pulled out of hole to 18838.0 ft Flow check Pulled out of hole to 665.0 ft Pulled BHA Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 9570.0 ft (4-1/2in OD) Installed Tubing handling equipment Ran Tubing to 18506.0 ft (4-1/2in OD) Rigged up High pressure lines Held safety meeting Reverse circulated at 18506.0 ft Rigged up High pressure lines Held safety meeting Tested High pressure lines Circulated at 18506.0 ft Injectivity test - 108.000 bbl injected at 5250.0 psi Circulated at 18506.0 ft Injectivity test - 340.000 bbl injected at 6600.0 psi Monitor pressures Bullhead well Monitor pressures FRAC job - 1012.000 bbl injected at 4550.0 psi Monitor pressures Monitor pressures (cont...) Circulated at 18506.0 ft Monitor wellbore pressures Circulated at 18506.0 ft Circulated at 18506.0 ft (cont...) Monitor wellbore pressures Progress Report Facility M Pt L Pad Well MPL-20 Rig Nabors 4ES Page 2 Date 04 May 98 Date/Time 21:00-21:15 21:15-21:30 21:30-22:00 22:00-03:30 13 Mar 98 03:30-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-00:00 14Mar 98 00:00-01:00 01:00-01:30 01:30-02:30 02:30-03:00 03:00-03:15 03:15-04:30 04:30-06:00 06:00-06:15 06:15-06:30 06:30-08:30 08:30-09:30 09:30-10:30 10:30-11:30 11:30-12:30 12:30-13:00 13:00-14:30 14:30-16:00 16:00-18:00 18:00-18:15 18:15-19:00 19:00-04:30 15 Mar 98 04:30-06:00 06:00-06:15 06:15-07:15 07:15-12:45 12:45-13:00 13:00-13:15 13:15-13:30 13:30-15:30 15:30-22:00 22:00-23:00 23:00-23:15 23:15-23:30 23:30-01:00 16 Mar 98 01:00-01:30 01:30-06:00 06:00-06:15 06:15-06:30 06:30-08:30 08:30-10:00 10:00-12:00 12:00-13:00 13:00-22:00 22:00-01:00 Duration 1/4 hr 1/4 hr 1/2 hr 5-1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 1/4 hr 17-3/4 hr lhr 1/2 hr lhr 1/2 hr 1/4 hr 1-1/4 hr 1-1/2 hr 1/4 hr 1/4 hr 2hr lhr lhr lhr lhr 1/2 hr 1-1/2 hr 1-1/2 hr 2hr 1/4hr 3/4 hr 9-1/2 hr 1-1/2 hr 1/4 hr lhr 5-1/2 hr 1/4 hr 1/4 hr 1/4 hr 2hr 6-1/2 hr lhr 1/4 hr 1/4hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/4 hr 1/4 hr 2hr 1-1/2 hr 2hr lhr 9hr 3hr Activity Rigged down Tubing handling equipment Rigged up Drillstring handling equipment Singled in drill pipe to 18620.0 ft Reverse circulated at 18620.0 ft Laid down 114.0 ft of 3-1/2in OD drill pipe Reverse circulated at 18506.0 ft Rigged up Tubing handling equipment Laid down 249.0 ft of Tubing Held safety meeting Laid down 18257.0 ft of Tubing Rigged up Drillstring handling equipment Made up BHA no. 2 R.I.H. to 2500.0 ft Reverse circulated at 2500.0 ft R.I.H. to 2683.0 ft Reverse circulated at 2683.0 ft Serviced Drillstring handling equipment Held safety meeting Serviced Draw works Reverse circulated at 2819.0 ft Serviced Block line R.I.H. to 5131.0 ft Reverse circulated at 5162.0 ft R.I.H. to 8090.0 ft Reverse circulated at 8121.0 ft R.I.H. to 13045.0 ft Reverse circulated at 13075.0 ft R.I.H. to 17150.0 ft Held safety meeting R.I.H. to 18622.0 ft Reverse circulated at 18830.0 ft Pulled out of hole to 17427.0 ft Held safety meeting Laid down 756.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 7.0 ft Pulled BHA Removed Wear bushing Installed BOP test plug assembly Tested All functions Serviced Annular preventor Tested Annular preventor Removed BOP test plug assembly Installed Wear bushing Made up BHA no. 3 Serviced Block line R.I.H. to 15400.0 ft Held safety meeting Serviced Draw works R.I.H. to 18809.0 ft Reverse circulated at 18809.0 ft Reamed to 18874.0 ft Serviced Swivel Reamed to 19358.0 ft Reverse circulated at 19358.0 ft Facility M Pt L Pad Progress Report Well MPL-20 Rig Nabors 4ES Page Date 3 04 May 98 Date/Time 17 Mar 98 18 Mar 98 19 Mar 98 01:00-04:30 04:30-06:00 06:00-07:30 07:30-08:15 08:15-08:30 08:30-09:00 09:00-10:30 10:30-21:30 21:30-23:00 23:00-23:30 23:30-02:00 02:00-04:00 04:00-06:00 06:00-06:15 06:15-06:30 06:30-16:00 16:00-18:00 18:00-18:15 18:15-03:00 03:00-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-10:00 10:00-10:30 10:30-11:30 11:30-12:30 12:30-13:30 13:30-14:00 14:00-15:30 15:30-16:00 Duration 3-1/2 hr 1-1/2 hr 1-1/2 hr 3/4 hr 1/4 hr 1/2 hr 1-1/2 hr llhr 1-1/2 hr 1/2 hr 2-1/2 hr 2hr 2hr 1/4hr 1/4hr 9-1/2 hr 2hr 1/4hr 8-3/4 hr 2-1/2 hr 1/2 hr 1/4 hr 1/4hr 1/2 hr 1/2hr 1/2 hr 2hr 1/2 hr lhr lhr lhr 1/2 hr 1-1/2 hr 1/2 hr Activity Reamed to 19600.0 ft Reverse circulated at 19600.0 ft Reverse circulated at 19600.0 ft (cont...) Circulated at 19600.0 ft Flow check Laid down 791.0 ft of 3-1/2in OD drill pipe Reverse circulated at 18809.0 ft Laid down 18050.0 ft of 3-1/2in OD drill pipe Pulled BHA Removed Wear bushing Installed Tubing handling equipment Installed Electrical submersible pumps Ran Tubing to 993.0 ft (2-7/8in OD) Held safety meeting Serviced Drillfloor / Derrick Ran Tubing to 9000.0 ft (2-7/8in OD) Installed Electric cable Held safety meeting Ran Tubing to 17582.0 ft (2-7/8in OD) Installed Electric cable Ran Tubing to 17708.0 ft (2-7/8in OD) Held safety meeting Serviced Draw works Ran Tubing to 18617.0 ft (2-7/8in OD) Installed Gas lift mandrel assembly Ran Tubing to 18739.0 ft (2-7/8in OD) Installed Electric cable Ran Tubing on landing string to 18763.0 ft Removed BOP stack Installed Xmas tree Tested Xmas tree Installed Hanger plug Freeze protect well - 84.000 bbl of Diesel Rigged down High pressure lines Schlumberger ANADRILL Survey Report EOW_survey.ASCII_FILE 28-AUG-97 12:55:20 Client: BP Exploration (Alaska), Inc. Field: Milne Point Well Name: MPL-20 Permanent datum GROUND LEVEL Depth measured from Rotary Table / Rig Floor Elevation of kelly bushing_ .49.85 FT Elevation of drill floor 49.85 FT Elevation of ground level 16.80 FT Magnetic Declination 27.99 DEG Grid Convergence 0.00 DEG Total Correction 27.99 DEG Page 001 TIE IN POINT Measured depth True vertica~ depth N/S disp (-ye for S) E/W disp (-ye for W) 0.00 FT 0.00 FT 0.00 FT 0.00 FT Inclination 0.00 DEG Azimuth 0.00 DEG Azimuth from rotary table to the target 232.20 DEG ORIGINAL Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION DEPTH DEPTH SECTION INCLN. FT FT FT FT DEG 0.0 0.00 0.00 0.00 0.00 100.0 100.00 100.00 -0.30 0.35 200.0 100.00 200.00 -0.85 0.30 300.0 100.00 300.00 -0.98 0.22 400.0 100.00 399.99 0.06 1.12 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 0.0 0.00 0.00 0.00 0.00 0.00 41.8 0.23 0.20 0.31 41.80 0.35 37.5 0.66 0.57 0.87 40.48 0.06 279.8 0.90 0.54 1.05 30.66 0.45 253.9 0.67 -0.59 0.89 318.34 0.93 500.0 100.00 499.95 2.74 2.20 599.0 99.00 598.83 7.20 3.28 699.0 100.00 698.47 15.37 6.30 800.0 101.00 798.58 28.65 8.85 900.0 100.00 896.74 47.62 13.08 254.5 -0.12 -3.38 3.38 268.00 1.08 250.1 -1.59 -7.88 8.03 258.58 1.11 238.8 -5.41 -15.26 16.19 250.49 3.15 232.8 -12.98 -26.19 29.23 243.64 2.64 227.3 -25.31 -40.64 47.88 238.09 4.35 1000.0 100.00 993.45 72.94 16.34 1100.0 100.00 1088.94 102.56 18.18 1200.0 100.00 1183.37 135.44 20.23 1300.0 100.00 1276.32 172.31 23.05 1400.0 100.00 1366.43 215.58 28.25 228.2 -42.36 -59.45 73.00 234.53 3.27 229.9 -61.79 -81.87 102.57 232.96 1.91 231.5 -82.60 -107.34 135.44 232.42 2.12 232.4 -105.31 -136.38 172.31 232.33 2.84 233.3 -131.42 -170.89 215.58 232.44 5.21 1500.0 100.00 1452.98 265.62 31.84 1600.0 100.00 1537.49 319.05 32.79 1700.0 100.00 1621.05 373.96 33.85 1800.0 100.00 1702.83 431.49 36.41 1900.0 100.00 1782.16 492.36 38.59 233.9 -161.11 -211.19 265.63 232.66 3.60 234.1 -192.53 -254.44 319.08 232.89 0.96 233.7 -224.90 -298.82 374.00 233.03 1.08 233.0 -259.26 -344.98 431.54 233.07 2.59 232.4 -296.15 -393.40 492.41 233.03 2.21 2000.0 100.00 1859.71 555.49 39.71 2100.0 100.00 1935.00 621.28 42.59 2200.0 100.00 2006.86 690.80 45.52 2300.0 100.00 2074.75 764.20 48.95 2400.0 100.00 2138.06 841.58 52.47 232.3 -334.72 -443.38 555.54 232.95 1.12 233.5 -374.39 -495.87 621.33 232.95 2.99 232.8 -416.09 -551.50 690.86 232.97 2.97 232.1 -460.84 -609.69 764.26 232.92 3.47 231.7 -508.59 -670.58 841.63 232.82 3.53 2500.0 100.00 2198.06 921.58 53.79 2600.0 100.00 2255.65 1003.33 55.89 2700.0 100.00 2309.47 1087.59 58.97 2800.0 100.00 2358.66 1174.64 62.09 2900.0 100.00 2403.43 1264.05 64.72 232.0 -558.01 -733.49 921.62 232.74 1.34 232.2 -608.22 -798.00 1003.36 232.69 2.11 232.2 -659.87 -864.58 1087.62 232.65 3.08 231.7 -713.53 -933.13 1174.67 232.60 3.15 231.6 -769.00 -1003.24 1264.07 232.53 2.63 3000.0 100.00 2443.51 1355.64 68.02 231.5 -825.97 -1074.98 1355.66 232.46 3.30 Page 1 EOW_survey.ASCII_FILE [] Schlumberger ANADRILL Survey Report 28-AUG-97 12:55:20 Page 002 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 3100.0 100.00 2477.87 1449.53 71.78 232.4 -883.83 -1148.92 1449.54 232.43 3.85 3200.0 100.00 2506.47 1545.33 74.97 233.2 -941.75 -1225.24 1545.35 232.45 3.28 3300.0 100.00 2531.46 1642.15 76.09 233.1 -999.82 -1302.72 1642.17 232.49 1.12 3400.0 100.00 2556.34 1738.98 75.10 233.7 -1057.57 -1380.48 1739.01 232.54 1.15 3500.0 100.00 2581.38 1835.74 75.90 234.6 -1114.26 -1458.95 1835.79 232.63 1.18 3600.0 100.00 2605.31 1932.73 76.41 235.0 -1170.23 -1538.29 1932.82 232.74 0.64 3700.0 100.00 2628.29 2029.94 77.01 234.9 -1226.12 -1617.96 2030.07 232.84 0.61 3800.0 100.00 2650.55 2127.32 77,27 235.2 -1282.04 -1697.82 2127.50 232.94 0.32 3900.0 100.00 2672.45 2224.76 77.43 235.2 -1337.87 -1777.85 2225.00 233.04 0.16 4000.0 100.00 2694.06 2322.29 77.61 234.8 -1393.94 -1857.78 2322.59 233.12 0.34 4100.0 100.00 2714.90 2420.01 78.33 234.4 -1450.60 -1937.50 2420.36 233.18 0.82 4200.0 100.00 2734.69 2517.95 78.84 234.6 -1507.52 -2017.30 2518.35 233.23 0.55 4300.0 100.00 2753.05 2616.16 80.00 234.8 -1564.39 -2097.48 2616.62 233.28 1.16 4400.0 100.00 2769.57 2714.68 80.99 234.8 -1621.31 -2178.02 2715.22 233.34 0.99 4500.0 100.00 2784.79 2813.46 81.50 233.3 -1679.33 -2258.02 2814.04 233.36 1.57 4600.0 100.00 2801.24 2912.08 79.56 233.1 -1738.42 -2337.00 2912.67 233.36 1.95 4700.0 100.00 2819.92 3010.30 78.91 233.7 -1796.99 -2415.87 3010.91 233.36 0.88 4800.0 100.00 2838.72 3108.48 79.42 234.0 -1854.93 -2495.18 3109.13 233.37 0.59 4900.0 100.00 2856.61 3206.80 79.96 234.4 -1912.48 -2574.98 3207.50 233.40 0.67 5000.0 100.00 2874.82 3305.10 79.06 232.4 -1971.10 -2653.91 3305.82 233.40 2.16 5100.0 100.00 2893.84 3403.27 79.01 232.5 -2030.93 -2731.75 3403.99 233.37 0.11 5200.0 100.00 2913.82 3501.25 77.94 233.0 -2090.31 -2809.69 3501.96 233.35 1.14 5300.0 100.00 2936.10 3598,73 76.32 233.3 -2148.84 -2887.64 3599.44 233.35 1.67 5400.0 100.00 2959.30 3695.98 76.84 233.2 -2207.04 -2965.58 3696.71 233.34 0.53 5500.0 100.00 2981.58 3793.44 77.42 233.6 -2265.16 -3043.85 3794.20 233.34 0.70 5600.0 100.00 3002.94 3891.12 77.91 232.8 -2323.68 -3122.07 3891.89 233.34 0.92 5700.0 100.00 3023.55 3988.97 78.31 232.1 -2383.32 -3199.65 3989.73 233.32 0.79 5800.0 100.00 3044.61 4086.72 77.37 231.1 -2444.04 -3276.26 4087.44 233.28 1.36 5900.0 100.00 3066.23 4184.33 77.66 230.7 -2505.61 -3352.03 4185.00 233.22 0.49 6000.0 100.00 3088.28 4281.83 76.86 230.6 -2567.46 -3427.45 4282.44 233.16 0.81 6100.0 100.00 3110.62 4379.27 77.32 230.9 -2629.13 -3502.94 4379.83 233.11 0.55 6200.0 100.00 3132.69 4476.78 77.18 231.1 -2690.57 -3578.68 4477.29 233.06 0.17 6300.0 100.00 3154.78 4574.29 77.30 230.8 -2752.08 -3654.37 4574.75 233.02 0.23 6400.0 100.00 3177.08 4671.76 76.93 231.7 -2813.10 -3730.39 4672.19 232.98 0.95 6500.0 100.00 3199.31 4769.25 77.38 231.8 -2873.46 -3806.96 4769.66 232.95 0.46 6600.0 100.00 3221.19 4866.83 77.34 232.0 -2933.67 -3883.74 4867.22 232.93 0.20 6700.0 100.00 3243.26 4964.36 77.16 232.0 -2993.72 -3960.60 4964.75 232.92 0.18 6800.0 100.00 3265.40 5061.88 77.26 231.8 -3053.89 -4037.34 5062.25 232.90 0.22 6900.0 100.00 3286.94 5159.53 77.86 231.7 -3114.34 -4114.03 5159.88 232.87 0.61 7000.0 100.00 3307.14 5257.46 78.83 231.4 -3175.25 -4190.73 5257.79 232.85 1.01 7100.0 100.00 3326.12 5355.62 79.29 231.0 -3236.77 -4267.25 5355.94 232.82 0.60 7200.0 100.00 3344.90 5453.83 79.06 231.2 -3298.45 -4343.69 5454.11 232.79 0.30 7300.0 100.00 3364.69 5551.84 78.11 231.8 -3359.47 -4420.40 5552.11 232.77 1.12 7400.0 100.00 3385.88 5649.57 77.43 231.7 -3419.97 -4497.15 5649.82 232.75 0.69 7500.0 100.00 3408.13 5747.05 76.85 232.0 -3480.19 -4573.81 5747.30 232.73 0.65 Page 2 [] Schlumberger ANADRILL Survey Report EOW_survey.ASCII_FILE 28-AUG-97 12:55:20 Page 003 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 7600.0 100.00 3431.12 5844.38 76.57 231.9 -3540.18 -4650.45 5844.62 232.72 0.30 7700.0 100.00 3453.68 5941.80 77.36 232.7 -3599.75 -4727.53 5942.04 232.71 1.11 7800.0 100.00 3474.73 6039.55 78.33 233.2 -3658.65 -4805.55 6039.79 232.72 1.09 7900.0 100.00 3494.64 6137.53 78.70 233.3 -3717.35 -4884.02 6137.79 232.72 0.37 8000.0 100.00 3513.85 6235.64 79.15 233.6 -3775.86 -4962.81 6235.92 232.73 0.60 8100.0 100.00 3533.34 6333.69 78.38 233.9 -3833.86 -5041.91 6333.98 232.75 0.82 8200.0 100.00 3553.67 6431.54 78.16 234.6 -3891.07 -5121.37 6431.86 232.77 0.72 8300.0 100.00 3574.83 6529.19 77.41 234.5 -3947.75 -5200.99 6529.55 232.80 0.76 8400.0 100.00 3597.16 6626.60 76.78 234.0 -4004.70 -5280.10 6626.99 232.82 0.80 8500.0 100.00 3620.32 6723.85 76.44 233.6 -4062.16 -5358.60 6724.26 232.84 0.52 8600.0 100.00 3644.41 6820.86 75.68 234.0 -4119.48 -5436.92 6821.30 232.85 0.85 8700.0 100.00 3669.64 6917.53 75.09 235.5 -4175.32 -5515.93 6918.01 232.88 1.57 8800.0 100.00 3696.17 7013.76 74.14 235.9 -4229,66 -5595.58 7014.31 232.91 1.03 8900.0 100.00 3723.24 7109.87 74.45 235.0 -4284.25 -5674.87 7110.48 232.95 0.92 9000.0 100.00 3748.40 7206.55 76.40 234.5 -4340.11 -5753.90 7207.21 232.97 2.01 9100.0 100.00 3771.03 7303.91 77.45 233.7 -4397.22 -5832.80 7304.60 232.99 1.31 9200.0 100.00 3791.77 7401.71 78.60 233.1 -4455.55 -5911.33 7402.42 232.99 1.29 9300.0 100.00 3812.22 7499.59 77.80 232.6 -4514.66 -5989.35 7500.30 232.99 0.94 9400.0 100.00 3834.04 7597.18 77.00 232.4 -4574.07 -6066.78 7597.89 232.99 0.82 9500.0 100.00 3856.29 7694.67 77.29 232.3 -4633.62 -6143.97 7695.38 232.98 0.31 9600.0 100.00 3877.17 7792.46 78.60 231.6 -4693.90 -6220.98 7793.15 232.96 1.48 9700.0 100.00 3897.15 7890.43 78.35 231.2 -4755.09 -6297.50 7891.10 232.94 0.55 9800.0 100.00 3916.38 7988.51 79.48 229.6 -4817.71 -6373.05 7989.13 232.91 1.86 9900.0 100.00 3935.09 8086.62 78.95 229.0 -4881.77 -6447.53 8087.17 232.87 0.79 END GYRO SURVEYS 9968.3 68.30 3948.73 8153.44 78.01 229.1 -4925.63 -6498.07 8153.94 232.84 1.38 10060.5 92.20 3968.49 8243.38 77.24 229.5 -4984.36 -6566.35 8243.83 232.80 0.94 10154.8 94.30 3989.12 8335.29 77.48 229.4 -5044.18 -6636.27 8335.69 232.76 0.27 10249.6 94.80 4009.77 8427.70 77.36 229.2 -5104.51 -6706.41 8428.05 232.72 0.24 10343.8 94.20 4031.04 8519.28 76.54 228.0 -5165.20 -6775.25 8519.58 232.68 1.52 10434.4 90.60 4052.42 8607.10 76.16 228.2 -5223.99 -6840.78 8607.34 232.63 0.47 10526.2 91.80 4073.98 8696.12 76.68 228.3 -5283.41 -6907.35 8696.32 232.59 0.58 10621.0 94.80 4095.20 8788.32 77.45 228.8 -5344.57 -6976.60 8788.48 232.55 0.96 10716.1 95.10 4115.32 8881.10 78.12 228.7 -5405.85 -7046.48 8881.23 232.51 0.71 10808.9 92.80 4134.00 8971.87 78.65 229.6 -5465.31 -7115.24 8971.97 232.47 1.11 10903.9 95.00 4152.94 9064.85 78.36 229.0 -5526.02 -7185.82 9064.92 232.44 0.69 10997.2 93.30 4171.54 9156.09 78.64 228.2 -5586.48 -7254.40 9156.15 232.40 0.89 11090.1 92.90 4190.42 9246.85 77.91 228.6 -5646.87 -7322.42 9246.89 232.36 0.89 11183.0 92.90 4210.12 9337.49 77.60 229.2 -5706.55 -7390.83 9337.51 232.33 0.71 11277.2 94.20 4230.31 9429.37 77.65 229.2 -5766.67 -7460.48 9429.39 232.30 0.05 11370.7 93.50 4250.51 9520.55 77.39 229.6 -5826.08 -7529.80 9520.56 232.27 0.50 11464.1 93.40 4270.62 9611.74 77.75 232.9 -5883.16 -7600.92 9611.74 232.26 3.47 11557.9 93.80 4290.50 9703.39 77.78 233.5 -5938.07 -7674.32 9703.40 232.27 0.63 11653.6 95.70 4310.96 9796.86 77.53 233.1 -5993.94 -7749.28 9796.87 232.28 0.48 11747.9 94.30 4331.30 9888.94 77.56 231.8 -6050.06 -7822.28 9888.95 232.28 1.35 11842.3 94.40 4351.30 9981.20 77.98 232.6 -6106.61 -7895.18 9981.21 232.28 0.94 Page 3 [] Schlumberger ANADRILL Survey Report EOW_survey.ASCII_FILE 28-AUG-97 12:55:20 Page 004 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET DEPTH DEPTH SECTION FT FT FT FT 11935.2 92.90 4370.60 10072.06 12029.3 94.10 4390.33 10164.07 12123.9 94.60 4410.39 10256.52 12216.4 92.50 4429.73 10346.97 12312.4 96.00 4448.86 10441.04 STATION INCLN. DEG 78.03 77.77 77.75 78.11 78.90 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 232.8 -6161.67 -7967.46 10072.08 232.28 0.22 232.6 -6217.43 -8040.66 10164.08 232.29 0.35 231.4 -6274.35 -8113.51 10256.53 232.28 1.24 231.7 -6330.59 -8184.35 10346.98 232.28 0.50 232.8 -6388.19 -8258.73 10441.05 232.28 1.39 12407.1 94.70 4466.59 10534.05 12500.7 93.60 4482.94 10626.20 12595.2 94.50 4498.55 10719.35 12688.2 93.00 4513.71 10811.08 12780.9 92.70 4529.03 10902.50 79.52 80.36 80.62 80.62 80.36 233.2 -6444.17 -8333.02 10534.07 232.28 0.78 233.5 -6499.18 -8406.96 10626.21 232.29 0.95 234.5 -6553.96 -8482.36 10719.37 232.31 1.08 232.7 -6608.41 -8556.21 10811.10 232.32 1.91 232.0 -6664.26 -8628.60 10902.52 232.32 0.80 12873.6 92.70 4544.78 10993.85 12967.0 93.40 4561.13 11085.80 13059.9 92.90 4577.42 11177.25 13154.7 94.80 4594.05 11270.56 13248.6 93.90 4611.04 11362.90 80.07 79.77 80.03 79.76 79.40 232.0 -6720.50 -8700.58 10993.87 232.32 0.31 231.1 -6777.68 -8772.60 11085.82 232.31 1.00 231.0 -6835.17 -8843.73 11177.26 232.30 0.30 231.7 -6893.46 -8916.62 11270.58 232.29 0.78 230.6 -6951.39 -8988.54 11362.91 232.28 1.21 13342.8 94.20 4628.11 11455.53 13437.2 94.40 4644.71 11548.45 13530.7 93.50 4661.06 11640.51 13627.0 96.30 4678.20 11735.26 13721.1 94.10 4695.34 11827.76 79.72 80.02 79.84 79.66 79.35 232.7 -7008.87 -9061.19 11455.54 231.5 -7065.95 -9134.51 11548.46 231.5 -7123.26 -9206.56 11640.52 231.0 -7182.58 -9280.46 11735.26 230.9 -7240.87 -9352.32 11827.76 232.28 2.22 232.28 1.29 232.27 0.19 232.26 0.54 232.25 0.35 13815.0 93.90 4712.91 11919.99 13909.3 94.30 4731.22 12012.48 14005.4 96.10 4750.64 12106.54 14100.0 94.60 4770.45 12199.00 14194.0 94.00 4790.53 12290.80 79.08 78.53 78.15 77.68 77.65 231.4 -7298.73 -9424.16 11919.99 230.9 -7356.75 -9496.20 12012.48 229.7 -7416.87 -9568.61 12106.54 231.2 -7475.77 -9639.93 12199.00 230.7 -7533.62 -9711.25 12290.80 232.24 0.60 232.23 0.78 232.22 1.29 232.21 1.63 232.20 0.52 14288.2 94.20 4811.30 12382.65 14383.9 95.70 4832.83 12475.88 14478.4 94.50 4853.44 12568.11 14571.2 92.80 4873.61 12658.68 14665.2 94.00 4894.25 12750.35 76.87 77.13 77.68 77.21 77.42 230.7 -7591.82 -9782.35 12382.65 231.7 -7650.25 -9855.02 12475.89 232.6 -7706.84 -9927.84 12568.11 230.4 -7763.22 -9998.73 12658.68 230.9 -7821.36 -10069.64 12750.35 232.19 0.83 232.18 1.05 232.18 1.10 232.17 2.37 232.16 0.56 14759.5 94.30 4915.15 12842.29 14853.2 93.70 4936.10 12933.61 14948.0 94.80 4956.94 13026.08 15021.9 73.90 4973.05 13098.19 15116.1 94.20 4993.85 13190.06 76.98 77.18 77.42 77.40 77.08 231.7 -7878.86 -10141.41 12842.30 231.3 -7935.71 -10212.88 12933.62 231.1 -7993.66 -10284.96 13026.09 231.2 -8038.90 -10341.13 13098.20 232.9 -8095.40 -10413.57 13190.07 232.16 0.95 232.15 0.47 232.15 0.33 232.14 0.13 232.14 1.79 15209.4 93.30 5014.81 13280.97 15304.3 94.90 5036.47 13373.30 15397.8 93.50 5057.91 13464.27 15491.8 94.00 5078.64 13555.96 15584.7 92.90 5098.44 13646.72 76.96 76.65 76.84 77.69 77.69 230.6 -8151 229.7 -8210 231.7 -8268 232.6 -8324 231.8 -8380 .68 -10484.96 13280.98 .88 -10555.89 13373.31 .52 -10626.32 13464.29 .78 -10698.71 13555.98 .41 -10770.43 13646.74 232.14 2.41 232,12 0.98 232.11 2.09 232.11 1.30 232.11 0.84 15679.8 95.10 5118.84 13739.61 15774.7 94.90 5139.51 13832.22 15868.7 94.00 5160.48 13923.82 15962.6 93.90 5182.01 14015.20 16055.9 93.30 5203.87 14105.86 77.54 77.30 76.92 76.57 76.33 231.9 -8437.79 -10843.48 13739.63 230.7 -8495.70 -10915.76 13832.24 230.8 -8553.67 -10986.72 13923.84 231.1 -8611.25 -11057.70 14015.22 230.0 -8668.89 -11127.74 14105.89 232.11 0.19 232.11 1.26 232.10 0.42 232.09 0.49 232.08 1.17 Page 4 Schlumberger ANADRILL Survey Report EOW_survey.ASCII_FILE 28-AUG-97 12:55:20 Page 005 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION DEPTH DEPTH SECTION INCLN. FT FT FT FT DEG 16150.2 94.30 5226.40 14197.34 76.03 16241.9 91.70 5248.41 14286.29 76.19 16333.5 91.60 5269.97 14375.28 76.58 16427.8 94.30 5291.75 14467.03 76.72 16522.8 95.00 5313.75 14559.42 76.50 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 229.5 -8728.05 -11197.63 14197.38 232.07 0.61 230.1 -8785.51 -11265.62 14286.33 232.05 0.66 231.4 -8841.83 -11334.56 14375.33 232.04 1.44 232.2 -8898.57 -11406.66 14467.08 232.04 0.84 229.8 -8956.73 -11478.48 14559.48 232.03 2.47 16617.3 94.50 5335.80 14651.22 76.51 16712.0 94.70 5357.66 14743.33 76.81 16805.3 93.30 5378.95 14834,17 76.81 16900.5 95.20 5400.78 14926,83 76.67 16994.5 94.00 5422.60 15018.26 76,49 229.6 -9016.16 -11548.56 14651.29 232.02 0.21 232.0 -9074.40 -11619.96 14743.41 232.01 2.49 232.2 -9130.20 -11691.64 14834.25 232.01 0.21 232.3 -9186.92 -11764.91 14926.91 232.01 0.18 231.3 -9243.47 -11836.76 15018.34 232.01 1.05 17089.1 94.60 5444.79 15110.19 76.38 17184.8 95.70 5467.70 15203.07 75.92 17279.4 94.60 5491.99 15294.47 74.32 17373.9 94.50 5518.54 15385.16 73.04 17469.8 95.90 5547.18 15476.68 72.21 230.3 -9301.59 -11908.02 15110.28 232.01 1.03 230.6 -9360.75 -11979.67 15203.16 232.00 0.57 231.5 -9418.23 -12050.77 15294.57 231.99 1.93 231.9 -9474.44 -12121.94 15385.26 231.99 1.41 233.5 -9529.90 -12194.74 15476.78 231.99 1.81 17562.6 92.80 5576.34 15564.71 71.17 17659.2 96.60 5608.76 15655.59 69.61 17752.5 93.30 5642.88 15742.27 67.49 17847.9 95.40 5681.24 15829.41 65.08 17941.0 93.10 5721.32 15913.34 63.92 235.3 -9581.19 -12266.37 15564.79 232.01 2.16 234.6 -9633.44 -12340.86 15655.67 232.02 1.75 236.6 -9682.50 -12412.50 15742.33 232.04 3.02 235.4 -9731.33 -12484.90 15829.46 232.07 2.78 234.7 -9779.47 -12553.78 15913.37 232.08 1.42 18035.2 94.20 5763.62 15997.39 62.72 18129.7 94.50 5808.68 16080.28 60.32 18224.1 94.40 5856.80 16161.30 58.38 18317.6 93.50 5907.50 16239.74 55.95 18413.3 95.70 5962.68 16317.87 53.62 235.6 -9827.57 -12622.85 15997.42 232.10 1.53 236.1 -9874.~20 -12691.58 16080.30 232.12 2.58 236.1 -9919.49 -12758.99 16161.31 232.14 2.06 234,4 -9964.25 -12823.54 16239.75 232.15 3.01 234.2 -10009.87 -12887.03 16317.88 232.16 2.44 18506.6 93.30 6019.51 16391.84 51.33 18601.1 94.50 6080.08 16464.37 48.94 18694.5 93.40 6143.32 16533.06 45.81 18789.4 94.90 6211.48 16599.02 42.36 18884.6 95.20 6283.93 16660.57 38.52 232.7 -10053.92 -12946.47 16391.84 232.17 2.77 231.7 -10098.36 -13003.79 16464.37 232.17 2.66 230.4 -10141.54 -13057.24 16533.07 232.16 3.50 229.0 -10184.22 -13107.60 16599.02 232.15 3.78 226.6 -10225.65 -13153.36 16660.58 232.14 4.35 18977.6 93.00 6358.27 16716.02 35.32 19035.3 57.70 6405.42 16748.93 35.09 19154.6 119.30 6502.86 16817.25 35.40 Projected to TD 19261.0 106.40 6589.59 16878.61 35.40 224.0 -10264.90 -13193.09 16716.04 232.12 3.83 223.8 -10288.87 -13216.16 16748.96 232.10 0.45 226.7 -10337.32 -13265.04 16817.30 232.07 1.43 226.7 -10379.59 -13309.90 16878.66 232.05 0.00 Page 5 ANADRILL SCHLUMBERGER Survey report Client ........... ~ ...... : BP Exploration (Alaska) Inc. Field ............ '}:i.' ....... : Milne Point Well ..................... : MPL-20 Spud date ................ : 27-July-97 .<tPI number ............... : 50-029-27790-00 Last survey date ......... : 17-Feb-98 Engineer ................. : J. Rathert, D. Milton Total accepted surveys...: 206 MD of first survey ....... : 0.00 ft MD of last survey ........ : 19701.53 ft Rig: .................... : Nabors 27E State: ................... : Alaska 18-Feb-98 06:28:02 Page 1 of 8 Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference - - Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 16.80 ft [B above permanent ....... : 49.85 ft DF above permanent ....... : 49.85 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point-- Latitude (+N/S-) ......... : Na Departure (+E/W-) ........ : Na Azimuth from rotary table to target: 232.20 degrees Geomagnetic data Magnetic model ........... : BGGM version 1997 Magnetic date ............ : 14-Mar-1998 Magnetic field strength..: 1145.71 HCNT Magnetic dec (+E/W-) ..... : 27.78 degrees Magnetic dip ............. : 80.74 degrees MWD survey Reference Criteria - Reference G .............. : 1003.00 mGal Reference H .............. : 1147.00 HCNT Reference Dip ............ : 80.74 degrees Tolerance of S ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections - -- Magnetic dec (+E/W-) ..... : 27.78 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.78 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c) 1998 Anadrill IDEAL ID5 OB 68R] _ -- ANADRILL SCHLUMBERGER Survey Report 18-Feb-98 06:28:02 Page 2 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.0 2 100.00 0.35 41.8 3 200.00 0.30 37.5 4 300.00 0.22 279.8 5 400.00 1.12 253.9 6 500.00 2.20 254.5 7 599.00 3.28 250.1 8 699.00 6.30 238.8 9 800.00 8.85 232.8 10 900.00 13.08 227.3 11 1000.00 16.34 228.2 12 1100.00 18.18 229.9 13 1200.00 20.23 231.5 14 1300.00 23.05 232.4 15 1400.00 28.25 233.3 16 1500.00 31.84 233.9 17 1600.00 32.79 234.1 18 1700.00 33.85 233.7 19 1800.00 36.41 233.0 20 1900.00 38.59 232.4 21 2000.00 39.71 232.3 22 2100.00 42.59 233.5 23 2200.00 45.52 232.8 24 2300.00 48.95 232.1 25 2400.00 52.47 231.7 26 2500.00 53.79 232.0 27 2600.00 55.89 232.2 28 2700.00 58.97 232.2 29 2800.00 62.09 231.7 30 2900.00 64.72 231.6 0.00 100.00 100.00 100.00 100.00 100.00 99.00 100.00 101.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) i00f) type type 0.00 0.00 0.00 100.00 -0.30 0.23 200.00 -0.85 0.66 300.00 -0.98 0.90 399.99 0.06 0.67 499.95 598.83 698.47 798.58 896.74 993.45 1088.94 1183.37 1276.32 1366.43 1452.98 1537.49 1621.05 1702.83 1782.16 1859.71 1935.00 2006.86 2074.75 2138.06 2198.06 2255.65 2309.47 2358.66 2403.43 2.74 -0.12 7.20 -1.59 15.37 -5.41 28.65 -12.98 47.62 -25.31 72.94 -42.36 102.56 -61.79 135.44 -82.60 172.31 -105.31 215.58 -131.42 265.62 -161.11 319.05 -192.53 373.96 -224.90 431.49 -259.26 492.36 -296.15 555.49 -334.72 621.28 -374.39 690.80 -416.09 764.20 -460.84 841.58 -508.59 921.58 1003.33 1087.59 1174.64 1264.05 0.00 0.20 0.57 0.54 -0.59 -3.38 -7.88 -15.26 -26.19 -40.64 -59.45 -81.87 -107.34 -136.38 -170.89 -211.19 -254.44 -298.82 -344.98 -393.40 -443.38 -495.87 -551.50 -609.69 -670.58 0.00 0.31 0.87 1.05 0.89 3.38 8.03 16.19 29.23 47.88 73.00 102.57 135.44 172.31 215.58 265.63 319.08 374.00 431.54 492.41 555.54 621.33 690.86 764.26 841.63 0.00 41.80 40.48 30.66 318.34 268.00 258.58 250.49 243.64 238.09 234.53 232.96 232.42 232.33 232.44 232.66 232.89 233.03 233.07 233.03 232.95 232.95 232.97 232.92 232.82 -558.01 -733.49 921.62 232.74 -608.22 -798.00 1003.36 232.69 -659.87 -864.58 1087.62 232.65 -713.53 -933.13 1174.67 232.60 -769.00 -1003.24 1264.07 232.53 0.00 0.35 0.06 0.45 0.93 1.08 1.11 3.15 2.64 4.35 3.27 1.91 2.12 2.84 5.21 3.60 0.96 1.08 2.59 2.21 1.12 2.99 2.97 3.47 3.53 1.34 2.11 3.08 3.15 2.63 TIP GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO [(c)1998 Anadrill IDEAL ID5 OB 68R] _ -- ANADRILL SCHLUMBERGER Survey Report 18-Feb-98 06:28:02 Page 3 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 3000.00 68.02 231.5 32 3100.00 71.78 232.4 33 3200.00 74.97 233.2 34 3300.00 76.09 233.1 35 3400.00 75.10 233.7 36 3500.00 75.90 234.6 37 3600.00 76.41 235.0 38 3700.00 77.01 234.9 39 3800.00 77.27 235.2 40 3900.00 77.43 235.2 41 4000.00 77.61 234.8 42 4100.00 78.33 234.4 43 4200.00 78.84 234.6 44 4300.00 80.00 234.8 45 4400.00 80.99 234.8 46 4500.00 81.50 233.3 47 4600.00 79.56 233.1 48 4700.00 78.91 233.7 49 4800.00 79.42 234.0 50 4900.00 79.96 234.4 51 5000.00 79.06 232.4 52 5100.00 79.01 232.5 53 5200.00 77.94 233.0 54 5300.00 76.32 233.3 55 5400.00 76.84 233.2 56 5500.00 77.42 233.6 57 5600.00 77.91 232.8 58 5700.00 78.31 232.1 59 5800.00 77.37 231.1 60 5900.00 77.66 230.7 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 TVD depth (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- disp zAzim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 2443.51 1355.64 -825 2477.87 1449.53 -883 2506.47 1545.33 -941 2531.46 1642.15 -999 2556.34 1738.98 -1057 2581.38 2605.31 2628.29 2650.55 2672.45 2694.06 2714.90 2734.69 2753.05 2769.57 2784.79 2801.24 2819.92 2838.72 2856.61 2874.82 2893.84 2913.82 2936.10 2959.30 2981.58 3002.94 3023.55 3044.61 3066.23 .97 -1074 .83 -1148 .75 -1225 .82 -1302 .57 -1380 .98 .92 .24 .72 .48 1835.74 -1114 1932.73 -1170 2029.94 -1226 2127.32 -1282 2224.76 -1337 .26 -1458 .23 -1538 .12 -1617 .04 -1697 .87 -1777 .95 .29 .96 .82 .85 2322.29 -1393 2420.01 -1450 2517.95 -1507 2616.16 -1564 2714.68 -1621 .94 -1857 .60 -1937 .52 -2017 .39 -2097 .31 -2178 .78 .50 .30 .48 .02 2813.46 -1679 2912.08 -1738 3010.30 -1796 3108.48 -1854 3206.80 -1912 .33 -2258 .42 -2337 .99 -2415 .93 -2495 .48 -2574 .02 .00 .87 .18 .98 3305.10 -1971 3403.27 -2030 3501.25 -2090 3598.73 -2148 3695.98 -2207 .10 -2653 .93 -2731 .31 -2809 .84 -2887 .04 -2965 .91 .75 .69 .64 .58 3793.44 -2265 3891.12 -2323 3988.97 -2383 4086.72 -2444 4184.33 -2505 .16 -3043 .68 -3122 .32 -3199 .04 -3276 .61 -3352 .85 .07 .65 .26 .03 1355.66 1449.54 1545.35 1642.17 1739.01 1835.79 1932.82 2030.07 2127.50 2225.00 2322.59 2420.36 2518.35 2616.62 2715.22 232.46 3.30 GYRO 232.43 3.85 GYRO 232.45 3.28 GYRO 232.49 1.12 GYRO 232.54 1.15 GYRO 232.63 1.18 GYRO 232.74 0.64 GYRO 232.84 0.61 GYRO 232.94 0.32 GYRO 233.04 0.16 GYRO 233.12 0.34 GYRO 233.18 0.82 GYRO 233.23 0.55 GYRO 233.28 1.16 GYRO 233.34 0.99 GYRO 2814.04 233.36 1.57 GYRO 2912.67 233.36 1.95 GYRO 3010.91 233.36 0.88 GYRO 3109.13 233.37 0.59 GYRO 3207.50 233.40 0.67 GYRO 3305.82 233.40 2.16 GYRO 3403.99 233.37 0.11 GYRO 3501.96 233.35 1.14 GYRO 3599.44 233.35 1.67 GYRO 3696.71 233.34 0.53 GYRO 3794.20 233.34 0.70 GYRO 3891.89 233.34 0.92 GYRO 3989.73 233.32 0.79 GYRO 4087.44 233.28 1.36 GYRO 4185.00 233.22 0.49 GYRO [(c) 1998 Anadrill IDEAL ID5 OB 68R] -- -- ANADRILL SCHLUMBERGER Survey Report 18-Feb-98 06:28:02 Page 4 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 6000.00 76.86 230.6 62 6100.00 77.32 230.9 63 6200.00 77.18 231.1 64 6300.00 77.30 230.8 65 6400.00 76.93 231.7 66 6500.00 77.38 231.8 67 6600.00 77.34 232.0 68 6700.00 77.16 232.0 69 6800.00 77.26 231.8 70 6900.00 77.86 231.7 71 7000.00 78.83 231.4 72 7100.00 79.29 231.0 73 7200.00 79.06 231.2 74 7300.00 78.11 231.8 75 7400.00 77.43 231.7 76 7500.00 76.85 232.0 77 7600.00 76.57 231.9 78 7700.00 77.36 232.7 79 7800.00 78.33 233.2 80 7900.00 78.70 233.3 81 8000.00 79.15 233.6 82 8100.00 78.38 233.9 83 8200.00 78.16 234.6 84 8300.00 77.41 234.5 85 8400.00 76.78 234.0 86 8500.00 76.44 233.6 87 8600.00 75.68 234.0 88 8700.00 75.09 235.5 89 8800.00 74.14 235.9 90 8900.00 74.45 235.0 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) I00f) type type 3088.28 3110.62 3132.69 3154.78 3177.08 3199.31 3221.19 3243.26 3265.40 3286.94 3307.14 3326.12 3344.90 3364.69 3385.88 3408.13 3431.12 3453.68 3474.73 3494.64 3513.85 3533.34 3553.67 3574.83 3597.16 3620.32 3644.41 3669.64 3696.17 3723.24 4281 4379 4476 4574 46'71 .83 -2567.46 -3427.45 .27 -2629.13 -3502.94 .78 -2690.57 -3578.68 .29 -2752.08 -3654.37 .76 -2813.10 -3730.39 4769 4866 4964 5061 5159 .25 -2873.46 -3806.96 .83 -2933.67 -3883.74 .36 -2993.72 -3960.60 .88 -3053.89 -4037.34 .53 -3114.34 -4114.03 5257 5355 5453 5551 5649 .46 -3175.25 -4190.73 .62 -3236.77 -4267.25 .83 -3298.45 -4343.69 .84 -3359.47 -4420.40 .57 -3419.97 -4497.15 5747 5844 5941 6039 6137 .05 -3480.19 -4573.81 .38 -3540.18 -4650.45 .80 -3599.75 -4727.53 .55 -3658.65 -4805.55 .53 -3717.35 -4884.02 6235 6333 6431 6529 6626 .64 -3775.86 -4962.81 .69 -3833.86 -5041.91 .54 -3891.07 -5121.37 .19 -3947.75 -5200.99 .60 -4004.70 -5280.10 6723 6820 6917 7013 7109 .85 -4062.16 -5358.60 .86 -4119.48 -5436.92 .53 -4175.32 -5515.93 .76 -4229.66 -5595.58 .87 -4284.25 -5674.87 4282.44 4379.83 4477.29 4574.75 4672.19 4769.66 4867.22 4964.75 5062.25 5159.88 5257.79 5355.94 5454.11 5552.11 5649.82 5747.30 5844.62 5942.04 6039.79 6137.79 6235.92 6333.98 6431.86 6529.55 6626.99 6724.26 6821.30 6918.01 7014.31 7110.48 233.16 233.11 233.06 233.02 232.98 232.95 232.93 232.92 232.90 232.87 232.85 232.82 232.79 232.77 232.75 232.73 232.72 232.71 232.72 232.72 232.73 232.75 232.77 232.80 232.82 232.84 232.85 232.88 232.91 232.95 0.81 0.55 0.17 0.23 0.95 0.46 0.20 0.18 0.22 0.61 1.01 0.60 0.30 1.12 0.69 0.65 0.30 1.11 1.09 0.37 0.60 0.82 0.72 0.76 0.80 0.52 0.85 1.57 1.03 0.92 GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO [(c)1998 Anadrill IDEAL ID5 OB 68R] _ -- ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 9000.00 76.40 234.5 100.00 92 9100.00 77.45 233.7 100.00 93 9200.00 78.60 233.1 100.00 94 9300.00 77.80 232.6 100.00 95 9400.00 77.00 232.4 100.00 96 9500.00 77.29 232.3 97 9600.00 78.60 231.6 98 9700.00 78.35 231.2 99 9800.00 79.48 229.6 100 9900.00 78.95 229.0 100.00 100.00 100.00 100.00 100.00 101 9968.31 78.01 229.1 102 10060.49 77.24 229.5 103 10154.82 77.48 229.4 104 10249.64 77.36 229.2 105 10343.81 76.54 228.0 68.30 92.20 94.30 94.80 94.20 106 10434.38 76.16 228.2 107 10526.19 76.68 228.3 108 10621.02 77.45 228.8 109 10716.13 78.12 228.7 110 10808.88 78.65 229.6 90.60 91.80 94.80 95.10 92.80 111 10903.93 78.36 229.0 112 10997.16 78.64 228.2 113 11090.06 77.91 228.6 114 11182.95 77.60 229.2 115 11277.22 77.65 229.2 95.00 93.30 92.90 92.90 94.20 116 11370.65 77.39 229.6 117 11464.10 77.75 232.9 118 11557.89 77.78 233.5 119 11653.60 77.53 233.1 120 11747.86 77.56 231.8 93.50 93.40 93.80 95.70 94.30 TVD depth (ft) 3748.40 3771.03 3791.77 3812.22 3834.04 3856.29 3877.17 3897.15 3916.38 3935.09 3948.73 3968.49 3989.12 4009.77 4031.04 4052.42 4073.98 4095.20 4115.32 4134.00 4152.94 4171.54 4190.42 4210.12 4230.31 4250.51 4270.62 4290.50 4310.96 4331.30 18-Feb-98 06:28:02 Vertical Displ section +N/S- (ft) (ft) Page 5 of 8 7206.55 -4340.11 7303.91 -4397.22 7401.71 -4455.55 7499.59 -4514.66 7597.18 -4574.07 Displ Total At DLS Srvy Tool +E/W- disp1 Azim (deg/ tool qual (ft) (ft) (deg) i00f) type type 7694.67 -4633. 7792.46 -4693. 7890.43 -4755. 7988.51 -4817. 8086.62 -4881. -5753.90 -5832.80 -5911.33 -5989.35 -6066.78 8153.44 -4925. 8243.38 -4984. 8335.29 -5044. 8427.70 -5104. 8519.28 -5165. 62 -6143.97 90 -6220.98 09 -6297.50 71 -6373.05 77 -6447.53 8607.10 -5223. 8696.12 -5283. 8788.32 -5344. 8881.10 -5405. 8971.87 -5465. 63 -6498.07 36 -6566.35 18 -6636.27 51 -6706.41 20 -6775.25 9064.85 -5526. 9156.09 -5586. 9246.85 -5646. 9337.49 -5706. 9429.37 -5766. 99 -6840.78 41 -6907.35 57 -6976.60 85 -7046.48 31 -7115.24 9520.55 -5826. 9611.74 -5883. 9703.39 -5938. 9796.86 -5993. 9888.94 -6050. 02 -7185.82 48 -7254.40 87 -7322.42 55 -7390.83 67 -7460.48 08 -7529.80 16 -7600.92 07 -7674.32 94 -7749.28 06 -7822.28 7207.21 7304.60 7402.42 7500.30 7597.89 232.97 2.01 GYRO 232.99 1.31 GYRO 232.99 1.29 GYRO 232.99 0.94 GYRO 232.99 0.82 GYRO 7695.38 232.98 0.31 GYRO 7793.15 232.96 1.48 GYRO 7891.10 232.94 0.55 GYRO 7989.13 232.91 1.86 GYRO 8087.17 232.87 0.79 GYRO 8153.94 232.84 1.38 8243.83 232.80 0.94 8335.69 232.76 0.27 8428.05 232.72 0.24 8519.58 232.68 1.52 8607.34 232.63 0.47 8696.32 232.59 0.58 8788.48 232.55 0.96 8881.23 232.51 0.71 8971.97 232.47 1.11 9064.92 9156.15 9246.89 9337.51 9429.39 MWD MWD MWD MWD MWD 9520.56 9611.74 9703.40 9796.87 9888.95 MWD MWD MWD MWD MWD 232.44 0.69 MWD 232.40 0.89 MWD 232.36 0.89 MWD 232.33 0.71 MWD 232.30 0.05 MWD 232.27 0.50 MWD 232.26 3.47 MWD 232.27 0.63 MWD 232.28 0.48 MWD 232.28 1.35 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1998 Anadrill IDEAL ID5 OB 68R] ANADRILL SCHLUMBERGER Survey Report 18-Feb-98 06:28:02 Page 6 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 11842.34 77.98 232.6 122 11935.25 78.03 232.8 123 12029.34 77.77 232.6 124 12123.85 77.75 231.4 125 12216.42 78.11 231.7 126 12312.36 78.90 232.8 127 12407.13 79.52 233.2 128 12500.71 80.36 233.5 129 12595.24 80.62 234.5 130 12688.17 80.62 232.7 131 12780.87 80.36 232.0 132 12873.55 80.07 232.0 133 12967.02 79.77 231.1 134 13059.88 80.03 231.0 135 13154.72 79.76 231.7 136 13248.63 79.40 230.6 137 13342.82 79.72 232.7 138 13437.21 80.02 231.5 139 13530.68 79.84 231.5 140 13626.96 79.66 231.0 141 13721.05 79.35 230.9 142 13814.97 79.08 231.4 143 13909.33 78.53 230.9 144 14005.40 78.15 229.7 145 14099.98 77.68 231.2 146 14194.00 77.65 230.7 147 14288.22 76.87 230.7 148 14383.88 77.13 231.7 149 14478.35 77.68 232.6 150 14571.19 77.21 230.4 94.40 92.90 94.10 94.60 92.50 96.00 94.70 93.60 94.50 93.00 92.70 92.70 93.40 92.90 94.80 93.90 94.20 94.40 93.50 96.30 94.10 93.90 94.30 96.10 94.60 94.00 94.20 95.70 94.50 92.80 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 4351.30 4370.60 4390.33 4410.39 4429.73 4448.86 4466.59 4482.94 4498.55 4513.71 4529.03 4544.78 4561.13 4577.42 4594.05 4611.04 4628.11 4644.71 4661.06 4678.20 4695.34 4712.91 4731.22 4750.64 4770.45 4790.53 4811.30 4832.83 4853.44 4873.61 9981.20 -6106.61 10072.06 -6161.67 10164.07 -6217.43 10256.52 -6274.35 10346.97 -6330.59 -7895.18 9981.21 -7967.46 10072.08 -8040.66 10164.08 -8113.51 10256.53 -8184.35 10346.98 10441.04 -6388.19 10534.05 -6444.17 10626.20 -6499.18 10719.35 -6553.96 10811.08 -6608.41 -8258.73 10441.05 -8333.02 10534.07 -8406.96 10626.21 -8482.36 10719.37 -8556.21 10811.10 10902.50 -6664.26 10993.85 -6720.50 11085.80 -6777.68 11177.25 -6835.17 11270.56 -6893.46 -8628.60 10902.52 -8700.58 10993.87 -8772.60 11085.82 -8843.73 11177.26 -8916.62 11270.58 11362.90 -6951.39 11455.53 -7008.87 11548.45 -7065.95 11640.51 -7123.26 11735.26 -7182.58 -8988.54 11362.91 -9061.19 11455.54 -9134.51 11548.46 -9206.56 11640.52 -9280.46 11735.26 11827.76 -7240.87 11919.99 -7298.73 12012.48 -7356.75 12106.54 -7416.87 12199.00 -7475.77 -9352.32 11827.76 -9424.16 11919.99 -9496.20 12012.48 -9568.61 12106.54 -9639.93 12199.00 12290.80 -7533.62 12382.65 -7591.82 12475.88 -7650.25 12568.11 -7706.84 12658.68 -7763.22 -9711.25 12290.80 -9782.35 12382.65 -9855.02 12475.89 -9927.84 12568.11 -9998.73 12658.68 Srvy tool type 232.28 0.94 MWD 232.28 0.22 MWD 232.29 0.35 MWD 232.28 1.24 MWD 232.28 0.50 MWD 232.28 1.39 MWD 232.28 0.78 MWD 232.29 0.95 MWD 232.31 1.08 MWD 232.32 1.91 MWD 232.32 0.80 MWD 232.32 0.31 MWD 232.31 1.00 MWD 232.30 0.30 MWD 232.29 0.78 MWD 232 28 232.28 232.28 232 27 232.26 232 25 232.24 232.23 232 22 232.21 1.21 2.22 1.29 0.19 0.54 0.35 0.60 0.78 1.29 1.63 0.52 0.83 1.05 1.10 2.37 232 20 232.19 232.18 232 18 232.17 MWD MWD MWD MWD MWD MWD MWD M-WD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c)1998 Anadrill IDEAL ID5 OB 68R] ANADRILL SCHLUMBERGER Survey Report 18-Feb-98 06:28:02 Page 7 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 151 14665.18 77.42 230.9 152 14759.47 76.98 231.7 153 14853.15 77.18 231.3 154 14948.03 77.42 231.1 155 15021.87 77.40 231.2 156 15116.07 77.08 232.9 157 15209.38 76.96 230.6 158 15304.29 76.65 229.7 159 15397.81 76.84 231.7 160 15491.84 77.69 232.6 161 15584.66 77.69 231.8 162 15679.80 77.54 231.9 163 15774.67 77.30 230.7 164 15868.66 76.92 230.8 165 15962.64 76.57 231.1 166 16055.94 76.33 230.0 167 16150.15 76.03 229.5 168 16241.89 76.19 230.1 169 16333.47 76.58 231.4 17'0 16427.82 76.72 232.2 171 16522.78 76.50 229.8 172 16617.28 76.51 229.6 173 16711.95 76.81 232.0 174 16805.31 76.81 232.2 175 16900.48 76.67 232.3 176 16994.46 76.49 231.3 177 17089.05 76.38 230.3 178 17184.82 75.92 230.6 179 17279.38 74.32 231.5 180 17373.89 73.04 231.9 94.00 94.30 93.70 94.80 73.90 94.20 93.30 94.90 93.50 94.00 92.90 95.10 94.90 94.00 93.90 93.30 94.30 91.70 91.60 94.30 95.00 94.50 94.70 93.30 95.20 94.00 94.60 95.70 94.60 94.50 TVD depth (ft) 4894.25 4915.15 4936.10 4956.94 4973.05 4993.85 5014.81 5036.47 5057.91 5078.64 5098.44 5118.84 5139.51 5160.48 5182.01 5203.87 5226.40 5248.41 5269.97 5291.75 5313.75 5335.80 5357.66 5378.95 5400.78 5422.60 5444.79 5467.70 5491.99 5518.54 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) I00f) type type 12750.35 -7821 12842.29 -7878 12933.61 -7935 13026.08 -7993 13098.19 -8038 13190.06 -8095 13280.97 -8151 13373.30 -8210 13464.27 -8268 13555.96 -8324 13646.72 -8380 13739.61 -8437 13832.22 -8495 13923.82 -8553 14015.20 -8611 14105.86 -8668 14197.34 -8728 14286.29 -8785 14375.28 -8841 14467.03 -8898 14559.42 -8956 14651.22 -9016 14743.33 -9074 14834.17 -9130 14926.83 -9186 15018.26 -9243 15110.19 -9301 15203.07 -9360 15294.47 -9418 15385.16 -9474 .36 -10069.64 12750.35 .86 -10141.41 12842.30 .71 -10212.88 12933.62 .66 -10284.96 13026.09 .90 -10341.13 13098.20 232.16 0.56 MWD 232.16 0.95 MWD 232.15 0.47 MWD 232.15 0.33 MWD 232.14 0.13 MWD .40 -10413.57 13190.07 .68 -10484.96 13280.98 .88 -10555.89 13373.31 .52 -10626.32 13464.29 .78 -10698.71 13555.98 232.14 1.79 MWD 232.14 2.41 MWD 232.12 0.98 MWD 232.11 2.09 MWD 232.11 1.30 MWD .41 -10770.43 13646.74 .79 -10843.48 13739.63 .70 -10915.76 13832.24 .67 -10986.72 13923.84 .25 -11057.70 14015.22 232.11 0.84 MWD 232.11 0.19 MWD 232.11 1.26 MWD 232.10 0.42 MWD 232.09 0.49 MWD .89 -11127.74 14105.89 .05 -11197.63 14197.38 .51 -11265.62 14286.33 .83 -11334.56 14375.33 .57 -11406.66 14467.08 232.08 1.17 MWD 232.07 0.61 MWD 232.05 0.66 MWD 232.04 1.44 MWD 232.04 0.84 MWD .73 -11478.48 14559.48 .16 -11548.56 14651.29 .40 -11619.96 14743.41 .20 -11691.64 14834.25 .92 -11764.91 14926.91 232.03 2.47 MWD 232.02 0.21 MWD 232.01 2.49 MWD 232.01 0.21 MWD 232.01 0.18 MWD .47 -11836.76 15018.34 .59 -11908.02 15110.28 .75 -11979.67 15203.16 .23 -12050.77 15294.57 .44 -12121.94 15385.26 232.01 1.05 MWD 232.01 1.03 MWD 232.00 0.57 MWD 231.99 1.93 MWD 231.99 1.41 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1998 Anadrill IDEAL ID5 OB 68R] _ -- 3LNADRILL SCHLUMBERGER Survey Report 18-Feb-98 06:28:02 Page 8 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) At DLS Srvy Tool Azim (deg/ tool qual (deg) i00f) type type 181 17469.75 72.21 182 17562.55 71.17 183 17659.16 69.61 184 17752.47 67.49 185 17847.89 65.08 233.5 95.90 5547.18 15476.68 -9529.90 -12194.74 15476.78 231.99 1.81 235.3 92.80 5576.34 15564.71 -9581.19 -12266.37 15564.79 232.01 2.16 234.6 96.60 5608.76 15655.59 -9633.44 -12340.86 15655.67 232.02 1.75 236.6 93.30 5642.88 15742.27 -9682.50 -12412.50 15742.33 232.04 3.02 235.4 95.40 5681.24 15829.41 -9731.33 -12484.90 15829.46 232.07 2.78 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 186 17941.04 63.92 187 18035.15 62.72 188 18129.75 60.32 189 18224.07 58.38 190 18317.56 55.95 234.7 93.10 5721.32 15913.34 -9779.47 -12553.78 15913.37 232.08 1.42 235.6 94.20 5763.62 15997.39 -9827.57 -12622.85 15997.42 232.10 1.53 236.1 94.50 5808.68 16080.28 -9874.20 -12691.58 16080.30 232.12 2.58 236.1 94.40 5856.80 16161.30 -9919.49 -12758.99 16161.31 232.14 2.06 234.4 93.50 5907.50 16239.74 -9964.25 -12823.54 16239.75 232.15 3.01 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 191 18413.34 53.62 192 18506.64 51.33 193 18601.13 48.94 194 18694.50 45.81 195 18789.45 42.36 234.2 95.70 5962.68 16317.87 -10009.87 -12887.03 16317.88 232.16 2.44 MWD 6-axis 232.7 93.30 6019.51 16391.84 -10053.92 -12946.47 16391.84 232.17 2.77 MWD 6-axis 231.7 94.50 6080.08 16464.37 -10098.36 -13003.79 16464.37 232.17 2.66 MWD 6-axis 230.4 93.40 6143.32 16533.06 -10141.54 -13057.24 16533.07 232.16 3.50 MWD 6-axis 229.0 94.90 6211.48 16599.02 -10184.22 -13107.60 16599.02 232.15 3.78 MWD 6-axis 196 18884.64 38.52 197 18977.55 35.32 198 19035.26 35.09 199 19154.62 35.40 200 19226.56 37.51 226.6 95.20 6283.93 16660.57 -10225.65 -13153.36 16660.58 232.14 4.35 MWD 6-axis 224.0 93.00 6358.27 16716.02 -10264.90 -13193.09 16716.04 232.12 3.83 MWD 6-axis 223.8 57.70 6405.42 16748.93 -10288.87 -13216.16 16748.96 232.10 0.45 MWD 6-axis 226.7 119.30 6502.86 16817.25 -10337.32 -13265.04 16817.30 232.07 1.43 MWD 6-Axis 223.9 72.00 6560.77 16859.71 -10367.42 -13295.42 16859.77 232.05 3.73 MWD 6-axis 201 19323.76 35.98 202 19418.04 33.03 203 19512.94 30.82 204 19607.25 29.38 205 ~19701.53 27.10 Survey Projected to TD: 206 19770.00 27.10 223.1 97.20 6638.66 16917.19 -10409.59 -13335.46 16917.27 232.02 1.65 MWD 6-axis 225.9 94.20 6716.28 16970.05 -10447.67 -13372.81 16970.15 232.00 3.55 MWD 6-axis 229.0 94.90 6796.83 17020.04 -10481.63 -13409.74 17020.16 231.99 2.90 MWD 6-axis 227.9 94.30 6878.41 17067.23 -10512.99 -13445.14 17067.36 231.98 1.64 MWD 6-axis 230.6 94.30 6961.48 17111.77 -10542.13 -13478.90'17111.91 231.97 2.77 MWD 6-axis 230.6 68.50 7022.46 17142.96 -10561.94 -13503.02 17143.11 231.97 0.00 MWD M - [(c)1998 Anadrill IDEAL ID5 OB 68R] -- -- Directional Survey Calculator Report Well: MPL-20 Access Date and Time: Thu Jan 8 18:04:49 1998 Facility: M Pt L Pad Operator: BP Exploration Ail Depths relative to BRT . Listing contains: 202 points. Vertical Section Details: Origin North Origin East Section Azimuth (ft) (ft) (deg) 0.00 0.00 232.25 Max Depth(TVD) (ft) Applied to TD Tie In Details: MD Inc Azi North (ft) (deg) (deg) (ft) 32.50 0.000 0.000 0.00 Survey Instrument Depth Range Summary: Instrument MWD - Standard (declination corrected) East TVD (ft) (ft) 0.00 32.50 Start(ft) End(ft) 206.51 19788.00 Corrected Survey Data Stn Measured No Depth Inc (ft) (deg) 1 206.51 0.340 2 293.64 0.260 3 382.88 1.090 4 472.79 1.960 5 563.38 2.980 Drl Grid Azi (deg) 40.950 291.380 240.630 256.200 258.550 Computed Positional Information Local 3-D Co-ordinates North East TVD (ft) (ft) (ft) 0.39 0.34 206.51 0.66 0.32 293.64 0.31 -0.60 382.87 -0.47 -2.84 472.75 -1.31 -6.66 563.25 Travelling Cylinder Co-ords Vertical DLS Section (deg/100ft) (ft) 0.195 -0.51 0.565 -0.66 1.061 0.29 1.063 2.54 1.131 6.06 Relative Radial Relative Depth Dist Azimuth (ft) (ft) (deg) 206.51 0.516 40.950 293.64 0.733 26.222 382.86 0.872 7.001 472.74 2.106 11.745 563.18 5.164 16.182 6 653.16 5.000 7 742.16 7.830 8 831.36 9.580 9 922.27 13.950 10 1018.60 16.790 243 237 230 228 228 .810 .910 .200 .690 .280 -3.50 -12.45 652.81 -8.43 -21.07 741.25 -16.41 -31.92 829.42 -28.49 -45.97 918.40 -45.42 -65.08 1011.27 2.505 11.99 652.69 8.711 18.349 3.261 21.82 741.31 11.516 19.475 2.354 35.29 830.06 13.640 23.464 4.818 53.80 920.45 14.123 28.814 2.950 79.27 1016.24 12.533 33.963 11 1111.01 18.440 12 1203.30 20.150 13 1299.40 22.980 14 1392.90 27.580 15 1487.17 31.940 230 232 233 233 234 .460 .490 .420 .570 .030 -63.61 -86.32 1099.35 -82.58 -110.19 1186.45 -103.85 -138.39 1275.82 -127.59 -170.48 1360.34 -155.21 -208.23 1442.16 1.923 107.19 1108.18 11.325 39.227 1.990 137.68 1200.03 11.342 41.256 2.966 173.00 1295.65 11.655 39.279 4.920 212.91 1388.69 9.995 31.824 4.631 259.67 1482.50 6.121 1.110 16 1578.93 31.990 17 1675.59 33.230 18 1769.90 35.250 19 1863.63 37.160 234.720 234.050 233.680 232.860 -183.50 -247.72 1520.01 -213.84 -290.06 1601.43 -245.13 -332.91 1679.39 -278.25 -377.28 1755.02 0.402 308.21 1574.05 1.336 360.27 1670.78 2.153 413.31 1765.26 2.102 468.66 1859.21 6.705 310.674 9.368 297.457 11.273 294.719 12.438 294.165 Stn No 2O Corrected Survey Data Measured Drl Grid Depth Inc Azi (ft) (deg) (deg) 1957.12 39.070 232.900 Computed Positional Information Travelling Cylinder Co-ords Local 3-D Co-ordinates Vertical Relative Radial Relative North East TVD DLS Section Depth Dist Azimuth (ft) (ft) (ft) (dew/100ft) (ft) (ft) (ft) (dew) -313.07 -423.29 1828.57 2.043 526.36 1952.73 13.655 290.481 21 22 23 24 25 2052.17 40.020 233.700 2145.57 43.610 233.400 2239.66 46.260 232.950 2332.14 49.770 231.940 2425.70 52.240 231.700 -349.23 -471.81 1901.86 1.134 586.86 2048.16 -386.23 -521.89 1971.46 3.850 649.11 2141.96 -426.06 -575.08 2038.06 2.837 715.55 2236.48 -467.97 -629.55 2099.92 3.881 784.28 2329.42 -512.91 -686.71 2158.79 2.648 856.99 2423.50 15.193 289.118 16.474 291.312 17.728 291.263 18.491 288.732 18.864 284.268 26 27 28 29 30 2515.75 53.600 232.260 2609.93 55.970 232.710 2704.46 58.810 232.560 2798.79 62.060 231.970 2893.83 64.340 231.630 -557.16 -743.30 2213.08 1.590 928.83 2514.11 -604.01 -804.33 2267.38 2.547 1005.76 2608.82 -652.33 -867.61 2318.32 3.007 1085.38 2703.78 -702.54 -932.49 2364.86 3.488 1167.42 2798.46 -755.00 -999.15 2407.71 2.420 1252.24 2893.78 18.602 283.630 17.968 288.014 17.440 294.185 16.773 298.947 15.534 303.815 31 32 33 34 35 2987.14 67.010 231.010 3082.02 70.520 231.900 3177.84 73.880 232.740 3273.38 76.430 232.370 3367.77 76.100 232.910 -808.14 -1065.51 2446.14 2.925 1337.25 2987.24 -863.23 -1134.68 2480.50 3.801 1425.66 3082.17 -918.99 -1206.87 2509.79 3.605 1516.88 3177.99 -975.13 -1280.19 2534.27 2.695 1609.22 3273.50 -1030.77 -1353.07 2556.68 0.657 1700.91 3367.84 13.611 311.081 12.160 318.663 12.256 323.049 12.781 326.548 13.820 336.901 36 37 38 39 4O 3461.98 76.660 234.130 3557.09 76.220 233.970 3652.71 77.830 234.490 3745.02 77.630 234.500 3840.95 77.740 234.490 -1085.21 -1426.69 2578.86 1.392 1792.45 3461.99 -1139.49 -1501.53 2601.16 0.491 1884.86 3557.02 -1193.95 -1577.13 2622.63 1.765 1977.98 3652.57 -1246.34 -1650.56 2642.25 0.217 2068.11 3744.81 -1300.77 -1726.86 2662.71 0.115 2161.76 3840.67 16.556 343.768 20.218 347.356 23.791 347.432 27.168 344.945 30.745 343.074 41 42 43 44 45 3935.59 77.600 234.540 4028.45 78.060 232.490 4124.42 78.590 234.130 4219.33 79.050 233.860 4314.43 79.900 234.200 -1354.44 -1802.14 2682.92 0.157 2254.15 3935.24 -1408.41 -1875.12 2702.50 2.214 2344.89 4028.07 -1464.56 -1950.48 2721.92 1.762 2438.86 4124.02 -1519.30 -2025.81 2740.32 0.559 2531.92 4218.87 -1574.21 -2101.48 2757.69 0.960 2625.38 4313.90 34.338 341.635 36.295 340.871 37.760 339.117 40.117 335.969 42.456 331.715 46 47 48 49 50 4405.12 80.850 234.140 4500.66 81.600 232.840 4596.63 80.050 232.630 4690.35 79.600 233.390 4783.06 79.220 232.540 -1626.56 -2173.97 2772.86 1.050 2714.74 4404.45 -1682.73 -2249.86 2787.43 1.557 2809.14 4499.81 -1740.10 -2325.25 2802.73 1.629 2903.87 4595.66 -1795.60 -2398.93 2819.29 0.931 2996.11 4689.32 -1850.49 -2471.68 2836.33 0.990 3087.23 4781.99 44.985 326.260 46.975 319.422 48.253 313.740 50.000 310.461 51.641 308.145 51 52 53 54 4878.21 79.980 234.030 4972.56 79.020 232.700 5063.93 79.060 232.220 5156.26 78.520 232.360 -1906.43 -2546.70 2853.50 1.735 3180.80 4877.08 -1961.79 -2621.14 2870.70 1.719 3273.55 4971.37 -2016.44 -2692.27 2888.07 0.518 3363.25 5062.73 -2071.84 -2763.92 2906.02 0.603 3453.82 5155.05 53.999 305.756 56.492 303.789 57.379 302.238 57.920 300.992 Stn No 55 Corrected Survey Data Measured Drl Grid Depth Inc Azi (ft) (deg) (deg) 5249.62 77.130 232.890 Computed Positional Information Travelling Cylinder Co-ords Local 3-D Co-ordinates Vertical Relative Radial Relative North East TVD DLS Section Depth Dist Azimuth (ft) (ft) (ft) (deg/100ft) (ft) (ft) (ft) (deg) -2127.24 -2836.44 2925.71 1.589 3545.08 5248.40 58.407 301.382 56 57 58 59 60 5341.22 76.710 232.970 5433.86 77.480 232.760 5529.18 77.980 233.350 5623.36 78.010 232.510 5717.69 78.320 232.660 -2181.02 -2907.63 2946.44 0.466 3634.29 5339.98 58.845 303.240 -2235.53 -2979.62 2967.13 0.860 3724.59 5432.60 59.337 304.799 -2291.52 -3054.06 2987.39 0.801 3817.72 5527.91 60.484 305.495 -2347.05 -3127.56 3006.98 0.873 3909.83 5622.09 61.556 305.715 -2403.14 -3200.89 3026.32 0.364 4002.15 5716.42 62.179 305.535 61 62 63 64 65 5811.91 77.630 230.970 5906.86 77.750 230.640 6002.54 77.210 230.640 6097.46 77.690 230.600 6191.91 77.570 230.480 -2460.11 -3273.32 3045.95 1.901 4094.30 5810.63 61.526 305.305 -2518.73 -3345.22 3066.20 0.362 4187.04 5905.55 59.165 305.041 -2577.97 -3417.43 3086.94 0.564 4280.41 6001.19 56.428 305.011 -2636.75 -3489.05 3107.56 0.507 4373.02 6096.07 53.667 305.020 -2695.38 -3560.28 3127.80 0.178 4465.24 6190.48 50.884 304.668 66 67 68 69 70 6287.58 77.590 229.050 6382.21 77.100 231.270 6477.33 77.270 231.590 6570.39 77.220 231.510 6664.45 77.110 231.620 -2755.73 -3631.60 3148.37 1.460 4558.58 6286.06 46.838 303.903 -2814.88 -3702.49 3169.11 2.347 4650.84 6380.62 43.326 303.763 -2872.71 -3775.01 3190.21 0.374 4743.58 6475.72 41.675 304.830 -2929.15 -3846.09 3210.75 0.100 4834.34 6568.76 40.285 305.900 -2986.16 -3917.93 3231.65 0.163 4926.04 6662.81 38.884 307.256 71 72 73 74 75 6758.67 76.980 231.860 6854.41 77.920 231.580 6948.99 78.560 231.350 7043.20 79.090 231.240 7136.30 79.430 231.130 -3043.02 -3990.03 3252.77 0.284 5017.86 6757.01 37.733 309.104 -3100.91 -4063.38 3273.57 1.022 5111.31 6852.75 36.709 310.053 -3158.60 -4135.81 3292.85 0.717 5203.89 6947.32 35.581 308.855 -3216.39 -4207.94 3311.11 0.574 5296.30 7041.50 34.463 305.922 -3273.72 -4279.21 3328.46 0.383 5387.75 7134.56 33.528 301.600 76 77 78 79 80 7229.17 78.380 231.840 7324.64 77.660 232.200 7419.67 77.330 231.590 7514.55 76.810 232.100 7608.02 76.280 231.420 -3330.47 -4350.51 3346.33 1.357 5478.88 7227.41 32.993 298.324 -3387.94 -4424.13 3366.15 0.840 5572.27 7322.88 32.703 297.855 -3445.20 -4497.13 3386.72 0.716 5665.04 7417.90 31.876 298.649 -3502.33 -4569.84 3407.95 0.758 5757.51 7512.77 30.717 300.636 -3558.59 -4641.24 3429.70 0.907 5848.41 7606.21 29.212 304.240 81 82 83 84 85 7702.29 77.130 232.610 7795.68 78.160 233.170 7890.38 78.470 233.120 7983.75 78.620 233.360 8077.20 78.620 233.310 -3615.05 -4713.55 3451.38 1.524 5940.15 7700.45 28.285 307.937 -3670.09 -4786.30 3471.36 1.249 6031.37 7793.83 29.163 309.363 -3725.71 -4860.51 3490.54 0.331 6124.10 7888.52 30.714 308.854 -3780.48 -4933.82 3509.09 0.299 6215.60 7981.87 32.484 307.825 -3835.19 -5007.31 3527.53 0.052 6307.19 8075.30 34.445 306.773 86 87 88 89 8359.05 76.950 234.010 8452.32 77.040 233.800 8546.50 75.570 233.140 8641.41 75.490 235.810 -3998.42 -5229.19 3587.16 0.640 6582.57 8357.05 40.843 310.392 -4051.96 -5302.62 3608.15 0.240 6673.41 8450.27 43.143 313.128 -4106.42 -5376.15 3630.44 1.703 6764.88 8544.39 44.741 316.938 -4159.81 -5450.93 3654.16 2.725 6856.70 8639.14 48.117 322.101 Stn No 9O Corrected Survey Data Measured Drl Grid Depth Inc Azi (ft) (deg) (deg) 8736.78 74.510 237.310 Computed Positional Information Travelling Cylinder Co-ords Local 3-D Co-ordinates Vertical Relative Radial Relative North East TVD DLS Section Depth Dist Azimuth (ft) (ft) (ft) (deg/100ft) (ft) (ft) (ft) (deg) -4210.58 -5527.80 3678.85 1.834 6948.56 8734.13 55.249 327.265 91 8821.81 73.920 236.940 92 8923.62 75.440 234.100 93 9019.38 76.600 234.620 94 9113.26 77.590 233.100 95 9206.97 78.640 232.330 -4254.99 -5596.52 3701.98 0.810 7030.09 8818.69 62.862 331.792 -4310.58 -5677.44 3728.88 3.077 7128.11 8920.16 69.513 335.775 -4364.72 -5752.96 3752.02 1.321 7220.96 9015.80 73.634 337.595 -4418.69 -5826.86 3772.98 1.898 7312.43 9109.64 76.486 338.097 -4474.24 -5899.81 3792.28 1.379 7404.13 9203.34 77.126 337.746 96 9303.34 77.780 233.290 97 9396.98 76.920 232.400 98 9493.51 76.720 232.730 99 9588.00 77.800 232.620 100 9682.40 78.070 233.100 -4531.26 -5974.96 3811.98 1.322 7498.46 9299.70 77.899 337.249 -4586.45 -6047.78 3832.48 1.305 7589.82 9393.33 79.072 337.751 -4643.58 -6122.41 3854.49 0.392 7683.81 9489.84 80.094 338.957 -4699.46 -6195.70 3875.33 1.149 7775.97 9584.32 81.080 339.582 -4755.19 -6269.29 3895.06 0.574 7868.27 9678.71 82.024 339.387 101 9778.26 78.620 230.150 102 9873.77 78.670 229.560 103 9968.31 78.010 229.060 104 10060.49 77.240 229.500 105 10154.82 77.480 229.440 -4813.47 -6342.88 3914.43 3.068 7962.14 9774.56 80.849 339.152 -4873.84 -6414.46 3933.24 0.608 8055.70 9869.98 76.771 339.179 -4934.21 -6484.67 3952.34 0.869 8148.17 9964.40 72.051 339.800 -4992.95 -6552.91 3972.10 0.957 8238.08 10056.46 67.794 341.422 -5052.76 -6622.86 3992.74 0.262 8330.02 10150.67 63.945 343.569 106 10249.64 77.360 229.240 107 10343.80 76.540 227.950 108 10434.38 76.160 228.160 109 10526.19 76.680 228.340 110 10621.02 77.450 228.790 -5113.06 -6693.07 4013.39 0.242 8422.44 10245.37 59.948 345.996 -5173.72 -6761.87 4034.65 1.594 8513.98 10339.34 55.408 350.017 -5232.56 -6827.34 4056.03 0.476 8601.77 10429.65 51.180 355.929 -5291.98 -6893.92 4077.59 0.598 8690.79 10521.21 47.701 2.576 -5353.15 -6963.21 4098.81 0.934 8783.02 10615.84 44.421 9.016 111 10716.13 78.120 228.680 112 10808.88 78.650 229.620 113 10903.93 78.360 229.040 114 10997.16 78.640 228.190 115 11090.06 77.910 228.620 -5414.45 -7033.08 4118.94 0.713 8875.80 10710.78 40.969 15.121 -5473.88 -7101.80 4137.61 1.145 8966.52 10803.40 37.620 20.461 -5534.58 -7172.45 4156.55 0.671 9059.54 10898.33 34.536 26.369 -5594.98 -7240.99 4175.14 0.943 9150.72 10991.37 31.600 35.166 -5655.36 -7309.02 4194.02 0.907 9241.47 11084.07 29.882 46.131 116 11182.95 77.600 229.220 117 11277.22 77.650 229.190 118 11370.65 77.390 229.620 119 11464.10 77.750 232.950 120 11557.89 77.780 233.480 -5715.01 -7377.44 4213.72 0.714 9332.10 11176.81 30.122 56.224 -5775.17 -7447.15 4233.92 0.061 9424.04 11270.95 31.387 65.095 -5834.53 -7516.42 4254.11 0.529 9515.15 11364.27 33.362 72.423 -5891.60 -7587.61 4274.23 3.501 9606.39 11457.69 34.495 74.457 -5946.49 -7661.02 4294.11 0.553 9698.03 11551.47 34.220 71.876 121 11653.60 77.530 233.120 122 11747.86 77.560 231.790 123 11842.34 77.980 232.580 124 11935.25 78.030 232.750 -6002.36 -7735.99 4314.57 0.451 9791.51 11647.16 34.148 68.891 -6058.45 -7808.96 4334.90 1.378 9883.55 11741.41 34.687 68.057 -6115.06 -7881.91 4354.92 0.930 9975.89 11835.89 34.991 68.092 -6170.18 -7954.17 4374.23 0.187 10066.77 11928.80 34.722 67.090 Corrected Survey Data Computed Positional Information Travelling Cylinder Co-ords Stn Measured Drl Grid Local 3-D Co-ordinates Vertical Relative Radial Relative No Depth Inc Azi North East TVD DLS Section Depth Dist Azimuth (ft) (deg) (deg) (ft) (ft) (ft) (deg/lOOft) (ft) (ft) (ft) (deg) 125 12029.34 77.770 232.580 -6225.97 -8027.32 4393.95 0.328 10158.76 12022.89 34.627 65.992 126 12123.85 77.750 231.390 -6282.85 -8100.08 4413.99 1.231 10251.12 12117.40 35.025 66.550 127 12216.42 78.110 231.730 -6339.13 -8170.99 4433.34 0.529 10341.64 12209.96 35.334 68.252 128 12312.96 78.900 232.750 -6397.06 -8245.78 4452.58 1.320 10436.24 12306.49 34.430 68.708 129 12407.13 79.520 233.240 -6452.74 -8319.65 4470.21 0 834 10528.74 12400.63 32.100 67.699 130 12500.71 80.360 233.460 -6507.74 -8393.57 4486.56 0.927 10620.86 12494.14 28.502 66.010 131 12595.24 80.620 234.490 -6562.57 -8468.97 4502.18 1 109 10714.05 12588.53 23.827 61.846 132 12688.17 80.620 232.700 -6616.98 -8542.76 4517.32 1.900 10805.71 12681.33 19.248 57.673 133 12780.87 80.360 232.010 -6672.82 -8615.16 4532.64 0.786 10897.13 12773.94 15.134 58.512 134 12873.55 80.070 232.020 -6729.03 -8687.14 4548.39 0 313 10988.46 12866.54 11.550 62.343 135 12967.02 79.770 231.060 -6786.27 -8759.20 4564.75 1.061 11080.48 12959.95 8.742 73.458 136 13059.88 80.030 231.030 -6843.75 -8830.29 4581.04 0 282 11171.88 13052.74 7.120 97.820 137 13154.72 79.760 231.700 -6902.04 -8903.23 4597.68 0.752 11265.24 13147.51 6.758 127.176 138 13248.63 79.400 230.630 -6959.96 -8975.17 4614.66 1.184 11357.58 13241.36 8.324 148.593 139 13342.82 79.720 232.670 -7017.43 -9047.81 4631.73 2 157 11450.20 13335.51 9.907 163.383 140 13437.21 80.020 231.500 -7074.53 -9121.12 4648.33 1.261 11543.12 13429.84 11.657 177.597 141 13530.68 79.840 231.490 -7131.82 -9193.13 4664.68 0 193 11635.14 13523.25 14.648 185.208 142 13626.98 79.660 231.030 -7191.12 -9267.05 4681.81 0.506 11729.89 13619.49 17.945 188.737 143 13721.05 79.350 230.920 -7249.37 -9338.91 4698.95 0.349 11822.36 13713.50 21.219 189.464 144 13814.97 79.080 231.400 -7307.23 -9410.77 4716.52 0 579 11914.61 13807.38 23.937 189.765 145 13909.33 78.530 230.900 -7365.29 -9482.86 4734.84 0.781 12007.15 13901.71 26.181 188.991 146 14005.40 78.150 229.670 -7425.41 -9555.23 4754.26 1.315 12101.18 13997.72 28.928 185.222 147 14099.98 77.680 231.220 -7484.30 -9626.53 4774.06 1.678 12193.62 14092.25 31.086 181.481 148 14194.00 77.650 230.740 -7542.13 -9697.89 4794.15 0.500 12285.44 14186.25 32.411 178.572 149 14288.22 76.870 230.730 -7600.29 -9769.04 4814.92 0.828 12377.31 14280.43 33.780 174.582 150 14383.88 77.130 231.690 -7658.68 -9841.69 4836.44 1.015 12470.50 14376.06 34.436 170.854 151 14478.35 77.680 232.650 -7715.23 -9914.51 4857.04 1.150 12562.70 14470.53 34.132 169.443 152 14571.19 77.210 230.440 -7771.58 -9985.47 4877.23 2.378 12653.31 14563.35 34.772 167.412 153 14665.18 77.420 230.800 -7829.76 -10056.35 4897.87 0.435 12744.96 14657.30 36.746 164.216 154 14759.47 76.980 231.710 -7887.30 -10128.06 4918.76 1.050 12836.90 14751.57 37.807 161.585 155 14853.15 77.180 231.310 -7944.13 -10199.53 4939.70 0.468 12928.20 14845.23 38.490 159.017 156 14948.03 77.420 231.090 -8002.13 -10271.66 4960.56 0.339 13020.74 14940.09 39.833 156.841 157 15021.87 77.400 231.250 -8047.31 -10327.80 4976.66 0.213 13092.79 15013.91 40.985 155.428 158 15116.07 77.080 232.940 -8103.75 -10400.29 4997.47 1.782 13184.66 15108.10 40.980 153.771 159 15209.38 76.960 230.620 -8160.00 -10471.72 5018.43 2.426 13275.58 15201.39 41.440 151.520 Corrected Survey Data Computed Positional Information Travelling Cylinder Co-ords Stn Measured Drl Grid Local 3-D Co-ordinates Vertical Relative Radial Relative No Depth Inc Azi North East TVD DLS Section Depth Dist Azimuth (ft) (deg) (deg) (ft) (ft) (ft) (deg/100ft) (ft) (ft) (ft) (deg) 160 15304.29 76.650 229.670 -8219.22 -10542.66 5040.09 1.028 13367.92 15296.22 44.548 148.405 161 15397.81 76.840 231.650 -8276.92 -10613.05 5061.54 2.071 13458.91 15389.68 46.900 145.683 162 15491.84 77.690 232.640 -8333.20 -10685.47 5082.26 1.368 13550.62 15483.70 47.012 144.315 163 15584.66 77.690 231.790 -8388.77 -10757.14 5102.05 0.895 13641.31 15576.52 47.053 143.812 164 15679.80 77.540 231.940 -8446.15 -10830.23 5122.46 0.220 13734.23 15671.65 47.664 143 136 165 15774.67 77.300 230.750 -8503.98 -10902.54 5143.12 1.250 13826.81 15766.51 49.120 142.093 166 15868.68 76.920 230.810 -8561.93 -10973.53 5164.10 0.409 13918.42 15860.48 51.491 140 571 167 15962.64 76.570 231.070 -8619.56 -11044.55 5185.64 0.460 14009.85 15954.39 53.672 138.532 168 16055.94 76.330 230.010 -8677.20 -11114.58 5207.50 1.134 14100.51 16047.62 56.575 136.243 169 16150.15 76.030 229.540 -8736.28 -11184.42 5230.00 0.580 14191.91 16141.70 60.859 133 899 170 16241.89 76.190 230.140 -8793.72 -11252.49 5252.03 0.658 14280.89 16233.32 65.035 131.804 171 16333.47 76.580 231.360 -8850.03 -11321.41 5273.59 1.363 14369.86 16324.83 67.808 130 085 172 16427.82 76.720 232.230 -8906.80 -11393.55 5295.37 0.909 14461.66 16419.15 68.995 128.481 173 16522.78 76.500 229.750 -8964.95 -11465.32 5317.36 2.551 14554.01 16514.06 71.513 127.140 174 16617.28 76.510 229.620 -9024.40 -11535.39 5339.42 0.134 14645.81 16608.44 76.117 126 209 175 16711.95 76.810 231.960 -9082.63 -11606.76 5361.26 2.426 14737.88 16703.05 78.972 125.193 176 16805.31 76.810 232.250 -9138.46 -11678.49 5382.57 0.302 14828.78 16796.39 79.750 123 972 177 16900.48 76.670 232.340 -9195.11 -11751.78 5404.40 0.174 14921.41 16891.54 80.331 122.601 178 16994.46 76.490 231.300 -9251.61 -11823.63 5426.21 1.093 15012.82 16985.49 81.749 121.285 179 17089.05 76.380 230.340 -9309.71 -11894.91 5448.39 0.993 15104.74 17080.02 84.798 120 264 180 17184.82 75.920 230.590 -9368.90 -11966.62 5471.32 0.543 15197.68 17175.70 88.626 119.162 181 17279.38 74.320 231.490 -9426.36 -12037.68 5495.60 1.926 15289.05 17270.12 92.298 116.969 182 17373.89 73.040 231.930 -9482.56 -12108.87 5522.16 1.426 15379.74 17364.91 96.175 113.483 183 17469.75 72.210 233.500 -9537.98 -12181.65 5550.79 1.787 15471.22 17462.70 98.421 110.360 184 17562.55 71.170 235.300 -9589.27 -12253.28 5579.94 2.156 15559.26 17557.61 97.389 107.753 185 17659.16 69.610 234.610 -9641.52 -12327.79 5612.37 1.749 15650.16 17656.53 94.713 105.576 186 17752.47 67.490 236.640 -9690.56 -12399.45 5646.49 3.043 15736.85 17752.06 90.939 103.440 187 17787.89 65.080 235.410 -9708.68 -12426.35 5660.73 7.510 15769.20 17788.32 89.636 102.309 188 17941.04 63.920 234.730 -9787.82 -12539.67 5726.67 0.857 15907.26 17945.30 84.969 99.029 189 18035.15 62.720 235.600 -9835.85 -12608.69 5768.92 1.519 15991.24 18041.66 79.900 98.424 190 18129.75 60.320 236.060 -9882.55 -12677.48 5814.03 2.573 16074.22 18138.29 73.492 97.792 191 18224.07 58.380 236.090 -9927.84 -12744.81 5862.11 2.057 16155.18 18234.44 66.676 97.123 192 18317.56 55.950 234.390 -9972.61 -12809.34 5912.80 3.015 16233.62 18329.59 60.548 97.404 193 18413.34 53.620 234.180 -10018.28 -12872.88 5968.03 2.439 16311.81 18426.93 55.247 98.859 194 18506.64 51.330 232.700 -10062.34 -12932.31 6024.86 2.758 16385.78 18521.56 50.890 101.573 Corrected Survey Data Computed Positional Information Travelling Cylinder Co-ords Stn Measured Drl Grid Local 3-D Co-ordinates Vertical Relative Radial Relative No Depth Inc Azi North East TVD DLS Section Depth Dist Azimuth (ft) (deg) (deg) (ft) (ft) (ft) (deg/100ft) (ft) (ft) (ft) (deg) 195 18601.13 48.940 231.690 -10106.79 -12989.62 6085.42 2.659 16458.30 18617.20 47.875 106.090 196 18694.50 45.810 230.430 -10149.94 -13043.06 6148.64 3.496 16526.98 18711.53 46.711 111.298 197 18789.45 42.360 229.030 -10192.62 -13093.47 6216.84 3.775 16592.96 18807.21 47.938 115.847 198 18884.64 38.520 226.570 -10234.04 -13139.23 6289.28 4.368 16654.50 18902.26 53.053 116.222 199 18977.55 35.320 224.020 -10273.25 -13178.91 6363.55 3.818 16709.89 18995.80 61.692 114.078 200 19035.28 35.090 223.790 -10297.23 -13201.99 6410.72 0.460 16742.82 19054.01 67.618 113.375 201 19154.62 35.400 226.710 -10345.70 -13250.89 6508.19 1.436 16811.16 19174.63 76.164 114.809 202 19788.00 35.000 227.000 -10595.37 -13517.28 7025.76 0.068 17174.64 - Survey below plan data State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 22-Mar-98 Well Name ~ ~ --/'~ f¢ ~MPL-20 Services Bluelines R/F Sepia Film GR/CCL TCP CORR. 1 1' 0 ~ Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. MEMORANDUM TO: David John, Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 15, 1998 THRU: FROM: Blair Wondzell, ~ P. I. supervisor John Spauldin~¢_~_ SUBJECT: Petroleum Insp4'. FILE NO: awnlcpfe.doc BOPE Test Nabors 4ES BPX MPU L-20 PTD 97-136 Sunday March 15, 1998: I traveled to BPX's Milne Point Unit to witness the BOPE Test on Nabors rig 4ES. The AOGCC BOPE Test Report is attached for reference. As noted on the Test report 3 failures were observed, annular prevent_er, 1 choke valve and the hydraulic controlled valve on the choke side of the mud (;ross. T--~"~'~ were all repaired or replaced and re-tested and were in compliance. Summary: i witnessed the successful BOPE Test on Nabors rig 4ES 17 components, 3 failures, 9 hours __ Attachments: awnlcpfe.xls X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover:__ Drlg Contractor: Nabors Rig No. Operator: BPX / Shared Services Well Name: L-20 Casing Size: 4 1/2 Set @ 16,961 Test: Initial Weekly X Other 4ES PTD # Rep.: Rig Rep.: Location: Sec. DATE: 3/15/98 97-136 Rig Ph.# 659-4454 David Oryall Gene Sweatt 8 T. 13N R. IOE Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted OK Well Sign OK Drl. Rig OK Hazard Sec. OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F '1 300/3,000 P I 500/5,000 P 1 500/5,000 P 1 500/5,000 P 1 500/5,000 P 2 500/5,000 P 1 500/5,000 P NA FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 11 500/5,000 P 28 500/5,000 P I P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Clos'_'.re 1,800 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 33 Trip Tank OK OK System Pressure Attained 3 minutes 10 Pit Level Indicators OK OK Blind Switch Covers: Master: X Remote: Flow Indicator OK OK Nitgn. Btl's: 4 @ 2000 A VG Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK sec. sec. X Number of Failures: 3 ,Test Time: 9.0 Hours. Number of valves tested 17 Repair or Replacement of Failed Equipment will be made within 1 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No, 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector Fl-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Awnlcpfe.xls ,To h n t4. Spa u/ding Shared Services Drilling Contact: Lance Spencer 564-5042 Well Name: J MPU L-20 J Intoduction MPU L-20 was designed as a slim hole well with 9-5/8" casing set above the Schrader Bluff, 7" intermediate casing top set above the Kuparuk sands, and a 4-1/2" liner set in the Miluveach below the ~roposed Kuparuk production interval. This design was necessary because of the unusually high reservoir pressure in the Kuparuk which was the result of offsetting injection. When the well was initially permitted the reservoir pressure was estimated to be 4,399 psi (13.1 ppg EMW) at 6,482' tvdbkb in the Kuparuk C Sand. As planned the 12-1/4" surface hole was ddlled to 8180'. The 9-5/8" surface casing was run and shallow set above the Schrader Bluff at 8160' md (3544' bkb) and cemented in place in two stages. The 8-1/2" intermediate hole was then drilled to 19,124' and the 7" casing was cemented in place in two stages. The 7" casing was set above the Kuparuk D-Shale at 19,103' md (6,442' TVDbkb) to isolate the Ugnu and Schraber Bluff from the Kuparuk interval. At the time, in order to provide sufficient kick tolerance prior to drilling ahead into the Kuparuk it was determined that a formation integrity test resulting in at least a 15.5 ppg EMW was required because the casing shoe could potentially be exposed to a 13.1 ppg EMW reservoir pressure. After drilling out, just below the 7" casing shoe into the Kulubik and Kuparuk D shales mud losses to the formation could not be remedied and when tested after squeezing the formation would not provide the minimum required FIT to proceed safely beyond 19,262' with a 13.3 ppg mud in the hole. As described, in the Detailed Summary of the Previous Drilling Operations a number of LOT's and FiT's where performed after squeezing the open hole section while drilling to 19,262'. In two instances, a LOT of 15.6 ppg EMW at 19,165' and a LOT of 15.0 ppg EMW at 19,195' were obtained. However, in both cases after drilling ahead the formation broke down again. Altogether a total five squeezes were attempted to shut off the loss circulation: two at 19,145', one at 19185, and two at 19,262'. The productive or hydrocarbon bearing Kuparuk Sands were never penetrated while drilling to 19,262' in the 6" hole section. On the last at'tempt an HES EZSV retafner was set at 18,835' and 50 sack, 15.8 ppg, Premium G Cement balanced plug was spotted above the retainer from 18,568-18,1835 because it was not possible to squeeze into the formation below the retainer. Operations were suspended on Aug 31, 1997 after setting the retainer and cementing. Sundry approval was given by the AOGCC on 11-06-97 to suspend operations on MPU L-20. Subsequent Reduction in Kuparuk Reservoir Pressure Since the suspension of MPU L-20, Kuparuk Unit well 30-09, MPU wells L-32 and L-36 have produced sufficient fluids to reduce the Kuparuk reservoir pressure from the initial estimate of 4400 psi to the current estimate of between 3,600-3,800 psi (11.1 ppg EMW). Pressure build up and fall off surveys were taken in MPU L-32 after it was initially completed and again after it was produced for several months. A comparison of these pressure build up and fall off tests confirmed that a pressure reduction has occurred in the reservoir. In addition, MPU L-36, a direct southerly offset to L-20 was drilled with a drilling mud weight of 10.2 in the Kuparuk. MPU L-36 was subsequently completed put on production. The lower mud weight required drill L-36 is further evidence of a reservoir pressure below the initial estimate. Justification for re-entry into L-20 is based upon the reduction in reservoir pressure which is estimated between 3,600-3,800 psi (11.1 ppg EMW). Now that the reservoir pressure is lower, it should be possible to drill the production hole with an 11.3 ppg mud. While drilling L-20 mud losses never occurred when the well was static with a 13.3 ppg mud in the hole or when the weight was reduced to 12.5 ppg and static. Mud losses occurred whenever the equivalent circulating densities exceeded 14.5 ppg. When the mud weight was reduced to 12.5 ppg losses also occurred whenever the ECD exceeded 14.5 ppg. With an 11.3 ppg mud circulating at 5 bpm the maximum expected equivalent circulating densities is 12.3 ppg. Since this ECD of 12.3 ppg is below the 14.5 ppg ECD at which point losses occurred it should be possible to drill the remaining 6" hole without losing circulation. However, if losses occur remedial action will be before proceeding into the Kuparuk. 1998 I Type of Well (producer or iniector): Well Plan Summary I KuJ3aruk Producer Surface Location: 3629' NSL, 5165' WEL, Sec. 08, T13N ,R10E, UM., AK Kuparuk Target 3836' NSL, 2777' WEL, Sec. 23, T13N, R09E, UM., AK Bottom Hole Location: 3684' NSL, 2972' WEL, Sec. 23, T13N, R09E, UM., AK I AFE Number: I ~~Ii~ I I Rig: I Nabors 27-E I I Estimated Start Date: I I Feb 98 I i Operating days to complete: I 15 I I MD: 119,788' I I TVD: 17,027'Bkb I I KBE: 150 I IWell Design: Ultra Slim Hole Formation Markers: 9-5/8", 40# Surface; 7", 26# Intermediate; 4-1/2"[ 12.6# Production Liner Formation Tops MD TVD (bkb).. '-EMW Formation Pressur~ TKLB(MK- 19) 18951 6338 9.4 ppg 310.5psi TKUD 19128 6490 9.4 ppg 3172 psi TKUB 19267 6600 11.1 ppg 3809 psi TKA3/TARGET1 19358 6675 11.1 ppg 3858 psi .. TKA2 19387 6698 11.1 ppg 3866 p__si TKA1 19430 6734 11.1 ppg 3887 psi TMLV 19488 6781 11.1 ppg 3914 psi Total Depth 19788± ..7027,,. 11.1 ppg 4056 psi · *These are estimated maximum pressures. Installed Casing Program: Hole Size (~sg/ ' Wt/Ft Grade Conn Length Top Btm · .Tbg O.D. MD/I'VD MD/TVD 24" 20" 91.1 # H-40' Weld 80 32/32 112/112 12 1/4" 9-5/8" _. 40# L-80 btrc 8,129 _31/31 8,160/,3544 8-1/2" 7" 26# L-80" btm 19,073 30/30 19,103/6466' P~r°p°sed Additi°nal ! 12.6#/ L-80 16, I 4.1/2, Casing Pr°gram IIBT-I 885 modl I 18'9°3/6'3°3 I 19'788/7'°27 I The internal yieId pressure of the 7", 26# casing is 7240 psi. The internal yield pressure of the 4-1/2", 12.6# liner is 8430 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at + 6,781 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of -,-6,781 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,914 psi is 3,236 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. Cementing 'rogram for the 4-1/2' Liner: Halliburton Cementinq Services Hole ' Ca'sing Interval -- ' Volume~ Spacer 'Type of Cement ' ' Properties' Category Size/Depth Production Tail" Tai~l Tai__[I- Den 15.8 ppg Liner 4-t/2" @ 18,903- 120 sx 20 bb]s. Premium Class "G" w/ Yield 1.15 ft 3/sx First Stage 19,788' 19,788' 26 bbls Fresh water 0.2 % CFR-3 Water 5.0 gps 50 bbls NSCI 0.1% HR-5 'IT 3.5-4.5 hfs @140° F 0.45% Halad 344 FL 50cc/30 rnln @ 140° F t, Volumes are rounded up to the nearest 10 sacks. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and muds to ensure compatibility pdor to pumping job. MP L-20 Re-Entry Well Plan PAGE 2 LJS 1:43 PM 1/14/98 3. The production hole First Stage Tail Cement Volume covers the interval from 19,103-19,788 md The estimated first stage tail cement volume is equivalent to the open hole annular volume calculated from 19,103-19,788 to TD plus 30% open hoie excess, a 200' liner lap from 18,903-19,103 and the shoe joint volume, The estimated shoe joint volume is equivalent to the capacity of 160'md of 4-1/2", 12,6# casing. SLURRY PLACEMENT The final TOC is equivalent to the liner top at 18,903' MD/6,466' 'I'VD Adjust volumes to fit "as drilled" formation tops and final measured. The 4-1/2" Production Liner Cement Volume is calculated as follows in the table below, fi3 bbls Sacks 19,103 to 19,788 equals 685' of 6" x 0.0859ff$/ff '0.0153 bbl/ft 58.84 10.48 51.17 4-1/2" open hole +30% Excess + 20O' lap 4-1/2" x 7" 0.1044ft3/ff 0,0186 bbl/ft 20,88 3.72 18.16 · + 300' above TOL 7"x 3-1/2" 0.1480ft3/ft 0.0264 bbl/ff 44.40 7.92 38.61 + 160'x 4-1/2" shoe 0.08544ft3/ft 0.01522 bbl/ff 13.67 2.435 1 i.89 ITM I 137-791 25.56 I 119.831 4. Run two turbulators per joint over the entire liner except for the joints that will be reciprocating in and out of the intermediate shoe. (all 1/8" under hole size) 5. Place all centralizers in middle of joints using stop collars. 6. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no_.[t necessary. Logging/Formation Evaluation Program: Anadrill Schlumberger Final P~:oduction 1. MWD Directional and LWD (Visio~ 475 Impulse) from 7" shoe to TD. Real 6 .... Time ,,. Cased Hole Lo,is: N/A Mud Logging Schlumberger IDEAL'System in the surface and pr~)duction holes. SPIN Log: Record: GR, Depth, Surface Torque end DWOB/DTOQ, ROP, Hook Load, RPM, Pump Press.ure, GPM (in and out) during all oRerations. 6" Hole ROP: ;MWD Vision 475 ADN4/GR Rate of penetration Directional Inclination and Azimuth Telemetry Impulse 5 Phase Resistivity Density Neutron/Gamma ray Mud Program: Baroid Drilling Fluids Inc. Production Mud Properties LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point . ~lel gel Filtrate %LGS 11.1-11.3 43-48 15-20 6-8 8-12 8-9 3-4 10-12 <6 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures, The diverter, BOPE and drilling fluid system schematics are on file with AOGCC, Directional: Maximum Hole Ang]e .. , 76-78° from 3;273-17,0_89' Close Approach Wells There are no close approaches and all wells may remain flowing while drilling Survey Program 1. ~~~9,138' Disl3osal: No "Drilling Wastes" will be injected or disposed into L-20 while drilling this well. Cuttin.qs Handlinq: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handlinq: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. MP L-20 Re-Entry Well Plan PAGE 3 jAN q 4 1998 LJS 1:43 PM 1/14/98 Oil & Gas ~ns. GENERAL DISCUSSION Geolo.qv MP L-20 (W Target ) is a Kuparuk well that will penetrate a fault block into the most western side of the Milne Point Unit. This bottom hole location was selected in order to tap into the eastern edge of the Kuparuk A sand accumulation which has been developed within the Kuparuk Unit from 30 and 3K Pad injection area. L-20 is positioned to take advantage of the injection support from the ARCO Kuparuk 30 Pad injection wells. L-20 (MPL-96W) will target the Kupauk A3, A2 and A1 sands with some potential in the Kuparuk B and C sands. The L-20 fault block contains an estimated 35.6 MSTBO in place, with 12.4 MSTBO of reserves (5.3 MSTBO primary and 7.1 MSTBO secondary). The closest faults from the target center are: 775' northeast, 800' southwest, 1200' northwest, and 1450 east. The shallowest OWC could be at 6,708' TVDss with oil up to 6646' TVDss. The nearest well to the target location is approximately 3910' away and is L-34i. DRILLING HAZARDS AND RISKS SUMMARY: An 11,1 ppg EMW formation pressure is anticipated in the Kuparuk. This pressure is above normal pressure due to injection into the fault block from Kuparuk Unit Wells 3R-20, 30-07, 30-14, and 30-05; however the pressure is lower than the original prognoses when the well was initially permitted. Recent production from MP L-32 and L-36 has reduced to reservoir pressure from original estimate of 4,399 psi. The intermediate casing was installed to alleviate potential problems due to nearby WAG injection. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation occurred when the 6" hole was originally drilled but is not expected to cause major problems now that a lower mud weight (11.1 ppg) will be used to dril! the 6" production hole. .Close Approaches There are no close approaches associated with the drilling of MP L-20; however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Impact of WAG Injection on L-20 BHP Prediction The impact of the nearby injection welds has been reduced because of production from KU 30-09, MP L-32 and MP L-36. The Bottom Hole Pressure in the Kuparuk at the L-20 bottom hole location has been revised to between 10.5 ppg and 11.1 ppg EMW. It is highly probable that L-20 communicates with the Kuparuk injectors 3R-20, 30-07, 30-14, and 30-05 as is still slightly above normal at 11.1 ppg EMW. Recent shut in pressure data from MP L-32 indicated formation pressures to be drawn down from the initial estimate of 13.1 ppg EMW to a maximum pore pressure of 11.1 ppg EMW. L-36 was drilled through the Kuparuk interval with normal mud weights from 10.1-10.3 ppg. An 11.3-11.4 ppg mud weight should be maintained during the production interval to alleviate any potential problems due to the nearby WAG injection. Annular Injection Currently annular injection is not permitted on L-Pad. Lost Circulation: Major losses occurred while drilling the 6" production hole on the previous attempt with weighted mud at 13.3 PPg. Stuck Pipe Potential: Kuparuk Formation Pressure Over pressure is expected, be very cautious 11.1 ppg EMW. Differential sticking is likely if pressures vary between Kuparuk sands, Formation Pressure: KUPARUK A1 .SAND 6,734' TVDbkb 3887 PSI 11.1 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at ± 6,781' 'rVDbkb. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of :L--6,781' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 6,781 psi is 3,914 psi. The maximum expected pore pressure for this well is 11.1 ppg EMW (3,914 psi @ 6,781' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for information on L pad and review recent wells drilled on L Pad. MP L-20 Re-Entry Well Plan PAGE 4 LJS 1:43 PM 1/14/98 Proposed Summary of Operations for MP L-20 Kuparuk Producer I MIRU Nabors 27E. ND tree. NU BOPE, install and test to 5000 psi. 2 Pick up and make up 6" BHA with MWD/LWD. TIH with BHA and displace the 8.4 ppg freshwater from the intermediate casing to 11.3 _+ppg LSND mud. R1H to PBTD and perform a casing integrity test. 4.1 Test the casing to 5000 psi for 30 min prior to drilling out the float collar. 5 Drill out the cement (TOC _ 18,568') and EZSV at 18,835'. Re-enter the initial 6" hole and ream to bottom at 19,262', Drill to 6" hole to production hole TD as per plan to 19,788_+. 8 PU the 4-1/2", 12.6#, L-80, ITC-Modified casing with 2-7/8" PH6 inner sting on 3-1/2" drill pipe. Run the 9.1 9.2 9.3 9.4 9,5 9.6 9.7 9.8 9.9 Liner and Inner string as follows: HOWCO down jet f/oat shoe ~.. 4-1/2; 12.6#, L-80, IBT Mod. HOWCO F/oat Collar) ~. 4-1/2'; 12. 6#, L-80, /BT Mod Baker 0[/ Tools 4-1/2" Type I Landing Collar The Remaining 4-1/2'; 12.6#, L-80, IBT Mod as required to provide 200'/ap inside 7" casing. Pick up Baker liner hanger assembly and XO to 2-7/8" PH6 9.7.1.1 . Make up the 2-7/8" 8rd pups and crossover to 2-7/8" PH-6 off the bottom of the C-2 setting in order to wash the string. RIH on drill pipe filling the drill pipe as required. I0 Perform the 4-1/2" liner cement job. 11 Set the liner hanger and then the packer. 12 After PU 50'_+, circulate out conventionally the excess cement until the returns and hole are clean. 13 POOH until inner string is above liner and circulate 120% of the annular volume while working the drill string. 14 Close the rams. Test the liner and liner lap to 4000 psi for 30 minutes. 15 Circulate and displace the hole to 8.6 ppg. filtered sea water. 16 PU out of the liner with the inner string to the TOL and then displace the remaining annulus to 8.6 ppg. filtered sea water. 17 18 POOH and LD the running string. A liner clean out trip should not be necessary but if a clean out trip is warranted. 19 ND 13-3/8' BOPE. Install the well head and NU BOPE. TEST to 5000 psi. 19.1 NU tubing spool(Cooper 2-9/16" tree) with 7" BPV in tubing hanger. 19.2 Test Tree to 5000 psi. 20 Freeze protect 9-5/8" x 7" casing annulus to 2200' md and note on morning report. 21 Secure well. Release rig. RDMO Nabors 27E. JAN 9 4 1998 MP L-20 Re-Ent~ Well Pman PA~E ~ , LJS 1:43 PM 1/14/gB Detailed Summary of the Previous Drilling Operations After cementing the intermediate casing the top of cement inside the 7" casing was located at 10,398' which was 4B' above the ES Cementer at 10,446'. The cement above the ES cementer and the ES cementer were drilled out. The BHA was tripped in the hole and the top of cement was located above the float collar at 18,975'. Cement was drilled to 19,005. The casing was successfully tested to 5000 psi for 30 minutes before drilling out the float equipment. The 9.3 ppg mud system was displaced with a 13.3 ppg LSND mud before drilling out the float equipment. First, 20 ft of new formation was drilled to 19,145' where severe losses were encountered. At 19,145' while circulating at 4 bpm losses were 50%, at 3 bpm losses were 25% and at 2 bpm losses were minimal. The wellbore was stable and no losses were observed when circulation was stopped. A 20 bbl LCM pill of Barofiber and Baracarb was spotted across the losses interval. When the pump rate was increased from 5 bpm to 6 bpm a loss rate of 25% developed. Next, the drill sting was pulled to 18,848' the first squeeze was attempted. A slurry consisting of 11 bbls of Mineral OIL Spacer, 5 bbl Halliburton FLEX PLUG (Loss circulation polymer treatment) and 5 bbls Mineral OIL Spacer were pumped down the drill pipe. The HES Flex Plug packed off in the BHA and was not pumped into the formation. The drill string was pulled and BHA was laid out along with 18 jts of drill pipe which where are plugged with HES Flex Plug. A 2-7/8" tubing stinger was run in the hole on 4" drill pipe and a second squeeze was done. A balanced plug consisting of 100 sacks of 15,8 ppg Premium G was spotted on bottom. The drill string was pulled to 18,275' and the 11.5 bbls of cement was squeezed into the formation from 19,104-19,145'. A 630 psi squeeze pressure was he/d on the formation for 30 min. The 630 psi squeeze pressure was equiva/ent to a 15,2 ppg EMW. Circulation was established at 2 bpm with 1000 psi of pump pressure without losses. The pump rate was increased to 5 bpm with 2550 of pump pressure without losses, The 2-7/8" tubing stinger was pulled out and laid down. A drilling assembly was run then in the hole and the top of the cement was located at 18,990'. Cement was drilled from 18,990 to TD at 19,145'. Afterwards, new formation was drilled from 19,145-19,165' mud losses increased from 40% to 70%. With the BHA at 19,165' a 20 bbl LCM pill with 60 Ib/bbl LCM pill containing Barofiber and Baracarb was spotted on bottom, The well bore was stable and no losses were observed when circulating was stopped after spotting the LCM. The BHA was pulled out of the hole and changed. After this BHA was tripped in the hole to 18,420' the mud weight was reduced from 13.3 ppg to 12,0 ppg, No mud losses were noted at a final circulation rate of 4.5 bpm. The BHA was washed down and the formation was logged by MAD passing with MWD from 18,420-19,165' without losses at 4.5 bpm. The 6" hole was circulated clean after pumping several sweeps around at 19,165' and no losses were repoded. The BHA was pulled inside the 7" casing shoe to 19,077' and the draw works was repaired. After repairing the draw-works a Leak Off Test was performed with 12.0 ppg mud in the hole. While testing the pressure started leaking off at 1200 psi which is a 15.6 ppg EMW. Following the LOT circulation was started and the mud weight was increased to 12.5 ppg. ft and 20 ft of new formation was ddlled to 19,185'. Over the next 36.5 hrs the well was circulated at 2 bpm with the BHA inside the intermediate casing at 19,077' while the top drive was repaired. After repairing the top drive and tripping into the hole to 19,185' the pump rate was increased to 4 bpm losses of 30 bbls per hour were observed. While circulating at this depth mud weighing in excess of 14.5 ppg was circulated out. The high mud weight was a result of "Barite Sag". Barite falling out of suspension while circulating at Iow rates in highly deviated well bores. The drilling BHA was pulled out of the hole and laid out. A 2-7/8" tubing stinger was run in the hole on 4" drill pipe to 19,185' and a third squeeze was done. A 165 sack 15.8 ppg Premium G balanced plug was spotted on bottom. The drill string was pulled to 18,200' and the circulation was established at 4.5 bpm and 1200 psi without losses. Nest 7.5 bbls of cement was squeezed into the formation from 19,104-19,185'. A 1200 psi squeeze pressure was held on the formation for I hour. The 1200 psi squeeze pressure was equivalent to a 16.1 ppg EMW. After down squeezing the cement the well was monitored while waiting on cement for 4 hours. The 2-7/8" tubing stinger was POOH and laid out. MP L-20 Re-Entry Well Plan PAGE 6 LJ9 1:43 PM 1/14/98 A drilling assembly was run in the hole and the top of the cement at 18,283', Circulation was established at 2 bpm with 1000 psi of pump pressure without losses. Cement was ddlled from 18,283 to TD at 19,185' without mud losses. Another 10' of new formation was dri//ed to 19,195 and a Leak Off Test was performed. Pressure started/eaking off at 850 psi. An 15.0 ppg EMW /eak off was obtained. Drilling was resumed and the 6" hole was drilled to 19,237'. Mud losses of 20 bbls. per hour were reported while drilling 'from 19,195-19,237. The ROP dropped to 5 fi/hr because the bit balled up after drilling to 19,237'. Several attempts were made to un- ball the bit without success. Before tripping the BHA a 15 bbl LCM pill with 15 Ib/bbl LCM pill of Barofiber and Baracarb was spotted on bottom. The drilling BHA was then pulled out of the hole and changed. The next drilling assembly was run in the hole to TD at 19,237' and circulation was established on bottom at 3 bpm but losses of 80 bbls per hour were reported. The losses slowed to 25 bph and drilling was resumed. New formation was drilled from 19,237-19,260' and ddlling was stopped to monitor losses. A 30 ppb concentration of LCM was incorporated into the entire mud system. While circulating at 4 bpm losses of 60-90 bbl/hr were reported. Next new hole was ddlled from 19,260-19,262'. Ddlling was stopped to monitor losses. After stabilizing the well the ddiling BHA was pulled out of the hole due to excessive mud losses and laid out. A 2-718" tubing stinger was run in the hole on drill pipe to 19,262' on 4" drill pipe and a fourth squeeze was done, After circulation was established on bottom at 19,262' a 165 sack, 15.8 ppg, Premium G balanced plug was spotted on bottom. The drill string was pulled to 18,000' and 12 bbls of cement was squeezed into the formation from 19,104-19,262'. A 760 psi squeeze pressure was held on the formation for 1/2 hour. Circulated bottoms up from 18,000' at 3 bpm and a 20 bbl mud loss was reported. After circulating a 1200 psi down squeeze pressure was held for on cement for 4.5 hours. A total of 32.5 bbls, was lost to the formation while maintaining the squeeze pressure. The applied squeeze pressure had an 16.1 ppg EMW. The 2-7/8" tubing stinger was POOH and laid out. A drilling assembly was run in the hole to 18,000'. The casing was washed and reamed from 18,000-19,104, The top of the cement was located cement at 19,225', Cement was drilled from 19,225-19,262 with mud losses at 80 bph. Drilling was stopped and the well monitor at 19,262'. The drilling BHA was pulled out of the hole and laid out. The AOGCC was notified and appraised of the problems associated with L-20, Blair Wondzell gave verbal approval to suspend operations, An HES EZSV was picked up on drill pipe and was run in the hole to 18,835' to attempt a fifth squeeze. The retainer was set at 18,835' and the drill string was released from the retainer. Circulation was established above the retainer. The drill stdng was re-stung into the retainer. An Iow injection rate(0.25 bbl/min) and high pressure was observed. The drill string was released from the retainer and again circulation was established above the retainer. The drill string was re-stung into the retainer. Again an unsatisfactory injection rate and pressure was observed. The drill string was released from the retainer and again circulation was established above the retainer. A 50 sack, 15.8 ppg, Premium G balanced plug was spotted on above the cement retainer after contacting the AOGC appraising of them of mechanical problems with the retainer and that it was not possible to cement the open-hole below the 7" casing. Approval was received to proceed by (Jack Hartz). The LSND ddlling mud was displaced to freshwater and the drill pipe was laid down while POOH. Once the drill pipe was laid down the BOPE stack was dgged down and the tubing head, hanger and Gen 5 tree installed and tested to 5000 psi, The 2 way check pulled and the back pressure valve was installed. The 9-5/8" x 7" annulus was freeze protected with diesel and Nabors 27E was rigged down and released. JAN 1 4 1998 ~Jaska roil & Gas Cons. Commission MP L-20 Re-Entry Well Plan PAGE 7 LJS 1:43 PM 1114/98 STATE OF ALASKA ALASKA ~,,L AND GAS CONSERVATION COfv~,v,!lSSlON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3629' NSL, 5164' WEL, SEC. 8, T13N, R10E, UM At top of productive interval 3836' NSL, 2777' WEL, SEC. 23, T13N, R9E, UM (Planned) At effective depth 1177' SNL, 2312' WEL, SEC. 23, T13N, R9E, UM At total depth 3684' NSL, 2972' WEL, SEC. 23, T13N, R9E, UM (Planned) 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 49.85' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-20 9. Permit Number 97-136 10. APl Number 50-029-22790 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 19262 feet true vertical 6591 feet Effective depth: measured 18575 feet true vertical 6063 feet Plugs (measured) Junk (measured) Cement plug at 18575' Casing Length Size Structural Conductor 80' 20" Surface 8124' 9-5/8" Intermediate 19069' 7" Production Liner Cemented MD TVD 250 sx Arcticset I (Approx.) 112' 112' 2200 sx 'G', 1250 sx PF 'E' 8160' 3546' 425 sx Class 'G' 19104' 6462' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) EZSV at 18835' 6'~',s Con.. Anoflor~ dbmrni~siOn ORIGINAL 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation February 1, 1998 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Lance Spencer, 564-5042 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~ ~.~ ~ Title Senior Drilling Engineer C,~.~ Commission Use Only I Co~~_~pproval: Notify Commission so representative may witness IP'~¥~:~r~[~'~O~/ Plug integrity_ BOP Test .,"- Location clearance ~'\ ~ Mechanical Integrity Test Subseauen.t form required 10- I~ 0rigin, ar b-~gnuu ~y Approved by order of the Commission [.}~.t\ ,0. W. J0hnst0r~ Commissioner Date Date /}:~ Submit/In T]'iplicate Form 10-403 Rev. 06/15/88 Vertical Section Displacement vs TVD Operator BP Exploration Field Milne Point Well MPL-20 Page 1 Rig Nabors 27E Date 09:42, 08 Jan98 Origin North Origin East Section Azimuth Max Depth(TVD) ft ft deg ft 0.00 0.00 232.25 Applied to TD 0 2000 3000 4000 50OO 6OOO 7000 8000 ' -2000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 D~placementfromVerficalSecfion Origin (~) Vertical Section Displacement r BP EXPLORATION November 13, 1997 David W. Johnston. Chairman Alaska Oil & Ga-~ Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501-3192 Subiect: Request for Waiver to Sections i, j, k, and I of 20 ACC 2,5.015 Plugging, Suspension, and Abandonment of Wells and for Section c 20 ACC 25,010 Suspended Wells for MPL-20. Dear Mr. Johnston, This correspondence is submitted in order to be in compliance with AOGCC Regulations 20 ACC 2,5,015 Plugging, Suspension, and Abandonment of Wells, Sections i, j, k and I and with AOGCC Regulation 20 ACC 25.010 Suspended Wells, Section c. A variance from the requirements of these sections is being requested as a result of extreme lost circulation at the 7" casing shoe while drilling the 6" hole section in the Kuparuk D Shale of well MP Even though operations were suspended, it is the intention of BPX to re-enter MP L-20 on or before March 31, 1998 and resume operations. It should be noted that operations on L-20 were suspended on tempora~ basis to provide time to more accurately determine Kuparuk formation pressures and to devise an alternative drilling plan. The well was secured prior to moving the rig by placing a subsurface EZSV plug in the 7" casing at 18,835', putting 244 sacks off cement above EZSV plug and installing a Gen 5a tubing head with a back pressure valve at the surface. Thank-you for your consideration in this matter and if you have any questfons or need additional information concerning this request for waiver from AOGCC Regulations 20 ACC 25.015 Plugging, Suspension, and Abandonment of Wells, Sections l, j, k and I and with AOGCC Regulation 20 ACC 25.010 Suspended Wells, Section c. please contact me in Anchorage at 564-5042. Respectfully, Lance Spencer Drilling Operations Engineer BPX-Shared Services Drilling Blair Wondzell, AOGCC Randy Thomas, SSD-ARCO Chip Alvord, SSD-ARCO .... STATE OF ALASKA ALASKA ,~IL AND GAS CONSERVATION COiwlVllSSlON APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3629' NSL, 5164' WEL, SEC. 8, T13N, R10E, UM At top of productive interval N/A At effective depth 1177' SNL, 2312' WEL, SEC. 23, T13N, R9E, UM At total depth 1474' SNL, 2631' WEL, SEC. 23, T13N, R9E, UM 5. Type of well: [~ Development [] Exploratory [--I Stratigraphic I~ Service 6. Datum Elevation (DF or KB) KBE -- 49.85' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-20 9. Permit Number 97-136 10. APl Number 50-029-22790 1. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 19262 feet 6591 feet 18575 feet 6063 feet Plugs (measured) Junk (measured) Cement plug at 18575' Casing Length Size Structural Conductor 80' 20" Surface 8124' 9-5/8" Intermediate 19069' 7" Production Liner Cemented MD TVD 250 sx Arcticset I (Approx.) 112' 112' 2200 sx 'G', 1250 sx PF 'E' 8160' 3546' 425 sx Class 'G' 19104' 6462' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) EZSV at 18835' 13. Attachments [] Description summary of proposal [--I Detailed operations program [] BOP sketch 14. Estimated date for commencing operation August 28, 1997 16. If proposal was verbally approved Blair Wondzell, Jack Hartz Name of al)prover 8/28/97 Date approved Contact Engineer Name/Number: Lance Spencer, 564-5042 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip AIvord ~ ~_~ ~_ Title Senior Drilling Engineer Commission Use Only Date Il/6 1 ,,o,~ Conditions of Approval: Notify Commission~o representative may witness Plug integrity ~ BOP Test ~ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- Original S~~,-.'-'',. ,.- ,- Approved by order of the Commission David W. J0hnsto, .o"1 Commissioner I Approval No~O)q-I°~% Submit~ln Yriplic/a, te~ Form 10-403 Rev. 06/15/88 L-20 Operations Summary .~'i ?~;~?,-~.., f,~ ~: ~?:~:'i ':':':'. '~;- '~ :,,i~,~:., ::. :~:-:~. After running and cementing the 7" casing numerous attempts were made to drill the 6" production hole without success as a result of lost circulation. Five squeezes were attempted to shut off loss circulation zone just below the casing shoe without success. The following information summarizes those events. Note that the all the losses occurred in the Kuparuk D- Shale and the no productive or hydrocarbon bearing formations were penetrated. On Aug. 9, 1997 in well MP L-20 an intermediate casing string of 7", L-80, 26ppf was ran to 19,104' and cemented in two stages: the first stage was cemented with 175 sacks of 15.8 ppg and 1.15 yield Premium G cement and the second stage was cemented after opening the ES Cementer at 10,446' with 250 sacks of 15.8 ppg and 1.15 yield Premium G cement. The cement plugs bumped on strokes as calculated and the floats held pressure after displacing the cement with drilling mud following each stage. On Aug. 12, 1997 the top of cement was located at 10,398' which was 48' above the ES Cementer at 10,446'. The cement above the ES cementer and the ES cementer were drilled out. Afterwards the BHA was tripped in the hole and the top of cement was located at 18,975'. Cement was drilled to 19,005. The casing was successfully tested to 5000 psi for 30 minutes before drilling out the float equipment. The 9.3 ppg mud system was displaced with an 13.3 ppg LSND mud before drilling out the float equipment. On Aug. 13, 1997 after drilling out the float equipment and 20 ft of new formation to 19,145' severe losses were encountered. While circulating at 4 bpm losses were 50%, at 3 bpm losses were 25% and at 2 bpm losses were minimal. The wellbore was stable and no losses were observed when circulating was stopped. A 20 bbl LCM pill of Barofiber and Baracarb was spotted across the losses interval. When the pump rate was increased from 5 bpm to 6 bpm a loss rate of 25% developed. On Aug 15, 1997 the drill sting was pulled to 18,848' and 11 bbls of Mineral OIL Spacer, 5 bbl Halliburton FLEX PLUG (Loss circulation polymer treatment) and 5 bbls Mineral OIL Spacer was pumped down the drill pipe. The HES Flex Plug packed off in the BHA and was not pumped into the formation. The drill string was pulled and laid out with 18 its of drill pipe which where are plugged with Flex Plug. On Aug. 16, 1997 a 2-7/8" tubing stinger was run in the hole on drill pipe and a 100 sack 15.8 ppg Premium G balanced plug was spotted on bottom. The drill string was pulled to 18,275' and the 11.5 bbls of cement was squeezed into the formation from 19,104-19,145'. A 630 psi squeeze pressure was held on the formation for 30 min. Circulation was established at 2 bpm with 1000 psi of pump pressure without losses. The pump rate was increased to 5 bpm with 2550 of pump pressure without losses. The 2-7/8" tubing stinger was pulled out and laid down and a drilling assembly was run in the hole and the top of the cement was located at 18,990'. Cement was drilled from 18,990 to TD at 19,145' with 40% losses initially which increased to 70% when new formation was drilled form 19,145-19,165'. On Aug. 17, 1997 with the BHA at 19,165' a 20 bbl LCM pill with 60 Ib/bbl LCM pill of Barofiber and Baracarb was spotted on bottom. The well bore was stable and no losses were observed when circulating was stopped. The BHA was pulled out of the hole and changed. On Aug. 18, 1997 the BHA was tripped in to 18,420'. The mud weight was reduced from 13.3 ppg to 12.0 ppg. No mud losses were noted at a final circulation rate of 4.5 bpm. The BHA was washed down and MAD passed with MWD from 18,420-19,165' without losses at 4.5 bpm. Circulated hole clean after pumping sweeps at 19,165' without losses. The BHA was pulled inside the 7" casing shoe to 19,077' and the draw works was repaired and a Leak off test was performed. Pressure started leaking off at 1200 psi. A 15.5 ppg EMW leak off was obtained. Started circulating after the leak off and began increasing the mud weight to 12.5 ppg. From 23:30 hours on Aug. 18, 1997 until 12:00 hours on Aug. 20, 1997 the well was circulated with the BHA inside the intermediate casing at 19,077' while the top drive was repaired. After repairing the top drive and tripping into the hole to 19,185' the pump rate was increased to 4 bpm losses of 30 bbls per hour were observed. On Aug. 21, 1997 the drilling BHA was pulled out of the hole and laid out. A 2-7/8" tubing stinger was run in the hole on drill pipe to 19,185'. On Aug. 22, 1997 an 165 sack 15.8 ppg Premium G balanced plug was spotted on bottom. The drill string was pulled to 18,200' and the circulation was established at 4.5 bpm and 1200 psi without losses. Then 7.5 bbls of cement was squeezed into the formation from 19,104-19,185'. A 1200 psi squeeze pressure was held on the formation for 1 hour. After down squeezing waited on cement for 4 hours. On Aug. 23, 1997 the 2-7/8" tubing stinger was POOH and laid out A drilling assembly was run in the hole and the top of the cement was located cement stringers at 18,283'.. Circulation was established at 2 bpm with 1000 psi of pump pressure without losses. Cement was drilled from 18,283 to TD at 19,185' without mud losses. Another 10' of new formation was drilled to 19,195 and a Leak off test was performed. Pressure started leaking off at 850 psi. A 15.0 ppg EMW leak off was obtained. Mud losses of 20 bbls. per hour were reported. The RQP dropped to 5 ft/hr because the bit balled up after drilling to 19,237'. A 15 bbl LCM pill with 15 Ib/bbl LCM pill of Barofiber and Baracarb was spotted on bottom. On Aug. 24, 1997 the drilling BHA was pulled out of the hole and changed. A drilling assembly was run in the hole to TD at 19,237'. On Aug. 25, 1997 circulation was established on bottom at 3 bpm and losses of 80 bbls per hour were reported. Losses slowed to 25 bph and drilling was resumed. New formation was drilled from 19,237- 19,260'. Drilling was stopped to monitor losses. A 30 ppb concentration of LCM was incorporated into the entire mud system. While circulating at 4 bpm losses of 60-90 bph were reported. Drilled from 19,260- 19,262'. Drilling was stopped to monitor losses. After stabilizing the well the drilling BHA was pulled out of the hole. On Aug. 26 1997 the drilling BHA was pulled out of the hole and laid out. A 2-7/8" tubing stinger was run in the hole on drill pipe to 19,262'. On Aug. 27, 1997 circulation was established on bottom at 19,262 then a 165 sack 15.8 ppg Premium G balanced plug was spotted on bottom. The drill string was pulled to 18,000'. Squeezed 12 bbls of cement into the formation from 19,104-19,262'. A 760 psi squeeze pressure was held on the formation for 1/2 hour. Circulated bottoms up from 18,000' at 3 bpm and a 20 bbl. Loss was reported. On Aug. 28, 1997 after circulating a 1200 psi down squeeze pressure was held for on cement for 4.5 hours. A total of 32.5 bbls. was lost to the formation while maintaining the squeeze pressure. The 2-7/8" tubing stinger was POOH and laid out A drilling assembly was run in the hole to 18,000'. The casing was washed and reamed from 18,000-19,104. The top of the cement was located cement at 19,225'. Cement was drilled from 19,225-19,262 with mud losses at 80 bph. Drilling was stopped and the well monitor. On Aug. 29 1997 the drilling BHA was pulled out of the hole and laid out. An HES EZSV was picked up on drill pipe and was run in the hole on drill pipe to 18,835'. The retainer was set at 18,835' and the drill string was released from the retainer. Circulation was established above the retainer. The drill string was re- stung into the retainer and an unsatisfactory injection rate and pressure was established. The drill string was released from the retainer and again circulation was established above the retainer. The drill string was re-stung into the retainer and an unsatisfactory injection rate and pressure was established. The drill string was released from the retainer and again circulation was established above the retainer. A fifty sack 15.8 ppg Premium G balanced plug was spotted on above the cement retainer. The LSND drilling mud was displaced to freshwater and the drill pipe was laid down while POOH. On Aug. 30 1997 the drill pipe was laid down while POOH. Rigged down the BOPE stack and installed the tubing head, hanger and Gen 5 tree. Tested tree to 5000 psi. Pulled 2 way check and installed back pressure valve. Free protected the 9-5/8" x 7" annulus with diesel. Rigged down and released the rig. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 17.1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Milne Point Unit MPL-20 BP Exploration (Alaska) Inc. Permit No: 97-136 Sur. Loc. 3629'NSL, 5165'WEL, Sec. 08, T13N, R10E, UM Btmhole Loc' 3684'NSL, 2972'WEL, Sec. 23, T13N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by laxv from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (.BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed betbre drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlffenclosures cc; Department of Fish & Game, Habitat Section w/o encl. Department of Envinomment Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single ZOne [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 49.3' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025514 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3629' NSL, 5165' WEL, SEC. 8, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3836' NSL, 2777' WEL, SEC. 23, T13N, R9E MPL-20 At total depth 9. Approximate spud date Amount $200,000.00 3684' NSL, 2972' WEL, SEC. 23, T13N, R9E 07/21/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025513, 115'I No Close Approach 2560 19691' MD / 6911' TVD ...... 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 77-94° Maximum surface 3857 psig, At total depth (TVD) 6665' / 4523 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 8107' 31' 31' 8138' 3549' 980 sx PF 'E', 2163 sx Class 'G' 8-1/2" 7" 26# L-80 Btrc 19119' 30' 30' 19119' 6442' :158 sx Class 'G' 6" 4-1/2" 12.6# L-80 IBT-Mod 822' 18869' 6242' 19691' 6911' 129 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production [2 E C Liner ~'- jUL -! "~ Perforation depth: measured 01 161NA!. true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoarnor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord _~4~ ~ ~/~Z_ Title Senior Drilling Engineer Date ~ Commission Use Only PermLt Number I APINumber I ApprovalDa~ _., See cover letter ~,~ _ ~,_,,.2 ¢~' 50- O 2.. ~' -- Z_. 2.,'~ 90 "7 '- / "7 -- ~" "'// for other requirements Conditions of Approval: Samples Required []Yes [~ No Mud Log Required []Yes [] No Hydrogen Sulfide Measures []Yes .]~'No Directional Survey Required [~Yes [] No Required Working Pressure for BOPE I-I2M; 1'-13M; [~'SM; I--I10M; I-I15M Other: Onginai Signed By by order of Approved By no,,~,4 ~At ~,,~,,.,.~.,-,.. Commissioner the commission Dat~ Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: Lance Spencer IMPL-20 I Well Plan Summary 564-5042 I Type of Well (producer or injector): I Kuparuk Producer Surface Location: 3629' NSL, 5165' WEL, Sec. 08, T13N ,R10E, UM., AK Kuparuk Target 3836' NSL, 2777' WEL, Sec. 23, T13N, R09E, UM., AK Bottom Hole Location: 3684' NSL, 2972' WEL, Sec. 23, T13N, R09E, UM., AK I AFE Number: I Rig: I Nabors27-E Estimated Start Date: 1 21 July 97 I I Operating days to complete: I MD: I19,691' I I TVD: 16,911' Bkb I IKBE' 123 149.3 IWell Design: Ultra Slim Hole I9-5/8", 40# Surface; 7", 26# Intermediate; 4-1/2" 12.6# Production Liner Formation Markers: Formation Tops MD TVD (bkb) EMW Formation Pressure Base Permafrost 1910 1799 8.4 ppg 786 psi NA/Schrader Bluff 10054 3949 8.4 ppg 1725 psi Target OB 11011 4149 8.4 ppg 1812 psi Base Schrader 12447 4449 8.4 ppg 1943psi Top HRZ 18794 6192 8.8 ppg 2834 psi Base HRZ 18901 6272 8.8 ppg 2870 psi TKLB(MK-19) 19005 6352 9.4 ppg 3105psi TKUD 19119 6442 9.4 ppg 3149 psi TKUC 19168 6482 13.1 ppg 4399 psi TKUB 19188 6498 13.1 ppg 4410 psi TKA3/TARGET1 ~,Y2262 6559 13.1 ppg 4451 psi TKA2 /q1~290 6582 13.1 ppg 4467 psi TKA1 19334 6618 13.1 ppg 4491 psi TMLV 19391 6665 13.1 ppg 4523 psi Total Depth 19691 ± 6911 _ 13.1 ppg 4690 psi · *These are estimated maximum pressures. Casinq/'l'ubing Pro! ram: Hole Si~ze C-sg/ ~- Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1 # H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btm 8,107 31/31 8,138/,3549 8-1/2" 7" 26# L-80 btrc 19,119 30/30 19,119/6,442 6" 4-1/2" 12.6# L-80 IBT 822 18,869/6,242 19,691/6,911 mod The internal /ield pressure of the 7" 26# casing is 7240 psi. The internal yield pressure of the 4-1/2"12.6# casing is 8430 psi T The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at ± 6,665 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of ±6,665 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 4,523 psi is 3,857 psi using a 0,1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP L-20 (L-97W) Drilling Permit 1 7/9/97 Cementinc Program Halliburton Cementinq Services Hole Casing Interval Volume~ Spacer Type of Cement Properties2 Category Size/Depth Surface Tai~l Tail5 Lead Tait Premium Class "G" Tai~l First Stage 9-5/8" @ 2010-8138' 2163 sx 70 bbls Fresh w/ Den 15.8 ppg 8,138' 443 bbls water 0.2 % CaCI, Yield 1.15 ft 3/sx 0.15 #/sk Celoflakes Water 4.9 gps TT 4.0 hrs ....... §~;;~;'~'~i ...................................................................... ~!i i:~i~' ............. ~';~;~' .................... i'¥;~i ...................................... i'~'~;~i ......................................................... Stage ~.:.!@i :~ 0-1910' 980 sx 75 bbls Fresh Permafrost "E" Same as above ~i~.~:~ 1910-2010 411 bbls water Wellhead If _Lead~ Lead Lead Stabili ,ty Cmt necessary. 150 sx Permafrost "E" Same as above Intermediate Tail~ Tai__l Tai__t Den 15.8 ppg First Stage 7" @ 18,919- 158 sx 20 bbls. Premium Class "G" w/ Yield 1.15 ft 3/sx 19,119' 19,119' 32 bbls Fresh water 0.2 % CFR-3 Water 5.0 gps 70 bbls NSCI 0.1% HR-5 TT 3.5-4.5 hrs @140° F 0.45% Halad 344 FL 50cc/30 rain @140° F Production .Tail" Tai__l Tai._~l Den 15.8 ppg Liner 4-1/2" @ 18,869- 129 sx 20 bbls. Premium Class "G" w/ Yield 1.15 ft 3/sx First Stage 19,691' 19,691' 27 bbls Fresh water 0.2 % CFR-3 Water 5.0 gps 50 bbls NSCI 0.1% HR-5 TT 3.5-4.5 hrs @ 140° F 0.45% Halad 344 FL 50cc/30 min @ 140° F 1. Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and muds to ensure compatibility prior to pumping job. 3. A Type H ES Cementer-will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2110'MD_+ 4. The surface hole First Stage TAIL Cement Volume covers the interval from 2,110-8,138' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 2,110 (200' below the base of the permafrost) to surface TD at 8,138' md (3,549' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9~5/8", 40# casing. 5. The surface hole Second Stage Lead Cement Volume covers the interval from 0-2,110' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,110' MD (200' below the base of the permafrost) to surface. From 1833' to surface include 250% open hole excess and from 1,910-2,110' use 30% open hole excess. 6. The estimated Well head stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the well head. 7. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 8. The intermediate hole First Stage Tail Cement Volume covers the interval from 18,119-19,119' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 18,119 to TD at 19,119' plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 26# casing. 9. i!~i!ii:ii~:!:::.~~:,:::::!i~!~ffii:::iiii~Sii:!:~Y~ :!ii! ~:~::~i~:~:~g~~ of at !~ast.:~10::feet cumulative of net oil in the ~C~.::'~i~ff ~'~;';~ ,,.~:~:;; ~:. ~:::~b:,:~iac!~g~.:~ ES ce~ente~at 1:1,211' (200 below the Base of ~b:':.:' ~:.~he intermediate hole Second Stage LEAD Cement Volume would cover the interval from 9,553-11,211' md. The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 11,211' MD to 9,553' which is 500' above the Schrader Bluff NA sandplus 30% open hole excess. 10. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install TWO per joint from 120' below to 120' above any potential hydrocarbon bearing sands. 11. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5~8" casing. 12. Install two 7" marker joints and position three joints above the Kuparuk C sand. 13. ~.~:.~:~:~~:~.~:::~:.~y~b~:~~:;:~si~~~ of ~t !e~S~ 10: feet cumulati,~e of net oil in the ~ ~:::~::~;t~:::.:~;:::..~;~:.~: of 9'5/8 casing to ~ver the ' 14. The production hole First Stage Tail Cement Volume covers the interval from 18,869-19,691 md The estimated first stage tail cement volume is equivalent to the open hole annular volume calculated from 18,119 to TD plus 30% open hole excess, a 250' liner lavp from 18869-19,119 and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 12.6¢ casing. The 4-1/2" Production Liner Cement Volume is calculated as follows in the table below. MP L-20 (L-97W) Drilling Permit 2 7/9/97 ft3 bbls Sacks 19,119 to 19,691 equals 572' of 6" x 0.0859ft3/ft 0.0153 bbl/ft 63.87 11.38 55.54 4-1/2" open hole +30% Excess + 250' lap 4-1/2" x 7" 0.1044ft3/ft 0.0186 bbl/ft 26.01 4.65 22.69 + 300' above TOL 7"x 3-1/2 0.1480ft3/ft 0.0264 bbl/ft 44.40 7.92 38.61 + 160' 4-1/2"shoe 0.08544ft3/ft 0.01522 bbl/ft 13.67 2.435 11.89 ITM I 147'95 I 26'39 I 128'73 I 15. Run two turbulators per joint over the entire liner except for the joint that will be reciprocating in and out of the intermediate shoe. (1/8" under hole size) 16. Place all centralizers in middle of joints using stop collars. 17. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no~t necessary. SLURRY PLACEMENT Intermediate Final Production 8-1/2" Cased Hole Logs: Mud Logging The final TOC is equivalent to the liner top at 18,869' MD/6,242' TVD Adjust volumes to fit "as drilled" formation tops and final measured Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. DWOB/DTOQ from top to bottom of surface hole. 3. M10 Power Plus MWD Directional from top to bottom of surface hole.. 4. L~.D (CDR/G~BQ.P)from T.OP Schrader Bluff to TD of surface hole. 5. bWDi:':~BBii:i:ii:(D~e~i~i:.':~rbsi~;:.:.~ic)~ro~::TOP Schrader Bluff to TD of 6. DWOB/DTOQ from top to bottom of surface hole. 7.MWD Directional and LWD (SHARP-ARC5/GR) from & shoe to TD. Real Time N/A Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DVVOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. 12-1/4" and 8-1/2" Hole M10 PowerPlus IWOB: GR: CDR: ADN: ROP: Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Mud Program. Baroid Drilling Fluids Inc. Special design considerations Prior to spudding a complete review of the L-Pad drilling hazards is required. Keep the mud weights as Iow as possible (9.4-9.6 ppg) in the intermediate hole to minimize the overbalance across the Schrader Bluff and to avoid the breathing phenomena. Hydraulics will be limited in the 6" by the pressure drop in the 3-1/2" drill pipe. A complete mud displacement will be done at the 7" shoe to ensure a clean mud in the 6" hole. The effectiveness of the lubricate "cocktail" in 13.3 ppg mud should be closely monitored. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point ~lel 9el Loss % 8.6-9.3 30-45 6-20 3-10 7-20 8.5-9.5 6-12 to 4-6 <6 MP L-20 (L-97W) Drilling Permit 3 7/9/97 Production Mud Properties LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel ~lel Filtrate %LGS 8.6-9.6 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 <6 <4 Production Mud Properties LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point ~lel gel Filtrate %LGS 13.3-13.5 43-48 15-20 6-8 8-12 8-9 3-4 10-12 <6 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. Directional: KOP1 Tangent Hole Angle Drop Maximum Hole Angle Close Approach Wells Survey Program 300' Start Variable @ 1.0°- 2.5 °/100 and Az 232.25°. EOB 3302' 75.59° @ Az 232.25° from 3,302-17,337' 7,826 @ 1.75 °/100 to 29.66° incl. and 232.25 Az o EOD 10452" 77.94° from 3,302-17,337' All wells may remain flowing while drilling ~20 and no shut-ins are required. 1. Surface to 8,700' MWD surveys. 2. ~ ~?19,138' 'lN~H~leReference~after~drilling out surface casing. 3. In-Hole referenced MWD Surveys from 9,138' to 19,119' 4. MWD Surveys fro~ 19,119' to TD 5. ~.~.9,138 ~i~:i.i~ffe~ ~~ ~it~ Nab°rS27E. Disposal: No "Drilling Wastes" will be injected or disposed into L-20 while drilling this well. Cuttinqs Handlinq: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handlinq: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPL-20 is planned as a high angle 78°, high departure 17,136', ERD 19,691' md Kuparuk River A Sand producer. The S-shaped well profile with a final angle of 35° that will intersect the target objectives and provide optimum inclination for fracture stimulation. The surface casing will be shallow set above the Schrader Bluff at 8138'md (3549' bkb). This well is unique in that due to high formation pressure in the Kuparuk sands which dictate a 13.3 ppg mud weight, the Kuparuk sands will be top set at 19,119' (top of Kuparuk D shale) with a 7" casing string and then a 6" production hole will be drilled to a TD of 19,691' where a 4-1/2" liner will be run and set. The intermediate casing is being set in the Kuparuk D-Shale at 19,119' (6,442'bkb) to isolate the Ugnu and Schraber Bluff from the Kuparuk interval which could be abnormally pressured by area injection. The Kuparuk pressure is expected to be above normal with an estimated pore pressure of 13.05 ppg EMW. The target location is directly offset by Kuparuk Unit injection and production from 3R and 30 pads. Communication across the faults is anticipated. To date, no wells have penetrated the L-20 fault block. MP L-20 (L-97W) Drilling Permit 4 7/9/97 Geoloav L-20 (W) is the Kuparuk well to penetrate this particular fault block into the most western side of the MiJne Point Unit. This bottom location was selected in order to tap the eastern edge of the Kuparuk A sand accumulation which has been developed within the Kuparuk Unit from 30 and 31( Pads. The wells are positioned to take advantage of the injection support from the ARCO Kuparuk 30 Pad injection wells. L-20 (MPL-96W) will target the Kupauk A3, A2 and A1 sands with some potential in the Kuparuk B and C sands. The L-20 fault block contains an estimated 35.6 MSTBO in place, with 12.4 MSTBO of reserves (5.3 MSTBO primary and 7.1 MSTBO secondary). The closest faults from the target center are: 775' northeast, 800' southwest, 1200' northwest, and 1450 east. The shallowest OWC could be at 6,708' TVDss and with oil up to 6646' TVDss. The nearest well to the target location is approximately 3910' away and is L-34i. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be above normal. 13.05 ppg EMW in the Kuparuk due to injection in the fault block from Kuparuk Unit Wells 3R-20, 30-07, 30-14, and 30-05. The intermediate casing design is recommended to alleviate potential problems due to nearby WAG injection. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation and stuck pipe have occurred recently but are not expected to cause major problems. Close Approaches There are no close approaches associated with the drilling of MP L-20, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Impact of WAG Injection on L-20 BHP Prediction The impact of the nearby injection wells and the actual BHP in the Kuparuk at the L-36 bottom hole location is uncertian. It is highly probable that L-36 communicates with the Kuparuk injectors 3R-20, 30-07, 30-14, and 30- 05. which means the fault block could be over pressured in the Kuparuk formation. Recent shut in pressure data indicated formation pressures to be above normal at a 13.3 ppg EMW pore pressure in the Kuparuk due to the injection. The injectors are not BP operated, hence will not be shut-in to allow the pressures to stabilize. In addition, production from 30-07, 30-03, and 30-08, 30-18 will not, while drilling L-20, draw down the formation pressure enough to substantially minimize the risk of drilling into over pressured formation. The intermediate casing design and mud weights of 13.3 ppg during the production interval should alleviate the potential problems due to the nearby WAG injection. However, due the uncertainty in predicting the actual BHP and mud weights to necessary to stabilize the Kuparuk while drilling, be advised the possibilities of being over or under balanced exits. Be very cautious when selecting the intermediate casing seat and while drilling the production section. Make sure mud weights are sufficient to avoid taking a kick or to high to avoid breaking down the formation. Intermediate Casinq Point Selection Selecting the intermediate casing seat and obtaining a suitable LOT is critical to the success of this well. It is essential that this casing be installed into the Kuparuk D-shale without entering the Kuparuck C-sand. The D Shale was selected because it offers the deepest possible setting depth and will provide protection to the Ugnu and Schrader Bluff formations. After exiting the HRZ and Kalubik Shale (MK 19Marker) enter the Kuparuk D- Shale carefully and drill only enough hole to identify the interval with CDP,/GR in order to confirm the intermediate casing setting depth. It is imperative that every precaution be taken to insure that the D Shale is not exited and the Kuparuk C is inadvertently entered. The lithology must be clearly understood prior to drilling below the HRZ. The actual setting depth may be adjusted if geological uncertainties develop Le. formation thickness and pressure integrity cannot be confirmed Annular Injection Currently annular injection is not permitted on L-Pad. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. MP L-20 (L-97W) Drilling Permit 5 7/9/97 Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on L-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9-5/8" casing has been stuck. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. Caution is advised while drilling the Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is common occurrence, has often caused difficulties, so care should be taken to avoid the stuck pipe while drilling the 8 1/2" production interval. Attention should be given to avoid excessive mud's weights to keep the HRZ and Kalubik shale's stabilized and risk breaking down the Kuparuk formations.. Differential sticking and lost circulation is most likely to occur while running and cementing the production string. Formation Pressure: KUPARUK C SAND 6,482' TVDbkb 4399 PSI 13.05 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _. 6,665' TVDbkb. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _-,-6,665' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 4,423 psi is 3,857 psi. The maximum expected pore pressure for this well is 13.05 ppg EMW (3,857 psi @ 6,665' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for information on L pad and review recent wells drilled on L Pad. MP L-20 (L-97W) Drilling Permit 6 7/9/97 Proposed Summary of Operations for MP L-20 Kuparuk Producer 1. Drill and set 20" conductor. Weld on an FMC landing ring for an FMC Gen 5A well head onto the conductor and a nipple to aid in performing a potential well head stability cement job. 2. Prepare the location for a rig move. 3. MIRU Nabors 27E drilling rig. Notify the AOGCC 24 hrs prior to spud to witnes the test of the diverter system. 4. NU and test the 20" diverter system. Build the spud mud. Ensure that the diverter system is installed, inspected, and tested per AOGCC specifications and is approved by and AOGCC inspector. 5. Spud well and drill 12-1/4" hole. Start variable build at 300'. Build to 77.94'~' inclination and 232.25° azimuth by 3,202' md. Continue drilling to 9-5/8" casing point at 8,138'. 6. Run the 9-5/8" 40# L-80 BTC-Modified casing. Complete the surface casing check list. 7. Perform the TWO STAGE cement job with the Halliburton ES TYPE Cementer placed at 2110' md (200' measured depth below the Permafrost). 8. Land casing, ND 20" diverter, install and TEST the well head and BOPE to 5000 psi. Notify the AOGCC of the upcoming BOPE test. Note Witness of BOPE Test on IADC and DEAP morning reports. 9. Pick up and make up 8-1/2" BHA. Run M10 directional MWD and CDR/GR LWD to 8-1/2" TD. 10. RIH and drill out the stage tool and perform a casing integrity test. Drill out float equipment and 20' of new hole. Perform leak off test as per recommended practices. SEE REVISED LOT PROCEDURES. Test the casing to 3500 psi for 30 min prior to drilling out the float collar. Immediately notify the drilling Superintendent if the LOT does not yield an equivalent mud weight of at least 12.5 ppg. 11. Drill to 8-1/2" hole to intermediate hole TD as per directional plan. Note the presence of any hydrocarbons in the UGNU of Schrader Bluff. 12. Run the 7", 26#, L-80, BTC-Modified casing. 13. Perform the 7" cement job. Refer to 7" Cement Recommendation. 14. Land the 7" casing, ND 13-3/8" BOPE. Install the well head and NU BOPE. TEST to 5000 psi.. Notify the AOGCC of the upcoming BOPE test. Note Witness of BOPE Test on IADC and DEAP morning reports. 15. Pick up and make up 6" BHA. Precondition drilling mud prior to TIH. The mud shall include the a minimum 4% lubricant concentration (3% EP Mud Lude, 1% Drill-N-Slide) at a weight of 13.3 ppg prior to displacing the 9.6 ppg LSND to the 13.3 ppg LSND mud. 16. While RIH every 2000' _+ and displace the 9.6 ppg mud to 13.3 ppg LSND mud. 17. RIH and perform a casing integrity test. Test the casing to 5000 psi for 30 min prior to drilling out the float collar. 18. Drill out the float equipment and 20' of new hole. After drilling 20' of new hole, POOH to the 7" csg. shoe. Circulate and condition the mud. 19. MIRU cement pumping unit and perform the LOT. Perform leak off test as per recommended practices. SEE REVISED 7 RP LOT procedure vl-0. Doc. MP L-20 (L-97W) Drilling Permit 7 7/9/97 20. Drill to 6" hole to production hole TD as per directional plan. The Production Interval will be logged by 1), REAL time while drilling with SHARP/ARC5 (Gamma Ray/Resistivity)to TD. or 2) MAD Passing after drilling the interval on a later trip if the MWD/LWD is not run initially. 21. PU the 4-1/2", 12.6#, L-80, ITC-Modified casing with 2-7/8" PH6 inner sting on 3-1/2" drill pipe. 22. Run the Liner and Inner string as follows: HOWCO down jet float shoe, 2 jt. 4-1/2", 12.6#, L-80, IBT Mod., HOWCO Float Collar), 2 jt. 4-1/2", 12.6#, L-80, IBT Mod., Baker Oil Tools 4-1/2" Type 1 Landing Collar, and the remaining 4-1/2", 12.6#, L-80, IBT Mod as required to provide 250' lap inside 7" casing. 23. Pick up Baker liner hanger assembly and XO to 2-7/8" PH6 24. RIH on drill pipe to approximately 15' from TD. On the last single in, Pick up circulating head and wash to bottom. Liner depth is planned for 300 BELOW THE BASE OF THE Miluveach. 25. Perform the 4-1/2" liner cement job. 26. Set the liner hanger and then the packer. 27. After PU 10', reverse out any excess cement until the and returns and hole are olean. 28. Close the rams. Test the liner and liner lap to '!~Si f. Or:'~O' ~[nUtes .If the liner lap test fails, remedial action may be required. Contact the drilling superintendent if the test is unsuccessful. 29. Circulate and displace the hole to 8.6 ppg. filtered sea water. 30. PU out of the liner with the inner string to the TOL and then displace the remaining annulus to 8.6 ppg. filtered sea water. 31. POOH and LD the running string. 32. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree.Test Tree. RDMO Nabors 271::. 33. RDMO Nabors 27E THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP L-20 (L-97W) Drilling Permit 8 7/9/97 Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPL-20 (P03) Field ........ : Milne Point, L-Pad Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.49779778 N Surface Long.: 149.63434888 W ~ , Legal Description Surface ...... : 3629 FSL 5165 FEL Target ....... : 3836 FSL 2777 FEL BHL .......... : 3684 FSL 2972 FEL LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord S08 T13N R10E UM 544712.98 6031817.73 S23 T13N R09E UM 531422.00 6021398.00 S23 T13N R09E UM 531228.19 6021246.06 PROPOSED WELL PROFILE STAT I ON MEASURED I NCLN IDENTIFICATION DEPTH ANGLE KB 0.00 0.00 KOP BUILD 1.5/100 300.00 0.00 BUILD 2/100 400.00 1.50 500.00 3.50 CURVE 2.5/100 600.00 5.50 mmmmmmm ! ! mmmmmmmmmmmmmmmm! DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA m mmmmmmm~ 0.00 0.00 -49.30 232.'25 300.00 250.70 232.25 399.99 350.69 232.25 499.89 450.59 232.'25 599.57 550.27 Prepared ..... : 30 Jun 1997 Vert sect az.: 232.25 KB elevation.: 49.30 ft Magnetic Dcln: +28.061 (E) Scale Factor.: 0.99990227 Convergence..: +0.34467375 mmmmmmmm SECTION COORDINATES-FROM DEPART WELLHEAD 0.00 0.00 N 0.00 E -0.00 0.00 N 0.00 E 1.31 0.80 S 1.03 W 5.67 3.47 S 4.48 W 13.52 8.27 S 10.69 W ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN ;5 ..... I ii . I~lm i i urlm ii m, lm -tm4q~,~mds,dlm.,mmamdm4mu~ ~4m mm mm~m mmmLm ALASKA Zone 4 X Y 544712.98 6031817.73 544712.98 6031817.73 544711.95 6031816.92 544708.52 6031814.23 544702.34 6031809.39 700.00 8.00 800.00 10.50 900.00 13.00 1000.00 15.50 1100.00 18.00 1200.60 20.50 1300.00 23.00 232.25 698.87 649.57 232.25 797.57 748.27 232.25 895.46 846.16 232.25 992.38 943.08 232.25 1088.13 1038.83 25.27 15.47 S 19.98 W 41.34 25.31 S 32.69 W 61.70 37.78 S 48.79 W 86.32 52.85 S 68.25 W 115.14 70.49 S 91.04 W 232.25 1182.53 1133.23 148.10 90.67 S 117.10 W 232.25 1275.40 1226.10 185.15 113.36 S 146.40 W 544693.10 6031802.14 544680.45 6031792.23 544664.42 6031779.66 544645.06 6031764.48 544622.38 6031746.70 544596.44 6031726.36 544567.28 6031703.51 mmmm mmmm TO0b DL/ FACE 100 ~ ~mmm 128L 0.00' 128L 0.00 128L 1.50 128L 2.00 ~s ~.oo HS 2.50 HS 2.50 HS 2.50 HS 2.50 HS 2.50 HS 2.50 HS 2.50 (Anadrill (c)97 MPL20P03 3.0C 3:33 PM P) MPL-20 (P03) 30 Jun 1997 Page 2 STATION IDENTIFICATION END 2,5/100 CURVE BASE PERMAFROST c-~.~ a/,lOO 9-5/8" CASING POINT NA MEASURED INCLN DEPTH ANGLE 1400.00 25.50 1500.00 28.00 1600.00 30.50 1700.00 33.00 1800.00 35,50 1872.71 37.32 1910.44 37.32 1948.15 37.32 2000.00 38.87 2100.00 41.87 2200.00 44.87 2300.00 47.87 2400.00 50.87 2500.00 53.87 2600.00 56.87 2700.00 59.87 2800.00 62.87 2900.00 65.87 3000.00 68.87 3100.00 71.87 3200.00 74.87 3300.00 77.87 3302.37 77.94 8138.41 77.94 10053.51 77.94 OB 11011,06 77,94 BASE SCHRADER 12447,39 77.94 CURVE 2.5/100 17337,32 77,94 PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 232,25 1366,57 1317,27 232,25 1455.86 1406,56 232,25 1543,11 1493.81 232.25 1628.13 1578.83 232.25 1710.79 1661.49 SECTION COORDINATES-FROM DEPART WELLHEAD 226,22 138,50 S 178,87 W 271,23 166,05 S 214,46 W 320.09 195.97 S 253.09 W 372.70 228.18 S 294.69 W 428.98 262.63 S 339.19 W 232.25 1769.30 1720.00 472.13 289.05 S 373.31 W 232,25 1799,30 1750,00 495,00 303.05 S 391,39 W 232,25 1829,30 1780,00 517,87 317,05 S 409,47 W 232,25 1870,10 1820,80 549,86 336,64 S 434,76 W 232,25 1946,27 1896,97 614,62 376,29 S 485.97 W 232,25 2018,96 1969,66 683,29 418,33 S 540,27 W 232,25 2087,94 2038,64 755,67 462,64 S 597,49 W 232,25 2153,05 2103,75 831,55 509,10 S 657,50 W 232,25 2214,09 2164,79 910,75 557,58 S 720,11 W 232,25 2270,91 2221,61 993,02 607,96 S 785,17 W 232,25 2323,34 2274,04 232,25 2371,25 2321,95 232',25 2414,49 2365,19 232,25 2452,96 2403,66 232,25 2486,55 2437,25 232.25 2515.16 2465.86 232.25 2538.72 2489.42 232.25 2539.21 2489.91 232.25 3549.30 3500.00 232,25 3949,30 3900,00 1078.16 1165.93 1256.08 1348.37 1442.55 1538.36 1635.53 1637.85 6367.23 8240.09 232,25 4149.30 4100,00 9176,52 232,25 4449,30 4400,00 10581,17 232,25 5470.64 5421,34 15363,25 ALASKA Zone 4 X Y 544534,96 6031678,17 544499,55 6031650,41 544461.10 6031620.26 544419.70 6031587.80 HS 544375,41 6031553,09 HS FACE 100 HS 2.50 HS 2,50 HS 2,50 2.50 2.50 544341,46 6031526,47 HS 2.50 544323.46 6031512,36 HS 0,00 544305,47 6031498,25 HS 0,00 544280,29 6031478,52 HS 3,00 544229.33 6031438.56 ~S 3.00 544175.29 6031396.20 HS 3.00 544118.34 6031351.55 MS 3.00 544058.62 6031304.73 HS 3.00 543996.31 6031255.88 HS 3.00 543931.56 6031205.12 HS 3.00 660.08 S 713.81 S 769.01 S 825.51 S 883.17 S 852.48 W 543864.57 6031152.60 HS 3.00 921.88 W 543795.50 6031098.45 HS 3.00 993.16 W 543724.56 6031042.84 HS 3.00 1066.13 W 543651.94 6030985.90 HS 3.00 1140.60 W 543577.83 6030927.80 HS 3.00 941.83 S 1001.32 S 1002.74 S 3898.19 S 5044.81 S 1216,35 W 543502,43 6030868,70 HS .3,00 1293,19 W 543425,97 6030808,75 HS 3,00 1295,02 W 543424,14 6030807,32 HS 3,00 5034,45 W 539702,56 6027889,71 HS 0,00 6515,29 W 538228,79 6026734,32 HS 0,00 5618,12 S 7255,71 W 6478,08 S 8366,34 W 9405,81 S 12147,44 W 537491,90 6026156,62 HS 0,00 536386,58 6025290,08 HS 0.00 532623,52 6022339,96 LS 0,00 (Anadrill (c)97 MPL20P03 3,0C 3:33 PM P) MPL-20 (P03) 30 Jun 1997 Page 3 STATION IDENTIFICATION < < < END 2.5/100 CURVE MEASURED INCLN DEPTH ANGLE 17400.00 76.38 17500.00 73.88 17600.00 71.38 17700.00 68.88 17800.00 66.38 17900.00 63.88 18000.00 61.38 18100.00 58.88 18200.00 56.38 18300.00 53.88 18400.00 51.38 18500.00 48.88 18600.00 46.38 18700.00 43.88 18793.74 41.53 TOP HRZ 18793.74 41.53 BASE HRZ 18900.61 41.53 DROP 2.5/100 18900.61 41.53 19000.00 39.05 TKLB 19005.39 38.91 19100.00 36.55 T~UD/ 7 ~j~ 19118.84 36.08 E~ 2.5/100 DROP 19161.96 35.00 T~C 19167.96 35.00 19168.84 35.00 _ TKUB 19187.49 35.00 TARGET ************* 19261.96 35.00 TKA3 19261.96 35.00 (Anadrill (c)97 MPL20P03 3.0C 3:33 PM P) PROPOSED WELL PROFILE mmmmmmmmm mmmmmmmmsmtmmmmmm DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 232.25 5484.57 5435.27 232.25 5510.24 5460.94 232.25 5540.09 5490.79 232.25 5574.08 5524.78 232.25 5612.14 5562.84 mmmmmmmm SECTION DEPART 15424.36 15521.00 15616.43 15710.47 15802.94 232.25 5654.20 5604.90 15893.65 232.25 5700.17 5650.87 15982.45 232.25 5749°98 5700.68 16069.16 232.25 5803.52 5754.22 16153.61 232.25 5860.69 5811.39 16235.64 232.25 5921.38 5872.08 16315.11 232.25 5985.49 5936.19 16391.85 232.25 6052.88 6003.58 16465.72 232.25 6123.42 6074.12 16536.58 232.25 6192.30 6143.00 16600.15 232.25 6192.30 6143.00 16600.15 232.25 6272.30 6223.00 16671.01 232.25 6272.30 6223.00 16671.01 232.25 6348.11 6298.81 16735.28 232.25 6352.30 6303.00 16738.68 232.25 6427.12 6377.82 16796.57 232.25 6442.30 6393.00 16807.73 232.25 6477.39 6428.09 16832.79 232.25 6482.30 6433.00 16836.23 232.25 6483.02 6433.72 16836.73 232.25 6498.30 6449.00 16847.43 232.25 6559.30 6510.00 16890.14 232.25 6559.30 6510.00 16890.14 mmmmmmmmmmmmmmmmmmmmm COORDINATES-FROM WELLHEAD 9443.22 S 12195.76 W 9502.38 S 12272.17 W 9560.81 S 12347.63 W 9618.38 S 12421.98 W 9674.99 S 12495.09 W mmmmmmmmmmmmmmmmmmmm ALASKA Zone 4 X Y 532575.44 6022302.26 532499.39 6022242.64 532424.29 6022183.77 532350.30 6022125.76 532277.53 6022068.71 9730.53 S 12566.82 W 9784.89 S 12637.03 W 9837.98 S 12705.59 W 9889.68 S 12772.36 W 9939.91 S 12837.23 W 9988.56 S 12900.06 W 10035.54 S 12960.73 W 10080.77 S 13019.14 W 10124.15 S 13075.17 W 10163.07 S 13125.44 W 532206.15 6022012.75 532136.27 6021957.97 532068.04 6021904.48 532001.59 6021852.38 531937.03 6021801.77 531874.50 6021752.7~ 531814.11 6021705.41 531755.98 6021659.83 531700.22 6021616.12 531650.20 6021576.90 10163.07 S 13125.44 W 10206.45 S 13181.47 W 10206.45 S 13181.47 W 10245.80 S 13232.28 W 10247.88 S 13234.96 W 531650.20 6021576.90 531594.44 6021533.19 531594.44 6021533.19 531543.86 6021493.54 531541.19 6021491.44 10283.32 S 13280.74 W 531495.64 6021455.73 10290.15 S 13289.56 W 531486.86 6021448.85 10305.49 S 13309.38 W 531467.14 6021433.39 10307.60 S 13312.10 W 531464.43 6021431.26 10307.91 S 13312.50 W 531464.03 6021430.95 10314.46 S 13320.96 W 531455.61 6021424.35 10340.61 S 13354.73 W 531422.00 6021398.00 10340.61 S 13354.73 W 531422.00 6021398.00 mmm! mmmm TOOL DL/ FACE 100 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 LS 2.50 HS 2.50 HS 2.50 LS 0.00 LS 0.00 LS 2.50 LS 2.50 LS .2.50 LS 2.50 HS 2.50 HS 0.00 HS 0.00 HS 0.00 HS 0.00 HS 0.00 MPL-20 (P03) 30 Jun 1997 Page 4 PROPOSED WELL PROFILE sTATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE TKA2 19290.04 35.00 TKA1 19333,98 35.00 TMLV 19391.36 35.00 TD / 4-1/2" LINER PT 19691.36 35.00 DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 232.25 6582.30 6533.00 232.25 6618.30 6569,00 232.25 6665.30 6616,00 232.25 6911.05 6861.75 mmmmmmmm SECTION DEPART 16906.25 16931.46 16964.37 17136.44 mmmmmmmwmmmmmmmmmmmmm COORDINATES-FROM WELLHEAD 10350.47 S 13367.46 W 10365.90 S 13387.39 W 10386.05 S 13413.41 W 10491.40 S 13549.47 W mmmmmmmmmmmmmmmmmmmm mmmm mmmm ALASKA Zone 4 TOOL DL/ X Y FACE 100 mmmmmmmmm mmmmmmm m m m mm m m m m mm 531409.33 6021388.07 HS 0,00 531389.49 6021372.51 HS 0,00 531363.59 6021352.21 HS 0.00 531228.19 6021246.06 0.00 ANADRILL AKA-DPC APPROVED. FOR PERMITTING ONLY ,..':_ ....... :.=.-- (Anadrill (c)97 MPL20P03 3.0C 3:33 PM P) SHARED SERVT_CES DR'[LLTNG ,4nadni ]] Sch]umbengen <KE T Marker Identification MD BKB SECTN A) KB 0 0 0 B) KOP BUILD'I.5/IO0 300 300 -0 C) BUILD 2/100 400 400 D} CURVE 2.5/100 600 600 E) END 2.5/100 CURVE 1873 t769 472 F) CURVE 3/100 ' t948 t829 518 G) END 3/100 CURVE 3302 2539 1638 H) 9-5/8' CASING POINT 8138 3549 6367 I) CURVE 2.5/100 17337 5471 15363 J) END 2.5/100 CURVE 18794 6t92 16600 K) DROP 2.5/100 18901 6272 16671 L) END 2.5/100 DROP 19162 · 6477 16833 M) 7' CASING POINT 19169 6483 16837 N) TARGET xxxxxxxxxxxxx 19262 6559 16890 O) TD / 4-1/2" LINER PT 19691 6911 17136 INCLN 0.00 0.00 1.50 5.50 37.32 37.32 77.94 77.94 77.94 41 53 4i 53 35 O0 35 O0 35 O0 35 O0 MPL-20 (PO3) VERTICAL SECTION VIEN Section at: TVD Sca]e · Oep Sca]e' Drawn · 232.25 I inch : 2400 feet 1 inch : 2400 feet 30 Jun 1997 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN # ~ ............ A , ~ ~,~-~ ~"~:~- 4.z;;Z.r___.., '~Z'S~' ~ ~'~4~¢ ............................ ~j~ -.---------- ====================== iii-iii~::::: , ., 0 1200 2400 3600 4800 6000 7200 8400 9600 10800 12000 13200 14400 15600 16800 18000 19200 20400 Sect ion Departure (Anadri)] (c)97 MPL2OP03 3.0C 3:36 PM P) et ) SHARED SERVI.CES DRILLING --~ IVil-' L- C::U ~l"k/,]) VERTICAL SECTION VIEW Section at: 232.25 TVD Scale · ! inch: 100 feet _- ~ ................... T~-m~ Dep Scale' I inch = 100 feet ,Drawn · 30 Jun I997 ~.:~ ......... - ~~ ............ Ana~r~ JJ $ch]uml~erger Marker Identification MD BKB SECIN INCLN _ A) END 2.5/~00 CURVE ~8794 6192 16600 4~.53 B) DROP 2.5/100 18901 6272 16671 41.53 C} END 2.5/100 DROP i9162 6477 16833 35.00 '[~L~'-b'~ ........... O) 7' CASING POINT 19169 6483 16837 35.00 E) TARGET ~~ 19262 6559 16890 35.00 F) TO / 4-1/2" LINER PT 19691 6911 17136 35.00 IKUO b4~t ~N~ ,f~rnPl' (l~adius 2(0 feet ;kNADR LL A KA-DP(' FC R PJ!RMITTII'IG F 16500 16550 16600 16650 ' 16750 16800 16850 16900 t695C 7000 17050 17100 17t50 17200 ~- Section Departure ..... ' _ . ~nadri]] Sshlu~berger SHARED SERVICES DRILLING · . · MPL-20 (PO3) PLAN VIEW APPROVEDpl:DkAiTTiNI~ CLOSURE'~36 ¢,,t ~t ,z~mut, 2~.~5 FOR -~.-.,...----..,-- DECLI4ATION.' +28.061 (E) OhlLY SCALE ' ~ ~nch : ~000 feet PLAN ~ ~ DRAWN · 30 Jun ~997 ' ' Marker Identification MB N/S E/W ~ ~ -- KB 0 0 N 0 E KOP BUILD 1.5/100 300 0 N 0 E ~ BUILD 2/100 400 I S I W D) CURVE 2.5/J00 600 8 S 11W E) END 2.5/J00 CURVE 1873 289 S 373 W F) CURVE 3/~00 1948 3J7 S 409 , G) END,~300 CURVE 3302 JO03 S ~295" H) 9-5~ CASING POINT 8~38 3898 S 5034 W I) CURVE 2.5/100 ~7337 9406 S ~2147 W J) END 2.5/~00 CURVE I8794 t0163 S ~3125 W K) DROP 2.5/100 18901 ~0206 S ~3181W END 2.5/100 DROP 19162 10305 S 13309 W 7" :ASING POINT ~9169 ~0308 S ~3312 W O) TD / 4-J/2" LINER PT J969l t049i S 13549 W / , T~nnn~,, - ~ ~nr ~ ) :~,' ,, , , , ~7000 lBO00 15000 14000 ~3000 J~O00 1~000 10000 9000 8000 7000 6000 5000 4000 3000 2000 ~000 0 1000 <- WEST' EAST -> I m (~nad¢i]] (c)97 MPL~OPO$ 3.0C 3:37 PM P) ., · WELL PERMIT CHECKLIST COMPANY ~ WELL NAME ,,,~/~..- ..~__O PROGRAM: exp [] dev/~redrll [] serv [] wellbore seg U ann. disposal para req E1 FIELD & POOL ~'::2__~/C)<--~ INIT CLASS ._,L/),~i ./-- ,~,'/ GEOLAREA ('~_~ UNIT# //~,~__~' ON/OFF SHORE ('3,,~] . ADMINISTRATION .__R DAT, E 1. Permit fee attached ....................... 2. Lease number appropriate .................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... N N N N N N N N N N Y N N N ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved...'/~r-~,. 22. Adequate wellbore separation proposed ............. ~i-N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... 25. DOPEs, do they meet regulation te'st't~ ' _ . . 26. BOPE press rating appropriate; Psig' 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY APPR AT 30. Permit can be issued w/o hydrogen sulfide measures ..... ; ~./,¢/(,, )z~, 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. Y//N ~' .... 33. Seabed condition survey (if off-shore) ............. N 34. Contact name/phone for we.eklypro.qress reDo. ds ..... / Y N jexplora'tory omyj REMARKS GEOLOGY: ENGINEERING: COM,~: SEW ~ T//.-<'' DWJ~-" JDH ~ RNC"~/,,-~ Comments/Instructions: HOWlljt - A:\FORMS\cheklist rev 07/97 B.P. EXPLORATION L PAD, WELL NO. MPL-20 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Inside 5" DRILL PIPE Survey date' 03-AUGUST, 1997 Job number :A0897GCE417 O IGINAL CONTENTS JOB NUMBER :A0897GCE417 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION; SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' A0897GCE417 Tool 777 was run in WELL# MPL-20 on SCHLUMBERGER 7/32" wireline inside DRILL PIPE. The survey was run without problems. SURVEY CERTIFICATION SHEET JOB NUMBER: A0897GCE417 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the odginal data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A0897GCE417 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: L PAD, ALASKA WELL: MPL-20 LATITUDE: 70.497 N LONGITUDE: 149.5 W SURVEY DATE: SURVEY TYPE : 03, AUGUST, 1997 GYRO MULTISHOT IN 5" DRILL PIPE DEPTH REFERENCE: 49.3' MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 9900' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-9900' APl NUMBER: 050-029-22790 TARGET DIRECTION: 232.2 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLOP~ATION L PAD, WELL NO. MPL-20 MILNE POINT FIELD, ALASKA Job Number: A0897GCE417 Run Date: 3-Aug-97 07:45:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.495000 deg. N Sub-sea Correction from Vertical Reference: 49.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True'North Proposed Well Direction: 232.200 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION L PAD, WELL NO. MPL-20 ~ILNE POINT FIELD, ALASKA 3ob Number: A0897GCE417 Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0 100 200 300 400 .0 .0 .0 .0 .0 0.00 0.00 0.0 .35 41.81 100.0 .30 37.45 200.0 .22 279.84 300.0 1.12 253.87 400.0 0.0 0.00 0.0 0.0 - . 3 . 35 . 3 41 .~8 -.9 .05 .9 40.5 -1.0 .45 1.1 30.8 .1 .93 .9 318.8 0.00 N 0.00 E .23 N .20 E .66 N .57 E .91 N .54 E .67 N .58 W 5OO 599 699 8O0 900 .0 .0 .0 .0 .0 2.20 254.49 499.9 3.28 250.06 598.8 6.30 238.80 698.5 8.85 232.81 798.6 13.08 227.28 896.7 2.7 1.08 3.4 268.0 7.2 1.11 8.0 258.6 15.4 3.15 16.2 250.5 28.6 2.65 29.2 243.6 47.6 4.35 47.9 238.1 .12 S 3.37 W 1.59 S 7.86 W 5.40 S 15.24 W 12.97 S 26.17 W 25.31 S 40.62 W 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 16.34 228.20 993.4 18.18 229.94 1088.9 20.23 231.54 1183.4 23.05 232.37 1276.3 28.25 233.29 1366.4 31.84 233.95 1453.0 32.79 234.06 1537.5 33.85 233.72 1621.1 36.41 232.99 1702.8 38.59 232.41 1782.2 72.9 3.26 73.0 234.5 102.5 1.91 102.6 233.0 135.4 2.11 135.4 232.4 172.3 2.84 172.3 232.3 215.6 5.21 215.6 232.4 265.6 3.61 265.6 232.7 319.0 .95 319.1 232.9 373.9 1.08 374.0 233.0 431.5 2.60 431.5 233.1 492.3 2.21 492.4 233.0 42.36 S 59.43 W 61.78 S 81.85 W 82.57 S 107.33 W 105.28 S 136.38 W 131.40 S 170.88 W 161.08 S 211.19 W 192.50 S 254.44 W 224.87 S 298.81 W 259.22 S 344.97 W 296.11 S 393.38 W 2000.0 39.71 232.28 1859.7 2100.0 42.59 233.50 1935.0 2200.0 45.52 232.77 2006.9 2300.0 48.95 232.10 2074.8 2400.0 52.47 231.68 2138.1 555.5 1.12 555.5 233.0 621.2 2.99 621.3 232.9 690.8 2.98 690.8 233.0 764.2 3.47 764.2 232.9 841.5 3.53 841.6 232.8 334.69 S 443.37 W 374.37 S 495.84 W 416.08 S 551.46 W 460.85 S 609.64 W 508.61 S 670.52 W A Gyro da t a Di r e c t i ona i Survey B.P. EXPLORATION L PAD, WELL NO. MPL-20 MILNE POINT FIELD, ALASKA Job Number: A0897GCE417 Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2500.0 2600.0 2700.0 2800.0 2900.0 53.79 231.97 2198.1 55.89 232.19 2255.7 58.97 232.19 2309.5 62.09 231.66 2358.7 64.72 231.62 2403.4 921.5 1.34 921.6 232.7 1003.3 2.12 1003.3 232.7 1087.6 3.08 1087.6 232.6 1174.6 3.14 1174.6 232.6 1264.0 2.64 1264.0 232.5 558.05 S 733.41 W 608.30 S 797.90 W 659.96 S 864.47 W 713.64 S 933.00 W 769.13 S 1003.11 W 3000.0 3100.0 3200.0 3300.0 3400.0 68.02 231.51 2443.5 71.78 232.39 2477.9 74.97 233.23 2506.5 76.09 233.06 2531.5 75.10 233.66 2556.3 1355.6 3.30 1355.6 232.5 1449.5 3.84 1449.5 232.4 1545.3 3.30 1545.3 232.4 1642.1 1.13 1642.1 232.5 1738.9 1.14 1739.0 232.5 826.08 S 1074.86 W 883.94 S 1148.80 W 941.84 S 1225.13 W 999.93 S 1302.60 W 1057.73 S 1380.31 W 3500.0 3600.0 3700.0 3800.0 3900.0 4000.0 4100.0 4200.0 4300.0 4400.0 75.90 234.57 2581.4 76.41 234.98 2605.3 77.01 234.95 2628.3 77.27 235.15 2650.6 77.43 235.15 2672.5 77.61 234.83 2694.1 78.33 234.43 2714.9 78.84 234.63 2734.7 80.00 234.75 2753.1 80.99 234.76 2769.6 1835.7 1.18 1835.8 232.6 1932.7 .65 1932.8 232.7 2029.9 .61 2030.0 232.8 2127.3 .32 2127.5 232.9 2224.7 .16 2225.0 233.0 2322.2 .36 2322.5 233.1 2420.0 .82 2420.3 233.2 2517.9 .54 2518.3 233.2 2616.1 1.17 2616.6 233.3 2714.6 .99 2715.2 233.3 1114.47 S 1170.47 S 1226.34 S 1282.20 S 1337.96 S 1393.98 S 1450.60 S 1507.47 S 1564.29 S 1621.21 S 1458.75 W 1538.07 W 1617.75 W 1697.66 W 1777.73 W 1857.70 W 1937.44 W 2017.28 W 2097.49 W 2178.04 W 4500.0 4600.0 4700.0 4800.0 4900.0 81.50 233.30 2784.8 79.56 233.12 2801.3 78.91 233.74 2819.9 79.42 234.03 2838.7 79.96 234.40 2856.6 2813.4 1.53 2814.0 233.4 2912.0 1.95 2912.6 233.4 3010.3 .90 3010.9 233.4 3108.4 .58 3109.1 233.4 3206.7 .65 3207.5 233.4 1679.26 S 1738.33 S 1796.86 S 1854.75 S 1912.28 S 2258.03 W 2337.01 W 2415.91 W 2495.26 W 2575.07 W A Gyr oda t a D i r e c t i ona i Sur-vey B.P. EXPLORATION L PAD, WELL NO. MPL-20 MILNE POINT FIELD, ALASKA Job Number: A0897GCE417 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5000.0 79.06 232.44 2874.8 5100.0 79.01 232.55 2893.9 5200.0 77.94 232.95 2913.8 5300.0 76.32 233.30 2936.1 5400.0 76.84 233.18 2959.3 3305.0 2.13 3305.8 233.4 3403.2 .11 3403.9 233.4 3501.2 1.14 3501.9 233.4 3598.7 1.66 3599.4 233.4 3695.9 .53 3696.7 233.3 1970.87 S 2030.64 S 2089.95 S 2148.45 S 2206.66 S 2654.02 W 2731.91 W 2809.90 W 2887.88 W 2965.81 W 5500.0 77.42 233.57 2981.6 5600.0 77.91 232.80 3003.0 5700.0 78.31 232.13 3023.6 5800.0 77.37 231.06 3044.6 5900.0 77.66 230.67 3066.3 3793.4 .70 3794.2 233.4 3891.1 .90 3891.8 233.3 3988.9 .77 3989.7 233.3 4086.7 1.40 4087.4 233.3 4184.3 .48 4184.9 233.2 2264.82 S 2323.35 S 2382.97 S 2443.70 S 2505.33 S 3044.05 W 3122.25 W 3199.85 W 3276.45 W 3352.18 W 6000.0 76.86 230.62 3088.3 6100.0 77.32 230.91 3110.7 6200.0 77.18 231.05 3132.7 6300.0 77.30 230.76 3154.8 6400.0 76.93 231.73 3177.1 4281.8 .80 4282.4 233.2 4379.2 .54 4379.8 233.1 4476.7 .19 4477.2 233.1 4574.2 .30 4574.7 233.0 4671.7 1.01 4672.1 233.0 2567.18 S 2628.83 S 2690.24 S 2751.74 S 2812.77 S 3427.60 W 3503.09 W 3578.87 W 3654.56 W 3730.58 W 6500.0 77.38 231.82 3199.3 6600.0 77.34 231.97 3221.2 6700.0 77.16 232.04 3243.3 6800.0 77.26 231.83 3265.4 6900.0 77.86 231.74 3287.0 4769.2 .46 4769.6 233.0 4866.8 .16 4867.2 232.9 4964.3 .19 4964.7 232.9 5061.8 .23 5062.2 232.9 5159.5 .60 5159.8 232.9 2873.10 S 29.33.31 S 2993.35 S 3053.48 S 3113.88 S 3807.17 W 3883.95 W 3960.82 W 4037.59 W 4114.32 W 7000.0 78.83 231.39 3307.2 7100.0 79.29 230.99 3326.2 7200.0 79.06 231.18 3344.9 7300.0 78.11 231.76 3364.7 7400.0 77.43 231.71 3385.9 5257.4 1.03 5257.7 232.9 5355.6 .60 5355.9 232.8 5453.8 .29 5454.1 232.8 5551.8 1.12 5552.1 232.8 5649.5 .68 5649.8 232.8 3174.76 S 3236.30 S 3298.00 S 3359.06 S 3419.58 S 4191.03 W 4267.54 W 4343.96 W 4420.64 W 4497.37 W A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION PAD, WELL NO. MPL-20 ~ILNE POINT FIELD, ALASKA ~ob Number: A0897GCE417 Page ~EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7500.0 76.85 231.99 3408.2 7600.~0 76.57 231.89 3431.2 7700.0 77.36 232.74 3453.7 7800.0 78.33 233.16 3474.8 7900.0 78.70 233.25 3494.7 5747.0 .63 5747.2 232.7 5844.3 .29 5844.6 232.7 5941.7 1.14 5942.0 232.7 6039.5 1.05 6039.7 232.7 6137.5 .38 6137.7 232.7 3479.80 S 4574.04 W 3539.80 S '4650.67 W 3599.36 S 4727.77 W 3658.26 S 4805.79 W 3716.95 S 4884.26 W 8000.0 79.15 233.65 3513.9 8100.0 78.38 233.89 3533.4 8200.0 78.16 234.63 3553.7 8300.0 77.41 234.51 3574.9 8400.0 76.78 233.69 3597.2 6235.6 .59 6235.9 232.7 6333.6 .81 6333.9 232.8 6431.5 .76 6431.8 232.8 6529.1 .76 6529.5 232.8 6626.5 1.01 6626.9 232.8 3775.39 S 3833.36 S 3890.55 S 3947.21 S 4004.37 S 4963.10 W 5042.22 W 5121.69 W 5201.32 W 5280.28 W 8500.0 76.44 233.60 3620.4 8600.0 75.68 234.03 3644.5 8700.0 75.09 235.53 3669.7 8800.0 74.14 235.87 3696.2 8900.0 74.45 235.00 3723.3 6723.8 .36 6724.2 232.8 6820.8 .87 6821.3 232.9 6917.5 1.57 6918.0 232.9 7013.7 1.01 7014.3 232.9 7109.8 .90 7110.4 233.0 4062.03 S 4119.34 S 4175.15 S 4229.48 S 4284.10 S 5358.63 W 5436.96 W 5516.00 W 5595.65 W 5674.92 W 9000.0 76.40 234.50 3748.5 9100.0 77.45 233.70 3771.1 9200.0 78.60 233.11 3791.8 9300.0 77.80 232.62 3812.3 9400.0 77.00 232.36 3834.1 7206.5 2.01 7207.2 233.0 7303.9 1.31 7304.5 233.0 7401.7 1.29 7402.4 233.0 7499.5 .93 7500.3 233.0 7597.1 .84 7597.8 233.0 4339.95 S 4397.07 S 4455.39 S 4514.48 S 4573.90 S 5753.95 W 5832.85 W 5911.39 W 5989.43 W 6066.84 W 9500.0 77.29 232.28 3856.3 9600.0 78.60 231.59 3877.2 9700.0 78.35 231.15 3897.2 9800.0 79.48 229.64 3916.4 9900.0 78.95 228.98 3935.1 7694.6 .31 7695.3 233.0 7792.4 1.47 7793.1 233.0 7890.4 .50 7891.0 232.9 7988.5 1.86 7989.1 232.9 8086.6 .84 8087.1 232.9 4633.50 S 4693.79 S 4754.96 S 4817.52 S 4881.56 S 6144.00 W 6221.00 W 6297.54 W 6373.15 W 6447.63 W A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION L PAD, WELL NO. MPL-20 ~ILNE POINT FIELD, ALASKA Job Number: A0897GCE417 Page ~EASURED I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet Final Station Closure: Distance: 8087.12 ft Az: 232.87 deg. A Gyroda t a D i re c t i ona i Survey for B.P. EXPLORATION L PAD, WELL NO. MPL-20 MILNE POINT FIELD, ALASKA Iob Number: SUB418 ~un Date: 3-Aug-97 07:45:00 Surveyor: TOM STODDARD 2alculation Method: MINIMUM CURVATURE Survey Latitude: 70.495000 deg. N Sub-sea Correction from Vertical Reference: 49.3 ft. Azimuth Correction: ~yro: Bearings are Relative to True North Proposed Well Direction: 232.200 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t iona i Survey ~.P. EXPLORATION j PAD, WELL NO. MPL-20 ~ILNE POINT FIELD, ALASKA rob Number: SUB418 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet -49.3 0.00 0.00 0.0 100.0 .33 39.66 149.3 200.0 .26 156.96 249.3 300.0 .66 267.04 349.3 400.0 1.65 254.18 449.3 0.0 0.00 0.0 0.0 .20 .9 41.2 .25 1.1 35.7 .69 .9 172.8 1.00 3.4 293.8 0.00 N 0.00 E .44 N .38 E .78 N .55 E .79 N .56 W .40 S 1.96 W 5OO 600 700 8O0 900 .0 .0 .0 .0 .0 2.74 252.28 549.3 5.0 4.81 244.36 649.3 11.3 7.59 235.76 749.3 22.1 11.04 229.95 849.3 38.4 14.85 227.78 949.3 61.4 1.10 8.0 263.3 2.14 16.2 254.5 2.89 29.2 247.0 3.53 47.9 240.8 3.76 73.0 236.1 .85 S 5.61 W 3.52 S 11.60 W 9.25 S 20.79 W 19.35 S 33.64 W 34.58 S 50.84 W 1000 1100 1200 1300 1400 .0 .0 .0 .0 .0 17.42 229.22 1049.3 19.49 230.96 1149.3 22.23 232.13 1249.3 27.26 233.11 1349.3 31.69 233.92 1449.3 90.2 123.6 161.6 207.3 263.5 2.48 102.6 233.6 2.04 135.4 232.6 2.63 172.3 232.4 4.76 215.6 232.4 3.67 265.6 232.7 53.72 S 72.54 W 75.07 S 98.14 W 98.68 S 127.94 W 126.44 S 164.33 W 159.82 S 209.48 W 1500 1600 1700 1800 1900 .0 .0 .0 .0 .0 32.94 234.01 1549.3 34.73 233.47 1649.3 37.69 232.65 1749.3 39.56 232.30 1849.3 43.17 233.35 1949.3 326.8 393.8 467.1 547.0 635.1 .97 374.0 232.9 1.60 431.5 233.1 2.37 492.4 233.0 1.27 555.5 233.0 2.98 690.8 233.0 197.07 S 260.71 W 236.73 S 314.75 W 280.83 S 373.32 W 329.50 S 436.65 W 382.66 S 506.90 W 2000.0 2100.0 2200.0 2300.0 2400.0 47.67 232.35 2049.3 52.71 231.73 2149.3 55.66 232.16 2249.3 61.49 231.76 2349.3 68.66 231.66 2449.3 736.6 856.5 994.3 1158.0 1371.4 3.28 764.2 232.9 3.12 921.6 232.8 2.03 1003.3 232.7 3.13 1174.6 232.6 3.39 1449.5 232.5 444.06 S 587.82 W 517.86 S 682.29 W 602.74 S 790.77 W 703.41 S 919.94 W 835.82 S 1087.31 W A Gyroda t a D i re c t i ona i Survey ~.P. EXPLORATION PAD, WELL NO. MPL-20 ~ILNE POINT FIELD, ALASKA Iob Number: SUB418 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet 2500.0 75.38 233.49 2549.3 2600.0 77.26 235.14 2649.3 2700.0 79.76 234.72 2749.3 2800.0 79.74 234.25 2849.3 2900.0 76.61 233.23 2949.3 1711.5 1.14 1739.0 232.5 2121.7 .34 2127.5 232.9 2595.9 1.04 2616.6 233.3 3166.5 .62 3207.5 233.4 3653.9 1.01 3696.7 233.4 1041.35 S 1358.29 W 1279.01 S 1693.10 W 1552.61 S 2081.00 W 1888.70 S 2542.36 W 2181.53 S 2932.17 W 3000..0 77.43 230.97 3049.3 3100.0 77.27 230.83 3149.3 3200.0 77.19 231.98 3249.3 3300.0 78.85 231.31 3349.3 3400.0 77.21 232.57 3449.3 4107.7 1.20 4184.9 233.3 4549.9 .27 4574.7 233.0 4990.8 .20 5062.2 232.9 5475.4 .47 5552.1 232.8 5922.7 .98 5942.0 232.7 2456.96 S 3292.75 W 2736.39 S 3635.66 W 3009.67 S 3981.65 W 3311.47 S 4360.88 W 3587.70 S 4712.68 W 3500.0 78.21 234.47 3549.3 3600.0 75.56 234.31 3649.3 3700.0 76.44 234.47 3749.3 3800.0 77.20 232.30 3849.3 3885.8 78.95 228.98 3935.1 6410.2 .77 6431.8 232.8 6839.3 1.00 6918.0 232.9 7210.1 1.98 7304.5 233.0 7663.7 .48 7695.3 233.0 8086.6 .84 8087.1 232.9 3878.12 S 5104.40 W 4130.03 S 5452.10 W 4342.06 S 5756.86 W 4614.62 S 6119.57 W 4881.56 S 6447.63 W Final Station Closure: Distance: 8087.12 ft Az: 232.87 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: A0897GCE417 TOOL NUMBER: 777 MAXIMUM GYRO TEMPERATURE: 74.8C MAXIMUM AMBIENT TEMPERATURE: 28.8 C MAXIMUM INCLINATION: 81.50 AVERAGE AZIMUTH: 232.20 WIRELINE REZERO VALUE: N/A REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 2040 CALIBRATION USED FOR FINAL SURVEY: 2040 PRE JOB MASS BALANCE OFFSET CHECK: -.20 POST JOB MASS BALANCE OFFSET CHECK~: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.10 UPON ARRIVAL AT RIG: O.K. UPON COMPLETION OF SURVEY: O.K. UPON RETURN TO ATLAS O.K. BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 9873 78.87 229.6 3933 -4873 -6414 FINAL SURVEY 9900 78.95 228.9 3928 -4881 -6449 FUNCTION TEST JOB NUMBER: A0897GCE417 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 996 16.37 16.37 16.37 16.37 16.37 AZIMUTH M.D. ft I 2 3 4 5 996 228.16 228.19 228.25 228.20 228.21 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: A0897GCE417 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 777 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 767 GYRO SECTION DATA SECTION POWER SECTION A0169 C0111 C0112 A0160 C0089 C0086 COMPUTER A0349 POWER SUPPLY PRINTER A0079 INTERFACE A0143 COMPUTER A0222 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0085 A0107 WIRELINE COMPANY: CABLE SIZE: 7/32" SCHLUMBERGER RUNNING GEAR 2.25" HOUSING W/ECCENTRIC BAR TOTAL LENGTH OF TOOL :32' MAXIMUM O.D.: 2.25 INCHES TOTAL WEIGHT OF TOOL: 200 POUNDS ~{)~OHDN~ 0£ Nr'dfLL~I 01:01 L6/'vO/80 'XVQNOIAI 0g:Sl 00:LI g[:£I 0g:ZI 00:0[ glo:L0 0g:L0 00:1~0 00:£0 00:~0 L6/EO/gO'XVQN~S X~ONV,I.S 00:60 £6/~,O/80'XV~VS 00:81 0~:1~[ 0£:~[ 00:£[ 00:60 00:80 L6/IO/80'XV~ ZI, ff:IOc'JZ680V : M~ISWnN 8oF .LblOd:::i~! -IVOIDO-IONOblHO
