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Home My WebLink About209-128 STATE OF ALASKA • • AIDKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ N2 FCO 0 Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other:ESP Change Out ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development E Exploratory ❑ 209-128 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22734-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025518/ADL0028231 MILNE PT UNIT KR E-14A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): '► ', ,� l..... "1 N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: .,£? 7 t`t ` Total Depth measured 10,194 feet Plugs measured 10,105 feet true vertical 7,120 feet Junk measured 10,036 feet Effective Depth measured 10,100 feet Packer measured 8,745 feet true vertical 7,026 feet true vertical 6,764 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 5,543' 9-5/8" 5,543' 4,587' 5,750psi 3,090psi Production 8,954' 7" 8,954' 6,942' 7,240psi 5,410psi Liner 7' 3-1/2" 8,766' 6,782' 10,160psi 10,540psi Liner 306' 3-3/16" 9,065' 7,016' N/A N/A Liner 1,373' 2-3/8" 10,120' 7,024' 7,700psi 8,100psi 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 8,552' 6,601' Packers and SSSV(type,measured and true vertical depth) S-3 Packe N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A p � Treatment descriptions including volumes used and final pressure: N/A CANNED M(/�' 9 3 i'" 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 340 0 Subsequent to operation: 12 1.1 853 204 240 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas [, WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 316-563 • Authorized Name: Bo York Contact Name: Taylor WellmanT iJ Authorized Title: Operations Manager Contact Email: twellmanc hiIcorp.com Authorized Signature:" r f, ._,-- Dab 5/15/2017 Contact Phone: 777-8449 Form 10-404 R 'fed 4/2017 S.42-•/ Submit Original Only 0/ RBDMS G1/4-- MAY 1 9 2017 7 • • Milne Point Unit Well: MPU E-14A SCHEMATIC Last Completed: 4/25/2017 llilcorp Alaska,LLC PTD: 209-128 TREE/WELLHEAD Tree Cameron 2-9/16"5M Wellhead 11"x 7-1/16"SM FMC Gen 5A Ultra Slim,w/2-1/2"Tbg Orig.KB EIev=57.6'/Orig.GL Elev.=24.7'Nabors 27E Hgr,2-7/8":EUE 8rd T&B Thread,2-1/2"CIW BPV Profile OPEN HOLE/CEMENT DETAIL 20 :„ L 20" 250 sx of Arcticset I(approx.) in 24"Hole 0. 9-5/8"" 1750 sx PF'E',300 sx Class"G",89 sx PF'C in 12-1/4"Hole ,- 7" 250 sx Class"G"in 8-1/2"Hole 3.5"& 3-3/16" Not Cemented,4-1/8"Hole 1 2-3/8" 19 sx Class'G'in 3"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40 N/A Surface 112' N/A 9-5/8"" Surface 40/L-80/Btrc. 8.835 Surface 5,543' 0.0759 #' 7" Production 26/L-80/NSCC 6.276 Surface 8,954' 0.0383 3-1/2" Liner 9.2/L-80/ 2.992 8,759' 8,766' 0.0087 `x 3-3/16" Liner 6.2/L-80 N/A 8,766' 9,065' N/A 2-3/8" Liner 4.7/L-80/STL 1.995 8,747' 10,120' 0.00387 9 5/8 A TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 8,552' 0.00579 WELL INCLINATION DETAIL JEWELRY DETAIL KOP @ 900'MD No Depth Item Max Hole Angle 52 Deg.@ 5,953' 1 140' STA#2:CAMCO 2-7/8"x 1" Side-pocket w/DSOV Hole Angle Thru Perfs>31 Deg. 2 8,287' STA#1:CAMCO 2-7/8"x 1" Side-pocket w/DMY GLM Max DLS=4.8 @ 5,543' 3 8,398' XN Nipple ID=2.205"No Go 4 8,438' Discharge,Bolt on 2 7/8",8rd 400X,416/420 SS 5 8,439' Pump#1-Model:347125 6 8,461' Pump#2-Model:347125 7 8,483' Pump#3-Model:347125 8 8,505' Gas Separator-Model:600501 9 8,507' Upper Tandem Seal:BPBSL,Premium Seals,AR Bearings 10 8,516' Lower Tandem Seal:BPBSL,Premium Seals,AR Bearings 11 8,524' Motor:456 Series,FMS,240 HP/2975V/58A 12 8,548' Gauge WeIILift MGU 2 13 8,550' Centralizer:Bottom @ 8,552' MINID=2.205" @8,450 3 14 8,706' BOT PBR 80-47 Seal Nipple,ID=3.870" 15 8,745' BOT 7"x 4.5"S-3 Packer 4 16 8,747' BOT Deployment Sleeve w/Plug Holder Bushing, ID=3.70" 17 8,759' BTT'Oiler"Liner Hanger Assy,ID-3.750" e, A n'5,6&7 18 8,766' XO3-1/2"STL x3-3/16"TCII,I0=3.5" A 116 19 8,816' 4.5"XN Nipple w/plug, I0=2.750" (Hi ,8 20 8,889' 4.5"WLEG,Bottom @ 8,890' v 21 8,950' BOT 4.5"Whipstock 9&10 22 8,975' 7"CIBP 23 9,064.65' BTT Aluminum Bull Nose Shoe,Btm @ 9,065' 11 24 10,105' BOT Landing Collar,ID=2.394" i 25 10,120' 2-3/8"Unique Biased Edge Guide Shoe,ID=2.650" 12 PERFORATION DETAIL #)1 13 Kuparuk Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status a1� '15 9,500 9,560' 7,043' 7,044' 60 12/24/09 Open m-16 B7 9,660' 9,900' 7,045' 7,041' 240 12/24/09 Open 4 17 9,960' 10,050' 7,036' 7,032' 90 12/24/09 Open 18 20 19 Perforation Charge Detail:1.56"6SPF 1606P GENERAL WELL INFO API:50-029-22734-01-00 21 23 7"Cased Hole -4/12/1997 ESP Completion-5/8/1997&9/15/1997 4 � ESP Completion,screen added-7/19/???? i 25 RWO(2) -3/21/2000&6/28/2008 r 4 6 Pull ESP and install CTD work String-11/19/2009 TD=10,194'(MD)/TD=7,120'(TVD) CTD Sidetrack and ESP Completion-1/5/2010 PBTD=10,100'(MD)/PBTD=7,026(1VD) RWO w/Doyon-8/12/2012 ESP Completion-4/25/2017 Revised By:TDF 5/2/2017 • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR#1 50-029-22734-00-00 209-128 11/8/16 4/25/2017 tail erations:19' Mill, ' 1,, 11 j 11/9/26/2016-Wednesday Continue to move rig &equipment on to MP-14,spot change out trailer&company man office, spot well site trailer, move rig on to mud boat. Raise Derrick& pin, install tie down anchors to rig & mud boat, Set cat walk& rig up, Rig up all circulating hoses, kill &choke lines. Install Koomey lines to BOP, Insulate & heat trace lines,torque BOP connections up. �Q Connect gas alarms and test all good. (Accepted rig @ 17:00 hrs. on 11-9-16). Function test equipment, body Test BOP.(Bob Noble with AOGCC waived right to witness BOP Test @ 7:27 AM on 11-9-16).Well support Greased all Choke and Bop ' j5� Valves,Test all Valves Ibop and Tiw Valves to 250/3,000psi 5min Each,Test Annular 250/2,500psi 5 min each,Test with 2- 7/8"test Joint Record Accumulator Pre-Charge Pressures and Test Chart Test. Held Safety Sundry Meeting with Rig Crew went over E-14 Procedure. Well head Rep Tee Bar and Removed TWC Valve from Hanger. Make up Landing Joint RIH Make up in Tubing Hanger, BOLDS Pull Hanger at 69k, Max Pull to Release Packer with 115k Let Packer Elements Relax Try to Re- land Tubing Hanger,Taking weight unable to re-land Hanger, Pull Hanger to Rig Floor. Rig up to Circulate Blow air Through all Lines, Pump Down Tubing take returns to Flow Back Tank, Pumped lbpm at 1,000psi Tubing Pressured up with no Returns, Bleed off Pressure, Double check Valve Alignment(Good). Break out landing joint Blow down all Service Lines, Break out and Lay down Tubing Hanger,Tubing is full and is not Draining out the GLM at 8,355'. Halliburton Slick Line was Called out to Pull Dummy Valve From GLM at 2,760'. above the Tri-point Twin seal ESP Packer. Rig up Halliburton Slick Line RIH. 11/10/2016-Thursday RIH with slick line, pull dummy from GLM @ 2,760'. POOH with slick line, bleed tubing off from out of balance fluids, Rig down slick line unit. Rig up&Circulate down tubing through GLM @ 2,760'taking returns to flow back tank. Pumped 81 bbls, attempted to move ESP packer, packer is free on up stroke but will not go down. Rig up sheaves for ESP cable & Dual capillary lines.TOOH, pulling slow due to pulling ESP packer, lay down 2-7/8"tubing f/8,532'md to tripoint packer located at 5,743'md. Unable to circulate so pipe pulling greasy out of the hole. Disconnect capillary line from vent port and packer, as well as ESP cable. L/D packer and associated pups (rubber sealing elements damaged in the TOOH). P/U 1 jnt of 2-7/8" TBG tie off loose lines to jnt and lower until smooth section of TBG is across the annular element. Close annular and line up to circulate down the TBG taking returns to the flowback tank. Circulate the wellbore w/60bbI Baraklean pill followed by 220bbls of heated seawater. Pump @ 3.0bpm w/780psi for a total of 280bbls,taking returns to the flowback tank. Fluids cleaned up after 280bbls away. Continue to POOH w/ESP completion on 2-7/8" 6.5ppf 8rd TBG f/5,743'md to 3,900'md. (Pipe pulling much cleaner after ciruclation) 11/11/2016-Friday Continue to TOOH laying down 2-7/8"Tubing, recovered 266 joints,4 GLM5&X nipple,XN nipple. Lay down ESP assembly, Discharge head had formation sand in it. Rig down ESP & capillary line sheaves & ESP cable hose. Service Rig, change oil on Rig Generator& Rig Engine. (NPT)Oil change truck generator shut down, needed repair prior to completing oil change). P/U 7" scraper cleanout BHA w/30' mule shoe stinger and RIH to"'7,200'md. (NPT) Rig locked driller out of controls half way into the hole with joint of 2-7/8"TBG. Error code reading transducer failure in the elevators and power swivel.Trouble shoot and find loose connections. Clean and tighten electrical connection. System back online. Continue to RIH w/7" scraper cleanout BHA to 7,500'md. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR#1 50-029-22734-00-00 209-128 11/8/16 Future Daily Operations; 11/12/2016-Saturday Continue to TIH with clean out assembly F/7,200'T/8,683'. Rig up & Reverse circulate washing down F/8,683'T/8,725' Tagged up solid @ 8,725' Reverse circulate 3 Tubing bottoms up, 2 bpm @ 380psi. Monitor well, blow lines down.TOOH, laying down 2-7/8"Tubing, break connections on scraper assy. (NPT) Change break band on Power Tongs. P/U Baker PBR Seal Assembly,verify all tool specs and RIH on 2-7/8" 6.5#8rd EUE TBG f/surface to no-go @ 8,718'md (ASR KB), 21'md into JNT 278. P/U 21' and sting back into PBR seal nipple to verify no-go depth (same). L/D JNTS 278, 277, and 276. P/U 3 pup JNTS (8.25', 8.25', 10.41')followed by JNT 276 and the TBG hanger. M/U 2-7/8" landing JNT to TBG hanger and 5' mark theTBG hanger into the TBG spool (17.8'ASR KB). Land TBG hanger and RILDS. Wellhead hand Greg Ruge on location to RILDS. L/D landing joint, close blind rams and test TBG seals w/1,500psi pressure. 11/13/2016-Sunday Rig up to Annulus, pressure up to 1,000psi on seal assembly,good test. Install BPV, Release Rig @ 0700 hrs. on 11-13-16. Prepare for Rig move, blow down lines, empty out mud pit fluids, disconnect gas alarms, disconnect circulating lines, ND BOP to 4 bolts. Unpin Derrick,disconnect anchor lines, lay Derrick over, move Rig off mud boat. Remove rig floor with crane, remove well enclosure, ND BOP. NU production tree,test hanger void to 500/5000psi. Pull BPV. Secure wellhead. Pulled BPV. 11/14/2016 Monday No activity to report. 11/15/2016-Tuesday No activity to report. • • ska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A CTU 50-029-22734-00-00 209-128 11/8/16 4/25/17 Daily Operatioifis;�`° �.�n 1, 2/8/2017-Wednesday Arrive on location. Spot in equipment. RU HES AMU # 1 with 1.5" CT. Start BOPE test.Test all rams and valves to 250/ 3,500psi. Function test BOPE.Test good. Stack back for the night. Location secure. 2/9/2017-Thursday On loc. PJSM. Complete hardline RU. Dress end of CT to accept drift ball. Get on well with BOPE and injector. Fluid pack. Found and fix leaks on flowback iron. Replace chiksan. PT stack to 2,300psi -good. Load, launch and drift CT w/ 1" steel ball. Pump to end of CT. Land ball with 27.9 bbls 60/40 meth. Stand back injector. Cut off end of CT. Recover 1" steel ball. MU BHA#1- 1.5" OD ROC, DBPV, Wt Bar, 1.55" OD DJN. OAL= 6.73'. Pull test connector to 20k.Stab on well. PT low and high -225psi/3,648psi. Pump SSV open, install fusible. Displace 60/40 in CT out to recycle tank with 1%.KCL. Open well to 220psi SITP. IAP= 58psi/OAP =Opsi. RIH with BHA#1. Open choke after immediate WHP increase. Mantain 100psi WHP taking returns to tank. Continue RIH pumping 1% KCL at .5 bpm making Wt Cks every 2,500-3,000 ft.Wt Ck at 8,650' _ 16.3k, RIH Wt= 3.8k. SD pump and RIH to dry tag. Set down at 8,843.7' down/8,836' up.Swap to SLK 1% KCL with pipe lube. RBIH jetting with full returns. Clean out from 8,829'to 9,480' ctmd. Short trip to 9,000'. RBIH.Able to reach 1.6 bpm at 4,755psi CTP/110psi WHP. Start losing returns. Reduce ECD by dropping rate and WHP. Recover returns. Clean out from 9,480'to tag depth of 10,036' ctmd. PU (17.6k) and re-tag, same. Make short trip to 9,600'. Pump 5 bbl geI pill. RBIH to bottom. Pump gel sweep off bottom plus 5 bbls KCL behind. POOH at 60%chasing returns at 1.2 - 1.3 bpm/2,800psi CTP/ Opsi WHP.Swap to 60/40 down coil at 5,000'. 60/40 at nozzle at 2,200'. Pull to surface. SD pump at 50' from surface. Perform swab checks every 12' until coil is above swab valve. With coil at surface, SI swab. Remove fusible and close SSV. Well secure. Blow down . RD off well. Remove P-sub. Lay down mast. Move CTU away. Wellsite assessment. End job. 2/10/2017- Friday No activity to report. 2/11/2017-Saturday No activity to report. 2/12/2017-Sunday No activity to report. 2/13/2017- Monday No activity to report. 2/14/2017-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR1 50-029-22734-00-00 209-128 11/8/16 4/25/17 Daily Operations: ~r' 3/1/2017-Wednesday No activity to report. 3/2/2017-Thursday No activity to report. 3/3/2017- Friday No activity to report. 3/4/2017-Saturday No activity to report. 3/5/2017 -Sunday Northern Energy Services, Crane on Location Assisting in Hoisting and Removing old Traveling Racks, F/Derrick and Installing New Traveling Racks, Install Carrier and Equipment into Derrick, Mounted Test Recorder in Choke House, Function Test Steam Heater in Cellar and Rig Floor Fix Leaks in Piping, Install and Nipple up Manual and Hydraulic Choke Valve on Mud Cross, Install Service Loop Hose in Derrick.;Continuing Digging Rig Equipment out after Snow Storm, Halliburton Wire Doing Prep Work for the ASR Rig on E-14A Removing dummy Valve F/GLM at 8,600 ft. Conduct Static Test at 8,640ft F/15 Min, and 7,640FT. F/15 min Retrieve a Bottom Hole Temp at 8,650 ft. at 3,017 psi With a kill weight Fluid of 8.8 ppg 3/6/2017- Monday Operations on MPE-14A with Little Red Services Pumped Total of 500 bbl. of 9.0 ppg Brine at 4 bpm with a FCP of 750 psi, Total Returns to Flow Back Tank=365 bbl.Total Loss=135 bbl. Pump 15 bbl. 60/40, ( Finished Well Kill OPS at 1400 hrs.) (Northern Energy Trucking on Location at 1200 hrs.) Rig Move F/MPA-Pad to MPE-14A;Sundry Pre Spud Safety Meeting on MPE-14A with Safety Rep Kacey Bond, Mark O'Malley, Stan Porhola,ASR Rig Crew,Tool Pushers, Company Man;Finish Rig Move F/MPA-Pad to MPE-14A (Released Trucks at 2200 Hrs.};Roads and Pads Level Location around Well Head, Set and Place Matting Boards,;Install Horse Shoe Scaffolding Around Well Head, Well Head Rep Greg Ruge on Location Tee Bar and Install BPV;Nipple Down Tree Check Travel on Lock Down Screws, and Lifting Threads on Tubing Hanger, Nipple up Bope Stack, 3/7/2017-Tuesday Finish Nipple up Bop'e Stack,Torque Up all Connections, Hoist Rig Floor and Place on Top of Well House, Hoist up and Level Well House Base, Hoisted Rig Tongs and Rig Equipment on Rig Floor, Spot Rig on Mud Boat, Spot Pit Module, Lift and Rig up Stairs to Rig Floor, Spot Well House Trailer, Spot Drill Cuttings Tank, Spotted Tool Connex;Raise Derrick Scope top Section and Pin, Hoisted Rotating Swivel to Rig Floor and Rig up on Carrier in Derrick, Rigged up Hydraulic Elevators, Move and Spot Certek Heaters into Place and Rig up, Pro Star Tec Trouble Shoot and Connect New Equipment into Service, Spot Cat Walk Rig up Hydraulic Lines to Bope Stack and Accumulator,;Rig Generator Running Poorly, Regen Air Code Readings and Exhaust Coolant Air Code Keeps Popping Up,VMS Shop Was Called Ammos was Dispatch out to Location, diagnose and Trouble shoot Codes, Continued Rigging up Lines and Equipment, (AOGCC Guy Cook was e-mailed bop testing will be Delayed about 12 Hrs. on 3-8-17 at 0515hrs.) • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR1 50-029-22734-00-00 209-128 11/8/16 4/25/17 Daily Operations: 3/8/2017-Wednesday Continue Rigging up Equipment with Pro Star Tec,Trouble Shoot Heater Glycol System, Electrician Brandon on Location Rigged up and Test Gas and Fire Alarms in Cellar, Rig Floor and Pit Module. Attempt to pull BPV. Discovered ice blockage above hanger. Wrap BOP stack in cellar and bring 2 heaters in to thaw ice plug (AOGCC was Notified of bop Inspection on 3-6-2017 at 15:09 hrs.) Continue to RU ASR 1. Observed noise from drive box area. Inspect drive box and discovered that the bearing was bad on the Durst Drive Box (This is another drive box coming off of the driveline that runs 4 hydraulic pumps). Disassemble hydraulic lines, etc. under rig to enable removal of drive box for replacement. Replaced Durst Drive Box, Continue Installing in Rig Carrier( Pit Module Generator Idler Pulley Broke off Engine at 0230hrs.) 3/9/2017-Thursday No operations to report. 3/10/2017- Friday No operations to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR 1 50-029-22734-00-00 209-128 11/8/16 4/25/17 Daily O ' rations: 4/19/2017 -Wednesday No activity to report. 4/20/2017 -Thursday No activity to report. 4/21/2017 - Friday Remove snow from rig equipment on A pad and on E pad. Place heating units on BOPE/wellhouse to warm stack in preparation for testing. Mobilize pit trailer, Doghouse, and WSM trailer,from A pad to E pad and spot all three in place. Spot catwalk into working position. Begin to R/U BOPE hydraulic lines from accumulator unit to stack. Prostar Rep Dan Kusler on location to verify system functionality.AOGCC BOPE test notification given @ 23:00 4/20/17. Rep Charles Scheve requested update of test time so he can witness. Complete bolting up suction screens upstream of charge pumps 1 and 2. Peak truck offload 290bbls of 8.9+ppg brine into pits in prep for circulation. Complete R/U of hydraulic lines on BOPE stack. Hilcorp Electricians on location to R/U and test fire and gas monitors. Wellhead Rep Greg Ruge on location to pull BPV. Small gas breakout as BPV was released. Well out of balance but not enough for pressure to register on gauge. Perform well Sundry meeting w/ night crew. R/U Certek glycol heating lines throughout rig. R/U to circulate out freeze protect from wellbore and kill well in the process. Hilcorp Electricians complete fire and gas monitor testing. R/U to circulate down the IA w/the centrifical pump and charge pump to allow well imbalance to level out. Pump 10bbls down the IA taking returns up the TBG to the flowback tank.After 10bbls away mud weight= 7.5ppg. Decision to stop and get main rig pump up and running prior to pumping any further. Continue to wrap glycol heating lines within tarp covers throughout the rig. Blow down circulation lines and prep to circulate freeze protect out of well utilizing rig pump. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR 1 50-029-22734-00-00 209-128 11/8/16 4/25/17 Daily Operations: z;�' 01-7 4/22/2017 -Saturday RU and circulate down tubing taking returns out to Flow back tank. Pumped 60 bbls(tubing volume = 50 bbls). w/34 bbls returned. Shut down and monitor well f/ 10 min. Static. SIMOPS: Continue to RU Catwalk, Pipe Racks, etc. Wellhead Rep installed TWC. RU to test BOPE. SIMOPS: Prostar Rep. continue to test/troubleshoot new components Perform BOPE "Pre Test" prior to calling AOGCC out for witness.Test all equipment using 2-7/8" test joint to 250 psi low, 3,000 high for 1/2 to 1 minute.Test Annular to 250, 2,500.Tighten up multiple connections that were leaking.At 12:00 hrs, call AOGCC Rep. Chuck Scheve and request for him to come out. NOTE: Original notification was given via AOGCC Website at 23:00 hrs on 4/20/17. AOGCC Rep. Chuck Scheve &Adam Earl arrived location. Discuss Sundry and begin testing per ASR 1 procedure and AOGCC Sundry.Test all equipment using 2-7/8" test joint.Test all equipment to 250 psi low, 3,000 psi high.Test annular to 250 low, 2500 high.All tests charted and held for 5 minutes each. RD test equipment. Check for pressure. Wellhead Rep pull TWC. PU 2-7/8" landing joint and engage hanger. BOLDS. Pull hanger free and pull same to Rig Floor w/ 53k up wt. LD hanger w/ pup. LD 1 joint of tubing and 3 space out pups. Continue to POOH w/2-7/8" 6.5#TBG f/8,714'md t/^'7,100'md. Dig production tree out from snow drift behind well house. Hydraulic fitting on catwalk side of carriage, located between the back of the derrick and the back of the carriage, caught on service loop while lowering the carriage and broke off. Hydraulic fluid leaked into containment. Shut down hydraulic system and create plan to fix leak. Decision to raise the carriage in the derrick to a height where the paneling on derrick can be removed to access the broken hydraulic fitting. Drive manlift over from B-pad and position in place to access derrick. Remove exterior derrick panel 3/4's of the way up the derrick to access broken fitting. Replace hydraulic fitting.Tie back loose hydraulic lines located at the top of the service loop, in order to prevent hydraulic fittings from catching in the future. Warm up hydraulic system after long shut down period. Continue to POOH w/2-7/8" 6.5#TBG f/^'7100'md to—4600'md 4/23/2017-Sunday Continue to POH w/2-7/8" completion f/4,600'to 1,900' (59 joints in hole).Shut down operations to replace a bad 0-ring in the High Pressure filter on the Hydraulic Pump. 0-ring failed and leaked hydraulic oil into containment pan under Hyd. Pump (<1 gallon). Notifications were made to Environmental. Continue to POH LD 2-7/8" completion f/ 1,900'to surface. Recovered Seal Assembly. LD same. Clear Rig floor. RU to run Summit ESP completion. Hang sheaves,feed ESP cable through same. Spot Summit ESP assembly on catwalk. Feed 3/8" cap line through sheaves to Rig Floor. PU 456 Series Motor to Rig Floor and service same while continuing to RU. Install MLE and secure same to motor. Continue to M/U and service Summit ESP as per procedure. RIH w/Summit ESP completion on 2-7/8" 6.5ppf, EUE tubing f/surface to 1000'md. M/U TBG to 2200 ft-lbs TQ.Test ESP cable every 500'md until we reach 2000'md depth and then test ESP every 2,000'md thereafter. Continue to RIH w/ Summit ESP completion on 2-7/8" 6.5ppf, EUE tubing f/ 1000'md to''3,400'md. M/U TBG to 2200 ft-lbs TQ.Test ESP cable every 500'md until we reach 2,000'md depth and then test ESP every 2,000'md thereafter. 4/24/2017 - Monday • 4 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR 1 50-029-22734-00-00 209-128 11/8/16 4/25/17 Daily Operations: A' # �a �s3�a 4/24/2017 - Monday Continue to RIH w/ ESP completion on 2-7/8" 6.5# L-80 EUE tubing f/3,400'to ±5,030'.Test cable conductivity every 2,000'.Splice ESP Cable. Continue to RIH w/ ESP completion f/5,030' to 8,300'.Test cable conductivity every 2,000'. Continue to RIH w/ ESP completion f/8,300' and to 8,500'md.Test cable conductivity every 2,000'. P/U and M/U hanger. Measure and mark ESP cable for proper length back to penetrator. Cut ESP cable and begin ESP cable to cable splice. SIMOPS: LRS on well E-04 to pump kill. Bleed off 650psi from IA back to tiger tank. Line up and pump 50bbls of 120deg seawater down TBG, followed by 240bbls down the IA. Well on a vac. Summit ESP reps on hand to perform cable to cable splice. Wellhead hand Greg Ruge on location to inspect and align hanger as well as cap off capillary line through the hanger. Prep well E-04 for rig arrival, spot half mats around well, place mud boat on rig matting. Land TBG hanger in wellhead, RILDS, L/D landing joint, and set BPV in TBG hanger. Prostar rep Dan Kusler on location to adjust rig parameters for smoother functionality. Begin R/D operation. N/D BOPE riser and prep BOP for removal. Blow down all fluid lines and prep mud pits for move to E-04. R/D Certek heating unit, unwrap all glycol lines and remove from tarp covers. NES on location to assist in rig move. Move ESP spooling unit to the side of location.Summit and Baker Centrilift on location to swap out ESP spools from unit. NES move mud pits from E-14A to E-04 and spot in place. Remove service loop rubber guard material from service loop. Clean rig to ensure no hydraulic oil is able to leave containment when rig is moved. Prep rig floor and BOPE for removal on E-14A. 4/25/2017-Tuesday Continue to R/D on well E-14A and R/U on well E-04. Continue to clean rig carrier of any potential contaminant prior to leap frogging unit from mud boat on E-14A to mud boat on E-04. Move rig carrier from E-14A to E-04 and spot on mud boat. Place all storage sea cans in position on E-04. N/D BOPE and N/U production tree on E-14A. Release from well E-14A @ 12:00pm 4/25/17. • oF� ,& THE STATE Alaska Oil and Gas �►;,"�� 0 L A S 1A Conservation Commission � s } 2_== 1_ 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 . ' P Main: 907.279.1433 A IC Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED FEB 2 8 201 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR E-14A Permit to Drill Number: 209-128 Sundry Number: 316-563 Dear Mr. York: 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, ze)/( Daniel T. Seamount, Jr. Commissioner DATED this 7 day of November, 2016. • RBDMS ttv NOV - 8 Zui • �, 110 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 1 2016 APPLICATION FOR SUNDRY APPROVALS Cr AAC 25.280 -' 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ?1Z rcV Hilcorp Alaska LLC • Exploratory 0 Development ❑✓ . 209-128 3.Address: 6.API Number: Stratigraphic ❑ Service ❑ 3800 Centerpoint Dr,Suite 1400 50-029-22734-01-00 ' 7. If perforating: . 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.432 Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT KR E-14A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518/ADL0028231 MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): '10,194' . 7,120' 10,100' , 7,026' 2,041 10,105' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' Surface 5,543' 9-5/8" 5,543' 4,587' 5,750psi 3,090psi Production 8,954' 7" 8,954' 6,942' 7,240psi 5,410psi Liner 7' 3-1/2" 8,766' 6,782' 10,160psi 10,540psi Liner 307' 3-3/16" 9,073' 6,222' N/A N/A Liner 1,373' 2-3/8" 10,120' 7,024' 7,700psi 8,100psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic• See Attached Schematic 2-7/8" 6.5#/L-B0/EUE 8rd 8,559 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): S-3 Packer and N/A . 8,745 MD/6,764 ND and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development El . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 11/15/2016 Commencing Operations: OIL El . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved 4 d 7009 herein will not be deviated from without prior written approval. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name I Bo York Title Operations Manager � /31b4, _ v / Signature . (�� U r�C Phone 777-8345 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 2D\LIZ.'-'4)Ct02 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance Other: 3coo rs . &P -7 C5 t 5'Dv jpS, n t 7 - f- RBDMS Liz NOV - 8 2816 Post Initial Injection MIT Req'd? Yes ❑ No. ❑ Spacing Exception Re uire ? Yes El No0. Subsequent Form Required: /0— y 0 41 —4=1( APPROVED BY Approved by:/C)14--- COMMISSIONER THE COMMISSION - Date: /1/ 7/i Submit Form and Form 10-40Revised 11/20�11�5�•�, RI°C p ti valid for 12 months from the date of approval. . Attachments in Duplicate ® ii_ 7-44, • Well Prognosis Well: MPU E-14A Hilcorp Alaska,LI) Date:10/29/2016 Well Name: MPU E-14A API Number: 50-029-22734-01 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: November 15, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 209-128 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,702 psi @ 6,610'TVD (From ESP Gauge 10/28/16; EMW= 7.86 ppg) Maximum Expected BHP: 2,702 psi @ 6,610'TVD (No new perfs being added, but possible C/O) Current Shut-In Tbg Pressure: 10 psi (ESP Packer in well.) Max. Predicted Surf Pressure: 2,041 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU E-14A was side tracked with a coiled tubing unit in January of 2010 and completed in the Kuparuk River formation. Since that time, three ESP units have been run in the well. The most recent pull and run was in March 2016. The well on March 22, 2016 passed a casing pressure test of 2,000 psi for 30 minutes. After the well was placed back on production, it produced for 1-1/2 months and then quit surfacing fluid. The ESP is still intact electrically. Possible causes are a hole in the tubing or a plugged lateral. Objective: The purpose of this work is to use the ASR# 1 rig to pull the existing completion, diagnose and remediate the problem and run a new ESP. There will be a decision point in the workover whereby if it is determined that the coil tubing drilled lateral is plugged,then a coil tubing unit will be brought in and the lateral cleaned out. Alag; Hilcorp is not planning on re-running an ESP packer in this well due to the EMW being below 8.5 PPG (CO k390A). Hilcorp will confirm the EMW if a Clean out is performed on the well. If the EMW is above 8.5PPG at✓ that time,we will re-run the ESP Packer in the well. 11� ,,i+ Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump.Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Forward circulate at least one wellbore (annular)volume with 8.5 ppg sea water down the tubing (thru open GLM pocket),taking returns up the annulus to the 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services Pump and reverse out skid. 8. RU crane.Set BPV. ND Tree. NU 11" BOPE. RD crane. 9. NU BOPE house.Spot mud boat. S ! . Well Prognosis Well: MPU E-14A Hilcorp Alaska,LD Date: 10/29/2016 WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. 11. Pull BPV. Bleed any pressure off tubing and casing. 12. Kill well w/8.5 ppg seawater as needed. Set TWC. ' '2-51)-D 13. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8"test joint. r14. 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. 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 .k5� 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. 15. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 16. MU 2-7/8" landing joint(EUE) and BOLDS. 17. Pull over string weight(approx.55k PU)on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 18. Pull over string weight 40,000 pounds to release ESP packer. 19. POOH with the ESP completion. •--'? LA-re-0- , 5 (-4,1-• pet- a. Note: Carefully inspect the 4 GLM's in this well and confirm that all dummy valves are properly seated. b. Note: Observe for any possible holes in the tubing string. c. Note depth and take samples of any scale or solids deposits found. d. Note: Inspect vent valve and packer and insure that they are functioning properly. e. Report any abnormalities to Ops Engineer. 20. MU 7" casing C/O Assembly and RIH w/WS. 21. C/O 7" 26#casing down to+/-8,706' MD (BOT S-3 Packer PBR). 22. Observe well. Fill hole and pressure up and establish PIR at 500, 1,000 and 1,500 psi. Shut down and record falloff pressure at 0, 5, 10, 15 min intervals. li 23. Consult with the Ops Engineer. If PIR is sufficient,go to step #38. Otherwise,go to step 24. 24. POOH with casing scraper.PU Locater and-entry-stinger-for BOT-PBR-80-47-Seal-Nipple located at 8,706' MD. RIH w/same and sting into PBR. • • Well Prognosis Well: MPU E-14A EIMaya Alaska,LU . FC-C)-C) Datee: 10/29/200 16 25. Freeze protect and hang off tubing. Insert TIW valve and secure for Coil tubing clean out. 26.,RDMO ASR#1 workover rig. 27. MIRU Coil unit. Notify AOGCC 24 hours prior to testing BOP. 28. Pressure Test BOPE to 250psi low/3,500psi high. Fill out state BOPE test form and submit within 5 �' days. 29. Make up coil connector pull test 25k. Make up Cleanout BHA with nozzle or MHA and extended �y reach vibratory tool. RIH WI Coil. Note: Min ID is 2.750" (XN Nipple @ 8,816'). 30. Start cleaning out fill from 8,889'to 10,000'. Come online with 2%safe lube if needed. This should aid with metal to metal friction. 31. Come online with N2 at 800-1500 scf/min and fluid rate of 1.5 bbls/min . Cleanout to 10,000' MD. Adjust N2 and fluid rate accordingly. Watch returns. Ensure return tanks is strapped to ensure 1:1. Adjust rates accordingly. 32. Once PBTD or max coil depth is reached continue to circulate bottoms up. 33. Start POOH . Come offline with N2 and fluid. Bleed N2 down . POOH with coil tubing. 34. RDMO Coil Unit. 35. MIRU ASR#1 Rig. 36. Test BOPE to 250 psi Low/3,000 psi High,annular to 250 psi Lowpsi High. (Note: Notify AOGCC 24 hrs in advance of BOP test.) 37. Bleed off pressure, insure the well is dead. NOTE: Nitrogen may be present. Hold safety briefing with the crew as to the importance of proper ventilation and insure monitors are in place. �.4A, s(..�:7 �L �S� �i,� - 38. Circulate well with kill fluid. Monitor well and calculate'new EMW. Discuss with Ops Engineer. If new EMW is less than 8.55 ppg,then an ESP packer is not needed. If Calculated EMW is greater than EMW, prepare to run ESP packer in completion. it),; = J) ri-tki 39. POOH with WS. 40. RU spoolers, PU RIH with new ESP completion on 2-7/8"tubing. `"` a. Set base of ESP at+1-8,555' (Pump intake around+/-8,520'). Land Tubing. Note PU (Pick Up)and SO (Slack Off)weights on tally. 41. RU Pump Truck. Freeze Protect down back side (+/-55 bbls.to 2,000'). 42. If a packer is required, Drop ball and Rod,Pressure up on tubing to 3,500 psi.to set packer. Hold 3,500 psi for 1 hour on chart. If packer is not needed,go to step#45. 43. Bleed off tubing pressure to tank. 44. Line up pump truck and pressure test back side to 1,500 psi for 30 min. on chart. 45. Land tubing hanger. RILDS. Lay down landing joint. 46. Set BPV.Test tubing hanger to 250/5,000 psi thru test port. 47. RD Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 1. RU SL and Pump Truck. Pull Ball and rod and Freeze Protect Tubing. ( If packer was ran.) 2. RD mud boat. RD BOPE house. Move to next well location. 3. RU crane. Pull BPV.Set TWC. ND BOPE. 4. NU existing 2-9/16" 5,000#tree.Test tree to 250/5,000 psi. Pull TWC. RD crane. 5. Move 500 bbl returns tank and rig mats to next well location. 6. Replace IA pressure gauge if removed (7"). 7. Turn well over to production. RU well house and flowlines. Attachments: • Well Prognosis Well: MPU E-14A lilcorp Alaska,Lb Date: 10/29/2016 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Nitrogen Procerdure 9. Nitrogen Flow diagram 10. Coil BOPE Schematic 11. Blank RWO Changes Form II 411 Milne Point Unit • Well: MPU E-14A SCHEMATIC Last Completed: 3/24/2016 Hi!corn AInakn,LLC PTD: 209-128 TREE/WELLHEAD OPEN HOLE/CEMENT DETAIL Tree Cameron 2-9/16"5M 20" 250 sx of Arcticset I(approx.) in 24"Hole 11"x 7-1/16"5M FMC Gen 1750 sx PF'E',300 sx Class"G",89 sx PF'C' 9-5/8"" Orig.KB Elev=57.6'/Orig.GL Elev.=24.7'Nabors 27E 5A Ultra Slim,w/2-1/2"Tbg in 12-1/4"Hole • Wellhead Hgr,2-7/8":EUE 8rd T&B 7" 250 sx Class"G"in 8-1/2"Hole ki 4 Thread,2-1 2"CIW BPV / 3.5"& 3-3/16" Not Cemented,4-1/8"Hole lk 20 t" Profile 2-3/8" 19 sx Class'G'in 3"Hole '# CASING DETAIL 11 f 1 b vent cap Size Type Wt/Grade/Conn ID Top Btm BPF u �„; String y ,. 20" Conductor 91.1/H-40 N/A Surface 112' N/A ' 9-5/8"" Surface 40/L-80/Btrc. 8.835 Surface 5,543' 0.0759 7" Production 26/L-80/NSCC 6.276 Surface 8,954' 0.0383 3-1/2" Liner 9.2/L-80/ 2.992 8,759' 8,766' 0.0087 2 3-3/16" Liner 6.2/L-80 N/A 8,766' 9,065' N/A 3 o 2-3/8" Liner 4.7/L-80/STL 1.995 8,747' 10,120' 0.00387 4 TUBING DETAIL l' 5 tv 3/8" Vent Cap String 2205 Stainless Steel N/A Surf 2,823' N/A 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 8,566' 0.00579 T5/8" if " 3/8" Cap String 2205 Stainless Steel N/A Surf 8,566' N/A WELL INCLINATION DETAIL JEWELRY DETAIL Cap String . KOP @ 900'MD No Depth Item Max Hole Angle 52 Deg.@ 5,953' ( 1 142' STA#4:2-7/8"x 1"Mana GLM w/BK-2 top Latch [ Hole Angle Thru Perfs>31 Deg. 2 2,760' STA#3:2-7/8"x 1"Mana GLM w/BK-2 top Latch Max DLS=4.8 @ 5,543' 3 2,823' Tripoint Twin Seal ESP Packer w/Weatherford Vent Valve 4 2,835' X Nipple-ID=2.312" 5 2,877' STA#2:2-7/8"x 1"Mana GLM w/BK-2 top Latch 3i 6 8,355' STA#1:2-7/8"x 1"Mana GLM w/BK-2 top Latch 7 8,466' XN Nipple ID=2.310"No Go 8 8,508.9' Discharge Head:GPDIS 9 8,509' Pump:161P11/PMSXD 10 8,531' Gas Separator:GRS FER N AR 11 8,534' Upper Tandem Seal:GSB3DB SB/SB PFSA 12 8,541' Lower Tandem Seal: GSB3DB SB/SB PFSA 13 8,548' Motor:MSP3-250-168hp/3,460V/30A Min ID=2.310 6 14 8,562' Sensor:WeIILIFT @8.466' x 15 8,564' Centralizer:Bottom @ 8,566' , 7 •e 16 8,706' BOT PBR 80-47 Seal Nipple,ID=3.870" s A to 8 17 8,745' BOT 7"x 4.5"S-3 Packer GENERAL WELL INFO 18 8,747' BOT Deployment Sleeve w/Plug Holder Bushing, ID=3.70" I. f 9 API:50-029-22734-01-00 19 8,759' BTT'Diler"Liner Hanger Assy,ID-3.750" 7"Cased Hole -4/12/1997 20 8,766' XO 3-1/2"STL x 3-3/16"TCII,ID=3.5" ,4 iii410 ESP Completion-5/8/1997,9/15/97 21 8,816' 4.5"XN Nipple w/plug, ID=2.750" v lir a= ESP Completion,screen added-7/19/???? 22 8,889' 4.5"WLEG,Bottom @ 8,890' a," $111&12 tl NE *; RWO(2) -3/21/2000&6/28/2008 23 8,950' BOT 4.5"Whipstock 1 Pull ESP/Install CTD work String-11/19/2009 24 8,975' 7"CIBP g" CTD Sidetrack and ESP Completion-1/5/2010 25 9,064.65' BTT Aluminum Bull Nose Shoe,Btm @ 9,065' 13 RWO w/Doyon-8/12/2012 26 10,105' BOT Landing Collar,ID=2.394" gii . 14 ESP Changeout w/ASR-3/24/2016 27 10,120' 2-3/8"Unique Biased Edge Guide Shoe,ID=2.650" 31 €15 PERFORATION DETAIL 11 16 lr *, ' , 17 Kuparuk Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status R 18 '1. 9,500 9,560' 7,043' 7,044' 60 12/24/09 Open v. 20 1, B7 9,660' 9,900' 7,045' 7,041' 240 12/24/09 Open Nk 22 21 9,960' 10,050' 7,036' 7,032' 90 12/24/09 Open AJ Perforation Charge Detail:1.56"6SPF 1606P 0 23;t' 25 24, . 441 14, 27 41 7"v TD=10,194'(MD)/TD=7,120'(TVD) PBTD=10,100'(MD)/PBTD=7,026(TVD) Revised By:TDF 5/18/2016 . Ei • • Milne Point Unit Well: MPU E-14A PROPOSED Last Completed: 3/24/2016 Mean)Alaska,LLC PTD: 209-128 TREE/WELLHEAD OPEN HOLE/CEMENT DETAIL Tree Cameron 2-9/16"5M 20" 250 sx of Arcticset I(approx.) in 24"Hole 11"x 7-1/16"5M FMC Gen 1750 sx PF'E',300 sx Class"G",89 sx PF'C' 9-5/8" Orig.KB Elev=57.6'/Orig.GL Elev.24.7'Nabors 27E 5A Ultra Slim,w/2-1/2"Tbg in 12-1/4"Hole Wellhead Hgr,2-7/8":EUE 8rd T&B 7" 250 sx Class"G"in 8-1/2"Hole r Thread,2-1/2"CIW BPV 3.5"& 3-3/16" Not Cemented,4-1/8"Hole 2D± Ir+ Profile 2-3/8" 19 sx Class'G'in 3"Hole k4 44 CASING DETAIL li Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H40 N/A Surface 112' N/A 9-5/8"" Surface 40/L-80/Btrc. 8.835 Surface 5,543' 0.0759 7" Production 26/L-80/NSCC 6.276 Surface 8,954' 0.0383 3-1/2" Liner 9.2/L-80/ 2.992 8,759' 8,766' 0.0087 3-3/16" Liner 6.2/L-80 N/A 8,766' 9,065' N/A kol +w 2-3/8" Liner 4.7/L-80/STL 1.995 8,747' 10,120' 0.00387 r TUBING DETAIL ' a 3/8" Vent Cap String 2205 Stainless Steel N/A Surf ±2,823' N/A 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf ±8,566' 0.00579 9-5/8"11 3/8" Cap String 2205 Stainless Steel N/A Surf ±8,566' N/A WELL INCLINATION DETAIL JEWELRY DETAIL Cap String KOP @ 900'MD No Depth Item Max Hole Angle 52 Deg.@ 5,953' 1 ±8,466' XN Nipple ID=2.310"No Go Hole Angle Thru Perfs>31 Deg. 2 ±8,508.9' Discharge Head:GPDIS Max DLS=4.8 @ 5,543' 3 ±8,509' Pump:161P11/PMSXD 4 ±8,531' Gas Separator:GRS FER N AR 5 ±8,534' Upper Tandem Seal:GSB3DB SB/SB PFSA I 6 ±8,541' Lower Tandem Seal: GSB3DB SB/SB PFSA 7 ±8,548' Motor:MSP3-250-168hp/3,460V/30A 8 ±8,562' Sensor:WeIILIFT 9 ±8,564' Centralizer:Bottom @±8,566' 10 8,706' BOT PBR 80-47 Seal Nipple,10=3.870" 11 8,745' BOT 7"x 4.5"S-3 Packer 12 8,747' BOT Deployment Sleeve w/Plug Holder Bushing, ID=3.70" 13 8,759' BTT'Diler"Liner Hanger Assy,ID-3.750" Min ID=2_ 14 8,766' XO 3-1/2"STL x 3-3/16"TCII,ID=3.5" @8,466 15 8,816' 4.5"XN Nipple w/plug, ID=2.750" 16 8,889' 4.5"WLEG,Bottom @ 8,890' 2 17 8,950' BOT 4.5"Whipstock 18 8,975' 7"CIBP ,'3 19 9,064.65' BTT Aluminum Bull Nose Shoe,Btm @ 9,065' 20 10,105' BOT Landing Collar,ID=2.394" III 4 21 10,120' 2-3/8"Unique Biased Edge Guide Shoe,ID=2.650" 5&6 PERFORATION DETAIL Kuparuk Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ,.,7 9,500 9,560' 7,043' 7,044' 60 12/24/09 Open B7 9,660' 9,900' 7,045' 7,041' 240 12/24/09 Open 8 9,960' 10,050' 7,036' 7,032' 90 12/24/09 Open Ii 9 Perforation Charge Detail:1.56"6SPF 1606P 10 ;_°_ ; 11 GENERAL WELL INFO - 12 "b API:50-029-22734-01-00 >* 14 sr 7"Cased Hole -4/12/1997 16 ' 15 ESP Completion-5/8/1997,9/15/97 ESP Completion,screen added-7/19/???? RWO(2) -3/21/2000&6/28/2008 Pull ESP/Install CTD work String-11/19/2009 17 19 CTD Sidetrack and ESP Completion-1/5/2010 18, Liber 0 RWO w/Doyon-8/12/2012 21 ESP Changeout w/ASR-3/24/2016 7"A I TD=10,194'(MD)/TD=7,120'(1VD) PBTD=10,100'(MD)/PBTD=7,026(TVD) Revised By:TDF 10/31/2016 • Mie Point 2016 ASR Rig 1 i t . Knight Oil Tools BOP Mem?Alsika. aw.. Stripping Head f i Shaffe114 „Air _ 5000 quit filth TULL LEL 17,U1' • 27/8" -5" VBR c -u =EP 11" 000 1111141°15A111" Blind 2" Kill Line 2" Choke Line itrisminarrai ecc ° E Li 4( ; Manual Manual Manual HCR Updated 2/29/16 . MPU E-14A EXISTING TREE/WELLHEAD Welihead/Tree xili Alaska,r.a,c Milne Point Unit Tree Cap Tree Valve 2-9/16" 5M o `' -al 0 in'Mgu! i e 7 - , O Tree Cross 2-9/16" 5M (®(o)o Tree Valve 2-9/16" 5M SSV 2-9/16" 5M O Alier.o�li. 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J m 2 2 -I H 1— ..n >,- v, 1— F. H H -NJ-- -NJ- -N- --f*J- -I I-— I a a c-- • I STANDARD WELL PROCEDURE lIileirp:�Inka. IJ( NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • I I = _ m m c mot" m 'O > Y .�7-. § O ? N cd L 5 ... ...•:,- r°"2 o j , U O U c id H w C W C W re `� 'o 71 d ¢�� 4�� .. .. .... w > 0.1 a UwC� 333 as 333 as '(w"�� . Ix W LL W LL 1, H a G L O Y Z —i— �j�i D Q > no W G ° N Q • 5 �o > , To F F a U ? 7 r Z • Z C7 _>. ° °> P. is r r • 'O w c w t U NMI A c LLr V 1141111116 7-7 € i 1110 II MN 1111 MI»:i 4, ` `r ,'„E. O O W Y N Z Wa W LL � C. 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O0 T3 , a) O co ,-4 O m E occ d 6 Y d Q CL t1/3 •,-i ...: V o in rn' ¢ 3 Q a LI a) OF E AKA OIL AND G STCONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 2 2 2016 1.Operations Abandon LJ Plug Perforations LI Fracture Stimulate ❑ Pull Tubing ❑✓ ?` ns shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing s Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ ESP Change-out ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: v.)/,Q,,Sc-r` Hilcorp Alaska LLC Development s Exploratory ❑ 209-128 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22734-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025518/ADL0028231 MILNE PT UNIT KR E-14A 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 10,194 feet Plugs measured 10,105 feet true vertical 7,120 feet Junk measured N/A feet Effective Depth measured 10,100 feet Packer measured 2,823&8745 feet true vertical 7,026 feet true vertical 2,714&6764 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 5,543' 9-5/8" 5,543' 4,587' 5,750psi 3,090psi Production 8,954' 7" 8,954' 6,942' 7,240psi 5,410psi Liner 7' 3-1/2" 8,766' 6,782' 10,160psi 10,540psi Liner 307' 3-3/16" 9,073' 6,222' N/A N/A Liner 1,373' 2-3/8" 10,120' 7,024' 7,700psi 8,100psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED APR 2 9 2016 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 8,566' 6,612' Ret.Hyd Dual ESP Packers and SSSV(type,measured and true vertical depth) S-3 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: 0 0 ' 0 260 0 Subsequent to operation: 7 1 39 240 184 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations s Exploratory❑ Developments 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. 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: 316-165 . Contact Ted Kramer Email tkramer(a�hilcorp.com Printed Name Bo Y Title Operations Manager Signature —27711 tir L- Phone 777-8345 Date 4/22/2016 Form 10-404 Revised 5/2015 v —.26 -/-4,. Submit Original Only /� 1/ 'n( RBDMS L-- APR 2 2 2016 • • Milne Point Unit Well: MPU E-14A SCHEMATIC Last Completed: 3/24/2016 H;Ieurp Alaska,LLC PTD: 209-128 TREE/WELLHEAD OPEN HOLE/CEMENT DETAIL Tree Cameron 2-9/16"5M 20" 250 sx of Arcticset I(approx.) in 24"Hole 11"x 7-1/16"SM FMC Gen 9-5/8"" 1750 sx PF'E',300 sx Class"G",89 sx PF'C' Orig.KB EIev=57.6'/Orig.a Elev.24.7'Nabors 27E 5A Ultra Slim,w/2-1/2"Tbg in 12-1/4"Hole Wellhead Hgr,2-7/8":EUE 8rd T&B 7" 250 sx Class"G"in 8-1/2"Hole Thread,2-1/2"CIW BPV 3.5"& 3-3/16" Not Cemented,4-1/8"Hole 20"x' ",' Profile 2-3/8" 19 sx Class'G'in 3"Hole CASING DETAIL 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40 N/A Surface 112' N/A lijj 9-5/8"" Surface 40/L-80/Btrc. 8.835 Surface 5,543' 0.0759 % 194-i- 7" Production 26/L-80/NSCC 6.276 Surface 8,954' 0.0383 3-1 2" Liner 9.2 L- 0 / 8 2.992 8,759' 8 7 ' ,, / / 66 0.0087 2 3-3/16" Liner 6.2/L-80 N/A 8,766' 9,065' N/A d 2-3/8" Liner 4.7/L-80/STL 1.995 8,747' 10,120' 0.00387 ..4 �� TUBING DETAIL 5 / 2-7/8" J Tubing 6.5/L-80/EUE 8rd 2.441 Surf ±8,559' 0.00579 9-5/8"y WELL INCLINATION DETAIL JEWELRY DETAIL KOP @ 900'MD No Depth Item Max Hole Angle 52 Deg.@ 5,953' 1 142' STA#4:GLM Hole Angle Thru Perfs>31 Deg. 2 2,760' STA#3:GLM Max DLS=4.8 @ 5,543' 3 2,823' Tri point Twin Seal ESP Packer w/Weatherford Vent Valve 4 2,835' XN Nipple 5 2,877' STA#2:GLM 6 8,355' STA#1:GLM 7 8,466' XN Nipple ID=2.205"No Go 8 8,508.9' Discharge Head:GPDIS 9 8,509' Pump:161P11/PMSXD 10 8,531' Gas Separator:GRS FER N AR 11 8,534' Upper Tandem Seal:GSB3DB SB/SB PFSA 12 8,541' Lower Tandem Seal: GSB3DB SB/SB PFSA 13 8,548' Motor:MSP3-250—168hp/3,460V/30A 14 8,562' Sensor:WeIILIFT 15 8,564' Centralizer:Bottom @ 8,566' 6 16 8,706' BOT PBR 80-47 Seal Nipple,ID=3.870" 7 17 8,745' BOT 7"x 4.5"S-3 Packer 18 8,747' BOT Deployment Sleeve w/Plug Holder Bushing, ID=3.70" 8 19 8,759' BTT'Diler"Liner Hanger Assy,ID-3.750" t+ 20 8,766' X0 3-1/2"STL x 3-3/16"TCII,ID=3.5" 9 21 8,816' 4.5"XN Nipple w/plug, ID=2.750" 22 8,889' 4.5"WLEG,Bottom @ 8,890' Ji '10 23 8,950' BOT 4.5"Whipstock 11812 24 8,975' 7"CIBP 25 9,064.65' BTT Aluminum Bull Nose Shoe,Btm @ 9,065' 26 10,105' BOT Landing Collar,ID=2.394" ' 41 13 27 10,120' 2-3/8"Unique Biased Edge Guide Shoe,ID=2.650" PERFORATION DETAIL o 1 115 3'114 Kuparuk Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 16 ';, 9,500 9,560' 7,043' 7,044' 60 12/24/09 Open "17 B7 9,660' 9,900' 7,045' 7,041' 240 12/24/09 Open 18 , 9,960' 10,050' 7,036' 7,032' 90 12/24/09 Open 20 '' Perforation Charge Detail:1.56"6SPF 1606P xi 22 21 GENERAL WELL INFO '? API:50-029-22734-01-00 7"Cased Hole -4/12/1997 234.? 25 ESP Completion—5/8/1997 6 ESP Completion—9/15/1997 24 ____ 7»? ESP Completion,screen added—7/19/.... 27 RWO(2) -3/21/2000&6/28/2008 7"4i 4 Pull ESP and install CTD work String—11/19/2009 TD=10,194(MD)/TD=7,120'(TVD) CTD Sidetrack and ESP Completion—1/5/2010 PBTD=10,100'(MD)/PBTD=7,026(TVD) RWO w/Doyon—8/12/2012 Revised B TDF 4/7/2016 ESP Changeout w/ASR—3/24/2016 y • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR 50-029-22734-00-00 209-128 3/14/16 3/24/16 Daily Operations: 3/9/2015-Wednesday No activity to report. 3/10/2015 -Thursday No activity to report. 3/11/2015- Friday No activity to report. 3/12/2015-Saturday No activity to report. 3/13/2015 -Sunday No activity to report. 3/14/2015- Monday Move Rig & Equipment from MPF pad to MP-E14A, Bullhead an additional 75 bbls down tubing, monitor well &flow back to Flowback tank. Well continued to flow. Well was shut in with 20psi on tubing. Discussed plan forward with Work Over Engineer. Roads and Pads Hauled CO, Man Trailer& Change House From MP F-02 to MP E-14a, Change Hydraulic Fluid in Rig, 1' Peak Truck on Location with 235 bbl. 8.7 ppg 3% KCL @ 0300 hrs @ 0330 Second Peak Truck with 135 bbl. 8.7 ppg 3% KCL Leaving Dead Horse, @ 0330 hrs. Little red Services was Called out For Well Kill Operation on MP E-14a, Circulated with 200 bbls returning to flow back tank, bullheaded 35 bbls down tubing. 3/15/2015-Tuesday Monitor Wellbore while waiting on second truck to arrive on location. Rig up second Vac Truck to Little Red services, Check weight on fluid, Incorrect weight was sent out, Fluid in truck was 8.4 ppg. Order 8.7 Brine from Baroid. Bullhead 290 bbl down Tubing&Annulus @ 4.5 BPM @ 1,100psi with a final pressure of 1,700psi, Shut down pump & let pressure bleed to formation, bled pressure off, Monitor wellbore for pressure. @ 1800 hr. Tbg 110psi- IA 145psi. Flow Back Tank Volume 30 bbl. @ 1800 hr Tbg psi=100- IA psi=145 Bleed off Tbg & IA to Flow Back Tank For 5 Min tbg Dropped to psi-50 Pressure on the IA Dropped to psi=90 Bleed off for 5 min Still Flowing into Tank,Tank Vol=31 bbl. Closed Well Back in,Tbg Raised Back up to psi=100 Pressure Annular Raised Back up to psi=120, Continue Monitor wellbore for pressure. Little Red Service Crew has Exceeded there Working Hours for the Day, Matt Linder Said For them to Freeze Protect Lines,Tbg & IA on Well. Close Well in and to Start again in the Morning. Rig Crew Maintain Rig. • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR#1 50-029-22734-00-00 209-128 3/14/16 3/24/16 Daily Operations: 3/16/2015 -Wednesday Monitor Wellbore Pressures. Bleed Backside off to flow back tank, gained 10 bbls in tank. Started with 27psi on tubing & 33 on annulus, bled down to 16psi on tubing & 12psi on annulus for 3 hours, shut well in for 1 hour, tubing psi increased to 18 & annulus increased to 14psi in 1 hour. Opened up annulus and bleed to flow back tank, bled pressure for 3 hours.Tubing Pressure 6psi, Annulus 6psi.Total of 16 bbls back to tank. Rig up Little Red Services, Bullhead 110 bbls of 8.7 brine down annulus @ 5 bpm, @ 800psi final pump pressure of 1,300psi. Bullhead 50 bbls of 8.7 brine down tubing @ 4.0 bpm @ 2,000psi shut well in & freeze protect lines. Monitor Wellbore pressure @ (17:10 hrs.)Tbg Pressure=428/ IA Pressure=440 (17:30 hrs.) Tbg Pressure = 280/ IA Pressure =293 (18:00hrs.)Tbg Pressure=201/ IA Pressure=220. Open Both Tbg& IA to flow Back Tank For 1'Hour,Total Start Tank Volume 53 bbl. Total Tank Volume After 1' Hour of Flowing Back 87 bbl Total bbls. Flowed back 34 bbl. Closed Well Back in, Peak Truck Arrived on Location @19:30 hr. with 290 bbls. of 9.0 ppg Brine. Ted Kramer was Call @ 19:37 hr. Discused Plan Forward, Little Red Sevices was called out to Bull Head 290 bbl of 9.0 ppg down Tbg & IA. Rigged up Little Red Services to Peak Truck Warmed up Equipment;Pumped & Bull Head 290 bbl. of 9.0 ppg down Tbg& IA ICP=5BPM @ 900psi with 240 bbl. FCP= 5BPM @ 1,700psi Last 50 bbl. Bull Head down Tbg @ 4bpm with 2,100psi. Monitor WellBore Pressures @ 22:00 hrs.Tbg psi=461/ IA psi=488 (2230hrs.Tbg psi=293/ IA psi=324)(23:00 hrs. Tbg psi=207/ IA psi=239) (23:30 hrs.Tbg psi=159/ IA psi=188) ( 00:00hrs.Tbg psi=127/ IA psi=154 )( 00:30hrs.Tbg psi=97/ IA psi=122 )( 01:00hrs.Tbg psi=79/ IA psi=105 ) @ 01:00 hrs. Open Tbg & IA to Flow Back Tank Total Volume in Tank 87 bbl. Flow Well into Tank 1' Hour Total Volume in Tank 110 bbl. with a Increase of 23 bbl. Closed well Back in, ( 02:00hrs.Tbg psi=2/ IA psi=8 ). Monitor Well Bore Pressures @ (02:30hrs.Tbg psi=13/ IA psi=47 ) ( 03:00hrs.Tbg psi= 9/ IA psi=47 ) Open Tbg Side Little Flow Still Closed Back in ( 03:30hrs.Tbg psi=7/ IA psi=43 ) ( 0400hrs.Tbg psi=6/ IA psi=40 ) 04:30hrs.Tbg psi= 2/ IA psi=37 ) Open Tbg Side Still Little Flow,Closed Tbg Back in, ( 0500hrs.Tbg psi= 2/ IA psi=37 )Open IA to the Flow Back Tank Attempt to Bleed Well Down. 3/17/2015-Thursday Monitor Wellbore Pressures, Slight flow on Annulus, Tubing on Vacuum. Notified AOGCC of rightto Witness BOP Test p 06:27 on 3-17-16. Install Horseshoe scaffolding on Wellhead, Install BPV with Hilcorp Wellhead hand. Suck out hard lines with Vac truck. Nipple Down Tree &Adapter flange. Nipple up BOPs. Set BOP Enclosure, spot Mud boat. Spot Rig up to Well on Mud Boat, Raise Derrick, Spot Mud Tanks Module, Spot Catwalk & Pipe Racks, Spot Well Site Trailer. Sundry Meeting with Crews. Haul Spot & Rig up CO,Man Shack &Change House, Rig Up Lines & Electrical Cables, Fill Pits with 35 bbl. Fresh Water for Testing Bop, Fill Boiler, Fill 4,200 Gal Fresh Water in Change House,Rig up Koomy Lines to BOP wrap Hydraulic Lines with Glycol Heater lines, Hilcorp Electricans Rig up Combustibale Gas (Methane) Detector&, H2S Dedector, mud pit Trailer&Combustible Gas, & H2S Dedector, Cellar& Drill Floor. Hoist X-Box, Power Tongs, Spacer Spool, Elevators & 2- 7/8" Handling Equipment to Rig Floor& Rig up, Hauled Spot ESP Spooler Unit on Location, Hang ESP Sheave in Derrick;Hilcorp Well Head Rep (Dean Norris) Pulled BPV& Installed TWC Valve. Well Support Crew Greased Bop Valves & Choke Manifold Valves, Fill & Circulate Fresh Water Through Lines, Function Test Bop, Rig up for BOP Test.Testing Bop, Test all valves & Rams to 250psi low/3,000psi high,Test Annular @ 250psi low/2,000psi high.(Johnnie Hill with AOGCC Waived right to witness Bop Test @ 21:00 hrs. on 3-17-16). 3/18/2015 - Friday Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR#1 50-029-22734-00-00 209-128 3/14/16 3/24/16 Daily Operations: Continue Testing Bop, Test all valves &_Rams_to 250psi low/3,000psi high,Test Annular @ 250psi low/ 2,000psi high.(Johnnie Hill with AOGCC Waived right to witness Bop Test @ 21:00 hrs. on 3-17-16),Tested Gas alarms, Performed Accumulator Test. Rig down Test equipment, Blow down lines. Monitor Wellbore, Pull TWC with Hilcorp Wellhead Rep. Make up Landing joint to Tubing Hanger, Back out Lock down screws, Monitor backside, PuIL.H.angerrtQRig Floor at 66 K. Back out & Lay down Landing joint &Tubing Hanger;TOOH, Laying down 2-7/8" Tubing on Pipe Rack. 3/19/2015-Saturday Service Rig, Check fluid on all equipment. Finish layingdown ESP Assembly. Work on Rocker for Power swivel, Load 3.5" work string on pipe rack. Rig up floor for 3.5" Tools. Make up Bit, 7" Casing scraper, 2 XO subs. Trip in the hole with Bit & scraper and 3.5" Work String to 4,000 ft. Service Rig, Check fluid on all equipment.Trip in the hole with Bit& scraper and 3.5" Work String with (293 Jts) @ 8,706 ft P/U=89K D/N=36K. Rig up & Circulate bottoms up, 190 Spm @ 4.18 Bpm Fcp= 250Psi (Total bbl. Loss=0) (Total Stks Pumped 12,100) Recovered Small Piece Rubber at Bottoms up. Blow Down surface lines.TOOH with 3.5" Work String & Casing Scraper. 3/20/2015-Sunday Service Rig & Check all fluids in Equipment. Troubleshoot Pit Volume Totalizers, Loose connection. TOOH, Laying down 3.5" Work string 7,100 ft. Service Rig & Check all fluids in Equipment.TOOH, Laying down 3.5" Work string From 7,100 ft. Break & Lay down 7' Casing Scraper& Bit. Pick & Make up 7' Champ 4 Packer. Trip in the Hole with 3.5" Work string to 4,950 ft. Hydraulic Hose Broke on Elevators, Made up New Hose and Replaced. Trip in the Hole with 3.5" Work string From 4,950 ft. 3/21/2015 - Monday Service Rig, Check all fluid levels on equipment. Continue to Trip in hole with Halliburton Test Packer on 3.5" Work string. vs Set Test Packer per Halliburton Rep,Test 7" Casing to 2,000psi charted for 30 minutes (Good Test), Bleed off& blow lines down, Release Packer, Monitor Wellbore.TOOH laying down 3.5" work string. (AOGCC, Chuck Scheve was on location and Inspected the rig @ 13:00 Hrs. with Hilcorp Wellsite Supervisor, No issues were reported.)Service Rig, Check all fluid levels on equipment. TOOH laying down 3.5" work string & 7' Champ Packer, (Notified AOGCC @ 18:56 PM of Right to witness ESP Packer Backside Test.). Change over 3-1/2" to 2-7/8" Handling Equipment. Load 2-7/8" Completion Tbg on Pipe Racks, Hang Sheaves in Derrick, String Rope over Sheaves,Torque up 2-10ft Pup Joints to 2,600 ft/lbs For Landing Joint. PJSM with Centrilift Rep, Rig Crew, & Hilcorp Rig Rep, Make up &Service ESP Assembly. 3/22/2015 -Tuesday Service Rig & Check fluids in all equipment.TIH with ESP Assembly on 2.7/8" Tubing.Test ESP cable and Capillary line every 2,000'to 5,760 ft. Pick & Make up 7' Retrievable Hyd ESP PKR. Splice & Install 3/8 Capillary Line into Bottom of PKR. Space out & Cut ESP Cable. Install Cable into Dual String PKR Element. Centrilift REP ESP Penetrator Splice into PKR.Tristate Rep Installed 3/8 Capillary Line to Top of PKR for Vent Valve.Testing ESP Cable & 3/8 Capillary Lines (Test Good).TIH with PKR & ESP Assembly on 2 7/8" Tubing. Test ESP cable and Capillary lines every 2,000'. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-14A ASR#1 50-029-22734-00-00 209-128 3/14/16 3/24/16 Daily Operations: 3/23/2015 -Wednesday Service Rig, Check fluids, Genset on Pit Module shut down, Radiator fan broke & Fan Blade bub came off, Install backup Genset. Continue Tripping in the hole with ESP Assy. on 2-7/8"Tubing from 6,700' Check Cable & capillary line every 2,000'. Make up Landing joint&Tubing Hanger, Install Penetrator Connector& capillary lines. Drain BOP Stack, Land Tubing Hanger, PU Weight 69K, Slack off weight 31K, Rig up Little Red for freeze protecting 2-7/8" x 7".Test Surface lines to 2,000psi. Freeze protect Annulus with 55 bbls of Diesel @ 1/2 BPM @ 400 psi. Bleed Pressure off Well, Drop Setting Ball 1.375 OD. Pressure Test Lines 4,000psi (No Leaks), Pump Down TBG Pressure up to 3,700psi. Set PKR Hold for 1'Hour Charted ( Good Test). Pressure Test Lines to 2,000psi (No leaks). Pump Down Back Side Pressure test Back Side 1,500 psi Hold For 30 min Charted (GoodTest). Bleed pressure off. Back out & lay down landing joint, Install BPV into Hanger. Remove ESP & Capillary Line Sheaves From Derrick, Remove Power Tongs- 2-7/8" Handling Equipment-6 ft Riser From Hydrill &X-Box From Rig Floor, Rig Down & Remove Koomey Lines From Bop Stack, Remove Pipe Ramps & pipe Skate, Nipple down Bop Flanges to four Bolts, Rig Down Electrical Kill & Choke Lines to Pits, Break over and Lower Derrick onto Carrier. RDMO ASR Rig- Roads & Pads Load Mud Boat and pits Haul to A-Pad, Remove Well House, Finish Nipple Down Bop Stack Load into Bop Trailer House. 3/24/2015 -Thursday Nipple up Tree &Adapter flange, Test Hanger void to 500 psi low/5,000psi High. Pull BPV with Tee bar, make final check on ESP penetrator per Baker Centrilift. Move all Rig & Equipment from MPE pad to MPA pad. Clean Mud tanks with Guzzler& Fairbanks Pump &Thaw. Raise Derrick& prep to remove Rig Floor. 3/25/2015 - Friday No activity to report. 3/26/2015-Saturday No activity to report. 3/27/2015-Sunday No activity to report. 3/28/2015- Monday No activity to report. 3/29/2015 -Tuesday No activity to report. • • Schwartz. Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, March 21, 2016 2:25 PM To: 'Ted Kramer' Subject: RE: MPU - E-14A Program Change - Sundry# 316-165, PTD# 209-128 Ted, You have approval to run packer as required by CO 390A. The attached procedure and new well sketch are sufficient documentation .. a sundry is not required. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell SCANNED APR 0 12016 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Monday, March 21, 2016 11:24 AM To: Schwartz, Guy L(DOA) Subject: MPU - E-14A Program Change - Sundry # 316-165, PTD # 209-128 Guy, Hilcorp requests a program change to the above Sundry to run a packer in the well in accordance with Conservation Order 390A. At the time the Sundry was submitted on 2-29-2016 the bottom hole pressure had an EMW 7.46 ppg. The offset injectors were left on after this well went down and by the time we rigged up on this well,the bottom hole pressure EMW had increased to 9.0 ppg. Since this new EMW is above the cut off of 8.55 ppg specified in CO 390A, Hilcorp requests a change to run an ESP packer in this well. Attached is a corrected procedure for running this packer. The changes are noted in red. Please let me know if this change is acceptable to the Commission. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1 • • From: Ted Kramer Sent: Monday, March 14, 2016 4:24 PM To: 'Schwartz, Guy L (DOA)' Cc: Tom Fouts; Donald Haberthur- (C); Craig Smith - (C); Matthew Linder; Rob Handy Subject: RE: MPU - E-14A Program Change - Sundry # 316-165, PTD # 209-128 Guy, Thanks for the reply. We are currently rigging up on the E-14A well and have found that we are having trouble killing the well with seawater. This is due to three things: 1.) The offset injectors were not SI while this well was down so the reservoir could have been charged up some over the two plus weeks the well was off line. 2.) We performed a scale squeeze over the weekend in advance of the rig. That could also have the near well bore area charged up to some degree. 3.) The tubing has a confirmed hole at 1900 feet. This hole is giving us trouble circulating below this point. I propose in order to move forward that Hilcorp be allowed to weight up(tubing currently has 20 psi on it),get the well killed so we can pull the tubing(eliminating the hole). We continue with our program of running the C/O assembly and the test packer through step#22. After step 23,we circulate the well with 8.5 ppg fluid and check for flow. If we have flow after this circulation,then we will discuss a waiver,or, running an ESP packer. Please let me know if the AOGCC approves of this plan forward. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@a�alaska.gov] Sent: Monday, March 14, 2016 2:54 PM To: Ted Kramer Cc: Tom Fouts; Donald Haberthur- (C); Craig Smith - (C) Subject: RE: MPU - E-14A Program Change - Sundry # 316-165, PTD # 209-128 Ted, Approved granted to use 31/2"workstring. Guy Schwartz Sr. Petroleum Engineer 2 AOGCC • 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Ted Kramer [mailto:tkramer©hilcorp.com] Sent: Monday, March 14, 2016 6:55 AM To: Schwartz, Guy L(DOA) Cc: Tom Fouts; Donald Haberthur- (C); Craig Smith - (C) Subject: MPU - E-14A Program Change - Sundry # 316-165, PTD # 209-128 Guy, Please be advised that we will be using a 3-1/2" work string(WS)for the above ESP Change out instead of the 2-7/8" WS mentioned in Step 19 of the Sundry The reason for this change is that we already have the 3-1/2" WS on the rig for the current well and it does not make economic sense to change it out. We will have both 3-1/2 and 2-7/8"test joints on location for the BOP test. Please e-mail back you agreement of this change and I will note it on the Work change form. Thanks, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 3 • • Well Prognosis Well: MPU E-14A Nikon)Alaska,Ll: Date: 2/29/2016 Well Name: MPU E-14A API Number: 50-029-22734-01 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: March 15, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 209-128 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907)331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,600 psi @ 6,603'TVD (From ESP Gauge 2/24/16; EMW= 7.46 ppg) Maximum Expected BHP: 2,600 psi @ 6,603' TVD (No new perfs being added) Current Shut-In Tbg Pressure: 70 psi (Current SITP w/existing fluid column) Max. Predicted Surf Pressure: 1,940 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU E-14A was side tracked with a coiled tubing unit in January of 2010 and completed in the Kuparuk River formation. Since that time, two ESP units have been run in the well. This RWO will use the ASR #1 rig to pull the current ESP completion, replace damaged tubing, and run a new ESP completion. A Scale inhibitor treatment will be pumped and the well placed back on production Objective: The purpose of this work is to use the ASR# 1 rig to pull the existing completion, replace damaged tubing, and run a new ESP. Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Forward circulate at least one wellbore (annular)volume with 8.5 ppg sea water down the tubing (thru open GLM pocket),taking returns up the annulus to the 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services Pump and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD crane. 9. NU BOPE house. Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Pull BPV. Bleed any pressure off tubing and casing. 12. Kill well w/8.5 ppg seawater as needed. Set TWC. 13. Test BOPE to 250 psi Low/3,000 psi High,annular to 250 psi Low/2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. • • Well Prognosis Well: MPU E-14A Hilcorp Alaska,LL Date:2/29/2016 a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8"test joint. 14. 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. 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. 15. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 16. MU 2-7/8" landing joint(EUE) and BOLDS. 17. Pull over string weight (approx. 55k PU)on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 18. POOH. Lay 2-7/8"tubing on the pipe rack(plan to change out tubing). Lay down ESP. 19. MU 7" casing C/O Assembly and RIH w/2-7/8"WS. 20. C/O 7" 26#casing down to+/-8,706' MD(BOT S-3 Packer PBR). 21. POOH. Lay 2-7/8"tubing on the pipe rack. LD bit and casing scraper. 22. PU, RIH with Test packer on 2-7/8"WS to+/-8,680' MD. Set packer and pressure test casing to 2,000 psi for 30 min. (on chart). 23. Bleed off pressure, unseat and POOH with packer. 24. PU new ESP completion consisting of the ESP, GLM's, ESP twinseal packer,chemical injection line, surface controlled annular packer vent valve with control line,and RIH on 2-7/8" 8RD EUE L-80 tubing as per schematic. a. Set base of ESP at+/-8,555' (Pump intake around+/-8,520'). Land Tubing. Note PU (Pick Up) and SO (Slack Off)weights on tally. 25. RU Pump Truck. Freeze Protect down back side (+/-55 bbls.to 2,000'). 26. Drop ball and Rod, Pressure up on tubing to 3,500 psi.to set packer. Hold 3,500 psi for 1 hour on chart. 27. Bleed off tubing pressure to tank. 28. Line up pump truck and pressure test back side to 1,500 psi for 30 min. on chart. 29. Land tubing hanger. RILDS. Lay down landing joint. 30. Set BPV.Test tubing hanger to 250/5,000 psi thru test port. 31. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: • • Well Prognosis Well: MPU E-14A Hileorp Alaska,LL Date:2/29/2016 1. RU SL and Pump Truck. Pull Ball and rod and Freeze Protect Tubing. 2. RD mud boat. RD BOPE house. Move to next well location. 3. RU crane. Pull BPV. Set TWC. ND BOPE. 4. NU existing 2-9/16" 5,000#tree.Test tree to 250/5,000 psi. Pull TWC. RD crane. 5. Move 500 bbl returns tank and rig mats to next well location. 6. Replace IA pressure gauge if removed (7"). 7. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO Changes Form • Milne Well: Point MPU E-14UnitA n • PROPOSED Last Completed: 8/2/2012 Hilcorp Alaska,rPTD: 209-128tit: TREE/WELLHEAD OPEN HOLE/CEMENT DETAIL Tree Cameron 2-9/16"5M 20" 250 sx of Arcticset I(approx.) in 24"Hole 11"x 7-1/16"5M FMC Gen9 5/8,,,, 1750 sx PF'E',300 sx Class"G",89 sx PF'C' Orig.KB Elev=57.6/Orig.GL Eley.24.7'Nabors 27E 5A Ultra Slim,w/2-1/2"Tbg in 12-1/4"Hole Wellhead . Hgr,2-7/8":EUE 8rd T&B 7" 250 sx Class"G"in 8-1/2"Hole .kji 0 Thread,2-1/2"CIW BPV 3.5"& 3-3/16" Not Cemented,4-1/8"Hole ' Profile 2-3/8" 19 sx Class'G'in 3"Hole t CASING DETAIL 1 de 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40 N/A Surface 112' N/A ► 9-5/8"" Surface 40/L-80/Btrc. 8.835 Surface 5,543' 0.0759 7" Production 2460/ 6/LL--8800 - 0// NSCC 6.276 Surface 8,954' 0.0383 3-1/2" Liner 9.2/L-80/ 2.992 8,759' 8,766' 0.0087 2 t 3-3/16" Liner 6.2/L-80 N/A 8,766' 9,065' N/A a 0 2-3/8" Liner 4.7/L-80/STL 1.995 8,747' 10,120' 0.00387 ' 3 f! TUBING DETAIL 5 '4 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf ±8,559' 0.00579 9.5/8"A • WELL INCLINATION DETAIL JEWELRY DETAIL KOP @ 900'MD No Depth Item Max Hole Angle 52 Deg.@ 5,953' 1 ±143' STA#4:GLM Hole Angle Thru Perfs>31 Deg. 2 ±2,750' STA#3:GLM Max DLS=4.8 @ 5,543' 6) ±2,800' Tripoint Twin Seal ESP Packer w/Weatherford Vent Valve 4 ±2,810' XN Nipple 5 ±2,820' STA#2:GLM 6 ±8,336' STA#1:GLM 7 ±8,450' XN Nipple ID=2.205"No Go 8 ±8,493' WeliLift Discharge Gauge Unit 9 ±8,497' Discharge Head 10 ±8,498' Pump 11 ±8,520' Gas Separator 12 ±8,525' Upper Tandem Seal 13 ±8,531' Lower Tandem Seal 14 ±8,538' Motor 15 ±8,555' Sensor 6 16 ±8,557' Centralizer:Bottom @±8,559' 7 17 8,706' BOT PBR 80-47 Seal Nipple,ID=3.870" 18 8,745' BOT 7"x 4.5"S-3 Packer 8 g 19 8,747' BOT Deployment Sleeve w/Plug Holder Bushing, 10=3.70" 5, 20 8,759' BTT'Diler"Liner Hanger Assy,ID-3.750" to 21 8,766' XO 3-1/2"STL x 3-3/16"TCII,ID=3.5" ; ,, 22 8,816' 4.5"XN Nipple w/plug, ID=2.750" Ili' ' 11 23 8,889' 4.5"WLEG,Bottom @ 8,890' '•'12&13 24 8,950' BOT 4.5"Whipstock 25 8,975' 7"CIBP 26 9,064.65' BTT Aluminum Bull Nose Shoe,Btm @ 9,065' `l ,t 27 10,105' BOT Landing Collar,ID=2.394" y,14 28 10,120' 2-3/8"Unique Biased Edge Guide Shoe,ID=2.650" :15 PERFORATION DETAIL l!t16 'A 17 :1 Kuparuk Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 71 ' y16 9,500 _ 9,560' 7,043' 7,044' 60 12/24/09 Open ry19�CV 3t 87 9,660' 9,900' 7,045' 7,041' 240 12/24/09 Open . ' 21 ' 9,960' 10,050' 7,036' 7,032' 90 12/24/09 Open 23 Perforation Charge Detail:1.56"6SPF 1606P " GENERAL WELL INFO .Y API:50-029-22734-01-00 24 4 26 7"Cased Hole -4/12/1997 25 ` 7 ESP Completion-5/8/1997 28 ESP Completion-9/15/1997 ESP Completion,screen added-7/19/???? 7"A 6 RWO(2) -3/21/2000&6/28/2008 TD=10,194'(MD)/TD=7,120'TVD) Pull ESP and install CTD work String-11/19/2009 PBTD=10,100'(MD)/PM=7,026(TVD) CTD Sidetrack and ESP Completion-1/5/2010 Revised By:TDF 3/21/2016 RWO w/Doyon-8/12/2012 • • SOF „i t s� THE STATE Alaska Oil and Gas o f e T e cKA Conservation Commission 1�1L�1V titTN- ._ 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage,GOVERNOR BILL WALKER Main: 907.279.1433 OFA ','c*t* Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager RAMMED tALIR 4 Hilcorp Alaska,LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR E-14A Permit to Drill Number: 209-128 Sundry Number: 316-165 Dear Mr. York: 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, Cathy '. Foerster Chair DATED this day of March, 2016. RBDMS L..L MAR 0 4 2016 STATE OF ALASKA '1��- FEB 2 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOf C ` 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 ' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 , Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska LLC ' Exploratory ❑ Development D. 209-128 ' 3.Address: Stratigraphic ❑ 6.API Number: ❑ Service 3800 Centerpoint Dr,Suite 1400 50-029-22734-01-00 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 n MILNE PT UNIT KR E-14A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518/ADL0028231 • MILNE POINT/KUPARUK RIVER OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,194'- 7,120' • 10,100'. 7,026' . 1,939 - 10,105' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' Surface 5,543' 9-5/8" 5,543' 4,587' 5,750psi 3,090psi Production 8,954' 7" 8,954' 6,942' 7,240psi 5,410psi Liner 7' 3-1/2" 8,766' 6,782' 10,160psi 10,540psi Liner 307' 3-3/16" 9,073' 6,222' N/A N/A Liner 1,373' 2-3/8" 10,120' 7,024' 7,700psi 8,100psi 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 8,559 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): S-3 Packer and N/A ' 8,745 MD/6,764 TVD and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development❑ - Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 3/15/2016 Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved 43.0 herein will not be deviated from without prior written approval. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date —2 I F�.S '%.. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. '3 \ 0 — `t.Q Plug Integrity ❑ BOP Test V Mechanical Integrity" Test ❑ CILocation Clearance Other: /c- 3 alfi S..- Alf r' -17:s ,e,5 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Q' Subsequent Form Required: / ;', —41f (1.:'1/ APPROVED BY Approved by: /� (r,7 ,,� COMMISSIONER THE COMMISSION Date: 3-(4-• /6 :5%714- Submit Form and Form 10-403 Revis 1/2015 a�p�:(`le lli n lid for 12months frJI 1/Y 7z jil date of a Attachments in Duplicate H Jw� I. RBDMS L-'- MAR 0 4 2015 • Well Prognosis Well: MPU E-14A Ililcora Alaska,LL} Date:2/29/2016 Well Name: MPU E-14A API Number: 50-029-22734-01 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: March 15, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 209-128 First Call Engineer: Ted Kramer (907)777-8420 (0) (985) 867-0665 Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,600 psi @ 6,603' TVD (From ESP Gauge 2/24/16; EMW= 7..6 ppg) Maximum Expected BHP: 2,600 psi @ 6,603' TVD (No new perfs being added) Current Shut-In Tbg Pressure: 70 psi (Current SITP w/existing fluid column) Max. Predicted Surf Pressure: 1,940 psi (Based on 0.10 psi/ft gas gradient) � iP g � s rjO Brief Well Summary: P�,�1� . ' e' / MPU E-14A was side tracked with a coiled tubing unit in January of 2010 and completed in the Kuparuk River formation. Since that time, two ESP units have been run in the well. This RWO will use the ASR #1 rig to pull the current ESP completion, replace damaged tubing, and run a new ESP completion. A Scale inhibitor treatment will be pumped and the well placed back on production I Objective: The purpose of this work is to use the ASR# 1 rig to pull the existing completion, replace damaged tubing, and run a new ESP. Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Forward circulate at least one wellbore (annular)volume with 8.5 ppg sea water down the tubing (thru open GLM pocket),taking returns up the annulus to the 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services Pump and reverse out skid. 8. RU crane.Set BPV. ND Tree. NU 11" BOPE. RD crane. 9. NU BOPE house.Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Pull BPV. Bleed any pressure off tubing and casing. 12. Kill well w/8.5 ppg seawater as needed.Set TWC. 13. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. • • Well Prognosis Well: MPU E-14A Iiilcorn Alaska.LL Date:2/29/2016 a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" test joint. 14. CLonti ngency: (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. b. With stack out of the test path, test choke manifold per standard procedure VV) , c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor 4,J 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. 15. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 16. MU 2-7/8" landing joint (EUE) and BOLDS. 17. Pull over string weight (approx. 55k PU) on tubing hanger to confirm free. LD tubing hanger. a. Conti_ (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 18. POOH. Lay 2-7/8"tubing on the pipe rack (plan to change out tubing). Lay down ESP. 19. MU 7" casing C/O Assembly and RIH w/2-7/8" WS. 20. C/O 7" 26#casing down to +/-8,706' MD (BOT S-3 Packer PBR). 21. POOH. Lay 2-7/8"tubing on the pipe rack. LD bit and casing scraper. 22. PU, RIH with Test packer on 2-7/8"WS to+/-8.680' MD. Set packer and pressure test casing to 2,000 psi for 30 min. (on chard it/ 23. Bleed off pressure, unseat and POOH with packer. fa 24. PU new ESP and RIH on 2-7/8" 8RD EUE L-80 tubing. a. Run 2-7/8" XN profile, and 2 ea GLMS. 25. Set base of ESP at+/-8,555' (Pump intake around +/-8,520'). 26. Land tubing hanger. RILDS. Lay down landing joint. a. Note PU (Pick Up) and SO (Slack Off) weights on tally. 27. Set BPV. Test tubing hanger to 250/5,000 psi thru test port. 28. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. Pull BPV. Set TWC. ND BOPE. 3. NU existing 2-9/16" 5,000#tree.Test tree to 250/5,000 psi. Pull TWC. RD crane. 4. Move 500 bbl returns tank and rig mats to next well location. 5. Replace IA pressure gauge if removed (7"). • Well Prognosis . g Well: MPU E-14A Ililcory Alaska,LL Date: 2/29/2016 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO Changes Form 0 • Milne Point Unit Well: MPU E-14A .11 SCHEMATIC Last Completed: 8/2/2012 Hilcorp Alaska,LLC PTD: 209-128 TREE/WELLHEAD Tree Cameron 2-9/16"5M Wellhead 11"x 7-1/16"5M FMC Gen 5A Ultra Slim,w/2-1/2"Tbg Orig.KB Elev=57.6'/Orig.GL Elev.=24.7'Nabors 27E Hgr,2-7/8":EUE 8rd T&B Thread,2-1/2"CIW BPV Profile ,J .,. OPEN HOLE/CEMENT DETAIL 20' 20" 250 sx of Arcticset I(approx.) in 24"Hole 9-5/8"" 1750 sx PF'E',300 sx Class"G",89 sx PF'C' in 12-1/4"Hole 7" 250 sx Class"G"in 8-1/2"Hole 1 3.5"& 3-3/16" Not Cemented,4-1/8"Hole 2-3/8" 19 sx Class'G'in 3"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40 N/A Surface 112' N/A 9-5/8"" Surface 40/L-80/Btrc. 8.835 Surface 5,543' 0.0759 " 7" Production 26/L-80/NSCC 6.276 Surface 8,954' 0.0383 a' 3-1/2" Liner 9.2/L-80/ 2.992 8,759' 8,766' 0.0087 3-3/16" Liner 6.2/L-80 N/A 8,766' 9,065' N/A 9-5/8" 6 2-3/8" Liner 4.7/L-80/STL 1.995 8,747' 10,120' 0.00387 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 8,559' 0.00579 WELL INCLINATION DETAIL JEWELRY DETAIL KOP @ 900'MD No Depth Item Max Hole Angle 52 Deg.@ 5,953' 1 143' STA#2:CAMCO 2-7/8"x 1" Side-pocket KBMM GLM w/DSOV Hole Angle Thru Perfs>31 Deg. 2 8,336' STA#1:CAMCO 2-7/8"x 1" Side-pocket KBMM GLM w/DMY Max DLS=4.8 @ 5,543' 3 8,450' XN Nipple ID=2.205"No Go 4 8,493' WeIILift Discharge Gauge Unit:PWLE0014 5 8,497' Discharge Head: GPDIS 6 8,498' Pump:161-P11 SXD 7 8,520' Gas Separator:GRSFTX AR H6(400 internals) 8 8,525' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 9 8,531' Lower Tandem Seal:GSB3DBLT SB/SB PFSA 10 8,538' Motor:KMH—210HP/2,380V/53A 11 8,555' Sensor:WeIILift MGU ` 2 12 8,557' Centralizer:Bottom @ 8,559' 13 8,706' BOT PBR 80-47 Seal Nipple,ID=3.870" 3 14 8,745' BOT 7"x 4.5"S-3 Packer 4. 4 15 8,747' BOT Deployment Sleeve w/Plug Holder Bushing, ID=3.70" i- 1 5 16 8,759' BTT'Diler"Liner Hanger Assy,ID-3.750" , ,i 17 8,766' X0 3-1/2"STL x 3-3/16"TCII,ID=3.5" 6 18 8,816' 4.5"XN Nipple w/plug, ID=2.750" Y:tBii 7 19 8,889' 4.5"WLEG,Bottom @ 8,890' f1." 20 8,950' BOT 4.5"Whipstock 8&9 9-1Alt. 1 21 8,975' 7"CIBP w� 22 9,064.65' BTT Aluminum Bull Nose Shoe,Btm @ 9,065' t Ga y� 23 10,105' BOT Landing Collar,ID=2.394" 10 1" 24 10,120' 2-3/8"Unique Biased Edge Guide Shoe,ID=2.650" • ' 11 /,{ PERFORATION DETAIL Ifni 12 ' Kuparuk Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status sie 13 9,500 9,560' 7,043' 7,044' 60 12/24/09 Open ' ._,z 14 15 B7 9,660' 9,900' 7,045' 7,041' 240 12/24/09 Open 0'a 16 9,960' 10,050' 7,036' 7,032' 90 12/24/09 Open 18 Perforation Charge Detail:1.56"6SPF 1606P 19 GENERAL WELL INFO API:50-029-22734-01-00 7"Cased Hole -4/12/1997 20 .a 22 ESP Completion—5/8/1997 21 - _ - � 3 ESP Completion—9/15/1997 24 ESP Completion,screen added—7/19/???? RWO(2) -3/21/2000&6/28/2008 7 Pull ESP and install CTD work String-11/19/2009 TD=10,194'(MD)/TD=7,120'(TVD) CTD Sidetrack and ESP Completion—1/5/2010 PBTD=10,100'(MD)/PBTD=7,026(TVD) RWO w/Doyon—8/12/2012 Revised By:TDF 2/25/2016 • • Milne Point Unit Well: MPU E-14A PROPOSED Last Completed: 8/2/2012 Ii[ilcorp Alaska,LLC PTD: 209-128 TREE/WELLHEAD Tree Cameron 2-9/16"5M Wellhead 11"x 7-1/16"5M FMC Gen 5A Ultra Slim,w/2-1/2"Tbg Orig.KB Elev=57.6'/Orig.GL Elev.=24.7'Nabors 27E Hgr,2-7/8":EUE 8rd T&B Thread,2-1/2"CIW BPV Profile j -.1 '',,', OPEN HOLE/CEMENT DETAIL 2 i ' 0" �. 20" 250 sx of Arcticset I(approx.) in 24"Hole 9-5/8"" 1750 sx PF'r,300 sx Class"G",89 sx PF'C in 12-1/4"Hole t6 7" 250 sx Class"G"in 8-1/2"Hole ral 4, 1 to 3.5"& 3-3/16" Not Cemented,4-1/8"Hole a- 2-3/8" 19 sx Class'G'in 3"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF t, 20" Conductor 91.1/H-40 N/A Surface 112' N/A " 9-5/8"" Surface 40/L-80/Btrc. 8.835 Surface 5,543' 0.0759 t' t} 7" Production 26/L-80/NSCC 6.276 Surface 8,954' 0.0383 t" 3-1/2" Liner 9.2/L-80/ 2.992 8,759' 8,766' 0.0087 3-3/16" Liner 6.2/L-80 N/A 8,766' 9,065' N/A 9-5/8"ill 2-3/8" Liner 4.7/L-80/STL 1.995 8,747' 10,120' 0.00387 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf ±8,559' 0.00579 WELL INCLINATION DETAIL JEWELRY DETAIL KOP @ 900'MD No Depth Item Max Hole Angle 52 Deg.@ 5,953' 1 ±143' STA#2:GLM Hole Angle Thru Perfs>31 Deg. 2 ±8,336' STA#1:GLM Max DLS=4.8 @ 5,543' 3 ±8,450' XN Nipple ID=2.205"No Go 4 ±8,493' WeIILift Discharge Gauge Unit 5 ±8,497' Discharge Head 6 ±8,498' Pump - 7 ±8,520' Gas Separator 8 ±8,525' Upper Tandem Seal 9 ±8,531' Lower Tandem Seal 10 ±8,538' Motor 11 ±8,555' Sensor 2 12 ±8,557' Centralizer:Bottom @±8,559' 13 8,706' BOT PBR 80-47 Seal Nipple,ID=3.870" 3 14 8,745' BOT 7"x 4.5"S-3 Packer 4 ° 15 8,747' BOT Deployment Sleeve w/Plug Holder Bushing, ID=3.70" V 5 16 8,759' BTT'Diler"Liner Hanger Assy,ID-3.750" 6 17 8,766' XO 3-1/2"STL x 3-3/16"TCII,ID=3.5" 18 8,816' 4.5"XN Nipple w/plug, ID=2.750" 7 19 8,889' 4.5"WLEG,Bottom @ 8,890' „_ MI 20 8,950' BOT4.5"Whipstock i s 8 &9 21 8,975' 7"CIBP a kl" 9 22 9,064.65' BTT Aluminum Bull Nose Shoe,Btm @ 9,065' A Mit °! 23 10,105' BOT Landing Collar,ID=2.394" 10 24 10,120' 2-3/8"Unique Biased Edge Guide Shoe,ID=2.650" PERFORATION DETAIL + 12 ,11 r; Kuparuk Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 13 li9,500 9,560' 7,043' 7,044' 60 12/24/09 Open 15 14XB7 9,660' 9,900' 7,045' 7,041' 240 12/24/09 Open �� 9,960' 10,050' 7,036' 7,032' 90 12/24/09 Open %.: 18 Perforation Charge Detail:1.56"6SPF 1606P 19 GENERAL WELL INFO API:50-029-22734-01-00 7"Cased Hole -4/12/1997 20•; 22 ESP Completion—5/8/1997 21 - 3 ESP Completion—9/15/1997 ESP Completion,screen added—7/19/???? 4! 24 RWO(2) -3/21/2000&6/28/2008 7 Pull ESP and install CTD work String—11/19/2009 TD=10,194'(MD)/TD=7,120(TVD) CTD Sidetrack and ESP Completion—1/5/2010 PBTD=10,100'(MD)/PBTD=7,026(TVD) RWO w/Doyon—8/12/2012 Revised By:TDF 2/25/2016 • • Milne Point ' I/ 2016 ASR Rig 1. mi.," c�.�,; .-ct,<, Knight Oil Tools BOP / \ Stripping Head rr IF"' aillE111 CI haffe } 4 11" - 5000 1i Z lTi tit , , )ti iii rut V i4■Mi� CI _U 2 7/8" — 5" VBR �'L f�®� ISI 1 D H 11" � � 000 41°la ,e® H Blind ® `wx 2" Kill Line J 2" Choke Line i L� ' - i l iii * ; [� 1 3 1 I �i .. ii - ■iiiil►141 Manual Manual Manual HCR Updated 2/29/16 • • H MPU E-14A • EXISTING TREE/WELLHEAD Wellhead/Tree H;ieor��Alaska,LLC Milne Point Unit Tree Cap ill I.. III i aco�0 Tree Valve 2-9/16" 5M "� p i:. is. Tree Cross 2-9/16" 5M [o(0)e Tree Valve 2-9/16" 5M 1; .rte c. SSV 2-9/16" 5M O a wit_s. ft. €--,n Tree Valve 2-9/16" 5M F4,1,(0 ‘6) ESP Cable "' 'i' i Tubing Adapter _ Tubing Head «o i#r 11" 5M Top x 11°' 5M Btm a it , aIiiii '; •%WII ma l *11 Casing Head ., , 11" 5M Top x 11" 5M Btm. • • - E ',It a4qt E •`,If 6ta CC.ce ,.., a, '7' 2 = 7t 7,7, 0 ..1111 '44 I X g Ci-g3 0 cn § § Mil Dal C104 -0 OTD 91) a> 0 a, r-.. 0 7 c . a ,) › ..,_ L:2,§ . z z- t.o• u: u z ..r 1-, a E .7g, °A .v_ •2 < ••• 110.- -Co:1D31—Dol . 03 d-] LT, > C_ 0.5 •;-' a: _E Z Lo ZD Lo: 63 TT) bT3 . -, 0 co co _, m 0 o co m o o < 8D m ,r-11 u ..:,, , faTr__, ci,z , c -Li a, -V 4 V 0 .0 U - , . Li.1 I • 3 1 g 7 . I o > -L? a,-1>-Barli pa. Vum nit>. I . - 0 . - . 23 --• -••••' g C Y z . :-, F D u a, u c co = c 0 -1-- 0 m -DOCI i' t 0—C ,H 1 I1-- cab H H §Y D y cci < Ln LE_ 0 E - - 2‹ 4 9N§1r 1.•.1 1,0.1 -I F• .1" ' § § -1 1-- , ....._ ... 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They ire available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. , 0? - tag Well History File Identifier Organizing (done) ❑ Two -sided III IIIIII I II 1111 ❑ Rescan Needed III 11 1111 111 1 I RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: gt Items: r ther, No/Type: G1) No, 1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: /� — /s/ BY: Maria �_ Date: g /3- I 1O Pit, f) Project Proofing II 111111111111 yvt P BY: Maria _ _ Date: g Ia.' //,_ /s/ in Preparation x 30 = CD D + 7 = TOT PAGES 69 Scanning p (Count does not include cover sheet) BY: Date: a /s/ k4 11 Production Scannin g I Stage 1 Page Count from Scanned File: / (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: U /0-1 J gt- /s/ WI p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I ReScanned II 1111111 1111 BY: Maria Date: /s/ Comments about this file: Quality Checked III I 10/6/2005 Well History File Cover Page.doc f { STATE OF ALASKA AOKA OIL AND GAS CONSERVATION CO ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ 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. ® Development ❑ Exploratory " 209 - 128 3. Address: ❑ Service ❑ Stratigraphic 6. API Number:. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22734 - 01 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025518 & 028231 w MPE - 14A 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): . Milne Point Unit / Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 10194' feet Plugs (measured) None feet true vertical 7020' feet Junk (measured) None feet Effective depth: measured 10105' feet Packer: (measured) feet true vertical 7025' feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 5511' 9 -5/8" 32' - 5543' 32' - 4587' 5750 3090 Intermediate Production Liner 8929' 7" 25' - 8954' 25' - 6942' 7240 5410 Liner 1373' 3 - 1/2" x 3 - 3/16" x 2 - 7/8" 8747' - 10120' 6765' - 7024' Perforation Depth: Measured Depth: 9500' - 10050' ,'k =.#4414 Ri i y t k i .01:1. True Vertical Depth: 7043' - 7032' Tubing (size, grade, measured and true vertical depth): 2 6 L - 8559' 6607' 4 - 1/2 ", 12.6# 8706' - 8890' 6731' - 6887' Packers and SSSV (type, measured and true vertical depth): 7" x 4 -1/2" Baker S -3 Packer 8745' 6764' 12. Stimulation or cement squeeze summary: y� V ED Intervals treated (measured): 6 Treatment description including volumes used and final pressure: AUG 2 8 2612 AOGCC 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 137 12 544 220 188 Subsequent to operation: 123 13 542 200 179 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: Q , ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations 16. Well Status after work: • ® 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 Printed Nam e L t Title Drilling Technologist /h 1,� Prepared By Name/Number Signature r , Phone 564 - 4091 Date ((/�` /I Joe Lastufka, 564 -4091 Form 10-404 Revise 11/2011 r/ a:- i l 414/ Original Only • • Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- 00VK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'15.912 "2 Long: 0149 °26'06.260 "W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/28/2012 12:00 - 12:30 0.50 MOB P PRE HELD PJSM - REVEIW DDI RIG MOVE SOP. - REVEIW RIG MOVE CHECK LIST. - DOYON DRILLING SAFETY REP PRESENT. - PERFORM PRE -TOUR CHECKS. 12:30 - 13:30 1.00 MOB P PRE R/D FOR MOVE. TEST MOVING SYSTEM. COMPLETE RIG MOVE CHECK LIST. 13:30 - 18:00 4.50 MOB P PRE MOVE RIG OFF MPE -30 WELL HEAD - WSL, PAD OPERATOR, DDI HSE REP AND TOOLPUSHER PRESENT. - MOVE ON MATS FROM MPE -30 TO MPE -14. - SHUFFLE RIG MATS AND MOVE IN FRONT OF MPE -14 18:00 - 18:30 0.50 MOB P PRE PJSM FOR BACKING OVER WELL. - DDI FIELD SUPERINTENDANT, WSL, TOOL PUSHER AND CREW IN ATTENDANCE. - ENSURE ALL TREE VALVES ARE CLOSED. - NOTIFY PAD OPERATOR. 18:30 - 19:00 0.50 MOB P PRE MOVE AND ALIGN RIG TO BACK OVER WELL. - POSITION MATS FOR CELLAR FOOT. 19:00 - 21:30 2.50 MOB P PRE BACK AND SPOT RIG OVER MPE -14. - SHIM AND LEVEL RIG. - SET CUTTINGS BOX. - RIG ACCEPTED ON MPE -14A AT 21:30 HRS. 21:30 - 00:00 2.50 RIGU P PRE SET RIG EQUIPMENT AND R/U. - WELL SUPPORT SPOT TIGER TANK ON ODS OF RIG. R/U HARDLINE. - R/U KILL MANIFOLD AND LINES. - R/U ALARM TO TIGER TANK AND TEST. - COMPLETE POST WELL TRANSFER PERMIT ON MPE -30A. - FILL PITS WITH 120 DEG 8.6 PPG KWF. 7/29/2012 00:00 - 01:00 1.00 RIGU P PRE PJSM. FINISH R/U KILL MANIFOLD IN CELLAR. - R/U 0/A LINE TO SLOP TANK. - LOAD PITS WITH 120 DEG 8.6 PPG KWF. 00:00 - 01:00 1.00 RIGU P PRE PJSM. FINISH R/U KILL MANIFOLD IN CELLAR. - R/U 0/A LINE TO SLOP TANK. - LOAD PITS WITH 120 DEG 8.6 PPG KWF. 01:00 - 02:00 1.00 RIGU P PRE R/U O/A TO SLOP TANK. - R/U AND TEST REMOTE ACTUATOR FOR SSV. 01:00 - 02:00 1.00 RIGU P PRE R/U O/A TO SLOP TANK. - R/U AND TEST REMOTE ACTUATOR FOR SSV. 02:00 - 03:00 1.00 BOPSUB P PRE PJSM, REVIEW DDI SOP FOR TESTING KILL MANIFOLD. - TEST KILL MANIFOLD AND CHECK VALVES TO 250/3500 PSI 5 MIN EA. CHARTED. 02:00 - 03:00 1.00 BOPSUB P PRE PJSM, REVIEW DDI SOP FOR TESTING KILL MANIFOLD. - TEST KILL MANIFOLD AND CHECK VALVES TO 250/3500 PSI 5 MIN EA. CHARTED. Printed 8/20/2012 12:14:25PM North America - Q• a io Sumr Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- 00VK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °2715.912 "2 Long: 0149°26'06.260'W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 03:45 0.75 BOPSUB P PRE CONDUCT RIG EVAC DRILL DUE TO LARGE GAS RELEASE. - MUSTER AT SAFE AREA: AAR - TOOK HEAD COUNT- MISSING DRILLER ASSUMED DOWN. MOTORMAN ASSUMED DRILLERS RESPONSIBILITY. SIMULATE NOTIFICATION TO ERT. TRUCK DRIVERS WERE ALERTED AND RESPONDED. - NOTED WIND DIRECTION BEFORE EXITING RIG. - LOADER OPERATOR SECURED PAD ENTRANCE. 03:00 - 03:45 0.75 BOPSUB P PRE CONDUCT RIG EVAC DRILL DUE TO LARGE GAS RELEASE. - MUSTER AT SAFE AREA: AAR - TOOK HEAD COUNT- MISSING DRILLER -- ASSUMED DOWN. MOTORMAN ASSUMED DRILLERS RESPONSIBILITY. SIMULATE NOTIFICATION TO ERT. - TRUCK DRIVERS WERE ALERTED AND RESPONDED. - NOTED WIND DIRECTION BEFORE EXITING RIG. - LOADER OPERATOR SECURED PAD ENTRANCE. 03:45 - 05:30 1.75 BOPSUB P PRE DSM R/U AND TEST LUBRICATOR FOR PULLING BPV TO 250/3500 PSI 5 MIN EA. CHARTED. - WAIT ON DAYLIGHT WELL KILL AS PER WELL PLAN. - O /A= 200 PSI. I /A= 275 PSI. 03:45 - 05:30 1.75 BOPSUB P PRE DSM R/U AND TEST LUBRICATOR FOR PULLING BPV TO 250/3500 PSI 5 MIN EA. CHARTED. - WAIT ON DAYLIGHT WELL KILL AS PER WELL PLAN. - O /A= 200 PSI. I /A= 275 PSI. 05:30 - 07:00 1.50 BOPSUB P PRE PJSM FOR RIGGING UP WELL KILL EQUIPMENT AND MANIFOLD. - RIG UP WELL KILL MANIFOLD IN CELLAR. RIG UP ASSOCIATED LINES. - WSL AND TOOLPUSHER VERIFY KILL SKID AND KILL LINE R/U. - AOGCC J, CRISP WAIVED WITNESS FOR INITIAL BOP TEST ON MPE -14A. 05:30 - 07:00 1.50 BOPSUB P PRE PJSM FOR RIGGING UP WELL KILL EQUIPMENT AND MANIFOLD. - RIG UP WELL KILL MANIFOLD IN CELLAR. RIG UP ASSOCIATED LINES. - WAIT ON JOHN RALL TO PERFORM WELL KILL. - AOGCC J. CRISP WAIVED WITNESS FOR INITIAL BOP TEST ON MPE -14A. Printed 8/20/2012 12:14:25PM ... .... - -. -.- . . g Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- 00VK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'15.912 "2 Long: 0149 °26'06.260 "W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 07:30 0.50 BOPSUB P PRE PJSM ON WELL KILL OPERATIONS. - BP SUPERINTENDENT, WSL, TOOL PUSHER, MI REP., CH2 SUPPORT CREW, AND RIG CREW IN ATTENDANCE. - REVIEWED DDI WELL KILL SOP. 07:00 - 07:30 0.50 BOPSUB P PRE PJSM ON WELL KILL OPERATIONS. BP SUPERINTENDENT, WSL, TOOL PUSHER, MI REP., CH2 SUPPORT CREW, AND RIG CREW IN ATTENDANCE. REVIEWED DDI WELL KILL SOP. 07:30 - 11:00 3.50 BOPSUB P PRE KILL WELL PER DDI SOP. - SITP=275 PSI, SICP =275 PSI, OA =200 - WSL AND TOOLPUSHER VERIFY VALVE ALIGNMENT. - VENT GAS TO FLOW BACK TANK VIA KILL MANIFOLD AND HARD LINE. - CIRCULATE 60 BBLS 8.6 PPG BRINE, DOWN 2 7/8" TBG, RETURNS TO FLOW BACK TANK - MAINTAIN150 PSI DOWN STREAM PRESSURE. ICP = 650 PSI. FCP = 470 PSI. CLOSE CHOKE AND BULLHEAD 20 BBLS 1CWF DOWN TBG. AT 3 BPM @ 930 PSI. - PUMPS OFF SITP = 300 PSI, PRESSURE INCREASE TO 900 PSI IN 5 MINUTES. - OPEN CHOKE AND CIRCULATE DOWN THE TBG, THROUGH THE HAND CHOKE TO THE FLOW BACK TANK. - CIRCULATE AT 5 BPM AT 1730 PSI. FOR A TOTAL OF 350 BBLS. - WHILE MAINTAINING 150 PSI DOWN STREAM PRESSURE. - AFTER 30 MINUTE SHUT -IN: TBG AND IA = —4 PSI. - WSL AND TOOLPUSHER VERIFY VALVE ALIGNMENT. - DISCUSS PLAN FORWARD WITH RWO ENGINEER. - SENT 192 BBLS CRUDE/BRINE (80/20 %) TO HYDROCARBON RECYCLE. - LOST 70 BBLS KWF TO THE FORMATION. - AAR FOR WELL KILL. - DISCUSS USING HAND HELD LEL MONITOR VERSUS H2S BADGE FOR SPOTTER AT TIGER TANK. Printed 8/20/2012 12:14:25PM ' America - ALASKA - BP v .: Operation Summary Repl Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- 00VK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'15.912 "2 Long: 0149°26'06.260'W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 11:00 3.50 BOPSUB P PRE KILL WELL PER DDI SOP. - SITP =275 PSI, SICP =275 PSI, OA =200 - WSL AND TOOLPUSHER VERIFY VALVE ALIGNMENT. - VENT GAS TO FLOW BACK TANK VIA KILL MANIFOLD AND HARD LINE. CIRCULATE 60 BBLS 8.6 PPG BRINE, DOWN 2 7/8" TBG, RETURNS TO FLOW BACK TANK - MAINTAIN 150 PSI DOWN STREAM PRESSURE. - ICP = 650 PSI. - FCP = 470 PSI. - CLOSE CHOKE AND BULLHEAD 20 BBLS KWF DOWN TBG. AT 3 BPM @ 930 PSI. - PUMPS OFF SITP= 300 PSI, PRESSURE INCREASE TO 900 PSI IN 5 MINUTES. - OPEN CHOKE AND CIRCULATE DOWN THE - TBG, THROUGH THE HAND CHOKE TO THE FLOW BACK TANK. - CIRCULATE AT 5 BPM AT 1730 PSI. FOR A - TOTAL OF 350 BBLS. WHILE MAINTAINING 150 PSI DOWN STREAM PRESSURE. AFTER 30 MINUTE SHUT -IN: TBG AND IA = —4 PSI. - WSL AND TOOLPUSHER VERIFY VALVE ALIGNMENT. - DISCUSS PLAN FORWARD WITH RWO ENGINEER. - SENT 192 BBLS CRUDE/BRINE (80/20 %) TO HYDROCARBON RECYCLE. - LOST 70 BBLS KWF TO THE FORMATION. - AAR FOR WELL KILL. - DISCUSS USING HAND HELD LEL MONITOR VERSUS H2S BADGE FOR SPOTTER AT TIGER TANK. 11:00 - 12:00 1.00 BOPSUB P PRE R/U TO CIRCULATE BACK TO THE PITS. - DISCUSSED KWF WEIGHT INCREASE TO 8.7 PPG BRINE. - LOSSES TO WELL IN LAST 12 HRS = 105 BBLS. 11:00 - 12:00 1.00 BOPSUB P PRE R/U TO CIRCULATE BACK TO THE PITS. - DISCUSSED KWF WEIGHT INCREASE TO 8.7 PPG BRINE. - LOSSES TO WELL IN LAST 12 HRS = 105 BBLS. 12:00 - 13:00 1.00 BOPSUB P PRE PJSM WITH DAY CREW COMMING ON TOUR - DDI WELL KILL SOP. - PERFORM PRE -TOUR CHECKS. 12:00 - 13:00 1.00 BOPSUB P PRE PJSM WITH DAY CREW COMMING ON TOUR - DDI WELL KILL SOP. - PERFORM PRE -TOUR CHECKS. 13:00 - 14:00 1.00 BOPSUB P PRE TEST CHOKE HOSE AND BODY TEST RIG CHOKE. - 250 PSI / 3500 PSI - 5 MINUTES CHARTED. PASSED. Printed 8/20/2012 12:14:25PM €� -mow , . 4 Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- 00VKI -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070°27'15.912'2 Long: 0149°26'06.260'W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 14:00 1.00 BOPSUB P PRE TEST CHOKE HOSE AND BODY TEST RIG CHOKE. - 250 PSI / 3500 PSI - 5 MINUTES CHARTED. PASSED. 14:00 17:00 3.00 BOPSUB P PRE WSL VERIFY VALVE ALIGNMENT AND DISCUSSED SECOND CIRCULATION. -- CIRCULATE 307 BBLS 8.7 PPG BRINE SURFACE TO SURFACE. - 4 -1/2 BPM/ 1130 PSI. - THROUGH THE 2" OPEN CHOKE TO THE GAS BUSTER TO THE PITS. - AFTER 30 MINUTE SHUT -IN, TBG AND IA ON SLIGHT VACUUM. - MONITOR WELL. WELL IS DEAD. CONTINUES ON SLIGHT VAC. 14:00 - 17:00 3.00 BOPSUB P PRE WSL VERIFY VALVE ALIGNMENT AND DISCUSSED SECOND CIRCULATION. - CIRCULATE 307 BBLS 8.7 PPG BRINE SURFACE TO SURFACE. - 4-1/2 BPM / 1130 PSI. THROUGH THE 2" OPEN CHOKE TO THE GAS BUSTER TO THE PITS. AFTER 30 MINUTE SHUT -IN, TBG AND IA ON SLIGHT VACUUM. - MONITOR WELL. WELL IS DEAD. CONTINUES ON SLIGHT VAC. 17:00 18:00 1.00 BOPSUR P PRE BLOW DOWN LINES. - R/D KILL MANIFOLD AND LINES. 17:00 - 18:00 1.00 BOPSUR P PRE BLOW DOWN LINES. - R/D KILL MANIFOLD AND LINES. 18:00 - 20:30 2.50 BOPSUR P PRE PJSM WITH DSM, WSL, TOOL PUSHER AND CREW. - REVIEW WELL PLAN REQUIRMENTS FOR TESTING TWC. - R/U LUBRICATOR AND PRESSURE TEST TO 250/3500 PSI 5 MIN EA. CHARTED. - INSTALL TWC. - PERFORM 500 PSI ROLLING TEST UNDER TWC FOR 10 MIN CHARTED. - PUMPING 2.8 BPM 500 PSI, FINAL 2 BPM 500 PSI. USE 23 BBLS 8.7 PPG KWF FOR ROLLING TEST. - TEST ABOVE TWC TO 250/500 PSI 5 MIN EA. CHARTED. 18:00 - 20:30 2.50 BOPSUR P PRE PJSM WITH DSM, WSL, TOOL PUSHER AND CREW. - REVIEW WELL PLAN REQUIRMENTS FOR TESTING TWC. - R/U LUBRICATOR AND PRESSURE TEST TO 250/3500 PSI 5 MIN EA. CHARTED. - INSTALL TWC. - PERFORM 500 PSI ROLLING TEST UNDER TWC FOR 10 MIN CHARTED. - PUMPING 2.8 BPM 500 PSI, FINAL 2 BPM 500 PSI. USE 23 BBLS 8.7 PPG KWF FOR ROLLING TEST. - TEST ABOVE TWC TO 250/500 PSI 5 MIN EA. CHARTED. 20:30 - 21:00 0.50 BOPSUR P PRE R/D LUBRICATOR AND TEST EQUIPMENT. 20:30 - 21:00 0.50 BOPSUR P PRE R/D LUBRICATOR AND TEST EQUIPMENT. Printed 8/20/2012 12:14:25PM f , z Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- OOVK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'15.912 "2 Long: 0149 °26'06.260 "W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 22:00 1.00 BOPSUR P PRE PJSM. REVIEW DDI SOP FOR N/D TREE. - R/U AND USE CONTINUOUS HOLE FILL DOWN VA WITH PUMP AND BYPASS LINE. - ESTABLISH HOLE FILL RATE DOWN BACKSIDE AT 8 BPH WITH 8.7 PPG KWF. - FMC REP BLEED DOWN TREE VOID. - WITH 2 BARRIERS IN PLACE. TESTED TWC, HANGER SEALS AND 8.7 PPG KWF. - N/D ADAPTOR FLANGE AND TREE. - FMC REP INSPECT HANGER THREADS VERIFY WITH PUP, 2 7/8 EUE 8RD. 10 TURNS. 21:00 - 22:00 1.00 BOPSUR P PRE PJSM. REVIEW DDI SOP FOR N/D TREE. - R/U AND USE CONTINUOUS HOLE FILL DOWN VA WITH PUMP AND BYPASS LINE. - ESTABLISH HOLE FILL RATE DOWN BACKSIDE AT 8 BPH WITH 8.7 PPG KWF. FMC REP BLEED DOWN TREE VOID. - WITH 2 BARRIERS IN PLACE. TESTED TWC, HANGER SEALS AND 8.7 PPG KWF. - N/D ADAPTOR FLANGE AND TREE. - FM C REP INSPECT HANGER THREADS VERIFY WITH PUP, 2 7/8 EUE 8RD. 10 TURNS. 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM. REVIEW DDI SOP FOR N/U BOPE. N/U BOPE. - USE CONTINUOUS HOLE FILL DOWN VA WITH 8.7 PPG KWF. - WELL TAKING 8 BPH. - LOSSES TO WELL IN LAST 12 HRS = 75 BBLS 8.7 PPG KWF. - LOSSES TO WELL IN LAST 24 HRS = 180 BBLS 8.7 PPG KWF. 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM. REVIEW DDI SOP FOR N/U BOPE. - N/U BOPE. - USE CONTINUOUS HOLE FILL DOWN VA WITH 8.7 PPG KWF. - WELL TAKING 8 BPH. - LOSSES TO WELL IN LAST 12 HRS = 75 BBLS 8.7 PPG KWF. - LOSSES TO WELL IN LAST 24 HRS = 180 BBLS 8.7 PPG KWF. 7/31/2012 00:00 - 00:15 0.25 PULL P DECOMP CREW CHANGE. - PJSM WITH CENTRILFT, TOOL PUSHER, WSL AND CREW. - REVIEW PLAN FOR LID ESP PUMP. - DISCUSS PLAN FOR NON SHEARABLES ACROSS BOP. 00:15 - 02:00 1.75 PULL P DECOMP SEND ESP CABLE TO UNIT AND SECURE. - L/D ESP PUMP AND MOTOR AS PER CENTRILIFT REP. - PREP SPOOL FOR REMOVAL. - CENTRILIFT INSPECT PUMP AND MOTOR. - SHAFT ON TOP PUMP SEIZED UP. - SOME SCALE ON HOUSING. - NO SAND FOUND. - ALL HARDWARE RECOVERED. Printed 8/20/2012 12:14:25PM Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- 00VK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'15.912 "2 Long: 0149 °26'06.260 "W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 03:00 1.00 PULL P DECOMP PJSM R/D ESP SHEAVE AND TRUNK. - LOAD PUMP INTO PIPESHED. - CLEAR RIG FLOOR. - LOAD 2 3/8" HANDLING EQUIP TO RIG FLOOR. - USE CONTINUOUS HOLE FILL WITH 8.7 PPG BRINE. - INSTALL 6.625" WEAR RING. RI2LDS. 03:00 - 03:45 0.75 ZONISO P DECOMP PJSM FOR BHA. - M/U 5.87 "OD CHAMP PACKER WITH STINGER BHA AS PER HES REP. - M/U 2 3/8" MULE SHOE, 2 JTS 2 3/8" TBG, XO, CHAMP PACKER, SER# 10256837, XO. 03:45 - 08:30 4.75 ZONISO P DECOMP RIH WITH CHAMP PACKER BHA ON 2 7/8" TBG FROM DERRICK. - MONITOR RIH SPEED AS TO NOT SURGE WELL. - USE CAUTION SETTING IN SLIPS AND NOT TO TURN PIPE. - PUW =85K, SOW =70K. 08:30 - 10:00 1.50 ZONISO P DECOMP P/U 2 PUPS AND SPACE OUT TO SET 7" CHAMP TEST PACKER. PJSM SET AT 8500' MD - R/U TEST EQUIPMENT .( - WSL VERIFY VALVE ALIGNMENT. V - MIT -IA, 7" 26 #, L -80 CSG TO 2500 PSI FOR 30 CHARTED MINUTES. PASSFO CRT -AK -10-45 7 - LEAK TIGHT - WSL / TOOLPUSHER VERIFY NO TRAPPED PRESSURE, OPEN RAMS AND CIRCULATE THROUGH KILL LINE TO VERIFY OPEN. - RECEIVED PERMISSION TO PROCEED FROM WTL AT 10:30 HRS. 10:00 - 11:00 1.00 ZONISO P DECOMP HES REP RELEASE CHAMP PACKER - FLOW CHECK WELL FOR 15 MINUTES. 11:00 - 16:00 5.00 ZONISO P DECOMP PJSM. POOH, STAND BACK 2 7/8" EUE 8 RND TBG. - CONTINUOUS HOLE FILL, LOSING APPROXIMATELY 6 BPH. - LAST 12 HRS WELL TOOK 35 BBLS 8.7 PPG BRINE. 16:00 - 16:30 0.50 ZONISO P DECOMP PJSM. UD PACKER AND TAIL PIPE ASSEMBLY. 16:30 - 18:00 1.50 RUNCOM P RUNCMP CLEAR / CLEAN RIG FLOOR. - PULL 6.625" WEAR RING. - RIG UP TO SERVICE PUMP. - PJSM, HANG ESP SHEAVE. - INSTALL GUARD ON BOTTOM OF PUMP. - TEST RIG ESD. 18:00 - 18:15 0.25 RUNCOM P RUNCMP PJSM WITH CENTRALIFT REP, WSL, TOOL PUSHER AND CREW. - FOR P/U ESP MOTOR ASSEMBLY. REVIEW DDI SOP. - REVIEW WELL PLAN STEPS. - DISCUSS PLAN FOR NON SHEARABLES ACROSS BOP. Printed 8/20/2012 12:14:25PM • North America - ALASKA - BP Operation Summary Report ' Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- 00VK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'15.912 "2 Long: 0149 °26'06.260 "W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:15 - 21:00 2.75 RUNCOM P RUNCMP P/U ESP PUMP AND MOTOR ASSEMBLY AS PER CENTRALIFT REP. - CENTRALIZER, WLMGU, KMH 190 HP MOTOR, LOWER AND UPPER TANDEM SEALS, GAS SEPERATOR, PUMP,DISCHARGE HEAD. - FILL PUMP WITH MINERAL OIL AS PER CENTRALIFT REP. - POH AND MONITOR WELL. - USE CONTINUOUS HOLE FILL WITH 8.7 PPG BRINE. 21:00 - 23:00 2.00 RUNCOM P RUNCMP WITH SWS R/D ON MPE -11 - SET SPOOLING UNIT IN PLACE WITH BED TRUCK. - R/U GENERATOR FOR SAME. - SET RECONDITIONED ESP CABLE SPOOL IN UNIT. 23:00 - 23:30 0.50 RUNCOM N RREP RUNCMP WELDER REPAIR BRACKET ON SPOOLER SHAFT. 23:30 - 00:00 0.50 RUNCOM P RUNCMP PJSM, PULL ESP CABLE TO RIG FLOOR. - LAST 12 HRS WELL TOOK 49 BBLS 8.7 PPG BRINE. - LAST 24 HRS WELL TOOK 84 BBLS 8.7 PPG BRINE. 8/1/2012 00:00 - 03:00 3.00 RUNCOM P RUNCMP RIH WITH ESP MOTOR AS PER CENTRILIFT., INSTALL CONTROL LINE AND ESP CABLE. - TEST CONTROL LINE. �Cj INSTALLED- , - 3 FLAT GUARD CLAMPS. - 5 PROTECTILIZERS. - 2 SINGLE PIN CANNON CLAMPS. 03:00 - 05:00 2.00 RUNCOM P RUNCMP RIH WITH 2 7/8" ESP COMPLETION AS PER TALLY TO 630' - RIH 2.5 - 3 MINUTES PER STAND. - INSTALL CANNON CLAMP ON EVERY COLLAR FOR THE FIRST 9 JTS. - THEN INSTALL CANNON CLAMPS EVERY OTHER JT. - MONITOR UNSPOOLING ESP CABLE. - USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE. - CONTINUOUS HOLE FILL WITH 8.7 PPG BRINE - FLUSH TBG AND TEST CONDUCTIVITY ON ESP ELECTRIC CABLE EVERY 2000'. - USE BEST 0 LIFE PIPE DOPE ON TBG THREADS. - TORQUING ALL 2 7/8" EUE CONNECTIONS TO 2300 FT /LBS. Printed 8/20/2012 12:14:25PM • orth America - AL Operation Summary Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- 00VK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'15.912 "2 Long: 0149 °26'06.260 "W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 11:30 6.50 RUNCOM P RUNCMP RIH WITH 2 7/8" ESP COMPLETION AS PER TALLY TO 630' - RIH 2.5 - 3 MINUTES PER STAND. - INSTALL CANNON CLAMPS EVERY OTHER JT. - MONITOR UNSPOOLING ESP CABLE. USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE. '- CONTINUOUS HOLE FILL WITH 8.7 PPG BRINE - FLUSH TBG AND TEST CONDUCTIVITY ON ESP ELECTRIC CABLE EVERY 2000'. - USE BEST 0 LIFE PIPE DOPE ON TBG THREADS. - TORQUING ALL 2 7/8" EUE CONNECTIONS TO 2300 FT /LBS. HOURLY LOSS RATE @ 5 - 6 BPH. - RIH TO 7516'. 11:30 - 14:30 3.00 RUNCOM P RUNCMP PJSM. CHANGE OUT ESP CABLE REELS. - MAKE REEL TO REEL SPLICE & TEST, OK. SPLICE @ 7616'. 14:30 - 16:00 1.50 RUNCOM ` P RUNCMP CONTINUE IN HOLE W/ 2 7/8" EUE 8 RND ESP COMPLETION. RAN (3) FLAT GUARDS, (5) PROTECTROLIZERS & 147 CANNON CLAMPS. - FLUSH TBG. PUMP 5 BBLS AT .5 BPM AT 1930 PSI. 16:00 - 18:30 2.50 RUNCOM . P RUNCMP PJSM. PICK UP LANDING JT. - MAKE UP HANGER, INSTALL PENETRATOR. - INSTALL BRASS SHIPPING CAP ON PENETRATOR. - ATTACH FIELD CONNECTION. - PLUG INTO PENETRATOR AND TEST AS PER CENTRILIFT. 18:30 - 19:00 0.50 RUNCOM P RUNCMP P/U WT 100K. S/O WT 79K.( INCLUDES 40K WITH TOP DRIVE) - LAND HANGER 23.30' RKB. SET AT 8558.95' MD. - FMC RILDS. 19:00 - 20:30 1.50 RUNCOM P RUNCMP SET TWC. - PERFORM 500 PSI ROLLING TEST UNDER TWC. - PUMP 3 BPM 500 PSI. FINAL 2.4 BPM 500 PSI. CHARTED, - CLOSE BLIND RAMS, TEST ABOVE TWC 250/3500 PSI 5 MIN EA. CHARTED. 20:30 - 21:30 1.00 BOPSUR P RUNCMP PJSM. REVIEW DDI SOP FOR ND BOP. - WITH 2 BARRIRES IN PLACE- TESTED TWC /HANGER SEALS AND 8.7 PPG KWF. - BLOW DOWN LINES. DRAIN STACK. - N/D BOPE Printed 8/20/2012 12:14:25PM Common Well Name: MPE -14 AFE No Event Type: WORKOVER (WO) Start Date: 7/28/2012 End Date: X4- OOVK1 -E: (900,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/11/2009 12:00:00AM Rig Release: 8/2/2012 9 p 9 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'15.912 "2 Long: 0149 °26'06.260 "W Active Datum: ORIG KELLY BUSHING @57.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ( ft) 21:30 - 00:00 2.50 WHSUR P RUNCMP PJSM. N/U TREE AND ADAPTOR FLANGE. - FMC TEST TREE VOID TO 5000 PSI. - PRESSURE TEST TREE AND ADAPTOR FLANGE TO 250/5000 PSI WITH DIESEL. - TEST 5 MIN EA. CHART TESTS. - CENTRILIFT MAKE FINAL ESP CONDUCTIVITY TEST. - AT HANGER PENETRATOR. ALL 3 PHASE TO PHASE = 3.8 - PHASE TO GROUND MEG = 770 - LAST 12 HRS WELL TOOK 62 BBLS 8.7 PPG BRINE. - LAST 24 HRS WELL TOOK 122 BBLS 8.7 PPG BRINE. 8/2/2012 00:00 - 00:30 0.50 WHSUR P RUNCMP CREW CHANGE. PJSM. - CONTINUE WITH 5000 PSI TEST FOR TREE WITH DIESEL. - CHART TEST. 00:30 - 02:00 1.50 WHSUR P RUNCMP PJSM WITH DSM. R/U AND TEST LUBRICATOR TO 250/3500 PSI. - PULL T\NC. TEST LUBRICATOR TO 250/3500 PSI. INSTALL BPV. - R/D LUBRICATOR. 02:00 - 02:30 0.50 WHSUR P RUNCMP - PERFORM 500 PSI ROLLING TEST UNDER BPV. - PUMP 3 BPM AT 500 PSI FOR 10 MIN. CHART TEST. 02:30 05:00 2.50 WHSUR P RUNCMP SECURE TREE. BLOW DOWN LINES. - CLEAN PITS. - VAC OUT SLOP TANK. - RELASE RIG FROM MPE -14A AT 05:00 HRS. Printed 8/20/2012 12:14:25PM r • • Tree: Cameron 2 9/16" 5M Orig. KB Elev. = 57.60' (N 27E) Wellhead: 11" x 7 1/16" 5M FMC M PU E -14a Orig. GL Elev. = 24.7' Gen 5A Ultra slim, w/ 2 1/2" Tbg Hgr RT To Tbg. Spool = 33.5' (N 27E) 2 7/8: EUE 8rd T &B thread 2 1/2" CIW BPV profile 0 7" Csg tested to 2500 psi @ / 8500' on 7131 /12 20" 91.1 ppf, H-40 112' 0 0 Camco 2 7/8" x 1" I 143' / sidepocket KBMM GLM KOP @ 900' % _ Max. hole angle = 52 deg. @ 5953' Hole angle thru' perfs = > 31 deg. / , NOTE: Well was side tracked Max. DLS = 4.8 @ 5431' 0 ; C TO fr the top of a WS @ 8950' with a CIBP set © 897 9 5/8 ", 40 ppf, L -80 Btrc. 5543' I p 1 • • • • • , Camco 2 7/8" x 1" sidepocket KBMM GLM I 8336' 2 7/8" 6.5 ppf, L -80, EU 8rd Tbg I 2 -7/8" XN Nipple (2.205 ") 8450' ( drift ID = 2.347 ", cap. = 0.0059 bpf) I MK 7" 26 ppf, L -80, NSCC production casing / ( drift ID = 6.151 ", cap. = 0.0383 bpf) 0 3 WeIILift Discharge Gauge 8493' ( cap w/ 2 7/8" tbg inside = 0.02758 bpf) � ' Gauge TVD = 6551' I Centrilift 161 -P11 ESP, SXD I 8498' I /, Gas Separator GRSFTXARH6 8520' _ Intake TVD = 6574' /b-� Tandem Seal Section I 8525' % � GSB3 DB LT /UT SB /SB PFSA mor Motor Rerated to KME -1 0frit 165 hp, 2230 volt, 43 amp I 8538' WeIILift MGU Gauge w/ 8555' I 6 fin centralizer Gauge TVD = 6603' BOT PBR 80-47 Seal Nipple I 8706' -... BOT 7" x 4.5" S -3 Pkr 8745' I BOT KB LTP w/ 4" GS fish neck & 42 -30 Seal Assy. 2.36" ID 4.5" XN Nipple ( 2.750 ") w/ 8816' 11 t plug GS fish neck & 3.00" sea bore & 4.5 " WLEG 8890' I I I I 1.750" min ID. 13 3/16" Solid Lnr Shoe (cD 90731 4$; ' 12 3/8" 4:7# L -80 STL Solid Cemented Lnr 1 I BOT 4.5 x 7" Whipstock @ 8950' 1 - - -> 17" CIBP g 8975' 1 7„ PBTD © 10,105" 1 d€ = 1 ; Perforation Intervals - - I All shots using 1.56" 6 SPF 1606P E 7" x 4.5" Versatrieve Pkr 8985' MD TVD 2 -3/8" Shoe @ 10120' - 9500' -9560' 7043' -7044' Tn @10104' 4.5" 316L 125 Micron Poroplus 9031' 9660' - 9900' 7045' - 7041' Screen 9960' - 10050' 7036' - 7037' 4.5" XN Nipple ( 2.750 ") w/ I 9103' I H plug WLEG 9115' 7" float collar (PBTD) 9260' short joints 8852' -8894' I ■ 7" float shoe 9344' DATE REV BY COMMENTS MILNE POINT UNIT 04 -12 -97 MDO 7" Cased hole Completion 27 05 -08 -97 MDO ESP Completion 4 -ES Well No : MPE -14a 9-15-9/ MDO 2nd ESP Completion 4 -ES 7 -19 -96 MDO ESP Completion /Screen Added 5 S API : 50- 029 - 22734 -01 03 -21 -00 M. Linder RWD4ES 6 -28 -08 Hulme RWO with 3S 11/19/09 Hulme RWO W/ 4E0 Pall ESP and install CTD work stnng BP EXPLORATION (AK) 1/5/10 Hulme CTD Side Track & ESP completion 8/12/12 Hulme RWO w/ Doyon 16 1 DATA SUBMITTAL COMPLIANCE REPORT 8/13/2012 Permit to Drill 2091280 Well Name /No. MILNE PT UNIT KR E -14A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 22734 -01 -00 I MD 10194 TVD 7020 Completion Date 1/6/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Sury Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, GR / CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr III Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt � LIS Verification 8544 10194 Open 3/25/2010 19489 ED , ---C .--- Lis 19489 Induction /Resistivity 8544 10194 Open 3/25/2010 OH LIS GR, ROP, RAD, RAS, RPD, RPS Data Plus CGM & PDF Graphics Log Induction /Resistivity 25 Col 8950 10194 Open 3/25/2010 MD MPR, GR Log r' Induction /Resistivity 5 CoI 8950 10194 Open 3/25/2010 TVD MPR, GR Log Gamma Ray 25 Col 8950 10194 Open 3/25/2010 MD GR Log '� Gamma Ray 5 Col 8540 10210 Open 3/25/2010 Depth Shift Monitor Plot � Rpt ` LIS Verification 8936 9170 Open 4/1/2010 PB1 19495 ED /`C Lis 19495 Gamma Ray 8936 9170 Open 4/1/2010 PB1 OH LIS GR, ROP Data Plus CGM & PDF Graphics Log ' Gamma Ray 25 CoI 8861 9170 Open 4/1/2010 PB1 MD GR III Log f Gamma Ray 5 Col 8930 9180 Open 4/1/2010 PB1 Depth Shift Monitor Plot ED /C Asc Directional Survey 9055 10194 Open Rpt / Directional Survey 9055 10194 Open ED /C Asc Directional Survey 8861 9170 Open PB1 Rpt Directional Survey 8861 9170 Open PB1 Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/13/2012 Permit to Drill 2091280 Well Name /No. MILNE PT UNIT KR E -14A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 22734 -01 -00 MD 10194 TVD 7020 Completion Date 1/6/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL INFORMATION Well Cored? Y D Daily History Received? N Chips Received? 1711-- Formation Tops N Analysis Y -f-td Received? Comments: - - - -- - - -- - -- — -- -- -- - — • Compliance Reviewed By: Date: — 1I — AA-Th ■. 1 • • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 ° Anchorage, Alaska 99501 RE' Attention: Christine Mahnken APR 0 1 10 , Reference: MPE- 14APB1 sk . Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) ; 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) LAC Job #: 2915301 a _ Sent by: Donna Moss Date: 03/31/10 Received by: n Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 7260 Homer Drive BAKER Anchorage, Alaska 99518 O —fa HUGHES Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 / �� . . EC ENED D APR 22113 BAKE -- IFIILIPCM4ES Baker Atlas PRINT DISTRIBUTION LIST COMPAN BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BORODUH WELL NAME MPE- 14APB1 STATE ALASKA FIELD Milne Point Unit DATE 3/31/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: Donna Moss SO #: 2915301 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF 01L & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: o9 -t(9) l 0 ) 6 (9 5 Page 1 of 1 • RE, DVh MAR 2 ki INTE • & Data Transmittal INTEQ Log ata a smittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: MPE -14A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) LAC Job #: 2915301 9o — /2 � 6t-/t Sent by: Donna Moss Date: 03/24/10 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 7260 Homer Drive BAKER MOMS Anchorage, Alaska 99518 Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 • • p ., , . MAR 2 5 2010 / /ate BAKER HILINDIFIES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUNI'Y NORTH SLOPE BOROUGH WELL NAME MPE -14A STATE ALASKA FIELD Milne Point Unit DATE 3/24/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: Donna Moss SO #: 2915301 Copts of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: ( 5L/9 Page 1 of 1 s Ill • RECEIVED STATE OF ALASKA FEB 0 2 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT Aitet0143 Cons. Commission la. Well Status:: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1 b. Well Class: Cberag4 20AAC 25.105 2OAAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 1/6/2010 209 - 128 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 12/14/2009 50 029 - 22734 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/22/2009 MPE -14A 3590' FSL, 1918' FEL, SEC. 25, T13N, R10E, UM 8. KB (ft above MSL): 57,7' 15. Field / Pool(s): Top of Productive Horizon: 626' FNL, 302' FWL, SEC. 31, T13N, R11E, UM GL (ft above MSL): 24.3' Milne Point Unit / Kuparuk River Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 1527' FNL, 868' FWL, SEC. 31, T13N, R11E, UM 10105' 7025' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 569228 y - 6016128 Zone- ASP4 10194' 7020' ADL 025518 & 028231 TPI: x- 571489 y- 6011933 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 572063 y 6011037 Zone- ASP4 None 18. Directional Survey: 181 Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all Togs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD DIR, GR, RES, GR / CCL 8954' 6942' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE ToP BOTTOM TOP l BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.1# H Surface 112' Surface 112' 24" 250 sx Arcticset 1 (Approx.) 9 -5/8" 40# L -80 32' 5543' _ 32' 4587' 12-1/4" 1750 sx PF 'E'. 300 sx Class 'G'. 89 sx PF 'C' 7" 26# L -80 25' 8954' 25' 6942" 8 -1/2" 250 sx Class 'G' 3 - 1/2" x 3 3/16" 9.2# / 6.2# L - 80 8767' 9073' 6782' 7020' 4 - 1/8" Not Cemented 2 - 3/8" 4.7# L - 80 8747' 10120' 6765' , 7024' 3" 19 sx Class 'G' 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 1.56" Gun Diameter, 6 spf 2 -7/8 ", 6.5#, L80 8703' N/A MD TVD MD TVD 4 -1/2" 8706' - 8890' 8745' / 6764' 9500' - 9560' 7043' - 7044' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9660' - 9900' 7045' - 7041' 9960' - 10050' 7036' - 7032' DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protected w/ 38 Bbls of Diesel 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): January 12, 2010 Electric Submersible Pump Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: 1/20/2010 6 Test Period 4 140 30 58 N/A 211 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 181 240 24 -Hour Rate ♦ 560 118 231 Not Available 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 1. LETION ATE None IFlEa . RBDMS FEB 0 31010 all Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE ` - .27_ Q Su bmit Original Only • 1 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C1 9047' 7007' None Kuparuk B / Kuparuk B8 9103' 7031' Kuparuk B7 9121' 7036' Kuparuk B6 9930' 7039' Formation at Total Depth (Name): Kuparuk B6 9930' 7039' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ` / O Signed: Terrie Hubble �� I QC�!` T itle: Drilling Technologist Date: /v, llb MPE -14A 209 -128 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Sean McLaughlin, 564 -4387 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/10/2009 02:00 - 02:05 0.08 MOB P PRE RIG RELEASED FROM W -25A AT 0200 HRS 02:05 - 04:00 1.92 MOB P PRE MOVE RIG FROM W -PAD TO SPINE ROAD. 04:00 - 09:00 5.00 MOB P PRE TURN ON TO SPINE ROAD HEADING WESTWARD TOWARDS MPU. 09:00 - 17:00 8.00 MOB P PRE TURN ON TO MP ROAD HEADING TOWARDS MP E -PAD. 17:00 - 17:30 0.50 MOB P PRE RIG ARRIVES ON MP E -PAD. SPOT RIG. RIG ACCEPT 17:00 HRS 12/10/09. 17:30 - 18:45 1.25 MOB P PRE ENTIRE RIG CREW ATTENDS ATP AT MPU CAMP. 18:45 - 19:00 0.25 RIGU P PRE PJSM FOR NIPPLE UP BOPE. 19:00 - 00:00 5.00 RIGU P PRE LEVEL RIG. SETY HANDY BERM CONTAINMENT. SPOT MISC EQUIP. NIPPLE UP BOPE. CONTINUED ON DIMS REPORT 12/11/09. 12/11/2009 00:00 - 02:30 2.50 RIGU P PRE CONTINUED FROM DIMS REPORT DATED 12/10/09. CONTINUE NU BOPE. 02:30 - 06:00 3.50 RIGU P PRE INSTALL 3" SLIP RAMS IN LOWER CAVITY OF UPPER COMBIS. 06:00 - 12:00 6.00 RIGU P PRE NIPPLE UP MANAGED PRESSURE DEPLOYMENT CIRCULATION LOOP TO WING AND MUD MANIFOLD. FUNCTION TFST RfPF 12:00 - 14:30 2.50 RIGU P PRE LIQUID PACK STACK AND MANAGED PRESSURE DEPLOYMENT CIRCULATION LOOP WITH WATER. PJSM FOR BOPE TEST (WITNESS WAIVED BY AOGCC REPRESENTATIVE CHUCK SCHEVE). BEGIN TO PRESSURE UP, FIND LEAK ON CHOKE HOSE AT GREYLOCK. REPLACE RING IN GREYLOCK. LOAD PITS WITH GEOVIS. 14:30 - 15:00 0.50 RIGU P PRE PRESSURE TEST LOOP AND BOPE 250/3500 PSI FOR 5 MINUTES (BODY TEST). 15:00 - 18:00 3.00 RIGU P PRE TEST BOPE 250/3500 PSI FOR 5 MINUTES AS PER STATE REGULATIONS. 18:00 - 18:30 0.50 RIGU P PRE CREW C/0. PJSM FOR CONTINUING BOPE TEST. 18:30 - 22:00 3.50 RIGU P PRE CONTINUE TESTING BOPE. MU 3" TEST JOINT. TEST RAMS, LD TEST JOINT. DRAWDOWN TEST. 22:00 - 22:15 0.25 RIGU P PRE PJSM FOR REPLACING VALVE (BOP #17) WHICH 4� P� EXPERIENCED A THROUGH -BORE LEAK. 22:15 - 00:00 1.75 RIGU P PRE REPLACE VALVE (BOP #17). 4'' CONTINUED ON DIMS REPORT 12/12/09. 12/12/2009 00:00 - 00:30 0.50 RIGU P PRE CONTINUED FROM DIMS REPORT 12/11/09. PT VALVE BOP #17. 00:30 - 01:00 0.50 RIGU P PRE PJSM PRIOR TO REPLACING BX 154 RING GASKET ON SWACO FLANGE. 01:00 - 02:30 1.50 RIGU P PRE REPLACE RING GASKET ON SWACO FLANGE. PT SAME. 02:30 - 03:15 0.75 RIGU P PRE SPOOL NEW SLICKLINE ONTO WINCH DRUM. TWIST TEST SLICKLINE: 25 TURNS, CLEAN BREAK. GOOD TEST. 03:15 - 03:40 0.42 RIGU P PRE PJSM FOR PICKING UP SLICKLINE LUBRICATOR. 03:40 - 09:45 6.08 RIGU P PRE RIGGING UP SLICKLINE LUBRICATOR. REBUILD STUFFING BOX, ROPE SOCKET. SET BACK LUBRICATOR FILL CT W/ RIG WATER AND CIRC IN BUNG HOLE 09:45 - 12:00 2.25 RIGU P PRE SAFETY MTG W/ MPU VALVE CREW. BRING LUBRICATOR TOOLS TO FLOOR. FILL TREE AND STACK W/ DIESEL. PULL 4" BPV AND FOUND NO PRESSURE ON WELL, IA 23, Printed: 1/25/2010 12:06:49 PM BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/12/2009 09:45 - 12:00 2.25 RIGU P PRE OA 18 RDMO VALVE CREW 12:00 - 13:00 1.00 RIGU P PRE SAFETY MTG. ND WING VALVE COMPANION BLIND FLANGE W/ 1/2" NPT CHEMICAL INJECTION PORT DUE TO THREADED CONNECTION. NU INTERIM 3650 PSI RATED BLIND FLANGE WHILE SOURCING CORRECT 5K FLANGE 13:00 - 15:00 2.00 BOPSUF P PRE SAFETY MTG. PU INJECTOR AND STAB ON. PT BLIND FLANGE, PACKOFF AND INNER REEL VALVE 250/3500. FIX THREE DRIPS 15:00 - 15:30 0.50 STWHIP P WEXIT SAFETY MTG. MU NOZZLE BHA 15:30 - 17:10 1.67 STWHIP P WEXIT RIH W/ 3" NOZZLE CIRC 0.51/200 FW WHILE TAKE DIESEL. FP TO TIGER TANK TO 8000' 17:10 - 18:30 1.33 STWHIP P WEXIT POH CIRC 1.63/1800 WHILE CYCLE SWACO CHOKE AND CHECK FOR CORRECT OPERATION W/ BOTH CREWS 18:30 - 18:45 0.25 STWHIP P WEXIT PJSM, FLOW CHECK. 18:45 - 19:00 0.25 STWHIP P WEXIT LAY DOWN NOZZLE ASSEMBLY. 19:00 - 20:30 1.50 STWHIP P WEXIT CUT CT UNTIL FIND WIRE (CUT 350' CT). TEST WIRE, REBOOT. MU INJECTOR. PERFORM SLACK MANAGEMENT. 20:30 - 23:30 3.00 STWHIP P WEXIT INSTALL CTC, PULL TEST TO 30K LB. REHEAD BHI, PT CONNECTOR 4000 PSI. 23:30 - 00:00 0.50 STWHIP P WEXIT PUMP SLACK FORWARD. T /I /O: 0/17/20 PSI. CONTINUNED ON DIMS REPORT 12/13/09. 12/13/2009 00:00 - 02:00 2.00 STWHIP N HMAN WEXIT CONTINUED FROM DIMS REPORT 12/12/09. T /I /O: 0/17/20 PSI. INSTALLED API 5000 BLIND FLANGE ON COMPANION SIDE OF FLOW CROSS (REPLACING ANSI 1500 FLANGE FROM SAME). PT TO 3000 PSI. 02:00 - 03:00 1.00 STWHIP P WEXIT PJSM FOR PRESSURE DEPLOYMENT PRACTICE RUN. 03:00 - 07:00 4.00 STWHIP P WEXIT Mll BHI TOOLS. PRACTICE RUN OF PRESSURE fFPI QYMENT. 07:00 - 07:45 0.75 STWHIP P WEXIT SAFETY MTG. LD DUMMY BHA. PT LUBRICATOR TO 2500 PSI. BREAK OFF LUBRICATOR AND FOUND SL HAD PARTED -3' FROM ROPE SOCKET. ASSUME THAT SL WAS NOT TAGGED UP PRIOR TO PT ATTEMPT TO BLOW DOWN CELLAR LINES THRU CHOKE LINE AND FOUND AN OBSTRUCTION 07:45 - 08:45 1.00 STWHIP N HMAN WEXIT RETHREAD SL THRU LUB, REBUILD ROPE SOCKET. STANDBACK LUB ASSY STEAM CHOKE LINE 08:45 - 13:30 4.75 STWHIP N RREP WEXIT CONTINUE TO TROUBLESHOOT RESTRICTION IN CHOKE LINE. DETERMINE LINE IS NOT FROZEN, THEN WORK TO FIND RESTRICTION. FIND OBSTRUCTION ABOUT 10' AND TWO 90'S UPSTREAM FROM GAS BUSTER. ALTERNATE USING AIR, MUD AND SNAKES TO MOVE SOLID GREASE BALL AND CIRC FREELY 13:30 - 13:45 0.25 STWHIP P WEXIT SAFETY MTG PRIOR TO MU BHA 13:45 - 16:30 2.75 STWHIP P WEXIT BLOW DOWN CIRC LOOP, KILL LINE AND CHOKE LINE PULL TEST SL TO MAX -1800# MU MILLING BHA FOLLOWING DEPLOYMENT SCHEDULE, BUT WO PRESSURE FIND MU POINT IS 44" FROM NO -GO, TAG UP IS 1.6' 16:30 - 18:10 1.67 STWHIP P WEXIT RIH CIRCULATING THROUGH MILL 0.51/282 Printed: 1/25/2010 12:06:49 PM • BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/13/2009 18:10 - 19:20 1.17 STWHIP P WEXIT TIE IN AT 8550' - 8850' W/ GR. CORRECTION OF +9.5'. 19:20 - 20:00 0.67 STWHIP P WEXIT MAKE CCL PASS FROM 8500' TO 8900'. 20:00 - 20:20 0.33 STWHIP P WEXIT TAG WHIPSTOCK AT 8956.9 WHILE PUMPING AT MIN RATE. 20:20 - 20:40 0.33 STWHIP P WEXIT BEGIN MILLING WINDOW. 2.17 BPM AT 3480 PSI FREESPIN. 20:40 - 22:00 1.33 STWHIP P WEXIT MILLING AHEAD. AT 21:10 HRS, RECEIVE NOTIFICATION FROM TOWER PUSHER THAT THERE HAS BEEN A SEWAGE RELEASE FROM THE RIG CAMP ON MP A -PAD. TOWER PUSHER BEGINS TO TROUBLESHOOT /STOP LEAK, CO. MAN BEGINS MAKING NOTIFICATIONS. NOTIFY MP RADIO, WHO NOTIFIES MP ENVIRONMENTAL, VAC TRUCK DRIVER, AND MP A -PAD OPERATOR. CO. MAN ALSO CALLS DRILLING HSE ADVISOR, CT DRILLING SUPERINTENDENT, AND MP WELLS GROUP. LEAK ISOLATED, APPROX VOLUME OF 20 GALLONS (LATER AMENDED TO APPROX 84 GALLONS). MP ENVIRONMENTAL ON LOCATION. SEWAGE VAC TRUCK ON LOCATION. DRILLING HSE TO ASSIST IN CREATING TRACTION REPORT IN THE AM. 22:00 - 23:15 1.25 STWHIP P WEXIT SWAP TO GEOVIS DOWN COIL THROUGH BIT WITH WATER RETURNS TO PIT 5. DIRTY VAC TYING IN TO PIT 5 TO TAKE WATER RETURNS. PRIOR TO SWAPPING TO GEOVIS, MILLING AHEAD AT 2.18 BPM AT 3700 PSI. SEEING OCCASIONAL MOTOR WORK (STACKING -1500 LB AT SURFACE WITH AN INCREMENTAL -200 PSI MOTOR WORK, MILLS OFF). 23:15 - 00:00 0.75 STWHIP P WEXIT STARTING TO GET GEOVIS/WATER INTERFACE BACK IN PITS. WAIT FOR CLEAN GEOVIS, THEN SWAP TO MUD PIT. CONTINUE CIRCULATING GEOVIS TO PIT 2. CIRC PRESSURE STABLE AT 2960 PSI AT 2.17 BPM, WHP = 70 PSI. PU. UP WEIGHT CLEAN AT 24,000 LB. CIRC PRESSURE 2960 PSI AT 2.17 BPM. INCREASE CIRC RATE. NEW FREESPIN 3310 PSI AT 2.41 BPM WITH 50 PSI WHP (FULL OPEN CHOKE). EQUIVALENT ECD IS 9.79 PPG. BEGIN TO APPLY BACKPRESSURE TO MAINTAIN 11.0 PPG ECD. ABLE TO HOLD 11.0 PPG EMW BY HOLDING 505 PSI ON CHOKE, 3750 PSI CIRC PRESSURE, 2.41 BPM. RBIH AND ENGAGE AT 8958.3'. SEE 200 LBS WOB INCREASE AND 40 PSI MOTOR WORK. MILL AHEAD. IAP STARTING TO INCREASE SLIGHTLY (FROM -15 PSI TO 355 PSI SINCE WE SWAPPED TO WARM GEOVIS). MONITOR IAP FOR CONTINUED THERMAL EXPANSION. T /I /0: 505/355/26 CONTINUED ON DIMS REPORT 12/14/09. 12/14/2009 00:00 - 03:15 3.25 STWHIP P WEXIT CONTINUED FROM DIMS REPORT 12/13/09. T /I /0: 513/344/28 PSI TJMF Mil 1 ING AT WINDOW. FREESPIN 3750 PSI, 2.41 BPM, 505 PSI WHP. SEE MOTOR WORK AT 8959.0'. STACK 3000 LB WOB AND SEE INCREMENTAL 500 PSI MOTOR WORK. MILLS OFF. CONTINUE TIME DRILLING AHEAD. Printed: 1/25/2010 12:06:49 PM • BP EXPLORATION Page 4 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/14/2009 03:15 - 07:00 3.75 STWHIP P WEXIT MILLING AHEAD. HOLDING 500 PSI WHP, CIRCULATING AT 3770 PSI AT 2.43 BPM. ECD AT BIT IS 11 PPG. TIME MILLING AT A RATE OF 0.1' PER 6 MINUTES. KEEPING -1000 LB WOB AND CONSISTENTLY SEEING -100 PSI MOTOR WORK. PVT 251 07:00 - 09:00 2.00 STWHIP P WEXIT DRILL FROM 8965.3' 2.43/3800 w/ 100 -150 psi diff, 1.5k wob, vib =4 holding 500 psi induced whp of 11.0 ppg ECD PVT 251 09:00 - 10:10 1.17 STWHIP P WEXIT 8970.3' 2.43/3800 W/0 PSI MW, 0.72K WOB, VIB =5 DRILL TO 8972.7' 10:10 - 10:55 0.75 STWHIP P WEXIT REAM AND BACKREAM 2.43/3655 VIB =4. DRY DRIFT CLEAN PVT251 10:55 - 12:30 1.58 STWHIP P WEXIT POOH CIRC THRU MILL 2.38/3600 WHILE FOLLOWING PRESSURE SCHEDULE FOR 11.0 PPG EMW VIB =4 DURING COMPLETE TOH 12:30 - 12:45 0.25 STWHIP P WEXIT TAG UP, SD BHI MWD. CIRC AT 0.38/1640 HOLDING 780 PSI WHP WHILE CONDUCT SAFETY MTG FOR UNDEPLOYMENT PVT 218 IA 460, OA 38 12:45 - 15:00 2.25 STWHIP P WEXIT PRESSURE UNDEPLOY BHA USING MPD LOOP HOLDING 780 PSI INDUCED WHP 15:00 - 15:15 0.25 STWHIP P WEXIT LD BHA. MILLGAUGED 3.77" NG, BUT THE LOWER 1/2 OF THE MILL GAUGE WAS LESS THAN 3.70" W/ NO DIAMONDS REMAINING. THERE WAS ALSO A CIRCULAR GROOVE AT THE STEP CHANGE. THE SR WAS 3.79" NG. LD LOAD OUT BTT TOOLS 15:15 - 16:15 1.00 DRILL P PROD1 BHI RECONFIGURE BHA 16:15 - 16:30 0.25 DRILL P PROD1 SAFETY MTG PRIOR TO PRESSURE DEPLOY 16:30 - 18:50 2.33 DRILL P PROD1 PRESSURE DEPLOY BUILD ASSY W/ 3.1 DEG MOTOR 18:50 - 20:45 1.92 DRILL P PROD1 RIH CIRCULATING THROUGH OPEN EDC AT 0.5 BPM AT 1700 PSI, HOLDING BACKPRESSURE TO MAINTAIN 11.0 PPG ECD. 20:45 - 21:15 0.50 DRILL P PROD1 TIE IN @ 8590', CORRECTION OF -6.5'. 21:15 - 23:30 2.25 DRILL P PROD1 TAG BOTTOM AT 8971'. ON BOTTOM DRILLING (EDC NOW CLOSED). ROP SLOW, ROUGHLY 0.1 - 0.2 FPM. PUMP RATE OF 2.24 BPM, FREESPIN OF 3600 PSI, HOLDING -4000 LB WOB, HOLDING 505 PSI WHP (11.0 PPG ECD) SEEING ITERATIVE MOTOR WORK IN THE RANGE OF 50 PSI TO 100 PSI. MILL AHEAD TO 8987.4' 23:30 - 00:00 0.50 DRILL P PROD1 AT 8987.4, PU CLEAN AT 21000 LB. INCREASE PUMP RATE TO 2.55 BPM. FREESPIN CIRCULATING PRESSURE OF 4080 PSI (PUMP PRESSURE IS 4200 PSI). HOLDING 510 PSI WHP (11.0 PPG ECD). VIBRATION OF 2. RBIH DRILLING. ENGAGE AT 8986.8'. SLOWLY WORK INTO IT. HOLDING 2500 LB WOB AND 50 PSI MOTORWORK AT MIDNIGHT, SLOWLY STACKING MORE WEIGHT ON BIT. T /I /O: 510/492/34 CONTINUED ON DIMS REPORT 12 -15 -09 12/15/2009 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUED FROM DIMS REPORT 12- 14 -09. T /I /O: 502/515/37 DRILLING ON BOTTOM. GRADUALLY INCREASE WOB TO 4000 LB W/ CIRC PRESSURE OF 4150 PSI ( -70 PSI MOTOR WORK). STALL #1. DOWN ON PUMP. Printed: 1/25/2010 12:06:49 PM • BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/15/2009 00:00 - 00:30 0.50 DRILL P PROD1 PU CLEAN AT 22000 LB. RE- ESTABLISH FREESPIN AT 2.53 BPM AT 3930 PSI. RBIH DRILLING. ENGAGE AT 8994.4' AND SLOWLY START STACKING WEIGHT. 00:30 - 04:20 3.83 DRILL P PROD1 DRILLING AHEAD MAKING CONSISTENT PROGRESS AT 4130 PSI CIRC PRESSURE (200 PSI MOTOR WORK) AND 3500 LB WOB. HOLDING 510 PSI WHP (11.0 ECD). TOOL VIBRATION OF 2. MAKING BETWEEN 0.2 AND 0.3 FPM. AS PER GEO: CUTTINGS LOOK LIKE D SHALE. NO LONG SLIVERS OR IRREGULARLY LARGE CHUNKS COMING BACK, WHICH IS A GOOD INDICATION THAT HOLE IS STABLE AND FORMATION IS NOT BREAKING OFF. DD TAKES SURVEY (WITH HIS SENSOR AT 8990' AND BIT AT 9022'). DOGLEG OF 35 DEGREES. BEGIN TO CORRECTIVELY STEER FROM SIDE TO SIDE TO REDUCE RATE OF BUILD; STEERING TO ENSURE WE LAND BELOW B8 SHALE. 04:20 - 06:00 1.67 DRILL P PROD1 ROP STILL RELATIVELY STEADY AT 0.2 FPM WITH PARAMETERS SAME AS ABOVE. TRY TO INCREASE WOB, STALL AT 4000 LB WOB AT 9044'. PU FOR WIPER TRIP. PU CLEAN AT 22,600 LB. FREESPIN 3980 PSI AT 2.55 BPM WITH 500 PSI BACKPRESSURE (11 PPG ECD). VIBRATION OF 4. RBIH DRILLING. ENGAGE AT 9044'. MILL AHEAD AT 3500 LB WOB WITH -4100 PSI CIRC PRESSURE (120 PSI MOTOR WORK). STALL TWICE AT 9048'. REPEAT WIPER TRIP. RBIH AND TIME DRILL INTO TAG DEPTH. RE- ENGAGE WITHOUT STALL AND CONTINUE DRILLING AHEAD. 06:00 - 09:00 3.00 DRILL P PROD1 AT 9073' AND DRILLING AHEAD. FREESPIN 3870 PSI. PUMP RATE 2.51 BPM. HOLDING 485 PSI BACKPRESSURE (11.02 PPG ECD). AVERAGE WOB OF 3500 LB. AVERAGE MOTOR WORK OF 70 PSI. VIBRATION IS 3. START SEEING FASTER PENETRATION IN INTERBEDDED SANDS AND GR IS BECOMING CLEANER TOO 09:00 - 10:35 1.58 DRILL P PROD1 9124' HAVING OCCASIONAL STALLS. HOLDING 460 PSI WHP TO MAINTAIN 11.0 ECD DUE TO MUD LOADING UP W/ SOLIDS. TURN ON CENTRIFUGES -A NORDIC THING. DRILL TO 9170' WHILE PREP TF FOR LATERAL BHA. SEE 10' OF GOOD TARGET SAND ON GR 10:35 - 10:45 0.17 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN 10:45 - 11:30 0.75 DRILL P PROD1 WIPER BACK IN HOLE AND SET DOWN AT 9065'. SPEND 20+ MINUTES REAMING AND BACKREAMING TF CHANGE AREA. CONTINUE WIPER BACK TO TD WHILE SLOW REAM AT 5' /MIN THRU 9065 -9130' WHICH IS TF CHANGES AND SHALE/SAND CHANGE AREA (72 DEG @ 6977' TVD). RETAG TD AT 9170' 2.52/3850 11:30 - 11:55 0.42 DRILL P PROD1 WIPER BACK OOH AT 10' /MIN THRU SAME AREA TO ADJUST FOR TF CHANGES. HAD 3K OP W/ MW AT 9065', OTHERWISE CLEAN. PULL THRU WINDOW, CLEAN. OPEN EDC 11:55 - 12:40 0.75 DRILL P PROD1 JET TUBING W/ OPEN EDC 2.60/3600 TO 7000' 12:40 - 13:00 0.33 DRILL P PROD1 RBIH WHILE START 20 BBL HI -VIS SPACER PILL FOLLOWED BY 11.0 NaCL BRINE Printed: 1/25/2010 12:06:49 PM • 1 BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/15/2009 13:00 - 13:10 0.17 DRILL P PROD1 LOG TIE -IN DOWN FROM 8600', CORR +2' 13:10 - 14:10 1.00 DRILL P PROD1 RIH TO 8960' WHILE FIN DISPLACEMENT. LET 10 BBLS HI -VIS COME OUT OF EDC AT 8920', THEN PARK W/ EDC AT 8910'. DISPLACE WELLBORE W/ 11.0# NaBr 2.40/3560 HOLDING INITIAL 500 PSI WHP TO GIVE 11.0 ECD. GRADUALLY OPEN CHOKE 14:10 - 15:45 1.58 DRILL P PROD1 POH W/ HI -VIS NEAR SURFACE AND ECD AT 11.05 PPG CONTINUE TO CIRC 2.22/3600. PAINT FLAG AT 8369.7' OR 8300' EOP POOH W/ OPEN CHOKE AFTER RETURNS WERE 10.6 PPG WHILE CIRC 1.0/ 15:45 - 16:00 0.25 DRILL P PROD1 TAG UP, FLOW CHECK WHILE HAVE SAFETY MTG FOR LD BHA AND PUMP SLACK 16:00 - 16:45 0.75 DRILL P PROD1 LD DRILLING BHA 16:45 - 17:50 1.08 CASE P LNR1 CUT OFF CTC. PUMP SLACK FORWARD. CUT 280' OF ELINE. 17:50 - 18:30 0.67 CASE P LNR1 MU BOT CTC PULL TEST TO 25K, PT TO 4000 PSI. 18:30 - 19:45 1.25 CASE P LNR1 PREP FLOOR TO RUN LINER. 19:45 - 20:00 0.25 CASE P LNR1 PJSM FOR RUNNING LINER 20:00 - 21:45 1.75 CASE P LNR1 PU ALUMINUM GUIDE SHOE, 9 JTS OF 3- 3/16" LNR, XO, 3 -1/2" PUP. LINER HANGER. DEPLOYMENT ASSY. XO. HILOAD, DBPV, XO, 2 JTS PH6, XO, QUICK CONNECT, CTC , STAB ON INJECTOR. 21:45 - 00:00 2.25 CASE P LNR1 RIH CIRC 0.33 BPM, 110 PSI TRIPS SET TO 500 PSI. 12/16/2009 00:00 - 00:10 0.17 CASE P LNR1 CONT RIH, STOP AT EOP FLAG WT CHK (21K) AND TIE IN ( -14.8' CORRECTION), CONT RIH, TAG UP AT 9066' 00:10 - 01:00 0.83 CASE N DPRB LNR1 PU CLEAN, ATTEMPT TO RIH AT 40 FPM, SET DOWN 4 TIMES AT 9066', RIH @ 75 FPM. SET DOWN HARD AT 9066', SET DOWN 10+ TIMES, CANNOT GET THROUGH, DECIDE TO POOH AND TRY NEW SHOE TRACK. 01:00 - 02:50 1.83 CASE N DPRB LNR1 POOH 02:50 - 03:00 0.17 CASE N DPRB LNR1 STAND BACK INJECTOR, START LD BHA 03:00 - 03:15 0.25 CASE N DPRB LNR1 SHUT DOWN TO DISCUSS CHANGE IN PLANS AND PROPER BREAKOUT OF BAKERLOCKED BHA TO SAVE RUNNING TOOL 03:15 - 03:30 0.25 CASE N HMAN LNR1 CONT LD 2 JTS PH6, BRING HI -LOAD ABOVE FLOOR AND REST OF BHA IS MISSING. FISH LEFT IN HOLE: REMAINDER OF HILOAD DISCONNECT, XO, SETTING TOOL, ADAPTER KIT, BTT /DILLER LINER HANGER, 3 -1/2" PUP, 3 -1/2" BY 3- 3/16" XO, 9 JTS 3- 3/16 ", BTT ALUMINUM BULLNOSE, 03:30 - 03:50 0.33 CASE N HMAN LNR1 INSPECT HILOAD AND CALL OUT FISHING TOOLS. �p SURFACE INSPECTION /DISASSEMBLY SHOWS SCREWS NOT SHEAR, SHEAR SCREWS WERE INSTALLED ABOVE THE SET GROOVE CAUSING MANDREL TO SHIFT AND RELEASE DOGS. 03:50 - 07:15 3.42 CASE N HMAN LNR1 WAIT ON FISHING TOOLS FROM DEADHORSE SAFETY MTG. BRING TOOLS TO FLOOR HOLE IS STABLE W/ NO FLUID LOSS 07:15 - 08:30 1.25 CASE N HMAN LNR1 MU FISHING BHANVOO 08:30 - 10:30 2.00 CASE N HMAN LNR1 RIH W/ BHA #5 (3" GS) CIRC THRU GS 0.24/55 10:30 - 11:00 0.50 FISH N HMAN LNR1 8700' 25.5k RIH TO SET DOWN AT 8776' CTD. PUH W/ 6K OP, THEN Printed: 1/25/2010 12:06:49 PM BP EXPLORATION Page 7 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/16/2009 10:30 - 11:00 0.50 FISH N HMAN LNR1 WITH 3K OVER STEADY 11:00 - 13:00 2.00 FISH N HMAN LNR1 POH W/ LINER FISH CIRC 0.53/330 13:00 - 13:20 0.33 FISH N HMAN LNR1 SAFETY MTG /FLOW CHECK 13:20 - 14:20 1.00 FISH N HMAN LNR1 LD LINER RUNNING ASSY 14:20 - 16:00 1.67 FISH N DPRB LNR1 LD HANGER, PUP AND FIRST JT. STAND BACK 4 STANDS. BREAK OFF DENTED ALUMINUM GUIDE SHOE. TRIED TO BREAK CONNECTIONS W/ FARRS, BUT HAD NO SUCCESS. USED ECKLES TO BREAK COLLARS OFF OF NON BAKERLOCKED CONNECTIONS. USED UPSIDE DOWN CEMENTRALIZERS AS LIFT SUBS 16:00 - 16:15 0.25 CASE N DPRB LNR1 SAFETY MTG FOR MU LINER 16:15 - 17:30 1.25 CASE N DPRB LNR1 MU NEWLY CUT ALUMINUM BULLNOSE GUIDE SHOE ON BTT BENT 2 DEG 10' 3- 3/16" PUP. MU ALL PRIOR USED TUBULARS AS BEFORE. USED BAKERLOCK ON ALL CONNECTIONS THAT MOVED 17:30 - 18:10 0.67 CASE N DPRB LNR1 MU 2 JTS PH6 ON TRIPLE CHECKED DISCONNECT W/ SWIVEL. STAB ON INJECTOR. 18:10 - 20:50 2.67 CASE N DPRB LNR1 RIH, PU FOR WT CHECK (25K) ABOVE WINDOW, CONT RIH © 40 FPM 20:50 - 22:10 1.33 CASE N DPRB LNR1 SET DOWN © 9039.5', WT COMES BACK, SLOWLY WORK DOWN TO 9060' AND NO FURTHER, BRING UP PUMPS, PU (5K OVERPULL) TO 9047', RIH KEEP SETTING DOWN, WT DOESN'T COME BACK, BULLNOSE IS PLUGGING OFF, WORK TO 9047' THEN KEEP LOSING GROUND W/ HEAVY PU (7K -15K), BREAKS FREE AND PULL UP, ABLE TO BREAK CIRCULATION, PU ABOVE WINDOW TO 8920', RIH, START STACKING AGAIN © 9026', WORK LNR DOWN STACKING WEIGHT, PRESSURING UP 500 PSI AT 0.15 BPM, ROLL PUMPS UP TO KEEP GETTING WT BACK, CANNOT MAKE PROGRESS PAST 9080', PU OFF BTM AND PRESSURE BLEEDS OFF, CYCLE PUMPS UP /DN AND ATTEMPT TO RIH, CANNOT GO PAST 9080', CIRC 0.13/0.13 500 PSI. 22:10 - 22:30 0.33 CASE N DPRB LNR1 CONSULT TOWN AND WOO. TOWN APPROVES WORKING /SETTING LINER RIGHT HERE. 22:30 - 23:30 1.00 CASE N DPRB LNR1 RAMP PUMPS TO 0.2 BPM © 1000 PSI, PU TO EVEN WT AND THEN STACK DOWN, NO MOVEMENT, KEEP TRYING WHILE BRINGING UP RATE 0.4 / 1300 PSI, PUMP 0.45 / 2000 PSI PU /SD NOTHING, DUMP BAKER CHOKE AND GAIN 5K #, STILL CANNOT PROCEED PAST 9080' 23:30 - 23:50 0.33 CASE P LNR1 DECIDE TO STOP WORKING PIPE AND WILL DROP BALL, CHECK MAX CIRC RATES, BRING RATE UP TO 1.0 IN / 2388 PSI AND RETURNS GO AWAY, LOWER RATE TO 0.25 IN/ 0.0 OUT 1000 PSI, REEL IS -180 DEG OUT, PU TO BREAK OVER (9070') GOOD DROP POSITION AND RETURNS COME BACK, LOAD 1/2" ALUMINUM BALL AND LAUNCH AT 400 PSI, CHASE AT 1.0 BPM 23:50 - 00:00 0.17 CASE P LNR1 RIH TO 9080 AND STACK WT BACK DOWN, CIRC 0.95/0.43 2180 PSI, RETURNS DROP TO 0.0, PU TO 9075' TO GET 1:1 RETURNS, PUMP BALL DOWN AT 0.9/0.9 1100 PSI, DROP RATE TO 0.5 BPM AT 27 BBLS AWAY 12/17/2009 00:00 - 01:00 1.00 CASE P LNR1 CONT CIRC BALL TO SEAT AT 0.5 BPM, BALL NOT ON SEAT © 44 BBLS AWAY (COIL VOL 39.9BBLS), SURGE Printed: 1/25/2010 12:06:49 PM • • BP EXPLORATION Page 8 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/17/2009 00:00 - 01:00 1.00 CASE P LNR1 PUMPS UP TO 1.0 BPM, BALL STILL NOT ON SEAT AT 63 BBLS AWAY. 01:00 - 01:55 0.92 CASE N SFAL LNR1 SHUT DOWN PUMPS, DROP 1/2" STEEL BALL, LAUNCH WITH 1000 PSI AND CHASE AT 1.5 BPM, HEAR A BALL ROLLING, LEAVES REELHOUSE @ 20 BBLS, SLOW TO 1.1 BPM / 1100 PSI, AT 27 BBLS AWAY SLOW DOWN TO 0.5 BPM 230 PSI, BALL LANDS AT 34.6 BBLS, STACK 10K BACK DOWN ON LINER, PRESSURE UP TO 1700 PSI, PU 10K, APPLY 2200 PSI TO RELEASE FROM HANGER, PUH (UP WT 21k) AND BLOW OUT BALL SEAT AT 3400 PSI 01:55 - 03:40 1.75 CASE P LNR1 POOH CIRC WITH .5 BPM RETURNS 03:40 - 04:15 0.58 CASE P LNR1 TAG UP, POP OFF INJECTOR, LD 2 JTS OF PH6, LD LINER RUNNING TOOL, RECOVER STEEL BALL ON SEAT WITH ALUMINUM BALL ABOVE IT. 04:15 - 04:40 0.42 CASE P LNR1 BREAK DOWN BOT TOOLS AND OFFLOAD 04:40 - 07:30 2.83 DRILL P PROD1 CUT DOWN ELINE AND REBOOT, STAB ON WELL AND CIRC SLACK BACK INTO REEL RU HYD CUTTER AND CUT OFF 315' OF CT. INSTALL CTC, PT 30K Q 07:30 - 09:00 1.50 DRILL P PROD1 HEAD UP BHI pp 09:00 - 11:20 2.33 BOPSUF P PROD1 CHANGE 3" SLIPS TO 2" COMBIS, VBR'S TO 2 -3/8" COMBIS. PRESSURE TEST RAMS 250/3500 AND EMAIL RESULTS TO AOGCC. WEEKLY FUNCTION TEST OF ALL RAMS 11:20 - 11:40 0.33 DRILL P PROD1 SAFETY MTG RE: MU BHA 11:40 - 13:50 2.17 DRILL P PROD1 PT CTC @ 4K. SET INJECTOR OVER BUNG HOLE MU NEW 2.74" WINDOW MILL ON STRAIGHT MOTOR W/ BHI 2 -3/8" OD MWD TOOL STRING. SPEND EXTRA TIME TO DETERMINE EXACT SPOT TO SET 2 -3/8" COMBIS TO ALLOW ACCESS TO DBV'S AT RIG FLOOR. ADD WEAR SUB PUMP SLACK FORWARD 1.5 CTV'S @ 2.0 BPM 13:50 - 15:15 1.42 DRILL P PROD1 RIH W/ BHA #7 CIRC 0.45/640 WHILE STARTING DISPLACEMENT W/ 19 BBLS HI -VIS PILL FOLLOWED BY 8.89 PPG USED GEOVIS 15:15 - 15:50 0.58 DRILL P PROD1 LOG TIE -IN TO MARKER AT 8596', CORR 9.5'. RIH AND LOG PAST RA PIPS AND FIND AT 8959.5' 15:50 - 16:00 0.17 DRILL P PROD1 CONTINUE RIH 1.0/2220 WHILE START DISPLACEMENT OF ANNULUS. RED RATE TO 0.5/1400 WHILE RIH TO SHOE. SEE BEND AT 9068', FILL AT 9070' AND SHOE AT 9073' 16:00 - 16:40 0.67 DRILL P PROD1 PUH 25.6K TO 9060' WHILE START MOTOR AT 1.35/2585. EASE IN HOLE TO FIRST WOB AT 9072.6'. MILL FILUALUMINUM W/ 0 PSI DIFF, 0.1 -0.36K WOB W/ OPEN CHOKE AT INITIAL 10.82 ECD WHILE FIN DISPLACEMENT OF ANNULUS TO AVG 9.04 PPG GEOVIS. MILL TO 9073.2' 16:40 - 18:15 1.58 DRILL P PROD1 PUH 23.0K, 10.7K 1.47/2360 W/ 50 PSI DIFF, 0.3K WOB W/ OPEN CHOKE AT 10.05 ECD -HOLE DISPLACED. MILL TO 9074.3' 18:15 - 21:50 3.58 DRILL P PROD1 TIME MILUDRILL AHEAD FROM 9074.3' W/ OPEN CHOKE AND ECD OF 9.99, 200 PSI MW AT 1.48/1.48 BPM, 2400 PSI. MILL FORMATION AT 9 FPH FROM 9076' TO 9080'. BACKREAM SLOWLY THROUGH SHOE (CLEAN), Printed: 1/25/2010 12:06:49 PM • • 1 BP EXPLORATION Page 9 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/17/2009 18:15 - 21:50 3.58 DRILL P PROD1 DRYDRIFT SHOE (CLEAN) 21:50 - 22:30 0.67 DRILL P PROD1 PULL BACK INTO LINER, CLOSE CHOKE TO HOLD 10 PPG EQUIV ON FORMATION AND CHECK FOR PRESS BUILD /LOSS. NO CHANGE. 22:30 - 00:00 1.50 DRILL P PROD1 POOH CIRC 1.0 BPM WHILE HOLDING BACK PRESSURE ON CHOKE ACCORDING TO SCHEDULE TO KEEP BHP @ 10.0 PPG EMW. 12/18/2009 00:00 - 00:10 0.17 DRILL P PROD1 CONT POOH ACORDING TO PRESSURE SCHEDULE 00:10 - 00:35 0.42 DRILL P PROD1 PJSM FOR PRESSURE UN- DEPLOY. DISCUSS ROLES /RESPONSIBILITIES AND PROPER RADIO CONFIRMATION. 00:35 - 02:00 1.42 DRILL P PROD1 UN- DEPLOY ACCORDING TO SLIM -HOLE CHECKLIST 02:00 - 02:45 0.75 DRILL N SFAL PROD1 SWACO CHOKE WONT STAY OPEN FAR ENOUGH AND KEEPS PRESSURING UP WELL, TROUBLESHOOT AND TRY INCREASING FLOW RATE FROM 0.5 TO 0.75, NO SUCCESS 02:45 - 04:00 1.25 DRILL P PROD1 CONTINUE PRESSURE UN- DEPLOY HOLDING -330 PSI ON WELL BY SHUTTING IN CHOKE AND OCCASIONALLY ROLLING MP2. 04:00 - 05:10 1.17 DRILL P PROD1 LD BHI MTR AND BREAK OFF MILL (2.72 NO, 2.73 GO), DIAL AKO MTR UP TO 1.7 DEG WHILE INSPECTING INJECTOR DUE TO SCARRED GRIPPER BLOCKS AND COIL 05:10 - 05:30 0.33 DRILL P PROD1 STAND BACK LUBRICATOR & BHI TOOLS AND PU INJECTOR OVER MOUSEHOLE TO INSPECT COIL WHILE MAINTAIN 330 PSI ON WELL WITH SWACO CHOKE (FIXED) & MPD LOOP. 05:30 - 11:00 5.50 DRILL N SFAL PROD1 INSPECT CT USING MOUSEHOLE AND FIND THAT THE , FIRST 20' CT HAS SCARS HP TO 0.120" DEEe. GRIPPER BLOCKS WERE SCARRED TOO. REPLACE 22 GRIPPER BLOCKS. CUT OFF 27 OF CT. INSTALL CTC. PT 30K. HEAD UP BHI. PT 4K 11:00 - 11:15 0.25 DRILL P PROD1 SAFETY MTG FOR DEPLOY BUILD BHA 11:15 - 14:00 2.75 DRILL P PROD1 PRESSURE DEPLOY BUILD BHA W/ 350 PSI INDUCED WHP 14:00 - 15:45 1.75 DRILL P PROD1 RIH W/ BHA #9 CIRC THRU OPEN EDC 0.52/1300 FOLLOWING PRESSURE SCHEDULE FOR 10.0 ECD BHP , 15:45 - 16:00 0.25 DRILL P PROD1 LOG TIE -IN DOWN TO RA MARKER AT 8959.5', CORR -9.5' 16:00 - 16:10 0.17 DRILL P PROD1 RIH THRU SHOE W/ SLI WT LOSS. TAG TD AT MIN RATE AT 9076'. PUH 24K, CLEAN. START PUMP 1.50/2540/58 W/ 50 PSI INDUCED WHP. EASE IN HOLE TO 9076.0' AND HAD FIRST MW PVT 364 16:10 - 20:25 4.25 DRILL P PROD1 DRILL NEW HOLE FROM 9076' W/ 1.50/2550/108 W/ 0.5 -1.2K WOB W/ 100 -200 PSI DIFF W/ 10.05 EDC W/ 50 PSI INDUCED WHP AT 70' /HR. DRILL TO 9100' AND WIPER BACK TO 9060' WAS CLEAN. DRILL TO 9165', END OF BUILD. 20:25 - 22:10 1.75 DRILL P PROD1 PUH INTO SHOE, CLOSE CHOKE TO HOLD 350 PSI WHP WHILE SD PUMPS AND OPEN EDC, POOH JETTING THROUGH OPEN EDC AT 2.0 BPM HOLDING WHP ACCORDING TO PRESSURE SCHEDULE 22:10 - 22:20 0.17 DRILL P PROD1 PJSM AT 500' TO DISCUSS PRESSURE UN- DEPLOY 22:20 - 00:00 1.67 DRILL P PROD1 PRESSURE UN- DEPLOY BHA W/ 350 PSI INDUCED WHP Printed: 1/25/2010 12:06:49 PM 4 1 BP EXPLORATION Page 10 of 17 Operations Summary Report -Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/19/2009 00:00 - 00:20 0.33 DRILL P PROD1 CONTINUE PRESSURE UN- DEPLOY BHA W/ 350 PSI INDUCED WHP 00:20 - 01:15 0.92 DRILL P PROD1 BREAK OFF BUILD MTR AND BIT (1,0,CT,I,X, 2 PLUGGED JETS), SWAP OUT HOT & DGS, ADD USMPR. PU 0.9 DEG MTR AND HYC SRRE BI- CENTER BIT 01:15 - 01:30 0.25 DRILL P PROD1 PJSM FOR PRESSURE DEPLOY OF LATERAL BHA 01:30 - 04:30 3.00 DRILL P PROD1 PRESSURE DEPLOY LATERAL BHA W/ 350 PSI INDUCED WHP DIFFICULTY BLOWING DOWN SURFACE LINES MULTIPLE TIMES TO DUE DEBRIS 04:30 - 06:05 1.58 DRILL P PROD1 RIH CIRC MIN RATE HOLDING CONSTANT BHP ACCORDING TO PRESS SCHED. 06:05 - 06:20 0.25 DRILL P PROD1 LOG TIE -IN TO RA MARKER, CORR -9' 06:20 - 06:30 0.17 DRILL P PROD1 RIH THRU SHOE, CLEAN. WIPER TO TD 1.4/2300 HOLDING 50 PSI WHP W/ CHOKE TO GIVE 10.0 PPG EMW AND SET DOWN AT 9118' 06:30 - 07:15 0.75 DRILL P PROD1 PUH W/ 6K OVERPULL TO 9100'. RBIH AND GET TO 9122'. PUH W/ 14K OP AND PACKING OFF. REAM DOWN AT 5' /MIN AND GET TO 9114' BEFORE SHOWING 2.5K WOB AND HAVING 5K OP'S ON PICKUPS THREE TIMES. REAM BACK DOWN CLEAN AND STALL TWICE AT 9114.9' AND NOW ASSUME WE WILL SIDETRACK IF CONTINUING. DISCUSS 07:15 - 07:50 0.58 DRILL P PROD1 CONTINUE REAMING AT DTF OF 5R AND WERE ABLE TO GET BY 9114.9' AND CLEAN UP SHALE TO STALL AT 9118.5'. DETERMINE THAT INADVERTENT SIDETRACK WOULD STILL LAND US IN THE TARGET SAND, SO CONTINUE W/ CLEANOUT. OPTIONS ARE FEW AND HIGH RISK. REAMING PAST 9118.5' W/ 1.0 -2.5K WOB ABOUT A FOOT AT A TIME AND PICKUPS ARE FAIRLY CLEAN. GET PAST 9121' AND WERE ABLE TO FINISH WIPER TO TD TAGGED AT 9165.0' PVT 372 07:50 - 08:05 0.25 DRILL P PROD1 WIPER TO SHOE TO CHECK FOR SLOUGHING WAS CLEAN UP THRU THE SHALE, BUT HAD 5K OP AND HIGH MW AS BIT ENTERED SAND AT 9100'. WIPER BACK TO TD AT 10' /MIN HAD NO MW ALTHOUGH SOME MINOR WT LOSS SPOTS. RETAG TD AT 9165'. PUH 27K 08:05 - 08:40 0.58 DRILL P PROD1 LOG MAD PASS UP FOR RES DATA 1.50/2520 W/ 60 PSI WHP TO MAINTAIN 10.03 ECD. NO OVERPULLS, BUT HIGH MW AT 9102' TRIPPED OUT PUMP. RBIH AND RELOG UP FROM 9120' AND HAVE HIGH MW AT 9108', BUT 9102' WAS CLEAN. LOG TO SHOE. WIPER BACK TO TD AT 20' /MIN WAS CLEAN! 08:40 - 10:45 2.08 DRILL P PROD1 DRILL FROM 9165' 1.45/2410/55L W/ 200 -400 PSI DIFF, 0.5 -2.0K WOB W/ 50 PSI WHP FOR 10.01 ECD. DRILL IN TARGET SAND TO 9300' 10:45 - 11:10 0.42 DRILL P PROD1 WIPER TO SHOE WAS CLEAN BOTH DIRECTIONS AT 20' /MIN 11:10 - 13:20 2.17 DRILL P PROD1 DRILL FROM 9300' 1.51/2530/108 W/ 200 -500 PSI DIFF, 0.5 -2.0K WOB W/ 50 PSI WHP TO HOLD 10.9 ECD. DRILL TO 9450' 13:20 - 13:45 0.42 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN EXCEPT FOR HIGH MW AT 9110'. WIPER TO TD WAS CLEAN Printed: 1/25/2010 12:06:49 PM • BP EXPLORATION Page 11 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/19/2009 13:45 - 16:15 2.50 DRILL P PROD1 DRILL FROM 9450' 1.51/2540/100R W/ 200 -300 PSI DIFF, 0.7 -1.8K WOB W/ 50 PSI INDUCED WHP AND 10.08 ECD AT 80' /HR IN B SAND. DRILL TO 9600' 16:15 - 16:45 0.50 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN EXCEPT FOR HIGH MW AND 5K OP AT 9102'. PUH THRU WINDOW CLEAN. OPEN EDC 16:45 - 17:25 0.67 DRILL P PROD1 CONTINUE WIPER TO 8000' WHILE JET SOLIDS OOH. REBOOT SWS CCAAT. RBIH TO TIE -IN DEPTH 17:25 - 17:40 0.25 DRILL P PROD1 LOG TIE -IN DOWN, CORR +2', CLOSE EDC 17:40 - 18:00 0.33 DRILL P PROD1 RIH THRU SHOE, CLEAN. WIPER BACK TO TD HAD SET SET DOWN /MW AT 91242, OTHERWISE CLEAN 18:00 - 21:20 3.33 DRILL P PROD1 DRILL FROM 9600' @ 1.5 BPM, FS 2640 PSI, 150 -250 PSI DIFF, 10.1 ECD, DHWOB 0.5 -1.5K, ROP 40 -100 FPH DRILL TO 9750' 21:20 - 22:20 1.00 DRILL P PROD1 WIPER TO SHOE, 2K OP AND MW FROM 9105' BACK TO 9090', WIPER BACK TO TD W/ SLIGHT MW @ 9115', BOBBLE & MW @ 9120 - 9130', 22:20 - 00:00 1.67 DRILL P PROD1 DRILL FROM 9750' @ 1.45 BPM, FS 2550 PSI, 75 -200 PSI DIFF, 10.1 ECD, DHWOB 0.5 -1.0K, ROP 40 -80 FPH 12/20/2009 00:00 - 03:30 3.50 DRILL P PROD1 CONT DRILL FROM 9780' @ 1.50 BPM, FS 2600 PSI, 250 -300 PSI DIFF, 10.2 ECD, DHWOB 0.7 -2.2K, ROP 20 -70 FPH DRILL TO 9900' 03:30 - 04:45 1.25 DRILL P PROD1 BEGIN WIPER, RECEIVE ORDERS TO POOH FOR AKO CHANGE, STALL OUT MTR & OP AT 9105', PUH TO 9080', RIH THROUGH SHALE WITH MW AND SET DOWN AT 9108' POP THROUGH, PUH THROUGH SHALE WITH NO OVERPULLS AND MINOR MW 04:45 - 06:30 1.75 DRILL P PROD1 PUH INTO LINER, SD PUMPS AND HOLD 420 PSI WHP, OPEN EDC, POOH CIRC THROUGH EDC @ 2.0 BPM ACCORDING TO PRESSURE SCHEDULE, HOLDING CONSTANT BHP OF 10.2 PPG EQUIV W/ CHOKE 06:30 - 08:15 1.75 DRILL P PROD1 PRESSURE UNDEPLOY W/ 420 PSI INDUCED WHP 08:15 - 09:45 1.50 DRILL P PROD1 LD DRILLING BHA. BIT WAS 1-2-1. ADJUST MOTOR TO 1.4 DEG SWS TIGHTEN COMEALONG TO HARDLINE IN REEL, REPLACED GOOSENECK SLING AND MECHANIC INSPECTED INJECTOR 09:45 - 10:00 0.25 DRILL P PROD1 SAFETY MTG RE: PRESSURE DEPLOY 10:00 - 11:40 1.67 DRILL P PROD1 PRESSURE DEPLOY W/ 430 PSI INDUCED WHP 11:40 - 13:30 1.83 DRILL P PROD1 RIH W/ BHA #9 CIRC THRU EDC 0.40/1340 RETIGHTEN COMEALONG PRIOR TO LOGGING 13:30 - 14:15 0.75 DRILL P PROD1 LOG CCL FROM 8600 - 8980', LOG GR TO RA MARKER, CORR -9.0' 14:15 - 14:50 0.58 DRILL P PROD1 RIH THRU SHOE AT 0.5/1400 AND HOLE WAS CLEAN TO 9135'. START PUMP AND BACKREAM 1.58/2750 TO 9095' W/ A LITTLE MW AND <5K OP'S FROM 9112- 9098', OTHERWISE CLEAN. RBIH THRU B8 SHALE AT 0.5 BPM AND WAS CLEAN. CONTINUE WIPER TO TD AND WAS CLEAN TO 12' FROM TD 14:50 - 15:05 0.25 DRILL P PROD1 TAG AT 9888' AND STACK OUT. ATTEMPT TO GET TO TD, BUT NOT. REAM AND BACKRE'AM OVER 9845 -9888' AND WAS STICKY W/0 MW TO 9882'. ASSUME THIS MAY BE A Printed: 1/25/2010 12:06:49 PM • BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/20/2009 14:50 - 15:05 0.25 DRILL P PROD1 FAULT AREA. CLEAN UP ENOUGH TO GET STARTED 15:05 - 17:45 2.67 DRILL P PROD1 DRILL FROM 9903' 1.58/2700/10L W /100 -250 PSI DIFF, 1.5 -2.0K WOB W/ OPEN CHOKE AND 10.21 ECD. DRILL IN PROBABLE SIDERITE, PAINFULLY SLOW TO 9936'. START MUD SWAP 17:45 - 19:00 1.25 DRILL P PROD1 DRILL FROM 9936' 1.55/2575/10L W/ 100 -350 PSI DIFF, 2.0 -2.0K WOB W/ 75 PSI ON CHOKE AND 10.20 ECD MUD SWAP COMPLETED 19:00 - 22:50 3.83 DRILL P PROD1 ROP PICKS BACK UP AT 9945' TO 40 -60 FPH, CONT DRILLING AHEAD AT 1.50 BPM/2475 PSI FS, 100 -250 PSI DIFF, 1.5 -2.0K DHWOB, W/ 100 PSI ON CHOKE PANEL & 10.2 ECD. DRILL TO 10,050' 22:50 - 00:00 1.17 DRILL P PROD1 WIPER BACK TO SHOE, PUH FROM 9130' TO 9090' @ 1.5 BPM / 10 FPM, 500 -600 PSI MW AND SLIGHT OP @ 9107', TURN AROUND AT 9080' AND RIH TO 9130' @ 0.5 BPM / 20 FPM CLEAN! CONT RIH AT 1.5 BPM CLEAN TO BOTTOM 12/21/2009 00:00 - 03:20 3.33 DRILL P PROD1 DRILL FROM 10,050' @ 1.51 BPM / 2450 PSI FS, 200 -300 PSI DIFF, 2.5 -3.0K DHWOB, HOLDING 100 PSI WHP TO MAINTAIN 10.2 PPG ECD. ROP IS PAINFULLY SLOW (5- 10' /HR) FROM 10,056' - 10,068' 03:20 - 07:30 4.17 DRILL P PROD1 ROP JUMPS TO 80 FPH @ 10,068', DRILL AHEAD @ 1.5 BPM / 2590 PSI FS, 350 -450' PSI DIFF, 2.0 -3.2K DHWOB, ROP = 60 FPH W/ MANY HARD STRINGERS, HOLDING 100 PSI TO INDUCE 10.2 PPG ECD ON BTM. DRILLED TO 10138' 07:30 - 10:00 2.50 DRILL P PROD1 DRILLING FROM 10138' IN ANOTHER SLOW PENETRATION RATE AREA. PU 25K, DN 7.2K 1.59/2740/15R 1.5K WOB AT 94 DEG NBI. LOOKING LIKELY WE HAVE CROSSED A/SOME FAULT(S). GEOS THINK WE ARE CURRENTLY IN THE B6 AND ARE DRILLING AGGRESSIVELY UP TO THE B7 TARGET SAND. DRILL TO 10152' AND ARE BACK ON ANOTHER ASSUMED SIDERITE STRINGER PVT 420 10:00 - 10:45 0.75 DRILL P PROD1 WIPER TO WINDOW PRIOR TO POOH FOR FRESH BIT AND AGITATOR. HOLE WAS CLEAN UNTIL 9103'. HAD 800 PSI MW AND 3K OP TO 9098'. PULL THRU WINDOW CLEAN W/ 10.01 ECD. OPEN EDC HOLDING 400 PSI SURFACE PRESSURE AND BHI SHOWING 9.97 ECD 10:45 - 12:30 1.75 DRILL P PROD1 POOH JETTING SOLIDS TO SURFACE THRU OPEN EDC AT 2.43/3150 FOLLOWING PRESSURE SCHEDULE 12:30 - 14:30 2.00 DRILL P PROD1 SAFETY MTG PRESSURE UNDEPLOY W/ 400 PSI WHP PVT 373 14:30 - 15:10 0.67 DRILL P PROD1 BREAK OFF MOTOR AND BIT. BIT WAS 2-3-1, MOTOR WAS OKAY. MU NEW HYC BI SRR BIT ONTO SAME MOTOR. ADD AGITATOR 15:10 - 15:20 0.17 DRILL P PROD1 SAFETY MTG RE: PRESSURE DEPLOY 15:20 - 17:20 2.00 DRILL P PROD1 PRESSURE DEPLOY BHA #11 W/ 430 PSI WHP 17:20 - 19:02 1.70 DRILL P PROD1 RIH CIRC THRU EDC 0.55/1420 FOLLOWING PRESSURE SCHEDULE 19:02 - 19:10 0.13 DRILL P PROD1 LOG TIE -IN PASS DOWN FROM 8990' ( -8.5' CORRECTION) 19:10 - 19:45 0.58 DRILL P PROD1 HOLD 400 PSI ON SURFACE AND SD PUMPS, CLOSE EDC, PUMP MIN RATE AND HOLD WHP AS NECESSARY TO Printed: 1/25/2010 12:06:49 PM • . BP EXPLORATION Page 13 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/21/2009 19:10 - 19:45 0.58 DRILL P PROD1 MAINTAIN BHP, CIRC MIN RATE AND RIH THROUGH SHOE, RIH CIRC MIN RATE AT 20' /MIN FROM 9090' -9130' CLEAN. CONT RIH I§ 1.32 BPM TO 10,152' 19:45 - 00:00 4.25 DRILL P PROD1 DRILL FROM 10,152' @ 1.52 BPM / 3470 PSI FS, 300 -450 PSI DIFF, 3.0 -3.5k DHWOB, 5- 10' /HR, HOLDING 100 PSI, e-..\ WHP. SLOW DRILLING. DRILL TO 10,176' 1 12/22/2009 00:00 - 01:35 1.58 DRILL P PROD1 CONT DRILL FROM 10,176' @. 1.52 BPM / 3200 PSI FS, 100 -200 PSI DIFF, 2.0 -3.0k DHWOB, 5- 10' /HR, HOLDING 100 PSI WHP. DRILLING BREAK TO 20' /HR FROM 10,180' 10,188' CONT. DRILLING TO 10,194.3' AT 10 FPH. 01:35 - 03:00 1.42 DRILL P PROD1 PU OFF BTM AND WIPER WHILE GEO/TOWN DISCUSS PLAN FORWARD, TOWN DECIDES TO RUN LINER. PUN THROUGH SHALE AT 15' /MIN W/ 600 PSI MW & 5K OVERPULLS @ 9,113' AND 9,098', PUH AND LOG TIE -IN PASS ( +1' CORRECTION) 03:00 - 03:10 0.17 DRILL P PROD1 LOG TIE -IN PASS ( +1' CORRECTION) 03:10 - 04:10 1.00 DRILL P PROD1 RIH THROUGH SHOE, RIH @ 20' /MIN AND PUMP 0.5 BPM FROM 9090' TO 9130' (CLEAN), RIH CIRC 1.5 BPM TO 10,150' 04:10 - 05:05 0.92 DRILL P PROD1 POOH, SLOW DOWN TO 10 FPM @ 9130' & PULL THROUGH SHALE W/ 600 PSI MW & 2K OP @ 9105' AND 700 PSI MW @ 9095', PUH INTO LNR. 05:05 - 11:30 6.42 DRILL N WAIT PROD1 WAIT ON KILL WEIGHT FLUID WHICH ARRIVES AT 0700 HRS. THEN, WO MT VAC TRUCK WHICH SHOWS UP AT 1100 HRS. LIMITED VAC TRUCKS DUE TO OTHER RIG WORK AND TIS THE SEASON. BEGIN TO VAC PITS PRIOR TO CLEANING FOR KWF 11:30 - 13:50 2.33 DRILL P PROD1 CLEAN PITS. 13:50 - 15:30 1.67 DRILL P PROD1 DISPLACE WELL FROM 9070'. GET KWF (9.9 PPG) BACK TO SURFACE. 15:30 - 16:50 1.33 DRILL P PROD1 CIRCULATE OUT OF HOLE. PAINT EOP AT 8000'. FLOW CHECK WELL. CONTINUE TO POOH. 16:50 - 18:15 1.42 DRILL P PROD1 GET OFF WELL. FLOW CHECK. UNSTAB COIL. LAY DOWN BHA. BREAK OFF BAKER UQC. 18:15 - 18:30 0.25 CASE P RUNPRD PUMP OUT ELINE SLACK, RECOVER 277 OF ELINE 18:30 - 18:50 0.33 CASE P RUNPRD PERFORM ANNUAL INSPECTION ON POWER PACK TRACTION MOTOR. 18:50 - 20:10 1.33 CASE P RUNPRD PREP FLOOR TO RUN LINER 20:10 - 20:45 0.58 CASE P RUNPRD BOOT ELINE AND INSTALL BOT CTC 20:45 - 21:00 0.25 CASE P RUNPRD PULL TEST CTC TO 35K, PT TO 4K 21:00 - 21:20 0.33 CASE P RUNPRD PJSM FOR MU LINER AND RUNNING TOOLS 21:20 - 23:45 2.42 CASE P RUNPRD MU 2 -3/8" LINER AND RUNNING ASSY, FILL LINER 23:45 - 00:00 0.25 CASE P RUNPRD STAB ON INJECTOR 12/23/2009 00:00 - 01:45 1.75 CASE P RUNPRD RIH W/ LINER BHA TOTAL LENGTH = 1449.5', CIRC WHILE RIH AND LOAD REEL WITH 2% DOUBLE SLICK KCL 01:45 - 02:15 0.50 CASE P RUNPRD PARK @ 9050' TO GET 2% KCL TO THE 2 -3/8" SHOE 02:15 - 03:30 1.25 CASE P RUNPRD START RUNNING IN OH CIRC MIN RATE, START TAKING WT 1 9095', 4K BOBBLE @ 9109' BUT THEN BOUNCES THROUGH, WT CHK CO 10,000' 28K, RIH TO BTM TAG NO -GO @ 10,120', PU & RE -TAG AGAIN @ 10,120' Printed: 1/25/2010 12:06:49 PM • BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/23/2009 03:30 - 04:45 1.25 CASE P RUNPRD CIRC 1.0 BPM ON BOTTOM TO FINISH SWAPPING WELL OVER TO 2% KCL 04:45 - 05:30 0.75 CASE P RUNPRD OUT DENSITY CLEANED UP TO 9.0, SHUT DOWN AND FLOW CHECK, GETTING RETURNS OUT COIL (U -TUBE EXPECTED BUT FLOATS SHOULD BE HOLDING), SHUT -IN BACKSIDE & FLOW CONTINUES. PUMP 0.75 BPM FOR 3 MIN TO FLUSH OFF FLOATS. FLOW CHECK (NO FLOW). 05:30 - 07:00 1.50 CASE P RUNPRD LOAD 5/8" STEEL BALL AND LAUNCH @ 1000 PSI, CHASE W/ 1.5 AT 1540 PSI. BPM, HEAR BALL ROLLING, SLOW DOWN @ 30 BBLS AWAY. STOP CIRC AT 60 BBLS AWAY. SHUT IN COIL. PRESSURE TO 3000 PSI. OPEN AND SURGE COIL. RESUME CIRC. BALL ON SEAT AT 62 BBLS PUMPED. PRESSURE TO 3150 PSI. BALL SEAT SHEARED. PU TO VERIFY RELEASE. UP WT: 24K #, 4K# LESS THAN BEFORE SHEAR. 07:00 - 07:30 0.50 CEMT P RUNPRD HOLD PJSM WITH SLB, NORDIC, CHILL. DISCUSS PT, PUMP SCHEDULE, HSE ISSUES, TRUCK HANDLING AND MORE. 07:30 - 08:00 0.50 CEMT P RUNPRD THAW SMALL ICE PLUG IN CEMENT LINE. 08:00 - 10:00 2.00 CEMT P RUNPRD BATCH MIX 12 BBLS CLASS G 15.8 CEMENT (TO GET ENOUGH IN MIX TUB) CMT UP TO WT AT 0830. CATCH SAMPLE FOR UC TEST. PRESSURE TEST SURFACE LINES TO 4000 PSI. PUMP 5 BBLS KCL WATER, 6.0 BBLS CEMENT. (1560 PSI AT 1.4 BPM) BLOW BACK TO CEMENTERS. DISPLACE CEMENT WITH 2PPB BIOZAN USING RIG PUMP. 2380 PSI AT 1.6 BPM IN /OUT. MAINTAIN 10K# OR MORE DN WT ON LINER TOP. STOP DISPLACEMENT 2 BBLS SHORT AT 37.3 BBLS (CALC. COIL VOL IS 39.3 BBLS) 1421 PSI AT 1.37 BPM. PU TO UP WT, PLUS 15' TO 10,109'. EXHAUST 2 BBLS CMT + 3 BBLS BIOZAN FROM COIL ABOVE SELRT. OPEN BAKER CHOKE. SLACK OFF INTO LINER TOP TO 10,128. CLOSE BAKER CHOKE. PLUG SHEARED AT 3025 PSI WITH 0.4 BBLS PUMPED IN TO COIL. DISPLACE CEMENT AT 2180 PSI AT 1.26 BPM. 1:1 RTNS. LAND AT 5.2 BBLS DISPLACEMENT IN LINER. PRESSURE TO 3200 PSI. PRESSURE BLEEDING OFF SLOWLY. RE- PRESSURE AND ISOLATE PUMPS. COIL BLEEDING OFF TO 1000 PSI. TOTAL LINER DISP WAS 5.8 BBLS. CALC'D LINER VOL WAS 5.3 BBLS. QLEED TO ZERO TO CHECK FLOATS. GOOD. PRESSURE COIL TO 1000 PSI. UNSTING AT 23K# UP WT. PRESSURE BLED TO ZERO. CIP AT 0945. 10:00 - 11:30 1.50 CEMT P RUNPRD CIRC BIO ACROSS LINER TOP TO CLEAN UP SAME. CIRCULATE OUT OF HOLE AT 1.5 BPM IN AT 1310 PSI. 1.37 BPM OUT. PAINT EOP FLAG AT 8000'. Printed: 1/25/2010 12:06:49 PM BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/23/2009 10:00 - 11:30 1.50 CEMT P RUNPRD NOTE CEMENT BACK TO SURFACE AT 118 BBLS PUMPED. DIVERT OUTSIDE. 9.30 PPG MAX AT SURFACE. 11:30 - 13:00 1.50 CEMT P RUNPRD FLOW CHECK. PJSM. GET OFF WELL. UNSTAB COIL. LD LINER RNG TOOLS. SEALS AND ALL SELRT COMPONENTS ARE IN PROPER CONDITION. 13:00 - 16:30 3.50 BOPSUF P RUNPRD FLUSH BOPS WITH COIL SWIZZLE BHA. FLUSH AND CHECK ALL CHOKE VALVES. ALSO CLEAN OUT GAS BUSTER LINES. OPEN BOP RAM DOORS TO CHECK FOR CEMENT. REPAIR BAKER CHOKE. FUNCTION TEST BOPS. 16:30 - 17:30 1.00 CEMT P RUNPRD MU SHORT MILLING BHA W/ 2 -1/8" BTT EXTREME MUD MOTOR, 4' SPACER PIPE, 1.875" D331 17:30 - 20:15 2.75 CEMT P RUNPRD RIH W/ MILLING BHA CIRC 0.4 BPM / 300 PSI 20:15 - 20:50 0.58 CEMT P RUNPRD TAG SELRT BUSHING AT 8758', PU & BRING ON PUMPS TO 1.49 BPM / 1120 PSI FS, PARK AND EASE INTO BUSHING TO GET 100 PSI MW, HOLD 100 PSI MW, MILL THROUGH IN 20 MIN, PU AND REAM THROUGH BUSHING AT 1' /MIN, DRY DRIFT (CLEAN) 20:50 - 22:45 1.92 CEMT P RUNPRD POOH, STOP AND PAINT FLAG AT 7000' EOP FOR NEXT RUN. 22:45 - 23:10 0.42 CEMT P RUNPRD TAG UP, POP OFF INJECTOR, LD SHORT MILLING BHA 23:10 - 23:15 0.08 CEMT P RUNPRD PREP FLOOR TO RUN CSH 23:15 - 00:00 0.75 CEMT N RREP RUNPRD WHILE PREPPING FLOOR, RED TUGGER (PULL BACK) WINCH BREAKS DOWN, ATTEMPT TO FIX WINCH, NORDIC DOES NOT HAVE SPARE WINCH MOTOR, WILL OPERATE WITH ONLY ONE (BLUE) WINCH UNTIL OTHER REPAIRED 12/24/2009 00:00 - 00:30 0.50 CEMT P RUNPRD FINISH PREP RIG FLOOR TO RUN 1" CSH 00:30 - 00:45 0.25 CEMT P RUNPRD PJSM FOR PICKING UP 1" CSH AND LINER CLEANOUT BHA 00:45 - 02:50 2.08 CEMT P RUNPRD MU LINER MILLOUT BHA W/ 1.875" MILL, 1- 11/16" MTR, 45 JTS 1" CSH, 2 JTS 2 -3/8" PH6 02:50 - 05:15 2.42 CEMT P RUNPRD RIH W/ LINER BHA MILLOUT BHA CIRC MIN RATE, TIE INTO EOP FLAG @ 8700', TAG PBTD @ 10,100.9', PU & TAG AGAIN @ 10,101' 05:15 - 05:25 0.17 CEMT P RUNPRD CIRC PERF PILL TO BIT 05:25 - 07:45 2.33 CEMT P RUNPRD POOH LAYING IN PERF PILL FROM PBTD 07:45 - 10:00 2.25 PERFOB P LOWER1 AT SURFACE. GET OFF WELL. UNSTAB. STAND BACK INJECTOR. STAND BACK 900' CSH. LD THE REST FOR OFFLOADING BEFORE MOVE 10:00 - 12:15 2.25 PERFOB P LOWER1 RU AND PRESSURE TEST LINER LAP. PRESSURE TO 2000 PSI AND SHUT IN. BLEED DOWN TO 1305 IN 30 MIN. CONTINUE TO BLEED OFF SLOWLY AT END OF TEST. CHART TEST. 12:15 - 12:45 0.50 PERFOB P LOWER1 HOLD PJSM WITH SLB AND NORDIC HANDS. REVIEW GUN HANDLING PROCEDURES. 12:45 - 13:30 0.75 PERFOB P LOWER1 LOAD GUNS IN TO PIPE SHED. 13:30 - 17:30 4.00 PERFOB P LOWER1 MU 27 1.56" 6 SPF 1606PJ GUNS ON 30 JTS OF 1" CSH., 17:30 - 19:35 2.08 PERFOB P LOWER1 RIH WITH PERFORATING GUNS 19:35 - 20:00 0.42 PERFOB P LOWER1 TAG PBTD @ 10,101.4', CORRECT TO 10,100', PU TO Pnnted: 1/25/2010 12:06:49 PM BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/24/2009 19:35 - 20:00 0.42 PERFOB P LOWER1 10,050.7' AND PERFORM RATE TESTS @ 0.3 BPM & 1.33 BPM. PIMP FFIRF RATF SEQUENCE. GUNS FIRED (SHOT DETECT GOOD) 20:00 - 21:30 1.50 PERFOB P LOWER1 POOH WHILE CIRC & HOLDING 100 PSI ON WELL WITH SWACO CHOKE. 21:30 - 22:00 0.50 PERFOB P LOWER1 FLOW CHECK WELL AT SURFACE. PJSM FOR LD CSH WHILE FLW CHK. 22:00 - 23:30 1.50 PERFOB P LOWER1 LD 1" CSH WORK STRING 23:30 - 00:00 0.50 PERFOB P LOWER1 PJSM FOR PREPPING THE FLOOR AND LD GUNS 12/25/2009 00:00 - 00:30 0.50 PERFOB P LOWER1 PREP RIG FLOOR TO LAY DOWN PERF GUNS 00:30 - 02:15 1.75 PERFOB P LOWER1 LD 27 SPENT PERF GUNS 02:15 - 03:30 1.25 PERFOB P LOWERI RIG DOWN SLB TCP, OFFLOAD SPENT PERF GUNS AND 1" CSH 03:30 - 04:30 1.00 ZONISO P LOWERI BRING BOT 4.5" KB LTP TO FLOOR, MU TO RUNNING BHA AND STAB ON INJECTOR 04:30 - 06:15 1.75 ZONISO P LOWERI RIH W/ LTP CIRC MIN RATE 25k# up, 11 K# DN WT AT 8600'. 06:15 - 06:45 0.50 ZONISO P LOWER1 LOCATE 45 "KB PACKER SEAL ASSEMBLY IN TO TIE BACK SLEEVE. 120 PSI AT 0.25 BPM IN/0.31 OUT. TAG SLEEVE TOP AT 8751' WHILE RIH. STACK OUT SEAL ASSY LOCATOR AT 8756'. UNSTING AT 8751'. 06:45 - 08:15 1.50 ZONISO P LOWER1 VERIFY STING IN /OUT. POSITION REEL TO DROP 5/8" BALL. SURGE BALL A FEW TIMES TO GET BALL MOVING. BALL OVER GOOSENECK. REDUCE RATE TO 0.56 BPM AT 225 PSI. BALL ON SEAT AT 39 BBLS. STING IN AND SPACE OUT 2' ABOVE UP STROKE STACK OUT. PRESSURE COIL TO 2500 PSI. SLACK OFF 5K #. TAKING WT 2' SHALLOWER. PRESSURE CT ANNULUS TO 1500 PSI. HELD SOLID FOR 10 MINUTES. PRESSURE CT TO 3450 PSI TO SHEAR RELEASE. PU WITH CT. 25K# UP WT. 08:15 - 10:30 2.25 ZONISO P LOWER1 PULL OUT OF HOLE. MONITOR HOLE FILL. 10:30 - 11:30 1.00 ZONISO P LOWER1 AT SURFACE. FLOW CHECK. GET OFF WELL. UNSTAB COIL. LD BHA. REMOVE BTT TOOLS FROM RIG FLOOR. 11:30 - 11:45 0.25 WHSUR P POST MU NOZZLE BHA. GET ON WELL. 11:45 - 15:00 3.25 WHSUR P POST RUN IN HOLE. HOLD PJSM WITH LRS. POOH AND LAY IN DIESEL FROM 2500'. POOH. RD LRS. 15:00 - 15:30 0.50 WHSUR P POST SERVICE TREE WITH GREASE CREW. 15:30 - 18:20 2.83 RIGD P POST HOLD PJSM. RU TO BLOW DOWN REEL WITH N2. PUMP INHIBITOR, FRESH WATER, 60/40 MEOH. BLOW DOWN WITH N2. 18:20 - 20:30 2.17 WHSUR P POST BRING BPV LUBRICATOR TO FLOOR, LUBRICATE IN BPV, OFFLOAD BPV CREW LUBRICATOR 20:30 - 22:45 2.25 RIGD P POST PREP COIL, INSTALL GRAPPLE, PULL COIL BACK TO REELHOUSE, SECURE AND LOWER REEL. 22:45 - 23:15 0.50 RIGD P POST PU INJECTOR AND SET DOWN PACKOFF ASSEMBLY, BEGIN CHANGING OUT GRIPPERBLOCKS AND PACKOFFS Printed: 1/25/2010 12:06:49 PM • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: REENTER +COMPLETE Start: 12/10/2009 End: 12/26/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/25/2009 23:15 - 00:00 0.75 RIGD P POST SUCK OUT BOP STACK AND SWAP OUT BOP RAMS 12/26/2009 00:00 - 02:30 2.50 RIGD P POST ND BOPE 02:30 - 03:30 1.00 WHSUR P POST MU TREE CAP AND PT WITH DIESEL 03:30 - 06:00 2.50 RIGD P POST ND MPD LOOP AND MU BLIND FLANGE TO SWAB, WARM UP MOVE SYSTEM 06:00 - 06:30 0.50 RIGD P POST CREW CHANGE. DISCUSS OPS AND PLAN. MAKE RIG ROUNDS. 06:30 - 08:00 1.50 DEMOB P POST CONTINUE TO WARM MOVING SYSTEM. HOLD PJSM WITH PAD OPERATOR BEFORE MOVE OFF. BACK RIG OFF WELL WITH NORDIC CREW. 08:00 - 09:00 1.00 DEMOB P POST CLEAN UP AREA AROUND WELL HEAD. PU RIG MATS AND STAGE FOR TRANSPORT TO C -PAD LOCATION. RIG RELEASED AT 09:00 HRS. ALL FURTHUR OPERATIONS ON MPC -24 REPORT. Printed: 1/25/2010 12:06:49 PM • MPE -14A, Well History (Post Rig Sidetrack) Date Summary 12/29/09 WELL S/I ON ARRIVAL. ASSIST SUPPORT TECHS REMOVE BPV. DRIFT 2' x 1 -7/8" stem, 3.81" G. RING TO 2,500' SLM. NO RESTRICTIONS. RAN DUAL SPARTEK GAUGES. 30 MIN GRADIENT STOP @ 8272' MD, 3 HR BHP STOP @ 8735' MD. 12/30/09 SET PLUG BODY IN X- NIPPLE @ 8680' MD. SET PRONG (oal 96 ") IN PLUG BODY @ 8680' MD. MIT TO 1100 LBS PASSED. WELL LEFT S /I, JOB COMPLETED. 12/30/09 WELL SHUT -IN. INITIAL T /I /O:0/0/0 PSI. RU E -LINE AND PRESSURE TEST WHE. PROBLEM GETTING PT TO PASS AT LOW PRESSURE, PUT HEAT ON CONNECTION FROM E -LINE WHE TO WELL HEAD CONNECTION AND PT PASSED. 12/31/09 INITIAL T /I /O:0/0/0 PSI. PUNCH TUBING FROM 8634' - 8636' WITH SMALL CHARGES LOADED 4 SPF, 0 DEG PHASING, 9 SHOTS TOTAL. TIED INTO TUBING TALLY DATED 19 -NOV -2009. LRS CMIT -TxIA TO 1000 PSI PASSED. ASSIST CH2MHILL TO SET BPV. DSO NOTIFIED OF FINAL VALVE POSITIONS: MASTER:O, WING:C, SWAB:C, SSV:C, IA/OA:OTG. WELL LEFT SHUT -IN. 12/31/09 T /I /O =0/0/0 CMIT TxIA PASSED to 1000 psi. Pumped 2 bbls diesel down Tbg to reach test pressure. 1st 15 min lost 20/0 psi, 2nd 15 min lost 0/0 psi for a total loss of 20/0 psi in 30 min. bled down pressure. DSO notified swab wino ssv shut, master is oa open. FW HP's =0/0/0 Nabors 4ES moved on well to pull workstring and run ESP completion. (12/31/09 - 01/06/10) Page 1 of 1 • BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: WORKOVER Start: 12/31/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/6/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 12/31/2009 06:00 - 11:00 5.00 RIGD P PRE RD AND BLOW DOWN LINES -LOWER DERRICK 11:00 - 12:00 1.00 RIGD P PRE SAND MPJ -19 AND INTERSECTION TO SPINE ROAD AND MPE -14. -MOVE PITS AND PIPE SHED -MOVE OFF WELL WITTNESSED BY BP -WSL, NABORS-TP AND PAD OPERATOR. 12:00 - 13:00 1.00 MOB P PRE PREP UNITS TO MOVE TO E PAD 13:00 - 16:30 3.50 MOB P PRE MOVE FROM MPU J PAD TO MPU E PAD 16:30 - 22:00 5.50 RIGU P PRE SPOT OVER E -14 WITNESSED BY PAD OPERATOR BP -.WSL AND NABORS -TP -SPOT UNITS -RAISE DERRICK -TAKE ON FUEL -RIG UP -SET BEAVER SLIDE -RIG ACCEPTED AT 22:00 HOURS. 22:00 - 00:00 2.00 RIGU P PRE SAFETY STAND DOWN 1/1/2010 00:00 - 02:00 2.00 RIGU P PRE SAFETY STAND DOWN. 02:00 - 05:00 3.00 RIGU P PRE CONTINUE TO RU LINES TO FLOWBACK TANK. TAKE ON SEAWATER 2 HOURS LATE DUE TO PHASE II WEATHER. 05:00 - 00:00 19.00 RIGU N PRE PHASE 3 WEATHER STAND DOWN WORK ACTIVITY - SUSPEND FLUID TRANSFER OPERATIONS. 1/2/2010 00:00 - 10:00 10.00 RIGU N PRE WOW CONTINUE PHASE 3 WEATHER CONDITIONS. 3 DAYS WORTH OF FUEL AND WATER ON HAND. 10:00 - 19:00 9.00 RIGU N PRE WOW. PHASE 2 LEVEL 3 - DIG -OUT ONLY 19:00 - 20:45 1.75 RIGU P PRE FINISH RU TO TAKE ON SEAWATER 20:45 - 21:00 0.25 RIGU P PRE PJSM 21:00 - 22:00 1.00 WHSUR P DECOMP PU LUBRICATOR AND TEST TO 500 PSI WITH DIESEL. PULL BPV WITH LUBRICATOR 22:00 - 00:00 2.00 WHSUR P DECOMP REPAIR BLEED OFF HOSE. TEST LINES SWING LEAKING CHANGE OUT SAME. BLEED OFF IA =20 PSI AND OA =0 PSI. 1/3/2010 00:00 - 01:20 1.33 KILL P DECOMP CIRCULATE 1.8 BPM AT 2600 PSI. DOWN TUBING. CIRCULATE 66 BBL CLEAN RETURNS. BECAUSE OF HIGH CIRCULATING PRESSURE AND LOW RATES DECIDED TO REVERSE CIRCULATE. REVERSE CRCULATEd FREEZE PROTECTION FROM TUBING 4.9 BPM @ 1500 PSI. RETURNS CLEAN AFTER 100 BBL. 01:20 - 01:35 0.25 KILL P DECOMP FLOW CHECK WELL. WELL DEAD. 01:35 - 03:00 1.42 WHSUR P DECOMP SET TWC WITH DRY ROD. TEST TWC FROM BELOW SILMUTANEOUSLY WITH CASING TO 1000 PSI FOR 10 MIN. JUG TIGHT. TEST TWC FROM ABOVE TO 3500 PSI FOR 10 MIN. GOOD TEST 03:00 - 05:00 2.00 WHSUR P DECOMP ND TREE . 05:00 - 08:00 3.00 BOPSUF P DECOMP NU BOPE -NU 11" X 1 3 5/8" DSA -NU BOPE, CHOKE AND KILL LINES. 08:00 - 09:00 1.00 BOPSUE P DECOMP MU TEST PLUG - FUNCTION TEST BOPE 09:00 - 15:00 6.00 BOPSUF P DECOMP TEST BOPE PER BP /AOGCC REQUIREMENTS: Printed: 1/25/2010 12:05:11 PM • • BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: WORKOVER Start: 12/31/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/6/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/3/2010 09:00 - 15:00 6.00 BOPSUF P DECOMP -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. - TESTED 2 -7/8" X 5" VBR'S WITH 4 1/2" TEST JOINTS. - TESTED ANNULAR WITH 2 7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. - TESTED KELLY & FLOOR VALVES. 200 PSI BUILD UP FROM 1700 PSI = 54 SECONDS. -FULL BUILD UP TO 3000 PSI = 195 SECONDS. -4 BOTTLES x 1612 PSI. -CHUCK SCHEAVE WAIVED AOGCC RIGHT TO WITNESS BOPE TESTING AT 10:00 -HRS. ON 12/31/2009 15:00 - 16:30 1.50 BOPSUF P DECOMP WEEKLY SAFETY MEETING - NABORS SAFETY- PAUL HOLLEY - "DROPPED OBJECT MANAGEMENT SYSTEM" 16:30 - 19:30 3.00 PULL P DECOMP RU DUTCH SYSTEM AND LUBRICATOR -PULL TWC -TBG AND IA = 0 PSI -RD LUBRICATOR AND DUTCH SYSTEM 19:30 - 19:40 0.17 PULL P DECOMP PU LANDING JOINT 19:40 - 20:00 0.33 PULL P DECOMP BREAK CIRCULATION INITIAL 62 SPM 700 PSI PRESSURE FLUCTUATING 53 STP @ 2000 PSI. STILL SOME TRASH /JUNK FLOATING AROUND. 20:00 - 20:55 0.92 PULL P DECOMP BACK OUT LDS. PU LANDING JOINT. PULL HANGER FREE 102K. UP WT 110K, RU CIRCULATION HOSE. 20:55 - 22:45 1.83 PULL P DECOMP CIRCULATE BOTTOMS UP.3 BPM WITH PRESSURE FLUCTUATING BETWEEN 1100 - 3400 PSI. PUMPED A TOTAL OF 3000 STROKES. 22:45 - 23:30 0.75 PULL P DECOMP FLOW CHECK. WELL DEAD. LD LANDING JOINT AND RU TO PULL TUBING. 23:30 - 00:00 0.50 PULL P DECOMP LD 4.5 L80 TUBING. 1/4/2010 00:00 - 08:30 8.50 PULL P DECOMP CONTINUE TO LD 4.5" L80 TUBING 08:30 - 10:00 1.50 PULL P DECOMP LD 218 JTS 4 1/2" TBG -9 HOLES PUNCHED IN MIDDLE OF JT ABOVE "X" NIPPLE -LD SEAL ASSEMBLY -CLEAN RIG FLOOR 10:00 - 12:00 2.00 RUNCOMP RUNCMP RU TO RUN 2 7/8" ESP COMPLETION -SPOT SPOOLER -LOAD ESP INTO PIPE SHED 12:00 - 15:00 3.00 RUNCOMP RUNCMP PU / MU ESP ASSEMBLY -SNAKE CABLE OVER SHEAVE 15:00 - 22:00 7.00 RUNCOMP RUNCMP RUN ESP COMPLETION ON 2 -7/8" 6.5 #, L -80 EUE, TBG. -WELL IS STATIC - "XN ", (1) GLM DUMMY -273 JTS RUN TOTAL 22:00 - 00:00 2.00 RUNCO F RUNCMP PERFORM REEL TO REEL CABLE SPLICE 1/5/2010 00:00 - 01:00 1.00 RUNCOMP RUNCMP WEEKLY SAFETY MEETING 01:00 - 09:30 8.50 RUNCOMP RUNCMP CONTINUE RUN ESP COMPLETION ON 2 -7/8" 6.5 #, L -80 EUE, TBG. -1 X 1 FROM PIPE SHED -WELL IS STATIC -175 JTS RAN AT 0500 HRS. Printed: 1/25/2010 12:05:11 PM • • BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPE -14 Common Well Name: MPE -14 Spud Date: 12/11/2009 Event Name: WORKOVER Start: 12/31/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/6/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/5/2010 09:30 - 12:00 2.50 RUNCOMP RUNCMP RUN DOWN HOLE PUMPS MAKE REEL TO REEL SPLICE CIRCULATE TO FLUSH PUPM @ 1BPM & 1,600PSI 12:00 - 14:00 2.00 RUNCOMP RUNCMP CONTINUE TO TRIP IN HOLE ADD 2.2' PUP BETWEEN JTS #253 & #254 = SPLICE DOWN 2' F/TOP OF #254 RAN TOTAL OF 273JTS 14:00 - 15:00 1.00 RUNCOMP RUNCMP MU LANDING JT & HNGR 55K UP WT & 40K DOWN WT 15:00 - 16:00 1.00 RUNCOMP RUNCMP CLEAR RIG FLOOR CUT ESP & PULL TO SPOOLER 16:00 - 18:00 2.00 RUNCOMP RUNCMP INSTALL PENETRATOR MU LOWER ESP CONNECTOR ATTACH & TEST SAME DRAIN STACK 18:00 - 19:00 1.00 RUNCOMP RUNCMP LAND HNGR & RILDS LD LANDING JT 19:00 - 20:00 1.00 BOPSUF P POST SET TWC & TEST 700 PSI FROM BOTTOM FOR 10 MIN & CHART 3,500 PSI FROM TOP FOR 10 MIN & CHART 20:00 - 22:00 2.00 BOPSUF P POST ND BOPE 22:00 - 00:00 2.00 BOPSUF P POST NU TREE TEST VOID TO 5,000 PSI FOR 30 MIN TEST TREE TO 5,000 PSI MAKE FINAL CHECK ON ESP 1/6/2010 00:00 - 01:00 1.00 BOPSUF P POST RU LUBRICATOR PT TO 500PSI PULL TWC & INST BPV RD LUBRICATOR RELEASE RIG @ 01:00 Printed: 1/25/2010 12:05:11 PM • I ■Aii . BAKER HUGHES 1NTEQ North America - ALASKA - BP Milne Point M Pt E Pad MPE -14 - Slot 14 MPE- 14APB1 Survey: MWD Survey Report - Geographic 23 December, 2009 � bp 0 0 swe MOUES Survey Report - Geographic bP INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPE -14 - Slot 14 Project: Milne Point TVD Reference: Mean Sea Level Site: M Pt E Pad MD Reference: MPE -14 RKB @ 57.70ft (MPE- 14RKB) Well: MPE -14 North Reference: True Wel'bore: MPE- 14APB1 Survey Calculation Method: Minimum Curvature Design: MPE- 14APB1 Database: EDM .16 - Anc Prod - WH24P Project Milne Point, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 1 Site M Pt E Pad, TR -13 -10 Site Position: Northing: 6,013,798.68ft Latitude: 70° 26' 52.982 N From: Map Easting: 569,440.72ft Longitude: 149° 26' 0.655 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 0.53 ° Well MPE -14 API No 500292273400 I Well Position +N / -S 0.00 ft Northing: 6,016,128.06 ft Latitude: 70° 27' 15.912 N +E / -W 0.00 ft Easting: 569,228.18 ft Longitude: 149° 26' 6.261 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore MPE- 14APB1 API No 500292273470 I Magnetics Model Name Sample Date Declination Dip Angle Field Strength j C) C) (nT) BGGM2009 10/21/2009 22.16 80.95 57,663 Des MPE- 14APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,861.09 Vertical Section: Depth From (TVD) +N /-S +E / -W Direction 1 (ft) (ft) (ft) C) -24.30 0.00 0.00 152.10 L Survey Program Date: 12/23/2009 1 From To (ft) (ft) Survey (Wellbore) Tool Name Description 212.69 8,861.09 1 : MWD - Standard (MPE -14) MWD MWD - Standard 8,951.00 9,170.00 MWD (MPE- 14APB1) MWD MWD - Standard L 12/23/2009 9:40:34AM Page 2 COMPASS 2003.16 Build 71 • N.■ BAICER HUGHES Survey Report - Geographic 0 bp INTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well MPE -14 - Slot 14 Project: Milne Point TVD Reference: Mean Sea Level Site: M Pt E Pad MD Reference: MPE -14 RKB © 57.70ft (MPE- 14RKB) Well: MPE - 14 North Reference: True Wel lbore: MPE 14APB1 Survey Calculation Method: Minimum Curvature Design: MPE 14APB1 Database: EDM .16 - Anc Prod - WH24P i Survey -- - - Measured ND Below Map Map Depth Inclination Azimuth System +NI-S +E/ -W Northing Easting (ft) (1 (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 8,861.09 31.54 133.24 6,804.81 - 4,100.29 2,106.85 6,012,047.91 571,372.84 70° 26' 35.584 N 149° 25' 4.408 W TIP 8,951.00 31.26 134.43 6,881.55 - 4,132.73 2,140.64 6,012,015.79 571,406.92 70° 26' 35.264 N 149° 25' 3.416 W KOP 8,970.66 33.74 131.20 6,898.13 4,139.90 2,148.39 6,012,008.69 571,414.74 70° 26' 35.194 N 149° 25' 3.189 W 8,990.18 40.72 128.03 6,913.67 - 4,147.40 2,157.50 6,012,001.27 571,423.92 70° 26' 35.120 N 149° 25' 2.921 W 9,021.98 51.82 132.50 6,935.62 - 4,162.29 2,174.94 6,011,986.55 571,441.50 70° 26' 34.974 N 149° 25' 2.409 W 9,055.35 61.85 141.92 6,953.88 - 4,182.81 2,193.77 6,011,966.20 571,460.51 70° 26' 34.772 N 149° 25' 1.857 W 9,087.43 66.91 148.93 6,967.76 - 4,206.62 2,210.13 6,011,942.55 571,477.09 70° 26' 34.538 N 149° 25' 1.377 W 9,116.45 72.16 138.93 6,977.93 - 4,228.53 2,226.14 6,011,920.79 571,493.30 70° 26' 34.322 N 149° 25' 0.907 W 9,170.00 72.16 138.93 6,994.33 - 4,266.96 2,259.63 6,011,882.68 571,527.14 70° 26' 33.944 N 149° 24' 59.924 W TD Targets Target Name - hit/miss target Dip Angle Dip Dir. ND +NI-S +E / -W Northing Easting , - Shape ( ( (ft) (ft) (ft) (ft) (ft) Latitude Longitude MPE -14A T1.5 0.00 0.00 6,985.00 - 4,502.10 2,520.34 6,011,650.00 571,790.00 70° 26' 31.631 N 149° 24' 52.273 W - survey misses target center by 351.20ft at 9170.00ft MD (6994.33 TVD, - 4266.96 N, 2259.63 E) - Point MPE -14A ploygon 0.00 0.00 -57.70 - 5,614.66 2,780.04 6,010,540.00 572,060.00 70° 26' 20.688 N 149° 24' 44.661 W - survey misses target center by 7059.78ft at 8861.09ft MD (6804.81 TVD, - 4100.29 N, 2106.85 E) - Polygon Point 1 -57.70 - 5,606.19 2,945.14 6,010,550.00 572,225.00 Point 2 -57.70 - 4,595.35 2,869.52 6,011,560.00 572,140.00 Point 3 -57.70 - 4,129.75 2,273.77 6,012,020.00 571,540.00 i Point4 -57.70 - 4,407.95 2,076.15 6,011,740.00 571,345.00 Point 5 -57.70 - 4,927.44 2,551.39 6,011,225.00 571,825.00 Point 6 -57.70 - 5,614.66 2,780.04 6,010,540.00 572,060.00 MPE -14A T2.5 0.00 0.00 6,970.00 - 5,511.72 2,895.01 6,010,644.00 572,174.00 70° 26' 21.700 N 149° 24' 41.285 W - survey misses target center by 1397.75ft at 9170.00ft MD (6994.33 TVD, - 4266.96 N, 2259.63 E) - Point Survey Annotations Measured Vertical Local Coordinates Depth Depth +N / -S +E/ -W (ft) (ft) (ft) (ft) Comment 8,861.09 6,804.81 - 4,100.29 2,106.85 TIP 8,951.00 6,881.55 - 4,132.73 2,140.64 KOP 9,170.00 6,994.33 - 4,266.96 2,259.63 TD _ J Checked By: Approved By: Date: 12/23/2009 9:40:34AM Page 3 COMPASS 2003.16 Build 71 • 0 RIM BAKER HUGHES INTEQ North America - ALASKA - BP Milne Point M Pt E Pad MPE -14 - Slot 14 MPE -14A Survey: MWD Survey Report - Geographic 23 December, 2009 � bp • 0 Mall HUGHES alum Survey Report - Geographic 0 bP 1NTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well MPE -14 - Slot 14 Project: Milne Point ND Reference: Mean Sea Level Site: M Pt E Pad MD Reference: MPE -14 RKB © 57.70ft (MPE- 14RKB) Well: MPE - 14 North Reference: True Welibore: MPE - 14A Survey Calculation Method: Minimum Curvature Design: MPE -14A Database: EDM .16 - Anc Prod - WH24P Project Milne Point, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt E Pad, TR -13 -10 I Site Position: Northing: 6,013,798.68ft Latitude: 70° 26' 52.982 NI I From: Map Easting: 569,440.72ft Longitude: 149° 26' 0.655 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.53 0 J Well MPE - 14 API No 500292273400 Well Position +N / - 0.00 ft Northing: 6,016,128.06 ft Latitude: 70° 27' 15.912 N +E / - 0.00 ft Easting: 569,228.18 ft Longitude: 149° 26' 6.261 W i Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft J I Wellbore MPE -14A API No 500292273401 I Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) (°) (nT) BGGM2009 12/22/2009 22.08 80.96 57,667 Design MPE -14A -- — - - -- Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,055.35 I Vertical Section: Depth From (ND) +N /-S +E/ -W Direction (ft) (ft) (ft) ( I -24.30 0.00 0.00 151.44 I Survey Program Date: 12/23/2009 From To (ft) (ft) Survey (Welibore) Tool Name Description 212.69 8,861.09 1 : MWD - Standard (MPE -14) MWD MWD - Standard 8,951.00 9,055.35 MWD (MPE- 14APB1) MWD MWD - Standard 9,073.00 10,194.00 MWD (MPE -14A) MWD MWD - Standard 12/23/2009 9:42:14AM Page 2 COMPASS 2003.16 Build 71 • • 0 • PI MOMS Survey Report - Geographic 0 bp INTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well MPE -14 - Slot 14 Project: Milne Point TVD Reference: Mean Sea Level Site: M Pt E Pad MD Reference: MPE -14 RKB @ 57.70ft (MPE- 14RKB) Well: MPE - 14 North Reference: True Wellbore: MPE - 14A Survey Calculation Method: Minimum Curvature Design: MPE - 14A Database: EDM .16 - Anc Prod - WH24P - -- --- - --------------------- Survey 1 Measured TVD Below Map Map Depth Inclination Azimuth System +NI-S +E/ -W Northing Easting ' (ft) ( (") (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,055.35 61.85 141.92 6,953.88 - 4,182.81 2,193.77 6,011,966.20 571,460.51 70° 26' 34.772 N 149° 25' 1.857 W TIP 9,073.00 64.59 145.85 6,961.84 - 4,195.54 2,203.04 6,011,953.56 571,469.90 70° 26' 34.647 N 149° 25' 1.585 W KOP 9,100.06 70.81 136.59 6,972.12 - 4,214.99 2,218.73 6,011,934.26 571,485.77 70° 26' 34.455 N 149° 25' 1.124 W 9,130.53 78.83 137.52 6,980.09 - 4,236.50 2,238.75 6,011,912.94 571,505.98 70° 26' 34.244 N 149° 25' 0.537 W 9,158.20 87.08 140.77 6,983.48 - 4,257.26 2,256.69 6,011,892.35 571,524.11 70° 26' 34.039 N 149° 25' 0.010 W 9,201.36 88.96 137.28 6,984.97 - 4,289.82 2,284.96 6,011,860.06 571,552.69 70° 26' 33.719 N 149° 24' 59.180 W 9,234.35 87.70 134.73 6,985.93 - 4,313.54 2,307.87 6,011,836.56 571,575.81 70° 26' 33.486 N 149° 24' 58.508 W1 9,268.17 86.81 131.17 6,987.55 - 4,336.55 2,332.59 6,011,813.78 571,600.74 70° 26' 33.259 N 149° 24' 57.783 W 9,313.92 88.89 127.49 6,989.27 - 4,365.52 2,367.94 6,011,785.14 571,636.36 70° 26' 32.974 N 149° 24' 56.745 W I 9,352.60 92.58 128.77 6,988.77 - 4,389.40 2,398.36 6,011,761.55 571,666.99 70° 26' 32.739 N 149° 24' 55.852 W 9,395.88 91.66 133.19 6,987.17 - 4,417.75 2,431.01 6,011,733.50 571,699.90 70° 26' 32.460 N 149° 24' 54.894 W 9,425.23 91.47 136.27 6,986.37 - 4,438.40 2,451.85 6,011,713.05 571,720.92 70° 26' 32.257 N 149° 24' 54.283 W 9,457.71 91.14 139.92 6,985.63 - 4,462.56 2,473.53 6,011,689.09 571,742.83 70° 26' 32.020 N 149° 24' 53.646 W � 9,487.95 90.61 142.60 6,985.17 - 4,486.14 2,492.45 6,011,665.69 571,761.97 70° 26' 31.788 N 149° 24' 53.091 W I 9,520.74 89.57 144.59 6,985.12 - 4,512.53 2,511.91 6,011,639.49 571,781.67 70° 26' 31.528 N 149° 24' 52.520 W i 9,550.32 88.68 147.17 6,985.57 - 4,537.01 2,528.50 6,011,615.16 571,798.48 70° 26' 31.287 N 149° 24' 52.033 W 9,580.68 87.63 149.60 6,986.55 - 4,562.85 2,544.40 6,011,589.47 571,814.63 70° 26' 31.033 N 149° 24' 51.567 W 9,609.90 88.00 153.45 6,987.66 - 4,588.52 2,558.32 6,011,563.95 571,828.78 70° 26' 30.781 N 149° 24' 51.158 W 9,643.41 90.80 156.59 6,988.01 - 4,618.88 2,572.47 6,011,533.71 571,843.21 70° 26' 30.482 N 149° 24' 50.743 W 9,670.05 94.03 161.00 6,986.89 - 4,643.69 2,582.09 6,011,509.00 571,853.06 70° 26' 30.238 N 149° 24' 50.461 W 9,700.73 93.69 164.81 6,984.82 - 4,672.94 2,591.09 6,011,479.84 571,862.33 70° 26' 29.950 N 149° 24' 50.197 W 9,724.78 92.58 166.94 6,983.51 - 4,696.23 2,596.95 6,011,456.61 571,868.40 70° 26' 29.721 N 149° 24' 50.026 W, 9,750.94 90.28 168.32 6,982.86 - 4,721.77 2,602.55 6,011,431.12 571,874.24 70° 26' 29.470 N 149° 24' 49.861 W 9,780.34 89.11 164.45 6,983.01 - 4,750.34 2,609.47 6,011,402.62 571,881.43 70° 26' 29.189 N 149° 24' 49.659 W 9,809.48 91.38 162.02 6,982.89 - 4,778.23 2,617.87 6,011,374.81 571,890.09 70° 26' 28.915 N 149° 24' 49.412 W 9,841.67 89.69 156.45 6,982.59 - 4,808.32 2,629.28 6,011,344.83 571,901.77 70° 26' 28.619 N 149° 24' 49.078 W I 9,870.67 89.54 153.34 6,982.78 - 4,834.57 2,641.58 6,011,318.69 571,914.32 70° 26' 28.360 N 149° 24' 48.717 W I, 9,899.68 90.03 150.83 6,982.89 - 4,860.21 2,655.16 6,011,293.19 571,928.13 70° 26' 28.108 N 149° 24' 48.318 W 9,924.05 93.41 147.08 6,982.16 - 4,881.07 2,667.72 6,011,272.45 571,940.88 70° 26' 27.903 N 149° 24' 47.950 W I 9,942.69 97.86 144.27 6,980.33 - 4,896.38 2,678.18 6,011,257.23 571,951.48 70° 26' 27.752 N 149° 24' 47.643 W 9,960.27 96.09 141.41 6,978.19 - 4,910.29 2,688.72 6,011,243.43 571,962.15 70° 26' 27.616 N 149° 24' 47.334 W 9,979.57 92.21 137.28 6,976.80 - 4,924.89 2,701.25 6,011,228.95 571,974.82 70° 26' 27.472 N 149° 24' 46.966 W 9,999.63 88.86 141.21 6,976.61 - 4,940.07 2,714.34 6,011,213.88 571,988.05 70° 26' 27.323 N 149° 24' 46.582 W 10,015.54 90.55 146.30 6,976.69 - 4,952.90 2,723.75 6,011,201.15 571,997.57 70° 26' 27.196 N 149° 24' 46.306 W I 10,029.32 93.75 147.03 6,976.17 - 4,964.40 2,731.31 6,011,189.71 572,005.24 70° 26' 27.083 N 149° 24' 46.084 W 10,045.76 96.62 148.72 6,974.69 - 4,978.27 2,740.02 6,011,175.93 572,014.07 70° 26' 26.947 N 149° 24' 45.829 W I 10,075.26 98.32 156.31 6,970.85 - 5,004.19 2,753.51 6,011,150.14 572,027.80 70° 26' 26.692 N 149° 24' 45.433 W I 10,100.02 95.04 160.53 6,967.97 - 5,027.05 2,762.55 6,011,127.36 572,037.05 70° 26' 26.467 N 149° 24' 45.168 W 10,129.71 93.41 166.59 6,965.78 - 5,055.44 2,770.92 6,011,099.06 572,045.69 70° 26' 26.188 N 149° 24' 44.922 W I 10,194.00 93.41 166.59 6,961.95 - 5,117.87 2,785.81 6,011,036.78 572,061.15 70° 26' 25.574 N 149° 24' 44.486 W TD - 2 - 718" I 12/23/2009 9.42 ::14AM Page 3 COMPASS 2003.16 Build 71 0 • rd RV 0 Survey Report - Geographic bP 1NTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well MPE -14 - Slot 14 Project: Milne Point TVD Reference: Mean Sea Level Site: M Pt E Pad MD Reference: MPE -14 RKB @ 57.70ft (MPE- 14RKB) I Well: MPE - 14 North Reference: True Weilbore: MPE - 14A Survey Calculation Method: Minimum Curvature Design: MPE - 14A Database: EDM .16 - Anc Prod - WH24P Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (In) (in) ! 10,194.00 6,961.95 2 -7/8" 2.875 4.125 1 Survey Annotations ! Measured Vertical Local Coordinates Depth Depth +N /-S +E/ -W (ft) (ft) � (ft) (ft) Comment 9,055.35 6,953.88 - 4,182.81 2,193.77 TIP 9,073.00 6,961.84 - 4,195.54 2,203.04 KOP I ! 10,194.00 6,961.95 - 5,117.87 2,785.81 TD L Checked By: Approved By: Date: 12/23/2009 9:42:14AM Page 4 COMPASS 2003.16 Build 71 • III Tree: Cameron 2 9/16" 5M Orig. KB Elev. = 57.60' (N 27E) Wellhead: 11" x 7 1/16" 5M FMC M PU E -14a Orig. GL Elev. = 24.7' Gen 5A Ultra slim, w/ 2 1/2" Tbg Hgr / . RT To Tbg. Spool = 33.5' (N 27E) 2 7/8: EUE 8rd T &B thread 0 'l 2 1/2" CIW BPV profile 0 20" 91.1 ppf, H-40 112' 0 0 Camco 2 7/8" x 1" I 140' 0 sidepocket KBMM GLM KOP @ 900' 0 NOTE: Well was side tracked Max. hole angle = 52 deg. @ 5953' 0 , i o CTD from the top of a WS @ Hole angle thru' perrs = > 31 deg. 0 8950' with a CIBP set @ 8975'. Max. DLS = 4.8 @ 5431' 0 NOTE: Due to Tbg tally discrepancies the GLMs, the XN nipple and the ESP top 9 5/8 ", 40 ppf, L - Btrc. 5543 I 0 e , may not be at the depths shown on drawing. 0 1/5/10 g o Camco 2 7/8" x 1" $ / i sidepocket KBMM GLM 8497' I 2 7/8" 6.5 ppf, L -80, EU 8rd Tbg ( drift ID = 2.347 ", cap. = 0.0059 bpf) / ma 7" 26 ppf, L -80, NSCC production casing $ 2 -7/8" XN Nipple ( 2.205 ") I 8611' ( drift ID = 6.151 ", cap. = 0.0383 bpf) 0 ( cap w/ 2 7/8" tbg inside = 0.02758 bpf) / Centrilift 137 -P17 ESP, I 8644' PMSXD 0 0 # Gas Separator GRSFTXARH6 I 8664' Intake TVD =' r' Tandem Seal Section I 8676' G563 DB LT /UT 0 ant Motor Rerated to KMH -A I 8682' 0 = 140 hp, 2244 volt, 37 amp ISIMMIL PumpMate XTO Sensor w/ I 8699' 6 fin centralizer PumpMate TVD =' BOT PBR 80 -47 Seal Nipple I 8706' I BOT 7" x 4.5" S -3 Pkr I 8745' I I BOT KB LTP w/ 4" GS fish neck & 42 -30 Seal Assy. 2.36" ID 4.5" XN Nipple ( ) 2.750" w/ I 8816' I 111 t BOT Lnr deployment sleeve w/ 4" plug 1 f GS fish neck & 3.00" seal bore & 4.5 " WLEG I 8890' I I 1 1.750" min ID. 3 3/16" Solid Lnr Shoe @ 9073'1 ` 12 3/8" 4.7# L-80 STL Solid Cemented Lnr 1807 4.5 x 7" Whipstock @ 8950' 1 7" CIBP (, 8975' - - -). IPBTD @ 10,105" ... :.: ' ::.i;C : ;;Zilltr , \ " Perforation Intervals All shots using 1.56" 6 SPF 1606P 7" x 4.5" Versatrieve Pkr I 8985' I MD TVD 2 -3/8" Shoe @10120' 9500' -9560' 7043' - 7044' TD @ 10194' MESIVISM 4.5" 316L 125 Micron Poroplusl 9031' I H ;i 9960' - 7 036 -7 2 ._,..,. 9960' - 10050' 7036' - 7032' Screen 4.5" XN Nipple ( 2.750 ") w/ I 9103' plug WLEG 9115' I 7" float collar (PBTD) 9260' I short joints 8852' -8894' I 4 7" float shoe 9344' DATE REV. BY COMMENTS MILNE POINT UNIT 04 -12 -97 MDO 7" Cased hole Completion 271 05 -08 -97 MDO ESP Completion 4 -ES Well No : MPE -14a 9-15 -9/ MDO 2nd ESP Completion 4-ES API • 50 -029- 22734 -01 7 - - MDO ESP Completion /Screen Added 5 S 03 -21 -00 M.Linder RWO 4-ES 6 -28 -08 LH RWO with 3S 11/19/09 LH RWO w/ 4ES: Pull ESP and install CTD work string BP EXPLORATION (AK) 1/5/10 LH CTD Side Track & ESP completion I • d , p i ' S S F no t" ;: pk'F 5� i G ? a N �, i t \ M SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION )" ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 Re: Milne Point, Kuparuk River Sands, MPE -14A BP Exploration (Alaska) Inc. Permit No: 209 -128 Surface Location: 3590' FSL, 1918' FEL, SEC.25, T13N, R10E, UM Bottomhole Location: 1918' FNL, 976' FWL, SEC. 31, T13N, R11E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). cerely, aniel T. Seamount, Jr. Chair DATED this day of November, 2009 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RECEIVED ALASIt OIL AND GAS CONSERVATION COMMI•N PERMIT TO DRILL OCT 2 7 2009 20 AAC 25.005 1 a. Type of work: lb. Proposed Well Class: ® Development Oil • ❑ Service - Winj ❑ Single Zone visite 0114frikitifigrn . for ❑ Drill ® Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed i l l t N El to Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp CC�n aShale Gas 2. Operator Name: 5. Bond: ® Blanket • ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 ' MPE - 14A • 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 - 6612 MD • 10615' TVD 6970'ss ' Milne Point Unit / Kuparuk , 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): River Sands , Surface: , • ADL 025518 & 028231 • 3590' FSL, 1918' FEL, SEC. 25, T13N, R10E, UM' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 483' FNL, 159' FWL, SEC. 31, T13N, R11E, UM December 1, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1918' FNL, 976' FWL, SEC. 31, T13N, R11E, UM 2560 6,025' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 57.7' . feet 15. Distance to Nearest Well Open Surface: x- 569228 y- 6016128 Zone- ASP4 GL Elevation above MSL: 24.3' feet to Same Pool: 2,840' 16. Deviated Wells: Kickoff Depth: 8950. feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 4730 Surface: 2400 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4 -1/8" 3- 3/16" 6.2# L -80 TCII 280' 8800' 6753'ss 9080' - 6965'ss Not Cemented 3" 2 -3/8" 4.7# L -80 STL 1835' 8780' 6736'ss 10615'- 6970'ss 27 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 9370' 7300' 9103' 9260' 7205' None Casing Length Size Cement Volume MD TVD Conductor / Structural 112' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5511' 9 -5/8" 1750 sx PF 'E'. 300 sx Class 'G'. 89 sx PF 'C' 5543' 4587' Intermediate Production Liner 9319' 7" 250 sx Class 'G' 9344' 7277' Perforation Depth MD (ft): 9030' - 9096' Perforation Depth TVD (ft): 7007' - 7063' 20. Attachments: ❑ Property Plat C BOP Sketch ■= Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564 -4387 Printed Name John . M ,, _ / Title Engineering Team Leader Prepared By Name/Number: Signature � / Al Phone 564 -4711 Date I v ' d 1 Terrie Hubble, 564 -4628 i ' Commission Use Only Permit To Drill API Number: Permit fr sl I I See cover letter for Number: ji� 50- 029 - 22734 -01 -00 ( / / / /� other requirements well may not be used to explore for, test, or produce coalbeC met ane, gas hydrates, of Approval: If box is checked, e y p drates, or gas contained shales: p 9 Y Other: It• 3 So O p S v ,B OP -- . f Samples Req'd: ❑ yes 12 Mud Log Req'd: ❑ yes No rAi / CH2S Measures: Yes ❑ No Directional Survey Req'd: Yes ❑ No 0 ,p.3 z A►1 n w�414'4' fag— svc.. ` 7 APPROVED BY THE COMMISSION / 2- Date , COMMISSIONER Form 10-401 Revised 0 /2009 This permit i aqd 211 nths from the d • - • approval (20 AAC 25.005(g)) Submit In Duplicate x A • 0 bP Co: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: October 16, 2009 Re: Milne Point E -14A PTD request Approval is requested for a permit to drill a CTD sidetrack from well Milne Point E -14. MPE -14 is a Kuparuk C/B sand producer that is high water cut (- -94 %). MPE -14A will be drilled to a more optimum location. The sidetrack, MPE -14A, is scheduled to be drilled by Nordic 2 starting December 1, 2009 using the managed pressure drilling technique. This horizontal lateral will target Kuparuk B sand reserves to capture currently nonrecoverable resources. The perforations in the parent well will be abandoned with a 7" cast iron bridge plug which is the subject of a separate sundry application. The "A" sidetrack lateral will exit the parent well at 8,950' - md in the D shale and drill a -130' build to a TO of 9,080' md. At this point uncemented 3 -3/16" drilling liner will be run to eliminate stability concerns of the D shale. A 3" lateral will then be drilled to 10,615' md. The sidetrack will be completed with a solid, cemented and perforated 2 -3/8" liner from TD to 40' above the 3 -3/16" shoe. Managed Pressure Drilling Technique The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure drilling technique. Due to uncertainties about the bottom hole pressures to be encountered as this sidetrack is drilled, managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using 8.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits and will be independent of the BOPE choke. This well does not have a functioning tubing sub - surface safety valve that could be utilized to facilitate BHA deployments and liner running. ft is possible that deployment of the BHA under trapped wellhead pressure may be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe /slips (3" or 2 -3/8" rams, see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected for MPE -14A: • Latest Reservoir pressure in the parent well: 3,100 psi at 7000' TVDSS, 8.5 ppg EMW, ° • The D shale is over pressured and is expected to be at a 9.5 --13.0 ppg EMW. Once behind pipe and ✓ pressure relaxed the D is expected to fall in and isolate it self. • Expected pressure as the lateral is drilled is the same as the parent (3100 psi). • Expected annular friction losses while circulating: 535 psi at KOP and 686 psi at TD (assuming 90 psi /1000 ft, for a 1680' lateral). • Planned mud density: 8.8 ppg equates to 3,143 psi hydrostatic pressure at the window. • While circulating 8.8 ppg fluid, at the start of the lateral (kick off in D shale), the bottom hole circulating pressure is estimated to be 3,678 psi or 10.3 ppg ECD. For shale stability an 11.0 EMW will be held while drilling ," thru the D shale. This equates to a -. 250 psi applied surface pressure while drilling. • When circulation is stopped, a -736 psi surface pressure will be applied to maintain a constant BHP of 11 ppg EMD. At the start of the lateral, the mud in the rig pits will be 8.8 ppg mud. KWF will be stored on location in upright --1 -q. The tankage will contain 2 weflbore volumes of KWF (11 ppg expected) to exceed the maximum possible ^nuntered as the lateral is drilled. This KWF will also be used for liner running operation. • • CTD Sidetrack Summary Prior to drilling operations a workover rig will lay down the ESP completion and run a 4-1/2" workstring. After the coil drilling unit is rigged down the workover rig will return to pull the kill string and rerun the ESP completion Nabors 4ES RWO operations: The RWO is slated to begin about November 1, 2009. 1. MIRU. Test BOPE to 3500 psi. 2. Kill Well 3. Pull 2 -7/8" ESP completion 4. Perform a scraper run in the 7" csg to the top of the 7" Versatrieve packer (actually tag pacer) 5. Set CIBP at 8975'. Test 7" csg integrity to,J1189-5 i. Z f'` ( /o 3c)-07) 6. Run 4 -1/2" workstring with a Baker S -3 pkr and PBR. Ensure TT is at or above 8850' MD. 7. Set packer 8. PT the IA and tbg to 1000 -psi surface pressure to ensure the seal assembly is holding and to test the casing /tubing integrity. 9. RDMO to allow Nordic II to sidetrack well Pre -CT Rig Work: The pre CTD work is slated to begin immediately following the RWO. 1. Pull ball and rod 2. Pull RHC sleeve 3. Run dummy WS drift to 8975' 4. Set Baker whipstock at 8,950' 5. Extend pad with an ice apron 6. Bleed, remove, and blind flowlines 7. Drill mousehole extension 3 Rig Sidetrack Operations: (Scheduled to begin on December 1, 2009 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7- 1/16" CT Drilling BOPE and test. 3. Mill 3.8" window in 7" casing from mechanical whipstock set at 8,950'. 4. Drill build section with 4 -1/8" bicenter bit, and land well in target B sand. 5. Flow check well and lay in KWF as needed. k,;,s 6. Run uncemented 3- 3/16" drilling liner across the D shale - 7. Drill lateral section to 10,615' 8. Flow check well and lay in KWF as needed. 9. Run and cement a 2 -3/8" L -80 liner string. Expect -5.5 bbl of 15.8 ppg cement 10. Make a cleanout run with mill and motor. 11. Make a logging run with a memory SWS GR -CCL logging tool. 12. Perforate well. 13. Circulate well to KWF brine. FP well to 2000'. 14. ND 7- 1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDMO Nordic 2. Nabors 4ES RWO operations: The RWO is slated to begin after the sidetrack. 1. MIRU after Nordic II finishes 2. Test BOPE to 3500 psi. 3. Shear PBR and pull 4 -1/2" workstring 4. run new ESP on 2 -7/8" tubing to above 8700' 5. RDMO Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Pull BPV. Mud Program: • Well kill: 11 ppg brine to start. Adjust whit real time BHP monitoring. • Milling /drilling: 8.8 ppg Geo -VIS or biozan for milling, new 8.8 ppg Geo -VIS for drilling. • KWF will be needed for running and cementing liner. BHP will be measured prior to tripping to run liner and KWF adjusted as needed. • Standby KWF. At the start of the well there will be 2 welibore volumes of 11.0 ppg KWF on location in upright tanks. Disposal: • All Class II drilling and completion fluids will go to Grind & Inject at DS 4, or to the KRU 1R pad disposal - well. • All Class II drilling solids will go to Grind & Inject at DS 4. • All Class 1 wastes will go to Pad 3 for disposal. Hole sizes: 4 -1/8 bi- center hole: 8,920' to 9,080' • 3.0" bi- center hole: 9,080' - 10,615' Casing Program: short drilling liner followed by a cemented production liner • 3- 3/16 ", L -80 6.2# TCII 8800' and - 9080' and • 2 -3/8 ", L -80 4.70# STL 8780' and - 10,615' and • A minimum of 5.5 bbls 15.8 ppg cement will be used for liner cementing. (Assuming 3.0" bit size and TD 10,615', with 10% excess in the open hole interval) • TOC planned at 9060' (Near bottom of 3- 3/16" liner) • A liner top packer will be run to isolate the annulus. Well Control: • Two welibore volumes of KWF ( -280 bbls) will be on location at all times during drilling operations. ' • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 92.0 deg at 10,018'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 6025 ft. (To planned perforations in new lateral) • Distance to nearest well within pool - 2840' from MPE -07 to planned perforations in new lateral. Anti - Collision • There are no collision issues Logging • MWD directional, Gamma Ray and Resistivity logs will be run over all of the open hole section. ' • Cased hole GR /CCL, logs will be run. Hazards • The maximum recorded H2S level on MPE -14 is 9.2 ppm. • The maximum recorded H2S level on MP E pad was 53 ppm on well MPE -17i. (February 2001).' • Lost circulation risk is low. Reservoir Pressure • The reservoir pressure on MPE -14 was last recorded at 3,100 psi at 7,000' TVDSS. (8.5 ppg equivalent) ' • Max. expected surface pressure with gas (0.10 psi /ft) to surface is 2,400 psi. • As the well is drilled, isolated areas with greater or lesser pressure than that found in the parent wellbore may be encountered. The max expected pressure is 4,730 psi (13.0 EMW) in the D shale. ✓ Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble • Tree: Cameron 2 9/16" 5M Orig. KB Elev. = 57.60' (N 27E) Wellhead: 11" x 7 1/16" 5M FMC M P U E -14 Orig. GL Elev. = 24.7' Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" RT To Tbg. Spool = 33.5' (N 27E) LH acme on top and 2 7/8" EUE 8 rd 0 k , on bottom, 2.5" CIW BPV profile 0 ■ 20" 91.1 ppf, H -40 112' 0 0 > Camco 2 7/8" x 1" 139' KOP @ 900' sidepocket KBMM GLM Max. hole angle = 52 deg. @ 5953' Hole angle thru' perfs = > 31 deg. 0 Max. DLS = 4.8 @ 5431' r, 9 5/8 ", 40 ppf, L -80 Btrc. 554 I ■ ; ! 0 l 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. g ( drift ID = 2.347 ", cap. = 0.00592 bpf) 7" 26 ppf, L -80, NSCC production casing %' ; ( drift ID = 6.151 ", cap. = 0.0383 bpf) t I Camco 2 7/8" x 1" sidepocket KBMM GLM 8670' / ; $ ME 2 -7/8" XN Nipple ( 2.205 ") 8813' I .... Centrilift 74 -P23 ESP, 8829' PMSXD 1:7 538 t II � 7 Intake Separator GRSFTXARH6 8840' `, ake TVD = 6845' 0- Tandem Seal Section 8845' ,' .' -' GSB3 DB FER HL SSCV H6 SB /SB PFSA Stimulation Summary , d- None performed /,, Motor Rerated to KMH -A 8859' 152 hp, 2152 volt, 31 amp MIN mise PumpMate XTO Sensor w/ 8873' — 6 fin centralizer Perforation Summary 01-MI TVD = 6873' MII Ref Ioa: GR/CCL 04/16/97 7" HES Versatrieve Pkr. 8985' Size Spf MD TVD 4.5" 316L 125 Micron Kup.'C' 9031' Poroplus screen 11.6# LTC 4.5" 5 9030-9060' (6998'- 7024') Kuo. `B' 4.5" 5 9066' -9096' 7029'- 7055) 1 4.5" HES XN Nipple (2.750" id) 9103' 37 gm. HyperJet II charges (EHD = (W/ Plug ) III 0.46 ", TTP = 34.58 ") 5 JSPF @ 60 WLEG 9115' deg. phasing 7" float collar (PBTD) 9260' short joints 8852' -8894' 4 , 7" float shoe 9344' DATE REV. BY COMMENTS 04 -12 -97 MDO 7" Cased hole Completion 27 MILNE POINT UNIT 05-08-97 MDO ESP Completion 4 -ES Well No : E -14 9 -15 -97 MDO 2nd ESP Completion 4 -ES API : 50 -029 -22734 7 - - MDO ESP Completion /Screen Added 5 S 03 -21 -00 M. Linder RWO4 -ES BP EXPLORATION (AK) 6 -28 -08 LH RWO with 3S • • MPU E -14A Proposed Single Lateral B7 Sand CTD Sidetrack Tree: Cameron 2 9/16" 5M Wellhead: 11" x 7 1/16" 5M FMC Orig. KB Elev. = 57.60' (N 27E) Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" Orig. GL Elev. = 24.7' LH acme on top and 2 7/8" EUE 8 rd RT To Tbg. Spool = 33.5' (N 27E) on bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H -40 112' Camco 2 7/8" x 1" 139' KOP @ 900' sidepocket KBMM GLM Max. hole angle = 52 deg. @ 5953' Hole angle thru' perfs = > 31 deg. Max. DLS = 4.8 @ 5431' 9 5/8 ", 40 ppf, L -80 Btrc. 5543 4 - 1/2" Workstring to be pulled 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. for ESP completion post CTD ( drift ID = 2.347 ", cap. = 0.00592 bpf ) 7" 26 ppf, L -80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383 bpf) Camco 2 7/8" x 1" sidepocket KBMM GLM 8670' 2 -7/8" XN Nipple ( 2.205 ") 8813' Centrilift 74 -P23 ESP, 8829' PMSXD 1:7 538 Gas Separator GRSFTXARH6 8840' Intake TVD = 6845' Tandem Seal Section 8845' GSB3 DB FER HL SSCV H6 SB /SB PFSA Stimulation Summary None performed Motor Rerated to KMH -A 8859' 152 hp, 2152 volt, 31 amp Baker 20' PBR Above Packer @8730' PumpMate XTO Sensor w/ 8873' Baker 7" x 4 -1/2" S -3 L -80 Packer J 6 fin centralizer (To Remain in the Hole post W /O) PumpMate TVD = 6873' @-8,750' j Liner top packer X NIP 3.813" ID @ 8820' 4 -1/2" TTail with WLEG @ Baker 4 -1/2" x 7" Whipstock 3- 3/16" Solid Liner @ 9080' @ 8,950' -7" CIBP @ 8975' TD= 10,600' J ` 7" HES Versatrieve Pkr. 8985' 4.5" 316L 125 Micron 9031' Poroplus screen 11.6# LTC 4.5" HES XN- Nipple (2.750" id) 9103' 2-3/8" Solid /Cmfd Liner ( (W/ Plug ) WLEG 9115' 7" float collar (PBTD) 9260' 7" float shoe 9344' DATE REV. BY COMMENTS 04 -12 -97 MDO 7' Cased hole Completion 27E MILNE POINT UNIT 05 -08 -97 MDO ESP Completion 4 -ES Well No : E -14 9 -15 -97 MDO 2nd ESP Completion 4 -ES API : 50- 029 -22734 7 -19 -96 MDO ESP Completion /Screen Added 5 S 03 -21 -00 M. Linder RWO4 -ES BP EXPLORATION (AK) 6 -28 -08 LH RWO with 3S EMI Baker Hughes INTEQ BAKER HUGE= Baker Hughes INTEQ Planning Report 0 bP INTEQ Company: North America - ALASKA - BP Local Coordinate Reference: Well MPE -14 - Slot 14 Project: Milne Point ND Reference: MPE -14 RKB @ 57.70ft (MPE- 14RKB) - Site: M Pt E Pad MD Reference: MPE -14 RKB © 57.70ft (MPE- 14RKB) Well: MPE -14 North Reference: True Wellbore: Plan 5, MPE -14A Survey Calculation Method: Minimum Curvature Design: Plan 5 Database: EDM 2003.16 Single User Db Survey Tool Program Date 10/26/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description i 212.69 8,861.09 1 : MWD - Standard (MPE -14) MWD MWD - Standard 8,861.09 10,614.98 Plan 5 (Plan 5, MPE -14A) MWD MWD - Standard Planned Survey MD Inc Azi TVDSS N/S EIW Northing Fasting DLeg V. Sec TFace (ft) (°) ( °) (ft) (ft) (ft) on (ft) ( ° 1100ft) (ft) ( °) 8,861.09 31.54 133.24 6,804.81 - 4,100.29 2,106.85 6,012,047.91 571,372.84 0.00 4,505.87 0.00 TIP 8,900.00 31.42 133.76 6,837.99 - 4,114.27 2,121.59 6,012,034.06 571,387.70 0.77 4,523.19 114.81 8,950.00 / 31.26 134.43 6,880.70 - 4,132.37 2,140.27 6,012,016.14 571,406.54 0.77 4,545.50 114.37 KOP 8,970.00 33.06 134.43 6,897.63 - 4,139.82 2,147.87 6,012,008.76 571,414.21 9.00 4,554.67 0.00 End of 9 Deg /100' DLS 9,000.00 42.00 134.43 6,921.40 - 4,152.60 2,160.90 6,011,996.11 571,427.37 29.80 4,570.39 0.00 9,100.00 71.80 134.43 6,975.39 - 4,210.59 2,220.05 6,011,938.68 571,487.05 29.80 4,641.71 0.00 9,161.07 90.00 134.43 6,985.01 - 4,252.63 2,262.94 6,011,897.04 571,530.32 29.80 4,693.41 0.00 End of 29.80 Deg /100' DLS 9,200.00 90.00 129.76 6,985.01 - 4,278.71 2,291.81 6,011,871.23 571,559.43 12.00 4,726.08 -90.0 9,270.00 90.00 121.36 6,985.01 - 4,319.39 2,348.71 6,011,831.09 571,616.70 12.00 4,780.10 -90.00 5 9,300.00 90.00 124.96 6,985.01 - 4,335.79 2,373.82 6,011,814.92 571,641.96 12.00 4,802.44 90.00 9,400.00 90.00 136.96 6,985.01 - 4,401.22 2,449.20 6,011,750.20 571,717.94 12.00 4,885.15 90.00 9,500.00 90.00 148.96 6,985.01 - 4,480.89 2,509.33 6,011,671.10 571,778.80 12.00 4,977.67 90.00 9,520.00 90.00 151.36 6,985.01 - 4,498.24 2,519.29 6,011,653.84 571,788.91 12.00 4,997.01 90.00 6 9,600.00 90.67 141.78 6,984.55 - 4,564.93 2,563.30 6,011,587.58 571,833.54 12.00 5,072.81 -86.00 9,620.00 90.83 139.39 6,984.28 - 4,580.38 2,576.00 6,011,572.25 571,846.38 12.00 5,091.02 -86.06 7 9,700.00 90.82 148.99 6,983.13 - 4,645.17 2,622.75 6,011,507.90 571,893.73 12.00 5,165.70 90.00 10/26/2009 9 :21 :55AM Page 3 COMPASS 2003.16 Build 71 EMI Baker Hughes INTEQ IIIIIXIR 0 ' IIIHN EU Baker Hughes INTEQ Planning Report bP INTEQ Company: North America - ALASKA - BP Local Co-ordinate Reference: Well MPE -14 - Slot 14 Project: Milne Point TVD Reference: MPE -14 RKB @ 57.70ft (MPE- 14RKB) Site: M Pt E Pad MD Reference: MPE -14 RKB @ 57.70ft (MPE- 14RKB) Well: MPE -14 North Reference: True Welibore: Plan 5, MPE -14A Survey Calculation Method: Minimum Curvature Design: Plan 5 Database: • EDM 2003.16 Single User Db Planned Survey MD 0) Inc I { )/ Azi TVDSS NIS E/W Northing E..a sting DLneng� V. Sec TFace (ft) (ftf ( 00 ( it) (ft) (ft) // tft) (1 �ft) (°) 9,800.00 90.77 160.99 6,981.73 - 4,735.61 2,664.95 6,011,417.86 571,936.76 12.00 5,263.99 90.14 9,870.00 90.72 169.39 6,980.82 - 4,803.23 2,682.83 6,011,350.42 571,955.27 12.00 5,333.93 90.3. 8 9,900.00 90.72 165.79 6,980.45 - 4,832.51 2,689.28 6,011,321.20 571,961.98 12.00 5,363.89 -90.00 10,000.00 90.69 153.79 6,979.21 - 4,926.18 2,723.76 6,011,227.87 571,997.33 12.00 5,463.28 -90.05 10,070.00 90.66 145.39 6,978.38 - 4,986.49 2,759.16 6,011,167.89 572,033.29 12.00 5,530.70 -90.19 9 10,100.00 90.71 148.99 6,978.03 - 5,011.70 2,775.41 6,011,142.84 572,049.77 12.00 5,559.26 89.20 10,200.00 90.85 160.99 6,976.66 - 5,102.14 2,817.61 6,011,052.80 572,092.81 12.00 5,657.54 89.24 10,300.00 90.95 172.99 6,975.09 - 5,199.39 2,840.08 6,010,955.78 572,116.18 12.00 5,757.29 89.41 10,320.00 90.97 175.39 6,974.75 - 5,219.28 2,842.11 6,010,935.90 572,118.39 12.00 5,777.03 89.60 10 10,400.00 90.96 165.79 6,973.40 - 5,298.10 2,855.17 6,010,857.22 572,132.18 12.00 5,856.54 -90.00 10,445.00 90.94 160.39 6,972.66 - 5,341.13 2,868.26 6,010,814.31 572,145.67 12.00 5,901.50 -90.16 11 10,500.00 90.93 166.99 6,971.76 - 5,393.88 2,883.69 6,010,761.71 572,161.59 12.00 5,956.44 90.00 10,600.00 90.89 178.99 6,970.17 - 5,492.94 2,895.88 6,010,662.78 572,174.69 12.00 6,055.28 90.1 10,615.00 - 90.88 180.79 6,969.94 , - 5,507.94 2,895.91 6,010,647.79 572,174.86 12.00 6,069.77 90.3 TD at 10615.00- 23/8" 10/26/2009 9 :21 :55AM Page 4 COMPASS 2003.16 Build 71 r M ra sioT,veNo sz in s° WELLBORE DETAILS: Plan 5, MPE -14A REFERENCE NFC9MATION 1111111 Project: Milne Point o,m Site: M PIE Pad MagneocFeld Parent Wellbore: MPE - Coadnate(NIE)Rek�ee: WeNMPE- 14- Sb114,TreeNoM BAKER Well MPE -14 Slang 11 5/6626sn1 Ikr aI(ND)Rekrence: MeanSeaLevd Tie on MD: 8861.09 Wellbore: Plan 5, MPE - 14A opn�leeoes° SecmnNS)Relerence: Sbl- 14(O.o0N,0.00E) UGH 0 bp ModABGGM P lan: Plan S ( MPE- 14JP Ian 5, MPE -14A) °a re 1 MeasuredCepERekrence MPE- 14wm @57.701t(MPE -14RB) Cat:u6GonMelhod, Mm;nuoCurvature INTEQ • -3600 , WELL DETAILS: MPE -14 3750 Ground Level: 0.00 ON / -S +EI -W Northing Easting La6ltude Longitude Slot ' 3900 000 000 6016128.06 569228.18 70° 27' 15.912 N 149° 26' 6.261 W 14 SECiIONDETAILS ANNOTATIONS 'It KOP - --. 'E - 14 Sec MD Inc Azi ssTVD +WS +E/ -W DLeg TFace VSec Target Annotation -4200 1 8861.09 31.54 133.24 6804.81 - 4100.29 2106.85 0.00 0.00 4505.87 TIP Endof9Deg/1 "DL :1.2 8950.00 31.26 134.43 6880.70 -4132.37 2140.27 0.77 114.81 4545.50 KOP 4 96.07 90.00 134.43 6985 -4252.63 2162.97 9.80 0.00 493.4 Endof2 8 Deg /DLS - 4 911611.07 90.00 134.43 6985.0,01 1 X252.63 2262.94 29.80 0.00 46693.41 1 Endof29.SODegr100DLS a -a 5N _ 5 9270.00 90.00 121.36 6985.01 - 4319.39 2348.71 12.00 270.00 4780.10 5 6 9520.00 90.00 151.36 6985.01 -0498.24 2519.29 12.00 90.00 4997.01 6 h cb I■ 7 9620.00 90.83 139.39 698428 -4580.38 2576.00 12.00 274.00 5091.02 7 ;- -4650 , � , 8 9870.00 90.72 169.39 6980.82 -4803.23 2682.83 12.00 90.00 5333.93 8 9 10070.00 90.66 145.39 6978.38 -4986.49 2759.16 12.00 270.00 5530.70 9 + 10 10320.00 90.97 175.39 6974.75 - 521928 2842.11 12.00 89.20 5777.03 10 ' - 4800 11 10445.00 90.94 160.39 6972.66 - 5341.13 2868.26 12.00 270.00 5901.50 11 p 12 10615.00 90.88 180.79 6969.94 - 5507.94 2895.91 12.00 9900 6069.78 TD at 10615.00 - 4950 .'S -5100 O En -5250. ' i14AT,:t2 54x1 -5711 ■.■■r Rum - 585 , --r'. .- .... .. ... .. .. .. .... - 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 4050 4200 West( - )/East( +) (150 ft/in) 6655 • 6711. II ■ • 6821 11P 6875 -11 KOP - /,. rg' A1PE -1 Tat 2 a' 6931 A - End of9Deg/l00'DLS - • ' ar5e I - TD 0 10615.00 �y 6985 ,: U E 7 3 9 10 II y 7041 t PE-I I /Plan 5, MPE -i 4A ' „ End 1f29.80 Deg/I)0' DLi a 7095 F - 7151 ■,. 7205 Mean Sea ,.,m ■� 4/MPE 14 IIIII- - 4180 4235 4290 4345 4400 4455 4510 4565 4620 4675 4730 4785 4840 4895 4950 5005 5060 5115 5170 5225 5280 5335 5390 5445 5500 5555 5610 5665 5720 5775 5830 5885 5940 5995 6050 6105 6160 6215 6270 6325 Vertical Section at 165.00° (55 ft/in) Rau • BPPASSPORT • Travelling Cylinder Report bP LNTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPE -14 - Slot 14 Project: Milne Point TVD Reference: Mean Sea Level Reference Site: M Pt E Pad MD Reference: MPE -14 RKB @ 57.70ft (MPE- 14RKB) Site Error: 0.00ft North Reference: True Reference Well: MPE -14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Weiibore Plan 5, MPE -14A Database: EDM .16 - Anc Prod - WH24P . Reference Design: Plan 5 Offset ND Reference: Offset Datum Reference Plan 5 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,861.09 to 10,615.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,258.16ft Error Surface: Elliptical Conic Survey Toot Program Date 10/26/2009 From To (ft) (ft) Survey (Welibore) Tool Name Description 212.69 8,861.09 1 : MWD - Standard (MPE -14) MWD MWD - Standard 8,861.09 10,615.00 Plan 5 (Plan 5, MPE -14A) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 10,615.00 6,969.91 2 3/8" 2.375 3.000 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Welibore - Design (ft) (ft) (ft) (ft) M Pt E Pad Jet - Plan Jet - Jet wp04 Out of range MPE-05 - MPE-05 - MPE -05 Out of range MPE -09 - MPE -09 - MPE -09 Out of range MPE -090H - MPE -090H - MPE -090H Out of range MPE -10 - MPE -10 - MPE -10 Out of range MPE -11 - MPE -11 - MPE -11 Out of range MPE -14 - MPE -14 - MPE -14 8,950.00 8,950.00 0.00 5.42 -2.46 FAIL - Major Risk MPE -17 - MPE -17 - MPE -17 Out of range MPE -22 - MPE -22 - MPE -22 Out of range MPE -23 - MPE -23 - MPE -23 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/26/2009 10 :58 :46AM Page 2 of 4 COMPASS 2003.16 Build 71 • . All Measurements are from top of Riser 10/26/2009 i (n CC MPE -14A for D shale drilling 4 -1/8" OH top of bag C BAG bttm of bag middle of blind /shear Blind /Shears I TOTs middle of pipes /slip I 3 slips I I Mud Cross Mud Cross middle of flow cross [ I I I middle of pipe /slip variable bore pipe 3 1/2 " -2 3/8" I I TOTs middle of pipe /slips I 2" pipe /slips • I I Swab Valve I I Flow Tee 1 • i All Measurements are from top of Riser 10/26/2009 i a) u) CC MPE -14A for B lateral drilling 3" OH top of bag t BAG bttm of bag 1 middle of blind /shear Blind /Shears TOTs I 2-3/8" combi ram /slips middle of pipes /slip Mud Cross middle of flow cross Mud Cross I I middle of pipe /slip variable bore pipe 3 1/2 " -2 3/8" I I TOTs middle of pipe /slips I 2" pipe /slips I Swab Valve I Flow Tee Page 1 of 2 • • Schwartz, Guy L (DOA) From: McLaughlin, Sean M [Sean.McLaughlin @ bp.com] Sent: Friday, October 30, 2009 10:24 AM To: Schwartz, Guy L (DOA) Subject: RE: MP E -14A CTD S/T (PTD 209 -128) I agree a SSSV would be nice. We kicked that around a bit and figured the carrot wasn't all that big for us. There were two reasons we didn't go that route. 1) We wanted the workstring and decomplete the be as simple as possible. 2) The bp and slb procedures are such that they don't recognize the SSSV as a barrier and we would have to kill the well anyways or get and exemption from a VP. I know CoP is running SSSV's for their wells and it is working out well for them but our well control policies are a bit tighter. The last year we drilled for them it was a point of contention. One more thing that factored in. The overpressure in the D has been primarily on the west side (F and L pad) so we really don't expect it to be a problem on E pad but will be watching for it. sean From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, October 30, 2009 9:41 AM To: McLaughlin, Sean M Subject: RE: MP E -14A CTD S/T (PTD 209 -128) Sean, One more question... with the uncertainty of BHP in the D shale why not run a SSSV in the workstring to facilitate the liner running ? ?? Seems like a better option than stripping in or bumping up mud weight. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Friday, October 30, 2009 9:28 AM To: Schwartz, Guy L (DOA) Cc: Bjork, David (Northern Solutions) Subject: RE: MP E -14 P & A Guy, No problem we will test the CIBP to 2000 psi. Regards, sean From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, October 30, 2009 8:56 AM To: McLaughlin, Sean M Subject: MP E -14 P & A Sean, 10/30/2009 Page 2 of 2 • • I have a question about the P & A procedure. Step 5 in the procedure calls for only testing the CIBP to 1000 psi. Are there casing integrity concerns ? Regulations call for a PT of .25 psi/TVD ft. Give me a call to discuss when you can. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 10/30/2009 • • TRANSMITTAL LETTER CHECKLIST WELL NAME 7 ? ► �'� `V,' PTD# / Z 6 t� Development Service Exploratory Stratigraphic Test Non - Conventional Well � " / ��'i� te e)( FIELD: 4 l % -i.t', C�:�t 1 POOL: - 'r.-c c_ � f Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ■ `' Field & Pool . .y z - __ - _ __ ___ —_ —_ __ _ _ Well Name: MILNE PT -UNIT KR E -14A Program DEV Well bore seg ❑ PTD #:2091280 Company BP EXPLORATION _(ALASKA) INC _ Initial Class/Type DEV / PEND GeoArea 890 Unit 11328 -- On /Off Shore On Annular Disposal ❑ Administration 11 Permit fee attached NA 2 Lease number appropriate Yes Top productive interval and TD in AD � 1/- -/-.L,7 3 Unique well name and number Yes 14 Well located in a defined pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 1 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 432C has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 432C has no interwell spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included Yes an external property line where ownership or landownership changes. 1 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 10/29/2009 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA • 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre - production Tess than 3 months (For service well only) NA 117 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided NA Conductor set in E -14 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in E -14 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in E -14 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in E -14 22 CMT will cover all known productive horizons Yes 2 3/8" liner to be cemented and perfed 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits 125 If a re-drill, has a 10 -403 for abandonment been approved Yes 309 -362 Sundry 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Closest well is P & A portion of E -14 1 27 If diverter required, does it meet regulations NA Wellhead and BOP are in place. Appr Date 128 Drilling fluid program schematic & equip list adequate Yes KWF = 8.5 ppg Drill with 8.8 ppg using MPD. D shale may be overpressure 13 ppg GLS 10/30/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2400 psi .. Will test BOP to 3500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes • 32 Work will occur without operation shutdown No Well will be drilled with Nordic 2 CTD... WO rig will pull wrk string and run ESP 33 Is presence of H2S gas probable Yes H2S present on MP E pad. Rig has sensors and alarms. i3 4 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No H2S is present in MPU E -14. Standard measures required. 1 Geology 1 36 Data presented on potential overpressure zones Yes Reservoir pressure expected to be 8.5 ppg EMW, but overlying Kup D shale may be over - Appr Date X 37 Seismic analysis of shallow gas zones NA pressured to 13.0 ppg. Mamaged pressure drilling techniques will be employed. SFD 10/29/2009 138 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering P • is Commissioner: Date: Commissioner: Date Com W .7. , : Date ', / /�-c�;; ie/ `l-o?-Uf • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infor nation. • tapescan.txt * ** REEL HEADER * * ** MWD 10/03/23 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 09/12/15 2915301 01 3" CTK * ** LIS COMMENT RECORD * ** 1111111 111111111111 Remark File Version 1.000 1 11 111 1111111111111 Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 8936.5000: Starting Depth STOP.FT 9170.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPE- 14APB1 FLD . FIELD: Milne Point Unit LOC . LOCATION: 70 deg 27' 15.912 "N 148 deg 26' 6.261 "w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 15 Dec 2009 API . API NUMBER: 500292273470 Parameter Information Block #MNEM.UNIT Value Description SECT. 25 Section TOWN.N T13N Township RANG. R1OE Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 57.70 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 57.70 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 '` � a . 9 -/a l9 e-/9 5 • tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths ( TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to 109 this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log from from well MPE -14A above the Kick Off Point of 9073 ft MD dated 22 Dec 2009 per Katie Nitzberg with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from MPE -14 through a milled window in a 7 inch liner. Top of window 8952 ft.MD (6882.8 ft.TVDSS) Bottom of window 8959.5 ft.MD (6888.8 ft.TVDSS) (9) Tied to MPE -14 at 8861 feet MD (6804.8 feet TVDSS). (10) Baker Hughes INTEQ run 1 was a drift run. No logging data collected. (11) The interval from 9141 ft to 9170 ft MD (6985.5 ft. to 6994.3 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP.AVG -> Rate of Penetration, feet /hour RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACLX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 8939.69, 8938.97, ! - 0.717773 8941.48, 8940.76, ! - 0.717773 8943.09, 8942.56, ! - 0.538086 8946.32, 8946.32, ! 0 8951.89, 8951.17, ! - 0.717773 8956.37, 8955.83, ! - 0.538086 8959.42, 8959.06, ! - 0.358398 8960.86, 8960.68, ! - 0.179688 8962.11, 8962.11, ! 0 8966.24, 8965.88, ! - 0.358398 8971.98, 8971.62, ! - 0.359375 8976.64, 8976.64, ! 0 8984.18, 8984.18, ! 0 8990.28, 8990.28, ! 0 8994.76, 8994.58, ! - 0.179688 8997.28, 8997.1, ! - 0.179688 9001.94, 9001.58, ! - 0.358398 9006.07, 9005.89, ! - 0.178711 9007.32, 9007.14, ! - 0.178711 9009.47, 9009.29, ! - 0.179688 9012.34, 9012.34, ! 0 9014.86, 9014.5, ! - 0.358398 9021.89, 9021.89, ! 0 Page 2 • tapescan.txt 9030.5, 9030.15, ! - 0.358398 9037.68, 9037.68, ! 0 9041.27, 9041.45, ! 0.179688 9043.6, 9043.24, ! - 0.358398 9047.01, 9047.19, ! 0.178711 9050.96, 9050.96, ! 0 9055.79, 9055.79, ! 0 9058.3, 9058.12, ! - 0.179688 9059.92, 9060.1, ! 0.178711 9063.15, 9062.61, ! - 0.538086 9065.84, 9065.66, ! - 0.179688 9069.25, 9069.25, ! 0 9071.58, 9071.4, ! - 0.179688 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 111 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 * ** LIS COMMENT RECORD * ** 11 Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log from well MPE -14A above the Kick Off Point of 9073 ft MD dated 22 Dec 2009 per Katie Nitzberg with BP Exploration (Alaska), In * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 one depth per frame (value= 0) Datum Specification Block Sub -type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Page 3 tapescan.txt Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 8 Total Data Records: 6 Tape File Start Depth = 8936.500000 Tape File End Depth = 9170.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 2 15 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD * ** 11111 IIIIIIIIIIII! Remark File Version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) p p C specification Block Sub-type Datum specs yp a is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 Page 4 . • tapescan.txt 8 Total Data Records: 12 Tape File Start Depth = 8937.000000 Tape File End Depth = 9170.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 3 21 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 09/12/15 2915301 01 * * ** REEL TRAILER * * ** MWD 10/03/23 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP 8936.5000 - 999.2500 - 999.2500 8937.0000 - 999.2500 - 999.2500 9000.0000 149.2450 19.5715 9100.0000 71.9844 65.9000 9170.0000 - 999.2500 32.1000 Page 5 410 410 tapescan.txt Tape File Start Depth = 8936.500000 Tape File End Depth = 9170.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP 8937.0000 - 999.2500 - 999.2500 8937.2500 - 999.2500 - 999.2500 9000.0000 145.8000 20.7000 9100.0000 67.6000 65.9000 9170.0000 - 999.2500 32.1000 Tape File Start Depth = 8937.000000 Tape File End Depth = 9170.000000 Tape File Level spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS Page 6 ^ • • tapescan.txt * * ** REEL HEADER * * ** MWD 10/03/19 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 09/12/22 2915301 01 3" CTK * ** LIS COMMENT RECORD * ** I1111liii! Remark File version 1.000 IIIIIIIII Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 8544.5000: Starting Depth STOP.FT 10194.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPE -14A FLD . FIELD: Milne Point Unit LOC . LOCATION: 70 deg 27' 15.912 "N 148 deg 26' 6.261 "w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 22 Dec 2009 API . API NUMBER: 500292273401 -Parameter Information Block #MNEM.UNIT Value Description SECT. 25 Section TOWN.N T13N Township RANG. R1OE Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 57.70 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 57.70 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 90°1 - to 75 /9,-(t9 • • tapescan.txt CASE.F N/A Casing Depth 051 . DIRECTIONAL Other Services Line 1 —Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log from Schlumberger GR CSG above the Kick off Point of 8957 ft MD dated 16 Apr 1997. The MWD data is the PDCL for well MPE -14A per Katie Nitzberg with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from MPE -12 through a milled window in a 7 inch liner. Top of window 8952.5 ft.MD (6882.8 ft.TVDSS) Bottom of window 8959.5 ft.MD (6888.8 ft.TVDSS) (9) Tied to MPE -14 at 8861.1 feet MD (6804.8 feet TVDSS). (10) Baker Hughes INTEQ run 1 was a drift run. No logging data collected. (11) Baker Hughes INTEQ runs 2 and 3 were used to drill MPE- 14APB1 and set a 3 3/16 inch liner. (12) An openhole sidetrack was drilled off of MPE- 14APB1 at 9073 ft MD (6961.8 ft TVDSS). (13) The interval from 10154 ft to 10194 ft MD (6963.5 ft. to 6981.5 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP AVG -> Rate of Penetration, feet /hour RPCLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 8547.35, 8546.82, ! - 0.538086 8553.81, 8553.27, ! - 0.538086 8560.63, 8559.91, ! - 0.717773 8562.07, 8561.35, ! - 0.717773 8564.58, 8562.78, ! - 1.79395 8569.06, 8567.81, ! - 1.25586 8571.93, 8570.68, ! - 1.25586 8581.8, 8580.9, ! - 0.897461 8584.67, 8583.06, ! - 1.61426 8594, 8592.92, ! - 1.07617 8600.1, 8597.77, ! - 2.33203 8603.33, 8602.25, ! - 1.07617 8607.81, 8606.02, ! - 1.79395 8612.11, 8610.68, ! - 1.43555 8618.39, 8617.67, ! - 0.716797 8624.67, 8623.41, ! - 1.25586 8629.33, 8628.26, ! - 1.07715 8637.05, 8635.79, ! - 1.25586 Page 2 • • tapescan.txt 8643.87, 8644.05, ! 0.179688 8658.94, 8657.86, ! - 1.07617 8666.29, 8665.04, ! - 1.25586 8667.91, 8666.65, ! - 1.25586 8685.43, 8684.18, ! - 1.25586 8691.89, 8691.35, ! - 0.538086 8697.63, 8696.2, ! - 1.43555 8703.91, 8704.27, ! 0.358398 8709.29, 8708.22, ! - 1.07617 8716.29, 8715.93, ! - 0.359375 8732.7, 8731.98, ! - 0.716797 8735.39, 8735.03, ! - 0.358398 8742.92, 8742.03, ! - 0.897461 8745.43, 8744.36, ! - 1.07617 8748.12, 8747.41, ! - 0.716797 8767.23, 8765.79, ! - 1.43555 8773.87, 8771.89, ! - 1.97363 8777.28, 8776.02, ! - 1.25586 8793.06, 8792.52, ! - 0.538086 8794.94, 8794.4, ! - 0.538086 8802.84, 8802.3, ! - 0.538086 8808.76, 8807.86, ! - 0.896484 8810.37, 8810.19, ! - 0.178711 8817.05, 8815.97, ! - 1.07617 8821.71, 8820.46, ! - 1.25586 8822.79, 8822.25, ! - 0.538086 8834.45, 8834.45, ! 0 8838.22, 8838.4, ! 0.179688 8842.34, 8841.63, ! - 0.717773 8938.98, 8938.44, ! - 0.538086 8941.85, 8941.13, ! - 0.717773 8946.33, 8946.33, ! 0 8951.89, 8950.82, ! - 1.07617 8953.33, 8953.15, . - 0.179688 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 132 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 °** LIS COMMENT RECORD * ** Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log from Schlumberger GR CSG above the Kick off Point of 8957 ft MD dated 16 Apr 1997. The MWD data is the PDCL for well MPE -14A Page 3 • • tapescan.txt per Katie Nitzberg with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 92 Tape File Start Depth = 8544.500000 Tape File End Depth = 10194.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet * * ** FILE TRAILER * * ** Tape Subfile: 2 105 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 I * ** LIS COMMENT RECORD * ** 11111111111 ,111111 Remark File Version 1.000 Page 4 • • tapescan.txt This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 184 Tape File Start Depth = 8544.750000 Tape File End Depth = 10194.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 3 197 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 09/12/22 2915301 01 * * ** REEL TRAILER * * ** Page 5 • • tapescan.txt MWD 10/03/19 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8544.5000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8545.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8600.0000 86.6791 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8700.0000 75.5907 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8800.0000 66.6279 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8900.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9000.0000 147.5281 20.0172 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9100.0000 67.4828 71.4969 5.0441 5.0542 5.1820 5.6456 9200.0000 25.9141 63.7531 12.1870 14.1424 14.2591 15.8199 9300.0000 48.5641 85.7047 12.3596 12.0759 13.5117 15.2667 9400.0000 61.2000 85.7437 15.6250 15.0008 14.3590 14.3460 9500.0000 60.7016 88.8594 13.2183 13.7034 16.4570 20.4668 9600.0000 62.4953 129.3750 8.9156 9.0559 Page 6 f • • • tapescan.txt 9.6339 10.2163 9700.0000 60.0016 73.6266 14.7766 18.9631 17.6910 18.8320 9800.0000 63.0609 34.2312 15.6429 18.1087 15.7256 15.3997 9900.0000 61.7719 61.8031 15.4304 23.9020 25.6619 31.5944 10000.0000 96.6156 9.1172 9.2674 7.7639 7.6882 7.1550 10100.0000 117.3844 54.7344 4.8304 4.7297 4.6110 4.6440 10194.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 8544.500000 Tape File End Depth = 10194.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8544.7500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8545.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8600.0000 85.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8700.0000 75.7000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8800.0000 67.5000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8900.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9000.0000 145.3000 20.7000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9100.0000 66.8000 72.0000 5.0560 5.0830 5.1960 5.6560 9200.0000 24.8000 62.1000 12.1870 14.1510 14.2030 15.7520 9300.0000 48.6000 81.5000 12.3330 12.0080 13.4600 15.2020 9400.0000 61.2000 85.6000 15.5650 14.9350 14.3590 14.3460 Page 7 . • • tapescan.txt 9500.0000 61.6000 88.5000 13.1770 13.6560 16.4570 20.5660 9600.0000 62.1000 133.4000 8.8980 9.0020 9.5710 10.1060 9700.0000 60.9000 72.8000 14.6440 18.8880 17.6910 18.7440 9800.0000 61.3000 33.8000 15.7320 18.3250 15.5290 15.2020 9900.0000 61.7000 68.2000 15.4570 23.9440 25.6260 31.4000 10000.0000 96.4000 5.2000 9.2530 7.7840 7.7220 7.2100 10100.0000 117.6000 53.8000 4.8340 4.7290 4.6110 4.6440 10194.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 8544.750000 Tape File End Depth = 10194.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS Page 8