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208-186
Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: kyle.wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 02/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-96 -PTD 208-186 -API 50-029-23406-00-00 Definitive Directional Survey (Gyro + MWD Composited) Gyrodata Survey 02/21/2023 MWD 01/26/2013 Main Folder Contents: Please include current contact information if different from above. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Change-out Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,915 feet N/A feet true vertical 7,140 feet N/A feet Effective Depth measured 13,858 feet feet true vertical 7,084 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 8rd EUE 11,995' 5,521' Packers and SSSV (type, measured and true vertical depth)N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 6,637' 5,210psi 6,890psi 2,470psi 4,790psi TVD Surface Production 8,644' 13,410' 10-3/4" 7-5/8" 8,644' 13,410' 4,338' N/A 13,209' 6,437' ZXP Liner Top Pkr WTRSP WAG 0 Water-Bbl MD 122' 13,914' 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 3500 122' Oil-Bbl measured true vertical Packer Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 352 Size 380 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-186 50-029-234060-00-00 Plugs ADL0025509 / ADL0355018 / ADL0388235 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-085 383 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 7,139' MILNE PT UNIT F-96 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 365 Gas-Mcf 540 Casing Pressure Tubing Pressure 27 N/A 2. Operator Name Casing Conductor Length 122' 705'Liner 20" 5-1/2" Senior Engineer: Senior Res. Engineer: Collapse 520psi 6,390psi Burst 1,530psi 7,740psi 777-8333 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 8:04 am, May 04, 2021 Chad Helgeson (1517) 2021.05.03 16:05:38 - 08'00' DSR-5/4/21 RBDMS HEW 5/5/2021 23406 SFD 5/4/2021 SFD 5/4/2021 MGR30JUL2021 _____________________________________________________________________________________ Revised By: DH 4/29/2021 SCHEMATIC Milne Point Unit Well: MP F-96 Last Completed: 4/14/21 PTD: 208-186 TD =13,915’ (MD) / TD = 7,140’(TVD) 20” Orig.KBE to MSL= 38.3’ (Nabors 7ES) 7-5/8” 7 6 3 9 10 10-3/4” 1 2 Min ID= 2.250” @ 11,916’ Kuparuk ‘A’ Sands PBTD =13,872’(MD) / PBTD =7,097’(TVD) 5-1/2” 4 5 12 11 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A 19.124 Surface 122’ 0.355 10-3/4" Surface 45.5 / L-80 / Btc. 9.950 Surface 8,644’ 0.0962 7-5/8” Production 29.7 / L-80 / IBT-M 6.875 Surface 13,410’ 0.0459 5-1/2” Liner 17/ L-80 / BTC-M 4.892 13,209’ 13,914’ 0.0233 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441” Surface 11,995’ 0.0058 3/8” Capstring Stainless Steel N/A Surface 11,995’ N/A JEWELRY DETAIL No Depth Item 1 193’ 2-7/8” x 1” GLM 2 w/DSOV 2 11,831’ 2-7/8” x 1”GLM 1 w/dummy valve 3 11,889’ XN-Nipple w/ 2.313 Profile – 2.250 No Go 4 11,941’ Discharge Head 5 11,942’ Pump #1 6 11,964’ Gas Separator 7 11,969’ Upper Tandem Seal 8 11,976’ Lower Tandem Seal 9 11,982’ Motor, 562XP 10 11,991 Motor Gauge 11 11,993’ 4 fin Centralizer – Bottom: 11,995’ 12 13,209’ BOT Flex Lock Liner Hanger & ZXP Liner Top Pkr w/ 4.75” ID PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Status A3 Sands 13,672’ 13,682’ 6,898’ 6,908’ 10 3/7/2009 Open A2 Sands 13,688’ 13,696’ 6,914’ 6,922’ 8 3/7/2009 Open A1 Sands 13,708’ 13,740’ 6,934’ 6,966’ 32 3/7/2009 Open OPEN HOLE / CEMENT DETAIL 20" 43 bbls of Arcticset I in 42” Hole 10-3/4" 843 bbls AS Lite, 174 bbls Class ‘G’ in a 13-1/2” Hole 7-5/8” 72 bbls Class ‘G’ in a 9-7/8” Hole 5-1/2” 23 bbls Class ‘G’ in a 6-3/4” Hole WELL INCLINATION DETAIL KOP @ 200’ Max Hole Angle = 71.4 deg. @ 3,150’ Hole Angle +66 Deg. From 2,600’ to 12,050’ TREE & WELLHEAD Tree 2-9/16” 5K Wellhead FMC MONO 11” x 11” 5K GENERAL WELL INFO API: 50-029-23406-00-00 Drilled and Completed by D-14 & N-7ES - 2/27/2009 ESP Completion by Nabors 3S – 4/9/2009 ESP RWO by Nabors 4ES – 9/10/2009 ESP RWO/ install screen & cup Pkr by N-4ES – 9/29/2009 ESP RWO install diverter valve by Nabors 4ES – 1/14/2010 ESP RWO FCO & move ESP up hole by D-16 – 4/6/2011 Convert to TTC-ESP by Doyon 19 – 6/28/2012 Set new PSP TTC-ESP C/O slickline 1.6 wire – 6/17/2014 ESP RWO by Nordic #3 – 11/28/2015 ESP RWO by ASR – 4/14/2021 STIMULATION DETAIL 3/11/2009 – Frac 106,880lbs of 16/20 Carbolite 60,880lbs behind pipe 3/11/2009 – Frac Well Name Rig API Number Well Permit Number Start Date End Date MP F-96 ASR 208-186 50-029-23406-00-00 4/7/2021 4/14/2021 4/7/2021 Hilcorp Alaska, LLC Weekly Operations Summary Pre Rig Pad Inspection with Pad Op. Prep location, hauling and staging equipment from L-07. Spotted mud boat, began crane ops fly on well house. Found BPV leaking and pressure on tubing and IA. Bleed pressure off tubing and IA. Install lubricator and pull BPV. Inspect and find heavy grease in BPV. Install new BPV. ND tree inspected lifting threads and tested void. Fly on and NU BOP's and rig floor. Spotted pits and set stairs. Laid out BOP control lines. RDMO crane. Spotted pusher shack and camps. Spotted ASR, raised mast and secured rack pins. Organized rig floor. Set stairs and hooked up kill/choke lines. Spotted in rig pump and conex's. Hooked up circulating lines. Spotted in glycol unit and began winterizing lines and equipment. Final torque up on stack. Connect Koomey lines. Spot and rig up flow back tank. Winterizing and warming rig. Load 40 bbls fresh water. 4/8/2021 PJSM, reviewed sundry with crew. Continued rigging up, winterizing equipment and spotting heathers on cold spots as needed. Set containment, spot catwalk and pipe racks. Moved camps to make room for spooler unit to RU. NU 6" flow spool and flowline. Hung cable sheave. SI/IA=80psi. Bleed off to flowback tank all gas. Crew eat lunch while equipment is warming. PU BOP testing equipment. Flooded stack with fresh water and circulated air out of system. Performed shell test 250/2500psi. Tested BOPE per sundry as following: Annular 250-2500psi, Rams 250-2500psi, Valves 150-2500psi. Tested Fire & Gas and Performed the Koomey drawdown. 2-7/8" Test used. No failures recorded. Witness waived by Lou Laubenstein on Wednesday, April 7, 2021 6:31 PM. Clean and clear rig floor. LD test joint. Prep to pull BPV. Attempt to pull BPV. Open poppet and find pressure under BPV. Pressure will not bleed off. Consult with Operations Engineer and discuss plan forward. Agree to pump tubing volume with source water while talking returns from IA. Reduce rate on supporting injector F-84 from 1800 bpd to 350 bpd. Pump 75 bbls 8.3ppg source water @ 1.2 bpm @ 2500psi. 1/1 returns. Shut down and monitor tubing and IA pressure. 0 psi on tubing. Pull BPV. MU landing joint. BOLDS. Pull tubing hanger to floor with 110k PUW. Disconnect cap string and ESP cable and prepare to spool. POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. Fill hole with source water and BaraKlean. Top drive Link-Tilt will not extend. Begin troubleshooting. Bleed hydraulic lines and link tilt is extending. Cont POOH. POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. Fill hole with source water and BaraKlean. Pull f/12011' t/9206',POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. Fill hole with source water and BaraKlean. Pull f/9206' t/8,771'. Total 100 jts LD. Joint 96,97,98 started seeing scale inside the pipe. Well Name Rig API Number Well Permit Number Start Date End Date MP F-96 ASR 208-186 50-029-23406-00-00 4/7/2021 4/14/2021 Hilcorp Alaska, LLC Weekly Operations Summary PJSM. Continued POH with 2-7/8" ESP Completion to the discharge head. GLM, XN-nipple and last joint out full of sand and scale. LD ESP Assembly. Pump was frozen up with scale inside and outside. Seals and motor still has good oil inside. Bad scaling around the entire assembly. Cleaned cleared rig floor. RD the elephant trunk and whipped off containment. RDMO the spooling unit. Racked and tally first 80 joints. PU/MU Cleanout BHA. 4.75 Varel Bit, 4.13" Bit Sub, XO 2-7/8"IF x 2-7/8" EUE. RIH on 2-7/8" 6.5# EUE L-80 8rd tubing t/2,500'. First 80 joints ran are used and the rest of the string is new tbg. Moved out pipe racks, MIRU crane. Fly power swivel to rig floor. RDMO crane. RU power swivel and functioned. Tested kelly valve 250low/2500high and charted each test for 5 mins. Spotted pipe racks. Racked and tally row of tubing. Continue RIH with cleanout BHA. Fill hole with 6 bbls 8.33 ppg source water. RIH w/ Cleanout BHA. 4.75 Varel Bit, 4.13" Bit Sub, XO 2- 7/8"IF x 2-7/8" EUE. RIH on 2-7/8" 6.5# EUE L-80 8rd tubing t/5,900'. RIH = 12k. RIH w/ Cleanout BHA. 4.75 Varel Bit, 4.13" Bit Sub, XO 2-7/8"IF x 2-7/8" EUE. RIH on 2-7/8" 6.5# EUE L-80 8rd tubing t/8,600'. RIH = 13.5k,Cont RIH w/ Cleanout BHA. 4.75 Varel Bit, 4.13" Bit Sub, XO 2-7/8"IF x 2-7/8" EUE. RIH on 2-7/8" 6.5# EUE L-80 8rd tubing t/10,790'. RIH = 14.5k. Cont RIH w/ Cleanout BHA. 4.75 Varel Bit, 4.13" Bit Sub, XO 2-7/8"IF x 2-7/8" EUE. RIH on 2-7/8" 6.5# EUE L-80 8rd tubing t/11,100'. 4/10/2021 4/9/2021 PJSM, service rig. POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. PUW 50k. Filling pipe displacement with source water and BaraKlean. SD due to 300k gen. 330k generator ran out of fuel. Filled up the generator and could not get it to start. Call VMS and found a bad fuse. Replaced fuse and fired it up. POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. Filling pipe displacement with source water and BaraKlean. Pull f/8,250' t/6,000'. Total 191 joints L/D. PUW @ 8,200'=49k, PUW @ 7,400'=46k (Had 2-3k drag f/7,400' t/7,200' 2-4 deg dogleg build). PUW @ 6,000'=36k. Reel swap @ 6,000'. POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. Joint 195 tubing started pulling wet L/D 3 jts with the mud bucket and tbg remained wet with heavy scale. Cut cable and secured with 2 cross collar clamps. PU 1 joint and set in slips and closed pipe rams. Lined up to reverse circulate well taking returns to the flowback tank. Pressured up on IA to 1,500psi observed pressure break and obtained circulation up the tbg to the flowback tank at 1bpm/1400psi. Pressure started building and reduced rate to .75pbm/1,500psi and maintained. Circulated 35bbl bottoms up. SD pump. Rig down and blow circulating lines dry. Pulled and LD 1 joint and tubing in draining. Connected cable and cap-sting over to spool. POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. Troubleshoot link tilt function. Unable to extend link tilt. Bleed hoses/hydraulic pressure from tilt cylinders. Replace poppet insert cartridge valves and link tilt function is 100%. POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. ESP cable ruptured/blown out in several places. POOH with 2-7/8" 6.5" L-80 EUE tubing, ESP cable and cap string. Jt 365jts LD. Repair/replace failed hydraulic hose on power tongs. Well Name Rig API Number Well Permit Number Start Date End Date MP F-96 ASR 208-186 50-029-23406-00-00 4/7/2021 4/14/2021 Hilcorp Alaska, LLC Weekly Operations Summary PJSM. Discussed daily activities. Parameters: 3bpm/900si, PUW 60K, SOW 23K ROT PU 40k Torque 1800/RPM 60. KIH washing down w/2-3k down on bit f/13657' t/13687’ while reverse circulating at 3bpm/900 psi. Returns 1 for 1 across shaker screens mainly grey water with formation sand and scale. Sent 40 pill of NXS Lube to help fight pipe fiction. PU joint jt 446 with same parameters continued KIH washing down with 2-3k down on bit f/13687'. Rev circulating at 3bpm/900psi with full returns. At 13697' seeing communication with .75bpm losses to the formation while pumping 3bpm/650psi. Continued washing down t/13716'. 40bph losses. Grey water with formation sand across shakers. PU joint jt 447 and Kelly up. Started pumping and the swivel packing started leaking. Shut down the pump and inspected swivel. We will have to rig down the swivel to replace the packing (12hr repair with RD and RU time). Called town and discussed plan. With the well on losses decided to circulated bottoms up and TOOH and pick up the ESP Completion. LD 4 Joints t/13600 and made up TIW and Kelly hose. Reversed circulated 80bbls at 3.5bpm/700psi, returns clean at bottoms up and SD pump. Monitored well Tbg/IA on a Vacuum. Blew lines dry. POOH with 2-7/8" 6.5# L-80 EUE 8rd Tubing and cleanout BHA f/13600',Repair front hydraulic cylinder on cat walk. POOH with 2-7/8" 6.5# L-80 EUE 8rd Tubing and cleanout BHA f/7,330' PUW 30k. 4/11/2021 PJSM, Checked fluids and serviced rig as needed. Working on replacing the proximity sensors to read RMP and torque on the power swivel. Both sensors looked to have been damaged while rigging up the swivel. Tapped out and replaced sensors, could read torque but could not read RPM's. Decided to continue RIH to TOL @ 13,209'. Started to RIH with jt 361 and pipe displacing heavy oil and scale coming out of the tubing. SD, rig up to circulate well @ 11,100'md. Spotted in and rig up 500bbl pigging tank to handle to scale returns. Spotted two vac trucks loaded with source water. Hooked up lines from the IA to pigging tank. Circulated well vol from 11,085' pumping down tbg, returns up the IA. Circulated 533bbls of 8.3 SW @ 3.5-4pbm/1000psi. Returns 1 for 1. First 90bbls of returned was heavy crude and scale. Blew lines dry and prepared to RIH with work-string. Established PUW 47k and SOW 24k. PU joint 361 and RIH tagged 10k down @ 11,090'. Laid down 1 joint. RU and Kelly hose to swivel and lines to the return tank. Finish rigging up kelly hose. Establish power swivel parameters. 1500 lbf. Wash down single joint with 3 bpm @ 800 psi pump pressure. Annular closed with ~ 750psi. Light solids in returns noted near tubing volume bottoms up. Pump 100 bbls and returns clear up. Blow lines down and prepare to cont/RIH on elevators. RIH with joint 362 on elevators. RIH w/clean out BHA on elevators. Frequent PUW. Clean trip in hole with no set downs noted to jt 390, 12,000'. Kelly up and line up to reverse circulate. Circulate 120 bbls 3bpm@ 800 psi. Returns clean after 100 bbls. Cont RIH to jt 428, 13172'. No set downs noted. Kelly up and reverse circulate while rotating. Pump 100bbls @ 3 bpm and 800psi. Dark grey returns with fine solids @ btms up. PUW = 42k, SOW = 25k while pumping with bag closed. After a total of 160 bbls pumped, clean returns noted. Shut down and RIH to TOL. Did not see liner top. Cont RIH on elevators to tag. RIH on elevators to jt 444, 13657' and tag with 5k down. RIH = 23k, PUW = 60k. Kelly up and prepare to wash down through perf intervals. Begin washing down f/13657' with 3 bpm @ 950 psi. Returns dark gray and blinding off shaker screens. Take returns outside to pigging tank. 4/12/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP F-96 ASR 208-186 50-029-23406-00-00 4/7/2021 4/14/2021 Hilcorp Alaska, LLC Weekly Operations Summary 4/14/2021 PJSM. Centrilift make reel to reel splice. Filling hole 5 bph. RIH with ESP on 2-7/8 6.5# L-80 EUE 8rd tubing f/7500' t/hanger depth, spooling cable and 1/4" capstring. Testing cable every 2000'. Clamping the 15 joints the every other. Filling hole 5bph. PU/MU landing joint and tbg hanger with BPV installed. Cut cable and 1/4" chemical line. Make final splice to penetrator. MU 1/4" chemical injection line to hanger. Final cable checks. Landed completion with 29k down on hanger. RILDS. EOT @ 11,995.31'. End of well work. Start RDMO ASR. Rig down glycol unit, pump, catwalk. Rig down hoses from pump, pit, Koomey and all heater hoses. Swap out service hydraulic hose #41. Pull rack pins and jack knife derrick. Pull swivel with crane. Finish rigging down and drive rig to A-pad tent. RD floor. ND BOP. NU and test tree. Clean location and sign off on all permits and location condition reports. Begin A pad rig prep and maintenance for next campaign. PJSM.Continued POOH with2-7/8" EUE and cleanout BHA. SD due to 300k generator died. Called VMS to trouble shoot. Fan lubes were not opening and low voltage codes. Fired up generator and continued ops while mechanic monitored generator. POOH with2-7/8" EUE and cleanout BHA f/2400 t/rig floor. LD BHA. Filling double hole displacement @ 2.5bbls every 15 joints out. Clean and cleared rig floor and prepared to RIH with ESP. Staged ESP assembly, GLM's and XN-Nipple on catwalk. Hung cable sheave and RU Spooler. Pulled rope thru sheave from spooler to rig floor. Racked and tallied 200 joints of 2-7/8" EUE Tbg. PU/MU and serviced new Centrilift ESP assembly. Final surface checks good. RIH with ESP on 2-7/8 6.5# L-80 EUE 8rd tubing per tally t/4,700', spooling cable and 1/4" capstring. Testing cable at 1000' then every 2000' after. Clamping the 15 joints the every other. SOW 18k. RIH with ESP on 2-7/8 6.5# L-80 EUE 8rd tubing f/4700' t/7500, spooling cable and 1/4" capstring. Testing cable every 2000'. Clamping the 15 joints the every other. Make reel splice while filling hole at 5bph. 4/13/2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Change Out 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,915 N/A Casing Collapse Conductor 520 psi Surface 2,090 psi Production 4,790 psi Liner 6,390 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT F-96 C.O. 432D ZXP Liner Top Pkr and N/A 13,209'(MD) & 6,437'(TVD) and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 13,914' Authorized Signature: 3/18/2021 2-7/8" Perforation Depth MD (ft): See Schematic See Schematic 122 20" 10-3/4" 7-5/8" 8,644' 5-1/2"705' 13,410' 3,580 psi 6,890 psi 4,338' 6,637' 7,136' 8,644' 13,410' 122' 122' 6.5# / L-80 / EUE 8rd TVD Burst 12,012' MD 1,530 psi 7,740 psi 50-029-23406-00-00 Hilcorp Alaska LLC Length Size 7,140 13,858 7,084 715 N/A MILNE POINT / KUPARUK RIVER OIL Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 / ADL0355018 / ADL0388235 208-186 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:39 pm, Feb 16, 2021 321-085 Chad Helgeson (1517) 2021.02.16 14:22:48 - 09'00' DSR-2/16/21DLB 02/16/2021 X BOPE test to 2500 psi. Annular to 2500 psi. 10-404 MGR16FEB21 1326 Comm. 2/17/21 dts 2/16/2021 JLC 2/16/2021 RBDMS HEW 2/25/2021 ESP RWO Well: MP F-96 2021 ESP Swap Well Name:MPU F-96 API Number:50-029-23406-00 Current Status:SI Producer (Failed ESP)Pad:F-Pad Estimated Start Date:March 18th , 2021 Rig:Doyon 14 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:208-186 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) AFE Number:Job Type:ESP RWO Current Bottom Hole Pressure: 1,100 psi @ 3,850’ TVD Estimated BHP (Fluid Level Shot)5.5 ppg EMW Maximum Expected BHP:1,100 psi @ 3,850’ TVD MPSP:715 psi (0.1 psi/ft gas gradient) Max Inclination:71° @ 9,763’ MD Horizontal @ 6,635’ MD Max Dogleg:5.71°/100’ @ 1,691’ TVD Brief Well Summary: Milne Point F-96 well was drilled as a Kuparuk development well that TD’d at 13,915’ in February 2009. The well was perforated and frac’d in the Kuparuk A sands and initially completed with an ESP in April 2009. This and subsequent ESPs failed and were replaced in July 2009, September 2009, October 2009, 2010, 2011 and 2015. During the 2015 completion the 4-1/2” TBG was replaced with 2-7/8” TBG and the 7-5/8” CSG was pressure tested to 2,000 psi. F-96 ESP failed 10/9/2020. Fluid level shot on 2-14-2021 had fluid level at 6,000’ MD with 500 psi on the IA, BHP estimated at 5.5 ppg EMW. Notes Regarding the Well & Design x 7-5/8” Casing MIT @ 13,120’ MD to 2,000 psig passed on 11/26/2015 x 3/8” Cap String Installed x Offset Injector Support o F-84 Objective: x Pull Failed ESP Completion with 3/8” Cap String (salvage Cap string) x Run new ESP Completion with 3/8” Cap String (re-install cap string) Pre-Workover Prep Procedure: 1. RD well house and flowlines. Clear and level area around well. 2. Set BPV Workover Procedure: 1. MIRU Doyon 14, ancillary equipment and lines to returns tank. 2. Pull the BPV. Bleed gas to 0 psi on the tubing and IA (if needed). 3. Circulate a minimum 450 bbls of seawater down the IA with the TBG open, then pump 70 BBLS down the TBG with the IA open. (NOTE: Circulation is not anticipated due to the low BHP, circulate clean fluids to clear TBG/IA of oil). 5.5 * 7136 * 0.052 = 2041 psi 2041- (0.1 * 7136) = 1326 psi 2041 psi @ 7,136' TVD 1326 psi ESP RWO Well: MP F-96 2021 ESP Swap 4. Monitor to confirm the well is dead for 30 minutes. If not, contact Operations Engineer and record SITP/SICP. 5. Set 2-1/2” HP BPV. 6. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. 7. NU 13-5/8” BOP stack with 2-7/8” x 5” VBR’s in the upper and lower ram cavities. 8. Test BOPE to 250/2,500 psi and annular to 250/2,500 psi. a. Notify the AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR’s and annular with 2-7/8” test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), AOGCC via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test if test witness was waived. 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. 9. RU to pull 2-7/8” ESP completion. 10. Pull plug off tool, check for pressure under the BPV, if needed kill the well with seawater and pull the BPV. 11. MU the landing joint to the tubing hanger, BOLDS, unseat the tubing hanger. 12. Pull the hanger to the rig floor. Lay down the landing joint and tubing hanger. RU to pull ESP cable and 3/8” chemical injection line over sheaves to spooling units. a. Inspect the tubing hanger and note any corrosion or damage. b. Plan to re-use chemical injection line, ensure to manage spooling the line as not to pinch the line. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 13. POOH the 2-7/8” tubing spooling ESP cable/chemical injection line and removing all jewelry as it presents itself. Lay down ESP components. a. Note any corrosion, sand, scale, damage or over torqued connections on the tubing with associated depths and ESP components on the morning report. Equipment Disposition Tubing hanger Visually inspect on site then reuse, restock or junk Tubing & Pup joints Visually inspect on site then reuse ESP RWO Well: MP F-96 2021 ESP Swap Gaslift Mandrels/Nipple Visually inspect on site then reuse ESP equipment/Power Cable Centerlift to take possession for inspection and teardown 3/8” Chemical Injection line Visually inspect on site then reuse Protectorlizer Visually inspect on site then reuse, restock Cannon clamps Visually inspect on site then reuse, restock Pump Clamps Visually inspect on site then reuse, restock Half Clamp Visually inspect on site then reuse, restock 14. RD ESP pulling equipment. 15. RU to run ESP completion. 16. PU and MU new Baker ESP assembly. Set base of ESP assembly at ±12,012’ MD. Check electrical integrity test every 1,000’. Install clamps on the first 15 joints then every other joint to surface. a. Motor centralizer b. Motor gauge unit c. ESP motor d. Lower tandem seal e. Upper tandem seal f. Gas separator g. Pump #1 h. Pump #2 i. Ported discharge head j. Bolt on discharge head with pup joint, 2-7/8”, 6.5#, L-80, EUE 8rd box up k. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing l. Nipple, 2.313” XN (2.205” no-go) with 10’ handling pups above and below m. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing n. GLM, 2-7/8” x 1”, DV installed with 10’ handling pups above and below (setting depth ±11,868’ MD) o. ~ 364 joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing p. GLM, 2-7/8” x 1”, DSOV installed with 10’ handling pups above and below (setting depth ±200’ MD) q. ~6 joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing 17. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator, MU the 3/8” Chemical injection line to the tubing hanger and dummy off any additional control line ports if present. 18. Land tubing hanger with extreme caution to avoid damaging the ESP cable, penetrator or 3/8” chemical injection line. RILDS. Record PU and SO weights on tally and WellEZ. 19. Set 2-1/2” HP BPV. 20. ND the BOP stack. Install the plug off tool. 21. NU the tubing head adapter and 2-9/16”, 5M tree. 22. PT tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 23. Pull plug off tool and BPV. 24. Replace gauge(s) if removed. Secure the tree and cellar. 25. RDMO ESP RWO Well: MP F-96 2021 ESP Swap Post-Rig Procedure: 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: TDF 2/16/2021 SCHEMATIC Milne Point Unit Well: MP F-96 Last Completed: 11/27/15 PTD: 208-186 TD =13,915’ (MD) / TD = 7,140’(TVD) 20” Orig.KBE to MSL= 38.3’ (Nabors 7ES) 7-5/8” 8 7 3 10 11 10-3/4” 1 2 Min ID= 2.250” @ 11,916’ Kuparuk ‘A’ Sands PBTD = 13,872’ (MD) / PBTD =7,097’(TVD) 5-1/2” 4 5 13 12 6 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A 19.124 0 122’ 0.355 10-3/4" Surface 45.5 / L-80 / Btc. 9.950 0 8,644’ 0.0962 7-5/8” Production 29.7 / L-80 / IBT-M 6.875 0 13,410’ 0.0459 5-1/2” Liner 17/ L-80 / BTC-M 4.892 13,209’ 13,914’ 0.0233 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441” 0 12,012’ 0.00579 3/8” Capstring Stainless Steel N/A Surface 12,012’ N/A JEWELRY DETAIL No Depth Item 1198’GLM w/ DSOV 2 11,868’ GLM w/ Dummy Valve 3 11,916’ XN-Nipple w/2.313 Profile – 2.250 No Go 4 11,927’ Discharge Head: FPDIS 5 11,928’ 1 st Pump: 134FLEX17.5 PMSXD 6 11,952’ 2 nd Pump: 134FLEX17.5 PMSXD 7 11,975’ Gas Separator: GRSFTX AR H6 8 11,980’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 11,987’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 10 11,994’ Motor: MSP-250 168HP / 2,295V / 45A 11 12,008 Sensor: Wellift 12 12,010’ 4 fin Centralizer – Bottom:12,012’ / 5,528’(TVD) 13 13,209’ BOT Flex Lock Liner Hanger & ZXP Liner Top Pkr w/ 4.75” ID PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Status A3 Sands 13,672’ 13,682’ 6,898’ 6,908’ 10 3/7/2009 Open A2 Sands 13,688’ 13,696’ 6,914’ 6,922’ 8 3/7/2009 Open A1 Sands 13,708’ 13,740’ 6,934’ 6,966’ 32 3/7/2009 Open OPEN HOLE / CEMENT DETAIL 20" 43 bbls of Arcticset I in 42” Hole 10-3/4" 843 bbls AS Lite, 174 bbls Class ‘G’ in a 13-1/2” Hole 7-5/8” 72 bbls Class ‘G’ in a 9-7/8” Hole 5-1/2” 23 bbls Class ‘G’ in a 6-3/4” Hole WELL INCLINATION DETAIL KOP @ 200’ Max Hole Angle = 71.4 deg. @ 3,150’ Hole Angle +66 Deg. From 2,600’ to 12,050’ TREE & WELLHEAD Tree 2-9/16” 5K Wellhead FMC MONO 11” x 11” 5K GENERAL WELL INFO API: 50-029-23406-00-00 Drilled and Completed by D-14 & N-7ES - 2/27/2009 ESP Completion by Nabors 3S – 4/9/2009 ESP RWO by Nabors 4ES – 9/10/2009 ESP RWO/ install screen & cup Pkr by N-4ES – 9/29/2009 ESP RWO install diverter valve by Nabors 4ES – 1/14/2010 ESP RWO FCO & move ESP up hole by D-16 – 4/6/2011 Convert to TTC-ESP by Doyon 19 – 6/28/2012 Set new PSP TTC-ESP C/O slickline 1.6 wire – 6/17/2014 ESP RWO by Nordic #3 – 11/28/2015 STIMULATION DETAIL 3/11/2009 – Frac 106,880lbs of 16/20 Carbolite 60,880lbs behind pipe _____________________________________________________________________________________ Revised By: TDF 2/16/2021 PROPOSED Milne Point Unit Well: MP F-96 Last Completed: 11/27/15 PTD: 208-186 TD =13,915’ (MD) / TD = 7,140’(TVD) 20” Orig.KBE to MSL= 38.3’ (Nabors 7ES) 7-5/8” 8 7 3 10 11 10-3/4” 1 2 Min ID= 2.250” @ 11,916’ Kuparuk ‘A’ Sands PBTD = 13,872’ (MD) / PBTD =7,097’(TVD) 5-1/2” 4 5 13 12 6 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A 19.124 Surface 122’ 0.355 10-3/4" Surface 45.5 / L-80 / Btc. 9.950 Surface 8,644’ 0.0962 7-5/8” Production 29.7 / L-80 / IBT-M 6.875 Surface 13,410’ 0.0459 5-1/2” Liner 17/ L-80 / BTC-M 4.892 13,209’ 13,914’ 0.0233 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441” Surface ±12,012’ 0.00579 3/8” Capstring Stainless Steel N/A Surface ±12,012’ N/A JEWELRY DETAIL No Depth Item 1 ±198’ GLM 2 2 ±11,868’ GLM 1 3 ±11,916’ XN-Nipple w/ 2.313 Profile – 2.250 No Go 4 ±11,927’ Discharge Head: 5 ±11,928’ 1st Pump: 6 ±11,952’ 2nd Pump: 7 ±11,975’ Gas Separator: 8 ±11,980’ Upper Tandem Seal: 9 ±11,987’ Lower Tandem Seal: 10 ±11,994’ Motor: 11 ±12,008 Sensor: 12 ±12,010’ 4 fin Centralizer – Bottom: ±12,012’ 13 13,209’ BOT Flex Lock Liner Hanger & ZXP Liner Top Pkr w/ 4.75” ID PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Status A3 Sands 13,672’ 13,682’ 6,898’ 6,908’ 10 3/7/2009 Open A2 Sands 13,688’ 13,696’ 6,914’ 6,922’ 8 3/7/2009 Open A1 Sands 13,708’ 13,740’ 6,934’ 6,966’ 32 3/7/2009 Open OPEN HOLE / CEMENT DETAIL 20" 43 bbls of Arcticset I in 42” Hole 10-3/4" 843 bbls AS Lite, 174 bbls Class ‘G’ in a 13-1/2” Hole 7-5/8” 72 bbls Class ‘G’ in a 9-7/8” Hole 5-1/2” 23 bbls Class ‘G’ in a 6-3/4” Hole WELL INCLINATION DETAIL KOP @ 200’ Max Hole Angle = 71.4 deg. @ 3,150’ Hole Angle +66 Deg. From 2,600’ to 12,050’ TREE & WELLHEAD Tree 2-9/16” 5K Wellhead FMC MONO 11” x 11” 5K GENERAL WELL INFO API: 50-029-23406-00-00 Drilled and Completed by D-14 & N-7ES - 2/27/2009 ESP Completion by Nabors 3S – 4/9/2009 ESP RWO by Nabors 4ES – 9/10/2009 ESP RWO/ install screen & cup Pkr by N-4ES – 9/29/2009 ESP RWO install diverter valve by Nabors 4ES – 1/14/2010 ESP RWO FCO & move ESP up hole by D-16 – 4/6/2011 Convert to TTC-ESP by Doyon 19 – 6/28/2012 Set new PSP TTC-ESP C/O slickline 1.6 wire – 6/17/2014 ESP RWO by Nordic #3 – 11/28/2015 STIMULATION DETAIL 3/11/2009 – Frac 106,880lbs of 16/20 Carbolite 60,880lbs behind pipe ] Milne Point Doyon 14 13-5/8” BOP Stack Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: February 16th, 2021Subject: Changes to Approved Sundry Procedure for Well MP F-96Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate ❑ Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well s Re-enter Susp Well❑ Other: ESP Changeout s 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Developments Exploratory ❑ 208-186 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23406-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509/ADL0355018/ADL0388235 MILNE PT UNIT KR F-96 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 13,915 feet Plugs measured N/A eE I V E D true vertical 7,140 feet Junk measured N/A feet DEC 17 2015 Effective Depth measured 13,858 feet Packer measured 13,208 feet OGCC true vertical 7,084 feet true vertical 6,437 feet Casing Length Size MD TVD Burst Collapse Conductor 122' 20" 122' 122' 1,530psi 520psi Surface 8,644' 10-3/4" 8,644' 4,338' 3,580psi 2,090psi Production 13,410' 7-5/8" 13,410' 6,637' 6,890psi 4,790psi Liner 705' 5-1/2" 13914 7,1336{' 7,740psi 6,390psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 12,012' 5,528' 13,209'(MD) Packers and SSSV(type,measured and true vertical depth) ZXP Packer N/A 6,437'(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 660 0 Subsequent to operation: 187 36 622 280 230 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: `� 315-592 Contact Paul Chan \.�v Email pchanCc�hilcorp.com Printed Name Bo York Title Operations Manager Signature "' Phone 777-8345 Date 12/17/2015 �s'46, RBDMSA-DEC 212015 Form 10-404 Revised 5/2015 kX7 Submit Original Only 14 • • Milne Point Unit Well: MPF-96 SCHEMATIC Last Completed: 11/27/15 llilcorp Alaska,1,1,CPTD: 208 186 TREE&WELLHEAD Orig.KBE to MSL=38.3'(Nabors 7ES) Tree 2-9/16"5K Wellhead FMC MONO 11"x 11"5K 20' OPEN HOLE/CEMENT DETAIL 20" 43 bbls of Arcticset I in 42"Hole 1 , 10-3/4" 843 bbls AS Lite,174 bbls Class'G'in a 13-1/2"Hole 7-5/8" 72 bbls Class'G'in a 9-7/8"Hole , 5-1/2" 23 bbls Class'G'in a 6-3/4"Hole if I CASING DETAIL 3 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40/N/A 19.124 0 122' 0.355 10 3/4" 10-3/4" Surface 45.5/L-80/Btc. 9.950 0 8,644' 0.0962 7-5/8" Production 29.7/L-80/IBT-M 6.875 _ 0 13,410' 0.0459 5-1/2" Liner 17/L-80/BTC-M 4.892 13,209' 13,914' 0.0233 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441" 0 12,012' 0.00579 WELL INCLINATION DETAIL KOP @ 200' Max Hole Angle=71.4 deg. @ 3,150' Hole Angle+66 Deg.From 2,600'to 12,050' JEWELRY DETAIL 2 Min IL 2.250' No Depth Item @ 11,916' „," 3 1 198' GLM w/DSOV 2 11,868' GLM w/Dummy Valve I` 4 3 11,916' XN-Nipple w/2.313 Profile-2.250 No Go 4 11,927' Discharge Head:FPDIS I 5 5 11,928' 1'`Pump:134FLEX17.5 PMSXD IIll 6 6 11,952' 2"d Pump:134FLEX17.5 PMSXD 7 11,975' Gas Separator:GRSFTX AR H6 7 8 11,980' Upper Tandem Seal:GSB3DBUTSB/SB PFSA 9 11,987' Lower Tandem Seal:GSB3DBUT SB/SB PFSA 10 11,994' Motor:MSP-250 168HP/2,295V/45A ;s 11 12,008 Sensor:Wellift ` 12 12,010' 4 fin Centralizer-Bottom: 12,012'/5,528'(TVD) '.w 13 13,209' BOT Flex Lock Liner Hanger&ZXP Liner Top Pkr w/ 4.75"ID 10 s PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Shot Date Status Viv A3 Sands 13,672' 13,682' 6,898' 6,908' 10 3/7/2009 Open A2 Sands 13,688' 13,696' 6,914' 6,922' 8 3/7/2009 Open Al Sands 13,708' 13,740' 6,934' 6,966' 32 3/7/2009 Open Jo STIMULATION DETAIL UP 11 3/11/2009 Frac 7-5/8" • 106,8801bs of 16/20 Carbolite 60,8801bs behind pipe GENERAL WELL INFO API:50-029-23406-00-00 Drilled and Completed by D-14&N-7ES -2/27/2009 Kuparuk'A'Sands ESP Completion by Nabors 35-4/9/2009 ESP RWO by Nabors 4ES-9/10/2009 ESP RWO/install screen&cup Pkr by N-4ES-9/29/2009 ESP RWO install diverter valve by Nabors 4ES-1/14/2010 .'„,'W.;', ESP RWO FCO&move ESP up hole by D-16-4/6/2011 5-1/2"&.', ': li Convert to TTC-ESP by Doyon 19-6/28/2012 TD 13,915'(MD)/TD 7,140(ND) Set new PSP TTC-ESP C/O slickline 1.6 wire-6/17/2014 PBTD=13,872'(MD)/PBTD=7,097'(TVD) ESP RWO by Nordic#3-11/28/2015 Revised By:TDF 12/16/2015(V) • • ii Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig Th's, API Number Well Permit Number Start Date End Date MP F-96 Nordic#3 50-029-23406-00-00 208-186 11/22/15 11/28/15 Daily Operations: C 11/18/2015-Wednesday No activity to report. 11/19/2015-Thursday No activity to report. 11/20/2015- Friday No activity to report. 11/21/2015 -Saturday No activity to report. 11/22/2015 Sunday Prep & move rig from L-48 to F-96. Rig accepted @ 10:30. Rig up Nordic 3. Move rig camp & spot same to F-96. Prep to N/D tree. Well pressures, tubing 230 psi, annulus 650 psi. Bleed pressures down to 70 psi on both sides. Mostly gas with a little diesel. Pump down annulus @ 6 bpm. Caught pressure 78 bbl away. Continue circulating @ 5 bpm 350 psi.Tubing open. Strap kill tank @ 100 bbl from pumping fluid &showing 70% returns. Losing 1.7 bpm, see diesel returns 590 bbls pumped, @ 602 bbls pumped start seeing seawater returns. Pump additional 100 bbls until clean 8.5 ppg seawater @ returns. Shut down pump, monitor I/A and tbg, tbg on slight vac, I/A static, well is dead.Total 733 bbls pumped, 448 bbls returned, lost 287 bbls during well kill. Blow down and R/D lines, set BPV. PJSM, N/D tree and adaptor flange. Wellhead rep inspect and clean hanger threads. N/U 11" 5M BOPE. Install 2-7/8" ram in lower BOP. Pull BPV, install TWC. Continue to fill pits with 8.5 ppg seawater. Set ESP spooling unit. PJSM, R/U test equipment, flood lines, perform body test to 250psi low/ 3,000psi high.AOGCC rep Bob Noble waived witness to test on 11-22-15 @ 10:13.Test BOPE using 2-7/8", 3-1/2" and 4- 1/2" test jts to 250 psi low and 3,000 psi high 5 min ea. charted. 11/23/2015- Monday Finished testing BOPs as per AOGCC Test BOPE using 2-7/8", 3-1/2" and 4-1/2"test jts to 2502si low and 3,000 psi high 5 min ea. charted. All test good. M/U landing joint& FOSV. Change handling equipment. R/D test equipment. B.O.L.D. Pull hanger. Movement @ 120k. Work 4.5". Pulling 200K. Work several times bringing wt up to 220k. Pulled free. Up wt 200K. Pull hanger to the floor.Terminate penetrator.Test cable under hanger. Phase to phase. Fill hole, took 77 bbl. Static loss @ 42 bph. L/D landing joint & hanger. Change handling equipment. R/U equipment. Pull 4-1/2" IBT tubing & L/D same. Filling the hole with double pipe displacement. F/ 11,996'T/7,200'. Pipe looks good. Swap ESP cable reels @ 7,340'. Perform F pad training with new crew. Continue POH with ESP completion L/D 4-1/2" IBT tubing from 7,200' to TTC tbg XO' ( 292 jts total 4-1/2" IBT tbg ) Continue filling hole using double pipe displacement @ approx 20 bph. POH with ESP assembly per rep, remove protectolizers and flat guards, drain oil, pull assembly and breakdown in mousehole. Fill and monitor well, 67 bbls to fill putting fluid level @ 1,500'.Static loss rate 72 bph. Continue w/ hole fill @ 20 bph. Wellbore fluid present in upper seal, lower seal and motor has clean oil, mild scale found on outside of equipment, extreme duty coupling between seal and TTC broken in half. 295 cannon clamps, 3 protectolizers, 2 flat guards recovered. Kickout ESP clamps, spool and secure ESP cable, clear and clean rig floor. R/U for 3-1/2" drill pipe. Continue with hole fill @ 20 bph. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-96 Nordic#3 50-029-23406-00-00 208-186 11/22/15 11/28/15 Daily Operations: 11/24/2015-Tuesday Finish to clean &clear floor. Load 3-1/2 Drill pipe. R/D ESP equipment. Set wear bushing with 10" ID. P/U Mule shoe, XO, XO, Scraper,two boot baskets XO to drill pipe.TIH picking up 3-1/2" drill pipe to 11,586'. Break circulation. Caught fluid in DP @ 45 bbls, pump 31 more bbls seeing returns (76bbls total).Static loss rate 73 bph. Continue to single in the hole to 13,130' (TOL @ 13,209'). M/U top drive. P/U 215K, S/O 78K, break circulation, caught fluid in DP in 30 bbls, 50 bbls pumped c`' see returns. Pump 6 bpm, 2,025 psi, pump 2 Bottoms up, see some oil breaking @ surface on first circulation,gas peak @ BU w/695u w/small amount of fine sand. Pump 892 bbls total. Note: losses while circulating, total 93 bbls.Static loss rate slowed to 20 bph. Blow down top drive. POH from 13,130'to 3,300' racking 3-1/2" drill pipe in derrick. Note: 42 bbls over calculated displacement at this point on trip out. . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-96 Nordic#3 50-029-23406-00-00 208-186 11/22/15 11/28/15 Daily Operations: 11/25/2015-Wednesday Continue to POOH from 3,300' racking back 3-1/2i°DP. Lay down scraper BHA. MU 7-5/8" Champ 4 packer on 3-1/2" drill pipe.TIH with Champ packer to 13,120'. Set Champ packer @ 13,120'. Rig up and test 7-5/8" casing to 2,000psi and chart r. for 30 minutes. Test good. Release Champ packer. POOH from 13,120'to 6,460' laying down 3-1/2" Drill pipe. Fill hole using double fluid displacement. Monitor well. M/U FOSV, hang blocks, cut and slip 63' drilling line, re-set and test crown saver. Service top drive, blocks and crown sheaves. Continue POOH L/D 3-1/2" Drill pipe from 6,460' to 2,900'. Continue filling hole with double fluid displacement. 11/26/2015-Thursday Continue to TOH laying down 3-1/2" drill pipe from 2,900' to surface. Lay down champ packer. Hole taking 8-10 bph. Clean and clear rig floor. Kick out all BOT tools. Change over to 2-7/8" handling equipment. Pull 10" ID wear bushing. MU mule shoe and TIH Picking up 2-7/8" tubing to 5,150'. Fill hole using double fluid displacement on trip in. Continue to single in the hole with 2-7/8" tbg from 5,150' to 11,830'. Fill hole using double fluid displacement on trip in. M/U head pin, pump and flush tbg, returns in 16 bbls putting fluid level @ 367'. Static loss rate 13.2 bph. Service rig, add oil to top drive. POH racking 2-7/8" tbg in derrick from 11,830' to 4,600'. Fill hole using double fluid displacement on trip out. 11/27/2015 - Friday Continue to POOH racking back 2-7/8" tubing from 4,600'to surface. Break off and lay down mule shoe. MU ESP Assy: Centralizer, Sensor, Motor CL5, Lower Tandem Seal, Upper Tandem Seal, Gas Separator, Pump, Pump, Discharge Head, Pup Joint. Rig up and tie in Control line. Meg test Cable.Test good. MU XN Nipple w/2.313" Profile, 1)Tubing Jt, Pup Jt, GLM #1 with Dummy valve, Pup Jt . RIH with new 475 series ESP on 2-7/8" EUE 6.5#8rd, L-80 tubing from the derrick. Run 3/8" control line. Install CC Clamps on the first 9 jts, then one clamp every other joint. Meg test ESP cable every 2,000', RIH to 8,821'. Continue w/20 bph hole fill while tripping in the hole. C/O control line tbg reel, splice same, RIH from 8,831' to 9,139', splice ESP cable per rep. 11/28/2015-Saturday Continue top splice ESP cable per rep. Meg and test cable.Test good. Continue to run in hole with ESP completion from 9,139' to 11,977'. Meg cable every 2,000' and installing CC Clamps every other joint. Continue w/20 bph hole fill. MU tubing hanger and landing joint. Make penetrator splice. Meg test cable. MU cable to penetrator. Blow down surface lines before landing out tubing hanger. Land hanger with end of pump assembly @ 12,011'. RILDS. Lay down landing Joint. Set BPV. Up Wt 120K, Dn Wt 60K, Block/TD Wt 36K. Ran completion as follows: 475 series ESP Assembly,XN Nipple w/2.313" Profile, 1)Tubing Jt, Pup it, GLM #1 with Dummy valve, Pup Jt, 374)Tubing Jts, Pup Jt, GLM #2 with DSOV, Pup Jt, 5)Tubing Jts,Tbg Hgr w/Pup. Ran 380 Jts 2-7/8"Tbg, 4 Protectalizer clamps, 2 Flat guard, 4 Pump Clamps, 196 CC Clamps. PJSM, N/D BOP and associated equipment. N/U Tbg head adapter and tree. Test tubing hanger void to 5,000psi. Pull BPV, set TWC.Test tree using diesel to 5,000psi. Pull TWC. Rep makes final ESP penetrator checks. Release rig @ 22:00 hrs. 11/29/2015-Sunday No activity to report. 11/30/2015 - Monday No activity to report. 12/1/2015 -Tuesday No activity to report. • • x, OF 77$, w\� �� s THE STATE Alaska Oil a Gas ,;-s• 1-'114of® Conservation Commission 333 West Seventh Avenue 1/4GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 � ti Main: 907.279.1433 ALAS— Fax: 907.276.7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer $CANNEV NOV 2 4 2O Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-96 Sundry Number: 315-592 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster /d. �� Chair DATED this f 6 day of November, 2015 Encl. RBDMsV1OV 18 2015 • • 3 �'E ' STATE OF ALASKA NOV 1 3 2411 ALASKA OIL AND GAS CONSERVATION COMMISSION 09:5(4/(//‘745- APPLICATION FOR SUNDRY APPROVALS A t-YN 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑✓ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Change Out Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ 208-186 3.Address. Stratigraphic ElService ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-23406-00-00 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MILNE PT UNIT KR F-96 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509/ADL0355018/ADL0388235 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): 13,915 7,140 13,858 7,084 1,547 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 122 20" 122' 122' 1,530 psi 520 psi Surface 8,644' 10-3/4" 8,644' 4,338' 3,580 psi 2,090 psi Intermediate Production 13,410' 7-5/8" 13,410' 6,637' 6,890 psi 4,790 psi Liner 705' 5-1/2" 13,914' 7,136' 7,740 psi 6,390 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80/IBT-M 11,996' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Pkr and N/A 13,209'(MD)&6,437'(TVD)and N/A 12.Attachments: Proposal Summary E Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic U Development❑ Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/19/2015 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 herein will not be deviated from without prior written approval. Contact PAUL CHAN Email pchan@hilcorp.com Printed Name Title BO YORK OPERATIONS MANAGER Signature Phone Date /, `771' ,..--- 907-777-8435 1 'k l� i7". COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 - 692- Plug 15 - 692Plug Integrity ❑ BOP Test [2l Mechanical Integrity,teTest ❑ Location Clearance n su❑ c Other: .�t' 0"a �p S 40 1 i.e. '- C /'Vt/4-SS,0 / [ 7 ,os-I Post Initial Injection MIT Req'd? Yes ❑ No ❑ qn Spacing Exception Required? Yes Ell M No Subsequent Form Required: /b - q o LI RBDMS ,NOV 18 2015 / APPROVED BY Approved by: Y�'� COMMISSIONER THE COMMISSION Date: /1— /6 -/s- clRtG4ic $r4viid Form 10-403 Revised 11/2015 for 12 monomte Sofapp�il.. 2Attachments in Duplicate 1166 it 14 //,/4 Y.r 0 • RECEIVED STATE OF ALASKA SEP 2 2 2015 . ALASKA OIL AND GAS CONSERVATION COMMISSION aj'S /1�/als APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations H Fracture Stimulate ❑ Pull Tubing El Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate H Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well J Re-enter Susp Well ❑ Other: ESP Change-out❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development E• 208-186 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-009-23406-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 432C Will planned perforations require a spacing exception? Yes ❑ No H / MILNE PT UNIT KR F-96 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509IADL0355018IADL0388235 - MILNE POINT/KUPARUK RIVER OIL • 11. PRESENT WELL CONDITION SUMMARY iJ- Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft...., Plugs(measured): Junk(measured): (f 13,915 - 7,140 - 13,858 7,084(!" N/A N/A Casing Length Size MD \\l TVD Burst Collapse Structural 2 Conductor 122' 20" 122' V 122' 1,530psi 520psi Surface 8,644' 10-3/4" 8,644' V 4,338' 3,580psi 2,090psi Intermediate Production 13,410' 7-5/8" 13,410' 6,637' 6,890psi 4,790psi Liner 705' 5-1/2" 13,914' 7,136' 7,740psi 6,390psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80/IBT-M 11,996 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Pkr and N/A . 13,209(MD)&6,437(TVD)and N/A 12.Attachments: Description Summary of Proposal Q. 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development❑� " Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 10/7/2015 ❑ Commencing Operations: OIL WINJ ❑ WDSPL H Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown H Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hilcoro.com Printed Name Stan Porhola Title Operations Engineer Signature ..44;--- /9�-•L.'t ._ Phone 777-8412 Date 9/22/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 6 . Plug Integrity ❑ BOP TU� [1], st Mechanical Integrity Test ❑ Location Clearance L' Other 3CIO 'r.): eft 1.0 / vs- ( ,vtAst 15"li7 541 Spacing Exception Requi d? Yes ❑ No Er Subsequent Form Required: 1v _Ii„,,-, s1 APPROVED BY Approved b • r • i7 mr COMMISSIONER C THE COMMISSION r1 t_t f=-t-z- —-— • AB 0 RIG INA II�yI� f�".1015- SubmittsiForm Duplicate Form 10-403 Revised 5/2015 8 valid for mo�tllA 7- t date of ap v81. Attachments in Duplicate Well Prognosis Well: MPU F-96 Hilcorp Alaska,LL Date:9/22/2015 Well Name: MPU F-96 API Number: 50-029-23406-00 Current Status: SI Oil Well [ESP] Pad: F-Pad Estimated Start Date: October 07th, 2015 Rig: Nordic#3 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 208-186 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: • 1tc-d— Current Bottom Hole Pressure: 2,247 psi @ 7,000' TVD (Last BHP measured 8/06/2013) �,. Maximum Expected BHP: 2,247 psi @ 7,000' TVD (No new perfs being added) Max. Allowahlp Surf Pressure: 4.0-p'si /S -1 7 r;, (Based on SBHP taken_;406/201 - • water cut of 50% (0.385psi/ft)wi • - -d•e• -fety factor Vr-t- of 1,000' . % •i cap) Brief Well Summary: 71, "U "- (- The Milne Point F-96 well was drilled as a Kuparuk development well that TD'd at 13,915' and ran and cemented 7" casing in February 2009. The well was perforated and frac'd in the Kuparuk A sands and initially completed with an ESP in April 2009. This and subsequent ESPs failed and were replaced in July 2009, September 2009, October 2009, 2010 and 2011. Most involved pump/solids related failures. In 2012 a TT-ESP (through-tubing) was installed at a shallower depth. This pump failed on May 6, 2015. The most recent casing pressure test performed during initial cementing of casing in 2009. A casing pressure test will be completed during this workover. An attempt to pull this completion with the Hilcorp ASR #1 rig in 2015 was aborted after the rig was unable to pull the tubing due to the weight of the string and friction exceeding the lifting capacity of rig. Due to observed scale issues, a downhole chemical injection line will be run as part of the new completion. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition • Casing last tested to 3,500 psi for 30 min down to 13,308' MD on 2/07/2009. Objective: The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP, changing the tubing string from 4-1/2" to 2-7/8". Brief Procedure: WO Rig Procedure: 1. MIRU Nordic#3 WO Rig. 2. Circulate well with 8.5 ppg sea water down tubing and fill casing. 3. Set BPV. ND Tree. 4. NU 11" BOPE. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test upper pipe rams on 2-7/8" test joint. c. Test lower pipe rams on 4-1/2"test joint. • • Well Prognosis Well: MPU F-96 Hilcora Alaska,LL Date:9/22/2015 5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 6. Bleed any pressure off tubing and casing. Pull BPV. 7. MU landing joint and pull 10k tension over string weight on tubing hanger to confirm ESP free. a. ***Contingency*** If landing joint won't make up to tubing hanger(bad threads). b. MU spear and pull 10k tension over string weight on tubing hanger to confirm tubing cut. 8. POOH. Rack back 4-1/2" tubing and lay down the failed ESP. 9. MU 7-5/8" casing scraper and RIH on 4-1/2"tubing to liner top at+/-13,209' MD. 10. Circulate bottoms up x 2 with 8.5 ppg sea water. 11. POOH. Lay down 7-5/8" casing scraper. Rack back 4-1/2" tubing. c..61,-5°/ 12. PU Champ Packer and RIH w/4-1/2"tubing. f" 13. Set Champ Packer at+/- 13,100' MD.Test casing to 2,000 psi for 30 min. cl 14. Release Champ Packer. POOH. LD Champ Packer. Lay down 4-1/2" tubing. 0 �o �,Y 15. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. a. Run new GLMs at+/- 174' and +/- 11,852' and XN profile at+/- 11,886'. b. Run new 3/8" control line to bottom of pump at+/- 11,996. 16. Set base of ESP at+/-11,996' MD (Pump intake around +/- 11,956' MD). Land tubing hanger. 17. Lay down landing joint. Set BPV. ND BOPE. NU new 2-9/16" 5,000#tree. Pull BPV. 18. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 19. RD Nordic#3 WO Rig. 20. Replace IA x OA pressure gauge if removed (7-5/8"x 10-3/4"). 21. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic H . . Milne Point Unit Well: MPF-96 SCHEMATIC Last Completed: 6/17/15 Hiicor)Alaska,LLC PTD: 208-186 CASING DETAIL Orig.KBE to MSL=38.3'(Nabors 7ES) Size Type Wt/Grade/Conn ID Top Btm i C, '4I ) 20" Conductor 91.1/H-40/N/A 19.124 0 122' 20"' t" " 10-3/4" Surface 45.5/L-80/Btc. 9.950 0 8,644' 7-5/8" Production 29.7/L-80/IBT-M 6.875 0 _ 13,410' •" 1 e t� 5-1/2" Liner 17/L-80/BTC-M 4.892 13,209' 13,914' 4; f> TUBING DETAIL s7 4-1/2" Tubing 12.6/L-80/IBT-M 3.958" 0 11,996' tt !d ';A of JEWELRY DETAIL 2 0 i0 No Depth Item 10-3/4"Al 10 1 174' SLB 4-1/2"x 1"KBMG GLM 2 11,951' TTC Tubing Cross-over 3 11,962' Tandem Seal Sections-GSB3 DB UT/LT HL H6 PFS 4 11,976' Motor:KMH-55hp/1,259V/26A 5 11,992' PumpMate w/4 fin Centralizer-Bottom:11,996' • 6 13,209' BOT Flex Lock Liner Hanger&ZXP Liner Top Pkr w/ 4.75"ID PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status A3 Sands 13,672' 13,682' 6,898' 6,908' 10 3/7/2009 Open A2 Sands _ 13,688' 13,696' 6,914' 6,922' 8 3/7/2009 _ Open Al Sands 13,708' 13,740' 6,934' 6,966' 32 3/7/2009 Open WELL INCLINATION DETAIL KOP @ 200' Max Hole Angle=71.4 deg. @ 3,150' Hole Angle+66 Deg.From 2,600'to 12,050' OPEN HOLE/CEMENT DETAIL 20" 43 bbls of Arcticset I in 42"Hole 10-3/4" 843 bbls AS Lite,174 bbls Class`G'in a 13-1/2"Hole 7-5/8" 72 bbls Class'G'in a 9-7/8"Hole 5-1/2" 23 bbls Class'G'in a 6-3/4"Hole Broken Shsft STIMULATION DETAIL •• 2 r 3/11/2009-Frac LIItl f" - r 106,8801bs of 16/20 Carbolate ,,3 60,880Ibs behind pipe li St R e TREE&WELLHEAD ITree Cameron 4-1/16"5M FMC * it 11"x 4-1/2"TC-B-EC w/4-1/2"Tubing Hanger 3.ti I 521 Hydril T&B Threads.4"CIW"H"BPV R 1 WellheadNt, Profile.Special seal sleeve machined @ BOT o 5 'it due to Hanger profile being too deep. 01 IV6 GENERAL WELL INFO 7-5/8'"1 I` API:50-029-23406-00-00 Drilled and Completed by D-14&N-7ES -2/27/2009 ESP Completion by Nabors 3S-4/9/2009 _ ESP RWO by Nabors 4ES-9/10/2009 ESP RWO/install screen&cup Pkr by N-4ES-9/29/2009 �Kupauk A'Sends ESP RWO install diverter valve by Nabors 4ES-1/14/2010 ESP RWO FCO&move ESP up hole by D-16-4/6/2011 =. Convert to TTC-ESP by Doyon 19-6/28/2012 Set new PSP TTC-ESP C/O slickline 1.6 wire-6/17/2014 5-1/2' # TD=13,915'(MD)/TD=7,140'(TVD) PBTD=13,872'(MD)/PBTD=7,097'(TVD) Created By:TDF 9/21/2015 0 0 Milne Point Unit • Well: MPF 96 PROPOSED Last Completed: 6/17/15 Hilcorp Alaska,LLC PTD: 208-186 CASING DETAIL Orig.KBE to MSL=38.3'(Nabors 7ES) Size Type Wt/Grade/Conn ID Top Btm ' i A 20" Conductor 91.1/H-40/N/A 19.124 0 122' 20' �: 10-3/4" Surface 45.5/L-80/Btc. 9.950 0 8,644' 7-5/8" Production 29.7/L-80/IBT-M 6.875 0 13,410' 1 5-1/2" Liner 17/L-80/BTC-M 4.892 13,209' 13,914' , TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441" 0 ±11,996' JEWELRY DETAIL No Depth Item 10-3/4" ► 1 ±174' GLM 2 ±11,852' GLM 3 ±11,886' XN-Nipple 4 ±11,936' Discharge Head 5 ±11,937' Pump 6 ±11,956' Gas Separator 7 ±11,962' Tandem Seal Sections 8 ±11,976' Motor 9 ±11,992' PumpMate w/4 fin Centralizer-Bottom:±11,996' 10 ±11,996' 3/8"Control Line 11 13,209' BOT Flex Lock Liner Hanger&ZXP Liner Top Pkr w/ 4.75"ID PERFORATION DETAIL 1111 2 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status 3 A3 Sands 13,672' 13,682' 6,898' 6,908' 10 3/7/2009 - Open A2 Sands 13,688' 13,696' 6,914' 6,922' 8 3/7/2009 Open 4 Al Sands 13,708' 13,740' 6,934' 6,966' 32 3/7/2009 Open Till WELL INCLINATION DETAIL 5 KOP @ 200' ill_ 6 Max Hole Angle=71.4 deg. @ 3,150' Hole Angle+66 Deg.From 2,600'to 12,050' 7 OPEN HOLE/CEMENT DETAIL 20" 43 bbls of Arcticset I in 42"Hole "'8 10-3/4" 843 bbls AS Lite,174 bbls Class'G'in a 13-1/2"Hole l' r 7-5/8" 72 bbls Class`G'in a 9-7/8"Hole y 9 5-1/2" 23 bbls Class'G'in a 6-3/4"Hole q4 , 10 STIMULATION DETAIL 3/11/2009-Frac 106,880Ibs of 16/20 Carbolite 60,8801bs behind pipe TREE&WELLHEAD 1 '' 11 Tree Cameron 4-1/16"5M FMC 7 5/8 +� 11"x 4-1/2"TC-B-EC w/4-1/2"Tubing Hanger Wellhead 521 Hydril T&B Threads.4"CIW"H"BPV Profile.Special seal sleeve machined @ BOT i due to Hanger profile being too deep. GENERAL WELL INFO Kupauk'A'Sands API:50-029-23406-00-00 EEE Drilled and Completed by D-14&N-7ES -2/27/2009 ESP Completion by Nabors 35-4/9/2009 ESP RWO by Nabors 4ES-9/10/2009 ESP RWO/install screen&cup Pkr by N-4ES-9/29/2009 5-1/Y't;':�i"'?", ESP RWO install diverter valve by Nabors 4ES-1/14/2010 ESP RWO FCO&move ESP up hole by D-16-4/6/2011 TD=13,915'(MD)/1D=7,140'(TVD) Convert to TTC-ESP by Doyon 19-6/28/2012 PBTD=13,872'(MD)/PBTD=7,097'(TVD) Set new PSP TTC-ESP C/O slickline 1.6 wire-6/17/2014 Created By:STP 9/22/2015 • • . 11 Milne Point MPU F-96 BOP Hikorr,auwk..L•I.c: 09/22/2015 1m[-it [11l ifi an if-I Hydril 11" 5M (ilii )[a1 if I . , Shaffer .„,„ ..), , ! 2 7/8" Pipe Rams J I. 1 11" 5M Blinds 3 1/8 5M Kill Valves / 3 1/8 5M Choke Valves Manual and HCR t11_ Manual and HCR _ 0 I io -1:: 'Op, ,• I - 1103411‘ I 1 a a s'..: a a . ir 0' .4 i i asll lig 1 Hydril - - 11" 5M1 4 1/2" Pipe Rams r 0 / ---- -----Ai • .L h1� • X t0 f CO N CD011Z Z F H ■ 4x • _ a g N 3 1 •,,i II.. Vii i 0:4 a_ a - '- W ¢y ° t FW • a ti ►•i 1 U r • a i W Z • Q° K w� r ii 1 U U r ■ _ 2 �s 1 1 # h 1 1 l, _ ° - ° 11 gY 11 r : f w .p �• .,I♦J f Y ff I... I i - et1 a s1 C) .lli -- I JIn 0 M 1 U 111.11:11'i 04 i o• OJO a � Ai i a ..2.• s X a a i— E i U a• 9 2 0 I' H ril ° s c i u i i 3 � g° ►l1 "0 f O U U i , K . 6 ry y • a -* O INN 1 0 Ci'm $ 2 L V¢ o Z ° 0 I • 0 9> Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Tuesday, November 10, 2015 11:14 AM To: Schwartz, Guy L (DOA) Subject: Nordic#3 Flow Diagram and MPSP for MPU F-96 (PTD 208-186) Attachments: Fluid Management One Line Diagram-3.xls Guy, See attached fluid diagram for Nordic#3.The current scope for MPU F-96(PTD 208-186) is to swap out the 4-1/2"thru- tubing ESP, run a casing scraper,test casing, and run a conventional ESP on 2-7/8" tubing. Updated Pressures: Current SITP: 270 psi (Based on current SIPT w/existing fluid column) MPSP: 1,547 psi (Based on 0.10 psi/ft gas gradient) Regards, Stan Porhola I Operations Engineer North Slope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 1 RECEIVED • STATE OF ALASKA ALlikA OIL AND GAS CONSERVATION COMilkSION SEP 2 1 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon L] Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: ESP Change-out 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 208-186 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23406-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509/ADL0355018/ADL0388235 MILNE PT UNIT KR F-96 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 13,915 feet Plugs measured N/A feet true vertical 7,140 feet Junk measured N/A feet Effective Depth measured 13,858 feet Packer measured 13,208 feet true vertical 7,084 feet true vertical 6,437 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 122' 20" 122' 122' 1,530psi 520psi Surface 8,644' 10-3/4" 8,644' 4,338' 3,580psi 2,090psi Intermediate . Production 13,410' 7-5/8" 13,410' 6,637' 6,890psi 4,790psi Liner 705' 5-1/2" 13914 7,136' 7,740psi 6,390psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet I); q , 2104 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT-M 11,996' 5,521' 13,209'(MD) Packers and SSSV(type,measured and true vertical depth) ZXP Packer N/A 6,437'(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 580 0 Subsequent to operation: 0 0 0 460 0 14.Attachments(required per 20 AAC 25.070..25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development El 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: 315-302 Contact Stan Porhola Email sporhoIat hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature No'4,04 _ Phone 777-8412 Date 9/21/2015 Form 10-404 Revised 5/2015 oil, t©_lsrcRBDMS SEP2 5 `UI Submit Original Only • 111 Milne Point Unit • Well: MPF-96 SCHEMATIC Last Completed: 6/17/15 Hilcor',Alaska,LLC PTD: 208-186 CASING DETAIL Orig.KBE to MSL=38.3'(Nabors7F5) Size Type Wt/Grade/Conn ID Top Btm I w s4 20" Conductor 91.1/H-40/N/A 19.124 0 122' 2p ! 10-3/4" Surface 45.5/L-80/Btc. 9.950 0 8,644' t'" 7-5/8" Production 29.7/L-80/IBT-M 6.875 0 13,410' t r 5-1/2" Liner 17/L-80/BTC-M 4.892 13,209' 13,914' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958" 0 11,996' 11 10 ft t. JEWELRY DETAIL 04 i, No Depth Item 10-3/4"•� t° 1 174' SLB 4-1/2"x 1"KBMG GLM 2 11,951' TTC Tubing Cross-over 3 11,962' Tandem Seal Sections-GSB3 DB UT/LT HL H6 PFS 4 11,976' Motor:KMH-55hp/1,259V/26A 5 11,992' PumpMate w/4 fin Centralizer-Bottom:11,996' 6 13,209' BOT Flex Lock Liner Hanger&ZXP Liner Top Pkr w/ 4.75"ID PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status A3 Sands 13,672' 13,682' 6,898' 6,908' 10 3/7/2009 Open A2 Sands 13,688' 13,696' 6,914' 6,922' 8 3/7/2009 Open Al Sands 13,708' 13,740' 6,934' 6,966' 32 3/7/2009 Open WELL INCLINATION DETAIL KOP @ 200' Max Hole Angle=71.4 deg. @ 3,150' Hole Angle+66 Deg.From 2,600'to 12,050' OPEN HOLE/CEMENT DETAIL 20" 43 bbls of Arcticset I in 42"Hole 10-3/4" 843 bbls AS Lite,174 bbls Class'G'in a 13-1/2"Hole 7-5/8" 72 bbls Class'G'in a 9-7/8"Hole Shaft 5-1/2" 23 bbls Class'G'in a 6-3/4"Hole BnokenSTIMULATION DETAIL ' •' 2 3/11/2009-Frac 106,8801bs of 16/20 Carbolite 3 60,8801bs behind pipe T TREE&WELLHEAD 4 Tree Cameron 4-1/16"5M FMC 11"x 4-1/2"TC-B-EC w/4-1/2"Tubing Hanger Wellhead 521 Hydril T&B Threads.4"CIW"H"BPV 5 Profile.Special seal sleeve machined @ BOT due to Hanger profile being too deep. GENERAL WELL INFO 7-5/8"a et API:50-029-23406-00-00 Drilled and Completed by D-14&N-7ES -2/27/2009 ESP Completion by Nabors 3S-4/9/2009 _ ESP RWO by Nabors 4ES-9/10/2009 ESP RWO/install screen&cup Pkr by N-4ES-9/29/2009 Kupauk' 'Sands ESP RWO install diverter valve by Nabors 4ES-1/14/2010 ESP RWO FCO&move ESP up hole by D-16-4/6/2011 Convert to TTC-ESP by Doyon 19-6/28/2012 Set new PSP TTC-ESP C/O slickline 1.6 wire-6/17/2014 In 5-1/2" .. w�1i TD=13,915'(MD)/TD=7,140'(TVD) PBTD=13,872'(N/0)/PBTD=7,097(TVD) Created By:TDF 9/21/2015 • Hilcorp Alaska, LLC Hi!carpAlaska.LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP F-96 50-029-23406-00-00 208-186 7/21/2015 8/5/820105 Daily Operations: 7/22/15-Wednesday MIRU assemble all rig components ready for BOP test on Aug 3 PM.Spot pipe racks, run BOP lines, install pumplines set up floor for handling 4.5"tubing. 7/23/15-Thursday No operations to report. 7/24/15-Friday No operations to report. 7/25/15-Saturday No operations to report. 7/26/15-Sunday No operations to report. 7/27/15-Monday No operations to report. 7/28/15-Tuesday No operations to report. • • Hilcorp Alaska, LLC Hi!cog)Alaska. Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP F-96 50-029-23406-00-00 208-186 7/21/2015 8/5/2015 Daily Operations: 07/29/15-Wednesday No operations to report. 07/30/15-Thursday No operations to report. 07/31/15-Friday No operations to report. 08/01/15-Saturday No operations to report. 08/02/15-Sunday No operations to report. 08/03/15-Monday Crew travel to MPU. PJSM crew assignments, orientation,gather parts from warehouse. Check all engines and fluid levels,start all equipment. No location communications. Discuss operations with Chuck Scheve,said to proceed with testing when able. Proceed with start up, offload 265 bbls hot seawater 150°. Fluids delayed by rig move on Spine Road. Wait on second load. Wire camp. Test H2S sensors and alarms.Test methane sensors operational on bypass. Pumping 8.5 ppg hot seawater. Pump packing leaking badly,shut down,tighten/lube, repeat,same problem, 100 bls pumped, lots of gas, just catching pressure, no returns,call LRS to finish pumping kill. Offload second SW truck rig up for LRS, pump remaining 410 bbls with circulation, recover heavy oil"'140 bbls before seawater returns. Total returns 230 bbls. Initiate BOP testing with LRS chart and pump. BOP testing witness waived by Chuck Scheve,AOGCC. 08/04/15-Tuesday PJSM. Continue with BOPE test. Shut down for LRS crew changeout. Rig maintenance waiting on crew change out. Continue BOP test all BOPE 250/3,000 psi. Failure on VBR rams troubleshoot change out same, continue test annular 250/2,500 psi, accumulator draw down test. Center rig over hole. Remove TWC, install BPV, Install 4.5" IBT landing joint w cover. PJSM on max pull operation safety and evacuation. Latch U. PU to 124K hanger movement noted 3.5'at 157K. Hydraulic stalling. Slack off reset increase hydraulic pressure PU to 168.7K gain an additional movement. Rig stalling out will not pull any more. Repeat several times. Not getting stretch out of pipe. Rangeland advises no more hydraulic pressure increase at peak load 4,800 psi on hydraulic hoses rated for 5,200 psi. Land hanger RILD. Flo-test operate pump after redress,calibrate telemetry to match flow rates and volume sensors,generator ran out of fuel. Fuel up. Begin RDMO. • • Hilcorp Alaska, LLC t,ileo,.,,Alaska.LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP F-96 50-029-23406-00-00 208-186 7/21/2015 8/5/2015 Daily Operations: 08/05/15-Wednesday PJSM RDMO, ND BOP NU Tree. Remove BPV Freeze protect well.Secure and turn well over to production. Rig off location. 08/06/15-Thursday No operations to report. 08/07/15-Friday No operations to report. 08/08/15-Saturday No operations to report. 08/09/15-Sunday No operations to report. 08/10/15-Monday No operations to report. 08/11/15-Tuesday No operations to report. -Zi —k•Ac Cc; • , oFTH 4.5'0\��j�,s. THE STATE Alaska Oil and Gas m�' '�-s�—''; OfA T 4 j\ J(j\ Conservation Commission !s z___ ,i :_,-_ 333 West Seventh Avenue ;� *h;, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 oFALAS�P Fax. 907.276.7542 www.aogcc.alaska.gov Chris Kanyer Operations Engineer SCANNED MAY 2 9 2015 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-96 Sundry Number: 315-302 Dear Mr. Kanyer: 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, / w7 4 Cathy . Foerster Chair DATED this tis-F day of May, 2015 Encl. -- ,z).1s BEDEWED STATE OF ALASKA j 2' MAY 15 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS A 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑✓ • Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑Q . Re-enter Susp Well ❑ Other: ESP Change-out❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development E, 208-186 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23406-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 432C ' Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT KR F-96• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL00255091ADL03550181ADL0388235 ' MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 13,915 7,140 13,858 7,084 N/A N/A Casing Length Size MD ND Burst Collapse Structural • Conductor 122' 20" 122' 122' 1,530psi 520psi Surface 8,644' 10-3/4" 8,644' 4,338' 3,580psi 2,090psi Intermediate Production 13,410' 7-5/8" 13,410' 6,637' 6,890psi 4,790psi Liner 705' 5-1/2" 13,914' 7,136' 7,740psi 6,390psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic / See Attached Schematic 4-1/2" 12.6#/L-80/IBT-M 11,996 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): ZXP Liner Top Pkr and N/A 13,209(MD)&6,437(ND)and N/A 12.Attachments: Description Summary of Proposal 0 '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑Q Exploratory ❑ Stratigraphic❑ Development❑, 4 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/23/2015 Commencing Operations: OIL 2- WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanver(u�hilcorr .com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 777-8377 Date 5/15/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -IS- So2 Plug Integrity 0 �BOP Test [1Q Mechanical Integrity Test ❑ Location Clearance� 0 y Other: lr 3� pS'. J Q e ,,,_#- ( /4A-S Toc- I j-17 p S,, ) - / 56)(..) p5 - (-4-5:D �.7Sf Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: I APPROVED BY J Approved by: _ 9tie.444.___ COMMISSIONER THE COMMISSION Date: ,S-2j -./5 /S -iVa 3/446 Submit Form and Form 1 .1-Revised 5/2015GgiI v lid for 12 months from ate of approval. Ariach is in Duplicate �//�. ,i,-- RBDMS4A MY 19 2015 II Well Prognosis Well: MPF-96 Mewls Alaska,LL Date:5/15/2015 Well Name: MPF-96 API Number: 50-029-23406-00-00 Current Status: SI Producer Pad: F Pad Estimated Start Date: May 26, 2015 Rig: Nordic 3 Reg.Approval Req'd? May 25, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 208-186 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907)250-0374 (M) Second Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) AFE Number: 1521324 Current Bottom Hole Pressure: —2,247 psi @ 7,000'TVD (Last BHP measured 8/6/2013) Maximum Expected BHP: —2,247 psi @ 7,000' TVD (No new perfs being added) Max.Allowable Surface Pressure: ‘.2-1si (Based on actual reservoir conditions and water cut of 67% (0.404psi/ft)with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: �2�7r 76) }` / J 17/ ,G 5-2-4 The Milne Point F-96 well was drilled as a Kuparuk development well that TD'd at 13,915' and ran and cemented 7" casing in February 2009. The well was perforated and frac'd in the Kuparuk A sands and initially completed with an ESP in April 2009. This and subsequent ESPs failed and were replaced in July 2009, September 2009, October 2009, 2010 and 2011. Most involved pump/solids related failures. In 2012 a TT-ESP (through-tubing) was installed at a shallower depth. This pump failed on May 6, 2015. The most recent casing pressure test performed during initial cementing of casing in 2009. A casing pressure test will be completed during this workover. Due to observed scale issues, a downhole chemical injection line will be run as part of the new completion. 7 No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issues suspected. l RWO Objective: �,� ' P c.,,J Pull 4-1/2"TT-ESP, perform cleanout, pressure test casing, & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. I .� 2. Attempt to circulate well with 8.5ppg seawater and monitor well. —6 -ti- -s' 3. ND tree, NU 11" BOPE and test to 250psi low/3,22 psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. 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. II Well Prognosis • Well: MPF-96 Hilcorp Alaska,LL Date:5/15/2015 b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 4-1/2"TT-ESP completion from 11,992'to surface and lay down same. 6. RIH with cleanout BHA to+/-13,850'. POOH with same. 7. RIH and set test packer at+/-13,100' (Note: above liner top+/-600ft above perfs,test of 7-5/8" casing only). 8. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. 9. MU and RIH with ESP with gas separator and 3/8"chemical injection line on 2-7/8" 8RD EUE L-80 tubing [new] Set ESP at+/-11,250'. Land tubing hanger. 10. ND BOP, NU and tree. 11. RDMO workover rig and equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit . iii Well: MPF-96 - SCHEMATIC Last Completed: 6/17/15 lliicoru Alaska,LLC PTD: 208-186 CASING DETAIL Ckig.KBE to MSL=38.3'(Nabors 7E5) Size Type Wt/Grade/Conn ID Top Btm 4 ." % 20" - Conductor 91.1/H-40/N/A 19.124 0 122' 20 ,kil, 10-3/4" Surface 45.5/L-80/Btc. 9.950 0 8,644' 7-5/8" Production 29.7/L-80/IBT-M 6.875 0 13,410' t 5-1/2" Liner 17/L-80/BTC-M 4.892 13,209' 13,914' l a TUBING DETAIL ,; 4-1/2" Tubing 12.6/L-80/IBT-M 3.958" 0 11,996' s. 4, JEWELRY DETAIL A, P No Depth Item 10-3/4".4 k 1 174' SLB 4-1/2"x 1"KBMG GLM 2 11,951' TTC Tubing Cross-over 3 11,962' Tandem Seal Sections-GSB3 DB UT/LT HL H6 PFS 4 11,976' Motor:KMH-55hp/1,259V/26A 5 11,992' PumpMate w/4 fin Centralizer-Bottom:11,996' 6 13,209' BOT Flex Lock Liner Hanger&ZXP Liner Top Pkr w/ 4.75"ID PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status J A3 Sands 13,672' 13,682' _ 6,898' 6,908' 10 3/7/2009 Open I A2 Sands 13,688' 13,696' 6,914' 6,922' 8 3/7/2009 Open Al Sands 13,708' 13,740' 6,934' 6,966' 32 3/7/2009 Open 1 WELL INCLINATION DETAIL KOP@200' Max Hole Angle=71.4 deg. @ 3,150' Hole Angle+66 Deg.From 2,600'to 12,050' OPEN HOLE/CEMENT DETAIL 20" 43 bbls of Arcticset I in 42"Hole 10-3/4" 843 bbls AS Lite,174 bbls Class'G'in a 13-1/2"Hole 7-5/8" 72 bbls Class'G'in a 9-7/8"Hole 5-1/2" 23 bbls Class'G'in a 6-3/4"Hole Brcken Shaft STIMULATION DETAIL ' 2 . 3/11/2009-Frac k •I_ I i it r 7i r 106,8801bs of 16/20 Carbolite PIM . 3 60,8801bs behind pipe ,' afi i tof: It .; TREE&WELLHEAD 4 Tree Cameron 4-1/16"5M FMC '' MI 11"x 4-1/2"TC-B-EC w/4-1/2"Tubing Hanger 521 Hydril T&B Threads.4"CIW"H"BPV " 2 Wellhead Profile.Special seal sleeve machined @ BOT A 6 due to Hanger profile being too deep. *� it 6 r GENERAL WELL INFO 7-5/8 API:50-029-23406-00-00 Drilled and Completed by D-14&N-7ES -2/27/2009 ESP Completion by Nabors 3S-4/9/2009 _ ESP RWO by Nabors 4ES-9/10/2009 ESP RWO/install screen&cup Pkr by N-4ES-9/29/2009 ltuparuk'A'Sands ESP RWO install diverter valve by Nabors 4ES-1/14/2010 ESP RWO FCO&move ESP up hole by D-16-4/6/2011 Convert to TTC-ESP by Doyon 19-6/28/2012 Set new PSP TTC-ESP C/O slickline 1.6 wire-6/17/2014 5-1/2' .P.i TD=13,915'(MD)/TD=7,140'(1VD) PBTD=13,872'(MD)/PBTD=7,097(TVD) Created By:TDF 5/15/2015 Well: MPF-96II Milne Point Unit • PROPOSED Last Completed: 6/17/15 Hilcorp Alaska,LLA: PTD: 208-186 CASING DETAIL Orig.KBEto MSL=38.3'(Nabors 7ES) Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A 19.124 0 122' 20 • 10-3/4" Surface 45.5/L-80/Btc. 9.950 0 8,644' 7-5/8" Production 29.7/L-80/IBT-M 6.875 0 13,410' ' 1 5-1/2" Liner 17/L-80/BTC-M 4.892 13,209' 13,914' . TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441" 0 ±11,696' JEWELRY DETAIL No Depth Item 10-3/4" a 6 1 ±174' GLM 2 ±11,852' GLM 3 ±11,886' XN-Nipple 4 ±11,936' Discharge Head 5 ±11,937' Pump 6 ±11,956' Gas Separator 7 ±11,962' Tandem Seal Sections 8 ±11,676' Motor 9 ±11,692' PumpMate w/4 fin Centralizer-B :gym:±11,696' 10 13,209' BOT Flex Lock Liner Hanger&ZXP Liner Top Pkr w/ 4.75"ID PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 2 I A3 Sands 13,672' 13,682' 6,898' 6,908' 10 3/7/2009 Open 3 A2 Sands 13,688' 13,696' 6,914' 6,922' 8 3/7/2009 Open Al Sands 13,708' 13,740' 6,934' 6,966' 32 3/7/2009 Open I' 14 WELL INCLINATION DETAIL KOP @ 200' 5 Max Hole Angle=71.4 deg. @ 3,150' .1111 6 Hole Angle+66 Deg.From 2,600'to 12,050' 7 OPEN HOLE/CEMENT DETAIL 20" 43 bbls of Arcticset I in 42"Hole .,, \H 10-3/4" 843 bbls AS Lite,174 bbls Class'G'in a 13-1/2"Hole 6 7-5/8" 72 bbls Class'G'in a 9-7/8"Hole 5-1/2" 23 bbls Class'G'in a 6-3/4"Hole 5 STIMULATION DETAIL 9 3/11/2009-Frac 106,8801bs of 16/20 Carbolite . 60,8801bs behind pipe • TREE&WELLHEAD • Tree Cameron 4-1/16"5M FMC • El IA 10 11"x 4-1/2"TC-B-EC w/4-1/2"Tubing Hanger 7-5/8 Wellhead 521 Hydril T&B Threads.4"CIW"H"BPV Profile.Special seal sleeve machined @ BOT due to Hanger profile being too deep. GENERAL WELL INFO API:50-029-23406-00-00 Drilled and Completed by D-14&N-7ES -2/27/2009 Kupauk'A Sands ESP Completion by Nabors 35-4/9/2009 ESP RWO by Nabors 4ES-9/10/2009 ESP RWO/install screen&cup Pkr by N-4ES-9/29/2009 ESP RWO install diverter valve by Nabors 4ES-1/14/2010 ESP RWO FCO&move ESP up hole by D-16-4/6/2011 5-1/2"g Convert to TTC-ESP by Doyon 19-6/28/2012 TD=13,915'(MD)/TD=7,140'(1VD) Set new PSP TTC-ESP C/O slickline 1.6 wire-6/17/2014 PBTD=13,872'(MD)/PBTD=7,097'(ND) Created By:TDF 5/15/2015 11" BOP Stack r \ O O illillelliellkillik Hydril 11" 5M [."111-H - e Shaffer — 1 ISO 2:0_---41 2 3/8" Rams * — 210 -C\ ii" 5MGoe 27/85.5 _ variables Hydril co—, r 11" 5M p Blinds > Optional valve port 4�� M40 ':o: ] [ €;L :I I' ` STATE OF ALASKA AKA OIL AND GAS CONSERVATION COOISSION 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 208 - 186 . 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 ' 50 029 - 23406 - 00 - 00 Name n 7. Property Designation (Lease Number): 8. Well Na e a d Number: ADL 025509 & 355018 MPF - ' 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): . "� Milne Point Unit / Kuparuk River s , i :3 I-, 11. Present well condition summary Total depth: measured 13915 feet Plugs (measured) None feet true vertical 7140' feet Junk (measured) None feet Effective depth: measured 13872' feet Packer: (measured) None feet true vertical 7098' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 122' 20" 122' 122' 1490 470 Surface 8609' 10 -3/4" 8644' 3166' 5210 2480 Intermediate Production 13377' 7 -5/8" 13410' 6637' 6890 4790 Liner 705' 5 -1/2" 13209' - 13914' 6437' - 7101' 7740 6280 5.1-44141N ED AUG 1 6 LIl Perforation Depth: Measured Depth: 13672' - 13740' True Vertical Depth: 6898' - 6966' Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# L - 11996' 5521' Packers and SSSV (type, measured and true vertical depth): None 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): JUL 2 5 201Z Treatment description including volumes used and final pressure: AOOCC 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 480 107 310 280 258 Subsequent to operation: 14. Attachments: ❑C opies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory 0 Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 16. Well Status after work: — ® Oil ' ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564 -4387 N/A Printed Name Joe Lastufka Title Drilling Technologist Prepared By Name /Number: Signature ��pp. JUL J1L 27 L- q Phone 564 -4091 Date Joe Lastufka, 564 -4091 Form 10-404 Revised 11/2011 Fif DMS 0al�� jit ) 7 27 i2 mit Original Onlyi.:9,i P • Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/22/2012 18:00 - 21:00 3.00 RIGD P POST PREPARE RIG FOR MOVE - OPEN DOORS IN CELLAR - LAY MATS FOR STEP DOWN AND TURN RADIUS OF RIG - ALL TREE VALVES ARE CLOSED, BPV SET - 18:45 - LEAVE MESSAGE "UPDATE" ON AOGCC PHONE FOR BOP TEST 21:00 - 00:00 3.00 RIGD P POST PJSM ON RIG MOVE, DAY AND NIGHT TOOLPUSHERS AND WSL PRESENT, PAD OPERATOR NOTIFIED - MOVE OFF MPF -05 6/23/2012 00:00 - 02:00 2.00 MOB P PRE PJSM, RIG MOVE AND SPOT OVER WELL MOVE FROM MPF -05 AREA, AROUND PAD TO MPF -96 - ENSURE TREE VALVES ARE CLOSED, NOTIFY PAD OPERATOR - SPOT RIG OVER MPF -96 02:00 - 06:00 4.00 RIGU P PRE RIG. UP ON WELL - SHIM RIG FOR LEVEL - SPOT SLOP TANK, CHANGE TRAILER, AND FUEL TANK HARDLINE CREW R/D HARDLINE AND FLOW BACK TANK FROM MPF -05 - MOVE / POSITION FLOW BACK TANK 100 +' AWAY FROM RIG ON MPF -96 - HARDLINE CREW RIG UP HARDLINE TO FLOW BACK TANK, DID NOT TEST IT - HOOK UP KILL MANIFOLD HOSES - FILL PITS WITH SEAWATER - BEGIN LOADING PIPESHED WITH 4 1/2 TUBING - RIG ACCEPTED AT 05:00 HRS - IA = 400 PSI - OA= 100PSI 06:00 - 06:30 0.50 WHSUR P DECOMP HELD RIG EVACUATION DRILL - AAR: DISCUSSED HOW THE WIND DIRECTION HAS CHANGED OVER THE PAST FEW DAYS. - DISCUSSED UP COMING BOPE TEST TIME WITH AOGCC INSPECTOR CHUCK SCHEVE, AGREED TO GIVE UP DATE AGAIN AT 18:00 HRS 6/23/12. 06:30 - 08:00 1.50 WHSUR P DECOMP PJSM, M/U WELL SUPORT LUBRICATOR. - PRESSURE TEST 250 LOW / 3500 PSI FOR 5 CHARTED MINTES. - PULL 2" TYPE 'H' BPV. - R/D LUBRICATOR. - SITP = 100 PSI. - SICP = 380 PSI - OA =80 PSI Printed 7/9/2012 11:37:22AM Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 08:30 0.50 WHSUR P DECOMP PJSM WELL KILL - REVIEW DOYON WELL KILL SOP. - WSL, REVIEW WELL PLAN KILL AND WELL HISTORY. - ATTENDED BY BP RWO SUPERINTENDENT, TOOLPUSHER, WSL, CHECK 6, TRUCK DRIVERS, MUD MAN AND CREW. 08:30 - 16:00 7.50 WHSUR P DECOMP WSL AND TOOLPUSHER VERIFY ALL VALVE ALIGNMENT. - BLEED GAS FROM THE IA, THROUGH THE MANUAL CHOKE TO THE FLOW BACK TANK, MAINTAINING 100 - 150 PSI DOWN STREAM PRESSURE. - BLEED IA PRESSURE FROM 380 PSI TO 50 PSI, WITH NO FLUID RETURNS. - WSL AND TOOLPUSHER VERIFY ALL VALVE ALIGNMENT. - PUMP 75 BBLS KWF (120 DEG. SEAWATER) DOWN THE TUBING UP THE IA THROUGH THE MANUAL CHOKE TO THE FLOW BACK TANK. -ICP= 3 BPM /100 PSI FCP = 3 BPM / 550 PSI - OA PRESSURE INCREASED FROM 80 PSI TO 340 PSI. - CAUGHT FLUID WITH 42 BBLS PUMPED. - MAINTAINING 100 - 150 PSI DOWN STREAM PRESSURE. - CLOSE CHOKE AND BULL HEAD DOWN THE TUBING TH KWF_ - START BULL HEAD @ 3 BPM / 1900 PSI FINISH BULL HEAD @3 BPM/ 1300 -1450 PSI - WSL AND TOOLPUSHER VERIFY ALL VALVE ALIGNMENT. - CIRCULATE 3 TO 4 -1/2 BPM DOWN THE TUBING UP THE IA THROUGH THE CHOKE TO THE FLOW BACK TANK. - ICP = 3 BPM / 650 PSI TBG, 300 PSI ON THE IA, 150 PSI DOWN STREAM OF CHOKE. - FCP = WITH 2" OPEN CHOKE, 4 -1/2 BPM / 1800 PSI TBG, 100 PSI ON THE IA, 90 PSI DOWN STREAM OF CHOKE. - RETURN KWF = 8.44 PPG, 100 DEG SEAWATER. - PUMPED 777 BBLS, 8.5 PPG, 116 DEG SEAWATER. - MAINTAIN OA PRESSURE AT 400 - 500 PSI WITH MINOR BLEED OFFS - MONITOR WELL FOR 30 MINUTES, BOTH TBG AND IA ON A VACUUM. - 95 BBLS LOSS TO FORMATION - 405 BBLS CRUDE / DIESEL RECOVERED AND SENT TO RECYCLE Printed 7/9/2012 11:37:22AM s c s ° s s Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:00 1.00 WHSUR P DECOMP PJSM TO INSTALL AND TEST TWC - R/U DSM LUBRICATOR TO TREE - TEST LUBRICATOR AGAINST MASTER VALVE - 250 PSI, 3500 PSI, 5 MIN, CHARTED - INSTALL TWC R/D LUBRICATOR 17:00 - 19:00 2.00 WHSUR P DECOMP " TEST TWC - PERFORM ROLLING TEST FROM BELOW TWC - FINAL CIRC. RATE DURING TEST, 2 BPM = 540 PSt, 10 MIN, CHARTED - TOOK 42 BBLS TO FILL IA - TEST FROM ABOVE, 250 PSI, 3500 PSI, 5 MIN, CHARTED - R/D TEST EQUIPMENT 19:00 - 20:00 1.00 WHSUR P DECOMP R/D CELLAR LINES - BLOW DOWN AND R/D KILL MANIFOLD - R/D CELLAR LINES - CLEAN / CLEAR CELLAR FLOOR 20:00 - 21:30 1.50 WHSUR P DECOMP PJSM, N/D TREE, N/U BOP FMC VERIFY PRESSURE IS BLED OFF ADAPTER SEAL ✓ N/D TREE, SPLIT ADAPTER FROM TREE FOR TRANSPORT TO SHOP 21:30 - 00:00 2.50 BOPSUR P DECOMP PJSM, N/U 13 5/8" X 5M BOP STACK - R/U 4" AND 2 7/8" TEST JOINTS - CONTINUE LOAD PIPE SHED WITH 4 1/2" TUBING - MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH W/ 8.5 SEA WATER - TOTAL FLUID LOSS TO HOLE = 206 6/24/2012 00:00 - 01:00 1.00 BOPSUR P DECOMP PJSM, N/U BOPE - CONTINUE N/U BOP - 4 PREVENTER BOP, CONFIGURATION TOP TO BOTTOM = - ANNULAR PREVERTER, 2 7/8" X 5" VBR, BLIND SHEAR RAMS, MUD CROSS, 2 7/8" X 5" VBR'S, 13 5/8" X 11" ADAPTER 01:00 - 01:30 0.50 BOPSUR P DECOMP R/U TO TEST BOP - M/U 2 7/8" TEST JOINT - M/U FLOOR VALVE EQUIPMENT Printed 7/9/2012 11:37:22AM Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4 -OOWHP E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 06:00 4.50 BOPSUR P DECOMP TEST BOP'S AS PER DOYON TEST PROCEDURE �DP - TEST ALL BOPE AND CHOKE MANIFOLD VALVES TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES, CHARTED - TEST ANNULAR USING 2 7/8" TEST JOINT - TEST VBR PIPE RAMS USING 2 7/8" AND 4 1/2" TEST JOINTS - TEST BOTH SETS OF 2 7/8" AND 4" FLOOR VALVES - TEST USING FRESH WATER - PERFORM DRAW DOWN TEST ON ACCUMULATOR - 200 PSI INITIAL PRESSURE RECOVERY = 16 SECONDS - FULL PRESSURE RECOVERY = 92 SECONDS MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH W/ 8.5 SEAWATER CHUCK SCHEVE OF AOGCC CALLED AT 12:30 AM AND INSTRUCTED US TO PROCEED WITH TEST 06:00 - 06:30 0.50 BOPSUR P DECOMP R/D TEST EQUIPMENT BLOW DOWN TOP DRIVE AND CHOKE MANIFOLD - M/U SAFETY JOINT. 06:30 - 09:30 3.00 WHSUR P DECOMP PJSM, PU / MU OPSO LOPSO LUBRICATOR EXTENSION AND INSTALL PUMP IN SUB. - M/U AND PRESSURE TEST WELL SUPPORT LUBRICATOR - 250 LOW AND 3500 PSI, CHARTED BOTH FOR 5 MINUTES. - PULL 2" TYPE 'H' BPV - TUBING ON A VAC. 09:30 - 10:30 1.00 WHSUR P DECOMP PJSM, M/U 2 7/8" LANDING JOINT WITH CLOSED FOSV. - WSL VERIFY NO TRAPPED PRESSURE UNDER HANGER. - FMC REP BOLDS. - 1. PULL TBG HANGER OFF SEAT AT 112 K - 2. MAX PULL 135 K, PUW = 125K, SOW = 60K, INCLUDES 40K BLOCK WT. - 3. CUT ESP CABLE AT —35 FT (AT FIRST CLAMP) SECOND CUT AT TBG HANGER. - 4. BRAKE OUT AND L/D TBG HANGER - 5. M/U SAFETY JOINT WITH FOSV. - 6. POSITION SAFETY JOINT ACROSS BOPE AND CLOSE ANNULAR PREVENTERS. - TIMED OPERATION TOOK 14 MINUTES, FROM HANGER OFF SEAT TO WELL SHUT IN. Printed 7/9/2012 11:37:22AM y Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 14:00 3.50 PULL P DECOMP CBU AT 4.5 BPM / 1790 PSI - RETURNS TO SURFACE AFTER 40 BBLS PUMPED. - CIRCULATED 360 BBLS, 8.5 PPG SEAWATER THROUGH THE GAS BUSTER - NO OIL OR GAS NOTED DURING CIRCULATION. LOST 48 BBLS TO THE FORMATION DURING CBU. - MONITOR WELL ON A VACUUM FOR 10 MINUTES. - WSL VERIFY NO TRAPPED PRESSURE - ANNULAR PREVENTOR WAS THEN OPENED. - DRILLER VISIBILITY VERIFIED ANNULAR WAS OPENED. 1 14:00 - 17:30 3.50 PULL P DECOMP PJSM, POH FROM 12,586' MD, W / ESP ON 2 -7/8" 8RD, EUE=TUBING. - STAND BACK IN DERRICK. - MAINTAIN20 BPH HOLE FEED WITH 8.5 PPG SEAWATER, WITH NO RETURNS. 17:30 - 18:30 1.00 PULL P DECOMP CONDUCT TRIP WHILE TRIPPING DRILL W/ ESP CABLE - HOLD AAR WITH CREW AND WSL 18:30 - 00:00 5.50 PULL P DECOMP CONTINUE POOH W/ 2 7/8" ESP COMPLETION TO 1848' MD - MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH W/ 8.5 SEA WATER - TOTAL FLUID LOSS TO HOLE = 514 BBLS 6/25/2012 00:00 - 03:00 3.00 PULL P DECOMP PJSM, SPCC CHECKS - CONTINUE TO POH WITH 2 7/8" ESP COMPLETION FROM 1848' TO 133' - BROKE OUT XN NIPPLE AND PULLED PIN OUT OF BOX AND 2 GALLONS OF OILY MUD AND SAND DRAINED OUT OF THE BOTTOM OF THE PIN ONTO THE RIG FLOOR - GAS MONITOR REVEALED ZERO LEL - DECIDED TO PUNCH LAST FULL JOINT AND PUP ABOVE MOTOR 03:00 - 04:00 1.00 PULL P DECOMP PJSM FOR PUNCHING PIPE - PUNCHED PIPE ABOVE AND BELOW CONNECTION - NO PRESSURE WAS OBSERVED AND VERY LITTLE DRAINAGE OF SAND - LAID DOWN JOINTS TO PIPE SHED - 1 JOINT = 10' PLUGGED WITH SAND - 1 JOINT =15' PLUGGED WITH SAND - WILL LEAVE IN PIPE SHED FOR OBSERVATION AND DRAINAGE Printed 7/9/2012 11:37:22AM • Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table ©38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 06:00 2.00 PULL P DECOMP PJSM, LID ESP MOTOR ASSEMBLY PER CENRILIFT REP - CENTRILIFT PROCEDURE WILL DRAIN AND RELEASE ANY PRESSURE IN PUMP OR MOTOR - DISCONNECT ESP CABLE AND SPOOL UP ON REEL - INSPECT AND UD ESP MOTOR AND PUMP ASSEMBLY - ESP FAILURE DUE TO SAND AND TWISTED SHAFT ON UPPER PUMP - FEED 20 BPH WITH NO RETURNS 06:00 - 07:30 1.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR -PJSM, R/D ESP CABLE SHEAVE FROM DERRICK. 07:30 - 08:00 0.50 WHSUR P DECOMP PJSM, INSTALL WEAR RING - WEAR RING ID = 7 1/16" 08:00 - 10:30 2.50 CLEAN P DECOMP P/U 3 JTS 2 -7/8" TBG AND STAND IN DERRICK. - LOAD AND STRAP 4" DP INTO PIPE SHED. P/U AND RIH AND RACK IN DERRICK 16 STANDS 4" DP. 10:30 - 12:00 1.50 __ CLEAN P DECOMP _ P/U M/U 2 -7/8" MULE SHOE JT = 25.00' LONG. - RIH FROM DERRICK 2 -7/8" TBG - TO 3290' MD. 12:00 - 12:30 0.50 CLEAN P DECOMP PJSM, PERFORM PRE -TOUR CHECKS - SERVICE TOP DRIVE 12:30 - 18:00 5.50 CLEAN P DECOMP CONTINUE RIH WITH 2 -7/8" MULE SHOE ON 2 -7/8" TBG FROM DERRICK - FROM 3290' TO 12524' MD. - 105K PUW. 60K SOW. - CROSS OVER TO 4" DRILL PIPE. - MAINTAIN CONTINUOUS HOLE FEED (8.5PPG SEAWATER) AT 20 BPH WITH OUT RETURNS. 18:00 - 20:00 2.00 CLEAN P DECOMP PJSM, CUT AND SLIP DRILLING LINE - CUT AND SLIP 200 FT. 1.25 DRILLING LINE. - CLEAN AND INSPECT INSIDE DRAW WORKS. 20:00 - 00:00 4.00 CLEAN P DECOMP CONTINUE TO RIH /WASH WITH CLEAN OUT ASSEMBLY. - WASH DOWN FROM F/ 12524' TO TOP OF LINER AT 13209' MD - 2 BPM = 290 PSI, SEEING RETURNS - PUMPED 2) 10 BBL SWEEPS OUT THE END OF MULE SHOE WHILE WASHING DOWN - DID NOT SEE TAG AT TOP OF LINER - PUWT = 112K, SOWT = 70K BEFORE ENTERING LINER TOP - TOTAL FLUID LOSS TO HOLE = 402 BBLS 6/26/2012 00:00 - 01:00 1.00 CLEAN P DECOMP PJSM, ON RIH, PUMPING SWEEPS, REVERSE CIRC DURING CLEAN OUT. - M/U FOSV AND PUMP IN SUB - CLOSE ANNULAR - REVERSE CIRCULATE PIPE VOL. AND SWEEP VOL. UNTIL CLEAN RETURNS - 4 BPM = 740 PSI - SWEEPS DID NOT BRING UP ANY SAND AT BOTTOMS UP Printed 7/9/2012 11:37:22AM • • # : • lift4B,71,ftlaimf,480V4441107a005416MArld.1114:15,>,44/740"45,,ri7oVe 1;4 Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 03:00 2.00 CLEAN P DECOMP CONTINUE WASH IN HOLE - FNTER 5 1/2" LINER TOP AT 13209', DID NOT TAG TOL - CONTINUE TO WASH DOWN F/ 13209' T/ 13820' - PUMPED 2) 10 BBL SWEEPS OUT THE END OF MULE SHOE WHILE WASHING DOWN - 1.5 BPM = 250 PSI - PUWT = 125K, SOWT = 75K 03:00 - 04:30 1.50 CLEAN P DECOMP M/U FOSV AND PUMP IN SUB AND CLOSE ANNULAR - REVERSE CIRCULATE PIPE VOL. AND SWEEP VOL. FROM BACK SIDE UNTIL CLEAN - 4 BPM = 74Q PS1 - OBSERVE A GOOD AMOUNT OF FRAC SAND AT BOTTOMS UP, -3 BBLS. - CLEAR SWEEPS FROM HOLE 04:30 - 05:00 0.50 CLEAN P DECOMP OPEN ANNULAR, MONITOR WELL - WASH IN HOLE F/ 13820' TO HARD TAG AT 15858' 05:00 - 06:00 1.00 CLEAN P DECOMP M/U FOSV AND PUMP IN SUB AND CLOSE ANNULAR - REVERSE CIRCULATE 1 PIPE VOLUME AT 13858' MD 4 BPM = 740 PSI - VERY LITTLE SAND NOTED AT SHAKER. - WSL / DRILLER VERIFY NO TRAPPED PRESSURE UNDER ANNULAR BOP. - ANNULAR BOP VERIFIED OPEN BY DRILLER. - MONITOR WELL FOR 15 MINUTES ON A VERY SLIGHT VACUUM. - BLOW DOWN TOP DRIVE & LINES. 06:00 - 08:30 2.50 CLEAN P DECOMP PJSM, POH / LD 4" DP, F/ 13858' MD WITH 2 -7/8" MULE SHOE T/ LINER TOP - LINER TOP @ 13209' MD. - L/D 16 JTS. T/13200' MD. - MONITOR WELL FOR 10 MINUTES, ON A SLIGHT VACUUM. 08:30 - 12:00 3.50 CLEAN P DECOMP CONTINUE POH WITH 2 -7/8" MULE SHOE AND L/D 1X1 TO PIPE SHED. - F/ 13200' MD T/ 9400' MD. - 18 BPH LOSS RATE WITH 8.4# SEAWATER. - LOSSES TO WELL LAST 12 HRS. = 405 BBLS. 12:00 - 12:30 0.50 CLEAN P DECOMP PJSM, CREW CHANGE, - PERFORM PRE -TOUR CHECKS - SERVICE TOP DRIVE. 12:30 - 22:00 9.50 CLEAN P DECOMP CONTINUE POH LJD 2 7/8" TBG 1X1 TO PIPE SHED. - F/ 9400' MD - L/D MULE SHOE. - STATIC LOSS RATE = 10.8 BPH. 22:00 - 23:00 1.00 RUNCOM P RUNCMP CLEAR AND CLEAN RIG FLOOR. - PULL WEAR RING. - RIG UP POWER TONGS AND 4.5" TBG HANDLING EQUIPMENT. Printed 7/9/2012 11:37:22AM Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4 OOWHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table ©38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations P P P (hr) (ft) 23:00 00:00 1.00 RUNCOM P RUNCMP PRESSURE TEST 5" FOSV TO 250/3500 PSI 5 MIN EACH. - M/U 4 1/2" LANDING JT WITH X/O AND TESTED FOSV. - LOSSES TO WELL LAST 12 HRS. = 156 BBLS 8.4 PPG KWF. LOSSES TO WELL LAST 24 HRS. = 561 BBLS 8.4 PPG KWF. 6/27/2012 00:00 02:00 2.00 RUNCOM P RUNCMP PJSM, M/U 4.5" LANDING JT. WITH FOSV. - CHECK CERTS ON CENTRALIFT SHEAVE TO CONFIRM CURRENT. - HANG ESP SHEAVE IN DERRICK, - MONITOR WELL. - STATIC LOSS RATE= 13 BPH. SEAWATER 02:00 02:15 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. 02:15 - 04:30 2.25 RUNCOM P RUNCMP P/U ESP MOTOR ASSEMBLY AS PER CENTRALIFT REP. - CENTRALIZER, PUMP MATE SENSOR, KMHG 190 HP MOTOR, LOWER AND UPPER TANDEM SEALS, TTC DRILLED TBG X/O. - FILL PUMP WITH MINERAL OIL AS PER CENTRALIFT REP. - INSTALL 2 FG CLAMPS, 3 PROTECTOLIZERS. 04:30 - 12:00 7.50 RUNCOM P RUNCMP PJSM, RUN TT -ESP COMPLETION ON DRIFTED 4 -1/2" IBT -M, 12.6#, L -80 TUBING - FROM PIPE SHED 1X1. - EVERY 30 JOINTS, FILL AND FLUSH MOTOR, CENTRILIFT CHECK CONDUCTIVITY OF ESP CABLE. - SPOOLING ESP CABLE. - INSTALL CANNON COLLAR CLAMPS ON EVERY JT. - BEST OF LIFE 2000 THREAD COMPOUND. - USE CONTINUOUS HOLE FILL WITH 8.4 PPG KWF. - 13 BPH LOSS RATE. - AVERAGE MAKE -UP TO THE DIAMOND WAS 3000 FT /LB TQ. - M/U #1 JOINT AT 0430 HRS. - WSL DISCUSSED WELL CONTROL AND USE OF IBT -M SEAL RINGS. - F/ JOINT# 1 T/ JOINT # 90 —3700' MD. - FILL AND FLUSH, 3 BPM / 70 PSI. - LOSS RATE AT 10 BPH WITH CONTINUOUS HOLE FILL, 8.4# SEAWATER. - LAST 12 HRS LOST 124 BBLS KWF. 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM, PERFORM PRE -TOUR CHECKS. - INSPECT TUBING HANDLING EQUIPMENT. Printed 7/9/2012 11:37:22AM 4 a a Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 20:30 8.00 RUNCOM P RUNCMP PJSM, RUN TT -ESP COMPLETION ON DRIFTED4 -1/2" IBT -M, 12.6#, L -80 TUBING - FROM PIPE SHED 1X1. - EVERY 30 JOINTS, FILL AND FLUSH MOTOR, CENTRILIFT CHECK CONDUCTIVITY OF ESP CABLE. - F/ JOINT # 90 T/ JOINT # 180 AT 7244' MD. P/U WT= 100K. S/O WT= 75K. 20:30 - 00:00 3.50 RUNCOM P RUNCMP CENTRILIFT REP MAKE ESP SPLICE AT 7500' MD. - SECURE SPLICE IN MIDDLE OF JT # 187 AT 7500' MD - PUMP 3 BPM AT 90 PSI AND FLUSH FLUSH MOTOR. PUMP 5 BBLS. - CENTRILIFT CHECK CONDUCTIVITY OF ESP CABLE AFTER SPLICE. - INSTALL 1 CANNON LONG SPLICE CLAMP. LOSSES TO WELL LAST 12 HRS= 98 BBLS 8.4 PPG KWF. LOSSES TO WELL LAST 24 HRS= 222 BBLS 8.4 PPG KWF. 6/28/2012 00:00 - 07:30 7.50 RUNCOM P RUNCMP CREW CHANGE. PJSM - CONTINUE TO RUN TT -ESP COMPLETION ON DRIFTED 4 -1/2" IBT -M, 12.6 #, L -80 TUBING - FROM PIPE SHED 1X1. - EVERY 30 JOINTS, FILL AND FLUSH MOTOR, CENTRILIFT CHECK CONDUCTIVITY OF ESP CABLE. - F/ JOINT # 187 AT 7500' MD. TO 11996' MD. - USE CONTINUOUS HOLE FILL WITH 8.4 PPG KWF. - PUMPED A TUBING VOLUME TO FLUSH MOTOR ASSEMBLY. 07:30 - 08:00 0.50 RUNCOM P RUNCMP PJSM, MU PUP, TBG HANGER - FMC REP INSTALL 4" TWC - PU 4 -1/2" HYDRIL 521 LANDING JT AND MU TO TBG HANGER. - ORIENT HANGER PER FMC REP. - STATIC LOSS RATE = —12 BPH. 08:00 - 10:00 2.00 RUNCOM P RUNCMP CENTRILIFT REP TERMINATE ESP CABLE TO HANGER. - CONTINUOUS HOLE FILL - CONDUCTIVITY TEST PASSED. 10:00 - 11:00 1.00 RUNCOM P RUNCMP PJSM, CENTRILIFT, FMC, WSL, TOOLPUSHER AND CREW. - LAND TBG HANGER. - PUW = 198,000 #, SOW = 70,000 #, INCLUDES 40,000# BLOCK WT. - FMC REP RILDS. - LAND ESP COMPLETION © 11996.19' - INSTALLED TOTAL 290 CANNON CLAMPS. - 2 FLAT GUARDS - 1 HALF CLAMP Printed 7/9/2012 11:37:22AM • Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:00 1.00 RUNCOM P RUNCMP PJSM, PERFORM ROLLING PRESSURE TEST. FROM BELOW TWC - TO 500 PSI FOR 10 CHARTED MINUTES. - 1 BPM / 500 - 600 PSI. PASSED. - PUMPED 28 BBLS 8.45 PPG SEAWATER. - PRESSURE TESTED TWC FROM ABOVE - 250 LOW AND 3500 PSI FOR 10 CHARTED MINUTES. PASSED. 12:00 - 13:30 1.50 RUNCOM P RUNCMP PJSM, N/D BOPE BLOW DOWN ALL LINES AND VALVES. - R/U TO FILL THE IA.. - 15 BPH CONTINUOUS HOLE FILL THROUGH THE IA. - N/D RISER AND INSTALL BOWL SAVER 13:30 - 14:00 0.50 RUNCOM P RUNCMP N/D 13 5/8" 5M BOPE - SET BACK BOP STACK. 14:00 - 15:45 1.75 RUNCOM P RUNCMP NU FMC TREE ADAPTER FLANGE: 11" 5M X 4 1/16 5M. - THE TBG HANGER SEAL SLEEVE WAS TO SHORT FOR PROPER M/U - BETWEEN THE HANGER AND TREE ADAPTER FLANGE, .9" TO SHORT. - AT 1540 HRS DISCUSSED PLAN FORWARD WITH RWO ODE AND RWO SUPERINTENDENT. 15:45 - 20:30 4.75 WHSUR N SFAL RUNCMP WAIT ON FMC TO MACHINE NEW TBG HANGER SEAL SLEEVE. - USE CONTINUOUS FILL WITH 8.4 PPG KWF DOWN VA WITH CHARGE PUMP AND BYPASS. - MONITOR HOLE FILL, WELL TAKING 15 BPH. - NEW TBG HANGER SLEEVE ON LOCATION AT 20:15 - INSTALL NEW TBG HANGER SEAL SLEEVE. - SET FMC 11" 5M X 4 1/16" 5M TREE ADAPTOR FLANGE IN PLACE. - OFF NPT AT 20:30 HRS. - 24 HR NOTIFICATION GIVEN TO AOGCC FOR INITIAL BOPE TEST ON MPF -37 AT 18:00. - AOGCC BOB NOBLE. 20:30 - 22:00 1.50 WHSUR P RUNCMP PJSM. WITH FMC REP AND CREW. - N/U ADAPTOR FLANGE, TBG HEAD ADAPTOR AND TREE. Printed 7/9/2012 11:37:22AM Common Well Name: MPF -96 AFE No Event Type: WORKOVER (WO) Start Date: 6/15/2012 End Date: X4- 00WHP -E: (2,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:00AM Rig Release: 6/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: Kelly Bushing / Rotary Table @38.30ft (above Mean Sea Level) Date From - To Hrs (hr) Task Code NPT NPT (ft) Depth Phase Description of Operations 22:00 - 00:00 2.00 WHSUR P RUNCMP PJSM, FMC TEST ADAPTOR SEALS AND HANGER VOID - PRESSURE TEST TO 250 PSI 5 MIN, 5000 PSI FOR 30 MIN. -- CENTILIFT PERFORM ESP CONDUCTIVITY PHASE TO PHASE AND PHASE TO GROUND FINAL TEST. PHASE TO GROUND= 801M, PHASE TO PHASE= 3.4, PHASE A TS= 12, PHASE B VOLTS= 6, PHASE G VOLTS 12, - SEE ATTATCHMENT FOR WELL LIFT I INSTALLATION SHEET. L AGAINST TWC TO 250/5000 PSIS TREEWIT MIN EACH - CHART TEST RECORD TESTS . LOSSES TO WELL 00 - 00:3 LAST = KWF. - LOSSES TO WELL LAST 24 12 HRSHRS= 63 198 BBLS BBLS 8.4 8.4 PPG PPG KWF. 6/29/2012 00:0 0.50 WHSUR P RUNCMP CREW CHANGE. CHECK EQUIPMENT. CONTINUE TO TEST TREE TO 5000 PSI 5 MIN. CHART RECORD TEST. 00:30 01:00 0.50 WHSUR P RUNCMP PJSM CR EW, CHECK EQUIPMENT CER AND TS. M/U AND TEST LUBRICATOR AGAINST MASTER VALVE TO 250/3500 PSI 5 MIN EACH CHART RECORD S. OPEN MASTER VALVE. PULL TWC. CLOSE MASTER TEST VALVE. TEST LUBRICATOR TO 250/3500 PSI 5MIN EACH, CHARTED. 8.4 PPG TESTED MASTER VALVE. - R/DTWC. - CLEAN PITS. 01:00 02:30 1.50 WHSUR P RUNCMP M/U BPV. TEST KWF AND LUBRICATOR AGAINST V TO 5 MIN EACH CHARTE MASTER D. ALVE OPEN MASTER VALVE. 250/3500 SET BPV. 02:30 - 03:00 0.50 WHSUR P RUNCMP OPEN WING VALVE AND WHITEY PSI VALVE. - PERFORM ROLLING PRESSURE TEST UNDER BPV. PUMP 1.5 BPM 680 PSI. MONITOR WING VALVE FOR FLUID. - PUMP 29 BBLS TEST. AWAY FOR 10 MIN ROLLING TEST, CHART TEST. - PASSING 2 BARRIERS- 8.4 PPG KWF AND TESTED BPV. - R/D LUBRICATOR. - CE VV RIG LOS ELEASED A AND FROM MPF -96 VALES. AT 03:00 HRS. 11:37:21AM Printed 7/9/2012 Tree: 4 1/16" - 5M FMC BE to MSL = 38.3' (N 7ES) Wellhead: 11" x 4 1/2 "" TC - mp F.96 L Elev. to MSL= w/ 4 1/2" Tubing Hanger Han 521 Hydril T &B O rig. RT - GL = 27.7' Y Orig. RT - BF = 27.3' Threads. 4" CIW "H" BPV profile Orig. RT - LDS = 25.05' I Special seal sleeve machined @ BOT due to Hgr profile being too deep. I j 20" 91.1# H -40 122` SLB 4 1/2" x 1" KBMG GLM ( 174' KOP @ 200' Max hole angle = 71.4° @ 3150 + 66° from 2600' to 12050' 10.75" 45.5# L -80 BTC casing 1 8644' • Vi D &D Tbg Stop 1 11915' D &D Packoff Assy Top 1 11917' Kobe Knockout Sub 1 11920' 4 1/2" 12.6 ppf, L -80 IBT -M (drift ID = 3.833 ", cap = 0.0152 bpf) Centrilift TTC -ESP Top ( 11925'1 7.625" 29.7# L -80 IBT -M casing (drift ID = 6.750 ", cap = 0.0459 bpf) (cap w/ 4 1/2" Tbg inside = 0.0262 bpf) 5.5" 17# L -80 BTC -M Liner (drift ID = 4.653 ", cap = 0.0232 bpf) `- TTC Drilled Tbg Crossover 1 11951' i Tandem Seal Sections F I Model GSB3 DB UT /LT HL H6 PFS 1 11962' JUL Motor, 55 HP, 1259 volt, 1 11976' Stimulation Summary: Not 26 amp, Model KMHA imi 3/11/09 - Frac 106880# of 16/20 Carbolite 60880# behind pipe PumpMate w/ 4 fin Centralizer 1 11992' PumpMate = 5520' TVD BOT Flex Lock Lnr Hgr & ZXP Lnr Top 13,209' Pkr w/ 4.750" ID Seal Bore Extension 75/8" Float Collar 1 13,390` A ■ Perforation Summary Size SPF Interval TVD 3 1/2" 6 13,672 - 13,682' 6,898' - 6,908' 3 1/2" 6 13,688' - 13,696' 6,914' - 6,922' • 3 1/2" 6 13,708 - 13,740' 6,933' - 6,965' FCO to 13858' during 4/6/11 RWO 51/2" Float Collar (PBTD) 113,872' 51 /2" Float Shoe 3,914'1 DATE REV. BY COMMENTS MILNE POINT eU�+NIT 2/27/09 L. Hulme Drilled & Completed (D -14 & N -7ES) WELL M P F _96 4/9/09 REH ESP completion Nabors -3S 9/10/09 REH ESPRWO- Nabors4ES API NO: 50- 029 - 23406 -00 9/29/09 REH ESP RWO /install screen & cup PKR - N 4ES 1/14/10 Hulme ESP RWO /install diverter valve - N 4ES 4/6/11 Hulme ESP RWO FCO & move ESP up hole - D -16 6/28/12 Hulme Convert to TTC -ESP - Doyon -16 BP EXPLORATION (AK) bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 =.. Post Office Box 196612 ' Anchorage, Alaska 99519 -6612 FEB I ZWZ December 30, 2011 1? I gb Mr. Tom Maunder )3D ' r_ Alaska Oil and Gas Conservation Commission I IC) 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF -41 1970950 50029227700000 0.8 N/A OS N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF -62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 , 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF-96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 STATE OF ALASKA _ ALAS AND GAS CONSERVATION COMMIS REPOR OF SUNDRY WELL OPERA 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing El Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory — 208 - 186 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 -- 50 - 029 - 23406 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 025509 & 355018 — MPF - 9. Field / Pool(s): — Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 13915' feet Plugs (measured) None feet true vertical 7140' feet Junk (measured) None Effective depth: measured 13872' feet Packer: (measured) None feet true vertical 7098' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 122' 20" 124' 124' 1490 470 Surface 8609' 10 -3/4" 8644' 3166' 5210 2480 Intermediate Production 13377' 7 -5/8" 13410' 6637' 6890 4790 Liner 705' 5-1/2" 13209' - 13914' 6437' - 7101' 7740 6280 . MIRY 0 3 2011 Perforation Depth: Measured Depth: 13672' - 13740' True Vertical Depth: 6898' - 6966' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L - 12586' 5863' Packers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: RECEIVED) Intervals treated (measured): Treatment description including volumes used and final pressure: Aleska Gil & Gas Cans. Commission fncrwatgr 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure 1 Prior to well operation: 452 54 242 320 279 Subsequent to operation: 464 60 300 300 276 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory .- ® Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Ryan Ciolkosz, 564-5977 N/A Printed Name Terrie Hubble Title Drilling Technologist /�j / epared Nme/Num Signature Phone 564-4628 Date �1 ' 'j t Terrie Pr Hubbl a e 564 4628 Form 10-404 Revised 10/2010 s-,2 /1 -' ubmit Original Only RBDMS APR 2 9 2011 W • 0 North America - ALASKA BP Page ta Operation Summary: Report ' Common Well Name: MPF -96 I AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2011 I End Date: 4/7/2011 X4- 00T6K -E: (800,000.00 ) i Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:OOAM Rig Release: 4/7/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: 10.6'CB +34.3•KB @44.9' @44.90ft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT ' NPT Depth Phase Description of Operations (hr) (ft) 3/31/2011 06:00 - 10:00 4.00 RIGD P POST R/D AND LOWER DERRICK 1 -PREP FOR RIG MOVE. I t 10:00 - 12:00 2.00 RIGD P POST MOVE OFF MPL -43 WITH WSL, PAD OPERATOR AND TOOLPUSHER PRESENT. -MOVE AROUND TO FRONT OF PAD. i_ - REMOVE BOPE STACK FOR MOVE. 12:00 14:00 2.00 MOB P PRE LPJSM: MOVE TO MPF PAD. f 14:00 - 16:00 2.00 MOB P PRE RAISE DERRICK & SECURE PINS. 16:00 - 00:00 ! 8.00 MOB P PRE , RECONFIGURE BOP STACK W/ SINGLE GATES. BRIDAL DOWN. SECURE RIG FLOOR. -INSPECT INSIDES OF HYDRAULIC SUPER & MANUAL CHOKES. I FLOOR. 1 RIG.UPRG 4/1/2011 00:00 - 05 :00 5.00 MOB p PRE ''CONTINUE TO RECONFIGURE STACK TO SINGLE GATE W/ 2 -7/8" x 5" RAMS. -SET HERCULITE & RIG MATS. 105:00 - 09:00 4.00 MOB P PRE MOVE OVER WELL MPF -96 WITH WSL AND ', TOOLPUSHER PRESENT. _1-CREW CHANGE, PJSM. 09:00 10:30 1.50 MOB P PRE SPOT CUTTING BOX AND FUEL TRAILER. -FLOW BACK TANK. ' "HELD RIG EVACUATION DRILL 10:30 11:00 0.50 RIGU P PRE ALL PERSONAL RESPONDED PLUS 3 THIRD PARTY WORKERS. ' -PAD OPERATOR NOTIFIED. -AAR: ONE WORKER WAS NOTIFIED INSIDE THE CHANGE TRAILER DURING THE DRILL, BECAUSE THE COMMUNICATION SYSTEM WAS NOT HOOKED UP YET. -SECURE CELLAR, BERM AROUND RIG. SPOT FLOW BACK TANK. 11:00 - 12:00 1.00 RIGU P PRE � CLEAR, CLEAN & PREPARE RIG. -T /I /O = 200/300/0 12:00 - 14:00 2.00 WHSUR P DECOMP START TAKING ON FLUID. ACCEPT RIG @ 12:00HRS. ✓ -RIG UP CELLAR. CLEAR & WARM LINES W/ STEAM. -BLOW AIR TO FLOW BACK TANK. -PT LINES TO 3500 PSI UPSTREAM AND 500 I PSI DOWN STREAM OF CHOKE. 14:00 - 17:00 3.00 WHSUR P DECOMP R/U & TEST LUBRICATOR. 250 PSI LOW & 1800 PSI HIGH PRESSURE. -CLEAR CIRCULATING LINES W/ STEAM. -BLOW THROUGH LINES TO FLOW BACK TANK W/ AIR. -PT LINES 3500 PSI UPSTREAM & 500 PSI DOWNSTREAM OF CHOKE. -TEST FOR 5 MINUTES EACH. PULL BPV. 1-RID LUBRICATOR. Printed 4/25/2011 11:05:56AM ,orthAmerica-ALASKA- o € , Operation: Summate Report Common Well Name: MPF -96 l AFE No Event Type: WORKOVER (WO) I Start Date: 3/31/2011 I End Date: 4/7/2011 1X4- 00T6K -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:OOAM Rig Release: 4/7/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: 10.6'CB +34.3'KB @44.9' @44.90ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) -- 17:00 - 19:30 2.50 WHSUR P I DECOMP I BLEED OFF GAS CAP FROM 300 PSI TO 100 PSI. -CIRC 76 BBLS OF SEAWATER DOWN TBG. RETURNS TO FLOW BACK TANK. I- PUMP3 BPM /350 -520 PSI. I 1 i -f3lJl I HFAn 75 FIR' S OF SEAWATER I � I II I I -PUMP @ ICP= 3 BPM / 820 PSI, FCP= 5 BPM / 2950 PSI. -BLEED BACK SLOW, 0 BBLS BACK. 19:30 - 23:00 3.50 I WHSUR P�, L DECOMP `LINE UP TO FLOW BACK TANK. CIRCULATE 756 BBLS OF SEAWATER. I -ICP= 3 BPM / 460 PSI. FCP= 5 BPM / 1510 PSI. I I -CLEAN SEAWATER TO SURFACE. WELL t I � I TOOK +/- 294 BBLS. 1 -SHUT DOWN & MONITOR WELL FOR 20 MINUTES. -HOLE TAKING 16BPH. C , R. R/D CIRCULATING LINES 23:00 - 00:00 1.00 WHSUR p , � DECOMP BLOW DOWN. AA R. SQUEEZE MANIFOLD. -RN TO FILL IA. 4/2/2011 00:00 - 01:00 1.00 WHSUR ' P DECOMP I CONTINUE TO R/D CIRCULATING LINES. 1 [ -R/U LINE TO FILL IA.. 01:00 04 :00 3.00 WHSUR 1 P DECOMP R/U & TEST LUBRICATOR. 250 PSI LOW & 1800 PSI HIGH PRESSURE. -TEST F/ 5 CHARTED MINUTES EACH - OK. - INSTALL TWC. TEST FROM ABOVE TO 3500 1 PSI F/ 10 CHARTED MINUTES. -TEST TWC FROM BELOW 500 PSI ROLLING 'TEST I -PUMP FOR 32 BBLS 3 BPM / 500 PSI.. 1 04:00 - 04:30 0.50 WHSUR P DECOMP j BLEED WELL TO ZERO. - MONITOR WELL. PJSM. 04:30 - 05:00 0.50 WHSUR r P , DECOMP 1 N/D TREE & ADAPTOR 05:00 - 09:00 4.00 WHSUR ' P DECOMP I N/U BOPE - GREASE CHOKE MANIFOLD VALVES. _ - FUNCTION TEST BOPE. 09:00 - 21:30 12.50 WHSUR P 1 DECOMP 'TEST BOPE. 250 PSI LOW, 3500 PSI HIGH PRESSURE. -ALL TESTS FOR 5 CHARTED MINUTES. I -TEST W/ 2 -7/8" & 4" TEST JTS. I -TEST WITNESSED BY: JEFF JONES- AOGCC, WSL W L & DDI TP. -CHOKE HCR FAILED / CHANGED OUT. -TOP DRIVE UPPER & LOWER IBOP FAILED / ISO CHANGE OUT. -HCR CHOKE & HYDRAULIC CHOKE FAILED / CHANGE OUT. PERFORM ACCUMULATOR DRAW DOWN I TEST. I -JEFF JONES AOGCC WILL COME BY IN AM & WITNESS RETEST. 21:30 00:00 2.50 WHSUR N RREP 1 DECOMP 1AAR. PJSM. - REMOVE SAVER SUB / LOWER IBOP. 4/3/2011 00:00 - 03:30 3.50 WHSUR N RREP DECOMP I CONTINUE TO CHANGE OUT LOWER & UPPER IBOP. I - REPLACE SEAT & PLUNGER FROM THE HYDRAULIC CHOKE. -16 -20 BPH LOSS RATE WITH CONTINUOUS HOLE FEED. (SEAWATER) Printed 4/25/2011 11:05:56AM , 9rthAmeFica..ALA$KA BP^ ` P 3 a 6 Opera Summa; Report Common Well Name: MPF -96 I AFE No Event Type: WORKOVER (WO) ! Start Date: 3/31/2011 End Date: 4/7/2011 X4- 00T6K -E: (800,000.00 ) I Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:OOAM Rig Release: 4/7/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: 10.6'CB +34.3'KB @44.9' @44.90ft (above Mean Sea Level) Date From - To 1 Hrs Task Code NPT l NPT Depth jl Phase I Description of Operations (hr) (ft) 03:30 - 04:00 0.50 WHSUR N DECOMP ,TEST HYDRAULIC CHOKE TO 1500 PSI. -TEST UPPER & LOWER IBOP. -TEST CHARTED TO 250 PSI LOW, 3500 PSI 1 HIGH PRESSURE. 04:00 - 05:00 1 1.00 WHSUR N DECOMP FINISH INSTALLING ROLLERS & RUBBER GUIDE ON TOP DRIVE. — -- - - - - -- — - -- 05:00 - 09:00 4.00 WHSUR P DECOMP ; INSTALL 2 -7/8" RISER WITH OTIS CONN. -P /U & TEST LUBRICATOR. 250 PSI LOW / 13500 PSI HIGH PRESSURE. 1-PULL TWC. -WAIT ONE HOUR TO RETRIEVE EXTENSION . l BAR. 1 -MILNE POINT WELL SUPPORT TECH RECEIVING TRAINING.ONHYDRAULIC LUBRICATOR FROM PBU DSM TEAM. 09:00 - 10:00 1.00 WHSUR P DECOMP ' L/D DSM LUBRICATOR & OPSO LOPSO. 10:00 - 10:30 0.50 WHSUR P DECOMP i•P /UTEST J_QINT,B/O LDS. -PULL TBG. HANGER. TO FLOOR, 120K -LBS. UP WT., 115K -LBS HANGER. FREE. 1-FMC INSPECTED HANGAR. _ -S /O TO 3' ABOVE TBG. SPOOL FOR WELL - i [CONTROL. i � -HOLD D-1 DRILL AND CUT ESP CABLE, WSL I � - HELD AAR: (NEED TO LOCATE TIE OFF LINE NEAR WORK j STATION, TO SECURE CABLE AFTER THE CUT) 10:30 - 11:00 ! 0.50 WHSUR P DECOMP R/U & CIRCULATE DOWN THE TBG a 4 -BPM, 11020-PSI. -50- -BBLS AWAY AND NO RETURNS. 11:00 - 12:00 1.00 WHSUR P 1 1 = DECOMP PULL TBG HANGER TO FLOOR -B /O LANDING JOINT AND HANGER. I I -R/U ESP SHEEVE IN DERRICK. 12:00 - 13:30 1.50 BOPSUR N i RREP DECOMP !TEST UPPER/ LOWER IBOP & HYDRAULIC CHOKE. -TEST TO 250 / 3500 PSI EACH - PASS. CHART ALL TESTS. - HYDRAULIC CHOKE HOLDING @ 950 PSI. -TEST WITNESSED BY AOGCC JEFF JONES & ' WSL DAVE RHODES. -16-20 BPH LOSS RATE WITH CONTINUOUS HOLE FEED (SEAWATER) 13:30 - 14:30 1.00 l PULL P DECOMP BLOW DOWN SURFACE LINES. -R/U ESP SHEAVE & RIG FLOOR TO PULL COMPLETION. 14:30 - 00:00 9.50 PULL P DECOMP POH W/ 2 -7/8 ". 6.5 #. EUE TBG & ESP , COMPLETION ASSEMBLY TO 6080' MD. -UD JT #4, 2 EC GLM'S. ' - CONTINOUSLY FILLING HOLE @ 20 BPH. 4/4/2011 I 00:00 - 06:00 6.00 PULL P DECOMP 1 POH W/ 2 -7/8 ", 6.5 #, EUE TBG & ESP COMPLETION ASSEMBLY FROM 6080' MD. I- CONTINOUSLY FILLING HOLE @ 20 BPH WITH NO RETURNS. L/D JTS# 414 AND #415 AND 10' PUP WITH XN NIPPLE. -UD A 10' PUP MADE UP TO THE ESP ' ASSEMBLY. -9 HOLES PUNCHED IN JOINT #414. Printed 4/25/2011 11:05:56AM ,orth Amen a -SA S BP Page 4 of8 Operation Summary Report Common Well Name: MPF -96 ! AFE No Event Type: WORKOVER (WO) I Start Date: 3/31/2011 1 End Date: 4/7/2011 IX4- 00T6K -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/13/2009 12:00:OOAM I Rig Release: 4/7/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: 10.6'CB +34.3'KB @44.9' @44.90ft (above Mean Sea Level) (hr) Date Hrs From - To Code ' Task Co NPT NPT Depth Phase j Description of Operations - -- - - - -- - -- 06:00 - 08:30 ' 2.50 PULL P (ft) DECOMP -BREAK DOWN ESP MOTOR. 1 1-LIGHT SCALE COVERS ABOUT 80% OF O.D. AREA STARTING BELOW THE XN. 1 -THE ESP ASSEMBLY, WITH 100% OF THE {O.D. COVERED BY LIGHT (1/32 ') OF SCALE. -SMALL AMOUNT OF FRAC SAND AND SCALE I , FOUND INSIDE, TOP OF AUTO- DIVERTER- VALVE. I I -MOTOR LOCKED. RECOVERED215 LASALLE,6 PROTECTOLIZERS, 3 FLAT GUARDS. -ESP SHORTED SOME WERE. (WILL _ DETERMINE IN THE SHOP) 08:30 - 09:30 1.00 PULL P ! DECOMP IR/D ESP CABLETRUNKi I ! -CLEAR FLOOR OF ESP LASELLA CLAMPS C AND TOOLS. ' 09:30 - 10:00 !, 0.50 WHSUR P DECOMP ', INSTALL WEAR RING. I LD.. =9 10:00 - 11:30 1 1.50 PULL P , DECOMP CLEAR & CLEAN RIG FLOOR. 11:30 - 21:00 ! 9.50 I CLEAN P DECOMP I M/U MULE SHOE. 1-R11-1W/ 2 -7/8" TBG FOR CLEAN OUT RUN. ! F -RIH T/ 12,892' MD FROM DERRCIK. 1-PUW= 100K, SOW= 65K. ! , - CONTINOUSLY FILLING HOLE @ 20 BPH. — — - 21 :00 - 22 :00 1 1.00 j CLEAN P DECOMP P/U 2 -7/8" TBG & SINGLE IN, 1 x 1 TO 13,176' MD. -PUW= 100K, SOW= 66K. 1 -M /U CIRCULATING HEAD AND FILL HOLE (26 I BBLS TO FILL). _ 1-BREAK CIRCULATION 3 BPM / 600 PSI. 1 22:00 - 23:00 '1 1.00 CLEAN LEAN - P DECOMP STAGE IN HOLE 1 x ,1, PUMP EACH JT DOWN. -3 BPM / 670 PSI TO 13,239' MD. ( LINER TOP @ 13,209" MD). -PUMP 20 BBL HI VIS PILL, LET SOAK 25 ; MINUTES. 23:00 - 00:00 1.00 CLEAN P DECOMP CONTINTINUE TO STAGE INTO THE HOLE TO I 1 13,301' MD. - SINGLE IN WHILE PUMPING 3 BPM / 670 PSI. -PUW= 105K, SOW= 65K. LOSSES @ 3-4 BPH. 4/5/2011 00:00 - 03:30 3.50 CLEAN P DECOMP ! CONTINUE TO STAGE IN THE HOLE FROM 13,301' TO 13,858' MD. I - PUMPING 3 BPM / 750 -850 PSI. PUW = 115K, SOW = 67K. 03:30 05:30 2.00 CLEAN P DECOMP PUMP: -20 BBL HV SWEEP, 75 BBLS SEAWATER, 20 BBL HV SWEEP. -3 BPM / 850 PSI. -STAGE PUMP UP TO 7 BPM / 3500 PSI. - LOSSES AT 30 BPH. PUMP 200 BBLS, NOTED 1200 PSI PRESSURE LOSS. -STOP, MONITOR WELL - OK. - CONTINUE PUMPING 5.5 BPM / 2200 PSI. 1 - CIRCULATE LAST SWEEP SURFACE TO SURFACE. 05:30 - 07:30 1 2.00 CLEAN P DECOMP MONITOR WELL. ' - --4 BPH LOSS RATE -CONTINUOUS HOLE FILL WITH SEAWATER. -POH UD 2 -7/8" TBG FROM 13,858' MD. I -43 JTS DOWN (12,547') Printed 4/25/2011 11:05:56AM oi,H Ar'nertca - ALASKA BP Page 5o#z6' Operation Summary Report Common Well Name: MPF -96 ; AFE No Event Type: WORKOVER (WO) , Start Date: 3/31/2011 End Date: 4/7/2011 X4- 00T6K -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 , Spud Date/Time: 1/13/2009 12:00:00AM 1 Rig Release: 4/7/2011 Rig Contractor: DOYON DRILLING INC. I UWI: 500292340600 Active Datum: 10.6'CB +34.3'KB @44.9' @44.90ft (above Mean Sea Level) Date ! From - To 1 Hrs Task Code NPT ; NPT Depth ; Phase [ Description of Operations (hr) 1 (ft) 07:30 - 13:00 5.50 CLEAN P DECOMP CONTINUE POH AND STAND 2 7/8 TBG IN 1 DERRICK. -UD MULE SHOE, NO MARKS NOTED. -4 -5 BPH LOSS RATE. 13:00 - 13:30 0.50 CLEAN P DECOMP ' ' PULL WEAR RING. RUNCOM P ■ 13:30 14.00 0.50 RUNCMP 'CLEAN RIG FLOOR. 14:00 - 15:00 ! 1.00 RUNCOM P RUNCMP` RU TO RUN ESP COMPLETION. 3 -HANG ESP CABLE SHEAVE IN DERRICK. _ -PJSM WITH..CENTRILIFT REP. � I 15:00 21 6. - fi 50 RUNCOM P RUNCMP P/U CENFRILIFT PUMP MOTOR ASSEMBLY. PRIME. AND TERMINATE SENSOR AND ESP __ ! I CABLE. 121:30 - 00:00 2.50 RUNCOM P I RUNCMP !1 RIH WITH 2 -7/8" 6.5# L -80 8 RD EUE TBG ! FROM DERRICK. 1 -RIH WITH ESP AND CABLE. [- TORQUE CONNECTIONS TO 2300 FT /LBS. CHANGE OUT SEAL RINGS IF NEEDED. 1- BEST -O- LIFE 2000 PIPE DOPE USED. -RIH TO 370' MD. I 1 1 -PUW OF 50K SOW OF 50K. 1-5 BPH LOSS RATE 1- CONTINUOUS HOLE FILL WITH SEAWATER. � - CENTRILIFT REP CHECK CONDUCTIVITY OF CABLE - 2,000'. 1 -FLUSH PUMP WITH 10 BBLS, THROUGH AD- 1 VALVE WITH CHARGE PUMP WITH 30-40 PSI AT -1/2 BPM. 4/6/2011 00:00 - 06:30 6.50 RUNCOM " P 1 RUNCMP RIH WITH 2 -7/8" 6.5# L -80 8 RD EUE COMPLETION. -RIH WITH ESP AND CABLE. 1- TORQUE CONNECTIONS TO 2300 FT /LBS. ' - CHANGE OUT SEAL RINGS IF NEEDED. [ [ 1 [ , 1-BEST 0 LIFE 2000 PIPE DOPE USED. I - CONTINUOUS HOLE FILL - -5 BPH LOSS RATE. - CENTRILIFT REP CHECK CONDUCTIVITY OF CABLE 2,000'. -FLUSH PUMP WITH 10 BBLS, THROUGH AD- ! VALVE WITH CHARGE PUMP WITH 30 -40 PSI AT -1/2 BPM. ! -76 STANDS RUN. 06:30 - 09:30 3.00 RUNCOM 1 P RUNCMP CENTRILIFT REP MAKE ESP CABLE SPLICE. -AT 7,775' MD 09 :30 - 11:00 1.50 RUNCOM !, P RUNCMP HELD D-1 BOP DRILL WHILE TRIPPING WITH NIGHT CREW. I- INCLUDES (SIMULATE) CUTTING ESP ' CABLE. 11 :00 - 13:00 ! 2.00 RUNCOM P 1 RUNCMP 1 1 RIH WITH 2 -7/8" 6.5# L -80 8 RD EUE COMPLETION. 1 -FROM CABLE SPLICE AT 7,775 FT - 10.100' MD 13 :00 - 13:30 0.50 RUNCOM P RUNCMP HELD D-1 BOP DRILL WHILE TRIPPING, WITH DAY CREW. -7 MINUTES TO SIMULATE, CUT ESP AND ! SECURE WELL. -ARR: USE 'ZIP -TIE' OR 'TIE -WRAP' TO I 1 SECURE CABLE TO TBG WHEN UNABLE TO CUT NEXT TO A CABLE I , CLAMP. Printed 4/25/2011 11:05:56AM Arth America - ALASKA BP Page 6 of S Operation Summary Report Common Well Name: MPF -96 j AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2011 1 End Date: 4/7/2011 X4- 00T6K -E: (800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 ; Spud Date /Time: Yf3/2009 - 12:00:00AM I Rig Release: 4/7/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292340600 Active Datum: 10.6'CB +34.3'KB @44.9' @44.90ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase Description of Operations ± (hr) 1 (ft) ' 1 13:30 - 17:30 ' 4.00 I RUNCOM P 1 RUNCMP RIH WITH 2 -7/8" 6.5# L -80 8 RD EUE COMPLETION. - 10,100' MD TO 12,586'. I -UP WT 115K, DWN WT 65K. I -FLUSH PUMP WITH 10 BBLS. -TOTAL SINGLE PIN CANNON CLAMPS = 3 EA. i -TOTAL LASALLE CLAMPS = 192 17:30 - 18 :00 0.50 j RUNCOM 1 P RUNCMP j'M /U HANGER AND LANDING JOINT. 18:00 20:00 2.00 RUNCOM P T � RUNCMP TERMINATE ESP CABLE AT THE TUBING I 1 HANGER. -TEST CABLE. GOOD -DOWN HOLE PSI OF 2620, TEMP OF 125 *. 20 :00 - 21 :00 1 1.00 RUNCOM P RUNCMP CLEAR AND CLEAN RIG FLOOR. -RIG DOWN SHEAVE FROM ESP CABLE. I 1 -LAND TUBING HANGER 23' IN. RILDS. 21:00 - 23:00 2.00 RUNCOM P I RUNCMP R/U OPSO- LOPSO. I -R/U LUBRICATOR, COULD NOT TEST DUE TO ■ 1 I BEING NO PLUG IN THE WELL TO TEST 1 AGAINST. 1- SET .TWC. i i R/D LUBRICATOR, R/D OPSO-LOPSO. 23:00 - 00:00 1.00 RUNCOM P ' RUNCMP R/U AND TEST TWC FROM ABOVE TO 1800 PSI FOR 10 CHARTED MIN. GOOD TEST. 1 ' -TEST TWC FROM BELOW TO 500 PSI ROLLING FOR 10 CHARTED MIN. GOOD TEST. 1 1 -MAINTAIN CONTINUOUS HOLE FILL AT 5 BPH LOSS RATE. 4/7/2011 :00:00 - 03:00 3.00 BOPSUR [ P L RUNCMP REMOVE LOWER RAMS AND REPLACE WITH 2 -7/8" SOLID RAMS. - REMOVE BLIND SHEAR RAMS. I -CLOSE DOORS TO BOPE. _ -N /D BOPE. 1 03:00 - 06:00 3.00 WHSUR P I RUNCMP I FMC PREP TREE AND ADAPTER. -N /U ADAPTER AND TREE. -TEST ADAPTER TO 5000 PSI. GOOD 1 1-TEST ESP AND CONTROL LINE AT 2548 PSI AND 124 *. 06:00 - 12:00 6.00 WHSUR P RUNCMP TEST TREE TO 250 LOW AND 5000 PSI HIGH FOR 30 CHARTED MINUTES. -PU DSM LUBRICATOR AND TEST TO 250 LOW AND 3500 HIGH FOR 5 CHARTED I ' MINUTES. I -PULL TWC -PU BPV - RETEST LUBRICATOR TO 250 LOW AND 3500 HIGH FOR 5 CHARTED MINUTES -SET BPV, LAY DOWN LUBRICATOR 1 -ROLLING TEST TO 500 PSI AT 1/2 BPM FOR 5 MIN, 0 PSI ON TREE CAP. 12:00 - 12:00 0.00 WHSUR P 1 RUNCMP RELEASE RIG AT 12:00 Printed 4/25/2011 11:05:56AM Tree: 2 9/16" - 5M FMC M P F - 9 6 Orig. K B MSL = 38.3' (N 7ES) Wellhead: 11" x 2 7/8 "" 5M Gen 6 on GL. to MSL= 11.0' w/ 2 7/8"" Tubing Hanger TC -II Orig. RT = 27.7' 9 9 er Orig. RT - BF = 27.3' 2.5" CIW "H" BPV profile - - - Orig. RT - LDS = 25.05' ,J 20" 91.1# H -40 122` Camco 2 -7/8" x 1" 132' KOP @ 200' sidepocket KBMG GLM Max hole angle = 71.4° @ 3150' + 66° from 2600' to 12050' NOTE: Tools will not pass through the diverter valve installed at 10.75" 45.5# L -80 BTC casing 8644'1 4 1. 13098' MD. Camco 2 -7/8" x 1" 12312' sidepocket KBMG GLM 2 -7/8" XN nipple 12454' 2.875" 6.5# L -80 EUE -8rd tubing (ID 2.250 ") ( cap = 0.0058 bbl /ft ) 7.625" 29.7# L -80 IBT -M casing Automatic Diverter Valve 12498' ( drift ID = 6.750 ", cap = 0.0459 bbl /ft ) WeIILift Discharge gauge 5.5" 17# L -80 BTC -M Liner TVD = 5807' 12511' ( drift ID = 4.653 ", cap = 0.0232 bbl /ft Tandem Pumps 119 -P23 Tungsten SXD, 12516' 18 -P75 Tungsten SXD, Gas Separator - 12541' TVD = 5829 ' I Tandem Seal Section 12546' 1 Model GSB3 DB UT /LT Motor - Rerated: 225 HP, 12560' Stimulation Summary; 2190 volt, 59 amp, KME -1 3/11/09 - Frac MP 106880# of 16/20 Carbolite WeIILift MGU gauge w/6 fin 12582' 1 / 60880# behind pipe 4131110 Centralizer TVD = 5860' BOT Flex Lock Lnr Hgr & ZXP Lnr Top 1 13,209` Pkr w/ 4.750" ID Seal Bore Extension 75/8" Float Collar 1 13,390` Perforation Summary , • Size SPF Interval TVD 3 1/2" 6 13,672 - 13,682' 6,898' - 6,908' 3 1/2" 6 13,688' - 13,696' 6,914' - 6,922' 3 1/2" 6 13,708 - 13,740' 6,933' - 6,965' FCO to 13858' during 4/6/11 RWO 51/2" Float Collar (PBTD) 113,872' 5 1/2" Float Shoe 1 13,914` DATE REV. BY COMMENTS MILNE POINT UNIT 2/27/09 L. Hulme Drilled & Completed (D -14 & N -7ES) WELL M P F' 6 4/9/09 REH ESP completion Nabors -3S 9/10/09 REH ESP RWO - Nabors 4ES API NO: 50- 029 - 23406 -00 9/29/09 REH ESP RWO /install screen & cup PKR - N 4ES 1/14/10 Hulme ESP RWO /install diverter valve - N 4ES 4/6/11 Hulme ESP RWOFCO & move ESP up hole - D -16 BP EXPLORATION (AK) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI• W REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 ACID Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ✓❑ Exploratory ❑ ft 208 -1860 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 r 50- 029 - 23406 -00 -00 8. Property Designation (Lease Number) : - s 9. Well Name and Number: ADLO- 355018 / 025509 3 g b MPF -96 10. Field /Pool(s): MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 13915 feet Plugs (measured) None feet true vertical 7140.45 feet Junk (measured) None feet Effective Depth measured 13872 feet Packer (measured) feet true vertical 7097. feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 122' 20" SURFACE - 124 SURFACE - 124 1490 470 Surface 8609' 10 -3/4" SURFACE - 8644 SURFACE - 3166 5210 2480 Intermediate Production 13377' 7 -5/8" SURFACE - 13410 SURFACE - 6637 6890 4790 Liner 705' 5 -1/2" 13209 - 13914 6437 - 7101 7740 6280 Liner Perforation depth: Measured depth: O 13672 - 13682 O 13688 -13696 O 13708 -13740 True Vertical depth: 6897.81 - 6907.78 6913.77 - 6921.75 6933.73 - 6965.67 Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 SURFACE - 13181 SURFACE - 6409 Packers and SSSV (type, measured and true vertical depth) NONE 5# QED D C � t E CE IVED 12. Stimulation or cement squeeze summary: 9E6 0 7 2010 Intervals treated (measured): COtl$. COtINTM$$jQp Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 445 54 247 291 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ✓❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ! Gas U WDSPL LJ GSTOR ❑ WINJ ❑ WAGE] 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: NA Contact Joe Lastufka Printed Nam Joe astu �a Title Data Manager Signature , Phone 564 -4091 Date 12/6/2010 0 8.101Qti /z �• �a Form 10 -404 Revised 10/2010 / bmit Original Only • • MPF -96 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I 11/25/2010 T /1 /0= 300/340/0 Diesel /Xylene Treatment Pumped 20 bbls 50/50 diesel /xylene down IA followed by 38 bbis crude. ESP overheated. * **Job In Progress Continued On WSR 11/26/10 * ** 11/26/2010 ** *Job In Progress Continued From WSR 11/25/10 * ** Diesel /Xylene Treatment 3 I Pumped remaining 22 bbls crude down FL. DSO notified swab shut, wing ssv master ' pia oa open. FWHP's= 300/340/0 12/1/2010 T / /1 /0= 200/290/0 ESP Acid Treatment Pump 10 bbis crude Inj. Test @ 1.3 bpm/ Max pressure 500 psi. Pump 10 bbis 12% DAD acid @ 1 bpm. Displace acid w/ 3 bbis 60/40 methanol followed by 2 bbls crude down Tbg. Tbg started to lock up w/0.4 bbis 60/40 away. DSO notified swab wing shut, ssv master is oa open. FWHP's= 3000/290/0 E j ___ _ _____.______.________ __.___._______._._._.____._... _ _._.___.0 -crude ___..._._..._... I 12/2/2010.. jT/I/0= ___1500/280/0 _ _ Displace Tbg. _ Pump 1.1 � bbis _ crude do . Tbg press_ ure holding steady @ 3100 psi. Pump 54 bbis crude followed by 5 bbls diesel down Flowline. Close Prod. Latural line and bleed line to Zero. FWHP = 3100/280/0. Swab, Ssv, Wing closed. Mst., IA, OA open. NOVP _ i 3 FLUIDS PUMPED BBLS 15 DIESEL 10 XYLENE 107 CRUDE 10 12% DAD ACID ✓ 3 60/40 145 TOTAL • Tree: 2 9/16" - 5M FMC , Orig. KUM MSL = 38.3'(N 7ES) Wellhead: 11" x 2 7/8 "" 5M Gen 6 MP _g 6 Orig. G v. to MSL= 11.0' w/ 2 7/8 "" Tubing Hanger TC -II Orig. FIT - GL = 27.7' CIW "H" BPV profile Orig. FIT - BF = 27.3' P Orig. FIT -LDS = 25.05' 20" 91.1# H -40 122' Cameo 2 -7/8" x 1" 161' KOP @ 200' sidepocket KBMG GLM Max hole angle = 71.4° @ 3150' + 66" from 2600' to 12050' 10.75" 45.5# L -80 BTC casing 8644' Cameo 2 -7/8" x 1" 1 2934' sidepocket KBMG GLM 2 -7/8" XN nipple 13076' 2.875" 6.5# L -80 EUE -8rd tubing (ID 2.250 ") ( cap = 0.0058 bbl/ft) Automatic Diverter Valve 7.625" 29.7# L -80 IBT -M casing 13098' ( drift ID = 6.750 ", cap = 0.0459 bbl /ft) WeIILift Discharge gauge 5.5" 17# L -80 BTC -M Liner TVD =6329' 13101' ( drift ID = 4.653 ", cap = 0.0232 bbl /ft Tandem Pumps 74 -P31 Tungsten SAD, 13106' 74 -P31 Tungsten SAD, Gas Separator 13135` TVD = 6363' Tandem Seal Section 13140' Model GSB3 DB UT/LT Motor, 266 HP, 2345 volt, 13154` Stimulation Summary : 69 amp, KMH 3/11109 - Frac 106880# of 16120 Carbolite WeIILift MGU w/6 fin 13177' 60880# behind pipe, Centralizer TVD =6405' BOT Flex Lock Lnr Hgr & ZXP Lnr Top 13,209` Pkr w/ 4.750" ID Seal Bore Extension 75/8" Float Collar 1373901' Perforation Summary Size SPF Interval TVD 3 1/2" 6 13,672 - 13,682' 6,898'- 6,908' 3 1/2" 6 13,688'- 13,696' 6,914'- 6,922' 3 1/2" 6 13,708 - 13,740' 6,933'- 6,965' 51/2" Float Collar (PBTD) 13,872' 5 1/2" Float Shoe r 13,914' DATE REV. BY COMMENTS MILNE POINT UNIT 2/27109 L. Hulme Drilled & Completed (D -14 & N -7ES) WELL M P F -96 419/09 REH ESP completion Nabors -3S 9/10/09 REH ESP RWO - Nabors 4ES API NO: 50- 029 - 23406 -00 9/29/09 REH ESP RWO /install screen & cup PKR - N 4ES 1/14/10 Hulme 1 ESP RWO /Installdivertervalve - N 4ES BP EXPLORATION M)
