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Home My WebLink About201-1701. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Change-out 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 18,595 feet 18,466 feet true vertical 7,853 feet N/A feet Effective Depth measured 18,466 feet 18,155 feet true vertical 7,727 feet 7,427 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8" 6.5# / L-80 / EUE R2 18,095' 7,369' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / IBT 18,193' 7,463' Packers and SSSV (type, measured and true vertical depth)Baker Premier 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 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 3,580psi 7,240psi18,555' 7,814' Burst N/A Collapse N/A 2,090psi 5,410psi Casing Conductor 18,523' 10,341'Intermediate Production 20" 10-3/4" 20" 112' 10,307' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-170 50-029-23040-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509, ADL0355016 & ADL0355018 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT F-94 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 96 Gas-Mcf MD 112' 360 Size 112' 4,454' 891 40078 119 349863 334 323-384 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 6.7 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:26 pm, Oct 05, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.10.05 14:41:37 - 08'00' Taylor Wellman (2143) WCB 4-12-2024 DSR-10/5/23 _____________________________________________________________________________________ Revised by: TDF 10/5/2023 SCHEMATIC Milne Point Unit Well: MPU F-94 Last Completed: 9/6/2023 PTD: 201-170 TD =18,595’ (MD) / TD = 7,853’(TVD) 20” KB Elev.: 44’/ GL Elev.: 11’ 7” 3 5 &6 8 & 9 10 & 11 12 13 14 15 3/8” Capstring 10-3/4” 1 2 10-3/4” Halliburton ES Cementer 16 17 & 18 Min ID= 2.205” @ 17,971’ MD KUP A Sands PBTD =18,466’(MD) / PBTD = 7,727’(TVD) 4 & 5 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94 / K-55 / N/A N/A Surface 112' 10-3/4" Surface 45.5 / L-80 / Btrc. 9.950 Surface 10,341’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 18,555’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE R2 2.441 Surface 18,095’ 4-1/2” Tubing 12.6 / L-80 / IBT 3.958 18,146’ 18,193’ CAPSTRING DETAIL 3/8” Capstring SS w/ 0.049 Wall N/A Surface 18,095’ JEWELRY DETAIL No Depth Item 1 204’GLM 2: 2 7/8 x 1'' Side pocket,,w/DPSOV & BK Latch– ID= 2.384” 2 17,852’GLM 1: 2 7/8 x 1'' Side pocket,,w/DPSOV & BK Latch– ID= 2.384” 3 17,973’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 18,023’ Discharge Head: B/O PMP 513 5 18,024’ Zenith Ported Sub: S/A B/O PRESS PORT 513/538P 6 18,024.4’ Pump 2: 538PMSXD 137 P17 M FER NO_PNT 7 18,043’ Pump 1: 538PMSXD 20 GINPSHH H6 FER 8 18,053’ Gas Separator: 538GM2T HV E V X MT HS FER STD 9 18,059’ Intake: GPXARCINT FER H6 PN: C141000513 10 18,060’ Upper Tandem Seal: GS3, B/B/L , SB, H6, PFSA,HL, FER,12CRC 11 18,066’ Lower Tandem Seal: GS3, B/B/L , SB, H6, PFSA,HL, FER 12CRC 12 18,073’ Motor: 562XP 250 Hp /2505 V / 61 A / 10R 13 18,090’ Motor Gauge & Centralizer – Btm @ 18,095’ 14 18,155’ 7” x 4.5” Baker Premier Pkr. 15 18,181’ 4.5” HES XN-Nipple (ID= 3.813” / No-go 3.725”) 16 18,193’ 4.5” WLEG 17 18,469’ 7” Float Collar 18 18,554’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 18,290’ 18,292’ 7,557’ 7,559’ 2 11/25/01 Open Kup. A Sands 18,300’ 18,310’ 7,566’ 7,576’ 2 12/8/01 Open Kup. A Sands 18,328’ 18,330’ 7,593’ 7,595’ 10 12/1/01 Open Kup. A Sands 18,325’ 18,335’ 7,591’ 7,600’ 10 12/9/01 Open Reference Log: SWS Anadrill CDR Resistivity - Dated 10/17/2001 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks of Arctic Set (Approx.) in 30” Hole 10-3/4" Cmt w/ 1,153 sks PF “L”, 300 sx PF “C, 900 sx ” in 13-1/2” Hole 7” Cmt w/ 400 sks Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ to 3,100’ Max Hole Angle = 77 deg. Hole Angle through perforations = 15 deg. Max. Dg Leg Severity = 6.21 @ 2,900’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” Gen 5 FMC 11” x 2-9/16” Hgr. w/ 2-7/8” NSCT T&B, & 2.5” Type “H” BPV Profile GENERAL WELL INFO API: 50-029-23040-00-00 Drilled and Run Frac String by Nabors 27E - 11/25/1997 Perforated and Frac’d w/ Wireline and CT– 12/11/2001 ESP Completion w/ Nabors 4-ES ESP Re-completions on 2/26/05, 2/8/06, 12/9/07, 4/25/08, 4/16/09, 6/7/09, 2/6/10, 4/20/11, 6/10/12, 3/14/13 & 11/17/14 , 10/13/2016 & 9/6/2023 FRAC SUMMARY 12/11/01 – 117,298lbs of 16/20 C/lite and 73,740lbs of 12/18 C/lite behind pipe. Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 ASR 50-029-23040-00-00 201-170 8/26/2023 9/7/2023 8/25/2023 - Friday No operations to report. 8/23/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/24/2023 - Thursday No operations to report. RIH w/ 7" casing scraper BHA on 2-7/8" 6.5# tubing F/ 6,500' T/ 7,070' Pump double displacement for pipe tripped in XO to 3- 1/2" workstring. P/U wt = 24K S/O wt = 17K. RIH w/ 7" casing scraper BHA on 3-1/2" 9.5# workstring F/ 7,070' T/ 8,151' Pump double displacement for pipe tripped in. Service rig, Check equip. fluid levels. Perform hazard hunt. RIH w/ 7" casing scraper BHA on 3-1/2" 9.5# workstring F/ 7,070' T/ 17,321' Pump double displacement for pipe tripped in. R/U to reverse circulate. Reverse circulate, pump at 3 BPM w/ 550 psi. Pump a total of 234 bbls. Bottoms up plus losses. Scrap interval 17,300' - 17,200' x 2 Returns coming back to pits clean, 8.4 ppg source water. Shut down monitor well. Well on vacuum. R/D circulating equipment & blow down. POOH w/ 7" casing scraper BHA on 3-1/2" 9.5# workstring F/ 17,170' T/ 15,759 ' Pump double displacement for pipe tripped out. Service rig, Check equip. fluid levels. POOH w/ 7" casing scraper BHA on 3-1/2" 9.5# workstring F/ 15,759' T/ 10,000 ' Pump double displacement for pipe tripped out. . Rig accepted at 06:00 8/26/2023. Fill BOP stack, manifold, choke & kill lines w/ fresh water. P/U & M/U 2-7/8" test joint. Purge air out of system. BOPE test as per approved sundry, AOGCC waive witness of test. Test BOPE T/ 250 psi low & 2,500 psi high for 5/5 charted mins. Blow down testing lines & L/D test joint. Fill gas buster w/ source 8.4 ppg water. Hang ESP sheave. Run lines to spooler. Change elevators. With IA open, pull CTS & BPV. No pressure in tubing. Fill well w/ 27 bbls on IA. Balanced fluid level in well was ~ 893' dw. M/U landing joint. BOLDS. Pull hanger to floor, hanger offseat at 95K. Weight increased to 116K before breaking over. Clean P/U wt = 103K. No drag observed. Fill tubing. Pump at 1.5 bpm w/ 300 psi. Returns observed at flow line. Well losing 24 BPH dynamically. Shut down pumps. L/D landing JT & hanger. POOH W/ ESP completion F/ 18,089' T/ 17,970'. Pumping double displacement. Service rig. Check equip. fluid levels. POOH W/ ESP completion F/ 18,089' T/ 14,500'. Pumping double displacement. 8/26/2023 - Saturday Perform reel swap. Remove full spool & replace w/ empty. Clear rig floor of ESP clamps. Cont. POOH f/ 2,800'. POOH W/ ESP completion F/ 2,800' T/ 128'. Pumping double displacement. L/D ESP assy. DS head, 3x pumps, GS, upper & lower seals, motor, sensor, cent, 1 tubing jt , cent. Clamps recovered = 576 CC, 5 pump clamps, 3 protectolizers, 3 flat guards, 2 half clamps. R/D ESP handling equip. Clean & clear floor. Load 7" scraper BHA on racks. Rack & tally 2-7/8" pipe. Hold PJSM on BHA. M/U 7" scraper BHA. Junk mill, 2 x boot basket, 7" csg scraper, Bit sub, bumper sub, oil jar, XO. RIH w/ 7" casing scraper BHA on 2-7/8" 6.5# tubing F/ 35' T/ 2,165' Pump double displacement for pipe tripped in. Service rig. Check equip. fluid levels. RIH w/ 7" casing scraper BHA on 2-7/8" 6.5# tubing F/ 2,165' T/ 6,500' Pump double displacement for pipe tripped in. 8/29/2023 - Tuesday 8/27/2023 - Sunday POOH W/ ESP completion F/ 14,500' T/ 11,475'. Pumping double displacement. P/U wt = 59K. Service Rig. Check equip. POOH W/ ESP completion F/ 11,457' T/ 10,069'. Pumping double displacement. Service Rig. Change out DEF sensor. Clear codes. POOH W/ ESP completion F/ 10,069' T/ 2,800'. Pumping double displacement. 8/28/2023 - Monday POOH W/ ESP completion F/ 14,500' T/ 11,475'. Pumping double displacement. P/U wt = 59K. Service Rig. Check equip. POOH W/ ESP completion F/ 11,457' T/ 10,069'. Pumping double displacement. Service Rig. Change out DEF sensor. Clear codes. POOH W/ ESP completion F/ 10,069' T/ 2,800'. Pumping double displacement. With IA open, pull CTS & BPV. No pressure in tubing. Fill well w/ 27 bbls on IA. Balanced fluid level in well was ~ 893' dw Well losing 24 BPH dynamically Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 ASR 50-029-23040-00-00 201-170 8/26/2023 9/7/2023 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 ASR 50-029-23040-00-00 201-170 8/26/2023 9/7/2023 9/1/2023 - Friday POOH w/ Test Packer while pumping double displacement to15,260'. Shut down to fix door on Tongs. POOH w/ Test Packer while pumping double displacement F/ 15,260' T/ 12,640'. Shut down to fix leaking fuel line on Rig. POOH w/ Test Packer while pumping double displacement F/ 12,640' T/11,210'. Shut down to duct tape the shroud coming loose and bending inward causing the service loop wrap to catch and rip again. Call for a rivet gun to affix permanently. POOH w/ Test Packer while pumping double displacement F/ 11,210' - T/ 7040'. Swap handling equipment from 3-1/2" - 2-7/8". POOH w/ Test Packer while pumping double displacement F/ 7040' - T/1796'. Install TIW, clean work areas, change-out at Doyon 14. Service Rig - add oil to 30MTU, grease tongs and elevators, inspect catwalk. POOH w/ Test Packer while pumping double displacement F/ 1796' - T/ Surf. Make service breaks on BHA, LD Packer. Packer intact. Remove wear bushing and install test Plug. Install 2- 7/8" test joint, fill stack and Manifold. Test BOPE as per procedure. 8/30/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary POOH w/ 7" casing scraper BHA on 3-1/2" 9.5# workstring T/ current depth of 10,500. Pumping double displacement. POOH T/ 7870' Pumping double displacement. PUW 26K, SOW 17K. Crew change. Check fluids and daily inspections. Continue POOH F/ 7870' T/ 4885', while pumping double displacement. Continue POOH F/ 4885' T/ 2166', while pumping double displacement. Continue POOH F/2166' T/ BHA , while pumping double displacement. L/D Scraper BHA. Recovered ~1cup of scale and 4ea. 3" sections of 1/4" SSCL. Prep floor and pipe shed for test packer run. Make up YJOS - 7" AS1X HT & crossovers necessary back to 2-7/8" EUE. Fill hole w/ 17BBLS. RIH w/ Test Packer on used 2-7/8" EUE Tubing T/790' MD. Shut down and check equipment. Cont. RIH w/ Test Packer on used 2-7/8" EUE Tubing F/790' T/ ~4200' MD. 8/31/2023 - Thursday Continue RIH Yellow Jacket - 7" AS1-X HT Test PKR. Currently RIH F/ 4200' - T/ 7070' w/ 2-7/8" EUE TBG while pumping double displacement. Swap handling equipment to 3-1/2" Work string. Crew change - check fluids and daily inspections. Continue RIH Yellow Jacket - 7" AS1-X HT Test PKR. Currently RIH F/ 7070' - T/ 11,973' w/ 3.5" work string while pumping double displacement. Kick while tripping drill - 1min 15sec. Hazard hunt focusing on tripping hazards. Continue RIH Yellow Jacket - 7" AS1-X HT Test PKR. Currently RIH F/ 11,973' - T/ 16,537' w/ 3.5" work string while pumping double displacement. Install TIW Valve. Shut down and crew departed to change-out at the moving Doyon 14 Rig. Toolpusher monitoring Rig/Well. Transfer fluid from upright to pits. Continue RIH Yellow Jacket - 7" AS1-X HT Test PKR F/ 16,537' to 17,230'. Install 10.02' & 5.04' Space- out Pups, JT# 480. Screw in Quill. Attach Kelly hose. PUW = 96K | SOW = 26K. At 35' in on minus RKB = 17,250' MD. Set Packer and apply 10K down. Fill IA w/ 10BBLS. Fill surface lines and manifold. Rock fluid and allow air to purge system. Initial pressures T/IA/OA: 0/0/190 Bring pump on down IA, bring press. up to 1600psi and isolate pump. T/IA/OA: 0/1600/200. 15min = T/IA/OA: 0/1600/200. 30min = T/IA/OA: 0/1600/200. Confirm good test with OE. Release packer, allow elements to relax, monitor well. Well on vac. RD surface lines. POOH w/ Test Packer while pumping double displacement F/ 17,250' T/ 15,210'. Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 ASR 50-029-23040-00-00 201-170 8/26/2023 9/7/2023 Hilcorp Alaska, LLC Weekly Operations Summary Continue BOPE tests. Rack and Tally 2-7/8" EUE in pipe shed. Ready pumps. Perform draw-down and Accumulator tests. All tests good. Pull test plug. Break XO from landing joint. RU Centrilift equipment. Pull 3/8" C/L over Sheave. PU Pump. Tie in 3/8" Cap line, circulate in oil. PU ESP Assembly. Motor, Seals, Pump. Install MLE. Clear floor of unneeded ESP equipment. Prep floor for ESP run on 2-7/8" TBG. RIH w/ Centrilift ESP, 2-7/8", 6.5#,L EUE R2 Tubing. JT#1 - 2.205" XN Assy. - JT# 2,3,4 - GLM#1 w/ BK DMY VLV. Pumping double displacement. Install Clamps every other joint as per Sundry. Test ESP Cable Comms @ 1161' - Good. Perform Kick while tripping drill - 3min and recap. RIH F/ 1161' - T/ 2757' Test ESP Cable comms - Good. RIH F/ 2757' - T/ 3376'. Install TIW and secure well. Travel to Doyon 14 for change-out. Check Rig fluids. Inspect pipe handling equipment. RIH F/ 3376' - T/ 4157' Test ESP Cable comms - Good. RIH F/ 4157' - T/ 5131' Test ESP Cable comms - Good. RIH F/ 5131' - T/ 6100' Test ESP Cable comms. 9/2/2023 - Saturday RU Slickilne. Rig crew building shelves for Conex. SL RIH w/ 10' x 2-5/8" R.Stem w/ 3.00" WHLS, O.Jars, LSS - 6.00" J.Basket to 18,205' SLM, POOH. OOH w/ tools, recovered remaining SS Band in J.Basket. RD Slickline, clean areas. PU / MU ESP. PU / MU Motor, seals, and pumps. Fill with dielectric mineral oil. Connect Cable and 3/8" Chemical Injection Line Pump and fill hole w/ 9bbls. Check fluids and daily inspections. RIH w/ Centrilift ESP, 2-7/8", 6.5#, L EUE R2 Tubing. JT#1 - 2.205" XN Assy. - JT# 2,3,4 - GLM#1 w/ BK DMY VLV. Pumping double displacement. Install Clamps every connection. Test ESP systems every 1000'. Kick while tripping drill - 1min 30sec. Test ESP system @ 1130' - good. Continue RIH F/ 1130' - T/ 2429' ESP test - good. RIH F/ 2429' - T/ 3340' ESP test - good. Shut down and check equipment, daily checklists. RIH F/ 3340' - T/ 4027' ESP test - good. RIH F/ 4027' - T/ 5003' ESP test - good. RIH to 5700'. 9/3/2023 - Sunday Continue RIH F/ 5906' (last comms test) w/ Centrilift ESP, 2-7/8", 6.5#, L EUE R2 Tubing. Pumping double displacement. Install Clamps every other joint as per Sundry. RIH to 7856'. Cable/ESP system found to be grounded. Inform OE & Wells Group. Call was made to POOH testing every 2000'. POOH while pumping double displacement T/ 7348'. Have additional equipment delivered for rerunning. Crew change. Check fluids and daily inspections. POOH while pumping double displacement and inspecting cable for damage T/ 5519'. Take on additional 8.4ppg source water to uprights and pits. Test Cable systems - remains grounded, continue OOH. POOH while pumping double displacement and inspecting cable for damage T/ 3829'. Perform "Kick While Tripping" Drill - 2min and recap of drill. POOH while pumping double displacement and inspecting cable for damage T/ 3000'. Test Cable Systems - remains grounded. POOH while pumping double displacement and inspecting cable for damage T/ 511'. Crew change - Check fluids, daily inspections. POOH while pumping double displacement and inspecting cable for damage T/ SURF. Upon disassembling the ESP, the cable was found to be impacted jest above the MLE interface with the bottom motor and below the corresponding clamp. Scrapes were found leading up to the damage from below on the lower motor. Both installed SS Bands were missing. Once the assembly was removed from the Stack, a Band could be seen across the CSG Hanger. Travel to Slickline unit on L-Pad. Gather wireline grabs, rope socket, and wire. Successfully fished the partial SS Band from stack. Inform OE of status. Decision was made to have Slickline retrieve the remaining SS Band pieces. Make calls. Fill hole w/ 14bbls. Inform Centrilift of plan forward. LD remaining ESP components. Shut Blinds and secure well. STBY for Slickline. Centrilift splicing cable for rerun. Rig crew moving equipment for Slickline arrival. Slickline RU. 9/4/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 ASR 50-029-23040-00-00 201-170 8/26/2023 9/7/2023 Hilcorp Alaska, LLC Weekly Operations Summary RIH w/ Centrilift ESP, 2-7/8", 6.5#, L EUE R2 Tubing F/ 5685' - T/ 7000' while pumping double displacement. Install Clamps every connection. Test ESP systems every 1000'. Reduce RIH speed from 60fpm to 30fpm @ 7000' due to DLS. Test ESP 7180' - good test. Perform Cable splice on JT# 243 | 8025'. ESP test good. Continue RIH F/ 8025' - T/ 9225'. Fire drill. 3min 15sec and review. ESP test - good. Continue RIH F/ 9225' - T/ 10,232' ESP test - good. Continue RIH F/ 10,232' - T/ 11,275' while pumping double displacement. ESP test - Good. Crew change, check equipment. Daily inspections. Continue RIH F/ 11,275' - T/ 12,208' Esp test - good. Continue RIH F/ 11,208' - T/ 12,989' Esp test - good. Continue RIH F/ 11,208' - T/ 14,000'. 9/5/2023 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 ASR & Wellhead 50-029-23040-00-00 201-170 8/26/2023 9/7/2023 9/8/2023 - Friday No operations to report. 9/6/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue RIH w/ Centrilift ESP, 2-7/8", 6.5#, L EUE R2 Tubing T/ 13,997' MD while pumping double displacement. Install Clamps every connection. Test ESP systems every 1000'. Currently testing ESP systems - good.;RIH F/ 13.997 - T/ 15,010'.;Test ESP - good;RIH F/ 15,010' - T/15,794' Test ESP - Good.;Swap ESP Reel. Insulate Standpipe, clean location and crew house. Tighten BOP stack on MPU L-39.;Continue Reel to Reel splice.;RIH F/ 15,794' - T/ 17,000'. Splice at 16,010' MD. ESP test - good.;RIH F/ 17,000' - T/ 18,061'.;PU & MU Landing Joint, 11"x2-7/8" TBG Hanger w/ BPV installed. Terminate 3/8" Chemical Injection line & ESP Cable. Prepare to land hanger. Fill hole w/ 15bbls. Blow down surface lines.;Land Hanger while monitoring ESP (good). RILDS. Final PUW = 78K - SOW = 25K. 9/7/2023 - Thursday WELLHEAD: BOP pulled, clean Hgr void, install (2) seal subs, neck seal, RX54 gasket and land tree/adapter. Tourque to spec and test Hgr void to 500/5000 (PASS). Pull Bpv, all valves in closed. No operations to report. No operations to report. 9/9/2023 - Saturday No operations to report. 9/12/2023 - Tuesday 9/10/2023 - Sunday No operations to report. 9/11/2023 - Monday Continue RIH w/ Centrilift ESP, 2-7/8", 6.5#, L EUE R2 Tubing T/ 13,997' MD while pumping double displacement. Install Clamps every connection RIH F/ 17,000' - T/ 18,061'.;PU & MU Landing Joint, 11"x2-7/8" TBG Hanger w/ BPV installed [file name] Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 8/29/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Well Control Drill Petroleum Inspector MPU F-94 Hilcorp Alaska LLC PTD 2011700; Sundry 323-384 8/29/2023: I stopped by Hilcorp’s ASR1 at Milne Point Well F-94 to see how operations were going (ESP change-out) and to have them perform an unscheduled well kick drill. I met with the company representative Scott Hiem and the tool pusher Chris Greub. We discussed what the rig was currently doing and spoke about their last well kick drill. Chris Greub initiated the drill, and I started timing. It took one minute and forty seconds for the rig hands to get into place, radio in that they were in place, stab the floor safety valve, shut the annular, close the choke, get the well pressures, and confirm that the well was under control. The rig hands did a good job performing the well kick drill in a safe and timely manner. Attachments: none       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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 18,595'N/A Casing Collapse Conductor N/A Intermediate 2,090psi Production 5,410psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng scott.pessetto@hilcorp.com 907-564-4373 2-7/8" 6.5# / L-80 / EUE 8rd 18,112 See Schematic See Schematic 4-1/2" Baker Premier and N/A 18,155(MD)/ 7,427(TVD) and N/A Scott Pessetto 112' 20" 10-3/4" 20" 10,307' 18,523' N/A 3,580psi 7,240psi 4,454' 7,814' 10,341' 18,555' Length Size Proposed Pools: 112' 112' 12.6# / L-80 / IBT TVD Burst 18,193 MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0355016 & ADL0355018 201-170 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23040-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 8/3/2023 Perforation Depth MD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT F-94 MILNE POINT KUPARUK RIVER OIL N/A 7,853' 18,466' 7,727' 2,023 18,466' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:23 pm, Jul 11, 2023 323-384 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.07.11 11:30:02 - 08'00' Taylor Wellman (2143) SFD 7/26/2023 DSR-7/12/23 10-404 2,023 MGR13JUL2023 * BOPE test to 2500 psi. GCW 07/26/2023JLC 7/26/2023 07/26/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.26 19:36:31 -06'00' RBDMS JSB 072823 Well: MPF-94 PTD: 201-170 API: 50-029-23040-00-00 Well Name:MPF-94 API Number:50-029-23040-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:8/3/2023 Estimated Duration:7 days Regulatory Contact:Tom Fouts Permit to Drill Number:201-170 First Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 862 psi @ 3,200’ TVD 6/22/2023 |7.1 PPGE Max Potential Surface Pressure: 2,023 psi Gas Column Gradient (0.1 psi/ft) Max Angle:74° Sail Angle from 3,000’ MD Brief Well Summary: MPU F-94 was drilled in November 2001 and completed in December 2001 as a Kuparuk River jet pump producer. The current ESP completion was installed in 2016. The ESP has failed due to a grounded motor. MPF- 94 has a long history of ESP installs with ESPs installed in 2005, 2006, 2007, 2008, 2009, 2010, 2011, 2012, 2013, 2014, and 2016. Scale deposition and under deposit corrosion have lead to a historically short tubing and ESP life. Through a combination of acid flushes down the tubing and annulus scale inhibition treatments the latest ESP completion was able to last almost seven years. Objectives: Pull failed ESP completion, run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 2,500 psi on 6/3/2012 at 17,250’ MD. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Attempt to pull dummy valve from GLM at 17,891’ MD and leave open. 4. Pull GLV and set dummy valve in upper GLM at 123’ MD. 5. RDMO. Coiled Tubing (Contingency) 1. Pressure test PCE to 250 psi low / 2,500 psi high. 2. PU 1.75” jet nozzle. 3. Jet down to discharge head at 17,981’ MD. 4. Following best practices in PE manual, pump gel sweeps to clean up tubing. 5. Chase gel out of hole. 6. PU tubing punch. 7. RIH and tag discharge head. 8. Pump down ball to fire tubing punch. 9. Confirm circulation by pumping down backside of coil. 10. Freeze protect tubing as POOH. 11. RDMO. Well: MPF-94 PTD: 201-170 API: 50-029-23040-00-00 Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable and 3/8” capillary string. a. Use extreme care in spooling the capillary string to promote reuse of the string. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC 11” x 2-9/16”, with 2-7/8” EUE thread. b. 2016 tubing PU weight on ASR #1 recorded as 99 kip. Slack off weight recorded as 25 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Do not keep tubing. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: Well: MPF-94 PTD: 201-170 API: 50-029-23040-00-00 i. Canon Clamps: 564 ii. Protectolizers: 3 iii. Pump Clamps: 8 10. Lay Down ESP. 11. Pressure test pulled 3/8” capillary tubing to 3500 psi. If PT passes, plan to save for future work. 12. PU 3-1/2” workstring, 7” casing scraper, and muleshoe. RIH to 18,145’ MD. 13. Circulate well clean. 14. Scrape casing interval from 17,200’ to 17,300’ MD. 15. POOH while filling hole with 2x displacement. 16. PU and RIH with 7” test packer to 17,250’ MD. 17. Test 7” casing to 1,500 psi for 30 minutes. 18. POOH with test packer. 19. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 18,110’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint d. Run single 3/8” cap string the length of the completion, clamping with cable. Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 34 Motor - 250HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 57 Pumps – Flex-17.5 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.505" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 17,650 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 Charted - mgr Well: MPF-94 PTD: 201-170 API: 50-029-23040-00-00 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 20. Land tubing hanger. Use extra caution to not damage cable. 21. Lay down landing joint. 22. Set BPV. 23. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised by: TDF 10/24/2016 SCHEMATIC Milne Point Unit Well: MPU F-94 Last Completed: 10/13/2016 PTD: 201-170 TD =18,595’ (MD) / TD = 7,853’(TVD) 20” KB Elev.: 44’/ GL Elev.: 11’ 7” 3 5 6 7 8 9 10 & 11 12 13 14 3/8” Capstring 10-3/4” 1 2 10-3/4” Halliburton ES Cementer 15 16 & 17 Min ID= 2.205” @ 17,971’ MD KUP A Sands PBTD = 18,466’(MD) / PBTD = 7,727’(TVD) 4 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 94 / K-55 / N/A N/A Surf 112' 10-3/4" Surface 45.5 / L-80 / Btrc. 9.794 Surf 10,341’ 7" Production 26 / L-80 / Btc Mod 6.151 Surface 18,555’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surf 18,112’ 4-1/2” Tubing 12.6 / L-80 / IBT 3.833 18,146’ 18,193’ CAPSTRING DETAIL 3/8” Capstring SS w/ 0.049 Wall N/A Surf 18,112’ JEWELRY DETAIL No Depth Item 1 123’STA 2: GLM 2-7/8” x 1”, KBMM w/ DSOV –ID= 2.347” 2 17,891’STA 1: GLM 2-7/8” x 1”, KBMM w/ Dummy -ID= 2.347” 3 17,971’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 17,981.5’ Discharge Head: FPDIS 5 17,982’ Pumps : 62 Flex 17.5 & (2)134 Flex 17.5 – Bottom @ 18,041 6 18,041’ Gas Separator: GRS FER N AR 7 18,044’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 18,051’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 9 18,058’ Motor: MSPI-250 10 18,074’ Sensor Well Lift Type E 11 18,076’ Centralizer 12 18,110’ Centralizer –Bottom @ 18,112’ 13 18,155’ 7” x 4.5” Baker Premier Pkr. 14 18,181’ 4.5” HES XN-Nipple (ID= 3.813” / No-go 3.725”) 15 18,193’ 4.5” WLEG 16 18,469’ 7” Float Collar 17 18,554’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 18,290’ 18,292’ 7,557’ 7,559’ 2 11/25/01 Open Kup. A Sands 18,300’ 18,310’ 7,566’ 7,576’ 2 12/8/01 Open Kup. A Sands 18,328’ 18,330’ 7,593’ 7,595’ 10 12/1/01 Open Kup. A Sands 18,325’ 18,335’ 7,591’ 7,600’ 10 12/9/01 Open Reference Log: SWS Anadrill CDR Resistivity - Dated 10/17/2001 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks of Arctic Set (Approx.) in 30” Hole 10-3/4" Cmt w/ 1,153 sks PF “L”, 300 sx PF “C, 900 sx ” in 13-1/2” Hole 7” Cmt w/ 400 sks Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ to 3,100’ Max Hole Angle = 77 deg. Hole Angle through perforations = 15 deg. Max. Dg Leg Severity = 6.21 @ 2,900’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” Gen 5 FMC 11” x 2-9/16” Hgr. w/ 2-7/8” NSCT T&B, & 2.5” Type “H” BPV Profile GENERAL WELL INFO API: 50-029-23040-00-00 Drilled and Run Frac String by Nabors 27E - 11/25/1997 Perforated and Frac’d w/ Wireline and CT– 12/11/2001 ESP Completion w/ Nabors 4-ES ESP Re-completions on 2/26/05, 2/8/06, 12/9/07, 4/25/08, 4/16/09, 6/7/09, 2/6/10, 4/20/11, 6/10/12, 3/14/13 & 11/17/14 & 10/13/2016 FRAC SUMMARY 12/11/01 – 117,298lbs of 16/20 C/lite and 73,740lbs of 12/18 C/lite behind pipe. _____________________________________________________________________________________ Revised by: TDF 7/7/2023 PROPOSED Milne Point Unit Well: MPU F-94 Last Completed: 10/13/2016 PTD: 201-170 TD =18,595’ (MD) / TD = 7,853’(TVD) 20” KB Elev.: 44’/ GL Elev.: 11’ 7” 3 5 6 7 8 9 10 & 11 12 13 14 3/8” Capstring 10-3/4” 1 2 10-3/4” Halliburton ES Cementer 15 16 & 17 Min ID= 2.205” @ 17,971’ MD KUP A Sands PBTD = 18,466’(MD) / PBTD = 7,727’(TVD) 4 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 94 / K-55 / N/A N/A Surf 112' 10-3/4" Surface 45.5 / L-80 / Btrc. 9.794 Surf 10,341’ 7" Production 26 / L-80 / Btc Mod 6.151 Surface 18,555’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surf ±18,112’ 4-1/2” Tubing 12.6 / L-80 / IBT 3.833 18,146’ 18,193’ CAPSTRING DETAIL 3/8” Capstring SS w/ 0.049 Wall N/A Surf ±18,112’ JEWELRY DETAIL No Depth Item 1 ±123’STA 2: GLM 2-7/8” x 1”, KBMM w/ DSOV – ID= 2.347” 2 ±17,891’STA 1: GLM 2-7/8” x 1”, KBMM w/ Dummy - ID= 2.347” 3 ±17,971’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 ±17,981.5’ Discharge Head: FPDIS 5 ±17,982’ Pumps: 62 Flex 17.5 & (2)134 Flex 17.5 – Bottom @ ±18,041 6 ±18,041’ Gas Separator: GRS FER N AR 7 ±18,044’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 ±18,051’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 9 ±18,058’ Motor: MSPI-250 10 ±18,074’ Sensor Well Lift Type E 11 ±18,076’ Centralizer 12 ±18,110’ Centralizer – Bottom @ ±18,112’ 13 18,155’ 7” x 4.5” Baker Premier Pkr. 14 18,181’ 4.5” HES XN-Nipple (ID= 3.813” / No-go 3.725”) 15 18,193’ 4.5” WLEG 16 18,469’ 7” Float Collar 17 18,554’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 18,290’ 18,292’ 7,557’ 7,559’ 2 11/25/01 Open Kup. A Sands 18,300’ 18,310’ 7,566’ 7,576’ 2 12/8/01 Open Kup. A Sands 18,328’ 18,330’ 7,593’ 7,595’ 10 12/1/01 Open Kup. A Sands 18,325’ 18,335’ 7,591’ 7,600’ 10 12/9/01 Open Reference Log: SWS Anadrill CDR Resistivity - Dated 10/17/2001 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks of Arctic Set (Approx.) in 30” Hole 10-3/4" Cmt w/ 1,153 sks PF “L”, 300 sx PF “C, 900 sx ” in 13-1/2” Hole 7” Cmt w/ 400 sks Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ to 3,100’ Max Hole Angle = 77 deg. Hole Angle through perforations = 15 deg. Max. Dg Leg Severity = 6.21 @ 2,900’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” Gen 5 FMC 11” x 2-9/16” Hgr. w/ 2-7/8” NSCT T&B, & 2.5” Type “H” BPV Profile GENERAL WELL INFO API: 50-029-23040-00-00 Drilled and Run Frac String by Nabors 27E - 11/25/1997 Perforated and Frac’d w/ Wireline and CT– 12/11/2001 ESP Completion w/ Nabors 4-ES ESP Re-completions on 2/26/05, 2/8/06, 12/9/07, 4/25/08, 4/16/09, 6/7/09, 2/6/10, 4/20/11, 6/10/12, 3/14/13 & 11/17/14 & 10/13/2016 FRAC SUMMARY 12/11/01 – 117,298lbs of 16/20 C/lite and 73,740lbs of 12/18 C/lite behind pipe. Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2022 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR 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: Convert to Water Injector 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): 18,595'N/A Casing Collapse Conductor N/A Intermediate 2,090psi Production 5,410psi 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 KR F-94 C.O. 432D Baker Premier and N/A 18,155(MD)/ 7,427(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. Authorized Signature: 12/7/2020 4-1/2"See Schematic MILNE POINT / KUPARUK RIVER OIL See Schematic 112' 20" 10-3/4" 20" 10,307' 18,523'7,240psi 4,454' 7,814' 10,341' 18,555' Perforation Depth MD (ft): 112' 112' 12.6# / L-80 / IBT TVD Burst 18,193 MD N/A Tubing Grade: 3,580psi 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23040-00-00 Hilcorp Alaska LLC Length Size 7,853' 18,466' 7,727' 2,105 18,466' Tubing MD (ft):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 ADL0355016 201-170 2-7/8" 6.5# / L-80 / EUE 8rd 18,112 dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:47 pm, Oct 23, 2020 320-454 Chad A Helgeson 2020.10.23 15:35:23 -08'00' DLB10/26/2020 ADL0025509 DSR-10/28/2020 X ADL0355018 MGR29OCT2020 BOPE test to 2500 psi. Per 20 AAC 25.412 (d) The operator shall provide a cement quality log. Per 20 AAC 25.412 (e) 24 hour notice for AOGCC to witness MIT-IA pressure test to 2000 psi. 10-404 Com m. 10/29/2020 dts 10/29/2020 JLC 10/29/2020 RBDMS HEW 11/9/2020 WINJ Conversion Well: MPU F-94 Date: 10-21-2020 Well Name:MPU F-94 API Number:50-029-23040-00 Current Status:ESP Producer Pad:F-Pad Estimated Start Date:December 7th, 2020 Rig:ASR Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:201-170 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Well EZ Entries Required Yes Current Bottom Hole Pressure:2,861 psi @ 7,557’ TVD SBHP:7.3 PPG Maximum Expected BHP:2,861 psi @ 7,557’ TVD SBHP:7.3 PPG MASP:2,105 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 75° @ 3,100’- 16,100’ MD Min ID:2.205” ID XN at 17,971’ MD Offset Injector Support:F-92, F-95 Brief Well Summary: MPU F-94 was drilled in November 2001 and completed in December 2001 as a Kuparuk River jet pumped producer. The first ESP was installed February 2002. MP F-94 has had multiple ESPs installed: February 2005, February 2006, December 2007, April 2008, April 2009, June 2009, February 2010, April 2011, June 2012, March 2013, November 2014, and October 2016. Notes Regarding Wellbore Condition x The 7” production casing was tested to 2,500 psi on 6/3/2012 down to 17,250’ MD Objective: x Pull existing ESP completion. x Install new 3-1/2” water injection completion. Area of Review (PTD#201170) Prior to the conversion of F-94 from Kuparuk production to Kuparuk Injection, an Area of Review (AOR) was conducted. This AOR found MP F-34 within ¼ mile of F-94’s entry point into the Kuparuk Formation. See attached table Area of Review MPU F-94 for annulus integrity and zonal isolation of all wells within the AOR. Sundry Procedure (Approval Required to Proceed) Pre-Rig Procedure 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. WINJ Conversion Well: MPU F-94 Date: 10-21-2020 5. Circulate wellbore volume (~610 BBLS) with source water down tubing, taking returns up casing to 500 bbl open top returns tank. Monitor well for returns during the well kill. 6. Confirm well is dead. Freeze protect tubing/casing as needed. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. 11. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/8.3 ppg source water prior to pulling BPV. 12. Set TWC. 13. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “ASR 1 BOP Test Procedure”. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8” and 3-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14.Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), (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 test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing. Pull TWC. Kill well w/8.3 ppg source water as needed. 16. Rig up spoolers for ESP cable and 3/8” Cap string. 17. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. Estimate 137K-lbs PU Wt. w/ no lubricated fluid (Note: Max Pull on 2-7/8” Connection: 144 K-lbs) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. Estimated PU wt. with lubricated fluid (90K-lbs – 110K-lbs). 18. Lay down tubing hanger. WINJ Conversion Well: MPU F-94 Date: 10-21-2020 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. a. Evaluate pulled tubing hanger for possible damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 19. POOH and lay down the 2-7/8” tubing while spooling ESP cable and 3/8” cap string. Lay down ESP and motor. a. Note any sand or scale inside or on the outside of the ESP in WSR. Pulled Equipment Disposition Tubing hanger Visually inspect on site then re-stock Tubing & Pup joints Junk ESP Cable Junk GLMS Visually inspect on site then re-stock ESP Equipment Visually inspect on site then provide to Baker for scrap Clamps Visually inspect on site then re-stock XN Nipple Visually inspect on site then re-stock 20. RU E-line 21. RIH Tractor/CBL and Log out from 18,140’ MD. (Review CBL Results with OE before running completion.) 22. RD E-line 23. PU and RIH w 3.5” 9.3# L-80 injection completion and packer. Ensure Bust Disk is run below the packer. Confirm the well is static before TIH with BHA. (Note: Top Fill the 3.5” TBG while TIH, Burst disk will prevent circulation down the TBG.) 24. Proposed Running Order a. WLEG b. Magnum Burst Disk (4,500 psi) c. 3-1/2” XN Nipple d. 10’ Pup Joint 3-1/2”, 9.3# tubing e. Packer set @ +/- 18,100’ MD (packer sets with 2,800 psi: Max 3,200 psi) f. 1 joint of 3-1/2”, 9.3# tubing g. 3-1/2” X Nipple (2.813” ID) h. ~ 509 jts of 3-1/2”, 9.3# tubing i. 3-1/2” X Nipple (2.813” ID) @ ±2,300’ MD j. ~ 74 jts of 3-1/2”, 9.3# tubing 25. Bullhead 415 bbls clean source water w/corrosion inhibitor and 65 bbls diesel freeze protect down the IA prior to setting the packer a. Freeze protect annular volume = .026 bpf*2,300’ = 60.6 bbls. 26. Space out to set packer at ±18,100’ and land the tubing into the hanger. RILDS. Lay down landing joint. a. Packer must be set within 200’ MD of the upper perfs. at 18,290’ MD. b. Note PU (Pick Up) and SO (Slack Off) weights on tally. CBL to AOGCC for review prior to POI. WINJ Conversion Well: MPU F-94 Date: 10-21-2020 27. Test tubing hanger to 250psi low/ 5,000psi High. 28. Pressure up the TBG to hydraulically set the packer per manufacturer’s setting procedure. 29. Conduct MIT-IA to 2,000 psi (0.25 psi/ 7,853’ Shoe TVD). i. Notify AOGCC at least 24 hours prior to performing Pre Injection MIT-IA ii. Submit completed Pre-Injection MIT-IA on 10-426 form 30. Set TWC. Post-Rig Procedure: 31. RD mud boat. RD BOPE house. Move to next well location. 32. RU crane. ND BOPE. 33. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 34. Pull TWC. 35. RD crane. Move returns tank and rig mats to next well location. 36. Replace gauge(s) if removed. 37. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form 5. AOR Map 6. AOR Review Isolation Sheet 7. MP F-34 CBL _____________________________________________________________________________________ Revised by: TDF 10/24/2016 SCHEMATIC Milne Point Unit Well: MPU F-94 Last Completed: 10/13/2016 PTD: 201-170 TD =18,595’ (MD) / TD = 7,853’(TVD) 20” KB Elev.: 44’/ GL Elev.: 11’ 7” 3 5 6 7 8 9 10 & 11 12 13 14 3/8” Capstring 10-3/4” 1 2 10-3/4” Halliburton ES Cementer 15 16 & 17 Min ID= 2.205” @ 17,971’ MD KUP A Sands PBTD =18,466’(MD) / PBTD = 7,727’(TVD) 4 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 94 / K-55 / N/A N/A Surf 112' 10-3/4" Surface 45.5 / L-80 / Btrc. 9.794 Surf 10,341’ 7" Production 26 / L-80 / Btc Mod 6.151 Surface 18,555’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surf 18,112’ 4-1/2” Tubing 12.6 / L-80 / IBT 3.833 18,146’ 18,193’ CAPSTRING DETAIL 3/8” Capstring SS w/ 0.049 Wall N/A Surf 18,112’ JEWELRY DETAIL No Depth Item 1123’STA 2: GLM 2-7/8” x 1”, KBMM w/ DSOV –ID= 2.347” 2 17,891’STA 1: GLM 2-7/8” x 1”, KBMM w/ Dummy -ID= 2.347” 3 17,971’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 17,981.5’ Discharge Head: FPDIS 5 17,982’ Pumps : 62 Flex 17.5 & (2)134 Flex 17.5 – Bottom @ 18,041 6 18,041’ Gas Separator: GRS FER N AR 7 18,044’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 18,051’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 9 18,058’ Motor: MSPI-250 10 18,074’ Sensor Well Lift Type E 11 18,076’ Centralizer 12 18,110’ Centralizer –Bottom @ 18,112’ 13 18,155’ 7” x 4.5” Baker Premier Pkr. 14 18,181’ 4.5” HES XN-Nipple (ID= 3.813” / No-go 3.725”) 15 18,193’ 4.5” WLEG 16 18,469’ 7” Float Collar 17 18,554’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 18,290’ 18,292’ 7,557’ 7,559’ 2 11/25/01 Open Kup. A Sands 18,300’ 18,310’ 7,566’ 7,576’ 2 12/8/01 Open Kup. A Sands 18,328’ 18,330’ 7,593’ 7,595’ 10 12/1/01 Open Kup. A Sands 18,325’ 18,335’ 7,591’ 7,600’ 10 12/9/01 Open Reference Log: SWS Anadrill CDR Resistivity - Dated 10/17/2001 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks of Arctic Set (Approx.) in 30” Hole 10-3/4" Cmt w/ 1,153 sks PF “L”, 300 sx PF “C, 900 sx ” in 13-1/2” Hole 7” Cmt w/ 400 sks Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ to 3,100’ Max Hole Angle = 77 deg. Hole Angle through perforations = 15 deg. Max. Dg Leg Severity = 6.21 @ 2,900’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” Gen 5 FMC 11” x 2-9/16” Hgr. w/ 2-7/8” NSCT T&B, & 2.5” Type “H” BPV Profile GENERAL WELL INFO API: 50-029-23040-00-00 Drilled and Run Frac String by Nabors 27E - 11/25/1997 Perforated and Frac’d w/ Wireline and CT– 12/11/2001 ESP Completion w/ Nabors 4-ES ESP Re-completions on 2/26/05, 2/8/06, 12/9/07, 4/25/08, 4/16/09, 6/7/09, 2/6/10, 4/20/11, 6/10/12, 3/14/13 & 11/17/14 & 10/13/2016 FRAC SUMMARY 12/11/01 – 117,298lbs of 16/20 C/lite and 73,740lbs of 12/18 C/lite behind pipe. _____________________________________________________________________________________ Revised by: TDF 10/23/2020 PROPOSED Milne Point Unit Well: MPU F-94 Last Completed: PTD: 201-170 TD =18,595’ (MD) / TD = 7,853’(TVD) 20” KB Elev.: 44’/ GL Elev.: 11’ 7” 3 5 6 7 8 10-3/4” 1 2 10-3/4” Halliburton ES Cementer 9 10 & 11 Min ID= 2.66” @ ±18,110’ MD KUP A Sands PBTD =18,466’(MD) / PBTD = 7,727’(TVD) 4 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 94 / K-55 / N/A N/A Surf 112' 10-3/4" Surface 45.5 / L-80 / Btrc. 9.794 Surf 10,341’ 7" Production 26 / L-80 / Btc Mod 6.151 Surface 18,555’ TUBING DETAIL 3-1/2" Tubing 6.5 / L-80 / EUE 8rd 2.992 Surf ±18,100’ 4-1/2” Tubing 12.6 / L-80 / IBT 3.833 18,146’ 18,193’ JEWELRY DETAIL No Depth Item 1 ±2,300’ 3.5” X-Nipple (2.813” ID) 2 ±18,069’ 3.5” X-Nipple (2.813” ID) 3 ±18,100’ 7” x 3.5” Baker Premier Pkr 4 ±18,110’ 3.5” XN-Nipple (2.66” ID) 5 ±18,112’ Magnum Burst Disk (2.92” ID) 6 ±18,114’ 3.5” WLEG 7 18,155’ 7” x 4.5” Baker Premier Pkr. 8 18,181’ 4.5” HES XN-Nipple (ID= 3.813” / No-go 3.725”) 9 18,193’ 4.5” WLEG 10 18,469’ 7” Float Collar 11 18,554’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 18,290’ 18,292’ 7,557’ 7,559’ 2 11/25/01 Open Kup. A Sands 18,300’ 18,310’ 7,566’ 7,576’ 2 12/8/01 Open Kup. A Sands 18,328’ 18,330’ 7,593’ 7,595’ 10 12/1/01 Open Kup. A Sands 18,325’ 18,335’ 7,591’ 7,600’ 10 12/9/01 Open Reference Log: SWS Anadrill CDR Resistivity - Dated 10/17/2001 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sks of Arctic Set (Approx.) in 30” Hole 10-3/4" Cmt w/ 1,153 sks PF “L”, 300 sx PF “C, 900 sx ” in 13-1/2” Hole 7” Cmt w/ 400 sks Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ to 3,100’ Max Hole Angle = 77 deg. Hole Angle through perforations = 15 deg. Max. Dg Leg Severity = 6.21 @ 2,900’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” Gen 5 FMC 11” x 2-9/16” Hgr. w/ 2-7/8” NSCT T&B, & 2.5” Type “H” BPV Profile GENERAL WELL INFO API: 50-029-23040-00-00 Drilled and Run Frac String by Nabors 27E - 11/25/1997 Perforated and Frac’d w/ Wireline and CT– 12/11/2001 ESP Completion w/ Nabors 4-ES ESP Re-completions on 2/26/05, 2/8/06, 12/9/07, 4/25/08, 4/16/09, 6/7/09, 2/6/10, 4/20/11, 6/10/12, 3/14/13 & 11/17/14 & 10/13/2016 FRAC SUMMARY 12/11/01 – 117,298lbs of 16/20 C/lite and 73,740lbs of 12/18 C/lite behind pipe. Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: October 23rd, 2020Subject: Changes to Approved Sundry Procedure for Well MP F-94Sundry #: 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 2019293077577507725770076757650762576007600757552575007500750074757450054774257425 740 0 740073757350732573257327325730073007300300727572752757 2 50507225720071757150712 5 25-7,589-7,158-7,267-7,513-7,313-7,356-7,439-7,194-7,333-7,262-7,262-7,328-7,447-7,088-7,473-7,394666191919199191972222222752225552222757225000007777377733-73F-17F-30F-30AF-34F-38F-65F-66AF-70F-70AF-70AL1F-74F-78F-78AF-78AL1F-78AL2F-92F-93F-93L1F-93L1-01F-93L1-02F-94F-95HILCORP ALASKA LLCMilne PointAOR MAP - WELL MPU F-940.25 MILE RADIUS CIRCLE IN REDTOP KUPARUK STRUCTUREPOSTED WELL DATAWell NumberSYMBOL HIGHLIGHTWELL SYMBOLSActive OilINJ Well (Water Flood)P&A OilShut In INJBy: RAGFEET0 1,500October 2, 2020PETRA 10/2/2020 11:22:21 AM Area of Review F-69PTD API WELL STATUSDistanceTop ofKuparuk Top of Cement Annulus IntegrityZonal Isolation201170 50029230400000 F-94 SI ESP Producer 0'18,249' MD(7,518' TVD)16,881'MD (est)(6,358' TVD)Passing casing test to2,500 psi against RBPset at 17,250' MD on6/3/20127" casing cemented with 400 sks (82 bbls) 15.8 ppgClass G cement inside 9-7/8" hole. Bumped plug.Estimated TOC at 16,881' MD. No CBL ran. 10-3/4"casing cemented inside 13-1/2" hole 2 stage cementjob with 240 BBLS cement to surface.197197 50029228240000 F-34 ESP Producer 600'18,958' MD(7,558' TVD)~18,040'MD(7,356' TVD)Passing casing test to2,000 psi against RBPset at 8,750' MD on9/29/20167" casing cemented with 263 sks Class G cementinside 8-1/2" hole. Bumped plug. Follow-up CBL on1/26/1998 showed TOC at ~18,040' MD. 9-5/8"casing cemented inside 12-1/4" hole with 506 bbls of15.6 ppg Class E and 500 bbls of 15.8 ppg Class Gcement.Area of Review MPU F-94 STATE OF ALASKA _ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate LI Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: ESP Replacement ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 201-170 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23040-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: - i ADL0355016 MILNE PT UNIT KR F-94 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): 0 C N/A MILNE POINT/KUPARUK RIVER OIL u 11.Present Well Condition Summary: -„ Total Depth measured 18,595 feet Plugs measured 18,466 feet true vertical 7,853 feet Junk measured N/A feet Effective Depth measured 18,466 feet Packer measured 18,155 feet true vertical 7,727 feet true vertical 7,427 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Intermediate 10,307' 10-3/4" 10,341' 4,454' 3,580psi 2,090psi Production 18,523' 7" 18,555' 7,814' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 18,112' 7,385' Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT 18,193' 7,463' Packers and SSSV(type,measured and true vertical depth) Baker Premier N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0- 0 0 440 0 Subsequent to operation: • 46 19 692 0 238 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ suss❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-497 Contact Paul Chan Email pchanhiIcorp.com J 01... fc-1 rA.y c Printed Name Bo York �( Z Title Operations Manager j J� Signature _ Phone 777-8345 Date-t 0 5 4 /z- s---(6 ,/4- RBDMS--tvOC -2 8 2-116 Form 10-404 Revised 5/2015 Submit Original Only Milne Point Unit Well: MPU F-94 SCHEMATIC Last Completed: 10/13/2016 Hi Anka,LLC PTD: 201-170 TREE&WELLHEAD KB Elev.:44'/GL Elev.:11' Tree 5M CIW 2-9/16" ;" 11"Gen 5 FMC 11"x 2-9/16"Hgr.w/2-7/8" &, j , s Wellhead NSCT T&B,&2.5"Type"H"BPV Profile 20' y ' 10-3/4" _ OPEN HOLE/CEMENT DETAIL Halliburton ES 1 1 20" Cmt w/260 sks of Arctic Set(Approx.)in 30"Hole Cementer i 10-3/4" Cmt w/1,153 sks PF"L",300 sx PF"C,900 sx"in 13-1/2"Hole 7" Cmt w/400 sks Class"G"in 9-7/8"Hole y i CASING DETAIL '4. Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 94/K-55/N/A N/A Surf 112' 10-3/4":ii ► 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 10,341' 7" Production 26/L-80/Btc Mod 6.151 Surface 18,555' TUBING DETAIL 2-7/8" _ Tubing 6.5/L-80/EUE 8rd 2.347 Surf 18,112' 3/8 Capstring� - 4-1/2" Tubing 12.6/L-80/IBT 3.833 18,146' 18,193' CAPSTRING DETAIL 3/8" Capstring SS w/0.049 Wall N/A Surf 18,112' ( WELL INCLINATION DETAIL KOP @ 500'to 3,100' Max Hole Angle=77 deg. Hole Angle through perforations=15 deg. Max.Dg Leg Severity=6.21 @ 2,900' JEWELRY DETAIL No Depth II Item 1 123' STA 2:GLM 2-7/8"x 1",KBMM w/DSOV-ID=2.347" 2 17,891' STA 1:GLM 2-7/8"x 1",KBMM w/Dummy-ID=2.347" 2 3 17,971' 2-7/8"HES XN-Nipple(2.205 No-go ID) 4 17,981.5' Discharge Head:FPDIS 5 17,982' Pumps:62 Flex 17.5&(2)134 Flex 17.5-Bottom @ 18,041 Mn ID 2205„@ r 4 6 18,041' Gas Separator:GRS FER N AR 17,971'MD- ra 3 7 18,044' Upper Tandem Seal: GSB3DBUT SB/SB PFSA k + 8 18,051' Lower Tandem Seal: GSB3DBUT SB/SB PFSA ,', 1 4 9 18,058' Motor: MSPI-250 i10 18,074' Sensor Well Lift Type E i" ( t 5 11 18,076' Centralizer 12 18,110' Centralizer-Bottom @ 18,112' 6 13 18,155' 7"x 4.5"Baker Premier Pkr. 7 14 18,181' 4.5"HES XN-Nipple(ID=3.813"/No-go 3.725") 1 e k 8 15 18,193' 4.5"WLEG k ,y 16 18,469' 7"Float Collar i i 17 18,554' 7"Float Shoe ak 9 PERFORATION DETAIL sA I 41 If 10&11 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status "; 31 "11 12 Kup.A Sands 18,290' 18,292' 7,557' 7,559' 2 11/25/01 Open 41/2' y Kup.A Sands 18,300' 18,310' 7,566' 7,576' 2 12/8/01 Open Kup.A Sands 18,328' 18,330' 7,593' 7,595' 10 12/1/01 Open V Kup.A Sands 18,325' 18,335' 7,591' 7,600' 10 12/9/01 Open 1' s 13 Reference Log:SWS Anadrill CDR Resistivity-Dated 10/17/2001 11 )'` FRAC SUMMARY I I 14 12/11/01-117,298lbs of 16/20 C/lite and («1 1 73,7401bs of 12/18 C/lite behind pipe. t 15 }KUPASands GENERAL WELL INFO 4',. 4'''.'° API:50-029-23040-00-00 7" J 16&17 Drilled and Run Frac String by Nabors 27E -11/25/1997 TD=18,595'(MD)/TD=7,853'(TVD) Perforated and Frac'd w/Wireline and CT-12/11/2001 PBTD=18,466'(MD)/PBTD=7,727'(TVD) ESP Completion w/Nabors 4-ES ESP Re-completions on 2/26/05,2/8/06,12/9/07,4/25/08, 4/16/09,6/7/09,2/6/10,4/20/11,6/10/12,3/14/13& 11/17/14&10/13/2016 hevised by:TDF 10/24/2016 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 CTU 50-029-23040-00-00 201-170 9/24/16 10/13/16 Daily Operations: 9/21/2016-Wednesday No activity to report. 9/22/2016-Thursday No activity to report. 9/23/2016- Friday No activity to report. 9/24/2016 -Saturday MIRU Halliburton 1.75" Mast CTU. Planned to test BOPE. Waiting for tanks and fluid. Return in morning .;No Activity. Daylight coil work only. 9/25/2016-Sunday Crew on site. Start equipment. PJSM. Prepare to start BOPE test. BOPE Test. MU and RIH with 1.75"jet nozzle.Jet down to 18,022' ctmd (discharge head) at 1 bpm/1650psi CTP/90 psi WHP. Tag at 18,022' ctmd. Pumped 2 x 5 bbl gel sweeps- 1 at 10,000'/ 1 on bottom. POOH jetting. FP coil and top of well.Tag up. Shut in well. L/D tools and MU Statewide MHA for tubing punch run tomorrow. Secure well for night. No Activity. Daylight coil unit only. 9/26/2016- Monday Arrive on site. SLB TCP on site. PJSM. PT MHA to 3,500psi. Circ coil over to water, capturing 60/40 meth for re-use. MU firing head. Get on well and PT externally around firing head. Get off well. MU 5' x 1.56" OD TCP gun. Get on well. PT QTS. • RIH with tubing punch gun.Tag discharge head at 18,023' ctmd. PU 1'. Pump down 1/2" steel ball. Land ball, shear firing head. 2 feet of shots/4 SPF/9 holes. POOH. Pump down backside of coil to verify circulation to IA. Caught pressure after 2 bbls. WHP shot up to 900psi. No indication of holes. Resume POOH. Tag up at surface. Shut in and L/D gun.All shots fired. Line up to pump down tubing and monitor both tubing and IA pressure. Able to bullhead down at 2 bpm 80 PSI WHP/ IA pressure 483psi and increasing.Tubing punch successful. FP tubing with 60/40 meth. RDMO. 9/27/2016-Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 ASR#1 50-029-23040-00-00 201-170 9/24/16 Future Daily Operations: 10/5/2016-Wednesday ASRC Crane Assisted Nipple down Tree and Remove/ Nipple up Bop Stack to Four Bolts. Install Well House and Rig Floor, Set Mud Boat, and Pit System into Place, Raise and Pin Derrick, Fill Active System with 270 bbls. Pumping and Thawing Heating up Pit fluid to 120 Degrees (Release ASRC Crane and Northern Energy Service Trucks at 2300 hrs.) Rig up and High Pressure Service Lines to Rig and Bop Stack, finish torqueing up Bop Flanges, Rig up Cat Walk and pipe Racks, Install Accumulator Lines to Bop Stack, Function Test Bop, Change out 5-1/5" Pipe Rams to 2-7/8" x 5" VBR'S in Stack. 10/6/2016 -Thursday Continue to RU on F-94. Torque BOP bolts, hook up accumulator lines. NOTE: AOGCC was notified of upcoming BOP test on F-94 via website at 11:13 hrs on 10-5-16. Pull BPV, Install TWC.Shell Test BOPs.Test BOPs per F-94 Sundry, Tested with 2- 7/8" Test joint,Test Rams & all valves to 250/2,500 psi,Tested Annular to 250/2,500 psi.Tested gas alarms & PVTs,Tested Accumulator(Test was witnessed by AOGCC Matthew Herrera.) Pull TWC. Close Blind Rams, Monitor Wellbore while waiting on Doyon 14 to arrive to L-pad while blocking the main Road. Maintain Rig, Clean and perform maintenance. 10/7/2016- Friday Perform Rig maintenance & maintain Rig while waiting on Doyon 14 to arrive on L-pad, Installed new Drip pan, clean BOP enclosure & BOPs. 10/8/2016-Saturday Continue to maintain Rig, Clean & perform maintenance on Rig while waiting on Doyon 14 to clear L-pad access road, Crew assisted with moving Matting boards with forklift. 10/9/2016-Sunday Continue to maintain Rig, Clean & perform maintenance on Rig while waiting on Doyon 14 to clear L-pad access road. 10/10/2016- Monday Continue to Clean & Maintain rig while waiting on Doyon 14 to clear MPL pad access road. Make up landing joint to tubing hanger, back out lock down screws, monitor wellbore, Pull Hanger to Rig floor, unseat hanger @ 86K, max pull 89K, disconnect ESP cable, remove penetrators, lay down tubing hanger.TOOH, Laying down 2-7/8" tubing to 15,300 ft. Rig Service. Continued Trip out of the hole F/15,300'.to 8,660'. Change over Reels in Spooler. Continued Trip out of the hole F/8,660' to 5,100' 10/11/2016-Tuesday Service Rig, Clear Codes on Rig Engine with ASRC mechanic. Continue to TOOH with 2-7/8" tubing F/5,100'T/2,040'. Pull spooling unit out, change out spools. Continue to TOOH with 2-7/8"tubing F/2,040'T/Surface. Lay down ESP Assy. Rig down elephant trunk ESP cable hose, clear& clean rig floor. Offload old ESP assembly. Load New ESP assembly on catwalk. Tally Tubing. Rig Service. Pick up Service New ESP Pump Assembly.Trip in the hole ESP Completion Assembly, Checking Cable on joint 63 @ 2,140 ft. R/U Circulate through ESP Pump Assembly, Fill Tubing w/4 bbl. Flushed Pump w/2 bbl with a Pump rate of 1 bpm at 75psi. Continued Trip in the hole ESP Completion Assembly to 3,400'. r Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-94 ASR#1 50-029-23040-00-00 201-170 9/24/16 10/13/16 Daily pperat :0s" _' y 1 10/12/2016-Wednesday Rig Service, Check fluids in equipment. Continue to TIH with ESP & 2-7/8"Tubing. Check ESP cable conductivity each 2,000' & Fill Tubing &flush 2 bbls through pump at each cable test,T/8,418'. Make Reel to Reel Splice on ESP Cable. Continue to TIH with ESP & 2-7/8"Tubing. F/8,418 ft.to 10,400'. Check ESP cable conductivity each 2,000' & Fill Tubing &flush 2 bbls through pump. Load and Tally Pipe. Continue to TIH with ESP & 2-7/8" Tubing. F/10,400'to 12,415'. Check ESP cable conductivity each 2,000' & Fill Tubing&flush 2 bbls through pump. Load and Tally Pipe. Continue to TIH with ESP & 2-7/8" Tubing. F/12,415'to 13,823'. 10/13/2016-Thursday Continue to TIH with ESP &2-7/8" Tubing F/ 13,823'T/ 16,914'. Check ESP cable conductivity each 2,000' & Fill Tubing & flush 2 bbls through pump at each cable test. Make reel to reel splice on ESP cable. Continue to TIH with ESP & 2-7/8" Tubing F/ 16,914 T/ 18,089'.AOGCC notified of upcoming BOP test f/ MPS-90 @ 15:59, witnessed waived by AOGCC rep Lou Grimaldi @ 16:10. Make up Landing joint&Tubing Hanger, Install ESP Penetrator, Install Penetrator connector and install Cap line to hanger. PU WT. = 99K,Slack off WT= 25K,Total of 573 joints run.Test connectivity of ESP cable at lower portion of penetrator, prior to landing TBG hanger. (Good Test)Adjust BOP riser to center hanger while attempting to land hanger on seat. RIH w/TBG hanger to 16.5'md f/floor and land on seat.Alaska Crane on location, due to high winds (Over 30mph),to perform rig floor pick, wellhouse pick, and set production tree. NES on location to begin moving equipment to well MPS-90. RILDS, B/O landing joint and L/D. P/U T-bar and have wellhead rep Dean Norris set BPV. (Released Rig @ 22:00 Hours on 10-13-16) Begin R/D process. Electricians on location to R/D fire and gas alarm system. L/D ESP sheave, un- pin torque tube connection in mast, adjust rig floor equipment into position f/move, load catwalk, pipe racks,tool sheds, etc and move to S-pad. Roll up herculite containment and re-use on S-pad. 10/14/2016- Friday No activity to report. 10/15/2016-Saturday No activity to report. 10/16/2016-Sunday No activity to report. 10/17/2016- Monday No activity to report. 10/18/2016-Tuesday No activity to report. • • V OF ro ce,l,1// 6), THE STATE Alaska Oil and Gas fLASI�:.A Conservation Commission i o A 5 j 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 OFA 5�P Fax: 907.276.7542 www.aogcc.alaska.gov Bo York ES) FEB B ?1L Operations Manager SCAM Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-94 Permit to Drill Number: 201-170 Sundry Number: 316-497 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this T`day of October, 2016. RBDMS UL 0 4 2016 • IP( F ,L,i.i,q' STATE OF ALASKA ✓ L/ �� SEP 2 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ADGCC 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q 1 Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ • Change Approved Program El Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Replacement❑✓ ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development 2. 201-170 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23040-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D • Will planned perforations require a spacing exception? Yes ❑ No 0 i MILNE PT UNIT KR F-94. 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0355016 • MILNE POINT/KUPARUK RIVER OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 18,595" 7,853' • 18,466'• 7,727' • 1,946 18,466' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Intermediate 10,307' 10-3/4" 10,341' 4,454' 3,580psi 2,090P si Production 18,523' 20" 18,555' 7,814' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-7/8" 6.5#/L-80/EUE 8rd 18,078 See Attached Schematic/ See Attached Schematic 4-1/2" 12.6#I L-801 IBT 18,193 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Premier and N/A i 18,155(MD)/7,427(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development Q ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/13/2016 Commencing Operations: OIL 0 • WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 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 pchant7a.hilcorp.com Printed Nam Bo York Title Operations Manager Signatur drIi. Phone 777-8345 Date 9/28/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. //11 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: -Yr t 5 P ) / SL ).- &-(7 —77--a . Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS 1 L.. Ut,I 0 4 2016 Spacing Exception Required? Yes ❑ _No_ Subsequent Form Required:. L10l_I / APPROVED BY / b I 1 I 1jApproved • COMMISSIONER THE COMMISSION Date: + D O D�6 f A' M Subs in Form and Form 10-403 Revised 11/2015 P'pi`r p IiT�'�o d for 1 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU F-94 Hilcorp Alaska,LL Date:09/27/2016 Well Name: MPU F-94 API Number: 50-029-23040-00 Current Status: Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: October 13th, 2016 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-170 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number 165463 t ' 1:01; ! l?e, '141 X11411': ESP Re air7, Current Bottom Hole Pressure: 2,681 psi © 7,349' TVD (ESP PP 09/07/2016/7.02 ppg EMW) Maximum Expected BHP: 2,681 psi @ 7,349' TVD (No new perfs being added) / MPSP: 1,946 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-94 was drilled in November 2001 and completed in December 2001 as a Kuparuk River jet pumped producer.The first ESP was installed February 2002. MP F-94 has had multiple ESPs installed: February 2005, February 2006, December 2007,April 2008,April 2009,June 2009, February 2010, April 2011,June 2012, March 2013, and November 2014. The ESP has failed. Notes Regarding Wellbore Condition • The 7" production casing was tested to 2,500 psi on 6/3/2012 down to 17,250' MD. • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. 4kck„24. N� �•� Objective: CO 310A Replace failed ESP. ! "� Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • Well Prognosis Well: MPU F-94 • Hilcorp Alaska,LL) Date:09/27/2016 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500-psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. 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 test. 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. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2014 ESP swap was 121K lbs. 45 le 1 .4,/Sok- /63 b. The PU weight during the 2013 ESP swap was 120K lbs. (includes 40K block weight) c. The PU weight during the 2012 ESP swap was 125K lbs. Brokeover at 145K lbs. Includes 40K block weight. d. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. e. Contingency Casing Jack Procedure: if the tubing hanger will not come off seat or the ESP crA5o%c, will not come off bottom after circulating lubricant, RU casing jacks as follows: PU Casing Jacks via the beaver slide and Tugger winches to rig floor ii. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test same. iii. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point iv. 100%Yield strength of 2-7/8", 6.5#, L-80= 145K lbs • • Well Prognosis Well: MPU F-94 Hamra Alaska,LU Date:09/27/2016 v. Cycle jacks up and down to ensure proper function (dry run without being connected to hanger). 16. Recover the tubing hanger. 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. 17. POOH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used as noted. Lay down failed ESP. a. Replace bad joints of tubing as necessary. b. Look for over-torqued connections from previous Doyon 16 tubing runs. 18. PU & RIH with 7" 26#scraper assembly to 18,145' MD (or as deep as practical) on 3-1/2" workstring. Circulate the well clean. 19. POOH. L/D scraper assembly and 3-1/2" workstring. 20. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at± 18,100' MD. a. Upper GLM @ ± 140' MD w/SO teji; b. Lower GLM @ ±17,900' MD c. 2-7/8" XN Nipple @ ±18,000'MD d. Base of ESP @ ± 18,100' MD e. Run 3/8" capillary string to base of ESP. 21. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 22. Set BPV. Post-Rig Procedure: 23. RD mud boat. RD BOPE house. Move to next well location. 24. RU crane. ND BOPE. 25. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 26. RD crane. Move 500 bbl returns tank and rig mats to next well location. 27. Replace gauge(s) if removed. 28. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO MOC Form • • Milne Point Unit • Well: MPU F-94 II SCHEMATIC Last Completed: 11/19/2014 Hilcorp Alaska,LLC. PTD: 201-170 TREE&WELLHEAD KB Elev.:44'/GL Elev.:11' Tree 5M CIW 2-9/16" _, '' 11"Gen 5 FMC 11"x 2-9/16"Hgr.w/2-7/8" 20 . , Wellhead NSCT T&B,&2.5"Type"H"BPV Profile 1. , 10-3/4" OPEN HOLE/CEMENT DETAIL Halliburton ES 1 i* 20 " Cmt w/260 sks of Arctic Set(Approx.)in 30"Hole Cementer .41 " 10-3/4" Cmt w/1,153 sks PF"L",300 sx PF"C,900 sx"in 13-1/2"Hole e. 7" Cmt w/400 sks Class"G"in 9-7/8"Hole is y, ; CASING DETAIL „1 Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 94/K-55/N/A N/A Surf 112' 10-3/4"° N 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 10,341' 7" Production 26/L-80/Btc Mod 6.151 Surface 18,555' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 18,078' 3/6”Capstrirg 1 4-1/2" Tubing 12.6/L-80/IBT 3.833 18,146' 18,193' CAPSTRING DETAIL 3/8" Capstring SS w/0.049 Wall N/A Surf 18,076' WELL INCLINATION DETAIL KOP @ 500'to 3,100' Max Hole Angle=77 deg. bi Z Hole Angle through perforations=15 deg. S-1--i0 Max.Dg Leg Severity=6.21 @ 2,900' s 4€ #, JEWELRY DETAIL No Depth Item 1 140' GLM 2-7/8"x 1",KBMM w/Dummy(ID=2.347")9-08-16 2 17,827' GLM 2-7/8"x 1",KBMM w/Dummy(ID=2.347") 2 3 17,979' 2-7/8"HES XN-Nipple(2.250 No-go ID) 4 18,022' GPDIS Discharge Head 5 18,023' 137-P17 SXD Pump MnID 225"@ 6 18,042' Gas Separator GRSFTX AR H6 17,979'ND 01 3 7 18,047' Upper Tandem Seal Section GSB3DBUT SB/SB PFSA 1 1 y 8 18,053' Lower Tandem Seal Section GSB3DBLT SB/SB PFSA CL5 4 81' 4 9 18,060' MSP1-250 Motor/168 HP/3460 Volt/30 Amp fi 10 18,074' Sensor Well Lift MGU 5 11 18,076' Centralizer-Bottom @ 18,078' r 12 , 18,155' 7"x 4.5"Baker Premier Pkr. R'6 13 18,181' 4.5"HES XN-Nipple(ID=3.813"/No-go 3.75") 7 14 18,193' 4.5"WLEG . 8 15 18,469' 7"Float Collar f 16 18,554' 7"Float Shoe ; : ; , 9 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 10 Kup.A Sands 18,290' 18,292' 7,557' 7,559' 2 _ 11/25/01 Open 11 Kup.A Sands 18,300' 18,310' 7,566' 7,576' 2 12/8/01 Open 41/2" up. ans , , , , 2/1/01 Open l;* -I 2/9/01 Open ill ,4, ' 4 n4, 4 , ,r, Kup.A Sands 18,325' 18,335' 7,591' 7,600' 10 1 Reference Log:SWS Anadrill CDR Resistivity-Dated 10/17/2001 12 FRAC SUMMARY Ir 13 12/11/01-117,2981bs of 16/20 C/lite and 73,7401bs of 12/18 C/lite behind pipe. 14 • 1 KUP ASaris GENERAL WELL INFO ) s0- API:50-029-23040-00-00 y' 1" 'k; 15816 Drilled and Run Frac String by Nabors 27E -11/25/1997 Perforated and Frac'd w/Wireline and CT-12/11/2001 TD=18,595'(MD)/TD=7,853'(TVD) ESP Completion w/Nabors 4-ES PBTD=18,466'(MD)/PBTD=7,727'(TVD) ESP Re-completions on 2/26/05,2/8/06,12/9/07,4/25/08, 4/16/09,6/7/09,2/6/10,4/20/11,6/10/12,3/14/13& 11/17/14 Revised by:BK 9/12/2016 H . • Milnll:e PointMPU Unit We • PROPOSED Last Completed: 11/19/2014 Ililcoru Alaska,LLC PTD: 201-170 TREE&WELLHEAD KB Elev.:44'/GL Elev.:11' Tree 5M CIW 2-9/16" Lwellhead 11"Gen 5 FMC 11"x 2-9/16"Hgr.w/2-7/8" 20" . ,d ., , NSCT T&B,&2.5"Type"H"BPV Profile 10-3/4" OPEN HOLE/CEMENT DETAIL Halliburton ES�' 1 20" Cmt w/260 sks of Arctic Set(Approx.)in 30"Hole Cementer 10-3/4" Cmt w/1,153 sks PF"L",300 sx PF"C,900 sx"in 13-1/2"Hole 7" Cmt w/400 sks Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 94/K-55/N/A N/A Surf 112' 143/4" A & 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 10,341' 7" Production 26/L-80/Btc Mod 6.151 Surface 18,555' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf ±18,100' 3/8"Capstring 4-1/2" Tubing 12.6/L-80/IBT 3.833 18,146' 18,193' CAPSTRING DETAIL 3/8" Capstring SS w/0.049 Wall N/A Surf 18,076' WELL INCLINATION DETAIL KOP @ 500'to 3,100' Max Hole Angle=77 deg. Hole Angle through perforations=15 deg. Max.Dg Leg Severity=6.21 @ 2,900' JEWELRY DETAIL No Depth Item 1 ±140' GLM 2-7/8"x 1",KBMM w/Dummy(ID=2.347")9-08-16 2 ±17,900' GLM 2-7/8"x 1",KBMM w/Dummy(ID=2.347") 2 3 ±18,000' 2-7/8"HES XN-Nipple(2.250 No-go ID) 4 ±18,038' GPDIS Discharge Head 5 ±18,040' 137-P17 SXD Pump Min ID 2.25"@ 6 ±18,061' Gas Separator GRSFTX AR H6 18,000'MD 3 7 ±18,066' Upper Tandem Seal Section GSB3DBUT SB/SB PFSA ifi 8 ±18,070 Lower Tandem Seal Section GSB3DBLT SB/SB PFSA CL5 i 4 9 ±18,077' MSP1-250 Motor/168 HP/3460 Volt/30 Amp 10 ±18,097' Sensor Well Lift MGU 5 11 ±18,099' Centralizer-Bottom @±18,100' 12 18,155' 7"x 4.5"Baker Premier Pkr. 6 13 18,181' 4.5"HES XN-Nipple(ID=3.813"/No-go 3.75") 14 18,193' 4.5"WLEG 1 t 8 15 18,469' 7"Float Collar 1 A "1 16 18,554' 7"Float Shoe \41..j e PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 10 am Kup.A Sands 18,290' 18,292' 7,557' 7,559' 2 11/25/01 Open 11 Kup.A Sands 18,300' 18,310' 7,566' 7,576' 2 12/8/01 Open 4-1/ ....,. ......_,,Altii 2" A Sands 18,328' 18,330' 7,593' 7,595' 10 12/1/01 Open Kup.A Sands 18,325' 18,335' 7,591' 7,600 10 12/9/01 Open i :. Reference Log:SWS Anadrill CDR Resistivity-Dated 10/17/2001 12 FRAC SUMMARY 13 12/11/01-117,2981bs of 16/20 C/lite and 73,7401bs of 12/18 C/lite behind pipe. 14 }KUPASands GENERAL WELL INFO JJ API:50-029-23040-00-00 7" 5&is Drilled and Run Frac String by Nabors 27E -11/25/1997 a iiiPerforated and Frac'd w/Wireline and CT-12/11/2001 1D=18,595'(MD)/TD=7,853'(TVD) ESP Completion w/Nabors 4-ES PBTD=18,466'(MD)/PBTD=7,727'(TVD) ESP Re-completions on 2/26/05,2/8/06,12/9/07,4/25/08, 4/16/09,6/7/09,2/6/10,4/20/11,6/10/12,3/14/13& 11/17/14 Revised by:STP 9/27/2016 • 0 . EiMilne Point ASR Rig 1 BOPE flilrr=rp_tla*Ra,t.1 t. 11" BOPE Stripping Head r r ll 3.98' ' Shaffer ° 11"- 5000 iii itiiii Illii I 1:11111 III 1! , \ ____;- 4,54' H CI A -U J H VBR or Pipe Rams ,0® 11" 5000®Lip (^J= 1= Blind .1 il 'eV III ail III f 1 ii 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves \ I i 2.00 _ ° ' _ ° k° �� ' ! c �r 1.1 ;' 0 71 I1I.1ii■i111TI 1► ilt Manual Manual Manual HCR Updated 8/19/2015 II • ! MPU F-94 EXISTING TREE/WELLHEAD Wellhead/Tree Hilcarp Alaska,LLCMilne Point Unit i1.1. t.! 111,01111,11 is0,/ 2 9/16" CIW 5M Swab Valve .!.IMO i.( N ,, t,-,,-.'0.,,, ,-,,--,i_. , 4. ,.... ,,I. 2 9/16" CIW 5M Wing Valve `` ,e 0 �' 2 9/16" CIW 5M SSV with Cameron actuator pOm „Iii '',v-, p - 2 9/16" CIW 5M Master Valve o V ` 4 .fi. ,.f. 11111"x29/16"FMC 5M iiir ESP Tbg Adapter 11"x 11"FMC 5M Tubing Head h-: u �. II' 'I �`�,� " 1 1141111 7 2 e ir 2 1/16"CIW 3M HWO Valve 1, 11111 , 1s® 11"x 11"FMC SMS__ � Casing Head 1.1: 1i1 I°� �- 2 1/16"CIW 3M HWO Valve • • - E _ a= . $ § � AL 7 ctA L b � � -t3� 1 o .; v F. w° w co a> xw X OTS 913 ma c v U 8 0. y T . Oy Z Z U: V!� y ,U .., O O % O z W Z363 TTS 1713 m D YO m-, U, m Ali co m d u °° m 0 o m 0 n o 83 m N. V I T U, C J N .'2' C J R N d4 � O L., A cc v W u @ d x , r..._ All. i- '- Zuignl I filt h I , Y N N Vl Z 0. 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II : CDrn 43 i i y O 0 o. 0a. ii o a as u - O 0 V , 2.2 co .r-i = a fl N 0 N Q a STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION C. /1ISSION ISG G N • REPORT OF SUNDRY WELL OPERATIONS DEC 16 2014 1. Operations Performed: AOGCc ❑Abandon ❑ Repair Well ❑ Plug Perforations 0 Perforate ❑ Re-Enter Suspended Well ❑Alter Casing ® Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other 0 Change Approved Program 0 Operation Shutdown ❑Stimulate-Other ElTime Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 0 Exploratory 0 Stratigraphic 201-170 3. Address: ® Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-23040-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025509&355016 MPF-94 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Milne Point Unit/Kuparuk River Sands 11. Present well condition summary: Total depth: measured 18595' feet Plugs:(measured) None feet true vertical 7853' feet Junk:(measured) None feet Effective depth: measured 18466' feet Packer: (measured) 18155' feet true vertical 7727' feet Packer: (true vertical) 7427' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 20" 35'- 112' 35'- 112' Surface 10307' 10-3/4" 34'- 10341' 34'-4454' 5210 2480 Intermediate Production 18523' 7" 32'- 18555' 32'-7814' 7240 5410 Liner Perforation Depth. Measured Depth: 18290'- 18335' feet True Vertical Depth: 7557'-7600' feet Tubing(size,grade,measured and true vertical depth): 2-7/8",6.5#; L-80; 18078'; 7353'; 4-1/2", 12.6# L-80 18146'- 18193' 7418'-7463' Packers and SSSV(type, measured and true vertical depth): 7"x 4-1/2" Baker Premier Packer 18155' 7427' 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED MAY 2 0 2015 Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 219 68 723 300 274 Subsequent to operation: 0 0 0 0 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑ Exploratory 0 Stratigraphic ® Development ❑Service ® Daily Report of Well Operations 16. Well Status after work: ®Oil 0 Gas ❑WDSPL ®Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG 0 GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Abby Warren, 564-5720 Email: Abigail.Warren©bp.com N/A Printed Name: Joe Lastufka Title: Drilling Technologist Signature: to A,.._ one: 564-4091 Date: 2.fJ 6/14- Form 10-404 Revised 10/2012T ubmit Original Only ,,i�,s/ � l'.' '✓ Z RBC MS DEC 17 20y North America-ALASKA-BP Page 1 of 6 Operation Summary Report Common Well Name:MPF-94 AFE No Event Type:WORKOVER(WO) I Start Date:11/14/2014 End Date:11/19/2014 X4-010W1-E:(1,930,000.00) Project:Milne Point I Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/15/2001 12:00:00AM Rig Release:11/19/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292304000 Active datum:Kelly Bushing/Rotary Table @44.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/14/2014 12:00 - 13:30 1.50 MOB P PRE PJSM,RDMO OF MPL-36 -BRIDLE UP BLOCKS,R/D RIG FLOOR 13:30 - 15:00 1.50 MOB P PRE MOVE RIG OFF OF MPL-36 AND POSITION ON PAD -LOWER DERRICK 15:00 - 16:00 1.00 MOB P PRE LOAD BOP ON BOP STAND AND REMOVE FROM CELLAR -INSTALL REAR BOOSTER WHEELS IN CELLAR AND FUNCTION SAME 16:00 - 17:30 1.50 MOB P PRE PJSM,MOVE RIG FROM MPL-PAD TO MPF-PAD 17:30 - 19:00 1.50 MOB P PRE REMOVE REAR BOOSTERS FROM CELLAR -INSTALL BOP ON STAND IN CELLAR 19:00 - 20:30 1.50 MOB P PRE MOVE RIG OVER WELL MPF-94,WSL PRESENT -SHIM AND LEVEL RIG SPOT CUTTINGS TANK 20:30 21:00 0.50 MOB P PRE 1PJSM,RAISE DERRICK AND PIN IN PLACE -SPOT CHANGE TRAILER 21:00 - 22:00 1.00 MOB P PRE BRIDLE DOWN BLOCKS -R/U RIG FLOOR EQUIPMENT 22:00 - 00:00 2.00 WHSUR P DECOMP TAKE ON 9.3 PPG BRINE,HEAT AND WATER BACK TO 9.0 PPG -R/U CIRCULATION LINES TO WELL KILL MANIFOLD,TREE,AND HARD LINE TO FLOW BACK TANKS -ACCEPT RIG AT 22:00 HOURS ON MPF-94 11/15/2014 00:00 - 03:00 3.00 WHSUR P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -R/U CIRCULATION LINES TO WELL KILL MANIFOLD,TREE,AND HARD LINE TO FLOW BACK TANKS -TEST LINES,250/3500 PSI,5 MIN,CHART -BLOW DOWN LINES -CONTINUE LOAD PITS WITH 120 DEGREE 9.0 PPG BRINE 03:00 - 03:30 0.50 WHSUR P DECOMP HOLD RIG EVACUATION DRILL AND AAR WITH ALL PERSONEL ON LOCATION 03:30 - 07:30 4.00 WHSUR P DECOMP PJSM,R/U WELL SUPPORT LUBRICATOR -TEST LUB,250/3500 PSI,5 MIN CHART -PULL BPV,R/D WELL SUPPORT -TUBING=400 PSI -IA=600 PSI -OA=10 PSI Printed 12/1/2014 11:22:16AM North America-ALASKA-BP Page 2 of 6 Operation Summary Report Common Well Name:MPF-94 AFE No Event Type:WORKOVER(WO) Start Date:11/14/2014 End Date: 11/19/2014 X4-010W1-E:(1,930,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/15/2001 12:00:OOAM Rig Release:11/19/2014 Rig Contractor DOYON DRILLING INC. UWI:500292304000 Active datum:Kelly Bushing/Rotary Table(§44.30usft(above Mean Sea Leven Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 12:00 4.50 KILLW P DECOMP PJSM.WELL KILL OPERATIONS -BLEED OFF GAS,OBSERVE FLUID RETURNS -PUMP 110 BBLS OF 9.0 PPG 120 DEGREE BRINE DOWN TUBING,TAKING RETURNS TO FLOW BACK TANK(FBT)3 BPM=1200 PSI CLOSE CHOKE TO FBT,BULLHEAD 20 BBLS TO FORMATION,3 BPM=1050 PSI -PUMP 40 BBL DEEP CLEAN PILL FOLLOWED BY 810 BBLS 9.0 PPG CLEAN BRINE DOWN TUBING,RETURNS TO FBT UNTIL CLEAN,5 BPM=2500 PSI 1-RECOVERED APPROXIMATELY-500 BBLS CRUDE RETURNS,SEND TO ORT -NO FLUID LOSS DURING CIRCULATION 12:00 - 13:00 1.00 KILLW P DECOMP MONITOR WELL -TUBINGANDIAIN ONAVACUUM 13.00 - 14:00 1.00 WHSUR P DECOMP BLOW DOWN ALL WELL KILL CIRCULATION LINES R/D KILL MANIFOLD,SECURE CELLAR AREA 14:00 - 15:00 1.00 WHSUR P DECOMP M/U WELL SUPPORT LUBRICATOR TO TREE -TEST,250/3500 PSI,5 MIN,SET TWC 15:00 - 16:00 1.00 WHSUR P DECOMP ATTEMPT ROLLING TEST BELOW TWC,3 BPM =500 PSI iTEST FROM TOP,250/3500 PSI,5 MIN, (CHART 16:00 - 19:00 3.00 WHSUR P DECOMP PJSM,FMC REP BLED HANGER VOID AND CONTROL LINE -N/D TREE AND ADAPTER FLANGE 19:00 - 21:30 2.50 BOPSUR P DECOMP PJSM,N/U FOUR PREVENTER BOPE -INSTALL RISER AND TURNBUCKLES -CONNECT KOOMEY LINES AND POWER UP KOOMEY 21:30 - 22:30 1.00 BOPSUR P DECOMP R/U BOPE TEST EQUIPMENT I-M/U FLOOR VALVES AND TEST JOINTS FOR 'TEST 22.30 - 00:00 1.50 BOPSUR P DECOMP PJSM,TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT -TEST BOPE ACCORDING TO AOGCC !I," REGULATIONS AND DOYON PROCEDURES i -TEST ANNULAR WITH 2 7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH.5 MINUTES EACH,CHARTED -TEST UPPER AND LOWER 2 7/8"X 5" VARIABLE RAMS WITH 2 7/8"AND 4"TEST JOINT,250 PSI,3500 PSI,5 MIN,CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI,5 MIN,CHARTED -TEST WITH FRESH WATER -PERFORM ACCUMULATOR DRAW DOWN TEST. -JEFF JONES OF AOGCC WAIVED STATES RIGHT OF WITNESS TO BOP TEST -MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST W/9.0 PPG BRINE Printed 12/1/2014 11:22:16AM • North America-ALASKA-BP Page 3 of 6 Operation Summary Report Common Well Name:MPF-94 AFE No Event Type:WORKOVER(WO) Start Date: 11/14/2014 End Date: 11/19/2014 X4-010W1-E:(1,930,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/15/2001 12:00:00AM Rig Release:11/19/2014 Rig Contractor DOYON DRILLING INC. l UWI:500292304000 Active datum:Kelly Bushing/Rotary Table©44.30usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/16/2014 00:00 - 02:30 2.50 BOPSUR P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -CONTINUE TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT -TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES -TEST ANNULAR WITH 2 7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH,5 MINUTES EACH,CHARTED -TEST UPPER AND LOWER 2 7/8"X 5" VARIABLE RAMS WITH 2 7/8"AND 4"TEST JOINT,250 PSI,3500 PSI,5 MIN,CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI,5 MIN,CHARTED -TEST WITH FRESH WATER -PERFORM ACCUMULATOR DRAW DOWN TEST. -JEFF JONES OF AOGCC WAIVED STATES RIGHT OF WITNESS TO BOP TEST -MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST W/9.0 PPG BRINE 02:30 - 03:30 1.10 BOPSUR P DECOMP R/D ALL TEST EQUIPMENT,UD TEST JOINTS -BLOW DOWN ALL LINES 03:30 - 05:00 1.50 WHSUR P DECOMP M/U WELL SUPPORT OFF-SET LUBRICATOR i-TEST LUB 250/3500 PSI,5 MIN,CHART -PULL TWC,R/D WELL SUPPORT 05:00 - 05:30 0.50 PULL P DECOMP M/U LANDING JOINT TO HANGER AND TOP DRIVE -DRAIN BOP STACK 05:30 - 06:30 1.00 PULL P DECOMP PULL HANGER TO RIG FLOOR -WSL ENSURE NO PRESSURE UNDER HANGER, WELL IS ON VAC -FMC REP BACK OUT LDS -LOSS RATE=13 BPH 9.0 PPG BRINE PUWr=121K,SOWT=81K 06:30 - 08:00 1.50 PULL P DECOMP CLOSE ANNULAR AROUND SLICK PIPE -CIRCULATE 1 TUBING VOLUME THRU GAS BUSTER -5.5 BPM=2970 PSI -OPEN ANNULAR,MONITOR WELL -HANG ESP SHEAVE,R/U CAP TUBE SPOOL 08:00 - 08:30 0.50 PULL P DECOMP UD LANDING JOINT AND HANGER -BLOW DOWN TOP DRIVE AND CHOKE 08:30 - 12:00 3.50 PULL P DECOMP PULL 2 7/8"6.5#EUE 8RD ESP COMPLETION ' -PULL 1 STAND,PULL ESP CABLE TO SPOOLING UNIT,ATTACH CAP TUBE TO SPOOLER ON FLOOR -PULL AND STAND BACK IN DERRICK,F/ 18070'T/14753'MD 12:00 - 12:30 0.50 PULL P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT .CHECKS -SERVICE RIG _ 12:30 - 16:30 4.00 PULL P DECOMP CONTINUE PULL 2 7/8"6.5#EUE 8RD ESP COMPLETION -F/14753'T/10470'MD 16:30 - 17:00 0.50 PULL P DECOMP CHANGE OUT ESP CABLE SPOOL TO EMPTY REEL AT 80 STANDS Printed 12/1/2014 11:22:16AM • North America-ALASKA-BP Page 4 of 6 Operation Summary Report Common Well Name:MPF-94 AFE No Event Type:WORKOVER(WO) Start Date:11/14/2014 End Date:11/19/2014 X4-010W1-E:(1,930,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/15/2001 12:00:00AM Rig Release:11/19/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292304000 Active datum:Kelly Bushing/Rotary Table©44.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 20:30 3.50 PULL P DECOMP CONTINUE PULL 2 7/8"6.5#EUE 8RD ESP COMPLETION -F/10470'T/7201'MD 20:30 - 21:00 0.50 PULL P DECOMP CHANGE OUT ESP CABLE SPOOL TO EMPTY REEL AT 115 STANDS 21:00 - 00:00 3.00 PULL P DECOMP CONTINUE PULL 2 7/8"6.5#EUE 8RD ESP COMPLETION F/7201'T/3441'MD -OA=40 PSI -24 HOUR LOSS RATE=314 BBLS,9.0 PPG BRINE 11/17/2014 00:00 - 00:30 0.50 PULL P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT ,CHECKS -INSPECT SPOOLING UNIT 00:30 - 03:30 3.00 PULL P DECOMP CONTINUE PULL 2 7/8"6.5#EUE 8RD ESP COMPLETION -F/3441'T/SURFACE ESP PUMP AND MOTOR -CIO JOINTS#504.509,518 03:30 - 06:00 2.50 PULL P DECOMP UD ESP PUMP AND MOTOR ASSY -DISCONNECT ESP CABLE AND CAP TUBE -OBSERVE BURNT ESP CABLE CONNECTION AT MOTOR TERMINAL=POSSIBLE FAILURE 06:00 - 09:00 3.00 PULL P DECOMP CLEAN/CLEAR RIG FLOOR -R/D ESP TRUNK,REMOVE CAP TUBE SPOOL OFF RIG FLOOR -C/O ESP CABLE SPOOLS IN UNIT -LOAD OUT ESP PUMP FROM PIPE SHED, LOAD NEW PUMP AND MOTORS,PREP TO PICK UP CLAMPS RECOVERED -CANNON CLAMPS=578 -PROTECTOLIZERS=5 -FLAT GUARDS=3 1/2 CANNON=1 12 HOUR FLUID LOSS=108 BBLS 9.0 BRINE 09:00 - 13:00 4.00 RUNCOM P RUNCMP M/U ESP PUMP AND MOTOR ASSY -PULL ESP CABLE AND CAP TUBE TO RIG FLOOR -SERVICE ESP PUMP AND MOTOR 13:00 - 15:00 2.00 RUNCOM P RUNCMP ATTACH CAP TUBE AND ESP CABLE -TEST SAME AND INSTALL CLAMPS 15:00 - 00:00 9.00 RUNCOM P RUNCMP PJSM,RUN 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/140'T/6621'MD -INSTALL 1 CANNON CLAMP EVERY COLLAR -TEST ESP CABLE AND CAP TUBE EVERY 2000' -PUMP THRU TUBING EVERY 2000',1 BPM= 1600 PSI AT 6380'MD -OA=30PSI -24 HOUR LOSS RATE=181 BBLS,9.0 PPG BRINE 11/18/2014 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -SERVICE RIG EQUIPMENT Printed 12/1/2014 11:22:16AM North America-ALASKA-BP Page 5 of 6 Operation Summary Report Common Well Name:MPF-94 AFE No Event Type:WORKOVER(WO) Start Date:11/14/2014 End Date:11/19/2014 X4-010W1-E:(1,930,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/15/2001 12:00:00AM Rig Release:11/19/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292304000 Active datum:Kelly Bushing/Rotary Table©44.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 02:00 1.50 RUNCOM P RUNCMP CONTINUE RUN 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/6621'T/7886'MD -INSTALL 1 CANNON CLAMP EVERY COLLAR -TEST ESP CABLE AND CAP TUBE EVERY 2000' -PUMP THRU TUBING EVERY 2000',1 BPM= 2200 PSI AT 7886'MD 02:00 - 06:30 4.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM REEL TO REEL SPLICE C/O ESP CABLE REELS 06:30 - 12:00 5.50 RUNCOM P RUNCMP PJSM.CONTINUE TO RIH W/2 7/8"ESP COMPLETION AND CAPILLARY LINE. -F/7886'T/12092'MD -INSTALL COLLAR CLAMPS ON EVERY COLLAR. -TEST ESP CABLE AND PUMP 1 BPM EVERY 2000',2150-2200 PSI. -LOSSES TO WELL BORE=101 BBLS OF 9.0 PPG BRINE. -0/A=25 PSI. 12:00 - 12:30 0.50 RUNCOM P RUNCMP SERVICE RIG AND INSPECT FLOOR EQUIPMENT. -CROWN 0 MATIC CHECK,OK. 12:30 - 16:30 4.00 RUNCOM P RUNCMP PJSM.CONTINUE TO RIH W/2 7/8"ESP COMPLETION AND CAPILLARY LINE -F/12092'T/15802'MD -INSTALL COLLAR CLAMPS ON EVERY COLLAR. -TEST ESP CABLE AND PUMP 1 BPM EVERY 2000',10 SPM=1550 PSI AT 15550'MD 16:30 - 21:00 4.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM REEL TO REEL SPLICE AT 15802'MD CIO ESP CABLE REELS 21:00 - 23:30 2.50 RUNCOM P RUNCMP CONTINUE RUN 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/15802'T/18078'MD -INSTALL 1 CANNON CLAMP EVERY COLLAR -TEST ESP CABLE AND CAP TUBE EVERY 2000' -PUMP THRU TUBING EVERY 2000',11 SPM= 1850 PSI AT 18046'MD 23:30 - 00:00 0.50 RUNCOM P RUNCMP CIO ELEVATORS,P/U LANDING JOINT,M/U HANGER TO COMPLETION -ATTACH CAPILLARY TUBE TO HANGER -CANNON CLAMPS=579 -1/2 CANNON CLAMPS=2 -FLAT GUARDS=2 -PROTECTOLIZERS=4 -OA=20PSI -24 HOUR LOSS RATE=167 BBLS,9.0 PPG BRINE 11/19/2014 00:00 - 01:00 1.00 RUNCOM P RUNCMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -CONTINUE INSTALL CAPILARY TUBE TO HANGER -INSTALL ESP PENETRATOR Printed 12/1/2014 11:22:16AM North America-ALASKA-BP Page 6 of 6 Operation Summary Report Common Well Name:MPF-94 AFE No Event Type:WORKOVER(WO) Start Date:11/14/2014 End Date: 11/19/2014 X4-010W1-E:(1,930,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/15/2001 12:00:00AM Rig Release: 11/19/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292304000 Active datum:Kelly Bushing/Rotary Table @44.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 03:00 2.00 RUNCOM P RUNCMP CENTRILIFT REP PERFORM ESP TEMINATION SPLICE AT ATTACH TO HANGER -R/D ESP SHEAVE 03:00 - 03:30 0.50 RUNCOM P RUNCMP DRAIN BOP STACK -PUWT=120K,SOWT=80K(INCLUDES 40K BLOCK WT) I-LAND HANGER IN WELL HEAD,FMC RUN IN ILDS 03:30 - 04:30 1.00 RUNCOM P RUNCMP LJD LANDING JOINT,FMC REP INSTALL TWC -REVIEW PRESSURE CROSS CHECK -TEST TWC FROM BELOW,ROLLING TEST 'TO 500 PSI,5 MIN,CHART -TEST TWC FROM ABOVE,250/3500 PSI,5 MIN,CHART 04:30 - 06:00 1.50 RUNCOM P RUNCMP PJSM,FLUSH MUD PUMP AND ALL LINES WITH FRESH WATER -DRAIN STACK I-N/D BOP AND STAND BACK ON STUMP 06:00 - 10:30 4.50 RUNCOM P RUNCMP PJSM.N/U ADAPTER FLANGE AND TUBING HEAD ADAPTER. NIPPLE UP TREE AND LUBRICATOR. -PJSM.REVIEW PRESSURE CROSS CHECK LIST. I-PRESSURE TEST TUBING HEAD ADAPTER @ 250/5000 PSI/30 MINUTES/CHARTED. -MAKE FINAL CHECK ON ESP CABLE,OK. 10:30 - 12:00 1.50 RUNCOM P RUNCMP •PJSM.REVIEW PRESSURE CROSS CHECK LIST. -PRESSURE TEST LUBRICATOR AND TREE @ 250 5000 PSI,OK. -PULL TWO WAY CHECK AND SET BPV. 12:00 - 13:00 1.00 RUNCOM P RUNCMP PJSM.PERFORM ROLLING TEST UNDER BPV /500 PSI,OK. -BLEED OFF AND BLOW DOWN ALL LINES. -SECURE CELLAR AND RELEASE RIG @ 13:00 HRS. Printed 12/1/2014 11:22:16AM Milne Point Unit • Well: MPU F-94 SCHEMATIC Last Completed: 11/17/2014 Ilileorp.Ua,ka.IAA: PTD: 201-170 CASING DETAIL KB Elev.:44'/GL Elev.:11' Size Type Wt/Grade/Conn Drift ID Top Btm v 2020" Conductor 94/K-55/N/A N/A Surf 112' �; 1p,'4 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 10,341' 10-3/4" 7" Production 26/L-80/Btc Mod 6.151 Surface 18,555' Halliburton 1 ± TUBING DETAIL Cementer •' •t. 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 18,078' 4-1/2" Tubing 12.6/L-80/IBT 3.833 18,146' 18,193' 'e 'r CAPSTRING DETAIL 3/8" Capstring SS w/0.049 Wall N/A Surf 18,076' ,# ill JEWELRY DETAIL 10-3/4" • No Depth Item 1 140' GLM 2-7/8"x 1",KBMM w/Screened Orifice(ID=2.347") 2 17,827' GLM 2-7/8"x 1",KBMM w/Dummy(ID=2.347") 3 17,979' 2-7/8"HES XN-Nipple(2.250 No-go ID) 3/8"Capstnng 4 18,022' GPDIS Discharge Head 5 18,023' 137-P17 SXD Pump 6 18,042' Gas Separator GRSFTX AR H6 PC'3 7 18,047' Upper Tandem Seal Section GSB3DBUT SB/SB PFSA v 8 18,053' Lower Tandem Seal Section GSB3DBLT SB/SB PFSA CL5 9 18,060' MSP1-250 Motor/168 HP/3460 Volt/30 Amp /.�5' 10 18,074' Sensor Well Lift MGU (/ \ 11 18,076' Centralizer-Bottom @ 18,078' ' t 12 18,155' 7"x 4.5"Baker Premier Pkr. 9- 13 18,181' 4.5"HES XN-Nipple(ID=3.813"/No-go 3.75") 14 18,193' 4.5"WLEG 15 18,469' 7"Float Collar 16 18,554' 7"Float Shoe 1 PERFORATION DETAIL 2 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A Sands 18,290' 18,292' _ 7,557' 7,559' 2 11/25/01 Open Kup.A Sands 18,300' _ 18,310' 7,566' 7,576' 2 12/8/01 Open II 3 Kup.A Sands 18,328' 18,330' 7,593' 7,595' 10 12/1/01 Open `_4 4 4 Kup.A Sands 18,325' 18,335' 7,591' 7,600' 10 12/9/01 Open A a WELL INCLINATION DETAIL 5 KOP @ 500'to 3,100' a Max Hole Angle=77 deg. 1='i fg 6 Hole Angle through perforations=15 deg. yr . 7 Max.Dg Leg Severity=6.21 @ 2,900' . 8 4 TREE&WELLHEAD Tree SM CIW 2-9/16" 4" tt 9 11"Gen 5 FMC 11"x 2-9/16"Hgr.w/2-7/8"NSCT T&B,&2.5" Wellhead __ "A Type"H"BPV Profile 10 OPEN HOLE/CEMENT DETAIL 11 4-1/2" "i �» " m / of rtSet ) "Hole13-1/2 t 10-3/420 " Cmt t www/1,153 sks PFA"cL"ic,300 sx PF"C,90030sx"in "Hole ri 7" CCmt w/400260 skssks Class"G"in 9-7/8(Approx."Hole in 4..); %. '- ' 12 NOTE: Need Cementing Report to Establish Tops 13 FRAC SUMMARY GENERAL WELL INFO 14KUPASands 12/11/01-117,2981bs of 16/20 C/lite and API:50-029-23040-00-00 73,7401bs of 12/18 C/lite behind pipe. Drilled and Run Frac String by Nabors 27E -11/25/1997 Perforated and Frac'd w/Wireline and CT-12/11/2001 7" 1 ig 158,16 ESP Completion w/Nabors 4-ES TD=9,440'(MD)/TD=7,191'(TVD) ESP Re-completions on 2/26/05,2/8/06,12/9/07,4/25/08, PBTD=9,332'(MD)/PBTD=7,123'(TVD) 4/16/09,2/6/10,4/20/11,6/10/12,3/14/13&11/17/14 Created By:TDF 12/16/2014 STATE OF ALASKA . AlikKA OIL AND GAS CONSERVATION CalISSION REPORT OF SUNDRY WELL OPERATIONS rk; ,i s,;-;_[1- 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. 0 Exploratory 0 Stratigraphic 201 -170 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 - 50 029 - 23040 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: • ADL 355016 MPF -94 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): — Milne Point Unit / Kuparuk River Sands 11. Present well condition summary: Total depth: measured 18595' feet Plugs:(measured) None feet true vertical 7853' feet Junk: (measured) None feet Effective depth: measured 18469' feet Packer: (measured) 18155' feet true vertical 7730' feet Packer: (true vertical) 7427' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 10307' 10 -3/4" 10341' 4454' 5210 2480 Intermediate Production 18523' 7 - 5/8" 18555' 7814' 6890 4790 Liner Perforation Depth: Measured Depth: 18290' - 18335' feet True Vertical Depth: 7557' - 7600' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8', 6.5# L -80 18074' 7349' 4-1/2", 12.6# L -80 18146' - 18193' 7418' - 7463' Packers and SSSV (type, measured and true vertical depth): 7" x 4.5" Baker Premier Packer 18155' 7427' 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED APR 2 2 2013 Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 428 101 827 248 290 Subsequent to operation: 424 102 528 140 228 14. Attachments ❑Copies of Logs and Surveys run 15 Well Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: r IN Oil ❑ Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Noel Nocas, 564 -4667 N/A Email: Noel.Nocas @bp.com Printed - - • Joe ( a Title: Drilling Technologist Signature. oA ; V \ ----- Phone: 564 - 4091 Date: 4/4///3 Form 10-404 Revised 10/201 R$DMS APR 0 5 2013c2: V1_-F/11 i i 3 '4,<AA" Submit Original Only • • • �:: / :� Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 317/2013 End Date: 3/13/2013 X4 -00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. Hrs UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Task Code NPT j NPT Depth Phase Description of Operations (hr) (usft) 3/6/2013 21:00 - 23:00 2.00 RIGD N WAIT PRE RIG RELEASED FROM MP L -14 RIG MOVE PREP COMPLETE - WAITING ON WIN CH TRACTOR, CURRENTLY STUCK BEHIND NABORS 27E RIG MOVE, TO MOVE FUEL TRAILER BEFORE MOVING OFF OF MP L -14 - LAY HERCULITE AND RIG MATS AROUND MP F-94 23:00 - 00:00 1.00 RI P PRE WINCH TRACTOR ON LOCATION - MOVE FUEL TRAILER - MOVE CHANGE TRAILER 3/712013 00:00 - 01:30 1.50 MOB P PRE P PREP R IG FOR MOVE OFF OF WELL M -14 - MAKE SPCC CHECKS - W SL, DAYAN NYGHTTOOLPUSHERS PRSENT, PAD RO NOTIFIED : P MOVE OFF OF OPE MPL -14 AT POSITION E RIG ON PAD TO R LOWER DERRICK 01:30 - 02:30 _ 1.00 MOB P PRE SM LOWER LOWER CATTLE DERRICK CHUT --P J LOWER DERRICK PREPARE TO MOVE OFF PAD TO MP F -94 02:30 - 04:30 2.00 ' P PRE MOVE FROM MPL PAD TO MPF PAD MOB -STAGE RIG ON F PAD I RAISE DERRICK 04:30 - 06:00 1.50 RIGD P PRE BACK OVER MP F -94 WSLAND NIGHT TOOLPUSHERSU PRESENT, PAD OPERATOR NOTIFIED - PJSM, BRIDLE DOWN AND SECURE DERRICK. j ! SPOT CUTTING BOX AND AILER R/U KILL SKID MANIFOLD AND FUEL CIRCULATING TR LINES IN CELLAR. - FILLAND PRESSURE TEST LINES. 06:00 - 11:00 5.00 RIGD P PRE ATTEMPED TO BD HARDLINE TO FLOW BACK TANK. - DISCOVERED ICE PLUG IN HAR LINES. '- BREAKAPART HARD LINES TO FLOW BACK ANK TO A ICE / ETH _Tip STEAM AL THAW LINES M TILL FREE ANOL OF PLU LUG. - BD TO ENSURE LINES ARE CLEAR TO FBT. . - 120 F. BRINE PPG THE RIG. KWF ) TO PITS. - PERFORM SPCC DEG CHECKS AROUN D SET UP COMMS. _ RIG ELECTRICIAN TESTING ALARMS AND GAS DETECTORS. - MANIFOLD / HARD LINES WITH DIESEL. ACCEPT FILL MA RIG AT 09:00 HRS. 11:00 13:30 2.50 WHSUR P DECOMP PJSM, RU TO PT KILL MANIFOLD AND HARDLINE TO FBT. _ PRESSURE TEST KILL MANIFOLD AND HARD LINE. - 2 / 5 CHA PASSED 3 . - TEST ALARM 00 PSI OF F_ W BACK RTED TANK. MIN. Printed 3/25/2013 10:14:48AM • • mss, North America - ALASKA - BP % { V4-4:,,,Agg",",r4V/745-:0;770.r �f Operation Summary Report ' Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 !)(400X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ( H (usft) I 13:30 - 14:00 0.50 WHSUR P DECOMP I HELD H2S EVAC DRILL. BP SUPERINTENDENT, WSL, TOOLPUSHER, SCS, RIG CREW, THIRD PARTY PERSONNEL PRESENT. AAR - GOOD RESPONSE TIME BY ALL. DRILLER / FLOOR HAND CONDUCTED SWEEP OF RIG ON WAY OUT. - ALL 21 PERSONNEL ON LOCATION ACCOUNTED FOR. - SIREN COULD BE HEARD BY ALL PERSONNEL INVOLVED ON BOTH SIDES OF RIG. FOUR OR FIVE VEHICLES WERE BLOCKED AT THE PAD ENTRANCE BY LOADER. 14:00 - 16:00 2.00 WHSUR P DECOMP PJSM, PU DSM LUBRICATOR. RU TEST HOSES. - TEST LUBRICATOR TO 250 / 3500 PSI FOR 5 CHARTED MIN. EACH. 1- PULL BPV WITH TESTED LUBRICATOR. SITP = 600 PSI. SICP = 800 PSI LD LUBRICATOR PER DSM REPS. Printed 3/25/2013 10:14:48AM • North America - ALASKA BP r 5 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date 3/7/2013 End Date: 3/13/2013 X4- 00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 21:30 5.50 WHSUR P DECOMP PJSM, WELL KILL / BULLHEAD. WSL, TOOLPUSHER, SCS, RWO SUPERINTENDENT RIG CREW IN ATTENDANCE. - REVIEW DDI WELL KILL SOP. DISCUSS VALVE ALIGNMENT, HAND HELD GAS DETECTOR WITH MAN AT FLOW BACK TANK. - DRILLER DISCUSSED ROLES AND RESPONSIBILITIES OF PERSONNEL. MPU SECURITY AND PAD OPERATOR NOTIFIED OF GAS VENTING ON PAD. WELL KILL WITH 9.7 PPG HEATED BRINE. WSL / TOOL PUSHER VERIFY VALVE ALIGNMENT. -SITP = 600 PSI, SICP = 800 PSI SIOA= 40 PSI - BLEED GAS FROM IA F/ 800 PSI T/ 150 PSI IN 6 MIN. SITP/ 300 PSI. _ - PUMPED 110 BBLS 9.7 PPG HEATED BRINE - AT 3 BPM WITH 1000 PSI DOWN THE TBG `THRU CHOKE SKID TO FLOW BACK TANK. -- ICP = 1000 PSI FCP = 2650 PSI - - BULL HEAD 50 BBLS DOWN THE TBG AT 2 -2.5 BPM / 1100 PSI ON IA. - 2650 PSI ON THE TBG. - NOTIFY TOWN RWO / ODE. MONITOR . - SITP AFTER 5 MIN. = 100 PSI. SICP = 700 PSI. PUMPED HEATED 9.7 PPG BRINE AT 3.5 BPM DOWN THE 2 7/8" 6.5# EUE TBG THRU CHOKE SKID TO FLOW BACK TANK. - ICP = 2 BPM / 1600 PSI. 3.5 BPM / 2800 PSI. - PUMPED TOTAL OF 702 BBLS KWF AT 3.5 BPM AND STARTED TO GET 9.3 PPG BRINE IN RETURNS AFTER PUMPING 575 BBLS KWF. - PUMPS OFF, SHUT -IN WELL. RECOVERED —250 BBLS CRUDE. MONITOR 30 MINUTES. - TBG AND IA ON A VACUUM IN 15 MINUTES. - BLOW DOWN HARD LINE. TOTAL LOSSES DURING WELL KILL - 50 BBLS BULLHEAD PLUS 65 BBLS KWF TO THE FORMATION. - RECOVERED 500 BBLS OF 100 % CRUDE, SENT TO MILNE POINT RECYCLE. 21:30 - 23:00 1.50 WHSUR P DECOMP RIG DOWN MANIFOLD - BLOW DOWN LINES - RIG DOWN CIRCULATING LINES & KILL MANIFOLD - R/U SECONDARY KILL LINE Printed 3/25/2013 10:14:48AM • North America - ALASKA - BP _' Page 4 of 11 • /// /'',A1 Operation Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 X4- 00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table ©44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 WHSUR P DECOMP PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC - M/U LUBRICATOR & TEST 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINS EACH , CHARTED CONTINUOUS HOLE FILL AT 15 BPH WITH 9.7 PPG KWF LOSSES TO WELL - DURING KILL = 65 BBLS - AFTER KILL = 21 BBLS 3/8/2013 00:00 - 01:00 1.00 WHSUR P WHDTRE PRESSURE TEST TWC - PERFORM ROLLING TEST BELOW TWC - PUMP DOWN IA @ 2 -1/2 BPM AND 500 PSI FOR 10 MINS, CHARTED (32 BBLS KWF PUMPED) - TEST TWC FROM ABOVE : 250 PSI LOW & 3500 PSI HIGH FOR 5 MINS EACH , CHARTED - PERFORM SPCC CHECKS 01:00 - 02:30 1.50 WHSUR P WHDTRE PJSM TO DRAIN AND NIPPLE DOWN TREE & N/U BOPE - NIPPLE DOWN FMC ADAPTER FLANGE & 2 9/16" , 5 M TREE - FMC REP CLEAN AND INSPECT EUE 8RD f HANGER THREADS 1- CONFIRM 9 TURNS BY HAND. 02:30 - 04:30 2.90 WHSUR' P DECOMP PJSM, NIPPLE UP BOPE - N/U 13 -5/8" BOPE STACK. INSTALL TURNBUCKLES AND FLOW NIPPLE. - RE- ENERGIZE ACCUMULATOR SYSTEM. 04:30 - 10:00 5.50 BOPSUR P DECOMP PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES L TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES ^ EACH, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST. NO FAILURES. WSL WINESSED TEST. - LOU GRIMALDI OF AOGCC WAIVED STATES , RIGHT OF WITNESS BOP TEST - MAINTAIN HOLE FILL TO THE IA DURING TEST @ -14 BPH , 9.7 PPG BRINE. 10:00 - 10:30 0.50 BOPSUR P DECOMP PJSM, RIG DOWN BOPE TEST EQUIPMENT. - DRAIN GAS BUSTER. BLOW DOWN TEST LINES. - CLEAR RIG FLOOR. 10:30 - 12:00 1.50 WHSUR P DECOMP PJSM, PU AND R/U DSM LUBRICATOR / OFFSET EXTENSION. - FILL BOP STACK WITH 9.7 PPG KWF. - CLOSE ANNULAR. PRESSURE TEST T/ 250 / 3500 PSI FOR 5 CHARTED MINUTES EACH. PASSED. - PULL TWC. R/D DSM LUBRICATOR AND 1 EXTENSION. Printed 3/25/2013 10:14:48AM Operation Su :,?7. .485.7-),473- „ ,j4? 41:2, 7/4 ,„4",f,;(1./p_P4',7 4.4?#'7,77 PW4P/7,V's,Itc:,4%;7 :////i,"" „"4 Altr /./ "*X/,' 4,;t1:,%/pp/*", /, '`;',;,%,;/'/ , p -,r� ( Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 X4- 00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 12:30 0.50 PULL P j DECOMP PJSM, RU TO PULL ESP COMPLE TION. CENTRILIFT REP TO CHECK REELS FOR AE ND AP _E PU ESP CENTRA LIFT C TOOLS TUBE. TO LO RU SHORT BALES. 12:30 - 13:00 0.50 PULL P DECOMP I PJSM ON PULLING 2 7/8" TBG HANGER TO FLOOR. F- L, SUPERINTENDENT, FMC REP, CENTRALIFT REP, RIG CREW IN ATTENDANCE . - DISCUSSED WELL CONTROL, CONTINUOUS HOLE FILL, DISCONNECTING ESP CABLE FROM PENETRATOR AND HANDLING 3/8" SS CAP TUBE. REVIEWED MSDS ON NALCO EC6085ASCALE INHIBITOR. 13:00 - 14:00 1.00 PULL P DECOMP MU 2 -7/B" EUE LANDING JOINT WITH FOSV TO TBG HANGER. BOLDS PER FMC REP. - WSL VERIFY NO TRAPPED PRESSURE UNDER TBG HANGER. -PULL TBG HANGER OFF SEAT @ 115K INCLUDES 40K BLK WT. MAX PULL 120K INCLUDES TOP DRIVE WT. - PUW= 120K,SOW =70K - PULL HANGER AND REMOVE CLAMP ON FIRST FULL JOINT, - CUT ESP CABLE AND CAPILLARY TUBE PER CENTRALIFT REP. - POSITION SLICK JOINT ACROSS BOPE. - K. H ELEPHANT HANG ESP TRUNK SHEAVE FOR IN ESP DERRIC CABLE. ANG 14:00 - 15:30 1.50 PULL P DECOMP PJSM, - NULAR CIRC. 104 CLOSE BBLS AN 9.7 PPG KWF DOWN TUBING THRU RIG CHOKE / GAS BUSTER TO PITS. - CIRC @ 2 BPM = 600 PSI. - WSL / DRILLER VERIFY VACUUM AND NO TRAPPED PRESSURE. - FLOW CHECK WELL FOR 10 MIN. - CONFIRM NO FLOW / SLIGHT VAC / SHUT IN. - LOSS RATE - 8 BPH. _ 15:30 - 16:15 0.75 PULL P DECOMP , CH TON. - WSLPJSM WEEKLY TOOLPUSHER , CENTRALIFT ANGE FROM REP, RIG CREW IN ATTENDANCE. - REVIEW CRENT WELL STATUS AND PAST OPERATIONS. UR - DISCUSSED DDI PULL ESP COMPLETION / CAP TUBE SOP. - REVIEWED MSDS ON NALCO EC6085A SCALE INHIBITOR. 16:15 - 19:00 2.75 PULL P DECOMP WSL /DRILLER VERIFY NO TRAPPED PRESSURE. - OPEN ANNULAR. ESTABLISH LOSS RATE @ 14 BPH. BD RIG CHOKE AND DRAIN GAS BUSTER. - RU TO PULL 2 7/8" 6.5# EUE ESP COMPLETION. Printed 3/25/2013 10:14:48AM • • North America - ALASKA - BP Operation Summary Report y , Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 IX4 -00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Datemme: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 19:00 - 22:00 3.00 PULL P DECOMP LULL 2 7/8" 6.5# EUE ESP COMPLETION - PULL COMPLETION W/ ESP CABLE AND CAPILARY TUBE - FROM 18092' MD. - REMOVE CLAMP FROM EVERY COLLAR 22:00 - 23:00 1.00 PULL P DECOMP CHANGE OUT ESP REELS - CHANGE OUT REELS WITH 25 STANDS OOH, - 15709' MD 23:00 - 00:00 1.00 PULL P DECOMP PULL 2 7/8" 6.5# EUE ESP COMPLETION - ESP REELS CHANGED - CONTINUE POOH WITH COMPLETION FROM 15709' TO 15050' MD. - 32 STANDS OOH MAINTAIN CONTINUOUS HOLE FILL WITH 9.7 PPG BRINE @ - 14 BPH. TOTAL LOSSES FOR THE DAY = 271 BBLS KWF 3/9/2013 00:00 - 05:00 5.00 PULL P DECOMP POH WITH 2 -7/8" EUE 8RD 6.5# TUBING AND ' ESP ASSEMBLY WITH CAPILLARY TUBE SPCC CHECKS AND PRE TOUR HANDOVER - REVIEWED MSDS ON NALCO EC6085A SCALE INHIBITOR. - CONTINUE STANDING BACK TUBING FROM 15050' MD TO 9285' MD. 05:00 - 06:00 1.0'0 ,PULL P DECOMP KICK WHILE TRIPPING DRILL AAR: - SAFETY VALVE & JOINT WAS STABBED ON IN TIMELY MANNER - DISCUSSED CUTTING AND SECURING BOTH ESP CABLE AND CAPILLARY TUBE WITH 1 TOOL - GOOD COMMUNICATION FROM RIG TEAM ONCE AT INDIVIDUAL STATIONS PUMP 50 BBLS KWF DOWN TBG AT 4.5 BPM / 1980 PSI. - SPR / 1 BPM / 140 PSI. 06:00 - 08:00 2.00 PULL P DECOMP PJSM, CONTINUE POH WITH ESP / CAP TUBE COMPLETION FROM 15050' MD TO 9,320' MD. CONTINUE TO STAND BACK IN DERRICK CONNECTIONS ARE TIGHT, US STEAM TO HEAT COLLARS. - INSPECT PIN AND BOX END ON TBG. 08:00 - 09:30 1.50 PULL P DECOMP WAIT ON MPU ROADS AND PADS LOADER TO ARRIVE ON LOCATION TO CHANGE REELS. - PREVIOUS WORK HAD LOADER IN USE. - CHANGE OUT REELS IN CENTRILIFT SPOOLER PER CENTRILIFT REP. Printed 3/25/2013 10:14:48AM • 'North America • "- Operation Summa ro Common Well Name: MPF -94 ! AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 IX4 -00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. 1 UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table ©44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 18:30 9.00 PULL P DECOMP PJSM, CONTINUE TO POH WITH ESP COMPLETION FROM 9,320' MD. STAND BACK 2 7T8 6183t EUE ESP TBG IN DERRICK PER WELL PLAN. - CONNECTIONS ARE TIGHT, USE STEAM TO HEAT COLLARS. - INSPECT PIN AND BOX ON TBG. - LAY DOWN LAST FULL JOINT ( PRE -RIG TUBING PUNCH AT 17,875' MD, 9 HOLES SHOT, 4 PLUGGED) - POOH TO ESP PUMP AND MOTOR ASSEMBLY - REPLACED TWO, JOINTS TBG DAMAGED I DURING BREAK -OUT. 18:30 - 22:00 3.50 PULL P DECOMP j PJSM LAY DOWN ESP PUMP AND MOTOR ASSEMBLY CUT &'TERMINATE CABLE AND CAPILLARY TUBE - FEED CABLE AND CAP TUBE THROUGH SHEAVE, SPOOL UP AND SECURE TO REELS - LAY DOWN ESP PUMP AND MOTOR UPPER PUMP LOCKED UP, LOWER PUMP STIFF TO ROTATE. RECOVERED 576 CANNON CLAMPS, 3 FLAT GUARDS, 5 PROTECTOLIZERS, 2 - SINGLE PIN, MID -JOINT CANNON CLAMPS 22:00 - 00:00 2.00 PULL;` DECOMP PREPARE TO RUN COMPLETION - RIG DOWN CENTRILIFT TOOLS AND SPILL CONTAINMENT - CLEAN AND CLEAR RIG FLOOR MAINTAIN CONTIGUOUS HOLE FILL WITH 9.7 PPG BRINE AT 14 BPH 24 HR LOSSES = 272 BBLS KWF 3/10/2013 00:00 - 01:00 1.00 RIGU P PRE - SPCC CHECKS AND PRE TOUR HANDOVER - REVIEWED SOP ON RUNNING ESP COMPLETION — CLEAN AND CLEAR RIG FLOOR 01:00 - 04:00 3.00 RUNCOM N RUNCMP WAIT ON CENTRILIFT REELA -FRAME REPAIR. CHANGE OUT REELS IN CENTRILIFT SPOOLER PER CENTRILIFT REP. - 1 ADDITIONAL HOUR DUE TO SPRING DAYLIGHT SAVINGS MAINTAIN CONTINUOUS HOLE FILL WITH 9.7 PPG BRINE. STATIC LOSS RATE AT 8 BPH 04:00 - 08:30 4.50 RUNCOM P RUNCMP PJSM, R/U TO RUN ESP COMPLETION - STRING ESP CABLE & CAPILLARY TUBE FROM SPOOLING UNIT TO RIG FLOOR AND TIE OFF - M/U ESP MOTOR AND PUM ASSEMBLY AS PER CENTRILIFT REP M/U .375" X .0049" CAPILLARY TUBE WITH 1 2500 PSI CHECK VALVE RESET TO 500 PSI, 1 AND FUNCTION TEST. GOOD. - M/U NEW FLAT CEBERSS LEAD, MOTOR LEAD AND ROUND ESP CABLE. Printed 3/25/2013 10:14:48AM North America - ALASKA - BP _. �� % � te r: 4 46*A /71.4 //// Operation Summary Report 4;;; Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 ,X4- 00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1 08:30 - 09:30 1.00 RUNCOM N RUNCMP THIRD PARTY AIR COMPRESSOR USED BY CENTRILIFT. - FAILS TO RUN PROPERLY. - MPU MECHANIC TROUBLE SHOOT, POSSIBLE WATER IN FUEL. - R/U AIR LINE FROM RIG TO SPOOLING UNIT. 09:30 - 17:00 7.50 RUNCOM P RUNCMP RUN 2 -7/8" ESP / CAP -TUBE COMPLETION _ 'FROM DERRICK - 2 -7/8" 6.5#, 8RD, EUE, L -80 TBG. - 3/8" CAP TUBE - DRIFT AND CHANGE -OUT TBG COLLAR ON I TOP OF FIRST JOINT BELOW THE DUMMY IGLM. A CANNON CLAMP ON EACH COLLAR. WSL COMPLETED MPG-18 HANDOVER WITH A FACE TO FACE MEETING WITH MPU OPS COORD. EVERY 2,000' FT I - CENTRILIFT REP FUNCTION TEST CAP TUBE.AT 5,000 PSI. - CHECK CONDUCTIVITY OF ESP CABLE. I- RIG PUMPED 5 BBLS KWF DOWN TBG TO FLUSH PUMP AT 1 BPM / 850 PSI. - TO -3875' MD. (40 STANDS) - STATIC LOSS RATE AT -6 BPH 17:00 - 22:30 5.50 RUNCOM N RUNCMP , LOST POWER TO ESP SPOOLER. THIRD PARTY GENERATOR SHUT DOWN. - CALL MILNE POINT ELECTRICIAN TO TROUBLESHOOT - WSL COMPLETED "WELL WORK TRANSFER PERMIT" WITH A FACE TO FACE MEETING WITH MPG -PAD OPERATOR FOR NEXT WELL MPG -18. 22:30 - 00:00 1.50 RUNCOM P RUNCMP POWER RESTORED TO SPOOLING UNIT - CONTINUE RIH WITH 2 -7/8" ESP / CAP -TUBE COMPLETION FROM DERRICK - CONTINUE FROM 40 STANDS IN HOLE ( -3875' MD) TO 5075' MD MAINTAIN CONTINUOUS HOLE FILL WITH 9.7 PPG BRINE AT 6 BPH 24 HR LOSSES = 162 BBLS KWF 3/11/2013 00:00 - 03:00 3.00 RUNCOM P RUNCMP PERFORM SPCC AND EQUIPMENT CHECKS RUN 2 7/8" 6.5# EUE 8RD TUBING ESP COMPLETION WITH CAPILLARY TUBE PER 1 RUNNING ORDER - RIH FROM 5075' - INSTALL CANNON CLAMPS ON EVERY COLLAR CHECK CONDUCTIVITY AND CAPILLARY LINE CHECK VALVE EVERY 2000' PUMP 5 BBLS DOWN TUBING AT 1/2 BPM EVERY 2000' . - 1/2 BPM = 890 PSI AT 5,800' MD - MAINTAIN CONTINUOUS HOLE FILL WITH 9.7 PPG BRINE AT -6 BPH Printed 3/25/2013 10:14:48AM • North America - ALASKA - BP' Operation Summary Report' Common Well Name: MPF - 94 AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 X4- 00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 05:30 2.50 RUNCOM P RUNCMP CHANGE OUT REELS IN SPOOLING UNIT. - 1ST MPU LOADER ON LOCATION NOT RATED FOR WEIGHT OF LEAD SPOOL & A -FRAME - SWAP LOADERS = (1.5 HRS.) - LOAD NEW REEL IN SPOOLING UNIT. 05:30 - 09:00 3.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM REEL TO REEL ESP / LEAD CABLE SPLICE SPLICE AT -7,430' MD. CHECK CONDUCTIVITY. 09:00 - 18:30 9.50 RUNCOM N RUNCMP GROUND FAULT DETECTED BETWEEN SPOOLING UNIT AND RIG POWER. - MILNE POINT ELECTRICIAN AND RIG ELECTRICAN TROUBLESHOOT FOR THE FAULT. - A LARGER PORTABLE GENERATOR ORDERED WAIT AN ARRIVAL FROM PBU FIELD. 18:30 - 00:00 5.50 RUNCOM P' ' RUNCMP 130 KW PORTABLE GENERATOR ON �{ LOCATION - WAIT FOR HOOKUP - PJSM W/ RIG CREW TO FOCUS ON RESTART OF RUNNING COMPLETION RUN 2 7/8" 6.5# EUE 8RD TUBING ESP COMPLETION WITH CAPILLARY TUBE PER RUNNING ORDER - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONDUCTIVITY AND CAPILLARY LINE CHECK VALVE - PUMP 5 BBLS DOWN TUBING AT 1 BPM = 980 PSI AT 9,676' MD & 1 BPM = 1190 PSI AT 11,350' - RIH FROM -7430' TO - 11,500' MAINTAIN CONTINUOUS HOLE FILL WITH 9.7 PPG BRINE AT -6 BPH 24 HR LOSSES = 140 BBLS KWF 3/12/2013 00:00 - 01:30 1.50 RUNCOM P RUNCMP PERFORM SPCC AND EQUIPMENT CHECKS RUN 2 7/8" 6.5# EUE 8RD TUBING ESP COMPLETION WITH CAPILLARY TUBE PER RUNNING ORDER - RIH FROM 11,500' TO 12652' MD. - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONDUCTIVITY AND CAPILLARY LINE CHECK VALVE EVERY 2000' - PUMP 5 BBLS DOWN TUBING AT 1 BPM EVERY 2000' . - MAINTAIN CONTINUOUS HOLE FILL WITH 9.7 PPG BRINE AT -6 BPH 01:30 - 03:00 1.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM CAPILARY TUBE SPLICE - CHANGEOUT CAPILARY TUBE REELS FROM SPOOLING UNIT - SPLICE CAP TUBE AT - 12,652' MD. - CHECK CAPILARY TUBE LINE. - CONTINUE IN HOLE FROM - 12,652' TO 13,310' MD Printed 3/25/2013 10:14:48AM • • North America - ALASKA - BP Operation Summary Report Common Well Name. MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 X4- 00X8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date<rme: 10/15/2001 12:00 Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 05:30 2.50 RUNCOM RUNCMP - CHECK CONDUCTIVITY OF CABLE AND CAPILLARY LINE CHECK - PUMP 5 BBLS DOWN TUBING AT 1 BPM . - 1 BPM = 1250 PSI AT 13,310' MD - CONTINUE RIH FROM - 13,310' TO 14,901' MD 05:30 - 10:00 4.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM REEL TO REEL ESP / LEAD CABLE SPLICE SPLICE STAND 157, - 14,901' MD. - CHECK CONDUCTIVITY EVERY 2,000'. - INSTALL CANNON CLAMPS ON EVERY COLLAR. 10:00 - 12:00 2.00 RUNCOM P RUNCMP PJSM, CONTINUE TO RIH WITH 2 7/8" 6.5# EUE 8RD. TBG ESP COMPLETION. - RIH FROM 14,901' MD. TO 16869" MD. - PUMP 5 BBLS DOWN TUBING AT 1 BPM EVERY 2000' MD. 12:00 - 14:00 2.00 RUNCOM P RUNCMP PJSM, CONTINUE TO - RIH FROM 16,869' MD WITH ESP COMPLETION. - PU GLM. RUN IN LAST STAND FROM DERRICK. - PU 10' 2 7/8" PUP. MU TBG HANGER. - RD POWER TONGS & ESP SHEAVE - RAN 578 - CANNON CLAMPS , 3 PROTECTOLIZERS, 1- CROSS COLLAR CLAMP ( HALF CANNON CLAMP ) 14:00 - 16:30 2.50 WHSUR P WHDTRE MAKE UP FMC 2 7/8" x 11" HANGER - PJSM TO DISCUSS M/U LANDING JOINT - M/U 2 7/8" EUE LANDING JOINT W/ FOSV TO HANGER - TERMINATE ESP CABLE / CAP TUBE TO PENETRATOR - INSTALL PENETRATORS IN HANGER 16:30 - 17:00 0.50 WHSUR P WHDTRE PJSM, LANDING 11" TBG HANGER. FMC REP, WSL, CENTRALIFT REP IN ATTENDANCE. - LAND HANGER PER FMC REP - PU WT = 121K, SOW = 81K. INCLUDING 40K TOP DRIVE WT. - HANGER SET AT 18,074' MD. - RUN IN LOCK DOWN SCREWS PER FMC REP. LD LANDING JOINT. 17:00 - 19:00 2.00 WHSUR P VVHDTRE PJSM, INSTALL AND TEST TWC - FMC REP INSTALL TWC - PERFORM ROLLING TEST FROM BELOW TWC. - PUMPED 20 BBL 9.7 PPG KWF AT 2 BPM TO ATTAIN 500 PSI, 10 MIN CHARTED TEST - TEST TWC FROM ABOVE, 250 / 3500 PSI FOR 5 CHARTED MIN. PASSED. - BLEED OFF PRESSURE. BLOW DOWN LINES. 19:00 - 20:30 1.50 WHSUR P -_ WHDTRE PJSM, NIPPLE DOWN BOP. - NIPPLE DOWN BOP RISER AND FLOW LINE 20:30 - 22:30 2.00 WHSUR P WHDTRE MAKE UP TUBING HEAD ADAPTER. - NIPPLE UP 11" X 2- 9/16" ADAPTER - CENTRALIFT MADE FINAL CHECKS ON HEAT TRACE / ESP. Printed 3/25/2013 10.14:48AM • • ("077 e North America - ALASKA 27 1 Operation Summary Re • Qrt Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 3/7/2013 End Date: 3/13/2013 X4 -OOX8P -E:RIG (1,300,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: 3/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active datum: Kelly Bushing / Rotary Table @44.30usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 WHSUR P WHDTRE FMC MKAE UP PT MANIFOLD - FMC REP MAKE UP PT MANIFOLD ON TUBING HEAD ADAPTER - BEGIN PRESSURE TEST OF HANGER VOID 24 HRS LOSSES = 105 BBLS 9.7 PPG BRINE 3/13/2013 00:00 - 04:00 4.00 WHSUR P WHDTRE SPCC CHECKS, PRE -TOUR MEETING TEST VOID, ADAPTER FLANGE TO 5000 PSI. FOR 30 CHARTED MIN. PASSED. WSL, FMC REP , AND TOOL PUSHER VTNESSED 04:00 - 05:00 1.00 WHSUR P WHDTRE - NIPPLE UP CAMERON 2- 9/16" TREE THE DRILL SITE MAINTENANCE CREW WITNESSED THE ALIGNMENT OF THE WING VALVES TO THE 'S' RISER. 05:00 - 07:00 2.00 WHSUR P WHDTRE TEST TREE - LINE UP TO TEST TREE 250 PSI LOW AND 5000 PSI HIGH FOR 5 CHARTED MINS EACH. GOOD TEST. 07:00 - 07:45 0.75 WHSUR P WHDTRE INSTALL BPV LUBRICATOR ONTO TREE. PRESSURE TEST AND CHART LUBRICATOR. 07:45 - 09:45 2.00 WHSUR P VVHDTRE - PULL TWC ABOVE MASTER AND SSV, CLOSE BOTH VALVES. TAKE OFF TWC FROM PULLING TOOL, INSTALL BPV. MAKE UP BPV LUBRICATOR AND PRESSURE TEST AGAIN. RUN IN AND SET BPV. 09:45 - 10:15 0.50 WHSUR P WHDTRE PERFORM ROLLING TEST OF BPV BY PUMPING 500 PSI DOWN IA AND WATCH FOR LEAKS ABOVE BPV. NO LEAKS SEEN. TEST IS WITNESSED BY WSL. 10:15 - 13:00 2.75 WHSUR P - WHDTRE START RIGGING DOWN. CLEAR RIG FLOOR AND INSTALL BRIDAL LINES TO PREP FOR DERRICK OVER. CLEAN PITS AND CUTTINGS BOX. LRS FREEZE PROTECTS TUBING BY BULLHEADING 15 BBLS DOWN TUBING 1,963' MD) , 65 BBLS DOWN IA (2,533' MD). DOYON TOUR CHANGE AT 11:30, DISCUSS CURRENT OPS AND HAZARDS WITH ONCOMING CREW. 13:00 - 14:00 1.00 WHSUR P WHDTRE CONTINUE PREP FOR PULLING OFF WELL. CLEAN UP CELLAR AREA. * ** RELEASE RIG AT 14:00 * ** 14:00 - 18:00 4.00 WHSUR P WHDTRE PJSM THEN LAY DOWN DERRICK. MOVE RIG OFF WELL. Printed 3/25/2013 10.14.48AM f Tree; 2 9/16" - 5M CIW 1110 M P F_94 IL Elev. = 44' (N -27E) Wellhead: 11" Gen 5 FMC Orig. GL Elev. = 11' 11 x 2 9/16" Hgr, w/ 2 7/8" NSCT T &B, - RT to Tbg. Spool = 33.0' (N -27E) & 2.5" Type 'H' BPV Profile 112' SLB 2 -7/8" x 1" KBMM GLM 141' 10 3/4" Halliburton ES Cementer 2493' 0 KOP @ 500' to 3100' 18,200' SS Cap Tub with 2500# Check Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' 10 3/4 ", 45 # /ft., L -80 BTC 10,341' 4 SLB 2 -7/8" x 1" KBMM GLM 117,820` HES 2.313" XN nipple 17,971' (No -Go ID 2.250 ") 2 7!8" 6.5 ppf, L-80 8 rd. EUE tubing GPDIS Discharge Head 18,014' (drift ID = 2.347 ", cap = 0.00592 bpf) Centrilift ESP, SXD 119 -P23 18,015' 7" 26 # /ft., L -80 BTC -MOD Production Casing, (Drift ID = 6.151 ", cap. = 0.0383 bpf) (cap w/ 2 7/8" tbg = .0302 bpf) Gas Separator 18,032` Capillary tube 3/8" OD x .049 wall GRSFTXAR H6 (capacity = 3.131 gallons / 1000') Tandem Seal Section 18,037` GSB3DBUT SB/SB PFSA / GSB3OBLT SB /SB PFSA Motor MSP1 -250 252 HP, 3440 volt, 44 amp 18,051' Well Lift MGU Sensor 18,070` Stimulation Summary w! 6 Fin Centralizer 12/11/01 Frac - 117,298# of 16/20 C /lite Gauge ND = 7345' 73,740# of 12/18 C /lite behind pipe. Perforation Summary Ref. Log SWS anadrill CDR resistivity. dated 10/17/01. "_ r+ 7" x 4.5" Baker Premier pkr. 1 18,155' Size SPF Interval (TVD) 2.5" 4 18290'- 18292' 7551' -7552' 2.5" 4 18328' - 18330' 7594' -7595' 181' 3 -3/8" 12 18300'- 18310' 7567` -7576' 4.5" HES XN- Nipple (3.813 ") 18, 1 3 -3/8" 12 18326- 18335' 7591`-7600' (No -go 3.75" id) 4 1/2" WLEG 1 18,193' (PBTD) 1 18,466' 7" Float Collar 18,469' I 7" Float Shoe 18,554' 1 DATE REV. BY COMMENTS MILNE POINT UNIT 12/9/07 Lee Hulme ESP Re- Completion 4ES 4 -25 -08 REH ESP Re- Completion Nabors 3S WELL M PF -94 (KU P) 4116/09 Lee Hulme ESP Re- Completion Nabors 3S 2/6/10 Lee Hulme ESP Re- Completion Nabors 4ES API No. 50 -029 -23040 04/20/2011 Brian Bixby ESP Re- Completion Doyon 16 06/10/12 Brian Bixby ESP Re- Completion Doyon 16 3 -14 -13 Lee Hulme ESP Re- Completion Doyon 16 BP EXPLORATION (AK) ` STATE OF ALASKA AL OIL AND GAS CONSERVATION COASSION 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 f 201 - 170 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 - 50 - 029 - 23040 - 00 - 00 7. Property Designation (Lease Number): • 8. Well Name and Number: ADL 355016 " • MPF - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 18595' feet Plugs (measured) None feet true vertical 7853' feet Junk (measured) None feet Effective depth: measured 18469' feet Packer: (measured) 18155' feet true vertical 7730' feet Packer: (true vertical) 7427' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 10307' 10 -3/4" 10341' 4454' 5210 2480 Intermediate Production 18523' 7 -5/8" 18555' 7814' • 6890 4790 Liner Perforation Depth: Measured Depth: 18290' - 18335' 5 CANNED AIL 0 3 2012 True Vertical Depth: 7557' - 7600' Tubing (size, grade, measured and true vertical depth): 2 , 6.5# L 18092' 7366' 4 - 12 ", 12.6# L - 80 18146' - 18193' 7418' - 7463' Packers and SSSV (type, measured and true vertical depth): 7" x 4 -1/2" Baker Premier Packer 18155' 7427' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RECEIVE Treatment description including volumes used and final pressure: JUN 2 6 2012 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 295 66 1134 320 270 Subsequent to operation: 357 52 924 Not Available Not Available 14. A ttac hm e n ts : ❑ Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory O = Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 16. Well Status after work: 4. IS Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564 -4387 N/A Printed Jo: L • Title Drilling Technologist 1 ` 1 Signature , ` _ Phone 564 409 Date (0(Zo/i_ Prer fk N/ Number : g 111 Joe Lastu fka, 56 4 ame 4091 Form 10-404 R - d 11/2011 * VMS JUN 2 7 2012 -p_ l e, _ t , z $ • I e r c � ubmit Original Only • • 'Patio i Of North Arl erk a - ALASKA - BP Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/27/2012 12:00 - 14:00 l 2.00 MOB P PRE PJSM, PREPARE TO MOVE RIG - PERFORM RIG MOVE CHECK LIST - PREP RIG TO MOVE, RAISE DOORS AND STAIRS WARM UP HYDRAULICS, AND PERFORM SPCC WALK THROUGH 14:00 - 19:30 5.50 1 MOB P PRE MOVE RIG OFF OF MPC-43 WSL, TOOL PUSHER AND PAD OPERATOR PRESENT WHEN MOVING OFF WELL - CONT. RIG MOVE TO STAGING AREA NEAR PAD ENTRANCE H SMALL #6 MOVING SYSTEM CONTROL HOSE BROKE ON LEFT REAR WHEEL - REPAIRED BROKEN HYDRAULIC HOSE ON MOVING SYSTEM '- NOTIFICATIONS MADE AND TRACTION REPORT FILED # IR- 4140266 - MPU ENVIRONMENTAL REP WITNESSED AREA AND ADVISED CLEAN UP HANDLING 1 19:30 - 22:30 3.00 BOPSUR P PRE PJSM, CUTTING OPERATIONS ON THE BOP STAND - CUT OFF 12" OF BOP STAND IN CELLAR 1 CLEAN AREA AROUND MPC-43 22:30 - 00:00 1.50 BOPSUR P PRE PJSM, WORK ON BOP STACK CONFIGURATION - N/D SINGLE GATE FROM ANNULAR 5/28/2012 00:00 06:30 6.50 BOPSUR P PRE PJSM, RECONFIGURE BOP STACK - N/D SINGLE GATE, N/U DOUBLE GATE - SET ON BOP CRADLE AND REMOVE FROM CELLAR '- INSTALL REAR BOOSTERS AND FUNCTION TEST I � HELD WEEKLY 1 HOUR SAFETY MEETING WITH "B" CREW 1 - CHECK 6 DISCUSSED SITUATIONAL AWARENESS, REVIEWED SAFETY BULLETINS - - - -- - - -- -- x06:30 - 07:00 0.50 MOB P PRE PJSM RIG MOVE - REVIEW PROCEDURE AND CHECK LIST DISCUSSED MOVING AROUND 90 DEG CORNER. - DISCUSSED MOVING ON RIG MATS. - SPILL PREVENTION AND RESPONSE PLAN. - TOOLPUSHER / TOUR PUSHER / DDI HSE REP AND WSL PRESENT. 07:00 - 12:00 5.00 MOB P PRE MOVE OFF MPC -PAD AND TRAVEL ON GOOD ROAD TO THE CORNER OF L & F PAD ROAD. - MADE 90 DEG CORNER IN 1 HRS. - TRAVEL TO MPL -PAD, ROAD CONDITION GOOD TO FAIR ARRIVED AT 11:15 HRS. - CREW PERFORM MOVING SYSTEM CHECKS. - TRAVLED 200 YARDS ON RIG MATS AND MADE CREW CHANGE. Printed 6/25/2012 11:27:14AM • North America - ALASKA - BP 2 of 2 Operation Summary Report Common Well Name: MPF -94 _ AFE No Event Type: WORKOVER (WO) ! Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) I , Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) , (ft) 12:00 - 12:30 0.50 MOB P PRE PJSM RIG MOVE I - REVIEW PROCEDURE AND CHECK LIST - POLAR BEAR WATCH DISCUSSED. I- DISCUSSED MOVING ON RIG MATS. - SPILL PREVENTION AND RESPONSE PLAN. - TOOLPUSHER / DDI HSE REP AND WSL PRESENT. ' I- CREW PERFORMED PRE -MOVE INSPECTION. -- - WSL PERFORM DERRICK INSPECTION. 12:30 - 00:00 j 11.50 MOB P PRE I MOVE FROM 200 YD PAST MPF -PAD TO END OF 280 MATS. - STOP AND LEAP -FROG MATS WITH TWO END LOADERS. - CONTINUE SAME PROCESS TO MPF -PAD - PERFORM ANNUAL WORK ON BAYLOR BRAKE ' - CLEAN MOTOR ROOM - WORK ON HOPKINS DERRICK AUDIT - PERFORM MP -2 WORK ORDERS 5/29/2012 00:00 - 06:00 6.00 MOB P PRE PJSM, RIG MOVE OPERATIONS. I- CONTINUE TO MOVE RIG FROM MIDDLE OF F -PAD ACCESS ROAD TO F -PAD - 150 YARDS AWAY FROM F -PAD ENTRANCE AT 0600 06:00 09:00 3.00 MOB P PRE 1PJSM, WITH TOOLPUSHER. , - LAY MAT FOR LEAP -FROM MOVE. - ARRIVE ON MPF -PAD AT 09:00 HRS. LEFT 24 HRS NOTICE TO AOGCC AT 07:00 HRS 5/29.12 AT 659 -3607. i - OF UP COMING BOPE TEST. 09:00 - 12:00 3.00 RIGD P PRE I PU MATS ON ROAD, - LAY MATS ON BUILT UP GRAVEL PAD AT MPF -94. REMOVE REAR BOOSTER TIRES , - REMOVE GOOSE NECK 12:00 - 13:00 1.00 RIGU h P PRE PJSM, CREW CHANGE - INSTALL BOP STACK ON TO PEDESTALS IN CELLAR. - INSTALL NEW BELL RISER. - MOVE RIG EQUIPMENT FROM MPC AND MPL PADS TO MPF -PAD. 13:00 P 21:00 8.00 RIGU PRE PJSM, - BACKFILL AROUND CELLAR WITH GRAVEL TO GRADE. - LAY DOWN HERCULITE. - LAY RIG MATS IN PLACE, BUILD RAMP I AROUND MPF -94. - STAGE RIG DOWN PAD TO ALLOW ACCESS TO MPF -37. - STAGE SQUEEZE MANIFOLD IN CELLAR 1 I AREA. - 24 HR NOTICE FOR INITIAL TEST. WITNESS Y WAIVED BY AOGCC MAT HERRERA Printed 6/25/2012 11:27:14AM • North America - ALASKA - BP lip ' Page 3 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) , Start Date: 5/30/2012 I End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task 1 Code NPT NPT Depth I Phase I Description of Operations 21:00 22:30 1.50 RIGU P (ft) I PRE I PJSM FOR BACKING RIG OVER WELL, 1 REVIEW BACKING OVER WELL SOP. NOTE TUBING= 100 PSI. BPV INSTALLED. 1 ' 1 I /A= 1250 PSI. O /A= 190 PSI. 1 1 1 - CLOSE ALL TREE VALVES. I I - BACK OVER AND SPOT RIG ON MPF -94. - LEVEL AND SHIM RIG. 1 I - LOWER CELLAR DOORS. 22:30 - 00:00 1.50 RIGU P PRE PJSM FOR RAISING DERRICK - PREP RIG FLOOR, RAISE DERRICK, CATTLE I CHUTE I- SECURE RIG FLOOR. - - - -- - - - - -- — -- 5/30/2012 00:00 - 04:00 1 4.00 RIGU P PRE PJSM, BRIDLE DOWN DERRICK. R/U CIRCULATING MANIFOLD ON RIG I FLOOR. I - R/U SSV ACTUATOR. OPEN SSV. 100 PSI ON I TBG. 1 - R/U KILL MANIFOLD IN CELLAR. - SPOT AND R/U FLOWBACK TANK, TEST HIGH LEVEL ALARM. - VALVE CREW R/U AND TEST HARDLINE TO 1 FLOWBACK TANK TO 250/3500 PSI 5 MINUTES EACH CHARTED. 04:00 - 04:30 1 0.50 RIGU P PRE CONDUCT H2S RIG EVACUATION DRILL. 1 - CONDUCT AAR FOR EVAC DRILL. - GOOD EVACUATION. WORKERS THROUGHOUT RIG RESPONDED QUICKLY. - TRUCK DRIVERS MONITORED HUB 188 AND RESPONDED. I- DISCUSSED AVAILABLE AIR PACK LOCATIONS. REVIEW MSDS SHEET FOR NALCO SCALE I INHIBITOR. - RIG ACCEPTED ON MPF -94 AT 04:30 HRS. 04:30 05:30 1.00 WHSUR P DECOMP PJSM, R/U TO TEST KILL MANIFOLD. - LOAD PITS WITH 11 PPG KWF. I- TEST MANIFOLD TO 250/3500 PSI 5 MIN EACH. CHART RECORD TESTS. 05:30 07:30 2.00 WHSUR P DECOMP --- PJSM, WELL SUPPORT LUBRICATOR. - P/U & M/U DSM LUBRICATOR TO TREE. - PRESSURE TEST AGAINST THE SSV VALVE - 250 PSI / 3500 PSI, BOTH FOR 5 CHARTED I MINUTES. PASSED. - PULL 2 1/2" TYPE 'H' BPV I I- SITP = 1360 PSI PRIME #1 MP WITH KWF. 07:30 - 10:00 2.50 J KILLW P 1 DECOMP 1 1 TRANSFER KWF FROM STORAGE TANKS ON I MPL -PAD. - ADJUST KWF TO 11.0 PPG NACL / NABR - MIX 0.5 % SAFELUBE - 675 BBLS KWF. 10:00 - 11:00 1.00 KILLW P DECOMP PJSM WELL KILL OPERATIONS. RIG CREW, TRUCK DRIVERS, SCS, MUD ENGINEER, TOOLPUSHER, DAY WSL AND , I RWO SUPERINTENDANT PRESENT. Printed 6/25/2012 11:27:14AM ilo North America - ALASKA - BP Page 4 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date I From - To Hrs I Task Code I NPT I NPT Depth Phase Description of Operations I hr (ft) 11:00 12:00 1.00 1 KILLW P DECOMP TOOLPUSHER AND WSL VERIFY VALVE 1 ALIGNMENT. - SITP = 1400 PSI - SI CP = 1250 PSI OA= 190 PSI - BLEED IA THROUGH THE CHOKE TO THE 1 FLOW BACK TANK 1 - FROM 1400 PSI TO 950 PSI IN -10 MINUTES TILL FLUID RETURNED. - SI WELL. 12:00 - 13:00 1.00 KILLW P DECOMP PERFORM PRETOUR CHECKS. - CHANGE OUT POWER TONGS TO RIG T FLOOR. 1 13:00 - 14:00 1.00 KILLW P DECOMP I PJSM, WELL KILL OPERATION. I- EACH WORKER DISCUSSED HIS / HER I ROLES & RESPONSIBILITY. T I I- REVIEW DDI WELL KILL SOP. 14:00 - 17:00 3.00 KILLW P DECOMP WELL KILL -TOOLPUSHER AND WSL VERIFY VALVE ALIGNMENT. - START TO PUMP, THE ANNULAS PRESSURE SENSOR FAILED. - SI WELL DISCUSS PLAN FORWARD. - CHANGED OUT SENSOR, PRESSURE 'TESTED 250 / 3500 PSI. - DISCUSSED TRAPPED PRESSURE ON ' MANIFOLD. - BLEED TRAPPED PRESSURE THROUGH 1/4" WHITEY VALVE. - PUMPED 110 BBLS 11.0 PPG NACL / NABR DOWN THE TBG - 3 BPM / ICP 1600 PSI, FCP 1130 PSI. SI WELL. -BULL HEAD DOWN THE TBG WITH 11 PPG KWF 1- 1 BPM / 260 PSI - 4 BPM /-2100 PSI - STOP, PUMP OFF - RECORD FORMATION BLEED DOWN FROM 700 PSI TO 260 PSI IN 5 MINUTES. Printed 6/25/2012 11:27:14AM North America - ALASKA - BP Page 5 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 23:45 6.75 KILLW P DECOMP PJSM, WELL KILL OPERATION. - WITH RWO FIELD SUPERINTENDANT, WSL AND TOOL PUSHER AT KILL MANIFOLD. - LINE UP TO PUMP DOWN TBG, AND TAKE RETURNS TO FLOWBACK TANK. - VERIFY VALVE ALIGNMENT. - START PUMPING SLOWLY OPENING CHOKE ON KILL MANIFOLD. ICP= 500 PSI - PUMP 11 PPG KWF 2.6 BPM WITH 930 PSI ON TBG HOLDING 1400 PSI BACK PRESSURE WITH CHOKE. - MONITOR PRESSURE ON LINE TO TIGER TANK KEEPING BELOW 150 PSI. - DUE TO ONLY 1 VAC TRUCK AVAILABLE TO (TRANSFER FLUID FROM UPRIGHTS AT MPL PAD TO MPF PAD, PUMP RATE REDUCED TO 2 BPM 650 PSI. - MAINTAIN 1170 PSI BACK PRESSURE WITH CHOKE. - MONITOR RETURNS TO FLOWBACK TANK. - LOSS RATE PUMPING 2 BPM NOTED AT -5/10 BPH. - PUMP 550 BBLS, REDUCE PUMP TO 1 BPM TO KEEP UP WITH FLUID TRANSFER RATE. WITH TBG AT 180 PSI HOLDING 220 PSI BACK PRESSURE WITH CHOKE. - SAMPLE RETURNS AND CHECK FLUID WEIGHT AFTER PUMPING 511 BBLS. - CHECK RETURN FLUID WEIGHTS AT 10 MIN INTERVALS. WITH 648 BBLS PUMPED RETURN FLUID WT 10.6 PPG, CHOKE FULLY OPEN. - 685 BBLS PUMPED RETURN FLUID WT 10.9 PPG. FCP= 120 PSI 23:45 00:00 0.25 KILLW P DECOMP - ' ,SHUT IN WELL, MONITOR SHUT IN PRESSURES FOR 30 MINUTES. - LOSSES TO WELL DURING WELL KILL 147 ' BBS. - LOSSES TO WELL IN THE LAST 24 HRS INCLUDING BULLHEADING= 197 BBLS. 5/31/2012 00:00 01:30 ' 1.50 KILLW P DECOMP MONITOR WELL FOR 30 MINUTES. - CHECK TBG, ON SLIGHT VAC. I/A= 9 PSI '- NOTIFY ODE AND RWO RIG SUPERINTENDANT. - DISCUSS PLAN FORWARD TO R/U AND ' CIRCULATE TO TAKE RETURNS THROUGH CHOKE VIA GAS BUSTER. DISCUSS PLAN FORWARD WITH CREW. 01:30 - 02:30 1.00 KILLW P DECOMP R/U TO CIRCULATE DOWN TBG TO TAKE RETURNS THROUGH CHOKE VIA GAS BUSTER. - PRESSURE TEST HOSE TO 250/3500 PSI 5 MIN EACH, CHART TEST. Printed 6/25/2012 11:27:14AM • North America - ALASKA - BP 410 Page 6 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 03:15 0.75 I KILLW P DECOMP OPEN WELL AGAINST RIG CHOKE. - START PUMP OPENING CHOKE TAKING RETURNS VIA GAS BUSTER. - PUMP 85 BBLS 2 BPM 530 PSI. WHILE PUMPING 2 BPM LOSSES AT 12 BPH. - 11 PPG KWF IN, CLEAN 11 PPG KWF OUT. - TOTAL PUMPED DURING KILL 770 BBLS. - SHUT DOWN PUMP. - SHUT IN WELL 03:15 - 04:00 0.75 KILLW P DECOMP !MONITOR WELL FOR 30 MINUTES. - TBG= 0 PSI. I /A= 0 PSI. - CHECK WHITEY VALVE, BOTH ON SLIGHT VAC. - OPEN WELL. MONITOR FOR 15 MIN. - CONTINUES ON SLIGHT VAC. - WELL IS DEAD. 04:00 04:30 0.50 EVAL P ! DECOMP CIRCULATE DOWN TBG AT .5 BPM. ESTABLISH RETURNS. - PUMP DOWN TBG WITH CHARGE PUMP ONLY. - ESTABLISH STATIC LOSS RATE AT 12 BPH. 04:30 - 05:00 0.50 WHSUR P DECOMP , PJSM WITH VALVE CREW. CHECK CURRENT CERTS ON LUBRICATOR. REVIEW SOP FOR SETTING TWC. - R/U LUBRICATOR. 05:00 - 06:45 1.75 WHSUR 1 P DECOMP PRESSURE TEST 2 1/2" TYPE 'H' TWC - TWC PRESSURE TESTED FROM ABOVE - 250 PSI / 3500 PSI BOTH FOR 5 CHARTED MINUTES. PASSED. - PFRFORM 10 MINIITF ROI I INC; TFST FROM QELOW, - 2 BPM / 500 PSI - PUMP OFF @ 400 PSI, PRESSURE DROP TO 260 PSI IN 1 MINUTE 180 PSI IN THE SECOND MINUTE. - 23 BBLS PUMPED, 4 BBLS BLEED BACK. ■- SECURE WELL. 06:45 - 07:00 0.25 WHSUR P DECOMP R/D WELL SUPPORT LUBRICATOR. - INSTALL & SECURED TREE CAP. UD LUBRICATOR. - 07 DECOMP M, 07:00 07:30 0.50 WHSUR P i PJSM, BLOW DOWN ALL CIRCULATING LINES / VALVES. - R/U TO FILL THE WELL AT THE IA VALVE. - PUMP 23 BBLS TO FILL THE IA WITH 11.0 PPG BRINE. 07:30 - 08:30 1.00 WHSUR P DECOMP PJSM, R/U CENTRILIFT PUMP TO CHEMICAL INJECTION LINE PRESSURE UP 4000 PSI NO BLEED OFF - DISCUSSED OPTIONS WITH RWO ENGINEER. - STOP OPERATION, BLEED TO '0' PSI AND R/D PUMP. Printed 6/25/2012 11:27:14AM • North America - ALASKA - BP • Page 7 of 22 ' Operation Summary Report Common Well Name: MPF -94 I AFE No 1 Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 1 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point j Site: M Pt F Pad —, Rig Name /No.: DOYON 16 ' Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task 1 Code 1 1 NPT 1 NPT Depth I Phase Description of Operations 10:30 2.00 WHSUR P (ft) 08:30 DECOMP (hr) I - PJSM IV/D 2 9/16" 5M PRODUCTION TREE. I- FMC REP BLEED OF HANGER VOID I- OBSERVED BUBBLE LEAKING FROM BLEED OFF TOOL - AFTER FLUID WAS BLED. - CONFERENCE CALL WITH ANCHORAGE RWO ETL AND RWO TEAM. I - DISCUSSED PLAN FORWARD WITH RWO SUPERINTENDENT. I - 8 TURNS TO M/U LANDING THREADS 2 7/8 ", 8RD EUE. 10:30 12:00 1.50 BOPSUR 1 P DECOMP ; PJSM. N/U 13 5/8" BOPE N/U 11" X 13 5/8" 5M, FLANGED SPOOL. - M/U 4 PREVENTER BOP STACK. 1- PER WELL PLAN. 12:00 - 16:00 4.00 BOPSUR P DECOMP ' PJSM, INSTALL BLIND SHEAR BOP RAMS. I - INSTALL UPPER 2 7/8" X 5" VBR - FUNCTION TEST BOPE. 16:00 - 17:00 1.00 BOPSUR P DECOMP PJSM, REVIEW DDI SOP FOR TESTING BOPE. - WITH 2 BARRIERS IN PLACE- 11 PPG KWF AND TESTED TWC. - RODY TFST ROP TO 250/3500 PSI 5 MIN EACH. 1- CONTINUE TO KEEP VA FULL USING CHARGE PUMP WITH BLEED LINE. 17:00 - 18:00 I 1.00 ' BOPSUR P ' I DECOMP SERVICE HCR KILL AND CHOKE. I 1 18:00 - 19:00 ' 1.00 , BOPSUR P DECOMP FINISH R/U BOP TEST EQUIPMENT. ' 1 19:00 - 00:00 5.00 BOPSUR P DECOMP CONDUCT TEST ON BOPE. p AOGCC STATE REP MATT HERRERA a WAIVED WITNESSING TEST. - BOP TEST WITNESSED BY WSL AND TOOL I PUSHER. CONDUCT FULL TEST ON ALL BOPE COMPONENTS. 1 - TESTING @ 250 / 3500 PSI, 5 MIN EACH / CHARTED. I - TEST ANNULAR PREVENTOR W/ 2 7/8" TEST ' JT @ 250 / 3500 PSI, 5 MIN EACH / CHARTED. 1 - TEST UPPER AND LOWER VBRS WITH 2 7/8" I AND 4" TEST JTS. CONTINUE TO KEEP VA FULL USING 1 CHARGE PUMP WITH BLEED LINE. - I/A TAKING APPROX 8 BPH. - LOSSES TO WELL IN LAST 12 HRS= 92 I I BBLS. - LOSSES TO WELL IN LAST 24 HRS= 210 BBLS 6/1/2012 00:00 - 01:00 1.00 BOPSUR 1 P I DECOMP PJSM WITH CREW. REVIEW DDI SOP FOR I TESTING BOP. - CONTINUE TEST ON LOWER VBRS WITH 4" TEST JT. - PERFORM ACCUMULATOR DRAW DOWN TEST. 1 1- PERFORM PRESSURE BLEED TEST ON 1 1 MANUAL AND HYD. CHOKE TO 1500 PSI 5 MIN 1 EA. CHARTED. 1 1 - CONTINUE TO KEEP VA FULL USING CHARGE PUMP WITH BLEED LINE. 1 - TEST LEL ALARMS. Printed 6/25/2012 11:27:14AM i North America - ALASKA - BP P 8 of 22 Operation Summary Report Common Well Name: MPF -94 I AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth 1 Phase 1 Description of Operations (hr) 01:00 - 02:00 1.00 BOPSUR P (ft) DECOMP � - ' i R/D TEST EQUIPMENT. - BLOW DOWN CHOKE MANIFOLD. - M/U SAFETY JT. - DRAIN BOP STACK. 02:00 - 04:00 2.00 BOPSUR P I DECOMP PJSM FOR PULLING TWC W/ DSM, WSL, I TOOLPUSHER AND CREW. - REVIEW DDI SOP FOR PULLING TWC. - R/U OPSO LOPSO LUBRICATOR W/ 2 7/8" I EUE PIN. - TEST LUBRICATOR AGAINST TWC TO 250/3500 PSI 5 MIN EACH. I , - CHART RECORD TEST. - PULL TWC - TBG ON SLIGHT VAC. - L/D LOPSO OPSO/ LUBRICATOR . , 1- CONTINUE TO KEEP VA FULL USING CHARGE PUMP WITH BLEED LINE. 04:00 - 04:30 0.50 BOPSUR P : DECOMP PJSM, ON PULLING TBG HANGER TO RIG FLOOR AND L/D SAME. ,- WSL, TOOLPUSHER, CENTRALIFT REP, FMC REP. AND CREW IN ATTENDANCE I REVIEW DDI SOP FOR PULLING HANGER WITH ESP. '- REVIEW STEPS IN WELL PLAN FOR PULLING ESP COMPLETION. - DISCUSS WELL CONTROL PLAN WHILE I PULLING ESP. - CHECK CERTIFICATIONS ON CENTRALIFT DUAL SHEAVE. - REVIEW HANGING SHEAVE, DROPPED OBJECT MITIGATION. - POTENTIAL HAZARDS WITH NALCO CHEMICAL IN CAP TUBE. 04:30 - 05:30 ' 1.00 PULL P DECOMP R/U 2 7/8" LANDING JT WITH TIW VALVE AND CLOSE SAME. - PERFORM CAP TUBE AND ESP CABLE I ! CUTTING DRILL WITH FLOOR CREW AND CENTRALIFT. - M/U LANDING JT TO HANGER. I- CLOSE VA VALVES. R/D VA FILL UP LINE. - FMC REP BOLDS. - WSL VERIFY NO TRAPPED PRESSURE UNDER TBG HANGER. I - HANGER OFF SEAT 125K. BROKE OVER 145K. P/U WT 125K. - SO WT 70K (40K BLOCK WT INCLUDED) 1 _ _ - PULL TBG HANGER TO RIG FLOOR. 05:30 - 06:00 0.50 PULL P I DECOMP REMOVE ESP CONNECTION FROM TBG 'HANGER - CUT ESP CABLE AND CHEMICAL TUBE I (REQUIRED PPE WAS USED) 1- L/D 11" FMC TBG HANGER. - M/U SAFETY JOINT WITH FOSV AND POSITION SLICK JOINT I , I - ACROSS BOP STACK. I I - CLOSE ANNULAR, OPEN CHOKE TO A FULL GAS BUSTER. ' - TIME FOR THIS JOB WAS 22 MINUTES. WSL ',PRESENT. ! Printed 6/25/2012 11:27:14AM • North America - ALASKA - BP • Page 9 of 22 Operation Summary Report , Common Well Name: MPF -94 -- AFE No Event Type: WORKOVER (WO) I Start Date: 5/30/2012 1 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To I Hrs Task Code ' NPT 1 NPT Depth I Phase I Description of Operations (hr) (ft) 1 06:00 - 06:30 0.50 PULL P DECOMP 1 PUMP 50 BBLS 11.0 PPG BRINE DOWN THE TBG, UP - THE IA THROUGH THE OPEN CHOKE TO THE GAS BUSTED - 3 BPM / 1280 PSI - 50 BBLS PUMPED, 9 BBLS LOST. 06:30 - 08:00 I} 1.50 PULL P DECOMP PJSM, HANG ESP DBL CABLE SHEAVE IN DERRICK. - MONITOR SI WELL FOR 15 MINUTES. I - WSL VARIED TBG AND IA ON A VACUUM - OPEN WELL. START CONTINUOUS HOLE FILL, 11.0# BRINE. - AAR: - WORKER TO SUIT -UP IN PPE PRIOR TO PULL TBG HANGER. I - MAKE ONLY ONE CUT ON THE CAP -TUBE AT I I THE 1ST CLAMP. - HANG ESP DBL CABLE SHEAVE IN I DERRICK. ATTACH CABLE TRUNK AND 'THREAD -ROPES TO SHEAVE. 08:00 - 08:30 0.50 i PULL 1 P DECOMP PJSM, CREW, CENTRILIFT REP, TOOL ' PUSHER AND WSL. DECOMP DOYON PULLING ESP S.O.P. I 08:30 11:30 3.00 PULL P I POH WITH ESP COMPLETION AND STAND IN 1 DERRICK - 2 7/8" 6.5#, EUE 8RD TBG. I - ESP CABLE AND CHEMICAL INJECTION LINE. I - CONTINUOUS HOLE FILL. 8 BPH LOSS RATE. - KWF 11.0 PPG BRINE. I - FROM SURFACE TO 16200' MD. SURPRISE "KICK WHILE TRIPPING ESP" I I DRILL. - BP RWO SUPERINTEND, WSL AND TOOL PUSHER PRESENT. -AAR: - 2.50 MINUTES, GOOD TIME WITH A FULL STAND ALMOST OUT OF THE HOLE. - FIND A THREAD PROTECTOR THAT CAN BE REMOVED FASTER FROM THE FOSV ASSEMBLY. 11:30 - 12:30 1.00 PULL P DECOMP DISASSEMBLE & REMOVE ALL HARD LINE CIRCULATION MANIFOLD COMPONENTS - FROM CELLAR. - 2' MANUAL CHOKE AND CHECK VALVES ASSEMBLY. - SENT TO GBR TO PREFABRICATE OF SAFETY STAND. 12 HRS LOSSES TO WELL = 79 BBLS. 1 I I - 8 BPH LOSS RATE. Printed 6/25/2012 11:27:14AM 0 North America - ALASKA BP ' • . Page 40 of 22. Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 X4-00W9Y-E: (1,480,000.00 ) 1 Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) ,12:30 - 13:00 '; 0.50 PULL P DECOMP I CONTINUE POH W/ 2 7/8" ESP COMPLETION 1 ASSEMBLY. - FROM 16000' TO 15600' MD. 1 - AT OLD SPLICE. NOTE CREW MEMBER CHANGES ON C ICI CREW. NEW RSTB WATCH MPU ORIENTATION VIDEO. - DDI ORIENTATION CHECKLIST TO COMPLETE. ,- 5 MINUTE ESCAPE PACK ORIENTATION. 1 - PROMOTED FROM PIT WATCHER TO DERRICKS. - PROMOTED FROM FLOORS TO PIT WATCHER. - PROMOTED FROM RSBT TO FLOORS. 13:00 - 13:30 0.50 PULL P DECOMP REMOVE REEL FROM ESP SPOOLING UNIT ' AND - LOAD WITH EMPTY. 13:30 - 18:00 I 4.50 PULL P DECOMP CONTINUE POH WITH ESP COMPLETION AND STAND IN DERRICK 2 7/8" 6.5#, EUE 8RD TBG. - SPOOLING ESP CABLE AND CHEMICAL ' INJECTION LINE. CONTINUOUS HOLE FILL. 8 BPH LOSS RATE. - KWF 11.0 PPG BRINE. - FROM 15600' TO 12000' MD. 1 - CONDUCT KICK WHILE TRIPPING DRILL WHILE PULLING ESP. - WSL PRESENT. I- AAR: 4 MINUTES. GOOD TIME FOR SECURING WELL WITH FULL STAND OUT. - TUBING CUTTER HANDLE SCREW CAME LOOSE CAUSING MORE TIME TO SIMULATE CAP TBG CUT. - INSPECT TOOLS PRIOR TO NEEDING, I ANOTHER TBG CUTTER AVAILABLE BUT WAS NOT OUT OF TOOL BOX READY FOR USE. 18:00 - 23:00 5.00 I PULL P DECOMP CONTINUE POH WITH ESP COMPLETION AND STAND IN DERRICK - 2 7/8" 6.5#, EUE 8RD TBG. - SPOOLING ESP CABLE AND CHEMICAL INJECTION LINE. - CONTINUOUS HOLE FILL, LOSS RATE 7 -8 I I 1 BPH 1 - KWF 11.0 PPG BRINE. - SPLICE IN ESP CABLE AT 10866'- 106 STANDS AND DOUBLE OUT. FROM 12000' TO 10366' - 110 STANDS IN DERRICK Printed 6/25/2012 11:27:14AM • North America - ALASKA - SP Page '11 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 1X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UW1: 500292304000 - - - - -- — - - -- - -- - - - - - -- - -- - -- Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 23:00 - 00:00 I 1.00 PULL P (ft) DECOMP REMOVE REEL FROM ESP SPOOLING UNIT AND - LOAD WITH EMPTY REEL. - LOSSES TO WELL IN LAST 12 HRS= 96.5 BBLS. - LOSSES TO WELL IN THE LAST 241-IRS= 175.5 BBLS. - INCLUDING PIPE DISPLACEMENT OF 42 BBLS PIPE DISP. AT 10866' - HOLE TAKING APPROX 7 -8 BPH. 6/2/2012 00:00 - 03:40 3.67 PULL P DECOMP PJSM FOR PULLING ESP COMPLETION. CONTINUE POH WITH ESP COMPLETION FROM 10366', STAND IN DERRICK - 2 7/8" 6.5#, EUE 8RD TBG. - SPOOLING ESP CABLE AND CHEMICAL INJECTION LINE. - CONTINUOUS HOLE FILL, 7 -8 BPH LOSS RATE. - KWF 11.0 PPG BRINE. 1- NOTE CREW MEMBER POSITION CHANGE, 1B CREW. h FROM RSTBT TO FLOORS. - FROM FLOORS TO RSTBT. - POH TO 2800'- WITH 162 STANDS IN DERRICK Printed 6/25/2012 11:27:14AM • North America - ALASKA : BP i Page 12 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 ! End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad 1 , Rig Name /No.: DOYON 16 Spud DatefTime: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Levef) Date From - To Hrs Task 1 1 Code NPT NPT Depth Phase Description of Operations (hr) -r 03:40 04:15 0.58 PULL P (ft) DECOMP CONDUCT COMPLEX WELL CONTROL DRILL WHILE PULLING ESP COMPLETION. WITH THE MOTORMAN ON THE BRAKE, WSL SAID THIS IS A DRILL, HOLE FILL INCORRECT. - STOPPED PULLING PIPE. SHUT DOWN HOLE FILL PUMP- SIMULATED WELL FLOWING. - WITH FULL STAND RACKED IN DERRICK, FLOORHANDS M/U FLOOR VALVE. TORQUED CONNECTION. - CLOSED TIW VALVE. - MOTORMAN SLACKED OFF ON BLOCKS AND LATCHED UP PIPE IN SLIPS. - PULLED SLIPS. P/U TO NEXT ESP CLAMP. SIMULATED CUTTING CABLE- CAP TUBE. - SLACK OFF SPACING TOOL JT AT FLOOR IN 3 MINUTES. - MOTORMAN WENT TO CLOSE ANNULAR. WSL SAID ONLY 300 PSI ON ACCUMULATOR MANIFOLD. - WSL ASKED WHAT IS HAPPENING- YOU HAVEN'T GOT ENOUGH PRESSURE TO CLOSE ANNULAR. - THE AIR PUMP AND ELECTRICAL PUMP ARE CONTINUOSLY RUNNING AND HYD RESIVOIR IS FULL. - WSL SAID POP VALVE ON ACCUMULATOR HAS TRIPPED OR FAILED CAUSING PUMPS TO RUN. - CAUSING ALL STORED MANIFOLD PRESSURE TO BLEED DOWN TO 300 PSI. - MOTORMAN SAID HE WOULD HAVE DESIGNATED HAND AT KOOMEY PUT BOP VALVE HANDLES IN NEUTRAL POSITION. SHUT OFF KOOMEY PUMPS. ISOLATE MANIFOLD TO OPERATE N2. - OPEN N2 BOTTLES AND CLOSE ANNULAR !! ! AT KOOMEY. - AAR HELD WITH CREW, TOOLPUSHER AND WSL: - LIFTING CAP NEEDS TO BE UNSCREWED AND NOT MADE UP ON FLOOR VALVE AFTER !BEING INSTALLED. POWER TONG DOOR WAS OPEN MAKING TUGGER INOPERABLE - CLOSE DOOR. 1- WHEN TOOL JT WAS POSITIONED AT FLOOR DO NOT SET SLIPS. 04:15 - 05:00 0.75 PULL P DECOMP CONTINUE POH WITH ESP COMPLETION FROM 2800', STAND IN DERRICK 2 7/8" 6.5#, EUE 8RD TBG. - FROM 2800' MD TO 242' MD. - SPOOLING ESP CABLE AND CHEMICAL INJECTION LINE. - CONTINUOUS HOLE FILL, 7 -8 BPH LOSS RATE. - KWF 11.0 PPG BRINE. Printed 6/25/2012 11:27:14AM i North America - ALASKA - BP lip Page 13 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) I Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To ! Hrs Task Code NPT I NPT Depth Phase Description of Operations 05:00 - 07:00 2.00 PULL 1 P (ft) DECOMP ''1 MONITOR WELL PRIOR TO TRIPPING NON SHEARABLES ACROSS THE BOP STACK. - LID 3 JOINTS 2 7/8" TBG, GLM AND 10' PUP I WITH 'XN' NIPPLE. - FROM 242' TO ESP ASSEMBLY @ 73' MD. 07:00 - 09:00 2.00 1 PULL P DECOMP POH AND BRAKE DOWN ESP PUMP AND 1 I MOTOR ASSEMBLY. I - SAMPLE TAKEN FROM CHEMICAL I , INJECTION LINE WAS DENTED - 3 FT FROM INSTALL POINT. 1 - WELL LIFT GAUGE LINE WAS DENTED -2" - I 1 3" FROM INSTALL POINT. - MOTOR CONDUCTIVITY TESTED GOOD. - PUMP HAD BROKEN SHAFT FROM TOP. ! - NO EXTERNAL SCALE NOTED. RECOVERED - 566 CANNON CLAMPS 5 PROTECTILIZERS - 3 ARMSTERGUARDS I- 2 HALF CLAMPS. REPLACED TOTAL 2 BAD JOINTS 2 -7/8" TBG. 09:00 - 10:30 1.50 I PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. REMOVE CABLE CLAMPS AND CUT OFF CABLE PIECES FROM FLOOR. - CLEAN FLOOR. - R/D & LOWER ESP CABLE TRUNK. 10:30 - 11:00 0.50 l WHSUR P DECOMP FLUSH BOP STACK 1 _ - INSTALL 7" WEAR RING WITH 4 L.D.S. ' 11:00 - 11:30 0.50 EVAL P DECOMP I PJSM, P/U 7" HES CHAMP TEST PACKER. ✓ - MU TO 1 JOINT 2 -7/8" TBG. T 11:30 12:00 0.50 EVAL P DECOMP RIH WITH 7" CHAMP PACKER ON 2 7/8" TBG FROM DERRICK. I -TO 570' MD. - USE CAUTION SETTING SLIPS AND NOT TO I TURN PIPE. I - TRIP AT MODERATE SPEED. I- USE CONTINUOUS HOLE FILL. 1 - 12 HRS LOSSES = 85 BBLS H -OA =250 PSI 12:00 - 13:00 1.00 EVAL 1 P 1 DECOMP 'TOUR CHANGE, PJSM, PERFORM PRE -TOUR CHECKS } I i - RIG SERVICE. 13:00 - 16:30 3.50 EVAL P T DECOMP RIH WITH 7" CHAMP PACKER, XO, 159 JTS 2 7/8" 6.5# EUE TBG- 53 STDS, XO, XO= 5014.59' I I- FROM 579' MD. I 1 , - REPLACED JOINT # 546. 1- TOOL SERVICE NORM TESTED 2 GLM'S AND BAD JT 2 7/8" TBG. - WSL COMPLETED FACE TO FACE 'HAND I OVER' WITH AK, OPS MPU WELL OPS FOR NEXT WELL MPF -18. Printed 6/25/2012 11:27:14AM i North America - ALASKA - BP Page 14 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 rX4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT I NPT Depth Phase Description of Operations (hr) (ft) 16:30 00:00 7.50 EVAL P ' DECOMP PJSM, R/U TO RUN 4" DRILL PIPE. ' DRIFT AND P/U 4" DRILL PIPE FROM PIPE SHED. - CONTINUE TO RIH TO 9770', 151 JTS 4" DP P /U. - USE CAUTION SETTING SLIPS AND NOT TO ' TURN PIPE. I - TRIP AT MODERATE SPEED. 1 - USE CONTINUOUS HOLE FILL. I I 1- WELL CONTINUES TAKING 8 BPH. I I - LOSSES TO WELL IN LAST 12 HRS= 71 , BBLS. - LOSSES TO WELL IN THE LAST 24 HRS= 156 BBLS. - O /A= 250 PSI. 6/3/2012 00:00 - 05:00 5.00 EVAL P DECOMP I PJSM, R/U TO RUN4" DRILL PIPE. - DRIFT AND P/U 4" DRILL PIPE FROM PIPE SHED. - CONTINUE TO RIH. - USE CAUTION SETTING SLIPS AND NOT TO TURN PIPE. - TRIP AT MODERATE SPEED. I- USE CONTINUOUS HOLE FILL. L - CURRENT DEPTH AT 05:00 14485' 1 05:00 - 09:30 4.50 EVAL P DECOMP CONTINUE - DRIFT AND P/U 4" DRILL PIPE FROM PIPE SHED. - FROM 14485' TO 17250' MD. WITH CONTINUOUS HOLE FILL 11.0 PPG BRINE. I - 6 - 8 BPH LOSS RATE. Printed 6/25/2012 11:27:14AM 0 North America - ALASKA - BP 0 Page 15 of 22 Operation Summary Report Common Well Name: MPF -94 I AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM I Rig Release: Rig Contractor: DOYON DRILLING INC. ,UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth I Phase I Description of Operations 09:30 - 12:00 2.50 EVAL P DECOMP PJSM, SET 7" CHAMP PACKER AND MIT -IA 7" , TEST CSG. - DISCUSSED VALVE ALIGNMENT, FLOW PATH, TRAPPED PRESSURE, VERIFY BOP RAMS ARE OPEN. - PURGE AIR FROM TOP DRIVE AND I I CIRCULATING LINES. , I I - CIRCULATE 19.5 BBLS KWF ACROSS SETTING DEPTH @ 5 BPM / 1400 PSI - PUW= 150K,SOW =96K, . 1 - ET 7" CHAMP TE T PACKER 17 250' MD WITH 20 -K ON PACKER, PER HES REP. LS`\ - WSL / TOOL PUSHER VERIFY VALVE vv ALIGNMENT. CI nSF UPPFR PIPF RAMS. - PUMPED 42 STROKES TO PRESSURE UP TO i 2500 PSI. !- GOOD 30 MINUTE FLAT -LINE TEST. (PER I ! I ADWOP CRT- AK- 10 -45) !- USED BP CALIBRATED CHART RECORDER. DATED 5/3/12. , , i- WSL / TOOL PUSHER VERIFY ALL TEST I 1 PRESSURE BLED TO '0'. - RELEASED CHAMP PACKER WITH 5 K OVER PULL. j - MONITOR WELL FOR 30 MINUTES. - OA PRESSURE INCREASED DURING TEST ' I FROM 210 PSI TO 475 PSI AND POST TEST 220 PSI. 1 , , VERIFY 7" CSG TEST RESULTS WITH WTL, 1 RWO FIELD SUPERINTENDANT AND ODE. 1- RECEIVED AUTHORIZATION FROM WTL TO ' PROCEED WITH WELL OPS. 12:00 13:00 I 1.00 + EVAL P DECOMP PJSM, TOUR CHANGE. - PERFORM PRE -TOUR CHECKS - BLOWN DOWN TOP DRIVE AND CHOKE / KILL LINE. T 13:00 - 00:00 11.00 EVAL P DECOMP POH UD 4" DP TO PIPE SHED 1X1. - WSL PRESENT WHILE POH FOR POSSIBLE 1 SWABBING. - POH FROM 17,250' MD TO 9387' MD -USE CONTINUOUS HOLE FILL. - 6 - 8 BPH LOSS RATE. I - LOSSES TO THE WELL THE LAST 12 HRS= 58 BBLS. - LOSSES TO THE WELL THE LAST 24 HRS= I 112 BBLS. P + - O /A= 220 PSI. 6/4/2012 00:00 - 01:00 1.00 EVAL , DECOMP POH WITH 7" PACKER. - - UD 4" DP TO PIPE - POH FROM 9387' MD TO 7319' MD -USE CONTINUOUS HOLE FILL- 11 PPG T BRINE. Printed 6/25/2012 11:27:14AM . . • North America - ALASKA - BP • Page 16 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 I End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date I From - To I Hrs I Task Code ' NPT NPT Depth I Phase Description of Operations I 1 I 101:00 02:30 1.50 EVAL I P + (ft) DECOMP PJSM, SLIP AND CUT DRILLING LINE AS PER • DDI SOP. ' - CONTINUOUSLY FILL HOLE - MONITOR HOLE FILL. 02:30 - 04:30 2.00 1 EVAL P DECOMP CONTINUE POH UD 4" DP TO PIPE SHED 1X1 - POH FROM 7319' MD TO 5003' MD -USE CONTINUOUS HOLE FILL. 04:30 - 07:00 2.50 EVAL P DECOMP R/U AND POH WITH 2 7/8" TBG FROM 5003' to ,SURFACE - STAND BACK 2 7/8" TBG IN DERRICK. ! -USE CONTINUOUS HOLE FILL WITH 11 PPG . KWF. 07:30 08:00 ' 0.50 RUNCOM ' P RUNCMP PJSM, PULL WEAR RING - M/U 2 7/8" FOSV WITH PUP. - STAGE OPEN ESP BOXES ON PIPE RACK IN PIPE SHED. 08:00 - 12:00 ' 4.00 RUNCOM I P RUNCMP I PJSM WITH CENTRILIFT REP: M/U ESP PUMP AND MOTOR ASSEMBLY. - M/l l FSP ASSFMRI Y WITH CHFMICAI INJECTION LINE , LINE IS (PURGED WITH HYDRAULIC OIL) ' PULL ESP CABLE AND CAPTUBE OVER DOUBLE SHEAVE IN DERRICK. - CENTRILIFT REP CHECK CONDUCTIVITY OF ' ESP CABLE. GOOD. - PUMP OPEN CAPTUBE TO CONFIRM Y } INTEGRITY. 12:00 - 12:30 P 0.50 RUNCOM - RUNCMP I TOUR CHANGE. PJSM, REVIEW DDI SOP FOR RUNNING ESP COMPLETION INCLUDING CAP TUBE. REVIEW PLAN FOR NON SHEARABLES AT I BOP. - USING CONTINUOUS HOLE FILL, I MONITORING LOSSES. i - PERFORM PRE -TOUR CHECKS. 12:30 - 13:00 0.50 RUNCOM P RUNCMP SERVICE RIG. - DRAWORKS AND TOP DRIVE. 13:00 - 16:30 3.50 RUNCOM P RUNCMP RIH WITH ESP COMPLETION PER WFI L PLAN AND TALLEY. - RUN 6 PROTECTORS, 3 F /G- 2 HALF CANNON CLAMPS ON PUMP AND MOTOR. - RUN TBG STANDS FROM DERRICK. - 2 7/8" 6.5#, EUE 8RD TBG. - MONITOR UNSPOOLING ESP CABLE AND I CHEMICAL INJECTION LINE. USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE OR CAP TUBE. ' - CONTINUOUS HOLE FILL. - 6 BPH LOSS RATE. - KWF 11.0 PPG BRINE. - RIH TO 1636' MD. Printed 6/25/2012 11:27:14AM ' • North America - ALASKA - BP t Page 17 of 22 . Operation Summary Report ' ' Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) I Start Date: 5/30/2012 End Date: 6/7/2012 'X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ' (hr) ' (ft) 16:30 - 17:00 0.50 RUNCOM P RUNCMP CONDUCT COMPLEX DRILL WHILE RIH WITH ESP COMPLETION. ' - SIMULATE CUTTING ESP CABLE AND CAP TUBE. - SIMULATE SHUTTING IN WELL WITH ANNULAR. - SIMULATE MAN DOWN IN FRONT OF WHEEL I WELL OF RIG. HAVE TO SHUT DOWN AC RIG POWER TO ' RETRIEVE MAN DOWN DUE TO ELECTROCUTION. - THIS WOULD KILL POWER TO ACCUMULATOR INCLUDING AIR TO PUMP. - ASKED WHAT WOULD BE THE NEXT STEP WITH ACCUMULATOR. - PUT ALL ACCUMULATOR HANDLES IN NEUTRAL POSITION EXCEPT ANNULAR L ISOLATE KOOMEY MAN FO TO OPERATE N2. - ENGAGE N2. AAR: "KICK WHILE TRIPPING ESP" DRILL, CREW SIMULATED CUTTING THE ESP AND CAP TUBE BY USING THE TOOLS AND PRE- RECORDED REAL TIME OF 11 SECONDS ON THE ESP CABLE AND — 1 MINUTE ON THE CAP TUBE, PERFORMED ONE OPERATION AT A TIME WITH PROPER PPE - BEFORE THE KICK DRILL WAS COMPLETED A MAN DOWN DRILL WAS CALLED. THE 'MOTORMAN CAME AND RELIEVED THE DRILLER, THE DRILLER WENT TO THE MAN I DOWN TO TAKE CHARGE, THE MOTORMAN CALLED THE DERRICKMAN AND INSTRUCTED HIM TO TAKE OVER THE KOOMEY, WHO WAS AT THE MANDOWN LOCATION. - DERRICK HAND WILL NEED MORE CROSS TRAINING TO RELIEVE AT THE 'ACCUMULATOR. '- DISCUSS POWER FAILURE IF REQUIRED TO AID THE MANDOWN WHEN THE ESD IS ENERGIZED. - FIRST ALARM ON RADIO CALLS ARE HEARD BY WSL,TOOLPUSHER AND SCS. THEY WILL I MAKE EMERGENCY CALLS. - WHILE CONDUCTING AAR: CENRALIFT REP CHECKED CONTINUITY ON ESP CABLE. I CONTINUITY TEST FAILED. NOTIFY ODE AND FIELD SUPERINTENDANT OF FAILURE. Printed 6/25/2012 11:27:14AM • North America - ALASKA - BP e Page 18 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 'X4- 00W9Y -E: (1,480,000.00 ) I Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date 1 1 From - To Hrs Task ' Code i l NPT NPT Depth 1 Phase Description of Operations (hr) I (ft) X 17:00 - 21:00 4.00 RUNCOM ' N I DEAL I 1,636.00 RUNCMP I PJSM FOR POH WITH ESP. '- POH INSPECTING ESP CABLE FOR DAMAGE. - SPOOLING ESP CABLE AND CAP TUBE. - STAND 2 7/8" TUBING IN DERRICK. - CONTINUOUS HOLE FILL WITH 11 PPG BRINE. 0.25 RUNCOM - POH 1 JT BELOW BOP. 1,636.00 21:00 - 21:15 N DFAL !RUNCMP FLOW CHECK WELL FOR 15 MIN BEFORE PULLING PUMP. HOLE CONTINUES TAKING 6 BPH. N DFAL 1,636.00 RUNCMP 21:15 - 21:30 0.25 RUNCOM PULL ESP PUMP TO SIIRFACF INSPFCTINn CABLE. - NO VISIBLE DAMAGE NOTED ON ESP CABLE. - CENTRALIFT REP TROUBLE SHOOT CONTINUITY FAILURE. - CANNOT DETERMINE SOURCE. � - CENTRALIFT PROCEDURE TO C/O MOTOR LEAD, MOTOR AND SENSOR. NOTIFY ODE. 1,636.00 RUNCMP 21:30 - 00:00 2.50 RUNCOM ! N DFAL PJSM, DISCONNECT ESP CABLE. - DISCONNECT CAP TUBE AND TIE BOTH BACK. DISCONNECT SENSOR WIRE. UD PUMP ASSEMBLY INTO BOXES IN PIPE SHED. s 1- CONTINUOUS HOLE FILL WITH 11 PPG �/ I BRINE. - O /A= 230 PSI. - HOLE CONTINUES TAKING 6 -7 BPH 1 - LAST 12 HRS HOLE TOOK 78 BBLS. - HOLE TOOK 150 BBLS IN THE LAST 24 HRS. 6/5/2012 00:00 - 05:30 1 , 5.50 RUNCOM N DFAL 1,636.00 RUNCMP PJSM, LOAD OUT ESP PUMP. - CENTRALIFT TAKE TO SHOP TO REPLACE 1 PUMP MOTOR AND SENSOR ASSEMBLY. - PERFORM DDI WORK ORDERS, CLEAN RIG ' I 'WHILE W/O PUMP REPAIR. I - MONITOR WELL, KEEP HOLE FULL WITH 11 PPG BRINE. 105:30 - 08:30 3.00 RUNCOM N DFAL 1,636.00 RUNCMP PJSM, PER CENTRALIFT - SPLICE MLE TO POWER CABLE ON ESP. 1 - PERFORM CONDUCTIVITY TEST. CONTINUE TO KEEP HOLE FULL WITH 11 PPG BRINE. 108:30 - 10:30 2.00 RUNCOM N DFAL 1,636.00 RUNCMP 1 PJSM FOR P/U ESP MOTOR ASSEMBLY. REVIEW SOP. REVIEW PLAN FOR NON SHEARABLES ACCROSS BOP. - P/U ESP MOTOR ASSEMBLY AS PER ICENTRALIFT REP. - ATTEMPT TO FILL WITH MINERAL OIL. I - CLOGGED IN SEAL SECTION. Printed 6/25/2012 11:27:14AM • North America - ALASKA - BP 0 Page 19 of 22 Operation Summary Report Common Well Name: MPF -94 - - AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 I End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) I Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. I UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table ©44.30ft (above Mean Sea Level) Date I From - To Hrs Task I Code NPT I NPT Depth I Phase Description of Operations (hr) (ft) 10:30 - 11:30 1.00 RUNCOM N DFAL 1,636.00 RUNCMP 'PJSM, INSTALL ALL PLUGS IN ESP MOTOR. - BREAK OUT TOP X/O ON MOTOR ASSEMBLY. - LID AND LOAD OUT FAILED SEAL SECTION. '- CONTINUE TO MONITOR WELL AND KEEP FULL WITH 11 PPG BRINE. 11:30 - 12:00 1 0.50 RUNCOM N DFAL 1,636.00 RUNCMP I WAIT ON NEW SEAL SECTION TO ARRIVE ' FROM CENTRALIFT. I- O /A= 230 PSI ' '- LOSSES TO WELL CONTINUE AT 4 -5 BPH. - LOSSES TO WELL IN LAST 12 HRS= 56 BBLS. 1 12:00 - 12:30 I 0.50 RUNCOM N DFAL 1,636.00 RUNCMP CREW CHANGE. PJSM FOR P/U AND RUNNING ESP COMPLETION. REVIEW DDI SOP FOR RUNNING ESP. REVIEW PLAN FOR NON SHEARABLES ACROSS BOP. + - SERVICE RIG AND INSPECT EQUIPMENT. 12:30 - 16:00 3.50 ' RUNCOM N DFAL 1,636.00 ! RUNCMP 1 Pit 1 FSP PU MP AND NEW SEAL ASSEMBLY. - INSTALL CONTROL LINE PROTECTORS AND F /G. - TEST ESP AND CONTROL LINE. - RUN 6 PROTECTORS, 3 F/G AND 2 HALF CANNON CLAMPS ON PUMP AND MOTOR. 16:00 - 17:30 1 1.50 RUNCOM N DFAL 1,636.00 RUNCMP RIH WITH ESP COMPLETION AS PER WELL PLAN AND TALLEY. - RUN TBG STANDS FROM DERRICK. 1- 2 7/8" 6.5#, EUE 8RD TBG. - RIH 2.5 - 3 MINUTES PER STAND. '- INSTALL CANNON CLAMP ON EVERY COLLAR. - MONITOR UNSPOOLING ESP CABLE AND I CHEMICAL INJECTION LINE. - USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE OR CAP TUBE. - CONTINUOUS HOLE FILL. - 4 -5 BPH LOSS RATE. '- KWF 11.0 PPG BRINE. I I - RIH TO 1636' MD. I - OFF NPT. BACK ON PLANNED OPERATIONS. Printed 6/25/2012 11:27:14AM • North America - ALASKA - BP Page 20 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) I Start Date: 5/30/2012 End Date: 6/7/2012 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date ' From - To Hrs Task Code I NPT NPT Depth Phase I Description of Operations (hr) (ft) 17:30 - 00:00 I 6.50 7 RUNCOM P RUNCMP RUN TBG STANDS FROM DERRICK. - 2 7/8" 6.5#, EUE 8RD TBG. I - RIH 2.5 - 3 MINUTES PER STAND. 1 - INSTALL CANNON CLAMP ON EVERY COLLAR. - MONITOR UNSPOOLING ESP CABLE AND CHEMICAL INJECTION LINE. - USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE OR CAP TUBE. - CONTINUOUS HOLE FILL. I r- 4 -5 BPH LOSS RATE. - KWF 11.0 PPG BRINE. - RIH TO 4950' - TEST CONDUCTIVITY ON ESP ELECTRIC CABLE EVERY 1000'. - LAST 12 HRS HOLE TOOK 57 BBLS. r- HOLE TOOK 113 BBLS IN THE LAST 24 HRS. - O /A= 230 PSI. 6/6/2012 00:00 - 04:00 4.00 RUNCOM P RUNCMP RIH WITH ESP COMPLETION PER WELL PLAN AND TALLEY FROM 4950' - RUN TBG STANDS FROM DERRICK. - 2 7/8" 6.5#, EUE 8RD TBG. - RIH 2.5 - 3 MINUTES PER STAND. I- INSTALL CANNON CLAMP ON EVERY ' COLLAR. - MONITOR UNSPOOLING ESP CABLE AND CHEMICAL INJECTION LINE. - USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE OR CAP TUBE. - CONTINUOUS HOLE FILL. - 4 -5 BPH LOSS RATE. 1 - KWF 11.0 PPG BRINE. - TEST CONDUCTIVITY ON ESP ELECTRIC CABLE EVERY 1000'. I - RIH TO 7506' 1 - P/U WT= 62K. S/O WT= 57K, THIS INCLUDES 07:30 3.50 RUNCOM P RUNCMP ' INSTALL DRIVE WT. 04:00 - INSTALL FOSV. - SPLICE ESP CABLE AT 7506' AS PER CENTRALIFT REP. - TEST SPLICE, OK. - MONITOR WELL, KEEPING HOLE FULL WITH 11 PPG BRINE. 07:30 - 12:00 4.50 RUNCOM P - RUNCMP CONTINUE TO RIH W/ 2 7/8" ESP COMPLETION STRING. ' I I- RIH TO 10,320'. 85K UP WT, 65K DOWN WT. THIS INCLUDES WT OF TOP DRIVE .... (40K). I LOSSES TO WELL LAST (12) HRS = 61 BBLS. 12:00 12:30 ' 0.50 r RUNCOM P RUNCMP SERVICE RIG, INSPECT EQUIPMENT. 12:30 - 18:00 5.50 RUNCOM P RUNCMP 1 PJSM. CONTINUE TO RIH W/ 2 7/8" ESP COMPLETION. '- INSTALL CONTROL LINE CLAMP ON EVERY COLLAR. - TEST CONTROL LINE EVERY 1000'. - 145 STANDS IN, © 13,770'. Printed 6/25/2012 11:27:14AM North America - ALASKA - BP 410 Page 21 of 22 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 5/30/2012 End Date: 6/7/2012 f X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations 18 :00 - 20:30 ! 2.50 RUNCOM P RUNCMP CONTINUE RIH WITH 2 7/8" ESP COMPLETION I FROM 13,770' RIH 2.5 - 3 MINUTES PER STAND. INSTALL CANNON CLAMP ON EVERY COLLAR. - MONITOR UNSPOOLING ESP CABLE AND CHEMICAL INJECTION LINE. I- USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE OR CAP TUBE. - CONTINUOUS HOLE FILL WITH 11 PPG BRINE. - TEST CONDUCTIVITY ON ESP ELECTRIC CABLE EVERY 1000'. - RIH TO 15,651' AT 165 STANDS IN. 20:30 00:00 3.50 RUNCOM P 1 RUNCMP INSTALL FOSV. - SPLICE ESP CABLE AT 15,651" AS PER CENTRALIFT REP. - R/U CIRC HOSE. PUMP 5 BBLS DOWN TBG AT .5 BPM 540 PSI WITH RETURNS TO ENSURE CLEAR. WELL CONTINUES TAKING 4 -5 BPH. LOSSES TO THE WELL IN LAST 12 HRS= 54 BBLS. - LOSSES TO THE WELL IN LAST 24 HRS= 115 BBLS. --- -- - -- - -- - O /A= 200 PSI 6/7/2012 00:00 01:30 1.50 RUNCOM P RUNCMP SPLICE ESP CABLE AT 15,651" AS PER CENTRALIFT REP. - TEST SPLICE, OK. - MONITOR WELL, KEEPING HOLE FULL WITH / 11 PPG BRINE. V 01:30 - 05:00 3.50 1 RUNCOM P RUNCMP CONTINUE RIH WITH 2 7/8" ESP COMPLETION FROM 15,651" RIH 2.5 - 3 MINUTES PER STAND. ,- INSTALL CANNON CLAMP ON EVERY I COLLAR. 1- MONITOR UNSPOOLING ESP CABLE AND CHEMICAL INJECTION LINE. - USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE OR CAP TUBE. - CONTINUOUS HOLE FILL WITH 11 PPG BRINE. - TEST CONDUCTIVITY ON ESP ELECTRIC CABLE EVERY 1000'. - RIH TO 15,778', ADD 4.10' 2 7/8" 6.5# PUP TO OFFSET ESP SPLICE FROM TBG COLLAR. - RIH TO 18,054' 05:00 - 06:00 Il i 1.00 RUNCOM P RUNCMP M/U 10' 2 7/8" PUP JT. I- 117K P/U WT. 75K S/O WT. THIS INCLUDES 40K TOP DRVE WT. - M/U FOSV AND CIRC HOSE. - CIRCULATE 5 BBLS, 1 BPM 1900 PSI. 577 TOTAL CLAMPS RUN. 06:00 - 09:30 3.50 RUNCOM P RUNCMP 1 PJSM. PICK UP AND MAKE UP HANGER & LANDING JT. - TERMINATE CHEMICAL INJECTION LINE & ESP LINE. - INSTALL 25 PSI CHECK VALVE IN CHEM INJ LINE UNDER HANGER. Printed 6/25/2012 11:27:14AM North America - ALASKA - BP Page 22 of 22 Operation Summary Report Common Well Name: MPF -94 1 AFE No — Event Type: WORKOVER (WO) I Start Date: 5/30/2012 End Date: 6/7/2012 1 X4- 00W9Y -E: (1,480,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. ! UWI: 500292304000 Active Datum: Kelly Bushing / Rotary Table @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:00 0.50 RUNCOM P RUNCMP PJSM LAND HANGER, RILDS, TOTAL DEPTH = 18,092'. BACK OUT & LAY DOWN LANDING JT. 10:00 - 11:00 1.00 RUNCOM P RUNCMP 1 PJSM. DRY ROD IN TWO WAY CHECK VALVE. - PERFORM ROLLING TEST FROM BELOW TWC. - 500 PSI / 10 MIN, PUMPING 2 BPM, INJECTED 24 BBLS, GOOD TEST. - TEST FROM ABOVE 250 / 3500 PSI, 5 MIN EACH / CHARTED TESTS. 11:00 - 12:00 1.00 BOPSUR P RUNCMP PJSM. N/D 135/8" X 5M BOPE. - LOSSES TO WELL LAST (12) HRS = 90 BBLS. - O/A PRESSURE = 200 PSI. 12:00 - 17:30 5.50 WHSUR P RUNCMP PJSM. N/U ADAPTER FLANGE, TBG HEAD & TREE. - PRESSURE TEST VOID & TREE 250 / 5000 PSI 5 MIN EACH. - CHART TEST. - BP WTL & SUPERINTENDANT, MILNE PT FIELD MANAGER, DOYON SUPERINTENDANT I MET WITH HANDS DURING THIS OPERATION, (1) HR. 17:30 20:00 2.50 WHSUR P RUNCMP PJSM WITH VALVE CREW. REVIEW SOP FOR PULLING TWC. - R/U AND TEST LUBRICATOR TO 250/3500 PSI 5 MIN EACH. I - CHART RECORD TEST. - PULL TWC. I 1 - 24 HR NOTICE GIVEN TO AOGCC AT 18:05 HRS. FOR INITIAL BOP TEST ON MPF -18. - LOU GRIMALDI WITH AOGCC WOULD LIKE — — AN UPDATE AT 06:00 20:00 - 22:00 2.00 RUNCOM P RUNCMP R/U TO SET BPV. - M/U AND TEST LUBRICATOR TO 250/3500 PSI 5 MIN EACH. - CHART RECORD TEST. I- INSTALL BPV. R/U AND PERFORM 500 PSI ROLLING TEST FROM BELOW FOR 10 MIN. 1- PUMP 3 BPM SLOWING TO 2 BPM AT 550 1 PSI. -CHART RECORD TEST. INSTALL TREE CAP. 1- SUCK OUT AND CLEAN PITS. 22:00 - 00:00 2.00 WHSUB P ' RUNCMP BLOW DOWN AND R/D LINES TO TREE. - INSTALL FLANGES ON 0/A AND VA. - CLOSE ALL TREE VALVES. - SUCK OUT AND CLEAN PITS. - RIG RELEASED FROM MPF -94 AT 2400 HRS. Printed 6/25/2012 11:27:14AM Tree: 2 9/16" - 5M CIW III M P F - 9 4 O B Elev. = 44' (N -27E) Wellhead: 11" Gen 5 FMC O L Elev. = 11' 11 x 2 9/16" Hgr, w/ 2 7/8" NSCT T &B, i s RT to Tbg. Spool = 33.0' (N -27E) & 2.5" Type 'H' BPV Profile 112' Camco 2 -7/8" x 1" 142' KBMM GLM 10 3/4" Halliburton ES Cementer 2493' 0 KOP @ 500' to 3100' 1 i Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' 11 18,200' SS Cap Tub with 2500# Check 10 3/4 ", 45 # /ft., L -80 BTC 10,341' 1 1 Camco 2 -7/8" xi" 117,825' KBMM GLM 2 -7/8" HES XN nipple 17,977' 11 1 (ID 2.250 ") IN Well Lift Discharge Gauge Unit 1 18,020` ,IE 21 2 7/8" 6.5 ppf, L-80 8 rd. EUE tubing 1 ® LI GPDIS Discharge Head 18,023' (drift ID = 2.347 ", cap = 0.00592 bpf) , Centrilift ESP, SXD 137 - P17 / 118,024' 7" 26 # /ft., L -80 BTC -MOD Production SXD 18 - P75 Casing, (Drift ID = 6.151 ", cap. = 0.0383 bpf) II OIL (cap w/ 2 7/8" tbg = .0302 bpf) Gas Separator 18,050' Capillary tube 3/8" OD x .049 wall I GRSFTX AR H6 Tandem (capacity = 3.131 gallons / 1000') i, I— Tandem Seal Section 1 18,055` GSB3DBUT SB /SB PFSA/ GSB3DBLT SB /SB PFSA `' Motor KMHG / 228 HP, EZRA MA 2305 volt, 60 amp, 18,089' WI Ini Well Lift MGU Sensor 118,091` w/ 6 Fin Centralizer 118 091 ` Stimulation Summary I 12/11/01 Frac - 117,298# of 16/20 C /lite PumpMate TVD = 7344' 73,740# of 12/18 C /lite behind pipe. Perforation Summary Ref. I og SWS anadrill CDR resistivity. 1 18,155' dated 10/17/01. 7" x 4.5" Baker Premier pkr. Size SPF Interval (TVD) 2.5" 4 18290'- 18292' 7551.-7552' mws 2.5" 4 18328'- 18330' 7594' -7595' _ 3 -3/8" 12 18300'- 18310' 7567' -7576' 4.5" HES XN- Nipple (3.813 ") 18,181' 3 -3/8" 12 18325'- 18335' 7591' -7600' (No -go 3.75" id) 4 1/2" WLEG 18,193' (PBTD) 1 18,466' 7" Float Collar 18,469' 7" Float Shoe I 18,554' 1 DATE REV. BY COMMENTS MILNE POINT UNIT 02/26/05 Lee Hulme ESP Re- Completion 4 -ES 02/08/06 Lee Hulme ESP Re-Completion 3S WELL MPF -94 (KUP) 12/9/07 Lee Hulme ESP Re- Completion 4ES 4 -25 -08 REH ESP Re- Completion Nabors 3S API No. 50-029 -23040 4/16/09 Lee Hulme ESP Re- Completion Nabors 3S 2/6/10 Lee Hulme ESP Re Completion Nabors 4ES 04/20/2011 Brian Bixby ESP Re- Completion Doyon 16 BP EXPLORATION (AK) 06/10/12 Brian Bixby ESP Re- Completion Doyon 16 • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 tANN ) FEB 2 1 ZOIZ Mr. Tom Maunder d — 1 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue f 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 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 ibis ft gal MPF -01 1950450 50029225520000 102 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 8/12011 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 8/12011 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 0.8 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 7/312011 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 8/42011 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 12 N/A 1.2 N/A 13.6 8/32011 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 WA 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 9/12011 - 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 ALASKAID AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 1151 Other ❑ HCL 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 El Exploratory ❑ : 201 -1700 3. Address: P.0, Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23040 -00 -00 8. Property Designation (Lease Number) : . 9. Well Name and Number: ADLO- 355016 — MPF -94 10. Field /Pool(s): MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 18595 feet Plugs (measured) None feet true vertical 7853 feet Junk (measured) None feet Effective Depth measured 18469 feet Packer (measured) 18155 feet true vertical 7730 feet (true vertical) 7427 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" Surface - 112 Surface - 112 Surface 10307' 10- 3/4 "45# L -80 34 - 10341 34 - 4454 5210 2480 Production 18523' 7" 26# L -80 32 - 18555 32 - 7814 7240 5410 .4t 'A AUG 1 6 201 Perforation depth: Measured depth: SEE ATTACHED - - True Vertical depth: _ _ - Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 33 - 18079 33 - 7354 4-1/2" 12.6# L -80 18146 - 18193 7418 - 7463 Packers and SSSV (type, measured and true vertical depth) 4.5" Baker Premier Packer 18155 7427 C t 1D 12. Stimulation or cement squeeze summary: ° j t l (1 Intervals treated (measured): r' rittA IC, tyti. f ltlfT1ISSiOf Treatment descriptions including volumes used and final pressure: kgas*� 9 ~ ,,N g rr s 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 391 176 1150 278 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development IS Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil J 0 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: NA Contact Elizabeth Barker Printed Name Elizabeth Barker Title Data Manager Signature j � i L, Phone (907) 564 -5674 Date 7/12/2011 S' 7// Form 10 -404 Revised 10/2010 RBDMS JUL 13 2011 J2 fl "l Submit Original Only "4 MPF -94 201 -170 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF -94 11/25/01 PER 18,290. 18,292. 7,556.74 7,558.67 MPF -94 12/1/01 APF 18,328. 18,330. 7,593.38 7,595.31 MPF -94 12/9/01 APF 18,325. 18,328. 7,590.48 7,593.38 MPF -94 12/9/01 APF 18,330. 18,335. 7,595.31 7,600.13 MPF -94 12/9/01 RPF 18,328. 18,330. 7,593.38 7,595.31 MPF -94 12/10/01 APF 18,300. 18,310. 7,566.38 7,576.02 MPF -94 1/27/02 FIL 18,331. 18,335. 7,596.27 7,600.13 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE I I • • • MPF -94 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY cI :: ,,, 6/26/2011 !T /I /0= 800/740/40 temp =si Acid treatment. Pumped 10 bbis crude to establish injection rate of 0.5 BPM @ 2900 psi. Pumped 20 bbls acid. Flushed lines with 2 !bbls 60/40 meth, displaced Tubing with 77 bbls crude flush. Tbg pressure fell 300 ;psi. pumped 1 additional bbl crude down Tbg. Flushed tank returns lines w/ 2 bbls ;crude. FWHP= 600/940/40 SV,WV,SSV shut. MV,IA,OA Open FLUIDS PUMPED BBLS 4 60/40 METH 22 ACID 90 CRUDE 116 TOTAL M Tree: 2 9/16" 5M CIW M p F _94 Orig. K. = 44' (N -27E) Wellhead: 11" Gen 5 FMC Orig. GL ev. = 11' 11 x 2 9/16" Hgr, w/ 2 7/8" NSCT T &B, RT to Tbg. Spool = 33.0' (N -27E) & 2.5" Type 'H' BPV Profile 1 ?P� 112' Camco 2 -7/8" x 1" I 141' ii )' KBMM GLM 10 3/4" Halliburton ES Cementer 1 2493' 0 KOP @ 500' to 3100' Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' t 18,079' SS Cap Tub with 2500# Check 10 3/4 ", 45#/ft., L -80 BTC ( 10,341' 4 11 Camco 2 -7/8" x 1" KBMM GLM 117,821' I 2 -7/8" HES XN nipple 17,973 (ID 2.250 ") ( 1 2 7/8" 6.5 ppf, L -80 8 rd. EUE tubing !1 GPDIS Discharge Head 118,019'1 (drift ID = 2.347 ", cap = 0.00592 bpf) ■ Centrilift ESP, SXD 137 - P17 118,020'1 7" 26#/ft., L -80 BTC -MOD Production Casing, (Drift ID = 6.151 ", cap. = 0.0383 bpf) (cap w/ 2 7/8" tbg = .0302 bpf) 1 z Gas Separator 118 040 = GRSFTX AR H6 (400 Internals) + Capillary tube 3/8" OD x .049 wall N (capacity = 3.131 gallons / 1000') vr Tandem Seal Section I GSB3DBUT / GSB3DBLT 118,052'1 r Et a_ Motor KMH / 190 HP, " 2415 volt, 48 amp, 118,058` Ja i PumpMate XTO w/ 6 Fin Centralizer 118 077 I Stimulation Summary 12/11/01 Frac - 117,298# of 16/20 C /lite PumpMate TVD = 7344' 73,740# of 12/18 C /lite behind pipe. Perforation Summary Ref. Log SWS anadrill CDR resistivity. ( 18,155' dated 10/17/01. 7" x 4.5" Baker Premier pkr. Size SPF Interval (TVD) 2.5" 4 18290'-18292' 7551' -7552' "U 2.5" 4 18328' - 18330' 7594` -7595' 181' 3 -3/8" 12 18300'- 18310' 7567-7576' -e 4.5" HES XN- Nipple (3.813 ") 1 18,181' I 3 -3/8" 12 18326- 18335' 7591' -7600' (No -go 3.75" id) 4 1/2" WLEG 1 18,193' I (PBTD) 1 18,466' I 7" Float Collar 1 18,469' I 7" Float Shoe 1 18,554' DATE REV. BY COMMENTS M I LN E POINT UNIT 02/26/05 Lee Hulme ESP Re- Completion 4 -ES 02/08/06 Lee Hulme ESP Re- Completion 3S WELL MPF -94 (KUP) 12/9/07 Lee Hulme ESP Re- Completion 4ES 4 -25 -08 REH ESP Re- Completion Nabors 3S API No. 50-Q29-?3040 4/16/09 Lee Hulme ESP Re- Completion Nabors 3S 0 7 2/6/10 Lee Hulme ESP Re- Completion Nabors 4ES 04/20/2011 Brian Bixby ESP Re- Completion Doyon 16 BP EXPLORATION (AK) STATE OF ALASKA . ALASKA" AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERA NS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ■1 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: l BP Exploration (Alaska) Inc. .' Development ❑ Exploratory ` 201 - 170 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 . 50 - 029 - 23040 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 355016 .'' ,. MPF -94 9. Field / Pool(s): _ Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 18595' feet Plugs (measured) None feet true vertical 7853' feet Junk (measured) None Effective depth: measured 18469' feet Packer: (measured) 18155' feet true vertical 7730' feet Packer: (true vertical) 7427' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 10307' 10 -3/4" 10341' 4454' 5210 2480 Intermediate Production 18523' 7 -5/8" 18555' 7814' 6890 4790 Liner MAY ti 3 NY! Perforation Depth: Measured Depth: 18290' - 18335' True Vertical Depth: 7557' - 7600' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 18079' 7354' 4 ", 12.6# L - 80 18146' - 18193' 7418' - 7463' Packers and SSSV (type, measured and true vertical depth): 7" x 4 - 1/2" Baker Premier Packer 18155' 7427' 11. Stimulation or cement squeeze summary: Intervals treated (measured): RECEIVED Treatment description including volumes used and final pressure: PP 9 ?(ir Alaska Oil & Gas Coos. Cnrftission 12. Representative Daily Average Production ot~Iijgl etg@ata Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 308 47 856 Not Available Not Available Subsequent to operation: 287 49 966 130 301 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 t IN Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564 -5743 N/A Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: Signature Phone 564 -4628 Date /�, Prepared Hu•ble, 564 -4628 Form 10-404 Revised 10/2010 $'•Z* •f/ RBDMS APR 2 9 2011 `f 7 'mit original Only . • • North America - ALASKA - BP Page 1 0 Operation Summary Report w „ Common Well Name: MPF -94 j AFE No Event Type: WORKOVER (WO) I Start Date: 3/29/2011 End Date: 4/13/2011 X4- 00T4J -E (750,000.00 ) Project: Milne Point I Site: M Pt F Pad —1 , Rig Name /No.: DOYON 16 1 / Spud Date/Time: 10/15/2001 12:00:OOAM , Rig Release: 4/13/2011 Rig Contractor: DOYON DRILLING INC. _ _ _ 1 UWL 500292304000 Active Datum: MPF -94 @44.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase ' Description of Operations (hr) ' (ft) I 4/7/2011 12:00 - 00:00 I 12.00 MOB P PRE MOB RIG OFF OF MPF -96. I 1 I -BACK RIG ONTO PAD AND FACE CELLAR 1 I OUT OF WIND. WSL & TOOLPUSHER PRESENT. - RECONFIGURE BOPE STACK WITH DOUBLE [GATES. : -STACK HAS 2 -7/8" SOLID BODY IN THE - I LOWER, BLIND SHEAR, AND 2 -7/8" X 5" VBRS, AND ANNULAR PREVENTER. , -MOB RIG OVER MPF -94 WELL. WSL & TOURPUSHER PRESENT. 4/8/2011 100:00 - 03:00 3.00 MOB P I PRE , FINISH MOB.. RIG OVER MPF -94. -SHIM RIG LEVEL ON DOUBLE RIG MATS. L -SPOT TANKS AND MODS. I ' I -RIG UP HARD LINE TO KILL TANK. 03:00 - 05:30 2.50 CLEAN P DECOMP 'ACCEPT RIG AT 0300 HOURS. II -R/U HARD LINE TO FLOW BACK TANK. 1-R/U LINES ON -CHANGE TREE EE TO CHOKE. CAP FITTING TO ALLOW MAKE UP OF LUBRICATOR. I I ' -R/U LUBRICATOR AND TEST TO 250 PSI LOW I , lAND4000 PSI HIGH. -PULL BPV, 1000 PSI ON TUBING AND 800 PSI ON IA -LAY DOWN LUBRICATOR 05:30 06:00 0.50 CLEAN P 1 DECOMP RIG EVAC DRILL -AAR RESULTS 1. ALL PEOPLE ON LOCATION ACCOUNTED j FOR (INCLUDING TRUCK DRIVERS AND DSM CREW) 2. PAD OPERATOR NOTIFIED 13. ALL TRUCK DRIVERS ARE ON RIG HUB WHEN THEY COME ON LOCATION SO THEY HEAR WHEN DRILL OR EMERGENCY IS I I ANNOUNCED 14. REVIEWED RIG ALARM WARNINGS _ (AUDIBLE AND VISIBLE) 106:00 - 12:30 6.50 KILLW P DECOMP PRESSURE TEST SURFACE LINES TO 4000 PSI UP AND DOWN STREAM OF CHOKE I -PJSM FOR WELL KILL WITH PROCEDURE REVIEW. - NOTIFY MPU AND PAD OPERATOR OF GAS VENTING -REVIEWED TANK USAGE PROCEDURE AND VERIFIED HATCH POSITION WITH WELL I SUPPORT (OPEN ON NEW TANK STYLE) I -BLEED OFF IA THROUGH MANUEL CHOKE FROM 830 PSI TO 400 PSI TAKING SAMPLES EVERY 5 -10 MINUTES -MONITOR PRESSURES - -SITP =260 PSI, SICP = 330 PSI - RECONFIGURE RETURNS TO GO THROUGH SUPERCHOKE -PUMP 106 BBLS OF 10.3# 120 DEG KWF DOWN TUBING AT 2 BBLS/MIN AND 900 PSI TUBING PRESSURE -SHUT DOWN PUMP, RECORD WELL HEAD PRESSURES SITP =0 PSI, SICP =660 PSI Printed 4/25/2011 11:06:24AM rah America ALA SKA BP Page afi Operation Summa Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) I Start Date: 3/29/2011 I End Date: 4/13/2011 X4- 00T4J -E (750,000.00 ) Project: Milne Point Site: M Pt F Pad I Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:OOAM I Rig Release: 4/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: MPF -94 @44.30ft (above Mean Sea Level) Date From - To Hrs I Task ! Code I NPT NPT Depth Phase Description of Operations ■ I i (hr) 1 (ft) L -- 12:30 - 18:00 5.50 KILLW P DECOMP SI RETURNS AND BULLHEAD 100 BBLS OF 10.3 # KWF AT 4 BPM AT 2850 PSI -IN 10 MIN TUBING PRESSURE DROPPED I FROM 540 PSI TO 0 PSI, SICP DROPPED FRM 1400 PSI TO 770 PSI. -VAC OUT FLOW -BACK TANK, 225 BBLS I RECOVERED -OPEN UP RETURNS TO TANK AND CIRCULATE 620 BBLS DOWN TUBING AT 3 BPM AT 1000 PSI -SHUT DOWN PUMP AND MONITOR SI WELLHEAD. PRESSURES FOR 20 MIN SITP = 0 I PSI, SICP =0 PSI , - RETURN FLUID WEIGHT = 10.3# -TUBING N G AND IA ON SLIGHT VACUUM U N - NOTIFY MPU OF GAS VENTING OPERATIONS COMPLETE. TOTAL. FLUID CIRCULATED = 727 BBLS I I TOTAL FLUID INJECTED (BULLHEAD) = 100 BBLS I -- `TOTAL FLUID LOST TO FORMATION= 130 � 'BBLS f 18:00 - 19:30 1.50 KILLW P DECOMP BLOW DOWN LINES AND SECURE ALL ' VALVES. -FILL WELL TAKING 27 BBLS TO GET IRETURNS. -CALCULATE FLUID LOSS AT 24 BPH. -R/U LINES TO KEEP HOLE FULL DURING WD. ! -R/U LINES TO PURGE CHEMICAL INJECTION LINE. 119:30 - 20 :30 1.00 KILLW P DECOMP I EATTEMPT TO PUMP DOWN CHEMICAL INJECTION LINE. - PRESSURE UP LINE SLOWLY TO 3000 PSI. PRESSURE HOLDING SOLID. 1 -REVIEW MSDS ON NALCO EC6085A SCALE INHIBITOR FOR PULLING LINE. -R/D LINES TO CHEMICAL INJECTION LINE. 20:30 22:00 1.50 I WHSUR P DECOMP I R/U LUBRICATOR ON TREE. -TEST LUBRICATOR TO 250 PSI LOW AND 4000 PSI HIGH. GOOD TEST. -INSTALL TWC. -TEST TWC FROM ABOVE TO 4000 PSI, AND 'ROLLING TEST FROM BELOW TO 500 PSI. G000 TEST AT 2 BPM AND 610 PSI TAKING 32 BBLS OF FLUID FOR THE 10 MIN TEST. 22 :00 - 00:00 2.00 WHSUR P DECOMP BLOW DOWN KILL LINE. -N /D TREE AND ADAPTER FLANGE. TREE BROKE FREE WITH 2K. -CLEAN TUBING SPOOL. - MAINTAIN CONTINUOUS HOLE FILL AT 8 BPH I LOSS RATE. r 4/9/2011 00 :00 02 :00 2.00 BOPSUR P DECOMP FMC PREP WELL HEAD CONTROL LINES. - CORROSION LINE THREADS WORN - RETHREAD IN HANGER AND INSTALLED 'LONGER PLUG. -FMC CLINT WILL EVALUATE HANGER BETTER ONCE IT IS PULLED TO THE FLOOR. -TEST FIT HANGER THREADS WITH 8 -1/2 TURNS. 8 RD EUE. 1 - MAINTAIN CONTINUOUS HOLE FILL AT 9 BPH LOSS RATE. Printed 4/25/2011 11:06:24AM r thAttertca- ALASKA B ; r Pa t"peraton Summary Common Well Name: MPF -94 I AFE No Event Type: WORKOVER (WO) I Start Date: 3/29/2011 ' End Date: 4/13/2011 X4- 00T4J -E (750,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 10/15/2001 12:00:OOAM I Rig Release: 4/13/2011 Rig Contractor: DOYON DRILLING INC. I UWL 500292304000 Active Datum: MPF -94 @44.30ft (above Mean Sea Level) Date From - To Hrs Task , Code ' NPT NPT Depth ' Phase Description of Operations — _ (hr) (ft)_ I — — 02:00 - 05:00 3.00 BOPSUR P DECOMP I N/U BOPE. I - CONFIGURED WITH ANNULAR, 2 -7/8" X 5" VBR, BLIND SHEAR, MUD X, 2 -7/8" SOLID BODY. DECOMP `T W.4000 PSI HIGH , 05:00 ST BOPF 250 PSI LO 10.00 5.00 BOPSUR � P F PRESSURE. _ -ALL TESTS FOR 5 CHARTED MINUTES. , -TEST W/ 2 -7/8 "TEST JOINT. -TEST ANNULAR WITH 2 -7/8" TEST JOINT TO 250 PSI LOW AND 3500 PSI HIGH. -ALL TEST PASSED EXCEPT 2 -7/8" DART ' VALVE, REPLACEMENT WILL BE TESTED b,nQ V�� UPON ARRIVAL. TESTWAIVED BY: CHUCK SHEVE- AOGCC. 1. -PERFORM ACCUMULATOR DRAW DOWN TEST: PRESSURE @ 2850 PSI DOWN TO 1700 1 PSI. 200 PSI INCREASE IN 20 SECONDS, FULL INCREASE IN BS SECONDS. 5 BOTTLES AT 1950 PSI. -TEST WITNESSED BY BP WSL, DDI TOOL PUSHER. 110:00 - 11:00 I 1.00 BOPSUR P DECOMP I RIG TEST EQUIPMENT -BLOW DOWN CHOKE AND KILL LINES -RIG UP ESP CABLE SHEAVE -BRING SCHLUMBERGER SPOOLING UNIT TO RIG FLOOR AND STAGE TO PULL ' COMPLETION. 11 :00 - 14:00 3.00 WHSUR P DECOMP I RIG UP OPSO- LOPSO, PUMP -IN SUB AND i , LUBRICATOR -TEST TO 300 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES I I -PULL TWC 1-TUBING AND IA ON SLIGHT VAC. -LAY DOWN LUBRICATOR, PUMP IN SUB AND OPSO -LOPSO 1 -TEST 2 -7/8" DART VALVE 250 PSI LOW AND I � 1 , 14000 PSI HIGH FOR 5 CHARTED MINUTES. GOOD TEST. -REVIEW MSDS ON NALCO EC6085A. 1 14:00 - 14:30 0.50 PULL P I DECOMP I PJSM: WELL CONTROL I I- SCHLUMBERGER SPOOLERS, CENTRILIFT, I MUD ENGINEER, AND RIG CREW - DISCUSSED BOP CLOSING PROCEDURE FOR WELL CONTROL WITH CABLE AND CHEMICAL LINE IN THE HOLE - DROPPED OBJECT PREVENTION PRIOR TO RIG UP TO PULL COMPLETION 14 :30 - 17:00 2.50 1 PULL P DECOMP PICK UP LANDING JOINT AND THREAD INTO ITUBING HANGER. 8-1/2 TURNS TO MAKE UP -BACK OUT LOCK DOWN SCREWS -PULL TUBING HANGER TO RIG FLOOR, HANGER OFF SEAT AT 100K, MAX PULL OF 155K, PUW OF 140K -CUT ESP CABLE AND CHEMICAL INJECTION LINE -LAY DOWN TUBING HANGER AND 10' PUP -RIG CIRCULATING HEAD. Printed 4/25/2011 11:06: 24AM rttt America _ ALASKA 7 BP Page 4 of T' Qperatior Sumitary Report C ommon Well Name: MPF -94 AFE Event Type: WORKOVER (WO) Start Date: 3/29/2011 i End Date: 4/13/2011 X4- 00T4J -E (750,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:OOAM Rig Release: 4/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: MPF -94 @44.30ft (above Mean Sea Level) Date From - To Hrs � Task Code NPT NPT Depth Phase ' Description of Operations I (hr) (ft) 17:00 - 20:00 3.00 PULL P DECOMP CIRCULATE BOTTOMS UP TO ENSURE KILL WEIGHT FLUID IN WELL AND SPOT SAFE -LUBE IN S -TURN SECTION OF WELL. -SLOW PUMP RATES: 30 SPM @ 690 PSI, 40 a SPM @ 1230 PSI 1 -28 BPH LOSSES DURING CIRCULATION AT 1 1900 PSI 20:00 - 20:30 0.50 PULL P DECOMP PJSM ON POH WITH ESP COMPLETION. 1 REVIEW PROCEDURES, DISCUSS WELL CONTROL, DROPPED OBJECTS WITH CREW, SCHLUMBERGER SPOOLER, CENTRILIFT l I HANDS. 20:30 - 21:00 0.50 PULL P DECOMP MONITORWELL.. ■ -'WELL ON A SLIGHT VAC OF 6 BPH. P DECOMP II POOH WITH ESP COMPLETION. 21:00 23:00 2.00 PULL -POOH WITH 2 -7/8" 6.5# L -80 8 RD EUE [TUBING. ` - : - RACKING BACK IN DERRICK FROM 18,000' TO 16,848'. '- PULLING ESP CONTROL LINE AND 1-PULLING LINE. I I CORROSION CONTINUOUS HOLE FILL AT 2 BPH t LOSS RATE. -SPR'S 30 SPM @ 690 PSI, 40 SPM © 1230 PSI. 23:00 - 00:00 1.00 PULL P DECOMP KICK WHILE TRIPPING DRILL WITH CREW. 1 -HOLD AAR AFTER DRILL. DRILL TOOK 5 MIN. 30 SEC. 4/10/2011 00:00 - 08:30 8.50 PULL P - j DECOMP POOH WITH ESP COMPLETION. I -POOH WITH 2 -7/8" 6.5# L -80 8 RD EUE TUBING. - RACKING BACK IN DERRICK FROM 16,848' TO —8500' MD'. I - PULLING ESP CONTROL LINE AND I CORROSION LINE. - MAINTAIN CONTINUOUS HOLE FILL AT 12 _ ; BPH LOSS RATE. 08:30 - 09:00 0.50 PULL P 1 DECOMP , CHANGE OUT CHEMICAL INJECTION LINE I 1 SPOOLING UNIT 09:00 - 10 :00 1.00 PULL P DECOMP CONTINUE TO POOH WITH ESP COMPLETION FROM 8500' TO 7600' MD -RACK 2 -7/8" TUBING OFF - DRILLER'S SIDE OF DERRICK 110 :00 - 11:00 1 1.00 PULL P DECOMP I SWAP ESP CABLE REELS IN SPOOLING UNIT. 11:00 - 12 :00 1 1.00 PULL P DECOMP CONTINUE TO POOH WITH ESP COMPLETION FROM 7600 - 5900' -RACK 2 -7/8" TUBING OFF - DRILLER'S SIDE OF DERRICK 12:00 - 12:30 . 0.50 PULL P DECOMP CREW CHANGE - PRE -TOUR CHECKS - MONITOR LOSSES FOR 30 MIN AT 10 BPH 12:30 - 14:30 ! 2.00 PULL P DECOMP CONTINUE TO POOH WITH ESP COMPLETION FROM 5900' -3800' -RACK 2 -7/8" TUBING OFF - DRILLER'S SIDE OF DERRICK 14:30 - 15:00 T 0.50 PULL P DECOMP 1 PJSM: RACK ON DRILLER'S SIDE OF DERRICK CLEAN FLOOR Printed 4/25/2011 11:06:24AM rth America.- ALASKA BPS ;, Page of 1 ' ., , , ' , , ' _ . - - - ' ., ',.—, 4 0 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) I Start Date: 3/29/2011 End Date: 4/13/2011 X4- 00T4J -E (750,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: 10/15/2001 12:00:OOAM I Rig Release: 4/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292304000 Active Datum: MPF -94 @44.30ft (above Mean Sea Level) Date 1 From - To Hrs Task Code I NPT NPT Depth Phase I Description of Operations ' (hr) (ft) I 15:00 - 20:00 5.00 PULL P DECOMP CONTINUE TO POOH WITH ESP COMPLETION FROM 3800'. -RACK 2 -7/8" TUBING DRILLER'S SIDE OF DERRICK _ _ [- CHANGE OUT JOINTS 499,526, 546 20:00 - 21:00 1.00 PULL 1 P DECOMP I TERMINATE ESP LINE. I I I - REMOVE SCHLUMBERGER SPOOLING UNIT FROM FLOOR AFTER NORM TEST. 1 21:00 - 21:30 0.50 PULL I P , DECOMP MONITOR WELL 10 BPH LOSS RATE. 1 _ -B/O 10' PUP FROM D ISCHARGE HEAD. 21:30 - 23:00 1.50 PULL P DECOMP UD ESP PUMP. -UD SEPARATOR, TANDEM SEAL SECTIONS, MOTOR. ' 1-576 CANNON CLAMPS RECOVERED. 23:00 - 00:00 1.00 PULL T P DECOMP I CLEAR AND CLEAN RIG FLOOR. -C /O POWER TONGS. ( R/D TRUNK AND RESTRING ROPE THROUGH SHEAVE: MAINTAN CONTINUOUS HOLE FILL OF 8 BPH � LOSS RATE. 4/11/2011 00:00 01:00 1.00 PULL - P DECOMP .FINISH CLEANING RIG FLOOR. 1 01:00 - 03:00 2.00 RUNCOM P r RUNCMP INSTALL NEW CABLE REEL FOR ESP COMPLETION. - I -R/U SPOOLING UNIT AND STRING CHEMICAL INJECTION LINE AND CABLE TO RIG FLOOR. i L ' - MAINTAIN CONTINUOUS HOLE FILL AT 8 BPH I LOSS RATE. 03:00 08:30 5.50 RUNCOM �' P RUNCMP P/U ESP MOTOR. - 1-M /U CABLE AND CHEMICAL INJECTION LINE -PU SEAL SECTIONS -PU GAS SEPARATOR, PUMP I,- CONNECT LINES TO DISCHARGE GUAGE UNIT I - COMPLETE SURFACE CHECKS ON CABLE 08:30 - 11:30 3.00 RUNCOM P RUNCMP RIH WITH ESP COMPLETION 1 -PU SINGLE, XN NIPPLE, 10' PUP, SINGLE, I , STAND AND LOWER GLM -RIH WITH 2 -7/8" 8RD EUE FROM DERRICK. 1 11:30 - 12:30 1.00 RUNCOM P RUNCMP CONDUCTIVITY CHECK OF CABLE, GOOD. I- FUNCTION TEST CHEMICAL INJECTION LINE -CLEAR PUMP WITH 1420 PSI AT 1 BPM 12:30 - 13:30 ! 1.00 r RUNCOM I P RUNCMP TEST ESP CABLE. I -R/U TO CIRCULATE. - CIRCULATE AT 10 SPM AND 1420 PSI. -R/D CIRCULATION EQUIPMENT. 13:30 - 14:30 1.00 I RUNCOM N SFAL ! RUNCMP WAIT ON PARTS FOR CENTRILIFT SPOOLER. - NEEDED LARGER AIR COMPRESSOR AND FITTINGS TO FUNCTION CHEMICAL INJECTION LINE. 14:30 - 23 :30 9.00 RUNCOM P RUNCMP (CONTINUE RIH WITH ESP COMPLETION FROM -2300 - -7664' 1- ESTABLISH CIRCULATION AND CONDUCTIVITY TEST EVERY 2000'. - CIRCULATE AT 10 SPM AND 1420 PSI. 23:30 00:00 0.50 RUNCOM ', P RUNCMP SPLICE ESP CABLE. -MAINTAIN CONTINUOUS HOLE FILL AT 9 BPH LOSS RATE. 4/12/2011 00.00 - 04:00 4.00 1 RUNCOM P RUNCMP 1 CENTRILIFT PERFORMING REEL TO REEL - -- i 1 SPLICE ESP CABLE @ - 7,664' _ Printed 4/25/2011 11:06:24AM Arrieriea - ALASKA BP% o 7 Operation Summary Repo Common Well Name: MPF -94 I AFE No Event Type: WORKOVER (WO) Start Date: 3/29/2011 I End Date: 4/13/2011 X4- 00T4J -E (750,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:OOAM I Rig Release: 4/13/2011 Rig Contractor: DOYON DRILLING INC. i UWI: 500292304000 Active Datum: MPF -94 @44.30ft (above Mean Sea Level) Date From - To Hrs Task 1 Code 1 NPT ' NPT Depth I Phase Description of Operations (hr) (ft) 04:00 - 14:30 10.50 RUNCOM P RUNCMP 'CONTINUE RIH WITH ESP COMPLETION FROM —7664' TO —16,000 ESTABLISH CIRCULATION AND CONDUCTIVITY TEST EVERY 2000'. —MAINTAIN CONTINUOUS HOLE FILL AT 9 BPH LOSS RATE. 14:30 - 19:00 4.50 RUNCOM P RUNCMP ' CENTRILIFT PERFORMING REEL TO REEL ESP CABLE SPLICE #2 1-MAINTAIN CONTINUOUS HOLE FILL WITH AVG LOSS RATE OF 8 BPH. -AT 19:15 NOTIFY SUPERINTENDANT OF CASE OF STAFF INFECTION OF A RIG HAND i 1 19 :00 3.00 RUNCOM P RUNCMP CONTINUE RIH WIT ME. 22 :00 ! _ 1 'THAT WAS - - - - - -_ ___ - -_ CONTINUE IH,ITH„ESP Cf)MPI FTInN FROM — 16,000 TO 18,079' '- ESTABLISH CIRCULATION AND 1 CONDUCTIVITY TEST EVERY 2000'. +- MAINTAIN CONTINUOUS HOLE FILL AT 9 BPH i ' - - -._._ L � LOSS RATE. 22:00 - 22:30 0.50 RUNCOM P i RUNCMP � M/U HANGER AND LANDING JOINT. -INSTALL FLOOR VALVE IN TOP OF LANDING JOINT. 22:30 - 00:00 1.50 RUNCOM ` P RUNCMP !INSTALL PENETRATOR AND TERMINATION SLEEVE. -RUN CHEMICAL LINE IN THROUGH HANGER. - MAINTAIN CONTINUOUS HOLE FILL AT 8.2 I 11 i BPH LOSS RATE. - 4/13/2011 00 :00 - 02:30 2.50 RUNCOM P RUNCMP I INSTALL PENETRATOR AND TERMINATION / SLEEVE. ` -TEST ESP CABLE - GOOD. -MAINTAIN CONTINUOUS HOLE FILL AT 8.2 ' I BPH LOSS RATE. 02:30 - 03:00 0.50 RUNCOM P 1 RUNCMP I LAND TUBING HANGER. 1 ' -UP WEIGHT OF 140K, DOWN WEIGHT OF 1 73K. 1 -LAND TUBING HANGER 23' IN. t { -RILDS. 03:00 - 04:00 ! 1.00 BOPSUR P r WHDTRE P/U AND R/U DSM LUBRICATOR. -R/U OPSO - LOPSO. -SET TWC. 04:00 - 05 :00 1.00 BOPSUR P WHDTRE • R/U AND TEST TWC. -TEST FROM ABOVE TO 250 PSI LOW AND 4,000 PSI HIGH FOR 10 MIN. -TEST TWC FROM BELOW TO 500 PSI AT 2.0 BPM AND 650 PSI TAKING 30 BBLS FOR A 10 MIN TEST. -BOTH TEST CHARTED AND GOOD. 05:00 06:30 1.50 BOPSUR P WHDTRE N/D 13 - 5/8" BOPE. -STAND BACK ON STAND 1 -NU TREE 06:30 - 08:30 ! 1 2.00 WHSUR P WHDTRE NU ADAPTER FLANGE AND TREE -CENTRILIFT CONDUCTING FINAL CHECKS FOR ESP PUMP & MOTOR. - INTAKE PSI OF 3870, DISCHARGE PSI OF 3840, TEMP OF 167 *, 337 MEGS. 08:30 - 10 :30 2.00 1 WHSUR P WHDTRE FMC REP PRESSURE TEST TUBING HEAD ADAPTER TO 250 PSI LOW AND 5000 PSI 1 HIGH FOR 30 CHARTED MIN Printed 4/25/2011 11:06:24AM 4Ipdh America - ALASKA- BP = Pa 0 Operation Summary Report Common Well Name: MPF -94 AFE No Event Type: WORKOVER (WO) Start Date: 3/29/2011 I End Date: 4/13/2011 X4- 00T4J -E (750,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/15/2001 12:00:OOAM I Rig Release: 4/13/2011 Rig Contractor: DOYON DRILLING INC. ,UWI_500292304000 Active Datum: MPF -94 @44.30ft (above Mean Sea Level) Date I From - To Hrs Task Code I NPT 1 NPT Depth I Phase I Description of Operations (hr) 1 (ft) 10 30 - 12:00 1.50 WHSUR P WHDTRE PRESSURE TEST TREE TO 250 PSI LOW AND 5000 PSI HIGH FOR 30 MIN. -LOST 50 PSI IN 30 MIN. 12:00 - 15:30 3.50 WHSUR I P WHDTRE I PU & MU HYD LUBRICATOR -TEST TO 250 LOW AND 4000 HIGH FOR 5 CHARTED MIN PULL TC, WELL ON VAC I l'-CHANGE OUT TO BPV ON RUNNING TOOL -MU AND TEST HYDRAULIC LUBRICATOR, 250 PSI LOW, 4000 PSI HIGH -SET BPV AND PERFORM ROLLING TEST TO 500 PSI FOR 5 CHARTED MIN. 15 :30 - 18 :00 ! 2.50 DEMOB j P POST FLUSH PUMP AND ALL LINES WITH FRESH 1 WATER AT 5; BPM I * ** RIG RELEASE AT 18:00 * ** / Printed 4/25/2011 11:06:24AM Tree; 2 9/16" - 5M CIW • M P F-94 Orig. KB = 44' (N -27E) Wellhead: 11" Gen 5 FMC Orig. GL = 11' 11 x 2 9/16" Hgr, w/ 2 7/8" NSCT T &B, - RT to Tb . pool = 33.0' (N -27E) & 2.5" Type 'H' BPV Profile 112' Camco 2 -7/8" x 1" I 141' KBMM GLM 10 3/4" Halliburton ES Cementer 2493' 0 1 r I 1 KOP @ 500' to 3100' Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 621 @ 2900' t 10 3/4 ", 45 # /ft., L -80 BTC 10,341' 4 i 18,079' SS Cap Tub with 2500# Check I Camco 2 -7/8" x 1" 17,821` KBMM GLM I I 1 j 2 -7/8" HES XN nipple 17,973` (ID 2.250 ") 2 7/8" 6.5 ppf, L -80 8 rd. EUE tubing I ■ ti GPDIS Discharge Head 18,019' (drift ID = 2.347 ", cap = 0.00592 bpf) CI 1 ( Centrilift ESP, SXD 137 - P1 7 18,020' 7" 26 # /ft., L -80 BTC -MOD Production 1. ; Casing, (Drift ID = 6.151 ", cap. = 0.0383 bpf) ifs. (cap w/ 2 7/8" tbg = .0302 bpf) Gas Separator 18,040' Capillary tube 3/8" OD x .049 wall GRSFTX AR H6 (400 Internals) (capacity = 3.131 gallons / 1000') Tandem Seal Section 18,052` GSB3DBUT /GSB3D6LT Ilk Motor KMH / 190 HP, 2415 volt, 48 amp, 18,058' PumpMate XTO 18,077 Stimulation Summary w/ 6 Fin Centralizer 12/11/01 Frac - 117,298# of 16/20 C /lite PumpMate TVD = 7344' 73,740# of 12/18 C /lite behind pipe. _ I Perforation Summary Ref. 1 ng SWS anadrill CDR resistivity. dated 10/17/01. 7" x 4.5" Baker Premier pkr. 18,155' Size SPF Interval (TVD) 2.5" 4 18290`- 18292' 7551' -7552' 13 2.5" 4 18328`- 18330' 7594' -7595' 18,181 ` 3 -3/8" 12 18300`- 18310' 7567` -7576' 4.5" HES XN- Nipple (3.813 ") 3 -3/8" 12 18325`- 18335' 7591` -7600' (No -go 3.75" id) 4 1/2" WLEG 18,193' (PBTD) 18,466' 7" Float Collar 18,469' r 7" Float Shoe 18,554' DATE REV. BY COMMENTS MILNE POINT UNIT 02/26/05 Lee Hulme ESP Re- Completion 4 -ES 02/08/06 Lee Hulme ESP Re- Completion 3S WELL MPF -94 (KUP) 12/9/07 Lee Hulme ESP Re- Completion 4ES 4 -25 -08 REH ESP Re- Completion Nabors 3S API No. 50 -029 -23040 4/16/09 Lee Hulme ESP Re- Completion Nabors 3S 2/6/10 Lee Hulme ESP Re- Completion Nabors 4ES 04/20/2011 Brian Bixby ESP Re- Completion Doyon 16 BP EXPLORATION (AK) STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS l~~G~{VED ER ~. ~. 2010 1. Operations Performed: ~8 >sl 1 8$ At13. Ott'M111$$~ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended®AOf8~8 ^ After Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Change Out ESP ' 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-170 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23040-00-00 7. Property Designation: 8. Well Name and Number: ADL 355016 MPF•94 9. Field /Pool(s) Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured \ 18595' feet true vertical ~ 7g53' feet Plugs (measured) None Effective depth: measured 18469' feet Junk (measured) None true vertical 773p' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' SurFace 10307' 10-3/4" 10341' 4454' 5210 2480 Intermediate Production 18523' 7-5/8" 18555' 7814' 6890 4790 Liner Perforation Depth: Measured Depth: 18290' - 18335' True Vertical Depth: 7557' - 7600' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 18073' 7348' ' ' ' ' 7418 - 7463 - 18193 4-12", 12.6# L-80 18146 Packers and SSSV (type, measured and true vertical depth): 7" x 4-1/2" Baker Premier Packer 18155' 7427' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12, Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run Well Class after work: ^ Exploratory ®Development ^ Service ® Dail Re ort of Well O erations y p p ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact David Reem, 564-5743 N/q Printed Name Terrie Hubble Title Drillin Technolo ist ~ t q Prepared By Name/Number ' Signature Phone 564-4628 Date V Terrie Hubble 564-4628 Form 10-404 Revisea'07/2009 ~~n..c ~ i A ~ ~~,L ~ a~ ~~, r~ Submit Original Only LM`7 1 ~G ~..,, MPF-94, Well History (Pre Rig Workover) Date Summary 01/20/10 WELL S/I ON ARRIVAL. RAN KJ, 2.15" CENT, S. ABSORBER, DUAL SPARTEK GAUGES. 15 MIN GRADIENT STOP C~3 17,499' SLM (17485' MD). 3 HR BHP STOP ~ 18010' SLM (17,996' MD). 01/21/10 LRS ASSISTED RIH, DISPLACED TBG. PULLED 1" BK-DGLV FROM ST #1 C~3 17,805' MD. PULLED 1" BEK-DPSOV FROM ST #3 C~3 138' MD. SET 1" BK-DGLV IN ST #3 C~ 138' MD. BPV NOT INSTALLED. WELL LEFT S/I, TURN OVER TO DSO. JOB COMPLETE. 01/21/10 T/I/0=1350/1120/0 Assist S-Line. Pumped 90bbls Diesel/Crude (50%/50%), 23bbls diesel down tubing. SL pulled valve. Verified valve OOH. FWHP's = 1500/1260/0. Slickline in control of well. 01/23/10 The Well Support Techs rigged up and set a back pressure valve, removed the wellhouse, removed the flowline, removed the foundation and installed a 2nd IA valve for the RWO. NOTE: The BPV was left IN. Page 1 of 1 • BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 1/28/2010 End: 2/5/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/5/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To ~ Hours ~~ Task Code NPT Phase Description of Operations 1/27/2010 19:00 - 00:00 5.00 RIGD P PRE RD RIG IN PREPARATION TO MPU F-94. HAD DIFFICULTIES PULLING PIT MODULE BACK. UNABLE TO GET SUFFIENT TRACTION WITH LOADER. REQUIRED ASSISTANCE FROM BED TRUCK. 1/28/2010 00:00 - 01:00 1.00 RIGD P PRE MOVE PITS, PIPE SHED, TIGER TANK, GENERATOR BUILDING, & SUB STRUCTURE OFF OF LOCATION 01:00 - 02:30 1.50 RIGU P PRE SPOT HERCULITE, RIG MATS, DOUBLE GATE AND LOADER 02:30 - 04:00 1.50 RIGU P PRE SPOT SUBSTRUCTURE OVER WELL. SPOT PIPE SHED AND PITS. 04:00 - 06:00 2.00 RIGU P PRE PJSM FOR RAISING DERRICK, RAISE AND SCOPE DERRICK. 06:00 - 08:30 2.50 RIGU P PRE RU LINES, HANDRAILS AND PUT STEAM AROUND. 08:30 - 11:30 3.00 RIGU P PRE ***ACCEPT RIG AT 08:30 HRS 1/28/2010*** -RU KILL LINES TO TREE AND TIGER TANK. -TAKE ON -120 DEG 10.1 PPG BRINE -TEST SURFACE LINES T/ 3,500 PSI -TEST TIGER TANK LINES W/ AIR TO 120 PSI 11:30 - 12:30 1.00 WHSUR DECOMP RU LUBRICATOR -TEST T/ 500 PSI W/DIESEL -PULL BPV -RD LUBRICATOR -TBG = 1050 PSI, IA = 1090 PSI, OA = 0 PSI. 12:30 - 13:00 0.50 KILL P DECOMP PJSM WITH CREW ON WELL KILL 13:00 - 18:00 5.00 KILL P DECOMP -WELL KILL -BLEED IA AND TBG THROUGH CHOKE TO TIGER TANK -PUMPED 104 BBLS OF_120F_10.1 PPG BRINE DOWN. TUBING AT 3-BPM . -IA=350 - OA=O -TBG=950 (RECOVERED -90 BBLS) -CLOSED CHOKE AND BULLHEADED 100 BBLS DOWN TBG AT 3 -BPM -IA= 1,450 PSI, TBG= 1,030 PSI. -OPENED CHOKE AND CONTINUED CIRCULATING DOWN THE TBG. -4 BPM / 1,540 PSI -PUMPED 557 BBLS UNTIL RETURNS = 10.1 PPG. -PUMPED A TOTAL OF 661 BBLS, GOT BACK -620 BBLS TO THE TIGER TANK. -SI WELL =TBG = 10 PSI, IA = 20 PSI 18:00 - 22:00 4.00 KILL N WAIT DECOMP -WAIT ON LAST LOAD OF KILL FLUID IN "PHASE ONE" AND "PHASE II" WEATHER CONDITION-TBG=10 PSI, IA = 20 PSI. BLEED OFF PRESSURE. WELL DEAD. 22:00 - 23:00 1.00 WHSUR P DECOMP INSTALL TWC WITH DRY ROD.<TEST BELOW TWC ROLLING TEST 500 PSI FOR 10 MIN. X38 SPM. TEST FROM ABOVE 3700 PSI FOR 10 MIN. GOOD TEST. 23:00 - 00:00 1.00 WHSUR P DECOMP E . 1/29/2010 00:00 - 12:00 12.00 BOPSU P DECOMP RECONFIGURE BOP ANNULAR DOUBLE GATE (BLIND AND VARIABLES) MUD CROSS AND PIPE RAMS.. NU BOP. CONTINUE PHASSE 2 DRIVING CONDITIONS. Pnntetl: 1/lU/ZUIU 3:S/:SU PM • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 1/28/2010 End: 2/5/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/5/2010 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/29/2010 12:00 - 14:00 2.00 BOPSU N WAIT DECOMP NIGHT CREW RETURN TO CAMP. -TWO MAN RIG WATCH TEAM ARRIVE AT 12:00 HRS -ALL FLIGHTS CANCELLED, NO FRIDAY CREW CHANGE FROM ANCHORAGE. 14:00 - 22:30 8.50 BOPSU P DECOMP DAY CREW RETURN TO WORK FROM MILNE POINT CAMP AND WORK AT RESTRICTED PACE DUE TO SAFETY CONCERNS OF NO AIR FLIGHTS AND LITTLE SLEEP. -INSTALL 2-7/8" X 5" VBR's, BLIND SHEAR RAMS, FIXED 2-7/8" RAM BLOCKS. 22:30 - 23:00 0.50 BOPSU P DECOMP FUNCTION TEST BOP. FILL BACKSIDE WITH 8.2 BBLS. FILL STACK. 23:00 - 00:00 1.00 BOPSU P DECOMP TEST BOP'S. WITNESSING TEST WAIVED BY BOB NOBEL OF AOGCC. -HINDGE SEAL REPLACED "O" RING. 1/30/2010 00:00 - 04:00 4.00 BOPSU P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S AND 2-7/8" FIXED RAMS WITH 2-7/8" TEST JOINT. -TESTED ANNULAR WITH 2 7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. -TESTED FLOOR VALVES. -PERFORM KOOMEY TEST -200 PSI BUILD UP TO 1600 PSI FROM 1800 PSI = 45 SECONDS. -FULL BUILD UP TO 3000 PSI = 181 SECONDS. -4 BOTTLES x 1850 PSI. -WITNESSING TEST WAIVED BY BOB NOBLE OF AOGCC. ON 1 /27/2010 04:00 - 06:00 2.00 BOPSU N DECOMP DOOR HINDGE SEAL LEAKED APPROXIMATELY 1 QUART OF HYDRAULIC OIL ONTO BOP AND MATS. -REPAIR DOOR HINDGE SEAL ON BLIND RAMS. 06:00 - 06:30 0.50 BOPSU P DECOMP RU DUTCH RISER SYSTEM. -CROSSOVER/LUBRICATOR 06:30 - 09:00 2.50 WHSUR P DECOMP RU LUBRICATOR AND TEST SAME TO 500 PSI WITH DIESEL. -PULL TWC. -TUBING AND IA ARE ON A VAC. -LD LUBRICATOR AND RD DUTCH SYSTEM. 09:00 - 10:00 1.00 WHSUR P DECOMP MU LANDING JOINT W/ TIW VALVE SCREW INTO -"FMC" BOLDS -TBG AND IA ON A SLIGHT VACUUM. -PULL TBG HANGER OFF SEAT ~ 60 K -PUW = 94 K, SOW = 40 K, MAX PULL= 105 K. -LD HANGER 10:00 - 13:30 3.50 PULL P DECOMP CIRCULATE BOTTOMS-UP -ABORT CIRCULATING AT 4 BPM / 1,500 PSI, DUE TO _ 50 BPH LOSS RATE. rnrnea: uiuizuiu ~:orsu rm BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 1/28/2010 End: 2/5/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/5/2010 Rig Name: NABOBS 4ES Rig Number: 4ES -I Date From - To I Hours Task -Code NPT Phase Description of Operations 1/30/2010 10:00 - 13:30 3.50 PULL P DECOMP -3 BPM / 1,000 PSI -PUMPED 555 BBLS 10.1# BRINE -LOST 78 BBLS -SPR = 1 BPM / 110 PSI 13:30 - 00:00 10.501 PULL ~ P 1/31/2010 100:00 - 06:00 I 6.001 PULL I P 06:00 - 06:30 0.50 PULL P 06:30 - 11:00 4.50 PULL P 11:00 - 13:30 I 2.501 PULL I P 13:30 - 14:00 0.501 PULL P 14:00 - 15:30 I 1.501 PULL I P 15:30 - 19:00 I 3.501 RU 19:00 - 00:00 I 5.001 RU 2/1/2010 00:00 - 02:30 2.501 RU 02:30 - 03:30 I 1.001 RU 03:30 - 06:00 I 2.50 DECOMP PU l P E.TION . -STAND 2-7/8" TBG IN DERRICK -SNAKE ESP CABLE OVER SHEAVE IN DERRICK -330 JOINTS OUT AT 00:00 HRS --13 BPH LOSS RATE DECOMP CONTINUE TO PULL COMPLETION IN STANDS -FROM JT #330, T/ JT #480 --13 BPH LOSS RATE DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. DECOMP POH F/ JT #480 T/ JT #513 -LAY DOWN BAD JOINTS, -THREADS IN SIDE THE TOOL COLLARS BELOW THE SEAL RING ARE EAT UP. -INSPECT EACH JOINT WHILE POH W/ ESP -LD 62 BAD JTS -RECOVERED: (380) LASALLE, (5) PROTECTOLIZERS, (3) FLAT GUARDS. DECOMP LD ESP ASSEMBLY -SCALE WITH FINE SAND ON ESP -MOTOR LOCKED-UP DECOMP CLEAR RIG FLOOR -REMOVE ESP BOXES FROM PIPE SHED -REDRESS GLM'S DECOMP BO / LD 12 BAD JOINTS 2-7/8" TBG FROM DERRICK -TOTAL 70 BAD JOINTS -F/ _15,824' MD T/ -18,042' MD. RUNCMP CLEAN AND CLEAR RIG FLOOR -RU TO RUN COMPLETION -LOAD ESP AND CAP-TUBE INTO SPOOLING UNIT -LOAD ESP ASSEMBLY INTO PIPE SHED -RD CABLE TRUNK RUNCMP ,~SEMBLE ESP MOTOR AND PUMP AND SERVICE SAME. PULL ESP CABLE AND CAPILARY LINE TO RIG FLOOR. MU FLATCABLE AND CAPILARY LINE TO PUMP ASSEMBLY. RUNCMP INSTALL TWO CHECK VALVES IN CAPILARY LINE. TEST CAPILARY LINE TO 2500 PSI. PRESSURED TO 5200 PSI WITH OUT ANY BLEED OFF. FAILED TEST RUNCMP BLEED OF PRESSURE ON CAPILARY LINE. LD ONE SINGLE. REMOVE ONE CK VALVE AND RETEST. PRESSURE TO 2700 PSI TO FIRST DRIP. PRESSURE, TO 3200 PSI TO OBTAIN CONTINUOUS WEEPING. GOOD TEST. APPEARS THAT WE WERE HYDRAULICLY LOCKED BETWEEN CK VALVES. PRE TEST BY SLB FAILED TO TEST VALVES IN TANDEM. RUNCMP $jH WITH ESP. PU 73 JOINTS FROM SHED, INSTALL CANNON CLAMPS ON EVERY COLLAR. TEST ESP CABLE AND CAPILARY LINE EVERY 2000'. -(24) JTS RAN AT 0600 HRS. -8 BPH LOSS RATE. Printed: Z/10/2010 3:57:30 PM • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 1/28/2010 End: 2/5/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/5/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 2/1/2010 06:00 - 06:30 0.50 BUNCO RUNCMP PJSM -RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 18:00 11.50 BUNCO P RUNCMP RUN ESP COMPLETION W/ CAP-TUBE -STARTING AT JOINT #25 -PU (TOTAL OF 73, CLASS 'B') REPLACMENT JOINTS F/ PIPE SHED -THEN RIH FROM DERRICK --2,000' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 830 PSI --2,000' MD, CIRCULATE CHECK VALVE 3,800 PSI, CLOSED 2,700 PSI --4,000' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 970 PSI --4,000' MD, CIRCULATE CHECK VALVE 4,100 PSI, CLOSED 3,000 PSI --6,000' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 1090 PSI --6,000' MD, CIRCULATE CHECK VALVE 4,200 PSI, CLOSED 3,000 PSI 18:00 - 23:00 5.00 BUNCO P RUNCMP CENTRILIFT MAKE REEL TO REEL CABLE SPLICE -AT JT #243 --8,000' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 1050 PSI --8,000' MD, CIRCULATE CHECK VALVE 4,200 PSI, CLOSED 3,000 PSI 23:00 - 00:00 1.00 BUNCO RUNCMP RUN ESP COMPLETION W/ CAP-TUBE. PU STANDS FROM DERRICK. -F/JT#243T/JT#300 2/2/2010 00:00 - 08:00 8.00 BUNCO RUNCMP RUN ESP COMPLETION W/CAP-TUBE. PU STANDS FROM DERRICK, JT # 300 --9,400' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 1080 PSI --9,400' MD, CIRCULATE CHECK VALVE 4,200 PSI, CLOSED 3,000 PSI --11,300' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 1080 PSI --11,300' MD, CIRCULATE CHECK VALVE 4,200 PSI, CLOSED 3,000 PSI --12,800' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 1100 PSI --12,800' MD, CIRCULATE CHECK VALVE 4,000 PSI, CLOSED 3,000 PSI BLEED T/ 1,400 PSI --12,800' MD, REPEAT TEST 4,000 PSI, CLOSE 3,100 PSI -3-4 BPH LOSS RATE -SUSPEND OPERATION DUE TO HI-WINDS 08:00 - 00:00 16.00 BUNCO WAIT RUNCMP PHASE 2 WEATHER CONDITION. -SECURE WELL -SUSPEND ALL OPERATIONS -09:00 HRS PHASE 3 -FLUID LOSS = 3.5 BPH 2/3/2010 00:00 - 12:00 12.00 BUNCO WAIT RUNCMP -SECURE WELL -CONTINUED WITH SUSPENDED OPERATIONS PHASE 3 -FLUID LOSS REMAIN= 3.5 BPH -WIND LAYED DOWN ~ 01:50. REQUESTED PERMISSION TO CREW CHANGE FROM IMT. PERMISSION DENIED BY MILNE POINT G AHUMADA. -IMT JERRY BIXBY APPROVED CREW CHANGE ~ 04:00. -MADE CREW CHANGE FROM MILNE POINT TO F-PAD Printed: 2/10/2010 3:57:30 PM • • BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 1/28/2010 End: 2/5/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/5/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date from - To Hours' Task Code NPT Phase . Description of Operations 2/3/2010 00:00 - 12:00 12.00 BUNCO WAIT RUNCMP 06:00 HRS. -PHASE 2 LEVEL 3 ~ 06:00 HRS -DIG OUT -MILNE POINT ROADS & PADS FORMAN STOPPED BY -& REPORTED THE ROAD IS OPEN TO MILNE POINT. 10:00 HRS. -PHASE 2 LEVEL 3 -MADE CREW CHANGE AT 12:00 TO 13:00. 12:00 - 22:00 10.00 BUNCO RREP RUNCMP -THAW ,TROUBLE SHOOTAND SERVICE SPOOLING UNIT WHICH DIED DURING THE BLOW. ATTEMPTED TO RUN ON RIG POWER GROUND FAULT FAILED. MPU MECHANICS SUCCESSFULLY REPAIRED GENERATOR ON SPOOLING UNIT. MADE BACKUP PLAN WITH PRECISION POWER FOR RENTAL UNIT. 22:00 - 00:00 2.00 BUNCO P RUNCMP RUN ESP COMPLETION W/ CAP-TUBE. PU STANDS FROM DERRICK --13,400' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 1170 PSI 2/4/2010 00:00 - 03:00 3.00 BUNCO P RUNCMP RUN ESP COMPLETION W/CAP-TUBE. PU STANDS FROM DERRICK RIH TO SPLICE AT 15400' --15,400' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 1170 PSI --15,400' MD, CIRCULATE CHECK VALVE 4,000 PSI, CLOSED 3,000 PSI 03:00 - 08:30 5.50 BUNCO RUNCMP CENTRILIFT - REEL TO REEL CABLE SPLICE AT 15,400'. 08:30 - 11:00 2.50 BUNCO RUNCMP CONTINUE RUN ESP COMPLETION W/CAP-TUBE. PU STANDS FROM DERRICK RIH FROM SPLICE AT 15,400' TO 18,091'. - -18,000' MD, FLUSH PUMP W/ 5 BBL, 1 BPM / 1170 PSI - -18,000' MD, CIRCULATE CHECK VALVE 4,000 PSI, CLOSED AT 3,300 PSI 11:00 - 11:30 0.50 BUNCO RUNCMP P AND MAKE UP TUBING HANGER. - BLEED OFF CAP-TUBE AND CUT. - MAKE UP CAP-TUBE TO HANGER AND TEST -CIRCULATED CHECK VALVE AT 4,000 PSI, CLOSED AT 3,300 PSI. 11:30 - 15:00 3.50 BUNCO RUNCMP CENTRILIFT - ~^-AKF l1P THE PENETRATOR SPLIC:F, -TEST CAP LINE 4000 PSI, BLEED OFF TO 3300 PSI. LAND HANGER AND RILDS. -P/U WT = 91 K LBS, S/O WT = 33K LBS. -RAN 566 CANNON CLAMPS, 3 FLAT GUARDS, AND 5 PROTECTOLIZERS. 15:00 - 16:30 1.50 WHSUR P WHDTRE INSTALL TWC AND TEST 16:30 - 22:00 5.50 WHSUR P WHDTRE ND DUTCH SYSTEM ,CHOKE AND KILL LINES. REMOVE RAMS FROM THE DOUBLE GATE 22:00 - 00:00 2.00 WHSUR P WHDTRE PJSM. BREAK DOWN BOP. REMOVE DOUBLE GATE AND INSTALL SINGLE GATE. 2/5/2010 00:00 - 04:30 4.50 WHSUR P WHDTRE CONTINUE TO BREAK DOWN BOP. REMOVE DOUBLE GATE AND INSTALL SINGLE GATE. 04:30 - 05:30 1.00 WHSUR N HMAN WHDTRE ACCIDENT: Printed: Z/10/2010 3:57:90 NM BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 1/28/2010 End: 2/5/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/5/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From -7o Hours Task Code NPT Phase Description of Operations ' 2/5/2010 04:30 - 05:30 1.00 WHSUR N HMAN WHDTRE DERRICK HAND PINCHED LEFT AND RIGHT RING FINGERS WHILE LATCHING BRIDLE LINE YOKE IN TRAVELING BLOCK HOOK. DERRICK HAND TRANSPORTED TO MILNE MEDIC. MEDIC SENT HAND TO ANCHORAGE FOR EVALUATION. STAND DOWN FOR NABORS'S INVESTIGATION. TRACTION INCIDENT #2010-IR-3394168. 05:30 - 11:00 5.50 WHSUR N HMAN WHDTRE CONTINUE TO STAND DOWN DUE TO INCIDENT. - CREW CHANGE. ONCOMING CREW PERFORMED ENVIRONMENTAL WALK AROUND. - NABOBS SAFETY, PAUL HOLLEY, AND BP ADW SAFETY, ALLEN GRAFF ON LOCATION TO PERFORM INCIDENT INVESTIGATION. - DISCUSSED INCIDENT WITH CREW. WORKED WITH CREW TO RE-ENACT INCIDENT AND TO DETERMINE A BEST PRACTICE FOR ATTACHING THE BRIDLE LINE YOKE TO THE TRAVELING BLOCK HOOK. 11:00 - 15:00 4.00 WHSUR N HMAN WHDTRE CONTINUE TO STAND DOWN DUE TO INCIDENT. -CREW DEVELOPED AND PRODUCED A POWERPOINT PROCEEDURE FOR ATTACHING THE BRIDLE LINE YOKE TO THE TRAVELING BLOCK HOOK. 15:00 - 18:00 3.00 WHSUR P WHDTRE CONTINUE TO RECONFIGURE BOP STACK. -TIGHTEN UP FLANGES ON BOP STACK AND RE-CHECK ALL BOLTS.. -INSTALL BLIND/SHEAR RAMS IN UPPER SINGLE GATE RAM. 18:00 - 19:30 1.50 WHSUR N HMAN WHDTRE -STAND DOWN TO DISCUSS INCIDENT WITH NIGHT CREW. 19:30 - 20:30 1.00 WHSUR P WHDTRE ND BOP 20:30 - 22:30 2.00 WHSUR P WHDTRE NU TREE & TEST ADAPTER FLANGE VOID TO 5000 PSI FOR 30 MIN. GOOD TEST. 22:30 - 23:00 0.50 WHSUR P WHDTRE TEST TREE TO 5000 PSI FOR 30 MIN. PERFORM FINAL TEST ON ESP CABLE AND PUMP. 23:00 - 00:00 1.00 WHSUR P WHDTRE MU LUBRICATOR AND TEST TO 500 PSI. PULL TWC. SET BPV. TEST TO 500 PSI ROLLING TEST. RELEASE RIG AT 00:00 HRS 2-5-2010 rnntea: znuizu~us:onsu rrw Tree: 2 9/16" - 5M CIW ~ ~ ~ 4 Orig. K~v. = 44' (N-27E) Wellhead: 11" Gen 5 FMC Orig. G ev. = 11' 11 x 2 9/16" Hgr, w/ 2 7/8" NSCT T&B, t' RT to Tbg. Spool = 33.0' (N-27E) & 2.5" Type 'H' BPV Profile 112' 10 3/4" Halliburton ES Cementer 2493' KOP @ 500' to 3100' Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' 10 3/4", 45#/ft., L-80 BTC 10,341` Camco 2-7/8" x 1" 138` KBMM GLM Camco 2-7/8" x 1" 17,849` KBMM GLM 2-7/8" XN nipple 17,970` (ID 2.250") 2 7/8" 6.5 ppf, L-80 8 rd. EUE tubing GPDIS Discharge Head 1$,012` (drift ID = 2.347", cap = 0.00592 bpf) ' Centrilift ESP, SXD 119-P23 1 $,013` 7" 26#/ft., L-80 BTC-MOD Production { Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) (cap w/ 2 7/8" tbg = .0302 bpf) Gas Separator 1$,031 ` GRSFTX AR H6 (400 Internals) Stimulation Summary 12/11/01 Frac - 117,298# of 16/20 C/lite 73,740# of 12/18 C/lite behind pipe. Perforation Summary Ref. Loq SWS anadrill CDR resistivity. Size SPF Interval TVD 2.5" 4 18290`-18292' 7551 `-7552' 2.5" 4 18328`-18330' 7594`-7595' 3-3/8" 12 18300`-18310' 7567`-7576' 3-3/8" 12 18325`-18335' 7591'-7600' Tandem Seal Section 18,035` GS83DB UT/LT SB/SB PFSA Motor (rerated), 195 HP, 2145 volt, 52 amp, KME1 1$,049` PumpMate XTO 18 069` w/ 6 Fin Centralizer PumpMate TVD = 7344` 7" x 4.5" Baker Premier pkr. 18,155' 4.5" HES XN-Nipple (3.813") 18,181` (No-go 3.75" id) 4 1/2" WLEG 18,193` (PBTD) 18,466' 7" Float Collar 18,469' 7" Float Shoe 18,554' DATE REV. BY COMMENTS 02/26/OS Lee Hulme omp etion - ESP Re-Completion 4-ES 02/08/06 12/9/07 Lee Hulme Lee Hulme ESP Re-Completion 3S ESP Re-Completion 4ES 4-25-OS 4/16/09 REH Lee Hulme ESP Re-Completion Nabors 3S ESP Re-Completion Nabors 3S 2/6/10 Lee Hulme ESP Re-Completion Nabors 4ES MILNE POINT UNIT WELL MPF-94 (KUP) API No_ 50-029-23040 STATE OF ALASKA ALf~A OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~I~~~ Jut Q ~ 2009 1. Operations Performed: ~~~~k,a QiE. ~ G~S CU61S, C~~'sr~'tiSSits ^ Abandon ~ Repair Well ^ Plug PerForations ^ Stimulate ^ Re-En~~~~~ded Well ^ Alter Casing ~ Pull Tubing , ^ Perforate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 201-170 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23040-00-00 ~ 7. KB Elevation (ft): ~ 33, 9. Well Name and Number: MPF-94 8. Property Designation: 10. Field / Pool(s): ~; % 4~~,/ ADL 355016 • Milne Point Unit / Kuparuk River,SaRds' ~ 7~•`'' 11. Present well condition summary Total depth: measured 18595 feet true vertical 7853 ~ feet Plugs (measured) None Effective depth: measured 18469 • feet Junk (measured) None true vertical 7730 , feet Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 112' 112' •~•- Surface 10307' 10-3/4" 10341' 4454' S210 2480 Intermediate Production 18523' 7-5/8" 18555' 7814' 6890 4790 Liner S~P,s'.+~~~iir~ 3 ~~ 4~ ` ~ V~ v W .. Perforation Depth MD (ft): 18290' - 18335' Perforation Depth ND (ft): 7557' - 7600' 2-7/8", 6.5# L-80 18113' Tubing Size (size, grade, and measured depth): 41~~ ~2 ~ -Rn ' Packers and SSSV (type and measured depth): 7" x 41/2" Baker Premier Packer 18155' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 350 0 Subsequent to operation: 625 130 795 350 30i 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 N/A Printed Name Sondra Stewman Title Dritling Technologist ~ Prepared By Name/Number Sig re Phone 564-4750 Date -'~7 ondra Stewman, 564~750 Form 10-404 Revised 04/2006 ~ ~~~~~ ~~ ~~~k ~ g 2pQg ~RI~I~AL Submit Original Only ~~ 7~.t~ ~~ ~~~-~os Tree: 2 9/16° - 5M CIW • Wellhead_ 11" Gen 5 FMC 11 x 2 9/16" Hgr, w/ 2 7/8" NSCT T&B, ! & 2.5" Type `H' BPV Profile 112' 10 3/4" Halliburton ES Cementer 2493' KOP @ 500' to 3100' Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' 10 3/4", 45#/ft., L-80 BTC 10,341 ` Ori~ Elev. = 44` (N-27E) Ori L Elev. = 11' RT to Tbg. Spool = 33.0' (N-27E) Camco 2-7/8" x 1° 138` KBMM GLM Camco 2-7/8" x 1" 14,971 ~ KBMM GLM Camco 2-7/8" x 1" 17,805` KBMM GLM 2-~/8" XN nipple 17,957` (ID 2.205") 2 7/8" 6.5 ppf, ~-80 8 rd. EUE tubing ~S Pressure Head 17,999~ (drift ID = 2.347", cap = 0.00592 bpf) rilift ESP, SXD 137-P17 17,998~ 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 (cap w/ 2 7/8" tbg =.0302 bpf) ; Separator 18 018~ FTX AR H6 (400 Internals) r Stimulation Summarv 12/11/01 Frac - 117,298# of 16/20 C/lite 73,740# of 12/18 C/lite behind pipe. Perforation Summarv Ref. Log SWS anadrill CDR resisti ~a+P.~ ~ni~~m~ Size SPF Interval TVC 2.5" 4 18290'-18292' 7551'-755 2.5" 4 18328'-18330' 7594'-759 3-3/8" 12 18300'-18310' 7567'-757 3-3/8" 12 18325'-18335' 7591'-760 ~dem Seal Section ? DB UT/LT SB/SB PFSA ~ H~OZJ~ tor, 152 HP, 2325 volt, ~mp, KMH ~ $,~37` ~mpMate XTO ~ 6 Fin Centralizer ~~ 18t13~ 4.5" Baker Premier pkr. 18,155' iES XN-Nipple (3.813") 18,181' (No-go 3.75" id) 4 1/2" WLEG 18,193' (PBTD) 18,466' 7" Float Collar 18,469` 7" Float Shoe 18,554` DATE REV. BY COMMENTS 12/11/01 02/08/02 M. Linder MDO Perfwith coil and Frac with D.S. ESP Completion 4-ES 02/26/05 02/08/06 Lee Hulme Lee Hulme ESP Re-Completion 4-ES ESP Re-Completion 3S 12/9/07 4-25-08 Lee Hulme REH ESP Re-Completion 4ES ESP Re-Completion Nabors 3S 4/16/09 Lee Hulme ESP Re-Completion Nabors 3S MILNE POINT UNIT WELL MPF-94 (KUP) API No. 50-029-23040 BP EXPLORATION (AK) M PF-94 ~ • BP EXPLORATIQN Page 1 a# 4 Operations Summary Rept~rt Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 5/30/2009 End: 6/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/7/2009 Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Qperations 6/2/2009 12:00 - 16:30 4.50 RIGD P PRE Rig down all modules in preparation for rig move. Move miscellaneous equipment to MPF-Pad. Scope and lower the Derrick. Trucks arrive on location at 1400 hrs. Move the Pits, Camp, Shop, Generator and Parts House from MPL-Pad to MPF-Pad. Move the Carrier off of well slot MPL-43 with the Pad Operator present at 1600 hrs. Spot the Carrier and Pipe Shed on the pad and prepare to mobilize. 16:30 - 17:00 0.50 MOB P PRE Move the Carrier and Pipe Shed from MPL-Pad to MPF-Pad. 17:00 - 23:00 6.00 RIGU P PRE Arrive on MPF-Pad. Spot the Pipe Shed and Carrier on the Pad. Back the Carrier over well MPF-94 with the Pad Operator present at 1930 hrs. Back and position the Pipe Shed and Pits Complexes alongside the Carrier. Connect power lines. Spot Upright and Tiger tanks. Move in surface equipment and various dumpsters to rig. 23:00 - 00:00 1.00 RIGU P PRE Raise and scope Derrick. Rig up board and floor. 6/3/2009 00:00 - 01:00 1.00 RIGU P PRE Continue to RU board and floor equipment. Evaluate diesel leak from Ch2mhill vac truck on pad with Pad-operator, report to Milne Pt. security and environmental tech. Rig accepted at 01:00 hrs on 06-03-2009. 01:00 - 04:30 3.50 KILL P DECOMP RU hardline from Tiger tank hardline to kill manifold. RU kill and choke lines to kill manifold. Install double annulus on IA and tie into kill manifold. Take on 106 degF, 9.78 ppg brine to pits at 0200 hrs. Test surface lines to 3,500 psi. Test hardline to Tiger tank to 500 psi. Initial WHPs of Tubing = 900 psi , IA = 1,000 si and OA = 50 psi. 04:30 - 05:00 0.50 WHSUR P DECOMP RU lubricator and test to 500 psi with diesel. Pull 2-1/2" Tvpe "H" BPV with DSM. LD Lubricator. 05:00 - 10:00 5.00 KILL P DECOMP o pre- i sa e y mee ing wi e crew and truck drivers. Open well to a closed Choke and WHPs of Tubing = 700 psi and IA = 730 psi. Bleed gas off the IA and Tubing. Break circulation down the Tubing up the IA through the Choke to the Tiger Tank with 100 degF, 9.8 ppg brine at a rate of 3 bpm / 1,050 psi and 450 psi on the IA. Pumped 115 bbls with 123 bbls of returns on surface. Close the Choke and bullhead a total of 100 bbls of 9.8 ppg brine down the Tubing at a rate of 3 bpm / 1,700 psi with final IA pressure of 1,550 psi. Open the Choke and resume circulating the well out with 9.8 ppg brine the long way until returns are clean and density in equals density out. Pumped a total of 580 bbls at a rate of 3 bpm / 820 psi (final tubing pressure of 1,080 psi) with the IA falling from 410 psi down to 40 psi. Weight of returns at end of circulation were 9.8 ppg. Total amount circulated for the well kill was 700 bbls with 635 bbls of returns on surface =-90% returns. 10:00 - 10:30 0.50 KILL P DECOMP Monitor the well for 30 minutes. After 30 minutes both the Tubing and IA are on a vacuum. 10:30 - 11:00 0.50 KILL P DECOMP Blow down mes an i ani o in the Cellar. RU Little Red to the IA. 11:00 - 12:30 1.50 WHSUR P DECOMP . Fill u th Tree and ressure test the TWC from above to 3,500 si for 10 charted mins - aood test. Pressure test the TWC from below bv pumpinq into the IA with Little Red with 9.8 ppa brine Printed: 6/15/2009 12:0726 PM • • BP EXPLORATION' Page 2 of ~ Qper~tions Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 5/30/2009 End: 6/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/7/2009 Rig Name: NABORS 3S Rig Number: N3S Date' From - To Haurs Task C~d~ NPT Phase ' Description caf Operations 6/3/2009 11:00 - 12:30 1.50 WHSUR P DECOMP at a rate of 2 bpm / 400 psi for 10 charted mins - qood test. It took 13 bbls to catch fluid and pumped a total of 37 bbls into the IA. Hang the Elephant Trunk. 12:30 - 14:00 1.50 WHSUR P DECOMP ND the 2-9/16" Tree and Adapter Flange with FMC rep. Check the Hanger threads - good. 7-1/2 turns with 8rd EUE. 14:00 - 18:00 4.00 BOPSU P DECOMP NU 11" x 13-5/8" Double Studded Adapter. NU 13-5/8" BOPE. Monitor the IA while ND/NU and keeping it full with 9.8 ppg brine by gravity feeding. 18:00 - 21:30 3.50 BOPSU P DECOMP Test BOPE with 250 si low / 3 500 si hi h on all components. Test 2-7/8" x 5" VBR and annular with 2-7/8" test joint. Complete Koomey draw down test. Test witnessed by WSL and Tourpusher. AOGCC rep Chuck Sheve waived the state's right to witness at 1715 hrs on 6-3-09. Suck out stack and blow down equipment. Gravity feed IA with 9.8 ppg brine during BOPE test - IA on vac. 21:30 - 23:30 2.00 WHSUR P DECOMP RU Opso-Lopso with torqued XO, pump-in-sub, Lo-torque valve and lubricator and MU to tubing hanger. Test e ui ment to 500 psi with diesel. Pull TWC with Wells Su ort. Tubing and IA on vacuum. LD surface equipment and lubricator. 23:30 - 00:00 0.50 PULL P DECOMP PU landing joint with TIW valve. Screw into tubing hanger with 7-1/2 turns. 6/4/2009 00:00 - 00:30 0.50 PULL P DECOMP PJSM with rig crew and FMC wellhead tech. Monitor IA vacuum for 20 min thru 2". BOLDS with FMC rep. Pull tubing h r r with 1 w' t. Close and cap IA. Space hanger below bag for circulation. 00:30 - 04:30 4.00 PULL P DECOMP Break circulation down tubing at 3.5 BPM / 1200 psi taking returns back to pits. Took 24 bbis to catch fluid. Returns have trace of crude with minimal gas break out. 9.7+ fluid on returns ac to pits. Circulate a total of 650 bbis (20% over annulus volume to correct for losses) and lost 105 bbis. 04:30 - 05:30 1.00 PULL P DECOMP Pull hanger to floor with i00K up weight. Cut ESP cable and remove penetrator with FMC. Inspect hanger and LD in pipe shed. LD landing joint and TIW valve. 05:30 - 06:00 0.50 PULL P DECOMP Clear rig floor and RU to pull 2-7/8" tubing. Maintain continuous hole fill with 9.8 ppg brine, static losses =-20 bbl/hr. 06:00 - 06:30 0.50 PULL P DECOMP Pre-tour checks and service the Rig. 06:30 - 00:00 17.50 PULL P DECOMP POOH with existinq ESP completion standinp back 2-7/8" EUE 8rd Tubinp in the Derrick. Maintain continuous hole fill with 9.8 ppg brine with averape hourlv losses of 15 bbis oer hour.. Change out spools from 1000 hrs to 1200 hrs. Continue POH with completion. Change out spools at 1800 hrs to 1930 hrs (163 stands out). Continue POH with completion, losses =-15 bbl/hr. 248 stands pulled at midnight. 6/5/2009 00:00 - 02:30 2.50 PULL P DECOMP Continue to POH with 2-7/8" ESP completion. Losses =-15 bbl/hr. Pulled 572 loints= 3 GLM's, 1 XN nipple, 386 LaSalle clamps, 5 protectalizers and 3 armster guards. 02:30 - 05:00 2.50 PULL P DECOMP LD ESP assembl as per Centrilift rep and set components in boxes. Pump section locked up and unable to function test shaft with hand tool. Appears to be locked u due to hea sands and scale build u ar un nd bushin s. Shaft section on um intake sna ed. 05:00 - 06:00 1.00 PULL P DECOMP Clean and clear rig floor. Remove LaSalle clamps from shed. Printed: 6/15/2009 12:07:26 PM ~ ~ BP EXPLURATIUN rage ~ or u~ Operations Summary Repc~rt ~Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 5/30/2009 End: 6/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/7/2009 Rig Name: NABORS 3S Rig Number: N3S Date From - To Hcaurs Task Code NPT Phase i Description of Qperatians ~ 6/5/2009 06:00 - 09:00 3.00 RUNCO RUNCMP PUMU new ESP Assembl with Centrilift re s. Maintain '~ continuous hole fill with 9.8 ppg brine while on surface. Service I the GLMs with the Milne Point PE. ! 09:00 - 09:30 0.50 RUNCO P RUNCMP Pre-job safety meeting on TIH with ESP from the Derrick. 09:30 - 00:00 14.50 RUNCO P RUNCMP RIH with new ESP Assembl on 2-7/8" 6.5# L-80 EUE 8rd Tubin from the Derrick. Maintain continuous hole fill with 9.8 ppg brine. Use LaSalle Clamps on every Joint for the first 6,000' in the hole and then every other Joint to surface. Using Best O Life 2000 Pipe Dope on all connections and making up each connection to 2,300 ft-Ibs. Stop every 2,000' to check the conductivity of the ESP cable. At every stop, fill the Tubing and flush the pump with 10 bbls of 9.8 ppg brine at a rate of 0.5 bpm / 500 psi. 1 st splice at 1945 hrs to 2300 hrs. Static losses = 9 bbl/hr. 6/6/2009 00:00 - 05:30 5.50 RUNCO RUNCMP Continue to RIH with new ESP Assembly on 2-7/8", 6.5#, L-80, EUE 8rd Tubing from the Derrick. Maintain continuous hole fill with 9.8 ppg brine. Use LaSalle Clamps on every other Joint to surface. Using Best O Life 2000 Pipe Dope on all connections and making up each connection to 2,300 ft-Ibs. Stop every 2,000' to check the conductivity of the ESP cable. At every stop, fill the Tubing and flush the pump with 10 bbls of 9.8 ppg brine at a rate of 0.5 bpm / 500 psi. Static losses = 8 bbl/hr. 05:30 - 08:30 3.00 RUNCO P RUNCMP Perform reel to reel splice with Centrilift rep. 08:30 - 10:30 2.00 RUNCO P RUNCMP Resume RIH with ESP Completion on 2-7/8" EUE 8rd Tubing. Ran a total of 574 Joints of Tubing, 380 LaSalle Clamps, 5 Protectolizers and 3 Flat Guards. 10:30 - 11:00 0.50 RUNCO RUNCMP Stab Headpin and perform final flush of the Tubing at a rate of 0.5 bpm / 600 psi. 11:00 - 12:00 1.00 RUNCO RUNCMP Pick up, make up Landing Joint with TIW valve and Hanger. Orient per FMC rep. Install Penetrator. Obtain final PUW = 100K , SOW = 30K. 12:00 - 14:00 2.00 RUNCO P RUNCMP Perform Penetrator splice with Centrilift rep. 14:00 - 14:30 0.50 RUNCO RUNCMP Land Tubin Han er and RILDS with FMC re . 14:30 - 16:00 1.50 WHSUR P RUNCMP PU T-bar and set 2-1/2" Type "H" TWC with FMC rep. Pressure test to 3,500 psi from above for 10 charted mins - good test. Line up to pump down the IA and pressure test from IIIIIIJ' VVU IGJI. 16:00 - 17:00 1.00 BOPSU P RUNCMP Blow down and RD test equipment. Flush the Stack with fresh water in preparation for ND. 17:00 - 20:00 3.00 BOPSU P RUNCMP ND BOPE and DSA. Remove remaining 9.8 ppg brine from upright and return to MI mud plant. 20:00 - 23:00 3.00 WHSUR P RUNCMP NU tree and adapter. Orient tree for well tie-in. FMC rep tested hanger void to 5,000 psi for 30 min. Centrilift rep make final checks: BHT = 174.7 degF, BHP = 3670 psi, Phase to Phase = 6.5 ohms, Phase to Ground = 200 meg ohms. Test tree with diesel to 5,000 psi for 5 min - charted. Remove double annulus valve and install IA flange with needle valve. 23:00 - 00:00 1.00 WHSUR P RUNCMP RU lubricator with Wells Su ort. Test to 500 si with diesel. Pull TWC - TBG on vac. Set BPV with lubricator. RD lubricator. Normal up tree and wellhead valves. Secure celiar. Begin to flush and clear pits of unused brine, suck out sumps. 6/7/2009 00:00 - 02:00 2.00 WHSUR P RUNCMP Finish sucking out pits and sumps of class 2 material. Clean Printed: 6/15/2009 12:07:26 PM ~ ~ BP EXPLC~RATIC~N' :Page 4 of 4 Qperations Summary R~port Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 5/30/2009 End: 6/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/7/2009 Rig Name: NABORS 3S Rig Number: N3S aate From - To Hours Task Code NPT Phase De~cription of C~perations 6/7/2009 00:00 - 02:00 2.00 WHSUR P RUNCMP pits. Rig released at 0200 hrs on 06-07-2009. Printed: 6/75/2009 12:07:26 PM STATE OF ALASKA snzros OIL AND GAS CONSERVATION COMMiSSiON BO PE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 6/3/09 Rig Rep.: J. Greco/J. Fritts Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. HoffmanN. Volpe E-Mail adwdr3snsu@bp.com Well Name: MPF-94 PTD #2011700 Operation: Drlg: Workover. x Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular. 250/3500 Valves: 250/3500 MISC. iNSPECTtONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NT Housekeeping: P Drl. Rig P Lower Kelly 0 NT PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc P Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NT Trip Tank P P Annular Preventer 1 13 5/8" P Pit Level Indicators P P #1 Rams 1 2 7/8 x 5" P Flow Indicator P P #2 Rams 1 blind P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc NA NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 0 NA HCR Valves 2 2 1116" 3 1/8" P Kill Line Valves 1 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 2900 P CHOKE MANIFOLD: Pressure After Closure 1700 P Quantity Test Result 200 psi Attained 34 sec P No. Valves 13 P Full Pressure Attained 145 sec P Manual Chokes 1 NT Blind Switch Covers: All stations Yes Hydraulic Chokes 1 NT Nitgn_ Bottles (avg): 4 2000 i CH Misc 0 NA ACC Misc NA Test Results Number of Failures: 0 Test Time: 4.0 Hours Repair or replacement of equipment will be made within days. Notify the N orth Slope Ins ector 659-3607, follow with written confirmation to Su rvisor at: __ Remarks: Tested with 2 7/8" test joints against TWC. Witnessed by Vince Volpe Bp WSL, Jimmy Fritts NAD TP 24 HOUR NOTICE GIVEN YES x NO Waived By Chuck Scheve Date 612/09 ~. « Time 0700 hrs Witness Test start 1730 hrs Finish 2130 hrs BOP 05!12/09 ~~~~L~ (f ~'xi Y :,f ?pp~ Nabors 3S BOP Test MPU F-94 6-3-2009.x1s STATE OF ALASKA s,/~ ALA OIL AND GAS CONSERVATION C011~SION MAYA 7 2~~ REPORT OF SUNDRY WELL OPERATIOIs~a ~i~ ~ ~,~ ~~~~ Cai~nm~sson 1. Operations Performed: ^ Abandon ®Repair Well., ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP- ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. -®Development ^ Exploratory 201-170 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23040-00-00 - 7. KB Elevation (ft): 44 33'- 9. Well Name and Number: . MPF-94 - 8. Property Designation: 10. Field /Pool(s): ADL 355016 - Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 18595 ' feet true vertical 7853 ~ feet Plugs (measured) None Effective depth: measured 18469 - feet Junk (measured) None true vertical 7730 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112` Surface 10307' 10-3/4" 10341' 4454' 5210 2480 Intermediate Production 18523' 7-5/8" 18555' 7814' 6890 4790 Liner Perforation Depth MD (tt): 18290' - 18335' Perforation Depth TVD (tt): 7557' - 7600' 2-718 ° 6.5# L-80 18054' Tubing Size (size, grade, and measured depth): 4-12"_ 12Fiit I -RO ' Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker Premier Packer 18155' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 291 40 370 320. 283 Subsequent to operation: 620 52 843 300 286 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: _ ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram -® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist /"r ,,,._~, _ ~•-" Prepared By NamelNumber '~~/ Si ature i , Phone 564-4750 Dat ~ "t_.X'- ondra Stewman 564-4750 Form 10104 Revised 04/2006 ~`~~ ~ ~ r ?`E. `; Submit Original Only Tree: 2 9/16" - 5M CIW • yj[ellhead: 11" Gen 5 FMC 11 x 2 9/16" Hgr, w/ 2 7/8" NSCT T&B, & 2.5" Type 'H' BPV Profile 112' ~ 10 3/4" Halliburton ES Cementer 2493' KOP @ 500' to 3100' Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' 10 3/4", 45#/ft., L-80 BTC 10,341 ` MPF- 4 Ori~ Elev. = 44' (N-27E) Orl L Elev. = 11' RT to Tbg. Spool = 33.0' (N-27E) Camco 2-7/8" x 1" 138` KBMM GLM Camco 2-7/8" x 1" 14,971 ` KBMM GLM Camco 2-7/8" x 1" 17,805` KBMM GLM 2 7/8" 6.5 ppf, L-80 8 rd. EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) (cap w/ 2 7/8" tbg = .0302 bpf) Stimulation Summary 12/11/01 Frac - 117,298# of 16/20 C/lite 73,740# of 12/18 C/lite behind pipe. Perforation Summary Ref. Loq SWS anadrill CDR resistivity. dated 10/17/n1 Size SPF Interval TVD 2.5" 4 18290'-18292' 7551'-7552' 2.5" 4 18328`-18330' 7594'-7595' 3-3/8" 12 18300'-18310' 7567'-7576' 3-3/8" 12 18325'-18335' 7591'-7600' 2-7/8" XN nipple 17,957` (ID 2.205") GPDIS Pressure Head 17,999` Centrilift ESP, SXD 137-P17 17,998` Gas Separator 18 018` GRSFTX AR H6 (400 Internals) ~ Tandem Seal Section ` GS83DB UT/LT 58/SB PFSA 18,023 Motor, 152 HP, 2325 volt, 40 amp KMH 18 037` , , PumpMate XTO 18 051 ` w/ 6 Fin Centralizer 7" x 4.5" Saker Premier pkr. 18,155' I 4.5" HES XN-Nipple (3.813") 18,181` (No-go 3.75" id) 4 1/2" WLEG 18,193' (PBTD) 18,466` 7" Float Collar 18,469' 7" Float Shoe 18,554` DATE ~ REV. BY 02/08/06 I Lee Hulme ~ ESP Re-Completion 3S COMMENTS 4-25-08 REH ESP Re-Completion Nabors 3S 4/16/09 Lee Hulme ESP Re-Completion Nabors 3S MILNE POINT UNIT WELL MPF-94 (KUP) API No. 50-029-23040 BP EXPLORATION (AK) r • MPF-94 Well History Date Summary 02/16/09 CTU #9 1.75" CT.<> finish spooling on extra pipe, Travel to Milne Point. Pump 1.25" ball. Perform weekly BOP test. MU/RIH w/ 1.75" JSN. Tag ESP pump @ 18013'. start pumping gel sweep. 02/17/09 Continue RIH w/ 1.75" JSN to top of ESP pump @ 18013' pump 21 bbl geovis sweep and chase to surface. RBIH w/ choke closed. Tag pump @ 18016' (ctm up). Park @ 18016'. Circ 20 bbl of 10% HCL to nozzle. Lay in wellbore, pull to safety @ 14291'. Pump 7 bbls acid. Start pump in reverse, then forward. SD pump. Displace remaining acid across pump. Soak acid. Line out to flowback tank. Start pump in reverse, then forward. Pump looks good. POOH w/ coil, pumping remaining freeze protect on coil. At surface ..continue to flow back acid. flowing well to plant at end of day. 02/18/09 CTU # 9 w 1.75" CT, Rig down equipment ,End ticket at 18:00 03/31/09 T/I/0= 450/400/0. Freeze protect TBG with 15 bbls diesel and FL with 3 bbls 60/40 and 3 bbls diesel. FW HP's=400/380/0 AT DEPARTURE VALVES in following positions -and operator notified of positions and result of job. Wing closed, Swab closed, SSV closed, Master open, IA open, OA open -Well SI 04/02/09 RIH W/2.16" CENT, W/DUAL SPARTEK GAUGES. 04/03/09 ~"' SBHP/RIG PREP "" CONT RIH W/2.16" CENT, DUAL SPARTEK GAUGES. MADE 15 MIN GRADIENT STOP @ 17,400' SLM (17,379' MD) TAG TOP OF ESP @ 18,020' SLM (17,999' MD) MADE 3 HR BHP STOP @ 18,017' SLM (17,996' MD) PULL ST# 1, 1" BK-DGLV @ 17,804' MD ("""LEFT POCKET OPEN'') PULLED ST# 3, 1" BEK-DPSOV @ 138' MD. SET 1" BK-DGLV ST# 3 @ 138' MD.. ASSIST WELL SUPPORT SET BPV. WELL LEFT S/I, TURNED OVER TO DSO. ~ ~~~ 04/10/09 WELL SUPPORT PULL BACK PRESSURE VALVE. MADE 15 MIN GRADIENT STOP @ 17,400' SLM (17,379' MD) TAG TOP OF ESP @ 18,020' SLM (17,999' MD) MADE 3 HR BHP STOP @ 18,017' SLM (17,996' MD) WELL LEFT S/I ON DEP, TURN OVER TO DSO. 04/15/09 SET DGLV/BK IN GLM #1, DGLV/BK IN GLM #2 AND DPSOV/BKP IN GLM #3 IN 3S PIPE SHED. ALL MANDRELS MARKED W/VALVE INFO AND DPSOV FLAGGED. 04/17/09 The Well Support Techs rigged up and set the foundation, installed the flowline and set the wellhouse, they then rigged up and pulled the back pressure vavel and pressure tested the flowline to 4000 psi. NOTE: The BPV was left OUT and the leak test was GOOD. as~r`~S 04/17/09 T/I/0=400/0/0. (Post RWO freeze protect) Freeze protect IA w/ 65 bbls crude. Freeze protect tbg w/ 15 bbls crude. DSO Notified swab aing ssv shut, master is oa open FW HP=250/200/0 Page 1 of 2 • • BP EXPLORATION Operations Summary Report Page 1 of 5 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: .From - To MPF-94 MPF-94 WORKO NABOB NABOB Hours VER S ALAS S 3S ~! Task. A DRI ', Code LING I NPT Start I Rig Rig Phase Spud Date: 10/15/2001 : 4/9/2009 End: 4/16/2009 Release: 4/16/2009 Number: Description of Operations 4/10/2009 00:00 - 01:30 1.50 RIGD P PRE Scope down and lay over derrick. 01:30 - 05:00 3.50 RIGD P PRE Jack, pin and pull away pipe shed and pit modules. Blow down steam and disconnect electrical. Roll tires on carrier. Jack down carrier. 05:00 - 07:00 2.00 MOB P PRE PJSM with crew and truck drivers. Pull trucks under mods and ull off MPF-96. Spot the Carrier, Pipe Shed and Pits Complex on the Pad for standby. 07:00 - 19:00 12.00 MOB N WAIT PRE Wait on Slickline to perform a static on MPF-94 and for the well to be de-mobilized and ready for Nabors 3S. Perform minor maintenance projects and housekeeping while waiting on work to be completed on MPF-94. Slickline RDMO off MPF-94 at 1900 hrs. Slickline headed back to shop for static data retrieval. 19:00 - 00:00 5.00 MOB N WAIT PRE Wait on Milne Pt. Wells Support to de-mob MPF-94. Continue housekeeping projects while waiting. Static data showing a 32 psi /day build rate. Confer with Day WSL and town for kill weight fluid. Calculate 9.3 ppg brine to kill well and hole fill thru life of workover operations. 4/11/2009 00:00 - 08:30 8.50 MOB N WAIT PRE Wait on Peak trucks from Prudhoe to move rig. 08:30 - 13:00 4.50 MOB P PRE Peak Sow and Truck Pusher arrives on location. Spot rig mats and herculite around well slot MPF-94. Spot the BOP Cradle and Kill Manifold behind the Rig. Spot the Pipe Shed Module. At 1200 hrs back the Carrier over well slot MPF-94 with Pad Operator, Toolpusher and Well Site Leader present. Spot the Pits Complex. At 0900 hrs, call CH2M Hill Dispatch and unable to get trucks. GC1 is having an emergency and all trucks are tied up. Peak has vac trucks available but no drivers due to all of them being tied up with rig moves. Nabors 4ES, Nabors 7ES, Nabors 27E and Nabors 3S all moving. At 1300 hrs, CH2M Hill Dispatch has two trucks for 4ES and they need three. Once 4ES is taken care of, they will start to get trucks for us. 13:00 - 20:00 7.00 RIGU P PRE Begin rigging up and connecting the Modules. Put steam and power around. At 1500 hrs, raise and scope the Derrick. Spot .and rig up hardline to the Tiger Tank. MU double annulus to IA. Rig up kill manifold in cellar and connect lines. Accept Rig at 1700 hrs on 4-11-09. 20:00 - 22:30 2.50 WHSUR N FLUD DECOMP Wait on trucks from GC1 shutdown and 4ES well kill operations. Trucks free at 2030 hrs. Trucks enroute to load kill fluid from MI mud plant. 22:30 - 23:30 1.00 WHSUR P DECOMP PU lubricator and MU to wellhead. Pressure test to 500 psi with diesel. Pull BPV with Wells Su orts. Initial pressures: TBG = 750 psi, IA = 740 psi, OA = 0+ psi. LD lubricator. Secure wellhead. 23:30 - 00:00 0.50 WHSUR N FLUD DECOMP Continue to wait on vac trucks from Prudhoe. 4/12/2009 00:00 - 03:30 3.50 WHSUR N FLUD DECOMP Continue to wait on vac trucks with 9.3 ppg kill fluid. 1st truck on location at 0030 hrs and 2nd truck on location at 0330 hrs. 03:30 - 04:30 1.00 WHSUR P DECOMP Conduct weekly safety meeting. Focus on IADC reports, procedures and hydraulic injection. 04:30 - 06:00 1.50 WHSUR N FLUD DECOMP Continue to wait for the final 2 vac trucks of 9.3 ppg kill fluid. 06:00 - 06:30 0.50 WHSUR P DECOMP Third load of 9.3 ppg brine arrives on location. Continue to wait for the fourth load to start well kill. Pre-tour checks and service Printed: 4/20/2009 12:12:32 PM • BP EXPLORATION Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Start: 4/9/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2009 Rig Name: NABOBS 3S Rig Number: Date ~ From - To Hours Task. ,Code N'PT Phase. Page 2 of 5 Spud Date: 10/15/2001 End: 4/16/2009 Description of Operations 4/12/2009 06:00 - 06:30 0.50 WHSUR P DECOMP the Rig. 06:30 - 07:30 1.00 KILL P DECOMP Take on heated 9.3 ppg brine into the Pits. Top off Pits. 07:30 - 08:00 0.50 KILL P DECOMP Fill lines and pressure test surface equipment to 3,500 psi - OK. Pressure test downstream line to the Tiger Tank to 500 psi - OK. 08:00 - 09:00 1.00 KILL N DECOMP Continue to wait on last load of 9.3 ppg brine. Delayed even more than normal due to drifted in roads in Prudhoe. 09:00 - 09:30 0.50 KILL N DECOMP Last load arrives on location. Spot on the pad ready to go. 09:30 - 10:00 0.50 KILL P DECOMP Hold pre-kill safety meeting with crew and CH2M Hill truck drivers. 10:00 - 14:00 4.00 KILL P DECOMP O en well to closed Choke. Tubin = 730 si , IA = 730 si , OA = 0 psi. Bleed gas off the IA down to 130 psi and the Tubing came down to 360 psi. Bleed gas off the Tubing down to 220 psi and the IA came down to 230 psi. Break circulation with 9.3 ppg brine at a rate of 4 bpm / 1,700 psi. The IA went from 200 psi to 430 psi. Pump a total of 115 bbls with 100 bbls bullhead 100 bbls of 9.3 ppg brine into the formation at a rate of 4 bpm / 2,100 psi with the IA increasing from 920 psi to 1,620 psi. Open the Choke and resume circulating the long way until clean brine observed on surface. Circulate at 4 bpm with final pressures of 1,720 psi on the Tubing and 110 psi on the IA. Pumped 630 bbls until 9.3 ppg returns observed on surface. Total fluid circulated was 745 bbls with 670 bbls of returns on surface (90% returns . 14:00 - 15:00 1.00 KILL P DECOMP Monitor the well dead. IA on sli ht vacuum and the Tubing is static. 15:00 - 16:00 1.00 KILL P DECOMP Blow down all circulating lines and hardline to the Tiger Tank. 16:00 - 18:00 2.00 WHSUR P DECOMP PU T-bar and set 2-1/2" Tvge "H" TWC with FMC rep. mins - OK. Line u to um down the IA and ressure test the ', TWC from below by rollin the um at a rate of 2 b m / 500 si for 10 charted mins - OK. It took 5 bbls to catch fluid and a total of 25 bbls were injected into the formation. Blow down and RD test equipment and kill equipment. 18:00 - 19:00 1.00 WHSUR P DECOMP Bleed off low charge pressure from TWC test off IA. RD kill manifold. IA on went on vac. RU LRS to IA and gravity feed at 15 BPH. 19:00 - 20:00 1.00 BOPSU P DECOMP Bleed hanger void with FMC rep. ND tree and adapter flange and set in cellar. FMC rep checked hanger threads, good condition with 9.5 turns. 20:00 - 23:00 3.00 BOPSU P DECOMP NU DSA and BOPE. 23:00 - 00:00 1.00 BOPSU P DECOMP Conduct initial BOPE test 250 psi low / 3,500 psi high. Test witnessed by WSL and Tourpusher. AOGCC rep John Crisp waived the state's right to witness on 4-11-09 at 1600 hrs. Gravity feed IA with 9.3 ppg brine during test. 4/13/2009 00:00 - 02:30 2.50 BOPSU P DECOMP Continue ROPE test 250 psi low / 3,500 psi hight. Test with 2-7/8" test joint on 2-7/8" x 5" VBR and annular preventer. Complete Koomey draw down test. Blow down lines and suck out BOP stack. 02:30 - 04:00 1.50 BOPSU P DECOMP PUMU Opso-Lopso and lo-torque with lubricator and MU to tubing hanger. RU Wells Support lubricator and P/T to 500 psi. Pull TWC. Tubing and IA on vac. LD lubricator and Printed: 4/20/2009 12:12:32 PM • BP EXPLORATION Page3of5~ Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 4/9/2009 End: 4/16/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2009 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase i Description of Operations 4/13/2009 02:30 - 04:00 1.50 BOPSU P DECOMP Opso-Lopso. Clear rig floor. 04:00 - 06:00 2.00 PULL P DECOMP PU landing joint with TIW valve and screw into hanger. Monitor IA for 15 minutes thru 2", IA on vac. BOLDS with FMC rep: OK less than 80% tensile strength including block weight). Lower hanger below bag and MU circulating hose. Circulate 108 bbls at 3.5 BPM / 1150 psi (tubing volume). Lost 18 bbls during circulation (84% returns). Confer with day WSL on how to proceed with pulling hanger. 06:00 - 06:30 0.50 PULL P DECOMP Pre-tour checks and service the Rig. 06:30 - 07:00 0.50 PULL P DECOMP Pull the Hanger off seat with PUW = 120K. Pull the Hanger to the Floor with PUW = 110K. Line up to circulate down the Tubing up the IA. Spot the Hanger below the Annular. 07:00 - 09:30 2.50 PULL P DECOMP Circulate bottoms up with 9.3+ ppg brine at a rate of 4 bpm / 1,500 psi with returns to the Pits. Pumped a total of 600 bbls with 41 bbls lost Burin the circulation (-7% losses). 09:30 - 10:30 1.00 PULL P DECOMP Monitor the well. RD circulating hose. 10:30 - 11:30 1.00 PULL P DECOMP Break out and lay down Tubing Hanger and Landing Joint with FMC rep. 11:30 - 12:30 1.00 PULL P DECOMP Pump 50 bbls of 9.4 ppg brine down the Tubing to ensure we won't pull wet (well is out of balance). Circulate with returns to the Pits at a rate of 3 bpm / 750 psi. RD circulating equipment. Tubing on vacuum and IA on slight vacuum. 12:30 - 19:30 7.00 PULL P DECOMP POOH with existin 2-7/8" ESP Com letion standin~back_ ir) 19:30 - 20:30 ~ 1.00 ~ PULL ~ C 20:30 - 22:00 I 1.50 I PULL I C 22:00 - 00:00 I 2.001 PULL I C 4/14/2009 ~ 00:00 - 02:00 ~ 2.00 PULL ~ C 02:00 - 09:00 I 7.001 PULL I P 09:00 - 11:00 I 2.001 PULL I P 11:00 - 19:30 I 8.501 PULL I P the Derrick. Maintain continuous hole fill with 9.4+ppg brine while POOH. Hourly losses averaging 8 bbls per hour. Increase weight in mud pits to 9.48 ppg. Changeout reels at 1730 hrs. POH with 2-7/8" tubing, 60 stands pulled at 1930 hrs. DECOMP Confer with town engineer about weight up entire system from 9.3+ ppg to 9.6 ppg to compensate for resevoir pressure build rate. Call Mud engineer to assist. DECOMP Wei ht u its from 9.4+ to 9.6 b adding NaCI thru hopper in preparation to circulate to displace. DECOMP Break circulation with 9.6 ppg brine at 3.5 BPM / 700 psi down tubing while weighting up returns to 9.6 ppg with Mud engineer. Able to maintain circulation with out shutting down pump and mixing in NaCI on the fly, bringing returns up to 9.6 ppg while maintaining 9.6 ppg circulating in continuously. DECOMP Continue circulating 9.6 ppg down tubing and mixing in NaCI on the fly to returns to bring up to 9.6 ppg. During displacement returns ranged from 9.2+ ppg to 9.6 ppg. Final circluation 4 BPM / 1150 psi. Circulated 687 bbls and lost 77 bbls (89% returns . Mixed a total of 279 sacks. Good 9.6 ppg all the way around. Monitor well for 20 min -well visibly on vac. Blow down lines. DECOMP POH with 2-7/8" tubing standing back in Derrick. Maintain continuous hole fill, loss rate is -15 BPH. Inspect tubing for corrosion and scale build up. DECOMP Stop with 172 stands out of the hole. Change out ESP reels to final one needed to finish POOH. Call out Milne Point loader to remove due to weight. DECOMP Continue POH with existing 2-7/8" ESP completion. Losses Printed: 4/20/2009 12:12:32 PM • BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To MPF-94 MPF-94 WORKO NABOB NABOB 'Hours VER S ALASK S 3S Task DRI ~ Code LING NPT Start I Rig Rig I Phase. Spud Date: 10/15/2001 : 4/9/2009 End: 4/16/2009 Release: 4/16/2009 Number: Description of Operations 4/14/2009 11:00 - 19:30 8.50 PULL P DECOMP averaging 15 bbls per hour with 9.6 ppg brine. BOLD jewlery. Pulled a total of 572 joints, 3 GLM's, 1 XN assembly, 384 LaSalle clamps, 5 protectalizers and 3 flat guards. Tubing in ood condition. 10' pup above XN nipple and 10' pup above pump have external corrosion and pitting on coupling and pipe body. LD pups to be replaced. 19:30 - 22:00 2.50 PULL P DECOMP Tail cable over sheave to spooling unit. Break down and drain ESP assembly with Centrilift rep. Discharge head spline shaft sheared and laying in top of Pump section, found quarter sized rock and metal fra ments in connection bowl. Take pictures and send to town. Take sample of Sands from ESP for Milne Pt. analysis. 22:00 - 23:00 1.00 BUNCO P RUNCMP RU floor to RIH with tubing and ESP assembly. RD ESP containment trunk and load new pump in pipe shed. 23:00 - 00:00 1.00 BUNCO P RUNCMP PUMU new ESP assembly with Centrilift. Loss rate during RD and ESP make up is 10 BPH. 4/15/2009 00:00 - 02:00 2.00 BUNCO P RUNCMP Continue to MU ESP assembly with Centrilift rep. Loss rate = 10 BPH. 02:00 - 10:00 8.00 BUNCO P RUNCMP RIH with 2-7/8" tubin out of Derrick. Install LaSalle clamps on every joint for first 6,000' then every other joint. Check conductivity every 2,000' and flush pump with 10 bbls at .5 BPM / 660 psi. Use Best-O-Life pipe dope on all connections, MU torque = 2,300 ft-Ibs. Loss rate = 7 BPH. 127 stands in hole at 1000 hrs. 10:00 - 13:30 3.50 BUNCO P RUNCMP Changeout reels. Centrilift make reel to reel splice. Check conductivity. 13:30 - 21:30 8.00 BUNCO P RUNCMP Continue to RIH with 2-7/8" tubing out of Derrick. Install LaSalle clamps on every other joint. Check conductivity every 2,000' and flush pump with 10 bbls at .5 BPM / 750 psi. Use Best-O-Life pipe dope on all connections, MU torque = 2,300 ft-Ibs. Loss rate = 7 BPH. 250 stands in hole at 2130 hrs. 21:30 - 00:00 2.50 BUNCO P RUNCMP Changeout reels in spooler unit. Conduct ESP reel to reel splice. Check conductivity. Continue pumping across top of hole loss rate = 7 BPH. Tourpusher conducted safety meeting on 3 competencies with rig crew. 4/16/2009 00:00 - 00:30 0.50 BUNCO P RUNCMP Finish ESP reel to reel splice with Centrilift rep. 00:30 - 02:30 2.00 BUNCO P RUNCMP RIH with 2-7/8" tubing out of Derrick. Install LaSalle clamps on every other joint. Use Best-O-Life pipe dope on all connections, MU torque = 2,300 ft-Ibs. Loss rate = 7 BPH. MU circulating pin and pump 10 bbls down tubing for final rate and pressure = .5 BPM / 750 psi. Ran a total of 572 joints, 3 GLM's, 1 XN ass'y, 386 LaSalle clamps, 5 protectalizers and 3 flat guards. 02:30 - 03:30 1.00 BUNCO P RUNCMP PU landing joint and MU to tubing hanger with FMG rep. MU tubing hanger to string and install ESP penetrator. 03:30 - 05:00 1.50 BUNCO P RUNCMP Make final penetrator splice to tubing hanger with Centrilift rep. Final checks on ESP cable: BHP = 3635 psi, BHT = 176.4 degF, phase to phase = 6.7 ohms, phase to ground = 300 meg ohms. 05:00 - 05:30 0.50 BUNCO P RUNCMP Final wei hts: PUW = 95K, SOW = 30K. Land tubing hanger and RILDS with FMC. 05:30 - 06:00 0.50 BUNCO P RUNCMP PU T-bar and d rod TWC in tubin han er with FMC. 06:00 - 08:00 2.00 BOPSU P RUNCMP Rig up circ hose. Test TWC from below at 3 BPM / 500 psi Printed: 4/20/2009 12:12:32 PM BP EXPLORATION Page 5 of 5 Operations Summary Report I'Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 4/9/2009 End: 4/16/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2009 Rig Name: NABOBS 3S Rig Number: Date ,From - To i Hours ', Task i Code NPT i Phase Description of Operations 4/16/2009 06:00 - 08:00 2.00 BOPSU P RUNCMP charted for 10 min (pumped 26 bbls and recovered 5 bbls back to its for 21 bbls in'ected . Drain stack an blow down lines. 08:00 - 13:00 5.00 BOPSU P RUNCMP ND BOPE and lay over in cradle. Pull cradle out of cellar. D DSA from wellhead. 13:00 - 15:00 2.00 WHSUR P RUNCMP NU tree and adapter flange. Centrilift conduct final checks: BHP = 3609 psi, BHT = 179 degF, phase to phase = 6.7 ohms, phase to ground = 300 meg ohms. 15:00 - 16:30 1.50 WHSUR P RUNCMP Test hanger void with FMC to 5,000 psi for 30 min -passed. Test tree with diesel to 5,000 psi for 5 min -charted. 16:30 - 17:30 1.00 WHSUR P RUNCMP PUMU lubricator with Wells Support and test to 500 psi with diesel. Pull TWC. Set BPV with lubricator. Final pressures: TBG =vac, IA, =vac, OA = 0 psi. 17:30 - 18:00 0.50 WHSUR P RUNCMP Remove double annulus. Release rig at 1800 hrs on 4-16-09. Printed: 4/20/2009 12:12:32 PM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regg(a~alaska.gov doa.aogcc. prudhoe.bayCa~alaska.gov bob.fleckenstein(a)alaska.gov Contractor: Nabors Rig No.: 3S DATE: 4/13/2009 Rig Rep.: J. Greco / J. Fritts Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. Hoffman / V.Volpe Field/Unit & Well No.: MPF-94 PTD # 2011700 Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8-2 1/16" P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector F P H2S Gas Detector F P Test Results Number of Failures: 0 Test Time: 3.5 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: iim.regg(a~alaska.gov Remarks: Test Against 2 Way Check valve /Test w/ 2 7/8" test L CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1750 P 200 psi Attained 32 sec P Full Pressure Attained 2 min 32 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 1975 psi FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P 24 HOUR NOTICE GIVEN YES x NO Date 04/11/09 Time 1700 hrs Waived By John Test start 2300 hrs Finish BOP Test (for rigs) ~"`~" ° ~ ~ h~~i BFL 11/14/07 ~~~~ ~~~~ ~~~ Witness J. Fritts / V. Nabors 3s BOP Test MPF-94 4-13-2009 .xls STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~D9 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated ~ ~Iher„Q ACI ' ATMENT- Performed: ~' " Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time ExtensiAorl~ ~0/d ~ ~~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended VI/~fl l~ry, ~ ~~ISS! 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory 201-1700. 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23040-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 44.33 KB ~ MPF-94' 8. Property Designation: 10. Field/Pool(s): ADLO-355016 - MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 18595 feet Plugs (measured) None true vertical 7852.97 feet Junk (measured) None Effective Depth measured 18469 feet true vertical 7730.04 feet Casing Length Size MD TVD Burst Collapse Conductor 112 20" Surface - 112 Surface - 112 Surface 10307 10-3/4" 45# L-80 Surface - 103451 Surface - 4454 5210 2480 Production 185230 7" 26# L-80 Surface - 18555 Surface - 7 814 7240 5410 + - ~`,;~~r3til~~ iY1~~ ~. `a L,UU Perforation depth: Measured depth: 18290 - 18292 _ _ _ _ True Vertical depth: 7556.74 - 7558.67 _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 18055' 4-1/2" 12.6# L-80 18146' - 18193' Packers and SSSV (type and measured depth) 7"X4.5" BAKER PREMIER PKR 18155' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions inGuding volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 438 93 626 376 Subsequent to operation: 478 99 706 242 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development - Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas r WAG ~ GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 2/23/2009 Q Form 10-404 Revised 04/2006 "~ ~" ~ "~" ~ " ~~~~~' ~. ~~ Submit Original Only c~-~ MPF-94 201-170 PERF ~TTArHMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-94 11!25/01 PER 18,290. 18,292. 7,556.74 7,558.67 MPF-94 12/1/01 APF 18,328. 18,330. 7,593.38 7,595.31 MPF-94 12/9/01 APF 18,325. 18,328. 7,590.48 7,593.38 MPF-94 12/9/01 APF 18,330. 18,335. 7,595.31 7,600.13 MPF-94 12/9/01 RPF 18,328. 18,330. 7,593.38 7,595.31 MPF-94 12/10/01 APF 18,300. 18,310. 7,566.38 7,576.02 MPF-94 1/27/02 FIL 18,331. 18,335. 7,596.27 7,600.13 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • MPF-94 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/13/2009f Freeze Protect Flowline. Pumped 3 bbls 60/40 methanol down lateral line. ;Closed lateral valve and bleed pressure down to 0 psi. , 2/15/2009 ~ CTU# 9 Add pipe 2/16/2009 CTU #9 1.75" CT.«interact publishing» finish spooling on extra pipe, Travel to Milne Point. Pump 1.25" ball. Perform weekly BOP test. MU/RIH w/ 1.75" JSN. Tag ESP pumg~g 18013'. start Bumping gel swee~**job :continued on WSR 12-17-09** 2/17/2009: continued from WSR 02-16-09 «interact publishing» Continue RIH w/ 1.75" JSN to top of ESP pump @ 18013' pump 21 bbl geovis sweep and 'chase to surface. RBIH w/ choke closed. Tag pump @ 18016' (ctm up). Park @ 18016'. Circ 20 bbl of 10% HCL to nozzle. Lay in wellbore. pull to safety @ 14291'. Pump 7 bbls acid. Start pump in reverse, then forward. pump. Displace remaining acid across pump. Soak acid. Line out to flowback tank. Start pump in reverse, then forward. Pump looks good. ,POOH w/ coil, pumping remaining freeze protect on coil. At surface ..continue to flow back acid. flowing well to plant at end of day. "*job complete** (rig down continued on 02-18-09) FLUIDS PUMPED BBLS 200 1% KCL 155 60/40 METH 21 10% ACID (TITRATION=10.3%, IRON <50 PPM) 21 GEOVIS 397 Total STATE OF ALASKA ~~'~~,~`~~~ ~ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS /~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Other Q ACID TREATMENT. 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. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 201-1700 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-23040-00-00 7. KB Elevation (ft): 9. Well Name and Number: 44.33 KB - MPF-94 8. Property Designation: 10. Field/Pool(s): ADLO-355016 ' MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 18595 ' feet Plugs (measured) None true vertical 7852.97 - feet Junk (measured) None 4~~~~ ~~~~ ~ ~a~ ~~,1_ Effective Depth measured 18469 - feet true vertical 7730.04... feet Casing Length Size MD TVD Burst Collapse Conductor 112 20" Surface - 112 Surface - 112 Surface 10307 10-3/4" 45# L-80 Surface - 103451 Surface - 4454 5210 2480 Production 18523 7" 26# L-80 Surface - 18555 Surface - 7814 7240 5410 Perforation depth: Measured depth: 18290 - 18292 _ _ True Vertical depth: 7556.74 - 7558.67 = _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE -18055' 4-1/2" 12.6# L-80 18146' - 18193' Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER PREMIER PKR 18155' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 402 76 336 248 Subsequent to operation: 404 78 341 253 14. Attachments: 15. WeII Class after proposed work: Copies of Logs and Surveys Run EXplOratOry ~ Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ ~ Gas ~~ WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 12/8/2008 Form 10-404 Re4ised 0412006 '"'~;~ f ~~;~ : ~ ..._ ~~~ ~ Submit Original Only MPF-94 201-170 PERF ~TTO[:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-94 11/25/01 PER 18,290. 18,292. 7,556.74 7,558.67 MPF-94 12/1/01 APF 18,328. 18,330. 7,593.38 7,595.31 MPF-94 12/9/01 APF 18,325. 18,328. 7,590.48 7,593.38 MPF-94 12/9/01 APF 18,330. 18,335. 7,595.31 7,600.13 MPF-94 12/9/01 RPF 18,328. 18,330. 7,593.38 7,595.31 MPF-94 12/10/01 APF 18,300. 18,310. 7,566.38 7,576.02 MPF-94 1/27/02 FIL 18,331. 18,335. 7,596.27 7,600.13 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • MPF-94 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~r , ,~ ~ ~.r 11/23/2008?CTU #9 w/ 1.75" OD CT. MIRU CTU. MU and RIH with 1.75" OD JSN. Tag ~TD @ 17993' (CTM -up). Pump 20 bbl Geovis pill. Continued on 11/24/08 'WSR. I _ _ _ __ _ _ _ ___ ( 11/24/2008 CTU #9 w/ 1.75" OD CT. Continued from 11/23/08 WSR. Interact publishing = no. Jet 20 bbls of Geovis on tag @ 18005 (ctm dn). Chase out w/ XS KCL. ~ RBIH to .Establish infectivity of -0.15 bpm at 920 psi ;through ESP. Spot 21 bbls 15% HCL acid on top of ESP. Squeeze 5 bbls F acid through ESP and allow to soak for approximately 3 hours. Infectivity [increased to 0.4 bpm at 935 psi. Centralift attempts to start ESP -starts both 1 'in reverse and forward. As per Centralift, continue to squeeze acid through ;ESP in stags both with ESP turning and ESP not turning. shutting down to let each stage soak. After complete acid displacement through ESP, POOH, allowing acid to soak. Prep to flow back well. Continued on 11/25/08 WSR. E 11/25/2008~CTU #9 w/ 1.75" OD CT. Continued from 11/24/08 WSR. Flowback acid by ;running ESP. Divert to facilities when pH reaches acceptable levels. Blowdown reel with N2. RDMO CTU. Leave well online with ESP flowing to facility. Job complete. FLUIDS PUMPED BBLS 21.4 15% HCL ACID 141 METHM/ATER 261 1 %KCL W/XS 8 N2 431.4 Total STATE OF ALASKA ~'~~~Ol~ A~ OIL AND GAS CONSERVATION COM~ION MAY 2 2 2008 REPORT OF SUNDRY WE PERATI N LL O O ~iasica Oil ~ Gas Cons. Commission 1. Operations Performed: ^ Abandon ®Repair Well. ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing, ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ~ ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-170 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23040-00-00 - 7. KB Elevation (ft): 44.33' ~ 9. Well Name and Number: MPF-94 8. Property Designation: 10. Field /Pool(s): - ADL 355016 ' Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 18595 ~ feet true vertical 7853 - feet Plugs (measured) None Effective depth: measured 18469 - feet Junk (measured) None true vertical 7730 - feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 10307' 10-3/4" 10341' 4454' 5210 2480 Intermediate Production 18523' 7-5/8" 18555' 7814' 6890 4790 Liner ~~r~ auN ~ 200 Perforation Depth MD (ft): 18290' - 18335' Perforation Depth TVD (ft): 7557' - 7600' 2-7/8", 6.5# L-80 18055' Tubing Size (size, grade, and measured depth): a-72" ~2~# ~ -Rn ' Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker Premier Packer 18155' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Sbl Casin Pressure Tubin Pressure Prior to well operation: 440 199 451 294 320 Subsequent to operation: 529. 322 873 340 294 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ff C.O. Exempt: Contact Nick Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist ~~~ Prepared By ~~ ~~ nature Phone 564-4750 Date 7 5b4 Sondra Stewm -4750 L- Form 10-404 Revised 04/2006 J Submit Original Only ~~ ~ ~ 1 ~ ~P, ~, ,s ~~: ~tul~~ ~ 200 ,~ ~~~~ Tree_ 2 9/16" - 5M CIW ~ M p F ~~JL+, ~g Elev. = 44` (N-27E) Wellheads 11" Gen 5 FMC ~~~ L Elev. = 11' 11 x 2 9/16" Hgr, w/ 2 7/8" N T&B, RT to Tbg. Spool = 33.0` (N-27E) & 2.5" Type 'H' BPV Profile 112' ~ 10 3/4" Halliburton ES Cementer 2493' KOP @ 500' to 3100' Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' 10 3/4", 45#/ft., L-80 BTC 10,341' Camco 2-7/8" x 1" 138` KBMM GLM Camco 2-7/8" x 1" 14,971' KBMM GLM Camco 2-7/8" x 1" 17,804` KBMM GLM 2-7/8" XN nipple 17,957` (ID 2.205") 2 7/8" 6.5 ppf, L-80 8 rd. EUE tubing GPDIS Pressure Head & 17,999° (drift ID = 2.347", cap = 0.00592 bpf) Centrilift ESP, SXD 137-P17 17 998' 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6,151 ", cap. = 0.0383 bpf) (cap w/ 2 7/8" tbg = .0302 bpf) Gas Separator GRSFTX AR H6 (400 Internals) 1 8,01 8` Stimulation Summary 12/11/01 Frac - 117,298# of 16/20 C/lite 73,740# of 12/18 C/lite behind pipe. Perforation Summary Ref. Log, SWS anadrill CDR resistivity. .~arAH ~n/~~/n~ Size SPF Interval TVD 2.5" 4 18290`-18292' 7551'-7552' 2.5" 4 18328'-18330' 7594'-7595' 3-3/8" 12 18300'-18310' 7567'-7576' 3-3/8" 12 18325'-18335' 7591'-7600' Tandem Seal Section 18,023` GS83D6 UT/LT SB/SB PFSA CLS Motor, 152 HP, 2325 volt, 40 amp, KMH 1$,037` Pumpmate XTO w/ 6 Fin Centralizer 18,051 ` 7" x 4.5" Baker Premier pkr. 18,155' 4.5" HES XN-Nipple (3.813") 18,181' (No-go 3.75" id) 4 1/2" WLEG 18,193' (PBTD) 18,466' 7" Float Collar 18,469' 7" Float Shoe 18,554' DATE 1 REV. BY I COMMENTS i ~vn/v_i civet unn ana run rrac smug. rv-ut 12/11/01 M. Linder Perf with coil and Frac with D.S. 02/08/02 MDO ESP Completion 4-ES 02/26/05 Lee Hulme ESP Re-Com letion 4-ES 02/08/06 Lee Hulme ESP Re-Completion 3S 12/9/07 Lee Hulme ESP Re-Completion 4ES REH 4-25-08 ESP Re-Completion Nabors 3S MILNE POINT UNIT WELL MPF-94 (,SUP) API No. 50-029-23040 BP EXPLORATION (~) Digital Well File Page 1 of 1 • • Well: MPF-94 Well History Well Date Summary MPF-94 4/13/2008 T/I/0=300/280/180 (Infectivity test /Freeze protect) -Pump down tbg w/30 bbls diesel, freeze protected flow line to production header w/3 bbls neat methanol & flow line to test header w/3 bbls neat methanol. Verify casing valves open to gauges, tag well & notify operator. Fina! WHP's=400/300/40 MPF-94 4/14/2008 ***WELL S/I ON ARRIVAL*** (rwo prep) RUNNING IN HOLE W/ DUAL SPARTEK GAUGES ***CONT ON WSR 4-15-08*** MPF-94 4/14/2008 Flush Flow line (Pre-RWO) -Pumped flow line to production header w/6 bbls 125* diesel & 3 bbls 60/40 methanol. Verify casing valves open to gauges, tag well & notify operator. MPF-94 4/15/2008 ***CONT FROM WSR 4-14-08*** (rwo prep) RIH W/ DUAL SPARTEK GAUGES TO TOP OF ESP AT 17996' SLM (17978' MD) PULL UP TO 17994' SLM (17976' MD) FOR 3 HOUR STOP. PUH TO 17494' SLM (17476' MD) FOR 30 MIN GRADIENT STOP PULLED 1" BK-DGLV FROM 17784' MD, LEFT POCKET OPEN (LRS ASSISTED TOOLS DOWNHOLE) PULL 1" BEK-DPSOV FROM 117' MD, SET 1" BK-DGLV. ***JOB COMPLETE, ALL SLICKLINE DEPTHS DEEPER THAN MD*** MPF-94 4/15/2008 T/I/0=850/700/0 Assist Slickline (Pre-RWO) -Pumped tbg w/125 bbls 80*F dieseUcrude 50-50 mix to assist s-line getting down hole. Verify casing valves open to gauges & notify operator. S-line still on well. Final WHP's=650/600/0 ~ ~ C i MPF-94 4/16/2008 The Well Support Techs rigged up and set a BPV and then remove the wellhouse flowlines and foundation for upcoming RWO. NOTE: The Back Pressure Valve was left IN!!!!!! MPF-94 4/24/2008 SET 1" DGLV'S W/BK LATCHES IN GLM'S #1 AND #2. SET 1" DPSOV IN GLM #3 IN PIPE SHED. ALL MANDRALS MARKED AND DPSOV IS FLAGGED. MPF-94 4/26/2008 T/I/0=0/0/0. (Post RWO freeze protect). Freeze protect IA w/ 65 bbls crude. Freeze protect tbg w/ 15 bbls ~ ~ H /2 / ~ ` ~ crude. FW P=600 00 0. ~ ~ MPF-94 4/26/2008 Re-hooked installed foundation ,flowlines 3'2500 TO 590 ftlbs ,Wing 2 9/16 1500 TO 287 ftlbs. set well house, pulled BPV and PT flow lines to 5000 psi. Lead Mikulecky MPF-94 5/13/2008 Transport Scale Inhibitor treatment to Milne Point MPF-94 5/14/2008 T/I/0=250/400/120 (Scale Inhibitor treatment). Load IA w/ 200 bbls crude. Pump 27.6 bbls 03VM082 scale inhibitor followed by 252 bbls crude for tbg displacement &over-displacement. Turn well over to DSO. Leave well shut in for 4 hrs. FWHP=650/820/40. Print Date: 5/22/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfolReports/ReportViewer.aspx 5/22/2008 BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 4/21/2008 End: 4/26/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2008 Rig Name: NABOBS 3S Rig Number: Date 'From - To I, Hours Task Code NPT Phase Description of Operations - - __ 4/20/2008 (13:00 - 22:00 9.00 MOB PRE Rig released from MPJ-09 ~ 13:00 hrs. Prepare for rig move. 22:00 - 00:00 2.00 MOB 4/21/2008 00:00 - 01:30 1.50 MOB P 01:30 - 03:00 1.50 MOB P 03:00 - 06:00 3.00 MOB P 06:00 - 13:30 7.50 MOB P 13:30 - 15:00 1.50 MOB P 15:00 - 16:30 1.50 KILL P 16:30 - 17:30 I 1.001 KILL I P 17:30 - 18:00 I 0.501 KILL I P 18:00 - 22:30 4.501 KILL P 22:30 - 00:00 I 1.501 KILL I N 4/22/2008 ~ 00:00 - 01:30 1.50 ~ KILL ~ N 01:30 - 03:00 1.501 KILL P 03:00 - 03:30 I 0.501 KILL I P 03:30 - 06:00 I 2.501 KILL I N 06:00 - 10:00 I 4.001 KILL I N 10:00 - 14:00 I 4.001 KILL I P Scope down and lower derrick. Waiting on Peak Trucks. PRE Blow down all steam lines. Make all disconnects. Wait on Peak PRE Wait on Peak Trucks PRE Peak Trucks arrive on location. move pits and pipe shed. Move carrier off of MPJ-09 Ca? 02:30. PRE Depart MPJ-Pad and move rig to MPF Pad. Arrive on MPF Pad C~3 06:00 PRE MIRU carrier, pipe shed, and pits. Position all auxilliary and support equipment. PRE Raise and scope Derrick. Continure hooking up rig components. DECOMP "' Accept Rip @ 1500 "' Rig up on tree for well kill. RU hardline and tiger tank for flowback. Spot vac trucks and load pits with SW. DECOMP PUMU lubricator. Pressure test to 2000 psi with diesel. Pump open SSV, Pull BPV. Pressures: T / IA / OA - 900 / 1060 / 0 psi DECOMP Blow air through lines. Pressure test hardline to closed choke to 3500 psi. Test hardline downstream of choke to tiger tank to 500 psi. DECOMP Bleed IA pressure, came down to 60 psi building back to 160 psi. Line up and circulate 140 degree seawater down tubing, taking returns up IA through choke manifold out to tiger tank 3 bpm with 1,030 psi on tubing. Pumped 105 bbls and 72 bbls to tiger tank. Line up and Bullhead 140 degree seawater down tubing, 3 bpm at 1,750 psi. Pumped 125 bbls. Line up and pump down tubing taking returns up the IA through the choke manifold out to the tiger tank. Pumped 250 bbls at 3-1/2 bpm with 1,850 psi. Mud pump went down. RREP DECOMP Trouble shoot problem on mud pump. Oiler pump for gearend was not on allowing the gearend to overheat. Unable to open up pump to inspect gearend. Call for Little Red Pump truck. RREP DECOMP Hold PJSM with all personnel involved. R/U Little Red Services Pump truck and pressure test lines to 3,500 psi. DECOMP Pump down tubing using Little Red pumping unit, taking returns out IA through the choke manifold to the tiger tank. Pump 350 bbls of heat seawater 4 bpm at 1,850 psi. DECOMP Monitor well. Pressures built to and stablized 120 psi on the tubing and 130 psi on the IA. Call for 9.6 ppq Brine. DPRB DECOMP Wait on 9.6 ppg Brine. Bob Noble with AOGCC waive State's right to witness BOPE testing. DECOMP Centrilift bring remote panel and check SBHP - 3301 psi / -emw - 8.7 #/gal, 177 deg F. Prep for BOPE testing and pulling completion. Wait on Brine. DECOMP PJSM. Check WHP'S: Tbg / IA / OA - 50 / 20 / 0 psi. LRS pump 9.6#/gal brine ~ 1 bpm - 250 psi, 2 BPM - 550 psi, 3 BPM - 1100 psi, 4 BPM - 2000 psi, 4 1/2 BPM - 2500 psi. IA pressure to 450 psi, open choke taking returns. Gradually open choke reducing IA pressure as circulate in 9.6# Brine. Circulate 770 Bbls total with 625 Bbls returned. Losses ~ 19 %. Good 9.6#/gal fluid in an out. Flowcheck well. Tbg and IA Printed: 5/15/2008 9:19:55 AM BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 4/21/2008 End: 4/26/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task ,Code NPT Phase I Description of Operations 4/22/2008 10:00 - 14:00 4.00 KILL P DECOMP on STRONG vacuum. 14:00 - 15:00 1.00 WHSUR P DECOMP D rod TWC. Unable to test from below due to well on STRONG vaccum. Test from above to 3500 psi for 10 minutes and chart. 15:00 - 16:30 1.50 WHSUR P DECOMP ND Tree. Gravity feed 30 Bbls of 9.6 #/gal brine in IA every 1 hour. Check hanger threads by screwing in XO - 8 turns. 16:30 - 21:00 4.50 WHSUR P DECOMP NU DSA. PU / NU the BOPE. Hook up accumulator hoses, kill and choke lines. 22:00 - 23:00 1.00 WHSUR P DECOMP Function test BOPE and MU test joint. Gravity feed 18 bph in the IA. 23:00 - 00:00 1.00 WHSUR P DECOMP Test BOPE 250 / 3500 psi with 2-7/8" test joint. Test annular to 3500 psi. State's right to witness testing waived by Bob Noble. 4/23/2008 00:00 - 03:00 3.00 WHSUR P DECOMP Continue to test BOPE 250 / 3500 psi with 2-7/8" test joint. 03:00 - 05:00 2.00 WHSUR P DECOMP BO/LD test joint, blow down lines. Rig down test equipment. RU to pull completion. 05:00 - 06:00 1.00 WHSUR P DECOMP PU/MU Opso Lopso and lubricator, torque XO on bottom of OL. MU to tubing hanger. RU pump in sub with valve. PUMU lubricator, pull TWC, Tbg and la on vaccuum. RD lub and OL. 06:00 - 07:00 1.00 PULL P DECOMP RU elephant trunk and spooling unit. PUMU landing joint with TIW valve installed. Screw into hanger with 8 turns, BOLDS 07:00 - 08:30 1.50 PULL P DECOMP Pull han er to floor with 110K PUW. Broke back to PUW of 96K. Load hole with 37 Bbls of 9.#/gal brine. Equalize to tubing side and flow check well. Fluid falling clnwly„_en/I D tubing hanger and landing joint. 08:30 - 09:00 0.50 PULL P DECOMP ESP cable check: 5.4 ohms balanced phase to phase /infinity phase to ground. POH running ESP cable over shieve. Attach to spooling unit and POH 09:00 - 18:00 9.00 PULL P DECOMP POH w/ 2 7/8" ESP completion standing back tubing in Derrick. 18:00 - 18:30 0.50 PULL P 18:30 - 00:00 5.50 PULL P 4/24/2008 00:00 - 01:30 1.50 PULL P 01:30 - 05:30 4.001 PULL P 05:30 - 07:30 2.00 PULL ~ P 07:30 - 10:00 2.50 BUNCO 10:00 - 13:30 I 3.50 13:30 - 18:30 I 5.00 Bbls/hr . After 30 stands OOH, change spools in spooling unit. (1 hr) POH to stand 158 and change spool # 2 DECOMP Rig service and perform pre-tour checks. DECOMP Continue POH w/ 2-7/8" ESP completion standing back tubing in derrick from stand 158 to 266. DECOMP Continue POH w/ 2-7/8" ESP completion assembly standing tubing back in derrick from stand 266 to 286. Lay down 1 joint tubing with XN nipple and 10 foot pup joint. DECOMP Tail ESP cable over sheave in derrick, BO/LD ESP pump & motor assembly. Recovered 3 flatguards, 384 LaSalle clamps, 6 Protectolizers. 3 GLM's redressed by Schlumberger. DECOMP RD elephant trunk, clean and clear rig floor. RUNCMP Pull Cable over shieve in Derrick. PUMU ESP. Charge pump filling hole ~ 15 BPH. RUNCMP MU motor lead to ESP. Start RIH w/ ESP on 2 7/8" tubino from D rri k. Birdnest ESP cable spool. Work to untangle ESP cable on spool. Run 1st 26 stands in hole slowly as work ESP cable off of drum. LaSalle cable clamps on first 193 joints (-6000'). RUNCMP RIH C~? normal speed. Hole fill C~ 15 BPH. Tbg torque - 2300 ft-Ib /best of life pipe dope, check conductivity of cable every 2000', flush pump with brine every 2000ft. (1/2 BPM, 450 psi). RIH to stand 112, -7200' i Printed: 5/15/2008 9:19:55 AM ~ ~ \ ~ BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 4/21/2008 End: 4/26/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2008 Rig Name: NABOBS 3S Rig Number: i Date From - To Hours Task Code ! NPT ' Phase Description of Operations 4/24/2008 18:30 - 22:30 4.00 BUNCO RUNCMP Remove empty ESP cable spool from spooling unit and replace with full spool. Prep ESP cable ends and begin making splice. Charge pump filling hole C~3 15 bph. 22:30 - 00:00 1.50 BUNCO RUNCMP Continue Run ESP completion on 2-7/8" tubing from derrick, from stand 112 to 150. Check conductivity of cable and flush pump with brine 1/2 BPM, 450 psi. 4/25/2008 00:00 - 06:30 6.50 BUNCO RUNCMP Continue Run ESP completion on 2-7/8" tubing from derrick, from stand 150 to 217 at 05:30. Check conductivity of cable every 2000' and flush pump with brine 1/2 BPM, 1,000 psi. 234 Stands in hole ~ 06:30. 06:30 - 10:30 4.00 BUNCO RUNCMP Make reel to reel cable splice. Fill tubing and flush pump with 20 Bbls of brine (~ 1/2 BPM, 1000 psi. 10:30 - 12:00 1.50 BUNCO RUNCMP Cable splice done. Continue RIH from stand #234, reduce hole fill to 10 Bbls/hr as RIH. 12:00 - 12:30 0.50 BUNCO RUNCMP At crew change, while RIH w/ last stand of the tour, Driller was lowering stand and spooler operated put the spooler in reverse. This tensioned the ESP cable, pulling the spool forward in the spooling unit. It stretched 1 hydraulic hose until connection broke. Resulted in 2 gal leak of hydraulic oil in spooler. 12:30 - 13:30 1.00 BUNCO RUNCMP Inspected shieve, shackles, slings in derrick for ESP cable. Centrilift check out ESP cable. Notified MPU environmental and MPU well operations. Diverted hydraulic fluid from forward spooling reel, and RIH final 12 stands by hand spooling cable off of spool. Clamp totals: 5 Protectolators / 3 Armsterguards / 374 LaSalle clamps. 13:30 - 14:00 0.50 BUNCO RUNCMP PUMU landing joint with TIW valve. PUMU re-dressed tubing hanger. Final ESP cable checks - OK. PUW of 90K, SOW of 40K 14:00 - 16:00 2.00 BUNCO RUNCMP Make penetrator splice. Cable check: 6.2 ohms -phase to phase / 400 meg ohms- phase to ground / 3613 BHP / 170 deg F BHT 16:00 - 18:00 2.00 WHSUR P RUNCMP Land tubing. RILDS. Back out landing joint and TIW valve. O-LD landing joint and TIW valve. rod TWC. Test from above to 3500 si h rt for 10 minutes. 18:00 - 18:30 0.50 BUNCO RUNCMP Held team safety meeting, with Rig crew, Nabors Safety Rep, Toolpusher and WSL. Discussed high risk equipment check off procedure /listing for employees. 18:30 - 21:00 2.50 WHSUR P RUNCMP Blow down lines, drain BOP stack, unhook turnbuckles, pull riser, unhook koomey lines and N/D BOPE and place stack in cradle. Crew change, perform pre-tour checks. 21:00 - 23:00 2.00 WHSUR P RUNCMP NU tree and pressure test the Hanger void with FMC rep to 5,000 psi for 30 mins. witnessed by WSL. Test tree to 5,000 psi for 10 charted min. Centrilift tech took final reading, Intake pressure = 3510 psi, Temperature at motor = 170 deg F, Temperature of fluid = 175 deg F. 23:00 - 00:00 1.00 WHSUR P RUNCMP PUMU lubricator, WS techs pull TWC, set BPV. 4/26/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP Lay down lubricator and norm up tree. Riq released for move ~ 01:00 hrs. Printed: 5/15/2008 9:19:55 AM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: 3i~ reg~ ~~as(<_~_~@,>u ~i2e,.%3~` CC. E":3L{I:;3t~.~~~;'~E:~r~S~K'u'.~UJ l;?tFl7.f~°{~ ~r:3l:etf;i3"#>~C)?Ic3;~i~:~. t3;.s~ Contractor: Nabors Rig No.: 3S DATE: 4/23/2008 Rig Rep.: J.Greco/R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659- 4486 Operator: BP Op. Phone: 659- 4485 Op. Fax: 659-4628 Rep.: J.Menke/D.Rhodes Field/Unit & Well No.: MPU F-94 PTD # 2011700 Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTI ONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 NT Housekeeping: P Drl. Rig P Lower Kelly 1 NT PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13 5/8 5000 P Quantity Test Result Pipe Rams 1 2 7/8 x 5 P No. Valves 13 P Lower Pipe Rams Manual Chokes 1 P Blind Rams 1 Blind P Hydraulic Chokes 1 P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P ACCUMULATOR SYSTEM: Kill Line Valves 1 2 1/16" 5000 P Time/Pressure Test Result Check Valve 0 NA System Pressure 3000 P Pressure After Closure 1600 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 27sec P Trip Tank P P Full Pressure Attained 2 min 33 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4@1950 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 4 Hours Components tested ALL Repair or replacement of equ ipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: "i3;:.€e~ ~ ~I~ESka. ~;v Remarks: 24 HOUR NOTICE GIVEN YES X NO Waived By John Cris Date 04/23/08 Time 0700 hrs Witness R.B~orhus / D.Rhodes Test start 23:30 Finish 0330 hrs BOP Test (for rigs) ~~1-t MQ~ s ~ ~~~~ BFL 11/14/07 1~ Nabors 3S BOP Test MP F-94 4-23-08.x1s STATE OF ALASKA ALA OiL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 'r~~~~ ~ ~ ~~~~ 1. Operations Performed: • ~° ` - ^Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ~ ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number:~v BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-1700@'' ~y~p 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23040-00-00 7. KB Elevation (ft): 44 33' ~ 9• Well Name and Number: . MPF-94 8. Property Designation: 10. Field /Pool(s): ~;( ~~/ ADL 355016 ~ Milne Point Unit / Kuparuk River Sands` /./E - ~~ 11. Present well condition summary Total depth: measured 18595 feet true vertical 7853 i feet Plugs (measured) None Effective depth: measured 18469 feet Junk (measured) None true vertical 7730 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 10307' 10-3/4" 10341' 4454' 5210 2480 Intermediate Production 18523' 7-5/8" 18555' 7814' 6890 4790 Liner t~~ JAS ~ ~ 208 Perforation Depth MD (ft): 18290' - 18335' Perforation Depth TVD (ft): 7557' - 7600' 2-7/8", 6.5# L-80 18067' Tubing Size (size, grade, and measured depth): a-12^_ 12fi# i -Rn - Packers and SSSV (type and measured depth): 7" x 4-1 /2" Baker Premier Packer 18155' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 467 205 398 300 285 Subsequent to operation: 427 108 429 300 282 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number. ~ ignature Phone 564-4750 Date ~ 1q LO Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~ ~~°~, ,i~3 ~ tj, jD~h Submit Original Only ~ ~~<~l~ jfee: 2 9/16" - 5M CIW M p F~ O~ Elev. = 44` (N-27E) Wellhead: 11" Gen 5 FMC Ori L Elev. = 11' 11 x 2 9/16" Hgr, w/ 2 7/8" NSCT T&B, RT to Tbg. Spool = 33.0` (N-27E) & 2.5" Type 'H' BPV Profile 112` 10 3/4" Halliburton ES Cementer 2493` KOP @ 500' to 3100` Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900` 10 3/4", 45#/ft., L-80 BTC 10,341' Camco 2-718" x 1" 117` KBMM GLM Camco 2-7/8" x 1" 14,950` KBMM GLM Camco 2-7/8" x 1" 17,784` KBMM GLM 2 7/8" 6.5 ppf, L-80 8 rd. EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) (cap w/ 2 7/8" tbg = .0302 bpf) Stimulation Summary 12/11/01 Frac - 117,298# of 16/20 C/lite 73,740# of 12/18 C/lite behind pipe. Perforation Summary Ref. Loa SWS anadrill CDR resistivity. datr~rl 1(1/17/n1 Size SPF Interval TVD 2.5" 4 18290`-18292' 7551 `-7552' 2.5" 4 18328'-18330' 7594`-7595' 3-3/8` 12 18300'-18310' 7567'-7576' 3-3/8" 12 18325'-18335' 7591'-7600' 2-7/8" XN nipple 17,936` (ID 2.205") MS-1 Pressure Head & 17,97$` GPXHVDIS Discharge Head Tandem Pump, 82GC2900 & 112GC2900 GPMTAR 1:1 17,981 ` Gas Separator 18 022, GRSFTX AR H6 (400 Internals) ~ Intake = 7299' TVD Tandem Seal Section 18,027` Motor, 195 HP, 2177 volt, 53 amp, KMH-A (rested) 18 041 ` GS63D6 UT/LT FER HL SSCV SB/SB PFSA CLS Phoenix XT-1 18 063` w/ 6 Fin Centralizer 18063` MD = 7338' TVD 7" x 4.5" Baker Premier pkr. 18,155' 4.5" HES XN-Nipple (3.813") 18,181` (No-go 3.75" id) 4 1/2" WLEG 18,193` (PBTD) 18,466' 7" Float Collar 18,469` 7" Float Shoe 18,554' DATE REV. BY COMMENTS 11/21/01 BMH Drill and run frac string. N-27E 12/11/01 M. Linder Perf with coil and Frac with D.S. 02/08/02 MDO ESP Completion 4-ES 02126/05 Lee Hulme ESP Re-Com letion 4-ES 02/08/06 Lee Hulme ESP Re-Completion 3S 12/9/07 Lee Hulme ESP Re-Completion 4ES MILNE POINT UNIT WELL MPF-94 (KUP) APF No_ 50-029 23040 BP EXPLORATION (AK) • • __ BP EXPLORATION Page 1 of 3 Qperations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 12/7/2007 End: 12/10/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date. I From - To ~ Hours Task I Code ~ NPT Phase I Description of Operations 12/6/2007 04:00 - 07:00 3.00 RIGD P PRE PJSM. Rig down rig and rig components, scope down and lay over derrick. 07:00 - 10:00 3.00 MOB P PRE PJSM. Conduct temporary building site assessment with regard to camp, come to agreement with drill site operator, Milne Pt Safety, Nabors Toolpusher and BP WSL on best placement for camp, move rig & rig components, & spot camp. 10:00 - 13:00 3.00 RIGU P PRE PJSM. Spot sub, rig up rig components, spot tiger tank, raise and scope up derrick, rig up lines. Rig accepted @ 13:00 hrs, 12/06/2007. 13:00 - 13:30 0.50 KILL P DECOMP PJSM. Rig up lines to tiger tank. 13:30 - 16:00 2.50 KILL P DECOMP PJSM. Pick up lubricator, pressure test lubricator to 3000 psi, OK. Pull BPV. SITP @ 700 psi, SICP @ 1160 psi. O/A @ 150 psi. 16:00 - 17:30 1.50 KILL P DECOMP Pre well kill meeting with all involved parties. Notify Milne Pt of impending gas venting operation, no restrictions. Bleed gas off tubing, OK. Line up to pump heated seawater down tubing, taking returns up the I/A, thru the choke, thru the micro motion meter and to the tiger tank, keeping the pressure on the line down stream of the choke under 350 psi. Circulate @ 3 bpm, 1600 psi, holding 1200 psi back pressure on the I/A. Pump 105 bbls, shut in and bullhead 40 bbls @ 1 bpm / 800 psi. Open back up and circulate 25 bbls, then shut in and monitor SITP. 17:30 - 18:00 0.50 KILL P DECOMP PJSM. Monitor well. SITP stabalized @ 330 psi. Calculate kill wt fluid with a 150 - 200 psi overbalance @ 9.8 ppg brine, order 9.8 brine from MI mud plant. 18:00 - 23:30 5.50 KILL P DECOMP PJSM. Held crew change and performed pre-tour checks. Continued to circulate heated seawater @ 3 bpm. Casing pressure 1550 psi - 1820 psi. Tubing pressure 960 psi - 900 psi. Pumped total of 1140 bbls heated seawater through GLM at 17,784'. OA pressure 150 psi - 600 psi. 23:30 - 00:00 0.50 KILL P DECOMP Shut down pump and monitored well. (SITP 610 psi. 12/7/2007 00:00 - 03:00 3.00 KILL P DECOMP Continued monitoring well. SITP fell from 610 psi to 470 psi during first hour, then stabilized. Bled tubing pressure from 470 psi through choke five times. Tubing pressure stabillized at 350 psi after final two pressure bleeds. 9.8 ppg brine thus results in approximately 180 psi overbalance. 03:00 - 07:00 4.00 KILL P DECOMP Displaced well to 9.8 ppg brine. Pumped 3 bpm, 1300 psi tubing pressure, 400 psi casing pressure. OA pressure fell to 200 psi. Pump until 9.7 heavy returns. Shut down pump. 675 bbls 9.8 ppg brine total pumped. 07:00 - 08:30 1.50 KILL P DECOMP PJSM. Monitor well. Well appears to be giving back fluid at a rate of 1.5 bpm and steadily dropping. Tubing is flowing back slowly, I/A, after watching for about 15 minutes has dropped back to giving back 5 gallons in about 5 minutes. Finally stabalized with tubing on a very slight vacuum. 08:30 - 09:30 1.00 KILL P DECOMP Set two way check valve and test from above @ 3500 psi, test from below by bullheading @ 1 bpm / 150 psi, OK. Fluid level in the I/A holding right there at surface. Talked to Milne about making sure all injectors that might be communicating with this well be shut in. They had shut in F-95, and agreed to shut in F-92. No lag time involved, so we will wait to see what happens then. 09:30 - 11:30 2.00 WHSUR P DECOMP PJSM. N/D tree, check threads on hanger, 2 7/8" EUE 8rnd, Pdnted: 12/19/2007 2:49:15 PM • • BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPF-94 -- Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 12/7/2007 End: 12/10/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 12/7/2007 09:30 - 11:30 2.00 WHSUR P DECOMP OK. 11:30 - 15:30 4.00 BOPSU P DECOMP PJSM. N/U BOPE. After nippling up BOPE, and after MPF-92 15:30 - 18:00 I 2.50{ BOPSUFjP 18:00 - 19:00 I 1.001 BOPSUFjP 19:00 - 20:00 1.00 WHSUR I P 20:00 - 21:00 I 1.00 I WHSUR I P 21:00 - 21:30 I 0.501 WHSUR I P 21:30 - 23:00 { 1.501 PULL I P 23:00 - 00:00 I 1.00 I PULL I P 12/8/2007 100:00 - 01:30 I 1.501 PULL I P 01:30 - 05:00 I 3.501 PULL I P 05:00 - 06:00 1.00 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 09:30 3.00 PULL P 09:30 - 14:30 1 5.001 PULL I P 14:30 - 16:30 I 2.001 PULL I P 16:30 - 18:00 1.501 PULL l P 18:00 - 00:00 I 6.001 PULL I P 112/9/2007 100:00 - 01:30 I 1.50 {PULL I P shut in and freeze protected, check I/A by pumping down. Pumped approximately 15 bbls to hit fluid .... fluid level around 500'. Back side is on a vacuum. DECOMP PJSM. Rig up to test BOPE. Conduct full BOPE test as per AOGCC and BP regs. Test witnessed by WSL, Toolpusher and AOGCC rep Bob Noble. DECOMP Held crew change. Performed pre-tour checks. Continued testing BOPE. Had one F/P: methane alarm. DECOMP RD BOPE test equipment. Drained stack. Shot fluid level at 110'. MU lubricator extension. DECOMP RU lubricator and tested to 500 psi. Pulled TWC, RD lubricator and extension. DECOMP PU landing joint with crossover. BOLDS. Pulled tubing hanger free with 86k Ib PU. Re-landed tubing hanger. DECOMP Held safety stand down with rig crew, toolpusher, WSL, RLG, Nabors Rig Superintendent, and BP Wells Superintendent. Discussed recent rig incident rate and ways to improve performance. DECOMP Pulled tubing string free with 100k Ib PU, breaking back to 90k Ib. LD tubing hanger, to be redressed. DECOMP RU head pin and lined up to circulate down tubing. Pumped and spotted 140 bbls 10.1 ppg brine at 4 bpm and 2000 psi. DECOMP Pulled ESP cable over sheave and attached to spooler. POH, standing back 2-7/8" tubing and spooling ESP cable. Used continuous hole fill of 9.8 ppg brine during first 20 stands pulled. Well took 48 bbls brine in 2 hours. Switched to double tubing displacement after 20 stands pulled. 24 stands stood back @ 05:00 hrs. DECOMP PJSM. W/ 24 stands out, change out reels. DECOMP Service rig, check PVT system, crown o matic, OK. DECOMP Safety Stand Down with James Willingham, Bob Mize, and the WSL and Toolpusher along with Del Brandenburg's crew as well as RLG coach Dave Cain. Meeting encompassed a variety of topics including individual responsibility, self imposed urgencies, accountabilities, mitigation of compromising behaviors before they tum in to incidents, open discussions with individual crew members on these subjects, and finally, recommitments by all of us to improve our operation with regard to safety. DECOMP PJSM. POH with old ESP completion. Stood back 2-7/8" tubing and spooled ESP cable. 127 stands out. DECOMP PJSM. Change out ESP cable reels and splice ESP cable. DECOMP PJSM. Continued POH with old ESP completion, standing back 2-7/8" tubing. DEGOMP Held crew change and performed pre-tour checks. Held weekly rig leadership meeting with Toolpushers, WSLs, Wells Superintendent, RLG, and Allen Graff. Discussed plans to improve rig operations and safety performance. Continued POH with old ESP completion, standing back 2-7/8" tubing. Fluid loss about 8 bph 9.8 ppg brine. DECOMP Tested multi-lead extension and new ESP. Removed ESP Printed: 72/19/2007 2:49:15 PM • BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date Frdm - To Hours Task Code NPT 12/9/2007 00:00 - 01:30 1.50 PULL P 01:30 - 03:00 1.50 PULL P 03:00 - 04:00 1.00 PULL P 04:00 - 06:00 I 2.00 06:00 - 09:00 I 3.00 09:00 - 13:00 I 4.00 13:00 - 16:30 I 3.50 16:30 - 17:30 1.00 RU 17:30 - 18:00 0.50 RU 18:00 - 19:30 1.50 RU 19:30 - 22:30 3.00 RU 22:30 - 00:00 1.50 RU 12/10/2007 100:00 - 05:00 I 5.001 RU 05:00 - 09:30 I 4.501 RU 09:30 - 11:30 I 2.00 11:30 - 13:00 I 1.50 13:00 - 14:00 I 1.00 14:00 - 15:00 I 1.001 BOPSURP 15:00 - 16:30 I 1.501 BOPSUF~P 16:30 - 20:00 3.50 WHSUR I P 20:00 - 21:00 I 1.001 WHSUR I P Start: 12/7/2007 Rig Release: 2/7/2002 Rig Number: 4ES Spud Date: 10/15/2001 End: 12/10/2007 Phase I Description of Operations DECOMP cable spools and installed new ESP cable reels. DECOMP Held PJSM. LD old ESP and motor ass'y. DECOMP Cleared and cleaned rig floor. RD elephant trunk. Unloaded old ESP ass'y. Held fire drill with all personnel. RUNCMP Held PJSM. Picked up and made up new ESP assembly. Average fluid loss continuing about 8 bph. RUNCMP Held crew change and performed pre-tour checks. Attached sensor line to ESP and tested. Pulled ESP cable over sheave and connected to pump. Tested ESP -good. RUNCMP RIH with new ESP ass'y on 2-7/8" tubing from derrick. Installed LaSalle clamps on each joint initially. Flushed and tested ESP each 2000' run, at 17 spm and 800 psi. RUNCMP Continued RIH with ESP ass'y on 2-7/8" tubing. Installed LaSalle clamps each joint to stand 62 run. RUNCMP Held weekly safety meeting with day crew. RUNCMP Continued RIH with ESP on 2-7/8" tubing. RUNCMP Held crew change and performed pre-tour checks. Continued in hole with ESP, testing and flushing tubing each 2000'. Installed LaSalle clamps every other joint from stand 62. RUNCMP Made reel-to-reef ESP cable splice. 84 stands in hole @ 19:30 hrs. Held weekly safety meeting with all rig personnel. RUNCMP Continued RIH with ESP on 2-7/8" tubing. Making up all 8 rnd connections to 2300 ftllbs. RUNCMP Continued RIH with ESP ass'y on 2-7l8" tubing. Flushed tubing and tested ESP each 2000'. Installed LaSalle clamps every other joint after stand 62. RUNCMP Made reel-to-reel ESP cable splice. 169 stands in hole @ 04:30 hrs. Held spill drill in well cellar. Daily fluid loss continuing about 8 bph. RUNCMP PJSM. Continue to RIH w/ 2 7/8" ESP completion, torquing connections to 2300 ftllbs, as per completion running detail. RUNCMP PJSM. Install penetrator, make EFT splice. Attach & test same. Flush pump w/ 10 bbls brine @ 1 bpm / 1030 psi, OK. RUNCMP PJSM. Land hanger, RILDs. Used a total of (3) Amsterguards, (398) LaSalle Clamps and (6) protectrofizers. 95K up wt, 40K down wt. Hanger threads are 2 7/8" EUE 8 md. RUNCMP PJSM. Set two way check valve, test from the top to 1000 psi / 10 minutes, OK. Test from the bottom by bullheading into the formation @ 3 bpm / 300 psi, 10 bbls pumped away, OK. RUNCMP PJSM. N/D BOPE. RUNCMP PJSM. N/U tree. Test void & tree to 5000 psi, OK. Make final check on ESP, OK . RUNCMP PJSM. Pick up lubricator & test to 3000 psi, OK. Set BPV. Test BPV from below @ 3 bpm ! 300 psi, OK. Secure well, release rig @ 21:00 hrs, 12/10/2007. Printed: 12/19/2007 2:49:15 PM . . - ... ....···...'·r····················' .." t ..:... ... .,.. . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marlœr.doc , \...... \." L- I V L... LJ ALASKA.L AND ~:~~g~S~L:~:~ON COalSSION FEB 2 1 2006 REPORT OF SUNDRY WELL OPERATION&a OiI&Gas Cons.Commissio Anchorage 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 355016 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend IS! Repair Well IS! Pull Tubing 44.33' 18595 7853 18466 7730 Length 112' 10307' 18523' Change Out ESP o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver IS! Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: IS! Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 201-170-00 6. API Number: 50-029-23040-00-00 99519-6612 9. Well Name and Number: MPF-94 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 112' 112' 10-3/4" 10341' 4454' 5210 2480 7-5/8" 18555' 7814' 6890 4790 c' c' 18290' - 18335' 7557' - 7600' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8",6.5# 4-12", 12.6# 7" x 4-1/2" Baker Premier Packer L-80 L-80 18060' 18146' - 18193' 18155' Treatment description including volumes used and final pressure: RBDMS 8Ft FEB 2 12006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Re resentative Dail Gas-Mcf Water-Bbl Tubin Pressure o Copies of Logs and Surveys run IS! Daily Report of Well Operations IS! Well Schematic Diagram 15. Well Class after proposed work: o Exploratory IS! Development 0 Service 16. Well Status after proposed work: IS! Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my know edge. Sundry Number or N/A if C.O. Exempt: 17. Title Technical Assistant Phone Date Ol:.Wí Prepared By NameINumber: dra Stewman, 564-4750 Submit Original Only 564-4750 Page 1 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date 'From - To i Hours i Task I Code NPT' Phase ___ ..._.._........_.. !.. ....._n__.._ ! 1/12/2006 18:00-19:00 1.00 DEMOB P 19:00 - 21 :00 2.00 DE MOB P 21 :00 - 00:00 3.00 DEMOB P 00:00 - 04:00 4.00 RIGD P 1/13/2006 POST POST POST PRE 04:00 - 12:00 8.00 MOB P 12:00 - 18:00 6.00 MOB P 18:00 - 00:00 6.00 MOB P 1/14/2006 00:00 - 01 :30 1.50 MOB P 01 :30 - 06:00 4.50 MOB P 06:00 - 12:00 6.00 MOB P 12:00 - 18:00 6.00 MOB P 18:00 - 00:00 6.00 RIGU P PRE PRE PRE PRE PRE PRE PRE PRE 1/15/2006 00:00 - 04:00 4.00 RIGU P 04:00 - 06:00 2.00 RIGU P 06:00 - 12:00 6.00 RIGU P 12:00 - 19:00 7.00 KILL P 19:00 - 00:00 5.00 KILL P 00:00 - 02:30 2.50 KILL P 02:30 - 06:00 3.50 KILL P DECOMP DECOMP PRE PRE PRE DECOMP DECOMP 1/16/2006 06:00 - 13:30 7.50 KILL DECOMP P 13:30 - 18:30 5.00 KILL P DECOMP 18:30 - 00:00 5.50 KILL P DECOMP 1/17/2006 00:00 - 04:30 4.50 KILL P DECOMP 04:30 - 06:00 1.50 KILL P DECOMP 06:00 - 10:30 4.50 KILL P DECOMP 10:30 - 13:30 P DECOMP 3.00 KILL Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Spud Date: 10/15/2001 End: Description of Operations Rig Released from 10-113 @ 1900 hrs on 1/12/2006 Scope Down Derrick and Ready Rig to Move. Continue to Ready Rig for Move. Move Rig off well and set sub and motor complex in middle of 1 D pad for maintenance. Rig Maintenance ATP and Safety Orientation at MPU Rig Maintenance; Jack floor to replace pin pockets on driller side sub base. Jack and install sleeve in pin pocket. Continue to install sleeve in pin pocket. Install Jack Foot and Wind Walls. Check Tires in prep for move, had to repair one tire on sub base. Continue Rig Maintenance and Ready Rig to Move Move Rig from 1 D Pad in Kuparuk to MPU F Pad. Spot BOPE behind well. Set Rig Mats and Herculite. Spot Sub Base over well. Move Pipe Shed and Motor Complex into place. Level Rig, Hook Up Steam and Elecrical. Move Trailers and Change House into place. Spot Cuttings box. Raise Derrick and scope Mast. Put together Floor and berm area. Rig Up to displacement tank and pressure test lines. Rig Up to wellhead for kill. Accept Rig @ 12:00 hrs 1/15/2006. ESP Spooler non-operable, Tech's looking into problem. Clean Rig while waiting. ESP Spooler repaired. Continue to Clean Rig while waiting on Seawater trucks. Continue to wait on Seawater Trucks. Clean Rig PJSM with all Rig Crew and Vac Tuck Drivers. Pull BPV and Laydown lubricator. Initial Wellhead pressures 1150psi on Tbg and Csg. Try to circulate well to Seawater. Found pump air locked. Prime Pump to Flowback tank. Displace tubing to Seawater, 110 bbls. Attempt to bullhead into formation, could only get away 14 bbls before pressuring up to 3000psi. Continue to displace wellbore to seawater. Total volume diplaced 670 bbls. Monitor wellhead pressures and calculate brine weight needed to kill well. 500 psi on IA and 488 psi on Tbg. Order 750 bbls on 10.2ppg brine. Clean and Service Rig. Wait on Brine Trucks. Continue to Clean and Service Rig. Load drill pipe in shed, number and strap. Berm for spooling unit Wait on 10.2 ppg Brine. Clean and Service Rig. Load and Strap DP in Shed. PJSM with Rig Crew and Vac Truck Drivers on Displacing Well to 10.2 ppg Brine. Displace Well bore to Brine, pump down Tbg and Take Returns to FLowback Tank. Pumped 133 bbls. Shut-down Pumps and Shutin Well. Found Leak in Flowback Tank on the Inlet Line. Have Flowback tank sucked dry and then hauled off. Have new flowback tank delivered. Rig up hardline to tank. Continue with Displacement of well to 10.2 ppg kill weight brine. Pump 750bbls at -3.5 bpm. Retunrs at surface showing Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report DECOMP 10.1 ppg. DECOMP Monitor well to see if dead. Small amount of pressure, bouncing back and forth from tubing to annulus. DECOMP Hook up Jumper Hose from Tbg to IA to allow well to U-Tube and Pressure to Equilize. Pressure at 1800hrs = 50 psi on tubing and casing, Pressure at 1900 hrs = 80 psi on tubing and casing. Pressure looked as if it had stabilized at 80 psi. DECOMP Bleed a small amount from well to bleed tank to see if the 80 psi was just trapped pressure. Would not bleed down. Talk with Day Supervisor and Town. Decide to circulate out well to 10.6 ppg Brine. Wait on Brine to arrive. Clean and Service Rig. Load and Strap more DP. Wait on 10.6 ppg Brine. Clean Rig and Service. Load and Strap DP. Two layers in Pipe Shed and remainder outside, numbered and segregated in 10-tube intervals on wooden sills. Circulate 80-Bbls of 10.2 ppg brine out of pits and follow with new 10.6 ppg brine kill weight fluid. Start w/ 80 psi on Casing and Tubing. Circulate 3.5 BPM @ 1440 psi Tbg and 350 psi Csg. Circulated 710 Bbls of 10.6 ppg brine until returns were 10.6 ppg. DECOMP SID and monitor well and casing was on vacuum; tubing bled off and went on vacuum. Leave well open for 1/2 hour and still on slight vacuum. S/I for 1-hour and see no pressure. Hold Safety meeting in Break Room with Wells Group Manager, Well Site Leader, and all hands. Check well and well on slight vacuum. P/U and install TWC. Test to 3,500 psi. N/D Tree. N/U BOPE. Continue to N / U BOPE. Modifed Riser, Change out flanges, Install new kill line hose w. uni-bolt flanges. Pick Up test joint and make up TIW and Dart Valve. Set Test Joint inside stack. Function Hydril. Fill stack and test equipment with fluid and Test BOPE. 250 psi low /3500 psi high. AGOCC waived withness of Test ( John Spalding ). Sealing Element in Hydril failed to pass test. All other tests passed. SID and remove Hydril, dismantle same, and install new sealing element. Successfully complete BOP Pressure Test on Hydril. Rig Down BOP Test Joint. Pick Up TWC Lubricator. PJSM. Make Up XO to Lubricator and Pull TWC. Well on Vac. Lay Down Lubricator. Rig Up Tubing Handling Equipment, Pick Up Landing Joint and Make Up Circulating Hoses. PJSM. RIH with Landing Joint and M/U to Hanger. Back out LDS and Pick up hanger. Circulate in 30 bbl Mud Lube Pill down IA to 16,000 feet. Continue with circulating Mud Lube Pill down IA. Displace 30 bbl Pill with 450 bbls of brine. Average circulating rate was 2.75 bpm and 875psi. Had multiple problems with the mud pump oiler system. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Date From - To HoUrs i ! Code NPT I Phas~_1 Task 1/17/2006 10:30 - 13:30 13:30 - 17:00 3.00 KILL 3.50 KILL P P 17:00 - 19:00 2.00 KILL P 19:00 - 20:00 1.00 KILL P 20:00 - 00:00 4.00 KILL P DECOMP 1/18/2006 00:00 - 08:00 8.00 KILL P DECOMP 08:00 - 12:00 4.00 KILL P DECOMP 12:00 - 14:30 2.50 KILL P 14:30 - 15:30 1.00 WHSUR P DECOMP 15:30 - 17:00 1.50 WHSUR P DECOMP 17:00 - 00:00 7.00 BOPSU P DECOMP 1/19/2006 00:00 - 02:30 2.50 BOPSU P DECOMP 02:30 - 03:30 1.00 BOPSU DECOMP 03:30 - 08:30 5.00 BOPSU DECOMP 08:30 - 17:30 9.00 BOPSU P DECOMP 17:30 - 18:30 1.00 BOPSU P DECOMP 18:30 - 19:30 1.00 PULL P DECOMP 19:30 - 20:30 1.00 WHSUR P DECOMP 20:30 - 22:00 1.50 PULL P DECOMP 22:00 - 22:30 0.50 PULL P DECOMP 22:30 - 00:00 1.50 PULL P DECOMP 1/20/2006 00:00 - 01 :30 1.50 PULL P DECOMP Page 2 of 16 Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Spud Date: 10/15/2001 End: Description of Operations ...... .......... ...... -.--- ..------.- Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report Page 3 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/20/2006 1/21/2006 1/22/2006 MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Spud Date: 10/15/2001 End: i From - To Hours ¡ Task ¡Code NPT Phase _.._.._.i.. ____--1_._...... Description of Operations 01 :30 - 02:00 02:00 - 04:00 0.50 PULL P 2.00 PULL P DECOMP Blow down and rig down circulating hoses and equipment. DECOMP Pick up and hang ESP Cable Sheave and Elephant Trunk. Pick up tubing handling equipment. DECOMP Pull Tubing Hanger to floor with 75,000 Ibs. Meg cable connection at penetrator, cut cable head off and meg again. Break off and lay down tubing hanger with 3 foot pup joint and 10 foot pup joint. DECOMP POOH with 2-7/8" EUE 8rd Tbg and SIB in the Derrick. Spool ESP Cable in Centrilift Spooling Unit. DECOMP Adjust Drawworks Brake. DECOMP Resume POOH and SIB 2-7/8" EUE, 8rd Tubing. 181 Stands in the Derrick at 24:00 hrs. Fluid Loss while POOH < 1 bbl/hr DECOMP Continue, POOH and SIB 2-7/8" 8rd EUE Tbg. 208 Stands in the Derrick Fluid Loss while POOH < 1 bbl/hr. DECOMP R/U pipe shed to UD Tbg. POOH and UD 2-7/8" 8rd EUE Tbg. DECOMP Check, dismantle, and UD ESP Pump, Gas Separator, Seal Section and Motor. DECOMP Remove ESP from Pipe Shed, Clean and Clear Rig Floor. DECOMP PJSM. P/U Rat hole and set in Rig Floor. P/U Swivel and Kelly. DECOMP P/U Kelly tongs from Pipe Shed, PJSM. M/U Kelly and Swivel, torque to 48K Ibs-ft. Set Kelly in Rat Hole. DECOMP Lay Down Kelly Tongs. Load and Strap 3-1/2" DP in Pipe Shed. P/U 2-7/8 DP handling Equipment and 3-1/2" DP Handling Equipment. DECOMP Load and Strap 2-7/8" PAC DP and additional 3-1/2" DP in Pipe Shed. Hook Up Rig Tongs and Pipe Spinners on Rig Floor. DECOMP PJSM, P/ U 2-7/8" Mule Shoe and BHA. DECOMP P/U DP from Pipe Shed 1 x 1 and RIH, 110 jts of 3-1/2" IF DP. Scale and Ice had to be cleaned out of many joints. DECOMP Reverse Circulate Tubing Volume to Clear Pipe. Load Pipe Shed w/3-1/2" HT38 DP, Strap and Talley DECOMP P/U DP from Pipe Shed 1 x1 and RIH, Jts #110 -#170. DECOMP Continue to P/U and RIH w/3-1/2" DP from Pipe Shed, Jt #187 in the hole. DECOMP Service Hydraulics. DECOMP P/U and RIH w/3-1/2" DP from Pipe Shed. Jt #210 in the hole. Fluid loss since Midnight = 7-Bbls, slightly less than 2-Bbls per hour. DECOMP Continue RIH w/3-1/2" DP from Pipe Shed. Joint #280 RIH @ 0810 hours. Rate is 16 to 17 joints per hour. At 1330 hours, the field-wide travel directives were upgraded to Phase 3. Stopped RIH with 390-jts of Drill Pipe run. P/U Floor Safety Valve, install on Drill Pipe, and begin Warm Shutdown of Nabors 3S. Wait on Phase 3 weather. Wait on Weather; Phase 3. RIH w/3-1/2" DP from Pipe Shed. to 18,083 ft (Jt # 564). Up Wt = 165,000# and Down Wt = 70,000#. M / U Jt # 565 and RIH. Tag Up with 19 ft in hole, = 18102 ft. Approx 36 ft high. Top of Stub around 18137.5 ft with N-3S RKB of 21.1 ft. Set Down 5,000 #, Hard Bottom. Double and Triple Check Joint Count on Location to ensure we are not off 1 04:00 - 05:00 1.00 PULL P 05:00 - 08:00 3.00 PULL P 08:00 - 10:00 2.00 PULL P 10:00 - 00:00 14.00 PULL P 00:00 - 03:15 3.25 PULL P 03:15 - 13:30 10.25 PULL P 13:30 - 17:00 3.50 PULL P 17:00 - 19:30 2.50 PULL P 19:30 - 22:30 3.00 PULL P 22:30 - 00:00 1.50 PULL P 00:00 - 02:00 2.00 CLEAN P 02:00 - 04:30 2.50 CLEAN P 04:30 - 07:30 3.00 CLEAN P 07:30 - 16:30 9.00 CLEAN P 16:30 - 20:00 3.50 CLEAN P 20:00 - 00:00 4.00 CLEAN P 1/23/2006 00:00 - 01 :45 1.75 CLEAN P 01 :45 - 02:30 0.75 CLEAN P 02:30 - 04:15 1.75 CLEAN P 04:15 - 13:30 9.25 CLEAN P 13:30 - 00:00 10.50 CLEAN P DECOMP 1/24/2006 00:00 - 06:00 6.00 CLEAN P DECOMP 06:00 - 15:00 9.00 CLEAN P DECOMP 15:00 - 17:30 2.50 CLEAN P DECOMP Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report joint. R / U Circ Head. P / U and Establish Parameters. Up Wt = 165,000#, Down Wt = 70,000#, Circ Rate Down Tubing = 2.6 bpm @ 660 psi. Reverse Circ Rate = 2.25 bpm @ 530 psi. RIH and Stack Out at 19 ft in on Jt #565. Begin Reverse Circ, Weight Falls Off. Tagged on Fill. DECOMP M / U Jt #566 and Reverse Circ w/3 bpm @ 810psi. Slowly Wash Down Joint to 18146 ft. Once Jt in Hole, Circulate another 100 bbls (-3/4 btm ups). No Noticable Returns except Pipe Dope seen on Shaker Screens. DECOMP M / U Jt# 567, Reverse Circ and Wash Joint Down @ 3.7bpm and 11 00 psi. Small amount of Formation Sand and Carbolite seen on Shakers. Reverse Circ another 100 bbls and M / U Jt # 568. Reverse Circ and Wash Joint Down at same Rate. No increase in Solids on Shaker. M / U Jt #569 DECOMP M / U Jt #570 and Reverse Circ w/ 4.0 bpm @ 1160 psi. Slowly Wash down hole to 18272 ft. Seeing Large amounts of Carbolite and some Formation Sand across Shakers. Circulate out all Carbolite and Sand. Losses for 18:00 to 24:00 hrs = 138 bbls. Finished Circ Sweep out of hole with no trace of Carbolite or Sand in Returns. Shut Down Circ. and Clean Out Possum Belly. M / U Joint #571. Wait on Super Sucker. Cuttings Tank Full, no room for additional material. Super Sucker on location and unloaded 3.5 yrds of material (-16.8 bbls). RIH with Jt #571 and tag at 18272 ft. Rev Circ and Wash down Joint, 4 bpm @ 810 psi. Losses at 0.75 to 1 bpm at this rate and depth. Required 5 bbls to fill hole initially. Wash Joint to 18304 ft and Circ Btms Up, No Noticable Solids in Returns. MU Jt #572 and Wait on Brine from MI. Reverse circulate and FCO at 4.5 BPM, 550 psi, to 18366'. Carbolite in returns with losses of 2 BPM. Offload 250 BBLS 10.6 #/gal Brine into pits. MU joint #574 and wash down while reversing at 4.5 BPM, 550 psi. Carbolite returns with losses of 2 BPM. Wash down to depth of 18398'. Reverse out DP volume. MU joint #575 and wash down while reversing at 4.5 BPM, 550 psi. Carbolite returns with losses of 2 BPM. Wash down to depth of 18429'. Reverse out DP volume. MU joint #576 and wash down to depth of 18434' while reversing at 4.5 BPM, 550 psi. Carbolite in returns and loss of 2+ BPM. Lose circulation with no noticeable increase in pump pressure. Work DP free with 5K overpull, re-establish reverse circulation at 4 BPM, 500 psi and pump 2 ea 15 bbl viscous sweeps bottoms up. When sweeps at surface, large amounts of carbolite in returns. Reverse until clean fluid returns. Total fluid pumped, 950 BBLs, losses of 320 bbls. Total proppant recovered 4+ yards. DECOMP Open annular preventer observe well flowing. Shut preventer, reverse circulate @ 2 BPM, 220 psi, 130 BBLs w/losses of 1 BPM. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 3S ! Date I From - To Hours Task Code NPT Phase j . -- --...-.---.... 1/24/2006 15:00 - 17:30 2.50 CLEAN P DECOMP 17:30 - 18:30 1.00 CLEAN P DECOMP 18:30 - 20:15 1.75 CLEAN P 20:15 - 22:00 1.75 CLEAN P 22:00 - 00:00 2.00 CLEAN P 1/25/2006 00:00 - 01 :45 1 .75 CLEAN P DECOMP 01 :45 - 03:00 1.25 CLEAN P DECOMP 03:00 - 04:00 1.00 CLEAN P DECOMP 04:00 - 06:30 2.50 CLEAN P DECOMP 06:30 - 08:30 2.00 CLEAN P DECOMP 08:30 - 09:30 1.00 CLEAN P DECOMP 09:30 - 10:30 1.00 CLEAN P DECOMP 10:30 - 13:00 2.50 CLEAN P DECOMP 13:00 - 15:00 2.00 CLEAN P Page 4 of 16 Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Spud Date: 10/15/2001 End: Description of Operations .. .. n. .._____ ________.__._...___..______.______..__ Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report Page 5 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Spud Date: 10/15/2001 End: Date I I I From - To Hours ¡ Task Code I NPT Phase ____L.u Description of Operations 1/25/2006 15:00 - 16:00 1.00 CLEAN P DECOMP Shut down pumping, open preventer and observe well. Well flowing 1 BBI every 10 minutes. POH laying down singles to 18093' (above tubing stub at 18146'). Stop and observe well. Continue POH to 18051'. Close well in and wellhead pressure build to 50 psi in 15 minutes. Wait for pressure to stabilize. DECOMP Wellhead pressure increase to 50 psi. Equivalent mud weight of 10.7 #/gal. Locate necessary materials to weight system to 10.9 #/gal with Bromide. Crystallization and freeze point at 20 deg F with 10.9 brine. DECOMP Circulate and weight up brine system to 10.9#/gal Bromide. 6 1/2 pallets Bromide. DECOMP PJSM with rig crew on PPE for Mixing Bromide and Well Kill Procedures. Initial Pressures 30 psi on Csg, 40 psi on Tbg. Circulate 10.9 ppg Brine, inital Pump Pressure 380 psi at 2 bpm. Pump Brine as per Well Kill Sheet. Initial Mud Weight in Returns = 10.5+. Drill String Volume = 127 bbls, Annular Volume = 471 bbls. At midnight 52.5 bbls pumped, 4 bbl losses, pump rate 2 bpm. 186 bbls Pumped, Rate 2 bpm. 414 bbls Pumped, Rate 2 bpm. 615 bbls Pumped, Rate 2 bpm. Returns 10.6 ppg DECOMP 722 bbls Pumped, Rate 2 bpm. Fluid losses = 102 bbls. Returns 10.75 ppg DECOMP 10.9ppg Brine in Returns. Shut-In and Monitor Well. Fill hole, monitor losses for 5 minutes, 2.5 BBls loss. POH 5 stands and fill hole to monitor losses. DECOMP 5 Stands OOH, losses at 8 BBls + 1.5 BBls for DP displacement. POH another 5 stands and repeat. DECOMP 5 stands OOH fill with 9.5 BBLs brine. POH and lay down 15 stands. Load the hole with double DP displacement of 10 BBLS. (no returns) POH and lay down 15 additional stands and completely fill the hole with volume of 13 BBLS (returns). DECOMP POH and lay down 31/2" DP. Loading the hole with 10.9 #/gal brine, double DP displacement of 10 BBILs every 15 stands. Contact AOGCC regarding BOP test due 1/26/06 (today) at 6:00 pm. They agreed to delay until out of hole with DP. Continue POH filling wI double displacement every 15 stands. RREP DECOMP 200 joints OOH. Secure well to troubleshoot pipe laydown machine -- Broken Chain. Hold Risk Assessment and discuss process with rig crew. Repair Laydown Machine, replace chain and teflon sliders. DECOMP Clear Laydown Machine area of tools and parts. Double Check Pipe Laydown Machine is operational. PJSM with Rig Crew on POOH and L / D 3-1/2" DP. DECOMP Continue to POOH and UD 3-1/2" DP, from Jt #200. Pumping Double Displacementof 5 bbls every 15 joints. DECOMP Contact MI plant in Prudhoe Bay and order 160 BBLs of 10.9 #/gal brine from plant. As per MI ETA on location at 8:00 am. Continue to POH and lay down 3 1/2" DP, filling hole with double DP displacement every 15 stands. DECOMP 1365 joints OOH. 210 joints remaining. Contact Chuck with ; AOGCC and discuss BOP test tentatively scheduled for 6:00 I ! DECOMP DECOMP DECOMP Fluid Losses = 30 bbls Fluid Losses = 61 bbls Fluid losses = 87 bbls. 16:00 - 16:30 0.50 CLEAN P 16:30 - 23:00 6.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P 1/26/2006 00:00 - 01 :00 1.00 CLEAN P 01 :00 - 03:00 2.00 CLEAN P 03:00 - 04:30 1.50 CLEAN P 04:30 - 05:30 1.00 CLEAN P 05:30 - 06:30 1.00 CLEAN P 06:30 - 07:00 0.50 CLEAN P 07:00 - 09:30 2.50 CLEAN P 09:30 - 14:30 5.00 CLEAN P 14:30 - 23:00 8.50 CLEAN N 23:00 - 00:00 1.00 CLEAN P 1/27/2006 00:00 - 03:30 3.50 CLEAN P 03:30 - 08:00 4.50 CLEAN P 08:00 - 10:00 2.00 CLEAN P Printed: 2/13/2006 12:00:59 PM e e BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: WORKOVER Start: 1/14/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/8/2006 Rig Name: NABORS 3S Rig Number: N3S Date From - To I Hours I Task . Code NPT Phase Description of Operations , , ~----_. --.- ...--.-..---- .--.. ........-.- . ----- -..-..-.- 1/27/2006 08:00 - 10:00 2.00 CLEAN P DECOMP pm tonight. State witness requirement waived. PU Kelly, break connections. 10:00 - 11 :30 1.50 CLEAN P DECOMP 380 joints OOH, fill hole with 13 BBS of 10.9 #/gal brine. 40 BBLs of 10.9 #/gal brine in pits. Contact MI regarding status of brine order and ETA. Have not started mixing as of yet, ETA of 4:00 pm. Secure well for ATP meeting at MPU for new crew coming in. 11 :30 - 14:30 3.00 CLEAN P DECOMP ATP and site orientation for Nabors 3S personnel at MPU. 14:30 - 15:00 0.50 CLEAN N FLUD DECOMP Wait on brine from MI mud plant. Prepare to mix 50 gal Baroid EP lube in 20 BBL pill to pump down annulus to load hole. 15:00 - 15:15 0.25 CLEAN C DECOMP Open annular to load well with 10.9 #/gal brine. No flow. 15:15 - 16:00 0.75 CLEAN C DECOMP Well starting to flow. Take 4 BBL of crude influx, close rams with 50 psi casing pressure. DP pressure at 20 psi. Secure well and monitor. Order additional 290 BBLs of 10.9 #/gal brine from MI mud plant. 16:00 - 17:15 1.25 CLEAN C DECOMP Contact Chuck with AOGCC and notify him of situation. Casing pressure increase to 110 psi 17:15 - 17:45 0.50 CLEAN C DECOMP CSG psi increase to 215 psi. Check DP pressure, change hoses and gauges. DP pressure at 0 psi. Remove gauge and open TIW valve to 0 pressure on DP. 17:45 - 20:00 2.25 CLEAN C DECOMP Call MI, 200 BBLs of 10.9 #/gal brine on road, 290 BBLs being loaded. Shut down mixing any additional brine. Rig up to circulate and kill well from DP depth of 6422'. 20:00 - 21 :00 1.00 CLEAN C DECOMP First Load of 10.9ppg Brine on location, 200 bbls. Second Load of 290 bbls has left MI yard. PJSM on well kill circ out. Fill Drill Pipe with Fluid, 11 bbls. Circ will require -9000 stks for tbg and IA volume. InitiallA pressure = 380 psi, Tbg pressure = 70 psi. Begin Pumping @ 1 bpm @ 250 psi pump pressure, IA pressure up to 390 psi. Open choke and IA pressure bled off rapidly to 60 psi and held there. Small amount of crude, mostly gas. 21 :00 - 21 :30 0.50 CLEAN C DECOMP Gained 9in in Flowback tank worth of returns @ 1775 stks (42 bbls), pumped more than drill pipe volume. Pump pressure a constant 250 psi at 2 bpm, Csg pressure at 60 psi. Returns very small in volume, mostly gas mixed with fluid, seems to be slugging. Shut-down and watch Csg pressure bleed from 60 to 10 psi very quickly. Still have positive pressure on Csg side all gas. Rig Crew Change Out - PJSM with new crew. 21 :30 - 22:30 1.00 CLEAN C DECOMP Continue with circulation. Csg pressure still holding at 60 psi, vary pump rate from 1-3 bpm. 3 bpm at 440 psi pump pressure. Seeing both brine and gas in returns. Circulate a total of 9000 stks ( 211 bbls ). 22:30 - 23:00 0.50 CLEAN C DECOMP Shut Down and watch pressures. Drill Pipe down to 0 psi and Csg down to 20 psi. Bleed csg to flowback tank for 10 minutes, gauge showing 10 psi. Very low pressure gas coming out of sample hose. Consult with Day Company Man and decide to no flow test to pits. Blow down all lines to avoid freeze up. Flow Back Tank Volume = 3' 6" ( 160 bbls ). 23:00 - 00:00 1.00 CLEAN C DECOMP No Flow Test to pits - no flow. Wait 10 minutes and Fill Hole- 6.5 bbls. Wait 10 minutes and No Flow Test again - No Flow. Fill Hole with 6.3 bbls, wait another 10 minutes and No Flow Test - No Flow. Well Dead, Fluid Level in Csg falling quickly. 1/28/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP PJSM on POOH and Well Control. POOH with Jts #381-390 Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report Page 7 of 16 Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date I From - To Hours Task i I Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Code I NPT I Phase I L___ Spud Date: 10/15/2001 End: Description of Operations 1/28/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP and Fill Hole = 8 bbls. POOH with Jts #391-400 and Fill Hole = 9 bbls. 01 :30 - 02:30 1.00 CLEAN P DECOMP POOH to Jt #410 and pump 5 bbls, 2 bbls over double displacement. POOH to Jt # 420 and pump 5 bbls again. 02:30 - 03:00 0.50 CLEAN P DECOMP POOH to Jt #430 and fill hole with 19 bbls with 50 gal EP lube. 03:00 - 05:30 2.50 CLEAN P DECOMP POOH to Jt #470 fill hole with 9.5 bbls. 05:30 - 06:45 1.25 CLEAN P DECOMP Crew change. Continue to Jt # 490 fill hole with 5 bbls. 06:45 - 07:35 0.83 CLEAN P DECOMP Contact Chuck with AOGCC. Update him on status of well, and notify him that will be BOP testing this afternoon. He waived witnessing the test. Continue POOH w/ DP. POOH to Jt #510 fill hole with 7 bbls. 07:35 - 09:00 1.42 CLEAN P DECOMP POH to JT #518 and notice well bubbling. Shut down and observe very slight flow. Shut well in, pressure build to 20 psi on csg, and 0 psi on DP. Circulate 3000 stks at 4 bpm, 400 psi on DP with returns to pits and no gas. Mud wt in and out at 10.8# +. Observe well. Fluid stable and dropping slightly but bubbling. After 20 minutes, well start to flow slightly. 09:00 - 10:00 1.00 CLEAN P DECOMP Shut well in and circulate 3000 strokes at 4.5 bpm with 500 psi on DP, 30 psi on Csg. No flow test. Well bubbling with no flow. Fluid level stable, then dropping slightly. After 20 minutes, well start to flow slightly and still bubbling. 10:00 - 11 :00 1.00 CLEAN P DECOMP Shut well in. Csg pressure at 10 psi, DP at 0 psi. Circulalte 4500 strokes at 5 bpm, 620 psi DP pressure, 20 psi Csg pressure.. No flow test. Well bubbling with no flow. Fluid level stable, then dropping slightly. After 20 minutes, well start to flow slightly and still bubbling. 11 :00 - 12:00 1.00 CLEAN P DECOMP Csg pressure at 10 psi. DP pressure at 0 psi. Contact MI and order 580 bbls of 10.9 #/gal brine. Call AOGCC and leave message. Contact LRS for pump truck to bullhead kill well. 12:00 - 12:30 0.50 CLEAN P DECOMP Csg pressure at 90 psi, open TIW valve to confirm no pressure on DP 12:30 - 15:00 2.50 CLEAN P DECOMP Csg pressure to 120 psi, 0 psi on DP. Confirm fluids order with MI and trucks with Peak. PJSM with rig crew and lay down Kelly. 15:00 - 16:30 1.50 CLEAN P DECOMP Csg pressure to 145 psi. Start to mix 30 bbl Dua-Vis pill w/ 10.9 #/gal NABR in pill pit. Continue lay down Kelly. 16:30 - 17:30 1.00 CLEAN P DECOMP 1st Vac truck with brine on location. Break out rathole. Wait on Brine. 17:30 - 18:00 0.50 CLEAN P DECOMP Rig crew change and pre-tour safety meeting. 18:00 - 21 :00 3.00 CLEAN P DECOMP Slip and cut drill line. Continue to wait on Vac Trucks. 21 :00 - 22:30 1 .50 CLEAN P DECOMP Finish Slip and Cut operations. Final Vac Truck on location. Fill Pits with Brine. PJSM on bullhead operations. 22:30 - 00:00 1.50 CLEAN P DECOMP Begin Bullhead into formation. Initial Pressures, IA = 435 psi. DP = 0 psi. Pump Down IA with LRS at 5 bpm and Rig Pumpd down DP at i 2 bpm. Shut-down LRS and pump only down DP w/ Rig Pump. I Pump 75 bbls down IA and 30 bbls down DP. Then pump 30 bbl Hi-Visc Pill and Chase with 15 bbls down DP. Continue Pumping down IA w/ LRS at 5 bpm for 450 bbls and Pump down DP w/ Rig at 2 bpm for 180 bbls. 1/29/2006 00:00 - 00:45 0.75 CLEAN P DECOMP Finish Bullhead operations. Pump pressure down IA was 2000 - 1850 psi at 5 bpm. Pump pressure down DP was 1600 - 1400 psi at 2 bpm. Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date I From - To ; Hours; Task Page 8 of 16 Spud Date: 10/15/2001 End: Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S i . Code! N PT ' Phase DECOMP Casing Pressure Down to 950psi from 1550psi. R/D LRS, Move Vac Trucks and Monitor Pressure. DECOMP Try Bleeding Pressure. Open Choke to pits and bleed from 930psi to 30 psi. Flow back 7 bbls. Shut-in and monitor pressure. Casing pressure built to 450 psi in 10 minutes. Open Choke and bleed again, 7 bbls back. Shut-in and monitor pressure. Casing pressure built to 380 psi in 10 minutes. Open choke and bleed again, 7 bbls back. DECOMP Shut-in choke and monitor pressure. Casing pressure built to 350 psi in 10 minutes. Open choke and bleed 7 bbls. Shut-in and moitor pressure, casing built to 320 in 10 minutes. Bleed 7 bbls. Shut-in choke and monitor pressure, casing built to 280 psi. DECOMP Bleed 7 bbls. Wait 10 mins casing pressure build to 260 psi. Bleed 7 bbls and wait 10 mins, casing pressure build to 230 psi. Bleed 7 bbls and wait 10 mins, casing build to 210 psi. Total volume back to pits is 60 bbls. Monitor well pressures. Casing pressure up to 270 psi. Bleed back 7 bbls to pits. Monitor well pressures. After 15 minutes casing built to 140 psi. Monitor well pressures. Csg pressure at 140 psi, 20 miutes to bleed 14 bbls back to pits. Monitor well pressures. Csg pressure at 120 psi. 20 minutes to bleed 10 bbls back to pits. Monitor well pressures. Csg pressure at 90 psi. 30 minutes to bleed 10 bbls back to pits. Monitor well pressures. Csg pressure at 70 psi. 40 minutes to bleed 10 bbls back to pits. Total volume of 121 bbls to pits. Monitor well pressures. Csg pressure at 50 psi. 60 minutes to 10 bbls back to pits. Monitor well pressures. Csg pressure at 30 psi. 40 minutes to bleed 5 bbl back to pits. Total volume of 136 bbls to pits. Monitor well pressures. Csg pressure at 30 psi. 15 minutes bleed 3 bbls back to pits. Total volume of 140 bbls to pits. Put 100 psi gauge on annulus, 34 psi on Csg. Discuss situation with town. Decision made to strip to bottom with 31/2" DP. Make preperations such as get extra annular etc. Contact AOGCC inform them of the decision. Unload 2 7/8" production tubing from pipe shed. Load pipe shed with 31/2" DP, and strap. Csg pressure at 50 psi. Continue preperations for stripping operations. PJSM, risk assessment, and plan forward with crew. Discuss stripping operation and roles and responsibilities. Csg pressure at 60 psi. MU Dart Valve to TIW. Open Pipe Rams, casing pressure down to 10 psi. Open TIW and Strip in hole. Release small amount of fluid when trying to pass TIW through bag. Pressure on csg down to zero. Flow Check well. No Flow. Pump in csg, took 3 bbls to fill. Still no pressure, flow check - no flow. DECOMP Open bag and check fluid level, fluid level down at wellhead level. Decide to circulate well. POOH and remove TIW and Dart Vavle. Rig Up Circ Head. 1/29/2006 00:45 - 01:15 0.50 CLEAN P 01:15 - 01:45 0.50 CLEAN P 01 :45 - 02:30 0.75 CLEAN P 02:30 - 03:00 0.50 CLEAN P 03:00 - 05:00 2.00 CLEAN P DECOMP 05:00 - 05:50 0.83 CLEAN P DECOMP 05:50 - 06: 10 0.33 CLEAN P DECOMP 06:10 - 07:50 1.67 CLEAN P DECOMP 07:50 - 08:55 1.08 CLEAN P DECOMP 08:55 - 10:10 1.25 CLEAN P DECOMP 10:10-11:35 1.42 CLEAN P DECOMP 11 :35 - 13:00 1.42 CLEAN P DECOMP 13:00 - 15:00 2.00 CLEAN P DECOMP 15:00 - 16:00 1.00 CLEAN P DECOMP 16:00 - 18:00 2.00 CLEAN P DECOMP 18:00 - 19:00 1.00 CLEAN P DECOMP 19:00 - 22:00 3.00 CLEAN P DECOMP 22:00 - 23:30 1.50 CLEAN P Description of Operations .---- ---------.. Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report Circulate The well throught Choke at 4.67 bpm and 600 psi for 105 bbls. Lost 3 bbls during circulation. Monitor Well for no flow. MU Dart Valve to Top of Joint #58 and Rig Up to RIH. RIH with Joints #58 thru 71. Fill Drill Pipe. 3.9 bbls Returned. RIH to Jt #80 and Fill Drill Pipe. 9 Joints Run, Returns = 3.2 bbls. RIH to Jt #90 and Fill Drill Pipe. 10 Joints Run, Returns = 3.3 bbls. RIH to Jt #100 and Fill Drill Pipe. 10 Joints Run, Returns = 3.2 bbls. RIH to Joint #110 and Fill Drill Pipe. 10 Joints Run, Returns = 3.7 bbls. Small flow of fluid between last two joints and when filling pipe. Shut-in Well. DECOMP Circulate 138 bbls, 4.66 bpm at 800 psi. Lost 6 bbls to well. DECOMP Flow Check well after circulation. Small flow, no presssure on casing. Shut in and monitor for 15 minutes. Open well again. Small flow of fluid but quickly died off. No Flow, open bag and view fluid level. Fluid down by wellhead. DECOMP RIH to Joint #120 and Fill Drill Pipe. 10 joints Run, Returns = 3.2 bbls. RIH to Joint #130 and Fill Drill Pipe. 10 joints Run, Returns 5.6 bbls. Well Trying to Flow between Joints. Shut in well, 40 psi on casing. Begin Stripping operations with Joint #131. Csg pressure at 60 psi. RIH wI Joint #140. Fill DP. Csg pressure at 120 psi. Continue to strip in hole, filling DP every 10 joints. RIH wI Joint #160. Fill DP. Csg pressure at 160 psi. Continue to strip in hole, filling DP every 10 joints. RIH wI Joint #170. Fill DP. Csg pressure at 180 psi. Bleed to 40 psi. (all gas) Continue to strip in hole, filling DP every 10 joints. RIH wI Joint #190. Fill DP, Csg pressure at 80 psi. Continue to strip in hole. Pit volume of 191 bbls 10.9#/gal brine. Csg pressure constant at 80 psi. Bleed to 0 psi and load Csg with 6.5 bbls of brine. Csg pressure to 20 psi. Continue to strip in the hole, filling DP every 10 joints. RIH wi Joint #210. Fill DP, Csp pressure at 20 psi, gas bubbling through Annular preventer. Continue to strip in hole, filling DP every 10 joints. RIH wI Joint #230. Fill DP, Csg pressure at 20 psi, gas bubbling through bag. Continue to strip in hole, filling DP every 10 joints. RIH wI Joint #310, Csg pressure at 80 psi, gas bubbling through Hydril Rubber. Bleed to 0 psi (1 bbl returns). Gas still bubbling, Csg pressure to 20 psi. Continue to strip in hole, filling DP every 10 joints. Fluid Slipping by Hydril Rubber. Will need to be changed out. DECOMP Shut Pipe Rams and work Hydril, try to re-energize and get to hold pressure. Circulate bottoms up prior to changing out Hydril Rubber. DECOMP Circulate Btm's Up at 4.6 bpm and 1200 psi, 280 bbls total. Some gas in returns from about 90 to 150 bbls, after 210 bbls no signs of gas. 8 bbls losses. Casing Pressure Initially 270 Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date . From - To ! Hours I Task : Code I NPT : ~ I Phase I n... ____...______ .-.--.----------.-... . 1/29/2006 23:30 - 00:00 0.50 CLEAN P DECOMP 1/30/2006 00:00 - 00:30 0.50 CLEAN P DECOMP 00:30 - 01 :00 0.50 CLEAN P DECOMP 01 :00 - 01 :30 0.50 CLEAN P DECOMP 01 :30 - 01 :50 0.33 CLEAN P DECOMP 01 :50 - 02:30 0.67 CLEAN P DECOMP 02:30 - 03:15 03:15 - 04:00 0.75 CLEAN P 0.75 CLEAN P 04:00 - 05:00 1.00 CLEAN P 05:00 - 06:30 1.50 CLEAN P DECOMP 06:30 - 08:30 2.00 CLEAN P DECOMP 08:30 - 09:20 0.83 CLEAN P DECOMP 09:20 - 10:30 1.17 CLEAN P DECOMP 10:30 - 12:15 1.75 CLEAN P DECOMP 12:15 - 14:00 1.75 CLEAN P DECOMP 14:00 - 16:15 2.25 CLEAN P DECOMP 16:15 - 21:00 4.75 CLEAN P DECOMP 21 :00 - 21 :30 0.50 CLEAN P 21 :30 - 23:30 2.00 CLEAN P Page 9 of 16 Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Spud Date: 10/15/2001 End: Description of Operations ---.....-----.-- _._____.__n__ ___ Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report Page 10 of 16 Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date I From - To Hours ¡ Task Code NPT i 1/30/2006 1/31/2006 Start: Rig Release: Rig Number: Phase Spud Date: 10/15/2001 End: 1 /14/2006 2/8/2006 N3S Description of Operations --..- ------------- --.......----.-..---...... 21 :30 - 23:30 23:30 - 00:00 2.00 CLEAN P 0.50 CLEAN P DECOMP psi prior to circulating, at shut-down it was 30 psi. DECOMP Monitor Well. Casing Pressure built from 30 psi to 160 psi. Crack Choke and bleed off. Pressure quickly bleeds down, bleed down to 20 psi before fluid in returns. Shut-in and Monitor, build rate slower. Start to Change Out Bag. DECOMP NID BOPE Riser and Top of Annular Preventer. Pull Old Annular Preventer element from BOPE. Casing Pressure beginning to rise. At 03:30 at 270 psi. Lube and Bleed down annulus. Pump 10 bbls down annulus at 1 bpm. No pressure build seen. Annulus pressure down to 140 psi and holding. DECOMP Install New Annular Preventer element in BOPE. N/U top of Annular Preventer and Riser. Crew change. PJSM discuss present operation, function testing of Annular, and plan forward. DECOMP Csg pressure at 40 psi, bleed to 0 psi and no flow test. 10 minutes with no flow, then start flowing. Pump 1 bbl down backside, csg pressure from 40 psi to 70 psi. Cycle Annular Preventer open and closed several times, close bag. Bleed Csg to 10 psi and open pipe rams. Gas leaking by Annular Preventer. Close rams and open Annular Preventer. 80 psi on csg and building. DECOMP Rig up to circ well. Open TIW valve to 0 psi DP pressue. Csg pressure at 140 psi. Circulate 115% bottoms up volume. at 4 bpm, 190 psi Csg and 950 psi DP pressure. 190 bbls away, reduce rate to 3 bpm. DECOMP Circulate 320 bbls, mud wt in and out at 10.9 #/gal, 3 bpm, 10 psi on Csg, 560 psi on DP. 34 bbls losses. Shut down and observe well. Returns slugging with 20 psi shut in pressure. RU for stripping operations. Open TIW to slight vacuum. PJSM and discussion with all crew members potential risk, roles and responsibilities, plan forward, and contingency plans. Begin stripping operations with #310 joints in hole. RIH wI joint #322, fill DP, 50 psi on Csg. Fluid will not remain static in DP, level falling. Fill to surface and resume stripping in hole. Fill DP every 10 joints. RIH wI joint #350, fill DP wI 3.2 bbls (DP volume for 10 joints is 2.2 bbls). Csg pressure 100 psi. RIH wI joint #360, (11650'), fill DP wI 3.2 bbls. Csg pressure at 120 psi. Continue to strip in the hole. RIH wljoint #379, (12,248'), fill DP w/3.2 bbls. Csg pressure at 20 psi. Continue to strip in hole. RIH wljoint #390, (12,595'), fill DP w/2.7 bbls. Csg pressure at 10 psi. Conducted no-flow test. Well flowed 1 bbl. back to pits in 5 minutes. Continue to strip DP in hole. Down wt. = 55K. RIH wljoint #406, (13,100'), fill DP w/3.2 bbls. Csg pressure at 50 psi. Annular Preventer element failed at 13,100' DP in well. Close pipe rams. Notified ADW Wells manager of Annular Preventer element failure via telephone. DECOMP Circulate well with clean brine returns and a trace of gas @ 4.0 BPM @ 980 psi on the DP and 20 psi casing pressure through choke. Fluid losses @ 4.0 BPM = -50 bbls. per hr. CBU (350 bbls.) with clean brine returns and a trace of gas @ 3.0 bpm @ 750 psi DP pressure and 20 psi casing pressure through 00:00 - 04:00 4.00 CLEAN C 04:00 - 07:00 3.00 CLEAN C 07:00 - 08:45 1.75 CLEAN C 08:45 - 10:30 1.75 CLEAN C 10:00 - 11 :30 1.50 CLEAN C 11 :30 - 12:30 1.00 CLEAN C DECOMP 12:30 - 13:15 0.75 CLEAN C DECOMP 13:15 - 16:00 2.75 CLEAN C DECOMP 16:00 - 16:55 0.92 CLEAN C DECOMP 16:55 - 18:00 1.08 CLEAN C DECOMP 18:00 - 20:30 2.50 CLEAN C DECOMP 20:30 - 21:15 0.75 CLEAN C DECOMP 21:15 - 00:00 2.75 CLEAN C Printed: 2/13/2006 12:00:59 PM Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Start: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 3S Rig Number: Date I From - To I Hours I Task _ _~~~:t~~~ _'~_h_a~~l___~ 1/31/2006 21:15 - 00:00 2/1/2006 00:00 - 03:00 03:00 - 05:00 BP EXPLORATION Operations Summary Report Page 11 of 16 1/14/2006 2/8/2006 N3S Spud Date: 10/15/2001 End: Description of Operations 2.75 CLEAN C DECOMP choke. Fluid losses at 3.0 bpm = 0 bbls.lhr. Total fluid lost during CBU = 6.3 bbls. Shut in well and monitor. Initial SIDPP = 0 psi. Initial SICP = 30 psi. Flow test well at 15 bbls.lhr. Prep to changeout Annular Preventer element while circulating well. DECaMP PJSM all crew. N/D BOPE riser and top of Annular Preventer. Pull old Annular Preventer element from BOPE. Inital SIDPP = o psi. initial SICP = 30 psi. SICP @ 01 :00 hrs. = 20 psi. SIDPP @ 01 :00 hrs. = 0 psi. DECaMP Install new Annular Preventer element in BOPE. N/U top of Annular Preventer and riser. Function test Annular Preventer. SIDPP = 0 psi, SICP = 20 psi. Bleed annulus to 0 psi pits through choke. Monitor well. Open annular preventer and fill hole w/3.2 bbls. RIH w/3-1/2" DP to 410 jts. (13,226'). Monitoring well and pits for gains. RIH w/3-1/2" DP to 420 jts. (13,541 '). Monitoring well closely for flow. No gains or losses to pits. Fill DP w/4.0 bbls. RIH wI 31/2" DP to 450 jts. (14,488'). Getting returns as RIH wI pipe, but stopping and falling in between joints. Fill DP wI 3.2 bbls. Order 290 bbls brine (already mixed in tank) from MI. 450 jts in hole, well start to flow and gas in returns. Return mud wt of 10.8 #/gal. Shut in well and circulate at 3 bpm, 700 psi on DP, 20 psi on Csg. Loss's at 20- bblslhr. 70 bbls 10.9 #/gal brine in pits. DECOMP 400 bbls circulated with 50 bbls losses. No flow test. Annulus fluid level dropping, but gas bubbling. After 15 minutes, well flowing and 10 psi SICP. 0 psi SIDP. Continue to circulate. Waiting on Peak to deliver brine. DECOMP 100 additional bbls circulated @ 3 bpm, 650 psi DP, 10 psi csg. 10 bbls losses. No flow test. Flluid level stable, no bubbling. RU to RIH picking up singles. DECOMP RIH wI DP. monitoring returns and filling DP every 10 joints. Well remaining stable. Displacements consistent, 2 bbls in DP and 1.6 bbls returns for every 10 joints. 540 joints in hole (17,326') at crewchange. DECOMP RIH wI DP. monitoring returns and filling DP every 10 joints. Well remaining stable. Displacements consistent, 2 bbls in DP and 1.6 bbls returns for every 10 joints. 561 joints in hole (17,988'). DECOMP RIH wI DP. monitoring returns and filling DP every 10 joints. Well remaining stable. Displacements consistent, 2 bbls in DP and 1.6 bbls returns for every 10 joints. Tag fill at 18366'. UD DP to put muleshoe at 18,335'. Rig up to CBU and condition hole. DECaMP Break circulation at 1 bpm @ 500 psi. increase circulation rate to 3.0 bpm @ 920 psi. CBU. Pumped 611 bbls for bottoms up. Losses during CBU = 65 bbls. Circulated additional 65 bbls. to cover losses. Mix 30 bbl.spacer in pill pit. MI mudman on location supervising spacer mixing. Clear and clean rig floor and general housekeeping on rest of rig equipment. DECOMP Monitor well for stable parameters. Well flowing a trickle and some gas breaking out at surface. Closed annular preventer 3.00 CLEAN C 2.00 CLEAN C 05:00 - 05:30 0.50 CLEAN C DECOMP 05:30 - 06:00 0.50 CLEAN C DECOMP 06:00 - 07:30 1.50 CLEAN C DECOMP 07:20 - 10:30 3.17 CLEAN C DECOMP 10:30 - 11 :30 11 :30 - 12:00 12:00 - 17:30 17:30 - 19:00 19:00 - 20:00 I 20:00 - 00:00 21212006 00:00 - 02:00 1.00 CLEAN C 0.50 CLEAN C 5.50 CLEAN C 1.50 CLEAN C 1.00 CLEAN C 4.00 CLEAN C 2.00 CLEAN C Printed: 2/13/2006 12:00:59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To . .n ___________._.___ ..-.....-.----- 2/2/2006 00:00 - 02:00 02:00 - 02:30 02:30 - 05:15 05:15 - 06:00 06:00 - 07:30 BP EXPLORATION Operations Summary Report Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Code I NPT i Ph~==J C DECOMP MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Hours Task ---.....--.... 2.00 CLEAN 0.50 CLEAN C DECOMP 2.75 CLEAN C DECOMP 0.75 CLEAN C DECOMP 1.50 CLEAN C DECOMP 07:30 - 09:30 2.00 CLEAN C DECOMP 09:30 - 10:00 0.50 CLEAN C DECOMP 10:00 - 13:30 3.50 CLEAN C DECOMP 13:30 - 15:30 16:30 - 17:30 2.00 CLEAN C DECOMP 1.00 CLEAN C DECOMP 17:30 - 18:00 0.50 CLEAN C DECOMP 18:00 - 20:00 2.00 CLEAN C DECOMP ; 20:00 - 22:00 2.00 CLEAN C ' DECOMP 22:00 - 23:00 1.00 CLEAN C DECOMP Page 12 of 16 Spud Date: 10/15/2001 End: Description of Operations and monitored SIDPP and SICP. SIDPP = 0 psi. SICP = 20 psi. Wait on LCM pill to arrive from MI plant. POH UD 14 jts. 3-1/2" DP to place bottom of BHA @ 17,893' (397' above bottom perf.) so that when tail of sized salat pill exits bottom of BHA, leading edge of salt pill will be at top perf @ 18,290'. Spot 12.7 #/gal sized salt pill across perfs. Pumped 15 bbl Flo-Vis spacer @ 10.9 #/gal, 12 bbl salt pill, 15 bbl Flo-Vis spacer followed by 81 bbls. 10.9 #/gal brine to spot leading edge of salt pill at muleshoe. Closed pipe rams and bullheaded 15 bbls. kill weight brine @ 2.0 bpm at 420 psi drill pipe pressure and 430 psi casing pressure, to spot leading edge of LCM pill at bottom perforation. SID pump and monitor well. Monitor SIDPP and SICP. SIDPP = 12 psi, SICP = 20 psi at 45 minutes after shutdown pump. SIDPP @ 10 psi, SICP at 20 psi. Pump 6 bbls at 1/2 bpm, no increase in pressures. Bleed and monitor well. Fluid level stable. Circulate wI 10.9 #1 gal brine @ 4 bpm, losing 10% to formation at this rate. Reduce rate to 3 bpm, 900 psi DP psi, no losses. Total losses of 10 bbls. (estimate 5 bbls pill and 10 bbls spacer in rathole). Circulate and sweep well bore with 5 bbls Flo-Vis spacer and condition brine. Circulate and condition brine, 10.8# heavy in and out, @ 3 bpm, 900 psi DP, 0 psi Csg pressure. No gains or losses to pits. 375 bbls returns, Flo-Vis spacer returns to pits (100 bbls early), continue to circulate. 65 bbls returns of 10.6# spacer-brine. Discuss current status of well with Lou Grimaldi of AOGCC. 500 bbls returns, (annulus volume 472 bbls). Brine returns at 10.8# +. Bleed and open to no-flow test. Well flowing slightly. Circulate and begin to increase brine weight to 11.1 #/gal. Circulate at 3 bpm, 950 psi DP, 0% losses. Circulate 700 bbls @ 3 bpm, weight brine from 10.8# + to 11.1 #/gal. Losses @ 3 bbls per hour, (12 bbls) Shut down and no-flow test well, fluid level falling. Circulate 100 bbls @ 2.5 bpm, , checking mud weight. Shut down pumping and no-flow test the well. Fluid losses at 12 bbls/hr. Pump 13 bbls of 12.7#/gal sized salt pill, displace with 11.1 #/gal brine. Squeeze 2 bbls into formation shut down and monitor pressures. Initial at shutdown of 220 psi Csg and 120 on DP. Bleed to 0 psi in 10 minutes. Open well and no-flow test. Well taking fluid at 12 bbls I hour After 15 minutes, fill hole with 1 bbl. Losses to 4 bbls per hour. Order 40 bbls of sized salt pill from MI, trucks from Peak. Monitor well parameters. Order 200 bbls 11.1 ppg brine, ultrasal (salt) for spacer from MI plant. Losses at -3 bbls. per hr. Circulate hole at 2.0 bpm at 390 psi DP. Wait on fluids to arrive. Losses 1.0 bbl. CBU @ 2.0 bpm @ 390 psi. to condition and even out brine weight distribution. No fluid losses. Fluids arrived on pad - 200 bbls. 11.1 ppg brine, 40 bbls sized salt LCM pill and 35 bags Ultrasal spacer material. Unloading 11.1 brine into pits. Rig loader broke down - repairing same. Mixing 35 bbls. 200K cPs Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report DECOMP LSRVspacer fluid in pill pit. DECOMP Prep to pump LCM sized salt pill. Mixing 35 bbls. 200K cPs LSRVspacer fluid in pill pit. Circulating well at 2.0 bpm at 400 psi. No fluid losses. DECOMP Prep to pump LCM sized salt pill. Mixing 35 bbls. 200K cPs LSRVspacer fluid in pill pit. Walk through procedure for pumping LCM pill. PJSM all crew. DECOMP Pump LCM pill per prescribed program from town. Pump 20 bbl. spacer, 40 bbl. LCM pill, 15 bbl. spacer, 65 bbl. 11.1 ppg brine flush. Close pipe rams and begin bullheading spacer into perfs. Perfs. locked up immediately after starting bullheading. Pressured up casing to 350 psi max. pressure. SID rig pump. SIDPP = 420, SICP = 350. DP bled off to 150 psi in 10 minutes and casing bled off to 110 psi in 10 minutes. DECOMP Pumped 2 bbls. @ 0.5 bpm and DP pressured up to 550 psi and casing pressured up to 350 psi. SID rig pump. SIDPP = 550 psi, SICP = 350. DP bled off to 230 psi in 10 minutes and casing bled off to 190 psi in 10 minutes. Bled DP and csg to 0 psi. No flow into pits through choke line. Line up manifold and pump 48 bbls. 11.1 ppg brine to clear DP and dart of LCM pill and spacer. SID rig pump and monitor well parameters. Monitor well parameters. Fluid dropped about 1.5 ft. in riser. Prep to POH wI DP to 120K PU weight. POH w/3-1/2" DP laying down to reach 120K pickup weight. Lay down 26 joints, BHA at depth of 17106'. PU weight of 128K. Hole taking twice DP displacement to fill. Shut down and observe fluid level. Fall 2' in riser in 15 minutes. Continue to POH. DECOMP 515 joints wI BHA in hole (16539') Monitor fluid level. Falling 4 ft in stack over 30 minutes. PUMU HES rtts wI storm packer set @ 40'. 120K pu wt. Pull wear ring and pump out stack. Install TWC and blank penetrator in tbg hanger. Set tbg hanger and FMC torque in lock down screws. N/D BOP's to change stack configuration to bring same into compliance with BP standards and state granted variance to AOGCC regs. N/U BOPE to change configuration to bring into compliance with BP standards and state granted variance to AOGCC regs. Continue to NU BOPE to change configuration. Safety meeting with crew to discuss operations and working safely with suspended loads. Call Lou Grimaldi wI AOGCC and notify of BOPE testing to start -12:30. Caledl Lou Grimaldi wI AOGCC for BOPE testing. State witnessing waived. Finishing NU operations and prep for BOPE test. Weekly BOPE testing. Test BOPE 250/3500 psi lolhi. Completed BOPE test. Blow down lines. Choke line beteen modules froze up. Steam thaw same and blowout choke line with air. UD test plug. P/U 1 jt. 3-1/2" DP and 7" HES RTTS retrieving tool to latch onto RTTS packer Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Date From - To ¡ Hours· Task i Code NPT: Phase . .-.....-..-------.-- ....--- 2/2/2006 22:00 - 23:00 23:00 - 00:00 1.00 CLEAN C 1.00 CLEAN C 2/3/2006 00:00 - 01 :40 1.67 CLEAN C 01 :40 - 02:55 1.25 CLEAN C 02:55 - 03:05 0.17 CLEAN C 03:05 - 03:30 0.42 CLEAN C DECOMP 03:30 - 04:05 0.58 CLEAN C DECOMP 04:05 - 05:00 0.92 CLEAN C DECOMP 05:00 - 07:15 2.25 CLEAN C DECOMP 07:15 - 08:30 1.25 CLEAN C DECOMP 08:30 - 12:00 3.50 CLEAN C 12:00 - 00:00 12.00 BOPSU C DECOMP 2/4/2006 00:00 - 06:00 6.00 BOPSU DECOMP 06:00 - 10:00 4.00 BOPSU DECOMP 10:00 - 12:00 2.00 BOPSU DECOMP 12:00 - 20:30 8.50 BOPSU DECOMP 20:30 - 00:00 3.50 CLEAN DECOMP 2/5/2006 00:00 - 00:30 0.50 BOPSU DECOMP 00:30 - 03:30 3.00 BOPSU DECOMP Page 13 of 16 Start: Rig Release: Rig Number: 1/14/2006 2/8/2006 N3S Spud Date: 10/15/2001 End: Description of Operations ..............--. .--... Printed: 2/13/2006 12:00:59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To - ------....- ._. --. 2/5/2006 00:30 - 03:30 03:30 - 04:30 04:30 - 06:30 06:30 - 08:30 08:30 - 11 :30 11 :30 - 13:00 13:00 - 15:00 15:00 - 16:00 Page 14 of 16 BP EXPLORATION Operations Summary Report MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Hours I Task Code I NPT I 3.00 BOPSU C 1.00 CLEAN C 2.00 CLEAN C 2.00 CLEAN C 3.00 CLEAN C 1.50 CLEAN C 2.00 CLEAN C 1.00 CLEAN C 16:00 - 17:00 1.00 CLEAN C 17:00 - 18:00 1.00 CLEAN C 18:00 - 19:00 1.00 CLEAN C 19:00 - 20:00 1.00 CLEAN C 20:00 - 21 :00 1.00 CLEAN C 21 :00 - 21 :30 0.50 CLEAN C 21 :30 - 00:00 2.50 CLEAN C Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Spud Date: 10/15/2001 End: Phase I Description of Operations ___ _----.1.____________ _ _ _____ _n_________nn______________n_ DECOMP and storm valve. DECOMP Close TIW valve. Sting into storm valve. Open TIW valve. DP on vacuum. Closed annular preventer. Released packer. SICP = 220 psi, SIDpp = 200 psi. Open choke and bleed off pressure to gas buster. Recovered 2.3 bbls. to pits. Open annular preventer. Fill stack and riser w/1.0 bbl. and monitor well. Well stable for 5-10 minutes and gas bubble migrated to surface. Shut well in and monitor pressures. SICP - 20 psi., SIDPP = O. DECOMP Monitor well parameters. Bleed Csg pressure, open well and fill the hole with 12 bbls. Break out and lay down RTTS and storm valve. Gas bubbling in riser. Bottom of BHA @ 16538' (515 joints). Top perf at 18290'. Rat hole volume from bottom of BHA to top perf of 67 bbls. DECOMP Circulate and condition brine. Pump @ 2 bpm, 450 psi DP, 20 psi Csg, total of 10 bbls to catch fluid and get returns. Losses at 18 blslhour. Increase pump rate to 3 bpm, 770 DP psi, 10 psi Csg, losses at 30 bbls/hr. Reduce rate back to 2 bpm. 220 bbls away, losses at 10 bbllhr. Continue to circulate and monitor. DECOMP 630 bbls circulated, (hole volume surface to surface of 551 bbls. MW in and out of 11.1 #/gal. Circulate back 50 bbls +1- of spacer. No sign of salt pill. Consistent losses of 13 - 15 bbls/hr. Total losses of 70 bbls. Shut down and no flow test well. DP on vacuum. Fluid level stable but gas bubbling at surface. Circulate at 2 bpm, taking returns out flow line. DECOMP Circulate 140 bbls (DP volume of 114 bbls, annular volume of 437 bbls.), MW in and out of 11.1 #/gal. Losses of 5 bbls I hour. No flow test well. Fluid level dropping slightly, gas bubbling. Circulate again increasing rate to 3 bpm monitoring gains and losses. DECOMP Circulate 100 bbls at 3 bpm, no loss I no gain. Magnitude of bubbling decreasing, increase circulation rate to 3.5 bpm. Circulate bottoms up DECOMP 430 bbls total circulation (bottoms up). Total losses of 3 bbls during this circulation. No flow test, hole stable wI no gas bubbling. Total losses since unseating RTTS wI storm valve and 2 circulations = 73 bbls. Begin POH and lay down 3 1/2" DP, circulating across the top with charge pump continuously. DECOMP 85 joints OOH, BHA @ 13857'. Minimal losses. Volume to fill hole slightly more than DP displacement. DECOMP 113 joints OOH, BHA @ 12974'. Calculated volume to fill hole of 9 bbls. Total losses of 10 bbls. (1 bbl more than calculated DP displacement) DECOMP 141 joints OOH, BHA @ 12091'. DECOMP 168 jts. OOH, BHA @ 11239'. 9.6 bbls to fill hole. Averaging 10 bbls./hr. fluid losses. DECOMP i 180 total jts. OOH. BHA @ 108600'. Avg. fluid losses = 3.1 i bbls/1 0 jts. pulled or double drill pipe displacement. Fluid losses consistent over last several hours. DECOMP 190 total jts. OOH. BHA @ 10544'. Fluid losses last 10 jts. = 1.8 bbls. or actual DP displacement. DECOMP 293 total jts. OOH. BHA @ 7277'. Fluid losses = 3.1 bbls. last Printed: 2/13/2006 12:00:59 PM BP EXPLORATION Operations Summary Report 10 jts. POH LDDP. 310 jts. OOH. BHA @ 6739'. Fluid losses 3.2 bbls. last 10 jts. POH LDDP. 390 jts. OOH. BHA @ 4201'. Fluid losses 3.1 bbls. last 10 jts. POH LDDP. 430 jts. OOH. BHA @ 2950'. Fluid losses 6.4 bbls. last 10 jts. POH LDDP. 470 jts. OOH. BHA @ 1720'. Fluid losses 3.1 bbls. last 10 jts. POH LDDP to 510 jts. OOH. BHA @ 482'. Fluid losses 6.2 bbls. last 10 jts. POH LDDP to 515 jts. OOH. Breakout and lay down BHA. Count DP and reconcile with tally. Clear rig floor, PU equipment to Run ESP PJSM. Discuss ESP handling and running procedures. Discuss well control responses and actions. Discuss roles and responsibilities. Discuss importance of staying focused and observant at all times. RUNCMP PUMU Centrilift ESP completion. Losses @ 10 bbls I hour as MU ESP. Continue to MU Centrilift BHA, on 10' pup, 1 jt 2 7/8" tbg. Test cable, MU XN nipple wI XXN plug with plug extension on 10' pup, 4 joints tbg and bottom GLM assembly (10' pups either side), with circ valve installed. Losses @ 10 bbll hour. Installing LaSalle cable clamp protectors on every joint for 6000'. RIH w/2 7/8" tbg out of derrick. 30 stds (2 its per stand) out of derrick in hole. Test cable every 2000'. RIH w/2 7/8" tbg out of derrick. 50 stds (2 jts per stand) out of derrick in hole. Test cable. Fluid losses = 10 bbls./hr. Ordered 180 bbls brine from MI. RIH w/2 7/8" tbg out of derrick. 90 stds (2 jts per stand) out of derrick in hole. Fluid losses = -10 bbls./hr. RIH w/2 7/8" tbg out of derrick. 110 stds (2 jts per stand) out of derrick in hole. Fluid losses = -10 bbls./hr. RIH w/2 7/8" tbg out of derrick. 120 stds (2 jts per stand) out of derrick in hole. Test ESP cable. Fluid losses = -6 bbls./hr. Noted spiral deformed cable on cable spool. Centrilift service technician made aware of deformation and cleared cable for installation in well. RIH w/2 7/8" tbg out of derrick. 122 stds (2 jts per stand) out of derrick in hole. Test and splice ESP cable. Fluid losses = -4 bbls./hr. RIH w/2 7/8" tbg out of derrick. 135 stds (2 jts per stand) out of derrick in hole. Fluid losses = -.6 bbls/hr. RIH w/2 7/8" tbg out of derrick. 155 stds (2 jts per stand) out of derrick in hole. Fluid losses = -0 bbls/hr. Crew change. Monitor well for fluid losses. Fluid losses = 6 bbls./hr. RIH w/2 7/8" tbg out of derrick. 185 stds (2 jts per stand) out of derrick in hole. Fluid losses = -6 bblslhr. Centrilift check cable. RIH w/2 7/8" tbg picking up singles out of pipe shed. Ran 208 stands out of derrick. Fluid losses = -8 blslhr Legal Well Name: MPF-94 Common Well Name: MPF-94 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S I ' , ' Date From - To : Hours I Task ¡ Code NPT' Phase 2/5/2006 21 :30 - 00:00 2.50 CLEAN C DECOMP 2/6/2006 00:00 - 01 :00 1.00 CLEAN C DECOMP 01 :00 - 03:00 2.00 CLEAN C DECOMP 03:00 - 04:30 1.50 CLEAN C DECOMP 04:30 - 06:00 1.50 CLEAN C DECOMP 06:00 - 07:00 1.00 CLEAN C DECOMP 07:00 - 09:00 2.00 CLEAN C DECOMP 09:00 - 10:00 1.00 RUNCO RUNCMP 10:00 -10:15 0.25 RUNCO RUNCMP 10:15 - 15:00 4.75 RUNCO 15:00 - 18:00 3.00 RUNCMP 18:00 - 19:30 1.50 RUNCMP 19:30 - 22:30 3.00 RUNCMP 22:30 - 00:00 1.50 RUNCMP 2/7/2006 00:00 - 00:15 0.25 RUNCMP 00: 15 - 03:30 RUNCMP 03:30 - 04:30 1.00 RUNCMP 04:30 - 05:30 1.00 RUNCMP I I 05:30 - 06:00 0.50 RUNCO RUNCMP 06:00 - 07:00 1.00 RUNCMP 07:00 - 08:30 1.50 RUNCO RUNCMP Page 15 of 16 Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S Spud Date: 10/15/2001 End: Description of Operations ...-.---..... Printed: 2/13/2006 12.00:59 PM Page 16 of 16 BP EXPLORATION Operations Summary Report Start: 1/14/2006 Rig Release: 2/8/2006 Rig Number: N3S p~~~~L___ n_______________~_~scr~~t~~nn~:_~~_e_~at_io~s RUNCMP RIH wI 41 joints out of pipe shed. (Total of 457 joints I includes 208 stands from derrick). Fluid losses = -8 bbls/hr. Continually keeping hole full. RUNCMP RIH w/2 7/8" tbg picking up singles out of pipe shed. 501 joints total. ESP at 15750'. Change spools and splice cable. Make ESP Cable Splice and test--good test. Continue RIH wI new ESP Completion. Install Penetrator and make Top Field Connection and Test downhole ESP unit and cable. Good test. PumpMate indicated pump intake pressure = 4220 psi. Fluid gradient = .575psi/ft. or 11.06 ppg. Land Tubing Hanger. Bottom ESP motor = 18064' md. Pump Intake @ 18023' md. RILDS. UD landing Joint. P/U lubricator. Set TWC and test to 2500 psi. Nipple Down BOPE. Nipple down BOPE. Set BOPE in transportation cradle. Nipple Up Lockdown Flange, Tubing Head Adaptor and Production Tree. Perform final electrical tests of downhole ESP system and Wellhead ESP Penetrator. Test void to 5000 psi. Charted test. P/U Lubricator, pull TWC. Set BPV. UD Lubricator. Secure Tree and Cellar. Release Rig @ 0600 Hours. Prep to RDMO. Cleaning Pits and Cuttings Box with hot water and Guzzler. Clean out free salt buildup in Pits using 50-Bbls hot water and Super Sucker. Super Sucker Truck developed leak from Glycol Reservoir Expansion Tank overflow. Truck driver found leak right away during normal walk-around. He shut down the truck and moved containment liner under the reservoir and expansion tank. Environmental Responder (Barron Rutherford) estimated 2-gals of Glycol were recovered from the hard-packed snow and 3-gals were recovered from the containment liner. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Date From - To Hours Task Code NPT _.. ..... n___ __ 2/7/2006 08:30 - 10:00 10:00 - 11 :30 1.50 11 :30 - 14:30 3.00 14:30 - 17:00 2.50 17:00 - 19:30 2.50 RUNCMP RUNCMP RUNCMP 19:30 - 20:00 0.50 RUNCMP 20:00 - 00:00 4.00 RUNCMP 2/8/2006 00:00 - 01 :30 1.50 BOPSU P RUNCMP 01 :30 - 04:00 2.50 WHSUR P WHDTRE 04:00 - 06:00 2.00 WHSUR P WHDTRE 06:00 - 09:30 3.50 DEMOB P POST 09:30 - 11 :00 1.50 DEMOB P POST Spud Date: 10/15/2001 End: Printed: 2/13/2006 12:00:59 PM ~ 29/16"-5M CIW. Wellhead' 11" Gen 5 FM 11 x 2 9/16" Hgr, w/2 7/8" T T&B, & 2.5" Type 'H' BPV Profile M PF -94 2.5" 4 2.5" 4 3-3/8" 12 3-3/8" 12 112' 10 3/4" Halliburton ES Cementer I KOP @ 500' to 3100' Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' 103/4", 45#/ft., L-80 BTC 110,341' I 27/8" 6.5 ppf, L-80 8 rd. EUE tubing (drift 10 = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift 10 = 6.151", cap. = 0.0383 bpf) (cap w/2 7/8" tbg = .0302 bpf) Stimulation Summarv 12/11/01 Frac -117,298# of 16/20 C/lite 73,740# of 12/18 C/lite behind pipe. Perforation Summary Ref LOI;I SWS anadrill COR resistivity. dated 10/17/01. Size SPF Interval 18290'-18292' 18328' -18330' 18300'-18310' 18325'-18335' 61. KB Elev. = 44' (N-27E) ~. GL Elev. = 11' RT to Tbg. Spool = 33.0' (N-27E) Camco 2-7/8" xi" KBMM GLM I 118' I Camco 2-7/8" xi" KBMM GLM 114,951' I Camco 2-7/8" xi" KBMM GLM 117,784' I 2-7/8" XN nipple (102.205") 117,937' I 117.979' I GPDIS Discharge Head Tandem Pump, 74 stage - GC2117 980' I & 112 stage - GC2900 GPMTAR . Gas Separator 118 019' 1 GRSFTX AR H6 (400 Series Internals) , Intake 18,019' MD = 7296' TVD Tandem Seal Section I 1 GSB3DB UT/LT AB/HSN PFSA 18,024' Motor, 2600 HP, 2345 volt, 69 amp, KMH 118,037' I Exp. PumpMate wI 6 Fin Centralizer 118,060' 1 18,060' MD = 7335' TVD 7" x 4.5" Baker Premier pkr. 118,155' 1 4.5"HESXN-Nipple(3.813") 118.181' I (No-go 3.75" id) 41/2" WLEG 118,193' I (PBTO) 118,466' I 7" Float Collar 118,469' I 7" Float Shoe I 18,554' I OATE REV. BY COMMENTS MILNE POINT UNIT 11/21/01 BMH Drill and run frac string. N-27E 12/11/01 M. Linder Perf with coil and Frac with D.S. WELL MPF-94 (KUP) 02108/02 MDO ESP Completion 4-ES API No 50-029-23040 02/26/05 Lee Hulme ESP Re-Completion 4-ES 02/08/06 Lee Hulme ESP Re-Completion 3-ES BP EXPLORATION (AK) ') STATE OF ALASKA ) ALASKA v{L AND GAS CONSERVATION COlvlMISSION DE REPORT OF SUNDRY WELL OPERATIONtt CEI'l~r) MAR 21 2005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 355016 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 0 Plug Perforations 0 Stimulate 181 Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well Alask~ ç¡t\aÐ~ß ~7~R~_.,._---~._- . · UII. ~e'r·,,¡mt ~J~mlTmuu:m oAnmW~nsion 44.33' 18595 7853 18469 7730 112' 10307' 18523' feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD 20" 112' 112' 1 0-3/4" 1 0341 ' 4454' 7-5/8" 18555' 7814' 99519-6612 18290' - 18335' 7557' - 7600' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 201-170-00 6. API Number: 50-029-23040-00-00 9. Well Name and Number: MPF-94 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands Burst Collapse 5210 2480 6890 4790 SCAN~~E[J) MAR ~~ ¿i~h lOOfil 2-7/8",6.5# 4-12", 12.6# 7" x 4-1/2" Baker Premier Packer L-80 L-80 18013' 18146' - 18193' 18155' Treatment description including volumes used and final pressure: &~BDMS 8Ft MAR 2 i 2005 13. Oil-Bbl Prior to well operation: 574 Subsequent to operation: 833 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 407 268 370 373 369 380 Tubinq Pressure 349 346 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 '17. Printed Name Sondra Stewman Sign --,,-:J:::L"--_ Form 1 0-404 Revised 04/2004~ Title Technical Assistant Phone Prepared By Name/Number: Date 0'-)' 2-J ,- 0 S Sondra Stewman, 564-4750 Submit Original Only 564-4750 I "'" I ... :, ¡ I \ -. l i \ ; f ; '-..,,1 l \ I.~_. ~ 41/16" - 5M CIW Wellhead: 11" Gen 5 FMC w/13 x 4.5" NSCT Hgr. ') 112' 1 A 10 3/4" Halliburton ES Cementer I 2493' 1 0 KOP @ 500' to 3100' Max. Hole Angle = 77 deg. Max. Hole Angle Thru Perfs. = 15 deg. Max. Dog leg Severity = 6.21 @ 2900' 103/4",45#/ft.,L-80BTC 110,341' I .. 27/8" 6.5 ppf, L-80 8 rd. EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151 ", cap. = 0.0383 bpf) (cap wI 27/8" tbg = .0302 bpf) Stimulation Summary 12/11/01 Frac - 117,298# of 16/20 C/lite 73,740# of 12/18 C/lite behind pipe. Perforation Summary Ref. J o<J SWS anadrill COR resistivity. dated 10/17/01. Size SPF Interval (TVD) 2.5" 4 2.5" 4 3-3/8" 12 3-3/8" 12 18290'-18292' 18328'-18330' 18300'-18310' 18325'-18335' 7551'-7552' 7594'-7595' 7567'-7576' 7591'-7600' MPF-94 :.1. ,I· ft ~~,), j::1 .( .} , I- ··'.1··.··. ;¡:' , ,;; 1 :i~ :¡~) -1. .j.*- 1I.:·:J. ~~. ~ 'r ¡.jio. J lì;:D ......;,J\.. ~ ;$:. ~..w;;.,·,,'~.;.t..¡¡,..¡.. in . I.J..I ;, Al: ill! JU[lll~l[(m¡:~ ( ) KB Elev. : 44: (N-27E) L. -d' GL Elev. - 11 RT to Tbg. Spool = 33.0' (N-27E) ~ Camco 2-7/8" x 1" KBMM GLM I 136' I Camco 2-7/8" x 1" 115000' 1 ~ KBMM GLM Camco 2-7/8" x 1" 117803' 1 KBMM GLM 2-7/8" XN nipple 117,955' I (ID 2.205") MS-1 Pressure Head 117,998' 1 Tandem Pump, 122 stage - GC2200 117 999' I & 19 stage - GC8200 GPMTAR 1:1 ' Gas Separator 118 027' 1 GRSTX AR H6 (400 Series Internals) , Intake 18,028' MD = 7,303' TVD Tandem Seal Section 1 I GSB3DB UT/L T AB/HSN PFSA 18,029' Motor, 190 HP, 2415 volt, 48 amp, KMH 118,043' 1 Phoenix MS-1 Sensor wI 6 Fin Centralizer 118,069' I 18,069' MD = 7,344' TVD 7" x 4.5" Baker Premier pkr. 118,155' 1 4.5" HES XN-Nipple (3.813") I 18,181' I (No-go 3.75" id) 41/2"WLEGI18,193' 1 (PBTD) 118,466' 1 7" Float Collar I 18,469' 1 7" Float Shoe I 18,554' 1 DATE REV. BY COMMENTS 11 /21 /0 1 BMH Drill and run frac string. N-27E 12/11/01 M. Linder Perf with coil and Frac with D.S. 02/08/02 MOO ESP Completion 4-ES 02/26/05 Lee Hulme ESP Re-Completion 4-ES Mil NF POINT UNIT WFJ J MPF-g4 (j<UP) API No. 50-n?g-?3040 RP FXP. ORATION (AK) ) ) SF' EXPLORATION ·'OperatipnsSuI111118ry:FfC!þort Page 1· ()f 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/22/2005 Rig Release: 2/26/2005 Rig Number: 4ES Spud Date: 10/15/2001 End: 2/26/2005 Date·. From - To Hours Task Code NPT Phase Description.ofOperations 2/22/2005 13:00 - 14:00 1.00 MOB P PRE Scope down & lower dewrrick. RID from MPF- 13. 14:00 - 15:30 1 .50 MOB P PRE Move from MPF-13 to MPF-94. Begin rigging up rig. Spot in Pits, pipe shed & Camp. 15:30 - 17:00 1.50 RIGU P PRE Rig up rig. Raise & scope up derrick. 17:00 - 18:00 1.00 RIGU P DECOMP R/U lines to tree. Spot in & lay lines to tiger tank. RIU HCR to IA. Accepted rig @ 1700 hrs. 18:00 - 19:00 1.00 PULL P DECaMP PIU lubricator, pull BPV & UD lubricator. Test lines to Trre & tiger tank. Take on seawater. 19:00 - 19:30 0.50 PULL P DECaMP Hold PJSM & Pre-spuid meeting wI all hands. 19:30 - 00:00 4.50 KILL P DECaMP Open well. SITP = 540 psi. SICP = 710 psi. Pump & circulate well wI hot seawater. 3 BPM @ 1100 psi. 2/23/2005 00:00 - 01 :30 1.50 KILL P DECaMP Con't to circulare well WI heated seawater. Pumped3 BPM @ 1100 psi. Pumped total of 680 bbls. SID & monmitor well. Well not dead. 01 :30 - 04:00 2.50 KILL P DECaMP Monitor well & obtain SI pressures. Last pressure 240 psi. Calc weight needed 9.4 ppg. Call for fluid. 04:00 - 05:00 1.00 KILL P DECOMP Circulate well wI excess seawater. Pumped 200 bbls, 3 BPM @ 1 050 psi. 05:00 - 06:00 1.00 KILL P DECOMP Monitor well & wait on 9.4 ppg fluid. 06:00 - 10:00 4.00 KILL P DECOMP continue to wait on 9.4 ppg Brine. Service Rig. Perform Derrick inspection. Continue to monitor Well. 10:00 - 15:00 5.00 KILL P DECOMP Take on first and second load of Brine in Rig Pits. Third and final load just leaving MI Plant. 15:00 - 20:30 5.50 KI LL P DECOMP SITP 290 psi, SICP 290 psi. Start killing Well with 9.4 ppg Brine down Tubing at 4.0 bpm/1680 psi. Take returns to Tiger Tank. Bull headed 25 bbls. 20:30 - 23:00 2.50 KILL P DECOMP SID monitor well. Well flowed, then died, then started to flow again. WIO salt to weight up to 9.6 ppg. TP 0 psi. Ann 0 psi. 23:00 - 23:30 0.50 KILL P DECOMP Weight up fluid in pits to 9.6 ppg. 23:30 - 00:00 0.50 KILL P DECaMP Kill well pump 9.6 ppg kill fluid. pumped tbg vol & SID Tbg on slight vacum. 4 BPM @ 1630 psi. 2/24/2005 00:00 - 03:00 3.00 KILL P DECaMP Con't to circulate & kill well wI 9.6 ppg brine. Pumped 4 BPM @ 1630 psi. Pumped total of 733 bbls. Have 9.6 in & out. SID & monitor well. Lost 111 bbls during circulation of 9.6 ppg brine. 03:00 - 04:00 1.00 KILL P DECaMP Monitor well. TP 0 psi, Ann 0 psi. Well flowing. leave well open & bleed off. Well slowly died. Monitor well, well dead. 04:00 - 04:30 0.50 WHSUR P DECaMP Install & test TWC. Drain & Blow down lines. RID lines. 04:30 - 05:30 1.00 WHSUR P DECaMP Bleed off hanger void & N/D tree. 05:30 - 08:00 2.50 BOPSUR P DECaMP Nipple up BOPE. 08:00 - 08:30 0.50 BOPSUP P DECaMP Rig up Test Equipment. 08:30 - 11 :30 3.00 BOPSUP P DECaMP Test BOPE per BP/AOGCC requirements. Test at 250/3,500 psi. Good Test. State's right to witness Test waived by C. Sheeve. WSL and Tool Pusher witnessed Test. 11 :30 - 12:00 0.50 BOPSUF P DECOMP Blow down lines. Rig down Test Equipment. 12:00 - 12:30 0.50 BOPSUPP DECOMP Pick-up Lubricator and pull TWC. Lay down same. Well on very slight vacuum. 12:30 - 13:30 1.00 PULL P DECOMP Pick-up Landing Joint. BOLDS. Pull Tubing Hanger to Floor. Hanger broke free at 11 OK...pulling free at 100K. Lay down Landing Joint and Hanger. 13:30 - 14:00 0.50 PULL P DECOMP Cut and test ESP Cable. Pull Cable over Sheave and attach to Spooling Unit reel. 14:00 - 18:00 4.00 PULL P DECOMP Start to POOH with 2 7/8" tubing and ESP assembly. 18:00 - 19:30 1.50 PULL P DECOMP Con't To POOH to 7920' & standback completion. Printed: 2/28/2005 9:05:11 AM ) ) BPEXPLdRATION Operatiol1sSUml'n.arY"Report ' Page 2.of.2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-94 MPF-94 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/22/2005 Rig Release: 2/26/2005 Rig Number: 4ES Spud Date: 10/15/2001 End: 2/26/2005 Date From-To Hours Task Co.de NPT Phase ' Description of Operations 2/24/2005 19:30 - 20:00 0.50 PULL P DECaMP Change out spool in spooling unit. Pump 70 bbls down tbg to circulate oil cap from Annulus. 20:00 - 00:00 4.00 PULL P DECaMP Con't to POOH & stand back completion. Had 150 stands out. Note: Had to cut several bolts on LaSalle clamps. 2/25/2005 00:00 - 02:00 2.00 PULL P DECOMP Con't to POOH & stand back completion. 02:00 - 04:00 2.00 PULL P DECOMP Inspect & LID ESP. Motor burned, pump clogged wI very fine sand & grit. 04:00 - 05:00 1.00 PULL P DECaMP Clear & clean rig floor. Change out spools in spooling unit. Load new ESP. 05:00 - 09:00 4.00 RUNCOMP RUNCMP Pick-up and service new ESP Assembly. 09:00 - 17:00 8.00 RUNCOMP RUNCMP TIH with ESP Assembly and 2 7/8" Tubing. Ran 80 stands. Pump thru ESP & check cable every 2000'. Ran 80 stands. 17:00 - 20:30 3.50 RUNCOMP RUNCMP Change reels & make reel to reel splice. Test same. 20:30 - 00:00 3.50 RUNCOMP RUNCMP Con't to RIH wI ESP on stands of 27/8" tubing. 132 stands in hole. Pump thru ESP & check cable evry 2000'. 2/26/2005 00:00 - 02:00 2.00 RUNCOMP RUNCMP Con't to RIH wI ESP completion on 2 7/8" tubing. Pump thru ESP & check cable every 2000'. 1 BPM @ 1080 psi. Ran 165 stands. 02:00 - 05:00 3.00 RUNCOMP RUNCMP Change reels & make reel to reel splice in cable. Test same. 05:00 - 06:30 1.50 RUNCOMP RUNCMP Continue to RIH with 2 7/8" ESP Completion as follows: ESP Assy, XN-Nipple, 3 ea GLMs, 572 Jts 2 7/8" 6.5 Iblft EUE 8rd L-80 Tubing. 06:30 - 07:00 0.50 RUNCOMP RUNCMP Pick-up Landing Joint. Make-up Tubing Hanger. Install Penertrator. 07:00 - 09:30 2.50 RUNCOMP RUNCMP Make top field Connector splice. Attach to Penetrator and test. 09:30 - 10:00 0.50 RUNCOMP RUNCMP Land Tubing Hanger. RILDS. Set and test TWC. 10:00 - 11 :00 1.00 BOPSUR P RUNCMP Nipple down BOP Stack. 11 :00 - 12:30 1.50 WHSUR P RUNCMP Nipple up Production Tree. 12:30 - 14:00 1.50 WHSUR P RUNCMP Test Production Tree and Hanger void to 5,000 psi. Good. Perform final ESP check. Good. Pick-up Lubricator and pull TWC. Set BPV. Secure Tree and Cellar. Blow down Lines. Release Rig at 14:00 hrs. Printed: 2/28/2005 9:05: 11 AM ~Co})Oß- DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2011700 Well Name/No. MILNE PT UNIT KR F-94 Operator BP EXPLORATION (ALASKA) INC Sp ~ I ~ ð f- ~ 1 API No. 50-029-23040-00-00 MD 18595 ~ TVD 7853 ..... Completion Date 11/25/2001 ...-- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION -- - -- - -.- ------ -- Mud Log No Samples No Directional Survey ~- y~ ~ - DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: ---- -------- (data taken from Logs Portion of Master Well Data Maint) .- Logl Electr Data Digital Dataset Type Med/Frmt Number / C 10541 Name Log Log Run Scale Media No 1 Interval OH I Start Stop CH Received 100 18595 Open 2/1/2002 Comments Well CoreslSamples Information: - -- - J Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y AQ) Daily History Received? ~/N tJN Chips Received? -y " t~~ Formation Tops Analysis Received? :u..N-- ---- Comments: (\ft~ t- ~ t\ If) b r^-J . C \') 1\ 'A.t-iJ rt-lrV"'~ M fJ ~ ~ tIl.- Q It> yZ (\0 11 ~',,~ ~ 'tv 0 ~ £. ß L-- - ---- -- ---- ----------- -- Com pliance Reviewed By: ~ Date: q k - -~Cj'- - - - - -- ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: D Operation Shutdown D Stimulate II Pull Tubing D Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 D Plugging D Perforate II Repair Well II Other 5. Type of well: 1m Development 0 Exploratory 0 Stratigraphic 0 Service Change to ESP Completion 6. Datum Elevation (OF or KB) KBE = 44.33' 7. Unit or Property Name Milne Point Unit 4. Location of well at surface 2284' NSL, 2801' WEL, SEC. 06, T13N, R10E, UM At top of productive interval 1493' NSL, 1132' WEL, SEC. 19, T14N, R10E, UM At effective depth 1548' NSL, 1128' WEL, SEC. 19, T14N, R10E, UM At total depth 1576' NSL, 1125' WEL, SEC. 19, T14N, R10E, UM 12. Present well condition summary Total depth: measured true vertical 8. Well Number MPF-94 9. Permit Number / Approval No. 201-170 10. API Number 50- 029-23040-00 11. Field and Pool Milne Point Unit / Kuparuk River Sands Effective depth: measured true vertical 18595 feet 7853 feet 18469 feet 7730 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner 112' 20" Cemented MD TVD 260 sx Arctic Set (Approx.) 1121 1121 1153 sx PF 'L', 300 sx PF 'C', 900 sx 'G' 10341' 44541 400 sx Class 'GI 18555' 78141 Length Size 10307' 18523' 10-3/4" 7-5/8" Perforation depth: measured Open: 18290' - 18292', 18300' - 18310', 18325' - 18335', true vertical Open: 7557' - 7559',7566' - 75761,75901 - 76001 Tubing (size, grade, and measured depth) 2-7/8",6.5#, L-80 tubing to 18069' and 4-1/2", 12.6#, L-80 tubing from 181461 to 181931. Packers and SSSV (type and measured depth) 7" x 4.5" Baker Premier Packer at 18155' 13. Stimulation or cement squeeze summary Intervals treated (measured) MAR () ? 2002 Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 0 Copies of Logs and Surveys run 1m Daily Report of Well Operations 17. I hereby certify that the foregoing is true an correct to the best of my knowledge ïCCL,,-- Tit~ Technical Assistant 16. Status of well classifications as: 1m Oil 0 Gas 0 Suspended Service Form 10-404 Rev. 06 1588 Date D - Œo- D'L 6i Prepared By Name/Number: Sondra Stewman, 564.475~ c\:) Submit In DuPlica~ ( ( BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: COMPLETION Start: 1/25/2002 End: 2/7/2002 Contractor Name: NABORS Rig Release: 2/7/2002 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/25/2002 14:00 - 15:30 1.50 MOB P PRE SCOPE AND LOWER DERRICK. 15:30 -18:00 2.50 MOB N WAIT PRE STAND-BYFOR SLICK LINE TO MOVE OFF OF WELL AFTER COMPLETING PREP WORK. 18:00 - 23:00 5.00 RIGU P PRE MOVE RIG TO MPF-94. BERM AND SPOT SUB, PITS, AND PIPE SHED. RAISE AND SCOPE DERRICK. ACCEPT RIG @ 23:00 HRS. 23:00 - 00:00 1.00 RIGU P DECOMP BEGIN TO RU LINES TO TIGER TANK. PULL BPV WITH LUBRICATOR. 1/26/2002 00:00 - 03:30 3.50 RIGU P DECOMP COMPLETE RU TO TIGER TANK. FINISH OFF-LOADING SEA WATER INTO PITS. TEST LINES TO 3,500 PSI. 03:30 - 06:00 2.50 KILL P DECOMP BEGIN KILLING WELL WITH SEA WATER. CREW CHANGE. 06:00 - 07:00 1.00 KILL P DECOMP UNABLE TO KILL WELL. POOR COMMUNICATION BETWEEN TBG/CSG. SUSPECT THAT THE SLIDING IS NOT COMPLETL Y OPEN. 07:00 - 13:00 6.00 PERF P DECOMP CALL OUT SWS TO JET CUT TBG. (LOAD PS WITH 2 7/8" TBG AND TALLY). 13:00 - 16:30 3.50 PERF P DECOMP PJSM. RIG UP SWS AND MAKE UP TOOL STRING. 16:30 -17:30 1.00 PERF P DECOMP MU JET CUTTER. PT LUBRICATOR. 17:30 -18:00 0.50 PERF P DECOMP SWS START RIH WITH JET CUTTER. CREW CHANGE. 18:00 - 23:00 5.00 PERF P DECOMP FINISH IN HOLE WITH JET CUTTER. LOG TIE-IN PASS. MADE JET CUT AT 18,11 O-FT. POOH. PUMP 25 BBLS SW DOWN ANNU TO ESTABLISH COMMUNICATIONS. RD SWS. 23:00 - 00:00 1.00 KILL P DECOMP PRESSURE TEST LINES. BEGIN WELL KILL WITH SEA WATER. 1/27/2002 00:00 - 06:00 6.00 KILL P DECOMP CIRCULATED WELL CLEAN WITH HOT SEA WATER. MONITOR. WELL FLOWING. BEGIN TO WT UP TO 8.8 # BRINE. CREW CHANGE. 06:00 - 11 :00 5.00 KILL P DECOMP CONTINUE TO WT UP TO 8.8 BRINE. MONITOR. 11 :00 - 11 :30 0.50 WHSUR P DECOMP SET AND TEST TWCV. BLOW DOWN LINES. 11 :30 - 12:30 1.00 WHSUR P DECOMP NIPPLE DOWN X-MASS TREE. 12:30 - 14:30 2.00 BOPSUF P DECOMP NIPPLE UP BOPE. 14:30 - 17:30 3.00 BOPSUF P DECOMP TEST BOPE AS PER BP AND AOGCC REQUIREMENTS. RIGHT TO WITNESS TEST WAIVED BY STATE...J. CRISP. 17:30 -18:00 0.50 BOPSUF P DECOMP RD TEST EQUIP. DRAIN BOP STACK. BLOW DOWN LINES. CREW CHANGE. 18:00 -19:00 1.00 WHSUR P DECOMP PICK UP LUBRICATOR AND PULL TWC. 19:00 - 20:00 1.00 PULL P DECOMP MAKE UP LAND JT. RIG UP FLOOR TO HANDLE 41/2" TBG. 20:00 - 00:00 4.00 PULL P DECOMP WORKING PIPE TO BREAK AT JET CUT. PUMP EP MUD LUB. CO NT WORKING PIPE. 1/28/2002 00:00 - 06:00 6.00 PULL P DECOMP MIX 4 DRUM OF EP MUD LUBE AND REVERSE IN TO JET CUT AT 18,110-FT. CONTINUE TO WORK PIPE. CREW CHANGE. 06:00 - 07:00 1.00 PULL P DECOMP CONTINUE TO WORK PIPE. NO JOY. 07:00 - 12:00 5.00 PULL P DECOMP WO ON SWS TO ARRIVE ON LOCATION FOR SECOND CUT. 12:00 -15:00 3.00 PERF P DECOMP PJSM. RU SWS. MAKE UP TOOLS. 15:00 -18:00 3.00 PERF P DECOMP MAKE UP JET CUTTER #2. START RIH. CREW CHANGE. 18:00 - 21:00 3.00 PERF P DECOMP CONTINUERIH WITH JET CUTTER. LOG TIE-IN PASS. LOG CUTTER IN PLACE. MAKE CUT AT 18,146-FT. POOH. RD. SWS STAND-BY. Printed: 2/20/2002 11:21 :36 AM ( ( BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: COMPLETION Start: 1/25/2002 End: 2/7/2002 Contractor Name: NABORS Rig Release: 2/7/2002 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/28/2002 21 :00 - 22:00 1.00 PULL P DECOMP WORK PIPE. STILL UNABLE TO BREAK FREE. 22:00 - 23:30 1.50 PULL P DECOMP CUT AND SLIP DRILLING LINE. MIX 6 DRUM OF EPML IN 50 BBL PILL. 23:30 - 00:00 0.50 PULL P DECOMP START TO PUMP EPML DOWN TBG. (CONT TO WORK PIPE WHILE WAITING FOR EPML TO GET ON BACKSIDE). 1/29/2002 00:00 - 06:00 6.00 PULL P DECOMP CONTINUE TO WORK PIPE WHILE PUMPING EPML UP THE BACKSIDE. FREE STUCK HANGER FROM BOP STACK. CREW CHANGE. 06:00 - 07:30 1.50 PULL P DECOMP CONTINUE TO WORK PIPE. DISCUSS OPTIONS WITH MPU AND ANCH OFFICE. 07:30 - 10:30 3.00 PULL P DECOMP ALERT SWS OF POSSIBLE CHEM CUT. CONTINUE TO WORK PIPE. 10:30 - 12:00 1.50 PULL P DECOMP RU SWS TO MAKE CHEM CUT. LEAVE TBG IN SLIPS WITH 35k TENSION. 12:00 -13:00 1.00 PERF P DECOMP PJSM. CLEAR FLOOR. LOAD CHEM CUTTER. 13:00 -17:00 4.00 PERF P DECOMP RIH WITH CHEM CUTTER. STOP AT 13,920-FT. AND MAKE CUT. LOST THE 35K TENSION IN TBG. 17:00 -18:00 1.00 PERF P DECOMP SWS START POOH WITH TOOL STRING. CREW CHANGE. 18:00 - 20:30 2.50 PERF P DECOMP SWS FINISH POOH. STOP ST 200-FT FROM SURFACE. PJSM. CONTINUE TO SURFACE. LAY DOWN CHEM CUTTER. RD. 20:30 - 21 :00 0.50 PULL P DECOMP PULL ON TBG. FREE. STRING WEIGHTS a5K. 21 :00 - 00:00 3.00 PULL P DECOMP START POOH WITH 41/2" FRAC STRING. 1130/2002 00:00 - 06:00 6.00 PULL P DECOMP CONTINUE POOH LD 41/2" TBG. CREW CHANGE. 06:00 - 08:00 2.00 PULL P DECOMP FINISH POOH WITH 4 1/2" TBG. 08:00 - 10:00 2.00 PULL P DECOMP CLEAR FLOOR. LOAD PS WITH 4 3/4" DC AND 31/2" DP. RU FLOOR TO HANDLE DRILL PIPE. 10:00 - 11 :00 1.00 PULL P DECOMP MAKE UP BHA #1 (41/2" GRAPPLE). 11 :00 - 18:00 7.00 PULL P DECOMP PICK UP DC. BEGIN RIH WITH BHA #1 AND 31/2" DP. CREW CHANGE. 18:00 - 00:00 6.00 PULL P DECOMP CONTINUE RIH WITH BHA #1 AND 3 1/2" DP. 1/31/2002 00:00 - 04:30 4.50 PULL P DECOMP CONTINUE RIH WITH BHA #1. TAG TOP OF FISH AT 13910-FT. WORK TOOLS. 04:30 - 06:00 1.50 PULL P DECOMP START POOH WITH BHA #1 AND FISH...REMAINDER OF 4 1/2" TBG. CREW CHANGE. 06:00 - 11 :00 5.00 PULL P DECOMP CONTINUE POOH. FLOW CHECK WELL. WELL FLOWING. 11 :00 - 15:30 4.50 PULL P DECOMP CIRCULATE OUT OIL AND GAS. CONDITION BRINE TO 9.0#. MONITOR WELL. 15:30-17:00 1.50 PULL P DECOMP CONTINUE POOH TO BHA. 17:00 -17:30 0.50 PULL P DECOMP LAY DOWN TOOL STRING. TOP OF FISH TO SURFACE. 17:30 -18:00 0.50 PULL P DECOMP RD 31/2" HANDLING EQUIP. RU 41/2" HANDLING EQUIP. 18:00 - 00:00 6.00 PULL P DECOMP POOH...LD 41/2" TBG. 2/1/2002 00:00 - 01 :00 1.00 PULL P DECOMP FINISH POOH WITH REMAINING 41/2" TBG. 01 :00 - 03:30 2.50 PULL P DECOMP BREAK OUT AND LD TOOLS. LD DRILL COLLARS. 03:30 - 05:00 1.50 PULL P DECOMP CLEAR AND CLEAN FLOOR. RU TO PU 2 3/8" AND 27/8" TBG. 05:00 - 06:00 1.00 PULL P DECOMP START RIH WITH CLEAN-OUT STRING. CREW CHANGE. 06:00 - 11 :00 5.00 PULL P DECOMP CONTINUE RIH WITH 2 3/8" AND 2 7/8" TBG. STOP TO CHANGE HANDLING EQUIPMENT. 11 :00 - 11 :30 0.50 PULL P DECOMP CHANGE OVER TO 31/2" EQUIPMENT. 11 :30 - 16:00 4.50 PULL P DECOMP CONTINUE RIH WITH 31/2" DP. TAG TOP OF FILL AT 18,300-FT. 16:00 - 18:00 2.00 PULL P DECOMP REVERSE CIRCULATE AND WASH DOWN. CREW Printed: 2/20/2002 11 :21 :36 AM ( ( BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: COMPLETION Start: 1/25/2002 End: 2/7/2002 Contractor Name: NABORS Rig Release: 2/7/2002 Rig Name: NABORS 4ES Rig Number: Date From - To Hou rs Activity Code NPT Phase Description of Operations 2/1/2002 16:00 - 18:00 2.00 PULL P DECOMP CHANGE. 18:00 - 00:00 6.00 PULL P DECOMP CONTINUE TO REVERSE OUT CARBOLITE. FLUID LOSS AND TBG PLUGGING PROBLEMS. 2/2/2002 00:00 - 06:00 6.00 PULL P DECOMP CONTINUE REV CIRC DOWN TO 18,357-FT. FLUID LOSS TO FORMATION AND PIPE PLUGGING OFF...PROBLEMS. CREW CHANGE. 06:00 - 08:00 2.00 PULL P DECOMP CONTINUE TO REV CIRC. TUBING PLUG ED AGAIN. WORK FREE. MONITOR WELL. 08:00 - 13:30 5.50 PULL P DECOMP LD 31/2" DP TO 18,100-FT. MONITOR WELL. WEIGHT UP FROM 8.7# TO 8.9#. 13:30 -18:00 4.50 PULL P DECOMP LD 31/2" DP TO 17,630-FT. MONITOR WELL. STILL HAVE SLIGHT FLOW. WEIGHT UP FROM 8.9# TO 9.1#. MONITOR. WELL. CREW CHANGE. 18:00 -18:30 0.50 PULL P DECOMP MONITOR WELL. DEAD. 18:30 -19:30 1.00 PULL P DECOMP LD DOWN 31/2" DP TO 17,100-FT. 19:30 - 20:00 0.50 PULL P DECOMP MAKE UP AND SET HALCO PKR JUST BELOW SURFACE. TEST. 20:00 - 22:30 2.50 PULL P DECOMP NO BOPE. CHANGE OUT TBG SPOOL. 22:30 - 00:00 1.50 PULL P DECOMP NU TBG SPOOL AND TEST. PREPARE TO NU BOPE. 2/3/2002 00:00 - 03:30 3.50 PULL P DECOMP TBG SPOOL SWAP COMPLETED. NU BOPE. BODY TEST. RIGHT TO WITNESS TEST WAIVE BY STATE...J. JONES. 03:30 - 04:30 1.00 PULL P DECOMP RELEASE HALCO PKR. LD. 04:30 - 05:30 1.00 PULL P DECOMP TBG AT 17,100-FT. REV CIRC TBG VOL UP ONE MORE FINAL TIME BEFORE POOH. NO CARB RECOVERED. 05:30 - 06:00 0.50 PULL P DECOMP BEGIN POOH. LD 31/2" DP. CREW CHANGE. 06:00 - 06:30 0.50 PULL P DECOMP MONITOR WELL. SERVICE RIG. 06:30 - 13:30 7.00 PULL P DECOMP POOH...LD 31/2" DP. RD 3 1/2" EQUIP. 13:30 -16:00 2.50 PULL P DECOMP POOH...STAND BACK 27/8" TBG. RD 27/8" EQUIP. 16:00 - 17:00 1.00 PULL P DECOMP POOH...LD 2 3/8" DP. CLEAR FLOOR. PREP FOR ESP COMPLETION. 17:00 -18:00 1.00 RUNCO~ Ip COMP BEGIN TO PU ESP ASSY. BEGIN SERVICE AND TEST. CREW CHANGE. 18:00 - 23:00 5.00 RUNCO~ Ip COMP FINISH PU ESP ASSY. FINISH SERVICE AND TEST. 23:00 - 00:00 1.00 RUNCO~ Ip COMP START RIH WITH ESP ASSY AND 2 7/8" TBG. 2/4/2002 00:00 - 03:30 3.50 RUNCO~ Ip COMP CONTINUE RIH WITH ESP ASY AND TBG. SET DOWN AT 3,238-FT. +1-. CHECK CABLE READING...BAD. 03:30 - 06:00 2.50 RUNCO~ 11\1 DPRB COMP START POOH WITH TBG AND ESP ASSY TO FIND PROBLEM. CREW CHANGE. 06:00 - 10:00 4.00 RUNCO~ 11\1 DPRB COMP FINISH POOH. INSPECT AND LD ESP ASSY. DAMAGE TO FLAT GUARD, MOTOR LEAD, AND POT HEAD. 10:00 -18:00 8.00 RUNCO~ 11\1 WAIT COMP WOW...PHASE 3. PUT ESP ASSY IN SHIPPING BOXES. SPLICE NEW MLE ON CABLE. 18:00 - 00:00 6.00 RUNCO~ rt-J WAIT COMP CONTINUE WOW. TIH WITH 72 JT 2 7/8" TBG TO 2,250-FT+/-...KILL STRING. 2/5/2002 00:00 - 08:00 8.00 RUNCO~ ft.J WAIT COMP CONTINUE WOW. 08:00 - 09:00 1.00 RUNCO~ r'N WAIT COMP POOH WITH 2 7/8 TBG...KILL STRING. 09:00 - 09:30 0.50 BOPSU¡:; P COMP PREPARE FOR WEEKLY BOPE TEST. INSTALL TEST PLUG. 09:30 - 14:00 4.50 BOPSU¡:; P COMP PERFORM WEEKLY BOPE TEST PER BPIAOGCC REQUIREMENTS. STATE RIGHT TO WITNESS TEST WAIVED BY J. SPAULDING. LD TEST PLUG. 14:00 - 15:00 1.00 CLEAN N DPRB COMP MU "SCOOP TOOL" (REV JUNK BASKET). 6.00" 0.0. Printed: 2/20/2002 11 :21 :36 AM . ( ( BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: COMPLETION Start: 1/25/2002 End: 2/7/2002 Contractor Name: NABORS Rig Release: 2/7/2002 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/5/2002 15:00 -18:00 3.00 CLEAN N DPRB COMP START RIH WITH BHA. RUN TBG FROM DERRICK. CONTINUE RUN FROM PIPE SHED. FOUND "TIGHT SPOT" AT 3,475-FT +1-. CREW CHANGE. 18:00 - 00:00 6.00 CLEAN N DPRB COMP CONTINUE RIH WITH SCOOP TOOL. 2/6/2002 00:00 - 01 :00 1.00 CLEAN N DPRB COMP FINISH RIH WITH SCOOP TOOL TO 18,140-FT. 01 :00 - 06:00 5.00 CLEAN N DPRB COMP POOH WITH TBG AND SCOOP TOOL. CREW CHANGE. 06:00 - 09:30 3.50 CLEAN N DPRB COMP FINISH POOH 09:30 - 10:30 1.00 CLEAN N DPRB COMP LAY DOWN SCOOP TOOL. RECOVERED 1 "x1 3/8"x5/8" CHUNK OF METAL. CLEAR FLOOR. 10:30 -13:00 2.50 RUNCO~ P COMP PU AND SERVICE ESP ASSY. 13:00 -18:00 5.00 RUNCO~ P COMP START RIH WITH ESP ASSY AND 2 7/8" TBG. 18:00 -19:30 1.50 RUNCO~ P COMP CONTINUE RIH WITH ESP AND TBG DOWN TO 7,900-FT. STOP FOR REEUREEL CABLE SPLICE. 19:30 - 22:30 3.00 RUNCO~ P COMP LOAD SPOOL. MAKE SPLICE. TEST. 22:30 - 00:00 1.50 RUNCO' P COMP CONTINUE RIH WITH ESP ASSY AND TBG. (11 ,225-FT +1-) 2/7/2002 00:00 - 03:00 3.00 RUNCO~ P COMP RIH WITH TBG. 03:00 - 06:00 3.00 RUNCO~ P COMP MAKE MID LINE SPLICE IN ESP CABLE. 06:00 - 07:00 1.00 RUNCO~ P COMP CONTINUE TO RIH TO ESP SETTING DEPTH. 07:00 - 09:00 2.00 WHSUR P COMP MU HANGER & MAKE ESP CABLE SPLICE AND LAND HANGER & RILDS. 09:00 - 11 :00 2.00 BOPSUR P COMP SET TWC & NIPPLE ON BOP 11:00 -14:00 3.00 WHSUR P COMP NIPPLE UP TREE & TEST SAME TO 5000 PSI. & PULL TWC & SET BPV. 14:00 - 18:00 4.00 CHEM P COMP FREEZE PROTECT WELL WITH HB&R 80- BBL. DEAD CRUDE & DIESEL IN TBG. RIG RELEASED @ 1800 HRS. 02/07/02 Printed: 212012002 11 :21 :36 AM 1/31/2002 -..1 NO. 1772 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie Company Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point - - '" - - .- - - - . MPF-94 21508 'M10 & CDR 11/08/01 1 MPF-94 21508 MD CDR RESISTIVITY 11/08/01 1 1 MPF-94 21508 TVD CDR RESISTIVITY 11/08/01 1 1 w L Dat CD S BL --' 0 \' I -. 0 C\S .-- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie Date Delivered: rES 0 1 2002 Alaska Oil & Gas Cons. ComIni88ion Received by: ~~ . ,~ ( STATE OF ALASKA t ALASKA LJlL AND GAS CONSERVATION COMM)~~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-170 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23040-00 4. Location of well at surface r" (-~-:j; ~,:':"':""JI~:!', lOCAìiONS 9. Unit or Lease Name 2284' NSL, 2801' WEL, SEC. 06, T13N, R10E, UM v~ Milne Point Unit At top of productive interval . .1' -,-- ' ¡ ',_,.".1 ::cJ. " JL:.z . (Sm 1493' NSL, 11321 WEL, SEC. 19, T14N, R10E, UM i - --="';"', ',\ :. ! ~', 10. Well Number At total depth i If[~¡;';;::,:,': i B. t'.t~~, MPF-94 1576' NSL, 11251 WEL, SEC. 19, T14N, R10E, UM j -,--~?1>.~-: -"""""""""~'.'" ~ 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease DesignàfiOn âñd Serial No. Milne Point Unit / Kuparuk River Sands KBE = 44.33' ADL 355016 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 10/16/2001 11/7/2001 11/25/2001 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 18595 7853 FT 18469 7730 FT ~Yes ONo N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, DIA, GR, RES, DEN, NEU 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# K-55 Surface 112' 30" 1260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 34' 10341' 13-1/2" 1153 sx PF 'L', 300 sx PF 'C', 900 sx 7-5/8" 29.7# L-80 32' 18555' 9-7/8" 1400 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 SPF 3-3/8" Gun Diameter, 12 SPF 4-1/2", 12.6#, L-80 18193' 18155' MD TVD MD TVD 18290' - 18292' 7557' - 7559' 18300' - 18310' 7566' - 7576' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 18328' - 18330' 7593' - 7595' 18325' - 18335' 7590' - 76001 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 18290' - 18335' Fractured; Placed 117,298#'s 16/20 and 73,740#'s 12/18 Carbolite behind pipe. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 26, 2001 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL -BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SI:~:::Krf} e1V ED No core samples were taken. JAN 2 5 2002 . ORIGINAL Alaska Oil & Gas Con;Comm;ssion Anchorage r-r-n I LD L CUU¿ Form 10-407 Rev. 07-01-80 RBDMS 8Fl r-¡:R Submit In Duplicate 'ì 'lnnl') " ".',' ~, " ~v ( ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top of Kuparuk 'C' 18250' 7518' Top of Kuparuk 'A' 18278' 7545' Top of Kuparuk 'A3' 18284' 7551' Top of Kuparuk 'A2' 18300' 7566' Top of Kuparuk 'A1' 18320' 7586' Top of Miuveach 183801 7644' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak of Integrity Test and Post Rig Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date Ol.~. MPF-94 Well Number 201-170 Permit No. I A Prepared By Name/Number: Sandra Stewman, 564-4750 roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ,. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/13/2001 10/14/2001 10/15/2001 10/16/2001 (' (' BP EXPLORATION Operations Summary Report MPF-94 MPF-94 DRILL +COMPLETE NABORS Nabors 27E 12:00 - 18:00 From - To Hours Activity Code NPT PRE 18:00 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 06:00 06:00 - 10:00 10:00 - 11 :30 11:30 -14:00 14:00 - 17:00 17:00 - 18:30 18:30 - 20:00 20:00 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 11 :00 11 :00 - 12:00 12:00 -13:00 13:00 - 18:00 18:00 - 20:00 20:00 - 00:00 00:00 - 09:30 09:30 - 10:30 10:30 - 11 :00 11:00 -12:00 12:00 - 13:00 6.00 MOB 6.00 MOB 2.00 MOB 1.00 MOB 3.00 MOB 4.00 MOB 1.50 MOB 2.50 MOB 3.00 MOB 1.50 MOB 1.50 MOB 4.00 RIGU 2.00 RIGU 1.00 DRILL 8.00 DRILL 1.00 DRILL 1.00 DRILL 5.00 DRILL 2.00 DRILL 4.00 DRILL 9.50 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL Phase P P PRE P PRE P P PRE PRE P PRE P PRE P PRE P PRE P P PRE PRE P PRE P PRE P SURF P SURF P SURF P P SURF SURF P P SURF SURF P SURF P P P P SURF SURF SURF SURF Page 1 of 15 Start: 10/13/2001 Rig Release: 11/17/2001 Rig Number: Spud Date: 10/15/2001 End: 11/17/2001 Description of Operations PREPARE RIG FOR MOVE FROM MPL-35A TO MPF-94 - BLOW DOWN STEAM, WATER LINES - KNOCK APART SAME - PICK UP MATTING BOARDS - PICK UP AROUND RIG MOVE - PUMP - PIT - ENGINE - BACK HALF OF PIPE SHED - HI-LINE MODULES - FROM MPL-35A TO MPF-94 - PULL SUB MODULE OUT FROM MPL-35A AND PREPARE TO MOVE TO MPF-94 MOVE TIRES TO INSIDE POSITION ON BACK OF SUB MODULE - PUT DRILLING LINE SPOOL ON BACK OF TRUCK - INSTALL YOKE TO SUB MOVE SUB MODULE FROM L- PAD TO F- PAD MOVE TIRES TO OUTSIDE POSITION - LAY HERTICULITE AND MATS - PUT WELL HEAD EQUIPMENT I TREE IN CELLAR SPOT SUB MODULE OVER MPF-94 - SPOT 1 ST SECTION OF PIPE SHED - BERM AROUND SUB MOVE 2ND PIPE SHED FROM L-PAD TO F-PAD AND SPOT IN PLACE LAY HERTICULITE AND MATS FOR MUD PITS - SPOT PIT MODULE SPOT MOTOR MODULE - HOOK UP LINES - LEVEL PIPE SHED - SET MATS FOR PUMP MODULE SPOT PUMP MODULE - HOOK UP LINES SET SHOPS - M II MUD LAB - ANDRILL MWD UNIT - HOOK UP POWER TO SAME BLOW AIR THROUGH ALL LINES - MUD I WATER I AIR I STEAM - FIRE BOILERS - TURN STEAM TO RIG - SET AND FIRE HOT AIR HEATER RIGGING UP - WORKING ON STEAM SYSTEM - WARMING UP RIG -ALL LINES MUD, AIR, WATER, STEAM HOOKED UP - STEAM SYSTEM CIRC - WATER SYSTEM CIRC- (ACCEPT RIG AT 02:00 HOURS ON THE 15TH OF OCT). CHANGE OUT SAVOR SUB ON TOP DRIVE FROM 4" TO 5" - CHANGE STABBING GUIDES - LOWER IBOP VALVE- LOADING 5" DRILL PIPE IN PIPE SHED INSTALL HEAD I RISER ON SURFACE PIPE - LOADING 5" DP IN PIPE SHED INSTALL MOUSE HOLE - CHANGE HEADS ON IRON ROUGH NECK STRING HI-LINE CABLE TO RIG WORK ON HI-LINE POWER - WELD ON RISER - INSTALL FLOW LINE - WORK ON DRAWWORKS (WATER PUMP ON BRAKE SYSTEM) CLEAN UP L-PAD - MOVE CAMP RIG UP TO PICK UP 5" DP - PICKING UP 5" DP AND STAND BACK IN DERRICK PICKING UP 5" DRILL PIPE 300 JTS S-135 MAKE UP TORQUE26,OOO#ANDSTAN~. 'E'.'~'I~.'m.'RR'C. ~i~.~."'I'.""'.:vr."!.;\); ,I i:.i- '\....".i\"~I""""\,,', PICKUPHWPANDSTANDBA ~,.,yt¡¡;j;~ "~ \I, :I:"."",:¡/,¡,'", PRE-SPUD MEETING WITH BOTH CREWS FINISH PICKING UP HWP 21 JTS . ,-~". "'1 -- INSTALL DRIP PAN UNDER FLOO~J I~ [\\1 Î::, ,5, ¿ I... I " ,,', , ' '^;" " AlaSKa \B~lri'te&~~':11M/~öb1\"'TU:U4:00 AM I~.¡!ci;¡ùr::;::e , BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/16/2001 13:00 - 14:00 1.00 DRILL P SURF MAKE UP 131/2 BIT AND CROSS OVER SUBS TAG UP @ 75 FT 14:00 - 15:00 1.00 DRILL P SURF FILL HOLE AND CIRC -CHECK FOR LEAKS, WASH 75 FT TO BOTTOM OF CONDUCTOR @ 112 FT 15:00 - 17:00 2.00 DRILL P SURF SPUD IN AND DRILL FROM 112 TO 235 FT, PUMPING 650 PSI, 375 GALS PER MIN, 60 RPMS 17:00 - 17:30 0.50 DRILL P SURF POH FOR BHA 17:30 - 22:30 5.00 DRILL P SURF PICKING UP BHA, BIT, XO, AIM9 ,1.5 MOTOR, NM PONY COLLAR, NM STAB, XO, ARC8, MWD, NM STAB, NM DC, NM DC, NM STAB, NM DC, XO 22:30 - 00:00 1.50 DRILL P SURF DIRECTIONAL DRILL 235-309 450 GALS MIN. 106 PUMP ST., 45 RPM, 8,000 -10,000 BIT WT, AIM TOOL NOT WORKING, HAS NOT PERIOD 10/17/2001 00:00 - 01 :00 1.00 DRILL P SURF DIRECTIONAL DRILL 309-382 450 GALS MIN. 106 PUMP ST., 45 RPM, 8,000 -10,000 BIT WT, AIM TOOL NOT WORKING 01 :00 - 01 :30 0.50 DRILL N DFAL SURF ATTEMPT TO GET AIM TOOL WORKING 01 :30 - 04:00 2.50 DRILL N DFAL SURF TRIP OUT FOR BHA, LAYING DOWN PWD AND AIM TOOL 04:00 - 04:30 0.50 DRILL N DFAL SURF CLEAR FLOOR 04:30 - 06:00 1.50 DRILL N DFAL SURF PICK UP NEW BHA, AND TRIP IN, BHA #2 BIT MX-C1 3/14'S AND 1/10 JETS XO, 1.5 MOTOR, NM PONY DC, NM STAB, XO, MWD, NM STAB, 2 NM DC, XO, 13 HWDP, JARS, 7 JTS HWDP, 06:00 - 00:00 18.00 DRILL P SURF DIRECTIONAL DRILL 382 -1492 550 GALS MIN. 130 PUMP ST., 45 RPM, 10,000-18,000 BIT WT, ART 7.5, AST 10 10/18/2001 00:00 - 19:30 19.50 DRILL P SURF DIRECTIONAL DRILL 1492-3226 586 GALS MIN. 140 PUMP ST., 45 RPM, 10,000-20,000 BIT WT, ART 4.1, AST 8.8 19:30 - 20:30 1.00 DRILL P SURF CIRC BOTTOMS UP @ 586 GALS MIN 20:30 - 00:00 3.50 DRILL P SURF TRIPPING OUT FOR BIT AND BHA TO 1200 FT PUMPED OUT TO 1500 FT WITH 586 GALS MIN, NO PROBLEMS 10/19/2001 00:00 - 00:30 0.50 DRILL P SURF FINISH TRIP OUT TO BHA 00:30 - 02:30 2.00 DRILL P SURF CHANGE OUT BHA AND BIT, BIT #2 MX-C1 CHANGE MOTOR TO 1.15 02:30 - 04:00 1.50 DRILL N RREP SURF RIG REPAIR ( TOP DRIVE) ADJUST BRAKES 04:00 - 06:00 2.00 DRILL P SURF TRIPPING IN 06:00 - 00:00 18.00 DRILL P SURF DIRECTIONAL DRILL 3226- 5319 675 GALS MIN. 160 PUMP ST., 120 RPM, 25,000-30,00 BIT WT, ART 8.0, AST.6 10/20/2001 00:00 - 01 :00 1.00 DRILL P SURF DIRECTIONAL DRILL 5319 - 5475 675 GALS MIN. 160 PUMP ST., 120 RPM, 25,000-30,00 BIT WT, ART .8 , AST 0 01 :00 - 03:00 2.00 DRILL P SURF CIRC, BOTTOMS UP TWICE, 675 GALS MIN, 120 RPMS 03:00 - 05:00 2.00 DRILL P SURF SHORT TRIP, PUMPING OUT WITH 675 GALS MIN. TO 3600 NO PROBLEMS 05:00 - 06:30 1.50 DRILL P SURF SHORT TRIP, PULLING PIPE FROM 3600 TO 1500, SWAB 2200 -1900 06:30 - 09:30 3.00 DRILL P SURF RIH, WORKED TRU BRIDGE @ 1900 - 2200 09:30 - 00:00 14.50 DRILL P SURF DIRECTIONAL DRILL 5475 - 6634 675 GALS MIN. 160 PUMP ST., 120 RPM, 25,000-30,00 BIT WT, ART 6.7, AST 1.9 STARTED MIXING MI FLOW LUBE @ 6435 FT. 6 DRUMS, TORQUE WAS UP TO 15,000 DROP TO 13,000 10/21/2001 00:00 - 05:30 5.50 DRILL P SURF DIRECTIONAL DRILL 6634-7138 675 GALS MIN. 2600 # PSI, 160 PUMP ST., 120 RPM, 25,000-30,00 BIT WT, TORQUE 13-14, ART 3, AST.5 ( {' Printed: 11/19/2001 10:04:55AM . BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/21/2001 05:30 - 07:00 1.50 DRILL N FLUD SURF CIRC SLOW, UGNA SANDS BLINDED OFF SHAKERS AND FILLED CUTTING TANK, CHANGE SCREENS TO 100 MESH, EMPTY CUTTING TANK 07:00 - 11 :30 4.50 DRILL P SURF DIRECTIONAL DRILL 7138- 7540 675 GALS MIN. 161 PUMP STKS., 2600# PSI., 120 RPM, 25,000-30,00 BIT WT, TORQUE 14-15, ART 1.5, AST 1.25, ADDING LUBETEX @ 7288 6 DRUMS, 1 DRUM OF MI FLOW LUB , TORQUE DROP FROM 17-18 TO 14 TO 15, 11:30 -14:30 3.00 DRILL P SURF CIRC, BOTTOMS UP TWICE, 23000 PUMP STKS. , 675 GALS MIN 2600 # PSI. 14:30 - 17:30 3.00 DRILL P SURF SHORT TRIP TO 3722, PUMPED OUT THE FIRST 10 SDS. NO PROBLEM, PULLED OUT TO 3722, WITH TIGHT SPOTS AT 6256 TO 6160 ---5360 TO 5320---4753 TO 4560---4200 TO 4090 OVER PULL WAS 25,000 TO 35,000, WIPE TIGHT SPOTS TWICE, (ALL TIGHT SPOTS WERE, WHERE WE WERE SLIDING OR A CROSS SANDS) 17:30 - 18:00 0.50 DRILL P SURF SERVICE TOP DRIVE 18:00 -19:30 1.50 DRILL P SURF TRIPPING FROM 3813 TO 7480, NO PROBLEMS, FILL PIPE EVERY 25 SDS. 19:30 - 20:00 0.50 DRILL P SURF WASH AND REAM FROM 7480 TO 7540 WITH 675 GALS MIN. 2600 # PSI, 120 RPM, TORQUE 14 20:00 - 00:00 4.00 DRILL P SURF DIRECTIONAL DRILL 7540 - 7854 675 GALS MIN. 161 PUMP STKS., 2600# PSI., 120 RPM, 25,000-30,00 BIT WT, TORQUE 14- 15, ART 2, AST .75 10/22/2001 00:00 - 00:00 24.00 DRILL P SURF DIRECTIONAL DRILL 7854 - 9733 675 GALS MIN. 161 PUMP STKS., 2800# PSI., 120 RPM, 25,000-30,00 BIT WT, TORQUE 15-17, ART 13, AST 1.75 ADDING LUBETEX @ 7415 4 DRUMS, 4 DRUMS OF MI FLOW LUB, AND @ 8978 4 DRUMS LUBETEX , 4 DRUMS FLOW LUB, TORQUE DROP FROM 19-20 TO 15 TO 16, 10/23/2001 00:00 - 09:30 9.50 DRILL P SURF DIRECTIONAL DRILL 9733 TO TD @ 10355 675 GALS MIN. 161 PUMP STKS., 2800# PSI., 120 RPM, 25,000-30,00 BIT WT, TORQUE 15-17, ART 4.25, AST 1.50 ADDING LUBETEX 6 DRUMS, 4 DRUMS OF MI FLOW LUBE 09:30 - 17:00 7.50 DRILL P SURF CIRC. 4 BOTTOMS UP 64,000 STK , STAND BACK ONE STAND EVERY 10,000 STK, 120 RPM 2,800 PSI TORQUE 16,000 17:00 - 00:00 7.00 DRILL P SURF SHORT TRIP TO BHA, OBSERVED WELL, TRIPPING TO 1500 FT., GETTING UP AND DOWN WTS. EVERY 5 SDS. HOLE STARTED TAKING MUD SLOW @ 5500 FT. TOOK 37 BBLS ON TRIP OUT DRAG @ 6138 TO 6060 --- 5500- 5200-- 30,000 OVER PULLS 10/24/2001 00:00 - 01 :00 1.00 DRILL P SURF SHORT TRIP TO 810'. UP AND DOWN WEIGHTS EVERY 5 STANDS. HOLE TOOK 8 BBL EXTRA FOR A TOTAL OF 45 BBL FOR TRIP. SLM NO CHANGE. 01:00 - 01:30 0.50 DRILL P SURF SERVICE TOP DRIVE AND CROWN. CLEAN RIG FLOOR. 01 :30 - 06:00 4.50 DRILL P SURF TIH FROM 810-10,355'. FILL PIPE EVERY 25 STANDS @ 3157,5495,7843'. TOOK DOWN DRAG 9200-9594' 25-30K. REAMED LAST 60' FROM 10,295-10,355. NO FILL. 06:00 - 14:00 8.00 DRILL P SURF CBU 4X 64,000 STROKES. STAND BACK ONE STAND EVERY 10,000 STROKES. TORQUE 18K @ 130RPM. (' (" Printed: 11/19/2001 10:04:55 AM BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/24/2001 06:00 - 14:00 8.00 DRILL P SURF 2900PSI @675GPM, 3250PSI@725GPM. 14:00 - 20:00 6.00 DRILL P SURF TRIPPING OUT TO BHA WORKED TIGHT SPOT @ 1,400 FT. 30,000 OVERPULL 20:00 - 22:30 2.50 DRILL P SURF LAYING DOWN BHA 22:30 - 23:30 1.00 DRILL P SURF PJSM AND CLEAR FLOOR 23:30 - 00:00 0.50 DRILL P SURF CUTTING DRILL LINE 10/25/2001 00:00 - 01 :00 1.00 DRILL P SURF CUT AND SLIP DRILLING LINE 1 OO-FT 01 :00 - 03:00 2.00 CASE P SURF RU 10.75-IN CASING TOOLS. PJSM. RU FRANKS FILL UP TOOL. 03:00 - 03:30 0.50 CASE P SURF PJSM ON RUNNING 10.75-IN CASING 03:30 - 13:00 9.50 CASE P SURF RUN 10.75-IN CASING @ 45-S/JNT 0 TO 7,OOO-FT, 60-S/JNT TO 8,000-FT, 120 TO 180-S/JNT TO TD. TAKE PUISO EVERY 5 JOINTS. HOLE TOOK 45.3 BBL OVER 12 HRS. 13:00 - 15:00 2.00 CASE P SURF CIRCULATE AT 5 TO 8-BPM, RECIPROCATE. CONDITION MUD @ 5,OOO-FT MD. 15:00 - 00:00 9.00 CASE P SURF CONTINUE RIH 10.75-IN CASING. TAKING PUiSO EVERY 5 JOINTS. LANDED CSG @ 10,342 WITH 100,000 # TIGHT SPOTS @ 9304-9356-9527-10020 CSG TRYING TO WALL STICK WHEN IN SLIPS FROM 8,000-FT TO TD. HOLE TOOK A TOTAL OF 113-BBL OF MUD WHILE RUNNING PIPE 10/26/2001 00:00 - 04:00 4.00 CASE P SURF CIRCULATE AND CONDITION MUD FOR CEMENT JOB AT 100 SPM AT 650 PSI. REDUCED YP TO 11 AND VIS TO 50. 04:00 - 04:30 0.50 CASE P SURF RIGGED UP HALLIBURTON CEMENTING HEAD AND HELD PJSM ON CEMENTING WELL. 04:30 - 08:30 4.00 CEMT P SURF PUMPED 5 BBLS OF FRESH WATER I TEST LINES TO 4000 PSII DROPPED BYPASS DART I LOAD SHUT OFF DART I PUMPED 45 BBLS WATER I MIXED 75 BBLS ALPHA SPACER AT 10.2 PPG I MIXED AND PUMPED 660 SXS CLASS L CEMENT YIELD 4.15 CFISX 448 BBLS AT 10.7 PPG I MIXED TAIL CEMENT WITH 900 SXS CLASS G CEMENT YIELD 1.15 CFISX 184 BBLAT 15.8 PPG. DROPPED SHUT OFF DART. KICKED OUT PLUG WITH 30 BBLS OF WATER. 08:30 - 11 :00 2.50 CEMT P SURF SWITCHED TO RIG PUMPS AND DISPLACED CEMENT. INITIAL RATE WAS 8 BPM AT 500 PSI. PUMPED 6950 STKS (695 BBLS) AND SWITCHED TO WATER. PUMPED 120 BBLS OF WATER AND SWITCHED BACK TO MUD DUE TO HIGH PUMP PRESSURE. SLOWED PUMPS TO 3 BPM DUE TO HIGH PUMP PRESSURE. LOST RETURN WITH 31 BBLS LEFT IN DISPLACEMENT. BUMPED PLUG WITH 953 BBLS OF FLUID AT 1800 PSI AT 1100 HRS. RELEASED PRESSURE AND FLOATS HELD. 11 :00 - 12:00 1.00 CEMT P SURF LOADED CEMENTING HEAD WITH CLOSING PLUG. PRESSURED UP ON CASING AND SHEARED ES CEMENTER WITH 2450 PSI. CIRCULATED OUT ALPHA SPACER AND CEMENT FROM ANNULUS. DISPLACED FRESH WATER FROM ANNULUS AND RECOVERED GOOD MUD. (' (' Printed: 11/19/2001 10:04:55 AM BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/26/2001 11 :00 - 12:00 1.00 CEMT P SURF 12:00 -15:30 3.50 CEMT P SURF CIRCULATE AND CONDITION HOLE FOR SECOND STAGE CEMENT JOB. 15:30 - 16:00 0.50 CEMT P SURF PJSM 16:00 - 18:00 2.00 CEMT P SURF MIX AND PUMP- 50 BBLS WATER, 50 ALPHA SPACER @ 10.2 WITH RED DYE, LEAD CEMENT MIXED @ 10.5 TOTAL MIXED 364 BBLS, MIXED AND PUMP 300 SX CLASS C @ 15.6 CEMENT WAS MIXED @ 5-6 BBLS MIN. 18:00 - 19:00 1.00 CEMT P SURF KICKED OUT CLOSING PLUG WITH 30 BBLS OF WATER, DISPLACE WITH RIG PUMPS 7 BBLS MIN. 500 PSI, CLOSING PLUG BUMP UP @ 95% PUMP EFF. 2086 PUMP STKS., CLOSE CEMENT TOOL WITH 1500 PSI OVER CIRC. PRESSURE TOTAL 2000#, TOTAL CEMENT TO SURFACE WAS 240 BBLS 19:00 - 20:30 1.50 CEMT P SURF CIRC TRU RISER AND FLOW LINES AND CLEAN OUT CEMENT, LAY DOWN LANDING JT. 20:30 - 00:00 3.50 BOPSUF P SURF NIPPLE DOWN RISER AND FLOW LINE 10/27/2001 00:00 - 06:30 6.50 BOPSUF P SURF NU WELLHEAD. TEST 1000PSI FOR 10 MIN. NU BOPS. 06:30 - 08:00 1.50 BOPSUF P SURF INSTALL LOWER SAFETY VALVE ON TOP DRIVE. 08:00 - 09:00 1.00 BOPSUF P SURF RIG UP BOP TESTING EQUIPMENT. 09:00 - 09:30 0.50 BOPSUF P SURF PJSM ON TESTING BOPS. 09:30 - 18:00 8.50 BOPSUF P SURF INSTALLED TEST PLUG AND ATTEMPTED TO TEST. PLUG LEAKING. PRESSURED UP ON PLUG WITH RIG PUMP THROUGH KILL LINE TO SET PLUG. UNABLE TO PRESSURE UP ON STACK. CHECKED TEST PUMP-OK. PULLED TEST PLUG AND CHECKED SEAL-OK. INSTALLED TEST PLUG AND TESTED BOPE 250 PSI LOW 13500 PSI HIGH FOR 10 MINUTES. RECORDED ON CHART. TEST WITNESSED BY AOGCC INSPECTOR CHUCH SCHEVE. 18:00 - 19:30 1.50 BOPSUF P SURF RIG DOWN TEST TOOLS, RUN WEAR RING 19:30 - 22:00 2.50 BOPSUF P SURF RIG UP FLOW LINE RISER AND FLOW LINE 22:00 - 22:30 0.50 BOPSUF P SURF PJSM ON PICKING UP BHA 22:30 - 00:00 1.50 DRILL P SURF PICKING UP BHA #4 BIT 9 7/8 RR FGSICT WITH 3/13S AND 1/10 JETS, BIT SUB, 3 FLEX WT. DC, XO, 13 HW PIPE, JARS, 7 JTS HW PIPE 10/28/2001 00:00 - 02:00 2.00 DRILL P SURF TIH TO 2461'. 02:00 - 02:30 0.50 DRILL P SURF CIRCULATE AND CONDITION MUD FOR CASING TEST. TEST TO 1500 PSI. TEST GOOD. 02:30 - 04:00 1.50 DRILL P SURF DRILL FROM 2461-2492' ES CEMENTER. WASH FROM 2495- 2593'. 04:00 - 04:30 0.50 DRILL P SURF CIRCULATE AND CONDITION MUD. TEST CASING TO 1500 PSI. HOLD FOR 10 MINS. 04:30 - 05:30 1.00 DRILL P SURF POH FROM 2593'. 05:30 - 07:00 1.50 DRILL P SURF LD BHA 07:00 - 08:00 1.00 DRILL P INT1 CLEAR RIG FLOOR. PJSM ON PU NEW BHA. 08:00 - 11 :00 3.00 DRILL N SFAL INT1 PICK UP ANADRILL ROTARY STEERABLE BHA. ASSEMBLY NOT WORKING PROPERLY. CHANGED OUT PAD ASSEMBLY. TRACED PROBLEM TO FAULTY CONTROLLER SUB. 11 :00 - 14:00 3.00 DRILL P INT1 CONTINUE TO PU BHA. 14:00 -17:30 3.50 DRILL N RREP INT1 RIG REPAIR (TOP DRIVE) ( (" Printed: 11/19/2001 10:04:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/28/2001 10/29/2001 10/30/2001 10/31/2001 ( (. BP EXPLORATION Operations Summary Report MPF-94 MPF-94 DRILL +COMPLETE NABORS Nabors 27E 17:30 - 00:00 From - To Hours Activity Code NPT INT1 00:00 - 00:30 00:30 - 06:30 06:30 - 09:00 09:00 - 10:00 10:00 - 11 :00 11 :00 - 17:00 17:00 - 18:00 17:30 -18:00 18:00 -18:30 18:30 - 00:00 00:00 - 10:00 10:00 - 10:30 10:30 - 16:00 16:00 - 17:00 17:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 00:00 - 04:30 04:30 - 05:00 05:00 - 08:30 6.50 DRILL 0.50 DRILL 6.00 DRILL 2.50 DRILL 1.00 DRILL 1.00 DRILL 6.00 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 5.50 DRILL 10,00 DRILL 0.50 DRILL 5.50 DRILL 1.00 DRILL 4.50 DRILL 1.50 DRILL 1.00 DRILL 4.50 DRILL 0.50 DRILL 3.50 DRILL P P P INT1 INT1 P P P P INT1 INT1 INT1 INT1 P INT1 P P INT1 INT1 P INT1 P INT1 P P INT1 INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P INT1 Page 6 of 15 Start: 10/13/2001 Rig Release: 11/17/2001 Rig Number: Spud Date: 10/15/2001 End: 11/17/2001 Phase Description of Operations TRIPPING IN PICKING UP SINGLES OUT OF PIPE SHED, FILLING PIPE EVERY 25 STANDS SERVICE RIG SINGLE IN DRILLPIPE WITH BHA#5. RUNNING STANDS FROM 8,OOO-FT. CIRCULATE AND CONDITION MUD FOR CASING TEST. PJSM. TEST CASING, 2,500-PSI, 30-MIN. @ 10250 D5 DRILL WITH CREW DRILL PLUGS, CEMENT AND SHOE FROM 1 O,250-FT TO 10,355-FT. DRILL 30-FT NEW FORMATION TO 10,355-FT TO 10,385-FT. ART 1, 550-GPM, 1 ,650-PSI, TORQ 20-22-KFT.LB, 120-RPM, 10-20 WOB. CIRCULATE AND CONDITION MUD FOR LOT. CONDUCT LOT; 1,1 OO-PSI WITH 9.2-LB/GAL MUD, 4,453-FT TVD, EMW 13.9-LB/GAL. DRILL FROM 10,385-FT TO 10,674-FT. ADD 650-BBL NEW MUD TO MUD VOLUME. ART 1.5, 230 PU, 70 SO, 140 ROB, TORQ 20-22 DIRECTIONAL DRILL FROM 10674' TO 11267'. 10-15K WOB, 5-15K TORQUE ON BOTTOM, 100-130RPM, 580GPM, PUMP 2000PSI, 1900PSI OFF BOTTOM, 5-13K TORQUE OFF BOTTOM, PU 170, SO 120, ROT 140. *NOTE: DRILL STRING SLIP-STICKING - WITH HIGH RPM AND LOW WEIGHT ON BIT - REDUCED RPM TO 100 AND INCREASED WOB FROM 10 K TO 25 K - SLIP-STICKING STOPPED CIRCUL TATE AND DOWNLINK @ 11267'. DIRECTIONAL DRILL FROM 11267' TO 11921' - RPM 100- GPM 580 - 2100 PSI- TQ 11K TO 12K - WOB 20 TO 25K - PU 170 - SO 125 -140 ROTATING ECD'S RISING TO 10.75 PPG - CIRC HOLE - ECD DROPPED TO 10.46 - RPM 130 - GPM 580 DIRECTIONAL DRILL FROM 11921' TO 12391' - RPM 110 GPM 580 - TQ 12K to 15K - 2150 PSI- WOB 20 TO 25 - PU 175 - SO 125 - ROT 135 ECD'S 11 PPG - CIRC ONE AND HALF BOTTOMS UP - ECD DROPPED TO 10.4 - TWO PIECES OF PLUG RUBBER BACK - NO INCREASE IN CUTTINGS ON BOTTOMS UP- RPM 130 - GPM 580 - 2200 PSI DIRECTIONAL DRILL FROM 12391' TO 12485' - RPM 110- GPM 580 - TQ 12K TO 15K - WOB 20 TO 25 - 2300 PSI- ECD AT 12485' 10.7 PPG DIRECTIONAL DRILL FROM 12485' TO 12861'. 13-14K TORQUE, 20K WOB, 90-110 RPM, 580 GPM, 2300 PSI. PU 180, SO 120, ROT 145. CIRCULATE AND CONDITION MUD AT 12861'. DOWNLINK ANADRILL POWERDRIVE ROTARY STEERABLE TOOL. DIRECTIONAL DRILL FROM 12861' TO 13143'. 13-14K TORQUE, 20-25K WOB, 110 RPM, 580 GPM, 2350 PSI. PU 185, SO 120, ROT 150. Printed: 11/19/2001 10:04:55AM ( f BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/31/2001 08:30 - 09:00 0.50 DRILL P INT1 CIRCULATE AND CONDITION MUD. DOWLINK ANADRILL POWERDRIVE ROTARY STEERABLE TOOL. 09:00 - 10:30 1.50 DRILL P INT1 DRILL FROM 13143' TO 13331'. 13-15K TORQUE, 20-25K WOB, 110 RPM, 580 GPM, 2450 PSI. PU 185, SO 120, ROT 150. 10:30 - 12:00 1.50 DRILL N RREP INT1 REPAIR TOPDRIVE. CHANGE DIE ON BREAKOUT. 12:00 - 16:00 4.00 DRILL P INT1 DIRECTIONAL DRILL FROM 13331' TO 13798'. 14-15K TORQUE, 20-25 WOB, 90-110 RPM, 580 GPM, 2550 PSI. PU 185, SO 125, ROT 150. 16:00 - 19:30 3.50 DRILL P INT1 ECD'S AT 11. 7PPG. CIRCULATE AT 580 GPM @ 2550 PSI. STAND BACK ONE STAND EVERY 30 MINS. ECD'S REDUCED TO 1 O.4PPG. 19:30 - 20:00 0.50 DRILL P INT1 CIRCULATE AND CONDITION MUD. DOWLINK TO ANADRILL ROTARY STEERABLE TOOL @ 13798'. 20:00 - 23:00 3.00 DRILL P INT1 DIRECTIONAL DRILL FROM 13978' TO 14080'. 14-15K TORQUE, 20K WOB, 90 RPM, 580 GPM, 2360 PSI, PU 190, SO 125, ROT 150. 23:00 - 00:00 1.00 DRILL N DPRB INT1 AT 14080'-REAMED STAND UP @ 125 RPM, 580 GPM, 2450 PSI. REAMING DOWN AT 125 RPM, 400 GPM, 1100 PSI. AT 14060', PRESSURE JUMPED TO 2200 PSI. STILL PUMPING 400 GPM. LOST RETURNS. SLOW PUMPS TO 31 STROKESIMIN, 1135 PSI. UP WEIGHT 210K FROM 190K. PU TO 14015', STARTING SEEING 6% RETURNS. PU TO 13990', LOST RETURNS, SHUT DOWN PUMP. CONTINUE TO PU TO 13883', BACK OUT STAND-STAND BACK. MUD BACK FLOWING UP DP. MU KELLY. SHUT STAND PIPE VALVE-5MIN 730 PSI. NO FLOW IN ANNULUS. ATTEMPT TO CIRCULATE @ 15 STROKES/MIN, 1056 PSI. ROTATE 51 RPM, 15K TORQUE. INCREASE TO 427 GPM, 2650 PSI. PARTIAL RETURNS OFF AND ON. TOTAL MUD LOST 34 BBLS. PUMP PRESSURE DROPPED TO 2350PSI. PWD ECD SHOWING 14.1 PPG. SHUT DOWN PUMPS AND ROTARY. BLEED OFF PRESSURE. SHUT STAND PIPE VALVE. 730 PSI IN 5 MIN. 11/1/2001 00:00 - 09:00 9.00 DRILL N DPRB INT1 WORK STRING FROM 13880' TO 13129 - ATTEMPT TO CIRC PRESSURE UP TO 850 NO RETURNS - BLEED OFF - PULLED 50K OVER - DID NOT BREAK FREE - ESTABLISHED ROTATION AT 90 RPM, 22K TORQUE- WORK STRING FROM 13129' TO 13070' - 90 RPM, 24K TORQUE. WORK STRING TO 13068'. TORQUE DROPPED OFF TO 12K TO 14K -WORK STRING TO 13042' - RIH TO 13050. ESTABLISH CIRCULATION, 4 BPM, 950 PSI. WORK STRING FROM 13042' TO 13074'. BRING PUMP UP SLOWLY TO 70 STROKES/MIN, 962 PSI. CLEAN HOLE FROM 13074' TO 13038'. CONTINUE TO WORK STRING OUT OF HOLE. RAISE STROKES TO 125 - 560 GPM - 2270 PSI. 47% FLOW. TORQUE 12K, ROTATING WEIGHT 140K. CONTINUE TO PULL OUT OF HOLE TO 12,293', 09:00 - 10:00 1.00 DRILL N DPRB INT1 TIH FROM 12293' TO 13987'. NO PROBLEMS. 10:00 - 10:30 0.50 DRILL N DPRB INT1 REAM AND WASH FROM 13987' TO 14080'. ESTABLISH CIRCULATION AT 580 GPM - 2450 PSI 10:30 -12:00 1.50 DRILL N DPRB INT1 CIRCULATE AND CONDITION MUD AT 137 STROKES/MIN, 2570 PSI. Printed: 11/19/2001 10:04:55AM ( ( BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/1/2001 12:00 - 12:30 0.50 DRILL N DPRB INT1 CONDITION MUD AND CIRCULATE ECD DOWN FROM 11.39 TO BASELINE 10.14 PPG. 12:30 - 00:00 11.50 DRILL P INT1 DIRECTIONAL DRILL FROM 14080' TO 14363'. BIT APPEARS TO BE BALLING. ROP VARIES FROM 150 FTIHR TO 10 FT/HR. AVERAGE 30 FT/HR. PUMP NUT PLUG AND SAP SWEEPS @ 14180',14310',14315',14350',14363' IN ATTEMPT TO UNBALL BIT. VARY WOB AND RPM TO TRY TO INCREASE ROP. 13-15K TORQUE, 20-35K WOB, 90-140 RPM, 580 GPM, 2350 PSI, PU 190, SO 125, ROT 155. 11/2/2001 00:00 - 08:30 8.50 DRILL P INT1 DIRECTIONAL DRILL FROM 14363' TO 14740'. 19-20K TORQUE, 30K WOB, 110-120 RPM, 580 GPM, 2300 PSI, PU 210, SO 115, ROT 155. 08:30 - 12:00 3.50 DRILL N FLUD INT1 CIRCIULATE HOLE CLEAN FOR TRIP. PULL 1 STAND EVERY 30 MINS. PUMP SWEEP AT 14424'. END CIRCULATING AT 14080'. 12:00 - 16:00 4.00 DRILL N FLUD INT1 POOH FROM 14080' TO 12240' WITHOUT PUMPS. 16:00 - 18:30 2.50 DRILL N FLUD INT1 PULLED TIGHT 12240' TO 11970'. 25-35K OVERPULL. STARTING BACKREAMING. NO OVERPULL NOTED PULLING THROUGH SHOE. 1 OK to 20K THROUGH CASING 18:30 - 19:00 0.50 DRILL P INT1 RIG SERVICE - TOP DRIVE 19:00 - 20:30 1.50 DRILL N FLUD INn CIRCULATE CASING CLEAN AT 10300' - 580 GPM -100 RPM 20:30 - 23:00 2.50 DRILL P INT1 PULL THREE STANDS TO 9900'- MAKE MAD PASS LOG FROM 9900' TO 9700' 20:30 - 00:00 3.50 DRILL N FLUD INT1 CON'T POOH. PULL FROM 9700' TO 8562' - 1 OK TO 20K DRAG THROUGH CASING 11/3/2001 00:00 - 03:30 3.50 DRILL N FLUD INT1 POH FROM 8725' - TO BHA 03:30 - 05:00 1.50 DRILL N FLUD INT1 LD BHA. 05:00 - 17:00 12.00 DRILL P INn PJSM ON TESTING BOPS. PULL WEAR BUSHING. PU TEST PLUG, RU TESTING EQUIPMENT. TEST VALVES 1-16 ON CHOKE MANIFOLD - MANUAL CHOKE - KILL VALVE - HCR CHOKE - KILL VALVE - 4" DEMCO MANUAL ON STAND PIPE - ANNULAR - TOP AND BOTTOM RAMS - ACCUMULATOR - BLIND RAMS - FLOOR VALVES - TOP DRIVE - ALL TEST CONDUCTED 250 LOW I 3500 HIGH - RIG DOWN TESTING EQUIPMENT - PULL TEST PLUG - SET WEAR RING 17:00 -18:30 1.50 DRILL N RREP INT1 WORK ON TOP DRIVE AND BLOW ALL TESTING EQUIPMENT DOWN. 18:30 - 21:00 2.50 DRILL N DFAL INT1 MU BHA - TEST TOOLS 21:00-21:30 0.50 DRILL N DFAL INT1 RIH 5 STANDS - TEST MWD 21 :30 - 00:00 2.50 DRILL N DFAL INn CON'T RIH TO 6009' 11/4/2001 00:00 - 03:00 3.00 DRILL N DFAL INT1 RIH FROM 6009' TO 10330'. 03:00 - 04:00 1.00 DRILL N RREP INT1 LUBRICATE RIG AND CHANGE SWIVEL PACKING. 04:00 - 07:00 3.00 DRILL N DFAL INT1 TIH FROM 10330' TO 14740' - WASH I REAM LAST STAND TO BOTTOM 07:00 - 10:00 3.00 DRILL P INT1 DIRECTIONAL DRILL FROM 14740' TO 15024'. 16-17K TORQUE, 20-22K WOB, 120RPM, 620 GPM, 2300 PSI. PU 200, SO 130, ROT 160. DROPPING ANGLE AT.5 DEGREES PER HUNDRED. ANADRILL ROTARY STEERABLE TOOL SET AT 20% UP GOING INTO HOLE. 10:00 - 11 :00 1.00 DRILL P INT1 CIRCULATE AND CONDITION MUD @ 15042 - DOWNLINK Printed: 11/19/2001 10:04:55AM (" ( BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/412001 10:00 -11:00 1.00 DRILL P INT1 TO ANADRILL POWER DRIVE ROTARY STEERABLE TOOL. CHANGING TOOL SETTING TO 40% UP AND 20 DEGREE RIGHT TO BUILD ANGLE. 11:00 -16:00 5.00 DRILL P INT1 DIRECTIONAL DRILL FROM 15024' TO 15493'. STILL HAVING TROUBLE BUILDING ANGLE. TOOL IS SLOWLY LOSING ANGLE. CHANGE ANADRILL POWER DRIVE ROTARY STEERABLE TOOL TO 60% UP. NO CHANGE. TRY 80% UP. NO CHANGE. 16:00 - 16:30 0.50 DRILL P INT1 SURVEY-SPR 16:30 - 19:30 3.00 DRILL N DFAL INT1 CIRCULATE 3 X BOTTOMS UP IN PREPARATION FOR POH - STAND BACK ONE STAND EVERY 30 MINUTES WHILE CIRCULATING 19:30 - 22:30 3.00 DRILL N DFAL INT1 MONITOR WELL - POH - PULL 6 STANDS WITH OUT PUMP - TO 14547' - PUMP DRY JOB - CON'T POH TO 10232'- HOLE IN EXCELLENT SHAPE 22:30 - 00:00 1.50 DRILL P INT1 PJSM ON CUTTING LINE - CUT DRLG LINE 11/5/2001 00:00 - 01 :00 1.00 DRILL N DFAL INT1 RIG SERVICE 01 :00 - 05:30 4.50 DRILL N DFAL INT1 POH FROM 10232' TO 9290' STRING PULLED WET - PUMP DRY JOB - BLOW DOWN TOP DRIVE - CON'T POH TO BHA 05:30 - 07:00 1.50 DRILL N DFAL INT1 UD ROTARY STEARABLE TOOL - MWD - DOWN LOAD MWD TOOL - UNABLE TO UNLOAD ELECTRONIC CONTROL UNIT ON ROTARY STEARABLE TOOL. 07:00 - 08:30 1.50 DRILL N DFAL INT1 PIU NEW ROTARY STEARABLE TOOL - MWD - TEST TOOL 08:30 - 17:30 9.00 DRILL N DFAL INT1 RIH WITH 5" DP TO 15493' - FILLING EVERY 25 STANDS TO 10300' - FILLING EVERY 10 STANDS FROM 10300' TO 15493' - HOLE IN EXCELLENT SHAPE - PRECAUTIONARY WASH LAST 90' TO BOTTTOM 17:30 - 23:00 5.50 DRILL P INT1 DIRECTIONAL DRILL FROM 15493' TO 16055' - RPM 120- GPM 600 - 2050 PSI - TQ 18K - WOB 20 - ECD 10.21 23:00 - 23:30 0.50 DRILL P INT1 DOWNLINK TOOL TO 180 DEGREE TOOLFACE @ 60% 23:30 - 00:00 0.50 DRILL P INT1 DIRECTIONAL DRILL FROM 16055' TO 16150' - WeB 18K TO 20K - RPM 120 - TO 18K - GPM 600 - 2125 PSI- EGD 10.3 11/6/2001 00:00 - 01 :30 1.50 DRILL P INT1 DIRECTIONAL DRILL FROM 16150' TO 16276' - WeB 18- RPM 120 - TO 18 - GPM 590 - 2070 PSI- ECD 10.2 - P/U210- SIO 130 - ROT 167 01 :30 - 02:00 0.50 DRILL P INT1 CIRCULATE - DOWNLINK POWER DRIVE - 219 DEG 80% 02:00 - 04:00 2.00 DRILL P INT1 DIRECTIONAL DRILL FROM 16276' TO 16494' - WeB 20 - RPM 125 - TO 18 - GPM 590 - PSI 2160 - ECD 10.4 - P/U 210 - SIO 140 - ROT 170 04:00 - 04:30 0.50 DRILL P INT1 CIRCULATE - DOWNLINK POWER DRIVE - 233 DEG 100% 04:30 - 06:00 1.50 DRILL P INT1 DIRECTIONAL DRILL FROM 16494' TO 16649' - WeB 20 - RPM 120 - TO 20 - GPM 590 - PSI 2190 - ECD 10.5 - P/U 210 - SIO 135 - ROT 170 06:00 - 06:30 0.50 DRILL P INT1 CIRCULATE - DOWNLINK POWER DRIVE -157 DEG 60% 06:30 - 10:00 3.50 DRILL P INT1 DIRECTIONAL DRILL FROM 16649' TO 16993' - WeB 20- RPM 120 - GPM 590 - TQ 20 - PSI 2220 - ECD 10.5 - P/U 220 - SIO 135 - ROT 170 10:00 -13:00 3.00 DRILL P INT1 CIRCULATE HOLE CLEAN FOR SHORT TRIP - STAND BACK ONE STAND EVERY 30 MINS WHILE CIRCULATING - 600 GPM - 120 RPM - TO 17 - SLOW PUMP TO 500 GPM WHEN SLACKING OFF TO KEEP ECD FROM SURGING 13:00 - 14:30 1.50 DRILL P INT1 POH WITH OUT PUMPING - TIGHT SPOT AT 15585' - 35 TO Printed: 11/19/2001 10:04:55AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/6/2001 11/7/2001 11/8/2001 (' ( BP EXPLORATION Operations Summary Report MPF-94 MPF-94 DRILL +COMPLETE NABORS Nabors 27E 13:00 - 14:30 From - To Hours Activity Code NPT INT1 14:30 -15:00 15:00 -16:00 16:00 - 20:30 20:30 - 21 :00 21 :00 - 00:00 00:00 - 02:00 02:00 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 10:30 10:30 - 14:30 14:30 - 21 :30 21 :30 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 07:00 1.50 DRILL 0.50 DRILL 1.00 DRILL 4.50 DRILL 0.50 DRILL 3.00 DRILL 2.00 DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 1.50 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 1.50 DRILL 4.00 DRILL 7.00 DRILL 2.50 DRILL 2.50 DRILL 0.50 DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 1.00 DRILL P P INT1 P INT1 P INT1 P P INT1 INT1 P INT1 P INT1 P P INT1 INT1 P INT1 P INT1 P INT1 P P INT1 INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P P INT1 INT1 P INT1 P INT1 Page 10 of 15 Start: 10/13/2001 Rig Release: 11/17/2001 Rig Number: Spud Date: 10/15/2001 End: 11/17/2001 Phase Description of Operations 45 OVER - KELLY UP - PUMP FROM 15585' TO 15397' - (CUTTINGS BEDS) CIRCULATE AT - 600 GPM - 2150 PSI- RPM 120 - CLEAN UP HOLE MOVE CUTTINGS BEDS UP HOLE - PULL ONE STAND WIO PUMP TO CHECK OUT HOLE OVER PULL - NO OVER PULL SEEN RIH FROM 15397' TO 16900' - PRECAUTIONARY WASH FROM 16900' TO 16993' - 590 gpm -120 rpm - DOWNLINK POWER DRIVE - 180 DEG 60% DIRECTIONAL DRILL FROM 16993' TO 17369' - WOB 11 - TO 21 - RPM 120 - GPM - 590 - 2100 - ECD 10.20 - (START WEIGHTING UP SYSTEM TO 9.6 @ 17350')( DOWNLI NK POWER DRIVE AT 17213' 202 DEG 60%) CIRCULATE - DOWNLINK POWER DRIVE - 219 DEG 80% DIRECTIONAL DRILL FROM 17369' TO 17746' - WOB 14- TO 22 - RPM 130 - GPM 590 - PSI 2350 - ECD 10.62 - PIU 235 - SIO 145 - ROT 175 DIRECTIONAL DRILL FROM 17745 TO 17900 - woe 15- GPM 590 - PSI 2330 - RPM 130 TO 22 - ECD 10.7 CIRCULATE HOLE ONE BOTTOM'S UP - LEVEL OUT MUD WEIGHT TO 9.7 - STAND BACK ONE STAND EVERY 30 MINS RIH FROM 17557' TO 17840' DOWNLINK POWER DRIVE TO 0 DEG 20% - WASH TO BOTTOM FROM 17840 TO 17900 DIRECTIONAL DRILL FROM 17900 TO 18059' - WOB 18 - RPM 140 - TO 23 - GPM 590 - PSI 2440 - ECD 10.7 CIRCULATE - DOWNLINK POWER DRIVE @ 18059 TO 337 DEG 60% DIRECTIONAL DRILL FROM 18059 TO 18158' - WOB 13- RPM 132 - TO 21 - GPM 590 - PSI 2480 - ECD 10.78 CIRCULATE - DOWNLINK POWER DRIVE 0 DEG 20% DIRECTIONAL DRILL FROM 18158' TO 18218' - WeB 14- RPM 135 - TO 22 - GPM 590 - PSI 2510 - ECD 10.8 CIRCULATE AND RAISE MUD WEIGHT FROM 9.7 TO 10 # TO PREPARE TO DRILL KUPARUK SANDS DIRECTIONAL DRILL FROM 18218' TO 18595' TD - WOB 15 - RPM 135 - TO 22 - GPM 590 - PSI 2640 - ECD 11.17 CIRCULATE - CLEAN HOLE UP 4 BOTTOMS UP - 52000 STKS - GPM 590 - RPM 130 - PSI 2650 POH WITH OUT PUMP - FROM 18121 TO 15863'- HOLE IN GOOD CONDITION POH FROM 15863' TO 12220' - TIGHT SPOTS 13611' 15K OVER - 13044' 12K OVER - 12220' 30K OVER - CUTTINGS BED'S CIRCULATE I CLEAN UP HOLE - @ 12220' 590 GPM 130 RPM - 2350 PSI - POH FROM 12220' TO 10229' - NO OVER PULLS SEEN CIRCULATE I CLEAN UP HOLE @ 10229' - 590 GPM - 130 RPM - 2350 PSI CLEAN RIG FLOOR OF MUD - P/U FLOOR - PREPARE TO CUT DRILL LINE CUT DRILLING LINE Printed: 11/19/2001 10:04:55AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/8/2001 11/9/2001 11/10/2001 ( (" BP EXPLORATION Operations Summary Report MPF-94 MPF-94 DRILL +COMPLETE NABORS Nabors 27E 07:00 - 09:00 From - To Hours Activity Code NPT INT1 09:00 - 12:00 12:00 - 12:30 12:30 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 18:30 18:30 - 00:00 00:00 - 01 :00 01:00 - 01:30 01 :30 - 02:00 02:00 - 08:30 08:30 - 12:00 12:00 - 12:30 12:30 - 15:00 15:00 -16:30 16:30 - 19:00 19:00 - 19:30 19:30 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 07:00 07:00 - 08:00 08:00 - 10:00 10:00 -18:00 18:00 -19:00 19:00 - 20:00 20:00 - 22:30 2.00 DRILL 3.00 DRILL 0.50 DRILL 2.50 DRILL 1.00 DRILL 0.50 DRILL 2.00 DRILL 5.50 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 6.50 DRILL 3.50 DRILL 0.50 DRILL 2.50 DRILL 1.50 DRILL 2.50 DRILL 0.50 DRILL 4.50 DRILL 1.00 DRILL 0.50 DRILL 5.50 DRILL 1.00 DRILL 2.00 DRILL 8.00 DRILL 1.00 DRILL 1.00 DRILL 2.50 DRILL P P P P P P P P INT1 INT1 INT1 INT1 INT1 INT1 INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P INT1 P P INT1 INT1 P P INT1 INT1 P INT1 P INT1 P P INT1 INT1 P N P INT1 RREP INT1 INT1 Page 11 of 15 Start: 10/13/2001 Rig Release: 11/17/2001 Rig Number: Spud Date: 10/15/2001 End: 11/17/2001 Phase Description of Operations CIRCULATE AT 10229' BOTTOMS UP 590 GPM -130 RPM- 2300' PSI POH FROM 10229' TO 5078' PJSM - ON POOH WITH TONGS POOH FROM 5078' TO BHA UD BHA PJSM ON RIG UP OFSCHLUMBERGER WIRE LINE PIU SCHLUMBERGER RFT TOOLS - TEST TOOLS RIH WITH SCHLUMBERGER TOOLS ON 5" DRILL PIPE - FILL PIPE BREAK CIRCULATION @ 5000' - CON'T RIH to 7132' RIH FROM 7132 TO 10238' WITH SCHLUMBERGER TLC RFT TOOL PJSM FOR HANGING SCHLUMBERGER SHEAVE IN DERRICK FOR WIRE LINE WORK HANG SCHLUMBERGER WIRE LINE SHEAVE - CIRC WITH 33 STKS AT 350 PSI WHILE HANGING SHEAVE CON'T RIH FROM 10238' TO - 16805' FILLING AND BREAKING CIRCULATION EVERY 10 STANDS ON TRIP IN WITH RFT TOOLS - @ 16805' DRILL PIPE PLUGGED - PSI 1000 NO RETURNS - PULL 5 STANDS ESTABLISH CIRC AT 16428' - RIH FROM 16428' TO 18030' WASHING EVERY OTHER STAND TO KEEP CIRC PORT SUB FROM PLUGGING PJSM RIGGING UP WIRE LINE SIDE ENTRY SUB AND RUNNING WIRE LINE IN HOLE THROUGH PIPE RIG UP SIDE ENTRY SUB @ 17968' - RUN WET CONNECT IN 5" DRILL PIPE ATTEMPT TO LATCH UP TO RFT TOOL WITH WET CONNECT PUMPING 6 TO 8 BPM - 1100 TO 1200 PSI - ATTEMPT TO LATCH 8 TIMES - NO SUCCESS IN LATCHING ONTO TOOL PULL WIRE LINE OUT OF HOLE - CHECK WET CONNECT- NO PROBLEMS WITH CONNECTION - TOOL OPERATIONAL RIG DOWN WIRE LINE - PUMP DRY JOB POOH WITH 5" DRILL PIPE - RFT TOOLS FROM 17968' TO 11221' CON'T POH WITH RFT TO 11221' RO 10281' RIG DOWN - LAY DOWN SHLUMBERGER SHEAVE FROM DERRICK - CLEAR FLOOR CON'T OUT OF HOLE FROM 10281' TO SCHLUMBERGER TOOL LAY DOWN SHLUMBERGER RFT TOOL AND EQUIPMENT - SCHLUMBERGER TOOL PACKED WITH CLAY - WET CONNECT ROD BENT TO ONE SIDE PICK UP I MAKE UP 9 7/8" BIT - WIPER BHA RIH WITH WIPER BHA TO 10300' - FILLING EVERY 25 STAND - CIRC AT 5000' BOTTOMS UP - CON'T RIH FILLING EVERY 25 STANDS TO 10300' CBU 1 X AT SHOE @10300' - 590 GPM 130 RPM WORK ON IRONROUGH NECK CON'T RIH FROM 10300' TO 14350' - FILLING EVERY 25 Printed: 11/19/2001 10:04:55AM BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/10/2001 20:00 - 22:30 2.50 DRILL P INT1 STANDS AND BREAKING CIRC - TAKING WEIGHT 40K DOWN OVER STRING - KELLY UP - BREAK CIRC - CIRCULATE HOLE - WASH AND REAM FROM 14330' TO 14391' 23:30 - 00:00 0.50 DRILL P INT1 CON'T RIH FROM 14391' TO 15153' - TAKING WEIGHT 20K- WASH REAM FROM 15116' TO 15175' - CLEAN UP HOLE 11/11/2001 00:00 - 00:30 0.50 DRILL P INT1 RIH WITH WIPER TRIP ASSEMBLY - FROM 15146' TO 15581' - TAKIING WEIGHT 40K - PIU 300K 00:30 - 02:00 1.50 DRILL P INT1 WASH I REAM 15524' TO 16558' - GPM 540 - 2400 PSI-130 RPM -17K TO 02:00 - 02:30 0.50 DRILL P INT1 CIRC OUT TRIP GAS - FLOW INCREASED FROM 45% TO 74% - MUD WEIGHT CUT FROM 10 TO 9.8 02:30 - 06:00 3.50 DRILL P INT1 CON'T TRIP IN HOLE WITH WIPER ASSY - TAKING WEIGHT AT 16996' 40K - REAM FROM 16934' TO 17028'- TAKING WEIGHT AT 17288' 40K - REAM FROM 17216' TO 17493' - CON'T RIH TO 18433' - REAM FROM 18433' TO 18595 - GPM 520 - PSI 2250 - RPM 120 - TO 20 TO 21 06:00 - 13:00 7.00 DRILL P INT1 CIRCULATE 56000 STKS - (4 X CBU) STAND BACK ONE STAND EVERY 10000 STKS PUMPED - 590 GPM -130 RPM - TO 22 - PSI 2900 - PIU 185 - SO 180 - SHAKERS CLEAN - LOWERED YIELD TO 15 TO PREPARE TO RUN 7" CASING 13:00 -13:30 0.50 DRILL N DPRB INT1 PUMP SLUG - ATTEMPT TO POOH - PULLING TIGHT- DRAG 30 TO 50K OVER - PULL FROM 18160' TO 18066'- NORMAL PIU 320 - SO 125 - 13:30 - 20:00 6.50 DRILL N DPRB INT1 BACKREAM FROM 18066' TO 15994' - RPM 130 - GPM 590 - PSI 2350 - TO 14K TO 21K - PIU 275 - SO 80 - ROT 160- ATTEMPT TO PULL WITHOUT PUMP THROUGH OUT SECTION - PIU WEIGHT 300+ CAN NOT PULL WITHOUT ROTATING AND PUMPING - COFFEE GRIND SIZE CUTTINGS OVER SHAKERS AFTER BOTTOMS UP FROM BACK REAMING 20:00 - 21 :00 1.00 DRILL N DPRB INT1 PUMP OUT OF HOLE WITH OUT ROTATING - FROM 15994' TO 15524' - HOLE DRAG INCREASING UP TO 290 TO 300- ACTS LIKE CUTTINGS BEDS 21:00-21:30 0.50 DRILL N DPRB INT1 CIRCULATE HOLE CLEAN FROM 15524' TO 15430'- 600 GPM - PSI 2650 - RPM 130 - TO 14K - PIU 155 - ROT 150- 4200 STKS CIRCULATED 21 :30 - 22:30 1.00 DRILL N DPRB INT1 POOH WITH OUT PUMP OR ROTATING - FROM 15430' TO 14302' - STRING DRAG 225K TO 275K 22:30 - 00:00 1.50 DRILL N DPRB INT1 CIRCULATE HOLE CLEAN - 628GPM - PSI 3075 - RPM 130- TO 14 - WORKING STRING FROM 14396' TO 14302' WHILE CIRCULATING CBU 11/12/2001 00:00 - 03:00 3.00 DRILL N DPRB INT1 RIH FROM 14302' TO 18438' - FILL PIPE I CIRC HOLE @ 15618' - 500 GPM - 2150 PSI- @ 17122' - 500 GPM - 2150 PSI 03:00 - 03:30 0.50 DRILL N DPRB INT1 PRECAUTIONARY WASH I REAM FROM 18438' TO 18595' - 500 GM - 120 RPM - 2200 PSI - 20K TO 03:30 - 10:00 6.50 DRILL N DPRB INT1 18595' TO 18061' - CIRCULATE I CONDITION HOLE I MUD- (4 X CBU) - FOR RUNNING CASING - 630 GPM 3350 PSI - 130 RPM - TO 23K - STANDING BACK ONE STAND EVERY 10,000 STKS - (15000 STKS PUMPED) - LOST # 2 MUD PUMP - FLUID END WASHED OUT - CIRCULATION RATE REDUCED - # 1 PUMP 481 GPM - PSI 2150 PSI- RPM 120- ( ( Printed: 11/19/2001 10:04:55AM ( ( BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/12/2001 03:30 - 10:00 6.50 DRILL N DPRB INT1 TO 20K - INCREASE YP 15 TO 30 - FOR HOLE CLEANING 10:00 -13:30 3.50 DRILL N DPRB INT1 18061' ATTEMPT TO POOH - DRAG 50K TO 75K OVE R - ATTEMPT TO PUMP OUT OF HOLE WITH OUT ROTATING- DRAG STILL 50K TO 75K OVER - BACK REAMING IN ORDER TO POH - BACK REAM FROM 18061' TO 15711'- 20K TO 25K DRAG - BACK REAMING FROM 18061' TO 16933' - SMOOTH ABOVE 16933' 13:30 -14:00 0.50 DRILL N DPRB INT1 CIRCULATE OPEN HOLE CLEAN - WORK PIPE FROM 15711' TO 15621' - GPM 481 - 1850 PSI- 120 RPM -15K TO 14:00 - 15:00 1.00 DRILL N DPRB INT1 CON'T POOH FROM 15711 TO 14750 - TIGHT @ 14750- 30K OVER 15:00 - 16:00 1.00 DRILL N DPRB INT1 PUMP OUT FROM 14750' TO 14019' - DRAG INDICATING CUTTINGS BEDS - 481 GPM - 1850 PSI 16:00 - 17:00 1.00 DRILL N DPRB INT1 CIRCULATE OPEN HOLE CLEAN - FROM 14019' TO 13929'- GPM 481 - 120 RPM - 1850 PSI - TO 14K 17:00 - 18:30 1.50 DRILL N DPRB INT1 POOH FROM 14019' TO 12234' - DRAG 225 TO 230 - TIGHT @ 12260 - 65K OVER 18:30 - 19:00 0.50 DRILL N DPRB INT1 CIRCULATE OPEN HOLE CLEAN - FROM 12328' TO 12234'- GPM 481 - PSI 1700 - TO 15K - RPM 120 19:00 - 20:30 1.50 DRILL N DPRB INT1 CON'T POOH FROM 12234' TO 10260' - DRAG 205K TO 225K - AVERAGE 215K 20:30 - 23:30 3.00 DRILL N DPRB INT1 CIRCULATE CASING CLEAN - WORK PIPE FROM 10260' TO 10190' - 481 GPM - PSI 1700 -120 RPM - TO 17K (3 X CBU) 23:30 - 00:00 0.50 DRILL P INT1 CUT DRLG LINE 11/13/2001 00:00 - 01 :00 1.00 DRILL P INT1 CUT DRILLING LINE 01 :00 - 01 :30 0.50 DRILL P INT1 SERVICE TOP DRIVE 01 :30 - 03:00 1.50 DRILL P INT1 TRIPPING OUT TO 7265 03:00 - 11 :00 8.00 DRILL P INT1 LAYING DOWN DRILL PIPE AND BHA FROM 7265 11 :00 - 11 :30 0.50 CASE P INT1 PULLED WEAR RING 11 :30 - 13:30 2.00 CASE P INT1 PJSM AND RIG UP CSGERS 13:30 - 14:00 0.50 CASE P INT1 PJSM ON RUNNING CSG 14:00 - 20:30 6.50 CASE P INT1 RUNNING CSG 7 " 26 # L-80 BTC -MOD TO 5,000 FT, FILLING EVERY JT. 20:30 - 21 :30 1.00 CASE P INT1 CIRC CSG @ 5000 FT. AND THIN MUD 600 PSI WI 93 PUMP STKS OR 390 GALS PER MIN, PUMPED A TOTAL OF 4,000 PUMP STKS 21 :30 - 22:00 0.50 CASE P INT1 RUNNING CSG 7 " 26 # L-80 BTC -MOD FROM 5,000 FT TO 5300 FILLING EVERY JT. 22:00 - 22:30 0.50 CASE N RREP INT1 SHORE POWER WENT DOWN, START MOTORS 22:30 - 00:00 1.50 CASE P INT1 RUNNING CSG 7 " 26 # L-80 BTC -MOD FROM 5,300 FT TO 6985 FILLING EVERY JT. 11/14/2001 00:00 - 04:00 4.00 CASE P INT1 RUNNING CSG 7 " 26 # L-80 BTC -MOD FROM 6985 FT TO 10,263 FILLING EVERY JT. 04:00 - 05:30 1.50 CASE P INT1 CIRC @ 10263 AND THIN MUD, SPOT 2 BBLS OF EP MUD LUBE OUT SHOE 900# AND 394 GALS MIN, LEFT IN CSG 8 DRUM LUBE- TEX IN CSG. 05:30 - 09:00 3.50 CASE P INT1 RUNNING CSG 7" 26 # L-80 BTC -MOD FROM 10,263 TO 13368 FILLING EVERY JT. 09:00 - 09:30 0.50 CASE P INT1 CIRC @ 133681000#AND 394 GALS MIN WORKED PIPE CIRC FOR 180 BBLS Printed: 11/19/2001 10:04:55AM ( (" BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: MPF-94 Common Well Name: MPF-94 Spud Date: 10/15/2001 Event Name: DRILL +COMPLETE Start: 10/13/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/14/2001 09:30 - 16:00 6.50 CASE P INT1 RUNNING CSG 7 " 26 # L-80 BTC -MOD FROM 13368 TO 18558 FILLING EVERY JT.- CIRC @ 16,460 TO 16543. WITH 1100# 343 GALS MIN FOR 180 BBLS, -TOTAL JTS. RUN 451 TAKING WT AND TRYING TO PACK OFF AS CIRC. DOWN JT. 451 16:00 - 18:00 2.00 CASE P INT1 CIRC. WITH FRANKS FILL UP TOOL, WITH 252 GALS MIN WORKING IT UP TO 394 GALS MIN AND 1100 PSI, SETTING CSG 37 FT OFF BOTTOM @ 18558 18:00 -19:00 1.00 CASE P INT1 PJSM AND RIG UP CEMENTING HEAD 19:00 - 23:00 4.00 CASE P INT1 CIRC WITH 1000# AND 394 GALS MIN. AND EMPTY PITS FOR CEMENT JOB, TRYED TO WORK PIPE, WOULDN'T MOVE WITH 400,000 # 23:00 - 00:00 1.00 CASE P INT1 PJSM AND FUSH MUD LINES WITH SEA WATER 11/15/2001 00:00 - 01 :00 1.00 CEMT P COMP TEST LINES TO 3500# MIX AND PUMP 10 BBLS WATER A HEAD, 50 BBLS ALPHA SPACER MIX @ 11.0 DROP BOTTOM PLUG, 400 SXS., CLASS G MIX @ 15.8 YIELD 1.15, 82 BBLS SURRY PUMP@ 5 BBL MIN. 800 PSI, WASH OUT CEMENT LINES, DROP TOP PLUG WITH 30 BBLS WATER 01 :00 - 02:30 1.50 CEMT P COMP DISPLACE WITH 677 BBLS OF SEA WATER @ 9 BBLS MIN , BUMP PLUG WITH 1000 PSI OVER CIRC. PRESSURE TOTAL 2200 PSI, FULL RETURNS TRU OUT JOB, FLOATS HELD, NO FLOW CIP @ 2.30 AM 02:30 - 03:00 0.50 CEMT P COMP RIG DOWN CEMENT HEAD 03:00 - 04:00 1.00 BOPSUF P COMP NIPPLE DOWN BOP AND PICK UP 04:00 - 05:30 1.50 BOPSUF P COMP INSTALL FMC C-21 SLIPS AND SET WITH 225,000# WT. 05:30 - 10:30 5.00 BOPSUF P COMP MAKE ROUGH CUT ON 7" CSG, MAKE FINAL CUT AND DRESS 7" STUB, INSTALL PACK-OFF, NIPPLE UP BOPS, TEST PACK OFF TO TO 3750# 10:30 - 11 :00 0.50 PULL P COMP RIG UP BAILS AND CLEAR FOOR TO LAY DOWN PIPE 11:00 -14:00 3.00 PULL P COMP PJSM AND LAYING DOWN DRILL PIPE IN MOUSE HOLE 14:00 - 15:00 1.00 PULL N RREP COMP REPAIR IRON ROUGHNECK 15:00 - 17:00 2.00 PULL P COMP LAYING DOWN DRILL PIPE IN MOUSE HOLE 17:00 - 19:00 2.00 PULL N RREP COMP REPAIR IRON ROUGHNECK 19:00 - 00:00 5.00 PULL P COMP LAYING DOWN DRILL PIPE IN MOUSE HOLE 11/16/2001 00:00 - 02:00 2.00 PULL P COMP LAYING DOWN DRILL PIPE IN MOUSE HOLE - LEFT 40 STANDS IN DERRICK FOR NEXT WELL -10 STANDS ON DRILLER SIDE, 30 STANDS OFF DRILLER SIDE 02:00 - 02:30 0.50 BOPSUF P COMP WASH BOP STACK AND KILL LINES WITH SEA WATER 02:30 - 03:30 1.00 BOPSUF P COMP PJSM, TEST 7" CSG WITH 3500 PSI FOR 30 MIN. GOOD TEST 03:30 - 17:30 14.00 RUNCO~ P COMP PJSM, RIG UP AND PICKING UP, 4.5 12.6# L-80 IBT TUBING TO 13,684 17:30 - 00:00 6.50 RUNCO~ N RREP COMP DOWN TIME, RIG REPAIR ( PIPE PICKUP MACHINE) CHANGE OUT HYDRAULIC PUMP MOTOR AND MAIN WINCH MOTOR 11/17/2001 00:00 - 01 :30 1.50 RUNCO~ N RREP COMP CONTINUE RIG DOWN TIME - REPAIR OF PIPE SKATE 01 :30 - 05:30 4.00 RUNCO~ P COMP FINISH PICKING UP TUBING - TOTAL 446 JTS 12.6# L-80 IBT 18,048' 05:30 - 06:00 0.50 RUNCO~ N RREP COMP ATTEMPT TO MAKE UP 5" DRILL PIPE LANDING JT WITH IRON ROUGHNECK - ROUGHNECK WILL NOT TORQUE CONNECTION 06:00 - 07:00 1.00 RUNCO~ P COMP MAKE UP FMC NEW SLIM HOLE 13 X 41/2" TUBING Printed: 11/19/2001 10:04:55AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( t' , Page 15 of 15 BP EXPLORATION Operations Summary Report MPF-94 MPF-94 DRILL +COMPLETE NABORS Nabors 27E 11/17/2001 06:00 - 07:00 From - To Hours Activity Code NPT Phase COMP Date 07:00 - 07:30 07:30 - 08:00 08:00 - 10:30 10:30 - 11 :00 11 :00 - 11 :30 11:30 -12:00 12:00 -13:00 13:00 - 16:30 16:30 -19:00 19:00 - 23:00 23:00 - 00:00 1.00 RUNCO~P 0.50 RUNCO~P 0.50 RUNCO~P COMP COMP 2.50 RUNCO~P COMP 0.50 RUNCO~fP 0.50 RUNCO~fP COMP COMP 0.50 RUNCO~fP COMP 1.00 RUNCO~/p 3.50 RUNCO~/p 2.50 RUNCO~fP COMP COMP COMP 4.00 RUNCO~ P COMP 1.00 RUNCO~ P COMP Start: 10/13/2001 Rig Release: 11/17/2001 Rig Number: Spud Date: 10/15/2001 End: 11/17/2001 Description of Operations HANGER - NSCT LANDING THREAD - LAND TUBING STRING - RUN IN LOCK DOWN SCEWS - STRING PICK UP WT. 190K - SLACK OFF WT. 90K - TOP DRIVE WT. 55K DROP 1 7/8" STEEL BALL - RIG UP LINES TO PUMP DOWN BALL AND TAKE RETURNS OUT ANNULUS VALVE PUMP BALL DOWN AT 3 BPM 400 PSI - BALL ON SEAT AT 0800 HRS PRESSURE UP TO 3000 PSI VERIFY PRESSURE HOLDING - CONTINUE PRESSURE UP TO 4200 PSI AND SET BAKER 7 X 4 1/2" PREMIER PACKER AT 18,154' - ATTEMPT TO PRESSURE TEST TUBING - TUBING WILL NOT TEST - PRESSURE BLED OFF 100 PSI PER MINUTE - CONTINUE TO ATTEMPT TUBING TEST - NO SUCCESS TEST ANNULUS TO 2200 PSI - HOLDING PRESSURE SWITCH BACK TO TUBING - ATTEMPT TO TEST TUBING TO 3500 PSI- NO TEST - PRESSURE LEAKING OFF AT 100 PSI I MINUTE AS BEFORE PRESSURE UP ANNULUS - SHEAR RP VALVE AT 2500 PSI - CIRCULATE 3 BPM 3700 PSI- CIRCULATION PRESSURE HIGH BACK OUT LANDING JT, SET 2-WA Y CHECK, TEST TO 1000 PSI FROM BELOW NIPPLE DOWN BOPS NIPPLE UP ADAPTER SPOOL, TEST PACK OFF TO 5000 PSI, NIPPLE UP 41/165000 psi CIW TREE AND TEST TO 5000 PSI FOR TEN MIN. PULL TWO CHECK, RIG UP HB&R TO 10314 * 7 ANN. TEST LINES TO 5000 PSI AND DEAD HEAD 100 BBLS DIESEL DOWN ANN. TO FREEZE PROTECT @ 3 BBLS MIN 1700 PSI, RIG UP ON 4.5 X 7" ANN. AND CIRC DOWN 75 BBLS DIESEL @ 2.6 BBLS MIN. 2700 PSI ALLOW TO U-TUBE FOR 1.5 HRS AND PRESSURE WAS 0, SET BPV INSTALL BULL PLUGS IN UPPER & LOWER ANN VALVES AND REMOVE PUMP IN FLANGE FROM WING VALVE, INSTALL BLIND FLANGE. ( RIG RELEASE TO MOVE TO MPF-90 @ 2400 HRS.) Printed: 11/19/2001 10:04:55AM Legal Name: Common Name: TestÐate 10/29/2001 LOT MPF-94 MPF-94 10,395.0 (ft) 4,452.0 (ft) 9.20 (ppg) Surface Pressure 1 ,100 (psi) Leak Off Pressure (BHP) 3,228 (psi) Page 1 o! 1 EMW 13.96 (ppg) ~ ~ Printed: 11/19/2001 10:04:47 AM ( (' c Well: Field: API: Permit: MPF-94 Milne Point Unit I Kuparuk River Sands 50-029- 23040-00 201-170 Rig Accept: Rig Spud: Rig Release: Drilling~: 10/15/01 10/16/01 11/17101 Nabors 27E -.------. ---.----.-- .-----.---..-.- POST - RIG WORK 11/25/01 SWS ARRIVED LOCATION, HELD PRE-JOB SAFETY MEETING, PRESSURE TEST EQUIPMENT. START IN THE HOLE WITH GR I CCL 2.5",2506 POWER JET, 4 SPF, 60 DEGREE PHASING, 2' GUN WITH 9 SHOT. RAN ROLLERS THROUGHOUT TOOLS INCLUDING BOTTOM OF GUN. ROLLED DOWN THE WELL WITHOUT ANY TROUBLE. HAD TROUBLE WITH LOWER CABLE ON THE SPOOL. WORKED TOOLS DOWN TO PBTD @ 18462' LOGGED UP TO 18000, DROPPED BACK AND MADE A TIE IN PASS USING GR ICCL. LOGGED UP INTO SHOT DEPTH. 10' FROM CCL TO TOP SHOT 18280',2' SHOT FROM 18290' -18292', TUBING WAS SITTING IN AT O-PSI - AFTER SHOT TUBING INCREASED TO 500 PSI POH ALL SHOTS FIRED. 12/01/01 SWS ARRIVED LOCATION, HELD PRE-JOB SAFETY MEETING, PRESSURE TEST EQUIPMENT. START IN THE HOLE WITH GR I CCL 2.5",2506 POWER JET, 4 SPF, 60 DEGREE PHASING 2' GUN WITH 9 SHOTS. RAN ROLLERS THROUGHOUT TOOLS INCLUDING BOTTOM OF GUN. ROLLED DOWN THE WELL WITHOUT ANY TROUBLE. STARTED PASS AT 18370' LOGGED UP TO 18100, TIED INTO GR I CCL (DATED 11/26/01), DROPPED BACK AND MADE A TIE IN PASS USING GR I CCL. LOGGED UP INTO SHOT DEPTH 10' FROM CCL TO TOP SHOT 18318',2 SHOT -- FROM 18328' - 18330', ADJUSTED SHOT DEPTH TO BEST PORTION OF THE ZONE. TUBING PRESSURED UP WHILE TOOLS ENTERED THE TUBING. PRESSURE WAS 550 PSI BEFORE ENTERING THE WELL; PRESSURE INCREASED TO 1050 PSI ATTEMPTED TO BLED DOWN TUBING BEFORE SHOT. TUBING DROPPED TO 700 PSI WELL FLUID PACKED. SHOT GUN. SAW SLIGHT DECREASE IN PRESSURE. 12/08/01 & 12/09/01 MIRU CTU #2. RIG UP IN PROGRESS. CONTINUE WI RIG UP. PUMP 718" BALL THROUGH CT. MU BAKER MHA, SCHLUMB MEM GR/CCL. RIH. LOG FROM 18100' TO PBTD. TAG 18355.6'. POOH, FLAG 18319.9', LOG TO 18100'. POOH. RD GR/CCL. GOOD DATA. RU 1ST GUN 10' OF 3-3/8" 3412 POWERFLOW HMX, 12SPF, 45 DEGREE PHASING. SHOOTING 18335-18325'. RIH. CORRECT FLAG DEPTH, SHOOT 18325-18335'. POOH. GUN FIRED OK. RU 2ND GUN OF 3-318" 3412 POWERFLOW HMX, 12SPF, 45 DEGREE PHASING. SHOOTING 18300'-18310'. RIH. TAG BTM, CORRECT TO FLAG DEPTH, SHOOT 18300'-18310'. POOH. FREEZE PROTECT FLOWLINE AND PROD TBG WI METHIWTR. RD. "': >-- 12/11/01 PUMP 150 BBL DATA FRAC AND FLUSH 288 BBL WF120. PUMP @ 10 BPM TILL PAD ON PERFS, INC RT TO 25 BPM @ 4000 PSI. SD ISIP=1986 PSI FG=.69. DECLINE ANALYSIS EST =15.5 MIN CLOSURE, CLOSURE PSI=1752 PSI, FLUID EFF=59%, 229# NET BUILD. RE AJUST PAD TO 100 BBL. START DH WI YF130LG FLUID 100 BBL PAD. RAMP FROM 1-6 PPA 16/20 C-LlTE. STEP FROM 6 TO 10 PPA. 9 AND 10 PPA STAGES 12/18 SAND. LAST 25 BBLS INCREASED TO 12 PPA. AVE PSI=3850 PSI AVE RT=25 BPM ONCE PAD ON PERF. PLACED 117,29816/20 C-LlTE AND 73,74012/18 C-LlTE (191038#) BEHIND PIPE. LEFT 1648# IN WELL BORE. MPF-94 Post Rig Summary .Page 2 ( ( 12/15/01 & 12/16/01 RIH W/2.5" JSN. TAG SAND TOP @ 177401. JET TO 18266 W/12 BBL FLOPRO, 16 & 10 BBL BIO SWEEPS CHASED UP. JET 11 BBL FLOPRO SWEEP FROM 18266', CHASE UP @ 50% TO 17123'. RIH TO 18625'. BEGIN TAKING 20' BITES W/12 BBL FLOWPRO CHASED BY 45 BBLS XS FROM 18265'. CLEAN OUT TO 18405'. JET OVER JEWLERY AND POOH @ 50%. APC FLOWMETER BROKEN, SEPARATOR HAS 4' OF FRAC SAND. RIH TO JETTING AND FCO TO 18200', WASH WITH KCL AND CHASE TO SURFACE @ 70%. STANDBY TO CLEAN OUT APC TEST SEPARATOR AND XS WATER HAULING. WSR. RIH, JETTING TO 1500'. JET 10 BBL FLOPRO SWEEP/30 XS WATER. MAX RATE. POH TO CHECK NOZZLE. SOME PLUGGING FOUND. RIH JETTING. FROM 15001-3000', TAKE 500'/10 BBL FLOPRO SWEEP BITE FOLLOWED BY 30 BBLS wrR. AT 3000'- CIRCULATE BOTTOMS UP. CONTINUE SAME PATTERN TO 4500'. AT 4500'-CIRCULATE BOTTOMS UP. FROM 4500'-18100', TAKE 3000' BITES W/10 BBL FLOPRO SWEEPS FOLLOWED BY 50 BBLS wrR @ MAX RATE. JETTED FLOPRO ACROSS JEWELRY FROM 17800'-18100 @ 54 FPM. PARK @ 18100 PUMP 50 BBL wrR, 20 BBL FLOPRO, 10 BBL WTR CHASER. POH @ 60% PUMP 2.1 BPM. POOH. RD AND MOVE TO EDGE OF PAD TO WAIT ON SL DRIFT. 12/21/01 SET JET PUMP W/ GAUGES @ 17,841' SLM. ANADRILL SCHLUMBERGER Survey report Client........... ... .....: BP Exploration (Alaska) Inc. Field.... ...... ..... .....: Milne Point Well. . . . . . . . . . . . . . . . . . . . .: MPF- 94 API number....... ........: 50-029-23090-00 Engineer....... ..... .....: St. Amour COUNTY: . . . . . . . . . . . . . . . . . .: Nabors 27E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... .... ....: Mason & Taylor ----- Depth reference ----------------------- Permanent datum. .... ... ..: GROUND LEVEL Depth reference....... ...: GL above permanent.......: KB above permanent..... ..: DF above permanent.......: 11.00 ft 0.00 ft 44.33.00 ft ----- Vertical section origin---------------- Latitude (+N/S-). ... .....: 0.00 ft Departure (+E/W-) ........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-). ........: -999.25 ft Departure (+E/W-)... .....: -999.25 ft Azimuth from rotary table to target: 6.22 degrees [(c)2001 Anadrill IDEAL ID6_1C_10] 7-Nov-200117:16:17 Spud date. . . . . . . . . . . . . . . . : Last survey date... .., ...: Total accepted surveys...: MD of first survey.......: MD of last survey... .....: Page 1 of 8 17-0ct-01 07-Nov-01 201 0.00 ft 18595.00 ft .~ ----- Geomagnetic data ---------------------- Magnetic model.. .... .....: BGGM version 2000 Magnetic date... ..... ....: 15-0ct-2001 Magnetic field strength..: 1148.89 HCNT Magnetic dec (+E/W-).....: 26.11 degrees Magnetic dip. ... .... .....: 80.81 degrees ----- IFR survey Reference Reference G......... .....: Reference H..... .... .....: Reference Dip. ....... ....: Tolerance of G.. ..... ....: Tolerance of H... .... ....: Tolerance of Dip..... ....: Criteria --------- 1002.69 mGal .: 1149.20 HCNT 80.82 degrees <+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ,~ ----- Corrections --------------------------- Magnetic dec (+E/W-). ....: 26.12 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.12 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N).. ......: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 7-Nov-200117:16:17 Page 2 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Disp1 Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 112.00 0.00 0.00 112.00 112.00 0.00 0.00 0.00 0.00 0.00 0.00 MWD 3 174.81 0.27 157.03 62.81 174.81 -0.13 -0.14 0.06 0.15 157.03 0.43 MWD 6-axis 4 203.13 0.27 167.81 28.32 203.13 -0.25 -0.26 0.10 0.28 159.58 0.18 MWD 6-axis 5 294.61 0.15 201.07 91.48 294.61 -0.57 -0.59 0.10 0.59 170.27 0.18 MWD 6-axis 6 316.01 0.05 276.80 21.40 316.01 -0.60 -0.61 0.08 0.62 172.44 0.68 IFR - -~. 7 385.94 0.40 7.06 69.93 385.94 -0.35 -0.36 0.08 0.37 167.52 0.58 IFR 8 477.19 1.40 356.38 91.25 477.18 1.06 1.06 0.05 1.07 2.66 1.11 IFR 9 568.65 2.11 356.02 91.46 568.59 3.82 3.86 -0.14 3.86 357.95 0.78 IFR 10 658.80 3.20 4.32 90.15 658.64 7.97 8.02 -0.06 8.02 359.55 1.28 IFR 11 747.58 4.57 8.52 88.78 747.22 13.98 13.99 0.65 14.01 2.65 1.58 IFR 12 840.71 5.61 9.14 93.13 839.98 22.23 22.16 1.92 22.24 4.95 1.12 IFR 13 934.45 7.86 10.33 93.74 933.07 33.20 32.99 3.80 33.20 6.57 2.40 IFR 14 1029.23 10.93 11.54 94.78 1026.56 48.62 .48.17 6.76 48.64 7.99 3.25 IFR 15 1122.92 13.11 7.65 93.69 1118.20 68.09 67.41 9.95 68.14 8.40 2.48 IFR 16 1216.83 14.35 4.48 93.91 1209.42 90.37 89.57 12.28 90.40 7.80 1.54 IFR 17 1310.48 16.72 7.39 93.65 1299.65 115.44 114.50 14.92 115.47 7.42 2.66 IFR 18 1408.78 20.79 6.80 98.30 1392.71 147.04 145.86 18.80 147.06 7.35 4.14 IFR 19 1505.23 20.65 6.91 96.45 1482.92 181.16 179.74 22.87 181.19 7.25 0.15 IFR 20 1592.72 21.97 6.93 87.49 1564.43 212.95 211.30 26.71 212.98 7.20 1.51 IFR 21 1686.87 26.47 7.84 94.15 1650.27 251.55 249.59 31.70 251.59 7.24 4.80 IFR ,--. 22 1781.35 27.67 8.12 94.48 1734.39 294.53 292.17 37.67 294.59 7.35 1.28 IFR 23 1878.57 26.14 7.72 97.22 1821.09 338.50 335.74 43.73 338.58 7.42 1.58 IFR 24 1971.07 27.31 6.82 92.50 1903.71 380.09 377.00 48.99 380.17 7.40 1.34 IFR 25 2068.98 32.55 8.69 97.91 1988.53 428.90 425.38 55.64 429.00 7.45 5.44 IFR 26 2164.83 37.11 7.99 95.85 2067.19 483.59 479.53 63.56 483.72 7.55 4.78 IFR 27 2258.56 39.15 9.13 93.73 2140.92 541.41 536.75 72.19 541.58 7.66 2.30 IFR 28 2350.54 43.91 7.98 91.98 2209.75 602.33 597.04 81.23 602.54 7.75 5.24 IFR 29 2444.25 49.01 6.34 93.71 2274.29 670.22 664.42 89.65 670.44 7.68 5.59 IFR 30 2538.01 53.26 5.54 93.76 2333.11 743.21 737.01 97.19 743.40 7.51 4.58 IFR ANADRILL SCHLUMBERGER Survey Report 7-Nov-200117:16:17 Page 3 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type ~~- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 31 2628.85 56.56 4.07 90.84 2385.32 817.50 811.07 103.39 817.64 7.26 3.87 IFR 32 2723.59 59.73 4.03 94.74 2435.32 897.90 891.33 109.08 897.98 6.98 3.35 IFR 33 2816.61 63.90 3.54 93.02 2479.24 979.80 973.12 114.48 979.84 6.71 4.51 IFR 34 2905.94 69.28 2.06 89.33 2514.72 1061.60 1054.97 118.46 1061.60 6.41 6.21 IFR 35 3003.97 73.59 2.24 98.03 2545.93 1154.27 1147.81 121.95 1154.27 6.06 4.40 IFR 36 3097.81 74.74 2.96 93.84 2571.53 1244.37 1238.00 126.05 1244.40 5.81 1.43 IFR - ~ 37 3192.44 73.86 3.64 94.63 2597.14 1335.35 1328.94 131.29 1335.41 5.64 1.16 IFR 38 3285.01 73.12 3.83 92.57 2623.45 1424.01 1417.51 137.07 1424.12 5.52 0.82 IFR 39 3379.14 74.07 4.38 94.13 2650.03 1514.25 1507.57 143.53 1514.39 5.44 1.15 IFR 40 3473.78 74.25 4.97 94.64 2675.86 1605.26 1598.32 150.96 1605.43 5.40 0.63 IFR 41 3565.82 74.99 4.43 92.04 2700.27 1693.97 1686.76 158.23 1694.17 5.36 0.98 IFR 42 3661.55 76.43 4.37 95.73 2723.90 1786.69 1779.25 165.34 1786.92 5.31 1.51 IFR 43 3755.83 75.46 4.25 94.28 2746.80 1878.10 1870.45 172.22 1878.36 5.26 1.04 IFR 44 3847.75 74.81 4.61 91.92 2770.38 1966.90 1959.03 179.08 1967.20 5.22 0.80 IFR 45 3939.81 75.82 4.78 92.06 2793.72 2055.92 2047.78 186.37 2056.24 5.20 1.11 IFR 46 4036.27 75.91 4.88 96.46 2817.27 2149.43 2140.99 194.24 2149.78 5.18 0.14 IFR 47 4129.73 76.02 5.18 93.46 2839.94 2240.08 2231.31 202.19 2240.45 5.18 0.33 IFR 48 4221.03 75.79 5.96 91.30 2862.17 2328.62 2319.44 210.79 2329.00 5.19 0.87 IFR 49 4314.39 75.46 6.17 93.36 2885.35 2419.06 2409.37 220.34 2419.43 5.23 0.42 IFR 50 4411.57 75.49 6.68 97.18 2909.73 2513.13 2502.85 230.87 2513.48 5.27 0.51 IFR 51 4504.70 75.61 6.90 93.13 2932.96 2603.31 2592.41 241.53 2603.63 5.32 0.26 IFR ,~ 52 4600.38 75.17 7.47 95.68 2957.10 2695.89 2684.26 253.11 2696.17 5.39 0.74 IFR 53 4691.85 74.40 7.44 91.47 2981.10 2784.13 2771.78 264.56 2784.38 5.45 0.84 IFR 54 4785.39 75.69 6.07 93.54 3005.24 2874.49 2861.52 275.19 2874.72 5.49 1.98 IFR 55 4878.95 76.25 7.03 93.56 3027.93 2965.26 2951.70 285.55 2965.48 5.53 1.16 IFR 56 4975.87 75.78 6.98 96.92 3051.35 3059.30 3045.04 297.01 3059.49 5.57 0.49 IFR 57 5069.96 75.11 7.96 94.09 3074.99 3150.34 3135.34 308.85 3150.51 5.63 1.23 IFR 58 5164.59 75.22 8.13 94.63 3099.22 3241.77 3225.91 321.66 3241.91 5.69 0.21 IFR 59 5257.59 75.70 8.32 93.00 3122.57 3331.74 3315.01 334.53 3331.84 5.76 0.55 IFR 60 5351.47 75.17 8.02 93.88 3146.18 3422.55 3404.95 347.45 3422.63 5.83 0.64 IFR f ANADRILL SCHLUMBERGER Survey Report 7-Nov-200117:16:17 Page 4 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 61 5441.90 74.57 8.41 90.43 3169.78 3509.79 3491.35 359.92 3509.85 5.89 0.78 IFR 62 5535.28 75.76 8.00 93.38 3193.69 3600.00 3580.69 372.80 3600.04 5.94 1.34 IFR 63 5631.45 75.99 8.25 96.17 3217.16 3693.21 3673.01 385.98 3693.24 6.00 0.35 IFR 64 5723.91 75.75 8.14 92.46 3239.73 3782.82 3761.76 398.76 3782.84 6.05 0.28 IFR 65 5818.88 75.96 8.56 94.97 3262.94 3874.85 3852.88 412.14 3874.86 6.11 0.48 IFR 66 5913.42 75.82 7.37 94.54 3285.99 3966.49 3943.68 424.84 3966.49 6.15 1.23 IFR - ~~~" 67 6007.07 75.55 7.56 93.65 3309.14 4057.21 4033.65 436.63 4057.21 6.18 0.35 IFR 68 6101.20 75.20 7.93 94.13 3332.91 4148.26 4123.90 448.90 4148.26 6.21 0.53 IFR 69 6194.32 75.05 6.16 93.12 3356.82 4238.24 4213.21 459.94 4238.24 6.23 1.84 IFR 70 6289.83 74.70 6.11 95.51 3381.74 4330.45 4304.89 469.80 4330.45 6.23 0.37 IFR 71 6384.27 74.37 6.12 94.44 3406.92 4421.47 4395.39 479.49 4421.47 6.23 0.35 IFR 72 6477.38 75.08 6.22 93.11 3431.45 4511.29 4484.69 489.15 4511.29 6.22 0.77 IFR 73 6572.92 75.88 6.29 95.54 3455.40 4603.77 4576.63 499.22 4603.77 6.23 0.84 IFR 74 6666.78 75.22 5.29 93.86 3478.83 4694.66 4667.05 508.39 4694.66 6.22 1.25 IFR 75 6762.21 75.13 5.68 95.43 3503.24 4786.91 4758.88 517.21 4786.91 6.20 0.41 IFR 76 6853.12 75.19 5.58 90.91 3526.53 4874.78 4846.34 525.83 4874.78 6.19 0.13 IFR 77 6949.41 75.11 6.35 96.29 3551.21 4967.85 4938.91 535.51 4967.85 6.19 0.78 IFR 78 7041.25 73.06 6.72 91.84 3576.39 5056.17 5026.65 545.55 5056.17 6.19 2.27 IFR 79 7136.94 73.81 5.57 95.69 3603.67 5147.88 5117.84 555.37 5147.88 6.19 1.39 IFR 80 7228.06 74.37 5.38 91.12 3628.65 5235.50 5205.07 563.73 5235.50 6.18 0.65 IFR ~ 81 7323.33 75.37 4.74 95.27 3653.52 5327.45 5296.67 571.84 5327.45 6.16 1.23 IFR 82 7416.94 75.49 4.63 93.61 3677.06 5418.02 5386.97 579.24 5418.02 6.14 0.17 IFR 83 7509.72 76.31 4.60 92.78 3699.67 5507.97 5476.66 586.48 5507.98 6.11 0.88 IFR 84 7603.66 76.46 4.67 93.94 3721.78 5599.23 5567.66 593.86 5599.25 6.09 0.18 IFR 85 7698.16 76.52 4.77 94.50 3743.86 5691.08 5659.24 601.42 5691.10 6.07 0.12 IFR 86 7791.73 75.82 4.97 93.57 3766.22 5781.92 5749.77 609.13 5781.94 6.05 0.78 IFR 87 7887.51 75.93 4.64 95.78 3789.60 5874.77 5842.32 616.91 5874.80 6.03 0.35 IFR 88 7982.69 75.90 4.21 95.18 3812.76 5967.04 5934.37 624.04 5967.09 6.00 0.44 IFR 89 8076.70 74.49 4.27 94.01 3836.78 6057.88 6025.01 630.76 6057.93 5.98 1.50 IFR 90 8168.39 75.79 4.11 91.69 3860.30 6146.44 6113.39 637.23 6146.51 5.95 1.43 IFR f - ANADRILL SCHLUMBERGER Survey Report 7-Nov-200117:16:17 Page 5 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azirn (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 91 8260.93 73.30 4.99 92.54 3884.96 6235.59 6202.29 644.30 6235.67 5.93 2.84 IFR 92 8354.50 73.21 6.16 93.57 3911.92 6325.19 6291.47 653.01 6325.27 5.93 1.20 IFR 93 8447.56 73.92 6.03 93.06 3938.24 6414.44 6380.22 662.48 6414.53 5.93 0.77 IFR 94 8542.56 74.99 6.27 95.00 3963.70 6505.97 6471.22 672.29 6506.05 5.93 1.15 IFR 95 8636.61 75.08 6.37 94.05 3987.99 6596.83 6561.53 682.29 6596.91 5.94 0.14 IFR 96 8731.41 75.17 6.06 94.80 4012.33 6688.45 6652.61 692.21 6688.53 5.94 0.33 IFR - ~".~ 97 8825.00 75.38 7.23 93.59 4036.12 6778.96 6742.52 702.68 6779.04 5.95 1.23 IFR 98 8917.44 75.58 7.46 92.44 4059.29 6868.43 6831.27 714.12 6868.50 5.97 0.32 IFR 99 9011.10 75.46 7.90 93.66 4082.71 6959.09 6921.14 726.24 6959.14 5.99 0.47 IFR 100 9104.54 74.87 8.15 93.44 4106.64 7049.37 7010.58 738.85 7049.41 6.02 0.68 IFR 101 9199.43 73.96 7.87 94.89 4132.13 7140.72 7101.09 751.59 7140.76 6.04 1.00 IFR 102 9294.12 73.66 8.42 94.69 4158.53 7231.60 7191.11 764.47 7231.63 6.07 0.64 IFR 103 9387.88 73.60 8.23 93.76 4184.96 7321.50 7280.12 777.50 7321.52 6.10 0.20 IFR 104 9482.12 73.10 8.39 94.24 4211.96 7411.73 7369.46 790.55 7411.74 6.12 0.55 IFR 105 9576.43 74.02 8.77 94.31 4238.65 7502.11 7458.90 804.04 7502.11 6.15 1.05 IFR 106 9672.86 73.25 8.89 96.43 4265.82 7594.54 7550.33 818.24 7594.54 6.19 0.81 IFR 107 9766.15 73.30 8.39 93.29 4292.67 7683.80 7638.66 831.67 7683.80 6.21 0.52 IFR 108 9861.69 74.49 8.71 95.54 4319.17 7775.51 7729.43 845.31 7775.51 6.24 1.29 IFR 109 9957.14 73.92 7.74 95.45 4345.15 7867.30 7820.33 858.45 7867.30 6.26 1.15 IFR 110 10049.66 74.52 7.74 92.52 4370.31 7956.30 7908.55 870.44 7956.31 6.28 0.65 IFR 111 10142.63 73.63 8.04 92.97 4395.82 8045.66 7997.10 882.72 8045.67 6.30 1.01 IFR ,-- 112 10238.15 72.89 8.02 95.52 4423.33 8137.09 8087.68 895.49 8137.10 6.32 0.77 IFR 113 10295.52 72.91 7.70 57.37 4440.20 8191.90 8142.00 902.99 8191.92 6.33 0.53 MWD M 114 10453.88 72.46 7.56 158.36 4487.33 8343.04 8291.84 923.07 8343.06 6.35 0.30 IFR 115 10548.63 72.55 7.10 94.75 4515.81 8433.39 8381.47 934.60 8433.41 6.36 0.47 IFR 116 10640.70 72.77 7.31 92.07 4543.26 8521.26 8468.66 945.62 8521.29 6.37 0.32 IFR 117 10733.00 72.96 6.19 92.30 4570.45 8609.46 8556.25 955.98 8609.49 6.38 1.18 IFR 118 10828.62 73.39 5.84 95.62 4598.13 8700.98 8647.27 965.58 8701.01 6.37 0.57 IFR 119 10922.11 73.47 6.19 93.49 4624.79 8790.59 8736.39 974.97 8790.62 6.37 0.37 IFR 120 11016.09 73.50 5.30 93.98 4651.51 8880.69 8826.04 983.98 8880.72 6.36 0.91 IFR ANADRILL SCHLUMBERGER Survey Report 7-Nov-200117:16:17 Page 6 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -~~ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 121 11108.08 73.53 5.64 91.99 4677.61 8968.89 8913.84 992.39 8968.91 6.35 0.36 IFR 122 11201.86 73.30 5.12 93.78 4704.38 9058.76 9003.32 1000.82 9058.78 6.34 0.59 IFR 123 11297.96 72.87 5.16 96.10 4732.34 9150.68 9094.90 1009.06 9150.70 6.33 0.45 IFR 124 11390.85 73.26 5.24 92.89 4759.40 9239.53 9183.39 1017.11 9239.55 6.32 0.43 IFR 125 11483.66 73.49 5.33 92.81 4785.95 9328.45 9271.95 1025.30 9328.46 6.31 0.26 IFR 126 11575.20 73.89 5.41 91.54 4811.66 9416.30 9359.42 1033.52 9416.31 6.30 0.44 IFR - -~ 127 11669.58 74.21 5.73 94.38 4837.59 9507.04 9449.73 1042.33 9507.05 6.29 0.47 IFR 128 11761.76 74.65 5.81 92.18 4862.33 9595.83 9538.08 1051.26 9595.84 6.29 0.48 IFR 129 11857.03 75.24 6.09 95.27 4887.08 9687.83 9629.58 1060.80 9687.84 6.29 0.68 IFR 130 11954.33 75.75 6.33 97.30 4911.45 9782.03 9723.23 1070.99 9782.04 6.29 0.58 IFR 131 12045.64 76.19 6.49 91.31 4933.59 9870.61 9811.26 1080.88 9870.62 6.29 0.51 IFR 132 12137.82 75.51 6.47 92.18 4956.12 9960.00 9900.07 1090.96 9960.00 6.29 0.74 IFR 133 12232.38 75.14 6.16 94.56 4980.08 10051.47 9990.99 1101.03 10051.48 6.29 0.50 IFR 134 12326.01 75.01 6.10 93.63 5004.19 10141.94 10080.95 1110.69 10141.95 6.29 0.15 IFR 135 12420.27 75.02 5.71 94.26 5028.56 10232.99 10171.52 1120.06 10233.00 6.28 0.40 IFR 136 12515.86 74.98 5.14 95.59 5053.31 10325.32 10263.44 1128.78 10325.32 6.28 0.58 IFR 137 12607.07 74.83 5.24 91.21 5077.06 10413.37 10351.14 1136.75 10413.37 6.27 0.20 IFR 138 12702.87 74.71 5.02 95.80 5102.22 10505.79 10443.20 1145.02 10505.79 6.26 0.25 IFR 139 12797.08 74.62 4.70 94.21 5127.14 10596.62 10533.73 1152.71 10596.62 6.25 0.34 IFR 140 12891.96 74.56 4.74 94.88 5152.35 10688.05 10624.89 1160.24 10688.05 6.23 0.08 IFR ~ 141 12983.03 75.13 4.12 91.07 5176.16 10775.91 10712.53 1167.03 10775.91 6.22 0.91 IFR 142 13078.89 75.77 4.30 95.86 5200.24 10868.64 10805.07 1173.84 10868.64 6.20 0.69 IFR 143 13172.52 76.33 4.05 93.63 5222.81 10959.45 10895.69 1180.46 10959.45 6.18 0.65 IFR 144 13267.63 76.46 3.98 95.11 5245.19 11051.82 10987.91 1186.93 11051.83 6.17 0.15 IFR 145 13361.50 76.48 4.23 93.87 5267.15 11143.03 11078.94 1193.46 11143.03 6.15 0.26 IFR 146 13455.99 76.49 4.11 94.49 5289.23 11234.84 11170.57 1200.14 11234.85 6.13 0.12 IFR 147 13549.78 76.60 3.78 93.79 5311.05 11325.98 11261.57 1206.42 11326.00 6.11 0.36 IFR 148 13641.67 76.66 3.89 91.89 5332.30 11415.31 11350.77 1212.40 11415.33 6.10 0.13 IFR 149 13733.26 76.72 3.57 91.59 5353.39 11504.35 11439.71 1218.20 11504.39 6.08 0.35 IFR 150 13827.27 76.54 4.23 94.01 5375.13 11595.74 11530.96 1224.42 11595.78 6.06 0.71 IFR ."" ANADRILL SCHLUMBERGER Survey Report 7-Nov-200117:16:17 Page 7 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azirn (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --""'" -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 151 13922.96 76.25 4.63 95.69 5397.64 11688.70 11623.68 1231.60 11688.75 6.05 0.51 IFR 152 14015.16 75.87 5.02 92.20 5419.85 11778.15 11712.85 1239.13 11778.21 6.04 0.58 IFR 153 14110.42 75.68 5.20 95.26 5443.25 11870.48 11804.82 1247.35 11870.54 6.03 0.27 IFR 154 14204.98 75.69 5.51 94.56 5466.64 11962.09 11896.05 1255.90 11962.16 6.03 0.32 IFR 155 14298.11 76.37 6.02 93.13 5489.12 12052.46 11985.96 1264.98 12052.53 6.02 0.90 IFR 156 14392.72 76.68 5.37 94.61 5511.16 12144.46 12077.51 1274.11 12144.53 6.02 0.74 IFR -" 157 14485.79 77.57 6.21 93.07 5531.90 12235.19 12167.78 1283.26 12235.26 6.02 1.30 IFR 158 14581.60 77.07 5.53 95.81 5552.93 12328.66 12260.76 1292.82 12328.73 6.02 0.87 IFR 159 14674.22 76.57 5.88 92.62 5574.05 12418.83 12350.49 1301.79 12418.91 6.02 0.65 IFR 160 14772.75 76.06 5.82 98.53 5597.36 12514.56 12445.73 1311.55 12514.64 6.02 0.52 IFR 161 14866.85 75.44 6.52 94.10 5620.53 12605.77 12536.40 1321.35 12605.85 6.02 0.98 IFR 162 14959.33 74.94 5.95 92.48 5644.17 12695.17 12625.28 1331.06 12695.25 6.02 0.80 IFR 163 15053.70 74.52 7.10 94.37 5669.02 12786.21 12715.73 1341.40 12786.29 6.02 1.26 IFR 164 15146.86 74.02 7.14 93.16 5694.28 12875.87 12804.71 1352.52 12875.94 6.03 0.54 IFR 165 15240.50 73.57 7.42 93.64 5720.41 12965.77 12893.90 1363.91 12965.84 6.04 0.56 IFR 166 15332.38 73.25 7.55 91.88 5746.64 13053.81 12981.21 1375.38 13053.87 6.05 0.37 IFR 167 15428.63 72.50 7.74 96.25 5774.98 13145.76 13072.37 1387.62 13145.81 6.06 0.80 IFR 168 15520.24 72.19 8.09 91.61 5802.77 13233.02 13158.84 1399.64 13233.06 6.07 0.50 IFR 169 15612.88 72.14 7.66 92.64 5831.14 13321.17 13246.19 1411.72 13321.21 6.08 0.45 IFR 170 15707.52 72.28 8.06 94.64 5860.06 13411.25 13335.46 1424.05 13411.28 6.10 0.43 IFR '-4- 171 15802.62 72.43 8.42 95.10 5888.88 13501.82 13425.15 1437.03 13501.84 6.11 0.39 IFR 172 15895.67 72.01 7.90 93.05 5917.30 13590.37 13512.86 1449.61 13590.39 6.12 0.70 IFR 173 15990.60 72.16 8.44 94.93 5946.50 13680.64 13602.27 1462.45 13680.66 6.14 0.56 IFR 174 16086.05 71.26 8.55 95.45 5976.45 13771.20 13691.90 1475.83 13771.21 6.15 0.95 IFR 175 16178.58 68.86 8.60 92.53 6008.01 13858.10 13777.91 1488.80 13858.11 6.17 2.59 IFR 176 16273.89 66.64 8.72 95.31 6044.09 13946.23 13865.11 1502.08 13946.23 6.18 2.33 IFR 177 16366.75 64.35 6.92 92.86 6082.61 14030.68 13948.81 1513.59 14030.69 6.19 3.03 IFR 178 16460.24 61.96 5.59 93.49 6124.83 14114.09 14031.71 1522.69 14114.09 6.19 2.85 IFR 179 16553.66 59.40 3.23 93.42 6170.57 14195.49 14112.91 1528.97 14195.49 6.18 3.52 IFR 180 16645.58 57.02 1.08 91.92 6219.00 14273.41 14190.97 1531.93 14273.42 6.16 3.26 IFR ANADRILL SCHLUMBERGER Survey Report 7-Nov-200117:16:17 Page 8 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) ( deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 181 16740.66 54.45 2.78 95.08 6272.53 14351.75 14269.49 1534.56 14351.77 6.14 3.08 IFR 182 16834.67 51.89 4.85 94.01 6328.88 14426.92 14344.56 1539.54 14426.94 6.13 3.24 IFR 183 16928.66 49.49 6.18 93.99 6388.42 14499.63 14416.94 1546.51 14499.65 6.12 2.78 IFR 184 17023.55 46.57 7.92 94.89 6451.88 14570.16 14486.95 1555.15 14570.18 6.13 3.37 IFR 185 17115.32 43.89 8.64 91.77 6516.50 14635.26 14551.42 1564.52 14635.28 6.14 2.97 IFR 186 17210.93 40.88 9.29 95.61 6587.11 14699.63 14615.07 1574.55 14699.64 6.15 3.18 IFR - -" 187 17304.66 38.10 9.01 93.73 6659.44 14759.16 14673.91 1584.03 14759.16 6.16 2.97 IFR 188 17399.54 35.04 8.25 94.88 6735.63 14815.63 14729.79 1592.53 14815.63 6.17 3.26 IFR 189 17492.41 32.04 5.92 92.87 6813.03 14866.92 14780.70 1598.89 14866.92 6.17 3.51 IFR 190 17587.06 28.80 3.50 94.65 6894.65 14914.81 14828.44 1602.88 14914.82 6.17 3.66 IFR 191 17682.20 25.30 0.91 95.14 6979.37 14957.96 14871.66 1604.60 14957.97 6.16 3.88 IFR 192 17774.02 22.19 0.79 91.82 7063.40 14994.77 14908.62 1605.15 14994.78 6.15 3.39 IFR 193 17867.68 18.78 1.71 93.66 7151.13 15027.42 14941.38 1605.84 15027.43 6.13 3.66 IFR 194 17964.60 16.71 2.63 96.92 7243.43 15056.88 14970.90 1606.95 15056.90 6.13 2.16 IFR 195 18059.00 14.88 2.39 94.40 7334.27 15082.52 14996.57 1608.08 15082.54 6.12 1.94 IFR 196 18152.09 15.89 0.29 93.09 7424.02 15107.12 15021.26 1608.64 15107.15 6.11 1.24 IFR 197 18248.88 15.76 2.60 96.79 7517.14 15133.42 15047.64 1609.30 15133.45 6.10 0.66 IFR 198 18342.67 15.20 3.74 93.79 7607.53 15158.42 15072.63 1610.68 15158.45 6.10 0.68 IFR 199 18434.55 13.55 4.45 91.88 7696.53 15181.21 15095.38 1612.31 15181.24 6.10 1.81 IFR 200 18531.63 12.67 5.67 97.08 7791.08 15203.22 15117.32 1614.24 15203.26 6.09 0.95 IFR Projected To TD of 18595.00 ft: ~-,~o 201 18595.00 12.10 6.50 63.37 7852.97 15216.81 15130.83 1615.68 15216.85 6.09 0.94 MWD M [(c)2001 Anadrill IDEAL ID6_1C_10] Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No MPF-94 Date Dispatche 27-Nov-O1 Installation/Rig Nabors 27E Dispatched By: Nate Rose " t MWD/LWD Log, Product Delivery (' Data No Of Prints No of Floppies Surveys dOJ-}lo 2 Received By: c7§. ~ I JJ 00 pt'o 1 1 RECE t\JED DEC 0 ~. 2001 Ai ~ska Oil & Gas ens. Commì55iŒl AncÞ~o age Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E, Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564~005 e-mail address: johnsojh@bp.com LWD Log Delivery V1.2, Dec 2001 (' ~~~~Œ ffi)~ ~~~~[{~ AlAS KA. 0 IL AND GAS CONSERVATI ON COMMISSION October 12, 2001 Mr. Steve Shultz Sr. Drilling Engineer BP Exploration (Alaska) Inc. Alaska Drilling and Wells PO Box 196612 ~chorage,AJ( 99519 Re: Request for Waiver of Diverter Requirements at 20 AAC 25.035 (c) Milne Point Unit F-94.. }~ll)\t~~\jM~O":."(' Dear Mr. Shultz: l \ TONY KNOWLES, GOVERNOR 333 w. ]TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 We have received your request for exception to the Diverter requirements at 20 AAC 25.035 (c) for Milne Point F-94. In support of this request, mud weight information gathered while drilling 3 wells (F-81, F-82, and F-83i) in 2000 and your most recent well F-86 was submitted. You further state and our Sr. Engineer confirms through personal experience that no pressure incidents, hydrates or shallow gas have been encountered in wells drilled in late 1998 at F pad. The majority of wells on F Pad are completed in Kuparuk River formation with a few wells completed in the Sag River. There are no Schrader Bluff wells. The ,Commission agrees that the available information does not reveal any existing problems with pressure, hydrates or shallow gas on F Pad. However, we believe it is inappropriate to grant a blanket waiver of the diverter system requirement for an indefinite number of wells. The Commission does have concerns with the potential development of subsurface problems due to ongoing enhanced recovery activities on F pad. F pad presently has upwards of 48 wells. The 31 production wells are produced using ESPs. There are 17 injectors on the pad with 6 of those potentially injecting MI. One water injector, F-83i, has a tubing leak. Continued injection into that well has authorized with daily monitoring of the injection rates and pressures by Milne Point operations. Casing integrity has been demonstrated. ( Request for Waiver of Diverter Kequirements at 20 AAC 25.035 (c) Milne Point Unit F-94...201-170 October 12, 2001 Page 2 of2 ( Regardless of the past drilling history in the F Pad area, the operator must be prepared to accommodate drilling hazards that may develop over time. Each well should be carefully monitored to detect any developing drilling hazards, and subsequent operations conducted accordingly. Dialogue with Milne Point operations should be ongoing so that any changes in injection well performance are highlighted. The Commission, therefore, will consider waiver of the diverter system requirement on a case-by-case basis for F Pad wells with surface casing set through the Schrader Bluff. Requests for this waiver may be included in the application for Permit to Drill (Form 10- 401) and should include an on-going assessment of shallow hazards based on all information available at the time the permit is submitted. Your request to waiver of the diverter requirements for MP F-94 (201-170) is approved. Sincerely, cÞ~~¡vk ~ Camille chsli Taylor Chair ", ( { ~. To: Conunissioner, AOGCC Date: October 1,2001 From: Steve Shultz Subject: . Dis ensation for 20 AAC 25.035 c on Milne Point F -94 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 MC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale of the request. To date, the most recent Kuparuk well (F -86) drilled In July and August, experienced no pressure control or shallow gas problems above or in the Schrader Bluff formation. This well never exceeded a 9.7 ppg mud weight, which was only needed for formation integrity and not pressure control. Also, this area has not exhibited any problems with hydrates. Therefore, we would like to request a waiver for F -94 to omit the diverter system helping us to drill this well in a more efficient manner. Presently we are drilling L-35A, our first ERD well. We should be finished by the middle of next week and moving to F-94 by the end of the week. Your consideration of this waiver is appreciated. Sincerely, Steve Shultz ADW Senior Drilling 564..5491 c 0 ro t-- -<:r Phoenix #1 -<:r Mukluk #1 --_--___---L-- ~ ' \' Sandpiper ~1 -<:r .: FREE GAS -.-----..-...-..--- Cress Islan ~1 ~ - --- ----'---~--- \ l 'T-------' \ \ --\-.-----.-..----.- ----------. ~,:.,' \ I, \ \ I .. ~ \ \ ~ i C-,,\, -----.-..----.... ..~---\""'~" .. ..- ----1 Narvaq #1 \ -<:r Wolfbutton # 32-7-8 1- ~.,_........_-- ( ~1f~1fŒ (ID~ ~~~~~~ ( ALAS KA 0 IL AND GAS CONSERVATI ON COMMISSION l I I / / I / / TONY KNOWLES, GOVERNOR 333 w. -¡n< AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James Franks Sr. Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit JvIPF-94 BP Exploration (Alaska), Inc. Permit No: 201-170 Sur Loc: 2284' NSL, 2801' WEL, SEC. 06, TI3N, RI0E, UM Btmhole Loc. 1617' NSL, 1103, WEL, SEC. 19, TI4N, RI0E, UM Dear Mr. Franks: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pernlitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for MPF -94. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. amel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION . DATED this 22od day of August, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work !HI Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2284' NSL, 2801' WEL, SEC. 06, T13N, R10E, UM At top of productive interval 1553' NSL, 1110' WEL, SEC. 19, T14N, R10E, UM At total depth 1617' NSL, 1103' WEL, SEC. 19, T14N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 355018, 1617' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' Maximum Hole Angle 18. CaSi~i?Z:rogram Specifications Hole Casino Weiaht Grade Couolina 30" 20" 94# K-55 Welded 13-1/2" 10-3/4" 45.5# L-80 BTC 9-7/8" 7-5/8" 29.7# L-80 BTC 6-3/4" 4-1/2" 12.6# L-80 BTC 1 b. Type of well Lenath 80' 10172' 18281' 565' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Casing Structural Conductor Surface 1 ntermediate Production Liner Length Size Perforation depth: measured true vertical ~fo 0 Exploratory 0 Stratigraphic Test !HI Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 44' Milne Point Unit / Kuparuk 6. Property Designation River Sands ADL 355016 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-94 9. Approximate spud date 09/15/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 5071 18715' MD / 7864' TVD 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} 0 75.4 Maximum surface 3288 psig, At total depth (TVD) 7500' I 4150 psig Setting Depth TI 10 Bottom MD TVD MD TVD 30' 30' 11 0' 11 0' 30' 30' 10202' 4429' 30' 30' 18311' 7474' 18150' 7317' 18715' 7863' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 .- of l t linclude staae data) 260 sx Arctic Set (Approx.) 1308 sx PF 'L', 122 sx PF 'C', 830 sx 'G' 261 sx Class 'G' 112 sx Class 'GI Plugs (measured) Junk (measured) Cemented MD TVD RECEIVED AUG 1 3 2001 Alaska Oil & Gas Cons. Commission Anchorage !HI Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch !HI Drilling Program !HI Drilling FluiçJ Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: James Franks, 564-4468 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the foregoing .is. tI e an. d co~rjct to the best of my knowledge Signed Brian Robertson .4 I ~'1l'TJ,~'\/ Title Senior Drilling Engineer Date '8/12-) v i " . '.. ';,'::,):,;:<:, ," ::" "":': ,,:~':!'::::::';/::>::':::::'Co~:mi:.~i:ø~:~~~:,iØrilj::'::'::.:';:':'::'.:,:::: ::;:",i,;:,';:",:,'/-; "," ': "",: '<~': '; ":', ,: , P~~ ~~'7 0 ::1 ~~7 - 2- 3 ð ~ C5 qAII~o~ rJ 1 ~~:~ho:re;~~~ti~~ments Conditions of Approval: Samples Required 0 Yes ..s No Mud Log Requiretj 0 Yes E No Hydrogen Sulfide Measures 0 Yes ...8 No Directional Survey Required ;g¡ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K ~.5K psi ~ Other: ':)~/~~N~l SIGNED BY by order of r4 y Or SeamQu f Commissioner the commission Date '- () ~,' D l. 0 R I (j , 1\ A ,"" Sut mit In Triplicate 20. Attachments Acoroved Bv Form 10-401 Rev. 12-01-85 ( ( MPF-94 Drillin9 Permit 1. Well Plan Summar'l IWeli Name: I MPF-94 lliPe of Well (producer or injector): l.!S!Paruk Grassroots Producer Surface Location: 2284IFSL,2801IFEL,SEC.6,T13N,R10E X = 541759.11 Y = 6035735.77 F-94 Target: 1553IFSL,1110IFEL,SEC.19,T14N,R10E X = 543305 Y = 6050852 Z = 7624 TVD F-94 Target (Bottom Hole 1617IFSL,1103IFEL,SEC.19,T14N,R10E Location): X = 543311.54 Y = 6050915.94 Z = 7864' TVD ~ Nabors 27E I I Estimated Start Date: KOP: ~tember 15, 2001 I 300' KBE: I I 30 I 75.4 0 I I I 44' lQperatin9 days to complete: I MDrkb I 18715' I I TVDrkb (TD) I 7864' I Max. Inc. I I Well DesiQ!!jconventional, slim hole, etc.)j Grassroots Slim hole Producer I Drill and Complete a Slim hole Producer in the Kuparuk sands. ~e: Version #1, 6/20/2001 ( (' MPF-94 Drillin9 Permit 2. Current Well Information 2.1. General Well Name: MPF-94 API Number: Well Type: Current Status: BHP: BHT: MPF-94 Development - Kuparuk Grassroots Producer Conductor Set 4150 psi @ 7500' TVDss Kuparuk C sands. 170°F @ 7000' TVDss Estimated (SOA) 2.2. Current Mechanical Condition MPF-94: Nabors 27E: Conductor: 2.3. Target Estimates Cellar Box above MSL = 11.0 KB from Ground Level = 33' 20", 92 I bItt, H-40 Welded set at 80' MD Estimated Reserves: 1.86MMBBL Expected Initial Rate: 2300 BOPD Expected 6 month avg: 1800 BOPD 2 ( t MPF-94 Drilline Permit 3. Drillinq Hazards and Continqencies Drill D1 D2 D3 D4 D5 3.2. Kick Tolerance t..._~' \ \... - \ ~ ,",SIt" \ ~ 0.. 'o~\",)~ ""t ~ ~ ~C'c:.. 3.2.1.The~casing will be cemented to~ The top of the 15.8lb/gal tail cement slurry is planned to be 500' MD above the NA Sands -8776' MD 3.2.2.The surface hole will be drilled on diverter. 3.2.3.The Kick Tolerance for the surface casing is 165 bbls with 9.5 ppg mud. 3.2.4.The Kick Tolerance for the intermediate casing based on the 4150 expected pore pressure is infinite. 3.3. Integrity Testing Test Point 10-3/4" shoe 7 -518" shoe Test De th 20' minimum from 10-3/4" shoe 20' minimum from the 7-5/8" shoe Test t e FIT FIT EMW 11.0 13.0 - minimum - minimum 3.4. Lost Circulation 3.4.1.There is a potential for losses while drilling through the HRl and Kalubik shale due to the faulted structure in the shale. Most lost circulation events at 'F' pad have been related to breathing and lifting cement behind production casing. 3.4.2. Breathing is well documented at Milne Point between the Schrader Bluff and the HRl when ECD's reach 11.5 ppg. If well bore breathing occurs on MPF-94, the ADW RP "Well Bore Breathing" will be followed. As stated in that RP, it is ADW policy that any flow from the well will be treated as a well control problem until a definitive well bore breathing diagnosis is made 3.4.3. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.5. Casing Setting Depth 3.5.1. Due to the abnormal pressure in the Kuparuk interval, it is extremely important that we set the intermediate casing string in the D shale above the Kuparuk producing sands. We will have Geologists on hand to pick the casing point. 3 (' ( M PF-94 Drillin9 Permit 3.6. Abnormal Pressures 3.6.1. Due to the use of injection to enhance oil recovery in the zone, an abnormal pressure gradient is expected while drilling the production hole section. It is because of the higher formation pressures in the Kuparuk that we are top-setting 7-5/8" casing in the D-shale prior to drilling through the productive interval. 3.7. Stuck Pipe 3.7.1.Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.7.2.Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.8. Pad Data Sheet 3.8.1. Please Read the F-Pad Data Sheet thoroughly. 3.9. Hydrocarbons 3.9.1. Hydrocarbons will be encountered in the Schrader Bluff and Kuparuk intervals. 3.10. Faults 3.10.1. Faults are not expected in the drilling of this well. There is a poor seismic area to the north of the target zone that could be faulted. Adhering to the directional profile mitigates the problems in this area. 3.11. Hydrogen Sulfide 3.11.1. MPF Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Well F- Location Well Type H2S Status Date taken 66A Surface Producer <2.00 Feb 2001 54 Surface Producer <2.00 Feb 2001 34 BHL Producer <2.00 Feb 2001 17 BHL Producer 2.18 Feb 2001 69 Max recorded Producer 23.5 Feb 2001 4 ( ( MPF-94 Drillin9 Permit Drillin~ Pro~ram Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells are required to be shut in prior to moving onto F-94 Close Approach Wells: There are no close approach wells Close Tolerance Wells: There is one close tolerance well- MPF-58 @ 1455' MO Well Name Current Production Precautions Status Priority MPF-58 Producer N/A Run Gyro during drilling- of Surface hole 4.2. Well Control Ex ected BHP 4150 psi @ 7500' TVDss estimated Max Ex BOPE Ratin 135/8" 5M Planned BOPE Test Pres. Rams & Valves: 3500 psi/250 psi Annular: 2500 si I 250 si 4.3. Mud Program 13-1/2" Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density I~~~\ Funnel visc YP HTHP pH API Filtrate LG Solids 8.6- 9.2 100 -150 25 - 60 N/A 9.0- 9.5 <8 < 6.5 9-7/8" Intermediate Hole Mud Properties: LSND Freshwater Mud Density /. .\ Funnel visc YP HTHP pH API Filtrate LG Solids 9.5 -10.5 40 - 55 12 - 20 10-12 8.5- 9.0 <10 < 6.5 6-1/8" Production Hole Mud Properties: LSND Freshwater Mud Density I~~~\ Funnel visc YP HTHP pH API Filtrate LG Solids 10.8 - 11.2 35 - 45 12-18 10-12 8.0- 8.5 <10 < 6.5 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to OS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 4.4. Formation Markers Formation Tops 1t MD 1t TVDss Base Permafrost 1850 1809 SBF2-NA 8775 4069 SBA5 {base OB} 10143 4414 TKUD 18311 7474 TKUC 18414 7574 TKUA 18466 7624 TKA3 18466 7624 TKA2 18481 7638 TKA1 18497 7654 TMLV 18565 7718 TD 18715 7864 5 ( ( MPF-94 Drillin9 Permit 4.5. CasingITubing Program Hole Size Csgl WtlFt Grade Conn Length Top Bottom Tbg O.D. M D I TVDrkb M D I TVDrkb 30" 20" 94# K-55 Welded 80' 30' I 30' 110' / 110' 13-1 12" 10-3/4" 45.5# L-80 BTC 10172' 30' 1 30' 1 0202' / 4429' 9-7/8" 7-5/8" 29.7# L-80 BTC 18281 ' 30' I 30' 18311' /7474' 6-3/4" 4-1 12" 12.6# L-80 BTC 565' 18150' 17317' 18715' /7863' Tubing 4-1/2" 12.6# L-80 NSCT 18120' 30' I 30' 18150' / 7317' 4.6. Cement Calculations Casing Size 110-3/4" 45.5 Ibltt L-80 BTC - Two Stage Basisl250% excess over gauge hole in permafrost interval, 30% excess over gauge hole below permafrost A Stage Tool will be placed below base of the permafrost -2000' MD. Total Cement Volume: 1 5t Stage Wash 20 bbl Freshwater Spacer 75 bbl of Viscosified Spacer weiahted to 10.20 ppq Lead 438 bbl1 0.7 Ib/gal Permafrost L cement - 4.15 cuft/sk Tail 20 bb115.7 Ib/qal Permafrost C cement - 0.92 cuft/sk 2na Stage Wash 20 bbl Freshwater Spacer 75 bbl of Viscosified Spacer weiahted to 10.20 ppg Lead 529 bbl10.7lb/aal Permafrost L cement - 4.15 cuft/sk Tail 170 bbl 15.8 Ib/aal Class G + adds - 1.15 cuft/sk Temp BHST ~ 80° F from SaR, BHCT 65° F Casing Size 17-5/8" 29.7 Ibltt L-80 BTC Basisl 30% excess over gauge hole - 1000' MD Total Cement Volume: Wash 20 bbl Freshwater Space r 50 bbl of Viscosified Spacer weiahted to 11.0 ppg Tail 54 bb115.8 Ib/aal Class G + adds - 1.16 cuft/sk Temp BHST ~ 170° F from SaR, BHCT 120-130° F Casing Size 14-1/2" 12.6 Ib/ft L-80 BTC Basisl 30% excess over gauge hole Total Cement Volume: Wash 20 bbl Freshwater Spacer 25 bbl of Viscosified Spacer weiahted to 11.5 ppg Tail 24 bb115.6 Ib/aal Class G + latex and adds - 1.20 cuft/sk Temp BHST == 170° F from SaR, BHCT 120-130° F 6 ( ( MPF-94 Drillin9 Permit 4.7. Survey and Logging Program 13-1/2" Hole Section: Open Hole: MWD / DIR / GR 9-7/8" Hole Section: Open Hole: MWD / DIR / GR / Res Res placed as close to bit as possible. Cased Hole: None 6-3/4" Hole Section: Open Hole: MWD / DIR / GR / Res / Den-Neu / RFT RFT Drill pipe conveyed in all 4 sands. 7 ( (" MPF-94 Drillinø Permit MPF-94 Operations Summar'l 5.1. Pre-Rig Operations 1. 2. Grade and level pad. Install 20" Conductor. 5.2. Procedure 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. ~\ U,.o(,~17. ~~ 18. ~Oo>~\\o \ E:. 19. 20. 21. 22. 23. 24. 25. MIRU 27E. NU the 21-1/4" Diverter, pick up 5" DP. MU 13-1/2" BHA, spud in drill to planned surface hole TD (-10,2021 md). POH, LD BHA. Run 10-3/4",45.5#, L-80, BTC casing and cement to surface in two stages. ND diverter, NU Big Bore wellhead system & 13-5/8" BOP, test. MU 9-7/8" BHA (dumb iron), drill stage collar, circulate and condition mud, POH with BHA, LD same.. PU 9-7/8" Powerdrive Rotary Steerable assembly, RIH, drill out shoe track. Drill 20-301 of new formation, and perform LOT Drill to planned intermediate hole TD (-18,3001 md). Run 7-5/8",29.7#, L-80, BTC casing and cement to 1,000' above the shoe. Freeze protect 10-3/4" X 7-5/8" annulus. LD 5" DP, PU 4" DP. MU 6-3/4" BHA, drill float equipment, swap out mud, circulate and condition. Drill 20-30' of new formation, perform LOT Drill to planned production hole TD (-18,7151 md). POH, standing back DP, LD BHA. Run 4-1/2" liner to TD, cement, circulate and condition cement contaminated mud Displace to brine POH, LD DP and liner running tool. Run 4-1/2" 12.6#, L-80 frac string to 18,000' with chemical cut permanent packer and sliding sleeve. Land tubing hanger, set packer, shear out RP shear valve in lower GLM. Set TWC, test. ND BOP, NU tree, test to 5,000 psi. Remove TWC, freeze protect, install BPV. RD, move off well. 5.3. Post Rig Operations 1. 2. 3. 4. 5. 6. 7. 8. MIRU E-Line and or Coil Tubing Pull RP shear valve in the GLM RIH retrieve RHC plug and ball RIH perforate the well. Frac the well RIH and remove frac sleeve guard on CMU Sliding Sleeve RIH and set jet pump across sliding sleeve RD/Move off Mike Aivano/Pat Collins on 564-5943/564-4363 will write the Post Rig program for the POT team. 8 ,i '. 5.4. MPF-94 Completion Operations Summary 1. 2. 3. 4. 5. 6. 7. 8. 9. MIRU Nabors 4ES Kill well with brine NO Tree/NU BOP, test Cut and pull 4-1/2" tubing above the packer Run ESP completion on 2-7/811 tubing to 18,000' MO. land tubing, set TWC NO BOP/NU Tree and test Freeze protect Release Rig 9 (I ,I \ MPF-94 DrillinQ Permit Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DOlI ERD ratio: Grid Coordinate System: Location LaULong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: KBE KOP 1/100 0.00 300.00 400.00 500.00 600.00 MPF-94 (P4) report.xls MPF-94 Schlumberger Proposed Well Profile - Geodetic Report April 27, 2001 AI~ska Drilling & Wells Milne Point Unit MPF / MPF-94 MPF-94 MPF-94 feasibility study nly Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Grid Coordinates Station ID MD Incl TVD VSec NI.S EI.W DLS Northing Easting (ft) (O) (ft) (ft) (ft) (ft) (O/100ft) (ftUS ftUS 0.00 0.00 0.00 0.00 0.00 0.00 0.87 0.87 0.09 3.49 3.47 0.37 7.85 7.81 0.84 Bid 1.5/100 700.00 4.00 6.16 699.68 13.96 13.88 1.50 1.00 6035749.66 541760.53 N 70.50858709 W 149.65831191 800.00 5.50 6.16 799.33 22.24 22.11 2.39 1.50 6035757.89 541761.38 N 70.50860957 W 149.65830463 ,-. 900.00 7.00 6.16 898.73 33.12 32.93 3.55 1.50 6035768.72 541762.47 N 70.50863913 W 149.65829514 1000.00 8.50 6.16 997.82 46.61 46.34 5.00 1.50 6035782.13 541763.85 N 70.50867576 W 149.65828328 Bid 2/100 1100.00 10.00 6.16 1096.51 62.68 62.32 6.73 1.50 6035798.12 541765.49 N 70.50871942 W 149.65826912 1200.00 12.00 6.16 1194.67 81.76 81.29 8.77 2.00 6035817.10 541767.42 N 70.50877124 W 149.65825243 1300.00 14.00 6.16 1292.10 104.26 103.65 11.19 2.00 6035839.47 541769.72 N 70.50883233 W 149.65823264 1400.00 16.00 6.16 1388.69 130.14 129.39 13.96 2.00 6035865.22 541772.34 N 70.50890264 W 149.65820997 1500.00 18.00 6.16 1484.32 159.37 158.45 17.10 2.00 6035894.30 541775.32 N 70.50898203 W 149.65818428 1600.00 20.00 6.16 1578.86 191.93 190.82 20.59 2.00 6035926.68 541778.63 N 70.50907046 W 149.65815573 1700.00 22.00 6.16 1672.22 227.76 226.45 24.44 2.00 6035962.33 541782.27 N 70.50916780 W 149.65812423 1800.00 24.00 6.16 1764.26 266.83 265.29 28.63 2.00 6036001.19 541786.25 N 70.50927390 W 149.65808995 Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: MPF-94 (P4) / April 27, 2001 135.773° /15260.87 ft /6.693/1.941 NAD27 Alaska State Planes, Zone 4, US Fool N 70.50854917, W 149.6583241S N 6035735.770 flUS, E 541759.110 flUS -+D.32209524° 0.99990198 0.00 0.00 1.00 2.00 3.00 6.16 6.16 6.16 6.16 6.16 0.00 300.00 399.99 499.96 599.86 0.00 0.00 1.00 1.00 1.00 6035735.77 6035735.77 6035736.64 6035739.24 6035743.58 Page 1 of 3 Minimum Curvature I Lubinski 6.160° N 0.000 ft, E 0.000 ft KB 44.0 ft relative to MSL 26.266° 57440.733 nT 80.808° April 27, 2001 BGGM 2000 True North +26.266° Well Head ,~- 541759.11 541759.11 541759.20 541759.46 541759.91 N 70.50854917 W 149.65832418 N 70.50854917 W 149.65832418 N 70.50855154 W 149.65832345 N 70.50855865 W 149.65832116 N 70.50857050 W 149.65831731 4/27/2001-2:32 PM Grid Coordinates Geo ra hie Coordinates Station ID MD Inel Azim TVD VSee N/.S EJ.W DLS Northing Easting Latitude Longitude (ft) (O) (O) (ft) (ft) (ft) (ft) (0/1DDft) (ftUS) ftUS End Bid Base Permafrost Bid 4/100 1850.00 1887.78 1925.00 25.00 25.00 25.00 6.16 6.16 6.16 1809.76 1844.00 1877.73 287.57 303.54 319.26 285.91 301.78 317.42 30.86 32.57 34.26 2.00 6036021.82 0.00 6036037.70 0.00 6036053.35 541788.36 N 70.50933023 W 149.65807170 541789.98 N 70.50937359 W 149.65805771 541791.58 N 70.50941631 W 149.65804389 2000.00 28.00 6.16 1944.84 352.73 350.69 37.85 4.00 6036086.63 541794.98 N 70.50950720 W 149.65801451 2100.00 32.00 6.16 2031.43 402.72 400.39 43.21 4.00 6036136.36 541800.06 N 70.50964298 W 149.65797066 2200.00 36.00 6.16 2114.32 458.62 455.98 49.21 4.00 6036191.97 541805.75 N 70.50979484 W 149.65792156 2300.00 40.00 6.16 2193.10 520.18 517.17 55.82 4.00 6036253.19 541812.02 N 70.50996200 W 149.65786748 2400.00 44.00 6.16 2267.40 587.08 583.69 63.00 4.00 6036319.75 541818.82 N 70.51014373 W 149.65780873 --~~ 2500.00 48.00 6.16 2336.85 659.00 655.19 70.72 4.00 6036391.28 541826.14 N 70.51033905 W 149.65774556 2600.00 52.00 6.16 2401.12 735.58 731.34 78.94 4.00 6036467.4 7 541833.93 N 70.51054708 W 149.65767830 2700.00 56.00 6.16 2459.88 816.47 811.76 87.62 4.00 6036547.93 541842.16 N 70.51076678 W 149.65760727 2800.00 60.00 6.16 2512.87 901.26 896.05 96.72 4.00 6036632.26 541850.78 N 70.51099705 W 149.65753280 2900.00 64.00 6.16 2559.80 989.53 983.82 106. 19 4.00 6036720.07 541859.76 N 70.51123682 W 149.65745531 3000.00 68.00 6.16 2600.47 1080.87 1074.63 115.99 4.00 6036810.93 541869.05 N 70.51148490 W 149.65737511 3100.00 72.00 6.16 2634.66 1174.82 1168.04 126.08 4.00 6036904.38 541878.61 N 70.51174009 W 149.65729254 End BId 3184.66 75.39 6.16 2658.43 1256.07 1248.81 134.80 4.00 6036985.19 541886.87 N 70.51196074 W 149.65722117 SBF2-NA 8775.57 75.39 6.16 4069.00 6666.10 6627.60 715.45 0.00 6042366.62 542437.22 N 70.52665472 W 149.65246571 SBA5 Base OB 10143.00 75.39 6.16 4414.00 7989.30 7943.15 857.47 0.00 6043682.82 542571.83 N 70.53024857 W 149.65130152 10-3/4 Csg Pt 10202.46 75.39 6.16 4429.00 8046.83 8000.35 863.64 0.00 6043740.05 542577.68 N 70.53040483 W 149.65125094 Drp 3/100 16083.78 75.39 6.16 5912.84 13737.90 13658.54 1474.46 0.00 6049401.02 543156.62 N 70.54586189 W 149.64623905 16100.00 74.90 6.16 5917.00 13753.57 13674.13 1476.14 3.00 6049416.61 543158.22 N 70.54590448 W 149.64622525 16200.00 71.90 6.16 5945.56 13849.39 13769.40 1486.42 3.00 6049511.93 543167.96 N 70.54616474 W 149.64614084 16300.00 68.90 6.16 5979.11 13943.59 13863.05 1496.53 3.00 6049605.63 543177.54 N 70.54642057 W 149.64605782 16400.00 65.90 6.16 6017.53 14035.90 13954.82 1506.44 3.00 6049697.44 543186.94 N 70.54667127 W 149.64597644 16500.00 62.90 6.16 6060.73 14126.07 14044.48 1516.12 3.00 6049787.15 543196.11 N 70.54691620 W 149.64589694 ,-~, 16600.00 59.90 6.16 6108.60 14213.86 14131.76 1525.54 3.00 6049874.4 7 543205.04 N 70.54715463 W 149.64581958 16700.00 56.90 6.16 6160.99 14299.02 14216.43 1534.68 3.00 6049959.18 543213.70 N 70.54738593 W 149.64574452 16800.00 53.90 6.16 6217.77 14381.33 14298.26 1543.51 3.00 6050041.05 543222.07 N 70.54760947 W 149.64567200 16900.00 50.90 6.16 6278.78 14460.55 14377.02 1552.02 3.00 6050119.85 543230.14 N 70.54782463 W 149.64560211 17000.00 47.90 6.16 6343.85 14536.47 14452.50 1560.16 3.00 6050195.37 543237.85 N 70.54803082 W 149.64553525 17100.00 44.90 6.16 6412.80 14608.88 14524.49 1567.93 3.00 6050267.39 543245.22 N 70.54822748 W 149.64547143 17200.00 41.90 6.16 6485.45 14677.58 14592.79 1575.31 3.00 6050335.72 543252.21 N 70.54841406 W 149.64541082 17300.00 38.90 6.16 6561.59 14742.38 14657.22 1582.26 3.00 6050400.19 543258.80 N 70.54859007 W 149.64535373 17400.00 35.90 6.16 6641.03 14803.11 14717.60 1588.78 3.00 6050460.60 543264.98 N 70.54875502 W 149.64530018 17500.00 32.90 6.16 6723.53 14859.60 14773.77 1594.84 3.00 6050516.79 543270.72 N 70.54890846 W 149.64525040 MPF-94 (P4) report. xis Page 2 of 3 4/27/2001-2:32 PM Geo ra hie Coordinates Station ID MD Inel Azim TVD VSee N/.S EI.W DLS Northing Easting Latitude Longitude (ft) (O) (O) (ft) (ft) (ft) (ft) (0/100ft) 17600.00 29.90 6.16 6808.87 14911.70 14825.56 1600.43 3.00 6050568.61 543276.02 N 70.54904994 W 149.64520449 17700.00 26.90 6.16 6896.83 14959.25 14872.84 1605.54 3.00 6050615.91 543280.86 N 70.54917910 W 149.64516251 17800.00 23.90 6.16 6987.15 15002.14 14915.49 1610.14 3.00 6050658.58 543285.22 N 70.54929561 W 149.64512473 17900.00 20.90 6.16 7079.60 15040.24 14953.37 1614.23 3.00 6050696.48 543289.10 N 70.54939909 W 149.64509113 18000.00 17.90 6.16 7173.91 15073.46 14986.39 1617.79 3.00 6050729.52 543292.47 N 70.54948929 W 149.64506189 End Drp 18096.67 15.00 6.16 7266.61 15100.83 15013.60 1620.73 3.00 6050756.74 543295.26 N 70.54956362 W 149.64503774 TKUD 18311.38 15.00 6.16 7474.00 15156.40 15068.85 1626.69 0.00 6050812.02 543300.91 N 70.54971455 W 149.64498878 7-5/8" Csg Pt 18311.39 15.00 6.16 7474.01 15156.40 15068.85 1626.69 0.00 6050812.02 543300.91 N 70.54971455 W 149.64498878 -----", TKUC 18414.90 15.00 6.16 7574.00 15183.19 15095.49 1629.57 0.00 6050838.67 543303.64 N 70.54978733 W 149.64496512 TKUAI A3 18466.66 15.00 6.16 7623.99 15196.59 15108.81 1631.01 0.00 6050852.00 543305.00 N 70.54982372 W 149.64495329 Target 18466.67 15.00 6.16 7624.00 15196.59 15108.81 1631.01 0.00 6050852.00 543305.00 N 70.54982372 W 149.64495329 TKA2 18481.16 15.00 6.16 7638.00 15200.34 15112.54 1631.41 0.00 6050855.73 543305.38 N 70.54983391 W 149.64495001 TKA1 18497.72 15.00 6.16 7654.00 15204.63 15116.80 1631.87 0.00 6050859.99 543305.82 N 70.54984554 W 149.64494623 TMLV 18565.01 15.00 6.16 7718.99 15222.04 15134.12 1633.74 0.00 6050877.32 543307.59 N 70.54989286 W 149.64493087 TD 14-1/2" Lnr pt 18715.02 15.00 6.16 7863.89 15260.87 15172.72 1637.90 0.00 6050915.94 543311.53 N 70.54999830 W 149.64489669 Leaal Description: Surface: 2284 FSL 2801 FEL S6 T13N R10E UM Target: 1553 FSL 1111 FEL S19 T14N R10E UM BHL: 1616 FSL 1104 FEL S19 T14N R10E UM Northina eY) rftUSl 6035735.77 6050852.00 6050915.94 Eastina eX) rftUSl 541759.11 543305.00 543311.54 ----- MPF-94 (P4) report. xIs Page 3 of 3 4/27/2001-2:32 PM ........... .pol Q) ........... Q)....J '+-CI) o~ 0 l!) Q) N > II 0 ..c c: CO T"""4:: _0 ..c:~ .poI-.:::t c..~ Q)- Dca -~ co (.)0.+-: .- Q) "55œ: > > Q) Q) :JW l- I- VERTICAL SECTION VIEW Shared Services Drilling Client: Well: MPF-94 (p4) Field: Milne Point Unit Structure: MPF Section At: 6.16 deg Date: April 27, 2001 0 KOP1/100300MD 300TVD 0.00' 6.16" az 0 departure ~ .--. -'7' nmnn m 0000 n nn nm. _m - - ._mm- -', -... __om' -_m - nmm nm.--- // Bid 1.5/100100MD 700 TVD 4,00' 6.16":az 14 departure n_'.o_.,_n_n_m___n.___n_n___nnn , . __n -~_.----- --'~ n- - _.~- n. .n- --. -- 0 o. 0 -- ____0'- _n - m- - -- 0 - - n- 0 0 . . . . 0 - Bld2l1001100MD 1097TVD 10.00' 6.16"az63departure End:Bld 1850 MD 1810 TVD 25,00" 6.16' az 288 departure nL 'HS-' ¡O-.""" 1"""'. fië> '~4d TV;) 2500 '- Bld4l1001925MD 1878TVD: , 25.00' 6.16'az 319departur4 _o_nnnno_nnnn_n___n_-on___m_on _oon_no_o._nn_o_nn__'nn_n_____._-_o nnnnnmom__m _nnnnmnn_nnnnno__n n,nn'_nnn____n.nnnm___n___nnnnon mni-n_non ! i ! 1G-3/4' Csg \'t 10202 MD 4429 TVD 75.39' 6.1~' az 8047 deparltjre 0 End BId -m nn - -- 3185 MD 2658 TVO 0'0075/39' n1J.16"-azo.o 1256 departure ----~ --, - 5000 -.-.-.'-- Hold Angle 75.39° 7500 m. . -no . O_n n _non' .-.. -'o"'o_o'--.o_o_o.oC;;;;;'o.ooC.ooo.,o,ooo_o.o.oo,o..ooo.,'0- - - ~ 00." "". ..... W"o '0-"' - -. nm n_n -. - _0 .- n. _'00 nm 0000 Hold f\ngle 15.00° 10000 0 2500 7500 10000 12500 5000 Vertical Section Departure at 6,16 deg from (0.0, 0,0). (1 in = 2500 feet) _nnnnn_o.nmnon m;m Drp 31100 1?084 MO - 5913 TVD 75.39': 6,16'az -13738<Jepartureo , , , Schlumberger '-'n. End Drp 18097 MO 7267 TVD 0 15,Wo 6.16"aZ015101 depatltJte 7-5/B" Cag PI18311 MD 7474 TVO 15.00' 6.16'az 15156departure ¡ , Targel 18467 MO 7624 TVD .15_00' 6.16' az 15197 departure ¡ , 15000 TD /4-112" lnr PI 18715 MO 7864 TVO 15.00' 6.16' az 15261 departure T~'.'!¡ ;;'-';' ;o{" !,1.',; "f') /T~"C"A1:.~ii;;:.::';:;) (:~"')"o:.<.,.;"(;i~"()""L'¡O"¡:o' .00'0 "00" ." .. ["t,.? 1/.1"1 '.") If:!" 1'0,<' ,-c 0;~:\1 'volt,,; '..1;; ;-6"", "0",,:, 'Tf.',:,:'!<-;("',r.'!;I:H,j";:U 17500 15000 12500 ^ ^ ^ I ~ 10000 0 Z 7500 I I- ::> 0 (j) V V V 5000 2500 0 ( ( PLAN VIEW Client: Shared Well: MPF-94 Field: Structure: Scale: Date: Services Drilling (P4) Milne Point Unit Schlumberger MPF 1 in = 2500 ft 27-Apr-2001 -5000 -2500 True North Mag Dec ( E 26.27° ) ...........,........................... ~ .............................¡............................ 0 2500 5000 TD/4-1/2" LnrPI 18715 MD 7864 lVD 15.00' 6.16'32 ; 15173N 1638E . """"'~~~~~I"""""""""_::"'.:~':~-~-,!:=:::'~<~~.- .- 18467 MD/7624lVD : 1 r.. i 15,00' 6.16' az i f 15109 N 1631 E . ' 7.5/S" Cog PI 18311 MD 7474 lVD 15,OO"""6,16"u"" 15069 N 1627 E 15000 End Drp 18097 MD 7267lVD 15.00' 6.16' az 15014 N 1621 E ...........,............ 12500 ...,........................... ........................¡............. ...................,...................................... . ¡ ¡ "'"----, End Bid 1850 MD 1810 rvb ~-. . 25.00' 6.16' az 286 N 31 E -~- -~'--,,-. /",,-- Bid 1.5/190700 MD 700 lVD ...................:............................................ """""""""""1"""""""""'" -- '---. .." 4.00' 6.116' az 14 N 1 E .......................... ";:",:............................................................¡.......................... ------------ KOP 1I10d 300 MD 300 lVD 0.00' 6.1~' az 0 N 0 E .. ¡....... .......i.... i ...¡... End Bid 3185 MD 265á lVD 75.39' 6.16' az 1249 ~ 135 E Bid 4/100 1925 MD 1878 ND 25.00' 6.16'az 317N ~4E -5000 -2500 «< WEST , Drp 3/100 16084 MD 5913lVD 75.39' 6.16' az 13659 N 1474 E , ¡ I I I i "I ! 10000 0 CO ~ cD .c: ..... :::¡ E ~.. "0 Õ J: -__.--¡.10-3/4"CogPI .I~] ..-P- ! ~~~~:M~.1:~:~TVD I' /................ : .8000N 864E 7500 i ¡ I 1 I ""1"""""" i ...r.. ...,.... 5000 I ..t... 2500 '" '-'... ----... " -_i i Bid 2I10~ 1100 MD 1097 TVD 10.00' ~.16'az 62N 7E ....i................. 0 0 2500 EAST »> 5000 (: ( BP Anticollision Report --- ---- --- --- -------- Company: BP Amoco I Field: Milne Point Reference Site: M Pt F Pad Co-ordinate(NE) Reference: Well: MPF-94, True North Reference Well: MPF-94 Vertical (TVD) Reference: MPF-94 Plan 44.0 __~efer~~!_~ ellpat~=-_~~~~~~~=~~---------------------------- --------------- --------- --- --------- -- -- -- --------------- -----_!>!>_:_- Sy~~se_______! ------------------------------------------- ------------ -------------------- --- ------- NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 33.00 to 18715.02 ft Scan Method: Trav Cylinder North Maximum Radius: 2045.42 ft Error Surface: Ellipse + Casing Date: 4/27/2001 Time: 16:22:46 Page: 1 ------------------------------ --------- ------- ------- -------_u_---------------------------------------------------------------- ---------- ---------------- -- ----------------------------------------------- -______n______------- ----------_--___--n______------------------- -----------------..- ------------------------, i Survey Program for Definitive Wellpath Date: 4/14/2000 Validated: No Version: 9 : Planned From To Survey Toolcode Tool Name : I ft ft I r- 44_00 500_0.° Plan~~d: -Pi~~-#5 Vi- - . _.. - -- no~------CB-GYRO:SS . - _C~';;e;;;¡;~~;;dgyro si~gle -'-h~¡;-- ---- . - 1_- 500.00 ~-~!_~-~~?~------~~-~~:~~~I~_n~_~_~1_____m_---------- _~WD+~_~~_~-~---------~-~~-+~~~_~--~~_Iti S_t~~~~ - ---- - ------- ------ -- J Casing Points ------------------ - --------------------------------- -------------------------------------------------------------------------- ------------------------------ ------------------------------------------- -------- MD TVD Diameter Hole Size ft ft in in - ----------------- ------------_---___n______------------- ------------------------ --- - --------------- ------------------------------------ 10204.10 4429.00 9.625 12.250 103/4" 18312.24 7474.00 7.000 8.500 7-5/8" 18715.00 7863.03 4.500 6.750 41/2" Name - ----------------------- ------------ ------------------------------------------------ ----------------- - ------_-____m______------------ ----- ---------------- ------ -- ------ ------ ---------------- --------------------------- --------- ---------------______n__-- --- ------ ---- ------------------------ --------------- Summary .---------------------------- -- --------- --------------- ------------ -- -----u--.---------- - .--------------._---------- -- ---- ---------- --------------------------------------------------------------------------------- <-------------------- Offset Well path ----------~-----------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Well path MD MD Distance Area Deviation Warning ft ft ft ft ft ------ - - -- ---- ----- ------ -- -- -- - ---- ----- - - - ---- -. - ------ - -- -- --- --- - - - - - -.-- --- ----- ----- - -- --------- - - - ---- -- - -- -- ----- - - -- ---- -------- -- -- - ------.. -- -- -- - --- - -- - -- -- --------- M Pt F Pad MPF-22 MPF-22 V3 1649.21 1800.00 364.62 31.37 335.06 Pass: Major Risk M Pt F Pad MPF-30 MPF-30 V1 344.41 350.00 341.36 6.56 334.80 Pass: Major Risk M Pt F Pad MPF-34 MPF-34 V7 Plan: Undefi 18259.97 18300.00 552.92 519.91 34.90 Pass: Major Risk M pt F Pad MPF-37 MPF-37 V1 439.54 450.00 387.00 9.03 377.97 Pass: Major Risk M pt F Pad MPF-38 MPF-38 V1 359.84 350.00 300.54 7.44 293.10 Pass: Major Risk MPtFPad MPF-42 MPF-42V6 1653.04 1750.00 206.12 31.78 176.30 Pass: Major Risk M Pt F Pad MPF-46 MPF-46 V4 595.65 600.00 264.29 11.53 252.77 Pass: Major Risk M pt F Pad MPF-50 MPF-50 V6 1712.72 1800.00 262.21 29.64 235.06 Pass: Major Risk M Pt F Pad MPF-53 MPF-53 V1 1700.00 1800.00 365.68 29.87 337.27 Pass: Major Risk M Pt F Pad MPF-530H MPF-530H V1 394.31 400.00 345.75 8.17 337.59 Pass: Major Risk M Pt F Pad MPF-54 MPF-54 V3 2018.67 2100.00 172.73 38.91 138.97 Pass: Major Risk M pt F Pad MPF-58 MPF-58 V1 1454.46 1500.00 39.30 35.93 4.30 Pass: Major Risk M Pt F Pad MPF-62 MPF-62 V1 541.73 550.00 226.87 10.24 216.64 Pass: Major Risk M pt F Pad MPF-66A MPF-66A V8 312.38 300.00 229.31 6.52 222.80 Pass: Major Risk M Pt F Pad MPF-66 MPF-66 V12 312.37 300.00 229.35 7.00 222.34 Pass: Major Risk M Pt F Pad MPF-66PB1 MPF-66PB1 V5 312.37 300.00 229.35 7.00 222.34 Pass: Major Risk M pt F Pad MPF-69 MPF-69 V1 880.74 900.00 336.79 14.85 322.06 Pass: Major Risk M pt F Pad MPF-70 MPF-70 V1 887.37 900.00 230.78 15.29 215.55 Pass: Major Risk M Pt F Pad MPF-74 MPF-74 V1 352.58 350.00 239.90 7.30 232.59 Pass: Major Risk M Pt F Pad MPF-78 MPF-78 V1 1058.53 1050.00 247.98 17.19 230.80 Pass: Major Risk M pt F Pad MPF-86 Plan MPF-86 V1 0 Plan: 396.56 400.00 240.66 9.84 230.82 Pass: Major Risk MPtFPad MPF-92 MPF-92V15 1089.96 1100.00 47.69 21.76 25.93 Pass: Major Risk M pt F Pad MPF-95 MPF-95 V14 Plan: Undef 902.49 900.00 35.80 18.57 17.26 Pass: Major Risk --- ------------- --- --------------------------- ------- ----------------------------- ------------------ ------------------------------------_____--m_----___---- Site: M pt F Pad Well: MPF-22 Wellpath: MPF-22 V3 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft -- ------------------------------------- ----- -- - ------ -- ---- -- ---- -- -------------- ----- ------- - _n___- - ------- -- --- ---------- --- -.----- --- .-- -- __On --- - -- ------------ ------- Reference Offset Semi.,Major Axis Ctr-Ctr No-Go Allowable MÐ TVD MD TVD Ref Offset TFO+AZI TFO-HSCasing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft -----_u_------------ ------ --------- ---------------------------------------- ------- ._n ------------.---------------------------------------------------------------------- -------------------------------------------------------------------------------- - ---------------------------- ------ 47.00 47.00 50.00 50.00 0.06 0.02 179.88 179.88 9.625 387.51 1.31 386.20 Pass 97.00 97.00 100.00 100.00 0.29 0.05 179.87 179.87 9.625 387.47 2.55 384_93 Pass 147.00 147.00 150.00 150.00 0.42 0.12 179.86 179.86 9.625 387.41 3.68 383.72 Pass 197.00 197.00 200.00 200.00 0.55 0.17 179.85 179.85 9.625 387.34 4.73 382.61 Pass 247.00 247.00 250.00 250.00 0.66 0.23 179.83 179.83 9.625 387.25 5.72 381.53 Pass 297.00 297.00 300.00 300.00 0.76 0.28 179.82 179.82 9.625 387.12 6.68 380.45 Pass 344.04 344.04 350.00 350.00 0.84 0.33 179.82 173.66 9.625 386.99 7.55 379.44 Pass 390.90 390.89 400.00 399.99 0.93 0.38 179.86 173.70 9.625 386.79 8.41 378.38 Pass 437.75 437.74 450.00 449.97 0.97 0.43 179.93 173.77 9.625 386.51 9.15 377.36 Pass 484.60 484.57 500.00 499.94 1.00 0.48 180.02 173.86 9.625 386.20 9.86 376.35 Pass --- -- __I -.--- ...- ---------- .----------------------------------------------------.------- ------------ ---..---------------- ----------------------------------------------------,---------- ------------------- --- -- ( Site: M Pt F Pad Drilling Target Conf.: 99% Centre Location: Map Northing: 6050852.00 ft Map Easting : 543305.00 ft Latitude: 70o32'59.365N Shape: Circle _.._---------------~-----_.._--- - ------------------------ ------------------------ Ç)~ ~ ~~ ~X) ~~ ~~ ~~ ~CO ~~ ~~ Target: MPF-94 Tgt -- - _m --- -- ------ --- ---------- ~- --°- ~---- / ( Well: MPF-94,MPF-34 Based on: Planned Program Vertical Depth: 7580.00 ft below Mean Sea Level Local +N/-S: 15110.97 ft Local +E/-W: 1610.72 ft Longitude: 149°38'41.832W Radius: 250 ft --------~~------------- _n___- - ---- /s{ 5b (/ ---- ------- ------------------ /$ ~~ /$ :?°O /$ /00 /S; °00 -- ( ( Proposed MPU F-94 Producer Schematic Tree: 4" Camero~ 5M Orig. KB Elev. = 33.5' (0141) Wellhead: FMC Big Bore" . Orig. GL Elev. = 11.0' Tubina Hanaer: 12" x 4-1/2 with 13-5/8" 4-1/16" adaptor flange 20" 54.5 ppf, K-55 1-100' MD 1 103/4", 45.5ppf, L-80 1 -10,200' MD I KOP @300' Max. hole angle = -75.5 deg. Angle through perfs = -15 deg. 7 5/8" 29.7 ppf, L-80, Mod. Btrc casing 4.5" 12.6ppf, NSCT, L-80 workstring DATE REV. BY 8/6/01 M Triolo roposed Post 27E Producer Completion COMMENTS Camco 4-1/2"x1" wlRP shear valve pinned for 2,500 psi - @ -2000' Drilling rig will leave the 4- 1/2" workstring and seawater in the well. Perfs, SBHP, frac, cleanout, frac flow back and TD tag will be performed without a riq on the well. Following the frac, the well will be jet-pump produced to clean the well up in preparation for an ESP comoletion. 4.5" HES XD Durasleeve with 3.813" 10 7 5/8" x 4.5" Baker Chemical cut or S3 packer 4.5" HES XN-Nipple (ID: 2.725") 4.5" WLEG Baker ZXP packer (-18,150' MD) Baker HMC liner hanger 7 5/8" casing shoe (18,312' MO) 4-1/2" landing collar (PBTO) 4-1/2" 12.6#, L-80 float shoe 1-18,635' MD 1 1-18,715' MD 1 MILNE POINT UNIT WELL F-94 API No: 50-029-XXXXX BP EXPLORATION (AK) ( ( Proposed MPU F-94 Producer Schematic Tree: 4" Cameron 5M Wellhead: FMC Big Bore TubinQ Hanqer: 12" x 4-1/2" with 4" 13-5/8" 4-1/16" adaptor flange 2011 54.5 ppf, K-55 1-100' MD I 103/411, 45.5ppf, L-80 I -10,200' MD I KOP @300' Max. hole angle = -75.5 deg. Angle through perfs = -15 deg. 7 5/811 29.7 ppf, L-80, Mod. Btrc casing DATE REV. BY 8/6/01 J Franks Proposed Completion COMMENTS Orig. KB Elev. = 33.5' (0141) Orig. GL Elev. = 11.0' Camco 2-7/8"x1" GLM I 150' 2-7/8" 6.3 ppf, EUE, L-80 tubing Cameo 2 7/811 x 1" KBMM I 17900' I GLM 2-7/8" HES XN-Nipple I 17950' I Centrilift ESP I 18000' I Baker ZXP packer (-18,150' MD) Baker HMC liner hanger 75/8" casing shoe (18,312' MO) 4-1/2" landing collar (PBTO) 4-1/2" 12.6#, L-80 float shoe 1-18,635' MD , 1-18,715' MD 1 MILNE POINT UNIT WELL F-94 API No: 50-029-XXXXX BP EXPLORATION (AK) H 193332 DATE INVOICE I CREDIT MEMO O/O20iiCKO/O201S PYMT OMMENTS: HANDL NG INST: DESCRIPTION CHECK NO. 00193332 DATE 07/06iO1 GROSS VENDOR DISCOUNT NET 100.00 iOO.OO perjit to Drill lee S/H - Terrie Hub Ie X4628 or Sandra Ste man X4750 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY To The ORDER O-f TOTAL ~ FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. OHIO No.H 193332 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 ~ 00193332 üNt HUNDRED & OO/10a***~********************************* us DOLLAR ALASKA OIL AND GAS. . . CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 m.'"..... . ...... n~;I1' \(.~~J"~A~ .._--~ III ~ g j j j 2111 I: 0 L. ~ 20 j a q 5.: 008 L. L. ¡ ~ III fL ';. ~c. ~o ""~.. CHECK 1 STANDARD LETTER D EVELO PMENT / DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL~R ~OSAL ~NO ANNULAR DISPOSAL l-> YES ANNULAR DISPOSAL THIS WELL \1\\/ ~ -~~ "CLUE" The permit is for a new well bore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS l-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. WEll PERMIT CHECKLIST COMPANY .6/ WELL NAME FIELD & POOL 52$ /0 c:; INIT CLASS .ó'e.-v /-01 ï ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . .'. . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can.be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided .. . . . . . . .. . . . . . . . . . 15. Surface casing protects all known USDWs. . .. . . . . . . . 16. CMT vol adequate to circulate on condudor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . .. . . . . 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate weilbore separation proposed.. . . . . . ~ . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . , 24. Drilling .fluid program schematic & equip list adequate. . ~ . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . R-J\.TE 26. BOPE press rating appropriate; test to ~sig. ..:!:i..J.Se. . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . ,. 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . ~ ~~!9 . 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . o/4~ 34. Contact name/phone for weekly progress reports [exploratory J ANNULAR DISPOSAl35. With proper cementing records, this plan. ' (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface:' , , ' (C) will not impair mechanical integrity 9f the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and ' ' E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLO Y: ENGINEERING:,' UICI nnular COMMISSION: ~~ WM '8~s~ JMf1 ~ DA ENGINEERING GEOLOGY 'APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ROGRAM: exp - dev X- redrU GEOlAREA ~9~ Y N Y N Y N Y N Y N Y N Y N. Y N Y N Y N Y N Y N 'l N N N .~' , ~ ~ Ç:.",*",,- ~'\s. I N:::> ~~~ ~ ' N ~ ""9;;- c::> ç' ~~!:. ~ ~~\~ N N ~ \-\~~V ~~'"'~~~ ~ ~~1'~\ N . Y ~ '\... Q.. ~ ~ It. ...... ( ~"Y::>~ <¡. serv wellbore seg _ann. disposal para req - // 3 ¿ <;¡ ON/OFF SHORE o.J UNIT# c 0 Z 0 -I ~ ::0 (' - -I' m -. Z -I ,:I: Q\o.~~ , - en )- ::0 m » ( N ~/,fl, Y N I' . yJ Y N Y N Y N Com mentsllnstructions: