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Home My WebLink About203-167Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/27/2025 InspectNo:susGDC250902152812 Well Pressures (psi): Date Inspected:9/2/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date: #320-356 Tubing:200 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:8/31/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT F-57A Permit Number:2031670 Wellhead Condition The wellhead looked to be in good condition. No wellhouse protecting the well, but there is a wellhead guard in place around the wellhead. Possible sealant on the flutes of the surface casing hanger. Surrounding Surface Condition Gravel pad with no signs of hydrocarbons. Condition of Cellar Full of water. No signs of hydrocarbons. Small amount of trash in the cellar. Comments Well location verified by well-site pad map Supervisor Comments Photos (8) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, October 27, 2025           2025-0902_Suspend_MPU_F-57A_photos_gc Page 1 of 4 Suspended Well Inspection – MPU F-57A PTD 2031670 AOGCC Inspection Rpt # susGDC250902152812 Photos by AOGCC Inspector G. Cook 9/2/2025 2025-0902_Suspend_MPU_F-57A_photos_gc Page 2 of 4 Tree Cap Pressure Gauge (Tbg Pressure) 2025-0902_Suspend_MPU_F-57A_photos_gc Page 3 of 4 IA Pressure Gauge OA Pressure Gauge 2025-0902_Suspend_MPU_F-57A_photos_gc Page 4 of 4 Surface Casing Fluted Hanger Well Cellar New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect well 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 16,285 feet N/A feet true vertical 7,743 feet 16,076 feet Effective Depth measured 15,089 feet 15,531 & 15,891 feet true vertical 6,653 feet 7,015 & 7,355 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" killl string 9.3# / L-80 / EUE 8rd 14,954' 6,560' 3-1/2"x7" Premier Packers and SSSV (type, measured and true vertical depth)VTA Retreivable N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Water-Bbl MD 115' 9,458' 16,243' TVD 115' measured true vertical Packer Size N/A Casing Conductor Length 115' Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-167 50-029-22747-01-00 Plugs ADL0025509 & ADL0355017 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com MILNE PT UNIT F-57A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A measured 9,308' 16,211' Surface Production Oil-Bbl 7,240psi 777-8333 20" 9-5/8" 7" 4,653' 7,702' 5,410psi WINJ WAG Hilcorp Alaska LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi Burst N/A 5,750psi Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:10 pm, Sep 23, 2021 Chad Helgeson (1517) 2021.09.23 14:01:10 - 08'00' DSR-9/23/21MGR15OCT2021 RBDMS HEW 9/24/2021 SFD 9/28/2021 Isolated SFD 9/28/2021 Suspended Well Inspection Review �Re%l��rt ^ - |nspectNo: sus8DB210919160117 Date Inspected: 9/I9/2021 ` ' Inspector: Brian Bixby Typeo[Inspection Weil Name: K4|LNEPTUNIT F'57A Permit Number: 2031670 Suspension Approval: ` Sundry # 320'356 Suspension Date: _ 9/20/2020 Location Verified? �� |fVerified, How? Other (specify incomments) ' � Offshore? U ` Initial Date A06C[Notified: 9/17/2021 Operator: Hi|corpA|aska, LL[ Operator Rep: Josh McNeal Wellbore Diagram Avai|? �� Photos Taken? 141 Well Pressures (Vs{): Tubing: 100 ' Fluid inCellar? E1 |A 1S0 BPV|nsta||ed/ [] OA� U VR Plug(s) |nstaUed� [� Wellhead Condition, Good, Verified all handles on tree, all valves work, all gauges work and there is no BPV or VR Plugs installed. Condition ofCellar Good /Clean /NoFluids ' Surrounding Surface Londibon Good /Clean / Comments Location Verified byAs-Built pad map Supervisor Comments Photos(2) , Tuesday, October 12,2O2l Suspended Well Inspection — MPU F -57A (PTD 2031670) AOGCC Inspect # susBDB210919160117 Photo by AOGCC Inspector B. Bixby 9/19//2021 2021-0919_Suspend_MPU _F-57A_photos.docx Page 1 of 1 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: 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 16,285 feet N/A feet true vertical 7,743 feet 16,076 feet Effective Depth measured 15,089 feet 15,531 & 15,891 feet true vertical 6,653 feet 7,015 & 7,355 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 / EUE 8rd 14,954' 6,560' 3-1/2"x7" Premier Packers and SSSV (type, measured and true vertical depth)VTA Retreivable N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi Burst N/A 5,750psi 777-8333 20" 9-5/8" 7" 4,653' 7,702' 5,410psi 9,308' 16,211' Surface Production Oil-Bbl 7,240psi MILNE PT UNIT F-57A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 600 Casing Pressure Tubing Pressure 0 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-356 N/A Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-167 50-029-22747-01-00 Plugs ADL0025509 & ADL0355017 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data N/A0 measured true vertical Packer Size N/A Casing Conductor Length 115' WINJ WAG 0 Water-Bbl MD 115' 9,458' 16,243' TVD 115' 0 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 4:01 am, Jul 12, 2021 Chad Helgeson (1517) 2021.07.09 09:51:16 - 08'00' DSR-7/13/21 RBDMS HEW 7/12/2021 SFD 7/16/2021MGR30JUL2021 Well Name Rig API Number Well Permit Number Start Date End Date MP F-57A LRS / ASR 50-029-22747-00-00 203-167 9/11/2020 9/20/2021 9/11/2020 - Friday RU and PT LRS 250L/ 3,000H for pre-rig well kill. Tbg 742psi/ IA 639psi/ OA 88psi. Bled gas off tbg and IA. Bullhead 8.4 Source water down Tbg after 47bbls away rate deceased .8bpm/ 2,100psi. SD. Pumped 4.5bpm/ 1,700psi down tbg returns up IA holding choke @ 500psi pumped away 520 bbls. Verified circuling thru holes in tbg @ 7,500psi. Monitored well SI pressured Tbg and IA @ 400psi. Called for MI to build KWF. RU and PT LRS. Pump 10.2ppg brine kill fluid at 4.1 bpm down tubing taking returns from IA. Noted brine returns at ~ 275 bbls vs 255 bbls calculated. Monitor pressure and found tubing on a vac. Install BPV and nipple down tree. MIRU ASR. Prep location and lay rig mats. Install BOPE and well house. Hilcorp Alaska, LLC Weekly Operations Summary Held PJSM and discussed daily activities. Continued MIRU ASR 1. Torqued BOP stack NU 6' Flow Spool. Fly on Rig Floor. Spotted Mud Boat and ASR. Raised Mast and secured rack pins. Spot rig pump, Pits and connected circulating lines. Hooked up Kill/ Choke Lines. Laid out Koomey Hoses and connected. Functioned BOP's. Laid containment and spot catwalk. Set company man and change out shacks. PU BOPE Testing Equipment. Preformed good shell test 250-2,500psi. Tested BOP's as following. Annular 250-2,500psi, Rams 250-2,500psi, Valves 250-2,500psi. Completed BOP test per AOGCC sundry and ASR procedure. Witness was waived by Guy Cook. L/D BOP Testing Equipment. Clear rig floor and offload BOP test fluid. Take on remaining KWF to pits. Pulled BPV monitored, tbg on vacuum. MU Landing Jt. BOLDS, Pulled hanger of seat 148k and pulled to rig floor and de-completed hanger. LD Landing joint and Hanger. 9/12/2020 - Saturday 9/13/2020 - Sunday Held PJSM and discussed daily activities. Checked fluids and serviced rig. L/D 2 Jts, cut esp cable and secured with 2 clamps. RIH and with cut cable just below the bop stack and closed pipe rams. Lined up valves to pump down the IA. Closed TIW and started pumping down IA at 2.5bpm, caught fluid after 10bbls away. Continued pumping and established injection rate @ 2.5bpm/2,200psi. pump away 36bbls and SD pump. Bled off IA returned 16bbls and then IA was static. POH L/D 4-1/2" 12.6 L-80 Hydril 521 spooling ESP cable f/ 14,561'md t/ 13,869'md. Pumping displacement every 5 jt w/ 10.3ppg brine. On jt # 17 carriage would not go up or dn. Secured well and began troubleshooting found as the carriage was travelling upwards, one of the service loops containing a 64 prong cable caught on one of the bolts on the rear of the carriage rack and parted the cable. Called out electricians to make the repairs. Filling hole at a 4 bph with 10.3 ppg brine while make repairs. Cont POH L/D 4-1/2" 12.6 L-80 Hydril 521 spooling ESP cable f/ 13,869' md f/ 7,073'. Pumping displacement every 5 jt w/ 10.3ppg brine. Well Name Rig API Number Well Permit Number Start Date End Date MP F-57A LRS / ASR 50-029-22747-00-00 203-167 9/11/2020 9/20/2021 Hilcorp Alaska, LLC Weekly Operations Summary 9/16/2020 - Wednesday Held PJSM, Checked fluids and serviced rig. RIH with 5.68" Baker cement retainer on 3-1/2" 9.3# L-80 EUE tubing f/6,200'md t/15,500' md. Spot crane and M/U power swivel on rig. Connect all hoses and function test. Pressure test and record low (250psi) and high (2,600psi) test. Simultaneously rig up HES cement pump. M/U power swivel hoses to pump while P/U and setting CMT Retainer. Attempt to set cement retainer per Baker representative. P/U and slack off with repeated attempts to transfer torque to setting depth. Confirm retainer is set with successful 500 psi backside pressure test and over pull. Inject through tubing and retainer @ 2 bpm and 3 bpm with 0 returns noted. Un-sting from retainer and circulate well to 8.3 ppg source water. Attempt to re-cover all 10.3 ppg for re-conditioning at MI. Rig up and pressure test HES cementers. Held PJSM and discussed daily activities. Checked fluids and serviced rig. Cont POH L/D 4-1/2" 12.6 L-80 Hydril 521 spooling ESP cable f/ 4,600' t/ ESP. Pumping displacement every 5 jt w/ 10.3ppg brine. Last 2 joint 355, 356 (14,461'md) had some pitting on the outside of the pipe. Pic in the file. L/D ESP assembly. Continue L/D ESP assembly. Re-test VBR pipe rams per AOGCC request post shut in. Good test w/ 3-1/2" Test Joint. Fill N2 accumulator bottles to 1,000psi. Load and tally 3-1/2" EUE tubing. P/U CIBP and MU on rig floor. Confirm max OD of 5.68" on lower most body of retainer. RIH with 5.68" Baker cement retainer on 3-1/2" EUE tubing f/ surface t/ 6,200'md. Held PJSM and discussed daily activities. Checked fluids and serviced rig. Continued POH on jt 186 found pitting and marks on the outside of the pipe. On jt 187 found a hole in the tbg on 7' above the connection. Tried breaking connection and fluid started coming out around the threads. MU connection and gas started coming out of the hole above the tool joint. Cut ESP cable and PU 1jt and ran it in the hole. MU TIW and closed pipe rams. 30min SI on Tbg/IA was 12psi. Bled of Tbg/IA to the flowback tank. Monitored for 30mins with no flow. POH L/D Jt #186 and 187(hole in tbg) and set in slips. Cut cable and MU TIW and closed pipe rams. MU Kelly hose to TBG. With IA shut in Pumped 2.5bbls down tbg and pressure climbed to 3,500psi. SD with slow leak off. Made several attempts to bullhead down the tbg with the same results. MIRU SL to shot holes in tbg. RIH w/ temp pressure survey tool and tagged top of ESP 6,888'slm. PU to 6,861 and set for 5mins to record. POOH. LD tool. PU/MU perf gun with timer set at 1hr and 45mins. and RIH. Work through depth 3,620' to 3,660' and unable to RIH. Consult with Wells Supervisor and well support and decide to POH. Re-configure tool string with heavier stem and bigger spangs. RIH with perf gun to shoot holes in tubing. Made it through trouble spot and tie in on depth. Fire guns 6,861' slmd @ 21:55. No immediate indication of shots fired. RU to pump down tubing and noted immediate response on IA. POH and confirm shots fired. RDMO SL unit. Clean and clear rig floor, prep for pumping operations. Bullhead 10.3 KWF down tubing @ 2 bpm and ~ 550psi. Tubing pressure tracking 1:1 with IA. Increase rate to 3.5 bpm and 2,500psi and finish displacing tubing w/ 105 bbls. Shut down pump and trap 1,300psi on both tubing and IA. Bleed gas and oil returns to tiger tank. Cont POH L/D 4-1/2" 12.6 L-80 Hydril 521 spooling ESP cable f/ 7,073' t/ 4,600. Pumping displacement every 5 jt w/ 10.3ppg brine. 9/15/2020 - Tuesday 9/14/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-57A LRS / ASR 50-029-22747-00-00 203-167 9/11/2020 9/20/2021 Hilcorp Alaska, LLC Weekly Operations Summary Held PJSM and discussed daily activities. Check fluids and serviced rig. PU/MU 3-1/2" WLEG and RIH w/WLEG on 3-1/2” 9.3# L-80 EUE 8rd Tbg f/surface and Tagged top of cmt retainer @ 15,440' uncorrected with 5k down wt. Repeat and confirm depth. POH 1 joint and position end of tubing 50' above cement retainer. Rig up Pollard wireline pump in sub and grease head. P/U logging and perforating BHA. RIH to end of tubing and correlate to WLEG pup. Slow RIH speeds to rust on eline drum. Able to pump down hole with 3bpm @ 65 fpm. Set down at 11,960' 9/19/2020 - Saturday Held PJSM and dicussed daily activities. Continued trying to RIH w/EL. Pump dn EL f/11,960wlm t/12,600'wlm set down several times at surface having issues with the line hanging up in the grease head. Checked diameter of line at 12,000' and found flat spots at .262". The grease tubes in pack off head are .262". Discussed issue in town. POOH and RDMO Pollard EL. Waiting on Halliburton EL to arrive from Endicott. MIRU Halliburton EL. Continue to R/U Halliburton EL. HAL does not have correct crossover to M/U to rig. Find XO in Kuparuk and send expeditor. Correct XO on location. Continue R/U. Multiple issues with tool string. Begin troubleshooting. Remove disconnect from tool string and tools check out. RIH with logging/perforating BHA. Pump 1 - 3 bpm with rig pump while RIH. Tie in to tubing tail and WLEG. Tag cement retainer twice at 15,422' elmd. POH 10' and fire perforating guns. Lost weight and indication of guns firing from eline truck. No increased pressure on well. POH. At surface. Confirm all shots have fired. RDMO Halliburton eline. MIRU Halliburton cement crew. 9/20/2020 - Sunday Held PJSM and discussed daily activities. Perform injectivity test @ 1bpm/2,280psi. Mix and circulated 11.5 bbls 15.8 class G cement followed by 131bbls of SW. SD Pump. POH with 16 jts and get above cement plug. SI TBG and squeezed 5bbls of cement into perfs above retainer @ 1bpm/1,480psi. SD and monitored pressure flat lined at 1,480psi. Bled off. Reversed Cir 140bbls @ 4bpm/700psi. BU returns clean. RDMO Halliburton Cement. WOC to reach 1000psi compression. Crew preformed rig maintenance while WOC. RIH and tag cement @ 15,089' tmd with 5k down. PUH and repeat tag with AOGCC witness. P/U and move fluid with rig pump to confirm tubing free of cement. PT casing and cement plug to 3,650psi for 30 charted minutes. AOGCC rep Brian Bixby witnessed and verified a passing test. POH L/D 6 jts. MU Landing jt and Tbg hanger. Land tubing and RILDS. P/U wt 86k, Slack off wt 34k. Set BPV. EOT @ 14,954' KB. End Of Well Work. RDMO ASR, Fly floor and well cellar off. ND BOP's/NU the Production Tree and tested 5,000psi. 9/17/2020 - Thursday Held PJSM with ASR and HEC Cementing crew. Continued RU HEC Cementing and PT Lines to 4,000psi. Mix 25bbls of 15.8 class G cement. Pumped 5 bbl fresh water spacer, 27 bbls of 15.8 class G cement followed by 135 bbl fresh water displacement. Pumped job away at 2.5- 3bpm 2,500-2,900psi, the last 5bbls pumped away had to drop rate to .8bpm/3,000psi showing good indication cement thru perfs. Un-sting from retainer. Lines up to rev circulate well. Lined up to rev circulate well. Reversed circulate 140 bbl of 8.33 Source Water @ 4bpm/550psi. After bottoms up returns clean at surface and SD Pump. Blew lines dry. 9/18/2020 - Friday _____________________________________________________________________________________ Revised By DH 6/28/2021 SCHEMATIC Milne Point Unit Well: MPU F-57A Last Completed: 5/11/2013 PTD: 203-167 TD= 16,285’ (MD) / TD = 7,743’(TVD) 20” Fish @ 16,076’: Parts are outer parts and slips Baker premier Packer, 3 – 10’ pups, 4-1/2” XN & WLEG Ori g. KB Elev.: 45.85’/ GL Elev.:12.1’Doyon 14 7” 2 5 6 TOC tagged @15,089’ on 9/20/2020 9-5/8 ” PBTD =16,163’ (MD) / PBTD = 7,622’(TVD) 3 1 KUP A Sands 4 ES Cementer @ 1,346’ 3 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' .0355 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 9,458’ 0.0759 7" Production 26 / L-80 / NSCC 6.151 Surface 16,243’ 0.0383 TUBING DETAIL 3-1/2” Kill String 9.3 / L-80 / EUE 8rd 2.992 Surface 14,954’ 0.009 JEWELRY DETAIL No Depth Item 1 15,422’ 7” Cement Retainer 2 15,531’ Baker Premier Packer 3 15,554’ 3.5” XN Nipple, 2.75” ID 4 15,562’ WLEG 5 15,891’ Halliburton VTA Retrievable Packer 6 15,947’ Dual Weatherford 500 Micron Screens PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status P&A Perf 15,412’ 15,413’ 6,911’ 6,912’ 1 9/19/2020 Squeezed Kuparuk A3 15,972’ 15,982’ 7,434’ 7,444’ 10 1/21/2004 Open OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 30” Hole 9-5/8" 2011sx Class ‘E’, 800 sx Class ‘G’ in a 12-1/4” Hole 7” 179 sx Class ‘G’ 8-1/2” Hole 7” 30 BBL Class G Plug Cement WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 70° to 76° from 3,600’ – 14,000’ Hole Angle through perf interval = 11° TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead FMC 11” x 4.5” Tbg.5M Gen 5, w/ 7” x 11” Tbg. Hngr., 2-7/8” EUE 8rd Threads T&B, 2-1/2” CIW “H” BPV profile Hanger TC-B-EC 11” x 4.5” Atlas Bradford TC-II 4” CIW – Type H BPV Profile GENERAL WELL INFO API: 50-029-22747-01-00 Sidetracked and Installed Frac String by Doyon 14 - 11/30/2003 ESP Completion Installed by Nabors 4ES - 4/28/2004 RWO ESP by Nabors 4ES 8/20/2004, 5/24/2005 & 6/30/2006 RWO ESP/ Run Screens by Nabors 4ES 5/18/2007 Pull ESP & Run Jet Pump by Nabors 4ES – 9/28/2007 Pull Jet Pump & Run TTC ESP by Doyon 16 – 5/11/2013 STIMULATION SUMMARY 1/28/2004 – 77K lbs. 16/20 Carbolite behind pipe. NOTES Casing landed on emergency slips w/ 230K down weight. Severe dog leg 12,890’ – 13,000’ creates high pickup weights after 14,500’ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Section: 6 Township: 13N Drilling Rig: Hilcorp ASR1 Rig Elevation: Operator Rep: Rich Burnett Casing/Tubing Data (depths are MD): DATE: September 20, 2020 SUBJECT: Plug Verification MPU -57A Hilcorp Alaska LLC. , PTD 2031670; Sundry 320-356 Range: 10E Meridian: Umiat Total Depth: 16,285 ft MD Lease No.: ADL0025509 Suspend: P&A: X Conductor: 20" 0. D. Shoe@ 115 Feet Surface: 9 5/8" 0. D. Shoe@ 9,340 Feet Intermediate: Feet 0. D. Shoe@ Feet Production: 7" 0. D. Shoe@ 16,243 Feet Liner: 0. D. Shoe@ Feet Tubing: 4.5" x 3.5" 0. D. Tail@ 15,564 Feet Plugging Data: Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Retainer 15,402 ft MD " 15,089 ft MD - 8.3 ppg - Drillpipe tag 300 300 Test Data (CMTI TxIA): Initial 1F min '10 min 4.5 min Result Tubing 3650 3620 - 3600 IA 3650 3620 3600 P OA 300 300 300 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I witnessed the top of cement tag with inch tubing and set down 5K on the plug (Hilcorp ASR1). Also witnessed the 30 - minute CMIT TxA to 3600psi. Attachments: none rev. 11-28-18 2020-0920_Plug_Verification_MPU_F-57A_bb 9M T-- 5-7 A PTS Z03) e�_, 10 Regg, James B (CED) From: Regg, James B (CED) Sent: Wednesday, September 16, 2020 9:17 AM ? To: David Gorm Subject: RE: MPU F -57a BOPE Test Report, Accumulator Pre -Charge Pressure AOGCC regulations currently do not incorporate API 16D so our current guidance regarding "accumulator precharge" come from API RP 53 (3rd Edition), Section 12.3.5. After rereading it does appear to provide for the precharge pressure do deviate +/-100psi: 12.3.5 Accumulator Pre:charge. The prec;harge pressure on each accumulator bottle should he measured prior to each BOP stack installation on each vell and adjusted if necessary, The minin'rum precharge pressure for a 3000 psi (20.7 MPa) working pressure accumulator should be It)W psi (6.9 NIN). I z. minimum precharge pressure for a 5N)O psi (34.5 NlPa) working pressure accumulator should be 1500 psi (107.3 NIPa). Only nitrogen gas should be used for aCCUtnulaLor pre - charge. The precharge pressure should he checked and adjusted to within 100 psi (OM Wa) of the s+ iected pre - charge pressure at the start of drilling each well, Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 0{,'1,44,*— ovdn Te, --,+-i CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: David Gorm <dgorm@hilcorp.com> Sent: Tuesday, September 15, 2020 4:43 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Chad Helgeson <chelgeson@hilcorp.com>; Nick Frazier - (C) <nfrazier@hilcorp.com> Subject: MPU F -57a BOPE Test Report, Accumulator Pre -Charge Pressure Mr. Regg, Per our conversation you were requesting that we increase our pre -charge pressure on our accumulator bottles to 1000 psi and referenced API 16D. In further review of API 16D (3rd Edition, November 2018) in regards to any required pre -charge pressure. Based on API 16D (3ed Edition, November 2018) (5.15.3.5) requirements for an accumulator system the base pre -charge pressure (nitrogen) should be greater than 25% of the rated working pressure of the accumulator system. For our 3000 psi system our minimum required pre -charge pressure would be 750 psi. Also API 16D (3rd edition, November 2018) 5.15.3.8 states " The amount of pre -charge pressure is variable depending on specific operating requirements of the equipment to be operated and the operating environment. Operation Manuals shall state any requirements for pre - charge pressure required based on design." Based on the current API 16D and the operating manual for our specific accumulator of ASR 1 that states pre -charge pressure to be 1000 psi +/- 10% we are in compliance with our current 900 psi pre -charge pressure. Then following AOGCC requirement to be 200 psi above our pre -charge pressure after BOP equipment actuation. Attached a copy of the Accumulator Manufactures Pre -Charge requirement. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. W 5.1 Before Start up Operator's Manual — API 5 Station 150 Gallon EH 1) Ensure the system bleed valve and all accumulator isolation valves are open. Ensure ail hydraulic pressure is bled from all the accumulator bottles mounted in the accumulator manifold. 2) Test the pre -charge pressure in all the accumulator bottles mounted in the accumulator manifold. Pre -charge using NITROGEN to 1,000 PSI (7,000 kPa) +/- 10%. DO NOT USE OXYGEN. A,yIZP `�3 3) Test the pre -charge in all 1 -US quart pulsation dampeners on the main unit. Pre - charge using NITROGEN only. DO NOT USE OXYGEN. Adjust pre -charge in primary dampener(s) to 1,000 PSI (7,000 kPa). 4) Check the fluid level in the reservoir on the main unit. The fluid level should be 8 to 10 inches (20-25 cm) from the top of the reservoir when the BOP Control System is completely bled off. The reservoir oil should be clean and free of water and dirt contamination. 5) Check the oil level in the pump crank cases. The oil level is visually inspected at the sigh gauge on the pump. The oil level should be visible in the middle of the sight gauge. The oil should be clean and free of water and dirt contamination. Fill as required suing appropriate crank case oil. Refer to manufacture specifications. 6) Inspect and clean pump suction screens. To remove the screen, first close the pump suction valve and remove the hex cap in the pump suction Y -strainer. The screen will be accessible in the strainer housing once the hex cap is removed. Clean the screen and re -install. Open the pump suction valve. 7) Inspect and clean high pressure T -strainer. The screen will be accessible in the strainer housing once the hex cap is removed. Clean the screen and re -install. 8) Check drivel belt for proper tension and belt integrity. Belt tension = 1/4" deflection of the belt between the drive and driven pulleys. Ensure there are no tom or frayed sections on the drive belts. Adjust or replace as required. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *All BOPE reports are due to the agency within 5 days of testing* Submit to: iim.regg(cD.alaska.gov; AOGCC.Inspectors(@alaska.gov; phoebe.brooks @alaska.gov Contractor: Hilcorp Rig No.: ASR 1 DATE: 9/13/20 Rig Rep.: Matt Beshea Rig Phone: 907-685-1266 Operator: Hilcorp Alaska Op. Phone: 907-685-1266 Rep.: Wade Hudgens E -Mail whudgens a()hilcorp.com Well Name: MPU F -57A - PTD # 2031670 Sundry # 320-356 " Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi -Weekly: Test Pressure (psi): Rams: 250-2500 Annular: 250-2500 Valves: 250-2500 MASP: 1476 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. NA Ball Type 1 P Standing Order Posted P Misc. NA Inside BOP t P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13-5/8" 5M P Pit Level Indicators P P #1 Rams 1 2-7/8"-5" VBR's P Flow Indicator P P #2 Rams I Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3-1/8" 5M FP Inside Reel valves 0 NA HCR Valves 1 3-1/8" 5M P Kill Line Valves 2 3-1/8" 5M P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi) 3100 P CHOKE MANIFOLD: Pressure After Closure (psi) 1150 P Quantity Test Result 200 psi Attained (sec) 20 P No. Valves 16 P Full Pressure Attained (sec) 103 P Manual Chokes I P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.): 2325 x 4 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 1 - Test Time: 4.0 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: 3-1/2" and 4-1/2" Test Joints used. 1 F/P recorded. C1 low test failed. Valve was not properly closed. Cycled valve and passed the subsequent test. Accumulator drawdown test result "P'; avg. initial pre -charge pressures on the system bottles is 900 psi; API RP 53 3rd edition, Section 12.3.5 requires 1000psi +/- 100psi; after the accumulator drawdown test, "Pressure After Close" = 1150 psi (250 psi above pre -charge pressure). AOGCC Inspection 24 hr Notice Yes Date/Time 9-11-20/18:25 Waived By Guy Cook est Start Date/Time: 9/12/2020 22:00 (date) (time) Witness est Finish Date/Time: 9/13/2020 2:00 Form 10-424 (Revised 04/2018) 2020-0913_BOP_Hilcorp_ASR1_MPU_F-57A 112,6 --a31(oZ o Regg, James B (CED) From: David Gorm <dgorm@hilcorp.com>�� Sent: Tuesday, September 15, 2020 8:50 AM To: DOA AOGCC Prudhoe Bay; Regg, James B (CED); Chad Helgeson; Tom Fouts Subject: MP F -57A (PTD: 203-167) Sundry 320-356, BOP Shut in Notification BOP Closure Notification: 9/14/2020, 6:30am MP F -57A (PTD:203-167) Rig: ASR 1 Operations: Prior to tripping the ESP completion the well was circulated with source water to kill the well. The TBG had a hole at 7,500' MD and the ESP was plugged off preventing ability to circulate the TBG clear of produced fluid below the hole in the TBG. Due to the high inclination of the well unable to get slick -line down to punch the TBG above the ESP prior to tripping the TBG. Circulated the TBG and IA with kill fluid from 7,500' MD to surface. On jt. 187 found a hole in the TBG 7' above the connection. Tried breaking the connection and fluid started coming out of the TBG. MU the connection, cut the ESP cable, clamped off, PU 1 joint and ran the TBG in the hole. MU the TIW and closed the pipe rams to secure the well and evaluate the flow. After 30 min shut in pressures reached 12 psi. Verified the IA was static, bled the pressure off of the TBG and verified the dead produced fluid below the hole in the TBG had gas breaking out inducing flow up the TBG as the gas broke out. Proceeded with pulling the joint with the hole RU slick -line, RIH, perforated the TBG above the ESP and circulated the dead produced fluid out of the TBG. Well was static. David Gorm Operations Engineer Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: Plug Back for Sidetrack 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): 16,285'16,076' Casing Collapse Conductor N/A Surface 3,090psi 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: 8/25/2020 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: dgorm@hilcorp.com 14,565' 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 4-1/2" COMMISSION USE ONLY Authorized Name: Authorized Title: Perforation Depth MD (ft): See Schematic See Schematic 12.6# / L-80 Hydril 521 Anchorage Alaska 99503 50-029-22747-01-00 Length Size MILNE POINT / KUPARUK RIVER OIL TVD PRESENT WELL CONDITION SUMMARY MD 7,743' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 / ADL0355017 3800 Centerpoint Dr, Suite 1400 203-167 Hilcorp Alaska LLC MILNE PT UNIT F-57A C.O. 432D N/A115' 20" 16,076' 7,536' 1,476 N/A Burst 115'115' 9,340'4,621'5,750psi 7,702'16,211'7" 9.3# / L-80 9,308'9-5/8" 7,240psi16,243' 15,531' - 15,564' Perforation Depth TVD (ft): Tubing Size: Authorized Signature: 10/15/2020 3-1/2" 15,531MD/ 7,015TVD & 15,891MD/ 7,355TVD and N/ABaker 7" x 3.5" Premier & VTA Retrievable and N/A Tubing Grade:Tubing MD (ft): Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate Chad A Helgeson 2020.08.26 13:05:57 -08'00' By Samantha Carlisle at 2:18 pm, Aug 26, 2020 320-356 10-407 DLB BOPE test to 2500 psi. Sidetrack to follow in November 2020. X X DLB 08/26/2020MGR10SEP2020 DSR-8/27/2020 9/11/2020 dts 9/10/2020 JLC 9/10/2020 RBDMS HEW 9/16/2020 Plugback Well: MPU F-57A Date: 8/13/2020 Well Name:MPF-57A API Number: 50-029-22747-01 Current Status:SI Rig:ASR Estimated Start Date:October 15 th, 2020 Estimated Duration:8days Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:203-167 First Call Engineer:David Gorm (907) 777-8333(O) (505)-215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8412 (O) (907) 331-8228 (M) Current Bottom Hole Pressure: 2,111 psi @ 6,342’ TVD DH Gauge: 2 month PBU (8/7/2020) |6.4 PPG Maximum Expected BHP:2,111 psi @ 6,342’ TVD DH Gauge: 2 month PBU (8/7/2020) |6.4 PPG MPSP:1,476 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 70-76° @ from 3,600’ to 14,000’ MD Min ID:2.75” ID of 3-1/2” XN at 15,554’ MD (in lower completion/below ESP) Brief Well Summary: MP F-57A is a Kuparuk producer with a thru-tubing ESP. The well does not have a production packer. The ESP failed to surface fluids and the pump section was changed out with coil tubing. After setting the packoff on the pump sections the tubing failed to pressure test. An LDL was run which identified a hole in the tubing at 7,510’ md and a tubing patch was installed 3/10/2019. Objective: x Pull existing 4-1/2” ESP completions. x Plug Back Existing zone, prepare the well to be sidetracked. Sundry Procedure (Approval Required to Proceed): Pre-Rig Procedure: 1. RU LRS and PT lines to 3000 psi. 2. Bullhead 220 bbls of produced/source water down the tubing to ESP pump. 3. Bullhead 300 bbls of produced/source water down IA to the formation,document the pump rate and pressure. Contact the operations Engineer if we cannot obtain an injection rate down the IA. 4. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 5. RD Little Red Services. 6. Clear and level pad area in front of well. Spot rig mats and containment. 7. RD well house and flowlines. Clear and level area around well. 8. RU crane. Set BPV. ND Tree. Inspect the tubing hanger lift thread and note any damage. 9. NU BOPE. RD Crane. 10. Spot mud boat. RWO Procedure (Prep Well for Sidetrack): 11. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. Plugback Well: MPU F-57A Date: 8/13/2020 12. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/produced/source water prior to pulling BPV. 13. Set TWC. 14. 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 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15.Contingency: If BOPE test fails 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. 16. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/produced/source water as needed. 17. Rig up spoolers for ESP cable. a. Baker Hughes representative should be onsite for ESP pull. 18. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. Estimate +/- 140 Klb PU wt. b. If needed, circulate (long or reverse) pill with lubricant, produced/source-water, and/or baraclean pill prior to laying down the tubing hanger. 19. 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. a. Evaluate pulled tubing hanger for possible damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 20. POOH and lay down the 4-1/2” tubing spooling ESP cable. Lay down ESP and motor. a. Note any corrosion, sand, or scale on the tubing with associated depths and ESP components on the morning report. Plugback Well: MPU F-57A Date: 8/13/2020 Equipment Disposition Tubing hanger Visually inspect on site restock or junk Tubing & Pup joints Junk ESP Junk 21. PU and MU 7” cement retainer. RIH on 3-1/2” TBG and set the cement retainer at +/-15,500’ MD. 22. PT the IA to 1,000 psi for 10 minutes. Establish injection into the reservoir. 23. RU HES cementer and PT lines. 24. Mix and pump 25 bbls of 15.8 ppg class G cement with spacers. Displace the cement with the rig to the end of the cement stinger. Pump 25 bbls of cement below the retainer, pull out of the cement retainer. 25. Install wiper ball and circulate the well clean from the top of the CMT retainer (note the volume of cement returns at surface). TOOH and lay down the cement retainer running tool. 26. TIH with 3-1/2” TBG open ended tag the top of the CMT retainer, PU 50’. 27. RU e-line, RIH with perf guns (note: As needed pump the tools down taking returns up the IA). 28. Tag the top of the CMT retainer, PU 10 ‘, perforate 4 holes. (Note: squeeze perforations for placement of CMT outside the 7” CSG) 29. POOH, RD E-line. 30. RU HES cementer and PT lines. 31. Conduct Injectivity Test. (Note: Notify Operations Engineer if no injectivity is achieved) 32. Mix and pump 10 bbls of 15.8 ppg class G cement with spacers. 33. Slowly TOOH ~16 jts get above Cement plug. Shut in the IA, Squeeze 5 BBLS cement out the perforations max squeeze pressure of 2,500 PSI. Install wiper ball and circulate the well clean (note the volume of cement returns at surface). 34. RD HES cementers. WOC to reach 2,000 psi compressive. RIH tag the TOC and PT the cement plug to 3,500 psi for 30 minutes (charted) (MIT 50% of internal yield pressure on 7” 26# L-80) a. Notify the AOGCC 24 hours in advance to witness the tag and PT. 35. TOOH to +/- 15,000’ MD, circulate the well clean. 36. Land 3-1/2” Kill String, pump 55 BBL Diesel to freeze protect. 37. RDMO Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form Mel, We are planning to have Doyon 14 sidetrack after the Plug back of the well. Our current Anticipated time for the Drilling sidetrack is currently for November 7th 2020. Thanks, David Gorm Operations Engineer Hilcorp Alaska _____________________________________________________________________________________ Revised By TDF 8/10/2020 SCHEMATIC Milne Point Unit Well: MPU F-57A Last Completed: 5/11/2013 PTD: 203-167 TD = 16,285’ (MD) / TD = 7,743’(TVD) 20” Fish @ 16,076’: Parts are outer parts and slips Baker premier Packer, 3 – 10’ pups, 4-1/2” XN & WLEG Ori g. KB Elev.:45.85’/ GLElev.: 12.1’ Doyon 14 7” 4 6 9 10 1 Tubing Patch from 7,500’ to 7,519’ SLM Set 3/10/2019 9-5/8” 2 & 3 PBTD = 16,163’ (MD) / PBTD = 7,622’(TVD) 7 5 KUP A Sands 8 ES Cementer @ 1,346’ CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' .0355 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 9,458’ 0.0759 7" Production 26 / L-80 / NSCC 6.151 Surface 16,243’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / Hydril 521 3.958 Surface 14,565’ 0.0152 JEWELRY DETAIL No Depth Item 1 14,523’ TCC Drilled Tubing Crossover 2 14,533’ Upper Tandem Seal 3 14,541’ Lower Tandem Seal 4 14,547’ Motor: CL6 MSP1, 250 Hp / 2,450 V / 31A 5 14,561 Sensor: WellLift MGU & Centralizer – Btm @ 14,565’ 6 15,531’ Baker Premier Packer 7 15,554’ 3.5” XN Nipple, 2.75” ID 8 15,562’ WLEG 9 15,891’ Halliburton VTA Retrievable Packer 10 15,947’ Dual Weatherford 500 Micron Screens PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup.aruk A3 15,972’ 15,982’ 7,434’ 7,444’ 10 1/21/2004 Open Ref Log: 12/24/2003 Memory SCMT Log –3.38” 12-SPF zpf 3412 HSD Gun OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 30” Hole 9-5/8" 2011sx Class ‘E’, 800 sx Class ‘G’ in a 12-1/4” Hole 7” 179 sx Class ‘G’ 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 70° to 76° from 3,600’ – 14,000’ Hole Angle through perf interval = 11° TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead FMC 11” x 4.5” Tbg.5M Gen 5, w/ 7” x 11” Tbg. Hngr., 2-7/8” EUE 8rd Threads T&B, 2-1/2” CIW “H” BPV profile Hanger TC-B-EC 11” x 4.5” Atlas Bradford TC-II 4” CIW – Type H BPV Profile GENERAL WELL INFO API: 50-029-22556-00-00 Sidetracked and Installed Frac String by Doyon 14 - 11/30/2003 ESP Completion Installed by Nabors 4ES - 4/28/2004 RWO ESP by Nabors 4ES 8/20/2004, 5/24/2005 & 6/30/2006 RWO ESP/ Run Screens by Nabors 4ES 5/18/2007 Pull ESP & Run Jet Pump by Nabors 4ES – 9/28/2007 Pull Jet Pump & Run TTC ESP by Doyon 16 – 5/11/2013 STIMULATION SUMMARY 1/28/2004 – 77K lbs. 16/20 Carbolite behind pipe. NOTES Casing landed on emergency slips w/ 230K down weight. Severe dog leg 12,890’ – 13,000’ creates high pickup weights after 14,500’ _____________________________________________________________________________________ Revised By DWG 8/19/2020 PROPOSED Milne Point Unit Well: MPU F-57A Last Completed: 5/11/2013 PTD: 203-167 TD = 16,285’ (MD) / TD = 7,743’(TVD) 20” Fish @ 16,076’: Parts are outer parts and slips Baker premier Packer, 3 – 10’ pups, 4-1/2” XN & WLEG Ori g. KB Elev.: 45.85’/ GL Elev.: 12.1’ Doyon 14 7” 2 5 6 9-5/8” PBTD = 16,163’ (MD) / PBTD = 7,622’(TVD) 3 1 KUP A Sands 4 ES Cementer @ 1,346’ 3 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' .0355 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 9,458’ 0.0759 7" Production 26 / L-80 / NSCC 6.151 Surface 16,243’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / 8 RD EUE 2.992 Surface 15,000’ 0.009 JEWELRY DETAIL No Depth Item 1 15,500’ 7” Cement Retainer 2 15,531’ Baker Premier Packer 3 15,554’ 3.5” XN Nipple, 2.75” ID 4 15,562’ WLEG 5 15,891’ Halliburton VTA Retrievable Packer 6 15,947’ Dual Weatherford 500 Micron Screens PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status P&A Perf 14,489’ 14,490’ 6,326’ 6,327’ 1 TBD Planned Kup.aruk A3 15,972’ 15,982’ 7,434’ 7,444’ 10 1/21/2004 Open OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) 30” Hole 9-5/8" 2011sx Class ‘E’, 800 sx Class ‘G’ in a 12-1/4” Hole 7” 179 sx Class ‘G’ 8-1/2” Hole 7” 35 BBL Class G Plug Cement WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 70° to 76° from 3,600’ – 14,000’ Hole Angle through perf interval = 11° TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead FMC 11” x 4.5” Tbg.5M Gen 5, w/ 7” x 11” Tbg. Hngr., 2-7/8” EUE 8rd Threads T&B, 2-1/2” CIW “H” BPV profile Hanger TC-B-EC 11” x 4.5” Atlas Bradford TC-II 4” CIW – Type H BPV Profile GENERAL WELL INFO API: 50-029-22556-00-00 Sidetracked and Installed Frac String by Doyon 14 - 11/30/2003 ESP Completion Installed by Nabors 4ES - 4/28/2004 RWO ESP by Nabors 4ES 8/20/2004, 5/24/2005 & 6/30/2006 RWO ESP/ Run Screens by Nabors 4ES 5/18/2007 Pull ESP & Run Jet Pump by Nabors 4ES – 9/28/2007 Pull Jet Pump & Run TTC ESP by Doyon 16 – 5/11/2013 STIMULATION SUMMARY 1/28/2004 – 77K lbs. 16/20 Carbolite behind pipe. NOTES Casing landed on emergency slips w/ 230K down weight. Severe dog leg 12,890’ – 13,000’ creates high pickup weights after 14,500’ Milne Point ASR Rig 1 BOPE 2020 Updated 1/09/2020 11” BOPE 4.48' 4.54' 2.00' INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR 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 HCRManualManualManual Stripping Head Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: August 26th, 2020Subject: Changes to Approved Sundry Procedure for Well MP F-78ASundry #: 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 L From: Schwartz, Guy L (CED) Sent: Monday, June 17, 2019 9:35 AM To: Tom Fouts Cc: David Haakinson; samantha.carlisle@alaska.gov Subject: RE: MP F -57A PTD: 203-167 / Sundry #: 319-235 Withdrawal Request Tom, The AGOCC will withdraw sundry 319-235 as requested below. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without First saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv schwartz@alaska gov). From: Tom Fouts <tfouts@hilcorp.com> Sent: Thursday, June 13, 2019 3:35 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: MP F -57A PTD: 203-167 / Sundry #: 319-235 Withdrawal Request Guy, Hilcorp Alaska LLC request to withdraw sundry number 319-235 for MP F -57A. Please feel free to contact me with any questions. Regards, Tom Fouts I Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfoutsPhilcoro.com Direct: (907) 777-8398 Mobile: (907) 351-5749 RBDMSLbA/JUN 2 0 2019 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should cany out such virus and other checks as it considers appropriate. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU F -57A Permit to Drill Number: 203-167 Sundry Number: 319-235 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the 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 f irther 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, zvz�� Daniel T. Seamount, Jr. Commissioner _ DATED this_ day of May, 2019. MAY 0 9 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 2Rn RECEIVED MAY 0 8 2018 A,000Q, 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ V Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Tubing Patch ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ Stra[igraphic Service El 203-167 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22747-01-00 ' 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 21 MILNE PT UNIT F -57A ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025509 ! ADL0355017 I MILNE POINT/ KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,743' 16,076' 7,536' 1,000 NIA 16,076' Length Size MD TVD Burst Collapse I 115' 20" 115' 115' N/A NIA 9,308' 9-5/8" 9,340' 4,621' 5,750psi 3,090psi 16,211' 7" 16,243' 7,702' 7,240psi 5,41 Opal Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" 12.6# / L-80 Hydril 521 14,565' See Schematic See Schematic 3-1/2" 9.3# / L-80 15,531'- 15,564' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker 7" x 3.5" Premier & VTA Retrievable and N/A 15,531 MD/ 7,015TVD & 15,891 MD/ 7,355TVD and N/A 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 5/12/2019 Commencing Operations: OIL � WINJ ❑ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR [I SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ElOp Shutdown 13Abandoned El17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized TRIe: Operations Manag Contact Email: dhaaklnson hll Or .com Contact Phone: 777-8343 Authorized Signature: Date: 5/8/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I _ Z 3l✓-, r Plug Integrity ❑ BOP Test E] Mechanical Integrity Test ❑ Location Clearance Other: 3BDMS�' MAY 0 9 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: 44~COMMISSIONER THE COMMISSION Date'. Form -4T0 03 Reused 4/2017 Approved application iOi IRrl1r It NO.AkLate of approval. Submit Form and Attachments in Du licate 0 Eiil.a p Alaska, LG Tubing Patch Well: MPF -57A PTD: 203-167 API: 50-029-22747-01 Well Name: MPF -57A API Number: 50-029-22747-01 Current Status: SI Rig: SL, EL, SL Estimated Start Date: May 12th, 2019 Estimated Duration: 3 days Reg.Approval Req'std? Yes (for patch set) Date Reg. Approval Rec'vd: N/A Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 203-167 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number 1952592 Current Bottom Hole Pressure: 3,676 psi @ 7,000' TVD (Downhole gauge reading on 01/14/2019) MPSP: 1,000 psi (Max recent surface pressure) Recent. SI Surface Pressure:—1,OOOpsi (Taken 01/02/2019) Min ID: 3.958", Drift ID of tubing down to the top of the TTC-ESP 2.0" ID with patch. Brief Well Summary: MPF -57A is a packer -less wireline retrievable ESP Kuparuk producer. A tubing leak was identified in 2018, and multiple troubleshooting attempts were made to locate and set a tubing patch. A LDL identified a hole in the tubing at 7,510' MD. The last tubing patch was set on 3/10/19 and lasted approximately one month to which the well was SI on 4/15/19. It is suspected that the lower paragon patch sealing element is located on or near the hole. There is a risk of additional tubing leaks deeper in the well. Notes Regarding Wellbore Condition: • A caliper was run on the well which shows over 50 joints with 40-82% wall penetrations. The highest penetration recorded was 82% at 7,508' MD. • The LDL performed on 2/4/19 indicated a tubing leak at 7,514' MD. Objective.- Test bjective:Test upper paragon packer and tubing above patch. • Pull existing tubing patch • Clean and dress tubing patch interval • Set new tubing patch. Procedure Part I (Non Sundry Diagnostics) Slickline 1. MIRU SL unit. Pressure test to 200 psi low and 2,000 psi high. a. Contact Quadco Representative to be on-site for packer pulls 2. RIH w/ Quadco patch test tool and land in 2.75" seal -bore @ —7,497' MD. 3. PT tubing to 1500 psig. a. The purpose of this test is to ensure top packer integrity and no further tubing leaks up -hole. 4. RIH w/ Quadco packer retrieval tool and pull upper packer and assembly @"'7,497' MD. a. Send packer to Quadco's Deadhorse shop to be redressed. 5. RIH w/ Quadco packer retrieval tool and pull lower packer @ —7,517' MD. a. Send packer to Quadco's Deadhorse shop to be redressed. 6. RIH w/ D&D holefinder to the top of the KB packer @ 14,430' MD and set holefinder. K HOW"' Alaska, LL, Tubing Patch Well: MPF -57A PTD: 203-167 API: 50-029-22747-01 a. The purpose of this D&D run is an attempt to determine the possibility of additional leaks. E -line has been unable to achieve depths greater that -7,600' MD. b. Pump 10 bbls of diesel down tubing @ 1 BPM. Document wellhead tubing pressure. 7. POOH to 7,600' MD and set D&D holefinder. a. Pump 10 bbls of diesel down tubing @ 1 BPM. Document wellhead tubing pressure or any change in the leak rate. 8. POOH to 7,400' MD and set D&D holefinder. a. PT tubing to 1,000 psig. b. If PT fails, pump 10 bbls of diesel down tubing @ 1 BPM. Document any change in tubing pressure or change in leak rate. 9. RIH w/ magnet to 7,550' MD. a. Assumes minimal leak rate change between 14,430' MD and 7,600' and passing PT at 7,400' MD b. Note that the last magnet run recovered 8 cups of metal shavings. 10. RIH w/ 4.5" tubing brush. Brush and flush tubing interval from 7,480' MD to 7,530' MD 11. RD Slickline Unit. Procedure Part II (10-403 SUNDRY REQUIRED) E -Line 1. MIRU Schlumberger EL unit. Pressure test to 200 psi low and 2,000 psi high. 2. RIH w/ GR, CCL, roller stem, and packer setting tool. 3. Set lower 4-1/2" paragon packer mid -element @ 7,524' MD. a. Correlate to LDL log dated 02-04-19. b. If unable to achieve at least 7,518' MD, POOH without setting packer. c. If lower packer was not set, slick -line will be utilized with a longer patch interval. 4. RD EL unit. Slickline 5. MIRU SL unit. 6. Pressure test lubricator to 200 psi low and 2,000 psi high. 7. RIH w/ DPU and BHA consisting of 4-1/2" paragon packer, 25' x 2-3/8" spacer pipe, and latch seal assembly. a. "'30' Element to Element. 8. Sting into lower paragon packer @ 7,524' MD, and set upper paragon packer with DPU. 9. RIH w/ Quadco patch test tool and land in 2.75" seal -bore @"'7,494' MD. 10. PT tubing to 1,500 psig. 11. RD SL unit. Attachments: 1. As -built Schematic 2. Proposed Schematic Tree: 41/16" -5M Cameron Wellhead: FMC 11" x 4.5" Tbg. Hanger: TC -B -EC 11"x 4.5" Atlas Bradford TC -II 4" CIW -Type H BPV profile 20" 91.1 ppf, H-40 115' 9 5B" Whipstock top 9317' Window in 9 5/a'9340-9356' 7" CIBP set @ 9490' Tubing Patch from 7,500' SLM to 7,519' SLM. Set on 3/10/2019 9 5/8", 40 ppf, L-80 Btrc. 9340' KOP @ 500' Max. hole angle = 70 to 76 deg. f/3600'to 14,000' Hole angle thru' parts = 11 deg. 4.5 12.6# L-80, Hydril 521 Tbg. (Drift ID= 3.958" ID, Cap =.0152 bpf) 7"26#, L-80, BTC casing (Drift ID = 6.151, Cap w/ tbg =.0186 bpf) IPerforation Summary Ref log: 1/21/04 Sim SPF Interval (TVD) 3 3/8" 12 15,972'-15,982' 7,434'-7,443- A [77(ni F1d4f1 Y r. I ■I.1i Nff in Fish: Top ® 16076' MD 6128/06 Lost during 428/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 4 12" XN and W LEG 7 of 8 anchor slips missing (2" x 1"x 3/4" thick) and 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). MPF -57A Orig. DF Elev. = 40.8'(N 22E) Orig. GL Elev. = 12.1' DF To 7" csg. hng. = 27.9'(N 2217) Casing landed on emergency slips w/ 230k down Howco 9 5/8" 'ES' Cementer -4ES This well has been sidetmcked from the original completion. Min. ID in tubing is XN 2.75' @ 15,554' NOTE, Severe don lea 12990,130061 Tbg top 45 KB Packer (CTM 14,434.7' Kobe Knockout,pup joint, D&D Stinger OAL 10.82' Centrilift TTC-ESPTop (CTM14,455' 3.80".24.5' AOL Pump Type 112P6, 380 SXD TTC Drilled Tbg Crossover 14,523' 4.5 NSTC PIN x45521 HYDRILL BOX Upper Tandem Seal Sections Model GSB3 DB UT/HL H6 PFS 14,533' Model MSP1 Motor, 120 HP, 3205 volt,23 amp, 14,547' PumpMate w/ 6 fin Centralizer PumpMate =' TVD 14,563' Baker 7" x 3.5" 15,531' Premier Pkr. 2.87" ID 3.5" XN Nipple 15,554' (2.75" No-go ID) WLEG 15,562` Halliburton "VTA" Retrievable LIL8L Packer- 3.880" I.D. Dual Weatherford 500 Micron 15947'- Duragrip Screens ,,,,,,,1, Note: 4ES RIH to 16070'. This is 6' above the flat Did not tag. 5-16-07 7" Weatherford float collar 16163' (PBTD) 7" Weatherford float shoe 16244' WELL MPF -57A API NO: 50-029-22747.01-00 Tree: 41/16" -5M Cameron Wellhead: FMC 11" x 4.5"Tbg. Hanger: TC -B -EC 11"x 4.5" Atlas Bradford TC -II 4" CIW - Type H BPV profile 20" 91.1 ppf, H-40 9 518" Whipstock top 9317' Window in 9 5/8'9340-9356' 7° CiBP set @ 9490' Tubing Patch from +7-7,496' SLIM to +/-7,524'. 9 5/8", 40 ppf, L-80 Btrc. 9340' 4.5 12.6# L-80, Hydril 521 Tbg. (Drift ID= 3.958" ID, Cap =.0152 bpf) 7" 26#, L-80, BTC casing (Drift ID = 6.151, Cap w/ tbg =.0186 bpf) I Perforation Summary Ref log: 1/21/04 Size SPF interval (TVD) 3 3/8" 12 15,972'-15,982' 7,434'-7,443' iFj iA f•T7C•'ti k191111191111111111111 Lost during 4/28/04 RWO to ESP. Includes: Outer pans and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 4 1/2" XN and WLEG 7 of 8 anchor slips a 3 of 8 anchor bands 3/4" thick) and -x 1/8'thick). MPF -57A 4ES Orig. DF Elev. = 40.8'(N 22E) Orig. GL Elev. = 12.1' DF To 7" csg. hng. = 27.9'(N 22E) Casing landed on emergency slips w/ 230k down Howco 9 5/8"'ES' Cementer This well has been sidetracked from the original ormpletion. Min. ID in tubing is XN 275' @ 15,554'fter 145W '— Tbg top 45 KB Packer Kobe Knockout,pup joint, D&D Stinger DAL 10.82' Centrilift TTC-ESP Top (C 3.80":24.5 AOL Pump Type 112P6, 380 SXD TTC Drilled Tbg Crossover 4.5 NSTC PIN X45 521 WORILL BOX Upper Tandem Seal Sections Model GSB3 DB UT/HL H6 PFS Model MSPi Motor,120 HP, 3205 volt,23 amp, PumpMate w/6 fin Centralizer PumpMate ='TVD Baker 7" x 3.5" Premier Pkr. 2.87" ID 3.5" XN Nipple (2.75" No-go ID) 114,434.7- 14,455' 14, 523' 14,533' 14,547' 14,563' 15,531' 15,554' WLEG 15,562' Halliburton "VTA" Retrievable 15891' Packer - 3.880" I.D. Dual Weatherford 500 Micron Duragrip Screens 5947' - Note: 4ES RIH to 16070'. This is 6' above the fist Did not tag. 5-16-07 7" Weatherford float collar 16163' (PBTD) 7" Weatherford float shoe 16244' PROPOSED MILNE POINT UNIT WELL MPF -57A API NO: 50-029-22747-01-00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations Li Fracture StimulatLi Pull Tubing U Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ =rforate New Pool ❑ Repair We(—] Re-enter Susp Well ❑ Other: Install Tubing Patch ❑� 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic ❑ Exploratory ❑ Service ❑ 203-167 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22747-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025509 / ADL0355017 MILNE PT UNIT F -57A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 16,285 feet Plugs measured N/A feet true vertical 7,743 feet Junk measured 16,076 feet Effective Depth measured 16,076 feet Packer measured 15,531 & 15,891 feet true vertical 7,536 feet true vertical 7,015 & 7,355 feet Casing Length Size MD TVD Burst Collapse Conductor 115' 20" 115' 115' N/A N/A Surface 9,308' 9-5/8" 9,340' 4,621' 5,750psi 3,090psi Production 16,211' 7" 16,243' 7,702' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6# / L-80 Hydril 521 14,565' 6,351' Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 15,531'- 15,564' 7,015' - 7,046' Baker 7" x 3.5" Premier Packers and SSSV (type, measured and true vertical depth) VTA Retrievable 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 0 840 0 Subsequent to operation: 80 8 42 200 235 14. Attachments (requlrea per 20 AAc 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 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: 319-014 Authorized Name: Chad Helgeson Contact Name: Taylor Wellman -✓ Authorized Title: Operations Manager Contact Email: fW@Ilmant )hilcorp.com Authorized Signature: V�'-' Dale: 3/14/2019 Contact Phone: 777-8449 Form 10-404 Revised 4/2017 RBDMSZ�/MAR 2 0 2019 Submit Original Only Tree: 4 1/16" - 5M Cameron Wellhead: FMC 11- x 4.5" Tbg. Hanger: TC -B -EC 11"x 4.5" Atlas Bradford TC -II 4" CIW -Type H BPV profile 20" 91.1 ppf, H-40 115' 9 518" Whipstock top 9317' Window in 998" 9340.9356' 7" 0131`set b,9490' (Tubing Patch from 7,500' SLM to 7,519' N SLM. Set on 3/10/2019 u , 40 ppf, L-80 Btrc. 1 9340' KOP @ 500' Max. hole angle = 70 to 76 deg. f/ 3600'to 14,000' Hole angle thru' pelts = 11 deg. 4.5 12.6# L-80, Hydril.521 Tbg. (Drift ID= 3.958" ID, Cap =.0152 bpf) 7"26#, L-80, BTC casing (Drift ID = 6.151, Cap w/ tbg =.01 86 bpf) I Perforation Summary Ref log: 1/21/04 Size SPF Interval I (TVD) 3 3/8" 12 15,972'-15,982' 7,434'-7,443' Fish: Topes 15531' MD 5113/13 Baker 7" x 3.5" Premier Pkr. 2.87" ID MPF -57A Orig. DF Ell = 40.8'(N 22E) Orig. GL Elev. = 12.1' DF To 7" csg. hng. = 27.9'(N 22E) Casing landed on emergency slips wl 230k down Howco 9 5/8"'ES' Cementer Fish, Topes 16076' MD 6128106 Lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel �/ retrieved), 3 - 10' pups, 4 1/2" XN and WLEG 1 CTU cut lost parts4/20104: 7 of 8 anchor slips missing 2'x 1"x 3/4" thick) and 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). DATE I REV. BY I COMMENTS 4ES This well has been sidetracked from the original completion. Min. ID In tubing is XN 2.75'@ 15,554' NOTE� Severe doa lea 12890,13000' Tbg top 45 KB Packer (G I M 14,434.7' Kobe Knockout,pup joint, DRD Stinger OAL 10.82' Centrilift TTC-ESP Top (C 3.80' 24.5' AOL Pump Type 112P6, 380 SXD Drilled Tbg Crossover 4 -G PIN X4.5521 n RLLL BOX L r Tandem Seal Sections r GSB3 DB UT/HL H6 PFS F, , Model MSP1 Motor,120 HP, 3205 volt,23 amp, C PumpMate w/ 6 fin Centralizer PumpMate = TVD 1 Baker 7" x 3.5" 15,531' Premier Pkr. 2.87" ID 3.5" XN Nipple 15,554' (2.75" No-go ID) HE WLEG 15,562' Halliburton "VTA" Retrievable 15891' Packer- 3.880" I.D. Dual Weatherford 500 Micron 15947'- Duragrip Screens 16007' Note: 4ES Rift to 16070'. This is 6' above the fish Did not tag. 5-16-07 7" Weatherford float collar F16163' (PBTD) 7" Weatherford float shoe F 16244' WELL MPF -57A API NO: 50-029.22747.01-00 [a Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig AN Number Well Permit Number StartDate End Date MP F -57A E -Line 50-029-22747-01-00 203-167 2/4/2019 3/10/2019 Daily Operations. 1/30/2019- Wednesday No activity to report. 1/31/2019 - Thursday No activity to report. 2/1/2019 - Friday No activity to report. 2/2/2019 -Saturday No activity to report. 2/3/2019 -Sunday No activity to report. 2/4/2019 - Monday "WELL S/I ON ARRIVAL(leak detect) PT PCE 300LP-1,500HP. RAN COLLAR LOG AND PINPOINT LEAK AT 7,514' RKB WITH GR/CCL/SPIN/TEMP/PRESSURE TOOLS. LEAK FOUND 6' FROM THE TOP OF JOINT #186. 2/5/2019 -Tuesday PT PCE 250LP-2,500HP(good). ATTEMPTED TO SET LOWER ANCHOR, ELINE HIGH STRANDED WHILE RIH. ELINE PARTED WHILE REPAIRING ARMOR BELOW GREASE HEAD. 1875' FEET OF 1/4" CABLE LEFT IN HOLE. 25.32' OAL, 1-3/8" FN. LOOKING UP. WELL LEFT 5/I ON DEPARTURE. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number I Start Date End Date MP F -57A E -Line 50-029-22747-00-00 203-167 2/4/2019 3/10/2019 Daily Operations. 2/6/2019 - Wednesday PT PCE 250L/3,000H**. DRIFT TBG W/ 3.85" CENT & 5/D ON TOP OF CUT WIRE @ 3,804' SLM. RUN 3.85" CENT & 4-1/2" WIRE FINDER, 5/D ON TOP OF WIRE @ 3807' SLM, BEAT WIRE DOWN TO 3,825' SLM. 2/7/2019 - Thursday No activity to report. 2/8/2019 - Friday No activity to report. 2/9/2019 -Saturday No activity to report. 2/10/2019 -Sunday PT PCE 250L/3,000H**. FISH E -LINE TOOLSTRING W/ 4-1/2" WIRE FINDER, 2.62" 3 PRONG WIRE GRAB (6 -barbs) FROM 3,830' SLM. HOIST E -LINE TOOLS OUT OF WELL AFTER E -LINE RECOVERS CUT WIRE. 2/11/2019 - Monday No activity to report. 2/12/2019 -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-57A E-Line 50-029-22747-00-00 203-167 2/4/2019 3/10/2019 Daily Operations. 2/13/2019- Wednesday No activity to report. 2/14/2019 - Thursday No activity to report. 2/15/2019 - Friday No activity to report. 2/16/2019 -Saturday No activity to report. 2/17/2019-Sunday No activity to report. 2/18/2019 - Monday No activity to report. 2/19/2019-Tuesday Pressure tested PCE to 30011 low / 2,700# high. Ran Packer in well to 4116.6' before needing to pump down, started pump rate at .5 BBL/Min and increased to 2 BBL/Min. as packer progressed down hole. Set down @ 7510.8' Mid Element of packer (top @ 7,509'), attempted multiple attempts to get deeper while pumping with no success. Set 4.5" Quadco Paragon II pkr . at 7,510.8 MD (mid element) (Correlated to AK E-Line LDL dated 2/4/19) (Pkr specs = 3.76" Max OD / 4.89" OAL / 2.0" ID) (Takes a 4.5" Paragon II pulling too to pull) LRS pumped down tbg and still indicating that hole isn't covered up. Well left shut in upon departure - notified pad op of well status. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-57A E-Line 50-029-22747-00-00 203-167 2/4/2019 3/10/2019 Daily Operations. 2/20/2019- Wednesday No activity to report. 2/21/2019 - Thursday No activity to report. 2/22/2019 - Friday No activity to report. 2/23/2019-Saturday No activity to report. 2/24/2019-Sunday No activity to report. 2/25/2019 - Monday No activity to report. 2/26/2019-Tuesday ***WELL S/I ON ARRIVAL***(set quadco paragon II packer). PT PCE TO 250psi LOW, 2,750psi HIGH (pass) SET UPPER SECTION OF PARAGON PACKER PATCH ASSEMBLY INTO LOWER PACKER. TOP OF UPPER SECTION SET @ 7,493' MD. USED LRS TO PUMP TOOLS DOWN HOLE. ****UPPER PKR / PATCH ASSEMBLY SPECS = 17.14' OAL / 3.76" Max OD / 2.0" Min ID.**** ***PAD-OP NOTIFIED OF DEPATURE AND TO POP WELL. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPI Slick Line 50-029-22747-01-00 203-167 2/4/2019 3/10/2019 Daily Operations. 3/6/2019 - Wednesday No activity to report. 3/7/2019 - Thursday PT PCE 250L/3,000H**. ATTEMPT TO PULL PATCH, UNABLE TO WORK GET PAST 1918' SLM. UNABLE TO GET IMPRESSON WITH 3.70" & 3.48" LIB. WORK 5'x 3.0" DRIVE DOWN BAILER, FLAT BALL BTM FROM 1,925' SLM TO 2,369' SLM, RECOVER 8 CUPS OF THICK SCHMOO & HYDRATES. 3/8/2019 - Friday PT PCE 250L/3,000H**. *LRS PUMP 70 BBL's OF PRODUCED WATER & 45 BBL's OF HOT DIESEL DOWN TBG*. PULL 4-1/2" PARAGON II PACKER (UPPER SECTION, CAL = 17.14') FROM TBG @ 7,491' SLIM. PULL4-1/2" PARAGON II PACKER (LOW E SECTION, OAL = 4.89') FROM TBG @ 7,506' SLM. 4 1 3/9/2019 -Saturday 412 PT PCE 250L/3,000H**. RUN 3.61" CENT, 1.75" SAMPLE BAILER, 3 STRAND PONYTAIL ROPE (12"), STOP @ 7,600' SLM BEGIN TO PUMP. DIESEL W/ LRS DOWN TBG @ .5BBLs A MIN, POOH @ 50fpm, SEE 300# OVERPULL @ 7,510' SLM (HOLE IN TBG), FLAG WIRE. 3/10/2019 -Sunday PT PCE 250L/3,000H**. SET 4-1/2" PARAGON II PACKER (LOWER SECTION, DAL = 59") ELEMENT @ 7,517' SLM. SET 4-1/2" PARAGON II PACKER (UPPER SECTION, CAL = 206") IN LOWER PARAGON II PACKER @ 7,514' SLIM. ELEMENT @ 7,502' SLM. 3/11/2019 - Monday No activity to report. 3/12/2019 -Tuesday No activity to report. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU F -57A Permit to Drill Number: 203-167 Sundry Number: 319-014 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the 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. eamount, Jr. Commissioner DATED this I Vdayof January, 2019. RBDMS"-V W I I I" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AN 15 2019 AOGCC� 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: Install Tubing Patch ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 203-167 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22747-01-00 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 Q MILNE PT UNIT F -57A 9. Property Designation (Lease Number): 10. Field/Pool(s): r ADL0025509 / ADL0355017 I MILNE POINT/ KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 16,285' 7,743' 16,076' 7,536' 1,000 N/A 16,076' Casing Length Size MD TVD Burst Collapse Conductor 115' 20' 115' 115' N/A N/A Surface 9,308' 9-5/8" 9,340' 4,621' 5,750psi 3,090psi Production 16,211' 7" 16,243' 7,702' 7,240psi 5,41 opsi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" 12.6# / L=80 Hydril 521 14,565' See Schematic See Schematic 3-1/2" 9.3# / L-80 15,531'- 15,564' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Faker 7"x 3.5" Premier & VTA Retrievable and N/A 15,531MD/ 7,015TVD & 15,891MD/ 7,355TVD and N/A 12. Att6chments: Proposal Summary a Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed OperaGnns Program- ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/25/2019 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman Tfi`J Authorized Title: Operations Manager Contact Email: twellmaD hilcor .Com Contact Phone: 777-8449 Authorized Si natur Q,�� a Date: 1/15/2019 COMMISSION USE ONLY , + Conditions of appy al: Notify Commission so that a representative may witness Sundry Number: I„ U ,„ I L11 (_A1 Plug Integrity ❑ BOP Test E] Mechanical Integrity Test E] Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No NK Subsequent Form Required: /O _. J sOy APPROVED BY Approved by: ilyCOMMISSIONER THE COMMISSION Date. J 1 RBUMSSt-IAN 2 1 1019�/-/7_ Submit Form and Ra Form 10-403 Revised 4/2017 Approved applicaQ dr, op the date of approval. Attachments in Duplicate �`IRa%Iica U Hfl om Alaska, LU Tubing Patch Well: MPF -57A PTD: 203-167 API: 50-029-22747-01 Well Name: MPF -57A API Number: 50-029-22747-01 Current Status: SI Rig: SL Estimated Start Date: Jan 25, 2019 Estimated Duration: 2 days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: N/A Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 203-167 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Current Bottom Hole Pressure: MPSP: Recent. SI Surface Pressure: Min ID: Brief Well Summary: 3,676 psi @ 7,000' TVD (Downhole gauge reading on 01/14/2019) 1,000 psi (Max recent surface pressure) —1,000psi (Taken 01/02/2019) 3.958", Drift ID of tubing down to the top of the TTC-ESP MPF -57A is a Kuparuk producer with a thru-tubing ESP. The well does not have a production packer. The ESP failed to surface fluids and the pump section was changed out with coil tubing. After setting the packoff on the pump sections the tubing failed to pressure test. An LDL was run which identified a hole in the tubing at 7,510' md. Notes Regarding Wellbore Condition: • A caliper was run on the well which shows over 50 joints with 40-82% wall penetrations. The highest penetration recorded was 82% at 7,508' md. Objective: Set patch over hole at 7,510' and Procedure: Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and 1,500 psi high 3. RIH with leak detect tool. Bring pumps online and find leak depth. Flag wire at leak depth and POOH. 4. RIH and set slipstop at ±7,514 md. 5. Sting into and set lower packoff. 6. Set 10'x 2-7/8" spacer pipe with stinger (upper packoff). a. It maybe possible to use 3-1/2" spacer pipe. 7. Set slipstop. Coordinate with operations to start ESP to check for surfacing fluids prior to rig down. 8. RD SL unit. Attachments: 1. As -built Schematic 2. Proposed Schematic Tree: 41/16" -5M Cameron Wellhead: FMC 11"x 4.5" Tbg. Hanger: TC -B -EC 11"x 4.5" Atlas Bradford TC -II 4" CIW - Type H BPV profile 20" 91.1 ppf, H-40 9 518" Whipstock top 9317' Window in 9 518'9340-9356' 7" CIBP set @ 9490' 9 5/8", 40 ppf, L-80 Btm. 9340' 4.5 12.6# L-80, Hydril 521 Tbg. (Drift ID= 3.958" ID, Cap = .0152 bpf) 7" 26#, L-80, BTC casing (Drift ID = 6.151, Cap w/ tbg = .0186 bpf) Perforation Summary Ref log: 1/21/04 Size SPF Interval (TVD) 3 3/8" 12 15,972'-15,982' 7,434'-7,443' Fish: '13/13 Baker 7" x 3.5" Premier Pkr. 2.87" ID Fish: Top Q 16076' MD 6/28106 Lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 -10' pups, 4 1/2" XN and WLEG 3 of 8 anchor ban DATE I MPF -57A missing (2' x V x 3/4' thick) and i1NV ds missing (12" x V x 1/8" thick). REV. BY I COMMENTS new -4ES Ong. DF Elev. = 40,8'(N 22E) Ong. GL Elev. = 12.1' DF To 7" csg. hng. = 27.9'(N 22E) Casing landed on emergency slips w/ 230k down Howco 9 5/8"'ES' Cementer .. Tbg top 45 KB Packer Kobe Knockout,pu olnt, D&D Stinger OAL 1Ds2' Cen ESP Top (C 3.80. 24.5' AOL Pump Type 112P6, 380 SXD TTC Drilled Tbg Crossover 4.5 NSTC PIN X4.5521 HYDRILL BOX Upper Tandem Seal Sections Model GSB3 DB UT/HL H6 PFS Model MSP1 Motor,120 HP, 3205 volt,23 amp, PumpMate w/6 fin Centralizer PumpMate ='TVD Baker 7" x 3.5" Premier Pkr. 2.87" ID 14,434.7' 15,554' WLEG 15,562' Halliburton "VTA" Retrievable Packer - 3.880" I.D. Dual Weatherford 500 Micron Duragrip Screens Note: 4ES RIH to 16070'. This is V above the fist Did not tag. 546-07 7" Weatherford float collar 16163' (PBTD) 7" Weatherford float shoe 16244' MILNE POINT UNIT WELL MPF -57A API NO: 50-029-22747-01-00 Tree: 41/16" -5M Cameron Wellhead: FMC 11" x 4.5" Tbg. Hanger: TC -B -EC 11"x 4.5" Atlas Bradford TC -II 4" CIW - Type H BPV profile 20" 91.1 ppf, H-40 115' 9 518" Whipstock top 9317' Window in 9 5/8'9340-9356' TOP set @ 9490' ITubina Patch from ±7,504'to ±7,514'1 9 5/8", 40 ppf, L-80 Btrc. 9340' KOP @ 500' Max. hole angle = 70 to 76 deg. f/ 3600' to 14,000' Hole angle thru' perfs = 11 deg. 4.5 12.8# L-80, Hydril 521 Tbg. (Drift ID= 3.958" ID, Cap = .0152 bpf) 7" 26#, L-80, BTC casing (Drift ID = 6.151, Cap w/ tbg =.0186 bpf) IPerforation Summary Ref log: 1/21/04 Size SPF Interval (TVD) 3 3/8" 12 15,972'-15,982' 7,434'-7,443' Fish, TopIll 15 "1S +SMD 51ill s Baker 7" x 3.5" Premier Pkr. 2.87" ID Fish- Top0 16076' MD 6/28106 Lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 4 1/2" XN and W LEG CTI I cunt lost Darts 4/20/04: 7 of 8 anchor slips missing (2" x 1" x 3/4" thick) and 3 of 8 anchor bands missing (12" x V x 1/8" thick). MPF -57A Ong. DF Elev. = 40.8' (N 22E) Orig. GL Elev. = 12.1' DF To 7" csg. hng. = 27.9'(N 22E) Casing landed on emergency slips w/ 230k down Howco 9 5/8"'ES' Cementer This well has been sidetracked from the anginal completion. Min. ID in tubing is XN 2.7F ®15,554' Tbg top 45 KB Packer (CTM 14,434.7' Kobe Knockout,pu olnt, D&D Stinger DAL 10.82 Cell ESP Top (CTM114 3.80" 124.6 AOL Pump Type 112P6, 380 SXD TTC Drilled Tbg Crossover 05 Ni PIN X4.5521 HYDRILL BOX L Upper Tandem Seal Sections Model GSB3 DB UT/HL H6 PFS 1 Model MSP1 Motor,t20 HP, 3205 volt,23 amp, PumpMate w/ 6 fin Centralizer PumpMate ='TVD Baker 7" x 3.5" 15,531' Premier Pkr. 2.87" ID 3.5" XN Nipple 15,554' (2.75" No-go ID) WLEG 15,562' Halliburton "VTA" Retrievable 15891' Packer- 3.880" I.D. Dual Weatherford 500 Micron 15947'- Duragrip Screens 16007' Note: 4ES RIH to 16070'. This Is 6' above the fish, Did not tag. 5-16-07 7" Weatherford float collar 16163' (PBTD) 7" Weatherford float shoe 16244' MILNE POINT UNIT WELL MPF -57A API NO: 50-029-22747-01-00 STATE OF ALASKA ,. ‘!-. •.. . ` -' AKA OIL AND GAS CONSERVATION C•ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing * ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver . ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Pull Jet Pump / Run ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. . ❑ Exploratory ❑ Stratigraphic 203 -167• 3. Address: . ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50. 029 - 22747 - 01 - 00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 355017 MPF -57A , 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 16285' feet. Plugs:(measured) None feet true vertical 7743' feet Junk: (measured) 16076' feet Effective depth: measured 16163' feet Packer: (measured) 15531', 15891' feet true vertical 7622' feet Packer: (true vertical) 7015, 7355 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' Surface 9308' 9 -5/8" 32' - 9340' 32' - 4621' 5750 3090 Intermediate Production 16211' 7" 32' - 16243' 32' - 7702' 7240 5410 Liner SCANNED .iUL 2 2 2013. Perforation Depth: Measured Depth: 15972' - 15982' feet True Vertical Depth: 7434' - 7444' feet Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# / 3 - 1/2 ", 9.3# L -80 14565' / 15531' - 6351' / 7015' - 15564' 7045' Packers and SSSV (type, measured and true vertical depth): Re ne able Packerremier Packer & Halliburton'VTA' 15531', 15891' 7015, 7355' Dual Weatherford 500 Micron Duragrip Screens 15947' - 16007' 7410' - 7468' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 50 0 Subsequent to operation: 183 18 59 50 0 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: • ® 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 Name: Lastufka Title: Drilling Technologist / 2 Signature: Phone: 564-4091 Date: 6/6/13 Form 10-404 Revised 1 012 )71 -one: 773/ 3 ',V, RBDMS JUN - 7 20 , Submit Original Only • • '',4)", 4,4;a0 / 11:- "; • • e/2407745': 1 //;' , "/ Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/18/2013 08:30 - 11:00 2.50 MOB P PRE FINISH RIGGING DOWN. SECURE CELLAR. PREP TO JACK UP RIG. BUILD A RIG MAT RAMP SO THE RIG CAN MOVE OFF THE WELL. 11:00 - 12:30 1.50 MOB P PRE PJSM THEN JACK UP RIG AND MOVE OFF WELL. MOVE OFF WELL WAS WITNESSED BY TOOLPUSHER AND WSL. MOVE RIG DOWN THE PAD AND SET DOWN. 12:30 - 00:00 11.50 MOB P PRE BUILD UP GRAVEL AROUND WELLHEAD BY 6". - LAY RIG MATS TO LIFT RIG 24" ABOVE PAD LEVEL - WORK ON MUD PUMP #1, INSPECT MUD ENDS, GEARS AND CROSS HEADS - CHANGE OUT SWAB AND LINER, C/O VALVE AND VALVE SEAT, CHANGE OUT PONY ROD - WELD GUARD IN PLACE IN MEZZANINE - TIGHTEN 11° FLANGE ON BOP H CLEAN RIG, PERFORM WORK ORDERS CLEAR SNOW OFF OF #2 MUD PUMP SKID AND R/U AIR HEATER 4/19/2013 00:00 - 03:30 3.50 MOB P PRE PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - LAY RIG MATS TO LIFT RIG 24" ABOVE PAD LEVEL - COMPLETE WORK ON MUD PUMP #1 - CLEAN RIG, PERFORM WORK ORDERS 03:30 - 05:30 2.00 MOB P PRE PJSM MOVING RIG OVER WELL - PAD OPERATOR NOTIFIED, DAY AND NIGHT TOOLPUSHERS PRESENT, WSL - MOVE RIG ON STEP UP MATS AND ONTO FULL MAT BOARD HEIGHT - SPOT RIG OVER WELL, MPF-57 05:30 - 08:00 2.50 MOB P PRE LOWER CELLAR DOORS AND STAIRS - REMOVE STEP UP MATS TO MAKE ROOM FOR CHANGE AND FUEL TRAILERS - RIG ACCEPT AT 06:00 HOURS 08:00 - 09:30 1.50 MOB P DECOMP SHIM RIG AND WEATHERPROOF CELLAR. RIG UP CIRC OUT SKID. 09:30 - 10:00 0.50 MOB P DECOMP CONDUCT RIG EVAC WITH JESSIE'S CREW, CH2 DRIVERS AND WELLS SUPPORT CREW. ALL PERSONS ACCOUNTED FOR IN 2 MIN. CONDUCT AAR AFTERWARDS. 10:00 - 12:30 2.50 WHSUR P DECOMP MOVE FLOVVBACK TANKS INTO POSITION AND RIG UP LINES AND MANIFOLD. INSTALL DE-MISTER. FLOOD LINES WITH DIESEL. 12:30 - 13:30 1.00 WHSUR P DECOMP PRESSURE TEST ALL LINES TO 250 / 3500 PSI, GOOD. 13:30 - 16:00 2.50 WHSUR P DECOMP INSTALL BPV LUBRICATOR AND PRESSURE TEST 250 / 3500 PSI, GOOD. PULL BPV. TUBING = 90 PSI, IA= 100 PSI, OA = 50 PSI. 16:00 - 16:30 0.50 KILLW P DECOMP PJSM FOR 1NELL KILL OPERATIONS. Printed 5/20/2013 10:10:52AM • :V• :; - '".'"W"t4r j« ; ,M:7010:01.*50.*W504'(.4 / 7",, 7/1 : • 1 06** 10140# Common Well Name: MPF-57 AFE No Event Type: WORKOVER (\NO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. U1M: Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 20:00 3.50 KILLW P DECOMP CIRCULATE WELL AS PER PROGRAM. - PUMP 500 BBLS 100 DEGREE 12.0 PPG BRINE DOWN TUBING TAKING RETURNS FROM IA, THRU CHOKE, OUT TO FLOWBACK TANK - PUMP AT 3 BPM, ICP TUBING = 625 PSI, ICP IA = 300 PSI, FCP TUBING = 500 PSI, FCP IA = 100 PSI -0 BBLS LOSS ON CIRCULATION - OA = 320 PSI 20:00 - 20:30 0.50 KILLW P DECOMP MONITOR WELL FOR 30 MINUTES - VERIFY WELL IS ON A SLIGHT VACUUM 20:30 - 21:00 0.50 KILLW P DECOMP BLOW DOWN AND R/D ALL CELLAR CIRCULATING LINES - BLOW DOWN AND RID KILL MANIFOLD '- VAC OUT FLOW BACK TANK 21:00 - 00:00 3.00 WHSUR P DECOMP R/U DSM LUBRICATOR - TEST 250 / 3500 PSI, 5 MIN, CHARTED - INSTALL TWC - ROLLING TEST FROM BELOW, .5 BPM = 500 PSI, 10 MIN, 10 BBLS PUMPED AWAY - TEST FROM ABOVE, 250 / 3500 PSI, 5 MIN I CHARTED - OA = 180 PSI - LOSS RATE =4 BPH - 24 HOUR FLUID LOSS = 14 BBLS 4/20/2013 00:00 - 02:00 2.00 WHSUR P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - NIPPLE DOWN FMC 11" X 3 1/8" ADAPTER FLANGE & 3 1/8" MCEVOY 5M TREE - FMC REP CLEAN AND INSPECT 3 1/2" TC-2 HANGER THREADS - CONFIRM 81/2 RH TURNS BY HAND I - OA = 0 PSI 02:00 - 05:00 3.00 BOPSUR P DECOMP N/U 13 3/8" BOP STACK AND RELATED EQUIPMENT - R/U TEST EQUIPMENT AND FLOOR VALVES FOR BOP TEST 1- RE-ENERGIZE ACCUMULATOR SYSTEM. Printed 5/20/2013 10:10:52AM t . _ • �'�; '��: % „' :f ?x t' �� +�j;; "vv �/ 'E�i "� "Pi .`�`: , � a.,. .>i" r , iri. /'✓� .�; / / /�. / / /, „/.� ✓r/ /� �' ", : i: ` %% . / -Q.. " " ✓r / /ma;> "t±,/ ` ✓'.,, �GIrF , -r ,%/ , / i r -✓ >.,. rkr/,.. ,•,sR, %�, /, ... /. �... , ,r'i�+v� 3 / ' . ". y �b.., ; %r,.yr /�r��rj7�> fr � �, �w 5 �i /, ;..? % /;' ;;y 4 ✓ ✓;!� air "> �?;,✓ /r / /!-lF/ .. / .o r te. / / / ,,/j tic, oFr% % ; rj /.. ,�,,'. �a� - ✓i, „�' ,% � 4 ,,� '.� „ f.., ; �1% ,.! ?r1i. ' 'f�r / / „i L;_.fGty:,,:;: / Vi �, ,, % /r /' % %'%' ��%;: 'ti�' .�.ri-`.�/ �� s ' � � �, / , / // r ra G � � - .�,. %mi <:xxr " ";,!!X" � / ' ` r r Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4 /18/2013 End Date: 5 /11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date /me: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 11:30 6.50 BOPSUR P DECOMP PJSM, TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT - BOP CONFIGURATION = ANNULAR, 2 7/8” X 5” VBR UPPER PIPE RAMS, BLIND SHEARS, MUD CROSS, 2 7/8” X 5" VBR LOWER RAMS - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES -TEST ANNULAR WITH 3 1/2” TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - TEST UPPER AND LOWER 2 7/8” X 5" VARIABLE RAMS WITH 3 1/2" AND 4 1/2" TEST JOINTS, 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. - BOB NOBLE. OF AOGCC WAIVED STATES RIGHT OF WITNESS FOR BOP TEST 4/19/2013 18:00 - MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST WITH 12.0 PPG BRINE, LOSS RATE = 1- 2 BPH 11:30 - 12:00 0.50 BOPSUR P DECOMP PERFORM ACCUMULATOR DRAWDOWN TEST. TEST IS WITNESSED BY TOOLPUSHER AND WSL.12:00 12:00 - 13:00 1.00 WHSUR P DECOMP CREW CHANGE AND EQUIPMENT CHECKS. INSTALL DUTCH RISER AND TWC LUBRICATOR. 13:00 - 14:30 1.50 WHSUR P DECOMP PRESSURE TEST LUBRICATOR 250 / 3500 PSI, GOOD. TRY TO ENGAGE TWC PROFILE WITH PULLING TOOL, CAN'T ENGAGE. 14:30 - 15:30 1.00 WHSUR N SFAL DECOMP REMOVE DUTCH RISER. VAC OUT STACK TO LOOK FOR DEBRIS IN TWC PROFILE. GET CENTRALIZER FROM MILNE PT WELL SUPPORT SHOP FOR PULLING TOOL EXTENSION BARS. 15:30 - 16:30 1.00 WHSUR N SFAL DECOMP ASSEMBLE TWC PULLING TOOL WITH CENTRALIZER. MAKE UP TWC LUBRICATOR AND PT 250 / 3500 PSI, GOOD. PULL TWC. WELL IS ON A VAC. 16:30 - 17:30 1.00 PULL P DECOMP PJSM THEN MAKE UP LANDING JOINT. SCREW IN TO TOP DRIVE. PULL HANGER TO FLOOR AND POSITION SLICK PIPE ACROSS BOP 95K UP WT TO START PIPE MOVING, 100K STEADY UP WEIGHT AFTER THAT 17:30 - 19:30 2.00 PULL P DECOMP CLOSE ANNULAR AND CBU 1XTHRU GAS BUSTER - 3 BPM = 450 PSI, 11 BBLS LOSS DURING CIRCULATION 19:30 - 20:00 0.50 PULL P DECOMP MONITOR WELL 10 MIN, WELL IS STATIC - BLOW DOWN TOP DRIVE AND CHOKE MANIFOLD - LID LANDING JOINT AND HANGER Printed 5/20/2013 10:10:52AM • • r i , ;, ! . y . i ' � / ; / 6' ru �, J r N �A+ " i 9 �'/Y, "�' 1, may., ip,� ; % r �� . .. %ri . /i�, ",f?� /fr / /. 'C / � ' 1 ��, ':� ,. -5 / /.<.l�'�, '.",,//�l+rr, - 9i ii i ,z X .at' �:�. , r„ "ili. %, ;'l; /,i s/�f', .�Jr� r� '•�. i� %iii ",.lv> �,. �1 f� %i�,, rii�7"', 7 r:; E .." +�": �,/ "% ti %',° =�� :. / ,/.3' > f� „ n... ! // �.� • : / : . � ' %. N, .fi .� ��,i 'a}' . ✓ s7 / �,y, ilf /r// r / ry .1 i,. -, „,- i ��si. .t. %;', r� s, /, , / g rf 4 • ' ' , -yy'./ 4y , � ., /. -i?;;, %' � , *; >� ; ':Ki r �„ o' -�� ?€q:' "l , t � , `� , . , ; Sr,;ir ✓ , 1" �u 9 ii y /�/ a 3t ,; s ,,,. q:.i /:.. %� . `tt .,,,o %ri /�,., /,�, ..,,a. % - ,re5 „ ^.-, t,,..s-ri/ .,, ✓.,i.l= „Y.i .s. // .> % ./� ter ,.yieaiir /i �uJirl /r1, / „r'k /�./� , = Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4- 00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 00:00 4.00 PULL P DECOMP PJSM, VD 3 1/2” 9.3# L -80 IBT -M TUBING 1X1 - FROM CUT AT 12265' TO 9449' MD - PUWT = 85K, SOWT = 80K OA =0PSI - LOSS RATE = 3 BPH - 24 HOUR FLUID LOSS = 88 BBLS 4/21/2013 00:00 - 00:30 0.50 PULL P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - SERVICE RIG EQUIP 00:30 - 10:30 10.00 PULL P DECOMP POOH AND VD 3 1/2” 9.3# L -80 IBT -M TUBING 1X1 - FROM 9449' TO SURFACE - 385 JTS TUBING LAYED DOWN, CUT JT = 5.29, 4” FLARE ON CUT - LOSS RATE = 3 BPH 10:30 - 15:00 4.50 PULL P DECOMP BRING JT #385 TO FLOOR, AND CUT JOINT IS 5.29 FT. CLEAR RIG FLOOR, PREP TO RUN BHA #1. INSTALL WEAR BUSHING, ID = 6.87" LOAD OUT REMAINING 3 -1/2" TUBING THAT WAS LAID DOWN. LOAD REMAINING 4" DP ON RIG OFF DRILLER'S SIDE. LOAD BAKER TOOLS ONTO RIG, SORT AND STRAP. 15:00 - 19:30 4.50 FISH P DECOMP PJSM FOR M/U BHA #1. MAKE UP BHA #1, WASH OVER SHOE WITH 7 JTS WASHOVER PIPE, 2 BOOT BASKETS, BUMPER JAR, OIL JAR, 6 DRILL COLLARS, ACCELERATOR, 4" DP BACK TO SURFACE. 19:30 - 21:00 1.50 FISH P DECOMP PJSM, SLIP AND CUT DRILLING LINE - INSPECT DRAW WORKS AND TOP DRIVE 21:00 - 00:00 3.00 FISH P DECOMP P/U AND RIH WITH 4" DRILL PIPE 1X1 - FROM BHAAT 448' TO 2881' MD -OA =40 PSI -LOSS RATE =3BPH - 24 HOUR FLUID LOSS = 72 BBLS 12 PPG BRINE 4/22/2013 00:00 - 00:30 0.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS _ ! - SERVICE RIG 00:30 - 06:00 5.50 FISH P DECOMP P/U AND RIH WITH 4" DRILL PIPE 1X1 - FROM 2881' TO 6770' MD - MIRU #2 MUD PUMP MODULE 06:00 - 10:30 4.50 FISH P DECOMP CONTINUE M/U 4" DP SINGLES FROM PIPE SHED. STOP AT 1030 TO FIX IRON ROUGHNECK. 10:30 - 11:00 0.50 FISH N RREP DECOMP I IRON ROUGHNECK DRIVE GEAR ON BASE OFF DRILLERS SIDE HAS GOTTEN ONE SLOT OUT OF ALIGNMENT FROM THE DRILLERS SIDE. PJSM THEN ADJUST GEAR BACK INTO POSITION. 11:00 - 14:45 3.75 FISH P DECOMP CONTINUE MAKE UP 4" DP SINGLES FROM PIPE SHED. Printed 5/20/2013 10:10:52AM • • M ;: %r..!,,r, `,C .!v✓.; %°,. / :sY°r�rs ��,s! y ` , ,, y / %i /� `:�1�' $`;,. ..; /moo"' ., • , % ;�,'/,ru , is rrrist�yp� „A� %%C > >i / ` 4 � o':x'- %,r ,i- .y C /� fi , ` � , '% � '�' � �� /� /� / %,e. ,ua ,,r✓'.-/ .; 1- � %i / -li %r. % ; r, {; / /,✓>.-:r /�±3;T's - Ff'i' // • «o -; /; .'r %. s: /' y.1tr y s %' 1�: ,ii,, aw ..`% rW- / n l i .,; / rri f r,:;� /��.r..ii %r / ///- ..,, r�,' ��/,, 6�..�,.,,,,�,�,,,,�,.��/��,� ��yi,.. Common Well Name: MPF -57 AFE No Event Type: WORKOVER MO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code F NPT NPT Depth I Phase Description of Operations (hr) (usft) 14:45 - 15:30 0.75 FISH P DECOMP SLOW RUNNING SPEED AT 12218 FT. CHECK UP WT IS 168K, DOWN WT IS 85K. CONTINUE RIH ON ELEVATORS TO 12352 FT, SLACKOFF IS 7K HERE. 15:30 - 16:00 0.50 FISH P DECOMP PICK UP AND ATTACH TOP DRIVE. PUMP 3 BPM = 460 PSI. i ROTATE 50 RPM DOWN TO 12357 FT, SLIGHT WT BOBBLES AND TORQUE SEEN. PICK UP AND RIH TO SAME DEPTH SLIDING, CLEAN. 16:00 - 17:30 1.50 FISH P DECOMP PICK UP JT #378, EASE DOWN FROM 12358 FT. SLOW PROGRESS, ALLOW WT ON BIT AND TORQUE TO DRILL OFF EACH TIME. 17:30 - 20:00 2.50 FISH P 1 DECOMP MILL OVER COLLAPSED 31/2" TUBING FROM 12355' TO 12378' MD " - PUWT = 168K, SOWT = 85K, 60 RPM = 8K FREE TORQUE - PUMP 3 BPM = 460 PSI, 70 RPM = 12K TORQUE WHILE MILLING, 5-10K WOB - SET DOWN SOLID AT 12378' MD, 60 RPM, TORQUE FELL BACK TO FREE TORQUE AT 8K - SLIDE OVER MILLED AREA WITHOUT ROTARY OR PUMPS = GOOD - POOH AND ATTEMPT TO ESTABLISH TOP OF STUMP, UNSUCCESSFUL - SLIDE BACK DOWN TO VERIFY DRIVE BUSHING TAG AT 12378', SET DOWN 10K - CONTACT ODE AND DECIDE TO POOH AND ADD 4 MORE JOINTS OF WASH PIPE 20:00 - 22:00 2.00 FISH P DECOMP CIRCULATE HI -VIS SWEEP SURFACE TO SURFACE - MINIMAL FINE METAL BACK WITH SWEEP - 6 BPM = 1490 PSI, R &R PIPE 80' DURING CIRCULATION - PUMPS OFF, MONITOR WELL 10 MIN, WELL IS STATIC 22:00 - 23:30 1.50 FISH P DECOMP POOH 5 STANDS, FROM 12378' TO 11898' MD - MONITOR WELL 10 MIN, WELL IS STATIC - BLOW DOWN TOP DRIVE AND KILL LINE - POOH FROM 11898' TO 10022' MD 23:30 - 00:00 0.50 FISH P DECOMP CLEAN RIG FLOOR OF SODIUM BROMIDE BUILD UP - USE FRESH WATER AND OVERBOARD TO CUTTINGS TANK - OA = 40 PSI - LOSS RATE = STATIC AT 24:00 HRS - 24 HOUR FLUID LOSS = 62 BBLS 12 PPG BRINE 4/23/2013 00:00 - 00:30 0.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - SERVICE RIG 00:30 - 04:30 4.00 FISH P DECOMP POOH FROM 10022' TO 448' (BHA) - STOP AND MONITOR WELL 10 MINUTES BEFORE PULLING BHATHRU STACK - SAFETY JOINT READY FOR USE WITH NON - SHEARABLES ACROSS STACK Printed 5/20/2013 10:10:52AM • • ;.rr. ".. „rr. <•o "...; / rn . -, o,,,;- ion, >HV,rfa �.; : /l; .r/ /// `¢X rhq ."-o op,.. ;,7. i + /Y /'.. ' "' / / 4: 'r H "" Y , ,�, .. / , g ; /, �%i /;` ;��.%i/f�ii /r:;;oG';:;'/h,'„ % G, B:��r /�rtr'/ /•�,. x's . ^y;' y %� / n :i /' %� /or �, / r /� /rr, ,,g,0017 ,,Wee Sri .r , < r , a r. �yj� r � /,v /, '6s/L; r, /. .� /� / / /.x �. 7i, ra t. .,,, ,.., r,, a/. ✓/, ,, /r., .. ,., /% j, : . / „a . �' !�a f:.. ;'.:'^ / - r.v. -.FY” /. : %.. /.> iGilr.. < <% 2;:.1j:`f, . � %i" %,,a. ; %y� (., lrr /l/ "�. H. :, Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table r©D40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (usft) 04:30 - 06:00 1.50 FISH P DECOMP PJSM, UD FISHING BHA #1 - M/U 1 JOINT OF HWDP TO TOP OF 2 COLLARS FOR SAFE HANDLING, STAND COLLARS IN DERRICK 06:00 - 10:00 4.00 FISH P DECOMP UD FISHING BHA #1 NO MARKS ON DRIVE SUB TO INDICATE PIPE 1 STUB MADE IT THAT FAR. CONTINUE UD WASH PIPE. FIND A PIECE OF 3-1/2 TUBING INSIDE THE LOWER 3 JTS OF WASH PIPE. UD WASH PIPE, CUT AND RETRIEVE 3-1/2 TUBING OUT OF IT. RECOVER 75.3 FT OF TUBING, OF WHICH THE LOWER 18 FT IS COLLAPSED. THIS INDICATES THAT THE TOP OF THE STUMP WAS AT - 12303' MD RECOVER AN 8 FT PIECE OF SLICKLINE FROM ONE OF THE JOINTS. 10:00 - 10:30 0.50 FISH P DECOMP DISCUSS FORWARD PLAN WITH ODE, I DECIDE TO RUN 4-1/2 ID WASHOVER SHOE WITH 10 JTS WASH PIPE. ASSEMBLE TOOLS ON RIG FLOOR, PREP TO RUN BHA #2. 10:30 - 13:30 3.00 FISH P DECOMP PJSM TO M/U FISHING BHA #2 - M/U 6" OD X 4 1/2” ID DRESS OFF SHOE - 10) 5 3/4" WASH PIPE - 2) BOOT BASKETS - 4 3/4" BUMPER SUB AND OIL JARS - FLOAT SUB WITH FLOAT - 6) 4 3/4" DRILL COLLARS - 3)4 "HWDP - ACCELERATOR JAR 13:30 - 15:00 1.50 FISH P ( DECOMP RIH ON DRILL PIPE - FROM BHA TO 3956' MD - FILL PIPE EVERY 2000' 15:00 - 16:00 1.00 FISH N WAIT DECOMP STOP RIG OPERATION DUE TO MILNE POINT 1ROAD CLOSURE '- WEATHER CAUSING LARGE DRIFTS - STUCK VEHICLES WAITING ON EXTRACTION - INADEQUATE ROAD MAINTENANCE DUE TO ROAD CREW EQUIPMENT OUT OF SERVICE 16:00 - 20:00 4.00 FISH P DECOMP ROAD PASSABLE, CONTINUE OPERATIONS - RIH F/ 3956' T/ 12203' MD - PUWT = 165K, SOWT = 85K 1 20:00 - 21:30 ; 1.50 FISH P DECOMP PJSM, SLIP AND CUT 48' 1.25" DRILLING LINE - INSPECT DRAVWVORKS 21:30 - 22:30 1.00 FISH P DECOMP RIH FROM 12203', TAG TOP OF 3 1/2" TUBING IN 7" CASING AT 12375' MD - PUWT = 168K, SOWT = 87K, ROTW = 117K, 50 RPM = 9 -10K TQ - SPR'S, 2 BPM = 230 PSI, 3 BPM = 450 PSI Printed 5/20/2013 10:10:52AM • • ,./ . 4,01AreciO44,34VAI.7iiiiit -,-,„,t,t.t et:4, to l'i'W v „4„/„ -:: Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (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 FISH P DECOMP WASH OVER AND DRESS OFF AROUND COLLAPSED 3 1/2" TUBING - FROM 12375' TO 12377' MD - WOB = 2-5K, 50 RPM = 10-12K TO - OA = 0 PSI - FLUID LOSS DURING TRIP IN THE HOLE = 12 BBLS - LOSS RATE DURING MILLING / WASHING = 6 BPH - 24 HOUR FLUID LOSS = 55 BBLS OF 12 PPG BRINE 4/24/2013 00:00 - 05:00 5.00 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - ATTEMPT TO WASH OVER AND DRESS OFF AROUND COLLAPSED 3 1/2" TUBING IN 7" CASING -3 BPM = 350 PSI, WOB = 5K, 70 RPM = 10K TQ - FROM 12377' TO 12379' MD - NO INDICATIONS THAT WE ARE GETTING OVER THE 3 1/2" STUB - DISCUSS OPTIONS WITH ODE - OA = 80 PSI 05:00 - 06:00 1.00 FISH P DECOMP PUMP HI-VIS SWEEP, STS -7 BPM= 1810 PSI - FLUID LOSS DURING CIRCULATION = 29 BBLS 06:00 - 07:00 1.00 FISH P DECOMP CONFIRM TAG DEPTH AT 12379' - WSL MONITOR WELL 10 MINUTES - BLOW DOWN TOP DRIVE. 07:00 - 12:00 5.00 FISH P DECOMP POH VVITH 4.50" WASH OVER SHOE AND WASH PIPE BHA. - F/ 12379' MD - WITH CONTINUOUS HOLE FILL. T/ 2060' MD DAY WSL ARRIVE ON LOCATION DURING LEVEL II WEATHER, CONVOY AT 10:00 HRS TO CHANGE OUT WITH NIGHT WSL. 12:00 - 12:30 0.50 FISH P DECOMP PJSM, PERFORM PRETOUR CHECKS - SERVICE TOP DRIVE - SERVICE DRAVWVORKS. _ 12:30 - 13:30 1.00 FISH P DECOMP POH WITH 4.50" WASH OVER SHOE AND WASH PIPE BHA. - F/ 2060' MD -WITH CONTINUOUS HOLE FILL. - T/ 638 MD - FLOW CHECK AT BHA. Printed 5/20/2013 10:10:52AM • • ,/, .f; : ;;¢>' ✓', g, ' rf� �i,' .r ;;T >i %s% , %z3a, "`riff; ; - i /-�,.i s'J, r,. 7➢ >. :.,, / -.;: rn %., ...1/,: r%' Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) j Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: _ Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 15:00 1.50 FISH P DECOMP PJSM UD WASH PIPE. - STAND BACK 4-3/4" D.C. / HWDP IN DERRICK - L/D JARS - BREAK OUT AND LAY DOWN 7 JOINTS 5.75" WASH PIPE TO PIPE SHED. - RECOVERED: 8" TWISTED PIECE AND TWO MORE CIRCULAR PIECES STUFFED INSIDE OF EACH OTHER. ( -8" LONG) - EXCESSIVE WEAR ON THE OUTER NOSE OF THE WASH OVER SHOE, ON THE BOTTOM 1/2" OF LEADING EDGE. - AVERAGE INSIDE CARBIDE WEAR NOTED. - 17 BBLS LOST TO WELL ON TRIP OUT OF HOLE. DISCUSS BHA WITH RWO ODE. 15:00 - 17:00 2.00 FISH P DECOMP PJSM TO M/U FISHING BHA #3 - M/U 6" OD X 4 3/4" ID DRESS OFF SHOE - 5) 5 3/4" OD WASH PIPE - 2) BOOT BASKETS - 4 3/4" BUMPER SUB AND OIL JARS - FLOAT SUB WITH FLOAT - 6) 4 3/4" DRILL COLLARS - 3)4 "HWDP - 4 3/4" ACCELERATOR JARS 17:00 - 23:00 6.00 FISH P DECOMP PJSM, RIH W/ WASH OVER SHOE AND WASH PIPE BHA - F/ -488' T/ 12355' MD - RIH ON 4" DRILL PIPE FROM DERRICK - FILL DRILL PIPE EVERY 20 STANDS - SPR'S, 2 BPM = 200 PSI, 3 BPM = 370 PSI - PUWT = 165K, SOWr = 90K, ROTW = 120K, 50 RPM = 8K FREE TQ - 20.4 BBL LOSS ON TRIP IN THE HOLE, 4 BPH STATIC LOSS RATE _ 23:00 - 00:00 1.00 FISH P DECOMP SLACK OFF WITH NO ROTATION AND TAG TOP OF 3 1/2" TUBING STUB IN 7" CASING AT 12379' MD - PICK UP AND BEGIN ROTATING 50 RPM = 8K FREE TQ, 3 BPM = 390 PSI - OBSERVE SHOE WASH OVER TOP OF 3 1/2" STUB WITH MINIMAL WOB OF 1 -2K - CONTINUE WASH AND ROTATE F/ 12379 T/ 12405' MD (- MILL ON JUNK AT 12405' MD, 50 RPM = 9-10K MILLING TQ -OA =60 PSI - FLUID LOSS DURING TRIP IN THE HOLE = 20.4 BBLS - LOSS RATE DURING MILLING / WASHING = 8 BPH - 24 HOUR FLUID LOSS TO WELL = 95 BBLS OF 12 PPG BRINE Printed 5/20/2013 10:10:52AM • s �,L., ..rrr , r, .^ M "a � �. �rrr n, y r r . ,/a,.,,,,, ;� „ r , q , i :k„ ,,,. !.u> • :, s l/.qq y ,r ;- ;' i ", . <r�, ,.,, : / : :::'i,, e / %':?'' , i/,.., -G: =<g'.,">a ,i'��„ / /�.., r��k'rfi; %.% >.,/k,`rry9 /.. ,�; ., Y-y' w �r'` /Ki ✓% n ",<rs ' i �,� �1 =, � :� c< �',ri< r- / ' gin: ,� /. 7 „�,:,�. ,6.. ;yam' fir ,r.,. .r - „ % ri /. � /i ' % ei ,y. � :%`^ �..,a %, <� < ;'i .r ., fir;' -' ,. . 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":c', - �: - t, <'w. .,, "sr�'< ,.,",, ,. , ,. ,,.,,,. .,',=os' „ ,k,,,, ,, ;,, , „#;,.. rs ” � ":, x ,,, / /� ,,. s^/�:,,r .�., ,,.r / /� /. ,,., 1? /, .�,.,, /r ...s! >- , �� ?"', /fir x ,... %TY.�Y. , :>Y,fsi. .. ✓,.,,'r: h. 4r Common Well Name: MPF -57 AFE No Event Type: WORKOVER (\NO) Start Date: 4/18/2013 I End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth ' Phase Description of Operations (hr) (usft) 4/25/2013 00:00 - 05:00 5.00 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT I CHECKS - CONTINUE TO WASH OVER AND MILL/ CLEAN -OUT OVER 3 1/2" TUBING IN 7" CASING F/ 12405' T/ 12530' MD 1 - TOTAL WASH OVER LENGTH = 151' (12379' TO 12530') - ESTIMATED LOWEST 3 1/2" TUBING COLLAR AT -- 12518' MD I - PUWT = 165K, SOWT = 90K, ROTW = 120K, 70 RPM = 10 -11K MILLING TQ, WOB = 1 -15K, 3 BPM = 450 PSI - INTERMITTENTLY PUSH AND MILL ON JUNK WHILE WASHING AND REAMING, 50-70 RPM = I 10-12K MILLING TQ - PICK UP AND WASH DOWN WITH WITH NO ROTATION EVERY 30' = 2K DRAG WHILE SLACKING OFF I - LOSS RATE DURING MILLING / WASHING = 6 I BPH 05:00 - 06:30 1.50 FISH P DECOMP PUMP HI -VIS SWEEP STS 1 I - 5 BPM 1090 PSI I - MONITOR WELL 06:30 - 07:30 1.00 FISH P i DECOMP POH F/ 12530' MD T/ 12367' MD - RIH WITH PUMPS OFF T/ 12430' MD AND ROTATE FOR VERIFICATION TO PASS OVER STUMP. PUW / 165K, SOW / 90K. - WSL VERIFIED FREE PASS OVER. 07:30 - 12:00 4.50 FISH P DECOMP PJSM, POH WITH 4.75" WASH OVER SHOE I AND WASH PIPE BHA. - F/ 12430' MD ' - WITH CONTINUOUS HOLE FILL. I - T/ 581' MD 12:00 - 14:00 2.00 FISH P i DECOMP PJSM UD WASH PIPE. - STAND BACK 4-3/4" D.C. / HWDP IN DERRICK - L/D JARS - BREAK OUT AND LAY DOWN 3 JOINTS 5.75" I WASH PIPE TO PIPE SHED. - NO JUNK RECOVERED. - EXCESSIVE WEAR ON THE BOTTOM NOSE FACE OF THE WASH OVER SHOE. - AVERAGE INSIDE CARBIDE WEAR NOTED. - 8 BBLS LOST TO WELL ON TRIP OUT OF HOLE. INSPECT AND DISCUSS BHA. 14:00 - 14:30 0.50 FISH P DECOMP PJSM, SERVICE DRAWWORKS - REPLACE GREASE FITTING TO DRILLER + _ SIDE BRAKE LINKAGE. 14:30 - 15:00 0.50 FISH P DECOMP PJSM TO M/U FISHING BHA#4 I - M/U 6" OD X 4 3/4" ID DRESS OFF SHOE I (RERUN) - 6" OUTSIDE CUTTER / TO CUT 3-1/2" TBG. - 5)53 /4" OD WASH PIPE I - FLOAT SUB WITH FLOAT - 6) 4 3/4" DRILL COLLARS I I -3)4 "HWDP Printed 5/20/2013 10:10:52AM • • zntr.,z >.. ,,<':,..'v.,,r;, .. ,..,..,,,....,, u ,.., -,.�. ., ,,,,,,,.,:�,,.r2,nyre .✓/ �;,% //47 : '[';,14a,%"S/: ,{, ems. '1?/, "'ri; f - 1. .. a, � :, c, -. „ /. es '.2„ ,. �'Y ,- .✓„3 ✓ :i!!'" . r,. ...... , , '<< k .. , ,i,y, i %." �v� %iv , �cq , r /7 % �� ;y � , rj �/ • , / r / j . .,22,;;4,,e;5;5,.; �P f. i�irr'�/ u „' �. rWa � < ry` . . / r..•r:/ / % %. r//� � ` y ' �4:r:•a r : . / . ' / (a f' w � .._ s cyr :...' r / Common Well Name: MPF -57 I AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4- OOX8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase i Description of Operations (hr) (usft) 15:00 - 21:00 6.00 FISH P DECOMP PJSM, RIH W/ WASH OVER SHOE AND WASH PIPE BHA - F/444'T/12293'MD - RIH ON 4" DRILL PIPE FROM DERRICK - FILL DRILL PIPE EVERY 20 STANDS - 15 BBL LOSS ON TRIP IN THE HOLE, 2 BPH STATIC LOSS RATE 21:00 - 22:00 1.00 FISH P DECOMP PJSM, SLIP AND CUT 61' 1.25" DRILLING LINE - INSPECT DRAWWORKS 22:00 - 23:00 1.00 FISH P DECOMP RIH F/12293 TO 12378' ESTABLISH PARAMETERS BEFORE WASHING OVER TOP OF FISH - SPR'S, 2 BPM = 240 PSI, 3 BPM = 380 PSI - PUWT = 168K, SOWT = 90K, ROTW = 122K, 30 RPM = 8K FREE TQ - 3 1/2" TUBING STUB AT 12379' MD - WASH DOWN FROM 12378' TO 12530' MD WITH NO ROTATION AND NO PUMP 23:00 - 00:00 1.00 FISH P DECOMP LOCATE 3 1/2" TUBING COLLAR FOR CUT AROUND 12517' MD - ROTATE 30 RPM = 9K FREE TQ, NO PUMPS - EASE CUTTER UP 1" AT A TIME, SEE SMALL INCREASES IN TORQUE AND DRAG ON WT. -OA =80 PSI - LOSS RATE = 3 BPH - 24 HOUR FLUID LOSS TO WELL = 77 BBLS OF 12 PPG BRINE 4/26/2013 00:00 - 01:00 1.00 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - CONTINUE 3 1/2" TUBING CUT OPERATIONS AT - 12517' MD - EASE CUTTER UP 1" ATATIME, SEE SMALL ' INCREASES IN TORQUE AND DRAG ON WT. - WORK CUTTER UP UNTIL OUTSIDE CUT IS COMPLETE ON 3 1/2" 9.3# TUBING - PICK UP SLOW WITH NO ROTATION F/ - 12517' T/ 12428' 01:00 - 02:00 1.00 FISH P DECOMP CIRCULATE BOTTOMS UP 1X - 5 BPM = 990 PSI - LOSS DURING CIRCULATION = 18 BBLS 02:00 - 02:30 0.50 FISH P DECOMP BLOW DOWN TOP DRIVE - WSL MONITOR WELL 10 MINUTES - LOSS RATE = 1.5 BPH 02:30 - 08:00 5.50 FISH P DECOMP PJSM - POOH FROM 12428' MDT/ 444' MD - CONTINUOUS HOLE FILL. - MONITOR WELL 10 MIN. PRIOR TO POH W/ BHA. Printed 5/20/2013 10:10:52AM • III . ,,,,,,,,,,,,,,,,-„,,„-,„„:,,,i •-•,%g-',441;;;',Z;:::;;%;'; ,':%;.":',71:1.;',:',;7211i1 7 :i:'-';': - '. / S:' , •':;;:'-'r'' '''. ' 94* :;%i . /'% - li f '' ' '',,e 4 , :::',',, ,';' , ', ; r ",' ', ‘,/''' , -*Ai' , " , , , .:': . ,;'';::'1';1'p' , 4 ,,4, #-, , ,', :,;-:,::::,;0; , , 4,, .;,-y,;;', , ' ',*" .,-', :: • &,:".;.•,::',:,;2.1V4:4,1,0,„--4,..,,,,;-0/, :.; ,•• , ..: , :ok: ;•?, y;•, . -,- -'4..7000;e4'...• . :' ,j. , : , :;''A%'' .W% • '••• = = = ' = V 7= :;:=: = • ?%' '•= f/YW • 4 - / = ; 4 5 , 7g ' % ':' . •,:' '%:%'•'. 4 % ,-,,,, e 1 ;' , /)PV - N 7 ='''' '‘‘P;/ ."% .' :::,,,,•p;,lx ,:=;•,, %%, ••':':%:= 'IA' = ==• • ''.= - %• = ' V<,e ‘ z liM c ' / 7: '7:,',7 : % >,4='• • . %,:%:= ,,,,A • '%, %, -• ; %:;,::,74 .%%: t:=,,%• % 7, 1 .:, -:' f ... 4,:. ., : .: . :4, '',.=.." Y • = • 4 : 'A , ,.' ,, , ;.., ., ', ",,,,,, ,,:' „P ,‘„ , ,, , , .4% ; 4 . , ,/;,,, : '..„;•A; •;;„,,„,. r.-• /.: ..,,:', , ,-, ,Y4/,,&' , :;1.'q' ,', .."/:” 4W. P .":e', * V', ,., , :,%/ :";‘,//: :,*" ''' , -%, ''% ' '"'i ' ' > ' , e–'"i / ' 0,/ 2 ' //' Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 10:30 2.50 FISH P DECOMP PJSM UD WASH PIPE. - STAND BACK 4-3/4" D.C. / HWDP IN DERRICK - BREAK OUT AND LAY DOWN 5 JOINTS 5.75" WASH PIPE TO PIPE SHED. , I - NO FISH RECOVERED. - NO ADDITIONAL WEAR TO WASH OVER I 1 SHOE NOTED. I I ! - 10 BBLS LOST TO WELL ON TRIP OUT OF HOLE. - ONE OF 5 CUTTERS MISSING. , 1 - FOUR OF 5 CUTTERS BROKEN OFF, MISSING. NOTIFYAOGCC INSPECTOR JEFF JONES OF ! BOPE TEST TIME, AT 11:00 AM BY PHONE I -- 10:30 - 11:00 0.50 I BOPSUR P I DECOMP PJSM, P/U WEAR RING TOOL I - PULL WEAR RING - INSTALL 11" FMC TEST PLUG. 11:00 - 12:30 1 1.50 FISH P DECOMP I CLEAN RIG FLOOR i _ CLEAR RIG FLOOR OF FISHING TOOLS. 12:30 - 13:30 1.00 BOPSUR P I I— 1 DECOMP PJSM, R/U BOP TEST EQUIPMENT. - DRILLER INSPECT TEST EQUIPMENT AND TEST JOINTS - AND FLOOR SAFETY VALVES. 1 I RWO SUPERINTENDENT REVIEW INCIDENT ON PARKER RIG WITH CREW. 13:30 - 20:00 I 6.50 BOPSUR P DECOMP PJSM, TEST FOUR PREVENTER BOPE AND ! RELATED EQUIPMENT I 1 - BOP CONFIGURATION = ANNULAR, 2 7/8" X 15" VBR UPPER PIPE RAMS, BLIND SHEARS, !MUD CROSS, 2 7/8" X 5" VBR LOWER RAMS 1 I - TEST BOPE ACCORDING TO AOGCC 1 1 REGULATIONS AND DOYON PROCEDURES 1 - TEST ANNULAR WITH 3 1/2" TEST JOINT TO 250 PSI LOW, 4000 PSI HIGH, 5 MIN, CHARTED I 1 1- TEST UPPER AND LOWER 2 7/8" X 5" 1 VARIABLE RAMS WITH 3 1/2" AND 4 1/2" TEST i I JOINTS, 250 PSI, 4000 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 4000 PSI, 5 ! I i I I MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST. 1 i - JEFF JONES OF AOGCC WAS PRESENT TO 1 WITNESS THE BOP TEST 20:00 - 20:30 0.50 BOPSUR P DECOMP I R/D BOPE TEST EQUIPMENT I - VAC OUT FRESH WATER FROM STACK TO I I PREVENT MIXING INTO MUD SYSTEM 1 - PULL TEST PLUG AND UD - STATIC LOSS RATE = 2 BPH 20:30 - 21:30 1.00 FISH P DECOMP INSTALL 6 7/8" ID WEAR BUSHING I I - CLEAN RIG FLOOR - MOBILIZE FISHING TOOLS TO RIG FLOOR Printed 5/20/2013 10:10:52AM • ww.Az r . 464 fr? , /./,./ , Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6200,000.00) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 00:00 2.50 FISH P DECOMP PJSM, M/U FISHING BHA #5 TO MAKE OUTSIDE CUT ON 3 1/2" 9.3# L-80 TUBING INSIDE 7" CASING AT -12502' MD - M/U SAFETY JOINT, FOR NON SHEARABLES ACCROSS STACK - M/U CROSSOVER FROM WASH PIPE THREAD TO FLOOR VALVE - M/U 6" OD X 43/4" ID WASH-OVER / ROTARY SHOE - M/U 6" OD X 47/8" ID OUTSIDE CUTTER -5) 53/4" OD WASH PIPE - FLOAT SUB WITH FLOAT - PUMP OUT SUB -6 COLLARS, 3 HVVDP - OA = 0 PSI - LOSS RATE =2 BPH -24 HOUR FLUID LOSS TO WELL = 48 BBLS OF 12 PPG 4/27/2013 00:00 - 00:30 0.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS RIH WITH FISHING BHA #5 TO MAKE OUTSIDE CUT ON 3 1/2" 9.3# L-80 TUBING INSIDE 7" CASING AT -12502' MD - 6" OD X4 3/4" ID SHOE, 6" OD X4 7/8" ID OUTSIDE CUTTER, WASH PIPE, FLOAT SUB, POS, COLLARS HWDP - RIH FROM 443' TO 1390' - RIH WITH FIRST 10 STANDS, FLOAT IS NOT HOLDING - PIPE IS FLOWING OVER AT 20' OFF RIG FLOOR DUE TO LARGE OD WASH PIPE ASSY - PUMP 3 BPM = 250 PSI, IN ATTEMPT TO FLUSH FLOAT AREA -LOSS RATE = 2 BPH 00:30 - 02:00 1.50 FISH P DECOMP POOH FROM 1390' TO FLOAT SUB AT 164' - REPAIR / REPLACE FLOAT SPRING - RIH FROM 164' TO 1390' 02:00 - 05:00 3.00 FISH P DECOMP CONTINUE TO RIH ON DP FROM DERRICK WITH FISHING BHA #5 - RIH F/ 1390' T/ 5846' - PUMP 20 BBL 12.5 PPG DRY JOB TO CONTROL PIPE FLOWING OVER = GOOD - CONTINUE RIH F/ 5846 T/ 8850' MD 05:00 - 07:30 2.50 FISH P DECOMP PJSM, CONTINUE TO RIH FROM DERRICK WITH BHA # 5. - RIH FROM 8850' MD TO 12387' MD. 07:30 - 08:30 1.00 FISH P DECOMP WASH OVER 3-1/2" TBG STUB - F/12387' TO 12510' MD. - ESTABLISH PARAMETERS BEFORE WASHING OVER TOP OF FISH - SPR'S, 2 BPM = 240 PSI, 3 BPM = 380 PSI - PUVVT = 170K, SOVVT = 87K, FR WT = 120K, 30 RPM = 8K FREE TQ -3 1/2" TUBING STUB AT 12379' MD - WASH DOWN FROM 12379' TO 12510' MD WITH NO ROTATION AND NO PUMP - ROTATE ONLY TO PASS OVER TBG COLLARS - AND CLOSE TO BOTTOM OF RUN. Printed 5/20/2013 10:10:52AM • • • a . % / ' GZ /,Lr;'O,y.?dl'uii /, % %: %l/�j' Y // ;,.y :.> "ass; / /17/VIP //!i.<Er . a`7; ,> /.: lv;% ., /';, , ��ilr ' � *' Y !3 �' �, '� yam ° % ?i .;;��:,�'" � `� ,/ ti y `:'" !i,i, c� % %� - ( ",1�� ' �. tt :u /2i /, .:�•u %/` ✓ /5„,..‘;`,4 �' r ;: i'. �? F ," // / �l,r �� '� �, r ;, . /: %: .,' ; , i, , v / , . �'',.. • '! r ' i; ,rte iah.' ;`, ..'//,� /, /TZS.:� ,,?,,. G /, /// {�, /, • z � 1:. / /4�' , .' „%. // .r .,. , r.i� �... ,/, � , ,,,. / .N . A, r4✓' x�„ r,., �. �/% �. i.. S. �1; �G. „.> ar ,'•- o,a�i.: r /�� ° , � �., .l:,v,�iai!/�G'."k:�F�:,,�.,,,,. is��YS4/ /x'�. Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 OOX8H -E:RIG (6,200,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name/No.: DOYON 16 1 Spud Date /me: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 12:00 3.50 FISH P DECOMP START OUT SIDE TBG CUT. - 3 1/2” 9.3 #, TUBING CUT OPERATIONS AT - 12510' MD - ROTATE 30 RPM = 8-10K FREE TQ, NO PUMPS. - EASE CUTTER UP 1" AT A TIME. - NO SIGNIFICANT INCREASES IN TORQUE AND DRAG. - F/ 12510' T/ 12493' MD. - PICK UP SLOW WITH SLOW ROTATION F/ - 12493' T/ 12483' MD. - NO OVER PULL OBSERVED, PULL STATIC TO 12379' MD I - LOST 19 BBLS 12 PPG BRINE , PAST 12 HRS. _ 112:00 - 12:30 0.50 FISH P DECOMP SERVICE RIG - SERVICE DRAWWORKS AND IRON ROUGHNECK. - PERFORM PRE -TOUR CHECKS 12:30 - 17:30 5.00 FISH P i DECOMP POOH WITH WASHPIPE AND TUBING CUTTER PUWT = 168K, SOWT = 90K - F/ 12379' T/ 444', BHA 17:30 - 19:30 2.00 FISH P ( DECOMP PJSM, L/D FISHING BHA #5 = WASH PIPE, CUTTER AND SHOE - RECOVER CUT 3 1/2" 9.3# L -80 TUBING FISH - 4 FULL JOINTS = 121.19 AND CUT JT. = 2.18, TOTAL 3 1/2: TUBING RECOVERED = 123.37 - NEW ESTIMATED TOP OF 3 1/2" TUBING STUB IN 7" CASING = 12502' MD - SHOE HAD MINIMUM WEAR, LEFT 4 EA. CUTTER BLADES IN THE HOLE, NO FLIPPER DOGS MISSING 19:30 - 21:00 1.50 FISH P ! DECOMP CLEAN / POWER WASH EXCESS BRINE FROM RIG FLOOR AND TOOLS - CLEAR RIG FLOOR OF BHA - MOBILIZE FISHING TOOLS TO RIG FLOOR - C/O ELEVATORS AND HANDLING j EQUIPMENT 21:00 - 21:30 0.50 FISH P DECOMP PJSM, M/U FISHING BHA #6 TO ENGAGE TOP OF 3 1/2" TUBING STUB IN 7" CASING - PLAN IS TO E -LINE A 2.50" JET CUTTER THRU DP, OVERSHOT AND TUBING, AND CUT ABOVE SLIDING SLEEVE - BHA = 5 3/4" OD OVERSHOT WITH 2 7/8" ID AND CROSSOVER TO DP W/ 2 5/8" ID 21:30 - 00:00 2.50 FISH P DECOMP RIH WITH OVERSHOT ON 4" HT38 DRILL PIPE FROM DERRICK - F/5'T/5029' -OA =0 PSI - LOSS RATE = 2 BPH - 24 HOUR FLUID LOSS TO WELL = 49 BBLS OF 12 PPG Printed 5/20/2013 10:10:52AM • S /' /:�z >/ r:ii,4,-" c� �yJ�f; F y , ' / r i /, r - "% " V iii it / %.. ,.S / -, ;,. -ill. ;° ;:r`; j/ y ,� N V.•? g • y fl 1 � , / / i %%3 , % �,.;e� % / : K��rY. '..f�: .r. ;v�<'i�. -. �. i5 3 :.3 {�W iS �i A°'�ss§ ', ��q� %/ % / J /�� .�,�,..',,'� :�r - . ! <' ' '. , /��.,, d.✓; ; 3 ri rv! ' e f' - ., r /, ,y,r/,,. // ./a ,/+ /// /' - 'i' .�, 1 , .. , -r �.n� ;. ri� %j,,.y // ,�/ t4 / S/t .. i/% .., ,, <. %£ ;./ ,rs rY „ 3,D , ' !G� � d/ ,��. ,��.b ;.�:� .ii' .,.C., -.s�', '��.”' %i� D.,.. / /�- / F s dr iot%/, . 0 // . ( O / < ,G ,,.yy y,'4' *1.41 !/.f ?'' > %. /i �: i 'ia / � < /.r , -i /µ,D ,. �: ;� � /' '� '� /{/ '- :r :wz %i�;,� //,' a '� ,. i7. �iG /v � %� j. a . > s � - :r,. r Y�4 r /, " y: = /, /. �,�, 1,. //ri ° - // ee0: /, i. g - i� " %�i''.r f /' r .� %; ,l„ /sOi,�%? -a:% it / a.;x y� ., %'. `:. ,r ��.i(j� /��. "';. < �fi � >' -y/ z , r ✓; f ;;j,%r"j, %Sy l7 %/ / l /7' ! ... -ir "` � /: /rr. / .._. , ,,9�, .r., /. /r�r_ .w« . /.. /.bT.'i' , Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©40.8ousft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ _ (usft) 4/28/2013 00:00 - 02:30 2.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - CONTINUE TO RIH WITH OVERSHOT BHA#6 TO ENGAGE TOP OF 3 1/2" TUBING STUB IN 7" CASING - PLAN IS TO E -LINE A 2.50" JET CUTTER THRU DP, OVERSHOT AND TUBING, ABD CUT ABOVE SLIDING SLEEVE - RIH FROM 5029' TO 12497' MD - P/U ADDITIONAL 4 " DP FROM PIPE SHED 1X1 - PUWT = 168K, SOWT = 85K, ROTW = 117K, 20 RPM = 7K FREE TQ, 3.5 BPM = 450 PSI (ALL WEIGHTS INCLUDE 40K TOP DRIVE WT) - SPR'S, 2 BPM = 100 PSI, 3 BPM = 200 PSI 02:30 - 04:00 1.50 FISH P DECOMP ESTABLISH FISH TOP AND ENGAGE GRAPPLE - 3.5 BPM = 440 PSI, SLACK OFF F/ 12497, SEE PRESSURE INCREASE AT 12502' MD, GRAPPLE NOT ENGAGED - P/U AND INSTALL 5' AND 15' (TOTAL 20') PUP JTS BELOW LAST FULL JOINT FOR SPACE OUT - M/U LAST FULL JOINT TO ENSURE SLICK PIPE ACROSS BOP AND LOW WORKING HEIGHT FOR SWS WIRE LINE 1 - SLACK OFF AND ENGAGE OVERSHOT ON 3 1/2" TUBING STUB AT 12502' MD - SET 12K ON GRAPPLE, PULL TEST GRAPPLE WITH 20K OVERPULL - SET STRING IN NEUTRAL PLUS 15K AT 145K IN THE UP STROKE - ESTABLISH PUMP RATE THRU SLIDING SLEEVE, 1 BPM = 900 PSI - TEST 4 1/2" FOSV FROM BELOW, 250 / 4000 PSI, 5 MIN, CHARTED 04:00 - 08:30 4.50 FISH P DECOMP PJSM WITH SLUMBERGER WIRE LINE SERVICES (SWS) - M/U XO AND 4 1/2" FOSV TO DP IN TABLE - MOBILIZE SWS TOOLS TO RIG FLOOR AND ASSEMBLE - TEST SWS PRESSURE CONTROL EQUIPMENT TO 250 / 4000 PSI FOR 5 CHARTED MIN. EACH. GOOD. 08:30 - 09:00 0.50 FISH P DECOMP PJSM, INSTALL CHEM CUTTER ASSEMBLY. - BACK OUT SWS LUBRICATOR. - BUILD SWS 2.50" CHEMICAL CUTTER ASSEMBLY. 09:00 - 09:30 0.50 FISH P DECOMP SWS CREW CHANGED OUT ON RIG. - PJSM WITH NEW SWS CREW, WSL, RIG CREW. - FOR JET CUT OPS. 09:30 - 10:30 1.00 CUT P DECOMP INSTALL SWS 2.50" JET CUT ASSEMBLY. - RETEST QUICK TEST SUB. Printed 5/20/2013 10:10:52AM • 0, jaff0W4e7MOYIP';'eff'f:01,7* : ' , •••"4, ,,,%;f4g?o4,,K,..,,,'4,, 4 ti,40*,0 41 7 'Mk* , /4'4, dOS. • Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud DatefTime: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 10:30 - 13:00 2.50 CUT N SFAL 41.00 DECOMP PJSM, RUN IN HOLE VVITH SWS 2.50" JET CUTTER ASSEMBLY. - CAN NOT GO PAST 37' MD. - SPR = 1 BPM / 650 PSI. - DISCUSS OPTIONS. - VERIFY E-LINE TOOL STRING. MAKE ADJUSTMENT TO SET SCREW. - WIRE LINE 2.50" TOOLS NO-GO AT -41 FT. - DRIFT RUN WITH 2.40" TOOLS NO-GO AT -41 FT. DISCUSS OPTIONS WITH ODE AND RWO SUPERINTENDENT. 13:00 - 15:00 2.00 CUT N SFAL 41.00 DECOMP PJSM, RIG DOWN SWS LUBRICATOR. - LAY DOWN JET CUTTER. - R/D WIRE LINE LUBRICATOR. - R/D WIRE LINE BOPE AND ASSOCIATED EQUIPMENT. - PU SINGLE JT OF 4" DP AND MU TO STUMP. 1- BAKER REP RELEASE FROM FISH AT 12502" MD. - ROTATE TO (R) AND P/U. - L/D 4" DP PUPS. 15' AND A 5'. - REPLACE WITH ONE JOINT 4" DP. - M/U LAST FULL JOINT TO ENSURE SLICK 1PIPE ACROSS BOP 1 - SLACK OFF AND ENGAGE OVERSHOT ON 3 1/2" TUBING STUB AT 12502' MD - SET 12K ON GRAPPLE, PULL TEST GRAPPLE WITH 20K OVERPULL - SET STRING IN NEUTRAL PLUS 15K AT 145K IN THE UP STROKE 15:00 - 17:30 2.50 CUT N SFAL 41.00 DECOMP PJSM, SWS R/U FULL PRESSURE CONTROL W/ LUBRICATOR. - DISCUSS 'WORKING AT HEIGHTS' AND 'MAN RIDER' PERMITS. - R/U PUMP-N-SUB AND M/U WIRE LINE BOPE. - HANG AND P/U LUBRICATOR FROM PIPE SHED - M/U SWS TOOL STRING FOR DRIFT RUN TO 150' - M/U 4 1/2" IF FOSV AND CROSSOVER ASSEMBLY TO DRILL PIPE - CONNECTION IS 15 FEET ABOVE RIG FLOOR, UNABLE TO TORQUE 4" HT 38 CONNECTION - STOP JOB 17:30 - 20:30 3.00 CUT N SFAL DECOMP DISCUSS PLAN FORWARD WITH DAYAND NIGHT WSL'S AND BOTH TOOL PUSHERS - NOTIFY RWO SUPERVISOR Printed 5/20/2013 10:10:52AM • • , <....- $' % / %-riu. �:.;'! "r " /rrgr.i'/ <:14:;.w i rr �,w ^.ii ' /'; u'X':imr,F'c ..,.: ,, rwro. %,� . / ,.�,,,r n, 'irr� > %:; / r�l /,., Tl�'<�' 't' y < � "''>' �:.rr is %v 3 ��(/(/� /, ; , /:: <s „� %� ' / iG, : ,� 4$t" %. ,.rs. ./. � / /.r ,'CN'� "�,',Zi < %sS/ � t, ��,,.,, 'r /- / / '� y . it ../ � ;�'��'" ": ;',,; U Gam .. L / / 5 � ,�i .✓ �" Vii � 'Si% �r Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 22:00 1.50 CUT N SFAL DECOMP PJSM WITH RIG CREW, BOTH TOOL PUSHERS, BOTH WSL'S AND SWS CREW - STAND BACK SWS BPOE / LUBRICATOR, R/D 4 1/2" IF FOSV - LOCATE ANOTHER 5' HT 38 PUP, CALIPER AND INSPECT - P/U 15' PUP AND SECURE IN MOUSE HOLE - HOLD WIRE LINE BOP AND LUBRICATOR ASSM ABOVE PUP JOINT - DRIFT 15' PUP JOINT WITH SWS TOOLS AND DRIFT ASSM = GOOD - DRIFT NEW 5' PUP JOINT WITH SWS TOOLS AND DRIFT ASSM = GOOD - BAKER REP RELEASE GRAPPLE FROM 3 1/2" FISH AT 12502" MD. - POH AND L/D 1 FULL JOINT - P/U AND INSTALL SWS DRIFTED 5' AND 15' PUP JTS BELOW LAST FULL JOINT FOR SPACE OUT - M/U LAST FULL JOINT TO ENSURE SLICK PIPE ACROSS BOP AND LOW WORKING HEIGHT FOR SWS WIRE LINE - SLACK OFF AND ENGAGE GRAPPLE ONTO 3 1/2" TUBING STUB AT 12502' MD - SET 12K ON GRAPPLE, PULL TEST GRAPPLE WITH 20K OVERPULL - SET STRING IN NEUTRAL PLUS 15K = 145K IN THE UP STROKE TORQUE FOSV AND CROSSOVER ASSM TO DRILL PIPE WITH IRON ROUGHNECK 22:00 - 23:30 1.50 CUT N SFAL DECOMP M/U SWS BOPE AND LUBRICATOR - TEST LUBRICATOR AGAINST CLOSED FOSV, 250 / 4000 PSI, 5 MIN, CHARTED 23:30 - 00:00 0.50 CUT N SFAL DECOMP PJSM, BREAK LUBRICATOR CONNECTION AT QUICK TEST SUB - CLEAR RIG FLOOR AND POST HANDS TO BLOCK ALL FLOOR ENTRANCES - M/U AND ARM JET CUTTER - OA = 0 PSI - LOSS RATE = 1 BPH - 24 HOUR FLUID LOSS TO WELL = 41 BBLS OF 12 PPG 4/29/2013 00:00 - 00:30 0.50 CUT N SFAL DECOMP PJSM, M/U AND ARM JET CUTTER - CLEAR RIG FLOOR AND POST HANDS TO BLOCK ALL FLOOR ENTRANCES - M/U AND TEST SWS QUICK TEST SUB = GOOD - RIH WITH JET CUTTER PAST 41' AREA Printed 5/20/2013 10:10:52AM • :Ifdt3,1" r'SW=INvefi ; ; ':e' 4 4 %4":44 q W4K , W 44 A0, 1 ::'6:;:i*%,V.F4* , 443M 4 ) 4 ,10,E,_:APft , :y3;,:t4 , Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 09:00 8.50 CUT P DECOMP RIH VVITH 2.5" JET CUT ASSM TO CUT 3 1/2" 9.3# TUBING ABOVE SLIDING SLEEVE - SET DOWN ON OBSTRUCTION / RESTRICTION AT 12874' WLM - CLOSE ANNULAR AND LINE UP TO TAKE RETURNS THRU GAS BUSTER - PUMP 1 BPM DOWN PIPE WITH RETURNS TO SURFACE - PRESSURE INCREASED TO 1990 PSI - TURN PUMPS OFF = PRESSURE HELD, THEN BEGAN BLEEDING OFF SLOWLY - CALL ODE AND DISCUSS OPTIONS - REVERSE CIRCULATE 5BBLS AT 1 BPM = 120 PSI, WITH FULL RETURNS OUT THE DP - ATTEMPT TO CIRCULATE DOWN THE PIPE AGAIN AT 1 BPM, PRESSURE INCREASED TO 2500 PSI AND HELD - BLEED OFF PRESSURE - RIH WITH SWS JET CUTTER, SET DOWN ON OBSTRUCTION / RESTRICTION AT 12874' WLM - CONFIRM JET CUT DEPTH WITH RWO ENGINEER. - LOCATE CUT POSITION WITH SWS 09:00 - 11:00 2.00 CUT P DECOMP PJSM AFTER SWS CREW CHANGE. - MAKE JET CUT @ 12,846 WLM. - BREAK CIRCULATION @ 1 BPM WITH 90 PSI TO CONFIRM SUCCESSFUL CUT. - SWS POOH WITH WIRE LINE TOOLS T/ 200. - WSL AND SWS VERIFY SHOT. - LOSS RATE LESS THEN 1 BPH. 11:00 - 12:00 1.00 CUT N SFAL 200.00 DECOMP SWS. E-LINE REEL BRAKES LOCKED UP. - PLACE HOT AIR HEATER ON REEL. - TROUBLE SHOOT BRAKE SYSTEM. 1 12:00 - 12:30 0.50 CUT P DECOMP PJSM, REMOVE JET CUTTER FROM LUBRICATOR. - CLEAR WORK AREA OF NONESSENTIAL PERSONAL. - PULL TOOLS STRING INTO LUBRICATOR. - CLOSE FOSV. VERIFY NO TRAPPED PRESSURE. - P/U LUBRICATOR AND VERIFY SHOT FIRED. - L/D TOOL STRING. 12:30 - 14:00 1.50 FISH P DECOMP CBU THRU THE CUT F/12846' WLM. -1 BPM / 70 PSI -2 BPM /260 PSI -3 BPM / 420 PSI -4 BPM / 700 PSI THROUGH GAS BUSTER. W/ 12 PPG BRINE. - NO OIL OR GAS IN BOTTOMS UP. - WSL / DRILLER VERIFY NO TRAPPED PRESSURE. OPEN ANNULAR. 14:00 - 16:30 2.50 CUT P DECOMP PJSM R/D SWS E-LINE EQUIPMENT. - BREAK OUT AND UD LUBRICATOR ASSEMBLY. - WIRE LINE BOPE AND PUMP-IN-SUB. - CLEAR RIG FLOOR, LOWER ALL SWS EQUIPMENT TO GROUND LEVEL. - BLOW DOWN CHOKE AND KILL LINES - MONITOR WELL 10 MINUTES, WELL IS STATIC Printed 5/20/2013 10:10:52AM • . /1,,, ;,rru.,. rf. ✓/ /G..,/ /, /,i9 v. •, �, ' ix ' ;� � ,.i; - 'gr ., rr ,: .., r. '.o-<h ,. :. '.;G'4!•<,....c .r , ✓:, d �-, //« -.. ,. ' , •;,- r; . ,:,r Y c 0 iv .- • a , a : /f p V x/ , a %' :, / : /,:: :'.. J .., ' •% •h' ?5,' / /r r' /YS. .t/A ,f,- ,3 ',H /!/ /, r,,,�� /: /`. /", "t., q i+. Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 I End Date: 5/11 /2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 23:00 6.50 FISH P DECOMP POOH WITH OVERSHOT FISHING RUN #6 - F/ 12846' T/ SURFACE - PUWT = 168K, OBSERVE DRAG AND 5K OVERPULL ON INITIAL PULL OFF BOTTOM 23:00 - 00:00 1.00 FISH P DECOMP DID NOT RECOVER 3 1/2" TUBING FISH - BREAK DOWN OVERSHOT ASSM - INSTALL NEW 3 1/2" GRAPPLE - INSTALL OVERSHOT EXTENSION TO ENABLE GRAPPLE TO BITE AT DIFFERENT AREA ON 3 1/2" TUBING FISH - WICKERSARE DULL AND WORN ON THE GRAPPLE THAT WE PULLED OUT OF THE HOLE - DISCUSS OPTIONS WITH ODE - OA = 0 PSI - 24 HOUR FLUID LOSS = 41 BBLS 4/30/2013 00:00 - 00:30 0.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS ' - M /U OVERSHOT WITH EXTENSION AND NEW 3 1/2" GRAPPLE TO LATCH ONTO 3 1/2" TUBING STUB AT '12502' MD IN 7" CASING - BHA #7 = OVERSHOT, BUMPER SUB, OIL JAR, DRILL COLLARS - RIH FROM SURFACE TO 306' MD (BHA) 00:30 - 04:00 3.50 FISH P DECOMP RIH WITH BHA #7 ON DRILLPIPE - F/ 306' T/ 12345' MD 04:00 - 04:30 0.50 FISH P DECOMP PJSM FOR SLIP AND CUT DRILLING LINE HELD WITH WSL, TOUR PUSHER, AND CREW - DISCUSSED HAZARDS OF WORKING AROUND A ROTATING DRUM AND MAINTAINING A HEIGHTENED STATE OF AWARENESS - GOOD COMMUNICATION, POSITIONS OF PEOPLE, HAZARD IDENTIFICATION AND PROCEDURES WERE REVIEWED 04:30 - 05:30 1.00 FISH P DECOMP SLIP AND CUT 89' OF DRILLING LINE - INSPECT DRAW WORKS AND BRAKE PADS - ADJUST BRAKE EQUALIZING BAR 05:30 - 06:00 0.50 FISH P DECOMP RIH WITH BHA #7 ON DRILLPIPE TO LATCH ONTO THE 3 1/2" FISH - F/ 12345' T/ 12490" MD - PUW / 170K, SOW / 90K, FREE ROTARY WT. 120K / 20 RPM / FREE TQ 7K, - WASH DOWN OVER FISH AT 12502' TO 12508' MD. - 3 BPM / 450 PSI, 4 BPM / 590 PSI - SET DOWN 10K. P/U -20' AND REPEAT SET 10K DOWN AGAIN. - 5K OVERPULL NOTED WHEN PULLING OFF BOTTOM. - MONITOR WELL 10 MINUTES. 06:00 - 06:30 0.50 FISH P DECOMP PJSM, POH FROM FISHING AT 12503' MD - POH WITH BHA #7 - F/ 12503' MD - T/11172'MD. Printed 5/20/2013 10:10:52AM I i ., ":�:-:::,,' ^; .. >.,,,.,..,, .- /, s „vu,9�,;.” r; ry r;?'>ii ' '� ';e�ii i,' /r� t?. y ... .�x .,..,r, /, /,.. -, /�� % e./ T.'9 � �n � -N // fy ' // // , �/ r 3; ?, „?Yy rife, "�� „'c, W: /:� r ,:t,o,.l+;, i' ,.r. jr ✓. - �' rr�, ,�s' /i , � s v,;9y. G•.:` `T, " � / / °r %/ ,,.y ]��¢�°; -'r /r, �, V, ; ''n. r � 3�� : a./ rte'.'' -`=° ,r ,// gif ., i.. ; � /,. � s ! Y� x'9.T � i/ 7i� �1' /''o � �, ` ; ' - r z / , /60 r-0 .ra / ,i %rs �. %, ;,: /�i, Jr/ =`f'r �':'' , /''a / sc . /.: ^tr,•= rte, , /�, .� N / / //, .r0i fir, %4n v: , iii' /'ni %f ✓. .9. � Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 ; End Date: 5/11/2013 X4- 00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 07:00 0.50 FISH P DECOMP DAY WSU DRILLER DISCUSSED DOYON RIG 14 INCIDENT -WITH NIGHT CREW. - HOW DO WE HANDLE / MANAGE SMALL TOOLS - LIKE: XO'S, BOOT BASKETS, BITS AND SUBS. - TWO MAN RULE 07:00 - 11:00 4.00 FISH P DECOMP CONTINUE POH VNTH FISH FROM 11172' MD TO 306' MD. - STAND BACK 4” DP IN DERRICK. - WSL, TOOL PUSHER, AND BOT FISHING REP ON RIG FLOOR FOR BHA. 11:00 - 12:00 1.00 FISH P DECOMP PJSM WITH BAKER REP, BREAK OUT FISH AND FISHING TOOLS. - WSL, TOOL PUSHER, AND BAKER REP ON RIG FLOOR FOR BHA #7. - B/O AND LID 29.44' CUT JOINT IN SIDE OF OVER SHOT. - LAY DOWN (10) FULL JTS OF 3 1/2” L -80 IBTM TBG = 311.71' - JET CUT JT =3.45' - TOTAL 3-1/2" TBG RECOVERED = 344.60" - RECOVERED A 10" WAD OF TWISTED TUBING AND ONE LOST CUTTER BLADE. - AND 3 MORE PIECES OF TBG. 1" X 2.50 ". A PIPE WRENCH WAS USED TO REMOVE THE - -10" LONG FISH FROM THE JET CUT AREA. - PIN END OF TBG CORRODED WITH SEVERE INTERNAL PITTING. NO OUTER DAMAGE. LOST 35 BBLS 12 PPG NABR IN THE LAST 12 HRS. 12:00 - 12:30 0.50 FISH P DECOMP RIG SERVICE - CLEAN AND CLEAR RIG FLOOR - ORGANIZE FISHING TOOLS. 12:30 - 13:00 0.50 FISH P DECOMP PJSM, M/U FISHING BHA #8 TO ENGAGE 3 1/2 TUBING AT - 12847' AND PERFORM BLIND BACK OFF - BHA #8 = OVERSHOT WITH HOLLOW MILL CONTAINER TO DRESS JET CUT FLARE, BUMPER SUB, OIL JARS, COLLARS 13:00 - 13:30 0.50 FISH P DECOMP DAY WSU TOOLPUSHER DISCUSSED DOYON RIG 14 INCIDENT - WITH DAY CREW. - HOW DO WE HANDLE / MANAGE SMALL TOOLS - LIKE: XO'S, BOOT BASKETS, BITS AND SUBS. - TWO MAN RULE 13:30 - 18:30 5.00 FISH P DECOMP RIH WITH BHA #8 TO ATTEMPTABLIND BACK -OFF ON THE 3 1/2" TUBING AT - 12845' - F/ 308' T/ 12849' MD TOP OF 3 1/2" TUBING FISH - PUWT = 173K, SOWT = 90K, ROTW = 130K, 3 BPM = 390 PSI, 30 RPM = 7K FREE TQ Printed 5/20/2013 10:10:52AM • , .r. r.y „- > �s , � ,., r i %i , �r n� ; .J",; � r� ' y / /,, is /�.;rl ". �%c: 1. j" r ,4'g?:., y,.r' ,i i'. %; �c�..'idr �'" � ii, /.a... -ii ?; :.. .'! ,cr "` l l" �' '., /: "v � '`,: ; ' ;;; �'.� ' /, r ✓/ 'l' ..�.. ',r�3-.;:.` >� / .- ..ni�� /% / , /t,.. Vi z.. /. °�✓ /'. 4 , .lfr//i ii "" y.. Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9 /1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table l 40.80usft (above Mean Sea Level) - i Description Operations tion of O Date From To Hrs Task Code NPT NPT Depth Phase p p (hr) (usft) 18:30 - 22:00 3.50 FISH P j DECOMP DRESS OFF JET CUT FLARE ON 3 1/2" TUBING STUB AT 12849' MD - SLIDE OVER TOP OF STUMP AND SWALLOW 7' TO 12856' - ATTEMPT BLIND BACK -OFF OF 3 1/2" TUBING - BACK OFF 2 TURNS TO THE LEFT AND WORK PIPE TO TRANSFER TURNS DOWN TO BACK OFF AREA - DO NOT LET TORQUE RAISE ABOVE 4500 FT /LBS - WORKATOTAL OF 24 LH TURNS INTO THE � I PIPE, WITH NO BACK OFF - JAR AT 90K OVER, AND PULL TO 125K OVER PUWT, 11X, NO MOVEMENT, -18' OF STRETCH - ATTEMPT TO PUMP DOWN TUBING TO CHECK FOR RESTRICTIONS, 1 BPM = 1050 PSI WITH LOW RATE OF RETURNS - PERFORM DERRICK INSPECTION FROM JARRING 22:00 - 23:30 1.50 FISH P DECOMP DISCUSS OPTIONS WITH TOWN ODE - DECIDE TO RELEASE GRAPPLE, AND POOH 23:30 - 00:00 0.50 FISH P DECOMP BLOW DOWN TOP DRIVE - PREP FLOOR TO POOH AND UD OVERSHOT ASSM - MONITOR WELL FOR 10 MINUTES = SLIGHT LOSSES - POOH F/ 12849' T/ 12536' MD -OA =0 PSI - 24 HOUR FLUID LOSS = 55 BBLS 5/1/2013 00:00 - 04:00 4.00 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - POOH F/ 12536' T/ 308' (BHA) 04:00 - 05:00 1.00 FISH P DECOMP UD FISHING BHA #8 = OVERSHOT / BACK OFF ASSM - STAND BACK COLLARS, UD BUMPER SUB AND JARS - SERVICE BREAK OVERSHOT AND UD SAME - NO FISH INSIDE OVERSHOT, GRAPPLE IN GOOD CONDITION - JARS AND TOP EXTENSION ARE MILDLY JUNK CUT 05:00 - 08:00 3.00 FISH P DECOMP PJSM, M/U BHA #9 TO WASH OVER -300' OUTSIDE 3 1/2" TUBING FISH - CLEAR /CLEAN RIG FLOOR BHA #9 = 6" OD X 4 3/4" ID WASHOVER SHOE, 301' WASHPIPE, BOOT BASKETS, BUMPER SUB, OIL JAR, FLOAT SUB, COLLARS 08:00 - 13:30 5.50 FISH P DECOMP PJSM, RIH BHA #9 WASH OVER ASSEMBLY. - RIH FROM DERRICK. - CHECK ALL DP CONNECTION FOR MAKE UP TQ. - T/ 9500' MD Printed 5/20/2013 10:10:52AM • ,.•, o „•,., ,.:,�; „r::r:.,,<-a, /;% /Gi / %,�� •rr y ; rr.., �. , .:7`'' e'ao ;.�; ry�r- rte ,'¢. a ,. / irr q;;> ,�: • . �/ ,;y' .?' (j r r, r•4 . � 5��, , � M r a y:E N� .�7i.�:;1�' � i�,a� � �:,- r6�; j < rr r 6/r rt";�. %,1 f�., / w ; ,', ;% .'/' .. .lr �a, 'arr / , ,k � , /,; �y�4 , f'?$'` ' % %.,j- , .,.G % .� , ��r r / ,Yy�'u �/r �?. 1 J ;/ •�i% -ir' /,'' % % /� % i; ''. r .'J� J/'G/ / " -'i: ,'•y "r "' 40// /% a • . �� rf ' , !�F c";..- /r,., >: / /,' � �,.,,, ,v �.i,:� /. %/. ,.. w,tt - . ,�- � r , , <„ ; ./ ,r / '�,, ,vi,.e ° /h.; '. } .,.� /! r ,; / r � , / � ✓ / / , ^d „' s,, fir r,G ° YBJ �� r , >��, ' � c hi ' ,c � /�'r�•' A�s1� /� < �o �/ %”, /� i,i., , > /sf / /,r n, �.,.,r ,.o „?, / -lei rr r�� > - % '; " ` ei ,,i,,,, ..� %s% 'r %i, , / r - : ' j . "., r %�;- r ; >r,r /��, .. ..., f .,. , / . .�- .;;;; ,i / `' .,G /, , ,.. . %i /c.y.,G %," �.Y,,.s a. ?3„`� ,. �;% /., .vf,. ,! e r..r,,... � / „ /�/ ¢, r., ,�., - �.., �� i „ {;,.> ,. ,/ „9,. �7�,i,: .:,i,� .r� /ii /�/ . �, /i � �� ' r.+�"7,?3m s, lH //�z�,s,�« t.u.,�r7.Py,l,JG, - /� f/;. ,�.s,'�ui..v Vii/ !.(% #r.,� �lr�i ��h ., ,.,,,r „x ' ✓)c ,,,., ., 'rr .... „a rnv ��6d, / !x! /�.,,,rr / /r, ...zz:,i / /�.:,i/2 Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 14:30 1.00 FISH P DECOMP HELD SURPRISE KICK WHILE TRIPPING DRILL. - ALL HANDS RESPONDED QUICKLY AND EFFECTIVLY AAR: ALWAYS COMMUNICATE THE KOOMEY PRESSURE AFTER WELL IS SHUT IN. BP RWO SUPERINTENDENT, DISCUSSED: - PAKER WHEEL ROOM INCIDENT. - DOYON RIG 14 COW INCIDENT. 14:30 - 17:30 3.00 FISH P DECOMP PJSM, CONTINUE RIH WITH BHA #9 WASH OVER SHOE. - F/ 9500' T/ 12847' MD - CHECK ALL DP CONNECTIONS FOR MAKE UP TQ 17:30 - 18:00 0.50 FISH P DECOMP M/U TOP DRIVE AND OBTAIN PARAMETERS - 5 BPM = 1150 PSI, 60 RPM = 8K FREE TQ - TAGGED JUNK AT 12792', BEGAN WASHING FROM 12792' TO 12847' MD - TAG TOP OF 3 1/2” TUBING STUB / FISH AT 12847' MD - PUMP HI -VIS SWEEP TO CLEAN OUT OVER TOP OF FISH STUMP, LOAD JUNK BASKETS _ 18:00 - 20:00 2.00 FISH P DECOMP WASH OVER TOF OF 3 1/2” TUBING STUB - WASH AND ROTATE DOWN F/ 12847' T/ 13149' MD - 60 RPM = 9-12K TQ, 5 BPM = 1150 PSI - MILLED ON JUNK AT TOP OF 3 1/2” TUBING STUB WITH WASHOVER SHOE FOR 20 MINUTES BEFORE SLIDING OVER - OBSERVED 1-4K WOB 3-4 MORE TIMES WHILE WASHING A TOTAL OF 302', AREAS MILLED OFF QUICKLY 20:00 - 21:30 1.50 FISH P DECOMP PUMP HI -VIS SWEEP STS - R & R DRILL PIPE, 30 RPM = 7K TQ, 6 BPM = 1740 PSI - SWEEP RETURNS = FINE METAL ON DITCH MAGNETS AT SHAKERS AND A SMALL AMOUNT OF SAND 21:30 - 23:00 1.50 FISH P DECOMP WORK PIPE UP AND DOWN OVER 3 1/2” TUBING F/ 12848' T/ 13149' MD SMOOTH WITH NO PUMPS AND NO ROTARY - PULL OFF TOP OF 3 1/2" STUB AND ATTEMPT TO SLIDE OVER = UNSUCCESSFUL - TURN ROTARY ON AT 20 RPM AND EASILY SLIDE OVER TOP OF STUB WITH NO PUMPS - POOH OFF OF FISH TO 12759' MD - MONITOR WELL 10 MINUTES = SLIGHT LOSSES 23:00 - 00:00 1.00 FISH P DECOMP BLOW DOWN TOP DRIVE AND R/U FLOOR TO POH - POOH F/ 12759' T/ 11716' MD - PUWT = 175K, SOWT = 87K - OA =OPSI - 24 HOUR FLUID LOSS = 50 BBLS 5/2/2013 00:00 - 04:30 4.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - POOH F/ 11716' T/ 625' WITH WASH OVER BHA #9 Printed 5/20/2013 10:10:52AM 0 0 „. ..; ”- . . ,�,,;'a' g.;¢ ,,'�:;�. ��` ri� /"irti � k /��: . ✓. �t,.�t�r'yr- %;i�'[y �y % %r'�f' %j;r'i `�hr �p�� iri /� ' , :. ; ,,, ,,, �' " ,- r0 .rir - , .o .cc / §r �. 4,", , , ,,; <,, :'i,G%/' ,. �l J ,e ir i,, . ,: / ` i%': v " //frl . I';��.u(c r ,, ., ; .�a�,^,),. ; �,. .l '.�v /`�:r / ".11�i. r %ll��' 'ry,,; i � /l<�' ` % % „',0e/,,;4; , ; ,✓' ;' :',(tr ;::a,v,,� Ry(r rte, JW” "1%4'7* (9, ,. ,. - // =c a ,r/.(/, >. ,. rryy % c,. ., l, ' %se n- ,.�r " l ,. P i " � -YS': r „a� ,,� "i<.,� r " � / � .. � . , , -. .. , ; , v .-; : : ' : ", ; c.: .',V,)::, , �.i •¢d er , 6 �," z /. /r / /r, ;/,//1P F �/ ;:un ' / / - r ;y, „/..i F , sY't Gfa %,a.>a' >il / %� ,/ /./ „r . .. , . ,. , ., � . / -. ..,.,.. -, , ,. ;,;�; ✓/�9�;�.�” s h iu'1'�i%��1.' /� e� „ �:,- - ar r /!�� ,. � ,.;.'�r,�. s �;'493;x".-.; , . / /.a >:s.S. / / //' / F.� � vy a%///a�ri /�/ Common Well Name: MPF -57 I AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.8ousft (above Mean Sea Level) Date From - To Hrs Task Code NPT j NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 07:00 2.50 FISH P DECOMP STAND BACK COLLARS IN DERRICK -1../D BOOT BASKETS, JARS, WASHPIPE AND SHOE - 1/2 GALLON OF CUTTER PIECES, FLIPPER 1 DOG PIECES, MISC METAL DEBRIS IN BOOT 1 BASKETS - SENT AOGCC 24 HOUR NOTIFICATION OF BOPE TEST, VIA E -MAIL, AT 6:08 AM 5/2/2013 - RECIEVED E -MAIL CONFIRMATION OF ` RECIEPT AT 7:00 AM 07:00 - 09:00 2.00 I FISH I, P DECOMP PJSM, MAKE UP BHA# 10. WSL, BOT REP, TOOL PUSHER, RIG CREW IN ATTENDANCE. - MAKE UP BOT 6" x 4 -5/8” CUTTER I ASSEMBLY PER BAKER REP. I - P/U AND RIH WITH 12 JOINTS WASH PIPE 1 FROM PIPE SHED. 09:00 - 11:00 2.00 FISH P DECOMP PJSM, RIH WITH BHA# 10. I- RIH WITH CUTTER ASSEMBLY 6" x 4-5/8" ON I 1 4" DP FROM DERRICK - FILL PIPE EVERY 30 STDS. - RIH TO 4505' MD. -1 - FILL PIPE. 11:00 - 11:30 0.0 FISH P DECOMP SAFETY STAND DOWN MEETING WITH BP SUPERINTENDANT. I- WSL, TOOL PUSHER, DDI I SUPERINTENDANT, RIG CREW IN I ATTENDANCE. - DISCUSSED RECENT EVENTS ON PARKER I 272 AND DOYON 14. - DISCUSSED PROPER PROCEDURES, PINCH 1 POINTS, DROPPED OBJECTS, GOOD COMMUNICATION BETWEEN WORKERS. DISCUSSED TWO MAN RULE ON AWKWARD OR HEAVY EQUIPMENT L HANDLING. 11:30 - 16:00 4.50 FISH P I DECOMP CONTINUE TO RIH WITH BHA# 10. - RIH FROM DERRICK FROM 4505' TO 12791' . j MD I 1 - CONTINUE TO FILL PIPE EVERY 30 STANDS. _ :16:00 - 17:30 1.50 FISH P DECOMP PJSM, SLIP AND CUT 84' OF DRILLING LINE 1 _ - INSPECT DRAW WORKS I 17:30 - 19:30 I 2.00 FISH P DECOMP RIH F/ 12791' TO TOP OF 3 1/2" TUBING STUB 1 AT 12847' MD - SLIDE OVER TOP OF FISH, 3 1/2" STUB, WITH SLIGHT ROTATION, NO PUMPS I - SLIDE DOWN HOLE OVER FISH WITH NO I ROTATION - MINOR HANG -UP ON TUBING COLLARS, ROCK / ROTATE TO GET OVER, THEN CONTINUE DOWN HOLE I - OBSERVE COLLAR AT 13186' MD - CONTINUE DOWN HOLE F/ 12847' TO 13200' 1 (SHOE DEPTH), FLIPPER DOGS AND BLADES ARE POSITIONED - 13193' I - CHUCK SCHEVE OF AOGCC WAIVED STATES RIGHT OF WITNESS FOR BOPE TEST Printed 5/20/2013 10:10:52AM ;;�," .`:' %" �,. '7 / /', ?, °z0 ' .// % .. �-'" � " • . ai zii N„ y ..i/, j// r:/ r/ _ - r . �Lg' , /. . ..,, ; . .�........, ,�. s .: . r/, h%:. °.. � 1l /r� s /�� §;�' 3,Gr✓y + r r wt 4G ,> /%'� :' ,' / �fi.3/f ./m -r: �.w' /, t i.� �7� / �i✓✓ / 4 � %fir /� � / ., �. �� .� � �� ,/�/ .�,. /;�..��! s�� .. " , � r /° � i �� . 4! >?s -,. ✓ ..f %.< -'�s' �:�i %1; .'rrzri ,vr .: i si��. 'f.v�/ r � . s >Y: o! .,7�f,s"` /./ ;� » . >��/l r pi „x� �, /. "� ..r ' y.' .^ . 9//' l b r a' t>../': . r u n, /6, : � ":' ,. � % < .,. ,'/ 1' /r,. 7 ✓ 1 / /� Xji,�: F �� , / ��y „� � %' �: 4fi �'�.Y�� ' %:�.. /��i / e� .iii/ / / / y� �„ � � • i a=� r� >.a,r �! i%i ��, /.i .l� / ,ril � y /%, .. 6- ✓''^r.ruD” r'i/irKry.,,, /'o, r/ r: . ?.J/iy.1991C1 .vl r . . j rf �°;, r Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 00:00 4.50 FISH P DECOMP BEGIN TO CUT 3 1/2" TUBING IN 7" CASING WITH OUTSIDE CUTTER AT 13200' SHOE DEPTH - ROTATE 30 RPM = 9 -10K TQ, ROTW = 120K - WORK CUTTER UP FROM 13193' TO 131179', 1 INCH AT A TIME EVERY 2 MINUTES - NEW ESTIMATED TOP OF 31/2" TUBING STUB = 13189' MD - OA = 30 PSI - 24 HOUR FLUID LOSS = 24 BBLS 5/3/2013 00:00 - 00:30 0.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - CUT 3 1/2" TUBING AT ESTIMATED 13189' MD - MONITOR 10 MINUTES = SLIGHT LOSSES 00:30 - 04:30 4.00 FISH P DECOMP POOH WITH SHOE, CUTTER AND WASH PIPE - F13170' TO 625' - PULLED FISH SLOWLY THRU 12 DEGREE DOG LEG © 9597' MD. - MONITOR WELL 10 MINUTES BEFORE PULLING BHA THRU STACK 04:30 - 06:00 1.50 FISH P DECOMP PJSM, UD OUTSIDE CUTTER BHA #10 - STAND BACK COLLARS - L/D 2 JTS WASH PIPE - THREADS PARTED ON WASH PIPE PIN - JOINT # 11 (18 LB /FT) 5.75" OD. - LEFT 310 ' OF WASH PIPE ASSEMBLY DOWN HOLE. - CROSSOVER BUSHING, 10 JTS (21 LB /FT) 5.75" OD. WASH OVER PIPE. - DISCUSSED OPTIONS WITH RWO TOWN ENGINEER. 06:00 - 07:30 1.50 BOPSUR P DECOMP PJSM, RIG UP TO TEST BOPE. - RU ALL RELATED TESTING EQUIPMENT TO TEST BOPE. - PULL WEAR RING. Printed 5/20/2013 10:10:52AM • KA7 , j - • , - Common Well Name: MPF-57 AFE No Event Type: WORKOVER (VVO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To 1 Hrs Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 13:30 6.00 BOPSUR DECOMP PJSM, TEST 13-5/8 BOPE. - BOP CONFIGURATION = ANNULAR, 2 7/8 X 5" VBR UPPER PIPE RAMS, BLIND SHEARS, MUD CROSS, 2 7/8" X 5" VBR LOWER RAMS - TEST BOP ACCORDING TO AOGCC 1 REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 3 1/2" TEST JOINT TO !250 PSI LOW, 4000 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST LOWER AND UPPER 27/8" X 5" VARIABLE RAMS WITH 3 1/2" AND 4" TEST JOINT, 250 PSI, 4000 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 4000 PSI, 5 MIN, CHARTED - COMPLETE ACCUMULATOR DRAW DOWN TEST. WITNESSED BY WSL. - HCR KILL VALVE WAS A FAIL / PASS, (VALVE WAS GREASED) - BLOW DOWN LINES - RIG DOWN TEST EQUIPMENT - SUCK OUT STACK - SET WEAR RING. CHUCK SCHEVE OF AOGCC WAIVED STATES RIGHT OF WITNESS BOP TEST. 1 - THIRD PARTY DERRICK INSPECTION PERFORMED BY NOV REP. 13:30 - 14:00 0.50 FISH P DECOMP HELD MEETING VVITH WAYNE HAUGER AND MARK OMALLEY AND FROM MPU. - DISCUSSED MPU OPERATIONS WITH JOHN HARRIS'S CREW. - MARK THANKED THE RIG CREW FOR A 1 1"JOB WELL DONE" HERE AT MILNE POINT. 14:00 - 15:30 I 1.50 FISH P DECOMP PJSM, MAKE UP BHA # 11 TO LATCH ON TO 3 1/2" TUBING STUB - M/U BOT OVERSHOT WITH 3 1/2" BASKET GRAPPLE, EXTENSIONS, CUT LIP GUIDE, !BUMPER SUB, JAR,COLLARS 15:30 - 20:00 4.50 FISH P DECOMP RIH VVITH DRILL PIPE FROM DERRICK - F/ 309' T/ 12823' MD Printed 5/20/2013 10:10:52AM • • I ,��:'; r' ,..;> ., _, /� �, , ,. .,. � , may' •;,;;��< -,. ;/ , x - >r' %r r . ;;,4 :l /�Xe, ;fir ✓ „ �s g ,', j !0, � , a x I •; ,. /A '; ;:;g41 � :s y �'` .. ,j o-g, rl .� • :F�a 3. %a,� ,',i5� 3� ;'G�'.,> r%/ a /.- , /,' `;,fir /;,, ,.i `7i"t' ,,,;. 1 44 6i rw'; i >' x / !%< , f% ry + f' /� 4 r /-1 / . x, rr � /,! /,, ,. '"� i;: y i , - /.l. - .;/,r /'rl. , i , �, /.�/ r %f-' , Z'- ./ /�' / ,,,.. �;,,,',''. , ,� , �� , 1i . ' . %.i%./ is //✓ .,/ J; /, �:'7' ii,✓ ;i i /��" '! y ,� � a ;F .t r � f' *;, M rr ./ . L, .e . 'i %1%'! „r , •.''up.r -a •,A .- nC /r., .G / /r,?. r%^!�,, a�i t;GU rrr.H. J �S .t /// .,4� C 'G .�, / 5'' ':7 <',,:, J, -.1 , �, r „✓ - =' a • /., <;G �._''; ; i/ ::�,;�i,�,. „ / yip , Js;;,.�:r, d,,,✓ /' % %rrr ,.; i /rFr •; / 41 , }yT+j,� Z [P * F i r „ � .; y 4� %' % %'r, g„ A';i:c.x „ /i x °. ..r !/iii -- urr. „��.' %iir .. � i/ s�: �3��w %Y�.N3a , / far`i,Si.�l'/ /r. %,2�r. / „ ..:�h .v r #i��' "� rr�:„ ./bi /r.ys'%sr,�.s .. % / /rr. ,,. �.��! . >., .. ...r Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 OOX8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.8ousft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 23:00 3.00 FISH P DECOMP ESTABLISH PARAMETERS AND ENGAGE 3 1/2" TUBING STUB - 3 BPM = 360 PSI, PUWT = 176K, SOWT = 95K, ROTW = 120K - TAG TOP OF 3 1/2” TUBING AT 12848', CONTINUE DOWN TO NO -GOAT 12857' MD - OBSERVED PRESSURE INCREASE, SHUT PUMPS OFF - ATTEMPT TO PULL FREE, TUBING IS NOT CUT, JAR 4X = UNSUCCESSFUL - DECIDE TO PERFORM BLIND BACK OFF ON 3 1/2” TUBING - BACK OFF 2 -3 TURNS AT A TIME, AVG LH TORQUE WAS -4500 FT /LBS - WORK PIPE EACH TIME TO TRANSFER TURNS TO BOTTOM - WORKED UP TO A TOTAL OF 31 LH TURNS, WITH TORQUE AS HIGH AS 8000 FT /LBS - PIPE CAME FREE, PICK UP WEIGHT INCREASED TO 210K = 34K OVERPULL FROM PREVIOUS PUWT - FISH ON - POH T/ 12832' AND MONITOR 23:00 - 23:30 0.50 FISH P DECOMP ESTABLISH CIRCULATION AT 2 BPM = 410 PSI WITH VERY LITTLE RETURNS - CLOSE ANNULAR AND ATTEMPT TO CBU THRU GAS BUSTER - PRESSURE INCREASED TO 2310 PSI AT > 1 BPM - UNABLE TO PUMP DOWN PIPE, PIPE IS STILL PLUGGED AS EXPERIENCED ON PREVIOUS RUNS - CALL TOWN ODE AND DISCUSS OPTIONS 23:30 - 00:00 0.50 FISH P DECOMP MONITOR WELL 30 MINUTES - WELL IS LOOSING 1 BPH, CONSISTENT WITH LAST 2 WEEKS OF OPERATIONS - OA = 30 PSI - 24 HOUR FLUID LOSS = 42 BBLS 5/4/2013 00:00 - 00:30 0.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS _ - MONITOR WELL 10 MINUTES 00:30 - 07:30 7.00 FISH P DECOMP POOH AND STAND BACK DP - F/ 12832' T/ 310' (BHA) - WSL PRESENT FOR FIRST 10 STANDS OUT OF HOLE - STOP AT 10 STAND OUT AND MONITOR 10 MINUTES = WELL IS STILL ON CONSISTENT LOSSES >1 BPH - POOH WET, DRILL PIPE IS PLUGGED - MONITOR DISPLACEMENT CLOSELY WHILE POOH Printed 5/20/2013 10:10:52AM • • • - SM" ,'‘I'i''''''',Arg="”r1 - ' 7 ,7* . :::10,(7::: • l''''40;471 e,q?;=:,':.4 ,,,, , , ,400„ 0000, .407 0, w , ,4,12,, , ,z 4 ;: , •yefiv,',. -::: ti>,?'',:(4""l. r ''":'; ' ' ''', X'%! z 4 /A ,'-g:':0,4i1)0''.:::$ .,/z,;:i•;-, ,,, P' , •;-•.`N, ,, P;v* . .,# be , upin.400pary / .0rv 'OtAliMfrO 4 44(44-00 *PS:14 .?! , c , ,•:‘4 ,, o0c1g,; , 4i,.pg , r- , Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4.00X8H-E:RIG (6,200,000.00) Project: Mitne Point Site: M Pt F Pad : Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 1 Rig Contractor: DOYON DRILLING INC. UVVI: I Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code I NPT NPT Depth Phase I Description of Operations (hr) (usft) 07:30 - 10:30 3.00 FISH P , DECOMP PJSM, LAY DOWN 3-1/2" TBG RETRIEVED 1 WITH BOT FISHING TOOLS. - PULLING PLUGGED FISHING STRING, PULLING WET PIPE. - DISCUSSED WELL CONTROL AND TRAPPED PRESSURE IN TBG. I - LAY DN 3-1/2" 9.3 # TBG. I - LAY DN TOP FISH JT, 84 FULL JTS TBG, 3 I PUP JTS, AND HES XD DURO SLIDING SLEEVE. 1 - LAST PUP OUT OF HOLE WAS THE 3-1/2" TC-II, FROM TOP OF PACKER. I I 1 I - TBG PUNCHED ABOVE AND BELOW SLIDING I SLEEVE. NO TRAPPED PRESSURE. I - TOP OF FISH @ -15,531' MD. , RECOVERED 66% OF A 3-1/2" TBG PIN. THAT i WAS ROLLED UP, FROM JT #12 OUT OF , HOLE.AND 2 PIECES OF TBG. 1.5" X 1.5". 10:30 - 11:00 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. I - OFF-LOAD 3.5" TBG OUT OF PIPE SHED. 11:00 - 12:00 1.00 FISH P DECOMP PJSM, BREAK-OUT FISH. 1 - P/U OVER SHOT AND BREAK OUT 3-1/2" TBG FISH.. I - FISH JT = 27.52' ! LOST 17 BBLS 12 PPG NABR PAST 12 HRS. 12:00 - 12:30 0.50 FISH I P DECOMP RIG SERVICE ' WSL / TOOLPUSHER, DISCUSSED: I I I I- PARKER WHEEL ROOM INCIDENT. - DOYON RIG 14 COW INCIDENT. I - WITH ED'S CREW. 12:30 - 14:00 1.50 FISH I P DECOMP PJSM, MAKE UP BHA # 12 TO SPEAR WASH PIPE / CUTTER BHA LEFT IN HOLE. I - M/U BOT 4.961" ITCO SPEAR- EXTENTION- XO-STOP SUB W/6" RING-BUMPER I SUB-JAR-COLLARS I - BHA = 310.49' 14:00 - 18:30 4.50 FISH P DECOMP RIM WITH STANDS FROM DERRICK - F/ 310' T/ 13095' 18:30 - 21:00 2.50 FISH P I DECOMP RIH, P/U DRILL PIPE 1X1 - F/ 13095' T/ 15003' MD 21:00 - 22:30 1.50 FISH P DECOMP PJSM FOR CUT AND SLIP DRILLING LINE 1 - CUT AND SLIP 68' DRILLING LINE - INSPECT DRAVVWORKS, GREASE DYNAMATIC BRAKE SPLINE 22:30 - 00:00 1.50 FISH P DECOMP PULL SLIPS, CLOSE ANNULAR AND LINE UP I ON GAS BUSTER ' - CBU lx, 5 BPM = 1250 PSI i - LOSS RATE DURING CIRCULATION = 6 BPH ,- OA = 140 PSI I - 24 HOUR FLUID LOSS = 50 BBLS -- , 5/5/2013 00:00 - 01:00 1.00 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT . I CHECKS - CONTINUE CBU THRU GAS BUSTER - 5 BPM = 1250 PSI I i I - LOSS RATE DURING CIRCULATION =6 BPH I ( I I -MONITOR WELL 10 MINUTES Printed 5/20/2013 10:10:52AM • • , 5::,,..,r r .1:;x; , . ,, :zf,xffl m o;Armx-ow.,'we475; Ay yAr, w a fiwt* . w -t ; A, w oioxg7c. , ,F,Q::,v:;a74.qv.gvnxv;x4000* :464", • wz'.: g:VWV;•;: i;rektwm Algt AP 4•AVVW;KAW :. mr. :ef..., 1,A 4w •pi.:. "-.Y4 4' • • Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 01:30 0.50 FISH P DECOMP RIH TO ENGAGE 53/4" WASH PIPE FISH - F/ 15003 T/ 15192' - PUWT = 237K, SOWT = 95K, 3 BPM = 450 PSI - TAG TOP OF 53/4" WASH PIPE FISH AT 15211' MD - OBSERVE GRAPPLE ENTER TOP OF FISH TO 15213' MD - SET DOWN 25K ON SPEAR 3X - P/U AND SEE 20K OVERPULL OFF BOTTOM - NEW PUWT = 252K - MONITOR WELL 10 MINUTES - BLOW DOWN TOP DRIVE AND GAS BUSTER 01:30 - 08:00 6.50 FISH P DECOMP POOH WITH 53/4" WASH PIPE FISH - F/15213' T/ 301 MD - MONITOR WELL F/ 10 MIN. SLIGHT LOSSES. 08:00 - 10:00 2.00 FISH P DECOMP STAND BACK COLLARS IN DERRICK - UD XO, JARS. - BREAK OUT AND UD SPEAR ENGAGED IN THE CROSS OVER BUSHING. - L/D 10 JTS WASHPIPE AND SHOE - TWO 1/4" PIECES MISC METAL DEBRIS RECOVERED FROM FISH. - DISCUSS WITH ETL ON THE MAGNETS TO BE RUN ON NEXT BHA. 10:00 - 11:00 1.00 CASING P DECOMP PJSM, MAKE UP BHA # 13 TO DRIFT 7" 26# CSG. - M/U BOT 3-1/2" BULL NOSE - 6.151" SMOOTH OD STRING MILL- 6.151" SMOOTH OD STRING MIL - - PIN BY PIN SUB - (3) BOOT BASKETS - BIT SUB - (2) 4-3/4"XTTREME MAGNETS - BUMPER SUB - - BOWEN OIL JAR -XO - COLLARS - BHA = 354.63' 11:00 - 12:00 1.00 CASING P DECOMP RIH VVITH 6.151" STRING MILLS ON 4" DP FROM DERRICK - F/ 354' T/ 3198' MD - LOST 17 BBLS OF 12 PPG NABR (BRINE) THE PAST 12 HRS. 12:00 - 12:30 0.50 CASING P DECOMP SERVICE RIG - PERFORM SPCC AND EQUIPMENT CHECKS. 12:30 - 17:30 5.00 CASING P DECOMP RIH VVITH 6.151" STRING MILLS ON 4" DP FROM DERRICK - F/ 3198' MD - T/ 14658' MD - TRIP IN HOLE AT ESP COMPLETION SLACK-OFF SPEED. 17:30 - 20:30 3.00 CASING P DECOMP , CIRCULATE BOTTOMS UP - MAKE UP TOP DRIVE, LINE UP TO CIRCULATE TO GAS BUSTER - OBTAIN SLOW PUMP RATE OF 260 PSI AT 2 BPM - CIRCULATE BOTTOMS UP AT 5 BPM AND , 1130 PSI - LOSS RATE DURING CIRCULATION = 5 BPH - MONITOR WELL FOR FLOW - CONFIRM NO FLOW - BLOW DOWN LINES, PREPARE TO TRIP OUT OF HOLE Printed 5/20/2013 10:10:52AM • • • .., ✓.,4. ,. ::, ./, rte,. 3 /�„ a / :/' %'- r /7 ° -ri / �'.✓' r� ' /�.. R / 1 ' h 7 z ; ., , 3 .;; :;w','3i�i r�/' /H,� z /.rt'i �/ :, /�., >:, /ri "i; ,�� .,� �r r / .r r� , ,4 - , �'�,.n;r ,i /� . , . _ ../ ( : / / /� R / > / � %� %n / 'r "p' /� ZZ , : f s r / � .m'{ r-1, %�l/G�'�t,'sT3 Common Well Name: MPF -57 AFE No Event Ty pe: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @a 40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 00:00 3.50 CASING P DECOMP PULL OUT OF HOLE WITH BHA # 13 ( 6.151" STRING MILLS ON 4" DP) - POOH FROM 14658' MD - POOH TO 5500' MD 24 HR LOSSES = 36 BBLS KWF 5/6/2013 00:00 - 02:00 2.00 CASING P DECOMP SAFETY MEETING & SPCC CHECKS - POOH FROM - 5,500' MD WITH STRING MILL ASSEMBLY (BHA # 13) - STOP AT 354' MD - FLOW CHECK - MINIMAL LOSSES 02:00 - 04:00 2.00 CASING P DECOMP PJSM W/ BOT & RIG CREW ON PULLING BHA THROUGH STACKAND LAYING DOWN STRING MILLASSEMBLY - BREAK OUT & LAY DOWN 4-3/4" DRILL COLLARS 1 - LAY DOWN MAGNETS - SMALL AMOUNT OF METAL FINES RECOVERED ACROSS MAGNETS - LAY DOWN STRING MILLS 04:00 - 05:00 1.00 CASING P DECOMP - REMOVE BOT EQUIPMENT FROM PIPE SHED AND RIG FLOOR - CLEAN AND CLEAR RIG FLOOR 05:00 - 11:00 6.00 CASING P DECOMP PJSM, PU / MU 7" HES RBP PACKER PER HES REP. - RIH ON 4" HT -38 DRILL PIPE FROM DERRICK. - RIH TO 15,225' MD. - PUW = 215K INCLUDING 40K TOP DRIVE / BLK WT. SOW = 95K. 111:00 - 12:00 1.00 CASING P DECOMP PJSM FOR CUT AND SLIP DRILLING LINE PER CALCULATED TONNE MILES. - CUT AND SLIP 75' DRILLING LINE - INSPECT DRAWWORKS, GREASE DYNAMATIC BRAKE SPLINE. 12:00 - 12:30 0.50 CASING P DECOMP PJSM, SETTING HES RPB. - WSL, TOOLPUSHER, HES REP, AND RIG CREW IN ATTENDANCE. - DISCUSSED HIGH PRESSURE AREAS -STAY CLEAR OF RIG FLOOR DURING TEST. 12:30 - 13:30 1.00 CASING P DECOMP RECIPROCATE / CIRC WHILE OBTAINING PARAMETERS FOR SET DEPTH. - CIRC 3 BPM © 380 PSI. - SET 7" HES RBP @ 15,200' MD. PER HES REP. - ROTATE( 5) LEFT HAND TURNS. SET DOWN 25K. - PUW = 215K INCLUDING 40K TOP DRIVE / BLK WT. SOW = 95K. Printed 5/20/2013 10:10:52AM • • :1; 4 •:4r- ,ziktAtiii(*tir 40 W,71 ; : „ , ;' • r -" , Y„ ;'p,ff„ „ • • 4 ; , f• ,;.„„ ' • VASW „1:100.011 us** ; Oft Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) I Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Mihe Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 15:30 2.00 CASING P DECOMP PJSM, MIT-IA, 7" L-80 26# BTC CSG. - WSL / TOOLPUSHER VERIFY VALVE ALIGNMENT. - PUMPED 60 STKS ( 5.7 BBLS) 12 PPG KWF TO / 3500 PSI FOR 30 CHARTED MINUTES. - OA PRESSURE INCREASE PRE TEST 10 TO 290 PSI DURING TEST, RETURN TO 10 PSI AFTER TEST. - MIT-IA TEST, MEETS BP STP CRT-AK-10-45 CRITERIA. - RECEIVED PERMISSION TO PROCEED FROM WTL. - BLEED OFF PRESSURE. " 0 " READING. BLED BACK --4.6 BBLS. - WSL/TOOLPUSHER/DRILLER VERIFIED NO TRAPPED PRESSURE. - BREAK CIRC DOWN DP UP THE IA - RIG DOWN TEST EQUIPMENT. 15:30 - 21:00 5.50 CASING P DECOMP PJSM, POH WITH 4" DP AND STAND BACK IN DERRICK. - POH TO 2924 MD 21:00 - 21:30 0.50 CASING P DECOMP PJSM, PU / MU 7" HES RTTS PER HES REP. - RIH ON 1 STAND 4" HT-38 DRILL PIPE FROM DERRICK. - RIH TO 100 FT BELOW RKB - PUW = 77K INCLUDING 40K TOP DRIVE / BLK WT. SOW = 75K 21:30 - 23:00 1.50 CASING P DECOMP SET 7" HES RTTS -90' MD. PER HES REP. - ROTATE 1/4 TURN TO THE RIGHT. - SET DOWN 36 K - PRESSURE TEST RTTS FROM ABOVE - TEST 250 PSI LOWAND 3500 PSI HIGH FOR 5 CHARTED MINUTES 1 23:00 - 00:00 1.00 CASING P DECOMP PREPARE FOR NIPPLE DOWN OF BOPS - BLOW DOWN CHOKE AND KILL LINES - SUCK OUT STACK -PULL WEAR RING 24 HR LOSSES = 24 BBLS 5/7/2013 00:00 - 02:00 2.00 WHSUR P DECOMP PRE-TOUR MEETING, SPCC CHECKS PJSM WITH RIG CREW ON N/D BOP - NIPPLE DOWN 13-5/8" BOP - INSTALL 11" FMC TC SPOOL ATTACHMENT AS PER FMC REP 02:00 - 03:30 1.50 WHSUR P DECOMP 1NIPPLE UP BOPS 1- INSTALL WEAR RING - RUN IN LOCK DOWN SCREWS 03:30 - 04:30 1.00 WHSUR P DECOMP !PRESSURE TEST BOP AND SPOOL BREAKS - PT BREAKS AGAINST SHALLOW SET STORM PACKER - TEST 250 PSI LOW AND 3500 PS HIGH FOR 30 CHARTED MINUTES Printed 5/20/2013 10:10:52AM • • ' filoi4tAiti60*0 -7.! Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 05:30 1.00 CASING P DECOMP PJSM WITH HES AND RIG CREW TO PULL 7" HES STORM PACKER - M/U STORM PACKER PULLING TOOL AND TIW VALVE - RELEASED TOOL WITH ANNULAR CLOSED - MONITOR WELL FOR 10 MINS - CONFIRM NO FLOW, VERIFY NO TRAPPED PRESSURE - OPEN ANNULAR - POOH & LAY DOWN STORM PACKER 05:30 - 09:00 3.50 CASING P DECOMP PJSM, RIH WITH 4" DP FROM DERRICK - RIH FROM 2924' MD. TO 15,200 MD. FROM DERRICK. - OBTAIN PARAMETERS TO UNSEAT HES RBP PER HES REP. 09:00 - 10:00 1.00 CASING P DECOMP PJSM, UNSEAT HES RBP. - LATCH INTO RPB WITH 4" DP FROM DERRICK. - CLOSE ANNULAR.. - UNSEAT HES RBP. - MONITOR WELL 10 MIN. - CONFIRM NO FLOW, WSL VERIFY NO TRAPPED PRESSURE 10:00 - 11:30 1.50 CASING P DECOMP CBU THROUGH RIG CHOKE AND GAS BUSTER. - CIRC .6 PERCENT SAFE LUBE SOLUTION 5 BPM @ 1040 PSI. - 11 BBLS KWF PUMPED AWAY DURING CBU. - NO GAS OR OIL TO SURFACE NOTED. - PUMPS OFF TO MONITOR WELL 10 MIN. 11:30 - 12:00 0.50 CASING P DECOMP PJSM, OPEN ANNULAR. - MONITOR WELL 40 MIN. - WSL, TOOLPUSHER VERIFY NO FLOW. 12:00 - 12:30 0.50 CASING P DECOMP PJSM, PULL HES RBP. - PULL 1 STAND 4" HT-38 DP FROM 15,200' MD TO 15,120' MD. - RIH PAST SETTING DEPTH TO 15,246' MD TO VERIFY FREE. 12:30 - 13:00 0.50 CASING P DECOMP SERVICE RIG EQUIPMENT AND INSPECT. - PREP FLOOR EQUIPMENT TO POH. 13:00 - 21:30 8.50 CASING P DECOMP POH VVITH HES RBP ON 4" HT-38 DP FROM 15,246' MD. - LAY DOWN DP 1X1 TO PIPE SHED. - PLACE DP IN NEW PIPE TUBS FROM PIPE SHED. - POOH TO 5440' MD 21:30 - 22:00 0.50 CASING P DECOMP KICK WHILE TRIPPING DRILL AAR: - RELIEF DRILLER & RELIEF FLOOR HAND - GOOD AWARENESS & REACTION TO SITUATION - DISCUSSED HAVING THOROUGH HANDOVERS EVEN IF FILLING A ROLE FOR A FEW MINUTES 22:00 - 00:00 2.00 CASING P DECOMP CONTINUE OUT OF HOLE WITH HES RBP ON 4" HT-38 DP FROM 5440 MD. - LAY DOWN DP 1X1 TO PIPE SHED. - POOH TO 3000' MD 24 HR LOSSES = 20 BBLS KWF Printed 5/20/2013 10:10:52AM • • U° 6,NOzeoyei T „ Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/8/2013 00:00 - 03:00 3.00 CASING P DECOMP PRE-TOUR MEETING, SPCC CHECKS PULL OUT OF HOLE WITH 7" HES RBP ON 4" HT-38 DP FROM 3000' MD. - LAY DOWN DP 1X 1 TO PIPE SHED 03:00 - 03:30 0.50 CASING P DECOMP PJSM W/ HES & RIG CREW ON PULLING RBP THROUGH STACK AND LAYING DOWN ASSEMBLY - LAY DOWN RBP - ELEMENTS SHOW CUT DAMAGE BUT ARE IN-TACT - M/U 4" TIW ON SAFETY JOINT 03:30 - 04:00 0.50 CASING P DECOMP MAKE UP WEAR RING PULLING ASSEMBLY - PULL WEAR RING - CLEAN AND CLEAR RIG FLOOR 04:00 - 08:00 4.00 RUNCOM P RUNCMP PJSM WITH CENTRILIFT AND RIG CREW FOR PICKING UP AND SERVICING MOTOR ASSEMBLY 1- MOBILIZE CENTRILIFT TOOLS TO RIG FLOOR - RIG UP CENTRILIFT SHEEVE - MAKE UP & SERVICE MOTOR ASEMBLY, THEN LAY MOTOR DOWN IN PIPE SHED. 08:00 - 09:30 1.50 BOPSUR P RUNCMP PREP RIG FLOOR TO TEST BOPS. RUN TEST PLUG IN TO TUBING HANGER PROFILE. BACK OUT LANDING JOINT. 09:30 - 18:30 9.00 BOPSUR P RUNCMP TEST 4-PREVENTER BOP STACK AND ANNULAR, ALL CHOKE VALVES AND FLOOR VALVES TO 250 / 4000 PSI. AOGCC HAS WAIVED WITNESS. BOP TEST IS WITNIESSED BY TOOLPUSHER AND WSL. 18:30 - 19:00 0.50 BOPSUR P RUNCMP PREP FOR COMPLETION MAKE UP - PULL TEST PLUG - CLEAN AND CLEAR RIG FLOOR - POSITION EQUIPMENT IN PIPE SHED AND TOOLS ON FLOOR 19:00 - 20:30 1.50 WHSUB P RUNCMP PJSM WITH CENTRILIFT, BAKER , DOYON CASING AND RIG CREW FOR PICKING UP MOTOR ASSEMBLY, DUMMY HANGER - PICK UP MOTOR ASEMBLY FROM PIPE SHED - MAKE UP SEAL ASSEMBLY - BOLT ON TTC DRILLED TUBING CROSSOVER TO SEAL ASSEMBLY - TOURQUE 4-1/2" 521 HYDRIL X 4-1/2" NSCT PIN X/0 ONTO TTC X/0 - LAY DOWN 4 FT HYDRIL 521 HANDLING PUP - MAKE UP & TORQUE 23.48 FT HYDRIL PUP AND 36.71 FT HYDRIL JOINT 20:30 - 21:00 0.50 WHSUB P RUNCMP MAKE UP 11" FMC DUMMY TUBING HANGER W/ TC-Il LANDING THREADS - LAND HANGER PER FMC REP - PU WT = 45K, SOW = 42K. INCLUDING 40K TOP DRIVE WT. - HANGER SET - RUN IN LOCK DOWN SCREWS PER FMC REP - LAY DOWN LANDING JOINT Printed 5/20/2013 10:10:52AM • • i • °�; / ",?'. /a' „ms's "'r' //. �i G /' ° %LY Gr✓�'4`> MTV j ,�' a . rLi % . �, , >,�,u,v " " / %r te . % ✓ ;,/ �;s /// ti ',rm�' vs%/ ////� /�%y %/ /;,r 'JY_ 'i's % < ,:;,, i / ',. i " / : ,.r , „/ . /��.,r� /�/ i�.^`` �.e,s �. i � �i` , /l G'..;x >/' :C s„r �` {r, wti ��" � � /; /- r ,y � /,:l /� . �e��'�/ � a' , . ..?lr �. n, " / /i y /,? si, < 4 't ii /1 „F / / :< r � / r� 5 a � "� t • s v .�, s , /r% �n / ,rf'� /�! / / /! /rr j ° ��, 0/ - ��i. :o< "�ya / / � �y ; a , i. fir s r / /f n.i /� % %, �. %%r � ,f� , ti � r, ,r .✓,< / , d � rr / a % % Cvdi Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4 -00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 22:00 1.00 RUNCOM P RUNCMP PJSM WITH RIG CREW & BOT TO MAKE UP PUMP RUNNING ASSEMBLY - CLOSE BLIND RAMS - PICK UP 3 JTS 2 -7/8" PAC DRILL PIPE AND 3-1/2" BUMPER SUB - ATTACH 4" HYDRAULIC GS SPEAR - OPEN BLINDS TORQUE CONNECTIONS 22:00 - 23:00 ' 1 00 RUNCOM P RUNCMP RUN PUMP ASSEMBLIES - PICK UP PUMP ASSEMBLY #1 AND ENGAGE GS SPEAR - RIH 82' AND LAND ON TTC COUPLING - PUMP 1 BPM @ 660 PSI TO RELEASE GS SPEAR - POOH AND CHANGE OUT 4" SPEAR FOR 3" 23:00 - 00:00 1.00 RUNCOM P RUNCMP RUN PUMP ASSEMBLY #2 - ENGAGE GS SPEAR ONTO PUMP #2 - RIH 59' , LAND ON TOP OF PUMP #1 - PUMP 1 BPM @ 360 PSI TO RELEASE GS SPEAR - POOH 24 HR LOSSES = 16 BBLS KWF 5/9/2013 00:00 - 01:30 1.50 RUNCOM P RUNCMP DISCUSS SPECIFIC STEPS FOR LANDING TTCESP IN PRE -TOUR MEETING - PERFORM SPCC CHECKS - RUN PACK OFF ASSEMBLY - ENGAGE GS SPEAR ONTO PACKOFF ASSEMBLY - RIH 52' , LAND ON TOP OF PUMP #2 - SET PACKOFF ELEMENTS WITH 5 K DOWN WEIGHT - PUMP 1 BPM @ 330 PSI TO RELEASE GS SPEAR - POOH 01:30 - 02:30 1.00 RUNCOM I P RUNCMP MAKEUP PACK OFF TEST TOOL - MAKE UP VVIRELINE DS TOOL AND TEST TOOL - RIH 47' AND STING INTO PACK OFF ASSEMBLY, SHEAR OFF TOOL - PRESSURE TEST PACK OFF FROM ABOVE TO 1000 PSI FOR 5 CHARTED MINS 02:30 - 03:00 0.50 RUNCOM P RUNCMP RETREIVE PACK OFF TEST TOOL - STING INTO DS TOOL , PULL TO FLOOR AND LAY DOWN - MAKE UP TUBING STOP WITH SHEAR PIN INSTALLED ON GS 03:00 - 03:30 0.50 RUNCOM P RUNCMP LAND TUBING STOP - RIH 50 FT , ENGAGE TUBING STOP ON TOP OF PACKOFF - PICK UP 1000 # AND SHEAR THE BRASS PIN -POOH 03:30 - 04:00 0.50 RUNCOM P RUNCMP PJSM WITH BOT, LAYING DOWN TOOLS - LAY DOWN BAKER GS SPEAR , BUMPER SUB, j - LAY DOWN 2 -7/8" PAC Printed 5/20/2013 10:10:52AM • 4"44 "A; 444 40;g44 4 4J 4 4 444 4 44: : , !'4 444 4 *4,4"4,';,/,,„ 720.5.'40e, , -; : ' ;444444- 4.44I4441'S4444iX,'' - /)4444.4t(att44 Attii: . ;:f4M.,4441:4441 , 1 , i4,61VA Common Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table @)40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 05:00 1.00 RUNCOM P i RUNCMP PJSM WITH FMC, PULLING DUMMY HANGER - PICK UP LANDING JOINT - BACK OUT LOCK DOWN SCREWS - UNSEAT 11" FMC DUMMY TUBING HANGER W/ TC-II LANDING THREADS TO FLOOR - LAY DOWN LANDING JOINT & HANGER - PULL MOTOR TO RIG FLOOR 05:00 - 06:00 1.00 RUNCOM P RUNCMP PJSM VVITH CENTRILIFT, RIG UP TO RUN 1 COMPLETION. - HAND PULL ESP POTHEAD AND CABLE OVER SHEAVE TO RIG FLOOR. - CENTRILIFT REP MAKE CONNECTIONS TO MOTOR ASSEMBLY. - CHECK CONDUCTIVITY PRIOR TO RIH. - MOBILIZE CLAMPS TO RIG FLOOR AND ORGANIZE. -WSL AND DRILLER VERIFY PIPE COUNT IN SHED. 06:00 - 09:30 3.50 RUNCOM P RUNCMP START M/U 4-1/2 CSH ESP COMPLETION. CHECK CONDUCTIVITY EVERY 1000 FT. USE TORQUE-TURN SERVICE FOR ALL CONNECTIONS. AT 0750 CONDUCT KICK WHILE TRIPPING DRILL. SIMULATE CUTTING THE CABLE THEN RIH AND PLACE CLEAN PIPE ACROSS THE BOPS. INSTALL TIW VALVE AND TORQUE IT UP. ALL HANDS REPORT TO ASSIGNED POSITIONS, THEN DISCUSS DRILL. CONTINUE RIH WITH COMPLETION. 09:30 - 10:30 1.00 RUNCOM P RUNCMP AFTER 35 JTS RAN, SOME FLOW OBSERVED FROM INSIDE PIPE AS ITS RUN IN. STOP HERE AND CHECK CONTINUITY, GOOD. CIRC B/U, CHECK OUT DENSITY. OUT DENSITY IS 11.9 PPG. MIX 10 SACKS NABR TO BRING DENSITY UP TO 12.0 PPG. LOSE 0.5 BBLS ON CIRCULATION. SHUT DOWN AND FLOW CHECK NO FLOW FROM PIPE OR ANNULUS. CONTINUE RIH WITH COMPLETION. 10:30 - 18:00 7.50 RUNCOM P RUNCMP CONTINUE M/U COMPLETION. CHECK CONDUCTIVITY EVERY 1000 FT. PUMP THROUGH EVERY 2000 FT. DOG COLLAR ALL CONNECTIONS. 18:00 - 00:00 6.00 RUNCOM P RUNCMP RIH WITH 4-1/2" 12.6# HYDRIL 521 TUBING & THROUGH TUBING ESP COMPLETION FROM PIPE SHED. - TUBING TORQUE = 4700 FT/LBS. - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONDUCTIVITY OF CABLE EVERY 1000 FT - PUMP 10 BBLS DOWN TUBING EVERY 2000' - PUMP 1 BPM AT 1050 PSI - RIH TO 6200 MD - 24 HOUR FLUID LOSS = 16 BBLS Printed 5/20/2013 10:10:52AM • • �:.d- % /,, : ✓ /, %C °y'/' ' % . "`" i�l '' , � ;, s / - ,i / 'rz,nn✓w .r ,' :r ` ' % "' %,h /' "Q.,t;'/f; rr :*r/ / / , , <j ::. / qs r ;- ./, / �k: /.. 9.1 ?' `. • + ;i /:;.'j:' ✓ „ r ' //�/ „ ` Q ;'�,','.2 4 '^ y±r µ /�;F :" ;y ; � , y „,,Vj.. �jJ�: % /rr%,� � / ?. /'., ,r ,,; • a r� :; /i ,:�� ; .� : , G ,� 4 �; • � , % / t"., y ear,. ” � ,/;. / � j /. / ', �' ;r /'r �� r� / -; / f � �/r r . �'�, r % "; / / %�/!.5., "%/ . '� .� ' % /?;,� /'> /r , yam .., ; / i= /� a % r.": :�'i�% al.. a //X / , .. �j,'', 9% / _:' '' ;!i i%" / �.q's`'' / / /rf' ^ <� %•r�r' '/'3.'Sr!>✓ii .,.1.,, <s -. , - .. : � /�i: / ri.� r.7% /r "ari, r / � .- ; /r, c.� 91 �'f � ! • .,: r J:,� / �r� H Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4- 00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table t40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/10/2013 00:00 - 02:00 2.00 RUNCOM P RUNCMP PRE -TOUR MEETING AND SPCC CHECKS RIH WITH 4-1/2" 12.6# HYDRIL 521 TUBING & THROUGH TUBING ESP COMPLETION FROM PIPE SHED. - RIH FROM 6200' MD I- TUBING TORQUE = 4700 FT /LBS. - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONDUCTIVITY OF CABLE EVERY 1000 FT - PUMP 5 BBLS DOWN TUBING EVERY 2000' - PUMP 1/2 BPM AT 600 PSI 02:00 - 08:00 6.00 RUNCOM P RUNCMP CENTRALIFT REP PERFORM REEL TO REEL ESP CABLE SPLICE - SPLICE MADE AT -7380' MD - CIRCULATE BOTTOMS UP DOWN TUBING AT 1 BPM & 1300 PSI RIHTO8100FT. 08:00 - 09:30 1.50 RUNCOM N WAIT RUNCMP WAIT ON DAY CREW TO ARRIVE FROM CAMP. DAY CREW IS ARRIVING ABOUT 1.5 HRS LATE DUE TO BEING DELAYED GETTING BACK TO CAMP LAST NIGHT DUE TO A RIG MOVE. WHILE DAY CREW IS AWAY, RIG IS MANNED BY TOOLPUSHER, NIGHT DRILLER, ELECTRICIAN, CASING HAND AND CENTERLIFT HAND. CONDUCT KICK DRILL WITH THESE PERSONNEL TO ENSURE WELL CAN BE SHUT IN WITH LIMITED CREWS, IT CAN. 09:30 - 14:00 4.50 RUNCOM P RUNCMP DAY CREW ARRIVE. PJSM THEN CONTINUE M/U COMPLETION FROM 8100 FT. 14:00 - 14:30 0.50 RUNCOM P RUNCMP STOP AT 9300 FT AND CHECK CONTINUITY. UNRAVEL SMALL TANGLE ON CABLE REEL. _ 14:30 - 00:00 9.50 RUNCOM P RUNCMP CONTINUE RIH WITH 4-1/2" HYDRIL 521 COMPLETION AND TTCESP ASSEMBLY - RIH FROM 9300' MD - TUBING TORQUE = 4700 FT /LBS. - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONDUCTIVITY OF CABLE EVERY 1000 FT - PUMP 5 BBLS DOWN TUBING EVERY 2000' - PUMP 1 BPM AT 1080 PSI - RIH TO 13,200' MD 24 HR LOSSES = 16 BBLS 5/11/2013 00:00 - 02:30 2.50 RUNCOM P RUNCMP CONTINUE RIH WITH 4-1/2" HYDRIL 521 COMPLETION AND TTCESP ASSEMBLY - RIH FROM 13200' MD - TUBING TORQUE = 4700 FT /LBS. - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONDUCTIVITY OF CABLE EVERY 1000 FT - PUMP 5 BBLS DOWN TUBING EVERY 2000' - PUMP 1 BPM AT 1080 PSI Printed 5/20/2013 10:10:52AM • Common Well Well Name: MPF-57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4-00X8H-E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table @40.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 06:30 4.00 RUNCOM P RUNCMP PJSM, M/U TBG HANGER, R/D CABLES AND SHEAVE. - M/U 11" FMC TBG HANGER TO LANDING JT. AND ORIENT PER FMC REP - FMC REP INSTALL ESP PENETRATOR INTO HANGER. - CENTRILIFT REP MAKE FINAL SPLICE AND TERMINATE CABLE 06:30 - 07:00 0.50 RUNCOM P RUNCMP FINISH CABLE TERMINATION AT HANGER. - PICK UP AND INSTALL FINAL CLAMP. - LAND TUBING HANGER WITH 160K UP WT, 87K DOWN WT. - HANGER SET, ESP CENTRALIZER AT 14565 ' MD. - RUN IN LOCK DOWN SCREWS PER FMC REP - LAY DOWN LANDING JOINT CLAMPS RUN: -360-2 CANNON CLAMPS - 3 - PROTECTOLIZERS - 2 - FLAT GAURDS 07:00 - 08:30 1.50 RUNCOM P RUNCMP DRY ROD IN TWC - PRESSRE TEST TWC FROM BELOW, PUT 500 PSI ON IA FOR 10 MIN WITH 0.5 BPM INJECTION RATE. I- VISUALLY CONFIRM NO LEAK FROM TWC. - PRESSURE TEST FROM ABOVE TO 250 / 3500 PSI, GOOD. 08:30 - 12:00 3.50 RUNCOM P RUNCMP REMOVE BOPS. CENTERLIFT PERFORM FINAL CHECKS IPRIOR TO INSTALLING TREE. 12:00 - 17:00 5.00 WHSUR P WHDTRE INSTALL TREE. PRESSURE TEST VOIDS TO 5000 PSI AND CHART. PRESSURE TEST TREE FLANGE AND BODY TO 250 / 3500 PSI, GOOD. 17:00 - 21:00 4.00 WHSUR WHDTRE PJSM, R/U AND TEST DSM LUBRICATOR - TEST 250 / 3500 PSI, FOR 5 CHARTED I MINUTES. - PULL TWC - RETEST LUBRICATOR, INSTALL 4" TYPE 'H' BPV. - PERFORM 500 PSI ROLLING TEST FROM BELOW. 1- 0.75 BPM / 600 PSI, 9 BBLS PUMPED. 21:00 - 23:00 2.00 RIGD P PRE PREP FOR RDMO - FLUSH LINES WITH FRESH WATER - BLOW DOWN / RIG DOWN LINES - CLEAN PITS - R/D SECONDARY KILL AND CEMENT LINES Printed 5/20/2013 10:10:52AM • • � :r --` : % %i` rr; ":,, r/n: rnia .,, / // � 7 -':f // ro // ri r'i o; �n:.,,. o,vr.�..,,�:,ia pa , p .- ,,;;4-Tj'!' , ,.,/f. '/. „/.c :,, y6' '/7„ - ! ;i / - f':^. ",ti >: /', ` r;�i /, „/. /. / -�,:' %;r4 %. .� /'YC< , � 443-#11,0P ..'€`,"j;'y j., ...y'ia r...i/ r" 27./ / ��,i,'� .h / yr rn „ „� r, w: , %y; ✓ ,� .� //t;:✓ ,� . !., � � % ” . i% / �'; , � ,, sr,., � / / ,,4,; '/r': .. .rte. .. O� ,:...r .. ../ - .., ;: .. /� -,. ,d, a' r, ;'s'- ( ,ri. ,� /�r �ii(�p ,w i %iii', ".�8: <7 % / -,� / F s , �;:z t ;a. vrr Common Well Name: MPF -57 AFE No Event Type: WORKOVER (WO) Start Date: 4/18/2013 End Date: 5/11/2013 X4- 00X8H -E:RIG (6,200,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/9/1997 12:00:00AM Rig Release: 5/11/2013 Rig Contractor: DOYON DRILLING INC. UVVI: Active datum: Kelly Bushing / Rotary Table ©40.80usft (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 RIGD P PRE MOBILIZE EQUIPMENT IN PREPARATION FOR RIG MOVE - MOVE FUEL TRAILER AND SLOP TANK TO MP L PAD - RIG DOWN 0/A LINE, INSTALL FLANGE - SECURE TREE AND CELLAR - RAISE CELLAR DOORS 24 HR LOSSES = 33 BBLS KWF - SITP = 0 PSI - SICP =0 PSI - OA = 50 PSI - RELEASED RIG FROM MPF -57A FOR MOVE TO MPL -20 AT 23:59 HRS, 5-11 -2013. Printed 5/20/2013 10:10:52AM Tree: 4 1/16" - 5M Caglipn MPF -57A Orig. Lev. = 40.8' (N 22E) Wellhead: FMC 11" x 4. bg. Orig. ev. = 12.1' Hanger: TC -B -EC 11 "x 4.5" DF To 7" csg. hng. = 27.9' (N 22E) Atlas Bradford TC -II 4" CIW - Type H BPV profile Casing landed on emergency slips w/ 230k down 20" 91.1 ppf, H -40 I 115' Howco 9 5/8" 'ES' Cementer 9 5/8" Whipstock top 9317' Window in 9 5/8" 9340 -9356' This well has been sidetracked from the 7" CIBP set @ 9490` original completion. Min. ID in tuN " li 15,554 .. , in. Severe bing is X dog lea 2.75 12890 130 00', Hiah PIt1 wts after 14500'.'*`" 9 5/8 ", 40 ppf, L -80 Btrc. r 1.340 A , D &D Tbg Stop 1 14,474' KOP @ 500' D &D PackoffAssy Max. hole angle = 70 to 76 deg. ( 14,476 f/ 3600' to 14,000' w/ Kobe Knockout Hole angle thru' perfs = 11 deg. Centrilift TTC -ESP Top 14,485'1 Z. r` - TTC Drilled Tbg Crossover 14,523' 1 4.5 NSTC PIN X4.5 521 HYDRILL BOX MEM Upper Tandem Seal Sections MN Model GSB3 DB UT /HL H6 PFS 14,533 , r- Er �,. Model MSP1 Motor,120 HP, _ MEM 3205 volt,23 amp, 1 14,547' 4[1] PumpMate = ' TVD Centralizer 14,563' Baker 7" x 3.5" 115,5311 Premier Pkr. 2.87" ID 4.5 12.6# L -80, Hydril 521 Tbg. (Drift ID= 3.958" ID, Cap = .0152 bpf) 1111 3.5" XN Nipple i (2.75" No -go ID) 115,554`1 7" 26 #, L -80, BTC casing (Drift ID = 6.151, Cap w/ tbg = .02758 bpf) II WLEG 115,562'1 Perforation Summary Ref log: 1/21/04 Halliburton "VTA" Retrievable 115891'1 Packer - 3.880" I.D. Size SPF Interval (TVD) 3 3/8" 12 15,972'- 15,982' 7,434`- 7,443' _ : : — Dual Weatherford 500 Micron • :... 15947 `- . Duragrip Screens " "' 16007' Fish: Top @ 15531' MD 5/13/13 ' Baker 7" x 3.5" Premier Pkr. 2.87" ID — r: : — Fish: Top ( 16076' MD 6/28/06 Note: 4ES RIH to 16070'. This is 6' above the fish. Lost during 4/28/04 RWO to ESP. Includes: Did not tag. 5 -16 -07 Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 4 1/2 XN and WLEG. 7" Weatherford float collar 1 16163' 1 . (PBTD) CU ct lost par 7 o 8 an slips mu g 2" x 1" x 3/4" thick) and • 7" Weatherford float shoe' 16244' 1 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). DATE REV. BY COMMENTS 5/02/01 M Linder Recompleted for Frac and Jet Pump MILNE POINT UNIT 6/22/01 B Hasebe ESP Completion Nabors 4ES 11/30/03 Lee Hulme Sidetrack and Frac String installed D -14 WELL MPF -57A gg WM • o : . 4 • L H u e�la u• .••• ' 5/ { EN HuIMe RR - t Eg bago�s 1ER API NO: 50- 029 - 22747 -01 -00 5/19/07 REH Re�iaccee ESP /Runbbcreens - 4ES 9/27/07 REH Pull ESP come. /Run J comp. -4ES BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder 3 / 67 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 5/A A 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 (10404) 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 It bbls ft pal 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 WA 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 WA 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 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF-38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF -41 1970950 50029227700000 0.8 N/A 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 -- -,B. MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF-66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/312011 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 NA 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 12 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 NA 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 8/132011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/32011 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 8/132011 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 9/12011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 _ 8/11/2011 • • ,tom _-.., MICROFILMED 03/01 /2008 DO NOT PLACE .~`=°:° ,~;,-- ,ate ~_ _- ~= ~;, ; ..q ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\C~rPgs_Inserts\Microfilm_Marker. doc STATE OF ALASKA ALA~KA OIL AND GAS CONSERVATION COM~SION ~~ REPORT OF SUNDRY WELL OPERATIONS 0~~2 ~® ~~~ ~`~~ ~.a ,. ~ ~aa~ 1. Operations Performed: ^ Abandon ®Repair Well - ~n~ ~~,"; ~ ^ Plug Perforations ^ Stimulate ^ Re-Ente~'~pend~~ ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Pull ESP/ Run Jet Pump completion ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ ®Development ^ Exploratory 203-167 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22747-01-00 .~ 7. KB Elevation (ft): KBE= 45.85' - 9• Well Name and Number: MPF-57A -~ 8. Property Designation: 10. Field /Pool(s): ADL 355017 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 16285 ~ feet true vertical 7743 'feet Plugs (measured) N/A Effective depth: measured 16163 feet Junk (measured) 16076' true vertical 7622 feet Casing Length Size MD ND Burst Collapse Structural Conductor 115' 20" 115' 115' Surface 9208' 9-5/8" 9340' 4621' 5750 3090 Intermediate Production 16211' 7" 16243' 7702' 7240 5410 Liner ~~„~~,~p NOV ~. ~ 2007 Perforation Depth MD (ft): 15972' - 15982' Perforation Depth TVD (ft): 7434' - 7444' 3-1/2", 9.3# L-80 15564' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Halliburton 'VTA' Retrievable Packer 15891' Dual Weatherford 500 Micron Duragrip Screen Assembly 15947' - 16007' 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-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 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 Aras Worthington, 564-4102 N/A Printed Name Sondra Stewman Title Drilling Technologist ~ Prepared By Name/Number: Si nature ~ .~ Phone 564-4750 t < Date (~' 7 "v7Sondra Stewman, 564-4750 ------ Form 10-404 Revised 04/2006 ~ ~ ~ ~ Submit Ori~~ l only Tree: 3 1/8" - 5M Ca Wellhead: FMC 11" x 3 1 2" Tbg. Hanger: TC-1A-EMS, 11"x 3.5" Atlas Bradford TC-II 3.5" CIW - Type H BPV profile 20" 91.1 ppf, H-40 115' 9 518" Whipstock top 9317' i Window in 9 518° 9340-9356' 7" CIBP set @ 9490' y 34u' 9 5/8", 40 ppf, L-80 Btrc. KOP @ 500' Max. hole angle = 70 to 76 deg. f/ 3600' to 14,000' Hole angle thru' perfs = 11 deg. "Reverse cirvianon'.iac wmp c«~"rei I I ~I R'~rM"~ LLI ~I , ~I 1 i i I I I { I I ~I Reservdr Fluid 3.5" 9.3# L-80 IBTM Tbg. (Drift ID= 2.867" ID, Cap = .0087 bpf) 7" 26#, L-80, BTC casing (Drift ID = 6.151, Cap w/ tbg = .02758 bpf) Perforation Summary Ref log: 1/21/04 Size SPF Interval (TVD) 3 3/8" 12 15,972`-15,982' 7,434`-7,443' Eish: Tom 16076` MD 8/28/06 Lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 4 1/2" XN and WLEG. CTU cut lost Darts 4/20/04: 7 of 8 anchor slips missing (2" x 1" x 314" thick) and 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). MPF-57A Orig. D~v. = 40.8' (N 22E) Orig. GL ev. = 12.1' DF To 7" csg. hng. = 27.9' (N 22E) "Casing landed on emergency slips w/ 230k down Howco 9 5/8" `ES' Cementer DATE REV. BY COMMENTS 0 1 .Linder ecomp eted or rac and Jet ump 1 /03 ee u me i track a d Fra n n talle -14 8/20/04 Lee Hulme Replace ESP -Nabors 4ES 5/25/05 Lee Hulme Replace ESP -Nabors 4ES 6/28/05 KDC Replace ESP -Nabors 4ES 5/19/07 REH Replace ESP/Run Screens - 4ES Camco 3 1/2" x 1" 2204` KBMG GLM This weN has been sidetracked from the original completion. Min. ID in tubing is XN 2.75" @ 15,554' ` *"* NOTE: Severe doq leg 12894-13004`. i Hig(~IU wts after 14540'. 3.5" HES "XD" Duro sliding sleeve I 2.813" ID (opens down) 15 476` It Baker 7" x 3.5" Premier Pkr. 2.87" ID 3.5" XN Nipple (2.75" No-go ID) 15,531` I 15,554` WLEG 15,562` I Ha{liburton "VTA" Retrievable 15891 ` I Packer - 3.880" I.D. Dual Weatherford 500 Micron 15947'- Duragrip Screens 16007' Note: 4ES RIH to 16070`. This is 6' above the fish. Did not tag. 5-16-07 7" Weatherford float collar 16163' (PBTD) 7" Weatherford float shoe 16244' MILNE POINT UNIT WELL MPF-57A API NO: 50-029-22747-01-00 BP EXPLORATION (AK) • BP EXPLORATION 'Page 1 of 4 Opelrations Summary Report Legal Well Name: MPF-57 Common Weli Name: MPF-57 Spud Date: 3/10/1997 Event Name: WORKOVER Start: 9/18/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/28/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/20/2007 06:00 - 07:30 1.50 RIGU P PRE Scope down derrick. Prepare to lay derrick down. Lay derrick down. 07:30 - 08:30 1.00 RIGU P PRE Prepare pits, sub and pipe shed to move. Notify pad operator to witness moving sub off of MPF-99. 08:30 - 12:30 4.00 RIGU P PRE Spot sub over MPF-57A. Spot pits and pipe shed. 12:30 - 13:00 0.50 RIGU P PRE PJSM -Raise derrick -All crew. 13:00 - 14:00 1.00 RIGU P PRE Raise derrick. 14:00 - 16:00 2.00 RIGU P PRE PJSM -Scope derrick up -All crew. Scope derrick. Accepted rig @ 16:00 hrs 9/20/2007. 16:00 - 18:00 2.00 RIGU P PRE RU lines to tree and Tiger tank. Loaded heated seawater into rig pits. 18:00 - 18:30 0.50 RIGU P PRE Held crew change and PJSM. Continued RU lines to tree and filling pits with heated seawater. 18:30 - 19:30 1,00 KILL P DECOMP PUMU lubricator and tested to 500 psi. Pulled BPV. LD lubricator. 19:30 - 23:30 4.00 KILL P DECOMP Tested lines to 3500 psi. Opened well, 1220 psi on tubing and inner annulus (IA). Pumped heated seawater down tubing taking returns through choke as follows: 1 bpm @ 600 psi; 2 bpm @ 900 psi; 4 bpm @ 1830 psi. Spotted 90 bbls seawater to open pocket mandrel at 15,610' md. Closed choke to shut in annulus and bullheaded 30 bbls heated seawater into formation: 1 bpm @ 800 psi; 2 bpm @ 1000 psi; 3 bpm @ 1700 psi. Reopened annulus and circulated a total of 625 bbls heated seawater until returns were clean. Held 500-700 psi back pressure while circulating. 23:30 - 00:00 0.50 KILL P DECOMP Shut in well and observed pressure build-up. ISITP 260 psi. 9/21/2007 00:00 - 03:00 3.00 KILL P DECOMP Continued monitoring well pressure buildup. SITP increased from 260 psi to 690 psi. Calculated resulting kill fluid density is 10.5 ppg with 75 psi overbalance. Filled rig pits with heated 10.9 ppg brine. 03:00 - 06:00 3.00 KILL P DECOMP Dis laced well to 10.9 brine. Pumped 4 bpm with pump pressure varying from 2050 to 1850 psi. Held 400-700 psi back pressure while displacing. 06:00 - 06:30 0.50 KILL P DECOMP Shut down pumping and monitor well for 30 minutes. Tubing on slight vacuum and IA stable. 06:30 - 07:30 1.00 KILL P DECOMP FMC dry rod set TWC. Test and chart_from below......... PR 07:30 - 10:30 ` 3.001 WHSUR~P 10:30 - 18:00 I 7.50 BOPSU P 18:30 - 2$:30 I 3.00 I BOPSU~ P 21:30 - 00:00 I 2.501 BOPSUR P 19/22/2007 100:00 - 03:00 I 3.001 BOPSUFd P 03:00 - 04:00 I 1.001 BOPSUF~P 04:00 - 04:30 I 0.501 KILL I P DECOMP ND Tree. DECOMP NU BOPE. Reconfigure 2 ram stack to 3 ram stack w/blind rams, 2-7/8" fixed rams and 2-7/8" x 5-1/2" VBR's. John Crisp - AOGCC waived state's right to witness BOPE test @ 1600-hrs. DECOMP Held crew change and PJSM. Performed pre-tour checks. DECOMP Installed choke line, MU adapter flange. Installed riser, blind and pipe rams. Function tested rams. MU test joint. DECOMP Tested BOPE to 250 psi low / 4200 psi high, annular to 250 psi low / 3500 psi high. All tests successful. DECOMP Continued BOPE test to 250 psi low /.4200 psi high, annular to 250 psi low / 3500 psi high. DECOMP Drained stack. RU lubricator and tested to 500 psi. Pulled TWC. RD lubricator. DECOMP Filled IA with 9 bbls 10.8 ppg brine. Lost 9.0-bbls. brine to well in 22-Hrs. Printetl: 90/23!2007 Z:SS:431'M C • BP EXPLORATION Paget of 4 Operations Summary Report Legal Well Name: MPF-57 Common Well Name: MPF-57 Spud Date: 3/10/1997 Event Name: WORKOVER Start: 9/18/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/28/2007 Rig Name: NABORS 4ES Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT Phase I Description of Operations 9!22/2007 104:30 - 11:00 I 6.501 KILL I P 11:00 - 15:30 I 4.501 KILL I P 15:30 - 17:00 1.501 KILL I P 17:00 - 18:00 1.00 PULL P 18:00 - 00:00 i 6.00 I PULL I P 19/23/2007 100:00 - 12:00 I 12.001 PULL I P 12:00 - 14:00 I 2.001 PULL I P 14:00 - 15:30 I 1.501 PULL I P 15:30 - 16:00 I 0.501 CLEAN I P 16:00 - 17:00 1.00 I CLEAN I P 17:00 - 18:00 1.00 CLEAN P 18:00 - 18:30 I 0.501 CLEAN P 18:30 - 21:00 2.50 CLEAN P 21:00 - 22:00 I 1.00 I CLEAN I P 22:00 - 00:00 2.00 CLEAN P 19/24/2007 i 00:00 - 02:00 I 2.00 I CLEAN I P 02:00 - 03:30 I 1.50 ~ CLEAN I P 03:30 - 05:30 2.00 CLEAN P 05:30 - 13:30 I 8.00 I CLEAN I P 13:30 - 15:45 I 2.251 CLEAN I P 15:45 - 16:30 I 0.75 f CLEAN I P 16:30 - 18:00 I` 1.501 CLEAN P 18:00 - 18:30 0.50 CLEAN P DECOMP Circulated well while waiting on 230-Bbls. 12.5-ppg brine to arrive from MI to weight up brine density to 11.2-ppg. S/D pump. Lost 75-Bbls. to well while circulating. SITP = 120-psi, SICP = 125-psi. DECOMP Pump 230-Bbls. 12.5-ppg NaCI/Nabr brine @ 3-4 BPM @ 1500-2000 psi mixing on the fly with returns from well to weight system up to 11.2-ppg. Shut down pumping when 11.2-ppg brine in returns. Lost 30-Bbls. to well while circulating. DECOMP Monitor well for flow. Drained stack. BOLDS. DECOMP Pulled tubing hanger free with 65k Ib PU. Pulled hanger to floor with 82k Ib. LD landing joint and hanger. DECOMP Held crew change and PJSM. Performed pre-tour checks. POH, LD 2-7/8" tubing, spooled ESP cable and recovered LaSalle clamps. Added single pipe displacement plus about 2 bph 11.2 ppg brine while POH. 194 jts LD @ 00:00 hrs. DECOMP Continued POH, LD 2-7/8" tubing. Spooled ESP cable and recovered LaSalle clamps. Added single pipe displacement plus about 2 bph 11.2 ppg brine while POH. Fluid losses = 2-BPH. 366 jts LD @ 05:30 hrs. Recovered 498 jts. 2-7/8" EUE 8RD. L80 Tubing, 2 ea. 2-7/8" x 1" KBMM GLM's, 1 x 2-7/8" "XN" nipple and 1 x 2', 1 x 4', 1 x 8' and 5 x 10' 2-7/8" EUE 8RD. L80 Tubing pups. Recovered -15,760' of #1 ESP Cable. All pipe, pups, jewelry and ESP cable looked good. DECOMP Centrilift service technican disassembled, inspected and layed down ESP BHA with rig crews assistance. DECOMP Clear and clean rig floor. Rig down ESP cable handling egpt. Fill hole with 10-Bbls. brine. Losses = -6-BPH. DECOMP PUMU 7" casing scraper BHA: 6-1/8" bit, 7" scraper, bit sub and XO. DECOMP Weekly safety meeting with day crew. DECOMP Filled well with 11 bbls 11.2 ppg brine. PU and RIH with 6-1/8" bit and 7" casing scraper on 3-1/2" IBT-Mod tubing. DECOMP Held crew change and PJSM. Performed pre-tour checks. DECOMP Continued RIH with scraper BHA on 3-1/2" IBT-Mod tubing. 100 jts RIH @ 21:00 hrs. DECOMP Held weekly safety meeting with night crew. DECOMP Continued RIH with B&S on 3-1/2" IBT-Mod tubing. 140 jts RIH @ 00:00 hrs. Losses = -4-BPH 11.2 ppg brine. DECOMP Continued RIH with 7" scraper BHA on 3-1/2" IBT-Mod tubing. 200jts RIH @ 02:00 hrs. DECOMP Slip and cut drilling line. DECOMP Continued RIH with 7" scraper BHA on 3-112" IBT-Mod tubing. 272 jts RIH @ 05:30 hrs. Losses = 2-4_BPH 11.2 ppg brine. DECOMP Continued RIH with 7" scraper BHA on 3-1/2" IBT-Mod tubing. Losses 2-4-BPH 11.2 ppg brine. 450 jts. RIH @ 12:00-hrs. DECOMP Reciprocate scraper from 15,493' to 15,560'. Note: Fluid foss average over last 18-hrs. = 4.4-BPH. Circulated surface to surface a 25.0-Bbl. hi-vis sweep @ 6.0-BPM @ 1800-PSI down tubing taking returns up IA. Losses = 13-Bbls. during circulation. DECOMP Rig down circulating lines and prepare to POH. DECOMP LD 1 jt. POH w/BHA#1 standing 3-1/2" tubing in derrick. ~, DECOMP Held crew change and PJSM. Performed pre-tour checks. Printed: 10!2312007 2:58:43 PM Y • • Legal Well Name: MPF-57 Common Well Name: MPF-57 Spud Date: 3/10!1997 Event Name: WORKOVER Start: 9/18/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/28/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9!24/2007 18:30 - 19:30 1.00 CLEAN P DECOMP Continued POH w/BHA#1 standing 3-1/2" tubing in derrick. Notified John Crisp, AOGCC of need to change fixed rams to 3-1/2". 19:30 - 21:00 1.50 CLEAN P DECOMP Waited for storm packer delivery. 21:00 - 22:00 1.00 CLEAN P DECOMP PUMU storm packer. RIH and set (a7 32'. Tested to 1000 psi for 10 minutes. 22:00 - 00:00 2.00 CLEAN P DECOMP Drained stack, pulled wear ring, set test plug. Replaced fixed rams with 3-1/2" and tested to 250 psi low / 4200 psi high. 9!25!2007 00:00 - 01:00 1.00 CLEAN P DECOMP Drained stack, pulled test plug, installed wear ring. Retrieved and LD storm packer. 01:00 - 06:00 5.00 CLEAN P DECOMP POH with scraper assy (BHA #1), standing back 3-1/2" tubing. Replaced IBT-Mod seal rings as indicated. Double displaced tubing volume with 11.2 ppg brine. Well taking 3-4 bph fluid. 161 stands POH @ 06:00 hrs. 06:00 - 06:30 0.50 CLEAN P DECOMP Pre-tour safety meeting. Crew change. Service rig, derrick inspection and check all PVT alarms. 06:30 - 07:00 0.50 CLEAN P DECOMP POH remaining 3-1/2" tubing and BHA #1: 7" scraper assy. 07:00 - 07:30 0.50 CLEAN P DECOMP BO/LD BHA #1: 7: scraper assy. 07:30 - 08:00 0.50 CLEAN P DECOMP PUMU 7" Halco RTTS packer. 08:00 - 15:30 7.50 CLEAN P DECOMP RIH w/7" Halco RTTS packer on 3-112" Tubing. 15:30 - 16:00 0.50 CLEAN P DECOMP Hook up circulating lines. Break circulation and pump @ 3.0-BPM @ 200-psi. 16:00 - 17:00 1.00 CLEAN P DECOMP Set packer @ 15,540' w/20K downweight. Close 3-1/2" fixed pipe rams. Pressure test casing to -psi or ,charted BP EXPLORATION Page 3 of 4 Operations Summary Report 17:00 - 18:00 1.00 CLEAN P DECOMP POH L/D 4 jts. leaving 490-jts. in hole. POH standing 489-jts. 3-1/2" tubing in derrick. 18:00 - 18:30 0.50 CLEAN P DECOMP Pre-tour safety meetng. Crew change. Service rig, derrick inspection and check all PVT alarms. 18:30 - 00:00 5.50 CLEAN P DECOMP POH w/7" Halco RTTS packer standing tubing in derrick. POOH & stand back 150 stands. Changed out seals in threads. 9/26/2007 00:00 - 01:00 1.00 CLEAN P DECOMP Con't to POOH & stand back 3 1/2" tubing. Changed out seals in threads. Pull & stood back 164 stands. 01:00 - 01:30 0.50 CLEAN P DECOMP Break out, inspect & L/D RTTS & running tool. Left top rubber element from RTTS in hole. Appeared to have come Off between 2nd & 5th stands off bottom. 01:30 - 02:00 0.50 CLEAN N DPRB DECOMP Clear & clean rig floor. Notified town .engineer & discussed slickline fishing operation to recover rubber. 02:00 - 03:00 1.00 FISH N DPRB DECOMP Nipple down flow nipple. N/U shooting flange. 03:00 - 10:00 7.00 FISH N DPRB DECOMP R/U slickline unit & lubricator. P/T lubricator - 200-psi Lo/500-psi Hi. 10:00 - 12:30 2.50 FISH N DPRB DECOMP RIH w/wire grab on slickline tool string and tag @ 15,842' SLM. Set down and work spangs several times. No overpull required to come off tag. 12:30 - 15:30 3.00 FISH N DPRB DECOMP POH w/wireline tool string. Recovered packer rubber element. Element missing a section about 1-1/2" square x 1/2" thick. 15:30 - 16:00 0.50 FISH N DPRB DECOMP RDMO slickline tools and equipment. 16:00 -18:00 2.00 FISH N DPRB DECOMP ND shooting flange and NU flow nipple. Rig up floor to run 3-1/2" completion tubing. Load pipe shed with completion jewelry. Fitl hole @ 1645-hrs. w/12-Bbls. fluid. 18:00 - 18:30 0.50 RUNCO RUNCMP Crew change. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 RUNCO RUNCMP Hold PJSM w/ all hands. Review Completion running order. 19:00 - 19:30 0.50 RUNCO RUNCMP P/U & RIH w/ Tail Pipe Assy, Packer Assy 1 jt of 3 1/2" tubing Printed: 10!23/2007 2:58:43 PM • • BP EXPLORATION' Page 4 of 4 Operations Summary Report Legal Wefl Name: MPF-57 Common Well Name: MPF-57 Spud Date: 3/10/1997 Event Name: WORKOVER Start: 9/18/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/28/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/26/2007 19:00 - 19:30 0.50 RUNCO RUNCMP & Sliding Sleeve Assy 19:30 - 00:00 4.50 RUNCO RUNCMP RIH w/ stands of 3 1/2" 9.3# L-80 IBT-M tubing. Torque connectionbs to 3200 ft-Ibs. Ran in hole w/ 128 stands. 9!27/2007 00:00 - 02:30 2.50 RUNCO RUNCMP Con't to RIH w/ 3 1/2" 9.3#, L-80, IBT-M tubing. Torque tubing connections to 3200 psi. Ran total of 489 jts. 02:30 - 03:30 1.00 RUNCO RUNCMP P/U space out pups, 9.81', 9.82', 3.86' & bury below 1 jt of 3 112" tubing. MIU hanger & landing jt. Land completion. P/U Wt = 98K, S/O Wt = 43K. RILDS. 03:30 - 06:00 2.50 RUNCO RUNCMP Drop Ball/Rod & allow to fall on seat. Pressure up & set packer. Con't to Pressure u to 4200 si & SI tubin .Test tubing for 30 min. Bleed off tubing to 3000 osi & SI. Pressure uo on annu us 06:00 - 08:30 I 2.50 08:30 - 09:00 ~ 0.50 09:00 - 15:00 I 6.001 BOPSUR P 15:00 - 15:30 I 0.501 BOPSUF# P 15:30 - 17:00 I 1.501 BOPSUt~P 17:00 - 18:00 1.00 BOP5U P 18:00 - 19:30 1.50 BOPSU P 19:30 - 20:00 0.50 BOPSU P 20:00 - 20:30 0.50 WHSUR P 20:30 - 23:30 3.00 WHSUR P 9!2812007 100:30 - 001:30 I 10.001 WHSUR ~ P 01:30 - 02:30 I 1.001 WHSUR I P 02:30 - 03:00 0.50 WHSUR P to 4200 si & test for 30 min. Bleed off tubing & shear DCK valve. Confirm clean shear & pump thru DCK both ways. Charted entire set & test procedure for 30-minutes on tubing and 30-minutes on IA. RUNCMP FMC d rod set TWC. Attempted to set TWC. No go. Tried to set second TWC. No go. Set BPV to chase threads. Pull BPV and set TWC successfully. PR TWC to 1000-psi from above and below for 10-charted minutes. RUNCMP Pre-tour meeting & crew changeout. Rig service: Derrick inspection, check PVT alarms, drawworks service. RUNCMP Nipple down ROPE. Reconfigure BOP stack from 3 ram configuration to 2 ram configuration. Install 2-318" pipe rams for next well. RUNCMP PJSM: Swap double gate preventer for single gate preventer. ND BOPE. RUNCMP Swap double gate preventer for single gate preventer. ND BOPE. RUNCMP Torque up bottom flange. Install choke HCR. RUNCMP Torque up annular flange.. R!U Koomey lines. Set back & secure stack. RUNCMP Adjust drawwork brakes. RUNCMP Prep new adapter flange & tree for installation. RUNCMP N/U adapter flane & tree. Tree orientation approved by Pad operator. Test hanger void to 5000 psi. Test tree to 5000 psi. Tested good. RUNCMP PIU lubricator Test to 500 psi. RUNCMP Pull TWC. Install BPV. L/D lubricator. RUNCMP R!U hot oilers. Pressure test lines. Freeze protect well w/ 69 bbls of diesel. Pumped 1.6 BPM @ 1550 psi. RUNCMP Pressure test BPV to 1000 psi for 10 min. Charted same. RUNCMP Secure cellar & tree. RELEASE RIG @ 0300 hrs. RDMO. Printed: 10/23/2007 2:58:43 PM A ,.~ /"I 1. Operations Performed: "/(,'lJorage -W17/11 o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other Change out ESP r o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number; BP Exploration (Alaska) Inc. ~ Development o Exploratory 203-167 3. Address: o Service o Stratigraphic 6. API Number: , P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22747 -01-00 7. KB Elevation (ft): KBE= 45.85' 9. Well Name and Number: , MPF-57 A 8. Property Designation: 10. Field 1 Pool(s): ADL 355017 . Milne Point Unit 1 Kuparuk River Sands , 11. Present well condition summary Total depth: measured 16285 ' feet true vertical 7743 . feet Plugs (measured) N/A Effective depth: measured 16163 . feet Junk (measured) 16076' true vertical 7622 . feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' Surface 9208' 9-5/8" 9340' 4621' 5750 3090 Intermediate Production 16211' 7" 16243' 7702' 7240 5410 Liner 5GANNEDJUN 2 6 2007 Perforation Depth MD (ft): 15972' - 15982' Perforation Depth TVD (ft): 7434' - 7444' 2-7/8",6.5# L-80 15822' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Halliburton 'VT A' Retrievable Packer 15891' Dual Weatherford 500 Micron Duragrip Screen Assembly 15947' -16007' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubin~ Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 214 ./ 53 371 290 277 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 Printed Name Sondra Stewman Title Technical Assistant ,~~ . ex 6ffi( Prepared By Name/Number: Sign ture . . ,1 Phone 564-4750 DatNc!r ondra Stewman, 564-4750 Form 10-404 tfevisedÕ4/ 06 . Submit On inal Onl . STATE OF ALASKA _~; R12CI2/I/I2D ALASKA Oil AND GAS CONSERVATION COM~ION JU/Ij 0 REPORT OF SUNDRY WELL OPERATIONS A/askaO/ï ì 200; &Gas,.. !.JOn s if} fl ~RIGINAL RBDMS BFl JUN 1 9 20D7 g ~ l\-. --<p ,·/$'·&>7 ~ / - Af/It '4Ø'/Þ? y Tree: 29/16" - 5M FrvA Wellhead: FMC 11" x 2W"rbg. Hanger, 2 7/8" EU 8rd T & B 2.5" CIW - Type H BPV profile 20" 91.1 ppf, H-40 95/8" Whipstock top 9317' Window in 9 5/8" 9340-9356' 7" CIBP set @ 9490' 115' I 95/8",40 ppf, L-80 Btrc. 9458' I KOP @ 500' Max. hole angle = 70 to 76 deg. f/3600'to 14,000' Hole angle thru' perfs = 11 deg. 27/8" 6.5# L-80 EUE 8rd (Drift ID= 2.347" ID, Cap = .0058 bpf) 7" 26#, L-80, BTC casing (Drift ID = 6.151, Cap w/ tbg = .02758 bpf) Perforation Summary Ref log: 1/21/04 Size SPF Interval 33/8" 12 15,972'-15,982' 7,434'-7,443' (TVD) Fish: Top @ 16076' MD 6/28/06 Lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 41/2" XN and WLEG. CTU cut lost parts 4/20/04: 7 of 8 anchor slips missing (2" x 1" x 3/4" thick) and 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). REV. BY 11/30/03 4/28/04 8/20/04 5/25/05 6/28/05 5/19/07 Lee Hulme Lee Hulme Lee Hulme Lee Hulme KDC REH MPF-57A Orig. D.ev. = 40.8' (N 22E) Orig. v.=12.1' DF To sg. hng. = 27.9' (N 22E) Howco 9 5/8" 'ES' Cementer Camco 27/8" x 1" KBMM I 138' GLM . Centrilift Motor 152 hp/KMHG 2325 Volt 1 40 Amps Rerate - KME-1/130 2145 volt/35 amp Phoenix Pumpmate 115818' 1 115820'1 Camco 2 7/8 sidepocket KBI\fM GLM HES 2.313 XN Nipple (2.205 No-go ID) Centrilift Discharge Head GPDIS Centrilift Pump Section PMSSDAR 1: 1 Centrilift Gas Separator GRSFTXAR 400 Internals Centrilift Tandem Seal Section GSB3DBFERHLSSCVHBS~SBPFSA 6 fin centralizer 115610'1 /15753" 1 15766' 115766' I 115785' I 115790' 1 115804' I Halliburton "VT A" Retrievable 115891' 1 Packer - 3.880" I.D. Dual Weatherford 500 Micron Duragrip Screens Note: 4ES RIH to 16070'. This is 6' above the fish. Did not tag. 5-16-07 7" Weatherford float collar I 16163' , (PBTD) 7" Weatherford float shoe I 16244' I COMMENTS Recompleteq for Frac and Jet Pump Sidetrack and Frac String installed D-14 Recomplete as ESP - Nabors 4ES Replace ESP - Nabors 4ES Replace ESP - Nabors 4ES Replace ESP - Nabors 4ES Re lace ESP/Run Screens - 4ES MILNE POINT UNIT WELL MPF-57 A API NO: 50-029-22747-01-00 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 3/10/1997 End: 5/18/2007 5/912007 23:00 - 00:00 1.00 RIGD P PRE Rigging down from DS17-05. Wait on trucking. 5/10/2007 00:00 - 06:00 6.00 RIGD P PRE Rigging down from DS17-05. Waiting on trucking. 06:00 - 19:30 13.50 RIGD P PRE Rigging down from DS17-05. Waiting on trucking. 1430-hrs. PJSM lay derrick over in preparation for arrival of trucks. 19:30 - 00:00 4.50 MOB P PRE Begin moving from DS -17 to MPF-57. 5/11/2007 00:00 - 00:00 24.00 MOB P PRE Continue moving to MPF-57a. 5/12/2007 00:00 - 03:00 3.00 MOB P PRE Finish moving to MPF-57a. Total move distance 48 miles. 03:00 - 05:30 2.50 RIGU P PRE Layout Herculite. Set matting boards. Spot in Rig Sub, Pits & Pipe Shed. RIU equip. 05:30 - 06:00 0.50 RIGU PRE ATP Meeting in rig doghouse with MPU Well Ops Supervisor and MPU Safety Lead. Meeting attended by night tour crew, day tour crew and night/day rig management team. 06:00 - 06:15 0.25 RIGU P PRE PJSM - Reviewed derrick raising procedure. 06:15 - 07:15 1.00 RIGU P PRE Rigging up floor and inspecting derrick. Raised derrick to half-mast. 07:15 - 07:30 0.25 RIGU P PRE PJSM - Reviewed scoping up derrick procedure. 07:30 - 08:15 0.75 RIGU P PRE Scoped and pinned derrick to full mast. 08:15 - 09:00 0.75 RIGU P PRE Rig up pits, circulatijng lines and Tiger Tank. Start taking seawater into pits @ 0900-hrs. Accept rig @ 0900-hrs. 09:00 - 10:30 1.50 KILL P DECOMP Continue rigging up lines and Tiger Tank. 10:30 - 11 :30 1.00 KILL P DECOMP Pick up lubricator. PUll BPV. SITP = 1600-psi, lAP = 1600-psi. 11 :30 - 13:00 1.50 KILL P DECOMP PIT circulating lines to 500-psi Lo, 3500-psi Hi. PJSM- Reviewed killing well procedure. 13:00 - 13:30 0.50 KILL P DECOMP Open up well and start bleeding gas to Tiger Tank. Start circulating @ 1.0-BPM. Mud pump #2 swab leaking. 13:30 - 15:30 2.00 KILL N RREP DECOMP Repair #2 mud pump swab and liner. 15:30 - 18:00 2.50 KILL N DECOMP Circulate well w/120F seawater down tubing taking returns to Tiger Tank through choke. Pumping 3.0 t03.5-BPM @ 2200-2300-psi w/1500-1700-psi backpressure through choke. 18:00 - 19:30 1.50 KILL N DECOMP Con't to circulate well w/ hot seawater. Pumped 3 BPM @ 1700 psi. CP = 850 psi. Pumped total of 647 bbls. Had hot water returns after 575 bbls. Recovered -475 bbls of oil. 19:30 - 21 :30 2.00 KILL N DECOMP S/O pump. Blow down lines & monotor well. ISIP 940 psi. on tbg & csg. Record 15 min SI pressures. FTP 1040 psi, FCP = 1030 psi. Order 11.7 ppg brine. 21 :30 - 00:00 2.50 KILL N DECOMP Monitor well. RIU ESP & tbg handling equip. Wait on 11.7 ppg kill fluid. 5/13/2007 00:00 - 05:00 5.00 KILL P DECOMP Wait on 11.7 ppg kill fluid. 1st truck arrived @ 00:30 hrs, 2nd truck arrived @ 0300 hrs. 3rd truck loaded & on the road @ 0500 hrs. 05:00 - 06:00 1.00 KILL P DECOMP Begin kill operation. Open well begin pumping 3 BPM @ 960 psi. 06:00 - 09:30 3.50 KILL P DECOMP Circulate 11.7-ppg kill weight fluid into well @ 3.0-BPM taking returns through choke to Tiger Tank. Final circulating rate = 3.0-BPM, Tubing FCP = 1100-PSI, IA FCP = 60-PSI. Measured weight of returns = 11.7-ppg. Shut down pumping to monitor well. Overdisplaced well by 78-Bbls. 09:30 - 10:30 1.00 KILL P DECOMP Monitor well for 1-hr. SITP = O-PSI, SICP = O-PSI. PJSM - Set TWC. 10:30 - 10:45 0.25 KILL P DECOMP FMC wellhead technician set TWC with dry rod. 10:45 - 11 :30 0.75 KILL P DECOMP PIT TWC from below. Establish injection rate @ x.x-BPM @ xxxx-PSI. test TWC from above to 3800-PSI. Charted both Printed: 5/21/2007 9:08:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 3/10/1997 End: 5/18/2007 tests for 10-minutes. ND production Tree. FMC function test lockdown screws. Weekly Safety Meeting - All crew. NU BOPE. 13-5/8" BOPE configuration from top down: Annular preventer, 2-7/8" x 5" VBR's, BlindlShear Rams, Flow Cross, 2-718" fixed Pipe Rams. 18:00 - 21 :30 DECOMP Remove Blind I Shear rams & 3 1/2" x 6" VBRs. N/D annular preventer. Remove choke & Kill HCR valves. Break out & UD single gate BOP. 21 :30 - 00:00 2.50 DECOMP N/U Double Gate BOP. Install Choke & Kill HCRs. N/U annular BOP. 5/14/2007 00:00 - 06:00 6.00 DECOMP Finish N/U annular BOP. Tighten up all flanged connections wI Sweeney wrench. Install Blind I Shear rams & 2 718" x 5" VBRs. Note: Bottom gate has 2 7/8" rams. John Cisp - AOGCC waived state's right to witness BOPE testing. 06:00 - 06:30 0.50 DECOMP Rigging up BOPE testing eqpt. Fill and circulate air from BOP stack. 06:30 - 11 :30 5.00 DECOMP PIT BOPE per AOGCC/BP requirements - 250-PSI Lo, 3800-PSI Hi. Tested annular preventer to 3500-PSI. 11 :30 - 12:30 1.00 PULL P DECOMP PUMU Lopso-Opso and lubricator. lAP = O-PSI. Pull TWC. UD lubricator and Lopso-Opso. Sonic fluid shot indicates fluid level in IA @ 175' from surface. IA and Tubing on slight vacuum. 12:30 - 13:00 0.50 PULL P DECOMP PJSM - Pull Tubing Hanger. 13:00 - 14:30 1.50 PULL P DECOMP PUMU 2-718" 8RD landing joint into Tubing Hanger. FMC wellhead technican BOLDS. Unland and hoist Tubing hanger to floor. PUW = 124K, SOW = 25K. BO/LD Tubing Hanger, 1 x 4' 2-7/8" L80 8RD pup and 1 x 8' 2-7/8" L80 8RD pup. Pull Tubing up to 1 st collar and cut off ESP cable. Secured cable with Lasalle cable clamp and 6 x 1-1/4" steel bands. Lower Tubing to floor level. 14:30 - 18:00 3.50 PULL P DECOMP Stab TIW valve and makeup circulating lines to circulate well. Circulate bottoms up prior to POH w/ESP completion. Circulating @ 3.0-BPM @ 1162-PSI. Had small amount of gas to surface. SID & monitor well. Took 5 bbls to fill hole & lossese were -8 BPH while circulating. Total losses = 9 bbls. 18:00 - 19:00 1.00 PULL P DECOMP Hold weekly safety meeting wI all hands on crew. Discussed safety bulletins, Reviewed Hallliburton Glove presentation & rig safety issues. 19:00 - 19:30 0.50 PULL P DECOMP Inspect derrick. Check PVT alarms. 19:30 - 20:30 1.00 PULL P DECOMP P/U 9 2 7/8" tubing singles & RIH to 16070.3'. Did not tag (+ 88' of rathole). This is -6 above fish. Bottom of perfs = 15982'. POOH & UD 9 singles. 20:30 - 00:00 3.50 PULL P DECOMP POOH, Stand back 2 7/8" tubing & spool up ESP cable. 64 stands out of hole. Lost 25 bbls. 5/15/2007 00:00 - 01 :30 1.50 PULL P DECOMP Con't to POOH & stand back 2 7/8" ESP completion. Pulled total of 94 stands. 01 :30 - 02:30 1.00 PULL P DECOMP Change out reels in Spooling unit. Lost - 5 bbls in 1 hr while changing reels. 02:30 - 06:00 3.50 PULL P DECOMP Con't to POOH & stand back 2 7/8" ESP completion. 06:00 - 08:30 2.50 PULL P DECOMP Con't to POOH & stand back 2 7/8" ESP completion. 166 stands POH @ 0830-hrs. Recovered 166 stands, + 3 singles, + 2 GLMs, + 2' Pup, + 10' Pup, + 363 LaSalle Clamps. Printed: 5/21/2007 9:08:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 3/10/1997 End: 5/18/2007 5/15/2007 08:30 - 11 :00 2.50 PULL P DECOMP BOILD ESP assembly. Pump was locked up. 2nd reel of cable checked BAD. 11 :00 - 12:00 1.00 PULL P DECOMP Clear and clean rig floor. 12:00 - 12:30 0.50 PULL P DECOMP IP/U running tool. Install Wear Bushing. UD same. 12:30 - 13:30 1.00 PULL P DECOMP M/U Muleshoe & Scraper Assy. 13:30 - 18:00 4.50 PULL P DECOMP RIH wI Scraper Assy on 2 7/8" tubing. 18:00 - 18:30 0.50 PULL P DECOMP Crew change. Inspect derrick. Check PVT alarms. 18:30 - 20:00 1.50 PULL P DECOMP Con't to RIH wI Scraper wI stands of 2 7/8" tubing. 20:00 - 20:30 0.50 PULL P DECOMP P/U 12 singles of tubing & finish RIH to 15972'. P/U Wt = 70K. SIO Wt = 30K. 20:30 - 22:30 2.00 PULL P DECOMP Circulate bottoms up Pump 4 BPM @ 1850 psi. lost 7 bbls during circulation. 22:30 - 23:00 0.50 PULL P DECOMP Break out circulating pin. Blow down lines. UD excess singles. (12 jts) 23:00 - 00:00 1.00 PULL P DECOMP POOH & stand back 2 7/8" tubing. Pulled 34 stands. 5/16/2007 00:00 - 03:30 3.50 PULL P DECOMP Con't to POOH & stand back 2 7/8" tubing. 03:30 - 04:00 0.50 PULL P DECOMP Break out & UD casing Scraper & Muleshoe. 04:00 - 05:00 1.00 PULL P DECOMP Clear & clean rig floor. 05:00 - 07:30 2.50 SANDO P INTERV P/U & M/U Screen & Packer Assy. 07:30 - 12:30 5.00 SANDO P INTERV PJSM. RIH wI screen assembly on 2 7/8" EUE 8 rnd tubing from derrick. 12:30 - 13:30 1.00 SANDO P INTERV Clear I clean rig floor, M/U crossover. 13:30 - 18:00 4.50 SANDO P INTERV PJSM. Continue running in hole wI screen assembly, picking up 3 1/2" DP 1 x1. P/U & RIH wI 140 jts. 18:00 - 18:30 0.50 SANDO P INTERV Crew change. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 SANDO P INTERV Con't to P/U 3 1/2" DP & RIH wI Screen Assy. 157 jt Of 31/2" DP. Space out screens. Packer @ 15891'. Screens 15947-16007'. P/U Wt = 93K, SIO Wt = 59K. 19:00 - 20:00 1.00 SANDO P INTERV Drop ball. Wait 15 min. RlU circulating pin. & test equip. Pump 2 BPM to set ball. Pumped 58 bbls. Pressure up to 500 psi. 20:00 - 21 :00 1.00 SANDO P INTERV Initally set packer wI 2550 psi & hold for 5 min. Bleed off. P/U to 103K, then SIO to 47K. Pressure up for final packer set wI 3100 psi, hold 5 min. bleed off. Pressure up to 1000 psi on Pkr I Csg annulus & test for 10 min. Bleed off. Pressure up on DP to 3100 psi & hold while picking up to shear out @ 117K. P/U & pull out of pkr. 21 :00 - 21 :30 0.50 SANDO INTERV Monitor well. RlU & blow down lines & test equip. RlU to LDDP. 21 :30 - 00:00 2.50 SANDO INTERV POOH & UD 3 1/2" DP. 5/17/2007 00:00 - 00:30 0.50 SANDO INTERV RID DP handling equip. RlU tubing tools. Install wiper rubbers. 00:30 - 02:00 1.50 SANDO INTERV Cut & slip 84' of drilling line. 02:00 - 05:00 3.00 SANDO INTERV Con't to POOH & stand back 2 7/8" tubing. 05:00 - 05:30 0.50 SANDO INTERV Break out & UD Halliburton Packer setting tools. 05:30 - 06:00 0.50 SANDO INTERV Drain stack. P/U retreiving tool. Pull & UD Wear Bushing. 06:00 - 09:00 3.00 RUNCO RUNCMP PJSM. Make up ESP pump assembly, fill wI oil & attach cables, test same, OK. 09:00 - 09:30 0.50 RUNCMP Service rig, check PVTs, crown 0 matic, OK. 09:30 - 17:30 8.00 RUNCMP PJSM. RIH wI ESP assembly on 2 7/8" EUE 8 rnd tubing, running stands out of derrick, attaching La Salle clamps every collar for 1 st 78 stands. Install clamps on every other collar thereafter. Test conductivity of cable every 2000' & pump down tubing @ 1 bpm I 2500 psi. Ran in hole wI 82 stands. 17:30 - 20:30 3.00 RUNCMP Make reel to reel splice. Test splice for continuity. 20:30 - 00:00 3.50 RUNCMP Con't to RIH wI stands of 2 7/8" tubing. Pump thru pump & Printed: 5/21/2007 9:08:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 3/10/1997 End: 5/18/2007 check continuity every 2000'. Install LaSalle clamp on every other jt. Pump thru pump 1 12BPM @ 2000 psi. Ran in hole wI 123 Stands. 5/18/2007 00:00 - 03:00 RUNCMP PJSM. Continue to RIH wI ESP completion on 2 7/8" EUE 8 .- rnd tbg, testing cable & pumping down tubing every 2000'. Ran total of 489 jts tbg. Used (3) flat guards, (5) protectrolizers, (370) La Salle Clamps. P/U landing joint. 82K up wt, 40K down wt. 03:00 - 05:00 2.00 RUNCMP PJSM. M/U tbg hanger, make up penetrator, splice cable & test same, OK. Land hanger. 05:00 - 06:00 1.00 RUNCMP PJSM. P/U tee bar, install two way check valve, test from the top @ 3500 psi. Test from bottom by bull heading @ 2 bpm I 1400 psi, OK. 06:00 - 15:00 RUNCMP PJSM. N/D double gate, install single gate on 135/8" x 5M BOP stack. 15:00 - 16:30 1.50 WHSUR P RUNCMP PJSM. N/U tree. 16:30 - 18:30 2.00 WHSUR P RUNCMP Pressure test hanger void to 5000 psi. Fill tree & pressure test to 5000 psi. Perform final check on ESP. 18:30 - 19:30 1.00 WHSUR P RUNCMP P/U lubricator. Pull TWC & UD same. Set BPV & RID lubricator. 19:30 - 20:30 1.00 WHSUR P RUNCMP Test BPV from bottom. Pump in @ 2 BPM. Pressure increased from 800 to 1400 psi. Charted same. 20:30 - 21 :00 0.50 WHSUR P RUNCMP Blow down & RID lines. Secure well & cellar. RELEASE RIG @ 2100 hrs. Printed: 5/21/2007 9:08:27 AM Re: MPF-57 BOP stack . . Your request to defer testing the lower pipe rams until after the tubing hanger is pulled is approved. The Commission would prefer that you plan for and address similar requests in the permit to drill application. SCANNEt) MAY 0' '1 2007 Pï1Y~- 2D 3 - J V1 Jim Regg AOGCC McLellan, Bryan J wrote: . IAPtÁ F_5ÎÂ ./ Jim, We are planning a RWO on MPF-57 to change out a failed ESP completion. The max possible surface pressure on this well is 3646 psi, based on bottom-hole pressure minus a full column of gas. This pressure requires a 3-ram BOP stack, with an annular, blind rams and two sets of pipe rams. Nabors 4ES will be performing the RWO. In the past, this rig has obtained approval from the AOGCC to perform RWO's on this well with a two-ram BOP stack, consisting of annular preventor, blind rams and a single set of pipe rams. With this short stack, we were able to place a spacer spool below the pipe rams. This spool provided enough room to place the pipe ram test joint below the pipe rams, without interfering with the ESP penetrator on the tubing hanger. We do not plan to seek approval for using the two ram stack configuration on this workover. However, with the three-ram stack configuration, there is not enough room below the rig floor to install a spacer spool below the lower set of pipe rams. Therefore, the ESP cable penetrator (sticking up through the tubing hanger) will be in the way of the pipe ram test joint. We propose the following course of action: 1. ND tree, NU BOP stack. 2. Perform BOP test on all but the lower set of pipe rams. 3. Pull and lay down the tubing hanger. 4. Hang the tubing string below a BOP test plug. 5. Test the lower set of pipe rams. 6. Pull the test plug and production tubing. Please let me know if you approve of this plan. If you have any questions, I can be reached at 440-7964, or contact Dave Reem at 632-2128. Thank you, Bryan McLellan BP Exploration Workover Engineer 1 of 1 5/4/2007 1 :23 PM fI¿ rlnk6 STATE OF ALASKA _ ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 4 2006 REPORT OF SUNDRY WELL OPERA TI8N8il & Gas Cons. Commission . RECEIVED 1. Operations Performed: OtherD Abandon 0 Repair Well 0 Plu: PerforationsO Stimulate ŒJ Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD 203-1670 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-22747-01-00 7. KB Elevation (ft): 9. Well Name and Number: 45.85 MPF-57 A 8. Property Designation: 10. Field/Pool(s): ADL-355017 Miline Point Unit J Kuparuk River Oil 11. Present Well Condition Summary: Total Depth measured 16285 feet true vertical 7743.0 feet Plugs (measured) None Effective Depth measured 16076 feet Junk (measured) Fish: Top@ 16076' MD (06/28/2006) true vertical 7536.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 20" 91.5# H-40 32 - 147 32.0 - 147.0 1490 470 SURFACE 9326 9-5/8" 40# L-80 31 - 9458 31.0 - 4653.0 5750 3090 PRODUCTION 6238 7" 26# L-80 30 - 16244 30.0 - 7703.0 7240 5410 Perforation depth: SCANNED SE? 2 0 2005 Measured depth: 15972-15982 True vertical depth: 7434-7443 Tubing ( size, grade, and measured depth): 2-7/8" 6.5# L-80 @ 29 - 15765 Bottom of Jet Pump @ 15821 Packers & SSSV (type & measured depth): No Packer in well. No SSSV in well. 12. Stimulation or cement squeeze summary: RBDMS BFl SEP 1 8 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubin: Pressure Prior to well operation: 82 11 9 --- 353 Subsequent to operation: 393 77 291 -- 373 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr NIA Printed Name DeWayne R. Schnorr - Title Petroleum Engineer .II , _/ 8.> ~ j¿J( ./ Signature ¿ J;; '4 Phone 564-5174 Date 9/7/06 ¡ ì!,~ 1,1' I !\ I A L Form 10-404 Revised 4/200:4'1 ì \I ~ . . MPF-57A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/22/2006 T/I/O=320/500/240 ( Acid Treatment) Rig - Up to IA , Pump 10 bbls diesel followed by 20 bbls Acid followed by 40 bbls diesel followed by 10 bbls meth for Acid Teatment. FWHP=320/400/240 04/29/2006 T/J/O=550/640/240. Pump 1.6 bbls diesel down tbg to assist w/ setting dummy valve. RU to IA. Pump 64 bbls diesel down IA @ 120* to assist w/ tbg scrape. FWP=500/850/280. 04/29/2006 *** ARRIV ON LOC WELL S/I*** PULLED DPSOV @ 124' SLM, TESTED GOOD DUMMY VALVE W/ BK LATCH, SET @ 124' SLM SCRAPE TUBING GOT TO 1100' SLM, POOH PER PAD OP.(PRESSURE SPIKE, WELL SHUT DOWN AGAIN) MAKE SECOND ATTEMPT GOT TO 650' SLM. ***LEFT WELL SI*** 05/08/2006 T/I/O=400/1150/200. Spear into IA w/ 10 bbls 60/40 meth followed by 15 bbls 12% DAD acid. Pump 325 bbls source water @ 120* down IA. Freeze protect IA w/ 90 bbls crude. Acid @ ESP. FWHP's=850/1850/150 05/09/2006 T/I/O=300/1350/100. (Flush acid treatment) Pump 122 bbls crude down fA. FWHP's=400/1960/120. FLUIDS PUMPED BBLS 10 Methanol 115.6 Diesel 212 Crude 325 Source Water 15 12% DAD Acid 20 HCL Acid 697.6 TOTAL Page 1 Tree: 29/16" - 5M F Wellhead: FMC 11" x 2 7 Tbg. Hanger, 2 7/8" EU 8rd T & B 2.5" CIW - Type H BPV profile 20" 91.1 ppf, H-40 9 5/8" Whipstock top 9317' Window in 9 5/8" 9340-9356' 7" CIBP set @ 9490' 95/8",40 ppf, L-80 Btrc.1 9458' I KOP @ 500' Max. hole angle = 70 to 76 deg. fl 3600' to 14,000' Hole angle thru' perfs = 11 deg. 27/8" 6.5# L-80 EUE 8rd (Drift ID= 2.347" ID, Cap = .0058 bpf) 7" 26#, L-80, BTC casing (Drift 10 = 6.151, Cap wI tbg = .02758 bpf) Perforation Summary Ref log: 1/21/04 Size SP Interval (TVD) 33/8' 12 15,972'-15,982' 7,434'-7,443' DATE REV. BY MPF-57A Orig. V. = 40.8' (N 22E) Orig. . = 12.1' DF To 7" csg. hng. = 27.9' (N 22E) Howco 9 5/8" 'ES' Cementer Cameo 2 7/8" xi" KBMM I 137' GLM . HES 2.313 XN Nipple (2.205 No-go ID) 115609' I 115752'1 Centrilift Discharge Head GPDIS Centrilift Tandem Pump Section 11 766' 1 GPMTAR 1:1 159GC1150 5 115765' I Centrilift Tandem Gas Separator I I GSVHVTXAR 15783' Centrilift Tandem Seal Section 115788' I GSB3DBFERHLSSCVH6SB/SBFSA Centrilift Motor 152 HP I KMHG 115803' 1 2325 Volt I 40 Amps Phoenix Pumpmate 6 fin centralizer 115816' I 115821'1 Fish: TaD @ 16016' MD 6/28/06 Lost during 4/28/04 RWO to ESP. Ineludes: Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 4 1/2" XN and WLEG. CTU cut lost Darts 4/20/04: 7 of 8 anehor slips missing (2" x 1" x 3/4" thiek) and 3 of 8 anehor bands missing (12" x 1" x 1/8" thiek). 7" Weatherford float collar I (PBTD) 7" Weatherford float shoe I COMMENTS ecompleted for Frac and Jet Pump ESP Completion Nabors 4ES Sidetrack and Frac String installed D-14 Recomplete as ESP - Nabors 4ES Replace ESP - Nabors 4ES Replace ESP - Nabors 4ES Re lace ESP - Nabors 4ES 16163' I 16244' I MILNE POINT UNIT WEll MPF-57A API NO: 50-029-22747-01-00 BP EXPLORATION I STATE OF ALASKA . ALAS OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS Revision: 08/01/06 Correct Production Data 1. Operations Performed: o Abandon ~ Repair Well . o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 203-167 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22747-01-00 ' 7. KB Elevation (ft): KBE= 45.85' 9. Well Name and Number: MPF-57A 8. Property Designation: 10. Field 1 Pool(s): t>Sv ?r¡;.'8.fÞ ADL 355017 Milne Point Unit 1 Kuparuk River S..PfICs 11. Present well condition summary . Total depth: measured 16285 . feet true vertical 7743 . feet Plugs (measured) N/A Effective depth: measured 16163 . feet Junk (measured) 16076' true vertical 7622 . feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' Surface 9208' 9-518" 9340' 4621' 5750 3090 Intermediate Production 16211' 7" 16243' 7702' 7240 5410 Liner '\tI~" .......'N, N :'!-'---\ (.' .. .: 0)0 ">, ,)'\. " ....!j, Ù ..1.,!LÄ (",,' ~~~)..: .......~- Perforation Depth MD (ft): 15972' - 15982' Perforation Depth TVD (ft): 7434' - 7444' 2-7/8",6.5# L-80 15823' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None ¡gl=~r=I\/r=n 12. Stimulation or cement squeeze summary: Intervals treated (measured): AUG 0 2 2006 Treatment description including volumes used and final pressure: Alaska Oil & Gas Cons. Commis:sion Anchorage 13. Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: 0 0 0 1450 0 Subsequent to operation: 73 13 21 160 380 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory ~ Development o Service o Daily Report of Well Operations 16. Well Status after proposed work: o Well Schematic Diagram ~Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant r--~--'-}~ Prepared By Name/Number: SilF:lature.i t<::cj:~ . . i - Phone 564-4750 DateC)6 -C\-Q I.p Sondra Stewman, 564-4750 Form 10-404 ReJltBDMS>8FL AUG 09 2006 h Submit Original Only ~1> &'S- ORIGINAL ~ ób ;g¿~/t:ð 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): 1. Operations Performed: o Abandon 8. Property Designation: I STATE OF ALASKA . ALAS OIL AND GAS CONSERVATION COM ION JUL 1 9 2006 REPORT OF SUNDRY WELL OPERATIONS AI k O. as a ,,& Gas C s. Commission rage o Re-Ente uspended Well ~ Othe C nge out ESP ~ Repair Well ~ Pull Tubing o Operation Shutdown 99519-6612 KBE= 45.85' ADL 355017 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 16285 . 7743 . 16163 7622 feet feet feet feet Size 115' 9208' 16211' Packers and SSSV (type and measur RECEIVED o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension 4. Well Class Before Work: ~ Development 0 Exploratory o Stratigraphic 0 Service it To Drill Number: 203-167 API Number: 50-029-22747-01-00 t Unit 1 Kuparuk River Sands Plugs (measured) Junk (measured) .~ ~'r~ TVD Burst Collapse 115' 4621' 5750 3090 7" 7702' 7240 5410 2-7/8",6.5# L-80 15823' None 12. Stimulation or cement squeeze s Intervals treated (measured): J v Treatment description inclu n~~lumes used and final pressure: Re resentative Dail Avera e Production or In"ection Data Gas-Met Water-Bbl Casin Pressure o 0 1000 431 230 400 15. Well Class after proposed work: o Exploratory ~ Development 0 Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~ Óil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I he eby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: C ntact David Reem, 564-5743 13. Oil-Bbl o Subseque to operation: 113 . o Copies of Logs and Surveys run ~ Daily Report of Well Operations n R \ ç:; \ \\\ A l Tubin Pressure o 395 Title Technical Assistant Phone Prepared By Name/Number: Date OÎ -ll~ Sondra Stewman, 564-4750 Sub~t Original Only ,4~ 7·'Z.O.Dfe> ~ 7Ä/t:6 564-4750 Tree: 2 9/16 " - 5M FM. Wellhead: FMC 11" x 2 bg. Hanger, 2 7/8" EU 8rd T & B 2.5" CIW - Type H BPV profile 20" 91.1 ppf, H-40 115' 1 95/8" Whipstock top 9317' Window in 9 5/8" 9340·9356' T' CIBP set @ 9490' 95/8",40 ppf, L-80 Btrc.1 9458' 1 KOP @ 500' Max. hole angle = 70 to 76 deg. f/3600' to 14,000' Hole angle thru' perfs = 11 deg. 27/8" 6.5# L-80 EUE 8rd (Drift ID= 2.347" ID. Cap = .0058 bpf) 7" 26#, L-80, BTC casing (Drift 10 = 6.151, Cap wI tbg = .02758 bpf) Perforation Summary Ref log: 1/21/04 Size SP Interval (TVD) 33/8' 12 15,972'-15,982' 7,434'-7,443' DATE 5/02/01 6/22/01 11/30/03 4/28/04 8/20/04 5/25/05 6/28/05 REV,BY M. Linder B. Hasebe Lee Hulme Lee Hulme Lee Hulme Lee Hulme KOC COMMENTS Recompleted for Frac and Jet Pump ESP Completion Nabors 4ES Sidetrack and Frac String installed 0-14 Recomplete as ESP - Nabors 4ES Replace ESP - Nabors 4ES Replace ESP - Nabors 4ES Re lace ESP - Nabors 4ES MPF-57A T~~ -:;::::~:":::::; Orig. ~v. = 40.8' (N 22E) Orig. cyv. = 12.1' DF To 7 csg. hng. = 27.9' (N 22E) Howco 9 5/8" 'ES' Cementer Camco 2 7/8" x 1" KBMM 1 137' GLM . Cameo 2 7/8 sidepcx:;ket KBMM GLM 115609' I HES 2.313 XN Nipple (2.205 No-go ID) 115752'1 g~~~~ft Discharge Head 115765' I Centrilift Tandem Pump Section 115766' 1 GPMTAR 1:1 159GC1150 . Centrilift Tandem Gas Separator I I GSVHVTXAR 15783' Centrilift Tandem Seal Section 115788' 1 GSB3DBFERHlSSCVH6SB/SBFSA Centrilift Motor 152 HP / KMHG 115803' I 2325 Volt /40 Amps Phoenix Pumpmate 115816'1 115821'1 6 fin centralizer Fish: Top @ 16076' MD 6/28/06 lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 41/2" XN and WLEG. CTU cut lost parts 4/20/04: 7 of 8 anchor slips missing (2" x 1" x 3/4" thick) and 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). 7" Weatherford float collar 1 16163' I (PBTD) 7" Weatherford float shoe I 16244' I MILNE POINT UNIT WELL MPF-57A API NO: 50-029-22747-01-00 BP EXPLORATION (AK) · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/25/2006 Rig Release: 6/30/2006 Rig Number: Spud Date: 3/10/1997 End: 6/30/2006 6/25/2006 18:00 - 19:30 1.50 MOB P PRE Scope down & lower Derrick. RID equip. 19:30 - 20:00 0.50 MOB P PRE Prepare to move rig. 20:00 - 21 :30 1.50 MOB P PRE Move rig from MPF-37 to MPF-57a. Spot sub over well. Spot pipe shed & pits. Beginn RlU equip. 21 :30 - 23:00 1.50 MOB P PRE Raise & scope up derrick. Con't to RlU equip. ACCEPTED RIG @ 2300 hrs. 23:00 - 00:00 1.00 RIGU P DECOMP RlU lines to tree & tiger tank. Install 2nd annular valve. 6/26/2006 00:00 - 00:30 0.50 RIGU P DECOMP Con't to RlU lines to tree & tiger tank. Take on hot (120 deg) Seawater. 00:30 - 01 :30 1.00 WHSUR P DECOMP P/U Lubricator & pull BPV. UD lubricator & BPV. 01 :30 - 02:00 0.50 WHSUR P DECOMP Hold Pre-Spud meeting & PJSM wI all hands.. Tested lines to 3500 psi. Ok. 02:00 - 06:00 4.00 KILL P DECOMP Open well. SITP 1260 psi. SICP = 1340 psi. OAP = 120 psi. Begin circulating well wI 120 degree seawater. Pump 3 BPM 2060 psi. CP 1100 psi. Pump 135 bbls. Bullheaded 15 bbls of seawater into formation. 2 BPM @ 2730 psi, CP 2630 psi. SID @ 6500 stks (385 bbls ) & check tiger tank. Recovered 375 bbls all oil. Con't to circulate well Pumped total of 610 bbls. TP 1990 psi, Annulus pressure 1170 psi. Needed 565 bbls to completely circulate well. Have Seawater returns. SITP & SICP 1050 psi. OAP increased from 120 psi to 700 psi. 06:00 - 10:00 4.00 KILL P DECOMP Pre Tour Safety meeting. Service rig. Monitor well. 1100 psi. SITP. 1100 psi SICP. 11.3+ ppg EMW. Order 870 bbls 11.7+ ppg brine. Formation is fairly tight...., this is about 150 psi overbalnce. 10:00 - 11 :30 1.50 KILL P DECOMP PJSM. While waiting on kill weight fluid, circulate the remainder of the heated seawater @ 3 - 4 bpm 12000 - 2550 psi, holding 1200 psi back pressure on the choke, taking returns to the tiger tank. 250 bbls pumped, 11 bbls lost to formation during this operation. Seawater returns. 11 :30 - 12:30 1.00 KILL P DECOMP PJSM. Shut well in & monitor while waiting on kill wt fluid. SITP & SICP still steady @ 1100 psi. 12:30 - 14:00 1.50 KILL P DECOMP Take on 11.7 - 11.8 ppg brine to the pits. 14:00 - 17:00 3.00 KILL P DECOMP PJSM. Bring on pump holding 1150 psi back pressure on the choke, taking seawater returns to the tiger tank. Initial circulating pressure = 2200 psi @ 3.5 bpm. With tubing volume pumped, circulating pressure down to 1700 - 1750 psi @ 3.5 bpm, holding 1150 psi back pressure on the choke. Circulate remainder of kill wt fluid @ 3.5 bpm 1700 - 1750 psi. 628 bbls total pumped. 11.7 ppg back to the pits. Final pit volume = 250 bbls. 50 bbls lost to formation & tiger tank during this operation. Shut down & open well to monitor. 17:00 - 18:00 1.00 KILL P DECOMP PJSM. Monitor well. Casing is on a slight vacuum, tubing is U tubing slightly, no flow. 18:00 - 18:30 0.50 WHSUR P DECOMP Set TWC. Test same to 3500 psi. Ok. 18:30 - 19:30 1.00 WHSUR P DECaMP Bleed off hanger void. NID X-mas tree. Remove tree from cellar. 19:30 - 22:00 2.50 BOPSU P DECOMP N/U BOPE. 22:00 - 00:00 2.00 BOPSU P DECaMP Pressure test BOPE as per BP/AOGCC requiremenmmts. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Chuck Sheve wI AOGCC. 6/27/2006 00:00 - 01 :30 1.50 BOPSU P DECOMP Finish testing BOPE as per BP/AOGCC requirements. LP 250 psi. HP 3500 psi. RID test Equip. Printed: 7/5/2006 10:11:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/25/2006 Rig Release: 6/30/2006 Rig Number: Spud Date: 3/10/1997 End: 6/30/2006 6/27/2006 01 :30 - 02:00 0.50 WHSUR P DECOMP P/U lubricator & pull TWC. Tubing on vacuum. UD TWC & lubricator. 02:00 - 03:00 1.00 PULL P DECOMP M/U landing jt. BOLDS. Pull hanger to floor w/100K. Cut cable & secured to tubing. UD hanger & landing jt. Fill hole wI 12 bbls. Calc FL @ 400' after 9 hrs. 03:00 - 04:00 1.00 PULL P DECOMP P/U 27/8" singles & RIH wI 6 full jts + 19' of Jt #7. Tagged up @ 15998' w/5K. NOTE: Bottom of perfs @ 15982'. (16' of rathole) POOH & UD excess 2 7/8" tubing. 04:00 - 04:30 0.50 PULL P DECOMP Pull cable over sheave & connect to reel on spooling unit. RlU to POOH. 04:30 - 05:30 1.00 PULL P DECOMP Well a little out of balance, slight flow up tubing. Line up & circulate down tubing, 30 bbls. Monitor well, tubing is dry now. 05:30 - 06:00 0.50 PULL P DECaMP POOH, standing back 2 7/8" EUE 8 round tbg & spooling up ESP cable. 06:00 - 06:30 0.50 PULL P DECOMP Service rig, crew change. 06:30 - 10:30 4.00 PULL P DECOMP PJSM. Continue to POOH w/2 7/8" EUE 8 round tubing, standing back same & spooling up ESP cable. 84 stands out. Well averaging 4 bph loss rate, over & above normal displacement. 10:30 - 11 :30 1.00 PULL P DECOMP PJSM. Cut & splice ESP cable, CIO spools on spooling unit. 11 :30 -17:00 5.50 PULL P DECaMP Continue OOH. ESP pump is full of sand & scale. (plugged). 17:00 - 19:30 2.50 PULL P DECOMP PJSM. UD ESP pump assembly. 19:30 - 21:30 2.00 PULL P DECOMP Remove Pump Assembly from Pipe Shed and RID Elephant Trunk Line. Clear and Clean Rig Floor. RlU to TIH with 2 7/8" Tubing from Derrick. 21 :30 - 00:00 2.50 CLEAN P DECOMP PJSM. Open Blind Rams and fill hole with brine. It took 5 bbls to fill. Loss rate of 4 bbls per hour. Make up 3 1/2" Muleshoe and TIH with 2 7/8" EUE 8 Round Tubing from Derrick. 6/28/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Continue TIH with 3 1/2" Muleshoe on 2 7/8" EUE 8 Round Tubing. 03:00 - 04:00 1.00 CLEAN P DECOMP In with 165 stands (495 joints) of 2 7/8" Tubing. PU 9 joints of 2 7/8" Tubing from Pipe Shed. MU 2 7/8" 8 Round x 3 1/2" IF XO. PU 4 joints of 3 1/2" DP. Up Wt = 72K , Down Wt = 31 K. PU DP Joint #5 and tag 26' in = 16,003'. MU Headpin and break circulation the long way at 3 bpm 11200 psi. P/U DP Joint #6. Close Annular and line up to reverse circulate. 04:00 - 06:00 2.00 CLEAN P DECOMP Reverse circulate @ 2 bpm 1250 psi. Strip in with DP Joint #6 and pressure increased to 350 psi. PU Joint #7 and reverse circulate @ 2 bpm 1450 psi. Bottom of Muleshoe = 16,073'. Monitor losses and steady at 3 bbls I 5 minutes. Increase rate to 3 bpm I 775 psi. CBU and getting back formation sand and clean pieces of frac sand. PU Joint #8 and tag hard 3' in = 16,076'. Reverse circulate clean. 06:00 - 07:00 1.00 CLEAN P DECOMP Crew change. Service rig. Monitor well. 87 bbls total lost to well during cleanout. Monitor well. Slight flow, (trickle), up annulus, fluid level dropping slowly in drill pipe. 07:00 - 08:00 1.00 CLEAN P DECOMP PJSM. POOH & UD 7 jts 3 1/2" DP & 9 jts 2 7/8" EUE 8 rnd tbg. Calculated hole fill 1.8 bbls, actual hole fill 0.2 bbls. Monitor well. No flow up tubing. Annulus is static. Watch for 15 minutes, slight flow up annulus, fluid level dropped in tubing. 08:00 - 15:00 7.00 CLEAN P DECOMP PJSM. Pull 10 stands, hole fill still not quite what it should be. Monitor well, no flow, fluid level in tbg & annulus dropping slowly. Pull 10 more, shut down & monitor well for 15 minutes, Printed: 7/5/2006 10:11:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 6/25/2006 6/30/2006 Spud Date: 3/10/1997 End: 6/30/2006 6/28/2006 08:00 - 15:00 7.00 CLEAN P DECOMP fluid level dropping in tubing & dropping slowly in annulus. Continue out of hole. wI 30 stands out, hole is taking slightly more than it should now. Continue to POOH, final hole fill = 55 bbls. Calculated hole fill = 40 bbls. 15:00 - 15:30 0.50 CLEAN P DECOMP PJSM. Clear I clean rig floor. Monitor well, fluid level dropping slowly in well bore. 15:30 - 18:30 3.00 RUNCO RUNCMP PJSM. Prep to pick up ESP Assembly. Service Pump and Motor. Changeout crews and hold Pre-Tour Safety Meeting with night crew. 18:30 - 20:00 1.50 RUNCO RUNCMP Pull Motor Lead Extension over Sheave and plug into the Motor. Run initial tests on cable - good. 20:00 - 00:00 4.00 RUNCO RUNCMP PJSM. RIH with ESP completion on 2 7/8" EUE 8 Round Tubing. Clamping the cable to the Tubing for the first 75 stands (225 joints) on every collar and every other collar after that. Stopping every 2,000 ft to check cable and pump through to ensure tubing is clear - pumping at 0.5 bpm 11400 psi. 6/29/2006 00:00 - 01 :00 1.00 RUNCO RUNCMP With 40 stands in the hole (120 joints) stopped and performed a cable check. The pressure sensor downhole is reading 0 psi. With 20 stands in the hole (60 joints) it had read 1221 psi. The motor and cable are reading okay and megging at 2 gigs. Stop TIH and Centrilift rep round tripped to obtain second measurement panel to re-test all parameters. Re-test and same results, pressure gauge reading 0 psi. 01 :00 - 04:30 3.50 RUNCO DFAL RUNCMP PJSM. Begin TOH with ESP Assembly on 2 7/8" EUE 8 Round Tubing. Re-tested pressure gauge with 20 stands out and still reading 0 psi. 04:30 - 06:00 1.50 RUNCO DFAL RUNCMP PJSM. On surface and lay down ESP Assembly in Pipe Shed. Change out pressure sensor and make up ESP Assembly. 06:00 - 06:30 0.50 RUNCO DFAL RUNCMP Service rig. Pre tour derrick inspection, OK. Work on ESP sensor replacement. 06:00 - 08:00 2.00 RUNCO DFAL RUNCMP PJSM. Make up & service ESP pump assembly, test same, OK. 08:00 - 09:00 1.00 RUNCO DFAL RUNCMP PJSM. RIH wI ESP pump assembly on 2 7/8" EUE 8 round 6.5# L-80 tubing. 09:00 - 10:00 1.00 RUNCO DFAL RUNCMP Noted bad spot in ESP cable armor, retape & re armor same. Conducted H2S drill. 10:00 - 12:00 2.00 RUNCO DFAL RUNCMP PJSM. Continue in hole wI ESP on 2 7/8" EUE 8 round tubing, torquing all connections to 2300 ftllbs & testing cable & flushing pump every 2000' @ 1/2 bpm 11400 psi, OK. 4000' in the hole. 12:00 - 14:30 2.50 RUNCO RUNCMP Continue to RIH from 4000' wI ESP on 2 7/8" tbg, checking cable & flushing pump every 2000', OK. 14:30·19:00 4.50 RUNCO RUNCMP PJSM. Make reel to reel splice @ 7176'. 19:00 - 00:00 5.00 RUNCO RUNCMP Continue to RIH with ESP Assembly on 2 7/8" EUE 8 Round Tubing. Check cable and flush pump every 2000' - OK. 6/30/2006 00:00 - 01 :00 1.00 RUNCO RUNCMP Continue RIH with ESP Assembly on 2 7/8" Tubing. 01 :00 - 03:00 2.00 RUNCO RUNCMP PU Landing Joint. MU Hanger and install Penetrator. Cut and splice ESP cable and attach field connector. Plug into Penetrator and test - OK. Final running parameters as follows: (4) Flat Guards, (3) Protectolizers, (367) LaSalle Clamps, Up Wt = 90K , Down Wt = 35K. 03:00 - 04:00 1.00 RUNCO P RUNCMP Land Tubing Hanger and RILDS. Lay down Landing Joint. Set TWC and test to 3000 psi - good test. Printed: 7/512006 10:11:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/25/2006 Rig Release: 6/30/2006 Rig Number: Spud Date: 3/10/1997 End: 6/30/2006 PJSM. NID BOPE. Remove HCR valve & manual valves. PJSM. N/U adapter flange & FMC 2 9/16" x 5M tree. Test to 5000 psi, OK. Perform final check on ESP cable, OK. Pull two ' way check valve, set BPV. Release rig @ 10:00 hrs, 06/30/2006. Printed: 7/5/2006 10:11:33AM e - WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 J êð4~ RE: MWD Formation Evaluation Logs MPF-57A + PBl, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPF-57 A + PBl: LAS Data & Digital Log Images: 50-029-22747-01, 70 D'b '~y ILÞ î 1 CD Rom G1~ ,r¡ j 99 /00 J 3 h~ DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 ~4-¿ I ì »cv J.HJ APrNo. 50-029-22747-01-00 Permit to Drill 2031670 Well Name/No. MILNE PT UNIT KR F-57A Operator BP EXPLORATION (ALASKA) INC MD 16285 ,/ TVD 7743'--/ Completion Date 1/13/2004''--'' Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, PWD, IFR/CASANDRA Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ See Notes 5 Blu 15800 16130 Case 8/5/2005 Channel Detection Log, TST Sigma/RST (RPV BoraxlWFL Stop Summary Directional Survey 12509 16285 1/13/2004 RPt/ Directional Survey 12509 16285 1/13/2004 MWD Rpt -' Directional Survey 9295 13239 1/13/2004 PB1 Rpt / Directional Survey 9295 13239 1/13/2004 PB1-MWD 58"" 0 12461 Induction/Resistivity 1-5 8037 16249 3/18/2004 GR, EWR4, CNP, SLD, ..-' ROP Rpt I nd uction/Resistivity 1-5 8037 16249 3/18/2004 GR, EWR4, CNP, SLD, ROP ,,-ED' 0 12461 Neutron 1-5 8037 16249 3/18/2004 GR, EWR4, CNP, SLD, ROP Bpt· Neutron 1-5 8037 16249 3/18/2004 GR, EWR4, CNP, SLD, ROP ~ 0 12461 Density 1-5 8037 16249 3/18/2004 GR, EWR4, CNP, SLD, ROP Rpt Density 1-5 8037 16249 3/18/2004 GR, EWR4, CNP, SLD, ROP ..ED-~'D 12461 Rate of Penetration 1-5 8037 16249 3/18/2004 GR, EWR4, CNP, SLD, ROP Rpt Rate of Penetration 1-5 8037 16249 3/18/2004 GR, EWR4, CNP, SLD, / / ROP ED 0 12462 Induction/Resistivity 1-3 9340 13203 3/18/2004 GR, EWR4, CNP, SLD, ROP - PB1 I L-- . . DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2031670 Well Name/No. MILNE PT UNIT KR F-57A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22747-01-00 MD 16285 TVD 7743 Completion Date 1/13/2004 Completion Status 1-01L Current Status 1-01L UIC N Rpt Induction/Resistivity 1-3 9340 13203 3/18/2004 GR, EWR4, CNP, SLD, ROP - PB1 ~-D 12462 Neutron 1-3 9340 13203 3/18/2004 GR, EWR4, CNP, SLD, ROP - PB1 /' rKpt Neutron 1-3 9340 13203 3/18/2004 GR, EWR4, CNP, SLD, ROP - PB1 .......EO. 0 12462 Density 1-3 9340 13203 3/18/2004 GR, EWR4, CNP, SLD, ROP - PB1 . Rpt Density 1-3 9340 13203 3/18/2004 GR, EWR4, CNP, SLD, ROP - PB1 .-ro. 0 12462 Rate of Penetration 1-3 9340 13203 3/18/2004 GR, EWR4, CNP, SLD, ROP - PB1 ~j3f' Rate of Penetration 1-3 9340 13203 3/18/2004 GR, EWR4, CNP, SLD, ROP - PB1 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? .Y..L.iL-- Analysis ~.. Received? Daily History Received? ~: . Formation Tops Comments: Compliance Reviewed By: ~ Date: 3 h~ dJL}Ð \p -~-~--_. Schlumbel'ger Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well _ i/MPF-57A ~O)· '(17 / 02-28A .R C l'¡ .~ j ft, ..¡ j DS 18-23A \ q ) ~ rc¡ I /OWDW-SE 100- ,.'t}q v, E-23B rl CC I'I~ "I ., .....' E-23B 1...."'"' ".. ...A ("P-06A ¡ q 7-)' j,i.-( V' Y-09A I q 7· ~,3J V P2-49 1'1 ,l-ù).. ~¡ ,- os 04-23A t c¡ 3,· I)) vD.S.16-01 J:s 0 - r J (.¡ ,/4-10A/L-28 :ICJ. ~ ;1.] :3 ./ 01-49/P-21 I g ¡?- Q 73 -.-' '01-57/R-23 n':~ '-//"-1 BP Exploration (Alaska) Inc Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Job# 10672349 10928607 10942206 10893097 10889133 11039119 NIA 10942222 11062633 11051072 1105228 10662991 11072870 11072871 Log Description CHANNEL DETECTION LOG MCNL MCNL RST -BORAX CHANNEL DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG MEM PPROF W/DEFT PRODUCTION PROFILE W/DEFT PRODUCTION LOG W/DEFT INJECTION PROFILE UTe- RST PRODUCTION PROFILE WIGHOST PRODUCTION PROFILE WIGHOST Date 01/24/04 12/11/04 04/20/05 03/25/05 07/16/04 05/08/05 06/04/05 07/14105 07/02/05 07/13/05 07/21/05 02/05/04 07/11/05 07/12/05 Date Delivered: ') l"Lh'1- erU'6 (;> c:¡o( I ,( 08/04/05 NO. 3447 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 Color . CD 1 1 1 1 1 1 1 1 1 1 1 1 JJ"'~ : n:lJg }) ..t ,1l) . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9~.5~3}Íl38 I, , II I ATTN: Beth F // .,' Î}// j Received by: .f!ýf-l/\n~( Cjid/',c:// { , . STATE OF ALASKA ALASKA AND GAS CONSERVATION COelSSION REPORT OF SUNDRY WELL OPERATIONS '" 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 355017 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): o Suspend a Repair Well a Pull Tubing KBE= 45.85' 16285 7743 16163 7622 115' 9208' 16211 ' Chatlge o~fE~P o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver a Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: a Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 203-167 6. API Number: 50-029-22747-01-00 99519-6612 9. Well Name and Number: MPF-57A 10. Field I Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) 16051 ' feet Size MD TVD Burst Collapse 20" 115' 115' 9-5/8" 9340' 4621' 5750 3090 7" 16243' 7702' 7240 5410 15972' - 15982' 7434' - 7444' 2-7/8",6.5# L-80 15823' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): None Treatment description including volumes used and final pressure: RBDMS 8Ft JUN 2 4 7005 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure Tubinq Pressure 15. Well Class after proposed work: o Exploratory a Development 0 Service 16. Well Status after proposed work: aOil o Gas DWAG DGINJ DWINJ DWDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 o Copies of Logs and Surveys run a Daily Report of Well Operations a Well Schematic Diagram Printed Name Sondra Stewman S~ature ~ J ..~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone _ -þepared By Name/Number: Date Olo"Z3üS§ondra Stewman, 564-4750 Submit Original Only 564-5803 Tree: 29/16" - 5M F. Wellhead: FMC 11" x Tbg. Hanger, 27/8" EU 8rd 2.5" CIW - Type H BPV profile 20" 91.1 ppf, H-40 115' I- 9 5/8" Whipstock top 9317' Window in 9.5/8" 9340-9356' 7" CIBP set @ 9490' 9:::J.-JO ' 95/8", 40 ppf, L-80 Btrc·1 ~ I ~ KOP @ 500' Max. hole angle = 70 to 76 deg. f/ 3600' to 14,000' Hole angle thru' perfs = 11 deg. 27/8" 6.5# L-80 EUE 8rd (Drift ID= 2.347" ID, Cap = .0058 bpf) 7" 26#, L-80, BTC casing (Drift 10 = 6.151, Cap w/ tbg = .02758 bpf) Perforation Summary Ref log: 1/21/04 Size SPF (TVD) Interval 33/8" 12 15,972'-15,982' 7,434'-7,443'_ MPF-57 A - :Î,,·d..........T~· ,.------.------ .-.::-.:.:."'-'--'.',," ~"'::"<;',:"", ~ orig'llev. = 40.8' (N 22E) Orig. ev. = 12.1' DF To sg. hng. = 27.9' (N 22E) I Casir'Ì'g lànded'biì emergenCy I slips wI 230k down Howco 95/8" 'ES' o Cementer Camco 2 7/8" x 1" KBMM I 140' GLM Ii This well has.beeo sidétt:acked from:the. . é>rigfriål completiori. :" .hha m; Lf "s't r Min.ID in tubing is XN 2.250" @ 15'722' .... NOTE: Severe dog leg 12890·13000', .Hi~h P/U wtutter 14500', .... Cameo 2 7/8 sidepocket KBMM GLM HES 2.313 XN Nipple (2.205 No-go ID) MS-01 Pressure Sensor 115611' I 115754'1 115769'1 115770'1 Centrilift Discharge Head GPHVDIS Centrilift Tandem Pump Section 115771' I GPMTAR 1:1 151GC1150 Centrilift Tandem Gas separator I GRSFTXARH6 15788' Centrilift Tandem Seal Section I I GSB3 DB UT/L T IL H6 PFS AFLAS/HSN 15793' Centrilift Motor 133 HP I KMH 2205 Volt 137 Amps 115807' I Phoenix MS-01 Sensor w/ 6 fin centralizer Sensor TVD 17286' I 115819' I Fish: Top @ 16051' MD Lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel retrieved), 3 - 10' pups, 4 1/2" XN and WLEG. CTU cut lost parts 4/20/04: 7 of 8 anchor slips missing (2" x 1" x 3/4" thick) and 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). 7" Weatherford float collar I 16163' I (PBTD) 7" Weatherford float shoe I 16244' I DATE 5/02/01 6/22/01 11/30103 4128/04 8/20104 5/25/05 REV. BY M. Linder B. Hasebe Lee Hulme Lee Hulme Lee Hulme Lee Hulme COMMENTS Recompleted for Frac and Jet Pump ESP Completion Nabors 4ES Sidetrack and Frac String installed 0-14 Recomplete as ESP - Nabors 4ES Replace ESP - Nabors 4ES Replace ESP - Nabors 4ES MILNE POINT UNIT WELL MPF-57A API NO: 50-029-22747-01-00 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report . MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours ' Task !Code NPT, Phase 5/21/2005 00:00 - 01 :00 1.00 RIGD P PRE 01 :00 - 02:00 1.00 RIGD P PRE 02:00 - 07:30 5.50 MOB P PRE 07:30 - 08:30 1.00 MOB P PRE 08:30 - 10:00 1.50 RIGU P DECOMP 10:00 - 11 :30 1.50 RIGU P DECOMP 11 :30 - 12:30 1.00 RIGU P DECOMP 12:30 - 13:30 1.00 WHSUR P DECOMP 13:30 - 14:30 1.00 KILL P DECOMP 14:30 - 18:30 4.00 KILL P DECOMP RID rig & equip. Scope down & lower dserrick. Move from MPJ-24 to MPF-57. Approx. distance is 10 miles. Spot rig over well. Spot in pit module. Berm around rig. Raise & scope up derrick. R/U rig & equip. R/u lines to Tree. ACCEPED RIG @ 1000 hrs. Con't to R/U lines to pits. Begin taking on 8.5 ppg seawater in pits. R/U lines to Tiger Tank. Spot in Camp & Pipe Shed. P/U lubricator & pull BPV. UD same. Hold PJSM & Pre-Spud meeting w/ all hands. Test kill lines to 3500 psi, Ok. Open well. SITP 1310 psi, SICP 1270 psi. Circulate well wI 8.5 ppg 120 degree seawater. Pumped @ 3 BPM, 1000 psi. Pumped total of 730 Bbls. Recovered 612 Bbls of 95% oil & 5% water. Monitor well & calc needed kill wt fluid. Pressure built to 610 psi. Ordered 10.4 ppg kill fluid. Wait on kill fluid & circ remaing 8.5 ppg fluid. Clean & maintain rig. Con't to wait on 10.4 ppg kill fluid. Service, clean & maintain rig. Finished pumping remaing 200 bbls of 8.5 ppg heated seawater. Take on 1st load of 10.4 ppg kill fluid. TP = 820. AP = 820. Swab Well over to 10.4 Ib/gal Brine at 3 - 4 bpm/1450 Psi. 10.4lb/gal returns but still slight oil/gas cut. Continue to circulate with 10.4 Iblgal to clean up. Shut in Well to stablize and monitor pressure. Well stab at 130 -140 psi. DECOMP Call out clean Vac Trucks to haul 11.0 Iblgal Brine from storage tank at MPU D-Pad to Rig and to haul recovered 10.4 Ib/gal from Well returns to storage tanks on B-Pad and F-Pad. Built berm and spot the storage tank on F-Pad. DECOMP PJSM. SITP 150 psi, SICP 160 psi. Open well & Pump 11 ppg kill fluid. 3 BPM @ 1300 psi. Displaced 10.4 ppg fluid & recovered same. DECOMP Finish displacing well to 11 ppg fluid & kill well. 3 BPM @ 1300 psi. Pumped 560 bbls & had 11 ppg returns. SID DECOMP Monitor well. Well dead. Blow & N/D kill lines. Install TWC & test same to 3500 psi. DECOMP Bleed off void & N/D X-mas tree. DECOMP N/U BOPE. DECOMP Test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 3500 psi. Chuck Sheve wI AOGCC waived witnessing test. DECOMP P/U lubricator & pull TWC. UD lubricator & TWC. Monitor well. well dead. took 7 bbls to fill hole. DECOMP M/U landing jt into hanger. BOLDS. Pull hanger to floor wi 110K. No problems. DECOMP UD landing jt & tubing hanger. Cut ESP cable. Pull ESP cable over sheave & attach to spooler. DECOMP POOH w/2 7/8" ESP completion. Pulled 83 stands. DECOMP Change out ESP cable spool in spooling unit. DECOMP Con't to POOH & stand back 2 7/8" ESP completion. DECOMP Break out, inspect & UD ESP. ESP had twisted shaft. DECOMP Clear & clean rig floor. DECOMP Finish cleaning rig floor. Load new ESP in pipe shed. R/U to 18:30 - 00:00 5.50 KILL P DECOMP 5/22/2005 00:00 - 08:30 8.50 KILL P DECOMP 08:30 - 14:00 5.50 KILL P DECOMP 14:00 - 21 :00 21 :00 - 00:00 5/23/2005 00:00 - 01 :00 01 :00 - 02:00 02:00 - 03:00 03:00 - 05:00 05:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 10:30 5/24/2005 10:30 - 15:00 15:00 - 16:00 16:00 - 21 :00 21 :00 - 23:30 23:30 - 00:00 00:00 - 01 :00 7.00 KILL P 3.00 KILL P 1.00 KILL P 1.00 KILL P 1.00 WHSUR P 2.00 BOPSUP P 3.50 BOPSUP P 0.50 WHSUR P 0.50 PULL P 1.00 4.50 PULL P 1.00 PULL P 5.00 PULL P 2.50 PULL P 0.50 PULL P 1.00 PULL . Page 1 of 2 , " ," .::') }; ¿ (J:.; 5 Start: 5/20/2005 Rig Release: 5/24/2005 Rig Number: Spud Date: 3/10/1997 End: Description of Operations Printed: 5/31/2005 8:04:16 AM ,. . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 5/24/2005 00:00 - 01 :00 01 :00 - 03:30 03:30 - 06:00 06:00 - 06:30 06:30 - 10:00 10:00 - 14:00 14:00 - 18:00 18:00 - 20:30 20:30 - 21 :30 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 . . Page 2 of 2 BP EXPLORATION Operations Summary Report MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours: Task I Code NPT 1.00 PULL 2.50 RUNCOM 2.50 RUNCOM 0.50 RUNCOM 3.50 RUNCOM 4.00 RUNCOM 4.00 RUNCOM 2.50 RUNCOM 1.00 RUNCOM 1.00 BOPSUF 1.00 WHSUR 0.50 WHSUR Start: 5/20/2005 Rig Release: 5/24/2005 Rig Number: Spud Date: 3/10/1997 End: Phase Description of Operations ----....----.--.--.... -- ... --- ---------- - --...-- -....- - --..-----.. ---- --- - .....--..---------.- DECOMP run same. P/U new LaSalle Clamps. Remove elephant trunk. Change out spools in spooling unit. RUNCMP M/U service ESP. Run new cable over sheave. Plug in & Test new ESP. RUNCMP RIH w/ new 2 7/8" ESP completion. Test & pump thru ESP every 2000' . RUNCMP Lubricate & service rig. RUNCMP Con't to RIH w/2 7/8" ESP completion. Test & pump thru ESP every 2000'. RUNCMP Change out reels in spooling unit. Make reel to reel splice in ESP cable. Test same. RUNCMP Con't to RIH w/2 7/8" ESP completion. Test & pump thru ESP every 2000'. Ran 498 jts. TL = 15823'. Ran 3 Flat guards, 5 Protectolizers & 371 LaSalle Clamps. RUNCMP P/U hanger& landing jt. Install penetrator & make field splice to connector. Test same, OK. RUNCMP Land hanger. P/U Wt = 100K, S/O Wt = 30K. RILDS. Clear & clean rig floor. Set & test TWC. RUNCMP N/D BOPE. RUNCMP N/U X-mas tree. Test tree & hanger to 5000 psi, OK. RUNCMP Perform final test on ESP, OK. P/U lubricator & pull TWC. Install BPV. UD lubricator. Clean cellar & Secure well. RELEASE RIG @ 2400 hrs. Printed: 5/31/2005 8:04:16 AM · ", _ STATE OF ALASKA _ ALASKA_L AND GAS CONSERVATION C~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program aD Repair Well aD Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Re-Enter Suspended Well Change out ESP aD Other o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage. Alaska 7. KB Elevation (ft): 4. Current Well Class: aD Development 0 Exploratory o Stratigraphic 0 Service 5. PermitTo Drill Number; 203-167 6. API Number: 50-029-22747-01-00 99519-6612 KBE= 45.85' 9. Well Name and Number: MPF-57A 8. Property Designation: ADL 355017 10. Field I Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 16285 feet true vertical 7743 feet Plugs (measured) NIA Effective depth: measured 16163 feet Junk (measured) 16051' true vertical 7622 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' Surface 9208' 9-5/8" 9340' 4621' 5750 3090 Intermediate Production 16211' 7" 16243' 7702' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 15972' - 15982' 7434' - 7444' Tubing Size (size, grade. and measured depth): Packers and SSSV (type and measured depth): 2-7/8", 6.5# L-80 15825' None 12. Stimulation or cement squeeze summary: Intervals treated (measured): SEP 1 4; !l}ff RECEIVED SEP 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: o Exploratory aD Development 0 Service 16. Well Status after proposed work: aD Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 o Copies of Logs and Surveys run aD Daily Report of Well Operations aD Well Schematic Diagram Printed Name Sondra Stewman Title Technical Assistant -ÕRIG'MÄL ."""li ....,..,¡, Prepared By NamefNumber: Date l/I -I 0 ~Sondra Stewman, 564-4750 Submit Original Only Tree: 29/16" - 5M F_ Wellhead: FMC 11" x Tbg. Hanger, 2 7/8" EU 8rd B 2.5" CIW - Type H BPV profile 20" 91.1 ppf, H-40 115' 1- 9 5/8" Whipstock top 9317' Window in 9 5/8" 9340-9356' 7" CIBP set @ 9490' 95/8",40 ppf, L-80 Btrc. 9458' I. KOP @ 500' Max. hole angle = 70 to 76 deg. fl 3600' to 14,000' Hole angle thru' perfs = 11 deg. 27/8" 6.5# L-80 EUE 8rd (Drift 10= 2.347"10, Cap = .0058 bpf) 7" 26#, L-80, BTC casing (Drift ID = 6.151, Cap wI tbg = .02758 bpf) Perforation Summary Ref log: 1/21/04 Size SPF Interval (TVD) 33/8" 12 15,972'-15,982' 7,434'-7,443' MPF-57 A Or~g. --lev.: 40.~' (N 22E) Ong. lev. - 12.1 OF To 7' csg. hng. = 27.9' (N 22E) I Casing landed on"émergency I slips wI 230k down Howco 9 5/8" 'ES' o Cementer =¡......... -.,,""'-::- è,,:".'·'X"__è ~ DATE 5/02/01 6/22/01 11/30/03 4/28/04 8/20/04 REV. BY M. Linder B. Hasebe Lee Hulme Lee Hulme Lee Hulme COMMENTS Recompleted for Frac and Jet Pump ESP Completion Nabors 4ES Sidetrack and Frac String installed D-14 Recomplete as ESP - Nabors 4ES Replace ESP - Nabors 4ES Cameo 2 7/8" x 1" KBMM 139' GLM This well has been sidetracked from the' original completion. Min. ID in tubing is XN 2.250" @ 15722' **** NOTE: Severe do!;! leg 12890·13000', High P/U wts after 14500', **** Cameo 27/8 sidepocket KBMM GLM HES 2.313 XN Nipple (2.250 No-go 10) 115611' 115722' I Centrilift Discharge Head GPHVOIS 115766' I Centrilift Tandem Pump Section 115767' I GPMTAR 1:1 159 Stage GC1150 Centrilift Tandem Gas Separator I GRSFTXARH6 15785' Centrilift Tandem Seal Section 1 I GSB3 DB UT/L T IL H6 PFS AFLAS/HSN 15790' Centrilift Motor 152 HP / KMH 2325 Volt / 40 Amps 115804' 1 Phoenix MS-01 Sensor 115819' Fish: Top @ 16051' MD Lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel - retrieved), 3 - 10' pups, 41/2" XN and WLEG. CTU cut lost parts 4/20/04: 7 of 8 anchor slips missing (2" x 1" x 3/4" thick) and 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). 7" Weatherford float collar 16163' 1 (PBTD) 7" Weatherford float shoe I 16244' I MILNE POINT UNIT WELL MPF·57 A API NO: 50-029-22747-01-00 BP EXPLORATION (AK) ... e e BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 8/17/2004 I ¡ Code I NPT : From - To · Hours Task ! ' .! 18:00 - 19:30 1.50 MOB P 19:30 ' 00:00 4.50 MOB P 00:00 - 01 :00 1.00 MOB P 01 :00 - 03:00 2.00 MOB P 03:00 - 04:30 1.50 KILL P 04:30 - 05:30 1.00 KILL P 05:30 - 06:00 0.50 KILL P 06:00 - 06:30 0.50 KILL P 06:30 - 08:30 2.00 KILL P DECOMP Phase ! PRE PRE 8/18/2004 PRE PRE DECOMP DECOMP DECOMP DECOMP 08:30 - 11 :00 2.50 KILL P DECOMP 11 :00 - 14:30 3.50 KILL P DECOMP 14:30 - 18:00 3.50 KILL P DECOMP 18:00 - 19:00 1.00 WHSUR P DECOMP 19:00 - 19:30 0.50 WHSUR P DECOMP 19:30 - 21 :00 1.50 BOPSUP P DECOMP 21 :00 - 00:00 3.00 BOPSUF P DECOMP 8/19/2004 00:00 - 00:30 0.50 WHSUR P DECOMP 00:30 - 01 :00 0.50 PULL P DECOMP 01 :00 - 01 :30 0.50 PULL P DECOMP 01 :30 - 05:00 3.50 PULL P DECOMP 05:00 - 05:30 0.50 PULL P DECOMP 05:30 - 10:00 4.50 PULL P DECOMP 10:00 - 12:30 2.50 PULL P DECOMP 12:30 - 13:30 1.00 PULL P DECOMP 13:30 - 16:00 2.50 RUNCOMP RUNCMP 16:00 - 22:30 6.50 RUNCOMP RUNCMP 22:30 - 00:00 1.50 RUNCOMP RUNCMP 8/20/2004 00:00 - 01 :30 1.50 RUNCOMP RUNCMP 01 :30 - 06:00 4.50 RUNCOMP RUNCMP Page 1 of 2 Start: Rig Release: Rig Number: Spud Date: 3/10/1997 End: 8/20/2004 8/18/2004 8/20/2004 Description of Operations --------.....-.... ..........---. PJSM. Scope down & layover derrick. Prep rig components for move. PJSM. Move rig & rig components from MP J Pad to MP F Pad. Continue to move rig & rig components to MP F-57. PJSM. Spot sub, pipe shed & pits. Raise & scope derrick. Rig accepted @ 03:00 hrs, 08/18/2004 Take on 125 deg seawater. Rig up lines to tree & tiger tank. PJSM. Pick up lubricator, pull BPV, UD lubricator. Test lines to 3500 psi, OK. Conduct pre kill safety meeting. Emphasis on fluid & pressure monitoring. SITP = 760 psi, SICP = 1080 psi, O/A = 50 psi. Commence circulating @ 2bpm, 1050 psi, taking returns to tiger tank. Bring rate up to 4 bpm 11450 psi. Circulate (1) tubing volume. Shut in & bullhead (15) bbls @ 2 bpm 11400 psi, final injection pressure = 2 bpm @ 2000 psi. Circulate 25 bbls & shut in. Moniotor SITP, after 45 minutes stabalized @ 570 psi. Order out 10.5 ppg NaBr. Continue to circulate well, taking returns to tiger tank to clean seawater returns. Shut in well. Monitor shut in tubing & casing pressures while waiting on kill weight brine. SICP & SITP = 570 psi. Commence circulating 10.5 ppg NaBr @ 4 bpm/1650 psi, holding 375 psi back pressure on choke, taking seawater returns to tiger tank. Pumped 600 Bbls. Had 10.5 ppg fluid returns. SID, well dead. Monitor well, Well dead. Set TWC. Test same. Blow down & RID lines to tree. Bleed off void. N/D tree. N/U BOPE. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Chuck Shevev wI AOGCC @ 1800 hrs. RID test equip. Drain BOP stack. P/U lubricator. Pull TWC. UD lubricator. M/U landing jt in to hanger. BOLDS. Pull hanger to floor wI 105K. Check ESP cable. UD hanger & landing jt. Pull ESP cable over sheave & connect to spooler. POOH w/2 7/8" ESP completion. Stand back 81 in derrick. Change out reels in spooling unit. Con't to POOH w/2 7/8" ESP completion PJSM. UD ESP pump assembly. (Lower cable section did not test, cause for pump failure). Clear I Clean rig floor. Change out ESP cable reels. PJSM. Pick up & service ESP pump assembly. PJSM. RIH w/2 718" ESP completion string, same running order as it came out of the hole. Ran in hole wI 81 stands. (+1-7760'). check cable & pump thru pump every 2000'. Make splice in ESP cable Check same. change reels in spooling unit. Finish making reel to reel splice @ +1-7760'. change reels in spooling unit. Con't to RIH wI new ESP completion on 2 7/8" trbg. check cable & pump thru pump every 2000'. Printed: 8/23/2004 9:25:21 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e BP EXÞLORA TION Operations Summary Report MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To ! Hours Task; Code NPT Phase _.._.________._. ___d. 06:00 - 06:30 0.50 RUNCOMP RUNCMP 06:30 - 08:00 1.50 RUNCOMP RUNCMP 08:00 - 08:30 0.50 RUNCOMP RUNCMP 08:30 - 09:30 1.00 BOPSUP P RUNCMP 09:30 - 12:00 2.50 WHSUR P RUNCMP 12:00 - 13:00 1.00 WHSUR P RUNCMP 8/20/2004 Page 2 of 2 Start: 8/18/2004 Rig Release: 8/20/2004 Rig Number: Spud Date: 3/10/1997 End: 8/20/2004 Description of Operations PJSM. Pick up landing joint, make up hanger & install penetrator. Attach field connector & test, OK. 387 La Salle clamps used. PJSM. 98K up WI, 37K down WI. Land hanger, RILDs. Set two way check & test @ 3500 psi, OK. PJSM. N/D BOPE. PJSM. N/U & test void & tree @ 5000 psi, OK. Make final test on ESP cable. Initial test was no good, dried out penetrator & retested, OK. PJSM. Pick up lubricator, pull two way cheek, set BPV, secure well. Rig released @ 13:00 hrs, 8/20/2004. Printed: 8/23/2004 9:25:21 AM .. STATE OF ALASKA .. ALASKA_L AND GAS CONSERVATION CdWvtlSSION REPORT OF SUNDRY WELL OPERATIONS '" 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): o Suspend iJ Repair Well iJ Pull Tubing KBE= 45.85' 8. Property Designation: ADL 355017 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 16285 7743 16163 7622 Casing Structural Conductor Surface Intermediate Production Liner Length 115' 9426' 16699 Perforation Depth MD (ft): Perforation Depth rvD (ft): o Operation Shutdown 0 Perforate o Plug Perforations 0 Stimulate o Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: a Development 0 Exploratory o Stratigraphic Test 0 Service 99519-6612 o Waiver iJ Other o Time Extension Change out ESP o Annular Disposal 5. Permit To Drill Number 203-167 6. API Number: 50-029-22747-01-00 9. Well Name and Number: MPF-57 A 10. Field I Pool(s): Milne Point Unit I Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) 16051' feet Size MD TVD Burst 20" 115' 115' 9-5/8" 9458' 4653' 5750 7" 16731 ' 7794' 7240 Collapse 3090 5410 RECEiVED Tubing Size (size. grade, and measured depth): Packers and SSSV (type and measured depth): None 2-7/8", 6.5# MAY 2 8 2004 Alaska 011 &. Gas Cons. Commis."i!On L-80 .AnchomQÐ5826' 15972' - 15982' 7434' - 7444' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: r~ Lt.:ílIC· I!\.~~ [Q}1f';L. JUM @, 3 1t]O~ 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure 15. Well Class after proposed work: o Exploratory a Development 0 Service 16. Well Status after proposed work: aOil o Gas o WAG OGINJ OWINJ OWDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem. 564-5743 o Copies of Logs and Surveys run a Daily Report of Well Operations a Well Schematic Diagram Printed Name ,Sondra Stewman Title Technical Assistant ?"';;:'_0.-~""" . . ..,' .. hone ~Ignature ;"\,.... ( (/~i._)...... .... r....,..)" \_.>_..........._ ............_..-12 y ." C-~ L ,-,j-,y ,...'X v Form "t04CJ4'Revised 12/2003 ..... 564-5803 Dr- .' Prepared By Name/Number: Date ") .. 4..A-O..fsondra Stewman, 564-4750 '" 'I "I' "\.i I' 1 ~i"2iJ P, t, c),<",,< Ii "~\ e e Page 1 of 3 BP EXPLORATION Operations Summary Report' Legal Well Name: MPF-57 Common Well Name: MPF-57 Event Name: WORKOVER Start: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 4ES Rig Number: 4ES Date I From - To ' Hours I Task, Code: NPT: Phase ......----.--.. ....-......----- 4/22/2004 1.00 RIGD 1.00 RIGD 2.00 RIGU 2.00 RIGU 0.50 RIGU 1.00 RIGU POST POST 18:00 - 19:00 19:00 - 20:00 P P 20:00 - 22:00 P PRE 22:00 - 00:00 P PRE 4/23/2004 00:00 - 00:30 00:30 - 01 :30 P P DECOMP DECOMP 01 :30 - 02:30 02:30 ' 03:00 03:00 - 03:30 03:30 - 06:00 1.00 KILL P 0.50 WHSUR P 0.50 KILL P 2.50 KILL P DECOMP DECOMP DECOMP DECOMP 06:00 - 18:00 12.00 KILL P DECOMP 18:00 - 21 :30 3.50 KILL P DECOMP 21 :30 - 22:30 1.00 KILL P DECOMP 22:30 - 23:00 0.50 WHSUR P DECOMP 23:00 - 00:00 1.00 WHSUR P DECOMP 4/24/2004 00:00 - 01 :00 1.00 WHSUR P DECOMP 01 :00 - 02:30 1.50 BOPSUF P DECOMP 02:30 - 05:30 3.00 BOPSUP P DECOMP 05:30 - 06:00 0.50 WHSUR P DECOMP 06:00 - 08:00 2.00 PULL P DECOMP 08:00 - 15:00 7.00 PULL C DECOMP 15:00 - 17:00 2.00 PULL C DECOMP 17:00 - 23:30 6.50 PULL C DECOMP 23:30 - 00:00 0.50 PULL C DECOMP 4/25/2004 00:00 - 01 :00 1.00 PULL C DECOMP 01 :00 - 02:00 1.00 PULL C DECOMP 02:00 - 02:30 0.50 PULL C DECOMP :-> . 4/23/2004 Spud Date: 3/10/1997 End: 4/30/2004 Description of Operations -.---...------. Scope and lower Derrick. Move off MPF-87a. Pick-up Rig Mats and Herculite. Clean Location. Move to MPF-57a. Had to wait for Electrictions to remove light pole from side of Well House. Spot Camp. Accepted Rig at 22:00 hrs. Spot Sub, Pits, and Pipe Shed. Raise and scope Derrick. Spot Tiger Tank. Lay lines. Rig up HCR Valve to Annular valve. Pump open Accuator Valve. Test Hard Lines to 3,500 psi. Pick-up Lubricator. Pull BPV. Lay down same. Hold Pre-spud & PJSM with all hands. Open well. SITP 1000 psi. SI Ann press. 1200 psi. Circulate well wi 100 degree heated seawawter. Pump @ 4 BPM , 1300 psi. Circulate entire hole volume & displace out diesel & oil. SID & record SITP. Calc kill weight fluid, 11.1 ppg. Con't well kill ops. Order 11.1 ppg kill fluid. Wait on kill fluid. Circulate out oil that migrated to surface as needed. Take on kill fluid in rig pits. Prep to swap Well over to Kill Weight Na Br Brine (11.1 Ib/gal). Hold PJSM wI new crew. Open well. SITP 800 psi, SI Ann Press 800 psi. Circulate & kill well w/11.1 ppg fluid. SID & monitor well. Formation slightly charged. Open to pits & con't to circulate well. 3 BPM @ 400 psi. Circulate 80 bbls & check fluid wts, 11.1 ppg in & out. SID & monitor well. Well dead. Install TWC & test to 3500 psi. Blow down & RID lines to tree. Bleed down void & N/D tree. Finish NID tree. N/U BOPE. Pressure test BOPE. LP 250 psi, HP 3500 ps. Test witnessing waived by John Crisp wI AOGCC @ 12:15 hrs. Rig up Lubricator. Pull TWC. Lay down same. Pick-Landing Jt and screw into Tbg Hanger. BOLDS. Attempt to pull Hanger to Rig Floor with 240K (80%). No movement at Packer. Worked up to 80% several times. No-Joy. Discuss plan forward with Anch Eng. Decide to call out SWS for Chemical Cutting operation. Clean and maintain Rig. WO SWS. PJSM with All for SWS rig-up and chemical cutting ops. RIH wi CCL & chemical cutter. on e-line. Had to pump down tubing @ 1 1/2 BPM from 12800 to 13500' 100 psi circulating pressure. Took 9 bbls to fill hole & get returns when circulating. Cut tubing @ 15854'. Good indication. Had to work tool free to get above cut. POOH. RID E-line equip & stand back out of the way. M/U landing jt into hanger. BOLDS. Attempt to pull completion. worked pipe up to 240K. String would not come free, UD landing jt. P/U 4 1/2 tubing & MIU into hanger. P/U wi 200k. R/U E-line equip to cut tubing. Printed: 4/30/2004 1:46:16 PM e e Page 2 of 3 BP EXPLORATION Operations Summary Report Legal Well Name: MPF-57 Common Well Name: MPF-57 Event Name: WORKOVER Start: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 4ES Rig Number: 4ES ! ! I- ! I I _~~ei_~.~~~ -T~___i__Hours IT~S,~J Code I N~~ I PhaseL, Description of operations_,__ 02:30 - 06:00 3.50 PULL C DECOMP M/U chemical cutter & CCL. RIH. Had to pump @ 1 1/2 BPM from 12800 to 13500' to get tool down hole. Took 14 bbls to fill hole. correlate & make cut in pup jt @ 15840'. ( 2' below collar on 1 st pup above pkr) had good indication of cut @ surface. Start POOH wi chemical cutter. DECOMP Stop at 250-ft. Clear all personel from Rig Floor. Finish POOH with Chemical Cutting Tool String. SWS LD Tool String. Rig SWS back. Pull Tubing Hanger to Floor. Tubing free...String Wt = 160K. Finish RD SWS and release. Clear Rig Floor. DECOMP Lay down Tubing Hanger and 4 1/2" Pup Jt. Single down 4 1/2" 12.61b/ft L-8- TCII and NSCT Tbg. Recovered 194 jts of TCII, 198 jts of NSCT, Sliding sleeve assy, GLM assy, "X" nipple assy & 2.3' cut of jt. Now have 7.47' of cut off tbg pup looking up. Top of fish @ 15828.5' Clear & clean rig floor. UD tubing tools. Install wear bushing & R/U to P/U 3 1/2" DP. P/U, tally & M/U Overshot Assy. BHA #1 as folloews: O/S guide, O/S bowl, 2 Extensions, Top Sub, 2 Bumper jars, Oil Jars, 9* 4 3/4" Des, Accelerator & pump out Sub. TL = 328.14'. P/U 3 1/2" DP & single in hole. Continue to single in with 3 1/2" Drill Pipe (300 Jts) from Pipe Shed. Re-Ioad Pipe Shed with 200 more Jt of 31/2" Drill Pipe. Tally same. Continue to single in with BHA #1 and 3 1/2" Drill Pipe (488 Jts). PUW = 225K...SOW = 59K. Pick-up Kelly. PUW = 230K...SOW = 60K. Break circulations at 2.25 bpm/575 psi. Work over TOF at 15,835' 4es kb. Swallow Fish down to 15,842'. Circulating pressure increased to 2.25 bpm/800 psi. Pull up to 300K. Fire Jars. Re-cock Jars. Fired Jars 3 more times at 300K. Packer moved up hole (10') with 25K drag (255K). Unable to go downhole. Work Fish up hole still pulling between 230K - 255K. Set back Kelly. Monitor Well. Slight flow up Drill Pipe. Circulate Bottoms Up. Monitor well. POOH & LD DP. Finish POOH wi fish. Recovered 12.12' fish. Left packer body in hole. Cut mandril pulled out of body, no slips recovered. Break out & UD fish. UD BHA #1. Clear & clean rig floor. Load pipe shed. Strap & tally 460 jts used 2 7/8" L-80, 8RD, EUE tbg. RIU Tubing tools. Change of Plan. Unload 2 7/8" tbg & load 3 1/2" DP. PJSM. Pick up packer milling BHA #2. P/U 31/2" DP & RIH wI BHA #2 to mill packer @ 15845'. 425 jts in hole @ midnight. Con't to PIU 3 1/2" DP & RIH. Tag up on fish. Ran 488 jts, +10' pup, + 19' Kelly. TL = 15845'. Break circulation & establish milling parameters. Torque too high. Pump 1 drum of EP-Iube, 4 BPM @ 1500 psi. P/U 220K, S/O 68K. Rot 11 OK. Torque dropped off, @ 65 RPMs 10K torque. Pump 2nd drum of EP-Iube. Work pipe. DPRB DECOMP Mill on packer. New parameters after pumping 2nd drum of EP Mud Lube. P/U 155K, S/O 80K. Rot 118K. Pump 2 BPM 500 4/25/2004 06:00 - 07:30 1.50 PULL C 07:30 - 19:30 12.00 PULL P 19:30 - 21 :30 2.00 PULL P DECOMP 21 :30 - 23:30 2.00 FISH P DECOMP 23:30 - 00:00 0.50 FISH P DECOMP 4/26/2004 00:00 - 07:00 7.00 FISH C DECOMP 07:00 ' 08:00 1.00 FISH C DECOMP 08:00 - 12:00 4.00 FISH C DECOMP 12:00 - 13:30 1.50 FISH C DECOMP 4/27/2004 13:30 - 14:00 0.50 FISH C DECOMP 14:00 - 15:30 1.50 FISH C DECOMP 15:30 - 00:00 8.50 FISH C DECOMP 00:00 - 01 :00 1.00 FISH C DECOMP 01 :00 - 02:30 1.50 FISH C DECOMP 02:30 - 08:00 5.50 FISH C DECOMP 08:00 - 13:00 5.00 FISH N DPRB DECOMP 13:00 - 14:00 1.00 FISH N DPRB DECOMP 14:00 - 00:00 10.00 FISH N DPRB DECOMP 00:00 - 01 :30 1.50 FISH N DPRB DECOMP 01 :30 - 03:00 1.50 FISH N DPRB DECOMP 4/28/2004 03:00 - 07:00 4.00 FISH N 4/23/2004 Spud Date: 3/10/1997 End: 4/30/2004 Printed: 4/30/2004 1:46:16 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/28/2004 4/29/2004 4/30/2004 e e Page 30f3 BP EXPLORATION Operations Summary Report MPF-57 MPF-57 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 4/23/2004 Spud Date: 3/10/1997 End: 4/30/2004 Start: Rig Release: Rig Number: 4ES I Code! NPT : Phase 03:00 - 07:00 From - To : Hours I Task DPRB DECOMP ......--.... ...-----. 4.00 FISH N 07:00 - 19:30 12.50 FISH N DPRB DECOMP 19:30 - 21 :00 1.50 RUNCOMP COMP 21 :00 - 23:30 2.50 RUNCOMP COMP 23:30 - 00:00 0.50 RUNCOMP COMP 00:00 - 02:30 2.50 RUNCOMP COMP 02:30 - 04:00 1.50 RUNCOMP COMP 04:00 - 14:00 10.00 RUNCOMP COMP 14:00 - 16:30 2.50 RUNCOMP COMP 16:30 ' 00:00 7.50 RUNCOMP COMP 00:00 - 01 :30 1.50 RUNCOMP COMP 01 :30 - 02:00 02:00 - 03:30 03:30 - 04:00 04:00 - 04:30 04:30 - 06:00 06:00 - 09:00 0.50 RUNCOMP 1.50 RUNCOMP 0.50 RUNCOMP 0.50 WHSUR P 1.50 RUNCOMP 3.00 RUNCOMP COMP COMP COMP COMP COMP COMP Description of Operations . ...----..--- .....----.--... psi. Packer rubbers packing off annulus. Work pipe & mill wlo circulation. Resume circulation & milling. Packer moving down hole. Con't to mill & push packer to 16,051 '. Bottom of tailpipe @ 16089'. Mill & run on packer, unable to push any further. Stand back kelly. PJSM. POOH & LID 3 1/2" DP. LID BHA #2. Clean junk baskets. Recovered packer ring & pieces of rubber element on mill body. Clear & clean rig floor. Load, tally & prep remaining 2 7/8" tubing. Install rope thru ESP sheave. R/U floor & completion running tools. Load ESP into pipe shed. P/U pump & motor. Assemble & service ESP. Con't to assemble ESP. Install & test control line. Pull electrical cable over sheave. Plug into pump & test same. P/U 2 7/8" tubing & RIH w/ ESP completion. Ran in hole wI 255 jts. Meg cable every 2000' & pump thru pump. Splice ESP power cable. Pump thru pump & meg cable. Con't to RIH wI ESP completion. Ran 450jts @ midnight. Meg & pump thru cable every 2000'. Con't to RIH wi 2 7/8" ESP completion. Ran 498 jts. Meg cable & pump thru pump every 2000'. Pump in @ 1 BPM @ 1700 psi. Bottom Of string @ 15826'. "XN" Nipple @ 15722'. GLM wi Dummy @ 15611'. GLM wi DSOV @ 139'. Pump Intake @ 15786' . P/U landing jt & M/U hanger. Install penetrator. Make splice & attach field connection. Land hanger. RILDS. LID landing jt. P/U 77K, S/O 44K. Install TWC. N/D BOPE. PJSM. N/U & test tree. Leave well wi 2 way check, Lee Hulme & Mark O'Malley advised. Secure well. Rig released @ 09:00 hrs. Printed: 4/30/2004 1 :46: 16 PM Tree: 29/16" - 5M F. Wellhead: FMC 11" x Tbg. Hanger, 2 7/8" EU 8rd B 2.5" CIW - Type H BPV profile 20" 91.1 ppf, H-40 115' I· 9 5/8" Whipstock top 9317' Window in 9 5/8" 9340-9356' 7" CIBP set @ 9490' 95/8",40 ppf, L-80 Btrc. 9458' I j KOP @ 500' Max. hole angle = 70 to 76 deg. f/3600'to 14,000' Hole angle thru' perfs = 11 deg. 27/8" 6.5# L-80 EUE 8rd (Orift 10= 2.347" 10, Cap = .0058 bpf) T' 26#, L-80, BTC casing (Drift ID = 6.151, Cap w/ tbg = .02758 bpf) Perforation Summary Ref log: 1/21/04 Size SPF (TVD) Interval 33/8" 12 15,972'-15,982' 7,434'-7,443' _ MPF-57A ; E! ~. Or~g. _lev.: 40.~' (N 22E) Ong. lev. - 12.1 OF To 7' csg. hng. = 27.9' (N 22E) I,F~Sing lånded on emergency 1 }sllps wI 230k down ~ . Howco 9 5/8" 'ES' o Cementer Camco 2 7/8" x 1" KBMM 1 139' GLM This well has·þeensidetracked from the· original completion. . Min.'íD in tubing is XN?250"@15722' **** NOTE: Severe dOQ leg 12890·13000', >High P/U wts after 14500',**** Camco 27/8 sidepocket KBMM GLM HES 2.313 XN Nipple (2.250 No-go 10) 115611' I 115722'1 Centrilift Oischarge Head GPHVOIS 115767' 1 Centrilift Tandem Pump Section 11 68'1 GPMTAR 1:1 151 Stage GC1700 57 Centrilift Tandem Gas Separator 1 1 GRSTXBARH6 15786' Centrilift Tandem Seal Section 1 1 GSB3 DB UT/LT IL H6 PFSAFLAS/HSN 15790' Centrilift Motor 171 HP / KMH 2390 Volt / 44 Amps 115804'1 Phoenix MS-01 Sensor 115820'1 Fish: Top @ 16051' MD Lost during 4/28/04 RWO to ESP. Includes: Outer parts and slips of Baker Premier Pkr (mandrel - retrieved), 3 - 10' pups, 41/2" XN and WLEG CTU cut lost parts 4/20/04: 7 of 8 anchor slips missing (2" x 1" x 3/4" thick) and 3 of 8 anchor bands missing (12" x 1" x 1/8" thick). 7" Weatherford float collar I (PBTD) 7" Weatherford float shoe I 16163' I 16244' I DATE 5/02/01 6/22/01 11/30/03 4/28/04 REV. BY M. Linder B. Hasebe Lee Hulme Lee Hulme COMMENTS Recompleted for Frac and Jet Pump ESP Completion Nabors 4ES Sidetrack and Frac String installed 0-14 Recomplete as ESP Nabors 4ES MILNE POINT UNIT WELL MPF-57 A API NO: 50-029-22747-01-00 BP EXPLORATION (AK) . . (J03 -) 0 '7- WELL LOG TRANSMITIAL. To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 11, 2004 RE: MWD Formatiùn Evaluation Logs MPF-57 A, AK-MW-2760572 1 LIS formatted Disc with verification listing. API#: 50-029-22747-01 J & L l.tJ \ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF mE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signe~~~ ~~ RECEIVED > 1 8 2004 ¡:;\ia$ka Oil & Gas Cons, Commission Anooorage flLJQ I¡j) l{ f'\ lO1rVC'ì !"'J}\\rt u \J LùiJ'+ . . ¿Y03-} lsJ':::[- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 March 11, 2004 RE: MWD Formation Evaluation Logs MPF-57 A PB 1, AK-MW-2760572 1 LIS fonnatted Disc with verification listing. J f))....} ÙJ[). API#: 50-029-22747-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. J\nchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. J\nchorage, Alaska 99649-6612 Date: Sign:;-~C\ ~_~'-"- ~ RECEIVED '1 0 0!'\iìA ; ì J'qq~., , ,~, ..._1"" U ""i t:1J;ì1aka Oil 8: Gas Cons, Commission AooI'torag6 RBDMS RD MAR 3 0 200' .' . .. STATE OF ALASKA e ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .. 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CASING, LINER AND CEMENTING RECORD SETtiNG DEPTHM[) SETTING DEPTH NO HOLE Top BOTTOM Top BOTTOM SIZE Surface 115' Surface 115' 24" 132' 9340' 132' 4621' 12-1/4" 32' 16243' 32' 7702' 8-1/2" o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2052' NSL, 2555' WEL, SEC. 06, T13N, R10E, UM Top of Productive Horizon: 770' NSL, 4402' WEL, SEC. 28, T14N, R10E, UM Total Depth: 809' NSL, 4366' WEL, SEC. 28, T14N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): J Surface: x- 542007 y- 6035505 J Zone- ASP4 TPI: x- 550631 y- 6044835 Zone- ASP4 Total Depth: x- 550666 I y- 6044875' Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD , GR , RES, PWD , IFRlCASANDRA 22. 20" 9-5/8" 7" 91.1# 40# 26# H-40 L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3.38" Gun Diameter, 12 SPF MD TVD MD TVD 15972' - 15982' 7434' - 7444' 26. Date First Production: February 23, 2004 Date of Test Hours Tested PRODUCTION FOR 2-22-2004 1 TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE""'" One Other 5. Date Comp., Susp., or Aband. 1/13/2004 I 6. Date Spudded 11/17/2003 ' 7. Date T.D. Reached 11/24/2003 8. KB Elevation (ft): KBE= 45.85' 9. Plug Back Depth (MD+ TVD) 16163 + 7622 Ft 10. Total Depth (MD+TVD) ,¡ 16285 + 7743 / Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL I 24. SIZE 4-1/2", 12.6#, L-80 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-167 13. API Number 50-029-22747-01-00 14. Well Name and Number: MPF-57A 15. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 16. Property Designation: ADL 355017 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) --r/ tv~ 13';0' nil> / ' £/632." 71IZ> CEMENTING RECORD 250 sx Arcticset I (Approx.) 2011 sx PF 'E', 800 sx Class 'G' 179 sx Class 'G' AMOUNT PUllED DEPTH SET (MD) 15875' PACKER SET (MD) 15836' DEPTH INTERVAL (MD) 15972' -15982' AMOUNT & KIND OF MATERIAL USED Fractured A Sands with 206900 #'5 16/20 Carbolite Placed 77000 #'s behind pipe Freeze Protected with 60 Bbls of Diesel 2100' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl GAs-McF WATER-Bsl 17.6 3.38 0 Oll-Bsl 424 GAs-McF 81 W A TER-Bsl o I GAS-Oil RATIO 192 Oil GRAVITY-API (CORR) CHOKE SIZE None CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state 27. _~zr!:Þ.i .v...'·.) _. /S:~"~:¡:~-- Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE SIDE i 4 .... BFL ....\~ ,. t ,.... . .... .' j e 28. GEOLOGIC MARKERS NAME MD TKUP (TKUD) 15740' TKC1 15908' LCU (TKUB) 15912' TKUA 15961 ' TKA3 15967' TKA2 15983' TKA1 16008' TMLV 16063' 29. e FORMATION TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 7210' None 7372' 7376' 7423' 7429' 7445' 7469' 7523' t Å' ;, 30. List of Attachments: Summary of Daily Drilling Reports, Surveys, Wellbore Schematic Diagram and a Post Rig Work Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra ~~~_ Title Technical Assistant Date 03·- II ~ O~ MPF-57A 203-167 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Matt Green, 564-5581 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OR\G\NÞJ .. e e Page 1 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/6/2003 11/7/2003 Skid rig floor from drlg position to move position Move rig off well MPK-21A Install boosters front and back Pick up and clean up pad Move rig from K-Pad to F-Pad road Move rig from Milne PT and F-Pad road to F-Pad Take boosters off rig - Lay herculite - Set rig mats - Prepare to move rig over well MPF-57A - (Well pressure @ 04:00 Hrs 620 psi) - Install heaters in sub - Install cellar doors on Move rig over well MPF-57A - Shim rig Skid rig floor from move position to drlg position Rig up floor - Accept rig At 14:30 hrs 11/7/2003 Fill pits with 11 ppg mud - Rig up on tree and flow back tank for well kill operations Rig up lubricator - Pull BPV with DSM Con't rig up lines for well kill operations Pre Spud meeting Test lines to 2500 psi - Bullhead fluid @ 1.5 bpm pumped 9.4 bbls pressure @ 2500 psi and increasing - Shut down bullheading - Displace tbg volume @ 3 bpm @ 550 psi - with 11 ppg mud - pump 84 bbls - Bullhead 11.1 bbls mud @ 1.5 bpm Con't circulating out Annulus with 11 ppg mud @ 3 bpm ICP 770 psi FCP 2250 psi - Last 800 stks increased pump to 3.5 bpm at 2700 psi 5216 stks mud back to surface 9.2 - Bypass flow tank - take returns into pits through choke - Circulate additional 134 bbls mud weight back 10.6+ Shut in choke - Bleed off pressure on tubing - monitor well Monitor well - No pressure build up on tubing or annulus - Well dead - Pump 1.8 bbls fill annulus Rig down circulating lines I equipment Suck down lines I Tree - Install TWC - test from below 500 psi Nipple down Tree - Adapter flange - check threads on hanger - good Nipple up BOP's - Riser - mud lines - choke lines Rig up to test BOP's Annular 250 low 3500 high 5 mins each test - Top rams 250 low 3500 high 5 mins each test - Blind rams 250 low 3500 high for 5 mins each test - Choke manifold - Hyd choke I Kill valves - Manual choke I Kill valves - Floor valves - Upper I Lower IBOP valves - 250 low 3500 high 5 mins each test - Accumulator test - Old not test lower rams - will test when out of the hole with ESP - Witness of BOP test wavied by John Crisp with AOGCC - PRE Rig down testing equipment - shut annulus valves - Change bails to long bails STUC DECOMP Attempt to pull 2 7/8" tbg hanger to surface - Pull 150K tbg no movement - Slack off - Start pumps @ 3.5 bpm at 2720 psi - work tubing at 160K no movement - Pull to 175K no movement MPF-57 MPF-57 REENTER+COMPLETE DOYON DRILLING INC. DOYON 14 ! From - To : Hours: Task Code ¡ NPT Phase ! 12:00 - 13:00 1.00 MOB P PRE 13:00 - 14:00 1.00 MOB P PRE 14:00 - 17:00 3.00 MOB P PRE 17:00 - 18:00 1.00 MOB P PRE 18:00 - 00:00 6.00 MOB P PRE 00:00 - 03:30 3.50 MOB P PRE 03:30 - 11 :00 7.50 MOB P PRE 11 :00 - 13:00 2.00 MOB P PRE 13:00 - 14:00 1.00 RIGU P PRE 14:00 - 14:30 0.50 RIGU P PRE 14:30 - 16:00 1.50 RIGU P PRE 16:00 - 16:30 0.50 RIGU P PRE 16:30 - 17:30 1.00 RIGU P PRE 17:30 - 18:00 0.50 RIGU P PRE 18:00 - 23:30 5.50 RIGU P PRE 23:30 - 00:00 0.50 RIGU P PRE 11/8/2003 00:00 - 00:30 0.50 RIGU P PRE 00:30 - 01 :30 1.00 RIGU P PRE 01 :30 - 02:30 1.00 RIGU P PRE 02:30 - 03:30 1.00 RIGU P PRE 03:30 - 05:30 2.00 RIGU P PRE 05:30 - 06:30 1.00 RIGU P PRE 06:30 - 11 :30 5.00 BOPSURP PRE 11 :30 - 12:00 0.50 BOPSURP 12:00 - 13:00 1.00 PULL N 13:00 - 18:00 5.00 PULL N STUC DECOMP Con't circulating @ 3.5 bpm at 3500 psi - Work tbg every 15 mins to 160K while waiting on lubricants Start: 9/24/2003 Rig Release: 11/30/2003 Rig Number: 14 Spud Date: 3/10/1997 End: 11/30/2003 Description of Operations .... _.....__.____n._ Printed: 121112003 9:53:45 AM -- e Page 2 of 10 BP EXPLORATION Operations Summary Report Pick up 2 joints 4" DP - Pick up Halliburton Mechanical setting tool - Halliburton 7" EZSV cement retainer - Make up same RIH with Halliburton EZSV retainer on 4" DP from pipe shed - Rabbit each joint picked up - RIH to 16105' Circulate @ 3 bpm at 2500 psi prior to setting EZSV - Set EZSV - Rotate 40 turns to the right - Tq 8K - PU 240K to release from EZSV and set element - Set 25K on EZSV to insure packer set - PU off EZSV - Rotate 20 turns to the right to extend stinger DFAL DECOMP Attempt to test 7" casing to 3000 psi - No test leaking off - Test surface equipment - Isolate # 2 pump - Test surface equipment - Circulate hole - Attempt to test casing through kill line with Howco valve on DP closed - Pump to 3200 psi - no test leaking off - Open up Howco valve on DP - Attempt to test through DP and Kill line 3000 psi - No test leaking off - Establish injection rate .5 bpm at 3200 psi - Sting into EZSV - Attempt to test DP X 7" annulus to 3000 psi - No test - Injection rate same .5 bpm 3200 psi - Check 9 5/8" annulus - No pressure on annulus DFAL DECOMP Rig down test lines - Cement lines - Prepare to POH with setting tool - Pump dry job DFAL DECOMP POH for Howco 7" Champ packer DFAL DECOMP Con't POH for Howco 7" Champ packer legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 REENTER+COMPlETE DOYON DRilLING INC. DOYON 14 ¡ I Date From - To ¡Hours· Task : Code t N PT ¡ Phase I ' -------.-.----- 11/8/2003 18:00 - 20:30 2.50 PULL P DECOMP 20:30 - 21 :30 1.00 PULL P DECOMP 21 :30 - 23:30 2.00 PULL P DECOMP 23:30 - 00:00 0.50 PULL P DECOMP 11/9/2003 00:00 - 00:30 0.50 PULL P DECOMP 00:30 - 09:30 9.00 PULL P DECOMP 09:30 - 10:30 1.00 PULL P DECOMP 10:30 - 23:00 12.50 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 11/10/2003 00:00 - 00:30 0.50 PULL P DECOMP 00:30 - 02:00 1.50 PXA P DECOMP 02:00 - 03:00 1.00 PXA P DECOMP 03:00 - 03:30 0.50 PXA P DECOMP 03:30 - 16:00 12.50 PXA P DECOMP 16:00 - 17:00 1.00 PXA P DECOMP 17:00 - 19:00 2.00 PXA N 19:00 - 19:30 0.50 PXA N 19:30 - 00:00 11/11/2003 00:00 - 00:30 4.50 PXA 0.50 PXA N N Start: Rig Release: Rig Number: Spud Date: 3/10/1997 End: 11/30/2003 9/24/2003 11/30/2003 14 Description of Operations n. .. ... __ _._.._........_._______...._....._ _.....__......___.__..._._.._.___._.___ Pump lubricants down hole - Con't working pipe - Pipe free - PU 160K - SO 75K - Pull hanger to rig floor Con't circulating while rig down to pull 2 7/8" ESP completion - Circulate out lubricants from tubing into annulus Break and lay down hanger - Landing joint - 1 10' pup - Rig up Centerlift to spool ESP cable - Change out long bails for short bails - Rig up double stack 2 7/8" tongs - PJSM with Centerlift operator on pulling and spooling ESP cable - Pump dry job Lay down 2 7/8" tubing and ESP - Total joints laid down 20 PJSm With Centerlift operator - Tong operator - Crew on spooling up ESP cable and laying down 2 7/8" tubing Lay down 2 7/8" tubing and ESP - Total 245 joints two joints bad - galled threads - Box and Pin marked and flagged - Lay down 1 GLM + 1 pup joint Install TIW valve - monitor well - String out highline power cable with all rig hands Con't laying down 2 7/8" tubing with ESP cable - ESP cable was damaged in one spot looked like armor had rubbed on casing - marked with red paint - Laid down 507 joints of 27/8" tubing - Recovered 3 flat clamps - 5 Protectolizers - 260 La salle Clamps - Missing on La salle clamp per running program Break and lay down ESP pump assembly Con't breaking and laying down ESP pump assembly Rig down tongs - Elevators - ESP cable - Centerlift sheeve - Clear rig floor of stack tongs and all equipment not needed Rig up test equipment - Install test plug - Open annulus valves - Test Upper Rams - Lower kelly valve on Top Drive - Lower Rams - to 250 low 3500 high for 5 mins each test - Recorded on chart - Shut annulus valves - Pull test plug - Install wear ring Printed: 121112003 9:53:45 AM e e BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: MPF-57 Common Well Name: MPF-57 Spud Date: 3/10/1997 Event Name: REENTER+COMPLETE Start: 9/24/2003 End: 11/30/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 11/30/2003 Rig Name: DOYON 14 Rig Number: 14 I Date From - To ¡Hours Task Code NPT: Phase Description of Operations ___..____n ____n__..____... - ....----.------ -- ---.----- _. - -. --...-.--..- ----.- -.- 11/11/2003 00:30 - 01 :00 0.50 PXA N DFAL DECOMP Break and lay down EZSV setting tool - Pick up - Make up 7" Howco Champ packer 01 :00 - 04:30 3.50 PXA N DFAL DECOMP RIH to 6043' - Set packer - Test 7" casing to 3000 psi - Good test - 04:30 - 06:00 1.50 PXA N DFAL DECOMP Con't RIH with 7" Champ Packer to 8067' - Set packer - Test casing to 3000 psi - 06:00 - 13:30 7.50 PXA N DFAL DECOMP Con't RIH with 7" Champ packer test csg at 10061 and 11982, 13978 and 16040 all good test, test backside @ 16040 to 3,000 psi for 30 min 13:30 - 20:30 7.00 PXA N DFAL DECOMP Slug pipe and tripping out with Champ packer, lay down same 23:30 - 00:00 0.50 PXA N DFAL DECOMP Pick EZSV star tool, tripping into 14,303 11/12/2003 00:00 - 01 :00 1.00 PXA N DFAL DECOMP Tripping in with EZSV star tool to 16030 01 :00 - 02:00 1.00 PXA N DFAL DECOMP Slip and cut Drilling line 02:00 - 03:00 1.00 PXA N DFAL DECOMP Change Bails and space out for cement job, PJSM 03:00 - 06:00 3.00 PXA N DFAL DECOMP Sting in to retainer and establish injection rate went to 3850 on pipe, bleed off @ 100 psi every two min., bleed off pull out of retainer circ,sting back in went to 3900 psi bleed off @ 100 psi every 2 min.bleed off pull out of retainer circ,sting back in went to 4000 psi bleed off @ 100 psi every 2 min., Bleed off pull out and test csg above retainer to 3500 psi, bleed off 250 psi in 5 min. 06:00 - 08:00 2.00 PXA N DFAL DECOMP Circ and Condo mud for Balance cement plug 08:00 - 09:30 1.50 PXA N DFAL DECOMP Cement with Schlumberger with 5 bbls water, test lines to 4,000 psi, 6 bbls water, 25 bbls class G mixed @ 15.8, 5 bbls , displace with153 bbls mud., top of cement 15,451 after we pull out 09:30 - 10:30 1.00 PXA P DECOMP Poh to 14,976 10:30 - 11 :30 1.00 PXA P DECOMP Reverse circ. two drill pipe volumes, 5 bbls 1800 psi 11 :30 - 12:00 0.50 PXA P DECOMP Change Bails 12:00 - 19:00 7.00 PXA P DECOMP Tripping out, lay down excess drill pipe 19:00 - 20:00 1.00 PXA P DECOMP Test 7" csg for 30 min with 3,000 psi, good test 20:00 - 00:00 4.00 PXA P DECOMP Pick up 7" CIBP, trip in to 9490 11/13/2003 00:00 - 00:30 0.50 PXA P DECOMP Set CIBP @ 9490', shear off with 175,000# 00:30 - 01 :00 0.50 PXA P DECOMP Pressure test csg to 3,000 psi for 15 min., tag top of plug to Verify depth 01 :00 - 05:00 4.00 PXA P DECOMP Slug pipe, Trip out with running tools, lay down same 05:00 - 09:30 4.50 PXA P DECOMP Pick up Baker mechanical csg cutter and 6 1/8 stab, Tripping in 09:30 - 10:30 1.00 PXA P DECOMP Attempt to cut csg @ 9385, 100 rpms, 5K torque, suspect broke cutters 10:30 - 14:00 3.50 PULL N DFAL DECOMP Poh with cutters, lay down same 14:00 - 14:30 0.50 PULL N DFAL DECOMP Pull wear ring, and 7 X 9 5/8 packoff 14:30 - 15:30 1.00 PULL N DFAL DECOMP Mlu spear, stab in to 7" hanger, pull 400K an attemp to pull csg free, csg not cut. 15:30 - 16:00 0.50 PULL N DFAL DECOMP Reinstall 7 x 9 5/8 packoff 16:00 - 20:00 4.00 PULL N DFAL DECOMP Pick up Baker mechanical csg cutter and 6 1/8 stab, Tripping in 20:00 - 21 :00 1.00 PULL N DFAL DECOMP Cutting csg @ 9383' 100 rpms, 5-7K torque, good flow back on 7 X 9 5/8 annulus 21 :00 - 23:30 2.50 PULL P DECOMP Tripping out with cutters,laydown same, letting diesel u-tube to rockwasher, 60 bbls 23:30 - 00:00 0.50 PULL P DECOMP Pull 9 5/8 packoff 11/14/2003 00:00 - 00:30 0.50 PULL P DECOMP MIU 7" spear and pull 7" csg to floor, with 230K PIU, free 190K 00:30 - 01 :00 0.50 PULL P DECOMP Lay down spear and csg hanger 01 :00 - 01 :30 0.50 PULL P DECOMP Rig up to circ. Printed: 12/1/2003 9:53:45 AM . . . -- e Page 4 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: MPF-57 Common Well Name: MPF-57 Event Name: REENTER+COMPLETE Start: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date I From - To 'Hours Task COde: NPT! Phase ì I i ----------.- 11/14/2003 01 :30 - 03:00 1.50 PULL P DECOMP 03:00 - 13:30 10.50 PULL P DECOMP 13:30 - 14:00 0.50 PULL P DECOMP 14:00 - 15:00 1.00 PULL P DECOMP 15:00 - 17:30 2.50 PULL P DECOMP 17:30 - 18:30 1.00 PULL P DECOMP 18:30 - 21 :30 3.00 PULL P DECOMP 21:30 - 00:00 2.50 PULL P DECOMP 11/15/2003 00:00 - 03:00 3.00 PULL P DECOMP 03:00 - 03:30 0.50 PULL P DECOMP 03:30 - 06:30 3.00 PULL P DECOMP 06:30 - 12:00 5.50 PULL P DECOMP 12:00 - 12:30 0.50 PULL P DECOMP 12:30 - 16:30 4.00 PULL P DECOMP 16:30 - 17:00 0.50 PULL P DECOMP 17:00 - 18:00 1.00 PULL P DECOMP 18:00 - 18:30 0.50 PULL P DECOMP 18:30 - 19:00 0.50 PULL P DECOMP 19:00 - 19:30 0.50 PULL P DECOMP 19:30 - 21 :00 1.50 REMCM-P DECOMP 21 :00 - 22:00 1.00 REMCM-P DECOMP 22:00 - 00:00 2.00 PULL P DECOMP 11/16/2003 00:00 - 02:30 2.50 PULL P DECOMP 02:30 - 03:00 0.50 PULL P DECOMP 03:00 - 05:00 2.00 BOPSUB P DECOMP 05:00 - 09:30 4.50 BOPSURP DECOMP 09:30 - 10:00 0.50 BOPSURP DECOMP 10:00 - 13:30 3.50 PULL P DECOMP 13:30 -16:00 2.50 PULL P DECOMP 16:00 - 19:30 3.50 STWHIP P DECOMP 19:30 - 21 :00 1.50 STWHIP P DECOMP 21 :00 - 00:00 3.00 STWHIP P DECOMP 11/17/2003 00:00 - 02:00 2.00 STWHIP P DECOMP 02:00 - 04:00 2.00 STWHIP P DECOMP 9/24/2003 11/30/2003 14 Spud Date: 3/10/1997 End: 11/30/2003 Description of Operations .._____u__.___..___ Circ and con. mud with 6 bbls min 600 psi, Rig up to lay down 7" csg PJSM, lay down 7" csg, clear floor Install wear ring Pickup 8.5 MX-C1 bit and 9 5/8 csg scraper, service break baker tools Trip in with bit and scraper to 9383 tag cut jt. cut and slip drill line, circ slow Circ and con mud to 10.2, 420 gals min 3350 psi worked pipe, no rotation Slug pipe, laying down 4" drill pipe laying down 4" drill pipe, went off shore power @ 02:30 started motors Break bit, scraper,bit sub,xo, lay down same PJSM, change out HT38 saver sub, for 4 1/2 IF Picking up 9.625 EZ-SV Cement retainer and 5" 19.5# S135 drill pipe, 28,500 make up Service rig Finish picking up 5" drill pipe, tag up on cut jt. @ 9383 to verify depth Pull up to 9364 and rig up to set EZ cement retainer Circ clean packer setting depth, set EZSV retainer, shear off with 215 K, 50K over string wt. and unsting from same Rig up and test csg and retainer to 1750 psi for 30 min. Sting in and establish injection rate, 1 bbl min. 1400 psi, 1.5 bbls=1500 psi, 2 bbls=1550 psi Unsting and eire, PJSM with Schlumberger Pump 5 bbls water, test lines to 3500 psi, 5 bbls water, 25 bbls class G mixed @ 15.8, 3 bbls water, 124 bbls mud, pumped cement in place with 6 bbls min 1500 psi, holding 700 psi on backside, sting in and inject with 35 bbls mud, 2 bbls min. 1700 psi with annulus open Unsting and reverse circ on top of retainer 2 drill pipe vol., 7 bbls min. 800 psi Slug pipe and tripping out with running tools Tripping out with running tools, laying down same,clear floor Pull wear ring and install test plug Change out upper rams to 4.5 x 7 Test Bops and manifold 250-3500 psi 5 min per test, Hydril 250-2,500 psi 5 min per test. the right to witness test was wavier by Jeff Jones AOOGC, (top rams failed changed out) Pull test plug and install wear ring Picking up 6.125 de and 5" hwdp and stand in derrick Picking up whipstock and 8.5 mills,Surface test MWD Tripping in with whipstock to 9,317 Orientate whipstock 68 degree to left of high side, and set @ 9364' with 20K to set anchor, 50K to shear lug Mill window from 9340 to 9,350 with 110 rpm , 550 gpm 2250 psi Mill window from 9340 to 9356 with 120 rpm , 550 gpm 2250 psi Drill open hole to 9,372' ( top window 9,340 bottom 9,356) Circ and work window, circ two bottoms up with 550 gals min. Printed: 12/1/2003 9:53:45 AM '-. e e BP EXPLORATION Operations Summary Report Page 5 of 10 Legal Well Name: MPF-57 Common Well Name: MPF-57 Spud Date: 3/10/1997 Event Name: REENTER+COMPLETE Start: 9/24/2003 End: 11/30/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 11/30/2003 Rig Name: DOYON 14 Rig Number: 14 , , NPT i Date From - To Hours Task !Code Phase Description of Operations , --.-------..--...- 11/17/2003 02:00 - 04:00 2.00 STWHIP P DECOMP 2250 psi 04:00 - 07:30 3.50 STWHIP P DECOMP Slug pipe and tripping out with Mills 07:30 - 09:30 2.00 STWHIP P DECOMP Lay down BHA ~l"') 09:30 - 10:30 1.00 STWHIP P DECOMP Clear floor, pick up Johnny Wacker was and flush BOP stack ()1'J.~k. 10:30 - 13:00 2.50 DRILL P -fÑT1 Picking up BHA #2,8.5 MXC1 w/3x13 1x10 jets,7" SperryDrill w/1.5 bend.Stab,float sub,flew DC,hang off collar,Stab,2 flex DC,stab, 12 HWP,Jars,5 HWP 13:00 - 18:30 5.50 DRILL P INT1 Tripping in picking up drill pipe 5' 19.5# S 135 from pipe shed, 18:30 - 19:00 0.50 DRILL P INT1 Orient and slide tru window, no problems 19:00 - 19:30 0.50 DRILL P INT1 Directional drill 9372 to 9376, circ for FIT 19:30 - 20:00 0.50 DRILL P INT1 FIT test with 9.5 MW, 9376 MD, 4630 TVD, 720 psi = 12.5 EMW 20:00 - 00:00 4.00 DRILL P INT1 Directional drill 9376' to 9,632' with 80 rpms, 450 gpm, 2400 psi AST 1.67, ART 1.58 TQ 7,000 11/18/2003 00:00 - 00:30 0.50 DRILL P INT1 Directional drill 9632' to 9,650' with 80 rpms, 450 gpm, 2400 psi 00:30 - 02:00 1.50 DRILL P INT1 Circ two bottoms up with, 450 gals min., 2200 psi, 80 rpms 02:00 - 03:00 1.00 DRILL P INT1 pump out to window @ 9356 with full drilling rate, pull tru window with out pump. 03:00 - 06:30 3.50 DRILL P INT1 Flow check, slug pipe, Tripping out 06:30 - 08:30 2.00 DRILL P INT1 Stand back BHA, lay down stabs and mud motor 08:30 - 11 :00 2.50 DRILL P INT1 Pickup Geo-Pilot steerable assy., pressure test manifold to 3500psi, surface test MWD 11 :00 - 14:00 3.00 DRILL P INT1 Tripping in to 7788' 14:00 - 1.5:30 1.50 DRILL P INT1 Cut and slip drill line, service top drive 15:30 - 18:30 3.00 DRILL P INT1 Tripping in to 9320, Mad pass from 8150 to 8450, 9100 to 9320 18:30 - 19:00 0.50 DRILL P INT1 Orient and side tru window, no problems 19:00 - 20:00 1.00 DRILL P INT1 Mad pass to bottom and got ECD base line with 550 gals min 175 rpms was 11.0 20:00 - 00:00 4.00 DRILL P INT1 Directional drill 9,650' to 10231 with 175 rpms, 550 gpm, 2750 psi TQ 10-12K, ART 2.5 ECD 11.5 11/19/2003 00:00 - 17:00 17.00 DRILL P INT1 Directional drill 10,231' to 12056' with 175 rpms, 550 gpm, 3200 psi ECD 12.2 17:00 - 17:30 0.50 DRILL P INT1 Mud out of balanced, circ,cond. ECD 12.0,Due to hole mud dilution 17:30 - 22:00 4.50 DRILL P INT1 Directional drill 12056' to 12671' with 175 rpms, 550 gpm, 3200 psi ECD 11.9 ART 14.45 TQ 10K 22:00 - 00:00 2.00 DRILL P INT1 Circ two bottoms up with 175 rpms, 550 GPM, 3200 psi, ECD drop to 11.2, mud wt 9.1 down from 9.4 11/20/2003 00:00 - 04:00 4.00 DRILL P INT1 Pumped out to window @ 9,340, with full drilling rate, light drag 10-15,000 overpull, no packing off @ 11,540 to 11,450, stab were going tru 8 degree dog leg, 10-15,00 drag 9950 to 9900, 20-25000 drag when bit came into csg 04:00 - 04:30 0.50 DRILL P INT1 Service top drive 04:30 - 06:00 1.50 DRILL P INT1 Trip back to bottom, wash last stand to bottom 06:00 - 11 :00 5.00 DRILL P INT1 Directional drill 12671' to 13,239 with 175 rpms, 600 gpm, 3600 psi ECD 11.3, dropping angle, drop 9 degrees with tool straight 11 :00 - 13:00 2.00 DRILL N DFAL INT1 Circ two bottoms up with 600 gpm 3400 psi 175 rpms (lost signal to GEO- tools) 13:00 - 16:00 3.00 DRILL N DFAL INT1 Pumped out to 11,065 with full drilling rate, pulled out from 11,065 to 9250 W/O pump, no problems Printed: 12/1/2003 9:53:45 AM ',' tit e BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: MPF-57 Common Well Name: MPF-57 Spud Date: 3/10/1997 Event Name: REENTER+COMPLETE Start: 9/24/2003 End: 11/30/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 11/30/2003 Rig Name: DOYON 14 Rig Number: 14 Date From - To . Hours Task Code NPT Phase Description of Operations ".--.---..-----.----- 11/20/2003 16:00 - 19:00 3.00 DRILL N DFAL INT1 POH to BHA 19:00 - 21 :00 2.00 DRILL N DFAL INT1 Down load MWD, Lay down Geo-Pilot tools 21 :00 - 00:00 3.00 DRILL N DFAL INT1 Pick up new Geo-Pilot BHA and upload MWD tool, surface test tools 11/21/2003 00:00 - 04:00 4.00 DRILL N DFAL INT1 RIH to 9,288 04:00 - 05:00 1.00 DRILL N DFAL INT1 Slip and cut drilling ling, service top drive 05:00 - 06:30 1.50 DRILL N DFAL INT1 RIH to 12,202 06:30 - 10:00 3.50 DRILL N DFAL INT1 Attempt Open hole side track well @ 12202 with no success 10:00 - 10:30 0.50 DRILL N DFAL INT1 Rih to 12500 10:30 - 12:00 1.50 DRILL N DFAL INT1 Open hole side track well @ 12,518 to 12,579 12:00 - 15:00 3.00 DRILL N DFAL INT1 Directional drill 12,579' to 13,239' with 175 rpms, 600 gpm, 3400 psi ECD 11.1, TQ 13K 12:00 - 00:00 12.00 DRILL P INT1 Directional drill 13,239' to 14,452' with 175 rpms, 600 gpm, 3400 psi ECD 11.1, TQ 13KART 10.22 11/22/2003 00:00 - 06:00 6.00 DRILL P INT1 Directional drill 14,452' to 15,145' with 175 rpms, 600 gpm, 3400 psi Raised mud weight to 10.6 ppg. 06:00 - 06:30 0.50 DRILL P INT1 Rotate and reciprocate at reduced pump rates due to high ECDs. Slowly stage pumps up to 600 gpm as ECDs decrease. 06:30 - 07:30 1.00 DRILL P INT1 Directional drill from 15145' to 15217'. Control drilling at 1 00-150'/hr to keep ECDs below 12.5 ppg. 07:30 - 09:30 2.00 DRILL P INT1 Circulated and conditioned hole for short trip. Circulated 2 bottoms up and attempting to level out mud weight in circulating system. 09:30 - 13:00 3.50 DRILL P INT1 Pumped out of hole at 550 gpm @ 3300 psi. Pulled into tight spot at 13963'. Unable to work throught tight spot. Backreamed from 13995'-13900'. Worked area with no problems. Continued pumping out of hole to 12400' (100' above open hole sidetrack). 13:00 - 14:30 1.50 DRILL P INT1 Ran back in hole with no problems. Broke circulation and washed last stand to bottom at 450 gpm. 14:30 - 18:30 4.00 DRILL P INT1 Directional drill from 15,217 t015,504 . Control drilling at 100-150'/hrto keep ECDs below 12.5 ppg. (raise mud wt. to 11.0#) 150-175 rpm 525 GPM, 3600 psi TQ 18k-20K, Top drive kicking out, kicked out 5 times in last four hrs, 18:30 - 21 :30 3.00 DRILL N RREP INT1 Circulated Three bottoms, checking top drive, 150 rpms 525 gpm, 3500 psi ECD 12.4 21 :30 - 00:00 2.50 DRILL N RREP INT1 Pumping out 15,504 to 12,500 with full drilling rate, no problems 11/23/2003 00:00 - 00:30 0.50 DRILL N RREP INT1 Pumping out 12,500 to 12,400 with full drilling rate, no problems pull to 12,100 00:30 - 05:00 4.50 DRILL N RREP INT1 Pump slug and tripping out to BHA 05:00 - 07:00 2.00 DRILL N RREP INT1 Stand back BHA and lay down Geo-Pilot tools 07:00 - 12:00 5.00 DRILL P INT1 Pull wear, rig up Test BOPS and Manifold 250-3500 psi, Hydrill 250-2500 psi 5 min per test, Witness by Chuck Scheve AOOGC 12:00 - 12:30 0.50 DRILL P INT1 Service rig 12:30 - 14:30 2.00 DRILL N RREP INT1 Service top drive, working on top drive 14:30 - 16:00 1.50 DRILL N RREP INT1 MIU bit and Geo-Pilot and MWD, surface test tools 16:00 - 19:00 3.00 DRILL N RREP INT1 Trip in to 9291 19:00 - 20:00 1.00 DRILL N RREP INT1 Slip and cut drillline,circ bottoms up and working on top drive 20:00 - 00:00 4.00 DRILL N RREP INT1 working on topdrive, spot EP mud lube pill in csg 11/24/2003 00:00 - 03:00 3.00 DRILL N RREP INT1 Tripping in hole to 15,420', wash last stand to bottom 03:00 - 04:00 1.00 DRILL P INT1 Circ slow with high ECD 12.8 with 330 gpm, raise pump rate as Printed: 121112003 9:53:45 AM e e BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 REENTER+COMPLETE DOYON DRILLING INC. DOYON 14 Date From - To ; Hours Task Code NPT! Phase ______.____.. .__n. .. - . -- -------- --- 11/24/2003 03:00 - 04:00 1.00 DRILL P INT1 04:00 - 07:30 3.50 DRILL N RREP INT1 07:30 - 23:00 15.50 DRILL P INT1 23:00 - 00:00 1.00 CASE P COMP 11/25/2003 00:00 - 02:00 2.00 CASE P COMP 02:00 - 03:00 1.00 CASE P COMP 03:00 - 03:30 0.50 CASE P COMP 03:30 - 06:30 3.00 CASE P COMP 06:30 - 10:30 4.00 CASE P COMP 10:30 -12:30 2.00 CASE N DPRB COMP 12:30 - 16:30 4.00 CASE N DPRB COMP 16:30 - 18:30 2.00 CASE N DPRB COMP 18:30 - 23:30 5.00 CASE N DPRB COMP 23:30 - 00:00 0.50 CASE N DPRB COMP 11/26/2003 00:00 - 01 :00 1.00 CASE N DPRB COMP 01 :00 - 04:00 3.00 CASE N DPRB COMP Page 7 of 10 Start: 9/24/2003 Rig Release: 11/30/2003 Rig Number: 14 Spud Date: 3/10/1997 End: 11/30/2003 Description of Operations _.___._.______. u_ ... "..----.-----.-.. ECD dropped, circ bottoms up ECD drop to 12.3 with 540 gals min. 60 rpms Circ.and reciprocate, Reprogram top drive, max RPM when we got in hole was 100 Directional drill 15504' to 16285' with 118 rpms, 500 gpm, 3500 psi ECD 12.5, TQ 15,000K Circ Three bottoms up with 120 rpms, 550 gals min, 3700 psi. 12.4 ECD Finish Circ Three bottoms up with 120 rpms, 550 gals min, 3700 psi. 12.4 ECD, Ecd dropped to 12.3 Pump out to 15,430 with full drilling rate, tight spot @ 15650,some packing off, worked it 3 times and cleared up, could have been cutting bed or 7 degree dog leg Trip back to bottom Circ Three bottoms up with 120 rpms, 550 gals min, 3700 psi. Starting 12.5 ECD, dropped to 12.3 Pumping out of hole with 525 gpm and 3200 psi. from 16285' to 14950'. Began getting ratty and pulling 10-20K over from 14950' to 13500'. Packed off. Bled off pressure and attempted to pull through tight spot at 13,300' Unable to work through. Ran back in the hole to 13640' and backreamed to 13500' without any problems. Unable to work through tight spot at 13620' . Broke circulation and circulated hole. 480 gpm at 2670 psi. ECD 12.63. Slowly worked rate up as ECDs decreased. Final circulating rate was 515 gpm with ECD of 12.5. Small amount of shale and sand over shake. No indication of unloading hole. PU wt 190K SO wt 125K. Attempted to pump out of hole with 500 gpm at 3000 psi. Hole packing off. Shut down pump and pulled 2 stand out of the hole slowly. Hole appeared to be taking fluid down the drill string. Pumped 200 gpm at 810 psi and continued pumping out of hole with occasional packing off. Hole appeared to be taking mud. Continued pumping out of hole to 11630'. Unable to work through tight spot at 11635' and sets down 11625'. PU wt 190K SO wt 125K pipe is free to rotate between 11635' to 11625' with partial returns. Shut down pump and attempted to pull through tight spot at 11625'- Pulled 265K (75K over). Attempted to circulate at 350 gpm and drill through bridge at 11630' - losing 3 bbllmin and unable to drill with 20K WOB - Back ream up against tight spot with 5K over, let wt drill off, continue to pull up against tight spot with 5k rotating at 110 rpm's - Got by tight spot on second drill off Back ream 11,625 to 9650 with 2bbls min. 500 psi, 100 rpms, would lose mud if pumped any faster, pulled BHA across whipstock with out rotation. 15K to pull stabilizers into casing, 25K to pull bit into casing. - Estimate 129 bbls of 11.0 ppg mud lost to formation last 24 hrs. Monitor well, with slight flow back Pull 5 stands to 8,754 - Improper hole fill, well swabbing, - Monitor well, As drill string pulled up, mud swabbed out of well bore, as drill string lowered mud pushed away. Break circulation at 5 bpm 750 psi, mud lost rate 1/2 bpm - Printed: 12/1/2003 9:53:45 AM ',' e e BP EXPLORATION Operations Summary Report Page 8 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-57 MPF-57 REENTER+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 9/24/2003 Rig Release: 11/30/2003 Rig Number: 14 Spud Date: 3/10/1997 End: 11/30/2003 Date From - To Hours Task 'Code NPT i Phase Description of Operations --------- .... n___ 11/26/2003 01 :00 - 04:00 3.00 CASE N DPRB COMP shaker covered with fine sand and silt - stage rate up as return rate increased - stage up to 500 gpm 1900 psi - with pipe rotating, returns decreased. - shakers starting to clean up after two bottoms up - Circulate total of three bottoms up - no mud lost after first bottoms up 04:00 - 06:30 2.50 CASE N DPRB COMP Monitor well, Well breathing - Return flow rate 15% slowing down to 3% - Gain 39 bbls of mud, Return flow 0-3% on flow meter at 0630 hrs 06:30 - 10:00 3.50 CASE N DPRB COMP Pooh slowly, no slug - Hole taking proper fill after 20 stands 10:00 -13:30 3.50 CASE N DPRB COMP Stand back Hwt drill pipe, Lay down rest of BHA - top two stabilizer & bit partially balled, No balling on Reference sub - Down load MWD and lay down - Clear rig floor - Replace Card in top drive (top drive still will only rotate at 118 rpm's) 13:30 - 14:00 0.50 CASE N DPRB COMP Attempt to make up Re-run 81/2" bit on to NB stabilize, Bad thread on Near bit 4 1/2 reg connection, damaged bit starting thread - could not make up bit. 14:00 - 16:30 2.50 CASE N RREP COMP Continue installing New CUVC card in top drive system, New card did not work - Install old card 16:30 -17:00 0.50 CASE N DPRB COMP Make up BHA #7: 8 1/2" Hughes mill tooth bit, Near bit stabilizer, Hwt drill pipe, Stabilizer, 2 jts Hwt, stabilizer 17:00 - 22:00 5.00 CASE N DPRB COMP TIH - Break circulation and circulate bottoms up at 3,200', full returns - Continue TIH to 9,250' - fill pipe every 25 stands- Trip pipe slowly, good mud returns while trip in hole 22:00 - 23:00 1.00 CASE P COMP Slip and cut drill line 23:00 - 00:00 1.00 CASE N DPRB COMP Circulate bottoms up inside 9 5/8 casing at 9,250' - stage up to 500 gpm 1500 psi, Did not rotate drill string - Mud lost 15 bbll hr - Monitor well, slight flow back -P/U 160K, S/O 115K, Rt 132K - Mud lost to formation last 24 hrs 133 bbls 11/27/2003 00:00 - 01 :00 1,00 CASE N DPRB COMP TIH 9,250 to 11,710' slowly, good mud returns - S/O 11 OK (5K less than inside casing) - no obstruction noticed 01 :00 - 02:00 1.00 CASE N DPRB COMP Break circulation, stage pumps up from 3 bpm to 12 bpm (500 gpm) - Rotate pipe at 150 rpm's - Mud loss at 500 gpm & 150 rpm's 420 bblslhr - slow pumps to 400 gpm with 150 rpm's - Mud loss 180 bblsl Hr - Lost 200 bbls mud in 30 minutes - Blow down top drive. 02:00 - 02:30 0.50 CASE N DPRB COMP Continue TIH very slowly to 12,400' while discussion with Anchorage 02:30 - 11 :00 8,50 CASE N DPRB COMP Pooh stand back drill pipe untill inside casing - Lay down drill pipe 11:00 -11:30 0.50 CASE N DPRB COMP Lay down BHA 11 :30 - 12:30 1.00 CASE N COMP Pull wear bushing, Clear rig floor of tools 12:30 - 14:00 1.50 CASE N COMP Rig up 350 ton air operated Casing equipment and Franks fill up tool - Load pipe shed with 7" casing on driller side 14:00 - 14:30 0.50 CASE N COMP Pre-Job safety meeting with drill crew - Make up shoe and float jts and circulate through - all ok 14:30 - 20:00 5.50 CASE N COMP Run 7" 26# L-80 Btc-mod casing - average make up torque 8,000 ftIlbs -Running speed 60 seconds per jt on slack off - Good mud returns to approx 3700', returns started decreasing slow slack off more - continue run casing to approx 4,500' 20:00 - 20:30 0.50 CASE N COMP Attempt to circulate casing - Break circulation at 1.5 BPM 400 psi - Lost rate 50% - pump total of 15 bbls to break gel strength 20:30 - 00:00 3.50 CASE N COMP Continue running 7" casing at 60 second per jt. - 50% retruns Printed: 12/1/2003 9:53:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02:00 - 02:30 02:30 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 12:30 12:30 - 13:30 13:30 - 15:30 15:30 - 16:30 16:30 - 20:30 e e Page 9 of 10 BP EXPLORATION Operations Summary Report MPF-57 MPF-57 REENTER+COMPLETE DOYON DRILLING INC. DOYON 14 0.50 CASE P COMP Date From - To Hours Task Code NPT Phase ___.__...._______._. . .... _n . ". .. .~. ...~_. 11/27/2003 20:30 - 00:00 3.50 CASE N COMP 11/28/2003 00:00 - 02:00 2.00 CASE P COMP 7.50 CASE P COMP 1.00 CASE P COMP 1.00 CASE P COMP 0.50 CEMT P 1.00 CEMT P COMP COMP 2.00 CEMT P COMP 1.00 WHSUR P COMP 4.00 WHSUR P COMP 20:30 - 21 :30 1.00 WHSUR P COMP 21 :30 - 00:00 2.50 CASE P COMP 11/29/2003 00:00 - 03:30 3.50 CASE P COMP 03:30 - 04:30 1.00 RUNCOMP COMP 04:30 - 05:00 0.50 RUNCOMP COMP Start: 9/24/2003 Rig Release: 11/30/2003 Rig Number: 14 Spud Date: 3/10/1997 End: 11/30/2003 Description of Operations ___._m_..____. __..._ .._ .. ...__._nm____ to approx 7600' - Hole staying full, but no returns below 7600' - 8400' in hole at 2400 hrs. 241 bbls of 11.0 ppg mud lost to formation last 24 hrs. Continue running 7" 26# L-80 btc-mod production casing to 9,327' - 13' above window - 60 second per 40' on slack off while running pipe - Hole staying full, No returns - slack off wt above window 122K Attempt break circulation at 1.5 bpm - pump away 15 bbls, no returns - Safety meeting with new drill crew on running casing. Continue running casing into open hole, 60 second per jt. on slack off. - Hole staying full, no returns - Slack off wt. 115K tangent section, increasing to 130K during angle drop section - Pushing all mud away while running casing. Make up FMC 7 x 11" mandrell casing hanger & Landing jt. - attempt to land casing, tag fill at 16,248' - 37' of fill - Attempt to wash down at 4 bpm 1800 psi with no returns, work down, unable to get below 16,253' - Lost 156 bbls of mud to formation - out of mud - P/U 375K, slack off to block wt. at 50K - Pick up 10' off of fill to 16,243' Rig down Franks fill up tools, Blow down top drive, Make up Dowell cement head Casing shoe at 16,243' Float collar at 16,162' Pre-Job safety meeting on cementing job Pump 5 bbls Fresh water, Test lines 4500 psi, 15 bbls of CW-100 + 20 bbls of Mud Push II mixed at 12.0 ppg - Drop bottom plug, Followed by 180 sx Class 'G' wI .28% 0-65 + .3% 0167 + .15% 0800 + .2% 046 -Yield 1.16 cf/sx - 37 bbls of slurry mixed at 15.8 ppg - Shut down, flush out lines from cement unit to rig floor with water Drop top plug & Displace with 8.5 ppg seawater at average 7 bpm 2100 psi - Bump plug to 3300 psi - CIP at 1514 hrs 11/28/2003 - Floats ok - Did not reciprocate pipe, NO RETURNS, Lost 1,732 bbl of mud to formation running & cementing casing - Lost total 1 ,900 bbls for Well. Rig Down Cement head, Break casing head I Tubing head flange & Pick up Bop stack- No flow back on annulus side Install 11 x7" casing slip with 230k net on slips - void seawater out of 7" casing, Rough cut & Lay down landing jt with mandrell hanger and 25.71' of cut off casing - Make final cut & dress off casing stub - Install FMC Pack-off - Nipple up tubing head & test void area to 4300 psi (80% collapse of 7") for 10 minutes- ok Clear rig floor of casing tools & rig up to lay down drill pipe from derrick Lay down 5" drill pipe out of derrick in mouse hole Continue lay down 5" drill pipe out of derrick in mouse Rig up 4 1/2" YT elevator and power tong - Load pipe with completion equipment Pre-Job safety meeting with drill crew on running completion - Verify torque value: 4 1/2 Nsct = 4000 ftjlbs 4 1/2 TC II = 2700 ftjlbs Printed: 12/1/2003 9:53:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 11/29/2003 04:30 - 05:00 05:00 - 06:00 06:00 - 22:30 22:30 - 23:00 e e BP EXPLORATION Operations Summary Report MPF-57 MPF-57 REENTER+COMPlETE DOYON DRilLING INC. DOYON 14 : Hours I Task I Code NPT I I Phase --..----.---....-.. ". .- -- .. --..- 0.50 RUNCOMP 1.00 RUNCOMP COMP COMP 16.50 RUNCOMP COMP 0.50 RUNCOMP COMP 23:00 - 00:00 1.00 BOPSURP COMP 11/30/2003 00:00 - 00:30 0.50 BOPSURP COMP 00:30 - 01 :30 1.00 BOPSURP COMP 01 :30 - 03:00 1.50 WHSUR P COMP 03:00 - 03:30 0.50 WHSUR P COMP 03:30 - 04:00 0.50 RUNCOMP COMP 04:00 - 05:00 1.00 RUNCOMP COMP 05:00 - 05:30 0.50 RUNCOMP COMP 05:30 - 06:30 1.00 RUNCOMP COMP 06:30 - 07:30 1.00 WHSUR P COMP 07:30 - 09:00 1.50 RIGD P COMP Page 10 of 10 Start: 9/24/2003 Rig Release: 11/30/2003 Rig Number: 14 Spud Date: 3/10/1997 End: 11/30/2003 Description of Operations __. .. n_____..___ _____ Jet Lube seal guard pipe dope on both Run 4 1/2" Frac string completion with Baker 7 x 4 1/2" Premier Packer & Baker 4 1/2" CMD sliding Sleeve Continue to run Frac string completion - Run 199 jts (8,127') of 41/2" 12.6# L-80 Nsct Class 'B' followed by 194 jts (7,599') of 41/2" 12.6# L-80 TC II Class 'B' Tubing - Due to rust debris on connections, clean each connection with steam and re-dope with Jet lube Seal Guard Make up Fmc 11 x 4 1/2" tubing hanger with two way check in place -4 1/2" TC II landing thread - Land tubing string - P/U wt. 215K, S/O 90K - Block wt. 50K - Run in lock down screws - Lay down landing jt. Change top rams to 2 7/8 x 5" Varaible, Change top drive saver sub to 4" HT-38 Finish changing rams & Saver sub Nipple down and set back 13 5/8 5K bop stack Nipple up Fmc 11 x 41/16" 5k adapter spool- Test pack-off to 5000 psi for 10 minutes - Nipple up CIW 41/16 5K Tree, shell test tree to 5000 psi with water - ok Pull CIW 4" Two way check valve with dry rod Drop 1 7/8 ball on roller stem & wait for ball to seat in HRC plug at 15,862' - Pre-Job safety meeting on setting packer & testing casing Pressure up with First Energy pump truck to 4000 psi- set packer at 15,836' and test tubing to 4000 psi for 30 minutes - ok - Bled pressure to 2500 psi Test Packer and casing to 4500 psi for 30 minutes - ok Bled tubing pressure and shear RP valve - bled both sides to zero through RP valve - Rig up on annulus & pump 71 bbls of 80 degree diesel for freeze protection to 2100' Install 4" CIW type 'H' BPV and test from below with HB&R with diesel - ok Vac out lines - Remove double annulus valve, Clean out cellar - secure well - Released rig at 0900 hrs 11/30/2003 9 518 x 7" annulus freeze protected on 11/29/2003 with 60 bbls of diesel to 2100' Printed: 12/1/2003 9:53:45 AM e e Well: Field: API: Permit: MPF-57A Milne Point Unit I Kuparuk River Sands 50-029-22747-01-00 203-167 Accept: Spud; Release: Rig: 11/07/03 11/17/03 11/30/03 Doyon 14 . '·Y· NM'· "' ~··'MH' ~ ·'·'''·'N'=~'' POST-RIG WORK 12/01/03 HAD A DIFFICULT TIME PASSING TOOLS THROUGH 12890'-13700'WLM. PULLED BALL & ROD @ 15830'WLM. WILL RETURN IN AM TO PULL & SET DGLV @ 2108'MD, AND ATTEMPT TO PULL RHC PLUG BODY. 12/02/03 PULLED SOV, AND SET DV @ 2108'MD. ATTEMPTED TO GET DOWN TO RHC PLUG BODY WITH A LIGHTER TOOL STRING, BUT WAS UNABLE TO DO SO. 12/23/03 PULL RHC, SCMT LOG I CTU #5; MIRU, RIH WITH 41/2" GS. LATCH RHC PLUG AT 15870' CTM. PULL FREE WITH 3 JAR LICKS. POOH WITH RHC PLUG. MU AND RIH WITH SLB MEMORY SCMT. 12/24/03 RIH WITH MEMORY SCMT LOG DOWN AND UP PASSES FROM 15750' TO 16160' CTMD AT 0 AND 1000 PSIG WHP. POOH. WELL FREEZE PROTECTED TO 3150' WITH 60/40 METHANOL. UPON RECOVERING DATA, TOOLS GATHERED DATA, HOWEVER PROBLEM DOWNLOADING THE DATA. RDMO AND SLB TO CONTINUE TRYING TO DOWNLOAD DATA. 01/13/04 PERFORATE WITH 3412 POWERFLOW CHARGES @ 12 SPF. RUN GUN GAMMA RAY WITH DUAL ROLLERS AND 10 FOOT GUN ON 1 ST RIH = 30.3 FT X 3.625" MAX OD. DEEPEST PENETRATION = 3820 FT. 2ND RIH - SAME GUN, BUT NO GAMMA RAY - REPLACED WITH COLLAR LOCATOR ONLY. THIS REDUCED OVERALL LENGTH, AND REDUCED LENGTH OF TOOL AT 3.625" OD. 2ND TOOL = 26.8 FT X 3.625" MAX OD. DEEPEST PENETRATION = 3885 FT. 3RD RIH - SAME ARRANGEMENT AS GUN #2, EXCEPT GUN OD REDUCED TO 2 7/8" @ 6 SPF. TOOL = 27 FT X 3.625" MAX OD (AT WHEELS). DEEPEST PENETRATION = 8336 FT. 01/21/04 PERFORATED 15972-15982 WI 3.38" 12-SPF PF-3412 HSD GUN. NEEDED TO PUMP FLUIDS DOWN TUBING WI RETURNS TO IA VIA SLIDING SLEEVE IN ORDER TO FALL THROUGH DEVIATION. PUMPED LUBETECH TO REDUCE LINE FRICTION IN HOLE TO SAFELY LOG BELOW 15,500' MD. TAGGED TD @ 16162' MD. NO OTHER PROBLEMS RIH OR POOH. ,/ 01/22/04 CLOSED SSD, PRESSURE TEST CASING TO 3500#. HELD. PICKUP WEIGHT AT SSD AFTER MUD LUBE PILL WERE ABOUT 1100# @ 100-150'/MIN. INJECT DIESEL DOWN IA TO VERIFY SLIDING SLEEVE IS CLOSED PT IA TO 3500PSI 01/23/04 T/I/O=1450/2820/420 PRE LOG INJECTIVITY TEST FOR BORAX. FWP = 1450/2940/650 01/24/04 LOGGED CHANNEL DETECTION LOG WI RST TOOL IN SIGMA/BORAX MODE AND WATERFLOW MODE. FOUND POSSIBLE CHANNELING BOTH UP AND DOWN FROM PERFOATIONS. APPEARS THAT UPFLOW STOPS CHANNELING AND ENTERS FORMATION BY 15925' MD. TAGGED TD @ MPF-57A Page 2 e e 16153' MD. NO PROBLEMS RIH OR POOH. T/I/O:::: 1800/2700/150, PUMPED 50 BBLS OF SEAH20, 106 BBLS OF BORAX, 269 BBLS OF SEAH20, 56 BBLS OF PILL, & 48 BBLS OF MEOH AS REQUESTED FOR RST LOG, T/IIO:::: 2300/2280/120. 01/28/04 FRAC'D A SANDS PERFS 15972'-982 WI 206.9K# CARBOLlTE USING YF-130LG SYSTEM. PLACED 77.0K# BEHIND PIPE, LEFT 63.0K# IN CSG. EST. TOS:::: 9300' MD. NWB SCREENOUT WITH 8 PPG PROPPANT AT PERFS. MAX TREAT:::: 8700 PSI, AVG TREAT ::::5480 PSI. LOAD TO RECOVER- 1206 BBLS, 1/4 RUBBER CUP FROM ISOLATION TOOL NOT RECOVERED. 01/30/04 ATTEMPTED TO BAIL PIECE OF MISSING SEAL FROM TREE SAVER. RETREIVE AND COUPLE OF SMALL PIECES; BUT BASED ON DESCRIPTION OF WHAT WAS LOST THERE IS SOME RUBBER STILL REMAINING. APPROXIMATE SIZE IF IN ON PIECE IS 1/2" X 1/4" X 3". 02110/04 COMPLETE BOP TEST. MU 2" JSN FOR JETTING ICE/FCO. JET TO 155', NOTICE BAD SECTION OF COIL, POOH. CUT 330' COIL. WINDS PICKING UP TO 45 MPH. STANDBY FOR WEATHER. 02115/04 REVERSE CLEAN OUT FROM 15,855' TO 16,125' CTMD. PUMPED 5 BBL FLO PRO SWEEP DOWN TBG & REVERSE UP COIL FOR FINAL SWEEP AROUND. DRY TAG TD AT 16,105' CTMD, BULLHEAD FREEZE PROTECT THE COIL. (FINAL INJ WHP::::1800 PSI @ 1 BPM PUMPING DOWN COIL). POOH PUMPING 60/40 METH DOWN BACKSIDE FILLING VOIDAGE. WELL IS FP TO +3500' MD. 02117/04 SET 13X JET PUMP (SER# BP-1036). e e Well: Field: API: Permit: MPF-57A Milne Point Unit I Kuparuk River Sands 50-029-22747 -01-00 203-167 Accept: Spud: Release: Rig: 11/07/03 11/17/03 11/30103 Doyon 14 ··M~ '='M='==·~~~===.N~·' POST-RIG WORK 12/01/03 HAD A DIFFICULT TIME PASSING TOOLS THROUGH 12890'-13700'WLM. PULLED BALL & ROD @ 15830'WLM. WILL RETURN IN AM TO PULL & SET DGLV @ 2108'MD, AND ATTEMPT TO PULL RHC PLUG BODY. 12/02/03 PULLED SO V, AND SET DV @ 2108'MD. ATTEMPTED TO GET DOWN TO RHC PLUG BODY WITH A LIGHTER TOOL STRING, BUT WAS UNABLE TO DO SO. 12/23/03 PULL RHC, SCMT LOG / CTU #5; MIRU, RIH WITH 4 1/2" GS. LATCH RHC PLUG AT 15870' CTM. PULL FREE WITH 3 JAR LICKS. POOH WITH RHC PLUG. MU AND RIH WITH SLB MEMORY SCMT. 12/24/03 RIH WITH MEMORY SCMT LOG DOWN AND UP PASSES FROM 15750' TO 16160' CTMD AT 0 AND 1000 PSIG WHP. POOH. WELL FREEZE PROTECTED TO 3150' WITH 60/40 METHANOL. UPON RECOVERING DATA, TOOLS GATHERED DATA, HOWEVER PROBLEM DOWNLOADING THE DATA. RDMO AND SLB TO CONTINUE TRYING TO DOWNLOAD DATA. 01/13/04 PERFORATE WITH 3412 POWERFLOW CHARGES @ 12 SPF. RUN GUN GAMMA RAY WITH DUAL ROLLERS AND 10 FOOT GUN ON 1 ST RIH = 30.3 FT X 3.625" MAX OD. DEEPEST PENETRATION = 3820 FT. 2ND RIH - SAME GUN, BUT NO GAMMA RAY - REPLACED WITH COLLAR LOCATOR ONLY. THIS REDUCED OVERALL LENGTH, AND REDUCED LENGTH OF TOOL AT 3.625" OD. 2ND TOOL = 26.8 FT X 3.625" MAX OD. DEEPEST PENETRATION = 3885 FT. 3RD RIH - SAME ARRANGEMENT AS GUN #2, EXCEPT GUN OD REDUCED TO 2 7/8" @ 6 SPF. TOOL = 27 FT X 3.625" MAX OD (AT WHEELS). DEEPEST PENETRATION = 8336 FT. 01/21/04 PERFORATED 15972-15982 WI 3.38" 12-SPF PF-3412 HSD GUN. NEEDED TO PUMP FLUIDS DOWN TUBING WI RETURNS TO IA VIA SLIDING SLEEVE IN ORDER TO FALL THROUGH DEVIATION. PUMPED LUBETECH TO REDUCE LINE FRICTION IN HOLE TO SAFELY LOG BELOW 15,500' MD. TAGGED TD @ 16162' MD. NO OTHER PROBLEMS RIH OR POOH. 01/22/04 CLOSED SSD, PRESSURE TEST CASING TO 3500#. HELD. PICKUP WEIGHT AT SSD AFTER MUD LUBE PILL WERE ABOUT 1100# @ 100-150'/MIN. INJECT DIESEL DOWN IA TO VERIFY SLIDING SLEEVE IS CLOSED PT IA TO 3500PSI 01/23/04 T/I/O=1450/2820/420 PRE LOG INJECTIVITY TEST FOR BORAX. FWP = 1450/2940/650 01/24/04 LOGGED CHANNEL DETECTION LOG WI RST TOOL IN SIGMA/BORAX MODE AND WATERFLOW MODE. FOUND POSSIBLE CHANNELING BOTH UP AND DOWN FROM PERFOATIONS. APPEARS THAT UPFLOW STOPS CHANNELING AND ENTERS FORMATION BY 15925' MD. TAGGED TD @ MPF-57A Page 2 e e 16153' MD. NO PROBLEMS RIH OR POOH. T/I/O= 1800/2700/150, PUMPED 50 BBLS OF SEAH20, 106 BBLS OF BORAX, 269 BBLS OF SEAH20, 56 BBLS OF PILL, & 48 BBLS OF MEOH AS REQUESTED FOR RST LOG, T/I/O= 2300/2280/120. 01/28/04 FRAC'D A SANDS PERFS 15972'-982 WI 206.9K# CARBOLlTE USING YF-130LG SYSTEM. PLACED 77.0K# BEHIND PIPE, LEFT 63.0K# IN CSG. EST. TOS= 9300' MD. NWB SCREENOUT WITH 8 PPG PROPPANT AT PERFS. MAX TREAT = 8700 PSI, AVG TREAT =5480 PSI. LOAD TO RECOVER- 1206 BBLS, 1/4 RUBBER CUP FROM ISOLATION TOOL NOT RECOVERED. 01/30/04 ATTEMPTED TO BAIL PIECE OF MISSING SEAL FROM TREE SAVER. RETREIVE AND COUPLE OF SMALL PIECES; BUT BASED ON DESCRIPTION OF WHAT WAS LOST THERE IS SOME RUBBER STILL REMAINING. APPROXIMATE SIZE IF IN ON PIECE IS 1/2" X 1/4" X 3". 02110/04 COMPLETE BOP TEST. MU 2" JSN FOR JETTING ICE/FCO. JET TO 155', NOTICE BAD SECTION OF COIL, POOH. CUT 330' COIL. WINDS PICKING UP TO 45 MPH. STANDBY FOR WEATHER. 02115/04 REVERSE CLEAN OUT FROM 15,855' TO 16,125' CTMD. PUMPED 5 BBL FLO PRO SWEEP DOWN TBG & REVERSE UP COIL FOR FINAL SWEEP AROUND. DRY TAG TD AT 16,105' CTMD. BULLHEAD FREEZE PROTECT THE COIL. (FINAL INJ WHP=1800 PSI @ 1 BPM PUMPING DOWN COIL). POOH PUMPING 60/40 METH DOWN BACKSIDE FILLING VOIDAGE. WELL IS FP TO +3500' MD. 02117/04 SET 13X JET PUMP (SER# BP-1036). MPF-57A Page 3 e e 02121/04 HEAT & PUMP SOURCE WATER DOWN IA TO HELP WARM UP & LIFT GEUFRAC SAND FROM WELL BORE (POST FRAC JOB) INITIAL PRESSURES TIIIO 1200/31010 FINAL PRESSURES T/I/O=250/155010. 133 BBLS SOURCE WATER @ 120* & 12 BBLS 60/40 METH.50 BBLS 60/40 METH CHARGED TO THIS WELL Tree: 41/16" - 5M Cit Wellhead: FMC 11" x ' Tbg. Hanger, 4 1/2" TC-II T 4" CIW - Type H BPV profile 20" 91.1 ppf, H-40 115' I- 9 5/8" Whipstock top 9317' Window in 9 5/8" 9340-9356' 7" CIBP set @ 9490' 95/8",40 ppf, L-80 Btrc. 9458' I. KOP @ 500' Max. hole angle = 70 to 76 deg. fl 3600' to 14,000' Hole angle thru' perfs = 11 deg. 41/2" 12.6# L-80 TC-II (Drift 10= 3.864" 10, Cap = .0152 bpf) T' 26#, L-80, BTC casing (Orift 10 = 6.151, Cap wI tbg = .0186 bpf) Perforation Summary Ref log: Size SPF Interval (TVD) 33/8" 12 15,972'-15,982' 7,434'-7,443' 1/ rLc+ ~ý\C\-l CW~YLA-m..- MPU F-57A A Or~g. _lev.: 40.~' (N 22E) Ong. lev. - 12.1 OF To 7' csg. hng. = 27.9' (N 22E) I Casing landed on e"m.erge~cy 1 slips wI 230k down,· " ' ~ " .' o Howco 9 5/8" 'ES' Cementer Camco 4 1/2" x 1" KBG-2 I 2108' GLM This well has been sidètrack~.d from the originalcomplètiop. , ;' ,", Min.ID intubirgl~ XW3.750" @ 15863' "-->,..... ~.:.' ."!: .... NÒTE: 'Severe dOQ leg 12890· 13000', High P/U:wts åfter14500' **** 41/2" 'CMO' Sliding Sleeve I 15801' I opens down (10 3.813") 4.5" HES X nipple (103.813) 15825' 7" Baker Premier Packer 15836' 4.5" HES XN nipple (3.813"/3.75" no-go) 15863' WLEG (bottom) 15875' 7" Weatherford float collar I 16163' (PBTD) .. 7" Weatherford float shoe I 16244' DATE REV. BY COMMENTS 03/25/97 JBF Drilled and Cased by Nabors 22E MILNE POINT UNIT 06/26/97 MOO ESP Completion 4-ES WELL F-57 A 10/29/97 JBF ESP Changeout by Nabors 4-ES API NO: 50-029-22747-01-00 12/07/97 JBF ESP Replacement by Nabors 4-ES 05/02/01 M. Linder Recompleted for Frac and Jet Pump 06/22/01 B. Hasebe ESP Completion Nabors 4ES BP EXPLORATION (AK) 11/30/03 Lee Hulme Sidetrack and Frac String installed 0-14 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-57 A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,509.25' MD 12,518.00' MD 16,285.00' MD . (if applicable) ~ C)3 -.- \ (s) 7-- 29-Dec-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 1 3 2a~,\ Alaska Oil & GasrAns.COtmnIion Andtorá9& DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPF MPF-57 A e Job No, AKZZ0002760572, Surveyed: 24 November, 2003 Survey Report 22 December, 2003 Your Ref: API 500292274701 Surface Coordinates: 6035505.30 N, 542007.17 ~(70° 30' 28.4965- N, 149039' 22.6989- W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1035505.30 N, 42007.17 E (Grid) Surface Coordinates relative to Structure Reference: 5489.08 N, 10223.93 E (True) Kelly Bushing Elevation: 45.85ft above Mean Sea Level Kelly Bushing Elevation: 45.85ft above Project V Reference Kelly Bushing Elevation: 45. 85ft above Structure Reference !!IP,E!'r"r"Y-!!IUI! DA1L.L.IN (;$ eRV I c:e 5 A Halliburton Company Survey Ref: svy1318 .... Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57A Your Ref: API 500292274701 Job No. AKZZ0002760572, Surveyed: 24 November, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12509.25 68.830 49.650 5620.84 5666.69 7178.38 N 6931.39 E 6042722.76 N 548897.86 E 9977.61 Tie On Point 12518.00 68.890 49.570 5624.00 5669.85 7183.67 N 6937.61 E 6042728.09 N 548904.05 E 1.094 9985.72 Window Point 12604.19 69.500 48.820 5654.61 5700.46 7236.32 N 6998.59 E 6042781.08 N 548964.73 E 1.078 10065.84 12698.95 70.430 48.120 5687.07 5732.92 7295.35 N 7065.24 E 6042840.48 N 549031.04 E 1.202 10154.48 12793.79 70.700 48.230 5718.63 5764.48 7354.99 N 7131.88E 6042900.50 N 549097.35 E 0.305 10243.58 e 12887.95 71.930 46.820 5748.80 5794.65 7415.22 N 7197.67 E 6042961.10 N 549162.79 E 1.928 10332.51 12982.44 75.980 39.960 5774.94 5820.79 7481.19 N 7259.95 E 6043027.43 N 549224.70 E 8.187 10423.24 13075.66 75.780 39.390 5797.68 5843.53 7550.77 N 7317.67 E 6043097.33 N 549282.02 E 0.631 10513.48 13169.85 75.650 39.210 5820.92 5866.77 7621.41 N 7375.48 E 6043168.29 N 549339.44 E 0.231 10604.55 13264.44 75.520 39.430 5844.47 5890.32 7692.28 N 7433.53 E 6043239.49 N 549397.09 E 0.264 10695.95 13358.90 75.390 38.320 5868.19 5914.04 7763.46 N 7490.92 E 6043311.00 N 549454.07 E 1.146 10787.13 13453.72 74.200 37.790 5893.06 5938.91 7835.51 N 7547.32 E 6043383.36 N 549510.06 E 1.366 10878.26 13546.08 73.460 37.290 5918.78 5964.63 7905.84 N 7601.37 E 6043454.00 N 549563.71 E 0.955 10966.54 13641.28 72.250 36.930 5946.84 5992.69 7978.39 N 7656.25 E 6043526.85 N 549618.19 E 1.321 11057.00 13736.43 71.010 36.210 5976.83 6022.68 8050.91 N 7710.06 E 6043599.68 N 549671.58 E 1 .488 11146.70 13830.33 70.560 34.940 6007.73 6053.58 8123.02 N 7761.64 E 6043672.09 N 549722.75 E 1.364 11234.59 13924.70 69.950 35.360 6039.62 6085.47 8195.65 N 7812.78 E 6043745.00 N 549773.48 E 0.770 11322.54 14019.12 68.980 35.350 6072.74 6118.59 8267.76 N 7863.94 E 6043817.40 N 549824.23 E 1.027 11410.14 14113.89 67.910 35.810 6107.55 6153.40 8339.45 N 7915.22 E 6043889.37 N 549875.11 E 1.216 11497.51 14208.18 65.620 36.400 6144.75 6190.60 8409.45 N 7966.27 E 6043959.66 N 549925.76 E 2.496 11583.48 14302.13 64.340 36.370 6184.48 6230.33 8477.98 N 8016.77 E 6044028.48 N 549975.87 E 1.363 11668.02 e 14396.41 62.830 37.800 6226.43 6272.28 8545.34 N 8067.68 E 6044096.13 N 550026.40 E 2.100 11751.97 14491.65 61.900 39.770 6270.61 6316.46 8611.11 N 8120.52 E 6044162.19 N 550078.87 E 2.076 11836.09 14585.76 61.910 40.070 6314.92 6360.77 8674.78 N 8173.80 E 6044226.16 N 550131.78 E 0.281 11918.98 14678.76 60.290 38.840 6359.87 6405.72 8737,64 N 8225.54 E 6044289.31 N 550183.17 E 2.092 12000.22 14775.42 58.040 37.200 6409.41 6455.26 8803.01 N 8276.66 E 6044354.97 N 550233.92 E 2.746 12082.88 14868.30 53.870 38.220 6461.40 6507.25 8863.89 N 8323.71 E 6044416.11 N 550280.63 E 4.581 12159.47 14961.60 49.720 39.020 6519.09 6564.94 8921.16 N 8369.45 E 6044473.65 N 550326.04 E 4.499 12232.53 15056.69 44.770 40.120 6583.63 6629.48 8974.98 N 8413.89 E 6044527.72 N 550370.18 E 5.274 12302.19 15149.25 40.430 41.630 6651.75 6697.60 9022.37 N 8454.86 E 6044575.33 N 550410.87 E 4.817 12364.77 15243.00 36.990 41.620 6724.89 6770.74 9066.19 N 8493.79 E 6044619.37 N 550449.56 E 3.669 12423.37 15337.28 33.600 41.850 6801.83 6847.68 9106.83 N 8530.05 E 6044660.22 N 550485.58 E 3.598 12477.82 15430.36 30.100 41.330 6880.88 6926.73 9143.56 N 8562.66 E 6044697.13 N 550517.98 E 3.772 12526.91 15525.33 26.770 39.300 6964.39 7010.24 9178.00 N 8591.94 E 6044731.74 N 550547.07 E 3.651 12572.07 15619.81 20.290 37.370 7050.96 7096.81 9207.52 N 8615.38 E 6044761.39 N 550570.35 E 6.906 12609.63 22 December, 2003 - 15:46 Page 20f4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57 A Your Ref: AP/500292274701 Job No. AKZZ0002760572, Surveyed: 24 November, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 15713.86 18.560 38.330 7139.66 7185.51 9232.22 N 8634.56 E 6044786.20 N 550589.39 E 1.870 12640.78 15807.38 16.380 39.400 7228.86 7274.71 9254.09 N 8652.17 E 6044808.16 N 550606.87 E 2.356 12668.77 15901.96 14.610 39.470 7320.00 7365.85 9273.60 N 8668.22 E 6044827.77 N 550622.81 E 1.872 12693.98 15994.85 11.360 44.030 7410.50 7456.35 9289.23 N 8682.03 E 6044843.47 N 550636.53 E 3.666 12714.82 16087.48 9.360 42.250 7501.62 7547.47 9301.36 N 8693.43 E 6044855.67 N 550647.87 E 2.186 12731.48 e 16182.11 7.390 43.020 7595.23 7641.08 9311.51 N 8702.76 E 6044865.87 N 550657.14 E 2.085 12745.26 16214.01 6.840 44.890 7626.89 7672.74 9314.36 N 8705.50 E 6044868,73 N 550659.86 E 1.871 12749.21 -+6285.00 6.840 44.890 7697.37 7743.22 L... 9320.35 N 8711.47 E 6044874.76 N 550665.79 E - 0.000 12757.66 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 43.170° (True). Magnetic Declination at Surface is 25.078° (12-Nov-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 16285.00ft., The Bottom Hole Displacement is 12757.68ft., in the Direction of 43.066° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) e Comment 12509.25 12518.00 16285.00 5666.69 5669.85 7743.22 7178.38 N 7183.67 N 9320.35 N 6931.39 E 6937.61 E 8711.47 E Tie On Point Window Point Projected Survey 22 December, 2003 - 15:46 Page 3 of 4 Dri/lQuest 3.03.05.005 Milne Point Unit Survey too/program for MPF-57 A From Measured Vertical Depth Depth (ft) (ft) 0.00 9295.05 0.00 4608.19 22 December, 2003 - 15:46 To Measured Vertical Depth Depth (ft) (ft) 9295.05 16285.00 4608.19 7743.22 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57 A Your Ref: API 500292274701 Job No. AKZZ0002760572, Surveyed: 24 November, 2003 BPXA Survey Tool Description AK-1 BP _HG (MPF-57) AK-6 BP _IFR-AK (MPF-57APB1) e e Page 4 of 4 DrillQuest 3.03.05.005 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-57 A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,509.25' MD 12,518.00' MD 16,285.00' MD (if applicable) . ;&0:3-/ wi- 29-Dec-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager Attachment(s) RECEIVED JAN 1 3 2~û4 r1laska 011 & GasCOns..CommisSOn Ar~1Ofàae Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPF MPF-57 A MWD e Job No. AKMW0002760572, Surveyed: 24 November, 2003 Survey Report 22 December, 2003 Your Ref: API 500292274701 Surface Coordinates: 6035505.30 N, 542007.17 E (70030' 28.4965" N, 149039' 22.6989" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1035505.30 N, 42007.17 E (Grid) Surface Coordinates relative to Structure Reference: 5489.08 N, 10223,93 E (True) Kelly Bushing Elevation: 45,85ft above Mean Sea Level Kelly Bushing Elevation: 45.85ft above Project V Reference Kelly Bushing Elevation: 45. 85ft above Structure Reference 5p'·""''''''V-5U., CRIL-LING ·SERVIc:eS A Halliburton Company Survey Ref: svy1319 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57 A MWD Your Ref: AP/500292274701 Job No. AKMW0002760572, Surveyed: 24 November, 2003 BPXA Milne Point Unit Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("¡100ft) 12509.25 68.830 49.340 5620.84 5666.69 7177.30 N 6932.49 E 6042721.68 N 548898.97 E 9977.57 Tie On Point 12518.00 68.890 49,570 5623.99 5669.84 7182.60 N 6938.70 E 6042727.02 N 548905.14 E 2.546 9985.68 Window Point 12604.19 69.500 48.480 5654.61 5700.46 7235.43 N 6999.52 E 6042780.20 N 548965.67 E 1.378 10065.83 12698.95 70.430 49.320 5687.07 5732.92 7293.95 N 7066.61 E 6042839.10 N 549032.42 E 1.287 10154.40 12793.79 70.700 49.330 5718.63 5764.48 7352.24 N 7134.44 E 6042897.77 N 549099.92 E 0.285 10243.33 e 12887.95 71.930 47.310 5748.80 5794.65 7411.56 N 7201.05 E 6042957.46 N 549166.19 E 2.416 10332.16 12982.44 75.980 41.260 5774.93 5820.78 7476.55 N 7264.37 E 6043022.81 N 549229.15 E 7.498 10422.88 13075.66 75.780 39.560 5797.67 5843.52 7545.38 N 7322,97 E 6043091,97 N 549287.36 E 1.782 10513.18 13169.85 75.650 40.110 5820.91 5866,76 7615.47 N 7381.44 E 6043162.39 N 549345.43 E 0.582 10604.30 13264.44 75.520 39.400 5844.46 5890.31 7685,90 N 7440.03 E 6043233.15 N 549403.62 E 0.740 10695,75 13358.90 75.390 39.360 5868.18 5914.03 7756,58 N 7498,04 E 6043304.15 N 549461.23 E 0.144 10786.98 13453,72 74,200 38.410 5893.05 5938.90 7827.80 N 7555.48 E 6043375.70 N 549518.27 E 1.584 10878.22 13546.08 73.460 37.800 5918.77 5964.62 7897,60 N 7610.22 E 6043445,81 N 549572.61 E 1.022 10966.58 13641.28 72.250 38.470 5946.84 5992.69 7969,15 N 7666.39 E 6043517.67 N 549628.38 E 1 .438 11057.20 13736.43 71,010 36.060 5976.83 6022.68 8041.00 N 7721.07 E 6043589,84 N 549682.65 E 2.734 11147.01 13830.33 70.560 36.800 6007.73 6053.58 8112.34 N 7773.73 E 6043661.47 N 549734,90 E 0.885 11235.07 13924.70 69.950 34.970 6039.62 6085.47 8184.30 N 7825.79 E 6043733.72 N 549786,55 E 1.936 11323.17 14019.12 68.980 36.460 6072,74 6118.59 8256.09 N 7877.40 E 6043805.81 N 549837.76 E 1.800 11410.83 14113.89 67.910 36,530 6107,56 6153.41 8326.95 N 7929,82 E 6043876.96 N 549889.78 E 1.131 11498.38 14208.18 65.620 36.580 6144,75 6190.60 8396.54 N 7981.42 E 6043946.84 N 549940.98 E 2.429 11584.44 14302,13 64,340 37.660 6184.49 6230.34 8464.43 N 8032.79 E 6044015.02 N 549991,97 E 1,715 11669.09 e 14396.41 62.830 39.080 6226.43 6272,28 8530.63 N 8085.20 E 6044081.51 N 550044.00 E 2.094 11753.23 14491.65 61,900 39.820 6270,60 6316.45 8595.78 N 8138,81 E 6044146.97 N 550097,24 E 1.195 11837.42 14585.76 61.910 41.580 6314,93 6360,78 8658.72 N 8192.94 E 6044210.21 N 550151.02 E 1.650 11920.36 14678.76 60,290 40.350 6359.87 6405.72 8720.19 N 8246.32 E 6044271.98 N 550204.05 E 2.092 12001.71 14775.42 58.040 37.910 6409.42 6455,27 8784,55 N 8298.70 E 6044336.63 N 550256.07 E 3.180 12084.49 14868,30 53.870 38.710 6461.41 6507.26 8844,93 N 8346.39 E 6044397.28 N 550303.41 E 4.546 12161.16 14961.60 49.720 38.750 6519.10 6564.95 8902,11 N 8392.25 E 6044454.72 N 550348.95 E 4.448 12234.24 15056.69 44.770 39,890 6583.63 6629.48 8956.12 N 8436.46 E 6044508.99 N 550392.85 E 5.279 12303.87 15149,25 40.430 41 .1 00 6651.75 6697,60 9003.77 N 8477.11 E 6044556.86 N 550433,23 E 4.771 12366.44 15243,00 36.990 42.630 6724.90 6770.75 9047,44 N 8516.21 E 6044600.76 N 550472.08 E 3.808 12425.04 15337.28 33.600 42.040 6801,84 6847,69 9087.70 N 8552,90 E 6044641,22 N 550508.54 E 3,614 12479,50 15430.36 30.100 40.690 6880.89 6926.74 9124.54 N 8585.37 E 6044678.24 N 550540.81 E 3.8'37 12528.58 15525.33 26.770 39.360 6964.39 7010.24 9159,14 N 8614.47 E 6044713.01 N 550569.71 E 3.569 12573.73 15619,81 20.290 37.880 7050.97 7096.82 9188.55 N 8638.05 E 6044742.55 N 550593.12 E 6,887 12611.31 22 December, 2003 - 15:49 Page 2 of4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57A MWD Your Ref: AP/500292274701 Job No. AKMW0002760572, Surveyed: 24 November, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0¡100ft) 15713.86 18.560 38.280 7139.66 7185.51 9213.17 N 8657.33 E 6044767.28 N 550612.27 E 1,845 12642.46 15807.38 16.380 39.570 7228.86 7274.71 9235.03 N 8674.96 E 6044789.23 N 550629.77 E 2.367 12670.46 15901.96 14.610 39.850 7320.00 7365.85 9254.47 N 8691.10 E 6044808.76 N 550645.80 E 1.873 12695.68 15994.85 11.360 44.440 7410.51 7456.36 9270.00 N 8705.01 E 6044824.37 N 550659.62 E 3.668 12716.53 16087.48 9.360 42.540 7501.62 7547.47 9282.06 N 8716.49 E 6044836.50 N 550671.04 E 2.190 12733.18 e 16182.11 7.390 43.230 7595.24 7641.09 9292.17 N 8725.87 E 6044846.66 N 550680.35 E 2.084 12746.96 16214.01 6.840 45.170 7626.89 7672.74 9295.00 N 8728.62 E 6044849.51 N 550683.09 E 1.881 12750.91 16285.00 6.840 45.170 7697.38 7743.23 9300.96 N 8734.61 E 6044855.50 N 550689.05 E 0.000 12759.36 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 43.170° (True). Magnetic Declination at Surface is 25,064° (24-Nov-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 16285.00ft., The Bottom Hole Displacement is 12759.36ft., in the Direction of 43.201 0 (True). Comments e Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12509.25 12518.00 16285.00 5666.69 5669.84 7743.23 7177.30 N 7182.60 N 9300.96 N 6932.49 E 6938.70 E 8734.61 E Tie On Point Window Point Projected Survey 22 December, 2003 - 15:49 Page 3 of 4 DrillQuest 3.03.05.005 t Milne Point Unit Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57A MWD Your Ref: AP/500292274701 Job No. AKMW0002760572, Surveyed: 24 November, 2003 .' BPXA Survey too/program for MPF-57 A MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 9295.05 0.00 4608.19 22 December, 2003 - 15:49 To Measured Vertical Depth Depth (ft) (ft) 9295.05 16285.00 4608.19 7743.23 Survey Tool Description AK-1 BP _HG (MPF-57) MWD Magnetic (MPF-57APB1 MWD) e e Page 4 of4 DrillQuest 3.03.05.005 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . &03 -llo1- 29-Dec-03 Re: Distribution of Survey Data for Well MPF-57A PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,295.05' MD 9,340.00' MD 13,239.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED 1 -r '1'\(\ ~ JAN v LUUCoJ AlækaOiI & Gas Cons. Commlion Þ.ndlOfáge DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPF MPF-57APB1 e Job No. AKZZ0002760572, Surveyed: 20 November, 2003 Survey Report 22 December, 2003 Your Ref: API 500292274770 Surface Coordinates: 6035505.30 N, 542007.17 E (70030' 28.4965" N, 149039' 22.6989" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1035505.30 N, 42007.17 E (Grid) Surface Coordinates relative to Structure Reference: 5489.08 N, 10223.93 E (True) Kelfy Bushing Elevation: 45. 85ft above Mean Sea Level Kelfy Bushing Elevation: 45. 85ft above Project V Reference Kelfy Bushing Elevation: 45.85ft above Structure Reference SI]:3E!r"r"Y-SUf1 OFHL.L.ING SEAVICES A Halliburton Company Survey Ref: svy1316 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57 APB1 Your Ref: API 500292274770 Job No. AKZZ0002760572, Surveyed: 20 November, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9295,05 73.390 43.030 4562.34 4608.19 4813.20 N 5058.83 E 6040347.03 N 547038.71 E 6971.47 Tie On Point AK-6 BP _IFR-AK 9340.00 73.010 41 .180 4575.34 4621.19 4845.12 N 5087.69 E 6040379.11 N 547067.38 E 4.030 7014.49 Window Point 9378.85 74.900 39.580 4586.08 4631.93 4873.56 N 5111.87 E 6040407.69 N 547091.40 E 6.271 7051.78 9473.72 74.300 35.670 4611.28 4657.13 4945.98 N 5167.70 E 6040480.43 N 547146.82 E 4,023 7142.80 e 9568.42 71.950 31.760 4638.78 4684.63 5021.33 N 5218.00 E 6040556.06 N 547196.69 E 4.665 7232.17 9596.85 72.180 30.590 4647.53 4693.38 5044.47 N 5232.00 E 6040579.28 N 547210.56 E 3.998 7258.62 9694.02 72.510 30.230 4677.00 4722.85 5124.33 N 5278.87 E 6040659.40 N 547256.98 E 0.490 7348.93 9789.72 73.290 28.670 4705.14 4750.99 5203.98 N 5323.84 E 6040739.30 N 547301.50 E 1.758 7437.79 9880.80 72.580 26.460 4731.87 4777.72 5281.15 N 5364.13 E 6040816.70 N 547341.35 E 2.447 7521.64 9974.08 72.880 25.860 4759.57 4805.42 5361.10 N 5403.40 E 6040896.87 N 547380.17 E 0.693 7606.82 10067.71 69.960 29.030 4789.40 4835.25 5439.85 N 5444.28 E 6040975.85 N 547420.60 E 4.475 7692.22 10162.14 68.840 32.100 4822.63 4868.48 5515.96 N 5489.21 E 6041052.21 N 547465.10 E 3.266 7778.46 10254.78 68.520 34.500 4856.32 4902.17 5588.08 N 5536.59 E 6041124.60 N 547512.07 E 2.438 7863.48 10348.96 69.310 37.490 4890.21 4936.06 5659.16 N 5588.23 E 6041195.97 N 547563.31 E 3.079 7950.65 10443.86 69.760 38.990 4923.39 4969.24 5728.99 N 5643.26 E 6041266.11 N 547617.94 E 1.555 8039.23 10538.50 70.550 40.020 4955.52 5001.37 5797.67 N 5699.89 E 6041335.11 N 547674.18 E 1.321 8128.07 10633.66 70.750 40.190 4987.05 5032.90 5866,35 N 5757.73 E 6041404.11 N 547731.63 E 0.269 8217.72 10727.52 68.850 39.570 5019.46 5065.31 5933.94 N 5814.21 E 6041472.02 N 547787.73 E 2.117 8305.66 10822.40 69.040 38.490 5053.54 5099.39 6002.72 N 5869.96 E 6041541.12 N 547843.10 E 1.081 8393.97 10914.68 69.100 37.500 5086.51 5132.36 6070.64 N 5923.02 E 6041609.34 N 547895.77 E 1.004 8479.81 11007.49 68.850 36.850 5119.81 5165.66 6139.67 N 5975.37 E 6041678.66 N 547947.72 E 0.707 8565.97 e 11096.25 67.970 37.800 5152.47 5198.32 6205.30 N 6025.41 E 6041744.57 N 547997.39 E 1.405 8648.07 11192.65 65.960 40.850 5190.19 5236.04 6273.92 N 6081.60 E 6041813,51 N 548053.20 E 3.581 8736.56 11287.38 70.290 47.730 5225.52 5271.37 6336.73 N 6142.98 E 6041876.67 N 548114.22 E 8.141 8824.37 11381.50 73.460 49.140 5254.80 5300.65 6396.06 N 6209.91 E 6041936.38 N 548180.81 E 3.657 8913.42 11475.05 73.350 48.580 5281.51 5327.36 6455.04 N 6277.42 E 6041995.74 N 548247.99 E 0.586 9002.63 11569.24 73.460 47.630 5308.42 5354.27 6515.32 N 6344.62 E 6042056.39 N 548314.84 E 0.974 9092.57 11663.20 72.390 44.850 5336.01 5381.86 6577.43 N 6409.48 E 6042118.87 N 548379.36 E 3.049 9182.24 11758.46 71.080 40.190 5365.88 5411.73 6644.07 N 6470.61 E 6042185.85 N 548440.10 E 4.844 9272.67 11849.75 70.750 39.410 5395.73 5441.58 6710.35 N 6525.83 E 6042252.45 N 548494.95 E 0.885 9358.79 22 December, 2003 - 15:51 Page 2 of 4 DrillQuest 3,03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57APB1 Your Ref: AP/500292274770 Job No. AKZZ0002760572, Surveyed: 20 November, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11944.08 70.110 40.440 5427.33 5473.18 6778.51 N 6582.87 E 6042320.93 N 548551.61 E 1.232 9447.52 12037.54 70.540 39.140 5458.79 5504.64 6846.13 N 6639.19 E 6042388.87 N 548607.54 E 1,388 9535.37 12131.75 71.400 39.650 5489.51 5535.36 6914.96 N 6695.71 E 6042458.01 N 548663.67 E 1.047 9624.24 12225.69 71.190 40.220 5519.64 5565.49 6983.18 N 6752,83 E 6042526.56 N 548720.40 E 0.617 9713.08 12319.82 68.700 40.370 5551,91 5597.76 7050.62 N 6810.01 E 6042594.32 N 548777.20 E 2.650 9801.38 e 12413.84 68.590 42.020 5586,15 5632.00 7116.51 N 6867.68 E 6042660.53 N 548834.50 E 1.639 9888.89 12509.25 68.830 49.650 5620.84 5666.69 7178.38 N 6931.39 E 6042722.76 N 548897.86 E 7.455 9977.61 12602.62 73.080 61.170 5651.39 5697.24 7228.28 N 7003.95 E 6042773.07 N 548970.13 E 12.514 10063.64 12698.21 72.570 59.860 5679.62 5725.47 7273.23 N 7083.45 E 6042818.47 N 549049.38 E 1.414 10150.81 12792.56 74.450 58.380 5706.40 5752.25 7319.66 N 7161.08E 6042865.34 N 549126.75 E 2.496 10237.79 12886.53 73.370 53.870 5732.46 5778.31 7369.97 N 7236.03 E 6042916.07 N 549201.41 E 4.752 10325.75 12980.76 71.800 42.310 5760,75 5806.60 7429.87 N 7302.83 E 6042976.35 N 549267.87 E 11.821 10415.15 13075.38 71.420 38,660 5790.61 5836.46 7498.15 N 7361 .11 E 6043044.95 N 549325.77 E 3.682 10504.82 13170.66 68.990 38.190 5822.87 5868.72 7568.37 N 7416.83E 6043115.49 N 549381.08 E 2.592 10594.16 13239.00 68.990 38.190 5847.37 5893.22 7618.51 N 7456.27 E 6043165.86 N 549420.24 E 0.000 10657.71 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 43.170° (True). Magnetic Declination at Surface is 25.078° (12-Nov-03) e Based upon Minimum Curvature type calculations, at a Measured Depth of 13239.00ft., The Bottom Hole Displacement is 10660.1 Oft., in the Direction of 44.383° (True). 22 December, 2003 - 15:51 Page 3 of 4 DrillQuest 3.03.05.005 ,. Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57APB1 Your Ref: API 500292274770 Job No. AKZZ0002760572, Surveyed: 20 November, 2003 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9295.05 9340.00 13239.00 4608.19 4621.19 5893.22 4813.20 N 4845.12 N 7618.51 N 5058.83 E 5087.69 E 7456.27 E Tie On Point Window Point Projected Survey e Survey too/program for MPF-57 APB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9295.05 0.00 9295.05 4608.19 13239.00 4608.19 AK-1 BP _HG (MPF-57) 5893.22 AK-6 BP _IFR-AK (MPF-57APB1) e 22 December, 2003 - 15:51 Page 4 of4 DrillQuest 3,03,05.005 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . dc)3- ) tr-'9- 29-Dec-03 Re: Distribution of Survey Data for Well MPF-57A PB1MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,295.05' MD 9,340.00 I MD 13,239.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager Attachment(s) RECEIVED JAN 1 3 2JJ4 ÞJatkaOU & Gas COns.CommiIiDn And\orâge Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPF MPF-57APB1 MWD e Job No. AKMW0002760572, Surveyed: 20 November, 2003 Survey Report 22 December, 2003 Your Ref: AP/500292274770 Surface Coordinates: 6035505.30 N, 542007.17 E (70030' 28.4965" N, 149039' 22.6989" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1035505.30 N, 42007.17 E (Grid) Surface Coordinates relative to Structure Reference: 5489.08 N, 10223.93 E (True) Kelly Bushing Elevation: 45.85ft above Mean Sea Level Kelly Bushing Elevation: 45.85ft above Project V Reference Kelly Bushing Elevation: 45.85ft above Structure Reference spe.-..-.y-su., DFtl'LLING $EFtVI'C:E$ A Halliburton Company Survey Ref: svy1317 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57 APB1 MWD Your Ref: AP/500292274770 Job No. AKMW0002760572, Surveyed: 20 November, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9295.05 73.390 43.030 4562.34 4608.19 4813.20 N 5058.83 E 6040347.03 N 547038.71 E 6971.47 Tie On Point MWD Magnetic -- 9340.00 73.010 41 .180 4575.34 4621.19 4845.12 N 5087.69 E 6040379.11 N 547067.38 E 4.030 7014.49 Window Point 9378.85 74.900 39.580 4586.08 4631.93 __ 4873.56 N 5111.87 E 6040407.69 N 547091.40 E 6.271 7051.78 9473.72 74.300 35.670 4611.28 4657.13 4945.98 N 5167.70 E 6040480.43 N 547146.82 E 4.023 7142.80 e 9568.42 71.950 31.760 4638.78 4684.63 5021.33 N 5218.00 E 6040556.06 N 547196.69 E 4.665 7232.17 9596.85 72.180 30.690 4647.53 4693.38 5044.46 N 5232.02 E 6040579.27 N 547210.58 E 3.671 7258,63 9694.02 72.510 30.540 4677.00 4722.85 5124.15N 5279.18 E 6040659.22 N 547257.29 E 0.370 7349.01 9789.72 73.290 28.190 4705.14 4750.99 5203.86 N 5324.02 E 6040739.18 N 547301.68 E 2.484 7437.83 9880,80 72.580 26.340 4731.87 4777.72 5281.25 N 5363.91 E 6040816.80 N 547341.13 E 2.092 7521.56 9974.08 72.880 25.730 4759.57 4805.42 5361,28 N 5403.01 E 6040897.05 N 547379.77 E 0.702 7606.68 10067.71 69.960 29.400 4789.41 4835.26 5439.95 N 5444.04 E 6040975.94 N 547420.36 E 4.850 7692.12 10162.14 68.840 32.060 4822.63 4868.48 5515.92 N 5489.20 E 6041052.17 N 547465.09 E 2.891 7778.43 10254.78 68.520 34.530 4856.32 4902.17 5588.05 N 5536.57 E 6041124.57 N 547512.05 E 2.508 7863.44 10348.96 69.310 37.470 4890.21 4936.06 5659.13 N 5588.21 E 6041195.94 N 547563.29 E 3.031 7950.62 10443.86 69.760 38.990 4923.39 4969.24 5728.97 N 5643.23 E 6041266.09 N 547617.92 E 1.574 8039.19 10538.50 70.550 40.130 4955.52 5001,37 5797.59 N 5699.93 E 6041335.03 N 547674.22 E 1 .407 8128.03 10633.66 70.750 40.140 4987.05 5032.90 5866.24 N 5757.80 E 6041404.00 N 547731.71 E 0.210 8217.69 10727.52 68.850 39.550 5019.46 5065.31 5933.86 N 5814.24 E 6041471.95 N 547787.76 E 2.108 8305.63 10822.40 69.040 38.630 5053.55 5099.40 6002.59 N 5870.07 E 6041540.98 N 547843.20 E 0.927 8393.95 10914,68 69.100 37.210 5086.51 5132.36 6070.58 N 5923.04 E 6041609.27 N 547895.79 E 1 .439 8479.77 11007.49 68.850 36.450 5119.81 5165.66 6139.92 N 5974.97 E 6041678.91 N 547947.32 E 0.810 8565.87 e 11096.25 67.970 37.840 5152.47 5198.32 6205.71 N 6024.80 E 6041744.98 N 547996.78 E 1.762 8647.95 11192.65 65.960 40.560 5190.20 5236.05 6274.45 N 6080.85 E 6041814.04 N 548052.44 E 3.330 8736.43 11287.38 70.290 47.570 5225.52 5271.37 6337.50 N 6141.98E 6041877.43 N 548113.22 E 8.247 8824.24 11381.50 73.460 49.090 5254.80 5300.65 6396.95 N 6208.80 E 6041937.26 N 548179.69 E 3.701 8913.31 11475.05 73.350 48.670 5281.52 5327.37 6455.91 N 6276.34 E 6041996.60 N 548246.90 E 0.446 9002.52 11569.24 73.460 47.830 5308.42 5354.27 6516.01 N 6343.68 E 6042057.08 N 548313.90 E 0.863 9092.43 11663.20 72.390 45.140 5336.01 5381.86 6577.85 N 6408.81 E 6042119.28 N 548378.68 E 2.964 9182.09 11758.46 71.080 40.350 5365.88 5411.73 6644.24 N 6470.20 E 6042186.03 N 548439.69 E 4.969 9272.51 11849.75 70.750 39.470 5395.73 5441.58 6710.42 N 6525.55 E 6042252.51 N 548494.67 E 0.980 9358.64 22 December, 2003 - 15:51 Page 2 of 4 DrillQuest 3.03.05,005 Halliburton Sperry-Sun Survey Report for Milne Point MPF· MPF-57 APB1 MWD Your Ref: AP/500292274770 Job No, AKMW0002760572, Surveyed: 20 November, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11944.08 70.110 40.620 5427.33 5473.18 6778.46 N 6582.73 E 6042320.88 N 548551.46 E 1.334 9447.39 12037.54 70.540 39.290 5458.80 5504.65 6845.92 N 6639.24 E 6042388.65 N 548607.59 E 1.417 9535.25 12131.75 71.400 39.910 5489.52 5535.37 6914.54 N 6696.01 E 6042457.59 N 548663.97 E 1.105 9624.14 12225.69 71.190 40.630 5519.64 5565.49 6982.43 N 6753.53 E 6042525.81 N 548721.10 E 0.760 9713.00 12319.82 68.700 40.330 5551.92 5597.77 7049.68 N 6810.92 E 6042593.38 N 548778.12 E 2.662 9801 .32 e 12413.84 68.590 42.350 5586.16 5632.01 7115.42N 6868.76 E 6042659.45 N 548835.58 E 2.004 9888.83 12509.25 68,830 49.340 5620.84 5666.69 7177.30 N 6932.49 E 6042721.68 N 548898.97 E 6.830 9977.57 12602.62 73.080 61.130 5651.40 5697.25 7227.41 N 7004.89 E 6042772.20 N 548971.08 E 12.769 10063.65 12698.21 72.570 59.570 5679.62 5725.47 7272.58 N 7084.26 E 6042817.83 N 549050.19 E 1.648 10150.90 12792.56 74.450 56.770 5706.41 5752.26 7320.30 N 7161.11 E 6042865.98 N 549126.77 E 3.474 10238.27 12886.53 73.370 54.300 5732.46 5778.31 7371.38 N 7235.54 E 6042917.48 N 549200.91 E 2.775 10326.46 12980.76 71.800 39.880 5760.79 5806.64 7432.37 N 7301.22 E 6042978.84 N 549266.25 E 14.692 10415.87 13075.38 71.420 38.420 5790.65 5836.50 7502.00 N 7357.91 E 6043048.78 N 549322.54 E 1,518 10505.43 13170.66 68.990 37.240 5822.91 5868.76 7572.79 N 7412.89 E 6043119.89 N 549377.12 E 2.804 10594.69 13239.00 68.990 37.240 5847.41 5893.26 7623.58 N 7451.50 E 6043170.90 N 549415.44 E 0.000 10658.14 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey), Vertical Section is from Well and calculated along an Azimuth of 43.170° (True). Magnetic Declination at Surface is 25.078° (12-Nov-03) e Based upon Minimum Curvature type calculations, at a Measured Depth of 13239.00ft., The Bottom Hole Displacement is 1 0660.39ft., in the Direction of 44.346° (True). 22 December, 2003 - 15:51 Page 3 of 4 Dri/lQuest 3.03,05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-57 APB1 MWD Your Ref: API 500292274770 Job No. AKMW0002760572, Surveyed: 20 November, 2003 . BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9295.05 9340.00 13239.00 4608.19 4621.19 5893.26 4813.20 N 4845.12 N 7623.58 N 5058.83 E 5087.69 E 7451.50 E Tie On Point Window Point Projected Survey e Survey tool program for MPF-57 APB1 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9295.05 0.00 9295.05 4608.19 13239.00 4608.19 AK-1 BP _HG (MPF-57) 5893.26 MWD Magnetic (MPF-57APB1 MWD) e 22 December, 2003 - 15:51 Page 4 of 4 DrillQuest 3,03,05.005 (ill }.!Æ~ @ ~/? 1M ~ _ilk . / FRANK H. MURKOWSKI, GOVERNOR / ! , í 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AI,ASHA OIL AND GAS CONSERVATION COMMISSION Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPF-57 A BP Exploration (Alaska), Inc. Pennit No: 203-167 Surface Location: 2052' NSL, 2555' WEL, Sec. 06, Tl3N, RlOE, UM Bottomhole Location: 838' NSL, 4307' WEL, Sec 28, T14N, R10E, UM Dear Mr. Archey: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~Ä Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this...L.tL day of October, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2052' NSL, 2555' WEL, SEC. 06, T13N, R10E, UM ' Top of Productive Horizon: 784' NSL, 4353' WEL, SEC. 28, T14N, R10E, UM ' Total Depth: 838' NSL, 4307' WEL, SEC. 28, T14N, R10E, UM . . STATE OF ALASKA . ALASKA C. ~ND GAS CONSERVATION COM SION PERMIT TO DRILL 20 MC 25.005 11 b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: B Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 16286' ' TVD 7695" 7. Property Designation: ADL 355017 #to ('7 'm" t II Development Oil D,Multiple Zone o Development Gas 13" Single Zone AJ 11. Well Name and Number: MPF-57A 12. Field I Pool(s): Milne Point Unit 1 Kuparuk River Sands 8. Land Use Permit: 13. Approximate Spud Date: 10/11/03 14. Distance to Nearest Property: 2530' 9. Acres in Property: 2560 4b. Location of Well (State Base Plane Coordinates): Surface: X-542007 ' y-6035505 . Zone-ASP4 ' 16. Deviated Wells: Kickoff Depth 18.<Cél~ing Program Size Casinç¡ 7" Hole 8-1/2" 9500' ft Maximum Hole Angle Specifications Grade Couplinç¡ L-80 BTC-M Weiç¡ht 26# 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): Plan~~d1~BE= feet 700' away from MPF-57 17. Anticipated pressure (see 20 AAC 25.035) 72 0 Max. Downhole Pressure: 4101" psig. Max. Surface Pressure: 3355 psig Setting Depth Quantity of Cement Top Bottom (c.f. or sacks) Lenç¡th MD TVD MD TVD (including stage data) 16286' Surface Surface 16286' 7741' 157 sx Class 'G' 19. ÞRESENT WELL CONbJ'TION SUMMARY (TO be oomþlètèdfOr Redl'ilfANbRè-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 16750 7811 NIA 16648 7720 Casing Length Size Cement Volume MD Structural Conductor Surface . Intermediate Production Liner Junk (measured): 16648 TVD 115' 9426' 20" 9-5/8" 250 sx Arcticset 1 (Approx.) 2011 sx PF 'E', 800 sx 'G' 115' 9458' 115' 4653' 16699 7" 250 sx Class 'G' 16731' 7794' 20. Attachments B Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 7473' -7491' B Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 0 Drilling Fluid Program B20 AAC 25.050 Requirements Perforation Depth MD (ft): 16370' - 16390' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Date: Contact Matt Green, 564-5581 Phone Permit APP!Ol~1 / Date: /0/ (¡If 03 Mud Log Required Directional Survey Required See cover letter for other requirements o Yes ~o Was 0 No Permit To Drill . API Number: " Number: 22)3 - /67 50-029-22747-01-00 Conditions of Approval: Samples Required 0 Yes ~No Hydrogen Sulfide Measures J2(Yes 0 No Other: ~~O~C;\ t'^-.\~\ ......'-.)\M.. '\3CJ"'?-\-ê,,>-\- t'-' '~,-- 1) 1 t..·........ , Approved By: 8 ~I!"\ RdcA.1I~lbrAF4 Form 10-401 Revised 3/2003' 1), I U . I ~ J-\ L BY ORDER OF THE COMMISSION Date /S/¿/Q1 Submit In Duplicate tit .e Point MPF-57A Well Permit IWell Name: IMPF-57A Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Producer ,- Surface Location: 3227' FNL, (2053' FSL);' 2555' FEL; (2603' FWL), SEC. 6, T13N, R1 OE / E=542007.18/N=6035505.29' 4495' FNL, (784' FSL),"'4353' FEL;'(927' FWL), SEC. 28, T14N, R10E /' E=550680 N=6044850 Z=7430-ft TVDss 4442' FNL, (838' FSL)~ 4307' FEL; (972' FWL), SEC. 28, T14N, R10E / E=550725 N=6044904 Z=7695-ft TVDss Target Location: Top A-Sand Target Location: BHL A-Sand Well TD I AFE Number: I I Estimated Start Date: 111 Oct 2003 I MD: 116,286 "I TVD: 17,695i I Rig: I Doyon 14 I Operating days to complete: 118.0 I Max Inc: 171 I I KOP: 19500 1 I KBE: 146.1 I Well Design (conventional, slim hole, etc.): I Conventional Sidetrack Frac Producer I Objective: I Kuparuk A-Sand / Mud Program: 8.S-in Intermediate Hole Mud Properties: Density (ppg) I PV VP I HTHP 11.0 - 11.2 1 10 - 20 22 - 28 N/A LCM Restrictions: None. ,/ Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-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. LSND Freshwater Mud pH I API Filtrate LG Solids 9.0 - 9.5 < 8 < 12 Cement Program: CasinQ Size 17.0-in 26.0-lb/ft L-80 BTC-M Intermediate Casing Basis 140% excess over gauge hole. Lead 500-ft MD above top of Kuparuk D-Sand. Total Cement Volume: 39-bbl Wash 5-bbl water Spacer Lead Temp 30-bbI10.2-lb/gal Spacer _.,._,_...__ 32-bbl, 157-sx 15.6 Ib/gal Prem G - 1.22 fe/sx (top of lead at 15,267-ft MD) BHST = 175°F from SOR 1 · _e Point MPF-57A Well Permit Evaluation Proaram: ~ 8.5-in Section Open Hole: MWD/GRlRES PWD / I FRlCASANDRA Cased Hole: N/A Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* KLGM 15631 7112 3068 8.35 0/ TKUD 15767 7241 3124 10.64 TKC1 15922 7389 4063 10.64 TKUB 15928 7395 4066 10.64 TKUA 15986 7451 4097 10.64 TKA3 15994 7458 4101 " 10.64 TKA2 16008 7472 4109 10.64 TKA1 16033 7496 4122 10.64 TMLV 16086 7547 4150 10.64 / CasingITubing Program: Hole Csg WtJ Grade Conn Burst Collapse Length Top Bottom Size Diam Ft MD/TVDrkb MD/TVDrkb 42-in 20-in* 92 H-40 Weld 1530 520 122-ft 0 122-ft / 122·ft 12.25-in 9.625-in 40 L-80 BTC-M 5750 3090 9,458-ft 0 9,458-ft / 4,656-ft 8.5-in 7.0-in 26 L-80 BTC-M 7240 5410 16,286-ft 0 16,286-ft / 7,741-ft "--. - Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type 1 8.5-in 3,832 - 9,423-ft PDC Nozzle/Flow rate 3-15 & 1-1 0 2 .... .ne Point MPF·57A Well Permit ',- Well Control: Intermediate and Production Intervals · Maximum anticipated BHP: 4,101-psi @ 7,458-ft TVDss - Top of Kuparuk A-sand · Maximum suñace pressure: 3,355-psi @ surface (Based on BHP and a full column of gas from TO @ 0.1-psi/ft) · Planned BOP test pressure: Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 3,500-psi high. An FIT to 12.5-lb/gal will be made at the 9.625-in casing shoe. 32-bbl with 11.0-lb/gal mud and FIT of 11.5-lb/gal @ 9.625-in window. 10.8-lb/gal NaCI / 6.8-lb/gal Diesel · Integrity test: · Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: Lost Circulation · The possibility of lost circulation is high on MPF-57 A using the relatively high mud density of 11.0-lb/gal. · 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. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling through the Schrader Bluff. The reservoir pressure in the Kuparuk formations is overpressured on MPF-57 A. The most recent offset pressure on MPF-57 (19 Aug 03) was 4,063-psi @ 7,447-ft TVO or 10.5-lb/gal. Pad Data Sheet · Please read the F-Pad Data Sheet thoroughly. Breathing · Wellbore breathing is a moderate possibility with the relatively high mud density used. Good operating practices to minimise ECD and surge/swab pressures should be employed. Hydrocarbons · Hydrocarbons will be encountered in the Kuparuk sands. The Schrader Bluff will be behind the existing surface casing and will not be exposed. Faults · No faults are predicted in the sidetrack interval. Hydrogen Sulfide 3 . ene Point MPF-57A Well Permit · MPF-Pad is not designated as an HzS Pad, however Standard Operating Procedure for HzS precautions should be followed at all times. Highest Level of HzS on F-Pad 17.7 ppm on MPF-22, Feb 2001 19.9 ppm on MPF-30, Feb 2001 16.4 ppm on MPF-62, Feb 2001 23.5 ppm on MPF-69, Feb 2001 Anti-collision Issues · None. Distance to Nearest Property · MPF-57 A is 2,530-ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPF-57A is 700-ft from the Kuparuk A-sand penetration in MPF-57. 4 1. MIRU. NU BOPE and test. 2. Pull 2.875-in ESP completion. 3. P & A Kuparuk zone per AOGCC regulations. 4. Make mechanical cut at +/- 9,550-ft in 7.0-in casing. Pull and lay down. 5. Set cement plug from 7.0-in stub to 100-ft inside 9.625-in casing. wac. ~ ~rilling Procedure with Doyon-14 c,~~ \~ ?t(JY ~ -- .ne Point MPF-57A Well Permit DRILL & COMPLETION PROCEDURE Decompletion with Doyon-14 --- ~ 6. TIH with drilling assembly. Test casing to 3,500-psi 7. Drill out cement and 20-ft new formation and perform FIT. 8. Drill 8.5-in hole as per directional plan. 9. Run and cement 7.0-in casing to TD. 10. Displace drilling mud to brine. 11. Perforate well. -' 12. Run 4.5-in frac string completion as per schematic. 13. Land tubing hanger and test. 14. Set BPV. 15. ND BOP. 16. Install and test tree. 17. Pull BPV. 18. Test 7" x 4-1/2" annulus. 19. Freeze protect both annuli. 20. Install BPV and secure well. 21. RD/MO. Completion Procedure 22. MIRU Frac Equipment. 23. Frac A-Sand. 24. Open Sliding Sleeve and run Jet pump. 25. Flow well to clean-up. 26. MIRU 4ES. 27. PuIl4.5-in frac string. 28. Run 2.875-in ESP completion. 29. RD/MO 5 Tree: 2-9/16" - 5M CI1I Wellhead: FMC 11" x 2- bg. Hanger, 2-7/8 NSCT T&B, 0-4Pkt. CIW - BPVT, 2-7/8" 8 rd. pup jt. in bttm. of hanger. 20" 91.1 ppf, H-40 115' I- KOP @ 500' Max. hole angle = 72 to 75 deg. f/3650'to 14,000' Hole angle thru' perfs = 28 deg. 9 5/8", 40 ppf, L-80 Btrc. 9458' I ~ 2-7/8",6.5#, L-BO 8rd,aJE (2.441" 10, Cap. .00579 bbls/ft.) 7' 26 ppf, L-80, Btrc.prod. casing, (drift 10= 6.151", cap. = 0.0383 bpf) Stimulation Summary 06/18/97 - 61 M# of 16-20 Carbolite behind pipe. Formation screen out. Perforation Summary Ref log: SWS GRlCCL 05/12/97 Size SPF I Interval (TVD) 33/8' 6 16370'-16390' (7447'-7475') 24 gm ROX Big Hole @ 60 deg. phasing (EHD = 0.56", TTP = 12.89") Reperf for frac 4/29/01 Size SPF Interval (TVD) 4.5" 12 16370'-16380' (7447'-7464') Sch 43CJ charge @ 135/45 deg. phasing (EHO 0.77, TTP = 5.93") MPU F-57 A DATE 03/25/97 06/26/97 10/29/97 12/07/97 05/02/01 06/22/01 REV. BY JBF MDO JBF JBF M. Linder B. Hasebe COMMENTS Drilled and Cased by Nabors 22E ESP Completion 4-ES ESP Changeout by Nabors 4-ES ESP Replacement by Nabors 4-ES Recompleted for Frac and Jet Pump ESP Completion Nabors 4ES Or!g. OFAv.: 40.~' (N 22E) Ong. G~. - 12.1 DF To 7' csg. hng. = 27.9' (N 22E) Howco 9 5/8" 'ES' o Cementer Cameo 2-7/8" x 1" side pocket KBMM GLM " 27/8" 'XU' Sliding Sleeve opens up (10 2.313") 2-7/8" XN nipple (ID 2.205") Pump, 159 stg. GC1150 Tandem Gas Separator (Intake 7,177' TVO) Tandem Seal Section I GSB3 DB UT/LT IL H6 PFS Aflas/HSN Motor, 130 HP KME-1 2145 volt, 35 amp 450 Series Phoenix MS1 w/6 fin Centralizer 138' 15,968' 16,011' 16,025' 16,045' 16,050' 16,064' 16,083' Tubing Cut at 16,148' 7" Baker S-3 packer 16153' I 4.5" HES XN nipple 16176' 3.813"/3.75" no-go Baker shear out sub (5.22 Od~ 16188' x Marker Jts 16,207' - 16,249' RKB Fish: Baker shear out seat and packer setting ball. 7" float collar (PBTO) ~ 7" float shoe 16648 ' 16731 ' MILNE POINT UNIT WELL F-57 API NO: 50-029-22747 BP EXPLORATION (AK) Tree: 2-9/16" - 5M CIW~ MPU F-57 ABANDONMENT Orig. OF&v. = 40.8' (N 22E) Wellhead: FMC 11" x 2- bg. Orig. G~. = 12.1' Hanger, 2-7/8 NSCT T&B, 0-4Pkt. DF To 7' csg. hng. = 27.9' (N 22E) CIW - BPVT, 2-7/8" 8 rd. pup jt. in bttm. of hanger. 20" 91.1 ppf, H-40 I 115' I" KOP @ 500' Max. hole angle = 72 to 75 deg. f/3650'to 14,000' Hole angle thru' perfs = 28 deg. 9 5/8", 40 ppf, L-80 Btrc.1 9458' I. T' 26 ppf, L-80, Btrc.prod. casing, (drift 10= 6.151", cap. = 0.0383 bpf) Stimulation Summary 06/18/97 - 61 M# of 16-20 Carbolite behind pipe. Formation screen out. Perforation Summary Ref log: SWS GRlCCL 05/12/97 Size SPF Interval (TVD) 33/8' 6 16370'-16390' (7447'-7475') 24 gm ROX Big Hole @ 60 deg. phasing (EHO = 0.56", TTP = 12.89") Reperf for frac 4/29/01 Size SPF Interval (TVD) 4.5" 12 16370'-16380' (7447'-7464') Sch 43CJ charge @ 135/45 deg. phasing (EHD 0.77, TTP = 5.93") DATE 03/25/97 06/26/97 10/29/97 12/07/97 05/02101 06/22/01 Howco 9 5/8" 'ES' o Cementer Camco 2-7/8" x 1" side pocket KBMM GLM 138' " 7.0-in CIBP ~ JO'c>~\~<..«:.~ , '\<000 ~\ ~~ ~n:.."" t 7.0-in EZSV \<.0 \OCJ ~<!'\ ~<:J.\- ~~~'l '>- \ \ ~~\"> (_.cè.~~ ~ Tubing Cut at 16,148' 7" Baker S-3 packer 16153' 4.5" HES XN nipple 16176' 3.813"/3.75" no-go r\. Baker shear out sub (5.22 od~ 16188' x Marker Jts 16,207' - 16,249' RKB A REV. BY COMMENTS JBF Drilled and Cased by Nabors 22E MDO ESP Completion 4-ES JBF ESP Changeout by Nabors 4-ES JBF ESP Replacement by Nabors 4-ES M. Linder Recompleted for Frac and Jet Pump B. Hasebe ESP Completion Nabors 4ES Fish: Baker shear out seat and packer setting ball. ~ 7" float collar (PBTD) 7" float shoe 16648 ' 16731 ' MILNE POINT UNIT WELL F-57 API NO: 50-029-22747 BP EXPLORATION (AK) ~ 4-1/16"-5M FMC a Wellhead: 11" x 4.5" 5M Gen. w/4.5" TCII T&B Tubing Hanger CIW "H" BPV profile .. DF elev. = 40.S?' (N22E) . GL. elev.= 12.1 MPF-57A Proposed l 20" 91.1-lblft H-40 ~ D!Ð 9.625-in 40-lblft L-SO BTRC casing 19458' I.. Sidetrack on Cement Plug at 9500' 7.0-in 26-lb/ft L-80 IBT-M casing (drift ID = 6.151", cap = 0.0383-bbl/ft) 4.5" 12.6# L-80 IBT-M tubing Reservoir Fluid Perforated and frac Kuparuk A-sands 7.0-in Float Shoe 16.286'/ I ~ DATE REV. BY COMMENTS 24-Sep-03 MDG Proposed Sidetrack Producer KOP @ 500' Max hole angle in tubing = 71 degree 15 degrees at sleeve Cameo 4.5" x 1" wI BK latch sidepocket KGB-2 GLM 1 2100' I Phoenix Discharge gauge (3.833-in drift ) I 3.5" HES "XD" Dura sliding sleeve 3.813" 10 (Opens down) Phoenix Jet Pump gauge sensor NOTE: ID change min. 3.833-in 7.0" x 4.5" Baker Premier Packer 115,800'1 4.5" HES XN-Nipple WLEG I ~ MILNE POINT UNIT WELL MPF-57A API NO: 50-029-22747 BP EXPLORATION (AK) COMPANYDEfAILS REFERENCE INFORMATION SURVEY PROGRAM Deplh Fro Deplh To SurveylPim 9500.00 16286.40 Planned: MPF-57 A wpœ V5 Plan: :MPF·57 A wp08 (:MPF-57JPlan MPF-51 A NW target) OP Armco Cakulawn Method: Mininmm Curvature == ~~:¿~erNorth W=~:~~ i:boc~~asing Co-ordina1l: (NÆ) Reference: Well Centæ: MPF·57, True North Vertical(fVD) Reference: 64: 61 8Il7!1995 00:0046.10 Sccwn (VS) Reference: Sbt - 57 (O.cION,O.OOE) Meas~~~~=~; ~I~~~:OO 46.10 Tool MWD+IFR+MS Created By: Bart Goff Check<d: Date: 08/2912003 Date:_ Reviewed: Date:_ CASING DETAILS WELL DErAILS 400()- Name +NI-S +FJ-W NordWg ....... LatÈdc longäude Snt No. TVD MD Name Size MPF-57 5503.68 10217.39 6035505.29 542007.18 70'3<728.496N 149"39'22.699W 57 7740.98 16286.39 7" 7.000 TARGET DEl' AILS ...... TVD MPF·57ANWTI 7476.10 +NI·S +FJ-W 9296.39 8726.44 No...... 6014840.96 &sting Shape S5œ80.06 Polygon 300()- I ~ I I ~ ~ ", " " " ',..... '" .......... ;11 All TVD depths are ssTVD plus 72'for RKBE. Start Dir 4""00': 9500' MD. 4668.69'TVD End Dir : 9775' MD. 4756.84' TVD Start Dir 4""00': 10050' MD, 4847.85'TVD EndDir: 10248.44'MD.4913.62'TVD SECTION DETAILS Sec MD Inc Azi TVD +N/,S +EI,W DLeg TFace VSec Target I 9500.00 72.05 42.92 4668.69 4956.82 5192.48 0.00 0.00 7167.66 2 9775.00 70.67 31.40 4756.84 5164.01 5349.63 4.00 ,99.00 7426.28 3 10050.00 70.67 31.40 4847.85 5385.51 5484.82 0.00 0.00 7680.32 4 10248.44 70.68 39.81 4913.62 5537.60 5593.71 4.00 91.35 7865.75 e 5 14405.11 70.68 39.81 6288.85 8550.86 8105.08 0.00 0.00 11781.59 6 15725.42 17.87 39.81 7201.10 9234.08 8674.51 4.00 180.00 12669.46 7 16012.16 15.00 39.81 7476.10 9296.39 8726.44 1.00 180.00 1275Q.43 MPF,57 A NW T1 8 16136.40 15.00 39.81 7596.10 9321.09 8747.02 0.00 0.00 12782.53 9 16286.40 15.00 39.81 7740.99 9350.91 8771.88 0.00 0.00 12821.29 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 7112.10 15630.83 KLGM 2 7241.10 15767.40 TKUD 3 7389.10 15921.90 TKC1 4 7395.10 15928.14 TKUB 5 7451.10 15986.27 TKUA 6 7458.10 15993.52 TKA3 7 7472.10 16008.02 TKA2 8 7496.10 16032.87 TKA1 9 7547.10 16085.67 TMLV 5000 ~ § '" i5. ð ij 6000 € " > 2 f- Slart Dir4"/I00': 14405.11' MD, 6288.85'TVD ~~ 7000 e Start Dir 1"/100': 15725.42' MD. 720l.t'TVD ,\6: _ End Dir : 16012.16' MD, 7476.1' TVD '), MPF,57A wp08 8000 6000 7000 8000 9000 10000 11000 Vertical Section at 43.17" [IOOOft/in] 12000 I I I 13000 I I I I I , I ' 14000 I I I I I I t , I ' 15000 COMPANY DErAIlS BP Armco CakuJalÎon Method: Mnimun Curvature =:red:t !f~v~~~erNOrth W=;=d~ ~1ic~:Jasing REFERENCE INFORMATION Co~rdÎnll.Ie (NÆ) Reference: Wet Centre: MPF-57, True North Ver6cal(TVD) Reference: 64 :618117/1995 000046.10 Section (VS) Reference: Sbt - 57 (O.OON,O.ooE) rms'ë'.~~~e=d; ~lg~~OO 46.10 10000- MPF,57 A NW Tl 9000 ":"., - .:: :5 ~ +' :E t 0 ~ :E 7000 :; 0 '" .:; .,,=- 4000 I I I I I I I I I I I , I ' 9000 5000 6000 7000 West(,)lEast(+) [500fUin] 8000 SURVEY PROGRAM Depth Fm Depth. To SurveyJPIan 9500.00 16286.40 PBnned: MPF·57A wpœ V5 Plan: MPF-57 A WJiJ8 (MPF-57/Plan MPF-57 A NW target) T~l MwD+IFR+MS Created By. Batt Goff Check'" Date: 0812912003 Date:_ Date:_ Reviewed: SECTION DETAILS See MD Ine Azi TVD +N/,S +E/,W DLeg TFace VSee Targl't 1 9500.00 72.05 42.92 4668.69 4956.82 5192.48 0.00 0.00 7167.66 2 9775.00 70.67 31.40 4756.84 5164.01 5349.63 4.00 ,99.00 7426.28 3 10050.00 70.67 31.40 4847.85 5385.51 5484.82 0.00 0.00 7680.32 4 10248.44 70.68 39.81 4913.62 5537.60 5593.71 4.00 91.35 7865.75 5 14405.11 70.68 39.81 6288.85 8550.86 8105.08 0.00 0.00 11781.59 6 15725.42 17.87 39.81 7201.10 9234.08 8674.51 4.00 180.00 12669.46 7 16012.16 15.00 39.81 7476.10 9296.39 8726.44 1.00 180.00 12750.43 MPF,57 A NW Tl 8 16136.40 15.00 39.81 7596.10 9321.09 8747.02 0.00 0.00 12782.53 9 16286.40 15.00 39.81 7740.99 9350.91 8771.88 0.00 0.00 12821.29 WElL œrAIlS ....... +N/-S +Fl·W No_ Easmg ùlitnde Longitude Sb, MPF-57 5503.68 10217.39 6035505.29 542007.18 7O"30'2ß.496N 149"39'22.699W 57 T ARGEl' DETAILS wp08 ....... TVD +NI-S +Fl-W No_ Easling S"'pc e MPF-57A NW T1 7476.10 9296.39 8726.44 6044849.96 550680.06 Polygon CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Formation 7740.98 16286.39 7" 7.000 1 7112.10 15630.83 KLGM 2 7241.10 15767.40 TKOO 3 7389.10 15921.90 TKCl All TVD depths are 4 7395.10 15928.14 TKUB 5 7451.10 15986.27 TKUA 6 7458.10 15993.52 TKA3 ssTVD plus 72'for RKBE. 7 7472.10 16008.02 TKA2 8 7496.10 16032.87 TKAl / l '~I 9 7547.10 16085.67 TMLV "- e I I I I I .#' .,' "" " '#, ""Q;¡, ", ~ , ~ , ~~' ~~ ~ / Q;¡, e Sperry-SUD Planning Report - Geographic Compall1~': I''ield: Site: Well: \\'elllI1th: BP Amoco Milne Point M PI F Pad MPF-57 Plan MPF-57 A NW target )Ille: 08/29/2003 1'iml~: 13:00:47 Co-onlinute(NE) neferenl"e: Well: MPF-57, True North Vertical (TVI» Rerel'enee: 64: 618/17/199500:0046.1 Sl~l:lion (\'8) Referem:e: Well (0.00N,O.OOE,43.17Azi) I'¡III: MPF-57A wp08 -------..-. ------.... Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Dlltum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: M PI F Pad TR-13-10 UNITED STATES: North Slope Site Position: NortWng: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6029958.49 ft 531814.44 ft Latitude: 70 29 Longitude: 149 44 North Reference: Grid Convergence: e __A"'. .__.__.___. __ _______ I'a~e: . . ____ n._ .__._ ..---- Alaska, Zone 4 Well Centre bggm2OO3 34.438 N 23.616 W True 0.25 deg WeD: MPF-57 Slot Name: 57 MPF-57 Surface Position: +N/-S 5503.68 ft Northing: 6035505.29 ft Latitude: 70 30 28.496 N +EI-W10217.39 ft Easting : 542007.18 ft Longitude: 149 39 22.699 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 5503.68 ft Northing: 6035505.29 ft Latitude: 70 30 28.496 N +EI-W10217.39 ft Easting : 542007.18 ft Longitude: 149 39 22.699 W Measured Depth: 34.00 ft Inclination: 0.00 deg VerticllI Depth: 34.00 ft Azimuth: 0.00 deg WeD path: Plan MPF-57A NW target Current Datum: Magnetic Data: Field Strength: Vertical Section: Plan: MPF-57A wp08 PrincipllI: Yes Plan Section Information MD Ind ft deg '9500.00 72.05 9775.00 70.67 10050.00 70.67 10248.44 70.68 14405.11 70.68 15725.42 17.87 16012.16 15.00 16136.40 15.00 16286.40 15.00 Section 1 : Start , ·MD Ind ft deg 9500.00 72.05 9600.00 71.47 9700.00 70.98 9775.00 70.67 Section 2 : Start MD Ind ft deg 9800.00 70.67 9900.00 70,67 64: 61 8/17/199500:00 07/30/2003 57530 nT Depth From (TVD) ft 34.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 Height 46.10 ft +N/-S ft 0.00 Date Composed: Version: Tied-to: MPF-57 9500.00 ft Mean Sea Level 25.15 deg 80.86 deg Direction deg 43.17 08/27/2003 5 From: Definitive Path ·A7Jm TVD +N/-S +EI-W DLS Build Turn TFO deg ft ft ft deg/1ooft deg/100ft deg/100ft deg 42.92 4668.69 4956.82 5192.48 0.00 0.00 0.00 0.00 31.40 4756.84 5164.01 5349.63 4.00 -0.50 -4.19 -99.00 31.40 4847.85 5385.51 5484.82 0.00 0.00 0.00 0.00 39.81 4913.62 5537.60 5593.71 4.00 0.00 4.24 91.35 39.81 6288.85 8550.86 8105.08 0.00 0.00 0.00 0.00 39.81 7201.10 9234.08 8674.51 4.00 -4.00 0.00 180.00 39.81 7476.10 9296.39 8726.44 1.00 -1.00 0.00 180.00 39.81 7596.10 9321.09 8747.02 0.00 0.00 0.00 0.00 39.81 7740.99 9350.91 8771.88 0.00 0.00 0.00 0.00 Target MPF-57A NW T1 Azim TVD +N/-S +FJ-W VS DLS Build 'furn·.. TFO deg ft .. ft ft ft deg/100ft deg/100ft deg/100ft deg'· 42.92 4668.69 4956.82 5192.48 7167.66 0.00 0.00 0.00 0.00 38.75 4700.00 5028.66 5254.56 7262.53 4.00 -0.58 -4.17 -99.00 34.56 4732.20 5104.59 5311.07 7356.57 4.00 -0.49 -4.19 -97.70 31.40 4756.84 5164.01 5349.63 7426.28 4.00 -0.41 -4.21 -96.34 ....-.-....-. Azim TVD +N/-S +FJ-W VS DLS Build Turn TFO deg ft ft ft ft degl100ft degl100ft deg/10OO deg 31.40 4765.12 5184.15 5361.92 7449.37 0.00 0.00 0.00 0.00 31.40 4798.21 5264.69 5411.08 7541.75 0.00 0.00 0.00 0.00 ---- --------- COInpan)': I'ield: Site: Well: WellJlath: Section BP Amoco Milne Point MPtFPad MPF-57 Plan MPF-57 A NW target 2 : Start 1\11) It 10000.00 10050.00 Section 3: Start -.--.-----. !\IJ) ft 10100.00 10200.00 10248.44 Section 4: Start MD «> 10300.00 10400.00 10500.00 10600.00 10700.00 10800.00 1 0900.00 11000.00 11100.00 11200.00 11300.00 11400.00 11500.00 11600.00 11700.00 11800.00 11900.00 12000.00 12100.00 12200.00 12300.00 12400.00 12500.00 12600.00 12700.00 12800.00 12900.00 13000.00 13100.00 13200.00 13300.00 13400.00 13500.00 13600.00 13700.00 13800.00 13900.00 14000.00 14100.00 14200.00 14300.00 14405.11 Section 5: Start MD ft 14500.00 14600.00 Incl deg 70.67 70.67 Azim dog - ---.. ...-. 31.40 31.40 TVI> ft 4831.31 4847.85 e Sperry-Sun Planning Report - Geographic ....____ .------______0· _... --..---. +NI-S ft --.--.---. 5345.24 5385.51 -.-.-----.--------.. - .-----.- Ind deg 70.64 70.64 70.68 "····Incl , deg 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 Incl deg 66.88 62.88 ^zim deg 33.52 37.76 39.81 Azim deg 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 A7.Îm deg 39.81 39.81 1'\'1) ft 4864.42 4897.58 4913.62 TVD ft 4930.68 4963.77 4996.85 5029.94 5063.02 5096.11 5129.19 5162.28 5195.36 5228.44 5261.53 5294.61 5327.70 5360.78 5393.87 5426.95 5460.04 5493.12 5526.21 5559.29 5592.38 5625.46 5658.55 5691.63 5724.72 5757.80 5790.89 5823.97 5857.06 5890.14 5923.23 5956.31 5989.40 6022.48 6055.57 6088.65 6121.74 6154.82 6187.91 6220.99 6254.08 6288.85 TVD ft 6323.19 6365.62 +N/-S ft 5425.32 5501.98 5537.60 +N/-S' , ..,.. ...,·ft 5574.98 5647.47 5719.97 5792.46 5864.95 5937.44 6009.93 6082.43 6154.92 6227.41 6299.90 6372.39 6444.89 6517.38 6589.87 6662.36 6734.85 6807.35 6879.84 6952.33 7024.82 7097.31 7169.81 7242.30 7314.79 7387.28 7459.77 7532.27 7604.76 7677.25 7749.74 7822.24 7894.73 7967.22 8039.71 8112.20 8184.70 8257.19 8329.68 8402.17 8474.66 8550.86 +N/-S ft 8618.80 8688.34 e -_._-,--,_...._-....,-- 1)¡lle: 08/29/2003 Time: 13:00:4'7 l'a¡:e: Co-ordinate(;\;E) Reference: Well: MPF-57, True North Vertical (TVI» Refcl'ence: 64: 61 8/17/199500:0046.1 Section (VS) Referenee: Well (0.OON,0.OOE,43.17Azi) l'lan: MPF-57A wp08 +E/-W ft 5460.24 5484.82 +EJ-W ft 5510.13 5565.09 5593.71 +EI-W ft. 5624.87 5685.28 5745.70 5806.12 5866.54 5926.95 5987.37 6047.79 6108.21 6168.62 6229.04 6289.46 6349.88 6410.30 6470.71 6531.13 6591.55 6651.97 6712.38 6772.80 6833.22 6893.64 6954.05 7014.47 7074.89 7135.31 7195.72 7256.14 7316.56 7376.98 7437.40 7497.81 7558.23 7618.65 7679.07 7739.48 7799.90 7860.32 7920.74 7981.15 8041.57 8105.08 +EI-W ft 8161.70 8219.66 VS ft 7634.13 7680.32 VS ft .. - -....-------. 7726.67 7820.18 7865.75 7914.32 8008.53 8102.73 8196.94 8291.15 8385.35 8479.56 8573.76 8667.97 8762.18 8856.38 8950.59 9044.80 9139.00 9233.21 9327.41 9421.62 9515.83 9610.03 9704.24 9798.44 9892.65 9986.86 10081.06 10175.27 10269.47 10363.68 10457.89 10552.09 10646.30 10740.50 10834.71 10928.92 11023.12 11117.33 11211.53 11305.74 11399.95 11494.15 11588.36 11682.57 11781.59 VS ft 11869.87 11960.25 2 ------ . ... .-- .-- m.s nuild Turn deg/100lt deg/1001t deg/10OfI 0.00 0.00 0.00 0.00 0.00 0.00 TH) deg 0.00 0.00 .----------. m.s Build Turn deg/100ft deg/10Oft dog/100ft 4.00 -0.07 4.24 4.00 0.00 4.24 4.00 0.08 4.24 TH) deg 91.35 90.65 89.24 'rro ;:'~eg':..,... 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 DLS Build .<'·'rurn deg/100ft deg/1 Ö()ft dé{íl1 (J()ft.·.; 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dl.S Build. Turn' degl100ft degl100ft deg/10Oft 4.00 -4.00 0.00 4.00 -4.00 0.00 TFO deg 180.00 180.00 e Sperry-Sun Planning Report - Geographic ...___________ ___, ~.~."_..,,_. ._un Company: Held: Site: Well: Wellpath: Section BP Amoco Milne Point MPtFPad MPF-57 Plan MPF-57 A NW target 5 : Start MI> fl 14700.00 14800.00 14900.00 15000.00 15100.00 15200.00 15300.00 15400.00 15500.00 15600.00 15700.00 15725.42 fne! deg 58.88 54.88 50.88 46.88 42.88 38.88 34.88 30.88 26.88 22.88 18.88 17.87 Section 6: Start Ine! deg 17.12 16.12 15.12 15.00 15800.00 15900.00 16000.00 16012.16 Section 7: Start ··..··:i;)i;iif 16100.00 16136.40 loci deg 15.00 15.00 Section 8: Start ······;;;·MDi··;····, ·..··ft .,' .. 16200.00 16286.40 Survey MD .. . ft 9500.00 9600.00 9700.00 9775.00 9800.00 9900.00 10000.00 10050.00 10100.00 10200.00 10248.44 10300.00 10400.00 10500.00 10600.00 10700.00 10800.00 10900.00 11000.00 11100.00 JJicl deg 15.00 15.00 Incl. ···..deg 72.05 71.47 70.98 70.67 70.67 70.67 70.67 70.67 70.64 70.64 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 70.68 ----.----- -' .- Azim deg 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 Azilll deg 39.81 39.81 39.81 39.81 Azilll deg 39.81 39.81 Azim deg 39.81 39.81 . .. .. :Azim' deg 42.92 38.75 34.56 31.40 31.40 31.40 31.40 31.40 33.52 37.76 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 39.81 TVI> ft 6414.27 6468.89 6529.23 6594.97 6665.81 6741.40 6821.37 6905.33 6992.87 7083.57 7176.98 7201.10 TVI>:' ft· . 7272.23 7368.05 7464.35 7476.10 TV!) . ft ': 7560.94 7596.10 TVD ft .' 7657.54 7740.99 TVI> ft 4668.69 4700.00 4732.20 4756.84 4765.12 4798.21 4831.31 4847.85 4864.42 4897.58 4913.62 4930.68 4963.77 4996.85 5029.94 5063.02 5096.11 5129.19 5162.28 5195.36 +1'1;/-8 ft 8755.44 8819.76 8881.01 8938.87 8993.07 9043.34 9089.43 9131.13 9168.23 9200.55 9227.93 9234.08 +N/-S ft 9251.31 9273.28 9293.96 9296.39 +Nï-s ft 9313.86 9321.09 +N/-S ft 9333.74 9350.91 +N/-S;" ft 4956.82 5028.66 5104.59 5164.01 5184.15 5264.69 5345.24 5385.51 5425.32 5501.98 5537.60 5574.98 5647.47 5719.97 5792.46 5864.95 5937.44 6009.93 6082.43 6154.92 e I>ate: 0812912003 Time: 13:00:47 Co-ordinate(NE) Reference: Well: MPF-57, True North Vertical ('I'\'» Reference: 64: 61 8/17/199500:00 46.1 S(~(~tion (VS) ]~eference: Well (0.00N,0.ooE,43.17Azi) 1'I1In: MPF-57A wp08 --.-----.--- --. - . -- - --- - - .---------- +E/-W VS I>J.S lIuild Turn ft ft deg/100ft degl100ft degl100fl n_.... __. .........______ ____________________ 8275.58 12047.44 4.00 -4.00 0.00 8329.19 12131.04 4.00 -4.00 0.00 8380.24 12210.63 4.00 -4.00 0.00 8428.46 12285.82 4.00 -4.00 0.00 8473.63 12356.25 4.00 -4.00 0.00 8515.53 12421.58 4.00 -4.00 0.00 8553.95 12481.48 4.00 -4.00 0.00 8588.70 12535.67 4.00 -4.00 0.00 8619.62 12583.88 4.00 -4.00 0.00 8646.56 12625.88 4.00 -4.00 0.00 8669.37 12661.46 4.00 -4.00 0.00 8674.51 12669.46 4.00 -4.00 0.00 +FJ-W. ft 8688.86 8707.17 8724.41 8726.44 .'. V:})¡!;i!:~~~ft !;~~ft d~n;OOft 12691.84 1.00 -1.00 0.00 12720.40 1.00 -1.00 0.00 12747.28 1.00 -1.00 0.00 12750.43 1.00 -1.00 0.00 +FJ-W VS ft ft· 8740.99 12773.13 8747.02 12782.53 . DLS lIuild Turn ":'dEig/100ft degl100ft degl100ft 0.00 0.00 0.00 0.00 0.00 0.00 +FJ-W VS ft ft 8757.56 12798.97 8771.88 12821.29 -tFJ-W ft 5192.48 5254.56 5311.07 5349.63 5361.92 5411.08 5460.24 5484.82 5510.13 5565.09 5593.71 5624.87 5685.28 5745.70 5806.12 5866.54 5926.95 5987.37 6047.79 6108.21 DLS Build Turn ..' dEig/100ft dEig/10Oftdegl10Qft 0.00 0.00 0.00 0.00 0.00 0.00 Map Northing ft 6040490.91 6040563.09 6040639.33 6040698.96 6040719.16 6040799.98 6040880.80 6040921.20 6040961.15 6041038.11 6041073.89 6041111.44 6041184.27 6041257.09 6041329.92 6041402.74 6041475.57 6041548.39 6041621.22 6041694.04 Map Easting ft 547171.03 547232.71 547288.78 547326.99 547339.17 547387.87 547436.57 547460.92 547466.01 547540.52 547568.94 547599.88 547659.88 547719.88 547779.88 547839.88 547899.88 547959.88 548019.89 548079.89 <---- Latitude ----> Deg Min See 70 31 17.227 N 70 31 17.933 N 70 31 18.680 N 70 31 19.264 N 70 31 19.462 N 70 31 70 31 70 31 70 31 70 31 70 31 70 31 70 31 70 31 70 31 70 31 70 31 70 31 70 31 70 31 ]'3¡:e: 3 TFO deg 180.00 180.00 180.00 180.00 180.00 180.00 180.00 180.00 180.00 180.00 180.00 180.00 _un __ ___ ~ n-ø.: d~ 180.00 180.00 180.00 -180.00 '1'1"0. deg 0.00 0.00 "/TFO' ·deg. 0.00 0.00 <--- Longitude --> .. Deg Min See . 149 36 49.671 W 149 36 47.839 W 149 36 46.172 W 149 36 45.035 W 149 36 44.672 W 20.254 N 149 36 43.222 W 21.045 N 149 36 41.771 W 21.441 N 149 36 41.046 W 21.833 N 149 36 40.299 W 22.586 N 149 36 38.677 W 22.936 N 149 36 37.833 W 23.304 N 149 36 36.914 W 24.016 N 149 36 35.132 W 24.729 N 149 36 33.349 W 25.441 N 149 36 31.567 W 26.154 N 149 36 29.784 W 26.866 N 149 36 28.002 W 27.578 N 149 36 26.219 W 28.291 N 149 36 24.437 W 29.003 N 149 36 22.654 W e Sperry-Sun e Planning Report - Geographic _____~ - . ___n __ . . - -...-------... -- .'''..,,-.----.. . ,----"-,-,, ""... ComplU1Y: BP Amoco Hide: 08129/2003 Tillie: 13:00:47 I'a~e: 4 Held: Milne Point Co-ordin.'llc(~¡';) Reference: Well: MPF-57, True North Site: M Pt F Pad Vertkal (T\'D) Reference: 64 : 61 8/17/199500:00 46.1 Well: MPF-57 Sedioll (\'8) Referenœ: Well (0.00N,O.OOE,43.17Azi) Wellpnth: Plan MPF-57A NW target l'lan: MPF-57A wp08 -- - . ..._____n. . . _____... . -- Survey ----" .._-_.._.~.._--- :\1.;11) Map <---- T .atitude ----> <--- Longitude ---> 1\o1l> Incl Azim TVI) +:'Ii/-S +I'J-\" Sorlhing 1~ll~ti n~ Ueg Min Sel~ De~ !\Iin See ft deg deg fI fI fI ft ft ---. ---- - -- .---- -----.----- - n__... n________ ___..._. 11200.00 70.68 39.81 5228.44 6227.41 6168.62 6041766.87 548139.89 70 31 29.716 N 149 36 20.871 W 11300.00 70.68 39.81 5261.53 6299.90 6229.04 6041839.69 548199.89 70 31 30.428 N 149 36 19.089 W 11400.00 70.68 39.81 5294.61 6372.39 6289.46 6041912.52 548259.89 70 31 31.141 N 149 36 17.306 W 11500.00 70.68 39.81 5327.70 6444.89 6349.88 6041985.35 548319.89 70 31 31.853 N 149 36 15.523 W 11600.00 70.68 39.81 5360.78 6517.38 6410.30 6042058.17 548379.89 70 31 32.566 N 149 36 13.741 W 11700.00 70.68 39.81 5393.87 6589.87 6470.71 6042131.00 548439.89 70 31 33.278 N 149 36 11.958 W 11800.00 70.68 39.81 5426.95 6662.36 6531.13 6042203.82 548499.89 70 31 33.990 N 149 36 10.175 W 11900.00 70.68 39.81 5460.04 6734.85 6591.55 6042276.65 548559.89 70 31 34.703 N 149 36 8.392 W 12000.00 70.68 39.81 5493.12 6807.35 6651.97 6042349.47 548619.89 70 31 35.415 N 149 36 6.609 W 12100.00 70.68 39.81 5526.21 6879.84 6712.38 6042422.30 548679.90 70 31 36.128 N 149 36 4.826 W 12200.00 70.68 39.81 5559.29 6952.33 6772.80 6042495.12 548739.90 70 31 36.840 N 149 36 3.043 W 12300.00 70.68 39.81 5592.38 7024.82 6833.22 6042567.95 548799.90 70 31 37.552 N 149 36 1.260 W 12400.00 70.68 39.81 5625.46 7097.31 6893.64 6042640.77 548859.90 70 31 38.265 N 149 35 59.477 W 12500.00 70.68 39.81 5658.55 7169.81 6954.05 6042713.60 548919.90 70 31 38.977 N 149 35 57.694 W 12600.00 70.68 39.81 5691.63 7242.30 7014.47 6042786.42 548979.90 70 31 39.690 N 149 35 55.911 W 12700.00 70.68 39.81 5724.72 7314.79 7074.89 6042859.25 549039.90 70 31 40.402 N 149 35 54.128 W 12800.00 70.68 39.81 5757.80 7387.28 7135.31 6042932.08 549099.90 70 31 41.114 N 149 35 52.345 W 12900.00 70.68 39.81 5790.89 7459.77 7195.72 6043004.90 549159.90 70 31 41.827 N 149 35 50.561 W 13000.00 70.68 39.81 5823.97 7532.27 7256.14 6043077.73 549219.90 70 31 42.539 N 149 35 48.778 W 13100.00 70.68 39.81 5857.06 7604.76 7316.56 6043150.55 549279.90 70 31 43.251 N 149 35 46.995 W 13200.00 70.68 39.81 5890.14 7677 .25 7376.98 6043223.38 549339.90 70 31 43.964 N 149 35 45.211 W 13300.00 70.68 39.81 5923.23 7749.74 7437.40 6043296.20 549399.91 70 31 44.676 N 149 35 43.428 W 13400.00 70.68 39.81 5956.31 7822.24 7497.81 6043369.03 549459.91 70 31 45.388 N 149 35 41.645 W 13500.00 70.68 39.81 5989.40 7894.73 7558.23 6043441.85 549519.91 70 31 46.101 N 149 35 39.861 W 13600.00 70.68 39.81 6022.48 7967.22 7618.65 6043514.68 549579.91 70 31 46.813 N 149 35 38.078 W 13700.00 70.68 39.81 6055.57 8039.71 7679.07 6043587.50 549639.91 70 31 47.525 N 149 35 36.294 W 13800.00 70.68 39.81 6088.65 8112.20 7739.48 6043660.33 549699.91 70 31 48.238 N 149 35 34.511 W 13900.00 70.68 39.81 6121.74 8184.70 7799.90 6043733.16 549759.91 70 31 48.950 N 149 35 32.727 W 14000.00 70.68 39.81 6154.82 8257.19 7860.32 6043805.98 549819.91 70 31 49.662 N 149 35 30.943 W 14100.00 70.68 39.81 6187.91 8329.68 7920.74 6043878.81 549879.91 70 31 50.375 N 149 35 29.160 W 14200.00 70.68 39.81 6220.99 8402.17 7981.15 6043951.63 549939.91 70 31 51.087 N 149 35 27.376 W 14300.00 70.68 39.81 6254.08 8474.66 8041.57 6044024.46 549999.91 70 31 51.799 N 149 35 25.592 W 14405.11 70.68 39.81 6288.85 8550.86 8105.08 6044101.01 550062.98 70 31 52.548 N 149 35 23.717 W 14500.00 66.88 39.81 6323.19 8618.80 8161.70 6044169.26 550119.21 70 31 53.215 N 149 35 22.046 W 14600.00 62.88 39.81 6365.62 8688.34 8219.66 6044239.12 550176.77 70 31 53.899 N 149 35 20.335 W 14700.00 58.88 39.81 6414.27 8755.44 8275.58 6044306.52 550232.31 70 31 54.558 N 149 35 18.683 W 14800.00 54.88 39.81 6468.89 8819.76 8329.19 6044371.15 550285.55 70 31 55.190 N 149 35 17.101 W 14900.00 50.88 39.81 6529.23 8881.01 8380.24 6044432.67 550336.24 70 31 55.792 N 149 35 15.593 W 15000.00 46.88 39.81 6594.97 8938.87 8428.46 6044490.80 550384.13 70 31 56.360 N 149 35 14.169 W 15100.00 42.88 39.81 6865.81 8993.07 8473.63 6044545.25 550428.99 70 31 56.893 N 149 35 12.836 W 15200.00 38.88 39.81 6741.40 9043.34 8515.53 6044595.75 550470.60 70 31 57.387 N 149 35 11.599 W 15300.00 34.88 39.81 6821.37 9089.43 8553.95 6044642.05 550508.75 70 31 57.840 N 149 35 10.464 W 15400.00 30.88 39.81 6905.33 9131.13 8588.70 6044683.95 550543.27 70 31 58.249 N 149 35 9.438 W 15500.00 26.88 39.81 6992.87 9168.23 8619.62 6044721.21 550573.98 70 31 58.614 N 149 35 8.525 W 15600.00 22.88 39.81 7083.57 9200.55 8646.56 6044753.68 550600.72 70 31 58.931 N 149 35 7.730 W 15700.00 18.88 39.81 7176.98 9227.93 8669.37 6044781.18 550623.39 70 31 59.200 N 149 35 7.056 W 15725.42 17.87 39.81 7201.10 9234.08 8674.51 6044787.37 550628.48 70 31 59.261 N 149 35 6.904 W 15800.00 17.12 39.81 7272.23 9251.31 8688.86 6044804.67 550642.74 70 31 59.430 N 149 35 6.480 W 15900.00 16.12 39.81 7368.05 9273.28 8707.17 6044826.74 550660.92 70 31 59.646 N 149 35 5.940 W 16000.00 15.12 39.81 7464.35 9293.96 8724.41 6044847.52 550678.05 70 31 59.849 N 149 35 5.430 W 16012.16 15.00 39.81 7476.10 9296.39 8726.44 6044849.96 550680.06 70 31 59.873 N 149 35 5.371 W. 16100.00 15.00 39.81 7560.94 9313.86 8740.99 6044867.51 550694.51 70 32 0.045 N 149 35 4.941 W ·.. ' ,'< .. e Sperry-Sun Planning Report - Geographic e .'....;..,..FiS~l:te'::::Pa.:...'..n. y:.!.' . ;~~n~~~~t . :HMPt F·Pad ".,'....,. '::~::I~~~;>:!!.'~i:~M~þ-$?A NW target . ... . .. ..:... .. .. ..... . .. Date: 08129/2Q93. Time:' J3:00:47,.:,:,,:,;:;';:;r .. ·'P3ge: '. ..~~~~~~~:~:~:~~e: ~~J~w~~~r~~æ:~rt~6.1 ."i~::r?:Ð'S)Rererence:"·'..,.·?M~~~z~~OOE;43.17 Azi) 5 Survey --- -- -----.- -----. -".. ..... l\I~l) l\1~p <---- I"lIlitude ----> <--- Longitude ---> 1\11> locI '\zi III n') +:\/-S +IU-W Norlhin~ E¡L~tin~ )e¡: Mill See ))e~ Min See ft deg deg ft ft It ft ft -.-. n_. .. _n.. ._______._ ------ I 16136.40 15.00 39.81 7596.10 9321.09 8747.02 6044874.78 550700.50 70 32 0.116N 149 35 4.763 W 16200.00 15.00 39.81 7657.54 9333.74 8757.56 6044887.48 550710.97 70 32 0.240 N 149 35 4.452 W 16286.40 15.00 39.81 7740.99 9350.91 8771.88 6044904.74 550725.18 70 32 0.409 N 149 35 4.029 W I 149 40 w Feet 3,000 4,000 I 149 32 00 ~ --..j c (.,. I'V C C Z DATE I I CHECK NO. p055144 8/22/2003 055144 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 8/22/2003 INV# PR082003F PERMIT TO DRILL FEE H OCT 0 1 e ,.l.' rrxW'- l) --1 A_ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 NATIONAL·CITY BANK Ashland, Ohio 56"389 412 No. P 055144 CONSOLIDATED COMMERCIAL ACCOUNT TO THE ORDER OF: ALASKA OIL & GAS 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 B'P rrlu, 111II 11Ift . . .'.:) . Cu.) ':.11) ......, PAY: e AMOUNT AugÚst 22.2003 Iii **Ù***$1()O,OO******j NOT ';'~~;;T~:~~::~::;'~J7:,};~:/'\;~.k/::<::::::; ::",:, .\.::~:~~:~::;::::·:S:-:~:-;:~~::· j~:/,:;....: ::':i.:::\~.. ):~:~~)i(~:1<;~{~{:~;~:·~~t~ti 1110 5 5 L.... ....11· I: 0 ~ L· 2 0 ~ B 11 51: 0 L 2 7 B 11 b lIa .. · e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME //lß~ ¡;:--.s-7Þ! PTD# 203 ,- /,0 7 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wellbore segment of existing weD-, Permit No, API No. Production sbould continue to be reported as a function' of tbe original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot bole 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). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 Ojody\templates Tbe permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing . exception that may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals tbrough target zones. oT5 Geologic Commissioner: Date: ;0/6/:3 ~~~ CQnta,ct nam,elp/1one}or,weekly progre&s,rep.orts [exploratory ,only]. Public Commissioner Engineering Commissioner: Date _ t ~ ~~ ~---~ ....... Date Appr SFD 35 36 Date 37 10/2/2003 38 39 Pe(l1}it can be tssued wlo hydr:ogen_ s,ulfide rneasur:es ,Data_preseoted on pote_ntial oven¡re~sure ,zones ,Seisrn[c,analysJs_ of sbaJlow gas,zooes_ Seabedcondjtioo survey -(if off-shor:e) No .Yes NA NA NA 1-125 bas been, mea_sured aUevelsup to 23,5 ppm, io I<uparukproductioo wells Jrorn.F-Pad, Per:20,AAC25,Oß5 (b),H2S,measure~ are reJ:uired. _ Expected reservoir pressure is J 0.35 ppg EMW~ wilJ be driJIed with 1.1 - '11 .2 ppg mud,. Geology Appr Date , ~2I2003 21 22 23 24 25 26 27 28 29 30 31 32 33 34 1& pre~ence_ Qf H2S gas, prob_able Mecba_n[caLcoodJtton of wells within80B. verified (For,s,ervice we/! only) (pu.t PSig in,comrnenlsL Chokemanjfold compJies w/API.RF'-53 (May 84) Work will occ,ur without.operation,sbutdown ,BOPEs, ,do they meet reguJation _BOPEpress ra.ting appropriate; ,test to .If. diverter required, dQes it meet reguJations, ,Drilling fluid, program schernatic&, eq.uip Jist.adequatß C"T~ B_&_permafrost Adequate.tankage,or re_serve pit _ If a re-d(ilt bas, a, 1.0,4,03 fQr abandon_ment Adequate wellbore &eparationpropo&ed been apprQved Gasing designs adeQua.te fo( CMT. vol adequ,ate to ~e-tnJQng ,string to,sur:f c&g, ,CMT. will coyer ,all!<oolNJ1pro_ductiye borizon,s 18 19 20 ,Surface ,ca&ing_ prQtects_ all,known, USDWs ,CMT, vol. adequ,ate to circul<lte_on,conductor, & surf.csg .Yes NA .Yes No .Yßs .Yes .Yßs .Yes .Yes NA .Yes .Yes .Yes .Yes .Yes No, ,NA Mud &hOUld pr:eclude_ H2,S, on Jbe, rig, HJg is equJpped with, s_ensor~ and _alarm~. CalcuJa.ted, MA5P, 3355 P&i., Plann,ed BOP ,test press,ur:e 3,500 psi. Maximum BI-IP '10.6., Plann,ed mud weigbU'I .D -1 .2ppg. B.ig is_ e_quippe,d witb steel pits. , No reseJ\'epit plan oed 30_3-3D2 re_comrnendßd for approval, _ Pro~irni.t)l analysis perfo(mest Origioal wellbo(e,will be 7,OO'dislant at JD, W,eU(s), No other: wens proxirnate., All wa&te to Class In place, _sidetra_cl< of.existin.g,well. M aquifer& eJternpted 40 CfB. '147.1.02 ,(b)(3) I.n place, ,sidetra_cl< of.existin.g,We Engineering Appr e 101212003 Date It PTD#: 2031670 Administration Company BP EXPLORATION (ALASKA) Pe(mitfee attached _ , ' ,Leas,e,nurnber ,appropriate, _ Unique well n,ameand oumber 12 13 14 15 16 17 2 3 4 5 6 7 8 9 10 11 ACMP Fjndjng ,of Consistency has been J&sued, for tbis proiect. ,Cooductor stÖllg,prQv[ded AJI welJs,wit/1in,1l4_mile,area_of (eyiew identtfied (FOr: ~ervjce.well only) Pre-produced injector; duratio,nof pre-productioo less, than_ 3 mooths_ (For ,servi~ well Qnly) Pe(mit ,S,ufficien!.acreage,ayailable [n_drilJiog unit Jfdßviated, is, weJlbore plat incJu,ded Wen .located tnad,efioedpool WelUocated proper ,d [stan ce, from driJling uoitb,ound<lry, Well .IQcated properdtstance_ from. otber wells Field & Pool MILNE POINT, KUPARUK RIVER OIL affected party appropri.ate_ Qond in force tssued witbout conserva,tioo order Pß(mit c;: 10 be issu,ed witbout adsnioistr:ati\[e_approvaJ ,C_an permit Þe approved before J 5-day waJt. , _ Well .IQcated wtthill area and,strata authorized by_lojectiolJ Ordßr # (Put, can be 10#[n cornmeots), (For NC 525100 Initial ClasslType .Yes .Yes .Yes .Yes .Yes ,Yes .Yes .Yes .Yes .Yes Yes .Yes .Yes NA NA NA NA Sidetr:ack of ,existtng welJ CO 432B:Milne Poiot, Well Name: MILNE PT UNIT KR DEV I PEND GeoArea 890 KUP<lr:u!< ,River: OilPQol F-57A Unit 11328 Program DEV On/Off Shore On Well bore seg Annular Disposal o o e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ng Services LIS sca~ility . ()ð3~ I (Q1- $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 11 11:49:24 2004 '\ ,U¡ ~ \ )rJv Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .04/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPF-57A 500292274701 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 11-MAR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002760572 C.A. DEMOSKI C. DIXON MWD RUN 2 MW0002760572 R. FRENCH C. DIXON MWD RUN 3 MW0002760572 R. FRENCH E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002760572 T. MCGUIRE E. VAUGHN MWD RUN 5 MW0002760572 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 6 13N 10E 2052 2555 RECEIVED 45.85 12.10 r·; .I¡ R ~nO'4 ~ ,~, 0.- 1,;." . # WELL CASING RECORD OPEN HOLE CASING DRILLERS p,ïaska Oil & Gas Cons.Commmo ,AJìchorage ,~._~ ~,L1 ~ ¡", i",. r;--, Ii" ~~' /" :_~~' (j) (.¡'ç-..~' Lvu1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S~ (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 9340.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL (AN OPENHOLE SIDETRACK) EXITS THE MPF-57A PB1 WELLBORE AT 12518'MD/5670'TVD, WITHIN THE MWD RUN 3 INTERVAL. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND DRILL SUFFICIENT FORMATION TO BURY THE STABILIZERS FOR THE GEOPILOT BHA. THE TOP OF THE WHIPSTOCK WAS AT 9340'MD/4621'TVD AND THE BOTTOM WAS AT 9356'MD/4626'TVD, WITHIN THE MPF-57 WELLBORE. 5. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) i PRESSURE WHILE DRILLING (PWD); AND GEOPILOT ROTARY-STEERABLE BHA. UPHOLE TIE-IN SGRC DATA WERE ACQUIRED WHILE RIH FOR RUN 3. THESE MAD PASS DATA WERE MERGED WITH RUN 3 MWD DATA. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED l' UPHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 3 MARCH 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1 - 5 REPRESENT WELL MPF-57A WITH API#: 50-029-22747-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16285'MD/7743'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SHIFT-DERIVED RESISTIVITY ( SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record.~35 File Type...............W' Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 . and clipped curves; all bit runs merged. .5000 START DEPTH 8037.0 9319.0 9319.0 9319.0 9319.0 9319.0 9339.0 STOP DEPTH 16249.0 16241.5 16241.5 16241.5 16241.5 16241.5 16284.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8037.0 16284.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: GR 8038.0 16285.0 BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 9340.0 9372.5 8038.0 12518.0 15501.0 MERGE BASE 9372.0 9560.0 12518.0 15501.0 16285.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max First Reading Last Reading Mean Nsam DEPT FT 803. 16284 12160.5 16495 . 8037 16284 ROP MWD FT/H 3.75 995.65 196.917 13891 9339 16284 GR MWD API 24 196.95 99.9596 15194 8037 16249 RPX MWD OHMM 0.82 2000 3.65928 13846 9319 16241. 5 RPS MWD OHMM 0.91 2000 3.69784 13846 9319 16241.5 RPM MWD OHMM 0.89 2000 3.85393 13846 9319 16241. 5 RPD MWD OHMM 0.94 2000 6.27464 13846 9319 16241. 5 FET MWD HOUR 0.1233 46.5589 1.90499 13846 9319 16241. 5 First Reading For Entire File......... .8037 Last Reading For Entire File.......... .16284 File Trailer Service name............ .STSLIB.001 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 9340.0 STOP DEPTH 9372.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-NOV-03 Insite 4.3 Memory 9372.0 9340.0 9372 . 0 73.4 73.4 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (I~ DRILLER'S CASING DEPT~FT) : # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record.. .......... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 8.510 9340.0 LSND 9.80 60.0 10.0 80 7.8 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 9340 6.35 Max 9372 28.34 First Reading For Entire File......... .9340 Last Reading For Entire File.......... .9372 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF Mean 9356 13.5858 Nsam 65 65 . .0 .0 .0 .0 First Reading 9340 9340 Last Reading 9372 9372 File Header ... Service name........... .~SLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 9372.5 STOP DEPTH 9560.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 18-NOV-03 Insite 4.3 Memory 9560.0 9372.0 9560.0 72.0 74.9 TOOL NUMBER 8.500 9340.0 LSND 9.40 60.0 8.0 60 5.6 .000 .000 .000 .000 .0 98.7 .0 .0 Data Format Specification R~d Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 Name Service Unit DEPT FT ROP MWD020 FT/H Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Min 9372.5 19.09 Max 9560 542.91 Mean 9466.25 103.657 First Reading For Entire File......... .9372.5 Last Reading For Entire File.......... .9560 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD RPS RPX FET ROP $ 4 Nsam 376 376 . First Reading 9372.5 9372.5 Last Reading 9560 9560 header data for each bit run in separate files. 3 .5000 START DEPTH 8038.0 9320.0 9320.0 9320.0 9320.0 9320.0 9560.5 STOP DEPTH 12518.0 12518.0 12518.0 12518.0 12518.0 12518.0 12518.0 . # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record.. . . . . . . . . . . .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 20-NOV-03 Insite 66.37 Memory 12518.0 9560.0 12518.0 68.5 74.5 TOOL NUMBER 155789 56933 8.500 9340.0 LSND 9.40 54.0 8.0 70 5.3 1.300 .680 1.700 .540 65.0 129.8 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 FET MWD030 OHMM . HOUR 4 1 68 1 68 24 28 ~. First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8038 12518 10278 8961 8038 12518 ROP MWD030 FT/H 13.22 605.6 202.39 5916 9560.5 12518 GR MWD030 API 24 126.76 92.5697 7730 8038 12518 RPX MWD030 OHMM 0.82 2000 4.21102 6397 9320 12518 RPS MWD030 OHMM 1. 81 2000 4.29701 6397 9320 12518 RPM MWD030 OHMM 1. 88 2000 4.53578 6397 9320 12518 RPD MWD030 OHMM 1.8 2000 9.71256 6397 9320 12518 FET MWD030 HOUR 0.1308 46.5589 2.96108 6397 9320 12518 First Reading For Entire File......... .8038 Last Reading For Entire File.......... .12518 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 12466.0 12518.5 12518.5 12518.5 12518.5 12518.5 12518.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : STOP DEPTH 15467.0 15458.5 15459.0 15458.5 15458.5 15458.5 15501.0 22-NOV-03 Insite 66.37 Memory TD DRILLER (FT): . TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 15501.0 12518.0 15501.0 30.1 76.0 TOOL NUMBER 155789 145654 8.500 9340.0 LSND 11.00 44.0 8.0 80 3.0 1. 900 .900 2.600 2.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam . 68.0 151.0 68.0 68.0 First Reading Last Reading DEPT FT 1246. 15501 13983.5 6071 .12466 15501 ROP MWD040 FT/H 6.18 995.65 231.042 5966 2518.5 15501 GR MWD040 API 62.08 144.63 104.868 6003 12466 15467 RPX MWD040 OHMM 1. 56 7.62 3.28081 5881 12518.5 15458.5 RPS MWD040 OHMM 1. 48 8.17 3.301 5881 12518.5 15458.5 RPM MWD040 OHMM 1. 38 7.79 3.42218 5881 12518.5 15458.5 RPD MWD040 OHMM 1. 35 7.39 3.4903 5882 12518.5 15459 FET MWD040 HOUR 0.1233 38.5 0.493299 5881 12518.5 15458.5 First Reading For Entire File......... .12466 Last Reading For Entire File.......... .15501 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPX FET RPD GR ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 15459.0 15459.0 15459.0 15459.0 15459.5 15467.5 15501.5 STOP DEPTH 16242.5 16242.5 16242.5 16242.5 16242.5 16250.0 16285.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 24-NOV-03 Insite 66.37 Memory 16285.0 15501.0 16285.0 6.8 26.8 # BOTT' TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O . TOOL NUMBER 155789 145654 8.500 9340.0 LSND 10.90 52.0 8.0 80 4.0 2.400 1.080 3.000 1. 000 64.0 151.0 64.0 64.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15459 16285 15872 1653 15459 16285 ROP MWD050 FT/H 3.75 312.84 76.3886 1568 15501.5 16285 GR MWD050 API 39.27 196.95 117.975 1566 15467.5 16250 RPX MWD050 OHMM 0.94 66.52 2.8279 1568 15459 16242.5 RPS MWD050 OHMM 0.91 56.47 2.74175 1568 15459 16242.5 RPM MWD050 OHMM 0.89 43.54 2.69149 1568 15459 16242.5 RPD MWD050 OHMM 0.94 32.93 2.6914 1567 15459.5 16242.5 FET MWD050 HOUR 0.355. 37.8357 2.89118 1568 . 15459 16242.5 First Reading For Entire File......... .15459 Last Reading For Entire File.......... .16285 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type...... . . . . . . . . . .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .04/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... .,.... .LISTPE Date.................... .04/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Ð03- lç:::¡- Sperry-Sun Dr"'ng Services LIS sca~ility . J 1 <{~ ~ $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 11 09:34:17 2004 Reel Header Service name. . . . . . . . . . . . .LISTPE Date.................... .04/03/11 Origin.................. .STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date.................... .04/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPF-57APB1 500292274770 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 11-MAR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002760572 C.A. DEMOSKI C. DIXON MWD RUN 2 MW0002760572 R. FRENCH C. DIXON MWD RUN 3 MW0002760572 R. FRENCH E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 6 13N 10E 2052 2555 MSL 0) 45.85 12.10 RECEIVED # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 9340.0 .4 ("¡ Anti A ! (, ";IU" . ',j (,,- I.¡. Þ~a$k~ Oil 8: Gas Cons, Commission i"m:;.!1¡jrage # ~DMS RD -MAR 3 0 2004 REMARKS: 1. ALL DEPTH~RE MEASURED DEPTH (MD) UNLESS ~RWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND DRILL SUFFICIENT FORMATION TO BURY THE STABILIZERS FOR THE GEOPILOT BHA. THE TOP OF THE WHIPSTOCK WAS AT 9340'MD/4621'TVD AND THE BOTTOM WAS AT 9356'MD/4626'TVD. 4. MWD RUN 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ PRESSURE WHILE DRILLING (PWD) ¡ AND GEOPILOT ROTARY- STEERABLE BHA. UPHOLE TIE-IN SGRC DATA WERE ACQUIRED WHILE RIH FOR RUN 3. THESE MAD PASS DATA WERE MERGED WITH RUN 3 MWD DATA. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED l' UPHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 3 MARCH 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1 - 3 REPRESENT WELL MPF-57A PBl WITH API#: 50-029-22747-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13239'MD/5893'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SHIFT-DERIVED RESISTIVITY ( SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves¡ all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP $ START eH 8037.0 9319.0 9319.0 9319.0 9319.0 9319.0 9339.0 STOP DEPTH 13203.5 13195.5 13195.5 13195.5 13195.5 13195.5 13238.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8037.0 13238.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 8038.0 13239.0 BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 9340.0 9372.5 8038.0 MERGE BASE 9372.0 9560.0 13239.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 8037 6.35 24 0.82 1. 81 1. 88 1.8 0.1308 Max 13238 605.6 130.98 2000 2000 2000 2000 46.5589 Mean 10637.5 206.368 94.2805 4.08298 4.16151 4.38052 8.6692 2.58542 First Reading For Entire File......... .8037 Last Reading For Entire File.......... .13238 Nsam 10403 7799 9103 7754 7754 7754 7754 7754 First Reading 8037 9339 8037 9319 9319 9319 9319 9319 Last Reading 13238 13238 13203.5 13195.5 13195.5 13195.5 13195.5 13195.5 File Trailer ~ Service name............ ~LIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 9340.0 STOP DEPTH 9372 .0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 17-NOV-03 Insite 4.3 Memory 9372 . 0 9340.0 9372 .0 73.4 73.4 TOOL NUMBER 8.510 9340.0 LSND 9.80 60.0 10.0 80 7.8 .000 .000 .000 .0 .0 .0 MUD CAKE AT MT: . .000 . # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 9340 6.35 Max 9372 28.34 Mean 9356 13.5858 Nsam 65 65 First Reading 9340 9340 Last Reading 9372 9372 First Reading For Entire File......... .9340 Last Reading For Entire File.......... .9372 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type....... . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type...... . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 4IÞ DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 9372.5 $ STOP DEPTH 9560.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 4IÞ l8-NOV-03 Insite 4.3 Memory 9560.0 9372.0 9560.0 72.0 74.9 TOOL NUMBER 8.500 9340.0 LSND 9.40 60.0 8.0 60 5.6 .000 .000 .000 .000 .0 98.7 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H . 1 68 4 2 . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9372 .5 9560 9466.25 376 9372.5 9560 ROP MWD020 FT/H 19.09 542.91 103.657 376 9372.5 9560 First Reading For Entire File........ ..9372.5 Last Reading For Entire File.......... .9560 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 8038.0 9320.0 9320.0 9320.0 9320.0 9320.0 9560.5 STOP DEPTH 13204.5 13196.5 13196.5 13196.5 13196.5 13196.5 13239.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 20-NOV-03 Insite 66.37 Memory 13239.0 9560.0 13239.0 68.5 74.5 # BOTT. TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . TOOL NUMBER 155789 56933 8.500 9340.0 LSND 9.40 54.0 8.0 70 5.3 1.300 .680 1.700 .540 65.0 129.8 65.0 65.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8038 13239 10638.5 10403 8038 13239 ROP MWD030 FT/H 13.22 605.6 213.319 7358 9560.5 13239 GR MWD030 API 24 130.98 94.2805 9103 8038 13204.5 RPX MWD030 OHMM 0.82 2000 4.08298 7754 9320 13196.5 RPS MWD030 OHMM 1. 81 2000 4.16151 7754 9320 13196.5 RPM MWD030 OHMM 1. 88 2000 4.38052 7754 9320 13196.5 RPD MWD030 OHMM 1.8 2000 8.6692 7754 9320 13196.5 FET MWD030 HOUR 0.130. 46.5589 2.58542 7754 . 9320 13196.5 First Reading For Entire File......... .8038 Last Reading For Entire File.......... .13239 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation...... .04/03/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name....... . . . . . .LISTPE Date.................... .04/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... . . . . . . .LISTPE Date.................... .04/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.... . . . . . . .UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File