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198-247
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 Convert to Water Injector 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,860'N/A Casing Collapse Conductor 470psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT L-28A MILNE POINT KUPARUK RIVER OIL 7,323' 12,768' 7,237' 2,170 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 12/20/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388235 198-247 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22859-01-00 Hilcorp Alaska LLC C.O. 816 Length Size Proposed Pools: 112' 112' 6.5# / L-80 / EUE 8rd TVD Burst 12,337' MD 1,490psi 5,750psi 7,240psi 4,471' 7,316' 7,177' 12,852' 112' 20" 9-5/8" 7" 7,177' 12,852' Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" N/A and N/A N/A and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:32 pm, Nov 04, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.11.04 13:18:42 - 09'00' Taylor Wellman (2143) 324-63 Convert to Water Injector SFD 11/6/2024 SFDADL0025509, MGR25NOV24 10-404X X * BOPE pressure test to 2500 psi. * AOGCC to witness MIT-IA to 4000 psi after packer set. * AOGCC to witness MIT-IA to 2000 psi after 10 days of stabilized injection. 2,170 DSR-11/6/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.26 08:26:10 -09'00' 11/26/24 RBDMS JSB 112624 Convert to injector Well: MPL-28A PTD: 198-247 API:50-029-22859-01 Well Name:MPL-28A API Number:50-029-22859-01 Current Status:SI Failed ESP Rig:ASR 1 Estimated Start Date:12/20/2024 Estimated Duration:5 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:198-247 First Call Engineer:Ryan Lewis 303-906-5178 (M) Second Call Engineer:Taylor Wellman 907-947-9533 AFE Number: Current Bottom Hole Pressure: 2842 psi @ 6717’ TVD SBHP on 9/30/24 8.2 MWE 8.4KWF Max. Proposed Surface Pressure: 2170 psi Gas Column Gradient (0.1 psi/ft) Min ID:2.205” @ 12,257’ XN Nipple Max Inc: 78 o @ 6250’ MD Brief Well Summary The Milne Point L-28A well was redrilled as a Kuparuk development well that TD’d at a depth of 12,769’ and ran and cemented 7” production casing in January 1999. The well was perforated and Frac’d in the Kuparuk A sands and initially completed with an ESP. ESP pull and replacements were performed in December 1999, 2000, 2002, 2005, 2007, and 2008, with last ESP failure in December 2014. The well was last worked over in 2016 with an ESP completion. 12/6/23 the ESP tripped, after trying to restart it several times it was grounded and unbalanced. Hilcorp would like to convert it to a water injection well. Notes Regarding Wellbore Condition 7’’ Casing tested 2/17/2015 to 1700 psi Objective x Pull ESP replace with an injection string Sundried work: Well Support- 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 3. Pressure test lines to 3,000 psi. 4. Circulate at least one wellbore volume with source/produced water down tubing, taking returns up casing to 500 bbl returns tank. a. Returns will likely not be seen. After attempting circulation down the tubing, bullhead and load the tubing and IA. 5. RD Little Red Services and reverse out skid. 6. RU crane. Set CTS BPV. ND Tree. NU BOPE. RD Crane. 7. NU BOPE house. Spot mud boat. Brief RWO Procedure: 8. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 9. Check for pressure and if 0 psi. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ source/produced water prior to setting CTS Plug. Set CTS Plug. 10. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure pp , y g convert it to a water injection well Convert to injector Well: MPL-28A PTD: 198-247 API:50-029-22859-01 b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8’’ and 3-1/2’’ test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (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. 12. Bleed any pressure off casing to the returns tank. Pull CTS, lubricate if pressure expected. Kill well as needed. 13. MU landing joint or spear and BOLDS. 14. Attempt to pull tubing. a. 2015 RWO Nabors 3S PUW= 80k and SOW=40k b. 2-7/8” L-80 EUE yield is 144 kip. c. RU spooler for ESP Cable and dual cap string. 15. 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. 16. POOH and lay down the 2-7/8’’ tubing and 3/8” cap string. a. Tubing will be wash and tossed. b. Ensure all clamps are recovered 2015 RWO noted c. Total clamps= i. 205 Cross Collar Clamps ii. 1 Motor clamp iii. 5 Pump clamps 17)Contingency: If the ESP comes out comes out clean proceed to run Injector completion. If it come out with scale then, MU 7” casing scraper and TIH w/ 3-1/2” workstring to ±12,300’ MD . 18) POOH and reciprocate the 7” scraper across the following interval. a. 12,300’-12,200’ MD 19) POOH and LD scraper. 20) PU new 3-1/2’’ injection completion. 21) The tubing will be plugged with the IMAG in both directions. Fill the tubing every10 joints on the way in. Convert to injector Well: MPL-28A PTD: 198-247 API:50-029-22859-01 Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Connection Notes WLEG L-80 EUE ~12,390’ MD 3.5'' 30’ 1 joint 9.3 L-80 EUE 3.5''10'Pup Joint 9.3 L-80 EUE 3.5''IMAG Burst Disc 9.3 L-80 EUE 3.5''10'Pup Joint 9.3 L-80 EUE 3.5'' 30’ 1 joint 9.3 L-80 EUE 3.5''10'Pup Joint 9.3 L-80 EUE 3.5''XN Nipple 2.813" No-Go 2.666”9.3 L-80 EUE 3.5''10'Pup Joint 9.3 L-80 EUE 3.5'' 30’Joints 9.3 L-80 EUE 3.5''10'Pup Joint 9.3 L-80 EUE 3.5'' 7'' Baker premier Packer Set ~12,250' MD 9.3 L-80 JFE BEAR 3.5''10' Pup Joint 9.3 L-80 JFE BEAR 3.5'' 10,200’ 1 joint 9.3 L-80 JFE BEAR 3.5''10'Pup Joint 9.3 L-80 JFE BEAR 3.5''X Nipple 2.813"9.3 L-80 JFE BEAR 3.5''10'Pup Joint 9.3 L-80 JFE BEAR 3.5'' 2,000’Joints 9.3 L-80 JFE BEAR 3.5''Tubing Hanger 9.3 L-80 22) Space out and land the hanger. 1. Note PU (Pick Up) and SO (Slack Off) weights on tally. 2. During space out do not forget to maintain constant hole fill 23) RILDS. Lay down landing joint. 24) Bullhead 275 bbls Corrosion inhibited fluid down the IA followed by 53 bbls of diesel. 25) Load the tubing with source/produced water and hydraulically set the packer as per Vendor’s setting procedure. 26) Pressure up and test the tubing to 4000 psi for MIT-T. Bleed off the tubing to 0 psi. Test the IA to 4000 psi for MIT-IA. a. Notify AOGCC 24 hours in advance of MIT-IA test. 27) Pressure up the tubing to 5,000 psi to burst the discs top and bottom. Record and notate all pressure tests (30 minutes) on chart. 28) Set CTS BPV. 29) RDMO ASR. Convert to injector Well: MPL-28A PTD: 198-247 API:50-029-22859-01 Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. 5. Pull CTS. 6. RD crane. Move 500 bbl returns tank and rig mats to next well location. 7. Replace gauge(s) if removed. 8. Turn well over to injection. Attachments: 1. Well Schematic Current 2. Well schematic Proposed 3. Double BOP Drawing 4. AOR * AOGCC to witness MIT-IA to 2000 psi after 10 days of stabilized injection. _____________________________________________________________________________________ Created By: TDF 3/3/2015 SCHEMATIC Milne Point Unit Well: MPU L-28A Last Completed: 2/18/2015 PTD: 198-247 TD = 12,860’ (MD) / TD = 7,323’(TVD) 20” Orig. KB Elev.: 33’/ GL Elev.: 16.9’ 7” 3 6 7 8 9 9 9-5/8” 1 2 KUP A3Sands PBTD = 12,769’ (MD) / PBTD = 7,237’(TVD) 5 9-5/8” HOWCO ‘ES’ Cementer @ 2,035’ KUP A2 Sands 4 KUP A1 Sands 3/8” SS Capstring CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 7,177’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,852’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surf 12,337’ 3/8” Capstring Stainless Steel N/A N/A 12,337’ JEWELRY DETAIL No Depth Item 1 137’ GLM 2 442’ GLM 3 12,083’ GLM 4 12,257’ XN-Nipple 5 12,267’ Discharge Head 6 12,268’ Tandem Pumps 7 12,292’ Gas Separator 8 12,297’ Tandem Seal Section 9 12,311’ Motor 10 12,333’ PumpMate w/ 6 Fin Centralizer Bottom @ 12,337’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A3 Sands 12,436’ 12,456’ 6,924’ 6,943’ 20 6/19/2005 Open Kup. A2 Sands 12,458’ 12,478’ 6,945’ 6,964’ 20 2/2/1999 Open Kup. A1 Sands 12,484’ 12,514 6,969’ 6,997’ 20 6/19/2005 Open OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 500 sx PF “E”, 900 sx Class “G”, 1,300 sx PF E, 300 sx C in 12-1/4” Hole 7” 250 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1,000’ Angle passes 50 deg. @ 3,600’= 48.8 deg. @ 9,282’ Max Hole Angle = 78 deg. @ 6,250’ Max Hole Angle through perforations = 21 deg. TREE & WELLHEAD Tree 5M FMC 2-9/16” Wellhead 11” 5M FMC Gen 5A, w/ FMC Tbg. Hngr., 2-7/8” EU Threads T&B, 2-1/2” CIW “h” BPV profile GENERAL WELL INFO API: 50-029-22859-01-00 Drilled and Cased by Nabors 27E - 5/22/1998 Wellbore Sidetracked by Nabors 27E – 1/10/1999 Perf & Completion w/ De-sander by Nabors 4-ES – 2/25/1999 RWO by Nabors 4ES – 12/13/1999 RWO by Nabors 4ES – 11/5/2000 Add Perfs & ESP Re-run w/ Nabors 4-ES – 6/20/2005 RWO / Add SPM by Nabors 3S – 4/28/2007 ESP Replacement / TD Tag by Nabors 3S – 2/6/2008 ESP Changeout w/ Nordic #3 – 2/18/2015 STIMULATION SUMMARY Kuparuk “A” Sand: 45,226# of 16/20 AEA Chemflow inhibitor impregnated proppant + 135,213# of 16/20 carbolite _____________________________________________________________________________________ Revised By: TDF 10/24/2024 PROPOSED Milne Point Unit Well: MPU L-28A Last Completed: 2/18/2015 PTD: 198-247 TD =12,860’ (MD) / TD = 7,323’(TVD) 20” Orig. KB Elev.: 33’/ GL Elev.: 16.9’ 7” 4 9-5/8” 2 3 KUP A3 Sands PBTD =12,769’ (MD) / PBTD = 7,237’(TVD) 5 9-5/8” HOWCO ‘ES’ Cementer @ 2,035’ KUP A2 Sands 1 KUP A1 Sands CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 7,177’ 7" Production 26 / L-80 / Hydril 563 6.151 Surface 12,852’ TUBING DETAIL 3-1/2”" Tubing 9.3 / L-80 / JFE Bear 2.347 Surf ±XX,XXX’ JEWELRY DETAIL No Depth Item 1 ±X,XXX’ 3-1/2” X-Nipple 2 ±12,250’ 7'' Baker premier Packer Set 3 ±XX,XXX’ 3-1/2” XN-Nipple 4 ±XX,XXX’ IMAG Burst Disk 5 ±XX,XXX’ WLEG – Btm @ ±12,340’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A3 Sands 12,436’ 12,456’ 6,924’ 6,943’ 20 6/19/2005 Open Kup. A2 Sands 12,458’ 12,478’ 6,945’ 6,964’ 20 2/2/1999 Open Kup. A1 Sands 12,484’ 12,514 6,969’ 6,997’ 20 6/19/2005 Open OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 500 sx PF “E”, 900 sx Class “G”, 1,300 sx PF E, 300 sx C in 12-1/4” Hole 7” 250 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1,000’ Angle passes 50 deg. @ 3,600’= 48.8 deg. @ 9,282’ Max Hole Angle = 78 deg. @ 6,250’ Max Hole Angle through perforations = 21 deg. TREE & WELLHEAD Tree 5M FMC 2-9/16” Wellhead 11” 5M FMC Gen 5A, w/ FMC Tbg. Hngr., 2-7/8” EU Threads T&B, 2-1/2” CIW “h” BPV profile GENERAL WELL INFO API: 50-029-22859-01-00 Drilled and Cased by Nabors 27E - 5/22/1998 Wellbore Sidetracked by Nabors 27E – 1/10/1999 Perf & Completion w/ De-sander by Nabors 4-ES – 2/25/1999 RWO by Nabors 4ES – 12/13/1999 RWO by Nabors 4ES – 11/5/2000 Add Perfs & ESP Re-run w/ Nabors 4-ES – 6/20/2005 RWO / Add SPM by Nabors 3S – 4/28/2007 ESP Replacement / TD Tag by Nabors 3S – 2/6/2008 ESP Changeout w/ Nordic #3 – 2/18/2015 STIMULATION SUMMARY Kuparuk “A” Sand: 45,226# of 16/20 AEA Chemflow inhibitor impregnated proppant + 135,213# of 16/20 carbolite TOC est 10,723' MD w/ 30% washout Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR bĺϙſôīīæĺŘôŜĺŕôIJϙĖIJϙťēôXŪŕÍŘŪħϙŕĺĺīſĖťēĖIJϙήϙıĖīôĺċϙ[ϱ͑͗Agree. SFD STATE OF ALASKA AL __.(A OIL AND GAS CONSERVATION COML__AON ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well LJ Plug Perforations U Perforate U Other U ESP Changeout Performed: Alter Casing ❑ Pull Tubing Q Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development LI Exploratory ❑ 198-247 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22859-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0388235 MILNE PT UNIT KR L-28A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): V N/A Milne Pont Field/K1aparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,860 feet Plugs measured N/A RECEIVED true vertical 7,323 feet Junk measured N/A feet MAR 0 3 2015 Effective Depth measured 12,768 feet Packer measured N/A feet A��� true vertical 7,237 feet true vertical N/A feet AO GCC Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 7,177' 9-5/8" 7,177' 4,471' 5,750psi 3,090psi Intermediate Production 12,852' 7" 12,852' 7,316' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic SCANNED True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 12,337'(MD) 6,832'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 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: 270 81 975 280 228 Subsequent to operation: 407 54 1,503 140 223 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-068 Contact Chris Kanyer Email ckanverahilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature (s .44,,,,,, Phone 907-777-8377 Date 3/3/2015 .114 RBDMS'' MAR - 5 2015 Form 10-404 Revised 10/2012 /7.4.-- Submit Original Only Milne Point Unit Well: MPU L-28A SCHEMATIC Last Completed: 2/18/2015 Uncoil)Alaska,LLC PTD: 198-247 CASING DETAIL Orig.KB Elev.:33'/GL Elev.:16.9' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' • 9-5/8" Surface 40/L-80/Btc. 8.679 Surface 7,177' 20 7" Production 26/L-80/Hydril 563 6.151 Surface 12,852' TUBING DETAIL , 1 , 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 12,337' 3/8" Capstring Stainless Steel N/A N/A 12,337' JEWELRY DETAIL . 2 No Depth Item 1 137' GLM 2 442' GLM 312,083' GLM 4 12,257' XN-Nipple ' 5 12,267' Discharge Head gyg• 6 12,268' Tandem Pumps HMCO'ES' 7 12,292' Gas Separator Cemsnter@ 8 12,297 Tandem Seal Section 2035 9 12,311' Motor 10 12,333' PumpMate w/6 Fin Centralizer Bottom @ 12,337' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 9-5/8" Kup.A3 Sands 12,436' 12,456' 6,924' 6,943' 20 6/19/2005 Open Kup.A2 Sands _ _12,458' 12,478' 6,945' 6,964' 20 2/2/1999 Open Kup.Al Sands 12,484' 12,514 6,969' 6,997' 20 6/19/2005 Open 3/8"ssCapstring WELL INCLINATION DETAIL `, ,‘,k. KOP @ 1,000' Angle passes 50 deg.@ 3,600'=48.8 deg. @ 9,282' Max Hole Angle=78 deg.@ 6,250' Max Hole Angle through perforations=21 deg. 3 STIMULATION SUMMARY il Kuparuk"A"Sand: 45,226#of 16/20 AEA Chemflow inhibitor ' impregnated proppant+135,213#of 16/20 carbolite a OPEN HOLE/CEMENT DETAIL .5 20" 250 sx of Arcticset I(Approx)in 24"Hole 9-5/8" 500 sx PF"E",900 sx Class"G",1,300 sx PF E,300 sx C in 12-1/4"Hole I:1:1: ,•6 7" 250 sks Class"G"in 8-1/2"Hole 7 TREE &WELLHEAD - Tree 5M FMC 2-9/16" Wellhead 11"5M FMC Gen 5A,w/FMC Tbg.Hngr.,2-7/8"EU Threads T&B, ;.8 2-1/2"CIW"h"BPV profile GENERAL WELL INFO • III 9 ' API:50-029-22859-01-00 ' Drilled and Cased by Nabors 27E -5/22/1998 Wellbore Sidetracked by Nabors 27E-1/10/1999 Perf &Completion w/De-sander by Nabors 4-ES-2/25/1999 ,r ,KUPA3 Sands RWO by Nabors 4ES-12/13/1999 � RWO by Nabors 4ES-11/5/2000 }KUPA2 Sands Add Perfs&ESP Re-run w/Nabors 4-ES-6/20/2005 s }KUPA1 Sands RWO/Add SPM by Nabors 3S-4/28/2007 ESP Replacement/TD Tag by Nabors 3S-2/6/2008 7" ..ai , ESP Changeout w/Nordic#3-2/18/2015 TD=12,860'(MD)/ID=7,323'(TVD) PBTD=12,769'(MD)/PBTD=7,237'(TVD) Created By:TDF 3/3/2015 Hilcorp Alaska, LLC ;,,,,Vk,,,,,,,,: Weekly Operations Summary Well Name API Number •Well Permit Number Start Date _End Date MPL-28A 50-029-22859-01-00 198-247 2/13/2015 2/18/2015 Daily Operations: 2/11/15-Wednesday No operations to report. 2/12/15-Thursday No operations to report. 2/13/15-Friday MIRU.Continue RU,Offload 580 bbls 8.5 seawater. 140 degree heated,hook up kill tank. Remove BPV, BOPE witnes waived @ 17:00 hour by AOGCC's Lou Grimaldi.Well control drill,spot ESP spooler and mats. PJSM pressure test and purge all Lines 250psi low/2,000 psi high. SITP 680 psi.SICP 680 psi.Blow down tubing and annulus to<30 psi no fluid during vent. Line up and pump 75 bbl heated 8.5#seawater down tubing 400-650 psi. No returns, swap over and pump down annulus 390 bbl @ 140-920psi @ 4bpm No returns,monitor well, light vacuum then static. No flow, Instal BPV.Total fluid pumped 465 bbl. ND tree,offload 290 bbls 8.5#seawater, NU 13-5/8"5M BOPE, Pull BPV Install TWC RU for BOP Test.Shell Testing Change leaking Grayloc 2/14/15-Saturday PJSM,continue shell test replace bad Gralocs tighten all loose connections. BOPE test all rams,flanges,and valves 250psi low/3,000psi high.Annular 250psi low/2,500psi high.Accumulator draw down test OK. LD rest mandrel, remover TWC well on slight vacuum, backout all lockdown pins, Install landing joint. Pull to 130K string moving at 115K w easy 10K drag. Pull to hanger, remove penetrators and ESP cable,cable head assy is shorted and flooded. Motor harness test 1 leg shorted. Hanger was damaged when originally landed seal was cut and frayed with blow by,explains gas in void. Hanger will be redressed and reused. BO/LD hanger,2'and 10'2-7/8" pups, pull two stands pulling 3rd stand connect ESP cable to spooler. Lasalle clamps are corroded and difficult to remove pins. POOH to GLM 1 BO/LD, POOH to GLM#2 BO/LD, POOH to jt 103,fight connection was cross threaded. Replace collar on 1T 104 will LD JT 103 in way in hole next trip. Pump tubing volume to clear gas,continue POOH to GLM#3 BO/LD, POOH LD single and 10'. BO/LD pump assy,On load 8 jts 2-7/8"pipe to achieve Scraper depth and 52 jts caliper identified replacements. Remaining pipe visual inspection appears OK. 2/15/15-Sunday PJSM,finsih BO/LD motor assy,clean rig floor,PU/MU muleshoe,scraper,x-over,5'pup, RIH to it 103 and swap out same,crossed threads from original completion.Well control trip drill response time to SI 42 seconds.Continue RIH scraper @ 12,350'Mixing sized salt pill,recipe for 25bbls 55sx NaCI(fluid density at this stage was 12.4)2 sx polymer,2 sx fluid loss,followed with additional 38 sx NaCI. Rig up hardline and pump 21 bbl pill est ppg 15 heavy(cannot weigh in balance or pressure balance to volumetric.) Difficult pumping through surface lines once in the hole 1 BPM @ 50 psi pump 72 bbls displacement @ 400 psi.After 56 bbls displacement gas to surface all floor alarms work,continue displacement crude oil to surface approx 10 bbls recovered.Oil is observed at surface and fluid level dropping. Monitor well and mix new SSS pill.Rig up to pump oil displacement to kill tank.POOH stand back 5 stands depth of scraper MS 11,880'finish mixing sized salt pill blow down hardline to kill tank.Pumping 25 bbl SSS pill 1 BPM 50-0 psi pump displacement 3 BPM 470 psi gain returns(oil and water mix gassy)after 11 bbls pump additional 56 bbls to clear pipe. Observe well 30 min,.After 15 minutes took 16+ bbls to fill annulus 15 minute time on losses 1.5 bpm. Losses increasing.Annulus gassy. Build sized salt pill 25 bbl pill. Build 8.5 brine volume 65 bbls w/boiler water.Vac off 118 bbl oil water mix returns and send to MPU. Pumping 25 bbl SSS pill 1 BPM 50-0 psi pump displacement 3 BPM 450 psi gain returns oil/water gassy after 10 bbls pump additional 57 bbls to clear pipe.Observe well on trip tank well taking 1.5 bpm. Rig down circulation iron,purge all lines prepare RIH w/scraper to 12,340'.POOH Laying down bad singles Identified with 30%wall loss on PDS pre rig caliper run. 2/16/15-Monday No operations to report. 2/17/15-Tuesday No operations to report. Hilcorp Alaska, LLC ,i;,,,,,,, Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPL-28A 50-029-22859-01-00 198-247 2/13/2015 2/18/2015 Daily Operations: 2/18/15-Wednesday PJSM.Continue RIH with 2-7/8" ESP completion to 11,000'.Change capillary reel in spooling unit and splice in remaining cap.Test cable and cap string.Cycle on cap check is 4,300 psi.Continue to RIH.Cable check and install hanger.Connect cap string test same. Connect ESP cable check good. Land tbg hanger.SW is 112 Up 70 K down. BHA depths as follows: pump centralizer 12,334', motor 12,311',gas separator 12,293', discharge head 12,267',XN 12,257', GLM 12,083',GLM 442',GLM 137'. RI lock down screws. Install BPV. ND BOP ND Tree. Remove BPV, install 2 way check. Test tree 250psi low/5,000psi high.Test void to 5,000 psi.All good.Jack up rig on move rate.Well turned over to production.Total Losses on well including sized salt pills 1,085 bbl 8.5 seawater. 2/19/15-Thursday No operations to report. 2/20/15-Friday No operations to report. 2/21/15-Saturday No operations to report. 2/22/15-Sunday No operations to report. 2/23/15-Monday No operations to report. 2/24/15-Tuesday No operations to report. OF yw\� I�j,�s THE STATE Alaska Oil and Gas frt.> , of Conservation Commission _ ALASIc:A _�y 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 04t, �Tti• Main: 907.279.1433 ALAS)P+ Fax• 907.276.7542 www.aogcc.alaska.gov Chris Kanyer SCANNED I- 0 1i1;� Operations Engineer c� Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 �, Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU L-28A Sundry Number: 315-068 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this )2 day of February, 2015 Encl. LIVED • STATE OF ALASKA FEB 0 9 2015 • ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGDC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend 0 Plug Perforations ❑ Perforate E Pull Tubing Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ESP Change-out ❑] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC - Exploratory ❑ Development ❑✓ • 198-247 3.Address: Stratigraphic 0 Service El6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22859-01-00 • 7.If perforating: y��+'►0 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 1T3 Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT KR L-28A' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0388235 ' Milne Pont Field/lc(paruk River Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,860• 7,323' . 12,769' 7,237' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 7,177' 9-5/8" 7,177' 4,471' 5,750psi 3,090psi Intermediate Production 12,852' 7" 12,852' 7,316' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 12,382' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal Q . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/12/2015 Oil Q• Gas 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer(cilhilcorp.com Printed Name ChrisX7/ Kanyer Title Operations Engineer Signature a Phone 777-8377 Date 2/9/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: --St 5 — Oc:10Ctr Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance 0 Other: at 3Ced ,pSi i3oP 7 t' ( /t L P ' z d`GM,/- ) Spacing Exception Required? Yes 0 No Er Subsequent Form Required: /0—d/041 APPROVED BY / I Approved by: r COMMISSIONER THE COMMISSION Date: Z 2 1,5 d.//•7S /'� 1 1'�CLS �'t���S /�.+�p�--�5 Submd Form and Form 10-403(Re sed 10/2012) gplrll IlettiAdifor 12 months from the date of approval. Attachment i Duplicate v , ` L. ,,A.07144.50". RBDMS FEB 1 3 2015 • Well Prognosis • Well: MPL-28A Iiileorp Alaska.LL Date:2/9/2015 Well Name: MPL-28A API Number: 50-029-22859-01-00 Current Status: SI Producer Pad: L Pad Estimated Start Date: February 12, 2015 Rig: Nordic 3 Reg.Approval Req'd? February 12, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-247 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 1520161 Current Bottom Hole Pressure: — 1,928 psi @ 7,000' ND (Last BHP measured 1/11/2015) Maximum Expected BHP: y 3,500 psi @ 7,000' ND (Assume virgin pressure gradient of 0.5psi/ft for added perfs: Kuparuk C sands) Max.Allowable Surface Pressure: 860 psi (Based on actual reservoir conditions and water cut of 50% (0.385psi/ft) (currently WC 89%)with an added safety factor of 1000' ND of oil cap) Brief Well Summary: 3S The Milne Point L-28A well was redrilled as a Kuparuk development well that TD'd at a depth of 12,769'and ran and cemented 7" production casing in January 1999.The well was perforated and Frac'd in the Kuparuk A sands and initially completed with an ESP. ESP pull and replacements were performed in December 1999, 2000, 2002, 2005, 2007, and 2008, with last ESP failure in December 2014. The well has remained shut in ever since. The last 7" casing pressure test was performed in January 1999. le- A downhole chemical injection line will be run as part of the new completion, but no scaling issues suspected in this well. No subsidence issues are expected in this well. A tubing caliper has been run on 2/2/2015 as part of the rig prep of this well and did not indicate any issues. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: Pull ESP, add perforations in Kuparuk C sands, & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg brine. Monitor well. 3. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi low/3,9215i high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Unseat hanger and pull 2-7/8" ESP completion from 12,382'to surface and lay down same. 5. RIH with 7" cleanout BHA to+/-12,400'. POOH with same. 6. RIH with 7" packer and TCP gun assembly to+1-12,400'. ' 7. RU Eline, correlate TCP guns on depth, POOH with Eline. • . 14 • Well Prognosis Well: MPL-28A Ililcorp Alaska,LL Date:2/9/2015 8. Set packer at+/-12,000' (within 500ft of open perforations). ., 9. Pressure test and chart casing annulus to 1.500psi for 30min. Bleed off pressure. iv,1 10. Perforate Kuparuk C sands from+/-12,380' to+/-12,398'. 11. Monitor well. Bullhead +/-9.6ppg brine to kill well. 12. Monitor well, unseat packer, circulate well over to+/-9.6ppg brine to kill well. 13. Monitor well, POOH with packer&TCP gun assembly and LD same. 14. MU and RIH with ESP with gas separator and 3/8"chemical injection line on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-12,330'. Land tubing hanger. 15. ND BOP, NU and tree. 16. RDMO workover rig and equipment. 17. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit II WelL SCHEMATIC Lastl:CompletedMPU28A: 2/6/2008 Hacorp Alaska,LLC PTD: 198-247 CASING DETAIL Orig.KB Elev.:33'/GL Elev.:16.9' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' j .. 20" 9-5/8" Surface 40/L-80/Btc. 8.679 Surface 7,177' 7" Production 26/L-80/Hydril 563 6.151 Surface 12,852' ... II, . TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 12,382' ;• JEWELRY DETAIL 1 2 No Depth Item �J 1 138' Camco 2-7/8"x 1"Sidepocket KBMM GLM :,.. 2 444' Camco 2-7/8"x 1"Sidepocket KBMM GLM %.' 3 12,139' Camco 2-7/8"x 1"Sidepocket KBMG-M-2 GLM 4 12,281' 2-7/8"XN-Nipple(2.205 No-go ID) 5 12,300' Discharge Head 6 12,301' Tripple Tandem Pumps SXD 074P31/074P31/18P75 F-OA 7 12,337' Gas Separator GRSFTXAR FIOV\CO'ES' Cernanter 8 12,341' Tandem Seal Section 2, '� 9 12,355' Motor,266HP,3545 Volt,69 amp,Model KMH 10 12,378' PumpMate XTO w/6 Fin Centralizer 6,870'ND/Bot.12,382' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 9-5/8,'4 4 Kup.A3 Sands 12,436' 12,456' 6,924' 6,943' 20 6/19/2005 Open Kup.A2 Sands 12,458' 12,478' 6,945' 6,964' 20 2/2/1999 Open Kup.Al Sands 12,484' 12,514 6,969' 6,997' 20 6/19/2005 Open WELL INCLINATION DETAIL KOP @ 1,000' Angle passes 50 deg.@ 3,600'=48.8 deg. @ 9,282' Max Hole Angle=78 deg.@ 6,250' Max Hole Angle through perforations=21 deg. STIMULATION SUMMARY s Kuparuk"A"Sand: 45,226#of 16/20 AEA Chemflow inhibitor impregnated proppant+135,213#of 16/20 carbolite OPEN HOLE/CEMENT DETAIL 4 20" 250 sx of Arcticset I(Approx)in 24"Hole e.' L • 9-5/8' 500 sx PF"E",900 sx Class"G",1,300 sx PF E,300 sx C in 12-1/4"Hole '• 7" 250 sks Class"G"in 8-1/2"Hole ' 1 I 5 ;. TREE&WELLHEAD 6 Tree 5M FMC 2-9/16" 11"5M FMC Gen 5A,w/FMC Tbg.Hngr.,2-7/8"EU Threads T&B, 1. 1111 7 Wellhead 2-1/2"CIW"h"BPV profile 11:' `'s GENERAL WELL INFO API:50-029-22859-01-00 r' 9 Drilled and Cased by Nabors 27E -5/22/1998 Wellbore Sidetracked by Nabors 27E-1/10/1999 L,' Perf &Completion w/De-sander by Nabors 4-E5-2/25/1999 . 10 RWO by Nabors 4E5-12/13/1999 kl KIP A3Sands RWObyNabors4ES-11/5/2000 Add Pers&ESP Re-run w/Nabors 4-ES-6/20/2005 t` }KUPA2 Sands RWO/Add SPM by Nabors 3S-4/28/2007 II _J KLPA1 Saids ESP Replacement/TD Tag by Nabors 3S-2/6/2008 7"a I' 1D=12,860'(MD)/TD=7,323'(TVD) PBTD=12,769'(MD)/PBTD=7,237'(TVD) Created By:TDF 1/13/2015 • Milne Point Unit II Well: MPUL-28A PROPOSED Last Completed: 2/6/2008 Hileorp Alaska,LEA: PTD: 198-247 CASING DETAIL Orig.KB Elev.:33'/GL Elev.:16.9' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 9-5/8" Surface 40/L-80/Btc. 8.679 Surface 7,177' 20' 7" Production 26/L-80/Hydril 563 6.151 Surface 12,852' TUBING DETAIL 1 ,r 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf ±12,330' / 3/8" Capstring Stainless Steel N/A N/A ±12,330' ✓ JEWELRY DETAIL •1 2 No Depth Item 1 ±140' GLM 2 ±440' GLM < 3 ±12,090' GLM • 4 ±12,250' Discharge Head 5 ±12,251' Tandem Pumps gyg^ 6 ±12,290' Gas Separator HMCO'ES 7 ±12,291' Tandem Sealscharge Ceme •• 8 ±12,305' Motor 2,035 9 ±12,330' PumpMate w/6 Fin Centralizer Bottom @±12,330' PERFORATION DETAIL • Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ' Kup.C Sands ±12,380' ±12,398' ±6,872' ±6,889' ±18 Future Future 9-5/8"'4 6 Kup.A3 Sands 12,436' 12,456' 6,924' 6,943' 20 6/19/2005 Open Kup.A2 Sands 12,458' 12,478' 6,945' 6,964' 20 2/2/1999 Open Kup.Al Sands 12,484' 12,514 6,969' 6,997' 20 6/19/2005 Open WELL INCLINATION DETAIL 3/8"SSCapstring _KOP @ 1,000' _Angle passes 50 deg.@ 3,600'=48.8 deg. @ 9,282' Max Hole Angle=78 deg.@ 6,250' Max Hole Angle through perforations=21 deg. STIMULATION SUMMARY 3 Kuparuk"A"Sand: 45,226#of 16/20 AEA Chemflow inhibitor impregnated proppant+135,213#of 16/20 carbolite OPEN HOLE/CEMENT DETAIL 4 20" 250 sx of Arcticset I(Approx)in 24"Hole 9-5/8" 500 sx PF"E",900 sx Class"G",1,300 sx PF E,300 sx C in 12-1/4"Hole 5 7" 250 sks Class"G"in 8-1/2"Hole 88. •6 TREE&WELLHEAD 7 Tree 5M FMC 2-9/16" Wellhead 11"5M FMC Gen 5A,w/FMC Tbg.Hngr.,2-7/8"EU Threads T&B, 2-1/2"CIW"h"BPV profile ti ' 8 GENERAL WELL INFO API:50-029-22859-01-00 II 9 Drilled and Cased by Nabors 27E -5/22/1998 Wellbore Sidetracked by Nabors 27E-1/10/1999 Perf &Completion w/De-sander by Nabors 4-ES-2/25/1999 KUP C Sands Y RWO by Nabors 4ES-12/13/1999 RWO by Nabors 4ES-11/5/2000 KIP A3 Sands Add Perfs&ESP Re-run w/Nabors 4-ES-6/20/2005 fil KUP A2 Sands RWO/Add SPM by Nabors 3S-4/28/2007 }KLPA1 Sands ESP Replacement/TD Tag by Nabors 35-2/6/2008 7" TD=12,860'(MD)/TD=7,323'(TVD) PBTD=12,769'(MD)/PBTD=7,237(TVD) Created By:TDF 2/9/2015 MPU BOP Stack v v , iii i ii Hydril 13 5/8 5M 13 5/8 5M u 2 7/8"-5-%2" variables CUP OW OOP 111P 11011j Spacer spool 13 5/8 5M 13 5/8 5M j _ Blinds ■ 6 11-1 "GA, 1p I c 1,4 • ■ Spacer spool 13 5/8 5M iii DSA Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, February 11, 2015 9:26 AM To: 'Chris Kanyer' Cc: Tom Fouts Subject: RE: Rush: MPL-28A 10-403 API#50-029-22859-01-00 PTD#198-247 Chris, Thanks.. looking at MPL-28A today. Guy Schwartz Senior 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(Guy.schwartz@alaska.gov), From: Chris Kanyer [mailto:ckanyer hilcorp.com] Sent: Wednesday, February 11, 2015 9:16 AM To: Schwartz, Guy L (DOA) Cc: Tom Fouts Subject: Rush: MPL-28A 10-403 API#50-029-22859-01-00 PTD#198-247 Guy, Due to The MPC-43L1-01 ESP change out finishing up late tonight (2/11/15)a full two days early, I request your expedited review of the submitted 10-403 sundry of the MPL-28A(API#50-029-22859-01-00 PTD#198-247)submitted on Monday 2/11/15. I also submitted the next well following this to ensure you have sufficient time to review. To be more transparent of upcoming work, see the updated schedule below.As you can see we started to work out the bugs with the new rig in field and started beating planned days on the last two projects. # Well Project WO Days Actual Stat Date End Date 1 MPE-18 ESP Changeout 6 6.5 1/19/2015 1/25/2015 2 MPE-19 ESP Changeout 6 8 1/25/2015 2/2/2015 3 MPE-11 TTC-ESP CO to 2-7/8"ESP 8 7 2/2/2015 2/9/2015 4 MPC-43L1-01 ESP CO (downsize) 6 ^'4 2/9/2015 2/13/2015 5 MPL-28A ESP CO& Perf Add 8 2/13/2015 2/21/2015 Submitted 2/9/15 6 MPL-02A ESP Changeout 5 2/21/2015 2/26/2015 Submitted 2/9/15 7 MPL-07 ESP CO (upsize) 6 2/26/2015 3/4/2015 8 MPL-12 ESP Changeout 6 3/4/2015 3/10/2015 9 MPF-01 ESP Changeout 7 3/10/2015 3/17/2015 10 MPF-81 ESP Changeout 6 3/17/2015 3/23/2015 11 MPF-05 ESP CO & Perf Add 6 3/23/2015 3/29/2015 12 MPJ-01A ESP Changeout 4 3/29/2015 4/2/2015 1 • 113 I MPJ-09A I ESPCP Changeout I 4 I 14/2/2015 I 4/6/2015 I Let me know if you have any questions. Chris Kanyer j Operations Engineer Ildrnrh 11:wka.LTA. ckanyer@hilcorp.com Direct: (907) 777-8377 Mobile: (907) 250-0374 2 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /(~ (~...~0/._//~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by~ildred Daretha Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is/ • • bp BP Exploration (Alaska) Inc. 0 , Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder 56 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPL -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPL -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, ..„,7) . a 7 1 ------ ,---- Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPL -Pad Date: 10/08/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPL -01A 2030640 50029210680100 Sealed conductor N/A N/A N/A N/A NA MPL -02A 2091470 50029219980100 Sealed conductor N/A N/A N/A N/A NA MPL -03 1900070 50029219990000 Tanko conductor N/A N/A N/A N/A NA MPL-04 1900380 50029220290000 Sealed conductor N/A N/A N/A N/A NA MPL -05 1900390 50029220300000 Sealed conductor N/A N/A N/A N/A NA MPL-06 1900100 50029220030000 Sealed conductor N/A N/A N/A N/A NA MPL -07 1900370 50029220280000 Sealed conductor N/A N/A N/A N/A NA MPL -08 1901000 50029220740000 Sealed conductor N/A N/A N/A N/A NA MPL -09 1901010 50029220750000 Sealed conductor N/A N/A N/A N/A NA MPL -10 1901020 50029220760000 Sealed conductor N/A N/A N/A N/A NA MPL -11 1930130 50029223360000 Sealed conductor N/A N/A N/A N/A NA MPL -12 1930110 50029223340000 Sealed conductor N/A N/A N/A N/A NA MPL -13 1930120 50029223350000 Sealed conductor N/A N/A N/A N/A NA MPL -14 1940680 50029224790000 Sealed conductor N/A N/A N/A N/A NA MPL -15 1940620 50029224730000 3.3 N/A 3.3 N/A 15.3 8/9/2011 MPL -16A 1990900 50029225660100 23 Needs top job MPL -17 1941690 50029225390000 0.2 N/A _ 0.2 N/A 5.1 9/1/2011 MPL -20 1971360 50029227900000 0.4 N/A 0.4 N/A 3.4 8/10/2011 MPL -21 1951910 50029226290000 1.7 N/A 1.7 N/A 8.5 8/10/2011 MPL -24 1950700 50029225600000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -25 1951800 50029226210000 1.7 N/A 1.7 N/A 15.3 8/10/2011 - - - 7 , ' MPL -28A 1982470 50029228590100 0.3 N/A 0.3 N/A 8.5 10/8/2011 MPL -29 1950090 50029225430000 0.5 N/A 0.5 N/A 3.4 8/7/2011 MPL -32 1970650 50029227580000 0.5 N/A 0.5 N/A 5.1 8/10/2011 MPL -33 1971050 50029227740000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -34 1970800 50029227660000 1.7 N/A 1.7 N/A 8.5 8/9/2011 MPL -35A 2011090 50029227680100 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL-36 1971480 50029227940000 0.1 N/A 0.1 N/A 7.6 9/1/2011 MPL -37A 1980560 50029228640100 6 N/A 6 N/A 47.6 8/13/2011 MPL -39 1971280 50029227860000 1.7 N/A 1.7 N/A 6.8 8/8/2011 MPL -40 1980100 50029228550000 1 N/A 1 N/A 6.8 8/8/2011 MPL -42 1980180 50029228620000 5.3 N/A 5.3 N/A 30.6 8/14/2011 MPL -43 2032240 50029231900000 17.5 Needs top job MPL-45 1981690 50029229130000 10 N/A 10 N/A 8.5 _ 8/10/2011 STATE OF ALASKA ~ ~ ALASKA OIL AND GAS CONSERVATION COM SION MAR 0 5 2008 REPORT OF SUNDRY WELL OPERATIS a 0+1 ~ Gas Cons. Commissio~t 1. Operations Performed: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 198-247 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22859-01-00 ' 7. KB Elevation (ft): 49 90 ~ 9. Well Name and Number: MPL-28A 8. Property Designation: 10. Field /Pool(s): ." ~,; ADL 388235 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 12860 " feet true vertical 7323 - feet Plugs (measured) None Effective depth: measured 12769 feet Junk (measured) None true vertical 7237. feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 7177' 9-5/8" 7177' 4471' 5750 3090 Intermediate Production 12819' 7" 33' - 12852' 33' - 7316' 7240 5410 Liner ~~~N~ APR 4 ~ 200$ Perforation Depth MD (ft): 12436' - 12504' Perforation Depth TVD (ft): 6924' - 6988' 2-7/8", 6.5# L-80 12382' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 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: 0 0 0 1780 0 Subsequent to operation: 284 915 1084 480 285 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 Nick, Frazier, 564-5633 N/A Printed Name. Sondra Stewman Title Drilling Technologist c/ Prepared By Name/Number: ~3"~~ b nature Phone 564-4750 Date Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~~~~a =~~ 1j ~ Submit Original Only L -, ~ ,~~3~r~~ Tree: 2-9/16" - 5M FMC Ilh ~ 11" 5M FMC Gen 5 w/FMC Tbg. Hgr., 2 7/8" EU Threads T&B, 2 1/2" CIW "H" BPV profile, 20" 91.1 ppf, H-40 112` M PL-28A Orig~Elev. = 49.90' (N 27E) Orig. GL Elev. = 16.90' (N 27E) Camco 2-7/8" x 1" 138` sidepocket KBMM GLM Camco 2-718" x 1" 444' sidepocket KBMM GLM 9-5/8" Howco `ES' Cementer 2035` (drift ID = 8.835", cap. _ .0758 bpf) 9-5/8", 40#/ft., L-80 BTC 7177' KOP @ 1000' ~ Camco 2-718" x 1 " 12138`' Angle passes 50° @ 3600` sidepocket KBMG-M-2 Max. Hole Angle = 78° @ 6250` GLM Hole Angle Thru Perfs. = 21 ° ~ HES 2 7/8" XN Nipple 12281' (2.205 min ID) Discharge Head 12300` 2-7/8 6.5 ppf, L-80 8 rd. tbg. {drift ID = 2.347", cap = 0.00592 bpf) Triple Tandem Pumps, 12301` 7" 26 ppf, L-80, Hydril 563 casing sxD o74P31 / o74P31 / 1 sP75 .(drift ID = 6.151", cap. = 0.0383 bpf} (cap w/ tbg = .02758 bpf) ~~ The original wellbore has been sidetracked. Stimulation Summary: Kuparuk "A" sand: 45,226# of 16/20 AEA Chemflow inhibitor impregnated proppant + 135,213# of 16/20 Carbolite Perforation Summary Ref. log: CDR dated 1/2/99 "Marked line log was unobtainable due to hole angle" Add Pert: 6/19/05 Size SPF Interval (MD) (TVD) 3 3/8 6 12436' - 12456` (6924' - 6943`) 3-3/8 6 12458` - 12478' (6945` - 69641 3 3/8 6 12484' - 12504' (6969' - 6988') SWS 41 B RDX 'bighole charges' 2 (20') Markerjoints from 12-224'-12283` DATE REV. BY COMMENTS 1/10/99 ML ri a an case y a ors Wellbore sidetracked by Nabors 27E 1.2113/99 ML ' w RWO Nabors 4ES 11/5/00 6/20/05 GMH LH RWO Nabors 4ES Elective Pull /Add Perf Nabors 4ES 4/28/07 REH RWO N-3S /Add SPM 2/6/08 L. Hulme ESP Replacement) TD Tag Nabors 3S Gas Separator 12337 GRSFTXAR Intake TVD = 6832' TVD Tandem Seal Section, 12341' Motor, Model - KMH 12355` 26fi HP, 2345 volt, 69 amp GSB3DBUT SB/SB PFSA GS63DBLT SBISB PFSA PUMPMATE XTO 12378` wI6 fin Centralizer PumpMate TVD = 6870' TVD Last TD tag: RWO 2/4/08 @ 12553` 7" Float Collar 12769' 7" Float Shoe 12'852` BP EXPLORATION • • BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPL-28A Common Well Name: MPL-28A Spud Date: 2/2/2008 Event Name: WORKOVER Start: 2/2/2008 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 3S Rig Number: Date ~ From - To Hours Task Code ~ NPT Phase Description of Operations _ _- - _ -- 2/1/2008 -- 21:00 - 00:00 3.00 P ---- PJSM with welder. Make rig repairs. Both derrick foot, lock-down bolts and pinning tabs were replaced with new parts. (cutting and welding) TRI-FLO Auto-Choke & seat replaced on choke manifold. Safety chain installed across door way on rig floor (dyed for rig moves). Safety chain added to (off-drillers-side) floor plate next to derrick leg. 2/2/2008 00:00 - 03:00 3.00 RIGD P PRE Continue rig welding repairs:PJSM with welder. Make rig repairs. Both derrick foot, lock-down bolts and pinning tabs were replaced with new parts. (cutting and welding) TRI-FLO Auto-Choke & seat replaced on choke manifold. Safety chain installed across door way on rig floor (used for rig moves). Safety chain added to (off-drillers-side) floor plate next to derrick leg. 03:00 - 06:00 3.00 RIGD P PRE PJSM. Rig down rig and rig components. Scope down and lay over derrick. -30 def F ambient temperature. 06:00 - 18:00 12.00 RIGU P PRE Pull Rig off of MPL-03. LRS rig up and freeze protect . Position matting boards, BOPE, and wellhead behind MPL-28. Align carrier. Notified (at 12:00 noon) Chuck Scheve w/ AOGCC of upcoming BOPE test. Lay out herculite and position carrier, pipe shed, pit modules. RU handi-berm. Hook up rig components. 15:00 raise Derrick. 16:30 scope derrick up. 18:00 - 20:00 2.00 RIGU P PRE Herculite burming in place,RU stair landings and hand rails, spot tiger tank and bleed tank, take on sea water to pits. Ri acce ted at 20:00 hrs. 2/2/2008 20:00 - 00:00 4.00 RIGU P PRE RU lines to tiger and bleed tanks.Tree valves failed to hold pressure. BPV failed .Valves serviced by well tech and are holding. 2/3/2008 00:00 - 05:00 5.00 KILL P DECOMP PJSM. RU hard lines to tree, bleed tank and tiger tank, and test all surface line 3500 si. Lines to tiger tank tested 500 psi. Blow down lines. All tree valves and SSV's leaking (would not hole pressure). 05:00 - 06:00 1.00 WHSUR P DECOMP SITP = 2000 si IA = 1500 si, PU and MU lubricator, test to 2500 si. Swab and master valves leaking, no visible leaks C~ 2500 psi. 06:00 - 11:00 5.00 KILL P DECOMP Pull BPV. T / IA / OA - 2200 / 1600 / 140 psi. Notify MPU of venting gas. Bleed gas from IA to Tiger Tank. Pump 100 Bbls of 130 degree SW down tubing C~ 4 BPM / 70 psi. Close choke and bullhead 25 Bbls SW into formation C~3 4 BPM / 600 psi. Shutdown, Tbg pressure to 0 psi. Circulation kill with SW 4 BPM / 260 psi on Tbg, IA / 580 psi maintaining 200 psi downstream of choke.525 Bbls away, circulating ~ 4 BPM, 800 psi on Tbg, IA ~ 10 psi. 220 Bbls returns to tiger tank. 700 Bls circulated w/ 270 Bbls crude and SW returns. Final circulation pressures of T / IA / OA - 920 / 10 / 260 psi. 11:00 - 13:30 2.50 WHSUR P DECOMP Flowcheck well ro 45 minutes. Tubin and IA on vacuum. FMC d rod TWC. Test from below b um in in IA ~ 3 BPM, ressure from 210 psi to 450 psi after 30 minutes. Well took 25 bbls to catch fluid after 1 hr shutdown. Test from above to 3500 si for 30 minutes. Both tests charted. 13:30 - 14:30 1.00 WHSUR P DECOMP Notify Chuck Scheve w/ AOGCC regarding upcoming BOPE testing. Inspect top hanger threads - ok, 8 turns w/ 2 7/8" to make up to hanger. Printed: 2/13/2008 2:24:54 PM ~' `~ ~.,..-~ BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPL-28A Common Well Name: MPL-28A Spud Date: 2/2/2008 ,Event Name: WORKOVER Start: 2/2/2008 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 2/6/2008 Rig Name: NABOBS 3S Rig Number: Date From -7o Hours Task Code NPT Phase Description of Operations 2/3/2008 14:30 - 22:30 8.00 WHSUR P DECOMP PUMU BOPE. 30 Bbls SW gravity feed to IA @ 15:00, 22 Bbls C«3 16:00, 20 bbls C~1 17:00. Installed new API ring, nuts and bolts on lower ram body kill flange. Grease and work choke and manual valves Q 20:00, 17 bbls., Pre heat BOP'S with SW and steam, Function test BOPE. 22:30 - 00:00 1.50 WHSUR P DECOMP Hang trunk hose to ESP sheave in derrick, spot spooling u nit. Clean up Geller. 2/4/2008 00:00 - 05:00 5.00 WHSUR P DECOMP BOPE, choke mainifold, and floor valves tested. Test witnessed b Chuck Scheve from AOGCC. One F/ P (TIW - floor safety valve). BOPE tested to 250 / 3500 psi. Annular tested to 3500 psi. All tests charted. 05:00 - 06:00 1.00 WHSUR P DECOMP LD test jt, blow down lines and secure valves. 06:00 - 07:30 1.50 PULL N FLUD DECOMP Crew change. PJSM (re: pulling hanger and completion, banding cable to tbg, PU singles to RIH and possibly tag fill). Flnish blowing down lines. Thaw out ice plug in choke line. (frozen where goes between rig and pit module) 07:30 - 09:00 1.50 PULL P DECOMP PUMU Opso-Lopso. RU 2" nipple and to-torc valve on OL. PUMU Lubricator. IA on vacuum. uIIB TWC. Tbg on vacuum. Laydown lubricator and OL. 09:00 - 09:30 0.50 PULL P DECOMP PUMU 2 7/8" landing joint w/TIW valve. Screw into hanger w/ 8 turns. Attempt to load stack w/ SW. 09:30 - 11:00 1.50 PULL N FLUD DECOMP Troubleshoot and thaw out ice plug in kill line. FMC BOLD screws. 11:00 - 11:30 0.50 PULL P DECOMP Pull hanger to floor w/ 80K PUW. Load well w/ 19 Bbls. Open IW valve, Tbg and IA w/ 0 psi. Break out and lay down tubing hanger. 11:30 - 18:00 6.50 PULL P DECOMP Cut ESP cable and band to tubing. PU 6 joints of 2 7/8" tubing while RIH (186') string wt 50K. Total depth of 12553'. No evidence of fill (bottom pert C~ 12504'). POH lay down 6 18:00 - 18:30 0.50 PULL P 18:30 - 00:00 5.50 PULL P 2/5/2008 00:00 - 02:30 2.50 i PULL i P 02:30 - 05:00 ~ 2.50 i PULL i P 05:00 - 07:00 2.00 07:00 - 11:30 4.50 11:30 - 21:00 I 9.50 DECOMP Rig service DECOMP Losses of 22 Bbls in 1 hour. POH w/ continuous hole fill. Losses of 25 Bbls @ 13:30. Continue POH utilizing double displacement method, standing tubing back in Derrick. 17:00 - at cable splice. Change reels in spooling unit. Total losses 76 Bbls C~3 18:00 and 144 joints out. Losses average 14 BPH., 382 jts out at 00.00 hrs. 44 bbls to fill well. 190 psi on OA. DECOMP Continue to POH standing back 2-7/8" tbg in derrick, with double displacement method. The box on joint # 4 (run in hole) and the pin end of 10 ft. pup under the first GLM (run in hole) were galled. Pull ESP cable over sheave. DECOMP BOLD ESP pump and motor. Recovered: 3 flat guards, 5 protectolizers, 205 Laselle clamps. RUNCMP Clean and clear rig floor. Prep for PUMU new ESP assembly. RUNCMP PUMU new ESP assembly. Run cable over sheave and MU to ESP motor. RUNCMP RIH (from derrick) ESP on 2 7/8", 6.5#, L-80, EUE, 8 rd. tbg, torqued to 2,300 ft-Ibs, Lasalle cable protectors on first nine joints then every second joint on the round cable, also on all GLM pups but not on the tubing hanger pup. Check cable conductivity and pump through motor every 2,000' @ 1 bpm / 480 psi, pumping a total of 10 bbls SW each time. 175 psi on OA. Printed: zn:tizuots z:za:5a t'nn BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPL-28A Common Well Name: MPL-28A Spud Date: 2/2/2008 Event Name: WORKOVER Start: 2/2/2008 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/5/2008 11:30 - 21:00 9.50 BUNCO ~UNCMP Stopped at 20:00 hrs had returns with 32 bbl pumped. Stopped 21:00 - 00:00 3.00 ~ RU 2/6/2008 00:00 - 02:00 i 2.00 ~ RU 02:00 - 07:00 I 5.00 RU 07:00 - 08:00 1.00 I RU RIH 130 stands (-8150 ft) RUNCMP Centrilift made ESP cable splice to new reel & tested. Fj ill well with 10 bbl SW eve hour. RUNCMP Centrilift made ESP cable splice to new reel & tested. Fill well with 10 bbl SW every hour. RUNCMP Continue running ESP completion and pump on 2-7/8" 8rd Tubing from the Derrick. Filling the hole with 10 bbl of seawater every hour. Check conductivity of ESP every 2,000 ft. RUNCMP Ran a total of 391 Joints of 2-7/8", 6.5#, L-80, 8rd EUE Tubing. Ran a total of 207 LaSalle Clamps, 7 Protectolizers and 3 Flat Guards. Fill the hole with 15 bbls of seawater and flush the pump with 10 bbls o seawater. Re-dress the Tubing Hanger 08:00 - 09:00 1.00 BUNCO RUNCMP Pick up and make up the Landing Joint to the Tubing Hanger with FMC rep. PUW = 80K ,SOW = 40K {block weight = 10K). 09:00 - 11:00 2.00 BUNCO RUNCMP Perform penetrator splice with Centrilift reps. 11:00 - 12:00 1.00 BUNCO RUNCMP Land Tubing Hanger with FMC rep and RILDS. Dry rod TWC with FMC re . 12:00 - 14:30 2.50 W HSUR P RUNCMP Pressure test TWC from below by injecting at 2.5 bpm / 480 ps 14:30 - 17:30 17:30 - 20:30 3.00 3.00 BOPSU WHSUR P P RUNCMP RUNCMP ND BOPE. Pull Riser and ND Choke Line. Lay down ROPE in the Cradle and remove from the Cellar. NU Tree. FMC test hanger void to 5,000 si for 30 minutes. Install blind flange on wing valve. Test tree and valves to 5,000 psi no visible leaks. (Crew change pre-tour checks). 20:30 - 21:00 0.50 BUNCO RUNCMP Final ESP conductivity checks by Centrilift: 400 Meg phase to ground / 4.4 OHM phase to phase / 158 deg F intake temp / 2,930 psi at intake. 21:00 - 22:00 1.00 WHSUR P RUNCMP Pull TWC with lubricator and Install BPV, Remove secondary annulus valve and secure tree and cellar. Release Rig for move to MPE-28 @ 2200 hrs 2/6/2008. rnmea: u i oicuuo c.w.ov nvi • • BP EXPLORATION Page 2 of 3 ~ Operations Summary Report Legal Well Name: MPL-28A ,Common Well Name: MPL-28A Spud Date: 2/2/2008 Event Name: WORKOVER Start: 2/2/2008 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/612008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours ' Task Code NPT I! Phase Description of Operations 2/3/2008 14:30 - 22:30 8.00 WHSUR P DECOMP PUMU ROPE. 30 Bbls SW gravity feed to IA ~ 15:00, 22 Bbls (~ 16:00, 20 bbls ~ 17:00. installed new API ring, nuts and ~ bolts on lower ram body kill flange. Grease and work choke and manual valves C~ 20:00, 17 bbls., Pre heat BOP'S with SW and steam, Function test BOPE. 22:30 - 00:00 1.50 WHSUR P DECOMP Hang trunk hose to ESP sheave in derrick, spot spooling u nit. Clean up Geller. 2/4/2008 00:00 - 05:00 5.00 WHSUR P DECOMP BOPE, choke mainifold, and floor valves tested. Test witnessed b Chuck Scheve from AOGCC. One F/ P (TIW - floorsafety valve). BOPE tested to 250 / 3500 psi. Annular tested to 3500 psi. All tests charted. 05:00 - 06:00 1.00 WHSUR P DECOMP LD test jt, blow down lines and secure valves. 06:00 - 07:30 1.50 PULL N FLUD DECOMP Crew change. PJSM (re: pulling hanger and completion, banding cable to tbg, PU singles to RIH and possibly tag fill). Finish blowing down lines. Thaw out ice plug in choke fine. (frozen where goes between rig and pit module) 07:30 - 09:00 1.50 PULL P DECOMP PUMU Opso-Lopso. RU 2" nipple and to-torc valve on OL. PUMU Lubricator. IA on vacuum. uIIB TWC• Tbg on vacuum. Laydown lubricator and OL. 09:00 - 09:30 0.50 PULL P DECOMP PUMU 2 7/8" landing joint w/TIW valve. Screw into hanger w/ 8 turns. Attempt to load stack w/ SW. 09:30 - 11:00 1.50 PULL N FLUD DECOMP Troubleshoot and thaw out ice plug in kill line. FMC BOLD screws. 11:00 - 11:30 0.50 PULL P DECOMP Pull hanger to floor w/ 80K PUW. Load well w/ 19 Bbls. Open IW valve, Tbg and IA w/ 0 psi. Break out and lay down tubing hanger. 11:30 - 18:00 6.50 PULL P DECOMP Cut ESP cable and band to tubing. PU 6 joints of 2 7/8" tubing while RIH (186') string wt 50K. Total depth of 12553'. No evidence of fill (bottom perf ~ 12504 POH lay down 6 singles. 18:00 - 18:30 0.50 PULL P DECOMP Rig service 18:30 - 00:00 5.50 PULL P DECOMP Losses of 22 Bbls in 1 hour. POH w/ continuous hole fill. Losses of 25 Bbls C«? 13:30. Continue POH utilizing double displacement method, standing tubing back in Derrick. 17:00 - at cable splice. Change reels in spooling unit. Total losses 76 Bbls ~ 18:00 and 144 joints out. Losses average 14 BPH., 382 jts out at 00.00 hrs. 44 bbls to fill well. 190 psi on OA. 2/5/2008 00:00 - 02:30 2.50 PULL P DECOMP Continue to POH standing back 2-7/8" tbg in derrick, with double displacement method. The box on joint # 4 (run in hole) and the pin end of 10 ft. pup under the first GLM (run in hole) were galled. Pull ESP cable over sheave. 02:30 - 05:00 2.50 PULL P DECOMP BOLD ESP pump and motor. Recovered: 3 flat guards, 5 protectolizers, 205 Laselle clamps. 05:00 - 07:00 2.00 BUNCO RUNCMP Clean and clear rig floor. Prep for PUMU new ESP assembly. 07:00 - 11:30 4.50 BUNCO RUNCMP PUMU new ESP assembly. Run cable over sheave and MU to ESP motor. 11:30 - 21:00 9.50 BUNCO RUNCMP RIH (from derrick) ESP on 2 7/8", 6.5#, L-80, EUE, 8 rd, tbg, torqued to 2,300 ft-Ibs, Lasalle cable protectors on first nine joints then every second joint on the round cable, also on all GLM pups but not on the tubing hanger pup. Check cable conductivity and pump through motor every 2,000' ~ 1 bpm / 480 psi, pumping a total of 10 bbls SW each time. 175 psi on OA. Printed: 2/13/2008 2:24:54 PM • • BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPL-28A Common Well Name: MPL-28A Spud Date: 2/2/2008 Event Name: WORKOVER Start: 2/2/2008 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 3S Rig Number: ~ ' NPT Phase Description of Operations Date` From - To Hours Task Code 2/5/2008 11:30 - 21:00 9.50 BUNCO RUNCMP Stopped at 20:00 hrs had returns with 32 bbl pumped. Stopped RIH 130 stands (-8150 ft) 21:00 - 00:00 3.00 BUNCO RUNCMP Centrilift made ESP cable splice to new reel & tested. Fill well with 10 bbl SW eve hour. 2/6/2008 00:00 - 02:00 2.00 BUNCO RUNCMP Centrilift made ESP cable splice to new reel & tested. Fill well with 10 bbl SW every hour. 02:00 - 07:00 5.00 BUNCO RUNCMP Continue running ESP completion and pump on 2-7/8" 8rd Tubing from the Derrick. Filling the hole with 10 bbl of seawater every hour. Check conductivity of ESP every 2,000 ft. 07:00 - 08:00 1.00 BUNCO RUNCMP Ran a total of 391 Joints of 2-7/8", 6.5#, L-80, 8rd EUE Tubing. Ran a total of 207 LaSalle Clamps, 7 Protectolizers and 3 Flat Guards. Fill the hole with 15 bbls of seawater and flush the pump with 10 bbls of seawater. a-dress the Tubing Hanger wi rep. 08:00 - 09:00 1.00 BUNCO RUNCMP Pick up and make up the Landing Joint to the Tubing Hanger with FMC rep. PUW = SOK ,SOW = 40K (block weight = 10K). 09:00 - 11:00 2.00 BUNCO RUNCMP Perform penetrator splice with Centrilift reps. 11:00 - 12:00 1.00 BUNCO RUNCMP Land Tubing Hanger with FMC rep and RILDS. D rod TWC with FMC re . 12:00 - 14:30 2.50 WHSUR P RUNCMP Pressure test TWC from below by injecting at 2.5 bpm / 480 psi for 30 charted mins. Blow down lines and RU to test from above. Test the rom a ove to psi or carted mins. 14:30 - 17:30 3.00 BOPSU P RUNCMP ND BOPE. Pull Riser and ND Choke Line. Lay down BOPE in the Cradle and remove from the Cellar. 17:30 - 20:30 3.00 WHSUR P RUNCMP NU Tree. FMC test hanger void to 5,000 si for 30 minutes. Install blind flange on wing valve. Test tree and valves to 5,000 psi no visible leaks. (Crew change pre-tour checks). 20:30 - 21:00 0.50 BUNCO RUNCMP Final ESP conductivity checks by Centrilift: 400 Meg phase to ground / 4.4 OHM phase to phase / 158 deg F intake temp / 2,930 psi at intake. 21:00 - 22:00 1.00 WHSUR P RUNCMP Pull TWC with lubricator and Install BPV, Remove secondary annulus valve and secure tree and cellar. Release Rig for move to MPE-28 ~ 2200 hrs 2/6/2008. Printed: 2/13/2008 2:24:54 PM ~ R\:.vc\ '11'-"" . STATE OF ALASKA .svp-p~ 07 ALA~ OIL AND GAS CONSERVATION COM.ION MAY 0 9 20 REPORT OF SUNDRY WELL OPERA TI 0 NSJ\ \<1 s\c..a Oil & Gas Cons. commission /"d' h ge !loc ora 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. 181 Development o Exploratory 198-247 / 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22859-01-00 / 7. KB Elevation (ft): 49.90 - A~ ¿,lOP 9. Well Name and Number: MPL-28A / 8. Property Designation: ADL 388235/AN ;;,sSO,;/..$ 10. Field I Pool(s): Milne Point Unit I Kuparuk River Sands . 11. Present well condition summary , Total depth: measured 12860 ( feet true vertical 7323 I feet Plugs (measured) None Effective depth: measured 12769 feet Junk (measured) None true vertical 7237 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 7177' 9-518" 7177' 4471' 5750 3090 Intermediate Production 12819' 7" 12852' 7316' 7240 5410 Liner :')~MAY 142007 Perforation Depth MD (ft): 12436' - 12504' Perforation Depth TVD (ft): 6924' - 6988' 2-7/8",6.5# L-80 12371' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily AveraQe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: 0 0 0 740 Subsequent to operation: 243 530 630 320 270 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 Printed Name Sondra Stewman Title Technical Assistant -a ,. ~~~ Prepared By Name/Number: S!goatur~~ .11 Q Phone 564-4750 Date O';5,c9r-òì Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 0 R Rt BFl MAY I 4 2007 Þ-5\ Submit Original Only IGINAL 1'-\ I.œ.e.; 2-9/16" - 5M FMC . Wellhead: 11" 5M FMC Gen 5 w/FMC Tbg. Hgr., 2 7/8" EU Threads T&B, 21/2" CIW "H" BPV profile 20" 91.1 ppf, H-40 112' I 9-5/8" Howco 'ES' Cementer I 2035' I (drift ID = 8.835", cap. = .0758 bpf) 9-5/8", 40#/ft., L-80 BTC I 7177' I KOP @ 2000' Max. Hole Angle = 77.7 deg. @ 6250' Hole Angle Tru Perfs, = 21 degrees 2-7/86.5 ppf, L-80 8 rd, tbg. (drift ID = 2.347", cap = 0.00592 bpf) 7" 26 ppf, L-80, Hydril 563 casing (drift ID = 6.151 ", cap. = 0.0383 bpf) The original wellbore has been sidetracked. Stimulation Summary: Kuparuk 'W' sand: 45,226# of 16/20 AEA Chemflow inhibitor impregnated proppant + 135,213# of 16/20 Carbolite Perforation Summary Ref. log COR dated 112/99 "Marked line log was unobtainable due to hole angle" Add Perf: 6/19/05 Size SPF Interval (MD) (TVD) 33/8 6 12436' - 12456' (6924' - 6943') 3-3/8 6 12458' - 12478' (6945' - 6964\ 33/8 6 12484' - 12504' (6969' - 6988') SWS 41 B RDX 'bighole charges' 2 (20') Marker joints from 12-224'-12283' DATE REV. BY MPL-28A COMMENTS 11/5/00 GMH RWO Nabors 4ES Elective Pull/ Add Perf Nabors 4ES 6/20/05 4/28/07 LH REH RWO N3S / Add SPM orig,.lev. = 49.90' (N 27E) Orig. lev. = 16.90' (N 27E) Camco 2-7/8" x 1" sidepocket KBMM GLM 138' Camco 2-7/8" x 1" I I sidepocket KBMM GLM 444' Cameo 2-7/8" x 1" 112138' sidepocket KBMG-M-2 GLM HES 2 7/8" XN Nipple 112281'1 (2.205 min ID) Discharge Head 112292' I Tandem Pump, 112293' 1 PMSXD 1.3/126P31 PMSXO 1.3/18P75.1 Tandem Gas Separator 112323' 1 GRSFTXAR Tandem Seal Section, 112328' I GSB30BFERHLH6SSCVSB/SBPFSA GSB3DBFERHLH6SSCVSB/SBPFSA Motor, 304 HP, 2290 volt, 112342' I 81 amp, Model - KMHG (Rerate KME-1 255HP 2145 volt \ 69 amp) PUMPMATE XT-O 112367' 1 w/6 fin Centralizer 7" Float Collar 112769' I 112852' I 7" Float Shoe MILNE POINT UNIT WELL MPL-28a API No. 50-029-22541 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-28 MPL-28 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/21/2007 Rig Release: 4/26/2007 Rig Number: Spud Date: 4/6/1998 End: 4/26/2007 4/21/2007 19:00 - 00:00 5.00 RIGD PRE Rig down from MPK-38. Prepare for move to MPL-28A. 4/22/2007 00:00 - 06:00 6.00 RIGU PRE MIRU on MPL-28A. Spotting and rigging equipment and support equipment. 06:00 - 14:00 8.00 RIGU PRE Align carrier over wellhead. Pull forward, position BOPE, rig mats, herculite. Back carrier over wellhead. RU Handi-Berm, position and RU pipe shed and pit module. 14:00 - 19:30 5.50 RIGU PRE Notified AOGCC for 24 hours advance of BOPE testing. (left 2 messages on recorder). Continue to hook up rig modules. Raise and scope Derrick. Continiue rigging up. 19:30 - 00:00 4,50 RIGU PRE Accept rig @ 19:30 hrs. Rig up hard line to Tiger Tank, and circulation lines on tree wI choke and kill lines. Pressure test lines to 3000 psi. 4/23/2007 00:00 - 00:30 0.50 RIGU PRE Pressure test lines to Tiger tank to 3000 psi. 00:30 - 01 :00 0.50 WHSUR WHDTRE Pull BPV wI lubricator. 01:00 - 02:15 1.25 WHSUR WHDTRE Hold PJSM for well kill. Initial pressures T/I/O = 500/710/140 psi. Bleed gas off IA to tank. Pump 43 bbls seawater down tubing at 3.5 bpm with 27 Bls of returns to tank. 02:15 - 09:00 6.75 WHSUR N RREP WHDTRE Loud noise heard coming from micro motion meter. Shut down pumping operation to replace micro motion. Replace and repair. Pressure test line to 4000 psi. 09:00 - 09:30 0.50 KILL P DECOMP Kill well. Tbg IIA I OA @ start = 360/280/140. Bleed gas to tiger tank from IA. Circulate down tubing taking returns thru choke to tiger tank @ 3.5 BPM, 640 psi Tbg 1230 psi IA 1110 psi downstream of choke. Circulate 100 Bbls and get 60 Bbls returns. Bullhead 25 Bbls into formation, shut down for SITP of o psi. 09:30 - 12:30 3.00 KILL P DECOMP Open choke and pump down tubing taking returns from annulus @ 4 BPM, 1020 psi on Tbg, 380 psi on lA, 150 psi downstream of choke. Circulate gas from wellbore to rate of 4 BPM, 1110 psi on Tbg, 10 psi on IA. OA pressured to 600 psi. Bleed OA to 120 psi. Pump total of 800 Bbls (includes initial 100 Bbls), with 460 Bbls returns. Clean SW @ 8.5 #Igal returns. Lost 330 Bbls to formation during well kill. Shut down and monitor Tbg IIA. 0 psi on both. Well on vacuum. 12:30 - 14:00 1.50 WHSUR P DECOMP Dry rod TWC. Pump SW in IA @ 4 BPM wI injection pressure of 500 psi for total of 50 Bbls to test TWC from below. Test TWC from above to 3500 psi. Both tests ok, and recorded on test chart. 14:00 - 15:30 1.50 WHSUR P DECOMP ND tree. Gravity feed 30 Bls of SW into IA every hour. Test hanger lifting threads by screwing in pup joint 8 turns. Contact Jim Regg wI AOGCC re: State witness of BOPE testing. Witness of testing waived by Regg. 15:30 - 22:00 6.50 WHSUR P DECOMP NU DSA (13 518" x 11 ") to tubing spool. NU BOPE. 22:00 - 00:00 2.00 BOPSU P DECOMP Function test BOP's. Start BOP pressure test at 23:00. Troubleshoot leaks in Choke manifold flanges. Continue BOP test to 250 psi lowl 3500 psi high. 4/24/2007 00:00 - 05:30 5.50 BOPSU DECOMP Continue testing BOP's low 250 psVhigh 3500 psi. TIW valve leaked. Replaced with new TIW and passed. Annular required some cycling and increasing bag pressure to 1750 psi for pass (new annular element). Shot IA fluid at 04:30 = 550 ft. 05:30 - 06:30 1.00 WHSUR DECOMP BOLD BOPE testing equipment. Crew change. Prep floor for pulling completion. PUMU Opso-Lopso. Pull TWC with Tbg on vacuum. BOLD Lubricator and Opso-Lopso. Printed: 4/30/2007 11 :50:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-28 MPL-28 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/21/2007 Rig Release: 4/26/2007 Rig Number: Spud Date: 4/6/1998 End: 4/26/2007 4/24/2007 06:30 - 08:00 1.50 PULL DECOMP PUMU landing joint with TIW, screw into hanger. Shoot fluid level. FL @ 1300'. BOLDS, Pull hanger wI 68K #'s. Pump 30 Bbls SW into well with no returns. BOLD tubing hanger. 08:00 - 09:30 1.50 PULL DECOMP RU elephant trunk and shieve. Stand back tubing as run cable over shieve. Lay down 10' pup joint, 1 full joint, 1 GLM. 09:30 - 11 :30 2.00 PULL DECOMP Pull 1 0 stands standing back in Derrick. Double displace wI SW down IA. Shoot fluid level. FL @ 1200'. POOH another 10 stands and double displace and shoot another fluid level. FL @ 1200' 11 :30 - 17:00 5.50 PULL DECOMP POOH standing back 2 7/8" tubing in Derrick with double displacement of SW every 5 stands. Lay down 3 bad jts due to galled threads. 75 Stds OOH @ 15:00, change out spool on spooling unit. Continue POOH. 105 Std OOH @ 17:00. 17:00 - 00:00 7.00 PULL DECOMP Shoot fluid level. FL @ 1200'. Continue POOH wI double displacement. Pre-tour safety meeting with Night Crew. Continue POOH with existing ESP Completion standing back in the Derrick. 140 stands out @ 19:00 hrs. Laid down 3 bad Joints due to "crimping I egging" of the Pipe on the Pin Ends, 1 bad Joint due to it being bent near the Box End and 1 bad Joint due to gouging from previous workover. 165 stands out @ 22:00 hrs. Recovered 1 XN Nipple Assembly with an 8' Pup and a 2' Pup. 4/25/2007 00:00 - 00:30 0.50 PULL P DECOMP On surface with ESP Assembly at 00:30 hrs. Recovered a total of 6 Protectolizers, 3 Flat Guards and 205 LaSalle Clamps. 00:30 - 05:30 5.00 PULL P DECOMP PJSM, Break down, lay down and inspect ESP Components with Centrilift rep. Cut the Cable and send over the Sheave to the Spooling Unit. Pump 20 bbls of seawater down the well every hour while on surface. Disconnect and lay down Elephant Trunk down. 05:30 - 10:00 4.50 RUNCO RUNCMP RU to run new ESP Assembly. Inspect, PU and MU new ESP Assembly with Centrilift rep. Continue to pump 20 bbls of seawater down the well every hour. 10:00 - 19:15 9.25 RUNCO RUNCMP PUMU XN nipple on 1 Jt. tbg from previous completion. Run 3 new jts of 27/8" tubing, 1 new GLM KBMG-M-2 wI DGLV installed. RIH w/2 7/8" Tbg from Derrick. MU torque - 2300 ft-Ibs. 5 protectolators and 3 flat guards. Put LaSalle cable clamps on the 1st nine connections and every other as RIH. Pump 10 Bbls of SW into well every 1 hour as RIH. Check cable conductivity, load Tbg and flush pump w/10 Bbls of SW every 2000' and at the splice. 19:15 - 23:15 4.00 RUNCO RUNCMP Stop with 122 stands of 2 7/8" Tubing in the well to perform a reel to reel splice. Filled the Tubing with 7 bbls and flushed the pump with 10 bbls of seawater at a rate of 1 bpm 1340 psi. The well is on a strong vac. 23:15 - 00:00 0.75 RUNCO RUNCMP Continue RIH with the new ESP Assembly on 2 7/8" Tubing from the Derrick. MU Torque for Tubing = 2,300 ft-Ibs. Utilizing Best 0 Life Dope on all connections. At 00:00 hrs, there were 140 stands in the well. 4/26/2007 00:00 - 03:30 3.50 RUNCO RUNCMP Continue RIH with the new ESP Assembly on 2 7/8" Tubing from the Derrick. MU Torque for Tubing = 2,300 ft-Ibs. Utilizing Best 0 Life Dope on all connections. Pumping 10 bbls of seawater down the well every hour while RIH. Stop every Printed: 4/30/2007 11 :50:34 AM "', Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-28 MPL-28 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/21/2007 Rig Release: 4/26/2007 Rig Number: Spud Date: 4/6/1998 End: 4/26/2007 18:00 - 20:00 2.00 WHSUR P 2,000' to check the conductivity of the cable and flush the pump with 10 bbls of seawater. At 02:30 hrs, we had 175 stands in the well. Find bad pin on pup jt below GLM as picking up. Break out pup joint. Lay down GLM, PUMU 10' pup, break collar and PUMU GLM to string. RIH wI remaining completion. MU TIW and head pin, fill tubing and flush pump w/10 Bbls SW. Ran a total of 205 LaSalle Clamps, PUMU hanger. Torque and'align to proper orientation. Install penetrator and make cable-connector splice. Let epoxy dry on penetrator cable connection. Final checks thru hanger and penetrator of: 4.214.214.2 ohms phase to phase, 702 meg ohms phase to ground, 2993 psi - 148 deg F @ 12369'. PU wt of 68K #'s, SO wt of 45K #'s. Land hanger and RILDS. Break out landing joint. Check torque on LDS. Dry rod TWC and test from above to 1000 psi and chart. Change 2 7/8" Fixed pipe rams to 2 7/8" x 5 1/2" variable rams. ND BOPE. Remove DSA. NU Tree. Centrilift final checks: 4.2 ohms phase to phase I 650 meg ohoms phase to ground I 2772 psi @ Intake 1162 deg F @ motor, 160 deg F @ intake. Test tree and tubing head adaptor to 5000 psi wI diesel, and chart. WHDTRE PU Lubricator. Pull TWC with Lubricator. Run in BPV with Lubricator. Final WHP's: Tbg IIA I OA - 0 I 0 1140 psi. Secure Tree and Cellar. Rig released at 20:00 hrs on 4/26/2007. 03:30 - 05:00 RUNCMP 05:00 - 06:30 RUNCMP 06:30 - 08:00 1.50 RUNCMP 08:00 - 09:00 1.00 RUNCMP 09:00 - 10:00 1.00 WHSUR P TUBHGR 10:00 - 15:30 5.50 WHSUR P WHDTRE 15:30 - 18:00 2.50 WHSUR P WHDTRE Printed: 4/30/2007 11 :50:34 AM 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program , STATE OF ALASKA '\ ALASKAJL AND GAS CONSERVATION CO...j~ISSION REPORT OF SUNDRY WELL OPERATlqtlSçe;JVED JlJLiO G 2'005' o Other ,'Jska Oil' &"6,' a'~ Con~UÜo:"mm' . iJ. I,; ISSIon o Re-EntérSLJSp~ndcA:h~age .,' o Time Extension o Suspend 0 Operation Shutdown III Perforate III Repair Well 0 Plug Perforations 0 Stimulate II Pull Tubing 0 Perforate New Pool 0 Waiver 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: III Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 198-247 6. API Number: 50-029-22859-01-00 99519-6612 49.90 9. Well Name and Number: MPL-28A 8. Property Designation: ADL 388235 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 12860 feet true vertical 7323 feet Plugs (measured) None Effective depth: measured 12769 feet Junk (measured) None true vertical 7237 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 7177' 9-5/8" 7177' 4471' 5750 3090 Intermediate Production 12819' 7" 12852' 7316' 7240 5410 Liner SCANNED JUL Ü 7 2005 Perforation Depth M D (ft): Perforation Depth TVD (ft): 12436' - 12504' 6924' - 6988' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8", 6.5# L-80 12428' None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFl .JUl 0 7 2005 13. Oil-Bbl Prior to well operation: 284 Subsequent to operation: 642 14. Attachments: 0 Copies of Logs and Surveys run III Daily Report of Well Operations III Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 371 278 340 962 598 341 Tubinq Pressure 298 319 15. Well Class after proposed work: o Exploratory III Development 0 Service 16. Well Status after proposed work: III 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. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman ~--',~~ S~ªtuLE!.J0'c~~~t:;J Form 10-404 Revised 04/2004 Title Technical Assistant ~o~) , ~~47. L l'r\\u~~\Jt\ c- Prepared By Name/Number: Date Ot -<..)lD~ondra Stewman I 564-4750 Submit Original Only ~ 2-9/16" - 5M FMC ) Wellhead: 11" 5M FMC Gen 5 wlFMC Tbg. Hgr., 27/8" EU Threads T&B, 4" CIW "H" BPV profile, 20" 91.1 ppf, H-40 112' I ~ 9-5/8" Howco 'ES' Cementer 1 2035' 1 0 (drift ID = 8.835", cap. = .0758 bpf) 9-5/8", 40#/ft., L-80 BTC l 7177' I ~ KOP @ 2000' Max. Hole Angle = 77.7 deg. @ 6250' Hole Angle Tru Perfs. = 21 degrees 2-7/8 6.5 ppf, L-80 8 rd. tbg. (drift 10 = 2.347", cap = 0.00592 bpf) 7" 26 ppf, L-80, Hydril 563 casing (drift 10 = 6.151 ", cap. = 0.0383 bpf) The original wellbore has been sid etra cked. Stimulation Summary: Kuparuk "A" sand: 45,226# of 16/20 AEA Chemflow inhibitor impregnated proppant + 135,213# of 16/20 Carbolite, perforation Summary Ref. log: COR dated 1/2/99 "Marked line log was unobtainable due to hole angle" Add Perf: 6/19/05 Size SPF Interval (MD) (TVD) 33/8 6 12436' - 12456' (6924' - 6943') 3-3/8 6 12458' - 12478' (6945' - 6964) 33/8 6 12484' - 12504' (6969' - 6988') SWS 41 B RDX 'bighole charges' 2 (20') Marker joints from 12-224'·12283' MPL-28A @o . = = ~"$P1:M!:Pk)rj:%m#%%WK~ DATE REV. BY COMMENTS 5/22/98 1/10/99 2/25/99 12113/99 ML Drilled and cased by Nabors 27E ML Wellbore sidetracked bv Nabors 27E MOO Completion wI desander Nabors 4ES ML RWO Nabors 4ES 11/5/00 6/6/02 6/20/05 GMH RWO Nabors 4ES LH LH RWO Nabors 4ES Elective Pull 1 Add Perf Nabors 4ES Ori£ ') Elev. = 49.90' (N 27E) Orig. Gl Elev. = 16.90' (N 27E) " 1 Camco 2-7/8" X 1,ï' .1'1361'1 sidepocket KBMM GLM ~ Camco 2-7/8" x 1 1 1 sidepocket KBMM GLM 12204' ~ HES 27/8" XN Nipple 112344' I (2.205 min 10) MS-1 Pressure Head 112357' I 112359' 1 Tandem Pump, 151GC1700 I 19GC8200 GPMTAR 1:1 Tandem Gas Separator GRSFTXARH6 112383' I Tandem Seal Section, 112388' 1 GSB30B UT/L T AB/HSN PFSAlFSA CL5 Motor, 165 HP, 2133 volt, 46 amp, Model - KMH-A 112402' I Phoenix XT-1 MultiSensor w/6 fin Centralizer Sensor TVD 112422' I 16911' I = = 112769' I 112852' I 7" Float Collar 7" Float Shoe MILNE POINT UNIT WELL MPL-28a API No. 50-0?9-??541 BP EXPLORATION (AK) ) ) BPEXPLORATION OperatiOl'lsSul11 mEiryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-28 MPL-28 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/17/2005 Rig Release: 6/21/2005 Rig Number: 4ES Spud Date: 4/6/1998 End: Date From- To Hours Task Code NPT Phase Description of Operations 6/17/2005 06:00 - 08:00 2.00 MOB P PRE Move Rig from MPL-06 to MPL-28A. 08:00 - 10:00 2.00 RIGU P PRE Spot Sub Base, Pits, Pipe Shed, and Camp. Raise and socpe Derrick. 10:00 - 11 :00 1.00 RIGU P PRE Take on 120 deg F. Sea Water in Pits. Spot Tiger Tank and lay Line. Rig up to Tree. Pressure Test Line to 3,50'0 psi. Accept Rig at 10:00 hrs. 11 :00 - 11 :30' 0.50 KI LL P DECOMP Pick-up Lubricator and pull BPV. Lay down same. TP = 120'0 psi. CP = 1400 psi. 11 :30 - 12:00 0.50 KILL P DECOMP PJSM with all. Discuss venting gas and well kill operations. 12:00 - 16:0'0' 4.00 KILL P DECOMP Bleed large volume of dry gas. Start Well Kill with hot Sea Water at 4 bpm/800 psi. Pumped 450 bbls Sea Water taking oil returns to Tiger Tank at a final rate of 3 bpm/600 psi. Monitor clean returns to Pits and check return rate. Lost 6 bbls/1O' mins. Shut down Pump. Monitor 0 psi. 16:00' - 16:30 0.50 WHSUR P DECOMP Set TWC. Test to 3500 psi, Ok. 16:30 - 17:30 1.00 WHSUR P DECOMP Bleed off tubing void. NID X-mas tree. 17:30 - 20':00 2.50 BOPSUR P DECOMP N/U BOPE. change out blind rams for rebuilt Blind/Shear rams. 20:0'0 - 21 :00' 1.00 BOPSUR P DECOMP Cycle & attempt to pressure test blind/shear rams. No test. 21 :00' - 22:30 1.50 BOPSUP P DECOMP Change out Blind/Shear rams back to Blind rams. 22:30 - 00:00 1.50 BOPSUP P DECOMP Pressure test BOPE as per BP/AOGCCrequirements. BOP test witnessing waived by John Crisp wi AOGCC. 6/18/20'0'5 0'0':00' - 0'1 :30' 1.50' BOPSUP P DECOMP Finish testing BOPE as per BP/AOGCC requirements. No failures. 0'1 :30 - 02:00 0.50 WHSUR P DECOMP RID test Equip. Blow down lines & drain stack. 0'2:00 - 0'2:30 0.50 WHSUR P DECOMP M/U lubricator & pull TWC. UD lubricator. 0'2:30 - 0'3:00 0.50 PULL P DECOMP M/U landing jt into hanger. BOLDS. Pull hange to floor wi 105K. UD landing jt & hanger. Pull ESP cable over sheave & attach to cable reel inspooloing unit. 0'3:0'0' - 0'6:0'0 3.00 PULL P DECOMP POOH & stand back 2 7/8" ESP completion. 06:00 - 07:00 1.00 PULL P DECOMP Stop to change Cable reels out in Spooling Unit. 07:00' - 11 :30 4.50 PULL P DECOMP Finish POOH with 2 7/8" Tbg 394 Jts, 2 ea GLMs and XN-Nipple. 11 :30 - 13:30' 2.0'0 PULL P DECOMP Lay down ESP Assembly. 13:30 - 15:00 1.50' PULL P DECOMP Rig down Elephant Trunk and drain Hose from ESP Sheave. Clear and clean Floor. 15:00 - 16:30' 1.50 CLEAN P CLEAN M/U muleshoe & RIH wi 40' stands of 2 7/8" tubing. 16:30 - 17:30' 1.0'0 CLEAN P CLEAN Cut & slip 84' of drilling line. Service rig. 17:30 - 20:30 3.00 CLEAN P CLEAN Con't to RIH wi muleshoe on strands of 2 7/8" tubing. 20:30 - 21 :00 0'.50 CLEAN P CLEAN Single in wi jts of 2 7/8" tubing. Ran total of 210 jts & tagged up on hard fill. Tagged @ 12765'. 21 :00 - 23:00 2.00 CLEAN P CLEAN M/U head pin & R/U to reverse circulate. Pumped 20 bbls of EP-Lube ahead. Filled hole wi 30 bbls. Reverse circ, 3.5 BPM @ 600 psi. Pumped total of 400 bbls. Losses averaged approx 1 BPM while circulating. Recovered small amount of sand, pipe dope & scale. 23:00 - 23:30 0'.50 CLEAN P CLEAN Monitor well. UD head pin. Prep to POOH. 23:30 - 0'0:00 0.50 CLEAN P CLEAN POOH & stand back 27/8" tubing. 6/19/2005 0'0:00 - 0'3:00 3.00 CLEAN P CLEAN Con't to POOH & stand back 2 7/8" tubiing. UD mule shoe. 03:00 - 04:30' 1.50 CLEAN P CLEAN Clear & clean rig floor. NID bell nipple. Install shooting flange on annular. 04:30 - 06:00 1.50 PERFOB N WAIT OTHCMP Wait on Schlumberger (Crew getting proper rest before starting our job) perforators. Clean & maintain rig. 06:00' - 0'7:30 1.50 PERFOB N WAIT OTHCMP Maintaine Rig. SWS arrive on Location at 07:30 hrs. Printed: 6/27/2005 11: 14:50 AM ') -) BPEXPLORATION Operations Suml11aryReport:,_ Page 2 öf 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-28 MPL-28 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/17/2005 Rig Release: 6/21/2005 Rig Number: 4ES Spud Date: 4/6/1998 End: Date From - To Hours Task Code NPT Phase Description of Opera.tions 6/19/2005 07:30 - 09:00 1.50 PERFOB P OTHCMP Spot SWS E-Line Unit. Bring equipment into Pipe Shed and up on Floor. PJSM with All. 09:00 - 13:30 4.50 PERFOB P OTHCMP Continue with Rig-Up. Install BOP, Lubricator sections, and Pack-off. Attempted two times to get a pressure test. No-Joy. Rig-down Pack-off. Cut cable. Run cable through Grease Injector Head. Re-head cable. Pick-up Grease Injector. Pressure test to 500 psi. Good test. 13:30 - 14:00 0.50 PERFOB P OTHCMP Arm and pick-up Gun #1 14:00 - 19:30 5.50 PERFOB P OTHCMP RIH with Gun #1 (20'). Tie into Perforating Record Log dated: 02/02/1999. Log Gun #1 into place with top shot at 12,494' - 12,514'. Fire Gun. Good. Log off. POOH. All shots fires. Pick-up Gun #2 (10'). RIH. Log Tie-in pass. Log Gun #2 into place with top shot at 12,484' - 12,494'. Fire gun. Good. Log off. POOH. 19:30 - 20:00 0.50 PERFOB P OTHCMP LID gun, all shots fired. Re-dress firing head. M/U guns for run #3. 20:00 - 22:30 2.50 PERFOB P OTHCMP RIH & correlate depth. perforate 12436-12456'. 6 spf. POOH & inspect guns. All shots fired. total 120 shots. LId guns. 22:30 - 00:00 1.50 PERFOB P OTHCMP RID perforating equip. N/D shooting flange. N/U flow nipple. 6/20/2005 00:00 - 02:00 2.00 RUNCOMP RUNCMP R/U to run ESP completion. Load pipe shed. Spot in spooling unit. Load in reel. 02:00 - 05:00 3.00 RUNCOMP RUNCMP P/U, M/U & service ESP. Plug in electrical cable & test same. 05:00 - 06:00 1.00 RUNCOMP RUNCMP RIH w/2 7/8" ESP completion. Pump thru ESP & test every 2000'. 06:00 - 10:30 4.50 RUNCOMP RUNCMP Continue TIH with ESP Assembly and 2 7/8" Tubing. RIH wi 83 stands. (7958') 10:30 - 16:00 5.50 RUNCOMP RUNCMP Pull empty cable from Spooling Unit. Load next cable spool. Splice in second cable reel. 16:00 - 18:30 2.50 RUNCOMP RUNCMP Continue RIH with ESP Assembly and 2 7/8" Tubing. Pump thru ESP & test every 2000'. 18:30 - 23:00 4.50 RUNCOMP RUNCMP P/U landing jt & hanger. Install penetrator. Make field splice in cable. Plug in & test. 23:00 - 00:00 1.00 RUNCOMP RUNCMP Land completion. RILDS. UD landing jt. Set TWC. 6/21 12005 00:00 - 01 :00 1.00 BOPSUR P RUNCMP NID BOPE. 01 :00 - 02:00 1.00 WHSUR P RUNCMP N/U tree & adapterflange. Test void & tree to 5000 psi, Ok. 02:00 - 03:00 1.00 WHSUR P RUNCMP P/U lubricator. Pull TWC. Install BPV. UD lubricator. Clean cellar, Secure well. RELEASE RIG @ 0300 hrs. 03:00 - 06:00 3.00 RIGD P POST RDMO to MPL-25. Printed: 6/27/2005 11: 14:50 AM ) ,) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 4. Current Well Class: Development IX) Stratigraphic D 9. Well Name and Number: MPL-28A 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk River Oil Pool Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0.2 265 380 0.2 262 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 RepairWellD PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 49.90 8. Property Designation: ADL-355023 11. Present Well Condition Summary: Total Depth measured 12852 feet true vertical 7315.6 feet Plugs (measured) Effective Depth measured 12769 feet Junk (measured) true vertical 7236.9 feet Casing Conductor Production Surface Length 80 12822 7146 MD 32 112 30 - 12852 31 - 7177 Size 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation depth: Measured depth: 12458 - 12478 True vertical depth: 6944.78 - 6963.47 Tubing ( size, grade, and measured depth): 2-7/8" 6.5# L-80 @ 28 13 Prior to well operation: Subsequent to operation: Oil-Bbl 420 430 Stimulate I!J WaiverO OtherD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 198-2470 6. API Number 50-029-22859-01-00 Exploratory 0 Service 0 None None TVD Burst Collapse 32.0 - 112.0 1490 470 30.0 - 7315.6 7240 5410 31.0 - 4471.5 5750 3090 ~~C 4~.I'Æ . J41\t I ;IV~D lJ I)¡¡ & G ¿005 qs~ 12354 41!Ch, O/JJ: c: l1fðDe (J111tt¡I,'ltl¡i'¡ ¡"l Tubing Pressure 323 318 Copies of Logs and Surveys run- Daily Report of Well Operations - ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil [!] Gas D 14. Attachments: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron .I)1~ C~ Signature DevelopmentŒ] Service D WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Title Production Technical Assistant Phone 564-4657 Date 1/10/05 RBDMS BFL JAN J 5 2nDS SCANNED FEB 0 2005 Form 1 0-404 Revised 4/2004 ÁJ \1~S ) ) MPL-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~.~.~ 11/17/04 TI0=320/380/440 PICKLE ACID TREATMENT PUMPED 10 BBLS OF 7.5% ACID 14 BBLS METH 39 BBLS CRUDE TI0=300/350/400. RETURN WELL TO PRODUCTION AND WILL DO MATRIX ACID JOB TOMORROW. 11/18/04 LRS LOADED THE IA WITH 235 BBLS OF DEAD CRUDE. PUMPED AT 2 BPM AT 950 PSI. RDMO. . SCHLUMBERGER MIRU AND PUMPED ACID TREATMENT DOWN TUBING. PUMPED 50 BBLS OF 10% DAD ACID FOLLOWED BY 80 BBLS OF 2% KCL WATER. PUMPED ALL FLUIDS AT 1.3 BPM AT 2900 PSI. BBLS 274 50 80 10 14 428 FLUIDS PUMPED Crude 10% Dad Acid 2% KCL 7.50/0 Dad Acid Methanal TOTAL Page 1 ~ 2-9/16" - 5M FMC ) Wellhead: 11" 5M FMC Gen 5 w/FMC Tbg. Hng., Threads top and bottom, 4" CIW "H" BPV profile, 20" 91.1 ppf, H-40 9-5/8" Howco 'ES' Cementer (drift ID = 8.835", cap. = .0758 bpf) 9-5/8", 40#/ft., L-80 BTC KOP@ 200Q~ Max. HOlE:! J\nglø . = 77.7 deg.@6250' Hole Angle TruPerfs.=21 qegrees 2-7/86.5þpf,L-808 rd. tbg. (driftlD = 2.34T',c8p= 0;00592 bpf) 7" 26 ppf,L-80,Hydril 563 casing (driftlD = 6,151", cap. == 0.0383bpf) The original wellbore has been sidetracked. Stimulation Summary: Kuparuk "A" sand: 45,226# of 16/20 AEA Chemflow inhibitor impregnated proppant + 135,213# of 16/20 Carbolite, Perforation Summary Ref. log: CDR dated 1/2/99 "Marked line log was unobtainable due to hole angle" Size SPF Interval (MD) (TVD) 3-3/8 6 12458' - 12478' (6945'- 6964) SWS 41 B RDX 'bighole charges' 2 (20') Marker joints from 12-224'-12283' j MPU L-28A 0 j . = = ~ DATE REV. BY COMMENTS 5/22/98 ML Drilled and cased by Nabors 27E 1110lQq MI Wp.llhnrp. !':irtptrAr.kp.rt hv NAhnrc; ?7F ?/25/99 MDO ComDletion w/desander Nabors 4FS 1 ?/13/99 ML RWO Nabors 4FS 11/5/00 GMIi RWO Nabors 4FS ô/ôlO? IH RWP N;:!bon:; 4~S 00 = = ~ HES 27/8" XN Nipple (2.25 min ID) Pump, 151 stg. GC1700 GPMTAR 1:1 ,Discharge Head 112354;1 & Discharge PSI Sub Intake TVD Tandem Gas Separator GRSTXBARH6 Orig. ..)Elev. = 49.90' (N 27E) Orig. GL Elev. = 16.90' (N 27E) Camco 2-7/8" x 1" sidepocket KBMM GLM ~ Camco 2-7/8" x 1" I sidepocket KBMM GLM ~ Tandem Seal Section, GSB3DBUT/L TILH6PFS Motor, 150 HP, 2210 volt, 39 amp, Model- KME-1 Phoenix MultiSensor w/6 fin Centralizer 7" Float Collar 7" Float Shoe 112769' I 112852'1 WELLL-28a MILNE POINT UNIT API No. 50-0.?9-??541 BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '1. Operations Performed':'' ~' 'ope~atio'n 'shutdown''~ stimul;t; ~ Plugging r"! Perforate I~ Pull Tubing !"1 Alter Casing I~1 Repair Well I~1 Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3680' NSL, 5196' WEL, SEC. 08, T13N, R10E, UM At top of productive interval 1540' NSL, 2908' WEL, SEC. 01, T13N, R09E, UM 5. Type of well: I~ Development I'"! Exploratory r-I Stratigraphic r-! service At effective depth 1581' NSL, 3008' WEL, SEC. 01, T13N, R09E, UM At total depth 1592' NSL, 3034' WEL, SEC. 01, T13N, R09E, UM , , , , ,, , , , , , 12. Present well condition summary Total depth: measured 12860 feet true vertical 7323 feet Plugs (measured) Effective depth: measured 12769 feet true vertical 7237 feet Junk (measured) Casing Length Structural Conductor Surface Intermediate Production Liner Size 76' 20" 7142' 9-5/8" Change Out ESP 6. Datum Elevation (DF' or KB) KBE = 49.90' 7. Unit or Property Name Milne Point Unit 8. W~'ll Number MPL-28A 9. Permit Number / ApprovaI'' No. 198-247 10. APl Number 50-029-22859-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands Cemented MD TVD 250 sx Arcticset I (Approx.) 500 sx PF E, 900 sx G, 1300 PF E, 300 sx C 12819' 7" 250 sx Class 'G' 112' 112' 7177' 4471' 12852' 7316' Perforation depth: measured 12458' - 12478' true vertical 6945' - 6963' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12411' Packers and SSSV (type and measured depth) None 131 stirn'~'lat'i0n ~)"r'~;'nent sqUeeze ~umma~'' Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JUH 'l 8 20O2 Alaska 0il & Gas 6or, s. 60mm~ssm~. Anchorage OiI-Bbl Prior to well operation: Subsequent to operation: 15, Attachments Representative Daily Average' Production or Injection Data Gas-Mcf Water-Bbl 16. Status of well classificatiOns as: Casing Pressure O Copies of Logs and Surveys run I~1 Oil O Gas r-I Suspend~~~~U~ I~! Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~. ~_ ¢. ,¥_ ~..~.~.~,.~___._._._itle Technical Assistant Form 10-404 Rev. 06/15/88 Tubing Pressure Date ~ .~(~- l ~_' ~~,_~ Prepared By Name/Number: Sondra Stewman, 564-4750 Submit In Duplicate Legal Well Name: MPL-28 Common Well Name: MPL-28 Spud Date: 4/6/1998 Event Name: WORKOVER Start: 6/3/2002 End: 6/5/2002 Contractor Name: NABORS Rig Release: 6/5/2002 Rig Name: NABORS 4ES Rig Number: 'i!'!i'~'ii~':'~'iii~'i!~~ii'!i!ii'ii!i!i::!!:: :ii!~i:iiiii'ii~~'~iiii!~iiiii Iii!i!!i~~iiiii 'i!'"'~~":'i:: i"~:~il !i:i;i!ii!~ ~iiiili !i!!!ii:i:'~i~:~i~:':i'iiii::'~':':':il'iii!!'''~'::i''i'ii'i .................. i' .......... ' DeSCriPtion of ©Per:ations" i.' 6~3~2002 18:00 - 00:00 6.00 MOB P PRE RIG DOWN OF MPK-02 & MIRU ON MPL-28 6~4~2002 00:00 - 02:00 2.00 MOB P PRE RIG UP 02:00- 03:00 1.00 KILL P DEGOMP RIG LINES TO TRE & TIGER TANK 03:00- 03:30 0.50 KILL P DECOMP RIG LUB & PULL BPV 03:30- 04:30 1.00 KILL P DEGOMP TAKE ON SEA WATER & TEST LINES TO 3500 PSI. 04:30 - 08:30 4.00 KILL P DECOMP BULL HEAD ANNULUS INFLUX INTO FORMATION & BULL HEAD TBG. 08:30 - 10:00 1.50 WHSUR P DEGOMP SET TWO TEST & NIPPLE DN TREE 10:00- 12:00 2.00 BOPSUF P DECOMP NIPPLE UP BOP 12:00 - 13:00 1.00 BOPSUF P DEOOMP TEST BOP (BODY TEST & FUNCTION TO 250 LOW & 3500 HIGH) 13:00 - 14:00 1.00 PULL P DEOOMP MU LANDING JT. TO HANGER & PULL SAME TO SURFACE & TEST & LAY DN. 14:00- 15:00 1.00 PULL P DECOMP REVERSE ClRC INFLUX OUT OF TBG. 15:00 - 16::30 1.50 PULL P DECOMP POOH TO ESP CABLE SPLICE 16:30 - 17:00 0.50 PULL P DEGOMP CHANGE OUT ESP CABLE SPOOL 17:00 - 22:00 5.00 PULL P DECOMP CONTINUE TO POH TO ESP ASSY 22:00-00:00 2.00 PULL P DEGOMP LAY DN ESP COMPLETION 6~5~2002 00:00- 01:00 1.00 PULL P DECOMP LAY DN ESP COMPLETION 01:00- 03:30 2.50 RUNCOr~ COMP MU ESP ASSY. 03:30- 08:00 4.50 RUNCOI~I:' COMP SPLICE ESP TO MOTOR LEAD 08:00- 12:30 4.50 RUNCOI~i::' COMP RIH TO 7700' 12:30- 14:30 2.00 RUNCOI~ COMP CHANGE REELS & SPLICE ESP CABLE MID-LINE 14:30 - 17:00 2.50 RUNCOI~I:' COMP RIH WITH ESP COMPLETION TO SETTING DEPTH @12411' 17:00- 19:00 2.00 RUNCOI~/P COMP MU HANGER & MAKE EFT CONNECTOR TO CABLE & ATTACH TO HANGER & TEST SAME. 19:00- 20:00 1.00 RUNCOI~ COMP LAND HANGER 20:00- 20:30 0.50 RUNCOI~/P COMP SAFETY MEETING (BP ANHORAGE PERSONELL) 20:30 - 22:00 1.50 BOPSUIq P COMP SET TWC & TEST & ND BOP 22:00 - 23:00 1.00 WHSUR P COMP NIPPLE UP TREE & TEST TO 5000 PSI. & MAKE FINAL ESP CHECK. 23:00 - 00:00 1.00 WHSUR :' COMP RIG LUB & PULL TWC & SET BPV (RIG RELEASED @ 2359 HRS. 6/5/2002 Prin...~ .~/10/20o2 9:26:45 AM STATE OF ALASKA ALASKf _ AND GAS CONSERVATION COMI' 31ON RE'~--ORT OF SUNDRY WELL OPERATICN-$' 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other FCO- Pump 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 49.90' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3680' NSL, 5196' WEL, SEC. 08, T13N, R10E, UM MPL-28A At top of productive interval 9. Permit Number / Approval No. 198-247 1540' NSL, 2908' WEL, SEC. 01, T13N, R09E, UM 10. APl Number At effective depth 50-029-22859-01 1580' NSL, 3007' WEL, SEC. 01, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1592' NSL, 3034' WEL, SEC. 01, T13N, R09E, UM Sands 12. Present well condition summary Total depth: measured 12860 feet Plugs (measured) true vertical 7323 feet Effective depth: measured 12769 feet Junk (measured) true vertical 7237 feet Casing Length Size Cemented MD TVD Structural Conductor 76' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 7142' 9-5/8" 500 sx PF E, 900 sx G, 1300 PF 7177' 4471' Intermediate Production 12819' 7" 250 sx Class 'G' 12852' 7316' Liner Perforation depth: measured 12458' 12478' true vertical 6945' - 6963' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12400' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative 'l~aily ~tera.qe Production or Ini~cti°n Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Michael Williams ~~ ~d~ V~--------'~ Title Technical Assistant Date ....................... Form 10-404 Rev. 06/15/88 Submit In Duplica't,e,~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended E~ Abandoned [~ Service 1'2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-247 "3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22859-01 4. Location of well at surface ~ ;.;¥. ci.!~ i'13,'~ i 1 ' ~ 9. Unit or Lease Name 3680' NSL, 5196' WEL, SEC. 8, T13N, R10E, UMI r;A'm ! :l~ ' Milne Point Unit At top of productive interval ~..~/~.,.~._! i:. -- ~,-~--,44.,,~ 10. Well Number 1538' NSL, 2902' WEL, SEC. 1,T laN, ReE, UM i= ;',~,~J~l~:9 : ~ll~i;~mi MPL-28A At total depth 1 1. Field and Pool 1592' NSL, 3034' WEL, SEC. 1, T13N, R9E, Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 49.90'I ADL 388235 12. Date Spudded1/2/99 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband115' Water depth' if °fish°re 116' N°' °f cOmpleti°nsl/6/99 2/23/99 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12860 7323 FTI 12769 7237 FTI []Yes [~NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD/LWD, D&I, CDR, GR, ADN, PWD, DWOB, DTQE 23. CASlNG~ LINER AND CEMENTING RECORD CASING SE-I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO%I-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 Surface 7177' 12-1/4" 500 sx PF E, 900 sx G, 1300 PF E, 300 sx C 7" 26# L-80 33' 12852' 8-1/2" 250 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 12583' None MD TVD MD TVD 12458' - 12478' 6945' - 6964' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Frac 'A' Sands 45 M# of 16/20 Chemflow Prop. behind pipe Frac 'A' Sands 135.2 M# of 16/20 Carbolite behind pipe Freeze Protect with 12 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ~,~ [ ~ ~-~ March 15, 1999I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, appareni dips and presence of oil, gas or water. Submit core chips. · ;. , /. ?, :'~ ....... !:, , .'-', Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. BHRZ 12098' 6613' TKUD 12266' 6766' TKUB 12382' 6874' TKUA 12430' 6919' TKA3 12438' 6926' TKA2 12456' 6943' TKA1 12483' 6968' Miluveach 12548' 7029' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the fpregoing is,,true and correct to the best of my knowledge Signed TerrieHubble ¢"~' ~ i'j~~.~.,,' t- ~ Title Technical Assistant III Date ~'"/~"(:~¢ MPL-28A 98-247 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. ~ NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM ,5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. RECEIVED Form 10-407 Rev. 07-01-80 Alaka0il&6asCo s. Progress Report Facility M Pt L Pad Well MPL-28A Rig Nabors 27E Page 1 Date 10 February 99 Date/Time 30 Dec 98 00:00-06:00 06:00-02:30 31 Dec 98 02:30-05:00 05:00-06:00 06:00-07:30 07:30-09:30 09:30-14:00 14:00-18:00 18:00-00:30 01 Jan 99 00:30-03:00 03:00-04:00 04:00-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-09:30 09:30-11:30 11:30-13:00 13:00-16:00 16:00-18:00 18:00-20:00 20:00-22:00 22:00-02:30 02 Jan 99 02:30-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-11:30 11:30-17:00 17:00-19:00 19:00-19:30 19:30-20:00 20:00-06:00 03 Jan 99 06:00-07:00 07:00-08:30 08:30-12:00 12:00-15:00 15:00-16:00 16:00-16:30 16:30-20:00 20:00-20:30 20:30-22:00 22:00-06:00 04 Jan 99 06:00-06:30 06:30-13:30 13:30-15:00 15:00-16:00 16:00-17:00 17:00-18:00 18:00-06:00 05 Jan 99 06:00-06:30 06:30-18:30 18:30-20:30 Duration 6hr 20-1/2 hr 2-1/2 hr 1 hr 1-1/2 hr 2 hr 4-1/2 hr 4 hr 6-1/2 hr 2-1/2 hr 1 hr 1-1/2 hr 1/2 hr 1 hr 1 hr 1 hr 1/2 hr 2 hr 1-1/2 hr 3 hr 2hr 2hr 2hr 4-1/2 hr 3-1/2 hr 1/2 hr 1 hr 2-1/2 hr 1-1/2 hr 5-1/2 hr 2 hr 1/2 hr 1/2 hr 10hr 1 hr 1-1/2 hr 3-1/2 hr 3hr 1 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 8 hr 1/2 hr 7hr 1-1/2 hr lhr lhr lhr 12hr 1/2 hr 12hr 2 hr Activity Rig moved 25.00 % Rig moved 100.00 % Rig moved 100.00 % Tested Casing Tested Casing Rigged down Xmas tree primary components Rigged up BOP stack Tested BOP stack R.I.H. to 1780.0 ft R.I.H. to 6685.0 ft Circulated at 6685.0 ft Tested Casing Pulled out of hole to 6000.0 ft Pulled out of hole to 3000.0 ft Serviced Top drive Pulled out of hole to 551.0 ft Pulled BHA Tested Casing Serviced Swivel Ran Drillpipe in stands to 6650.0 ft Tested Casing Pulled out of hole to 0.0 ft Made up BHA no. 2 R.I.H. to 6685.0 ft Drilled cement to 6685.0 ft Drilled cement to 7250.0 ft Circulated at 7090.0 ft Drilled cement to 7250.0 ft Circulated at 7250.0 ft Drilled to 7330.0 ft Circulated at 7330.0 ft Performed formation integrity test Circulated at 7330.0 ft Drilled to 8300.0 ft Serviced Top drive Circulated at 8325.0 ft Drilled to 8732.0 ft Drilled to 8832.0 ft Circulated at 8832.0 ft Pulled out of hole to 7185.0 ft Circulated at 8832.0 ft R.I.H. to 8832.0 ft Circulated at 8832.0 ft Drilled to 9829.0 ft Held safety meeting Drilled to 10676.0 ft Circulated at 10676.0 ft Pulled out of hole to 8700.0 fi R.I.H. to 10676.0 ft Held safety meeting Drilled to 11516.0 ft Held safety meeting Drilled to 12270.0 ft Circulated at 12270.0 ft RECEIVED Facility M Pt L Pad Progress Report Well MPL-28A Rig Nabors 27E Page Date 2 10 February 99 Date/Time 06 Jan 99 07 Jan 99 08 Jan 99 09 Jan 99 20:30-21:30 21:30-22:00 22:00-23:00 23:00-06:00 06:00-06:30 06:30-08:00 08:00-10:30 10:30-11:00 11:00-13:00 13:00-18:00 18:00-23:00 23:00-00:30 00:30-01:00 01:00-03:00 03:00-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-15:00 15:00-19:30 19:30-22:00 22:00-00:00 00:00-01:00 01:00-06:00 06:00-11:00 11:00-12:00 12:00-18:00 18:00-06:00 06:00-09:00 09:00-15:00 15:00-18:00 18:00-20:30 20:30-21:30 21:30-22:30 Duration 1 hr 1/2 hr 1 hr 7 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 2 hr 5 hr 5 hr 1-1/2 hr 1/2 hr 2 hr 3 hr 1/2 hr 2hr 1/2 hr 6 hr 4-1/2 hr 2-1/2 hr 2 hr 1 hr 5 hr 5hr 1 hr 6 hr 12hr 3 hr 6hr 3 hr 2-1/2 hr lhr 1 hr Activity Pulled out of hole to 10395.0 ft R.I.H. to 12270.0 fl Circulated at 12270.0 ft Drilled to 12860.0 ft Held safety meeting Circulated at 12860.0 ft Pulled out of hole to 7177.0 ft Serviced Top drive R.I.H. to 12860.0 fir Circulated at 12860.0 ft Pulled out of hole to 630.0 fl Pulled BHA Retrieved Wear bushing Rigged up Handling equipment Ran Casing to 2500.0 fir (7in OD) Held safety meeting Ran Casing to 7140.0 fir (7in OD) Circulated at 7140.0 ft Ran Casing to 12852.0 ft (7in OD) Circulated at 12852.0 ft Mixed and pumped slurry - 51.000 bbl Rigged down Handling equipment Installed Accessories Laid down 4700.0 ft of 5in OD drill pipe Laid down 9000.0 ft of 5in OD drill pipe Tested Casing Ran Tubing to 0.0 ft (4-1/2in OD) Ran Tubing to 10600.0 fl (4-1/2in OD) Ran Tubing to 11961.0 fl (4-1/2in OD) Removed BOP stack Installed Xmas tree Circulated at 11961.0 fir Freeze protect well - 75.000 bbl of Diesel Freeze protect well - 65.000 bbl of Base oil RECEIVED '-::".':. 15 1999 i'.: i'~ MILNE POINT, ALASKA TO: FROM: WELL# Main Category: Sub Category: Operation Date: Bill Hill Matthew Linder L-28a E-line Initial perforation 2/2/99 I II Objective: Schlumberger will perform initial perforating after aborted GR/marked line survey. Operation' Rig up SWS and HB&R. Pressure test lubricator to 3000 psi. RIH w/GR/CCL and 3- 3/8"x 10' perf gun to 4680' where tools quit falling. Worked tools to 6000' before bringing on HB&R. Pushed tools in hole at 1 bpm, 250 psi circulating down the tubing taking returns up the annulus to a tiger tank. After pumping 18 bbls of diesel and rolling tools to 7500', shut down pumping and rolled tools to PBTD. Tagged TD and ran correlation strip to 11990' keeping tools from entering frac string. Made + 60' depth correction. TD is 12735' MD. Logged perf gun into position. Eight feet from CCL to top shot. CCL depth is 12460'. Perforated casing from 12468'-12478'. Good shot. Log off and POOH. Note: while correlating perf guns, the tubing and annulus were u-tubed so to refreeze protect the casing. Laid down GR, spent perf gun and picked up last 10' gun. RIH to 5600' started pumping down tubing and circulating up annulus to tank. Once gun reached 7600' after pumping 20 bbls of diesel, shut down pumping and rolled gun to bottom. Tied into short joints. Logged gun into position, 6' from CCL to top shot. CCL depth is 12452'. Perforated 12458'-12468'. Good indication of gun firing. Log off shot. POOH. Rig down SWS Note: while correlating perf guns, the tubing and annulus were u-tubed so to refreeze protect the casing. To ensure a good annulus freeze protection HB&R began pumping diesel down annulus. After 22 bbls away casing pressure was 3000 psi. Shut down pumping. Pressure slowly falling off. Formation looks pretty tight. Conclusion: Perforated Kuparuk A-2 intervals from 12458'-12478' using 3-3/8", 6 spf, 60 degree phasing using 41B UP RDX charges. Reference log is CDRl/2-1/6/99 Field copy. After perforating HB&R had trouble establishing an injection rate. Casing pressured up to 3000 psi and slowly bled off after 22 bbls of bullheading. SIWHP:360 IA: 360 OA: Note all depths are slickline measurement unless noted. Diesel Used I 60 bbls I Methanol Used I RECEIVED 1 5 1999 Oit & Cons. Commission Anchorage BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Bill Hill FROM: J. Spearman DATE: 02-13-99 RE: L-28A DATA FRAC AND FRAC SERVICE CO'S.: Dowell and Peak An initial injectivity test was performed using 100 bbls of XL YF140. Rate was pickup to 30 bpm as surface treating pressure allowed. NWFP was around the 573 psi range so the scour treatment was deleted from the schedule. Next, a 200 bbl data frac was pumped. The XL fluid was displaced at 10 bpm to within 10 bbls of the top perf. Rate was lowered to 4 bpm until XL was at the perforations. Rate was brought up with a surface limitations of 6500 psi. The XL fluid was thick in the tubing and required about 6 mins until 30 bpm was achieved. The NWFP was 411 psi. The Nolte Smith plot showed high Pnet for the first 4 minutes indicating either Iow fracture height or higher than anticipated modulus. After the 4 minute mark, net pressure fell indicating radial growth into a possible lower stress zone. The data frac was analysed on the slope by Mike Martins with DS. The data frac efficiency possibilities ranged anywhere from 35% to 50%. With the spread in efficiency and radial growth determined, the frac was designed to ensure proppant was entering the perforations after the height growth occurred. With surface pressure limitation being reach during the data frac, the decision was made to increase surface treating limitation to 7400 psi P/T lines to 8400 psi.. The high surface treating pressure where related to slow pump rates developing high XL viscosity. The frac was pumped to completion at 30 bpm. DS sand chief was having problems delivering sand near the end of the treatment, therefore rate was dropped to get ppg up. The problem was not correct and flush was called. A total of 189,000 lbs of proppant was pumped with 180,000 lbs behind pipe. The frac was flush 45 bbls short to ensure the high concentration of ppg was near wellbore. No tip screen out was observed (and the additional 20,000 lbs of proppant would not of induced a TSO). 04/15/99 8:37 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL RECEIVED ~,?~ 1 5 '{999 ~aska Oil & Gas Cons. Com~n Anchorage JOB SUMMARY INJECTIVITY TEST 30 100 30 2880 2307 573 0.75 DATA FRAC 200 202 14:06 2731 2320 411 0.74 FRAC Flush 189,108 48,000 141,108 180,~9 8669 NO : p~i: ::ii ......................................... 376 12,157 4253 2472 152 11.2% N/A no Operational problems After coming out of -55 degree weather, we had a few froze up hoses. The problems were dealt with very little delay. Comments Weather for the day was very little wind and -18 F degrees. RECEIVED L?~ '! 5 't999 Alaska Oil & Gas Cons. Commission Anchorage Facility M Pt L Pad Progress Report Well MPL-28A Rig ~ I~m q~ Page Date 1 12 April 99 Date/Time 18 Feb 99 19 Feb 99 20 Feb 99 21 Feb 99 22 Feb 99 23 Feb 99 00:00-06:00 06:00-10:00 10:00-14:00 14:00-15:30 15:30-17:00 17:00-21:00 21:00-22:30 22:30-23:30 23:30-03:00 03:00-06:00 06:00-07:00 07:00-19:00 19:00-21:30 21:30-06:00 06:00-13:00 13:00-16:30 16:30-19:00 19:00-22:00 22:00-02:00 02:00-05:30 05:30-06:00 06:00-08:00 08:00-10:30 10:30-16:30 16:30-17:30 17:30-21:30 21:30-01:30 01:30-02:30 02:30-06:00 06:00-14:30 14:30-18:00 18:00-22:00 22:00-03:30 03:30-06:00 06:00-06:30 06:30-08:30 08:30-13:00 13:00-14:00 14:00-15:00 15:00-16:00 16:00-17:00 17:00-19:00 19:00-20:00 Duration 6hr 4hr 4hr 1-1/2 hr 1-1/2 hr 4hr 1-1/2 hr lhr 3-1/2 hr 3 hr 1 hr 12hr 2-1/2 hr 8-1/2 hr 7hr 3-1/2 hr 2-1/2 hr 3 hr 4 hr 3-1/2 hr 1/2 hr 2hr 2-1/2 hr 6hr lhr 4hr 4hr lhr 3-1/2 hr 8-1/2 hr 3-1/2 hr 4 hr 5-1/2 hr 2-1/2 hr 1/2 hr 2hr 4-1/2 hr lhr lhr lhr lhr 2hr 1 hr Activity Rig moved 100.00 % Rigged up High pressure lines Circulated closed in well at 12852.0 fl Removed Xmas tree Rigged up BOP stack Tested BOP stack Retrieved Hanger plug Retrieved Tubing hanger Reverse circulated at 12457.0 ft Reverse circulated at 12715.0 ft Reverse circulated at 12715.0 fl Laid down 12715.0 fl of Tubing Rigged up sub-surface equipment - ESP Ran Tubing to 5260.0 ft (2-7/8in OD) Ran Tubing to 6175.0 fl (2-7/8in OD) Pulled Tubing in stands to 220.0 ft Rigged down sub-surface equipment - ESP Ran Tubing in stands to 5898.0 ft Pulled Tubing in stands to 0.0 ft Ran Tubing in stands to 5198.0 fl Reverse circulated at 5198.0 ft Reverse circulated at 5983.0 ft Mixed and pumped 30.000 bbl of treatment Reverse circulated at 6485.0 ft Ran Tubing to 7576.0 fl (2-7/8in OD) Reverse circulated at 7576.0 fl Ran Tubing to 12765.0 fl (2-7/8in OD) Laid down 398.0 fl of Tubing Reverse circulated at 12358.0 ft Reverse circulated at 12358.0 fl Pulled Tubing in stands to 100.0 fl Installed ESP Pulled Tubing in stands to 910850.0 ft Serviced ESP Held safety meeting Pulled Tubing in stands to 12334.0 ft Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Tested Xmas tree Removed Hanger plug Freeze protect well - 12.000 bbl of Diesel Installed Hanger plug RECEIVED /:.27 15 1999 Alaska Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field ............ ~ ....... : Milne Point Unit~ Well ..................... : MPL-28A API number ............... : 50-029-22859-01 Engineer ................. : J. Rathert Rig: ..................... : Nabors 27E 'iState: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference - Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 16.90 ft KB above permanent ....... : 49.90 ft DF above permanent ....... : 49.90 ft Vertical section origin-- Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point-- Latitude (+N/S-) ......... : -999.25 ft j/Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 289.49 degrees 6-Jan-99 10:54:45 Page RECEIVED JAN I Z {999 o ,QPXA PDC Spud date ................ : 02-Jan-99 Last survey date ......... : 06-Jan-99 Total accepted surveys...: 184 MD of first survey ....... : 0.00 ft MD of last survey ........ : 12860.00 ft Geomagnetic data Magnetic model ........... : BGGM version 1998 Magnetic date ............ : 31-Dec-1998 Magnetic field strength..: 1145.75 HCNT Magnetic dec (+E/W-) ..... : 27.36 degrees Magnetic dip ............. : 80.75 degrees MWD survey Reference Criteria Reference G .............. : 1003.00 mGal Reference H .............. : 1145.75 HCNT Reference Dip..' .......... : 80.75 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections ....... Magnetic dec (+E/W-) ..... : 27.36 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.36 degrees (Total az corr = magnetic dec - grid conv) Sag hpplied (Y/N) ........ : No degree: 0.00 [ (c)1999 Anadrill IDEAL ID5 iA 12RI -- -- RECEIVED 15 1999 Alaska Oil & Gas Cons. Commission. Anchorage ANADRILL SCHLUMBERGER Survey Report 6-Jan-99 10:54:45 Page 2 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 ,0.00 0.0 2 100.00 0.52 42.5 3 200.00 1.06 50.8 4 300.00 0.90 37.1 5 400.00 1.05 16.0 6 500.00 1.62 331.6 7 600.00 1.93 325.1 8 700.00 2.64 307.8 9 800.00 2.68 310.6 10 900.00 3.91 305.6 11 1000.00 5.19 291.4 12 1100.00 5.82 291.5 13 1200.00 6.17 289.6 14 1300.00 6.84 288.8 15 1400.00 6.98 290.9 16 1500.00 7.07 290.3 17 1600.00 7.32 289.5 18 1700.00 7.39 289.7 19 1800.00 7.48 288.2 20 1900.00 7.69 285.3 21 2000.00 9.73 292.2 22 2100.00 12.15 291.3 23 2200.00 15.35 290.9 24 2300.00 17.64 290.8 25 2350.00 19.22 290.6 26 2400.00 20.60 290.8 27 2450.00 '21.80 291.1 28 2500.00 22.87 291.8 29 2550.00 24.48 292.4 30 2600.00 25.40 292.4 [(c)1999 Anadrill IDEAL ID5 IA 12RI -- -- 0.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) ' 0.00 100.00 199.99 299.97 399.96 499.93 599.89 699.81 799.70 899.53 999.22 1098.76 1198.21 1297.57 1396.84 1496.09 1595.30 1694.48 1793.64 1892.76 1991.61 2089.78 2186.90 2282.78 2330.22 2377.23 2423.84 2470.09 2515.88 2561.22 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 0,00 -0.18 -0.84 -1.55 -1.74 -0.63 1.79 5.34 9.71 15.17 22.96 32.55 42.99 54.32 66.35 78.58 91.10 103.90 116.84 130.02 145.14 164.10 187.85 216.24 232.04 0.00 0.00 0.33 0.31 1.25 1.33 2.46 2.52 3.97 3.25 6.10 2.83 8.72 1.19 11.51 -1.59 14.4'5 -5.19 17.95 -9.73 21.59 -16.72 25.10 -25.65 28.76 -35.43 32.48 -46.13 36.57 -57.44 40.87 -68.89 45.13 -80.67 49.42 -92.73 53.63 -104.96 57.42 -117.60 62.38 -131.88 69.40 -149.51 77.95 -171.69 88.05 -198.22 93.64 -213.01 ., 249.06 99.66 -228.93 267.14 106.12 -245.82 286.13 113.07 -263.50 306.18 120.63 -282.10 327.24 128.66 -301.59 0.00 0.00 0.00 0.45 42.50 0.52 1.83 46.69 0.55 3.53 45.64 0.28 5.13 39.26 0.39 6.72 24.88 1.14 8.80 7.78 0.37 11.62 352.13 0.98 15.35 340.25 0.14 20.42 331.53 1.26 27.30 322.24 1.70 35.88 314.38 0.63 45.63 309.07 0.40 56.41 305.15 0.68 68.09 302.48 0.29 80.10 300.68 0.12 92.43 299.23 0.27 105.08 298.06 0.07 117.87 297.06 0.21 130.87 296.03 0.44 145.89 295.32 2.29 164.83 294.90 2.43 188.55 294.42 3.20 216.90 293.95 2.29 232.68 293.73 3.16 249.68 293.52 2.76 267.75 293.35 2.41 286.74 293.22 2.21 306.81 293.15 3.26 327.89 293.10 1.84 TIP GYRO GYRO GYRO GYRO GYRO' GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO RECEIVED. ] fi 1999 A aska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2650.00 26.43 292.3 32 2700.00 27.74 292.3 33 2750.00 28.47 292.3 34 2800 . 00 30.14 292.9 35 2850.00 31.25 293.1 36 2900.00 32.58 293.1 37 2950.00 33.93 293.5 38 3000.00 35.07 293.7 39 3050.00 36.22 293.7 40 3100.00 37.59 294.0 41 3150.00 38.67 293.4 42 3200.00 40.17 292.6 43 3250.00 41.07 292.4 44 3300.00 42.22 292.2 45 3350.00 43.87 292.6 46 3400.00 44.82 292.5 47 3450.00 46.36 292.4 48 3500.00 47.34 292.4 '49 3550.00 48.33 292.5 50 3600.00 49.59 292.7 51 3650.00 51.20 292.5 52 3700.00 52.47 292.4 53 3750.00 54.06 292.7 54 3800.00 54.95 292.7 55 3850.00 55.99 293.0 56 3900.00 56.90 293.0 57 3950.00 58.08 293.2 58 4000.00 58.90 293.3 59 4050.00 59.87 293.5 60 4100.00 61.15 293.5 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 2606.19 2650.71 2694.81 2738.41 2781.40 2823.84 2865.66 2906.86 2947.49 2987.47 3026.80 3065.43 3103.38 3140.74 3177.28 3213.04 3248.03 3282.22 3315.79 3348.61 3380.49 3411.38 3441.29 3470.32 3498.66 3526.30 3553.17 3579.30 3604.76 3629.38 6-Jan-99 10:54:45 Page 3 of 8 Vertical Displ Displ Total At DLS section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (deg) 100f) 349.06 371.80 395.33 419.76 445.24 471.62 498.98 527.22 556.28 586.22 617.01 648.70 681.20 714.39 748.47 783.37 819.04 855.47 892.48 930.14 968.60 1007.86 1047.87 1088.52 1129.64 136 145 154 163 173 .97 .61 .55 .96 .93 -321.80 -342.87 -364.66 -387.25 -410.74 184 195 206 218 230 .3O .15 .48 .20 .34 349.74 293.06 2.06 372.50 293.01 2.62 396.06 292.97 1.46 420.53 292.95 3.39 446.05 292.95 2.23 242 255 267 280 293 .74 .15 .60 .21 .22 Srvy tool type 306 320 334 348 362 .62 .26 .16 .31 .80 GYRO GYRO GYRO GYRO GYRO 377 392 407 423 439 .61 .62 .98 .69 .69 -435.06 472.48 292.96 2.66 GYRO -460.24 499.90 292.98 2.74 GYRO -486.19 528.22 293.01 2.29 GYRO -512.87 557.35 293.05 2.30 GYRO -540.33 587.38 293.09 2.76 GYRO 455 472 489 5O6 523 .97 .51 .34 .43 .78 -568.60 -597.82 -627.90 -658.64 -690.19 1171.22 1213.30 1255.84 1298.77 1342.18 618.25 293.12 2.28 649.99 293.11 3.17 682.54 293.08 1.82 715.77 293.05 2.32 749.89, 293.02 3.34 GYRO GYRO GYRO GYRO GYRO -722.47 784.84 293.00 1.91 GYRO -755.48 820.55 292.97 3.08 GYRO -789.20 857.03 292.95 1.96 GYRO -823.45 894.09 292.93 1.99 GYRO -858.27 931.80 292.91 2.54 GYRO 970.32 292.90 3.23 1009.63 292.88 2.54 1049.70 292.87 3.22 1090.41 292.87 1.78 1131.60 292.86 2.14 -893.83 -930.16 -967.17 -1004.72 -1042.68 -1081.04 -1119.82 -1158.99 -1198.48 -1238.39 GYRO GYRO GYRO GYRO GYRO 1173.26 292.87 1.82 GYRO 1215.43 292.88 2.38 GYRO 1258.05 292.89 1.65 GYRO 1301.08 292.91 1.97 GYRO 1344.60 292.93 2.56 GYRO Tool qual type [(c)1999 Anadrill IDEAL ID5 iA 12RI -- -- ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 61 4150.00 61.59 293.4 62 4200.00 63.31 293.5 63 4250.00 64.12 293.5 64 4300.00 65.57 293.4 65 4350.00 66.26 293.4 66 4400.00 67.65 293.2 67 4450.00 68.87 293.3 68 4500.00 69.92 293.2 69 4550.00 70.27 293.6 70 4600.00 71.11 293.8 71 4650.00 71.69 293.7 '72 4700.00 73.06 293.9 73 4750.00 73.76 293.9 74 4800.00 74.71 294.0 75 4850.00 75.02 293.9 76 4900.00 75.56 292.5 77 4950 · 00 75 · 48 292.3 78 5000.00 75.65 292.4 79 5050.00 74.76 292.0 80 5100.00 75.02 291.2 81 5150.00 74.53 291.0 82 5200.00 74.72 291.1 83 5250.00 74.19 291.2 84 5300.00 73.87 291.2 85 5350.00 74.25 291.2 86 5400.00 74.39 291.0 87 5450.00 75.32 291.0 88 5500.00 75.16 291.1 89 5550.00 75.34 291.2 90 5600.00 75.74 291.1 [(C)1999 Anadrill IDEAL ID5 iA 12RI -- -- Course length (ft) 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 3653.34 3676.46 3698.60 3719.86 3740.26 3759.83 3778.35 3795.95 3812.97 3829.50 3845.45 3860.59 3874.87 3888.45 3901.51 3914.20 3926.71 3939.17 3951.94 3964.97 3978.10 3991.36 4004.76 4018.52 4032.25 4045.76 4058.82 4071.56 4084.29 4096.78 6-Jan-99 10:54:45 Vertical Displ DisPl section +N/S- +E/W- (ft) (ft) (ft) 1385.97 1430.19 1474.91 1520.06 1565.60 541.25 -1278.65 558.89 -1319.32 576.77 -1360.43 594.78 -1401.95 612.90 -1443.84 1611.51 1657.85 1704.55 1751.45 1798.51 631.10 -1486.10 649.43 -1528.77 667.91 -1571.77 686.58 -1614.91 705.55 -1658.12 1845.77 1893.29 1941.06 1989.03 2037.15 2085.41 2133.76 2182.12 2230.41 2278.65 724.63 -1701.50 743.86 -1745.10 763.28 -1788.91 782.81 -1832.88 802.40 -1876.99 821.45 -1921.44 839.90 -1966.2'0 858.31 -2010.98 876.58 -2055.74 894.35 -2100.62 2326.87 2375.07 2423.22 2471.27 2519.32 911.72 -2145.63 929.03 -2190.63 946.41 -2235.55 963.80 -2280.37 981.18 -2325.19 .. 2567.44 2615.69 2664.02 2712.35 2760.75 998.51 -2370.10 1015.81 -2415.16 1033.18 -2460.28 1050.62 -2505.38 1068.09 -2550.53 Page 4 of 8 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) I00f) type type 1388.49 292.94 0.90 GYRO 1432.81 292.96 3.44 GYRO 1477.64 292.97 1.62 GYRO 1522.90 292.99 2.91 GYRO 1568.54 293.00 1.38 GYRO 1614.55 293.01 2.80 GYRO 1660.99 293.02 2.45 GYRO 1707.79 293.02 2.11 GYRO 1754.81 293.03 1.03 GYRO 1801.99 293.05 1.72 GYRO 1849.37 293.07 1.18 GYRO 1897.02 293.09 2.77 GYRO 1944.94 293.11 1.40 GYRO 1993.05 293.13 1.91 GYRO 2041.31 293.15 0.65 GYRO 2089.67 293.15 2.92 GYRO 2138.08 293.13 0.42 GYRO 2186.49 293.11 0.39 GYRO 2234.83 293.09 1.94 GYRO 2283.08 293.06 1.63 GYRO 2331.30 293.02 1.05 GYRO 2379.48 292.98 0.43 GYRO 2427.63 292.95 1.08 GYRO 2475.68 292.91 0.64 GYRO 2523.74 292.88 0.76 GYRO 2571.85 2620.09 2668.42 2716.75 2765.15 292.85 0.48 GYRO 292.81 1.86 GYRO 292.78 0.37 GYRO 292.75 0.41 GYRO 292.72 0.82 GYRO REC.'.EWED /_ 1,5 1999 Oil & Gas Oons. Oommi 'mn ANADRILL SCHLUMBERGER Survey Report 6-Jan-99 10:54:45 Page 5 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 5650.00 75.48 291.1 , 92 5700.00 75.91 291.1 93 5750.00 75.66 291.1 94 5800.00 75.26 291.2 95 5850.00 75.65 291.2 96 5900.00 75.64 291.2 97 5950.00 76.24 291.2 98 6000.00 76.54 291.2 99 6050.00 76.57 291.2 100 6100.00 77.20 291.3 101 6150.00 77.23 291.2 102 6200.00 77.59 291.4 103 6250.00 77.68 291.4 104 6300.00 76.15 291.0 105 6350.00 76.30 291.0 106 6400.00 76.08 291.0 107 6450.00 76.65 291.1 108 6500.00 76.41 291.0 109 6550.00 76.16 290.9 110 6600.00 76.08 290.9 111 6650.00 75.89 290.8 112 6700.00 76.30 290.7 113 6750.00 76.05 290.7 114 6800.00 76.17 290.7 115 6850.00 75.99 290.4 116 6900.00 75.90 290.3 117 6950.00 76.48 290.2 118 7000.00 76.34 290.1 119 7050.00 76.36 289.9 120 7100.00 76.39 289.8 50.00 50.00 50.00 50.00 50.00' 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 4i109.20 4121.56 4133.83 4146.39 4158.94 4171.34 4183.49 4195.25 4206.88 4218.22 4229.29 4240.19 4250.89 4262.21 4274.12 4286.05 4297.84 4309.49 4321.34 4333.34 4345.45 4357.46 4369.41 4381.41 4393.44 4405.58 4417.52 4429.27 4441.07 4452.84 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 2809.16 2857.59 2906.04 2954.42 3002.79 3051.21 3099.69 3148.27 3196.87 3245.55 3294.28 3343.06 3391.87 3440.55 3489.09 3537.63 3586.21 3634.81 3683.37 3731.90 3780.39 3828.92 3877.46 3925.98 3974.51 4023.00 4071.55 4120.15 4168.74 4217.33 1085 1102 1120 1137 1155 .53 -2595.72 .97 -2640.92 .42 -2686.14 .88 -2731.28 .38 -2776.40 1172 1190 1208 1225 1243 .90 -2821.56 .44 -2866.78 .01 -2912.09 .60 -2957.43 .24 -3002.81 1260 1278 1296 1314 1331 .92 -3048.26 .64 -3093.72 .46 -3139.19 .08 -3184.60 .48 -3229.93 1348 1366 1383 1401 1418 .88 -3275.26 .33 -3320.61 .80 -3365.99 .17 -3411.35 .48 -3456.70 1435.75 1452.94 1470.10 1487.26 1504.30 _. 1521.16 1537.97 1554.71 1571.33 1587.83 -3502.03 -3547.42 -3592.84 -3638.24 -3683.69 -3729.16 -3774.72 -3820.34 -3866.00 -3911.70 2813.56 292.69 0.52 2861.99 292.67 0.86 2910.44 292.64 0.50 2958.83 292.62 0.82 3007.21 292.59 0.78 3055.63 292.57 0.02 3104.12 292.55 1.20 3152.70 292.53 0.60 3201.32 292.51 0.06 3250.00 292.49 1.27 3298.75 292.47 0.20 3347.54 292.46 0.82 3396.37 292.44 0.18 3445.06 292.42 3.16 3493.61 292.40 0.30 3542.15 292.38 0.44 3590.73 292.37 1.16 3639.34 292.35 0.52 3687.90 292.33 0.54 3736.42 292.31 0.16 3784.92 292.29 0.43 3833.44 292.27 0.84 3881.97 292.25 0.50 3930.49 292.23 0.24 3979.00 292.21 0.68 4027.48 292.19 0.26 4076.01 292.17 1.18 4124.58 292.14 0.34 4173.13 292.12 0.39 4221.69' 292.09 0.20 GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO [ (c)1999 Anadrill IDEAL ID5 iA 12RI -- -- RECEIVED ,~'.u~ 3 5 1999 AlaS~ Oil & ~as Cons. Cmm~ss'mn A~omge ANADRILL SCHLUMBERGER, Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 7150.00 ,75.83 289.7 50.00 122 7200.00 75.86 289.8 50.00 123 7250.00 75.52 289.5 50.00 124 7316.21 72.51 291.3 66.20 125 7411.11 71.24 290.5 94.90 126 7504.30 69.77 289.7 93.20 127 7597.31 69.53 290.0 93.00 128 7691.17 69.24 289.5 93.90 129 7785.44 69.29 289.0 94.20 130 7880.93 69.67 289.3 95.50 131 7975.23 69.89 288.5 132 8068.69 69.79 287.8 133 8164.21 70.05 288.3 134 8261.63 70.01 287.5 135 8352.33 69.00 288.2 94.30 93.50 95.50 97.40 90.70 136 8445.39 69.06 288.4 93.10 137 8540.46 68.82 287.7 95.10 138 8634.41 68.99 289.4 93.90 139 8727.99 68.92 288.9 93.60 140 8820.58 68.55 288.2 92.60 141 8914.78 69.04 288.7 142 9007.38 69.13 290.4 143 9102.10 69.70 291.3 144 9197.02 69.88 291.4 145 9291.42 69.95 291.3 146 9384.76 69.92 290.7 147 9477 . 97 69.78 291 · 0 148 9573.89 69.31 289.4 149 9668.17 69.00 289.2 150 9762.32 69.04 288 · 7 94.20 92.60 94.70 94.90 94.40 93.40 93.20 95.90 94.30 94.10 TVD depth (ft) ~464.85 4477.07 4489.43 4507.66 4537.18 4568.29 4600.63 4633.69 4667.04 4700.52 4733.11 4765.33 4798.12 4831.39 4863.14 4896.46 4930.64 4964.44 4998.05 5031.63 5065.70 5098.76 5132.06 5164.84 5197.26 522.9.31 5261.41 5294.93 5328.48 5362.18 6-Jan-99 10:54:45 Page 6 of 8 Vertical Displ Displ Total At DLS section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (deg) 100f) 4265.87 4314.35 4362.80 4426.42 4516.58 4604.43 4691.62 4779.51 4867.60 4957.04 5045.53 5133.27 5222.94 5314.45 5399.37 5486.28 5575.00 5662.60 5749.95 5836.23 1604.23 -3957.39 1620.61 -4003.02 1636.91 -4048.64 1659.08 -4108.29 1691.25 -4192.54 1721.45 -4275.04 1751.06 -4357.06 1780.76 -4439.77 1809.80 -4522.94 1839.14 -4607.44 1867.80 -4691.15 1895.14 -4774.56 1922.94 -4859.84 1951.07 -4946.95 1977.11 -5027.82 2004.41 -5110.35 2031.91 -5194.J3 2059.78 -5277.78 2088.43 -5360.31 2115.89 -5442.12 2143.68 -5525.42 2172.63 -5606.93 2204.18 -5689.78 2236.60 -5772.72 2268.88 -5855.30 2300.32 -5937.20 2331.46 -6018.97 2362.49 -6103.29 2391.62 -6186.47 2420.15 -6269.57 5924.04 6010.53 6099.16 6188.17 6276.78 4270.18 4318.63 4367.03 4430.64 4520.81 4608.62 4695.76 4783.58 4871.59 4960.94 5049.32 5136.92 5226.44 5317.80 5402.58 5489.39 5577.98 5665.48 5752.78 5838.97 5926.69 6013.15 6101.80 6190.86 6279.52 6367.25 6454.74 6544.58 6632.66 6720.46 6364.48 6451.95 6541.80 6629.92 6717.78 Srvy Tool tool qual type type 292.07 1.14 GYRO - 292.04 0.20 GYRO - 292.01 0.89 GYRO - 291.99 5.24 MWD 6-axis 291.97 1.56 MWD 6-axis 291.93 291.89 291.86 291.81 291.76 291.71 291.65 291.59 291.52 291.47 291.42 291.36 291.32 291.29 291.25 291.20 291.18 291.18 291.18 291.18 1.77 0.40 0.59 0.50 0.49 0.83 0 .'71 0.56 0.77 1.33 0.21 0.73 1.70 0.50 0.81 0.72 1.72 1.07 0.21 0.12 0.60 0.34 1.64 0.38 0.50 291.18 291.17 291.16 291.14 291.11 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD "6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis [(c)1999 Anadrill IDEAL ID5 iA 12R] -- -- ANADRILL SCHLUMBERGER Survey Report 6-Jan-99 10:54:45 Page 7 of 8 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 151 9857.41 ~9.35 288.9 152 9951.85 69.03 289.5 153 10044.46 68.72 289.3 154 10138.09 68.74 289.1 155 10232.90 68.66 289.0 156 10327.42 68.77 288.9 157 10421.02 69.18 288.5 158 10516.65 69.07 289.6 159 10609.35 68.80 291.1 160 10699.46 69.12 290.8 161 10792.86 67.54 292.0 162 10887.07 64.57 293.4 163 10982.26 61.34 293.5 164 11074.78 57.84 293.2 165 11167.99 54.51 292.8 166 11263.86 51.18 291.1 167 11356.87 48.37 291.3 168 11451.57 45.62 291.0 169 11543.21 43.16 292.1 170 11637.85 40.07 291.9 171 11732.53 37.30 291.9 172 11826.32 35.10 291.5 173 11920.60 33.09 292.5 174 12014.25 30.78 292.2 175 12109.76 26.77 292.5 176 12203.45 22.62 292.3 177 12295.68 21.95 291.1 178 12390.36 21.31 291.1 179 12485.67 20.75 290.6 180 12579.78 20.53 292.1 [(C)1999 Anadrill IDEAL ID5 iA 12R] -- -- Course length (ft) 95.10 94.40 92.70 93.60 94.80 94.50 93.60 95.60 92.80 90.10 93.40 94.20 95.20 92.50 93.20 95.90 93.00 94.70 91.60 94.60 94.70 93.80 94.30 93.60 95.60 93.60 92.30 94.70 95.30 94.10 TVD depth (ft) 5i395.96 5429.49 5462.90 5496.86 5531.29 5565.60 5599.18 5633.25 5666.60 5698.95 5733.44 5771.67 5814.95 5861.76 5913.64 5971.55 6031.61 6096.19 6161.64 6232.36 6306.27 6381.96 6460.05 6539.48 6623.26 6708.28 6793.68 6881.72 6970.67 7058.73 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 6806.67 6894.91 6981.38 7068.61 7156.93 7244.98 7332.34 7421.66 7508.24 7592.31 7679.06 7765.00 7849.58 7929.16 8006.43 8082.77 8153.74 8222.96 8286.99 8349.75 8408.88 8464.23 8517.04 8566.49 8612.44 8651.48 8686.46 8721.35 8755.54 8788.69 2448.80 -6353.72 2477.82 -6437.05 2506.54 -6518.61 2535.22 -6600.99 2564.05 -6684.47 2592.65 -6767.76 2620.66 -6850.51 2649.81 -6934.94 2679.93 -7016.13 2709.99 -7094.67 2741.66 -7175.48 2774.86 -7254.90 2808.60 -7332.67 2840.22 -7405.90 2870.47 -7477.16 2899.06 -7548.03 2924.73 -7614.22 2949.72 -7678.80 2973.24 -7738.40 2996.78 -7796.64 3018.85 -7851.56 3039.34 -7903.03 3059.13 -7952.04 3077.96 -7997.83 3095.45 -8040.38 3110.35 -8076.53 3123.30 -8109.04 3135.86 -8141.61 3148.04 -8173.57 3160.11 -8204.46 6809.29 6897.48 6983.92 7071.10 7159.37 291.08 0.38 MWD 291.05 0.68 MWD 291.03 0.39 MWD 291.01 0.20 MWD 290.99 0.13 MWD 7247.37 7334.67 7423.94 7510.54 7594.63 290.96 0.15 MWD 290.93 0.59 MWD 290.91 1.08 MWD 290.91 1.54 MWD 290.91 0.47 MWD 7681.42 7767.46 7852.16 7931.85 8009.21 290.91 2.07 MWD 290.93 3.43 MWD 290.96 3.39 MWD 290.98 3.79 MWD 291.00 3.59 MWD 8085.62 8156.62 8225.87 8289.94 8352.74 291.01 3.75 MWD 291.01 3.03 MWD 291.01 2.91 MWD 291.02 2.81 MWD 291.03 3.27 MWD 8411.92 8467.31 8520.16 8569.66 8615.66 291.03 2.93 MWD 291.04 2.36 MWD 291.04 2.21 MWD 291.05 2.47 MWD 291.06 4.20 MWD 8654.74 8689.74 8724.65 8758.84 8792.01 291.06 4.43 MWD 291.06 0.88 MWD 291.06 0.68 MWD 291.06 0.62 MWD 291.07 0.61 MWD RECEIVED 15 999 Gas Cons. Commission An o ge 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis "6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-aXis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 6-Jan-99 10:54:45 Page 8 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 181 12672.13 ,19.65 ~93.2 182 12766.93 18.89 293.5 183 12793.34 18.49 293.5 Survey Projected to TD: 184 12860.00 18.49 293.5 92.30 94.80 26.40 66.70 [(c)1999 Anadrill IDEAL ID5 iA 12RI TVD depth (ft) q145.41 7234.90 7259.91 7323.16 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type .type 8820.34 8851.56 8860.00 8881.10 3172.31 -8233.72 3184.71 -8262.45 3188.08 -8270.20 3196.52 -8289.60 8823.70 291.07 8854.96 291.08 8863.42 291.08 1.04 0.81 1.52 MWD MWD MWD 8884.55 291.09 0.00 Proj 6-axis 6-axis 6-axis February 17, 1999 GeoQuest Schlumberger GeoQuest 3940 Arctic Boulevard Anchorage, Alaska 99503 (907) 273-1700 (907) 561-8317 (Fax) TO: The following data of the MD CDR & 1'VD for well MPL-28A. Job # 99069 was sent to: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 E-TRANS- 2/17/99 3 Bluelines each 1 Film each State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 OH LIS Tape 1 Blueline each 1 Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 · 1 OH LIS Tape 1 Blueline each 1 Sepia each Sent Certified Mail: P 067 695 535 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc, Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Al a s ka :,~.;5~fl7664-2; ?, Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie~~x....~., Received ~.,. /x--E~~k.~ STATE OF ALASKA ALASK~ _AND GAS CONSERVATION COMI~ .~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 49.90' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3680' NSL, 5196' WEL, SEC. 08, T13N, R10E, UM MPL-28A At top of productive interval 9. Permit Number / Approval No. 198-247 1540' NSL, 2908' WEL, SEC. 01, T13N, R09E, UM 10. APl Number At effective depth 50- 029-22859-01 1580' NSL, 3007' WEL, SEC. 01, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1592' NSL, 3034' WEL, SEC. 01, T13N, R09E, UM Sands 12. Present well condition summary Total depth: measured 12860 feet Plugs (measured) true vertical 7323 feet Effective depth: measured 12769 feet Junk (measured) true vertical 7237 feet Casing Length Size Cemented MD TVD Structural Conductor 76' 20" 250 sx Arcticset I (Approx.) 112, 112' Surface 7142' 9-5/8" 500 sx PF E, 900 sx G, 1300 PF 7177' 4471' Intermediate Production 12819' 7" 250 sx Class 'G' 12852' 7316' Liner Perforation depth: measured 12458' - 12478' true vertical 6945' - 6963' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12400' Packers and SSSV (type and measured depth) None RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) DEC 2 2 ?r~13~ Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage~ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerdeHubble ~_~~' ~ Title Technical Assistant Date j~"~,~/"~ Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate~ BP EXPLO ION- _-: - _--- -. i - Page1 of_2 Operations sUmmary RePOrt - -: Legal Well Name: MPL-28 Common Well Name: MPL-28 Spud Date: 4/6/1998 Event Name: REPAIR Start: 11/3/2000 End: 11/7/2000 Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABOP, S 4ES Rig Number: Date From- To Hours Task ~oUdbe I PhaSe'' "I': ''~" '::" ":i DescriPti°n: 1 .°fOperati°ns i.. i~ i :- 111312000 00:00- 10:00 10.00 MOB PRE MORU. MOVED FROM MPK-37 TO MPL-28. RIG UP. 10:00 - 13:00 3.00 RIGU PRE SET & BERM TIGER TANK. RIG UP HARD LINES. M/U HOR VALVE TO TREE. PULL PULL BPV. TAKE ON KILL FLUID. TEST LINES TO 2500 PSI, OK. 13:00 - 16:30 3.50 KILL DEOOMP SITP 90 PSI, SlOP 210 PSI. OPEN WELL. KILL WELL W/ SEAWATER. (8.4 PPG). 3.5 BPM @ 900 PSI. CIRC 540 BBLS TO CLEAN WELL UP. MENTOR WELL. 16:30- 18:00 1.50 WHSUR DECOMP SET & TEST TWO VALVE. N/DX-MASTREE. 18:00 - 20:30 2.50 BOPSUF DECOMP N/U BOPE. 20:30 - 23:30 3.00: BOPSUF DEGOMP TEST BOPE. TEST WAIVED BY CHUCK SHEVE W/AOGCC. TESTED 250~3500 PSI, OK. 23:30 - 00:00 0.50 WHSUR DEOOMP PULL TWO VALVE 11/4/2000 00:00 - 00:30 0.50 WHSUR DEOOMP PULL TWO VALVE. 00:30 - 01:00 0.50 WHSUR DEOOMP M/U LANDING JT. ROLDS. 01:00 - 02:30 1.50 PULL DECOMP PULL TBG HANGER. p/u WT 95K. FILL HOLE W/55 BBLS. MONITOR WELL. CUT EFT CONNECTOR. BAND ESP CABLE. P/U 3 1/2" DP X-OVERED TO TBG. RIH & TAG FILL @ 12478'. POOH & L/D DP. 02:30 - 12:00 9.50 PULL DECOMP POOH & TALLY COMPLETION STRING. 12:00 - 13:30 1.50 PULL DEGOMP HOLD SAFETY MTG. PUNCH & L/D LAST 3 JTS OF PLUGGED TBG. TBG PLUGGED W/SAND. NO ACID. 13:30 - 17:00 3.50 PULL DECOMP POOH, INSPECT & L/D ESP. LOAD OUT ESP. CLEAR RIG FLOOR & R/U TO RUN DP. 17:00 - 18:00 1.00 CLEAN DECOMP P/U MILL, DUAL SCRAPERS & 6 * 4 3/4" DOS. RIH W/BHA. 18:00 - 00:00 6.00 CLEAN DECOMP P/U 3 1/2" STRAP & RABBIT DP & RIH TO 6000'. 11/5/2000 00:00 - 07:00 7.00 CLEAN DEOOMP P/U TALLY & RIH W/3 1/2" DP TO 12636'. 07:00 - 09:00 2.00 CLEAN DECOMP REVERSE CIRCULATE & WASH DOWN TO 12753' 09:00 - 11:00 2.00 CLEAN DECOMP MIX & PUMP 50 BBL SWEEP & CLEAN HOLE. RECOVERED SAND & CARBOLITE. 11:00 - 15:30 4.50 CLEAN DECOMP PULL OUT OF HOLE TO TO 4000'. 15:30 - 16:30 1.00 CLEAN DECOMP REVERSE CIRCULATE & PUMP 25 BBL SWEEP @ 5 BPM & 700 PSI. 16:30 - 17:00 0.50 CLEAN DEOOMP RIH HOLE TO 6000' 17:00 - 18:00 1.00 CLEAN DEGOMP REVERSE CIRCULATE & PUMP 25 BBL SWEEP. 5 BPM & 900 PSI. 18:00- 19:00 1.00 CLEAN DEGOMP RIH TO 8000' 19:00 - 20:00 1.00 CLEAN DEGOMP REVERSE CIRCULATE & PUMP 25 BBL SWEEP. 5 BPM @ 950 PSI. 20:00 - 21:00 1.00 CLEAN DEOOMP RIH TO t0000' 21:00-22:00 1.00 CLEAN DECOMP REVERSEGIROULATE&PUMP25BBLSWEEP5BPM@1100PSI. 22:00 - 23:00 1.00 CLEAN DECOMP RIH & TAG UP 12753'. NO FILL 23:00 - 00:00 1.00 CLEAN DECOMP REVERSE CIRCULATE & PUMP SWEEP. 5 BPM @ 1300 PSI. HOLE CLEAN. 11/6/2000 00:00 - 00:30 0.50 CLEAN DECOMP REVERSE CIRCULATE. 5 BPM @ 1300 PSI. 00:30 - 03:00 2.50 CLEAN DECOMP P/U KELLY. CIRCULATE & RECIPROCATE. PUMP 6 BPM @ 1250 PSI. 65 RPMS. P/U WT 185K 03:00- 04:00 1.00 CLEAN DECOMP POOH TO 11500' 04:00 - 07:30 3.50 CLEAN DECOMP PUMP 18 BBL DIESEL/XYLENE PILL FOLLOWS BY 20 BBL HI-VIS SWEEP. DISPLACE HOLE TO CLEAN SEAWATER. BLOW DOWN LINES. PREPARE TO LDDP.RECEIVED 07:30 - 10:00 2.50 CLEAN DECOMP POOH & L/D DRILL PIPE. 10:00 - 11:30 1.50 CLEAN DECOMP CUT & SLIP 84' OF DRILLING LINE. 11:30-20:30 9.00 CLEAN DECOMP POOH & L/D DRILL PIPE. DEC 2 20:30 - 21:30 1.00 CLEAN DECOMP L/D BHA. CLEAR FLOOR. .. Pdnted; 11~28/2000 Anonorage Legal Well Name: Common Well Name: Event Name: 'Contractor Name: Rig Name: Date 1116/2000 11/7/2000 From - To 21:30 - 22:30 22:30 - 23:30 00:00 - 02:00 02:00 - 08:30 08:30 - 11:00 11:00 - 14:30 14:30 ~ 16:00 16:00- 17:00 17:00- 19:00 19:00 - 20:00 20:00 - 22:00 22:00 - 23:00 MPL-28 MPL-28 REPAIR NABORS NABORS 4ES Spud Date: 4/6/1998 Start: 11/3/2000 End: 11/7/2000 Rig Release: Group: RIG Rig Number: 'DECOMP COMP COMP COMP COMP :COMP COMP COMP COMP COMP COMP COMP PULL WEAR BUSHING. M/U ESP & SERVICE SAME. M/U ESP. CONNECT CABLE TO ESP & INSTALL FLAT GUARDS. TIH W/2 7/8" TCOMPLETION ASSY. CHECK CABLE EVERY 2000'. to 8400' Splie esp cable & cont to run esp completion to 12399' make up hanger & rig up to circ. splice esp connector to hanger. land hanger & set twc nipple down hop's nipple up tree test tree to 5000 psi. & make final checks, on equipment. rig lubricator & pull twc& set bpv. & secure tree & cellar area. RECEIVED DEC g % 2000 AWska ~ & Gas Cons. Commissior~ Anchorage Printed: 11/28/2000 8:53:41 AM STATE OF ALASKA ALASKA'-~iL AND GAS CONSERVATION C0i~fMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well []Other Change Out ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3680' NSL, 5196' WEL, SEC. 8, T13N, R10E, UM At top of productive interval 1538' NSL, 2902' WEL, SEC. 1, T13N, R9E, UM At effective depth 1580' NSL, 3007' WEL, SEC. 1, T13N, R9E, UM At total depth 1592' NSL, 3034' WEL, SEC. 1, T13N, R9E, UM 12. Present well condition summary Total depth: measured 12860 feet true vertical 7323 feet Effective depth: measured 12769 feet true vertical 7237 feet Casing Length Size Structural Conductor 76' 20" Surface 7142' 9-5/8" Intermediate Production 12819' 7" Liner t5. Type of well: IX] Development [] Exploratory [] Stratigraphic F-IService RECEIVED DEC 17 1999 NIiCia 0il & Gas C0ns. Commission An~.h0rage 6. Datum Elevation (DF or KB) KBE = 49.90' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-28A 9. Permit Number / Approval No. 198-247 10. APl Number 50-029-22859-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 500 sx PF E, 900 sx G, 1300 PF E, 300 sxC 250 sx Class 'G' MD TVD 112' 112' 7177' 4471' 12852' 7316' Perforation depth: measured 12458'- 12478' true vertical 6945' - 6964' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12391' Packers and SSSV (type and measured depth) None OR!G!!dAL 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the fgregoing is true an,d correct to the best of my knowledge Terrie Hubble ." Title Technical Assistant III Prepared By Name/Number: Terrie Hubble, 564-4628 ~ ~n ~uplicate Form 10-404 Rev. 06/15/88 Facility Date/Time 09 Dec 99 10 Dec 99 11 Dec 99 Progress Report M Pt L Pad Well MPL-28A Page 1 Rig Nabors 4ES Date 17 December 99 06:00-13:00 06:00-13:00 13:00 13:00-16:00 13:00-16:00 16:00 16:00-20:00 16:00-20:00 20:00 20:00-22:00 20:00-22:00 22:00 22:00-01:00 22:00-22:30 22:30 22:30-01:00 01:00 01:00-03:30 01:00-03:30 03:30 03:30-06:00 03:30-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-20:00 07:00-17:00 17:00 17:00-20:00 20:00 20:00-06:00 20:00-00:00 00:00 00:00-06:00 06:00 06:00-13:00 06:00-06:30 06:30 06:30-13:00 Duration 7 hr 7hr 3 hr 3hr 4 hr 4 hr 2 hr 2 hr 3 hr 1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr lhr 1 hr 13hr 10hr 3 hr 10hr 4 hr 6hr 7 hr 1/2 hr 6-1/2 hr Activity Move rig Rig moved 100.00 % At well location - Slot Fluid system Fill pits with Seawater Rig tiger tanks & take on sea h20 & rig lines to tree etc. Completed operations Well control Circulated closed in well at 12242.0 ft test lines to 3000 psi. & hold pre-job safety meeting, open well & record pressures Tbg. O psi. SICP =500 psi. & circ. well bore fluids out with 5-bpm 1000 psil. Influx Out of hole Suspend operations Held safety meeting Safety meeting & discuss derrick pin incident. & review procedures & inspect derrick for safety factors etc. Completed operations Wellhead work Installed Hanger plug Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack RECEIVED .... " '/7 1999 n Pressure test completed successfully - 3500.000 psi Test waived by Chuck Sheve with AOGC. Wellhead work Removed Hanger plug Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 75.0 ft Mu landing jt. & pull hanger to floor & check & pooh with esp completion. Completed operations Rigged down sub-surface equipment - ESP Lay dn esp & inspect & lay dn desander & 3.5" sand trap. Equipment work completed Run Triple completion, 2-7/8in O.D. Installed ESP Equipment work completed Ran Tubing in stands to 7440.0 ft Stopped: To hold safety meeting Run Triple completion, 2-7/8in O.D. (cont...) Held safety meeting Completed operations Ran Tubing in stands to 12390.0 ft Facility M Pt L Pad Progress Report Well MPL-28A Page Rig Nabors 4ES Date 2 17 December 99 Date/Time 13:00 13:00-15:15 13:00-15:15 15:15 15:15-16:30 15:15-16:30 16:30 16:30-17:30 16:30-17:30 17:30 17:30-19:00 17:30-19:00 19:00 19:00-06:00 19:00-00:00 12 Dec 99 00:00 Duration 2-1/4 hr 2-1/4 hr 1-1/4 hr 1-1/4 hr 1 hr lhr 1-1/2 hr 1-1/2 hr llhr 5 hr Activity Completed run with ESP to 12390.0 ft Wellhead work Installed Tubing hanger install hanger & make esp splice & land hanger & rilds & set twc & test to 2500 psi. Tie-down bolts energised Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree install tree & test same to 5000 psi. Equipment work completed Wellhead work Installed Hanger plug pull twc & set bpv Equipment work completed Fluid system Freeze protect well - 80.000 bbl of Diesel Used Hb&r & freeze protect well . Had trouble pumping. & rig lubricator & pull bpv & freeze protect tbg.. & re-set bpv & secure tree & cellar. Completed operations RECEIVED 1999 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dcccmbcr 8, 1998 Chuck Mallar,' Drilling Enginccring Supervisor, Acting BP Exploration (Alaska) Inc,. POBox 196612 Anchorage, AK 99519-6612 Rc: Milne Point Unit MPL-28A BP Exploration (Alaska), Inc. Permit No: 98-247 Sur Loc: 3680'NSL, 5196'WEL. Sec. 08, T13N, RIOE. UM Btmholc Loc. 1550'NSL, 3084'WEL, Sec. 01, T13N. R09E. UM Dear Mr. Mallarv: Encloscd is thc approved application for permit to rcdrill thc above refcrcnccd well. Thc permit to rcdrill docs not exempt you from obtaining additional permits rcquircd by law from other governmental agencies, and does not authorize conducting drilling opcrations until all other required pcrmitting dctcrminations arc made. Blowout prevention cquipmcnt (BOPE) must bc tcstcd in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a tcst of BOPE installed prior to drilling ncw hole. Notice may be given bv contacting thc Commission pctrolcum field inspcctor on thc North Slope pager at 659-3607. · Commissioner BY ORDER OF THE COMMISSION dlf/Enclosurcs CC~ Dcpartmcnt of Fish & Game. Habitat Section w/o cncl. Dcpartmcnt of Environmental Conservation w/o cncl. STATE OF ALASKA "- ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork E]Drill C~Redrill Ilb. Typeofwell []Exploratory FlStratigraphicTest C~ Development Oil [] Re-Entry [] DeepenI F-lService [] Development Gas I--]Single Zone [] Multiple Zone 2'. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 43.8' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation ,,~'< Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 !4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3680' NSL, 5196' WEL, SEC. 8, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1504' NSL, 2953' WEL, SEC. 1, T13N, R9E, UM MPL-28A At total depth 9. Approximate spud date Amount $200,000.00 1550' NSL, 3084' WEL, SEC. 1, T13N, R9E, UM 12/09/98 12. Distance to nearest property lineJ 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025509, 3084'I No Close Approach 2560 12883' MD / 7327' TVD 16. TO be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 7317' Maximum Hole Angle 75-4° Maximum surface 2583 psig, At total depth (TVD) 6935' / 3227 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 Hydril 563 12853' 30' 30' 12883' 7277' 160 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 16475 feet Plugs (measured) Cement retainer at 16319'; Cement retainer at 16208' true vertical 6693 feet Effective depth: measured 16158 feet Junk (measured) Fish at 16685'-16775' true vertical 6625 feet Casing Length Size Cemented MD TVD Structural Conductor 76' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 7142' 9-5/8" 180o sx PF 'E', 900 sx 'G', 300 sx PF 'C' 7177' 4471' Intermediate Production 16539' 7" 200 sx Class 'G' 16572' 6716' ' ORIGINAL true vertical ~,i~ O~ & Gas. Cons. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ..... Contact £n~ineor N~me/Number: Tom Maonder, $~4-442 ~ {~ ,% Prepared By Namo/Nombor: Kathy Campo~mor, $~4-$ ~ 22 21. I hereby certif¥/f~at thg/~§oin~T~s~e and correct to the best of my knowledge Signed c~,~ ..- ~ itle Drilling Engineering Supervisor, Acting Date Permit Number I APl NumGerJ I Approval Date i See cover letter /~¢_~__Z~ I 50-029-2~'59-01 I ~0%~'O~ ~('~t for other requirements Conditions of Approval: Samples Required [] Yes ,~,No Mud Log Required [] Yes ]~No Hydrogen Sulfide Measures []Yes ,~No Directional Survey Required ~Yes [] No Required Working Pressure for DOPE []2K; []3K; []4K; ~]5K; [] 10K; [] 15K Other: (}i'i?~iFl~/ $igi~ed ,".. ~., by order of Approved By David W. ,~oht'ls~o'l-i Commissioner the commission Date/~,~ Shared Services Drilling Contact: I Well Name: Tom Maunder IMP L-28a Well Plan Summary 564-4429 I Type of Well (producer or injector): Sidetrack Kuparuk Producer Surface Location: Target Kuparuk Bottom Hole Location: 3680' NSL, 5196' WEL, Sec. 08, T13N ,R10E, DM., AK 1504' NSL, 2953' WEL, Sec. 01, T13N, R09E, UM., AK 1550' NSL, 3084' WEL, Sec. 01, T13N, R09E, UM., AK I AFE Number: I-unassigned I ~%?[ ~% '~ I Rig I ., , : Nabors 27-E I.Estimated Start Date: 19 Dec. 98 I I Operatin~l days to complete: I MD: 112,883' I I TVD: 17,327' Bkb I I' KBS: Well Design: Sidetrack US Hole Well I 7", 29# Intermediate Surface casing already in place. Formation Markers: 19 I I43.8' Formation Tops MD TVD (ss) EMW Formation Pressure Base Permafrost NA NA NA NA NA Top Schrader Bluff NA NA NA NA NA NA NA NA NA Top HRZ Truncated Base HRZ 12040 6495 8.4 ppg 2837 psi MK-19 12119 6565 8.4 ppg 2867 psi TKU D 12290 6720 9.1 ppg 3165 psi TKUB 12423 6845 8.9 ppg 3168 psi ~KUA 12472 6890 8.9 ppg 3200 psi TKUA3/Target 12477 6895 8.9 ppg 3202 psi TKUA2 12493 6910 8.9 ppg 3210 psi TKA1 12519 6935 8.9 ppg 3227 psi Miluveach 12583 6995 9.1 ppg 3310 psi Total Depth 12883 7277 9.1 ppg 3443 psi · *These are estimated maximum pressures and the actual pressures may be lower. Casin~'l'ubin~l Pro~lram: 9-5/8" is already )lace. Hole ~ize Csg'/ Wt/Ft Grade C~)nn Length Top Btm Tb~l O.D. MD/I'VD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 Butt 7146 31/31 7,177/4465 8-1/2" 7" 26# L-80 Hyd ril 12,853 30/30 12,883/7,277 563 The internal yield pressure of the 7" 29# casing is 8,160 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _ 6,935' TVDbkb, In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +_6,935' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,227 psi is 2,583 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. ORIGINAL PAGE I TEM 11:30 11/23/98 Cementing I'roc. tram: Halliburton Cementinc Services Hole " -'Casing Interval & V~)lume~ Spacer Type of Cement Propertiesz Cate~lor¥ Size/Depth Excess Surface 9-5/8" @ Already in 7,177' place Production 7" @ 11,423- 160 sx_b 70 bbls. Premium Class "G" w/ Den 15.8 ppg First Stage 12,883' 12,883' 33 bbls NSCI Spacer 0.2 % CFR-3 Yield 1.15 ft 3/sx 0.1% HR-5 Water 5.0 gps 0.45% Halad 344 TT 3.5-4.5 hrs @ 140° F FL 50cc/30 rain @140° F 1. Volumes may have been rounded. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and mud's to ensure compatibility prior to pumping job. 3. 9-5/8 "surface casing previously set @ 7,177'_+. 4. The production hole will be cemented in a single stage. The estimated first stage tail cement volume is designed to fill the annular volume calculated from 11,423' which is 1000'+_ above the Kuparuk B Sand to TD at 12,883' plus 30% open hole excess and the shoe joint volume. 5. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install one per joint from 120' above the Kupaurk B-Sand. Use two centralizers per joint on the shoe joints. 6. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 7. Install two 7" marker joints and position three joints above the Kuparuk B sand. 8. Place all centralizers in middle of joints using stop collars. 9. Mixing style for the production slurry is being evaluated. ORIGINAL PAGE 2 TEM 11:30 11123/98 . Loggin~l/Formation Evaluation Pro~lram: Anadrill Schlumberqer "Surface--12-1/4" 1. NA. Surf'ace hole drilled in well L-2'8 9-5/8"/7" Cased Hole 1. NA. No cased hole logs planned for side track Production-8-1/2" 1. MWD/LWD D& I/C D R/G R/AD N/PW D/DWO B/DTQ E. All logs required from drill out of 9-5/8" to TD, real time and recorded. Mud Logging 1. Schlumberger IDEAL System in all hole sizes. Real time and recorded logs as per Anadrill/SSD log standards. Lo_q_q in .q Nomenclature D&I DWOB/DTQE: GR: CDR: ADN: ROP: PWD Directional Inclination and Azimuth Downhole weight on bit and torque Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Pressure While Drilling Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: NA Surface Casing already set. Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % Production Mud Properties to Change LSND Freshwater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point ~lel gel Filtrate %LGS 8.6-9.3 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 <6 Production Mud Properties from HRZ to LSND Freshwater Mud TD. Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 9.6 35-45 6-20 3-10 7-20 8.5-9.5 <4 8-10 for <6 HRZ Miluveach The planned mud weight will give 200 psi overbalance at the TKA1. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. OR181i\l/ L PAGE 3 TEM 11:30 11/23/98 Directional: KOP1 Tangent Hole Angle Final Drop Maximum Hole Angle Close Approach Wells Survey Program 7317' Start drop @ 3.0°/100 drop/turn from 75.4° inc. and 289° az. to 69.0° inc. with no azimuth change. EOD @ 7,528'. 69.0° from 7,528-10,742' 3.0°/100 from 69.0° to 20.0° EOD 12,377' md 75.4° from 4,297-6100' (In original wellbore.) All wells may remain flowing while drilling L-28a and no shut-ins are required. 1. 7,317'-TD MWD surveys. Drillinq Waste Disposal: All mud and cuttings should be hauled to the facility at CC-2A for disposal. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Disposal of Other Wastes: Any other waste should be properly disposed of as recommended in the "Red Book". GENERAL DISCUSSION Well Objective: MPU L-28a is a planned side track of MPU L-28. L-28 was originally drilled in spring 1998. The 7" casing string was stuck while running and cemented in place at 16,572'. Attempts to sidetrack out of 7" casing were not successful and the well was suspended. Since the original reservoir target of L-28 is presently being drilled to by F-84, the opportunity exists to sidetrack the well to a new bottomhole location along the well path. The 7" casing is planned to be cut at -7477' about 300' below the 9-5/8" shoe and the required abandonment plug set up into the casing. This work will be done using rig 4ES prior to moving 27E to L pad. Rig 27E will sidetrack the well to the new bottomhole location. Geolo_qv The target for MPL-28a is between wells F-05 and F-06. The bottomhole locations of these wells are separated by some 5,000'. With the variety of faulting in the area and the waterflood response of the wells after completing MPL-33i, there is a high potential to tap upswept reserves at this bottomhole location. Hydrocarbons are expected in the A sand series. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be around 8.9 ppg in the A sands (TA1 @ 6935' SS) due to the injection support in the area. This higher pressure is not expected to result in any increased risk of breathing. Recent work at F pad has indicated that at the planned mud weight of 9.6 ppg, breathing has not occurred. Close Approaches There are no close approaches associated with the drilling of MP L-28a, however, tolerance lines will be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Injection There has been injection into the hydraulic unit from L-33i and pressure/rate response has been seen from F-05 and F-09. L-33i may be shut in while drilling L-28a. Lost Circulation Lost circulation is prevalent while running casing and cementing in the surface but also occurs in the production hole. Losses are extremely probable while cementing the production casing in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing to bottom. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Stuck Pipe Potential: The surface casing is already in place. ORIGii'1AL While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk D Shale. This common occurrence has often caused difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2', production interval. Shale instability is possible in the Miluveach and may result in tight hole or packing off so preventative measures must be taken to alleviate this risk prior to PAGE 4 TEM 11:30 11/23/98 drilling the Miluveach. Differential sticking can occur while running the production string. Formation Pressure: KUPARUK A1 SAND 6,935' TVDss 3,227 PSI 8.9 PPG EMW Formation pressures are estimated at 8.9 ppg EMW. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _+ 6,935' TVDss. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+6,935' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,227 psi is 2,533 psi. See the updated Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for information on L pad and review recent wells drilled on L Pad. ORIGINAL PAGE 5 TEM 11:30 11/23/98 MP L-28a Side Track Kuparuk Producer Summary of Proposed Operations It is planned that the original wellbore will abandoned, casing cut and pulled from -7,477 300' below the 9-5/8" shoe. An abandonment plug will then be set from the top of the stub up into the 9-5/8" casing. It is planned to tag the cement plug with the drilling assembly. 1. MI RU Nabors 27E. 2. ND tree and NU BOP. Test per SSD/AOGCC requirements. 3. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/ADN/PWD/DWOB/DTOQ/PWD). RIH, drill out float equipment and 20' of new formation. Perform the Leak Off Test as per Recommended Practices. Record pressure versus cumulative volume during the LOT test for the wail'file. 4. Drill 8.5" hole to TD as per directional plan. TD is planned 300' into the Miluveach. 5. Run 7" casing. 6. Perform Single Stage Cement Job. Complete the production casing cementing check list. 7. Displace cement with 8.9 ppg filtered brine bump plug and test to 3500 psi.and enough diesel to cover from the base of permafrost to surface (+-2200' MD). 8. Raise BOP and set slips if necessary. Cut pipe and install packoff. NU and test tubing head. Reland BOP. 9. Close blind rams and test casing to 4500 psig. 10. Run 4-1/2" frac string to -12100'. Land tubing. 11. ND BOPE and NU 4" frac tree. Test Tree to 5000 psi. 12. Freeze protect tubing and inner annulus to 2200' md by pumping diesel down annulus and allowing to U-tube to tubing. 13. Freeze protect 9-5/8" x 7" annulus to 2200' with crude. 14. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. PAGE 6 TEM 11:30 11/23/98 Orig KB Elev. = XXX (N 27E) Tree: 2 ~"~" ~' M P U L-28A O~'0. O~ ~'O'-' ××× Wellhead: i i Abandonment Plug for PROPOSED SIDETRACK : /~. / X Z~.~¢ " Directional Plan #3A : / ~K' / KOP:7,317' ' ' /~[ / M~xa.¢ ~de~ ® ~,~' ' / ~K.-- / ........... ^.~,e,h..,.,~ru*: ~0de~. i / ~ ISide~ac~ I1~ ;I /Camco ~"× ~" lllb is, L__, 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. Il ~ ~'- :j ~' _-¢ 2-7/8- HES XN-Nipple cas,n, lIi B'0"'d' Stimulation Summaw !~ I~i~ I centrilift GO 1150 ESP, i I I~ p.r,~s~.~,M~'A,,:,. ' ' ~, Cab,~ I~ ~ I' ,,s'~' ~ ~ separator J I ~ I ~entrilift GSB3UT/LT I B ~ I AFLAS/HSN series 513 , ~.- '~ . , ,ize S PF: I n..terval . . i(~D) ~ ~ hi cet;t;;;t,~H 562 series 7" 26# t_-Sq prod. csg. @ 12,883' ~illilll~ ~___ COMPLFTIO~ DATE REV. BY COMMENTS MILNE POINT UNIT Drilled by Nabors 27-E WELL L-28A 11/09/98 DKJ Proposed APl No: BP EXPLORATION (A'K) . Anad~ill Sehl umber~er 3940 Arctic A~chorage AK . 99503 (907) 2q3-1700 Fax 561~8537 DIRECTIONAL ~IELL PLAN for SHAPED SERVICES DRILLING ~e]l ......... : MPL-28A {F05/F09) ~034 ?ield ........ : Mklne Po!pt Com~utatlon..: Min£u~u~ Curvature Units ........ : FEET Surface bat,.: 70.49793~8 N ~-k~rface Lonq.: 149.63460976 W LOCATIONS - A/~ASKA Zone~ be~a~ Description X-Coor~ Surface ...... : 3680 FSL 5196 FEb S08 T13N R10~ ~4 S44680.77 ?re-in survey: 52 FSL ~005 ~EL 806 T~3N R~OE UM 5405~7.00 Targe~ ....... : 1504 FSL 295~ ~ S01 T13N RO9B UM 536454.00 BHL .......... : 1550 F~b 3~B4 FEL S0[ TI3N RO~~ UM 536322.70 4 Y-Coord' 6031868.89 6033497.08 6034928.00 6034973,59 PROPOSED WELL PROFILE STATIO~ MEASURSD INCLN DrP. ECTIO~ V~RTICAL-DRPI~{S IDEntIFICATION DE~ ~ AZ[~H T~ S~-SHA TIE-ID S~gY 7300,00 7¢.5~ / 289,30 4501.93 4452.O~ KOP CURV~ 3/i00 .~ 7317.00 75.36 ,'; 289,23 4506.20 44~6.30 ~ 7400.00 72.88 / 2B9,33 452B.91 4479.01 7500,00 69.88 ~8~.46 4560.84 4510.94 ~ 3/100 7528,01 69.04 289.~9 4570.67 ~520.77 SECTION D~PART 44LL.21 4~27,67 4507,~9 4609.25 4628.48 Prepared ..... : 06 No~ L998 Ver~ sect az.: 289.49 KB elevation,: 49.90 ft Ma~netic Dc~n: ~27.458 Scale ~actoT.: 0.99990227 Conver(3ence,.: a0.34442~1~ ANADR1LL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOP, EXECUTION PL AN COOP. D/NATES-FROM ALASKA Zone'~ TOOL DL/ W~/.~[~FOkD X Y FACE L 00 1652.99 N 4094,3l W 540577.QO 60~549~,08 1658,42 N 4109.84 W 54056[.44 60~3~02,41 178R 1.0~ 5684,78 N 4185,~9 W 540484,94 6033528,3] [78R 3.00 ~716,24 }~ 4174.57 W 540396,38 6033559,24 178R 3.00 1724.98 N 4299.30 W 5~0371.60 6033567,83 HS DROP 3/100 11200.00 55.31 ... ~(Anadril[ (c)98 MPb28AP3 3,2C 11:02 A~4 P) ~07~2.55 69,04 289.49 5720.68 5670.78 7630.2? 10800,00 67.35 2B9.49 5~42,04 5692.k% 7685.60 10900.00 64.3~ 289.49 5783,00 5733.10 7774.8~ klODO,O0 61,31 289.49 5828.69 S778.79 ~863.75 11100,00 58,31 ~89.49 5678.96 5829.06 7950.18 289.49 5933 ,69 S883,79 8033.86 2726,56 N 7129,06 W 557~36,15 6034~52.29 LS 0.00 2744,36 }~ 7179.34 W 537485,77 6034569.78 bS 3,00 2774.79 N 7265,32 W ~37399.61 6034599.69 LS 3,00 2804.47 N 7349.17 W 537315.60 6034628.86 LS 3.00 2832,3[ N 7430.64 W 537233,96 6024657,20 LS 3,00 2861.23 N 7S09.53 W 537lS4.91 6034684,65 LS 3,00 STATION :D~NT t FI C-~T I ON TKUD EbrD ]/I00 DROP ?KUA TARGET ~ L V TD ]13OO.00 52.31 1%400.D0 ~9,31 11500,D0 11600,00 43.31 ]2700.00 40.3] 11800,00 ]1900.00 34.31 £2000.00 i2100.00 28,3~ 12200,00 2~,31 ~2290.56 ~2.~ 12300.00 22.3l ~23~7.14 20.00 Z2~91,82 20.00 ~2497.Z4 20,00 ]25~3.56 20.00 L2883.56 20.00 :, PROPOSBD WELB',' PROF£L8 .., DIRECTION YERTIC-AL-DRDTKS AZ[MUT~ TVD · SUB -SEA 289.49 5992.'72 5942.82 289,49 6055,'90 6006.00 289',~9 6123,05 6093,15 289.49 6193.98 6144.08 ~89.49 6268.50 6218,60 289.~9 6346.'41 6295.51 289.49 6427.49 6]~9.59 289.49 651Z.~2 646~.62 289,49 6598.28 6548.38 289.49 6687,~2 6637.62 289.49 6769.90 6720,00 289,49 6~78.99 6729,09 289.~9 68~0,93 289.49 6939.90 6890,00 289.49 6944.~0 .6Bgs,0O 289.49 7044.90 699~.00 2~9.49 7326.~1 7276.9~ 06 ~ov 1998 FaDe 2 SECT£O;~ COORDINATeS-FROM ALAST$~ Zone 4 TOOL DL/ DEPART WELLHEAD X ¥ FACE 8174.56 2888.16 N 7585.6[ N 537078.68 6034711.11 LS 8L92.06 2914,01 N 9658.67 W 539005.48 6034736.58 LS 3,00 8266.~5 2938.71 N 7728.51 ~ 53693£.49 6034~60.83 LS 3.00 8336.63 296~.25 N 779~.94 W 536868,93 603478].94 LS 3.00 8403,~9 ~984,49 N 7857.79 W ~36~05.96 6034805.80 LS 3.00 8465.96 ]005.40 N ~916,89 W 536746.76 6034826.36 L~ ],00 8524.47 3024.93 N 7972.02 ~ 536691.49 6014~45.55 LS 8578,66 3043.0~ N 8023.11 H $36640,3[ 6034863.~2 LS 3.00 8628.37 3059,59 N 8069.97 W $36593.35 6034879,62 LS 3,00 8673.48 3074.64 N 8112,49 W ~36550.94 603~894.41 L~9 3.00 8710,09 3086.86 N 8147.03 W $36576.16 6034906,42 LS 3,00 B71],85 ~088.£~ N 8L~0,S~ W 536S12,6£ 60~490~,65 LS 3.00 874~.69 3097,40 ~ 8176,79 N ~36456.3~ 60349~6,78 8774.07 3i08.21 N 8207,32 W 536455.72 6034927.40 H$ 0,O0 8775,~9 3108.82 N B209,04 W 53645~,00 6034928.00 HS 0,0O 8812.29 3]20.96 N 8243,35 ~ $364[9.62 6Q~9.94 89£4.90 3[5~.20 N 8340,07 ~ 536322.70 6034973.S9 O.0O ANAD~ILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR m":CUTION (Anadril] (c)98 MPL28AP3 3,2C il:02 AM P) nA ru SERVIC'ES , ~ Marker Ident]lication MD BK8 SECTN fNCLN A/ lIE-Ut SURVEY 7300 4502 4~! 75.53 8~ xOP CURVE 3/100 7317 4506 442B 75.36 C) E~,~O 3/~00 7528 457~ 46~8 69.04 D) ~P 3/100 t0743 5721 7630 69,04 E] E~O 3/~00 OR~ t2377 ~851 8742 20.00 F) TA~ET ~2477 6945 8776 20.00 G) TO ~2BB4 73~7 89~5 20.00 DRILLING ........ i i · i · i i mi III I -._ ! ANADR!LL AKA-DP< FEASI. BILITY PLAN NOT APPROVED FOR EXECUTION F.'.LAN :~._~_ Anadrj]] Sch]umberger ~ m i i j iii u i i i PL-28A (F05/F09)P0SA VERTICAL SECTION V~EW ~_O scale,: I inch 800 (eet jtpacale.: I inch BO0 leer wSn 0B Nov 1998 i i m , ~"'~, ----------------------,.-----' B · /~3oo ........... I ............ ........ . . I )O I '- I I I I I I : I 4000 ~OO 4800, ~5200 5600 60OO 6400 6800 7200 7600 8000 8400 BBO0 9200 9500 ~OOO0 ~0400 ~OBOO 11200 Sec t ion Oeparture , , r:l) (~)90 ttF-"L~SAP3 3.~ ii: i3 ~ PI .... 540 uP__HViCES D ILLIN8 Anadri ]j Schlumberger ..... MPL-28A (F05/F09) PLAN PO3A CLOSURE ' 89t7 feet at Azimuth 290 72 ..,F~,$tBI_,IT P~N , ISC,~ ....... : t~o~: ~oo ~XE(;U'TION ~[ ~k.l ~ ~ ~]~ [~[li~t~n ~ NfS ..... ~~= ~{ TIE-Itl SURVEY 7300 t553 N 4094 ........ "::=' .......='=~~~ .... ~-~-: BI K~ C~VE 3/~00 7317 1558 ~ END 3/100 7528 1725 N 4299 ......... 8ROP 3/I00 i074~ 2787 N 7129 ~~ TARGET 12477 3109 N ~09 ,, END 3/100 DRDP ~23'77 30~7 N 8~77 j ~. , 6} TD J2884 3~55 N 8340 ......................................... .... ~~et lPoint) , ' .-, L ,,,,'~'"' ) ~,~oo ............ -'~-,' ~-' . .............. ~__ ._ ......................... .... ~ ......... ~ ,, t 3 ..... ;~,.,,~ ~ - ,: ~,m ,,,~ ~ : ' .... :, · ~ ..... ,, ,: i0-I - ~ ........... I I I .......I I I 1 ~3500 t2800 t200D ' 1~200 10400 9500 BBOO B000 7200 6400 ~00 4800 4000 3200 2400 i~O 800 <- WEST' EkS1 / I NOTES 2 4 -~) 25 20-1) 21 164)- 17 13 [] 1 [] L PAD 2 [] 12 [] [] [] [] [] 6 4 5 11 I I 1. DATE OF SURVEY: JANUARY 6 & 9, 1995. 2. REFERENCE FIELD BOOK: MP95-Ol(pgs. 1-10). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 4. PAD SCALE FACTOR IS 0.999902.3. 5. HORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS L-1 NORTH AND L-2 SOUTH. 6. ELEVATIONS ARE MILNE POINT DATUM M.S.L It"-:- VICINITY MAP LEGEND + AS-BUILT CONDUCTOR EXISTING WELLS SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSEO TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT --]HIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNOER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 6, 1995. LOCATED WITHIN PROTRACTED SEC. 8, T. 13 N., R. 10 E., U.M., AK. WELL /~.S.P. PLANT GEODETIC GEODETIC SECTION CELLAR NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) OFFSETS BOX ELEV. Y=6,031,792.72 N. 1585.04- 70'29'51.825" 70.4977292' .~604'FSL 16 X= 544,728.92 E. 1225.55 14-9'38'03.191" 149.6342197'I 5148'FELi 16.6' Y=6,031,850.18 N. 1584..39 70'29'52.585" 70.4978847' 3660'FSL 16.7' 17 X= 544,822.11 E. 1335.04 149'38'00.438" 149.6334550' 5055'FEL Y= 6,031,817.73 N. 1614.70 70'29'52.072" 70.4977978' 3629'FSL 20 X= 544,712.98 E. 1225.29 149'38'03.656' 149.6343489' 5164'FEL 16.8' Y= 6,031,876.39 N. 1615.06 70'29'52.643" 70.4979564'i 368TFSL 16.7" 21 X= 544,806.19 E. 1335.43 149'38'00.902' 149.6335839' 5070'FEL: Y= 6,O31,843.08 N. 1644.88 70'29'52.322" 70.4978672' 3654'FSL 24 X= 544,696.61 E. 1224.84 149'38'04.133" 149.6544814' 5180'FEL 16.8' Y= 6,051,901.35 N. 1644.83 70'29'52.890" 70.4980250' 3712'FSL 16.5' 2.5 X= 544,789.96 E. 1334.89 149'38'01.375" 149.6357155 5086'FEL Y=6,031,868.89 N. 1675.16 70'29'52.577" 70.4979381' 5680'FSL 16.9' 28 X= 544,680.77 E. 1225.09 149'38'04.595" 149.6546097' 5196'FEL Y=6.O31,927.32 N. 1675.05 70'29'55.146" 70.4980961' 3738'FSL 17.0' ' 29 X= 544.774.49 E. 1335.53 149'38'01.826" 149.6338405' 5102'FEL OARNHART DALE: ,18Is 5 IMPt f' ADAFI Jo(I _ _ · ,c ,*d ! BP EXPLORATION MILH[~ POINT l_ PA~ COtqDUCTOf,~ A% [3t)lt T Wi]_I:; 16.17,2().21.'24.2'.-).28.29 IL Field Milnc Poi,ti Facility M Pi I~ Pad Target Analysis Report Well MPL-28A Target MPL-28A (Steve) Page 2 Date 18:38, 04 Nov 98 Well l)ata at Intersection of Wl)F on target plane MD 12675.00 fl Inclination Highsidc (ft) Lateral (ft) Random 17.08 54.55 Bias 0.91 -23.72 Semi-Major Axis Uncertainty 54.67 ft Uncertainties at 1-sigma = 68 % confidence 18.945 dcg TVD (ft) 15.94 0.00 % Bias Magmtude Azinmth 286.256 deg 23.74 ft 400 200 - ' ............................. :i~: :~~~: ~~ It ............................ 0 ................................ ~ ........... l' ~¥~~;-~¥~: ~~ ---'%lr-- ~ .................................. -200 ................................ x ................ -40O -400 -200 0 200 East fit) Geological Target 99.(×)% inclusion contour Driller's Target 95.00% inclusion contour 40O Target Analysis Report M I)~ I. I~ad l,'or[n:,lion Kt~l)art[k River TVI) (SS) 6S95.() fl Projection TM Al.$ K4V Datum NAI)27AIq' Well MPI,-28A 'i':~['/4e! MI)L-28A (Slcvc) . Page Dale I 18:38, 04 Nov 98 Latitude Longitude Dip 0.00 (Icg l)ip Azinmth 180.00 dcg 70 30 23.107 N Easting fit) 149 42 06.345 W Northing fit) wrl(;Rll) North 536454.~) 6034928.00 Geological Target Boundary Easting (ft) Northing (ft) 536653.95 6035127.95 536653.98 6034928.00 536638.76 6034851.47 536595.41 6034786.59 536530.53 6034743.24 536454.00 6034728.02 536377.47 6034743.24 536312.59 6034786.59 536269.24 6034851.47 536254.02 6034928.00 536254.05 6035127.95 Driller's Target Boundary Easting (~) Northing (~) 536589.14 6035064.77 536609.26 6035054.87 536619.47 6035024.84 536610.16 6034904.45 536590.29 6034874.24 536520.27 6034843,74 536460.10 6034843,38 536369.61 6034882.95 536349.44 6034902.89 536308,79 6034992,90 536308,55 6035033,01 536318.45 6035053.12 536338.45 6035063.27 TVDSS (fl) Distance(fi) Bearing (deg) 6895.00 282.8 45.00 6895.00 200.0 90.00 6895.00 200.0 112.50 6895.00 200.0 135.00 6895.00 200.0 157.50 6895.00 200.0 180.00 6895.00 200.0 202.50 6895.00 200.0 225.00 6895.00 200.0 247,50 6895.00 200.0 270.00 6895.00 282.8 315.00 TVDSS (~) Distance(fl) Bearing (deg) 6895.00 192.3 44.66 6895.00 200.5 50.75 6895.00 191.7 59.66 6895.00 157.9 98.58 6895.00 146.5 111.53 6895.00 107.2 141.81 6895.00 84.8 175.87 6895.00 95.7 241.90 6895.00 107.5 256.49 6895.00 159.1 294.08 6895.00 179,4 305.83 6895.00 184.5 312.71 6895.00 177.9 319.50 Survey Programme Section Details No Instrument Run Type I Gyrodata drillpipe tnultishot-continuous 2 MWD - Standard (declination corrected) Smrt Depth (ft) End Depth (R) i00.00 10150.00 10150.00 I3100.00 OP;IGiNAL STATE OF ALASKA ALASN,-~ OIL AND GAS CONSERVATION C'~:¢'MMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: ~ Abandon ~] Suspend ~ Plugging i~ Alter Casing [] Repair Well ,'~ Pull Tubing _~ Change Approved Program _F-q" Operation Shutdown , .,i~ Re-Enter Suspended Well 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface At total depth 4113' NSL, 1170' WEL, SEC. 2, T13N, R9E, UM 16475 feet 6693 feet 16158 feet 6625 Length 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of well: ~ Development ~ Exploratory ~! Stratigraphic i~ Service 3680' NSL, 5196' WEL, SEC. 8, T13N, R10E, UM 9. At top of productive interval N/A 10. At effective depth 3889' NSL, 978' WEL, SEC. 2, T13N, R9E, UM 1. Plugs (mea ent retainer at 1631 . Junk (m~s~r'~d) Fish 16685 -16775' 76' 7142' 16539' Structural Conductor Surface Intermediate Production Liner Casing feet Size Cemented i0 sx Arcticset I (Approx.) 9. 1800 sx PF 'E', 900 sx 'G', 300 sx PF 'C' 200 Sx Class 'G' Perforation depth: measured N~/~~ true vertical ~ ~ Tubing(size, grade, and ~~¢h)N/A Packers and SSSV (type and %red depth) Time Extension ~ Perforate Variance ~ Other Stimulate Plug Back for Sidetrack 6. Datum Elevation (DF or KB) KBE = 49.9' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-28i Permit Number 98-14 APl Number 50-029-22859 Field and Pool Milne Point Unit / Kuparuk River Sands 9', Cement retainer at 16208' N/A ;i 13. Attachments ~ Description su ary of proposal 14. Estimated date for commencing o45eration November 26, 1998 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Preston Evans, 564-5540 Detailed operations program .,~ BOP sketch Date approved 15. Status of well classifications as: ~--] Oil ~ Gas ~-~ , . ~ Suspended Service Water & Gas Injector MD TVD 112' 112' 7177' 4471' 16572' 6716' Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 8obLau,e ,~~~,~z~-'~--.~'~ Title Lead Workover/Completions Engineer Date Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- Approval Approved b~/order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 110&98 C½110&98A 100. O0 100. O0 HANDLING INST: S/H KATHY CAMPOAMOR X5122 THE A~ACHED CHECK IS I" PAYMENT FOR ~MS DE~RIBED ABOVE. OO. OO oo 'BP E:~pLORAT!0N (ALASKA),/NC! P.o. BOX: 196612 ':" 'ANCHORAGE, ALASKA ~ 99519-661 PAY :T° The: ALASKA STATE?DEPT.:i. OF REVENUE :O~d e:l~ 'i'!:: ::300 I:';!'.:.:::PoRcuP I'NE! i;:DR':'' '!":::.: . ' ::'" ANCHORAOE ': ',~.:':"': '::':'f':':'~;:? ~' DATE :~:f~:':':;~: ~ :':::~?' ,:;:';;? ~ :' ':':, ':'':AMOUNT.,,, ? ~: .::+',::,:; '::'~ALID A~ER 1~ D~YS ,::::'.:, ':'::. . ':'::: '. ; .... . <': :..:. .,,,,, ,:.v ': ' ::.;: .:.,:.,. :: ':~".~S :': :: ;' '::' >:' ,,. ,::, ......:;~.,. .: .:..::::::: ,,,' ,~.::, ,::':?.,~,::~ :~:. ~ 99501-3120 513 S ;[," '-'0 h i [?.0 :),,q, cl el,-" 008 h · -wELL PERM~:~HECKLIST WELL NAME PROGRAM: exp'~dev [] redrll~serv [] wellbore seg II ann. disposal para req II FIELD & POOL ,_~-2-~_/.~_~> ..... ADMINISTRATION INIT CLASS ~z,,' ./- ~.,, ",/ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected parly ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR... DATE GEOLAREA N 14. Conductor string provided ................... /~ N 15. Surface casing protects all known USDWs ........... y~ N 16. CMl' vol adequate to circulate on conductor & surf csg ..... N 17. cMr vol adequate to tie-in long string to surf csg ........ Y N 18. CMr will cover all known productive horizons .......... (~ N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. ~ N.. 21. If a re-drill, has a ~0-403 for abandonment been approved... N 22. Adequate wellbore separation proposed ............. 23. If d/verier required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ,..~3o~___~ psig. (~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. UNIT// //-.~,..~_._,,~ ON/OFF SHORE __ GEOLOGY APPR DA'f F_2 ANNULAR DISPOSAL APPR DATE - 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~Y N . 31. Data presented on potential overpressure zones ....... Y.,,N" ~,~,//~_ 32. Seismic analysis of shallow gas zones. ' ~ ., 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone.for weekly progress reports ....... / Y N [exploratory only] 35. With proper cementing records, this pi, an (A) will contain waste in/~suitable re/~Zeiving zone; ....... Y N (B) will not contaminate fr~shwate, K', or cause drilling waste... Y N lo surface; J ~ (C) wdl not'tmpalr.._rnechan~a~if~tegrity of the well used for dtsposal Y N (D) will nol damage prong formation or impair recovery from a Y N pool; and / ~ (E) will not circumvent 20 AAC~52 or 20 AAC 25.412.' ,,. :, Y N GEO, LJ;;;)~Y: COMMISSION: Comments/Instructions: M cheklisl mv 05~29~98 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. * ALASKA COMPUTING CENTER . . ............................ ....... SCHLUlVZBERGER ....... . COMPANY NAME : BP EXPLOKATION WELL NAME : MPL-28A FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292285901 REFERENCE NO : 99069 ?:~ 24 1999 A~aska Oil a Gas Cons. Commi~io[~ ,~chora~e LIS Tape Verif£=udion Listing Schlumberger Alaska Computing Center 17-FEB-1999 11:50" PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/02/17 ORIGIN : FLIC REEL NAME : 99069 CONTINUATION # : PREVIOUS REEL : COf/k4ENT : BP EXPLORATION, MILNE POINT, MPL-28Aj API #50-029-22859-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/02/17 ORIGIN : FLIC TAPE NAME : 99069 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, MILNE POINT, MPL-28A, API #50-029-22859-01 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOP~qSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN1 ......... 99069 J. RATHERT J PYRON WELL CASING RECORD 1ST STRING 2ND STRING MPL-28A 00292285901 BP EXPLORATION SCHLUMBERGER WELL SERVICES 17-FEB-99 BIT RUN 2 BIT RUN 3 8 13N tOE 3680 5196 49.90 49.90 16.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 24.000 20.000 112.0 12.250 9.625 7177.0 LIS Tape Verifih~tion Listing Schlumberger Alaska Computing Center 17-FEB-1999 11:50~-~' 3RD STRING 8. 500 PRODUCTION STRING 7.000 REMARKS: CONTAINED HEREIN IS SCHLUMBERGER ANADRILL'S MEASUREMENT WHILE DRILLING CDR RESISTIVITY DATA. DEPTH SHIFTING HAS BEEN WAIVED AT CLIENTS REQUEST. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUFk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH ~ 7150.0 12859.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: THIS FILE CONTAINS THE MEASUREMENT WHILE DRILLING DATA ACQUIRED USING ANADRILLS CDR RESISTIVITY TOOL. ONLY ONE BIT RUN WAS ACQUIRED FROM 7150' TO 12859'. DEPTH SHIFTING WAS WAIVED AT CLIENTS REQUEST. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verifi'cation Listing Schlumberger Alaska Computing Center 17-FEB-1999 11:50~ ~ PAGE: 3 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT ll 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 i 1 4 68 0000000000 RA MWD OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~I O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHNk4 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7150.000 FET.MWD 0.679 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 82.575 GR.MWD 49.748 DEPT. 12859.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 165.209 GR.k4WD -999.250 ** END OF DATA ** LIS Tape Verifi'ca'~ion Listing Schlumberger Alaska Computing Center 17-FEB-1999 11:50 .... '~ PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~BER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 7150.0 12860.0 CDR $ LOG HEADER DATA DATE LOGGED: 6 -JAN- 99 SOFTWARE: SURFACE SOFTWARE VERSION: ID5 OC O1 DOWNHOLE SOFTWARE VERSION: CDR VS. OC DATA TYPE (MEMORY or REAL-TIME): MEMORY TD DRILLER (FT) : 12860.0 TOP LOG INTERVAL (FT) : 7150.0 BOTTOM LOG INTERVAL (FT) : 12860.0 BIT ROTATING SPEED (RPM) : 90 HOLE INCLINATION (DEG) MINIMUM ANGLE: 18.5 MAXIMUM ANGLE: 75.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RES I STIVI TY/GR $ TOOL NI3?~BER CDR 7077 LIS Tape Verifi-C~ion Listing Schlumberger Alaska Computing Center 17-FEB-1999 11:50 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. 8.500 7177.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 600 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 400 MUD CAKE AT (MT): 1. 700 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 ************* RUN #1 FROM 7177' TO 12860' TOOLS: ~IDC 379, CDR 7077 SOFTWARE: MDC V5.0 CDR VS.0C, ID50C O1 9.625" CASING SHOE AT 7177' SIDETRACK STARTS 7250'. $ LIS FORMAT DATA 68.0 65.0 63.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 LIS Tape Verifio-~tion Listing Schlumberger Alaska Computing Center 17-FEB-1999 11:50'~.J. PAGE: TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM3~ SAMP ELE~I CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 TVDE LW1 FT O0 000 O0 0 2 1 1 4 68 0000000000 ROP$ LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OH~4 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 Ot~4~I O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LW1 OH~4 O0 000 O0 0 2 1 1 4 68 0000000000 PSVR LW1 0I~4~4 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7150. 000 TVDE.LW1 4464. 851 ROPS.LW1 82.575 TABR.LW1 ATR. LW1 - 999. 250 PSR. LW1 - 999. 250 GR . LWl 49 . 748 ATVR. LW1 PSVR. LW1 -999. 250 DEPT. 12860. 000 TVDE. LW1 7323.167 ROP5. LW1 165.138 TABR. LW1 ATR. LW1 1.815 PSR. LW1 1. 812 GR. LW1 99.507 ATVR. LW1 PSVR. LW1 -999. 250 2446.000 -999.250 34778.531 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE . 99/02/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verif~.~cion Listing Schlumberger Alaska Computing Center 17-FEB-1999 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/02/17 ORIGIN : FLIC TAPE NAME : 99069 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT · BP EXPLORATION, MILNE POINT, MPL-28A, API #50-029-22859-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 99/02/17 ORIGIN · FLIC REEL NAME · 99069 CONTINUATION # : PREVIOUS REEL : COM~4ENT · BP EXPLORATION, MILNE POINT, MPL-28A, API #50-029-22859-01 1. OperatiOns p(~rf0rmed: 'r-i ~peration 'Sl~utci0wn' !-I Stimulate' ~ Pull Tubing 2. Name of Operator BP Exploration (Alaska) Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 99519-6612 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 3680' NSL, 5196' WEL, SEC. 08, T13N, R10E, UM At top of productive interval 1540' NSL, 2908' WEL, SEC. 01, T13N, R09E, UM At effective depth 1581' NSL, 3008' WEL, SEC. 01, T13N, R09E, UM At total depth 1592' NSL, 3034' WEL, SEC. 01, T13N, R09E, UM , , ,, , 12.' Present Weil Condition summary Total depth: measured true vertical measured true vertical Effective depth: 12860 feet 7323 feet 12769 feet 7237 feet Length 76' 7142' 12819' D i~lugging F1 Perforate r-I Alter Casing I~ Repair Well I~1 Other Size 20" 9-5/8" 7" Casing Structural 5. Type of well: I~ Development I~ Exploratory I"i Stratigraphic D Service Plugs (measured) Junk (measured) Conductor Surface Intermediate Production Liner Cemented 250 sx Arcticset I (Approx.) 500 sx PF E, 900 sx G, 1300 PF E, 300 sx C 250 sx Class 'G' Change Out ESP 6. Datum Elevation (DF or KB) KBE = 49.90' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-28A 9. Permit Number / Approval No. 198-247 10. APl Number 50-029-22859-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands ...... MD TVD 112' 112' 7177' 4471' 12852' 7316' Perforation depth: measured 12458' - 12478' true vertical 6945' - 6963' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12411' Packers and SSSV (type and measured depth) None 131 siimul'ation'o'~ cemeni' squeeze s'Umrna~y'' Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JUH 1 8 2OO2 Alaska 0il & Gas Anchorage 14. Oil-Bbl Prior to well operation: Subsequent to operation: 15. Attachments r-I copies of Logs and Surveys run IR! Daily Report of Well Operations Representative Daily Average Production'or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 16. Status of well classifications as: I~ Oil D Gas r"! Suspend;~jl~N~d~j 17. I hereby certify that the foregoing is true and correct to the best of my knowledge _ Signed itle TechnicaiAssistant Date ~~)"-I ~-~'~~ · ' - ~ Prepared By Name/Number: Sor~dra steWman, 564'4750 Form10-404 Rev. 06/15/88 0~[~I~~iAL ' Submit ln Duplicate Legal Well Name: MPL-28 Common Well Name: MPL-28 Spud Date: 4/6/1998 Event Name: WORKOVER Start: 6/3/2002 End: 6/5/2002 Contractor Name: NABORS Rig Release: 6/5/2002 Rig Name: NABORS 4ES Rig Number: i:~::~.Desc~iPtiOn~0fOPerati:ons,' :6~3~2002 18:00 - 00:00 6.00 MOB P PRE RIG DOWN OF MPK-02 & MIRU ON MPL-28 6~4~2002 00:00 - 02:00 2.00 MOB P PRE RIG UP 02:00- 03:00 1.00 KILL P DECOMP RIG LINES TO TRE & TIGER TANK 03:00 -03:30 0.50 KILL P DECOMP RIG LUB & PULL BPV 03:30 -04:30 1.00 KILL P DECOMP TAKE ON SEA WATER & TEST LINES TO 3500 PSI. 04:30 - 08:30 4.00 KILL P DECOMP BULL HEAD ANNULUS INFLUX INTO FORMATION & BULL HEAD TBG. 08:30 - 10:00 1.50 WHSUR P DECOMP SET TWC TEST & NIPPLE DN TREE 10:00- 12:00 2.00 BOPSUF P DECOMP NIPPLE UP BOP 12:00 - 1:3:00 1.00 BOPSUF P DECOMP TEST BOP (BODY TEST & FUNCTION TO 250 LOW & :3500 HIGH) 13:00- 14:00 1.00 PULL P DECOMP MU LANDING JT. TO HANGER & PULL SAME TO SURFACE & TEST & LAY DN. 14:00- 15:00 1.00 PULL P DECOMP REVERSE CIRC INFLUX OUT OF TBG. 15:00- 16:30 1.50 PULL P DECOMP POOH TO ESP CABLE SPLICE 16:30 - 17:00 0.50 PULL P DECOMP CHANGE OUT ESP CABLE SPOOL 17:00- 22:00 5.00 PULL P DECOMP CONTINUE TO POH TO ESP ASSY 22:00- 00:00 2.00 PULL P DECOMP LAY DN ESP COMPLETION 6~5~2002 00:00- 01:00 1.00 PULL P DECOMP LAY DN ESP COMPLETION 01:00 - 03:30 2.50 RUNCOI~ COMP MU ESP ASSY. 03:30 - 08:00 4.50 RUNCO~ COMP SPLICE ESP TO MOTOR LEAD 08:00- 12:30 4.50 RUNCOI~ COMP RIH TO 7700' 12:30- 14:30 2.00 RUNCOI~!~ COMP CHANGE REELS & SPLICE ESP CABLE MID-LINE 14:30- 17:00 2.50 RUNCOI~ COMP RIH WITH ESP COMPLETION TO SETTING DEPTH @12411' 17:00- 19:00 2.00 RUNOOI~/F:' COMP MU HANGER & MAKE EFT CONNECTOR TO CABLE & ATTACH TO HANGER & TEST SAME. 19:00- 20:00 1.00 RUNGOI~/F:' COMP LAND HANGER 20:00- 20:30 0.50 RUNCOI~ COMP SAFETY MEETING (BP ANHORAGE PERSONELL) 20:30 - 22:00 1.50 BOPSUI; P COMP SET TWC & TEST & ND BOP 22:00 - 23:00 1.00 WHSUR P COMP NIPPLE UP TREE & TEST TO 5000 PSI. & MAKE FINAL ESP CHECK. 23:00- 00:00 1.00 WHSUR 3 COMP RIG LUB & PULL TWC & SET BPV (RIG RELEASED @ 2359 HRS. 6~5~2002 Pri~ ~/10/2002 9:26:45 AM
