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Home My WebLink About200-1031. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 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): 13,094' N/A Casing Collapse Conductor N/A Production 3,090psi 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 WTRSP Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Lewis Contact Email: Contact Phone: 303-906-5178 Authorized Title: 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 N/A 7,197' 5,518' 3,668' 872 4,176' Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT I-09 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2/15/2026 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 200-103 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22964-00-00 Hilcorp Alaska LLC C.O. 477.05 Size Proposed Pools: 110' 110' 17# / L-80 / IBT TVD Burst 3,022' MILNE POINT SCHRADER BLUFF OIL 110' 20" 9-5/8"6,562' MD N/A 5,750psi4,087'6,562' Length 9-5/8" Versa-Trieve and N/A 3,183 MD/ 2,689 TVD and N/A ryan.lewis@hilcorp.com Perforation Depth MD (ft): See Schematic See Schematic 5.5" Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Wells Manager Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2026.01.27 08:51:58 - 09'00' Taylor Wellman (2143) 326-060 By Grace Chistianson at 9:24 am, Jan 27, 2026 DSR-2/2/26TS 1/28/26BJM 2/9/26 10-404 Note: this is a change to sundry 325-026. BOP test to 1500 psi. JLC 2/10/2026 02/10/26 Well: MPI-09 PTD: 200-103 API: 50-029-22964-00-00 Well Name:MPI-09 API Number:50-029-22964-00-00 Current Status:Shut-in WSW Rig:ASR #1 Estimated Start Date:2/15/2026 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:200-103 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1146 psi @ ,2607 TVD 12/22/2025 | 8.45 EMW, 8.6 KWF Max Potential Surface Pressure: 885 psi Gas Column Gradient (0.1 psi/ft) Max Angle:59° Sail Angle from 3,077 MD DSL: Brief Well Summary: MPU I-09 is a current online WSW averaging 12,000 BWPD. 2024 the ESP was upsized to produce 24,000 BWPD. The rate burned through the screens and the gravel pack proppant to surface. We produced the well at 7K BWPD and it would not produce sand and proppant but the pump ran in downthrust and twisted a shaft. Our goal is to shut off the sand and regain productivity from the well. Objectives: Pull failed ESP completion, Set a RBP between sets of perfs, Run new ESP completion. Notes Regarding Wellbore Condition: The 9-5/8 production casing passed an MIT to 2000 psi on 6/20/20 Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 1,500psi high. 2. Drift and tag with sample bailer. 3. Caliper the 5-1/2 tubing from the discharge head at 2,913 to surface. 4. RDMO. Coiled Tubing (Contingency) 1. Pressure test PCE per CT weekly test protocol. 2. PU Down jet nozzle. 3. Jet down to discharge head at 2,913 MD. 4. Following best practices in PE manual, pump gel sweeps to clean up tubing. 5. Chase gel out of hole. 6. PU a Read 40-arm Caliper and log from 2,913 MD to surface. a. Reads main dispatch 907-250-8233 7. PU tubing punch with 5 of titan Circ charges at 2,908 MD 8. RIH and tag discharge head. 9. Pump down ball to fire tubing punch. 10. Confirm circulation by pumping down backside of coil. 11. Freeze protect tubing as POOH. 12. RDMO. Well: MPI-09 PTD: 200-103 API: 50-029-22964-00-00 Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.6# brine tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of 8.6# brine. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with 8.6# brine prior to setting CTS. 3. Test BOPE to 250 psi low/ 1,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test 5-1/2 ram on test joint. e. Test VBR rams on 3-1/2 test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 8.6# brine as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Summit for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an 11 5M FMC Gen 6 w/ 5-1/2 TC-II T&B Thread FMC Tubing Hanger 5.0 CIW H BPV Profile b. 2024 tubing PU weight on ASR #1 recorded as 58 kip. Slack off weight recorded as 43 kip. c. 5-1/2 17# L-80 JFEBear yield is 397 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 5-1/2 tubing. a. Plan to re-use the tubing based on the caliper results. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. Well: MPI-09 PTD: 200-103 API: 50-029-22964-00-00 d. Recorded Clamp Totals: i. Canon Clamps: 50 ii. Motor Clamps: 4 iii. Seal clamps: 4 iv. Pump Clamps: 4 10. Lay Down ESP. 11. PU 3-1/2 workstring, 5-1/2 casing scraper, and muleshoe. RIH to 4,163 MD, bottom of screens. 12. Circulate well clean. 13. Scrape casing interval from 3,765 to 3,915 MD. 14. POOH while filling hole with 2x displacement. Eline On rig assist: 15. RU Eline. 16. RIH with a Read 40 arm caliper across the screens 4,163 3,213 MD. a. Have Read prepared for rush processing prior to running RBP. 17.RIH with a LDL (temp spinner) a.Tie in to the 5.5 screen tally. b.Drop down to below the screens @ 4,163 MD. Log baseline pass up to 3,290MD c.Drop back down to 4,163MD. d.Start pumping 5-7 BPM from uprights with clean source water. e.Log up to the top of the screens 3,290MD. Contingency: Make determination if we are going to set the Baker RBP or a Tripoint patch across the screens. 18. RIH with Baker 5-1/2 RBP and set in the middle of the pup at +-3,794 MD. 19. POOH. RD Eline. Or: 20.If we are going to set a patch. RIH and set the 5-1/2 x 3.00 Permapak lower packer on Eline at a depth determined by the LDL. 21. TIH with sealbore assembly, spacer pipe and 5-1/2 x 3.00 Permapak upper packer. a. The length of spacer pipe will be based the LDL results. 22. Sting into sealbore, drop the ball and set the upper packer and shear out of it with the running tools. 23. TOOH. 24. RIH with 5-1/2 17# L-80 JFEBear ESP completion to +/- 3,130 MD and obtain string weights. a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. c. Install ESP clamps per Summit, and cross coupling clamps every joint for the 1 st 32 joints, then every other joint. Nom. Size Length Item Lb/ft Material 5.85 2 Centralizer 4 4.5 2 Zenith Sensor 30 5.62 31 Motor - 500HP 80 5.62 31 Motor - 500HP 80 Well: MPI-09 PTD: 200-103 API: 50-029-22964-00-00 5.2 9 Lower Tandem Seal 38 5.2 9 Upper Tandem Seal 38 5.2 1 Intake/Gas Separator 52 6.75 21 Pumps PMP 675 SH22000 45 1 Ported Discharge Head 13 L-80 5-1/21 CROSSOVER 5.5'' IBT BOX X 4.5'' 8RND EUE 5-1/29 Handling Pup Joint 5.5'' IBT 5-1/2 3 XO - 5-1/2",17#,L, JFEBEAR Box x IBT Pin 5-1/2 42 5-1/2",17#,L, JFEBEAR R3 L-80 5-1/2 2 XO - 5-1/2",17#,L, IBT Box x JFEBEAR Pin L-80 5-1/210 5 1/2",17.0#,L-80, IBT Pup Joint L-80 5-1/22 XN-Nipple 4.563" Profile, 4.455" No-Go L-80 5-1/210 5 1/2",17.0#,L-80, IBT Pup Joint L-80 5-1/2 3 XO - 5-1/2",17#,L, JFEBEAR Box x IBT Pin L-80 5-1/2 2914 5-1/2",17#,L, JFEBEAR R3 5-1/2 2 XO - 5-1/2",17#,L, IBT Box x JFEBEAR Pin L-80 5-1/2 2 5-1/2",17#,L,TC-II Pin x IBT Pin HGRPup Joint 5-1/2 1 11"x 5-1/2" TC-II Top & BTM Gen 6 HGR L-80 25. Land tubing hanger. Use extra caution to not damage cable. 26. Lay down landing joint. 27. Set BPV. 28. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Triple BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 11/17/2025 SCHEMATIC Milne Point Unit Well: MP I-09 Last Completed: 6/13/2024 PTD: 200-103 TD =13,094(MD) / TD =7,197(TVD) 20 Orig. KB Elev.:62.25/ Orig. GL Elev.:35.0 RKB Tbg Hngr: 21.55 (Nabors 4ES) 9-5/8 2 7 & 8 13 12 14 Estimated TOC ~5,518 PBTD =5,089 (MD) / PBTD =3,477(TVD) 3 TAM Port Colalr 979 MD Lower Prince Ck Middle Prince Ck 10 11 9 4 5 & 6 1 15 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124 18.936 Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835 8.679 Surface 6,562 0.0758 TUBING DETAIL 5-1/2 Tubing 17 / L-80 / JFEBEAR 4.892 4.767 Surface 3,022 0.0232 JEWELRY DETAIL No. Top MD Item ID 1 2,844 XN Nipple HES 4.562"w/ 4.455" No Go 4.455 2 2,913 Ported Press. Sub Sensor & B/O Discharge Head: 675X 416SS N/A 3 2,915 Pump 1: PMP 675 SH35000 37 INC 15 1:1 XRC SH8TS3 N/A 4 2,937 Gas Intake: 675-513 INC 41665 SN N/A 5 2,938 Upper Tandem Seal: 513 SERIES BPBSL INCONEL SHAFT N/A 6 2,947 Lower Tandem Seal: 513 SERIES BPBSL INCONEL SHAFT N/A 7 2,956 Motor #2: 562 KMS3 LT 500HP1800V 17A EXD WB N/A 8 2,986 Motor #1: 562 KMS3 LT 500HP1800V 17A EXD WB N/A 9 3,017 Zenith Guage E7 w/ Centralizer:Btm @ 3,022 N/A LOWER COMPLETION DETAIL 10 3,183 9-5/8 Versa-Trieve Packer 6.000 11 3,213 Blank Pipe, 5-1/2, 17#, L-80, LTC Blank Pipe 4.860 12 3,300 5-1/2 Gravel Pack Screens (250 Micron) Top 4.818 13 4,166 5-1/2 Gravel Pack Screens (250 Micron) Bottom 4.818 14 4,166 Shoe:Bottom @ 4,1674.818 15 4,176 CIBP CTMD 0 TREE & WELLHEAD Tree Cameron FLS, 7 x 5-1/2 - 5M Wellhead 11 5M FMC Gen 6 w/ 5-1/2 TC-II T&B Thread FMC Tubing Hanger 5.0 CIW H BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 8/13/2000 Convert to Injector Nabors 4ES 7/03/2002 ESP Completion w/ Lower Screens 6/27/2020 ESP Swap w/ ASR#1 6/13/2024 OPEN HOLE / CEMENT DETAIL 20 260 sx Arctic Set (Approx.) in a 24 Hole 9-5/8 840 sx ASL, 385 sx Class G in a 12-1/4 PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310 3,765 2,746 2,963 455 12 4-5/8 6/25/2020 Open Lower PC 3,915 4,155 2,983 3,077 240 12 4-5/8 6/25/2020 Open Ref Log: USIT 8/12/2000 Perf Guns 4-5/8, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400 Max hole angle = 68 deg. At 3,636 MD Ange at perfs = 68 deg _____________________________________________________________________________________ Revised By: TDF 1/13/2026 PROPOSED Milne Point Unit Well: MP I-09 Last Completed: 6/13/2024 PTD: 200-103 TD =13,094(MD) / TD =7,197(TVD) 20 Orig. KB Elev.:62.25/ Orig. GL Elev.:35.0 RKB Tbg Hngr: 21.55 (Nabors 4ES) 9-5/8 2 7 & 8 13 14 12 15 Estimated TOC ~5,518 PBTD =5,089 (MD) / PBTD =3,477(TVD) 3 TAM Port Colalr 979 MD Lower Prince Ck Middle Prince Ck 10 11 9 4 5 & 6 1 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124 18.936 Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835 8.679 Surface 6,562 0.0758 TUBING DETAIL 5-1/2 Tubing 17 / L-80 / JFEBEAR 4.892 4.767 Surface ±X,XXX 0.0232 JEWELRY DETAIL No. Top MD Item ID 1 ±X,XXX XN Nipple HES 4.562" w/ 4.455" No Go 4.455 2 ±X,XXX Ported Press. Sub Sensor & B/O Discharge Head:N/A 3 ±X,XXX Pump: PMP N/A 4 ±X,XXX Gas Intake:N/A 5 ±X,XXX Upper Tandem Seal:N/A 6 ±X,XXX Lower Tandem Seal:N/A 7 ±X,XXX Motor #2:N/A 8 ±X,XXX Motor #1:N/A 9 ±X,XXX Zenith Guage w/ Centralizer: Btm @ ±X,XXXN/A LOWER COMPLETION DETAIL 10 3,183 9-5/8 Versa-Trieve Packer 6.000 11 3,213 Blank Pipe, 5-1/2, 17#, L-80, LTC Blank Pipe 4.860 12 3,300 5-1/2 Gravel Pack Screens (250 Micron) Top 4.818 13 ±4,163 REBP 14 4,166 5-1/2 Gravel Pack Screens (250 Micron) Bottom 4.818 15 4,166 Shoe:Bottom @ 4,1674.818 16 4,176 CIBP CTMD 0 TREE & WELLHEAD Tree Cameron FLS, 7 x 5-1/2 - 5M Wellhead 11 5M FMC Gen 6 w/ 5-1/2 TC-II T&B Thread FMC Tubing Hanger 5.0 CIW H BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 8/13/2000 Convert to Injector Nabors 4ES 7/03/2002 ESP Completion w/ Lower Screens 6/27/2020 ESP Swap w/ ASR#1 6/13/2024 OPEN HOLE / CEMENT DETAIL 20 260 sx Arctic Set (Approx.) in a 24 Hole 9-5/8 840 sx ASL, 385 sx Class G in a 12-1/4 PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310 3,765 2,746 2,963 455 12 4-5/8 6/25/2020 Open Lower PC 3,915 4,155 2,983 3,077 240 12 4-5/8 6/25/2020 Open Ref Log: USIT 8/12/2000 Perf Guns 4-5/8, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400 Max hole angle = 68 deg. At 3,636 MD Ange at perfs = 68 deg Updated 1/13/2026 11 BOPE INTEGRATED 11'-5000 INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind 11'- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 5-1/2" Pipe Ram Milne Point ASR 11 BOP w/ Jacks 05/17/2017 Milne Point ASR 11 BOP (Triple) 1/13/2026 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 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): 13,094' N/A Casing Collapse Conductor N/A Production 3,090psi 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 WTRSP Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Lewis Contact Email: Contact Phone: 303-906-5178 Authorized Title: 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 9-5/8" Versa-Trieve and N/A 3,183 MD/ 2,689 TVD and N/A ryan.lewis@hilcorp.com Perforation Depth MD (ft): See Schematic See Schematic 5.5" 110' 20" 9-5/8"6,562' MD N/A 5,750psi4,087'6,562' Length Size Proposed Pools: 110' 110' 17# / L-80 / IBT TVD Burst 3,022' MILNE POINT SCHRADER BLUFF OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 200-103 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22964-00-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2/15/2026 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT I-09 N/A 7,197' 5,518' 3,668' 885 4,176' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2026.01.13 16:29:35 - 09'00' Taylor Wellman (2143) 326-026 By Grace Christianson at 8:20 am, Jan 14, 2026 10-404 MGR15JAN2026 SFD 1/14/2026 * BOPE test to 1500 psi. DSR-1/22/26JLC 1/22/2026 01/22/26 Well: MPI-09 PTD: 200-103 API: 50-029-22964-00-00 Well Name:MPI-09 API Number:50-029-22964-00-00 Current Status:Shut-in WSW Rig:ASR #1 Estimated Start Date:2/15/2026 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:200-103 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1146 psi @ ,2607 TVD 12/22/2025 | 8.45 EMW, 8.6 KWF Max Potential Surface Pressure: 885 psi Gas Column Gradient (0.1 psi/ft) Max Angle:59° Sail Angle from 3,077 MD DSL: Brief Well Summary: MPU I-09 is a current online WSW averaging 12,000 BWPD. 2024 the ESP was upsized to produce 24,000 BWPD. The rate burned through the screens and the gravel pack proppant to surface. We produced the well at 7K BWPD and it would not produce sand and proppant but the pump ran in downthrust and twisted a shaft. Our goal is to shut off the sand and regain productivity from the well. Objectives: Pull failed ESP completion, Set a RBP between sets of perfs, Run new ESP completion. Notes Regarding Wellbore Condition: The 9-5/8 production casing passed an MIT to 2000 psi on 6/20/20 Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 1,500psi high. 2. Drift and tag with sample bailer. 3. Caliper the 5-1/2 tubing from the discharge head at 2,913 to surface. 4. RDMO. Coiled Tubing (Contingency) 1. Pressure test PCE per CT weekly test protocol. 2. PU Down jet nozzle. 3. Jet down to discharge head at 2,913 MD. 4. Following best practices in PE manual, pump gel sweeps to clean up tubing. 5. Chase gel out of hole. 6. PU a Read 40-arm Caliper and log from 2,913 MD to surface. a. Reads main dispatch 907-250-8233 7. PU tubing punch with 5 of titan Circ charges at 2,908 MD 8. RIH and tag discharge head. 9. Pump down ball to fire tubing punch. 10. Confirm circulation by pumping down backside of coil. 11. Freeze protect tubing as POOH. 12. RDMO. Well: MPI-09 PTD: 200-103 API: 50-029-22964-00-00 Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.6# brine tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of 8.6# brine. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with 8.6# brine prior to setting CTS. 3. Test BOPE to 250 psi low/ 1,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test 5-1/2 ram on test joint. e. Test VBR rams on 3-1/2 test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 8.6# brine as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Summit for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an 11 5M FMC Gen 6 w/ 5-1/2 TC-II T&B Thread FMC Tubing Hanger 5.0 CIW H BPV Profile b. 2024 tubing PU weight on ASR #1 recorded as 58 kip. Slack off weight recorded as 43 kip. c. 5-1/2 17# L-80 JFEBear yield is 397 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 5-1/2 tubing. a. Plan to re-use the tubing based on the caliper results. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. Well: MPI-09 PTD: 200-103 API: 50-029-22964-00-00 d. Recorded Clamp Totals: i. Canon Clamps: 50 ii. Motor Clamps: 4 iii. Seal clamps: 4 iv. Pump Clamps: 4 10. Lay Down ESP. 11. PU 3-1/2 workstring, 5-1/2 casing scraper, and muleshoe. RIH to 4,163 MD, bottom of screens. 12. Circulate well clean. 13. Scrape casing interval from 3,765 to 3,915 MD. 14. POOH while filling hole with 2x displacement. Eline On rig assist: 15. RU Eline. 16. RIH with a Read 40 arm caliper across the screens 4,163 3,213 MD. a. Have Read prepared for rush processing prior to running RBP. 17. RIH with Baker 5-1/2 RBP and set in the middle of the pup at +-3,794 MD. 18. POOH. RD Eline. 19. RIH with 5-1/2 17# L-80 JFEBear ESP completion to +/- 3,130 MD and obtain string weights. a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. c. Install ESP clamps per Summit, and cross coupling clamps every joint for the 1 st 32 joints, then every other joint. Nom. Size Length Item Lb/ft Material 5.85 2 Centralizer 4 4.5 2 Zenith Sensor 30 5.62 31 Motor - 500HP 80 5.62 31 Motor - 500HP 80 5.2 9 Lower Tandem Seal 38 5.2 9 Upper Tandem Seal 38 5.2 1 Intake/Gas Separator 52 6.75 21 Pumps PMP 675 SH22000 45 1 Ported Discharge Head 13 L-80 5-1/21 CROSSOVER 5.5'' IBT BOX X 4.5'' 8RND EUE 5-1/29 Handling Pup Joint 5.5'' IBT 5-1/2 3 XO - 5-1/2",17#,L, JFEBEAR Box x IBT Pin 5-1/2 42 5-1/2",17#,L, JFEBEAR R3 L-80 5-1/2 2 XO - 5-1/2",17#,L, IBT Box x JFEBEAR Pin L-80 5-1/210 5 1/2",17.0#,L-80, IBT Pup Joint L-80 5-1/22 XN-Nipple 4.563" Profile, 4.455" No-Go L-80 5-1/210 5 1/2",17.0#,L-80, IBT Pup Joint L-80 5-1/2 3 XO - 5-1/2",17#,L, JFEBEAR Box x IBT Pin L-80 5-1/2 2914 5-1/2",17#,L, JFEBEAR R3 Well: MPI-09 PTD: 200-103 API: 50-029-22964-00-00 5-1/2 2 XO - 5-1/2",17#,L, IBT Box x JFEBEAR Pin L-80 5-1/2 2 5-1/2",17#,L,TC-II Pin x IBT Pin HGRPup Joint 5-1/2 1 11"x 5-1/2" TC-II Top & BTM Gen 6 HGR L-80 20. Land tubing hanger. Use extra caution to not damage cable. 21. Lay down landing joint. 22. Set BPV. 23. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Triple BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 11/17/2025 SCHEMATIC Milne Point Unit Well: MP I-09 Last Completed: 6/13/2024 PTD: 200-103 TD =13,094(MD) / TD =7,197(TVD) 20 Orig. KB Elev.:62.25/ Orig. GL Elev.:35.0 RKB Tbg Hngr: 21.55 (Nabors 4ES) 9-5/8 2 7 & 8 13 12 14 Estimated TOC ~5,518 PBTD =5,089 (MD) / PBTD =3,477(TVD) 3 TAM Port Colalr 979 MD Lower Prince Ck Middle Prince Ck 10 11 9 4 5 & 6 1 15 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124 18.936 Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835 8.679 Surface 6,562 0.0758 TUBING DETAIL 5-1/2 Tubing 17 / L-80 / JFEBEAR 4.892 4.767 Surface 3,022 0.0232 JEWELRY DETAIL No. Top MD Item ID 1 2,844 XN Nipple HES 4.562"w/ 4.455" No Go 4.455 2 2,913 Ported Press. Sub Sensor & B/O Discharge Head: 675X 416SS N/A 3 2,915 Pump 1: PMP 675 SH35000 37 INC 15 1:1 XRC SH8TS3 N/A 4 2,937 Gas Intake: 675-513 INC 41665 SN N/A 5 2,938 Upper Tandem Seal: 513 SERIES BPBSL INCONEL SHAFT N/A 6 2,947 Lower Tandem Seal: 513 SERIES BPBSL INCONEL SHAFT N/A 7 2,956 Motor #2: 562 KMS3 LT 500HP1800V 17A EXD WB N/A 8 2,986 Motor #1: 562 KMS3 LT 500HP1800V 17A EXD WB N/A 9 3,017 Zenith Guage E7 w/ Centralizer:Btm @ 3,022 N/A LOWER COMPLETION DETAIL 10 3,183 9-5/8 Versa-Trieve Packer 6.000 11 3,213 Blank Pipe, 5-1/2, 17#, L-80, LTC Blank Pipe 4.860 12 3,300 5-1/2 Gravel Pack Screens (250 Micron) Top 4.818 13 4,166 5-1/2 Gravel Pack Screens (250 Micron) Bottom 4.818 14 4,166 Shoe:Bottom @ 4,1674.818 15 4,176 CIBP CTMD 0 TREE & WELLHEAD Tree Cameron FLS, 7 x 5-1/2 - 5M Wellhead 11 5M FMC Gen 6 w/ 5-1/2 TC-II T&B Thread FMC Tubing Hanger 5.0 CIW H BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 8/13/2000 Convert to Injector Nabors 4ES 7/03/2002 ESP Completion w/ Lower Screens 6/27/2020 ESP Swap w/ ASR#1 6/13/2024 OPEN HOLE / CEMENT DETAIL 20 260 sx Arctic Set (Approx.) in a 24 Hole 9-5/8 840 sx ASL, 385 sx Class G in a 12-1/4 PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310 3,765 2,746 2,963 455 12 4-5/8 6/25/2020 Open Lower PC 3,915 4,155 2,983 3,077 240 12 4-5/8 6/25/2020 Open Ref Log: USIT 8/12/2000 Perf Guns 4-5/8, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400 Max hole angle = 68 deg. At 3,636 MD Ange at perfs = 68 deg _____________________________________________________________________________________ Revised By: TDF 1/13/2026 PROPOSED Milne Point Unit Well: MP I-09 Last Completed: 6/13/2024 PTD: 200-103 TD =13,094(MD) / TD =7,197(TVD) 20 Orig. KB Elev.:62.25/ Orig. GL Elev.:35.0 RKB Tbg Hngr: 21.55 (Nabors 4ES) 9-5/8 2 7 & 8 13 14 12 15 Estimated TOC ~5,518 PBTD =5,089 (MD) / PBTD =3,477(TVD) 3 TAM Port Colalr 979 MD Lower Prince Ck Middle Prince Ck 10 11 9 4 5 & 6 1 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124 18.936 Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835 8.679 Surface 6,562 0.0758 TUBING DETAIL 5-1/2 Tubing 17 / L-80 / JFEBEAR 4.892 4.767 Surface ±X,XXX 0.0232 JEWELRY DETAIL No. Top MD Item ID 1 ±X,XXX XN Nipple HES 4.562" w/ 4.455" No Go 4.455 2 ±X,XXX Ported Press. Sub Sensor & B/O Discharge Head:N/A 3 ±X,XXX Pump: PMP N/A 4 ±X,XXX Gas Intake:N/A 5 ±X,XXX Upper Tandem Seal:N/A 6 ±X,XXX Lower Tandem Seal:N/A 7 ±X,XXX Motor #2:N/A 8 ±X,XXX Motor #1:N/A 9 ±X,XXX Zenith Guage w/ Centralizer: Btm @ ±X,XXXN/A LOWER COMPLETION DETAIL 10 3,183 9-5/8 Versa-Trieve Packer 6.000 11 3,213 Blank Pipe, 5-1/2, 17#, L-80, LTC Blank Pipe 4.860 12 3,300 5-1/2 Gravel Pack Screens (250 Micron) Top 4.818 13 ±4,163 REBP 14 4,166 5-1/2 Gravel Pack Screens (250 Micron) Bottom 4.818 15 4,166 Shoe:Bottom @ 4,1674.818 16 4,176 CIBP CTMD 0 TREE & WELLHEAD Tree Cameron FLS, 7 x 5-1/2 - 5M Wellhead 11 5M FMC Gen 6 w/ 5-1/2 TC-II T&B Thread FMC Tubing Hanger 5.0 CIW H BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 8/13/2000 Convert to Injector Nabors 4ES 7/03/2002 ESP Completion w/ Lower Screens 6/27/2020 ESP Swap w/ ASR#1 6/13/2024 OPEN HOLE / CEMENT DETAIL 20 260 sx Arctic Set (Approx.) in a 24 Hole 9-5/8 840 sx ASL, 385 sx Class G in a 12-1/4 PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310 3,765 2,746 2,963 455 12 4-5/8 6/25/2020 Open Lower PC 3,915 4,155 2,983 3,077 240 12 4-5/8 6/25/2020 Open Ref Log: USIT 8/12/2000 Perf Guns 4-5/8, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400 Max hole angle = 68 deg. At 3,636 MD Ange at perfs = 68 deg Updated 1/13/2026 11 BOPE INTEGRATED 11'-5000 INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind 11'- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 5-1/2" Pipe Ram Milne Point ASR 11 BOP w/ Jacks 05/17/2017 Milne Point ASR 11 BOP (Triple) 1/13/2026 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Completion Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,094 feet 4,176 feet true vertical 7,197 feet N/A feet Effective Depth measured 6,470 feet 3,183 feet true vertical 4,053 feet 2,689 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)5.5" 17# / L-80 / IBT 3,022' 2,610' Packers and SSSV (type, measured and true vertical depth)9-5/8" Versa-Trieve N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WTRSP Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: Burst N/A Collapse N/A 3,090psi ADL0025517 & ADL0025906 MILNE POINT / SCHRADER BLUFF OIL measured true vertical Packer measured Length measured TVD N/A Water-Bbl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-103 50-029-22964-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: MILNE PT UNIT I-09 Plugs Junk MD 110' Size 110' 4,087' Casing Conductor 6,562' N/A Surface 20" 9-5/8" 110' 6,562'5,750psi Brian.Glasheen@hilcorp.com 907-564-5277 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf 14,064 200 Brian Glasheen Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Oil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 324-177 0 78013,369 800 0120 P G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:08 pm, Jul 10, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.07.10 13:29:29 - 08'00' Taylor Wellman (2143) DSR-7/10/24WCB 12-3-2024 RBDMS JSB 071124 _____________________________________________________________________________________ Revised By: TDF 7/9/2024 SCHEMATIC Milne Point Unit Well: MP I-09 Last Completed: 6/13/2024 PTD: 200-103 TD =13,094’(MD) / TD =7,197’(TVD) 20” Orig. KB Elev.: 62.25’/ Orig. GL Elev.: 35.0’ RKB – Tbg Hngr: 21.55’ (Nabors 4ES) 9-5/8” 2 7 & 8 13 12 14 Estimated TOC ~5,518’ PBTD =5,089’ (MD) / PBTD =3,477’(TVD) 3 TAM Port Colalr 979’ MD Lower Prince Ck Middle Prince Ck 10 11 9 4 5 & 6 1 15 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” 18.936” Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835” 8.679” Surface 6,562’ 0.0758 TUBING DETAIL 5-1/2” Tubing 17 / L-80 / JFEBEAR 4.892” 4.767” Surface 3,022 0.0232 JEWELRY DETAIL No. Top MD Item ID 1 2,844’ XN Nipple HES 4.562" w/ 4.455" No Go 4.455 2 2,913’ Ported Press. Sub Sensor & B/O Discharge Head: 675X 416SS N/A 3 2,915’ Pump 1: PMP 675 SH35000 37 INC 15 1:1 XRC SH8TS3 N/A 4 2,937’ Gas Intake: 675-513 INC 41665 SN N/A 5 2,938’ Upper Tandem Seal: 513 SERIES BPBSL INCONEL SHAFT N/A 6 2,947’ Lower Tandem Seal: 513 SERIES BPBSL INCONEL SHAFT N/A 7 2,956’ Motor #2: 562 KMS3 LT 500HP1800V 17A EXD WB N/A 8 2,986’ Motor #1: 562 KMS3 LT 500HP1800V 17A EXD WB N/A 9 3,017’ Zenith Guage E7 w/ Centralizer:Btm @ 3,022 N/A LOWER COMPLETION DETAIL 10 3,183’ 9-5/8” Versa-Trieve Packer 6.000 11 3,213’ Blank Pipe, 5-1/2”, 17#, L-80, LTC Blank Pipe 4.860 12 3,300’ 5-1/2” Gravel Pack Screens (250 Micron) Top 4.818 13 4,166’ 5-1/2” Gravel Pack Screens (250 Micron) Bottom 4.818 14 4,166’ Shoe:Bottom @ 4,167’4.818 15 4,176’ CIBP CTMD 0 TREE & WELLHEAD Tree Cameron FLS, 7” x 5-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 5-1/2” TC-II T&B Thread FMC Tubing Hanger 5.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 – 8/13/2000 Convert to Injector Nabors 4ES – 7/03/2002 ESP Completion w/ Lower Screens – 6/27/2020 ESP Swap w/ ASR#1 – 6/13/2024 OPEN HOLE / CEMENT DETAIL 20” 260 sx Arctic Set (Approx.) in a 24” Hole 9-5/8” 840 sx ASL, 385 sx Class ‘G’ in a 12-1/4” PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310’ 3,765’ 2,746’ 2,963’ 455 12 4-5/8” 6/25/2020 Open Lower PC 3,915’ 4,155’ 2,983’ 3,077’ 240 12 4-5/8” 6/25/2020 Open Ref Log: USIT – 8/12/2000 – Perf Guns 4-5/8”, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400’ Max hole angle = 68 deg. At 3,636’ MD Ange at perfs = 68 deg Well Name Rig API Number Well Permit Number Start Date End Date MP I-09 ASR#1 50-029-22964-00-00 200-103 6/8/2024 6/14/2024 Continue testing BOPE w/ 5-1/2". Mud seal on ODS side leaking. Blow down and replace seal. BOPE testing complete, 250psi low/ 2,500psi high. Issues pulling CTS/BPV due to rubber debris from BOPE testing. TBG and IA on vacuum. PU Landing joint. MU Kelly hose and TIW. RU GB&R equipment. Inform security - workers in non-regulated confined space. BOLDS. Inform security - workers out of non-regulated confined space. Pull hanger w/ 58.8K off seat, 56K free. POOH W/ 5-1/2",17#, L, IBT- M ESP completion F/ 3,083' MD - T/ 1,574' pumping 2x displacement. MIRU to Skid, PT lines to 3,000 psi, FTN/CV pass, heat diesel. Pumped 80 bbls of 100* 8.5 brine down TBG up IA taking returns to tank. Minimal returns. Swapped to IA and pumped 200 bbls of 100* 8.5 brine down IA. Well didn't die Pumped 25 bbls of 80* 9.0 brine down TBG and 55 bbls of 9.0 brine down IA.. Freeze protected surface lines with 5 bbls diesel. BPV set. Final Whps=0/0 6/8/2024 - Saturday Continue venting IA gas to Tiger Tank, Gas becomes crude/diesel w/ 7.0ppg returns. RU Bleed trailer to IA. w/ 6.7ppg returns. Bleed until no flow. Attempt to test BOPE - Mud Seals on Blinds and Pipe Rams leaking. Replace Seals, Begin testing BOPE. 6/11/2024 - Tuesday 6/9/2024 - Sunday Accept rig 18:00. Pump 167 bbls 8.7ppg Brine down IA to kill well. Shut in and monitor - pressure increasing (see log). 6/10/2024 - Monday 6/7/2024 - Friday No operations to report. 6/5/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/6/2024 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-09 ASR#1 & WH 50-029-22964-00-00 200-103 6/8/2024 6/14/2024 No operations to report. No operations to report. 6/15/2024 - Saturday No operations to report. 6/18/2024 - Tuesday 6/16/2024 - Sunday No operations to report. 6/17/2024 - Monday 6/14/2024 - Friday MU tree nad adaptor to wellhead. Torque up stud bolts. assist with MU of Tri-Bore manifolds PT ADPT void to 500/5000 PSI for 5/10 MIN (PASS) Pull BPV and secured well. 6/12/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Conintue POOH W/ 5-1/2",17#, L, IBT-M ESP completion F/ 1,574' MD pumping 2x displacement. OOH w/ Baker ESP. Pump #1 BTM Shaft sheared off. All Clamps and equipment accounted for. Pump #1 BTM Shaft sheared off. All Clamps and equipment accounted for. Multiple bad/questionable threads. PU/MU & RIH w/ 5-1/2",17#,L, JFEBEAR R3 - Summit ESP completion pumping 2x disploacement. 6/13/2024 - Thursday Continue RIH w/ 5-1/2",17#,L, JFEBEAR R3 ESP (Torque-Turn) completion pumping 2x displacement F/118' - T/ 2994' MU TBG Hanger. PUW = 58K, SOW = 43K. Feed ESP cable through Hanger. ESP systems check through Hanger - Good. Land Hanger placing base of ESP at 3,062' ORKB, RILDS. Install BPV/CTS. Rig Down ASR-1. Release rig 6/13/2024. Continue RIH w/ 5-1/2",17#,L, JFEBEAR R3 ESP (Torque-Turn) completion pumping 2x displacement F/118' - T/ 2994' MU TBG Hanger. PUW = 58K, SOW = 43K. Feed ESP cable through Hanger. ESP systems check through Hanger - Good. Land Hanger placing base of ESP at 3,062' ORKB, RILDS. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240612 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPI-06 50029228220000 197195 5/2/2024 READ Caliper Survey MPI-09 50029229640000 200103 5/2/2024 READ Caliper Survey PBU B-04A 50029200720100 210095 5/20/2024 HALLIBURTON RBT PBU B-29B 50029215230200 217114 5/20/2024 HALLIBURTON RBT PBU C-26A 50029208340100 198145 5/24/2024 HALLIBURTON RBT PBU D-09A 50029203810100 199085 5/18/2024 HALLIBURTON RBT PBU D-23A 50029207380100 196188 5/18/2024 HALLIBURTON RBT PBU L-295 50029237740000 223115 5/25/2024 HALLIBURTON PPROF Please include current contact information if different from above. T38893 T38894 T38895 T38896 T38897 T38898 T38899 T38900 MPI-09 50029229640000 200103 5/2/2024 READ Caliper Survey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:38:22 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Completion 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): 13,094' N/A Casing Collapse Conductor N/A Production 3,090psi 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 WTRSP Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Brian Glasheen Contact Email: Contact Phone: Authorized Title: 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 9-5/8" Versa-Trieve and N/A 3,183 MD/ 2,689 TVD and N/A Brian.Glasheen@hilcorp.com 907-564-5277 Perforation Depth MD (ft): See Schematic See Schematic 5.5" 110' 20" 9-5/8"6,562' MD N/A 5,750psi4,087'6,562' Length Size Proposed Pools: 110' 110' 17# / L-80 / IBT TVD Burst 3,083' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 200-103 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22964-00-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/15/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT I-09 MILNE POINT SCHRADER BLUFF OIL N/A 7,197' 6,470' 4,053' 872 4,176' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Wells Manager By Samantha Coldiron at 7:43 am, Mar 26, 2024 324-177 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.22 15:35:38 - 08'00' Taylor Wellman (2143) DSR-3/27/24A.Dewhurst 27MAR24 872 10-407 BOPE pressure test to 2500 psi. MGR27MAR24JLC 3/27/2024 ESP Change-Out Well: MPU I-09 Well Name:MPU I-09 API Number: 5002922296400 Current Status:Online ESP WSW Pad:I-Pad Estimated Start Date:4/15/2024 Rig:ASR Reg. Approval Reqd?Yes Date Reg. Approval Recvd: Regulatory Contact:Tom Fouts Permit to Drill Number:200103 First Call Engineer:Brian Glasheen 907-545-1144 Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907)-947-9553 (M) AFE Number:242-00503 Current Bottom Hole Pressure:1136 psi @ 2638 TVD ESP Pressure Gauge 10/12/23 8.3 PPG Maximum Expected BHP:1136 psi @ 2638 TVD ESP Pressure Gauge 10/12/23 8.3 PPG MPSP:872 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 68° @ 3819MD Brief Well Summary: MPU I-09 is a current online WSW averaging 12,000 BWPD. With new I pad development in 2024, I-09 current ESP will not maintain a VRR of 1 to support all the new drills at I pad. I-09 existing permit allows for 25,000 bwpd of off take. The new ESP will be sized to meet 25,000 bwpd to support the future development in 2024. Notes Regarding Wellbore Condition The 9-5/8 production casing passed an MIT to 2000 psi on 6/20/20 Objective: Pull ESP. Install new ESP Non- Sundried work SL: Caliper Sundry Procedure (Approval Required to Proceed) Pre-Rig Procedure 1. RU FB and PT lines to 3,000 psi. 2. Review the well Kill procedure with the engineer, plan to pump estimated 8.5 ppg kill wt fluid down the IA taking returns to the TBG . Shut the well in obtain updated shut-in well pressures with known fluids. 3. Confirm well is dead. 4. RD FB. 5. Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. 7. RU crane. Set BPV. ND Tree. Inspect the tubing hanger lift thread and note any damage. 8. NU BOPE. RD Crane. 9. Spot mud boat. RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. ESP Change-Out Well: MPU I-09 11. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/8.5 ppg KWF prior to pulling BPV. 12. Set TWC. 13. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per ASR 1 BOP Test Procedure c. Confirm test pressures per the Sundry Conditions of approval. d. Test rams on 5-1/2 test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14.Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), 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 wouldnt hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg KWF as needed. 16. Rig up spoolers for ESP cable. 17. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. 84 Klbs up and 75k down when landed 2020. 18. Lay down tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. a. Evaluate pulled tubing hanger for possible damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 19. POOH and lay down the 5-1/2 tubing while spooling ESP cable. Lay down ESP and motor. a. Inspect the connections b. Re-use existing TBG, Inspect the connections c. Note any sand or scale inside or on the outside of the ESP in WSR. d. The completion has the following amount of clamps: i. 74 Cross Collar Clamps ii. 1 LaSalle Seal Protectolizer clamps iii. 2 Pump Protectolizer ESP Change-Out Well: MPU I-09 iv. 1 BOI Protectolizer Pulled Equipment Disposition Tubing hanger Visually inspect on site then re-stock Tubing & Pup joints Re-use ESP Cable Inspect GLMS N/A ESP Equipment Visually inspect on site then provide to Baker for tear down, PU new Summit ESP Clamps Clamps will be replaced from Summit XN Nipple Re-use 20. PU new ESP and RIH on 5-1/2 17 lbs/ft L-80 tubing. Set base of ESP assembly at ± 3083 MD. a. Check ESP cable conductivity every 2,000. Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes 5- 1/2Centralizer ~3083 MD 17 L-80 5- 1/2Sensor, Zenith 17 L-80 Baker 5- 1/2Motor 17 L-80 Summit 5- 1/2Lower Tandem Seal 17 L-80 Summit 5- 1/2Upper Tandem Seal 17 L-80 Summit 5- 1/2Pump 17 L-80 Summit 5- 1/2Pump 17 L-80 Summit 5- 1/2 1 joint 17 L-80 5- 1/210'Pup Joint 17 L-80 5- 1/2XN nip 17 L-80 5- 1/210'Pup Joint 17 L-80 ESP Change-Out Well: MPU I-09 5- 1/2Joints 17 L-80 5- 1/2Space out PUPS 17 L-80 5- 1/2 1 joint 17 L-80 5- 1/2PUP 17 L-80 5- 1/2Tubing Hanger 17 L-80 PU and MU the 5-1/2 tubing hanger with landing joint. Make the final splice of the ESP cable to the penetrator. Plug off any additional control line ports if present. 21. Land the tubing hanger and RILDS (Caution do not damage the Cable when landing). Lay down landing joint. Note Pick-up and slack-off weights on tally. 22. Set TWC. 23. RDMO ASR. Post-Rig Procedure: 24. RD mud boat. RD BOPE house. Move to next well location. 25. RU crane. ND BOPE. 26. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 27. Pull TWC. 28. RD crane. Move returns tank and rig mats to next well location. 29. Replace gauge(s) if removed. 30. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic _____________________________________________________________________________________ Revised By: TDF 7/16/2020 SCHEMATIC Milne Point Unit Well: MP I-09 Last Completed: 6/27/2020 PTD: 200-103 TD =13,094(MD) / TD =7,197(TVD) 20 Orig. KB Elev.: 62.25/ Orig. GL Elev.: 35.0 RKB Tbg Hngr: 21.55 (Nabors 4ES) 9-5/8 3 9 & 10 14 12 15 16 Estimated TOC ~5,518 1 PBTD =5,089(MD) / PBTD =3,477(TVD) 4 & 5 TAM Port Colalr 979 MD Lower Prince Creek Middle Prince Creek 12 13 11 6 7 & 8 2 14 17 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124 18.936 Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835 8.679 Surface 6,562 0.0758 TUBING DETAIL 5-1/2 Tubing 17 / L-80 / IBT 4.892 4.767 Surface 3,0750.0232 JEWELRY DETAIL No. Top MD Item ID 1 27 XO: Tbg Hanger FMC 11"X 5.5" 5.5 TCII 5 Sea Control line ports. 4.892 2 2,933 XN Nipple HES 4.562" w/4.455" No Go 4.455 3 2,985 Discharge Head: Bolt On 675 Series Pump N/A 4 2,986 Pump 1: HPHVMARC S/N 1520572 N/A 5 3,002 Pump 2: HPHVMARC S/N 1520573 N/A 6 3,018 Bolt On Intake: S/N 14991207 N/A 7 3,019 Upper Tandem Seal: HSB3 UT FER EHL INV S/N 15018460 N/A 8 3,026 Lower Tandem Seal: HSB3 LT FER EHL S/N 15018465 N/A 9 3,033 Motor 1: HMIU 500Hp/ 1,965V/ 153A N/A 10 3,055 Motor 2: HMIL 500Hp/ 1,965V/ 153A N/A 11 3,079 Sensor: Zenith w/Centralizer:Btm @ 3,083N/A LOWER COMPLETION DETAIL 12 3,183 9-5/8 Versa-Trieve Packer 6.000 13 3,213 Blank Pipe, 5-1/2, 17#, L-80, LTC Blank Pipe 4.860 14 3,300 5-1/2 Gravel Pack Screens (250 Micron) Top 4.818 15 4,166 5-1/2 Gravel Pack Screens (250 Micron) Bottom 4.818 16 4,166 Shoe:Bottom @ 4,1674.818 17 4,176 CIBP CTMD 0 TREE & WELLHEAD Tree Cameron FLS, 7 x 5-1/2 - 5M Wellhead 11 5M FMC Gen 6 w/ 5-1/2 TC-II T&B Thread FMC Tubing Hanger 5.0 CIW H BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 8/13/2000 Convert to Injector Nabors 4ES 7/03/2002 ESP Completion w/ Lower Screens 6/27/2020 OPEN HOLE / CEMENT DETAIL 20 260 sx Arctic Set (Approx.) in a 24 Hole 9-5/8 840 sx ASL, 385 sx Class G in a 12-1/4 PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310 3,765 2,746 2,963 455 12 4-5/8 6/25/2020 Open Lower PC 3,915 4,155 2,983 3,077 240 12 4-5/8 6/25/2020 Open Ref Log: USIT 8/12/2000 Perf Guns 4-5/8, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400 Max hole angle = 68 deg. At 3,636 MD Ange at perfs = 68 deg _____________________________________________________________________________________ Revised By: TDF 3/19/20204 PROPOSED Milne Point Unit Well: MP I-09 Last Completed: 6/27/2020 PTD: 200-103 TD =13,094(MD) / TD =7,197(TVD) 20 Orig. KB Elev.: 62.25/ Orig. GL Elev.: 35.0 RKB Tbg Hngr: 21.55 (Nabors 4ES) 9-5/8 2 8 13 12 14 Estimated TOC ~5,518 PBTD =5,089 (MD) / PBTD =3,477(TVD) 3&4 TAM Port Colalr 979 MD Lower Prince Ck Middle Prince Ck 10 11 9 5 6 & 7 1 15 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124 18.936 Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835 8.679 Surface 6,562 0.0758 TUBING DETAIL 5-1/2 Tubing 17 / L-80 / IBT 4.892 4.767 Surface ±3,083 0.0232 JEWELRY DETAIL No. Top MD Item ID 1 ±X,XXX XN Nipple HES 4.562" w/ 4.455" No Go 4.455 2 ±X,XXX Discharge Head:N/A 3 ±X,XXX Pump 1:N/A 4 ±X,XXX Pump 2:N/A 5 ±X,XXX Bolt On Intake:N/A 6 ±X,XXX Upper Tandem Seal:N/A 7 ±X,XXX Lower Tandem Seal:N/A 8 ±X,XXX Motor:N/A 9 ±X,XXX Sensor w/ Centralizer: Btm @ ±3,083 N/A LOWER COMPLETION DETAIL 10 3,183 9-5/8 Versa-Trieve Packer 6.000 11 3,213 Blank Pipe, 5-1/2, 17#, L-80, LTC Blank Pipe 4.860 12 3,300 5-1/2 Gravel Pack Screens (250 Micron) Top 4.818 13 4,166 5-1/2 Gravel Pack Screens (250 Micron) Bottom 4.818 14 4,166 Shoe:Bottom @ 4,1674.818 15 4,176 CIBP CTMD 0 TREE & WELLHEAD Tree Cameron FLS, 7 x 5-1/2 - 5M Wellhead 11 5M FMC Gen 6 w/ 5-1/2 TC-II T&B Thread FMC Tubing Hanger 5.0 CIW H BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 8/13/2000 Convert to Injector Nabors 4ES 7/03/2002 ESP Completion w/ Lower Screens 6/27/2020 OPEN HOLE / CEMENT DETAIL 20 260 sx Arctic Set (Approx.) in a 24 Hole 9-5/8 840 sx ASL, 385 sx Class G in a 12-1/4 PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310 3,765 2,746 2,963 455 12 4-5/8 6/25/2020 Open Lower PC 3,915 4,155 2,983 3,077 240 12 4-5/8 6/25/2020 Open Ref Log: USIT 8/12/2000 Perf Guns 4-5/8, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400 Max hole angle = 68 deg. At 3,636 MD Ange at perfs = 68 deg 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 5-1/2 Fixed Rams MPI‐09 Formation Tops Formation MD TVD SV5 1368 1355 SV1 2128 2033 UG3 3123 2660 UG1 4335 3150 LA3 4707 3305 MD 5349 3594 NA 5785 3779 NB 5854 3808 NC 5930 3840 NE 5978 3860 NF 6081 3904 OA 6172 3941 OBa 6346 4007 HRZ 12116 6355 Kuparuk D 12575 6723 Kuparuk B 12774 6903 Kuparuk A 12898 7017 Kuparuk A3 12909 7027 Kuparuk A2 12938 7054 Kuparuk A1 13009 7119 Miluveach 13025 7134 1 Guhl, Meredith D (OGC) From:Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent:Wednesday, March 27, 2024 1:00 PM To:Guhl, Meredith D (OGC) Cc:Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL] RE: MPU I-09, PTD 200-103, Formation Tops Attachments:I-09 Formation Tops.xlsx Meredith, It appears the formaƟon tops submiƩed when the well was drilled in 2001 were inaccurate, perhaps they listed TVD instead of MD. Please see aƩached for accurate formaƟons tops, including a few addiƟonal formaƟon tops for the shallower interval. Please let me know if you have any quesƟons. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Wednesday, March 27, 2024 11:07 AM To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] RE: MPU I‐09, PTD 200‐103, Formation Tops Joe, I read the wrong line, the sundry is for an ESP compleƟon, not perforate new pool. But we sƟll do need the corrected formaƟon tops, please. Thanks, M From: Guhl, Meredith D (OGC) Sent: Wednesday, March 27, 2024 11:05 AM To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: MPU I‐09, PTD 200‐103, Formation Tops Hello Joe, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 A review is being made of MPU I‐09 as part of the sundry request to perforate a new pool. The formaƟon top depths reported on the 10‐407 submiƩed in July 2001 are very different than the formaƟon top depths on the prognosis in the 10‐401 packet. 407: 401: Could Hilcorp please provide a corrected list of formaƟon tops for MPU I‐09 that can be used to evaluate the sundry request and also inserted into the well history ﬁle? Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant 3 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793‐1235 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 Meredith Guhl at 907‐793‐1235 or meredith.guhl@alaska.gov. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/03/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-09 (PTD 200-103) JET CUT RECORD 06/20/2020 CAST IRON BRIDGE PLUG SETTING RECORD 06/24/2020 Please include current contact information if different from above. Received by the AOGCC 11/03/2020 Abby Bell 11/03/2020 PTD: 2001030 E-Set: 34178 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/03/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-09 (PTD 200-103) JET CUT RECORD 06/20/2020 CAST IRON BRIDGE PLUG SETTING RECORD 06/24/2020 Please include current contact information if different from above. Received by the AOGCC 11/03/2020 Abby Bell 11/03/2020 PTD: 2001030 E-Set: 34179 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 1Z C I FROM: Lou Laubenstein Petroleum Inspector Section: 33 Township: 13N Drilling Rig: NA Rig Elevation: NA Operator Rep: Jeff Jones Casing/Tubing Data (depths are MD): DATE: June 20, 2020 SUBJECT: Plug Verification Milne Point Unit 1-09 Hilcorp Alaska LLC PTD 2001030; Sundry 320-223 Range: 10E Meridian: Umiat Total Depth: 13094 ft MD Lease No.: ADL0025906 Suspend: P&A: Conductor: 20" -O.D. Shoe@ 110 Feet Surface: 0. D. Shoe@ Feet Intermediate: 0. D. Shoe@ Feet Production: 9-5/8" 0. D. Shoe@ 6562 Feet Liner: 0. D. Shoe@ Feet Tubing: 3-1/2" 0. D. Tail@ 6349 Feet Plugging Data: Test Data: Type Plug Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ 5790 Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Retainer 5748 ft MD 5088 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing 2204 2071 2037 - IA 0 0 0 P OA Initial 15 min 30 min 45 min Result Tubing 142 164 162 IA 2168 2118 2096 P OA Remarks: Plug back for recompleting well as a water source well. I witnessed E -line tag on what appeared to be top of cement @ 5088 ft MD. This was over 400 ft higher then their projected tag depth. The engineer for Hilcorp called the approving AOGCC engineer (Guy Schwartz) and obtained approval to proceed with an MIT of the cement plug in the tubing and the inner annulus. Both of the tests passed without issue or concern. Attachments: none rev. 11-28-18 2020-0620_Plug_Verification_MPU_I-09_11 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing GP & ESP Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Cement Perfs Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,094 feet 4,176 feet true vertical 7,197 feet N/A feet Effective Depth measured 6,470 feet 3,183 feet true vertical 4,053 feet 2,689 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)5.5" 17# / L-80 / IBT 3,083' 2,641' Packers and SSSV (type, measured and true vertical depth)9-5/8" Versa-Trieve N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data WTRSP GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8434 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi 20" 9-5/8"4,087' Burst N/A 5,750psi Casing Conductor Length 110' 6,562'Surface MILNE PT UNIT I-09 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Casing Pressure Tubing Pressure 0 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-223 & 320-224 0 Authorized Signature with date: Authorized Name: Ian Toomey itoomey@hilcorp.com 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-103 50-029-22964-00-00 Plugs ADL0025517 & ADL0025906 5. Permit to Drill Number: MILNE POINT / TERTIARY UNDEFINED WTRSP Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 0 Oil-Bbl measured true vertical Packer Size N/A WINJ WAG 0 Water-Bbl MD 110' 6,562' TVD 110' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 10:35 am, Jul 19, 2020 Chad A Helgeson 2020.07.17 16:32:05 -08'00' MGR22JUL2020 SFD 7/20/2020RBDMS HEW 7/20/2020 DSR-7/20/2020 _____________________________________________________________________________________ Revised By: TDF 7/16/2020 SCHEMATIC Milne Point Unit Well: MP I-09 Last Completed: 6/27/2020 PTD: 200-103 TD =13,094’ (MD) / TD =7,197’(TVD) 20” Orig. KB Elev.: 62.25’/ Orig. GL Elev.: 35.0’ RKB – Tbg Hngr: 21.55’ (Nabors 4ES) 9-5/8” 3 9 & 10 14 12 15 16 Estimated TOC ~5,518’ 1 PBTD = 5,089’ (MD) / PBTD =3,477’(TVD) 4 & 5 TAM Port Colalr 979’ MD Lower Prince Creek Middle Prince Creek 12 13 11 6 7 & 8 2 14 17 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” 18.936” Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835” 8.679” Surface 6,562’ 0.0758 TUBING DETAIL 5-1/2” Tubing 17 / L-80 / IBT 4.892” 4.767” Surface 3,075’0.0232 JEWELRY DETAIL No. Top MD Item ID 1 27’ XO: Tbg Hanger FMC 11"X 5.5" 5.5 TCII 5 Sea Control line ports. 4.892 2 2,933’ XN Nipple HES 4.562" w/4.455" No Go 4.455 3 2,985 Discharge Head: Bolt On 675 Series Pump N/A 4 2,986’ Pump 1: HPHVMARC S/N 1520572 N/A 5 3,002’ Pump 2: HPHVMARC S/N 1520573 N/A 6 3,018’ Bolt On Intake: S/N 14991207 N/A 7 3,019’ Upper Tandem Seal: HSB3 UT FER EHL INV S/N 15018460 N/A 8 3,026’ Lower Tandem Seal: HSB3 LT FER EHL S/N 15018465 N/A 9 3,033’ Motor 1: HMIU 500Hp/ 1,965V/ 153A N/A 10 3,055’ Motor 2: HMIL 500Hp/ 1,965V/ 153A N/A 11 3,079’ Sensor: Zenith w/Centralizer:Btm @ 3,083’N/A LOWER COMPLETION DETAIL 12 3,183’ 9-5/8” Versa-Trieve Packer 6.000 13 3,213’ Blank Pipe, 5-1/2”, 17#, L-80, LTC Blank Pipe 4.860 14 3,300’ 5-1/2” Gravel Pack Screens (250 Micron) Top 4.818 15 4,166’ 5-1/2” Gravel Pack Screens (250 Micron) Bottom 4.818 16 4,166’ Shoe:Bottom @ 4,167’4.818 17 4,176’ CIBP CTMD 0 TREE & WELLHEAD Tree Cameron FLS, 7” x 5-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 5-1/2” TC-II T&B Thread FMC Tubing Hanger 5.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 – 8/13/2000 Convert to Injector Nabors 4ES – 7/03/2002 ESP Completion w/ Lower Screens – 6/27/2020 OPEN HOLE / CEMENT DETAIL 20” 260 sx Arctic Set (Approx.) in a 24” Hole 9-5/8” 840 sx ASL, 385 sx Class ‘G’ in a 12-1/4” PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310’ 3,765’ 2,746’ 2,963’ 455 12 4-5/8” 6/25/2020 Open Lower PC 3,915’ 4,155’ 2,983’ 3,077’ 240 12 4-5/8” 6/25/2020 Open Ref Log: USIT – 8/12/2000 – Perf Guns 4-5/8”, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400’ Max hole angle = 68 deg. At 3,636’ MD Ange at perfs = 68 deg Middle PC 3,310’ 3,765’ 2,746’ 2,963’ 455 12 4-5/8” 6/25/2020 Open Lower PC 3,915’ 4,155’ 2,983’ 3,077’ 240 12 4-5/8” 6/25/2020 Open R fL USIT 8/12/2000 P f G 4 5/8” 12 SPF M F HMXRef Log: USIT 8/12/2000 Perf Guns 4 5/8” 12 SPF MaxForce HMX Well Name Rig API Number Well Permit Number Start Date End Date MPU I-09 CTU #6 / Innovation 50-029-22964-00-00 200-103 6/17/2020 6/27/2020 PT 250 PSI LOW, 3500 HIGH (PASS). TAG POSSIBLE CEMENT STRINGERS AT 5089' ELMD. DECISION MADE TO PERFORM MIT- T AND MIT-IA BEFORE CUT. CUT 3.5" TUBING W/ 2.70" JET CUTTER AT 5015', CCL TO CUTTER OFFSET: 5', CCL STOP DEPTH: 5010'. MIT-T and IA to 2000 psi (MIT-T PASSED) MIT-IA PASSED)(Witnessed by Lou Laubenstein) (Pressure test equipment 250/2500 psi) Pump 0.4 bbls Dsl down Tbg to reach test pressure. 1st 15 Min Tbg lost 133 psi. 2nd 15 Min Tbg lost 34 psi. Bleed Tbg down w/ 0.5 bbls Dsl returned. Pump 7.3 bbls Dsl down IA to reach test pressure. 1st 15 Min IA lost 50 psi. 2nd 15 Min IA lost 22 psi. Bleed IA down w/ 3.5 bbls Dsl returned. 6/20/2020 - Saturday PJSM Spot shop on corner of pad. Split Pipe Shed and Motor Mod. Remove Geo Span for maintenance. Spot Pits and Catwalk. Start walking Sub of I-20 at 14:00. Press wash Mods while walking Sub. PJSM Cont walking Sub to I-09. Spot, shim and set down Sub on I-09 at 23:00. Lay matt boards for Pipe Shed. Spot Pit Module to access 30’ matt boards and swap out for 40’ matts. PJSM Cont swpping out matts. Stage matts for the rig. Spot Cattle Chute, Pipe Shed and Mud Mod. Cont Press washing around rig. Install cellar grating and set out riggers. 6/21/2020 - Sunday No operations to report 6/22/2020 - Monday 6/19/2020 - Friday MU tubing punch BHA with 2" OD gun - 5 ft of shots at 4 SPF. PT to 288/ 1500 psi. RIH, TAG retainer at 5744' ctmd PU and shoot holes at 5733' to 5738' ctmd. POOH. Ball recovered - ASF. MU big hole nozzle BHA. PT to 318 / 3990 psi. RIH, TAG retainer at 5746' ctmd, PU to 5725'. Pump 19 bbl balanced cement plug across tubing and IA, water spacers above cement and diesel freeze protect on top. Estimated TOC at ~5518' ctmd. Secure well. RDMO. 6/17/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MIRU SLB CTU #6 with 2 CT. Perform full BOP test to 250/ 3500 psi and record on 10-424. MU 3-1/2" one trip cement retainer. On well - PT to 300/3800 psi. RIH and set retainer at 5,748' ctmd. Upon ball seat shearing, stinger unstung from retainer. Unable to sting back in. POOH to remove dual check valves from BHA. Another run with coil may cause SLB personnel to exceed maximum hrs worked and still drive as per their driving policy. Secure well and equipment. SDFN to return in the morning and resume work. 6/18/2020 - Thursday Get on well with BHA #2. PT to 320/4050 psi. RIH with 1st retainer stinger. Sting into retainer at 5,748' ctmd but unable to shift opening sleeve in the retainer to provide flow path through the retainer. Try all the tricks with no luck. POOH to pick up milling assembly. MU and RIH with jars, motor/venturi/ and 2.75" OD burn shoe. Burn over retainer from 5757' to 5758.5' ctmd. RIH to 5827' freely. Able to establish injection at .9 bpm at 1306 psi WHP. POOH. MU and RIH with 2nd 3-1/2" 1-trip retainer and set at 5748' ctmd. Unstung while setting but able to sting back in. Pump 20 bbls 15.8 ppg "G" cement - with ~19.5 bbls below retainer, unsting from retainer and lay in remaining bbl of cement. Clean out from top of retainer to surface while POOH. L/D setting tool. Secure well and SDFN. Well Name Rig API Number Well Permit Number Start Date End Date MPU I-09 CTU #6 / Innovation 50-029-22964-00-00 200-103 6/17/2020 6/27/2020 Hilcorp Alaska, LLC Weekly Operations Summary Finish spotting, setting and shimming mud and gen mods. Spot and set break shack and enviro-vac. SimOps: Hook up all interconnects. Clean out suction on MP1, safeout walkways, stairs and landings, rig up air, water and steam systems. Start working on rig acceptance checklist. Scope derrick up. Load seawater in pits and begin heating. Continue working on rig acceptance checklist. Bridle down. Hang rig tongs. Spot cuttings box. Clean MP2 suction. Rig up lines to tiger tank and PT. Open SSV to displace out diesel. Pump 38 bbls of heated brine with Baraclean followed by 5 bbls of seawater, ICR 2 bpm, 950 psi; slow rate as well pressures up, final circulating rate 0.25 bpm, 1500 psi. Shut down due to excessive pressure. Flush lines and blow down. Rig Accepted at 15:30. Install BPV. N/D tree. Install CTS in BPV. Verify and inspect 3.5" NSCT hanger threads - 7 turns. N/U 11" spacer spool, DSA, 13-5/8" spacer spool, and BOP stack. M/U choke and kill lines. Obtain RKB's. Torque choke and kill lines. Finish torque spacer spool, DSA.,M/U 5.5" and 3.5" test joints, TIW, Dart. Flood stack and purge air. Obtain good shell test. Test BOPE's on 5.5" test joints 250/3000 psi. AOGCC right to witness waived by Austin McLeod. 6/23/2020 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MPU I-09 CTU #6 / Innovation 50-029-22964-00-00 200-103 6/17/2020 6/27/2020 6/24/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Isolate koomey and bleed down lines to upper pipe rams. Open door and inspect rams. Found damage seals. Replaced upper rams with rebuilt spares. Recharge system. Test upper pipe w/ 3.5" and 5.5" test joints (Pass). Finish testing BOP's 250/3,000psi w/ 5 min hold on each. Witness waived by Austin McLeod (AOGCC rep). Drawdown - 3,050 initial, 1,650 drawdown, 200psi inc 19 secs, full charge 78 secs. 1 F/P on UPR. Test gas alarms 10/20 ppm H2S, 20/40% LEL (test good). Test PVT and alarms (test good). R/D test equipment. L/D test jt. Sim ops - R/U IA to flowback tank. M/U "T" bar and retrieve CTS from BPV. Redress "T" bar and attempt to retrieve BPV (no go). Vac out stack and retrieve BPV. M/U 5" DP w/ xo for landing jt to 3.5" NSCT hanger profile. BOLDS and unseat hanger from wellhead w/ free pipe @ 67k up. Pulled clean without overpull. PJSM, Circulate 50 bbls out to flowback tank @ 2 BPM, 350psi (saw 250psi on flowback gauge indicating partially plugged choke valve on flowback tank). Shut down and divert to overboard line via pits to cutting box. Circulate a total of 340 bbls heated (120° F) seawater w/ condet @ 6 BPM, 320psi. Displace wellbore w/ 8.8 2% KCL. Pump a total of 382 bbls @ 6 BPM, 320psi. Pull hanger to floor, break out and L/D landing joint. Install 3-1/2" elevators. POOH laying down 3- 1/2", 9.3#, L-80 8rd tubing to surface. L/D total of 159 joints, 1 GLM. 1 'X' nipple, and cut joint (14.24');Shut blind rams. PT casing to 3,000psi for 10 minutes - good. 4.9 bbls pumped, 4.8 bbls bled back. Rig up Halliburton E-line. Hang sheave in elevators, P/U CIBP with CCL/GR. RIH to 4,300' and perform correlation log to 4,010'. Correlate to UCIF log from 8/12/2000, moving down 7'. Confirm correlation with Hilcorp engineer. RIH to 4,300', POOH confirming correlations and putting top of CIBP at 4177'; CCL stop depth 4,164.1 (12.9' from CCL to top of CIBP.). Set CIBP, observing 300# lost and jump in line. Pick up on tool string. Slack off and tag top of CIBP to confirm set depth. POOH and R/D E-Line. Install wear bushing, ID 9.125", L=24";Bring tools to RIH with TCP guns to rig floor. C/O elevators to 5". P/U and M/U safety joint. Check Halliburton TCP tally. Pick up and M/U 4-5/8 12 SPF TCP guns and blanks: Bull plug, 240' live guns, 150' blank guns, 455' live guns, safety spacer, ball seat firing head with crossovers to 867.69' Well Name Rig API Number Well Permit Number Start Date End Date MPU I-09 CTU #6 / Innovation 50-029-22964-00-00 200-103 6/17/2020 6/27/2020 Hilcorp Alaska, LLC Weekly Operations Summary 6/25/2020 - Thursday Continue running in hole w/ 4-5/8" 12 spf MaxForce, HMX TCPs F/ 867' - T/ 4,177' on 5" NC50 DP (Drift = 3.125"). 100 fpm running speed. 107k up, 89k dn. Soft tag w/ 3k dn @ 4177' MD. Calculated displacement for trip. Tag on jt #105. L/D 3 jts. M/U 20' pup and single in tagging on depth at 4,177' to verify tag depth while establishing parameters. P/U 20.9' putting guns on depth. Verify with engineer for perf depths. Drop 1.375" steel ball. Pump dn @ 2 bpm, 52psi. Ball on seat @ 315 stks. Close annular.psi up firing guns @ 2,000psi (pipe jump). Well on vac with initial static loss rate 62 bph. Monitor well v ia choke (0psi). Open annular and circulate across top of hole. 27 bbls lost before returns to surface. 20-30 bph static loss rate . L/D single and pup to 4109' MD. Perfs @ 3,310' (top shot)-3,765', 3,915'-4,155' (btm shot). POOH F/ 4,109' - T/ 3,282' to clear spent guns from perf intervals. Pulled clean without issue. 87k dn, 97k up. Circulate and condition @ 2,415' Circulation port @ firing head w/ shoe @ 3282' MD. 6 bpm, 80psi, 44 BPH dynamic loss rate (8.8 MW). No gas @ btms up. TIH F/ 3,282' - T/ 4,177 tagging on original depth (no fill). 90k dn, 107k up. 24 BPH loss rate. POOH F/ 4,177' - T/ surface. Rack back 52 stands 5" DP. L/D 845' total TCP's. All shots fired. R/D TCP handling equipment. Clean and clear rig floor. Mob Weatherford casing tools to rig floor. C/O handling equipment. Mob BOT 3.5" inner string handling equipment to rig floor and stage same. M/U xo w/ TIW safety valve. Verify pipe count and placement in shed. Pick up and RIH with 5-1/2", 17#, L-80, LTC 250 micron HES screens as per tally to 953'. M/U TQ 3410 ft-lbs. Running speed 60 fpm. PUW 51K, SOW 50K. Set 'C' plate on stump, and rig up false boal. Change out elevators to 3-1/2". P/U 1st joint of 3-1/2", 9.2#, P110, H511 and M/U mule shoe on bottom. RIH with 3-1/2" H511 inner string to 944', M/U TQ 1400 ft-lbs, drift pipe to 2.767". M/U liner hanger to 3-1/2" and 5-1/2". SImOps: Halliburton spot in equipment and start building manifold on ground. Rig down power tongs, Clear rig floor of Weatherford equipment, Baker handling tools. C/O elevators. SimOps: Continue building manifold on ground. RIH with 5-1/2" gravel pack assembly on drill pipe from 991' to 3,211', above top perfs. PUW 100, SOW 86. Rig up and reverse circulate at 0.75 bpm, 16psi for ~5 bbls to clear drill string of any potential pipe dope. Bring iron to rig floor to connect to manifold. Check manifold on ground. Static loss rate 24 bph. Continue to RIH with 5-1/2" gravel pack assembly on drill pipe from 3,211' at 60 fpm. Obtain PUW 110K, SOW 90K at 4,040'. Tag up on CIBP at 4,176', 1' higher than tag depth with TCP assembly. Pick up 9' to put packer on depth. Mark pipe. L/D one joint. Pick up to packer setting depth, mule shoe depth 4,167'. Drop 1-3/4" packer setting ball at 03:15. Rig up iron on rig floor, return line, and tie in mud pumps. Flood lines and purge air, PT rig lines 4,500psi and HES lines 7500psi. Set packer as per Halliburton. Pressure up in 500psi increments and hold for 2 minutes up to 2675psi and hold for 3 minutes. Bleed pressure. Pick up 20K over to 130K, slack off 20K to 70K to ensure slips set. Pressure back up to 2,675 and hold for 1 minutes, pressure up to 3150psi and hold for five minutes to set element. Bleed off pressure. Well Name Rig API Number Well Permit Number Start Date End Date MPU I-09 CTU #6 / Innovation 50-029-22964-00-00 200-103 6/17/2020 6/27/2020 Hilcorp Alaska, LLC Weekly Operations Summary 6/26/2020 - Friday PJSM, R/U and test 9-5/8" X 5-1/2" HES screen packer assy down IA. Test to 1,000psi w/ 15 min hold (test good). Chart and record same. Walkpsi up @ 1/2 BPM shearing burst disc @ 2,650psi. Bleed to "0" andpsi up dn drill pipe to 3,500psi P/U shearing running tool @ 127k (86k after). Swap to test pump and continuepsi up to 4,810psi to shear ball seat. Slack off 7' and close annular and P/T IA (unable to buildpsi). S/O T/ WD (30k dn). HES P/T lines 7,500psi (good). Pump 6.2 bbls 15% HCL pickle, 44 bbls 2% KCL brine, 2 bbls water down dp stopping 5 bbls shy of 5" xo to tbg 4 BPM in/1.2 BPM out w/ 100% open choke. Line up on IA with rig and reverse circulate pickle out of DP taking returns to flowback tank 5 bpm, 175psi w/ 107 bbls 2% KCL. Strip down putting tool in "WD" position. Establish circulation at 1,2,3 bpm w/ 30psi and no returns. 4 bpm,psi climbed to 140psi after losing 50 bbls. Turnover to HES for step rate test - Lineup to inject down dp into formation below pkr @ 4 bpm, 170 initial / 210 finalpsi, 6 bpm, 460 initial / 520psi final. 60 bbls pumped away. Saw 30 bph static loss rate, 60 bph dynamic loss rate. Discuss plan forward with HES Gravel Pack Engineer. Lineup HES to pump dn dp in the "WD" position. Establish parameters 4 bpm then increase to 6 bpm, 600psi. Mix and pump 20/40 LWP sand @ 2 ppg blending w/ 8.6 ppg 2% KCL. Pump a total of 16,000# proppant with a final circulatingpsi 550 @ 5 bpm. Sand out and trip kickouts @ 2,150psi. P/U to "R" position and lineup rig, reverse circulate 7.5 bpm, 300psi taking returns across shakers dressed w/ 270 screens. Clear workstring of residual sand. Work string back dn to "WD" position and pump @ 1 bpm, 690psi with no returns. Discuss with HES "GP" engineer in town. Decision made to "Call It". P/U slowly clearing seals and shift MCS sleeve closed. POOH laying down drill pipe from 4140' to 988' liner running tool. R/U power tongs and L/D running tool. Rig up 3-1/2" elevators. POOH and L/D 3-1/2" inner string. Loss rate 20-25 bph. Pull wear bushing. L/D Weatherford 3-1/2" handling equipment, wear bushing. Bring Centrilift job box, 74 cannon clamps, ESP sheave to righ floor. Hang sheave in derrick. Load shed with ESP assembly. M/U ESP assembly: Centralizer, motor gauge, (2) 500 HP motors, tandem seals, bolt on intake, (2) pumps, discharge head, pup joint. Connect MLE cable to motor. Service motor and pumps filling with oil and purging air while picking up. (4) protectolizers ran on ESP assembly. Check MLE cable - good. RIH with ESP assembly on 5.5", 17#, L-80, IBT tubing from 115' to 2,072'. Installing cannon clamps every joint. M/U first 15 connections to Opt M/U circle mark and record TQ to establish average M/U TQ of 5,600 ft-lbs. PUW 71K, SOW 67'. Test ESP cable every 1,000'. Continue running 5.5" IBT, 17#, L-80 ESP completion F/ 2,072' - T/ 3,040' MD. Cannon clamp every jt, 5.5k ft/lbs tq on connections. 47 bbl loss for completion run. 74ea cannon clamps, 4ea protectolizers. Continuity test every 1,000'. M/U hanger and landing jt w/ xo. Terminate ESP cable. Test same (good). R/D casing equipment and L/D same while splicing cable. S/O and Landout hanger @ final set depth 3,083' w/ 40k string wt on hanger (75k dn, 84k up). RILDS. L/D landing jt. Note: Last 42 bbls pumped down IA treated w/ corrosion inhibitor prior to landing out. Install BPV. Flush and blow down: kelly hose, choke and kill lines, choke manifold with hot water. Pull riser. Nipple down BOPE: Bleed off accumulator. Break bolts on stack., choke and kill lines, spacer spools and DSA. Set stack back on pedestal and cahin off. Remove spacer spool, DSA. SimOps: unhang rig tongs, clean pits, blow down mud pumps. Load 5" drill pipe in shed. Feed ESP through tubing adapter. Conduct final check on ESP cable - good. N/U tubing adapter and tree. Test tubing hanger void and tree 500/5,000psi - good. Pull CTS. 6/27/2020 - Saturday No operations to report. 6/28/2020 - Sunday No operations to report. 6/29/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MPU I-09 CTU #6 / Innovation 50-029-22964-00-00 200-103 6/17/2020 6/27/2020 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/30/2020 - Tuesday 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: GP & ESP 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,094'N/A Casing Collapse Conductor N/A Production 3,090psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative:WTRSP GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Ian Toomey Operations Manager Contact Email: Contact Phone: 777-8434 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A & N/A Tubing MD (ft): 9-5/8" Tubing Grade: ±3,077 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 6,562'6,562' 4,087' 5-1/2" Perforation Depth MD (ft): See Schematic See Schematic Perforation Depth TVD (ft): Tubing Size: 20"110' C.O. 477.05 N/A110'110' TVD Burst MILNE PT UNIT I-09 MILNE POINT / SCHRADER BLUFF OIL 5,750psi MD 50-029-22964-00-00 Length Size 7,197' 6,470' 4,053' 1,046 6,470' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 200-103 7/14/2020 17.0 / L-80 / IBT itoomey@hilcorp.com COMMISSION USE ONLY Authorized Name: Authorized Signature: N/A & N/A Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:01 pm, Jun 01, 2020 320-224 Chad A Helgeson 2020.06.01 10:28:39 -08'00' 10-404 Alaska SFD 6/1/2020 GP & ESP water source ADL0025906 X SFD 6/1/2020 SFD 6/1/2020 Irig SFD 6/1/2020 (prince crk fm) convert to WSW DSR-6/1/2020 Perforate New Pool (combine reports 320-223 and 320-224) *3000 psi BOPE test Tertiary Undefined WTRSP gls 6/2/20 Comm 6/2/2020 dts 6/2/2020 JLC 6/2/2020 RBDMS HEW 6/4/2020 Convert to WSW Well: MPU I-09 Date: 5/27/2020 Well Name:MPU I-09 API Number:50-029-22664-00-00 Current Status:Suspended Pad:I-Pad Estimated Start Date:July 14 th, 2020 Rig:I-Rig Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:200-103 First Call Engineer:Ian Toomey (907) 777-8434 (O)(907) 903-3987 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:Convert to WSW Most recent SBHP:Not perforated Maximum Expected BHP:1,354 psi @ 3,077’ TVD MPSP:1,046 psi Gas Column Gradient = 0.1 psi/ft Max Inclination 68° @ 3,636’ MD Max Dogleg:4.3°/100ft @ 2,243’ MD Brief Well Summary: Well I-09 was drilled as a Kuparuk producer by Doyon 141 in August 2000 but the sands were wet. The well was then perforated in the SB O & N sands and a jet completion was installed. The well was POP in April 2001 and produced until March 2002 when the jet pump failed due to sand influx. In July 2002 the well was completed as a selective injector. Notes Regarding the Well & Design x 9-5/8” Casing MIT to 1,900 psi passed on 4/25/2019 x The I-09 suspended well application was submitted on separate 10-403 sundry. Objective: x Convert I-09 to WSW x Perforate the middle and lower Prince Creek formation. x Gravel pack (GP) the Prince Creek formation. x Run 5-1/2” ESP completion. Pre-Rig Procedure: 1. On SB abandonment sundry. Continued from step 32 of suspension sundry. RWO Procedure: 1. RU E-line. PU and MU HES CIBP assembly. 2. RIH, correlate CIBP on depth using USIT log dated 8/12/2000 and set the CIBP at ±4,165’ MD. RD E-line. 3. PU and MU 4-5/8”, 12 SPF, MaxForce, HMX TCP gun assembly per HES representative (240’ of guns, 150’ of blank & 455’ of guns). 4. RIH with TCP gun assembly on 5” DP to ~4,150’ MD. 5. Lightly tag the CIBP set at ±4,165’ MD. 6. PU and space out to place the guns on depth. If needed use E-line to correlate on depth. a. Perforation intervals: 4,155’ to 3,915 and 3,765’ to 3,310’. Note: SB sands plugged per sundry 320-223 Plug perfs/pre-rig 320-223 Objective: Convert I-09 to WSW x Perforate the middle and lower Prince Creek formation. x Gravel pack (GP) the Prince Creek formation. x Run 5-1/2” ESP completion. Depth control for Gravel pack assembly. (TCP perfs) 320-223 Convert to WSW Well: MPU I-09 Date: 5/27/2020 7. Close the annular or UPR. Drop activation ball and allow the ball to gravitate to seat. Pressure up on the DP to ~2,500 psi to fire the guns. 8. Check for pressure under the annular and bleed to 0 psi if needed. Open the annular or UPR and observe the well for flow (the well should go on a slight vac). 9. Circulate a bottoms up. Ensure the well is static or on a slight vac (contact town engineer if the well goes on a significant vac). 10. PU to ensure the guns are free then RIH to tag and note depth. Compare previous tag depth to determine if any perforation debris or sand influx. A cleanout may be need it the perforations are covered with sand. This tag depth will be used to space out the GP screens 11. TOOH with 5” DP and lay down spent TCP gun assembly. 12. PU, MU and RIH with the following gravel pack assembly: a. Round solid nose shoe with 10’ handling pup, 5-1/2”, 17#, L-80, LTC Box x Pin b. (7) Gravel pack screen joints (250 micron), 5-1/2”, 17#, L-80, LTC Box x Pin c. (3) 5-1/2” blank joints, 5-1/2”, 17#, L-80, LTC Box x Pin d. (12) Gravel pack screen joints (250 micron), 5-1/2”, 17#, L-80, LTC Box x Pin e. (2) 5-1/2” blank joints, 5-1/2”, 17#, L-80, LTC Box x Pin Recommended MU Torque for 5-1/2”, 17#, L-80, LTC = 3410 ft-lbs 13. RU false rotary table and change handling equipment to 3-1/2”. 14. PU, MU and RIH with 3-1/2”, 9.2#, P110, Hydril 511 inner string. Recommended MU Torque for 3-1/2”, 9.2#, P110, Hydril 511 = 1400 ft-lbs 15. PU the gravel pack packer assembly. MU the 3-1/2” inner string to the running tool and MU the packer assembly to the blank joint. 16. RD false rotary table. 17. TIH with the gravel pack assembly on 5” DP to just above the perforations. 18. Reverse circulate 1.5 DP volume at 2 BPM (max) to ensure DP is clear. 19. Continue to RIH with the gravel pack assembly to just above tag post perforating (step 10). 20. Tag the top of the CIBP and PU to place the gravel pack assembly on depth (ensure the packer is above the perforations). 21. PU to neutral weight and drop 1-3/4” setting ball. Allow time for the ball to gravitate to the ball seat. 22. Pressure up and set the gravel pack packer per HES representative. Note: Packer initiation setting pressure = 1840 psi and final set pressure = 3121 psi. 23. PT the IA to 1000 psi for 10 minutes (charted). Continue to pressure up on the IA to 2500 psi to burst the rupture disc. Bleed the IA to 0 psi. 24. Pressure up on the DP to 3,000 psi and slowly PU to release the running tool. Once it is verified the running tool is release bleed the DP to 0 psi. 25. PU to reverse position. Slowly pressure up to 4,700 psi (± 500 psi) to shear the ball seat. 26. SO, set down 30K and mark the pipe as circulating position. PU the string weight, close the annular and pressure up the IA to 500 psi. Slowly strip through the annular until the IA pressure dumps, stop and mark the pipe as reverse position. Ensure the IA pressure is 0 psi and open the annular. 27. With the running tool in the reverse position, pump 6.2 bbls of pickle (15% HCl) displace down to the DP crossover with 8.8 ppg brine with 2% KCl. gravel pack assembly CIBP @ 4165' pickle tubing Convert to WSW Well: MPU I-09 Date: 5/27/2020 28. Line up to take return from the DP. Reverse circulate out the pickle to the flow back tank. 29. SO to circulating position and perform injection step rate test at 1, 2, 4 & 6 BPM. Shut down and monitor the tubing and casing pressures. 30. Pump the gravel pack with ±20K lbs of 20/40 Carbolite proppant per HES representative. 31. PU to reverse position and reverse circulate until returns are clean (2 BU minimum). 32. Slowly PU and shift the MCS sleeve closed. 33. POOH laying down the 5” DP and lay down the running tool. 34. Change handling equipment to 3-1/2”. POOH laying down 3-1/2” inner string. 35. RU to run 5-1/2” ESP completion. Pull the wear ring. 36. RIH with the following ESP completion equipment to ~3,255’ MD installing cross coupling clamps on every connection: a. Centralizer b. Motor Gauge, Zenith c. ESP motor #1, 500 HP, 1965V, 153A d. ESP motor #2, 500 HP, 1965V, 153A e. Lower tandem seal f. Upper tandem seal g. Intake h. Pump #1 i. Pump #2 j. Discharge Head, 5-1/2”, 17#, L-80, LTC box up k. Crossover, 5-1/2”, 17#, L-80 IBT Box x LTC Pin l. 1 joint, 5-1/2”, 17#, L-80 IBT Box x Pin m. Nipple, HES, 4.562” XN Profile with 4.455” no-go, 10’ handling pups above and below. MU the first 15 joint to the base of the stamped triangle taking note of the required torque for each connection. Calculate the average torque and use that MU torque on the remaining connection. 37. Continue to RIH with the ESP completion on 5-1/2”, 17#, L-80, IBT tubing. 38. PU and MU the tubing hanger with the landing joint. Terminate the ESP cable and splice to the penetrator. Ensure all control line ports are dummied off. a. Tubing Hanger, FMC TC-1A-EMS, 11” x 5-1/2” TC-II top and bottom with 5” H BPVG b. Crossover Pup, 5-1/2”, 17#, L-80 TC-II Pin x IBT Pin 39. Land the tubing hanger with extreme caution to avoid damaging the ESP cable or penetrator. RILDS. 40. Install the TWC. 41. ND the BOP stack. 42. NU the tubing head adapter and PT the tubing hanger void to 250/5000 psi. 43. NU the tree and PT the tree to 250/5000 psi. 44. Install gauges on the tree and secure the cellar. Release and RDMO Innovation Rig. 45. Turn the well over to operations via handover form. Run ESP Completion 20K lb pack Convert to WSW Well: MPU I-09 Date: 5/27/2020 Attachments: 1. Current schematic 2. Proposed schematic 3. BOP Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: BK 5/18/2020 SCHEMATIC Milne Point Unit Well: MP I-09 Last Completed: 7/03/2002 PTD: 200-103 TD =13,094’(MD) / TD =7,197’(TVD) 20” Orig. KB Elev.: 62.25’/ Orig. GL Elev.: 35.0’ RKB – Tbg Hngr: 21.55’ (Nabors 4ES) 9-5/8” 3 7 14 12 15 16 Top of 2 fish 5- 18-2020 SL tool string 33.7’ cutter 6.9 ’ 1 Minimum ID= 2.750” @ 6,336’ PBTD =6,470’ (MD) / PBTD = 4,052’(TVD) 4 TAM Port Colalr 979’ MD OB Sands 17 OA Sands NC Sands Tubing Leak @ 6,240’ 9 10 13 11 8 6 5 2 NB Sands 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” 18.936” Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835” 8.679” Surface 6,562’ 0.0758 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 2.992” 2.867” Surf 6,349’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,084’ 3.5” HES X-Nipple (2.813” Profile) GLM DETAIL: 3.5” x 1.5” Camco MMG w/ 1.5” RK Latch 2 2,127’Sta #5:[MMG GLM]Valve - Dummy / Date- 7/21/2002 3 5,774’ 3.5” HES X-Nipple (2.813” Profile) 4 5,795’ 9-5/8” x 3.5” HES PHL Packer 5 5,823’Sta #4:[MMG GLM]Valve - Dummy / Date- 8/16/2012 6 5,914’Sta #3:[MMG GLM] Valve –200 bwpd / Date- 11/14/2017 7 6,098’ 9-5/8” x 3.5” HES PHL Packer 8 6,158’Sta #2:[MMG GLM]Valve –200 bwpd / Date- 11/14/2017 9 6,186’RMX Prong – removed 5-17 2020 10 6,198’RMX Sub/3’ Spacer Pipe/Snap Latch 11 6,217’Sta #1:[MMG GLM] Valve –Extended pkg Dummy / Date- 8/18/2012 12 6,218’ Upper Patch Baker 35KB Packer 13 6,239’ Lower Patch Baker 35KB Packer (15k Shear Release) Btm @ 6,245’ 14 6,309’ 9-5/8” x 3.5” HES PHL Packer 15 6,336’ 3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) 16 6,348’ 3.5” WLEG – Bottom @ 6,349’ 17 6,470’ Baker Model K Cement Retainer TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” NS-CT T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 – 8/13/2000 Convert to Injector Nabors 4ES – 7/03/2002 OPEN HOLE / CEMENT DETAIL 20” 260 sx Arctic Set (Approx.) in a 24” Hole 9-5/8” 840 sx ASL, 385 sx Class ‘G’ in a 12-1/4” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 5,860’ 5,870’ 3,810’ 3,814’ 10 4 2-1/8” 3/10/2001 Open 5,890’ 5,910’ 3,823’ 3,831’ 20 4 2-1/8” 3/10/2001 Open NC 5,932’ 5,942’ 3,841’ 3,845’ 10 4 2-1/8” 3/10/2001 Open OA 6,180’ 6,200’ 3,944’ 3,952’ 20 4 2.0” 11/15/2000 Open 6,200’ 6,230’ 3,952’ 3,964’ 30 4 2-1/8” 3/10/2001 Open 6,230’ 6,250’ 3,964’ 3,971’ 20 4 2.0” 11/15/2000 Open OB 6,350’ 6,360’ 4,008’ 4,012’ 10 4 2-1/8” 3/10/2001 Open 6,360’ 6,380’ 4,012’ 4,019’ 20 4 2-1/8” 9/02/2000 Open 6,380’ 6,400’ 4,019’ 4,027’ 20 4 2-1/8” 3/10/2001 Open Ref Log: USIT – 8/12/2000 – Perf Guns 2-1/8” Enerjet 4 spf @ 90 Deg / 2.0” Enerjet 4 spf @ 90 Deg WELL INCLINATION DETAIL KOP @ 400’ Max hole angle = 68 deg. At 3,636’ MD Ange at perfs = 68 deg Current (before pre-rig plug perfs) _____________________________________________________________________________________ Revised By: IAT 5/19/2020 SCHEMATIC Milne Point Unit Well: MP I-09 Last Completed: 7/03/2002 PTD: 200-103 TD =13,094’(MD) / TD =7,197’(TVD) 20” Orig. KB Elev.: 62.25’/ Orig. GL Elev.: 35.0’ RKB – Tbg Hngr: 21.55’ (Nabors 4ES) 9-5/8” 3 7 14 12 15 16 Estimated TOC ~5,517’ 1 PBTD =±5,514’ (MD) / PBTD =±3,667’(TVD) 4 TAM Port Colalr 979’ MD Lower Prince Creek Middle Prince Creek 9 10 13 11 8 6 5 2 V CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” 18.936” Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835” 8.679” Surface 6,562’ 0.0758 TUBING DETAIL 5-1/2” Tubing 17 / L-80 / IBT 4.892” 4.767” Surface 3,075’0.0232 JEWELRY DETAIL No. Top MD Item ID 1 ±29’ XO: 4.5” TCII Pin X 4.5” BTC Pin – Min ID= 3.958”4.892 2 ±2,951’ Nipple HES 4.562" XN profile w/ 4.455" nogo 4.455 3 ±3,005 Discharge Head: Bolt On 675 Series Pump N/A 4 ±3,006’ Pump: 675 PMP HPHVL 035 HC20000 FER I N/A 5 ±3,024’ Upper Tandem Seal: HSB3DBXLT INV SSCV EHL PF N/A 6 ±3,032’ Lower Tandem Seal: HSB3DBXLT INV SSCV EHL PF N/A 7 ±3,040’ Motor: HMIX 800Hp /4,225V/114A N/A 8 ±3,075’ Sensor: Zenith w/Centralizer: Btm @ 3,077’N/A LOWER COMPLETION DETAIL 9 ±3,180’ 9-5/8” Versa-Trieve Packer 6.000 10 ±3,183’ 7-5/8” x 5-1/2 Crossover”4.860 11 ±3,185’ Blank Pipe, 5-1/2”, 17#, L-80, LTC Blank Pipe 4.818 12 ±3,305’ 5-1/2” Gravel Pack Screens (250 Micron)4.818 13 ±3,770’ Blank Pipe, 5-1/2”, 17#, L-80, LTC Blank Pipe 4.818 14 ±3,910’ 5-1/2” Gravel Pack Screens (250 Micron)4.818 15 ±4,160’ Shoe 0 16 ±4,165 CIBP 0 TREE & WELLHEAD Tree Cameron FLS, 7” x 5-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 5-1/2” TC-II T&B Thread FMC Tubing Hanger 5.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 – 8/13/2000 Convert to Injector Nabors 4ES – 7/03/2002 OPEN HOLE / CEMENT DETAIL 20” 260 sx Arctic Set (Approx.) in a 24” Hole 9-5/8” 840 sx ASL, 385 sx Class ‘G’ in a 12-1/4” PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD)Btm (TVD)FT SPF Size Date Status Middle PC 3,310’ 3,765’ 3,823’ 3,831’ 455 12 4-5/8”TBD Open Lower PC 3,915’ 4,155’ 3,841’ 3,845’ 240 12 4-5/8”TBD Open Ref Log: USIT –8/12/2000 –Perf Guns 4-5/8”, 12 SPF, MaxForce, HMX WELL INCLINATION DETAIL KOP @ 400’ Max hole angle = 68 deg. At 3,636’ MD Ange at perfs = 68 deg lower section of wellbore not shown. PROPOSED CIBP ESP Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: May 29, 2019Subject: Changes to Approved Sundry Procedure for Well MPU I-09 Convert to WSWSundry #: TBDAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date MP I-09 Proposed Completion Water Source Well FMC 11 x 5 1/2Tree, Cameron FLS, 7 x 5 ½PN 2365597-03(Still boxed)Swab Valve, Cameron 7 x 5 ½ FLS, EEPNWIng Valve, Cameron 7 x 5 ½ FLS, EEPNSSV Valve, Cameron 7 x 5 ½ FLS, EE, Cameron actuator,PNMaster Valve, Cameron 7 x 5 ½ FLS, EEPNAdapter, FMC, 11 x 7, with 5 control line ports, SBMS seal prepPN P100088902-001Tubing Hanger, FMC, TC-1A-EMS, 11 x 5 ½ TCII top and bottom, 5" “H” BPV, w/ 5ea Control line ports, BB-KU, w/ SBMS prep topPN P1000201334 ___________________________________________________________________________________ Revised By: TDF 5/21/2020 PROPOSED with CT Milne Point Unit Well: MP I-09 Last Completed: 7/03/2002 PTD: 200-103 TD =13,094’(MD) / TD =7,197’(TVD) 20” Orig. KB Elev.: 62.25’/ Orig. GL Elev.: 35.0’ RKB – Tbg Hngr: 21.55’ (Nabors 4ES) 9-5/8” 3 7 14 12 15 16 TOC ~5,568’1 Minimum ID= 2.750” @ 6,336’ PBTD =6,470’ (MD) / PBTD = 4,052’(TVD) 4 TAM Port Colalr 979’ MD OB Sands 17 OA Sands NC Sands Tubing Leak @ 6,240’ 9 10 13 11 8 6 5 23 NB Sands 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” 18.936” Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835” 8.679” Surface 6,562’ 0.0758 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 2.992” 2.867” 5,790’ 6,349’ 0.0087 JEWELRY DETAIL No Depth Item 1 ±5,000’Tubing Cut 2 ±5,788’3.5” Cement Retainer 3 5,774’ 3.5” HES X-Nipple (2.813” Profile) 4 5,795’ 9-5/8” x 3.5” HES PHL Packer 5 5,823’Sta #4: [MMG GLM] Valve - DV 6 5,914’Sta #3: [MMG GLM] Valve – DV 7 6,098’ 9-5/8” x 3.5” HES PHL Packer 8 6,158’Sta #2: [MMG GLM] Valve – DV 11 6,217’Sta #1: [MMG GLM] Valve – Extended pkg Dummy / Date- 8/18/2012 12 6,218’ Upper Patch Baker 35KB Packer 13 6,239’ Lower Patch Baker 35KB Packer (15k Shear Release) Btm @ 6,245’ 14 6,309’ 9-5/8” x 3.5” HES PHL Packer 15 6,336’ 3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) 16 6,348’ 3.5” WLEG – Bottom @ 6,349’ 17 6,470’ Baker Model K Cement Retainer TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” NS-CT T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 – 8/13/2000 Convert to Injector Nabors 4ES – 7/03/2002 OPEN HOLE / CEMENT DETAIL 20” 260 sx Arctic Set (Approx.) in a 24” Hole 9-5/8” 840 sx ASL, 385 sx Class ‘G’ in a 12-1/4” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 5,860’ 5,870’ 3,810’ 3,814’ 10 4 2-1/8” 3/10/2001 Abandon 5,890’ 5,910’ 3,823’ 3,831’ 20 4 2-1/8” 3/10/2001 Abandon NC 5,932’ 5,942’ 3,841’ 3,845’ 10 4 2-1/8” 3/10/2001 Abandon OA 6,180’ 6,200’ 3,944’ 3,952’ 20 4 2.0” 11/15/2000 Abandon 6,200’ 6,230’ 3,952’ 3,964’ 30 4 2-1/8” 3/10/2001 Abandon 6,230’ 6,250’ 3,964’ 3,971’ 20 4 2.0” 11/15/2000 Abandon OB 6,350’ 6,360’ 4,008’ 4,012’ 10 4 2-1/8” 3/10/2001 Abandon 6,360’ 6,380’ 4,012’ 4,019’ 20 4 2-1/8” 9/02/2000 Abandon 6,380’ 6,400’ 4,019’ 4,027’ 20 4 2-1/8” 3/10/2001 Abandon Ref Log: USIT – 8/12/2000 – Perf Guns 2-1/8” Enerjet 4 spf @ 90 Deg / 2.0” Enerjet 4 spf @ 90 Deg WELL INCLINATION DETAIL KOP @ 400’ Max hole angle = 68 deg. At 3,636’ MD Ange at perfs = 68 deg 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,094'N/A Casing Collapse Conductor N/A Production 3,090psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Ian Toomey Operations Manager Contact Email: Contact Phone: 777-8434 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 5,795 MD/ 3,783 TVD, 6,098 MD/ 3,911 TVD, 6,218 MD/ 3,959 TVD, 6,239 MD/ 3,967 TVD & 6,309 MD/ 3,993 TVD and N/A itoomey@hilcorp.com COMMISSION USE ONLY Authorized Name: Authorized Signature: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 200-103 MD 50-029-22964-00-00 Length Size 7,197'6,470'4,053'1,472 6,470' PRESENT WELL CONDITION SUMMARY 20"110' C.O. 477.05 N/A110'110' TVD Burst MILNE PT UNIT I-09 MILNE POINT / SCHRADER BLUFF OIL Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 6,562'6,562' 4,087' 3-1/2" Perforation Depth MD (ft): See Schematic See Schematic Perforation Depth TVD (ft): 9-5/8" x 3.5" HES PHL, 9-5/8" x 3.5" HES PHL, Upper Patch Baker 35KB, Lower Patch Baker 35KB & 9-5/8” x 3.5” HES PHL Packer and N/A Tubing MD (ft): 9-5/8" Tubing Grade: 6,349' Tubing Size: 5,750psi 7/12/2020 9.3 / L-80 / EUE ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:00 pm, Jun 01, 2020 320-223 Chad A Helgeson 2020.06.01 10:25:43 -08'00' X Plug Perforations SFD 6/1/2020 gls XX SFD 6/1/2020 Innovation X WINJ Suspended gls DSR-6/1/2020 cement perfs * Separate sundry to convert well to WSW (water source well) ADL0025906 * BOPE test to 3000 psi (combine reports 320-223 and 320-224) 10-404 Pull Tubingll Tubing X gls 6/2/20 Comm 6/3/2020 dts 6/2/2020 JLC 6/2/2020 RBDMS HEW 6/4/2020 Suspend SB Sands Well: MPU I-09 Date: 5/29/2020 Well Name:MPU I-09 API Number:50-029-22664-00-00 Current Status:SI –SB Injector Pad:I-Pad Estimated Start Date:July 12 th, 2020 Rig:I-Rig Reg. Approval Req’d?Yes Date Reg.Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:200-103 First Call Engineer:Ian Toomey (907) 777-8434 (O) (907) 903-3987 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:Suspend SB Sands Most recent SBHP:1,856 psi @ 3,841’ TVD EMW = 9.30 ppg;KWF = 9.6 ppg Maximum Expected BHP:1,856 psi @ 3,841’ TVD EMW = 9.30 ppg MPSP:1,472 psi Gas Column Gradient = 0.1 psi/ft Max Inclination 68° @ 3,636’ MD Max Dogleg:4.3°/100ft @ 2,243’ MD Tree:Cameron 3-1/8” 5M Wellhead:FMC Gen 6, 11” x 11” 5M Tubing Hanger Lift threads:3-1/2” NSCT top x EUE 8rd bottom BPV Profile:3” CIW Type H Brief Well Summary: Well I-09 was drilled as a Kuparuk producer by Doyon 141 in August 2000 but the sands were wet. The well was then perforated in the SB O & N sands and a jet completion was installed. The well was POP in April 2001 and produced until March 2002 when the jet pump failed due to sand influx. In July 2002 the well was completed as a selective injector. Notes Regarding the Well & Design x 9-5/8” Casing MIT to 1,900 psi passed on 4/25/2019 Objective: Option #1: CTU (depend if the CTU fits on pad with the Innovation rig) x Plug the SB sand with cement utilizing a 3-1/2” cement retainer. x Punch holes above the top packer. x Pump balanced cement plug. Tag TOC & PT 9-5/8” casing to 2,000 psi. x Cut the tubing above TOC. x Convert I-09 to WSW (separate sundry). Option #2: Innovation Rig (I-rig) x Pull 3-1/2” tubing. x Plug the SB sand with cement utilizing a cement retainer. x Tag TOC above cement retainer & PT 9-5/8” casing to 2,000 psi. x Convert I-09 to WSW (separate sundry). Option #2: 320-224 for conversion to WSW Option #1: C Suspend SB Sands Well: MPU I-09 Date: 5/29/2020 Option #1 Pre-CTU Procedure: 1. RU slickline. 2. Pull RMX prong at 6,186’. 3. Pull RMX sub, spacer tube and snap latch at 6,198’. 4. Pull WFRV from station #2 at 6,158' and station #3 at 5,914'. 5. Install DV in station #2 at 6,158' and station #3 at 5,914'. 6. Obtain SHBP. 7. RD slickline. CTU Procedure: 8. MIRU CTU with 2” coil and spot ancillary equipment. 9. Pressure test BOPE to 3,000/250 psi. a. Each subsequent test of the lubricator will be to 3,000/250 psi to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. If within the standard 7 day test BOPE test period for Milne Point, 10. MU cement retainer and cementing nozzle and RIH to 5,763’ MD. 11. Set the cement retainer mid joint at 5,748’ (Mid Element Set Depth). 12. Mix and pump 20 bbls of 15.8 ppg class G cement with spacers. 13. Pump 19.5 bbls of cement below the cement retainer, unsting and circulate the coil clean. 14. POOH and lay down the cementing BHA. 15. PU, MU and RIH with tubing punch to the top of the cement retainer. 16. Punch holes in the tubing just above the cement retainer at 5,788’ MD. 17. POOH and lay down tubing punch BHA. 18. PU, MU and RIH with cement nozzle BHA to the top of the cement retainer. 19. Mix and pump 16 bbls of 15.8 ppg class G cement with spacers. 20. Lay in balanced cement plug. PU to safety depth ~5,000 and circulate the coil clean. 21. RDMO CTU. Post-CTU Procedure: 22. RU E-line. 23. RIH and tag the TOC. PT the cement plug to 2,000 psi for 30 minutes (charted) a. Notify the AOGCC 24 hours in advance to witness the tag and PT 24. PU, MU and RIH with jet or chemical cutter with CCL. Cut the 3-1/2” tubing at ~5,000’ MD. 25. RD E-line. 26. RU LRS pumping equipment and flow back tanks. 27. Bleed gas off the tubing an IA if needed. Reverse circulate 8.8 ppg brine with 2% KCL until clean brine is at surface (minimum of 400 bbls). Monitor the well to ensure the well is dead. 28. RD LRS equipment. 29. Set 3” HP BPV. 30. Continue to Option #2 step 15 omitting steps 25 -33. take returns up IA valve test Verify Injectivity before CTU arrives. cut tubing (est circulation) cement IA & tbg to 5500 ft. MIT-IA and MIT-T both .0401 x 300 ft = 12 bbl + .0087 x 300 ft = 3 bbll Suspend SB Sands Well: MPU I-09 Date: 5/29/2020 Option #2 (contingency if CTU does not fit next to the I-rig while drilling) Pre-Rig Procedure: 1. RU slickline. 2. Pull RMX prong at 6,186’. 3. Pull RMX sub, spacer tube and snap latch at 6,198’. 4. Pull WFRV from station #2 at 6,158' and station #3 at 5,914'. 5. Install DV in station #2 at 6,158' and station #3 at 5,914'. 6. Obtain SHBP. 7. RD slickline. 8. RU E-line. 9. Cut the 3-1/2” tubing at 5,790’ with jet or chemical cutter. 10. RD E-line. 11. RU LRS pumping equipment and flow back tanks. 12. Bleed gas off the tubing an IA if needed. Reverse circulate 9.6 ppg NaCl until clean 9.6 ppg brine is at surface (~421 bbls). Monitor the well to ensure the well is dead. Note: KWF may change pending the SBHP survey completed in step 6. If so it will be documented on the RWO MOC from 13. RD LRS equipment. 14. Set 3” HP BPV. RWO Procedure: 15. MIRU the I-Rig and ancillary equipment. RU hardline and returns tanks. 16. ND Tree. Inspect the lift threads on the tubing hanger. Install plug off tool into the BPV. 17. NU 13-5/8”, 5M BOP stack with 3-1/2” x 6” VBR’s. 18. Test BOPE to 250/3,000 psi and annular to 250/3,000 psi. a. Notify the AOGCC 24 hours in advance of BOP test. b. Perform test per I-Rig BOPE test procedure. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR’s and annular with 3-1/2” and 5-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test if test witness was waived. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. Rig Procedure Rig BOPE test 3000 psi ( IA and tubing hydrostatic balanced at cut) Suspend SB Sands Well: MPU I-09 Date: 5/29/2020 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. 19. RU to pull 3-1/2” tubing. 20. Pull plug off tool, check for pressure under the BPV and IA, if needed kill the well with KWF and pull the BPV. 21. MU the landing joint to the tubing hanger, BOLDS, unseat the tubing hanger and pull to the rig floor. 22. Lay down the landing joint and tubing hanger. a. Inspect the tubing hanger and note any corrosion or damage. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 23. POOH laying down the 3-1/2” tubing removing all jewelry as it presents itself. a. Note any corrosion, sand, or scale on the tubing with associated depths and ESP components on the morning report. Equipment Disposition Tubing hanger Visually inspect on site restock or junk Tubing & Pup joints Junk Gaslift Mandrels/Nipple Junk 24. RD 3-1/2” handling equipment. RU 5” handling equipment. Install the wear ring. 25. PU and MU 9-5/8” cement retainer. RIH on 5” DP and set the cement retainer at 5,780’. 26. PT the IA to 1,000 psi for 10 minutes. Establish injectivity into the reservoir. 27. RU HES cementer and PT lines. 28. Mix and pump 40 bbls of 15.8 ppg class G cement with spacers. 29. Displace the cement with the rig to the end of the cement stinger. Pump 20 bbls of cement below the retainer, pull out of the cement retainer and pump remaining 20 bbls of cement on top of the retainer. 30. Slowly TOOH ~5 stands. Install wiper ball and circulate the well clean (note the volume of cement returns at surface). TOOH and lay down the cement retainer running tool. 31. RD HES cementers. WOC to reach 2,000 psi compressive. RIH with muleshoe and tag the TOC and PT the cement plug to 2,000 psi for 30 minutes (charted) a. Notify the AOGCC 24 hours in advance to witness the tag and PT. 32. Circulate the well over to clean 8.8 ppg brine with 2% KCl. 33. TOOH and lay down the muleshoe. 34. Work to continue to convert to WSW on separate completions sundry. Attachments: 1. Current schematic 2. Proposed schematic 3. CTU BOP Schematic 4. I-rig BOP Schematic 5. Blank RWO MOC Form (tbgiscutat5790ft) TOC approx 5500 ft. 9 5/8" retainer at 5780 ft 320-224 9 5/8" = .0758 bb/ ft _____________________________________________________________________________________ Revised By: BK 5/18/2020 SCHEMATIC Milne Point Unit Well: MP I-09 Last Completed: 7/03/2002 PTD: 200-103 TD =13,094’(MD) / TD =7,197’(TVD) 20” Orig. KB Elev.: 62.25’/ Orig. GL Elev.: 35.0’ RKB – Tbg Hngr: 21.55’ (Nabors 4ES) 9-5/8” 3 7 14 12 15 16 Top of 2 fish 5- 18-2020 SL tool string 33.7’ cutter 6.9 ’ 1 Minimum ID= 2.750” @ 6,336’ PBTD =6,470’ (MD) / PBTD = 4,052’(TVD) 4 TAM Port Colalr 979’ MD OB Sands 17 OA Sands NC Sands Tubing Leak @ 6,240’ 9 10 13 11 8 6 5 2 NB Sands 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” 18.936” Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835” 8.679” Surface 6,562’ 0.0758 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 2.992” 2.867” Surf 6,349’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,084’ 3.5” HES X-Nipple (2.813” Profile) GLM DETAIL: 3.5” x 1.5” Camco MMG w/ 1.5” RK Latch 2 2,127’Sta #5:[MMG GLM]Valve - Dummy / Date- 7/21/2002 3 5,774’ 3.5” HES X-Nipple (2.813” Profile) 4 5,795’ 9-5/8” x 3.5” HES PHL Packer 5 5,823’Sta #4:[MMG GLM]Valve - Dummy / Date- 8/16/2012 6 5,914’Sta #3:[MMG GLM] Valve –200 bwpd / Date- 11/14/2017 7 6,098’ 9-5/8” x 3.5” HES PHL Packer 8 6,158’Sta #2:[MMG GLM]Valve –200 bwpd / Date- 11/14/2017 9 6,186’RMX Prong – removed 5-17 2020 10 6,198’RMX Sub/3’ Spacer Pipe/Snap Latch 11 6,217’Sta #1:[MMG GLM] Valve –Extended pkg Dummy / Date- 8/18/2012 12 6,218’ Upper Patch Baker 35KB Packer 13 6,239’ Lower Patch Baker 35KB Packer (15k Shear Release) Btm @ 6,245’ 14 6,309’ 9-5/8” x 3.5” HES PHL Packer 15 6,336’ 3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) 16 6,348’ 3.5” WLEG – Bottom @ 6,349’ 17 6,470’ Baker Model K Cement Retainer TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” NS-CT T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 – 8/13/2000 Convert to Injector Nabors 4ES – 7/03/2002 OPEN HOLE / CEMENT DETAIL 20” 260 sx Arctic Set (Approx.) in a 24” Hole 9-5/8” 840 sx ASL, 385 sx Class ‘G’ in a 12-1/4” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 5,860’ 5,870’ 3,810’ 3,814’ 10 4 2-1/8” 3/10/2001 Open 5,890’ 5,910’ 3,823’ 3,831’ 20 4 2-1/8” 3/10/2001 Open NC 5,932’ 5,942’ 3,841’ 3,845’ 10 4 2-1/8” 3/10/2001 Open OA 6,180’ 6,200’ 3,944’ 3,952’ 20 4 2.0” 11/15/2000 Open 6,200’ 6,230’ 3,952’ 3,964’ 30 4 2-1/8” 3/10/2001 Open 6,230’ 6,250’ 3,964’ 3,971’ 20 4 2.0” 11/15/2000 Open OB 6,350’ 6,360’ 4,008’ 4,012’ 10 4 2-1/8” 3/10/2001 Open 6,360’ 6,380’ 4,012’ 4,019’ 20 4 2-1/8” 9/02/2000 Open 6,380’ 6,400’ 4,019’ 4,027’ 20 4 2-1/8” 3/10/2001 Open Ref Log: USIT – 8/12/2000 – Perf Guns 2-1/8” Enerjet 4 spf @ 90 Deg / 2.0” Enerjet 4 spf @ 90 Deg WELL INCLINATION DETAIL KOP @ 400’ Max hole angle = 68 deg. At 3,636’ MD Ange at perfs = 68 deg ___________________________________________________________________________________ Revised By: TDF 5/21/2020 PROPOSED Milne Point Unit Well: MP I-09 Last Completed: 7/03/2002 PTD: 200-103 TD =13,094’(MD) / TD =7,197’(TVD) 20” Orig. KB Elev.: 62.25’/ Orig. GL Elev.: 35.0’ RKB – Tbg Hngr: 21.55’ (Nabors 4ES) 9-5/8” 7 14 12 15 16 TOC ~5,517’ 1 Minimum ID= 2.750” @ 6,336’ PBTD =6,470’ (MD) / PBTD = 4,052’(TVD) 4 TAM Port Colalr 979’ MD OB Sands 17 OA Sands NC Sands Tubing Leak @ 6,240’ 9 10 13 11 8 6 5 2 3 NB Sands 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” 18.936” Surface 110' 0.3550 9-5/8" Production 40 / L-80 / BTC 8.835” 8.679” Surface 6,562’ 0.0758 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 2.992” 2.867” 5,790’ 6,349’ 0.0087 JEWELRY DETAIL No Depth Item 1 ±5,780’Cement Retainer 2 ±5,790’Tubing Cut 3 5,774’ 3.5” HES X-Nipple (2.813” Profile) 4 5,795’ 9-5/8” x 3.5” HES PHL Packer 5 5,823’Sta #4: [MMG GLM] Valve - DV 6 5,914’Sta #3: [MMG GLM] Valve – DV 7 6,098’ 9-5/8” x 3.5” HES PHL Packer 8 6,158’Sta #2: [MMG GLM] Valve – DV 11 6,217’Sta #1: [MMG GLM] Valve – Extended pkg Dummy / Date- 8/18/2012 12 6,218’ Upper Patch Baker 35KB Packer 13 6,239’ Lower Patch Baker 35KB Packer (15k Shear Release) Btm @ 6,245’ 14 6,309’ 9-5/8” x 3.5” HES PHL Packer 15 6,336’ 3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) 16 6,348’ 3.5” WLEG – Bottom @ 6,349’ 17 6,470’ Baker Model K Cement Retainer TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” NS-CT T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22964-00-00 Drilled & Cased by Doyon 141 – 8/13/2000 Convert to Injector Nabors 4ES – 7/03/2002 OPEN HOLE / CEMENT DETAIL 20” 260 sx Arctic Set (Approx.) in a 24” Hole 9-5/8” 840 sx ASL, 385 sx Class ‘G’ in a 12-1/4” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 5,860’ 5,870’ 3,810’ 3,814’ 10 4 2-1/8” 3/10/2001 Abandon 5,890’ 5,910’ 3,823’ 3,831’ 20 4 2-1/8” 3/10/2001 Abandon NC 5,932’ 5,942’ 3,841’ 3,845’ 10 4 2-1/8” 3/10/2001 Abandon OA 6,180’ 6,200’ 3,944’ 3,952’ 20 4 2.0” 11/15/2000 Abandon 6,200’ 6,230’ 3,952’ 3,964’ 30 4 2-1/8” 3/10/2001 Abandon 6,230’ 6,250’ 3,964’ 3,971’ 20 4 2.0” 11/15/2000 Abandon OB 6,350’ 6,360’ 4,008’ 4,012’ 10 4 2-1/8” 3/10/2001 Abandon 6,360’ 6,380’ 4,012’ 4,019’ 20 4 2-1/8” 9/02/2000 Abandon 6,380’ 6,400’ 4,019’ 4,027’ 20 4 2-1/8” 3/10/2001 Abandon Ref Log: USIT – 8/12/2000 – Perf Guns 2-1/8” Enerjet 4 spf @ 90 Deg / 2.0” Enerjet 4 spf @ 90 Deg WELL INCLINATION DETAIL KOP @ 400’ Max hole angle = 68 deg. At 3,636’ MD Ange at perfs = 68 deg Tag plug and pressure test to 2000 psi Set up to convert to WSW. 20 bbls cmt above retainer COIL BOPE MPU I-09 13д X9з X 7 X 3½ Valve, Swab, WKM-M, 3 1/8 5M FE Valve, Upper Master, Baker, 3 1/8 5M FE, w/ Hydraulic Valve, Lower Master, WKM-M, 3 1/8 5M FE Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe Manual Gate 2 1/8 5M 2.00" Single Stripper Crossover spool 4 1/16 10M X 4 1/16 5M Manual Gate 2 1/8 5M Tubing Adapter, 3 1/8 5M Pump-In Sub 4 1/16 5M 1502 Union Crossover spool 4 1/16 5M X 3 1/8 5M Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: May 29, 2019Subject: Changes to Approved Sundry Procedure for Well MPU I-09 Suspend SB sandsSundry #: TBDAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I 67/ I l9 DATE: Tuesday, April 30, 2019 SUBJECT: Mechanical Integrity Tests P.I. Supervisor 1 `e�Q { t HILCORP ALASKA LLC 1-09 FROM: Guy Cook MILNE PT UNIT 1-09 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry .V NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT 1-09 API Well Number 50-029-22964-00-00 Inspector Name: Guy Cook Permit Number: 200-103-0 Inspection Date: 4/25/2019 ✓ Insp Num: mitGDC190427055401 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-09 ' Type Inj w -TVD 3783 Tubing o9s 1098 loge 09' PTD 2001030 ' Type Test sPT�Test psi 1500 IA a3 9zo sn s5-1 BBL Pumped: 3 . iBBL Returned: 31 OA Interval aYRTST _ WIT P A Little Red Services um truck and calibrated gauges were used for testing. No OA for this well. Notes: pump g g g� Tuesday, April 30, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: I DATE: Wednesday,April 15,2015 Jim Regg 1- I15 P.I.Supervisor e SUBJECT:Mechanical Integrity Tests HILCORP ALASKA LLC I-09 FROM: John Crisp MILNE PT UNIT SB I-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry , k'-- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB I-09 API Well Number 50-029-22964-00-00 Inspector Name: John Crisp Permit Number: 200-103-0 Inspection Date: 4/9/2015 Insp Num: mitJCr150413042138 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-09 " 'Type Inj W TVD 3783 I Tubing 1248 1244 1248 - 1254 - PTD 2001030 - Type Test SPT Test psi 1500 f IA 322 2074 - 2035 2025 • Interval J4YRTST P/F P OA Notes: 3 2 bbls pumped for test Monobore injector SCANNED MAY 0 4 2D15 Wednesday,April 15,2015 Page 1 of 1 • 0).,, ,/,7,‹,s. THE STATE Alaska it and as ALAS, A Conservation Co ission GOVERNOR SEAN PARNELL 333 West Seventh Avenue rh OF Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 rt\ Fax: 907.276.7542 Alecia Wood Petroleum Engineer BP Exploration(Alaska), Inc. O 103 P.O. Box 196612 Q� Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPI-09 Sundry Number: 313-446 Dear Ms. Wood: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this day of September, 2013. Encl. • STATE OF ALASKA PIS 7t 1/..3 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate El- Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 200-103-0 ■il 3.Address: Stratigraphic ❑ Service El • 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22964-00-00• 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? AA447.05 SBL MPI-09 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517• MILNE POINT, SCHRADER BLFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total ota Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): s. 13094 - 7197 - 6470 •4052 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.1#H-40 28-108 28-108 Surface None None None None None None Intermediate None None None None None None Production 6535 9-5/8"40#L-80 27-6562 27-4086.71 5750 3090 Liner 15 2-7/8"6.5#L-80 6225-6240 3961.71-3967.3 10570 11160 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment • See Attachment 3-1/2"9.3#L-80 L-80 26-6349 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 113.Well Class after proposed work: Detailed Operations Program 0 e BOP Sketch ❑ Exploratory ❑ Development ❑ Service el 14.Estimated Date for '15.Well Status after proposed work: Operations: 9/1/13 Commencing Oil g O p ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 151. GINJ ❑ WAG ❑ Abanda,ed ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Alecia.WoodOBP.com Printed Name Alecia Wood Title PE Signature j on ( Pho ne Date l564-5492 8/15/2013 COMMISSION USE ONLY �j Conditions of approval: Notify Commission so that a representative may witness Sundry Number v 1' - -I(J qo Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBEA OCT 1 0 AI- Spacing Exception Required? Yes ❑ No VI Subsequent Form Required: /0 — !�Q+ APPROVED BY I Approved by: (r!--i/t./-i;,(� �� COMMISSIONER THE COMMISSION Date: --,5 /3 Form 10-403 Revised 1/2010 ApprcQ RifG if A I months from the date of approval Subb iitt in Duplicate �\y�\ • • bp To: Mark O'Malley/Rob Handy Date: August 14, 2013 MPU Well Operations Supervisor From: Alecia Wood, MPU Schrader Pad Engineer 907-564-5492 Subject: MPI-09 Acidize Stimulation Step Unit Operation 1 S WFRV change outs for zonal acid stimulation 2 F Acidize HISTORY MPI-09 was converted to a regulated injector from a producer in 2002. This well initially had good injectivity but struggles with Schmoo build-up and other wellbore debris in the tubing. An IPROF was run on 4/15/11 while injecting 1750 bwpd, showing most of the water exiting the GLM @ 5823' with the rest of the fluid exiting at the GLM @ 5914'. Both of these GLM are in the N sand. On May 22, 2011, all the WFRV's were changed out and the suspected leaking dummy in the GLM @ 5914' was changed out. Upon putting on injection the pressure was increased to ensure the WFRV's were functioning and the rate jumped to 3000 bwpd when the valves had a total rating of 1700 bwpd. The well was then re-entered and all the GLM's were dummied. A LDL found the tubing leak at 6240'MD, which is in the OA. A WFRV was run in the XN nipple and packoff over the leak at 6240'. The well continued to struggle to inject at the total valve ratings of 1779 bwpd. The upper two valves above the patch were changed out in November 2011, but the well still injected below target. An injectivity test of the lower valve was performed 6/18/12 and found to be plugged completely, holding 1200psi WHIP with zero injection. In October 2012 the patch was Re-Set with a top sub assembly to allow for an RMX Prong to be set with a WFRV to allow for the OB valves to be changed out without having to pull the patch over the leaking tubing in the OA. Offset producers have gone to high GOR, and the targets for this well were increased. The well has since not been able to take its target rate, and an IPROF confirmed that the OA is the zone not taking its target. MPI-09 is injecting —1050bwpd. The desired injection rate is 1750bwpd. OBJECTIVE The objective of this program is to acidize the OA to increase injectivity into the zone. PROCEDURE 1. RU, hold pre-job safety meeting, PT 2. Dummy off the N sand @ 5914'MD 3. Set retrievable plug above the OB prong @ 6200'MD 4. Pump 20 bbls of HCL/Xylene and soak OA perfs. 5. Flush with a minimum of 50 bbls of Produced Water. 6. Pull Dummy from N, set WFRV 7. Pull plug over OB 8. RDMO SL • • 1 • Tree: 31/8"-5M MPU 1-09 Wellhead:11" 5M FMC Gen.6 Orig.DF Neer= 6225'(Di on 141) w/10"x 3.5"FMC Tbg.ling 3.F - Orig.GL.elev.= 34.5' NSCT top&bottom RT to 95/8"csg.hog.=21.55' connection crossed bark to 31/2"8 rd,3" CIW '1.1"BPV profile 20"91.1 pp(,H-40 113' I 1 -1ES X-Nipple 2.813"Mn.id 2084' KOPLP 400' Max.hole angle=67 deg. 3000'-PBTD 60 deg.to 68 deg. Hole angle through perfs=68 deg. ' 3 1/2'X 1 1/2 A4MG SPM 2127 9-5/8',40 ppf,L-80,Btrc. (drift ID=8.835",c =0.0758 L91) 3 1/2"9.3 p0,L-80,8 rd_Eta tbg. (drift ID=2867",rap_=0.0087 bpf} Minimum tubing restriction= 1.62"D&D Paciwff I@ 6232"MD I I HES X-Nipple 2 813"Mn.id 5774' 9 5/6"x3 12'HES PHU Pkr 5795' Valves in SPM/XN: Arrangement as of 10125112 Max rai from SBH 1 P5 5/31110 to e/16 0: 31/2 X 1 12 !NAG SPAT ' N Sands:2630 psi OA Sands:2697 psi 08 Sands:2494 psi ' 312'X 1 117 MUG SPM 5914' 3-1 ir DOT lfBPadmlf " Across tole at 8240'LC ..- 8 518'X 3 112 HES'PHL'Pkr ' Tap elrn 4[?t at 8225'A — Bottom element at 624f MD ., Sea 111/23/12 3 177 X 1 117 MUG Snap latch extensan,above patch — SPM Erna with MAX sub ataohed Peoforabon S1 err — :?VZ X 1 1."2"MMG SPM 6217' Ref Ioq.. USIT 8112100 ;` p�* size SPF Wawa' (1V _. rs.,,. 9 5/8'X 3 1/Z'HES 1=1"1:Pkr 6309' 2-W 4 6055-6070' 3410'-3015' Tl. HES XI4 tkiple 275"Min.d I 6336' I 2-iA' 4 40S1r'•6011G1 31127-3e31' _. 23/4' 4 ø •- C 31$41•31141 1 n 31/2"AUG CA tondo 2-44 4 Y14J 108111" Of f•310T1' -- _--.--. Biker leach!K Comae Mahal"8470' i6 9b1a of orla G wari.ms bekxic 013 sands 2-1/8' i 4 8350'-8400' 4808'-40211 IL 95/8'float aailffi PBTD) 6476. 9 5/e"oasng shoe 6560' Well plugged back ba'sance plug eat top 0 12.000' org.Id 4 13,084' DATE REV.BY COMMENTS MILNE POINT UNIT erz„oc MCa raum bird Compiddr1 Dwon 141 WELL i-09 11/16000 MO What. m PVfirwm DA 03/10/01 M.Linder Convert to producer API NO: 50-029-22964-00 7/3102 Lee Hulme Conversion to Injector BP EXPLORATION (AK) • • Perforation Attachment ADL0025517 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPI-09 6/18/12 STO 5860 5870 3810 3814 MPI-09 6/18/12 STO 5890 5910 3823 3831 MPI-09 6/18/12 STO 5932 5942 3841 3845 MPI-09 8/18/12 STC 6180 6200 3944 3952 MPI-09 8/18/12 STC 2 6 00 6230 3952 396 4 MPI-09 8/18/12 STC 6230 6250 3964 3971 MPI-09 9/24/03 STO 6350 6360 4008 4012 MPI-09 9/24/03 STO 6360 6380 _ 4012 4019 MPI-09 9/24/03 STO 6380 6400 4019 4027 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF RECEIVED STATE OF ALASKA /AKA OIL AND GAS CONSERVATION COM� Al1R�ION NOV 2 0 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate 11 OtherU Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved P g App ed rogram ❑ Operat. Shutdown0 Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ 200 -103 -0 3. Address: P.O. Box 196612 Strati ra hi Service 6. API Number: 9 p � 0 .,- Anchorage, AK 99519 -6612 50- 029 - 22964 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: f ADL0025517 - SBL MPI -09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): J To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 13094 feet Plugs measured None feet true vertical 7196 feet Junk measured None feet Effective Depth measured 6470 feet Packer measured See Attachment feet true vertical 4052.46 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.1# H-40 28 - 108 28 - 108 1530 520 Surface None None None None None None Intermediate None None None None None None Production 6535 9 -5/8" 40# L -80 27 - 6562 27 - 4086.71 5750 3090 Liner 15 2 -7/8" 6.5# L -80 6225 - 6240 3961.71 - 3967.3 10570 11160 Perforation depth Measured depth 5860 - 5870 feet 5890 - 5910 feet 5932 - 5942 feet 6180 - 6200 feet 6200 - 6230 feet 6230 - 6250 feet 6350 - 6360 feet 6360 - 6380 feet 6380 - 6400 feet True Vertical depth 3810.27 - 3814.44 feet 3822.81 - 3831.22 feet 3840.51 - 3844.75 feet 3944.49 - 3952.23 feet 3952.23 - 3963.58 feet 3963.58 - 3971.02 feet 4008.3 - 4012.01 feet 4012.01 - 4019.41 feet 4019.41 - 4026.77 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 26 - 6349 26 - 4007.93 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: SCANNED Intervals treated (measured): SCANNED FEB 2 8 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1118 0 1289 Subsequent to operation: 0 0 1024 0 1014 14. Attachments: 15. Well Class after work: ,. Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service ID Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: , Oil ❑ Gas U WDSPLU GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUC-❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry.Catfon BP.Com Printed Name Garry Catron Title PDC PE Signature it1/1 4 _ 7 , &N Phone 564 -4424 Date 11/19/2012 !2d?' 1 Z l2 6 (/y Form 10-404 Revised 10/2012 Submit Original Only • • Packers and SSV's Attachment ADL0025517 SW Name Type MD TVD Depscription MPI -09 PACKER 5795 3720.94 3 -1/2" HES PHL PACKER MPI -09 PACKER 6098 3849.12 3 -1/2" HES PHL PACKER MPI -09 PACKER 6225 3899.46 2 -7/8" Baker KB Packer MPI -09 PACKER 6240 3905.05 2 -7/8" Baker KB Packer MPI -09 PACKER 6309 3930.76 3 -1/2" HES PHL PACKER • • Daily Report of Well Operations ADL0025517 AC * ** CONTINUED FROM 10 -22 -12 * ** (set patch) DRIFT W/ 2.80" GAUGE RING,TAGGED @ 6218' SLM. RAN HALLIBURTON DPU W/ BAKER SNAP LATCH & PATCH ASSEMBLY.SET @ 6218' SLM. MADE SEVERAL ATTEMPTS W/ VARIOUS SET UPS TO SET TOP SNAP LATCHW/ RMX SUB @ 6197' SLM (see log). UNSUCCESSFUL LATCHING LOWER ASSEMBLY. 10/23/2012 * ** CONTINUE ON 10 -24 -12 * ** * ** CONTINUED FROM T0- 13 -12* (set patch) MADE SEVERAL ATTEMPTS SETTING BAKER SNAP LATCH W/ RMX SUB @ 6197' SLM.NO LUCK LATCHING IN (see log). HOLD WELL CONTROL DRILL. MADE SEVERAL ATTEMPTS W/ BAKER SNAP LATCH W/ 12' SPACER PIPE & RMX @ 6197' SLM.UNABLE TO LATCH IN (see log). 10/24/2012 * ** CONTINE ON 10 -25 -12 * ** ***CONTINUED FROM 10 -24 -12 * ** (set patch) SET RMX SUB W/ 12' SPACER & BAKER SNAP LATCH @ 6198' SLM. HELD MAN DOWN & WELL CONTROL SAFETY DRILL. SET RMX PRONG W/ 1.5" P -15 (350 bwpd) @ 6186' SLM. 10/25/2012 * ** WELL LEFT S/I ON DEPARTURE * ** T /I= 800/80 Freeze protect tubing and injection line. Pumped 22 bbls 60/40 11/17/2012 down tubing and 5 bbls 60/40 down injection line. Final WHPs= 800/80 • • Tree: 3 1/8" - 5M MPU 1 -09 Orig. DF elev. = 62.25' (Doyon 141) Wellhead: 11" 5M FMC Gen. 6 g' w /10" x 3.5" FMC Tbg. Hng., 3.5" Orig. GL. elev.= 34.5' NSCT top & bottom RT to 95/8" csg. hng. = 21.55' connection crossed back to 3 1/2" 8 rd., 3" CIW "H" BPV profile 20" 91.1 ppf, H -40 113' 1 1 HES X Nipple 2.813" Min. id 2084' KOP @ 400' Max. hole angle = 67 deg. 3000'- PBTD 60 deg. to 68 deg. �, Hole angle through perfs = 68 deg. 3 1/2' X 1 1/2" MMG SPM 2127' 9 -5/8' , 40 ppf, L -80, Btrc. ( drift ID = 8.835 ", cap. = 0.0758 bpf ) 3 1/2" 9.3 ppf, L -80, 8 rd. EUE tbg. ( drift ID = 2.867 ", cap. = 0.0087 bpf ) Minimum tubing restriction = 1.62" D&D Packoff @ 6232' MD 1 1 HES X- Nipple 2.813" Min. id 5774' 9 5/8" X 3 1/2" HES 'PHL' Pkr 5795' Valves in SPM / XN: 1 Arrangement as of 10/25/12 DV Max osi from SRHPS 5/31/10 to 6/16/10; 3 1/2' X 1 1/2" MMG SPM 5823' N Sands: 2630 psi OA Sands: 2697 psi RWF OB Sands: 2494 psi 600 3 1/2' X 1 1/2" MMG SPM 5914' 3 " Pack° 3 hole BOT KB at 6240' D 9 5/8" X 3 1/2" HES 'PHL' Pkr Top element at 6225' MD 6098' Bottom element at 6245' MD RWF Set 10/23/12 290 31/2 X 1112' MMG SPM1 Snap latch extension above patch , €.1e.:8' ___ j with RMX sub attached , DV Perforation Summery w/ ext D 3 1/2' X 1 1/2" MMG SPM 6217' Rel Ion: USIT 8/12100 p Si :e SPF Interval (TVD) ----- 9 5/8" X 3 1/2" HES 'PHL' Pkr 6309' II- 2 -1 1!<" 4 68e0'-6870' 3810'., 3816' HESXI'4 t'#ipple 2.7E" Mm. id 1 6336' 2 -112' 4 MO- f411a 3822-3831' 2 -110" 4 61132- 6841' 3841Y-3848 / 31/2 "WLEG 1 6349' i 0A. rankle 2 -118 4 8180- 6260" ! 304? -3971' l ,.1:„.z.44..,. - I3ak @r model f: t;evoeht retainer Girt 6470' ff�fi 16 8bfs of crass G cement below. OB sands 2 -1/8" 4 6350' -6400' 4008' -4026' 9 5/8" float collar (PBTD) 6476' 9 5/8" casing shoe 6560' Well plugged back balance plug est. top @ 12,600' / arg. td @ 13,094' DATE REV. BY COMMENTS MILNE POINT UNIT 8/21/00 MDO Drilled and Completed Doyon 141 11/15/00 MDO Initial Perforations OA WELL 1 - 09 03/10/01 M. Linder Convert to producer API NO: 50 - 029 - 22964 - 7/3/02 Lee Hulme Conversion to Injector BP EXPLORATION (AK) ■ I I I I I MI , A � � � THE STATE Alaska Oil and Gas Of ALAS A Commission Conservation Commissi S - -' Its ~ GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op, ALAS Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Alecia Wood i:. ±t:A. NE,0 i % ij " < Production Engineer BP Exploration (Alaska), Inc. !� a0 0-10 3 P.O. Box 196612 p� Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPI -09 Sundry Number: 312 -363 Dear Ms. Wood: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, acv r Cathy 1 Foerster Chair DATED this ? day of October, 2012. Encl. 0 0 RECEIVED STATE OF ALASKA � S EP 2 2 012 (SI ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrili ❑ Perforate New Pool ❑ Repair Well o • Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ ))__Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: . cafi e 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 200 -103-0 • 3. Address: Stratigraphic ❑ Service ID • 6. API Number. P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 22964 -00 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No IN MPI - • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025517 • MILNE POINT, SCHRADER BLFF OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13094 • 7197 • 6470 4052 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.1# H-40 28 - 108 28 - 108 Surface None None None None None None Intermediate None None None None None None Production 6535 9 -5/8" 40# L -80 27 - 6562 27 - 4086.71 5750 3090 Liner None None None None None None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 3 -1/2" 9.3# L -80 L -80 26 - 6349 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 19 BOP Sketch ❑ Exploratory ❑ Development ❑ Service El P 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1010.11@ Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 , GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Prepared by Garry Catron 564 -4424 Printed Name Alecia Wood Title Production Engineer Signature n p � � Phone 564 -5492 Date QHa4 4c)kp COMMISSION USE ONLY l Iv Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 (03 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 1 4.__ APPROVED BY Approved by: j > Y 4�J i COMMISSIONER THE COMMISSION Date: / C — S ° �Z Form 10-403 Revised 1/2010 /CO / Z r 1 1 R211 ` l �� SubmrA 0 I I licat� t 0 VV /� ,v y' 0 Perforation Attachment ADL0025517 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPI -09 9/24/03 STO 5860 5870 3810 3814 MPI -09 9/24/03 STO 5890 5910 3823 3831 MPI -09 9/24/03 STO 5932 5942 3841 3845 MPI -09 7/21/02 STO 6180 6200 3944 3952 MPI -09 7/21/02 STO 6200 6230 3952 3964 MPI -09 7/21/02 STO 6230 6250 3964 3971 MPI -09 9/20/06 CKS 6350 6360 4008 4012 MPI -09 9/20/06 CKS 6360 6380 4012 4019 MPI -09 9/20/06 CKS 6380 6400 4019 4027 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE CKS CHOKE SET CKP CHOKE PULLED FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Packers and SSV's Attachment ADL0025517 Well Facility Type MD Top Description TVD Top MPI -09 PACKER 5795 3 -1/2" HES PHL PACKER 3783 MPI -09 PACKER 6098 3 -1/2" HES PHL PACKER 3911 MPI -09 PACKER 6309 3 -1/2" HES PHL PACKER 3993 bp To: Mark O'Malley/Rob Handy Date: September 13, 2012 Field Ops Team Leads From: Alecia Wood, Tract 14 PE AFE: Subject: MPI -09 Patch Reset w/KB and Top Sub Assembly Est. Cost: Rev 2. Updates in Red. IOR: 75 Step Unit Operation 1- P's, Pull D&D Patch and WFRV, Complete 2 E Run bottom packer of Baker 35 KB Straddle V 3 S Run slick sticks, top packer, Baker snap latch /BP Top Sub Assembly and RMX Prong with WFRV. krorret Current Status: Operable PWI (44-1- Last Injection: 982 bwpd @ 1284 psi WHIP 07/01/12 Max Deviation: 60 - 68° from 3000' through 11,000'MD. Min ID: 1.62 "@ 6232'MD. D &D Packoff. Last Tag TD: 08/30/12: 6310'MD w /10'drift. Last Down hole Op: 8/30/12: Drift for patch. Objective The objective of this procedure is to obtain zonal static reservoir pressures and to replace the D &D Straddle Assembly with a KB Patch and top sub assembly with a profile to set an RMX Prong, allowing access to the regulation of the OB zone. Sep 13 updated program due to short drift length of 10'. Change is to allow EL to set bottom packer only, Slickline to set spacer pipe and top packer of the patch. Background MPI -09 was converted to a regulated injector from a producer in 2002. This well has good injectivity but struggles with Schmoo build -up and other wellbore debris in the tubing. Entering this well at a minimum of yearly to change valves and conduct a general cleanup should help avoid poor injection conformance and extended cleanups. An IPROF was run on 4/15/11 while injecting 1750 bwpd, showing most of the water exiting the GLM @ 5823' with the rest of the fluid exiting at the GLM @ 5914'. Both of these GLM are in the N sand. On May 22, 2011, all the WFRV's were changed out and the suspected leaking dummy in the GLM @ 5914' was changed out. Upon putting on injection the pressure was increased to ensure the WFRV's were functioning and the rate jumped to 3000 bwpd when the valves had a total rating of 1700 bwpd. The well was then re- entered and all the GLM's were dummied. A LDL found the tubing leak at 6240'. A WFRV was run in the XN nipple and packoff over the leak at 6240'. The upper 2 zones also have WFRV's installed. The well continued to struggle to inject at the total valve ratings of 1779 bwpd. The upper two valves above the patch were changed out in November 2011, but the well still injected below target. An injectivity test of the lower valve was performed 6/18/12 and found to be plugged completely, holding 1200psi WHIP with zero injection. The upper valves were changed out with new targets. General Procedure: Slickline (Shelter during TAR): Complete 1. MIRU SL unit. 2. RIH and pull dummy from 5823'MD • p_, '1. RIH and sct dummy at 5823'MD 5. RIH and pull dummy from 6217'MD • - _ ' . • . 7. RIH and sct dummy at 6217'MD 8. Pull D &D Packoff assembly from 6235'MD 9. RIH and bail fill as nccdcd 1 41. n 11. D &T w /dmy patch. Adjust SBHP depth as necessary. Longest Drift was 10ft. • •!_1 •! 13. RDMO SL Electric Line Reference Log: SLB PDSView LDL Dated 6/15/2012. ➢ Patch Specifications: 3 -1/2" Baker KB packer 15' Element to Element L -80 patch. Min ID = 1.830" Maximum OD = 2.78." (See attached) 14. MIRU EL 15. RIH and tie into SLB PDSView LDL dated 6/15/12. • 16. Set bottom packer only for depth control of 15' Baker KB patch to be set from 6230' to 6245 `MD per manufacturer's specifications to straddle the tubing leak at - 6240'MD. (See attached annotated jewelry log). Note that the previous patch was set on SL. The top packer annotated at 6235' would sit directly on a tubing collar if this were its true set depth. The LDL shows the leak at somewhere between 6232' and 6240'MD, so the patch length was increased to 15' to straddle the leak and CC. Please note: SL was only able to drift with a l Oft drift. EL to set bottom packer for depth control, SL to set slick sticks, top packer, top sub assembly and WFRV. 17. RDMO EL Slickline 18. MIRU SL 19. RIH and set slick stick spacers pipes to allow for the top packer to sit at 6245'MD. Note that the longest drift was 1 Oft. 20. Set top packer at 6245'MD. 21. Set Baker Snap Latch with BP Top Sub Assembly. This will incorporate a profile for an RMX lock as shown in the attachment below. This snap latch will be removable from the straddle assembly without pulling the straddle, and allow for change outs of the WFRV to regulate the OB flow. Note Min ID of Snap Latch is 1.62," Min ID of Top Sub is 1.56 ". The Top Sub Assembly is being built at Unique Machine. 22. Set prong with WFRV set for - 350bwpd in top sub assembly. (Brad Elias and Johnny Kenda were both consulted and are on board with this configuration). 23. RDMO SL Operations 24. Put well on injection with a target of 1000 bwpd with max injection pressure of 1200 psiq. Please don't hesitate to contact Alecia Wood with any comments or suggestions at 907 - 394 -2485 (cell) or 564 -5492 (work). cc: Anchorage MPI -09 well file ‘4 MPI -09 Injection Straddle Baker 35 "KB" Ah.1�!Pi�EC OD tD Length BP Top Sub 3" "GS" FN x 2 3/8" STE Pin 2.704" 1.560" 1,92` With "RIM" Profile Run on 5/E • ''" Latch Baker 3 .4 Snap Eatc 2.700" 1.,62" 2.34' Made up to BP Top Sub Run on 5/E II • • 6230' Baker 35 "KB' Single Set Straddle 2.78" 1.81" 25.17" it EtoE W /ESet ■.■ .e. Wf 'YI..iVx, Fovea tnd decor err aarwMute AskoI dnrral a 6r4snmtrrd tr same. . wdltr upon rr.stj. sre`w *aka I wtry aid a,prrr. cu -e116-12 • 0 MPI -09 _ injection Straddle ""-....' Baker 35 "KB" IT a • AFE# AMPINJEC , •a PX Prong - Assembly w/ RWF /RMX Valve ' Baker 35 "KB" 07 Straddle Packler f i . o . r .. e, n BP Top Sub w/ R:WF /RMX Profile — -- t r - - -1 1 Baker Snap latch 10 . - MIN a i1 UL a. U a. In#tto, sod d4Ha a.appasknata Advai tirmesicta iu6.c.t.lt+nrm+i Lwwra .un*wmun..wsr mluimah. 1 w bV P.d .np?a.n, LU 4 Pt 7 �. Top Sub 3' "GS" FN x RMX Profile x Blank for 2 3/B" Pin MPI-09 AFE# AMPINIEC 23,30' '2 .2 76L i .275" 4—LW 0 <_' t 3.5i217 # I W6 A .657' dre 270C• 2.32' 1.99r " egg' 2.31" y 1" 2.4tC?" 1 Cheerier grader WE' Leae dare de remakes 7o 2IS' 3TL Pin or t Or 2 "0 WD Fin • Varier SI'ouaer 1H6' r sa.w'a+4nn"M !D i.:4' 0 • TUBING SUMMARY ' RIG NABORS 4ES Date 7/'22002 '' Br, WEL s MPLOq TUBING 3.5" 1-90 WiD EUE MOO TBG WT. 0.3 220 JTS ON RACK 194 JTS RAN OKB TO BF 6861.78 FT ON RACK FT RAN ITEM Description includes: SIZE, TYPE, CONNECTION (JTS 94) ITEM ID OD LENGTH TOP BOTTOM 3.5" WLEG OCR 1.30 6347.58 634828 3.5" 921 Lao NSCT BXP 9.85 6337.73 6347.56 PIES 3.5" "Mr NIPPLE OCR 124 6336.49 633723 3.5" 9.39180 X -OVER EUE ORD X B X NSCT 10.00 63126.40 6336.49 32" 92e L -80 ORD EUE PUP 10.03 6316.37 6326.40 Leak between PIES g-5r PHL 401-471 RET. PKR 7.75 6306.62 6316.37 6232' and 3.5'921180 3RD EUE PUP 10.00 6298.62 6 08 6240'MD 2-JTS. 3.5" 0.211-00 ORD EUE TBG. 62.73 6235.69 6298.62 3.5" 9.31100 ORD EUE PUP 10.05 6225.64 623180 3.E X 1.5" 'MMG W+ DUMMY 8.44 6217.40 6225.84 3.5" 9.31180 ORD EUE PUP 10.01 6207.39 6217.40 1JTS. 3.r 9 e 1410 =`'r EUE t . 31.37 6176.02 6207.39 3.5" 931180 ORD EUE PUP 10.06 6165.94 6176.02 3.5" X I" "MMG' WI DUMMY 942 6157.52 6165.94 3.5" 9.311 L90 ORD EUE PUP 10.07 6147.45 6157.52 1 -JTS. 3.r 0.21180 8RD EUE TBG. 31.41 6116.04 6147.45 3.5" 9.31 LBO SRO EUE PUP 10.00 610604 6116.04 PIES 9-56" PHI. 409 -471 RET. PKR 7.74 6090.30 6106.04 3.5" 9.311110 ORD EUE PUP 10.00 6088,30 6095.30 5- 0 . 80 't+' , 155.31 5932.99 6008.30 3.5" 9.31160 eRG EUE PUP 10.10 5922.89 593290 33" X 1.5" "WIG' WI DUMMY 8,45 5914.44 502289 3.5'" 9.31 LSO ORD EUE PUP 10.10 5904.34 5014.44 II' . 5" 9 . 2 ' i % . 62.77 5041.57 5904.34 3.5" 9.31 LSO ORD EUE PUP 10.10 5031.47 5841.57 3.5" X 1.5" "PANG' WI DUMMY 8.45 502302 5831.47 3.5" 9.31180 ORD EUE PUP 10.10 5312.92 582102 3.5" 9.31 190 ORD EUE PUP 10.01 500291 581292 11 . • . PKR 7.75 5795.16 5002.91 3.5" 9.31 Lao WO EUE PUP 10.00 5785.16 5795.16 3.5' 9.211.80 ORD EUE PUP 10.00 5775.16 57135.16 1.41 577175 5775.16 3.5" 9.31 L80 ORD EUE PUP 10.00 5763.75 5773.75 116JT$.3.3" 0.3Q VW FYF 3618,36 2145.39 5763.75 3.5" 9.31 Leo ORD EUE PUP 10.06 2135.33 2145.39 3.5" X 1.5" WAG WI RP SHEAR VALVE 8.41 2126.92 2135.33 1 3.5" 9.31 Leo MD EUE PUP 10.01 2116.91 2126.92 1 -JTS. 3-5" 9 , • y TUG. 31.33 2005.58 l 2116.91 ''1.7 t 1.41 2004.17 203528 -.13:111.417Ple 'I i J X13)1 205935 2422 2034.17 3.5" 9.31 180 eRG 2.52 22.30 24.82 HANGER .75 21.55 22.30 RT -TS 21.55 _ 21.55 di r iliT — "• ..... . PSRP: Production Services Recorder Platform system and misaadana ripflon of this pus DO Depth Offset for Playback 21.0 FT PP Playback Processing NORMAL :ormat: FULL_PL1 Vertical Scale: 5" per 100 Graphics File Created: 19-Jun-2011 1008 OP System Version: 18C0-147 PFCS-A 18C0-147 PILS-A 1SCO-147 PSRP 18C0-147 Input DLIS Files DEFAULT Flip_FCS _ILS_PSP_034PUP PRODUCER 19-Jun-2011 09:33 6293.7 FT 5700.2 FT Output DLIS Files DEFAULT FCS_ILS_PSP_054PUP FN:96 PRODUCER 19-Jun-2011 10:08 CUSTOMER FCS_ILS_PSP_054PUC FN:97 CUSTOMER 19-Jun-2011 10:08 ckluokerpr Memory Leak Detect Log S Injecting 1 BPM Pass 80 FPM Up Input DLIS Files DEFAULT FCS_ILS_PSP_004PUP FN:3 PRODUCER 18-Jun-2011 20:06 6275.5 FT 5688.0 FT Output DLIS Files DEFAULT FCS_ILS_PS1 FN:98 PRODUCER 19-Jun-2011 10:09 6297.5 FT 5710.0 FT CUSTOMER FCS_ILS_PSP_OS5PUC FN:99 CUSTOMER 19-Jun-2011 10:09 8297,5 FT 5710.0 FT OP System Version: 18C0-147 PFCS-A 18C0-147 PILS-A 18C0-147 PSRP 18C0-147 .... _ PIP SUMMARY e Mark Every an $ , Well Temperature (LNTED _ 1 20 (DEir6 220 ; Well ..... 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Iii .. _ L II MN _ . 0111/M111111 __ INA - - ... - A i 1 111 I PFCS X Cable Voir:icily (CYR.) — Caliper Filtered Main Spinner (SPIN) '...200 IF.MN) 200 (Pi- CI) _20 (BPS) 20 0 (iN) 4 PFCS Y Discriminated CCL (CCLD) Caliper Well Torok:nature (WYE!! -18 (V) i _iPFC2) 80 (DEGF) 100 4 (IN) 0 Gamma Ray (019) Well Pressure (WPRE) 0 (GAPI) 100 1800 (PSIA) 3400 Well Pressure (WPFIE) Differential Telltyerature IWTGR) 0 (PSIA) 4000 -0.5 (DR'F) 05 Well Temperature TEFI) 20 (DEGF) 220 ................-- SL Set D &D Patch WSR's: WELL SERVICE REPORT Set Top Slip Stop WELL DATE JOB SCOPE DAY SUPV MPI -09 7/21/2011 WATERFLOOD REGULATOR PERL AFE Code DAILY WORK NIGHT SUPV AMSIPDWL09 PATCH TUBING / CASING COYNE MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0 " 0 FT 0 " SWCP- MENDEZ SWCP #09 DAILY SUMMARY * ** CONTINUED FROM 7-20-11*** (set tbg patch,c/o wfrv's) SET 3.5" A SUP STOP 0 6210' SLM. LRS PERFORMED INJECTIVITY TEST (see Irs log). SET 3.5" WHIDDON @ 6207' SLM. PULLED 1.5" DGLV & SET 1.5" WFRV (605 bpwd, 15/64 ") IN ST #3 @ 5914' MD. HELD MANDOWN SAFETY DRILL. PULLED 1.5" DGLV FROM ST #2 @ 6158' MD. * ** CONTINUE ON 7-22-11*** LOG ENTRIES !nit Tbg, IA, OA -> 1 1,0001 01 TIME COMMENT 00:00 CONTINUE RIH W/ 3.5" A SLIP STOP. LOOMED TOP OP PATCH 621 a . D R,1 . ., . 01:56 OOH W/ TOOL,SIBO. T /1- 750/0. SLIP STOP SET. CHECKED WHLS, STBY FOR LRS. 03:16 STAB ON BHA. P/T QTS. P/T LUB 300 PSI & 3000 PSI. 05:20 C/O TO COPE. 09:00 LRS ON LOCATION, HOLD JSA AND PJSM, R/U AND PT HOSE. 09:51 GOOD PT ON LRS HOSE. OPEN SWAB FOR INJECTIVITY TEST. /R 10:15 LRS D HOSE. 1 SR 10:54 RIH W/ QC, KJ, 2.62" CENT, 3' x 1 7/8" STEM, 3.5" GS (1/2 Brass Pin ) 3.5" WHIDDON. S/D @ 6207' SLM, OOH SIBD, (T /1/0- 800/0/0 ) WHIDDON SET. 12:51 P!T QTS, EQZ LUBE TO 1000 PSI, (T /I -800/0 ), RIH W/ QC, SWIVEL, 3.5" OM -1 ( long tray catcher) 10" EXT, 1 5/8" JDS ( steel pin) LOC S/D STA #2 @ 6139' SLM/6158' MD. OOH SIBD, (T /I- 350 -0) RECOVER 1.5" DUMMY. 15:00 P/T QTS, EQZ LUBE TO 1000 PSI, (T /1- 350/0) RIH W/ QC, SWIVEL, 3.5" OM -1 ( long tray catcher) RK- DUMMY, LOC S/D STA _ #2 @ 6139' SLM/6158' MD. OOH, SIBD. (T /I/ -250/0 ) VALVE SET. 16:27 P/T QTS, EQZ LUBE TO 1500 PSI, (T /I- 550/0) RIH W/ QC, SWIVEL, 3.5" OM -1 ( long tray catcher) 10" EXT, 1 5/8" JDS (steel pin). STOPPED @ 5825' SLM. BRING TRIPLEX ON LINE, PRESSURED UP TBG TO 1100 PSI. 17:20 C/O TO MENDEZ. HELD PJSM, INSPECT LOC. REVIEW NEW WELL HOUSE ENTRY PROCEDURE. 18:05 CONTINUE RIH W/ KOT. LOC & S/D IN ST #3 @ 5896' SLM/5914' MD. JARRED FREE, TBG PRESSURE DROPPED TO 850 PSI. _ POOH. T /I- 700 /0. RECOVERED 1.5" DGLV. REPIN KOT. 19:00 P/T QTS. EQZ LUB TO 1300 PSI. T /I- 800 /0. RIH W/ QC, SWIVEL, 3.5" OM -1 (long tray) W/ 1.5" WFRV (605 bwpd, 15/64 "). LOC & S/D @ ST #3 @ 5896' SLM/5914' MD. JARRED DOWN FOR 40 MINUTES, GOOD PULL TEST. SHEARED OFF. POOH.T /I- 650/0. VALVE SET, REPIN KOT. 21:30 WSL (oneal Coyne) ON LOC. HELD MANDOWN SAFETY DRILL. 21:50 P!T QTS. EQZ LUB 1300 PSI. T /I- 800/0.. RIH W/ QC, SWIVEL, 3.5" OM -1 W/ EXT, 1.625" JDS (steel pin). LOC & S/D @ ST #2 @ 6139' SLM/6158' SLM. JARRED FREE, TBG PRESSURE DROPPED TO 500 PSI. POOH. T /I- 500/0. RECOVERED 1.5" DGLV._ 23:30 P/T QTS. EQZ LUB TO 1300 PSI. T /I- 500 /0.RIH W/ QC, SWIVEL, 3.5" OM -1 W/ 1.5" WRFV (504 bwpd, 14/64 "). 23:59 CONTINUE ON 7- 22 -11. Final Tbg, IA, OA -> I 5001 01 1 WELL SERVICE REPORT RIH w /Top Slip Stop WELL DATE JOB SCOPE DAY SUPV MPI -09 7/20/2011 WATERFLOOD REGULATOR PERL AFE Code DAILY WORK NIGHT SUPV AMSIPDWL09 PATCH TUBING / CASING COYNE MIN ID I DEPTH TTL SIZE [KEY PERSON UNIT 0 11, I 0 " 10 FT 10 " SWCP- MENDEZ I SWCP #09 DAILY SUMMARY *** CONTINUED FROM 7 -20 -11 *** (set tbg patch) �� RAN 2.62" CENT, 3' X 1.875" STEM, 2.79" CENT & 2.75" LIB. SA) r� 6224 \ ' . RECOVERED F,N t SION. LRS ASSISTED WHILE RUNNING PATCH. SET 3.5" TBG PATCH (oal- 164 ") @ 6224' SLM. RIH W/3.5" A-1 SUP STOP. *** CONTINUE ON 7 -21 -11 *** LOG ENTRIES !nit Tbg, IA, OA ->1 5001 01 TIME COMMENT 00:00 CONTINUE FROM 7- 19 -11. 00:20 P/T LUB 300 PSI & 3000 PSI. RIH W/ QC, KJ, 2.62" CENT, 3' X 1.875" STEM, 2.80" CENT & 2.75" LIB. DOWN S T POC44. RECOVEM IVAIPSSION 'OP AO-210P. CHECKED WHLS. 02:30 P/T QTS. EQZ LUB TO 1500 PSI. T /I- 500/0. RIH W QC, KJ, 3.5" GS (brass pin) W/ 041 ACM Ft O ", 4'D) THEN MOOD 03:37 TOOLS OtAr PA4fN G *MUM, , WORKED FOR SEVERAL MINUTES. NO LUCK, NOTIFIED WSL. STBY FOR LRS. 05:20 C/O TO COPE. HELD PJSM, STBY FOR LRS. 17:20 C/O TO MENDEZ. HELD PJSM, CONTINUE STBY FOR LRS. 18:54 LRS ON LOC. HELD PJSM, R/U & P!T HOSE. T /I- 500/0. 19:39 _6 .._ WAITS 1140444MAitED '1 1.1 20:32 DOWN ON PUMP. STOPPED @ 6200' SLM. T /1- 1200/0. LET WELL STABILIZE TO INITIAL TBG PRESSURE BEFORE SETTING PATCH. 20:50 RID LRS. PUMPED @ TOTAL OF 39 BBLS. 22:25 TBG PRESSURE © 500 PSI. Si)$ ' ' " I '• 23:17 0011 W/ TOOLS. T /I- 400/0. TRIPLEX ON LINE, PRESSURED TBG UP TO 1200 PSI. SIBO.PATCH SET, CHECKED WHLS. 23:40 P/T QTS. EQZ LUB TO 2100 PSI.T /I- 1000/0. RIH W/ QC,2.62" CENT, 3' X 1.875" STEM, 2.79" CENT & 3.5" GS (half brass) W/ 3.5" A -1 SLIP STOP (oal -20 "). 23:59 CONTINUE ON 7- 21 -11. Final Tbg, IA, OA ->i 1,000 I 0 � 1 WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV MPI -09 7/19/2011 WATERFLOOD REGULATOR PERL AFE Code DAILY WORK NIGHT SUPV AMSIPDWL09 RIG UP COYNE MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0 " 0 FT 0 " SWCP- MENDEZ SWCP #09 DAILY SUMMARY * ** WELL S/I ON ARRIVAL * ** (set tbg patch) R/U SLICKLINE EQUIPMENT. PERFORMED WEEKLY WLV TEST, WITNESSED BY ONEAL COYNE. *** CONTINUE ON 7 -20 -11 * ** LOG ENTRIES !nit Tbg, IA, OA -> I 2001 01 TIME COMMENT 20:00 TRAVEL TO CFP FROM MPF -PAD. PICKED UP TOOLS FROM FIRE HALL. 21:00 AOL. HELD PJSM, INSPECT LOC. START R/U. FUNCTION TEST WLV. TESTED WIRE 23/25/23. TOOL STRING- RS, QC, 10' X 1.875" RLR (2.60" WHLS), QC, OJ, QC, KJ, LSS. _ ®� 23:15 STAB ON W/ BHA. P/T QTS. mm 23:25 PERFORM WEEKLY WLV TEST (passed).WITNESSED BY ONEAL COYNE. 23:59 CONTINUE ON 7- 20 -11. WELL SERVICE REPORT Set Bottom Slip Stop. Top wouldn't Fall. WELL I DATE I JOB SCOPE I DAY SUPV 410 S MPI-09 16/21/2011 WATERFLOOD REGULATOR PERL AFE Code DAILY WORK NIGHT SUPV AMSIPDWL09 ATTEMPT COYNE MIN ID DEPTH TTL SIZE KEY PERSON UNIT 2.75 " 6336 FT 3.5 " SWCP-MENDEZ SWCP #09 DAILY SUMMARY *** CONTINUED FROM 6-20-11 *** (set tbg patch) SET 3.5" AD-2 SLIP STOP @ Ear SLMAl249' MD. LRS ASSISTED PIMPING PATCH DOWN HOLE. ATTEMPTED TO SET 3.5" AD-2 PACK OFF W/ TBG PATCH. S/D @ 5891' SLM, UNABLE TO WORK THRU. PERFORMED WEEKLY WLV, WITNESSED BY ONEAL COYNE. PRIORITY JOB, RETUN ON LATER DAY. ***WELL LEFT S/I *** LOG ENTRIES !nit Tbg, IA, OA -> I 450 I 0 I TIME COMMENT 00:00 CONTINUE POOH W/ TOOLS. 00:37 OOH W/ TOOLS. T/I-450/0. RECOVERED 3.5" AD-2 SLIP STOP. 00:59 EQZ LUB TO 1000 PSI. T/I-550/0. RIH WI 00, 2.78" CENT, 3" .100 (boss pie) IN/ 38" AD-2 SUP STa* teeing toots& *I-25", zeroed @ AVM@ 8225' Stalt AIMED DOWN FOR 10 MINUTES. PICKED OFF FREELY, POOH. 03:00 0011 W/ TOOLS. T/1-500/0. SLIP STOP SET. BREAK OFF 5' RLR, CHECKED WHLS. 03:30 EQZ LUB TO 1000 PSI. T/I-500/0. RIH W/ QC, 3.5" GS (half brass) W/ 3.5" AD-2 PACK OFF (aol-29 1/4", zeroed below pack off). SIDt 6224' SLM, JARRED DOWN FOR 10 MINUTES. LOST 25 LBS, POOH. 05:07 OOH W/ TOOLS. T/I-500/0. 05:30 AOL, INSPECT LOCATION, HOLD JSA AND PJSM, REVIEW AWGRS, 07:00 MAKE NEW DRAWING W/ ALL DETAILS OF MEASUREMENTS, LENGTHS, ID'S AND OD'S. 08:12 EQZ LUB TO 1000 PSI. T/I-550/0. RIH W/ QC, KJ, 3.5" GS (half brass) W/ AD-2 HIGH FLOW PACKOFF ( oal 164", zero @ bottom no-go ) lOOLS WANTING TO S/D FROM 3815' SLM TO 4025' SLM, CONFER W/ WSL. STOP & STBY FOR LRS. 09:00 STBY FOR LRS. 17:30 C/O TO MENDEZ. HELD PJSM, INSPECT LOC. 17:35 LRS ON LOC. HELD PJSM, R/U & P/T HOSE. 18:30 PUMP ON LINE .5 BBL A MINUTE. TOOLS NOT FALLING, INCREASED TO 1.25 BBL A MINUTE (see Irs log). 19:00 S/D © 5891' SLM, DOWN ON PUMP. NOTIFIED WSL. 1910 PUMP ON LINE G 1.5 BBL A MINUTE. WORK FOR SEVERAL MINUTES. NO LUCK. R/D LRS. POOH. 19:45 OOH W/ TOOLS. T/1-800/0.1NSPECT PATCH, NO VISIBLE MARKS. 20:30 PERFORMED WEEKLY WLV TESTED. WITNESSED BY ONEAL COYNE. 21:00 START R/D EQUIPMENT, PRIORITY JOB ON E-PAD. RETURN ON LATER DAY. 23:00 R/D COMPLETED. TRAVEL TO FIREHALL & DROP OFF TBG PATCH. 23:59 END TICKET. TRAVEL TO MPE-PAD. Final Tbg, IA, OA -> I 550 1 0 I 1 WELL SERVICE REPORT Attempt to set bottom Slip Stop WELL DATE JOB SCOPE DAY SUPV MPI-09 6/20/2011 WATERFLOOD REGULATOR PERL AFE Code DAILY WORK NIGHT SUPV AMSIPDWL09 TRBLSHT COYNE MIN ID DEPTH TTL SIZE KEY PERSON UNIT 2.813 " 5774 FT 0" SWCP-HEALY SWCP #09 DAILY SUMMARY **tONt'D FROM 6- PULLED AD-2 SUP STOP FROMO228'SUANI2SYM0 SET AD-2 SLIP STOP @Mr 81W IA/ LOCATED COLLARS 618? SLM, MAX 6121, SLM, ALL WITH A 24' FT CORRECTION.(S** log fo r details). RAN 3° COLLAR LOC 2nd TM FORM CORRECTION. (see log for details). PULLED AD-2 SUP STOP FROM S221 SLM/8245 MD. *** CONTINUE ON 6-21-11 *** LOG ENTRIES • !nit Tbg, IA, OA -> TIME COMMENT 00:01 CONT'D FROM 6 -19 -11 01:00 OOH W/TOOLS 01:15 RIH W/2.78" CENT, 3" JDS, BRASS PIN, SD @ 6226'SLM, ONE SPAG LICK, POOH 02:07 SIBO, OOH W/TOOLS & AD -2 SLIP STOP 02:32 RIH W/2.78" CENT, 3" JDS & AD -2 SLIP STOP(25" long) SD @ 6308' SLM, SHEAR PIN ON THE AD -2 SLIP STOP 03:45 SET AD -2 SLIP STOP @ 6225' SLM, JAR DOWN FOR 10 MIN'S, POOH - 04:07 - 00H W/TOOLS & NO SLIP STOP 04:16 RIH W/2.78" CENT, 3" JDS, 3" COLLAR LOCATOR, SD @ 6225' SLM, WAS ABLE TO LOCATE @ 6187' SLM, 6156' SLM, 6126' SLM 05:20 CALLED FOR VAC TRUCK FOR THE BLEED TAND 05:38 00H W/TOOLS, 05:55 CHANGE OUT TO SLEGERS, INSPECT LOC, PJSM. 06:30 HOT SHOT BACK TO CAMP TO EVALUATE DEPTHS AND SLIP STOP W/WSL 07:30 BACK ON LOC. GET TOOLS READY. 08:00 PUT 600 ON LUBE, RIH W/ 3" JDC (brass), 3" COLLAR LOC. TAG SLIP STOP @ 6,222' SLM, PUH LOC 1st Pt. '12.5' aftrifi3,236' aid) .8' m4 3id (6,,84' sinve,2or md) TT WSL, POOH. 0_9:45 OOH W/TOOLS. START RIG DOWN EQUIP. 11:20 HEAD INTO CAMP FOR C /O. 18:00 AOL, CHECK EQUIPMENT, INSPECT LOCATION, REVIEW CHANGE OUT NOTES, AWGRS, HOLD JSA AND PJSM. 19:00 RE-PAC STUFFING BOX. W 20:46 C/O TO MENDEZ. HELD PJSM, INSPECT LOC. REVIEW C/O NOTES. CONTINUE R/U EQUIPMENT. 22:56 P/T LUB 300 PSI & 2500 PSI. 23:34 144- QC, 2.78" CENT, 3" JDS (brass pin). LATCHED @ 6221' SLM. JARRED FREE, POOH. 23:59 CONTINUE ON 6- 21 -11. Final Tbg, IA, OA ->I 4501 0 WELL SERVICE REPORT WFRV Below Patch WELL DATE JOB SCOPE DAY SUPV MPI -09 6/19/2011 WATERFLOOD REGULATOR PERL AFE Code DAILY WORK NIGHT SUPV AMSIPDWL09 WFR -- FOR RATE; TRBLSHT COYNE MIN ID DEPTH TTL SIZE KEY PERSON UNIT 2.813 " 5774 FT 0 " SWCP -HEALY SWCP #09 DAILY SUMMARY * * *CONT'D FROM 6- 18- 11 * * *(LDL,patch) RAN 2.78 "CENT, 2 -1/2 "JDC, PULLED RMX PRONG & REDRESSED SET RMX PROW Vt51.01 pmt 5ght spring) 833r MD. SET AD -2 SLIP STOP @ 6,228' SLM (6,242' MD). RAN 3" COLLAR LOCATOR, TAG SLIP STOP @ 6,225' SLM, UNSUCCESSFUL LOC COLLAR. PULL 3" AD -2 SLIP STOP @ 6,225' SLM. RAN =JAR LO ATTAR TTD 5 COLLARS, ALL WITH A 24' FT CC TlOPL (sop log for j. ATTEMPTED TO SET AD -2 SLIP STOP @ 6,226' SLM. RAN 2.78" CENT, 3" JDS, SD @ 6226'SLM/6250' MD RAN 2.78" CENT, 3" JDS, COLLAR LOCATOR, LOCATED THREE COLLARS ** *CONTINUE ON 6- 20 -11 * ** LOG ENTRIES Init Tbg, IA, OA -> TIME COMMENT _ _. 00:01 CONT'D FROM 6- 18 -11, RIH W/ 2.78" CENT, 2 -1/2 "JDC 00:17 S/D @ 6305' SLM/6336' MD, LATCED UP, BEGIN JARRING 00:51 UNABLE TO PULL THE PRONG, BLEED TUBING DOWN 100 LBS 01:05 UNABLE TO PULL PRONG, BLEED DWON ANOTHER 100 LBS, 15 MIN'S OF JARRING, CAME FREE, POOH 01:28 SIBO, OOH W/TOOLS & PRONG 01:42 REDRESS THE RMX PRONG 01:59 RIH W/2.78" CENT, 2 -1/2" SB, RMX PRONG, W/1.5" P- 15/XJR(670bwpd, 22/64" port light spring) 02:40 SET THE PRONG • 6336' MD/ 6305' SLM, POOH 03:08 OOH W/TOOLS, NO PRONG 03:21 RIH W/ 2.78" CENT, 3" JDC, 3 "AD -2 SLIP STOP (spring loaded). 05:15 STOPED @ 6201' SLM, WAIT FOR DAY CREW 06:00 CHANGE OUT TO SLEGERS, INSPECT LOC, PJSM. CONT RIH. 06:30 SD @ 6,308' SLM, PUH 80' 6,228' SLM, SET 3" AD -2 SLIP STOP, SET SLIP STOP, PICK OFF CLEAN, POOH. OOH W /JD (sheared), SLIP STOP SET. 08:25 PUT 600 W /DIESEL ON LUBE, RIH W /3" JDC (brass), 3" COLLAR LOCATOR. TAG TOP OF SLIP STOP @ 6,225' SLM, PUH COLLAR LOC TRIPPED @ 6,218' SLM, ATTEMPTED TO SIT DOWN, UNABLE, WOULD ONLY LIGHTLY SIT DOWN. PUH TO 6,189' SLM, ATTEMPTED THAT COLLAR, UNSUCCESSFUL, POOH. 10:00 OOH W/ JD, 3" COLLAR LOCATOR TRIPPED. NEED TO MOVE SLIP STOP DOWN 2'. 10:20 PUT 600 W /DIESEL ON LUBE, RIH W /3" JDC (brass). SD @ 6,225' SLM, LATCH & PULL SLIP STOP. POOH. OOH W/ /SLIP STOP. 12:10 PUT 600 PSI ON LUBE, RIH W /3" JDC (brass), 3" COLLAR LOCATOR (zero'd @ arms). LOC & SD COLLAR @ 6,275' SLM (6,298' MD according to tbg talley). FLAG WIRE, PUH TO NEXT COLLAR. LOC COLLARS @ 6,243' SLM (6,267' MD), 6,212' SLM (6,236' MD), 6,202' SLM (6,226' MD), 6,184' SLM (6,208' MD). CORRECTION OF 24'. POOH. OOH W/TOOLS. 13:50 PUT 600 ON LUBE, RIH W /3" JDC (brass), 3" AD -2 SLIP STOP (spring loaded, OAL =25 ", max od= 2.72 "). STOP AT FLAG @ 6,275' SLM, WAIT FOR WSL. WSL ON LOC, SHEAR SLIP STOP, PUH 49' TO 6,226' SLM. BEAT DOWN FOR 10 MIN, JD WOULD NOT RELEASE, WHILE WORKING TOOLS, MOVED SLIP STOP UP HOLE, POOH TO RE- DRESS. 16:20 OOH W/TOOLS, NO SLIP STOP, JDC SHEARED. 3RD HAND HOT SHOT TO WLB FOR DIFFERENT 3" JDC, WSL NEEDS OURS FOR RIG JOB. STAND -BY. 17:50 C/O TO HEALY. INSPECT LOC,PJSM, READ OVER AWGRS 18:49 RIH W/2.78"CENT, 3 "JDS, SD @ 6226' SLM/ 6250' MD, SHEAR OF POOH 20:43 OOH W/TOOLS & NO SLIP STOP, 3 "JDS SHEARED, CHECK PINS ON ROLLER STEM CALL PE, STAND BY AND WAIT FOR PE TO GET ON LOC 22:45 PE ON LOC, 22:51 RIH W /2.78 "CENT, 3 "JDS, COLLAR LOCATOR, SD @ 6226'SLM/6250'MD 23:58 WAS ABLE TO LOCATE THREE COLLARS, 6204' SLM/6228' MD, 6197'SLM/6221'MD, 6187' SLM/6211' MD, UNABLE TO LOCATE ANY MORE, POOH 23:59 CONTINUE ON 6 -20 -11 WELL SERVICE REPORT LDL WELL DATE JOB SCOPE DAY SUPV MPI -09 6/18/2011 WATERFLOOD REGULATOR PERL AFE Code DAILY WORK NIGHT SUPV AMSIPDWL09 DRIFT TUBING ;, MAX DETEOTION LOG COYNE MIN ID DEPTH TTL SIZE KEY PERSON UNIT 2.75 " 6336 FT 2.992 " SWCP -HEALY SWCP #09 DAILY SUMMARY ** *WELL S/I ON ARRIVAL *** (LDL, patch) DRIFT W/2.60" CENT, 3' x 1 -7/8" STEM, 2.78" CENT, 2.5" LIB. TAG PRONG @ 6,305' SLM (6,336' MD). RAN 2.78" CENT, KJ, SLB LDL MEMORY TOOLS, GOOD DATA ** *CONTINUE ON 6- 19 -11*** LOG ENTRIES Init Tbg, IA, OA -> I 300 I 0 TIME COMMENT 07:01 TRAVEL FROM MP' Y' TO LOC. TS= 10' x 1 -7/8" r.stem (2.6" wls), KJ, 5' x 1 -7/8" r.stem_(2.6" wls), OJ, KJ, LSS. 07:20 SPOT UP EQUIP, PJSM, INSPECT LOC, REV AWGR'S & JSA, START RIG UP EQUIP, FUNCTION BOP'S, STROKE SSV. _ _ 08:50 SWAB NOT _ HOLDING, CALL GREASE CREW. v 09:30 GREASE CREW OFF LOC, GREASED SWAB & SSV. HOLDING, POP CAP. 10:20 PT LUBE 30002500H. RIH W/2.60" CENT, 3' x 1 -7/8" STEM, 2.78" CENT, XO, 2.5" LIB. TAG PRONG @ 6,305' SLM, 411 • PO TO 6,275' SLM, FLAG WIRE, POOH. OOH W /LIB, CLEAN IMP OF PRONG. TAKE OFF OJ's, AND 5' x 1- 7/8" r.stem. 12:25 SLB MEMORY ON LOC, PJSM W /CREW. START RE- PROGRAM TOOLS. 13:40 TOOLS PROGRAMMED, WSL ON WAY TO LOC. 14:00 WSL LEADER ON LOC, PJSM W /ALL CREWS (slb s/I & slb memory, LRS WSL). 14:40 PUT TOGETHER TOOLS, FOUND DING IN WIRE, LAY DOWN PULL WIRE, TOOLS HAVE TO BE RE- PROGRAMMED. 15:15 TOOLS RE- PROGRAMMED, PUT TOGETHER TOOLS, STANDBY 15 MIN FOR TOOLS TO TURN ON. 15:45 PUT 500 W /DIESEL ON LUBE, LRS RIG UP TO P &S. 16:10 RIH W/2.78" CENT, XO, KJ, SLB MEMORY TOOLS (17' long). 17:10 STOP @ 5,700' SLM. 17:12 RIH @ 80 FPM TO 6,275' SLM. 17:21 LRS ON -LINE. PUMPED 5 BBLS 1 @ BPM, 1550 PSI. 17:32 5 MIN STOP @ 6,275' SLM. 17:37 PUH @ 150' FPM. 17:38 STOP @ 6,175' SLM FOR 5 MIN. 17:43 RIH TO 6,275' SLM. TOOLS GOT SUCKED INTO HOLE IN TBG @ 6,220' SLM. DOWN ON PUMP, TOOLS CAME FREE, PUMP BACK ON -LINE, CONT RIH. 17:47 STOP @ 6,275' SLM FOR 1 MIN. 17:48 PUH TO 5,700' SLM @ 80 FPM. 17:56 STOP @ 5,700' SLM FOR 1 MIN. 17:57 RIH TO 6,275' SLM. TOOLS GOT TO 6,219' SLM, SD, SHUT DOWN PUMP, TOOLS RELEASED, RIH, PUMP BACK ON -LINE. 18:05 STOP @ 6,275' SLM FOR 1 MIN. 18:06 PUH @ 40' FPM. 18:12 C/O W /HEALY, STOP @ 6067' SLM FOR 5 MIN, POOH 19:12 S/I BLEED OFF, LRS R /D, OOH W/TOOLS, STAB LUB BACK ON TREE, STAND BY FOR DATA 21:02 PERFORMED A MAN DOWN DRILL 23:31 RIH W/2.78" CENT, 2 -1/2" JDC 23:59 CONTINUE ON 6 -19 -11 Final Tbg, IA, OA -> I ] j WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV MPI -09 5/30/2011 WATERFLOOD REGULATOR PERL AFE Code DAILY WORK NIGHT SUPV AMSIPDWL09 MIT -T COYNE MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0 " 0 FT 0 " LRS - GARRELS JUSTIN LRS 64 DAILY SUMMARY _ _ _ __ T /I /O =850/0 Temp= S /I. Assist SSL. MIT -T FAILED to 2000psi. Pumped a total of 7.2 bbls ambient Diesel down Tubing in attempt to pressure up tubing. Captured LLR of 1.6 BPM @ 2000psi for 5 bbls. FWHP's= 900/0. SSL still on well at time of departure. LOG ENTRIES Init -> 850 0 _ TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 02:00 Start ticket, road to B -pad, load Diesel 02:37 Finish loading, road to location 03:07 Arrive on location, spot in unit, PJSM, MIRU to treecap 03:51 PT lines low= 410 psi, high= 2710 psi 04:30 1 st diesel amb 850 0 Start into well w/ diesel 04:38 1.6 7.2 " " 2000 0 SD, maintained 1.6 BPM LLR for 5 bbls, call WSL 04:40 Bleed Tbg pressure down 04:51 SD Tbg pressure bleed, RDM O 05:59 End ticket Final -> 900 0 JOB COSTS Tree. 1/8' - 5,1 WpIthipad; 11" 5141 FMC Gen. 6 Pit 1-09 0119. DF eiev = 62.25' (Doyon 141) x 8.5' FMC Tbg, Hng., 8.5' I I Orig. GL. elev.= WS' tiSCT top Z.' bo1cii 1 C g5/8° cog. hng. = 21.55' c.sonnection Moved back to 8 1/2" 8 d.. a. CM "H BPV prof 'e 20" 91.1 ppf H I I I HES X 2 913' Min, id I 2004' KiDP 430 Max ho e angle = 67 deg 01Y3C - PFTD 60 deg. to 68 dej. Hcle angle tfroixgh per = 68 dec 3 1,2 X 1 12*MMG %I I 2:127 9 , 40 ppf. L-80, Etrc e, drift ID = c = 3.0758 Opt I 3 1/2' 9.3 ppf, L-80, 8 rd. EUE tbg t drD=2867',cap.=OOO27bpt *Jibing reatnction = 1_62' DD Padfrooff 6287 MD I I HES X-kiipole 2 813' Ws. C 5774 I 9 51* X 3 1,2•44Ez PtL Pkr ':31•, 3P1.' e.” as of T.22;11 CV — 3 1 2' X 1 1 MMG .T.PM I 5823 l",ar as: 2630 osi D. Car as: 267 pa Clarts: 24;4 psi &C 3 1..2' X 11.2' IMMG 5.1,1311 j 5914 3 D&3 High Fla% Pastor Acton Mole all 6210' MD 9 5.6' X 31.2' HES DHL Pkr Top element X. 6235 MD Bottom element at 6244 ' MD Del 07-20-11 :See Well ¶ Tor :rawIng X1117 MM.; 51'si G150 Perforation Summon' t!eIWU. U5IT .3 12' 1 1,2' MMG SPV 111=110_ i SZi SPF Irimrtta I ITVD I 111.1.MM g tdr X 3 1,2" 'PHL Pkr 5309i I 110111.1 a PetU -Pe 'u 14 idipria 9 1'44 n i , 633:3 , g• 2 ron Wt•fr 3822 8&31 - • 2 a :./92' •A4' :144 WI Fr' 1. GA 3endf, J "vdP '!!! U. j • - 11 bbl: of owls Li bertreirl below DE card& 2 - 1 'r I 6360 9 5.43' foal collar rPBTDI I 6476' I 9 53' caping :hoe I 6:560' I WGI plugged hate balance dug act tee rot 11930" crg. ttl 4 13,Cia." DATE PE*/ DOM/VETTI; MILNE POINT UNIT 7.+ Cctu, urt we_ WELL 1-09 C%3]1 0t'1 M. Lnder Canve• to oroducer API NO: 50-029-22964-00 7.2/02 Lee Hulrile Convercion to In sector • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 ~~ Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 PONE° 201 � � - ° 3 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission lIAf I - 333 West 7 Avenue r ' Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI -02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI-04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI -08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 'r' MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 1019/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 STATE OF ALASKA ALASKA gIPAND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS TTti 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other El SET P ACKOFF Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ID Exploratory ❑ 200 -1030 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 " 50- 029 - 22964 -00 -00 8. Property Designation (Lease Number) : ,. 9. Well Name and Number: ADLO- 025517 . MPI -09 10. Field /Pool(s): „ MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 13094 feet Plugs (measured) 6470 feet true vertical 7196.92 feet Junk (measured) None feet Effective Depth measured 12600 feet Packer (measured) 5795 6098 6309 feet true vertical 6745.53 feet (true vertical) 3783 3911 3993 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 20" 91.1# H -40 28 - 138 28 - 138 Surface 9 -5/8" 40# L -80 27 - 6562 27 - 4087 5750 3090 Intermediate {, c l Production t:Ot ,.;f A U 1c Liner Liner Perforation depth: Measured depth: SEE ATTACHED - - True Vertical depth: _ - Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 26 - 6349 26 - 4008 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" HES PHL PKR N. 5795 " 3783 3 -1/2" HES PHL PKR 6098 3911 3 -1/2" HES PHL PKR 6309 3993 RECEIVE/4Z° 12. Stimulation or cement squeeze summary: AUG 16 2011 Intervals treated (measured): Okla descriptions including volumes used and final pressure: V1i & Gas C "ry"h$si An i 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 1781 1131 Subsequent to operation: 1090 1240 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service I] Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ in 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: 311 -197 Contact Joe Lastufka Printed N- _ Last g lik, I Title Petrotechnical Data Technologist Signat - alligit ‘ 1 .... . Phone 564 -4091 Date 8/15/2011 . Nill ‹t 8174( Form 10 -404 Revised 10 /2010RBDMS AUG 17 2011 08, Submit Original Only / MPI -09 200 -103 . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI -09 9/20/00 PER 6,360. 6,380. 4,012.01 4,019.41 MPI -09 11/15/00 APF 6,180. 6,200. 3,944.49 3,952.23 MPI -09 11/15/00 APF 6,230. 6,250. 3,963.58 3,971.02 MPI -09 3/10/01 APF 6,380. 6,400. 4,019.41 4,026.77 MPI -09 3/10/01 APF 6,350. 6,360. 4,008.3 4,012.01 MPI -09 3/10/01 APF 6,200. 6,230. 3,952.23 3,963.58 MPI -09 3/10/01 APF 5,932. 5,942. 3,840.51 3,844.75 MPI -09 3/10/01 APF 5,890. 5,910. 3,822.81 3,831.22 MPI -09 3/10/01 APF 5,860. 5,870. 3,810.27 3,814.44 MPI -09 7/20/01 FIL 5,904. 6,250. 3,828.69 3,971.02 MPI -09 11/26/01 FCO 5,904. 6,463. 3,828.69 4,049.88 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • . MPI -09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/19/2011;" ** WELL S/I ON ARRIVAL * ** (set tbg patch) R/U SLICKLINE EQUIPMENT. 'PERFORMED WEEKLY WLV TEST, WITNESSED BY ONEAL COYNE. * ** CONTINUE ON 7 -20 -11 * ** E I € I I 7/20/2011 "T /I /0 =300/0 Assist S -Line (Set Patch) Pumped 39 bbls diesel down Tbg to assist S- ;Line RIH. FWHP= 1200/0 Casing valves open to gauges, S -Line on location upon departure � 1 7/20/2011, * ** CONTINUED FROM 7 -20 -11 * ** (set tbg patch) I RAN 2.62" CENT, 3' X 1.875" STEM, 2.79" CENT & 2.75" LIB. S/D @ 6224' SLM. =RECOVERED F.N IMPRESSION. LRS ASSISTED WHILE RUNNING PATCH. SET 3.5" TBG PATCH (oal- 164 ") 6224' SLM. RIH W/ 3.5" A -1 SLIP STOP. * ** CONTINUE ON 7 -21 -11 * ** 7/21/2011 temp= SI Assist Slickline with injectivity test to verify tubing patch successful. Pumped 6.5 bbls diesel down tubing to verify tubing patch reduced injection rate. * *S /L in control of wellhead on departure ** FWHP's= 1000/0 ' 3 } 3 • • FLUIDS PUMPED BBLS 45.5 DIESEL 45.5 TOTAL • • Tree: 3 1/8" - 5M Wellhead: 11" 5M FMC Gen. 6 MPU I -09 Orig. DF elev. = 62.25' (Doyon 141) w /10" x 3.5" FMC Tbg. Hng., 3.5" Orig. GL. elev.= 34.5' NSCT top & bottom RT to 95/8" csg. hng. = 21.55' connection crossed back to 3 1/2" 8 rd., 3" CIW "H" BPV profile 20" 91.1 ppf, H -40 113' I _ ----- . I HES X- Nipple 2.813" Min. id 2084' KOP @ 400' Max. hole angle = 67 deg. 3000'- PBTD 60 deg. to 68 deg. Hole angle through perfs = 68 deg. / 110 r 31/2' X 1 1/2" MMG SPM 2127' 9 -5/8' , 40 ppf, L -80, Btrc. ( drift ID = 8.835 ", cap. = 0.0758 bpf ) 3 1/2" 9.3 ppf, L -80, 8 rd. EUE tbg. ( drift ID = 2.867 ", cap. = 0.0087 bpf ) Minimum tubing restriction = 1.62" D &D Packoff @ 6232' MD 1___J HES X- Nipple 2.813" Min. id 5774' 9 5/8" X 3 1/2" HES 'PHL' Pkr 5795' Valves in SPM / XN: Arrangement as of 7/22/11 'DV l i • Max DSi from SBHPS 5 /31/10 to 6/16/10: — — 3 1/2' X 1 1/2 MMG SPM 5823' N Sands: 2630 psi OA Sands: 2697 psi R WF i OB Sands: 2494 psi 600 - -- 3 1/2` X 1 1/2" MMG SPM 5914' — - ..... e 3 -1/2" D &D High Flow Packoff li Acrossed hole at 6240' MD 9 5/8" X 3 1/2" HES 'PHL' Pkr 6098' Top element at 6235' MD Bottom element at 6248' MD I RWF 07 -20 -11 500 1 See Well file for drawing 3 12'X11/2'IutlO S PM 51 E Perforation Suu'vT ry ° -DV — RAF Iort: U91T $/12,00 ,• I 3 1/2' X 1 1/2 MMG SPM 6217' Si :e SP Irrten'al (T' /Dj loollolloolmolm 95/8" X 3 1/2" HES `PHL' Pkr 6309' 11- oando 2 -t ra" 4 9g30L8g70' 3g1 -3g1b' Fgx7 HES XN- Idipple27F'Min.id I 6336' 2 -1 f8' 4 Sale- 8310' 323.E - 3331' w /a -,s rong 2 -Ira' 4 5832' -9342' 3a43.-3g45' 1 r 31/2" ALEG I 634.9' Ge. outdo 2 ra 4 01gI1 - 6290" 3944 - 3971' Baker nradel k Cenr.nt retainer 0 84713' "l b Bbls ot class i cemeritbeIow. OB sands 2 -1 /8" 4 6350' -6400' 4008' -4026' , , 9 5/8" float collar (PBTD) 1 6476' 9 5/8" casing shoe 6560' Well plugged back balance plug est. top @ 12,600' / org. td @ 13,094' DATE REV. BY COMMENTS MILNE POINT UNIT 8/21/00 MDO Drilled and Completed Doyon 141 WELL I - 09 11/15/00 MDO Initial Perforations OA 03/10/01 M. Linder Convert to producer API NO: 50 - 029 - 22964 - 7/3/02 Lee Hulme Conversion to Injector BP EXPLORATION (AK) 13 -JUL -2011 '2.222..6) $caMerger No. 5764 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD W -223 BCRJ -00086 ISOLATION SCANNER 18- May -11 1 1 W -221 BJGT -00040 USIT 16-Jun-11 1 1 C - 11A BLPO -00111 PPROF W GHOST 14-Jun-11 1 1 H -19B BLPO -00109 MEMORY PPROF W GHOST 12-Jun-11 1 1 V -227 BCRJ -00090 SCMT 19- Jun -11 1 1 X -22A AWJI -00143 USIT 18-Jun-11 1 1 ill 7./........"> MPI -09 14 -36 J -27A BCRC -00067 MEMORY LEAK DETECTION LOG 18-Jun-11 -11 1 1 BCRJ -00091 IPROF 21 - Jun - 1 1 BAUJ -00090 PPROF W GHOST 20-Jun-11 1 1 D -06A BL65 -00041 PPROF W DEFT GHOST 24-Jun-11 1 1 16 -05A BSM4 -00008 LEAK DETECTION LOG 27-Jun-11 1 1 Z -27 BSM4 -00009 GAS LIFT SURVEY 2-Jul-11 1 1 09 -22 BJGT -00048 IPROF 4-Jul-11 1 1 W -08A BBSK -00076 SCMT 25-Jun-11 1 1 Y -04 AWJI -00147 PPROF W DEFT GHOST 22-Jun-11 1 1 R•28 BJGT -00047 SBHPS 3- Jul -11 1 1 U -11B BG4H -00058 PPROF 16-Jun-11 1 1 Z -31 BCRJ -00093 SCMT 10-Jul-11 1 1 , F-48 BG4H -00062 PPROF W DEFT GHOST 9-Jul-11 1 1 06 -11 BSM4 -00012 PPROF W DEFT GHOST 4-Jul-11 1 1 , C -32C BLPO -00117 PPROF W GHOST 5-Jul-11 1 1 01 -31 BP5G -00001 RST EDIT 17-Mar-11 1 1 N -17 BJOH -00007 PDC -GR EDIT 9- Feb -11 1 C -12B BAUJ -00064 MCNL EDIT 9- Mar -11 1 1 C -22A BL65 -00022 MCNL EDIT 7- Mar -11 1 1 14 -33A BL65 -00023 MCNL EDIT 6- Apr -11 1 1 S -129 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 S- 129PB1 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 S- 129PB2 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 - 2525 Gambell Street, Suite 400 ' - „ '” « 'e" .• 900 E. Benson Blvd. Anchorage, AK 99503 -2838 SCANNED FEB 2 2 2013 • • 'd ATI [E [F ALAS SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez Petroleum Engineer BP Exploration (Alaska), Inc. cl o 1 o3 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Pool, MPI -09 Sundry Number: 311 -197 Dear Mr. Lopez: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, 4 <c)* Daniel T. Seamount, Jr. Chair DATED this C day of June, 2011. Encl. STATE OF ALASKA 1,1\RECEIVEtPD -L —// ALASKA. AND GAS CONSERVATION COMMISSIO APPLICATION FOR SUNDRY APPROVALS ",�,.�t IN 0 2 01i 20 AAC 25.280 V 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ y e P ��► �i��t;1 ��'� g ��i`0$ ro ion Suspend ❑ Plug Perforations ❑ PerforateD Pull Tubing ❑ Time Extension Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El F Alter Casing ❑ Other: SET PACK F r 9(j ® - El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 200 -1030 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ig - 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22964 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ MPI -09 - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 025517 - MILNE POINT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13094 - 7196.92 • 12600 6745.53 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 91.1# H-40 28 138 28 138 Surface 6535' 9 -5/8" 40# L -80 27 6562 27 4087 5750 3090 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3 -1/2" 9.3# L -80 26 6349 Packers and SSSV Tvoe: 3 -1/2" HES PHL PKR Packers and SSSV MD and TVD (ft): 5795 3783 3 -1/2" HES PHL PKR 6098 3911 3 -1/2" HES PHL PKR 6309 3993 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/15/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ a' GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and corre to the best of my knowledge. Contact Keith Lopez Printed Name Keith Lopez Title PE Signature Z..O:14 Phone Date 564 -5718 6/1/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1 - tell Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: ( d —'O L( APPROVED BY Approved by w COMMISSIONER THE COMMISSION Date: / / ( � � B UMS JuN 0 9 201 " ' , ��, Form 10 -403 Revised 1/2010 �' ORIGINAL Submit in Duplicate MPI-09 200 -103 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI-09 9/20/00 PER 6,360. 6,380. 4,012.01 4,019.41 MPI-09 11/15/00 APF 6,180. 6,200. 3,944.49 3,952.23 MPI -09 11/15/00 APF 6,230. 6,250. 3,963.58 3,971.02 MPI -09 3/10/01 APF 6,380. 6,400. 4,019.41 4,026.77 MPI -09 3/10/01 APF 6,350. 6,360. 4,008.3 4,012.01 MPI -09 3/10/01 APF 6,200. 6,230. 3,952.23 3,963.58 MPI -09 3/10/01 APF 5,932. 5,942. 3,840.51 3,844.75 MPI-09 3/10/01 APF 5,890. 5,910. 3,822.81 3,831.22 MPI -09 3/10/01 APF 5,860. 5,870. 3,810.27 3,814.44 MPI -09 7/20/01 FIL 5,904. 6,250. 3,828.69 3,971.02 MPI -09 11/26/01 FCO 5,904. 6,463. 3,828.69 4,049.88 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 110 bp 0 To: Mark O'Malley/Rob Handy Date: June 1, 2011 From: Keith Lopez Schrader Tract 14 Pad Eng Subject: MPI -09 Set Packoff Est. Cost: IOR: N/A AFE: AMSIPDWL09 Objective Set packoff to isolate leaking GLM Step Unit Operation 1 S Set packoff Background MPI -09 was converted to a regulated injector from a producer in 2002. This well has good injectivity but struggles with Schmoo build -up and other wellbore debris in the tubing. Entering this well at a minimum of yearly to change valves and conduct a general cleanup should help avoid poor injection conformance and extended cleanups. An IPROF was run on 4/15/11 while injecting 1750 bwpd, showing most of the water exiting the GLM @ 5823' with the rest of the fluid exiting at the GLM @ 5914'. Both of these GLM are in the N sand. The upper mandrel should have a dummy installed and the lower has a WFRV. There are two more WFRV's installed below these depths that could take water but the N sand is dominating and exiting the tubing where it should not be. On May 22, 2011, all the WFRV's were changed out and the suspected leaking dummy in the GLM @ 5914' was changed out. Upon putting on injection the pressure was increased to ensure the WFRV's were functioning and the rate jumped to 3000 bwpd when the valves had a total rating of 1700 bwpd,_ The well was then re- entered and all the GLM's were dummied. A D &D holefinder was then run and found the GLM @ 6217' leaking and the tubing holding pressure above this mandrel. The plan forward is to change out the XN plug body and WFRV, set the packoff, and set the remaining WFRV's. A P -15 XJR is requested for the bottom valve in the XN nipple due to the history of fill in the tubing potentially due to crossflow. • • General Procedure: Slickline: 1. MIRU SL unit. 2. Run leak detect log. 3. RIH & pull RMX prong with dummy and plug body if necessary. Replace plug body and set RMX prong with P -15 XJR WFRV rated for 670 bw�d ----=r !L- s4 4. RIH and set packoff across MMG @ 6217'. 5. RIH & pull dummy in MMG @ 6158' and set WFRV rated for 504 bwpd at same depth. .— m ° s'4 JD 6. RIH & pull dummy in MMG @ 5914' and set WFRV rated for 605 bwpd at same depth. -'*' To Y' SAN' 7. Conduct injectivity tests as follows: a. Inject for 30 minutes at 1000 psig b. Inject for 30 minutes at 1200 psig c. Inject for 30 minutes at 1400 psig d. Inject for 30 minutes at 1600 psig 8. RDMO SL Operations 9. Bring well on injection with new targets of 1800 bwpd with max injection pressure of 1200 Egg. Contact Keith Lopez: 564 -5718 or 903 -5432 (cell) with any questions or comments. cc: Anchorage MPI -09 well file • Tree; 31,x' - 5M M P U 1-09 1 Trig. DF elev. Wellhead:11" 5M RAC Gen. elev. = 62.25' {{Doywrl 81 H110' x 3.5' FMG Tbg Hr1g., as" Orig. GL. e!e'r 34.5' NSCT to 8 bottom FIT to 95113' cg. hng. = 21.55' ccnn+ection a occed back to 3 117' 8 rd., 3' CIW "H' BPV profile 20" 91.1 pp €, H40 1 113 I I HEE X- Flipple 2 813' Min. id I 2084' KOP r?i' 400 Max. hole angle = 67 deg. 3300'- PBTD 60 deg. to 68 deg.. Hole angle through pert; = 68 deg. 3 1 7 X 1 1 MMG C DM I 2 9-57'8 , 40 pp', L -80, Btrc. ( drift ID = 8.835', cap. = 0.0758 bpf 3 1.2' 9.3 ppf, L -80, 8 rd. EUE tbg. {dritID= 2.86:+', cap. = 0.0087bpf'I Minimum tktir g restriction = 2.750" 'XN' No-Go ID 't 6836' HES X -Ne 2.813' Min. id �— ^ X 3 112 HES 'PHL' Ptr I 5 •ies In SPY t XN: Anargenerl as of 5i311' 1 C p 1a t: � w i ficm +HP t I i � to 5 +15!s p 3 12 X I lir MMG SPb+ I 58' N Sands: 2634 psi OA Sands: 2657 as R'A'F 0+3 Sands: 2154 pia 6 , 31,7X1117 WAG SPIV 591 -' 500 9 5P8' X 3112' HES'PHL' PRr I 60®6• h SET 611&113 310X1 WAG 51'M I G Perforation Summitry r RYE I+ay UgIT Bll2(00 ' 3 172' X 1 1.17 MMG SPM I 6217` I / ✓ ` 1 e' ) S2d 1 1t1I4'tXli I IVUI 3 Sir X 3 ll2' HES 'PHL' Pis I ?,_lg Nv�u 11V 1 MI IIPA1 1111il Mifl:U :9 POWER HlrA xri' ruitidW } 1.'i r41 i1 id I U3d6 1a a Bbo'^as ro 68CC' 3081' ,s 6832' , ;842' 28,wa04 s 1r3 °`WLC0 I '304J OA Neva ._,. 4 aim .a95r 'MIA . 4trr1 . 17171. „erraCCel K Uarnen1 tT g+trL 1 tl bblt at CIE DI UL9 oerrleM below OE car.X ^1 'S' 4 33s0--3 O acaa'a¢De' 3 5;8' font collar (PBTD'' I 6476. 9 5'8' tadi oboe h ;: • 't'Vai pup,,aa Wok Paanoa Wm; act. tor? ';41 1,^.BO3'. OM :9 ' t 7 stew DATE r'w= '.'. OOMMeNt . MILNE POINT UNIT 9.1 03 VOX: 3■1r7.-, ,kncirbgrl Po ulnae 4400 a.-e. v+ WELL I - 09 03/10101 M. Linder Comer to producer API NO: 50 -029- 22964 -00 7'3402 Lee Hulne van^aeroion to Injector BP EXPLORATION (AK) • • TUBING SUMMARY j }� RK NABORS 4ES Date 7/22002 I BPr WELL# UPI-09 TUBMG 3.5" L-80 8110 EUE MOO TBG WT. 9.3 220 JTS ON RACK 194 JTS RAN OKB TO BF 6861.78 FT ON RACK FT RAN ITEM Description includes. SIZE, TYPE, CONNECTION (JTS 14) ITEM ID OD LENGTH TOP BOTTOM 3.5" WLEG 9CR 1.30 6347.58 6348.88 3.5" 9.21 L80 NSCT BXP 9.85 633773 6347.58 HES 3.5 " 'IN" NIPPLE 9CR 1.24 6336.49 6337.73 3,5" 9.31 L80 X -OVER ELE 9110 X B X NSCT 10.09 6326.40 6336.40 3.5" 9.20 1-808110 EUE PUP 10.03 6316.37 6326.40 HES 0 &'8" PHL 400 -471 RET. PKR 7.75 6308.62 6316.37 32"9.21 L90 8110 EUE PUP 10.00 6290.62 6308.62 2-JTS. 3.5" 9.21 L-80 8RD EUE TBG. 6273 6235.89 6298.62 3r 9.31 180 8111) ELE PUP 10.05 6225.84 623529 3.5" X 1.5 'MMG' WI DUMMY 6.44 6217.40 622524 3,5" 0.31 180 8111) EUE PUP 10.01 6207.39 6217.40 1,ITS. 3.5" 920 L-90 8RD EUE TBG. 31.37 6176.02 6207.39 3,5" 9.31 L80 8110 EUE PUP 10.00 6165.94 6176.02 3.5' X 1" "HMG' WI DUMMY 0.42 6157.52 6165.94 3.5" 9.31 L80 ORD EUE PUP 10.07 6147.45 6157.52 1 -JTS. 3.5' 921 - 00 ORD EUE TBG. 31.41 6116.04 6147.45 3.5" 9.31 L80 BRIO EUE PUP 10.00 6106.04 6116.04 HES 9-5'6" PHL 400 -471 RET. PKR 7.74 6098.30 6106.04 3r 9.31 180 8110 EUE PUP 10.00 6088.30 6099.30 5-JTS. 3.5" 9211 -90 910 EUE TBG. 155.31 593299 600920 3r 9.31 180 8110 EUE PUP 10.10 5922.89 593290 3.r X 1.5" "PANG' WI DUMMY 8.45 5914.44 592229 3r 9.31 L80 8110 EUE PUP 10.10 5904.34 5914.44 2-JTS. 3.5" 9211 -00 8RD EUE TBG. 62.77 5941.57 5904.34 3r 9.31 L80 ORD EUE PUP 10.10 5831.47 5841.51 3.5" X 1,5" "MPG WI DUMMY 8.45 5823.02 5831.41 3.5" 9.30 180 ORD EUE PUP 10.10 581292 5823.02 3r 9.31 180 9110 EUE PUP 10.01 500291 581292 HES 9-56" PHL 401 -471 RET. PKR 7.75 5795.16 580291 3.5" 9.31 L80 ORD EUE PUP 10.00 5785.16 5795.16 3.5" 921 L4i0 ORD EUE PUP 10.00 5775.16 5785.16 3.5" "X" PROFILE NPPLE 1.41 5773.75 5775.16 3r 9.31 L80 ORD EUE PUP 10.00 5763.75 5773.75 116- JTS.3.5' 9.31180 8110 EUE 3616.36 2145.39 5763.75 3r 9.31' L80 ORD EUE PUP 10.06 2135.33 2145.39 3.5" X 1.5' WAG WI RP SHEAR VALVE 8.41 2126.92 2135.33 3r 9.31 L80 ORD EUE PUP 10.01 2116.91 2126.92 1 -JTS. 3.5" 9.21 L-80 9110 EUE TBG. 31.33 2085.58 2116.91 3.5" -I" PROFILE NPPLE 1.41 2084.17 2085.58 66- ITS. 3 5" 9.21E L -80 0110 EUE TBG. 2050.35 24,82 2084.17 3.5" 9.31180 ORD EUE PUP 2.52 22.30 24.82 HANGER .75 21.55 22.30 RT -TS 21.55 . 21.55 • i WELL LOG TRANSMITTAL PROACTIVE DINCINOSUIC SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 900 Benson Blvd. u d A Oo r /63 e9091 Anchorage, Alaska 99508 - UTO Q6 - ?SI 0 696-5-- and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road *AM- MAY 2, i 2 01' Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Injection Profile 15-Apr-11 MPU I -09 BL / EDE 50-029 - 22964-0 • 2) Injection Profile 16-Apr-11 MPU I -16 BL / EDE r'`'- - $b-c 3 21 -00 Signed : Date : 1 Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL: sam: �s "2tlrnd3leiTAoraocl.u+.31;, WEBSITE: lTWW,sy.emoriloq,mom C:\Documenls and Settings\Diane Williams \ Desktop \BP_Trensmitdam( • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 13, 2011 TO: Jim Regg +HI 11 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC I -09 FROM: Chuck Scheve MILNE PT UNIT SB I -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB I -09 API Well Number: 50- 029 - 22964 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS110410160756 Permit Number: 200 -103 -0 Inspection Date: 4/9/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1-09 Type Inj. W, TVD 3783 IA 420 2000 1950 1950 ' P.T.DI 2001030' TypeTest ; SPT I Test psi ; 1500 OA Interval 4YRTST P/F P - Tubing 1100 1100 1100 1100 Notes: Well is a single casing string design. Wednesday, April 13, 2011 Page 1 of 1 . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg kc?f~' 4/4; ¡o1 P.I. Supervisor ( 1 /' DATE: Monday, April 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-09 MILNE PT UNIT SB 1-09 Src: Inspector \O? ~OO; FROM: Lou Grimaldi Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv, 'Œ(2A'/ Z-6lð 7 Comm Well Name: MILNE PT UNIT SB 1-09 API Well Number: 50-029-22964-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG070420052638 Permit Number: 200- I 03-0 Inspection Date: 4/19/2007 Rei Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1-09 Type Inj. w TVD 3993 I IA 500 1590 I 1550 1550 P.T.D 2001030 TypeTest SPT Test psi 1500 lOA I Interval REQVAR P/F P V Tubing 1650 1650 I 1650 1650 I Notes: Monobore injector. Pretest conditions observed for thirty minutes to satisfy 500 psi DP req. ~ scANNED APR 3 0 2007 Monday, April 23, 2007 Page I of 1 WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowtedge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 1 BL / EDE Disk 2J 3) 4) 5) 6) 7) Signed : (Ljj~ MPU I - 091 Injection Profile 08-Dec-06 U ..LC- 8óo -I 03 ::ti: 1L...{3D"'3 ~JAN 0 82007 RE:CE. \\IE-O JA'N0 9 ?J}D7 Date: Print Name: ~ /h rkh 1/1 0 fYl Q íl VI k tI>{/1 PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAil: ,::c.C¿':''-'-;_~~.:-:' :;2,:;:::': '::'.', " " . ',H ,. WEBSITE: ".,....... ".:~':: ;~":'.: 3. ': :';:' .---- 0:\00 ~ PDSA...i'!C- 2006\Z _ W ord\Dîstnbution\ Transmittal_ Sheets\ TransmIt_Original. doc Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well . MPI-09 MPI-09.;zùQ - {~J__ ~-O~J.L~ INK-08A NK-08A 18-34 'G\S- -It, ¥ 04-05A iG3'" / 3 b~ 18-05A lç,).-1.tq 07 -36 t q 7 - t ~ 'I 14-36 /8 J .. I (,..3 C-13A I q 7 - I '-i J U -12 ¡ 8 S- - I ð...l.. R-21 J S ~ ~ I .1... ~ R-12 193-- o;~"'" E-16 laC - (l' :3 J-23 I 8 7... 9'> t F-31 I..~ ~ - 1';-7 H-35 I G S" .... J ~ q Job# 10563225 10980572 10772241 10560316 10703956 10564525 10703939 10563112 10866557 10564527 11075900 10674388 10687647 10564529 10663003 10703943 10563217 10563216 Log Description INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PSP GLS PPROF W/DEFT PSP LDL PRODUCTION PROFILE LEAK DETECTION LOG LEAK DETECTION LOG INJECTION PROFILE MEM PROD & INJECTION PROFILE LDL PRODUCTION PROFILE PSP PPROF W/GHOSTlDEFT PRODUCTION PROFILE SBHP SURVEY SBHP SURVEY PPROF W/GHOST PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ) I ;{ ÀV U- (¡j .... J L .-... v',-~ ) SCANNEC S E P t; Date 10/05/03 06/09105 04/04/04 10/22/03 11/27103 09/27/03 10/24/03 10/13/03 07/14/04 09/29/03 07/05/05 10/27/07 09/20/03 10/01/03 03/10/04 10/28/03 09/28/03 09/27/03 ü 2005 07/20/05 NO. 3438 d 00· ---IQð- Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD -- -- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth F1 'I J \L Í ¡ ! ¡ r'\ f¡ Received by: i)fJl,¡"lVV't "- C) ~ '- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1~ Operations performed: Operation shutdown_ Stimulate _ P. lugging_ Perforate _ CONVERTED to H20 INJECTOR Pu, tubing_ Alter casing_ Repair well_ Other_X CONVERTED to H20 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2948' FNL, 3727' FEL, Sec. 33, T13N, R10E, UM At top of productive interval 42' FNL, 722' FEL, Sec. 32, T13N, R10E, UM At effective depth 4902' FNL, 1093' FEL, Sec. 29, T13N, R10E, UM At total depth 716' FNL, 4825' FEL, Sec. 29, T13N, R10E, UM 5. Type of Well: Development __ Explorato~___ Stratigraphic_ Service__X (asp's 551644, 6009447) (asp's 549342, 6012338) (asp's 548966, 6012754) X (asp's 545195, 6016916) 6. Datum elevation (DF or KB feet) RKB 62 feet 7. Unit or Property name Miline Point Unit MPI-09 9. Permit number / approval number 200-103 / 302-197 10. APl number 50-029,22964-00 11. Field / Pool Miline Point Unit / Schrader Bluff Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Production 6534' 13094 feet Plugs (measured) 7197 feet 6470 feet Junk (meaSured) 4052 feet BKR Model K Cementer Retainer @ 6470'. 16 BBLS Class 'G' cement below retainer. Size Cemented Measured Depth True Vertical Depth 20" 260 sx ArcticSet I (Aprox) 138' 138' 9-5/8" 840 sx ArcticSet Lite, 6562' 4087' 385 sx Class 'G' Perforation depth: measured Open Perfs 5860'-5870', 5890'-5910', 5932'-5942', 6180'-6250', 6350'-6400' true vertical Open Perfs 3810'-3815', 3823'-3831', 3840'-3845', 3944'-3971'j~0L~0~,61V E D Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 TBG @ 6349'. 3 2003 Packers & SSSV (type & measured depth) 9-5/8" x 3-1/2" HES 'PHL' PKR's @ 5795', 6098' & 6309'. HES X-Nipple @ 2084'. Alaska 0JJ & Gas C0tlS. Cnmmissjo~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Anchorage 14. Prior to well operation SHUT-IN Subsequent to operation 08/11/2002 Representative Daily Avera_qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1417 Tubing Pressure 1692 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil _ Gas _ Suspended _ Service WATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~'~~~~~ Ti tie: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · BBMS BFL Date January 21, 2003 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE F:\LaserFiche\CvrPgs _I nserts\M icroft 1 m _Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE '<f"'"(I'''' ..pI' -':"~~......... .1.....: ) 07/21/2002 07/22/2002 O7/3O/2OO2 O8/O 1/2OO2 08/02/2002 08/02/2002 10/31/2002 11/18/2002 11/20/2002 01/20/2003 07/21/O2 07/22/02 O7/O3/O2 08/01/02 08/02/02 08/02/O2 MPI-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SET WATERFLOOD REGULATOR IN 'OA' SANDS SBHP SURVEY SET WATER FLOOD VALVE. SBHP SURVEY STEP PATE/PULL PLUG FIRST WATER INJECTION FREEZE PROTECT WELL/TTE IN WORK SLZCKLINE/DRIFT FOR IPROF SLICKLINE/]:PROF TESTEVENT --- INJ PRESS, PSI: 1,649 TYPE: PW VOLUME: 1,916 BWPD EVENT SUMMARY SET XXN PLUG. PULLED LOWRE DGLV IN 'OA' SANDS. PERFORMED PRESSURE SURVEY. WELLIS NOT STATIC. RETURN IN A.M. FOR SBHP SURVEY. PERFORMED SBHP SURVEY ON 'OA' SANDS. STILL LOSING PRESSURE ON LAST STATIC LAST READING --- 1630 PSI @ 66 DEG. SET WATERFLOOD REGULATOR. TESTED REGULATOR. VALVE WORKED AS DESIGNED EXCEPT CONTROLLED RATE WAS TO LOW. PULLED WATERFLOOD REGULATOR BACK OUT TO VERIFY PORT SIZE. VALVE WAS AS TAGGED. PUMPED TOTAL OF 7 BBLS OF WATER. WELL WAS FREEZED PROTECTED WITH DIESEL ON THE RIG. DID NOT LOOSE THE FREEZE PROTECTION. SET 1.5" (0.314 PORT) WATER FLOOD REGULATOR VALVE @ 6207' SLM. ESTIMATED RATE 1058 BPD. OBTAINED SBHP @ 6300' SLM ON THE 'OA' SANDS, LAYED DOWN EQUIPMENT FOR THE EVENING. SBHP 1569 PSI @ 78 DEGREES @ 3990' TVD. NOTE: THE PRESSURE DROPPED FROM 1571 PSI TO 1569 PSI IN ONE HOUR. HBR VERIFIED INJECTION RATE OF 0.67 BPM @ 1700 PSI. PULLED PLUG. INJECTED DOWN TUBING WITH SOURCE THROUGH WATER FLOOD VALVE. STARTED PUMPING AT 0.75 BPM @ 1350 PSI. AT 23 BBLS PUMPED PRESSURE CAME UP TO 1875 PSI AND CONTINUED TO CLIMB TO 3100 PSI. BACKED OFF ON RATE TO 0.54 BPM AND PRESSURE DROPPED TO 3000 PSI. SHUT DOWN PUMP AND LET THE PRESSURE ON WELL BLEED DOWN, STARTED UP AT 0.57 BPM AND MAINTAINED A PRESSURE OF 1650 PSI. INCREASED THE RATE TO 0.67 BPM AND PRESSURE STAYED AT 1700 PSI. AT 0.67 BPM - 975 BPD. FIRST WATER INJECTION. Page I 10/31/02 11/18/02 11/20/02 01/20/03 MPI-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FREEZE PROTECT WELL FOR SHUT-IN SO LATERAL LINE CAN BE REMOVED AND WELL 1-02 WATER LINE CAN BE TEED IN AT THE HEADER. TAGGED TD @ 6402' MD. LOCATED TUBING TAIL @ 6349' MD. RAN PDS INJECTION SURVEY. RKB MEASUREMENTS OBTAINED, USING 27' CORRECTION FROM DRIFT AND TAG ON 11/18/2002. TESTEVENT --- IN] PRESS, PSI: 1,649 TYPE: PW VOLUME: 1,916 BWPD FLUIDS PUMPED BBLS DISCRIPTION 21 METHANOL 21 TOTAL Page 2 Tree: 3 1/8" - 5M Wellhead: 11" 5M FMC Gen. 6 w/10" x 3.5" FMC Tbg. Hng., 3.5" NSCT top & bottom connection crossed back to 3 1/2" 8 rd., 3" CIW "H" BPV profile 20" 91.1 ppf, H-40 ~ KOP @ 400' Max. hole angle = 67 deg. 3000'- PBTD 60 deg. to 68 deg. Hole angle through perfs = 68 deg. 9-5/8', 40 ppf, L-80, Btrc. ( drift ID = 8.835", cap. = 0.0758 bpf ) 3 1/2" 9.3 ppf, L-80, 8 rd. EUE tbg. ( drift ID = 2.867", cap. = 0.0087 bpf ) Minimum tubing restriction = 2.750" 'XN' No-Go ID @ 6336' MPU 1-09 Orig. DF elev. = 62.25' (Doyon 141) Orig. GL. elev.= 34.5' RT to 95/8" csg. hng. = 21.55' HES X-Nipple 2.813" Min. id [ 2084' J HES X-Nipple 2.813" Min. id I 5774' 9 5/8" X 3 1/2' HES 'PHL' Pkr I 5795' J 3 1/2'X 1 1/2" MMG SPM I 5823' 3 1/2' X 1 1/2" MMG SPM 9 5/8" X 3 1/2" HES 'PHL' Pkr 5914' J [ ~0~' J P errora~i 011 SUI111tiiPII' Ref Ioa: U SIT R~12~00 ~iaaa,-aa?a, i ~iaaa'-aala, 6350'-6400' Interval (T:~D) 391~'- 3ala, 3g~_~.3a31, 4008'-4026' 3 1/2' X 1 1/2"M~lG S PM [ 61~8' J 3 1/2' X 1 1/2" MMG SPM I 6217' 9 5~8" X 3 1/2" HES 'PHL' Pkr I 6309' HE~×N-Nippl~2.TE'Min. id J Bd.e.r ~,~d~114 C~n,e. nt ~aner ~ ................... '~d TSb'ls o't dlass~ cemen't'D~low. 'J LO5/8"floatcollar(PBTD) [ 6476' 9 5/8" casing shoe I 6560' Well plugged back balance plug est. top @ 12,600' / org. td @ 13,094' DATE REV. BY COMMENTS &,'21/C~ MDO Drilled and Ccmplete<t Do~n !41 11/15/00 MDO Initial Perforations OA 03/10/01 M. Linder Convert to producer 7/3/02 Lee Hulme Conversion to Injector MILNE POINT UNIT WELL I - 09 APl NO: 50-029-22964-00 BP EXPLORATION (AK) Permit to Drill 2001030 MD 13094 -- TVD DATA SUBMITTAL COMPLIANCE REPORT 9/912002 Well Name/No. MILNE PT UNIT SB 1-09 Operator BP EXPLORATION (ALASKA) INC 7197. Completion Dat 9/2/2000 Completion Statu 1-OIL Current Status 1WINJ APl No. $0-029-22964-00-00 UIC Y REQUIRED INFORMATION Mud Log N__9o Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital TYP~edia Fmt ~. L L L k k Log LOg Run Name Scale Media No LIS Verification Interval Start Stop FINAL (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments 2/23/2001 c~ q= )- USIT 5 MD Res/GR . TVD Res/GR MD GR/Neu/Den TVD GR/Neu/Den 9905 2/5 2/5 2/5 2/5 FI NAL 100 6430 100 6430 58 13029 FI NAL 120 13094 FI NAL 120 13094 FI NAL 120 13094 FI NAL 120 13094 FINAL LIS Verification Paper Copy CH 9/8/2000 BL(C) 100-6430 Case 10/3/2000 09755 100-6430 ~-['~' 2/22/2001 09905 58-13029 CH 2/21/2001 120-13094 BL, Sepia CH 2/21/2001 120-13094 BL, Sepia CH 2/21/2001 120-13094 BL, Sepia CH 2/21/2001 120-13094 BL, Sepia 2/23/2001 9905 LIS Verification Digital Data Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y / Chips Received? Analysis -?'TN,, R ~.r.~.iv~.d ~ Daily History Received? ~/N Formation Tops ¢/N Comments: DATA SUBMITTAL COMPLIANCE REPORT 9/912002 Permit to Drill 2001030 Well Name/No. MILNE PT UNIT SB 1-09 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22964-00-00 MD 13094 TVD 7197 Compliance Reviewed By: Completion Dat 9/2/2000 Completion Statu 1-OIL Current Status 1WINJ UlC Y Date: 1. Operations performed: 'lr-I Operation Shut~10wn []'Stimulate' [] Plugging [] Perforate ' ' ' [] Pull Tubing [] Alter Casing [] Repair Well [] Other Convert to Injector 2. Name of"(~perator ......... 5. Type of well: 6. D~tum NiceSt'ion (DF '(~r KBi ....... BP Exploration (Alaska) Inc. [] Development KBE ~ 62~25 .. . ........... I-I Exploratory 7. uni:~ or 'Prol~e'rty 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 2331' NSL, 3725' WEL, SEC. 33, T13N, R10E, UM MPI-09i At top of productive interval 9. Permit Number / Approval No. 200-103 302; 197 3728' NSL, 4790' WEL, SEC. 33 T13N, R10E, UM 10. APl Number At effective depth 50-029-22964-00 4543' NSL, 4846' WEL, SEC. 29, T13N, R10E, UM !11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 4562' NSL, 4824' WEL, SEC. 29, T13N, R10E, UM , 12. Present well condition summary Total depth: measured 13094 feet Plugs (measured) true vertical 7197 feet Effective depth: measured 6470 feet Junk (measured) true vertical 4052 feet Casing Length Size Cemented MD TVD Structural Conductor 112' 20" 260 sx Arcticset (Approx.) 112' 112' Surface Intermediate 6534' 9-5/8" 840 sx Arcticset 3-Lite, 385 sx 'G' 6562' 4087' Production Liner Perforation depth: measured 5860' - 5870', 5890'- 5910', 5932' - 5942', 6180' - 6250', 6350' - 6400' true vertical 3810' - 3814', 3823' - 3831', 3841' - 3845', 3944' - 3971', 4008' - 4027' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, 8RD Eue Mod tubing to 6349'. Packers and SSSV (type and measured depth) HES 9-5/8" PHL, 40# - 47# Ret. Packers at 5795', 6098' and 6309'. HES 3-1/2" 'X' Nipple at 2084'. r't r r r 1% I ~ r~ 'i3' Stimulation or cement squeeze summary ~ ~. ~, ~. I ¥ [- L~ Intervals treated (measured) JUL 1 6 2002 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. G0mmtss~o~'~ ........................, . ,,,,, ,,, ................... ,,,,,,,, ...... An~.hnra~e 14. Representative Daily Averac]e Production or Injection Data Oil. 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 r"l Oil [] Gas [] Suspended Service Water Injection [] Daily Report of Well Operations 17.1 hereby cede go~d correct to the best of my knowledge ' ' - ~' .. Signed s~-/~~ Title Technical ASsistant Date ~.~ -- t ~- ~)~ Prepared By Name/Number: Sondra Stewrnan, 564-4750 'l~orm 10-404 Rev. 06/15/88 JUL I 8 21~bmit In buplicate . . O ions! s ummaryiRePo . Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: Event Name: WORKOVER Start: 612712002 End: 71312002 Contractor Name: NABORS DRILLING CO. Rig Release: 7~3~2002 Rig Name: NABORS 4 Rig Number: 4ES i: ~i :' ~°m;i~o ~u~ ~ ¢0~, i~ ~h~ :: i : i~s¢~i~ii~n6f ~P~ratibns 'i "ii 6/28/2002 16:00 - 00:00 8.00 MOB P PRE RIG DOWN OFF MPL-32 & MI/RU ON MPI-09 6/29/2002 00:00 - 01:00 1.00 MOB P PRE MI/RU 01:00 - 02:00 1.00 KILL P DECOMP RIG LINE TO TREE 02:00 - 03:00 1.00 KILL P DECOMP RIG LUB & PULL BPV 03:00 - 06:00 3.00 KILL P DECOMP CIRC INFLUX OUT OF WELL BORE 06:00- 07:00 1.00 WHSUR P DECOMP SET TWC 07:00 - 08:00 1.00 WHSUR P DECOMP NIPPLE DN TREE 08:00 - 10:00 2.00 BOPSUI; P DECOMP NIPPLE UP BOP 10:00 - 13:00 3.00 BOPSUI; P DECOMP TEST BOP TO 250/2500 PSI. (TEST WAIVED BY JEFF JONES WITH AOGC) 13:00 - 14:00 1.00 BOPSUF P DECOMP PULL TWC & BOLDS 14:00 - 18:30 4.50 PULL P DECOMP LAY DN HANGER & POOH LAYING DN TBG. 18:30 - 19:30 1.00 FISH P DECOMP CLEAR & CLEAN RIG FLOOR 19:30 - 22:00 2.50 FISH P DECOMP MU FTA # 1 BURNING SHOE+EXTENSIONS+BUMPER SUB+JARS+10-6-1/4' DC 22:00 - 00:00 2.00 FISH P DECOMP RIH WITH FTA # 1 ON 3.5" DP FROM SHED. 6/30/2002 00:00 - 02:00 2.00 FISH P DECOMP RIH WITH FTA # 1 02:00 - 09:00 7.00 FISH P DECOMP MILL OVER PKR. @5667 & PUSH TO 5675' 09:00 - 10:30 1.50 FISH P DECOMP CIRC GAS OUT OF WELL BORE. 10:30- 12:30 2.00 FISH P DECOMP POOH W/FTA#1 12:30 - 14:30 2.00 FISH P DECOMP LAY DN FTA #1 & MU FTA # 2 OVERSHOT & ETC. 14:30 - 17:00 2.50 FISH P DECOMP RIH WITH FTA # 2 & CHASE FISH TO 5744' & LATCH SAME 17:00 - 21:00 4.00 FISH P DECOMP POOH WITH FTA # 2& LATCHED FISH OVER PULL TO 40-50K AT TIMES. 21:00 - 22:00 1.00 FISH P DECOMP LAY DN FISH & FTA # 2 22:00 - 23:00 1.00 CLEAN P DECOMP MU CLN-OUT ASSY #3 BIT+ SPACED SCRAPER & JARS & DC'S 23:00 - 00:00 1.00 CLEAN P DECOMP RIH WITH CLN-OUT ASSY FTA # 3 7/1/2002 00:00 - 01:00 1.00 CLEAN P DECOMP RIH WITH CLN-OUT ASSY. #3 TAG SD @ 5752' 01:00 - 12:00 11.00 CLEAN P DECOMP REVERSE CIRC SAND OUT OF WELL BORE 5752' TO 6468' (NOTE:LAST 90' TO PBTD REQUIRED NO PUMP OR ROTATION TO MAKE FORWARD PROGRESS. 12:00 - 16:00 4.00 CLEAN P DECOMP REVERSE CIRC WELL BORE CLN AT 5-BPM & CHANGE OUT WELLBORE FLUIDS TO CLN-SEAWATER TREATED WITH CORROSION INHIBITOR. 16:00-21:00 5.00 CLEAN P DECOMP LAYDN3.5"DP&BHA(CLN-OUTASSY.#3) 21:00 - 00:00 3.00 CLEAN P DECOMP RIG HES & RIH WITH 8.51" GR/JB & TAG @ 6344' POOH REC. METAL & SAND. RUN # 2 2.50" BAILER & TAG @ 6344' POOH & REC. SAND. RIG DN HES WIRE LINE. 7/2/2002 00:00 - 02:00 2.00 CLEAN P COMP LOAD PIPE SHED WITH 3.5" DP FOR WELL BORE CLN-OUT RUN 02:00- 05:00 3.00 CLEAN N RREP COMP CHANGE OUT TRANSFORMER IN PIPE SHED DAMAGE DUE TO HEAVY RAIN. 05:00 - 10:30 5.50 CLEAN N DPRB COMP RIH WITH 3.5" DP & MULE SHOE TO 6468' TAGGED PBTD. (SEEN NO OBSTRUCTION ON TIH) 10:30- 12:00 1.50 CLEAN N DPRB COMP REVERSE CIRC BOTTOMS UP 12:00- 16:00 4.00 CLEAN N DPRB COMP LAY DN 3.5" DP & MULE SHOE. 16:00 - 17:00 1.00 RUNCOI~ COMP RIG UP TO RUN TRIPLE PKR. COMPLETION. 17:00 - 00:00 7.00 RUNCOI~ COMP RIH WITH 3.5" TRIPLE COMPLETION TO SETTING DEPTH. 7/3/2002 00:00 - 00:30 0.50 RUNCOI~ COMP MU HANGER & LAND SAME 00:30- 01:00 0.50 RUNCOI~ COMP SETTWC 01:00 - 02:00 1.00 BOPSUI; ~ COMP NIPPLE DN BOP 02:00 - 03:30 1.50 WHSUR ~ COMP NIPPLE UP & TEST TREE TO 5000 PSI. - Printed: 7/10/2002 12:24:40 PM Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: Event Name: WORKOVER Start: 6/27/2002 End: 7/3/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 7/3/2002 Rig Name: NABORS 4 Rig Number: 4ES 7/3/2002 03:30 - 06:00 2.50 RUNCOI~ COMP DROP BALL & ROD & PRESSURE TBG. TO 4000 PSI. & HOLD FOR 30-MIN (GOOD TEST) BLEED TBG. TO 2500 PSI. & PRESSURE ANNULUS TO 4000 PSI. & MONITOR FOR 30 -MIN GOOD TEST. 06:00 - 09:00 3.00 CHEM i P COMP BLEED TBG DN TO 2330 PSI. & SHEAR VALVE IN TOP GLM & PUMP 160 BBL. DIESEL TO FREEZE PROTECT TBG. 09:00 - 10:00 1.00 WHSUR i P COMP PU LUBRICATOR & SET BPV & SECURE CELLAR AREA. 10:00 - 12:00 2.00 CLEAN i P COMP CLEAN SAND OUT OF PITS. RIG RELEASED @ 1200 HRS. 7-03-02 Printed: 7/10/2002 12:24:40 PM 1. Type ~"~:~quest: Abandon_ Suspend_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operational shutdown _ Re-enter suspended well _ Conversion Conversion from Alter casing _ Repair well _ Prod to Iniect Well Change approved program _ Plugging _ Time extension _ Stimulate _ Prod to Inject Pull tubing _ Variance _ Perforate _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 2948' FNL, 3727' FEL, Sec. 33, T13N, R10E, UM At top of productive interval 42' FNL, 722' FEL, SEC 32, T13N, R10E, UM At effective depth 4902' FNL, 1093' FEL, Sec. 29, T13N, R10E, UM At total depth 716' FNL, 4825' FEL, Sec 29 T13N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Sen/ice_ (asp's 551644, 6009447) (asp's 549342, 6012338) (asp's 548966, 6012754) (asp's 545195, 6016916) 6. Datum elevation (DF or KB feet) RKB 62.3 feet 7. Unit or Property name Milne Point Unit 8. Well number MPI-09 9. Permit number/approval number _ 200-103 -- 10. APl number 50-029-22964-00 11. Field / Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Production 6534' 13094 feet 7197 feet Plugs (measured) 6470 feet 4052 feet Junk (measured) Size Cemented Measured Depth 20" 260 sx AS (Approx) 138' 9-5/8" 840 sx Arctic set Lite, 6562' 385 sx Class 'G' True vertical Depth 138' 4087' Perforation depth: measured Open Perfs 5860'-5870', 5890'-5910', 5932'-5942', 6180'-6250', 6350'-6400' true vertical Open Perfs 3810'-3815', 3823'-3831', 3840'-3845', 3944'-3971', 4008'-4026' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 2-7/8", 6.5#, L-80 TBG @ 5668' MD. 2-7/8", 6.5#, L-80 Tubing Tail @ 5751'. 9-5/8" x 2-7/8" Baker S-3 Permanent Packer @ 5668'. 2-7/8" HES X-Nipple @ 2012' MD. 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 15. StatUs of well classification as: 14. EStimated date for commencing operat, j,on July 1, 2002 16. If proposal was verbally approved Name of approver Date approved Oil _ X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sean Petersen Title: Milne Point Production Engineer FOR COMMISSION USE ONLY Questions? Call Sean Petersen @ 564-5025. Date June 19, 2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so represent~tive may witness Plug integrity_ ~OP Test~ Location clearance _ Mechanical Integrity Test ~, R E C E i ~EDnt form required ,0. qOq Approved by order of the Commission , ,,, ~~~ Ta~ Commissioner dUiq ~ ~ Approval no. Date q!/f~,/0 ~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp ( BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 29, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue SUite 100 Anchorage, AK 99501 Dear Tom' Re: Sundry Notice for MPI-09 Conversion from Producer to a Water Injector BP Explor/ation Alaska, Inc. proposes to convert well MPI-09 from a shut-in producer'to an active injector to provide water to the surrounding wells MPJ-03, MPI-08, MPI-19A, and MPJ-21 in the Milne Point Production Unit. MPI-09 was originally drilled as a Kuparuk River producer, but the sands were wet. The well was cemented off to become a Schrader Bluff injector, but based on initial pressures it was thought that it would not be in communication with the surrounding producers. MPI-09 was then put on production as a jet pump producer, but has had sanding problems due to lack of sand control. Based on recent hydraulic reviews, there is evidence that MPI-09 will support the surrounding producers once it is converted to an injector. /~ Path forward is to convert MPI-09 into an injector to support the surrounding wells. A packer completion will be installed in MPI-09 above all perforations. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5025, home 349-3098, or e-mail me at mailto:peterssd(~_,bp.com Sincerely, Sean Petersen Milne Point Unit/Schrader Bluff Production Engineer Well MPI-09 Current Status: · Fill (fine formation sand) @ 5755', February 17, 2002. · Well is shut-in and freeze protected. Order of Operations: 10. 1. Kill well and Chemical Cut Tubing four to six ft above packer. 2. MIRU Work Over Rig. 3. Pull existing completion. 4. USIT cement bond log was run at the time of the initial completion and indicates suffienct zone isolation above the perforated intervals. 5. Run Packer completion w/3.5" injection string. 6. Obtain a state witness of MITIA. 7. RDMO Work Over Rig. 8. Install surface injection equpment and tie in. 9. Commence injection into the Schrader Bluff sands with water for 6-9 months. Run state required injection profile survey. ITree: 3 1/8" - 5M Wellhead: 11" 5M FMC Gen. 6 w/10" x 3.5" FMC Tbg. Hng., 3.5" nsct. lift threads 3.5" Btrc. bottom connection crossed back to 2 7/8" 8 rd., 3" ClW "H" BPV profile 20" 91.1 ppf, H-40 ]--~ MPU 1-09 Orig. DF elev. -- 62.25' (Doyon 141) Orig. GL. elev.= 34.5' RT to 95/8' csg. hng. = 25.69' KOP @ 400' Max. hole angle = 67 deg. 3000'- PBTD 60 deg. to 68 deg. Hole angle through perfs = 68 deg. 9-5/8', 40 ppf, L-80, Btrc. ( drift ID = 8.835", cap. = 0.0758 bpf ) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) Minimum tubing restriction = 2.205" 'XN' profile @ 5717' HES X-Nipple 2.313" id [ 2,012' Perforation Summary Ref lo,q: USIT 8/12/00 ! Size ~ SPF Interval I N-sands 2-1/8"/ 4 I 5860'-5870' 2-1/8"/ 4 I 5890'-5910' 2-1/8" J 4 I 5932'-5942'OA sands 2-1/8 / 4 I 6180'-6250"OB sands 2-1/8" ~ 4 I 6350'-6400' (TVD) 3810'-3.8~' 3822'-3831' 3840'-3'845' 5 holes from 5,620' to 5621' shot 4/10/01 HES X-Nipple 2.313" id I 5,623' 9 5/8"x 27/8 .... Baker,I 5,668' S-3 Permanent Packer 3944'-3971' 4008'-4O26' 2 7/8" HES 'XN' npl. 15,717' I (w/2.313" packing bore & 2.205" no-go) 2 7/8" WLEG J 5,751' ] Baker model K Cement retainer @ 6470' 16 Bbls of class G cement below. 9 5/8" float collar (PBTD) I 6476' 9 5/8' casing shoe I 6560' Well plugged back balance plug est. top @ 12,600'/org. td @ 13,094' DATE REV. BY COMMENTS 8/21/00 MDO Drilled and Completed Doyon 141 11/15/00 MDO Initial Perforations OA 03/10/01 M. Linder Convert to producer 4/10/01 J. Jones Punch tbg. for jet pump 09/17/01 B. Hasebe Addition of Jet Pump flow schematic MILNE POINT UNIT WELL I - 09 APl NO: 50-029-22964-00 BP EXPLORATION (AK) .-- Pr~CHA~ICAL il~ffEG~TM IYEPO~T - Casing: ~.r/~" Shoe: f/~{,,L kid VO~TVD; DV: ~ ~ -TVD Liner' Shoe: 'lole S±?e /%''/~/" ~ and ~CP32qEC;_L iNTEGRITY - P.~T fl Annulus Press Test: Z? ~ 15 mit ; 30 mit iNTEGRITY - PART Cement Volumes :-g~nt. Liner Theoretical TOC Cement Bond Log (Yes or No) ; In AOGCC File CBL Evaluation, zone above perfs ~ ,,~.~C~. '~ Production Log: T~e ; Evaluation STATE OF ALASKA ALAS ~JIL AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil I'"1 Gas I-I Suspended [] Abandoned [] Service ~ TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-103 300-207 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50- 029-22964-00 4. Location of well at surface i CO;"~,'.:-~'~ ? ;'~ !:'r~t 14 "! ~VEt~IItD 'ii ~, ' Ifil) 9. Unit or Lease Name 2331' NSL, 3725' WEL, SEC. 33, T13N, R10E, UM i ~ ¢_~_~_.O____.~ i i'. ~~~;'~iA Milne Point Unit At top of productive intervali~27 ~I, 3728' NSL, 4790' WEL, SEC. 33 T13N, R10E, UM .......... ~11,~ i" 10. Well Number At total depth :! ~~------. ~' MPI-09 4562' NSL, 4824' WEL, SEC. 29, T13N, R10E, UM ~-~ ................ -,' 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE -- 62.25 ADL 025517 12' Date Spudded ! 10' Date T'D' Reached 114' Date C°m'P" Susp" °r Aband' 115' Water depth' if °fish°re 116' N°' °f C°mpleti°ns7/30/2000 8/9/2000 ¢,. o 2~ .~000 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of 15ermafrost 13094 7197 ETI 6470 4052 FTI [] Yes ~ NoI , N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, LWD, GR, RES, DEN, NEU, PWD, USIT 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.,1# H-40 28' 110' 24" 260 SX Arctic Set (Approx.) 9-5/8" 40# L-80 28' 6562' 12-1/4" 840 sx Arctic Set Lite~ 385 sx Class 'G' 124. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/8" Gun Diameter, 4 spf 2'7/8", 6.5#, L-80 5751' 5668' MD TVD MD TVD 5860' - 5870' 3810' - 3814' 5890' - 5910' 3823' - 3831' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 5932' - 5942' 3841' - 3845' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6180' - 6250' 3944' - 3971' 12600' - 13094' Abandon Kuparuk with 218 sx Class 'G' 6470' ' Set Cement Retainer, Pumped 6350,. 6400, 4008'. 4027, 72 sx Class ,G' Below Retainer '" 2400' Freeze Protect with 176 Bbls of Diesel '27. ' PRODUCTION TEST " Date First Production Method of Operation (Flowing, 'gas lift, 'etc.) June 16, 2001 Other (explain) - Jet Pump Date of Test Hours Tested PRODUCTION FOR OIL;BBL GAS-McF WATER-DEL CHOKE SIZE I GAs'OIL RATIO 6/26/2001 TEST PERIOD 329 86I 260 Flow TUbing Casing Pressure CALCULATED OIL-BBL G^s'MCF WATER-DEL OIL GRAViTY-APl (CORR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water.Su mitR IVED JUL .t 8 Z0Ol Alaska Oil & Gas Cons. Commission Anchorage 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 recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. NA 3719' 2905' NB 3744' 2915' NC 3776' 2928' NE 3792' 2934' NF 3842' 2954' OA 3876' 2967' OB 3941' 2993' HRZ 6288' 3985 Kuparuk D 6650' 4120' Kuparuk C 6834' 4193' Kuparuk B 6847' 4198' Kuparuk A 6952' 4240' I-~CEIvE KuparukA3 6962' 4244' JUL 8 2001 Kuparuk A2 6989' 4255' Kuparuk A1 7055' 4279' Alaska Oil & Gas Cons. Comm-s--ls ion Anchorage Miluveach 7070' 4285' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble v~r~~ ~,~ Title TechnicalAssistant Date MPI-09 200-103 300-207 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. ~ Approval No. ,,, , , , ,, , ,,, , , ,,, , , ,,, , , , , , ,,, ,, ,,,, , ,,,, ,, ,, , , , ,,,, INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: MPI-09 Common Name: MPI-09 8/4/2000 LOT 6,560.0 (ft) 4,086.0 (ft) 8.40 (ppg) 1,490 (psi) 3,273 (psi) 15.42 (ppg) , Printed: 6128/2001 2:17:26 PM : : Operations summa RePo Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: 7/29/2000 Event Name: ORIG DRILLING Start: 7/28/2000 End: 8/13/2000 Contractor Name: DOYON Rig Release: 8/13/2000 Group: RIG Rig Name: DOYON 141 Rig Number: 7/28/2000 19:30 - 00:00 4.50 MOVE PRE Move rig from MPF-83i to MPI-09. 00:00 - 0.00 MOVE PRE ........................ 06:00 hrs update ...................... 00:00-06:00 Continue to move from MPF-83i to MPI-09. Spot sub. Lay mats and spot pit module and pump module. Presently spotting last module on location. 7/29/2000 00:00 - 10:00 10.00 MOVE PRE Spotted complexes, rockwasher and pipe shed. 10:00 - 14:00 4.00 RIGU PRE Take on 600 bbls of mud. Install 6" liners in pump. Calibrate and test gas alarms. Nipple up riser and flowlines. Secure diverter lines. Spot and rig up Baroid solids van. Work to top drive gear box oil pump. NOTE: RIG ACCEPTED AT 1400 HRS 7-29-2000. 14:00 - 22:00 8.00 DRILL SURF Load pipe shed with 5" drill pipe. Picked up 5" drill pipe and HWDP and racked in derrick. Performed Diverter function test. Witnessed by AOGCC Inspector, John Crisp. 22:00 - 00:00 2.001 DRILL SURF Picked up BHA #1. Picked up motor and MWD tools. Made up bit, set motor at 1.57, orient and load MWD. 00:00 - 0.00 DRILL SURF .............................. 06:00 hr update ......................... 00:00-01:00 Held PreSpud Meeting with all rig personnel. 01:00-02:00 Spud well at 01:00 hrs 7-30-2000. Drill from 110'-183'. ART 1.2 hrs 02:00-02:30 Set back stand of HWDP and pick up flex collars. 02:30-06:00 Drill from 183'-275'. ART-.5 hrs AST- 1 hr. 7/30/2000 00:00 - 01:00 1.00 DRILL SURF Held PreSpud Meeting with all rig personnel. 01:00 - 02:00 1.00 DRILL SURF Spud well at 01:00 hrs 7-30-2000. Drill from 110'-183'. ART 1.2 hrs 02:00 - 02:30 0.50~ DRILL SURF Set back stand of HWDP and pick up flex collars. 02:30 - 00:00 21.50! DRILL SURF Drill and slide as per directional plan from 183'-1675'. ART 6.3 hrs AST 10 hrs. 00:00 - 0.00 DRILL SURF ......................... 06:00 hrs update ........................... 00:00-06:00 Drill and slide as per directional plan from 1675'-2493'. 7/31/2000 00:00 - 06:00 6.00 DRILL SURF Drill and slide as per directional plan from 1675'-2493'. 06:00 - 07:00 1.00 DRILL SURF Pumped high vis sweep and circulated hole clean. Checked flow and pumped dry job. 07:00 - 09:00 2.00 DRILL SURF Short tripped from 2493' to HWDP at 823'. Hole began pulling tight and swabbing. Pumped out from 2031'-1876' and 1566'-1411'. Tripped back Printed: 8/30/2000 2:14:39 PM Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: 7~29~2000 Event Name: eRIC DRILLING Start: 7~28~2000 End: 8/13/2000 Contractor Name: DOYEN Rig Release: 8/13/2000 Group: RIG Rig Name: DOYEN 141 Rig Number: ::~D~te ~rs:~:Acti~i~ ~d~ :: ~: D~scripti~ ~f:oP~ti~n~: 7/31/2000 07:00 - 09:00 2.00 DRILL SURF in hole with no problems. 09:00 - 17:00 8.00 DRILL SURF Drill and slide as per directional plan from 2493'-3513'. 17:00 - 18:00 1.00 DRILL SURF Pumped high vis sweep and circulated hole clean. Checked for flow and pumped dry job. 18:00 - 20:30 2.50 DRILL SURF Short tripped from 3513'-1375' with no problems. 20:30 - 00:00 3.50 DRILL SURF Drill and slide as per directional plan from 3513'-3884'. AST 4.5 hrs ART 7.5 hrs. 00:00 - 0.00 DRILL SURF ........................... 06:00 hrs update ........................... 00:00-06:00 Drill and slide as per directional plan from 3884'-4442'. 8/1/2000 00:00 - 13:30 13.50 DRILL SURF Drill & slide per dir. plan f/3884' to 5091'. 13:30 - 14:30 1.00 DRILL SURF Pump hi-vis sweep & circ. hole clean. 14:30 - 16:30 2.00 DRILL SURF Short trip f/5091' to 3423'. No problems. Drag data: 5100' Up 150K Dn 95K 4600' Up 145K Dn 90K 4100' Up 140K Dn 85K 3600' Up 136K Dn 85K 16:30 - 00:00 7.50 DRILL SURF Drlg. f/5091' to 5741'. AST 4.5 hrs. ART 10.5 hrs. - 0.00 DRILL SURF ..................... 0600 update ...................... 0000 - 0600 Drill f/5741' to 6275'. 8/2/2000 00:00 - 11:30 11.50 DRILL SURF Drilled from 5741' to 6572' to SC TD. 11:30 - 13:00 1.50 DRILL SURF Pump hi-vis sweep & circ. hole clean 13:00 - 15:30 2.50 DRILL SURF Short trip f/6572' to 5000'. No problems. Recorded torque & drag !readings every 5 stands for PU, SO and Rot wt. 15:30 - 20:30 5.00 DRILL SURF Pump hi-vis sweep. Circ. & cond. hole. Drop survey tool. Spot lubricant (additional 2%) and 5 ppb stickless beads. Rot and recip as circ. lube and beads to surface. Pump dry job. 20:30 - 00:00 3.50 DRILL SURF POH w/DP. (10 - 20K overpull f/2600' to 2200' - no swabbing'). Start LD BHA. Recorded drag readings every 5 stands for PU & SO wt. 00:00- 0.00 DRILL SURF ................. 0600 Update ...................... 0000 - 0200 Finish LD BHA. 0200 - 0330 Clear floor to run csg. PJSM held. 0330 - 0600 Run 9-5/8" casing per proc. Printed: 8/30/2000 2:14:39 PM Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: 7~29~2000 Event Name: ORIG DRILLING Start: 7~28~2000 End: 8/13/2000 Contractor Name: DOYEN Rig Release: 8/13/2000 Group: RIG Rig Name: DOYEN 141 Rig Number: ~ate ACti:~i~ ~bdb i ~ 8/2/2000 00:00- 0.00 DRILL SURF 8/3/2000 00:00 - 02:00 2.00 DRILL SURF Finished pulling out of hole with BHA. Laid down HWDP, jars and flex collars. Retrieved survey tool. Down load MWD, drain motor and reset at 07. 02:00 - 03:30 1.50 CASE SURF Cleared floor. Rigged up to run 9-5/8" casing. Held PJSM on casing running procedures. 03:30 - 07:30 4.00! CASE SURF Picked up and Bakerlocked 9-5/8" shoe track. Ran in hole with 9-5/8" casing. Began taking weight at 2200'. Worked pipe in hole to 3618'. Pipe free up but unable to run in hole. 07:30 - 09:30 2.00 CASE SURF Circulated casing string with casing fill up tool. Slowly brought rate up to 12 bpm at 1040 psi. Circulated 2 calculated bottoms up. Recovered small amounts of shale and stickless beads across shaker. 09:30 - 12:00 2.50 CASE SURF Continued running casing to bottom. Ran a total of 159 jts of 9-5/8" 40# L80 BTC casing. 12:00 - 15:00 3.00 CASE SURF Rigged down fill up tool and made up Dowell cementing head. Broke circulation and slowly brought circulation rates up to 12 bpm at 980 psi. Circulated 3 bottoms up at 12 bpm. 15:00 - 17:00 2.00 CEMT SURF I Switched over to Dowell. Pumped 10 bbls water, test lines to 3500 psi and pumped 10 bbls of water. Dropped top plug. Mixed and pumped 65 bbls of 10.4 ppg B-45 spacer followed by 840 sxs 6(.6_~bbls) of Artic Set Lite + 30% D053 Thixotrop. +.6% D046 Antifoam + 1.5% D079 Extender + 1.5% S001 Accelerator + 50% D124 Extender + 9% D04 Accelerator mixed in at 107 ppg slurry with a yield of 4.44 ft3/sx. Followed lead slurry with tail slurry. 385 sxs (7_~,9 bbls) Class G + .2% D046 Antifoam + .3% D065 Dispersant + 1% S001 Accelerator mixed in a 15.8 ppg slurry with a yield of 1.17 ft3/sx. Dropped top plug with 10 bbl of water. 17:00 - 18:30 1.50 CEMT SURF Displaced cement with rig pumps at 7 bpm. Displaced with water. Circulated 160 bbls of good cement to surface. Bumped plug at 1810 hrs with 2500 psi. Held pressure to 10 minutes. Released pressure and float held. 18:30 - 19:30 1.00 CEMT SURF Laid down cementing head. Backed out landing joint. Flushed stack and flowline with water. Laid down casing equipment and changed out bails. 19:30 - 21:00 1.50 BOPSUR SURF Nipple down diverter system. 121:00 - 21:30 0.50 WHSUR SURF Nippled up PBU Gen 5 M X M Xl 1" -5M starting head and 11-5K X 11"-5K tubing head. Tested metal to metal seal to 1000 psi-OK. 21:30 - 23:30 2.00 BOPSUR SURF Nipple up 13-5/8" 5 M BOPE. 23:30 - 00:00 0.50 BOPSUI; SURF Install test plug and test joint. Rig up to test BOPs. 00:00 - 0.00 BOPSUI~ SURF ........................ 06:00 hrs update ............................. Printed: 8/30/2000 2:14:39 PM Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: 7/29/2000 Event Name: ORIG DRILLING Start: 7~28~2000 End: 8/13/2000 Contractor Name: DOYON Rig Release: 8/13/2000 Group: RIG Rig Name: DOYON 141 Rig Number: ~hase :~iPti~' of ~Peraii~ns ~: 8~3~2000 00:00- 0.00 BOPSUI; SURF 00:00-03:00 Test all rams and valves 250 psi Iow / 3500 psi high.Tested annular to 250 psi Iow/1500 psi high. Low pressure test held for 5 minutes and high pressure test for 10 minutes. All test with water and charted. Function test accumulator. Rigged down test equipment. Right to witness test waived by AOGCC Inspector John Crisp. Installed wear bushing. 03:00--3:30 Made up riser and install flowline. 03:30-04:30 Cut and slip drill line. Service top drive. 04:30:05:30 PU 36 jts of 5" drill pipe and stand in derrick. 05:30-06:00 Make up drilling BHA #2. 8~5~2000 00:00 - 11:00 11.00 DRILL PROD1 Directional drill as per well plan from 7842'-8493'. 11:00 - 12:30 1.50 DRILL PROD1 Pumped a weighted high vis sweep and circulated hole clean. 12:30 - 13:30 1.00 DRILL PROD1 Check flow and pumped slug. Pulled out of the hole to the shoe at 6560. Check flow-negative. 13:30 - 14:00 0.50 DRILL PROD1 Serviced top drive. 14:00 - 14:30 0.50 DRILL PROD1 Tripped back in hole. Washed and reamed last stand as a precaution. No problems. 14:30 - 00:00 9.50 DRILL PROD1 ~ Directional drill from 8493'-9472'. Pumping high vis sweeps as needed to clean hole. 00:00 - 0.00 DRILL PROD1 .......................... 06:00 hrs update ........................... 00:00-05:30 Directional drill from 9472'-9979'. ECD approaching 11.2 PPg. 05:30-06:00 Pumping high vis sweeps to clean hole prior to short trip. 8~6~2000 00:00 - 05:30 5.50 DRILL PROD1 Directional drill from 9472'-9979'. ECD approaching 11.2 ppg. 05:30 - 07:30 2.00 DRILL PROD1 Pumped high vis sweep and circulated around. Pumped additional sweep and circulated hole clean. ECD down to 10.9 ppg. 07:30 - 09:30 2.00 DRILL PROD1 Made a wiper trip from 9979'- 8403'. Hole took good fill. Ran back in hole. Washed and reamed last stand as a precaution. No problems. 09:30 - 13:00 3.50 DRILL PROD1 Directional drill from 9979'-10323'. Control drill at 100-150'/hr. Reduced YP from 20 to 18. Drilling with 10.8 ECD. Lost top drive rotary. 13:00 - 14:30 1.50 DRILL TDRV PROD1 Circulated bottoms up and reciprocated drill pipe. Printed: 813012000 2:14:39 PM Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: 7~29~2000 Event Name: ORIG DRILLING Start: 7~28~2000 End: 8/13/2000 Contractor Name: DOYON Rig Release: 8/13/2000 Group: RIG Rig Name: DOYON 141 Rig Number: ~ie :: ACti~i~ '~;de: 8~6~2000 14:30 - 16:00 1.50 DRILL TDRV PROD1 Observe well. Pump slug and pulled into 9-518" casing shoe at 6560'. 16:00 - 00:00 8.00 DRILL TDRV PROD1 Monitor well on trip tank. Wait on parts for top drive. 00:00 - 0.00 DRILL PROD1 ...................... 06:00 hrs update .............................. 00:00-03:30 Monitored well on trip tank while repairing top drive. 03:30-04:30 Circulated bottoms up at shoe. 04:30-06:00 RIH to 8670'. Broke circulation and circulated for 10 minutes. Continued running in hole to bottom atg 10323'. 8~7~2000 00:00 - 03:30 3.50 DRILL TDRV PROD1 Monitored well on trip tank while repairing top drive. 03:30 - 04:30 1.00 DRILL TDRV PROD1 Circulated bottoms up at shoe. 04:30 - 06:00 1.50 DRILL TDRV PROD1 RIH to 8670'. Broke circulation and circulated for 10 minutes. Finished running in hole to bottom at 10323'. No problems. 06:00 - 00:00 18.00 DRILL PROD1 Directional drill from 10323' to 11615'. ART 11.14 hrs AST 3.25 hrs. Began drop at 11300'. Began raising mud weight from 9.2 to 10 ppg at 11500'. ECD running 11.5 ppg. 00:00 - 0.00 DRILL PROD1 ............................. 06:00 hrs update ........................ 00:00-06:00 Directional drill from 11615'-11930'. 8~8~2000 00:00 - 06:30 6.50 DRILL PROD1 Directional drill from 11615'-11 g40'. ECD approaching 11.5 emw. 06:30 - 08:00 1.50 DRILL PROD1 Circulated out and conditioned mud. ECD dropped from 11.5-11.3. 08:00 - 13:30 5.50 DRILL PROD1 Directional drill from 11940'-12072'. 13:30 - 15:00 1.50 DRILL PROD1 Pumped 30 bbls weighted barafiber sweep and circulated hole clean. 15:00 - 17:30 2.50 DRILL PROD1 Check for flow-negative. Pump slug. Made a wiper trip from 12072'-10256'. Recorded PU, SO, Rot and rotary torque readings every 5 stands. No problems. 17:30 - 00:00 6.50 DRILL PROD1 Directional Drill 12,072 to 12,325' at 00:00 hfs - Drop angle at 4? / 100' starting at 11,500' - Maintain mud wt. at 10.0 ppg - 525 gpm 2800 psi - 80 rpm, 18,000 ft/# torque - ECD 11.2 to 11.3 ppg while drilling - Last 24 hrs Art 5.7 hrs, Ast 10.8 hrs, Average Rop 43 fi/hr :00:00 - 0.00 DRILL PROD1 ............................... 0600 hrs Update ....................................... Continue drilling 12,325 to 12,580' at 0600 hrs - dropping angle at 4? / 100' 8/9/2000 00:00 - 19:30 19.50 DRILL PROD1 Directional drill 12,325 to TD as per geologist at 13,094' - Art 8.75 hfs, Ast 8.25, Average Rop 45 ft/hr - Finish angle drop from 68 to 23? at 12,800' - rotate ahead to TD - Maintain mud wt. at 10.0 ppg - Pumping/ 523 gpm @ 2800 psi - 80 rpm 19,000 ft/# torque - Top drive electrical" failure at 19:30 hrs depth of 13,094' - can not rotate or back out with top drive 19:30 - 21:30 2.00 DRILL PROD1 Circulate hole clean - 10.0 ppg mud wt. in and out Printed: 8/30/2000 2:14:39 PM perations summa Ropo 0 Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: 7~29~2000 Event Name: ORIG DRILLING Start: 7~28~2000 End: 8/13/2000 Contractor Name: DOYON Rig Release: 8/13/2000 Group: RIG Rig Name: DOYON 141 Rig Number: : ate From~ To HOUrs ActiVi~ code Phase : :: ::DescriPtionofioperations : 8~9~2000 19:30 - 21:30 2.00 DRILL PROD1 Formation Tops: Kuparuk B @ 12,772 md - 6902 TVD Kuparuk A3 @ 12,914 md - 7032 'FVD Kuparuk A2 @ 12,947 md - 7062 'FVD 21:30 - 00:00 2.50 DRILL PROD1 Pooh slowly with recorded LWD logs - Record up & down wt. every 5 stands - could not take rotating wt. due to top drive failure 8/10/2000 00:00 - 05:30 5.50 DRILL PROD1 Continue Pooh stand back 5" drill pipe 05:30 - 09:00 3.50 DRILL PROD1 Lay down BHA - Down load LWD & remove source 09:00 - 09:30 0.50 DRILL PROD1 Service rig 09:30 - 10:30 1.00 PXA PROD1 Pick up 40 its 1275' 3?" 13.30 S-135 drill pipe 10:30 - 12:00 1.50 PXA PROD1 TIH with 3?" stinger on 5" drill pipe to 9 5~8" casing shoe 12:00 - 13:00 1.00 PXA PROD1 slip & cut 105' drill line 13:00 - 15:30 2.50 PXA PROD1 Finish TIH to TD at 13,094' 15:30 - 17:00 1.50 PXA PROD1 Circulate bottoms up at 13,094' - 508 gpm 3000 psi 17:00 - 18:30 1.50 PXA PROD1 Pre-Job safety meeting -Rig up Dowell - Test lines 3000 psi - Pump 16 bbls fresh water ahead - Cement with 218sx Class 'G'w/.3% D-065 + .15% D-800 + .4% D-167 + .2% D-046 - yield 1.16 cfs - 45 bbls slurry mixed at 15.8 ppg on fly - Followed by 2 bbls fresh water - Pump to balance plug with 206 bbls 10.0 ppg mud - Est top of cement at 12,600' 18:30 - 20:00 1.50 PXA PROD1 Pooh slowly 16 stands to 11,589' 20:00 - 22:30 2.50 PXA PROD1 Circulate full circulation long way - no cement back - 500 gpm 3000 psi - monitor well - Pump slug 22:30 - 00:00 1.50 PXA PROD1 Pooh stand back total 70 stands drill pipe in derrick - Lay down excess drill pipe at 00:00 hrs 8/11/2000 00:00 - 06:00 6.00 PXA PROD1 Finished pulling out of hole laying down excess 5" drill pipe and 40 jts of 3-1/2" drill pipe and muleshoe. 06:00 - 06:30 0.50 PXA PROD1 Service rig and topdrive. 06:30 - 11:00 4.50 PXA PROD1 Picked up 9-5~8" Baker Model K-1 cement retainer and ran in hole with 5" drill pipe to 6470'. Set cement retainer at 6470'. Pulled 30K over and sat 50K down on retainer. Rotated stinger out of retainer. Tested retainer and casing to 1500 psi-OK. 11:00 - 12:00 1.00 PXA PROD1 Held PJSM. Stung into cement retainer and establised injection rates as follows: I bpm - 400 psi, 3 bpm - 730 psi and 5 bpm - 1100 psi. Pumped a total of 15 bbls water ahead. Pulled out of retainer. Mix and spotted 16 bbls (72 sxs) Class "G" cement w/.3% D-065 dispersant + .2% D-046 antifoam + 1% S-001 accelerator mixed in a 15.8 ppg slurry with a yield of 1.17 ft3. Followed cement with 2 bbls of water. Pumped 80 bbls of mud displacement and stung into cement retainer and displaced 15 bbls of water and 16 bbls of cement below retainer at 6470'. 12:00 - 13:00 1.00 PXA PROD1 Pulled out of cement retainer and reversed 2 drill pipe volumes. 13:00 - 14:00 1.00 PXA PROD1 Circulated and conditioned mud for displacement. 14:00 - 16:00 2.00 PXA PROD1 Reversed circulated mud out of hole with seawater at 420 gpm @ 3000 psi. - Circulate through surface equipment 16:00 - 18:30 2.50 PXA PROD1 Pooh with running tool - stand back drill pipe 18:30 - 20:30 2.00 VVHSUR COMP Set back 13 5/8 BOP stack - Nipple down & remove FMC Gen 5 11" Printed: 8/30/2000 2:14:39 PM : , operations summa Repo. Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: 7~29~2000 Event Name: ORIG DRILLING Start: 7~28~2000 End: 8/13/2000 Contractor Name: DOYON Rig Release: 8/13/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Da~e Er°~ To ACtNi~[COde Phase 8/11/2000 18:30 - 20:30 2.00 WHSUR COMP 5K tubing head and 11" 5K x SO casing head - nipple down to 9 5~8" mandrell hanger 20:30 - 00:00 3.50 WHSUR COMP Nipple up FMC Gen 6 11" 5K x SO metal to metal seal Casing head - test to 1,000 psi -ok - Nipple up 11" x 13 5/8" 5K spool & 13 5/8" 5K drill spool - Nipple up 13 5/8" 5K BOP stack 8/12/2000 00:00 - 06:30 6.50 BOPSUI~ COMP Installed test plug and test BOPE. Tested all valves and rams 250 psi Iow / 3500 psi high. Tested annular preventer 250 psi Iow / 1500 psi high. Held Iow pressure test 5 minutes and high pressure for 10 minutes. All test were recorded on charts. 06:30 - 07:00 0.50 BOPSUF COMP Serviced rig and top drive. 07:00 - 09:30 2.50 CLEAN COMP Made up 5" muleshoe. Tripped in hole with 5" drill pipe to cement retainer at 6470'. 09:30 - 10:.30 1.00 CLEAN COMP Closed annular and reverse circulated 2 drill pipe volumes (220 bbls) at 460 gpm @ 550 psi. 10:30- 11:00 0.50 CLEAN COMP Open Hydrill - Pump 35 bbls caustic wash + 50 bbls Dirt magnet + 35 bbls high vis sweep 11:00 - 13:00 2.00 CLEAN COMP Followed by 830 bbls of Filtered Seawater - Pump at 588 gpm 560 psi, Reciprocate & Rotate at 120 rpm w/6500 ft / lbs torque - Final NTU 31 13:00 - 17:30 4.50 CLEAN COMP Pooh lay down 5" drill pipe 17:30 - 21:30 4.00 EVAL COMP Rig up Schlumberger wireline - RIH with 8.5" GPJJB to PBTD at 6469' wlm. RIH w/ CCL / GR / Controled USIT to 6430' - Log 6430 to surface - Rig down Schlumberger - USIT was Marked Line :21:30 - 22:30 1.00 RUNCOI~! COMP Rig up Doyon tubing tongs - Pre-Job safety meeting with drill crew 22:30 - 00:00 1.50 RUNCOI~I COMP Run 2 7/8" 6.5# L-80 Eue 8rd AB-Mod Completion with Baker 9 5/8" S-3 permanent Packer 8/13/2000 00:00 - 06:00 6.00 RUNCOI~I COMP Ran 181 jts of 2 7/8" 6.5~ L-80 Eue 8rd AB-Mod Completion with Baker 9 5/8" S-3 permanent Packer. Bottom of WLEG at 5750.6'. Packer at 5668.08'. 06:00 - 06:30 0.50 RUNCOI~ COMP Landed tubing hanger and installed TWC. Ran in lock down screws. Pressure tested TWC from bottom with 1000 psi- OK. Laid down landing joint. 06:30 - 09:00 2.50 BOPSUF COMP Nipple down BOP equipment. 09:00 - 11:30 2.50 WHSUR COMP Nipple up FMC 11" 5K x 3 1/8" 5K tubing head adapter and 3-1/8" 5K WKM single actuated production tree. Tested hanger and tree to 5000 psi for 10 minutes-OK. 11:30 - 15:00 3.50 CHEM COMP Reverse circulated 300 bbls of seawater w/25 gals/100 bbls Corexit 7726 at 2? BPM 500 psi Printed: 813012000 2:14:39 PM : : . Legal Well Name: MPI-09 Common Well Name: MPI-09 Spud Date: 7/29/2000 Event Name: ORIG DRILLING Start: 7/28/2000 End: 8/13/2000 Contractor Name: DOYON Rig Release: 8/13/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Date ~ From~To HOUrs ACtivi~ COde Phase Description of operations ::: 8/13/2000 15:00 - 16:30 1.50 CHEM COMP Rig up HB&R pump truck - Pump 176 bbls Diesel down annulus at 2.3 BPM 700 psi taking returns up tubing 16:30 - 17:30 1.00 CHEM COMP Rig up hose - Let diesel U-Tubing to tubing string - Freeze protect to 2400' md 17:30 - 18:00 0.50 RUNCOI~ COMP Drop 1 5/16" ball with rod & rollers - let fall to RHC plug in 'XN' nipple at 5718' 18:00 - 18:30 0.50 RUNCO~I COMP Pressure up to 3500 psi with diesel to set Baker S-3 packer at 5668' 18:30 - 20:00 1.50 RUNCO~I COMP Test tubing to 3000 psi for 30 minutes on chart, no bled off - Test annulus to 3000 psi for 30 minutes on chart - loss 100 psi in 30 minutes 20:00 - 21:00 1.00 WHSUR COMP Install 2?" ClW type 'H' BPV ~ Secure well - Install blind flange on wing valve - Vac out cellar - Rig Released at 2100 hrs 8/13/2000 Printed: 8~30~2000 2:14:39 PM Well: MPI-09 Rig Accept: 07/29/00 Field: Milne Point Unit Rig Spud: 07/30/00 APl: 50-029-22964-00 Rig Release: 08/13/00 Permit: 200-103 Drillir 141 POST - RIG WORK 09/02/00 Perforated OB interval from 6360' - 6380' using 2-1/8" Enerjet guns. Reference log was SWS USIT log dated 08/12/00. Tubing pressure was 350 psi when guns fired, good indication, pressure slowly bled off. O9~2O/OO Obtained SBHP at 6447' SLM /4044' TVD. Bottom 1703 psi, 81 degrees; Top 1701 psi, 81 degrees. Pressure was higher than expected. Pressure was not stable through the survey. The well will be bled down and another static will be done. 10/08/00 It is thought that the initial perfs may have not penetrated deep enough or are plugged with debris. Attempted to breakdown perfs using diesel. No breaks were seen in injection pressures. 10/30/00 Obtained SBHP at mid perfs. Downhole gauges read 1667 psi at 81 degrees. 11/15~00 Shot two intervals in the OA sands with 20' 2" Enerjet 4 spf strip, 90 degree phased; 6230' - 6250' and 6180' - 6200'. The well will remain shut in until a static survey can be run. 11/24/00 Obtained SBHP at 6440' sim of 1654 psi at 81 degrees. 03/07 - 03/10/01 MPI-09 wa? slatted to.__be__a Sch~rad~ but once perforated, reservoir pressures showed the well was in its own fault block. The well will be converted from an injector to a producer. Finished perforating using 2-1/8" Enerjet guns, 4 spf, 21.9" penetration hole, .31" entrance hole. 5860'- 5870'N Sand 5890'- 5910'" 5932'-5942'" 6200'-6230' OA Sand 6350'-6360' OB Sand 6380'-6400'" 03/12/01 Obtained SBHP at 6175' sim. Mid perf of OA sands. BHP 1584 psi, 76 degrees. 04/10/01 Shot 1' with 5 holes in tubing from 5620' to 5621' for jet pump. 04/25/01 Set Jet Pump assembly. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska 99501 February 08,2001 MWD Formation Evaluation Logs - MPI-09, AK-MM-00120 MPI-09: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22964-00 1 Blueline 1 Rolled Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22964-00 1 Blueline 1 Rolled Sepia 2" x 5" MD Neutron & Density Logs' 50-029-22964-00 1 Blueline 1 Rolled Sepia 2" x 5" TVD Neutron & Density Logs: 50-029-22964-00 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEItrr BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATI'ENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signed~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs January 25, 2001 MPI-09, AK-MM-00120 1 LDWG formatted Disc with verification listing. API#: 50-029-22964-00 PLEASE ACKNOWLEDGE RECEItrl' BY SIGNING A COPY OF TI-IE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: ! GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 597 Company Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorages- AK 99501 Milne Point (Cased Hole) 1 O/11/00 Well Job # Log Description Date BL -Sepia CD MPI-09 ~ ~ 'J~ ~- 20408 USIT(PDC) 000812 1 MPF-83 I~- ~-~-I~~ 20409' USlT(PDC) 000817 1 · · . · .. · · , · · · PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Bivd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie Received ~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 465 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 8/30/00 Well Job # Log Description Date BL Sepia Color MPI-09 20350 USIT 000812 1 MPF-83 20354 USIT 000817 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center MB3-3 9[]0 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED SEP 08 2000 Alaska 0il & Gas Cons. CommiSsion Anchorage Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99~3 Al'tN: Sherrie .~ \ _~.~_.---~. /} North Slope Alaska Alaska State Plane 4 Milne Point MPi MPI-09 MWD Surveyed: 9 August, 2000 SURVEY REPORT 24 August, 2000 Your Reft API.500292296400 Surface Coordinates: 6009446.72 N, 551644.73 E (70° 26' 11.6006" N, 149° 34' 44.1541" W) Kelly Bushing: 62.25ft above Mean Sea Level ,4, HAI,t~BUL~TQN COM~AN~ Survey Reft svy9534 Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API.500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate (°ll00ff) Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment MPI-09 PGSS o.0o o.o00 o.0oo .62.25 0.oo 119,0o 0,350 278.000 56.75 119.oo 205.00 o~62o 20.270 142.75 205.00 302,90 1.47o 35.630 240.63 302.88 394.93 3.490 28.730 332.57 394.82 o.oo N 0.00 E 0.05 N 0.36 W 0.52 N 0.46 W 2.04 N 0.46 E 5.46 N 2,49 E 6009446.72 N 551644.73 E 6009446.77 N 551644.37 E 6009447.24 N 551644.27 E 6009448,76 N 551645.17 E 6009452.19 N 551647.18 E 0.294 0.900 0.907 2.215 0.00 0.27 0.70 1.29 2.64 Tie-on to PGSS MPI-09 MWD 486.28 4.150 26.330 423.72 485.97 578.52 7.250 32.490 515.49 577.74 668.87 7.420 22.310 605.10 667.35 758.98 9,050 12.520 ,694.29 756.54 852.08 9.790 7.160 786.13 848.38 944.65 9.170 351.770 877.45 939.70 1036,78 9.790 336.780 968.34 1030.59 1129.55 10.810 319.170 1059.63 1121.88 1222.13 11,850 314.780 1150.41 1212.66 1315.69 14.450 316.930 1241.51 1303.76 1408.23 14.770 317.920 1331.06 1393.31 1499,16 16.400 322.060 1418.64 1480.89 1593.41 20.530 325.800 1508.03 1570.28 1686,57 23.380 327.480 1594.42 1656.67 1778.76 26.050 325.400 1678,16 1740.41 10.86 N 5.29 E 18.76 N 9.90 E 28.97 N 15.18 E 41.27 N 18.92E 56.27 N 21.50 E 71.38 N 21.42E 85.85 N 17.28 E 99.68 N 8.48 E 112.95 N 3.94 W 128.25 N 18.73 W 145.44N 34,52W 164.16 N 50.19W 188.34N 67.66W 217.44N 86.79W 249.53 N 108.12W 6009457.61N 551649.95 6009465.55 N 551654.50 6009475.79 N 551659.71 6009488.12 N 551663.37 6009503.14 N 551665.84 6009518.25 N 551665.66 6009532.69 N 551661.42 6009546.46 N 551652.52 6009559.64 N 551640.01 6009574.83 N 551625.11 6009591.91 N 551609.20 6009610.53 N 551593.41 6009634.59 N 551575.76 6009663.56 N 551556.44 6009695.50 N 551534.89 E 0.743 5.04 E 3.421 8.22 E 1.449 12.76 E 2.380 19.90 E 1.232 29.86 E 2.810 41.59 E 2.754 55.40 E 3.552 71.67 E 1.459 89.81 E 2.827 111.02 E 0.439 134.32 E 2.169 158.74 E 4.556 188.51 E 3.132 223.14 E 3.046 261.48 MWD Magnetic Continued... 24 August, 2000 - 12:58 - 2- DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: AP1-$00292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (fi) (ft) (ft) (ft) 1871.89 29.960 324.210 1760.37 1822.62 1964.92 33,620 324.840 1839.43 1901.68 2058.02 36.590 322.840 1915.59 1977.84 2150.74 38.970 320.990 1988.87 2051.12 2243.10 42.840 319.560 2058.66 2120.91 2336.09 45.080 319.680 2125.60 2187.85 2428.89 45.770 320.240 2190.73 2252.98 2521.25 48.280 319.490 2253.68 2315.93 2614.74 51.410 321.410 2313.97 2376.22 2707.73 53.300 321.140 2370.76 2433.01 2799.49 53.240 323.790 2425.64 2487.89 2892.07 56.390 322.890 2478.98 2541.23 2987.25 58.910 321.360 2529.91 2592.16 3077.05 59.640 322.090 2575.79 2638.04 3173.01 62.810 320.030 2621.98 2684.23 3265.93 62.990 320.760 2664.31 2726.56 3358.12 66.020 320.000 2703.99 2766.24 3450.63 66.910 319.970 2740.93 2803.18 3540.91 67,940 317.890 2775.59 2837.84 3635.64 68.670 319.780 2810.61 2872.86 3727.33 66.010 320.800 2845.93 2908.18 3819.34 66.590 320.680 2882.91 2945.16 3914.32 67.280 321.170 2920.13 2982.38 4007.15 66.630 320.040 2956.46 3018.71 4100.34 66.460 320.130 2993.56 3055.81 285.24 N 133.34W 6009731.03 N 551509.42E 325.16 N 161.77W 6009770.75 N 551480.72 E 368.35 N 193.38W 6009813.72 N 551448.81 E 413.04 N 228.43W 6009858.17 N 551413.45 E 459.52 N 267.09W 6009904.38 N 551374.46 E 508.69 N 308.91W 6009953.26 N 551332.31 E 559.30 N 351.43W 6010003.58 N 551289.43 E 610.96 N 394.99W 6010054.93 N 551245.51 E 666.06 N 440.46W 6010109.71N 551199.67 E 723.50 N 486.52W 6010166.83N 551153.21 E 781.81N 531.32W 6010224.83 N 551108.01E 842.49N 576.50W 6010285.20 N 551062.41E 905.94 N 625.87W 6010348.30 N 551012.60 E 966.54N 673.69W 6010408.57 N 550964.36 E 1031.94 N 726.56W 6010473.60 N 550911.04 E 1095.67 N 779.29W 6010536.96 N 550857.87 E 1159.75 N 832.35W 6010600.68 N 550804.36 E 1224.71N 886.89W 6010665.26 N 550749.38 E 1287.55 N 941.66W 6010727.72 N 550694.18 E 1353.81N 999.59W 6010793.57 N 550635.79 E 1418.89 N 1053.65W 6010858.28 N 550581.28 E 1484.12 N 1106.96W 6010923.14 N 550527.52 E 1551.96 N 1162.04W 6010990.60 N 550471.97 E 1617.97N 1216.26W 6011056.23 N 550417.30 E 1683.54 N 1271.11W 6011121.42 N 550361.99 E Dogleg Rate (°/lOOft) 4.241 3.950 3.421 2.843 4.311 2.411 0.859 2.782 3.697 2.045 2.315 3.494 2.975 1.072 3.802 0.726 3.370 0.963 2.414 2.008 3.077 0.642 0.868 1.321 0.203 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 305;09 353.97 407.42 464.20 524.66 589.19 655.29 722.86 794.30 867.92 941.41 lO16.98 1097.35 1174.53 1258.62 1341.34 1424.54 1509.35 1592.67 1680.64 1765.24 1849.49 1936.87 2022.29 21o7.78 Continued... DrillQuest 1.05.04e 24 August, 2000 - 12:58 .3 - Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4192.47 66.990 319.870 3029.96 3092.21 4285.31 65.500 320.520 3067.36 3129.61 4378.88 66.020 321.070 3105.78 3168.03 4469.64 65.730 322.820 3142.87 3205.12 4565.00 64.600 322.410 3182.93 3245.18 4657.99 65.580 320.730 3222.09 3284.34 4748.82 63.680 323.630 3261.02 3323.27 4841.76 63.470 325.300 3302.38 3364.63 4935.09 63.450 324.340 3344.08 3406.33 5027.79 62.600 324.270 3386.13 3448.38 5120.66 62.620 324.780 3428.86 3491.11 5213.59 62.710 324.330 3471.53 3533.78 5305.85 64.010 324.970 3512.90 3575.15 5399.02 63.680 323.260 3553.97 3616.22 5491.78 64.300 323.590 3594.64 3656.89 5585.22 65.440 320.970 3634.33 3696.58 5677.68 65.820 318.410 3672.49 3734.74 5770.37 65.440 320.230 3710.74 3772.99 5863.26 65.350 320.860 3749.41 3811.66 5955.12 64.830 321.720 3788.10 3850.35 6048.77 64.400 320.410 3828.25 3890.50 6140.86 66.200 317.950 3866.74 3928.99 6235.36 68.190 317.990 3903.36 3965.61 6326.51 68.050 318.110 3937.33 3999.58 6418.61 68.560 317.060 3971.38 4033.63 1748.38 N 1325.51W 1813.65 N 1379.91W 1879.77 N 1433.84W 1944.99 N 1484.90W 2013.75 N 1537.44W 2079.81N 1589.86W 2144.62 N 1640.19W 2212.34 N 1688.56W 2280.59 N 1736.67W 2347.68 N 1784.87W 2414.83 N 1832.72W 2482.08 N 1880.60W 2549.35 N 1928.31W 2617.10 N 1977.32W 2684.05 N 2027.00W 2750.95 N 2078.75W 2815.16 N 2133.23W 2879.19 N 2188.27W 2944.40 N 2241.94W 3009.41N 2294.04W 3075.22 N 2347.21W 3138.52 N 2401.90W 3203.22 N 2460.22W 3266.13 N 2516.76W 3329.31N 2574.48W 6011185.88 N 550307.14 E 6011250.77 N 550252.29 E 6011316.51N 550197.91E 6011381.38 N 550146.40 E 6011449.77 N 550093.38 E 6011515.47N 550040.50 E 6011579.93 N 549989.73 E 6011647.32 N 549940.89 E 6011715.23 N 549892.31 E 6011781.98 N 549843.65 E 6011848.80 N 549795.33 E 6011915.72 N 549746.99 E 6011982.65 N 549698.82 E 6012050.07 N 549649.33 E 6012116.67 N 549599.20 E 6012183.21N 549546.98 E 6012247.05 N 549492.05 E 6012310.69 N 549436.58 E 6012375.52 N 549382.46 E 6012440.17 N 549329.91E 6012505.61N 549276.28 E 6012568.53 N 549221.16 E 6012632.83 N 549162.39 E 6012695.34 N 549105.41E 6012758.12 N 549047.25 E Dogleg Rate (°ll00ft) 0.631 1.728 0.772 1.789 1.248 1.948 3.563 1.625 0.920 0.919 0.488 0.441 1.539 1.685 0.741 2.816 2.555 1.835 0.624 1.021 1.345 3.116 2.106 0.196 1.195 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 2192.41 2277.38 2362.70 2445.50 2531.99 2616.31 2698.34 2781.37 2864.64 2947.09 3029.36 3111.71 3193.97 3277.44 3360.71 3445.26 3529.46 3613.86 3698.32 3781.63 3866.23 3949.85 4036.87 4121.37 4206.82 Continued... DrillQuest 1.05.04e 24 August, 2000 - 12:58 - 4. Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl. 6504.48 68.790 6589.75 67.800 6682.07 67,230 6776.15 66.520 6868.31 65.740 6960.74 67.200 7053.46 68.110 7146.75 67.620 7238.48 68.460 7331.99 68.15o 7424.40 67.710 7516.78 67.610 7610,31 67.750 7702.33 67.430 7795.86 67.350 7890,08 67.16o 7984.14 66.910 8077.07 67.260 8169.16 68.470 8262.93 68.220 8356.01 68,130 8446.22 67.91o 8539.30 67.670 8633.57 67.430 8726.77 66.870 Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) 339.600 4002.96 4065.21 3396.83 N 2616.13W 317.570 4034.83 4097.08 3463.94N 2657.05W 317.880 4070.14 4132.39 3527.06 N 2714.43W 318.300 4107.09 4169.34 3591.44N 2772.22W 315.860 4144.39 4206.64 3653.16 N 2829.61W 317.250 4181.29 4243.54 3714.69 N 2887.87W 319.000 4216.54 4278.79 3778.54 N 2945.11W 318.950 4251.69 4313.94 3843.73 N 3001.83W 320.310 4286.00 4348.25 3908.55 N 3056.93W 323.340 4320.57 4382.82 3976.84 N 3110.63W 321.020 4355.30 4417.55 4044.49 N 3163.13W 321.080 4390.41 4452.66 4110.94 N 3216.85W 322.830 4425.93 4488.18 4179.07 N 3270.17W 319.800 4461.02 4523.27 4245.47N 3323.33W 320.320 4496.98 4559.23 4311.67 N 3378.76W 319.430 4533.41 4595.66 4378.11N 3434.76W 316.760 4570.11 4632.36 4442.56 N 3492.59W 317.240 4606.30 4668.55 4505.16 N 3550.97W 319.990 4641.00 4703.25 4569.16 N 3607.35W 320.340 4675.60 4737.85 4636.08 N 3663.18W 319.830 4710.21 4772.46 4702.36 N 3718.62W 319.500 4743.97 4806.22 4766.12 N 3772.76W 321.010 4779.16 4841.41 4832.38 N 3827.86W 318.580 4815.16 4877.41 4898.91N 3884.09W 318.840 4851.36 4913.61 4963.45 N 3940.77W Global Coordinates Northings Eastings (ft) (ft) 6012825.36 N 549005.14 E 6012892.18 N 548963.76 E 6012954.90 N 548905.94 E 6013018.88 N 548847.70 E 6013080.20 N 548789.90 E 6013141.32 N 548731.20 E 6013204.78 N 548673.52 E 6013269.57 N 548616.35 E 6013334.01N 548560.81E 6013401.92 N 548506.64 E 6013469.20 N 548453.67 E 6013535.28 N 548399.49 E 6013603.05 N 548345.70 E 6013669.07 N 548292.08 E 6013734.89 N 548236.20 E 6013800.94 N 548179.74 E 6013864.99 N 548121.46 E 6013927.18 N 548062.65 E 6013990.79 N 548005.83 E 6014057.32 N 547949.54 E 6014123.21N 547893.64 E 6014186.60 N 547839.05 E 6014252.48 N 547783.50 E 6014318.62 N 547726.80 E 6014382.76 N 547669.69 E Dogleg Rate (°/lOOft) 24.432 24.011 0.691 0.859 2.565 2.097 2.003 0.528 1.652 3.029 2.375 0.124 1.737 3.064 0.520 0.894 2.627 0.607 3.062 0.438 0.518 0.418 1.524 2.396 0.654 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 4285.44 4363.28 4448.47 4534.90 4619.01 4703.54 4789.21 4875.59 4960.64 5047.50 5133.1o 5218.54 5305.04 5390.09 5476.43 5563.31 5649.82 5735.24 5820.48 5907.63 5994.04 6077.68 6163.85 6250.95 6336.79 Continued... 24 August, 2000- 12:58 ' $ ' DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl, Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8819.31 66.510 317.730 4887.97 4950.22 8912.08 66.350 316.230 4925.07 4987.32 9005.01 66.220 317.400 4962.45 5024.70 9096.78 65.800 317.740 4999.76 5062.01 9189.51 66.060 319,500 5037.58 5099.83 9280.49 66.380 320.120 5074.27 5136.52 9375.27 67.370 322.530 5111,50 5173,75 9471.04 68.930 323.240 5147.14 5209.39 9562.86 68.780 323,060 5180.26 5242.51 9655.29 68.560 322.140 5213.88 5276.13 9747.82 68.400 321.330 5247.83 5310.08 9841.10 68.520 322.020 5282.07 5344.32 9934.35 68.560 321.340 5316.19 5378.44 10026.69 68.780 321.190 5349.78 5412.03 10120.30 68.790 320.960 5383.65 5445.90 10213.84 66.810 320.100 5418.99 5481.24 10305.10 66.790 319.350 5454,95 5517,20 10398.45 67.200 317.990 5491.43 5553.68 10490.52 67.330 319.520 5527.01 5589.26 10584.04 67.220 318.050 5563.14 5625.39 10677.06 67.310 317.070 5599.09 5661.34 10769.41 67.460 318.460 5634.61 5696.86 10862.92 67.590 317.460 5670.35 5732.60 10954.17 65.690 318.080 5706.53 5768.78 11047.30 65.650 318,150 5744.90 5807.15 5026.89 N 3997.32W 6014445.81N 547612.70 E 5089.05 N 4055.33W 6014507.57 N 547554.26 E 5151.09 N 4113.55W 6014569.20 N 547495.60 E 5212,97 N 4170.12W 6014630.69 N 547438.61E 5276.50 N 4226.09W 6014693.83 N 547382.21 E 5340.10 N 4279.81W 6014757,05 N 547328.04 E 5408.14 N 4334.27W 6014824.72N 547273.11E 5479.03 N 4387.90W 6014895.23 N 547218,99 E 5547.55 N 4439.26W 6014963.40 N 547167.16 E 5615,95 N 4491.56W 6015031.43 N 547114.39 E 5683.54 N 4544.86W 6015098,65 N 547060.62 E 5751.60 N 4598.67W 6015166.34 N 547006.34 E 5819.69 N 4652.48W 6015234.06 N 546952.06 E 5886.79 N 4706,30W 6015300.78 N 546897~78 E 5954.68 N 4761.13W 6015368.29 N 546842,48 E 8021.53 N 4816.18W 6015434.76 N 546786.97E 6085.53 N 4870.40W 6015498.38 N 546732.30 E 6150.05 N 4927.15W 6015562.50 N 546675.12 E 6213.90 N 4983.13W 6015625.96 N 546618.69 E 6278.78 N 5039.96W 6015690.45 N 546561.41E 6342.09 N 5097.85W 6015753.36 N 546503.08 E 6405.21N 5155.15W 6015816.08 N 546445.35 E 6469.38 N 5213.02W 6015879.85 N 546387.04E 6531.40 N 5269o32W 6015941.48 N 546330.31 E 6594.58 N 5325.97W 6016004.26 N 546273.22 E Dogleg Rate (°ll00ff) 1.168 1.492 1.161 0.569 1.755 0.716 2.561 1.768 0.245 0.957 0.833 0.700 0.680 0.282 0.229 2.281 0.756 1.411 1.539 1.455 0.976 1.399 0.998 2.174 0.081 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 6421.71 6506.56 6591.45 6675.18 6759.79 6843.03 693o.18 7019.00 7104.55 719o.6o 7276.66 7363.41 7450,18 7536.19 7623.46 7710.06 7793.93 7879.80 7964.67 8050.88 8136.55 8221.69 8308.00 8391.66 8476.44 Continued... 24 August, 2000 - 12:58 - 6- DrillQuest 1.05,04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. 11140.25 65.480 317.130 11232.94 65.450 316.470 11324.91 63.720 314.000 11417.83 61.460 315.000 11510.46 61.830 315.820 11603.64 61.940 320.290 11695.67 58.950 319.730 11789.79 56.220 319.410 11883.67 53.680 319.040 11974.50 50.950 319.120 12069.40 47.060 318.690 12162.66 43.660 319.340 12255.66 39.370 318.820 12349.13 35.980 320.590 12441.86 32.550 318.730 12530.75 28.600 317.280 12625,02 25.240 317.960 12716.35 24.290 318.460 12810.39 23.750 317.020 12902.26 23.660 316.630 12995.60 23.600 317.160 13046.88 23.190 316.590 13094.00 23.190 316.590 Sub-Sea Depth (ft) 5783.35 5821.84 5861.32 5904.09 5948.08 5992.01 6037.40 6087,85 6141.76 6197.28 6259.52 6325.04 6394.66 6468.64 6545.26 6621.78 6705.82 6788.75 6874.65 6958.77 7044.28 7091.35 7134.66 Vertical Local Coordinates Depth Northings Eastings (fi) (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (fl) (ft) (°llOOft) 5845.60 6657.11N 5382.99W 6016066.40 N 546215.77 E 5884.09 6718.58 N 5440.71W 6016127,46 N 546157.62 E 5923.57 6777.56 N 5499.19W 6016186.04 N 546098.74 E 5966.34 6835.36 N 5558.03W 6016243.43 N 546039.50 E 6010.33 6893.42 N 5615.25W 6016301.09 N 545981.88 E 6054.26 6954.52 N 5670.16W 6016361.81N 545926.54 E 6099.65 7015.85 N 5721.60W 6016422.79 N 545874.68 E 6150.10 7076.33 N 5773.12W 6016482.91N 545822.74 E 6204.01 7134.53 N 5823.31W 6016540.75 N 545772.16 E 6259.53 7188.84 N 5870.39W 6016594.74 N 545724.70 E 6321.77 7242.81N 5917.45W 6016648.38 N 545677.26 E 6387.29 7292.89 N 5960.98W 6016698.16 N 545633.40 E 6456.91 7339.47 N 6001.33W 6016744.45 N 545592.72 E 6530.89 7383.01N 6038.30W 6016787.74 N 545555.45E 6607.51 7422.82 N 6072.05W 6016827.31N 545521.42 E 6684.03 7456.43 N 6102.27W 6016860.72 N 545490.97E 6768.07 7487.95 N 6131,05W 6016892.03 N 545461.98 E 6851.00 7516.47 N 6156.55W 6016920.38 N 545436.28 E 6936.90 7544.80 N 6182.28W 6016948.53 N 545410.35 E 7021.02 7571.73 N 6207.55W 6016975.29 N 545384.89 E 7106.53 7599.05 N 6233.12W 6017002.43 N 545359.14 E 7153.60 7613.91N 6247.04W 6017017.19 N 545345.12 E 7196.91 7627.39 N 6259.79W 6017030.58 N 545332.27 E 1.016 0.649 3.069 2.613 0.875 4.233 3.292 2.915 2.725 3.006 4.113 3.679 4,628 3.807 3.867 4.520 3.579 1.065 0.847 0.197 0.236 0.913 0.000 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 8560.95 8645.08 8727.77 8809.78 8890.96 8973.03 9053.07 9132.51 9209.33 9281.18 9352.76 9419.08 9480.69 9537.80 9589.98 9635.14 9677.76 9715.98 9754.21 9791.06 9828.39 9848.71 9867.22 Last Survey Station Projected Survey Continued... DrillQuest 1.05,04e 24 August, 2000 - 12:59 - 7- Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: AP1-500292296400 Surveyed: 9 AugUSt, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPI All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPI-09. Northings and Eastings are relative to MPI-09. Magnetic Declination at Surface is 26.579° (21-Aug-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPI-09 and calculated along an Azimuth of 320.624° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13094.00ff., The Bottom Hole Displacement is 9867.22ft., in the Direction of 320.624° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 394.93 394.82 5.46 N 2.49 E Tie-on to PGSS 13046.88 7153.60 7613.91 N 6247.04 W Last Survey Station 13094.00 7196.91 7627.39 N 6259.79 W Projected Survey Continued... -8- DrillQuest 1.05.04e 24 August, 2000- 12:59 Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: AP1-$00292296400 Surveyed: 9 August, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPI Survey tool program From Measured Vertical Depth Depth (ft) 0.00 0.00 486.28 485.97 To Measured Depth (ft) 486.28 13094.00 Vertical Depth (ft) 485.97 7196.91 Survey Tool Description AK-2 BP_CG MWD Magnetic 24 August, 2000 - 12:59 - 9 - DrillQuest 1.05.04e North Slope Alaska Alaska State.. Plane 4 Milne Point MPI MPI-09 Surveyed: 9 August, 2000 SURVEY REPORT 21 August, 2000 Your Reft API.500292296400 Surface Coordinates: 6009446.72 N, 551644.73 E (70° 26' 11.6006" N, Kelly Bushing: 62.25ft above Mean Sea Level 149° 34' 44.1541" W) A IIAI~IBITRTON CON. ANY Survey Ref: svy9530 Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (fi) Dogleg Rate (°/lOOft) Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment MP~09 PGSS 0.00 o.000 0.000 -62.25 o.oo 119.o0 0.350 278.000 56.75 119.0o 205.00 0.620 20.270 142.75 205.00 302.90 1.47o 35.630 240.63 302.88 394.93 3.490 28.730 332.57 394.82 o.o0 N 0.00 E 0.05 N 0.36 W 0.52 N 0.46 W 2.04 N 0.46 E 5.46 N 2.49 E 6009446.72 N 551644.73E 6009446.77 N 551644.37E 6009447.24 N 551644.27 E 6009448.76 N 551645.17 E 6009452.19 N 551647.18 E 0.294 0.900 0.907 2.215 0.00 0.27 0.70 1.26 2.54 Tie-on to PGSS MPI-09 486.28 4.150 26.330 423.72 485.97 578.52 7.250 32.380 515.49 577.74 668.87 7.420 22.960 605.10 667.35 758.98 9.050 12.710 694.29 756.54 852.08 9.790 7.110 786.13 848.38 944.65 9.170 351.580 877.45 939.70 1036.78 9.790 336.540 968.34 1030.59 1129.55 10.810 318.720 1059.63 1121.88 1222.13 11.850 314.430 1150.41 1212.66 1315.69 14.450 316.270 1241.51 1303.76 1408.23 14.770 317.170 1331.06 1393.31 1499.16 16.400 321.990 1418.65 1480.90 1593.41 20.530 325.160 1508.03 1570.28 1686.57 23.380 325.380 1594.42 1656.67 1778.76 26.050 324.260 1678.16 1740.41 10.86 N 5.29 E 18.77 N 9.89 E 28.95 N 15.22 E 41.23 N 19.05 E 56.22 N 21.64 E 71.33 N 21.53 E 85.78 N 17.34 E 99.56 N 8.46 E 112.74 N 4.06W 127.90 N 18.99W 144.89 N 34.99W 163.51N 50.78W 187.57N 68.42W 216.19 N 88.26W 247.68 N 110.48W 6009457.61N 551649.95 E 6009465.55 N 551654.49 E 6009475.78 N 551659.75 E 6009488.08 N 551663.49E 6009503.09 N 551665.98 E 6009518.20 N 551665.77 E 6009532.62 N 551661.48 E 6009546.34 N 551652.50 E 6009559.43 N 551639.89 E 6009574.49 N 551624.86 E 6009591.37 N 551608.74 E 6009609.88 N 551592.82 E 6009633.81N 551575.01E 6009662.30 N 551554.98 E 6009693.63 N 551532.54 E O.743 3.419 1.343 2.428 1.264 2.834 2.763 3.59O 1.445 2.814 0.424 2.288 4.508 3.061 2.940 4.84 7.88 12.18 19.04 28.78 40.35 54.07 70.32 88.47 109.69 133.00 157.41 187.17 221.82 260.20 AK-6 BP_IFR-AK Continued... 21 August, 2000- 12:17 -2- DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings. (fi) (ft) (ft) 1871.89 29.960 323.030 1760.37 1822.62 1964.92 33.620 323.660 1839.43 1901.68 2058.02 36.590 321.890 1915.59 1977.84 2150.74 38.970 320.250 1988.87 2051.12 2243.10 42.840 318.970 2058.66 2120.91 2336.09 45.080 319.330 2125.59 2187.84 2428.89 45.770 320.380 2190.73 2252.98 2521.25 48.280 320.660 2253.68 2315.93 2614.74 51.410 320.770 2313.96 2376.21 2707.73 53.300 321.100 2370.75 2433.00 2799.49 53.240 321.430 2425.63 2487.88 2892.07 56.390 321.330 2478.97 2541.22 2987.25 58.910 320.700 2529.90 2592.15 3077.05 59.640 320.020 2575.78 2638.03 3173.01 62.810 319.350 2621.96 2684.21 3265.93 62.990 319.350 2664.29 2726.54 3358.12 66.020 318.750 2703.97 2766.22 3450.63 66.910 318.690 2740.91 2803.16 3540.91 67.940 317.790 2775.57 2837.82 3635.64 68.670 319.050 2810.59 2872.84 3727.33 66.010 319.860 2845.91 2908.16 3819.34 66.590 319.150 2882.89 2945.14 3914.32 67.280 319.520 2920.10 2982.35 4007.15 66.630 319.230 2956.44 3018.69 4100.34 66.460 318.940 2993.53 3055.78 Global Coordinates Northings Eastings (ft) (ft) 282.88 N 136o42W 6009728.64 N 551506.36 E 322.19 N 165.66W 6009767.76 N 551476.84E 364.80 N 198.06W 6009810.14 N 551444.14 E 408.97 N 233.77W 6009854.06 N 551408.13 E 455.00 N 272.97W 6009899.82 N 551368.62 E 503.83N 315.18W 6009948.35 N 551326.06 E 554.36 N 357.80W 6009998.59 N 551283.10 E 606.51N 400.76W 6010050.45 N 551239.78E 661.82 N 445.99W 6010105.43 N 551194.16 E 718.98 N 492.39W 6010162.28 N 551147.37E 776.35 N 538.41W 6010219.32 N 551100.96 E 835.46 N 585.63W 6010278.10 N 551053.33 E 897.95 N 636.22W 6010340.24 N 551002.31E 957.39 N 685.46W 6010399.34 N 550952.65 E 1021.51N 739.88W 6010463.09 N 550897.79 E 1084.27 N 793.77W 6010525.47 N 550843.47E 1147.11N 848.30W 6010587.93 N 550788.50 E 1210.85 N 904.26W 6010651.28 N 550732.11E 1273.03 N 959.78W 6010713.07 N 550676.16 E 1338.87 N 1018.19W 6010778.51N 550617.29 E 1403.16 N 1073.19W 6010842.41N 550561.85 E 1467.22 N 1127.90W 6010906.10 N 550506.69 E 1533.51N 1184.85W 6010971.99 N 550449.29 E 1598.34 N 1240.46W 6011036.44 N 550393.23E 1662.95 N 1296.45W 6011100.65 N 550336.79 E Dogleg Rate (°/100fi) 4.244 3.950 3.372 2.786 4.287 2.424 1.097 2.727 3.349 2.052 0.296 3.404 2.706 1.041 3.360 0.194 3.339 0.964 1.466 1.456 3.013 0.947 0.810 0.757 0.339 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 303.82 352.71 406.16 462.93 523.40 587.94 654.04 721.60 793.03 866.64 94o.15 1015.77 1096.15 1173.33 1257.43 1340.15 1423.35 1508.15 1591.49 1679.49 1764.09 1848.34 1935.73 2021.15 2106.63 Continued... 21 August, 2000 - 12:17 - 3, DrlllQuest 1.05. 04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 4192.47 66.990 318.640 3029.94 3092.19 4285.31 65.500 319.750 3067.34 3129.59 4378.88 66.020 320.560 3105.75 3168.00 4469.64 65.730 322.770 3142.85 3205.10 4565.00 64.600 323.280 3182.90 3245.15 4657.99 65.580 323.320 3222.07 3284.32 4748.82 63.680 323.530 3260.99 3323.24 4841.76 63.470 323.870 3302.35 3364.60 4935.09 63.450 323.500 3344.05 3406.30 5027.79 62.600 323.800 3386.10 3448.35 5120.66 62.620 324.020 3428.82 3491.07 5213.59 62.710 323.480 3471.50 3533.75 5305.85 64.010 322.860 3512.86 3575.11 5399.02 63.680 321.490 3553.93 3616.18 5491.78 64.300 321.500 3594.61 3656.86 5585.22 65.440 319.720 3634.29 3696.54 5677.68 65.820 316.770 3672.45 3734.70 5770.37 65.440 318.670 3710.70 3772.95 5863.26 65.350 319.200 3749.38 3811.63 5955.12 64.830 319.730 3788.07 3850.32 6048.77 64.400 320.090 3828.22 3890.47 6140.86 66.200 317.520 3866.70 3928.95 6235.36 68.190 317.240 3903.33 3965.58 6326.51 68.050 317.340 3937.30 3999.55 6418.61 68.560 317.580 3971.34 4033.59 Global Coordinates Northings Eastings (ft) (ft) 1726.62 N 1352.21W 6011163.93 N 550280.59 E 1790.93 N 1407.74W 6011227.86 N 550224.62 E 1856.44 N 1462.41W 6011292.99 N 550169.50 E 1921.40 N 1513.78W 6011357.59 N 550117.68 E 1990.54 N 1565.83W 6011426.37 N 550065.15 E 2058.16 N 1616.24W 6011493.64 N 550014.28 E 2124.06 N 1665.14W 6011559.20 N 549964.92 E 2191.14 N 1714.41W 6011625.94 N 549915.19 E 2258.42 N 1763.86W 6011692.87 N 549865.27 E 2324.96 N 1812.83W 6011759.07 N 549815.85 E 2391.59 N 1861.40W 6011825.36 N 549766.82 E 2458.16 N 1910.21W 6011891.60 N 549717.54 E 2524.17 N 1959.65W 6011957.26 N 549667.65 E 2590.23 N 2010.93W 6012022.96 N 549615.91E 2655.46 N 2062.83W 6012087.83 N 549563.56 E 2720.83 N 2116.52W 6012152.83 N 549509.42 E 2783.65 N 2172.60W 6012215.26 N 549452.91E 2846.11N 2229.40W 6012277.33 N 549395.68 E 2909.79 N 2284.88W 6012340.62 N 549339.76 E 2973.11N 2339.02W 6012403.56 N 549285.17 E 3037.84 N 2393.51W 6012467.91N 549230.24 E 3100.77 N 2448.62W 6012530.46 N 549174.70 E 3164.87 N 2507.60W 6012594.15 N 549115.27 E 3227.02 N 2564.97W 6012655.90 N 549057.47 E 3290.08 N 2622.83W 6012718.55 N 548999.18 E Dogleg Rate (°/lOOft) 0.648 1.942 0.965 2.245 1.281 1.055 2.102 0.398 0.355 0.961 0.211 0.525 1.532 1.367 0.668 2.113 2.935 1.912 0.528 0.771 0.576 3.201 2.123 0.184 0.604 Alaska State Plane 4 Milne pOint MPI Vertical Section (ft) Comment 2191.26 2276.23 2361.54 2444.31 2530.70 2614.86 2696.74 2779.75 2863.03 2945.44 3027.67 3110.00 3192.30 3275.84 3359.16 3443.74 3527.92 3612.31 3696.76 3780.07 3864.67 3948.32 4035.36 4119.88 4205.40 Continued... 21 August, 2000 - 12:17 - 4 - DrlllQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: AP1-$00292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 6504.48 68.210 317.020 4002.97 4065.22 6589.75 67.800 318.630 4034.91 4097.16 6682.07 67.230 316.320 4070.22 4132.47 6776.15 66.520 315.560 4107.17 4169.42 6868.31 65.740 315.070 4144.47 4206.72 6960.74 67.200 315.890 4181.37 4243.62 7053.46 68.110 317.130 4216.62 4278.87 7146.75 67.620 316.910 4251.77 4314.02 7238.48 68.460 318.590 4286.07 4348.32 7331.99 68.150 319.370 4320.64 4382.89 7424.40 67.710 321.280 4355.37 4417.62 7516.78 67.610 320.240 4390.48 4452.73 7610.31 67.750 320.120 4426.00 4488.25 7702.33 67.430 319.840 4461.08 4523.33 7795.86 67.350 319.440 4497.04 4559.29 7890.08 67.160 318.840 4533.47 4595.72 7984.14 66.910 318.010 4570.17 4632.42 8077.07 67.260 319.770 4606.35 4668.60 8169.16 68.470 320.580 4641.05 4703.30 8262.93 68.220 320.280 4675.66 4737.91 8356.01 68.130 320.010 4710.26 4772.51 8446.22 67.910 319.600 4744.02 4806.27 8539.30 67.670 319.410 4779.21 4841,46 8633.57 67.430 318.770 4815.21 4877.46 8726.77 66.870 317.910 4851.40 4913.65 3348.74 N 2676.97W : 6012776.85 N 548944.64 E 3407.34N 2730.05W 6012835.07 N 548891.15 E 3470.20 N 2787.70W 6012897.53 N 548833.07 E 3532.37 N 2847.87W 6012959.29 N 548772.47 E 3592.29 N 2907.13W 6013018.80 N 548712.80 E 3652.72 N 2966.54W 6013078.81N 548652.96 E 3714.93 N 3025.56W 6013140.61N 548593.52 E 3778.15 N 3084.47W 6013203.42 N 548534.17 E 3841.13 N 3141.67W 6013266.00 N 548476.54 E 3906.68 N 3198.69W 6013331.15 N 548419.06 E 3972.59 N 3253.37W 6013396.68 N 548363.93 E 4038.76 N 3307.41W 6013462.48 N 548309.43E 4105.22 N 3362.82W 6013528.55 N 548253.56 E 4170.37N 3417.53W 6013593.32 N 548198.41E 4236.16 N 3473.44W 6013658.72 N 548142.04 E 4301.88 N 3530.29W 6013724.05 N 548084.74 E 4366.66 N 3587.76W 6013788.44 N 548026.82 E 4431.15 N 3644.03W 6013852.53 N 547970.10 E 4496.67 N 3698.66W 6013917.67 N 547915.02 E 4563.85 N 3754.18W 6013984.46 N 547859.04 E 4630.18 N 3809.55W 6014050.41 N 547803.21E 4694.08 N 3863.54W 6014113.93 N 547748.78 E 4759.61N 3919.50W 6014179.08 N 547692.36 E 4825.46 N 3976.56W 6014244.52 N 547634.85 E 4889.62 N 4033.64W 6014308.29 N 547577.32 E Dogleg Rate (°/lOOfl) 0.731 1.816 2.393 1.059 0.976 1.777 1.579 0.569 1.930 0.843 1.974 1.047 0.191 0.447 0.404 0.621 0.855 1.785 1.546 0.399 0.286 0.487 0.320 0.677 1.041 Alaska State Plane 4 Milne Point MPI Vertical Section (fi) Comment 4285.16 4364.19 4449.42 4535.77 4619.81 4704.33 4789.96 4876.29 4961.32 5048.20 5133.82 5219.25 5305.77 5390.84 5477.18 5564.07 5650.65 5736.24 5821.54 5908.68 5995.08 6078.73 6164.91 6252,03 6337.89 Continued... 21 August, 2000 - 12:17 - 5 - DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl, Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8819.31 66.510 317.270 4888.02 4950.27 8912.08 66.350 316.460 4925.12 4987.37 9005.01 66.220 315.820 4962.49 5024.74 9096.78 65.800 315.270 4999.80 5062.05 9189.51 66.060 317.190 5037.63 5099.88 9280.49 66.380 318.490 5074.31 5136.56 9375.27 67.370 320.440 5111.54 5173.79 9471.04 68.930 321.780 5147.18 5209.43 9562.86 68.780 321.660 5180.31 5242.56 9655.29 68.560 321.690 5213.93 5276.18 9747.82 68.400 320.750 5247.87 5310.12 9841.10 68.520 320.020 5282.12 5344.37 9934.35 68.560 319.960 5316.23 5378.48 10026.60 68.780 320.370 5349.79 5412.04 10120.30 68.790 319.460 5383.70 5445.95 10213.80 66.810 318.960 5419.02 5481.27 10305.10 66.790 319.080 5454.99 5517.24 10398.40 67.200 318.190 5491.45 5553.70 10490.50 67.330 318.410 5527.05 5589.30 10584.00 67.220 317.110 5563.17 5625.42 10677.00 67.310 317.160 5599.11 5661.36 10769.40 67.460 317.120 5634.64 5696.89 10862.90 67.590 317.440 5670.38 5732.63 10954.10 65.690 317.230 5706.54 5768.79 11047.30 65.650 316.590 5744.94 5807.19 4952.37 N 4090.96W 6014370.64 N 547519.57 E 5014.42 N 4149.10W 6014432.29 N 547461.01E 5075.77 N 4208.05W 6014493.23 N 547401.63 E 5135.61N 4266.77W 6014552.66 N 547342.50 E 5196.75 N 4325.33W 6014613.39 N 547283.52 E 5258.47 N 4381.21W 6014674.72 N 547227.21E 5324.71N 4437.85W 6014740.57 N 547170.11E 5393.90 N 4493.65W 6014809.37 N 547113.84 E 5461.12 N 4546.70W 6014876.23 N 547060.32 E 5528.67 N 4600.10W 6014943.40 N 547006,46 E 5595.77 N 4654.01W 6015010.13 N 546952.08 E 5662.61N 4709.33W 6015076.58 N 546896.30 E 5729.08 N 4765.13W 6015142.67 N 546840.04 E 5795.07 N 4820.17W 6015208.27 N 546784.54E 5861.90 N 4876.42W 6015274.71N 546727.83 E 5927.44 N 4932.97W 6015339.85 N 546670.83 E 5990.79 N 4988.00W 6015402.82 N 546615.36 E 6055.24 N 5044.76W 6015466.88 N 546558.16 E 6118.66 N 5101.26W 6015529.91N 546501.22 E 6182.51N 5159.24W 6015593.35 N 546442.81E 6245.38 N 5217.59W 6015655.82 N 546384.02 E 6307.90 N' 5275.60W 6015717.94 N 546325.57E 6371.38 N 5334.22W 6015781.01N 546266.52 E 6432.94 N 5390.96W 6015842.17 N 546209.36 E 6494.96 N 5448.97W 6015903.79 N 546150.91 E Dogleg Rate (°/lOOft) 0.745 0.819 0.646 0.714 1.911 1.354 2.161 2.083 0.204 0.240 0.961 0.739 0.074 0.478 0.905 2.175 0.123 0.982 0.262 1.288 0.109 0.167 0.345 2.094 0.627 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 6422.83 6507.76 6592.69 6676.32 6760.84 6844.06 6931,21 7020.07 71o5.64 7191.69 7277.73 7364.49 7451.27 7537.19 7624.54 7711.10 7795.02 7880.88 7965.81 8052.00 8137.70 8222.92 8309.24 8392.90 8477.73 Continued... 21 August, 2000- 12:17 -6- DrlllQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 11140.20 65.480 315,950 5783.37 5845.62 11232.90 65.480 316.010 5821.84 5884.09 11324.90 63.720 312.930 5861.31 5923.56 11417.80 61.460 313.580 5904.07 5966.32 11510.40 61.830 313.970 5948.05 6010.30 11603.60 61.940 316.260 5991.98 6054.23 11695.60 58.950 318.070 6037.36 6099.61 11789.70 56.220 319.090 6087.79 6150.04 11883.60 53.680 319.440 6141.72 6203.97 11974.50 50.950 318.630 6197.28 6259.53 12069.40 47.060 318.840 6259.52 6321.77 12162.60 43.660 319.100 6325.00 6387.25 12255.60 39.370 318.870 6394.62 6456.87 12349.10 35.980 320.020 6468.61 6530.86 12441.80 32.550 318.590 6545.22 6607.47 12530,70 28.600 316.720 6621.74 6683.99 12625.00 25.240 317.520 6705.81 6768.06 12716.30 24.290 318.220 6788.71 6850.96 12810.30 23.750 316.880 6874.57 6936.82 12902.20 23,660 316.670 6958.72 7020.97 12995.60 23.600 316.570 7044.29 7106.54 13046.80 23.190 316.110 7091.28 7153.53 13046.88 23.190 316.110 7091.35 7153.60 13094,00 23.190 316.110 7134.67 7196.92 6556.07 N 5507.44W 6015964.50 N 546092.03 E 6616.72 N 5566.04W 6016024.74 N 546033.00E 6674.94 N 5625.33W 6016082.55 N 545973.32 E 6731.45 N' 5685.39W 6016138.63 N 545912.86 E 6787.82 N 5744.23W 6016194.60 N 545853.63 E 6846.06 N 5802.23W 6016252.44 N 545795.23 E 6904.72 N 5856.65W 6016310.72 N 545740.41E 6964.28 N 5909.20W 6016369.91N 545687.44E 7022.52 N 5959.37W 6016427.80 N 545636.88 E 7076.84 N 6006.52W 6016481.80 N 545589.35 E 7130,67 N 6053,75W 6016535.30 N 545541.75 E 7180.68 N 6097.28W 6016585.01N 545497.87 E 7227.19 N 6137.72W 6016631.23 N 545457.11 E 7270.58 N 6174.89W 6016674.37 N 545419.65 E 7310.16 N 6208.89W 6016713.71N 545385.37 E 7343.61N 6239.31W 6016746.94 N 545354.72 E 7374.87 N 6268.37W 6016778,01N 545325,45 E 7403.23 N 6294.02W 6016806.19 N 545299,59 E 7431.47N 6319.84W 6016834.25 N 545273,58 E 7458.39 N 6345,15W 6016860.99 N 545248,09 E 7485.60 N 6370.86W 6016888,02 N 545222.19 E 7500.31N 6384.90W 6016902.63 N 545208.05 E 7500.33 N 6384.92W 6016902.66 N 545208.03 E 7513.70 N 6397.78W 6016915.94 N 545195.07 E Dogleg Rate (°ll00ff) 0.653 0,059 3,578 2.511 0.545 2.17o 3.673 3.042 2.722 3.085 4.102 3.653 4.616 3.703 3.800 4.570 3.584 1.089 0.817 0.134 0.077 0.877 0.000 o.o00 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 8562.17 8646.34 8729.1o 8811.06 8892.13 8974,o8 9054.02 9133.44 9210.30 9282.22 9353.83 9420.13 9481.76 9538.89 9591.o7 9636.25 9678.90 9717.13 9755:36 9792.27 9829.65 9849.95 9849.98 9868.50 Last Survey Station Pmjecled Survey Continued.., 21 August, 2000- 12:17 - 7- DrlllQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API.500292296400 Surveyed: 9 August, 2000 North Slope Alaska All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPI-09. Northings and Eastings are relative to MPI-09. Magnetic Declination at Surface is 26.579° (21-Aug-O0) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPI-09 and calculated along an Azimuth of 319.586° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13094.00ft., The Bottom Hole Displacement is 9868.50ft., in the Direction of 319.586° (True). Alaska State Plane 4 Milne Point MPI Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (fi) (ft) (fi) 394.93 394.82 5.46 N 2.49 E Tie-on to PGSS 13046.88 7153.60 7500.33 N 6384.92 W Last Survey Station 13094.00 7196.92 7513.70 N 6397.78 W Projected Survey Continued... DrlllQuest 1.05.04e 21 August, 2000- 12:17 -8- Sperry-Sun Drilling Services Survey Report for MPI-09 Your Ref: API-500292296400 Surveyed: 9 August, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPI Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 486.28 485.97 To Measured Depth (ft) 486.28 13094.00 Vertical Depth (ft) 485.97 7196.92 Survey Tool Description AK-2 BP_CG AK-6 BP_IFR-AK 21 August, 2000 - 12:17 - 9 - DrlllQuest 1.05.04e STATE OF ALASKA ALASK,~ L AND GAS CONSERVATION COMI~~ APPLICATION FOR SUNDRY APPROVAL ~ION 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] 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 2331' NSL, 3725' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 4506' NSL, 4735' WEL, SEC. 29, T13N, R10E, UM (As Planned) At effective depth 4543' NSL, 4846' WEL, SEC. 29, T13N, R10E, UM At total depth 4543' NSL, 4846' WEL, SEC. 29, T13N, R10E, UM 5. Type of well: I~! Development I-I Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) Plan KBE = 29.5' 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-09 9. Permit Number 200-103 10. APl Number 50- 029-22964-00 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 13094 feet Plugs (measured) 7197 feet 13094 feet Junk (measured) 7197 feet Length Size 112' 6534' ORIGINAL Cemented MD TVD 112' 112' 6562' 4087' 20" 260 sx Arcticset (Approx.) 9-5/8" 840 sx Arcticset 3-Lite, 385 sx 'G' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation August 9, 2000 16. proposal was Tom Maunder verbally app rovede/F~ Name of approver 8/9/2000 Date Approved Contact Engineer Name/Number: Steve Shultz, 564-5491 15. [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 7. I hereby certify that the f~is trod co2~ct to the best of my knowledge Signed Steve Shultz ,,,/~ / tmon, ~t~) ~4/'~ Title Senior Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness Approval No. Plug integrity '~ BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required lO- Approved Copy Approved by order of the Commission ~D,,-, Returrled Commissioner Form 10-403 Rev. 06/15/88 D Taylor Seamount ............. 3o0-2oV Dare'IISi/3 Submit Ih'Tril~licate Hubble, Terrie L (NANA) From: Sent: To: Subject: Shultz, Steve M (ARCO) Thursday, August 10, 2000 10:21 AM Hubble, Terrie L (NANA) 403 for 1-09 Terrie, We are going to plug back MPI-09 and complete in the Schrader Bluff. Could you please work up a 403 with the following data. 9 5~8" shoe at 6561' 8 1/2" hole to 13.094' Top of Kuparuk at 12,772' Thanks Steve , 2. 3. 4. 5. . 7. 8. 9. 10. RIH with open ended drill pipe to TD Spot cement from 13,094' TD to 12,672' (100' over Kupa.ruk) POOH ¢: "~"~,~ ~,.~ ~',,'~ RIH with 9 5/8" retainer and set at +/-6550 (";'""'"~"~ ~"~\'"1 Establish injection and pump 10 bbls of water followed by 15 bbls of cement ~~o~~ Change 9 5/8" casing over to seawater POOh ~%~ ~~~ Run CBL from retainer back to su~ace ~ Run 9 5~8" permenant packer on 2 7~8" tubing Land tubing, NU X-mas tree Page I 1-09i ~1 2.75" X nipple (2.313" ID) at 2000 ft 2 7/8" 6.5 ppf, L-80 tubing 9 5/8", 40#, L-80 Csg ',l~i i ii~ I 2 7/8"X nipple (2.313" ID) I jt above packer Baker hydraulic set packer @ +~-5690' 2 7~8" XN' nipple ( 2.205" no-go) 1 jt below packer 2 7~8" WLEG @+/- 5750 j ~ ~ ~ · 9 5/8" Bridgeplug +~-6560' TOC @ +/-12,572' 13,094' M DTD DATE REV. BY COMMENTS MILNE POINT UNIT 8/10/00 SMS Completion in Schrader Bluff Proposed Tract 14 injector completion BP EXPLORATION (AK) MPU 1-09 Drilling Permit, Subject: MPU 1-09 Drilling Permit, C7~O (~) '-' I (,~ ~ Date: Thu, 27 Jul 2000 17:11:27 -0500 From: "Miller, Mike E" <MillerME~BP.com> To: "'blair_wondzell~admin. state.ak.us'" <blair_wondzell~admin. state.ak.us> CC: "Gunkel, Fritz" <GunkelFP~BP.com>, "Mallary, Chuck (ARCO)" <MallarCR~BP.com>, "Cooper, Katrina N" <CooperKN~BP.com>, "Triolo, Mike T" <TrioloMT~BP.com> Blair, this is to follow-up our conversation regarding the frac of Milne Point Unit 1-09 well and the Drilling Permit. As we discussed, during normal frac process, pressures will not reach the maximum allowable of 80% of Burst rating for the 7" casing. Maximum pressures could be realized in the event of a screenout. If the frac screens out AND the operator does not shut the pumps down quickly, pressures nearing burst for the 7" could be realized. But the risk of this pressure on the 7" casing is mitigated by annulus pressure monitoring and control: * with the 4-1/2" frac string and no packer, annulus pressures can be monitored during the job - indicating screenout potential before actual screenout. This allows the operator to maintain pump control. * the tubing and tubing-casing annulus are tested for communication PRIOR to pumping the frac. This ensures that all valves are open and that there is no ice plug or blockage in the tubing-casing annulus. * A 3" pop-off valve is installed on the annulus. This valve is tested in the shop just prior to the job. The pop-off is set at 4300 psi, which is. well below the maximum allowable pressure of 5792 psi (which is 80% of 7240 psi burst pressure). We feel that these controls adequately mitigate the risk of excessive pressure on the casing. The frac procedure will include these assurance steps of ensuring communication and annulus pop-off. Thank you for bringing this to our attention as it gave us an opportunity to have the whole team look closely at the frac process and procedure. thanks >From Blair to Fritz 7/25/00: > Good Morning Fritz, > The Permit To Drill program for MPU well No. i9 calls for 7' 26 lb L > casing, running a 4.5' frac string, and fracing the well. Move off the > drill rig. > Then move in the workover rig, pull the 4.5', clean out and run the ESP > completion. > We are concerned about fracing the well with no packer. > Estimated spud date has been moved up to this weekend. > What do you think. > Regards, Blair Wondzell Mike Miller BP Alaska Drilling/Wells Drilling Superintendent office: 907-564-5066 cell/pager: 907-240-8066 fax: 907-564-5193 millerme@bp.com Connect: http://connect.bpweb.bp.com/search/record.asp?IDN=57490 1 of 1 7/27/00 2:44 PM MPU 1-09 Drilling Permit, Subject: MPU 1-09 Drilling Permit, Date: Thu, 27 Jul 2000 17:11:27-0500 From: "Miller, Mike E" <MillerME@BP.com> To: "'blair_wondzell~admin. state.ak.us'" <blair_wondzell~admin.state.ak.us> CC: "Gunkel, Fritz" <GunkelFP~BP.com>, "Mallary, Chuck (ARCO)" <MallarCR~BP.corn>, "Cooper, Katrina N" <CooperKN~BP.com>, "Triolo, Mike T" <TrioloMT~BP.com> Blair, this is to follow-up our conversation regarding the frac of Milne Point Unit 1-09 well and the Drilling Permit. As we discussed, during normal frac process, pressures will not reach the maximum allowable of 80% of Burst rating for the 7" casing. Maximum pressures could be realized in the event of a screenout. If the frac screens out AND the operator does not shut the pumps down quickly, pressures nearing burst for the 7" could be realized. But the risk of this pressure on the 7" casing is mitigated by annulus pressure monitoring and control: * with the 4-1/2" frac string and no packer, annulus pressures can be monitored during the job - indicating screenout potential before actual screenout. This allows the operator to maintain pump control. * the tubing and tubing-casing annulus are tested for communication PRIOR to pumping the frac. This ensures that all valves are open and that there is no ice plug or blockage in the tubing-casing annulus. * A 3" pop-off valve is installed on the annulus. This valve is tested in the shop just prior to the job. The pop-off is set at 4300 psi, which is well below the maximum alloWable pressure of 5792 psi (which is 80% of 7240 psi burst pressure). We feel that these controls adequately mitigate the risk of excessive pressure on the casing. The frac procedure will include these assurance steps of ensuring communication and annulus pop-off. Thank you for bringing this to our attention as it gave us an opportunity to have the whole team look closely at the frac process and procedure. thanks >From Blair to Fritz 7/25/00: > Good Morning Fritz, > The Permit To Drill program for MPU well No. i9 calls for 7' 26 lb L > casing, running a 4.5' frac string, and fracing the well. Move off the > drill rig. > Then move in the workover rig, pull the 4.5', clean out and run the ESP > completion. > We are concerned about fracing the well with no packer. > Estimated spud date has been moved up to this weekend. > What do you think. > Regards, Blair Wondzell Mike Miller BP Alaska Drilling/Wells Drilling Superintendent office: 907-564-5066 cell/pager: 907-240-8066 fax: 907-564-5193 millerme@bp.com Connect: http://connect.bpweb.bp.com/search/record.asp?IDN=57490 I of 1 7/27/00 2:44 PM /IPU 1-09 Drilling Permit, ~Oo - l c) 2 Subject: MPU 1-09 Drilling Permit, Date: Thu, 27 Jul 2000 17:11:27 -0500 From: "Miller, Mike E" <MillerME~BP.com> To: "'blair_wondzell~admin. state.ak.us'" <blair_wondzell~admin.state.ak.us> CC: "Gunkel, Fritz" <GunkelFP~BP.com>, "Mallary, Chuck (ARCO)" <MallarCR~BP.com>, "Cooper, Katrina N" <CooperKN~BP.com>, "Triolo, Mike T" <TrioloMT~BP.com> Blair, this is to follow-up our conversation regarding the frac of Milne Point Unit 1-09 well and the Drilling Permit. As we discussed, during normal frac process, pressures will not reach the maximum allowable of 80% of Burst rating for the 7" casing. Maximum pressures could be realized in the event of a screenout. If the frac screens out AND the operator does not shut the pumps down quickly, pressures nearing burst for the 7" could be realized. But the risk of this pressure on the 7" casing is mitigated by annulus pressure monitoring and control: * with the 4-1/2" frac string and no packer, annulus pressures can be monitored during the job - indicating screenout potential before actual screenout. This allows the operator to maintain pump control. * the tubing and tubing-casing annulus are tested for communication PRIOR to pumping the frac. This ensures that all valves are open and that there is no ice plug or blockage in the tubing-casing annulus. * A 3" pop-off valve is installed on the annulus. This valve is tested in the shop just prior to the job. The pop-off is set at 4300 psi, which is well below the maximum allowable pressure of 5792 psi (which is 80% of 7240 psi burst pressure). We feel that these controls adequately mitigate the risk of excessive pressure on the casing. The frac procedure will include these assurance steps of ensuring communication and annulus pop-off. Thank you for bringing this to our attention as it gave us an opportunity to have the whole team look closely at the frac process and procedure. thanks >From Blair to Fritz 7/25/00: > Good Morning Fritz, > The Permit To Drill program for MPU well No. i9 calls for 7' 26 lb L > casing, running a 4.5' frac string, and fracing the well. Move off the > drill rig. > Then move in the workover rig, pull the 4.5', clean out and run the ESP > completion. > We are concerned about fracing the well with no packer. > Estimated spud date has been moved up to this weekend. > What do you think. > Regards, Blair Wondzell Mike Miller BP Alaska Drilling/Wells Drilling Superintendent office: 907-564-5066 cell/pager: 907-240-8066 fax: 907-564-5193 millerme@bp.com Connect: http://connect.bpweb.bp.com/search/record.asp?IDN=57490 1 of 1 7/31/00 1:21 PM JUL-27~O0 Tttli OS:04 ?H AOGC~ P. 002 ?, 08/10 ALASUA OIL AB]I) CONIBRYATIOI CO~I~[ISSION Chuck MnJlary Senior Drilling Enginecr BP Exploration (Alaska) 1nc, P 0 Box 196617. Anchorage, Ag 99519-6612 /,' tony A"NOW~S, P~O¥~RNO~ 3001 POI~OUPtNE, DI?,VE ANCHORAQE, ^L/~,K/~, 79501.3192 PI,.ION;:; (907) 279-M33 ~Ax: ~07) ~,z6-7642 Milno Point 'Unit MFi-(}9 BP 'Exploration (Alaska) lac, Permit No: 200-103 Sur. Loc, 2331'NSL, 3725'WEL, gee. 33, TI3N, RIOE, tim Blmhol¢ Leo. 4516'NSL, 4793'WPL7 Sea. 29, TI3N, RIOE, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill th~ above retraced ,sell, Thc permit to drill does not exmnpl you from ubtaining additional p0tmits required by law from oUIcr governmenlal agencies, ~md does not authorize conducting drilling operations tmtil all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tgsted in accordanco with 20 AAC 25.035; and thc mechanical intcgrity (MI) ofthc in. jeetion wells must bo demonstrated under 20/LAC 25.412 and 20 AAC 25.030(§){3). Sutticient notice (approximately 24 hours) or ~ M1 test before operation, and of th~ BO, PE test performed before drilling below the surface casing shoe, must bc given so that a representative of risc Commission may wimoss thc tosts, Notice may be given by contacting thc CommJssio~ petroleum field inspector on the Norlh Slope pager at 659-3607, Daniel T. Seamounl, Jr. s,;omm~ssmner BY ORDER OF 'FH.E CO'MMISSlON .DATED this '~ ~' ~ day er July, 2000 dlf/En¢los,rcs ¢¢: Departmenl offish & Game, Habltal $~tion w/o end. Oel~Ithm,'nl of Envirofl~tlo~]lal Cottservation w/o oriel. STATE OF ALASKA ALASL, OIL AND GAS CONSERVATION COI~.,,,SSION PERMIT TO DRILL 20 AAC 25.005 Ila Ddll r'l Reddll 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 29.5' Milne Point Unit / Kuparuk 3. Address 6. Property Designation ~,~-~' River Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 oz~'~o4~,, ~b 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2331' NSL, 3725' WEL, SEC. 33, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 4506' NSL, 4735' WEL, SEC. 29, T13N, R10E, UM MPI-09 Number 2S100302630-277 At total depth 9. Approximate spud date 4576' NSL, 4793' WEL, SEC. 29, T13N, R10E, UM 08/05/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025515, 704' MDI No Close Approach 2560 13074' MD / 7253' TVD/BKB ! 6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 67.28 ° Maximum surface 2820 p$ig, At total depth ('I'VD) 6810' / 3500 psig 18. Casing Program Specifications Setting Depth Size Top Bottom , Quantity of Cement Hole Casinq Weiqht Grade Couplina Lenqth MD TVD MD TVD (include staqe data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' ;~60 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTRC 6373' 31' 31' 6404' 4059' 883 sx Arctic Set 3-Lite~ 348 sx 'G' 8-1/2" 7" 26# L-80 BTRC 13044' 30' 30' 13074' 7253' 141 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production ~'~ ~{~,~,~ ~ .... Liner ORIGINAL Perforation depth: measured Alaska 0ii & Gas Co~s. Common true vertical A~chorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Shultz, 564-5491 Prepared By Name/Number: Terrie Hubble, 564-4628 Signed Chuck Ma,ary/llll~l--~l,/~-~r fL, ! ¢~,,,....--~' Title Senior Drilling Engineer Date ~" po rm it N,,~)~:) _/4~:)~_~ 5~PlNumber L/ ~1:~.~ a2 ~ See cover letter . (~..~.. ~___~'~,, 4~- ~ ~) for other requirements Conditions of Approval: Samples Required [] Yes I~1 No Mud Log Required r'l Yes I~1 No Hydrogen Sulfide Measures [] Yes J~ No Directional Survey Required IRI Yes [] No Required Working Pressure for DOPE [] 2K; [] 3K; [] 4K; I~! 5K; [] 10K; [] 15K Other: '~5(~~, ~(~'~'¥e._~.~ ORiGiNAL .~JGNED BY by order of Approved, By F~ Tavjgr Seamount Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: I MPI-09 Well Plan Summary RECE!VED JUL 1 '/200 Alaska 0i! & Gas Cons. Commission Anchorage Type of Well (producer or injector): I Kuparuk Producer Surface Location: Target Location: Bottom Hole Location: 2331 NSL 3725 WEL Sec 33 T13N R10E UM. AK. 4506 NSL 4735 WEL Sec 29, T13N R10E UM. AK 4576' NSL 4793 WEL Sec 29, T13N R10E UM. AK AFE Number: 1337188 Estimated Start Date: I 8/05100 [Rig: I Doyon#141 Operating days to complete: 1 22 MD: 113074' I ITvD: Well Design (conventional, slimhole, etc.): 17253' bkb I IKBE: I29.5, Milne Point Slimhole 7LS Formation Markers: Formation Tops MD TVD (bkb) EMW and Formation Pressure base permafrost 2000 1800 8.4 ppg, 786 psi Schrader NA 6121 3738 8.4 ppg, 1633 psi Seabee Shale 6404 3995 8.4 ppg, 1745 psi' Top of HRZ 12119 6328 8.4 ppg, 2764 psi Bottom of HRZ 12250 6430 8.4 ppg, 2808 psi MK-19 12356 6520 8.4 ppg, 2848 psi TKUD 12506 6656 9.1 ppg, 2907 psi Kuparuk C Not Present Kuparuk B 12670 6810 9.6 ppg, 3399 psi Kuparuk A 12802 6934 9.6 ppg, 3462 psi TKA3 12812 6943 9.6 ppg, 3466 psi TKA2 12841 6970 9.6 ppg, 3479 psi TKA1 12908 7033 9.6 ppg, 3511 psi Miluveach 12924 7048 9.6 ppg, 3518 psi Total Depth 13074 7253 Casing/Tubing Program Hole Size Csgl Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 6373 31/31 6404/4059 8 1/2" 7" 26# L-80 btrc 13044 30/30 13074?7253 2 7~8" 6.5# L-80 8rd 12000 30/30 1200076350 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 6810'TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3500 psi is 2820 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: JOpen Hole Logs: Surface Intermediate Final MWD Directional and Gr/Res (CDR) N/A PDC Bit f/Seabee to TD w/MWD Dir and LWD GrlReslDenlNeu and PWD. Mud Program: ISpecial design considerations I None- SPUD MUD Su~ace Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 1 O0 35 15 30 10 15 Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Cementing Program: Calculated from 6404 to Surface 9 5/8", 40# Casing in 12 ¼" Hole Type Excess Volume Yield Sx Lead in Permafrost Arctic Set 3-Lite 12.0 ppg 250% 1721 ft3 4.43 ft3/sk 389 Lead in Open Hole Arctic Set 3-Lite 12.0 ppg 30% 1303 ft3 4.43 ft3/sk 294 Tail Class "G" 15.8 ppg 30% 407 ft3 1.17 ft3/sk 348 Callculated from 13074'-12074' 7", 26# Casing in 8 %" Hole r I Type I Excess I Volume, Yield , Sx , Tail Class"G" 15.8 ppg 30% I 165 I 1.17 I 141 I Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Formation pressures seen in this area do not exceed 3500 psi pore pressure and with a column of gas to surface from 6810' TVD(gradient of .1 ppg) the maximum surface pressure would be 2820 psi. Therefore, the BOPE equipment will be tested to a maximum of 3500 psi. Kick Tolerance: The kiCk tolerance analysis shows that with a 9.6 ppg pore pressure at the "A" sands (6934' TVD), a 100 psi overbalance and a 12,2 ppg weak point pressure at the shoe of the 9 5/8" casing the well can tolerate a 50.0 bbl kick while drilling the Kuparuk formation. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I 300', build to 67°(~2.5°/100', hold to 11567', drop I J to 20° at 5.7°/100' and hold to TD of 13,074' I I Maximum Hole Angle: . I 67.28u I Close Approach Wells: I None I Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at Drill Site 4. The Milne Point reserve pit can be opened in emergencies by notifying (Julie Arin 659-4650) with request. Fluid Handling: All drilling and completion fluids will be taken to drill site 3. RECE: v:D JUL 1 1 200) AJaska Oi! & Gas C~s, Commission Aqchor~e Drilling Discussion The purpose of this section of the well plan is to explain the well objective, point out potential problem areas, and highlight lessons learned on the previous wells. Well Objective: This well is planned as a Kuparuk A1 sand producer. The 9-5/8" surface casing is being set deep through the Shrader Bluff Formation -- if the Kuparuk sands are wet, the well will be completed as a Schrader Bluff producer or injector based on the MWD logs results. Geolo_clv Well 1-09 is planned as a conventional producer in an untested Kuparuk fault block, The key risks are fault seals and oil charge. The MPI-09 fault block lies between the current Kuparuk J-pad development wells to the north and the N-pad wells to the south. Success on this well requires a fault seal between the MPI-09 well location and the N-pad wells updip to the south; as well as oil migration into_the block.. Variable oil-water contacts between separate fault blocks are common at Milne Point. Rick on this well in finding trapped hydrocarbons is probably about 1 in 3. ~. Drilling Hazards and Risks: Formation pressures are expected to be in the normal range for Mi/ne (3500 psi) as indicated from offset well data on MPN-01 and MPJ-18, reservoir pressure is estimated at 3500 psi at 6810 feet in the Kuparuk formation No major faults will be crossed with this we//bore There are no close approach issues on this well for directional Lost circulation is a possibility on surface while running casing and cementing, but in the production interval there is sufficient reservoir pressure to mitigate the possibility of having mud losses. Differential sticking concerns can exist in the surface interval with the Schrader Bluff sands and others exposed. Normal precautions should be employed. Differential sticking concerns are reduced in the production interval due to pore pressure being sufficient as to not cause a differential from the mud column to the formation. As can be seen from the mud section there is the possibility that we may have to raise the mud weight to 10. 4 ppg. In the event this were to happen the additional mud weight along with the frictional forces in the annulus would elevate the ECD while drilling and could initiate we//bore breathing problems. In this case flowrates, rheologies and mud sweeps would be worked in order to keep the breathing at a minimum. ~::~,~-_ ~'% ~,,~, .¢~ir~ JUL 1 'i _POOD Gas Cons. ~mmission . 2. 3. 4. o . 8. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. MPI-09 Proposed Summary of Operations Prepare location for rig move. MIRU Doyon #141 drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan to 6404 and run and cement 9-5/8" casing. Run only Dir MWD and LWD CDR (Gr/Res). ND 20" Diverter, NU and Test 9-5/8" BOPE. MU 8 %" bit on a motor with MWD/LWD (GRIP, es,New, Dens) and PWD, RIH, Drill out FE and 20' of new formation -- Perform LOT to a minimum of 12.5 ppg. Drill 8 %" hole directionally to 13,074' MDTD and Run and Cement 7" casing. PU and RIH with 12,000' of 4 %" frac string Freeze Protect Top 2000' of tubing and annulus with diesel. ND BOPE, NU and Test Tree. RDMO Doyon #141 RU wireline and RIH with GR/JB to float shoe RIH with wireline perforating guns and perforate as per production RU Dowell frac trucks and frac as per production program, RDMO frac fleet MIRU Nabors 4ES PU 2 7/8" tubing and cleanout to float collar of 7" long string Change over to +9.8 ppg brine, POOH POOH with 4 1/2" frac string and LD same RIH with dual ESP on 2 7/8" production tubing Secure well, RDMO Nabors 4ES Shared Services Drilling I .DriflQuesr 1250 2500 Dir @ 1.500°/100ft: 300.00ft MD, 300.00ft TVD in Dir Rate @ 2.000°/100ft: 500.00ft MD, 499.91ft TVD in Dir Rate @ 2.500°/100ft: 750.00ft MD, 684.18ft TVD in Dir Rate @ 3.000°/100ft: 1001.08ft MD, 932.37ft TVD B Perm - 1864,50 TVD Dir: 2875.79ft MD, 2394.99ft TVD ~ 3750 .-- 50OO o~ 6250 II o-- ~ 75o0 JUL ,'u~. 0ii & Gas Corn 0 Scale: linch = 1250ft MPI-09 Shradet 3944.50 TVD MPI-09 Wp 03 Begin Dir { · 5924.30ft ~ ID, 9ft TVD .3885.Z3ft TVD Schrader N,4 - Proposal Data for MPI-09 Wp03 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ft North Reference: True North Dogleg severity: Degrees per 100fl Vertical Section Azimuth: 319.773° Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Az im~II~veV North in g, Depth ~, ~91~ 0.00 0.000 0.397'~ -- 0.00 0.00 N 300.00 0.000 ~1, 300.00 0.00 N 500.00 3.000 499,91 5.23 N 748.68 29.19 N 996.87 63.64 N 1800.00 331.49 N 1900.00 388.89 N 321.461 2459.49 899.62 N 321.461 3866.69 3014.88 N 3944.50 3140.67 N 318.373 3950.23 3150.79 N 318.373 6053.83 6905.71 N 318.386 6345.40 7196,41 N 318,386 6460.00 7265,80 N 319.970 6723. I 0 7378.03 N 319.970 7007.50 7457.29 N 319.970 7112.50 7486.56 N 319.970 7253,45 7525.84 N 39.000 20.000 20.000 20.000 20.000 Eastlngs Vertical Dogleg Section Rate 0.00 E 0.00 0.00 E 0.00 0.000 0.00 E 4.00 1.500 0.00 E 22.29 2.000 13.73 W 57.45 2.500 230.63 W 402.04 3.000 277.12 W 475.89 0.000 686.64 W 1130.30 3.000 2371.55 W 3833.42 0.000 2478.23 W 3998.36 3.000 2487.29 W 4011.94 3.000 5824.17 W 9033,80 0.000 6082.46 W 9422.56 5.759 6144.09 W 9515.34 0.000 6241.85 W 9664.16 6.262 6308.43 W 9767.68 0.000 6333.01 W 9805.89 0.000 6366.01 W 9857.20 0.000 Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference : Ref. Geographical Coordinates: RKB Elevation: MPI-09 As-Built WPS North Reference: Units: 6009446.57 N, 551644.92 E 342.23 S, 533.11 W 70° 26' 11.5991" N, 149° 34' 44.1486" W 64.50ft above Structure Reference True North Feet 5/8" Casing 4059.50 TVD MPI-09 Jun-14 Target 7007,50 TVD .............................................................................................................. ~45~:29 N, 7" Liner 13074.06 MD 7253.45 TVD I I I I I I I I 1250 2500 3750 5000 6250 7500 8750 10000 Vertical Section .... .[lldl~ : .6.4.94.50 TYD MK-19- 6584.50 TI/D TKUD- 6720.50 TYD Kup B - 6874.30 TI/D - 7097.50 TKD TKD Section Azimuth: 319.773° (True North) ORI / / III~IG Shared Services Drilling MPI-09 Wo 03 · I DrillQuesf 7500 6250 500O 3750 250O 1250 Scale: linch = 1250ft Eastings -6250 -5000 -3750 -2500 -1250 0 7" Liner MPI-09 Polygon 13074.06 M D 7253.45 TVD -- I ~ Dir: 12509.66ft MD, 6658.59ft TVD ~ r~ /~egin Dir @ 6.262°/100ft: 12205.99ft MD, 6395.50ft TVD -'",~¥,~o E nd / ,t,:~-~,~_/Begin Dir @ 5.759o/100ft: 11567.52ft MD, 5989.33ft TVD _ REC , D - ~aska 0it & Gas C~s. ~mi~n ~~% 95/8" Casing ' ~X' ~End Dir: 6121.48E MD, 3005.73~ ~D ~ ~ ~ ~Begin Dir~3000~/100~· -~ ~*,-o9sn,~,~ ~ .... 5924.30ff MD '3802.19ff ~D ~ 3944.50 TVD X ' -- ~0~~ 3140.67 N, 2478.23 W -- End Dir: 2875.7~ MD, 2394.9~ WD ~ Begin Dir ~ 3.000o/j0q~:. 20~[7~.~,j 8~:~_~D ~ ~ .... Begin Dir ~ 1.500~/100ff: 300.0~ MD, 300.00ff ~D I I I I I -6250 -5000 -3750 -2500 -1250 0 Scale: linch = 1250ft Eastings Reference is True North 7500 625O 5OOO 3750 2500 1250 North Slope Alaska Alaska State Plane 4 MILNEPT MPI-MP, Slot MPI-Og A, MPI-09 As-Built WPS - MPI- Revised: 22 June, 2000 WPS Surface Coordinates: PROPOS REPORT l~~~/~no, 2000 600944~ 551644.92 E (70° 26' 11.5991"N, 149° 34' 44.1486" W) K~Og'hing: 64.50fl above Mean Sea Level JUL l 'i 20!3) Alaska Oil & Gas Cons. Commission Anchorage Ct RI ~ L~.!:N::~ ..... S:WR_.M ! :~W:~.~ Proposal Reft pro9097 ,~. '!f.¢..I,~!~.,,'%'~i ( ~ rvices Sperry-Sun Drilling Proposal Data - MPI-Og As. Built WPS - MPI-Og Wp03 0.00 0.00 22 June, 2000 - 15:29 .1- JUL 11 Alaska Oil & Gas C~s, Commission Anchor~ DrillQuest JUL 11 A~aska Oi~ & Gas Cons. CommissiOn Anchor~JO North SlOpe Alaska Measured Depth (ft) 0.00 100.00 200.00 300.00 Incl. 0.000 0.000 0.000 0.000 400.00 1.500 500.00 3.000 600.00 5.000 700.00 7.000 750.00 8.000 800.00 8.058 900.00 8.723 1000.00 9.984 1001.08 10.000 1100.00 12.968 1200.00 15.968 1300.00 18.968 1400.00 21.968 1500.00 24.968 1600.00 27.968 1700.00 30.968 Sperry-Sun Drilling Services Proposal Report for MPI-09 As.Built WPS - MPI-09 Wp03 Revised: 22 June, 2000 ~ Sub-Sea Vertical Local Coordinates Global Coo~ Dogleg Azim. Depth Depth Northings Eastings Northings s Rate (~) (~) (~) (~) (~) (~) (~100~) 0.000 -64.50 0.00 0.00N 0.00E 551644.92 E 0.000 35.50 100.00 0.00 N 0.00 E .N 551644.92 E 0.000 0.000 135.50 200.00 0.00 N 0.00 E N 551644.92 E 0.000 0.000 235.50 300.00 0.00 N 0.00 E N 551644.92 E 0.000 0.000 335.49 399.99 1.31N 0.00 E 6009447.88 N 551644.91E 1.500 0.000 435.41 499.91 5.23N ~.O 6009451.80 N 551644.88 E 1.500 0.000 535.16 599.66 12.21 N ~'~1~) E 6009458.78 N 551644.84 E 2.000 0.000 634.61 699.11 22.66 N _ ~, ~0.00 E 6009469.23 N 551644.76 E 2.000 0.000 684.18 748.68 29.19 I~,~ 0.00 E 6009475.76 N 551644.72 E 2.000 334.467 832.63 . ~ 4.90 W 6009496.43 N 551639.67 E 2.500 321.124 931.31 995.81 ~, 'l~J~9 N 13.62 W 6009509.96 N 551630.87 E 2.500 321.000 932.37 996.87 ~ 63.64 N 13.73 W 6009510.11 N 551630.75 E 2.500 321.000 1126.12 6009544.63 N 551602.39 E 3.000 321.000 1221.50 I~2~.00 121.68 N 60.73 W 6009567.82 N 551583.34 E 3.000 321.000 1315.1~,~1~~"68 148.85 N 82.74 W 6009594.84 N 551561.15 E 3.000 321.000 140(~i}ll~e 1471.40 179.80 N 107.80 W 6009625.61 N~ 551535.88 E 3.000 321.00- 14~.~t~v 1560.91 214.43 N 135.84 W 6009660.05 N 551507.60 E 3.000 321.000~~~v 1647.96 252.65 N 166.80 W 6009698.06 N 551476.38 E 3.000 Alaska State Plane 4 MILNEPT MPI-MP Vertical Section (ft) 0.00 0.00 0.00 0.00 1.00 4.00 9.32 17.30 22.29 27.94 41.26 57.27 57.45 77.14 102.12 132.12 167.08 206.89 251.44 300.62 Comment Benin Dir ~ 1.500°/100ft: 300.00ft MD, 300.00ft TVD Increase in Dir Rate ~. 2.000°/100ft: 500.00~ MD, 499.91ft TVD Increase in Dir Rate (~. 2.500°/100ff: 750.00fl MD, 684.18ft TVD Increasein Dir Rater 3.000°/100ff :1001.0~ff MD, 932.37ffTVD Continued... 22 June, 2000-15:34 -2- DrillQuestl. 05.04c JUL 11 2uu) Alaska 0i! & Gas Co~s. Co~mi~n North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (fi) 1800.00 33.968 321.000 1667.82 1882.84 36.453 321.000 1735.50 1900.00 36.453 321.000 1749.30 1963.03 36.453 321.000 1800.00 2000.00 36.453 321.000 1829.73 2007.17 36.453 321.000 1835.50 2100.00 39.238 321.071 1908.80 2200.00 42.237 321.140 1984.56 2300.00 45.237 321.200 2056.80 2400.00 48.237 321.255 2125.33 2500.00 51.236 321.305 2189.95 2600.00 54.236 321.350 2250.50 2700.00 57.236 321.393 2306.79 2800.00 60.236 321.432 2358.68 2875.79 62.509 321.461 2394.99 2900.00 62.509 321.461 2406.17 3000.00 62.509 321.461 2452.33 3100.00 62.509 321.461 2498.49 3200.00 62.509 321.461 2544.65 3300.00 62.509 321.461 3400.00 62.509 321.461 3500.00 62.509 321.461 3600.00 62.509 321.461 3700.00 62.509 321 3800.00 62.509 321 Sperry-Sun Drilling Services Proposal Report for MPI.09 As-Built WPS. MPI.09 Wp03 Revised: 22 June, 2000 ~ 26: 2821.61 Ve~ical Local Coordinates Global Coo~ Dogleg Depth Nodhings Eastings Nothings s Rate (fi) (~) (E) (fi) (~) (~100ff) 1732.32 294.37 N 200.58W 601 551442.31E 3.000 1800.00 331.49 N 230.63W 551412.00 E 3.000 1813.80 339.41N 237.05W 33 N 551405.53 E 0.000 1864.50 368.51N 260.62W, N 551381.76 E 0.000 1894.23 385.58 N 274.44W 6009830.24 N 551367.82 E 0.000 1900.00 388.89 N 2~1~1{~ 6009833.54 N 551365.11E 0.000 1973.30 433.18 N ~/1~'~' 6009877.57 N 551329.00 E 3.000 2049.06 483.96 N 3~90W 6009928.07 N 551287.67 E 3.000 2121.30 537.81 N . ~, 397.25 W 6009981.62 N 551243.96 E 3.000 2189.83 594.581~,~442.84W 6010038.07N 551197.97E 3.000 2254.45 ~1k,~,6'4 ~t~~ ~490.57 W 6010097.27 N 551149.83 E 3.000 2315.00 ~0~rl b-~,~,~ 540.29 W 6010159.05 N 551099.68 E 3.000 2371.29 591.88 W 6010223.25 N 551047.65 E 3.000 2423.18 645.19W 6010289.69 N 550993.88 E 3.000 2459.49 899.62 N 686.64W 6010341.42 N 550952.06 E 3.000 '.15 2701.47 2747.63 2793.79 2839.95 2886.11 916.42 N 700.03W 6010358.12 N 550938.57 E 0.000 985.81 N 755.30W 6010427.13 N 550882.82 E 0.000 1055.20 N 810.56W 6010496.13 N 550827.07 E 0.000 1124.58 N 865.83W 6010565.13 N 550771.32 E 0.000 1193.97 N 921.10W 6010634.13 N 550715.57 E 0.000 1263.36 N 976.37W 6010703.13 N 550659.82 E 0.000 1332.74 N 1031.64W 6010772.14 N 550604.07 E 0.000 1402.13 N 1086.91W 6010841.14 N 550548.32 E 0.000 1471.52 N 1142.18W 6010910.14 N 550492.57 E 0.000 1540.90 N 1197.45W 6010979.14 N 550436.83 E 0.000 Alaska State Plane 4 MILNEPT MPI-MP VeAical Section 354.28 402.04 412.23 449.67 471.63 475.89 532.82 598.06 667.16 739.95 816.23 895.77 978.38 1063.81 1130.30 1151.77 1240.44 1329.11 1417.78 1506.45 1595.12 1683.79 1772.46 1861.13 1949.80 Comment End Dir' 1882.84ft MD, 1735.50ff TVD B Perm Beain Dir (~. 3.000°/100ft: 2007.17ft MD, 1835.50ft TVD End Dir: 2875.79ft MD, 2394.99ft TVD Continued... 22 June, 2000- 15:34 - 3- DrillQuest 1.05,04c JUL 1 1 2000 A~aska 0il & Gas 0o~$, CorniSh North Slope Alaska Sperry-Sun Drilling Services Proposal Report for MPI-09 As-Built WPS - MPI-09 Wp03 Revised: 22 June, 2000 ~ Measured Depth Incl. Azim. (~) 3900.00 62.509 321.461 4000.00 62.509 321.461 4100.00 62.509 321.461 4200.00 62.509 321.461 4300.00 62.509 321.461 4400.00 62.509 321.461 4500.00 62.509 321,461 4600.00 62.509 321.461 4700.00 62.509 321.461 4800.00 62.509 321.461 4900.00 62.509 321.461 5000.00 62.509 321.461 5100.00 62.509 321.461 5200.00 62.509 321,461 5300.00 62.509 321.461 5400.00 62.509 321.461 5500.00 62.509 321.461 5600.00 62.509 321.461 5700.00 62.509 321.461 5785.24 62.509 321.461 5800.00 62.509 5900.00 62.509 5924.30 62.509 6000.00 64.363 6100.00 66.833 Sub-Sea Depth (~) 2867.77 2913.93 2960.09 3006.25 3052.41 3098.57 3144.73 3190.89 3237.05 3283.21 3329.37 3375.53 3421.69 3467.85 3514.01 3560.17 3606.33 3652.49 3698.65 3736.00 321.461 d~ 3744. 321.461 379 321.461 3~1~- 319.994 ~8'~ 318.1~"11~7.36 Ve~ical Local Coordinates Global Coo Dogleg Depth Nothings Eastings Nothings Rate (~) (~) (~) (~) (~) (°/100~) 2932.27 1610.29 N 1252.72 W 6011 550381.08 E 0.000 2978.43 1679.67 N 1307.99W 601 550325.33 E 0.000 3024.59 1749.06 N 1363.26W 550269.58 E 0.000 3070.75 1818.45 N 1418.53W ~255.15 N 550213.83 E 0.000 3116.91 1887.83 N 1473.80 550158.08 E 0.000 1957.22 N 550102.33 E 2026.61N 550046.58 E 2095.99 N 549990.83 E 2165.38 N 549935.08 E 2234.77 N 549879.34 E 2304.15 549823.59 E 2373.~ 549767.84 E 3163.07 3209.23 3255.39 3301.55 3347.71 3393.87 3440.03 3486.19 3532.35 3578.51 3624.67 3855.48 3866.69 3900.55 3941.86 N N N E720.47 N 2789.86 N 2859.24 N 2918.39 N 2928.63 N 2998.02 N 3014.88 N 3067.29 N 3136.06 N W 805.42W W 1915.96W 1971.23W 2026.50W 2081.77W 2137.04W 2192.31W 2247.58W 2294.69W 2302.85W 2358,12W 2371.55W 2414.41W 2474.09W 393.15 N 6011462.16 N 6011531.16 N 6011600.16 N 6011669.16 N 6011738.17 N 6011807.17 N 6011876.17 N 6011945.17 N 6012014.17 N 6012083.18 N 6012152.18 N 6012221.18 N 6012290.18 N 6012349.00 N 6012359.18 N, 6012428.19 N 6012444.95 N 6012497.06 N 6012565.42 N 549712.O9 E 549656.34 E 5496OO.59 E 549544.84 E 549489.09 E 549433.34 E 549377.60 E 549330.08 E 549321.85 E 549266.10 E 549252.55 E 549209.33 E 549149.17 E 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 3.000 3.000 Alaska State Plane 4 MILNEPT MPI-MP VeAical Section 2038.47 2127.14 2215.81 23O4,48 2393.15 2481.82 2570.49 2659.16 2747.83 2836.50 2925.17 3013.84 3102.51 3191.18 3279.85 3368.52 3457.20 3545.87 3634.54 3710.11 3723.21 3811.88 3833.42 3901.12 3992.16 Comment Schrader NA Beain Dir ~. 3.000°/100ft: 5924.30ft N3D, 3802.19ff TVD Continued... 22 June, 2000 - 15:34 - 4 - DrillQuest 1.05.04c JUL 1 1 200,) ~sKa 01~ & G~s C~s~ C~m~n North Slope Alaska Sperry-Sun Drilling Services Proposal Report for MPI-09 As-BuNt WPS - MPI-09 Wp03 Revised: 22 June, 2000 ~ Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 6106.74 67.000 318.000 3880.00 6121.48 67.278 318,373 3885.73 6200.00 67.278 318.373 3916.06 6300.00 67.278 318,373 3954.68 6400.00 67.278 318.373 3993.31 6404.38 67.278 318,373 3995,00 6500.00 67.278 318.373 4031.94 6600.00 67.278 318.373 4070.56 6700.00 67.278 318.373 4109.19 6800.00 67.278 318.373 4147.82 6900.00 67.278 318,373 4186.44 7000.00 67.278 318.373 4225.07 7100.00 67.278 318.373 4263.69 7200.00 67.278 318.373 7300.00 67.278 318.373 7400.00 67.278 318.373 7500.00 67.278 318.373 7600.00 67.278 318.373 7700.00 67,278 318.373 7800.00 67,278 7900.00 67.278 318.373 8000.00 67.278 318.373 8100.00 67.278 318.373 8200.00 67.278 31~ 8300.00 67.278 318.: Vertical Local Coordinates Global Dogleg Depth Northings Eastings Northings Is Rate (~) (~) (~) (~) (~) (°/i OOff) 3944.50 3140.67 N 2478.23W 6012~ 549145.00 E 3.000 3950.23 3150.79 N 2487.29W N 549135.87 E 3.000 3980.56 3204.93 N 2535.40W N 549087.39 E 0,000 4019.18 3273.88 N 2596.67 N 549025.64 E 0.000 4057.81 3342.83 N 2657.94 ).91N 548963.89 E 0.000 4059.50 3345.84 N 6012773.91N 548961.19 E 0.000 4096.44 3411.77 N 6012839.43 N 548902.15 E 0.000 4135.06 3480.72 N W 6012907,95 N 548840.40 E 0,000 4173.69 3549.67 W 6012976.47 N 548778.65 E 0.000 4212.32 361; W 6013045.00 N 548716.90 E 0.000 4250.94 2964.30W 6013113.52 N 548655.15 E 0,000 4289.57 3025.57W 6013182.04 N 548593.41E 0,000 4328.19 ,, N 3086.84W 6013250.56 N 548531.66 E 0.000 4302.32 4366.82 &~,3894.41N 3148.12W 6013319.08 N 548469,91E 0,000 4340.95 4405.45,~l~k~963.35N 3209.39W 6013387.60N 548408.16E 0.000 4379.57 4444d~~ 4032.30N 3270.66W 6013456.13N 548346.42E 0.000 4418.20 ~1~8~,~ '~ 4101.25N 3331.93W 6013524.65N 548284.67E 0.000 4456.83 [452~.'3=J' 4170.20N 3393.20W 6013593.17N 548222.92E 0.000 4495.45 ~11~.95 4239.15 N 3454.47W 6013661.69 N 548161.17 E 0.000 4598.58 4308.09 N 3515.75W 6013730.21N 548099.43 E 0.000 4637.21 4377.04 N 3577.02W 6013798.74 N 548037.68 E 0.000 4675.83 4445.99 N 3638.29W 6013867.26 N 547975.93 E 0.000 4714.46 4514.94 N 3699.56W 6013935.78 N 547914.18 E 0.000 4753.08 4583.88 N 3760.83W 6014004.30 N 547852.43 E 0.000 4791.71 4652.83 N 3822.10W 6014072.82 N 547790.69 E 0.000 8.373 4534 8.37~ ~t~8.58 ~73~4727.21 Alaska State Plane 4 MILNEPT MPI-MP Vertical Section (ft) 3998.36 4011.94 4084.34 4176.55 4268.77 4272.80 4360,98 4453.19 4545.40 4637.61 4729.82 4822.03 4914.24 5006,46 5098.67 5190.88 5283.09 5375.30 5467.51 5559.72 5651.94 5744.15 5836.36 5928.57 6020.78 Comment Taroet-MPI-09 Shrader, Ge~ogical End Dir'6121.48ff MD, 3885.73ff'I'VD 9 5/8" Casin_~ Base Schrader Continued.,. 22June, 2000- 15:34 - 5- DrillQuest 1.05.04c ,JUL 1 2.00) Alaska Oi~ & Gas C~s. OOmPh North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 8400.00 67.278 318,373 4765,84 8500.00 67.278 318.373 4804.46 8600.00 67.278 318.373 4843.09 8700.00 67.278 318.373 4881.72 8800.00 67.278 318.373 4920.34 8900.00 67.278 318.373 4958.97 9000.00 67.278 318.373 4997.60 9100.00 67.278 318.373 5036.22 9200.00 67.278 318.373 5074.85 9300.00 67.278 318,373 5113.47 9400.00 67.278 318.373 5152.10 9500.00 67.278 318.373 5190.73 9600,00 67,278 318.373 5229.35 9700.00 67.278 318.373 5267.98 9800.00 67.278 318.373 5306.61 9900.00 67.278 318.373 5345.23 10000.00 67.278 318.373 5383.86 10100.00 67.278 318.373 5422.48 10200.00 67.278 318.373 5461.11 10300.00 67,278 318.373 5499.74 10400.00 67.278 318.373 10500.00 67.278 318.373 10600.00 67.278 318.373 10700.00 67.278 318.373 10800.00 67.278 318.373 5538. Sperry-Sun Drilling Services Proposal Report for MPI-09 As-Built WPS - MPI-09 Wp03 Revised: 22 June, 2000 ~ Ve~ical Local Coordinates Global Coo Dogleg Depth Nothings Eastings Nothings Rate (fl) (fl) (~) (E) (fl) (°1100~) 4830.34 4721.78 N 3883.38W 547728.94 E 0.000 4868.96 4790.73 N 3944.65W 601 N 547667.19 E 0.000 4907.59 4859.67 N 4005.92W N 547605.44 E 0,000 4946.22 4928.62 N 4067.19W .91N 547543.70 E 0.000 4984.84 4997.57 N 4128,46 i.43 N 547481.95 E 0.000 5023.47 5066.52 N 41~ 1.95 N 547420.20 E 0.000 5062.10 5135.47 N 6014552.47 N 547358.45 E 0.000 5100.72 5204.41N 6014621.00 N 547296.71E 0,000 5139.35 5273.36 N 6014689.52 N 547234.96 E 0.000 5177.97 5342.31N 44 W 6014758.04N 547173.21E 0,000 5216.60 5411.26 ;.09W 6014826.56 N 547111.46 E 0.000 5255.23 6014895.08 N 547049.72 E 0.000 5293.85 4618.64W 6014963.61N 546987.97 E 0.000 5332.48 N 4679.91W 6015032.13 N 546926.22 E 0.000 5371.11 N 4741.18W 6015100.65 N 546864.47 E 0.000 5409.73 2.86 5641.49 5680.12 5718.74 5757.37 N 4802.45W 6015169.17 N 546802.72 E 0.000 N 4863.72W 6015237.69 N 546740.98 E 0.000 5893.89 N 4925.00W 6015306.21 N 546679.23 E 0.000 5962.84 N 4986.27W 6015374.74 N 546617.48 E 0.000 6031,79 N 5047.54W 6015443.26 N 546555.73 E 0.000 6100.73 N 5108.81W 6015511.78 N 546493.99 E 0.000 6169,68 N 5170.08W 6015580.30 N 546432.24 E 0.000 6238.63 N 5231.35W 6015648.82 N 546370.49 E 0.000 6307.58 N 5292.63W 6015717.34 N 546308.74E 0.000 6376.52 N 5353.90W 6015785.87 N 546247.00 E 0,000 Alaska State Plane 4 MILNEPT MPI-MP Ve~ical Section (fi) 6112.99 6205.20 6297.41 6389.63 6481.84 6574.05 6666.26 6758.47 6850.68 6942.89 7035.11 7127.32 7219.53 7311.74 7403.95 7496.16 7588.37 7680.58 7772.80 7865.01 7957.22 8049.43 8141.64 8233.85 8326.06 Comment Continued... 22 June, 2000-15:34 - 6- DrillQuestf,05.04c JUL 1 1 20 i) Alaska 0il & Gas CMs, Commm~n chorage North Slope Alaska Sperry-Sun Drilling Services Proposal Report for MPI-09 As.Built WPS - MPI-09 Wp03 Revised: 22 June, 2000 ~ Measured Sub-Sea Depth Incl. Azim. Depth (~) 10900.00 67.278 318.373 5731.50 11000.00 67.278 318.373 5770.12 11100.00 67.278 318.373 5808.75 11200.00 67.278 318.373 5847.37 11300.00 67.278 318.373 5886.00 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 5796.00 6445.47 N 5415.17 W 5834.62 6514.42 N 5476.44 W 5873.25 6583.37 N 5537.71 W 5911.87 6652.31 N 5598.98 W 5950.50 6721.26 N 5660.26 11400.00 67.278 318.373 5924.63 5989.13 11500.00 67.278 318.373 5963.25 6027.75 11567.52 67.278 318.373 5989.33 6053.83 11600.00 65.407 318.374 6002.37 6066.87 11700.00 59.648 318.376 6048.48 6112.98 11800.00 53.889 318.378 6103.26 6167.76 11900.00 48.130 318.381 6166.15 6230.65 12000.00 42.371 318.384 6236.52 6301.02 12058.52 39.000 318.386 6280.90 6345.40 12100.00 39.000 318.386 6313.13 12119.14 39.000 318.386 6328.00 12200.00 39.000 318.386 6390.84 12205.99 39.000 318.386 6395.50 12249.56 36.273 12300.00 33.116 318.520 6430.00 318.698 6471~/~% 319.970~'6658.60 6377.63 ~41~7215.93 N 6392.50~ ~/'224.93 N 645~1~ 7262.98 N ~l~llt~ll~ ' 7265-80 N 6790.21N 5721.5~1k 6859.16N 57~.~ 6905.71N ~ 6927.95 N ,584~.93 W 6994.241~~902.84W 7056.7~11~'~958.38W 7~1~!1~ 6009.98W ~67.~ 6057.13W 7~l~lN 6082.46W 12356.83 29.560 12400.00 26.859 12500.00 20.604 12506.90 20.173 12509.66 20.000 6535.96 7307.24 N 6584.50 7329.48 N 6622.54 7344.89 N 6714.03 7375.47 N 6720.50 7377.30 N 6723.10 7378.03 N Global Coo Northings fit) 601! 601 H97.00 N 6016265.52 N 6016311.78 N 6016333.88 N 6016399.77 N 6016461.88 N 6016519.60 N 6016572.35 N 6016600.69 N 6099.80W 6016620.08 N 6107.79W 6016629.03 N 6141.59W 6016666.84 N 6144.09W 6016669.65 N 6161.74W 6016689.43 N 6180.72W 6016710.84 N 6200.18W ~"~6016732.94N 6213.56W 6016748.26 N 6239.69W 6016778.65 N 6241.24W 6016780.48 N 6241.85W 6016781.20 N Alaska State Plane 4 MILNEPT MPI-MP Dogleg Vertical Rate Section (~) (°/lO0~) (~) 546185.25E 0.000 8418.28 546123.50 E 0.000 8510.49 546061.75 E 0.000 8602.70 546000.00 E 0.000 8694.91 545938.26 E 0.000 8787.12 545876.51E 0.000 8879.33 545814.76 E 0.000 8971.54 545773.07 E 0.000 9033.80 545753.15 E 5.759 9063.54 545693.79 E 5.759 9152.20 545637.82 E 5.759 9235.79 545585.82 E 5.759 9313.46 545538.30 E 5.759 9384.43 545512.77 E 5.759 9422.56 545495.30 E 0.000 9448.66 545487.24 E 0.000 9460.70 545453.18 E 0.000 9511.57 545450.66 E 0.000 9515.34 545432.88 E 6.262 9541.94 545413.75 E 6.262 9570.64 545394.13 E 6.262 9600.19 545380.65 E 6.262 9620.59 545354.30 E 6.262 9660.81 545352.74E 6.262 9663.21 545352.13 E 6.262 9664.16 Comment Be~in Dir (~. 5.759°/100ft: 11567.52ftTvlD, 5989.33ft TVD End Dir: 12058.52ft MD, 6280.89ft TVD THRZ Be.clin Dir ~ 6.262°/100ft: 12205.99ft'g4D, 6395.50ft TVD BHP, Z MK-19 TKUD End Dir: 12509.66ft MD, 6658.59ft TVD Continued... 22 June, 2000 - 15:34 - 7 - DrillQuest f.05.04c JUL 11 20OO A~a~ka Oi~ & Gas 0o~$o Commi~N~n A~ch0.r~e North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (fi) (fi) 12600.00 20.000 319.970 6743.49 12670.78 20.000 319.970 6810.00 12700.00 20.000 319.970 6837.45 12800.00 20.000 319.970 6931.42 12802.74 20,000 319.970 6934.00 12812.32 20.000 319.970 6943.00 12841.05 20.000 319.970 6970.00 12900.00 20.000 319.970 7025.39 12908.09 20.000 319.970 7033.00 12924.06 20.000 319.970 7048.00 13000.00 20.000 319.970 7119.36 13074.06 20.000 319.970 7188.95 Sperry-Sun Drilling Services Proposal RePort for MPI-09 As-Built WPS . MPI-09 WpO$ Revised: 22 June, 2000 ~t~ Ve~ical Local Coordinates Global Coo Dogleg Depth Nothings Eastings Nothings Rate (~) (~) (~) (~) (~) (*/100~) 6807.99 7401.69 N 6261.72W 545332.09 E 0.000 6874.50 7420.23 N 6277.30W 601 545316.39 E 0.000 6901.95 7427.88 N 6283.72W N 545309.91 £ 0.000 6995.g2 7454.07 N 6305.72W N 545287.73 E 0.000 6998.50 7454.78 N 6306.32 N 545287.12 E 0.000 7007.50 7457.29 N 6308.4 8880.00 N 545285.00 E 0.000 7034.50 7464.82 N 6016867.48 N 545278.63 E 0.000 7089.89 7480.26 N 6016882.83 N 545265.55 E 0.000 7097.50 7482.38 N 6329.50W 6016884.94 N 545263.76 E 0.000 7112.50 7486.56 W 6016889.09 N 545260.22 E 0.000 7183.86 6349.72W 6016908.86 N 545243.37 E 0.000 7253.45 6366.01W 6016928.15 N 545226.95 E 0.000 All data is in feet unless otherwise stated. Directions and Vertical depths are relative to Well. Northings and lates are relative to True North. to Well. Alaska State Plane 4 MILNEPT MPI-MP Ve~ical Section (~) 9695.06 9719.27 9729.26 9763.46 9764.40 9767.68 9777.50 9797.67 9800.43 9805.89 9831.87 9857.20 Comment Kup B Kup A TKA3 MPI-09 Jun-14 Target, Geological TKA2 TKA1 Miluveach Total Depth: 13074.06ft MD, 7188.95ft TVD 7" Liner The Dogleg Severity is in Degrees per 10 Vertical Section is from Well and calc~ Based upon Minimum Curvature The Bottom Hole Di,, an Azimuth of 319.773° (True). at a Measured Depth of 13074.06ft., in the Direction of 319.773° (True). Continued... 22 June, 2000 - 15:34 - 8 - DrillQuest 1.05.04c JUL 11 A~a~ka Oi~ & Gas Cms~ Commando North Slope Alaska Sperry-Sun Drilling Services Proposal Report for MPI-09 As-Built WPS . MPI-09 Wp03 Revised: 22 June, 2000 ~ Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 300.00 300.00 0.00 N 0.00 E 500.00 499.91 5.23 N 0.00 E 750.00 748.68 29.19 N 0.00 E 1001.08 996.87 63.64 N 13.73 W 1882.84 1800.00 331.49 N 230.63 W 2007.17 2875.79 5924.30 6121.48 11567.52 12058.52 12205.99 12509.66 13074.06 1900.00 388.89 N 277.12W 2459.49 899.62 N 686.64W 3866,69 3014.88 N 2371.55W 3950.23 3150.79 N 2487.29W 6053.83 6905.71N 5824.17W 6345.39 7196.41N 6082.46W 6460.00 7265.80 N 6144.09W 6723.09 7378.03 N 6241., 7253.45 7525.84 N 6366.01 Comment Begin Dir @ 1.500°/100ft: 300.00ft TVD Increase in Dir Rate @ : 500.00ft MD, 499.91ft TVD Increase in Dir Rate @ 2. : 750.00ft MD, 684.18ft TVD Increase in Dir Rate 1001.08ff MD, 932.37ft TVD End Dir: TVD Begin Dir @ 3 : 2007.17ft MD, 1835.50ft TVD End Dir: MD, 2394.99ft TVD Begin : 5924.30ft MD, 3802.19ft TVD End Di MD, 3885.73ft 'FVD 5.759°/100ft: 11567.52ft MD, 5989.33ft TVD : 12058.52ft MD, 6280.89ft TVD Dir @ 6.262°/100ft: 12205.99ft MD, 6395.50ft TVD End Dir: 12509.66ft MD, 6658.59ft TVD Depth: 13074.06ft MD, 7188.95ft TVD Alaska State Plane 4 MILNEPT MPI-MP Continued... 22 June, 2000 - 15:34 - 9 - DrillQuest 1.05.04c JUL Oil & G~s North Slope Alaska Formation Tops Measured Ve~ical Depth Depth (~) 1963.03 1864.50 5785.24 3802.50 6404.38 4059.50 12119.14 6392.50 12249.56 6494.50 12356.83 6584.50 12506.90 6720.50 12670.78 6874.50 12802.74 6998.50 12812.32 7007.50 12841.05 7034.50 12908.09 7097.50 12924.06 7112.50 Sperry-Sun Drilling Services Proposal Report for MPI-09 As-Built WPS - MPI-09 Wp03 Revised: 22 June, 2000 ~ Sub-Sea Depth Nothings Eastings Formation Name. (fi) (~) 1800.00 368.51N 260.62W B Perm 3738.00 2918.39 N 2294.69 W Schrader NA 3995.00 3345.84 N 2660.62W Base Schra~ 6328.00 7224.93 N 6107.79W THR~ 6430.00 7285.71N 6161.74W B~~ 6520.00 7329.48 N 6200.18 W ~K-I~ 6656.00 7377.30N 6241.24W _ ~UD 6810.00 7420.23N 6277.30W~,41~B 6934.00 7454.78 N 6306.32~11~~A 6943.00 7457.29N 63~%~TKA3 6970.00 7464.82 N 6~ TKA2 !~'.'.'.'.'.'.'.'.'M~ W TKA1 7033.00 7482.38 N ,i~32 7048.00 7486.56 N ,~'~1~33.01W Miluveach Alaska State Plane 4 MILNEPT MPI-MP Continued... 22 June, 2000- 15:34 - 10- DrillQuest 1.05.04c JUL Oit & Ga,. Con,,,. Comm~ion North Slope Alaska Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 6404.38 <Surface> <Surface> 13074.06 Targets associated with this wellpath Target Name MPI-09 Jun-14 Target MPI-09 Polygon Sperry-Sun Drilling Services Proposal Report for MPI-09 As-Built WPS - MPI-09 Wp03 Revised: 22 June, 2000 ~ Vertical Depth Casing Detail (ft) 4059.50 9 5/8" Casing 7253.45 7" Liner Mean Coordinates: Coordinates: Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 Mean Sea Level/Global Coordinates #1 #2 #3 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 7007.50 7457.29 N 6308.43W 6943.00 6016860.00 N 545285.00 E 70°27'24.9208"N 149° 37'49.4934"W 64.50 7875.16 N 6720.55W 0.00 6017275.00 N 544870.00 E 70° 27'29.0273"N 149° 38'01.6126"W 64.50 7875.16 N 6720.55W 64.50 7537.46 N 5898.87W 64,50 7042.47 N 5902.29W 64.50 7380.17 N 6723.98W 0.00 6017275.00 N 544870.00 E 0.00 6016943.00 N 545694.00 E 0.00 6016448.00 N 545694.00 E 0.00 6016780.00 N 544870.00 E Alaska State Plane 4 MILNEPT MPI-MP Target Target Shape Type Point Geological Polygon Geological Continued... 22 June, 2000 - 15:34 - 11 - DrillQuest 1.05.04c JUL 11 ~' "16"-5M CIW MPU 1-09 ( o,g. DFElev.: 29.5'RKB(D141) ..Wellht .. 11" x 7" 5M FMC Gen 5a , Odg. GL Elev. = 34.5' w/2 7/8" FMC Tbg Hng, 3" Acme lift threads on top and 2 7/8" 8 rd on bottom, 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 ,,, KOP @ 300' Camco 2 7/8" x 1" [ 126' -- Max. hole angle = 62 to 67 ' sidepocket KBMM GLM deg. f/2800' to 11,900' Hole angle thru' perfs = 20 deg DLS = 5.8 deg/100' @ 12050' ,.DLS = 6.3 de~/100' @ 12500' . 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7", 26 ppf, L-80, Btm. production casing ( ddft ID = 6.151", cap. = 0.0383 bpf) Centrilift FPMTARC Pump FC 650 w/184 stage Tandem gas seperator (GRSTZBARH6) Centrilift GSTGDBHL seal section Centriliff KME1G 562 series, 50 hp, 1250 v./23 amps. Centrilift PHD 7" float collar (PBTD) 7" float shoe ['"'"13074' DATE REV. BY COMMENTS .MILNE POINT UNIT ..WELL 1-09 BP EXPLORATION (AK) k DATE , CHECK NO. VENDOR ALASKAST 14 GO DATE INVOICE / CREDIT MEMO ~ESCRIPTION GROSS DISCOUNT NET 062900 CKOb2900F 100.00 100.00 HANDLING INST' PH 'i~RRI HUBBLE X4628 THEA~ACH£DCHECKISINPAYME~FOR~MSDE~RIBEDABOVE' ~ 100.00 ...100,00 · .,:BP EXPLORATION (ALASKA).i::..INC., . -.-- P.O.. · -B0~ 196612 .... ;. NAt~QNiE':CI~.:BANK ...... .... ".~:; ." .:' . :QE~VE[~NO O'HIO ANCHORAGE;ALASKA" 99519-6612 - ' ;'.: .;::- ... ,: .... - ............ ..:.,- . :- .... - ..... :. , ..,..:.. . . : ....."' ::...... '.-. · ;~:- .. :: · .. ';:.. ' ' '..; ': :.. ' :":/::?; ....... ~ ::":"56-389'. 412 PAY To.. Th..e:~ 'i-~ DRiDER ONE HUNDRED: ::& 00:/100'~'~"~-'~'~'~'~'~'~'~'~~''~:'~'~''~'~''~'~'~''~~'~'~'~ USYDOLLAR ALASKA STATE :DEPT DF REVENUE AOGCC... ' ~.OO'! :ip'ORCUP I NE.-.::'DR .... AK 99501-3120 ANCHORAOE DATE "- AMOUNT O&/29/OO ] $100. O0 I ,,,oi.....~....~.~," ,~-- ~'~~...-.'" '"' ~ .~ ...~,~,, ,~0 ~.:'"S :~-,,. ':-",.%..'~. ~'i i:.;!! iil it, ~ ?0 ci ;i, ti"' t:O [, 2. EEl :~ ~ St: o0,q, h h ~ ct,' WELL PERMIT CHECKLIST COMPANY /~7~3 FIELD & POOL ~-'2... _ ADMINISTRATION WELL NAME -.~- ~ ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .......... ........ 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ...... '. 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... PROGRAM: exp ~ dev ~ GEOL AREA ~;;~ .~ N v' redrll serv ~ wellbore seg ~ ann. disposal para req ~ ON/OFF SHORE DATE 22. Adequate wellbore separation proposed ............. 23. If diverter 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 '~C~_ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... (~N_ 31. Data presented on potential overpressure zones ....... . .~ 32. Seismic analysis of shallow gas zones ............ ,/.~_.~'- Y N 33. Seabed condition survey (if off-shore) ......... ..,/'¢'../v' ' Y N 34. Contact name/phone for weekly progress reports [e,xlSloratory only] Y N II ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N N N GEOLOGY:. ENGINEERING: UIC/Annular TEM~ "~t/( ,,~ COMMISSION: Comments/Instructions: jo I°z c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File. APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No Special'effort has been made to.chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Jan 12 14:23:41 2001 Reel Header Service name ............. LISTPE Date ..................... 01/01/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/01/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-00120 ADAM WEAVER EDDIE VAUGHN MPI-09 500292296400 BP Exploration (Alaska) , Inc. Sperry-Sun Drilling Services 09-JAN-01 MWD RUN 2 AK-MM-00120 JACK FOLEY EDDIE VAUGHN 33 13N 10E 2331 3726 .00 62.25 34.50 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT 12.250 20.000 112.0 8.500 9.625 6561.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 COMPRISES DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. MWD RUN 2 COMPRISES DIRECTIONAL, DGR, EWR4, COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 4. DIGITAL AND LOG DATA ONLY ARE SHIFTED TO THE USIT WIRELINE GAMMA RAY LOG RUN ON 12 AUGUST 2000. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1 AND 2 REPRESENT WELL MPI-09 WITH API# 50-029-22964-00. THIS WELL REACHED A TOTAL DEPTH OF 13,094'MD/7197'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY SPSF = SMOOTHED NEUTRON POROSITY(SANDSTONE MATRIX, FIXED HOLE SIZE) SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD SALINITY: 10.0 PPG 300 PPM CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: 23,000 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE START DEPTH GR 58.0 RPX 67.5 RPS 67.5 RPM 67.5 RPD 67.5 FET 81.0 ROP 107.5 NPHI 6470.0 NCNT 6472.5 FCNT 6472.5 PEF 6483.5 RHOB 6563.5 RHOB 6563.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 16 17 18 19 20 22 22 25 27 27 28 28 8.0 135.5 146.0 161.0 8.5 9.0 5.5 1.0 8 5 3 0 7 5 1 5 0 0 7 5 2.0 4.5 GR 60.5 138.0 148.0 162.0 173.0 182.0 189.0 195.5 212.5 228.0 233 0 256 5 274 0 283 0 285 5 290 5 STOP DEPTH 13029 5 13040 0 13040 0 13040 0 13040 0 13040 0 13096 0 12993 0 12993 0 12993 0 13004 0 13004 0 13004 0 EQUIVALENT UNSHIFTED DEPTH 287.0 329.5 362.0 394.5 430.0 472.0 481.5 499.5 525.5 528.5 535.5 581.5 590.5 600.0 610.0 645.0 653.5 670.0 673.5 700.0 704.5 716.5 734.0 741 0 791 0 809 0 820 0 822 5 835 5 850 0 861 0 892 0 979 0 999 0 1051 5 1065 0 1073 5 1087 0 1108 5 1123 5 1142 0 1273.5 1303.0 1318.5 1329.5 1341.0 1351.5 1365.0 1385.5 1404.0 1409.5 1432.5 1481.0 1528.5 1614.0 1633.0 1641.5 1688.0 1704.5 1737.5 1754.0 292. 334. 366. 399. 436. 477. 488. 503. 531. 534. 541. 586. 596. 606. 615. 651. 660. 675. 680. 704. 709. 723. 740. 746. 796. 813. 824. 827 842 853 866 897 982 1004 1055 1066 1077 1090 1113 1128 1141 1276 1303 1323 1329 1346 1355 1367 1392 1410. 1417 1440 1485 1533 1617 1635 1644 1690 1706 1740 1756 1762.0 1775.0 1781.5 1837.5 1867.0 1880.0 1896.5 1906.5 1976 0 1990 5 2026 5 2036 0 2122 5 2151 0 2292 0 2343.0 2367.5 2380.5 2401.5 2413.0 2438.0 2474.0 2513.5 2529.5 2540.5 2562.0 2601.0 2605.5 2623.5 2652.5 2675.5 2696.0 2717 5 2736 5 2774 0 2795 0 2816 5 2829 5 2863 0 2880 0 2932 0 2974 0 2990.0 3068 5 3073 5 3081 0 3087 5 3105 5 3118 0 3122 5 3129 5 3147 0 3165 0 3221.0 3245.5 3255.0 3267.5 3289.5 3343.5 3374.5 3391.0 1764.5 1778.5 1784.0 1840.5 1869.0 1882.5 1899.0 1909.5 1977.5 1992.0 2027.5 2038.0 2127.5 2154.0 2293.0 2346.0 2370.0 2382.5 2402.5 2411.0 2436.0 2476.0 2516.0 2534.0 2544.0 2564.0 2604.0 2607.5 2626.0 2654.0 2677.0 2697.5 2720.0 2737.5 2775.0 2796.5 2819.0 2832.0 2865.0 2882.0 2934.5 2976.0 2995.5 3068.5 3075.0 3082.5 3087.5 3106.5 3118.5 3124.5 3131.5 3149.0 3168.5 3223.0 3247.0 3256.5 3268.0 3287.5 3341.0 3371.5 3388.5 3406.5 3418.0 3436.0 3452.5 3462.5 3495.0 3522.5 3535.5 3581.0 3621.5 3676.5 3755.5 3787.0 3831.0 3851.5 3862.5 3869.5 3872.0 3879.5 3903.0 3915.0 4050.5 4058 5 4077 5 4097 0 4122 0 4130 5 4153 5 4172 0 4187 5 4205 0 4210.5 4247.0 4258.0 4286 5 4301 5 4329 5 4354 5 4370 0 4377 0 4391 0 4496 5 4531.5 4541.0 4555.0 4568.5 4614.5 4640.0 4660.5 4666.0 4669.5 4705.5 4720.0 4725.5 4742°5 4777.5 4793.0 4842.0 4861.5 4877.5 4896.0 3402.5 3414.0 3429.5 3451.0 3458.5 3494.0 3524.0 3536.0 3583.0 3624.5 3678.5 3761.0 3790.5 3835.0 3853.0 3862.5 3870.5 3873.0 3883.5 3906.0 3918.0 4055.5 4062.5 4083.0 4103.5 4125.0 4132.5 4156.0 4174.0 4187.5 4203.0 4210.0 4249.0 4260.0 4291.0 4303.0 4330.0 4356.5 4375.5 4382.5 4394.0 4498.5 4533.0 4542.5 4555.5 4568.5 4613.5 4638.5 4659.5 4664.0 4669.0 4707.5 4722.0 4726.5 4744.5 4777.0 4792.0 4843.5 4862.5 4878.5 4897.0 491 492 495 499 502 504 5O5 508 513 515 5160 5163 5180 5195 5203 5207 5214 5238 5251 5268 5292 5310 5329 5349 5370 5388 5492 5498 5521 5564 5571 5633 5640 5649 5674 5692 5718 5751 5763 5770 5785 5788 5832 5837 5849 5865 5880 5906 5925 5945 6035 6064 6084 6104 6113 6138 6140 6146 6200 6213 6236 5.5 6.0 4.5 5.5 8.0 8.0 9.0 0.0 4.5 3.0 0 0 0 5 0 0 .0 5 5 0 0 0 5 0 0 5 0 5 5 0 0 0 0 5 0 0 5 5 5 0 0 5 0 0 5 0 5 5 .5 0 0 0 5 5 5 0 5 5 0 0 0 4916.5 4925.5 4953.0 4995.0 5028.0 5047.0 5059.5 5079.5 5133.5 5152.0 5156.5 5162.0 5180.5 5195.0 5205.0 5210.0 5215.0 5240 0 5251 5 5269 0 5295 0 5308 0 5329 5 5347.0 5366.5 5386.0 5493.0 5498.0 5522.0 5566.5 5573.5 5636.0 5641.5 5652.5 5677.5 5692.5 5720.5 5752.0 5762.5 5767.0 5785.0 5789.0 5832.0 5836.0 5851.0 5866.0 5881.0 5906.0 5927.0 5950.5 6037.5 6068.0 6087.5 6107.0 6116.5 6137.0 6141.0 6145.0 6200.0 6211.5 6237.0 6255.0 6255.5 6333.0 6333.5 6343.0 6342.0 6348.0 6347.0 6375.5 6374.0 6387.5 6385.5 13096.0 13094.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 $ # REMARKS: MERGED MAIN PASS. $ MERGE TOP 60.5 6468.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 6571.5 13094.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 N?HI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 58 13096 ROP MWD FT/H 0 497.36 GR MWD API 19.42 333.51 RPX MWD OHMM 0.25 1751.14 RPS MWD OHMM 0.06 2000 RPM MWD OHMM 0.12 2000 RPD MWD OHMM 0.13 2000 FET MWD HOUR 0.11 56.28 NPHI MWD PU-S 11.21 73.16 FCNT MWD CNTS 459 1171 NCNT MWD CNTS 2045 3222 Mean Nsam 6577 26077 154.265 25978 90.9548 25944 10.4653 25946 13. 2125 25946 17.1364 25946 21.9153 25946 0.955455 25919 40.3677 13047 743.118 13042 2472.28 13042 First Reading 58 107.5 58 67.5 67.5 67.5 67.5 81 6470 6472.5 6472.5 Last Reading 13096 13096 13029.5 13040 13040 13040 13040 13040 12993 12993 12993 RHOB MWD G/CM 2.045 3.323 DRHO MWD G/CM -0.22 0.443 PEF MWD BARN 0.48 13.04 2.37977 12882 0.0488526 12882 2.07528 13042 6563.5 6563.5 6483.5 13004 13004 13004 First Reading For Entire File .......... 58 Last Reading For Entire File ........... 13096 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC SEXP SESP SEDP SEMP SFXE SROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 60.5 70 0 70 0 70 0 70 0 83 5 110 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG STOP DEPTH 6521.5 6531 0 6531 0 6531 0 6531 0 6531 0 6571 5 02-AUG-00 Insite 5.46 Memory 6571.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .6 68.7 TOOL NUMBER PB01587CGR8 PB01587CGR8 PB01587CGR8 PB01587CGR8 12.250 20.0 Water Based 9.10 75.0 9.1 4OO 6.2 2. 600 1.981 2.100 2. 950 70.0 94.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 60.5 6571.5 ROP MWD010 FT/H 0 497.36 GR MWD010 API 19.42 135.64 RPX MWD010 OHMM 0.25 1751.14 RPS MWD010 OHMM 0.24 2000 RPM MWD010 OHMM 0.25 2000 RPD MWD010 OHMM 0.15 2000 FET MWD010 HOUR 0.11 4.02 First Mean Nsam Reading 3316 13023 60.5 166. 071 12924 110 71.7241 12923 60.5 17.7704 12923 70 23.253 12923 70 30.5982 12923 70 35.5532 12923 70 0.513993 12896 83.5 Last Reading 6571.5 6571.5 6521.5 6531 6531 6531 6531 6531 First Reading For Entire File .......... 60.5 Last Reading For Entire File ........... 6571.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit ~un in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 6468.0 FCNT 6470.5 NCNT 6470.5 PEF 6481.5 GR 6522.0 RPD 6531.5 RPX 6531.5 RPM 6531.5 FET 6531.5 RPS 6531.5 RHOB 6561.5 STOP DEPTH 12991 0 12991 0 12991 0 13002 0 13027 5 13038 0 13038 0 13038 0 13038 0 13038 0 13002 0 DRHO 6561.5 ROP 6572.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 13002.0 13094.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 09-AUG-00 Insite 65.41 Memory 13094.0 23.2 68.8 TOOL NUMBER PB01577NLP6 PB01577NLP6 PB01577NLP6 PB01577NLP6 8.500 9.6 Water Based 10.00 52.0 9.4 300 3.6 1.600 .889 1.300 1.500 67.0 126.0 67.0 67.0 Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 Name Service Unit Min Max DEPT FT 6468 13094 ROP MWD020 F?/H 0 406.58 GR MWD020 API 37.9 333.51 RPX MWD020 OHMM 0.29 15.48 RPS MWD020 OHMM 0.06 16.85 RPM MWD020 OHMM 0.12 2000 RPD MWD020 OHMM 0.13 2000 FET MWD020 HOUR 0.19 56.28 NPHI MWD020 PU-S 11.21 73.16 FCNT MWD020 CNTS 459 1171 NCNT MWD020 CNTS 2045 3222 RHOB MWD020 G/CM 2.045 3.323 DRHO MWD020 G/CM -0.22 0~443 PEF MWD020 BARN 0.48 13.04 Mean Nsam 9781 13253 142.368 13045 110.085 13012 3.22961 13014 3.29989 13014 3.80469 13014 8.47155 13014 1.3962 13014 40.3677 13047 743.118 13042 2472.28 13042 2.37977 12882 0.0488526 12882 2.07528 13042 First Reading 6468 6572 6522 6531.5 6531.5 6531.5 6531.5 6531.5 6468 6470.5 6470.5 6561.5 6561.5 6481.5 Last Reading 13094 13094 13027.5 13038 13038 13038 13038 13038 12991 12991 12991 13002 13002 13002 First Reading For Entire File .......... 6468 Last Reading For Entire File ........... 13094 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/01/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 01/01/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File