The URL can be used to link to this page

Home My WebLink About199-1142025-1030_Suspend_MPU_J-09A_wellsign_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10/30/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Suspended Well – Follow-up Petroleum Inspector MPU J-09A Hilcorp Alaska LLC PTD 1991140 10/30/2025: I traveled to Milne Point Unit J-pad to follow-up on a well sign issue observed during Guy Cook’s suspended well inspection on 9/2/2025. At issue was tape used on the well sign to adjust information to MPU J-09 and operator to Hilcorp Alaska LLC. When I arrived at MPU J-pad, I found the tape had been removed from the well name on the well sign revealing the correct well name – MPU J-09A. I was told by the Hilcorp representative at location that they are obtaining new well signs because tape used to change the operator name from BPXA to Hilcorp have been falling off at some wells. Attachments: Photos (2)    2025-1030_Suspend_MPU_J-09A_wellsign_ksj Page 2 of 2 Well Sign – MPU J-09A (PTD 1991140) Photo by G. Cook, 9/2/2025 Photo by K. StJohn, 10/30/2025 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/27/2025 InspectNo:susGDC250902175719 Well Pressures (psi): Date Inspected:9/2/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:4/5/2022 #322-010 Tubing:0 IA:0 OA:100 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:8/31/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT J-09A Permit Number:1991140 Wellhead Condition The wellhead is in good condition. No wellhouse protecting the well from the elements. There is a wellhead guard in place around the well. Surrounding Surface Condition Good clean gravel pad. Condition of Cellar Some water in the cellar. The cellar box consists of what appears to be to different sections that are not aligned or attached to one another exposing pad gravel lower than the top of the pad. Comments Well location verified by well-site pad map Supervisor Comments Photos (6) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, October 27, 2025            2025-0902_Suspend_MPU_J-09A_photos_gc Page 1 of 3 Suspended Well Inspection – MPU J-09A PTD 1991140 AOGCC Inspection Rpt # susGDC250902175719 Photos by AOGCC Inspector G. Cook 9/2/2025 2025-0902_Suspend_MPU_J-09A_photos_gc Page 2 of 3 Tree Cap Pressure Gauge (Tbg Pressure) IA Pressure Gauge 2025-0902_Suspend_MPU_J-09A_photos_gc Page 3 of 3 IA Pressure Gauge Well Cellar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´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y Anne Prysunka at 9:15 am, Nov 15, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ DSR-11/15/22WCB 11-29-2024 RBDMS JSB 111722 BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗>tϰͬϰͬϮϬϮϮ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϬϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϬͬϮϬϭϴ Wd͗ϭϵϵͲϭϭϰ dс ϴ͕Ϯϯϱ͛;DͿͬdсϰ͕Ϭϲϰ͛;dsͿ ϭϯͲϯͬϴ͟ < ůĞǀ͗͘ Ϯϵ͘ϲ͛ͬ'>ůĞǀ͗͘ϭϳ͘Ϭ͛ Kƌŝ ŐZ<͗Ϯϵ͘ϲ͛ ϳ͟ ϵͲϱͬϴ͟ dKΛϱϮϯϬ͛dD ϯͬϮϵͬϮϮ Wdс ϴ͕Ϯϯϱ͛;DͿͬWdсϰ͕Ϭϲϰ͛;dsͿ ϰͲϭͬϮ͟ ´%RQ]DL&RPSOHWLRQ Z+RUL]6ORWWHG/LQHU 0LOOHG´:LQGRZ# ¶WR¶¶ &OHDQRXWWR RQ 0LQ,' ´,' 0LQ,' ´,' 0LQ,' ´,' ´RI%ODVW5LQJV :KLSVWRFN6HW# ¶ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ,ͲϰϬͬEͬ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ ϭϭϮ͛ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ Ϯ͕ϵϯϲ͛ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬE^ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϱ͕ϯϯϰ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϭϵϵ͛ ϲ͕ϭϯϳ͛ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ ϲ͘Ϯͬ>ͲϴϬͬ^>d ϯ͘ϵϱϴ ϲ͕ϭϯϳ͛ ϴ͕Ϯϯϱ͛ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬh Ϯ͘ϴϲϳ ^ƵƌĨ ϱ͕ϮϬϴ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕Ϯϳϵ͛ ϯͲϭͬϮ͟ǆϭ͟<D''>D;^ŚĞĂƌsĂůǀĞ^Ğƚǁͬ<ůĂƚĐŚ͖^ŚĞĂƌĞĚͿ Ϯ ϱ͕Ϭϴϳ͛ ϯͲϭͬϮ͟y^ůŝĚŝŶŐ^ůǀ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/͖ ϯ ϱ͕ϭϭϭ͛ ϯͲϭͬϮ͟EW'Ͳ^ŝŶŐůĞͲĚƌŽƉ/ŶƚĂŬĞ'ĂƵŐĞ;Ϯ͘ϴϵϴ͟/Ϳ ϰ ϱ͕ϭϯϴ͛ ϯͲϭͬϮ͟yWƌŽĨŝůĞ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/Ϳ ϱ ϱ͕ϭϱϵ͛ ϳ͟ǆϯͲϭͬϮ͟ZĞƚƌŝĞǀĂďůĞ,ǇĚƌĂƵůŝĐ^ĞƚDZW,EZWĂĐŬĞƌ;Ϯ͘ϵϬϳ͟/Ϳ͕ϱϬŬƌĞůĞĂƐĞ ϲ ϱ͕ϭϴϲ͛ ϯͲϭͬϮ͟yEƉƌŽĨŝůĞ;DŝŶ/сϮ͘ϳϱ͟/EŽͲ'ŽͿ ϳ ϱ͕ϭϵϵ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌǁͬϲ͛dŝĞĂĐŬ;ϱ͘Ϯϱ͟/Ϳ ϴ ϱ͕ϮϬϳ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϬϴ͛Ϳ;Ϯ͘ϴϳϱ͟/Ϳ͖ƵƌŝĞĚϵ͛ŝŶƐŝĚĞůŝŶĞƌƚŽƉ ϵ ϱ͕Ϯϭϱ͛ ĂŬĞƌϱ͟ǆϳ͟,D>ŝŶĞƌ,ĂŶŐĞƌ;ϰ͘ϯϳϱ͟/Ϳ ϭϬ ϲ͕Ϭϭϯ͛ ĂŬĞƌ,DsĞŵĞŶƚsĂůǀĞ ϭϭ ϲ͕ϬϯϮ͛ ĂŬĞƌdϮϬ͛WWW ϭϮ ϴ͕ϭϵϬ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞWĂĐŬͲKĨĨƵƐŚŝŶŐ ϭϯ ϴ͕Ϯϯϱ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟Η ŵƚǁͬϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϱϳϮƐǆW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϰϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ ϰͲϭͬϮ͟ ŵƚǁͬϵϳƐŬƐůĂƐƐ͞'͟ŝŶϲͲϭͬϴ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϲϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϵĚĞŐ͘Λϯ͕ϯϬϬʹϯ͕ϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞс,ŽƌŝǌŽŶƚĂů dZΘt>>, dƌĞĞ ĂŵĞƌŽŶϯͲϭͬϴ͟ϱD tĞůůŚĞĂĚ t<Dϭϭ͟ǆϭϭ͟ϱD͕t<Dǁͬϭϭ͟ǆϯͲϭͬϮ͟ƚƵďŝŶŐŚĂŶŐĞƌͬh ƚŚƌĞĂĚƐƚŽƉĂŶĚďŽƚƚŽŵĂŶĚϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϰϵϱͲϬϭͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϭͬϭϰͬϭϵϵϱ ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϮͬϭϱͬϭϵϵϱ ^ĐŚƌĂĚĞƌůƵĨĨZĞĐŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϰͬϭϵͬϭϵϵϳ ^ĐŚƌĂĚĞƌůƵĨĨ^ĂŶĚdĞƐƚηϮʹϴͬϭϱͬϭϵϵϳ ^ŝĚĞƚƌĂĐŬĞĚǇEŽƌĚŝĐϯʹϭϮͬϭϱͬϭϵϵϵ ZtKďǇEĂďŽƌƐϰ^ʹϭͬϮϰͬϮϬϬϬ ZtKďǇEĂďŽƌƐϰ^ʹϭϮͬϭϭͬϮϬϬϯ ^WZtKďǇEĂďŽƌƐϯ^ʹϲͬϭϲͬϮϬϬϴ ZtKWWWƵŵƉďǇŽǇŽŶϭϲʹϰͬϭϯͬϮϬϭϯ ^WŚĂŶŐĞͲŽƵƚďǇEŽƌĚŝĐϯʹϰͬϮϵͬϮϬϭϱ d&ŝůůůĞĂŶͲŽƵƚͲϵͬϭϰͬϮϬϭϱ ^WWŚĂŶŐĞͲŽƵƚͲϭϮͬϰͬϮϬϭϱ ^ZϭŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉͲϰͬϭϬͬϮϬϭϴ d&ŝůůůĞĂŶͲŽƵƚͲϱͬϭϱͬϮϬϭϴ ZĞƐĞƌǀŽŝƌ^ƵƐƉĞŶƐŝŽŶďǇŽŝůĞĚdƵďŝŶŐʹϯͬϮϵͬϮϬϮϮ 0,/1( 3 2, 1 7 - 3 $ ' 6HF $'/ 81( 0,/1(32,1781,7 ) % &/ 6 (- ,.+ $ 0,1( &)3 ' * 0 0,1( 1 6 . 0226( 3$' 7(;$&2 0,/1(32,1781,7 038-3$' /2&$7,210$3 'DWH 'HFHPEHU 0DS$XWKRU +$.05$0DSRI 0DS&HQWHU&RRUGLQDWHV /$7 /21 1$''HFLPDO'HJUHHV 0DS,PDJHU\'DWH46, LQFK IHHW )HHW0DS6FDOH :HOO-$ Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 12/22/2022 InspectNo:susRCN221110110246 Well Pressures (psi): Date Inspected:11/5/2022 Inspector:Bob Noble If Verified, How?Other (specify in comments) Suspension Date:4/5/2022 #322-010 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Billy Krunskie Date AOGCC Notified:11/4/2022 Type of Inspection:Initial Well Name:MILNE PT UNIT J-09A Permit Number:1991140 Wellhead Condition Good clean well head with no signs of leaks or drips. All lines are blinded with guages. Surrounding Surface Condition Well protected with guard rail - no wellhouse. Condition of Cellar Cellar has good clean fresh snow in it. Comments Location verified with pad map. Supervisor Comments Photos (2) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Thursday, December 22, 2022 2022-1105_Suspend_MPU_J-09A_photos.docxPage 1 of 1 Suspended Well Inspection – MPU J-09AAOGCC Inspect # susRCN221110110246PTD 1991140Photos by AOGCC Inspector B. Noble 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 17.0' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 13-3/8" K-55 112' 9-5/8" L-80 2,529' 7" L-80 3,828' 4-1/2" L-80 4,046' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Gas-Oil Ratio: Flow Tubing Choke Size:Water-Bbl: PRODUCTION TEST Date of Test: Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information 26# 8,235' 29' 3,758' 54.5# 40# 112' 29' 5,334' CASING WT. PER FT.GRADE 12.6# 549396 549396 TOP SETTING DEPTH MD 32' 5,215' 32' 12-1/4" 250 sx Arctic Set (approx.) 31' 572 sx PF 'E', 250 sx Class 'G' 6017207 1,800' (approx.) SETTING DEPTH TVD 6017125 TOP ADL0025509, ADL0025517 HOLE SIZE AMOUNT PULLED suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 552129 6014741 4835' NSL, 634' WEL, SEC. 29, T13N, R10E 50-029-22495-01-00 Milne Point J-09A2347' NSL, 2090' EWL, SEC. 28, T13N, R10E N/A 12/10/1999 65.32' 4769'NSL, 2840' WEL, SEC. 29, T13N, R10E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG N/A Milne Point / Schrader Bluff Oil Gas 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 4/5/2022 12/7/1999 8,235' MD / 4,046' TVD 5,230' MD / 3,767' TVD 5,334' MD / 3,828' TVD 24" BOTTOM 31' 2,936' CEMENTING RECORD 5,208'3-1/2" SIZE DEPTH SET (MD) 5,159' MD / 3,727' PACKER SET (MD/TVD) 400 sx Class 'G'8-1/2" 199-114 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 97 sx Clas 'G'6-1/8" TUBING RECORD Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 1:01 pm, Apr 22, 2022 547180.2 Suspended 4/5/2022 MDG RBDMS 4/25/2022 MDG xG DLB 04-27-2022MGR05JUNE2023 DSR-4/25/22 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1,810 1,760 6,005' 4038' 5,406' 3,868' SBF1-NB 5,468' 3,897' SBE4 - NC 5,552' 3,930' 5,638' 3,955' SBE1 - NF 5,856' 4,003' 6,014' 4,040' Schrader Bluff Schrader Bluff 31. List of Attachments: Wellbore schematic and daily operations reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. David Haakinson Contact Name:Darci Horner Operations Manager Contact Email:dhorner@hilcorp.com Authorized Contact Phone:907-777-8406 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: SBE2 - NE SBF2 - NA TSBD - OA This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Top of Productive Interval If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.04.22 09:38:35 -08'00' David Haakinson (3533) _____________________________________________________________________________________ Revised By: DLW 4/4/2022 Milne Point Unit Well: MPU J-09A Last Completed: 4/10/2018 PTD: 199-114 TD =8,235’ (MD) / TD =4,064’(TVD) 13-3/8” KB Elev.: 29.6’/ GL Elev.: 17.0’ Ori g RKB: 29.6’ 7” 7 9 10 9-5/8” 11 12 13 TOC @5230’ CTM 3/29/22 PBTD =8,235’(MD) / PBTD =4,064’(TVD) 4-1/2” 4.5” Bonzai Completion w/ Horiz. Slotted Liner Milled 6-1/8” Window @ 5,334’ to 5,346’ (12’) Clean-out to 8,172 on 5/15/2018 5 2 4 3 6 8 Min ID = 2.813” ID Min ID = 2.813” ID 1 Min ID = 2.750” ID 18” of Blast Rings Whipstock Set @ 5,355’ 12/6/99 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / H-40 / N/A 12.615 Surface 112’ 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 2,936’ 7" Intermediate 26 / L-80 / NSCC 6.276 Surface 5,334’ 4-1/2” Liner 12.6 / L-80 / IBT 3.958 5,199’ 6,137’ 4-1/2” Slotted Liner 6.2 / L-80 / SLT 3.958 6,137’ 8,235’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 2.867 Surf 5,208’ JEWELRY DETAIL No Depth Item 1 2,279’ 3-1/2” x 1” KBMG GLM (Shear Valve Set w/ BK latch; Sheared) 2 5,087’ 3-1/2” XD Sliding Slv (2.813” Packing Bore Min ID; 3 5,111’ 3-1/2” NDPG-C Single-drop Intake Gauge (2.898” ID) 4 5,138’ 3-1/2” X Profile (2.813” Packing Bore Min ID) 5 5,159’ 7” x 3-1/2” Retrievable Hydraulic Set MRP HNBR Packer (2.907” ID), 50k release 6 5,186’ 3-1/2” XN profile (Min ID = 2.75” ID No-Go) 7 5,199’ Baker ZXP Liner Top Packer w/ 6’ Tie Back (5.25” ID) 8 5,207’ Wireline Entry Guide (Btm at 5,208’) (2.875” ID); Buried 9’ inside liner top 9 5,215’ Baker 5” x 7” HMC Liner Hanger (4.375” ID) 10 6,013’ Baker HMCV Cement Valve 11 6,032’ Baker CTC 20’ PZP ECP 12 8,190’ 4.5” Baker Drillable Pack-Off Bushing 13 8,235’ 4.5” Baker Drillable Guide Shoe OPEN HOLE / CEMENT DETAIL 13-3/8”" Cmt w/ 250 sx of Arcticset I in 24” Hole 9-5/8" Cmt w/ 572sx PF “E”, 250 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 400 sx Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 97 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 59 deg. @ 3,300 – 3,500’ MaxHole Angle = Horizontal TREE & WELLHEAD Tree Cameron 3-1/8” 5M Wellhead WKM 11” x 11” 5M, WKM w/ 11” x 3-1/2” tubing hanger/ EUE threads top and bottom and 3” CIW H PBV Profile GENERAL WELL INFO API: 50-029-22495-01-00 Drilled and Cased by Nabors 22E - 1/14/1995 Completion by Nabors 4ES – 2/15/1995 Schrader Bluff Recompletion by Nabors 4ES – 4/19/1997 Schrader Bluff Sand Test #2 – 8/15/1997 Sidetracked By Nordic 3 – 12/15/1999 RWO by Nabors 4ES – 1/24/2000 RWO by Nabors 4ES – 12/11/2003 ESP RWO by Nabors 3S – 6/16/2008 RWO PCP Pump by Doyon 16 – 4/13/2013 ESP Change-out by Nordic 3 – 4/29/2015 CT Fill Clean-out - 9/14/2015 ESPCP Change-out - 12/4/2015 ASR 1 Convert to Jet Pump - 4/10/2018 CT Fill Clean-out - 5/15/2018 Reservoir Suspension by Coiled Tubing – 3/29/2022 Well Name Rig API Number Well Permit Number Start Date End Date MP J-09A CTU #9 50-029-22495-01-00 199-114 3/26/2022 3/29/2022 Hilcorp Alaska, LLC Weekly Operations Summary Continue to chase gel to surface 1:1 returns. On surface w/BHA. Flush coil and BOP stack. WOC compressive. Sent 24 hr notice for AOGCC witness test and tag TOC. RIH and tag TOC at 5237'. Wait on on AOGCC inspector. AOGCC witnessed tag on TOC @ 5,237' ctm in compression 8k down, 5,230' @ neutral weight. Performed AOGCC witnessed MIT-Tubing to 1855 psi, lost 82 psi 1st 15 minutes, lost 23 psi 2nd 15 minutes. Test passed. Pooh w/BHA. Begin RDMO CTU9. Completed weekly BOP test. N/U BOP stack and function test on wellhead. Make up BHA = 2.15" x .29' CTC, 2" x 1.1' DFCV, 2" x 4.75' Stinger x 2, 2.30" x .57' JSN. BHA OAL = 11.46'. RIH w/BHA = 2.30" JSN. Tagged 8,211' ctm / 8,222’ mechanical. Tag multiple times, pick up weight off bottom = 24k. Flag pipe @ 8,150’. Contact OE to discuss tag depth/plan forward. Mobilize HES cement and Worley GeoVis/Contam. Pooh w/BHA. depth @ 04:30 am = 3,500’ Pooh. 3/26/2022 - Saturday WOC compressive. MU and RIH w/ 2.27" BDJSN. Well started to pressure up 1200' ctm. Tagged 5,587' ctm. PUH and FP well 2000' TVD. RIH & tag TOC = 5601' ctm. PJSM w/HES to pump cement. CEMENT WET 21:08 PM. Layed in 8 bbls of 15.8 ppg class G cement from 5,601' - 4970', PUH to 4500'. Load & launch 3/4" ball. Contaminate cement with 10 bbls of geovis and cleanout to 5,195' ctm. Chase gel to surface 1:1 returns. On surface w/BHA. Flush coil and BOP stack. WOC compressive. Sent 24 hr notice for AOGCC witness test and tag TOC (3/29/22 @ 00:30 am). 3/29/2022 - Tuesday 3/27/2022 - Sunday RIH w/BHA = 2.30" JSN. Tagged 8,211' ctm multiple times, pu weight off bottom = 24k. Contact OE to discuss tag depth/plan forward. Pooh w/BHA. Make up 2.27" BDJSN & RIH. At flag depth 8,152' ctm. Reciprocate pipe until rig is clear of the access road. Loaded the tubing w/ KCL. Hung up 8,037' ctm. Worked pipe and came free. PUH into 3.5" tubing at 5,175' ctm. Discuss plan forward w/OE. Dry drift and tag bottom @ 8,213' ctm. Pull up hole into 3.5" tubing to 5,175' ctm with no issues, RIH to flag 8,150' ctm. PJSM w/HES cement. Open choke for returns, WHP = 2 psi. Layed in 50 bbls of 15.8 ppg class G cement in liner. Adjust coil speed and pump rate to attempt 1:1 returns while laying in cement. Losing cement to formation (BHP=1040 psi). Pump rate .6 bpm, .4 bpm returns. With 50 bbls cement out nozzle had 28 bbls total returns, estimated 22 bbls lost to formation. Estimated TOC = 6,384'. FP coil while Pooh w/BHA. On surface begin flushing coil with KCI, Geovis, and diesel to open top tank while WOC. 3/28/2022 - Monday Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1991140 Type Inj N Tubing 0 1665 1546 1501 Type Test P Packer TVD 3722 BBL Pump 1.5 IA 62 64 61 61 Interval O Test psi 1500 BBL Return OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1991140 Type Inj N Tubing 1492 1855 1773 1750 Type Test P Packer TVD 3722 BBL Pump 0.1 IA 62 62 60 61 Interval O Test psi 1500 BBL Return 1.3 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:AOGCC MIT-TBG for P&A. Test lost 82 psi 1st 15 minutes, lost 23 psi the 2nd 15 minutes. Test passed. Notes: Notes: Hilcorp Alask, LLC Milne Point / MPU / J Pad Austin McLeod Eli Wilson 03/29/22 Notes:AOGCC MIT-TBG for P&A. Test passed by 1 psi. After discussing results with Austin McLeod, recommended a 2nd test to verify results. Notes: Notes: Notes: J-09A J-09A Form 10-426 (Revised 01/2017)MIT-T MPU J-09A 03-29-2022 for P&A 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. From:Darci Horner - (C) To:Guhl, Meredith D (OGC) Subject:FW: looking for x and y coordinates for Milne Point J-09A Date:Monday, April 25, 2022 10:24:16 AM Hi Meredith, Oops. I made a typo when transcribing the Xs provided by our geologist. The bottom hole X should have been 547180 as shown in the email below, which is within the +/- 10 feet discrepancy. That’s on me. I apologize. Thanks, Darci From: Katharine Cunha <Katharine.Cunha@hilcorp.com> Sent: Monday, April 18, 2022 4:26 PM To: Stuart Sanchez <Stuart.Sanchez@hilcorp.com>; Nathan Sperry <Nathan.Sperry@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com> Subject: RE: looking for x and y coordinates for Milne Point J-09A Hi Guys, I have some J-09A info for you. Please let me know if you have any questions. J-09A X Y TVDSS MD SHL 552129.2 6014741 65 0 BHL 547180.2 6017125 -3981 8235 TPI (Top Oa Sand within Schrader Bluff) 549396.2 6017207 -3973 6005 Thanks, Katie From: Stuart Sanchez <Stuart.Sanchez@hilcorp.com> Sent: Monday, April 18, 2022 3:31 PM To: Nathan Sperry <Nathan.Sperry@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Katharine Cunha <Katharine.Cunha@hilcorp.com> Subject: RE: looking for x and y coordinates for Milne Point J-09A Thank you Nate. From: Nathan Sperry <Nathan.Sperry@hilcorp.com> Sent: Monday, April 18, 2022 3:20 PM To: Stuart Sanchez <Stuart.Sanchez@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Katharine Cunha <Katharine.Cunha@hilcorp.com> Subject: RE: looking for x and y coordinates for Milne Point J-09A Hi guys, Katie is the j-pad geologist. We will need the top of the productive horizon from her (either in MD, TVD, or TVDss – I can look up the other values once I have one of them). I can also pull the BHL from the surveys. Thx, Nate Sperry Drilling Engineer Hilcorp Alaska, LLC O: 907-777-8450 C: 907-301-8996 From: Stuart Sanchez Sent: Monday, April 18, 2022 2:52 PM To: Darci Horner - (C) <dhorner@hilcorp.com>; Nathan Sperry <Nathan.Sperry@hilcorp.com> Subject: RE: looking for x and y coordinates for Milne Point J-09A Nate, Can you help Darci with her request, I would but don’t have the information for MPU J-09A TPH and BHL. Only SHL. Stuart From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Thursday, April 14, 2022 1:26 PM To: Stuart Sanchez <Stuart.Sanchez@hilcorp.com> Subject: looking for x and y coordinates for Milne Point J-09A Hi Stuart, Are you the right person to ask for some x and y coordinates for a Milne Point well? If not, just let me know, k? I don’t often fill out 10-407 forms for the AOGCC, but this month I have to submit one for J-09A. I think the only info that is missing is the location of well (State Base Plane coordinates, NAD 27) as you can see highlighted in the attached form. I believe the top of the productive interval would be the top of the slotted liner at 6,137’ MD as shown on the attached schematic but please correct me if you think that isn’t the case. Can you provide the x an y coordinates for the surface, TPI and bottom hole locations? Thank you! Darci Horner Technologist Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com 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. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 28 Township: 13N Range: 10E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 8,235 ft MD Lease No.: ADL 0025517 Operator Rep: Suspend: X P&A: Conductor: 13-3/8" O.D. Shoe@ 112 Feet Csg Cut@ NA Feet Surface: 9-5/8" O.D. Shoe@ 2,936 Feet Csg Cut@ NA Feet Intermediate: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production: 7" O.D. Shoe@ 5,334 Feet Csg Cut@ NA Feet Liner: 4-1/2" O.D. Shoe@ 8,235 Feet Csg Cut@ NA Feet Tubing: 3-1/2" O.D. Tail@ 5,208 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bottom 8,235 ft MD 5,230 ft MD 6.8ppg C.T. Tag Initial 15 min 30 min 45 min Result Tubing 1665 1546 1501 IA 64 61 61 OA 0 0 0 Initial 15 min 30 min 45 min Result Retest Tubing 1855 1773 1750 IA 62 60 61 OA 0 0 0 Remarks: Attachments: I traveled to Coil Tubing Unit #9 to witness the tag and pressure test of a cement plug that had been set in the well's 4-1/2-inch liner string. Cement was in place (CIP) at 01:00 3/29/2022. Planned top of cement (TOC) was 5,200 ft MD. With the 2.27-inch assembly they started taking weight at 5,230 ft MD with 8k set down at 5,237 ft MD. The tag was 30-foot low (0.5 barrels). This depth has the cement outside the 3-1/2-inch tubing tail but a full column to the well's Total Depth. Witnessed two passing pressure tests. Due to being extremely close to the failing pressure test criteria, I requested they bump back up and retest. March 29, 2022 Austin McLeod Plug Verification Milne Point Unit J-09A Hilcorp Alaska LLC PTD 1991140; Sundry 322-010 none Plugging Data: Test Data: P Casing Removal: Eli Wilson P Casing/Tubing Data (depths are MD): rev. 11-28-18 2022-0329_Plug_Verfication_MPU_J-09A_am 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 99 9 9 1501 gppg Due to being extremely close to the failing pressure test criteria, I requested they bump back up and retest. ) tag was 30-foot low (0.5 barrels) p( 8k set down at 5,237 ft MD. James B. Regg Digitally signed by James B. Regg Date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y Samantha Carlisle at 9:48 am, Jan 11, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ '65 6)' 6)' 0*5-$1 VXVSHQVLRQ KRXUQRWLFHIRU$2*&&WRZLWQHVVWDJDQG0,77WRSVL :HOOVLWHLQVSHFWLRQZLWKLQPRQWKVIROORZLQJLQLWLDOLQVSHFWLRQUHTXLUHGZLWKLQGD\VRIVXVSHQGHGZHOOLQVSHFWLRQ dts 1/26/2022 JLC 1/26/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.26 12:00:11 -09'00' RBDMS HEW 1/28/2022 ZĞƐĞƌǀŽŝƌ ^ƵƐƉĞŶƐŝŽŶ tĞůů͗ DW:ͲϬϵ ĂƚĞ͗ ϭͬϳͬϮϬϮϮ tĞůůEĂŵĞ͗DWh :ͲϬϵW/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϰϵϱͲϬϭͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗&ůŽǁŝŶŐ KŝůtĞůů ΀:ĞƚWƵŵƉ΁ WĂĚ͗DŝůŶĞWŽŝŶƚ :ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶƵĂƌǇϯϬƚŚ ϮϬϮϮ ZŝŐ͗dhηϲ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϵͲϭϭϰ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀŝĚ'Žƌŵ ;ϵϬϳͿϳϳϳͲϴϯϯϯ;KͿ ;ϱϬϱͿϮϭϱͲϮϴϭϵ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ & EƵŵďĞƌ͗:ŽďdǇƉĞ͗ZĞƐĞƌǀŽŝƌ^ƵƐƉĞŶƐŝŽŶ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϭ͕ϭϵϭ ƉƐŝΛ ϰ͕ϬϱϬ͛ds ;>ĂƐƚ,WŵĞĂƐƵƌĞĚϭ͕ϬϰϬ ƉƐŝ ϬϳͬϭϮͬϮϬϮϭͿ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗ϭ͕ϭϵϭ ƉƐŝΛϰ͕ϬϱϬ͛ds ;EŽŶĞǁƉĞƌĨƐďĞŝŶŐĂĚĚĞĚͿ DW^W͗ϳϴϲ ƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭϬƉƐŝͬĨƚŐĂƐ ŐƌĂĚŝĞŶƚͿ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ dŚĞDŝůŶĞWŽŝŶƚ:ͲϬϵǁĞůůǁĂƐƌĞĚƌŝůůĞĚĂƐĂ^ĐŚƌĂĚĞƌůƵĨĨĚĞǀĞůŽƉŵĞŶƚǁĞůůƚŚĂƚd͛ĚĂƚϴ͕Ϯϯϱ͛ĂŶĚƌĂŶ ϮϮũƚƐŽĨƐŽůŝĚϰ͘ϱ͟ůŝŶĞƌĂŶĚ ϰ͘ϱ͟ƐůŽƚƚĞĚůŝŶĞƌ ĨƌŽŵϲ͕ϭϯϳ͛DƚŽd ŝŶƚŽŽƉĞŶŚŽůĞŝŶĞĐĞŵďĞƌϭϵϵϵ͘dŚĞǁĞůů ǁĂƐŝŶŝƚŝĂůůǇĐŽŵƉůĞƚĞĚǁŝƚŚĂƚŚƌŽƵŐŚƚƵďŝŶŐ^WW;ůĞĐƚƌŝĐĂů^ƵďŵĞƌƐŝďůĞWƌŽŐƌĞƐƐŝǀĞĂǀŝƚǇWƵŵƉͿďƵƚ ĨĂŝůĞĚ ŝŵŵĞĚŝĂƚĞůǇƵƉŽŶŝŶƐƚĂůů͘dŚŝƐǁĂƐƌĞƉůĂĐĞĚǁŝƚŚĂŶ^WŝŶ:ĂŶƵ ĂƌǇϮϬϬϬ͘dŚŝƐĨĂŝůĞĚĂŶĚƐƵďƐĞƋƵĞŶƚ ^WƐǁĞƌĞ ƌĞƉůĂĐĞĚŝŶϮϬϬϯĂŶĚϮϬϬϴ͘dŚĞƚƌĂĚŝƚŝŽŶĂů^WǁĂƐƌĞƉůĂĐĞĚǁŝƚŚĂŶ^WWŝŶϮϬϭϯ͘dŚĂƚƉƵŵƉĨĂŝůĞĚ&ĞďƌƵĂƌǇ ϵ͕ϮϬϭϱ͘dŚĞƉƵŵƉǁĂƐƌĞƉůĂĐĞĚŝŶDĂǇϮϬϭϱ͘ƵƌŝŶŐĂƉŽǁĞƌŽƵƚĂŐĞŝŶƵŐƵƐƚϮϬϭϱ͕ƚŚĞǁĞůůǁĂƐƵŶĂďůĞƚŽ ƐƵƐƚĂŝŶĨůŽǁĚƵĞƚŽƐŽůŝĚƐďƵŝůĚ ƵƉŝŶƐŝĚĞƚŚĞƚƵďŝŶŐ͘d&K ĐůĞĂŶĞĚŽƵƚƐĂŶĚƚŽƚŚĞƚŽƉŽĨƚŚĞ^WWŝŶ ^ĞƉƚĞŵďĞƌ ϮϬϭϱ͘dŚĞ^WWŝƐƐƚŝůůĞůĞĐƚƌŝĐĂůůǇĞĨĨĞĐƚŝǀĞ͕ďƵƚƵŶĂďůĞƚŽƐƵƌĨĂĐĞĨůƵŝĚƐ͘dŚĞƌĞ ǁĞƌĞ ŵŝŶŝŵĂů ŽďƐĞƌǀĞĚƐĐĂůĞŝƐƐƵĞƐ͕ŵŽƐƚĨĂŝůƵƌĞƐĂƌĞƌĞůĂƚĞĚƚŽƐŽůŝĚƐƉƌŽĚƵĐƚŝŽŶ͘ dŚĞ^WWǁĂƐŵŽƐƚƌĞĐĞŶƚůǇĐŚĂŶŐĞĚŽƵƚ ŝŶĞĐĞŵďĞƌϮϬϭϱ͘/ŶϮϬϭϴƚŚĞ^WĐŽŵƉůĞƚŝŽŶǁĂƐ ƉƵůůĞĚ͕ ĂŶĚĂ:WĐŽŵƉůĞƚŝŽŶǁĂƐŝŶƐƚĂůůĞĚ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x ^ƵĐĐĞƐƐĨƵůD/dͲ/ƚŽϯ͕ϬϬϬƉƐŝ Λϱ͕ϭϱϵ͛D^ ŽŶ ϬϰͬϭϭͬϮϬϭϴ͘ x dŚĞǁĞůůŝƐĐƵƌƌĞŶƚůǇŽŶůŝŶĞĨůŽǁŝŶŐĂƚĂƉƉƌŽǆŝŵĂƚĞůǇϲϱďŽƉĚ͘ x EĞǁƉƵŵƉ ;ϴͿ ƐĞƚďǇƐůŝĐŬůŝŶĞ ŽŶ ϭϭͬϬϳͬϮϬϮϭ͘ KďũĞĐƚŝǀĞ͗ ZĞƐĞƌǀŽŝƌ^ƵƐƉĞŶƐŝŽŶŽĨƚŚĞK>ĂƚĞƌĂů͘ dŚĞƉůĂŶŶĞĚƌĞĚĞǀĞůŽƉŵĞŶƚƉĂƚƚĞƌŶĨŽƌƚŚĞ /ͲWĂĚ^ĐŚƌĂĚĞƌůƵĨĨƌĞƋƵŝƌĞƐƚŚŝƐ KͲƐĂŶĚůĂƚĞƌĂůƚŽďĞƐƵƐƉĞŶĚĞĚ ƉƌŝŽƌƚŽĚƌŝůůŝŶŐĨƵƚƵƌĞǁĞůůDW/ͲϯϬŝ ĚƵĞƚŽĐƌŽƐƐŝŶŐƚŚĞƉůĂŶŶĞĚŝŶũĞĐƚŽƌƚŽĞŶƐƵƌĞƉƌŽƉĞƌƌĞƐĞƌǀŽŝƌĨůŽŽĚŝŶŐ͘DW :ͲϬϵ ŵƵƐƚďĞƐƵƐƉĞŶĚĞĚƚŽ Εϴ͕Ϯϯϱ͛D ;WdͿ ƚŽŚĞůƉŵŝŶŝŵŝǌĞƉŽƚĞŶƚŝĂůĐŽŵŵƵŶŝĐĂƚŝŽŶ;D͛ƐͿ ŽŶĨƵƚƵƌĞ/Ͳ ƉĂĚƌĞĚĞǀĞůŽƉŵĞŶƚǁĞůůƐ͘ ^ůŝĐŬůŝŶĞ WƌŽĐĞĚƵƌĞ͗ ϭ͘ D/Zh^>͘ Ϯ͘ Z/,ĂŶĚƉƵůůũĞƚƉƵŵƉĨƌŽŵ ϱ͕Ϭϴϳ͛D͘WKK,͘ ϯ͘ DhƐŚŝĨƚŝŶŐƚŽŽů͘ ϰ͘ Z/,ĂŶĚĐůŽƐĞ,^͞y͟ƵƌĂƐůŝĚŝŶŐƐůĞĞǀĞΛ ϱ͕Ϭϴϳ͛D͘ ϱ͘ WƌĞƐƐƵƌĞƵƉƚŚĞ/ƚŽϭ͕ϱϬϬƉƐŝƚŽ ĐŽŶĨŝƌŵƐůĞĞǀĞĐůŽƐĞĚ͘ dŚĞƉůĂŶŶĞĚƌĞĚĞǀĞůŽƉŵĞŶƚƉĂƚƚĞƌŶĨŽƌƚŚĞ /ͲWĂĚ^ĐŚƌĂĚĞƌůƵĨĨƌĞƋƵŝƌĞƐƚŚŝƐ KͲƐĂŶĚůĂƚĞƌĂůƚŽďĞƐƵƐƉĞŶĚĞĚ ƉƌŝŽƌƚŽĚƌŝůůŝŶŐĨƵƚƵƌĞǁĞůůDW/ͲϯϬŝ ĚƵĞƚŽĐƌŽƐƐŝŶŐƚŚĞƉůĂŶŶĞĚŝŶũĞĐƚŽƌƚŽĞŶƐƵƌĞƉƌŽƉĞƌƌĞƐĞƌǀŽŝƌĨůŽŽĚŝŶŐ͘ ZĞƐĞƌǀŽŝƌ ^ƵƐƉĞŶƐŝŽŶ tĞůů͗ DW:ͲϬϵ ĂƚĞ͗ ϭͬϳͬϮϬϮϮ ŽŝůĞĚdƵďŝŶŐ WƌŽĐĞĚƵƌĞ͗ ;ƉƉƌŽǀĞĚ^ƵŶĚƌǇƌĞƋƵŝƌĞĚƉƌŝŽƌƚŽƉƌŽĐĞĞĚŝŶŐͿ ϭ͘ D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚĂŶĚƐƉŽƚĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚ͘&ŝůůƐŽ ƵƌĐĞƚĂŶŬǁͬϭй<ů͘ Ϯ͘ WƌĞƐƐƵƌĞƚĞƐƚKWƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>Žǁ͕ϭϬŵŝŶ,ŝ͕ϱŵŝŶ>ŽǁĞĂĐŚ ƚĞƐƚ͘ Ă͘ /ĨǁŝƚŚŝŶƚŚĞƐƚĂŶĚĂƌĚϳͲĚĂǇƚĞƐƚKWƚĞƐƚƉĞƌŝŽĚĨŽƌDŝůŶĞWŽŝŶƚ͕ĂĨƵůůďŽĚǇƚĞƐƚĂŶĚĨƵŶĐƚŝŽŶ ƚĞƐƚŽĨƚŚĞƌĂŵƐŝƐƐƵĨĨŝĐŝĞŶƚ͘ ď͘ ĂĐŚƐƵďƐĞƋƵĞŶƚƚĞƐƚŽĨƚŚĞůƵďƌŝĐĂƚŽƌǁŝůůďĞƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>ŽǁƚŽĐŽŶĨŝƌŵŶŽůĞĂŬƐ͘ ϯ͘ Z/,ǁͬϮ͟ dǁͬ:^E ĂŶĚĐůĞĂŶŽƵƚ,ĂŶĚĐůĞĂŶŽƵƚƚŽWdĂƚнͬͲ ϴ͕Ϯϯϱ͛D͘WKK,͘ ;ZĞǀŝĞǁ,K͛Ɛ ĂŶĚǁĞůůďŽƌĞ/͛ƐǁŝƚŚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌͿ͘ Ă͘ ƵĞƚŽƚŚĞĂŶƚŝĐŝƉĂƚĞĚ>Žǁ,W͕ĂƚƚĞŵƉƚƚŽĐŝƌĐƵůĂƚĞĂŶĚƉƵƐŚĂŶǇƐŽůŝĚƐďĂĐŬŽƵƚŝŶƚŽ ĨŽƌŵĂƚŝŽŶ͘ ϰ͘ WKK,͘ ϱ͘ DhďĂůůĚƌŽƉĐĞŵĞŶƚŝŶŐŶŽǌǌůĞĂŶĚ Z/,ƚŽ ϴ͕Ϯϯϱ͛ŽƌĚĞĞƉĞƐƚĚĞƉƚŚƌĞĂĐŚĞĚĚƵƌŝŶŐ&K͘ ϲ͘ ZhĐĞŵĞŶƚĞƌƐ͘ ϳ͘ DŝǆĂŶĚƉƵŵƉ ϱϬ ďďůƐŽĨϭϱ͘ϴƉƉŐůĂƐƐ'ĐĞŵĞŶƚĚŽǁŶƚŚĞĐŽŝůƚƵďŝŶŐƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞ ϯͲϭͬϮ͟ ƚƵďŝŶŐ ;ůŝŵŝƚĞĚƚŽŶŽƌĞƚƵƌŶƐŵĂǇďĞŽďƐĞƌǀĞĚͿ͘hƐĞĨƌĞƐŚǁĂƚĞƌƐƉĂĐĞƌƐĂƐŶĞĞĚĞĚ ĂƌŽƵŶĚƚŚĞĐĞŵĞŶƚ͘ Ă͘ŽŶƚĂĐƚŶŐŝŶĞĞƌĂŶĚĂĚũƵƐƚǀŽůƵŵĞďĂƐĞĚŽŶĨŝŶĂůĐůĞĂŶŽƵƚĚĞƉƚŚƌĞĂĐŚĞĚ ď͘ ϰͲϭͬϮ͟ůŝŶĞƌǀŽů͗Ϭ͘ϬϭϱϮϭ ǆ;ϴ͕Ϯϯϱ͛ ʹ ϱ͕ϮϬϬ͛ͿсΕϰϲ ďďůƐ Đ͘ ϰ ďďůƐŽĨƐƉĂƌĞǀŽůƵŵĞƚŽƐƋƵĞĞǌĞĂǁĂǇŽƌĐŽŶƚĂŵŝŶĂƚĞ͘ ϴ͘ ůůŽǁΕϭďďů ŽĨĐĞŵĞŶƚĂƌŽƵŶĚƚŚĞĐĞŵĞŶƚŝŶŐŶŽǌǌůĞĂŶĚůĂǇƚŚĞ ƌĞƐƚŽĨƚŚĞĐĞŵĞŶƚŝŶ ďĂĐŬƚŽϱ͕ϮϬϬ͛ D͘ ;ǆƉĞĐƚ ŶŽƚ ƚŽ ŚĂǀĞƌĞƚƵƌŶƐ͕ƌĞǀŝĞǁƉůĂŶƐǁŝƚŚŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌƉƵŵƉŝŶŐĂŶĚWKK,ďĂƐĞĚŽŶ ǀŽůƵŵĞƐ͘Ϳ ϵ͘ Wh ϱϬϬ͛ ϭϬ͘ ^ǁĂƉƚŽĐŽŶƚĂŵŝŶĂƚĞĂŶĚZ/,ƚŽ ϱ͕ϮϬϬ͛D;ƉůĂŶŶĞĚ dKͿ͘ ϭϭ͘ WKK,ĂŶĚĐŝƌĐƵůĂƚĞĐŽŝůƚƵďŝŶŐĐůĞĂŶĂƐŶĞĞĚĞĚ͘ Ă͘ &ƌĞĞǌĞƉƌŽƚĞĐƚǁĞůůŽŶǁĂǇŽƵƚŽĨŚŽůĞ ĂƐŶĞĞĚĞĚ͘ ϭϮ͘ tĂŝƚŽŶĐĞŵĞŶƚƚŽŐĂŝŶ ĂŵŝŶŝŵƵŵ ϭ͕ϬϬϬƉƐŝĐŽŵƉƌĞƐƐŝǀĞƐƚƌĞŶŐƚŚ͘ ϭϯ͘ WƌĞƐƐƵƌĞƚĞƐƚƚŚĞĐĞŵĞŶƚƚŽϭ͕ϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ;ĐŚĂƌƚĞĚͿ͘ /ĨƚŚĞƉůƵŐƚĞƐƚƐ ŐŽŽĚ͕d/,ǁŝƚŚŽŝůĂŶĚ ƚĂŐƚŚĞdK͕ƉůĂŶŶĞĚdKΛϱ͕ϮϬϬ͛D͘;ŽŶƚĂĐƚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌǁŝƚŚĨŝŶĂůƚĂŐĚĞƉƚŚ͘Ϳ Ă͘ /ĨƚŚĞƉƌĞƐƐƵƌĞƚĞƐƚŽĨƚŚĞĐĞŵĞŶƚƉůƵŐĨĂŝůƐ͕ĐŽŶƚĂĐƚƚŚĞKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌƚŽĚŝƐĐƵƐƐ ƉƵŵƉŝŶŐĂĚĚŝƚŝŽŶĂůĐĞŵĞŶƚ͘ ď͘ EŽƚŝĨǇK'ϮϰŚŽƵƌƐ ŝŶĂĚǀĂŶĐĞƚŽǁŝƚŶĞƐƐ ƚĂŐĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚ͘ ϭϰ͘ WKK, ĨƌĞĞǌĞƉƌŽƚĞĐƚŝŶŐĂƐŶĞĞĚĞĚ͘ ϭϱ͘ ZdƵŶŝƚ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůĞĚdƵďŝŶŐ KW^ĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭͬϮϰͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϬϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϬͬϮϬϭϴ Wd͗ϭϵϵͲϭϭϰ dс ϴ͕Ϯϯϱ͛;DͿͬdсϰ͕Ϭϲϰ͛;dsͿ ϭϯͲϯͬϴ͟ < ůĞǀ͗͘ Ϯϵ͘ϲ͛ͬ'>ůĞǀ͗͘ϭϳ͘Ϭ͛ Kƌŝ ŐZ<͗Ϯϵ͘ϲ͛ ϳ͟ ϵͲϱͬϴ͟ dKΛ цϱ͕ϮϬϬ͛ Wdс ϴ͕Ϯϯϱ͛;DͿͬWdсϰ͕Ϭϲϰ͛;dsͿ ϰͲϭͬϮ͟ ´%RQ]DL&RPSOHWLRQ Z+RUL]6ORWWHG/LQHU 0LOOHG´:LQGRZ# ¶WR¶¶ &OHDQRXWWR RQ 0LQ,' ´,' 0LQ,' ´,' 0LQ,' ´,' ´RI%ODVW5LQJV :KLSVWRFN6HW# ¶ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ,ͲϰϬͬEͬ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ ϭϭϮ͛ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ Ϯ͕ϵϯϲ͛ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬE^ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϱ͕ϯϯϰ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϭϵϵ͛ ϲ͕ϭϯϳ͛ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ ϲ͘Ϯͬ>ͲϴϬͬ^>d ϯ͘ϵϱϴ ϲ͕ϭϯϳ͛ ϴ͕Ϯϯϱ͛ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬh Ϯ͘ϴϲϳ ^ƵƌĨ ϱ͕ϮϬϴ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕Ϯϳϵ͛ ϯͲϭͬϮ͟ǆϭ͟<D''>D;^ŚĞĂƌsĂůǀĞ^Ğƚǁͬ<ůĂƚĐŚ͖^ŚĞĂƌĞĚͿ Ϯϱ͕Ϭϴϳ͛ϯͲϭͬϮ͟y^ůŝĚŝŶŐ^ůǀ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/͖ΎΎΎ^Ğƚϳ:WŽŶϭϮͬϮϭͬϮϬΎΎΎ ϯ ϱ͕ϭϭϭ͛ ϯͲϭͬϮ͟EW'Ͳ^ŝŶŐůĞͲĚƌŽƉ/ŶƚĂŬĞ'ĂƵŐĞ;Ϯ͘ϴϵϴ͟/Ϳ ϰ ϱ͕ϭϯϴ͛ ϯͲϭͬϮ͟yWƌŽĨŝůĞ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/Ϳ ϱ ϱ͕ϭϱϵ͛ ϳ͟ǆϯͲϭͬϮ͟ZĞƚƌŝĞǀĂďůĞ,ǇĚƌĂƵůŝĐ^ĞƚDZW,EZWĂĐŬĞƌ;Ϯ͘ϵϬϳ͟/Ϳ͕ϱϬŬƌĞůĞĂƐĞ ϲ ϱ͕ϭϴϲ͛ ϯͲϭͬϮ͟yEƉƌŽĨŝůĞ;DŝŶ/сϮ͘ϳϱ͟/EŽͲ'ŽͿ ϳ ϱ͕ϭϵϵ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌǁͬϲ͛dŝĞĂĐŬ;ϱ͘Ϯϱ͟/Ϳ ϴ ϱ͕ϮϬϳ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϬϴ͛Ϳ;Ϯ͘ϴϳϱ͟/Ϳ͖ƵƌŝĞĚϵ͛ŝŶƐŝĚĞůŝŶĞƌƚŽƉ ϵ ϱ͕Ϯϭϱ͛ ĂŬĞƌϱ͟ǆϳ͟,D>ŝŶĞƌ,ĂŶŐĞƌ;ϰ͘ϯϳϱ͟/Ϳ ϭϬ ϲ͕Ϭϭϯ͛ ĂŬĞƌ,DsĞŵĞŶƚsĂůǀĞ ϭϭ ϲ͕ϬϯϮ͛ ĂŬĞƌdϮϬ͛WWW ϭϮ ϴ͕ϭϵϬ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞWĂĐŬͲKĨĨƵƐŚŝŶŐ ϭϯ ϴ͕Ϯϯϱ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟Η ŵƚǁͬϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϱϳϮƐǆW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϰϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ ϰͲϭͬϮ͟ ŵƚǁͬϵϳƐŬƐůĂƐƐ͞'͟ŝŶϲͲϭͬϴ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϲϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϵĚĞŐ͘Λϯ͕ϯϬϬʹϯ͕ϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞс,ŽƌŝǌŽŶƚĂů dZΘt>>, dƌĞĞ ĂŵĞƌŽŶϯͲϭͬϴ͟ϱD tĞůůŚĞĂĚ t<Dϭϭ͟ǆϭϭ͟ϱD͕t<Dǁͬϭϭ͟ǆϯͲϭͬϮ͟ƚƵďŝŶŐŚĂŶŐĞƌͬh ƚŚƌĞĂĚƐƚŽƉĂŶĚďŽƚƚŽŵĂŶĚϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϰϵϱͲϬϭͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϭͬϭϰͬϭϵϵϱ ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϮͬϭϱͬϭϵϵϱ ^ĐŚƌĂĚĞƌůƵĨĨZĞĐŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϰͬϭϵͬϭϵϵϳ ^ĐŚƌĂĚĞƌůƵĨĨ^ĂŶĚdĞƐƚηϮʹϴͬϭϱͬϭϵϵϳ ^ŝĚĞƚƌĂĐŬĞĚǇEŽƌĚŝĐϯʹϭϮͬϭϱͬϭϵϵϵ ZtKďǇEĂďŽƌƐϰ^ʹϭͬϮϰͬϮϬϬϬ ZtKďǇEĂďŽƌƐϰ^ʹϭϮͬϭϭͬϮϬϬϯ ^WZtKďǇEĂďŽƌƐϯ^ʹϲͬϭϲͬϮϬϬϴ ZtKWWWƵŵƉďǇŽǇŽŶϭϲʹϰͬϭϯͬϮϬϭϯ ^WŚĂŶŐĞͲŽƵƚďǇEŽƌĚŝĐϯʹϰͬϮϵͬϮϬϭϱ d&ŝůůůĞĂŶͲŽƵƚϵͬϭϰͬϮϬϭϱ ^WWŚĂŶŐĞͲŽƵƚϭϮͬϰͬϮϬϭϱ ^ZϭŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉϰͬϭϬͬϮϬϭϴ d&ŝůůůĞĂŶͲŽƵƚϱͬϭϱͬϮϬϭϴ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭͬϮϰͬϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϬϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϬͬϮϬϭϴ Wd͗ϭϵϵͲϭϭϰ dс ϴ͕Ϯϯϱ͛;DͿͬdсϰ͕Ϭϲϰ͛;dsͿ ϭϯͲϯͬϴ͟ < ůĞǀ͗͘ Ϯϵ͘ϲ͛ͬ'>ůĞǀ͗͘ϭϳ͘Ϭ͛ Kƌŝ ŐZ<͗Ϯϵ͘ϲ͛ ϳ͟ ϵͲϱͬϴ͟ Wdс ϴ͕Ϯϯϱ͛;DͿͬWdсϰ͕Ϭϲϰ͛;dsͿ ϰͲϭͬϮ͟ ´%RQ]DL&RPSOHWLRQ Z+RUL]6ORWWHG/LQHU &OHDQRXWWR RQ 0LQ,' ´,' 0LQ,' ´,' 0LQ,' ´,' ´RI%ODVW5LQJV :KLSVWRFN6HW# ¶ 0LOOHG´:LQGRZ# ¶WR¶¶ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ,ͲϰϬͬEͬ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ ϭϭϮ͛ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ Ϯ͕ϵϯϲ͛ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬE^ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϱ͕ϯϯϰ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϭϵϵ͛ ϲ͕ϭϯϳ͛ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ ϲ͘Ϯͬ>ͲϴϬͬ^>d ϯ͘ϵϱϴ ϲ͕ϭϯϳ͛ ϴ͕Ϯϯϱ͛ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬh Ϯ͘ϴϲϳ ^ƵƌĨ ϱ͕ϮϬϴ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕Ϯϳϵ͛ ϯͲϭͬϮ͟ǆϭ͟<D''>D;^ŚĞĂƌsĂůǀĞ^Ğƚǁͬ<ůĂƚĐŚ͖^ŚĞĂƌĞĚͿ Ϯϱ͕Ϭϴϳ͛ϯͲϭͬϮ͟y^ůŝĚŝŶŐ^ůǀ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/͖ΎΎΎ^Ğƚϳ:WŽŶϭϮͬϮϭͬϮϬΎΎΎ ϯ ϱ͕ϭϭϭ͛ ϯͲϭͬϮ͟EW'Ͳ^ŝŶŐůĞͲĚƌŽƉ/ŶƚĂŬĞ'ĂƵŐĞ;Ϯ͘ϴϵϴ͟/Ϳ ϰ ϱ͕ϭϯϴ͛ ϯͲϭͬϮ͟yWƌŽĨŝůĞ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/Ϳ ϱ ϱ͕ϭϱϵ͛ ϳ͟ǆϯͲϭͬϮ͟ZĞƚƌŝĞǀĂďůĞ,ǇĚƌĂƵůŝĐ^ĞƚDZW,EZWĂĐŬĞƌ;Ϯ͘ϵϬϳ͟/Ϳ͕ϱϬŬƌĞůĞĂƐĞ ϲ ϱ͕ϭϴϲ͛ ϯͲϭͬϮ͟yEƉƌŽĨŝůĞ;DŝŶ/сϮ͘ϳϱ͟/EŽͲ'ŽͿ ϳ ϱ͕ϭϵϵ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌǁͬϲ͛dŝĞĂĐŬ;ϱ͘Ϯϱ͟/Ϳ ϴ ϱ͕ϮϬϳ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϬϴ͛Ϳ;Ϯ͘ϴϳϱ͟/Ϳ͖ƵƌŝĞĚϵ͛ŝŶƐŝĚĞůŝŶĞƌƚŽƉ ϵ ϱ͕Ϯϭϱ͛ ĂŬĞƌϱ͟ǆϳ͟,D>ŝŶĞƌ,ĂŶŐĞƌ;ϰ͘ϯϳϱ͟/Ϳ ϭϬ ϲ͕Ϭϭϯ͛ ĂŬĞƌ,DsĞŵĞŶƚsĂůǀĞ ϭϭ ϲ͕ϬϯϮ͛ ĂŬĞƌdϮϬ͛WWW ϭϮ ϴ͕ϭϵϬ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞWĂĐŬͲKĨĨƵƐŚŝŶŐ ϭϯ ϴ͕Ϯϯϱ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟Η ŵƚǁͬϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϱϳϮƐǆW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϰϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ ϰͲϭͬϮ͟ ŵƚǁͬϵϳƐŬƐůĂƐƐ͞'͟ŝŶϲͲϭͬϴ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϲϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϵĚĞŐ͘Λϯ͕ϯϬϬʹϯ͕ϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞс,ŽƌŝǌŽŶƚĂů dZΘt>>, dƌĞĞ ĂŵĞƌŽŶϯͲϭͬϴ͟ϱD tĞůůŚĞĂĚ t<Dϭϭ͟ǆϭϭ͟ϱD͕t<Dǁͬϭϭ͟ǆϯͲϭͬϮ͟ƚƵďŝŶŐŚĂŶŐĞƌͬh ƚŚƌĞĂĚƐƚŽƉĂŶĚďŽƚƚŽŵĂŶĚϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϰϵϱͲϬϭͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϭͬϭϰͬϭϵϵϱ ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϮͬϭϱͬϭϵϵϱ ^ĐŚƌĂĚĞƌůƵĨĨZĞĐŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϰͬϭϵͬϭϵϵϳ ^ĐŚƌĂĚĞƌůƵĨĨ^ĂŶĚdĞƐƚηϮʹϴͬϭϱͬϭϵϵϳ ^ŝĚĞƚƌĂĐŬĞĚǇEŽƌĚŝĐϯʹϭϮͬϭϱͬϭϵϵϵ ZtKďǇEĂďŽƌƐϰ^ʹϭͬϮϰͬϮϬϬϬ ZtKďǇEĂďŽƌƐϰ^ʹϭϮͬϭϭͬϮϬϬϯ ^WZtKďǇEĂďŽƌƐϯ^ʹϲͬϭϲͬϮϬϬϴ ZtKWWWƵŵƉďǇŽǇŽŶϭϲʹϰͬϭϯͬϮϬϭϯ ^WŚĂŶŐĞͲŽƵƚďǇEŽƌĚŝĐϯʹϰͬϮϵͬϮϬϭϱ d&ŝůůůĞĂŶͲŽƵƚϵͬϭϰͬϮϬϭϱ ^WWŚĂŶŐĞͲŽƵƚϭϮͬϰͬϮϬϭϱ ^ZϭŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉϰͬϭϬͬϮϬϭϴ d&ŝůůůĞĂŶͲŽƵƚϱͬϭϱͬϮϬϭϴ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗E>tϭϮͬϮϭͬϮϬϮϬ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϬϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϬͬϮϬϭϴ Wd͗ϭϵϵͲϭϭϰ dс ϴ͕Ϯϯϱ͛;DͿͬdсϰ͕Ϭϲϰ͛;dsͿ ϭϯͲϯͬϴ͟ <ůĞǀ͗͘Ϯϵ͘ϲ͛ͬ'>ůĞǀ͗͘ϭϳ͘Ϭ͛ Kƌŝ ŐZ<͗Ϯϵ͘ϲ͛ ϳ͟ ϵͲϱͬϴ ͟ Wdс ϴ͕Ϯϯϱ͛;DͿͬWdсϰ͕Ϭϲϰ͛;dsͿ ϰͲϭͬϮ͟ ´%RQ]DL&RPSOHWLRQ Z+RUL]6ORWWHG/LQHU 0LOOHG´:LQGRZ# ¶WR¶¶ &OHDQRXWWR RQ 0LQ,' ´,' 0LQ,' ´,' 0LQ,' ´,' ´RI%ODVW5LQJV ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ,ͲϰϬͬEͬ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ ϭϭϮ͛ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ Ϯ͕ϵϯϲ͛ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬE^ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϱ͕ϯϯϰ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϭϵϵ͛ ϲ͕ϭϯϳ͛ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ ϲ͘Ϯͬ>ͲϴϬͬ^>d ϯ͘ϵϱϴ ϲ͕ϭϯϳ͛ ϴ͕Ϯϯϱ͛ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬh Ϯ͘ϴϲϳ ^ƵƌĨ ϱ͕ϮϬϴ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕Ϯϳϵ͛ ϯͲϭͬϮ͟ǆϭ͟<D''>D;^ŚĞĂƌsĂůǀĞ^Ğƚǁͬ<ůĂƚĐŚ͖^ŚĞĂƌĞĚͿ Ϯϱ͕Ϭϴϳ͛ϯͲϭͬϮ͟y^ůŝĚŝŶŐ^ůǀ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/͖ΎΎΎ^Ğƚϳ:WŽŶϭϮͬϮϭͬϮϬΎΎΎ ϯ ϱ͕ϭϭϭ͛ ϯͲϭͬϮ͟EW'Ͳ^ŝŶŐůĞͲĚƌŽƉ/ŶƚĂŬĞ'ĂƵŐĞ;Ϯ͘ϴϵϴ͟/Ϳ ϰ ϱ͕ϭϯϴ͛ ϯͲϭͬϮ͟yWƌŽĨŝůĞ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/Ϳ ϱ ϱ͕ϭϱϵ͛ ϳ͟ǆϯͲϭͬϮ͟ZĞƚƌŝĞǀĂďůĞ,ǇĚƌĂƵůŝĐ^ĞƚDZW,EZWĂĐŬĞƌ;Ϯ͘ϵϬϳ͟/Ϳ͕ϱϬŬƌĞůĞĂƐĞ ϲ ϱ͕ϭϴϲ͛ ϯͲϭͬϮ͟yEƉƌŽĨŝůĞ;DŝŶ/сϮ͘ϳϱ͟/EŽͲ'ŽͿ ϳ ϱ͕ϭϵϵ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌǁͬϲ͛dŝĞĂĐŬ;ϱ͘Ϯϱ͟/Ϳ ϴ ϱ͕ϮϬϳ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϬϴ͛Ϳ;Ϯ͘ϴϳϱ͟/Ϳ͖ƵƌŝĞĚϵ͛ŝŶƐŝĚĞůŝŶĞƌƚŽƉ ϵ ϱ͕Ϯϭϱ͛ ĂŬĞƌϱ͟ǆϳ͟,D>ŝŶĞƌ,ĂŶŐĞƌ;ϰ͘ϯϳϱ͟/Ϳ ϭϬ ϲ͕Ϭϭϯ͛ ĂŬĞƌ,DsĞŵĞŶƚsĂůǀĞ ϭϭ ϲ͕ϬϯϮ͛ ĂŬĞƌdϮϬ͛WWW ϭϮ ϴ͕ϭϵϬ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞWĂĐŬͲKĨĨƵƐŚŝŶŐ ϭϯ ϴ͕Ϯϯϱ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟Η ŵƚǁͬϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϱϳϮƐǆW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϰϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ ϰͲϭͬϮ͟ ŵƚǁͬϵϳƐŬƐůĂƐƐ͞'͟ŝŶϲͲϭͬϴ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϲϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϵĚĞŐ͘Λϯ͕ϯϬϬʹϯ͕ϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞс,ŽƌŝǌŽŶƚĂů dZΘt>>, dƌĞĞ ĂŵĞƌŽŶϯͲϭͬϴ͟ϱD tĞůůŚĞĂĚ t<Dϭϭ͟ǆϭϭ͟ϱD͕t<Dǁͬϭϭ͟ǆϯͲϭͬϮ͟ƚƵďŝŶŐŚĂŶŐĞƌͬh ƚŚƌĞĂĚƐƚŽƉĂŶĚďŽƚƚŽŵĂŶĚϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϰϵϱͲϬϭͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϭͬϭϰͬϭϵϵϱ ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϮͬϭϱͬϭϵϵϱ ^ĐŚƌĂĚĞƌůƵĨĨZĞĐŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϰͬϭϵͬϭϵϵϳ ^ĐŚƌĂĚĞƌůƵĨĨ^ĂŶĚdĞƐƚηϮʹϴͬϭϱͬϭϵϵϳ ^ŝĚĞƚƌĂĐŬĞĚǇEŽƌĚŝĐϯʹϭϮͬϭϱͬϭϵϵϵ ZtKďǇEĂďŽƌƐϰ^ʹϭͬϮϰͬϮϬϬϬ ZtKďǇEĂďŽƌƐϰ^ʹϭϮͬϭϭͬϮϬϬϯ ^WZtKďǇEĂďŽƌƐϯ^ʹϲͬϭϲͬϮϬϬϴ ZtKWWWƵŵƉďǇŽǇŽŶϭϲʹϰͬϭϯͬϮϬϭϯ ^WŚĂŶŐĞͲŽƵƚďǇEŽƌĚŝĐϯʹϰͬϮϵͬϮϬϭϱ d&ŝůůůĞĂŶͲŽƵƚϵͬϭϰͬϮϬϭϱ ^WWŚĂŶŐĞͲŽƵƚϭϮͬϰͬϮϬϭϱ ^ZϭŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉϰͬϭϬͬϮϬϭϴ d&ŝůůůĞĂŶͲŽƵƚϱͬϭϱͬϮϬϭϴ 6XSHUFHGHG BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗E>tϭͬϭϬͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϬϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϬͬϮϬϭϴ Wd͗ϭϵϵͲϭϭϰ dс ϴ͕Ϯϯϱ͛;DͿͬdсϰ͕Ϭϲϰ͛;dsͿ ϭϯͲϯͬϴ͟ <ůĞǀ͗͘Ϯϵ͘ϲ͛ͬ'>ůĞǀ͗͘ϭϳ͘Ϭ͛ Kƌŝ ŐZ<͗Ϯϵ͘ϲ͛ ϳ͟ ϵͲϱͬϴ ͟ dKΛ цϱ͕ϮϮϬϬ͛ Wdс ϴ͕Ϯϯϱ͛;DͿͬWdс ϰ͕Ϭϲϰ͛;dsͿ ϰͲϭͬϮ͟ ´%RQ]DL&RPSOHWLRQ Z+RUL]6ORWWHG/LQHU 0LOOHG´:LQGRZ# ¶WR¶¶ &OHDQRXWWR RQ 0LQ,' ´,' 0LQ,' ´,' 0LQ,' ´,' ´RI%ODVW5LQJV ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ,ͲϰϬͬEͬ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ ϭϭϮ͛ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ Ϯ͕ϵϯϲ͛ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬE^ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϱ͕ϯϯϰ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϭϵϵ͛ ϲ͕ϭϯϳ͛ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ ϲ͘Ϯͬ>ͲϴϬͬ^>d ϯ͘ϵϱϴ ϲ͕ϭϯϳ͛ ϴ͕Ϯϯϱ͛ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬh Ϯ͘ϴϲϳ ^ƵƌĨ ϱ͕ϮϬϴ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕Ϯϳϵ͛ ϯͲϭͬϮ͟ǆϭ͟<D''>D;^ŚĞĂƌsĂůǀĞ^Ğƚǁͬ<ůĂƚĐŚ͖^ŚĞĂƌĞĚͿ Ϯϱ͕Ϭϴϳ͛ϯͲϭͬϮ͟y^ůŝĚŝŶŐ^ůǀ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/͖ΎΎΎ^Ğƚϳ:WŽŶϭϮͬϮϭͬϮϬΎΎΎ ϯ ϱ͕ϭϭϭ͛ ϯͲϭͬϮ͟EW'Ͳ^ŝŶŐůĞͲĚƌŽƉ/ŶƚĂŬĞ'ĂƵŐĞ;Ϯ͘ϴϵϴ͟/Ϳ ϰ ϱ͕ϭϯϴ͛ ϯͲϭͬϮ͟yWƌŽĨŝůĞ;Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞDŝŶ/Ϳ ϱ ϱ͕ϭϱϵ͛ ϳ͟ǆϯͲϭͬϮ͟ZĞƚƌŝĞǀĂďůĞ,ǇĚƌĂƵůŝĐ^ĞƚDZW,EZWĂĐŬĞƌ;Ϯ͘ϵϬϳ͟/Ϳ͕ϱϬŬƌĞůĞĂƐĞ ϲ ϱ͕ϭϴϲ͛ ϯͲϭͬϮ͟yEƉƌŽĨŝůĞ;DŝŶ/сϮ͘ϳϱ͟/EŽͲ'ŽͿ ϳ ϱ͕ϭϵϵ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌǁͬϲ͛dŝĞĂĐŬ;ϱ͘Ϯϱ͟/Ϳ ϴ ϱ͕ϮϬϳ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϬϴ͛Ϳ;Ϯ͘ϴϳϱ͟/Ϳ͖ƵƌŝĞĚϵ͛ŝŶƐŝĚĞůŝŶĞƌƚŽƉ ϵ ϱ͕Ϯϭϱ͛ ĂŬĞƌϱ͟ǆϳ͟,D>ŝŶĞƌ,ĂŶŐĞƌ;ϰ͘ϯϳϱ͟/Ϳ ϭϬ ϲ͕Ϭϭϯ͛ ĂŬĞƌ,DsĞŵĞŶƚsĂůǀĞ ϭϭ ϲ͕ϬϯϮ͛ ĂŬĞƌdϮϬ͛WWW ϭϮ ϴ͕ϭϵϬ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞWĂĐŬͲKĨĨƵƐŚŝŶŐ ϭϯ ϴ͕Ϯϯϱ͛ ϰ͘ϱ͟ĂŬĞƌƌŝůůĂďůĞ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟Η ŵƚǁͬϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϱϳϮƐǆW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϰϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ ϰͲϭͬϮ͟ ŵƚǁͬϵϳƐŬƐůĂƐƐ͞'͟ŝŶϲͲϭͬϴ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϲϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϱϵĚĞŐ͘Λϯ͕ϯϬϬʹϯ͕ϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞс,ŽƌŝǌŽŶƚĂů dZΘt>>, dƌĞĞ ĂŵĞƌŽŶϯͲϭͬϴ͟ϱD tĞůůŚĞĂĚ t<Dϭϭ͟ǆϭϭ͟ϱD͕t<Dǁͬϭϭ͟ǆϯͲϭͬϮ͟ƚƵďŝŶŐŚĂŶŐĞƌͬh ƚŚƌĞĂĚƐƚŽƉĂŶĚďŽƚƚŽŵĂŶĚϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϰϵϱͲϬϭͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϭͬϭϰͬϭϵϵϱ ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϮͬϭϱͬϭϵϵϱ ^ĐŚƌĂĚĞƌůƵĨĨZĞĐŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϰͬϭϵͬϭϵϵϳ ^ĐŚƌĂĚĞƌůƵĨĨ^ĂŶĚdĞƐƚηϮʹϴͬϭϱͬϭϵϵϳ ^ŝĚĞƚƌĂĐŬĞĚǇEŽƌĚŝĐϯʹϭϮͬϭϱͬϭϵϵϵ ZtKďǇEĂďŽƌƐϰ^ʹϭͬϮϰͬϮϬϬϬ ZtKďǇEĂďŽƌƐϰ^ʹϭϮͬϭϭͬϮϬϬϯ ^WZtKďǇEĂďŽƌƐϯ^ʹϲͬϭϲͬϮϬϬϴ ZtKWWWƵŵƉďǇŽǇŽŶϭϲʹϰͬϭϯͬϮϬϭϯ ^WŚĂŶŐĞͲŽƵƚďǇEŽƌĚŝĐϯʹϰͬϮϵͬϮϬϭϱ d&ŝůůůĞĂŶͲŽƵƚϵͬϭϰͬϮϬϭϱ ^WWŚĂŶŐĞͲŽƵƚϭϮͬϰͬϮϬϭϱ ^ZϭŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉϰͬϭϬͬϮϬϭϴ d&ŝůůůĞĂŶͲŽƵƚϱͬϭϱͬϮϬϭϴ 6XSHUFHGHG ZĞƐĞƌǀŽŝƌďĂŶĚŽŶŵĞŶƚ tĞůů͗DWh:ͲϬϵ ϭϮͲϭϯͲϮϬϮϭ K/>KW sĂůǀĞ͕^ǁĂď͕t<DͲD͕ ϰϭͬϭϲϱD& sĂůǀĞ͕hƉƉĞƌDĂƐƚĞƌ͕ĂŬĞƌ͕ ϰϭͬϭϲϱD&͕ǁͬ,ǇĚƌĂƵůŝĐ EϮͲϬϮ ϯϬyϮϬyϭϯдyϵзyϳyϰЪ ŽŝůdƵďŝŶŐKW sĂůǀĞ͕>ŽǁĞƌDĂƐƚĞƌ͕t<DͲD͕ ϰϭͬϭϲϱD& ůŝŶĚͬ^ŚĞĂƌ ůŝŶĚͬ^ŚĞĂƌ >ƵďƌŝĐĂƚŽƌƚŽŝŶũĞĐƚŝŽŶ ŚĞĂĚ ϰϭͬϭϲϭϬD ^ůŝƉ ^ůŝƉ ůŝŶĚͬ^ŚĞĂƌ ůŝŶĚͬ^ŚĞĂƌ WŝƉĞ WŝƉĞ DĂŶƵĂů'ĂƚĞ ϮϭͬϴϱD ϮдΗ^ŝŶŐůĞ^ƚƌŝƉƉĞƌ ƌŽƐƐŽǀĞƌƐƉŽŽů ϰϭͬϭϲϭϬDyϰϭͬϭϲϱD DĂŶƵĂů'ĂƚĞ ϮϭͬϴϱD dƵďŝŶŐĚĂƉƚĞƌ͕ϰϭͬϭϲϱD WƵŵƉͲ/Ŷ^Ƶď ϰϭͬϭϲϱD ϭϱϬϮhŶŝŽŶ STATE OF ALASKA • iKA OIL AND GAS CONSERVATION CO SION RRT OF SUNDRY WELL OPE TIONS MAY 3 0 2018 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate Li Pull Tubing Lis 4_• tit wn U Performed: Suspend 111 Perforate El Other Stimulate El Alter Casing❑ Change pprove rogram ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:CT Clean-out w/N2 Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development Q Exploratory❑ 199-114 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: AK 99503 50-029-22495-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 MILNE PT UNIT J-09A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Schrader Bluff Oil 11.Present Well Condition Summary: Total Depth measured 8,235 feet Plugs measured N/A feet true vertical 4,064 feet Junk measured N/A feet Effective Depth measured 8,235 feet Packer measured 5,199 feet true vertical 4,064 feet true vertical 3,749 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' N/A N/A Surface 2,936' 9-5/8" 2,936' 2,529' 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,828' 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' 4,050' 8,430psi 7,500psi Slotted Liner 2,098' 4-1/2" 8,235' 4,046' N/A N/A Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3/L-80/EUE 8 rd 5,208' 3,754' _ 5,199'MD Packers and SSSV(type,measured and true vertical depth) ZXP Packer N/A 3,749'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A SCOW JUN 2 1 ,LU 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 280 0 Subsequent to operation: 22 1 0 2,556 238 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D Exploratory❑ Development0 Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SP UG❑ 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: 318-185 Sfil Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilCorp.com Authorized Signature: 9, -- Date: 5/30/2018 Contact Phone: 777-8412 . Form 10-404 Revised 4/2017 "ii? RBDM MAY 3 1206 Submit Original Only tir • • Milne Point Unit Well: MPU J-09A SCHEMATIC Last Completed: 4/10/2018 Ilileorp Alaska,LLC PTD: 199-114 KBEIev.:29.6'/GLEIev.:17.0' TREE&WELLHEAD Orifi RKB:29.6' Tree Cameron 3-1/8"5M WKM 11"x 11"5M,WKM w/11"x 3-1/2"tubing hanger/EUE . Wellhead § threads top and bottom and 3"CIW H PBV Profile 4. 3/8OPEN HOLE/CEMENT DETAIL :1.4! ;1 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 111/4"Hole . / v 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 1.' 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole A . CASING DETAIL 9-5/8"74 ei' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/H-40/N/A 12.615 Surface 112' 1 18"of Blast Ri s 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 2,936' 7" Intermediate 26/L-80/NSCC 6.276 Surface 5,334' 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 3, 4-1/2" Slotted Liner 6.2/1-80/SLT 3.958 6,137' 8,235' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 2.867 Surf 5,208' WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=59 deg. @ 3,300—3,500' MaxHole Angle=Horizontal JEWELRY DETAIL No Depth Item 1 2,279' 3-1/2"x 1"KBMG GLM(Shear Valve Set w/BK latch;Sheared) 2 5,087' 3-1/2"XD Sliding Sleeve(2.813"Packing Bore Min ID;Opened on 5/15/18) Mn ID=2813"ID CE t:; 2 3 5,111' 3-1/2"NDPG-C Single-drop Intake Gauge(2.898"ID) 4 5,138' 3-1/2"X Profile(2.813"Packing Bore Min ID) 3 5 5,159' 7"x 3-1/2"Permanent Hydraulic Set MRP HNBR Packer(2.907"ID),50k release 6 5,186' 3-1/2"XN profile(Min ID=2.75"ID No-Go) ( 7 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) r 8 5,207' Wireline Entry Guide(Btm at 5,208')(2.875"ID);Buried 9'inside liner top Mn ID=2.813"ID 4 k: t 9 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) i 31 i _ 5 10 6,013' Baker HMCV Cement Valve 1Lm 11 6,032' Baker CTC 20'PZP ECP 12 8,190' 4.5"Baker Drillable Pack-Off Bushing s 9 13 8,235' 4.5"Baker Drillable Guide Shoe MnID=2.750'ID ;,4 6 GENERAL WELL INFO 1 API:50-029-22495-01-00 tg 7 Drilled and Cased by Nabors 22E -1/14/1995 4.5"Bonzai Completion 1(,, Completion by Nabors 4E5—2/15/1995 w/Hort.Slotted Liner 401- f 9 Schrader Bluff Recompletion by Nabors 4ES—4/19/1997 �,y Schrader Bluff Sand Test#2—8/15/1997 Sidetracked By Nordic 3—12/15/1999 ili, fi. �1 RWO by Nabors 4ES—1/24/2000 killed 61/8"Wndow @ RWO by Nabors 4ES—12/11/2003 6334to5,340(12) 111111; ESP RWO by Nabors 3S—6/16/2008 RWO PCP Pump by Doyon 16—4/13/2013 111111 . ESP Change-out by Nordic 3—4/29/2015 Clean-out to 8,172 cn 5/15/2018 111111 I; CT Fill Clean-out 9/14/2015 { ESPCP Change-out 12/4/2015 1111111 ASR 1 Convert to let Pump 4/10/2018 CT Fill Clean-out 5/15/2018 411/2" 1111111 12 13 TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:TDF 5/30/2018 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP J-09A Slickline 50-029-22495-01-00 199-114 5/6/18 5/15/18 Daily Operations: 5/2/2018-Wednesday No activity to report. 5/3/2018-Thursday No activity to report. 5/4/2018 - Friday No activity to report. 5/5/2018-Saturday No activity to report. 5/6/2018-Sunday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. BRUSH & FLUSH XD-SS AT 5,087' MD WITH LRS. PUMPING 20bbls DIESEL. CLOSE XD-SS AT 5087' MD. LRS MIT-IA 1500psi TO CONFIRM XD-SS CLOSED (pass, see LRS log). RDMO, NOTIFY PAD-O. 5/7/2018- Monday No activity to report. 5/8/2018-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPJ 09A Slickline 50-029-22495-01-00 199-114 5/6/18 5/15/18 Daily Opel' 5/9/2018-Wednesday No activity to report. 5/10/2018-Thursday No activity to report. 5/11/2018- Friday No activity to report. 5/12/2018-Saturday No activity to report. 5/13/2018-Sunday SLB CTU 6: BOP test to 250psi low and 4,000psi high. No failures. Configuration is (Upper Blinds, Lower Blinds,Slip rams, Pipe rams). R/U for cleanout job. Perform chain inspection. Changeout packoffs. 5/14/2018 Monday CTU 6 w/ 14,880' of 2" coil. PJSM - MU BHA#1- 1.75" OD int CTC(Pull test to 12k), 1.69" DFPV,Wt bar, Wt bar, 2.3"JSN. OAL=9.7'. PT PCE to 300psi/4,000psi. Bleed down to 2,000psi.Test downhole checks. Open well and WHP is 200psi. RIH with BHA#1. Begin FCO by circulating 150 degree slk 1% KCL at 1.5 BPM and 900 scf/min.Alternate 30 bbls KCL with 5 bbl gel sweeps. Cleanout from 5,400'to 8,172'while circulating 150 degree 1%slk KCL and N2 alternating with Nvis gel sweeps at 1.5 bpm and 900 scf/min. 100% returns seen during cleanout. Clear evidence of fill in lateral. POH to surface and wash across sliding sleeve several times as POH. At surface. FP coil,well to 2,500', and tree. L/D BHA#1. RDMO to MPH-18. 5/15/2018-Tuesday ,PT PCE 250L/2500H**. SHIFT 3-1/2 XD-SS AT 5087' MD OPEN. SET 3"JET PUMP (serial#BP-1063, ratio: 6C, OAL=70") IN XD- SS AT 5087' MD. immemisk LOF T • "„1//72,v THE ST E Alaska Oil and Gas k 1 °A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ain: 907.27 .1433 ALAS� MFax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SCOW 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU J-09A Permit to Drill Number: 199-114 Sundry Number: 318-185 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of May, 2018. RBDR/IS C- MAY 032018 ' ' 0 • RECEIVED STATE OF ALASKA MAY ALASKA OIL AND GAS CONSERVATION COMMISSION o 1 � � sl2lfg' APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 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: CT Fill Clean-out L• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ✓/ xf 4- Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ . 199-114 - 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22495-01-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑., MILNE PT UNIT J-09A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 • MILNE POINT/SCHRADER BLUFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,235 . 4,046 . 8,235 4,046 1,061 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' N/A N/A Surface 2,936' 9-5/8" 2,936' 2,529' 5,750 psi 3,090 psi Production 5,334' 7" 5,334' 3,828' 7,240 psi 5,410 psi Liner 938' 4-1/2" 6,137' 4,050' 8,430 psi 7,500 psi Slotted Liner 2,098' 4-1/2" 8,235' 4,046' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2" 9.3#/L-80/EUE 8rd 5,208' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SLB MRP Packer;Baker ZXP Liner Top Packer and N/A 5,159'(MD)/3,722'(TVD);5,199'(MD)/3,749'(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic LI 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/11/2018 ❑ CICommencing Operations: OIL WINJ ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. yrio Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: SpOrhOlahiICorp.COm - Contact Phone: 777-8412 Authorized Signature:."71" Date: 5/1/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I'65 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 12' Subsequent Form Required: /0•- '--/C el APPROVED BY Approved by: ~� COMMISSIONER THE COMMISSION Date: I / s--.2. /8 A 5./ i . -, ,..„. 4 A Sbmit Form and �,h Form 10-403 Revised 4/2017 Approved appOl sGfirNAh!from tR8D L-MAY p 31 �hments in Duplicate i Well Prognosis Well: MPU1-09A Hilcorp Alaska,Lb Date:5/01/2018 Well Name: MPU J-09A API Number: 50-029-22495-01 Current Status: SI Oil Well [Jet Pump] Pad: J-Pad Estimated Start Date: May 11th, 2018 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-114 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFI=Number: _ _°_ __ if Foam Cleanout; Current Bottom Hole Pressure: 1,642 psi @ 4,000' TVD (Last BHP 4/30/2018/7.90 ppg EMW) Maximum Expected BHP: 1,642 psi @ 4,000' TVD (No new perfs being added) MPSP: 1,242 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point J-09A well was redrilled as a Schrader Bluff development well that TD'd at 8,235' and ran 4.5" slotted liner into open hole in December 1999. The well was initially completed with a through tubing ESPCP (Electrical Submersible Progressive Cavity Pump), but failed immediately upon install. This was replaced with an ESP in January 2000. This failed and subsequent ESPs were replaced in 2003 and 2008. The traditional ESP was replaced with an ESPCP in 2013. That pump failed February 9, 2015. The pump was replaced in May 2015 with the Nordic#3. During a power outage in August 2015,the well was unable to sustain flow due to solids build up inside the tubing. A CT FCO cleaned out sand to the top of the ESPCP in September. The ESPCP is still electrically effective, but unable to surface fluids.The-last7"casing test was performed to 2,000psi on 4/06/2013. There are minimal observed scale issues, most failures are related to solids production. No subsidence issues are expected in this well. A caliper was run on the upper 1,000' of 7" casing in April 2013. The ESPCP was most recently changed out in December 2015.The ESPCP was pulled, and the well was converted to jet pump in April 2018. Fill has been tagged in the lateral at 5,519' and to fully clean out the well, a coil foam cleanout is planned. Notes Regarding Wellbore Condition k / • Casing last test to 3,000 psi for 30 min down to 5,159' MD on 4/10/2018. • Tubingtested to 4 000 psi for 30 min on 4/10/2018. • Max angle 59.3° @ 3,397' MD down to liner top. • Hole angle 56.3° @ 5,199' MD at liner top. • Hole angle (horizontal) in liner starting at 6,118' MD. Objective: The purpose of this work is to cleanout the lateral from 5,519' MD to PBTD of 8,235' MD. Work Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to),500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. • 11 Well Prognosis Well: MPU J-09A Iliku,c„Alaska,Lb Date:5/01/2018 3. RIH w/2.00" coil w/2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,235' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,235' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 4. PU to 2,500' and freeze protect well. POOH w/coil. 5. RD Coiled Tubing and ancillary equipment. 6. Turn well over to production. Wireline Procedure: 7. MIRU Slickline. PT lubricator to 2,000 psi Hi 250 Low. 8. RIH and shift sleeve open at+/- 5,087' MD. POOH. 9. RIH and set jet pump in sliding sleeve profile at+/-5,087' MD. POOH. 10. RD Slickline. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen & Foam Flow Diagram III. Milne Point Unit Well: MPU J-09A SCHEMATIC Last Completed: 4/10/2018 flacon,Alaska,LLC PTD: 199-114 KBEIev.:29.6'!GLEIev.:17.0' TREE&WELLHEAD Orifi RKB:29.6' Tree Cameron 3-1/8"5M 4 1:1;1 t WKM 11"x 11"5M,WKM w/11"x 3-1/2"tubing hanger/EUE t " t Wellhead threads top and bottom and 3"CIW H PBV Profile 133/8' OPEN HOLE/C EMENT DETAIL 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole += �_ 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole f', / 7" Cmt w/400 sx Class"G"in 8-1/2"Hole `" 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole iii 1 CASING DETAIL 9-5/8, te Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/H-40/N/A 12.615 Surface 112' 18'of Blast RI s 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 2,936' 7" Intermediate 26/L-80/NSCC 6.276 Surface 5,334' 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 2.867 Surf 5,208' WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=59 deg. @ 3,300-3,500' MaxHole Angle=Horizontal JEWELRY DETAIL f No Depth Item . ` "Q 1 2,279' 3-1/2"x 1"KBMG GLM(Shear Valve Set w/BK latch;Sheared) Mn ID=2.813"ID 2 . I �� 2 5,087' 3-1/2"XD Sliding Sleeve(2.813"Packing Bore Min ID;Closed) 3 5,111' 3-1/2"NDPG-C Single-drop Intake Gauge(2.898"ID) 3 4 5,138' 3-1/2"X Profile(2.813"Packing Bore Min ID) 5 5,159' 7"x 3-1/2"Permanent Hydraulic Set MRP HNBR Packer(2.907"ID),50k release y 6 5,186' 3-1/2"XN profile(Min ID=2.75"ID No-Go) Mn ID=2.813'ID tF a 4 7 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 8 5,207' Wireline Entry Guide(Btm at 5,208')(2.875"ID);Buried 9'inside liner top I t 1 5 9 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 10 6,013' Baker HMCV Cement Valve 11 6,032' Baker CTC 20'PZP ECP 12 8,190' 4.5"Baker Drillable Pack-Off Bushing Mn ID=2.750'ID 6 13 8,235' 4.5"Baker Drillable Guide Shoe 7 • I 4.5'Bonzai Completion 1 w/Honz.Slotted Liner ,L GENERAL WELL INFO API:50-029-22495-01-00 41 I. 9 Drilled and Cased by Nabors 22E -1/14/1995 r Completion by Nabors 4ES-2/15/1995 7 i 10 Schrader Bluff Recompletion by Nabors 4E5-4/19/1997 6 11 Schrader Bluff Sand Test#2-8/15/1997 Milled 6-1/8'Wndov@ 5,334'to 5,346'(12') IIIIII1 Sidetracked By Nordic 3-12/15/1999 RWO by Nabors 4E5-1/24/2000 IIIIIIIIRWO by Nabors 4E5-12/11/2003 Deanoutto7,075' r ESP RWO by Nabors 3S-6/16/2008 on 4/28/2015 11111111. RWO PCP Pump by Doyon 16-4/13/2013 ESP Change-out by Nordic 3-4/29/2015 1111111 , CT Fill Clean-out 9/14/2015 IIIMI' 12 ESPCP Change-out 12/4/2015 4-1/2" 13 ASR 1 Convert to Jet Pump 4/10/2018 6/ TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:STP 4/10/2018 11 0 • COIL BOPE MILNE POINT UNIT MPU J-09A Hilcorp Alaska,LLC 5/01/2018 MPU J-09A 13% X9% X7X 3% Coil Tubing BOP Lubricator to injection head 0 I I 2.00"Single Stripper I J I„I Blind/Sheaf, 1/16 10J Blind/Shear _ _J l_li` Blind/Shear®� ® Blind/Shearl,I,l•IJ �® J `=--1�\` I. Vor Slip Slip =J € —— Pipe -' Pipe 1114 SF 611 Crossover spool 4 1/16 10M X 4 1/16 5M c Mir Pump-In Sub ` 9r, i• 9; 4 1/16 5M (°)•[ i• ° •} 19 1502 Union Manual Gate Manual Gate Crossover spool 2 1/8 5M 2 1/8 5M 4 1/16 5M X 3 1/8 5M771_1 04\ Valve,Swab,WKM-M, L 3 1/8 5M FE 34 5O imminiiialinelia, \402., „\S lit.:(741 In Valve,Upper Master,Baker, ti 3 1/8 5M FE,w/Hydraulic t p,41. ... Valve,Lower Master,WKM-M, ,Pc•. `:" 3 1/8 5M FE :i► Ili Adapter,3 1/8 5M • S STANDARD WELL PROCEDURE Hi!carp Alaska,LAX NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 H • MN . -0 ..;:i..... : z 8.. 21,L':..1:e aq2 : 0 rjoiitt._1a-7i.10lie-— 71l —•-•-— u U01 i.•.-•••.:'1 YZ •• :..i.*:••..-: -..•.,.•%.;.•.., •:,•1 *5 a...s 4. .4.8 Tr° 3,••• • . w ._, g m g ._,- 2 2.••• w > c_ 4 U a. (..)4.(...) . ••••• • ....,2 , ,Lr I• 44 2 a u i 1 i ..5 ...,. , .,.... ,.. - A MI iralik -o*Fcs- ,./. .? V ,‘ _ - Kc 0 0050 ° 1 ar. 0 II ,, ••a.NM i 'N. o, -c) IL a,C o 0 o o et L. ea 8 o ce .1 .. V Lc ILI'd F 2 cc----4 0 w 11 "" ¢ 1.- 2 x 0 2 coct a. a a 2 mai 8 vr •t: it STATE OF ALASKA •SKA OIL AND GAS CONSERVATION COVIISSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate U Pull Tubing U Operat ons shu own U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Ch�1ge;Aprkyiesram ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Convert to Jet Pump 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development Q Exploratory ❑ 199-114 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22495-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 MILNE PT UNIT SB J-09A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Schrader Bluff Oil 11.Present Well Condition Summary: Total Depth measured 8,235 feet Plugs measured N/A feet true vertical 4,064 feet Junk measured N/A feet Effective Depth measured 8,235 feet Packer measured 5,199 feet true vertical 4,064 feet true vertical 3,749 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' N/A N/A Surface 2,936' 9-5/8" 2,936' 2,529' 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,828' 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' 4,050' 8,430psi 7,500psi Slotted Liner 2,098' 4-1/2" 8,235' 4,046' N/A N/A Perforation depth Measured depth See Schematic_ feet SCANNED True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3/L-80/EUE 8 rd 5,208' 3,754' 5,199'MD Packers and SSSV(type,measured and true vertical depth) ZXP Packer N/A 3,749'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 460 460 Subsequent to operation: 0 0 0 80 50 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 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❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SP UG❑ 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: 317-563 c Authorized Name: Bo York Contact Name: Stan Porhola SIP Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.COm Authorized Signature: Date: 5/1/2018 Contact Phone: 777-8412 2,1_ S '!•/ec / Form 10-404 Revised 4/2017 , `� Submit Original Only aol l 0 AtliSIAMEIF Milne Point Unit H . III Well: MPU J-09A ‘ EiSCHEMATIC Last Completed: 4/10/2018 aacorp Alaska,LLC PTD: 199-114 KBEIev.:29.6'/GLEIev.:17.0' TREE&WELLHEAD Ori•RKB:29.6' Tree Cameron 3-1/8"5M „,et 1 WKM 11"x 11"5M,WKM w/11"x 3-1/2"tubing hanger/EUE Iwo 4, g Wellhead threads top and bottom and 3"CIW H PBV Profile 13-3/8" w ( � OPEN HOLE/CEMENT DETAIL 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole +-z / I ' 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole to7" Cmt w/400 sx Class"G"in 8-1/2"Hole Ft) 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole t CASING DETAIL ie Size Type Wt/Grade/Conn ID Top Btm 9-5/8"�� 13-3/8" Conductor 54.5/H-40/N/A 12.615 Surface 112' 18'of Bast F3 s 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 2,936' 7" Intermediate 26/L-80/NSCC 6.276 Surface 5,334' 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 2.867 Surf 5,208' WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=59 deg. @ 3,300-3,500' MaxHole Angle=Horizontal JEWELRY DETAIL a� fNo Depth Item N. 1 2,279' 3-1/2"x 1"KBMG GLM(Shear Valve Set w/BK latch;Sheared) Mn ID=2.813"ID ist 2 J,'w 2 5,087' 3-1/2"XD Sliding Sleeve(2.813"Packing Bore Min ID;Closed) 3 5,111' 3-1/2"NDPG-C Single-drop Intake Gauge(2.898"ID) 3 4 5,138' 3-1/2"X Profile(2.813"Packing Bore Min ID) 5 5,159' 7"x 3-1/2"Permanent Hydraulic Set MRP HNBR Packer(2.907"ID),50k release It , 6 5,186' 3-1/2"XN profile(Min ID=2.75"ID No-Go) Mn ID=2.813 ID -s: 4 7 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 8 5,207' Wireline Entry Guide(Btm at 5,208')(2.875"ID);Buried 9'inside liner top ilium i 5 9 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 10 6,013' Baker HMCV Cement Valve 11 11 6,032' Baker CTC 20'PZP ECP _ 12 8,190' 4.5"Baker Drillable Pack-Off Bushing Mn ID=2.750ID 6 13 8,235' 4.5"Baker Drillable Guide Shoe Il 7 46'BonzaiC«ngetion GENERAL WELL INFO ""d Fbnz'Slotted Liner ' API:50-029-22495-01-00 9 Drilled and Cased by Nabors 22E -1/14/1995 7, t Completion by Nabors 4ES-2/15/1995 .- 4 10 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 Killed 6-1/8v6sndoov@ - 0 11 Schrader Bluff Sand Test#2-8/15/1997 5,334'to 5,346'(12) 1111111 1 Sidetracked By Nordic 3-12/15/1999 , e _s RWO by Nabors 4ES-1/24/2000 IIIIIII RWO by Nabors 4ES-12/11/2003 Clean-out to 7,075' g' ESP RWO by Nabors 3S-6/16/2008 on 4/28/2015 11111111 RWO PCP Pump by Doyon 16-4/13/2013 ;1111111 1. ESP Change-out by Nordic 3-4/29/2015 CT Fill Clean-out 9/14/2015 11111112 ESPCP Change-out 12/4/2015 4-1/2" 13 ASR 1 Convert to Jet Pump 4/10/2018 TD=8,235'(MD)/TD=4,064'(1VD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:STP 4/10/2018 • Hilcorp Alaska, ~ Weekly perat'ons Summary Well Name Rig API Number Well Permit Number Start Date End Date MP]'09A ASR#1 50-029'22495'81-00 199-114 4/5/18 4/10/18 4/4/2018-Wednesday No activity to report. /5/2018-Thursday Rig Crews arrive on A pad, begin warming up equipment and removing snow. Well kill complete on J-09A. Roads and Pads on A pad w/crane to load well house and rig floor. Prep all equipment needed for N/Dproduction tree and N/UB0PEon] 09A. Continue to R/U on well J-09ASpot mud boat into position and then spot BOPE into place followed by the well house and rig floor utilizing roads and pads crane. Utilize NES winch tractor with hydraulic 5th wheel to move pit trailer and spot into place. Back rig carrier into position on mud boat and raise mast. l8- � - y Continue to R/U on well J-09A w/ASR#1. Secure mast into position and enclose into rig floor. Relocate doghouse and company rep trailer from A to Pad. L/D herculite containment and spot catwalk into position. R/U Certek unit and spot into position. Run fluid/hydraulic/glycol/elechc lines and cover properly.Verify nitrogen pre-charge in accumulator botles. Function test BOPE system.Take on 180bbls of fresh water. Continue to R/U and prep for testing BOPE,verify lineups. Well ' support on location to grease BOPE. Rig crew grease all choke and kill manifold valves.Take on fluids and perform shell test, � Perform BOPEtest asper Sundry.Test UOPEw/2'7/8" and 3 1/2" teotjoints to2SUpsi |owand3SOUpsih�ohf 5cha�ed V�/�` __- � mins each.Test annular w/2-7/8"joint to 250psi low, 2,500psi high f/5 charted mins.Witness waived by AOGCC rep Adam Earl. Drain stack and blow down all lines, R/U and prep to pull blanking plug. M/U blanking plug retrieving head to landing joint. 4Y7/2018-Saturday Perform rig service Pull blanking plug,wellhead rep on location to pull BPV.Verify no pressureonthe |AphortopuUin0DPV. Line up to bullhead down the IA. Having issue getin8 rig centrifugal to function from the rig floor. Contact Prostar and discuss potential issues. Decision made to manually function centrifugal from mud pits in order to run rig pump. Close blind rams. Bullhead 30bbls of freshwater/Baraklean mix and chase w/50bbls of fresh water down the IA. Pump @ 3.5BPM w/ 300psi pump pressure. Blow down lines, M/U landing joint and 5' into proper depth in TBG hanger. M/U w/8-1/2 turns BOLDS. Pull TBG hanger, max weight(41.8klbs) seen,weight broke over at 40.8klbs.TBG seems to be pulling clean, no weight chatter. POOH w/E3PCPon2-7YD" 6.Spp0EUETBG f/~5,OSU'mdto-4,S00'mdTBG very greasy, having difficulty spooling heat trace and ESP on one spool in spooling unit. Decision made to shut down and locate cap string spooler at A pad. Well support hands on location to assist w/ pump/motor and TBG pull. Locate spooler on A pad, load and move to 1- 09A, Re|ocatecapssthngf/xpoo|ingunittohydrau|ichandspoo|er, Removeheattracehnmhnntxpoo| andsLretchtorear spool. Continue toPOOH w/ESP[PonZ'7/8" 6.SppfEUETBG f/~4S0U'mdto~4000'md. Fill hole utilizing double metal displacement in addition to any fluid that is needed to clean pipe. Service Rig. Continue toPOOH w/ESPCPon2'7/8" 6.5ppf EUE TBG f/-4,000'md to ESPCP @ 55'md. L/D ESPCP and swap pipe handling equipment over to 3.5" in prep for RIH w/ bit/scraper BHA. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPJ-09A ASR#1 50-029-22495-01-00 199-114 4/5/18 4/10/18 Daily Operations: 4/8/2018-Sunday Rig service M/U Weatherford Bit/Scraper BHA on 3.5" work string and RIH f/surface to"4,600'md. Hydraulic leak noted from line on the tongs. Shut down and investigate. Replacement hydraulic line needed.TP build new hose at VMS. Clean out bird bath on rig floor and tidy up rig. Continue to RIH w/Weatherford Bit/Scraper BHA on 3.5" work string f/4,600'md to ^'5150'md. PUW=44klbs,SOW=28klbs Ease into hole and tag top of LNR 12' into jnt 130=5,200'md. Set down 2klbs, P/U, break string weight over and verify tag depth. Set down 5klbs. Consistent tag. Fill hole prior to POOH. (15bbls to fill). POOH f/^'5,200'md to 3,780'md. Perform well control drill with rig crew. Kick while tripping w/AAR to follow. (3mins) Once drill is complete, line up and bullhead remaining 20bbls of Baraklean mix fluid down the IA @ 4BPM w/40psi.Verify no remaining pressure on IA, open well and continue to POOH w/Weatherford Bit/Scraper BHA f/3,870'md to^'800md. Crew change, rig service. POOH w/remaining 800'md of 3.5"TBG and L/D Bit/Scraper BHA. M/U Weatherford test PKR and function test. RIH w/Weatherford test PKR on 3.5" work string f/surface to^'5100'md. PUW=44klbs,SOW= 29klbs Ease down to PKR setting depth @ 5170'md and work through PKR setting sequence. Once set, attempt to PT CSG to 3,000psi f/30 charted mins. CC Pressure up to 1,000psi and note 100psi leak off per minute. Release PKR, P/U 15'md, close pipe rams and bullhead 5 bbls 5 down IA to clear any obstructions. Set PKR and prep to test 7" CSG. 4/9/2018-Monday Crew change, rig service Leak noted coming from hydraulic system on rig carrier. Shut down and fix leak. Set Weatherford test PKR @ 5,175'md and allow air to work out of system.Test 7" CSG to 3,000psi for 30 charted mins (Good Test) Bleed down and blow down. Close pipe rams and bullhead 15bbls down the IA to clear anything below PKR POOH w/Weatherford test PKR f/5175'md to surface. L/D test PKR (PKR looked good,seals and slips) Load and tally 3.5" completion in prep for RIH, hang SLB I-wire sheave. Break all thread protectors and prep TBG connections. Continue to prepare for completion run. M/U shoe track followed by remaining jewelry above the production PKR. RIH w/Jet Pump Completion as per Sundry on 3.5" EUE completion pipe f/160'md to^'3,900'md. 4/10/2018-Tuesday Crew change, rig service Continue to RIH w/Jet Pump Completion on 3.5" 9.3# EUE TBG f/^'3,900'md to tag 5,175'md. Ease down f/5,175'md to tag depth at 5,200'md. PUW=36klbs, SOW= 26klbs.Tag up 20' into joint 162 (5,200'md) Set down w/ 5klbs, P/U and break over weight indicator and repeat tag. Depth consistent. 12' into TBR. L/D joints 162, 161, and 160. P/U two 10' pups, a 4' pup, and the TBG hanger w/pup. SIMOPS: N/D production tree on 1-17, check LDS, lifting threads, and insert blanking plug in lifting thread profile. Run I-wire through TBG hanger,grease hanger seals, and land TBG hanger, utilizing 5' marks to verify hanger is on depth, RILDS, Drop ball and rod.SIMOPS: Continue to R/U on well 1-17, stab BOP double gate rams and M/U. Line up to pump down the TBG and set the production PKR. Pressure up TBG to 4,000psi utilizing rig pump and BOPE pump. PKR start to set= 1,500psi,full set=3,500psi. Hold TBG pressure at 4,000psi f/30 charted mins. (Good test). Bleed TBG pressure down to 2,000psi. Pressure up IA to 3,000psi and hold for 30 charted mins. Dump TBG pressure to shear DCK valve from the IA to the TBG. Circulate through the DCK shear valve to ensure communication. Wellhead reps on location to set BPV. (16:00) Rig crew begin R/D M/O process. OF 7.4, • S e��,��sv THE STATE Alaska Oil and Gas � - �� of e T ® KA Conservation Commission it 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York JAS! 1J 5 :211 Operations Manager Hilcorp Alaska, LLC SCANNED 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU J-09A Permit to Drill Number: 199-114 Sundry Number: 317-563 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, d4Qa(- Hollis S. French IL Chair DATED this/6 day of November, 2017. REC.27 t L,r, • • RECEIVED Nov 282017 STATE OF ALASKA Dr S I/! 2.q/ 1 ALASKA OIL AND GAS CONSERVATION COMMISSION OG CC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate El Pull Tubing Q , Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El Alter Casing ❑ Other: Convert to Jet Pump ❑., 4 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q ' 199-114 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22495-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No ❑., MILNE PT UNIT J-09A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 • MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,235 , 4,046. 8,235. 4,046, 1,061 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' N/A N/A Surface 2,936' 9-5/8" 2,936' 2,529' 5,750 psi 3,090 psi Production 5,334' 7" 5,334' 3,828' 7,240 psi 5,410 psi Liner 938' 4-1/2" 6,137' 4,050' 8,430 psi 7,500 psi Slotted Liner 2,098' 4-1/2" 8,235' 4,046' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" 6.5#/L-80/EUE 8rd 5,065' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker ZXP Liner Top Packer and N/A t 5,199'(MD)/3,749'(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory El Stratigraphic❑ Development❑✓ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/13/2017 Commencing Operations: OIL ❑� • WINJ El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG El GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STP Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporholaahilcorp.com Contact Phone: 777-8412 Authorized Signature: Date: 11/27/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 I 64°3 Plug Integrity ❑ BOP TestLrl Mechanical Integrity Test ❑ Location Clearance ❑ Other: t 2..,Sp0 (51. 6 Or 1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ 017 2 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: f 0-- Li D 4-ia L -i;37 J i1 LO 11 APPROVED BY 1 I4 Approved by: til) , COMMISSIONER THE COMMISSION Date: 1 qi9i) ONO- 44 it(*7 ORIGINAL 74 /,,t, ./7,t, /7 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Ililcora Alaska,LLI Well: MPU J-09A Date:11/27/2017 Well Name: MPU J-09A API Number: 50-029-22495-01. Current Status: SI Oil Well [ESPCP] Pad: J-Pad Estimated Start Date: December 13th, 2017 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: _ 199-114 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number Job T 4: 4- ,r �R T� °- .� � 0- 11'��` °Conuert t©JeR1OpA' Current Bottom Hole Pressure: 1,461 psi @ 4,000' TVD (Last BHP 11/12/2017/7.02 ppg EMW) Maximum Expected BHP: 1,461 psi @ 4,000' TVD (No new perfs being added) MPSP: 1,061 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point J-09A well was redrilled as a Schrader Bluff development well that TD'd at 8,235' and ran 4.5" slotted liner into open hole in December 1999. The well was initially completed with a through tubing ESPCP (Electrical Submersible Progressive Cavity Pump), but failed immediately upon install. This was replaced with an ESP in January 2000. This failed and subsequent ESPs were replaced in 2003 and 2008. The traditional ESP was replaced with an ESPCP in 2013. That pump failed February 9, 2015. The pump was replaced in May 2015 with the Nordic#3. During a power outage in August 2015,the well was unable to sustain flow due to solids build up inside the tubing. A CT FCO cleaned out sand to the top of the ESPCP in September. The ESPCP is still electrically effective, but unable to surface fluids.The last 7"casing test was performed to 2,000psi on 4/06/2013. There are minimal observed scale issues, most failures are related to solids production. No subsidence issues are expected in this well. A caliper was run on the upper 1,000' of 7" casing in April 2013. The ESPCP was most recently changed out in December 2015. Notes Regarding Wellbore Condition • Tubing clean down to top of ESPCP at 4,995'SLM. • Casing last test to 2,000 psi for 30 min down to 5,121' MD on 4/06/2013. • Tubing tested to 3,500 psi for 5 min (ESPCP plugged). • Max angle 59.3° @ 3,397' MD down to liner top. • Hole angle 56.3° @ 5,199' MD at liner top. • Hole angle (horizontal) in liner starting at 6,118' MD. Objective: The purpose of this work rk is to pull the failed ESPCP pump and convert the well to a new 3-1/2"jet pump tubing- packer completion. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg Seawater down tubing, taking returns up casing to 500 bbl returns tank. • • Well Prognosis Hamra Alaska,Ili Well: MPU 1-09A Date: 11/27/2017 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg Seawater prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" and 3-1/2"test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. -' 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor l )Z.) the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg Seawater as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESPCP swap was 82k lbs (block weight of 38k). b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rollinglest was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8"tubing. Tubing will be inspected. Lay down the failed ESPCP. a. Keep all joints of 2-7/8" tubing for possible inspection. b. Keep all gaslift mandrels for possible inspection. c. Note any sand or scale inside or on the outside of the tubing on the morning report. . 11 ! • Well Prognosis Well: MPU J-09A Maori)Alaska.LLI Date: 11/27/2017 18. MU 7" 26#scraper assembly and RIH w/3-1/2" workstring to±5,199' MD (liner top). Circulate the well clean with 8.5 ppg Seawater. 19. POOH and LD 3-1/2" workstring and scraper assembly. 20. PU 7" RTTS test packer and RIH on workstring to+/-5,150' MD. Cisiwt� 21. Set test packer and pressure test 7" casing to 3,000 psi for 30 min (charted). "re)- 22. Unseat test packer and POOH while laying down the workstring. 23. PU completion and RIH on 3-1/2" tubing. a. Tubing is 3-1/2" 9.3# L-80 EUE (Range 2) b. Sliding Sleeve @ ±4,950' MD c. Downhole Gauge @ ±5,010' MD d. Packer @ ±5,090' MD e. 3-1/2" XN (2.75" No-Go) @ ±5,135' MD [Pre-load RHC plug body] f. 3-1/2" WLEG @ ±5,170' MD 24. Space out above the liner top at±5,170' MD. Land hanger.RILDS. 25. Circ inhibited 8.5 ppg Seawater packer fluid and freeze protect fluid. 26. Drop ball and rod. Pressure up and set Packer(start 2,000 psi/final 4,000 psi). 27. Pressure test tubing to 4,000 psi for 30 min and chart. Bleed tubing to 2,000 psi. 28. Test inner annulus to 3,000 psi for 30 min and chart. Monitor tubing for packer leak. 29. Bleed tubing to 0 psi. Pop shear valve from annulus to tubing (2,000 psi differential). 30. Freeze protect annulus and tubing. 31. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 32. Set BPV. Rig down ASR. Post-Rig Procedure: 33. RD mud boat. RD BOPE house. Move to next well location. 34. RU crane. ND BOPE. 35. NU new 3-1/8" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 36. RD crane. Move 500 bbl returns tank and rig mats to next well location. 37. Replace gauge(s) if removed. 38. Turn well over to production. RU well house and flowlines. Wireline Procedure: 39. RU Slickline.Test lubricator to 250/3,000 psi. 40. RIH and pull ball/rod and RHC plug body from XN profile at±5,135' MD. POOH. 41. RIH and drift tubing and tag PBTD. POOH. 42. RD Slickline. Attachments: 1. As-built Schematic 2. Proposed Schematic • II • Well Prognosis Well: MPU J-09A M"""Alaska,LD Date: 11/27/2017 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Proposed Tree/Wellhead 6. Blank RWO Changes Form II • • Milne Well: MPUPoint J-09A Unit SCHEMATIC Last Completed: 12/04/2015 Hilean)Alaska,LLC. PTD: 199 114 KBEIev.:29.6'/GLEIev.:17.0 TREE&WELLHEAD Tree Cameron 2-9/16"5M 'j WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hang er/8RD F Wellhead threads top and bottom and 2.5"CIW H PBV Profile 13-3/a" , OPEN HOLE/CEMENT DETAIL 4 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole i 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/400 sx Class"G"in 8-1/2"Hole ' 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole CASING DETAIL 9-5/8„ Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/H-40/N/A 12.615 Surface 112' 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 2,936' Fieat Trace @ 7" Intermediate 26/L-80/NSCC 6.276 Surface 5,334' 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 3/3'SS Capst ng 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' 4---- TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 5,065' 3/8" Cap String Stainless Steel N/A Surface 5,065' WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=59 deg. @ 3,300—3,500' MaxHole Angle=Horizontal JEWELRY DETAIL 2 No Depth Item 1 138' 2-7/8"x 1"Side Pocket KBMM w/Orifice set 12/04/15 2 4,856' 2-7/8"x 1"Side Pocket KBMM w/DGLV set 10/22/17 3 3 4,994' 2-7/8"XN Nipple(2.25"Min ID) 4 4 5,005' WeIILift Discharge Gauge Unit 11 5 5 5,011' Centrilift ESP:PCP w/Flex Shaft 3.75" 6 5,044 Upper Tandem Seal 9 6 7 5,051' Gear Reduction Unit GRU 538B 11.42:1 8 5,052' Motor MSP-3-250 7 9 5,061' Sensor w/6 fin Centralizer—Bottom @ 5,065' 10 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 8 11 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) t,;� 12 6,013' Baker HMCV Cement Valve 13 6,032' Baker CTC 20'PZP ECP 9 14 8,190' 4.5"Baker Drillable Pack-Off Bushing 15 8,235' 4.5"Baker Drillable Guide Shoe 4.5"Bonze!Completion ,'1 f 10 GENERAL WELL INFO w/Honz.Slotted Liner API:50-029-22495-01-00 4 j 11 Drilled and Cased by Nabors 22E -1/14/1995 7 Completion by Nabors 4ES—2/15/1995 A 7 12 Schrader Bluff Recompletion by Nabors 4ES—4/19/1997 13 Schrader Bluff Sand Test#2—8/15/1997 Mlled6-1/8"vetow@ IIIIII1 5,334'to 5,346' 12 i Sidetracked By Nordic 3—12/15/1999 RWO by Nabors 4ES—1/24/2000 IIIIIIIIF RWO by Nabors 4ES—12/11/2003 Clean-art to 7,075 ESP RWO by Nabors 3S—6/16/2008 m4/28/2015 I IIIIIIIII1 RWO PCP Pump by Doyon 16—4/13/2013 I III III IIII ESP Change-out by Nordic 3—4/29/2015 CT Fill Clean-out 9/14/2015 IIIIIIIII(i 1 4-1/2" 15 ESP Change-out 12/4/2015 TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:STP 11/27/2017 . 0 Milne Well: MPUPoint J-09UnitA PROPOSED Last Completed: 12/04/2015 Bacon,Alaska,LLC PTD: 199-114 KBEIev.:29.6/GLEIev.:17.0 TREE&WELLHEAD Tree Cameron 3-1/8"SM 'AWKM 11"x 11"5M,WKM w/11"x 3-1/2"tubing hanger/8RD 11 r Wellhead threads top and bottom and 3"cmH PBV Profile t wl 3/8 ) OPEN HOLE/CEMENT DETAIL I* 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 4 l °; 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole V. ' 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole 1 14, CASING DETAIL 15/8„a i Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/H-40/N/A 12.615 Surface 112' 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 2,936' 7" Intermediate 26/L-80/NSCC 6.276 Surface 5,334' 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 2.867 Surf 5,170' WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=59 deg. @ 3,300—3,500' ;.--rv,,ir' MaxHole Angle=Horizontal „re,- JEWELRY DETAIL MnID=2.813"ID Iiiiii 2 No Depth Item 3 1 2,400' 3-1/2"x 1"SPMO-1.0M GLM(DGLV Set) 2 4,950' 3-1/2"XD Sliding Sleeve(2.813"Packing Bore Min ID;Closed) '. 3 5,010' 3-1/2"NDPG-C Single-drop Intake Gauge(2.913"ID) Mn ID=2.813"ID .. 4 t„.,04 5,070' 3-1/2"X Profile(2.813"Packing Bore Min ID) 1 r r 6 oqb 5 5,090' 7"x 3-1/2"Permanent Hydraulic Set Packer(2.867"ID) e 5 6 5,135' 3-1/2"XN profile(Min ID=2.75"ID No-Go) 7 5,170' Wireline Entry Guide(Btm at 5,170') 8 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) Mn ID=2.750ID ' 6 9 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) l'1'' 10 6,013' Baker HMCV Cement Valve 1111 11 6,032' Baker CTC 20'PZP ECP 7 12 8,190' 4.5"Baker Drillable Pack-Off Bushing 13 8,235' 4.5"Baker Drillable Guide Shoe 8 4.S'Bonzai Completion ToGENERAL WELL INFO�► w/Horiz.Slotted Liner API:50-029-22495-01-00 9 Drilled and Cased by Nabors 22E -1/14/1995 7" Completion by Nabors 4ES—2/15/1995 !10 Schrader Bluff Recompletion by Nabors 4ES—4/19/1997 11 Schrader Bluff Sand Test#2—8/15/1997 NIDed 61/8'V6indow@ 111111 Sidetracked ByNordic 3—12/15/1999 5,334'to5,346'(17) RWO by Nabors 4ES-1/24/2000 1111111 RWO by Nabors 4ES—12/11/2003 Gears-ore to 7,075' . 1 ESP RWO by Nabors 3S—6/16/2008 an4/28/2015 1111111 RWO PCP Pump by Doyon 16—4/13/2013 1111111 ESP Change-out by Nordic 3—4/29/2015 CT Fill Clean-out 9/14/2015 41/2 '. s1111111 1 1ESP Change-out 12/4/2015 TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:STP 11/27/2017 4110 • Milne Point ASR Rig 1 BOPE nt r�p�a�a,L u; 2017 11" BOPE , , Stripping Head 1 4.48' ,!, °II-lydriI G �`4 11" - 5000 . lit li i t rlilrlililil 1111111111111 III 111111 UI In 4.54' mmI��l ® (IS - VBR or Pipe Rams �� 11" 5000 •MP gyral 01I—B Blind I®1 111 HI 1#1 li1 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves 1P111'Il'11PI1 ' 13 1 ' t ' ;2.00 ; °) ,C °_\ 'iIIs - Iii■Iil■lildil I1t Manual Manual Manual HCR Updated 11/20/2017 • • MPU J-09A EXISTING TREE/WELLHEAD Wellhead/Tree Hilcorp Alaska,LLC Milne Point Unit Tree Cap III It, 411110 AIM Tree Valve 2-9/16" 5M tot r , Itt 1.1 VOW Iy ~ (lei Tree Cross 2-9/16" 5MON Tree Valve 2-9/16" 5M ,.,. SLI SSV 2-9/16" 5M CEO , ;r vim '41. 07 Iu. Tree Valve 2-9/16" 5M . , -, Itr 18111.6/III ESP Cable !I1 III Heat Trace ---------------______1,_ Control Line Tubing Adapter it triwil Tubing Head us-- ,-- � �„ .1 11" 5M Top x 11" 5M Bt `% 1 ion' -.011PA II i '..,°47. ..t,N I'iii a. I3 ISI UI CasingHead w "` 11" 5M Top x 11" 5M Btm InVIIIpow ;� , ]1 1,' • • MPU J-09A . H PROPOSED TREE/WELLHEAD Wellhead/Tree Hilcorp Alaska,LLC Milne Point Unit ili Tree Cap at lit fii �0'W.ta'tLi! Tree Valve 3-1/8" 5M �r° 40"-(5-0 ' PaP=_...Pa. c -. o Tree Cross 3-1/8" 5M II[ (°) tJ� Tree Valve 3-1/8" 5M `--61O „ SSV 3-1/8" 5M O Cf.owl"till X00 Tree Valve 3-1/8" 5M ri c;14 000 IOP 11111.PaP Tubing Adapter -1.141fall a MS111.1111, Tubing Head Iii ..... P Ill 11" 5M Top x11" 5M Bt LI10. 11 ' 1111111i� 1�] Jit fit 11 Iii •a lIli 1244: ill rt� Casing Head ft� 11" 5M Top x 11" 5M Btm ®III ■�illllil, �]� I�#-e.. • • CO „. _ . .., A g o 5 � � ca 2 / 0 > g > o / / 00. = c « tea E £ E C S = % .13 / b < k 'g * � ko.- �/ o. < m to• / = 2 � � o2 0_k E / � � as g) - k2 < 03 e ■ +c, A Cu Cu \f _ Q . B "0 1!; 4 pc ■ a. � � .0CD 10 = k / E 7 � � - 0 cio ■ E b 2 ] Ga) ct 2 -0 AC / / ti S k / 0 1 . E c Cl) / F 2 ( co c O c w 2 o > \ 0 U o. 2 - ■ QCO ' CO O ■ 4 -CCI Q.CA 6. RI 2 % / CI § O m Q ■ X I- ,-4 Cu - CD 0 c ./ IS U > CU q .o m CO Cu 7 § � � z o : / a Cu it / _ .. .... _qct9 t / > / co 2 k c/ a CO Mila m @ < < m < a. STATE OF ALASKA ALISA OIL AND GAS CONSERVATION COM SION • - REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations u Fracture Stimulate ❑ Pull Tubing IA Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program El Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ESPCP Change-out 0 2. Name: 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 199-114 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400,Anchorage AK 99503 50-029-22495-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: r$�! ADL0025517 MILNE PT UNIT SB J-09A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Schrader Bluff Oil JAN' 0 6 2016 11.Present Well Condition Summary: AOGCC Total Depth measured 8,235 feet Plugs measured N/A feet true vertical 4,046 feet Junk measured 7,075(Fill) feet Effective Depth measured 7,075 feet Packer measured 5,199 feet true vertical 4,050 feet true vertical 3,749 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' N/A N/A Surface 2,936' 9-5/8" 2,936' 2,529' 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,828' 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' 4,050' 8,430psi 7,500psi Slotted Liner 2,098' 4-1/2" 8,235' 4,046' N/A N/A Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED SEP 1 5 2016 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 5,065' 3,676' 5,199'MD Packers and SSSV(type,measured and true vertical depth) ZXP Packer N/A 3,749'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 254 58 250 400 226 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: %��/� 315-703 ''''lContact Paul Chan s�1`.— Email pchan@hilcorp.com Printed Name Bo York Title Operations Engineer Signature ke,,1 0-f a- r- 80 York Phone 777-8345 Date 1/6/2016 / i-i%76 )5v RBDMS .SAN 0 7 2016 Form 10-404 Revised 5/2015 � I Submit Original Only �/ H . • Milne Point Unit Well: MPU J-09A . in • SCHEMATIC Last Completed: Proposed Ilileora Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/H-40/N/A 12.615 Surface 112' ii 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 2,936' 13-3/8" 7" Intermediate 26/L-80/NSCC 6.276 Surface 5,334' - 1 v 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' V +' TUBING DETAIL E 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 5,065' 3/8" Cap String Stainless Steel N/A Surface 5,065' 4, 1r v i& JEWELRY DETAIL 9-5/8"`6 No Depth Item 1 138' 2-7/8"x 1"Side Pocket KBMM w/Orifice Heat T�@ 2 4,856' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi ' 3 4,994' 2-7/8"XN Nipple(2.25"Min ID) 4 5,005' WellLift Discharge Gauge Unit 3- Capstnng .4----- 5 5,011' Centrilift ESP:PCP w/Flex Shaft 3.75" - 6 5,044 Upper Tandem Seal 7 5,051' Gear Reduction Unit GRU 538B 11.42:1 8 5,052' Motor MSP-3-250 9 5,061' Sensor w/6 fin Centralizer-Bottom @ 5,065' 10 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 11 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 12 6,013' Baker HMCV Cement Valve 13 6,032' Baker CTC 20'PZP ECP 14 8,190' 4.5"Baker Drillable Pack-Off Bushing 15 8,235' 4.5"Baker Drillable Guide Shoe 2 WELL INCLINATION DETAIL :! KOP @ 600' 3 Max Hole Angle=59 deg. @ 3,300-3,500' x. 4 MaxHole Angle=Horizontal 5 OPEN HOLE/CEMENT DETAIL Nip1'06 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole it 7 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole at 8 TREE&WELLHEAD = Tree Cameron 2-9/16"5M 9 WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/8RD Wellhead threads top and bottom and 3"CIW H PBV Profile 45"Bornai Completion 10 GENERAL WELL INFO %V Horiz.Slotted Liner ♦ API:50-029-22495-01-00 11 Drilled and Cased by Nabors 22E -1/14/1995 7„ Completion by Nabors 4ES-2/15/1995 ;A; - •12 Schrader Bluff Recompletion by Nabors 4ES-4/19/19.97_ 13 Schrader Bluff Sand Test#2-8/15/1997 Milled 5,10 Wridow@ 111111 5,334'to5,346(12) I Sidetracked By Nordic 3 12/15/1999 RWO by Nabors 4ES-1/24/2000 1111111 RWO by Nabors 4ES-12/11/2003 Clean-out to 7,075' ESP RWO by Nabors 3S-6/16/2008 on 4/28/2015 i 1111111 RWO PCP Pump by Doyon 16-4/13/2013 (111111 ESP Change-out by Nordic 3-4/29/2015 CT Fill Clean-out 9/14/2015 111 145 ESP Change-out 12/4/2015 4-1/2" TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:TDF 1/6/2016 • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPJ-09 Nordic#3 50-029-22495-01-00 199-114 11/30/15 12/4/15 Daily Operations: 11/25/2015-Wednesday No activity to report. 11/26/2015-Thursday No activity to report. 11/27/2015 - Friday No activity to report. 11/28/2015-Saturday No activity to report. 11/29/2015 -Sunday No activity to report. 11/30/2015- Monday Continue to move Nordic#3 to MPJ-09A. Rig on location @ 07:00 hrs. Remove snow drifts from Tee Mats and cutting box area. Contact Pad Operator, pull over well. Set down and berm up rig.ACCEPT RIG @ 08:00 hrs. Spot cutting box,welding shop, mud engineer shack, flow back tank. Rig up hard line to flow back tank and test same to 3,000 psi. Load pits with Sea Water. Open up well to Choke manifold with 20psi on tubing and IA. Bleed IA and tubing to flow back tank with Opsi in 10 minutes. Line up to pump down the tubing,taking returns through full open choke to flow back tank. Established returns @ 71 bbls away. Continue circulate STS @ 4 BPM with 570psi through GLM @ 4,853'. End of Pump Assembly @ 5,063', pump 421 total Obis, 100 bbls over, lost 193 bbls to formation. Monitor well for 10 min. I/A and tubing both on vac, dynamic loss rate 77 bph. Well is dead. Blow down lines. Install BPV per wellhead rep, N/D tree and hang in cellar, inspect hanger threads, N/U 11" 5M BOPE. Pull BPV, install TWC. R/U test equipment, flood stack and lines with water, perform stack body test to 3,000psi. Replace dart valve during body test due to scarred face.Test BOPE,AOGCC rep Matt Herrera waived witness to test on 11/30/2015 @ 11:25 hrs.Test BOPE using 2-7/8" test joint to 250psi low/3,000psi high, 5 min each, chart record all tests. 12/1/2015 -Tuesday Continue to test BOPE using 2-7/8" test joint to 250psi low/3,000psi high, 5 min each, chart record all tests. Perform accumulator test.Test gas alarms. Pull TWC, rig down test equipment. Monitor well on trip tank. Blow down surface equipment. Discovered ice plug in TD. Break Kelly hose at TD goose neck.Thaw Kelly hose and TD with steam stinger to upper stand pipe Goose neck. Re-install Kelly Hose to lower TD Goose neck. Blow down Top Drive. Attempt to test Kelly Hose connections. Had to replace gray lock ring on hub connection. Re-test upper and lower TD Valves to 250psi low/ 3,000psi high on chart for 5 minutes each test. MU Landing joint to Top Drive BOLDS. Pull on and unseat tbg hgr. Fill hole and establish static loss rate @ 210 BPH.Terminate ESP& heat trace from hanger. L/D hanger. R/U ESP, swap out ESP sheave in derrick to a double sheave. Rack back one stand in derrick to pull cable over the sheave. Rack back second stand to connect cables to spool. Filled hole through tubing 57bb1 to fill. Little oil on top no gas. Static losses rate 210 bph. POOH @ 900', racking back 2-7/8" tubing derrick& laying down ESP. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP J-09 Nordic#3 50-029-22495-01-00 199-114 11/30/15 12/4/15 Daily Operations: _ r 12/2/2015 -Wednesday Continue to POOH from 900' racking back 2-7/8" tubing derrick& lay down ESP assembly. Clean and clear rig floor. C/O ESP and Heat Trace Spools. Use crane to stage ESP and Heat trace Spoolers on the rig floor. MU PCP Pump and Mtr Assembly. Service new Motor. Load ESP Spool onto spooler with crane while serving motor. Hang Heat trace sheave. Fill capillary line with diesel and test same to 3,600psi. Pull Cables over sheaves. Connect capillary tubing to mandrel. Install DGU. Connect MLE cable. RIH with 2-7/8" ESP completion +Cap Inj.tbg to 2,089'. Meg Test ESP cable &function test Cap. Injection Tubing.After going through troubleshoot procedures it was determined that the Cap injection tube failed the test.Town personnel was notified and the decision was made to pull out and find the problem (possible hole in line or connection leak at the pump). Rig up to pull out of the hole with ESP completion, rig up power to the hyd. spooler and attempted to operate (No Go) call out elec. to trouble shoot problem (Plugged into wrong terminal) corrected problem and POOH. POOH with ESP with 2-7/8" ESP completion +Cap Inj.tbg.to find leak. Leak found @ gauge unit(check valve) on ESP pump call out for a new valve, install, test GOOD. Rescuer Cap Inj. tubing to ESP pump & RIH with 2-7/8" ESP completion +Cap Inj. tbg to 2,600'. 12/3/2015 Thursday Continue to RIH with 2-7/8" ESP completion + Heat trace/Cap Inj.tbg from 2.600'to 4.360',Testing cable and cap line every 2.000'. Park @ 4,360' and make cable splice to 2nd ESP Spool.Test cable and capillary line. Continue to RIH with ESP/Heat Trace completion from 4,360'to 4,595'.Armor on ESP splice came undone: repair and test(good). Continue to RIH with ESP/Heat Trace completion from 4,595'to 5,030'. Cap Inj. line Estimate for length was to short, add 6'test (good). Make up hanger, install penetrators and terminate cap inj. line @ hanger. Make final splice on ESP and Heat trace and install to tubing hanger. Land hanger @ 5,062' (44k) string weight, run in lock downs, laydown landing jnt. P/U 86k S/O 82k(top drive 38k). Set TWC, N/D BOP's N/U Tree. 12/4/2015- Friday Continue to N/U Tree.Test Tree and Tubing Head adapter to 5,000psi.Test good. Pull TWC. Clean up cellar area. Use crane to remove spoolers and associated equipment from rig floor. RELEASE RIG FROM J-09A @ 08:00 Hrs. Prep to move Nordic 3 to K-30. 12/5/2015-Saturday No activity to report. 12/6/2015 -Sunday No activity to report. 12/7/2015 - Monday No activity to report. 12/8/2015-Tuesday No activity to report. OF Tye ID • c THE STATE Alaska Oil and Gas ofA tAsKA Goseati®n Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALA`*P' Fax: 907.276.7542 2 42-° www.aogcc.alaska.gov Bo YorkelkO Operations ManagerI I Hilcorp Alaska, LLC I 3 800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool,MPU SB J-09A Sundry Number: 315-703 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster ,�/� Chair DATED this 17'clay of November, 2015 Encl. a 1Q1� M \tC, i • _ a .. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION y APPLICATION FOR SUNDRY APPROVALS pz7s '41 '7 f 1 S 20 AAC 25.280 ` k ' ` ,pp L,'s, 1.Type of Request: Abandon ❑ Plug Perforations 9 Fracture Stimulate 9 Repair Well p 0 Operations shutdown❑ Suspend p Perforate ❑ Other Stimulate 9 Pull Tubing 9 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 9 Re-enter Susp Well 9 Alter Casing 0 Other. ESPCP Change-out 9 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development 9. 199-114 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK,99503 50-029-22495-01-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / MILNE PT UNIT SB J-09A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 ' MILNE POINT/SCHRADER BLUFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,235 . 4,046 - 8,235• 4,046 - 1,075 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 112' 112' 1,730 psi 740 psi Surface 2,936' 9-5/8" 2,936' 2,529' 5,750 psi 3,090 psi Production 5,334' 7" 5,334' 3,828' 7,240 psi 5,410 psi Liner 938' 4-1/2" 6,137' 4,060' 8,430 psi 7,500 psi Slotted Liner 2,098' 4-1/2" 8,235' 4,060' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic • See Attached Schematic 2-7/8" 6.5#/L-80/8RD EUE 5,063' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker ZXP Liner Top Packer and N/A • 5,199'(MD)/3,749'(1VD)and N/A 12.Attachments: Proposal Summary 9 Wellbore schematic 9 13.Well Class after proposed work: Detailed Operations Program 9 BOP Sketch 9 Exploratory 9 Stratigraphic ❑ Development 9• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/27/2015 OIL ❑ - WINJ 9 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 9 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact PAUL CHAN Email Achan@hilcorp.com Printed Name Title BO YORK Operations Manager Signature Phone Date ,77,/,' 907-777-8435 \3 M ,/ I % COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3(S- `70° Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4- 3 00& / S;, gj 6 / ' S t` ( M ' = I O T r a ) 4oIn‘i 1 A 2.015 Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS %1 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: Jo"''(09 APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date:/�— /7_ /s— /11(o-�� OrR464clin Submn Form ane Form 10-403 evise 1/2075 }�v lid for 12 months from th d to f ap oval / Attachments in Duplicate • • • Well Prognosis Well: MPU J-09A Hilcarp Alaska,LL Date: 11/13/2015 Well Name: MPU 1-09A API Number: 50-029-22495-01 Current Status: SI Oil Well [ESPCP] Pad: 1-Pad Estimated Start Date: November 27th, 2015 Rig: Nordic#3 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-114 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,475 psi @ 4,000' TVD (Last BHP measured 3/03/200 Hci. � 17. Maximum Expected BHP: 1,475 psi @ 4,000' TVD (No new perfs being added) / Current Shut-In Tbg Pressure: 20 psi (Based on current SITP w/existing fluid column) Max. Predicted Surf Pressure: 1,075 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: The Milne Point J-09A well was redrilled as a Schrader Bluff development well that TD'd at 8,235' and ran 4.5" slotted liner into open hole in December 1999. The well was initially completed with a through tubing ESPCP (Electrical Submersible Progressive Cavity Pump), but failed immediately upon install.This was replaced with an ESP in January 2000.This failed and subsequent ESPs were replaced in 2003 and 2008.The traditional ESP was replaced with an ESPCP in 2013.That pump failed February 9, 2015.The pump was replaced in May 2015 with the Nordic#3. During a power outage in August 2015, the well was unable to sustain flow due to solids build up inside the tubing. A CT FCO cleaned out sand to the top of the ESPCP in September. The ESPCP is still electrically effective, but unable to surface fluids.The last 7"casing test was performed to 2,000psi on 4/06/2013. There are minimal observed scale issues, most failures are related to solids production. No subsidence issues are expected in this well.A caliper was run on the upper 1,000' of 7" casing in April 2013. Notes Regarding Wellbore Condition • Sand/mud in tubing up to 4,715' MD cleaned out with coil as of 9/14/2015. ' • Casing last tested to 2,000 psi for 30 min down to 5,121' MD on 4/06/2013. ' c`` • Lower GLM pocket left open as of 11/03/2015. Dummy valve set in upper GLM. ce His-6 Objective: The purpose of this work is to pull the failed ESPCP and run a new ESPCP. / Brief Procedure: WO Rig Procedure: 1. MIRU Nordic#3 WO Rig,ancillary equipment and lines to 500 bbl returns tank. 2. Pull BPV(if set) Pump down well with 8.5 ppg sea water down tubing and casing. - 3. Set TWC. ND Tree. NU 11" BOPE and test. 4. Test BOPE to 250 psi Low/3,000 p,s.i High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Nordic 3 BOP Test Procedure. • • • Well Prognosis Well: MPU J-09A Hilcorp Alaska,Li) Date: 11/13/2015 b. Notify AOGCC 24 hrs in advance of BOP test. c. Submit completed 10-424 BOPE test results within 5 days of completed test. d. Confirm test pressures per the Sundry Conditions of approval. e. Test VBR rams on 2-7/8"test joint. 5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor P the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking C>~ ' anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 6. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 7. MU 2-7/8" landing joint (EUE) and BOLDS. a. Contingency: (If landing joint won't make up to tubing hanger) (bad threads). b. MU spear and pull 10k tension over string weight on tubing hanger to confirm free. 8. Pull over string weight (approx.40k PU) on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 9. POOH. Rack back 2-7/8" tubing and lay down the failed ESP. a. Replace bad joints of tubing as necessary. b. Look for over-torqued connections from previous Doyon#16 tubing runs. 10. PU new 3.75" stator OD ESPCP and RIH with existing 2-7/8" 8RD EUE L-80 tubing. a. Run 2-7/8"XN profile. / \ b. Run Upper GLM at+/- 150'w/valve and Lower GLM at+/-4,850'w/valve.( '5 V' i' ) c. Run 3/8" external capillary string w/clamps down to base of ESP. \ d. Run heat trace to+/-2,500'. e. Ensure correct and adequate clamps for capillary string and heat trace. 11. Set base of ESPCP at+/-5,060' (Pump intake around +/- 5,030'). 12. Land tubing hanger. RILDS. Lay down landing joint.Test tubing hanger to 250/5,000 psi a. Note PU (Pick Up)and SO (Slack Off)weights on tally. 13. Set TWC. ND BOPE. 14. NU existing 2-9/16" 5,000#tree and test to 250 psi low/5,000 psi high. Pull TWC. 15. RD Nordic#3 WO Rig,ancillary equipment and lines to 500 bbl returns tank. 16. Replace IA x OA pressure gauge if removed (7"x 9-5/8"). 17. Turn well over to production. RU well house and flowlines. • S Well Prognosis Well: MPU J-09A ffilcoru Alaska,LLQ Date: 11/13/2015 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. Nordic#3 Flow Diagram 7. Blank RWO Changes Form H . 0 Milne Point Unit Well: MPU J-09A SCHEMATIC Last Completed: 4/29/2015 Hiker])Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm {to to 1::4'. 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/8" ( 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' .r y 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' i.,. 1 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' ',,r ' TUBING DETAIL i 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,063' 9 3/8" Capstring Stainless Steel N/A 0 5,063' JEWELRY DETAIL 9-5/8"le No Depth Item Heat 1 139' 2-7/8"x 1"Side Pocket KBMM w/DPSOV T @ 2 4,853' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi 2' 3 4,994' 2-7/8"XN Nipple(2.25"ID) 4 5,006' WeIlLift Discharge Gauge Unit 38" ny 5 5,009' Centrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,033' Flex Shaft Assembly EUE 8rd Box 7 5,043 Single Seal Section 8 5,049' Gear Reduction Unit GRU 538(311.57:1 9 5,051' Motor MSP1/54 HP,890 Volt,39 Amp 10 5,059' WeIlLift MGU w 6 fin Centralizer—Bottom @ 5,063' 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 2 16 8,235' 4.5"Baker Drillable Guide Shoe III WELL INCLINATION DETAIL 13 KOP @ 600' Max Hole Angle=59 deg. @ 3,300—3,500' vm 4 MaxHole Angle=Horizontal I 5 Pc() 6 OPEN HOLE/CEMENT DETAIL 7 13-1- 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 8 fr-,�4- 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 9 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole _'4' 10 TREE&WELLHEAD Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT 11 threads top and bottom and 3"CIW H PBV Profile 45"BonzaiCompletion`ii `` GENERAL WELL INFO w.Hor¢Slated Liner :; .f iii 12 API:50-029-22495-01-00 111 Drilled and Cased by Nabors 22E -1/14/1995 y 13 Completion by Nabors 4ES—2/15/1995 A a 14 Schrader Bluff Recompletion by Nabors 4ES—4/19/1997 killed 6-1/8"Wisdom@ Schrader Bluff Sand Test#2—8/15/1997 5,334'to5,345(17) Sidetracked By Nordic 3—12/15/1999 I: RWO by Nabors 4ES—1/24/2000 Clean-cut to 7,075 RWO by Nabors 4ES—12/11/2003 an 4/28/2015 ESP RWO by Nabors 3S—6/16/2008 RWO PCP Pump by Doyon 16—4/13/2013 ,Iiiit ESP Change-out by Nordic 3—4/29/2015 CT Fill Clean-out 9/14/2015 ¢u2„ 1516 TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(1VD) Revised By:TDF 10/1/2015 . U H . PROPOSED SCHEMATIC Last Completed: Proposed Hilcorp Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0Size Type Wt/Grade/Conn ID Top Btm w =s 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' r o ± 9-5 /8" Surface 40/L-80/Btrc. 8.835 0 2,936' 1.13-3/8" 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' e 1 J.44, 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' ,a 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' TUBING DETAIL >;; 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 ±5,060' ))7 ` JEWELRY DETAIL 9-5/8"rN W 9tan3b N�7 No Depth Item 1 ±150' 2-7/8"x 1"Side Pocket KBMM w/DPSOV Heat Trace@ 2 ±4,850' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi 2' 3 ±4,990' 2-7/8"XN Nipple(2.25"ID) 4 ±5,001' WeIILift Discharge Gauge Unit 3/8 raF bn9 5 ±5,004' Centrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 ±5,028' Flex Shaft Assembly EUE 8rd Box 7 ±5,038' Single Seal Section 8 ±5,043' Gear Reduction Unit GRU 538B 11.57:1 9 ±5,045' Motor MSP1/54 HP,890 Volt,39 Amp 10 ±5,055' 3/8"External Capillary String 11 ±5,055' WeIILift MGU w 6 fin Centralizer-Bottom @ 5,060' 12 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 13 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 14 6,013' Baker HMCV Cement Valve 15 6,032' Baker CTC 20'PZP ECP 2 16 8,190' 4.5"Baker Drillable Pack-Off Bushing 111 17 8,235' 4.5"Baker Drillable Guide Shoe I s WELL INCLINATION DETAIL KOP @ 600' 4 rc- Max Hole Angle=59 deg. @ 3,300-3,500' 5 MaxHole Angle=Horizontal 6 7 OPEN HOLE/CEMENT DETAIL 8 r� 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 9 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole . 10 11 TREE&WELLHEAD Tree Cameron 2-9/16"5M :' 12 Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/8RD 4.5'Bola Carpleticn :: :< threads top and bottom and 3"CIW H PBV Profile w'Holz.Slotted Liner i '`• iiii ' : 13 n GENERAL WELL INFO f 533,x, API:50-029-22495-01-00 iii ii 14 Drilled and Cased by Nabors 22E -1/14/1995 0 *15 Completion by Nabors 4ES-2/15/1995 Idled 6-va'Wnd @ Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 5,334'to 5,346'(17) 111111 Schrader Bluff Sand Test#2-8/15/1997 Sidetracked By Nordic 3-12/15/1999 Gearroutto7,W5 111111; RWO by Nabors 4ES-1/24/2000 m 4/182015 l 1111111. RWO by Nabors 4ES-12/11/2003 ESP RWO by Nabors 3S-6/16/2008 1111111 RWO PCP Pump by Doyon 16-4/13/2013 11111111 16 ESP Change-out by Nordic 3-4/29/2015 4-1/2" 17 CT Fill Clean-out 9/14/2015 TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:STP 10/15/2015 • ! Milne Point Nordic#3 Class III BOPE 1.1.1, 11/12/2015 11111.11...1111111111111 O ,r n rel rfl � int1L 1 L Hydril 11" 5M felall nal 111 I � C41Cf-- Shaffer ®® 2 7/8"-5-%2" VBR • 11" 5M tx) Blinds 'a E. — 3 1/8 5M Kill Valves i 3 1/8 5M Choke Valves Manual and HCR Manual and HCR IFF 4Vr ile0 • U I'1L it l l` I' I " " A. 4 Y Y _ „ 4 Y Y _ Y . „ „ ” " 4 Y • a Y • „. „.„. _ ” o " . "" . " w" ti �U " 4 1111 it •(1001 Vii" „_ w"_" .v."..4/'..'4A...:„, " . . Y " ., .1,,, '.v."..'..• _ ♦1 -.A."'*A6_7.MF,.y„a0'.,...s-.M14A,,''>"A.,...',..AA...'....''.*...,..v.v:..',.A..A.AA"A.A....4:'"A.,VV,.:.Vv.:.V'...,I " . "+ " „ „ 4LF.Alli; mil. ..,41 . . ...%%.,,,..,,%,.,%,., YyY " v4 Y. a w ” A. Y CO „ �i ”__._ ..__. ._." .."".. .III .7 141 ii . „, _ , . . „ . „ . „ : gu.,.. . ,,,„ ,:„ 0 :.'::::: ::: ::::: " '" v'Mi7=^*.O.:aii:::.i.*::'i:::: „ „ ,, iiP(15 .....7*.....v,T.v.svAv.v,v,,,v...v.„%v*v.,,,v,.........v...v„,v,„ ir COkfi .....'y v w v V+y v w v (II) 4 ": AYE Y�Y Y 4 w". "Y"Yw "AAAA:': AA Y. . Y „4 „ Y "" Y 4 . Y " (41) .a emir.,-wi .., w t = = iti V^.^.'.' '.^ .. . . . . . . . . v V.4 4. . YY . YY . 4 = •11111 : v y y v y 01111C rr, ........„.„ 14 .I�I I�. .I I I� .I .,„... ;., :,,B a . . . . v .. . " . . . a . . . 4 . . . A . . . A A . AA a " . AA +- AA r - , ..: ::,:,:... .„, , .. .. „.... ... ........ . .,_ . .. .vv . y , ..y, A v ,. ,, ,, , , , v y ,, # vw A " III-II I-II 1^111 r w+ 4 v w,Y I II 1 II 1 11 Iv. 'i,..*4 P18 a w w a a v " a w "" v w .a + w w+ " .av Y 4 A . v Y 4 v r 4 v v w " " a „ „ > ♦ w v Y mJ P ,V'.V.VV.V r*V.%/...... V r'....V'V.V^V^V'V.../..V%V..'V^V.'V r.V^V.'V r.'.'...'V r'''.^V.'V'V'VV.14•s. ^ -.. k 3 w..4 a w w „w + w + " +. w " 4 v v v "" ' " 0 gw a _ _ yAr'vAyAy%AyAr''.A.AvA'..AyAwAyAvA..,AvAwAvAvA.AmAyA.A.A.A.AA,AvArAvAvAy^.AVAvAvAyA.A, -P '. A.A.AyA.^.A.A.%AyAr'svAyAv%AyAw^vAvArr%AyAv^vAyAr^wAYAW' v O d • • Il EXISTING TREE/WELLHEAD MPU J-09A Wellhead/Tree iiii.•nrp:Uacka,HA Milne Point Unit 0 Tree Cap ... ... rfet` 0O Tree Valve 2-9/16"5M $;;."5"e ... .. Tree Cross 2-9/16"5M I[o(, 1o)® Tree Valve 2-9/16"5M SSV 2-9/16" 5M O rllnlor Tree Valve 2-9/16" 5M : • i o`e. 40 ..i INES'.. ESP Cable ... Heat Trace �—� Control Line 5 Tubing Adapter _ ....1 „,Tubing Head 1I1 _ ,.Ills 11"5M Top x 11" 5M Bt : :/1 -,11S)11* ' 16, 10111 ,� 5 1 II 111 :...0 A 11.E • ..f 1�1 Casing Head i� — fes1,0 ' n11"5M Top x 11"5M Btm IIIIlj, NEI -4 nu ,-4 ,ir III t \I.1 • • 0 m co z : Ha s GS . , waY Z n 1011[11...f u 5 m Z v W ES w 1 — - Ia 7 0:401P4 5 • k2 *4 w • t.4 g § • i L' t'1 " ' : x „ _ 0:4 : o Lu d o < PAj LL f , 1�4 s fr 4 ao f rco a W2 LL w;. ' T':-1 ifi o OiY U u 11 ?'.1 0 11" f f u I IY '.. m _ i ♦-. E S' n f 2 I Y I .. I II eon.,alma see Y " N MI MN X N t.. —mg_ U a U 1 1./ f 1 U o f �• - ^ 0.4 2 e^ o U o U = U f . ., ,: ... i '� a s w ___ t, f i g v • .. . •. d 2 x o _ i $� C �'o f u : 1./ u o • � U Iiiiiti WJ 014 o IF ki O j .Y �4 11 �L� • • a) 0 . ai DC) a) cat cmm U r) d R = (1) P 0 0 V E ° 5 ce c ° V c a) aa)) Oo ° = aa)) 0 0 Q a °) T Qa L Da) � � a) v) Y > C. Q c- al a) I- (6 .(1) V — 2 a) d CO 0) Y fal >+ � 0 0 N N CU Itl 2 d mF. 0) i E C O d N N L L U L o 4 a) o Q V -0 Q oa) o > co a -) o ` 0. -o Las § _° • 0 cu c o 4. � � v O a • 0 i o - a) a` _ - 5 0 - a) Z' 3 U a) c • ` a) IZ cnCO co c U5. o c)--1 oL fx a-1 H O o a rA cd w x ° 3 ate,) H R Cet CD 4-4w x c .ID ea. r C.) Co 64 y V x c° Q ii 0o Q" ii o _ Oi x U = EU U ° .0 aU as a > as 0 V UoU) ) �Qoa)U) QQ `a • 1, of 77 4717,\ \7 I�7, sv THE STATE Alaska Oil and Gas o f LAsKA Conservati®n Commission _ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 STM,, GOVERNOR BILL WALKER ora g Main: 907.279.1433 C7";,41;\ Main: Fax: 907.276.7542 www.aogcc.alaska.gov Stan Porhola `,," '-EP SAN 1 4 2*(1j), Operations Engineer Q j Hilcorp Alaska, LLC t, t 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil, SB J-09A Sundry Number: 315-653 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this day of November, 2015 Encl. RBDMS V 12 2015 • • RECEIVE STATE OF ALASKA OCTA6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION nl. )1160g— APPLICATION FOR SUNDRY APPROVALS ,r'rr+ 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ ' -' II Clean-out 0 Plug for Redrill❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: ESPCP Change-out 0 2.Operator Name: '4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ - 199-114 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22495-01-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT SB J-09A • 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0025517, Milne Point Field/Schrader Bluff 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): 8,235 - 4,046 { 8,235 , 4,046 - N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' 1,730psi 740psi Surface 2,936' 9-5/8" 2,936' 2,529' 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,828' 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' 4,060' 8,430psi 7,500psi Slotted Liner 2,098' 4-1/2" 8,235' 4,060' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 5,063' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker ZXP Liner Top Packer and N/A . 5,199'(MD)/3,749'(TVD)and N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Strati ra hic g p ❑ Development ✓❑ s Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: t k/ o ( 1`,., OIL ❑✓ ti WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Stan P. ola Title Operations Engineer Signature i l Phone 777-8412 Date 10/16/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316 -4 SS Plug Integrity ❑ BOP Test 1 Mechanical Integrity Test ❑ Location Clearance111# Other: ?,.,r 4) (05:. Std/ /es ( /IA ,. fes'_ /a0vosL 11 i 0 4/1/ RBDM 7 �� NN°V i 2 2015 Spacing Exception Required? Yes CI No Subsequent Form Required: / .- '`it s..'-` r i ')/n APPROVED BY Approved by: I/ // COMMISSIONER THE COMMISSION Date: I/ .....-/5 ® R r -INA,� Submn Form ane Farm 10-403 Revised 5/2015 O�rlvly 1 valid for 12 months from the date of a proval. Attachments in Duplicate 111 Well Prognosis Well: MPU J-09A Hilcorp Alaska,LL, Date: 10/15/2015 Well Name: MPU J-09A API Number: 50-029-22495-01 Current Status: SI Oil Well [ESPCP] Pad: J-Pad Estimated Start Date: November 5th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-114 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,475 psi @ 4,000' TVD (Last BHP measured 3/03/2015) Maximum Expected BHP: 1,475 psi @ 4,000' TVD (No new perfs being added) Max. Allowable Surf Pressure: 10 psi (Based on SBHP taken 3/03/2015 and water cut of 33% (0.366psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: The Milne Point 1-09A well was redrilled as a Schrader Bluff development well that TD'd at 8,235' and ran 4.5" slotted liner into open hole in December 1999. The well was initially completed with a through tubing ESPCP (Electrical Submersible Progressive Cavity Pump), but failed immediately upon install.This was replaced with an ESP in January 2000.This failed and subsequent ESPs were replaced in 2003 and 2008.The traditional ESP was replaced with an ESPCP in 2013.That pump failed February 9, 2015.The pump was replaced in May 2015 with the Nordic#3. During a power outage in August 2015, the well was unable to sustain flow due to solids build up inside the tubing.The ESPCP is still electrically effective, but unable to surface fluids with the solids on top of the pump.The last 7"casing test was performed to 2,000psi on 4/06/2013.There are minimal observed scale issues, most failures are related to solids production. No subsidence issues are expected in this well.A caliper was run on the upper 1,000' of 7" casing in April 2013. Notes Regarding Wellbore Condition • Sand/mud in tubing up to 4,715' MD as of 8/20/15. • Casing last tested to 2,000 psi for 30 min down to 5,121' MD on 4/06/2013. Objective: The purpose of this work/sundry is to pull the failed ESPCP, cleanout fill inside the slotted liner completion and run a new ESPCP. Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Reverse circulate at least one casing volume with 8.5 ppg sea water down casing, taking returns up tubing to 500 bbl returns tank. 6. Pump at least one tubing volume of 8.5 ppg seawater down tubing. • • Well Prognosis Well: MPU J-09A Hilcorp Alaska,LL Date: 10/15/2015 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 8. RD Little Red Services Pump and reverse out skid. 9. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD crane. 10. NU BOPE house. Spot mud boat. WO Rig Procedure: 11. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 12. Pull BPV. Bleed any pressure off tubing and casing. 13. Kill well w/8.5 ppg seawater as needed. Set TWC. 14. Test BOPE to 250 psi Low/3,000psiHigh, 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 hrs in advance of BOP test. b. Test VBR rams on 2-7/8"test joint. c. Test Pipe rams on 2-3/8" test joint. c-' 15. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking \i1K, anywhere at surface.) c �� d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 16. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. Pull TWC. Bleed any pressure off tubing and casing. Kill well w/8.5 ppg seawater as needed. 18. MU 2-7/8" landing joint (EUE) and BOLDS. ` --�f-- 19. Pull over string weight (approx. 36k PU) on tubing hanger to confirm free. LD tubing hanger. 20. POOH. Lay 2-7/8"tubing on the pipe rack(plan to re-run tubing). Lay down ESPCP. 21. MU 6-1/8" bit and casing scraper and RIH w/2-7/8"tubing. 22. Scrape 7" 26#casing down to+/-5,199' MD (ZXP Packer). 23. POOH. Lay 2-7/8" tubing on the pipe rack. LD bit and casing scraper. 24. MU 3-5/8" mill, 2-7/8" motor,jars and RIH 100 jts of w/2-3/8" 5.95# PH-6 tubing. 25. MU crossover from 2-3/8" PH-6 x 2-7/8" EUE tubing. " 26. RIH w/2-7/8" tubing and clean out fill to PBTD,at+/-8,235' MD. FCC' �IA a. Min ID is 3:844" at Indicator Subs at+/-6,005' and 6,025' MD. in b. Drift ID of liner is 3.833". 'P� 27. Attempt to circulate fill out of hole.Take returns to 500 bbl returns tank. tie IQ1- EC() ci Ju+ S— a' /I/6 1-461- • Well Prognosis Well: MPU J-09A ❑;ie°"'Alaska,LLDate: 10/15/2015 a. Clrc 20-40 bbl hi-vis sweeps using 8.5 ppg sea water w/N-VIS at 2-4 lb/bbl. 28. POOH. Lay down 2-3/8" and 2-7/8"tubing on the pipe rack. LD mill, motor and jars. 29. PU new 475 series ESPCP and RIH with existing 2-7/8"8RD EUE L-80 tubing. a. Run 2-7/8"XN profile, 2 ea GLMS, and heat trace to+/-2,500'. b. RU to use clamps to secure heat trace to tubing (ensure adequate clamps). 30. Set base of ESPCP at+/-5,060' (Pump intake around +/- 5,030'). 31. Land tubing hanger. RILDS. Lay down landing joint. a. Note PU (Pick Up) and SO (Slack Off)weights on tally. 32. Set BPV.Test tubing hanger to 250/5,000 psi. 33. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 34. RD mud boat. RD BOPE house. Move to next well location. 35. RU crane. ND BOPE. NU existing 2-9/16" 5,000#tree. Pull BPV. 36. Set TWC. Test tree to 250/5,000 psi. Pull TWC. RD crane. 37. Move 500 bbl returns tank and rig mats to next well location. 38. Replace IA&OA pressure gauges if removed (7" &9-5/8"). 39. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic • • Milne Point Unit 11 Well: MPU J-09A SCHEMATIC Last Completed: 4/29/2015 Hilcorp Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' ►f it 1 ), 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/8" 07" Intermediate 26/L-80/NSCC 6.276 0 5,334' 4-1/2" liner 12.6/L-80/IBT 3.958 5,199' 6137' ,.•-' 1 4-1/2" Slotted Liner 6.2/L-80/SLT TUBING DETAIL 3.958 6,137' 8,235' (;i ' t 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,,063' w' 3/8" Capstring Stainless Steel N/A 0 5,063' fa JEWELRY DETAIL 95/g'. ll No Depth Item 1 139' 2-7/8"x 1"Side Pocket KBMM w/DPSOV Heat Trace@ 2 4,853' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi 2'500 3 4,994' 2-7/8"XN Nipple(2.25"ID) 4 5,006' WeIILift Discharge Gauge Unit 36'SSCapstring 5 5,009' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,033' Flex Shaft Assembly EUE 8rd Box 7 5,043 Single Seal Section 8 5,049' Gear Reduction Unit GRU 538B 11.57:1 9 5,051' Motor MSP1/54 HP,890 Volt,39 Amp 10 5,059' WeIILift MGU w 6 fin Centralizer—Bottom @ 5,063' 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 2 16 8,235' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL 3 KOP@600' Max Hole Angle=59 deg. @ 3,300—3,500' MaxHole Angle=Horizontal 5 6 OPEN HOLE/CEMENT DETAIL „. 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole '" 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/400 sx Class"G"in 8-1/2"Hole a 9 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole 10 TREE&WELLHEAD Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT 11 threads top and bottom and 3"CIW H PBV Profile 4.5'Bonzai Completion iiii mi Horiz.Slotted Liner GENERAL WELL INFO 12 API:50-029-22495-01-00 Drilled and Cased by Nabors 22E -1/14/1995 Y i;' iE 13 Completion by Nabors 4ES—2/15/1995 dA A 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 Nilled 61/8°\Aindow , Schrader Bluff Sand Test#2—8/15/1997 5,334'to5,345(17) IIIIII Sidetracked By Nordic 3—12/15/1999 RWO by Nabors 4ES—1/24/2000 Clean-out to 7,075' III • IIIy RWO by Nabors 4ES—12/11/2003 m4/28/2015 1111111 i ESP RWO by Nabors 3S-6/16/2008 ( RWO PCP Pump by Doyon 16-4/13/2013 .1111111' ESP Change-out by Nordic 3—4/29/2015 4-1/2" 111111 116 CT Fill Clean-out 9/14/2015 TD=8,235'(MD)/TD=4,064'(1VD) PBTD=8,235'(MD)/PBTD=4,064'(1VD) Revised By:TDF 10/1/2015 H . Milne Point Unit Well: MPU J-09A PROPOSED SCHEMATIC Last Completed: Proposed Hilcorp Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm ' 70 #= -:, L 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112'ii `06,14 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/8" j 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' t4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' t 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' ' TUBING DETAIL v. i 14 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 ±5,060' ak. 1 JEWELRY DETAIL 9-5/8'`� No Depth Item 1 ±150' 2-7/8"x 1"Side Pocket KBMM w/DPSOV Heat Trace @ 2 ±4,850' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi ±2'503' 3 ±4,990' 2-7/8"XN Nipple(2.25"ID) 4 ±5,001' WeIILift Discharge Gauge Unit tri"9 5 ±5,004' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 ±5,028' Flex Shaft Assembly EUE 8rd Box 7 ±5,038' Single Seal Section 8 ±5,043' Gear Reduction Unit GRU 5388 11.57:1 9 ±5,045' Motor MSP1/54 HP,890 Volt,39 Amp 10 ±5,055' 3/8"External Capillary String 11 ±5,055' WeIILift MGU w 6 fin Centralizer-Bottom @ 5,060' 12 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 13 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 14 6,013' Baker HMCV Cement Valve 15 6,032' Baker CTC 20'PZP ECP 2 16 8,190' 4.5"Baker Drillable Pack-Off Bushing 17 8,235' 4.5"Baker Drillable Guide Shoe II WELL INCLINATION DETAIL 3 KOP @ 600' 4 Max Hole Angle=59 deg. @ 3,300-3,500' 5 MaxHole Angle=Horizontal 6 7 OPEN HOLE/CEMENT DETAIL 8 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 9 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole 10 11 TREE&WELLHEAD Tree Cameron 2-9/16"5M 12 Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/8RD 4.5"Balza Canpietiai iii threads top and bottom and 3"CIW H PBV Profile Nd Hai.Slatted Lina ilii •.. 13 GENERAL WELL INFO API:50-029-22495-01-00 14 Drilled and Cased by Nabors 22E -1/14/1995 $15 Completion by Nabors 4ES-2/15/1995 trilled 61/8"Wndow@ Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 5,334'to5,348(77) Schrader Bluff Sand Test#2-8/15/1997 Sidetracked By Nordic 3-12/15/1999 Cleon-a,tto7,075 , RWO by Nabors 4E5-1/24/2000 on4/28/2015 RWO by Nabors 4ES-12/11/2003 ESP RWO by Nabors 3S-6/16/2008 RWO PCP Pump by Doyon 16-4/13/2013 'E' ESP Change-out by Nordic 3-4/29/2015 4-1/Y' ! 167 CT Fill Clean-out 9/14/2015 TD=8,235'(MJ)/TD=4,064'(TVD) PBTD=8,235'(ND)/PBTD=4,064'(1VD) Revised By:STP 10/15/2015 • • . tili Milne Point 2015 ASR Rig 1 11,1.“,i, %i.�.►.�.1.11 Knight Oil Tools BOP / \ Stripping Head G haffé 1111 _ 5000 1.11 1M1 III 1111111 4ii, 111P all I/ liJJUJIWI alf CT:IJ Ca _U I : 27/8- 5VBR H C 11” ® 000F111_,104_, H Blind ca, II .I_ Ilviii ivIri c v: 'Iles 'i “ ii T(-. ' t ' '- j Ali owi � 23/8 Pipe H ( 1111: 000fil_let ,11 I P-3 H I T' 11_11 tU1 ii iii iii iii iii Updated 10/15/15 • • II Choke Manifold ASR#1 09/29/2015 Ifilnorp %Isola.I I i Digital Reverse line back to Kill Line Pressure Readout rtc'1 C2 �O�a vs*kvoD C3 IL Digital Pressure Transmitter; — __ - Nt C5 1 1t011 0 0 � From Choke Line Manual Choke ��I 0 O I B y� a ;,;. 0n O et / N "' Remote A Choke C4 C5 lel � C6 C7 Ns i 7 7 F 00 0 00 ..1 E 7 : € _,, ., .. , H I :el : 1 r,. _ t , b. , . b. 01 tr I NI ui, III lima C9 MIN 0 _ All Valves 2" 5,000 psi ., I Piper Series PB Ball Valves PIT C8 - C11 IMI C10 Mk-if u iii` t I C13 ... C15 / ..,111 r,: O � 0 ., o � � i 0 � p . III _ 1 I � O c� COQ O O p n 0 'oav ; 0 �O 0 r. C12 O C14 C16 Clig To Panic Line 1502 Union Outside End Capped To Gas Buster • • EXISTING TREE/WELLHEAD MPU J-09A Wellhead/Tree Hilcorp Alaska,LLCMilne Point Unit Tree Cap 1 Tree Valve 2-9/16"5M ° 01) ,.. ., co I. Tree Cross 2-9/16"5M ;I10(0)81 Tree Valve 2-9/16"5M o SSV 2-9/16" 5M 0 0, Tree Valve 29/16" 5M _ � ESP Cable ,. Heat Trace Control Line Tubing Adapter111 . ,/ „ Tubing Head 11"5M Top x 11" 5M Bt - • IS I It. lin artry t--41:011 1 111 rii lbw le I- --- X1,1 Casing Head — �►��t - 44 11"5M Top x 11" 5M Btm Mill �' : ]� E /tl t .1111 0 • 7t E g ..t g A 72 A 74 1 . A 0 1 I X Z 12-313 0 ,0 Cal 0 TD u 013 913 1 0 0-, p i vi• .9 R.. . -• v: v • 0•4.•• .1,1 M F— W GO .-.7 —I Z Lai n )..n: 6 ID VID ,,, ...I ri Y m • ro 2 0§ °. •—I • 0 • 03 m 0 , 8 m 4 4 4114 8 4 83 IN• ,—I• l.). 16: Q.1 . .E ?: ; .,t) —I rel 3 a. o .c A -41 8- a ::4 0. o > 0 -- , •-.. 0 y A 3 2,5 - - . -. i' IMMEM—,..7 . - - 00 z - - - 71 • c a' - ,.. g i -4 1... — O , , --.....,t, co In -0 • . (1• le III c.. W C. •... . r 2 7 u Fc 0 D _,.5. co co cc 4 1 .. -MOO ii ..-.t'••-. r H I- 6. v, w D 03 4 t.9 2 -0O3- d —I I- R qg2 ,, A v, >. in I— HI— HF —N-- —I I-— 03 a (-- 0.. . 21 • • / \ k o -5 c2 \ 5 tia E � k � 2 0o . � � c � E ° ' o f E 0 0_S •§ « tea � Q 2 � 2 _ ± Yo ■m�I a \jj a. 0 RI 9.2 E / V - a © o � _ a 2 / z $� Cl o co it as / / "0 \CD \ @ -a ,- <C.) e = E O 9 > m o § L 2 co \ -o0 ea J f2 0 § k O ) � ' 0 u c 2 kft2 f / 0. a) \ F37 ■ ±« & c tz § / / . 2 Qp co I -0 > 24 o 2 © 2 2 - @ 1-1 L' < o_ 4-3 > O cos. . x (8 - .2 R ® Ct & 9 u) : t co a & / / a co k ¢ W S ( Q it .. « \ _ .. a n. 0 Z" ° 0 & > e E 2 f o a 0 f 0 2 2 \ / Cl a gl 0 U) RECEIVED STATE OF ALASKA OCT 3 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑1 Change Program 0 Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Fill Clean-out ❑� Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 2 Re-enter Susp Well ❑ Other: ESPCP Change-out ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑. 199-114 3.Address: Stratigraphic [1] Service El6.API Number 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22495-01-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 - Will planned perforations require a spacing exception? Yes ❑ No ❑ i MILNE PT UNIT SB J-094 1�(^f 9. Property Designation(Lease Number): 10. Field/Pool(s): \\ \\\ ADL0025517, Milne Point Field/Schrader Bluff Oil ' a 11. PRESENT WELL CONDITION SUMMARY // \ Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): iR `' Junk(measured): ' 8,235 • 4,046 ' 8,235 . 4,046 /A 0 N/A Casing Length Size MD TVD �7 ,,, Burst Collapse Conductor 112' 13-3/8" 112' 112' -( 1,730psi 740psi Surface 2,936' 9-5/8" 2,936' 2,.2• 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,8 ;'j. 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' t' 8430 7,500psi °` , psi Slotted Liner 2,098' 4-1/2" 8,235' 060' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: .ing e a.-: \ Tubing MD(ft): See Attached Schematic 1 See Attached Schematic 2-7/8" ' \ 6.5• x,AA9.0/EUE 8rd 5,063' Packers and SSSV Type: Pac S SV MD .nd VD (ft): Baker ZXP Liner Top Packer and N/A \ 5,199'(MD)/3,749'(TVD)and N/A 12.Attachments: Description Summary of Proposal ❑✓ 13. ell C:ss : - .•.posed\vork: Detailed Operations Program ❑ , BOP Sketch ❑ ./.)X'xploratork 111, Stratigraphic❑ Development 0' Service ❑ 14. Estimated Date for V tu 15.Well Staafter proposed work: Commencing Operations: 11/6/2015 1►-�" OIL ❑ • WINJ ❑ WDSPL 16.Verbal Approval: Date: N/A -� ;y°� GAS ❑ WAG El GSTOR ❑ Suspended ❑ Commission Representative: N/A % GINJ ❑ Op Shutdown ❑ Abandoned ❑ El SPLUG Ill u..)/ 17. I hereby certify that the foregoing is true and correct to th est of my knowledge. Contact Stan Porhola Email sporhola(a�hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature O Phone 777-8412 Date j(•/j0(6-- COMMISSION USE ONLY Conditions of approval: Notify Commissipfn so that a representative may witness Sundry Number: (� '] 5� 6 - vLoi Plug Integrity ❑ BOrTest ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: %AWED JAN 1 4 2.016 Spacing Exception Required? Yes ❑ No II Subsequent Form Required: RBDMS Nevi 1 2 2015 � APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: '121441 0/6- A l9� p' OdRiOnAisiamrt-INie Submit Form and Form 10-403 Revised 5/2015 Aproved aplication is date of approval. Attachments in Duplicate • Milne Point Unit Well: MPU J-09A . H tec., 4111 t� t�'3I/S SCHEMATIC Last Completed:4/29/2015 Hilcorp Alaska,LLC 1143 PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm PI 'i4 1111 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' le 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/8" . 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' lit 1 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' t: 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' TUBING DETAIL x 0 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,063' 3/8" Capstring Stainless Steel N/A 0 5,063' i JEWELRY DETAIL 9-5/8"4 te No Depth Item 1 139' 2-7/8"x 1"Side Pocket KBMM w/DPSOV Heat Trace@ 2 4,853' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi 2' 3 4,994' 2-7/8"XN Nipple(2.25"ID) 4 5,006' WeIILift Discharge Gauge Unit 3/8"SS Capstnng 5 5,009' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,033' Flex Shaft Assembly EUE 8rd Box 7 5,043 Single Seal Section 8 5,049' Gear Reduction Unit GRU 538B 11.57:1 9 5,051' Motor MSP1/54 HP,890 Volt,39 Amp 10 5,059' WeIILift MGU w 6 fin Centralizer-Bottom @ 5,063' 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 2 16 8,235' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL III 3 KOP@600' Max Hole Angle=59 deg. @ 3,300-3,500' a° 4 MaxHole Angle=Horizontal I 5 6 OPEN HOLE/CEMENT DETAIL 7 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 8 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/400 sx Class"G"in 8-1/2"Hole AT 9 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole MN Ai j • 10 TREE&WELLHEAD Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT 11 , threads top and bottom and 3"CIW H PBV Profile 4.5'Bonzai Completion 8 GENERAL WELL INFO w/Hariz Slotted Liner $,': :. 12 API:50-029-22495-01-00 Drilled and Cased by Nabors 22E -1/14/1995 7 p 13 Completion by Nabors 4ES-2/15/1995 A 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 Milled 6-1/8"Wndow@ Schrader Bluff Sand Test#2-8/15/1997 5,334'to 5,346'(12') i Sidetracked By Nordic 3-12/15/1999 RWO by Nabors 4ES-1/24/2000 Clean-out to 7,075' RWO by Nabors 4ES-12/11/2003 on4/28/2015 '1:::t ESP RWO by Nabors 3S-6/16/2008 RWO PCP Pump by Doyon 16-4/13/2013 ESP Change-out by Nordic 3-4/29/2015 CT Fill Clean-out 9/14/2015 41/2„ 15 16 TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(1VD) Revised By:TDF 10/1/2015 . . 11 H . • Milne Point Unit Well: MPU J-09A SCHEMATIC Last Completed: 4/29/2015 Hilcorp Alaska,LLC 'c.! 6/37 AP PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm i ` 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' to9 5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/8" 3., 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' 1 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' ft I 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' ti• 3TUBING DETAIL 3` 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,063' ' 3/8" Capstring Stainless Steel N/A 0 5,063' a, :, JEWELRY DETAIL :4 l' 9-5/8"'ts No Depth Item 1 139' 2-7/8"x 1"Side Pocket KBMM w/DPSOV Heat Trace@ 2 4,853' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi 2' 3 4,994' 2-7/8"XN Nipple(2.25"ID) 4 5,006' WeIILift Discharge Gauge Unit 3/8"SS Capstring 5 5,009' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,033' Flex Shaft Assembly EUE 8rd Box 7 5,043 Single Seal Section 8 5,049' Gear Reduction Unit GRU 5388 11.57:1 9 5,051' Motor MSP1/54 HP,890 Volt,39 Amp 10 5,059' WeIILift MGU w 6 fin Centralizer-Bottom @ 5,063' 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 2 16 8,235' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL 3 KOP @ 600' Max Hole Angle=59 deg. @ 3,300-3,500' ow 4 MaxHole Angle=Horizontal 5 m it6 OPEN HOLE/CEMENT DETAIL 7 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 4 WS 8 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/400 sx Class"G"in 8-1/2"Hole iii nu 9am 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole nut AQ 1- 10 TREE&WELLHEAD Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT 11 threads top and bottom and 3"CIW H PBV Profile 4.5"Bonzai Completion 8 i w/Horiz.Slotted Liner 0 (� GENERAL WELL INFO iC 12 API:50-029-22495-01-00 ': Drilled and Cased by Nabors 22E -1/14/1995 7 13 Completion by Nabors 4ES-2/15/1995 1! A 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 NlIled6-1/8'Wndoyv@ `; Schrader Bluff Sand Test#2-8/15/1997 5,334'to 5,346'(12') ' Sidetracked By Nordic 3-12/15/1999 1111111 RWO by Nabors 4ES-1/24/2000 Clean-out to 7,075' 1, RWO by Nabors 4ES-12/11/2003 on 4/28/2015 ESP RWO by Nabors 3S-6/16/2008 RWO PCP Pump by Doyon 16-4/13/2013 IIIIIIIII ESP Change-out by Nordic 3-4/29/2015 CT Fill Clean-out 9/14/2015 4-1/2" 15 16 TD=8,235'(MD)/TD=4,064'(1VD) PBTD=8,235'(MD)/PBTD=4,064'(ND) Revised By:TDF 10/1/2015 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 06, 2015 2:50 PM To: 'Stan Porhola' Cc: samantha.carlisle@alaska.gov Subject: RE: Disregard Sundry 315-677 (MPU J-09A PTD 199-114) Stan, The AOGCC will rescind sundry 315-677 per your request for J-09A. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@aknska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Friday, November 06, 2015 2:47 PM To: Schwartz, Guy L(DOA) Subject: Disregard Sundry 315-677 (MPU J-09A PTD 199-114) Guy, Please disregard Sundry 315-677 for well MPU 1-09A(PTD 199-114). Regards, Stan Porhola Operations Engineer North Slag.._ Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 1 STATE OF ALASKA • AIL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 1 j Plug Perforations Li Fracture Stimulate ❑ Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: CT Fill Clean-oUtL 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development❑., Exploratory ❑ 199.114 • 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22495-01-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 ' MILNE PT UNIT SB J-09A • RiC,CEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Schrader Bluff Oil • D C i 1 5 2015 11.Present Well Condition Summary: AOGCC Total Depth measured 8,235 • feet Plugs measured N/A feet true vertical 4,046 • feet Junk measured 7,075(Fill) feet Effective Depth measured 7,075 feet Packer measured 5,199 feet true vertical 4,050 feet true vertical 3,749 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' Surface 2,936' 9-5/8" 2,936' 2,529' 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,828' 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' 4,050' 8,430psi 7,500psi Slotted Liner 2,098' 4-1/2" 8,235' 4,046' N/A N/A Perforation depth Measured depth See Attached Schematic feet SCANNED True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 5,063' 3,675' 5,199'MD Packers and SSSV(type,measured and true vertical depth) ZXP Packer N/A 3,749'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 120 163 Subsequent to operation: 0 0 0 0 219 14.Attachments(required per 20 AAC 25.070..25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Li Exploratory Development 4 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas Li WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ • SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-162 Contact Stan Porhola Email sDorhola(C hilcoro.com Printed Name ,�(� /Stan Porhola Title Operations Engineer Signature rk�� of7��_ Phone 777-8412 Date 10/1/2015 Form 10-404 Revised 5/2015 e. A="1-4-": RBDMS1nrT 7 1 nig Submit Original Only 1 orr2(/c 14 • 0 Milne Well: Point MPU J-09Unit A SCHEMATIC Last Completed: 4/29/2015 Hilcorp Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm %' ! A 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' �' 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 133/8" * t' 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' 1 1 i% 4- 1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' . 8 s TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,063' 14 '' " 3/8" Capstring Stainless Steel N/A 0 5,063' i JEWELRY DETAIL 9-5/8" t le 1 No Depth Item 1 139' 2-7/8"x 1"Side Pocket KBMM w/DPSOV Heat Trace @ 2 4,853' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi 2500 3 4,994' 2-7/8"XN Nipple(2.25"ID) 4 5,006' WellLift Discharge Gauge Unit .SSnn9 5 5,009' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,033' Flex Shaft Assembly EUE 8rd Box 7 5,043 Single Seal Section 8 5,049' Gear Reduction Unit GRU 538B 11.57:1 9 5,051' Motor MSP1/54 HP,890 Volt,39 Amp 10 5,059' WellLift MGU w 6 fin Centralizer-Bottom @ 5,063' 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 1 13 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 2 16 8,235' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL 3 KOP @ 600' Max Hole Angle=59 deg. @ 3,300-3,500' "` 4 MaxHole Angle=Horizontal 5 6 OPEN HOLE/CEMENT DETAIL 11 7 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole ,. 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole ge 8 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 9 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole AIM •;= 1a TREE&WELLHEAD Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT 11 threads top and bottom and 3"CIW H PBV Profile 45'Baizaigxrpletion GENERAL WELL INFO w'Hort.Slotted Liner iiii y iiii iii 12 API:50-029 22495-01-00 Drilled and Cased by Nabors 22E -1/14/1995 y' ii 13 Completion by Nabors 4E5-2/15/1995 ill A 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 Allied 6-1/8"Wndwv@ Schrader Bluff Sand Test#2-8/15/1997 5,334'to 5,345(12) Sidetracked By Nordic a-12/15/1999 rilli RWO by Nabors 4ES-1/24/2000 Clean-cut to 7,075 RWO by Nabors 4ES-12/11/2003 m4/28✓2015 I ESP RWO by Nabors 35-6/16/2008 RWO PCP Pump by Doyon 16-4/13/2013 ESP Change-out by Nordic 3-4/29/2015 CT Fill Clean-out 9/14/2015 4-1/Z' _( 15 16 1D=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(M))/PBTD=4,064'(TVD) II Revised By:TDF 10/1/2015 • Hilcorp Alaska, LLC i,;,,.tg")_,,., k.,. ,,11A. Weekly Operations Summary Well Name _API Number Well Permit Number Start Date End Date MP J-09A 50-029-22495-01-00 199-114 9/13/2015 9/14/2015 Daily Operations: 9/9/15-Wednesday No operations to report. 9/10/15-Thursday No operations to report. 9/11/15-Friday No operations to report. 9/12/15-Saturday MIRU Coil Unit. 9/13/15-Sunday PJSM. Raised lubricator and BOP's.Connected BOPE hoses. LD flow cross off lubricator, made up 5k to 10k xo spool and 10k to 15k xo spool. RU 50bbI freeze protect tank to CT pump.Stabbed injector head onto riser, RU riser wellhead and secured.Offloaded 40bbls of 60/40. Pumped 35 bbls of 60/40 and broke circulation.SD Pump. Lined valves to perform full body Test. Performed shell test 250-3,500psi-test ok. Performed BOPE per AOGCC Reg:Valves 250-3,500psi, Rams 250- 3,500psi, Blinds 250-3,500psi and held for 5 mins. Performed drawdown-0 failures recorded. LD lubricator and injector head,SDFN. 9/14/15-Monday PJSM and discuss job to be performed. ND night ACP, MU injector to lubricator and PU off mass truck. MU CT connector and pull tested to 20k-Test Good. RD lubricator and injector head to BOP's, PT 4,000psi-test good.Circulated 35 bbls of 60/40 of freeze protect out of the coil to the 50bbI open top tank. Opened SSV with fuseable cap, pressured up coil to 500psi and opened well.SITP Opsi. RIH at 50 fpm, rolled over pump.5bpm at 500'. Continued in hole and tagged pump @ 4,998 CTM, pumped bottoms-up, returns crude, PW and trace of sand. PU 20'then RIH and comfirmed tag at 4,998'CTM. Lost curculation. PU CT 50'and parked.Started ESP and monitored well, no returns or BHP decrease.SD ESP pump.SI the choke and tried pressuring up the the production tubing with no luck.Confirmed shear valve was ruptured.Open choke back up and POOH with CT. RDMO CT Unit and associated equipment. 9/15/15-Tuesday MIRU CTU on 1-08. • ti OF TFJ evi) 1�jam,s� THE STATE Alaska Oil and Gas rw '-sem—'� of Conservation Commission � �-�� ALASI; 41 -14.---,--,-,'4:-E1-; 333 West Seventh Avenue �ti„ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OF ALAS' Fax: 907.276 7542 CANNED _ ;, www.aogcc.alaska.gov Stan Porhola a q... /I y' Operations Engineer ! t JJ Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-09A Sundry Number: 315-540 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1447 P9;tei cL Cathy P. Foerster Chair DATED this of September, 2015 RBDMS SEP 0 9 2015 Encl. RECEIVED STATE OF ALASKA AUG 3 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION p�-S `) icrr(S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request Abandon❑ Plug for Redrill ❑ Perforate New Pool p Repair Well T • Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other. CT Fill Clean-out ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development Q • 199-114 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22495-01-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 • Will planned perforations require a spacing exception? Yes 0 No 0 - MILNE PT UNIT SB J-09A 9 Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 - Milne Point Field/Schrader Bluff 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). 8,235 - 4,046 - 8,235 ' 4,046 - N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' 1,730psi 740psi Surface 2,936' 9-5/8" 2,936' 2,529' 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,828' 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' 4,060' 8,430psi 7,500psi Slotted Liner 2,098' 4-1/2" 8,235' 4,060' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic. See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 5,063' Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft): Baker ZXP Liner Top Packer and N/A - 5,199'(MD)/3,749'(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory 0 Stratigraphic 0 Development ❑., Service ❑ 14.Estimated Date for 15 Well Status after proposed work: Commencing Operations. 9/13/2015 Oil IA 0) Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ 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 Stan Porhola Email sporhola(c�hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ,,,,,j0. --- peri______ Phone 777-8412 Date 8/31/2015 - COMMISSION USE ONLY Conditions of approval. Notify Commission so that a representative may witness Sundry Number: 315 - 5yo Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other. 1 Spacing Exception Required? Yes 0 No Subsequent Form Required: /p -I 0 ^ APPROVED BY Approved by: L�„►.„ COMMISSIONER THE COMMISSION Date 9-8 /,5^ 1.2-is' fliid 4/NIIS— ` A- � it Form and Form 10-403(Revised 1 012) AGRalp&t f r • l f�r 12 months from the date.1'", SEP tt h int Duplicate Well Prognosis Well: MPU J-09A llilcor')Alaska.LL' Date:8/31/2015 Well Name: MPU J-09A API Number: 50-029-22495-01 Current Status: SI Oil Well [ESPCP] Pad: J-Pad Estimated Start Date: September 13th, 2015 Rig: Coil Reg.Approval Req'd? Yes _ Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-114 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,475 psi @ 4,000' TVD (Last BHP measured 3/03/2015) Maximum Expected BHP: 1,475 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surf Pressure: 10 psi (Based on SBHP taken 3/03/2015 and water cut of 33% (0.366psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: The Milne Point J-09A well was redrilled as a Schrader Bluff development well that TD'd at 8,235' and ran 4.5" slotted liner into open hole in December 1999. The well was initially completed with a through tubing ESPCP (Electrical Submersible Progressive Cavity Pump), but failed immediately upon install.This was replaced with an ESP in January 2000.This failed and subsequent ESPs were replaced in 2003 and 2008.The traditional ESP was replaced with an ESPCP in 2013.That pump failed February 9, 2015.The pump was replaced in May 2015 with the Nordic#3. During a power outage in August 2015,the well was unable to sustain flow due to solids build up inside the tubing.The ESPCP is still electrically effective, but unable to surface fluids with the solids on top of the pump.The last 7"casing test was performed to 2,000psi on 4/06/2013.There are minimal observed scale issues, most failures are related to solids production. No subsidence issues are expected in this well. A caliper was run on the upper 1,000'of 7" casing in April 2013. Notes Regarding Wellbore Condition • Sand/mud in tubing up to 4,715' MD as of 8/20/15. • Casing last tested to 2,000 psi for 30 min down to 5,121' MD on 4/06/2013. Objective: The purpose of this work/sundry is to clean out fill to the top of the ESPCP. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 2. RIH w/2.00" coil w/2.125" wash nozzle to TOF (top of fill) at+/-4,715' MD. 3. Wash down and cleanout to top of ESPCP+/-5,006' MD. POOH. a. Min ID is 2.25"thru XN-profile at+/-4,994' MD. 4. RD Coiled Tubing. 5. Turn well over to production. Attachments: Well Prognosis Well: MPU J-09A Ilileorp Alaska,LL Date:8/31/2015 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic Milne Point Unit Well: MPU J-09A II SCHEMATIC Last Completed: 4/29/2015 llilcorp Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm A r l'" / I to 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' Ili '' i" 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/8" M;„ v 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' 1 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' , 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137 8,235' TUBING DETAIL s? > 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,063' 3/8" Capstring Stainless Steel N/A 0 5,063' JEWELRY DETAIL s 9-5/8" le No Depth Item 1 139' 2-7/8"x 1"Side Pocket KBMM w/DPSOV Heat Trace @ 2 4,853' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi 2' 3 4,994' 2-7/8"XN Nipple(2.25"ID) 4 5,006' Welllift Discharge Gauge Unit 3/8 SS Capstring 5 5,009' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,033' Flex Shaft Assembly EUE 8rd Box 7 5,043 Single Seal Section 8 5,049' Gear Reduction Unit GRU 538B 11.57:1 9 5,051' Motor MSP1/54 HP,890 Volt,39 Amp Tag fill @4,715' I 10 5,059' WellLift MGU w 6 fin Centralizer-Bottom @ 5,063' 8/20/15 ,..-i. 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) Z?^% 12 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) a.i' 13 6,013' Baker HMCV Cement Valve tf+ 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 2 16 8,235' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL 3 KOP @ 600' Max Hole Angle=59 deg. @ 3,300-3,500' 'mit, 4 MaxHole Angle=Horizontal 5 6 OPEN HOLE/CEMENT DETAIL 41 7 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 8 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole - 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 1,41 9 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole 10 TREE&WELLHEAD Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT 11 threads top and bottom and 3"CIW H PBV Profile 4.5'Bonzai Completion How Slotted Liner GENERAL WELL INFO ,j 12 API:50-029-22495-01-00 ,,1 Drilled and Cased by Nabors 22E -1/14/1995 7 XiCompletion r4E -2/15/1995 ,� 13 by Nabors S 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 Nilled6-10Wndcw@ ,E Schrader Bluff Sand Test#2-8/15/1997 5,334'to 5,346'(12) Sidetracked By Nordic 3-12/15/1999 RWO by Nabors 4E5-1/24/2000 aean-art to 7,075' RWO by Nabors 4E5-12/11/2003 on 4/28(2015 ESP RWO by Nabors 3S-6/16/2008 _ RWO PCP Pump by Doyon 16-4/13/2013 ESP Change-out by Nordic 3-4/29/2015 ¢s/r' _ 15 16 1D=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:STP 8/31/2015 14 Milne Point Unit Well: MPU J-09A PROPOSED SCHEMATIC Last Completed: 4/29/2015 Hileorp Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm A ` 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' *VI 6 i i 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/8" i, 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' t 1 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' TUBING DETAIL ,0 3 f 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,063' 3/8" Capstring Stainless Steel N/A 0 5,063' St 1 JEWELRY DETAIL 9-5/8"'6r.No Depth Item 1 139' 2-7/8"x 1"Side Pocket KBMM w/DPSOV Heat Trace@ 2 4,853' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi 2' 3 4,994' 2-7/8"XN Nipple(2.25"ID) 4 5,006' WeIILift Discharge Gauge Unit 3/8"ss Cvstring 5 5,009' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,033' Flex Shaft Assembly EUE 8rd Box 7 5,043 Single Seal Section 8 5,049' Gear Reduction Unit GRU 538B 11.57:1 9 5,051' Motor MSP1/54 HP,890 Volt,39 Amp 10 5,059' WeIILift MGU w 6 fin Centralizer-Bottom @ 5,063' 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 2 16 8,235' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL I; 3 KOP @ 600' Max Hole Angle=59 deg. @ 3,300-3,500' ""' 4 MaxHole Angle=Horizontal ' S 6 OPEN HOLE/CEMENT DETAIL 7 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 8 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/400 sx Class"G"in 8-1/2"Hole allik a 9 4 -1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole sor 1 10 TREE&WELLHEAD Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT 11 threads top and bottom and 3"CIW H PBV Profile 45"BonzaiCompletion y GENERAL WELL INFO vd Horiz.Slotted Liner i 40 12 API:50-029-22495-01-00 Drilled and Cased by Nabors 22E -1/14/1995 7 �R 13 Completion by Nabors 4ES-2/15/1995 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 IVilled 6-1/8"VUrdcw@ Schrader Bluff Sand Test#2-8/15/1997 5,334'to 5,346(17) Sidetracked By Nordic 3-12/15/1999 ii. RWO by Nabors 4ES-1/24/2000 Clean-out to 7,075' owe RWO by Nabors 4ES-12/11/2003 m 4/28/2015 , ESP RWO by Nabors 3S-6/16/2008 RWO PCP Pump by Doyon 16-4/13/2013 ESP Change-out by Nordic 3-4/29/2015 41111111 4-1/2 1 16 1D=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:STP 8/31/2015 s . Milne Point Unit 11 COIL BOPE MPU J-09A ilaroA .p.AiA.t .i.1: 08/31/2015 MPU J-09A 13% X9%X7 X2% Coil Tubing BOP ME ILubricator to injection head Baal[ 111110 1.75"Tandem Stripper IIIIIIIIIIIII 1610 j•',I, Blind/Shear 1/16Mai'Blind/Shear , r' Ii'•'3 •11111 Blind/Shear - _~Blind/Shear liii - ®o C lilt Slip -- _E 01 Slip 1111111 11111 Pipe _ -W Pipe Malt / Mud Cross 11111111111111— IL). � M- 4 1 16 10M X 4 16 10M 7Outlet w/2-2 1/16 TOM full 1 I. — opening FMC valves imi gli W- ° iI . i (- O r full �'�.'°� � � � 111 ® ice Manual Manual Manual Manual 1 2 1/16 10M 21/1610M .r 2 1/16 10M 2 1/16 10M Crossover spool aasgay 4 1/16 10M X 2 9/16 5M IIIIIIIIIIIIIIIIII 0, 1., • ,tsi\L° Valve,Swab,WKM-M, ter,., NO' �F� 2 9/16 5M FE v - i �a�se 91165 .11.11.1 (i,Q2,; I Valve,Upper Master,Baker, 1 2 9/16 5M FE,w/Hydraulic Valve,Lower Master,WKM-M, illt'' 2 9/16 5M FE U MI IVINIZ MI Tubing Adapter,2 9/16 5M WI W STATE OF ALASKA AL .CA OIL AND GAS CONSERVATION COI. SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other. ES-PCP Change-out Q 2.Operator Name' 4.Well Class Before Work 5.Permit to Drill Number. Hilcorp Alaska,LLC Development Q Exploratory ❑ 199-114 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22495-01-00 7.Property Designation(Lease Number). 8.Well Name and Number. ADL0025517 MILNE PT UNIT SB J-09A RECE!VED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Schrader Bluff Oil JUN 04 2015 11.Present Well Condition Summary. o Total Depth measured 8,235 feet Plugs measured N/A feet �� true vertical 4,046 feet Junk measured 7,075(Fill) feet Effective Depth measured 7,075 feet Packer measured 5,199 feet true vertical 4,050 feet true vertical 3,749 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' Surface 2,936' 9-5/8" 2,936' 2,529' 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,828' 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' 4,050' 8,430psi 7,500psi Slotted Liner 2,098' 4-1/2" 8,235' 4,046' N/A N/A Perforation depth Measured depth See Attached Schematic feet SCANNED ,'UN 1 8 2015 True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 5,063' 3,675' 5,199'MD Packers and SSSV(type,measured and true vertical depth) ZXP Packer N/A 3,749'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 44 3 26 80 219 Subsequent to operation: 81 2 83 240 232 14.Attachments(required per 20 AAC 25 070,25 071,s 25 283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work. Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 315-162 ✓ Contact Chris Kanyer Email ckanyer(c�hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature C.t Phone 777-8377 Date 6/3/2015 r Form 10-404 Revised 5/2015 i 6 iO' . , Su it Original Only 6�� RBDM� JUN - 4 2015 Milne Point Unit Well: MPU J-09A 14 SCHEMATIC Last Completed: 4/29/2015 Hhlcorp Alaska,LLC PTD: 199-114 CASING DETAIL KBEIev.:29.6'/GLEIev.:17.0 Size Type Wt/Grade/Conn ID Top Btm Js " ' 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' 4 E.i ' 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/g' w L + 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' ''1 1 4-1/2" Liner 12.6/L-80/IBT 3.958 5,199' 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' s, TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,063' JEWELRY DETAIL a No Depth Item 9-5/8'`l1 139' 2-7/8"x 1"Side Pocket KBMM w/DPSOV 2 4,853' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi Heat Trace@ 3 4,994' 2-7/8"XN Nipple(2.25"ID) 2,500' 4 5,006' WellLift Discharge Gauge Unit 5 5,009' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,033' Flex Shaft Assembly EUE 8rd Box 7 5,043 Single Seal Section 8 5,049' Gear Reduction Unit GRU 538B 11.57:1 9 5,051' Motor MSP1/54 HP,890 Volt,39 Amp 10 5,059' WellLift MGU w 6 fin Centralizer-Bottom @ 5,063' 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 16 8,235' 4.5"Baker Drillable Guide Shoe 2 WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=59 deg. @ 3,300-3,500' III 3 MaxHole Angle=Horizontal 5 OPEN HOLE/CEMENT DETAIL 6 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 1,1 7 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 8 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole ma, i s TREE&WELLHEAD 1„, 10 Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT threads top and bottom and 3"CIW H PBV Profile 11 GENERAL WELL INFO 4.5"Bonzai Completion; P API:50-029-22495-01-00 w'Horiz.Slotted Liner � 12 Drilled and Cased by Nabors 222/1E5/-119/9145/1995 ;A Completion by Nabors 4E5- 7" ., Schrader Bluff Recompletion by Nabors 4E5-4/19/1997 A ';13 Schrader Bluff Sand Test#2-8/15/1997 1a Sidetracked By Nordic 3-12/15/1999 willed 6-1/8"Wndow@ 5,334'to 5,346'(17) I j RWO by Nabors 4ES-1/24/2000 US RWO by Nabors 4E5-12/11/2003 I I ESP RWO by Nabors 35-6/16/2008 Clean-out to7,075 RWO PCP Pump by Doyon 16-4/13/2013 an 4/28/2015 ESP Change-out by Nordic 3-4/29/2015 i 4-1/2„ ' ''', 15 16 TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) Revised By:TDF 3/23/2014 Hilcorp Alaska, LLC HIeor')Alaska,IAA: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP J-09A 50-029-22495-01-00 199-114 4/26/2015 4/30/2015 4/26/15-Sunday MIRU.Spot tanks, berm cellar MU hardline to kill tanks. Pull BPV,tested lines to 3,000psi-test ok,filled pits with 2 loads of 120deg seawater.SITP 240psi,SICP 240psi, bled csg/tgb down to Opsi,started pumping hot seawater, rev cir @ 3bpm and broke cir at 25 bbbls. Increased rate to 4 bpm, continued circulate kill fliud,with returns clean,SD pump-well on static. 272 bbls pumped, 246 bbls returned, 26 bbls lost.Set BPV and ND tree, NU BOP's and connected lines.Tried pulling BPV and well had pressure.Opened casing with a slight blow. Lined up manifold started pump,circulate 1 well volume casing/tubing slight blow.SI casing and bullhead down tubing, catch 1,800psi after 4 bbls pumped. Bled off to Opsi. Opened casing to kill tank, pulled BPV/installed TWC. Filled BOP stack and performed shell test(250psi-3,000psi). Tested BOPE per sundry,annular 250psi low/2,500psi high, rams 250psi low/3,000psi high,valves 250psi low/3,000psi high, performed kommey drawdown and gas dection. No failures recorded. 4/27/15-Monday Preped rig floor to TOH w/completion,opened casing pulled TWC and backed out lockdown pins.MU Landing jt, pulled 85k unseat hanger, pulled hanger to rig floor, meg. cable,good decompleted hanger and L/D same. PU stand and hang cables over sheave to spooler.TOH w/completion,tallied tbg out, L/D 24 jts indentifed as bad on PDS caliper log plus 6 more with bad pin ends and tong markes,GLV's,xn-nipple and ESP assembly, packed sand small flakes of scale around the pump and intake. Cleaned and cleared rig floor, RD riser NU stripped head and preped to trip cleanout string. PU/MU 2-3/8" mule shoe.TIH w/101 jts of 5.8#2-3/8" PH6 xo 6.5#2-7/8" EUE 8rd,5,000' at report time. 4/28/15 Tuesday Continued TIH w/cleanout string,Tag hard @ 5199', PU 10', up weight 65k,down weight 55k. MU wash stand.Started pumping reverse circulate, broke circulation and washed down returns, heavy sand,tag hard @ 5,275'washed thru scale/sand bridge and continued washing down with heavy sand returns to top of slotted liner @ 6135'. Pumping 4bpm 1,300psi,total losses est 190 bbl. Immediate pump pressure 140 psi. RIH with 2 stands full reciprocation, check drag, continue RIH with all pipe in derrick to 7,075'. Install dart bottom jt 3. RU to pump N2 and surfactant.Witness all valves lined up for displacement of N2 to kill tank. Pressue test all lines 250psi low/2,500psi high. Problems with leaking valves on cement manifold.Grease and service same, PT OK. Pump 25 bbl Baraklean surfactant pill and chase with 10 bbls saltwater.Close annular BOP. Initiate pumping N2 500 SCFM ICP 850psi,appeared to catch fluid after 45,000 SCF pressure increase to 1,350 psi, bump rate to 1000 SCFM pressure 1,500psi increase to 1500 SCFM pressure 1,580psi.After 100,000 SCF still no returns continue pumping drop rate to 1,000 SCFM pressure maintaining 1,500psi continue pumping to 155,000 SCFM (note total hole volume should be approx 240,000) still no returns. Discuss with engineering. Decison to stop pumping N2 205,000 SCF gone no returns. Discussed ESP recovery with vendor, it was noted that tandem seals from recovered ESP assy were bone dry, rest of assembly was sand packed. RD N2 equipment,annulus beginning to unload clean fluid and N2 tbg pressure at 1,300psi,flowing anuulus pressure surging 2-300psi est. Pump tubing volume,tubing on vacuum,annulus still unloading.Continue to flow back annulus and monitor well is flowing slugs of crude and intermittent N2,some saltwater. 154 bbls recovered"'50%oil.Well appears dead.Spot A frame w/crane on rig floor for heat trace ESP run while blowing down well.Check pressure on annulus 0 psi.Tubing has check valve.Open annular BOP, pull 1 stand bleed off check on tubing,0 psi. Pump 180 bbl 8.6#saltwater down annulus, partial returns after 60 bbls. Pump 40 bbls down tubing, intermittent returns again, monitor well 15 minutes.Well is static light vacuum.Trip BOP drill, rig up to trip, latch on to first stand, pipe stuck no up no down.Work pipe no room to go down. PU single rig up to circulate down annulus pump 2-3 BPM.Work pipe 20K over, no movement,circulation intermittent after 17 bbls pumped. Flip circulation over, MU top drive,circulate down tubing 4 BPM,work 20-25K over, pipe is free. reciprocate pipe during circulation, 1 bottoms up with—50 bbl losses and crude in partial returns. POOH w/ 2-7/8"tbg racking back in derrick. 4/29/15,-Wednesday POOH and rack 42 stands 2-7/8" L-80 production string. Monitor well, POOH LD 2-3/8"workstring and M/S BHA.Offload 2-3/8" PH6 C/O string,on load Centrilift gear, GLMs, ND stripping head NU riser/bellNipple.Assemble and service PCP ESP assembly PJ and X-Nipple(ID=2.313),string cable and cap over sheaves, hook up ESP connection and 3/8"stainless cap w/Check.Test @ 900 psi. PU RIH tbg,shear valve GLM continued TIH w/ESP completion testing cable and cap check every 2,000'. Cap check was 1,100psi. 2,525'from surface,string heat trace through sheave,attach/clamp heat trace. Continue RIH time per stand for HT and ESP clamps is 25 minutes. Install upper orifice GLM and final tbg.At report time still 3 stands in derrick and new replacement singles to PU. 4/30/15-Thursday Continue RIH w/ESP/cap/HT. PU landing joint. Install hanger and penetrators.Test cables,cap string,and heat trace.Cut and splice cable connectors and cap string, install same. Meg check connector.Test heat trace connector. Land string SW 80K up 72K dn. Depths as follow: Hanger, Pup,3 jts 2-7/8" L-80 6.5#tbg, pup,GLM @ 139', 150 jts tbg, pup GLM @ 4,853',4 jts tbg,XN-Nipple @ 4,994', pup. Head @ 5,005', Pump/Flex Shaft @5,010, EOT Centralizer @ 5,063'. Run in lock down screws. ND BOPE. NU tree.Test all breaks and void 250/5,000 psi. Release Rig. of \��\ 7- HE STATE Alaska Oil and Gas �� 9 T • ' �---� Of ALASKA Conservation Commission _,= — 333 West Seventh Avenue 0 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1433 pp, ALAS*P- Fax 907 276.7542 www.aogcc.alaska.gov Chris Kanyer Operations Engineer 1 qal ( 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-09A Sundry Number: 315-162 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy P. roerster Chair DATED this e.A.D day of March, 2015 Encl. . RECEIVED STATE OF ALASKA MAR2 3 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 3AO CC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 2 - Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate❑= Pull Tubing❑✓ - Time Extension ❑a Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Atter Casing 0 Other. ESP Changeout Q• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development Q * 199-114 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22495-01-00 , 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477- Will planned perforations require a spacing exception? Yes ❑ No O / MILNE PT UNIT SB J-09A . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 • Milne Point Field/Schrader Bluff Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured). 8,235 • 4,046 . 8,235 • 4,046 - N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' 1,730psi 740psi Surface 2,936' 9-5/8" 2,936' 2,529' 5,750psi 3,090psi Production 5,334' 7" 5,334' 3,828' 7,240psi 5,410psi Liner 938' 4-1/2" 6,137' 4,060' 8,430psi 7,500psi Slotted Liner 2,098' 4-1/2" 8,235' 4,060' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5*/L-80/EUE 8rd 5,083' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker ZXP Liner Top Packer and N/A •5,199'(MD)/3,749'(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development❑✓ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/1/2015 Oil Q • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ 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 Chris Kanyer Email ckanyer(a�hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature a 7/6., Phone 777-8377 Date 3/23/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . \L-01.-- Plug Integrity ❑ BOP Test d Mechanical Integrity Test ❑ Location Clearance ❑ Other: - .?000 Pyr, i.JV i I C MA-s-1° = 41‘•/.1 Spacing Exception Required? Yes ❑ No Li/ Subsequent Form Required: / 6 --9 OL( f/�� ,/,' APPROVED BY _ / Approved by: / L- 4kL COMMISSIONER THE COMMISSION Date: 3 ,2,5--/S- 7/- � ,S 7/' 3-2 '-is&Rai A I '�zit's40,44 . Submit Form and Form 10-403(Revised 10/2012) 6iiNiAl14 fLor 12 months from the date of approval. Attachme in Duplicate .3-zS-14 RBDMS APR - 3 2015 Well Prognosis Well: MPJ-09A Hilcorp Alaska,LL, Date:3/23/2015 Well Name: MPJ-09A API Number: 50-029-22495-01-00 Current Status: SI Producer Pad: J Pad Estimated Start Date: April 1, 2015 Rig: Nordic 3 Reg.Approval Req'd? March 31, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-114 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907)250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907)727-9247 (M) AFE Number: 1550677 Current Bottom Hole Pressure: — 1,475 psi @ 4,000' TVD (Last BHP measured 3/3/2015) Maximum Expected BHP: — 1,475 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surface Pressure: 46 psi (Based on actual reservoir conditions and water cut of 33% (0.366psi/ft)with an added safety factor of 1000'TVD of oil cap) D (c-- Brief Well Summary: The Milne Point J-09A well was redrilled as a Schrader Bluff development well that TD'd at 8,235' and ran 4.5" slotted liner into open hole in December 1999. The well was initially completed with a through tubing ESPCP (Electrical Submersible Progressive Cavity Pump), but failed immediately upon install.This was replaced with an ESP in January 2000.This failed and subsequent ESPs were replaced in 2003 and 2008.The traditional ESP was replaced with a ESPCP in 2013.This recent pump failed February 9, 2015.The last 7"casing test was performed to 2,000psi on 4/2/2013. 1/ c l`— There are minimal observed scale issues, most failures are related to solids production. No subsidence issues are expected in this well.A caliper was run on the upper 1,000'of 7" casing in April 2013. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issues suspected. RWO Objective: I Pull ESP, perform cleanout,& run 2-7/8" ESP completion. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure Well Prognosis Well: MPJ-09A Hilcorp Alaska,LL Date:3/23/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" ESPCP completion from 5,083'to surface and lay down same. 6. RIH with tapered cleanout BHA and circulate well clean to+/-8,200'. POOH with same. 7. MU and RIH with ESPCP with gas separator and +/-2,500'of heat trace on 2-7/8"8RD EUE L-80 tubing [to be replaced if necessary]. Set ESPCP at+/-5,083'. Land tubing hanger. 8. ND BOP, NU and tree. 9. RDMO workover rig and equipment. 10. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit . II Well: MPU J-09A SCHEMATIC Last Completed: 4/13/13 Hilcorp Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm 4 ' ' ` 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' 1; '' ; 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 133/8" ! 7" Intermediate 26/L-80/NSCC 6.276 0 5,334' i i 4-1/2" Liner 12.6/L-80/IBT _ 3.958 5,199" , 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' Y TUBING DETAIL ; !, 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 5,083' JEWELRY DETAIL 44 r No Depth Item 95/8"`4 1 133' 2-7/8"x 1"Side Pocket KBMM w/DPSOV 2 4,846' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi Heat Trace@ 3 4,985' 2-7/8"XN Nipple(2.25"ID) 3,365 4 5,027' WellLift Discharge Gauge Unit 5 5,030' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 5,053' Flex Shaft Assembly EUE 8rd Box 7 5,062' Single Seal Section 8 5,068' Gear Reduction Unit GRU 538B 11.57:1 9 5,070' Motor MSP1/54 HP,890 Volt,39 Amp 10 5,079' WellLift MGU w 6 fin Centralizer-Bottom @ 5,083' 11 5,199' • Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 _ 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP ir- 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 16 8,235' 4.5"Baker Drillable Guide Shoe 2 WELL INCLINATION DETAIL KOP @ 600' A Max Hole Angle=59 deg. @ 3,300-3,500' U: 3 MaxHole Angle=Horizontal 4 11 5 OPEN HOLE/CEMENT DETAIL 6 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 7 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/400 sx Class"G"in 8-1/2"Hole ti 8 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole az 9 TREE&WELLHEAD NW 10 Tree Cameron 2-9/16"5M Wellhead WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT threads top and bottom and 3"CIW H PBV Profile 11 GENERAL WELL INFO 4.5'Bonzai Completion ii - API:50-029-22495-01-00 IN Honz Sidled Liner `' Drilled and Cased by Nabors 22E -1/14/1995 .. 12 Completion by Nabors 4ES-2/15/1995 7" iiEi Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 13 Schrader Bluff Sand Test#2-8/15/1997 4 A 14 !tilled 61/8"window@ Sidetracked By Nordic 3-12/15/1999 5,334'to 5,345(17) RWO by Nabors 4ES-1/24/2000 RWO by Nabors 4ES-12/11/2003 ESP RWO by Nabors 35-6/16/2008 RWO PCP Pump by Doyon 16-4/13/2013 4-1/7' 15 16 TD=8,235'(MD)/TD=4,064'(TVD) PBTD=8,235'(MD)/PBTD=4,064'(TVD) - Revised By:TDF 3/23/2014 Milne Point Unit Well: MPU J-09A PROPOSED Last Completed: 4/13/13 Ililcorp Alaska,LLC PTD: 199-114 CASING DETAIL KB Elev.:29.6'/GL Elev.:17.0' Size Type Wt/Grade/Conn ID Top Btm ` 13-3/8" Conductor 54.5/H-40/N/A 12.615 0 112' 14 ?`(; P,' 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,936' 13-3/8" 7" Intermediate _ 26/L-80/NSCC 6.276 _ 0 5,334' '� 1 ; 4- 1/2" Liner 12.6/L-80/IBT 3.958 5,199" 6,137' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 6,137' 8,235' TUBING DETAIL ); .: 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 ±5,083' 1 ;1 JEWELRY DETAIL .. " No Depth Item 9-5/8"'is • 1 ±133' 2-7/8"x 1"Side Pocket KBMM w/DPSOV / 2 ±4,846' 2-7/8"x 1"Side Pocket KBMM Shear Valve set @ 2,000psi Heat Trace@ 3 ±4,985' 2-7/8"XN Nipple(2.25"ID) , ' 4 _ ±5,027' WeIILift Discharge Gauge Unit 5 ±5,030' ZCentrilift ESP:PCP 200D 2600 Pump 3.75"/22.42' 6 _ ±5,053' Flex Shaft Assembly EUE 8rd Box 7 ±5,062' Single Seal Section 8 ±5,068' Gear Reduction Unit GRU 538B 11.57:1 9 ±5,070' Motor MSP1/54 HP,890 Volt,39 Amp 10 ±5,079' WeIILift MGU w 6 fin Centralizer-Bottom @±5,083' 11 5,199' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 _ 5,215' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 _ 6,013' Baker HMCV Cement Valve 14 6,032' Baker CTC 20'PZP ECP 15 8,190' 4.5"Baker Drillable Pack-Off Bushing 16 8,235' 4.5"Baker Drillable Guide Shoe 2 WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=59 deg. @ 3,300-3,500' I 3 MaxHole Angle=Horizontal 4 OPEN HOLE/CEMENT DETAIL 5 6P 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 7 �� 9-5/8" Cmt w/572sx PF"E",250 sx Class"G"in 12-1/4"Hole as 7" Cmt w/400 sx Class"G"in 8-1/2"Hole 8 4-1/2" Cmt w/97 sks Class"G"in 6-1/8"Hole IIIIV 9 TREE&WELLHEAD 10 Tree Cameron 2-9/16"5M WKM 11"x 11"5M,WKM w/11"x 2-7/8"tubing hanger/NSCT Wellhead threads top and bottom and 3"CIW H PBV Profile 11 GENERAL WELL INFO 4.5'Bonzai Completion;; API:50-029-22495-01-00 vie Horiz.Slotted Liner `' iii Drilled and Cased by Nabors 22E -1/14/1995 12 lii iii] Completion by Nabors 4E5-2/15/1995 7" ii Schrader Bluff Recompletion by Nabors 4E5-4/19/1997 iiii `.':13 Schrader Bluff Sand Test#2-8/15/1997 A 4 14 Sidetracked By Nordic 3-12/15/1999 5,334 to 6' IIIIIII RWO by Nabors 4E5-1/24/2000 5,334'to 5,346'(12) RWO by Nabors 4ES-12/11/2003 MN; -2..,- (4614-(AJ IIIIII' r4614-(AJ 2008 RWO CP Pump by Doyon 16 6/16/4/ 13/2013 IIIIIII (IIIIIII 4-1/2" IIIIIII! 1;6 1D.8,235'(IVO)/TD=4,064'(1VD) PBTD=8,235'(MD)/PBTD=4,064'(1VD) Revised By:TDF 3/23/2014 11" BOP Stack r � O O i1I i Hydril 11" 5M MM. Shaffer 2 7/8-5.5 = variables _) 11" SM Blinds *1(till t .111 [1111:11-1711111,1:1111 11"5M STATE OF ALASKA l~ZS-09 j ALAS OIL AND GAS CONSERVATION COMM~ION ~~~~ '~ 4 200 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate Q' r A ENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver[ Time Ext~g Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~ 1991~114Q 3. Address: P.O. Box 196612 Stratigraphic Service ~~~ 6. API Number: Anchorage, AK 99519-6612 50-029-22495-01-00 7. KB Elevation (ft): 9. Well Name and Number: 65.32 KB _ MPJ-09A - 8. Property Designation: 10. Field/Pool(s): ADLO-025517 - MILNE POINT Field/ SCHRADER BLFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 8235 - feet Plugs (measured) None true vertical 4045.59 - feet Junk (measured) None Effective Depth measured 8190 feet true vertical 4044.58 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.1# H-40 SURFACE - 112 SURFACE - 112 1490 470 Surface 2905 9-5/8" 40# L-80 SURFACE - 2936 SURFACE - 2529 5750 3090 Production 5305 7' 26# L-80 SURFACE - 5334 SURFACE - 3828 7240 5410 Liner 3020 4-1/2" 12.6# L-80 5215 - 8235 3758 - 4046 8430 7500 Perforation depth: Measured depth: SL 6137' - 8190' _ _ _ True Vertical depth: SL 4050' - 4045' _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 5091' 0 0 - Packers and SSSV (type and measured depth) BAKER ZXP LINER TOP PACKER 5199' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ '~ ' ~ ~ ~~? ~ ~- ~~~% Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 318 157 45 343 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pr ble Title Data Management Engineer Signature Phone 564-4944 Date 3/23/2009 Form 10-404~evised 04/2006 ~ ~ ~ ; ~ ~'~ ~~~ ~ `,~-.~ `~ ~~ bmit Original Only MPJ-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/9/2009 CTU #5 w/1.75" Coil Job Scope: FCO/ESP Acid Wash «InterAct Publishing ~» Arrive on location (Drifted in) Heavy equipment removing snow. MIRU CTU I ...Coat job on 3/10/2009... ~ 3/10/2009', CTU #5 w/1.75" Coil Job Scope: FCO/ESP Acid Wash «InterAct Publishing » ...Continue job from 3/9/2009... continue with rig up and perform weekly BOPE testing. RIH w. 2" JDN and washed top of ESP. Spotted 12 bbls of 10° HCL DAD Acid and let soak for one hour then attempted to squeeze through 'ESP holding 2500 psi, Turned pump on at various speeds forward and backward attempting to shear solids. Pump was giving indication at power skid Ithat it was spinning freely . No indication at surface of it trying to lift. BHP 'staying constant no signs of life. Gave it the ole "Bixby bump" several times at vering speeds. Called town APE and discussed. Flush 10% HCL DAD to surface and neutralize. Left diesel in hole w. 2 bbls 60/40 on top. RD CTU leaving well S/I ***Job Complete*** FLUIDS PUMPED BBLS 13 60/40 METH 63 DIESEL 90 2% KCL 12 10% HCL DAD ACID .BLEND 178 Total STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ,I~1_ R ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ;,, Q Re-Enter Suspen~e~Well ~t :<~.;n~ ,r 3r ~ r, . .o '6.+~. e f ~ ^ Alter Casing ®Pull Tubing ~ , . ^ Perforate New Pool ^ Waiver ®Other ~ (~;, ~~. Chang~t3~ft ASP -, ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 199-114 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22495-01-00 7. KB Elevation (ft): KBE = 63.25' 9• Well Name and Number: MPJ-09A 8. Property Designation: 10. Field /Pool(s): ADL 025517 Milne Point Unit / Schrader Bluff - 11. Present well condition summary Total depth: measured 8235 feet true vertical 4046 ~ feet Plugs (measured) N/A Effective depth: measured 8235 feet Junk (measured) N/A true vertical 4046 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 112' 112' 2730 1130 Surface 2905' 9-5/8" 2936' 2529' 5750 3090 Intermediate Production 5305' 7" 5334' 3828' 7240 5410 Liner 3020' 4-1/2" 5215' - 8235' 3758' - 4046' ~~N AllG ~ ~ ~0~8 Perforation Depth MD (ft): 6137' - 8190' Slotted Liner Perforation Depth TVD (ft): 4050' - 4045' Slotted Liner 2-7/8", 6.5# L-80 5091' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker ZXP Liner top packer 5199' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nick Frazier, 564-5633 NIA Printed Name Sondra Stewman Title Technical Assistant Prepared By Name/Number: ~~'~ ~~ ~~ ~ Sig ature Date Phone ' Sondra S 564-4750 Form 10-404 Revised 04/2006 ~ pCl_ ~~G ~ ~ Z~O~ r~i"- tewman, }~~- Submit Original OnIyF4~" ~3 ~~ 7• /8 DS' Tree:2-9/16", 5M Wellhead: WKM 11" x 11" 5M, WKM w/ 11" x 2 7/8" tbg. hnr. w/ NSCT threads top and bottom and 3" CIW H BPV profile 20" 91.1 ppf, H-40 115' 9 5/8", 40 ppf, L-80 Btrc. 2,936' KOP C~3 600' Max angle in tubing 59° @3300-3500` Max. hole angle =Horizontal MPJ-09a 2-7/8" 6.5# L-80 EUE 8rd tubing (drift ID = 2.347", cap. = 0.0058 bpf ) 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) 4.5" Bonzai completion I n(~ w/ Horizontal slotted liner. ~U Stimulation Summary Milled 6-1/8" window at 5334'-5346' (12') DATE I REV. BY I COMMENTS Oai75/97 M.Linder Schrader Bluft sand test #2 12/15/99 M.Linder Sidetracked by Nordic 3 1/24/00 M.Linder RWO Nabors 4ES 12-11-03 Lee Hulme RWO Nabors 4ES 06-16-08 REH ESP RWO -Nabors 3S Orig. KB Elev. = 46.6' (N 22E} Orig. GL Elev. = 17.0 ' RT To Tbg. Spool = 28.8' (N 22E 2-7/8" x 1" KBMM GLM 141' Centrilift heat trace 3365' 2-7/8" x 1" KBMM GLM 4854' 2-7/8" XN nipple 2.25" ID 4993' Centrilift ESP: 5040' 160 P11 Coated STG Pump Centrilift GasMaster (coated) 5057' Tandem Seal Section .51 06~ Centrilift KMH series 5076' 114 hp. motor, 2330v/30amp Re-rated to KMH-A 83 hp 2159v/23amp Centrilift Pumpmate XTO 5087' 6 Fin Motor centrilizer 5089' Baker ZXP Liner top packer " ' 5199' tie back (5.25 ID) wJ6 Baker 5"x7" HMC liner 5215' hanger (4.375" ID) 6013' Baker HMCV cement valve Baker CTC 20' PZP ECP 6032' 22 jts of 4.5", 12.6# L-801ST Solid liner. 50 jts of 4.5" 12.6#, L-80 I BT Slotted liner from 6137'-8190' 4.5" Baker drillable pack off bushing 8190' 4.5" Baker drillable guide shoe 8235' MILNE POINT UNIT WELL J-09a API NO: 50-029-22495-01 BP EXPLORATION (AK) / • • Well History Well Date Summary WPJ-09A 4/20/2008 Freeze F-otect (Fbst Fas) - R.irrped down IA w/40 bbls 50*F diesel, Rirrped dow n tbg w/35 bbls 50*F diesel. Fag on well. NPJ-09A 4/22/2008 CTLH#5 (scope; fill cleanout w/ N2) Fag up .pull BF'~/. job in progress*"* NPJ-09A 4/22/2008 CTlJlt5 Job Scope: Nitrified FII Clean Out. «InterAct PUblishing» IWRU 1.75" CT RIH w. 2" JSN ...Continue job on 4/23/2008... NPJ-09A 4/22/2008 **` WELL SI ON ARRIVAL'""` ««< PULL® BACK PRESSURE VALVE »»> NPJ-09A 4/22/2008 CTUI#5 (scope; fill cleanout w/ N2) Fag up .pull BPS/. * job in progress**" NPJ-09A 4/22/2008 Continue job from 4/22/2008 CTU #5 Job Scope: Nitrified FII Clean Out. «InterAct FUblishing» RIH w . 2" JSN NPJ-09A 4/22/2008 Continue job from 4/22/2008 CTU #5 Job Scope: Nfitrified Fill Clean Out. «InterAct PUblishing» RIH w. 2" JSN WPJ-09A 4/23/2008 Continue job from 4/22/2008 CTU #5 Job Scope: Nitrified FII Clean Out. «InterAct FUblishing» RIH w . 2" JSN Tag fill @ 6152' CTM broke through three bridges and continued cleaning liner getting more a c w eiq fy ~ggrPCS ive ...Job in progress... NPJ-09A 4/23/2008 Continue job from 4/22/2008 CTU #5 Job Scope: Nitrified FII Bean Out. «InterAct PUblishing» RIH w. 2" JSN. Cleaned out from6152 to 8203. (hard btm). **"job in progress*** NPJ-09A 4/23/2008 Continue job from 4/22/2008 CTU #5 Job Scope: Nitrified FII Clean Out. «InterAct PUblishing» RIH w. 2" JSN Tag fill @ 6152' CTM, PUH and started lifting well from2000' Once returns were established ran in hole w ith fluid pump rate of 1.2 bprr>!N2 pump rate of 500 scf tagged fill (il 6152' and started clean out. Broke through 3 bridges between initial starting point and 6220' continued cleaning liner till hard Freeze protected w orkstring to 2500' RD bottom w as tagged at 8203' CTM POOH ~ 60% through liner. . CTU and left well S/I Next up: well ready for workstring to be pulled and new corrpletion to be run **"Job Conplete*** NPJ-09A 5/11/2008 Well Support Techs rigged up and set a BP/ for upcorring RWO. NOTE BFV w as left IN and w ell is ready for RWO NPJ-09A 6/15/2008 ***SURFACE WORK NIABORS 3S*** SET 1" BB<l7PSOV IN SPM TO BE RUN ON TOP (MAFa<® AND FLAGGED) VERIFI® 1" BK DGLV IN SPM TO BE RUN ON BOTTOM "'"'JOB COMPLETE*** NPJ-09A 6/19/2008 (Freeze R-otect w ell) T/VO = 0/0/0 FUrrp 15 bbls dead crude dow n TBG follow ed by 65 bbls dead crude down TBG to freeze protect well . FWHI} 0/0/0 NPJ-09A 7/7/2008 The Well Support Techs rigged up and changed out the w ing valve and the swab valve. They then rigged up and leak tested the tree to 5000 psi and the flow lines to 1150 psi. The back pressrue valve w as then pulled. NOTE The leak tests w ere all GOOD and the BFV w as left OUT. Print Date: 7/17/2008 Page 1 of 1 • • BP Exploration Operations Summary Report Page 1 of 5 ~ Legal Well Name: MPJ-09 Common Well Name: MPJ-09A Spud Date: 7/28/1994 Event Name: WORKOVER Start: 4/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/20/2008 Rig Name: NABOBS 3S Rig Number: D F T H T k NPT C ' Ph D ti f O ti i ate rom - o ours as ode , ase on o pera ons escr p 4/16/2008 06:00 - 00:00 18.00 __! MOB _ I P __ ~ PRE Wait on M PU to prep MPF-94. At 14:00 hours, decision made 14/17/2008 100:00 - 06:00 I 6.00 i MOB ~ P 06:00 - 08:00 2.00 MOB P 08:00 - 09:30 1.50 MOB P 09:30 - 11:30 2.00 MOB P 11:30 - 13:30 2.00 MOB P 13:30 - 16:00 2.50 MOB P 16:00 - 17:00 1.00 MOB P 17:00 - 20:00 3.00 KILL P 20:00 - 21:00 1.00 KILL P to move to MPJ-09. Call for Trucks to move rig, rig maintenance and prep for rig move. Inspect tires on rig. C/O fire on carrier. No trucks available due to multiple rig moves in process. At 16:30 notified AOGCC of upcoming BOPE test. State's right to witness was waived by John Crisp. PRE Perform general rig maintenance, Prep around MPJ-09A for upcoming rig move. Smooth out hump behind wellhead. Still waiting on trucks due to ongoing rig moves. PRE Trucks depart PEAK Base in Deadhorse. Blow down all steam lines. Scope down and lower derrick. PRE Begin moving rig components from MPJ-24. Jack down Carrier and move around corner. PRE Spot BOP Stack behind MPJ-09A. Line up Carrier with well. Lay herculite and spot Carrier over Well MPJ-09A. PRE Jack up and level Carrier. Spot Pipeshed and Pits. PRE Raise and scope Mast. Pull and hook up electrical lines. Hook up steam and water lines, put steam around rig. PRE Berm rig, R/U floor, install handrails and walkways. Spot cuttings tank, boiler blowdown tank, and change room. *** Ri9 Acce fed at 17:00 Hour *** DECOMP Install secondary annulus valve on the IA. R/U lines to the well and the Tiger Tank. Test Pump lines to 2,500 psi and the hardline to the Tiger Tank to 500 psi. DECOMP R/U Well Tech Lubricator and test to 500 psi. Pull 2-1/2" Type 21:00 - 00:00 3.00 KILL P DECOMP Pump 30 bbls of 140 degree seawater down tubing taking returns up the IA through the choke to the Tiger Tank. 4 bpm at 80 psi. Shut return line in and Bullhead down the tubing. Caught fluid with 50 bbls total fluid pumped. With 31 bbls away pressured up to 1,850 psi. Shut down and monitor pressure. Bled down to 1,450 psi in 10 minutes. Open up and pump the long way at 4 bpm with 780 psi. Fluid cleaning up with 150 bbls pumped. Pump 210 bbls good seawater returns. 4/18/2008 00:00 - 00:30 0.50 KILL P DECOMP Monitor well for 30 minutes, 0 psi on tubing and 0 psi on IA. 00:30 - 01:30 1.00 WHSUR P DECOMP FMC Wellhead Tech installed 2-1/2" T e H TWC. Test to 1,000 si from below for 10 minutes and 3,500 si from above fo_r 10 minutes. Chart both tests. 01:30 - 03:30 2.00 WHSUR P DECOMP N/D and remove tree. Inspect hanger threads(2-7/8" EUE 8rd in good condition). Function lockdown screws. 03:30 - 06:00 2.50 BOPSU P DECOMP N/U DSA. Stand up BOP stack and remove from cradle. Stab BOP stack onto DSA. Install Choke and Kill lines. Install Koomey lines. 06:00 - 07:30 1.50 BOPSU P DECOMP Function test BOPE components. Prep for BOPE testing. 07:30 - 13:00 5.50 BOPSU P DECOMP BOPE test to 250 si low 3500 si hi h. Test annular to 3500 psi. Use 2 7/8" and 4 1/2" test joints. Perform Koomey draw down test. Rig down test equipment and drain stack. 13:00 - 15:00 2.00 WHSUR N DECOMP Prep for pulling completion. Install Opso-Lopso in tubing hanger. MU nipple and to-torq valve. Hang double shieve and elephant trunk. Wait on WS techs to pull TWC. (They were on Doyon 14 pulling BPV) 15:00 - 16:30 1.50 WHSUR N DECOMP PUMU lubricator with polish rod and Type H pulling tool. MU to Opso-Lopso. Pressure test to 500 psi. Enaaae TWC and pull, Printed: 7/17/2008 71:52:37 AM • • BP Exploration Operations Summary Report Page 2 of 5 ~ !Legal Well 'Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To MPJ-09 MPJ-09A WORKO NABOB NABOB Hours VER S ALAS S 3S Task A DRI !Code LING NPT Start I Rig Rig ' Phase Spud Date: 7/28/1994 : 4/16/2008 End: Release: 4/20/2008 Number: Description of Operations 4/18/2008 15:00 - 16:30 1.50 WHSUR N DECOMP into OL. 0 psi on tubing, IA static. BOLD lubricator, polish rod, and OL. 16:30 - 17:30 1.00 PULL N DECOMP PUMU 2 7/8" landing joint w/ TIW valve and head pin installed. Screw into hanger w/ 9 turns. BOLDS. IA static. Pull hanger into BOPE below annular. Load hole w/ 5 1/2 Bbls SW. Tubing and IA static. Check ESP cable (3.4 gig balanced / infinite phase to ground), Heat Trace cable (3.6 ohm balanced / infinite phase to ground) 17:30 - 18:00 0.50 PULL N DECOMP Cut ESP /Heat Trace cables. BOLD tubing hanger. 18:00 - 18:30 0.50 PULL N DECOMP Service Rig. 18:30 - 20:00 1.50 PULL N DECOMP Run ropes over sheaves and through containment hose. Pull ESP and Heat Trace cables over sheave and secure to spools. 20:00 - 00:00 4.00 PULL N DECOMP POOH with ESP Completion with Heat Trace laying down 2-7/8" EUE 8 rd tubin . An air chisel is being ultilized to cut metal bands on the Heat Trace flat guards. 45 joints laid down at 24:00 hours. Maintaining continuous hole fill. 4/19/2008 00:00 - 04:00 4.00 PULL P DECOMP Continue to POOH with ESP Completion with Heat Trace laying down 2-7/8" EUE 8 rd tubing. An air chisel is being ultilized to cut metal bands on the Heat Trace flat guards. 80 joints laid down at 03:00 hours 99 joints laid down at 04:00 hours. Heat Trace ended at joint 99. Using continuous hole fill. 04:00 - 05:00 1.00 PULL P DECOMP R/D Heat trace handling equipment and clear rig floor. Run end of Heat Trace cable over sheave and tie off on spool. 05:00 - 07:30 2.50 PULL P DECOMP POOH with ESP Completion laying down 2-7/8" tubing. Maintain continuous hole fill. Recovered: Flatguards - 483 ea 6' / 18 ea 4' / 11 ea 3' - 1527 steel bands - 35 LaSalle clamps - 5 protectolators - 3 armster guards. 07:30 - 11:00 3.50 PULL P DECOMP BOLD ESP. No sign of fill in oumo. Final checks on ESP moter: 2.0 ohms balanced (phase to phase) / 30 K ohms phase to ground. 11:00 - 12:00 1.00 BUNCO P RUNCMP C & C Rig floor. Remove double shieve and elephant trunk from derrick. 12:00 - 15:00 3.00 BUNCO P RUNCMP Remove all 2 7/8" tubing and jewelry from pipe shed. Prep for running 4 1/2" workstring. Remove 2 9/16" tree from cellar, place 4 1/16" tree in cellar. Load remaining 4 1/2" tubing in pipe shed. 15:00 - 20:30 5.50 BUNCO P RUNCMP O en blind rams. Fill hole w/ 6 Bbls of SW. PUMU 4 1/2" MS w/ pup joint, XN nipple (3.725" ID), XO pup. OAL - 22.33'. RIH on 114 jts of 4 1/2" 12.6#, 114, L-80 tubing - NSCT, 10.15' XO pup, and 11 jts of IBT-M to 5,170'. 20:30 - 22:00 1.50 BUNCO P RUNCMP R/U circulating head and hose on joint# 126. Circulate at 1 bpm with 40 psi Wash down and tao TOL at 5 200'. Uable to sting into liner. Work 1/4 turn into pipe. Will not go past liner top. Vary pump rate from no pump to 2 bpm and continue to work right hand turn into pipe 1/4 to 1/2 turn at at time. No icrease in pump pressure with setting down on TOL and no indication of washing down. Call and discuss with Well Engineer. Dec, i_sion made to s ace out -40' above TOL. 22:00 - 23:00 1.00 BUNCO RUNCMP B/O circulating head and hose. L/D Jt #126 and #125. 23:00 - 00:00 1.00 BUNCO P RUNCMP M/U FMC 11" x 4-1/2" tubing hanger and land workstring. Up weight 64K, Down weight 45K. Spaced out to land the WLEG at 5,159'. 4/20/2008 00:00 - 00:30 0.50 BUNCO P RUNCMP Run in Lock Down Screws. Lock downs were torqued to 450 Printed: 7/17/2008 11:52:37 AM • ~ BP Exploration Page 3 of 5 Operations Summary Report Legal Well Name: MPJ-09 Common Well Name: MPJ-09A Spud Date: 7/28/1994 Event Name: WORKOVER Start: 4/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/20/2008 Rig Name: NABOBS 3S Rig Number: ' ' Description of Operations Date 'From - To Hours ' Task Code NPT Phase 4/20/2008 00:00 - 00:30 0.50 BUNCO P RUNCMP ft/Ibs. 00:30 - 02:00 1.50 BUNCO P RUNCMP T-bar in 4" type H TWC with FMC Wellhead Tech, Test from below to 1,000 si. After 3 minutes ressure dro ed to 500 psi. Started in'ectin into formation at 1/2 b m with 1 000 si dro in to 70 si at 1/2 b m. Test to 3,500 psi from above for 10 minutes. Chart tests. 02:00 - 06:30 4.50 BOPSU P RUNCMP N/D BOPE. Blow down lines and drain BOP stack. Unhook Choke and Kill lines, Unhook Koomey lines and pull riser. Break bolts on stack and DSA. Lift BOP stack and lay over in cradle. 06:30 - 09:30 3.00 WHSUR P RUNCMP Crew Change. AAR of camp fire drill which was done on previous tour. NU 4 1/6" tree. Test hanger void to 5000 psi for 30 minutes. Test Tree and Tbg head adaptor to 5000 psi. 09:30 - 11:00 1.50 WHSUR P RUNCMP RU Tree for Freeze protect, RU LRS. Test LRS lines to 2500 psi. 11:00 - 12:30 1.50 WHSUR N RUNCMP Wait on BPV crew due to problems on Doyon 14. 12:30 - 14:00 1.50 WHSUR P RUNCMP BPV crew on location. PUMU lubricator. Tbg / IA on vacuum. Pump diesel for freeze protect: 40 Bbls down IA and 35 Bbls Tbg. Injection rate and pressure of 2 BPM, 500 psi. Lubricate BPV, 14:00 - 15:00 1.00 WHSUR P RUNCMP Normal up Tree and cellar. Ria released ~ 15:00 hrs. . 6/14/2008 14:00 - 19:30 5.50 MOB SURE Rig released from MPL-13 ~ 14:00 hrs. Prep for move to MPJ-09. 19:30 - 00:00 4.50 MOB SURE Peak trucks on location. Move pits and pipeshed. Pull carrier off of MPL-13. Move down MPL -Pad access road, right on Milne Point Main Road, right on Tract 14 road down to MPJ-Pad. 6/15/2008 00:00 - 01:00 1.00 MOB P SURE Stage equipment on location. 01:00 - 06:00 5.00 MOB P SURE Spot BOPE behind MPJ-09A, Lay mats and herculite around well. Line up carrier and back over well. BP WSL and BP Pad operator observed spotting of carrier. Jack and level carrier. Spot pipeshed and pits. 06:00 - 09:00 3.00 MOB P SURE Continue to hook up rig modules. Raise and scope derrick. 09:00 - 11:00 2.00 RIGU P DECOMP Accept Rig ~ 09:00; Rig up tree and cellar for well kill. Load pits with 140 deg F Seawater. Rig up flowback tank for kill. Test Hardline to Tiger tank to 500 psi, test to closed choke to 3500 psi. 11:00 - 17:00 6.00 WHSUR P DECOMP PU lubricator. Test lubricator to 500 psi. Pull BPV. WHP's: T / IA/ OA = 750 / 1050 / 0. Bleed IA and tubing to 570 psi, come on line pumping 4 BPM for 80 Bbls, no returns. Close choke and bullhead 100 Bbls ~ 870 psi. Open choke and attempt to circulate. Minimal retums with gas. Shut in and Bullhead 100 Bbls of SW. Flowcheck well. Tubing and IA w/ 30 - 40 psi. Circulate down tubing with returns from IA 100 Bbls with 80 Bbls returns. Flowcheck well, tubing and IA flowing with 0 psi. bottoms up 100 Bbls with 85 Bbls returns. Flowcheck C I rc u I ate.._.... . , ,~, ~.. ... . well Tubing and IA on vacuum. 365 Bbls lost to formation durin well kill. 17:00 - 18:00 1.00 WHSUR P DECOMP D rod TWC. Test from above to 3500 si. Chart for 10 minutes. 18:00 - 19:30 1.50 WHSUR P DECOMP N/D Tree. Inspect hanger threads and function lock down screws. 19:30 - 00:00 4.50 BOPSU P DECOMP N/U BOPE. Hook up choke, kill and koomey lines. Printed: 7/17/2008 11:52:37 AM • • BP Exploration Page 4 of 5 Operations Summary Report Legal Well Name: MPJ-09 Common Well Name: MPJ-09A Spud Date: 7/28/1994 Event Name: WORKOVER Start: 4/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/20/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task ! Code I NPT ~ Phase Description of Operations -- 6/16/2008 00:00 - 01:00 1.00 BOPSU P DECOMP Install turnbuckles, install flow nipple. 01:00 - 02:00 1.00 BOPSU P DECOMP Function test BOPE, Fill BOP Stack and Choke Manifold with water and purge air from system. 02:00 - 06:00 4.00 BOPSU P DECOMP Test ROPE to 250 psi low and 3,500 psi high pressures. Tested Blinds, VBR's, Annular Preventer, HCR Choke and Kill Valves, Manual Choke and Kill Valves, Choke Manifold Valves, TIW and Dart Floor Valves. Used 4-1/2" and 2-7/8" Test Joints. AOGCC witness of BOPE Test was waived by Bob Noble. Test was witnessed by BP WSL and Nabors Toolpusher. 06:00 - 07:00 1.00 BOPSU P DECOMP Perform Koomy draw down test. Rig down BOPE test equipment, drain stack 07:00 - 09:00 2.00 WHSUR P DECOMP PUMU Opso-Lopso. Drift and MU with proper torque, XO for hanger lifting threads. MU OL to hanger. PUMU lubricator w/ CIW type H pulling tool and polish rod. Test to 500 psi with Diesel. Pull TWC w/ 0 psi on Tbg / IA / OA. BOLD lubricator, polish rod, and Opso Lopso. 09:00 - 10:00 1.00 PULL P DECOMP PUMU landing joint. Torque XO to 4 1/2" NSCT XO for lifting threads. MU TIW valve. Screw into tubing hanger. BOLDS. ,Pull hanger to floor with 62.000 #'s PU weight. Pump 30 Bbls into IA. No returns. 10:00 - 11:00 1.00 PULL P DECOMP BOLD tubing hanger. Break out XO and TIW valve from landing joint. Lay down landing joint. Prep for pulling 4 1/2" workstring. 11:00 - 16:00 5.00 PULL P DECOMP POH la in down 4-1/2" work strip and 'ewel Maintainin hole fill ~ -30 Bbls er hour as POH 16:00 - 17:00 1.00 PULL P DECOMP Clean and clear rig floor of 4-1/2" handling equipment. RU floor for running ESP on 2-1/8" tubing completion. 17:00 - 19:00 2.00 BUNCO P RUNCMP Slip and cut 150' of drill line. Inspect drawworks and blocks. 19:00 - 20:00 1.00 BUNCO P RUNCMP Hang double sheave, R/U to P/U ESP. 20:00 - 00:00 4.00 BUNCO P RUNCMP M/U ESP and service pump as per Centrilift. Attach motor lead and check. P/U first joint on 2-7/8" tubing. Spooler operator noticed knot about 300'-400' on spool. L/D joint of 2-7/8" tubing and unhook motor lead. Run ESP cable back through sheave and remove knot from ESP cable. Run back through sheave and reattach to ESP. Check connection. Maintaining hole fill ~ -30 bbls/hr. 6/17/2008 00:00 - 02:30 2.50 BUNCO RUNCMP RIH to 1,703' with ESP completion picking up 2-7/8", 6.5#, L-80 EUE 8 rd tubin Using Best-O-Life 20 pipe ope, /U torque of 2,300 ft/Ibs. Maintaining hole fill ~ -30 bbls/hr. 02:30 - 06:00 3.50 BUNCO RUNCMP RIH with ESP completion and Heat Trace picking up 2-7/8", 6.5#, L-80, EUE 8 rd tubing. Using Best-O-Life 2000 pipe dope, M/U torque of 2,300 ft/Ibs. Maintaining hole fill ~ -30 bbls/hr. Started Heat Trace on the middle of joint #52. 06:00 - 00:00 18.00 BUNCO RUNCMP Continue RIH w/ ESP completion. With 74 jts in hole, ~ 08:45, hole fill at 25 Bbls/hr, returns possible. Hole full and stable. losses C~ 25 Bbl/hour . Centrilift tech checked the conductivity of ESP cable every -2000 ft while running in hole. Fill tubing and flush pump with 10 bbl seawater, 1.5 BPM at 1,050 psi, Total joints ran = 158, LaSalle clamps = 31, Protectolizers = 5, Flat Guards = 3. SOW = 35K, PUW = 45K 6/18/2008 00:00 - 01:00 1.00 BUNCO P RUNCMP MU landing joint, 10' pup and tubing hanger (2-7/8" EUE 8rd threads). 01:00 - 05:00 4.00 BUNCO RUNCMP Perform Penetrator splices on the ESP and Heat Trace cables Printed: 7/17/2008 11:52:37 AM A ~ ` ~ BP Exploration Operations Summary Report Page5of5~ Legal Well Name: MPJ-09 Common Well Name: MPJ-09A Spud Date: 7/28/1994 Event Name: WORKOVER Start: 4/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/20/2008 IRig Name: NABOBS 3S Rig Number: I ~ ~ I Date From - To Hours Task Code ~ NPT Phase Description of Operations 6/18/2008 01:00 - 05:00 4.00 BUNCO P RUNCMP with Centrilift reps. Final ESP and Heat Trace checks, HT Phase to phase = 3.9 ohms, ESP cable phase to phase = 3.4 ohms, Motor temp = 62.4 deg, intake temp = 67.4 deg, HT megs = 92.4 G ohm, ESP cable Megs = 2.06 G ohm. 05:00 - 06:30 1.50 BUNCO P RUNCMP Land Tubing Hancaer as per FMC wellhead tech. Run in lock down screws and torque to 450 ft/Ibs. Back out landing joint and lay down. 06:30 - 07:30 1.00 BUNCO P RUNCMP Set TWCV. Test at 3,500 psi x 10 minutes. Record on chart. Good test. 07:30 - 11:00 3.50 BOPSU P RUNCMP Blow down lines. Drain Stack. Nipple down BOP Stack. Set in transport skid. 11:00 - 12:00 1.00 WHSUR P RUNCMP Nipple up Tree and adepter, test Hanger void to 5000 psi for 30 minutes and Production Tree to 5,000 psi for 10 minutes. Record on chart. 12:00 - 13:30 1.50 WHSUR P RUNCMP PU and test lubricator to 500 psi, FMC rep pulled TWC, tubing on a Vac, LD lubricator, FMC rep dry rod BPV. Final ESP and Heat Trace checks, HT Phase to phase = 3.9 ohms, ESP cable phase to phase = 3.4 ohms, Motor temp = 62.4 deg, intake temp = 67.4 deg, HT megs = 92.4 G ohm, ESP cable Megs = 2.06 G ohm. 13:30 - 15:00 1.50 WHSUR P RUNCMP Secure Tree and cellar. Rig released for move to MPE-19 at Printed: 7/17/2008 11:52:37 AM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: ,jis~t.r ~~I~~It~~~v c3e~~ _~ca~cc.€~ru€~t~a~_a.,l~a~~i~~ka,~cair bob.l`[eck~r,~s~~in.:-~lae>~~,c~cv_ Contractor: Nabors Rig No.: 3S DATE: 6/16/2008 Rig Rep.: J. Greco J R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: J.Menke / B. Burson Field/Unit & Well No.: MP J- 09A PTD # 19911114 Operation: Drlg: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250!3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Test Result P P P Quantity Size Test Result Annular Preventer 1 13 518 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Bali Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1800 P 200 psi Attained 23sec P Full Pressure Attained 1 min 32sec P Blind Switch Covers: All stations P Nitgn. Battles {avg): 2025 Number of Failures: 0 Test Time: 51/2 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: Sir~~,re~~~l~~k~~~c~lr Remarks: Tested with 4 1 /2" and 2 7/8" test joints. 24 HOUR NOTICE GIVEN YES x NO Waived By Bob Noble Date 06/14/08 Time 6:30 -'" ' Wifness R.Biorhus / B.Burson est start 2:00 Finish BOP Test (for rigs) BFL 11/14/07 S~ANNE~ JUN 1 6 2008 Nabors 3s BOP Test MP J-09A 6-16-08.x1s - STATE OF ALASKA 11!14!07 OiL AND GAS CONSERVATION CONINIiSS10N BOPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 4/181200$ Rig Rep.: J. Greco / R.Bjorhus R~ Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: !.Menke / B. Burson Field/Unit 8 Well No.: MP J- t19A 1 Operation: Drlg: Test: initial: x Test Pressure: Rams: 250/3500 Workover: x Weeky: _ MISC. INSPECTIONS: Tes# Result Test Result Location Gen.: P WeN Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sea P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer i 1 3 518 5000 P Pipe Rams 1 2 71$ X 5 P Lower Pipe Rams 0 NA Blind Rams 1 t3Nnd P Choke Ln. Valves 1 31!8" 5000 P HCR Valves 2 3118" 5400 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: usual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Lower Keinr 0 NA Ball Type 1 P Inside BOP 1 P Explor.: Bi-Weekly Valves: 250!3500 FLOOR SAFETY VALVES: Quantity Test Result Upper KeNy 0 NA CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraul~ Chokes 1 P AGCUMULATaR S1fSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After C1os1ue 1700 P 200 psi Attained 37sec P FuN Press~xe Attained 1 min 54sec P Bind Switch Covers: A~ stations P Nitgn. Bottles (avg}: 2000 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time:. d 1/3 Hours Repair or replacement of ec~ment w~ be made within days. Inspector 659-3607, fallow with written confirmation to Superviser at: Remarks: Tested with 4112" and 2 7/8" testjo 24 HOUR NOTICE GIVEN YES x NO Date 04/16/08 Time 14:30 Test start 8:30 Finish 12:30 BOP Test (for rigs) BFL 11114/07 ~~~~~ AFR ~ ~ 2Q~~ Gomponerrts tested ALL Notify the North Slope By __ John Witness !.Greco / !.Menke Nabors 3s BOP Test MP J-09A 4-18-08.x1s . í ,- STATE OF ALASKA ALASKA ( .AND GAS CONSERVATION CO( 'SSION RFCEIVED REPORT OF SUNDRY WELL OPERATION~N 232004 1. Operations Performed: Alaska Oil & Gas Cons. ... on 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver r8I OJmthorage 0 Alter Casing r8I Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension Changeout ESP 0 Chanqe Approved Proqram r8I Pull Tubinq 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. iii Development 0 Exploratol) 199-114 3. Address: 0 Stratigraphic Test 0 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22495-01-00 7. KB Elevation (ft): KBE = 63 25' 9. Well Name and Number: . MPJ-09A 8. Property Designation: 10. Field 1 Pool(s): ADL 025517 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 8235 feet true vertical 4046 feet Plugs (measured) NIA Effective depth: measured 8235 feet Junk (measured) NIA true vertical 4046 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 112' 112' 2730 1130 Surface 2905' 9-5/8" 2936' 2529' 5750 3090 Intermediate Production 5305' 7" 5334' 3828' 7240 5410 Liner 3020' 4-1/2" 5215' - 8235' 3758' - 4046' Perforation Depth MD (ft): 6137' - 8190' Slotted Liner Perforation Depth TVD (ft): 4050' - 4045' Slotted Liner Tubing Size (size, grade, and measured depth): 2-7/8",6.5# L-80 5132' Packers and SSSV (type and measured depth): Baker ZXP Liner top packer 5199' 12. Stimulation or cement squeeze summary: R E C E. .1. VF. 0 Intervals treated (measured): J ",' '. .,- Treatment description including volumes used and final pressure: J A N 2 3 7004 Alaska Oil & Gas Lons. Gornmission 13. Representative Daily Average Production or Injectio~,;~ 01 e Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: 293 97 78 271 Subsequentto operation: 308 183 157 352 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: a D .1 R rt f W II 0 t' 0 Exploratory iii Development 0 Service IoQI al y epo 0 e pera Ions a W II S h t. D. 16. Well Status after proposed work: IoQI e c ema IC lagram iii Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing IS true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 N/A Printed Name Sondra Stewman Title Technical Assistant - - ~ l . c"~. '."" - . Prepared By Name/Number: SigQature~~~- Phone JloL{ -Q"'lS"'D DateOl l31tl-{ SOr).c[~~t ,.:;~t4750 Form 10-404 Revised 12/2003 ð(¡?j-%rNH~EI¡ ~J6~N 2 .~ 200/], ilJDMS BFL JAW. ,,\~ L\D~J" . '1U Tree: 2-9/16", 5M MPJ-09a Orig.( :lev. = 46.6' (N 22E) Wellhead: WKM 11" x 11" 5M, Orig. GL Elev. = 17.0 ' WKM wI 11" x 2 7/8" tbg. hnr. wI RT To Tbg. Spool = 28.8' (N 22E) NSCT threads top and bottom and 3" CIW H BPV profile 20" 91.1 ppf, H-40 I 115' I 2-7/8" x 1" KBMM GLM I 148' I 9 5/8", 40 ppf, L-80 Btrc. I 2,936' I Centrilift heat trace I 3350' I 2-7/8" x 1" KBMM GLM I 4954' I KOP @ 600' Max angle in tubing 59° @3300-3500' I I Max. hole angle = Horizontal 2-7/8" XN nipple 2.205" 10 5063' 2-7/8" 6.5# L-80 EUE 8rd tubing Centrilift GC1150 ESP I 5079' I (drift 10 = 2,347", cap. = 0.0058 bpf ) GPMTAR 1: 1 159 stages 7" 26 ppf, L-80, NSCC production casing Centrilift tandem gas sep. I 5097' I ( drift 10 = 6.151", cap. = 0.0383 bpf ) I 3693' tvd I I I Tandem seal section 5102' Centrilift KMH 562 series I 5116' I 114 hp. motor, 2330 v/30 amp 4.5" Bonzai completion 6 Fin Motor centrilizer I 5130' I wI Horizontal slotted liner. Stimulation Summary Baker ZXP Liner top packer I 5199' I w/6' tie back (5.25" 10) Baker 5"x7" HMC liner I 5215' I Milled 6-1/8" window at 5334'-5346' (12') hanger (4.375" 10) I I Baker HMCV cement valve 6013' Baker CTC 20' PZP ECP I 6032' I 22 jts of 4.5", 12.6# L-80IBT Solid liner. 11111 11111 50 jts of 4.5" 12.6#, L-80 IBT 11111 Slotted liner from 6137'-8190' 11111 4.5" Baker drillable I I pack off bushing 8190' 4.5" Baker drillable I I guide shoe 8235' DATE REV: BY COMMENTS MILNE POINT UNIT 1 -14-95 Drilled cased Nabors 22E 2-15-95 Completion Nabors 4 ES WELL J-09a 04 /19/97 JBF Schrader Bluff Re-completion by Nabors 4ES API NO: 50-029-22495-01 08/15/97 M.Linder Schrader Bluff sand test #2 12/15/99 M.Linder Sidetracked by Nordic 3 1/24/00 M.Linder RWO Nabors 4-ES 12-11-03 Lee Hulme RWO Nabors 4ES BP EXPLORATION (AK) .~ (" ( BP Exploration Page 1 of2 Operations Summary Report Legal Well Name: MPJ-09 Common Well Name: MPJ-09A Spud Date: 7/28/1994 Event Name: WORKOVER Start: 12/8/2003 End: 12/11/2003 Contractor Name: Nabors Rig Release: 12/11/2003 Rig Name: Nabors 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2003 00:00 - 01 :00 1.00 MOB P PRE Arrive on Location from MP CFP-1. Spot Sub over MPJ-09a Well. Spot Pipe Shed. 01 :00 - 02:00 1.00 RIGU P PRE Raise and Scope Derrick. 02:00 - 03:00 1.00 RIGU P PRE Spot Pits and Rig Camp. 03:00 - 05:00 2.00 RIGU P PRE Spot tiger Tank. Hook up lines to Tree. Take on Hot Sea Water in Rig Pits. 05:00 - 06:30 1.50 WHSUR P DECOMP Accept Rig at 05:00 hrs. Lay lines to Tiger Tank. Pick-up Lubricator. Pull BPV. Lay down same. 06:30 - 08:30 2.00 KILL P DECOMP Continue to take on Hot Sea water. Blow all lines. 08:30 - 09:00 0.50 KILL P DECOMP PJSM with all. Well Kill Operations. 09:00 - 09:30 0.50 KILL P DECOMP Pressure test lines to 3,500 psi. 09:30 - 11 :30 2.00 KILL P DECOMP Circulated Tbg Volume plus 25 bbls with 120 deg Sea Water at 4 bpm/950 psi. Closed choke and attempted to Bullhead Casing volume but pressure climbed. Finished circulating remaining Annulus volume to surface. Monitor well. Attempted to establish an injection rate as follows: 10:38--1/2 bpm/1000 psi. 10:40--1/2bpm/1600 psi. 10:41--5 spm (less then 1/2 bpm) 2000 psi. SD pump. Liner is packed off. Blow down lines. 11 :30 - 12:00 0.50 WHSUR P DECOMP Set TWC. 12:00 - 13:30 1.50 WHSUR P DECOMP Nipple down Production Tree. 13:30 - 15:00 1.50 BOPSUF P DECOMP Nipple up BOPE. 15:00 - 15:30 0.50 BOPSUF P DECOMP R/U test equipment. Fill BOP stack. 15:30 - 19:00 3.50 BOPSUF P DECOMP Test BOPE. LP 250 psi, HP 3500 psi. Tested rams. choke manifold, kelly & valves, Koorney. Tested annular to 2500 psi. Test witnessing waived by Jeff Jones wI AOGCC. 19:00 - 20:30 1.50 BOPSUR P DECOMP RID test equip & drain BOP stack. 20:30 - 21 :00 0.50 PULL P DECOMP M/U landing jt. BOLDS. Hold PJSM. 21 :00 - 22:00 1.00 PULL P DECOMP Pull hanger to floor. P/U wt 48K. LID hager & landing jt. 22:00 - 23:30 1.50 PULL P DECOMP M/U head pin in tbg. Circulate bottoms up @ 4 BPM, 500 psi. No losses. 23:30 - 00:00 0.50 PULL P DECOMP Attach power cable, I wire & heat trace to spooler. POOH & stand back 2 7/8" ESP completion. 12/9/2003 00:00 - 03:30 3.50 PULL P DECOMP POOH w/2 7/8" tubing, heat trace, I-wire & ESP cable. Finish spooling up heat trace. 03:30 - 05:00 1.50 PULL P DECOMP Con't to POOH & standback 27/8" tubing. 05:00 - 07:30 2.50 PULL P DECOMP LID ESP. Recovered 6 protectolizers, 2 flat guards, 49 Lasalle clamps, 148 bands, 357 6' guards wI 1134 bands. 07:30 - 13:00 5.50 CLEAN P DECOMP PJSM. Pick up mule shoe & RIH on 2 7/8" PAC, (99) jts. 13:00 - 17:00 4.00 CLEAN P DECOMP PJSM. M/U xIo to PAC & continue in hole w/3 1/2" DP. WI 68 jts 3 1/2" DP in hole, go through liner top @ 5199' with no indication. Continue in hole w/3 1/2" DP. Tag top of fill @ 5653' DPM. 17:00 - 23:00 6.00 CLEAN P DECOMP M/U head pin on 3 1/2" DP. Break circulation @ 3 BPM, 700 psi. Wash down from 5655 to 6162'. P/U wt 691K, SID 47K. No losses initially. Reverse circulated out oil, very fine sand & black heavies. Started losing fluid upon washing thru slotted liner @ 6137'. Fluid Losses increased to 60 %. 23:00 - 00:00 1.00 CLEAN P DECOMP Con't to reverse circulate @ reduced rate of 2 BPM, 200 psi. Washed from 6162 to 6251'. Losses decreased to 50 %. Unable to continue, running out of fluid.. 12/10/2003 00:00 - 00:30 0.50 CLEAN P DECOMP RID & blow down reverse circulating lines. 00:30 - 07:30 7.00 CLEAN P DECOMP POOH & LID 3 1/2" DP & 2 7/8" PAC & mule shoe. Printed: 12/17/2003 9: 14: 16 AM ." ( ( BP Exploration Page 2 of 2 Operations Summary Report Legal Well Name: MPJ-09 Common Well Name: MPJ-09A Spud Date: 7/28/1994 Event Name: WORKOVER Start: 12/8/2003 End: 12/11/2003 Contractor Name: Nabors Rig Release: 12/11/2003 Rig Name: Nabors 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/10/2003 07:30 - 09:00 1.50 RUNCO~/P COMP PJSM. Rig up to run ESP completion. Warm up ESP pumplmotor components. 09:00 - 11 :00 2.00 RUNCO~/P COMP Make up ESP pump assembly & power cable, test same, OK. 11 :00 - 18:00 7.00 RUNCO~(P COMP RIH wI "XN" Nipple, (3) jts 2 7/8" EUE 8rnd tubing, GLM, (57) jts 2 7/8" EUE 8 rnd tbg. M/U heat trace & RIH wI heat trace & ESP completion. Approximate depth of heat trace = 3350' (+ -). 18:00 - 21 :00 3.00 RUNCO~~ COMP Con't to RIH w/2 7/8" tbg, heat trace & ESP. Test ESP every 1000'. 21 :00 - 21 :30 0.50 RUNCO~ P COMP Bring additional flat guards to floor & dress wI bands. 21 :30 - 00:00 2.50 RUNCO~ P COMP Con't to RIH w/2 7/8" tbg, heat trace & ESP. Test every 1000'. 12/11/2003 00:00 - 00:30 0.50 RUNCO~ P COMP Con't to RIH w/2 7/8" tbg, heat trace & ESP. Test every 1000'. 00:30 - 05:00 4.50 RUNCO~ P COMP M/U landing jt & hanger. Install penetrators. Attach field connector & splice ESP & heat trace line. Plug in & test, OK. 05:00 - 05:30 0.50 RUNCO~P COMP Land hanger & RILDS. P/U 44K, S/O 34K. 05:30 - 06:00 0.50 BOPSU¡:; P COMP Install TWC & test to 3500 psi. 06:00 - 07:00 1.00 BOPSU¡:; P COMP PJSM. NID BOPE. 07:00 - 10:00 3.00 WHSUR P COMP PJSM, Nipple up & test tree @ 5000 psi, OK. Test ESP conductivity, OK. Set BPV. Secure well. Rig released @ 10:00 hrs, 12-11-2003. Well to be freeze protected by MP Wells group. Printed: 12/17/2003 9:14:16 AM DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1991140 Well Name/No. MILNE PT UNIT SB J-09A Operator Bt> EXPLORATION (ALASKA) INC APl No. 50-029-22495-01-00 MD 8235 TVD 4046 Completion Date 1/24/2000 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No ~-- ~2.~_~ ~2~'2'd~'~--_~____~/ 2--.~__-57£ ~-~----~_~_~d~_~_~'-~_-~'2~-_-.~Z.~_~_~_.~£~2~£~..~_--_~ ........... 2'-'-2L~_2. T'-i~-£_~L7~ .~2C~ 'L-~_~ '?' 5~2 - ''572' V.' 7-2'-~---~ ........... '.~'~Y~2~7. ~ DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Interval Data Digital Digital Log Log Run OH / Dataset Type Media Format Name Scale Media No Start Stop Clt Received Number Comments ,.~- R ....~;Rv~-'~i:q' 3~. ..... 8235- .... ~H .... ~i~)20-o0 .......... [ LL~.~ DGR/EWR4-'I-VD 25 FINAL 3828 4046 OH 1/26/2000 Well Cores/Samples Information: Interval Dataset Name Start .Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / ~ Daily History Received? ~ N Formation Tops Receuived? ~)/N Comments: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner DATE: April 22, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Milne Point Unit J'&l Pads Sunday April 22, 20.0i: I traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components With no failures. Lee Huime performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the well houses on these pads during the SVS testing. All the wellhouses were very clean and the equipment appeared to be in excellent condition. Summary: i witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, 11wells 22 components 0 failures MPU I Pad 6wells 12 components 0 failures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X UnClassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By:' cl~Uck ~cheve Date: Field/U~ad: Milne Point / MPU / I Pad Separator psi: LPS 140 HPS 4/22/01 i . i i i. i i i i i ii ii i i i i . i i i i :.-~'ii.i:-':~ ;iSS,.? SSS'V :': ~Retest.'~ Well rype-~.. : Well Permit Separ Set L~ T~t Test Test Date ~l, WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed G~ or CYCL~ 1-01 1900900 1-02' 1900910 140 100' " 95 '~ P '~ ' OiL ,. 1-03 1900920' 140 100 95 P P OIL , I-m 190~30 140 100 95 P P OIL 1-06 ' 1971950 140 100 '~ 95 e 'P .... 0IL 2o7 9s15io 140 106' 95' e'' 'P OIL 1-08 1971920 '140 100 95 P P oIL .,, .,. Wells: 6 Components: 12 Failures: 0 Failure Rate: 0.00% [2]90 var Remarks: RJF 1/16/01 Page 1 ofl SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Milne Point / MPU / J Pad Separator psi: LPS 140 HPS 4/22/01 i i _ . i! .... i i i _ i i i [~iSSV?':] SSSVt i i'i Retest , Well Type.:: Weft Permit Separ Set L/P Test Test Test Date Oil, WAG, GI~J, Numbe, r Number ,PSI PSI Trip Code Code Code Passed GAS or ,CYCLE . :J-01A 1991110 140 100: 95 P P OIL [1-03 1900970 146 1001 95 P P OIL ~j'o4 ' 1900980 ' ' ' 140 100 95 ' P P ........ OiL :J-05 ' 1910950 140 - 100 95 'P P '" OiL J-06 1940950 140 100 125 P P OIL J-07 'i910~;/0 140 100 95 ' 1:; e "' OiL J-08A 1991170 140 100 95 P '~ ' OIL J-09A i991140 140"' 100 110 P ' P "' OIL J-10 .... 1941100 140 100 95 P " P "' OIL J-11 1941140 J-12 '1941180 ....... j'.18' 1972200 ...... J-19A 1951700 J.20, , 1.9.72150........ J-21 ' 1972000 " 140 " 100i "' 95 P P ..... 0IL J-22 ' ' i 38i24o ' 140 100 "' 95: "P 'P OIL J-23 2001200 Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% [] 90 oar Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU J Pad 4-22-01 CS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [-] Suspended [--I Abandoned [--J Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 199-114 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22495-01 4. Location of well at surface , ~ :-~ · '~ :; ' 9. Unit or Lease Name At top of productive interval --~1 10. Well Number 4835' NSL, 634' WEL, SEC. 29, T13N, R10E -~:_~.~.,.._~u,~ .... ~.., ·~~ MPJ-09A At total depth . ~. 11. Field and Pool 4769' NSL, 2840' WEL, SEC. 29, T13N, R10E : ' ~:' ~ ' ~ ' Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 65.32' AMSLi ADL 025517 12. Date Spudded12/07/99 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re 116' N°' °f C°mpleti°nsl 2/10/99 01/24/00 N/A MSL One 17. Total Depth (MD+'l'VD)8235 4046 FT'I18' Plug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set 121' Thickness °f Permafr°st8235 4046 FT, [~ Yes [--~ No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD 23. CASING~ LINER AND CEMENTING RECORD CASING SE'Iq'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 32' 112' 24" 250 sx Arctic Set (Approx.) 9-5/8" 40# L-80 31' 2936' 12-1/4" 572 sx PF 'E', 250 sx Class 'G' 7" 26# L-80 29' 5334' 8-1/2" 400 sx Class 'G' 4-1/2" 12.6# L-80 5215' 8235' 6-1/8" 97 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 6.5#, L-80 5130' MD TVD MD TVD 6137'- 8190' 4050' _ 4045, .. 26. ACi~'D, FRACTURE, CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 62 Bbls of Dead Crude Freeze Protect with 15 Bbls of Diesel 27. PRODUCTION TEST ' ~)at~ First Production IMeth°d °f Operati°n (Fl°wing' gas lift' Otc') 0 ~ib i i~'~ /~ L January 27, 2000 i Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATE OIL-BBL !GAs-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. ID 24-HOUR 28. RATE CORE DATA 'Brief description of'lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Subr~it core chips. RECEIVED ..,?.; 6 2000 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 and Marker Name Depth Depth gravity, GOR, and time of each phase. SBF2 - NA 5406' 3868' SBF1 - NB 5468' 3897' SBE4- NC 5552' 3930' SBE2 - NE 5638' 3955' SBE1 - NF 5856' 4003' TSBD - OA 6014' 4040' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby c~rtify that the foregoing is true and correct to the best of my knowledge Terrie Hubble f~,)~ - Title Technical Assistant III Date (~).~-.." I (~:?' M PJ-09A 199-114 Prepared By Name/Number: Terrie Hubb/e, 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'. RECEIVED Form 10-407 Rev. 07-01-80 Alaska Oit & Gas C, ons, Com Facility M Pt J Pad Progress Report Well MPJ-09A Page 1 Rig Nordic3 Date 06 January 00 Date/rime 03 Dec 99 06:01-15:00 06:01-10:30 10:30 10:30-15:00 15:00 15:00-16:00 15:00-16:00 16:00 16:00-21:00 16:00-21:00 21:00 21:00-06:00 21:00-21:30 21:30 21:30-22:30 22:30 22:30-00:00 04 Dec 99 00:00 00:00-01:30 01:30 01:30-03:30 03:30 03:30-04:00 04:00 04:00-05:00 05:00 05:00-05:45 05:45 05:45-06:00 Duration 8-3/4 hr 4-1/4 hr 4-1/2 hr lhr lhr 5hr 5hr 9 hr 1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 1 hr 3/4 hr 1/4 hr Activity Move rig Rig moved 100.00 % Move rig from MP J-01A to MP J-09A. Attempt to lay herculite. Wind blowing herculite. Finally laid herculite around cellar and as good as possible under rig area. Spot rig over cellar. Rig accepted @ 1030 hrs on 12/3/99. At well location - Cellar Rigged up Drillfloor / Derrick Berm around tanks and rig. Equipment work completed Wellhead work Removed Hanger plug Pull BPV. Equipment work completed Fluid system Fill pits with Seawater RU kill lines. Spot cuttings box and kill tank. RU lines & test to 120 psi w/air. Fill pits with 120 deg seawater. Completed operations Wellhead work Tested Chicksan lines PJSM. Test hardlines to 2000 psi-OK. Pressure test completed successfully - 2000.000 psi Circulated at 0.0 ft Pump down tbg w/1 bpm @ 1300 psi. No circulation. Attempt to pump down annulus. Pumped -1 bbl and pressure up to 2000 psi. Checked all surface equipment. Annulus frozen. Began precautionary measures Monitor pressures Steam wellhead and WO hot oil truck. RU HB&R. Test lines to 3000 psi. Resumed operations Circulated at 0.0 ft Pressure well to 2500 psi w/methanol and maintain pressure. Pumped a total of 7 bbls methanol to thaw well. Broke circulation Circulated at 0.0 ft Displace well with hot seawater. Monitor well-OK. Hole displaced with Seawater - 110.00 % displaced Installed Hanger plug Attempt to set TWC. Well started flowing. Shut in. SITP: 0 psi; SICP: 30 psi. Aborted equipment work Circulated at 0.0 ft CBU Hole displaced with Seawater - 120.00 % displaced Installed Hanger plug Set TWC. Eqpt. work completed, running tool retrieved Removed Xmas tree ~)tO~l. L INL,I Lt~._~k,., ~l, llU CLUdJ_/LL~I. RECEIVED Facility M Pt J Pad Progress Report Well MPJ-09A Page 2 Rig Nordic3 Date 06 January 00 Datefrime 05:45-06:00 06:00-08:00 06:00-08:00 08:00 08:00-10:30 08:00-09:30 09:30 09:30-10:30 10:30 10:30-15:00 10:30-14:30 14:30 14:30-15:00 15:00 15:00-15:30 15:00-15:30 15:30 15:30-23:30 15:30-16:30 16:30 16:30-23:30 23:30 23:30-00:15 23:30-00:15 05 Dec 99 00:15 00:15-00:30 00:15-00:30 00:30 00:30-06:00 00:30-03:30 03:30 03:30-05:45 05:45 05:45-06:00 Duration 2hr 2hr 2-1/2 hr 1-1/2 hr lhr 4-1/2 hr 4hr 1/2 hr 1/2 hr 8 hr lhr 7 hr 3/4 hr 3/4 hr 1/4 hr 1/4 hr 5-1/2 hr 3 hr 2-1/4 hr 1/4 hr Activity RECEIVED Removed Xmas tree Finish ND tree and adapter. Wellhead work (cont...) Removed Xmas tree (cont...) I:: ~ :;.'.. 't 6 11000 Finish ND tree and adapter. Equipment work completed Nipple up BOP stack Rigged up BOP stack Work completed - BOP stack in position Rigged up Top ram Change rams to 3.5". Equipment work completed Test well control equipment Tested BOP stack Test BOPE to 250/3000 psi; annular to 250/2500 psi. Witnessing waived by John Spaulding-AOGCC Field Inspector. Pressure test completed successfully - 3000.000 psi Held safety meeting HSE meeting w/HSE Advisor. Discussed week's LCIR's. Completed operations Wellhead work Removed Hanger plug Pull TWC. Equipment work completed Pull Tubing, 3-1/2in O.D. Retrieved Tubing hanger MU landing it. BOLDS. Pull hanger to floor. Monitor well. 19 bbls to fill. Equipment work completed Laid down 5324.0 ft of Tubing LD kill string. Strap & drift. 170 joints laid out Test well control equipment Tested Bottom ram Set test'plug. Test lower pipe ram and break to 250/3000 psi-OK. LD Test jt & 'test plug. Pressure test completed successfully - 3000.000 psi Wellhead work Rigged up Wear bushing Equipment work completed Electric wireline work Conducted electric cable operations PJSM. RU Schlumberger w/lubricator. Ran 5.83" GR/JB to 5395'. POH. Completed run with Junk basket/gauge ring from 5395.0 ft to 0.0 ft Set downhole equipment (wireline) RIH w/EZSV retainer. Tie in to CBL dated 4/18/99. Set retainer @ 5360'. Completed run with Cement retainer to 5360.0 ft Conducted electric cable operations POH. Facility M Pt J Pad Progress Report Well MPJ-09A Page 3 Rig Nordic3 Date 06 January 00 Date/Time 05:45-06:00 06:00-06:30 06:00-06:30 06:30 06:30-16:00 06:30-07:00 07:00 07:00-08:00 08:00 08:00-08:30 08:30 08:30-10:00 10:00 10:00-12:00 12:00 12:00-12:30 12:30 12:30-13:00 13:00 13:00-14:00 14:00 14:00-16:00 16:00 16:00-02:00 16:00-17:00 17:00 17:00-20:15 20:15 20:15-21:00 21:00 21:00-21:15 21:15 21:15-21:30 21:30 21:30-22:30 22:30 22:30-00:15 Duration 1/4 hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 1/2 hr 1/2 hr 1 hr 2hr 10hr 1 hr 3-1/4 hr 3/4 hr 1/4 hr 1/4 hr lhr 1-3/4 hr Activity Conducted electric cable operations Fin POH & RD Schlumberger. Electric wireline work (cont...) Conducted electric cable operations (cont...) Fin POH & RD Schlumberger. Completed run with Setting tools from 5360.0 fl to 0.0 fl 3-1/2in. Drillpipe workstring run Rigged up Drillstring handling equipment Work completed - Drillstring handling equipment in position Ran Drillpipe in stands to 2000.0 fl Stopped: To change handling equipment Rigged down Instrument lines RD Baker TEC wire sheave for Nabors 4ES. Equipment work completed Ran Drillpipe in stands to 5360.0 ft Fin RIH w/cement stinger. Tag retainer & verify w/ 20k down. On bottom Functioned Cement retainer Break circ. Sting into retainer. Attempt to inject. Press up to 2000 psi. Very slow bleed off. Unsting & check surface equipment. Sting in & pressure to 3000 psi. Bled to 2800 in 10 min. Began precautionary measures Cleared Standpipe manifold Blow down lines. Equipment work completed Tested Casing Stung into retainer. Test 7" f/30 min-OK. Pressure test completed successfully - 3000.000 psi Monitor pressures WO AOGCC approval to proceed with well plan. Resumed operations Pulled out of hole to 0.0 ft POH w/stinger. At Surface: 0.0 ft BHA run no. 1 Made up BHA no. 1 ;'~. :'?-~ ~ 6 ]}000 MU milling assembly. ' '-: -~ BHA no. 1 made up R.I.H. to 5360.0 ft On bottom Held safety meeting PreSpud meeting & TL Awards. Completed operations Pulled out of hole to 5100.0 ft Start POH. Dragging 10-15k. Observed 15.00 klb overpull R.I.H. to 5360.0 ft On bottom Circulated at 5360.0 ft Circ @ 7.5 bpm. Obtained clean returns - 200.00 % hole volume Pulled out of hole to 1474.0 ft RECEIVED Facility Date/Time 06 Dec 99 M Pt J Pad Progress Report 00:15 00:15-01:00 01:00 01:00-02:00 02:00 02:00-06:00 02:00-05:00 05:00 05:00-06:00 06:00-22:00 06:00-08:30 08:30 08:30-09:30 09:30 09:30-10:30 10:30 10:30-15:00 15:00 15:00-17:00 17:00 17:00-20:30 20:30 20:30-22:00 22:00 22:00-06:00 22:00-02:00 07 Dec 99 02:00 02:00-04:30 04:30 04:30-06:00 06:00-06:00 06:00-01:30 Duration 3/4 hr lhr 4hr 3hr lhr 16hr 2-1/2 hr lhr lhr 4-1/2 hr 2hr 3-1/2 hr 1-1/2 hr 8 hr 4hr 2-1/2 hr 1-1/2 hr 24 hr 19-1/2 hr Activity At BHA RECEIVED Pulled BHA BHA Stood back Serviced Block line - -:'.',~ '1 ~ ~000 Slip & cut drlg line. ~ Line slipped and cut ~ 0~1 & ~ C~$, G0ffi~ BHA mn no. 2 Made up BHA no. 2 l~]01'i~ MU whipstock assembly. Orient. MU BHA. Test MWD. BHA no. 2 made up R.I.H. to 3200.0 ft Finish RIH w/whipstock. Fire Drill-OS-30 sec. BHA mn no. 2 (cont...) R.I.H. to 5290.0 ft (cont...) Finish RIH w/whipstock. Fire Drill-OS-30 sec. Stopped ' To take survey Took MWD survey at 5200.0 ft Orient whipstock. Set @ 5355' DPM. PU: 90k; SO: 75k. Set 40 deg left of high. Shear off. Acceptable survey obtained at 5200.0 ft Circulated at 5350.0 ft ~ Displace well to milling fluid. Hole displaced with Water based mud - 100.00 % displaced · Milled Casing at 5334.0 ft Milled window f/5334'-5346'. Milled to 5363'. Completed operations Circulated at 5363.0 ft Pump sweeps. Reciprocate back and forth through window. Window in good shape. Monitor well-OK. Pump dry job. Blow down. Hole swept with slug - 200.00 % hole volume Pulled out of hole to 1491.0 ft At BHA Pulled BHA LD MWD & mills. Mulls in gauge. Clear floor. BHA Stood back BHA mn no. 3 Made up BHA no. 3 PU 4.75" directional tools. Upload MWD. Orient. Check MWD. Blow down. BHA no. 3 made up R.I.H. to 5362.0 ft SLM in hole. D 1 Drill-OS-35 sec. On bottom Drilled to 5415.0 ft Continue directional drilling 6.125" hole F/5415' to 6283' ECD 10.7 while sliding for direction and angle. Up/wt 85k, Dn/wt 75K w/rotary. Pumped sweep @ 5992' 38 bbl's Hi-vis Hi-wt w/fiber. Brought up a good load of cuttings. ECD 11.1 BHA run no. 3 (cont...) Drilled to 6283.0 ft (cont...) Continue directional drilling 6.125" hole F/5415' to 6283' ECD 10.7 while sliding for direction and ~__,_ ,T_, ....o~,. ~,_, .... '~"~ w/rotary. P ..... -' swccp O. II~IU. U[J/ WL O3IN~, UIIJ WL /31'~- LIIIIJJ~-.,U Well MPJ-09A Page 4 Rig Nordic3 Date 06 January 00 Facility M Pt J Pad Progress Report Well MPJ-09A Page 5 Rig Nordic3 Date 06 January 00 Date/Time 08 Dec 99 01:30 01:30-03:00 03:00 03:00-05:00 05:00 05:00-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-11:00 11:00 11:00-12:30 12:30 12:30-15:00 15:00 15:00-06:00 09 Dec 99 06:00-06:00 06:00-12:00 12:00 12:00-14:30 14:30 14:30-16:00 16:00 16:00-17:30 17:30 17:30-06:00 Duration 1-1/2 hr 2hr lhr 24 hr 1/2 hr 4-1/2 hr 1-1/2 hr 2-1/2 hr 15hr 24 hr 6 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 12-1/2 hr Activity @ 5992' 38 bbl's Hi-vis Hi-wt w/fiber. Brought up Stopped · To circulate Circulated at 6283.0 ft Circulate & reciporcate pump sweep Hi-vis Hi-wt w/ fiber ECD 11.1, Clean hole for short trip. Hole swept with slug - 200.00 % hole volume Pulled out of hole to 2000.0 fl POOH to 7" csg window. Hole in good condition. Blow down top drive. POOH stand back DP & HWDP At top of check trip interval R.I.H. to 5334.0 ft RIH w/3.5" DP to 7" Window @ 5334'. Continue cleaning pit for BARADRILn fluid. @ 0600 hrs At 5334in casing shoe BHA run no. 3 (cont...) Serviced Top drive Equipment work completed Cleared Trip tank Clean mud tanks & trip tank. Take on new 9.1 ppg BARADRILn fluuid E4uipment work completed R.I.H. to 6283.0 ft RIH to 5334' 7" window. Orient tool to whipstock. Trip through 6-1/8" open hole to 6283' Hole iiin good condition. On bottom Circulated at 6283.0 ft Circulate bottoms up, Pump Hi-vis, Lo-Vis Sweep ahead of new BARADRILn 9.1 ppg drilling fluid. Hole apeared to have been clean. Obtained req. fluid properties - 100.00 %, hole vol. Drilled to 7210.0 fl Geostreer horizontal 6.125" hole f/6283' to 7210'. pumped sweeps ECD 10.7 MAX 11.4 w/sweep. BHA run no. 3 (cont...) Drilled to 7515.0 ft Continue drilling from 7210' to 7515' md. ECD = 10.7-10.8, max ECD while circulating sweeps = 11.4. Solids level in mud beginning to climb. Began precautionary measures Circulated at 7515.0 ft Circulate bottoms-up and pump sweep. Obtained clean returns - 100.00 % hole volume Pulled out of hole to 6283.0 ft Short trip to 6283' to condition hole. Hole in good shape. Run back to bottom. Began precautionary measures ~ 0il & Gas C0115 Circulated at 7515.0 ft Swap out 240 bbls of mud reduce solids load. Obtained req. fluid properties - 100.00 %, hole vol. Drilled to 8030.0 ft Continue drilling from 7515' to 8030' md. ECD = 10.8-10.9 ppg. Having trouble dropping angle to RECEI /ED Facility M Pt J Pad Progress Report Well MPJ-09A Page 6 Rig Nordic3 Date 06 January 00 Date/Time 10 Dec 99 06:00-06:00 06:00-11:00 11:00 11:00-12:30 12:30 12:30-15:30 15:30 15:30-17:45 17:45 17:45-18:00 18:00 18:00-20:30 20:30 20:30-21:00 21:00 21:00-00:30 21:30 llDec99 00:30 00:30-01:00 01:00 01:00-02:30 02:30 02:30-03:30 03:30 03:30-06:00 06:00-10:15 06:00-07:30 07:30 07:30-08:00 08:00 08:00-09:30 09:30 09:30-10:15 Duration 24 hr 5hr 1-1/2 hr 3hr 2-1/4 hr 2-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1 hr 2-1/2 hr 4-1/4 hr 1-1/2 hr 1/2 hr 1-1/2 hr 3/4 hr Activity sweep, BHA run no. 3 (cont...) Drilled to 8235.0 ft Continue to drill from 8030' to TD at 8235'. Up wt = 95klb, dn wt = 60klb, rot wt. = 75klb, ECD = 10.81 ppg at TD. Reached planned end of run - Section / well T.D. Circulated at 8235.0 ft Pump sweep, rotate and reciprocate pipe. Obtained clean returns - 100.00 % hole volume Pulled out of hole to 5300.0 ft Blow down top drive and POOH to window for short trip. Hole in good condition. At top of check trip interval At window. Serviced Top drive blower Service top drive & draw works, grease crown. Repair top drive blower motor. Equipment work completed Took EMS survey at 8200.0 ft Drop survey shot. Acceptable survey obtained at 8200.0 ft R.I.H. to 8123.0 ft RIH from 5300 to 8220'. Blow down top drive. On bottom Circulated at 8220.0 ft Broke circulation Circulate at 245 gpm, 2300 psi and reciprocate from 8123' to 8220'.. Circulated at 8220.0 ft Pump 30 bbl hi-wate, hi-vis sweep. On bottom Hole displaced with Water based mud - 300.00 % displaced Off load 200 bbls of mud. Up wt = 80klb, dn wt = 75klb, rot wt = 75klb. Took MWD survey at 8220.0 ft Acceptable survey obtained at 8220.0 ft Pulled out of hole to 5334.0 ft At 7in casing shoe Attempt to blow down top drive. No luck. Serviced Top drive Thaw goose neck on top drive, blow down top drive. Equipment work completed Pulled out of hole to 1000.0 ft Continue to POOH, filling hole every 5 stands. Hole fill OK. No problems pulling out of open hole. BHA run no. 3 (cont...) Pulled out of hole to 160.0 ft POOH filling every 5 stands. At BHA Downloaded MWD tool Completed operations Pulled BHA BHA Laid out RECEIVED 't 6 2000 Removed Drillstring handling equipment Facility M Pt J Pad Progress Report Well MPJ-09A Page 7 Rig Nordic3 Date 06 January 00 Date/Time 10:15 10:15-06:00 10:15-11:00 11:00 11:00-11:30 11:30 11:30-17:00 17:00 17:00-18:00 18:00 18:00-18:30 18:30 18:30-22:30 22:30 22:30-00:00 12 Dec 99 00:00 00:00-02:30 02:30 02:30-04:30 04:30 04:30-06:00 06:00-12:00 06:00-07:30 07:30 07:30-12:00 Duration 19-3/4 hr 3/4 hr 1/2 hr 5-1/2 hr lhr 1/2 hr 4 hr 1-1/2 hr 2-1/2 hr 2hr 1-1/2 hr 6hr 1-1/2 hr 4-1/2 hr Activity Equipment work completed Run Liner, 4-1/2in O.D. Installed Casing handling equipment -' ;.'~ '~ ~ ~0~ R/u floor to run 4-1/2" liner. P/U 6 jts. 4-3/4" DC' s and stand back. Equipment work completed Held safety meeting Hold PJSM w/company man & Baker prior to RIH w/ liner. Completed operations Ran Liner to 3047.0 ft (4-1/2in OD) P/U, rabbit, & RIH with 4-1/2" liner. M/U to mark on liner, not exceeding 4000 ft-lbs of torque. Up wt = 50 klb, Dn wt = 48 klb. At Top of liner' 3047.0 ft Removed Casing handling equipment R/D 4-1/2" liner equipment & R/U 2-7/8" handling equipment. Equipment work completed Held safety meeting Held PJSM on picking up 2-7/8" tube and RIH to window. Completed operations Ran Tubing to 3047.0 ft (2-7/8in OD) P/U and RIH w/67 its. of 2-7/8" tubing, cup tool & indicator tool, and 2-7/8" tbg to jt 93. Space out and tag joint # 94 at 7 ft. L/D g94. At Top of liner · 3047.0 ft Installed Liner hanger M/U liner hanger and liner running tool. Up wt - 70 klb, dn wt = 65 klb. RIH w/one stand HWDP. R/U circulating hose and pump 16 bbls @ 2-1/2 bpm and 450 psi. Equipment work completed Ran HWDP in stands to 5300.0 ft RIH w/11 stands HW, 6 stands DC's, and 6 stands of DP to just inside window. At 7in casing shoe Circulated at 5300.0 ft K/U and break circulation @ 44 spm and 450 psi. Up wt = 110 klb, dn wt = 92 klb w/o pump. Obtained clean returns - 100.00 % hole volume Ran Drillpipe to 8235.0 ft (3-1/2in OD) Run drillpipe in stands. Run Liner, 4-1/2in O.D. (cont...) Ran Drillpipe to 8235.0 ft (3-1/2in OD) (cont...) Run drillpipe in stands. On bottom Continue to run liner on 3-1/2" DP to bottom. Observed differential sticking on connections. Took 10 to 25 klbs to break free. On bottom up wt = 120 klb, dn wt = 65 klb. Circulated at 8235.0 ft M/u cement head and break circulation at 3 bpm, 830 psi. RECEIVED Facility M Pt J Pad Progress Report Well MPJ-09A Page 8 Rig Nordic3 Date 06 January 00 Date/Time 12:00 12:00-23:00 12:00-13:30 13:30 13:30-14:00 14:00 14:00-16:00 16:00 16:00-17:00 17:00 17:00-17:30 17:30 17:30-18:00 18:00 18:00-23:00 23:00 23:00-06:00 23:00-02:00 13 Dec 99 02:00 02:00-04:00 04:00 04:00-06:00 06:00 06:00-23:00 06:00-12:00 12:00 12:00-13:00 13:00 13:00-13:30 Duration llhr 1-1/2 hr 1/2 hr 2hr 1 hr 1/2 hr 1/2 hr 5 hr 7 hr 3hr 2 hr 2 hr 17hr 6 hr 1 hr 1/2 hr Activity Dropped ball Pressure up to 1600 psi to set hanger. Inflate ECP with 1100 psi. Packer inflated with 0.18 bbls - 6-3/8" open hole. Cement: Liner cement Rigged up Cement unit R/U Dowell, install pump down plug, m/u circulating head. Equipment work completed Held safety meeting Held PJSM w/rig crew, Dowell & Baker on cement job. Stay clear of high pressure lines while testing. Completed operations Mixed and pumped slurry - 12.700 bbl Pump 15.8 ppg slurry and displace with 40 bbls fluid. Cement pumped Functioned Circulating sub Reverse circulate 2 bbls, shear dump valve and cirulate b/u. Observed traces of cement at surface. Equipment work completed Functioned Permanent packer L/d circ. head, set packer with 35 klb. Pressure test annulus with 1000 psi. Test OK. Equipment work completed Rigged down Circulating head Break down circulating head and 1/d single. Up wt = 100 klb, dn wt -- 70 klb. Equipment work completed Circulated at 6015.0 ft M/u top drive and circulate and reciprocate. Pump sweep. Obtained req. fluid properties - 100.00 %, hole vol. Pull Drillpipe, 3-1/2in O.D. Pulled Drillpipe in stands to 3047.0 ft POOH w/DP, collars, and HWDPin stands. Completed operations Pulled Tubing in stands to 2220.0 ft Stand back 8 stands 2-7/8" tubing. L/d cup tool and indicator. RIH one stand 2-7/8. Completed operations Serviced Block line Slip and cut drlg line. Line slipped and cut RECEIVED Pull Drillpipe, 3-1/2in O.D. (cont...) Ran Drillpipe to 8203.0 ft (3-1/2in OD) RIH to 8203' & tag. Pump lo/hi-vis spacer displace to clean sea water. Clean out pits. On bottom Circulated at 8203.0 £t Spot 70 bbl Mudzyne pill. Began precautionary measures Held safety meeting TT~I..1 I~TC~.ff 1~1,~...' .... T ~"-~TI~ ? Facility M Pt J Pad Progress Report Well MPJ-09A Page 9 Rig Nordic3 Date 06 January 00 Datefrime 14 Dec 99 13:30 13:30-16:00 16:00 16:00-20:30 20:30 20:30-23:00 23:00 23:00-06:00 23:00-04:00 04:00 04:00-06:00 06:00 06:00-06:00 06:00-07:30 07:30 07:30-08:00 08:00 08:00-08:30 08:30 08:30-12:00 12:00 12:00-13:00 13:00 13:00-18:00 18:00 18:00-20:00 20:00 20:00-06:00 Duration 2-1/2 hr 4-1/2 hr 2-1/2 hr 7 hr 5 hr 2 hr 24 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2hr 1 hr 5 hr 2 hr lOhr Activity Completed operations Installed Lines / Cables Onload 1-wire spool, ESP cable, Stand and gaurds with crane. Equipment work completed Pulled Drillpipe in stands to 6060.0 ft POOH 23 stands. Displace with fresh seawater. Blow TD. POOH with 54 more stands of 3-5" DP. Change to Eckles tongs, R/U 2-7/8" handling equipment. At top of check trip interval Pulled Tubing in stands to 0.0 ft Pull 2-7/8" tubing and slick stinger. Clear pipe shed. Retrieved 0.0 ft from Downhole equipment Run Single completion, 3-1/2in O.D. Ran Tubing to 4970.0 ft (3-1/2in OD) P/u 3.5" tubing. On bottom Pulled Tubing in stands to 0.0 ft Pull tbg and stand back in derrick. Completed operations Run Single completion, 3-1/2in O.D. (cont...) Pulled Tubing in stands to 0.0 ft Stand back 3-1/2" tubing. Pull wear ring. Completed operations Installed Cable head Hang 1-wire sheave and ESP spool gaurds. Equipment work completed Held safety meeting Held PJSM on ESP completion Completed operations Installed ESP P/U motor assembly. R/U Halliburton wireline, set pump and packoff and Pressure test to 2500 psi for 15 minutes. Pull packoff, set tubing stop, and R/D HES. Equipment work completed Held safety meeting Held PJSM on ESP cable spooler with ARCO engineer. Completed operations Conducted electric cable operations String ESP cable and attach to pot head. Attach Baker sentry gauge. RIH to stand #25. Began precautionary measures Ran Tubing in stands to 2256.0 ft Continue to RIH to 2256'. Install heat trace and band flat gaurds. Test ESP cable. Stopped: To splice cable Ran Tubing in stands to 5100.0 ft Continue to RIH testing heat trace every 540' and testing ESP and 1-wire every 1000', banding every 2'. Spacing out at report time. RECEIVED Facility M Pt J Pad Progress Report Well MPJ-09A Page Rig Nordic3 Date 10 06 January 00 Date/Time 15 Dec 99 06:00 06:00-12:00 06:00-06:30 06:30 06:30-08:00 08:00 08:00-10:30 10:30 10:30-12:00 12:00 12:00-14:30 12:00-12:30 12:30 12:30-13:30 13:30 13:30-14:30 14:30 14:30-17:00 14:30-17:00 17:00 17:00-02:00 17:00-18:00 18:00 18:00-19:00 19:00 19:00-01:30 16 Dec 99 01:30 01:30-02:00 02:00 Duration 6hr 1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr lhr lhr 2-1/2 hr 2-1/2 hr 9hr 1 hr 1 hr 6-1/2 hr 1/2 hr Activity On bottom Run Single completion, 3-1/2in O.D. (cont...) Installed Tubing hanger M/U landing joint to tubing hanger. Equipment work completed Installed Tubing hanger Cut tec wire, m/u swedge locks and pressure test to 5000 psi. Install penetrators. Hook up and test Raychem heat trace cable. Test OK. Cable wrapped around tubing 3 times before being made up to hanger. Equipment work completed Installed Tubing hanger Splice ESP cable, connect to hanger and test. Test OK. Equipment work completed Installed Tubing hanger Land Tubing. p/u wt = 65 klb, s/o wt = 50 klb with blocks. RILDS, lay down landing joint and set TWC. Equipment work completed Nipple down BOP stack Rigged down BOP stack Began precautionary measures Held safety meeting Safety Standown with Fritz Gunkel and Tom Blackwell. Completed operations Removed BOP stack Equipment work completed Raychem heat trace cable test failed. Nipple up BOP stack ~:~ ,', 'I (~ 2000 Installed BOP stack Wellhead work ~~ Removed Tubing hanger Pull TWC, M/U landing jt, BOLDS, Pull tubing hanger to floor. Cable failed - Change operation Heat trace cable parted 5 feet below hanger. Held safety meeting Held PJSM on picking up spool with crane, r/d spool gaurds. Completed operations Serviced Tubing hanger Begin splicing heat trace cable. Work on No. 1 charge pump. Equipment work completed Well took 6 bbls while splicing heat trace cable. Installed Tubing hanger Land hanger, p/u wt = 65 klb, s/o wt = 55 klb. RILDS. L/D landingjt. Equipment work completed RECEIVED Facility M Pt J Pad Progress Report Well MPJ-09A Page Rig Nordic3 Date 11 06 January 00 Date/Time 02:00-04:00 02:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-07:00 06:00-06:45 06:45 06:45-07:00 07:00 07:00-08:30 07:00-08:00 08:00 08:00-08:30 08:30 08:30-09:00 08:30-09:00 09:00 09:00-06:00 09:00-12:00 12:00 Duration 2hr 2hr 2hr 2hr lhr 3/4 hr 1/4 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1/2hr 21hr 3 hr Activity Nipple down BOP stack Removed BOP stack N/D BOP's. Equipment work completed Wellhead work Installed All tree valves Test Raychem heat trace. NFO tree and adaptor. Feed 1-wire through adaptor flange and N/U tree. Equipment work completed Wellhead work (cont...) Tested Xmas tree Test tbg hd adapter & tree to 250 / 5000 psi-OK. Pressure test completed successfully - 5000.000 psi Removed Hanger plug Pull TWC. Equipment work completed Fluid system Freeze protect well - 62.000 bbl of Oil RU HB&R. Test lines. Bullhead dead crude down annulus. Completed operations Freeze protect well - 15.000 bbl of Diesel Bullhead diesel down tbg. Completed operations Wellhead work Installed Hanger plug Set BPV. Eqpt. work completed, running tool retrieved Move rig Rig moved 25.00 % Secure well & clean cellar. Move off MP J-09A, Pickup & dispose of pit liner. Clean area. Rig off station Rig released @ 1200 hrs on 12/16/99. Facility M Pt J Pad Progress Report Well MPJ-09A Page 1 Rig Nabors 4ES Date 24 January 00 Date/Time 20 Jan 00 21 Jan 00 22 Jan 00 22:00-06:00 22:00-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-12:00 08:00-12:00 12:00 12:00-13:30 12:00-13:30 13:30 13:30-15:30 13:30-14:00 14:00 14:00-15:30 15:30 15:30-18:00 15:30-18:00 18:00 18:00-20:00 18:00-20:00 20:00 20:00-21:00 20:00-21:00 21:00 21:00-01:00 21:00-01:00 01:00 01:00-06:00 01:00-06:00 06:00 06:00-13:00 06:00-13:00 13:00 13:00-01:00 13:00-23:00 23:00 Duration 8 hr 8 hr 2 hr 2 hr 4 hr 4hr 1-1/2 hr 1-1/2 hr 2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 2 hr 2 hr 1 hr 1 hr 4 hr 4 hr 5 hr 5 hr 7 hr 7 hr 12hr 10hr Activity Move rig Rig moved 100.00 % move rig from mpc-14 to mpj-09 & set in ..& safe out At well location - Slot Fluid system Fill pits with Seawater Fill pits & rig hard lines to tank. for well kill Completed operations Derrick management Rigged up High pressure lines rig hcr valve and lines to tree & test same to 2500 psi. & pull bpv Equipment work completed Well control Circulated closed in well at 5100.0 ft kill well wit sea h20 well was on a slight vacumn Hole displaced with Seawater - 125.00 % displaced Wellhead work Installed Hanger plug & test same to 250 0 psi. Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Wellhead work Retrieved Hanger plug rig floor to pull esp completion with heat trace & baker sensor. Equipment work completed Pull Single completion, 3-1/2in O.D. Laid down 1937.0 ft of Tubing lay dn tubulars removing completion equipment. Stopped: To hold safety meeting crew change Pull Single completion, 3-1/2in O.D. (cont...) Laid down 5100.0 ft of Tubing Finish laying down esp ttescp & investigate for failure. Completed operations Run Tubing, 2-7/8in O.D. Ran Tubing to 4965.0 ft (2-7/8in OD) Load tbg. in pipe shed & strap & drift. (drifting difficult due to ice & snow & debri in tbg. & run in hole with same On bottom RECEIVED Facility M Pt J Pad Progress Report Well MPJ-09A Page 2 Rig Nabors 4ES Date 24 January 00 Date/Time 23 Jan O0 24 Jan 00 23:00-23:30 23:30 23:30-01:00 01:00 01:00-06:00 01:00-06:00 06:00 06:00-16:30 06:00-16:30 16:30 16:30-22:30 16:30-21:00 21:00 21:00-22:30 22:30 22:30-00:00 22:30-00:00 00:00 00:00-02:30 00:00-01:30 01:30 01:30-02:30 02:30 02:30-06:00 02:30-04:00 04:00 Duration 1/2 hr 1-1/2 hr 5 hr 5 hr 10-1/2 hr 10-1/2 hr 6 hr 4-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr Activity Circulated at 4965.0 ft circ. a tbg. volume @ 5.5 bpm 1125 psi. Hole displaced with Seawater - 100.00 % displaced Pulled Tubing in stands to 4965.0 ft Completed operations Run Single completion, 2~7/8in O.D. Ran Tubing in stands to 1200.0 ft Rig floor & mu esp assy & rih with same Stopped: To hold safety meeting Run Single completion, 2-7/8in O.D. (cont...) Ran Tubing in stands to 5130.0 ft cont. to rih with esp assy installing heat trace+baker sensor +esp cable On bottom Wellhead work Rigged up Tubing hanger mu tbg. hanger & install esp cable & heat trace & baker sensor & check out. & land hanger & rilds. Work completed - Tubing hanger in position Installed Hanger plug install twc & test to 2500 psi. Equipment work completed Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree install tree & test to 5000 psi. Equipment work completed Installed Hanger plug pull twc & set bpv & make final check on all equipment. Equipment work completed Fluid system Freeze protect well - 70.000 bbl of Diesel freeze protect well with HB&R. & rd cellar area * secure well. Completed operations RECEIVED ,* North~ Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-O9A Surveyed: 10 December, 1998 SURVEY REPORT RECEIVED 14 December, 1999 Your Ref: A PI-500292249501 Surface Coordinates: 6014745.62 N, 552129.93 E (70° 27' 03.6847" N, 149° 34' 28.8254" W) Kelly Bushing: 65.32ft above Mean Sea Level DRILLING SERVICE':: Survey Reh svy8920 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 5300.34 53.410 334.980 3742.07 5334.00 52.960 334.600 3762.24 5335.00 52.940 334.590 3762.84 5353.09 54.820 334.580 3773.51 5387.51 57.490 331.590 3792.68 5420.65 60.280 328.880 3809.80 5449.78 62,240 326.610 3823.81 5484.90 65.120 324.000 3839.38 5516.04 67.790 321.790 3851,82 5546.59 71.010 319.140 3862.57 5580.30 72.800 318.170 3873.04 5611.44 73.490 316.470 3882.07 5642.30 74.540 315.210 3890.57 5675.67 75.690 311.970 3899.14 5706.80 77.240 309.220 3906.43 5739.73 78.450 306.050 3913.37 5773.20 79.070 302.600 3919.89 5806.63' 78.350 300.800 3926.44 5837.36 75.920 299.640 3933.28 5871.17 75.380 297.060 3941.66 5903.54 76.180 293.790 3949.61 5934.08 76.330 289.380 3956.87 5967.65 76.320 285.780 3964.81 6000.17 77.680 284.940 3972.13 6031.83 80.040 284.020 3978.24 Survey Report for MPJ-O9A Your Ref: API-500292249501 Surveyed: 10 December, 1998 Sperry-Sun Drilling Services RECEIVED ~0il & Gas 6oas. Comm'mek~ Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) (ft) Dogleg Rate (°/100ft) 3807,39 2066,19 N 2237,87,W 6016796,11N 549877,66 E 3827,56 2090,57 N 2249,35W 6016820,41N 549866,01E 3828,16 2091,29 N 2249,69W 6016821,13 N 549865,67 E 3838,83 2104,49 N 2255,96W 6016834,28 N 549859,30 E 3858,00 2129,97 N 2268,91W 6016859,67 N 549846,18 E 3875.12 2154.59 N 2283,00W 6016884,19 N 549831,92 E ,3889,13 2176,18 N 2296,63W 6016905,68 N 549818,13 E 3904,70 2202,05 N 2314,55W 6016931,43 N 549800.03 E 3917,14 2224,82 N 2331,78W 6016954,07 N 549782,65 E 3927,89 2246,86 N 2349.98W 6016975,99 N~ 549764,29 E 3938,36 2270.91 N 2371,15W 6016999,89 N 549742,95 E 3947,39 2292,82 N 2391,35W 6017021,66 N 549722.60 E 3955,89 2314,10 N 2412.02W 6017042,79 N 549701.78 E 3964,46 2336,33 N 2435,37W 6017064.86 N 549678.27 E 3971,75 2356,02 N 2458,35W 6017084.39 N 549655,16 E 3978,69 2375,68 N 2483,84W 6017103,86 N 549629,53 E 3985,21 2394.18 N 2510,95W 6017122,18 N 549602.29 E 3991.76 2411,41 N 2538.84W 6017139.21 N 549574.28 E 3998.60 2426,49 N 2564.73W ' 6017154,11 N 549548,29 E 4006.98 .2442,04 N 2593,55W 6017169.46 N 549519.36 E 4014.93 2455.51 N 2621,88W 6017182,73 N 549490.93 E 4022.19 2466,42 N 2649,46W 6017193,44 N 549463.28 E 4030,13 2476.27 N 2680.55W 6017203.08 N 549432.12 E 4037,45 2484.66 N 2711,11W 6017211.26 N 549401.51 E 4043.56 2492.43 N 2741,18W 6017218,81N 549371.38 E 1.614 2.153 10.393 10.592 10.948 9.589 10.564 10.763 13.304 5.973 5.675 5.194 9.996 9.927 10.102 10.278 5.703 8.722 7.563 10.099 14.035 10.420 4.881 7.981 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 2923,64 2944,77 2945.39 2956.88 2979.82 30O3.39 3025.21 3052.78 3078.33 3104.44 3134.11 3161.95 3189.93 3220.74 3250.08 3281.65 3314.16 3346.81 3376.70 3409.43 3440.80 3470.35 35O2,57 3533.67 3564,06 Tie-on Survey Window Point (Whipstock) Continued... 14 December, 1999 - 13:42 - 2 - DrillQuest North Slope Alaska Measured Depth (ft) Incl. Azjm. Sub-Sea Depth (ft) Sperry-Sun,. Drilling Services Survey Report for MPJ-O9A YourRef:API-500292249501 RECEIVED Surveyed: 10 December, 1998 =: 'i 6 2.000 Vertical Depth (ft) 6065.89 84.170 284.190 3982.92 4048.24 6098.54 88,460 285,400 3985.02 4050.34 6128.92 92.800 285.230 3984.69 4050.01 6162.69 93.420 281.650 3982.85 4048.17 6195.72 94.530 278.610 3980.56 4045.88 6225.90 94.440 276,300 3978.20 4043.52 6263.23 93,330 273,950 3975.67 4040.99 6293.63 91,350 272.450 3974.43 4039.75 6324.41 90,550 271.590 3973.92 4039.24 6356.75 90.920 272.080 3973.51 4038.83 6389.68 '91.050 271.760 3972.94 4038.26 6412.30 91.420 272.160 3972.45 4037.77 6453.75 90.740 272.000 3971.67 4036,99 6486.48 88,370 271,750 3971.93 4037.25 6516.82 86,830 271.190 3973.20 4038,52 6551.79 85,100 270.100 3975.66 4040.98 6582.64 85,100 270.090 3978.29 4043.61 6612.86 85.280 '269,540 3980.83 4046.15 6650.20 85.660 269.330 3983.78 4049.10 6681.21 86.980 269,810 3985.77 4051.09 6710.69 88.550 269,730 3986.92 4052.24 6745.21 89.350 269.790 3987.55 4052.87 6777.87 89.320 270.000 3987.93 4053.25 6807.04 .89.170 270.210 3988.31 4053.63 6841.98 88.890 268.560 3988.90 4054.22 Ala a'Oil & Gas Cons. Commiaakm kldlO Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) ',' (ft) (ft) (ft) 2500.65 N 2773,89W 6017226.80 N 2508.97 N'. 2805.39W 6017234.90 N 2516.99 N, 2834,68W 6017242.72 N 2524.82 N 2867.47W 6017250.32 N 2530.62 N 2899,90W 6017255.89 N 2534.52 N 2929,73W 6017259.59 N 2537.85 N 2966,83W 6017262.65 N 2539.54 N 2997.15W 6017264.14 N 2540,63 N 3027.91W 6017265,01 N 2541,66 N 3060.23W 6017265.82 N 2542.77 N: 3093.13W 6017266.69 N 2543,54 N' 3115.74W 6017267.30 N 2545.05 N 3157.15W 6017268.52 N 2546.12 N 3189.86W 6017269.36 N 2546.89 N 3220.16W 6017269.93 N 2547.29 N 3255.04W 6017270.07 N 2547.34 N 3285.78W 6017269.91 N 2547.24 N 3315.89W 6017269.60 N 2546.87 N 3353.11W' 6017268.98 N 2546.64 N 3384.06W 6017268.53 N 2546.52 N 3413.51W 6017268.20 N 2546.38 N' 3448.03W 6017267.82 N 2546.32 N 3480.69W 6017267.53 N 2546.37 N 3509.85W 6017267.38 N 2546.00 N 3544.78W 6017266.76 N Dogleg Rate (°/100ft) 549338.61E 12.136 549307.06 E 13.650 549277.71 E 14,297 549244.87 E 10.743 549212.40 E 9,777 549182.54 E 7,636 549145.42 E 6,949 549115.09 E 8,169 549084.32 E 3.816 549052.00 E 1.898 549019.08 E 1.049 548996.48 E 2.409 548955.05 E 1.685 548922.34 E 7,281 548892.03 E 5.400 548857.15 E 5.843 548826.41E 0.032 548796.30 E 1.909 548759.08 E 1.162 548728.14 E 4.528 548698.69 E 5.333 548664.17 E 2,324 548631.52 E 0.649 548602.35 E 0.885 548567.42 E 4.789 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 3597.01 3628.92 3658.72 3691.57 3723.19 3751.64 3786.34 3814.25 3842.27 3871.67 3901.63 3922.22 3959.97 3989.74 4017.22 4048.63 4076.18 4103,10 4136,27 4163.87 4190.20 4221.04 4250.26 4276.40 4307.51 Continued... 14 December, 1999 - 13:42 - 3 - DrlllQuest North Slope Alaska I~leasured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for MPJ-O9A Your Ref: APl-500292249501 RECEIVED Surveyed: 10 December, 1998 6873.46 89.080 268.120 3989.46 4054.78 6903.44 89.910 267.830 3989.72 4055.04 6939.04 91.170. 268.070 3989.39 4054.71 6971.07 91.700 267.580 3988.59 4053.91 7001.32 91.690 267.100 3987.69 4053.01 7035.79 91.880 266.860 3986.62 4051.94 7069.20 92.490 267.290 3985.34 4050.66 7098..37 92.460 268.120 3984.08 4049.40 7133.28 90.520 267.040 3983.18 4048.50 7164.72 90.000 266.500 3983.03 4048.35 7192.29 88.340 265.940 3983.43 4048.75 7230.48 88.520 265.450 3984.48 4049.80 7263.49 88.150 264.580 3985.44 4050.76 .7288.97 88.710 264.190 3986.14 4051.46 7326.98 88.980 264.620 3986.90 4052.22 7358.66 89.910 264.500 3987.21 4052.53 7387.32 90.520 264.350 3987.10 4052.42 7422.81 90.710 264.540 3986.72 4052.04 7455.46 90.430 264.590 3986.40 4051.72 7483.90 91.380 264.630 3985.95 4051.27 7519.29 96.170 264.690 3983.62 4048.94 7552.17 98.240 265.530 3979.50 4044.82 7582.17 97.660 265.500 3975.35 4040.67 7614.58 95.770 264.810 3971.56 4036.88 7649.31 93.230 264.720 3968.83 4034.15 Local Coordinates Northings Eastings (ft) (ft) '~': :::~ '~ 6 2000' ~Oii & Gas Cons. C~mi~io~ ~or~e Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 2545.09 N 3576.25W 2544.03 N 3606.21W 2542.75 N 3641.78W 2541.54 N 3673.78W 2540.13 N 3703.98W 2538,32 N. 3738.39W 2536,62 N 3771.73W 2535,45 N 3800.85W 2533.98 N 3835.71W 2532.20 N 3867.10W 2530.39 N 3894.61W 2527.52 N 3932.68W 2524.65 N 3965.55W 2522.16 N 3990.90W 2518.46 N 4028.72W 2515.45 N 4060.25W 2512.67 N 4088.78W 2509.23 N 4124.10W 2506.14 N 4156.60W- 2503.47 N 4184.91W 2500.18 N 4220.06W 2497.40 N 4252.56W 2495.08 N 4282.18W 2492.36 N 4314.25W 2489.20 N 4348.73W 6017265.63 N 548535.97 E 1.522 6017264.36 N 548506.02 E 2.933 6017262.84 N 548470.45 E 3.603 6017261.40 N 548438.46 E 2.253 6017259.78 N 548408.27 E 1.586 6017257.73 N 548373.88 E 0.888 6017255.79 N 548340.55 E 2.233 6017254.42 N 548311.44 E 2.845 6017252.70 N 548276.58 E 6.360 6017250.71N' 548245.21E 2.384 6017248.70 N 548217.72 E 6.354 6017245.57 N 548179.67 E 1.366 6017242.47 N 548146.82 E 2.863 6017239.80 N 548121.49 E 2.678 6017235.83 N 548083.69 E 1.336 6017232.61N 548052.18 E 2.960 6017229.62 N 548023.68 E 2.192 6017225.94 N 547988.38 E 0.757 6017222.62 N 547955.90 E 0.871 6017219.75 N 547927.61 E 3.343 6017216.22 N 547892.48 E 13.536 6017213.21 N 547860.00 E 6.787 6017210.68 N 547830.40 E 1.936 6017207.74 N 547798.35 E 6.203 6017204.34 N 547763.90 E 7.318 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 4335.28 4361.64 4392.93 4421.04 4447.46 4477.46 4506.56 4532.12 4562.68 4590.o0 4613.83 4646.64 4674.80 4696.39 4728.61 4755.51 4779.81 4809.91 4837.64 4861.80 4891.82 4919.68 4945.17 4972.68 5002.15 Continued... 14 December, 1999 - 13:42 .4 - DrillQuest North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim, Depth Depth (ft) (ft) (ft) Your Ref: A PF500292249501 · '~m-.v m.,., m ,~ m.... ~ Surveyed: 10 December, 1998 Alaaka'~&~~s.~~ Alaska State Plane 4 Andtor~e Milne Point MPJ Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) Comment 7679.15 91.110 263.830 3967.70 4033.02 7714.07 91.110 264.340 3967.03 4032.35 7746.56 91.420 263.870 3966.31 4031.63 7776.98 90.460 263:540 3965.81 4031.13 7808.83 89.850 263.710 3965.72 4031.04 7845.63 88.620 264.320 3966.21 4031.53 7872.64 88.400 264.710 3966.92 4032.24 7906.04 87.810 263.330 3968.02 4033.34 7940.47 86.210 263.730 3969.82 4035.14 7969.52 85.290 263,260 3971.97 4037.29 8002.90 87,100 262,890 3974.18 4039.50 8035.86 88.310 263.570 3975.50 4040.82 8061.97 88,740 263,390 3976.18 4041.50 8100.14 88.520 262.300 3977.09 4042.41 8132.92 88,550 262,260 3977.93 4043.25 8156,41 88.680 262.310 3978,50 4043.82 8175.75 88,710 262.980 3978.94 4044.26 8235.00 88,710 262,980 3980.27 4045.59 2486.23 N 4378.39W 2482.63 N 4413.12W 2479.29 N 4445.43W 2475.96 N 4475.66W 2472.42 N 4507.32W 2468.59 N 4543.91. W 2466.01N 4570.79W 2462.53 N 4603.99W 2458.65 N 4638.15W 2455.37 N 4666.93W 2451.36 N 4700.00W 2447.47 N 4732.70W 2444.51 N 4758.63W 2439.76 N 4796.49W 2435.35 N 4828.97W 2432.20 N 4852.24W 2429.73 N' 4871.41W 2422.49 N 4930.20'W 6017201.16 N 547734.25 E 7,704 5027.39 6017197,32 N 547699.55 E 1.460 5056.89 6017193.76 N 547667.26 E 1.733 5084.33 6017190.21 N 547637.06 E 3.337 5109.92 6017186,45 N 547605.43 E 1.988 5136.69 6017182.36 N 547568.86 E 3.731 5167.75 6017179.59 N 547542.00 E 1,657 5190.67 6017175.88 N 547508.83 E 4,491 5218.85 6017171.77 N 547474.69 E 4.790 5247.72 6017168.28 N' 547445.93 E 3.554 5272.04 6017164.04 N 547412.90 E 5.534 5299.86 6017159.93 N 547380.23 E 4.210 5327.41 6017156.78 N 547354.31 E 1.785 5349.32 6017151.76 N 547316.49 E 2.912 5381.10 6017147.13 N 547284.05 E 0.153 5408.22 6017143.82 N 547260.80 E 0.593 5427.66 6017141.21 N 547241.64 E 3.467 5443.73 6017133.56 N 547182.90 E 0.000 5493.15 Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 296.430° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8235.00ft., The Bottom Hole Displacement is 5493.21ft., in the Direction of 296.168° (True). Continued,.. 14 December, 1999 - 13:42 - 5 - DrlllQuest Sperry-Sun Drilling Services Survey Report for MPJ-OgA Your Ref: API-500292249501 Surveyed: 10 December, 1998 North Slope Alaska Comments Measured Depth (.) 5300.34 5334.00 8235.00 Station Coordinates TVD Northings Eastings (fi) (ft) 3807.39 2066.19 N 2237.87W 3827.56 2090.57 N 2249.35W 4045.59 2422.49 N 4930.20W Comment Tie-on Survey Window Point (Whipstock) Projected Survey RECEIVED Al~JlcaOil & Gas Cons. Gommimiton ,And~or~e Alaska State Plane 4 Milne Point MPJ Survey tool program From , Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 8235.00 4045.59 Survey Tool Description MWD Magnetic 14 December, 1999 - 13:42 - 6 - DrillQuest To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPJ-09A, AK-MM-90203 January 27, 2000 MPJ-09A: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22495-01 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22495-01 Blueline Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHEII COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPJ-09A, AK-MM-90203 December 23, 1999 1 LDWG formatted Disc with verification listing. API#: 50-029-22495-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company Re: Milne Po/nt well J-09A PTD 99 - 114 :~-', Subject: Re: Milne Point well J-09A PTD 99 - 114 Date: Mort, 06 Dec 1999 08:28:28 -0900 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Mallary, Chuck (ARCO)" <MallarCR~bp.com> CC: Tom Maunder <torn_maunder~admin.state.ak.us> Chuck, This is as we agreed. Thanks for the record. Good Luck With the Well, Blair "Mallary, Chuck (ARCO)" wrote: > Mr. Wondzell, > Documenting our conversation of 5 Dec 1999, approximately 1:45 pm: > Preparations are underway to sidetrack Milne Point well J-09 with Nordic rig > 3. A cement retainer was set at 5360-ft wireline depth and we attempted to > establish injectivity through it for the purpose of placing cement across > gravel pack screens in the Schrader Bluff formation. Extremely low > injectivity was observed - pressuring up to 3000 psi we recorded only 200 > psi bleed off in 10 minutes. > Our proposal at this point was to abandon attempts to place cement below the > retainer. We believe that placing cement on top of the retainer is not > indicated in this instance, because: (1) A 4-1/2" slotted/solid liner will > be run in this well, with the solid portion extending from the top of the > productive zone (OA sand) to at least 150-ft above the window; (2) an > external casing packer will be set at the base of the solid liner and cement > placed up into the the liner lap; (3) A liner top packer will be set and > tested at the top of the liner. > respectfully, 0 ~ > Sr. Drilling Engineer, WNS/ENS > Shared Services Drilling > (907) 564-5061 1 of 1 12/6/99 9:14 AM TONY KNOWLE$, GOVERNOR ALAS OILAND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Charles Mallary Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re ~ Milne Point Unit MPJ-09A BP Exploration (Alaska), Inc. Permit No: 199-114 Sur Loc: 23472NSL, 2090'EWL, SEC. 28, T13N, R10E. UM Btmhole Loc. 4839'NSL. 2921~WEL. SEC. 29. TI3N. R10E. UM Dear Mr. Mallarv: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. / ,,,;, Robert N. Christenson. P. E. Chairman BY ORDER OF y_~ COMMISSION DATED this ]-~ ~ day of November, 1999. dlf/Enclosures cc: Department of Fish & Game. Habitat Section w. o encl. Department of Environmental Conservation w o encl. .... . STATE OF ALASKA ALASH. ,.)IL AND GAS CONSERVATION CCi PERMIT TO DRILL 20 AAC 25.005 ISSION la. Type of work I--lDrill l~Redrill IlL. Type of well I-IExploratory I-IStratigraphicTest I~ Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator !5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 65.50' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2347' NSL, 2090' EWL, SEC. 28, T13N, R10E Milne Point Unit At top of productive interval !8. Well Number Number 2S100302630-277 4724' NSL, 620' WEL, SEC. 29, T13N, R10E MPJ-09A At total depth 9. Approximate spud date Amount $200,000.00 4839' NSL, 2921' WEL, SEC. 29, T13N, R10E 11/22/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025515. 441' MDI 237' from MPJ-19 at 7320' MD 2560 8270' MD / 4035' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 5366' MD Maximum Hole Angle 93° Maximum surface 1340 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3069' 5200' 3738' 8269' 4035' 50 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Cement plug at 10083' (4/97) Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) 5' Perforated Sub, XO Sub, three 2-3/4" seal units and ball true vertical feet seat assembly left in frac pack assembly at 5468' (10/98) Casing Length Size Cemented MD TVD Structural Conductor 80' 13-3/8" 250 sx Arcticset (Approx.) 112' 112' Surface 2905' 9-5/8" 572 sx PF 'E', 250 sx 'G' 2936' 2529' Intermediate ~. Production 10811' 7" 400 sx Class 'G' 10840' 7479' Liner :, _ . ~ -.;,,,: -; ., Perforation depth: measured 5460'- 5480', 5680'- 5700', 5780'- 5800' (open) 10328' - 10342', 10355' - 10361', 10442' - 10462', 10475' - 10507' (squeezed) true vertical 3905' - 3917', 4047' - 4060', 4114' - 4127' (open) 7049'- 7061', 7072' - 7077', 7144' - 7161', 7172' - 7198' (squeezed) "~0. 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: Fred Johnson, 564-5427 Mik Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certiC~:hat)~ foregoing, l~/{'~e and correct to the best of my knowledge Charles Mall(a/y~-''''` / ~'' ~"~~~ Title Senior Drilling Engineer Date er~ Commission Use Only Permit Number ' ' APl Numb J /, .~ro~a~Date I See cover letter //'~"//¢ I 50'029'22495'01 l ld for other requirements Conditions of Approval: Samples Required [] Yes ]~No Mud Log R quir [] Yes J~No Hydrogen Sulfide Measures []Yes I~'No Directional Survey Required ,~Yes I-] No Required Working Pressure for BOPE I-'I2K; 1'-13K; []4K; 1~5K; [] 10K; [] 15K Other: .~'z.~, '¥~c.~-k- ~"",c~>,~,~ ~ '~(~JC:) ~ ORIGINAL SIGNED.BY by order of., Approved By Robert N. Christell$Orl Commissioner the commission Date /i/-(/~ "' )-) Form 10-401 Rev. 12-01-85 Submit In Triplicate Current Well Information Well Name: APl Number: Well Type: Current Status: Last H2S Sample: Cement: TD / PBTD: BHP: BHT: Is this well frac'd? MPJ-09 50-029-22495 Shrader Bluff Producer All open perf's P & A'd 0 ppm TOC planned to be at top of 7" window at 5,350'. Liner top at 5,200'. 8,269' / 8,269' 1,850 psi Schader Bluff 'OA' sand. Estimated from shut-in pressure & offset wells 80°F@ 4,020' ss Estimated No Mechanical Condition: MPJ-01 Wellhead: Nordic 3: Tubing: Liner: Casing: Casing Head: Casing Hanger: 7" Packoff: Tubing Spool: Tbg. Hanger: Tree: Cellar Box MSL = 34.7' KB / MSL = 65.5' 3-1/2% 9.3#, L-80, EUE 8rd kill string at 5324' None Conductor: 112', 13 3/8", 54.5#, K-55, BTC Welded Surface: 2,936', 9-5/8", 40#, L-80, BTC Production: 10,840', 7", 26#, L-80, BTC WKM 10 3,¢ BTC x 11 ", 5M 7" WKM Mandrel WKM Mandrel type FMC Gen 5, 11" x 11", 5M FMC 11" x 3-1/2" NSCT top and btm. ESP and heat trace penetrator prep. 3", 'H' type BPV profile Cameron 5M, 3-1/8" open Perfs: :open peals in 5460~,5;802, (Fish s!,uck in gravel pack packer at 5470' ~bi~ig; FlUidS: ::~ ;: :; ~ S~:~i~h dieset cap down to -2000 AnnuluS;FlUidS::;;; ::;; :sW :~ith;diesel;cap d°wn t° -2000' Target Estimates: Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Materials Needed: L-80 Intermediate: Expected reserves 1.3 mmbbl Production rate: 1,000 b/d Production rate: 1,000 b/d L-80 Production: L-80 Completion: 764' 2,305' 7" x 4-1/2" 4-1/2" 20 - 4-5/8" x 5 7/8" x 8" 5,100' ESPCP 2 - 3-1/2x1" 5,100' 2,265' 5100' BHP Gauge 4.5", 12.6#, L-80, IBT-Mod Slotted Liner 4.5", 12.6#, L-80, IBT-Mod Solid Liner Baker liner top hanger / packer Halliburton Guide Shoe Rigid Straight Blade Centralizers 3-1/2", 9.3#, L-80, 8rd EUE tubing Grade B Centrilift Sidepocket GLM's Centrilift #4 flat cable Raychem heat trace Baker TEC Wire Baker Sentry Gauge JWell Name: IMPJ-09A I Well Plan Summary J Type of Well (producer or injector): I Producer I Surface Location: 2347' NSL, 2090' EWL, Sec. 28, T13N, R10E X = 552,129.93 Y = 6,014,745.62 Target Start: 4724' NSL, 620' WEL, Sec. 29, T13N, R10E X = 549,397.00 Y = 6,017,104.00 Z = 3,985' TVDss Intermediate Target End: 4839' NSL, 2921' WEL, Sec. 29, T13N, R10E X = 547,095.00 Y = 6,017,205.00 Z = 3,970' TVDss I AFE Number: 1337171 I I Rig: I Nordic 3 I Estimated Start Date: I Nov 22, 1999 I I Operating days to complete: I 14.5 I MD 18,270' J I TVDrkb: 14,035' J IEEE: Well Design (cOnventiOnal' slim hOle'etc.): IEXtended HOrizOntal Sidetrack 165.50' Objective: Sidetrack out of existing 26#, 7" csg into the Ugnu Formation, directionally drill 6 1/8" hole thru the Ugnu ,formation, land horizontally in the Schrader Bluff 'OA' sands. Geosteer horizontally through the OA target sands to TD at 8,270' MD. Run, cmt and test a 4 1/2" Banzai (slotted/solid) liner, complete with an ESPCP pump, 3-1/2", L-80, EUE tubing. Drilling Hazards and Contin_qencies 1) Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diver[er Prior to spud, per crew Once per week per crew while drilling with diver[er in place. D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when openhole sections are exposed. · IN ALL CASES, ENSURE THAT THE DRILLS ARE CAREFULLY CARRIED OUT AND DO NOT EXPOSE EQUIPMENT, CASING OR FORMATION TO EXCESSIVE PRESSURES AND LOADS. · See BP Well Control Manual for all details of these drills. 2) 3) Hydrogen Sulfide · MP J Pad is not designated as an H2S Pad. Kick tolerance · The kiCk:t°leranCe f°r the6 1/81!open h°le SectiOnlwoUld be 32 bbls assuming an influx at the 8269' TD in. the Schrader OA:formation. This is a worst case scenario based on a 8.8 ppg pore reSS~re gradibnt i~ the tbPOf the ~r°dUCtion:section and a minimum fracture gradient of 12.5 Pg 5elov~ th ~ '9 5/8!!: ~brfa~e c~si n~ sh°e:with: a9:4 PPg mud in the hole. · LOT at the 9 5/8" shoe after the original drill out: 12.5 ppg EMW 4) Breathing · No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. s) 6) Lost Circulation · One fault is possible in the target at 7600' MD, 3968' TVDss · Follow the LOST CIRCULATION DECISION MATRIX if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Faults · One fault is possible in the target at 7600' MD, 3968' TVDss. 7) 8) Hydrocarbons · Will be kicking off below the Ugnu interval, therefore the first possible hydrocarbon zone will be the Schrader Bluff 'NA' sand at @ 5,400' MD, 3,802' TVDss. Geosteering · (2) rig site geologists are required onsite for accurate geosteering through the thin OA sands 9) Pad Data Sheet · Please Read the J-Pad Data Sheet thoroughly. Drillin Pro ram Overview Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPJ-01A. Close Approach Wells: To be determined. IWell Name I Current Status Production Priority Precautions I I Well Control: Expected Formation Pressures & BOPE Test Pressures Expected BHP 1,800 psi, 4,000' TVDss (estimated) Max Exp Surface Pressure 1,340 psi (.115 psi/ft gas gradient) BOPE Rating 5,000 psi WP (entire stack & valves) Planned BOPE Test Pres. 3,500/250 psi Rams and Valves 2,500/250 psi Annular Mud Program Production Mud Properties: 9% KCL BaraDriln I 6 1/8" hole section Density (PPg) I Funnel vis YP I HTHP I 9.6 40 - 55 20 - 27 10 - 15 pHI APl Filtrate I LG Solids 8.0 - 8.5 4 - 6 < 15 ppb NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or ARCO KRU 1R. Formation Markers Formation Tops MD TVDss Pore Psi EMW(ppg) Comments TUZC NP TUZB NP Planned Kick Off Point KOP 536O 3782 NA 5400 3802 8.9 NB 5456 3832 8.9 NC 5523 3867 8.9 NE 5572 3890 8.9 NF 5700 3940 8.9 TOA 5964 3977 8.9 Top OA sand. Set ECPinthe sand TD 8269 3970 8.9 Casing/Tubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/'FVD 6 1/8" 4 1/2" 12.6# L-80 IBT-Mod 3,069' 5,200'/3,738' 8,269¥4035' Banzai Tubing 3-1/2" 69.3# L-80 EUE 8rd 5,100' 30'/30' 5100'/3,682' w/ESPCP Cement Calculations ILiner Size J 4 Y2" Banzai IBT-Mod I BasisI 0% excess in o ~en hole (6 1/8" hole), No cement in liner lap (7" casing) or above liner top (3 ~" dp) I ECP 5,964' MD 4,050 TVDrkb), Window at 5,350' (3,847'), Liner top at 5,200' (3,738') Total Cement Spacer None if well displaced to completion fluid. Contingency 15 bbls of B45 Volume: Viscosified Spacer Weighted to 10.2 ppg if cementing in mud Tail 50 sxs, Class 'G'+ .30%D65 + .5%S001 + .4% D167 + .2% D046 Temp BHST -80° F from SOR, BHCT 85° F estimated by' Dowell Centralizer Placement: 1. Run (2) rigid straight centralizer per joint'first 300' above the ECP 2. Run (1) rigid straight centralizer per joint to the window. 2. Run each single centralizer in the middle of each joint of casing. Other Cement Considerations: 1. Batch mix this single slurry. Survey and Logging Program 6 1/8" Section: Open Hole: MWD / GR/Res / PWD - Over production interval. Sample Catchers - None! Cased Hole: None Perforating: None Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzle / Flow Rate K-Rev's Hours Number and Section I 6 1/8" 5,350' - 8,269 PDC 15-15-15: 250+ gpm - - Motors and Required Doglegs BHA Motor Size and Motor Flow Rate RPM's Required Doglegs Number Required I 4 3/4" Sperrydrill 4/5, 6.3 stg Slow 250 - 300 gpm 75 mtr, 60 Build out of window at (PDC) Speed, 1.15° adj w/5.9" sleeve rotate 12°/100 to horizontal. Drill to TD. MPJ-09A Operations Summary Pre-Ric~ Operations li ~Test7' packoff Snapshot of Well Proc~ram 1. MIRU Nordic 3. 2. Circ well. ND Tree, NU Stack and Test. 3. POOH w/3-1/2" tbg. Note: Plan to rerun 3-1/2" tbg, tubing hanger, tree. 4. RU E-line. Set EZSV on EL @ 5360'. Note: EZSV to be used as base for setting whipstock. EZSV must be set so that window is not milled thru 7" casing coupling 5. RIH with stinger. Cmt sqz existing perfs. Circ hole clean on top of EZSV. POOH 6. Run and set whipstock on EZSV. Mill window. 7. MU 6 1/8" BHA. RIH. 8. Drill 6-1/8" hole. Build angle and steer to land horizontal in OA sand. 9. Displace hole to new BARADRILn mud. Drill horizontal section. 10. Run 4-1/2" Bonzai liner and inner string. 11. Displace hole to 9.0 KCL completion fluid thru inner string 12. Spot Starch Enzyme in 4-1/2" x 6-1/8" open hole annulus 13. PU and displace liner to completion fluid and spot enzyme in liner if required. 14. Inflate ECP and cement top liner interval above slotted liner. Circ. POOH. 15. Run 2-7/8" ESP completion with Raychem heat trace and Baker Sentry gauge with TEC wire, 16. ND BOPE, NU tree. Release rig. Tree: 3-1/2", 5M Wellhead: FMC G 5 11" 5m Tbg head FMC w/ 11" x 3-1/2" tbg. hnr. w/ NSCT and 3"" CIW H BPV profile WKM 11" 5m csg Head 13-3/8" 54.5 ppf, K55 I 112' I I I MPU J-09 Orig. KB Elev. -- 46.6' (N 22E) Orig. GL Elev. = 17.0 ' RT To Tbg. Spool = 28.8' (N 22E) KOP @ 6OO' Max. hole angle = 52 to 59 deg. f/ 2,500' to 9,500' Hole angle thru' perfs = 33 deg DLS = 6.6 deg./100' @ 9,750' 9 5/8", 40 ppf, L-80 Btrc. 12,936' md I PRESENT CONDITION 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151" cap. = 0.0383 bpf ) 3.5", 9.2# L-80 EUE 8rd tbg I 5324' Stimulation Summary N-Sand frac pack: 9/29/98 - 93.4 M# 16/20 carbolite behind screens. OA Sand PropLok Frac: 9/26/98 - 48.5 M# of resin coated16/20 Carbolite behind pipe. OB Sand PropLok Frac: 9/26/98 - 99.8 M# of resin coated 16/20 Carbolite behind pipe. Perforation Summary Ref log: 4/18/97 CBT/GR/CCL Size I SPF 4.5" 15&4 4.5" /4 4.5" Interval (TVD) 'N'Sand 5460'-5480'3 'OA'Sand 5680'-5700' OB'Sand 5780'-5802' 4 t38'-3853' 4047'-4060' 122'-4135' IInitial ped's. SWS 37 gr. RDX 51B 'big hole' charges, 72 deg. phasing. Lastest perf's 9/22J98: SWS HSD 430 UP (big hole). Abandoned Perforations 4" 14 1~,328' - 10,342' (7p49'-7081') 4" 14 1~,355' - 10,361' (7p72'-7077') 4" 14 1~,442' - 10,462' (71144'-7161') 4" 14 lf,475' - 10,507' (7~ 72'-7199') Fish left in frac pack assembly. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: DATE 1 -14-95 REV. BY COMMENTS Drilled cased Nabors 22E 2-15-95 Completion Nabors 4 ES See fishing folder in well file for detail of fish. 7" HESVersatrievepkr. I 5395' I Closing sleeve ass'bly I 5401' I 3.5", 9.2 ppf, N-80, LTC blank pipe (ID =2.991") [ 5426' I 3.5", 0.02" Ga. welded - screen (ID =2.991") I 5455' I 'lIES Honed Tube (ID = 2.75")~"~;-~ 15485'1 End of assembly I 5494' I HES 7" 'BBI' packer 5580' 7" HES BBI BBI packer I 5725' 7"HES Fas Drill bridge plug I 5815' I 7" Howco ES cementer I 6018' I Tubing chemical cut at 9893' (14' above collar) Partial jet cutter cut @ 9990' J 10,019' I 7"x 3.5" SABL-3 Baker Pkr. I 3.5" WLEG 10,068' TOC tagged @ 10,083' 4/13/97 7" float collar I 10,797' I MILNE POINT UNIT WELL J-09 APl NO: 50-029-22495 Tree:3-1/8", 5M J-09 Orig. KBElev.= 46.6' '--~E) Wellhead: FMC Gen 511" x 11" 5M Orig. GL Elev. = 17.0 ' Tbg Head w/3-1/2" ESP/HT tbg. hnr. RT To Tbg. Spool = 28.8' (N 22E) w/ NSCT threads top and bottom and 3" CIW H BPV profile. Wellhead is WKM11"5m i 112, i~ 13-3/8" 54.5 ppf, K-55 i KOP @ 600' Proposed P&A Status I Max. hole angle = 52 to 59 deg. f/ Prior to Sidetrack J 2,500' to 9,500' Hole angle thru' perfs = 33 deg DLS = 6.6 deg./100' @ 9,750' 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151" cap. = 0.0383 bpf ) 3.5", 9.2# L-80 EUE 8rd tbg I I Stimulation Summary. N-Sand frac Deck: 9/29/98 - 93.4 M# Cmt Retainer at 5360' 16/20 carbolite behind screens ..................................... OA Sand ProDLok Frac: 9/26/98 - 48.5 M# of resin coated16/20 Carbolite ~iii~iii!~ii~ii X 7" HES Versatrieve pkr. I 5395' ................... ~ Closing sleeve ass'bly I 5401' behind pipe. ' i~!i!i~ili;~iiii OB Sand ProoLok Frac: 9/26/98 - ~ :: iil;i::~i¢!::~i:::, i: 3.5", 9.2 ppf, N-80, LTC I 5426' J 99.8 M# of resin coated 16/20 Carbolite :i: ~ii~i: ; blank pipe (ID =2.991") '~!~;: ............... 3.5", 0.02" Ga. welded behind pipe. : : ~i~i~!~l : I 5455' J~~:'"'""'""~i' ~ screen (ID =2.991 ") Perforation Summary ~ : HES Honed Tube (ID = 2.75")1 ~485' I Ref Icg: 4/18/97 CBT/GR/CCL :: ~ - I 5485' I ~ En~ of assembly I 5494' Size SPF Interval (TVD) Fish Suck 'N' Sand in Packer HES 7" 'BBI' packer 5580' 4.5" 5&4 5460'-5480' 3~38'-3853' 'CA' Sand ~ 4.5" 4 5680'-5700' 4047'-4060' ~ OB' Sand =~!!~i~!~,17" HES BBI BBI packer 15725' 4.5" 5&4 5780'-5802' 4122'-4135' Initial perf's. ~] SWS 37 gr. RDX 51B 'big hole' charges, ~, 7" HES Fas Drill bridge plug I 5815' Lastest perf's 9/22/98: i ) 7" Howco ES cementer I 6018' SWS HSD 43C UP (big hole). Tubing chemical cut at 9893' (14' above collar) Abandoned Perforations ~ Partial jet cutter cut @ 9990' 110,019' 7"x 3.5' SABL-3 Baker Pkr. :i:~:i:~:i:~:i:i:i:i:i:i:i:i:i:i:i:i:~:i:i~:i:i:i~:~:~:i:~:~:!: 3.5" WLEG I 10,068' Size SPF Interval (TVD)~~ii!~~!!!ii!!i!;ii[TOctaggod @ 10'083' 4/13/977" float collar ' 4" 4 1 t,328'- 10,342' (7349'-7081') 10,797' I 4" !4 1 ~,355' 10,361' (7372'-7077') ~ I I ' 7" float shoe 110,840' I DATE REV. BY COMMENTS MILNE POINT UNIT 1 -14-95 Drilled cased Nabors 22E 2-15-95 Completion Nabors 4 ES WELL J-09 04 / 19/97 JBF S ;hrader Bluff Re-completion by Nabors 4ES 08/15/97 M.Linder Schrader Bluff sand test #2 BP EXPLORATION (AK TREE: Cameron 3-1/8" 5M , WELLHEAD: FMC Gen 5 11" x 11 ", 5M tbg. hea¢ 11" x 3-1/2", NSCT (top & btm) ESP, HT FMC tbg. hanger, 'H' BPV profile Csg head is WKM 11" 5m I 1'~2~ I 13-3/8", 54.5 #/ft, L-80, Welded 3-1/2", 9.3#, L-80, 8rd EUE * ( Run Used Tbg. From Whse Inventory) Drift. I.D.: 2.992" Capacity: .0087 bbl/ft Centrilift ~4 Flat cable 7", 26#, L-80, BTC Drift. I.D.: 6.151" Capacity: .0383 bbl/ft Window in 7" casing @ 5,350' DATE Cement retainer at 5360' All Perforations P & A'd PBTD I 5~815' I TD I I 0~840' I REV. BY COMMENTS 11/6/99 FJ Horizontal Sidetrack KB. ELEV = 65.50' Cellar Box ELEV = 34.70' 3-1/2"xl"sidepocketGLM J ']24wI Raychem Heat Trace Baker TEC Wire 3-1/2" x 1" sidepocket GLM Centrilift ESPCP I 5,100' J Baker Sentry Gauge + TEC 7"x 4 1/2" liner/hgr pkr. Baker ECP (top of 'OA' sand) 4 1/2" liner TD 5,964' 8,269' 4-1/2", 12.6# L-80, Banzai Liner Top packer at 5395' Milne Point Ul~it WELL: J-09A APl NO: 50-029- 22495-01 par, r', j-sun DrillQ MPJ-0OA Wp8 uest Scale: linch = 400ft Eastings -4800 -4400 -4000 -3600 -3200 -2800 -2400 -2000 I I I I I I I I, 2800 - - 2800 Total D~ ,: 8268.69ff MD, 4034.65ff TVD .,~' r- ~D, 4049.80ft T VD 'F 2400 - ~,.z-o~n r4 f]..tyz)- roi,t · o~.0o 2~o ..../ 2400 o I : z I :~nrj-v~n t-o~y ljune~l . Dir Rate Increase @ 11.315°/100ft: 5390-~- "~.0o ..00ff MD, 3860.~ i . 2000 - -- 2000 ,r'-' I I I I I I I -4800 -4400 -4000 -3600 -3200 -2800 -2400 -2000 Scale: linch = 400ft Eastin.qs Reference is lrue North Current Well Properties Proposal Data for MPJ-09A Wp8 s~g~ We, Tarot Oa~a for Well: MPJ-09A Vertical Origin: Well ! Moa~r~t ~: Horizontal Origin: Well Coo~l~te Horizontal Coordinates: Measurement Units: ft ~.~T~"t 1~ I'VO Ref. Global Coordinates: 6014744.52 N, 552129.11 E North Reference: True North Ref. Structure RefereoCe : 1324.40 N, 70~.30 E MPI-09AFmkl Ena-y Po~ 0.O~ 64.80 2,452.09 N 43~7.07W ~OI?I~6.00N 547745.00 E I~ Ref. Geographical Coordinates: 70° 27" 03.6739' N, 149' 34' 28.8496' W Dogleg sevedty: Degrees I~r lOOft Vertical Secfio~ Azimuth: 297.035e Bo~ Point ~ o.oo 64.80 25:~1.95 N 4~.44~37 w 60172~S.00 N ~47'/65.o0 E 4336.37 W 0.00 6017-2~00 lq ~.IT~ ~.00 £ RKB l:loYation: 04.80ff ahoY0 Mean ~a Loyef V~*tical $~-'tion ~cription:Well ¢ 0.00 ~.~0 2~2.2~ zq a~?.7* w ~0~0~.00 ~ ~rr~.oo £ Ol.80tt abovo 8tmcturo Referonc~ ¥0,tical ,~:tion Or, in: 0.00 N.O.00 £ z> 0.00 ~0 2~2.~ M~asur~ Incl. Azlm. ¥~'tlc~l Northlng,, ~tlngs ¥~tle~l l:~j l~j ~^ ~0,,,~2~ r.~ ~oi~ 0.00 ~ zuo.o~ ~ Nodh Roforotmo: True North D~th D,~pth ,~tlotz Rate ~,/I~^ 0.00 ~.~0 22~.0~ ,~.~w ~t~,~o.oo~ s~?no.oo£ Units: Feet 5360.00 52.(K}0 334.292 3843.0g 2109.63 N 2258.46 W 2970.58 [a o.oo 6~.so zzl~.o~ t~ 2wo.r~ w 6at o;,4o.oo ~ ~2~.oo E DC 64.1o 2045...~9 N ~295.16 W 0.0o 6016T/4.00 N 549~ 19.o0 E 539~.00 54.922 331.936 3860.82 2131.20 N 2269.40 W 2990.14 10.000 i o.oo 64.so 5964.21 89.344 272.534 4049.80 237g.2g N 2715.61 W 3499.90 !1315 EF 0.0o 64J0 0.00 64J0 Zl93.03 N 4929.00 W ~017603.00 N ~47 Il0.00 E 6400.47 $9.~43 272.537 4054.$0 2397.58 N 3151.42 W 3896.85 0.001 7489.55 92.762 272.475 4034.$0 2445.19 N 4239.11 W 4857.33 0.~14 [ I4PJ.o9^ TI 0~h, ;) F,,~ I~o~ :~0.oo ~,o44 Jo Z~IZO9 ~ 8118.69 $~. 149 274.523 4029.$0 2483.58 N 4~5.~5 W 54~3.93 0.802 8268.69 88.149 274.523 4034.65 2495.41 N 5016.31 W 5602.72 0.000 MIU-09AI~ (~1) ~Polm ~90.00 4054~0 ~ '~ Tie-on Start Dir @ 10.000°/10Oft: 5360.00ft MD, 3843.08ft TVD }a'~m^T40.~ F-..~,i~ ~.00 40~.S0 __1~(~ ' ....~.. ,~'r Rate Increase @ 11.315°/100ft: 5390.00ft MO. 3860.82ft TVO ...... (D II ~ ,- :::::::::::::::::::::::::::::::: ~. ?~:4~.~ 1~10;~((/.~ ~ i~:~.~:~K~l~;'.4~:~.¢'.og~lOllllZilllll::lllZll::::: '.c.~.(~( ~ :0.'..~.bg:o,:. (..~. :::L4.~.E~.~Z&b:.Z4~. ~; .~. ~. ~ ~ l ~;~ ~ o ........... -,%% ................... ,7 ........................ ~ ~'s't,~;. '~' 8;:~f,i~/~ ~ i ~'dd.~.~t' i,.,f¢; ~,b'r;4.~' 'i~'¢ ....... '.~ ......................................... ~,~- :~¢.~:~ "~o'- '"' ..... ~ ............. / ....................... / ........................................................ c/ .......................... ~,~ ............ 400O ~F- TVD "-- ....... ~ ...... ~ ;= =/=~x~ ................ -~/ .............................. ~x',~ ~ ............. --" - .................... r~ ~ ~.~,~ ~_¥., ~ ..... '~ .... T3BC@TD-403<SOTVD ~X, MPJ-O~A TI (Jury 1) MPJ-O~A I'2 (July1) - Point MPJ-~A TS (Julyl) - Poi~ MPJ-O~A T4 (Jutyl) - Poi~ Tnt=~ r~,,th - n~c--~ ~off Mn anP, z ~ 0 ",~ Not Hit 4054.80 TVD 4034.80 TVO 4029.80 TVD ....... ~' ..................... TVD CI') . -'on% 2397.58 N~ 3151.42 W 2445.19 N, 4239.11 W 2483.58 N, 4866.86 W I I I I I I 3200 31500 4000 4400 4800 5200 5600 Scale: linch = 40Oft Vertical Section Section Azimuth: 297.035° (True North) Sperry-Sun Drilling Services Proposal Report for MPJ-O9A Wp8 Revised: 19 July, 1999 Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100fi) (fi) 5360.00 52.600 334.292 3782.37 3847,17 2103.23 N 2264.37W 5390.00 54.922 331.936 3796.02 3860.82 2131.20 N 2269.40W 5400.46 55.299 330.569 3802.00 3866.80 2138.72 N 2273.53W 5456.48 57.570 323.464 3833.00 3897.80 2177.81 N 2298.95W 5522.72 60.738 315.549 3867.00 3931.80 2220.96 N 2335.88W 5571.77 63.370 310.017 3890.00 3954.80 2250.36 N 2367.68W 5700.82 71.185 296.626 3940,00 4004.80 231'5.17 N 2466.98W 5964.21 89.344 272.534 3985.00 4049.80 2378.28 N 2715.61W 6000.00 89.344 272.534 3985.41 4050.21 2379.87 N 2751.37W 6400.47 89.343 272.537 3990.00 4054.80 2397.58 N 3151.42W 6016831.85 N 549850.08 E 2964.13 6016859.79 N 549844.86 E 10.000 2981.10 6016867.28 N 549840.68 E 11.315 2988.14 6016906.20 N 549814.99 E 11.315 3028.31 6016949.09 N 549777.76 E 11.315 3080.59 6016978.26 N 549745.75 E 11.315 3122.16 6017042.37 N 549646.00 E 11.315 3239.93 6017103.75 N 549396.93 E 11.315 3490.65 · 6q17105.08 N 549361.17 E 0.001 3523.37 6017120.00 N 548961.00 E 0.001 3889.44 7000.00 91.225 272.503 3987.03 4051.83 2423.94 N 3750.33W 7489.55 92.762 272.475 3970.00 4034.80 2445.19 N 4239.11W 8000.00 89.019 274.137 3962.07 4026.87 2474.63 N 4748.54W 8118.69 88.149 274.523 3965.00 4029.80 2483.58 N 4866.86W 8268.69 88.149 274.523 3969.85 4034.65 2495.41 N 5016.31W 6017142.17 N 548361.91E 0.314 4437.41 6017160.00 N 547873.00 E 0.314 4884.50 6017185.87 N 547363.38 E 0.802 5353.72 6017194.00 N 547245.00 E 0.802 5463.64 6017204.78 N 547095.47 E 0.000 5602.72 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 MILNEPT MPJ Comment Tie-on, Start Dir @ 10.000°/100ft: 5360.00ft MD, 3843.08ft TVD Dir Rate Increase @ 11.315°/100ft: 5390.00ft MD, 3860.82ft TVD NA NB NC NE NF Geosteer @ 0.001°/100ft: 5964.21ft MD, 4049.80ft TVD Geosteer @ 0.314°/100ft · 6400.47ft MD, 4054.80ft TVD Target- MPJ-09A T2 (July1) Geosteer @ 0.802°/100ft · 7489.55ft MD, 4034.80ft TVD Target- MPJ-09A T3 (July1) Target - MPJ-09A T4 (July1) Total Depth · 8268.69ft MD, 3969.85ft 'I'VD The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 296.448° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8268.69ft., The Bottom Hole Displacement is 5602.72ft., in the Direction of 296.448° (True). Continued... 19 July, 1999 - 15:30 - 2 - DrillQuest VEN~n ALASKAST14 ,, DATE 'INVOICE/CREDIT MEMO DEscRIPI~ioN GROss. DISCOUNT NE1: ...... 1 O;27c)c2 Cl~ ! OP7c2c2D .... 1 OO. OO 1 OO. OO HANDL]'NG INST: $/H TERRIE HUBBEE X46;28 rilE &TI'ACHED CHECK IS IN PAY~.N'T FOR ~EMS DE~Hi~ED ABOVE. ml[e]filll ] 100, OO ,1 OO_ OO :. BP EXPLORATION (ALASKA),.:.INC. ' i: ~i :'P.O,'BOX;196612 :.' :i:i~ :~: :::::: ::::~:::~: ~:: AN~HORAGEi:ALASKA~' 99519-6612,2,:. .'::?':!' ..'~.: :,.' ..:::. 'FIRST NATIoNALBANI( :OF AsHLaND '! '.:'i: ' ? ,:A~',AI~FILIATE O~ ::.:::~'~ '" :. :~::: .: ' NATIONA~:Ci~ B~K ' .:: CLEVELAND, OHiO :. , :: · :~.::: 56-389. i: ] :; 412 No., :H ::...1 581 9.1: coMM E.C,AL. ACCOU.T ' CONSO,,~,,r~D::~::., :.... '.i::. 'i:i:i: i.::. · "00158:1~ 1 :': PAY ORDER ::: .: · . ::.'~ :: :L ':!~ ::' .i!: :: :.'::. :'~ :::' .: i:i:' :' DATE :; '.'. .':': .:AMOUNT l :!'0/28/c?* l~ i "' :ALASKA ST^TE':DEPT..OF REVENUE .:::" .? ::':'..' :.::'? 3001 ;PORCUP I NE ':' DR ·. · : .: :..... ..:. . :,. . .. .: ANCHORAOE AK ~501-3120 $100.00 ," ;i, 5,°, l,q l,," ~:13h l, aO ~,,°,q Sm'- OORm.,h l,q," STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C( MISSION APPLICATION FOR SUNDRY APPROVAL 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 1. Type of Request: .'~ Abandon [] Suspend [] Plugging [] Time Extension [] Perforate ~, Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. I [] Development KBE = 65.06' : [] Exploratory 7. Unit or Property Name E~ Stratigraphic Milne Point Unit [--I Service 4. Location of well at surface 2347' NSL, 2090' EWL, SEC. 28, T13N, R10E At top of productive interval 4522' NSL, 200' WEL, SEC. 29, T13N, R10E At effective depth 2495' NSL, 1523' WEL, SEC. 20, T13N, R10E At total depth 2912' NSL, 1616' WEL, SEC. 20, T13N, R10E 8. Well Number MPJ-09 9. Permit Number 194-101 10. APl Number 50- 029-22495 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 10860 true vertical 7431 Effective depth: measured 10083 true vertical 6693 Casing Length Structural Conductor 80' Surface 2905' Intermediate Production 10811' Liner feet Plugs (measured) feet feet Junk (measured) feet Cement plug at 10083' (4/97) 5' Perforated Sub, XO Sub, three 2-3/4" seal units and ball seat assembly left in frac pack assembly at 5468' (10/98) Size Cemented MD TVD 13-3/8" 250 sx Arcticset (Approx.) 112' 112' 9-5/8" 572 sx PF 'E', 250 sx 'G' 2936' 2529' 7" 400 sx Class 'G' 10840' 7479' Perforation depth: measured 5460'- 5480', 5680'- 5700', 5780'- 5800' (open) 10328' - 10342', 10355' - 10361', 10442' - 10462', 10475' - 10507' (squeezed} true vertical 3905' - 3917', 4047' - 4060', 4114' - 4127' (open) 7049' - 7061', 7072'- 7077', 7144'- 7161', 7172'- 7198' (squeezed} Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, EUE 8rd tubing to 5324' Packers and SSSV (type and measured depth) Sand Frac Pack Assembly with a 7' HES Versatrieve packer at 5395' and a 7" HES 'BBI' packer at 5580'; 7' HES 'BBI' packer at 5725'; 7" HES Fas Drill Bridge Plug at 5815'; 7' x 3-1/2" SABL-3 Baker packer w/K-anchor at 10019' 13. Attachments [~ Description summary of proposal I--~ Detailed operations program [--] BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: November 22, 1999 16. If proposal was verbally approved [] Oil [] Gas [] Suspended Service Name of approver Date al)proved Contact Engineer Name/Number: Fred Johnson, 564-5427 Mik Triolo, 564-5774 Prepared By Name/Number: 17. I hereby cert~ th/C~/tb.,e_foreg/e/~/~/~s true and correct to the best of my knowledge Signed '"h '~'~//~; ~ ~ ar,es Mallary _~"7 Title Senior Drilling Engineer (/_ Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Terrie Hubble, 564-4628 Approved by' order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate WELL PERMIT CHECKLIST ~,DMINISTRATi~iq COMPANY ............... ,, , WELL NAME~_~/~_'_'__.~.~ .............. :~.-'.._~.. __~ PROGRAM: exp ___ dev _._¢._ redrll .. C/_~__ serv .................. wellbore seg ............ ann. disposal para req .............. ------ ~' 7' P~ii[-f-e-q~t-G-c-~E.--:-~-7"-2'-: '-7-7" :' "'-:"--:"'"'i'"'-~-' 2. Lease number appropriate ................... '~)N 3. Unique well name and number .................. ~ N · 4. Well located in a defined pool .................. ~ N ......................................................................................................................................................................................................... 5. Well located proper distance from drilling unit boundary .... ~.,~,~ N . 6. Well located proper distance from other wells .......... ~. N ......................................................... i ........................................................................................................................................................... . 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included~ .............. ~ N ................................................................................................................................................................................................. 9. Operator only affected pady ................... ~ N . 10. Operator has appropriate bond in force ............. ~ N ................................................................................................................................................................................... 11. Permit can be issued without conservation order ........ ~,~) N 12. Permit can be issued without administrative approval ...... . .~,. ~ N 13. Can permit be approved before 15-day wait ........... ~N II AP, FAR DATE ~'ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. cMr vol adequate to tie-in long string to surf csg ........ 18. CM-r will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. · . 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ,~o~ DATE 26. BOPE press rating appropriate; te'st't(~ I'~t/i5-ez~"~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ " ' ~' 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. N ... - N ....~,~..~_.~._M_,,-.__~._~,_ ._~::~.t' .................... N ...~_~_~.._~..~..~_~_ _~.. ~_~.~...~& 'V N ............................................................... ~~ ................................................................................................................................. Y N~ Y N~]Zg DATE 33. Seabed condition survey (if off-shore) ............. Y_ N ',.,~7./g: .............................................................................................. ~/, t5'~'~¢'~ 34. Contact name/phone for weekly progress repods [explorator_~ ANNULAR DISPOSAL 35. WTth--~op-~¢-~--~~~~l~ .... (A) will contain waste ina suitable re~eiv~ ...... Y N '"'"' APPR DATE (B) will not contaminate freshwater;,,~use drilling waste... Y N .................. "~ ....... ' "'( ~ . to surface; (C) will not impair mech (D) will not damage p ..... ~ ............. pool; and (E) will not circumv t 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: JDH ,~ ~ RNC ~ Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09/27/99) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° 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 $ Sat Dec 18 14:52:11 1999 Reel Header Service name ............. LISTPE Date ..................... 99/12/18 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 ..................... 99/12/18 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 Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPEP~ATOR: 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: MWD RUN 2 AK-MM-90203 B. HENNINGSE D. WESTER MPJ-09A 500292249501 BP Exploration (Alaska) Sperry Sun 18-DEC-99 13N 10E 2347 2090 .00 RECEIVED 2000 Naska Oil & Gas C, ons. Commission DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 65.32 34.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 13.375 112.0 9.675 2936.0 6.125 7.000 5335.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . REAL TIME GAMMA P~AY DATA IS USED IN THE INTERVAL 5993'MD TO 6045'MD DUE TO MEMORY FAILURE. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM D DOUGLAS FOR M VANDERGON OF BP EXPLORATION (ALASKA), INC. ON 12/15/99 MWD DATA IS CONSIDERED PDC. KICKOFF POINT FROM PARENT WELLBORE FOR THIS WE IS 5335'MD, 3828'TVD. 5. MWD RUNS 1-2 REPRESENT WELL MPJ-09A WITH API#: 50-029-22495-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8235'MD, 4046'TVI). 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. $ ~ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/18 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. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 5319.5 RPX 5326.5 RPS 5326.5 RPM 5326.5 RPD 5326.5 FET 5326.5 ROP 5363.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 8190 5 8197 5 8197 5 8197 5 8197 5 8197 5 8235 0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH .... BIT RUN NO MERGE TOP 200 5319.0 MERGED MAIN PASS. $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 8235.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 5319.5 8235 ROP MWD FT/H 0 575.78 GR MWD API 34.85 134.45 RPX MWD OHMM 0.49 2000 RPS MWD OHMM 0.83 1863.43 RPM MWD OHMM 1.34 2000 RPD MWD OHMM 2.25 2000 FET MWD HOUR 0.16 13.83 Mean Nsam 6777.25 5832 136.973 5744 78.1188 5743 15.8136 5743 17.5654 5743 18.265 5743 20.6581 5743 1.01211 5743 First Reading 5319 5 5363 5 5319 5 5326 5 5326 5 5326 5 5326 5 5326 5 Last Reading 8235 8235 8190 5 8197 5 8197 5 8197 5 8197 5 8197 5 First Reading For Entire File .......... 5319.5 Last Reading For Entire File ........... 8235 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/18 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 ....... 99/12/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NTIMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5319.5 RPX 5326.5 RPS 5326.5 RPM 5326.5 RPD 5326.5 FET 5326.5 ROP 5363.5 STOP DEPTH 8190.5 8197 5 8197 5 8197 5 8197 5 8197 5 8235 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWAYHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MI/D 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 ~paelng ..................... 60 .lin 10-DEC-99 Insite 041 Memory 8235.0 54.8 98.2 TOOL NUMBER P1335GRV4 P1335GRV4 6. 125 Water Based 9.20 45.0 9.6 18000 3.8 .220 .179 .160 .350 72.0 90.0 72.0 72.0 Max frames per record · .Undefined Absent value ...................... -999.25 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 MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD 2 FT/H GR MWD 2 RPX MWD 2 OHMM RPS MWD 2 OHMM RPM MWD 2 OHMM RPD MWD 2 OHMM FET MWD 2 HOUR Min Max Mean Nsam 5319.5 8235 6777.25 5832 0 575.78 136.973 5744 34.85 134.45 78.1188 5743 0.49 2000 15.8136 5743 0.83 1863.43 17.5654 5743 1.34 2000 18.265 5743 2.25 2000 20.6581 5743 0.16 13.83 1.01211 5743 First Reading 5319 5 5363 5 5319 5 5326 5 5326 5 5326 5 5326 5 5326 5 Last Reading 8235 8235 8190 5 8197 5 8197 5 8197 5 8197 5 8197 5 First Reading For Entire File .......... 5319.5 Last Reading For Entire File ........... 8235 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/12/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LI~TP~ Date ..................... 99/12/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services physical EOF Physical EOF End Of LIS File