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199-107
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: __________________ 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. W ell Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s): GL: 35.1 BF: N/A 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. W ater Depth, if Offshore:21. Re-drill/Lateral Top W indow MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 13-3/8" L-80 110 5-1/2" J-55 4,247 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 30 7,083 24" HOLE SIZE AMOUNT PULLED 490sx Arctic Set 3, 390sx Glass G 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, TUBING RECORD 6,3903-1/2" SIZE DEPTH SET (MD) 6,281 / 3,839 PACKER SET (MD/TVD) BOTTOM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas 199-107 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 10/8/2020 November 10, 1999 50-029-22952-00-00 November 15, 1999 MILNE PT UNIT J-152,345' SL, 3,348' EL, SEC. 28, T13N, R10E, UM MILNE POINT / SCHRADER BLUFF OIL 65.1 ADL0025906 & ADL03158487,000 / 4,203 7,145 / 4,280551973.5392 6014739.58 1,619' SL, 5,157' EL, SEC. 21, T13N, R10E, UM 1,918' SL, 5,270' EL, SEC.21, T13N, R10E, UM CEMENTING RECORD 6019285.603 SETTING DEPTH TVD 6019576.973 N/A TOP 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 N/A 1,800' Approx. N/A Surface 7-7/8" 260sx Arctic Set (Approx) 30 CASING WT. PER FT.GRADE 550126.2428 55003.4876 TOP SETTING DEPTH MD Surface68 15.5 110 PRODUCTION TEST 12/17/1999 Date of Test: Oil-Bbl: Water Injection Per 20 AAC 25.283 (i)(2) attach electronic information Flow Tubing Gas-Oil Ratio:Choke Size: Sr Res EngSr Pet Geo Water-Bbl: Sr Pet Eng Oil-Bbl: Water-Bbl: Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 2:45 pm, Jan 11, 2021 / 320-352 Abandonment Date 10/8/2020 HEW RBDMS HEW 1/14/2021 xGDSR-1/14/21DLB 01/26/2021 MGR24FEB2021 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD ±1,800 ±1,593 Top of Productive Interval 5,382 3,409 6,430 3,912 6,770 4,084 6,912 4,157 Base of Schrader Bluff 6,958 4,181 SCHRADER BLUFF 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Chad Helgesen Contact Name: Tom Fouts Operations Manager Contact Email:tfouts@hilcorp.com Authorized Contact Phone:907-777-8398 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: OA Sand Welbore Schematic and daily operations reports. Ugnu 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): 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: Top of Schrader Bluff OB Sand 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. 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: 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Chad Helgeson (1517) 2021.01.11 14:21:26 - 09'00' _____________________________________________________________________________________ Downhole Revised: 1/07/2018 Revised By: TDF 10/15/2020 SCHEMATIC Milne Point Unit Well: MPU J-15 Last Completed: 12/9/1999 PTD: 199-107 TD =7,145’ (MD) / TD =4,280(TVD) 13-3/8” Orig. KB Elev.: 65.1’/ GL Elev.: 35.1’ Nordic #3 RKB – Tbg Spool: 28.6’ Nordic #3 5-1/2” 3 4 5 6 7 9 1 2 PBTD =7,000’ (MD) / PBTD = 4,203’(TVD) 8 2 ea 20’ Short Jts 6,461’ / 6,510’ Minimum ID = 2.635” @ 6,297’ Minimum ID = 2.635” @ 6,378’ Tubng Punch 6,169’ MD NB OA OB CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift ID Top Btm BPF 13-3/8" Conductor 68 / L-80 / N/A 12.415” 12.259” Surface 110' 0.1497 5-1/2" Production 15.5 / J-55 / BTC 4.950” 4.825” Surface 7,081’ 0.0238 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / NS-CT 2.992” 2.867” Surf 6,390’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,194’ 3.5” HES X-Nipple: ID= 2.813” 2 6,272’ 3.5” HES X-Nipple: ID= 2.813” 3 6,281’ 5.5” x 3.5” Baker SABL-3 Permanent Packer 4 6,297’ 3.5” HES XN-Nipple: Packer Bore 2.750”,ID= 2.635” 5 6,308’ Unique Machine Overshot – Bottom @ 6,318’ 6 6,347’ 3.5” HES X-Nipple: ID= 2.813” 7 6,356’ 5.5” x 3.5” Baker SABL-3 Permanent Packer 8 6,378’ 3.5” HES XN-Nipple: Packer Bore 2.750”,ID= 2.635” 9 6,389’ 3.5” WLEG – Bottom @ 6,390’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 6,504’ 6,506’ 3,949’ 3,950’ 2 1 2-1/4” 9/05/2005 Open 6,513’ 6,518’ 3,954’ 3,956’ 5 6 2” 8/27/2014 Open 6,500’ 6,520’ 3,947’ 3,957’ 20 5 2-3/8” 4/08/2018 Open OA 6,775’ 6,795’ 4,086’ 4,097’ 20 20 4 5 2” 2-3/8” 12/12/1999 4/08/2018 Open Open 6,820’ 6,840’ 4,109’ 4,120’ 20 20 4 5 2” 2-3/8” 12/12/1999 4/08/2018 Open Open OB 6,915’ 6,955’ 4,158’ 4,179’ 40 4 2” 12/12/1999 Open 6,915’ 6,955’ 4,158’ 4,179’ 40 6 2” 8/27/2014 Open Ref Log: SWS CBL 11/19/1999 – Perf Guns: 2.0” PJ 4 spf (12/12/99)/2.25” PJ 1 spf (9/05/05)/2.0” PJO 6 spf (8/27/14) WELL INCLINATION DETAIL KOP @ 450’ Max Hole Angle = 62 deg. @ 5,500’ 60 Deg. to 62 Deg. 1,900’ to 6,300’ Hole Angle thru perfs = ग़ 59 Deg. TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 7-1/16” 5M Vetco Gray 5.5” Emergency slips Vetco Tubing Hanger 3” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-22952-00-00 Drilled, Cased & Comp by Nordic 3- 11/20/1999 Recomplete due to leaking lower packer – 12/9/1999 Initial Perforations – 12/12/1999 Add NB Perfs – 9/5/2005 & 8/27/2014 P&A - 10/8/2020 OPEN HOLE / CEMENT DETAIL 13-3/8” 260 sx Arctic Set (Approx.) in a 24” Hole 5-1/2”490 sx Arctic Set 3, 390 sx Class “G” in a 7-7/8” Hole Cement to surface (46 bbl) NOTE: Lower packer leaked during initial completion. Tubing was cut leaving 9’ pup and 9’ of tubing stub above X-Nipple at 6,347’. Unique Machine overshot swallowed 7’ of tubing stub. Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 CTU 50-029-22952-00-00 199-107 9/8/2020 11/27/2020 9/4/2020 - Friday No operations to report. 9/2/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/3/2020 - Thursday No operations to report. CTU #6 - MIRU, PT to 250 low and 3,500 high. MU Nozzle BHA w/DFCV's and RIH. RIH to 6,960' with a couple bobbles in weight. PUH to SLMD Tag and start clean out holding 150psi WHP (1:1 returns). FCO pumping 10 bbl gel sweeps every 50' and PUH to TT every 100'. Tag hard bottom at 9,007' PBTD. Allow last 10 bbl pill out and chase OOH. At surface, line up to FP well down the backside. WHP starting to climb and leveled off at 485psi. Call OE and discuss with slope team. I-37 injector is online 200' from J-15 and is injecting at 500psi. I-37 will be shut in. LD BHA, swap nozzle to 2" BDN, Install Night Cap and PT to 250/2,500. No operations to report. 9/5/2020 - Saturday No operations to report. 9/8/2020 - Tuesday 9/6/2020 - Sunday No operations to report. 9/7/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 SL & CTU 50-029-22952-00-00 199-107 9/8/2020 11/27/2020 9/11/2020 - Friday No operations to report. 9/9/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue OPS from WSR 9/8/2020 - MU 2" BDJS Nozzle BHA. Tag PBTD at 7,001', Circ bottoms up holding 150psi WHP, bottoms up is clean reduce rate to 1 bpm with 1:1 returns. Mix up 20 bbls 15.8ppg Class G Cement and pump. Allow 1 bbl out then POOH 1:1 laying in CMT. Stop at 6,273', close choke and squeeze remaining 3.5 bbls of CMT to formation. Pumped 3.5 bbls into formation at 460 psi WHP and PUH to safety holding 400+ WHP and stopped at 5,714'. Shut down pump and allow CMT to build a filter cake for 30 Min. Pressure bled down 45psi, slowly bled off to 0psi and came online with Gel down to coil drop 9/16" ball to clean out CMT. RIH to 6,275' chasing gel Pill OOH. FP well f/2,700' MD with diesel, trap 150psi WHP for HSP loss for diesel and shut in well. 9/10/2020 - Thursday No operations to report. No operations to report. No operations to report. 9/12/2020 - Saturday No operations to report. 9/15/2020 - Tuesday 9/13/2020 - Sunday No operations to report. 9/14/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 Pump Truck 50-029-22952-00-00 199-107 9/8/2020 11/27/2020 No operations to report. No operations to report. 9/19/2020 - Saturday No operations to report. 9/22/2020 - Tuesday 9/20/2020 - Sunday No operations to report. 9/21/2020 - Monday 9/18/2020 - Friday No operations to report. 9/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/17/2020 - Thursday Flush Latural (Post Coil P&A) (Pressure Test Surface lines 250/3,500 psi) Pump 5 bbls 60/40 down Injection Latural. Bleed Latural to zero. Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 SL 50-029-22952-00-00 199-107 9/8/2020 11/27/2020 9/25/2020 - Friday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. RAN 2'x1-7/8" STEM, 2.5" CENT, SAMPLE BAILER & TAGGED CEMENT @ 6,167' SLM (6,197' MD), RECOVERED 2.5 CUPS OF CEMENT IN BAILER. PRESSURED UP TUBING TO 1,500psi & WATCHED FOR 30min, LOST 25psi THE FIRST 15min & 0psi THE SECOND 15min (pass). WELL S/I ON DEPARTURE, DSO NOTIFIED. 9/23/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/24/2020 - Thursday No operations to report. No operations to report. WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. RAN 3'x1-1/2", 2.85" CENT & TAGGED X-NIPPLE @ 2,183' SLM (2,194' MD), -11 SLM CORRECTION. RAN 2'x1-7/8" STEM, 2.5" CENT, 5'x2" DRIVE DOWN BAILER W/ BALL BOTTOM & TAG CEMENT @ 6,168' SLM (6,179' MD), RECOVERED 1/4gal OF CEMENT IN BAILER. PERFORMED STATE WITNESSED MIT ON TUBING (pass), REFER TO JOB LOG FOR RUN DETAILS. RAN HES PRESSURE & TEMP TOOL DOWN TO CEMENT @ 6,168' SLM (6,179' MD), (good data). RAN HES MAXFIRE TUBING PUNCH & TAGGED CEMENT @ 6,168' SLM (6,179' MD), P/U 10' TO 6,158' SLM (6,169' MD), SHOT 5' 0 phased, SMALL CHARGE TUBING PUNCH, 4spf, .61" HOLES. PERFORMED CMIT - TxIA, (pass), REFER TO JOB LOG FOR DETAILS. WELL S/I ON DEPARTURE, DSO NOTIFED. 9/26/2020 - Saturday No operations to report. 9/29/2020 - Tuesday 9/27/2020 - Sunday No operations to report. 9/28/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 Pump Truck 50-029-22952-00-00 199-107 9/8/2020 11/27/2020 10/9/2020 - Friday No operations to report. 10/7/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/8/2020 - Thursday PT Surface lines to 2,500 psi. Pump 70 bbl fresh water spacer followed by 137 bbl's of 15.8 ppg Class G cement with good returns to surface. Flush tubing in tree w/ small amount of diesel and IA valve w/ Nitrogen. Grease tree and R/D hardline. No operations to report. No operations to report. 10/10/2020 - Saturday No operations to report. 10/13/2020 - Tuesday 10/11/2020 - Sunday No operations to report. 10/12/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 N/A 50-029-22952-00-00 199-107 9/8/2020 11/27/2020 No operations to report. T/I/O= 20/0+0 Well Support Techs bled WHPS to 0 psi pre P&A. Bled TBG from 20 psi to 0 psi <1 min. Bled IA to 0 psi. Monitored WHPS for 30 mins with no increase in pressure. 11/14/2020 - Saturday No operations to report. 11/17/2020 - Tuesday 11/15/2020 - Sunday No operations to report. 11/16/2020 - Monday 11/13/2020 - Friday No operations to report. 11/11/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/12/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 N/A 50-029-22952-00-00 199-107 9/8/2020 11/27/2020 11/20/2020 - Friday No operations to report. 11/18/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/19/2020 - Thursday No operations to report. P&A (on going) Excavated to 14' and installed 10' x 10' cellar box. Bell & Assoc identified pad as worst case, is 9-1/2' thick to tundra level. Photos at dig location identify tundra level at 8-1/2'. Wellhead cut with Super D wachs saw at 13' below pad grade which puts cut at 4-1/2' below tundra grade. Annulus and tubing string had a void of 6' each. Mixed 15.7 ppg AS-1 and filled voids after AOGCC witnessed (Bob Noble). No operations to report. 11/21/2020 - Saturday No operations to report. 11/24/2020 - Tuesday 11/22/2020 - Sunday No operations to report. 11/23/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 N/A 50-029-22952-00-00 199-107 9/8/2020 11/27/2020 11/27/2020 - Friday AOGCC inspector came out for final inspection of cement and plate. All good. Welded plate to well. 11/25/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/26/2020 - Thursday No operations to report. No operations to report. No operations to report. 11/28/2020 - Saturday No operations to report. 12/1/2020 - Tuesday 11/29/2020 - Sunday No operations to report. 11/30/2020 - Monday MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re gg I<«� DATE: 12-06-2020 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector MPU J-15 ' Hilcorp Alaska LLC PTD 1991070; Sundry 320-352 11/27/2020: 1 traveled out to MPU J-15 to inspect the well cutoff, the site, and marker plate. All strings were full of hard cement. The well was cut off at approximately 4.5 feet below tundra grade. The correct information was verified on the marker plate. No issues. Photos: 2020-1127—Surface—Abandon MPU—J- I 5ae.docx Page 1 of 2 F t . Vo . ad � N6 U 03 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �Q,`i DATE: 11/24/2020 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector MPU J-15 Hilcorp Alaska LLC PTD 1991070; Sundry 320-352 11/24/2020: 1 traveled to Hilcorp Alaska's MPU J-15 to inspect their surface abandonment prior to casing cut-off. I met with Hilcorp representative Jon Arend at f location. The depth of cement was found approximately 6 feet from surface in the tubing. The tubing -casing annulus (IA) was full of cement and the casing -casing annulus (OA) was also 6 feet low. I told Jon to top the tubing and OA off with cement and send a notification out for another inspection when it was hard. f Attachments: none [file name] Page l of 1 MEMORANDUM Founded on State of Alaska Depth To MW Above Alaska Oil and Gas Conservation Commission TO: Jim Regg 6,179 ft MD DATE: September 26, 2020 Wireline tag P.I. Supervisor � `�� SUBJECT: Plug Verification MPU J-15 s FROM: Brian Bixby Hilcorp Alaska LLC Petroleum Inspector PTD 1991070; Sundry 320-352 Section: 28 Township: 13N Range: 10E - Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 7,145 ft MD " Lease No.: ADL0315848 , Operator Rep: Nathan Williams Suspend: P&A: XXX Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 13 3/8" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: O.D. Shoe@ Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5 1/2" O.D. Shoe@ 7,083 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 6,390 Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To MW Above verltled Perforation Bottom 6,996 ft MD' 6,179 ft MD 8.3 ppg - Wireline tag Initial Ir; min ,�n min 45 min Result Tubing 1719 - 1688 1674 IA 2 1 1 P OA NA NA NA Tubing IA OA Initial 15 min 30 min 45 min Result Remarks: 15.8 Class "G" Cement, Pretest Pressures T/1/0= 48/1/NA Monobore Completion ✓'- Attachments: none rev. 11-28-18 2020-0926_Plug_Verification_MPU_J-15_bb 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: Cement Plug 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,145'N/A Casing Collapse Conductor 2,260psi Production 4,040psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name:Ian Toomey Operations Manager Contact Email:itoomey@hilcorp.com Contact Phone: 777-8520 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker SABL-3; Baker SABL-3 / N/A 6,281' MD/3,839' TVD; 6,356' MD/3,876' TVD / N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Tubing MD (ft): See Schematic See Schematic 110' 13-3/8" 5-1/2"7,083' Perforation Depth TVD (ft): 3-1/2" Perforation Depth MD (ft): 4,247'7,083' 110' 110' 9.2# / L-80 / NS-CT Tubing Grade: Burst 6,390 MD 5,020psi 50-029-22952-00-00 1,292 7,001' MILNE PT UNIT J-15 Tubing Size: 4,810psi Length Size 4,280' 7,001' 4,203' PRESENT WELL CONDITION SUMMARY TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0315848 199-107 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 MILNE POINT / SCHRADER BLUFF OIL Hilcorp Alaska LLC C.O. 477.05 COMMISSION USE ONLY Authorized Name: 9/20/2020 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:47 pm, Aug 21, 2020 320-352 Chad A Helgeson 2020.08.21 13:23:02 -08'00' DSR-8/21/2020 MIT-T to 1500 psi after reservoir plug in place. Tag top of plug ~6275' CTMD. MGR04SEP20 SFD 8/21/2020 10-407 SFD 8/21/2020 , ADL0025906 Photo document as described. AOGCC to witness cement tops in all annuli before topping off. Comm . 9/8/2020 dts 9/8/2020 JLC 9/8/2020 RBDMS HEW 9/9/2020 P&A Well: MPU J-15 Date: 08-19-20 Well Name: MPU J-15 API Number: 50-029-22952-00 Current Status: Shut-in injector Pad: J-Pad Estimated Start Date: August 28th, 2020 Rig: CTU Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-107 First Call Engineer: Ian Toomey (907) 777-8343 (O) (907) 903-3987 (M) Second Call Engineer: David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number: Job Type: P&A Current Bottom Hole Pressure: 1,696 psi @ 4,045’ TVD SBHP on 1/12/20 | 8.1 ppg Maximum Expected BHP: 1,696 psi @ 4,045’ TVD SBHP on 1/12/20 | 8.1 ppg MPSP: 1,292 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 62° at 5,516’ MD Max Dogleg: 6.55°/100ft at 1,355’ MD BPV Profile: 3” CIW Type H Minimum ID: 2.635” at 6,297’ & 6,378’ MD Brief Well Summary: MPU J-15 was drilled in November 1999 by Nordic 3 as an OA/OB Schrader Bluff injector. However a RWO was done in December 1999 due to leaking packer where a new packer was stacked on top. The NB sand was perforated in 2005. This P&A is to support the I-pad redevelopment. Notes Regarding Wellbore Condition x The 5-1/2” production casing passed an MIT to 2,500 psi on 9/10/19. x 5-1/2” cement job: While circulating and reciprocating during phase 3 weather the 5-1/2” casing became stuck 62’ off bottom. Still had good circulation, pumped 467 bbls of cement and got 46 bbls of cement to surface. Objective: x P&A well J-15. CTU: 1. MIRU CTU and spot support equipment. Fill uprights with 8.3 ppg source water. 2. Pressure test BOPE to 250/3,000 psi for 10 minutes each. a. Each subsequent test of the lubricator will be to 250/3,000 psi to confirm no leaks. b. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient to meet the weekly BOPE test requirement. 3. RIH with 2” nozzle to tag on top of fill at 6788’ MD. Cleanout the 5-1/2”, 15.5# casing to the top of the float collar at 6,960’ with 8.3 ppg source water and gel sweeps. a. Contingency: If unable to get good returns, Nitrogen will be used to facilitate the cleanout. Review Nitrogen SOP protocol with on-site personnel. 4. POOH and lay down the BHA. 5. MU ball drop cementing nozzle and RIH to 7,000’ or deepest depth reached during FCO. 6. RU cementers. P&A Well: MPU J-15 Date: 08-19-20 7. Mix and pump 20 bbls of 15.8 ppg Class G cement down the coil tubing taking returns up the 3-1/2” tubing. Use freshwater spacers as needed around the cement. 8. Allow ~1 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. Pause at 6,273’ md and attempt to squeeze ±5bbls cement until a bump in pressure is observed. 9. PU to safety, swap to contaminate and RIH to cleanout/wash down to 6,275’ MD. 10. POOH and circulate CT clean as needed. a. Freeze protect the tubing on way out of hole. 11. RDMO CTU. Wells Support: 12. Install TWC. 13. ND the existing tree and NU a dry hole tree. 14. PT to 250/3,000 psi. 15. Pull TWC. Slickline: 16. Notify the AOGCC 24 hours in advance for tag of TOC and PT. 17. MIRU the slickline unit and support equipment. 18. RIH with drive down bailer, tag TOC (note tag depth on report) and POOH. 19. PT the tubing and cement plug to 1,500 psi for 30 minutes (charted). 20. PU, MU and RIH with tubing punch to just above the nipple at 6,272’. 21. PU to 6,260’ (first full joint above the packer), punch the tubing and POOH. 22. CMIT – TxIA to 1,500 psi for 30 minutes (charted) to confirm the integrity of the 5-1/2” casing. 23. RDMO the slickline unit. Cementing: 24. MIRU cementing unit and support equipment. 25. Line up to circulate down the tubing taking return up the IA to tanks. PT lines to 2,500 psi. 26. Establish circulation and pump 40 bbls of fresh water to recover the diesel on the IA. 27. Pump ±30 bbl spacer followed by ±170 bbls of 15.8 ppg class G cement. a. Wellbore volume (T + IA) to 6,260’ MD = 129 bbls 28. Once good cement is at surface, swap to clean fluid to displace past the tree and shut down the pump. 29. Flush all surface line with fresh water to tanks. 30. RDMO the cementing unit. Surface Abandonment: 31. Notify the AOGCC 24 hours in advance of cutting off the wellhead and welding the marker plate. 32. Excavate the cellar, cut off the wellhead and casing 3’ below natural ground level. a. Ensure cement to surface in all strings per 20 ACC 25.112 (d)(2)(A) b. If cement is not to surface, contact the OE to discuss plan forward. c. Will need AOGCC approval before proceeding. d. Photograph the cement top and casing cut below natural ground level. AOGCC to witness before topping annuli of with cement. P&A Well: MPU J-15 Date: 08-19-20 33. Create a well abandonment marker per 20 AAC 25.120. The following information must be bead welded directly to the marker plate. a. Hilcorp Alaska, LLC b. PTD: 199-107 c. Well Name: MPU J-15 d. API: 05-029-22952-00-00 34. Set the marker plate per 20 AAC 25.120 and collect GPS coordinates. 35. Photograph the casing stub and the installed welded plate. 36. Backfill the excavation and close out the location. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Blank MOC Form 4. Coil BOPE Schematic 5. Nitrogen Operations Procedure 6. Nitrogen & Foam Flow Diagram. _____________________________________________________________________________________ Downhole Revised: 1/07/2018 Revised By: STP 9/17/2019 SCHEMATIC Milne Point Unit Well: MPU J-15 Last Completed: 12/9/1999 PTD: 199-107 TD = 7,145’(MD) / TD = 4,280(TVD) 13-3/8”88 Orig. KB Elev.: 65.1’/ GL Elev.: 35.1’ Nordic #3 RKB – Tbg Spool: 28.6’ Nordic #3 5-1/2” 3 4 5 6 7 9 1 2 PBTD = 7,000’ (MD) / PBTD = 4,203’(TVD) 8 2 ea 20’ Short Jts 6,461’ / 6,510’ Minimum ID = 2.635” @ 6,297’ Minimum ID = 2.635” @ 6,378’ Tag @ 6.865’ RKB 8/20/19 NB OA OB CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift ID Top Btm BPF 13-3/8"Conductor 68 / L-80 / N/A 12.415”12.259”Surface 110'0.1497 5-1/2"Production 15.5 / J-55 / BTC 4.950”4.825”Surface 7,081’0.0238 TUBING DETAIL 3-1/2”Tubing 9.2 / L-80 / NS-CT 2.992”2.867”Surf 6,390’0.0087 JEWELRY DETAIL No Depth Item 1 2,194’3.5” HES X-Nipple: ID= 2.813” 2 6,272’3.5” HES X-Nipple: ID= 2.813” 3 6,281’5.5” x 3.5” Baker SABL-3 Permanent Packer 4 6,297’3.5” HES XN-Nipple: Packer Bore 2.750”,ID= 2.635” 5 6,308’Unique Machine Overshot –Bottom @ 6,318’ 6 6,347’3.5” HES X-Nipple: ID= 2.813” 7 6,356’5.5” x 3.5” Baker SABL-3 Permanent Packer 8 6,378’3.5” HES XN-Nipple: Packer Bore 2.750”,ID= 2.635” 9 6,389’3.5”WLEG –Bottom @ 6,390’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 6,504’ 6,506’ 3,949’ 3,950’2 1 2-1/4”9/05/2005 Open 6,513’ 6,518’ 3,954’ 3,956’5 6 2”8/27/2014 Open 6,500’ 6,520’3,947’3,957’20 5 2-3/8”4/08/2018 Open OA 6,775’ 6,795’ 4,086’ 4,097’ 20 20 4 5 2” 2-3/8” 12/12/1999 4/08/2018 Open Open 6,820’ 6,840’ 4,109’ 4,120’ 20 20 4 5 2” 2-3/8” 12/12/1999 4/08/2018 Open Open OB 6,915’ 6,955’ 4,158’ 4,179’ 40 4 2”12/12/1999 Open 6,915’ 6,955’ 4,158’ 4,179’ 40 6 2”8/27/2014 Open Ref Log: SWS CBL 11/19/1999 –Perf Guns: 2.0” PJ 4 spf (12/12/99)/2.25”PJ 1 spf (9/05/05)/2.0” PJO 6 spf (8/27/14) WELL INCLINATION DETAIL KOP @ 450’ Max Hole Angle = 62 deg. @ 5,500’ 60 Deg. to 62 Deg. 1,900’ to 6,300’ Hole Angle thru perfs = ग़ 59 Deg. TREE & WELLHEAD Tree 3-1/8”5M FMC Wellhead 7-1/16” 5M Vetco Gray 5.5” Emergency slips Vetco Tubing Hanger 3” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-22952-00-00 Drilled, Cased & Comp by Nordic 3-11/20/1999 Recomplete due to leaking lower packer –12/9/1999 Initial Perforations –12/12/1999 Add NB Perfs –9/5/2005 & 8/27/2014 OPEN HOLE / CEMENT DETAIL 13-3/8”260 sx Arctic Set (Approx.) in a 24” Hole 5-1/2” 490 sx Arctic Set 3, 390 sx Class “G” in a 7-7/8” Hole Cement to surface (46 bbl) NOTE: Lower packer leaked during initial completion. Tubing was cut leaving 9’ pup and 9’ of tubing stub above X-Nipple at 6,347’. Unique Machine overshot swallowed 7’ of tubing stub. _____________________________________________________________________________________ Downhole Revised: 1/07/2018 Revised By: IAT 8/17/2020 PROPOSED Milne Point Unit Well: MPU J-15 Last Completed: 12/9/1999 PTD: 199-107 TD = 7,145’ (MD) / TD = 4,280(TVD) 13-3/8”88 Orig. KB Elev.: 65.1’/ GL Elev.: 35.1’ Nordic #3 RKB – Tbg Spool: 28.6’ Nordic #3 5-1/2” 3 4 5 6 7 9 1 2 PBTD = 7,000’ (MD) / PBTD = 4,203’(TVD) 8 2 ea 20’ Short Jts 6,461’ / 6,510’ Minimum ID = 2.635” @ 6,297’ Minimum ID = 2.635” @ 6,378’ Tubng Punch 6,260’ MD NB OA OB CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift ID Top Btm BPF 13-3/8"Conductor 68 / L-80 / N/A 12.415”12.259”Surface 110'0.1497 5-1/2"Production 15.5 / J-55 / BTC 4.950”4.825”Surface 7,081’0.0238 TUBING DETAIL 3-1/2”Tubing 9.2 / L-80 / NS-CT 2.992”2.867”Surf 6,390’0.0087 JEWELRY DETAIL No Depth Item 1 2,194’3.5” HES X-Nipple: ID= 2.813” 2 6,272’3.5” HES X-Nipple: ID= 2.813” 3 6,281’5.5” x 3.5” Baker SABL-3 Permanent Packer 4 6,297’3.5” HES XN-Nipple: Packer Bore 2.750”,ID= 2.635” 5 6,308’Unique Machine Overshot –Bottom @ 6,318’ 6 6,347’3.5” HES X-Nipple: ID= 2.813” 7 6,356’5.5” x 3.5” Baker SABL-3 Permanent Packer 8 6,378’3.5” HES XN-Nipple: Packer Bore 2.750”,ID= 2.635” 9 6,389’3.5”WLEG –Bottom @ 6,390’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 6,504’ 6,506’ 3,949’ 3,950’2 1 2-1/4”9/05/2005 Open 6,513’ 6,518’ 3,954’ 3,956’5 6 2”8/27/2014 Open 6,500’ 6,520’3,947’3,957’20 5 2-3/8”4/08/2018 Open OA 6,775’ 6,795’ 4,086’ 4,097’ 20 20 4 5 2” 2-3/8” 12/12/1999 4/08/2018 Open Open 6,820’ 6,840’ 4,109’ 4,120’ 20 20 4 5 2” 2-3/8” 12/12/1999 4/08/2018 Open Open OB 6,915’ 6,955’ 4,158’ 4,179’ 40 4 2”12/12/1999 Open 6,915’ 6,955’ 4,158’ 4,179’ 40 6 2”8/27/2014 Open Ref Log: SWS CBL 11/19/1999 –Perf Guns: 2.0” PJ 4 spf (12/12/99)/2.25”PJ 1 spf (9/05/05)/2.0” PJO 6 spf (8/27/14) WELL INCLINATION DETAIL KOP @ 450’ Max Hole Angle = 62 deg. @ 5,500’ 60 Deg. to 62 Deg. 1,900’ to 6,300’ Hole Angle thru perfs = ग़ 59 Deg. TREE & WELLHEAD Tree 3-1/8”5M FMC Wellhead 7-1/16” 5M Vetco Gray 5.5” Emergency slips Vetco Tubing Hanger 3” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-22952-00-00 Drilled, Cased & Comp by Nordic 3-11/20/1999 Recomplete due to leaking lower packer –12/9/1999 Initial Perforations –12/12/1999 Add NB Perfs –9/5/2005 & 8/27/2014 OPEN HOLE / CEMENT DETAIL 13-3/8”260 sx Arctic Set (Approx.) in a 24” Hole 5-1/2” 490 sx Arctic Set 3, 390 sx Class “G” in a 7-7/8” Hole Cement to surface (46 bbl) NOTE: Lower packer leaked during initial completion. Tubing was cut leaving 9’ pup and 9’ of tubing stub above X-Nipple at 6,347’. Unique Machine overshot swallowed 7’ of tubing stub. Wallace, Chris D (CED) From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Wednesday, February 5, 2020 11:55 AM To: Regg, James B (CED); Brooks, Phoebe L (CED); Wallace, Chris D (CED); DOA AOGCC Prudhoe Bay Cc: Wyatt Rivard; Alaska NS - Milne - Wellsite Supervisors; Matthew Linder; William Kruskie Subject: Shut-in injector Milne Point J-15 due for AOGCC MIT -IA All, Milne Point water injector MP J-15 (PTD # 1991070) has been shut in since 8/22/2019 for reservoir management. The well was due for an AOGCC witnessed MIT -IA last month. The well will not be brought online in time for the test and will remain shut-in for the foreseeable future. It will be added to the Quarterly North Slope LTSI injector report. Once the well is ready to be brought online an MIT -IA will be performed. Regards, Darci Horner (Northern Solutions) Regulatory Technologist Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Wallace, Chris D (CED) From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Wednesday, February 5, 2020 11:55 AM To: Regg, James B (CED); Brooks, Phoebe L (CED); Wallace, Chris D (CED); DOA AOGCC Prudhoe Bay Cc: Wyatt Rivard; Alaska NS - Milne - Wellsite Supervisors; Matthew Linder; William Kruskie Subject: Shut-in injector Milne Point 1-15 due for AOGCC MIT -IA All, Milne Point water injector MP J-15 (PTD # 1991070) has been shut in since 8/22/2019 for reservoir management. The well was due for an AOGCC witnessed MIT -IA last month. The well will not be brought online in time for the test and will remain shut-in for the foreseeable future. It will be added to the Quarterly North Slope LTSI injector report. Once the well is ready to be brought online an MIT -IA will be performed. Regards, Darci Horner (Northern Solutions) Regulatory Technologist Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. SCANNED 7r), 1 0 202, • • OFT� 6., THE STATE Alaska Oil and Gas ofALASKA Conservation Commission 5f}£_ 333 West Seventh Avenue "1�__ i. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �FALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Satit4U Operations Manager Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool,MPU J-15 Permit to Drill Number: 199-107 Sundry Number: 318-082 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, V Hollis S. French Chair DATED this l'O day of March,2018. REDS C MAR 8 2018 1 r t# IV L:� 4 FEB 2 8 2018 STATE OF ALASKA 075 3 J C 0 82 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate D Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 199-107 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ $e�ice ❑ 6.API Number: Anchorage Alaska 99503 50-029-22952-00-00 • 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 J-15 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0315848 ' 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): 7,145' - 4,280' - 7,001' ., - 4,203' 1,000 7,001' N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' 5,020psi 2,260psi Production 7,083' 5-1/2" 7,083' 4,247' 4,810psi 4,040psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.2#/L-80/NS-CT 6,390 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SABL-3;Baker SABL-3/N/A • 6,281'MD/3,839'TVD;6,356'MD/3,876'TVD/N/A 12.Attachments: Proposal Summary O Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service EJ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/15/2018 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. Authorized Name: Bo York Contact Name: Stan Porhola 5.-r? Authorized Title: Operations Manager Contact Email: sporhoIa fl hilcorp.con'1 7.17)e' ...--\ Contact Phone: 777-8412 Authorized Signature: Date: 2/27/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31'7 - OIL Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes No Subsequent Form Required: ..- < E","'")! Af i✓ 2018 Approved by: dC.X.D . COMMISSIONER APPROVED BY THE COMMISSION Date: k Ile ?ii41 3/2./N he ORIGINAL r 3.- s'/E' 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 Well: MPU 3-15 Hilcorp Alaska,LU Date:2/26/2018 Well Name: MPU J-15 API Number: 50-029-22952-00 Current Status: Water Injector Pad: Milne Point J-Pad Estimated Start Date: March 15th, 2018 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom louts Permit to Drill Number: 199-107 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) -ACENumber: . lobfiype _ 6 Id Ffer Current Bottom Hole Pressure: 1,800 psi @ 4,000' TVD (SBHPS 4/23/2016/8.65 ppg EMW) Maximum Expected BHP: 1,800 psi @ 4,000' TVD (No new perfs being added, EMW= 8.65 ppg) MPSP: 1,000 psi (Based on maximum surface injection pressure) Objective: Add perforations to the NB zone along with a reperf of the NB zone and reperf the OA zones. This injection well supports offset producers J-25 (PTD 204-073) in the NB sands, J-01A (PTD 199-111) and 1-19 (PTD 204-135) in the OA sands, and J-01A(PTD 199-111),J-08A(PTD 199-117)and 1-19 (PTD 204-135) in the OB sands. Brief Procedure: Procedure: 1. RU E-line.Test lubricator to 250/2,000 psi. 2. MU 20' of 2-3/8" perf guns. 3. RIH and perforate the Schrader Bluff OA from +/-6,820'—6,840' MD. POOH. 4. MU 20' of 2-3/8" perf guns. 5. RIH and perforate the Schrader Bluff OA from +/-6,775'—6,795' MD. POOH. 6. MU 20' of 2-3/8" perf guns. 7. RIH and perforate the Schrader Bluff NB from +/-6,500'—6,520' MD, POOH. 8. POOH. RD E-line. 9. Turn well over to injection. Attachments: 1. Current Schematic 2. Proposed Schematic • • . Milne Point Unit Well: MPU J-15 SCHEMATIC Last Completed: 12/9/1999 iil�p Alaska,LLCPTD: 199-107 TREE&WELLHEAD Orig.KB Elev.:65.1'/GL Elev.:35.1'Nordic#3 Tree 3-1/8"5M FMC RKB—Tb_Spool:28.6'Nordic#3 7-1/16"5M Vetco Gray 5.5"Emergency slips s1 i; fl 'I Wellhead .e * ",ii "44 Vetco Tubing Hanger 3"CIW"H"BPV profile 10 t r OPEN HOLE/CEMENT DETAIL 13-3/8" (' 13-3/8" 260 sx Arctic Set(Approx.)in a 24"Hole 5 1/2" 490 sx Arctic Set 3,390 sx Class"G"in a 7-7/8"Hole 4' g Cement to surface(46 bbl) PCASING DETAIL Size Type Wt/Grade/Conn ID Drift ID Top Btm BPF 13-3/8" Conductor 68/L-80/N/A 12.415" 12.259" Surface 110' 0.1497 5-1/2" Production 15.5/J-55/BTC 4.950" 4.825" Surface 7,081' 0.0238 " j TUBING DETAIL > 1 3-1/2" Tubing 9.2/L-80/NS-CT 2.992" 2.867" Surf 6,390' 0.0087 I 11 WELL INCLINATION DETAIL i- I KOP@450' Max Hole Angle=62 deg. @ 5,500' 1 60 Deg.to 62 Deg.1,900'to 6,300' " ir Hole Angle thru perfs=>59 Deg. ir .' JEWELRY DETAIL No Depth Item t 1 2,194' 3.5"HES X-Nipple:ID=2.813" 2 6,272' 3.5"HES X-Nipple:ID=2.813" !, 1, 3 6,281' 5.5"x 3.5"Baker SABL-3 Permanent Packer 1 �, 4 6,297' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 5 6,308' Unique Machine Overshot—Bottom @ 6,318' 6 6,347' 3.5"HES X-Nipple:ID=2.813" 7 6,356' 5.5"x 3.5"Baker SABL-3 Permanent Packer r 8 6,378' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 9 6,389' 3.5"WLEG—Bottom @ 6,390' PERFORATION DETAIL • A.- ' Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT SPF Size Date Status ),; l'' 6,504' 6,506' 3,949' 3,950' 2 1 2-1/4" 9/05/2005 Open t i i 2 i NB 6,513' 6,518' 3,954' 3,956' 5 6 2" 8/27/2014 Open ' 6,775' 6,795' 4,086' 4,097' 20 4 2" 12/12/1999 Open ( 3 OA 6,820' 6,840' 4,109' 4,120' 20 4 2" 12/12/1999 Open ik !r" OB 6,915' 6,955' 4,158' 4,179' 40 4 2" 12/12/1999 Open N3nimmlD 6,915' 6,955' 4,158' 4,179' 40 6 2" 8/27/2014 Open 2.635 @6'297 4 Ref Log:SWS CBL 11/19/1999—Peri Guns:2.0"PJ 4 spf(12/12/99)/2.25"P.11 spf(9/05/05)/2.0"PJO 6 spf(8/27/14) J' 1. $' 2. x k' 5 NOTE: a t 6 07,pg Lower packer leaked during initial completion.Tubing was cut leaving 9'pup and 9'of tubing stub above X-Nipple at 6,347'. ( . , a m Unique Machine overshot swallowed 7 of tubing stub. Ninirrum ID q 2.635"@6,378 ' ' 8 14 GENERAL WELL INFO API:50-029-22952-00-00 + 9 f, Drilled,Cased&Comp by Nordic 3-11/20/1999 2 ea 20'Short Jts 6,461'/6,519NB Recompletedue toleaking lower packer—12/9/1999 *' Initial Perforations-12/12/1999 DA Add NB Perfs-9/5/2005&8/27/2014 Tag @6950'R4B Cal Cleanout ),' OB 1/08/18 iggi, 5-1/2"1 $114331 TD=7,145'(MD)/TD=4,280(TVD) PBTD=7,000'(MD)/PBTD=4,203'(TVD) Downhole Revised:1/07/2018 Revised By:STP 2/26/2018 Milne Point Unit n • Well: MPU J-15 PROPOSED Last Completed: 12/9/1999 flilcorp Alaska,LLC PTD: 199-107 TREE&WELLHEAD Orig.KB Elev.:65.1'/GL Elev.:35.1'Nordic#3 Tree 3-1/8"5M FMC RKB–TbSpool:28.6'Nordic#3 7-1/16"5M Vetco Gray 5.5"Emergency slips .-4 ,,, m,4 x Wellhead Vetco Tubing Hanger 3"CIW"H"BPV profile lai; ? : riLo OPEN HOLE/CEMENT DETAIL 13-3/8^ _ 13-3/8" 260 sx Arctic Set(Approx.)in a 24"Hole t ' 4 5.1/2„ 490 sx Arctic Set 3,390 sx Class"G"in a 7-7/8"Hole 4; v Cement to surface(46 bbl) I.r l'' CASING DETAIL ( " Size Type Wt/Grade/Conn ID Drift ID Top Btm BPF h 13-3/8" Conductor 68/L-80/N/A 12.415" 12.259" Surface 110' 0.1497 I. F'°./ 5-1/2" Production 15.5/1-55/BTC 4.950" 4.825" Surface 7,081' 0.0238 TUBING DETAIL 3-1/2" Tubing 9.2/L-80/NS-CT 2.992' 2.867" Surf 6,390' 0.0087 1 WELL INCLINATION DETAIL ,? % KOP @ 450' " = N. Max Hole Angle=62 deg.g• @ 5,500' 60 Deg.to 62 Deg.1,900'to 6,300' Hole Angle thru perfs=>59 Deg. JEWELRY DETAIL k, ' No Depth Item 11 e 1 2,194' 3.5"HES X-Nipple:ID=2.813" 2 6,272' 3.5"HES X Nipple:ID=2.813" 1. 3 6,281' 5.5"x 3.5"Baker SABL-3 Permanent Packer z4 6,297 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 5 6,308' Unique Machine Overshot–Bottom @ 6,318' ' ii 6 6,347' 3.5"HES X-Nipple:ID=2.813" 20 r 7 6,356' 5.5"x 3.5"Baker SABL-3 Permanent Packer 8 6,378' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 9 6,389' 3.5"WLEG–Bottom @ 6,390' PERFORATION DETAIL L£ R Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Size Date Status ' 2 6,504' 6,506' 3,949' 3,950' 2 1 2-1/4" 9/05/2005 Open r i. NB 6,513' 6,518' 3,954' 3,956' 5 6 2" 8/27/2014 Open " 3 ±6,500' ±6,520' ±3,947' ±3,957' 20 5 2-3/8" Prop Prop + 20 4 2" 12/12/1999 Open MnimumlD= 6,775' ±6,795' ±4,086' ±4,097' 2 nimu 6,29T ° 4 d; OA 20 5 2-3/8" Prop Reperf Prop ±6,820' ±6,840' ±4,109' ±4,120' 20 4 2" 12/12/1999 Open 20 5 2-3/8" Prop Reperf Prop 5 6,915' 6,955' 4,158' 4,179' 40 4 2" 12/12/1999 Open '• OB 6,915' 6,955' 4,158' 4,179' 40 6 2" 8/27/2014 Open . . 7 NOTE: Mnim,m ID= Lower packer leaked during initial completion.Tubing was cut 2.635'@6,378' t 8 leaving 9'pup and 9'of tubing stub above X-Nipple at 6,347'. Unique Machine overshot swallowed 7 of tubing stub. u 9 2 ea 20'Short Jts 6,461'/6,510' 4NB GENERAL WELL INFO API:50-029-22952-00-00 OP, Drilled,Cased&Comp by Nordic 3-11/20/1999 Tag @695g RIS — Recomplete due to leaking lower packer-12/9/1999 Co1�08/lgout og x ,,,} f Initial Perforations–12/12/1999 51/2 ' r',1;y ?i Add NB Perfs–9/5/2005&8/27/2014 TD=7,145'(MD)/TD=44,280(TVD) PBTD=7,000'(MD)/PBTD=4,203'(TVD) Downhole Revised:1/07/2018 Revised By:STP 2/26/2018 STATE OF ALASKA RECEIVB AKA OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS FEB z $ 2018 1.Operations Abandon U Plug Perforations Ll Fracture Stimulate Lf Pull TubingU D pGtiO ogown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑✓ Alter Casing ❑ g v _ ogram Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MBE Treatment ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC ment Develo Exploratory❑ p lorato rY ❑ 199-107 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑✓ 6.API Number: AK 99503 50-029-22952-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0315848 MILNE PT UNIT .J-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 7,145 feet Plugs measured 7,001 feet true vertical 4,280 feet Junk measured N/A feet Effective Depth measured 7,001 feet Packer measured 6,281 &6,356 feet true vertical 4,203 feet true vertical 3,839&3,876 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' 5,020psi 2,260psi Production 7,083' 5-1/2" 7,083' 4,247' 4,810psi 4,040psi i)' Perforation depth Measured depth See Schematic feet 6� S CA�ra1EQ l''' True Vertical depth See Schematic feet 1's Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/NS-CT 6,390' 3,892' Baker SABL-3 Packers and SSSV(type,measured and true vertical depth) Baker SABL-3 N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 2,712 Subsequent to operation: 0 0 532 40 666 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development III Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q 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: 317-397 c�r) Authorized Name: Bo York Contact Name: Stan Porhola 'T Authorized Title: Operations Manager Contact Email: sporhola@hllcorp.com Authorized Signature. Date 2/27/2018 Contact Phone: 777-8412 —7–le A '77' rz'=L-""s ki„1:.',� I 2t18 Form 10-404 Revised 4/2017 Submit Original Only H . Milne Point Unit 40 Well: MPU J-15 SCHEMATIC Last Completed: 12/9/1999 Dilcarp Alaska,LLC PTD: 199-107 TREE&WELLHEAD Orig.KB Elev.:65.1'/GL Elev.:35.1'Nordic#3 Tree 3-1/8"SM FMC RKB-Tbg Spool:28.6'Nordic#3 i C Wellhead 7-1/16"5M Vetco Gray 5.5"Emergency slips a Vetco Tubing Hanger 3"CIW"H"BPV profile ' " OPEN HOLE/CEMENT DETAIL to V 4 `4 13-3 8" 260 sx Arctic Set A �_3/g�� fa / ( pprox.)in a 24"Hole 490 sx Arctic Set 3,390 sx Class"G"in a 7-7/e Hole *+ 3 *05-1/2" Cement to surface(46 bbl) / b gF CASING DETAIL ATSize Type Wt/Grade/Conn ID Drift ID Top Btm BPF 13-3/8" Conductor 68/L-80/N/A 12.415" 12.259" Surface 110' 0.1497 5 1/2" Production 15.5/1-55/BTC 4.950" 4.825" Surface 7,081' 0.0238 0 TUBING DETAIL 1 q 3-1/2" Tubing 9.2/L-80/NS-CT 2.992" 2.867" Surf 6,390' 0.0087 . WELL INCLINATION DETAIL .. KOP @ 450' N' Max Hole Angle=62 deg. @ 5,500' 14 i 60 Deg.to 62 Deg.1,900'to 6,300' Hole Angle thru perfs=>59 Deg. ;, JEWELRY DETAIL No Depth Item 1 2,194' 3.5"HES X-Nipple:ID=2.813" 2 6,272' 3.5"HES X-Nipple:ID=2.813" 3 6,281' 5.5"x 3.5"Baker SABL-3 Permanent Packer 4 6,297' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 5 6,308' Unique Machine Overshot-Bottom @ 6,318' 6 6,347' 3.5"HES X-Nipple:ID=2.813" 7 6,356' 5.5"x 3.5"Baker SABL-3 Permanent Packer 8 6,378' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 9 6,389' 3.5"WLEG-Bottom @ 6,390' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Size Date Status NB 6,504' 6,506' 3,949' 3,950' 2 1 2-1/4" 9/05/2005 Open . 42 2 6,513' 6,518' 3,954' 3,956' 5 6 2" 8/27/2014 Open 6,775' 6,795' 4,086' 4,097' 20 4 2" 12/12/1999 Open e aa- ' IOA 3 6,820' 6,840' 4,109' 4,120' 20 4 2" 12/12/1999 Open ° 6,915' 6,955' 4,158' 4,179' 40 4 2" 12/12/1999 Open MnimumID- 7 r OB 6,915' 6,955' 4,158' 4,179' 40 6 2" 8/27/2014 Open 2.635 @ 6,29Ts b, 4It Ref Log:SWS CBL 11/19/1999-Perf Guns:2.0"PJ 4 spf(12/12/99)/2.25"PJ 1 spf(9/05/05)/2.0"PJO 6 spf(8/27/14) NOTE: 6 Lower packer leaked during initial completion.Tubing was cut„ it leaving 9'pup and 9'of tubing stub above X-Nipple at 6,347. u ir '7 Unique Machine overshot swallowed 7'of tubing stub. Mnirrum ID= i 2.635'@6,378 8 GENERAL WELL INFO 9 API:50-029-22952-00-00 2 ea 20'Short its Drilled,Cased&Comp by Nordic 3-11/20/1999 6,461'/6,510' I NB Recomplete due to leaking lower packer-12/9/1999 Initial Perforations-12/12/1999 OA Add NB Perfs-9/5/2005&8/27/2014 Tag @ 6.950RKB Coil aeanout — OB 1/08/18 �' :•, 5-112„;4 ..........r:' TD=7,145'(MD)/TD=4,280(TVD) PBTD=7,000'(MD)/PBTD=4,203'(TVD) Downhole Revised:1/07/2018 Revised By:STP 2/26/2018 ! I Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 Pump 50-029-22952-00-00 199-107 11/9/17 11/17/17 Daily Operations: ` 11/8/2017-Wednesday No activity to report. 11/9/2017-Thursday MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 250psi low/ 4,000psi high-test OK. Perform injectivity test at 1.0 bpm @ 600 psi.;Mix and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/47.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 20 bbl of diesel. SD Pumps. Monitor well. Final SITP of 960 psi. RDMO Cement Pump Unit & Little Red Pump Unit. Move to MPU 1-16. 11/10/2017 - Friday No activity to report. 11/11/2017-Saturday No activity to report. 11/12/2017-Sunday MIRU Little Red Pump Unit. PT lines to 250psi low/4,000psi high -test OK. Perform injectivity test at 1.0 bpm @ 860 psi. RDMO Little Red Pump Unit. Move to MPU 1-16. 11/13/2017- Monday No activity to report. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP J-15 Pump 50-029-22952-00-00 199-107 11/9/17 11/17/17 Daily Operations: 11/15/2017 -Wednesday No activity to report. 11/16/2017-Thursday No activity to report. 11/17/2017- Friday MIRU Cement Pump Unit and Little Red Pump Unit. PT lines 250 low/4,000 psi High-test OK. Perform injectivity test at 1.0 bpm @ 860 psi. Mix and pump 10 bbl of HEC, 10 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/47.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 20 bbl of diesel. SD Pumps. Monitor well. Final SITP of 1,000 psi. RDMO Cement Pump Unit & Little Red Pump Unit. 11/18/2017 -Saturday No activity to report. 11/19/2017-Sunday No activity to report. 11/20/2017- Monday No activity to report. 11/21/2017-Tuesday No activity to report. • • OF 74, • 414 I//7;4 THE STATE Alaska Oil and Gas Of LAsKA Conservation Commission 'Witt � 333 West Seventh Avenue w GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *el\ Main: 907.279.1433 ALAS 1 Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SGANNEQ 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU J-15 Permit to Drill Number: 199-107 Sundry Number: 317-397 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 AZ DATED this 17 day of August, 2017. RBDMS W AU Z 3 2017 • • RECEIVED STATE OF ALASKA AUG 1 8 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 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 Q Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Treatment' 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 199-107 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic IIIService 2. 6.API Number: Anchorage Alaska 99503 50-029-22952-00-00 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 J-15 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0315848 % 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): 7,145' 4,280' . 7,001' . 4,203' 3,500 7,001' N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' 5,020psi 2,260psi Production 7,083' 5-1/2" 7,083' 4,247' 4,810psi 4,040psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.2#/L-80/NS-CT 6,390 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker SABL-3;Baker SABL-3/N/A 6,281'MD/3,839'TVD;6,356'MD/3,876'ND/N/A 12.Attachments: Proposal Summary Q Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service El 14.Estimated Date for 15.Well Status after proposed work: 9/1/2017 Commencing Operations: OIL ❑ WINJ 0 • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ Q 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. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhoIa C(I�hiIcorp.com Contact Phone: 777-8412 Authorized Signature: Date: 8/17/2017 COMMISSION USE ONLY Conditions of approval: otify Commission so that a representative may witness Sundry Number: 3ti- 317 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS I,v Post Initial Injection MIT Req'd? Yes ❑ No El7AUS 3 2017 Spacing Exception Required? Yes El No g Subsequent Form Required: 1 u Li o 11 APPROVED BY Approved by: (CO__Q___ COMMISSIONER THE COMMISSIONDate: Z') I►q .Ria 8/211/7- x'',18._`- cef OR1G1NAL , '>/,7 g1a3v1 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 Well: MPU 1-15 Flacon)Alaska.LLQ Date:8/17/2017 Well Name: MPU J-15 API Number: 50-029-22952-00 Current Status: Water Injector Pad: Milne Point J-Pad Estimated Start Date: September 1st, 2017 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-107 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: 1,400 psi @ 4,000' TVD (Last BHP based on offset well J-01A) Maximum Expected BHP: 1,400 psi @ 4,000' TVD (No new perfs being added, EMW= 6.73 ppg) MPSP: 3,500 psi (Based on maximum surface injection pressure) Brief Well Summary: MPU J-15 was drilled with Nordic#3 in 1999 as a deviated injector in the Schrader Bluff NB, OA, and OB sands and provides support in hydraulic unit 1 for offset producer MPU J-01A(PTD 199-111).The well developed a packer leak and was repaired in 1999 by cutting the tubing and running an overshot and an additional packer. The well has had several MBE treatments that have been treated with some limited success. The most recent MBE treatment was in June 2016. Notes Regarding Wellbore Condition • Well is a deviated water injector(max hole angle 62° @ 5,500'). • Last MIT-IA to 1,680 psi on 1/05/2016. . • Confirmed MBE between MPU J-01A(ESP Oil Producer) based on red dye test. Objective: The purpose of this work/sundry is to pump a'MBE treatment and place well back on water injection. 1:1.44N "re -Je•-+J ( `e°c-') �� Brief Procedure: CL), (_ tt fco e(ea.i.-o-�.k t iJe,�;J eS Pumping Procedure: 1. Production to SI offset producers up to 5 days prior to treatment. 2. Production to SI offset injectors up to 2 days prior to treatment. 3. MIRU Cement Pumping Unit and Little Red Pumping Unit. PT lines to 4,000 psi. [TREATMENT#1] a. Setup fluid manifold to allowing switching over from Cement Unit to Little Red. 4. Perform injectivity test w/8.5 ppg fresh water. _ 1 _,-, r'g.CSA r/ ,i- a. Inject at 1.0 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. 5, Mix and bullhead the following fluids with the Cementing Unit: a. +/- 10 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. b. +/- 15 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. • • Well Prognosis Well: MPU J-15 llilcorp Ala:4(a,LU Date:8/17/2017 6. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-47.0 bbl of 1% KCL water. b. +/-20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 7. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 8. RDMO Cement Pumping Unit and Little Red Pumping Unit. 9. WOC 48 hours. 10. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#1] 11. Mix and bullhead the following fluids: AQs i a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/-20 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 12. SMO Little Red Pumping Unit. Contingency: If unable to establish injectivity: a. MIRU Slickline. PT lubricator to 4,000 psi Hi 250 psi Low. b. RIH and tag cement top. POOH. c. RIH and bail cement. POOH. C..1— d. RIH w/dump bailer and spot 15% HCI acid to dissolve cement in tubing. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). C,- s f. RIH and bail cement. POOH. g. RD Slickline. C('' 4 14. Contingency: If residual cement exists: a. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. b. Pressure test BOPE to 4,500 psi Hi 250 psi Low, 10 min each test. CP� i. Notify AOGCC 24 hrs. ii. Test using 60/40 methanol or 8.5 ppg seawater. iii. Each subsequent test of the lubricator will be to 4,000 psi Hi 250 psi Low to confirm no leaks. c. RIH w/2.00" coil w/2-1/8" wash nozzle to cement top. Circulate well w/8.5 ppg seawater. d. Continue to RIH and cleanout cement to+/-7,000' MD (PBTD). e. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 15. Contingency: If unable to cleanout cement w/wash nozzle. a. RIH w/2.25" OD mill, 2-1/8" motor, and oil jars and cleanout cement to+/-7,000' MD (PBTD). b. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 16. Contingency: If able to cleanout cement but unable to establish injectivity. a. RIH w/2-1/8" wash nozzle to+/-7,000' MD(PBTD). b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 4,000 psi. c. Mix and pump 5-10 bbl of 15% HCI acid. Displace acid w/8.5 ppg seawater. POOH. d. RD acid pumping unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. Circulate acid out of well pumping 8.5 ppg seawater. g. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 17. Contingency: If unable to establish injectivity test after HCI soak, repeat Step#16[a-g]. 18. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#2] 19. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. i i Well Prognosis Mem)Alaska,LLI Well: MPU J-15 Date:8/17/2017 20. Fluid-pack and maintain tubing pressure on offset well affected by MBE (MPU J-01A). 21. Mix and bullhead the following fluids with the Cementing Unit: a. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. +/- 10 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. 22. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-47.0 bbl of 1% KCL water. b. +1-20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 23. Discontinue maintaining tubing pressure on offset well affected by MBE (MPU J-01A). 24. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 25. RDMO Cement Pumping Unit and Little Red Pumping Unit. 26. WOC 48 hours. 27. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#2] 28. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/-20 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 29. RDMO Little Red Pumping Unit. 30. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Fluid Flow Diagram-Acidizing H . 0 Milne Point Unit Well: MPU J-15 SCHEMATIC Last Completed: 12/9/1999 PTD: 199-107 Hilcora Alaska,LLC — TREE&WELLHEAD Orig.KB Elev.:65.1'/GL Elev.:35.1'Nordic#3 Tree 3-1/8"5M FMC RKB–Tbg Spool:28.6'Nordic#3 7-1/16"5M Vetco Gray 5.5"Emergency slips Wellheadlif: Vetco Tubing Hanger 3"CIW"H"BPV profile OPEN HOLE/CEMENT DETAIL 13-3/8 13-3/8" 260 sx Arctic Set(Approx.)in a 24"Hole 490 sx Arctic Set 3,390 sx Class"G"in a 7-7/8"Hole 5-1/2" Cement to surface(46 bbl) CASING DETAIL Size Type Wt/Grade/Conn ID Drift ID Top Btm BPF 13-3/8" Conductor 68/L-80/N/A 12.415" 12.259" Surface 110' 0.1497 ;:t Lol 5-1/2" Production 15.5/1-55/BTC 4.950" 4.825" Surface 7,081' 0.0238 TUBING DETAIL —) 1 ' 3-1/2" Tubing 9.2/L-80/NS-CT 2.992" 2.867" Surf 6,390' 0.0087 WELL INCLINATION DETAIL KOP@450' Max Hole Angle=62 deg. @ 5,500' 60 Deg.to 62 Deg.1,900'to 6,300' Hole Angle thru perk=>59 Deg. JEWELRY DETAIL No Depth Item 1 2,194' 3.5"HES X-Nipple:ID=2.813" 2 6,272' 3.5"HES X-Nipple:ID=2.813" 3 6,281' 5.5"x 3.5"Baker SABL-3 Permanent Packer 4 6,297' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 5 6,308' Unique Machine Overshot–Bottom @ 6,318' 6 6,347' 3.5"HES X-Nipple:ID=2.813" 7 6,356' 5.5"x 3.5"Baker SABL-3 Permanent Packer 8 6,378' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 9 6,389' 3.5"WLEG–Bottom @ 6,390' PERFORATION DETAIL / Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT SPF Size Date Status 6,504' 6,506' 3,949' 3,950' 2 1 2-1/4" 9/05/2005 Open a 2 NB 6,513' 6,518' 3,954' 3,956' 5 6 2" 8/27/2014 Open OA 6,775' 6,795' 4,086' 4,097' 20 4 2" 12/12/1999 Open 3 6,820' 6,840' 4,109' 4,120' 20 4 2" 12/12/1999 Open OB 6,915' 6,955' 4,158' 4,179' 40 4 2" 12/12/1999 Open NinirrumID= 6,915' 6,955' 4,158' 4,179' 40 6 2" 8/27/2014 Open 2.635 @6,297 ' 4 Ref Log:SWS CBL 11/19/1999–Perf Guns:2.0"PJ 4 spf(12/12/99)/2.25"P.11 spf(9/05/05)/2.0"PJO 6 spf(8/27/14) 5 NOTE: 6 Lower packer leaked during initial completion.Tubing was cut leaving 9'pup and 9'of tubing stub above X-Nipple at 6,347'. R-' '#'a, 7 Unique Machine overshot swallowed 7 of tubing stub. IVinimam ID= 2.635"@6,378'_ ► 8 GENERAL WELL INFO 9 API:50-029-22952-00-00 2 ea 20Short Jts Drilled,Cased&Comp by Nordic 3-11/20/1999 6,461'/6,510 II Recomplete due to leaking lower packer-12/9/1999 Initial Perforations-12/12/1999 Schrader Sands Add NB Perfs–9/5/2005&8/27/2014 Cleanout w/2.6" . a mill @6.98e C 7/10/16 51/2„ %`...........:i TD=7,145'(MD)/TD=4,280(TVD) PBTD=7,000'(MD)/PBTD=4,203'(TVD) Downhole Revised:7/10/2016 Revised By:STP 7/25/2016 • • II Milne Point Unit COIL ROPE MPU J-15 8/17/2017 oikorp l84,a.i.i,t. MPU J-15 13% X 5% X 3% Coil Tubing BOP Lubricator to injection head m 2.00"Single Stripper I I Blind/Shear —41/1610 5_BIind/Shear __ _\ !I.'.I,IBlind/Shear All --Blind/Shear 114.'•" IIMIfi _— C_ Slip =a Slip •4 i 1 RUN 011411 Pipe elm =® Pipe MO 4 Eia 1111111M— a or Crossover spool 4 1/16 10M X 4 1/16 5M ons-:ff R5, ;6t,. Pump-In Sub (°):11 { . IMO 1502 Union 4 1/16 5M m ®i j .. Manual Gate Manual Gate se Crossover spool •>r 2 1/8 5M 2 1/8 5M 41/165MX31/85M Valve,Swab,WKM-M, Lk,'o ���l�' 3 1/8 5M FE \e S1 4,1\ e. s4. °) it �' m1 a Valve,Upper Master,Baker, 0, 3 1/8 5M FE,w/Hydraulic ,... ,et, Valve,Lower Master,WKM-M, r lb(-0-\*. 31/85M FE �u"ot -- A u.a-Villi IliMitil Tubing Adapter,3 1/8 5M if li • • p 1-- 2 1- Fe o a E 0 a -.1 D 1 a m . _. m . . • ..,., 0 la •:1. o •C '' cl. •• • . ... ..• • ••• •• E"73•••S ce W w ce w r•::....... • • ••• ' .,, a, ..>--' o"- .E 0 .5, ti < ce 2 < c4 Z • L7-. fil 0 1 r:,... 4i LI m < co Lo 4 k 0 )411 —1—.4-09.---r— tn 11XZZIO Li ..; a : . 0 . • z ...: -0 a . . > t. -,--t u - 0 : i •• 5 . > .?, seil 140.).;,...„ 0 i...: < •• 0 . • 2 - Q., > w < ••••. Z (11 0 74 > E r•••• C.T. ,., 1.> > ,-, ..- = NI . • (.7 , __.,› .1-.' '' 8 ,,,T, itillnik 4'...; _ :••• .) ; 0 II 'a g-0 75 r- c 3 u lir 46:: i 0 '''',4,,,,„:,,..!, • , r.t. .„.,..,.. . ..,. .. , . . ..6., op- VIIIII 1.- . . '5- -i T• o _ __ ... ,_ g ''• Et 1 i V 5 1 7 7 8. '--• I -°,I = c ,.. ...... 0 ,r_ tti::': 11 if.':: t$ EffE04-`:•41.011F_L-43 .c, •••••i..----..... ' ' All Li,i pm 1-— a - 41 rii __.1_ 7.. a ,f, u k 8 8 ca 0 o co ol .. \-7 2 4 I- 0 o Lc, 4. STATE OF ALASKA ALSA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations LI Fracture Stimulate u Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑✓ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MBE Treatment Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑ Exploratory❑ 199-107 3.Address: Stratigraphic Service Q 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22952-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0315848 MILNE PT UNIT SB J-15 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): JUL N/A MILNE POINT/SCHRADER BLUFF OIL 2 5 2016 11.Present Well Condition Summary: AOGCC Total Depth measured 7,145 feet Plugs measured 7,001 feet true vertical 4,280 feet Junk measured N/A feet Effective Depth measured 7,001 feet Packer measured 6,281 &6,356 feet true vertical 4,203 feet true vertical 3,839&3,876 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' 5,020psi 2,260psi Production 7,083' 5-1/2" 7,083' 4,247' 4,810psi 4,040psi Perforation depth Measured depth See Attached Schematic Ma True Vertical depth See Attached Schematic �� Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/NS-CT 6,390' 3,892' Baker SABL-3 Packers and SSSV(type,measured and true vertical depth) Baker SABL-3 N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 411 20 479 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 ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q 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: 316-066 Si"? Contact Stan Porhola Email sporhola(U7hilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 7/25/2016 "i 74_x.6 /1 3/-7.4. Form 10-404 Revised 5/2015 RBDMS V JUL 2 6 2016 Submit Original Only • Milnll:e PointMPU Unit We ' SCHEMATIC Last Completed: 12/9/1999 Hileorp Alaska,LLC PTD: 199-107 TREE&WELLHEAD Orig.KB Elev.:65.1'/GL Elev.:35.1'Nordic#3 Tree 3-1/8"5M FMC RKB Ts:Spool:28.6'Nordic#3 7-1/16"5M Vetco Gray 5.5"Emergency slips R k Wellhead ke Vetco Tubing Hanger 3"CIW"H"BPV profile `° OPEN HOLE/CEMENT DETAIL I. 13-3/8" 1� 13-3/8" 260 sx Arctic Set(Approx.)in a 24"Hole ? h 490 sx Arctic Set 3,390 sx Class"G"in a 7-7/8"Hole 5-1/2" Cement to surface(46 bbl) kF 'i ' k CASING DETAIL to Size Type Wt/Grade/Conn ID Drift ID Top Btm BPF 13-3/8" Conductor 68/L-80/N/A 12.415" 12.259" Surface 110' 0.1497 4, 5-1/2" Production 15.5/J-55/BTC 4.950" 4.825" Surface 7,081' 0.0238 0TUBING DETAIL i t 1 ' 3-1/2" Tubing 9.2/L-80/NS-CT 2.992" 2.867" Surf 6,390' 0.0087 WELL INCLINATION DETAIL is ti KOP @ 450' Max Hole Angle=62 deg. @ 5,500' 41 60 Deg.to 62 Deg.1,900'to 6,300' Hole Angle thru perfs=>59 Deg. to' i4,. JEWELRY DETAIL to No Depth Item -, 1 2,194' 3.5"HES X-Nipple:ID=2.813" 2 6,272' 3.5"HES X-Nipple:ID=2.813" to :4 3 6,281' 5.5"x 3.5"Baker SABL-3 Permanent Packer t" # 4 6,297' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 5 6,308' Unique Machine Overshot—Bottom @ 6,318' xl 6 6,347' 3.5"HES X-Nipple:ID=2.813" ,.: so 7 6,356' 5.5"x 3.5"Baker SABL-3 Permanent Packer 4 8 6,378' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 4 9 6,389' 3.5"WLEG—Bottom @ 6,390' 4 zm, Y;; PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status NB 6,504' 6,506' 3,949' 3,950' 2 1 2-1/4" 9/05/2005 Open 2 st6,513' 6,518' 3,954' 3,956' 5 6 2" 8/27/2014 Open 6,775' 6,795' 4,086' 4,097' 20 4 2" 12/12/1999 Open k' OA 6,820' 6,840' 4,109' 4,120' 20 4 2" 12/12/1999 Open it i 6,915' 6,955' 4,158' 4,179' 40 4 2" 12/12/1999 Open NinimamlD '> OB 6,915' 6,955' 4,158' 4,179' 40 6 2" 8/27/2014 Open 2.635'@6,297 a Ref Log:SWS CBL 11/19/1999—Perf Guns:2.0"PJ 4 spf(12/12/99)/2.25"P.11 spf(9/05/05)/2.0"PJO 6 spf(8/27/14) A NOTE: .', F Lower packer leaked during initial completion.Tubing was cut in • leaving 9'pup and 9'of tubing stub above X-Nipple at 6,347'. '" ' ' * 7 Unique Machine overshot swallowed 7'of tubing stub. 44 Minimum ID= t I '' Zs35'@6,378 8 GENERAL WELL INFO t 9 API:50-029-22952-00-00 2ea20 ShorlJls Drilled,Cased&Comp by Nordic 3-11/20/1999 6,461'/6,510 Recomplete due to leaking lower packer-12/9/1999 4 Initial Perforations—12/12/1999 Tag Fill‘Al 1 5' ' Schrader Sends Add NB Perfs—9/5/2005&8/27/2014 bailer @6.923' l;A W9/18/14 l ...„.....vs,.. y � I. 5-112 ,...,.-,. TD=7,145'(MD)/TD=4,280(TVD) PBTD=7,000'(MD)/PBTD=4,203'(TVD) Revised By:STP 1/12/2016 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPJ-15 50-029-22952-00-00 199-107 6/27/16 6/27/16 Daily Operations: 6/22/2016 -Wednesday No activity to report. 6/23/2016-Thursday No activity to report. 6/24/2016- Friday No activity to report. 6/25/2016-Saturday No activity to report. 6/26/2016 -Sunday No activity to report. 6/27/2016- Monday MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 4,000 psi-test OK. Perform injectivity test at 1.0 bpm @ 620 psi. Mix and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/47.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 20 bbl of diesel. SD Pumps. Monitor well. Final SITP of 1,040 psi. RDMO Cement Pump Unit& Little Red Pump Unit. Move to J-19A. 6/28/2016-Tuesday No activity to report. OFT • • \\\1%%i 4N THE STATE Alaska Oil and Gas w — ofL � �, Conservation Commission � == 333 West Seventh Avenue _� .STM,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS"- Fax: 907.276.7542 ANNEV FE , , 'n SC www.aogcc.alaska.gov Bo York Operations Manager r 0�J Hilcorp Alaska, LLC ( (�' ` J 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-15 Permit to Drill Number: 199-107 Sundry Number: 316-066 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. oerster Chair DATED this.3 day of February, 2016. RBDMS FEBl,i.- 0 4 2016 • • RECEIVED STATE OF ALASKA FEB 01 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 075 Z 1� APPLICATION FOR SUNDRY APPROVALS OG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ . Other Stimulate ❑✓ . Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re'er�fer Susp-Nelllit Alter Casing ❑ Other. MBE Treatment Q. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC • Exploratory ❑ Development ❑ 199-107 3.Address: Stratigraphic ❑ Service Q, 6.API Number: 3800 Centerpoint Dr,Suite 1400,Anchorage AK,99503 50-029-22952-00-00 • 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-15 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0315848 . 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): 7,145' - 4,280' - 7,001' • 4,203' 3,500 r.c., 7,001' N/A Casing Length Size MD ND Burst Collapse Conductor 110' 13-3/8" 110' 110' 5,020psi 2,260psi Surface Intermediate Production 7,083' 5-1/2" 7,083' 4,247' 4,810psi 4,040psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic. See Attached Schematic 3-1/2" 9.2#/L-80/NS-CT 6,390 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): , Baker SABL-3;Baker SABL-3/N/A 4 6,281'MD/3,839'TVD;6,356'MD/3,876'TVD/N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic ❑ Development❑ Service 0 ` 14.Estimated Date for 15.Well Status after proposed work: 2/12/2016 Commencing Operations: OIL ❑ WINJ ❑., . WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola .`,• Email sporhola@hilcorp.com Printed Name Bo York Title Operations Manager Signature li Phone 777-8345 Date 1/29/2016 /' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. if-i 3 l l�. - O Co C,, Plug Integrity ❑ BOP Test I Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,} Lf SCS pc: .1-3 a i' 7:3"- c C'T7i Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No LrJ Subsequent Form Required: /0-4/011. APPROVED BY Approved by: Ake / ,,Z.ti. COMMISSIONER THE COMMISSION Date: Z. -3 / L a-Z' /(e, 4M ,JI r Submit Form and Form 10-403 ReVed 11/2015 OpRvidGpicNn iralid for 12 months fromgg315tg ip u LvaLFEB 0 4 2016ttachments in Duplicate • • Well Prognosis Well: MPU J-15 Hilcorp Alaska,LL) Date: 1/29/2016 Well Name: MPU J-15 API Number: 50-029-22952-00 Current Status: SI Water Injector Pad: Milne Point J-Pad Estimated Start Date: February 12th, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-107 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: 1,400 psi @ 4,000' TVD (Last BHP based on offset well J-01A) Maximum Expected BHP: 1,400 psi @ 4,000' TVD (No new perfs being added, EMW= 6.73 ppg) ✓ MPSP: 3,500 psi (Based on maximum surface injection pressure) Brief Well Summary: MPU J-15 was drilled with Nordic#3 in 1999 as a deviated injector in the Schrader Bluff NB, OA, and OB sands and provides support in hydraulic unit 1 for offset producer MPU J-01A (PTD 199-111). The well developed a packer leak and was repaired in 1999 by cutting the tubing and running an overshot and an additional packer.The well has had several MBE treatments that have been treated with some limited success. Notes Regarding Wellbore Condition • Well is a deviated water injector(max hole angle 62° @ 5,500'). • Last MIT-IA to 1,680 psi on 1/05/2016. • Shut-in water injection due to previous MBE (Matrix Bypass Event). J • Confirmed MBE between MPU J-01A(ESP Oil Producer) based on increased water cuts in the producer, coming from water injection into the OA sands. Objective: The purpose of this work/sundry is to pump a MBE treatment and place well back on water injection. / Brief Procedure: Pumping Procedure: 1. Production to SI offset producers up to 5 days prior to treatment. 2. Production to SI offset injectors up to 2 days prior to treatment. 3. MIRU Cement Pumping Unit and Little Red Pumping Unit. PT lines to 4,000 psi. [TREATMENT#1] a. Setup fluid manifold to allowing switching over from Cement Unit to Little Red. 4. Perform injectivity test w/8.5 ppg fresh water. a. Inject at 1.0 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. 5. Mix and bullhead the following fluids with the Cementing Unit: / a. +/- 10 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. b. +/- 15 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC (hydroxy ethyl cellulose)tail spacer pill. . • Well Prognosis Well: MPU J-15 Hilcorp Alaska,LL Date: 1/29/2016 d. Drop foam ball. 6. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-47.0 bbl of 1% KCL water. b. +/- 20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 7. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 8. RDMO Cement Pumping Unit and Little Red Pumping Unit. 9. WQC 48 hours. 10. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INACTIVITY TEST#1] 11. Mix and bullhead the following fluids: a. +/- 5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. l<- d. <d. +/-20 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 12. RDMO Little Red Pumping Unit. 13. Contingency: If unable to establish injectivity: a. MIRU Slickline. PT lubricator to 4,000 psi Hi 250 psi Low. b. RIH and tag cement top. POOH. V. RIH and bail cement. POOH. Diqv,- d. RIH w/dump bailer and spot 15% HCI acid to dissolve cement in tubing. `p{I' e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. RIH and bail cement. POOH. g. RD Slickline. 14. Contingency: If residual cement exists: a. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. b. Pressure test BOPE to 4,500 psi Hi 250 psi Low, 10 min each test. I. Notify AOGCC 24 hrs. G/ ii. Test using 60/40 methanol or 8.5 ppg seawater. iii. Each subsequent test of the lubricator will be to 4,000 psi Hi 250 psi Low to confirm no leaks. c. RIH w/2.00" coil w/2-1/8" wash nozzle to cement top. Circulate well w/8.5 ppg seawater. d. Continue to RIH and cleanout cement to +/-7,000' MD (PBTD). e. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 15. Contingency: If unable to cleanout cement w/wash nozzle. a. RIH w/2.25" OD mill, 2-1/8" motor, and oil jars and cleanout cement to+/-7,000' MD (PBTD). c. b. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 16. Contingency: If able to cleanout cement but unable to establish injectivity. a. RIH w/2-1/8" wash nozzle to+/-7,000' MD (PBTD). b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 4,000 psi. c. Mix and pump 5-10 bbl of 15% HCI acid. Displace acid w/8.5 ppg seawater. POOH. d. RD acid pumping unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. Circulate acid out of well pumping 8.5 ppg seawater. g. RU to test injectivity thru the tubing tail. Do not exceed 35.500 p..L_2.00H. 17. Contingency: If unable to establish injectivity test after HCI soak, repeat Step#16[a-g]. 18. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#2] • • Well Prognosis Well: MPU J-15 Ilileorp Alaska,LLQ Date: 1/29/2016 19. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. 20. Fluid-pack and maintain tubing pressure on offset well affected by MBE (MPU J-01A). 21. Mix and bullhead the following fluids with the Cementing Unit: a. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. +/- 10 bbl of 15.8 ppg acid soluble cement. c. +/- 5 bbl of 100 ppt HEC (hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. 22. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-47.0 bbl of 1% KCL water. b. +/- 20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 23. Discontinue maintaining tubing pressure on offset well affected by MBE (MPU J-01A). 24. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 25. RDMO Cement Pumping Unit and Little Red Pumping Unit. 26. WOC 48 hours. 27. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#2] 28. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/- 20 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 29. RDMO Little Red Pumping Unit. 30. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Fluid Flow Diagram -Acidizing • • Milne Point Unit 14Well: MPU J-15 SCHEMATIC Last Completed: 12/9/1999 Hilcorp Alaska,LLC PTD: 199-107 TREE&WELLHEAD Orig.KB Elev.:65.1'/GL Elev.:35.1'Nordic#3 Tree 3-1/8"5M FMC RKB—Tb&Spool:28.6'Nordic#3 7-1/16"5M Vetco Gray 5.5"Emergency slips j ik 1, 4' Wellhead J f Vetco Tubing Hanger 3"CIW"H"BPV profile Q OPEN HOLE/CEMENT DETAIL • 13-3/8" 260 sx Arctic Set(Approx.)in a 24"Hole 13-3/g 490 sx Arctic Set 3,390 sx Class"G"in a 7-7/8"Hole i 5-1/2" r Cement to surface(46 bbl) CASING DETAIL N'iSize Type Wt/Grade/Conn ID Drift ID Top Btm BPF 13-3/8" Conductor 68/L80/N/A 12.415" 12.259" Surface 110' 0.1497 5-1/2" Production 15.5 0-55/BTC 4.950" 4.825" Surface 7,081' 0.0238 `; TUBING DETAIL 6 e 1 '4, 3-1/2" Tubing 9.2/L-80/NS-CT 2.992" 2.867" Surf 6,390' 0.0087 sl WELL INCLINATION DETAIL KOP @ 450' ' Max Hole Angle=62 deg. @ 5,500' 60 Deg.to 62 Deg.1,900'to 6,300' Hole Angle thru perfs=>59 Deg. JEWELRY DETAIL No Depth Item 1 2,194' 3.5"HES X-Nipple:ID=2.813" 2 6,272' 3.5"HES X-Nipple:ID=2.813" , 3 6,281' 5.5"x 3.5"Baker SABL-3 Permanent Packer 4 6,297' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" 5 6,308' Unique Machine Overshot—Bottom @ 6,318' ,V f 6 6,347' 3.5"HES X-Nipple:ID=2.813" '7 6,356' 5.5"x 3.5"Baker SABL-3 Permanent Packer 8 6,378' 3.5"HES XN-Nipple:Packer Bore 2.750",ID=2.635" r: ,° 9 6,389' 3.5"WLEG—Bottom @ 6,390' PERFORATION DETAIL • L',7 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status F 6,504' 6,506' 3,949' 3,950' 2 1 2-1/4" 9/05/2005 Open 2 NB 6,513' 6,518' 3,954' 3,956' 5 6 2" 8/27/2014 Open 1 6,775' 6,795' 4,086' 4,097' 20 4 2" 12/12/1999 Open OA 6,820' 6,840' 4,109' 4,120' 20 4 2" 12/12/1999 Open jik OB 6,915' 6,955' 4,158' 4,179' 40 4 2" 12/12/1999 Open MnimumID= 6,915' 6,955' 4,158' 4,179' 40 6 2" 8/27/2014 Open 2.635 @6'297 10.; : k Ref Log:SWS CBL 11/19/1999—Perf Guns:2.0"PJ 4 spf(12/12/99)/2.25"PJ 1 spf(9/05/05)/2.0"PJO 6 spf(8/27/14) e/ o� NOTE: al I E00 Lower packer leaked during initial completion.Tubing was cut � , leaving 9'pup and 9'of tubing stub above X-Nipple at 6,347'. ' . 7 Unique Machine overshot swallowed 7'of tubing stub. MnimumID= ;` w 2.635 '@6,378 I s , at GENERAL WELL INFO 9 API:50-029-22952-00-00 2 ea 20'Short.Its 5o Drilled,Cased&Comp by Nordic 3-11/20/1999 6,461'/6,510' w. 6 6,,4 �^ Recompletedue toleaking lower packer—12/9/1999 ilk 06 Initial Perforations—12/12/1999 Tag Fill w'1.5' _ ,;•4 -•- Sands Add NB Perfs—9/5/2005&8/27/2014 bailer @6.923 r; ND 9/18/14 - ,,c 5-1/2 ,4" TD=7,145'(MD)/TD=4,280(TVD) PBTD=7,000'(MD)/PBTD=4,203'(TVD) Revised By:STP 1/12/2016 • • II Milne Point Unit COIL BOPE MPU J-15 12/30/2015 flilrorp%bs4 a.LLC MPU J-15 13% X 5% X 3% Coil Tubing BOP n Lubricator to injection head T-0 2.00"Single Stripper 11 1 1 Pills Blind/Shea = 1/1610 !:BhmndI5he& 1I11 rommi I _1h1hI Blind/Shear - 1E1E14 !mom 0 Mine 0G0 =Emilie r_ —— Slip �— Ell l• Slip Ill" II 6111111.1 iimmL RENE •LI,I Pipe Illim Pipe HI MEOW 6 F Crossover spool 4 1/16 10M X4 1/16 5M � Pump In Sub u-: (� r 7.P 1502 Union 41/16 5M ���/// Manual Gate Manual Gate Crossover spool 2 1/8 5M 2 1/8 5M 4 1/16 5M X3 1/8 5M On Valve,Swab,WKM-M, A®; w, �4LO 3 1/8 5M FE `�dr 3�`��A� F� qls ASA tie,- 3a g r{ , Valve,Upper Master,Baker, 3 1/8 5M FE,w/Hydraulic . A 00107.71 Valve,Lower Master,WKM-M, r 3 1/8 5M FE ilimposwiti Tubing Adapter,3 1/8 5M 0 0 1- I I- 0 I 2 Lo 0_ 2 e D 13. •E' g m m m f.i:::".....1 ,.„:..... 1 .„... . tt I' a F. 3 •• • ..- .5 > > (..) ____, .• = .T..–9 ..::***.• '6 '') > g R w ce u., (....- V/ VI DA' ‘) '1- 4.1-.- I X Z Z 0 -C.... 3 2 ! n en --•... 0 • -o c._ 1/4., °- III 0 ' : dOr-Tll",bh •••; i I 4 a. 0 2 i w -10110T4M11- 1 III.- , 2 -1161 A . _ V ._ ! 7 i•7 1,----- ts' a ° 1, -,-- .„,. wrIper , 00,, 1.11 I I"1 — .2. ....--1 , g g !A hi PO il E H — . . -r4 -0, o o 0 0 ct 1-2 co 0 o m In „,_ 7 z .4 . LA 2 .... m co 8 0 e. 4 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,January 07,2016 TO: Jim Regg —� P.I.Supervisor 1 I 1411(e SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J-15 FROM: Matt Hen-era MILNE PT UNIT SB J-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry i NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB J-15 API Well Number 50-029-22952-00-00 Inspector Name: Matt Herrera Permit Number: 199-107-0 Inspection Date: 1/5/2016 Insp Num: mitMFH160106131020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J-15 Type Inj W'TVD 3839 - Tubing 419 - 426 - 421 - 422 - PTD 1991070 Type Testt PT Test psi 1500 - IA 628 1683 1631 - 1631 - Interval 4YRTST P/F P / OA Notes: Test to 1650 Per Operator's request.Monobore completion,no OA sapitiED Thursday,January 07,2016 Page 1 of 1 • 6w\�4\I7 j,�sN THE STATE Alaska Oil and Gas In ALASKA Conservation Commission GOVERNOR SEAN PARNELL F � 333 West Seventh Avenue OA, e, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Alicia Wood CANNED i' , N Pad Engineer j Q BP Exploration (Alaska), Inc. 1 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPJ-15 Sundry Number: 313-510 Dear Mr. Wood: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P444/1/•- Cathy P. oerster Chair, Commissioner DATED this day of September, 2013. Encl. 5,� STATE OF ALASKA '�- �4� ALASKA OIL AND GAS CONSERVATION COMMISSION DI S wckl2 f 6 APPLICATION FOR SUNDRY APPROVALS ' 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: MBE Treatment . 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 199-107-0, 3.Address: Stratigraphic ❑ Service El+ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22952-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? SBL MPJ-15 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0315848 . MILNE POINT,SCHRADER BLFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7145 -, 4280 ' '7000 ,4203 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 13-3/8"68#L-80 31-111 31-111 Surface None None None None None None Intermediate None None None None None None Production 7053 5-1/2"15.5#J-55 30-7083 30-4246.85 4810 4040 Liner None None None None None None I Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 1 5t4. 444,6504-6506 3949.11-3950.12 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths/ No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 . BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ El • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Alecia.Wood @BP.Com Printed Name Alecia Wood Title Pad Engineer tili Signature Phone 564-5492 Date Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 1\ ' J`C) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RE3nMS, OCT 1 0 24 Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: /V 4..0 4 APPROVED BY Approved by: /9 9„,,,,,i4,....__ COMMISSIONER THE COMMISSION Date: Q, zs Form 10-403 Revised 10/2012 Approved application is valid for 12 months from the date of approval. Submit Form and Attachmen ' Icat '1/24-113 - Casing Summary ADL0315848 Casing Length Size MD Top MD Base ND Top ND Base Burst Collapse Grade CONDUCTOR 80 13-3/8"68# L-80 31 111 31 111 5020 2260 L-80 PRODUCTION 7053 5-1/2" 15.5#J-55 30 7083 30 4247 4810 4040 J-55 TUBING 6298 3-1/2"9.2# L-80 29 6327 29 3861 10160 10530 L-80 TUBING 63 3-1/2" 9.2# L-80 6327 6390 3861 3892 10160 10530 L-80 • • • Packers and SSV's Attachment ADL0315848 Well Facility Type MD Top Description TVD Top MPJ-15 PACKER 6281 3-1/2" Baker SABL-3 Packer 3839 MPJ-15 PACKER 6356 3-1/2" Baker SABL-3 Packer 3875 • • . bp To: Mark O'Malley/Rob Handy Date: September 18, 2013 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907-564-5492 Subject: MPJ-15 Preventative MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPJ-15 2 F Bullhead treatment down MPJ-15 (OA sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. OBJECTIVE On average, cement and polymer MBE treatments break down after -6 months. This treatment has been holding for one year. The objective of this polymer job is to extend the life of the successful 2012 MBE treatment by pumping a preventative polymer job. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPJ-15 was drilled and completed as an unregulated OA/OB injector in 1999. A packer leak required that the tubing be cut and an overshot with new packer be run immediately after completion. In 2005 2' of perforations were added to the N-sand to help support the heel of MPJ-25. The limited interval and pert density was used in an attempt to control the injection into what should have been a thief zone. The injector is the sole supporter for MPJ-01A (250 IOR) and helps to support MPJ-25 (30010R). An MBE was first noted in MPJ-15 to MPJ-01A in 2009 however it did not become catastrophic until April 2012 when the wellhead injection pressure fell to 500psi. In March 2012 the tubing and IA pressures began to converge but the well passed an MIT-IA to 2000psi and remains operable. An IPROF was performed July 6th 2012 which identified the MBE to MPJ-01A in the OA sands with the OB completely covered with fill. In September of 2012 a Thermatek and H2Zero MBE treatment was pumped that was successful in reducing injectivity of J-15 and reducing the WC of J-01A. The injectivity in J-15 has since increased, although the WC in J-01A has remained steady. • PROCEDURE Stage 1. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre-flush followed by high volume gel treatment and diesel over flush. 7. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 8. Rig down all equipment and hold post job assessment meeting to capture [earnings to be incorporated into future jobs. 9. Forward all post job assessments (w/all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • . • • ill . _ 111E; 3 1/8"-5M FMC MPU J-151 Orig.KB Bev.= 65.1'Nordic#3 Wellhead;7-111.5° 5A4 Vetco gray Orig.GL Bev.= 35.1' 5.5"Emergency slips. Vetco Tbg. RT To Msg.Spool=MO Nordic#3 Hng.,threads top and bottom,3' CM' .Er BPV profile KOP P. 450 a 3.5'HES X-Nipple(2.8135d) 2- Max.hole angle=62 deg.4.11.1 5.500' 60 deg.to 62 deg.(1900'-6,300, Hole angle thru'pens=>59 deg.. 3.5"9.3 ppr, L-80 NSCT tubing (cap.=0.0087 DO,drift=2.867' 5.5"15.5 ppf,J-55, Btrc prod.casing (drift ID=4..950",cap.=0.0M8 bpf) a 3.5•HES X-ttippila(2.213id.1 9272' I 6.6' 3.5'Behar SABL-3 ••■•■■■ 9291' ..,- Perm OM • Note:Lower teswaver Waked during Initial N- acespiation.Tubing wee sett terming 9'PUP ill 9 9'.-t,ES XN-Nipple 8297' t 2.710'pk.bons.2.1935°d 1 and 9 of kibing co4b abeme X nipple at 9347. Unique Mannino overahot oWillikalleil 1" tubing stub. Unique Mahn.ormrahae 9319' = III 3_5'NES X-Nip pie(2.913id I 9347' Perforation Starirnary 111 - Z Ref log:SWS CBL dated 11119199 6..6•*3.5"Baker SABL4 6356' ememir Perm pia. Size SPf Irrearral rival 111- 2' 1 9504-65013' 3949-3060' all 3.6'HES XN-Nippla 2' 4 6775'4971M' 4179T-4090' (2.750'plc bare 2.836°M ill 2° 4 69:0'49,10' 41074118' WLEG 2° 4 091E49E6" 4155-4175' 1 6303' 2-20'short joints 9461'4510' 5.5'float collar(PBTO) 700 0' ',:..:,...:.:,:•1';':.:.::.•:."..'..X.:;,X.'..: 5.5"float shoe 71121' DATE REV.BY COMMENTS MILNE POINT UNIT 11/19(99 k0210 Drilled and cased&completed Nordic#3 WELL..11-15i 12_009 M.Linder nocernpleted OUP ICI Mame;beer pooker API No:50-029-22952 1.211203 M.Lender initial petionatione. 99/09 Lee field's Add N5 Paris BP EXPLORATION (AK) RECEIVED 1 , STATE OF AKA OIL AND GAS CONSERVATION COMMISSION UL ! .1 2 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate L( Other Li MBE Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdowr0 Stimulate - Other ❑ Re -enter Suspended WeIf 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ 199 -107 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number:, Anchorage, AK 99519 -6612 50- 029 - 22952 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: v ADL0315848 SBL MPJ -15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): . To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 7145 feet Plugs measured None feet true vertical 4280.29 feet Junk measured None feet Effective Depth measured 7000 feet Packer measured See Attachment feet i true vertical 4202.63 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 13 -3/8" 68# L -80 31 - 111 31 - 111 5020 2260 Surface None None None None None None Intermediate None None None None None None Production 7053 5 -1/2" 15.5# J -55 30 - 7083 30 - 4246.85 4810 4040 Liner None None None None None None Perforation depth Measured depth 6504 - 6506 feet 6775 - 6795 feet 6820 - 6840 feet 6915 - 6955 feet True Vertical depth 3949.11 - 3950.12 feet 4086.32 - 4096.55 feet 4109.36 - 4119.6 feet 4158.16 - 4178.98 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JAN 2 8 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 839 0 519 Subsequent to operation: 0 0 526 0 869 14. Attachments: 15. Well Class after work: - r Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas U WDSPIU 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: 312 -282 Contact Nita Summerhays Email Nita.Summer bos om Printed Name Nita Summerhays Title Petrotechnical Data Technician Signs ri �� / . A I A / /.r►. Phone 564 -4035 Date 10/11/2012 Rg MS OCT 15 ' 2012 , to .rli_ Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0315848 ACTIVITYDATE ( SUMMARY ero rea men on rom • on inue pumping ' ero rea men a ` .6 • pm `° •■ 890 psig Pumped a total of 423 bbls of H2 Zero at a final rate of 1.0 bpm @ 930 psig WHP. Displace H2 Zero to formation with 70 bbls produced water followed by 10 bbls of 50/50 meth - water. Final injection at 1.0 bpm @ 900 psig WHP. Shut -in and secure well. RD HES. .... Job Complete 9/22/2012 FLUIDS PUMPED BBLS 423 H2ZERO 70 PRODUCED WATER 10 50/50 METH 503 TOTAL • • • Packers and SSV's Attachment ADL0315848 SW Name Type MD TVD Depscription MPJ -15 PACKER 6281 3773.85 3 -1/2" Baker SABL -3 Packer MPJ -15 PACKER 6356 3810.33 3 -1/2" Baker SABL -3 Packer Casing / Tubing Attachment ADLO315848 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 13 -3/8" 68# L -80 31 - 111 31 - 111 5020 2260 PRODUCTION 7053 5 -1/2" 15.5# J -55 30 - 7083 30 - 4246.85 4810 4040 TUBING 6298 3 -1/2" 9.2# L -80 29 - 6327 29 - 3861.31 10160 10530 TUBING 6298 3 -1/2" 9.2# L -80 29 - 6327 29 - 3861.31 10160 10530 TUBING 63 3 -1/2" 9.2# L -80 6327 - 6390 3861.31 - 3892.09 10160 10530 • • 1 Tree: 3 1/8" - 5M FMC • 15i OrigElev. = 65.1' Nordic #3 Wellhead:7- 1/16" 5M Vetco gray MPU J Orig. GL Elev. = 35.1' 5.5" Emergency slips, Vetco Tbg. 'x RT To Tbg. Spool = 28.6' Nordic #3 z z Hng., threads top and bottom, 3" CIW "H" BPV profile KOP @ 450' I 3.5" HES X- Nipple ( 2.813 "id) 2194' Max. hole angle = 62 deg. @ 5,500' 60 deg. to 62 deg. (1900' - 6,300') Hole angle thru' perfs = > 59 deg. r ; ; A 3.5" 9.3 ppf, L -80 NSCT tubing (cap. = 0.0087 bpf, drift = 2.867' 5.5" 15.5 ppf, J -55, Btrc. prod. casing ( drift ID = 4.950 ", cap. = 0.0238 bpf) 3.5" HES X- Nipple ( 2.813 "id) 6272' is 5.5 "x 3.5" Baker SABL -3 6281' Perm pkr. Note: Lower packer leaked during initial completion. Tubing was cut leaving 9' pup 3.5" HES XN- Nipple 6297' and 9' of tubing stub above X nipple at 6347'. (2.750" pk. bore. 2.635 "id ) Unique Machine overshot swallowed 7' of tubing stub. Unique Machine overshot 6318' k : 3.5" HES X- Nipple ( 2.813 "id) 6347' Perforation Summary Ref log: SWS CBL dated 11/19/99 • 5.5"x 3.5" Baker SABL -3 6356' Perm pkr. Size SPF Interval (TVD) 2" 1 6504' -6506' 3949' -3950' 3.5" HES XN- Nipple 6378' 2" 4 6775'- 6795' 4087' -4096' ( 2.750" pk. bore. 2.635 "id ) 2" 4 6820' -6840' 4109' -4118' 1 WLEG 6390' ii i■ 2" 4 6915' -6955' 4158' -4178' 1: i ■ u i• 9 i• • n n is n 1• 2 -20' short joints 6461' -6510' : : 1 ■ ii 11 i■ 11 i■ n ;; II 5.5' float collar (PBTD) 7000' 11 5.5' float shoe 7081' DATE REV. BY COMMENTS MILNE POINT UNIT 11/19/99 MDO Drilled and cased & completed Nordic #3 WELL J - 15i 12/9/99 M. Linder Recompleted due to leaking lower packer API No: 50 -029 -22952 12/12/99 M. Linder Initial perforations. 9/5/05 Lee Hulme Add NB Perfs BP EXPLORATION (AK) • 1 3 - 1 , h F L SEAN PARNELL, GOVERNOR CYO U ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION RVA1IO1s COM IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Alecia Wood Production Engineer 07 BP Exploration (Alaska), Inc. I �I P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPJ -15 Sundry Number: 312 -282 Dear Ms. Wood: SLf N ED AUG 0 8 202 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '' . Foerster Chair / S DATED this I day of August, 2012. Encl. II a �/ RECEIVED STATE OF ALASKA JUL 2 5 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION ® ^ � G APPLICATION FOR SUNDRY APPROVALS ('� 20 ARC 25.280 1. Type of Request: Abandon ❑ Rug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations it 1/C'. , i \1 Perforate 0 Put: Tubing ❑ Ti . j x t sion (� , Operations Shutdown ❑ Re -enter Susp. Well ❑ `r " Stimulate ❑ Alter Casing ❑ Other. •�ytgl/M1ll 2. Operator Name: 4. Current Well Cass: 5. Permit to Dnit Number BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 199 -107-0 ' 3. Address: Stratigraphic ❑ Service © - 8. API Number P.O. Box 196612, Anchorage, AK 99519 -6612 50- 029 - 22952 - 00-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No E MPJ-15 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0315848 • MILNE POINT, SCHRADER BLFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7145 . 4280 7000 4203 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 13 -3/8" 68# L -80 31 - 111 31 - 111 Surface None None None None None None Intermediate None None None None None None Production 7053 5 -1/2" 15.5# J -55 30 - 7083 30 - 4246.85 4810 4040 Liner None None None None None None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSV Installed No SSV Installed 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 Service © - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ IS 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 Prepared by Garry Catron 564 -4424 Printed Name Alecia Wood Title Production Engineer Signature __ �y Phone Date C�he �t r (l1 5 /6)6%/, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2 ca z Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 Other: Subsequent Form Required: /1 ) t — F 4 APPROVED BY Approved by: , L, A',., COMMISSIONER THE COMMISSION Date: e•" to_ Z- VL OR1GINAIL A IIS AUG 0 1 zog . i or / ' 7/Ate p Form 10-403 Revised 1/2010 7 ./ 3 i% � Z ubmit in Duplicate A • Packers and SSV's Attachment AD L0315848 Well Facility Type MD Top Description TVD Top MPJ -15 PACKER 6281 3 -1/2" Baker SABL -3 Packer 3839 MPJ -15 PACKER 6356 3 -1/2" Baker SABL -3 Packer 3875 • • Perforation Attachment ADL0315848 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPJ -15 9/5/05 APF 6504 6506 3949 3950 MPJ -15 12/12/99 PER 6775 6795 4086 4097 MPJ -15 12/12/99 PER 6820 6840 4109 4120 MPJ -15 12/10/99 PER 6915 6955 4158 4179 - AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 1 • • Casing Summary ADL0315848 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse CONDUCTOR 80 13 -3/8" 68# L -80 31 111 31 111 5020 2260 PRODUCTION 7053 5 -1/2" 15.5# J -55 30 7083 30 4247 4810 4040 TUBING 6298 3 -1/2" 9.2# L -80 29 6327 29 3861 10160 10530 TUBING 63 -1/2" 9.2# L -80 6327 6390 3861 3892 10160 10530 U G 3 3 by • • 0 To: Mark O'Malley /Rob Handy Date: July 06, 2012 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPJ -15 MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPJ -15 2 F Bullhead treatment down MPJ -15 (OA sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPJ -15 was drilled and completed as an unregulated OA/OB injector in 1999. A packer leak required that the tubing be cut and an overshot with new packer be run immediately after completion. In 2005 2' of perforations were added to the N -sand to help support the heel of MPJ -25. The limited interval and pert density was used in an attempt to control the injection into what should have been a thief zone. The injector is the sole supporter for MPJ -01A (250 IOR) and helps to support MPJ -25 (300 IOR). An MBE was first noted in MPJ -15 to MPJ -01A in 2009 however it did not become catastrophic until April 2012 when the wellhead injection pressure fell to 500psi. In March 2012 the tubing and IA pressures began to converge but the well passed an MIT -IA to 2000psi and remains operable. An (PROF was performed July 6 2012 which identified the MBE to MPJ -01A in the OA sands with the OB completely covered with fill. • • PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post -job assessment meeting to capture (earnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • • Tree; 3 118" - 5M FMC MPU J-15i 1Drig. KB Bev. = 65.1' Nordic *3 Wellhead; 7-1116 51441 Vetco way Orig. GL Elev. = 5.5" Emergency shwa, Vetco Tbg. RT To Tbg. Spool = 28.6 Nordic Hng., threads top and bottom. 3"'• C1W BPV waffle KOP 450" 35 HES X-Nipple C 22131d) 21S4,. Max. hole angle = 62 deg. 2' 5,500' 60 deg. to 62 deg. (1800' - 6,300) Hole angle i perfa >50 eiLeg. 85" 8.3 ppf, L-80 NSCT titising (cap. = 0.0087 bpi, drift = 2.867' 5.5" l55 pp J-55, 8Irc_ prod_ casing ( drift ID = 4.050", cap. = 0.08 bpf ) 3.5° HES X-Naania4 2_8131d ) IfL"72' I 5.6 'At 3E' &akar SABL-3 5261' I P411719 Oa, Naas: Lamar taankar lsakad during nitiJ uoinaIation. Tubng was out leaving t pug al /V 'HES XN-Naais e " .- ' 2.755'0. bora. 2.8351d and ff of tubng oath obeys X mania at 5347. Unicnua Maohna overshot aaI 441;417'0, tubing ;nab. Unique Manhaa aranahat sal a I • 3.5' HES X-Niapts 2.513V 6347 Perforation Summary fielL1Q9'...SVILSS.4810datittELlidaggl 6.6443.5' Balm SABL emer I Pam 4as SPf Inkarval rrio) 3.5' HES XN-Nandia 6376' r 1 6654'4506' 394i4L3 r 4 6778 4667-4656 2.75IF sat bons 2.635`d r 4 55640' 410' -4110' WLE'G I 6391 I 4 691 6,4Bgey 4155?-4176' 2 -22 4,nort :FlirtiZ 6461-6510' 5_5 float collar (PBTE11 7560 5.5' float choe 7661' I DATE gel. BY COMMENTS MILNE POINT UNIT 11/18100 MDO Drilled and cased & cxampfeted Nordic #3 WELL - 4.0 - 115i 12099 M. Linder 1 u uu to leaking lawar soaker API No: 50 1 2/1260 M. Linder Initial PaniorAliom. aisTe Loa Haulms Add NB Pada BP EXPLORATION (AK) • • cr is Pro Regg, James B (DOA) 061/070 From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] 4/���� Sent: Saturday, April 14, 2012 6:27 PM / ` To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU'Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wood, Alecia Cc: AK, D &C Well Integrity Coordinator; King, Whitney; LeBaron, Michael J; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M Subject: NOT OPERABLE: Injector MPJ -15 (PTD #1991070) Suspected TxIA Communication Attachments: MPJ -15 (PTD # 1991070) TIO and Injection Plot.doc; MPJ -15 (PTD # 1991070) wellbore schematic.pdf All, Water injector MPJ -15 (PTD #1991070) was being monitored for potential TxIA communication. The well passed an AOGCC witnessed MIT -IA on 01/07/2012 but has started exhibiting a potential slow TxIA communication trend over the last week. When the well was shut -in on 04/14/2012 to bleed the IA pressure, it was observed that the tubing and IA both went on a vacuum suggesting they are in communication. The well is reclassified as Not Operable. Plan forward: 1. Fullbore: MIT -IA to 2000 psi 2. WIE: Pending MIT -IA results, evaluate plan forward 3. WIE: If MIT -IA passes, resume injection monitoring for 10 -14 days for TxIA communication — A TIO and Injection plot and a wellbore schematic have been included for reference. «MPJ -15 (PTD # 1991070) TIO and Injection Plot.doc» «MPJ -15 (PTD # 1991070) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) 4itatatiED APR I. 8 2131 Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1 • • MPU J -15 PTD # 1991070 4/14/2012 TIO Pressures Plot Wek MPJ -15 4,000 3,000 t T6p -4F- IA 2,000 - --A,- OA 00A 0004 On / 1 ,000 AIL 411116.111BilhailkiliSm._ � r 01/14/12 01/21/12 01/28/12 02/04/12 02/11/12 02/18/12 02/25/12 03/03/12 03/10/12 03 /17/12 03/24/12 03/31/12 04/07/12 04/14/12 Injection Plot Wel: MPJ -15 - 1,000 750 - - 900 700 650 - 800 ',. 600 700,,,. 550 500 -600 £ -WHIP /1- 450 - v PpW - 500 n - MI 350 I ob 400 300 - On 250 - 300 200 j 50 - 200 100 - 100 50 01/14 /12 01/21/12 01/2842 02/04/1 2 02 /11/12 02/18/12 02/25/12 03/03/12 03/10/12 03/17/12 03/24/12 03/31/12 04/07/12 04/14/12 Tree: 3 1/8" - 5M FMC 411 M P U J-1 5 i Orig. •Iev. = 65.1' Nordic #3 Wellhead: 7- 1/16" 5M Vetco gray Orig. GL Elev. = 35.1' 5.5" Emergency slips, Vetco Tbg. RT To Tbg. Spool = 28.6' Nordic #3 Hng., threads top and bottom, 3" CIW "H" BPV profile KOP @ 450' 3.5" HES X- Nipple ( 2.813 "id) 2194' • Max. hole angle = 62 deg. @ 5,500' 60 deg. to 62 deg. (1900' - 6,300') Hole angle thru' perfs = > 59 deg. } 4 3.5" 9.3 ppf, L -80 NSCT tubing (cap. = 0.0087 bpf, drift = 2.867' 5.5" 15.5 ppf, J -55, Btrc. prod. casing ( drift ID = 4.950 ", cap. = 0.0238 bpf a 3.5" HES X- Nipple ( 2.813 "id) 6272' 5.5 "x 3.5" Baker SABL -3 6281' Perm pkr. Note: Lower packer leaked during initial completion. Tubing was cut leaving 9' pup 3.5" HES XN- Nipple 6297' and 9' of tubing stub above X nipple at 6347'. (2.750" pk. bore. 2.635 "id ) Unique Machine overshot swallowed 7' of tubing stub. Unique Machine overshot 6318' it 3.5" HES X- Nipple ( 2.813 "id ) 6347' Perforation Summary Ref log: SWS CBL dated 11/19/99 5.5 "x 3.5" Baker SABL -3 6356' Perm pkr. Size SPF Interval (TVD) 3949' - 3950' 3.5" HES XN- Nipple 6378' 2" 1 6504' -6506' 2" 4 6775' -6795' 4087' -4096' ( 2.750" pk. bore. 2.635 "id ) 2" 4 6820' -6840' 4109' -4118' WLEG 6390' 2" 4 6915' -6955' 4158' -4178' 2 -20' short joints 6461' -6510' ss 5.5' float collar (PBTD) 7000' ������•������������•���' 5.5' float shoe 7081' DATE REV. BY COMMENTS MILNE POINT UNIT 11/19/99 MDO Drilled and cased & completed Nordic #3 WELL J - 15i 12/9/99 M. Linder Recompleted due to leaking lower packer API No: 50- 029 -22952 12/12/99 M. Linder Initial perforations. 9/5/05 Lee Hulme Add NB Perfs BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 SLANNED FEB 2 1 Z Mr. Tom Maunder 1� 1 Alaska Oil and Gas Conservation Commission ' J C' 333 West 7 Avenue (J Anchorage, Alaska 99501 I r r Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator . • 1 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ-02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ-05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ-08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 -^ilo• MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 199 -k07 2..toigg 24 -AUG -2011 $cMknbErgeP No. 5782 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 - Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD l 11 -09A BCRC -00086 PPROF W/ DEFT & GHOST 16-Jul-11 1 1 MPJ -15 BD88 -00141 IPROF 25-Jul-11 1 1 MPJ -18 BCRC -00108 (PROF 24-Jul-11 1 1 MPI -08 BAUJ -00096 IPROF 26-Jul-11 1 1 3-31/K -32 BBSK -00082 PPROF WI DEFT & GHOST 26-Jul-11 1 1 M -08 BCRJ -00104 SBHPS 8- Aug -11 1 1 01 -28A BUTT -00001 PPROF W/ DEFT & GHOST 2- Aug -11 1 1 01 -28A BUTT -00001 CEMENT BOND LOG 3- Aug -11 % ( 1 • 2- 34/P -14 BCRC -00109 IPROF 27-Jul-11 1 1 Z -12 BJGT -00058 (PROF 2- Aug -11 1 1 V -03 BG4H -00066 SBHPS 29-Jul-11 1 1 W-34A BINC-00054 PRIMARY DEPTH CONTROL 26-Jul-11 1 1 17 -02 AWJI -00151 PPROF W /DEFT 14-Jul-11 1 1 A -11 BSM4-00018 IPROF 1- Aug -11 1 1 P1 -07A AWJI -00152 XFLOW 8- Aug -11 1 1 F -29A BG4H -00072 SBHPS 10- Aug -11 1 1 11 -11 BBSK -00085 PPROF W /DEFT 1- Aug -11 1 1 Z -06 BD88 -00146 TEMP SURVEY 3- Aug -11 1 1 Z -20 BBSK -00085 SBHPS 31-Jul-11 1 1 MPF -13 BUTT -00003 IPROF 9- Aug -11 1 1 MPL -15 BUTT -00003 IPROF 5- Aug -11 1 1 MPK -33 BJGT -00056 USIT 30Jul -11 £L. l 1 L2 -18A AWJI -00153 LEAK DETECTION LOG 11- Aug -11 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: • BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 $0 MAY 1 6LO1 ~;~L ~~i~~~~ ~,. PrtoA-crive DIAyNOSric SERViCES~ )Nt. To: AOGCC Christine -Pb4shrtlcen s~or'~z e ~ 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~J RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile O2,.1u~10 MPU J-15 2) Si ned : ~-_ _~~~~ 9 Print Name: J~. L' bit - t ~'?- ~~~~ Date Cali ~ rea rt PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RO SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL : pdsanchoraae(a~memorVlog.com WEBSn'E : www.memorylog.com BL / EDE C:\Documenis and Settings\Diane Williams\Desktop\Transmit_BP.docx • • ,.t~ .~ ~y ~?scmi~~~ ~i~qn.~ss~c ~~r~vi~s, l~. ~~~~ ~'~~ , ; ':~ To: AOGCG Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907J 793-1225 RE : Cased Hole/Open Hole/Mechanicai Logs and /or Tubing Inspection(Caliper/ MTTj The technica) data listed 6elow is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka lR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Internativnal Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1] Injection Profile 05-Jun-09 MPU J-15 ~~ 9 /, f ~ I Signed. , _~_ _ _.__-- _" '~~ V Print Name: ~~ . ~~,~~~~~ ~~ij~, t .,. ?t~C~~ ~~.~r ~ a~ v~~? t99 - dU°"r d~lb~~ BL / EDE 50-029-22952-00 Date : _ _ . PROACTNE DIAGAIOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RQ SU1TE C, AMCHORAGE, APC 9931$ PHONE: ~907)245-8951 FAx: (907)245-88952 E-MAII : :'. . - _:': , . '' VVEBSITE : , . - ,~ -- ---._._ __,___. _ __._ __ _-~ . ___ _____- -- -, ,~ C:~DocumeMS and Se[tings\Ownet~Desktop\Transmit_BP.docx • MEMORANDUM To: Jim Regg ~~~ ~ Z f L P.I. Supervisor FROM: John Crisp Petroleum Inspector i State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, February 07, 2008 SUBJECT: Mechanical Integ~~iry TesCs BP EXPLORATION (ALASKA) INC 1-l~ MIL~IE PT C,'NIT SB J-li Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~_ Comm Well Name: MILNE PT UNIT SB J-15 Insp Num: mitJCr080201044822 Rel Insp Num: API Well Number: 50-029-22952-00-00 Permit Number: 199-107-0 Inspector Name: John Crisp Inspection Date: 1/27/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1-15 Type Inj. I w ; TVD 3ss9 .~ IA ~,~ zoo '~ lsso -~~ ~ ~ ls2o ' Is2o _ _ P T i I99IOVO '~TypeTest ` sPT ~ Test psi i _ lsoo --~' pA ~, ~ ~ j ~i 4YRTST P Interval P1F _ Tllbin T 900 ~ 900 g' ! 900 ~ 900 ~_ I _ _ NOteS• .6 bbls pumped for test. Monobore injector no OA to monotor. ~~~.~1NE~ FEB 2 4 200 Thursday, February 07, 2008 Pave 1 of Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 L ATTN: Beth . ~ \ ). of- ~1~eß' ¡,' 08/30/07 NO. 4396 SCfiNNEC SEP 1 8 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay E di U ~ n co Job# Log Description Date BL Color CD l MPC-08 J N/A RSTIWFL 08/10/07 1 1VIr.T-~ 11767136 MEM INJ PROFILE I J-:r-l' /{;. ,&j-/ð-"¡' 08/12/07 1 P2-16 11856185 INJECTION PROFILE UTI' Ie. I~-t.:::l~ 08/02/07 1 07-02A 11649983 MEM PROD PROFILE ¡qr~ - Hi< ~ 08/07/07 1 R-13 11856186 INJECTION PROFILE l r:I:l' '" r3 - d/q 08/02/07 1 D-11A 11649982 MEM PROD PROFILE ICt" -t~~ 07/26/07 1 S-42 11686773 LDL ICJ~ -('Ü4 08/02/07 1 S-43 11855804 LDL J q.q. - t'ì~:J 08/02/07 1 16-07 11855806 STATIC PRESSURE SURVEY I irS""" - {:J.o4 08/04/07 1 16-21 11855805 STATIC PRESSURE SURVEY J"fif\ -,~l~ 08/04/07 1 1-09A1L-21 11849930 SBHP SURVEY J '1 ~ - (')::Jq 08/04/07 1 2-68/S-17 11630491 LDL L1Ó(- rA'+- . 07/27/07 1 1-23/0-15 11846802 STATIC PRESSURE SURVEY U:r:0 ¿ 194 -//J 'X' 08/11/07 1 Z-46 11057080 CH EDIT PDC GR (USITJdlX')-Jf\1 "rt l::-'", ,...Jd 12/14/05 1 A-09A 11216203 MCNL ,Q{X)- I":}.£.{" '~{/IJ'-( 06/29/06 1 1 L3-11 11801065 RST I "ð6"" ~~ I .... .~ ~_~ 05/31/07 1 1 . . PLEASE ACKNOWLEDGE RECEIPI~ '~l',S3'I~~~N~ R~~~RNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, f¡'''{ ~~,-, 11 i' N-=, ~ \1' ~,.." Petrotechnical Data Center LR2-1 . ",..,-- '" "..." I, " l,~_,~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: EP Lj Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 A~h_.AK '''''D~ ATTN: Beth C /~ Received by ,_ .--- '\1"',,·1,'.,,, \'1 (). . , " ;""""",,,~'.',:. \,/J, (\:: {.'¡::y~ (:(}r'¡,:'~ t '(ìI"¡'IP}~r':I1:'"'!("I" .._~.:. """.,0"\"',1, '.... ,:.'. ~,~J':-~','.'....,J,;¡; RECE'VED SEP 2 6 20'05 \ STATE OF ALASKA } ALA... A OIL AND GAS CONSERVATION COMrvllvSION REPORT OF SUNDRY WELL OPERATIONS D Stimulate D , Othli!{~ I COßI.,CommiSlion D WaiverD TinA".m~ a [1] Re-enter Suspended Well nthora. 5. Permit to Drill Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic C: Exploratory C 199-1070 Service P 6. API Number: 50-029-22952-00-00 9. Well Name and Number: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 65.12 KB MPJ-15 8. Property Designation: 10. Field/Pool(s): Milne Point Unit Field/ Schrader Bluff Oil Pool ADL-315848 11. Present Well Condition Summary: Total Depth measured 7145 feet true vertical 4280.29 feet Effective Depth measured 7000 feet true vertical 4202.63 feet Casing Length Size MD Surface 80 13-3/8" 68# L-80 30 - 11 0 Production 7051 5-1/2" 15.5# J-55 30 - 7081 Plugs (measured) None Junk (measured) None TVD 30 - 11 0 30 - 4245.77 Burst 5020 4810 Collapse 2270 4040 Perforation depth: Measured depth: 6504 - 6506 True Vertical depth: 3949.11 - 3950.12 6775 - 6795 6820 - 6840 4109.36 - 4119.6 6915 - 6955 4158.16 - 4178.98 4086.32 - 4096.55 Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 29 - 6390 Packers and SSSV (type and measured depth) 3-1/2" Baker SABL-3 Packer 3-1/2" Baker SABL-3 Packer 6281 6356 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final press~ÇANNEb NO" (J 92D05 RBDMS BFL SEP 2 8 2005 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 1422 0 o 1478 0 15. Well Class after proposed work: Exploratory r Development r 16. Well Status after proposed work: Oil r Gas r WAGr GINJ r Oil-Bbl o o Tubing pressure 1054 979 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service P x WINJ ~ WDSPL r 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 Sharmaine Vestal Printed Name Sharmaine Vestal Title Data Mgmt Engr 6iA£ (' r-'ì ~ t, . t t,·"" ¡ \,...1 '.; \¡ Signat~~:/~ Phone 564-4424 Date 9/23/2005 ('" ~ ¡ -" f >,,,/ : ¡ ~~.~ Form 10-404 Revised 04/2004 Submit Original Only .,. ') ) MPJ·15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDA TE I SUMMARY 9/5/2005 Perforated 2 1/4" HSD PJ from 6504'-6506', 1 spf 2 shots total, random orientation, CCL to top shot 6.1', CCL stop depth 6497.9'. ***Job Complete*** FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL ( ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~11'1'f"¡JCIf DATE: January 8,2004 P. I. Supervisor SUBJECT: Mechanical Integrity Tests FROM: Jeff Jones BP{XA Petroleum Inspector B, J Pads B-12, B-18, J-11 J-15 MPU Milne Point Field NON- CONFIDENTIAL 4 P 4 P 4 P 4 P Type Test Interval M= Annulus Monitoring 1= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey V= Required by Variance A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details January 8, 2004: I traveled to BPXA's Milne Point Field wells B-12, B-18, J-11 and J-15 to witness MITis. Lee Hulme was the BPXA representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with each well passing the MIT. Four well houses were inspected with no exceptions noted. Summary: I witnessed successful MITis on BPXA's Milne Point Field wells B-12, B-18, J-ll and J-15. Four well house inspections conducted, no exceptions noted. M.I.T.'s performed: ! Number of Failures: Q Total Time during tests: 6 hrs Attachments: cc: 8íGAlNJNfJ.::[ JJc~\~~ ~:~ 9 2f]D¿~. MIT report form 5/12/00 L.G. MIT MPU B-12, B-18, J-11, J-151-8-04 JJ.xls 1/15/2004 ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us 5ßR- J jq{O4 OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration - Alaska Milne Point Unit / B-pad & J-pad 01/08/04 Packer Depth Pretest Initial 15 Min. 30 Min. Well B-12 Type Inj. P TVD 6,998' Tubing 2,140 2,140 2,140 2,140 Interval 09:38 P.T.D. 1850800 Type test P Test psi 1,750 Casing 550 1,800 1,760 1,750 P/F Pass Notes: 1 bbls diesel to 1800 OA 650 750 750 750 Bled back to 500 Well B-18 Typelnj. P TVD 6,854' Tubing 2,550 2,550 2,550 2,550 Interval 10:40 P.T.D. 1852290 Type test P Test psi 1,714 Casing 500 2,200 2,180 2,170 P/F Pass Notes: 2 bbls diesel to 2200 OA 300 480 480 480 Bled back to 500 Well J-11 Type Inj. P TVD 3,913' Tubing 1,920 1,920 1,920 1,920 Interval 13:45 P.T.D. 1941140 Type test P Test psi 1,500 Casing 740 2,600 2,550 2,550 P/F Pass Notes: 1.2 bbls diesel to 2600 OA 650 750 750 750 Bled back to 500 Well J-15 Type Inj. P TVD 3,839' Tubing 1,180 1,180 1,180 1,180 Interval 12:45 P.T.D. 1991070 Type test P Test psi 1,500 Casing 500 2,025 1,980 1,950 P/F Pass Notes: .7 bbls diesel to 2025 OA 650 750 750 750 Bled back to 500 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) SCANNEr,:, JAW 1 4 2004 MIT Report Form Revised: 06/19/02 2004-01 08_MIT _MPU_J-15.xls WELL LOG TRANSMI AL ProActive Diagnostic Services, Inc. To; State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE · Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM BLUELINE Open Hole I I 1 J-15i 6-15-03 Res. Eval. CH 1 i~ )'''~/ 1 1 Mech. CH 1 Caliper Survey Signed · Print Name: Date ' ProActive Diagnostic Services, Inc., Po Box 1369 Stafford '[X 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog, com Wcbsite: www.memorylog, com DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1991070 Well Name/No. MILNE PT UNIT SB J-15 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22952-00-00 MD 7145 TVD 4280 Completion Date 12/9/1999 Completion Status 1WINJ Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey No -- __ 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 rpe Media Format Name Scale Media No Start Stop CH Received Number Comments C .................. ~"'I~,S~ .......................... -~) ......... FINAL 5906' ' 6960 (~h ' ' 6/2~720-00 ................................. SCMT 5 FINAL 5300 6960 DGR/EWR4-TVD 25 FINAL 111 4282 DGR/EWR4-.]ikI~/'/~ ~) 25 FINAL 111 7147, Injection Profil ~.~ 0~3t",~3 {) ~ FINAL 6660 6958 I~' STAT PRES SRVY ~VY RPT 5 FINAL 6775 6962 5 FINAL 6600 6923 0 7145 CH 12/8/1999 BL(C) 11/19/99UIC OH 2/16/2000 UIC OH 2/16/2000 UIC CH 11/1/2000 BL, Sepia O 1/26/2000 09096L~ 51-7105 C 1/26/2000 09094~..--' 6600-6923 CH 12/29/1999 12/12/99UIC CH 1/2,6/2000 12/22/99UIC OH 1/12/2000 SPERRY .UIC C 2/15/2000 09433 c_. 5278-6960 C 6~27~2000 09639 L_- 5850-6941 C 11/28/2000 10318 ~ 6660-6958 Well Cores/Samples Information: Interval Dataset Name Start Stop Seut Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~} Anal~[s-P~e[ved? ~ Daily History Received? ~____~/N Formation Tops Receuived? DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1991070 Well Name/No. MILNE PT UNIT SB J-15 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22952-00-00 MD 7145 TVD 4280 Completion Date 12/9/1999 Completion Status 1WINJ Current Status IWINJ UIC Y ~_~ ~-_~2~ ~ . ~d~- ~£ "£-~7_7~ -.~-~- 7~ .~-~£~--- ~" ~_~ ~"_~ ' ~ i~ .~Z~. ~.~'2d ~_~ 2~'7-Z '.~---- ~Z_~ .... 2F~'~-2~.~iZ-'.~Z _~_ ~.--_'-~ .... ~ ~ -~ ' '.~-.~.T~2~2..~-Z~- ' ~_-2'_-~_~_ .......... ~_ Comments: Compliance Reviewed By: __ _/,,~-~ ................... Date: . ~ .~.? ..~ _. ~'~. ~ c~'~ .~_~. TRA/ $/ /TTA L, ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Robert Richey ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration(Alaska), Inc. Petro-Technical Data Center MB 3-3 900 East Benson Blvd. Anchorage, Alaska 99508 I LoG DIGITAL MYLAR / BLUE LINE REPORT WELL~ DATE TYPE OR SEPIA PRINT(S ) OR i CD-ROM FILM BLUELINE Open Hole I I 1 J-15i I 10-23-00 Res. Eval. CH I I 1 I Mech. CH 1 .... r t Caliper Survey I 1BL/1Fq Rptor Print Name: ProActive Diagnostic ~ervices, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~,memorylog.com Websitc: ..... :~ ,, GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 281 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 6/27/00 Well Job # Log Description Date BL Sepia CD MPF-81 PRODUCTION LOG 000621 1 1 MPJ- 15 ~ ~l~,c~ 20227 RST 000511 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 R£CF..IYED JUN 27 000 Date Delivered: Alaska Oil & Gas Co,",3. rjcmm!s~inn Anchorage Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al-tN: Sherrie Received WELL LOG TRANSMYFrAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPJ- 15, AK-MW-90186 February 15, 2000 MPJ-15: '~"" 5" MD Resistivi~, and r- 50-029-22952-00 2"x 5" TVD Resistivity_ and Gamma Ray Logs: 50-029-22952-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNENG A~ND RETURNLNG ~ ATTACHED COPIES OF THE TRANS~~ LE!q'~. ~R TO THE ATrE~,wrI..ON OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. AnchrKag,e~ BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date' - v-" ~ ,~ask~ Oil & Gas C~ns, Commission Si~ned:~..-'~~) Anchorago " 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company 2/$/00 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 121155 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: MIIne Point (Cased Hole) Well Job # Log Description Date BL Sepia CD MPJ-15 ~t C~ 20015 PDC GR 991119 M PL-16A ¢,' 20055 P DC G R ~ ~';/'c~'?~~' 000116 I 1 I.l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED FEB 1§ 2000 Alaska 011 & Gas Cmos. Commisslor~ Anchorage Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, A'n'N', She~ ./) / 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- 15I, January 20, 2000 1 LDWG formatted Disc with verification listingl APl#: 50-029-22952-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMYI'TAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jan Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: C-t~tl ~ 0 2000 Naka OI & Gas Oons. Commiss~ 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 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 I--1 Suspended []Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 199-107 399-244 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22952-00 4. Location of well at surface ?- _- ...... 9. Unit or Lease Name 2345' NSL, 3348' WEL, SEC. 28, T13N, R10E, UM ! ,:~'. ! ! ::-~.!: i ~~ Milne Point Unit At to,p, of productiv.,e interval 1619 NSL, 5157 WEL, SEC. 21,T13N, R10E, UM ! !_.2.,/,~'.~'~_~._/~. i~ ~ 10. WellNumber ~ MPJ-15i At total depth , ~:~.. ':. i ~,~'~~ 11. Field and Pool 1918' NSL, 5270 WEL, SEC. 21, T13N, RIOE, UM !.. ,,,~F-~-- .' ,~ ._f'~' 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease DesignatiOn and SerialLNb-'''~ ' '''' Milne Point Unit/ Schrader Bluff KBE = 65.12' AMSL I ADL 315848 12. Date Spudded11/10/99 I13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re 16' N°' °' C°mpleti°nsl 1/15/99 12/9/99 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Survey [20. Depth where SSSV set 121. Thickness of Permafrost 7145 4280 FT 7001 4203 FTI [~Yes [] No! (Nipple) 2194' MD I 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, PWD, RES, CBL, CCL 23. CASING, LINER AND CEMENTING RECORD CASING SE'FI-lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68# L-80 Surface 110' 24" 260 sx Arctic Set (Approx.) 5-1/2" 15.5# J-55 30' 7083' 7-7/8" 490 sx ArcticSet 3, 390 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 3-1/2", 9.2#, L-80 6318' 6281' MD TVD MD TVD 3-1/2", 9.2#, L-80 6318'- 6390' 6775' - 6795' 4086' - 4097' 6820' - 6840' 4109' - 4120' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 6915' - 6935' 4158' - 4169' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6935' - 6955' 4169'- 4179' Freeze Protect with 75 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) December 17, 1999 J Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATE OIL-BBL GAS-MCF WATER-BBL O~L GRAWTY-API (CORR) Press. :D 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . ECEiVED Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Ugnu 5382' 3409' Top of Schrader Bluff 6430' 3912' CA Sand 6770' 4084' OB Sand 6912' 4157' Base of Schrader Bluff 6958' 4181' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I he re by certify that the foregoing is true and c or re ct to the best of my knowledge Signed~"'~~ ~ Terrie Nubble , Title Technical Assistant III Date (~'~' ] )' ~)(~ M PJ-15i 199-107 399-244 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. RECE!VED Form 10-407 Rev. 07-01-80 0il & G,~.s Cons, comm, issior~ Anchorage Facility Date/Time 08 Nov 99 09 Nov 99 10 Nov 99 Progress Report M Pt J Pad Well MPJ- 15 Page 1 Rig Nordic3 Date 30 November 99 20:00-06:00 20:00-06:00 06:00 06:00-10:00 06:00-10:00 10:00 10:00-12:00 10:00-12:00 12:00 12:00-18:00 12:00-18:00 18:00 18:00-04:00 18:00-04:00 04:00 04:00-05:30 04:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00-06:30 06:00-06:30 06:30 06:30-09:30 06:30-09:30 09:30 09:30-15:30 09:30-15:30 15:30 15:30-16:30 15:30-16:30 Duration lOhr lOhr 4hr 4hr 2hr 2hr 6hr 6hr lOhr lOhr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3hr 3hr 6hr 6hr lhr lhr Activity Move rig Rig moved 100.00 % Trun key rig move f/C pad to J pad. 6.3 miles. Lay pit liner and backed over J-15 @ 0530. Berm around rig @ 0600 Accepth rig for operations. At well location - Cellar Nipple up Divertor Installed Divertor Bring 13-5/8" 5M annular into cellar & worm up. Have wrong DSA for between Hydril & divertor. Wait on double stud adapter. Aborted equipment work Planned maintenance Serviced Rig services Rebuild #1 charge pump. Fab & Install drain on trip tank. Repair auger bearings. Equipment work completed Fluid system Fill pits with Water based mud Load mud tanks w/240 bbl's spud mud. While loading pipe shed w/200its of 3-1/2" 13.3# S-135 DP Completed operations Nipple up Divertor Rigged up Divertor Install double stud adapter, 13-5/8" 5M hydril, Flow nipple to short extend same. Install 4" nipple in riser. Install 16" kinve valve & devertor line. Function test O.K. Equipment work completed Derrick management Racked back drill pipe R/U to P/U & stand 3-1/2" DP in derrick. Stopped: To hold safety meeting Derrick management Held safety meeting Pre-spud D-3 drill Derrick management (cont...) Held safety meeting Continue Pre-spud D3 Divertor & Evacuation Drill Completed operations Nipple up Bell nipple Serviced Flowline Remove flow nipple for modifications,short by 2'. Install 2 3" Block draiin valves on divertor. Install stack trun buckles. Equipment work completed Derrick management Racked back drill pipe P/U & MFLI 3.5" DP in mouse hole Stand b k derrick 66 std's. ,~a~ 198 joints picked up Derrick management Serviced Crown block Slip & cut drilling line. ~ .... ,.,, Anchorage Facility M Pt J Pad Progress Report Well MPJ- 15 Page 2 Rig Nordic3 Date 30November 99 Date/rime 16:30 16:30-17:30 16:30-17:30 17:30 17:30-19:30 17:30-19:30 19:30 19:30-21:00 19:30-21:00 21:00 21:00-06:00 21:00-06:00 11 Nov 99 06:00-06:00 06:00-00:30 12 Nov 99 00:30 00:30-01:30 01:30 01:30-03:00 03:00 03:00-03:30 03:30 03:30-06:00 06:00-23:30 06:00-14:00 14:00 14:00-15:30 Duration lhr lhr 2hr 2hr 1-1/2 hr 1-1/2 hr 9hr 9hr 24 hr 18-1/2 hr 1 hr 1-1/2 hr 1/2 hr 2~1/2 hr 17-1/2 hr 8hr 1-1/2 hr Activity Equipment work completed Derrick management Made up BHA in derrick P/U & M/U 3.5" HWDP, Flex weight stand back. Install flow nipple. Required components racked in derrick BHA run no. 1 Made up BHA no. 1 M/U BHA #1 Bit #1 RIH tag bottom @ 116' BHA no. 1 made up Test well control equipment Rigged up Divertor Function Hydril and diveertor knife valve. Water test hydril seal O.K. Fill hole and test knife valve & divertor liiiines for leaks O.K. Equipment work completed BHA run no. 1 Drilled to 750.0 ft Drill 7.875" hole f/116' to 264'. Start buliding angle and directional drill to 750' @ 0600 hrs HSE incident: Motorman sent to Anchorage for medical evaluation of strained back. Motorman has had history of lower back problems. Began precautionary measures Circulated at 3638.0 ft Circulate and reciprocate, mix hi-vis barofibre sweep & pump at 14:45. BHA run no. 1 (cont...) Drilled to 2571.0 ft .t3,1a~A{a 0il Slide drilling 7-7/8" hole f/750' to 1900' MD, building angle to 60 degrees. Pumped sweeps periodically as needed. Rotate ahead to 2571' MD. Started scheduled wiper trip: due to Footage drilled Circulated at 2571.0 ft Pump sweep, circulate and clean hole for short trip. Hole swept with slug - 100.00 % hole volume Pulled out of hole to 1640.0 fl Pulled 10 stds. Tight spot at 2150' MD, 25klbs overpull. Worked tight spot, hole cleaned up. No overpull.. At top of check trip interval R.I.H. to 2571.0 ft RIH to 2475', wash last stand to bottom, -20' of fill. On bottom Drilled to 2861.0 ft Drilling ahead at report time. ECD 9.9 to 10.1 ppg. Hole appears to be clean. BHA run no. 1 (cont...) Drilled to 3638.0 ft ROP began to drop. Decided to make bit trip based on footage, ROP and hours. Facility M Pt J Pad Progress Report Well MPJ- 15 Page 3 Rig Nordic3 Date 30 November 99 Date/Time 15:30 15:30-16:00 16:00 16:00-21:00 21:00 21:00-22:30 22:30 22:30-23:30 23:30 23:30-06:00 23:30-01:00 13 Nov 99 01:00 01:00-02:00 02:00 02:00-06:00 06:00-06:00 06:00-20:00 20:00 20:00-22:00 22:00 22:00-23:00 23:00 23:00-01:00 14 Nov 99 01:00 01:00-06:00 06:00-06:00 06:00-07:30 Duration 1/2 hr 5hr 1-1/2 hr lhr 6-1/2 hr 1-1/2 hr lhr 4 hr 24 hr 14hr 2hr lhr 2hr 5hr 24 hr 1-1/2 hr Activity Hole swept with slug - 100.00 % hole volume Took MWD survey at 3638.0 ft Acceptable survey obtained at 3638.0 ft Pulled out of hole to 0.0 ft POH slow, swabbing. Pipe dragging 100k up, 45k dn. K/U on stand #6 & backream. Encountered ledges at 1089' and 992' MD. K/U and back ream through. At BHA At surface. Downloaded MWD tool Break bit and m/u new 7-7/8" MX-C 1 bit. Bit graded 2-3-WT-A-E-I-ER-HR. Completed operations Serviced Top drive Equipment work completed BHA run no. 2 R.I.H. to 2640.0 ft Tagged up on bridge at 2640' MD. Unable to RIH w/o top drive. Began precautionary measures Washed to 3638.0 ft M/U top drive, wash and ream to bottom. Pumped at 2 bpm, 600 psi, rotate at 50 RPM, Taking weight occasionally. ROP = 400 fpm. On bottom Drilled to 4023.0 ft Drill ahead from 3638' to 4023. Drilling ahead at ~_!,5., i,; report time. BHA run no. 2 (cont...) Drilled to 5572.0 ft A~ch0ra~jo Continue drlg ahead f/4023' t/5572', pumping 10 bbl hi wt, 20 bbl vis sweeps every 500'. No Rotate: up=90k, dn=45k Rotate: up=65k, dn=55k Started scheduled wiper trip: due to Footage drilled Circulated at 5572.0 ft Pump sweep, work & rotate pipe to clean hole. Hole swept with slug - 100.00 % hole volume Pulled out of hole to 4950.0 ft Short trip -- pull 6 stands, started packing off on std #7 at 4950'. RIH to 5475. Observed 25.00 klb overpull Washed to 5572.0 fl M/U TD, wash & rotate to bottom. Mix and pump sweeps. Hole cleaning, continue to work DP. Circulate at 197 spin, 3950 psi. No further resistance Pulled out of hole to 4898.0 ft 25k overpull. R/U TD, pump and rotate pipe. Packing off. Worked to 3900' at report time. BHA run no. 2 (cont...) R.I.H. to 5575.0 ft RIH 19 stands on short trip. Wash and ream last stand to bottom. No problems. Facility M Pt J Pad Date/Time 07:30 07:30-16:00 16:00 16:00-17:30 Duration 8-1/2 hr 17:30 17:30-20:00 20:00 20:00-06:00 1-1/2 hr 15 Nov 99 06:00-06:00 06:00-07:00 07:00 07:00-15:30 15:30 15:30-18:00 2-1/2 hr 10hr 24 hr lhr 8-1/2 hr 2-1/2 hr 18:00 18:00-00:15 6-1/4 hr 16 Nov 99 00:15 00:15-01:30 01:30 01:30-05:00 1-1/4 hr 3-1/2 hr 05:00 05:00-06:00 06:00-14:00 06:00-07:30 07:30 07:30-08:30 08:30 08:30-12:30 12:30 12:30-13:00 13:00 lhr 8hr 1-1/2 hr lhr 4hr Progress Report Well MPJ- 15 Page 4 Rig Nordic3 Date 30 November 99 Activity On bottom Drilled to 6348.0 ft Drill ahead from 5575-6348, pumping hi-weight, lo-vis sweep every 500'. Up wt = 100k, dn wt = 45k no rotation. Pistons failed - Work string Serviced Mud pumps Change out swab and liner gasket on #1 rig pump. Service top drive. Equipment work completed Drilled to 6639.0 ft Mud pump fluid end failed - Work string Serviced Mud pump fluid end Replaced cracked pod in pump #1. BHA run no. 2 (cont...) Serviced Mud pump fluid end Continue to replace #3 fluid pod on #1 pump. Equipment work completed ~fl~ ~ Drilled to 7145.0 ft ~, ~ "~ Continue drlg from 6636' to 7145' MD (4280 TVD). Reached planned end of run - Section / well T.D.~.~,..;~' r, ?~ ~ .~. ,-,,'"i~ Circulated at 7145.0 ft Circulate, reciprocate, rotate and pump s~.~(~ 0il & ~!~3 Con~, C.I Rot up wt = 80k, dn wt = 75k. ~4r~ch0rag0 Slide up wt = 120k, dn wt - 55k Obtained clean returns - 100.00 % hole volume Pulled out of hole to 630.0 ft Made short trip to top of HWDP. Pumped and reamed out first 9 stands after experiencing overpull. Pulled free to 889' and got hung up. Pumped and reamed one stand through tight spot. Broke off kelly and pulled back through 889' with no problem. Began precautionary measures Serviced Top drive Equipment work completed R.I.H. to 7145.0 ft Ran back to bottom with no problems. ECD on bottom @ 10.8 ppg. Began precautionary measures Circulated at 7145.0 ft Circulate and condition mud. BHA run no. 2 (cont...) Circulated at 7145.0 ft Condition hole for 5-1/2" csg. 115k up, 55k dn. Stopped: To take survey Dropped EMSS survey barrel Drop ESS tool to take survey. Began precautionary measures Pulled out of hole to 0.0 ft Stand back DP, HWDP, and Non-mag drill collars. At Surface: 0.0 ft Downloaded MWD tool Completed operations ,0 Facility M Pt J Pad Progress Report Well MPJ- 15 Page 5 Rig Nordic3 Date 30November 99 Date/Time 13:00-14:00 14:00 14:00-06:00 14:00-16:00 16:00 16:00-19:00 19:00 19:00-05:00 17 Nov 99 05:00 05:00-06:00 06:00 06:00-19:00 06:00-11:00 11:00 11:00-15:00 15:00 15:00-19:00 19:00 19:00-00:45 19:00-20:00 20:00 20:00-20:30 20:30 20:30-21:00 21:00 21:00-22:00 Duration lhr 16hr 2hr 3hr lOhr lhr 13hr 5 hr 4hr 4hr 5-3/4 hr lhr 1/2 hr 1/2 hr lhr Activity Pulled BHA L/D MWD, motor, jars. BHA Laid out Run Casing, 5-1/2in O.D. Racked back Tubing R/U tubing tongs, p/u and stand back 33 jts of 3-1/2", 9.2 #, L-80, NSCT tubing as contingency for secondary cement job through TAM port collar. Phase III weather conditions declared. Dowell cement crews and trucks forced to turn back to Deadhorse. Required components racked in derrick Held PJSM regarding fould weather conditions. Installed Completion string handling equipment R/U to run 5-1/2" casing. Change elevator bails and pick up float equipment. Install Frank's fill-up tool. Circulate and check floats. Equipment work completed Held PJSM with new crew regarding foul weather conditions. Ran Casing to 7090.0 ft (5-1/2in OD) ~ ~: C ~: I V Run total of174 jts of 5-1/2", 15.4#,L-80, ~=::, ,~,~ , L,: .., buttress casing. Install TAM port collar at 1010' MD. Completed run with Casing to 7090.0 ft ,,.. ii /~':,,?'! "1 ,L:' ,..9(~',,. Rigged up Casing hanger running tool Circulate and prepare landing jr. Equipment work completed Run Casing, 5-1/2in O.D. (cont...) Circulated at 7090.0 fl Phase III. Circulate and reciprocate. Waiting for weather to clear so Dowell cement trucks can mobilize. Load out extra casing, clear rig floor. Got stuck whilst pipe moving Got stuck at 7083' while reciprocating. Worked stuck pipe at 7083.0 fl Pull 80 % of tensile strength. Pump at 3.75 bbl/min, SPP = 365 psi. No pipe movement. Began precautionary measures Circulate and wait on weather. Rigged up Circulating head Equipment work completed Continue to circulate. Cement · Casing cement Rigged up Cement head Equipment work completed Held safety meeting Held PJSM w/Nordic, BP, Dowell, and Peak on cement job. Completed operations Pumped Seawater spacers - volume 60.000 bbl Pump 5 bbls flush and pressure test lines to 3000 psi (test OK), pump 15 bbls water and 40 bbl spacer. Required volume of spacer pumped Mixed and pumped slurry - 467.000 bbl mmissi0.r Facility M Pt J Pad Progress Report Well MPJ- 15 Page Rig Nordic3 Date 6 30 November 99 Date/Time 22:00 22:00-00:00 18 Nov 99 00:00 00:00-00:45 00:45 00:45-06:00 00:45-02:45 02:45 02:45-06:00 06:00-08:30 06:00-08:00 08:00 08:00-08:30 08:30 08:30-19:45 08:30-11:00 11:00 11:00-18:00 18:00 18:00-19:30 19:30 19:30-19:45 19:45 19:45-02:30 19:45-23:30 23:30 23:30-00:00 19 Nov 99 00:00 00:00-01:00 01:00 01:00-02:30 Duration 2 hr 3/4 hr 5-1/4 hr 2hr 3-1/4 hr 2-1/2 hr 2 hr 1/2 hr 11-1/4 hr 2-1/2 hr 7hr 1-1/2 hr 1/4 hr 6-3/4 hr 3-3/4 hr 1/2 hr lhr 1-1/2 hr Activity 80 bbls tail cement, followed by 2 bbls water. Cement pumped Pumped Brine spacers - volume 166.000 bbl Displace cement with rig pumps. Bump plug with 2500 psi, bleed off, r/d circulating hose and check floats for 10 minutes. Floats OK. Got 46 bbls cement at surface. Observed change in Cutting volumes Cement at surface at 35 bbls displaced. Returns slowed w/75 bbls to go. Lost returns. Slowed pump to 2.25 bpm. Partial returns recovered. Plug bumped 1 bbl early @ 3312 stks. Cleared Cement pump Rig down Dowell. Equipment work completed Wellhead work Removed Divertor Equipment work completed Installed Slip & seal assembly Set emergency slips in 170klb tension. Cut hole to drain tubing. Cut tubing and lay down Annular preventer. Nipple down Divertor Rigged down Divertor Finish ND diverter, riser and adapter spools. Work completed, equipment laid out Serviced Block line Cut & slip 97.5'. Line slipped and cut Wellhead work Welded casing stub Cut, dress, and weld on spool adapter pin. Completed operations Rigged up Conversion sleeve WO spool adapter pin weld to cool. Onload, strap, & drift 3.5" tbg. Equipment work completed Installed Tubing head spool MU & torque tbg hd to 8000 ft/lbs. Equipment work completed Installed BOP test plug assembly Equipment work completed Nipple up BOP stack Rigged up BOP stack Stopped: To hold safety meeting Held safety meeting Discuss recent LCIR's and need to stay focused on job at hand. Completed operations Rigged up BOP stack Finish NU BOPE. Work completed - BOP stack in position Rigged up Top ram Change top rams from 4.5" to 3.5". Facility M Pt J Pad Progress Report Well MPJ- 15 Page 7 Rig Nordic3 Date 30 November 99 Date/Time 02:30 02:30-03:30 02:30-03:30 03:30 03:30-06:00 03:30-04:00 04:00 04:00-06:00 04:00-06:00 06:00-07:30 06:00-06:45 06:45 06:45-07:30 07:30 07:30-08:30 07:30-08:30 08:30 08:30-10:00 08:30-10:00 10:00 10:00-10:30 10:00-10:30 10:30 10:30-21 '30 10:30-12:00 12:00 12:00-13:00 13:00 13:00-18:00 18:00 18:00-18:45 18:45 18:45-21:15 Duration lhr lhr 2-1/2 hr 1/2 hr 2hr 2hr 1-1/2 hr 3/4 hr 3/4 hr lhr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr llhr 1-1/2 hr lhr 5hr 3/4 hr 2-1/2 hr Activity Equipment work completed Test well control equipment Tested BOP stack Tested breaks, body, and top ram to 3000 psi-OK. Pressure test completed successfully- 3000.000 psi ~ ~ (i FI\~ Electric wireline work Rigged up Rigging equipment RU Schlumberger .~,,':" '.,'.II .~ ~j: ,:: Work completed - Rigging equipment in position Conducted electric cable operations ~.lt~t~l(a {.3il ~ 6:~.:-_; ~30n$, Finish running CBL & POH. Ar~chorar.j~ Conducted electric cable operations RIH w/CBL/GR to 6930'. Logged up to 5300'. Logging repeat section. Electric wireline work (cont...) Conducted electric cable operations (cont...) RIH w/CBL/GR to 6930'. Logged up to 5300'. Logging repeat section. Completed logging run with Cement bond log from 6968.0 ft to 5300 Rigged down Rigging equipment RD Schlumberger Work completed, equipment laid out Perform integrity test Tested Casing Test 5.5" csg f/30 min-OK. Csg hd weld had previously been tested to 3200 psi-OK. Pressure test completed successfully - 3000.000 psi Electric wireline work Conducted electric cable operations Evaluate log. Completed logging run with Cement bond log from 6968.0 ft to 5300 Wellhead work Rigged down Wear bushing Pull wear ring. Work completed, equipment laid out Run Single completion, 3-1/2in O.D. Rigged up Tubing handling equipment RU to run tbg. Finish loading pipe shed. Work completed - Tubing handling equipment in position Held safety meeting PJSM and discuss recent LCIR's. Completed operations Ran Tubing to 4500.0 ft (3-1/2in OD) PU tailpipe assembly & 5.5" Baker 'SABL-3' packer assembly. RIH on 3.5", 9.2#, L-80 NSCT. Stopped · To hold safety meeting Held safety meeting Safety meeting with crew, Nordic safety, and Milne Pt Well Ops Supv. Discussed safety expectations and recent LCIR' s. Completed operations Ran Tubing to 6390.0 ft (3-1/2in OD) Ran total of 200 jts 3.5" tbg. Buried space out pups. MU hanger and land. WLEG @ 6390', Packer @ 6356'. )it Progress Report Facility M Pt J Pad Well MPJ-15 Page 8 Rig Nordic3 Date 30November 99 Date/Time 20 Nov 99 21:15 21:15-21:30 21:30 21:30-21:45 21:30-21:45 21:45 21:45-23:30 21:45-23:30 23:30 23:30-01:30 23:30-01:00 01:00 01:00-01:30 01:30 01:30-02:00 01:30-02:00 02:00 02:00-03:00 02:00-03:00 03:00 03:00-04:30 03:00-04:30 04:30 04:30-06:00 04:30-05:45 05:45 05:45-06:00 05:45-06:00 06:00-16:00 06:00-06:30 06:30 06:30-09:00 09:00 09:00-09:45 Duration 1/4 hr 114 hr 1/4 hr 1-3/4 hr 1-3/4 hr 2hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr lhr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/4 hr 1/4 hr 1/4 hr 10hr 1/2 hr 2o 1/2 hr - 3/4 hr Activity Hanger landed Rigged down Tubing handling equipment Backout & LD landing it. Work completed, equipment laid out Wellhead work Installed Hanger plug Set TWC. Eqpt. work completed, running tool retrieved Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree NU tbg hd adapter & 3 1/8" 5M tree. Equipment work completed Tested Xmas tree Tested tree, adapter, and hanger to 250 / 5000 psi f/15 min-OK. Pressure test completed successfully - 5000.000 psi Wellhead work Rigged down Hanger plug Pull TWC. Work completed, equipment laid out Chemical treatment Circulated at 6390.0 ft RU to circ down backside. Reverse circ inhibited 9.6# brine down 3.5" x 5.5" annulus. Obtained req. fluid properties - 60.00 %, hole vol. Fluid system Freeze protect well - 75.000 bbl of Diesel Pumped 75 bbls diesel down annulus. Allow to U-tube to tbg. Completed operations Run Single completion, 3-1/2in O.D. Set packer at 6356.0 ft with 4500.0 psi Drop setting ball. WO ball to drop. Packer set at 6356.0 ft Tested Tubing Finish testing tubing. Tested Tubing Test tubing to 3000 psi. Run Single completion, 3-1/2in O.D. (cont...) Tested Tubing (cont...) Test tubing to 3000 psi. Pressure test completed successfully - 3000.000 psi Tested Permanent packer Press annulus to 1500 psi--annulus tracked up to 1000 psi. SD & press equalized. Bled down. Pressure tbg to 4500 psi-OK. Bled down. Pressure annulus to 800 psi--equalizing. Suspended pressure test on Permanent packer, observed leak Tested Tubing hanger Retest hanger to 250 / 5000-OK Oil,:,, ° Facility M Pt J Pad Progress Report Well MPJ-15 Page 9 Rig Nordic3 Date 30 November 99 Date/Time 09:45 09:45-16:00 16:00 16:00-16:30 16:00-16:30 16:30 16:30-06:00 16:30-18:00 18:00 Duration 6-1/4 hr 1/2 hr 1/2 hr 13-1/2 hr 1-1/2 hr Activity Pressure test completed successfully - 5000.000 psi Tested Permanent packer Repress tbg to 5000. Bleed off. Isolate all rig lines. RU hot oil. Press ann to 2400 w/tbg tracking. Bleed off. Press tbg to 5000. Bled tbg to 3000 & repress fast to 5000. Starting to see equalization f/ tbg to ann. Press ann to 3000-tbg 2500. Bleed off Suspended pressure test on Permanent packer, observed leak Wellhead work Installed Hanger plug Set BPV. Eqpt. work completed, running tool retrieved Move rig Rigged down Drillfloor / Derrick RD HB&R. Blow down lines. Prep rig f/move. Work completed, equipment laid out Rig released @ 1800 hrs on 11/20/99. Facility Date/Time 07 Dec 99 08 Dec 99 09 Dec 99 M Pt J Pad Progress Report Well MPJ-15 Page 1 Rig Nabors 4ES Date 06 January 00 22:00-05:00 22:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-09:00 07:00-09:00 09:00 09:00-11:00 09:00-11:00 11:00 11:00-12:00 11:00-12:00 12:00 12:00-14:30 12:00-14:30 14:30 14:30-20:00 14:30-20:00 20:00 20:00-21:30 20:00-21:30 21:30 21:30-23:00 21:30-23:00 23:00 23:00-00:00 23:00-00:00 00:00 00:00-02:00 00:00-02:00 02:00 02:00-06:00 02:00-03:00 03:00 Duration 7hr 7hr lhr lhr lhr lhr 2hr 2hr 2hr 2hr lhr lhr 2-1/2 hr 2-1/2 hr 5-1/2 hr 5-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr lhr 2hr 2hr 4hr lhr Activity Move rig Rig moved 100.00 % MI/RU At well location - Slot Derrick management Rigged up High pressure lines rig lines from tree to tiger tank Prepare to pull bpv Equipment work completed Wellhead work Retrieved Hanger plug Pull bpv & set twc & Nd 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 Tubing hanger Mu landing jt. & pull hanger to floor & remove. Equipment work completed Pull Single completion, 3-1/2in O.D. Pulled Tubing in stands to 0.0 ft Completed operations Run Single completion, 3-1/2in O.D. Ran Tubing in stands to 6317.0 ft Mu Unique overshot & baker pkr. assy & rih & tag & space to place overshot 2.55' from being fully extended, mu hanger & land same & set twc & test. On bottom Nipple down BOP stack Rigged down Well control Equipment work completed Wellhead work Installed Xmas tree install tree & test same to 5000 psi. Equipment work completed Wellhead work Removed Hanger plug Equipment work completed Run Single completion, 3-1/2in O.D. Set packer at 6281.0 ft with 4500.0 psi psi. tbg. to 4500 & mon. 30-min & bleed to 2000 psi. & psi. annulus to 4500 & monitor 30-min good test. (test waived by Blair Wonzell Packer set at 6281.0 ft Wellhead work Installed Hanger plug set bpv & secure tree area & release rig for move to MPL-28 Equipment work completed MILNE POINT, ALASKA TO: FROM: WELL# Main Category: Sub Category: Operation Date: Pat Collins Matthew Linder J-15i E-line Initial perf/static/perf 12/1 O- 1 2/1 2/99 Objective: Perform inital perforations on OB sands. Let well stablize for +24 hours and perform initial static on OB sands. Perform initial perforations on OA sands. Reference log is SWS CBL dated 11/19/99. Perf guns are 2" power jet, 4 SPF, 2006 HMX, 6.5 gms, .20" entrance hole, 18.6" penetration. Operation: 1 2/10/99 3:30 pm. Rig up and pulled BPV. Rig up SWS. Pressure tested lubricator to 2500 psi. Jewelry Log and gun run number #1 RIH w/GR/CCL (COL to top shot is 10') and 20' perf gun. Tied into short joints and recorded jewelry log. Dropped back and tagged TD at 6954'. Logged three collars. Repeat logging pass. Tools on depth. Dropped back to TD. Logged up and onto depth no collars recorded. Pulled into position placing CCL at 6925'. Perforated interval 6935'-6955'. Good indication of guns firing. Logged off catching three collars. POOH. All shots Fired. Gun run number #2. RIH with second gun to TD at 6954'. Logged three collars, log on depth. Retagged, logged into position catching collar at 6919'. Pulled into position at 6905' CCL depth and perforated 6915'-6935'. OB perforation interval completed at 11:28 pm. Set BPV for wellhouse installation. 1 2/1 2/99 5:30 pm. Initial "OB" static survey. Rig up SWS. Pulled BPV, well is stagnate. RIH w/GR/CCL and pressure/temp tool parking manometer at mid perf at 6935'. Initial pressures indicated 2140 psi and falling fast (2 psi per minute). Noticed wellhead pressure had increased from running in the hole from 0- 240 psi due to line and tool displacement. Bled wellhead to zero and let tools stabilize. Recorded a bottom hole pressure of 1775 psi at 82.59° degrees for 30 minutes. POOH. Gun run number #3. RIH w/GR/CCL (CCL to top shot is 4') and 20' perf gun. Tied into short joints. Dropped back and tagged TD at 6954'. Logged up from 6947'-6700'. Tools on depth. Dropped back and logged tools into position placing CCL at 6816'. Perforated interval from 6820'-6840'. Logged off and POOH. Gun run number #4. RIH with forth and final perf gun to TD at 6954'. Logged three collars tools on depth. Dropped back and logged gun into position placing CCL at 6771 '. Perforated interval from 6775'-6795'. Logged off through short joint. POOH and rigged down. Conclusion: Perforated "OB" sand from 6915'-6955'. Wait a day and half. Ran static to mid perf of "OB" sands (6935') recording a BHP of 1775 psi at 86°. Perforated to "OA" sand from 6820'-6840' and 6775'-6795'. Rig down SWS. SIWHP: 0 IA:0 OA: N/A Note: All measurements are slickline depths unless otherwise noted. Diesel Used [ J Methanol Used North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-15 Surveyed: 15 November, 1999 SURVEY REPORT 14 December, 1999 Your Ref: AP1-500292295200 Surface Coordinates: 6014742.32 N, 551972.61 E (70° 27' 03.6630" N, 149° 34' 33.4467" W) Kelly Bushing: 65.12ft above Mean Sea Level DRILLING SERVIr'Ec; Survey Ref: svy8922 A IL~I I IEIU~TON Sperry-Sun Drilling Services Survey Report for MPJ-15 Your Ref: AP1-500292295200 Surveyed: 15 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -65.12 0.00 208,84 0,430 225.380 143.72 208.84 301.73 0,570 304.050 236.61 301.73 394.33 1.490 331.950 329.'19 394.31 485.56 2.800 341.950 420.35 485.47 579.67 6.680 344.270 514.12 579.24 675.80 9.390 343.810 609.30 674.42 774.15 11.450 345.930 706.03 771.15 870.19 15.270 342.260 799.45 864.57 967.38 20.390 338.460 891.94 957.06 1063.83 23.850 328.920 981.31 1046.43 1162.20 27.960 331.290 1069.78 1134.90 1256.81 32.280 329.590 1151.60 1216.72 1354.69 38,690 330.140 1231.26 1296.38 1450.34 42,670 331.500 1303.78 1368.90 1547.53 45,890 330.440 1373.35 1438.47 1643.93 51,400 331.360 1437.02 1502.14 1741.41 54,610 334.140 1495.68 1560.80 1837.20 57.550 333.450 1549.13 1614.25 1934.26 61.370 337.470 1598.46 1663.58 2032.37 61.420 338.230 1645.43 1710.55 2126.88 60,480 337.240 1691.32 1756.44 2225.59 60.160 336.520 1740.20 1805.32 2322.68 60.210 338.560 1788.48 1853.60 2419.04 59.500 337.420 1836.87 14 December, 1999 - 14:34 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E 0.55 S 0.56 W 0.54 S 1.19 W 0.78 N 2.14 W 3.95 N 3.38 W 11.41 N 5.58 W 24.32 N 9.28 W 41.50 N 13.90W 62.80 N 20.07W 90.76 N 30.19W 123.10 N 46.44W 160.38 N 67.79W 201.64 N 91.25W 250.76 N 119.74W 305.20 N 150.10W 364.51N 183.04W 427.73 N 218.19W 496.94 N 253.80W 568.24 N 288.90W 644.28 N 323.55W 724.05 N 356.03W 800.51 N 387.33W 879.38 N 421.00W 957.23 N 453.18W N 484.40W 1901.99 1034.48 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 6014742.32 N 551972.61 E 6014741.77 N 551972.06 E 6014741.78 N 551971.43 E 6014743.09 N 551970.47 E 6014746.25 N 551969.20 E 6014753.69 N 551966.95 E 6014766.58 N 551963.16 E 6014783.72 N 551958.43 E 6014804.98 N 551952.10 E 6014832.86 N 551941.79 E 6014865.10 N 551925.32 E 6014902.22 N 551903.70 E 6014943.32 N 551879.96 E 6014992.24 N 551851.13 E 6015046.47 N 551820.38 E 6015105.55 N 551787.03 E 6015168.51 N 551751.44 E 6015237.48 N 551715.35 E 6015308.54 N 551679.75 E 6015384.32 N 551644.57 E 6015463.87 N 551611.54 E 6015540.11 N 551579,71 E 6015618.75 N 551545,49 E 6015696.36 N 551512,77 E 6015773.40 N 551481.00 E 0.206 0.692 1.103 1.488 4.127 2.820 2.130 4.072 5.400 5.161 4.308 4.654 6,557 4.263 3.399 5.760 4.003 3.127 5.311 0.682 1.352 0.712 1.824 1.261 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 0.00 -0.31 -0.07 1.50 4.90 12.65 26.03 43.72 65.81 95.54 131.57 174.03 220.98 277.07 338.79 405.99 477.62 555.02 634.18 717.59 803.71 886.31 972.02 1056.23 1139.55 Continued... -2- DrillQuest Sperry-Sun Drilling Services Survey Report for MPJ-15 Your Ref: API-500292295200 Surveyed: 15 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 2516.43 58.630 337.470 1886.93 1952.05 2613.34 60.390 341.570 1936.12 2001.24 2709.27 61.750 343.830 1982.53 2047.65 2806.84 61,980 342.510 2028.54 2093.66 2903.53 62.100 344.750 2073,87 2138.99 2999.96 62.610 343.950 2118.62 2183.74 3097.84 62,550 343.350 2163.69 2228.81 3194.43 60.180 339.240 2209.99 2275.11 3292.18 60.540 337.940 2258.34 2323.46 3389.28 60,800 339.040 2305.90 2371.02 3484.56 61.120 337.420 2352.15 2417.27 3582.72 60.980 337.240 2399.67 2464.79 3677.58 59,030 339.450 2447.09 2512.21 3773.10 58.900 340.070 2496.34 2561.46 3871.92 58.800 337.150 2547.47 2612.59 3968.17 58.810 339.610 2597.32 2662.44 4066.04 58.710 340.270 2648.08 2713,20 4161.08 57.330 339.670 2698.42 2763.54 4257.47 57.830 339.490 2750.09 2815.21 4355.04 57.440 340.100 2802.32 2867.44 4452.17 57.340 338.820 2854.67 2919.79 4548.38 57.600 339.130 2906.41 2971.53 4644.87 57.750 339.230 2958.00 3023.12 4741.56 57.150 338,620 3010.02 3075.14 4838.91 59.170 338.790 3061.38 3126.50 Global Coordinates Northings Eastings (ft) (ft) 1111.63 N 516.45W 6015850.32 N 551448.42 E 1189.84 N 545.63W 6015928.32 N 551418.70 E 1269.99 N 570.58W 6016008.30 N 551393.18 E 1352.34 N 595.49W 6016090.48 N 551367.70 E 1434.28 N 619.56W 6016172.24 N 551343.06 E 1516.53 N 642.61W 6016254.33 N 551319.44 E 1599.90 N 667.06W 6016337.53 N 551294.41E 1680.18 N 694.21W 6016417.62 N 551266.70 E 1759.27 N 725.22W 6016496.49 N 551235.14 E 1838.03 N 756.26W 6016575.03 N 551203.55 E 1915.39 N 787.15W 6016652.17 N 551172.12 E 1994.64 N 820.26W 6016731.19 N 551138.46 E 2070.98 N 850.59W 6016807.32 N 551107.60 E 2147.78 N 878.90W 6016883.91 N 551078.75 E 2226.51 N 909.74W 6016962.43 N 551047.36 E 2303.04 N 940.07W 6017038.75 N 551016.50 E 2381.64 N 968.77W 6017117.15 N 550987.25 E 2457.38 N 996.38W 6017192.69 N 550959.11 E 2533.64 N 1024.77W 6017268.75 N 550930.19 E 2610.98 N 1053.24W 6017345.89 N 550901.19 E 2687.59 N 1081.94W 6017422.30 N 550871,95 E 2763.31 N 1111.04W 6017497.81 N 550842.32 E 2839.52 N 1140.02W 6017573.82 N 550812.81 E 2915.57 N 1169.33W 6017649.66 N 550782.98 E 2992.62 N 1199.36W 6017726.50 N 550752.41 E Dogleg Rate (°/~00ft) 0.894 4.073 2.502 1.216 2.050 0.905 0.548 4,468 1.213 1.023 1.524 0.215 2.880 0.573 2.531 2.186 0.586 1.548 0.542 0.662 1.115 0.383 0.178 0.817 2.080 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 1223.06 1306.53 1390.29 1476.09 1561.19 1646.22 1732.80 1817.46 1902.42 1987.07 2070.36 2156.22 2238.36 2320.20 2404.76 2487.08 2570.74 2651.34 2732.7O 2815.10 2896.91 2978.03 3059.56 3141.07 3223.76 Continued... 14 December, 1999 - 14:34 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for MPJ-15 Your Ref: API-500292295200 Surveyed: 15 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. 4934.82 59.430 338.990 5033.50 58.230 338.410 5130.30 57.450 338.170 5227.11 57.900 337.230 5323.07 60.230 336.430 5419.36 59.940 335.940 5516.66 62.220 339.570 5614.10 61.820 337.860 5710.21 61.910 337.470 5806.56 61.750 338.140 5903.99 61.470 338.360 6000.44 62.130 338.270 6097.91 60.680 340.400 6195.19 60.570 340.450 6293.11 60.990 339.010 6388.53 60.650 341.320 6486.75 59.520 338.280 6583.52 59.670 338.640 6679.90 59.690 340.650 6778.00 59.220 340.260 6874.60 59.150 340.440 6971.58 58.330 339.070 7069.40 57.610 337.890 7089.64 57.350 338.430 7145.00 57.350 338.430 Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (fi) (ft) (ft) (ft) 3110.35 3175.47 3161.42 3226.54 3212.94 3278.06 3264.71 3329.83 3314.04 3379.16 3362.06 3427.18 3409.12 3474.24 3454.84 3519.96 3500.16 3565.28 3545.65 3610.77 3591.97 3657,09 3637.55 3702.67 3684.20 3749.32 3731.92 3797.04 3779.72 3844.84 3826.25 3891.37 3875.24 3940.36 3924.22 3989.34 3972.88 4038.00 4022.73 4087,85 4072.22 4137.34 4122.55 4187.67 4174.43 4239.55 4185.31 4250.43 4215.17 4280.29 Global Coordinates Northings Eastings (ft) (ft) 3069.55 N 1229.06W 6017803.23 N 550722.17 E 3148.22 N 1259.73W 6017881.68 N 550690.95 E 3224.35 N 1290.04W 6017957.60 N 550660.11 E 3300.04 N 1321.09W 6018033.07 N 550628.54 E 3375.70 N 1353.48W 6018108.50 N 550595.62 E 3452.06 N 1387.17W 6018184.62 N 550561.39 E 3530.87 N 1419.38W 6018263.21 N 550528.64 E 3611.05 N 1450.61W 6018343.16 N 550496.85 E 3689.44 N 1482.82W 6018421.33 N 550464.10 E 3768.09 N 1514.91W 6018499.75 N 550431.46 E 3847.70 N 1546.67W 6018579.13 N 550399.15 E 3926.68 N 1578.08W 6018657.90 N 550367.19 E 4006.74 N 1608.28W 6018737.75 N 550336.42 E 4086.62 N 1636.69W 6018817.42 N 550307.46 E 4166.78 N 1666.29W 6018897.38 N 550277.30 E 4245.14 N 1694.56W 6018975.54 N 550248.48 E 4325.02 N 1723.94W 6019055.22 N 550218.55 E 4402.66 N 1754.58W 6019132.63 N 550187.36 E 4480.65 N 1783.52W 6019210.43 N 550157.88 E 4560.27 N 1811.78W 6019289.84 N 550129.07 E 4638.40 N 1839.68W 6019367,78 N 550100.62 E 4716.18 N 1868.36W 6019445.35 N 550071.40 E 4793.33 N 1898.78W 6019522.29 N 550040.45 E 4809.17 N 1905.13W 6019538.08 N 550033.99 E 4852.51 N 1922.27W 6019581.31 N 550016.55 E Dogleg Rate (°/lOOft) 0.325 1.316 0.833 0.943 2.531 0.534 4.019 1.603 0.370 0.635 0.349 0.689 2.428 0.122 1.353 2.143 2.919 0.356 1.800 0.589 0.176 1.474 1.260 2.591 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 3306.23 3390.66 3472.60 3554.39 3636.64 3720.01 3805.14 3891.18 3975.92 406O.84 4146.55 4231.54 4317.11 4401.85 4487.3O 4570.58 4655.69 4739.15 4822.33 4906.78 4989.72 5072,60 5155.53 5172.59 5219.20 Projected Survey Continued.,. 14 December, 1999- 14:34 -4- DriliQuest Sperry-Sun Drilling Services Survey Report for MPJ- 15 Your Ref: API.500292295200 Surveyed: 15 November, 1999 North Slope Alaska Alaska State Plane 4 Milne Point MPJ 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. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 338.870° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7145.00ft., The Bottom Hole Displacement is 5219.39ft., in the Direction of 338.390° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 7145.00 4280.29 4852.51 N 1922.27 W Projected Survey Continued... 14 December, 1999 - 14:34 - 5 - DriilQuest North Slope Alaska Sperry-Sun Drilling Services Survey Report for MPJ-15 Your Ref: API.500292295200 Surveyed: 15 November, 1999 Alaska State Plane 4 Milne Point MPJ Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Depth (ft) 7145.00 Vertical Depth (ft) 4280.29 Survey Tool Description MWD Magnetic 14 December, 1999- 14:34 -6- DriilQuest GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 121037 Company Field: Alaska Oil & Gas Cons Comm Altn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 12/21/99 ion Well Job # Log Description Date BL Sepia CD MPJ-15 STATIC PRESSURE SURVEY 991212 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc, Petrotectnical Data Center MB3-3 900 E. Benson Blvd, Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED 1999 Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK fi~3 Al-tN: Sherri.~/~J.~~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'I'N: Sherrie NO. 12979 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 12/1/99 Well Job # Log Description Date Color Sepia CD MPJ-15 99427 SCMT 991119 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson BIvd, Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED : .' ,~ 0 8 1999 Alaka 0il & Gas Cons. Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 9~s~03 . '~-~ STATE OF ALASKA --' ALASKA ~IL AND GAS CONSERVATION CO,v, MISSION APPLICATION FOR SUNDRY APPROVAL . . . 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 Repair Pkr & Complete Name of Operator BP Exploration (Alaska) Inc. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2344' NSL, 3347' WEL, SEC. 28, T13N, R10E, UM At top of productive interval 1257' NSL, 4966' WEL, SEC. 21, T13N, R10E, UM At effective depth 1803' NSL, 5224' WEL, SEC. 21, T13N, R10E, UM At total depth 1916' NSL, 5270' WEL, SEC. 21, T13N, R10E, UM (Planned) (Not Final) (Not Final) 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Datum Elevation (DF or KB) Plan KBE = 65.95' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-15i 9. Permit Number 199-107 10. APl Number 50- 029-22952-00 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 7145 feet true vertical 4306 feet Effective depth: measured 7000 feet true vertical 4203 feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 110' Surface 7053' Intermediate Production Liner Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) Cemented MD TVD 13-3/8" 260 sx Arctic Set (Approx.) 5-1/2" 490 sx Arctic Set III, 390 sx Class 'G' 110' 110' 7083' 4247 ORIGINAL 3-1/2", 9.2#, L-80 to 6390' Packers and SSSV (type and measured depth) (Leaking) 5-1/2" SAB-L packer at 6356'; 'X' Nipple at 2196' 13. Attachments [] Description summary of proposal 14. Estimated date for commencing operation December 6, 1999 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Date approved Robert Laule, 564-5195 [] Detailed operations program [] BOP sketch 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Robert Laule ,.~/~.L.~.~..-~.v~(,_.~ Title Operations Drilling Engineer Commission Use Only Plug integrity__ BOP Test m.~ Location clearance __ I 009 Mechanical Integrity Test "~ Subsequent form required 10- '~' ~ ORIGINAL SIGNED' BY Commissioner Date - p~e~~Ybf the Commission -~0-403 Rev. 06/15/88 ................. ~"~" Submit In Triplicate During the November completion of J-15 with Nortic #3. The new completion would not pass the MIT. Subsequently the packer has been identified as the source of the leak. The well was left unperforated until the completion was repaired, The following is the proposed procedure for the repair of the well. PRE-RIG SCOPE 1. Chemically cut the tubing in the first full joint above the packer. 2. Set BPV. RIG SCOPE of WORK: 1. MIRU Work Over Rig 2. Pull BPV. Set TWC. ND Tree, NU BOP and test. 3. Pull existing tubing string. 4. Run GR/JB to top of fish. 5. Run 3-1/2" packer completion overshot old tailpipe assembly 6. Freeze protect annulus. Set packer and test. Test to be witnessed by AOGCC. 7. RDMO Work Over Rig. ~ ~,, ~__ ~ 7-1/16' 5M Vetco gray Orig. GL EJev. ~ 35.1' 5.5 Emergency slips, Yetco Tbg. RT To Tbg, Speel = 28:6' Nordic #3 Hng., threads top and bottom, 3" .... PV f' CtW H B pro lie KOP @ 450' Max. h01e angl& = 62 deg. @ 5,500' 60 deg, to 62 d, eg, (1900' - 6,300') H01e ang e thru peris = > 59 deg. 3.5" HES X-Nipple ( 2.813"id ) 5,5" 15.5 ppf, J-55, Btrc. pred. cesing ( drift tD = 4.950", cap, = 0.0238 bpf ) 3.5" 9.3 ppf, L-80 NSCT tubing (cap. = 0.0087 bpf, drift = 2.867") 5.5'x 3.5" Baker SABL-3 I6290 Perm pkr, 3.5"HESX-Nipp[e(2.8t3"id) I 6,320' Failed Packer stimulation Spmmary_ Perforation Summary Ret log2_.' Size SPF interval (TVD) F 5.5"X 3.5" Baker SABL-3 6,356' L Perm pkr. 3.5" HES XN-Nipple F 6,378~ ( 2.750" pk. bore. 2.635"id ) WLEG I 6,390' 5.5" float coElar (PBTD) t 7,000' 55" float shoe L 7,081' DATE IREV:~Y j COMN~ENFS MIl-NE POINT UNiT 11/19/99 MDO f ,illed and cased & co,~~ WELL j.~5! BP EXPLORATIO~ ~AK) Re: MP J-15I Completion Status 9'~- to7 Subject: Re: MP J-15I Completion Status Date: Tue, 23 Nov 1999 07:38:49 -0900 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Johnson, Frederick C (ARCO)" <JohnsoFC~BP.com> CC: "Triolo, Mike T" <TrioloMT~BP.com>, "Cocking, David A" <CockingD~BP.com>, "Mallary, Chuck (ARCO)" <MallarCR~BP.com>, "Laule, Robert B" <LauleRB@BP.com>, "Collins, Patrick J" <CollinsP~BP.com> Fred, Thanks for documenting our discussion. Blair Wondzell "Johnson, Frederick C (ARCO)" wrote: > Well Name: MP J-15I > Permit No: 199-107 > The MP J-15I has been drilled and completed by Nordic 3. The rig was > released on November 20, 1999 after running the 3-1/2" tubing completion. > The MIT test on this well failed due to a suspected leaking packer. The > well has not been perforated. The forward plan for this well will be to > recomplete the well with a new packer. The well will not be put on > injection until the well is recompleted. 1 of 1 11/23/99 7:39 AM TONY KNOWLE$, GOVERNOR ALAS OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 2, 1999 Charles MallaD' Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Milne Point Unit MPJ- 15i BP Exploration (Alaska) Inc. Permit No: 199-107 Sur. Loc. 2344~NSL, 3347"WEL, Sec. 28, T13N, R10E. UM Btmhole Loc. 1894~SL? 5201%VEL. Sec. 21, T13N, R10E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced wcll. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity, (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may 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 THE COMMISSION dlffEnclosure Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ..... STATE OF ALASKA - , ALASK OIL AND GAS CONSERVATION CO,, PERMIT TO DRILL 20 AAC 25.0O5 ~ISSION la. Type of work [] Drill [] Redrill Ilb- Type of well [] Exploratory [] Stratigraphic Test [] 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 = 65.95' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 315848 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2344' NSL, 3347' WEL, SEC. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1257' NSL, 4966' WEL, SEC. 21, T13N, R10E, UM MPJ-15i At total depth 9. Approximate spud date Amount $200,000.00 1894' NSL, 5201' WEL, SEC. 21, T13N, R10E, UM 11/09/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025515, 79' MDI MPJ-08, 396' at 6462' MD 1280 7114' MD / 4260' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 350' MD Maximum Hole Angle 60° Maximum surface 1090 psig, At total depth (-I-VD) 4000' / 1550 psig ;18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 13-3/8" 68# L-80 Welded 81' Surface Surface 81' 81' 260 sx Arctic Set (Approx.) 7-7/8" 5-1/2" 15.5# J-55 BTC 7139' 30' 30' 7109' 4258' 489 sx ArcticSet 3, 390 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Productionlntermediate~7%, ~""~= ~¢* i!! i ~ ¢ i:~ ~'~ Liner Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Oontact Engineer Name/Number: Mik Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-462~ 21. I hereby certify..t~at ~e forego~is true and correct to the best of my knowledge ChadesMallary .- Title Senior Drilling Engineer Date '//--//-- ¢ ~ r (" // Commission Use Only Permit Number I APl Numb.`-/- er I Approval Date See cover letter / ~.~'¢'/~//'(,~'~ ~ ] 50- (~ ~ ~' .- /~~'.~/Z.. -~..~ I // "' ¢~' "' ¢' ~ for other requirements Conditions of Approval: Samples Required [--I Yes .~ Mud Log Required Hydrogen Sulfide Measures []Yes Directional Survey Required [] No Required Working Pressure for BOPE I--]2K; I~K; I--I4K; E]SK; [-]10K; E]15K Other: by order of Approved By .J~iGINAL SIGNED BY Commissioner the commission Date(/"~ ~'~; Form 10-401 Rev. 12-01-85 , [obert N. Ch~i~Len~ur~ Submit In Triplicate ¥ ell Name: MPJ-15i Well Plan Summary I Type of Well (producer or injector): I Water Injector Surface Location: 2344' NSL, 3347' WEL, Sec. 28, T13N, R10E X = 551,972.54 Y = 6,014,742.33 Target Start: 1257' NSL, 4966' WEL, Sec. 21, T13N, R10E 200' Radius X = 550,314.00 Y = 6,018,923.00 Z = 3,800' TVDss Intermediate Bottom Hole Location: 1894' NSL, 5201' WEL, Sec. 21, T13N, R10E X = 550,072.45 Y = 6,019,558.49 Z = 4,195' TVDss I AFE Number: ]337168 I [Rig: I Nordic 3 ]Estimated Start Date: I Nov.9, 1999 I ]Operating days to complete: 112.5 IMD I 7,114' I ITvorkb: I4,260' I [KBE: I Well Design (conventional, slim hole, etc.): I Conventional Injector (grass roots well) [ 65.95' Objective: Drill a single 7 7/8" hole out of 13 3/8" conductor to TD. Build angle from 2° - 5°/100' out of the conductor, reaching 60° tangent angle at +1,831' MD. Hold tangent angle to target and to TD/PBTD 7,114' (4,260' TVD)/7,024' (4,215' TVD). Run, cement and test 5.5", 15.5#, L-80 BTC long string. Will complete the well 3 Y2", 9.3#, L-80 tbg. The well is designed for water injection into the Schrader Bluff 'OA' and 'OB' sands. Asset Production/Injection Forecast: Estimated Reserves: Injector to sweep 1,000 MSTBO Expected Initial Rate: Injection rate: 2,000 b/d Expected 6 month avg: Injection rate: 1,500 b/d Current Well Information Well Name: APl Number: Well Type: BHP: BHT: MP J-15i Water Injector 1,550 psi @ 4,000' TVD (estimated from offset wells) => 7.5 ppg EMW 80°F @ 4,020' TVDss Mechanical Condition MPJ-15i Cellar box: RKB to Cellar box: Nordic 3: Conductor: Elevation above MSL = 35.1' 30.85' RKB + MSL = 65.95' 80' of 13 3/8", 48#, H-40, BTC Drillinq Proqram Ove . iew Surface and Anti-Collision Issues Surface Shut-in Wells: None required by Milne Point policy. Well J-16 spaced 30' South. Close Approach Wells: NONE- All wells may flow. Well Name Current Status Production Priority Precautions MPJ-08 Lower perfs N/A Closest approach at 6,462' md. Point abandoned by 4ES to point separation 396'. Surveys will prior to drill-out, be taken every 30' while drilling through the close approach region. Well Control: Expected Formation Pressures & BOPE Test Pressures Expected BHP Max Exp Surface Pressure I BOPE Rating I Planned BOPE Test Pres. 1,600 psi, 3,535' TVDss 1,193 psi I 5,000 psi WP I 3,500/250 psi Rams and Valves (estimated) 8.7 ppg (.115 psi/ft gas gradient) (Entire stack & valves) 2,500/250 psi Annular Note: The wellbore will be drilled from surface to TD in the Schrader Bluff through a 13 5/8" surface diverter stack. The diverter will be removed and an 11 ", 5M BOP stack will be installed and tested prior to running the 3-1/2" completion. Mud Program A detailed Baroid mud program is included with the well plan. In summary, an LSND system with a 120 viscosity will be used initially to help lift the heavy gravels at the surface. The viscosity will then be relaxed to the 70-75 range for the remainder of the well. There are no LCM restrictions for this well. Density Funnel Yield pH APl Solids 10 Sec 10 Min (ppg) Viscosity Point Filtrate (% LGS) Gels Gels 8.6 120 50 8.5 12 < 6% 20 30 to to to to to to to 9.2+ 70 23 9.5 6 8 10 Waste Disposal' No annular injection is allowed at Milne point. All drilling waste will be hauled to KRU 'IR' pad or PBU Drillsite 4. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be prepared. Formation Markers Formation Tops MD TVDss Pore EMW Comments Pressure (ppg) (psi) Base Permafrost 2286 1780 TUZC 5325 3300 1494 8.71 TUZB 5794 3535 1600 8.70 Lower Ugnu; Possible hydrocarbon bearing sands SBF2-NA 6420 3848 1539 7.69 ToD of the Schrader Formation TSBD-OA 6760 4018 1607 7.69 Top of the 'OA' sands Base OA 6832 4054 1622 7.69 TSBB-OB 6904 4090 1836 8.63 Top of the 'OB' sands Base OB 6954 4115 1846 8.63 TD 7109 4193 1874 8.59 Casing/Tubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 7 7/8" 5 Y2" 15.5# J-55 BTC 7,139' 30'/30' 7,109¥4,258' Tubing 3 ~" 9.3# L-80 NSCT 6,790' 30'/30' 6,760'/4,083' Cement Calculations rLiner Size 1 5 1/2" BTC I Basis I 80' shoe jts, 50% excess in open hole, 250% in permafrost (7 7/8" hole), cement to surface. lTD 7,114' MD (4,260' TVDrkb' Total Cement Volume: Pre-flush Spacer Lead Tail Temp 20 bbls of Chemical wash (B47 + J237a). 75 bbls of B45 Viscosified (1.5%) Spacer Weighted to 10 ppg. 489 sxs (386.7 bbls), ArcticSet 3 - Lite, Yield 4.44 ft3/sx, mix fluid 20.1 gps 390 sxs (80.6 bbls), Class 'G' + .3% D65 + .5% S001 + .40% D167 + 0.2% D46, Yield 1.16 ft3/sx, mix fluid 5.08 gps BHST -80° F from SOR, BHCT 65° F estimated by Dowell Centralizer Placement: 1. Run (1) rigid straight blade centralizer per joint on the first 28 joints. 2. Screw down each centralizer in the middle of each joint. 3. Run 1 Bow Spring centralizer on either side of the Port collar. Other Cement Considerations: 1. Batch mix this slurry (< 50 bbl). 2. Confirm blends and calculations at the rig site. Materials Needed: L-80 Long String: L-80 Completion: 7,110' 5-1/2" 5-1/2" 28 - 5 Y2" x 7 5/8" x 8" 2 - 5 Y2"x 8-1/2" x 14" 1 -5W' 6,800' 5 ¼" x 3-1/2" Will run 'X' nipple I -3~" 2 - 3-1/2" 3-1/2" 2 Each - 3-1/2" 5.5", 15.5#, J-55, BTC Casing Halliburton float collar Halliburton EDJ float shoe Rigid Straight Bladed Centralizers Bow Spring Centralizer on either side of port collar TAM Port collar 3.5", 9.3#, L-80 NSCT tubing (Grade 'B') Baker 'SABL' production packer SSSV, NSCT threads 'XN' nipple 'X' Nipple (including upper 'X' nipple) WLEG 10', 8', 6', 4', 2' NSCT space out pups Survey and Logging Program 7 7/8" Section: Open Hole: MWD/GR / PWD Will add Res on second bit run Sample Catchers - None required Cased Hole: None. Perforating: Will be perforated, t-Rig via CT conveyed 2" guns. Locations OA and OB sands Perf Interval: 60' - 100' Gun Size/Type: 2" powerjet 60° phasing loaded @ 4 spf Delivery: E-line Under Balance: No, overbalance BHP: 1,550 @ 4,000' TVD BHT: 80°F Bit Recommendations Bit Hole Size Depths (MD) Bit Type Nozzle / Flow Rate K-Rev's Hours Type and Section Hughes 2, MX-C1 7 7/8" Surface - 7,109' TD Mill tooth 15, 15, 15, 10 300 30 Mill tooth Insert Bits: If a 7 7/8" insert bit is run, notify the ODE before exceeding 450K rev's or 40 hours on the bit. Motors and Required Doglegs BHA Motor Size and Motor Flow Rate RPM's Required Doglegs Number Required I 6 1/4" Sperrydrill 8/9, 4 stg Slow 170 - 400 gpm 53 - 124 motor Spud in and build to 60° @ (Mill tooth) Speed, 1.5° adj w/7.6" sleeve 60-100 rotate 5°/100' and hold tangent to TD 2 Same Same Same Hold 60° tangent angle to TD (Mill tooth) Note: 4.0 stage slow speed motor turns at .31 rpm/gal MPJ-15i Operations Summary Snapshot of Well Proqram 1. MIRU Nordic 3. 2. NU diverter, pick up DP 3. MU 7 7/8" BHA, spud in drill to planned TD (7,114' md). 4. Run, cement and test 5 Y2", 15.5#, J-55, BTC long string. 5. ND diverter, NU wellhead & BOP, test. 6. Run CBL 7. Run 3 W', 9.3#, L-80, NSCT completion assembly. 8. Install TWC. 9. ND BOP, NU tree, test to 5,000 10. Remove TWC, install BPV, freeze protect and set packer. 11. RD, move off well. 12. Post rig work: Remove BPV, perforate Dri,,,n Hazards and Cont,,,.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 Diverter Prior to spud, per crew Once per week per crew while drilling with diverter 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) Hydrogen Sulfide · MP J Pad is not designated as an H2S Pad. 3) Hydrates and Shallow Gas · Always be prepared for the unexpected possibility of hydrates, shallow gas and hydrocarbons. There has never been any hydrate, shallow gas or unexpected hydrocarbon problems on J pad. 4) Lost Circulation · There is no history of lost circulation problems drilling to the Schrader Bluff formation on J pad and none expected drilling this well. 6) Faults · Use the target circle as a hard line due to faults, 800' North of the target, 700' East of the target and 700' West of the target. 7) Unexpected High Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Adjacent Well J-19 was recently shut-in where reservoir pressure is 1,850 psi, 4,000'TVDss or 8.9 EMW. In this well, the Schrader Bluff formation will be drilled with 9.4 ppg mud. 8) Pad Data Sheet · Please Read the J-Pad Data Sheet Thoroughly. W¢lheed: 7 1/16-, 5M MPJ-15i Cellar Box Elevation' 35.1' 3.5", Gray hgr, w/3 1/2" _PROPOSED CO._..MPLETIO__.N. Rig RKB Elevation: 30.85' NSCT threads pin x box 3" CIW "H" BPV profile 13 3/8", 68#, L-80, Welded ~ ........ ..... I - - ~ 51/2" TAM Port Collar I ~ I 2.600' I 31/2" 'X' nipple, ID 2.750" Note: The completion tubing will ~ ~-~ ~ ~ be used for water injection 31/2", 9.3#, L-80, NSC DIRECTIONAL PLAN ~ 31/2" ' X' nipple, 2.750" ID (PROPOSED PLAN Wp 2) ~ 51/2" x 31/2" Baker SABL Pkr w K-Anchor · - 6 400' 31/2" ' XN' nile, 2 635" ID Grass Roots ConventIonal Injector ~ , PP · Max. hole angle - 60° Tangent fro ~ Tubing Tail (WLEG) Hole angle thru perf zone = 60° .Schrader'OA' SANDS PERFORATION ZONES: ~ PBTD 'Schrader' OB' SANDS ~ ' ' HOLE ANGLE at TM: 60° DATE REV. BY COMMENTS MILNE POINT UNIT 9/20/99 RMK Proposed Completion Well J-lEi APl No: BP EXPLORATION (AK} J-1 NORTH ID' d-2 SOUTH [~.1 + N 40f¢ 1 · 11 B 2 · · 8 · 3 · 10· 4 · MPJ-15i · 16 · 12 ·17 m 19 ms · 20 · 14 I 21 · 7 · 22 LEGEND N 180~ + 3RN 21'01 4'26 No.002 P.02 VICINITY NAP, N.T.$. MPU J-PAD . t¢~,~:. Jeffrey J. Cotton /i~ ~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT TH!S PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 15, 1999, AS-BUILT CONDUCTOR EXISTING CONDUCTOR NOTES 1. DATE OF' SURVEY: OCTOBER 15, l ggg. 2. REFERENCE FIELD BOOKS: MPg9-o1 (PCS. 20). 3, ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 4. GEODETIC COORDINATES ARE NAD 27. 5. PAD SCALE FACTOR IS 0.9999031. 6. HORIZONTAL &: VERTICAL CONTROL IS BASED ON J PAD WELLS J-1 AND J-2. 7. ELEVATIONS ARE BPX Ik~I[_NE PO[NT DATUM M.S.L. LOCATED WITHIN PROTRACTED SEC. 28, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. '" ' PL'ANT GEOD~'Ti C GEOD£T[C .... CELLAR SECTION NO. COORDINATES COORDINATE__S POSITION(DMS) POSITION(D.DD)_._BO.X. 6.LEV. OFFSETS J_lSi Y= 6,014,742.32 N= 1000.05 70'27'03.663' 70.4510175' 35.1, 2,345;FsL X= 551,972.61 E= 1024.89 149'34'33.447' 14.9.5759575' 3,348' FEL ISSUED FOR INFC~RMATION I ~~--e~ Udm~ /"~'~ Alaska State Plane Zone 4 Milne Point MPJ MPJ-15 WPS __ 800 - 1600 - 2400 -- 3200 - I DrilIQuest' Proposal Data for MPJ-151 Wp4 Hodzoo~al Odgirl: flWII Relerence Mee.sur~'nent Units: North Reference: True Nor~ VDO<:jleg severity: Degrees per 100fl ertical Secqion Azimuth: 338.868° Vertical Sect~n Description: MPJ-Test2 Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azlm. VerticalNorthlngs Ea~llngs Vertical Dogleg I 0.00 0.0000.400 O.O0 0.00 N Q00 F, O.00 I 350.40O.(XX) 0.4CO 350.40 0.00 N O.CO E 0.00 0.O00 I 550.404.000325.000 55024 5;.72 N 4.00 W 6,78 L./2<OP: Start Dir @ 2.000°/100ff: 350.4Oft MD 350.40ft 'I-VD ;s3.~ umo 3z~.(ro ~La~ ~O.6~, 2;.,~W ~.~3 I~'-~'~ ' I033.7321.000325.1X)O1021.44 8'7.02 N ~0.94 W 103.14 4,000 ~]' 1831.4259.98~339.578 1617.59 546.46 N 272.01 W(:~'/.78 5.000 / . 6324 8 59983 ~395'/8 3865. O 4 92. 5N 6294 W 449767 0000 ! /D~r Rate Increase @ 3.000°/lOOft: 550.40ft MD, 550.24ft TVD ?m3.~ ~.¢8~ 33~ ,m.~o a~6~, ~Lo~w ~.o~ o.mo ~Dir Rate Increase @ 4.000°/10Oft: 783.73, MD, 781.43ft TVD ~ -- Cu-¥~-~rent Well Pro~s -- -- [ IWo,: -- ----~.,~-r~-F- -- -- I~'°}Dir Rate Increase @ 5.000°/100ft: 1033.73ft MD 1021.44ft TVD I H°~?L .c?~.~a~? . .................. V I Ref, Sm~cture Refo*ence: 1323.31 N. 546.75 E ~200.O0 I FIKI~ [IovatJoo: 65.10fl abova Moan Sea I.e/el ~ / 65.10ff above Structure Refere*tce %. I North Reference: True Nodh nd Dir: '1831.42ft MD, 1617.59ft TVD ................................. ~ ............................................................................... Base Permafrost - 1845.10 TVD 700.00 ............................................................................................................................ OOp Ugnu - TUZC - 3365.10 TVD I I I I I 0 800 1600 2400 3200 Scale: linch = 800ft Section Azimuth: 338.868° (True North) Vortical Soction ............................................................................................. Top Ugnu - TUZC - 3365.10 TVD 3600 .......... ~ ...................................................................... Top Ugnu M- TUZB - 3600.10 TVD -~oo MPJ INJ Target - Circle ~ 3865.10 TVD '~oo 4192.15 N, 1629.41 W t ..................................................... ~ ................................................ SBF2-NA- 3913.10 TVD | ................................................................ ~'~c"°°'°° ......................................... SBFI-NB- 3941.10 TVO 4000 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ ........................................................................... '"~I~~ .............................. SBEI-NF- 4046.10 TVD I ............................................................................... ~ ............................ TSBD-OA- 4083.10 TVD ................................................................................ '~o:~o ................... TSBC- 4119.10 TVO ....................................................................................... ~4~:- .................... TSBB-OB - 4155.10 TVD ................................................................. ~o;,[,~ 'm~- ............ SBAS - 4180.10 'z~./~, 0o o [ e th' 1 9 2 1 ftTVD ;o~ ~ 1~;~ [~a~ng '-~(~933.."/~ ~D~, 4D2~5~.~60(~ I I I I 3600 4000 4400 4800 5200 Scale: linch = 400ft Section Azimuth: 338.868° (True North) Vertical Section F'h~dtme Bay Unit Alaska State Plane Zone 4 Milne Point MPJ MPJ-15 WPS Eastings Scale: linch -- 70Oft 4900-~ -1400 -700 I I Depth · 7113.79ft MD, 4260.10ft -I-VD ] DrillQuestTM Current Well Properties Weft: MPJ-15 WPS Hodzo~tal Coo~dilates: Ref. Gk:4:~al Coordinates: 6014742.32 N, 551972.61 E Ref. Structure Reference : 1323.31 N, 546.75 E Ref. Geographical Coordinales: 70* 27' 03.6630' N, 149' 34' 33,4467' W RKB Elevation: 65.10ft above Mean Sea Level 65,10ff above Structure Reference Nor~ Refera~:e: True North Un~s: Feet 49OO o Z MPJ INJ Target- Circle 4200 -- 3865.10 TVD 4192.15 N, 1629.41 W 3500 -- 2800 -- : :~: 2100 - : 1400 ~ : 700 -- 0-- I I -1400 -700 Scale: linch = 70Oft ~astin,-,s 42OO 350O 28OO o Z 2100 1400 7OO - 1831.42ft MD, 1617.59ft TVD Dir Rate Increase- @ 5.000°/100ft' 1033.73ft MD, 1021.44ft TVD Dir Rate Increase @ 4.000°/100ft · 783.73ft MD, 781.43ft TVD 0 Dir Rate Increase @ 3.000°/100ft · 550.40ft MD, 550.24ft TVD KOP · Start Dir @ 2.000°/100ft: 350.40ft MD, 350.40ft TVD Reference is True North Sperry-Sun Drilling Services Proposal Report for MPJ-15 WPS- MPJ-15i Wp4 Revised: 1 November, 1999 Depth Incl. Azim. Depth (ft) (ft) 0.00 0.000 0.000 -65.10 350.40 0.000 0.000 285.30 400.00 0.992 325.000 334.90 500.00 2.992 325.000 434.83 550.40 4.000 325.000 485.14 600.00 5.488 325.000 700.00 8.488 325.000 783.73 11.000 325.000 534.57 633.81 716.33 800.00 11.651 325.000 732.28 900.00 15.651 325.000 829.44 1000.00 19.651 325.000 1033.73 21.000 325.000 924.71 956.34 1100.00 24.141 327.753 1017.53 1200.00 28.950 330.827 1106.96 1300.00 33.811 333.086 1192.31 1400.00 38.703 334.834 1272.93 1500.00 43.617 336.244 1348.19 1600.00 48.544 337.421 1417.54 1700.00 53.482 338.431 1480.43 1800.00 58.428 339.319 1536.40 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 6014742.32 N 551972.61 E 350.40 0.00 N 0.00 E 6014742.32 N 551972.61 E 400.00 0.35 N 0.25 W 6014742.67 N 551972.36 E 499.93 3.20 N 2.24 W 6014745.50 N 551970.35 E 550.24 5.72 N 4.00 W 6014748.01 N 551968.57 E 599.67 9.08 N 6.36W 6014751.35 N 551966.19 E 698.91 19.04 N 13;33W 6014761.27 N 551959.14 E 781.43 30.65 N 21.46W 6014772.82 N 551950.94 E 797.38 33.27 N 23.29W 6014775.42 N 551949.09 E 894.54 52.59 N 36.83W 6014794.66 N 551935.42 E 989.81 77.43 N 54.21 W 6014819.37 N 551917.86 E 1021.44 87.02 N 60.94W 6014828.92 N 551911.07 E 1082.63 108.22 N 74.98W 6014850.01 N 551896.88 E 1172.06 146.67 N 97.70W 6014888.31 N 551873.89 E 1257.41 192.64 N 122.11W 6014934.10 N 551849.16 E 1338.03 245.78 N 148.02W 6014987.06 N 551822.88 E 1413.29 305.68 N 175.22W 6015046.77 N 551795.26 E 1482.64 371.90 N 203.52W 6015112.79 N 551766.50 E 1545.53 443.91 N 232.70W 6015184.60 N 551736.82 E 1601.50 521.18 N 262.54W 6015261.66 N 551706.44 E Alaska State Plane Zone 4 Milne Point MPJ Dogleg Rate (°/100ft) 0.000 2.000 2.000 2.000 3.000 3.000 3.000 4.000 4.O0O 4.000 4.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 Vertical Section (ft) 0.00 0.00 0.42 3.79 6.78 10.76 22.57 36.33 39.43 62.33 91.77 103.14 127.97 172.03 223.71 282.61 348.30 420.26 497.95 580.79 Comment KOP · Start Dir @ 2.000°/100ft : 350.40ft MD, 350.40ft TVD Dir Rate Increase @ 3.000°/100ft · 550.40ft MD, 550.24ft TVD Dir Rate Increase @ 4.000°/100ft · 783.73ft MD, 781.43ft TVD Dir Rate Increase @ 5.000°/100ft- 1033.73ft MD, 1021.44ft TVD Continued... 1 November, 1999- 10:30 - I - DrillQuest 1.05.04c Measured ~j.~'~/~' jj~.. Sub-Sea Depth Incl, Azim, Depth (ft) (ft) 1831.42 59.983 339.578 1552.49 2000.00 59.983 339.578 1636.82 2286.22 59.983 339.578 1780.00 3000.00 59.983 339.578 2137.07 4000.00 59.983 339.578 2637.32 5000.00 59.983 339.578 3137.58 5324.68 59.983 339.578 3300.00 5794.45 59.983 339.578 3535.00 6000.00 59.983 339.578 3637.83 6324.18 59.983 339.578 3800.00 6420.13 59.983 339.578 3848.00 6476.10 59.983 339.578 3876.00 6538.07 59.983 339.578 3907.00 6590.05 59.983 339.578 3933.00 6686.00 59.983 339.578 3981.00 6759.96 59.983 339.578 4018.00 6831.92 59.983 339.578 4054.00 6903.89 59.983 339.578 4090.00 6953.86 59.983 339.578 4115.00 7000.00 59.983 339.578 4138.08 7093.79 59.983 339.578 4185.00 7113.79 59.983 339.578 4195.00 Sperry-Sun Drilling Services Proposal Report for MPJ-15 WPS- MPJ-15i Wp4 Revised: 1 November, 1999 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (ft) 1617.59 546.46N 272.01W 6015286;87N 551696.79 E 1701.92 683.25N 322.95W 6015423.30 N 551644.91E 1845.10 915.51N 409.42W 6015654.95 N 551556.81E 2202.17 1494.71N 625.08W 6016232.64 N 551337.12 E 2702.42 2306.17 N 927.21W 6017041.97 N 551029.34 E 3202.68 3117.63 N 1229.34W 6017851.30 N 550721.56 E 3365.10 3381.10 N 1327.43W 6018114.08 N 550621.63 E 3600.10 3762.29 N 1469.36W 6018494.27 N 550477.04 E 3702.93 3929.09 N 1531.47W 6018660.63 N 550413.78 E 3865.10 4192.15 N 1629.41W 6018923.00 N 550314.00 E 3913.10 4270.01 N 1658.40W 6019000.66 N 550284.47 E 3941.10 4315.43 N 1675.31W 6019045.96 N 550267.24 E 3972.10 4365.71N 1694.04W 6019096.11N 550248.17 E 3998.10 4407.89 N 1709.74W 6019138.17 N 550232.17 E 4046.10 4485.75 N 1738.73W 6019215.83 N 550202.64 E 4083.10 4545.76 N 1761.07W 6019275.69 N 550179.87 E 4119.10 4604.16 N 1782.82W 6019333.93 N 550157.73 E 4155.10 4662.55 N 1804.56W 6019392.18 N 550135.58 E 4180.10 4703.11 N 1819.66W 6019432.62 N 550120.20 E 4203.18 4740.55 N 1833.60W 6019469.96 N 550105.99 E 4250.10 4816.65 N 1861.94W 6019545.87 N 550077.13 E 4260.10 4832.88 N 1867.98W 6019562.06 N 550070.97 E Dogleg Rate (°/100ft) 5.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 o.oo0 0.0o0 0.000 0.000 o.000 0.0oo o.ooo 0.0oo 0.000 0.0oo o.ooo o.ooo Alaska State Plane Zone 4 Milne Point MPJ Vertical Section (ft) 607.78 753.73 1001.54 1619.55 2485.36 3351.17 3632.29 4039.02 4216.99 4497.67 4580.74 4629.20 4682.86 4727.86 4810.93 4874.97 4937.28 4999.58 5042.85 5082.80 5164.01 5181.32 Comment End Dir: 1831.42ft MD, 1617.59ft TVD Base Permafrost Top Ugnu - TUZC Top Ugnu M -TUZB MPJ INJ Target, 200.00 Radius. SBF2-NA SBF1-NB SBF4-NC SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 5 1/2" Casing Total Depth :7113.79ft MD, 4260.10ft TVD Continued... 1 November, 1999- 10:30 -2 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for MPJ-15 WPS- MPJ-15i Wp4 Revised: 1 November, 1999 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. Magnetic Declination at Surface is 27.187° (04-Aug-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPJ-Test2 and calculated along an Azimuth of 338.868° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7113.79ft., The Bottom Hole Displacement is 5181.32ft., in the Direction of 338.868° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 350.40 350.40 0.00 N 0.00 E 550.40 550.24 5.72 N 4.00 W 783.73 781.43 30.65 N 21.46 W 1033.73 1021.44 87.02 N 60.93 W 1831.42 1617.59 546.46 N 272.01 W 7113.79 4260.10 4832.88 N 1867.98W Comment KOP: Start Dir @ 2.000°/100ft: 350.40ft MD, 350.40ft TVD Dir Rate Increase @ 3.000°/100ft: 550.40ft MD, 550.24ft TVD Dir Rate Increase @ 4.000°/100ft: 783.73ft MD, 781.43ft TVD Dir Rate Increase @ 5.000°/100ft: 1033.73ft MD, 1021.44ft TVD End Dir: 1831.42ft MD, 1617.59ft TVD Total Depth :7113.79ft MD, 4260.10ft TVD Alaska State Plane Zone 4 Milne Point MPJ Continued... I November, 1999 - 10:30 - 3 - DriliQuest 1.05.04c ~Unit Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 2286.22 1845.10 1780.00 5324.68 3365.10 3300,00 5794,45 3600.10 3535.00 6420.13 3913.10 3848.00 6476.10 3941.10 3876.00 6538,07 3972.10 3907.00 6590,05 3998.10 3933.00 6686.00 4046.10 3981.00 6759.96 4083.10 4018.00 6831.92 4119.10 4054.00 6903.89 4155.10 4090,00 6953.86 4180.10 4115.00 Sperry-Sun Drilling Services Proposal Report for MPJ-15 WPS- MPJ-15i Wp4 Revised: 1 November, 1999 Northings Eastings Formation Name (ft) (ft) 915.51 N 409.42 W Base Permafrost 3381.10 N 1327.43 W Top Ugnu - TUZC 3762.29 N 1469.36 VV Top Ugnu M - TUZB 4270.01 N 1658.40 W SBF2-NA 4315,43 N 1675.31 W SBF1-NB 4365.71 N 1694.04 W SBF4-NC 4407.89 N 1709,74 W SBE2-NE 4485.75 N 1738.73 W SBE1-NF 4545.76 N 1761,07 W TSBD-O^ 4604,16 N 1782.82 W TSBC 4662.55 N 1804.56 W TSBB-OB 4703.11 N 1819.66 W SBA5 Alaska State Plane Zone 4 Milne Point MPJ Continued... I November, 1999 - 10:30 - 4 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for MPJ-15 WPS- MPJ-15i Wp4 Revised: 1 November, 1999 P'~j/ll~~ Unit Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> To Measured Depth (ft) 7093.79 Targets associated with this wellpath Target Name MPJ INJ Target MPJ INJ TD Vertical Depth (ft) 4250.10 Casing Detail 5 1/2" Casing Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Alaska State Plane Zone 4 Milne Point MPJ Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3865.10 4192.15 N 1629.41 W 3800.00 6018923.00 N 550314.00 E 70° 27' 44.8941" N 149° 35' 21.3327" W 4250.10 4824.64 N 1842.01 W 4185.00 6019554.00 N 550097,00 E 70° 27' 51.1147" N 149° 35' 27.5851" W Target Shape Circle Point Target Type 1 November, 1999 - 10:30 - 5 - DrillQuest 1.05.04c VENDOR ALABKAST14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT ~ I027cF? CKIO~7C?c~ 100. O0 100. O0 HANDLING INST: S/H TERRIE HUBBLl: X4628 C.ECK m m ~,^vm~rr ~ ~ ~scnmm~ ^mo~ ~m~ 100. oo 100_ oo 4E ATTACHED ::.,BP.EXPLORATION (ALASKA).,i.:I~ /,:.,~,,,.......,-,-::'' m' m m :a' ~)m"~[."AN ~ ~F AS "~N ~No..'.H i.' "' :-'~ :?-':::~:::':'C 'f.":::.:i~ .':.!-i- .~:~,'Fm~ATE O~ '.:.i ..... '. ' .......................~"" ,. PAY ONE :'"HUNDREDi:i:-::i& ':O0:Z 1 *********************************************** US:DOLLAR ALASKA STATE.!:.DE~T.i>:iOF-: REVENUE AK ~9501-3120 ANCHORAGE FIELD & POOL _~"-'2.~.~"~'"'//~'~z"~_) INIT CLASS )f/,gJj,'~,,A//,J~ GEOL AREA ADMINISTRATION 1 A..,,~2~ DATE ..,, ~- d." i~ .~ z' ~? · Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells.-,''~ ........ 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without, conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17· 18. 19. 20. 21. 22. 23. 24. 25. t 28. 29. GEOLOGY 30. 31. 32. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~ ~q.~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Permit can be issued w/o hydrogen sulfide measures ..... Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. redrll serv ¢//"'"wellbore seg __ UNIT# ann. disposal para req __ ON/OFF SHORE (L~/¢/ N N N Y R DATE 33. · /Z/--~'~¢/-~/~ 34. ANNULAR DISPOSAL 35. APPR DATE Seabed condition survey (if off-shore) ............. Y N Contact name/phone for weekly progress reports [exploratory onl)~_~ N With proper cementing records, this plan Y N (A) will contain waste in a~ .... (B) will not contam~ cause drilling wa~ Y N to surface; ~ (C) will not i~¢r~~l used for disposal; (D) will n/ot~amage producing formation or impair recovery from a Y po..~, and -"~-~._..~~ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412· Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: RP .... BEW ~ WM ~ ~,~ /I DWJ ~-' SFD~'~' JDH ,,,._.. - ~"'1,~-~:;~/', coRNC-'"'~---;--~-m - T E rvl~,' .,~ _';;~. / ~.G_ ~c.t . ._ _c_._._._._._._.~. _. _ ]_- ~__ .... Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09~27~99) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi 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 $ Tue Jan 18 17:02:50 2000 Reel Header Service name ............. LISTPE Date ..................... 00/01/18 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 ..................... 00/01/18 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: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW-90186 E. CRIBBS D. WESTER RECEIVED 20 2000 MPJ-15i 500292295200 BP Exploration (Alaska) Inc. Sperry Sun 18-JAN-00 MWD RUN 2 AK-MW-90186 B. HENNINGSE D. WESTER 13N 10E 2344 3347 65.12 65.12 35.10 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.880 13.375 3639.0 7.880 7146.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD DIGITAL DATA AND LOG DATA IS DEPTH CORRECTED TO THE PDC GR OF 11-19-99 SCHLUMBERGER USIT GR) with KBE = 65.95'A.M.S.L. LOG HEADER DATA RETAINS ORIGINAL DRILLER'S DEPTHS. 5. MWD RUNS 1-2 REPRESENT WELL MPJ-15 WITH API#: 50-029-22952-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7145'MD, 4280'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/01/19 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 SGRC 51.5 SFXE 52.0 SEDP 52.0 STOP DEPTH 7107.0 7114.0 7114.0 SEMP 52.0 SESP 52.0 SEXP 52.0 SROP 85.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 51 5 5279 5 5285 0 5292 0 5302 0 5312 5 5317 0 5324 5 5332 0 5345 5 5355 0 5362 5 5386 5 5390 0 5393 0 5411 0 5420 0 5428 5 5461 0 5469 5 5481.0 5499.5 5518.0 5521 5 5527 5 5542 0 5561 0 5566 0 5603 5 5614 0 5630 5 5633 0 5637.0 5661 5 5678 5 5705 0 5709 0 5715 5 5746 0 5751 0 5759 5 5773 0 5781 5 5792 5 5821 0 5833 0 5853 0 5865 5 5873 0 5877 5 5902 5 GR 5O 5278 5285 5291 5301 5311 5316 5324 5330 5344 5354 5361 5384 5388 5391 5409 5418 5426 5459 5467 5480 5499 5517 5520 5525 5540 5556 5562 5599 5609 5626 5628 5632 5656 5676 5702 5705 5712 5743 5747 5756 5771 5778 5790 5819 5832 5853 5863 5870. 5873. 5898. 0 0 5 5 5 0 5 0 5 0 5 0 5 5 0 0 0 0 5 5 5 0 5 5 5 5 5 0 0 5 0 5 5 5 0 0 0 5 0 0 0 0 0 5 0 0 5 5 0 5 5 7114.0 7114.0 7114.0 7148.0 EQUIVALENT UNSHIFTED DEPTH 5915 5925 5939 5968 5973 5985 6018 6032 6043 6048 6103 6106 6119 6130 6140 6149 6174 6189 6196 6215 6223 6238 6252 6260 6272 6296 6343 6348 6356 6377 6397 6418 6433 6444 6469 6496 6533 6545 6557 6589 6607 6660 6673 6681 6697 6707 6710 6716 6748 6775 6782 6790 6824 6833 6845 6878 6892 6896 6903 6912 6918 5910 5 5919 0 5933 0 5964 5 5970 5 5981 5 6014.5 6028 5 6039 0 6045 0 6099 0 6102 5 6115 0 6127 5 6138 0 6148 0 6173 0 6185 5 6194 0 6211 0 6219 0 6235 0 6250 0 6256 5 6269 5 6291 5 6341 5 634 6 5 6356 0 6374 0 6393 0 6417 5 6432 0 6444 0 6467 0 6494 5 6532 0 6545 5 6556 5 6590 0 6609 5 6659 5 6673 5 6679 5 6695 5 6706 0 6708 0 6714 5 6746 0 6772.5 6778.5 6787.5 6822 0 6832 0 6842 0 6875 5 6888 5 6891 5 6901 0 6909 0 6915 0 6927.0 6923.5 6932.5 6929.0 6934.0 6931.0 7148.0 7144.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 100 MWD 200 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 50.0 3598.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 3639.0 7144.5 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 51.5 7148 ROP MWD FT/H 0 1805.91 GR MWD API 7.12 134.16 RPX MWD OHMM 0.17 2000 RPS MWD OHMM 0.16 2000 RPM MWD OHMM 0.21 2000 RPD MWD OHMM 0.24 2000 FET MWD HOUR 0.13 12.09 Mean Nsam 3599.75 14194 173.609 13888 66.2048 14112 23.6055 14125 31.7716 14125 44.6367 14125 55.2439 14125 0.675557 14125 First Reading 51.5 85.5 51.5 52 52 52 52 52 Last Reading 7148 7148 7107 7114 7114 7114 7114 7114 First Reading For Entire File .......... 51.5 Last Reading For Entire File ........... 7148 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/01/18 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 ....... 00/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC SEXP SFXE SEDP SESP SEMP SROP $ 5O 0 5O 5 5O 5 50 5 5O 5 50 5 84 0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): STOP DEPTH 3596 5 3603 5 3603 5 3603 5 3603 5 3603 5 3639 0 12-NOV-99 Insite 0.41 Memory 3638.0 .4 62.6 TOOL NUMBER P1349GRV4 7.880 110.0 Water Based 9.30 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 87.0 8.2 4OO 4.6 3.800 3.140 3.500 2.100' Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 API 4 1 68 8 3 RPX MWD 1 OHMM 4 1 68 12 4 RPS MWD 1 OHMM 4 1 68 16 5 RPM MWD 1 OHMM 4 1 68 20 6 RPD MWD 1 OHMM 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 69.0 85.0 69.0 69.0 Name Service Unit DEPT FT ROP MWD 1 FT/H GR MWD 1 API RPX MWD 1 OHMM RPS MWD 1 OHMM RPM MWD 1 OHMM RPD MWD 1 OHMM FET MWD 1 HOUR Min 5O 28 95 15 33 0 17 0 16 0 21 0 24 0 14 First Max Mean Nsam Reading 3639 1844.5 7179 50 1805.91 163.955 6873 84 128.93 62.742 7094 50 2000 38.2914 7107 50.5 2000 53.9127 7107 50.5 2000 79.2855 7107 50.5 2000 100.497 7107 50.5 3.27 0.406026 7107 50.5 Last Reading 3639 3639 3596 5 3603 5 3603 5 3603 5 3603 5 3603 5 First Reading For Entire File .......... 50 Last Reading For Entire File ........... 3639 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC SEDP SEMP SESP SEXP SFXE SROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 3598.0 3604 0 3604 0 3604 0 3604 0 3604 0 3639 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 7110 7110 7144 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ STOP DEPTH 7103 5 7110 5 7110 5 7110 5 5 5 5 15-NOV-99 Insite 0.41 Memory 7145.0 57.2 62.2 TOOL NUMBER P1349GRV4 P1349GRV4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY {HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 7.880 Water Based 9.50 65.0 8.9 400 3.4 2.350 1.800 2.200 2.400 76.0 101.0 76.0 76.0 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 API RPX MWD 2 OHMM RPS MWD 2 OHMM RPM MWD 2 OHMM RPD MWD 2 OHMM Min Max Mean Nsam 3598 7144.5 5371.25 7094 0 645.62 183.057 7011 7.12 134.16 69.6127 7012 1.62 81.64 8.74514 7014 1.6 109.99 9.36866 7014 1.59 140.61 9.56995 7014 1.52 85.46 9.43497 7014 First Reading 3598 3639.5 3598 3604 3604 3604 3604 Last Reading 7144 5 7144 5 7103 5 7110 5 7110 5 7110 5 7110 5 FET MWD 2 HOUR 0.13 11.45 0.817465 7014 3604 7110.5 First Reading For Entire File .......... 3598 Last Reading For Entire File ........... 7144.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/01/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/01/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
