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Home My WebLink About204-064Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/27/2025 InspectNo:susGDC250903202158 Well Pressures (psi): Date Inspected:9/2/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:4/5/2022 #322-038 Tubing:0 IA:0 OA:20 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:8/31/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT J-26 Permit Number:2040640 Wellhead Condition Wellhead was in good condition. The wing valve was blinded off and is not connected to the flowlines. There is a wellhouse in place protecting the well from the elements. Surrounding Surface Condition Good clean gravel pad with no signs of hydrocarbons. Condition of Cellar Dry with some trash. Comments Well location verified by well-site pad map Supervisor Comments Photos (10) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, October 27, 2025            2025-0902_Suspend_MPU_J-26_photos_gc Page 1 of 5 Suspended Well Inspection – MPU J-26 PTD 2040640 AOGCC Inspection Rpt # sus250903202158 Photos by AOGCC Inspector G. Cook 9/2/2025 2025-0902_Suspend_MPU_J-26_photos_gc Page 2 of 5 Wellhouse Backside Valve Tree 2025-0902_Suspend_MPU_J-26_photos_gc Page 3 of 5 Tree Cap Pressure Gauge (Tbg Pressure) IA Pressure Gauge 2025-0902_Suspend_MPU_J-26_photos_gc Page 4 of 5 OA Pressure Gauge Power Fluid Piping 2025-0902_Suspend_MPU_J-26_photos_gc Page 5 of 5 Tree Wing Outlet Blinded Well Cellar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Suprv Comm ________ JBR 12/29/2022 InspectNo:susRCN221110104014 Well Pressures (psi): Date Inspected:11/5/2022 Inspector:Bob Noble If Verified, How?Other (specify in comments) Suspension Date:4/5/2022 #322-038 Tubing:0 IA:50 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Billy Kruskie Date AOGCC Notified:11/4/2022 Type of Inspection:Initial Well Name:MILNE PT UNIT J-26 Permit Number:2040640 Wellhead Condition Good well with no signs of leaks or drips. Flowlines have been removed and lines have been blinded with good gauges. SSV had to be pumped open to get tubing pressure. Surrounding Surface Condition Well had a wellhouse protecting it. Condition of Cellar Cellar had clean water in it. Comments Location verfied with pad map. Supervisor Comments Photos (2) attached. Multi-larteral; Suspension also affects MPU J-26L1 (PTD 2040660; Sundry 322-039) and MPU J-26L2 (PTD 2040670; Sundry 322-040) Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Thursday, December 29, 2022 Photos (2) attached. Multi-larteral; Suspension also affects MPU J-26L1 (PTD 2040660; Sundry 322-039) and MPU J-26L2 2022-1105_Suspend_MPU_J-26_photos.docxPage 1 of 1 Suspended Well Inspection – MPU J-26AOGCC Inspect # susRCN221110104014PTD 2040640Photos by AOGCC Inspector B. Noble Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-26 (PTD 204-064) COILFLAG 03/30/2022 Please include current contact information if different from above. PTD:204-064 T36626 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.18 09:52:03 -08'00' 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: _3 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 34.9'' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 20" H-40 112 10-3/4" L-80 2624 7-5/8" L-80 3895 4-1/2" L-80 3850 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Gas-Oil Ratio:Choke Size: Flow Tubing Water-Bbl: PRODUCTION TEST Date of Test: Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information 29.7 8760 33 4046 92 45.5 112 33 6405 WT. PER FT.GRADE 12.6 547609 546508 TOP SETTING DEPTH MD 34 5695 34 13-1/2" 260 sx Arctic Set (approx.) 35 417 sx PF 'L', 258 sx Class 'G' 1,800' (approx.) SETTING DEPTH TVD 6015735 TOP ADL0025517, ADL0025906 HOLE SIZE AMOUNT PULLED suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 552055 CASING 50-029-23205-00-00 Milne Point J-262157' FSL, 3267' FEL, SEC. 28, T13N, R10E UM N/A 5/20/2004 68.7' 3373' FSL, 3523' FEL, SEC. 29, T13N, R10E UM (NB) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG N/A Milne Point / Schrader Bluff Oil Gas 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 4/5/2022 5/11/2004 8,760' MD / 3,850' TVD 5,089' MD / 3,905' TVD 6014554 1839' FSL, 2437' FEL, SEC. 29, T13N, R10E UM (NB) 6014208 N/A 42" BOTTOM 35 3105 CEMENTING RECORD 5,075' MD / 3,899' TVD 5,240'4-1/2" SIZE DEPTH SET (MD) 5,022' MD / 3,876' TVD PACKER SET (MD/TVD) 278 sx Class 'G'9-7/8" 204-064 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, Sand screen liner6-3/4" TUBING RECORD Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment xG / 322-038 By Meredith Guhl at 2:06 pm, Apr 28, 2022 Suspended 4/5/2022 MDG RBDMS 4/28/2022 MDG DSR-4/28/22MGR24AUG2022SFD 8/9/2022 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1,800' 1,654' 6,716' 3,837' Schrader Bluff Schrader Bluff 31. List of Attachments: Wellbore schematic and daily operations reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. David Haakinson Contact Name:Darci Horner Operations Manager Contact Email:dhorner@hilcorp.com Authorized Contact Phone:907-777-8406 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Top of Productive Interval If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): 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: 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. 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. 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: See Attachment 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.04.28 12:41:59 -08'00' David Haakinson (3533) 29. GEOLOGIC MARKERS (List all formations and markers encountered): SBF1-NB 4,936' 3,840' SBF12 4,984' 3,860' SBE4 - NC 5,003' 3,868' SBE41 5,017' 3,874' SBE3-ND 5,027' 3,879' SBE2 - NE 5,049' 3,888' SBE1 - NF 5,161' 3,934' TSBD-OA 5,270' 3,968' TSBC 5,400' 3,997' TSBB-OB 5,554' 4,027' TSBB-OB 5,993' 4,018' TSBC 6,122' 3,985' TSBD-OA 6,238' 3,948' SBE1-NF 6,349' 3,913' SBE2-NE 6,538' 3,859' SBE3-ND 6,559' 3,855' SBE41 6,586' 3,851' SBE4-NC 6,612' 3,847' SBF12 6,637' 3,844' SBF1-NB 6,716' 3,837' SBF1-NB 6,855' 3,835' SBE4-NC 7,583' 3,834' SBF12 7,798' 3,823' _____________________________________________________________________________________ Revised By: DH 4/7/2022 SCHEMATIC Milne Point Unit Well: MPU J-26 Last Completed: 10/10/2019 PTD: 204-064 22 Cleanout NB lateral to 8,719’ CTM 10/4/2018 Tagged PBTD TD =8,760’ (MD) / TD = 3,850’(TVD) 20” TOC @ 5,089’ 7-5/8” ISO Sleeve across OB lateral Min ID: 2.57” 18 19 10-3/4” 13 202” Perfs in ISO Sleeve 5,562’-5,566’ Northern Solutions 4-1/2” cement retainer @ 5,520’ “OB” Lateral PBTD =5,354’(MD)/ PBTD =3,988’(TVD) Quadco 4-1/2” cast iron cement retainer @ 5,220’ “NB” Lateral 13 14 18 19 “ 9 7 6 1 Orig. KB Elev.: 68.7’/ Orig. GL Elev.: 34.9’ RKB – Hanger: 30.27’ (Doyon 14) 13 “OA” Lateral cemented 4-4-2022 10 11 12 15 16 17 21 3 2 8 Min ID = 3.688” 4 5 Min ID = 3.688” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 3,105’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 6,405' 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 5,265’ 8,513’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 5,553’ 8,635’ 4” Liner “C” 9.5 / L-80 / IBT 3.548 5,695’ 8,760’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958 Surface 5,051’ 4-1/2” Tubing 12.6 / L-80 / TC-II 3.958 5,051’ 5,240’ LINER DETAIL 4-1/2” ‘OA’ Liner 12.6 / L-80 / IBT 3.958 5,259’ 8,513’ 4-1/2” ‘OB’ Liner 12.6 / L-80 / IBT 3.958 5,553’ 8,635’ 4” ‘NB’ Liner 9.35# / L-80 IBT 3.548 5,682’ 8,760’ JEWELRY DETAIL No Depth Item (All depths to Orig RKB) 1 4,974’ 4-1/2” XD Sliding Sleeve 12.6# 9Cr ***Set 8A JP on 8/29/21** 2 4,991’ 4.5" SGM, Tbg Porte, 12.6# TCII 3 5,022’ 7-5/8” x 4-1/2” Baker Premier Production Packer 4 5,036’ 4-1/2” XN Profile (3.725” Packing Bore ID) 5 5,043’ Overshot – Bottom @ 5,051’ 6 5,075’ 7-5/8” x 4-1/2” HES TNT Packer 7 5,115’ 4-1/2” X Profile (3.813” Packing Bore ID) 8 5,187’ 4-1/2” XN Profile (3.725” No-Go ID) 9 5,239’ Wireline Entry Guide (Btm at 5,240’) 10 5,228’ OA Lateral Tie Back Sleeve 11 5,239’ OA Lateral ZXP Liner Top Packer 12 5,255’ OA Lateral LEM #2 (Lateral Entry Module) –MIN ID = 3.688” 13 5,265’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 14 5,288’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 15 5,501’ OB Lateral Tie Back Sleeve 16 5,512’ OB Lateral ZXP Liner Top Packer 17 5,543’ OB Lateral LEM #1 (Lateral Entry Module) -MIN ID = 3.688” 18 5,553’ OB Lateral Hook Wall, Hanger above 7-5/8” Window 19 5,576’ OB Lateral Hook Wall, Hanger below 7-5/8” Window 20 5,695’ NB Lateral ZXP Liner Top Packer 21 5,717’ NB Lateral 7-5/8” x 5-1/2” Flex-Lock Liner Hanger 22 8,717’ NB Lateral 4-1/2” Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 497 sx PF “L”, 261 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 278 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 300’ MD Max Wellbore Angle = 74.0 deg @ 3,735’ MD 65 deg @ 4,960’ MD (Sliding Sleeve & Jet Pump) WELLHEAD Wellhead FMC Tubing Hanger, 11” x 4-1/2” TC-II Top & Bottom GENERAL WELL INFO API: 50-029-23205-00-00 Drilled and Completed by Doyon 14 – 5/31/2004 Convert to Jet Pump by Doyon 16 – 2/25/2014 R&R Jet Pump and Coil Cleanout – 10/4/2018 Tubing Cut/ Upper Completion By ASR1– 10/10/2019 Abandon “NB” lateral by CTU – 8/21/2020 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,270’ MD; Bottom @ 5,282’ MD; Angle @ top of window 75 deg Top of “OB” Window @ 5,558’ MD; Bottom @ 5,570’ MD; Angle @ top of window 78 deg Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 CTU #9 50-029-23205-00-00 204-064 3/30/2022 4/5/2022 4/1/2022 - Friday CTU#9 2" Coil Job Objective: P&A. POOH with perf gun. Lay down perf gun. Make up and RIH with BOT 3.60" drift BHA. Tagged hard at 5260 and could not work/jet past. POOH for motor and mill. MU & RIH with 3-1/8' milling assembly w/ 3.64" Junk mill. Tagged down at 5258'/5255' up. Milled something hard from 5255.9-5557.8'. Suspected we may be milling at the base of the window. PUH. Dry drift and made it by and tagged top of ISO sleeve at 5533' ctm. PUH and encountered several tights spots. Became detained at 5321' but able to get free. Backreamed past LEM#2 and appears we left what was above us at the LEM. Freeze protected coil. Pop of well and inspect mill. The Opticut buttons were worn with some chipped off. There was a gouge in the water course and on the opticut of the backreamer and was undersized to 3.60". Perform weekly BOP test to 250/4000psi. 3/30/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Rig down off of MPJ-09. Move in/rig up on MPU J-26. Make up BOT MHA and HES 2.200” GR/CCL carrier with 2.300” JSN. Discover the tree is frozen. Thawed out and RIH with drift/log BHA. Tagged high at 5380CTM. Jetting on obstruction now. 3/31/2022 - Thursday CTU#9 2" Coil Job Objective: P&A. RIH with HES 2.200" GR/CCL and 2.300" JSN. Tag fiill at 5380' ctm. Fluff and stuff fill w/ slick 1% KCL into upper lateral. Tagged hard bottom at 5566'. Dry drift from 4200' to 5566'. Log from compression at 5566' to 4700'. Flag coil at 5450'. Pooh. Log shows a +5.75' correction. Run in hole with 2" HES millenium perf gun, 6spf, 60degree phased, 4' loaded. Perforate middle of OB window and iso-sleeve at 5562-5566. POOH. CTU#9 2" Coil Job Objective: P&A. Complete weekly BOP test to 250/4000psi. RIH with BOT 3.65" Venturi/Burnshoe BHA. Venturi from 5150' to top of ISO sleeve at 5532'. PUH above upper LEM. Dry drift from 5150' to 5532'. Pooh. Recovered metal debris/shavings. MU & RIH with same BHA. Cleaned up section between LEMs and got a successful dry drift. POOH and minimal metal shavings in venturi filter screen. Make up and RIH with Northern Solutions 1-trip cement retainer. Set at 5502. Got an immediate pressure response on the WHP when the retainer was set. Begin troubleshooting. 4/2/2022 - Saturday 4/3/2022 - Sunday CTU #9 2" Coil Job Objective: P&A. Continue trouble shooting cement retainer set at 5502. Tried various methods of getting stung in to no avail. POOH to check tools. Tools all normal. All indications are that we were stung in during/after the initial set. Discuss options with OE, decison to abort the P&A on the OB lateral and proceed with the P&A on the OA lateral. Make up and RIH with BOT type 2 LEM diverter. Set the diverter at 5265' . Pump off and pooh. MU 2.25" nzl BHA. RIH and unable to enter the window. Pooh. MU Baker Hipp Tripper with GS spear. Set down on diverter and engage HT. Diverter fell through LEM. Retrieved the diverter on top of the cement retainer. Reset diverter at 5245'. ctm. Pooh. RIH with 2.25" nozzle BHA. Tagged right at window and could not jet and make forward progress. Appears as though diverter sleeve is not oriented. RIH with 4" GS to pull diverter. Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 CTU #9 50-029-23205-00-00 204-064 3/30/2022 4/5/2022 Hilcorp Alaska, LLC Weekly Operations Summary CTU#9 2" Coil Job Objective: P&A. Make up drift/tag BHA. WOC for compressive strength and AOGCC witnessed tag and test. AOGCC Rep (Lou Laubenstein) witness tag TOC at 5089'. Target TOC = 5100'. MIT T PASSED to 1864 psi. Pressured tbg to 1950 psi. Lost 76/10 for a total loss of of 86 psi in 30 mins. Pooh pumping pipe displacement. RDMOL. Job Complete. CTU #9 2" Coil Job Objective: P&A. Continue OOH with diverter. Paint tie in flag for retainer set. OOH with diverter and find metal marks going down the tray of the diverter. Appears to be an orientation/alignment issue with the LEM. Make up and RIH with 4.5" Quadco cement retainer BHA. RIH to flag, correct depth and set cement retainer. Establish an injection rate of 1.0 bpm at 1100 psi. 1.5 bpm at 20000 psi. Cementers rigged up an pt's lines to 4500 psi. Pump 105 bbls of 15.8ppg class G cement when backside pressure increasing (58 bbls behind pipe). Open choke and verified flow to surface. Unsting and start reversing. Lay in ~12 bbls of cement making cement top at ~4400'. Pooh. RIH and freeze protect well. Standby for compressive strength and AOGCC witnessed tag. 4/5/2022 - Tuesday 4/4/2022 - Monday Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040640 Type Inj N Tubing 0 1950 1874 1864 Type Test P Packer TVD 3876 BBL Pump 1.6 IA 175 175 176 176 Interval O Test psi 1500 BBL Return OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj N Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska, LLC Milne Point / MPU / J Pad Lou Laubenstein Mark Spiller 04/05/22 Notes:AOGCC MIT-TBG for P&A according to Sundries 322-038, 322-039, and 322-040. Notes: Notes: Notes: J-26 Form 10-426 (Revised 01/2017)MIT-T MPU J-26 04-05-2022 for P&A CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220315 1449 APPROVAL to revise Sundry 322-038 MPU J-26 (PTD#: 204-064) Remove proposed CMT Date:Tuesday, March 15, 2022 2:52:50 PM David, Hilcorp is approved to remove step 6 on approved sundry 322-038. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: David Gorm <dgorm@hilcorp.com> Sent: Tuesday, March 15, 2022 2:40 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MP J-26 (PTD#: 204-064) Remove proposed CMT Mel, In our approved sundry for MP J-26 we had proposed spotting cement on top of our planned cement retainer between the two laterals. Requesting approval to remove Step #6 adding 2 bbls cement on top of the cement retainer set at 5,470’ MD in sundry # 322-038. The planned cement work above in the upper lateral will provide the required zonal isolation of the Schrader. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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ƉƌĞƐƐƵƌĞĨŽƌŝŶũĞĐƚŝŽŶϴϬϬƉƐŝͿŝŶƚŽƚŚĞKůĂƚĞƌĂů͕ƚŚĞŶƌĞǀŝĞǁƚŚĞƌĂƚĞĂŶĚƉƌĞƐƐƵƌĞǁŝƚŚƚŚĞ KƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ͘ Ă͘ /ĨŝŶũĞĐƚŝŽŶƌĂƚĞƐĂƌĞĂƉƉƌŽǀĞĚďǇƚŚĞŽƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ͕DŝǆĂŶĚďƵůůŚĞĂĚϰϲ>^ŽĨϭϱ͘ϴ WW'ůĂƐƐ'ĞŵĞŶƚŝŶƚŽƚŚĞK>ĂƚĞƌĂů͘ ď͘ /ĨŶŽŽƌůŝŵŝƚĞĚŝŶũĞĐƚŝŽŶƌĂƚĞĐĂŶďĞŽďƚĂŝŶĞĚĂĨƚĞƌƌĞǀŝĞǁǁŝƚŚŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌ͕ƐƚŝŶŐŽƵƚ ŽĨƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌ͕ĂŶĚŵŽǀĞƚŽƚŚĞŶĞǆƚƐƚĞƉ͘ ϲ͘ ^ƚŝŶŐŽƵƚĂŶĚƐƉŽƚϮ>ƐŽĨϭϱ͘ϴůĂƐƐ'ĐĞŵĞŶƚĨƌŽŵƚŚĞDdƌĞƚĂŝŶĞƌƚŽϱ͕ϯϱϬ͛D͘ ϳ͘ Wh,ƚŽϱ͕ϯϬϬ͛DĂŶĚƉƵŵƉϭϬϬ>ŽĨϭй<ůŝŶƚŽƚŚĞKůĂƚĞƌĂůƚŽĐŽŶƚĂŵŝŶĂƚĞĂŶǇƌĞƐŝĚƵĂůDd ĨƌŽŵƚŚĞůŽǁĞƌƉůƵŐƐĞƚ͕WKK,͘ ϴ͘ WhĂŶĚZ/,ǁͬϮ͟dǁͬ>DŬŝĐŬŽƵƚƚŽŽů͘^ĞƚƚŚĞ>D<ŝĐŬŽƵƚŝŶƚŚĞƵƉƉĞƌK>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞ ;>DͿ͘ ϵ͘ WKK,ĂŶĚDh:^EĂŶĚĐůĞĂŶŽƵƚ,͕Z/,ĐůĞĂŶŽƵƚƚŚĞK>ĂƚƚŽWdĂƚнͬͲϴ͕ϱϭϯ͛D͘WKK,͘ ;ZĞǀŝĞǁ,K͛ƐĂŶĚǁĞůůďŽƌĞ/͛ƐǁŝƚŚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌͿ͘ Ă͘ ŝƌĐƵůĂƚĞŽƵƚĨŝůůƵƐŝŶŐϭй<ůǁͬĨƌŝĐƚŝŽŶƌĞĚƵĐĞƌ͘WƵŵƉϱͲϭϬďďů'Ğů^ǁĞĞƉƐƚŽŚĞůƉƌĞŵŽǀĞ ƐŽůŝĚƐĨƌŽŵƚŚĞůŝŶĞƌ͘ ď͘ŽŶƚŝŶŐĞŶĐǇ͗/ĨƵŶĂďůĞƚŽĐŝƌĐƵůĂƚĞĨůƵŝĚƚŽƐƵƌĨĂĐĞǁŝƚŚŽƵƚƐŝŐŶŝĨŝĐĂŶƚůŽƐƐĞƐ;фϱϬйƌĞƚƵƌŶƐŽƌ ůŝƚƚůĞƚŽŶŽƐŽůŝĚƐĐŝƌĐƵůĂƚĞĚƚŽƐƵƌĨĂĐĞͿ͘ŝƌĐƵůĂƚĞŽƵƚĨŝůůƵƐŝŶŐϴ͘ϱƉƉŐϭй<ůǁͬůŝƋƵŝĚĨŽĂŵĞƌ ĂŶĚŵŝǆǁŝƚŚEŝƚƌŽŐĞŶ;ƐĞĞEŝƚƌŽŐĞŶƉƌŽĐĞĚƵƌĞĂŶĚĚŝĂŐƌĂŵͿ͘ ϭϬ͘ WKK,ƚŽWhƚŚĞDd,͘ ϭϭ͘ DhďĂůůĚƌŽƉĐĞŵĞŶƚŝŶŐŶŽǌǌůĞĂŶĚZ/,ƚŽϴ͕ϱϭϯ͛ŽƌĚĞĞƉĞƐƚĚĞƉƚŚƌĞĂĐŚĞĚĚƵƌŝŶŐ&K͘ Ă͘ ŽŶƚŝŶŐĞŶĐǇ͗/ĨƵŶĂďůĞƚŽĂĐĐĞƐƐƚŚĞƵƉƉĞƌůĂƚĞƌĂůƚŽůĂǇĐĞŵĞŶƚ͕WƵůůƚŚĞ<ŝĐŬŽƵƚdŽŽů͕WhĂϰͲ ϭͬϮ͟DdƌĞƚĂŝŶĞƌĂŶĚƐĞƚĂƚϱ͕ϮϬϬ͛D͕ƐƚĂďůŝƐŚ/ŶũĞĐƚŝŽŶZĂƚĞ;ŵĂǆŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞϴϬϬ ƉƐŝͿ͕ƌĞǀŝĞǁǁŝƚŚƚŚĞŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌƉůĂŶƚŽďƵůůŚĞĂĚϱϬ>Ɛϭϱ͘ϴƉƉŐůĂƐƐ'ĞŵĞŶƚ ďĞůŽǁƚŚĞƌĞƚĂŝŶĞƌ͘ ď͘^ƉŽƚϭϱ͘ϴƉƉŐůĂƐƐ'ĐĞŵĞŶƚƵƉƚŽϱ͕ϭϬϬ͛DŽŶƚŽƉŽĨƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌ͘ŝƌĐƵůĂƚĞƚŚĞĐŽŝů ĐůĞĂŶ͕ĐŽŶƚĂŵŝŶĂƚĞĂŶĚƐƉŽƚĨƌĞĞǌĞƉƌŽƚĞĐƚŽŶƚŚĞdKK,͘;^ŬŝƉƐƚĞƉƐϭϯͲϭϳŝĨƌĞƚĂŝŶĞƌƵƐĞĚĨŽƌ ƵƉƉĞƌůĂƚĞƌĂůͿ͘ ZĞƐĞƌǀŽŝƌ^ƵƐƉĞŶƐŝŽŶ tĞůů͗DW:ͲϮϲ ĂƚĞ͗ϬϭͬϬϳͬϮϬϮϮ ϭϮ͘ DŝǆĂŶĚƉƵŵƉϱϱďďůƐŽĨϭϱ͘ϴƉƉŐůĂƐƐ'ĐĞŵĞŶƚĚŽǁŶƚŚĞĐŽŝůƚƵďŝŶŐƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞϰͲϭͬϮ͟ ƚƵďŝŶŐ;ůŝŵŝƚĞĚƚŽŶŽƌĞƚƵƌŶƐŵĂǇďĞŽďƐĞƌǀĞĚͿ͘hƐĞĨƌĞƐŚǁĂƚĞƌƐƉĂĐĞƌƐĂƐŶĞĞĚĞĚĂƌŽƵŶĚƚŚĞĐĞŵĞŶƚ͘ Ă͘ŽŶƚĂĐƚŶŐŝŶĞĞƌĂŶĚĂĚũƵƐƚǀŽůƵŵĞďĂƐĞĚŽŶĨŝŶĂůĐůĞĂŶŽƵƚĚĞƉƚŚƌĞĂĐŚĞĚ ď͘ ϰͲϭͬϮ͟ůŝŶĞƌǀŽů͗Ϭ͘ϬϭϱϮϭǆ;ϴ͕ϱϭϯ͛ʹϱ͕ϭϬϬ͛ͿсΕϱϮďďůƐ Đ͘ ϯďďůƐŽĨƐƉĂƌĞǀŽůƵŵĞƚŽƐƋƵĞĞǌĞĂǁĂǇŽƌĐŽŶƚĂŵŝŶĂƚĞ͘ ϭϯ͘ ůůŽǁΕϭďďůŽĨĐĞŵĞŶƚĂƌŽƵŶĚƚŚĞĐĞŵĞŶƚŝŶŐŶŽǌǌůĞĂŶĚůĂǇƚŚĞƌĞƐƚŽĨƚŚĞĐĞŵĞŶƚŝŶďĂĐŬƚŽϱ͕ϭϬϬ͛ D͘;EŽƚĞ͗ĞƉĞŶĚŝŶŐŽŶŽƚƚŽŵŚŽůĞƉƌĞƐƐƵƌĞ͕ŵĂǇŶŽƚŚĂǀĞƉƌĞƐƐƵƌĞŽƌƌĞƚƵƌŶƐŽŶƐƵƌĨĂĐĞ͕ƌĞǀŝĞǁ ǁŝƚŚŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌƉƵŵƉŝŶŐĐĞŵĞŶƚĂŶĚƉŽŽŚďĂƐĞĚŽŶǀŽůƵŵĞƐͿ ϭϰ͘ WhϱϬϬ͛ ϭϱ͘ ^ǁĂƉƚŽĐŽŶƚĂŵŝŶĂƚĞĂŶĚZ/,ƚŽϱ͕ϭϬϬ͛D;ƉůĂŶŶĞĚdKͿ͘ ϭϲ͘ ŝƌĐƵůĂƚĞĐŽŝůĐůĞĂŶŽŶƚŚĞƚƌŝƉďĂĐŬŽƵƚŽĨƚŚĞŚŽůĞ͘ Ă͘ &ƌĞĞǌĞƉƌŽƚĞĐƚǁĞůůŽŶǁĂǇŽƵƚŽĨŚŽůĞĂƐŶĞĞĚĞĚ͘ ϭϳ͘ tĂŝƚŽŶĐĞŵĞŶƚƚŽŐĂŝŶĂŵŝŶŝŵƵŵϭ͕ϬϬϬƉƐŝĐŽŵƉƌĞƐƐŝǀĞƐƚƌĞŶŐƚŚ͘ ϭϴ͘ WƌĞƐƐƵƌĞƚĞƐƚƚŚĞĐĞŵĞŶƚƚŽϭ͕ϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ;ĐŚĂƌƚĞĚͿ͘/ĨƚŚĞƉůƵŐƚĞƐƚƐŐŽŽĚ͕d/,ǁŝƚŚŽŝůĂŶĚ ƚĂŐƚŚĞdK͕ƉůĂŶŶĞĚdKΛϱ͕ϭϬϬ͛D͘;ŽŶƚĂĐƚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌǁŝƚŚĨŝŶĂůƚĂŐĚĞƉƚŚ͘Ϳ Ă͘ /ĨƚŚĞƉƌĞƐƐƵƌĞƚĞƐƚŽĨƚŚĞĐĞŵĞŶƚƉůƵŐĨĂŝůƐ͕ĐŽŶƚĂĐƚƚŚĞKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌƚŽĚŝƐĐƵƐƐ ƉƵŵƉŝŶŐĂĚĚŝƚŝŽŶĂůĐĞŵĞŶƚ͘ ď͘ EŽƚŝĨǇK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞƚŽǁŝƚŶĞƐƐ ƚĂŐĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚ͘ ϭϵ͘ WKK,ĨƌĞĞǌĞƉƌŽƚĞĐƚŝŶŐĂƐŶĞĞĚĞĚ͘ ϮϬ͘ ZdƵŶŝƚ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůĞĚdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϰ͘ EŝƚƌŽŐĞŶKƉĞƌĂƚŝŽŶƐWƌŽĐĞĚƵƌĞ ϱ͘ EŝƚƌŽŐĞŶ&ůŽǁŝĂŐƌĂŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗,ϭϮͬϮϳͬϮϬϮϭ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϮϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϬͬϭϬͬϮϬϭϵ Wd͗ϮϬϰͲϬϲϰ ϮϮ ůĞĂŶŽƵƚEůĂƚĞƌĂůƚŽϴ͕ϳϭϵ͛dD ϭϬͬϰͬϮϬϭϴdĂŐŐĞĚWddс ϴ͕ϳϲϬ͛;DͿͬdсϯ͕ϴϱϬ͛;dsͿ ϮϬ´ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ ³2%´/DWHUDO Wdсϱ͕ϯϱϰ͛;DͿ ͬ Wdсϯ͕ϵϴϴ͛;dsͿ ³1%´/DWHUDO KƌŝŐ͘<ůĞǀ͗͘ϲϴ͘ϳ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϰ͘ϵ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϬ͘Ϯϳ͛;ŽǇŽŶϭϰͿ ³2$´/DWHUDO 0LQ,' ´ 0LQ,' ´ dKϱ͕ϯϱϰ͛D ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ ϯ͕ϭϬϱ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdͲDK ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϲ͕ϰϬϱΖ ϰͲϭͬϮ͟ >ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕Ϯϲϱ͛ ϴ͕ϱϭϯ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϱϱϯ͛ ϴ͕ϲϯϱ͛ ϰ͟ >ŝŶĞƌ͟͞ ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϱϰϴ ϱ͕ϲϵϱ͛ ϴ͕ϳϲϬ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdyW ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϱ͕Ϭϱϭ͛ ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdͲ// ϯ͘ϵϱϴ ϱ͕Ϭϱϭ͛ ϱ͕ϮϰϬ͛ >/EZd/> ϰͲϭͬϮ͟ ͚K͛>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕Ϯϱϵ͛ ϴ͕ϱϭϯ͛ ϰͲϭͬϮ͟ ͚K͛>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϱϱϯ͛ ϴ͕ϲϯϱ͛ ϰ͟ ͚E͛>ŝŶĞƌ ϵ͘ϯϱηͬ>ͲϴϬ/d ϯ͘ϱϰϴ ϱ͕ϲϴϮ͛ ϴ͕ϳϲϬ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ;ůůĚĞƉƚŚƐƚŽKƌŝŐZ<Ϳ ϭ ϰ͕ϵϳϰ͛ ϰͲϭͬϮ͟y^ůŝĚŝŶŐ^ůĞĞǀĞϭϮ͘ϲηϵƌ ΎΎΎ^Ğƚϴ:WŽŶϴͬϮϵͬϮϭΎΎ Ϯ ϰ͕ϵϵϭ͛ ϰ͘ϱΗ^'D͕dďŐWŽƌƚĞ͕ϭϮ͘ϲηd// ϯ ϱ͕ϬϮϮ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟ĂŬĞƌWƌĞŵŝĞƌWƌŽĚƵĐƚŝŽŶWĂĐŬĞƌ ϰ ϱ͕Ϭϯϲ͛ ϰͲϭͬϮ͟yEWƌŽĨŝůĞ;ϯ͘ϳϮϱ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϱ ϱ͕Ϭϰϯ͛ KǀĞƌƐŚŽƚʹŽƚƚŽŵΛϱ͕Ϭϱϭ͛ ϲ ϱ͕Ϭϳϱ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟,^dEdWĂĐŬĞƌ ϳ ϱ͕ϭϭϱ͛ ϰͲϭͬϮ͟yWƌŽĨŝůĞ;ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϴ ϱ͕ϭϴϳ͛ ϰͲϭͬϮ͟yEWƌŽĨŝůĞ;ϯ͘ϳϮϱ͟EŽͲ'Ž/Ϳ ϵ ϱ͕Ϯϯϵ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϰϬ͛Ϳ ϭϬ ϱ͕ϮϮϴ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϭ ϱ͕Ϯϯϵ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϮ ϱ͕Ϯϱϱ͛ K>ĂƚĞƌĂů>DηϮ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿʹ D/E/сϯ͘ϲϴϴ͟ ϭϯ ϱ͕Ϯϲϱ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϰ ϱ͕Ϯϴϴ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϭϱ ϱ͕ϱϬϭ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϲ ϱ͕ϱϭϮ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϱ͕ϱϰϯ͛ K>ĂƚĞƌĂů>Dηϭ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿͲ D/E/сϯ͘ϲϴϴ͟ ϭϴ ϱ͕ϱϱϯ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϵ ϱ͕ϱϳϲ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϮϬ ϱ͕ϲϵϱ͛ E>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ Ϯϭ ϱ͕ϳϭϳ͛ E>ĂƚĞƌĂůϳͲϱͬϴ͟ǆϱͲϭͬϮ͟&ůĞǆͲ>ŽĐŬ>ŝŶĞƌ,ĂŶŐĞƌ ϮϮ ϴ͕ϳϭϳ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ŵƚǁͬϰϵϳƐǆW&͞>͕͟ϮϲϭƐǆůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟ ŵƚǁͬϮϳϴƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϯϬϬ͛D DĂǆtĞůůďŽƌĞŶŐůĞсϳϰ͘ϬĚĞŐΛϯ͕ϳϯϱ͛D ϲϱĚĞŐΛϰ͕ϵϲϬ͛D;^ůŝĚŝŶŐ^ůĞĞǀĞΘ:ĞƚWƵŵƉͿ t>>, tĞůůŚĞĂĚ &DdƵďŝŶŐ,ĂŶŐĞƌ͕ϭϭ͟ǆ ϰͲϭͬϮ͟dͲ//dŽƉΘŽƚƚŽŵ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϬϱͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďǇŽǇŽŶϭϰʹϱͬϯϭͬϮϬϬϰ ŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉďǇŽǇŽŶϭϲʹϮͬϮϱͬϮϬϭϰ ZΘZ:ĞƚWƵŵƉĂŶĚŽŝůůĞĂŶŽƵƚʹϭϬͬϰͬϮϬϭϴ dƵďŝŶŐƵƚͬhƉƉĞƌŽŵƉůĞƚŝŽŶǇ^ZϭʹϭϬͬϭϬͬϮϬϭϵ ďĂŶĚŽŶ͞E͟ůĂƚĞƌĂůďǇdhʹϴͬϮϭͬϮϬϮϬ >dZ>t/EKtd/> dŽƉŽĨ͞K͟tŝŶĚŽǁΛϱ͕ϮϳϬ͛D͖ŽƚƚŽŵΛϱ͕ϮϴϮ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϱĚĞŐ dŽƉŽĨ͞K͟tŝŶĚŽǁΛϱ͕ϱϱϴ͛D͖ŽƚƚŽŵΛϱ͕ϱϳϬ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϴĚĞŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭͬϭϬͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϮϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϬͬϭϬͬϮϬϭϵ Wd͗ϮϬϰͲϬϲϰ ϮϮ ůĞĂŶŽƵƚEůĂƚĞƌĂůƚŽϴ͕ϳϭϵ͛dD ϭϬͬϰͬϮϬϭϴdĂŐŐĞĚWddс ϴ͕ϳϲϬ͛;DͿͬdсϯ͕ϴϱϬ͛;dsͿ ϮϬ´ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ ϰ^ŚŽƚWĞƌĨƐ Λцϱ͕ϱϱϱ͛³2%´/DWHUDO Wdсϱ͕ϯϱϰ͛;DͿ ͬ Wdсϯ͕ϵϴϴ͛;dsͿ ³1%´/DWHUDO KƌŝŐ͘<ůĞǀ͗͘ϲϴ͘ϳ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϰ͘ϵ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϬ͘Ϯϳ͛;ŽǇŽŶϭϰͿ ³2$´/DWHUDO 0LQ,' ´ 0LQ,' ´ dKϱ͕ϯϱϰ͛D ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ ϯ͕ϭϬϱ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdͲDK ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϲ͕ϰϬϱΖ ϰͲϭͬϮ͟ >ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕Ϯϲϱ͛ ϴ͕ϱϭϯ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϱϱϯ͛ ϴ͕ϲϯϱ͛ ϰ͟ >ŝŶĞƌ͟͞ ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϱϰϴ ϱ͕ϲϵϱ͛ ϴ͕ϳϲϬ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdyW ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϱ͕Ϭϱϭ͛ ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdͲ// ϯ͘ϵϱϴ ϱ͕Ϭϱϭ͛ ϱ͕ϮϰϬ͛ >/EZd/> ϰͲϭͬϮ͟ ͚K͛>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕Ϯϱϵ͛ ϴ͕ϱϭϯ͛ ϰͲϭͬϮ͟ ͚K͛>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϱϱϯ͛ ϴ͕ϲϯϱ͛ ϰ͟ ͚E͛>ŝŶĞƌ ϵ͘ϯϱηͬ>ͲϴϬ/d ϯ͘ϱϰϴ ϱ͕ϲϴϮ͛ ϴ͕ϳϲϬ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ;ůůĚĞƉƚŚƐƚŽKƌŝŐZ<Ϳ ϭ ϰ͕ϵϳϰ͛ ϰͲϭͬϮ͟y^ůŝĚŝŶŐ^ůĞĞǀĞϭϮ͘ϲηϵƌ ΎΎΎ^Ğƚϴ:WŽŶϴͬϮϵͬϮϭΎΎ Ϯ ϰ͕ϵϵϭ͛ ϰ͘ϱΗ^'D͕dďŐWŽƌƚĞ͕ϭϮ͘ϲηd// ϯ ϱ͕ϬϮϮ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟ĂŬĞƌWƌĞŵŝĞƌWƌŽĚƵĐƚŝŽŶWĂĐŬĞƌ ϰ ϱ͕Ϭϯϲ͛ ϰͲϭͬϮ͟yEWƌŽĨŝůĞ;ϯ͘ϳϮϱ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϱ ϱ͕Ϭϰϯ͛ KǀĞƌƐŚŽƚʹŽƚƚŽŵΛϱ͕Ϭϱϭ͛ ϲ ϱ͕Ϭϳϱ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟,^dEdWĂĐŬĞƌ ϳ ϱ͕ϭϭϱ͛ ϰͲϭͬϮ͟yWƌŽĨŝůĞ;ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϴ ϱ͕ϭϴϳ͛ ϰͲϭͬϮ͟yEWƌŽĨŝůĞ;ϯ͘ϳϮϱ͟EŽͲ'Ž/Ϳ ϵ ϱ͕Ϯϯϵ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϰϬ͛Ϳ ϭϬ ϱ͕ϮϮϴ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϭ ϱ͕Ϯϯϵ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϮ ϱ͕Ϯϱϱ͛ K>ĂƚĞƌĂů>DηϮ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿʹ D/E/сϯ͘ϲϴϴ͟ ϭϯ ϱ͕Ϯϲϱ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϰ ϱ͕Ϯϴϴ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϭϱ ϱ͕ϱϬϭ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϲ ϱ͕ϱϭϮ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϱ͕ϱϰϯ͛ K>ĂƚĞƌĂů>Dηϭ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿͲ D/E/сϯ͘ϲϴϴ͟ ϭϴ ϱ͕ϱϱϯ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϵ ϱ͕ϱϳϲ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϮϬ ϱ͕ϲϵϱ͛ E>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ Ϯϭ ϱ͕ϳϭϳ͛ E>ĂƚĞƌĂůϳͲϱͬϴ͟ǆϱͲϭͬϮ͟&ůĞǆͲ>ŽĐŬ>ŝŶĞƌ,ĂŶŐĞƌ ϮϮ ϴ͕ϳϭϳ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ŵƚǁͬϰϵϳƐǆW&͞>͕͟ϮϲϭƐǆůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟ ŵƚǁͬϮϳϴƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϯϬϬ͛D DĂǆtĞůůďŽƌĞŶŐůĞсϳϰ͘ϬĚĞŐΛϯ͕ϳϯϱ͛D ϲϱĚĞŐΛϰ͕ϵϲϬ͛D;^ůŝĚŝŶŐ^ůĞĞǀĞΘ:ĞƚWƵŵƉͿ t>>, tĞůůŚĞĂĚ &DdƵďŝŶŐ,ĂŶŐĞƌ͕ϭϭ͟ǆ ϰͲϭͬϮ͟dͲ//dŽƉΘŽƚƚŽŵ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϬϱͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďǇŽǇŽŶϭϰʹϱͬϯϭͬϮϬϬϰ ŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉďǇŽǇŽŶϭϲʹϮͬϮϱͬϮϬϭϰ ZΘZ:ĞƚWƵŵƉĂŶĚŽŝůůĞĂŶŽƵƚʹϭϬͬϰͬϮϬϭϴ dƵďŝŶŐƵƚͬhƉƉĞƌŽŵƉůĞƚŝŽŶǇ^ZϭʹϭϬͬϭϬͬϮϬϭϵ ďĂŶĚŽŶ͞E͟ůĂƚĞƌĂůďǇdhʹϴͬϮϭͬϮϬϮϬ >dZ>t/EKtd/> dŽƉŽĨ͞K͟tŝŶĚŽǁΛϱ͕ϮϳϬ͛D͖ŽƚƚŽŵΛϱ͕ϮϴϮ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϱĚĞŐ dŽƉŽĨ͞K͟tŝŶĚŽǁΛϱ͕ϱϱϴ͛D͖ŽƚƚŽŵΛϱ͕ϱϳϬ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϴĚĞŐ ZĞƐĞƌǀŽŝƌďĂŶĚŽŶŵĞŶƚ tĞůů͗DWh:ͲϬϵ ϭϮͲϭϯͲϮϬϮϭ K/>KW sĂůǀĞ͕^ǁĂď͕t<DͲD͕ ϰϭͬϭϲϱD& sĂůǀĞ͕hƉƉĞƌDĂƐƚĞƌ͕ĂŬĞƌ͕ ϰϭͬϭϲϱD&͕ǁͬ,ǇĚƌĂƵůŝĐ EϮͲϬϮ ϯϬyϮϬyϭϯдyϵзyϳyϰЪ ŽŝůdƵďŝŶŐKW sĂůǀĞ͕>ŽǁĞƌDĂƐƚĞƌ͕t<DͲD͕ ϰϭͬϭϲϱD& ůŝŶĚͬ^ŚĞĂƌ ůŝŶĚͬ^ŚĞĂƌ >ƵďƌŝĐĂƚŽƌƚŽŝŶũĞĐƚŝŽŶ ŚĞĂĚ ϰϭͬϭϲϭϬD ^ůŝƉ ^ůŝƉ ůŝŶĚͬ^ŚĞĂƌ ůŝŶĚͬ^ŚĞĂƌ WŝƉĞ WŝƉĞ DĂŶƵĂů'ĂƚĞ ϮϭͬϴϱD ϮдΗ^ŝŶŐůĞ^ƚƌŝƉƉĞƌ ƌŽƐƐŽǀĞƌƐƉŽŽů ϰϭͬϭϲϭϬDyϰϭͬϭϲϱD DĂŶƵĂů'ĂƚĞ ϮϭͬϴϱD dƵďŝŶŐĚĂƉƚĞƌ͕ϰϭͬϭϲϱD WƵŵƉͲ/Ŷ^Ƶď ϰϭͬϭϲϱD ϭϱϬϮhŶŝŽŶ ^dEZt>>WZKhZ E/dZK'EKWZd/KE^ ϭϮͬϬϴͬϮϬϭϱ &/E>ǀϭ WĂŐĞϭŽĨϭ ϭ͘Ϳ D/ZhEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Ϯ͘Ϳ EŽƚŝĨǇWĂĚKƉĞƌĂƚŽƌŽĨƵƉĐŽŵŝŶŐEŝƚƌŽŐĞŶŽƉĞƌĂƚŝŽŶƐ͘ ϯ͘Ϳ WĞƌĨŽƌŵWƌĞͲ:Žď^ĂĨĞƚǇDĞĞƚŝŶŐ͘ZĞǀŝĞǁEŝƚƌŽŐĞŶǀĞŶĚŽƌƐƚĂŶĚĂƌĚŽƉĞƌĂƚŝŶŐƉƌŽĐĞĚƵƌĞƐĂŶĚ ĂƉƉƌŽƉƌŝĂƚĞ^ĂĨĞƚǇĂƚĂ^ŚĞĞƚƐ;ĨŽƌŵĞƌůǇD^^Ϳ͘ ϰ͘Ϳ ŽĐƵŵĞŶƚ 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X DSR-1/11/22 3105' 1R 6XEVHTXHQW)RUP55HTXLUHG $333529 &200,0,66,21(5 7++($2* XX 10--4041R 6XEVHTXHQW)RUP5HTXLUHG &200,66,21(5 7+($2* ( * 10 4041R 6XXEVHTXXHQW)RUP5HTXLUHG &200,66,21(5 7+($2* 9 * 10 404 ZĞƐĞƌǀŽŝƌ ^ƵƐƉĞŶƐŝŽŶ tĞůů͗ DW :ͲϮϲ ĂƚĞ͗ ϬϭͬϬϳͬϮϬϮϮ tĞůůEĂŵĞ͗DWh :ͲϮϲ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϮϬϱͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KŝůtĞůů΀:ĞƚWƵŵƉ΁ WĂĚ͗DŝůŶĞWŽŝŶƚ:ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶƵĂƌǇϯϬƚŚ ϮϬϮϮ ZŝŐ͗dhηϲ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇ ŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϰͲϬϲϰ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀŝĚ'Žƌŵ ;ϵϬϳͿϳϳϳͲϴϯϯϯ;KͿ ;ϱϬϱͿϮϭϱͲϮϴϭϵ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ &EƵŵďĞƌ͗:ŽďdǇƉĞ͗ZĞƐĞƌǀŽŝƌ^ƵƐƉĞŶƐŝŽŶ &XUUHQW%RWWRP+ROH3UHVVXUH SVL#¶79' %+3PHDVXUHG 0D[LPXP([SHFWHG%+3 SVL#¶79' (0: SSJ 0363 SVL %DVHGRQSVLIWJDVJUDGLHQW ƌŝĞĨtĞůů^ƵŵŵĂƌǇ DWh:ͲϮϲǁĂƐĚƌŝůůĞĚŝŶϮϬϬϰƵƐŝŶŐŽǇŽŶϭϰĂŶĚĐŽŵƉůĞƚĞĚĂƐĂƚƌŝͲůĂƚĞƌĂůŝŶƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨE͕K ĂŶĚKƐĂŶĚƐǁŝƚŚĂŶ^WĐŽŵƉůĞƚŝŽŶ͘dŚĞǁĞůůǁĂƐĐŽŶǀĞƌƚĞĚƚŽ:ĞƚWƵŵƉƵƐŝŶŐŽǇŽŶϭϲŝŶ&ĞďƌƵĂƌǇϮϬϭϰ͘dŚĞ ǁĞůůŚĂƐŚĂĚĂĨĞǁũĞƚƉƵŵƉĐŚĂŶŐĞͲŽƵƚƐƐŝŶĐĞϮϬϭϰ͘ ĞƚǁĞĞŶϴͬϳͬϮϬϮϬ ʹ ϴͬϮϭͬϮϬϮϬ ƚŚĞEůĂƚĞƌĂůǁĂƐ ĐĞŵĞŶƚĞĚĂŶĚŝƐŽůĂƚĞĚ͘ƵƌŝŶŐƚŚĞŽŝůǁŽƌŬƚŽĐĞŵĞŶƚƚŚĞEƐĂŶĚƚŚĞ/^KƐůĞĞǀĞŝƐŽůĂƚŝŶŐƚŚĞKůĂƚĞƌĂůǁĂƐ ŝŶĂĚǀĞƌƚĞŶƚůǇĐĞŵĞŶƚĞĚŝŶƉůĂĐĞ͘^ĞǀĞƌĂůĂƚƚĞŵƉƚƐǁĞƌĞŵĂĚĞƚŽĚƌŝůůŽƵƚĂŶĚƌĞƚƌŝĞǀĞƚŚĞŝƐŽůĂƚŝŽŶƐůĞĞǀĞǁŝƚŚ ŶŽƐƵĐĐĞƐƐ͘dŚĞƵƉƉĞƌŝƐŽůĂƚŝŽŶƐůĞĞǀĞĐŽǀĞƌŝŶŐƚŚĞKůĂƚĞƌĂůǁĂƐƌĞƚƌŝĞǀĞĚ͘ůĞĂŬĚĞƚĞĐƚůŽŐǁĂƐƌĂŶƚŽŝĚĞŶƚŝĨǇ ĂƉŽƚĞŶƚŝĂůůĞĂŬŝŶƚŚĞd'͘ůĞĂŬǁĂƐĚĞƚĞƌŵŝŶĞĚƚŽďĞŝŶƚŚĞƐůŝĚŝŶŐƐůĞĞǀĞ͘:WǁĂƐŝŶƐƚĂůůĞĚŝŶƚŚĞƐůŝĚŝŶŐ ƐůĞĞǀĞĂŶĚƚŚĞǁĞůůǁĂƐƉƵƚďĂĐŬŽŶ ƉƌŽĚƵĐƚŝŽŶŽŶϭϭͬϭͬϮϬϮϬ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x ĞǀŝĂƚŝŽŶĂƚƉƵŵƉŝƐϲϱ͘ϬΣ͘ x ĞǀŝĂƚŝŽŶĂƚƵƉƉĞƌǁŝŶĚŽǁŝŶƚŽƚŚĞKůĂƚĞƌĂůŝƐϳϱ͘ϭΣ͘ x ĞǀŝĂƚŝŽŶĂƚƵƉƉĞƌǁŝŶĚŽǁŝŶƚŽƚŚĞKůĂƚĞƌĂůŝƐϳϴ͘ϲΣ͘ x ĂƐŝŶŐůĂƐƚƚĞƐƚĞĚƚŽϯ͕ϲϬϬƉƐŝĨŽƌϯϬŵŝŶĚŽǁŶƚŽϱ͕ϭϲϱ͛ŽŶϮͬϮϯͬϮϬϭϰ͘ x dƵďŝŶŐůĂƐƚƚĞƐƚĞĚƚŽϯ͕ϱϬϬƉƐŝĨŽƌϯϬŵŝŶĚŽǁŶƚŽϱ͕ϭϴϳ͛ŽŶϮͬϮϲͬϮϬϭϰ͘ x :ĞƚWƵŵƉĐƵƌƌĞŶƚůǇĂĐƚŝǀĞ͘ZĞĐĞŶƚůǇƐĞƚŽŶ ϴͬϮϵͬϮϬϮϭ KďũĞĐƚŝǀĞ͗ ZĞƐĞƌǀŽŝƌ^ƵƐƉĞŶƐŝŽŶŽĨƚŚĞKͬK >ĂƚĞƌĂů͘ dŚĞƉůĂŶŶĞĚƌĞĚĞǀĞůŽƉŵĞŶƚƉĂƚƚĞƌŶĨŽƌƚŚĞ/ͲWĂĚ^ĐŚƌĂĚĞƌůƵĨĨƌĞƋƵŝƌĞƐƚŚŝƐKͲKƐĂŶĚůĂƚĞƌĂůƚŽďĞƐƵƐƉĞŶĚĞĚ ƉƌŝŽƌƚŽĚƌŝůůŝŶŐĨƵƚƵƌĞǁĞůůDW/ͲϯϬŝ ĚƵĞƚŽĐƌŽƐƐŝŶŐƚŚĞƉůĂŶŶĞĚŝŶũĞĐƚŽƌƚŽĞŶƐƵƌĞƉƌŽƉĞƌƌĞƐĞƌǀŽŝƌĨůŽŽĚŝŶŐ͘DW :ͲϮϲ ŝƐƉůĂŶŶĞĚƚŽ ďĞƐƵƐƉĞŶĚĞĚƚŽ Εϴ͕ϱϭϯ͛D ;WdͿ ƚŽŚĞůƉŵŝŶŝŵŝǌĞƉŽƚĞŶƚŝĂůĐŽŵŵƵŶŝĐĂƚŝŽŶ;D͛ƐͿ ŽŶ ĨƵƚƵƌĞ/ͲƉĂĚƌĞĚĞǀĞůŽƉŵĞŶƚǁĞůůƐ͘ -00 DLB dŚĞƉůĂŶŶĞĚƌĞĚĞǀĞůŽƉŵĞŶƚƉĂƚƚĞƌŶĨŽƌƚŚĞ/ͲWĂĚ^ĐŚƌĂĚĞƌůƵĨĨƌĞƋƵŝƌĞƐƚŚŝƐKͲKƐĂŶĚůĂƚĞƌĂůƚŽďĞƐƵƐƉĞŶĚĞĚ ƉƌŝŽƌƚŽĚƌŝůůŝŶŐĨƵƚƵƌĞǁĞůůDW/ͲϯϬŝ ĚƵĞƚŽĐƌŽƐƐŝŶŐƚŚĞƉůĂŶŶĞĚŝŶũĞĐƚŽƌƚŽĞŶƐƵƌĞƉƌŽƉĞƌƌĞƐĞƌǀŽŝƌĨůŽŽĚŝŶŐ͘ ZĞƐĞƌǀŽŝƌ ^ƵƐƉĞŶƐŝŽŶ tĞůů͗ DW :ͲϮϲ ĂƚĞ͗ ϬϭͬϬϳͬϮϬϮϮ ^ůŝĐŬůŝŶĞ WƌŽĐĞĚƵƌĞ͗ ϭ͘ D/Zh^>͘ Ϯ͘ Z/,ĂŶĚƉƵůůũĞƚƉƵŵƉĨƌŽŵ ϰ͕ϵϳϰ͛D͘WKK,͘ ϯ͘ DhƐŚŝĨƚŝŶŐƚŽŽů͘ ϰ͘ Z/,ĂŶĚĐůŽƐĞ,^͞y͟ƵƌĂƐůŝĚŝŶŐƐůĞĞǀĞΛ ϰ͕ϵϳϰ͛ D͘ ϱ͘ WƌĞƐƐƵƌĞƵƉƚŚĞ/ƚŽϭ͕ϱϬϬƉƐŝƚŽĐŽŶĨŝƌŵƐůĞĞǀĞĐůŽƐĞĚ͘ ;EŽƚĞ͗ƉŽƐƐŝďůĞůĞĂŬŝŶƚŚĞƐůŝĚŝŶŐƐůĞĞǀĞ͕ ŵŽŶŝƚŽƌĨŽƌƌĞƐƚƌŝĐƚŝŽŶŝŶĚŝĐĂƚŝŶŐ ƚŚĞƐůŝĚŝŶŐƐůĞĞǀĞǁĂƐĐůŽƐĞĚ͘Ϳ ŽŝůĞĚdƵďŝŶŐ WƌŽĐĞĚƵƌĞ͗ ;ƉƉƌŽǀĞĚ^ƵŶĚƌǇƌĞƋƵŝƌĞĚƉƌŝŽƌƚŽƉƌŽĐĞĞĚŝŶŐͿ ϭ͘ D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚĂŶĚƐƉŽƚĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚ͘&ŝůůƐŽƵƌĐĞƚĂŶŬǁͬϭй<ů͘ Ϯ͘ WƌĞƐƐƵƌĞƚĞƐƚKWƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>Žǁ͕ϭϬŵŝŶ,ŝ͕ϱŵŝŶ>ŽǁĞĂĐŚƚĞƐƚ͘ Ă͘ /ĨǁŝƚŚŝŶƚŚĞƐƚĂŶĚĂƌĚϳͲĚĂǇƚĞƐƚKWƚĞƐƚƉĞƌŝŽĚĨŽƌDŝůŶĞWŽŝŶƚ͕ĂĨƵůůďŽĚǇƚĞƐƚĂŶĚĨƵŶĐƚŝŽŶ ƚĞƐƚŽĨƚŚĞƌĂŵƐŝƐƐƵĨĨŝĐŝĞŶƚ͘ ď͘ ĂĐŚƐƵďƐĞƋƵĞŶƚƚĞƐƚŽĨƚŚĞůƵďƌŝĐĂƚŽƌǁŝůůďĞƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>ŽǁƚŽĐŽŶĨŝƌŵŶŽůĞĂŬƐ͘ ϯ͘ Z/,ǁŝƚŚŵĞŵŽƌǇ>ůŽŐƚŽƚĂŐĚĞƉƚŚ͕WKK,͕ƐĞŶĚĚĂƚĂƚŽƚŚĞ KƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌƚŽĐŽƌƌĞůĂƚĞĚĞƉƚŚ ƚŽƚŚĞ>DŚĂŶŐĞƌƚĂůůǇ ĚĂƚĞĚϱͬϮϴͬϮϬϬϰĂŶĚϱͬϮϵͬϮϬϬϰ;ůŽǁĞƌĂŶĚƵƉƉĞƌ>DĂƐƐĞŵďůŝĞƐƚĂůůǇͿ͘ ϰ͘ ĨƚĞƌ ƌĞǀŝĞǁŽĨ ƚŚĞ > ůŽŐǁŝƚŚƚŚĞŽƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ ĂŶĚĐŽŶĨŝƌŵĞĚǁĞůůĐůĞĂŶĞĚŽƵƚĚĞĞƉĞŶŽƵŐŚ ƚŽĂĐĐĞƐƐƚŚĞůŽǁĞƌ>DŝƐŽůĂƚŝŽŶƐůĞĞǀĞ͕Wh WĞƌĨŽƌĂƚŝŽŶ'ƵŶƐ͕ Z/,ĂŶĚƉĞƌĨŽƌĂƚĞ ;ϰƐŚŽƚƐͿ ƚŚĞ K ŝƐŽůĂƚŝŽŶƐůĞĞǀĞĂƚϱ͕ϱϱϱ͛D ;ƚŽďĞĂĚũƵƐƚĞĚͿ͕ WKK,͘ ϱ͘ WhĂ ϰͲϭͬϮ͟ DdƌĞƚĂŝŶĞƌ ;ϯ͘ϱϵϯ͟KͿ͕ Z/,ĂŶĚƐĞƚĂƚϱ͕ϰϳϬ͛D͘ƐƚĂďůŝƐŚ ĂŶ ŝŶũĞĐƚŝŽŶƌĂƚĞ ;ŵĂǆ ƉƌĞƐƐƵƌĞĨŽƌŝŶũĞĐƚŝŽŶϴϬϬƉƐŝͿ ŝŶƚŽƚŚĞKůĂƚĞƌĂů͕ƚŚĞŶƌĞǀŝĞǁ ƚŚĞƌĂƚĞĂŶĚƉƌĞƐƐƵƌĞǁŝƚŚƚŚĞ KƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ͘ Ă͘ /Ĩ ŝŶũĞĐƚŝŽŶƌĂƚĞƐĂƌĞ ĂƉƉƌŽǀĞĚďǇƚŚĞŽƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ͕ DŝǆĂŶĚ ďƵůůŚĞĂĚ ϰϲ>^ ŽĨϭϱ͘ϴ WW'ůĂƐƐ'ĞŵĞŶƚ ŝŶƚŽƚŚĞK>ĂƚĞƌĂů͘ ď͘ /ĨŶŽ ŽƌůŝŵŝƚĞĚ ŝŶũĞĐƚŝŽŶƌĂƚĞĐĂŶďĞŽďƚĂŝŶĞĚ ĂĨƚĞƌƌĞǀŝĞǁǁŝƚŚŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌ͕ƐƚŝŶŐŽƵƚ ŽĨƚŚĞĐĞŵĞŶƚ ƌĞƚĂŝŶĞƌ͕ ĂŶĚŵŽǀĞƚŽƚŚĞŶĞǆƚƐƚĞƉ͘ ϲ͘ ^ƚŝŶŐŽƵƚ ĂŶĚƐƉŽƚ Ϯ>ƐŽĨϭϱ͘ϴůĂƐƐ' ĐĞŵĞŶƚĨƌŽŵƚŚĞDdƌĞƚĂŝŶĞƌƚŽϱ͕ϯϱϬ͛D͘ ϳ͘ Wh, ƚŽϱ͕ϯϬϬ͛DĂŶĚƉƵŵƉϭϬϬ>ŽĨϭй<ůŝŶƚŽƚŚĞKůĂƚĞƌĂůƚŽĐŽŶƚĂŵŝŶĂƚĞĂŶǇƌĞƐŝĚƵĂůDd ĨƌŽŵƚŚĞůŽǁĞƌƉůƵŐƐĞƚ͕WKK,͘ ϴ͘ WhĂŶĚ Z/,ǁͬϮ͟ dǁͬ >D ŬŝĐŬŽƵƚƚŽŽů͘^ĞƚƚŚĞ >D <ŝĐŬŽƵƚŝŶƚŚĞƵƉƉĞƌK>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞ ;>DͿ͘ ϵ͘ WKK,ĂŶĚDh :^E ĂŶĚĐůĞĂŶŽƵƚ,͕Z/, ĐůĞĂŶŽƵƚƚŚĞ K>Ăƚ ƚŽ WdĂƚнͬͲ ϴ͕ϱϭϯ͛D͘WKK,͘ ;ZĞǀŝĞǁ,K͛ƐĂŶĚǁĞůůďŽƌĞ/͛ƐǁŝƚŚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌͿ͘ Ă͘ ŝƌĐƵůĂƚĞŽƵƚĨŝůůƵƐŝŶŐϭй<ůǁͬĨƌŝĐƚŝŽŶƌĞĚƵĐĞƌ͘WƵŵƉϱͲϭϬďďů'Ğů^ǁĞĞƉƐƚŽŚĞůƉƌĞŵŽǀĞ ƐŽůŝĚƐĨƌŽŵƚŚĞůŝŶĞƌ͘ ď͘ŽŶƚŝŶŐĞŶĐǇ͗/ĨƵŶĂďůĞƚŽĐŝƌĐƵůĂƚĞĨůƵŝĚƚŽƐƵƌĨĂĐĞǁŝƚŚŽƵƚƐŝŐŶŝĨŝĐĂŶƚůŽƐƐĞƐ;фϱϬйƌĞƚƵƌŶƐŽƌ ůŝƚƚůĞƚŽŶŽƐŽůŝĚƐĐŝƌĐƵůĂƚĞĚƚŽƐƵƌĨĂĐĞͿ͘ŝƌĐƵůĂƚĞŽƵƚĨŝůůƵƐŝŶŐϴ͘ϱƉƉŐϭй<ůǁͬůŝƋƵŝĚĨŽĂŵĞƌ ĂŶĚŵŝǆǁŝƚŚEŝƚƌŽŐĞŶ;ƐĞĞEŝƚƌŽŐĞŶƉƌŽĐĞĚƵƌĞĂŶĚĚŝĂŐƌĂŵͿ͘ ϭϬ͘ WKK, ƚŽWhƚŚĞ Dd,͘ ϭϭ͘ DhďĂůůĚƌŽƉĐĞŵĞŶƚŝŶŐŶŽǌǌůĞĂŶĚZ/,ƚŽ ϴ͕ϱϭϯ͛Žƌ ĚĞĞƉĞƐƚĚĞƉƚŚƌĞĂĐŚĞĚĚƵƌŝŶŐ&K͘ Ă͘ ŽŶƚŝŶŐĞŶĐǇ͗/ĨƵŶĂďůĞƚŽĂĐĐĞƐƐƚŚĞƵƉƉĞƌůĂƚĞƌĂůƚŽůĂǇĐĞŵĞŶƚ͕WƵůůƚŚĞ<ŝĐŬŽƵƚdŽŽů͕WhĂϰͲ ϭͬϮ͟DdƌĞƚĂŝŶĞƌĂŶĚƐĞƚĂƚϱ͕ϮϬϬ͛D͕ƐƚĂďůŝƐŚ/ŶũĞĐƚŝŽŶZĂƚĞ ;ŵĂǆŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞϴϬϬ ƉƐŝͿ͕ƌĞǀŝĞǁǁŝƚŚƚŚĞŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌƉůĂŶƚŽďƵůůŚĞĂĚϱϬ>Ɛϭϱ͘ϴƉƉŐůĂƐƐ'ĞŵĞŶƚ ďĞůŽǁƚŚĞƌĞƚĂŝŶĞƌ͘ ď͘^ƉŽƚϭϱ͘ϴƉƉŐůĂƐƐ'ĐĞŵĞŶƚƵƉƚŽϱ͕ϭϬϬ͛DŽŶƚŽƉŽĨƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌ͘ŝƌĐƵůĂƚĞƚŚĞĐŽŝů ĐůĞĂŶ͕ĐŽŶƚĂŵŝŶĂƚĞ ĂŶĚƐƉŽƚĨƌĞĞǌĞƉƌŽƚĞĐƚŽŶƚŚĞdKK,͘;^ŬŝƉƐƚĞƉƐϭϯͲϭϳŝĨƌĞƚĂŝŶĞƌƵƐĞĚ ĨŽƌ ƵƉƉĞƌůĂƚĞƌĂůͿ͘ ŝƐŽůĂƚŝŽŶƐůĞĞǀĞĂƚϱ͕ϱϱϱ͛D ;ƚŽďĞĂĚũƵƐƚĞĚͿ͕ WKK,͘ Wh WĞƌĨŽƌĂƚŝŽŶ'ƵŶƐ͕ Z/,ĂŶĚƉĞƌĨŽƌĂƚĞ ;ϰƐŚŽƚƐͿ ƚŚĞ K ZĞƐĞƌǀŽŝƌ ^ƵƐƉĞŶƐŝŽŶ tĞůů͗ DW :ͲϮϲ ĂƚĞ͗ ϬϭͬϬϳͬϮϬϮϮ ϭϮ͘ DŝǆĂŶĚƉƵŵƉ ϱϱ ďďůƐŽĨϭϱ͘ϴƉƉŐůĂƐƐ'ĐĞŵĞŶƚĚŽǁŶƚŚĞĐŽŝůƚƵďŝŶŐƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞ ϰͲϭͬϮ͟ ƚƵďŝŶŐ ;ůŝŵŝƚĞĚƚŽŶŽƌĞƚƵƌŶƐŵĂǇďĞŽďƐĞƌǀĞĚͿ͘hƐĞĨƌĞƐŚǁĂƚĞƌ ƐƉĂĐĞƌƐĂƐŶĞĞĚĞĚĂƌŽƵŶĚƚŚĞĐĞŵĞŶƚ͘ Ă͘ŽŶƚĂĐƚŶŐŝŶĞĞƌĂŶĚĂĚũƵƐƚǀŽůƵŵĞďĂƐĞĚŽŶĨŝŶĂůĐůĞĂŶŽƵƚĚĞƉƚŚƌĞĂĐŚĞĚ ď͘ ϰͲϭͬϮ͟ůŝŶĞƌǀŽů͗Ϭ͘ϬϭϱϮϭ ǆ;ϴ͕ϱϭϯ͛ ʹ ϱ͕ϭϬϬ͛ͿсΕϱϮ ďďůƐ Đ͘ ϯ ďďůƐŽĨƐƉĂƌĞǀŽůƵŵĞƚŽƐƋƵĞĞǌĞĂǁĂǇŽƌĐŽŶƚĂŵŝŶĂƚĞ͘ ϭϯ͘ ůůŽǁΕϭďďůŽĨĐĞŵĞŶƚĂƌŽƵŶĚƚŚĞ ĐĞŵĞŶƚŝŶŐŶŽǌǌůĞĂŶĚůĂǇƚŚĞƌĞƐƚŽĨƚŚĞĐĞŵĞŶƚŝŶ ďĂĐŬ ƚŽϱ͕ϭϬϬ͛ D͘ ;EŽƚĞ͗ĞƉĞŶĚŝŶŐŽŶŽƚƚŽŵŚŽůĞƉƌĞƐƐƵƌĞ͕ŵĂǇŶŽƚŚĂǀĞƉƌĞƐƐƵƌĞŽƌƌĞƚƵƌŶƐŽŶƐƵƌĨĂĐĞ͕ƌĞǀŝĞǁ ǁŝƚŚŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌƉƵŵƉŝŶŐĐĞŵĞŶƚĂŶĚƉŽŽŚďĂƐĞĚŽŶǀŽůƵŵĞƐͿ ϭϰ͘ Wh ϱϬϬ͛ ϭϱ͘ ^ǁĂƉƚŽĐŽŶƚĂŵŝŶĂƚĞĂŶĚZ/,ƚŽ ϱ͕ϭϬϬ͛D;ƉůĂŶŶĞĚdKͿ͘ ϭϲ͘ ŝƌĐƵůĂƚĞ ĐŽŝůĐůĞĂŶŽŶƚŚĞ ƚƌŝƉďĂĐŬŽƵƚŽĨ ƚŚĞŚŽůĞ͘ Ă͘ &ƌĞĞǌĞƉƌŽƚĞĐƚǁĞůůŽŶǁĂǇŽƵƚŽĨŚŽůĞ ĂƐŶĞĞĚĞĚ͘ ϭϳ͘ tĂŝƚŽŶĐĞŵĞŶƚƚŽŐĂŝŶ ĂŵŝŶŝŵƵŵ ϭ͕ϬϬϬƉƐŝĐŽŵƉƌĞƐƐŝǀĞƐƚƌĞŶŐƚŚ͘ ϭϴ͘ WƌĞƐƐƵƌĞƚĞƐƚƚŚĞĐĞŵĞŶƚƚŽϭ͕ϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ;ĐŚĂƌƚĞĚͿ͘ /ĨƚŚĞƉůƵŐƚĞƐƚƐŐŽŽĚ͕d/,ǁŝƚŚŽŝůĂŶĚ ƚĂŐƚŚĞdK͕ƉůĂŶŶĞĚdKΛϱ͕ϭϬϬ͛D͘;ŽŶƚĂĐƚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌǁŝƚŚĨŝŶĂůƚĂŐĚĞƉƚŚ͘Ϳ Ă͘ /ĨƚŚĞƉƌĞƐƐƵƌĞƚĞƐƚŽĨƚŚĞĐĞŵĞŶƚƉůƵŐĨĂŝůƐ͕ĐŽŶƚĂĐƚƚŚĞKƉĞƌĂƚŝŽŶƐ ŶŐŝŶĞĞƌƚŽĚŝƐĐƵƐƐ ƉƵŵƉŝŶŐĂĚĚŝƚŝŽŶĂůĐĞŵĞŶƚ͘ ď͘ EŽƚŝĨǇK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞƚŽǁŝƚŶĞƐƐ ƚĂŐĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚ͘ ϭϵ͘ WKK, ĨƌĞĞǌĞƉƌŽƚĞĐƚŝŶŐĂƐŶĞĞĚĞĚ͘ ϮϬ͘ ZdƵŶŝƚ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůĞĚdƵďŝŶŐ KW^ĐŚĞŵĂƚŝĐ ϰ͘ EŝƚƌŽŐĞŶKƉĞƌĂƚŝŽŶƐWƌŽĐĞĚƵƌĞ ϱ͘ EŝƚƌŽŐĞŶ&ůŽǁŝĂŐƌĂŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗,ϭϮͬϮϳͬϮϬϮϭ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϮϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϬͬϭϬͬϮϬϭϵ Wd͗ϮϬϰͲϬϲϰ ϮϮ ůĞĂŶŽƵƚEůĂƚĞƌĂůƚŽϴ͕ϳϭϵ͛dD ϭϬͬϰͬϮϬϭϴdĂŐŐĞĚWddс ϴ͕ϳϲϬ͛;DͿͬdсϯ͕ϴϱϬ͛;dsͿ ϮϬ´ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ ³2%´/DWHUDO Wdсϱ͕ϯϱϰ͛;DͿ ͬ Wdсϯ͕ϵϴϴ͛;dsͿ ³1%´/DWHUDO KƌŝŐ͘<ůĞǀ͗͘ϲϴ͘ϳ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϰ͘ϵ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϬ͘Ϯϳ͛;ŽǇŽŶϭϰͿ ³2$´/DWHUDO 0LQ,' ´ 0LQ,' ´ dKϱ͕ϯϱϰ͛D ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ ϯ͕ϭϬϱ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdͲDK ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϲ͕ϰϬϱΖ ϰͲϭͬϮ͟ >ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕Ϯϲϱ͛ ϴ͕ϱϭϯ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϱϱϯ͛ ϴ͕ϲϯϱ͛ ϰ͟ >ŝŶĞƌ͟͞ ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϱϰϴ ϱ͕ϲϵϱ͛ ϴ͕ϳϲϬ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdyW ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϱ͕Ϭϱϭ͛ ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdͲ// ϯ͘ϵϱϴ ϱ͕Ϭϱϭ͛ ϱ͕ϮϰϬ͛ >/EZd/> ϰͲϭͬϮ͟ ͚K͛>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕Ϯϱϵ͛ ϴ͕ϱϭϯ͛ ϰͲϭͬϮ͟ ͚K͛>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϱϱϯ͛ ϴ͕ϲϯϱ͛ ϰ͟ ͚E͛>ŝŶĞƌ ϵ͘ϯϱηͬ>ͲϴϬ/d ϯ͘ϱϰϴ ϱ͕ϲϴϮ͛ ϴ͕ϳϲϬ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ;ůůĚĞƉƚŚƐƚŽKƌŝŐZ<Ϳ ϭ ϰ͕ϵϳϰ͛ ϰͲϭͬϮ͟y^ůŝĚŝŶŐ^ůĞĞǀĞϭϮ͘ϲηϵƌ ΎΎΎ^Ğƚϴ:WŽŶϴͬϮϵͬϮϭΎΎ Ϯ ϰ͕ϵϵϭ͛ ϰ͘ϱΗ^'D͕dďŐWŽƌƚĞ͕ϭϮ͘ϲηd// ϯ ϱ͕ϬϮϮ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟ĂŬĞƌWƌĞŵŝĞƌWƌŽĚƵĐƚŝŽŶWĂĐŬĞƌ ϰ ϱ͕Ϭϯϲ͛ ϰͲϭͬϮ͟yEWƌŽĨŝůĞ;ϯ͘ϳϮϱ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϱ ϱ͕Ϭϰϯ͛ KǀĞƌƐŚŽƚʹŽƚƚŽŵΛϱ͕Ϭϱϭ͛ ϲ ϱ͕Ϭϳϱ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟,^dEdWĂĐŬĞƌ ϳ ϱ͕ϭϭϱ͛ ϰͲϭͬϮ͟yWƌŽĨŝůĞ;ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϴ ϱ͕ϭϴϳ͛ ϰͲϭͬϮ͟yEWƌŽĨŝůĞ;ϯ͘ϳϮϱ͟EŽͲ'Ž/Ϳ ϵ ϱ͕Ϯϯϵ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϰϬ͛Ϳ ϭϬ ϱ͕ϮϮϴ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϭ ϱ͕Ϯϯϵ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϮ ϱ͕Ϯϱϱ͛ K>ĂƚĞƌĂů>DηϮ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿʹ D/E/сϯ͘ϲϴϴ͟ ϭϯ ϱ͕Ϯϲϱ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϰ ϱ͕Ϯϴϴ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϭϱ ϱ͕ϱϬϭ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϲ ϱ͕ϱϭϮ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϱ͕ϱϰϯ͛ K>ĂƚĞƌĂů>Dηϭ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿͲ D/E/сϯ͘ϲϴϴ͟ ϭϴ ϱ͕ϱϱϯ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϵ ϱ͕ϱϳϲ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϮϬ ϱ͕ϲϵϱ͛ E>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ Ϯϭ ϱ͕ϳϭϳ͛ E>ĂƚĞƌĂůϳͲϱͬϴ͟ǆϱͲϭͬϮ͟&ůĞǆͲ>ŽĐŬ>ŝŶĞƌ,ĂŶŐĞƌ ϮϮ ϴ͕ϳϭϳ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟WĂĐŬͲŽĨĨƵƐŚŝŶŐ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ŵƚǁͬϰϵϳƐǆW&͞>͕͟ϮϲϭƐǆůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟ ŵƚǁͬϮϳϴƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϯϬϬ͛D DĂǆtĞůůďŽƌĞŶŐůĞсϳϰ͘ϬĚĞŐΛϯ͕ϳϯϱ͛D ϲϱĚĞŐΛϰ͕ϵϲϬ͛D;^ůŝĚŝŶŐ^ůĞĞǀĞΘ:ĞƚWƵŵƉͿ t>>, tĞůůŚĞĂĚ &DdƵďŝŶŐ,ĂŶŐĞƌ͕ϭϭ͟ǆ ϰͲϭͬϮ͟dͲ//dŽƉΘŽƚƚŽŵ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϬϱͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďǇŽǇŽŶϭϰʹϱͬϯϭͬϮϬϬϰ ŽŶǀĞƌƚƚŽ:ĞƚWƵŵƉďǇŽǇŽŶϭϲʹϮͬϮϱͬϮϬϭϰ ZΘZ:ĞƚWƵŵƉĂŶĚŽŝůůĞĂŶŽƵƚʹϭϬͬϰͬϮϬϭϴ dƵďŝŶŐƵƚͬhƉƉĞƌŽŵƉůĞƚŝŽŶǇ^ZϭʹϭϬͬϭϬͬϮϬϭϵ ďĂŶĚŽŶ͞E͟ůĂƚĞƌĂůďǇdhʹϴͬϮϭͬϮϬϮϬ >dZ>t/EKtd/> dŽƉŽĨ͞K͟tŝŶĚŽǁΛϱ͕ϮϳϬ͛D͖ŽƚƚŽŵΛϱ͕ϮϴϮ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϱĚĞŐ dŽƉŽĨ͞K͟tŝŶĚŽǁΛϱ͕ϱϱϴ͛D͖ŽƚƚŽŵΛϱ͕ϱϳϬ͛D͖ŶŐůĞΛƚŽƉŽĨǁŝŶĚŽǁŝƐϳϴĚĞŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭͬϭϬͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϮϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϬͬϭϬͬϮϬϭϵ Wd͗ϮϬϰͲϬϲϰ ϮϮ ůĞĂŶŽƵƚEůĂƚĞƌĂůƚŽϴ͕ϳϭϵ͛dD ϭϬͬϰͬϮϬϭϴdĂŐŐĞĚWddс ϴ͕ϳϲϬ͛;DͿͬdсϯ͕ϴϱϬ͛;dsͿ ϮϬ´ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ ϰ^ŚŽƚWĞƌĨƐ Λцϱ͕ϱϱϱ͛³2%´/DWHUDO Wdсϱ͕ϯϱϰ͛;DͿ ͬ Wdсϯ͕ϵϴϴ͛;dsͿ ³1%´/DWHUDO KƌŝŐ͘<ůĞǀ͗͘ϲϴ͘ϳ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϰ͘ϵ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϬ͘Ϯϳ͛;ŽǇŽŶϭϰͿ ³2$´/DWHUDO 0LQ,' ´ 0LQ,' ´ dKϱ͕ϯϱϰ͛D ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ ϯ͕ϭϬϱ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdͲDK ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϲ͕ϰϬϱΖ ϰͲϭͬϮ͟ >ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕Ϯϲϱ͛ ϴ͕ϱϭϯ͛ ϰͲϭͬϮ͟ >ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϱϱϯ͛ ϴ͕ϲϯϱ͛ ϰ͟ >ŝŶĞƌ͟͞ ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϱϰϴ ϱ͕ϲϵϱ͛ ϴ͕ϳϲϬ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdyW ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϱ͕Ϭϱϭ͛ ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdͲ// ϯ͘ϵϱϴ ϱ͕Ϭϱϭ͛ ϱ͕ϮϰϬ͛ >/EZd/> ϰͲϭͬϮ͟ ͚K͛>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕Ϯϱϵ͛ ϴ͕ϱϭϯ͛ ϰͲϭͬϮ͟ ͚K͛>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϱϱϯ͛ ϴ͕ϲϯϱ͛ ϰ͟ ͚E͛>ŝŶĞƌ ϵ͘ϯϱηͬ>ͲϴϬ/d ϯ͘ϱϰϴ ϱ͕ϲϴϮ͛ ϴ͕ϳϲϬ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ;ůůĚĞƉƚŚƐƚŽKƌŝŐZ<Ϳ ϭ ϰ͕ϵϳϰ͛ ϰͲϭͬϮ͟y^ůŝĚŝŶŐ^ůĞĞǀĞϭϮ͘ϲηϵƌ ΎΎΎ^Ğƚϴ:WŽŶϴͬϮϵͬϮϭΎΎ Ϯ ϰ͕ϵϵϭ͛ ϰ͘ϱΗ^'D͕dďŐWŽƌƚĞ͕ϭϮ͘ϲηd// ϯ ϱ͕ϬϮϮ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟ĂŬĞƌWƌĞŵŝĞƌWƌŽĚƵĐƚŝŽŶWĂĐŬĞƌ ϰ ϱ͕Ϭϯϲ͛ ϰͲϭͬϮ͟yEWƌŽĨŝůĞ;ϯ͘ϳϮϱ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϱ ϱ͕Ϭϰϯ͛ KǀĞƌƐŚŽƚʹŽƚƚŽŵΛϱ͕Ϭϱϭ͛ ϲ ϱ͕Ϭϳϱ͛ ϳͲϱͬϴ͟ǆϰͲϭͬϮ͟,^dEdWĂĐŬĞƌ ϳ ϱ͕ϭϭϱ͛ ϰͲϭͬϮ͟yWƌŽĨŝůĞ;ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ/Ϳ ϴ ϱ͕ϭϴϳ͛ ϰͲϭͬϮ͟yEWƌŽĨŝůĞ;ϯ͘ϳϮϱ͟EŽͲ'Ž/Ϳ ϵ ϱ͕Ϯϯϵ͛ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ;ƚŵĂƚϱ͕ϮϰϬ͛Ϳ ϭϬ ϱ͕ϮϮϴ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϭ ϱ͕Ϯϯϵ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϮ ϱ͕Ϯϱϱ͛ K>ĂƚĞƌĂů>DηϮ;>ĂƚĞƌĂůŶƚƌǇDŽĚƵůĞͿʹ D/E/сϯ͘ϲϴϴ͟ ϭϯ ϱ͕Ϯϲϱ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϰ ϱ͕Ϯϴϴ͛ K>ĂƚĞƌĂů,ŽŽŬtĂůů͕,ĂŶŐĞƌďĞůŽǁϳͲϱͬϴ͟tŝŶĚŽǁ ϭϱ ϱ͕ϱϬϭ͛ K>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϭϲ ϱ͕ϱϭϮ͛ K>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϱ͕ϱϰϯ͛ 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&Z/d/KE ZhZ dŽ&ůŽǁůŝŶĞ E/dZK'EWhDWΘdE< W K/>hE/dt/d,ϭ͘ϱ͟ƚŽϮ͘Ϭ͟K/> ϰϬϬ>hWZ/',d ^tdZ tͬ &KDZ dZ/W>y Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-26 (PTD 204-064) Leak Detection Log 10/31/2020 Please include current contact information if different from above. PTD: 2040640 E-Set: 34448 Received by the AOGCC 12/22/2020 Abby Bell 12/23/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/04/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-26 (PTD 204-064) Multi Finger Caliper Log 09/29/2020 Please include current contact information if different from above. Received by the AOGCC 12/04/2020 PTD: 2040640 E-Set: 34361 Abby Bell 12/09/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Set CIBP Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,760 feet 5,345 feet true vertical 3,850 feet N/A feet Effective Depth measured 5,345 feet feet true vertical 3,986 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TC-II 5,240' 3,958' HES TNT & Packers and SSSV (type, measured and true vertical depth)(3) ZXP LTP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8485 2. Operator Name Senior Engineer: Senior Res. Engineer: 7,910psi Collapse N/A 2,090psi 3,843' 3,850' 4,790psi 7,500psi Burst N/A 3,580psi 6,890psi 8,430psi 6,590psi 7,500psi 20" 10-3/4" 7-5/8" 4-1/2" 8,430psi 305' 3,895' 3,834' Casing Structural Liner 3,065' Length 112' 3,105' 6,405' Conductor Surface 0 Casing Pressure Tubing Pressure 10 N/A measured 3,248' 3,082' N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-319 58 Authorized Signature with date: Authorized Name: Abhijeet Tambe Abhijeet.Tambe@hilcorp.com 2,136 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-064 50-029-23205-00-00 Plugs ADL0025517 / ADL0025906 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 Size MILNE PT UNIT J-26 Gas-Mcf 8,513' 8,635' Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16 Intermediate Production TVD 112' 105 Oil-Bbl measured true vertical Packer 4-1/2" 4" 5,075, 5,239, 5,512 & 5,695 3,899, 3,958, 4,019 & 4,046 WINJ WAG 0 Water-Bbl MD 112' 3,105' 6,405' 8,760' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad A Helgeson 2020.11.18 18:15:16 -09'00' By Samantha Carlisle at 10:34 am, Nov 19, 2020 DSR-11/23/2020 RBDMS HEW 11/20/2020 SFD 11/18/2020MGR30NOV20 _____________________________________________________________________________________ Revised By: TDF 11/17/2020 SCHEMATIC Milne Point Unit Well: MPU J-26 Last Completed: 10/10/2019 PTD: 204-064 22 Cleanout NB lateral to 8,719’ CTM 10/4/2018 Tagged PBTDTD =8,760’(MD) / TD = 3,850’(TVD) 20” 7-5/8” 18 19 10-3/4” 13 20 “OB” Lateral PBTD =8,760’(MD)/ PBTD =3,850’(TVD) “NB” Lateral 13 14 9 7 6 1 Orig. KB Elev.: 68.7’/ Orig. GL Elev.: 34.9’ RKB – Hanger: 30.27’ (Doyon 14) 13 “OA” Lateral 10 11 12 15 16 17 21 3 2 8 Min ID = 3.688” 4 5 Min ID = 3.688” TOC 5,354’ MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 3,105’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 6,405' 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 5,265’ 8,513’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 5,553’ 8,635’ 4” Liner “C” 9.5 / L-80 / IBT 3.548 5,695’ 8,760’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958 Surface 5,051’ 4-1/2” Tubing 12.6 / L-80 / TC-II 3.958 5,051’ 5,240’ LINER DETAIL 4-1/2” ‘OA’ Liner 12.6 / L-80 / IBT 3.958 5,259’ 8,513’ 4-1/2” ‘OB’ Liner 12.6 / L-80 / IBT 3.958 5,553’ 8,635’ 4” ‘NB’ Liner 9.35# / L-80 IBT 3.548 5,682’ 8,760’ JEWELRY DETAIL No Depth Item (All depths to Orig RKB) 14,974’4-1/2” XD Sliding Sleeve 12.6# 9Cr ***Set 9B JP on 5/30/20** 2 4,991’ 4.5" SGM, Tbg Porte, 12.6# TCII 3 5,022’ 7-5/8” x 4-1/2” Baker Premier Production Packer 4 5,036’ 4-1/2” XN Profile (3.725” Packing Bore ID) 5 5,043’ Overshot – Bottom @ 5,051’ 6 5,075’ 7-5/8” x 4-1/2” HES TNT Packer 7 5,115’ 4-1/2” X Profile (3.813” Packing Bore ID) 8 5,187’ 4-1/2” XN Profile (3.725” No-Go ID) 9 5,239’ Wireline Entry Guide (Btm at 5,240’) 10 5,228’ OA Lateral Tie Back Sleeve 11 5,239’ OA Lateral ZXP Liner Top Packer 12 5,255’ OA Lateral LEM #2 (Lateral Entry Module) –MIN ID = 3.688” 13 5,265’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 14 5,288’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 15 5,501’ OB Lateral Tie Back Sleeve 16 5,512’ OB Lateral ZXP Liner Top Packer 17 5,543’ OB Lateral LEM #1 (Lateral Entry Module) -MIN ID = 3.688” 18 5,553’ OB Lateral Hook Wall, Hanger above 7-5/8” Window 19 5,576’ OB Lateral Hook Wall, Hanger below 7-5/8” Window 20 5,695’ NB Lateral ZXP Liner Top Packer 21 5,717’ NB Lateral 7-5/8” x 5-1/2” Flex-Lock Liner Hanger 22 8,717’ NB Lateral 4-1/2” Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 497 sx PF “L”, 261 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 278 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 300’ MD Max Wellbore Angle = 74.0 deg @ 3,735’ MD 65 deg @ 4,960’ MD (Sliding Sleeve & Jet Pump) WELLHEAD Wellhead FMC Tubing Hanger, 11” x 4-1/2” TC-II Top & Bottom GENERAL WELL INFO API: 50-029-23205-00-00 Drilled and Completed by Doyon 14 – 5/31/2004 Convert to Jet Pump by Doyon 16 – 2/25/2014 R&R Jet Pump and Coil Cleanout – 10/4/2018 Tubing Cut/ Upper Completion By ASR1– 10/10/2019 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,270’ MD; Bottom @ 5,282’ MD; Angle @ top of window is 75 deg Top of “OB” Window @ 5,558’ MD; Bottom @ 5,570’ MD; Angle @ top of window is 78 deg Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 CTU 50-029-23205-00-00 204-064 8/7/2020 11/1/2020 No operations to report. RIH w/ LEM #1 ISO sat down at 5,271' ctmd attempted to get through with SI-DI Hipp Tripper. Hipp Tripper seemed to function erratically during process. Ran at a higher ROP and SD with Hipp Tripper. No luck getting through had to set off jars @ 10k over pick up weight. POOH and found bottom of ISO, mule shoe had deep scaring from metal to metal contact. Also scars across packing stack and just above. Pictures were taken and sent to OE in charge of operation. Called and discussed options plan forward. Ran BHA w/jars, motor and 3.66" OD Turbo mill. Dry drifted sat down and fell through bottom of LEM #2 @ 5,272' ctmd. Back reamed OOH and back down three times. Dry drifted down through both LEM #2 and LEM #1 smoothly continued down to 5,748' ctmd with no issues. POOH through both LEM's with no changes in weight to give indication of problems. Once through XN and at 50 deg. Inc. kicked pump on line down backside of CT to flush any debris down hole. OOH swap BHA to run LEM's Found a couple small chunks of steel trapped in between the cutter on the mill. Secure well for night and return in morning to continue operation. 8/8/2020 - Saturday RIH w/ 2.25" ball drop nozzle. Displaced well with 150 bbls 1% KCL then 68 bbls of diesel to get WHP of 92psi. Tagged PBTD at 8,720' ctmd and PUH 10' Pumped 5 bbl fresh water spacer, 48 bbls of 15.8 ppg Class G Cement, 2 bbl fresh water spacer, displacing cement from coil with diesel. Laid in cement 1:1 from 8,720' to 5,710' Closed choke and pumped coil displacement up to safety @ 4,985'. Shut down and wait for 15 m in. Pulled up hole pumping coil displacement to make sure coil is free to 4,899' wait 30 min. 3,020' of cement = 39.1 bbls of cement in place. Cement pumped into coil= 48 bbls Marker tank recovered 28 bbls CT displacement = 11.8 bbls Volume lost to resivoir 8.2 bbls Est TOC @ 5,710' Pilot report has slurry at 9.5 hours before 70 bc. Saw bump during laying in of cement. Did not "Squeeze" would have pushed away. UCA showing 1,000 psi compressive at 29 hours. Stack Injector and lubricator back and secure well for night. 8/11/2020 - Tuesday 8/9/2020 - Sunday RIH w/ LEM #1 ISO went through problem area smoothly and set in profile @ 5,562' isolating OB sands. RIH w/ LEM #2 ISO set in profile at 5,272' Isolating OA sands. RIH and drift LNR tag fill @ 8,016' ctmd (8.6 bbls) PUH to 4,100' Start N2 @ 1,500scf and blow coil down and start conditioning well for clean out. Once returns were established lowered N2 rate to 500 scf and start slick 1% KCL down CT Ran back in hole and cleaned fill from 8,016' to 8,717' ctmd using 12 bbl gel sweeps and chasing up hole to LEM #1. Once at TD. 8,766 ctmd. We pumped 20 bbl sweeper and chased to surface at 30% throughout the LNR Recipe up/down/up in the area between the LEM's a bit of sand trapped between. Continued OOH @ 30% until well inclination was at 50 deg. Secure well for night and return in morning to continue operation. 8/10/2020 - Monday 8/7/2020 - Friday Pressure Test BOP 300psi Low / 4,000psi High. RIH w/ LEM #1 ISO and sat down in XN nipple @ 5,187' Attempted to push through a coupel times sat down again and used Hipp-Triper lightly for very short time and went through. Continued in hole and sat down in LEM #2 @ 5,255' Attempeted to work through LEM then with Hipp-Tripper lightly and circulation pressure started climbing. Looked like the choke in the 4" Hydraulic GS was plugging off. Shut down pump and worked ISO then circulation pressure came down very slow. Circ pressure dropped and came on line with pump to clear up circlulation. Pulled up hole a couple hundred feet while reestablishing circulation. RIH with pumps off and engauged fishing neck of ISO and pulled free. POOH and recovered ISO covered with a light oil shean and fine sand. Packing in good condition. RIH with 2.81" OD jet down nozzle and washed accross xn down accross LEM #2 reciped above XN and back down arross XN, LEM #2, LEM #1 to 5,604' CTMD. Returned to serface and set up BHA with ISO for LEM #1 Stack CT injector with lubricater on back deck. Secure well for night and return in morning to continue operation. 8/5/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/6/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 Coil 50-029-23205-00-00 204-064 8/7/2020 11/1/2020 MU & RIH w/ 3-1/8" BHA w/ cutter brush. Tag at 5,537'. Work cutter brush from 5,537' to down to 5,538.82'. Reciprocate brush across fishing neck. POH, pump to 5,200', max rate. LD cutter brush - ring grove on end of cutter brush indicates TD of internal fishing neck has been reached. MU & RIH w/ 3-1/8" Fishing BHA. Tag at 5,535'. Unable to latch fishing neck - able to jar down & obtain 8k over pull friction bite. POH & LD fishing BHA. LD lubricator & set down injector. Change packoffs & check chains. PU lubricator. Test MHA. Lay down for the night. 8/15/2020 - Saturday 8/16/2020 - Sunday MU & RIH w/ 3-1/8" BHA w/ SLB jet blaster using 3.68" gauge ring. Tag at 5,531.6'. PUH & jet blast down from 5,450' to 5,531'. Unable to make any footage. POH with jet blaster. MU & RIH w/ 3-1/8" Fishing BHA. Tag at 5,535'. Unable to latch fishing neck. POH & LD fishing BHA. MU & RIH with 3-1/8" BHA & full bore 3.66" flat bottom milling BHA. Tag upper LEM at 5,247' & work through. Dry tag at 5,529'. Mill to a hard bottom and 300psi motor work at 5,543'. Backream to 5,488'. RIH & retag w/ 300psi motor work at 5,543'. Backream to 5,200'. POH. LD mill, wear ring on face of mill. MU tapered pilot step mill. Lay down for the night. 8/14/2020 - Friday MU & RIH w/ 2" BHA w/ 2" side jet nozzle. Dry tag twice at 5,582'. Lay in 5bbls of 15% HCL from 5,582' to 5,300', let acid soak across cement sheath in casing & lower iso sleeve/fishing neck. POH. LD nozzle BHA, lots of oil on tools. MU & RIH with fishing BHA. Tag fill at 5,445' & 5,482' while RIH, work past by pumping. Tag lower iso sleeve at 5,535'. Attempt to latch, with friction bites only. POH. LD fishing BHA, GS has cement in collet/finger area with two bent collets & lots of oil on tools. RIH w/ 2" BHA w/ 2" side jet nozzle. Tag at 5,575' - unable to get deeper. Lay in soda ash pill & let neutralize. Jet/reciprocate across fishing neck profile, max rate. POH, pump to 5,050', max rate. Lay down for the night. 8/12/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MU & RIH w/ 2-1/8" BHA & 2.50" flat bottom mill BHA. Work through top iso sleeve. Dry tag twice at 5,430'. Mill from 5,430', quick ROP down to 5,525' (stall). Continue to mill ahead to 5,537' with no further progress (multiple stalls). Assume mill is at top of lower iso sleeve and can't enter fishing neck due to cement ramp on low side preventing entry by forcing mill onto fishing neck. POH. LD milling BHA, minor cement chunks on mill body, face has been chipped. MU & RIH with fishing BHA. Jar upper iso sleeve at 5,255' free a'er 8 jar licks and multiple wash attempts. POH, well is on a vac. LD upper iso sleeve, minor cement sheath on collets of iso sleeve. LD fishing BHA. MU & RIH with 3-1/8" BHA & full bore 3.66" flat bottom milling BHA. Dry tag at 5,348'. Backream to 5,200'. Mill from 5,348' to 5,432', firm cement. Wiper to 5,200'. RIH. Mill from 5,432' (hard cement) to 5533' (top of lower fishing neck on iso sleeve). POH & lay down for the night. 8/13/2020 - Thursday MU & RIH w/ 3-1/8" BHA & 3.67" tapered bottom mill w/ 2.67" flutes (to clean GS profile in fishing neck of iso sleeve), mill has brass indicator ring at no-go area w/ limited fluid by-pass for further pressure indication. Work through top iso sleeve at 5,282'. Dry tag twice at 5,536'. Mill to stall at 5,535', repeat w/ same results. Backream to 5200'. POH. LD milling BHA w/ positive indication of no-go on fishing neck (brass ring is worn). MU & RIH w/ 2-1/8" BHA w/ 2.37" rounded turbo scale mill. Dry tag at 5,539'. Mill with great difficulty (multiple stalls, indicating hard cement) to 5582' (~27' of rat hole below iso sleeve - corrected depth based on iso sleeve depth). POH. LD milling BHA (signs of wear & water courses packed w/ cement). Perform weekly BOPE test 309psi Low/ 4,264psi High(Pass). Lay down for the night. Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 Coil 50-029-23205-00-00 204-064 8/7/2020 11/1/2020 Hilcorp Alaska, LLC Weekly Operations Summary MU & RIH w/ 3-1/8" BHA w/ SLB bead blaster using 3.68" gauge ring. Tag at 5,555.7'e / 5,529'm. Pump sterling beads/gel slurry through bead blaster. Unable to make any additional hole. Appears to be top of isolation sleeve. Work bead blaster from tag depth of 5,530'm up to 5,275'. Pooh. Trim 150' of pipe. Make up & RIH w/ Baker 4" G-Spear Fishing BHA w/ Tempress. Tag at 5,555', unable to latch. Work tempress, still unable to latch or get any deeper. Pooh. Discuss job w/ OE. OE says to rig down. Plans will be made at a later date to return. Freeze Protect Coil w/ 44 bbls diesel. Freeze Protect Tbg w/ 44 bbls ( 2,500' tvd). Rig Down & release CTU. MU & RIH w/ 3-1/8" BHA & 3.67" tapered bottom mill w/2.87" flutes. Dry tag at 5,547.6. Mill to 5,544.8' w/ five stalls resulting in 5k overpull with loss of CTP on coil pick up - indicating inside the profile. Backream to 5,200'. POH. LD mill - wear makes on leading edge of taper cutters, wear on brass ring indicating cement sheath in tubing. MU & RIH w/ 3-1/8" BHA w/ cutter brush. Dry tag at 5,549.6' Mill to stalls at 5,546.8'. Backream to 5,200'. POH. LD cutter brush. MU & RIH w/ 3-1/8" Fishing BHA. Tag at 5,547'. Unable to latch or fire jars. POH. LD fishing BHA - minor wear marks on the GS collets - indicating hitting fishing neck. Lay down for the night. 8/18/2020 - Tuesday 8/17/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 Coil 50-029-23205-00-00 204-064 8/7/2020 11/1/2020 No operations to report. No operations to report. 8/22/2020 - Saturday No operations to report. 8/25/2020 - Tuesday 8/23/2020 - Sunday No operations to report. 8/24/2020 - Monday 8/21/2020 - Friday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. RAN 10'x3" PUMP BAILER, MULE SHOE FLAPPER 2 TIMES, MADE IT FROM 5,362' SLM TO 5,375' SLM, RECOVERED 1gal OF SAND, SECOND RUN CAME BACK W/ METAL MARKS ON BAILER BOTTOM. SET 4-1/2" CAT STANDING VALVE IN XN NIPPLE @ 5,047' SLM (5,036' MD), OAL: 28". ASSISTED LRS W/ COMBO MIT (pass), REFER TO JOB LOG FOR DETAILS. RAN 4-1/2" D&D HOLE FINDER DOWN & SET @ 4,960' SLM (4,949' MD), TESTED TUBING EVERY 500' UP TO 3,960' SLM (3,949' MD), FOUND IN TUBING BETWEEN 3,960' SLM (3,949' MD) - 4,460' SLM (4,449' MD). PULLED 4-1/2" CAT STANDING VALVE FROM XN NIPPLE @ 5,047' SLM (5,036' MD), ALL PACKING RECOVERED. WELL S/I ON DEPARTURE, DSO NOTIFIED. Hole in tubing between 3,960' SLM (3,949' MD) - 4,460' SLM (4,449' MD). 8/19/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. RAN KJ, DUAL 3.5" X MAGNETS, 2.5" X MAGNET 3 TIMES & RECOVERED 19lbs OF COIL SHAVINGS, S/D @ 5,241' SLM (5,230' MD), UNABLE TO WORK PAST, MADE IT DOWN TO 5,263' SLM ON THE SECOND RUN, TOOK 200lb OVER PULL TO COME FREE, S/D @ 5,170' SLM ON THE THRID RUN & WORKED TOOLS DOWN TO 5,263' SLM, UNABLE TO WORK PAST. RAN 3.75" CENT, 3' x 1-7/8" STEM, 4-1/2" 42BO (keys up) DOWN TO XD SS @ 4,985' SLM (4,974' MD), MADE 12 PASSES THROUGH CLEAN W/ OUT HANGING UP, 42BO PIN UNTOUCHED, SLEEVE IS CLOSED. WELL S/I ON DEPARTURE, DSO NOTIFIED. 8/20/2020 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. RAN 2'x1-7/8" STEM, 3.6" CENT, SAMPLE BAILER, S/D @ 5,264' SLM WORK TOOLS DOWN TO 5,272' SLM, RECOVERED 1/2cup OF SAND IN BAILER. LRS ATTEMPED TO PERFORM MIT-IA, DID NOT PASS REFER TO JOB LOG FOR DETAILS. MADE MULTIPLE BAILER RUNS W/ 10'x3" PUMP & DRIVE DOWN BAILERS, S/D ON FRIST RUN @ 5,275' SLM & MADE IT DOWN TO 5,372' SLM, RECOVERED TOTAL OF 5.5gal OF SAND, LAST 2 BAILER RUNS BAILERS WHERE EMPTY DUE TO STUCK FLAPPERS / BALL BOTTOM, RECOVERED 1 LARGE ROCK AND SMALL ROCK PIECE ON LAST RUN. Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 Coil 50-029-23205-00-00 204-064 8/7/2020 11/1/2020 WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. RAN KJ, 3.25" CENT, 3'x1-7/8" STEM, 3.5" CENT, 2'x1-7/8" STEM, SAMPLE BAILER & DRIFTED DOWN TO 5,343' SLM (5,354' MD), UNABLE TO WORK PAST, BAILER WAS EMPTY, LIGHT METAL MARKS ON 3.5" CENT. RAN HES 40 ARM CALIPER & LOGGED UP FROM T/D @ 5,260' SLM (5,249' MD) TO SURFACE AS PER PROGRAM (bad data). RAN HES 40 ARM CALIPER & LOGGED UP FROM T/D @ 5,260' SLM (5,249' MD) TO SURFACE AS PER PROGRAM (good data). WELL S/I ON DEPARTURE, DSO NOTIFIED. No operations to report. 9/26/2020 - Saturday No operations to report. 9/29/2020 - Tuesday 9/27/2020 - Sunday No operations to report. 9/28/2020 - Monday 9/25/2020 - Friday No operations to report. 9/23/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/24/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 Slick Line 50-029-23205-00-00 204-064 10/31/2020 11/1/2020 No operations to report. WELL S/I ON ARRIVAL, PT PCE 250L/2,500H. SET 4-1/2" CAT-STANDING VLV @ 5,028' SLM (5036' MD). RAN LEAK DETECT LOG AS PER PROGRAM. 120 FPM & 60' FPM PASSES FROM 5,020' SLM JUST ABOVE STANDING VLV TO 3,490' SLM. GOOD DATA, APPEARS LEAK MAY BE THROUGH SLIDING SLEEVE PER HES ENGINEER. PULLED 4-1/2" CAT-STANDING VLV @ 5,028' SLM (5,036' MD). (Pressure test surface lines 250/2,500psi)(Assist Slickline with LDL) Pumped 142 bbls 120* SW down TBG up IA taking returns to Production while SL logged. Freeze protected surface lines with 2 bbls 60/40. (Pressure test surface lines 250/2,500psi) Pumped 5 bbls 60/40 down Prod header. 10/31/2020 - Saturday No operations to report. 11/3/2020 - Tuesday 11/1/2020 - Sunday WELL S/I ON ARRIVAL, PT PCE 250L/2,500H. RAN 3.70"" CENT., 5' x 1-7/8" STEM, 4-1/2" 42-BO SHIFTING TOOL (keys facing up), JARRED 10 MIN TO SHIFT SLIDING SLEEVE CLOSED @ 4974' SLM (4974' MD). SET 4-1/2" CAT-STANDING VLV @ 5,028' SLM (5,036' MD). PUMPED ~15 BBLS 60/40 DOWN TBG. GOOD PRESSURE TEST TO 1,500 PSI ON TBG, IA REMAINED @ 0 PSI THROUGHOUT TEST. PULLED 4-1/2" CAT-STANDING VLV @ 5,028' SLM (5,036' MD). RAN 3.70" CENT., 5' x 1-7/8" STEM, 4- 1/2" 42-BO SHIFTING TOOL (keys facing down), JARRED 10 MIN TO SHIFT SLIDING SLEEVE OPEN @ 4,974' SLM (4,974' MD). SET 3" JET PUMP (sn# BP-1017, ratio=9C) W/ SCREEN (oal lih=71") ACROSS SLIDING SLEEVE @ 4,974' SLM (4,974' MD). JOB COMPLETE, PAD OP TO POP. 11/2/2020 - Monday 10/30/2020 - Friday No operations to report. 10/28/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/29/2020 - Thursday No operations to report. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Set CIBP Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: 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): 8,760'N/A Casing Collapse Conductor N/A Surface 2,090psi Production 4,790psi Liner 7,500psi Liner 7,500psi Liner 6,590psi 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: Operations Manager Contact Email:Abhijeet.Tambe@hilcorp.com Contact Phone: 777-8485 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 Abhijeet Tambe COMMISSION USE ONLY Authorized Name: 7,910psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 / ADL0025906 204-064 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23205-00-00 Hilcorp Alaska LLC Length Size 3,850' 8,760' 3,850' 1,081 N/A MILNE POINT / SCHRADER BLUFF OIL 112' 112' 12.6# / L-80 / TC-II TVD Burst 5,240' 8,430psi MD N/A 8,430psi 3,580psi 6,890psi 305' 3,895' 3,834' 305' 6,405' See Schematic 4-1/2" 112' 20" 10-3/4" 7-5/8" 3,105' 4-1/2"3,248' 6,405' 3,843' Authorized Signature: 8/5/2020 8,760'3,065' 4-1/2" 3,850' Perforation Depth MD (ft): See Schematic 4" HES TNT Packer & (3) ZXP Liner Top Packers and N/A 5,075(MD)/ 3,899(TVD), 5,239(MD)/ 3,958(TVD), 5,512(MD)/ 4,019(TVD) & 5,695(MD)/ 4,046(TVD) and N/A MILNE PT UNIT J-26 C.O. 477.05 7/31/2020 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. 8,635' 8,513' 3,082' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:12 am, Aug 03, 2020 320-319 Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517), ou=Users Date: 2020.07.31 15:00:46 -08'00' Chad Helgeson (1517) DLB 08/03/2020 dsr-8/3/2020 DSR-8/3/2020 X x MGR04AUG20 10-404 Comm q 8/4/2020 dts 8/4/2020 JLC 8/4/2020 RBDMS HEW 8/5/2020 Reservoir Abandonment Well: MPU J-26 Date: 07/30/2020 Well Name:MPU J-26 API Number:50-029-23205-00 Current Status:Oil Producer [Jet Pump]Pad:Milne Point J-Pad Estimated Start Date:August 5, 2020 Rig:Coiled Tubing Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:204-064 First Call Engineer:Abhijeet Tambe (907) 777-8485 (O) (907) 331-9184 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:WellEz Entry Required:Yes Current Bottom Hole Pressure:1,335 psi @ 4,000’ TVD (Last SBHP measured 03/05/2015) Maximum Expected BHP:1,481 psi @ 4,000’ TVD (30 day PBU extrapolation) MPSP:1081 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU J-26 was drilled in 2004 using Doyon 14 and completed as a tri-lateral in the Schrader Bluff NB, OA and OB sands with an ESP completion. The well was converted to Jet Pump using Doyon 16 in February 2014. The well has had a few jet pump change-outs since 2014. The well is currently active and making approximately 200 bopd and 800+ bwpd. Notes Regarding Wellbore Condition x Deviation at jet pump is 65.0°. x Deviation at upper window into the OA lateral is 75.1°. x Deviation at upper window into the OB lateral is 78.6°. x Deviation at liner hanger into the NB lateral is 87.0°. x Casing last tested to 3,600 psi for 30 min down to 5,165’ on 2/23/2014. x Tubing last tested to 3,500 psi for 30 min down to 5,187’ on 2/26/2014. x Jet Pump currently active. Recently set on 5/30/2020. x Last Fill Depth: Nitrified Cleanout to 8,719’ CTM on 10/04/2018. Objective: To abandon the entire Nb horizontal lateral with cement. Nb lateral path crosses upcoming wells I-39 injector and I-40 producer. The objective is to isolate this lateral from the proposed upcoming drill wells. Contingency is included if Nitrogen is necessary to clean out the well. Brief Procedure: Pre-Coil Procedure: 1. Shut-in well and slickline to pull jet pump before coil tubing unit moves onto the well. Coiled Tubing Procedure: Reservoir Abandonment Well: MPU J-26 Date: 07/30/2020 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank with 8.4 ppg source water. Setup tanks for flowback of nitrogen and sweeps (Nitrified FCO is a contingency if cannot reach TD) 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. 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 weekly BOPE test requirement. 3. RIH w/ 2.00” coil w/ diverter sleeve and set in OA LEM #2 profile (Lateral Entry Module) at 5,255’. POOH. 4. RIH w/ 2.00” coil w/ diverter sleeve and set in OB LEM #1 profile (Lateral Entry Module) at 5,543’. POOH. 5. RIH w/ 2.00” coil w/ball drop cementing nozzle to PBTD. (Coil was able to reach 8,719’ in 2018 with a nitrified FCO). a.Contingency: : If unable to reach bottom, RIH w/ 2.0” to 3.25” mill and extended reach cleanout BHA and cleanout to PBTD using 8.5 ppg 1% KCl w/liquid foamer and mix with Nitrogen. b. Min ID is 3.688” in the LEMs (Lateral Entry Modules) at 5,255” & 5,543” MD. 6. Begin to mix cement. Once blend is up 15.8 ppg, pump ±43 bbls of cement down the coil tubing. a. Volumes: i. Liner volume (4” blanks & screens): 38 bbls ii. Coiled Tubing (2”CT, 16,215 ft): ~45 bbls 7. Use source (fresh) water spacer 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. 9. Pull out of the cement as the last of the cement exits the nozzle. 10. PU to safety and attempt to squeeze away ±5 bbls of cement. Do not exceed 500 psi above circulating pressure. 11. Estimated TOC @ 5,700’ md. 12. Swap to contaminate and RIH to cleanout to 5,690’ MD. 13. POOH and circulate coil tubing clean as needed. 14. Wait on cement to gain 1000 psi compressive strength. 15. RIH w/nozzle BHA and tag top of cement at estimated ± 5,700’ MD. (If tag high, contact OE to decide Bridge Plug setting depth in next step). 16. Pressure test 1,500 psi, if unable to get passing test, and tag cement above top of perfs, contingency to set CIBP. 17. POOH. 18. RIH and set 4.5” 12.6# Bridge Plug at ± 5,650. 19. RIH w/ 2.00” coil w/ 4” GS spear retrieval tool and recover diverter sleeve set in OB LEM profile at 5,543’. POOH. 20. RIH w/ 2.00” coil w/ 4” GS spear retrieval tool and recover diverter sleeve set in OA at 5,255’. POOH. 21. PU to 2,500’ and freeze protect well if necessary. POOH w/ coil. 22. RD Coiled Tubing and ancillary equipment. 23. Turn well over to production. Attachments: Reservoir Abandonment Well: MPU J-26 Date: 07/30/2020 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Nitrogen Operations Procedure 5. Nitrogen & Foam Flow Diagram _____________________________________________________________________________________ Revised By: TDF 7/28/2020 SCHEMATIC Milne Point Unit Well: MPU J-26 Last Completed: 10/10/2019 PTD: 204-064 22 Cleanout NB lateral to 8,719’ CTM 10/4/2018 Tagged PBTDTD =8,760’ (MD) / TD = 3,850’(TVD) 20” 7-5/8” 18 19 10-3/4” 13 20 “OB” Lateral PBTD =8,760’(MD)/ PBTD =3,850’(TVD) “NB” Lateral 13 14 9 7 6 1 Orig. KB Elev.: 68.7’/ Orig. GL Elev.: 34.9’ RKB – Hanger: 30.27’ (Doyon 14) 13 “OA” Lateral 10 11 12 15 16 17 21 3 2 8 Min ID = 3.688” 4 5 Min ID = 3.688” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 3,105’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 6,405' 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 5,265’ 8,513’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 5,553’ 8,635’ 4” Liner “C” 9.5 / L-80 / IBT 3.548 5,695’ 8,760’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958 Surface 5,051’ 4-1/2” Tubing 12.6 / L-80 / TC-II 3.958 5,051’ 5,240’ LINER DETAIL 4-1/2” ‘OA’ Liner 12.6 / L-80 / IBT 3.958 5,259’ 8,513’ 4-1/2” ‘OB’ Liner 12.6 / L-80 / IBT 3.958 5,553’ 8,635’ 4” ‘NB’ Liner 9.35# / L-80 IBT 3.548 5,682’ 8,760’ JEWELRY DETAIL No Depth Item (All depths to Orig RKB) 14,974’4-1/2” XD Sliding Sleeve 12.6# 9Cr ***Set 9B JP on 5/30/20** 2 4,991’ 4.5" SGM, Tbg Porte, 12.6# TCII 3 5,022’ 7-5/8” x 4-1/2” Baker Premier Production Packer 4 5,036’ 4-1/2” XN Profile (3.725” Packing Bore ID) 5 5,043’ Overshot – Bottom @ 5,051’ 6 5,075’ 7-5/8” x 4-1/2” HES TNT Packer 7 5,115’ 4-1/2” X Profile (3.813” Packing Bore ID) 8 5,187’ 4-1/2” XN Profile (3.725” No-Go ID) 9 5,239’ Wireline Entry Guide (Btm at 5,240’) 10 5,228’ OA Lateral Tie Back Sleeve 11 5,239’ OA Lateral ZXP Liner Top Packer 12 5,255’ OA Lateral LEM #2 (Lateral Entry Module) –MIN ID = 3.688” 13 5,265’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 14 5,288’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 15 5,501’ OB Lateral Tie Back Sleeve 16 5,512’ OB Lateral ZXP Liner Top Packer 17 5,543’ OB Lateral LEM #1 (Lateral Entry Module) -MIN ID = 3.688” 18 5,553’ OB Lateral Hook Wall, Hanger above 7-5/8” Window 19 5,576’ OB Lateral Hook Wall, Hanger below 7-5/8” Window 20 5,695’ NB Lateral ZXP Liner Top Packer 21 5,717’ NB Lateral 7-5/8” x 5-1/2” Flex-Lock Liner Hanger 22 8,717’ NB Lateral 4-1/2” Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 497 sx PF “L”, 261 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 278 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 300’ MD Max Wellbore Angle = 74.0 deg @ 3,735’ MD 65 deg @ 4,960’ MD (Sliding Sleeve & Jet Pump) WELLHEAD Wellhead FMC Tubing Hanger, 11” x 4-1/2” TC-II Top & Bottom GENERAL WELL INFO API: 50-029-23205-00-00 Drilled and Completed by Doyon 14 – 5/31/2004 Convert to Jet Pump by Doyon 16 – 2/25/2014 R&R Jet Pump and Coil Cleanout – 10/4/2018 Tubing Cut/ Upper Completion By ASR1– 10/10/2019 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,270’ MD; Bottom @ 5,282’ MD; Angle @ top of window is 75 deg Top of “OB” Window @ 5,558’ MD; Bottom @ 5,570’ MD; Angle @ top of window is 78 deg _____________________________________________________________________________________ Revised By: AT 7/31/2020 PROPOSED Milne Point Unit Well: MPU J-26 Last Completed: 10/10/2019 PTD: 204-064 23 Cleanout NB lateral to 8,719’ CTM 10/4/2018 Tagged PBTDTD =8,760’(MD) / TD = 3,850’(TVD) 20” 7-5/8” 18 19 10-3/4” 13 20 “OB” Lateral PBTD =8,760’(MD)/ PBTD =3,850’(TVD) “NB” Lateral 13 14 9 7 6 1 Orig. KB Elev.: 68.7’/ Orig. GL Elev.: 34.9’ RKB – Hanger: 30.27’ (Doyon 14) 13 “OA” Lateral 10 11 12 15 16 17 22 3 2 8 Min ID = 3.688” 4 5 Min ID = 3.688” CIBP ± 5690’ TOC @ ± 5700’ 21 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 3,105’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 6,405' 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 5,265’ 8,513’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 5,553’ 8,635’ 4” Liner “C” 9.5 / L-80 / IBT 3.548 5,695’ 8,760’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958 Surface 5,051’ 4-1/2” Tubing 12.6 / L-80 / TC-II 3.958 5,051’ 5,240’ LINER DETAIL 4-1/2” ‘OA’ Liner 12.6 / L-80 / IBT 3.958 5,259’ 8,513’ 4-1/2” ‘OB’ Liner 12.6 / L-80 / IBT 3.958 5,553’ 8,635’ 4” ‘NB’ Liner 9.35# / L-80 IBT 3.548 5,682’ 8,760’ JEWELRY DETAIL No Depth Item (All depths to Orig RKB) 14,974’4-1/2” XD Sliding Sleeve 12.6# 9Cr ***Set 9B JP on 5/30/20** 2 4,991’ 4.5" SGM, Tbg Porte, 12.6# TCII 3 5,022’ 7-5/8” x 4-1/2” Baker Premier Production Packer 4 5,036’ 4-1/2” XN Profile (3.725” Packing Bore ID) 5 5,043’ Overshot – Bottom @ 5,051’ 6 5,075’ 7-5/8” x 4-1/2” HES TNT Packer 7 5,115’ 4-1/2” X Profile (3.813” Packing Bore ID) 8 5,187’ 4-1/2” XN Profile (3.725” No-Go ID) 9 5,239’ Wireline Entry Guide (Btm at 5,240’) 10 5,228’ OA Lateral Tie Back Sleeve 11 5,239’ OA Lateral ZXP Liner Top Packer 12 5,255’ OA Lateral LEM #2 (Lateral Entry Module) –MIN ID = 3.688” 13 5,265’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 14 5,288’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 15 5,501’ OB Lateral Tie Back Sleeve 16 5,512’ OB Lateral ZXP Liner Top Packer 17 5,543’ OB Lateral LEM #1 (Lateral Entry Module) -MIN ID = 3.688” 18 5,553’ OB Lateral Hook Wall, Hanger above 7-5/8” Window 19 5,576’ OB Lateral Hook Wall, Hanger below 7-5/8” Window 20 5,695’ NB Lateral ZXP Liner Top Packer 21 ±5690 CIBP 22 5,717’ NB Lateral 7-5/8” x 5-1/2” Flex-Lock Liner Hanger 23 8,717’ NB Lateral 4-1/2” Pack-off Bushing OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 497 sx PF “L”, 261 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 278 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 300’ MD Max Wellbore Angle = 74.0 deg @ 3,735’ MD 65 deg @ 4,960’ MD (Sliding Sleeve & Jet Pump) WELLHEAD Wellhead FMC Tubing Hanger, 11” x 4-1/2” TC-II Top & Bottom GENERAL WELL INFO API: 50-029-23205-00-00 Drilled and Completed by Doyon 14 – 5/31/2004 Convert to Jet Pump by Doyon 16 – 2/25/2014 R&R Jet Pump and Coil Cleanout – 10/4/2018 Tubing Cut/ Upper Completion By ASR1– 10/10/2019 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,270’ MD; Bottom @ 5,282’ MD; Angle @ top of window is 75 deg Top of “OB” Window @ 5,558’ MD; Bottom @ 5,570’ MD; Angle @ top of window is 78 deg Reservoir Abandonment Well: MPU J-26 Date: 07/30/2020 COIL BOPE Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic END 2-02 30 X 20 X 13д X 9з X 7 X 4 ½ Coil Tubing BOP Valve, Lower Master, WKM-M, 4 1/16 5M FE Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe Manual Gate 2 1/8 5M 2д" Single Stripper Crossover spool 4 1/16 10M X 4 1/16 5M Manual Gate 2 1/8 5M Tubing Adapter, 4 1/16 5M Pump-In Sub 4 1/16 5M 1502 Union Coil Tubing Unit Fluid Flow Diagram Cleanout w/ Nitrogen & Foam Updated 9/22/16 LEGEND: Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Check Valve Manual Choke Pressure Gauge 500 BBL KILL TANK Choke Manifold P 400 BBL UPRIGHT P Open VBR BLIND COIL PUMP 400 BBL UPRIGHT Open Closed Open Open Open Open Open Open Open P SW or KCL W/ FOAMER OR FRIC TION REDUCER 50 BBL FREEZE PROTECT TANK SW or KCL W/ FOAMER OR FRIC TION REDUCER To Flowline NITROGEN PUMP & TANK P COIL UNIT WITH 1.5” to 2.0” COIL 400 BBL UPRIGHT SEAWATER W/ DEFOAMER TRIPLEX THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY November 5, 2019 Mr. Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-19-033 Defeated Safety Valve System MPU J-26 (PTD 2040640) Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed Hilcorp Alaska LLC (Hilcorp)'s November 4, 2019 explanation regarding the defeated safety valve system on Milne Point Unit J-26. Hilcorp summarized the findings from its internal investigation and corrective actions that have been implemented to prevent recurrence of defeated well safety valve systems at Hilcorp-operated wells within Alaska. These actions address the concerns identified in the violation. The AOGCC does not intend to pursue any further enforcement action regarding the Milne Point Unit J-26 defeated safety valve system. Sincerely, :i� Jere m Price Chair, Commissioner cc: P. Brooks AOGCC Inspectors Hilcorp Alaska, LLC Chea Operationstions Manager 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8405 November 4, 2019 chelgeson@hilcorp.com Jeremy Price, Chair Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RECEIVED Re: Docket No. OTH 19-033 Defeated Safety Valve System NOV 0 4 2019 Milne Point Unit J-26 (PTD # 2040640) AOGCC �-+��++ Dear Commissioner Price: Hilcorp Alaska, LLC ("Hilcorp") responds to your October 16, 2019 letter regarding the defeated but untagged safety valve system (SVS) low pressure detection device on well MPU J-26. We provide details regarding how the defeated device was found, the cause of the incident and the corrective actions we have taken to prevent future occurrences. Description of Events Milne Point Well J-26 is a Jet Pump production well that recently had a rig workover performed to replace the corroded tubing. Following the successful workover and tie-in of the well, the well's safety systems were commissioned on 10/12/19. As part of the commissioning, LPS control and sensing lines are pressure tested. Additionally, the LPS is blocked in and pressured up above the 100 psi setpoint and then manually bled off to verify activation of the SVS control panel solenoid. On 10/13/19 a Pre -Startup Safety Review (PSSR) was initiated prior to well startup. The PSSR includes a checklist with verification that "All PT, PSL, PSH and PSHH sensing lines are open" which was marked as complete. Shortly after the PSSR, the well was placed on production. On 10/14/19 SVS performance testing of J-26 was conducted as part of normal semi-annual SVS testing at J -pad. While tying in to the LPS with the test gauge, the LPS tripped prematurely. While investigating why the LPS tripped, two needle valves on the LPS sensing line were found closed tightly at the flowline. The valves were opened and well's SVS was retested successfully. Cause of Incident The well sat with —40 psi on the production flowline from the time that the LPS was commissioned until after it was placed on production at 4:40 pm on 10/13/19. Until flowline pressures had increased in excess of 100 psi, the LPS should have remained in a tripped state. However the LPS remained pressured up prior to and through initial startup and did not trip again until the 10/14/19 Commissioner Price November 4, 2019 Page 2 of 3 performance test. Through the investigation, we found that the two sensing line needle valves (shown in the attached photograph) had been left blocked in since commissioning. For this to occur, the PSSR was not performed correctly and LPS sensing line was never verified as normal/open yet the PSSR was signed off as complete. The defeated LPS was not tagged and, were it tagged, should still not have been left unmanned with the well on production per Hilcorp policy and State regulation. This policy was violated and there were personnel actions taken with the operators involved. Actions Going Forward Personnel Actions Upon completion of the investigation, two operators have been reprimanded with written deficiencies in their employment records. These operators will be withheld from promotions or performance pay increases for one year. PSSR Modification Following a new completion or workover of a well at Milne Point, a PSSR is perfonned. One element of this PSSR is to verify that the low pressure switch (LPS) is normalized. The best method to verify normalization is to physically function the LPS. A function test including activation of the LPS, will be performed as part of the PSSR (highlighted in red on page 4 of attached PSSR). Safety Valve Training Modifications Current Hilcorp safety valve training includes Hilcorp policies with respect to tagging defeated SVS components and not leaving a defeated SSV or LPS unmanned with the well on production. Additional discussion will be added specific to needle valves used in safety systems and the opportunity they present for inadvertent defeat of the system. Tools such as function testing will be presented as ways to verify normalization. Additionally, Hilcorp's expectation for 100% compliance in SVS normalization will be included in the training along with potential disciplinary actions including termination for inadvertently defeated SVS. Upon completion of training revisions, Hilcorp will provide AOGCC with a demonstration of the training content. If you have any additional questions, please contact myself at 777-8405 or by email at chelgeson@hilcorp.com or Wyatt Rivard at 777-8547 or wrivard@hilcorp.com. Sincerely, HILCORPP ALASKA, LLC Chad Helgeson Operations Manager Commissioner Price November 4, 2019 Page 3 of 3 Attachments: - Photograph of MPU J-26 Low Pressure Switch Defeated Valve Locations. - Modified Production Startup Safety Review (PSSR) MPU J-26 Defeated root valves leading to Low Pressure Switch Milne Point Field Operations Jet Pump Well Start-up Safety Checklist Pape 1 of 9 WELL MPJ -25 FIELD OPERATIONS JET PUMP WELL START-UP SAFETY CHECKLIST TABLE OF CONTENTS The following items are to be included in the well start WELL START-UP SAFETY CHECKLIST folder: Items completed by Wellsite Supervisor: WTI Walkdown WELL START-UP SAFETY CHECKLIST. Jet Pump Start-up WELL START-UP SAFETY CHECKLIST. Jet Pump Normalization WELL START-UP SAFETY CHECKLIST. 4 blank well start logs. Engineered Jet Pump Ramp -Up Guideline The latest revised completion diagram. Brine weight Wireline work Complete BPV removed Has FCO been completed ( Maintenance Lead) or Tory and Shane. Well is operable in swiss Well P&ID Tree / Flowline Leak Test Complete Tree Greased If new well add to FP sheet If new well add to JP tracker sheet Verified with well integrity that well does or does not need an MITIA Board Operator has been notified wel;l is being BOL. Well Operations Coordinator: NOTE: SVS Test rithin 5 days of start • Production Wells must have a low pressure pilot actuation pressure equal to at least 50 percent of separator inlet pressure or 25 percent of the flowing tubing pressure, whichever is greater. Document Number: UPS -US -AK -ACT -MPU -CH -0004 Print Date: 11/4/1019 Milne Point Field Operations Jet Pump Well Start-up Safety Checklist Page 2 of 9 Part One FIELD OPERATIONS WTI WALK -DOWN This page needs to be completed prior to last WTI turnover sign off to ops. Well Start-up Safety Checklist For WELL MPJ -25 OBJECTIVE: The following checklist is provided as a tool to lead the pad operator through a walkdown of a new or recently worked -over well tie in. DATE INITIAL Well has been verified as Operable Status Prior to putting online. Field Production Operations: Date: DATE I INITIAL Lateral valves are installed correctly and insure valve indication plate is in line with steam.. The check valve orientation is correct. The W bleed and vents are physically installed per P&ID. All bull plugs are installed and tight. Confirm needle valve stem packing is snug. Cable trays and flowlines are supported properly. The choke is installed correctly . Sample port, TI, and all Pi's are installed in applicable ranges. All bolts are installed on the AWV, SSV body. UA and 0/A valves are tubed above the floor grating with block and bleed. Note: Operator is to install all gauges using 0-5000 psi The WHSDP system return valve to the reservoir tank is wire - sealed.. Make sure SSV barrel has correct rated PRV installed. All tags to critical equipment are properly installed. All pressure switches are installed, calibrated correctly and tagged. The floor grating is installed and safe. Housekeeping is in order and the cellar is clean. Exterior/Interior well house equipment is in order (doors close, etc.) Well House Sign in place, VERIFY flowlines Have snow delineators installed. if problems contact well support techs. Well Cellar New style drip liner installed around well head. Field Production Operations: Date: Document Number: UPS -US -AK -ACT -MPU -CH -0004 Print Date: 11/4/2019 Milne Point Field Operations Jet Pump Well Start-up Safety Checklist Page 3 of 9 Part Two FIELD OPERATIONS JET PUMP WELL START-UP SAFETY CHECKLIST Well Start -Up Safety Checklist for WELL MPJ -25 OBJECTIVE: The following checklist is provided as a tool to lead the pad operator through a safe start-up of a new or worked over well. DATE I INITIAL Confirm that all required documentation is in the WELL START-UP SAFETY CHECKLIST folder. The engineered start-up procedure has been read and is fully understood by the responsible operator. The WTI Turnover Log is completely signed -off indicating FCO Work is completed and signed off for wells group work to do their work.. The required wireline work has been performed and the BPV has been removed from the well. The surface heat trace is energized. All PT, PSL, PSH and PSHH sensing lines are open. Confirm all bleed ports, bleed lines, valves, etc. are closed prior to proceeding with leak testing of lateral lines and wellhead valves and piping. Master, h°,, uH, ano lateral valves are open. The WHSDP is functioning normally. SSV and AWV are open and blocked or capped with a fusible The initial SBHP, WHP, IAP and OAP are recorded on start-up (if applicable). IOq. All master cards are closed out. Set up chemical injection at well head per MPU Brine Recovery Procedure. Increase E.B. where necessary and work with board operator. Note: (this is for Completion's with 9.0 Brine or greater only.) A pre -job safety meeting is held before start-up. MANNED WELL START APPROVED BY: Field Production Operations: Date: Document Number: UPS -US -AK -ACT -MPU -CH -0004 Print Date: 11/4/2019 Milne Point Field Operations Jet Pump Well Start-up Safety Checklist Page 4 of 9 Part Three FIELD OPERATIONS JET PUMP NORMALIZATION POST START-UP SAFETY Checklist FOR WELL MPJ -25 OBJECTIVE: Certain safety features have been bypassed for a safe start up of the well in a manned condition. This checklist is to verify that all bypassed systems are returned to normal prior to leaving the well site. DATE I INITIAL Make a copy of WELL START-UP SAFETY CHECKLIST for well log book Return the original WELL START-UP SAFETY CHECKLIST folder to the MPU Well Ops Coordinator. Well Ops Coordinator to send copy of the start-up log to Anchorage engineering. Well Ops Coordinator to place the original WELL START-UP SAFETY CHECKLIST folder in the well file. Confirm chemicals returned to normal rate and chemical injection pump has been flushed with Diesel or Varsol at completion. UNMANNED (NORMAL) WELL OPERATIONS APPROVED BY: Field Production Operations: Date: Document Number: UPS -US -AK -ACT -MPU -CH -0004 Print Date: 11/4/2019 N i J d CL d ol 3 LO Cl) w 00 O y Cl) < L <a c ip LO o �7 N O LO O M +I O M X N X FL d N CL ` M 'I O `O y N N O a O a 00 p a O O v t 6 a a .- 00 O0 COO ON Q Q J LU IL a a C m P)o O X > 'N a AMo o o 'IT 0 ({ a� ro c M 00 00 \ R o O m >1 N U) O Y m o J Y T c (0 U N a N w C ` <O i i y N N O 00 O O U c t 6 .- 00 O0 COO ON N -O55 2 0- IL a a C m P)o X > 'N Z w 4) p a� ro c R o N k m >1 L U) c o Y m o J Y V c (0 U N a N w LL LO c N — -0 X (D '� J m = d V LL c i .O C N .N Q -0o m m w C7 p w 3 D ma LL a s x LL MHne Point Field Operations Jet Pump Well Start-up Safety Checklist Daae 6 of 9 BP Well Startup Log WELL MPJ -25 Date / / _. TOTAL BBLS PF Prod. POWER RATE PF Fluid FLUID (24 Date/Time PIP PDP WHT BHT B/D PSI Flow FTP Shakeouts hrs) COMMENTS Document Number: UPS -US -AK -ACT -MPU -CH -00004 Print Date: 11/4/2019 M'Me Point Field Operations Jet Pump Well Start-up Safety Checklist Page 7 of 9 BP Well Startup Log WELL MPJ -25 Date / / TOTAL BBLS PF Prod. POWER RATE PF Fluid FLUID (24 Date/Time PIP PDP WHT BHT B/D PSI Flow FTP Shakeouts hrs) COMMENTS Document Number: UPS -US -AK -ACT -MPU -CH -00004 Print Date: 11/4/2019 MYne Point Field Operations Jet Pump Well Start-up Safety Checklist Page 8 of a BP Well Startup Log WELL MPJ -25 Date / / TOTAL BBLS KRATE Prod. POWER Fluid FLUID (24 Date/Time PIP PDP WHFlow FTP Shakeouts hrs) COMMENTS Document Number: UPS -US -AK -ACT -MPU -CH -00004 Print Date: M.Nne Point Field Operations Jet Pump Well Start-up Safety Checklist Pape 9 of 9 BP Well Startup Log WELL MPJ -25 Date / / TOTAL BBLS PF Prod. POWER RATE PF Fluid FLUID (24 Date/Time PIP PDP WHIT BHT BID PSI Flow FTP Shakeouts hrs) COMMENTS Document Number: UPS -US -AK -ACT -MPU -CH -00004 Print Date: 11/4/2019 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY October 16, 2019 Mr. Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH 19-033 Notice of Violation Defeated Safety Valve System MPU J-26 (PTD 2040640) Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. o og cc. a laska. gov The Alaska Oil and Gas Conservation Commission (AOGCC) was notified on October 15, 2019 by Hilcorp Alaska LLC (Hilcorp) that the well safety valve system was found defeated at Milne Point Unit J-26. An AOGCC witness of Milne Point Unit J -pad safety valve system performance testing was waived. Failure to maintain an operable safety valve system is a violation of State regulations. The cause of this defeated safety valve system is currently being investigated. Information provided to AOGCC indicates the low-pressure detection device required by 20 AAC 25.265 was blocked at the flowline and was not tagged as defeated. The well had been recently placed on production following completion of a rig workover. Paragraph (m) of 20 AAC 25.265 establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. Defeating any component of the critical well safety valve system — except as provided in 20 AAC 25.265 — will not be tolerated. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written summary of Hilcorp's internal investigation report and describe what has or will be done in the future to prevent its recurrence at Hilcorp-operated fields in Alaska. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Jeremy M. Price Chair, Commissioner cc: P. Brooks AOGCC Inspectors Regg, James B (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, October 1S, 2019 3:38 PM �� fol"5 ko, `( To: Regg, James B (CED) Cc: Chad Helgeson; Alaska NS - Wells Foreman; John Barnes Subject: MPU 1-26 (PTD # 2040640) Defeated Low Pressure Switch Jim, As discussed, Hilcorp identified a defeated low pressure switch on Milne Point producer J-26 (PTD # 2040640) during our witness waived semiannual 1 -pad SVS testing performed on 10/14. The low pressure switch was found blocked in at the flowline but was not tagged as defeated. The well had recently been brought online during a RWO and, at this point, it appears the well was online for less than 24hrs in a defeated state. Hilcorp takes the defeated valve very seriously and is conducting an investigation. Investigation results including a timeline, how the pilot was left defeated, and what corrective actions may be implemented will be made available once complete. Thank You, WyattRivard I Well lntegfity Erwki -' ''i -. -43547 1 C: ('509)670-£3U� wrivard@hilcorp.com 3800 l:cnn:rpuint Drive, Sults 1400 1 Aurhural;r, AN 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. DATE 10/29/2019 204064 Debra Oudean Hilcorp Alaska, LLC 3 1 4 0 0 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL CD: HALLIBURTON MULTI -FINGER CALIPER 12 JUL 2019 IWMA01 FIELD DATA RECEIVED Nov 042019 AOGCC 7/30/201910:11AM Filefolder 7/3D/201910:10Ah4 Filefelder Please acknowledge receipt bysiqning and returning one copy of this transmittal or FAX to 907 777.8337 Received By: jzKDate:2d q STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVE® OCT 17 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Pull Tubing ✓ a u w Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casin 9 ❑ Coil Tubing FCO w 2 ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well❑✓ Re-enter Susp Well ❑ Other: Tubing Cut Q 2. Operator Name: Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Development Q Exploratory ❑ 204-064 3. Adtlress: Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 AK 9 50-029-23205-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025517 / ADL0025906 - MILNE PT UNIT J-26 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 8,760 feet Plugs measured N/A feet true vertical 3,850 feet Junk measured N/A feet 5,075, 5,239, Effective Depth measured 8,760 feet Packer measured 5,512 & 5,695 feet 3,899, 3,958, true vertical 3,850 feet true vertical 4,019 & 4,046 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,105' 10-3/4" 3,105' 305' 3,580psi 2,090psi Production 6,405' 7-5/8" 6,405' 3,895' 6,890psi 4,790psi Liner 3,248' 4-1/2" 8,513' 3,834' 8,430psi 7,500psi Liner 3,082' 4-1/2" 8,635' 3,843' 8,430psi 7,500psi Liner 3,065' 4" 8,760' 3,850' 7,910psi 6,590psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 / TC -II 5,240' 3,958' HES TNT & Packers and SSSV (type, measured and true vertical depth) (3) ZXP _TP 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: 115 52 131 7 213 Subsequent to operation: 202 86 352 1 1,748 229 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil pJ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 'U� Authorized Name: Chad Helgeson Contact Name: David Haakinsor—j— Authorized Title: Operations Manager Contact Email: dhaakinson(( hilcorD.conn Authorized Signature: Date 10/17/2019 Contact Phone: 777-8343 Form 10-404 Revised 4/2017gDMSt�°" OCT Z 2 2019 Submit Original Only ��/�q LLC Orifi. KB Bev.: 6&7'/Wg. GL Elev.: 34.9' RKB–Hanger 30.27 (Doyon 14) 10-3/4' Mn(0=2L725" Mnio=a725' •� 8 I 101 i 113 12'' j 14 - "CA'Late� 15 16 ,ts f ' 1s 1711 j 'CB' Lateral c: <'0 21 75/8" Y•H"�e21 TD=8,760' (MD) /TD=3,850 WM) PBTD=8,760' (lVD) / PBTD=3,850'(M) SCHEMATIC WELLHEAD Wellhead FMC Tubing Hanger, it 4-1/2' TC -II Top & Bottom Milne Point Unit Well: MPU J-26 Last Completed: 10/10/2019 PTD: 204-064 20" Cmt w/ 260 sx of Arcticset I in 42" Hole 10-3/4" Cmt w/ 497 sx PF "I _,,ass Class "G" m 13-1/2" Hale 7-5/8" Cmt w/ 278 sx Class "G" in 9-7/8" Hole CASING DETAIL TUBING DETAIL Tubing 12.6/L-80/TXP 3.958 Surface 5,051' Tubing 12L-80/TC-II 3.958 5,051' 5,240' 4-1/2" 'OA' Liner LINER DETAIL 4-1/2" 'OB'Liner 12.6/L-80/IBT 3.958 5,259' Wj� 12.6/L-80/IBT 3.958 5,553' 4` 'NB' I iner 9.35#/ L-80 lBT 3.548 5,682' IF1A/[I ov nrr.., vv[LL INCLINATION DETAIL M KOP @ 300' D ==I—Max Wellbore Angle = 74.0 deg @ 3,735' MD 65 deg @ q,960' MD (Sliding Sleeve &Jet Pump) I3LNLRAL WELL INFO ====Z— API: 50-029-23205-00-00 Drilled and Completed by Doyon 14 -5/31/2004 Convert to Jet PImp b Doyon 16 - 2/25/2014 22 R&R Jet Pomp and Coil Cleanout -10/4/2018 Tubing Cut/ Upper Completion By ASR1-10/10/2019 Cleanout NB lateral to 8,719' CTM 10/4/2018 Tagged PBTD Revised By: TDF 10/10/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPJ -26 E -Line 50-029-23205-00-00 1 204-064 8/23/2019 1 10/10/2019 Daily Operations. 8/21/2019- Wednesday No operations to report. 8/22/2019 - Thursday No operations to report. 8/23/2019 - Friday Drive from Deadhorse to MP J-26. MIRU Alaska E -Line. Open SSV and install fusible cap. T/I/0 = 0/0/0. M/U BOPs and lubricator. M/U 1'tubing punch and CCL.P/T to 1,000 psi with N2. RIH with tubing punch to 5,178' (deviated out). Log up from 5,178' to 5,000'. Correct+14' in order to tie in. Send tie in log to town engineer and get confirmation we are on depth. Shoot 1' tubing punch from 5,062.6' to 5,063.6'. Top of pup joint above Packer is at 5,060.6'. CCL to top shot is 5.8'. Stopped to fire at 5,056.8'. Punch is at 5,062.6' to 5,063.6'. POH with spent tubing punch to surface. At surface. Clear indication that punch fired. L/O tubing punch. P/U RCT cutter. T/I/O = 0/0/0. P/T to 1,000 psi with N2. RIH with cutter to 4,700'. Unable to pass. Deviation is 60 degrees+. Attempt multiple times. Unable to pass into higher deviated section of wellbore. POH to surface. Remove 3 blades from each centralizer in toolstring. Each centralizer now has only 3 blades left. T/I/O = 0/0/0. P/T to 1,000 psi with N2. RIH with cutter to 5,140' and deviated out. POH for tie in pass. Correct -6'. Tie in log matches first correlation pass perfectly. Perform cut at 5,065.6' (-10' above the packer). CCL to cut = 13'. Stopped at 5,053.6'.A14. Set anchor. P/U V to 5,5052.6'. CUT at 5,065.6' (approximately 10' above packer). POH to surface. Good indication of cut. RDMO. 8/24/2019 -Saturday No operations to report. 8/25/2019 -Sunday No operations to report. 8/26/2019- Monday No operations to report. 8/27/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number I Well Permit Number Start Date End Date MPJ-26 Pump/ ASR 50-029-23205-OO-QO i 204-064 8/23/2019 10/10/2019 10/2/2Q ns19-Wednesday No operatioto report. 10/3/2019-Thursday No operations to report. 10/4/2019-Friday No operations to report. 10/5/2019-Saturday MIRU Little Red pumping, test lines to 3500psi for good test. Open well, TBGpsi = 400, IApsi = 40, OApsi = 0. Bleed tubing to 20psi and backside to 0. Start pumping down tubing @ 5bpm w/ tbg pressure at 0 and IA at 50psi and climbing. Indicating U tube pressure from freeze protect. Open choke on backside to 50% open and continue pumping @ 5bpm. 80 bbls away tbg pressure @ Opsi and IA @ 130psi and break-over and start falling. Continue pumping getting good returns from backside with tbg pressure @ Opsi and backside falling 2psi per minute. Diesel returns mostly. Slow pump rate to 3-4 bpm with casing pressure falling to Opsi and tubing pressure @ Opsi. pump away 90 bbls source water and well on strong vac. Estimated returns @ 100bbls - mostly diesel. Install BPV, test hanger void to 5,000psi for good test (indicating hanger integrity). Prep for ASR to MIRU. Total bbls pumped = 380 for kill and circulation. ASR Start RDMO L-41, Prep To Mobilize to 1-26. RD workfloor, RD rig. start crane operations, Fly off work floor, NO annular, NO BOPE, NU Wellhead 11" SM FMC Gen V and test Void to 500psi Low/ 5000Psi High, RD Well but stairs, Load HCR lines, Load Well but and floor onto trailer. RD and Prep Mud Pits to be moved. load trailers with Misc Equipment, Prep camps to be loaded and moved. Road all equipment to J-26. Start unloading equipment from trailers. Spot in Mud Boat, Spot in and unload pits, Move Camps to location, Unload BOBE Change out Pipe rams to 2-7/8"-5" VBR, Lay containment. 10/6/2019-Sunday Crew swap and morning safety meeting. Continue to MIRU ASR. Roads and pads assisted with crane and trucks, Pull tree, Spot well house nipple up BOP, Spot Rig Floor continue spot and R/U pits, pumps, conex's, and ancillary equipment. Raised Derrick and latched lock pins. Ran all BOP lines, fluid lines, choke /kill lines. Took on 30 bbls F/W for BOP test, Sundry meeting both crews. Finish RU to BOPE Test. RU 6" flow line. spot in HPH make up test mandrills, Grease the mud cross and choke manifold. NU Spacer Spool. Conduct PM's On Rig oil and filters, Rig Namco and Durst, change Hydraulic Filters on the Rig, 100K Generator Oil and filters, 300K Generator Oil and filters. Pick up 3.5" Test mandrill, Fill stack with test fluid and work air out of the system. Conduct BOPE Test as Per sundry Blinds and VBRs to 250psi low/3,500psi high, Annular 250psi low 2 500 si high with 3.5" and 4/5" test mandrils. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP J_; Pump/ASR 50-029-23205-00-00 204-064 8/23/2019 1 10/10/2019 10/7/2019 - Monday Crew swaps and continue testing BOP'S as per sundry. 250 low and 3,500psi high test. Currently on test 4. During test 4 on BOP test PRV on accumulator failed. Start troubleshooting accumulator. Rig mechanic from I -rig called to ASR to assist. Electricians called as well. Replaced control value and PRV. Functioned Accumulator. Continued testing BOPE per sundry. Values 250-3,500psi, Rams 3500psi, Annular 250-,2500psi, Gas Detection and Koomey Drawdown. No failures were recorded. LD testing equipment. RU pipe handler and spotted pipe racks. PU handling tools to pull completion. Opened IA and confirmed backside was static. Pulled Test Plug/Tbg on a slight blow pumped 57 bbls down tbg and monitored tag on a vacuum. Pulled BPV. PU 2-7/8 EUE Landing Jtw/OX sub and screwed into hanger threads. BOLDS. PU on completion Unseated Hanger cont PU to 75k 10k over string weight at 65k. Continued trying to work tbg free with PU's to 120k with no luck. Contacted Pollard in route with RTC. Continued working string while waiting on EL. Safety MTG, Crew change. E/L Arrive on location. Do tailgate MTG» Determine that we need to swap out Landing joint in order to get clearance for 2.5" RCT and 2.62" Rollers. Swapped out with 4.5" landing jnt setting our Limitations to the rig limits of 150K. Decided to try and pull free one more time before rigging up E/L pulled up to 138K when tbg came free. pulled hanger to surface up wt. @ 58K . Pump 50 BBLS down the IA. Prep and lay down TBG hanger, pull tech line over sheave and tie into O'Mally spooler. POOH With 4.5" 12.6# L-80 TCII TBG with Tech Wire. Filling double Displacement on the way out. 47jnts on the rack. clean and Inspect HPH, Making grinding noise from pipe skate. clean off any ice and dirt and re -level the unit. Skate Chain is rubbing on chain guards. Cont. POOH With 4.5" 12.6# L-80 TCI I TBG with Tech Wire 98 jnts on rack. 10/8/2019 -Tuesday PJSM, Crew swaps serviced equipment. Continued POOH with 4-1/2' completion noticed the door on the elevators would not latch up on pin due to wear. Replaced latch with spare and sent worn door latch over the welding shop for repairs. Continued POOH with 4-1/2" completion tbg. LD 121 jts of 12.6#/L-80/IBT, X Nipple, XD Sliding Sleeve, Discharge Gauge, GLM and 123 cannon clamps. While send in jewelry for inspecting to re -stocking. Cleaned and cleared Rig Floor, Repositioned cat walk to handle the 4-3/4" Drill Collars. Racked and Tallied Yellow Jacket Clean-out assembly. Racked and Tallied 3-1/2" Workstring. PU the Handling tools for the Clean-out BHA. Swapped out Doyon's Hydraulic regulator fittings back to the rig fitting for the tangs. MU Yellow Jackets Clean-out BHA consisting of 6" SOD SHOE W/ INDICATOR PINS, 6" WP EXTENTION, 7 5/8 CASING SCRAPER, 4-3/4" LUB. BUMPER SUB, 4-3/4" OIL JARS, 6- EACH 4 3/4 DRILL COLLARS. TIH w/ Clean- out BHA and 3.5" 10.37# NC -31 work string. 31 jts RIH at crew change. Safety MTG, Crew change, service and inspect rig and equipment. had to tighten up bolts on TBG tong backups to stop a leak. Finish TIH w/ Clean-out BHA and 3.5" 10.37# NC -31 work string. total of 121 jnts 34' in the hole. Tag up @ 5,077' with wash pipe swallowed. Put 5K on it Dwn wt @ 31K. Putting TOF @ 5,066.56' Perfect. Just to make sure we kicked on swivel and rotated down very slow tagging in the same spot. Kick off swivel Pull off bottom and rig up to reverse circ. 350 Bbls down the I.A. Reverse circulate 360 BBIs of 8.3# source water @ 4 BPM Returns @ 50 BBLS. total of 53BBL total return. Bleed down and blow down lines. Adjust sprocket on HPH. POOH w/ Clean-out BHA and 3.5" 10.37# NC -31 work string pumping double displacement. Total of 81 jts out at report Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date I End Date MPJ -26 ASR1 50-029-23205-00-00 204-064 8/23/2019 1 10/10/2019 10/9/2019- Wednesday PJSM and crew change check fluids and service equipment. Safety latch on the wench line hook broke. Replaced hook and continued ops. Continued TOH w/3-1/2" workstring and clean-out BHA. LD 121 jts w/BHA on surface. BO/LD Yellow Jackets clean-out assembly, Indicator pins inside shoe shows that the tbg stump was swallowed. Cleaned and cleared rig floor. Prepare to run completion. Racked and tallied the completion jewelry and 4-1/2" completion tbg. PU handling tools for the completion and cannon clamps for the control line. Spotted the cable spooler and treaded the cable thru the sheave. PU/MU Production sealed Over Shot, XN-nipple w/RHCP Body, Baker Premier Packer, Suction Gauge connected cable and tested on rig floor to 5,000psi-good test, XD sliding sleeve in closed position. TIH with completion Jewelry on 4- 1/2" 12.6#/TXP BTC /L-80 tbg Tag up at 123 jnts 15.56' in. Space outs with 27.58' of 4.5" 12.6# TXP PUPS. Space out under 1 full jnt. Make up TBG hanger and splice in the Gauge Line. Pumping Treated PKR fluid total of 26 BBIs followed by 100 Bbls of untreated source water. 10/10/2019 - Thursday PJSM crew change, Landed tbg hanger 35k down observed weight drop to 34k when OS swallowed 3' of the tbg stump before landing completion. RILDS. Dropped ball and rod, BO/LD 4-1/2" landing joint. Filled tbg with 15 bbls of source water. Pressured up on tbg to 3,500psi and held 5 mins to set packer. Bled back pressure on tbg to 2,000psi held and charted for 30mins. Filled IA w/17 bbls of source water. Pumped 4bbls to pressure on IA to 3,100psi. Held and charted for 30 mins-good test. Bled off pressures.;Set the BPV, circulated stack with clean fluid. Blowdown circulating lines and discounted. Cleaned and organized rig floor. Prep To move to J-26. MO Pipe Handler and pipe racks. RD Rig floor, LD Mass and moved rig off Mudboat, start crane operations, Fly off work floor. Safety MTG, Crew change. Continue Crane Operations, Load work floor RD well but stairs. Load floor and well but onto trailer. load HCR lines on the Pit catwalk. NO BOPE and annular. Load BOPE lines. Tie onto the Production tree. Prep Tech. Line and wellhead to NU Tree. NU tree with R- 54 API Ring. Could not get a seal on API Ring. Tree bottoming out on the TBG Hanger. NO tree and swapped out R-54 with RX -54 Ring. NU tree and got a good void test S00psi/Low 5,000psi High. Test Void on J-25 test good. Continue to RDMO Rig and equipment. Begin Spotting in on 1-25. Spot Mud Boat and Pits. Spot in Rig, Accumulator trailer, Dog house and company man shack. 10/11/2019 - Friday No operations to report. 10/12/2019 -Saturday No operations to report. 10/13/2019 -Sunday No operations to report. 10/14/2019 - Monday No operations to report. 10/15/2019 -Tuesday No operations to report. Regg, James B (CED) From: Brooks, Phoebe L (CED) Sent: Thursday, October 17, 2019 1:18 PM To: Carl Linaman - (C) A C j 2dl ZA1t9 Cc: Regg, James B (CED) I Subject: RE: MIT 7-5/8" CSG and PKR Test Report MPU J-26 Attachments: MIT MPU 1-26 10-10-19 Revised.xlsx Carl, Attached is a revised report for MIT MPU 1-2610-10-i9 correcting the formatting, including additional notes, and changing the interval to "0". Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.g, From: Carl Linaman - (C) <clinaman@hilcorp.com> Sent: Saturday, October 12, 2019 6:27 AM To: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Cody Rymut - (C) <crymut@hilcorp.com>; Wade Hudgens - (C) <whudgens@hilcorp.com> Subject: MIT 7-5/8" CSG and PKR Test Report MPU J-26 Please see attached MIT Report on 7-5/8" CSG and PKR. Thanks and have a Great day. Thanks! Carl Linaman Company Rep, ASR #1 Hilcorp, Alaska Cell: 307-277-0813 Office: 907-685-1266 clinaman@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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to limreag,15.1 ka. we A013C0InsoectorsNalaska. oov: OPERATOR: FIELD I UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: chris.wallace0leaska. oov Well MPU J-26 Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040640 Typelnj N Tubing 0 2000 2000 2000 Type Test P Packer TVD 3905 BBL Pump 1.5 IA 0 3100 - 3100 - 3100 Interval O Test psi 3000 BBL Return 1.5 - OA 0 0 0 0 Result P Notes: Producer. MIT -IA per sundry 319-365. Pressure up TBG to 3500psl to set 7-516"PKR, Blood oR to 2000psi and hold 30Min. on It, Pressure up Annulus to 3100psi and Chad for Well Pressures: Pretest Initial 15 Min, 30 Min, 45 Min. 60 Min. PTD Typelnj TubingType Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min, 45 Min. 60 Min. PTO Typelnj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Nates: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTD Typelnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTOType lnl Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Typelnj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Typelnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Realm OA Result Notes: TYPE INJ Codes W=was, G = Gaa S = Slurry I = Increase wastewater N=Nm Ii rm9 TYPE TEST Cade. P = Pressure Test 0= Other (deaoribe In Notes) INTERVAL Codes 1=their Tear 4=Four Year Cycle V = Required Ey Variance o= other (desccee In notes) Form 10-026 (Revised 01/2017) MIT MPU J-26161619 Revised Result Co.. P = Pass F=Fail 1=inconclusive THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 City, State, Zip Re: Milne Point Field, Schrader Bluff Pool, MPU J-26 Permit to Drill Number: 204-064 Sundry Number: 319-365 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such 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, vro�� Daniel T. Seamount, Jr. Commissioner DATED this % day of August, 2019. 1iBDMS4" AUG 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS N APPLICATION FOR SUNDRY APPROV S 20 AAC 25.280 AUG 7 7 201l� A0Q , . 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑� Coil Tubing FCO w/ N2 ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing Cut 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 204-064 3. Address: 3800 Centerpoinl Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23205-00-00 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 ❑� MILNE PT UNIT J-26 9. Property Designation (Lease Number): 10. Field/Pool(s): ADI -0025517'/ ADL00259C MILNE POINT/ SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,760' 3,850' 8,760' 3,850' 1,043 WA N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,105' 10-3/4" 305' 305' 3,580psi 2,090psi Production 6,405' 7-5/8" 6,405' 3,895' 6,890psi 4,790psi Liner 3,248' 4-1/2" 8,513' 3,834' 8,430psi 7,500psi Liner 3,082' 4-1/2" 8,635' 3,843' 8,430psi 7,500psi Liner 3,065' 4" 8,760' 3,850' 7,910psi 6,590psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6# / L-80 / TC -II 5,240' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HES TNT Packer & (3) ZXP Liner Top Packers and N/A 5,075(MD)/ 3,899(TVD), 5,239(MD)/ 3,958(TVD), 5,512(MD)/ 4,019(TVD) & 5,695(MD)/ 4,046(TVD) and N/A 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: 8/29/2019 OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinso Authorized Title: Operations Manager Contact Email: dhaakinson hi or .COM Contact Phone: 777-8343 Authorized Signature: Date: 817/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission sothat a representative may witness Sundry Number: 6 I c 1 — 3 � S Plug Integrity ❑ BOP Test LVj Mechanical Integrity Test ElLocation Clearance ElOther: ) j 35oo PS'` �Cp * asw A``w"�� ` T �' e.tZ RBDMS. AJ Post Initial Injection MIT Req'd? Yes E]No ❑,�,/ AUG 1 3 pp�g Spacing Exception Required? Yes E] No F7 Subsequent Form Required: /Q-- 10 L.I APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: !J ✓✓ g- X- "i Submit Form and For�eJai r�q/ r/i1 Approved appli r IICaIZ". 1 ff0 lNoAsrrOm the data of approve. - /7' / Ad -j C b 9/p/Iq H Hilmm M.A., LG RWO —Tubing Changeout Well: MPU J-26 PTD: 204-064 API: 50-029-23205-00 Well Name: MPU J-26 API Number: 50-029-23205-00 Current Status: S/I —Tubing Leak Rig: ASR #1 Estimated Start Date: August 29`h, 2019 Estimated Duration: 5 Days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 204-064 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: Maximum Expected BHP: Max. Anticipated Surface Pressure: Original RKB: Max Inc. (Within Work Interval): Max DLS: BPV Type: 1,309 psi @ 3,858' TVD 1,429 psi @ 3,858' TVD 1,043 psi 30.2' (Doyon 16) 65° @ 4,896' MD 6.6°/100 ft @ 952' MD 4" CIW "H" 6.52 PPGE I Downhole Gauge 7.12 PPGE 130 -day PBU Extrapolation Gas Column Gradient (0.1 psi/ft) Brief Well Summary: Milne Point producer J-26 was drilled in May 2004, and completed in the OA, OB, and NB sands. The well was last worked over in 2014 and has been a stable 200 BOPD producer until early July 2019, when a tubing leak developed resulting in the loss of drawdown from the jet pump. The leak was identified to exist between 2.680' MD and 2,695' MD. A subsequent caliper survey of the tubing indicated significant wall loss along many of the other tubingjoints. Notes Regarding the Well & Design: Subsequent well -work resulted in a passing MIT -IA of the 7-5/8" casing to 2500 psig on 7/10/19. Note that the newly installed XN Nipple will render the X Nipple (3.813" ID) at 5'LL5 MD, and XN Nipple (3.725" ID) at 5,187' MD inaccessible for plugs. ' o This is to allow for proper safety factor in hydraulic setting of retrievable plug. Offset Injector Support: SI 7 days prior to RWO o J-17: Online, injecting 1000 BWPD 0 1-19: Online, injecting 900 BWPD RWO Objective: 1. Pull Tubing String 2. Cleanout Run and dress tubing stub 3. Run anew 4-1/2" tubing completion with jet pump jewelry 4. Obtain passing MIT -IA Pre -Rig Procedure 1. MIRU E -Line Unit a. RIH w/ GR/CCL and RCT Cutter b. RIH and log uphole from 5,200' MD (below 3.725" XN Nipple). c. Pull uphole and tie into top of TNT packer @ 5,075' MD i. Compare CCL with tubing tally dated 2-25-14 ii. Find 14.8' Pup joint above packer RWO —Tubing Changeout Well: MPU J-26 PTD: 204-064 H&.p p Alaska, LU API: 50-029-23205-00 d. Fire RCT cutter 4' below top connection of the 14.8' joint. i. Approximate depth is ±5,064' RKB. _ b` i JK9 e. POOH and confirm fired RCT cutter. Y �( f. RDMO E -line 2. Clear and level pad area in front of well. Spot rig mats and containment. 3. RD well house and flowlines. Clear and level area around well. 4. RU Little Red Services Pump. Setup reverse out skid, returns tank, and additional upright tanks as needed. 5. Pressure test lines to 3,000 psi. 6. Bullhead 8.3 ppg source water down tubing to formation. a. Tubing volume to top of OA lateral: 81 bbls 7. Bullhead 8.3 ppg source water down the IA to formation. 8. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 9. RD Little Red Services Pump and reverse out skid. 10. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD crane. a. Make scribe mark on tree for orientation for re -installation. b. Function test all prior to arrival of AOGCC inspectors. 11. NU BOPE house. Spot mud boat. Workover Procedure: 12, MIRU ASR #1 Workover rig, ancillary equipment and lines to returns tank. 13. Pull BPV after confirming zero surface wellhead pressure. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.3 ppg source -water prior Zulling BPV. Set TWC. 14. Test BOPE to 250psi Low/ 3,500psi High, annular to 250psi Low/3hQtrpsi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 3-1/2" & 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) n Ril.rn Alaska, LL RWO—Tubing Changeout Well: MPU J-26 PTD: 204-064 API: 50-029-23205-00 f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 16. Bleed any pressure off casing to returns tank. Pull TWC. 17. RU spooler for tech -wire control line for downhole gauge pull. 18. MU 4-1/2" landing joint and BOLDS. a. Have E -line on stand-by with a 4-1/2" tubing RCT cutter in the event the tubing does not pull free. 19. Unseat hanger and pull over string weight on tubing and confirm free. a. Circulate as needed after confirming tubing is free. b. Replace blast rings as needed. The wellhead specialists have 4-1/2" blast rings in stock. c. Tubing was cut above the packer at ±5,064' MD. d. Anticipated PU weight: 56 k -lbs accounting for buoyancy. e. Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. f. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 20. Pull the 4-1/2" tubing from ±5,064' MD. a. Cannon clamps were installed on every collar per 2014 RWO. No clamp count recorded. b. Number all joints. c. Send tubing to G&I for cleaning and disposal. d. Inspect sliding sleeve, X -nipple, and GLM for possible re -stocking. i. Note condition of pipe in report. Denote depths of any external corrosion. Photograph and file pictures. 21. MU Yellow -Jacket cleanout assembly on 3-1/2" workstring with following equipment: a. 6" OD Shoe. b. Washover pipe with indicator pins for swallowed tubing stub. c. 7-5/8" Casing Scraper d. 4-3/4" Bumper Jar e. 4-3/4" Oil Jars f. 4-3/4" Drill Collars 22. RIH to ±5,064' MD and wash down to ±5,072' MD. a. Important to denote depth of final tag. Will only have 2' of travel on overshot for final completion and space out. b. Reverse circulate fluids down IA up work -string. Do not swap to forward circulation. 23. Reciprocate from 5,064' to 5,020' and circulate 2x bottoms up from 5,060' MD. 24. POOH and lay down cleanout BHA assembly. a. Report results of indicator pins and prepare for space out of completion. 25. Call out Schlumberger to run downhole gauges on completion. 26. PU 4-1/2" tubing completion and space out as followed: a. Tubing Overshot RWO -Tubing Changeout Well: MPU J-26 PTD: 204-064 Macara Alaska. LU API: 50-029-23205-00 b. Pup Joint: 4-1/2" L-80 tubing c. 4-1/2" XN Nipple (3.725" ID) w/ RHC plug body d. Pup Joint: 4-1/2" L-80 tubing e. Retrievable Packer (7-5/8" x 4-1/2" Baker Hughes Premier Packer) f. Pup Joint: 4-1/2" L-80 tubing g. Suction Gauge h. Pup Joint: 4-1/2" L-80 tubing i. 4-1/2" XD Sliding Sleeve (Closed Position): F j. Pup Joint: 4-1/2" L-80 tubing k. -124 joints 4-1/2" L-80 tubing I. Tubing hanger 27. Run tubing completion in hole, stopping @ 5,050' MD. 28. Tag top of tubing stub and space out for tubing hanger. 29. Prior to seating overshot, reverse circulate 26 bbls of 1%CRW (or equivalent corrosion inhibitor) source water, followed by 106 bbls of untreated source water down IA to spot corrosion inhibited fluid between packers. a. This will spot corrosion inhibited fluid between packers and up to sliding sleeve. 30. After pumping fluid, RIH to depth seating overshot on tubing stub. a. Overshot should be minimum 3' over 4-1/2" tubing stub. 31. After seating overshot, pick up slowly to neutral weight. Should have approximately 24-30" of travel. 32. Obtain pick-up and slack -off weights and note band/clamp summary. 33. Land the tubing hanger. Terminate downhole gauge wire. 34. Drop ball and rod and allow to fall on seat in RHC plug body in XN nipple. 35. Pressure up tubing to 2600 psis as per Baker Hughes to set the packer. a. Initial activation pressure: 1,350 psig b. Final Setting Pressure: 2,000 psig 36. Perform a tubing test to 2600 psig for 30 minutes. 37. Bleed tubing to 2000 psig 38. Pressure IA up to 3000 psig and perform a Charted MIT -IA for a minimum target pressure of 2700 psi for: min a. Notification to the AOGCC for witnessed -pest needs to be submitted 24 hrs prior to conducting test. k � . � �✓- A i,),4-1 ''`~ 39. Bleed tubing and inner -annulus pressures to zero. l� 40. RILDS and LD landing joint. S�.Y:li:J9t� 42. Test tubing hanger void to 500 psig low / 5000 psig high. 43. RD Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. Post WorkoverProcedure: 44. RD mud boat. RD BOPE house. 45. RU crane. ND ROPE. Pull BPV. Set TWC. 46. NU 4-1/16" 5,000# tree and adapter flange and test to 500 psi low/5,000 psi high. H Hil.ro Alaska. LU 47. Pull TWC. RD crane. 48. Move returns tank and rig mats. 49. Turn well over to wells team for post rig slickline work. 50. RU Slickline a. Pull Ball & Rod from X -Nipple b. Shift open XD Sliding Sleeve c. Pump freeze protect (if well is not BOL within 24 hours). i. Pump 92 bbls of diesel or 60/40 ii. RU jumper and allow freeze protect to U-tube. d. Install jet pump in XD sliding sleeve. e. RD Slickline. f. Turn well over to operations. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic RWO — Tubing Changeout Well: MPU J-26 PTD: 204-064 API: 50-029-23205-00 K T1ilcorP Alaeka, LLC SCHEMATIC WELLHEAD Wellhead FMC Tubing Hanger, 11"x Orig. KB Elev.: 68.7/ Orig. GL Elev.: 34.9' 1 1 4-1/2" TC -II Top & Bottom Milne Point Unit Well: MPU J-26 Last Completed: 2/25/2014 PTD: 204-064 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42" Hole 30-3/4" Mw/ 497 sx PF "L", 261 sx Class "G" in 13-1/2" Hale Cmt w/ 278 sx Class "G" in 9-7/8" Hole CASING DETAIL Type Wt/Grade/Conn ID Top Btm onductor 92/H-40/Welded N/A Surface 112' Surface 45.5/L-80/BTC 9.950 Surface 3,105' oduction 29.7 / L-80 / BTC -MOD 6.875 Surface 6,405' .iner "A" 12.6/L-80/IBT 3.958 5,265' 8,513' iner "B" 12.6 / L-80 / IBT 3.958 5,553' 8,635' .iner "C" 9.5 / L-80 / IBT 3.548 5,695' 8,760' TUBING DETAIL Tubing 12.6/L-80/TC-II 3.958 Surface 5,240' LINER DETAIL )A' Liner 12.6/L-8IBT 3.958 5,259' 8,513' )B' Liner 12.6/ L-80/0/IBT 3.958 5,553' 8,635' 413' Liner 9.35#/L-80IBT 3.548 5,682' 8,760' JEWELRY DETAIL Item (All depths to Orig RKB) 4.1/2" KBG-2 GLM 4.500" x 1" (Dummy Valve Set 3/31/14) 4-1/2" NDPG-C Multi -drop Discharge Gauge (3.833" ID) 4-1/2" XD Sliding Sleeve (Open) 4-1/2" NDPG-C Single -drop Intake Gauge (3.958" ID) 4-1/2" X Profile (3.813" Packing Bore ID) 7-5/8" x 4-1/2" HES TNT Packer 4-1/2" X Profile (3.813" Packing Bore ID) 4-1/2" XN Profile (3.725" No -Go ID) Wireline Entry Guide (Btm at 5,240') OA Lateral Tie Back Sleeve OA Lateral ZXP Liner Top Packer OA Lateral LEM #2 (Lateral Entry Module) OA Lateral Hook Wall, Hanger above 7-5/8" Window OA Lateral Hook Wall, Hanger below 7-5/8" Window OB Lateral Tie Back Sleeve OB Lateral ZXP Liner Top Packer 08 Lateral LEM #1 (Lateral Entry Module) OB Lateral Hook Wall, Hanger above 7-5/8" Window OB Lateral Hook Wall, Hanger below 7-5/8" Window NS Lateral ZXP Liner Top Packer NB Lateral 7-5/8" x 5-1/2" Flex -Lock Liner Hanger NB Lateral 4-1/2" Pack -off Bushing WELL INCLINATION DETAIL KOP @ 300' MD Max Wellbore Angle = 74.0 deg @ 3,735' MD 65 deg @ 4,960' MD (Sliding Sleeve & Jet Pump) LATERAL WINDOW DETAIL Vindow @ 5,270' MD; Bottom @ 5,282' MD; Angle @ top of window is 75 deg Jindow @ 5,558' MD; Bottom @ 5,570' MD; Angle @ top of window is 78 deg TD=8,76d(MD)/TD=3,85a(TVD) Cleanout NB lateral to 8,719' CTM PBTD=8,7W(MD)/PBTD=3,850'(TVD) 30/4/2018 Tagged PBTD GENERAL WELL INFO API: 50-029-23205-00-00 Drilled and Completed by Doyon 14-5/31/2004 Convert to Jet Pump by Doyon 16 — 2/25/2014 R&R Jet Pump and Coil Cleanout— 10/41/2018 Revised By: DAH 8/7/2019 H corn Alaska. LLC Orig. KB Elev.: 68.7/ Odg. GL Elev.: 34.9' PROPOSED WELLHEAD Wellhead FMC Tubing Hanger, 11" x 4-1/2" TC -II Top & Bottom Milne Point Unit Well: MPU J-26 Last Completed: 2/25/2014 PTD: 204-064 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42" Hole 10.3/4" Cmt w/ 497 sx PF "L", 261 sx Class "G" in 13-1/2" Hole 7-5/8" Cmt w/ 278 sx Class "G" in 9-7/8" Hole CASING DETAIL Type Wt/Grade/Conn ID Top Btm onductor 92/H-40/Welded N/A Surface 112' Surface 45.5/L-80/BTC 9.950 Surface 3,105' roduction 29.7/L-80/BTC-MOD 6.875 Surface 6,405' -iner"A" 12.6/L-80/IBT 3.958 5,265' 8,513' -iner"B" 12.6/ L-80/IBT 3.958 5,553' 8,635' -iner"C" 9.5/L-80/IBT 3.548 5,695' 8,760' Item (All depths to Orig RKB) 4-1/2" XD Sliding Sleeve 4-1/2" Suction Gauge 7-5/8" x4-1/2" Retrievable Packer 4-1/2" XN Profile (3.725" Packing Bore ID) Overshot — Bottom @ ±5,067' 7-5/8" x 4-1/2" HES TNT Packer 4-1/2" X Profile (3.813" Packing Bore ID) 4-1/2" XN Profile (3.725" No -Go ID) Wireline Entry Guide (Btm at 5,240') OA Lateral Tie Back Sleeve OA Lateral ZXP Liner Top Packer OA Lateral LEM #2 (Lateral Entry Module) OA Lateral Hook Wall, Hanger above 7-5/8" Window OA Lateral Hook Wall, Hanger below 7-5/8" Window OB Lateral Tie Back Sleeve OB Lateral ZXP Liner Top Packer OB Lateral LEM #1 (Lateral Entry Module) OB Lateral Hook Wall, Hanger above 7-5/8" Window OB Lateral Hook Wall, Hanger below 7-5/8" Window NB Lateral ZXP Liner Top Packer NB Lateral 7-5/8" x 5-1/2" Flex -Lock Liner Hanger NB Lateral 4-1/2" Pack -off Bushing WELL INCLINATION DETAIL KOP @ 300' MD Max Wellbore Angle = 74.0 deg @ 3,735' MD 65 deg @ 4,960' MD (Sliding Sleeve & Jet Pump) LATERAL WINDOW DETAIL indow @ 5,270' MD; Bottom @ 5,282' MD; Angle @ top of window is 75 deg indow @ 5,558' MD; Bottom @ 5,570' MD; Angle @top of window is 78 deg TD=8,760' (MD)/TD=3,850'(ND) Cleanout NB lateral to 8,719' CTM PBTD = 8,760' (MD) / PBTD = 3,85(YMO) 10/4/2018 Tagged PBTD GENERAL WELL INFO API: 50-029-23205-00-00 Drilled and Completed by Doyon 14 — 5/31/2004 Convert to Jet Pump by Doyon 16-2/25/2014 R&R Jet Pump and Coil Cleanout —10/4/2018 Revised By: DH 8/7/2019 TUBING DETAIL Tubing 12.6/L-80/TC-II 3.958 Surface ±5,067 Tubing 12.6/L-80/TC-11 3.958 ±5,060' 5,240' LINER DETAIL )A' Liner 12.6 / L-80 / IBT 3.958 5,259' 8,513' DB' Liner 12.6/ L-80/ IBT 3.958 5,553' 8,635' VB' Liner 9.35#/ L-801BT 3.548. 5,682' 8,760' JEWELRY DETAIL Item (All depths to Orig RKB) 4-1/2" XD Sliding Sleeve 4-1/2" Suction Gauge 7-5/8" x4-1/2" Retrievable Packer 4-1/2" XN Profile (3.725" Packing Bore ID) Overshot — Bottom @ ±5,067' 7-5/8" x 4-1/2" HES TNT Packer 4-1/2" X Profile (3.813" Packing Bore ID) 4-1/2" XN Profile (3.725" No -Go ID) Wireline Entry Guide (Btm at 5,240') OA Lateral Tie Back Sleeve OA Lateral ZXP Liner Top Packer OA Lateral LEM #2 (Lateral Entry Module) OA Lateral Hook Wall, Hanger above 7-5/8" Window OA Lateral Hook Wall, Hanger below 7-5/8" Window OB Lateral Tie Back Sleeve OB Lateral ZXP Liner Top Packer OB Lateral LEM #1 (Lateral Entry Module) OB Lateral Hook Wall, Hanger above 7-5/8" Window OB Lateral Hook Wall, Hanger below 7-5/8" Window NB Lateral ZXP Liner Top Packer NB Lateral 7-5/8" x 5-1/2" Flex -Lock Liner Hanger NB Lateral 4-1/2" Pack -off Bushing WELL INCLINATION DETAIL KOP @ 300' MD Max Wellbore Angle = 74.0 deg @ 3,735' MD 65 deg @ 4,960' MD (Sliding Sleeve & Jet Pump) LATERAL WINDOW DETAIL indow @ 5,270' MD; Bottom @ 5,282' MD; Angle @ top of window is 75 deg indow @ 5,558' MD; Bottom @ 5,570' MD; Angle @top of window is 78 deg TD=8,760' (MD)/TD=3,850'(ND) Cleanout NB lateral to 8,719' CTM PBTD = 8,760' (MD) / PBTD = 3,85(YMO) 10/4/2018 Tagged PBTD GENERAL WELL INFO API: 50-029-23205-00-00 Drilled and Completed by Doyon 14 — 5/31/2004 Convert to Jet Pump by Doyon 16-2/25/2014 R&R Jet Pump and Coil Cleanout —10/4/2018 Revised By: DH 8/7/2019 Milne Point ASR Rig 1 BOPE na . ,u..►., i.i.c 2019 11" BOPE Updated 1/05/2018 >_-7/8" x 5" VBR ind es OF ?kr, • • w\' 1�j, _6. THE STATE Alaska Oil and Gas bw -- '' �=9ConservationCommission "l��a Of A T A 1 - - 1 11J1 1�J� s t itt = 333 West Seventh Avenue 17 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 tft- ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC ' ` bt 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU J-26 Permit to Drill Number: 204-064 Sundry Number: 317-550 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, otA231 Hollis S. French L Chair 4.DATED this.-3° day of November, 2017. REE:273 L --{ . 1417 iiECEIVED • • NOV 2 O 2017STATE OF ALASKA OrS !t !2.21/, 2 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 ❑ Other Stimulate ❑ Pull Tubing ❑ Coil Tubing FCO w/N2 16 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El Alter Casing ❑ Other: Replace Jet Pump E, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q, 204-064 3.Address: 3800 Centerpoint Dr,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23205-00-00 , 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 El No ❑ f MILNE PT UNIT J-26 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517/ADL0025906 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,760' • 3,850' - 8,760' • 3,850' . 1,145 N/A N/A Casing Length Size MD ND Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,105' 10-3/4" 305' 305' 3,580psi 2,090psi Production 6,405' 7-5/8" 6,405' 3,895' 6,890psi 4,790psi Liner 3,248' 4-1/2" 8,513' 3,834' 8,430psi 7,500psi Liner 3,082' 4-1/2" 8,635' 3,843' 8,430psi 7,500psi Liner 3,065' 4" 8,760' 3,850' 7,910psi 6,590psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic 4-1/2" 12.6#/L-80/TC-II 5,240' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): HES TNT Packer&(3)ZXP Liner Top Packers and N/A 5,075(MD)/3,899(TVD),5,239(MD)/3,958(TVD),5,512(MD)/4,019(TVD)&5,695(MD)/ 4,046(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 1=1 Exploratory ❑ Stratigraphic❑ Development❑r . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/8/2017 OIL Q , 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 Authorized Title: Operations Manager Contact Email: sporhola(G7hiIcorp.com Contact Phone: 777-8412 Authorized Signature: ,oeDate: 11/20/2017 COMMISSION USE ONLY Conditions of approval: +otify Commission so that a representative may witness Sundry Number: 3ii. 550 Plug Integrity 0 BOP Test ❑ 111Mechanical Integrity Test 0 Location Clearance Other: * `-.54 1 -, 7cc',0 p 5 i //el ;,...:r..., Post Initial Injection MIT Req'd? Yes 0 No ❑ • t�•„ �-.. r Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 '�d i b i�r.°�` E v (+ L i Lf� APPROVED BY Approved by: 6Q1QCOMMISSIONER THE COMMISSION Date: rk '"I.,' ,i.` . ash 1i'/140- i/ /0y/�f /� //�� 0.2' •1 Submit Form and Form 10-403 Revised 4/2017 �°"" Ap rdved application is valid fdl 2I ttt 1Re�1 o'approval. Attachments in Duplicate • • • Well Prognosis Well: MPU J-26 Mean)Alaska,LL Date: 11J20J2017 Well Name: MPU J-26 API Number: 50-029-23205-00 _ Current Status: Oil Well [Jet Pump] Pad: Milne Point J-Pad Estimated Start Date: December 8th, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-064 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) ASE I�unr,��+tir� ``� �•w lob 1y41 ' COil Foam eleai o ' Current Bottom Hole Pressure: 1,545 psi @ 4,000' TVD (Last BHP measured 1/12/2014) Maximum Expected BHP: 1,545 psi @ 4,000' TVD (No new perfs being added, EMW= 7.43 ppg) MPSP: 1,145 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU J-26 was drilled in 2004 using Doyon 14 and completed as a tri-lateral in the Schrader Bluff NB, OA and OB sands with an ESP completion. The well was converted to Jet Pump using Doyon 16 in February 2014. The well has had a few jet pump change-outs since 2014.The well is currently active but continues to decline in production (suspected solids build-up). Notes Regarding Wellbore Condition • Deviation at pump is 65.0°. • Deviation at upper window into the OA lateral is 75.1°. • Deviation at upper window into the OB lateral is 78.6°. • Deviation at liner hanger into the NB lateral is 87.0°. • Casing last tested to 3,600 psi for 30 min down to 5,165'on 2/23/2014.1 • Tubing last tested to 3,500 psi for 30 min down to 5,187' on 2/26/2014. • Jet Pump currently active. Recently set on 6/25/2016. • Tubing Grade is L-80. Min ID is 3.725" in the 4-1/2". • Last Fill Depth: Cleanout to 8,726' CTM on 9/02/16. Objective: The purpose of this work is to cleanout the lower lateral (NB), and run a new Jet Pump on slickline. Brief Procedure: Pre-Coil Procedure: 1. Shut-in well and slickline to pull jet pump before coil tubing unit moves onto the well. Coiled Tubing Procedure: r If 2. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 3. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. • • Well Prognosis Well: MPU J-26 Meow Alaska,LI) Date:11/20/2017 a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. 4. RIH w/2.00" coil w/2.5" to 3.5" max OD wash nozzle and extended reach cleanout BHA(includes agitator) and cleanout to PBTD at+/-8,717' MD (in NB lateral). POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with Lateral Entry Modules (LEM) that require a lateral entry diverter to provide selective entry of the laterals. No diverter is planned to be run to selectively enter the OA or OB lateral. b. Min ID is 3.725" (XN profile at 5,187') in the 4-1/2"tubing. c. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. !v d. Contingency: If unable to circulate fluid to surface without significant losses (<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix rc'c with Nitrogen (see Nitrogen procedure and diagram). 5. Contingency: If unable to cleanout fill w/wash nozzle, RIH w/2.00" coil w/2.25"to 3.625" max OD motor and mill and extended reach cleanout BHA(includes agitator) and cleanout to PBTD at+/-8,717' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. b. Contingency: If unable to circulate fluid to surface without significant losses (<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 6. PU to 2,500' and freeze protect well. POOH w/coil. 7. RD Coiled Tubing and ancillary equipment. 8. Turn well over to production. Wireline Procedure: 9. MIRU Slickline. PT lubricator to 1,500 psi Hi 250 Low. 10. RIH and shift sliding sleeve open at+/-4,968' MD. 11. RIH and set jet pump in sliding sleeve profile at+/-4,968' MD. POOH. 12. RD Slickline. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen Flow Diagram Milne Point Unit . 1110 II Well: MPU J-26 SCHEMATIC Last Completed: 2/25/2014 Hilcorp Alaska,LLC PTD: 204-064 WELLHEAD OPEN HOLE/CEMENT DETAIL FMC Tubing Hanger,11"x 20" Cmt w/260 sx of Arcticset I in 42"Hole Wellhead 4-1/2"TC-II Top&Bottom 10-3/4" Cmt w/497 sx PF"L",261 sx Class"G"in 13-1/2"Hole Orig.KB Elev.:68.7'/Orig.GL Elev.:34.9' 7-5/8" Cmt w/278 sx Class"G"in 9-7/8"Hole RKB-Hanger:30.27'(Doyon 14) CASING DETAIL ia t L20' « Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,105' 7-5/8" Production 29.7/L-80/BTC-MOD 6.875 Surface 6,405' kv r; 4-1/2" Liner"A" 12.6/L-80/IBT 3.958 5,265' 8,513' ,. 4-1/2" Liner"B" 12.6/L-80/IBT 3.958 5,553' 8,635' VI 4" Liner"C" 9.5/L-80/IBT 3.548 5,695' 8,760' 0 1 TUBING DETAIL 10-3/4"It 4-1/2" Tubing 12.6/L-80/TC-II 3.958 Surface 5,240' LINER DETAIL 4-1/2" 'OA'Liner 12.6/L-80/IBT 3.958 5,259' 8,513' 4-1/2" 'OB'Liner 12.6/L-80/IBT 3.958 5,553' 8,635' 4" 'NB'Liner 9.35#/L-80 IBT 3.548 5,682' 8,760' JEWELRY DETAIL No Depth Item(All depths to Orig RKB) 1 2,500' 4-1/2"KBG-2 GLM 4.500"x 1"(Dummy Valve Set 3/31/14) 2 4,955' 4-1/2"NDPG-C Multi-drop Discharge Gauge(3.833"ID) 3 4,968' 4-1/2"XD Sliding Sleeve(8C let Pump 11/07/17) 4 4,978' 4-1/2"NDPG-C Single-drop Intake Gauge(3.958"ID) 5 5,050' 4-1/2"X Profile(3.813"Packing Bore ID) 2 6 5,075' 7-5/8"x 4-1/2"HES TNT Packer 7 5,115' 4-1/2"X Profile(3.813"Packing Bore ID) 3 8 5,187' 4-1/2"XN Profile(3.725"No-Go ID) i ii( 9 5,239' Wireline Entry Guide(Btm at 5,240') 4 10 5,228' OA Lateral Tie Back Sleeve N. -4 11 5,239' OA Lateral ZXP Liner Top Packer 12 5,255' OA Lateral LEM#2(Lateral Entry Module) 5 13 5,265' OA Lateral Hook Wall,Hanger above 7-5/8"Window e 14 5,288' OA Lateral Hook Wall,Hanger below 7-5/8"Window 6 15 5,501' OB Lateral Tie Back Sleeve 16 5,512' OB Lateral ZXP Liner Top Packer w * 17 5,543' 013 Lateral LEM#1(Lateral Entry Module) $ ' 18 5,553' OB Lateral Hook Wall,Hanger above 7-5/8"Window I,^ 10 `I 19 5,576' OB Lateral Hook Wall,Hanger below 7-5/8"Window NEI ID=3.725' ,s i c 20 5,695' NB Lateral ZXP Liner Top Packer n J. 0 21 5,717' NB Lateral 7-5/8"x 5-1/2"Flex-Lock Liner Hanger 22 8,717' NB Lateral 4-1/2"Pack-off Bushing 11 t' a WELL INCLINATION DETAIL a KOP @ 300'MD 4. ' 14 Max Wellbore Angle=74.0 deg @ 3,735'MD 12t ' ,�u _,,r- 65 deg @ 4,960'MD(Sliding Sleeve&Jet Pump) "OA"Lateral k; c:: > `3 N L LATERAL WINDOW DETAIL 15,,, so Top of"OA"Window @ 5,270'MD;Bottom @ 5,282'MD;Angle @ top of window is 75 deg 16 t$1 c ,'1g Top of"OB"Window @ 5,558'MD;Bottom @ 5,570'MD;Angle @ top of window is 78 deg i = ',, 19 -Ar' GENERAL WELL INFO 17ot. "OB" API:50-029-23205-00-00 Lated . ` Drilled and Completed by Doyon 14-5/31/2004 8! 20 Convert to Jet Pump by Doyon 16-2/25/2014 122 41 7 5/8" t �=yr F�-.GJ TD=8,760'(MD)/TD=3,850'(TVD) Cleanout NB lateral to PBTD=8,76('(MD)/PBTD=3,850'(1VD) 8,726'CTM 9/02/2016 Revised By:STP 11/20/2017 • • • I— teh 2 N I— a - z 2 O a W B c J 0 G C N r .r I s• w �/ \J / 91 ` , ga NAN s me a_ &t ti '3_a n - NI ,:TI,.. 2 N 'm IOU IN ® v7s �t m o0�F�➢ t tet . tt -T� `��a W J II II 1111 II 1 1111 IIII — - _d xam 0N Nm mo., ._ _ m' II{ I I co ^n c 0 tiO �s LII Jo _ � • E ~ — — . . O — _ o tet sea trt tet ws 3ef tet tei 2 `w N y II 2 Y LL h V1O N°ate 7 w II O 3N vNI IN W® ' na t - . a InC > > F '-i 23r i ; • • STANDARD WELL PROCEDURE IHilc„rpAlaska,I. C NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 411 0 ..:... ... g N O k. C Y W O_ W Y W O_ W to N O 3ao � � 3ao � u _ w co a o `o N OLL LL w OLL LL zi f /!� Z v B �Si ...N— E '..9 � 1X � ze '. L F F 3`D E a a ec _ x x o _ a_ o. _ Z : (u d > C. 3 • ''V g v �� m m Y r'; }.... > x �,7 C O o _ : W is ie 7 �G� '0.p e+ v in S•' Z }..•. ,.a W 7 E7 0..1 V at vC.'v 'ti ..t r 2 H v O 0 C w • o •• V il\ Lt,,?,,,..,..,.-- ,.v I 11141 D Doti Doti Z i V v ,1111 1111. W 3 r.."1111 ,�, t11 it till :: o uI , 4.; ��`! k, i ,...1 e4 N 11 Ie ',. y0. x L 1111 P = O O O 11.1 Z W W F LL I— O ce V d V u r O O O m r m O K in a 1 111"- cs W▪ W Q Q 3 o Q z W a L... 0 r H Y x 0 m al K 0 a o m m 0 0 a 0jr STATE OF ALASKA ' ALL OIL AND GAS CONSERVATION COMM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate L j Pull Tubing❑ Operations- CI �shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate [11 Alter Casing E Coil Tubir^ FCO w/N2 Q Plug for Redrill ❑ °rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Replace Jet Pump ❑Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development❑✓ Exploratory ❑ 204-064 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23205-00-4!._ 7.Property Designation(Lease Number): 8.Well Name and Number:. ECEIVED ADL0025517/ADL0025906 MILNE PT UNIT SB J-26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): SD-) 23 LUlb N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: AOGC Total Depth measured 8,760 feet Plugs measured N/A feet vv��44ee�� true vertical 3,850 feet Junk measured N/A feet 5,075,5,239, Effective Depth measured 8,760 feet Packer measured 5,512&5,695 feet 3,899,3,958, true vertical 3,850 feet true vertical 4,019&4,046 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,105' 10-3/4" 305' 305' 3,580psi 2,090psi Production 6,405' 7-5/8" 6,405' 3,895' 6,890psi 4,790psi Liner 3,248' 4-1/2" 8,513' 3,834' 8,430psi 7,500psi Liner 3,082' 4-1/2" 8,635' •37843''"..- �----ram-- 7,500psi Liner 3,065' 4" 8,760' 3,850' 7,910psi 6,590psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic r Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/TC-II 5,240' 3,958' HES TNT& Packers and SSSV(type,measured and true vertical depth) (3)ZXP LTP 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: 126 15 128 2,513 259 Subsequent to operation: 148 17 564 2,465 264 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 El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 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: 316-435 ��p Contact Stan Porhola Email sporhoIa C(77hilcorp.com �'v Printed Name Bo York Title Operations Engineer Signature '/7G ' . Phone 777-8345 Date 9/23/2016 Form 10-404 vised 5/201155 RBDMS (,c. SEP 2 6 2016 Submit Original Only H . • Milne Point Unit Well: MPU J-26 SCHEMATIC Last Completed: 2/25/2014 Ililcoeu Alaska,LICPTD: 204-064 " WELLHEAD OPEN HOLE/CEMENT DETAIL FMC Tubing Hanger,11"x 20" Cmt w/260 sx of Arcticset I in 42"Hole Wellhead 4-1/2"TC-II Top&Bottom 10-3/4" Cmt w/497 sx PF"L",261 sx Class"G"in 13-1/2"Hole Orig.KB Elev.:68.7/Orig.GL Elev.:34.9' 7-5/8" Cmt w/278 sx Class"G"in 9-7/8"Hole RKB-Hanger:30.27'(Doyon 14) CASING DETAIL Ls , jE': f Size Type Wt/Grade/Conn ID Top Btm 20 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,105' 7-5/8" Production 29.7/L-80/BTC-MOD 6.875 Surface 6,405' 4-1/2" Liner"A" 12.6/L-80/IBT 3.958 5,265' 8,513' 4-1/2" Liner"B" 12.6/L-80/IBT 3.958 5,553' 8,635' 4" Liner"C" 9.5/L-80/IBT 3.548 5,695' 8,760' l' 1 TUBING DETAIL 10-3/4" 4-1/2" Tubing 12.6/L-80/TC-II 3.958 Surface 5,240' LINER DETAIL 4-1/2" 'OA'Liner 12.6/L-80/IBT 3.958 5,259' 8,513' 4-1/2" 'OB'Liner 12.6/L-80/IBT 3.958 5,553' 8,635' 4" 'NB'Liner 9.35#/L-80 IBT 3.548 5,682' 8,760' JEWELRY DETAIL No Depth Item(All depths to Orig RKB) 1 2,500' 4-1/2"KBG-2 GLM 4.500"x 1"(Dummy Valve Set 3/31/14) 2 4,955' 4-1/2"NDPG-C Multi-drop Discharge Gauge(3.833"ID) 3 4,968' 4-1/2"XD Sliding Sleeve(7C Jet Pump 9/04/16) 4 4,978' 4-1/2"NDPG-C Single-drop Intake Gauge(3.958"ID) 5 5,050' 4-1/2"X Profile(3.813"Packing Bore ID) 6 5,075' 7-5/8"x 4-1/2"HES TNT Packer 7 5,115' 4-1/2"X Profile(3.813"Packing Bore ID) II 00". 3 8 5,187' 4-1/2"XN Profile(3.725"No-Go ID) 9 5,239' Wireline Entry Guide(Btm at 5,240') 4 10 5,228' OA Lateral Tie Back Sleeve Ill 5,239' OA Lateral ZXP Liner Top Packer 12 5,255' OA Lateral LEM#2(Lateral Entry Module) 5 13 5,265' OA Lateral Hook Wall,Hanger above 7-5/8"Window 14 5,288' OA Lateral Hook Wall,Hanger below 7-5/8"WindowAI it II Ni 5,501' OB Lateral Tie Back Sleeve 16 5,512' OB Lateral ZXP Liner Top Packer 17 5,543' OB Lateral LEM#1(Lateral Entry Module) ' 7 18 5,553' OB Lateral Hook Wall,Hanger above 7-5/8"Window 19 5,576' OB Lateral Hook Wall,Hanger below 7-5/8"Window / 8 20 5,695' NB Lateral ZXP Liner Top Packer 21 5,717' NB Lateral 7-5/8"x 5-1/2"Flex-Lock Liner Hanger T;9 22 8,717' NB Lateral 4-1/2"Pack-off Bushing i�. WELL INCLINATION DETAIL '13 KOP@300'MD 14 Max Wellbore Angle=74.0 deg @ 3,735'MD :., 1 65 deg @ 4,960'M D(Sliding Sleeve&Jet Pump) "OA'Lateral � LATERDA( AL WINDOW DETAIL 15 Top of"OA"Window @ 5,270'MD;Bottom @ 5,282'MD;Angle @ top of window is 75 deg 16 0 18 Top of"OB"Window @ 5,558'MD;Bottom @ 5,570'MD;Angle @ top of window is 78 deg 19 GENERAL WELL INFO 17 Lateral API:50-029-23205-00-00 13" 4..,,,:.,... 4a Drilled and Completed by Doyon 14-5/31/2004 \,...... Convert to Jet Pump by Doyon 16-2/25/2014 21 22 A "NB"Lateral 75/8 TD=8,760'(MD)/TD=3,850'(1YD) Cleanout NB lateral to PBTD=8,760'(MD)/PBTD=3,850'(TVD) 8,726'CTM 9/02/2016 Revised By:STP 9/16/2016 • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPJ-26 CTU5"29-23205-00-09' 0 029 23205 00 00 204-064 9/1/16 9/3/16 Daily Operations: 8/31/2016-Wednesday No activity to report. 9/1/2016-Thursday MIRU Halliburton AMU-01, 18,400' of tapered 1.75" CT. CV=35.4 bbls. Well flowing on arrival. PJSM. NU BOPE on pump in sub. PU 10' of lub. MU nozzle.Stab on BOPE;Start BOPE test. BOPE test complete. Shut in well at the wing. Shut in power fluid. MU Statewide CT tools and 4" GS. RIH. Set down at 4,972' ctmd (SS at 4,968'). Latch jet pump, PU and pull 7k over. Pull free. POOH. OOH. Shut in well.Jet pump recovered. MU and RIH with 4.5 SS shifting tool. RIH past SS to 5,000'. PUH through sleeve,see 1k over pull. RBIH past SS. PUH. No overpull. POOH. Load IA with power fluid. Pressure up to 2,500psi. Holding pressure. 10 minute test. Good. Bleed down to 500 psi. OOH,shut in well. L/D shifting tool. MU cleanout BHA. Stand injector back for night. Secure well. Return for cleanout in the morning. 9/2/2016-Friday Arrive on site. PJSM. MU and RIH dry with cleanout BHA 2.65" OD nozzle. Ran past OA, OB laterals with no weight bobbles. Assuming coil is in the NB lateral. Able to reach depth of 8,023' ctmd. Snubbing heavy- (-12k.) PUH (20k)to top of liner to initiate cleanout. No fill observed to 8,023' ctmd. Stop PUH at 5,600'. PJSM. PT hardline that was rigged up from the choke to the tiger tank to 1,000psi. Start pumping 1%x-slk water down coil with returns to tank. Open choke and wait for returns. Pumped round trip volume, unable to maintain steady returns with water. Returns-50%crude 50%water. Cool down N2. PT N2 line to 4000 psi. Bring N2 on at 500 scf/m,fluid at 1.5 bpm -equivalent rate of 2 bpm. RBIH from 5,600' pumping nitrofied fluid. Returns established (mostly water).At 7,750', started stacking pipe. At 7,943' coil went into lockup. Unable to get deeper. PUH to 6,000'. Attempt to get down running 100 fpm. No luck. Hit lockup at 8,077' ctmd. POOH. Call out agitator tool and more water with pipe on pipe FR added.Tag up. L/D BHA. MU 2nd BHA with agitator tool and 2.91" OD nozzle. Stab back on well. PT. RBIH to 4,000', Start pumping nitrofied 1%XSLK w/metal FR (2 bpm), establish returns after 100 bbls pumped. Continue RIH jetting.Able to reach depth of 8,726' ctmd and appear to tag. Original PBTD at 8,760' DD. Jet on bottom, unable to get deeper. Good returns of fluid and gas,with WHP at 200psi. Unable to determine amount of solids. Can't see in tank. POOH. PU was 16,000 lbs and clean.Shut off N2 at 1,900' while POOH to displace nitrofied fluid from coil. (159,000 SCF N2 pumped at average rate of 500 scf/m).Tag up.Allow well to blow down. Shut in and secure well. Stand injector back for night. Return in morning to open SS. No Activity- Daylight coil only. 9/3/2016-Saturday Arrive on site. PJSM. MU BHA with 4.5 SS shifting tool set for opening sleeve.Stab on well. PT. Open SSV, install fusible cap. Open Well to 25psi SITP. RIH with 4.5"SS shifting tool. Inner Annulus pressure =310 psi. Run thru SS at 4,970'ctmd. See annulus pressure drop to 0 psi.Small wt bobble on wt indicator. Make additional pass thru SS. Nothing observed. POOH. Pump 27 bbls 60/40 meth down tubing for well freeze protect.Tag up. Shut in and secure well. L/D tools. Shifting tool not ,/ sheared. RU N2 and blow down coil on Mast Unit-35 bbls recovered in tiger tank. RU N2 and blow down 2" coil unit that was used at C-15A -50 bbls fluid recovered in tiger tank. RDMO Halliburton N2 and CTU. 9/4/2016-Sunday No activity to report. 9/5/2016-Monday • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP J-26 CTU 50-029-23205-00-00 204-064 9/1/16 9/3/16 Daily Operations: No activity to report. 9/6/2016-Tuesday No activity to report. • V• OF T� e Ai/7,', THE STATE Alaska Oil and Gas �•'i ,, of//�� LAsKA Conservation Commission Sr£2 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 UFS Q. Main: 907.279.1433 A :S Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations ManagerSCANNED x1 s ,. Hilcorp Alaska, LLC cj. �% 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-26 Permit to Drill Number: 204-064 Sundry Number: 316-435 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair 5t DATED this 3) day of August, 2016. RBDMS (- SEP - 1 2016 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG2d 2016 APPLICATION FOR SUNDRY APPROVALS 11/ 4. 20 AAC 25.280 AO GC 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Coil Tubing FCO Q Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Replace Jet Pump❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: 1"1 t 2-�bs� i,��L.A....) Hilcorp Alaska LLC• Exploratory ❑ Development Q, 204-064 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23205-00-00 • 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 Q / MILNE PT UNIT SB J-26 • 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517/ADL0025906 ' MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,760' • 3,850'• 8,760' • • 3,850' 1,145 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,105' 10-3/4" 305' 305' 3,580psi 2,090psi Production 6,405' 7-5/8" 6,405' 3,895' 6,890psi 4,790psi Liner 3,248' 4-1/2" 8,513' 3,834' 8,430psi 7,500psi Liner 3,082' 4-1/2" 8,635' 3,843' 8,430psi 7,500psi Liner 3,065' 4" 8,760' 3,850' 7,910psi 6,590psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 4-1/2" 12.6#/L-80/TC-Il 5,240' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): , HES TNT Packer&(3)ZXP Liner Top Packers and N/A 5,075(MD)/3,899(TVD),5,239(MD)/3,958(TVD),5,512(MD)/4,019(TVD)&5,695(MD)/ 4,046(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/31/2016 ❑ ❑ ❑ Suspended CICommencing Operations: OIL WDSPL WINJ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El 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. Contact Stan Porhola Email sDorhoIaahilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 8/22/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \l c- - Q- �-( � Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance El Other: k 3 500 ps C ,'3o T C.S-F' (_ ,...w•� ) -. . Ci_.-...is illi k Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: t 0•-L1 04 RBDMS L� SEP - 1 2016 APPROVED BY Q Approved by: ti, "....20.e.s...754,..„ COMMISSIONER THE COMMISSION Date: D - 1 i hmi4 and Form o-403 a ised 112015 r v d ro s Lid for 12 months from the date of approval. y Attachments in Duplicate *8 gia6/ , /�/ ,..rig • • Well Prognosis Well: MPU J-26 Hileorp Alaska,LLQ Date:8/17/2016 Well Name: MPU 1-26 API Number: 50-029-23205-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point J-Pad Estimated Start Date: August 31st, 2016 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-064 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: 1,545 psi @ 4,000' TVD (Last BHP measured 1/12/2014) / Maximum Expected BHP: 1,545 psi @ 4,000'TVD (No new perfs being added, EMW= 7.43 ppg) MPSP: 1,145 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU J-26 was drilled in 2004 using Doyon 14 and completed as a tri-lateral in the Schrader Bluff NB,OA and OB sands with an ESP completion. The well was converted to Jet Pump using Doyon 16 in February 2014. The well has had a few jet pump change-outs since 2014.The well is currently active but continues to decline in production (suspected solids build-up). Notes Regarding Wellbore Condition • Deviation at pump is 65.0°. • Deviation at upper window into the OA lateral is 75.1°. - • Deviation at upper window into the OB lateral is 78.6°. • Deviation at liner hanger into the NB lateral is 87.0°. , • Casing last tested to 3,600 psi for 30 min down to 5,165'on 2/23/2014. • Tubing last tested to 3,500 psi for 30 min down to 5,187'on 2/26/2014. • Jet Pump currently active. Recently set on 6/25/2016. • • Tubing Grade is L-80. Min ID is 3.725" in the 4-1/2". • Last Fill Depth: No tags in any of the laterals. Objective: The purpose of this work is to cleanout the lower lateral (NB), and run a new Jet Pump on slickline. Brief Procedure: Pre-Coil Procedure: Q..�^'� 1. Shut-in well and slickline to pull jet pump before coil tubing unit moves onto the well. Coiled Tubing Procedure: 2. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. 3. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. Well Prognosis Well: MPU J-26 H,lcoru Alaska,LLI Date:8/17/2016 a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. Notify AOGCC 24 hours prior to testing BOPE. c. Submit 10-424 form within 5 days. 4. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,717' MD (in NB lateral). POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with Lateral Entry Modules (LEM)that require a lateral entry diverter to provide selective entry of the laterals. No diverter is planned to be run to selectively enter the OA or OB lateral. b. Min ID is 3.725" (XN profile at 5,187') in the 4-1/2"tubing. c. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. d. Contingency: If unable to circulate fluid to surface without significant losses(<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 5. Contingency: If unable to cleanout fill w/wash nozzle, RIH w/2.00" coil w/2.25"to 3.625" max OD motor and mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,717' MD. POOH. V Y#AD a. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help � remove solids from the liner. C,. . Contingency: If unable to circulate fluid to surface without significant losses (<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 6. PU to 2,500' and freeze protect well. POOH w/coil. 7. RD Coiled Tubing and ancillary equipment. 8. Turn well over to production. Wireline Procedure: 9. MIRU Slickline. PT lubricator to 1,500 psi Hi 250 Low. 10. RIH and shift sliding sleeve open at+/-4,968' MD. 11. RIH and set jet pump in sliding sleeve profile at+/-4,968' MD. POOH. 12. RD Slickline. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Nitrogen Operations Procedure 5. Nitrogen Flow Diagram H . IIIe WeMilnll: MPUPoint J-26Unit SCHEMATIC Last Completed: 2/25/2014 Ililtorp Alaska,LLC PTD: 204-064 WELLHEAD OPEN HOLE/CEMENT DETAIL FMC Tubing Hanger,11"x 20" Cmt w/260 sx of Arcticset I in 42"Hole Wellhead 4-1/2"TC-II Top&Bottom 10-3/4" Cmt w/497 sx PF"L",261 sx Class"G"in 13-1/2"Hole Orig.KB Elev.:68.7'/Orig.GL Elev.:34.9' 7-5/8" Cmt w/278 sx Class"G"in 9-7/8"Hole RKB-Hanger:30.27'(Doyon 14) CASING DETAIL 20 J L. Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,105' 61. 7-5/8" Production 29.7/L-80/BTC-MOD 6.875 Surface 6,405' 4-1/2" Liner"A" 12.6/L-80/IBT 3.958 5,265' 8,513' 4-1/2" Liner"B" 12.6/L-80/IBT 3.958 5,553' 8,635' 4" Liner"C" 9.5/L-80/IBT 3.548 5,695' 8,760' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 3.958 Surface 5,240' 10-3/4"4 c LINER DETAIL 4-1/2" 'OA'Liner 12.6/L-80/IBT 3.958 5,259' 8,513' 4-1/2" 'OB'Liner 12.6/L-80/IBT 3.958 5,553' 8,635' 4" 'NB'Liner 9.35#/L-80 IBT 3.548 5,682' 8,760' JEWELRY DETAIL No Depth Item(All depths to Orig RKB) 1 2,500' 4-1/2"KBG-2 GLM 4.500"x 1"(Dummy Valve Set 3/31/14) 2 4,955' 4-1/2"NDPG-C Multi-drop Discharge Gauge(3.833"ID) 3 4,968' 4-1/2"XD Sliding Sleeve(7C Jet Pump installed 6/25/16) 4 4,978' 4-1/2"NDPG-C Single-drop Intake Gauge(3.958"ID) 5 5,050' 4-1/2"X Profile(3.813"Packing Bore ID) 2 6 4 5,075' 7-5/8"x 4-1/2"HES TNT Packer 7 5,115' 4-1/2"X Profile(3.813"Packing Bore ID) lin 3 8 5,187' 4-1/2"XN Profile(3.725"No-Go ID) 9 5,239' Wireline Entry Guide(Btm at 5,240') 4 10 5,228' OA Lateral Tie Back Sleeve 11 5,239' OA Lateral ZXP Liner Top Packer 12 5,255' OA Lateral LEM#2(Lateral Entry Module) 5 ` 13 5,265' OA Lateral Hook Wall,Hanger above 7-5/8"Window 14 5,288' OA Lateral Hook Wall,Hanger below 7-5/8"Window t t i i15 5,501' OB Lateral Tie Back Sleeve 6 16 5,512' OB Lateral ZXP Liner Top Packer 17 5,543' OB Lateral LEM#1(Lateral Entry Module) 7 18 5,553' OB Lateral Hook Wall,Hanger above 7-5/8"Window 19 5,576' OB Lateral Hook Wall,Hanger below 7-5/8"Window _ X , a 20 5,695' NB Lateral ZXP Liner Top Packer 21 5,717' NB Lateral 7-5/8"x 5-1/2"Flex-Lock Liner Hanger 1, 9 22 8,717' NB Lateral 4-1/2"Pack-off Bushing 10" 11 , ,:INK WELL INCLINATION DETAIL ' IIII '13 KOP@300'MD Max Wellbore Angle=74.0 deg @ 3,735'MD 12 4"'�+.,;14. -I65 deg @ 4,960'MD(Sliding Sleeve&Jet Pump) OA"Lateral LATERAL WINDOW DETAIL 41 15 a Top of"OA"Window @ 5,270'MD;Bottom @ 5,282'MD;Angle @ top of window is 75 deg 16 «, 18iir Top of"OB"Window @ 5,558'MD;Bottom @ 5,570'MD;Angle @ top of window is 78 deg ''' 1: n :„ ,, ,,,,,. 19 GENERAL WELL INFO API:50-029-23205-00-00 Drilled and Completed by Doyon 14-5/31/2004 1 Convert to Jet Pump by Doyon 16-2/25/2014 p�\�"_'21 22 � ) "Ne'Lateral r - .f t 7-5/8" TD=8,760'(MD)/TD=3,850'(TVD) PBTD=8,760'(MD)/PBTD=3,850'(1VD) Downhole Revised:6/25/2016 Revised By:TDF 8/17/2016 H . • Milne Point Unit Well: MPU J-26 PROPOSED Last Completed: 2/25/2014 Mewl)Alaska.LLC PTD: 204 064 WELLHEAD OPEN HOLE/CEM ENT DETAIL FMC Tubing Hanger,11"x 20" Cmt w/260 sx of Arcticset I in 42"Hole Wellhead 4-1/2"TC-II Top&Bottom 10-3/4" Cmt w/497 sx PF"L",261 sx Class"6"in 13-1/2"Hole Orig.KB Elev.:68.7'/Orig.GL Elev.:34.9' - 7-5/8" Cmt w/278 sx Class"G"in 9-7/8"Hole RKB-Hanger:30.27'(Doyon 14) CASING DETAIL A ., Size Type Wt/Grade/Conn ID Top Btm 20 0., 20" Conductor 92/H-40/Welded N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,105' 7-5/8" Production 29.7/L-80/BTC-MOD 6.875 Surface 6,405' 4-1/2" Liner"A" 12.6/L-80/IBT 3.958 5,265' 8,513' 4-1/2" Liner"B" 12.6/L-80/IBT _ 3.958 5,553' 8,635' 4" Liner"C" 9.5/L-80/IBT 3.548 5,695' 8,760' i 1 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 3.958 Surface 5,240' 1x3/4"'A &" LINER DETAIL 4-1/2" 'OA'Liner 12.6/L-80/IBT 3.958 5,259' 8,513' 4-1/2" 'OB'Liner 12.6/L-80/IBT 3.958 5,553' 8,635' 4" 'NB'Liner 9.35#/L-80 IBT 3.548 5,682' 8,760' JEWELRY DETAIL No Depth Item(All depths to Orig RKB) 1 2,500' 4-1/2"KBG-2 GLM 4.500"x 1"(Dummy Valve Set 3/31/14) 2 4,955' 4-1/2"NDPG-C Multi-drop Discharge Gauge(3.833"ID) 3 4,968' 4-1/2"XD Sliding Sleeve(7C Jet Pump New) 4 4,978' 4-1/2"NDPG-C Single-drop Intake Gauge(3.958"ID) 5 5,050' 4-1/2"X Profile(3.813"Packing Bore ID) Fil 2 6 5,075' 7-5/8"x 4-1/2"HES TNT Packer 0. 7 5,115' 4-1/2"X Profile(3.813"Packing Bore ID) 3 8 5,187' 4-1/2"XN Profile(3.725"No-Go ID)CI' • 9 5,239' Wireline Entry Guide(Btm at 5,240') 4 10 5,228' OA Lateral Tie Back Sleeve 11 5,239' OA Lateral ZXP Liner Top Packer 12 5,255' OA Lateral LEM#2(Lateral Entry Module) 5 13 5,265' OA Lateral Hook Wall,Hanger above 7-5/8"Window 14 5,288' OA Lateral Hook Wall,Hanger below 7-5/8"Window J.Jtlt t 15 5,501' OB Lateral Tie Back Sleeve m 6 16 5,512' OB Lateral ZXP Liner Top Packer 104 17 5,543' OB Lateral LEM#1(Lateral Entry Module) 7 p.,.i, 18 5,553' OB Lateral Hook Wall,Hanger above 7-5/8"Window 11 19 5,576' OB Lateral Hook Wall,Hanger below 7-5/8"Window iltL g '•; 20 5,695' NB Lateral ZXP Liner Top Packer 21 5,717' NB Lateral 7-5/8"x 5-1/2"Flex-Lock Liner Hanger i 9 22 8,717' NB Lateral 4-1/2"Pack-off Bushing 10°' WELL INCLINATION DETAIL 111 i1 'x.713 KOP@300'MD t4 Max Wellbore Angle=74.0 deg @ 3,735'MD 12 x.:°£' 65 deg @ 4,960'MD(Sliding Sleeve&Jet Pump) OA'Lateral il W ,it, -y LATERAL WINDOW DETAIL 15 Top of"OA"Window @ 5,270'MD;Bottom @ 5,282'MD;Angle @ top of window is 75 deg 16 : 18 Top of"OB"Window @ 5,558'MD;Bottom @ 5,570'MD;Angle @ top of window is 78 deg t 19 GENERAL WELL INFO r 17 M-st API:50-029-23205-00-00 Drilled and Completed by Doyon 14-5/31/2004 Convert to Jet Pump by Doyon 16-2/25/2014 21 22 A 'NB'Lateral 7-5/8" TD=8,760'(MD)/TD=3,850'(TVD) PBTD=8,760'(MD)/PBTD=3,850'(TVD) Downhole Revised:6/25/2016 Revised By:TDF 8/17/2016 • • Milne Point Unit COIL BOPE MPU J-26 rirk,sp % fi a,W. 8/12/2016 MPU J-26 20x103/4x75/8x4'A Coil Tubing BOP To injection head 1 2.00"Double Stripper Lubricator 1 •',I, Blind �a 1/16 15 = Blind .11•f eI 011.11111:Mis =� Shear I I.�•`: :0° - C.' Iii Slip All _ Slip 11114'4 NEEm 0.1111 Pipe �� =- Mill ,'��I 091_1!1 Crossover spool 4 1/16 15M X 41/16 10M 11.1x9 Crossover spool uu 181 4 1/16 10M X 41/16 5M .9 Pump-In Sub 1 19 ° ® s , cy,41/165M MI i (° MI 1502 Union 1ke 11111111111111.1111 Manual Gate Manual Gate wii Valve,Swab,WKM-M, m 2 1/8 SM 2 1/8 5M 4 1/16 5M FE \00- -MEI IIII UM e Je't',(S\\ �\ 7 i A IV A J ! C, Valve,Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic . 111111101111111UI :I Valve,Lower Master,WKM-M, a c J 41/16 5M FE .�c;v' ...Tam... Tubing Adapter,41/16 5M 1�1 • • STANDARD WELL PROCEDURE Hileorp Alaska,in: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • I- = F t� _ R 2 J •C S y O .3.- ..:::-..! ! N N -+.1 L a o c m O G= • ... FL v - `C `° F•a C W 1' W =tz b ., F •� R 3 F- w .. .. Ci. 7 0. ..a 45. U w U a a 3 3 a ° . .. w 2 w o L � � g � � o Y ' max;�. a F Z 2 y > • l7 • w• v v• j > V ce C Mb k z Z c > :? g N w > C7 W U r f 0 g s 0 u u IN A 0 F f� 111 I1 IN Lu d N Z � � 1 w Q uY L- a) a = u rti c m m LAcc o_ V Y Z 4 H J J Y m O O to 2 r i STATE OF ALASKA A. KA OIL AND GAS CONSERVATION CC. JSSION ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: `Tx,t' I(_,,1,_; ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing IS Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ElChange Approved Program 0 Operation Shutdown 0 Stimulate-Other ElTime Extension Convert to Jet Pump 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 204-064 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 • 50-029-23205-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025906&025517 4 r MPJ-26 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point Unit/Schrader Bluff 11. Present well condition summary: Total depth: measured 8760' feet Plugs:(measured) None feet true vertical 3850' feet Junk:(measured) None feet Effective depth: measured • 8760' feet Packer: (measured) 5067' feet true vertical 3850' feet Packer: (true vertical) 3896' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34'- 112' 34'- 112' 1490 470 Surface 3070' 10-3/4" 35'-3105' 35'-2624' 5210 2480 Intermediate Production 6372' 7-5/8" 33'-6404' 33'-3896' 6890 4790 Liner 3065' 4-1/2"x 4" 5695'-8760' 4046'-3850' 8430/7910 7500/6590 Perforation Depth: Measured Depth: Sand Screens:6676'-8716' feet SCANNED JUL 1 6 2014 True Vertical Depth: Sand Screens:3840'-3848' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# L-80 5232' 3957' Packers and SSSV(type,measured and true vertical depth): 7-5/8"x 4-1/2"HES TNT L-80 Packer 5067' 3896' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: RBDMS MAY 14 2014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 600 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 0 Copies of Logs and Surveys run 15.Well Class after work: 0 Exploratory 0 Stratigraphic ®Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: • ®Oil 0 Gas 0 WDSPL ®Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Abby Warren,564-5720 Email:Abigail.Warren@bp.com N/A Printed Name: Joe LastufkTitle: Drilling Technologist Signature: k Phone: 564-4091 Date: 31�,5I 1 ' Form 10-404 Revised 10/2012 Submit Original Only V L,G' 5-/z 111 4 , t72%,,,y North America-ALASKA-BP Page 1 of 8 Operation Summary Report Common Well Name:MPJ-26 AFE No Event Type:WORKOVER(WO) Start Date:2/20/2014 End Date:2/26/2014 X4-00YP8-E:(1,680,000.00) Project:Milne Point Site:M Pt J Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/11/2004 12:00:00AM Rig Release:2/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292320500 Active datum:MPJ-26:(4968.70usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/20/2014 08:00 - 10:00 2.00 MOB P PRE PJSM,PREP FOR RIG MOVE -MOVE CUTTING TANK,CREW TRAILER AND FUEL TRAILER -WAIT FOR AMBIENT TEMP TO RISE TO-45 DEGREES 10:00 - 12:00 2.00 MOB P PRE PJSM TO MOVE RIG,NOTIFY PAD OPERATOR -RAISE CELLAR DOORS,MOVE RIG OFF WELL,STAGE RIG IN MIDDLE OF PAD 12:00 - 13:30 1.50 MOB P PRE PJSM,REMOVE BOPE FROM CELLAR AND PLACE ON CRADLE 13:30 - 15:00 1.50 MOB P PRE INSTALL REAR BOOSTER WHEELS 15:00 - 17:30 2.50 MOB P PRE PJSM FOR RIG MOVE 1-MOVE RIG FROM MPI-PAD TO MPJ AND `STAGE ON PAD 17:30 - 18:30 1.00 MOB P PRE REMOVE REAR BOOSTER WHEELS 18:30 - 19:30 1.00 MOB P PRE REMOVE BOP FROM CRADLE,INSTALL IN CELLAR AND SECURE 19:30 - 23:00 3.50 MOB P PRE PREP PAD BY DOYON FORKLIFT,DUE TO ROADS AND PADS COLD WEATHER RESTRICTIONS -CLEAR SNOW AROUND WELL,CLEAR DRIFTS AND PAD OUT FROM FRONT OF RIG -LAY MAT BOARDS 23:00 - 00:00 ' 1.00 MOB P PRE 1 PJSM,MOVE RIG AROUND PAD AND POSITION TO SPOT OVER WELL 2/21/2014 00:00 - 02:00 2.00 MOB P PRE PJSM,SPOT RIG OVER WELL MPJ-26 -SHIM WELL,SPOT CREW TRAILER.SECRUE STAIRS,ETC -ACCEPT RIG AT 02:00 02:00 - 03:30 1.50 WHSUR P j DECOMP PJSM.R/U CIRCULATING LINES TO TREE -SPOT FLOW BACK TANK,W/S RIG UP HARD LINE -R/U KILL MANIFOLD AND HARD LINES TO FLOW BACK TANK 03:30 - 05:00 1.50 WHSUR P DECOMP PJSM FOR TESTING -TEST ALL CIRCULATING LINES,KILL MANIFOLD,AND HARDLINES TO FLOW BACK TANK WITH DIESEL -250 PSI,3500 PSI,5 MIN,CHART -FUNCTION TEST REMOTE CONTROL OF SSV 05:00 - 06:30 1.50 WHSUR P DECOMP PJSM,M/U WELL SUPPORT LUBRICATOR TO TREE 1-TEST LUBRICATOR,250/3500 PSI,5 MIN, CHART 06:30 - 08:30 2.00 WHSUR P DECOMP PJSM FOR WELL KILL -TABLE TOP RIG EVAC DRILL,DISCUSSED EVAC IN EXTREME COLD WEATHER -WAIT FOR SECOND LOAD OF SEA WATER TO ARRIVE TO START WELL KILL Printed 3/10/2014 10:56:36AM North America-ALASKA-BP Page 2 of 8 Operation Summary Report Common Well Name:MPJ-26 AFE No Event Type:WORKOVER(WO) Start Date:2/20/2014 End Date:2/26/2014 X4-00YP8-E:(1,680,000.00) Project:Milne Point Site:M Pt J Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/11/2004 12:00:00AM Rig Release:2/26/2014 Rig Contractor.DOYON DRILLING INC. UW:500292320500 Active datum:MPJ-26:©68.70usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 11:30 3.00 KILLW P DECOMP BLEED OFF GAS I/A F/650 TO 0 PSI WITH NO FLUID RETURNS -PUMP 30 BBLS 8.5 SEA WATER,120 DEG D/N TUBING WITH NO RETURNS OUT I/A -PUMP BULL HEAD 128 BLS 8.5 SEA WATER 120 DEG DN TUBING,PRESSURE INCREASE ON I/A TO 150 PSI,INCREASE ON 0/A FROM 0 TO 400 PSI -PUMP 410 BLS 8.5 SEA WATER,120 DEG, D/N TUBING TAKING RETURNS FROM I/A -TOTAL FLUID RETURNED 214 BLS 11:30 - 12:00 0.50 KILLW P DECOMP MONITOR WELL 1-B/D ALL CIRC LINES 12:00 - 13:00 1.00 KILLW P DECOMP R/D ALL CIRC LINES -R/U SECONDARY KILL LINE TO IA FOR CONSTANT FILL -MAINTAIN CONSTANT HOLE FEED AT 20 BPH 8.5 PPG KWF 13:00 - 14:00 1.00 WHSUR P DECOMP PJSM,R/U W.S LUBRICATOR&PT 250/3500, SET TWC 14:00 - 15:30 1.50 WHSUR P DECOMP PREFORM ROLLING TEST ON TWC FROM BELOW T/500 PSI -P/T TWC F/ABOVE 250/4000 F/5 MIN CHART 15:30 - 17:30 2.00 WHSUR P DECOMP PJSM N/D TREE AND HANGER ADAPTER -CLEAN TBG HANGER -CHECK TUBING HANGER THREADS,9 RH 'TURNS,2 7/8"EUE 8RD THREADS 17:30 - 21:00 3.50 BOPSUR P DECOMP PJSM,N/U BOPE,CHOKE HOSE, TURNBUCKLES,MOUSE HOLE,RISER -M/U KOOMEY LINES,PERFORM KOOMEY SYSTEM PUMP TEST 21:00 - 22:30 1.50 BOPSUR P DECOMP R/U FLOOR VALVES,TEST JOINTS AND TEST EQUIPMENT -ATTEMPT PRELIMINARY BOP FLANGE AND BODY TEST AGAINST BLIND/SHEAR RAMS -BLIND RAMS WERE UNABLE TO HOLD PRESSURE 22:30 - 00:00 1.50 BOPSUR N RREP DECOMP PJSM,OPEN BLIND RAM DOORS AND INSPECT BY RIG MECHANIC -C/O BLIND/SHEAR RAMS -OA=20 PSI -24 HOUR FLUID LOSS=487 BBLS 8.5 PPG SEA WATER -MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH NO RETURNS 2/22/2014 100:00 - 03:00 3.00 BOPSUR N RREP DECOMP PJSM,CONT.C/O BLIND/SHEAR RAMS -CLEAN RAM CAVITY,MECHANIC INSPECTED DOORS AND WASH PLATE 03:00 - 04:00 1.00 BOPSUR P DECOMP FILL STACK,R/U TEST JOINTS AND TEST EQUIPMENT -PERFORM BODY/FLANGE/BLIND RAM TEST Printed 3/10/2014 10:56:36AM North America-ALASKA-BP Page 3 of 8 Operation Summary Report Common Well Name:MPJ-26 AFE No Event Type:WORKOVER(WO) Start Date:2/20/2014 End Date:2/26/2014 X4-00YP8-E:(1,680,000.00) • Project:Milne Point Site:M Pt J Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/11/2004 12:00:00AM Rig Release:2/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292320500 Active datum:MPJ-26:@68.70usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 10:00 6.00 BOPSUR P DECOMP PJSM,TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT -TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES -TEST ANNULAR WITH 2 7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH,5 MINUTES EACH,CHARTED -TEST 2 7/8"X 5"VARIABLE RAMS WITH 2 7/8" AND 4"TEST JOINT,250 PSI,4000 PSI,5 MIN, CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,4000 PSI,5 MIN,CHARTED -TEST WITH FRESH WATER -PERFORM ACCUMULATOR DRAW DOWN • ,TEST • -NO FAILURES -CHUCK SCHEVE OF AOGCC WAIVED STATES RIGHT OF WITNESS BOP TEST MAINTAIN CONTINUOUS HOLE FILL TO THE • IA DURING TEST @-20 BPH,8.5 PPG SEAWATER 10:00 - 11:00 1.00 BOPSUR P DECOMP R/D ALL TEST EQUIPMENT,BLOW DOWN LINES R/D TEST JOINTS AND FLOOR VALVES 11:00 - 14:00 3.00 EVAL N RREP DECOMP ATTEMPT TO PRESSURE TEST KELLY HOSE AND WASHPIPE PACKING -REMOVE WASHPIPE PACKING,MECHANIC INSPECT SURFACES AND 0-RINGS -CLEAN/DRESS SEALING SURFACES AND RE-INSTALL TEST KELLY HOSE AND WASHPIPE,250/ 4000 PSI,5 MIN EACH,GOOD TEST 14:00 - 15:30 1.50 WHSUR P DECOMP DRAIN BOP STACK,FLUSH TOP OF TWC -M/U OFF-SET LUBRICATOR TO HANGER TO PULL TWC • 15:30 - 17:00 1.50 EVAL N RREP DECOMP STOP OPERATION DUE TO LEAK DISCOVERED ON PIT#4,APPROX 2 BBLS SPILL ON RIG MATS -REMOVE SEAWATER FROM PIT AND INVESTIGATE SOURCE OF LEAK -REPAIR 3 HOLES IN BOTTOM OF MUD PIT#4 BY RIG WELDER 17:00 - 18:00 1.00 WHSUR P DECOMP TEST WELL SUPPORT LUBRICATOR -PULL TWC,R/D LUB 18:00 - 21:00 3.00 PULL P DECOMP PJSM,M/U LANDING JOINT TO HANGER -MOBILIZE AND R/U CENTRILIFT EQUIPMENT -HANG ESP SHEAVE AND TRUNK PJSM FOR PULLING HANGER TO RIG FLOOR •21:00 - 21:30 0.50 PULL P DECOMP PULL HANGER TO RIG FLOOR -PUWT=75K,SOWT=70K(40K BLOCK WT) -PULL AND CUT ESP CABLE AT BOTTOM OF FIRST FULL JOINT -PLACE SLICK PIPE ACROSS BOP -CLOSE ANNULAR AND LINE UP THRU GAS BUSTER Printed 3/10/2014 10:56:36AM North America-ALASKA-BP Page 4 of 8 Operation Summary Report Common Well Name:MPJ 26 AFE No Event Type:WORKOVER(WO) Start Date:2/20/2014 End Date:2/26/2014 X4-00YP8-E:(1,680,000.00) Project Milne Point Site:M Pt J Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/11/2004 12:00:00AM Rig Release:2/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292320500 Active datum:MPJ-26:@68.70usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 22:30 1.00 PULL P DECOMP CBU 1X THRU GAS BUSTER,5 BPM=1015 PSI -35 BBLS TO FILL HOLE,128 BBL LOSS ON CIRCULATION -STOP PUMPS,ENSURE NO PRESSURE UNDER BAG -OPEN ANNULAR,MONITOR WELL,WELL IS ON LOSSES -MAINTAIN CONSTANT HOLE FEED AT 20 BPH 8.5 PPG SEAWATER,NO RETURNS 22:30 - 23:00 0.50 PULL P DECOMP BLOW DOWN CHOKE AND TOP DRIVE -L/D HANGER AND LANDING JOINT 23:00 - 00:00 1.00 PULL P DECOMP PJSM,PULL 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION,STAND BACK IN DERRICK -F/5016'T/4716'MD -OA=40 PSI -24 HOUR FLUID LOSS=568 BBLS 8.5 PPG SEA WATER -MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH NO RETURNS 2/23/2014 00:00 - 00:30 0.50 PULL P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -CHECK CROWN SAVER 00:30 - 04:30 4.00 PULL P DECOMP PULL 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION,STAND BACK IN DERRICK -F/4016'T/ESP PUMP AND MOTOR -L/D JOINTS#92,93,97,98,102, 116,118,127, 135,140,141,145,147 04:30 - 07:30 3.00 PULL P DECOMP UD ESP PUMP AND MOTOR ASSY -SPOOL CABLE TO SPOOLING UNIT -CLEAR RIG FLOOR OF TOOLS 07:30 - 08:30 1.00 PULL P DECOMP R/D ESP SHEAVE AND TRUNK -CLEAR&CLEAN FLOOR 08:30 - 09:00 0.50 CASING P DECOMP INSTALL 7-1/16"WEAR RING,L/D RUNNING TOOL 09:00 - 12:00 3.00 CASING P DECOMP PJSM M/U BAKER EA RETRIEVAMATIC PACKER -RIH FROM SURFACE TO 3492' -PUW=57K/SOW=57K 12:00 - 12:30 0.50 CASING P DECOMP SERVICE INSPECT RIG FLOOR EQUIPMENT 12:30 - 14:30 2.00 CASING P DECOMP CONTINUE RIH W/BAKER TEST PACKER ON 2-7/8"X 4"F/3492'TO 5165' PUW=75K SOW=65K 14:30 - 16:30 2.00 CASING P DECOMP PJSM,R/U TO MIT-IA 7 5/8"L80 29.7#CASING BY 2-7/8"EUE TUBING -SET PACKER AT 5165'MD COE -MAINTAIN CONTINUOUS HOLE FILL WITH KWF DOWN TBG,DURING TEST -MIT-IA,3600 PSI 30 MIN,CHARTED,GOOD TEST -BLEED OFF PSI,TUBING FULL OF KWF, OPEN BAG,RELEASE PACKER 16:30 - 18:00 1.50 CASING P DECOMP CBU lX=1150 PSI -BLOW DOWN AND R/D ALL CIRC LINES -FLOW CHECK,WELL IS ON LOSSES 18:00 - 20:00 2.00 CASING P DECOMP PJSM,CUT AND SLIP 60'OF DRILLING LINE -CLEAN AND INSPECT INSIDE DRAW WORKS Printed 3/10/2014 10:56:36AM North America-ALASKA-BP Page 5 of 8 Operation Summary Report Common Well Name:MPJ-26 AFE No Event Type:WORKOVER(WO) Start Date:2/20/2014 End Date:2/26/2014 X4-00YP8-E:(1,680,000.00) Project:Milne Point Site:M Pt J Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/11/2004 12:00:00AM Rig Release:2/26/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292320500 Active datum:MPJ-26:@68.70usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20.00 - 00:00 4.00 CASING P DECOMP PJSM,POOH WITH TEST PACKER FROM 5165' MD -F/5165'T/2394'MD -PERFORM STATIC LOSS RATE=78 BPH -0A=10 PSI -24 HOUR FLUID LOSS=631 BBLS 8.5 PPG SEA WATER -MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH NO RETURNS 2/24/2014 00:00 - 00:30 0.50 CASING P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -SERVICE AND INSPECT PIPE SKATE 00:30 - 02:30 2.00 CASING P DECOMP POOH 1X1 WITH TEST PACKER FROM 5165' MD -L/D TUBING F/2394'T/SURFACE L/D BAKER TEST PACKER 02:30 - 03:30 1.00 EVAL P DECOMP PULL WEAR BUSHING -INSTALL TEST PLUG -R/U AUX KILL LINE TO IA,MAINTAIN CONSTANT HOLE FEED AT 20 BPH 03:30 - 04:00 0.50 EVAL P DECOMP INSTALL DUTCH RISER IN BOP STACK 04:00 - 06:00 2.00 EVAL P DECOMP PJSM,MOBILIZE SWS EQUIPMENT TO RIG FLOOR -R/U FULL PRESSURE CONTROL FOR CALIPER LOG SWS C/O TO DAY CREW 06:00 - 10:00 4.00 EVAL P DECOMP PJSM W/SWS DAY CREW -CONTINUE TO R/U PRESSURE CONTROL EQUIPMNET 10:00 - 10:30 0.50 EVAL P DECOMP PT SWS EQUIP.TO 250/3500 PSI FOR 5 CHARTED MIN.EA. 10:30 - 11:30 1.00 EVAL P DECOMP PULL SWS DUTCH RISER -PULL TEST PLUG -EST.LOSS RATE @ 75 BPH -INSTALL DUTCH RISER 11:30 - 13:30 2.00 EVAL P DECOMP M/U PDS LOGGING TOOL -TEST LUBRICATOR AT QUICK TEST SUB -RIH TO 1000',LOG UP TO SURFACE 13:30 - 15:00 1.50 EVAL P DECOMP R/D SWS FULL PRESSURE CONTROL EQUIPMENT CLEAR RIG FLOOR 15:00 - 18:00 3.00 RUNCOM P RUNCMP PJSM,R/U TO RUN 4 1/2"TC-11COMPLETION -R/U FULL TORQUE TURN EQUIPMENT, POWER TONGS -C/O TO LONG BALES,R/U STABBING BOARD 18:00 - 20:30 2.50 RUNCOM P RUNCMP M/U 4 1/2"HES TNT PACKER -M/U SLB SINGLE DROP GAUGE UNIT, SLIDING SLEEVE AND MULTI-DROP DISCHARGE GAUGE ASSY -CONNECT AND TEST SLB CAP LINE"I-WIRE" -BAKER LOC ALL CONNECTIONS BELOW PACKER Printed 3/10/2014 10:56:36AM North America-ALASKA-BP Page 6 of 8 Operation Summary Report Common Well Name:MPJ-26 AFE No Event Type:WORKOVER(WO) Start Date:2/20/2014 End Date:2/26/2014 X4-00YP8-E:(1,680,000.00) _ 1 Project:Milne Point Site:M Pt J Pad Rig Name/No.:DOYON 16 Spud DateTme:5/11/2004 12:00:00AM Rig Release:2/26/2014 Rig Contractor:DOYON DRILLING INC. UW:500292320500 Active datum:MPJ-26:(1268.70usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 00:00 3.50 RUNCOM P RUNCMP RUN 4 1/2"12.6#TC-11 L80 TUBING COMPLETION T/2155' -INSTALL CANNON CLAMP ON EVERY COLLAR VERIFY I-WIRE CONTINUITY EVERY 1000' -USE JET LUBE SEAL GUARD,TORQUE TURN T/3850 FTI#, -OA=0 PSI -24 HOUR FLUID LOSS=559 BBLS 8.5 PPG SEA WATER -MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH NO RETURNS 2/25/2014 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS DOUBLE CHECK COMPLETION RIG UP EQUIPMENT 00:30 - 08:00 7.50 RUNCOM P RUNCMP PJSM,RUN 4 1/2"12.6#TC-11 L80 TUBING COMPLETION -F/2155'T/5233'MD -PUW=95K/SOW=80K -NO-GO @ 5334'ON JOINT 121 08:00 08:30 0.50 RUNCOM P RUNCMP SPACE OUT,UD JOINTS 121/120/119 -P/U 5.78'&9.78'PUP JOINTS -P/U JOINT 119 08:30 - 09:30 1.00 RUNCOM P RUNCMP P/U HANGER,SLB/FMC TERMINATE I-WIRE 09:30 - 11:00 1.50 RUNCOM fi P RUNCMP LAND HANGER/FMC RILDS -L/D LANDING JOINT -FILL BACKSIDE W/50 BBLS CORR.INHIB. -BULL HEAD 23 BBLS CORR.INHIB DOWN IA 11:00 - 12:00 1.00 RUNCOM P I RUNCMP PT SURFACE LINES. -ATTEMPT TO SEAT BALD ROD&PT TBG -UNABLE TO OBTAIN PRESSURE 12:00 - 14:00 2.00 RUNCOM N DPRB RUNCMP DISCUSS OPTIONS WITH TOWN ENGINEERS AND THIRD PARTY PERSONEL 14:00 - 15:00 1.00 RUNCOM P RUNCMP R/D REMAINING TORQUE TURN EQUIPMENT -C/O TO SHORT BALES,R/D STABBING BOARD -M/U LANDING JOINT TO HANGER AND TOP - DRIVE 15:00 - 17:00 2.00 RUNCOM N DPRB RUNCMP WIAT ON FLUID VOLUME,.LOAD PITS -FMC REP BOLDS 17:00 - 19:00 2.00 RUNCOM N i DPRB RUNCMP PULL HANGER TO RIG FLOOR -PUMP DOWN TUBING AT 1-4 BPM=50-190 PSI,16 BBLS TO FILL,TAKE RETURNS UP ANNULUS -PULL PIPE UP 30',SHAKE DOWN IN AN ATTEMPT TO PLACE BALLAND ROD ON SEAT -UNABLE TO OBTAIN TUBING PRESSURE -TEST CAP I-WIRE LINE PER SLB REP= GOOD -LAND HANGER,FMC REP RILDS Printed 3/10/2014 10:56:36AM North America-ALASKA-BP Page 7 of 8 Operation Summary Report Common Well Name:MPJ-26 AFE No Event Type:WORKOVER(WO) Start Date:2/20/2014 End Date:2/26/2014 X4-00YP8-E:(1,680,000.00) Project:Milne Point Site:M Pt J Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/11/2004 12:00:OOAM Rig Release:2/26/2014 Rig Contractor:DOYON DRILLING INC. •UWI:500292320500 Active datum:MPJ-26:@68.70usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 20:30 1.50 RUNCOM N DPRB RUNCMP DISCUSS OPTIONS WITH TOWN ODE -R/U AND ATTEMPT TO REVERSE CIRCULATE AT 3 BPM -ANNULUS PRESSURED UP TO 960 PSI,NO RETURNS FROM TUBING,BLEED PRESSURE OFF -PUMP DOWN TUBING AT 2.5 BPM=190 PSI, 35 BBLS TO FILL,TAKE RETURNS UP ANNULUS DISCUSS OPTIONS WITH TOWN ODE 20:30 - 22:30 2.00 RUNCOM N DPRB RUNCMP CALL OUT SLICK LINE UNIT -PREP FOR WIRELINE,INSTALL DUTCH RISER -CONT'FILLING HOLE AT 20 BPH,8.5 PPG SEA WATER,NO RETURNS 22:30 - 00:00 1.50 RUNCOM N DPRB RUNCMP PJSM,SPOT AND R/U SLB SLICK LINE UNIT -OA=0 PSI -24 HOUR FLUID LOSS=617 BBLS 8.5 PPG SEA WATER -MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH NO RETURNS 2/26/2014 00:00 - 00:30 0.50 RUNCOM N DPRB RUNCMP CONTINUE R/U SLB SLICK LINE 00:30 - 01:30 1.00 RUNCOM N DPRB RUNCMP RIH WITH BELL-BLIND GUIDE,ROLLER WEIGHT BARS,JARS -TAG TOP OF BALL AND ROD AT 5174'WLM 01:30 - 02:00 0.50 RUNCOM N DPRB RUNCMP TEST TUBING TO 500 PSI TO VERIFY BALL IS ON SEAT=GOOD -POOH WITH WIRELINE TOOLS 02:00 - 03:00 1.00 RUNCOM N DPRB RUNCMP R/U CIRCULATION LINES,TEST 250/3500 PSI 03:00 - 05:00 2.00 RUNCOM P RUNCMP PJSM,PRESSURE UP ON TUBING TO SET PACKER AND TEST -250 PSI,3500 PSI,30 MIN,CHART,OBSERVE PACKER SET AT 2100 PSI -BLEED PRESSURE DOWN TO 1500 PSI -TEST 7 5/8"X 4 1/2"IA,250 PSI,3500 PSI,30 MIN,CHART -NOTIFY AND RECEIVE AUTHORIZATION TO PROCEED FROM WTL -SHEAR OUT DCK VALVE -PUMP BOTH WAY THRU DCK VALVE,3 BPM= 780 PSI 05:00 - 06:00 1.00 RUNCOM N DPRB RUNCMP R/D SLB SLICK LINE TOOLS AND UNIT -PULL DUTCH RISER,DRAIN BOP 06:00 - 07:00 1.00 WHSUR P OTHCMP FMC REP INSTALLED TWC -TEST TWC FROM BELOW AND ABOVE,250/ 3500 PSI,5 MIN EA,CHART 07:00 - 07:30 0.50 BOPSUR P OTHCMP BLOW DOWN CHOKE AND KILL LINES,PREP TO N/D BOP 07:30 - 08:30 1.00 BOPSUR P OTHCMP PJSM,N/D BOPE,RISER,REMOVE KOOMY LINES 08:30 - 10:00 1.50 WHSUR P OTHCMP FMC PREP HANGER,SLB PREP I-WIRE FOR TESTING N/U TUBING HEAD ADAPTER AND TREE • 10:00 - 11:00 1.00 WHSUR P OTHCMP SCHLUMBERGER REP,TEST I-WIRE=GOOD -FMC REP,TEST HANGER SEALS,250/5000 PSI,30 MIN Printed 3/10/2014 10:56:36AM North America-ALASKA-BP Page 8 of 8 Operation Summary Report .. . .._...._..._-- Common Well Name:MPJ-26 AFE No Event Type:WORKOVER(WO) Start Date:2/20/2014 End Date:2/26/2014 X4-00YP8-E:(1,680,000.00) Project:Milne Point Site:M Pt J Pad Rig Name/No.:DOYON 16 Spud Date/Time:5/11/2004 12:00:OOAM Rig Release:2/26/2014 Rig Contractor DOYON DRILLING INC. UWI:500292320500 Active datum:MPJ-26:©68.70usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 13:00 2.00 WHSUR P OTHCMP PJSM TO TEST TREE AND LUBRICATOR -R/U WELL SUPPORT LUBRICATOR TO TREE -TEST TREE AND LUBRICATOR TOGETHER -250/5000 PSI,5 MIN,CHART PULL TWC,R/D WS LUBRICATOR 13:00 - 16:30 3.50 WHSUR P OTHCMP PJSM,R/U TO FREEZE PROTECT -R/U LRS TO CIRC MANIFOLD AND TREE -TEST LINES,250/3500 PSI -RETURNING DIRTY VAC TRUCK FOR CUTTINGS TANK,EXPERIENCED FLAT TIRE CALL FOR ADDITIONAL TRUCK 16.30 - 20:00 3.50 WHSUR P OTHCMP 'LRS PUMP DOWN IA, 125 BBLS,80 DEGREE DIESEL FREEZE PROTECT.1 BPM=300 PSI -TAKE RETURNS UP TUBING TO CUTTINGS TANK -LET FREEZE PROTECT U-TUBE,1 HOUR FREEZE PROTECT TO 3015'MD,2500'TVD 20:00 - 22:00 2.00 WHSUR P OTHCMP PJSM,R/U WELL SUPPORT LUBRICATOR -TEST TO 250/3500 PSI,5 MIN,CHART -INSTALL BPV,R/D WS LUBRICATOR -LRS TEST BELOW BPV,250/1000 PSI,5 MIN,R/D LRS 22'00 - 00:00 2.00 WHSUR P OTHCMP PJSM,BLOW DOWN AND R/D ALL CIRC LINES IN CELLAR -INSTALL GAUGES AND SECURE TREE -PREP CELLAR AREA FOR RIG MOVE -SIM-OPS ON RIG FLOOR=BRIDLE UP BLOCKS AND PREP RIG FLOOR FOR DERRICK OVER -EMPTY CUTTINGS TANK AND FINISH PIT CLEANING -24 HOUR FLUID LOSS=77 BBLS 8.5 PPG SEA WATER RELEASE RIG AT 24:00 HOURS FROM MPJ-26, 2/26/2014 Printed 3/10/2014 10:56:36AM Tree; Cameron 4-1/16"-5M Or elev. = 69.00'(Doyon 14) # Wellhead: 11"x 4.5"Atlas Brau- MPJ-26/i,t/L?jOrig. Hgr elev.= 30.27'(Doyon 14) ford W/2 (3/8) I wire port w/4.5" TC-I-A EMS T&B Tub,Hanger. CIW BPV 4.5"H"Type Camco 4.5"x 1"w/BK latch 20"x 34"insulated,215#/ft A-53 112' 2 492„ 10 3/4"45.5 ppf L-408TRC sidepocket KGB-2 w/DCK-2 shear valve GLM (Drift ID=9.794,cap.=.0961 bpf) 10 3/4"Howco Float Shoe 11)104' I A KOP @ 300' 60+degree from 2550' Max hole angle=74 degree @ 3735' 68 degree @ SSD 'Reverse Circulation'Jet Pump Configuration ' i Phoenix Discharge gauge(3.833"id) 4,947"l iIFI i ( tL 4.5"HES"XD"Dura sliding sleeve 4,960" t r '� l'♦ I• = .. . l Phoenix gauge(3.958"id) 4,970" t 4.5"HES X Nipple(3.813 ID.") 5,041"1 lrrr r r °• -R 75/8"x 4.5"HES TNT L-80 Packer. 5,067"I Reservoir Fluid 4.5"HES X Nipple(3.813 ID.") 5,107" 4.5"HES XN-Nipple(3.725"W/RHC-M plug) 5,179" 7 5/8"29.7 ppf, L-80,BTRC-mod casing WLEG w/TC-11 and 5.00 OD. 5,231" (Drift ID=6.750",cap=0.0459 bpf) (7 5/8"X 2 7/8"Cap =.0379 bpf) (TBG 4.5 L-80 TC-11 12.6 lb PF) (TBG 4.5 Drift id=3.958"cap=.01522 bpf) OA Sands: 5270'-8535'MD 3954'-3987'TVD KOP @ 500' 6 1/8"Hole td @ 8535' i > >Baker Floatt shoe 8513' 50+degree from 4250' A Max hole angle in tbg= 64°@+4850' OA Lateral 76 jts.-4 1/2"Slotted Liner Rat Hole Window in 75/8"Casing©5270'-5282' 12.6#L-80 IBT(5334'-8469') 22' Well Angle @ window=75° W 4� Baker Tie Back Sleeve 5228' Baker ZXP Liner Top Packer 5239' Baker Hook Hanger LEM 5255'-5290' Baker Hook Wall Hanger inside 7-5/8"Window 5265' Baker Hook Wall OB Sands: 5558'-8670'MD Hanger outside 7-5/8"Window 5288' 4014'-4043'TVD Window in 7-5/8"Casing @ 5558'-5570' .:-.W///11PWAWI//IIMIP" Well Angle @ window=78° OB Lateral 72 its.-4 1/2"Slotted Liner Rat Hole Baker Tie Back Sleeve 5501' 12.6#L-80 IBT(bb11'-8591') 35' Baker ZXP Liner Top Packer 5512' Baker Hook Hanger LEM 5543'-5578' I,' �� Baker Hook Wall •. 6 1/8"Hole td @ 8670' Btm Baker"V"Float Shoe 8635' Hanger inside 7-5/8"Window 5553' Baker Hook Wall Hanger outside 7-5/8"Window 5570' NB Sands: 6405'-8760'MD 3818'-3894'TVD Baker ZXP Liner Top Packer 5695' 6 1/8"Hole td 8760' Btm Baker 4 1/2""V"Float Shoe 8760' Baker RS Packoff Seal Nipple 5714' NB Lateral@ Baker 7-5/8"x 5.5"Flex Lock Lnr Hgr 5717' ,, ,,40 jts.-4",9.5#L-80, IBT Blanks a,_ Rat0'Hole Baker 190-47 Seal Bore Extension 5730' nd 7-5/8"Weatherford Float Collar 6319' 26 jts Baker Med Excluder Screen((,'A4'-8716') 7-5/8"Weatherford Float Shoe 6404' DATE REV.BY COMMENTS MILNE POINT UNIT 6/7/04 Lee Hulme Drilled&Completed Doyon 14 WELL MPJ-26 2/25/14 B.Kruskie Doyon 16 changed from ESP to JP API NO: 50-029-23205-00 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 S i Ni FEB 2; I ZOIZ December 30, 2011 061 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission e3- g 333 West 7 Avenue Anchorage, Alaska 99501 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 • • 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 It API it 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 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 • • ~. °~ - MICROFILMED 03/0112008 DO NOT PLACE ~~",.. rt , ,~" s -: ,~. ,~_ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C`vrPgs_Inserts\Microfilm Marker.doc ) (::. Jw-.-).. ~ " DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040640 Well Name/No. MILNE PT UNIT SB J-26 Operator BP EXPLORATION (ALASKA) INC AP~~029~;2~-~ 'f MD 8760.,- TVD 3850 r- Completion Date 5/31/2004 ~ Completion Status 1-01L Current Status 1-01L ute N REQUIRED INFORMATION Mud Log No Samples No Directional su~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, ABI, IFR, CASANDRA, GYRO (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 6/9/2004 MWD Survey Directional Survey 0 0 6/9/2004 MWD D Asc Directional Survey 0 0 6/9/2004 IIFR Survey Directional Survey 0 0 6/9/2004 IIFR .ee- D Asc Directional Survey 0 0 6/9/2004 MWD Survey PB1 ~ Directional Survey 0 0 6/9/2004 MWD PB1 i IiiÐ" D Asc Directional Survey 0 0 6/9/2004 IIFR Survey PB1 B¢ Directional Survey 0 0 6/9/2004 IIFR PB1 ED.--- D Asc Directional Survey 0 0 6/9/2004 MWD Survey PB2 "Rí5t Directional Survey 0 0 6/9/2004 MWD PB2 æ-- D Asc Directional Survey 0 0 6/9/2004 IIFR Survey PB2 Rpt Directional Survey 0 0 6/9/2004 IIFR PB2 . D Lis 12538 Induction/Resistivity 69 8701 Open 7/9/2004 EWR4 GR ABI ROP ...ßI.*' LIS Verification 0 0 7/9/2004 DSN 12538 I ¡fit' D Lis 12539 Induction/Resistivity 69 8015 Open 7/9/2004 PB1 EWR4 GR ABI ROP 4 LIS Verification 69 8015 Open 7/9/2004 DSN 12539 PB1 EJY' D Lis 12540 Induction/Resistivity 69 8503 Open 7/9/2004 PB2 EWR4 GR ABI ROP I~ LIS Verification 69 8503 Open 7/9/2004 DSN 12540 PB2 EWR4 GR ABI ROP C Lis 13589 Induction/Resistivity 112 8760 Open 2/22/2006 ROP DGR EWR plus Graphics / PB 1 112-8074 ROP DGR EWR plus Graphics / PB 2 112-8562 ROP DGR EWR plus Graphics Permit to Drill 2040640 MD 8760 TVD 3850 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Analysis Received? ~ DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Well NamelNo. MILNE PT UNIT SB J-26 Operator BP EXPLORATION (ALASKA) INC Completion Date 5/31/2004 Completion Status 1-01L Current Status 1-01L Sample Set Number Comments ~/N G)N API No. 50-029-23205-00-00 UIC N Comments: Compliance Reviewed By: Interval Start Stop Sent Received Daily History Received? Formation Tops .~ Date: ;{>~~ . . · ~ WELL LOG TRANSMITTAL ~.løfo4 135ðCf February 16,2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Fonnation Evaluation Logs MPl-26 + PB1 + PB2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPJ-26 + PBl + PB2: LAS Data & Digital Log Images: 50-029-23205-00, 70, 71 1 CD Rom ~. f1r:t0[Júld · - WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 06, 2004 RE: MWDFonnationEvaluationLogs MPJ-26PB1, AK.-MW -3066223 1 LIS fonnatted Disc with verification listing. ~I#: 50~29-23205-70 i:\-- P \}. "{ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LEITER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: q ~ ~~ Signed: tl, aMlJ ¡.. ~..~-() ~ '-'\ e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 06, 2004 RE: MWD Fonnation Evaluation Logs MPJ-26 PB2, AK-MW-3066223 1 LIS fonnatted Disc with verification listin&J..J .' ) ¡ ç C( Ù ~I#: 50-029-23205-71 :rr PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: qJ V1~) hv~ Signed: MJOW -,2'-/' .. / / )/-/. /::x;,:"'~ /~¿) ç/ð c/-¿] (, 'I - e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corum. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 06, 2004 RE: MWD Formation Evaluation Logs MPJ-26, AK-MW-3066223 1 LIS formatted Disc with verification listing. llPI#: 50µ029-23205-O0 1) S-!?g PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITfAL LETTER TO mE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: C(Jv~~'1. Signed:_)~L 0 UvJ ):O~-Q~ ~( · STATE OF ALASKA e ALASKA~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ; 1a. Well Status: IBI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Cláss: 20AAC 25.105 20AAC 25.110 IBI Development o EXþloratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/31/2004 / 204-064 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 5/11/2004 / 50- 029-23205-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached / 14. Well Name and Number: Surface: 5/20/2004 MPJ·26 2157' NSL, 3267' WEL, SEC. 28, T13N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1839' NSL, 2437' WEL, SEC. 29, T13N, R10E, UM (NB) KBE = 68.70' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 3373' NSL, 3523' WEL, SEC. 29, T13N, R10E, UM (NB) 8760 + 3850 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 552055 j y- 6014554 I Zone- ASP4 8760 + 3850 Ft ADL 025517 TPI: x- 547609 y- 6014208 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 546508 y- 6015735 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IBI Yes DNo N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, ABI , IFR , CASANDRA , GYRO 22. CASING, LINER AND CEMENTING RECORD CASING SETTING EÞTH MD SETTING EPTHTVD ~~€ ...ii·· .... AMOUNT SIZE WT.PÊREr. GRADE lOP tsonOM lOP I tsOTTOM .. "PULLeo 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 3105' 35' 2624' 13-112" 497 sx PF 'L', 261 sx Class 'G' 7-5/8" 29.7# L-80 33' 6405' 33' 3895' 9-7/8" 278 sx Class 'G' 4"x5" 12.6#/9.5# L-80 5695' 8760' 4046' 3850' 6-3/4" Sand Screen Liner 23. Perforations oRen to Production (MD + TVD of Top and 24. .. TuBING RECÔRD .......... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4", 9.5#, L-80 Sand Screens 2-7/8", 6.5#, L-80 5023' N/A MD TVD MD TVD 25. ~êÔ;r~pJ,",',~,.. I::Tf' .... .. 6676' - 8716' 3840' - 3848' ............. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls Dead Crude 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 22, 2004 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-MCF W A TER-BBl CHOKE SIZE GAS-Oil RATIO 6-18-2004 6 TEST PERIOD -+ 365 327 79 896 Flow Tubing Casing Pressure CALCULATED + Oll-BBl GAs-MCF WATER-Bal Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 1458 1307 317 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~3Nl None JUl 12 ìOO~ s ~J"" · ffl1MSt)fL ORiG\NAL ~ -()(, f_~ ~"'h-J.,;O'-"\ L.,_..,.,__----.. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ""if ~\, ~ 28. GEOLOGIC MARKERS NAME MD TVD SBF2-NA SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB TSBB-OB TSBC TSBD-OA SBE1-NF SBE2-NE SBE3-ND SBE41 SBE4-NC SBF12 SBF1-NB SBF1-NB SBE4-NC SBF12 3809' 3815' 3833' 3840' 3860' 3868' 3874' 3879' 3888' 3934' 3968' 3997' 4027' 4018' 3985' 3948' 3913' 3859' 3855' 3851' 3847' 3844' 3837' 3835' 3834' 3823' 4866' 4878' 4920' 4936' 4984' 5003' 5017' 5027' 5049' 5161' 5270' 5400' 5554' 5993' 6122' 6238' 6349' 6538' 6559' 6586' 6612' 6637' 6716' 6855' 7583' 7798' 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None '\ 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram and Surveys. Signed f7 -(:")7- -Ql _ Title Technical Assistant Date 204-064 Permit No. I A roval 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. MPJ-26 Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Walter Quay, 564-4178 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 5/3/2004 5/31/2004 Spud Date: 5/11/2004 End: 5/10/2004 07:30 - 17:00 9.50 MOB P PRE Rig down, install booster wheels and move rig to MPJ-26, moved camp to MP-H pad, 17:00 - 19:30 2.50 MOB P PRE Remove booster wheels 19:30 - 22:00 2.50 MOB P PRE Spot rig over well, Rig up, Rig accepted @ 22:005/10/2004 22:00 - 00:00 2.00 RIGU P PRE Nipple up Diverter, mixing spud mud 5/11/2004 00:00 - 01 :30 1.50 RIGU P PRE Nipple up Diverter, mixing spud mud 01 :30 - 09:30 8.00 DRILL P SURF Picking up drill pipe out of pipe shed and standing in derrick, 273 jts, 91 stands 09:30 - 10:30 1.00 DRILL P SURF Pick up HWT 5" - Jars - Stand back same 10:30 - 11 :00 0.50 DRILL P SURF Mobilize BHA to rig floor 11 :00 - 11 :30 0.50 BOPSU P SURF Function test Diverter - Chuck Scheve with AOGCC waived witness of test 11 :30 - 13:00 1.50 DRILL P SURF Make up 8" DC's - Stand back same - Pick up Motor - Make up BHA - orient UBHO 13:00 - 13:30 0.50 DRILL P SURF Rig up Gyro - Purge MP's - Pre spud meeting 13:30 - 23:30 10.00 DRILL P SURF Directional Drill from 112' to 499' 23:30 - 00:00 0.50 DRILL N DPRB SURF POH 5/12/2004 00:00 - 00:30 0.50 DRILL N DPRB SURF Con't POH for BHA 00:30 - 02:30 2.00 DRILL N DPRB SURF Make up MWD - Re-set motor from 1.5 degree to to 1.83 degree - Not getting right build rate - building 1 degree per 100 - plan calling for 3 degree per 100 - 02:30 - 03:00 0.50 DRILL N DPRB SURF RIH with HWT DP to 499' 03:00 - 12:00 9.00 DRILL P SURF Directional Drill from 499' to 807' - WOB 25K - RPM 70 - GPM 375 - PP on 1100 - PP off 950 - TO on 5 - off 2 - PU 80 - SO 80 - ROT 80 - (POH for re-set motor from 1.83 to 2.38 - build rate 1.4 needed 5 per 100) 12:00 - 13:30 1.50 DRILL N DPRB SURF POH for BHA - UD MWD - UD motor 13:30 - 14:30 1.00 DRILL N DPRB SURF Make up BHA - Motor set at 2.38 - MWD - UBHO - Orient tools - RIH to 807' 14:30 - 18:30 4.00 DRILL P SURF Directional Drill from 807' to 1094' - WOB 30K - RPM 40 - TO on 5 - off 2 - GPM 400 - PP on 1220 - off 1020 - PU 91 - SO 90 - ROT 90 - (POH to re-set motor from 2.38 to 1.83 - build rate 6.4 need 5 per 100) 18:30 - 20:00 1.50 DRILL N DPRB SURF POOH - LD UBHO - Make up stab - Adjust motor to 1.83 - Orient 20:00 - 20:30 0.50 DRILL P SURF RIH to 1000' - Wash to btm @ 1094' 20:30 - 00:00 3.50 DRILL P SURF Directional Drill from 1094' to 1382' - WOB 25 - RPM 84 - TO on 6 - off 3 - GPM 400 - PP on 1510 - off.1250 - PU 91 - SO 89 - ROT 90 5/13/2004 00:00 - 07:30 7.50 DRILL P SURF Directional Drill From 1382' to 2150' - WOB 30K - RPM 80 - TO on 6 - off 3 - GPM 425 - PP on 1710 - off 1520 - PU 90 - SO 85 - ROT 90 - Perm a-frost base MD @ 2044' TVD 1840' 07:30 - 08:00 0.50 DRILL P SURF CBU 1X - GPM 425 - PP 1430 - RPM 80 - TO 6 08:00 - 09:00 1.00 DRILL P SURF Pump out to HWT at drilling rate 425 GPM - From 2150' to 618' - Back ream from 1100' to 810' 09:00 - 09:30 0.50 DRILL P SURF RIH from 618' to 2150' - Washdown last stand 09:30 - 15:00 5.50 DRILL P SURF Directional Drill- From 2150' to 3114' - WOB 30 - RPM 80 - TO on 6 - off 3 - GPM 490 - PP on 2500 - off 1800 - PU 105 - SO 85 - ROT 93 15:00 - 17:00 2.00 CASE P SURF CBU 3 X - GPM 490 - PP 1800 - RPM 80 - TO 5 17:00 - 18:30 1.50 CASE P SURF Pump out to HWT at drilling rate 480 gpm - From 3114' to 618' - Hole in good shape 18:30 - 19:30 1.00 CASE P SURF RIH fro 618' to 3014' - Wash from 3014' to 3114' Printed: 6/1/2004 9:19:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/3/2004 Rig Release: 5/31/2004 Rig Number: Spud Date: 5/11/2004 End: 5/13/2004 19:30 - 22:00 2.50 CASE P SURF CBU 3 X - GPM 490 - PP 1800 - RPM 80 - TQ 5 22:00 - 23:30 1.50 CASE P SURF Flow Check - Pump out to HWT at Drilling rate 490 gpm - From 3114' to 618' 23:30 - 00:00 0.50 CASE P SURF Change 4" elevators to 5" elevators - Stand back HWT and jars 5/14/2004 00:00 - 01 :30 1.50 CASE P SURF Lay down 8" DC's - MWD - Motor - Bit 01 :30 - 02:30 1.00 CASE P SURF Clear rig floor of all BHA and tools - Dummy run of 10 3/4" casing hanger 02:30 - 04:00 1 .50 CASE P SURF Rig up 10 3/4" casg equipment 04:00 - 04:30 0.50 CASE P SURF PJSM on running casing - Make up float joints and circ thru float equipment - check floats 04:30 - 08:00 3.50 CASE P SURF Pick up and run 103/4" casg to 3068' - Break circ - Circ down last joint run - Make up landing joint / hanger - Land casing 08:00 - 08:30 0.50 CASE P SURF Rig down Franks fill up tool - Make up Dowell Cementing head - Cementing lines 08:30 - 10:00 1.50 CASE P SURF Circulate two casing volumes - Condition mud for cement job (98 spm @ 420 psi - slow to 79 spm @ 310) 10:00 - 13:00 3.00 CEMT P SURF Give to Schlumberger - Pump 5 bbls water - (One gallon dye in first 5 bbls water) - Test lines to 4000 psi - Pump 10 bbls water - 20 bbls CW1 00 - Pump 75 bbls Alpha Spacer @ 10.3 @ 4.5 bpm - Drop bottom plug last 5 bbls spacer Mix and pump 417 sxs Type "ASL" Yield 4.44 cf/sx 352 bbls of slurry mixed at 10.7 ppg - @ 6.3 bpm Mix and pump 54.4 bbls Tail Class "G" 258 sxs with .5% S002 Accelerator.4% D-167 Fluid Loss .3% D065 Dispersant .2% D046 Antifoam - Yield 1.17 cf/sx - mixed at 15.8 ppg - @ 5 bpm Kick out top plug with Schlumberger 30 bbls water - Give to rig Rig displaced cement with 260 bbls mud @ 8.3 bpm 400 psi - last 10 bbls slowed down to 3.3 bpm 500 psi - Bump plug with 1500 psi - held for 3 mins - bleed off pressure - Floats held CIP 12:58 hrs - 166 bbls cement back to surface 13:00 - 14:30 1.50 CASE P SURF Rig down Schlumberger Cementing head - Lay down Landing joint - Flush out Diverter - Lay down casing tools - cementing head - Long bails - Install drilling bails - 5" elevators 14:30 - 15:00 0.50 CASE P SURF Nipple down Diverter System 15:00 - 15:30 0.50 CASE P SURF Nipple up FMC SSH 12" M to M seal bottom x 11" 5M - FMC tubing head 5M G5 - Test 1000 psi for 10 mins 15:30 - 17:30 2.00 CASE P SURF Nipple up BOP's 17:30 - 18:00 0.50 CASE P SURF Rig up to test BOPs - Open annulus valve - Set test Plug 18:00 - 21 :30 3.50 CASE P SURF Test BOPs - Test Annular 250 low 2500 high each test 5 mins- Pipe rams - Blind rams - HCR Choke - HCR kill - Manual Choke - Manual kill - Choke manifold - Upper / Lower IBOP - Floor safety valves to 250 low 3500 high 5 mins each test - Perform Accumulator test - All test good - John Crisp with AOGCC wavied witness of BOP test 21 :30 - 22:00 0.50 CASE P SURF Pull test plug - Set wear ring - Close annulus valves - Rig down testing equipment 22:00 - 23:00 1.00 CASE P SURF Cut drlg line - Service Top Drive - Rig Printed: 6/1/2004 9:19:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 5/3/2004 5/31/2004 Spud Date: 5/11/2004 End: 5/14/2004 23:00 - 23:30 0.50 CASE P SURF RIH with 5" HWT - Lay down 23:30 - 00:00 0.50 CASE P SURF Moblize BHA to rig floor 5/15/2004 00:00 - 01 :30 1.50 CASE P SURF Pick up Motor - Make up bit - Make up MWD - Orient same 01 :30 - 02:00 0.50 CASE P SURF Test 10314" casing to 2500 psi - Hold for 30 mins - Test good 02:00 - 02:30 0.50 CASE P SURF Rig down test equipment - Blow down choke manifold - Kill line 02:30 - 03:00 0.50 CASE P SURF Con't make up BHA - Surface test MWD 103 spm @ 900 psi 03:00 - 04:00 1.00 CASE P SURF RIH from 213' to 1573' - Break circulation - Con't RIH from 1573' to 2940' 04:00 - 04:30 0.50 CASE P SURF Break circulation - Wash to float collar from 2940' to 3016'- Circulate bottom up 04:30 - 06:00 1.50 DRILL P SURF Drill float equipment @ 3016' to 3114' - Drill 20' new hole from 3114' to 3134' 06:00 - 06:30 0.50 DRILL P SURF Displace well to new mud - RPM 40 - GPM 470 - PP 1600 06:30 - 07:00 0.50 DRILL P SURF FIT - Test Mud weight 8.8 - TVD 2623' - MD 3114' - Surface psi 300-EMW=11 ppg 07:00 - 16:00 9.00 DRILL P INT1 Directional Drill From 3134' to 4697' - WOB 5 to 10 - RPM 80- TO on 5 - off 4 - GPM 475 - PP on 2000 - off 1780 - PU 105- SO 90 - ROT 105 16:00 - 17:30 1.50 DRILL P INT1 Circ for short trip to shoe - GPM 475 - PP 1800 psi 17:30 - 18:30 1.00 DRILL P INT1 Pump out from 4697' to 3050' - GPM 475 - No problems on trip out 18:30 - 20:30 2.00 DRILL P INT1 CBU - Circ out clay balls - unplug flowline / posum belly on shaker / augar 20:30 - 22:30 2.00 DRILL P INT1 Cut drilling line - 1000' of line 22:30 - 23:30 1.00 DRILL P INT1 RIH from 3050' to 4650' - Precauctionary Ream from 4650' to 4697' - Hole in good shape 23:30 - 00:00 0.50 DRILL P INT1 Directional Drill - From 4697' to 4780' - WOB 5 to 10- RPM 80 - TO on 6 - off 4 - GPM 485 - PP on 2000 - off 1750 - PU 125- SO 90 - Rot 105 5/16/2004 00:00 - 18:30 18.50 DRILL P INT1 Directional Drill From 4780' to 6417' - (TD 9 7/8" hole) - WOB 8 to 10- RPM 80 - TO on 11 - off 6 - GPM 486 - PP 2440 - PU 130 - SO 80 - ROT 100 - (OA Sand Top 5270' - OB Sand Top 5560') 18:30 - 20:00 1.50 CASE P INT1 CBU 2 X - GPM 486 - PP 2000 - Flow check 20:00 - 23:00 3.00 CASE P INT1 Pump to shoe - (From 6417' to 3050') - 5408' to 4628' packing off - From 4628 to 3100' clay balls - binding off screens 23:00 - 00:00 1.00 CASE P INT1 CBU at shoe - Clean up well - massive cuttings / clay balls binding up screens 5/17/2004 00:00 - 00:30 0.50 CASE P INT1 Con't circulate cuttings / clay balls out of hole 00:30 - 01 :30 1.00 CASE P INT1 RIH from 3050' to 6417' - Fill pipe every 25 stands - Break circulation and wash from 6320' to 6417' - No problems going in hole - Hole in good shape 01 :30 - 04:00 2.50 CASE P INT1 CBU 3 X - RPM 80 - Tq 6- GPM 430 - ICP 1850 - FCP 1730 04:00 - 06:30 2.50 CASE P INT1 Pump out to shoe from 6417' to 3050' - Pump rate 430 GPM 06:30 - 07:00 0.50 CASE P INT1 CBU 1 X - RPM 60 - TO 4 - GPM 430 - PP 1650 07:00 - 08:30 1.50 CASE P INT1 Flow check - Pump dry job - POH to BHA 08:30 - 10:00 1.50 CASE P INT1 Lay down BHA 10:00 - 10:30 0.50 CASE P INT1 Pull wear ring - Install test plug 10:30 - 11 :30 1.00 CASE P INT1 Change rams to 7 5/8" - Test Door seals to 1500 psi - Pull test plug 11 :30 - 12:30 1.00 CASE P INT1 PJSM - Rig up casing equipment 12:30 - 15:00 2.50 CASE P INT1 PJSM - Pick up and run 7 5/8" / L-80 /29.7# / BTC-M casing to shoe (75 joints 3067') Printed: 6/1/2004 9: 19:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 5/3/2004 5/31/2004 Spud Date: 5/11/2004 End: 5/17/2004 15:00 - 15:30 0.50 CASE P INn Circulate casing volume - 142 bbls - 6 bpm - 800 psi 15:30 - 18:30 3.00 CASE P INT1 Con't RIH with 7 5/8" casing to 6331' Break circulation and circulate last joint down from 6331' to 6372' prior to picking up landing joint - 18:30 - 19:00 0.50 CASE P INT1 Make up landing joint / mandral hanger - RIH from 6372' to 6405' - Rig down Franks fill up tool - Make up Dowell Cementing head - cementing lines - 156 Total joints 7 5/8" casing run - Shoe @ 6404.48 - Float collar 6319.20 19:00 - 20:30 1.50 CASE P INT1 Circulate two casing volumes - Condition mud for cement job - 6 BPM - ICP 520 psi FCP 400 - PU 195K - SO 110K 20:30 - 22:30 2.00 CEMT P INT1 Give to Schlumberger - Pump 5 bbls water - Test lines to 4000 psi - Pump 25 bbls CW 100 @ 5.2 bpm 340 psi Pump 40 bbls Mud Push mixed at 10.3 @ 5 bpm 350 psi Mix and pump 157 bbls Class "G" Tail cement - Yield 1.16 cf/sx - 760 sxs - Mixed at 15.8 - @ 6.2 bpm 220 psi - Schlumberger Displaced with Oil Mud - WT 9.3 - 290 bbls - 6 bpm - PSI 60 to 900 - Slow to bump @ 3 bpm 775 psi - Bump plug with 297 bbls pumped - psi 1775 - Held for 2 mins - bleed back - Floats holding - CIP 23:37 hrs - No Losses - Full returns 22:30 - 00:00 1.50 CASE P INT1 Rig down Schlumberger cementing head - Make up Hydrill1" pipe - Blow Oil mud out 7 5/8" landing joint and 25' of 7 5/8" casing - Flush BOP stack - Drain stack - Back out landing joint 5/18/2004 00:00 - 01 :30 1.50 CASE P INT1 Install FMC 7 5/8" pack-off - RILD - Test to 5000 psi 01 :30 - 02:00 0.50 CASE P INT1 Clear casing equipment / tools off rig floor - Pump 20 bbls mud @ 1.5 bpm 1050 psi down 103/4" x 7 5/8" annulus 02:00 - 03:00 1.00 CASE P INT1 Change rams - Freeze protect 10 3/4" x 7 5/8" annulus with 85 bbls of diesel - Pump rate 1.5 bpm @ 1200 psi 03:00 - 04:00 1.00 CASE P INT1 Install test plug - Rig up test equipment 04:00 - 07:30 3.50 CASE P INT1 Test BOP's - Annular 250 low 2500 high 5 mins ea - Pipe rams - Blind rams - Choke manifold - HCR Choke / Kill - Manual Choke / Kill - Upper / Lower kelly valves - Floor safety valves - IBOP failed - Replaced - All test 250 low 3500 high 5 mins ea - Performed accumulator test - John Crisp with AOGCC waived witness of BOP test. 07:30 - 08:00 0.50 CASE P INT1 Rid down testing equipment - Pull test plug - Install wear ring - Close annulus valves 08:00 - 08:30 0.50 CASE P INT1 Pick up BHA to rig floor 08:30 - 09:30 1.00 CASE P INT1 Make up BHA 09:30 - 10:30 1.00 CASE P INT1 Flush pumps with Oil base mud - Test 7 5/8" cuing to 3500 psi for 30 mins 10:30 - 11 :00 0.50 CASE P INT1 Con't make up BHA - Surface test MWD - @ 56 spm 1450 psi 11 :00 - 13:30 2.50 CASE P INT1 RIH Tag float collar @ 6320' 13:30 - 14:00 0.50 CASE P INT1 Circulate hole volume @ 475 GPM - 2100 PSI - RPM 50 14:00 - 15:00 1.00 DRILL P INT1 Drill float equipment / cement from 6320' to 6386' - WOB 5 - RPM 56 - TO 8 - GPM 258 - PP 2000 15:00 - 16:00 1.00 DRILL N RREP INT1 Repair Hydralic hose on top drive 16:00 - 17:00 1.00 DRILL P INn Con't drill cement / Float equipment from 6386' to 6404' - clean out to 6417' drill 20' new hole from 6417' to 6437' - WOB 5 - RPM 60 - TO 6 - GPM 258 - PP 2000 17:00 - 18:00 1.00 DRILL P INT1 Circulate & Condition mud - FIT - TVD 3895 MD 6437' - MW 9.3 - Surface Pressure 550 =EMW 12.0 18:00 - 20:00 2.00 DRILL P PROD1 Directional Drill from 6437' to 6602' - WOB 5 to 6 - RPM 80 - TO on 4 - off 3 - GPM 256 - PP on 2340 - off 2250 - PU 125- Printed: 6/1/2004 9: 19:46 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: 5/3/2004 Rig Release: 5/31/2004 Rig Number: Spud Date: 5/11/2004 End: 5/18/2004 18:00 - 20:00 2.00 DRILL P PROD1 SO 80 - ROT 100 20:00 - 21 :00 1.00 DRILL N RREP PROD1 Repair hydralic fitting on top drive 21 :00 - 00:00 3.00 DRILL P PROD1 Directional Drill from 6602' to 6810' - WOB 5 to 6 - RPM 90- TO on 4 - off 4 - GPM 256 - PP on 2400 - off 22 - PU 118 - SO 77 - ROT 100 5/19/2004 00:00 - 14:00 14.00 DRILL P PROD1 Directional Drill from 6810' to 8073' - WOB 3 to 5 - RPM 80- TO on 4 - off 4 - GPM 258 - PP on 2580 - off 2450 - PU 125- SO 60 - ROT 95 14:00 - 14:30 0.50 DRILL N DPRB PROD1 POH from 8073' to 7275' for open-hole sidetrack - (Decision to ~ sidetrack due to marginal facies change) - Topped out NB 14:30 - 16:30 2.00 DRILL N DPRB PROD1 Sand 7985' ý>!? ~ .., .)CZs(::) - ~(:) '"1 <;; k~..() '"'"\ Cut trough from 7275' to 7280 - for open-hole sidetrack 16:30 - 00:00 7.50 DRILL P PROD1 Open hole sidetrack - ( Sidetrack MD 7280' TVD 3833') - Directional Drill from 7280' to 7898' - WOB 3 to 5 - GPM 256 - PP 2480 on - off 2420 - RPM 80 - TO on 4 - off 4 - PU 130 - SO 65 - ROT 100 5/20/2004 00:00 - 06:00 6.00 DRILL P PROD1 Directional Drill from 7898' to 8562' - WOB 3 to 5 - RPM 100 - TO on 6 - TO off 4 - GPM 258 - PP on 2580 - off 2450 - PU 125 - SO 60 - ROT 1 00 06:00 - 06:30 0.50 DRILL P PROD1 POH from 8562' to 8330' - For open hole side track # 2 06:30 - 07:30 1.00 DRILL P PROD1 Cut trough for open hole side track from 8330' to 8350' - GPk 258 - PP 2500 ç'ß d <6'3~o - ~Cø ð L: 07:30 - 12:30 5.00 DRILL P PROD1 Side track from 8330' to 8760' - WOB 3 to 5 - RPM 100 - TO " \ 't-d on 6 - off 4 - GPM 258 - PP on 2560 - off 2450 - PU 125 - SO 60 - ROT 97 12:30 - 15:00 2.50 CASE P LNR1 CBU 3 X - Flow check well - GPM 258 - PP 2500 15:00 - 19:30 4.50 CASE P LNR1 Pump out to shoe from 8760' to 6400' - Pump at drlg rate 258 gpm - Hole packing off from 7800' to 7000' - Attempt to circ @ 7000' packing off - RIH to 7095' - Attempt to circ packing off - RIH to 7190' - Circuluate hole at full pump rate 258 gpm - PP 2250 - Can't Pumping and back ream from 7190' to 6398' - Hole good no drag or packing off 19:30 - 20:30 1.00 CASE P LNR1 CBU 2 X - 275 GPM - 70 rpm - Circulate out cuttings 20:30 - 21 :30 1.00 CASE P LNR1 Cut drlg line - Service Top drive 21 :30 - 00:00 2.50 CASE P LNR1 RIH to 7275' - Orient tool face to 170 left - RIH to 7750'- Taking weight - Survey - Went into orqinal hole - POH from 7750' to 7275' - Orient 2nd time 170 left - Keep pump on RIH to 7370 - Take survey check OK - Can't RIH from 7370' to 8324'- Orient tool face 160 right - RIH to 8419' Take survery check OK - Can't RIH from 8419' to 8760' 5/21/2004 00:00 - 02:00 2.00 CASE P LNR1 CBU 3 X - GPM 260 - PP 2900 - RPM 100 - TO 6.5 - PU 130- SO 60 - ROT 100 02:00 - 03:00 1.00 CASE P LNR1 Displace old Oil Mud with New Oil Mud - GPM 260 - PP 2800 03:00 - 05:00 2.00 CASE P LNR1 Pump out to shoe from 8760' to 7372' - Shut pump off - Pull from 7372' to 7275' - RIH from 7275' to 7372' - Run check survey - Good - Pull out from 7372' to 7250' - Pump out from 7250' to 6315' 05:00 - 08:00 3.00 CASE P LNR1 Monitor well - POOH to BHA - 08:00 - 08:30 0.50 CASE P LNR1 Lay down BHA 08:30 - 09:00 0.50 CASE P LNR1 Clear Rig floor 09:00 - 10:00 1.00 CASE P LNR1 Rig up Casing equipment to run 4" screen liner 10:00 - 17:00 7.00 CASE P LNR1 PJSM - Pick up 4" Liner - Make up Baker Flex-Lock Liner Hanger / ZXP packer / Liner running tool Printed: 6/1/2004 9:19:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/3/2004 Rig Release: 5/31/2004 Rig Number: Spud Date: 5/11/2004 End: 5/21/2004 17:00 - 22:00 5.00 CASE P LNR1 Run 4" liner to 8760' @ 2 mins per stand to minimize surge ,/ pressures - Screw into each stand with top drive to prevent flow back with oil base mud - Tag bottom pick up 1 foot off bottom - Shoe 8759' - Top Tie back 5694' - 264" screens ran - 40 4" blanks - 18 4.5" Class B tubing ran - No Hole problems running liner 22:00 - 22:30 0.50 CASE P LNR1 Rig up cement hose - Rig up chart recorder - Rig up BOP test pump to cement manifold to shear out ball/ seat 22:30 - 23:30 1.00 CASE P LNR1 Drop ball - make up single joint DP with head pin - cement hose - Pump ball on seat - 56 bbls @ 2 bpm 390 psi - Pressure up to 2000 psi to set hanger - Slack off 80K weight indicator - Pressure up to 3400 psi packer set - Con't pressure up to 4000 with mud pump - Swap over to BOP test pump - Pressure up to 5200 psi - No shear out - Bleed off to 4000 psi - Pressure up to 5350 psi ball sheared out - Close Annular - Open kill line - Pressure up on Annulus to 1500 psi - Hold for 15 mins - Bleed off pressure - Open annular - Pull running tool out of liner - 23:30 - 00:00 0.50 CASE P LNR1 Lay down single in mouse hole - Rig down cement hose and test equipment 5/22/2004 00:00 - 02:00 2.00 CASE P LNR1 Clean pits - Mix spacers for Displacement of Oil Mud to Flo Pro mud 02:00 - 03:30 1.50 CASE P LNR1 Displace Oil Mud - Pump 35 bbls LVT - 35 bbls 150 vis Poylmer Brine spacer - 30 bbls Safe Surf 0 - 30 bbls 150 vis Poylmer Brine spacer - 235 bbls Flo Pro - 10 bpm @ 1300 psi 03:30 - 06:00 2.50 CASE P LNR1 POOH with Baker Liner setting / running tool 06:00 - 06:30 0.50 CASE P LNR1 Lay down Baker running tool 06:30 - 07:30 1.00 STWHIP P PROD2 Pick up Baker whipstock BHA to rig floor 07:30 - 09:00 1.50 STWHI P P PROD2 Make up Baker whipstock 09:00 - 10:00 1.00 STWHIP P PROD2 Pick up collars - HWT - MWD - Surface test MWD 54 spm @ 500 psi 10:00 - 13:00 3.00 STWHIP P PROD2 RIH with Baker Whipstock to 5568' @ reduced speed 13:00 - 14:00 1.00 STWHIP P PROD2 Orient Whipstock to 41 degree left of high side - PU 114 - SO 99 - Slack off set bottom trip anchor with 18K down weight - PU 1 OK over pick up weight to verify anchor set - SO to 39K under SO weight to shear Whipstock - verify shear - 70 rpm - TQ 3 - ROT 110K 0-18:30 4.50 STWHIP P PROD2 Mill Window - TOW 5558' - BOW 5570' - Milled to 5582' - Full ,- V\?.j -~<o L gauge hole to 5575' - WOM 3 to 8 - RPM 89 to 125 - TQ 3 to 8 - GPM 285 - PP 1550 Milled window in 2.6 hrs Avg ROP 4.6 ftIhr Mill open hole in 1.76 hrs Avg ROP 6.7 ftIhr Total milling time 4.38 hrs Avg ROP 5.5 ftIhr 18:30 - 20:00 1.50 STWHIP P PROD2 Work mills through window - Pump Hi-vis sweep - CBU 2 X - GPM 285 @ 1500 psi 20:00 - 21 :30 1.50 STWHIP P PROD2 Monitor well- Well static - POOH from 5582' to 832' 21 :30 - 23:00 1.50 STWHIP P PROD2 Change out handling equipment to 31/2" - Stand back 3 1/2" HWT - 4 3/4" DC's - Lay down MWD - mills - (Mills in gauge) 23:00 - 23:30 0.50 STWHIP P PROD2 Flush stack - Function BOPs - Flush stack 2nd time 23:30 - 00:00 0.50 STWHIP P PROD2 Lay down Mills - XO's down beaver slide - Clear rig floor 5/23/2004 00:00 - 01 :00 1.00 STWHIP P PROD2 Make up MWD - Surface test MWD @ 54 spm - 900 psi 01 :00 - 03:00 2.00 STWHIP P PROD2 RIH from 272' to 5452 - Break Circ - Orient tool face 41 L of high side - Shut down pump - Con't RIH from 5450 to 5582' Printed: 6/1/2004 9: 19:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/3/2004 Rig Release: 5/31/2004 Rig Number: Spud Date: 5/11/2004 End: 5/23/2004 03:00 - 00:00 21.00 DRILL P PROD2 Directional drill from 5582' to 7369' - WOB 5 to 15 - GPM 271 - PP on 2150 - off 1970 - RPM 100 - TO on 4 to 6 - off 3 to 4 - PU 115 - SO 85 - ROT 100 5/24/2004 00:00 - 14:00 14.00 DRILL P PROD2 Directional Drill from 7369' to 8670' - TD 6 3/4" OB Lateral - WOB 5 to 15 - GPM 275 - PP 2310 on - off 2100 - RPM 100- TO on 5 - off 4 - PU 120 - SO 75 - ROT 100 14:00 - 16:00 2.00 CASE P PROD2 CBU 3 X - RPM 100 - TO 4 - GPM 285 - ICP 2240 - FCP 2200 - Monitor well - Well static 16:00 - 19:00 3.00 CASE P PROD2 Pump out to shoe from 8670' to 5643' at drlg rate - Shut down pump @ 5643' - Pull through window from 5643' - 5547' 19:00 - 19:30 0.50 CASE P PROD2 CBU 1 X @ 5547' - Hole clean 19:30 - 20:30 1.00 CASE P PROD2 Cut Drilling line 20:30 - 22:30 2.00 CASE P PROD2 POH from 5547' to 271' 22:30 - 23:30 1 .00 CASE P PROD2 Stand back HWT - Jars - Flex DC's - lay down MWD - Mud motor 23:30 - 00:00 0.50 CASE P PROD2 Make up Whipstock retrieving tool - 1 jt 3.5" HWT - Float sub 5/25/2004 00:00 - 01 :00 1.00 CASE P PROD2 Con't making up Whipstock retrieving BHA - Surface test MWD at 56 spm @ 650 psi 01 :00 - 02:30 1.50 CASE P PROD2 RIH from 918' to 5462' 02:30 - 03:00 0.50 CASE P PROD2 Orient to 41 L - slack off - Hook whipstock - Pick up to 165K - Jar loose - Monitor well - well static 03:00 - 06:30 3.50 CASE P PROD2 POH from 5528' - Hole swabbing - Reduce pulling speed 06:30 - 07:00 0.50 CASE P PROD2 Stand back BHA 07:00 - 09:00 2.00 CASE P PROD2 Lay down whipstock,clear floor 09:00 - 09:30 0.50 CASE P PROD2 Rig up to pick up 4.5" 12.6 slotted liner 09:30 - 11 :30 2.00 CASE P PROD2 PJSM, Picking up 4.5, 12.6#, L-80, Slotted Liner and Baker Hook wall hanger, total slotted jts 72, total 2970 ft, 2 jts solid jts., total 83.88 ft , total footage run 3053 ft., 74 jts., 11 :30 - 15:30 4.00 CASE P PROD2 Tripping in with drill pipe to liner top @5,707 Pull back out to working thru window 5558' - 5570' on 3rd. try, trip in with liner to 8557 15:30 - 17:00 1.50 CASE P PROD2 Hooking, Baker hook wall hanger hooked on 3 rd. try @ 5570, drop ball pumped @ 2 bbls min 450 psi, pressure up to 4000 psi release from hanger, pull up and shear ball with 4400 psi, liner pick up wt 125K, slack off wt. 93K, 115K after release from liner 17:00 - 20:00 3.00 CASE P PROD2 Tripping out with running tool, laying down same 20:00 - 21 :30 1.50 CASE P PROD2 PJSM, picking up LEM assy., seal assy, cross over jt 4.5, 3 jts 4.512.6#, L-80 IBT tubing, LEM tool, pup jt, casg swivel, 190-47 seal bore extension, ZXP packer w/11' tie back sleeve 21 :30 - 00:00 2.50 CASE P PROD2 Tripping in with LEM assy. to 4663' 5/26/2004 00:00 - 01 :30 1.50 CASE P PROD2 Tripping in with LEM assy. to 5740', LEM tool 5577 to 5542, top of packer and seal assy. 5501', PU wt. 115k, S/O wt. 100K, Picked up to 122K to ensure LEM tool was engaged 01 :30 - 02:00 0.50 CASE P PROD2 Drop ball and pumped down 2 bbls min 470 psi, pressure up on ball with 10,000 wt.on packer, to 3,750 psi, ball sheared with 3750 psi, 02:00 - 02:30 0.50 CASE P PROD2 Test Annulus to 1,500 psi for 15 min. good test, packer set., pull up 20 ft to clear top of packer 02:30 - 04:30 2.00 CASE P PROD2 Tripping out with running tools 04:30 - 05:00 0.50 CASE P PROD2 Breaking and laying down running tools 05:00 - 06:30 1.50 CASE P PROD2 Change out saver sub. on top drive 06:30 - 11 :30 5.00 CASE P PROD2 Pull wear ring, rig up and Test BOPs and manifold 250-3500 Printed: 6/1/2004 9: 19:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 5/3/2004 5/31/2004 Spud Date: 5/11/2004 End: 5/26/2004 06:30 - 11 :30 5.00 CASE P PROD2 psi, 5 min. per test, Hydrill 250-2500 psi, 5 min. per test, the right to witness test was wavier by Jeff Jones AOGCC, Install wear ring 11 :30 - 14:00 2.50 STWHIP P PROD3 Pick up Whipstock BHA, seal assy. space out 3.5 pipe- 6 jts, bottom anchor, whipstock, mills,1 it 3.5 hwdp, MWD, bumper jars, 11 43/4 dc, 13 its 3.5 hwdp 14:00 - 16:30 2.50 STWHIP P PROD3 Tripping in with whipstock to 5393 16:30 - 17:00 0.50 STWHIP P PROD3 Orient Whip stock 7 degrees to right of high side, set bottom anchor with 15K down weight, verify with 130K pick up weight, shear off with 40k down weight 17:00 - 22:00 5.00 STWHIP P PROD3 Milling window, top of window 5270 bottom window 5282', ~~.J Col open hole to 5294', mill with 75 to 125 rpms, 280 gals min 1400 psi, 3-8K mill weight 22:00 - 23:00 1.00 STWHIP P PROD3 Circ. Pump sweep and work window 23:00 - 00:00 1.00 STWHIP P PROD3 Tripping out with Mills 5/27/2004 00:00 - 01 :00 1.00 STWHIP P PROD3 Finish trip out to BHA 01 :00 - 01 :30 0.50 STWHIP P PROD3 Standing back BHA, lay down mills 01 :30 - 02:00 0.50 STWHIP P PROD3 Pick up Johnny Wacker, flush BOPS 02:00 - 03:00 1.00 STWHIP P PROD3 Picking up BHA, 6 .75 bit, surface test MWD 03:00 - 04:30 1.50 STWHIP P PROD3 Tripping in to 5250 04:30 - 06:00 1.50 STWHIP P PROD3 Cut and slip Drill line, service top drive 06:00 - 06:30 0.50 STWHIP P PROD3 Orient and slide thru window 5270 -5282 06:30 - 00:00 17.50 DRILL P PROD3 Directional Drill 5294-7082 with 100 rpms, 280 gals min, 2000 psi, AST 4.86, ART 4.76, TQ 4K, 5/28/2004 00:00 - 15:30 15.50 DRILL P PROD3 Directional Drill 7082- 8535' TD with 100 rpms, 280 gals min, 2000 psi 15:30 - 17:30 2.00 CASE P PROD3 Circ, three bottoms up with 285 gpm., 2100 psi, 100 rpms 17:30 - 21 :00 3.50 CASE P PROD3 Pumping out to window @ 5270 with full drilling rate, pulled into window with out pumping 21 :00 - 21 :30 0.50 CASE P PROD3 Circ bottoms up @ 5250 , with 285 glm, 1680 psi, 50 rpms 21 :30 - 23:30 2.00 CASE P PROD3 Tripping out to BHA 23:30 - 00:00 0.50 CASE P PROD3 Stand back dc, lay down Motor 5/29/2004 00:00 - 03:30 3.50 CASE P PROD3 Change out MWD tools, program New MWD , picking up whipstock pulling BHA, test MWD 03:30 - 05:00 1.50 CASE P PROD3 Tripping in to top of whipstock 05:00 - 05:30 0.50 DRILL P PROD3 Orient and latch on to whipstock, came free with 50,000 overpull 05:30 - 07:30 2.00 DRILL P PROD3 Tripping out with whipstock 07:30 - 10:00 2.50 DRILL P PROD3 Stand back DC, lay down whipstock and tools, clear floor 10:00 - 10:30 0.50 CASE P PROD3 Rig up to pickup 4.512.6# 1-80 Slotted liner 10:30 - 14:00 3.50 CASE P PROD3 PJSM, pickup 4.512.6# 1-80 Slotted liner, total 76 jts Slotted and 2 solid jts, Baker hook wall hanger 14:00 - 15:00 1.00 CASE P PROD3 Tripping in with liner on drill pipe to top of window, @ 5270-5282, Working liner into window, went in on first try 15:00 - 17:00 2.00 CASE P PROD3 Tripping in with liner to 8512', pick up wt 123 k, S/o wt. 90K, top of liner hanger 5265' 17:00 - 19:00 2.00 CASE P PROD3 Hook liner hanger on first try,unhooked and run hanger past window,Rehooked, drop ball and pumped down 2 bbls min 400 psi, pressure to 3500 psi, release from liner hanger, pull one stand rig up test pump shear ball with 4,800 psi 19:00 - 21 :00 2.00 CASE P PROD3 Tripping out with running tools, laying down same 21 :00 - 22:00 1.00 CASE P PROD3 PJSM,Picking up LEM assy. seal assy, Cross over jt. 5 its 4.5 12.6# L-80 IBT tubing,LEM tool,Csg swivel,ZXP liner top Printed: 6/1/2004 9:19:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-26 MPJ-26 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/3/2004 Rig Release: 5/31/2004 Rig Number: Spud Date: 5/11/2004 End: 5/29/2004 21 :00 - 22:00 1.00 CASE P PROD3 packer. 22:00 - 00:00 2.00 CASE P PROD3 Tripping in with LEM assy. 5/30/2004 00:00 - 02:00 2.00 CASE P PROD3 Tripping in with LEM assy. to 5525', seals @ 5525, Lem tool 5289 to 5254, top of ZXP packer 5228', pick up wt 115K slack off 100K, before for latch of LEM tool, pull to 125K to make sure we were latch. 02:00 - 03:00 1.00 CASE P PROD3 Drop ball, pump down @ 2 bbls min. 400 psi, set packer with 4000 psi, release from LEM tool, test annulus to 1500 psi for 15 min., good test 03:00 - 03:30 0.50 CASE P PROD3 Pull one stand, rig up HB&R and shear ball with 5,000 psi 03:30 - 07:00 3.50 CASE P PROD3 Tripping out with running tools, laying down excess pipe, lay down running tools 07:00 - 08:00 1.00 CASE P PROD3 laying down 4 3/4 des out of derrick 08:00 - 10:00 2.00 CASE P PROD3 Tripping in with Johnny wacker to 5217' 10:00 - 11 :00 1.00 CASE P PROD3 Slip and cut drilling ling, service top drive 11 :00 - 12:30 1.50 CASE P PROD3 Displace well with 9.1 brine, 12 bbls min, 120 rpms 12:30 - 16:00 3.50 CASE P PROD3 Laying down drill pipe 16:00 - 17:00 1.00 CASE P PROD3 Pull wear ring, Rig up to run 2 7/8 Tubing and ESP. 17:00 - 21:00 4.00 CASE P PROD3 PJSM, Picking up ESP assy, fill with oil,M/U ESP cable and test continuity 21 :00 - 00:00 3.00 CASE P PROD3 Picking up 27/8 Tubing, fill pipe and check conductivity every 2,000 ft. 5/31/2004 00:00 - 03:30 3.50 CASE P PROD3 Picking up 2 7/8 Tubing, fill pipe and check conductivity every 2,000 ft., Total 154 jts 4830 ft., ESP assy,XN nipple,two GLMS, 5,021', P/U wt, 80K, S/O wt 75K, used 84 clamps 03:30 - 04:00 0.50 CASE P PROD3 Picking up tubing hanger, with TWC in place 04:00 - 06:00 2.00 CASE P PROD3 Hooking up ESP cable to Penetrator, land tubing, test TWC to 2500 psi 06:00 - 07:00 1.00 CASE P PROD3 Nipple down BOPS 07:00 - 09:30 2.50 CASE P PROD3 Nipple up adapter and 2.5625 CIW tree, test to 5,000 psi 09:30 - 10:30 1.00 CASE P PROD3 Pull TWC, install BPV, Secure Well, Police area, Rig release @ 10.305/31/2004 Printed: 6/1/2004 9:19:46 AM 5M FMC Gen 5 System 11", 5M Head: FMC 11" X 2.875" Hanger: 2-718" EU 8 Rd T&B 2-1/2" CIW Type H BPV Profile Cameo 2 7/8" x1" KBMM-2 @49' MD 6,5 ppf, L-aO, EUE production tubing (Drift ID = 2.347", cap =0.00579 bpf) Cameo 2 7/8" x 1" KBMM-2 GLM @ 4852' MD 27/8" XN Nipple, 2.25" ID @ 49(ì9' MD 10-3/4", 45.5#l-80BTC Csg @ 3,068' MD Centrilift at 4963' MD I CentrUift Tandem Gas Separator Centrilift Tandem Seal Section Centrilift HP, v ¡ 40AMotor PumpMate & Centralizer Liner Top Packer & Hanger @ MD Baker HookwaU Hanger@ Window in casing@ Well Inclination @ Window = 75" Baker Baker ZXP @ 5,695' MD 4-1/2" Baker ZXP Liner pa Hookwall Hanger @ 5,501' MD Window in 7-5/8" casing@5,558' Well inclination @ Window = 78" DATE REV. BY 0610712004 JRC Point J-26Ml . . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well' MPJ-26 02-Jun-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window I Kickoff Survey: Projected Survey: 8,304.92' MD 7,280.00' MD 8,760.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Þ1 / I ¡ I J I Date C(~a', "\ Signed -~ [)/,Jk...A Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) À ð '-I- ð ,<I Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ·26 Job No. AKZZ3066223, Surveyed: 20 May, 2004 Survey Report 3 June, 2004 Your Ref: API 500292320500 ,</. Surface Coordinates: 6014554.57 N, 552054.97 E (70· 27' 01.8108" N, 149· 34' 31.0662" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1014554.57 N, 52054.97 E (Grid) Surface Coordinates relative to Structure Reference: 1134.98 N, 627.81 E (True) Kelly Bushing Elevation: 68. 70ft above Mean Sea Level Kelly Bushing Elevation: 68. 70ft above Project V Reference Kelly Bushing Elevation: 68. 70ft above Structure Reference spe..........y-suf'1 DRILLING SESRvtces A Halliburton Company . ..... DEFINITIVE e e Survey Ref: svy1413 .- Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 Your Ref: API 500292320500 Job No. AKZZ3066223, Surveyed: 20 May, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8304.92 89.510 344.810 3756.05 3824.75 777.85 N 5429.93 W 6015294.47 N 546619.74 E 5468.69 Tie-on Point 8330.00 88.700 345.560 3756.45 3825.15 802.09 N 5436.34 W 6015318.67 N 546613.16 E 4.401 5480.24 Window Point 8352.63 87.960 346.230 3757.10 3825.80 824.03 N 5441.85 W 6015340.57 N 546607.50 E 4.410 5490.42 8400.63 86.050 346.340 3759.61 3828.31 870.60 N 5453.22 W 6015387.05 N 546595.81 E 3.986 5511.68 8449.75 87.530 346.590 3762.36 3831.06 918.28 N 5464.69 W 6015434.65 N 546584.00 E 3.056 5533.30 8494.73 87.220 346.760 3764.42 3833.12 962.00 N 5475.05 W 6015478.30 N 546573.34 E 0.786 5552.96 e 8542.55 85.990 347.010 3767.25 3835.95 1008.49 N 5485.88 W 6015524.72 N 546562.18 E 2.625 5573.68 8591.64 84.310 345.760 3771.41 3840.11 1056.03 N 5497.39 W 6015572.17 N 546550.33 E 4.260 5595.30 8636.53 86.970 345.750 3774.82 3843.52 1099.41 N 5508.41 W 6015615.47 N 546539.02 E 5.926 5615.53 8687.33 87.040 345.960 3777.47 3846.17 1148.60 N 5520.80 W 6015664.58 N 546526.28 E 0.435 5638.37 1./ 8760.00 87.040 345.960 3781.22 3849.92 ~. 1219.00 N 5538.41 W 6015734.86 N 546508.18 E 0.000 5670.94 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 282.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8760.00ft., The Bottom Hole Displacement is 5670.97ft., in the Direction of 282.413° (True). Comments e Measured Depth (ft) 8304.92 8330.00 8760.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3824.75 3825.15 3849.92 777.85 N 802.09 N 1219.00N 5429.93 W 5436.34 W 5538.41 W Tie-on Point Window Point Projected Survey 3 June, 2004 - 7:33 Page 2 of 3 DrillQuest 3.03.06.002 Milne Point Unit .- Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 Your Ref: API 500292320500 Job No. AKZZ3066223, Surveyed: 20 May, 2004 BPXA Survey too/program for MPJ-26 From Measured Vertical Depth Depth (ft) (ft) 0.00 631.00 0.00 630.50 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 631.00 8760.00 e 630.50 CB-SS-GYRO (MPJ-26 PB1 GYRO) 3849.92 MWD+IIFR+MS (MPJ-26 PB1) e 3 June, 2004 - 7:33 DrillQuest 3.03.06.002 Page 3 of 3 . . 02-Jun-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPJ-26 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,304.92' MD 7,280.00' MD 8,760.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /I ( J ¡( /1 I Date qJ~lðtN Signed ~ UItJ,t../ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) rÀO"i - ô ~ tI .. , Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ·26 MWD e Job No. AKMW3066223, Surveyed: 20 May, 2004 Survey Report 3 June, 2004 Your Ref: API 500292320500 Surface Coordinates: 6014554.57 N, 552054.97 E (70027' 01.8108" N, 149034' 31.0662" WJ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014554.57 N, 52054.97 E (Grid) Surface Coordinates relative to Structure Reference: 1134.98 N, 627.81 E (True) Kelly Bushing Elevation: 68. 70ft above Mean Sea Level Kelly Bushing Elevation: 68.70ft above Project V Reference Kelly Bushing Elevation: 68. 70ft above Structure Reference spe.............y-sul'1 DRILLING SERVICe¡S A Halliburton Company Survey Ref: svy1414 ~ Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ·26 MWD Your Ref: API 500292320500 Job No. AKMW3066223, Surveyed: 20 May, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8304.92 89.510 345.540 3756.11 3824.81 839.29 N 5404.63 W 6015356.09 N 546644.60 E 5457.43 Tie-on Point 8330.00 88.700 345.560 3756.50 3825.20 863.58 N 5410.89 W 6015380.33 N 546638.18 E 3.231 5468.85 Window Point 8352.63 87.960 346.870 3757.16 3825.86 885.55 N 5416.28 W 6015402.26 N 546632.63 E 6.646 5478.91 8400.63 86.050 346.170 3759.66 3828.36 932.16 N 5427.46 W 6015448.79 N 546621.14 E 4.237 5499.99 8449.75 87.530 347.030 3762.42 3831.12 979.86 N 5438.82 W 6015496.42 N 546609.44 E 3.483 5521.51 8494.73 87.220 347.090 3764.48 3833.18 1023.65 N 5448.88 W 6015540.14 N 546599.07 E 0.702 5540.89 e 8542.55 85.990 347.530 3767.31 3836.01 1070.22 N 5459.37 W 6015586.63 N 546588.26 E 2.731 5561.30 8591.64 84.310 345.910 3771.46 3840.16 1117.83 N 5470.60 W 6015634.16 N 546576.69 E 4.746 5582.66 8636.53 86.970 346.320 3774.87 3843.57 1161.28 N 5481.34 W 6015677.53 N 546565.65 E 5.995 5602.64 8687.33 87.040 346.770 3777.52 3846.22 1210.61 N 5493.15 W 6015726.78 N 546553.50 E 0.895 5624.94 8760.00 87.040 346.770 3781.28 3849.98 1281.26N 5509.76 W 6015797.31 N 546536.40 E 0.000 5656.58 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 282.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8760.00ft., The Bottom Hole Displacement is 5656.77ft., in the Direction of 283.091 0 (True). Comments e Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8304.92 8330.00 8760.00 3824.81 3825.20 3849.98 839.29 N 863.58 N 1281.26 N 5404.63 W 5410.89 W 5509.76 W Tie-on Point Window Point Projected Survey 3 June, 2004 - 8:41 Page 2 of 3 DrillQuest 3.03.06.002 Milne Point Unit \. Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 MWD Your Ref: API 500292320500 Job No. AKMW3066223, Surveyed: 20 May, 2004 BPXA Survey tool prOf/ram for MPJ-26 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 631.00 0.00 630.50 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 631.00 8760.00 e 630.50 CB-SS-GYRO (MPJ-26 PB1 GYRO) 3849.98 MWD Magnetic (MPJ-26 PB1 MWD) e 3 June, 2004 - 8:41 DrilIQuest~0~0~002 Page 3 of 3 . . 02-Jun-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPJ..æ PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,074.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date3 J ~ ,(M'1. Signed W ð//d Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ò'-t-ÐCðc-{ Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ-26 PS1 Job NO~KZZ3066223, Surveyed: 19 May, 200~ Survey Report 4 June, 2004 Your Ref: API 500292320570 Surface Coordinates: 6014554.57 N, 552054.97 IE (70027' 01.8108" N, 149034'31.0662" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1014554.57 N, 52054.97 IE (Grid) Surface Coordinates relative to Structure Reference: 1134.98 N, 627.81 E (True) Kelly Bushing Elevation: 68. 70ft above Mean Sea Level Kelly Bushing Elevation: 68. 70ft above Project V Reference Kelly Bushing Elevation: 68.70ft above Structure Reference st=!er"''''''\/-SUI! DR IL L IN GSe RVI c:: es A Halliburton Company , DEFINITIVE e e Survey Ref: svy1409 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PB1 Your Ref: API 500292320570 Job No. AKZZ3066223, Surveyed: 19 May, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 0.00 0.000 0.000 -68.70 0.00 0.00 N 0.00 E 6014554.57 N 552054.97 E 0.00 CB-SS-GYRO 89.00 0.900 73.000 20.30 89.00 0.20 N 0.67 E 6014554.78 N 552055.64 E 1.011 -0.61 180.00 0.250 78.000 111.29 179.99 0.45N 1.55 E 6014555.04 N 552056.51 E 0.716 -1.41 211.00 0.300 341.000 142.29 210.99 0.55N 1.59 E 6014555.13 N 552056.55 E 1.333 -1.43 272.00 0.400 301.000 203.29 271.99 0.81 N 1.35 E 6014555.39 N 552056.32 E 0.422 -1.14 e 367.00 1.300 254.000 298.28 366.98 0.68N 0.03 E 6014555.25 N 552055.00 E 1.124 0.12 418.00 1.800 251.000 349.26 417.96 0.26N 1.28W 6014554.82 N 552053.69 E 0.993 1.31 448.00 1.900 254.000 379.24 447.94 0.03S 2.21 W 6014554.52 N 552052.76 E 0.464 2.15 533.00 3.300 243.000 464.16 532.86 1.53 S 5.74W 6014553.00 N 552049.24 E 1.741 5.27 631.00 6.300 256.000 561.80 630.50 4.11 S 13.47 W 6014550.36 N 552041.53 E 3.237 12.25 MWD+IIFR+MS 752.46 7.740 267.670 682.36 751.06 6.06S 28.11 W 6014548.32 N 552026.90 E 1.663 26.11 855.42 12.330 270.330 783.71 852.41 6.28S 46.04 W 6014547.97 N 552008.97 E 4.480 43.56 952.12 18.730 269.840 876.84 945.54 6.26S 71.92 W 6014547.81 N 551983.10 E 6.620 68.81 1048.35 24.920 263.420 966.14 1034.84 8.63 S 107.55 W 6014545.19 N 551947.48 E 6.885 103.07 1133.80 28.610 264.800 1042.42 1111.12 12.55 S 145.82 W 6014541.00 N 551909.24 E 4.379 139.56 1229.65 31.660 266.060 1125.31 1194.01 16.36 S 193.78 W 6014536.86 N 551861.31 E 3.250 185.53 1324.78 34.290 268.190 1205.11 1273.81 18.92 S 245.48 W 6014533.94 N 551809.62 E 3.021 235.42 1420.21 36.320 268.230 1282.98 1351.68 20.64 S 300.61 W 6014531.83 N 551754.52 E 2.127 288.83 1518.98 36.720 266.580 1362.36 1431.06 23.31 S 359.32 W 6014528.75 N 551695.82 E 1.073 345.55 1614.76 37.230 264.370 1438.88 1507.58 27.86 S 416.74 W 6014523.80 N 551638.44 E 1.486 400.58 1706.96 36.780 263.560 1512.51 1581.21 33.69 S 471.92 W 6014517.59 N 551583.29 E 0.720 453.16 1806.04 39.560 264.190 1590.40 1659.10 40.21 S 532.80 W 6014510.64 N 551522.46 E 2.833 511.14 e 1902.45 39.850 263.570 1664.57 1733.27 46.78 S 594.04 W 6014503.64 N 551461.27 E 0.509 569.47 1996.66 41.480 263.560 1736.03 1804.73 53.66 S 655.04 W 6014496.34 N 551400.32 E 1.730 627.49 2092.10 41 .400 263.590 1807.58 1876.28 60.73 S 717.81 W 6014488.83 N 551337.60 E 0.086 687.20 2190.72 41.090 263.080 1881.73 1950.43 68.27 S 782.39 W 6014480.83 N 551273.08 E 0.464 748.57 2286.63 42.260 264.420 1953.37 2022.07 75.21 S 845.78 W 6014473.46 N 551209.74 E 1.533 808.91 2381.64 43.070 265.680 2023.23 2091.93 80.76 S 909.92 W 6014467.46 N 551145.63 E 1.239 870.30 2476.54 43.920 265.980 2092.08 2160.78 85.50 S 975.07 W 6014462.26 N 551080.52 E 0.922 932.83 2572.63 43.950 265.650 2161.27 2229.97 90.37 S 1041.56W 6014456.93 N 551014.07 E 0.240 996.65 2669.07 43.210 265.440 2231.13 2299.83 95.53 S 1107.84W 6014451.30 N 550947.82 E 0.782 1060.21 2765.69 42.790 265.840 2301.80 2370.50 100.54 S 1173.55 W 6014445.83 N 550882.15 E 0.518 1123.23 2860.25 42.120 265.620 2371.56 2440.26 105.30 S 1237.20 W 6014440.64 N 550818.54 E 0.726 1184.30 2957.08 41.540 265.820 2443.71 2512.41 110.12 S 1301.60 W 6014435.37 N 550754.18 E 0.615 1246.09 3052.79 40.840 266.220 2515.74 2584.44 114.49 S 1364.47 W 6014430.55 N 550691.33 E 0.781 1306.49 4 June, 2004 - 14:56 Page 2 of6 Dri/lQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PS1 Your Ref: API 500292320570 Job No. AKZZ3066223, Surveyed: 19 May, 2004 SPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3172.22 39.540 265.890 2606.97 2675.67 119.79 S 1441.36W 6014424.71 N 550614.48 E 1.103 1380.37 3266.58 41.250 265.470 2678.83 2747.53 124.40 S 1502.33 W 6014419.68 N 550553.54 E 1.835 1438.86 3362.99 41 .270 265.650 2751.31 2820.01 129.32 S 1565.72 W 6014414.31 N 550490.19 E 0.125 1499.64 3459.09 40.660 265.320 2823.87 2892.57 134.28 S 1628.53 W 6014408.92 N 550427.42 E 0.673 1559.85 3555.47 41.460 266.310 2896.54 2965.24 138.90 S 1691.67W 6014403.86 N 550364.32 E 1.070 1620.45 e 3651.68 41.310 266.620 2968.73 3037.43 142.82 S 1755.15 W 6014399.49 N 550300.86 E 0.264 1681.54 3748.11 41.090 266.490 3041.29 3109.99 146.64 S 1818.55 W 6014395.24 N 550237.48 E 0.245 1742.58 3844.29 40.810 266.430 3113.93 3182.63 150.53 S 1881.47W 6014390.90 N 550174.60 E 0.294 1803.13 3940.35 41.070 266.430 3186.49 3255.19 154.45 S 1944.29 W 6014386.55 N 550111.80 E 0.271 1863.58 4036.45 43.310 266.760 3257.69 3326.39 158.28 S 2008.71 W 6014382.27 N 550047.41 E 2.342 1925.60 4131.46 46.250 266.210 3325.12 3393.82 162.39 S 2075.50 W 6014377.69 N 549980.65 E 3.121 1989.88 4226.81 49.040 265.590 3389.36 3458.06 167.43 S 2145.78 W 6014372.15 N 549910.41 E 2.965 2057.36 4322.38 52.740 264.460 3449.63 3518.33 173.88 S 2219.64 W 6014365.19 N 549836.60 E 3.979 2128.02 4418.98 53.330 263.870 3507.72 3576.42 181.73 S 2296.42 W 6014356.80 N 549759.87 E 0.782 2201.24 4513.36 55.270 265.840 3562.80 3631.50 188.59 S 2372.75 W 6014349.41 N 549683.60 E 2.664 2274.22 4607.68 57.360 268.020 3615.11 3683.81 192.77 S 2451.11 W 6014344.68 N 549605.27 E 2.934 2349.77 4705.03 60.360 268.070 3665.45 3734.15 195.61 S 2534.37 W 6014341.26 N 549522.03 E 3.082 2430.41 4800.88 62.410 267.150 3711.35 3780.05 199.13 S 2618.44 W 6014337.16 N 549437.99 E 2.299 2511.67 4896.34 64.630 267.230 3753.91 3822.61 203.32 S 2703.77 W 6014332.37 N 549352.68 E 2.327 2594.03 4993.96 64.630 267.380 3795.74 3864.44 207.46 S 2791.88 W 6014327.61 N 549264.61 E 0.139 2679.10 5089.41 64.760 265.880 3836.54 3905.24 212.54 S 2878.02 W 6014321.94 N 549178.51 E 1.427 2762.05 5185.17 70.040 263.170 3873.33 3942.03 221.01 S 2965.98 W 6014312.85 N 549090.61 E 6.101 2846.03 e 5281.14 75.080 263.390 3902.09 3970.79 231.71 S 3056.88 W 6014301.51 N 548999.79 E 5.256 2932.40 5326.99 76.430 263.620 3913.37 3982.07 236.74 S 3101.03W 6014296.17 N 548955.67 E 2.984 2974.39 5376.50 78.710 264.310 3924.02 3992.72 241.82 S 3149.11 W 6014290.76 N 548907.63 E 4.802 3020.19 5424.02 79.270 263.670 3933.10 4001.80 246.71 S 3195.50 W 6014285.55 N 548861.27 E 1.771 3064.39 5472.23 79.010 263.130 3942.18 4010.88 252.15 S 3242.53 W 6014279.78 N 548814.28 E 1.225 3109.10 5521.77 78.890 262.020 3951.68 4020.38 258.43 S 3290.74 W 6014273.16 N 548766.11 E 2.212 3154.78 5569.00 78.390 261.570 3960.98 4029.68 265.04 S 3336.57 W 6014266.23 N 548720.33 E 1.412 3198.06 5665.16 84.430 263.190 3975.34 4044.04 277.63 S 3430.77 W 6014252.98 N 548626.22 E 6.498 3287.23 5713.11 88.270 263.710 3978.39 4047.09 283.09 S 3478.30 W 6014247.19 N 548578.73 E 8.081 3332.42 5760.65 90.620 263.420 3978.85 4047.55 288.42 S 3525.54 W 6014241.54 N 548531.53 E 4.981 3377.35 5804.97 92.960 262.970 3977.47 4046.17 293.66 S 3569.52 W 6014235.98 N 548487.59 E 5.376 3419.12 5857.03 96.490 262.640 3973.18 4041.88 300.16 S 3620.99 W 6014229.12 N 548436.17 E 6.810 3467.92 5904.37 99.920 262.860 3966.42 4035.12 306.07 S 3667.46 W 6014222.89 N 548389.74 E 7.260 3511.98 4 June, 2004 - 14:56 Page 3 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PS1 Your Ref: API 500292320570 Job No. AKZZ3066223, Surveyed: 19 May, 2004 SPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 5952.67 101.070 263.890 3957.63 4026.33 311.55S 3714.63 W 6014217.08 N 548342.60 E 3.173 3556.82 5999.92 102.690 264.250 3947.90 4016.60 316.33 S 3760.62 W 6014211.98 N 548296.65 E 3.509 3600.65 6048.20 104.600 264.470 3936.51 4005.21 320.94 S 3807.31 W 6014207.04 N 548249.99 E 3.981 3645.21 6096.21 105.950 264.240 3923.86 3992.56 325.50 S 3853.40 W 6014202.16 N 548203.94 E 2.850 3689.19 6143.81 107.800 263.760 3910.04 3978.74 330.26 S 3898.70 W 6014197.09 N 548158.68 E 4.005 3732.35 e 6191.45 108.910 263.760 3895.04 3963.74 335.17 S 3943.64 W 6014191.86 N 548113.76 E 2.330 3775.14 6238.52 109.380 263.630 3879.61 3948.31 340.05 S 3987.84 W 6014186.67 N 548069.60 E 1.032 3817.20 6291.81 108.540 267.520 3862.29 3930.99 343.94 S 4038.08 W 6014182.43 N 548019.39 E 7.081 3865.38 6334.54 108.150 270.950 3848.83 3917.53 344.48 S 4078.63 W 6014181.61 N 547978.85 E 7.674 3904.83 6408.47 108.470 272.560 3825.61 3894.31 342.33 S 4148.78 W 6014183.27 N 547908.68 E 2.112 3973.75 6432.88 108.540 272.520 3817.86 3886.56 341.30 S 4171.90W 6014184.13 N 547885.55 E 0.326 3996.54 6476.70 105.620 274.150 3804.99 3873.69 338.86 S 4213.71 W 6014186.28 N 547843.73 E 7.553 4037.88 6528.84 101.950 272.780 3792.57 3861.27 335.81 S 4264.25 W 6014188.98 N 547793.17 E 7.487 4087.86 6576.48 99.300 275.930 3783.78 3852.48 332.25 S 4310.93 W 6014192.22 N 547746.47 E 8.554 4134.19 6624.60 96.930 275.750 3776.99 3845.69 327.40 S 4358.31 W 6014196.73 N 547699.05 E 4.939 4181.49 6672.04 95.690 276.890 3771.78 3840.48 322.21 S 4405.18 W 6014201.60 N 547652.15 E 3.541 4228.35 6720.83 93.150 278.310 3768.02 3836.72 315.78 S 4453.39 W 6014207.69 N 547603.89 E 5.960 4276.81 6768.46 90.800 279.880 3766.37 3835.07 308.25 S 4500.39 W 6014214.89 N 547556.84 E 5.932 4324.31 6816.32 90.000 282.500 3766.04 3834.74 298.96 S 4547.33 W 6014223.85 N 547509.84 E 5.724 4372.15 6861.51 87.470 284.500 3767.04 3835.74 288.42 S 4591.26 W 6014234.09 N 547465.84 E 7.136 4417.32 6913.62 87.470 286.660 3769.34 3838.04 274.44 S 4641 .40 W 6014247.72 N 547415.60 E 4.141 4469.31 6961.60 89.440 289.190 3770.63 3839.33 259.68 S 4687.03 W 6014262.16 N 547369.87 E 6.681 4517.06 e 7009.61 90.370 292.870 3770.71 3839.41 242.45 S 4731.83 W 6014279.07 N 547324.95 E 7.906 4564.54 7054.28 89.010 295.600 3770.95 3839.65 224.12 S 4772.56 W 6014297.12 N 547284.09 E 6.828 4608.29 7104.67 92.040 296.840 3770.49 3839.19 201.86 S 4817.76 W 6014319.06 N 547238.74 E 6.497 4657.26 7152.49 92.840 301.830 3768.45 3837.15 178.46 S 4859.40 W 6014342.17 N 547196.94 E 10.559 4703.00 7201.98 92.590 307.090 3766.11 3834.81 150.50 S 4900.14 W 6014369.85 N 547156.00 E 10.628 4748.87 7249.53 90.490 310.690 3764.83 3833.53 120.66 S 4937.13 W 6014399.42 N 547118.80 E 8.762 4791.49 _ C\-\ S~-\~k:. 7297.76 89.940 313.350 3764.65 3833.35 88.38 S 4972.96 W 6014431.45 N 547082.75 E 5.632 4833.50 7347.50 90.680 319.450 3764.38 3833.08 52.38 S 5007.24 W 6014467.22 N 547048.22 E 12.353 4874.82 \0<:>\ l').~-~~~ 7393.70 91.230 322.590 3763.61 3832.31 16.47 S 5036.30 W 6014502.92 N 547018.91 E 6.899 4911.02 ~ 1t'\ ~ ' 7442.00 90.560 326.220 3762.86 3831.56 22.79 N 5064.40 W 6014541.98 N 546990.53 E 7.642 4947.03 7489.67 89.140 329.760 3762.98 3831.68 63.20 N 5089.66 W 6014582.22 N 546964.99 E 8.001 4980.51 7536.87 88.020 333.470 3764.15 3832.85 104.71 N 5112.09 W 6014623.57 N 546942.27 E 8.208 5011.46 7585.91 88.640 335.410 3765.58 3834.28 148.93 N 5133.24 W 6014667.64 N 546920.82 E 4.151 5041.76 4 June, 2004· 14:56 Page 4 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PS1 Your Ref: API 500292320570 Job No. AKZZ3066223, Surveyed: 19 May, 2004 SPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 7635.20 88.210 339.430 3766.93 3835.63 194.41 N 5152.15 W 6014712.99 N 546901.58 E 8.199 5070.16 7682.23 87.220 342.470 3768.81 3837.51 238.83 N 5167.49 W 6014757.29 N 546885.94 E 6.793 5094.83 7731.65 89.880 343.940 3770.06 3838.76 286.12 N 5181.76 W 6014804.48 N 546871.33 E 6.149 5119.09 7776.73 91.230 345.180 3769.62 3838.32 329.57 N 5193.77 W 6014847.85 N 546859.03 E 4.066 5140.29 7826.57 93.090 344.360 3767.75 3836.45 377.62 N 5206.85 W 6014895.81 N 546845.61 E 4.078 5163.56 e 7872.59 96.370 342.950 3763.95 3832.65 421.62 N 5219.75 W 6014939.72 N 546832.40 E 7.754 5185.76 7923.57 97.740 343.720 3757.69 3826.39 470.09 N 5234.26 W 6014988.09 N 546817.55 E 3.077 5210.51 7968.21 97.610 343.460 3751.73 3820.43 512.53 N 5246.76 W 6015030.44 N 546804.76 E 0.647 5231.98 8000.57 97.430 343.140 3747.49 3816.19 543.26 N 5255.98 W 6015061.10 N 546795.33 E 1.127 5247.69 8074.00 97.430 343.140 3738.00 3806.70 612.94 N 5277.10 W 6015130.63 N 546773.72 E 0.000 5283.52 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 282.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8074.00ft., The Bottom Hole Displacement is 5312.57ft., in the Direction of 276.625° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) e Comment 8074.00 3806.70 612.94 N 5277.10 W Projected Survey 4 June, 2004 - 14:56 Page 5 of 6 DrillQuest 3.03.06.002 Milne Point Unit .. Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PS1 Your Ref: API 500292320570 Job No. AKZZ3066223, Surveyed: 19 May, 2004 SPXA Survey tool program for MPJ-26 PS1 From Measured Vertical Depth Depth (ft) (ft) 0.00 631.00 0.00 630.50 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 631.00 8074.00 e 630.50 CB-SS-GYRO 3806.70 MWD+IIFR+MS e 4 June, 2004· 14:56 DrillQuest 3.03.06.002 Page 60f6 . . 02-Jun-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPJ-26 PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,074.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date <1jvw-~,,\ Signed U oJJJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Ât:1t.{ - ~W "" e e . Survey Ref: svy1410 Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ-26 PS1 MWD Job No. AKMW3066223, Surveyed: 19 May, 2004 Survey Report 4 June, 2004 Your Ref: API 5002923205070 Surface Coordinates: 6014554.57 N, 552054.97 E (70027' 01.8108" N, 149034' 31.0662" vv,J Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1014554.57 N, 52054.97 E (Grid) Surface Coordinates relative to Structure Reference: 1134.98 N, 627.81 E (True) Kelly Bushing Elevation: 68.70ft above Mean Sea Level Kelly Bushing Elevation: 68. 70ft above Project V Reference Kelly Bushing Elevation: 68. 70ft above Structure Reference ...,., Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ·26 PS1 MWD Your Ref: API 5002923205070 Job No. AKMW3066223, Surveyed: 19 May, 2004 SPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -68.70 0.00 0.00 N 0.00 E 6014554.57 N 552054.97 E 0.00 CB-SS-GYRO 89.00 0.900 73.000 20.30 89.00 0.20N 0.67 E 6014554.78 N 552055.64 E 1.011 -0.61 180.00 0.250 78.000 111.29 179.99 0.45 N 1.55 E 6014555.04 N 552056.51 E 0.716 -1.41 211.00 0.300 341.000 142.29 210.99 0.55N 1.59 E 6014555.13 N 552056.55 E 1.333 -1.43 272.00 0.400 301.000 203.29 271.99 0.81 N 1.35 E 6014555.39 N 552056.32 E 0.422 -1.14 e 367.00 1.300 254.000 298.28 366.98 0.68N 0.03 E 6014555.25 N 552055.00 E 1.124 0.12 418.00 1.800 251.000 349.26 417.96 0.26N 1.28W 6014554.82 N 552053.69 E 0.993 1.31 448.00 1.900 254.000 379.24 447.94 0.03 S 2.21 W 6014554.52 N 552052.76 E 0.464 2.15 533.00 3.300 243.000 464.16 532.86 1.53 S 5.74W 6014553.00 N 552049.24 E 1.741 5.27 631.00 6.300 256.000 561.80 630.50 4.11 S 13.47 W 6014550.36 N 552041.53 E 3.237 12.25 MWD Magnetic 752.46 7.740 268.380 682.36 751.06 5.96S 28.12 W 6014548.42 N 552026.90 E 1.713 26.14 855.42 12.330 270.330 783.71 852.41 6.09 S 46.05 W 6014548.16 N 552008.96 E 4.470 43.61 952.12 18.730 270.420 876.84 945.54 5.92 S 71.93 W 6014548.15 N 551983.09 E 6.618 68.90 1048.35 24.920 264.030 966.14 1034.84 7.91 S 107.58 W 6014545.91 N 551947.45 E 6.881 103.25 1133.80 28.610 265.560 1042.42 1111.12 11.37 S 145.89 W 6014542.18 N 551909.16 E 4.393 139.89 1229.65 31.660 266.180 1125.31 1194.01 14.82 S 193.88 W 6014538.39 N 551861.19 E 3.199 185.96 1324.78 34.290 270.080 1205.11 1273.81 16.45 S 245.61 W 6014536.41 N 551809.48 E 3.552 236.08 1420.21 36.320 269.000 1282.99 1351.69 16.91 S 300.75 W 6014535.56 N 551754.34 E 2.225 289.79 1518.98 36.720 267.330 1362.37 1431.07 18.79 S 359.50 W 6014533.27 N 551695.61 E 1.085 346.70 1614.76 37.230 264.910 1438.89 1507.59 22.70 S 416.96 W 6014528.96 N 551638.18 E 1.610 401.93 1706.96 36.780 263.520 1512.52 1581.22 28.29 S 472.17 W 6014522.99 N 551583.01 E 1.030 454.58 1806.04 39.560 264.360 1590.41 1659.11 34.74 S 533.05 W 6014516.11 N 551522.17 E 2.854 512.59 e 1902.45 39.850 263.720 1664.58 1733.28 41.13 S 594.31 W 6014509.29 N 551460.96 E 0.520 570.96 1996.66 41 .480 263.330 1736.04 1804.74 48.06 S 655.31 W 6014501.94 N 551400.02 E 1.751 628.97 2092.10 41 .400 263.550 1807.59 1876.29 55.27 S 718.06 W 6014494.28 N 551337.32 E 0.174 688.63 2190.72 41.090 260.660 1881.75 1950.45 64.20 S 782.45 W 6014484.91 N 551272.99 E 1.957 749.52 2286.63 42.260 265.500 1953.40 2022.10 71.85 S 845.71 W 6014476.82 N 551209.78 E 3.569 809.59 2381.64 43.070 266.030 2023.26 2091.96 76.60 S 909.93 W 6014471.62 N 551145.60 E 0.933 871.21 2476.54 43.920 266.570 2092.11 2160.81 80.81 S 975.11 W 6014466.95 N 551080.45 E 0.978 933.90 2572.63 43.950 265.310 2161.31 2230.01 85.53 S 1041.61 W 6014461.77 N 551013.98 E 0.910 997.76 2669.07 43.210 265.990 2231.17 2299.87 90.58 S 1107.90 W 6014456.26 N 550947.73 E 0.908 1061.34 2765.69 42.790 266.280 2301.83 2370.53 95.02 S 1173.64 W 6014451.36 N 550882.02 E 0.480 1124.53 2860.25 42.120 266.670 2371.60 2440.30 98.94 S 1237.35 W 6014446.98 N 550818.34 E 0.761 1185.84 2957.08 41.540 266.220 2443.75 2512.45 102.95 S 1301.81 W 6014442.53 N 550753.92 E 0.674 1247.86 3052.79 40.840 267.080 2515.77 2584.47 106.63 S 1364.73 W 6014438.41 N 550691.02 E 0.941 1308.46 4 June, 2004 - 10:24 Page 20f6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PS1 MWD Your Ref: API 5002923205070 Job No. AKMW3066223, Surveyed: 19 May, 2004 SPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3172.22 39.540 265.570 2607.01 2675.71 111.56 S 1441.63W 6014432.94 N 550614.15 E 1.360 1382.43 3266.58 41.250 264.590 2678.87 2747.57 116.81 S 1502.55 W 6014427.26 N 550553.27 E 1.933 1440.73 3362.99 41.270 265.1 00 2751.34 2820.04 122.53 S 1565.88 W 6014421.11 N 550489.99 E 0.349 1501.28 3459.09 40.660 265.050 2823.91 2892.61 127.93 S 1628.65 W 6014415.26 N 550427.26 E 0.636 1561.35 3555.47 41.460 266.300 2896.58 2965.28 132.70 S 1691.77 W 6014410.05 N 550364.17 E 1.189 1621.90 e 3651.68 41.310 266.660 2968.77 3037.47 136.61 S 1755.26 W 6014405.70 N 550300.71 E 0.292 1683.00 3748.11 41.090 266.820 3041.32 3110.02 140.22 S 1818.67 W 6014401.65 N 550237.32 E 0.253 1744.10 3844.29 40.810 267.100 3113.97 3182.67 143.56 S 1881.62 W 6014397.87 N 550174.40 E 0.348 1804.79 3940.35 41.070 267.220 3186.53 3255.23 146.68 S 1944.49 W 6014394.31 N 550111.56E 0.283 1865.46 4036.45 43.310 267.640 3257.73 3326.43 149.57 S 2008.96 W 6014390.97 N 550047.11 E 2.349 1927.74 4131.46 46.250 267.130 3325.16 3393.86 152.63 S 2075.80 W 6014387.44 N 549980.28 E 3.117 1992.30 4226.81 49.040 266.370 3389.39 3458.09 156.64 S 2146.14 W 6014382.95 N 549909.97 E 2.985 2060.07 4322.38 52.740 265.130 3449.67 3518.37 162.15S 2220.08 W 6014376.91 N 549836.08 E 4.000 2131.01 4418.98 53.330 264.490 3507.76 3576.46 169.14S 2296.94 W 6014369.39 N 549759.26 E 0.808 2204.50 4513.36 55.270 266.560 3562.84 3631.54 175.10 S 2373.35 W 6014362.90 N 549682.91 E 2.720 2277.75 4607.68 57.360 269.000 3615.15 3683.85 178.12 S 2451.76 W 6014359.33 N 549604.52 E 3.089 2353.61 4705.03 60.360 268.980 3665.49 3734.19 179.59 S 2535.06 W 6014357.28 N 549521.23 E 3.082 2434.57 4800.88 62.410 269.880 3711.39 3780.09 180.42 S 2619.19W 6014355.86 N 549437.10 E 2.292 2516.49 4896.34 64.630 269.610 3753.95 3822.65 180.80 S 2704.63 W 6014354.88 N 549351.67 E 2.339 2599.79 4993.96 64.630 267.860 3795.78 3864.48 182.75 S 2792.81 W 6014352.32 N 549263.51 E 1.620 2685.41 5089.41 64.760 266.540 3836.58 3905.28 186.96 S 2878.99 W 6014347.50 N 549177.35 E 1.258 2768.59 5185.17 70.040 262.700 3873.38 3942.08 195.30 S 2966.95 W 6014338.55 N 549089.45 E 6.640 2852.60 e 5281.14 75.080 263.270 3902.13 3970.83 206.47 S 3057.80 W 6014326.74 N 548998.69 E 5.282 2938.81 5326.99 76.430 261.860 3913.42 3982.12 212.23 S 3101.86W 6014320.68 N 548954.67 E 4.190 2980.55 5376.50 78.710 263.210 3924.07 3992.77 218.51 S 3149.80 W 6014314.07 N 548906.78 E 5.319 3025.96 5424.02 79.270 262.490 3933.15 4001.85 224.31 S 3196.08 W 6014307.94 N 548860.54 E 1.898 3069.86 5472.23 79.010 261.740 3942.23 4010.93 230.81 S 3242.98 W 6014301.12 N 548813.68 E 1.620 3114.20 5521.77 78.890 260.360 3951.73 4020.43 238.37 S 3291.01 W 6014293.22 N 548765.71 E 2.745 3159.42 5569.00 78.390 260.800 3961.03 4029.73 245.95 S 3336.69 W 6014285.32 N 548720.08 E 1.398 3202.34 5665.16 84.430 263.610 3975.39 4044.09 258.82 S 3430.84 W 6014271.79 N 548626.02 E 6.913 3291.40 5713.11 88.270 265.190 3978.44 4047.14 263.49 S 3478.45 W 6014266.79 N 548578.44 E 8.657 3336.85 5760.65 90.620 263.070 3978.90 4047.60 268.35 S 3525.73 W 6014261.60 N 548531.20 E 6.657 3381.92 5804.97 92.960 262.480 3977.52 4046.22 273.92 S 3569.68 W 6014255.72 N 548487.29 E 5.445 3423.59 5857.03 96.490 262.200 3973.23 4041.93 280.83 S 3621.09 W 6014248.45 N 548435.93 E 6.802 3472.25 5904.37 99.920 262.860 3966.47 4035.17 286.92 S 3667.54 W 6014242.03 N 548389.52 E 7.376 3516.25 4 June, 2004 - 10:24 Page 3 of6 Dril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PB1 MWD Your Ref: API 5002923205070 Job No. AKMW3066223, Surveyed: 19 May, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5952.67 101.070 263.690 3957.68 4026.38 292.49 S 3714.70 W 6014236.14 N 548342.40 E 2.920 3561.06 5999.92 102.690 264.170 3947.95 4016.65 297.38 S 3760.68 W 6014230.93 N 548296.46 E 3.570 3604.85 6048.20 104.600 264.910 3936.56 4005.26 301.84 S 3807.38 W 6014226.14 N 548249.79 E 4.227 3649.45 6096.21 105.950 264.100 3923.91 3992.61 306.27 S 3853.48 W 6014221.39 N 548203.72 E 3.249 3693.47 6143.81 107.800 263.880 3910.10 3978.80 311.04 S 3898.78 W 6014216.30 N 548158.46 E 3.912 3736.63 e 6191.45 108.910 263.490 3895.09 3963.79 316.02 S 3943.72 W 6014211.01 N 548113.55 E 2.456 3779.40 6238.52 109.380 263.220 3879.66 3948.36 321.16 S 3987.89 W 6014205.56 N 548069.42 E 1.136 3821.38 6291.81 108.540 267.680 3862.33 3931.03 325.15 S 4038.11 W 6014201.22 N 548019.23 E 8.070 3869.51 6334.54 108.150 271.080 3848.88 3917.58 325.59 S 4078.66 W 6014200.50 N 547978.68 E 7.607 3908.99 6408.47 1 08.4 70 272.560 3825.66 3894.36 323.36 S 4148.81 W 6014202.23 N 547908.52 E 1.949 3977.93 6432.88 108.540 274.310 3817.91 3886.61 321.98 S 4171.92 W 6014203.46 N 547885.40 E 6.805 4000.78 6476.70 105.620 275.940 3805.04 3873.74 318.23 S 4213.63 W 6014206.91 N 547843.67 E 7.553 4042.30 6528.84 101.950 276.690 3792.62 3861.32 312.66 S 4263.95 W 6014212.13 N 547793.31 E 7.176 4092.63 6576.48 99.300 277.620 3783.83 3852.53 306.83 S 4310.41 W 6014217.64 N 547746.81 E 5.884 4139.23 6624.60 96.930 277.800 3777.04 3845.74 300.43 S 4357.61 W 6014223.70 N 547699.57 E 4.939 4186.69 6672.04 95.690 279.270 3771.83 3840.53 293.44 S 4404.24 W 6014230.38 N 547652.89 E 4.039 4233.72 6720.83 93.150 281.050 3768.07 3836.77 284.86 S 4452.11 W 6014238.62 N 547604.95 E 6.351 4282.32 6768.46 90.800 282.880 3766.42 3835.12 274.99 S 4498.68 W 6014248.17 N 547558.32 E 6.252 4329.91 6816.32 90.000 285.790 3766.09 3834.79 263.14 S 4545.04 W 6014259.69 N 547511.88E 6.306 4377.74 6861.51 87.470 287.510 3767.09 3835.79 250.20 S 4588.32 W 6014272.33 N 547468.51 E 6.769 4422.80 6913.62 87.470 289.680 3769.39 3838.09 233.60 S 4637.66 W 6014288.58 N 547419.06 E 4.160 4474.58 6961.60 89.440 292.430 3770.68 3839.38 216.37 S 4682.41 W 6014305.50 N 547374.18 E 7.049 4522.01 e 7009.61 90.370 295.800 3770.76 3839.46 196.76 S 4726.22 W 6014324.81 N 547330.24 E 7.282 4569.05 7054.28 89.010 297.770 3771.00 3839.70 176.63 S 4766.10 W 6014344.66 N 547290.22 E 5.359 4612.36 7104.67 92.040 299.940 3770.54 3839.24 152.31 S 4810.22 W 6014368.66 N 547245.93 E 7.396 4660.73 7152.49 92.840 304.040 3768.51 3837.21 127.01 S 4850.74 W 6014393.68 N 547205.24 E 8.728 4705.79 7201.98 92.590 309.110 3766.16 3834.86 97.56 S 4890.42 W 6014422.85 N 547165.35 E 10.245 4750.96 7249.53 90.490 312.500 3764.88 3833.58 66.51 S 4926.39 W 6014453.65 N 547129.16 E 8.384 4792.84 -Q", ~ 7297.76 89.940 315.490 3764.70 3833.40 33.01 S 4961.09 W 6014486.91 N 547094.24 E 6.303 4834.02 -. ~\. , 7347.50 90.680 319.860 3764.43 3833.13 3.75 N 4994.57 W 6014523.44 N 547060.50 E 8.911 4874.72 ~'\~~O ' 7393.70 91.230 322.470 3763.66 3832.36 39.73 N 5023.53 W 6014559.21 N 547031.28 E 5.773 4910.85 7442.00 90.560 326.630 3762.91 3831.61 79.07 N 5051.54 W 6014598.35 N 547003.00 E 8.723 4946.77 7489.67 89.140 330.040 3763.03 3831.73 119.63 N 5076.56 W 6014638.74 N 546977.70 E 7.749 4980.05 7536.87 88.020 332.360 3764.20 3832.90 160.98 N 5099.29 W 6014679.93 N 546954.68 E 5.457 5011.26 7585.91 88.640 335.210 3765.63 3834.33 204.95 N 5120.94 W 6014723.75 N 546932.73 E 5.945 5042.00 4 June, 2004· 10:24 Page 4 of 6 Dril/Quest 3.03.06.002 .. Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PS1 MWD Your Ref: API 5002923205070 Job No. AKMW3066223, Surveyed: 19 May, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7635.20 88.210 339.240 3766.99 3835.69 250.37 N 5140.01 W 6014769.03 N 546913.34 E 8.219 5070.53 7682.23 87.220 342.170 3768.86 3837.56 294.72 N 5155.53 W 6014813.27 N 546897.50 E 6.571 5095.37 7731.65 89.880 343.810 3770.11 3838.81 341.96 N 5169.98 W 6014860.40 N 546882.72 E 6.322 5119.79 7776.73 91.230 345.360 3769.68 3838.38 385.41 N 5181.97W 6014903.77 N 546870.44 E 4.559 5140.98 7826.57 93.090 344.370 3767.80 3836.50 433.48 N 5194.97 W 6014951.76 N 546857.10 E 4.227 5164.17 e 7872.59 96.370 342.940 3764.00 3832.70 477.49 N 5207.87 W 6014995.67 N 546843.89 E 7.771 5186.38 7923.57 97.740 343.830 3757.74 3826.44 525.97 N 5222.34 W 6015044.05 N 546829.08 E 3.197 5211.09 7968.21 97.610 343.730 3751.78 3820.48 568.45 N 5234.70 W 6015086.44 N 546816.43 E 0.366 5232.43 8000.57 97.430 343.530 3747.54 3816.24 599.23 N 5243.74 W 6015117.15 N 546807.17 E 0.828 5247.97 8074.00 97.430 343.530 3738.05 3806.75 669.05 N 5264.38 W 6015186.83 N 546786.04 E 0.000 5283.37 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 282.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8074.00ft., The Bottom Hole Displacement is 5306.73ft., in the Direction of 277.243° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) e Comment 8074.00 3806.75 669.05 N 5264.38 W Projected Survey 4 June, 2004 - 10:24 Page 50f6 Drí/lQuest 3.03.06.002 Milne Point Unit Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PS1 MWD Your Ref: API 5002923205070 Job No. AKMW3066223, Surveyed: 19 May, 2004 SPXA Survey tool proaram for MPJ·26 PS1 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 631.00 0.00 630.50 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 631.00 8074.00 630.50 CB-SS-GYRO 3806.75 MWD Magnetic e e 4 June, 2004 - 10:24 DrillQuest 3.03.06.002 Page 60f6 . . 02-Jun-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Ho DEFINITIVE '¡~ Re: Distribution of Survey Data for Well MPJ$PB2 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,249.53' MD 7,280.00' MD 8,562.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date C J w. À.,ð ~ '1 Signed ~ tJJLI Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ;{ 0\;/ ~ð b'1 Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ·26 PB2 Job No. A~ZZ3066223, Surveyed: 20 May, ~ Survey Report 3 June, 2004 Your Ref: API 500292320571 Surface Coordinates: 6014554.57 N, 552054.97 E (70°27' 01.8108- N, 149° 34' 31.066r W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1014554.57 N, 52054.97 E (Grid) Surface Coordinates relative to Structure Reference: 1134.98 N, 627.81 E (True) Kelly Bushing Elevation: 68. 70ft above Mean Sea Level Kelly Bushing Elevation: 68. 70ft above Project V Reference Kelly Bushing Elevation: 68. 70ft above Structure Reference sp,e....,....,Y-SUií! DRILLING SEiRVH::eS A Halliburton Company .. .. DEFINITIVE e e Survey Ref: svy1411 ~ Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PB2 Your Ref: API 500292320571 Job No. AKZZ3066223, Surveyed: 20 May, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7249.53 90.490 310.690 3764.83 3833.53 120.66 S 4937.13 W 6014399.42 N 547118.80 E 4791.49 Tie-on Point 7280.00 88.690 312.890 3765.05 3833.75 100.36 S 4959.84 W 6014419.57 N 547095.95 E 9.329 4818.09 Window Point 7297.50 87.650 314.160 3765.61 3834.31 88.32 S 4972.53 W 6014431.52 N 547083.18 E 9.377 4833.10 7343.16 85.620 313.490 3768.29 3836.99 56.75 S 5005.41 W 6014462.85 N 547050.08 E 4.681 4872.08 7393.45 87.350 311.840 3771.37 3840.07 22.74 S 5042.32 W 6014496.61 N 547012.93 E 4.749 4915.53 e 7441.77 91.110 312.120 3772.02 3840.72 9.57 N 5078.23 W 6014528.67 N 546976.80 E 7.803 4957.63 7489.59 93.390 314.100 3770.14 3838.84 42.22 N 5113.11 W 6014561.08 N 546941.69 E 6.313 4998.80 7541.42 92.840 318.100 3767.32 3836.02 79.51 N 5148.99 W 6014598.11 N 546905.55 E 7.779 5041.96 7586.17 93.830 320.810 3764.72 3833.42 113.45 N 5178.02 W 6014631.85 N 546876.28 E 6.438 5077.71 7631.41 92.290 322.640 3762.31 3831.01 148.91 N 5206.00 W 6014667.11 N 546848.05 E 5.282 5112.77 7681.21 92.100 326.580 3760.40 3829.10 189.47 N 5234.82 W 6014707.47 N 546818.96 E 7.915 5149.75 7726.85 93.340 328.920 3758.23 3826.93 228.03 N 5259.14 W 6014745.85 N 546794.36 E 5.797 5181.91 7776.04 93.650 333.940 3755.23 3823.93 271.13 N 5282.62 W 6014788.79 N 546770.59 E 10.206 5214.23 7825.19 92.530 336.910 3752.58 3821.28 315.76 N 5303.02 W 6014833.28 N 546749.87 E 6.450 5243.89 7872.26 91.730 340.780 3750.83 3819.53 359.62 N 5320.00 W 6014877.02 N 546732.59 E 8.390 5270.04 7919.75 90.560 342.780 3749.88 3818.58 404.71 N 5334.84 W 6014922.01 N 546717.43 E 4.878 5294.38 7970.02 89.070 345.650 3750.04 3818.74 453.08 N 5348.51 W 6014970.28 N 546703.42 E 6.433 5318.29 8017.56 89.260 346.480 3750.74 3819.44 499.22 N 5359.96 W 6015016.34 N 546691.65 E 1.791 5339.54 8065.75 89.260 345.570 3751.36 3820.06 545.98 N 5371.60 W 6015063.01 N 546679.69 E 1.888 5361.11 8108.50 88.640 346.020 3752.14 3820.84 587.41 N 5382.09 W 6015104.37 N 546668.91 E 1.792 5380.40 8159.83 89.570 346.440 3752.94 3821.64 637.26 N 5394.30 W 6015154.14 N 546656.35 E 1.988 5403.21 8207.60 89.140 346.930 3753.48 3822.18 683.74 N 5405.30 W 6015200.54 N 546645.02 E 1.365 5424.10 e 8256.92 87.650 344.790 3754.86 3823.56 731.55 N 5417.35 W 6015248.26 N 546632.65 E 5.286 5446.30 8304.92 89.510 344.810 3756.05 3824.75 777.85 N 5429.93 W 6015294.47 N 546619.74 E 3.875 5468.69 _ Ü ~ S\~~~\~ 8352.44 90.000 344.830 3756.26 3824.96 823.71 N 5442.37 W 6015340.25 N 546606.98 E 1.032 5490.85 8401.60 92.160 347.920 3755.33 3824.03 871.47N 5453.95 W 6015387.92 N 546595.07 E 7.668 5512.58 Q ~ 'S30 8448.41 92.590 349.620 3753.39 3822.09 917.34 N 5463.05 W 6015433.73 N 546585.64 E 3.743 5531.49 \o~+ ~ ~ Sd'o\ 8488.13 92.410 349.350 3751.66 3820.36 956.36 N 5470.30 W 6015472.70 N 546578.13 E 0.816 5547.09 8562.00 92.410 349.350 3748.55 3817.25 1028.89 N 5483.94 W 6015545.13 N 546563.98 E 0.000 5576.24 Projected Survey ho'p All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 282.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8562.0Oft., 3 June, 2004 - 6:32 Page 2 of 3 DrillQuest 3.03.06.002 I' Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PB2 Your Ref: API 500292320571 Job No. AKZZ3066223, Surveyed: 20 May, 2004 BPXA Milne Point Unit The Bottom Hole Displacement is 5579.62ft., in the Direction of 280.626° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7249.53 7280.00 8562.00 3833.53 3833.75 3817.25 120.66 S 100.36 S 1028.89 N 4937.13 W 4959.84 W 5483.94 W Tie-on Point Window Point Projected Survey e Survey tool proaram for MPJ·26 PB2 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 631.00 0.00 630.50 631.00 8562.00 630.50 CB-SS-GYRO (MPJ-26 PB1 GYRO) 3817.25 MWD+IIFR+MS (MPJ-26 PB1) e 3 June, 2004 - 6:32 Page 3 of 3 DrillQuest 3.03.06.002 . . 02-Jun-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPJ~2 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,249.53' MD 7,280.00' MD 8,562.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date C( JMLu..e~ Signed ~ oW Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ,t ö \wi - ö b'l Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ·26 PB2 MWD e Job No. AKMW3066223, Surveyed: 20 May, 2004 Survey Report 3 June, 2004 Your Ref: API 500292320571 Surface Coordinates: 6014554.57 N, 552054.97 E (70027' 01.8108" N, 149034' 31.0662" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014554.57 N, 52054.97 E (Grid) Surface Coordinates relative to Structure Reference: 1134.98 N, 627.81 E (True) Kelly Bushing Elevation: 68. 70ft above Mean Sea Level Kelly Bushing Elevation: 68.70ft above Project V Reference Kelly Bushing Elevation: 68. 70ft above Structure Reference speraray-su1'1 I:U"UL-LtNG seRVtCeS A Halliburton Company Survey Ref: svy1412 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PB2 MWD Your Ref: API 500292320571 Job No. AKMW3066223, Surveyed: 20 May, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7249.53 90.490 312.500 3764.88 3833.58 66.51 S 4926.39 W 6014453.65 N 547129.16 E 4792.84 Tie-on Point 7280.00 88.690 312.890 3765.10 3833.80 45.85 S 4948.79 W 6014474.16 N 547106.62 E 6.045 4819.21 Window Point 7297.50 87.650 316.030 3765.66 3834.36 33.60 S 4961.27 W 6014486.32 N 547094.06 E 18.892 4834.07 7343.16 85.620 315.320 3768.34 3837.04 0.99 S 4993.12 W 6014518.70 N 547061.98 E 4.709 4872.27 7393.45 87.350 312.470 3771.42 3840.12 33.81 N 5029.28 W 6014553.25 N 547025.57 E 6.620 4915.16 e 7441.77 91.110 312.640 3772.07 3840.77 66.48 N 5064.87 W 6014585.67 N 546989.76 E 7.789 4957.03 7489.59 93.390 314.890 3770.19 3838.89 99.52 N 5099.37 W 6014618.47 N 546955.03 E 6.696 4997.92 7541.42 92.840 318.590 3767.38 3836.08 137.21 N 5134.83 W 6014655.91 N 546919.31 E 7.207 5040.75 7586.17 93.830 321.210 3764.77 3833.47 171.37N 5163.60 W 6014689.87 N 546890.29 E 6.249 5076.30 7631.41 92.290 322.960 3762.36 3831.06 207.01 N 5191.36 W 6014725.32 N 546862.29 E 5.149 5111.17 7681.21 92.100 327.350 3760.45 3829.15 247.84 N 5219.79 W 6014765.95 N 546833.58 E 8.817 5147.83 7726.85 93.340 329.700 3758.28 3826.98 286.72 N 5243.59 W 6014804.66 N 546809.51 E 5.817 5179.55 7776.04 93.650 334.590 3755.28 3823.98 330.12 N 5266.52 W 6014847.89 N 546786.27 E 9.943 5211.41 7825.19 92.530 337.670 3752.63 3821.33 374.99 N 5286.38 W 6014892.63 N 546766.10 E 6.659 5240.59 7872.26 91.730 341.440 3750.88 3819.58 419.06 N 5302.81 W 6014936.58 N 546749.36 E 8.182 5266.25 7919.75 90.560 343.570 3749.93 3818.63 464.34 N 5317.08 W 6014981.76 N 546734.78 E 5.116 5290.07 7970.02 89.070 346.640 3750.10 3818.80 512.91 N 5330.00 W 6015030.24 N 546721.52 E 6.788 5313.29 8017.56 89.260 348.370 3750.79 3819.49 559.32 N 5340.28 W 6015076.57 N 546710.91 E 3.661 5333.47 8065.75 89.260 346.980 3751.41 3820.11 606.39 N 5350.57 W 6015123.57 N 546700.30 E 2.884 5353.79 8108.50 88.640 347.400 3752.19 3820.89 648.07 N 5360.05 W 6015165.19 N 546690.53 E 1.752 5372.14 8159.83 89.570 347.190 3753.00 3821.70 698.14 N 5371.33 W 6015215.17 N 546678.89 E 1.857 5394.10 8207.60 89.140 348.090 3753.53 3822.23 744.80 N 5381.56 W 6015261.76 N 546668.34 E 2.088 5414.27 -~~S~~ 8256.92 87.650 345.720 3754.92 3823.62 792.81 N 5392.73 W 6015309.69 N 546656.84 E 5.674 5435.66 8304.92 89.510 345.540 3756.11 3824.81 839.29 N 5404.63 W 6015356.09 N 546644.60 E 3.893 5457.43 8352.44 90.000 345.410 3756.31 3825.01 885.29 N 5416.55 W 6015402.01 N 546632.37 E 1.067 5479.11 '&1>SCÝ 8401.60 92.160 348.350 3755.38 3824.08 933.15 N 5427.71 W 6015449.79 N 546620.88 E 7.420 5500.46 \C~~ d- š d-\)~ \J~ 8448.41 92.590 349.880 3753.44 3822.14 979.08 N 5436.54 W 6015495.65 N 546611.72 E 3.392 5519.11 8488.13 92.410 349.540 3751.71 3820.41 1018.13 N 5443.63 W 6015534.65 N 546604.36 E 0.968 5534.56 8562.00 92.410 349.540 3748.60 3817.30 1090.70 N 5457.03 W 6015607.13 N 546590.46 E 0.000 5563.49 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 282.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8562.00ft., 3 June, 2004 - 6:42 Page 2 of 3 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-26 PB2 MWD Your Ref: API 500292320571 Job No. AKMW3066223, Surveyed: 20 May, 2004 ~ BPXA Milne Point Unit The Bottom Hole Displacement is 5564.96ft., in the Direction of 281.303° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7249.53 7280.00 8562.00 3833.58 3833.80 3817.30 66.51 S 45.85 S 1090.70 N 4926.39 W 4948.79 W 5457.03 W Tie-on Point Window Point Projected Survey e Survey too/program for MPJ-26 PB2 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 631.00 0.00 630.50 631.00 8562.00 630.50 CB-SS-GYRO (MPJ-26 PB1 GYRO) 3817.30 MWD Magnetic (MPJ-26 PB1 MWD) e 3 June, 2004 - 6:42 Page 3 of 3 DrillQuest 3.03.06.002 . . lID n LL FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL Al'O) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPJ-26 BP Exploration (Alaska) Inc. Permit No: 204-064 Surface Location: 2156' NSL, 3268' WEL, SEC. 28, T13N, RIOE (As Staked) Bottomhole Location: 3306' NSL, 3446' WEL, SEe. 29, T13N, RI0E, UM (NB) Dear Mr. Archey: Enclosed is the approved application for pennit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector 3607 (pager). S cerl, BY ORDER OF THE COMMISSION DA TED thi~ / day of April, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work II Drill o Redrill 1b. Current Well Class o Exploratory II 'ibaR~a' 1011 ORe-Entry o Stratigraphic Test o Service o Development Ga..~ . SinaI'e Zone 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 MPJ·26 3. Address: 6. Proposed Dept'} / 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 8644' TVD 3839' Milne Point Unit I Schrader Bluff 4a. Location of Well (Governmental Section): 7. Property Designation:Jt ¡)2.Çif~'" ,g. I./(,oof Surface: ADL 025517 - 2156' NSL, 3268' WEL, SEC. 28, T13N, R10E, (As Staked) / Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1855' NSL, 2448' WEL, SEC. 29, T13N, R10E, UM (NB) 04/26/04 Total Depth: /9. Acres in Property: 14. Distance to Nearest Property: 3306' NSL, 3446' WEL, SEC. 29, T13N, R10E, UM (NB) 2560 7100' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool Surface: x-552054'¡ Y-6014554'/ Zone7\SP4 (Height above GL): KBE = 69' feet 350' away from MPJ-20 BHL 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Kickoff Depth 400 ft Maximum Hole Angle 108 0 Downhole: 1744" psig Surface: 1342 psig 18.) 'Casing Program Specifications Setting Depth i(c.[ :>rsåCkS) Size Top.<..· . .·.·..ßottom Hole Casina WeiQht Grade CouplinQ LenQth MD TVD MD TVD (includin staae data) 42" 20" 92# H-40 Welded 80' Surface Surface 112' 112' 60 sx Arctic Set Aoorox. ) 13-1/2" 10-3/4" 45.5# L-80 BTC-M 3110' Surface Surface 3110' 2639' 97~ 'L', 261 sx Class 'G' - 9-7/8" 7-5/8" 29.7# L-80 BTC-M 6364' Surface Surface 6364' 3934' !:ZA c>v rl",c>c> 'r,'~ ~ 41 -,~< VIo-?' . ¡ 6-3/4" 4"x5" L-80 2280' 6364' 3934' 8644' 3839' creen Assembly "\ '41 -. ~ V' \ .~~""t þ.'f ~' r'll 19. PRESËNT WELLCONDITIQN SUMMARY (TI). be completøc! for RedrillAND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): I£ènoth Si~è ) i Mº»/ )i TVD ~trllr.tllr~1 Conductor In Proctur.tion I inAr Perforation Depth MD (ft): \perfOration Depth TVD (ft): 20. Attachments a Filing Fee o BOP Sketch a Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report a Drilling Fluid Program a 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Walter Quay, 564-4178 Printed Name Pat Archey Title Senior Drilling Engineer P5 ct...h~ Prepared By Name/Number: Sianature Phone 564-5803 Date Sondra Stewman, 564-4750 ..) l Y$4Iøt.í~ ) ..i.).»·..... Permit To Drill t/- Cblf'l API Number: Permit APd~ ';;:1 ¿ I See cover letter for Number: 2D - 50- D2-9- 2!32DS;-00 Date: ':.J-./ ,,~ other requirements Conditions of Approval: Samples Required DYes J(No Mud Log Réquired I ~es {gNO roge fide Measures DYes ~o Directional Survey Required Yes No Other: '3C)O ~\ , ~~\SG\>~~. H8IJMS 8ft APR 28 lOfi~ 44 V ~C/. Aooroved Bd f"\nl~'f\' ^ I BY ORDER OF V THE COMMISSION Date Form 10-401 r«;'vised ~03 ~ U . \ I V Ii' (\ .... ~ubmit (n Duplicate .TATE OF ALASKA . .. ¡;. ALASKA Oil AN""GAS CONSERVATION COMMISSluN R E C FIVE D 4..{~ PERMIT TO DRILL APR 1 5 2004 20 MC 25.005 ~\ '1bl . . MPJ-26 Permit I Well Name: I MPJ-26 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Schrader Bluff Tri-Lateral Producer ./ Surface Location: 2,156' FSL, 3,268' FEL, SEC. 28, T13N, R10E (As Staked) E=552054 N=6014554 Target Location: 1855' FSL,2448' FEL,SEC.29,T13N,R10E Top NB E=547597 N=6014223 Z=3755' TVD SS Target Location: 3306' FSL,3446' FEL,SEC.29,T13N, R10E BHL NB Well TD E=546586 N=6015668 Z=3775' TVD SS Target Location: 1855' FSL, 2448' FEL, SEC. 29 , T13N, R10E Top OB E=547597 N=6014223 Z=3940' TVD SS Target Location: 3306' FSL, 3446' FEL, SEC. 29 , T13N, R10E BHL OB Well TD E=546586 N=6015668 Z=3945' TVD SS Target Location: 1855' FSL, 2448' FEL, SEC. 29 , T13N, R10E Top OA E=547597 N=6014223 Z=3885' TVD SS Target Location: 3306' FSL, 3446' FEL, SEC. 29 , T13N, R10E BHL OA Well TD E=546586 N=6015668 Z=3885' TVD SS Distance to Property line 7100' Distance to nearest pool 350' from J-20 Abandoned BH L f!!!!'!rtl~4 7 . . MPJ-26 Permit Mud Program: 13-1/2" Suñace Hole 0 - 3110' : Densi PV YP HTHP 9.0 - 9.3 10 - 20 25 - 30 10- 11 9-7/8" Intermediate Hole 3100 - 6364' : Densit PV YP HTHP 9.0 - 9.3 10 - 20 25 - 30 10- 11 6-3/4" NB Production Hole 6364-- 8643' : Densit PV YP HTHP 9.0 - 9.1 10 - 20 25 - 30 10- 11 6-3/4" OB Production Hole 5567-- 8647' : Densit PV YP HTHP 9.0 - 9.1 10 - 20 25 - 30 10- 11 6-3/4" OA Production Hole 5264-- 8651' : Densit PV YP HTHP 9.0 - 9.1 10 - 20 25 - 30 10- 11 LSND H API Filtrate LG Solids 9.0 - 9.5 < 6 < 15 LSND API Filtrate LG Solids < 6 < 15 MOBM API Filtrate LG Solids < 6 < 15 MOBM API Filtrate LG Solids < 6 < 15 MOBM API Filtrate LG Solids < 6 < 15 H 9.0-9.5 H 9.0-9.5 H 9.0-9.5 H 9.0-9.5 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU IR. Cement Pro ram: Size 10-3/4"45.5 Ibltt L-80 BTC Surface Casin Lead Slurry to surface. Excess 100% over gauge hole. of tail cement 500' MD above casin shoe. ~-.J'\:s>e'd ~b· ~~ -bbl 10.3-lb/ al un-viscosified AI ha S acer 394- I, 497 sx of 10.7 Permafrost L - 4.45 ft /sx 54-bbl, -sx 15.8 Ib/ al Prem G - 1.15 ft /sx Basis Total Cement Volume: 387 bbl Casin Basis Wash au e. S acer Lead Tail Tem 5-bbl water 30-bbl MW + 1 .O-Ib/ al AI NA 57-bbl, 278-sx 15.8 Ib/ al Prem G - BHST ::::80°F from SOR 8 RE: MPJ-26 Here is what the table on pag~hOUld be: . The basis remains unchanged.. I corrected the volumes for the 7-5/8" along with the lead for the Surface. . I hate when I make errors like this. Thanks Walter Quay quaywd@bp.com (907)564-4178 (907)440-8632 - Cell «MPJ-26 Permit P8.ZIP» d-()~ - 0 G/1 -----Original Message----- From: Thomas Maunder [mailto:tom maunder(â¿admin.state.ak.usl Sent: Tuesday, April 20, 20042:22 PM To: Quay, Walter (Natchiq) Subject: MPJ-26 Walter, I am reviewing the permit application. I am having difficulties determining the planned TOC for the 7-5/8" job. The text on page 8 mentions a lead and tail slurry but there is only a 200 4/21/2004 11: 11 AM RE: MPJ-26 . . ~~-O(P~ tail slurry given. Also, it appears If the md of the top of the NB is used that there is little to no excess. Could you check these numbers and get back to me. Thanks. Tom Maunder, PE AOGCC Permit Content-Description: MPJ-26 Pennit P8.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 30f3 4/21/2004 11: 11 AM . . MPJ-26 Permit E I r p va ua Ion rogram: 13-1/2" Section Open Hole: MWD/GR J IFR/CASANDRA Sperry InSite Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GRlRES ~ IFRlCASANDRA Sperry InSite Cased Hole: N/A 6-1/8" Section Open Hole: MWD/GRlRES/ABI -/ IFRlCASANDRA Sperry InSite Cased Hole: N/A Formation Markers: Formation Tops MDrkb TVDrkb (ft) Pore Estimated EMW (ft) Pressure (psi' (Ib/gal)* BPRF 2078 1,869 782 8.35 TUZC 4048 3,344 1422 8.35 Ugnu-MA 4367 3,574 1522 8.35 Ugnu-MBl 4375 3,579 1524 8.35 Ugnu-MB2 4454 3,629 1546 8.35 Ugnu-MC 4719 3,769 1607 8.35 SBF2-NA 4815 3,809 1655 8.51 SBFI-NB 4897 3,839 1668 8.51 / SBE4-NC 4985 3,869 1682 8.51 SBE2-NE 5028 3,884 1688 8.51 SBEI-NF 5149 3,924 1706 8.51 TSBD- Top OA 5263 3,954 1719 8.51 TSBC-Base OA 5424 3,984 1732 8.51 TSBB- Top OB 5566 4,009 1744 8.51 SBA5-Base OB 4,039 1757 8.51 TSBB-Top OB Upgoing 4,009 1744 8.51 TSBC-Base OA Upgoing 3,979 1730 8.51 TSBD-Top OA Upgoing 3,944 1715 8.51 SBEI-NF Upgoing 3,904 1697 8.51 SBE2-NE Upgoing 3,859 1677 8.51 SBE4-NC Upgoing 3,839 1668 8.51 SBF12-Base NB Sand 3,829 Upl{oinl{ NB OWC 4,099 OA OWC 4,159 OB OWC 4,214 -/ 9 . . MPJ-26 Permit c IT b- P aSln~ u In g rogram Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Welded 80' 0' 112' / 112' 13.5-in 10.75-in 45.5# L-80 BTC-M 3,110' 0' 3,110' / 2,639' 9.875-in 7.625-in 29.7# L-80 BTC-M 6,364' 0' 6,364 / 3,934' 6.75-in 4"X5" L-80 2280' 6,364 / 8,644'/3,839' NB Screens 3,934' 6.75-in 4.5-in 12.6# L-80 BTC 3080' 5567'/4009' 8647'/4014' OB Slotted 6.75-in 4.5-in 12.6# L-80 BTC 3387' 5264'/3954' 8651'/3954' OA Slotted Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13.5" 0' - 3110' Hughes MXC1 2 9.875" 3110' - 6364' PDC 3 6.125" 6364' -8644' PDC 10 . . MPJ-26 Permit Well Control: Intermediate/Production hole: · Maximum anticipated BHP: 1,744-psi @ 4,009-ft TVDrkb - TSBB-Top OB · Maximum surface pressure: 1 ,342 psi @ surface (Based on BHP and a full column of gas from TD @ O.l-psi/ft) · Planned BOP test pressure: 3,000-psi. · Integrity test: An FIT to 11.0-lb/gal at the 1O-3/4"shoe. Kick tolerance: 52-bbl with 9.0-lb/gal mud. · Planned completion fluid: MOBM in Laterals/9.8 ppg Brine/7.0-lb/gal Diesel (1 ,800-ft tvd). Drilling Hazards & Contingencies: · Hydr~ have not been encountered on J-Pad wells drilled to date. r · A Chert hard streak at -2710' tvd has been encounterd. -------.. · Tight hole and swabbing due to clays has occurred on J Pad wells. ~_._.,..,,---"--.,"" · Sticky hole, running gravels/sands have been problematic on J-Pad. Maintain adequate viscosity(100+ vis). Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · Not expected or predicted. Pad Data Sheet · Please Read the J-Pad Data Sheet thoroughly. Breathing · Not expected or predicted. Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. "'\ Faults · Four fault intersections are prognosed for this well. These are in the production (NB, OB & OA) intervals at following est. MDs: 4719'(downgoing), 6300'(Upgoing section and laterals NB, OA), 6900'(OAlOB Laterals) & 7200' (NB Lateral) Hydrogen Sulfide · MPJ Pad is not designated as an H2S Pad. J-Pad wells <50-ppm H2S reported. Latest samplings: r --.......... 11 . . MPJ-26 Permit o MPJ-06 (Kup) 9.6 o MPJ-10(Kup) 8 o MPJ-21 <2 o MPJ-10(Kup) 10 2/15/04 2/15/04 2/15/04 2/15/04 Anti-collision Issues · MPJ-26 passes the Major Risk Criteria. The closest issue is MPJ-22 at 300' with a 6.7' center to center distance. Distance to Nearest Property · MPJ-26 is 7,100 -ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPJ-26 is 350' from the Schrader Bluff sand penetration in MPJ-20 BHL (now abandonded). 12 · .! MPJ-26 Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. The 20" conductor is installed. 2. NU Diverter Drillina 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. MIRU Doyon 14, ND Tree/NU BOP. Function Test Diverter, PU 4" DP. Drill 13.5" surface hole. Run and cement 1 0.75" surface casing. ND diverter, install wellhead and NU/Test BOP. Drill 9.875" intermediate hole. Run and cement 7-5/8" intermediate casing. Displace ,to MOB~.1. Drill 6-3/4" NB horizontal production hole. Run 4.5" screens completion liner. Run whipstock and mill window for OB lateral. Drill 6-3/4" OB horizontal production hole. Retrieve whipstock. Run 4.5" slotted liner and hang off in 7.625" casing Run whipstock and mill window for OA lateral. Drill 6-3/4" OA horizontal production hole. Retrieve whipstock. Run 4.5" slotted liner and hang off in 7.625" casing Displace MOBM with Brine RU and Run 2.875" ESP Completion. ND BOP/NU Tree Freeze Protect. RDMO Doyon 14. 13 TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head wI?" mandrel hanger & packoff 11" x 11", 5M, tbg spool wI 11" x 4-1/2" tubing hanger with control line ports 11" X 4-1/16" Adaptor Flange MPJ-26 Proposed 9.2 PPG Versapro MOBM below Completion Baker Hookwall Hanger @ 5,xxx' M Window in 7-5/8" casing@ 5,567' M Well Inclination @ Window = 80° DATE REV. BY 0410712004 w. Quay I 109' Orig KB elev (D-14) = 69' Cameo 2 7/8" x 1" sidepocket KBMM GLM -150' 2-7/8" 6.5 ppf, L-80, EUE production tubing (Drift ID = 2.347", cap = 0.00579 bpf) Cameo 2 7/8" x 1" sidepocket KBMM GLM 2 Jts above ESP 27/8" XN Nipple. 1 Jt above ESP 10-3/4",45.5# L-80 BTC Csg @ 3,110' MD Centrilift ESP Centrilift Tandem Gas Separator Centrilift Tandem Seal Section Centrilift Motor 140 HP KMH-A 2244 Volt 37 Amp PumpMate & Centralizer Baker ZXP Liner Top Packer & Hanger @ 5,xxx' MD Baker Hookwall Hanger @ x,xxx' MD Window in 7-5/8" casing@ 5,264' MD Well Inclination @ Window = 7r I 6,364'-8,644' I 6-3/4" NB Lateral -.-.-.-. -.-. -.-. -.-.-.-. -.-.-.-. -.-. -.-. -.-. -.-.--.-.-.-.-.-.-.-.-. 17-5/8" Casing Shoe @ 6,364' MD I Baker Flexlock Liner Hanger Baker ZXP Liner Top Packer & Hanger @ 5,750' MD I 5,264'-8,651' I 6-3/4" OA Lateral ---------------- ---------------.- Baker ZXP Liner Top Packer & Hanger @ 5,xxx' MD COMMENTS Proposed Inverted Trilateral 7-5/8",29.7#, L-80, BTC-M Casing Drift: 6.75" Casing ID: 6.875" I 5,567'-8,648' I 6-3/4" OB Lateral Milne Point WELL: J-26ML API NO: 50-029- 50-029- 50-029- o o OCJ w + N 400 J-1 NORTH N 1800 + o o o;- ~ MPU J-PAD ,,--------- -- ------.., ( I I I I I I I i I i I I I I I I ~---J ( -+- J-25 24. 23. 1. 11. 2 . 8 . 3 . 10. 4 . 15. 16. 17· 18. 19. 20. 21. MPJ-22-+- J- 26 (ABANOONED) .6 . 12 .9 .13 .5 .14 .7 J-2 SOUTH ~ LOCA TED WITHIN PROTRACTED SEC. WELL ASP. PLANT NO. COORDINATES COORDINATES J-25 y= 6,015,137.64 N= 1,390.00 X= 551,903.29 E= 1,120.00 J-26 yO' Y= 6,014,554.57 N= 795.00 ;/ X= 552,054.97 E= 1,025.00 w . .:! 0) !'> ~h ~v1> -III¡- I VICINITY MAP N.T.S. WELL MPJ-22 ABANDONED WELL MPJ-22 HAS BEEN ABANDONED. MPJ-26 IS LOCATED 5 FEET NORTH OF THE PREVIOUS MPJ-22 LOCATION. NOTES: 1. STATE PLANE COORDINATES ARE ALASKA ZONE 4 NAD27. 2. GEODETIC COORDINATES ARE NAD-27. 3. MPU J-PAD FACILITY SCALE FACTOR IS 0.9999031. 4. HORIZONTAL CONTROL BASED ON MPU J-PAD OPERATOR MONUMENTS J-1 AND J-2. 5. ELEVATIONS ARE BPX MILNE POINT DATUM MEAN SEA LEVEL. LEGEND .. PROPOSED CONDUCTOR . EXISTING CONDUCTOR ~ SURVEY CONTROL MONUMENT 28, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA GEODETIC GEODETIC GROUND SECTION POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS 70'27'07.556" 70.4520989" 2,741' FSL 149'34'35.402" 149.5765006' N/A 3,413'FEL 70'27'01.811" 70.4505028' 2,156' FSL " 149'34'31.066" 149.5752961' N/A 3,267' FEL v ~, DRAWN: ObP JACOBS CHECKED: ALLISON DATE: 2/17/04 DRAINING: SHEET: FRB04 MPJ 01-00 MILNE POINT UNIT J-PAD ~ GJ~~[IJœo JOB NO: SCALE: PROPOSED CONDUCTORS JJC LOH ENClNEIRSNÐL.ANDSUA'oO'MS WELLS MPJ-25 & MPJ-26 1 OF 1 IID1'fIEST FIRE\IIŒD LANE 1"=200' BY CHK NtCHORAGE, AlASKA 11&503 o 2 17 04 ISSUE FOR INFORMATION NO, OA TE REVISION FORMATION TOP DETAILS No. TVDPath MDPath Formation SURVEY PROGRAM Depth Fro Depfu To Sl.Ifvey!Pt:m Tool Date: 4/7¡W04 34,00 1000.00 Plant CB-GYRO-SS Checked: Date:_ WOO.OO !1643.82 P1arn: MWD+!:FR+MS Reviewed Date_ ..... ....... -- WELL DETAILS Nmœ 4'J1-S +EI-W NortIUo¡¡ """"'" UoIi<uOO Umgi""" Slot PfunMPJ·26 1134.: 627.8Q 6014554.00 552055.00 70"'27'0I.805N ¡49"34'3L065W NlA ..... ....... TARGET DETAILS Nmœ TVD +Nt-S +Ef-W - Easting Shape 381 383 '83 J9:!: 392 393 394 41)1) 41)1 41)1 - - - - - SECTION DETAILS See MD Ino Azí TVD +NI-S +EI-W Dug TFace VSec Target 1 >0 2 >0 3 >0 4 0 5 >0 6 >0 7 ij 8 ij 9 6 10 >0 II "i- 12 >0 MPJ-26 rI. 13 5 14 >0 15 ·6 MP J·26 12. 16 ,9 17 0 18 ~ MPJ-26 T3. 19 4 20 10 MPJ-2614. 1 2 3 4 5 6 7 8 9 10 11 ]2 13 ]4 COMPANY DETAILS Sf> Amoco 7ii :¡¡ "" "" E:S -" iõ. " o -¡¡¡ Ë 240 " ;;- ~ Date:_ Date:_ Daœ:_ Plan, MPJ-26 wpíJB (Pkm MPJ-26lPlan MPJ·26) Created By: Troy Jakabosky Date: 41712004 Checked: Latitude. LoogÍ'tl1.de Slot 70"27'OUWSN 149<>]4'3l.065W ...... .............. -g Easting S. Reviewed; Approved WELL DETAILS NortbIDg EMling 6014554.00 552055.00 TARGET DETAILS +N!-8 "E!·W +E.I-W &,.r¡.80 TVD Tool +N/-S 134.58 SURVEY PROGRAM Depth Fro Depth Tù Surv¢yiPlan 34,00 ]000.00 ]ÛÙO.OO 8643.82 """" Plan MPJ-26 """" FORMATION TOP DETAILS TVDPa(h MDPath Formation No. I 2 3 4 5 6 7 8 9 10 II 12 13 14 Targe! MPJ·26 TI MPJ-26 T2. MPJ·26 T3. MPJ·26 T4. VSe<; TFace DLeg SECTION DETAILS +N/·S +E/-W TVD Azi Ino MD See 1 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 17 18 19 20 CASING DETAILS " :â o o ~ +' ~. " ~ ~ " '" · . Sperry-Sun - Draft Copy Sperry-Sun Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: M pt J Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6013415.23 ft 551435.10 ft Latitude: 70 26 Longitude: 149 34 North Reference: Grid Convergence: 50.647 N 49.503 W True 0.40 deg Well: Plan MPJ-26 Slot Name: Well Position: +N/-S 1134.58 ft Northing: 6014554.00 ft +E/-W 627.80 ft Easting: 552055.00 ft Position Uncertainty: 0.00 ft Latitude: Longitude: 70 27 1.805 N 149 34 31.065 W Wellpath: Plan MPJ-26 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Well Ref. Point 34.00 ft Mean Sea Level 25.19 deg 80.85 deg Direction deg 282.62 Current Datum: Magnetic Data: Field Strength: Vertical Section: 69.00' 8/13/2003 57536 nT Depth From (TVD) ft 34.00 Height 69.00 ft Casing Points 2078.57 1869.00 BPRF 0.00 0.00 4048.66 3344.00 TUZC 0.00 0.00 4367.50 3574.00 Ugnu-MA 0.00 0.00 4375.18 3579.00 Ugnu-MB1 0.00 0.00 4454.85 3629.00 Ugnu-MB2 0.00 0.00 4719.40 3769.00 Ugnu-MC 0.00 0.00 4814.73 3809.00 SBF2-NA 0.00 0.00 4897.41 3839.00 SBF1-NB 0.00 0.00 4985.13 3869.00 SBE4-NC 0.00 0.00 5028.98 3884.00 SBE2-NE 0.00 0.00 5149.67 3924.00 SBE1-NF 0.00 0.00 5263.92 3954.00 TSBD-Top OA 0.00 0.00 5424.82 3984.00 TSBC-Base OA 0.00 0.00 5566.92 4009.00 TSBB-Top OB 0.00 0.00 0.00 SBA5-Base OB 0.00 0.00 · . Sperry-Sun - Draft Copy Sperry-Sun MPJ-26 T3.1 3819.00 437.67 -5242.58 6014955.00 546810.00 70 27 6.091 N 149 37 5.041 W MPJ-26 T2.1 3839.00 -243.37 -4532.25 6014279.00 547525.00 70 26 59.398 N 149 36 44.166 W MPJ-26 T4.1 3839.00 1224.34 -5467.11 6015740.00 546580.00 70 27 13.826 N 1493711.652W MPJ-26 ONOB Poly 3924.00 -299.88 -4460.64 6014223.00 547597.00 70 26 58.843 N 149 36 42.062 W -Polygon 1 3924.00 -472.96 -4308.83 6014051.00 547750.00 70 2657.141 N 149 36 37.601 W -Polygon 2 3924.00 -230.07 -4289.13 6014294.00 547768.00 70 26 59.530 N 149 36 37.026 W -Polygon 3 3924.00 -114.76 -4761.38 6014406.00 547295.00 70 27 0.662 N 149 36 50.897 W -Polygon 4 3924.00 266.63 -5096.76 6014785.00 546957.00 70 27 4.410 N 149 37 0.754 W -Polygon 5 3924.00 1263.28 -5314.82 6015780.00 546732.00 70 27 14.211 N 149 37 7.180 W -Polygon 6 3924.00 1223.38 -5617.14 6015738.00 546430.00 70 27 13.816 N 149 37 16.059 W -Polygon 7 3924.00 209.20 -5322.18 6014726.00 546732.00 70 27 3.844 N 149 37 7.374 W -Polygon 8 3924.00 -339.11 -4857.96 6014181.00 547200.00 70 26 58.454 N 149 36 53.729 W MPJ-26 flt1 3929.00 -76.14 -4276.05 6014448.00 547780.00 70 27 1.044 N 149 36 36.645 W -Polygon 1 3929.00 -76.14 -4276.05 6014448.00 547780.00 70 27 1.044 N 149 36 36.645 W -Polygon 2 3929.00 -494.35 -3680.90 6014034.00 548378.00 70 26 56.934 N 149 36 19.160 W MPJ-26 flt3 4004.00 68.34 -5488.19 6014584.00 546567.00 70 27 2.457 N 149 37 12.246 W -Polygon 1 4004.00 68.34 -5488.19 6014584.00 546567.00 70 27 2.457 N 149 37 12.246 W -Polygon 2 4004.00 545.65 -5094.81 6015064.00 546957.00 70 27 7.154 N 149 37 0.703 W MPJ-26 T1.1 4014.00 -290.55 -3362.44 6014240.00 548695.00 70 26 58.940 N 149 36 9.811 W MPJ-26 flt2 4019.00 50.56 -4660.21 6014572.00 547395.00 70 27 2.288 N 149 36 47.929 W -Polygon 1 4019.00 50.56 -4660.21 6014572.00 547395.00 70 27 2.288 N 149 36 47.929 W -Polygon 2 4019.00 -754.67 -4641.83 6013767.00 547419.00 70 26 54.369 N 149 36 47.375 W Plan Section Information 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 2.00 265.00 399.98 -0.15 -1.74 2.00 2.00 0.00 265.00 1465.24 33.99 264.33 1400.00 -32.00 -325.00 3.00 3.00 -0.06 -0.70 2008.13 44.78 266.12 1819.00 -60.00 -667.80 2.00 1.99 0.33 6.70 2149.01 44.78 266.12 1919.00 -66.71 -766.81 0.00 0.00 0.00 0.00 2235.86 41.32 265.72 1982.46 -70.92 -825.93 4.00 -3.99 -0.46 -175.60 4169.54 41.32 265.72 3434.80 -166.26 -2099.02 0.00 0.00 0.00 0.00 4887.46 70.00 264.00 3835.60 -220.36 -2683.09 4.00 4.00 -0.24 -3.36 5087.46 70.00 264.00 3904.00 -240.00 -2870.00 0.00 0.00 0.00 0.00 5334.17 79.87 264.18 3968.05 -264.49 -3106.67 4.00 4.00 0.07 1.04 5595.34 79.87 264.18 4014.00 -290.55 -3362.44 0.00 0.00 0.00 0.00 MPJ-26 T1.1 6248.74 107.96 272.98 3969.79 -307.35 -4006.96 4.50 4.30 1.35 17.25 6446.87 107.96 272.98 3908.70 -297.54 -4195.19 0.00 0.00 0.00 0.00 6796.66 95.00 285.00 3839.00 -243.37 -4532.25 5.00 -3.70 3.44 136.36 MPJ-26 T2.1 6992.51 91.16 297.36 3828.44 -172.82 -4714.21 6.60 -1.96 6.31 106.89 7048.02 91.16 297.36 3827.32 -147.32 -4763.49 0.00 0.00 0.00 0.00 7825.49 90.00 344.00 3819.00 437.67 -5242.58 6.00 -0.15 6.00 91.09 MPJ-26 T3.1 7849.21 88.58 344.07 3819.29 460.47 -5249.10 6.00 -5.99 0.30 177.14 8643.82 88.58 344.07 3839.00 1224.34 -5467.11 0.00 0.00 0.00 0.00 MPJ-26 T 4.1 · . Sperry-Sun - Draft Copy Sperry-Sun 34.00 0.00 0.00 34.00 -35.00 6014554.00 552055.00 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 31.00 6014554.00 552055.00 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 131.00 6014554.00 552055.00 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 231.00 6014554.00 552055.00 0.00 0.00 0.00 CB-GYRO-SS 400.00 2.00 265.00 399.98 330.98 6014553.84 552053.26 1.66 2.00 0.00 CB-GYRO-SS 500.00 5.00 264.58 499.78 430.78 6014553.23 552047.19 7.47 3.00 359.30 CB-GYRO-SS 600.00 8.01 264.47 599.13 530.13 6014552.07 552035.92 18.24 3.00 359.72 CB-GYRO-SS 700.00 11.01 264.42 697.74 628.74 6014550.35 552019.50 33.93 3.00 359.82 CB-GYRO-SS 800.00 14.01 264.40 795.36 726.36 6014548.09 551997.96 54.51 3.00 359.87 CB-GYRO-SS 900.00 17.02 264.38 891.70 822.70 6014545.29 551971.36 79.91 3.00 359.90 CB-GYRO-SS 1000.00 20.02 264.37 986.51 917.51 6014541.96 551939.79 110.06 3.00 359.92 MWD+IFR+MS 1100.00 23.02 264.36 1079.53 1010.53 6014538.10 551903.32 144.89 3.00 359.93 MWD+IFR+MS 1200.00 26.02 264.35 1170.50 1101.50 6014533.72 551862.05 184.30 3.00 359.94 MWD+IFR+MS 1300.00 29.03 264.34 1259.17 1190.17 6014528.85 551816.10 228.18 3.00 359.94 MWD+IFR+MS 1400.00 32.03 264.34 1345.30 1276.30 6014523.49 551765.60 276.41 3.00 359.95 MWD+IFR+MS 1465.24 33.99 264.33 1400.00 1331.00 6014519.73 551730.26 310.15 3.00 359.95 MWD+IFR+MS 1500.00 34.68 264.48 1428.71 1359.71 6014517.69 551710.76 328.78 2.00 6.70 MWD+IFR+MS 1600.00 36.67 264.86 1509.94 1440.94 6014511.87 551652.75 384.25 2.00 6.58 MWD+IFR+MS 1700.00 38.65 265.21 1589.10 1520.10 6014506.16 551591.93 442.49 2.00 6.27 MWD+IFR+MS 1800.00 40.64 265.53 1666.10 1597.10 6014500.57 551528.38 503.42 2.00 6.00 MWD+IFR+MS 1900.00 42.63 265.83 1740.83 1671.83 6014495.11 551462.18 566.97 2.00 5.75 MWD+IFR+MS 2008.13 44.78 266.12 1819.00 1750.00 6014489.34 551387.70 638.55 2.00 5.53 MWD+IFR+MS 2078.57 44.78 266.12 1869.00 1800.00 6014485.64 551338.23 686.12 0.00 0.00 BPRF BPRF 2100.00 44.78 266.12 1884.21 1815.21 6014484.52 551323.18 700.59 0.00 0.00 MWD+IFR+MS 2149.01 44.78 266.12 1919.00 1850.00 6014481.94 551288.75 733.69 0.00 0.00 MWD+IFR+MS 2200.00 42.75 265.89 1955.82 1886.82 6014479.24 551253.59 767.49 4.00 184.40 MWD+IFR+MS 2235.86 41.32 265.72 1982.46 1913.46 6014477.32 551229.66 790.47 4.00 184.57 MWD+IFR+MS 2300.00 41.32 265.72 2030.63 1961.63 6014473.86 551187.46 830.98 0.00 0.00 MWD+IFR+MS 2400.00 41.32 265.72 2105.74 2036.74 6014468.47 551121.67 894.15 0.00 0.00 MWD+IFR+MS 2500.00 41.32 265.72 2180.85 2111.85 6014463.08 551055.87 957.32 0.00 0.00 MWD+IFR+MS 2600.00 41.32 265.72 2255.95 2186.95 6014457.69 550990.08 1020.49 0.00 0.00 MWD+IFR+MS 2700.00 41.32 265.72 2331.06 2262.06 6014452.30 550924.28 1083.66 0.00 0.00 MWD+IFR+MS 2800.00 41.32 265.72 2406.17 2337.17 6014446.91 550858.49 1146.83 0.00 0.00 MWD+IFR+MS 2900.00 41.32 265.72 2481.28 2412.28 6014441.52 550792.69 1210.00 0.00 0.00 MWD+IFR+MS 3000.00 41.32 265.72 2556.38 2487.38 6014436.13 550726.90 1273.17 0.00 0.00 MWD+IFR+MS 3100.00 41.32 265.72 2631.49 2562.49 6014430.74 550661.10 1336.34 0.00 0.00 MWD+IFR+MS 3110.00 41.32 265.72 2639.00 2570.00 6014430.20 550654.52 1342.65 0.00 0.00 103/4" 10 3/4" 3200.00 41.32 265.72 2706.60 2637.60 6014425.35 550595.31 1399.50 0.00 0.00 MWD+IFR+MS 3300.00 41.32 265.72 2781.70 2712.70 6014419.96 550529.51 1462.67 0.00 0.00 MWD+IFR+MS 3400.00 41.32 265.72 2856.81 2787.81 6014414.57 550463.72 1525.84 0.00 0.00 MWD+IFR+MS 3500.00 41.32 265.72 2931.92 2862.92 6014409.18 550397.92 1589.01 0.00 0.00 MWD+IFR+MS 3600.00 41.32 265.72 3007.03 2938.03 6014403.79 550332.13 1652.18 0.00 0.00 MWD+IFR+MS 3700.00 41.32 265.72 3082.13 3013.13 6014398.40 550266.33 1715.35 0.00 0.00 MWD+IFR+MS 3800.00 41.32 265.72 3157.24 3088.24 6014393.01 550200.54 1778.52 0.00 0.00 MWD+IFR+MS 3900.00 41.32 265.72 3232.35 3163.35 6014387.63 550134.74 1841.69 0.00 0.00 MWD+IFR+MS 4000.00 41.32 265.72 3307.46 3238.46 6014382.24 550068.95 1904.85 0.00 0.00 MWD+IFR+MS 4048.66 41.32 265.72 3344.00 3275.00 6014379.61 550036.93 1935.59 0.00 0.00 TUZC TUZC 4100.00 41.32 265.72 3382.56 3313.56 6014376.85 550003.15 1968.02 0.00 0.00 MWD+IFR+MS 4169.54 41.32 265.72 3434.80 3365.80 6014373.10 549957.40 2011.95 0.00 0.00 MWD+IFR+MS 4200.00 42.53 265.61 3457.46 3388.46 6014371.42 549937.12 2031.42 4.00 356.64 MWD+IFR+MS 4300.00 46.53 265.30 3528.73 3459.73 6014365.37 549867.27 2098.40 4.00 356.72 MWD+IFR+MS 4367.50 49.22 265.11 3574.00 3505.00 6014360.83 549817.43 2146.17 4.00 356.94 Ugnu-MA Ugnu- 4375.18 49.53 265.09 3579.00 3510.00 6014360.29 549811.62 2151.72 4.00 357.07 Ugnu-MB1 Ugnu- · . Sperry-Sun - Draft Copy Sperry-SUD 4500.00 54.52 264.77 3655.78 3586.78 6014350.91 549713.72 2245.43 4.00 357.21 MWD+IFR+MS 4600.00 58.51 264.55 3710.95 3641.95 6014342.57 549630.76 2324.75 4.00 357.28 MWD+IFR+MS 4700.00 62.51 264.35 3760.16 3691.16 6014333.54 549544.21 2407.43 4.00 357.40 MWD+IFR+MS 4719.40 63.28 264.31 3769.00 3700.00 6014331.72 549527.04 2423.83 4.00 357.50 Ugnu-MC Ugnu- 4800.00 66.50 264.16 3803.20 3734.20 6014323.88 549454.49 2493.08 4.00 357.52 MWD+IFR+MS 4814.73 67.09 264.13 3809.00 3740.00 6014322.40 549441.03 2505.92 4.00 357.58 SBF2-NA SBF2- 4887.46 70.00 264.00 3835.60 3766.60 6014314.93 549373.77 2570.08 4.00 357.59 MWD+IFR+MS 4897.41 70.00 264.00 3839.00 3770.00 6014313.89 549364.48 2578.95 0.00 0.00 SBF1-NB SBF1- 4900.00 70.00 264.00 3839.88 3770.88 6014313.62 549362.06 2581.25 0.00 0.00 MWD+IFR+MS 4985.13 70.00 264.00 3869.00 3800.00 6014304.70 549282.58 2657.06 0.00 0.00 SBE4-NC SBE4- 5000.00 70.00 264.00 3874.09 3805.09 6014303.14 549268.69 2670.30 0.00 0.00 MWD+IFR+MS 5028.98 70.00 264.00 3884.00 3815.00 6014300.11 549241.63 2696.11 0.00 0.00 SBE2-NE SBE2- 5087.46 70.00 264.00 3904.00 3835.00 6014293.98 549187.02 2748.18 0.00 0.00 MWD+IFR+MS 5100.00 70.50 264.01 3908.24 3839.24 6014292.67 549175.30 2759.37 4.00 1.04 MWD+IFR+MS 5149.67 72.49 264.05 3924.00 3855.00 6014287.44 549128.50 2804.00 4.00 1.04 MPJ-26 OAt MPJ-2 5166.60 73.17 264.06 3929.00 3860.00 6014285.65 549112.42 2819.34 4.00 1.03 MPJ-26 fit MPJ-2 5200.00 74.50 264.09 3938.30 3869.30 6014282.12 549080.54 2849.75 4.00 1.02 MWD+IFR+MS 5263.92 77.06 264.13 3954.00 3885.00 6014275.33 549018.97 2908.50 4.00 1.02 TSBD-Top 0 TSBD- 5300.00 78.50 264.16 3961.64 3892.64 6014271.49 548983.91 2941.95 4.00 1.01 MWD+IFR+MS 5334.17 79.87 264.18 3968.05 3899.05 6014267.85 548950.56 2973.78 4.00 1.00 MWD+IFR+MS 5400.00 79.87 264.18 3979.63 3910.63 6014260.83 548886.14 3035.26 0.00 0.00 MWD+IFR+MS 5424.82 79.87 264.18 3984.00 3915.00 6014258.18 548861.85 3058.44 0.00 0.00 TSBC-Base TSBC- s 5500.00 79.87 264.18 3997.23 3928.23 6014250.17 548788.29 3128.64 0.00 0.00 MWD+IFR+MS 5538.50 79.87 264.18 4004.00 3935.00 6014246.06 548750.62 3164.59 0.00 0.00 MPJ-26 fit MPJ-2 5566.92 79.87 264.18 4009.00 3940.00 6014243.03 548722.81 3191.13 0.00 0.00 TSBB- T op 0 TSBB- 5595.34 79.87 264.18 4014.00 3945.00 6014240.00 548695.00 3217.67 0.00 0.00 MPJ-26 T1. MPJ-2 5600.00 80.07 264.24 4014.81 3945.81 6014239.51 548690.43 3222.03 4.50 17.25 MWD+IFR+MS 5700.00 84.37 265.58 4028.35 3959.35 6014230.04 548591.84 3316.39 4.50 17.23 MWD+IFR+MS 5800.00 88.67 266.90 4034.42 3965.42 6014222.81 548492.32 3412.13 4.50 17.05 MWD+IFR+MS 5900.00 92.97 268.22 4032.99 3963.99 6014217.86 548392.49 3508.66 4.50 16.97 MWD+IFR+MS 6000.00 97.28 269.54 4024.05 3955.05 6014215.21 548292.96 3605.38 4.50 16.99 MWD+IFR+MS 6100.00 101.58 270.89 4007.68 3938.68 6014214.88 548194.35 3701.70 4.50 17.11 MWD+IFR+MS 6200.00 105.87 272.28 3983.96 3914.96 6014216.88 548097.26 3797.03 4.50 17.33 MWD+IFR+MS 6248.74 107.96 272.98 3969.79 3900.79 6014218.70 548050.67 3842.95 4.50 17.66 MWD+IFR+MS 6300.00 107.96 272.98 3953.98 3884.98 6014220.90 548001.96 3891.02 0.00 0.00 MWD+IFR+MS 6364.00 107.96 272.98 3934.25 3865.25 6014223.64 547941.15 3951.04 0.00 0.00 75/8" 7 5/8" 6400.00 107.96 272.98 3923.15 3854.15 6014225.18 547906.94 3984.81 0.00 0.00 MWD+IFR+MS 6446.87 107.96 272.98 3908.70 3839.70 6014227.19 547862.40 4028.76 0.00 0.00 MWD+IFR+MS 6500.00 106.02 274.89 3893.18 3824.18 6014230.33 547811.70 4078.99 5.00 136.36 MWD+IFR+MS 6600.00 102.35 278.38 3868.67 3799.67 6014240.88 547715.36 4175.38 5.00 136.91 MWD+IFR+MS 6700.00 98.63 281.78 3850.47 3781.47 6014257.43 547618.48 4273.58 5.00 137.77 MWD+IFR+MS 6796.66 95.00 285.00 3839.00 3770.00 6014279.00 547525.00 4369.52 5.00 138.39 MPJ-26 T2. MPJ-2 6800.00 94.94 285.21 3838.71 3769.71 6014279.85 547521.78 4372.85 6.60 106.89 MWD+IFR+MS 6850.00 93.97 288.38 3834.83 3765.83 6014293.91 547473.97 4422.56 6.60 106.91 MWD+IFR+MS 6900.00 92.99 291.53 3831.79 3762.79 6014310.61 547426.95 44 72. 05 6.60 107.15 MWD+IFR+MS 6950.00 92.00 294.69 3829.61 3760.61 6014329.90 547380.88 4521.16 6.60 107.34 MWD+IFR+MS 6992.51 91.16 297.36 3828.44 3759.44 6014348.27 547342.57 4562.49 6.60 107.48 MWD+IFR+MS 7000.00 91.16 297.36 3828.29 3759.29 6014351.66 547335.90 4569.73 0.00 0.00 MWD+IFR+MS 7048.02 91.16 297.36 3827.32 3758.32 6014373.43 547293.12 4616.16 0.00 0.00 MWD+IFR+MS 7050.00 91.16 297.48 3827.28 3758.28 6014374.33 547291.35 4618.08 6.00 91.09 MWD+IFR+MS · . Sperry-Sun - Draft Copy Sperry-Sun 7100.00 91.10 300.48 3826.30 3757.30 6014398.24 547247.46 4666.04 6.00 91.10 MWD+IFR+MS 7150.00 91.03 303.48 3825.37 3756.37 6014424.41 547204.88 4713.20 6.00 91.15 MWD+IFR+MS 7200.00 90.97 306.48 3824.49 3755.49 6014452.78 547163.73 4759.43 6.00 91.21 MWD+IFR+MS 7250.00 90.90 309.48 3823.67 3754.67 6014483.27 547124.12 4804.60 6.00 91.26 MWD+IFR+MS 7300.00 90.83 312.48 3822.92 3753.92 6014515.78 547086.16 4848.59 6.00 91.31 MWD+IFR+MS 7350.00 90.76 315.48 3822.22 3753.22 6014550.24 547049.95 4891.28 6.00 91.36 MWD+IFR+MS 7400.00 90.69 318.48 3821.59 3752.59 6014586.54 547015.59 4932.55 6.00 91.40 MWD+IFR+MS 7450.00 90.61 321.48 3821.03 3752.03 6014624.60 546983.18 4972.28 6.00 91.44 MWD+IFR+MS 7500.00 90.53 324.48 3820.53 3751.53 6014664.30 546952.80 5010.38 6.00 91.47 MWD+IFR+MS 7550.00 90.45 327.48 3820.10 3751.10 6014705.53 546924.54 5046.73 6.00 91.50 MWD+/FR+MS 7600.00 90.37 330.48 3819.74 3750.74 6014748.19 546898.48 5081.24 6.00 91.53 MWD+IFR+MS 7650.00 90.29 333.47 3819.45 3750.45 6014792.15 546874.68 5113.80 6.00 91.55 MWD+/FR+MS 7700.00 90.21 336.47 3819.23 3750.23 6014837.29 546853.22 5144.34 6.00 91.57 MWD+IFR+MS 7750.00 90.13 339.47 3819.08 3750.08 6014883.50 546834.15 5172.77 6.00 91.58 MWD+IFR+MS 7800.00 90.04 342.47 3819.01 3750.01 6014930.64 546817.52 5199.00 6.00 91.59 MWD+IFR+MS 7825.49 90.00 344.00 3819.00 3750.00 6014955.00 546810.00 5211.51 6.00 91.59 MPJ-26 T3. MPJ-2 7849.21 88.58 344.07 3819.29 3750.29 6014977.75 546803.32 5222.86 6.00 177.14 MWD+IFR+MS 7900.00 88.58 344.07 3820.55 3751.55 6015026.47 546789.05 5247.12 0.00 0.00 MWD+IFR+MS 8000.00 88.58 344.07 3823.03 3754.03 6015122.40 546760.94 5294.90 0.00 0.00 MWD+IFR+MS 8100.00 88.58 344.07 3825.51 3756.51 6015218.33 546732.84 5342.69 0.00 0.00 MWD+IFR+MS 8200.00 88.58 344.07 3827.99 3758.99 6015314.26 546704.73 5390.47 0.00 0.00 MWD+IFR+MS 8300.00 88.58 344.07 3830.47 3761.47 6015410.18 546676.63 5438.25 0.00 0.00 MWD+IFR+MS 8400.00 88.58 344.07 3832.95 3763.95 6015506.11 546648.52 5486.03 0.00 0.00 MWD+IFR+MS 8500.00 88.58 344.07 3835.43 3766.43 6015602.04 546620.42 5533.81 0.00 0.00 MWD+IFR+MS 8600.00 88.58 344.07 3837.91 3768.91 6015697.96 546592.32 5581.59 0.00 0.00 MWD+IFR+MS 8643.00 88.58 344.07 3838.98 3769.98 6015739.21 546580.23 5602.13 0.00 0.00 41/2" 4 1/2" 8643.82 /" 88.58 344.07 3839.00 ,/ 3770.00 6015740.00 546580.00 5602.53 0.00 0.00 MPJ-26 T4. MPJ-2 SURVEY PROGRAM Depth Fro Depth To Surwy/Ptan Tool 34.00 1000.00 CB..QYRO..sS 1000.00 8643.82 MWD+IFR+MS - WELLPATH DET~ Colour ToMD Plan MPJ~26 0 Rig: 500 Ref. Datum: fll.iJiY 69.00ft 1000 ~Fs Origin Starting +E!-W From T\.-'D 1500 282.62'" 0.00 0.00 34.00 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10500 COMPANY DETAff..S BP Amoco ANTI-COLLISION SETTINOS WELL DETATI-S Nillre "'-N!..s +EI·W Northing E3sting Laûtude Longitude Slot Plan!\..jpJ·26 113458 627.80 6014554.00 552055.00 70"27'{}L80SN 149"'34'3L065W NlA SECTION DEVùLS TYO +Ni..$ "'EJ·W D!-'ß Thœ vSœ Target MPJ~26 n MPJ-26 T2. MPJ·2613. MPJ-26 T4. "" In< MD "'" ! , 3 4 5 6 7 8 9 !Q II 12 I) 14 " 16 11 lS " 20 · . Sperry-Sun - Draft Copy Anticollision Report Company: BP Amoco Date: 416/2004 Time: 16:27:53 Page:· 1. Field: Milne Point Reference Site: M Pt J Pad Co-ordinate(NE) Reference: Well: Plan MPJ-26, True North Reference WeD: Plan MPJ-26 Vertical (TVD) Reference: 69.00' 69.0 Reference WeJlpath: Plan MPJ-26 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 ofreference Reference: Plan: MPJ-26 wp08 & NOT PLANNED P GRÞ Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 34.00 to 8643.82 ft Sean Method: Trav Cytinder North Maximum Radius: 1060.98 ft Error Suñace: Ellipse + Casing Casing Points MD TVD Diameter BoleSIie Name ft ft in in 3110.00 2639.00 10.750 13.500 103/4" 6364.00 3934.25 7.625 9.875 75/8" 8643.00 3838.98 4.500 6.125 4 1/2" Plan: MPJ-26 wp08 Date Composed: 2/19/2004 Version: 24 Principal: Yes Tied-to: From Well Ref. Point Summary < Offset WeDpath > Reference Offset Ctr"ctr No-GO AUowable Site WeD Wellpath MD MD Distance· Area Deviation ft ft ft It ft M pt I Pad MPI-09 MPI-09 V12 6100.00 7900.00 778.36 193.80 584.56 Pass: Major Risk M PtI Pad Plan MPI-LlNK Plan MPI-LlNK VO Plan: 6562.63 8400.00 417.47 203.45 214.01 Pass: Major Risk MPtJPad MPJ-03 MPJ-03 V1 1306.61 1400.00 295.83 35.62 260.21 Pass: Major Risk M PtJ Pad MPJ-05 MPJ-05 V1 395.00 400.00 170.69 9.67 161.02 Pass: Major Risk M PtJ Pad MPJ-06 MPJ-06 V1 400.00 400.00 250.25 7.44 242.81 Pass: Major Risk M PtJ Pad MPJ-07 MPJ-07 V1 394.47 400.00 149.95 10.51 139.44 Pass: Major Risk M ptJ Pad MPJ-09A MPJ-09A V3 411.01 400.00 206.35 7.58 198.77 Pass: Major Risk M pt J Pad MPJ-09 MPJ-09 V1 411.01 400.00 206.35 7.58 198.77 Pass: Major Risk MPtJPad MPJ-12 MPJ-12 V1 400.00 400.00 229.10 7.82 221.28 Pass: Major Risk M PtJ Pad MPJ-13 MPJ-13 V1 400.00 400.00 185.90 7.74 178.16 Pass: Major Risk M PtJ Pad MPJ-15 MPJ-15 V5 406.34 400.00 206.73 7.45 199.28 Pass: Major Risk M PtJ Pad MPJ-16 MPJ-16 V1 710.58 700.00 171.54 12.17 159.37 Pass: Major Risk M pt J Pad MPJ-17 MPJ-17 V1 812.75 800.00 151.48 15.71 135.77 Pass: Major Risk M pt J Pad MPJ-18 MPJ-18 V2 517.52 500.00 116.22 9.61 106.60 Pass: Major Risk MPtJPad MPJ-19A MPJ-19A V1 606.04 600.00 86.21 11.55 74.66 Pass: Major Risk MPtJPad MPJ-19 MPJ-19 V1 606.04 600.00 86.22 11.51 74.72 Pass: Major Risk M PtJ Pad MPJ-20 MPJ-20 V1 2798.00 2900.00 141.41 113.38 28.03 Pass: Major Risk M PtJ Pad MPJ-20 MPJ-20A V8 2738.63 2800.00 136.46 109.59 26.87 Pass: Major Risk M PtJ Pad MPJ-21 MPJ-21 V3 703.87 700.00 22.14 13.15 9.00 Pass: Major Risk M pt J Pad MPJ-22 MPJ-22 V4 278.98 300.00 6.67 5.74 0.93 Pass: Major Risk M pt J Pad Plan MPJ-14 Plan MPJ-14 V15 Plan: 400.00 400.00 157.04 9.40 147.64 Pass: Major Risk M pt J Pad Plan MPJ-14 Plan MPJ-14L 1 V5 Plan: 400.00 400.00 157.04 9.40 147.64 Pass: Major Risk M PtJ Pad Plan MPJ-25 Plan MPJ-25 KIO Plug 0 395.32 400.00 146.64 9.73 136.91 Pass: Major Risk M PtJ Pad Plan MPJ-25 Plan MPJ-25 VO Plan: M 395.32 400.00 146.64 9.60 137.05 Pass: Major Risk M PtJ Pad Plan MPJ-25 Plan MPJ-25PB1 VO Plan 395.32 400.00 146.64 9.88 136.76 Pass: Major Risk M PtJ Pad Plan MPJ-26 Plan MPJ-26L 1 VO Plan: 4100.00 4100.00 0.00 0.00 0.00 FAIL: NOERRORS M pt J Pad Plan MPJ-26 Plan MPJ-26L2 V1 Plan: 4100.00 4100.00 0.00 0.00 0.00 FAIL: NOERRORS MPtJPad Plan MPJ-Dozer Plan MPJ-Dozer VO Plan 1216.04 1300.00 195.68 24.74 170.95 Pass: Major Risk M PtJ Pad Plan MPJ-Jax Plan MPJ-Jax VO Plan: 801.86 800.00 344.30 17.63 326.68 Pass: Major Risk M PtJ Pad Plan MPJ-Switch Plan MPJ-Switch VO Pia 2404.34 2400.00 332.84 62.36 270.49 Pass: Major Risk Site: M PtI Pad Well: MPI-D9 Rule Assigned: Major Risk Wellpath: MPI-D9 V12 Inter-Site Error: 0.00 ft Reference Offset 8eJnI.,Major AXis Ctr-Ctr No-GO AUowable MD TVD MD TVD Ref Offset TFO+AZI TF()...HS CasinglBS)istance Area Deviation ft ft ft ft ft ft deg deg in ft ft ft 5839.66 4034.75 7200.00 4334.08 24.88 35.94 160.12 252.70 8.500 1029.05 212.18 816.87 Pass 5879.18 4033.90 7300.00 4371.01 25.10 37.14 157.24 249.30 8.500 973.23 214.28 758.96 Pass 5916.92 4032.00 7400.00 4408.38 25.30 38.36 153.82 245.38 8.500 921.61 215.24 706.37 Pass 5952.89 4029.19 7500.00 4446.34 25.49 39.59 149.82 240.91 8.500 875.43 214.70 660.73 Pass 6000.00 4024.05 7600.00 4484.35 25.73 41.09 145.49 235.95 8.500 837.20 213.71 623.49 Pass 6023.82 4020.83 7700.00 4522.44 25.84 42.25 140.34 23D.48 8.500 807.28 208.44 598.84 Pass 6058.31 4015.40 7800.00 4560.88 26.01 43.62 134.95 224.63 8.500 787.39 201.85 585.55 Pass . . Sperry-Sun - Draft Copy Anticollision Report Company: BP Amoco Date: 4/6/2004 Time: 16:27:53 Field: Milne Point ,Reference Site: ' MPtJPad Co-ordinate(NE) Reference: Reference Well: , PIaÍ1 MPJ-26 Vertical (fVD) Reference: Reference Wellpatb: Plan MPJ-26 Site: M pt I Pad Well: MPI-09 Rule Assigned: Major Risk Wellpatb: MPI-09 V12 Inter-Site Error: 0.00 ft . Refe..eøce Offset ' SeJlÚoooMajor Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFo-HS CasinglHS)istance Area Deviation ft ft ft ft ft ft deg deg in ft ft ft' 6100.00 4007.68 7900.00 4599.57 26.21 45.18 129.45 218.56 8.500 778.36 193.80 584.56 Pass 6125.75 4002.27 8000.00 4638.63 26.32 46.49 123.64 212.39 8.500 780.68 182.04 598.64 Pass 6157.74 3994.87 8100.00 4677.41 26.46 47.94 117.99 206.30 8.500 792.62 169.29 623.33 Pass 6200.00 3983.96 8200.00 4714.64 26.64 49.65 112.72 200.44 8.500 812.67 156.64 656.03 Pass 6218.56 3978.77 8300.00 4751.67 26.71 50.87 107.40 194.85 8.500 841.94 141.44 700.50 Pass 6248.74 3969.79 8400.00 4788.94 26.84 52.37 102.76 189.78 8.500 880.51 128.72 751.79 Pass 6296.21 3955.15 8500.00 4826.56 27.05 53.19 98.07 185.08 8.500 926.77 115.66 811.11 Pass 6345.24 3940.04 8600.00 4864.60 27.27 54.01 93.87 180.89 8.500 979.12 105.65 873.46 Pass 6394.72 3924.78 8700.00 4903.17 27.49 54.85 90.18 177.20 8.500 1036.82 98.52 938.30 Pass Site: M PtI Pad Well: Plan MPI-LlNK Rule Assigned: Major Risk Wellpatb: Plan MPI-LlNK VO Plan: MPI-Link wp01 V1 Inter-Site Error: 0.00 ft Reference Offset SeJni..Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFo-US CasingIBS>istance Area Deviation ft ft ft ft ft ft deg deg in ft ft ft 4635.96 3729.34 6200.00 3763.24 17.48 17.04 172.33 267.85 7.000 1043.57 122.39 921.18 Pass 4714.53 3766.80 6300.00 3804.54 17.96 16.38 171.85 267.53 7.000 981.86 124.77 857.09 Pass 4796.05 3801.62 6400.00 3844.65 18.46 15.70 171.25 267.09 7.000 924.90 127.30 797.59 Pass 4880.14 3833.07 6500.00 3883.38 18.98 15.06 170.49 266.48 7.000 873.02 129.97 743.05 Pass 4967.89 3863.10 6600.00 3920.52 19.53 15.40 169.76 265.76 7.000 826.49 132.72 693.77 Pass 5058.70 3894.16 6700.00 3955.91 20.10 15.83 169.20 265.20 7.000 785.42 135.63 649.78 Pass 5148.55 3923.67 6800.00 3989.37 20.66 15.67 168.77 264.73 7.000 750.06 138.96 611.10 Pass 5238.46 3948.08 6900.00 4020.75 21.22 15.45 168.15 264.04 4.500 720.81 142.40 578.41 Pass 5328.48 3967.04 7000.00 4039.75 21.78 15.56 168.04 263.87 4.500 691.69 146.34 545.35 Pass 5422.29 3983.55 7100.00 4040.90 22.35 16.07 169.12 264.94 4.500 660.62 149.95 510.67 Pass 5516.08 4000.06 7200.00 4039.74 22.92 16.61 170.51 266.33 4.500 629.64 153.57 476.08 Pass 5607.90 4016.15 7300.00 4038.58 23.48 17.19 172.18 267.82 4.500 599.09 157.43 441.67 Pass 5690.53 4027.39 7400.00 4037.42 24.00 18.13 174.44 268.99 4.500 570.22 162.46 407.76 Pass 5775.32 4033.62 7500.00 4036.26 24.51 19.28 176.30 269.72 4.500 543.50 167.31 376.19 Pass 5861.60 4034.43 7600.00 4035.10 25.00 20.60 177.64 269.93 4.500 518.77 172.10 346.67 Pass 5948.59 4029.58 7700.00 4033.94 25.46 22.03 178.35 269.49 4.500 496.00 176.98 319.02 Pass 6035.49 4019.09 7800.00 4032.78 25.90 23.53 178.35 268.33 4.500 475.38 182.04 293.34 Pass 6121.50 4003.20 7900.00 4031.62 26.30 25.07 177.54 266.35 4.500 457.34 187.30 270.05 Pass 6205.86 3982.35 8000.00 4030.46 26.66 26.61 175.87 263.50 4.500 442.64 192.60 250.04 Pass 6294.21 3955.77 8100.00 4029.30 27.04 27.68 172.67 259.69 4.500 431.94 196.83 235.11 Pass 6388.65 3926.65 8200.00 4028.15 27.46 28.25 168.40 255.42 4.500 423.87 199.39 224.48 Pass 6478.30 3899.31 8300.00 4026.99 27.77 29.07 165.53 251.41 4.500 418.45 201.38 217.07 Pass 6562.63 3877.10 8400.00 4025.83 27.88 30.35 165.58 248.49 4.500 417.47 203.45 214.01 Pass 6649.84 3858.80 8500.00 4024.67 27.95 31.72 166.43 246.35 4.500 420.46 205.14 215.33 Pass 6739.02 3845.11 8600.00 4023.51 27.97 33.16 168.15 245.07 4.500 426.52 207.11 219.40 Pass 6822.80 3836.84 8700.00 4022.35 27.81 34.83 171.35 244.69 4.500 435.26 210.05 225.21 Pass 6900.00 3831.79 8800.00 4021.19 27.28 36.82 176.62 245.09 4.500 449.38 213.81 235.57 Pass 6964.89 3829.13 8900.00 4020.03 26.67 38.39 181.62 245.99 4.500 469.42 217.19 252.23 Pass 7049.28 3827.29 9000.00 4018.87 26.69 39.36 184.64 247.20 4.500 494.42 221.28 273.14 Pass 7113.19 3826.05 9100.00 4017.71 25.97 40.61 189.78 248.51 4.500 523.16 223.94 299.22 Pass 7174.15 3824.94 9200.00 4016.55 25.19 41.64 194.84 249.91 4.500 557.85 225.85 332.00 Pass 7231.92 3823.96 9300.00 4015.39 24.35 42.46 199.73 251.33 4.500 598.16 227.00 371.16 Pass 7286.35 3823.12 9400.00 4014.23 23.49 43.10 204.39 252.73 4.500 643.73 227.42 416.31 Pass 7337.40 3822.39 9500.00 4013.07 22.61 43.57 208.78 254.06 4.500 694.17 227.18 466.98 Pass 7385.10 3821.77 9600.00 4011.91 21.73 43.90 212.88 255.29 4.500 749.05 226.38 522.67 Pass . . . . Sperry-Sun - Draft Copy Anticollision Report Compaay: BP Amoco Date: 4/6/2004 Time: 16:27:53 Field: Milne Point . Reference Site: . MPtJPad Co-ordinate(NE) Reference: Reference WeD: Plan MPJ·26 Vertieal (fVD) Reference: ReferenceWeDpath: Plan MPJ-26 Site: M Pt I Pad Well: Plan MPI-LlNK Rule Assigned: Major Risk Wellpath: Plan MPI-LlNK VO Plan: MPI-Link wp01 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go MD TV» MD TV» Ref Offset TFO+AZI TFO-HS CasinglHS>istance Area ft ft ft ft ft ft deg deg in ft ft 7429.57 3821.25 9700.00 4010.75 20.87 44.12 216.69 256.44 4.500 807.99 225.12 Pass 7470.94 3820.81 9800.00 4009.59 20.03 44.23 220.21 257.48 4.500 870.59 223.51 Pass 7500.00 3820.53 9900.00 4008.43 19.43 44.37 222.89 258.41 4.500 936.58 222.54 Pass 7550.00 3820.10 10000.00 4007.27 18.35 44.16 226.75 259.27 4.500 1005.37 219.05 Pass M pt J Pad MPJ-03 Rule Assigned: Major Risk MPJ-03 V1 Inter-Site Error: 0.00 ft Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TV» Ref Offset TFO+AZI TFQ..HS CaslngIHS>istance Area Deviation Warmng ft ft ft ft deg deg in ft ft ft 35.20 35.20 0.00 0.00 350.56 350.56 396.85 1.01 395.83 Pass 100.00 100.00 0.15 0.15 350.56 350.56 396.75 2.54 394.21 Pass 200.00 200.00 0.49 0.44 350.53 350.53 396.45 5.45 391.00 Pass 300.00 300.00 0.72 0.76 350.49 350.49 395.99 8.10 387.89 Pass 400.00 399.99 0.81 1.18 350.68 85.68 395.05 10.64 384.41 Pass 500.85 500.63 500.00 499.97 0.94 1.62 351.47 86.90 392.62 13.37 379.24 Pass 600.88 599.99 600.00 599.84 1.09 2.05 353.03 88.56 387.20 16.11 371.09 Pass 699.14 696.90 700.00 699.44 1.27 2.47 355.49 91.07 378.32 18.87 359.46 Pass 795.11 790.61 800.00 798.69 1.48 2.90 358.88 94.49 367.21 21.74 345.47 Pass 888.62 880.81 900.00 897.56 1.72 3.34 3.15 98.77 355.28 24.71 330.57 Pass 979.17 966.91 1000.00 995.68 1.85 3.78 8.41 104.05 342.19 27.30 314.89 Pass 1066.34 1048.44 1100.00 1092.60 1.90 4.23 14.80 110.44 328.21 29.59 298.62 Pass 1150.15 1125.42 1200.00 1188.03 1.96 4.68 22.36 118.01 314.98 31.76 283.22 Pass 1230.20 1197.53 1300.00 1281.09 2.05 5.12 31.24 126.89 302.92 33.80 269.12 Pass 1306.61 1264.94 1400.00 1371.93 2.16 5.57 41.43 137.09 295.83 35.62 260.21 Pass 1379.85 1328.16 1500.00 1461.50 2.31 6.02 52.39 148.05 298.69 37.13 261.56 Pass 1449.63 1387.02 1600.00 1549.62 2.48 6.47 63.39 159.05 312.93 38.35 274.58 Pass 1518.62 1443.98 1700.00 1636.30 2.68 6.92 73.67 169.12 338.90 39.59 299.30 Pass 1586.36 1498.98 1800.00 1722.94 2.90 6.99 82.33 177.52 375.79 39.93 335.86 Pass 1652.28 1551.59 1900.00 1808.84 3.13 7.07 89.48 184.43 419.93 40.53 379.40 Pass 1715.43 1601.13 2000.00 1891.75 3.37 7.53 95.80 190.53 468.19 42.35 425.84 Pass 1775.25 1647.25 2100.00 1970.80 3.61 8.00 101.51 196.06 520.25 44.37 475.88 Pass 1831.42 1689.83 2200.00 2045.52 3.85 8.48 106.72 201.10 576.09 46.54 529.56 Pass 1884.94 1729.73 2300.00 2117.47 4.08 8.96 111.28 205.50 635.99 48.70 587.28 Pass 1936.82 1767.76 2400.00 2188.18 4.32 9.43 115.14 209.21 699.57 50.81 648.76 Pass 1986.58 1803.64 2500.00 2256.10 4.56 9.92 118.59 212.52 765.58 52.92 712.66 Pass 2040.96 1842.30 2600.00 2321.36 4.82 10.41 121.66 215.54 833.68 55.34 778.34 Pass 2100.61 1884.65 2700.00 2385.75 5.11 10.84 124.32 218.20 903.07 57.77 845.31 Pass 2175.71 1938.13 2800.00 2449.76 5.43 11.11 126.62 220.61 972.98 60.39 912.59 Pass 2272.47 2009.95 2900.00 2514.37 5.69 11.21 128.64 222.92 1040.88 63.18 977.70 Pass Site: M Pt J Pad Well: MPJ-05 Rule Assigned: Major Risk Wellpath: MPJ-05 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TV» MD TVD Ref Offset TFO+AZI TFO-HS CaslugIHS>istance Area Deviation ft ·ft ft ft ft ft deg deg in ft ft ft 34.00 34.00 35.20 35.20 0.00 0.00 36.32 36.32 168.13 1.01 167.12 Pass 98.80 98.80 100.00 100.00 0.15 0.15 36.35 36.35 168.28 2.54 165.74 Pass 198.80 198.80 200.00 200.00 0.49 0.31 36.47 36.47 168.67 5.06 163.60 Pass 298.80 298.80 300.00 300.00 0.72 0.58 36.64 36.64 169.05 7.54 161.51 Pass 395.00 394.98 400.00 399.99 0.81 0.88 37.29 132.29 170.69 9.67 161.02 Pass . ~ . . Sperry-Sun - Draft Copy Anticollision Report Company: BP Amoccí Date: 4/6/2004 Time: 16:27:53 Field: Milne Point Reference Site: M PtJ Pad Reference WeD: Plan MPJ-26 . Referenee WeDpath: Plan MPJ-26 Site: M PtJ Pad Well: MPJ-05 Rule Assigned: WeDpath: MPJ-05 V1 Inter-Site Error: Reference Offset Semi-Major Axis Ctr..ctr No-Go MD TVD MD TVD Ref Offset TFO+AZI TFo-US CasingIHS>istanee Area ft ft ft ft ft ft deg deg in ft ft 489.00 488.82 500.00 499.99 0.93 0.91 38.85 134.25 175.28 11.06 Pass 582.07 581.36 600.00 599.98 1.07 0.98 41.40 136.92 183.56 12.57 Pass 673.84 672.03 700.00 699.98 1.22 1.26 44.70 140.27 195.97 14.73 Pass 763.93 760.28 800.00 799.97 1.41 1.29 48.33 143.93 212.83 16.12 Pass 851.99 845.62 900.00 899.96 1.62 1.29 52.06 147.67 234.25 17.43 Pass 937.60 927.55 1000.00 999.95 1.79 1.63 55.68 151.31 26Q.63 19.51 241.12 Pass 1020.39 1005.64 1100.00 1099.92 1.88 2.05 59.01 154.65 292.32 21.55 270.77 Pass 1100.00 1079.53 1200.00 1199.84 1.91 2.44 61.87 157.51 329.93 23.28 306.66 Pass 1175.05 1148.01 1300.00 1299.45 1.98 2.79 63.91 159.56 375.53 24.83 350.70 Pass 1245.24 1210.91 1400.00 1398.49 2.07 3.19 65.28 160.93 428.76 26.39 402.37 Pass 1311.23 1268.97 1500.00 1497.24 2.17 3.60 66.41 162.07 486.69 27.91 458.79 Pass 1373.66 1322.88 1600.00 1595.91 2.30 3.98 67.42 163.08 547.86 29.29 518.57 Pass 1432.50 1372.70 1700.00 1694.42 2.44 4.38 68.27 163.93 612.30 30.60 581.70 Pass 1490.16 1420.60 1800.00 1792.73 2.59 4.81 68.98 164.55 679.71 31.98 647.73 Pass 1547.94 1467.90 1900.00 1890.76 2.78 5.23 69.57 164.91 749.64 33.34 716.30 Pass 1600.00 1509.94 2000.00 1987.55 2.94 5.63 69.86 165.00 823.96 34.55 789.41 Pass 1649.33 1549.26 2100.00 2082.67 3.12 6.06 69.92 164.88 902.63 35.73 866.90 Pass 1700.00 1589.10 2200.00 2176.79 3.31 6.52 69.91 164.70 983.90 36.91 946.99 Pass Site: MPtJPad Well: MPJ-06 Rule Assigned: Major Risk WeUpath: MPJ-06 V1 Inter-Site Error: 0.00 ft . Reference Offset Semi-Major Axis Ctr-Ctr No-Go AUowable MD TVD MD TVD Ref Offset TFO+AZI TFO-RS CasingIR!ÐIstanee Area Deviation ft ft ft ft ft ft deg deg in ft ft ft 34.00 34.00 31.00 31.00 0.00 0.00 11.82 11.82 250.34 1.01 249.33 Pass 103.00 103.00 100.00 100.00 0.16 0.04 11.82 11.82 250.29 2.30 247.99 Pass 203.00 203.00 200.00 200.00 0.50 0.09 11.81 11.81 250.07 4.47 245.59 Pass 302.93 302.93 300.00 300.00 0.72 0.10 11.84 106.84 249.95 6.16 243.79 Pass 400.00 399.98 400.00 400.00 0.81 0.12 12.34 107.34 250.25 7.44 242.81 Pass 496.16 495.95 500.00 500.00 0.94 0.16 13.73 109.14 252.15 8.80 243.34 Pass 591.03 590.24 600.00 600.00 1.08 0.20 16.20 111.72 256.07 10.22 245.85 Pass 684.57 682.59 700.00 699.99 1.24 0.26 19.55 115.12 262.64 11.70 250.94 Pass 776.32 772.35 800.00 799.99 1.44 0.32 23.66 119.26 272.53 13.28 259.25 Pass 865.99 859.09 900.00 899.98 1.66 0.36 28.15 123.77 286.56 14.83 271.72 Pass 953.23 942.37 1000.00 999.98 1.81 0.41 32.88 128.51 304.96 16.19 288.77 Pass 1037.80 1021.90 1100.00 1099.98 1.89 0.45 37.61 133.25 327.93 17.21 310.72 Pass 1119.88 1097.79 1200.00 1199.96 1.93 0.48 41.90 137.55 355.80 18.14 337.66 Pass 1200.00 1170.50 1300.00 1299.91 2.00 0.54 45.63 141.28 388.67 19.19 369.48 Pass 1275.77 1237.91 1400.00 1399.84 2.11 0.60 49.01 144.67 426.42 20.21 406.22 Pass 1349.33 1301.99 1500.00 1499.72 2.25 0.66 51.91 147.57 468.44 21.22 447.22 Pass 1420.60 1362.70 1600.00 1599.35 2.41 0.74 54.13 149.79 514.03 22.32 491.71 Pass 1491.70 1421.88 1700.00 1698.52 2.60 0.85 55.71 151.27 562.81 23.55 539.26 Pass 1565.05 1481.78 1800.00 1797.11 2.83 1.00 56.85 152.12 613.13 24.97 588.16 Pass 1637.74 1540.07 1900.00 1894.83 3.08 1.20 57.57 152.57 663.38 26.54 636.84 Pass 1709.84 1596.78 2000.00 1991.27 3.35 1.50 57.91 152.66 713.35 28.35 685.00 Pass 1780.71 1651.41 2100.00 2086.31 3.63 1.86 57.94 152.47 764.17 30.41 733.76 Pass 1850.07 1703.81 2200.00 2179.68 3.93 2.30 57.70 152.02 816.17 32.68 783.48 Pass 1918.04 1754.07 2300.00 2271.37 4.23 2.78 57.28 151.40 869.11 35.13 833.97 Pass 1984.71 1802.31 2400.00 2362.30 4.55 3.30 56.87 150.82 923.08 37.71 885.38 Pass 2062.22 1857.39 2500.00 2452.24 4.92 3.79 56.42 150.30 977.13 40.49 936.63 Pass 2145.51 1916.52 2600.00 2541.77 5.33 4.27 55.94 149.82 1031.81 43.44 988.37 Pass 49 26 00 1-0il 0 0 z 1 Vi '1 49 34 00 III 1 o iii 3 w 4000 III I 00 I p055264 DATE 3/2/2004 PR022604F INVOICE I CREDIT MEMO DESCRIPTION GROSS DATE 3/2/2004 CHECK NO. 055264 VENDOR DISCOUNT NET V11 P~r- Z le Li J Ll.. PERMIT TO DRILL PPLlCATIONS POUCH TO TERRI UBBLE MB7-5 THE AITACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORA(3:I;, AK995t9-6612 PAY: TO THE ORDER OF: RECEIV 0 APR 1 5 20 4 laska Oil & Gas Cons. Anchorage TOTAL ~ NATIONAL CITY BANK Ashland, Ohio STATE OF ALASKA AOGCC 333 WEST 7TH AVENUE SUITE 1 ANCHORAGE AK 99501 1110 5 5 2 b ... III I: 0... . 2 0 ~ B 11 51: O. 2 7 B 11 b liD 56-389 "'"412 No. P 055264 CONSOLIDATED COMMERCIAL ACCOUNT DATE AMOUNT 3/2/2004 1..../I**t***$100 .Oo*****t NQ1~"~~·~&!!'<::,;"""":';'·,·¡·,:¡ '''~ ~j;f1~::;\:~~;~;;;Ä;::'~~i~~ H . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /fl(ì{ ~ ~ 2þ PTD# 20 tj- obi vi Development Service Exploration Stratigraphic CHECK WBA T ADD-ONS "CLUE"- APPLIES (OPTIONS) MULTI Tbe permit is for a Dew weHbore segment of LATERAL existing well , Permit No, API No. . (If API number Production. sbould continue to be reported as last two (2) digits a functioD 'of tbe original API number stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(f), an (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) .' and API Dum ber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing e:J cep1ion. (Company Name) assumes tbe Jiability of any protest to tbe spacinge:xceptioD tbat may occur. DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample inten'a)s through target zones. o o Well bore seg Annular Disposal On Program DEV On/Off Shore 11328 Unit J-26 Well Name: DEV L PEND GeoArea 89 MPU Schrader Bluff Oil POQI;_COnSEU'latiOIl On:ler_No, 417 Yi!S _Yi!S Yi!S Yi!S Yi!S Yi!S Yes Yes Yes Yi!S Xes Yi!S Yes NA _NA NA NA Initial Classffype MILNE POINT, SCHRADER BLFF OIL - 525140 ING Field & Pool Pi!rmit fee attached leasi! _number ~""", _U_nique weltna oc! lJumb_er ,....".ORriate_ WelUocati!d [n_a defined pool WeJUQcated pr:oper _distance from driJIing unitb9und~l)'_ Well Jocati!d proper distance_ from Qtber wells _S_utficient ~creage_aYailable in_drillilJg unjt incJudec! js weJlbore plat Jtdi!yiatec!, JQrce ~n be issued wjtbQut com¡ervaJion order ~an be issued wjtbout actmilJistratille_approyaJ _Operator only affected party _Oper:ator bas_approprlate_Qond in Pi!rmit Pi!rmit Can permit Well Jocati!d within area alldstrata _authorized by_'njectiolJ Ordi!r # (put 10# 15-day wait be approved before in_c~>t11mi!nts) (For service well onJy) servjej;! -"'lIeU only) than 3 montbs (For review jdi!otified duration_of pre-produGtion Ii!SS (For _All welJs_ wit)1in JlÜoile_area_of _Pre-produJ;ect injector 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 7 Administration Date Appr SFD 4/19/2004 w Well driJlect from exjstiog pad, Jb)(3). 102 47_. 811 a~uifers eXi!mpted 40 CFB $creenJinercompletion planne_d._ weU(s) J No reseJ'le_pjtplanoed, All waste to_Class Big js_equippe_d_with steeLpjts. includ_ed. I?r9~imiJY an~IY$is pertoune_d_and close_approa~heS identified, _Traveling _cyli_nder plot Direçtjonal_mitjgatiQn_ strati!gies av~jjaÞle, Maximum BHI? B._5EMW._ I?lann_ed m_ud weigbts 9.0 ppg. 9.1 -- . 3000 psUest pressure_proposed, 13~2 psi CalcuJaJed_MASP_ Yi!S NA Yes No_ No_ Yi!S Yi!S NA _Yi!S Yes Yi!S Yi!S Yes Yi!S Yi!S No_ NA Con_sistencyh_as beeRissued_ fortbis pr_oiect _ACMP Fjndjngof _C9ndu_ctor string_provided S_ud'ace _casingprQteds alLknowll USDWs & SUJtcsg conductor: _CMT v_ol adequate_ to tie-in Jong _string to_sud' CS-9_ CMT yol adequ_ate_ to circ_ulate_on knownpro_ductiye bOrJl:ons C, _CMT will coyer a] _Casing designs acteQua_te for _ T" B _&_ Rermafr_ost Jta_re-drilt has_a_ 10,.403 for abandOllme_nt bei!O approved Adequ~te _weUbore separatjo_n _proposed -- ,t meet reguJations _DJilliog fJujd_Rrogram s~hematic_& e~uipJistadequate _BOPEs,_d_o Jfdiverter re~uiJed, does jhey meet reguJa_tion psig in_comments) Work will occ_ur withoutoperatjon _shutdown_ Js presence_ of H2S gas_ RrOQable _ _ Mechan[caLcoodjtion otwells within 80B verified (For:s_ervice well ollly) _Adequatejankage_or re_serve pit test to (put _C_hokemanifold compJies wlAPI RF'-53 (May 84) ratiog appropriate; _BOPEpress 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Engineering App Date TEM 4/20/2004 Jft1T1 Hjg is equjpped with s_ensoJS and alarms. Walter QJJay, BP, 4J20iQ4; no H2$ known jll J-I?ad_ wells tod~te, SFD Expected reservojr pre_S$ure is8,5ppg EMW; wilLbe _drilled witb 9.1 ppg mud. Muct Sh9Uld preclude_ H2_S onJbe rig, Yi!S Yi!$ _NA cao be issued wio hydr:ogen sulfide measures Pi!rmit D_atapJeseoted on Rotential oyeJRreSsuri! _zones _Si!ismic_analysjs of sbaJlow gas_z90es _Seabed Conta_ct nam_el,p)1olle_forweekly progress reRorts Date _(if off-sh9re) Engineering Commissioner: conditioo survey Date: 35 36 37 38 39 Geology Date 4/20/2004 Geologic Commissioner a6 Appr SFD e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility e 'Z' ,- ~O /-J ;¡. Û 1/ ,- 0 (pc{ $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 30 15:08:14 2004 Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin.................. .STS Reel Name........... . . . . .UNKNOWN Continuation Number..... .01 Previous Reel Name..... ..UNKNOWN Comments.......... ..... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name..... ...... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 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 MPJ-26 PB2 500292320571 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 30-JUN-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 2 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 3 MW0003066223 T. MCGUIRE D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 5 MW0003066223 C.A. DEMOSKI E. VAUGHN MWD RUN 6 MW0003066223 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 28 13N 10E 2156 3267 68.70 34.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. 13.500 9.625 6.750 (IN) SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 109.0 3104.0 6404.0 e # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS SECTION, AN OPEN-HOLE SIDETRACK, EXITS THE MPJ-26 PB1 WELLBORE AT 7280'MD. MPJ-26 PB2 WAS PLUGGED BACK FOR GEOLOGICAL REASONS. MPJ-26 EXITS THIS WELLBORE AT 8330'MD. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 4 - 6 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 5 & 6 ALSO INCLUDED AT-BIT- INCLINATION (ABI). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 6/4/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 6 REPRESENT WELL MPJ-26 PB2 WITH API#: 50-029-23205-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8562'MD/3817'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 (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name....... ......STSLIB.001 Service Sub Level Name... Version Number..... .., ...1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type........... .....LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves¡ all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ .5000 e e START DEPTH 69.5 112.0 3085.5 3085.5 3085.5 3085.5 3085.5 STOP DEPTH 8503.5 8562.0 8510.5 8510.5 8510.5 8510.5 8510.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 69.5 808.0 MWD 2 808.0 1094.0 MWD 3 1094.0 3114.0 MWD 4 3114.0 6417.0 MWD 5 6417.0 7280.0 MWD 6 7280.5 8562.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction. ..... .......... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing..... ............... .60 .1IN Max frames per record............ . Undefined Absent value.... ................. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 8562 4315.75 16986 69.5 8562 ROP MWD FT/H 0 1524.69 222.953 16901 112 8562 GR MWD API 18.07 120.97 67.6405 16869 69.5 8503.5 RPX MWD OHMM 0.3 2000 26.146 10851 3085.5 8510.5 RPS MWD OHMM 0.28 2000 28.2616 10851 3085.5 8510.5 RPM MWD OHMM 0.06 2000 48.481 10851 3085.5 8510.5 RPD MWD OHMM 0.11 2000 54.1787 10851 3085.5 8510.5 FET MWD HOUR 0.11 48.61 1.32656 10851 3085.5 8510.5 First Reading For Entire Fi~. ........69.5 Last Reading For Entire File.......... .8562 e File Trailer Service name... ......... .STSLIB.001 service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.... ..... ..STSLIB.002 Physical EOF File Header Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 69.5 112.0 STOP DEPTH 771.0 808.0 # 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: 12-MAY-04 Insite 66.37 Memory 808.0 112.0 808.0 .3 7.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 120557 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 109.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: SPUD MUD 9.00 205.0 9.0 MUD CHLORIDES (PPM): tIÞ 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: 200 14.0 e .000 .000 .000 .000 .0 71. 6 .0 .0 # 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 .1IN Max frames per record............ . Undefined Absent value................... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 808 438.75 1478 69.5 808 ROP MWD010 FT/H 0.21 384.85 69.8718 1393 112 808 GR MWD010 API 26.42 106.82 59.7962 1404 69.5 771 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .808 File Trailer Service name.... ....... ..STSLIB.002 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type. .............. .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name...... .... ...STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type.... ...........tIt Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 771.5 808.5 STOP DEPTH 1055.0 1094.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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): 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.....O Logging Direction................ . Down 12-MAY-04 Insite 66.37 Memory 1094.0 808.0 1094.0 12.3 24.9 TOOL NUMBER 120557 13.500 109.0 SPUD MUD 9.00 205.0 9.0 200 14.0 .000 .000 .000 .000 .0 64.4 .0 .0 Optical log depth units.~...... .Feet Data Reference Point............. .Undefined Frame Spacing................ .....60 .1IN Max frames per record.... ... ......Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e Name DEPT ROP GR MWD020 MWD020 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Service Order Units FT FT/H API Size 4 4 4 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 771.5 1094 932.75 646 771.5 1094 ROP MWD020 FT/H 14.11 622.51 95.1629 572 808.5 1094 GR MWD020 API 29.65 101.36 69.4162 568 771.5 1055 First Reading For Entire File. ... ......771.5 Last Reading For Entire File...... .....1094 File Trailer Service name... ......... .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .....04/06/30 Maximum Physical Record..65535 File Type............... .LO Next File Name.. ........ .STSLIB.004 Physical EOF File Header Service name........ .... .STSLIB.004 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 1055.5 1094.5 STOP DEPTH 3069.0 3114.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 13-MAY-04 Insite 66.37 Memory e TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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): 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.....O Logging Direction..... ........... . Down Optical log depth units. . . . . . . . . . .Feet Data Reference Point.......... ... . Undefined Frame Spacing................ .....60 .1IN Max frames per record...... .......Undefined Absent value.... . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Units FT FT/H API 3114 . 0 1094.0 3114.0 28.6 44.0 TOOL NUMBER 120557 13.500 109.0 SPUD MUD 9.20 131.0 9.0 400 9.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 64.4 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1055.5 3114 2084.75 4118 1055.5 3114 ROP MWD030 FT/H 2.71 939.73 254.246 4040 1094.5 3114 GR MWD030 API 25.85 120.5 72.3332 4028 1055.5 3069 First Reading For Entire File......... .1055.5 Last Reading For Entire Fil~........ .3114 e File Trailer Service name............ .STSLIB.004 service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation... ... .04/06/30 Maximum Physical Record..65535 File Type........... .....LO Next File Name...... .....STSLIB.005 Physical EOF File Header Service name..... ....... .STSLIB.005 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type....... . . . . . .. . .LO Previous File Name... ... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPM RPS ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 3069.5 3085.5 3085.5 3085.5 3085.5 3085.5 3114.5 STOP DEPTH 6370.5 6363.0 6363.0 6363.0 6363.0 6363.0 6417.0 # 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: 16-MAY-04 Insite 66.37 Memory 6417.0 3114.0 6417.0 39.5 109.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 120558 134760 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.625 3104.0 # 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: e e LSND 9.10 46.0 8.5 530 7.0 3.000 2.210 3.900 2.000 64.0 89.1 64.0 64.0 # 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 .1IN Max frames per record.. .......... .Undefined Absent value..... ...... ......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3069.5 6417 4743.25 6696 3069.5 6417 ROP MWD040 FT/H 2.32 1524.69 281.718 6606 3114.5 6417 GR MWD040 API 18.07 120.97 68.8527 6603 3069.5 6370.5 RPX MWD040 OHMM 0.3 97 11.0497 6556 3085.5 6363 RPS MWD040 OHMM 0.28 1800.36 12.2644 6556 3085.5 6363 RPM MWD040 OHMM 0.16 2000 15.8618 6556 3085.5 6363 RPD MWD040 OHMM 0.11 2000 17.1925 6556 3085.5 6363 FET MWD040 HOUR 0.11 40.38 0.941396 6556 3085.5 6363 First Reading For Entire File..... .... .3069.5 Last Reading For Entire File.......... .6417 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number....... ... .1.0.0 Date of Generation..... .~/06/30 Maximum Physical Record. .65535 File Type.. .... ......... .LO Next File Name........ ...STSLIB.006 Physical EOF File Header Service name..... ....... .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type........... .....LO Previous File Name.. .....STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAWMWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPD RPM GR ROP $ 6 e header data for each bit run in separate files. 5 .5000 START DEPTH 6363.5 6363.5 6363.5 6363.5 6363.5 6371.0 6417.5 # 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: # STOP DEPTH 7280.0 7280.0 7280.0 7280.0 7280.0 7280.0 7280.0 19-MAY-04 Insite 66.37 Memory 7280.0 6417.0 7280.0 87.5 108.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 184054 159436 # 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): 6.750 6404.0 oil Based 9.35 71.0 .0 40000 .0 RESISTIVITY (OHMM) AT4ItMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: e .000 .000 .000 .000 .0 .0 .0 .0 # 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 .1IN Max frames per record.. .......... .Undefined Absent value........ ............ ..-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6363.5 7280 6821.75 1834 6363.5 7280 ROP MWD050 FT/H 0 470.16 164.583 1726 6417.5 7280 GR MWD050 API 34.6 100.45 68.1466 1819 6371 7280 RPX MWD050 OHMM 3.36 1149.73 16.7734 1834 6363.5 7280 RPS MWD050 OHMM 3.62 1573.53 19.3443 1834 6363.5 7280 RPM MWD050 OHMM 0.06 2000 49.3379 1834 6363.5 7280 RPD MWD050 OHMM 2.08 2000 86.6814 1834 6363.5 7280 FET MWD050 HOUR 0.36 48.61 3.61774 1834 6363.5 7280 First Reading For Entire File.. ........6363.5 Last Reading For Entire File.... ...... .7280 File Trailer Service name. ........ ....STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type........ ....... .LO Next File Name... ...... ..STSLIB.007 Physical EOF e File Header Service name. ........... .STSLIB.007 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type.. .... ......... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 7 e header data for each bit run in separate files. 6 .5000 START DEPTH 7280.5 7280.5 7280.5 7280.5 7280.5 7280.5 7280.5 STOP DEPTH 8510.5 8510.5 8510.5 8510.5 8503.5 8562.0 8510.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 20-MAY-04 Insite 66.37 Memory 8562.0 7280.0 8562.0 85.6 109.4 TOOL NUMBER 184054 159436 6.750 6404.0 Oil Based 9.30 73.0 .0 44000 .0 .000 .000 .000 .000 .0 .0 .0 .0 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): e e # 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 .1IN Max frames per record........... ..Undefined Absent value......... ...... ..... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7280.5 8562 7921.25 2564 7280.5 8562 ROP MWD060 FT/H 1.26 1326.13 173.212 2564 7280.5 8562 GR MWD060 API 23.27 102.51 60.3575 2447 7280.5 8503.5 RPX MWD060 OHMM 3.72 2000 73.3466 2461 7280.5 8510.5 RPS MWD060 OHMM 3.36 2000 77.5228 2461 7280.5 8510.5 RPM MWD060 OHMM 2.75 2000 134.739 2461 7280.5 8510.5 RPD MWD060 OHMM 3.51 2000 128.487 2461 7280.5 8510.5 FET MWD060 HOUR 0.33 10.67 0.645177 2461 7280.5 8510.5 First Reading For Entire File......... .7280.5 Last Reading For Entire File.......... .8562 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.. .....04/06/30 Maximum Physical Record. .65535 File Type... ... ......... .LO Next File Name.. ........ .STSLIB.008 Physical EOF Tape Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name......... ...... .UNKNOWN Continuation Number. ....~ 4IÞ Next Tape Name.......... . UNKNOWN Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........ .....LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name......... . . . . . . .UNKNOWN Continuation Number.... ..01 Next Reel Name...... .....UNKNOWN Comments. ............... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Dr~ing Services LIS Scan Utility e /zi:5 (1 $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 30 13:27:51 2004 Reel Header Service name..... ...... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ... ......... .UNKNOWN Continuation Number.. '" .01 Previous Reel Name.... ...UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 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 MPJ-26 PB1 500292320570 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 30-JUN-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 2 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 3 MW0003066223 T. MCGUIRE D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 5 MW0003066223 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 28 13N 10E 2156 3267 MSL 0) 68.70 34.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS -1o'l-~ ()G 4 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. 13 .500 9.625 6.750 (IN) SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 109.0 3104.0 6404.0 e # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THE MPJ-26 PB2 WELLBORE EXITS THIS SECTION AT 7280'MD. THIS SECTION WAS PLUGGED BACK FOR GEOLOGICAL REASONS. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 4 & 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 5 ALSO INCLUDED AT-BIT-INCLINATION (ABI) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 6/4/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 5 REPRESENT WELL MPJ-26 PB1 WITH API#: 50-029-23205-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8074'MD/3807'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 (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type.. .... ......... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # 1 and clipped curves; all bit runs merged. .5000 FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ e START DEPTH 69.5 112.0 3060.5 3060.5 3060.5 3060.5 3060.5 STOP DEPTH 8015.0 8073.5 8022.0 8022.0 8022.0 8022.0 8022.0 e # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 69.5 808.0 1094.0 3114.0 6417.0 MERGE BASE 808.0 1094.0 3114.0 6417.0 8073.5 # 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 .1IN Max frames per record............ . Undefined Absent value...... ............... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 69.5 0.21 18.07 0.3 0.28 0.06 0.11 0.11 Max 8073 .5 1524.69 120.97 1149.73 1800.36 2000 2000 48.61 Mean 4071.5 227.598 68.6166 16.5913 15.5748 23.8237 33.4859 1. 56225 Nsam 16009 15924 15892 9924 9924 9924 9924 9924 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .8073.5 First Reading 69.5 112 69.5 3060.5 3060.5 3060.5 3060.5 3060.5 Last Reading 8073 .5 8073.5 8015 8022 8022 8022 8022 8022 e File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type.. ............. .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type... .... ........ .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 e header data for each bit run in separate files. 1 .5000 START DEPTH 69.5 112.0 STOP DEPTH 771.0 808.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 12-MAY-04 Insite 66.37 Memory 808.0 112.0 808.0 .3 7.7 TOOL NUMBER 120557 13.500 112.0 SPUD MUD 9.00 205.0 9.0 200 14.0 MUD MUD MUD MUD AT MEASURED TE.RATURE (MT): AT MAX CIRCULATING TERMPERATURE: FILTRATE AT MT: CAKE AT MT: .000 .000 .000 .000 .0 71. 6 .0 .0 # 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.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point... ......... ..Undefined Frame Spacing...... .... .......... .60 .1IN Max frames per record........... ..Undefined Absent value............. ..... ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 808 438.75 1478 69.5 808 ROP MWD010 FT/H 0.21 384.85 69.8718 1393 112 808 GR MWD010 API 26.42 106.82 59.7962 1404 69.5 771 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .808 File Trailer Service name. ........ ... .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type........... .....LO Next File Name....... ... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type........... .....LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ e 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 771. 5 808.5 STOP DEPTH 1055.0 1094.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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): 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.....O Logging Direction.... ............ . Down Optical log depth units.......... .Feet Data Reference Point.. ........... . Undefined Frame Spacing..... .... ... ........ .60 .1IN 12-MAY-04 Insite 66.37 Memory 1094.0 808.0 1094.0 12.3 24.9 TOOL NUMBER 120557 13.500 112.0 SPUD MUD 9.00 205.0 9.0 200 14.0 .000 .000 .000 .000 .0 64.4 .0 .0 Max frames per record.. .tIt.... ...Undefined Absent value............... ...... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 771. 5 1094 932.75 646 771. 5 1094 ROP MWD020 FT/H 14.11 622.51 95.1629 572 808.5 1094 GR MWD020 API 29.65 101. 36 69.4162 568 771. 5 1055 First Reading For Entire File...... '" .771.5 Last Reading For Entire File.. ........ .1094 File Trailer Service name...... .......STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..04/06/30 Maximum Physical Record. .65535 File Type........ ...... ..LO Next File Name...... .....STSLIB.004 Physical EOF File Header Service name. .... ...... ..STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type............ ....LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 1055.5 1094.5 STOP DEPTH 3069.0 3114.0 # 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): 13 -MAY-04 Insite 66.37 Memory 3114 . 0 1094.0 3114 . 0 BIT ROTATING SPEED (RPM)~ HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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): 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.....O Logging Direction.... ...... ...... .Down Optical log depth units.......... .Feet Data Reference Point.... ......... .Undefined Frame Spacing................. ....60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 28.6 44.0 TOOL NUMBER 120557 13.500 112.0 SPUD MUD 9.20 131.0 9.0 400 9.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 64.4 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1055.5 3114 2084.75 4118 1055.5 3114 ROP MWD030 FT/H 2.71 939.73 254.246 4040 1094.5 3114 GR MWD030 API 25.85 120.5 72.3332 4028 1055.5 3069 First Reading For Entire File.. ...... ..1055.5 Last Reading For Entire File......... ..3114 e File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type............... .LO Next File Name........ ...STSLIB.005 Physical EOF File Header Service name~........... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type... ............ .LO Previous File Name.... ...STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 5 e header data for each bit run in separate files. 4 .5000 START DEPTH 3060.5 3060.5 3060.5 3060.5 3060.5 3069.5 3114 . 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 6363.0 6363.0 6363.0 6363.0 6363.0 6370.5 6417.0 16-MAY-04 Insite 66.37 Memory 6417 . 0 3114.0 6417.0 39.5 109.4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 120558 134760 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 9.625 3104.0 LSND 9.10 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: e 46.0 8.5 530 7.0 e 3.000 2.210 3.900 2.000 64.0 89.1 64.0 64.0 # 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.....O Logging Direction......... ........Down Optical log depth units.......... .Feet Data Reference Point........ ......Undefined Frame Spacing... ...... ........... .60 .1IN Max frames per record....... ..... . Undefined Absent value......... ............ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3060.5 6417 4738.75 6714 3060.5 6417 ROP MWD040 FT/H 2.32 1524.69 281.718 6606 3114.5 6417 GR MWD040 API 18.07 120.97 68.8527 6603 3069.5 6370.5 RPX MWD040 OHMM 0.3 97 11. 0201 6606 3060.5 6363 RPS MWD040 OHMM 0.28 1800.36 12.2587 6606 3060.5 6363 RPM MWD040 OHMM 0.16 2000 16.3385 6606 3060.5 6363 RPD MWD040 OHMM 0.11 2000 20.6207 6606 3060.5 6363 FET MWD040 HOUR 0.11 40.38 1. 22973 6606 3060.5 6363 First Reading For Entire File......... .3060.5 Last Reading For Entire File... ... .....6417 File Trailer Service name...... ...... .STSLIB.005 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type......... ...... .LO Next File Name....... ...4IÞSLIB.006 Physical EOF File Header Service name.. .......... .STSLIB.006 Service Sub Level Name. . . Version Number...... .... .1.0.0 Date of Generation.. ... ..04/06/30 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 6 e header data for each bit run in separate files. 5 .5000 START DEPTH 6363.5 6363.5 6363.5 6363.5 6363.5 6371.0 6417.5 STOP DEPTH 8022.0 8022.0 8022.0 8022.0 8022.0 8015.0 8073.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 19-MAY-04 Insite 66.37 Memory 8074.0 6417.0 8074.0 87.2 108.5 TOOL NUMBER 184054 159436 6.750 6404.0 Oil Based 9.35 710.0 .0 40000 .0 .000 .000 .0 .0 MUD FILTRATE AT MTe MUD CAKE AT MT: .000 .000 eo .0 # 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.....O Logging Direction................ . Down Optical log depth units........ ...Feet Data Reference Point........ ..... . Undefined Frame Spacing.. .................. .60 .1IN Max frames per record. ........... .Undefined Absent value. ........ ...... ..... ..-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6363.5 8073.5 7218.5 3421 6363.5 8073.5 ROP MWD050 FT/H 3.11 470.16 176.374 3313 6417.5 8073.5 GR MWD050 API 18.3 100.45 67.2181 3289 6371 8015 RPX MWD050 OHMM 3.36 1149.73 27.6834 3318 6363.5 8022 RPS MWD050 OHMM 3.62 1573.53 22.1768 3318 6363.5 8022 RPM MWD050 OHMM 0.06 2000 38.7263 3318 6363.5 8022 RPD MWD050 OHMM 2.08 2000 59.1 3318 6363.5 8022 FET MWD050 HOUR 0.34 48.61 2.22426 3318 6363.5 8022 First Reading For Entire File....... ...6363.5 Last Reading For Entire File.... ...... .8073.5 File Trailer Service name..... ....... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type............... .LO Next File Name... ....... .STSLIB.007 Physical EOF Tape Trailer Service name... ........ .4IÞSTPE 4IÞ Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.. ....01 Next Tape Name......... ..UNKNOWN Comments. ..... .......... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin....... ........... .STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.... .... ........ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drtlting Services LIS Scan Utility e $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 30 15:53:38 2004 c ~3 I) / Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. .... .......... . UNKNOWN Continuation Number. .....01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. tr J. t>vl-ù~~ Scientific Technical Services Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 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 MPJ-26 500292320500 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 30-JUN-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 2 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 3 MW0003066223 T. MCGUIRE D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003066223 T. MCGUIRE D. GREEN MWD RUN 5 MW0003066223 C.A. DEMOSKI E. VAUGHN MWD RUN 6 MW0003066223 C.A. DEMOSKI E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0003066223 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) 28 13N 10E 2156 3267 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: e e 68.70 34.80 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.625 6.750 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 109.0 3104.0 6404.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE, AN OPEN-HOLE SIDETRACK, EXITS MPJ-26 PB2 AT 8330'MD. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 4 - 7 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 5 - 7 ALSO INCLUDED AT-BIT- INCLINATION (ABI). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 6/4/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 7 REPRESENT WELL MPJ-26 WITH API#: 50-029-23205-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8760'MD/3850'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ RESISTIVITY (EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP File Header Service name...... ...... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 e e and clipped curves¡ all bit runs merged. .5000 START DEPTH 69.5 112.0 3085.5 3085.5 3085.5 3085.5 3085.5 STOP DEPTH 8701.0 8760.0 8708.0 8708.0 8708.0 8708.0 8708.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 69.5 808.0 MWD 2 808.0 1094.0 MWD 3 1094.0 3114.0 MWD 4 3114 . 0 6417.0 MWD 5 6417.0 7280.0 MWD 6 7280.5 8330.0 MWD 7 8330.0 8760.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type. .................0 Data Specification Block Type... ..0 Logging Direction............. ....Down Optical log depth units..... ......Feet Data Reference Point........ ......Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value......... ............ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 8760 4414.75 17382 69.5 8760 ROP MWD FT/H 0.21 1524.69 222.972 17297 112 8760 GR MWD API 18.07 120.97 66.8522 17264 69.5 8701 RPX MWD OHMM 0.3 2000 27.2218 11246 3085.5 8708 RPS MWD OHMM 0.28 2000 29.3404 11246 3085.5 8708 RPM MWD OHMM 0.06 2000 53.1268 11246 3085.5 8708 RPD FET MWD MWD OHMM HOUR 0.1_ 0.11 2000 48.61 60.7849 11246 1.30356 11246 -3085.5 3085.5 8708 8708 First Reading For Entire File......... .69.5 Last Reading For Entire File.. .........8760 File Trailer Service name... ......... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type......... .......LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number...... '" ..1.0.0 Date of Generation.... ...04/06/30 Maximum Physical Record. .65535 File Type......... ..... ..LO Previous File Name.. ... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 69.5 112.0 STOP DEPTH 771. 0 808.0 # 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: 12-MAY-04 Insite 66.37 Memory 808.0 112.0 808.0 .3 7.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 120557 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 .0 # 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: e SPUD MUD 9.00 205.0 9.0 200 14.0 e .000 .000 .000 .000 .0 71.6 .0 .0 # 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 .1IN Max frames per record.... ....... ..Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT Rap MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 808 438.75 1478 69.5 808 ROP MWD010 FT/H 0.21 384.85 69.8718 1393 112 808 GR MWD010 API 26.42 106.82 59.7962 1404 69.5 771 First Reading For Entire File....... ...69.5 Last Reading For Entire File...... .... .808 File Trailer Service name..... ....... .STSLIB.002 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation... ... .04/06/30 Maximum Physical Record. .65535 File Type..... ... ....... .LO Next File Name....... ....STSLIB.003 Physical EOF File Header Service name. .... ....... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ......04/06/30 Maximum Physical Record..65535 File Type....... ........ .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 771.5 808.5 STOP DEPTH 1055.0 1094.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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): 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: $ # 12-MAY-04 Insite 66.37 Memory 1094.0 808.0 1094.0 12.3 24.9 TOOL NUMBER 120557 13.500 .0 SPUD MUD 9.00 205.0 9.0 200 14.0 .000 .000 .000 .000 .0 64.4 .0 .0 Data Format Specification Rtltrd Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction.. ............. ..Down Optical log depth units.......... .Feet Data Reference Point........ ..... . Undefined Frame Spacing... ...... ......... ...60 .1IN Max frames per record........ .... .Undefined Absent value................... ...-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e Name Service Order DEPT Rap MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 771.5 1094 932.75 646 771.5 1094 ROP MWD020 FT/H 14.11 622.51 95.1629 572 808.5 1094 GR MWD020 API 29.65 101.36 69.4162 568 771.5 1055 First Reading For Entire File......... .771.5 Last Reading For Entire File..... ..... .1094 File Trailer Service name...... ..... ..STSLIB.003 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation..... ..04/06/30 Maximum Physical Record. .65535 File Type............ ....LO Next File Name..... ..... .STSLIB.004 Physical EOF File Header Service name....... ..... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/06/30 Maximum Physical Record. .65535 File Type...... ......... .LO Previous File Name... ....STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR Rap $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 1055.5 1094.5 STOP DEPTH 3069.0 3114.0 # LOG HEADER DATA DATE LOGGED: 13-MAY-04 e SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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): 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.....O Logging Direction.... ............ . Down Optical log depth units.......... .Feet Data Reference Point.. .......... ..Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ...... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Name Service Unit DEPT FT ROP MWD030 FT/H Min 1055.5 2.71 Max 3114 939.73 Insite 66.37 Memory 3114.0 1094.0 3114.0 28.6 44.0 TOOL NUMBER 120557 13.500 .0 SPUD MUD 9.20 131.0 9.0 400 9.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 Mean 2084.75 254.246 Nsam 4118 4040 e .0 64.4 .0 .0 First Reading 1055.5 1094.5 Last Reading 3114 3114 GR MWD030 API 25.8. 120.5 72.3332 4028 -1055.5 3069 First Reading For Entire File......... .1055.5 Last Reading For Entire File.......... .3114 File Trailer Service name............ .STSLIB.004 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type........ ...... ..LO Next File Name... ..... ...STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number. ......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type......... ..... ..LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 3069.5 3085.5 3085.5 3085.5 3085.5 3085.5 3114 . 5 STOP DEPTH 6370.5 6363.0 6363.0 6363.0 6363.0 6363.0 6417.0 # 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: 16-MAY-04 Insite 66.37 Memory 6417.0 3114.0 6417.0 39.5 109.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 TOOL NUMBER 120558 134760 # BOREHOLE AND OPEN HOLE DRILLER'S CASING DATAe BIT SIZE (IN): CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction.... ....... ......Down Optical log depth units.......... .Feet Data Reference Point... .......... . Undefined Frame Spacing..................... 60 .1IN Max frames per record.......... ...Undefined Absent value. .... ...... .......... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 9.625 3104.0 LSND 9.10 46.0 8.5 530 7.0 3.000 2.210 3.900 2.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD040 FT/H MWD040 API MWD040 OHMM MWD040 OHMM MWD040 OHMM MWD040 OHMM MWD040 HOUR Mean 4743.25 281.718 68.8527 11. 0497 12.2644 15.8618 17.1925 0.941396 Min 3069.5 2.32 18.07 0.3 0.28 0.16 0.11 0.11 Max 6417 1524.69 120.97 97 1800.36 2000 2000 40.38 First Reading For Entire File......... .3069.5 Last Reading For Entire File......... ..6417 Nsam 6696 6606 6603 6556 6556 6556 6556 6556 e 64.0 89.1 64.0 64.0 First Reading 3069.5 3114.5 3069.5 3085.5 3085.5 3085.5 3085.5 3085.5 Last Reading 6417 6417 6370.5 6363 6363 6363 6363 6363 e File Trailer Service name... ......... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record..65535 File Type.... ........ ... .LO Next File Name.. ........ .STSLIB.006 Physical EOF File Header Service name........ .... .STSLIB.006 Service Sub Level Name. . . Version Number. ......... .1.0.0 Date of Generation. ......04/06/30 Maximum Physical Record. .65535 File Type... ............ .LO Previous File Name. .... ..STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 6 e header data for each bit run in separate files. 5 .5000 START DEPTH 6363.5 6363.5 6363.5 6363.5 6363.5 6371.0 6417.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 7280.0 7280.0 7280.0 7280.0 7280.0 7280.0 7280.0 19-MAY-04 Insite 66.37 Memory 7280.0 6417.0 7280.0 87.5 108.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 184054 159436 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 6.750 6404.0 Oil Based 9.35 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: e 71.0 .0 40000 .0 e .000 .000 .000 .000 .0 105.8 .0 .0 # 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.....O Logging Direction................ . Down Optical log depth units....... ....Feet Data Reference Point... .......... . Undefined Frame Spacing. ............... .....60 .1IN Max frames per record.. .......... . Undefined Absent value.......... ...... ... ...-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWDOSO OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6363.5 7280 6821.75 1834 6363.5 7280 ROP MWD050 FT/H 3.11 470.16 164.783 1726 6417.5 7280 GR MWD050 API 34.6 100.45 68.1466 1819 6371 7280 RPX MWD050 OHMM 3.36 1149.73 16.7734 1834 6363.5 7280 RPS MWDOSO OHMM 3.62 1573.53 19.3443 1834 6363.5 7280 RPM MWD050 OHMM 0.06 2000 49.3379 1834 6363.5 7280 RPD MWD050 OHMM 2.08 2000 86.6814 1834 6363.5 7280 FET MWD050 HOUR 0.36 48.61 3.61774 1834 6363.5 7280 First Reading For Entire File......... .6363.5 Last Reading For Entire File......... ..7280 File Trailer Service name........ .... .STSLIB.006 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type....... ........ .LO Next File Name......... .~SLIB.007 Physical EOF File Header Service name. ........... .STSLIB.007 Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation.. .... .04/06/30 Maximum Physical Record. .65535 File Type................ LO Previous File Name. ..... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM ROP GR RPS RPD FET RPX $ 7 e header data for each bit run in separate files. 6 .5000 START DEPTH 7280.5 7280.5 7280.5 7280.5 7280.5 7280.5 7280.5 STOP DEPTH 8329.5 8330.0 8329.5 8329.5 8329.5 8329.5 8329.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 20-MAY-04 Insite 66.37 Memory 8330.0 7280.0 8330.0 85.6 109.4 TOOL NUMBER 184054 159436 6.750 6404.0 oil Based 9.30 73.0 .0 44000 .0 .000 .0 .000 105.8 MUD FILTRATE AT MTe MUD CAKE AT MT: .000 .000 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units. . . . . . . . . . .Feet Data Reference Point.. ........... . Undefined Frame Spacing....... ............. .60 .1IN Max frames per record.... ........ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7280.5 8330 7805.25 2100 7280.5 8330 ROP MWD060 FT/H 1.26 1326.13 169.897 2100 7280.5 8330 GR MWD060 API 23.27 100.81 57.2852 2099 7280.5 8329.5 RPX MWD060 OHMM 4.54 2000 84.9809 2099 7280.5 8329.5 RPS MWD060 OHMM 4.81 2000 89.8483 2099 7280.5 8329.5 RPM MWD060 OHMM 4.79 2000 156.834 2099 7280.5 8329.5 RPD MWD060 OHMM 4.67 2000 149.356 2099 7280.5 8329.5 FET MWD060 HOUR 0.33 10.67 0.663487 2099 7280.5 8329.5 First Reading For Entire File....... ...7280.5 Last Reading For Entire File....... ....8330 File Trailer Service name... ......... .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type........... . . . . .LO Next File Name... ....... .STSLIB.008 Physical EOF File Header Service name....... .... .~SLIB.008 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.. ... ..04/06/30 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR FET ROP $ 8 e header data for each bit run in separate files. 7 .5000 START DEPTH 8330.0 8330.0 8330.0 8330.0 8330.0 8330.0 8330.5 STOP DEPTH 8708.0 8708.0 8708.0 8708.0 8701.0 8708.0 8760.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20-MAY-04 Insite 66.37 Memory 8760.0 8330.0 8760.0 84.3 88.7 TOOL NUMBER 184054 159436 6.750 6404.0 Oil Based 9.30 73.0 .0 44000 .0 .000 .000 .000 .000 .0 105.8 .0 .0 # e e TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type.....O Logging Direction........... ... ...Down Optical log depth units.......... .Feet Data Reference Point....... ... ....Undefined Frame Spacing..... .... ........... .60 .1IN Max frames per record...... .... ...Undefined Absent value..... ................ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8330 8760 8545 861 8330 8760 ROP MWD070 FT/H 2.43 390.8 204.183 860 8330.5 8760 GR MWD070 API 26.41 88.73 54.5921 743 8330 8701 RPX MWD070 OHMM 7.85 273.59 32.4398 757 8330 8708 RPS MWD070 OHMM 7.9 146.9 33.669 757 8330 8708 RPM MWD070 OHMM 8.65 2000 97.4813 757 8330 8708 RPD MWD070 OHMM 11.92 2000 129.989 757 8330 8708 FET MWD070 HOUR 0.23 5.06 0.60823 757 8330 8708 First Reading For Entire File......... .8330 Last Reading For Entire File..... ..... .8760 File Trailer Service name...... ..... ..STSLIB.008 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation...... .04/06/30 Maximum Physical Record. .65535 File Type....... ........ .LO Next File Name.......... .STSLIB.009 Physical EOF Tape Trailer Service name...... ..... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number.... ..01 Next Tape Name.. ........ . UNKNOWN Comments........... ......STS LIS Writing Library. Scientific Technical Services e e Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name..... ... ...UNKNOWN Comments.. .............. .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File