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198-115
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED JUN 2 7 2019 ELL COOR RECOMPLETION REPORT G' 1a. Well StatuW❑GasMPLETION ❑ Other ❑ Abandoned Q Suspended❑ 2Wc 25.115 20MC25,110 GINJ ❑ WINJ ❑ WAG[—] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑✓ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Com ., Susp., or Aband.: 5/11/2019 14. Permit to Drill Number/ Sundry: 198-115 72 p �— 21 9 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage AK, 99503 7. ded: 8/25/1998 15. API Number: 50-029-22894-00-00 4a. Location of Well (Governmental Section): Surface: 1,477' FNL, 1,886' FEL, SEC. 25, T13N, R1 OE, UM, AK Top of Productive Interval: 1,836' FNL, 669' FWL, SEC. 30, Tl 3N, R11 E, UM, AK Total Depth: 1,900' FNL, 993' FWL, SEC. 30, Tl 3N, R11 E, UM, AK 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569258.357 y-6016340.638 Zone -4 - TPI: x- 571816.714 y- 6016005.191 Zone -4 Total Depth: x- 572141.021 y- 6015945.044 Zone -4 8. Date TO Reached: 8/28/1998 9. Ref Elevations: KB: GL:23.2 BF:55.9 16. Well Name and Number: MILNE PT UNIT E-21 17. Field / Pool(s): MILNE POINT / SCHRADER BLUFF OIL 10. Plug Back Depth MD/TVD: 5,876'/ 4,708' 1ADL0028231 11. Total Depth MD/TVD: 5,990'/4,784' 18. Property Designation: • ADLW 55(? 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 11800' (Approx.) S. Directional or Inclination Survey: Yes (attached) No ❑✓ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD. N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, 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 23_ CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CASING FF. GRADE TOP BOTTOM TOP BOTTOM CEMENTING RECORD AMOUNT PULLED 13-3/8" 72 L-80 36' 150 36' 150' 16" 250 sx Arcticset I (Approx) 7" 26 L-80 Surface 38' Surface 38' 16" 5-1/2" 15.5 J-55 34' 5,961' 34' 4,765' 6-3/4" 615 sx Coldset III, 220 sx foamed, 175 sx'G' Performed top job w/ AOGCC approval 100sx Coldset III 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perrd): D TE V RIFTED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2-3/8"/ 4.7#/ J-55 5,421' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ✓ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 121,840# Proplok 16/30 Badger behind pipe on all 3 intervals 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 IAB 81Z311ct CONTINUED ON PAGE 2 Submit ORIGINIAL only ' RBDMSL1��4"'�� `` JUL 0 12019 v//� OTA=l1 AI A1I1� Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 RBDMS_6✓JUN 2 12019 Submit ORIGINIAL only V 1 H 1 L V r HLH0r AND GAS CONSERVATION COMMISSION JUN 12 2019 OR RECOMPLETION REPORT AN 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other El Abandoned Q Suspended❑ 20A c 25.105 20AAc 25.110 GINJ❑ WINJ❑ WAG[] No. of Completions: 16. 1b. Well Class: Development 0 Exploratory ❑ Service{] Stratigraphic Test❑ 2. Operator Name: Hilcorp Alaska, LLC Date Comp., Susp., or Aband.: 5/11/2019 14. Permit toI Number / Sundry: Dr' 198-115 7SIS _Z g M41 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage AK, 99503 7. Date Spudded: 8/25/1998 15. API Number: 50-029-22894-00-00 4a. Location of Well (Governmental Section): Surface: 1,477' FNL, 1,886' FEL, SEC. 25, T13N, UM, AK Top of Productive Interval: 1,836' FNL, 669' FWL, SEC. 30, TI 3N, UM, AK Total Depth: 1,900" FN 9 ' WL, SEC. 30, T13N, R11 E, UM, AK 8. Date TD Reached: 8/28/1998 16. Well Name and Number: MILNE PT UNIT E-21 9. Ref Elevations: KB: GL:23.2 BF:55.9 17. Field / Pool(s): MILNE POINT / SCHRADER BLUFF OIL 10. Plug Back Depth MD/TVD: 5,876'14,708' 18. Property Designation: ADL0028231 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569258.357 y- 6016340.638 Zone -4 TPI: x- 571816.714 y- 6016005.191 Zone -4 Total Depth: x- 572141.021 y- 6015945.044 Zone -4 11. Total Depth MD/TVD: 5,990' / 4,784' 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MDT VD: 1,800' (Approx.) 5. Directional or Inclination Survey: Yes LJ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, 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 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD CASING FT HOLE SIZE GRADE TOP BOTTOM TOP BOTTOM AMOUNT CEMENTING RECORD PULLED 13-3/8" 72 L-80 36' 150 36' 150' 16" 250 sx Arcticset I (Approx) 7" 26 L-80 Surface 38' Surface 38' 16" 5-1/2" 15.5 J-55 34' 5,961' 34' 4,765' 6-3/4" 615 sx Coldset III, 220 sx foamed, 175 sx'G' Performed top job w/ AOGCC approval 100sx Coldset III 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd):Abaz�2-3/8"/ D TE �V F2i.2WIE.D 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/-rVD) 4.7#/ J-55 5,421' N/A 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC, Was hydraulic fracturing used during completion? Yes ❑' No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 121,840# Proplok 16/30 Badger behind pipe Ion all 3 intervals 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: ICalculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 RBDMS_6✓JUN 2 12019 Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, Fromrro), 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Top Schrader Bluff'D' 5,515' 4,475' Top Schrader Bluff 'C' 5,575' 4,513' Attach separate pages to this form, if needed, and submit detailed test Schrader Bluff 'B' 5,620' 4,542' information, including reports, per 20 AAC 25.071. Formation at total depth: Schrader Bluff 31. List of Attachments: Welllbore schemtic, operations summry and photos. 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. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman -M%j Authorized Title: Operations Manager Contact Email: twellmaf CoMIICOrD.COM Authorized Contact Phone: 777-8449 Signature: Date: 6/6/2019 INSTRUCTIONS General: 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 10404 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. Item 1 a: 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 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Milne Point Unit SCHEMATIC Well: MPU E-21 Last Completed: 9/13/1998 PTD: 198-115 Oig OF 9ei 550/fiBev.: 23.7 (144m 27E) .. r.. To= 5,9W (ND)/TD=a,2Ea(M) PSTD= 22Y (ND)/ P81FD=222' (W Revised By: TDF 6/6/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-21 I -Rig 50-029-22894-00-00 198-115 7/3/2018 5/11/2019 Daily Operations: 7/3/2018 -Tuesday Spot sub base over E-21. Shim sub base and level. Set matting boards. Spot catwalk. Spot pipe shed, pump module, and gen module. Mobiles sattelite camp to E -pad. Hook up interconnects lines. Lay herculite for cuttings box, set rig mats and set cuttings box. Spot break in shack in environvac. Hook up steam and water lines. Check well for pressure - static. Set BPV. Scope derrick up 7/4/2018 - Wednesday Continue R/U on E-21. Bridle Down. Secure lines in Derrick. Plug in upper Derrick Section. Hang new Rig Tongs and adjust counter wts. Complete rig acceptance check list. Inspect saver sub and change dies on Top Drive. Accept rig @ 12:00. N/D and remover Tree inspect Tbg Hgr threads. N/U BOPE. Accept rig @ 12:00. N/D and remover Tree inspect Tbg Hgr threads. N/U DSA/Spacer spool/DSA and BOPE. Install turnbuckles and center stack. Install pitcher nipple riser adn air up boots. Connect accumulator lines and pressure up. N/U choke and kill lines. Obtain RKBs. Function test BOPE. Pull BPV, set TWC. M/U test joint. R/U testing equipment. Fill stack and flood lines. Shell test BOPE. Test BOPE 250/3,000psi on 3-1/2" and 2- 7/8" test joints. AOGCC Guy Cook witness test. One failure, superchoke will not hold pressure Troubleshoot. Accumulator drawdown: Starting pressure 3,100psi, final 1500, 200psi recharge in 11 seconds, full recharge 93 seconds. 6N2 with 2267psi average. Rebuild superchoke. Test choke manifold breaks and superchoke - good. Rig down testing tools. Blow down choke manifold and kill line. Pull TWC. 7/5/2018 - Thursday Screw into Tbg Hgr. BOLDS. Pull Hgr to Rig Floor. L/D Tbg Hgr and 1 jt tubjng. M/U BOT G -Plug Retrievsl tool and make drift run to top of 5-1/2" casing, setting down @ 32.5' Innovation RKB. L/D Retrieval tool. RIH and set Model G PKR in 7" casing. C/O Annulus Valve. PT PKR from above to 500psi. Well head hand Remove damged IA Valve. Inspect 2" NPT Port on tbg Head. Saw partial PKR element across IA Valve. Install New IA Valve. Attempt to PT IA valve pumping through same with test pump. Unable to achieve Pressure. Release and L/D G PKR. P/U 5-1/2" Retrievematic PKR. RIH and set inside 5-1/2" casing @ 43'. PT IA valve to 1,500psi and chart same. Good Test. Release and L/D PKR. RU to handlle 4-1/2" Wash Pipe. MU 4-3/4" Rotary Shoe, 3 Jts 4-1/2" Wash Pipe and tagged @ 78' MD. RU Kelly Stick ontop of 3rd jt of wash pipe. Work past obstruction from 78' to 79'. Wash/Ream down from 79' to 108' @ 3 bpm/150psi, 35 rpm/1,200 tq. Send sweep around prior to connection. No notable debris after sweep. Make connetion and Wash/Ream f/108' to 142'. See Rotary shoe pass over Jars (LIH) @ 135'. Continue to wash over fish from 135' to 157', est top of drive sub. 60 rpms 700-1,500 ft -lbs, 2.5bpm/550psi slowing pumps down to 1 bpm 500psi. Pump 5bbl high viscosity sweep at 155'. Continue milling from 157' to 158' and observe a loss of pump pressure down to 50psi and gain in hookload. Continue to mill down to 159'. Circulate hole clean 3 bpm 126psi, circulate 5 bbls high viscosity sweep around laying down one joint. Attempt to POOH on elevators, pulled tight at 138'. Pick up single with XO to saversub. Attempt to move down, unable to. Establish circulation at 3 bpm 92psi, with minimal returns. Set torque limiter to 5K and continue working pipe down. Obtain full returns and rotary. Stage rotary up to 40 rpms, Stage pumps up to 5bpm 104psi pump high viscosity sweep around. Able to ream above tight spot at 138'. Shut down pumps/rotary and attempt to pull above tight spot, unable to. M/U 2nd set of crossovers. L/D joint. Continue to ream out of the hole 3 bpm/50psi, 20rpms/800 ft -lbs to 64'. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-21 I -Rig 50-029-22894-00-00 198-115 7/3/2018 5/11/2019 Daily Operations: 7/6/2018 - Friday Continue to Pump/Rotate OOH with Wash pipe. L/D Wash Pipe/Rotary Shoe Assy. Break Down Kelly Joint. MU Short Catch over shot. Engage TOF @ 79'. See 100psi pump pressure increase and 2k Tq. POOH w/ fish. L/D Overshot with 1-3 1/2" DC'. W/0 lift subs to L/D remaining BHA. Service Rig. Stage Milling BHA on rig floor. L/D Remaining Fish. Recovered (2) 3-1/2" DC's, Bumper sub/Oil Jar and drive sub. PU Milling BHA with 4-3/4" Metal Muncher Mill. Mill on wash pipe from 159' to 162' w/80 rpm/1200 tq On/518 Tq Off, 5 bpm/120psi. attempt various parameter to increase mill ROP. Max Tq @ 1200 and falling off to 680 Tq with no footage. POOH to inspect Mill. Carbide on mill rounded off and smooth. L/D Metal Muncher and PU PIRAHNA Mill. Continue Milling from 162' to 166'w/5 bpm/45psi, 80 rpm/800-900 Tq, WOB 2-4K. At 166' observe loss in WOB, increase in ROP and torque falling to 550-600 ft -lbs. Continue to mill down to 168' with little resistance suspect mill exited casing. Pump 5 bbls high viscosity sweep with few cuttings. Pick up to 152', shut down pumps and rotary. Slack off and tag up at 168' x 2. Pick up to 147' and slack off with no rotary to 164', pick up and put 1/2 turn and continue to try. and locate TOF, in case of casing exit, unable to. Wash down to 168' with 250 gpm/44psi set down 3K. Small amount of pea gravel/cement/metal observed in possum belly. Discuss options. RIH to 168' and continue milling down to 182' attempt to locate TOF in the event milling freed fish and it fell to bottom. 5 bpm/50psi, 80 rpms/650 ft -lbs with little resistance, no indication of fish. Pick up to 147'. Clean out possum belly. Discuss Options. POOH to 35', 3K overpull. Attempt to slack off, unable to. M/U XO to saver sub, and TD. slack off. Ream out to 20'10 rpms/2bpm. L/D mill, edges rounded and center shows signs of coring. In gauge. Cut mule shoe on 2-3/8" 8rd joint. M/U crossovers. RIH to 151' with mule shoe to attempt and enter TOF. Wash down and tag at 182', pick up to 157' and rotate 1/4 turn. RIH and tag at 182'. Pick up to 157' and rotate 1/4 turn RIH to 191' inside TOF. POOH with 2-3/8" 8rd mule shoe. M/U 15' pup on mule shoe to attempt and work through fish. RIH, washing down from 166', tag at 182' pick up to 158 and put 1/4 turn. Tag at 163' (window) x 2. On 7th attempt work through too of fish down to 195' and tag up with 2K 5' from exitin fish . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-21 I -Rig 50-029-22894-00-00 198-115 7/3/2018 5/11/2019 Daily Operations: 7/7/2018 -Saturday POOH with 2-3/8" Mule shoe assy. L/D same. C/O Elevators, MU Stack washing tool, jet stack, function BOP Components, Jeat stack again. R/D washing tool. Close Blinds, pump through Choke/Kill lines t/ shakers. C/O Elevators back to YT's. M/U 5- 1/2" Test PKR as per BOT Rep. Attempt to RIH and encounter Drag @ 34'. L/D Test PKR and M/U Mill. RIH with Junk Mill to 162'. Stage pumps to 10 bpm/130psi. Attempt to clean out any debris. Rot/Reiprocate pipe 70 rpm/700 Tq. POOH from 162' and L/D Junk Mill. M/U 5-1/2" Test PKR as per BOT Rep. RIH and set PKR @ 150' MD. Close Annular and PT casing to 1000psi f/15 min on chart.(Test Good). Move PKR Down hole to 160'. PKR would not set. Move PKR up hole to 155'. PT Casing to 1,000psi. (Test Good) R/D test equipment. Blow down Choke Manifold. POOH and L/D test PKR. MU 2-3/8" Mule shoe assy on 2 7/8" Work string, work through and get inside 4-1/2" Wash pipe fish Dn to 195'. Stage pump to 4 bpm/30psi. Circulate and work pipe while waiting on AOGCC approval of forward plan. Cement Forward Plan approved by AOGCC. Continue to Circulate while W/O Cementers to arrive location. Cementers loading out 20 bbl Perm L Cement. Spot in and rig up Halliburton cement trucks. Rig up head pin on rig floor. P1SM. Pump balanced cement plug at 195'. Halliburton pump 3 bbls of fresh water, shut down and PT lines 1000/3000psi - good. Pump 2 bbls of 15.6 ppg Class G 'Perm C' cement at 1 bpm 74psi, displace with 1.25 bbls fresh water at 1.8 bpm/104psi, leaving 1 bbl in pipe. CIP 20:23. Break out cmnt line, DP on vac. Rig up to flush cementers. POOH to 150'. Establish circulation staging pumps up to 3 bpm/35psi. Observe. approximately 1+ bbls of cement back at surface. Pick up to 140' (cement retainer setting depth) and continue to circulate hole clean. POOH with cement stinger. Change out elevators, Pick up stack washing tool. Jet BOP stack with black water. PJSM. Pick up and make up cement retainer as per BOT. RIH to 140', space out for upcoming cement job. Set retainer as per BOT. 10 turns to right, overpull 30K, slack off 13K x 2. Rotate 10 turns to release stinger. Slack off and sting back in. POOH to test retainer/casing. Rig up and PT casing/retainer to 1000psi for 15 minutes - good. RIH with cement retainer. Verify space out: sting into retainer. Make up crossovers, side entry pump in sub and rig up to cement. Unsting and break circulation at 2bpm/50psi. Sting into retainer and perform injectivity test: 0.5 bpm/100psi, lbpm/120psi, 2 bpm/220psi. Unsting from retainer. Pump 1.5 bbls water and PT lines 1,200/2,600psi - good. Sting in and inject 10 bbls 15.6 ppg class G "Perm C" cement at 1.5 bpm/ICP 165psi FCP 190psi. Shut down pumps and unsting from retainer. Pump additional 11.3 bbls of cement 2.2 bpm/250psi slowing to 1 bpm/80psi. 6 bbls of good cement back at surface. CIP 04:10. Contact Pad Operator prior to squeezing cement, stage hands in cellar and. checking well houses/pad during injection. Break cement hoses - pipe dry. POOH slowly at 20 fpm, pipe dry. Suck out BOP and fill with black water. Break down crossovers, pump in subs and clean out. Rig down Cementers and flush lines. Pick up stack washing tool and wash BOPE stack. 7/8/2018 -Saturday Clean and clear rig floor of subs, XO's and handling equipment. Sort and palletize. Close blinds flush choke, kill line and choke manifold with fresh water. Flush out mud pumps. Blow down all lines. N/D BOPE. Pull riser. Remove choke and kill lines. Break bolts on stack and rack back on stand. N/D DSA's and spacer spool. SimOps: Clean pits, remove tongs install bridle pennets on blocks. Grease bridle sheaves. Bridle up. N/U tree and secure cellar. 7/9/2018 -Sunday No activity to report. 7/10/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-21 I -Rig 50-029-22894-00-00 198-115 7/3/2018 5/11/2019 Daily Operations. 5/8/2019 - Wednesday Remove bolt nuts below tubing head adapter. Water wash and super suck gravel above 3 cables found in survey scan. Cables found. Remove enough gravel for electrician access. 5/9/2019 -Thursday Three cables in area of E-21 investigated. The one behind the well is undetermined source but traced out and found over 5' out side of excavation area. The one in front of the well is undetermined source but also >5' outside of excavation area. The one running along side and in front of well was found terminated and dead. Approval to begin excavation. Pull tree from wellhead. Begin excavating 10'W x 181 x 14"D pit 5/10/2019 - Friday Complete excavation of 10'W x 201 x 14" D pit around E-21. Ready to install trench boxes and cut well off 4' below tundra level tomorrow. 5/11/2019 -Saturday Install Trench boxes in pit around E-21 with crane. Cut well casings off 4-5' below tundra level. 5.5" has cement to surface. 5.5" x 13-3/8" has cement to surface. Dress top of casings for cover plate. Inspect well abandonment by AOGCC state inspector - (Jeff Jones). Approved to weld cover plate. Weld cover plate with engraved well info. Take photos. Pull Trench boxs and backfill pit. Well abandonment complete. 5/12/2019 -Sunday No activity to report. 5/13/2019 - Monday No activity to report. 5/14/2019 -Tuesday No activity to report. Winston, Hugh E (CED) From: Tom Fouts <tfouts@hilcorp.com> Sent: Thursday, June 27, 2019 12:34 PM To: Winston, Hugh E (CED) Cc: Taylor Wellman; Michael Anderson Subject: MP E-21 10-407 Side 1 Revision PTD: 198-115 Attachments: MP E-21 AOGCC 10-407 SUBMITTAL 6-12-2019.pdf Hugh, Hi. I spoke with our GIS Tech and he believes the surface coordinates we submitted are correct. I have corrected the "from west line" entry to "993"'. 1 have added the range information to the surface and TPI as well. I have attached a PDF copy but will be sending over a hard copy for your records. Please feel free to contact me with any questions you might have. Regards, Tom Fouts I Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcoro.com Direct: (907) 777-8398 Mobile: (907) 351-5749 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. Winston, Hugh E (CED) From: Taylor Wellman <twellman@hilcorp.com> Sent: Friday, June 21, 2019 4:26 PM To: Winston, Hugh E (CED) Subject: RE: [EXTERNAL] MPU E-21 Final Well Completion Report Surface Coordinates Hugh, We'll review this and get you the answers you need sir. Thanks, Taylor Taylor Wellman Hilcorp Alaska, LLC — Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Winston, Hugh E (CED) [mailto:hugh.winston@alaska.gov] Sent: Friday, June 21, 2019 3:46 PM To: Taylor Wellman <twellman@hilcorp.com> Subject: [EXTERNAL] MPU E-21 Final Well Completion Report Surface Coordinates Hi Taylor, I am entering data from the final 10-407 for MPU E-21 and there are a few things that need to be addressed: The surface coordinates listed in box 4a are different than the surface coordinates on the original 10-407 filed in 1998. Can you take a look let me know which one is correct? In box 4b, it looks like there is a typo in the "from west line" number for total depth. It says'99#'. Can you verify that number for me? • The range information is missing from the surface and the TPI coordinates in box 4a. Thanks, Huev Winston Statistical Technician Alaska Oil and Gas Conservation Commission huah.winston@alaska.eov 907-793-1241 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, • Pc13 oF I//i w , s THEATE Alaska Oil and Gas r� � ���\ ce _ ���, ofA L ® SKA Conservation Commission -;E2 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .. T�'. Main: 907.279.1433 of ALASY+ Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED MAY 3 0 2018 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-21 Permit to Drill Number '' 115 Sundry Number: 318-218 Dear Mr. York: 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, Hollis S. French Chair DATED this-14' day of May, 2018. • • RECEIVED MAY 232018 STATE OF ALASKA 07-5 5/3 a l) Fs} ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AC 20 AAC 25.280 1.Type of Request: Abandon Q ' Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q. 198-115 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 1:] Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22894-00-00 • 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 0 MILNE PT UNIT E-21 9.Property Designation(Lease Number): 10.Field/Pool(s): 11174, UU25.S L 0 ADL0028231 S 2.1MILNE 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): 5,990° - 4,784' ' 222' 222' 646 N/A 222 Cement Casing Length Size MD TVD Burst Collapse Conductor 150' 13-3/8" 150' 150' 1,661 psi 5,380 psi Surface 38' 7" 38' 38' 7,240 psi 5,410 psi Production 5,923' 5-1/2" 5,961' 4,765' 4,810 psi 4,040 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): I See Schematic See Schematic 2-3/8" 4.7#/J-55/8RD EUE 65' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary LJ Wellbore schematic El 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: 6/5/2018 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG El Commission Representative: GINJ ❑ Op Shutdown 0 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: Taylor Wellman 7Y.) Authorized Title: Operations Manager Contact Email: tvyeUman( hIICOfD.com (� Contact Phone: 777-8449 Authorized Signatur . /13^�- A b04k Date:5 123)Zq 13 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SundryNumber 3i/r -ZI ' Plug Integrity BOP Test V Mechanical Integrity Test ❑ Location Clearance 0 Other: I 300C)/05L LCof-,r� �S t- If- Ph 0"1-b AC ALJ C '-_i& cL& 00 i kid,/e-d,C ,Pic,_,4e . Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: /0--LID 7- Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: j bo 18 ORIGINAL „e4, 214v s;i7, ubmit Form and � Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • P&A Well: MPE-21 PTD: 198-115 API: 50-029-22894-00 Ililcorp Alaska,LL Well Name: MPE-21 API Number: 50-029-22894-00 Current Status: SI—ESP (Failed P&A) Pad: Milne Point Estimated Start Date: June 5, 2018 Rig: Innovation Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 _ First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Well EZ Inputs Required: Yes Current Bottom Hole Pressure: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) MPSP: 646 psi (Based on offset E-32 on 11/16/14 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Note: Current Surface pressure is 0 psi. Brief Well Summary: 1�-,--C1 �s<1uz�� crn.J -14-‘34) .441,-yt.As ' , n(0.J /47`f°k In November 2015 the well was attempted to be converted to an injection well. During the RWO,the ESP became stuck in the well and tubing was recovered down to 547 feet from surface. The ESP electrical cable and a control line stripped off of the tubing that was removed and was tagged prior to the cement job at 146'. In January of 2016 an attempt was made to P&A this well by bull heading 50 bbls of mud push with LCM material and 235 bbls of class "G" cement down the well. The P&A was unsuccessful in that the cement exited • the well bore shallow through a casing leak at ±165' and and migrated over and up the conductor by surface casing annulus on the MPE-17 injection well located six slots away on the same well pad. E-21 was cleaned out to 127' and pressure tested with a test packer. The well did not pass a pressure test ° down the tubing (100 psi bleed off in 5 minutes). The 5-1/2" casing passed a pressure test of 1,600 psi for 30 minutes. A second attempt to P&A the well was attempted in 2017. During these rig operations, the washover BHA became stuck and twisted off of a pin in the workstring at 87'. Multiple days and attempts to recover the fish were unsuccessful. The well began to suffer fluid losses and Doyon 14 was moved off to develop a better plan for the P&A. Notes Regarding Wellbore Condition 5-1/2" casing damage at±165' md. 87'-207' Washover BHA fish stuck in hole 222'—547' ESP cable, heat trace, &Cement 547'—Below Tbg, ESP cable, heat trace, ESP &Cement Injectivity is 0.5bpm at 1900psi (confirmed on 05/19/18) RWO Objective: Remove the fish from the wellbore and complete the P&A of the well. v Pre-Workover Prep Procedure: 1. Clear and level pad area in front of wellhouse. Spot rig mats and containment. • P&A Well: MPE-21 PTD: 198-115 API: 50-029-22894-00 I3ilearp Alaska,LL 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid and 500 bbl returns tank. Pressure test lines to 3,000 psi. 4. Forward circulate at least one wellbore volume with 8.5 ppg seawater down the tubing (thru kill string), taking returns up the annulus to the 500 bbl returns tank. 5. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 6. RD Little Red Services Pump and reverse out skid. Workover Procedure: 7. MIRU Innovation 8. Check for pressure and if needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/±8.5ppg seawater. 9. Set BPV. ND tree/ NU BOPE. Set TWC. 10. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. /� a. Perform Test per Innovation BOPE Test Procedure. 1A0X 117 b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 4-1/2" and 2-7/8" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. Contingency: (If the tubing hanger won't pressure test due to either a control line 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.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 12. Bleed anypressure off casingto 500 bbl returns tank. Pull TWC. Kill well w ±8.5 seawater as needed. / ppg 13. MU 2-3/8" landing joint or spear and BOLDS. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. • • P&A Well: MPE-21 PTD: 198-115 API: 50-029-22894-00 Ilileorp Alaska,LL 14. Pull 1 joint kill string and lay down same. Note: From this point forward,there are multiple options listed for recovery. If one option is successful, it may jump directly to"Fish Removed From Wellbore"steps beginning at Step#in the procedure. () Washover& Cut Washpipe From Fish ,* gti,4 15. PU 4-3/4"x3-13/16" washover shoe BHA and TIH. 16. Washover fish from 85' to -164' md. Mill a minimum of 1' once positive indication of milling on the fish is achieved. a. During the 2017 attempt, reports indicate that 3"-4" of the wash drive sub was milled. This was not enough to separate the upper fish from the wash pipe. 17. PU Jarring BHA and latch into the top of fish at 85'. Recover the upper portion of the fish. Backoff Recovery 18. PU 3-1/2" overshot,TIH and overshot fish at 87'. 19. Overpull on fish and set slips. 20. RU EL. RIH with a stringshot. Place stringshot across one of the 3-1/2" drill collared connections and shoot. a. Target depths 143' and or 113' md. b. EL was able to reach 135' and on 2/26/17 during the last P&A attempt. c. Contingency(If unable to enter into fish) i. PU dress off mill BHA and dress the top of fish. 21. POOH and RD EL. 22. Attempt backoff of the BHA. Recover pipe from backoff point. '1)) Severing Tool/Cut Fish 23. Contingency(if backoff did not recover the drill collars) a. TIH and thread back into the workstring. Overpull on fish and set slips. b. RIH w/ 1-3/8" severing tool. Use CCL to confirm depth and fire severing tool. i. Target depth to reach is 143' and (the collared connection between the drill collar and the jars). ii. EL was able to reach 135' and on 2/26/17 during the last P&A attempt. c. POOH and RD EL. 24. PU and confirm free. Recover and lay down upper portion of fish. 25. Contingency(if upper portion of fish is not free) a. PU Fishing BHA,TIH To latch fish and jar free. Lt) Milling Remainder of Fish 26. MU 4-3/4" milling BHA and TIH. 27. Tag top of fish, PU and obtain milling parameters. 28. Mill through fish down to ±220' md. • . P&A Well: MPE-21 PTD: 198-115 API: 50-029-22894-00 Hilcorn Alaska,LL a. Minimum target depth to reach is±190' md. b. The end of the fish is at 207' md.The deepest depth achieved during previous milling runs to that was 222' md. c. Note that losses may increase as further milling/circulating warm fluids are pumped and the permafrost is thawed around the wellbore. 29. Circulate 2 bottoms up or until satisfied that all recoverable debris is recovered. Fish Removed From Wellbore 30. MU 5-1/2" casing test packer and TIH. 31. Set test packer at 150' and and test backside to 1000psi. a. Move uphole testing to find deepest competent casing depth. b. During the 2016 P&A attempt a 5-1/2"test packer was run and the casing from 129' and up passed an MIT to 1600psi on 01/28/16. 32. MU 5-1/2" cement retainer and TIH to set at±200' md. Confirm injectivity down the workstring and to the reservoir. 2,00 33. Begin mixing cement. Once up to weight pump±20 bbls of 15.6ppg Class G cement down the workstring. �� � With 1bbl of cement left in the tubing, PU out of the retainer and allow last bbl of cement to lay in on top vtii of retainer. a. Estimated TOC at 158' md. 34. PU to 150' and and circulate until clean returns are observed. c 35. MU 5-1/2" cement retainer and TIH to set at±140' md. Confirm injectivity down the workstring and to the casing leak point. re, !", 36. Begin mixing cement. Once up to weight pump±15bbls of AS1 cement down the workstring. After 3bbls of cement have been pumped through the retainer, PU out of the retainer and continue pumping 5-10bbls of cement on top of the retainer to get clean cement to surface. 37. TOOH while pulling wet. Place each joint in the mousehole and circ clean. Drop foam ball to clean each joint of drillpipe of cement. 38. Set TWC and ND BOPE and NU adapter flange and dryhole tree. Test to 5,000 psi. 39. Pull TWC. RDMO. Post Workover Procedure: y' ���, 40. Notify AOGCC inspectors 24 hrs prior to cutoff of wellhead and welding marker plate.41. Excavate cellar, cut off wellhead and casing 3' below natural GL. a. If cement fell back, bring cement top to level of cut. 42. Photograph casing stub before setting marker plate. 43. Set marker plate, collect GPS coordinates. 44. Photograph casing stub after setting marker plate. af4. t 45. Backfill cellar, close out location. • S P&A Well: MPE-21 PTD: 198-115 API: 50-029-22894-00 Hikora Alaska,Lb Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 0 . Milne Point Unit itirWell: MPU E-21 SCHEMATIC Last Completed: 9/13/1998 Hikorp.Alaska,LEA. PTD: 198 115 Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) RKBTHF:33.6'(Doyon 14) t t,4 �- 40 141 S`, g a „y CASING DETAIL ,, Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" 4 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 0.148 ' 1 7" Prod X-Over 26/L-80/BTC-MOD 6.151 Surface 38' 0.0383 kt ,,A1 7"x5.5" ;ft 5.5" Production 15.5/J-55/BTC-MOD 4.825 38' 5,961' 0.0238 2 @l 3g TUBING DETAIL y, 4.! p V P.1 .)x, 22-3/8" Kill String 4.7/J-55/EUE 8rd 1.901 Surface 65' 0.00387 F g' 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.901 547' 5,421' 0.00387 V ISI JEWELRY DETAIL a TWSin `''' No Depth Item OD ID off pin 1 34' Tubing hanger 6.276" 1.995" 2 65' 2-3/8"Tubing EUE(1 jt) 2.375" 1.995" Collar r',4 3 87 3-1/2"Drill Collar,2-3/8"IF(Twisted pin on top) 3.500" 1.500" "" rrilledto 4 116' 3-1/2"Drill Collar,2-3/8"IF 3.500" 1.500" li` ,;' 31//OD 5 145' Bumper Sub and Oil Jar 3.750" 1.000" 6 166' 4-1/2"Washpipe(1 jt) 4.500" 3.812" 3 y +* 7 203' 4-3/4"Rotary Shoe 4.750" 3.562" W. 4;' i e 4 4 g . v L 'k" Obstruction inside,, �4 fish@145' Damaged easing / 165 Jut ikffll on backside 6 165 7 Shoe Depth 207 ND Milling 222'MD 222'MD .4 Unkna+n x , Fill a Cement or Void ESP CableHeat Trace k .! Tubing Cut t x ' 547 5.5"155#i. • TD=5,990'(MD) TD=4,784111/D) PBTD=222'(MD)/PBTD=222'(ND) Revised By:TTW 05/14/18 H . • Milne Point Unit Well: MPU E-21 PROPOSED SCHEMATIC Last Last Completed: flacon)AIa ka.1.1A: PTD: 198-115 Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) RKB—THF:33.6'(Do on 14) [ • ;a CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" k . 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 0.148 • § 7" Prod X-Over 26/L-80/BTC-MOD 6.151 Surface _ 38' 0.0383 i'S 5.5" Production 15.5/J-55/BTC-MOD 4.825 38' 5,961' 0.0238 P A, JEWELRY DETAIL d 4i1No Depth Item OD ID x+ . 1 ±150' 5-1/2"Cement Retainer t. 2 ±190' 5-1/2"Cement Retainer ' 3 222' Top of fish(ESP cable/heat trace/cement) 4 • 5 3 6 7 ';, ! ' a i 14, 1 i Damaged Casing 165 • 2 3 Deepest Millin 222 MD *Unkna.n* FII cc Cement or Void ESP Cabl4.e T. ` s „Au< Heat Trace A.,7 �1. 0, Tubing Cut 5.5"155# � 547 ar y TD=5,990'(MD)/TD=4,784'(TVD) PBTD=222'(MD)/PBTD=222'(TVD) Revised By:TTW 05/18/18 : a : • • • co E ra co cC >. 13 c) g -5" 8 C .:-.1., --6 . -a C O 0 0 0 (...) , a) Lo 2 g t-- -5 In o Co C .... ..c in 0 Co -5 Co c Lei -5 A cv A A (1) o .,-- I- () a- — }-- 0 2 2 co Lc) 2 Co '1'5 i i c:Jtf:tx :17 x co c - = tri 5 A c ,-- < in!:0>< I k 11 , ' imu.... ] ti . .. .... . 0 re1: 1) ,..,..., ;1 (4) Ili 41.-..r) . 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Ii cr ry1 kg roll SI. - . alitt �_ ilia TI 1 . a I I.11 AA Li 1 + - a • r , , n, STATE OF ALASKA '' A KA OIL AND GAS CONSERVATION COP SION �� REPORT OF SUNDRY WELL OPERATIONS MAR 4 2017 1.Operations *91 Ab don U Plug Perforations U Fracture Stimulate U Pull Tubing U si �^'�f Performed: `� Suspend El Perforate ,,I ��shutdown U ❑ Other Stimulate ❑ Alter Casing❑ Change Apprv'd Prgrm Sndry 316-0380 Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development❑ Exploratory❑ 198-115 3.Address: Stratigraphic❑ Service❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 , `L. Ml g �� 50-029-22894-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028231 MILNE PT UNIT SB E-21 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 5,990 feet Plugs measured N/A feet true vertical 4,784 feet Junk measured 222(Cement) feet Effective Depth measured 222 feet Packer measured true vertical 222 feet N/A feet true vertical N/A feet Casing Length Size MD TVD Burst ConductorCollapse Surface 150' 13-3/8" 150' 150' 1,661psi 5,380psi 38' 7" 38' 38240 7, si Production 5,923' 5-1/2" 5,961' 4,765' p 4,410psi 4,810psi ,040psi Perforation depth Measured depth See Attached Schematic t �� True Vertical depth SCANNED APR jk `�1, P See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/J-55/8RD EUE 65' 65' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/Ac�� N/A,1 12.Stimulation or cement squeeze summary: N/A fjv k Intervals treated(measured): N/A cryO X to -LN 4/,,,,,i- Treatment descriptions including volumes used and final pressure: N/A it Nr 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: o 0 0 0 Subsequent to operation: o 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development❑ Elervice ❑ Stratigraphic Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ Gas ❑ WDSPL❑ WINJ ❑ WAG ❑ GINJ❑ S1 - Abandon 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: 316-201 Contact Taylor Wellman Email twellmanCa�hilcorp.com"NJ Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 3/10/2017 / p REFJa-qt3 (lz) try k ;.i L I. Eus Form 10-404 Revised 5/2015 Z��;r1/;.1 Submit Original Only H . • Mime MPU Point UnitE-21 W SCHEMATIC Last Completed: 9/13/1998 PTD: 198-115 Hileorp Alaska,LLC Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) RKB-THF:33.6'(Dolton 14) to I f 1 CASING DETAIL s ' Size Type Wt/Grade/Conn Drift ID Top Btm BPF i t F IRS k M 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 0.148 , 7" Prod X-Over 26/L-80/BTC-MOD 6.151 Surface 38' 0.0383 N50 11 q 7"x5.5' 5.5" Production 15.5/J-55/BTC-MOD 4.825 38' 5,961' 0.0238 2 @3g r b TUBING DETAIL 1 �* 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.901 547' 5,421' 0.00387 41 . }.. JEWELRY DETAIL No Depth Item OD ID S 1 34' Tubing hanger 6.276" 1.995" !.+ k Twisted off pin 2 65' 2-3/8"Tubing EUE(1 it) 2.375" 1.995" 87' r 3 87' 3-1/2"Drill Collar,2-3/8"IF(Twisted pin on top) 3.500" 1.500" rk t: .'•, If 4 116' 3-1/2"Drill Collar,2-3/8"IF 3.500" 1.500" # Collar 5 145' Bumper Sub and Oil Jar 3.750" 1.000" °'* milled to V, 6 166' 4-1/2"Wash pipe(1 jt) 4.500" 3.812" z e 3-1/4"OD it4.750" 3.562" 7 203' 4-3/4"Rotary Shoe 0 1 IA E 4 ° )r' a i 13-3/8" 5:z Fill inside fish 145 yyr f Damaged Casing ip Yt. a; 3� `t,'; 165 at i Fill on backside 4� i 6 150 k .r :gfiS D. 7 Shoe Depth 207 ND — Deepest Nilling 22 zzz ND *LkIknown* Fill or Cement or Void ESP Cable Heat Trace Tubing Cut 547 5.5"15.5# TD=5,990'(MD)/TD=4,784'(TVD) PBTD=222'(MD)/PBTD=222'(TVD) Revised By:STP 02/27/17 • Hilcorp Alaska, LLC HiksorpAlaska,IAA: Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-21 Doyon 14 50-029-22894-00-00 198-115 2/15/2017 Future -7 , sal' 3 '` F F _ /15/1 Wednesdt �d� ��i 1 'I���I) '. v y � �� a � � - ��� ..I � Move rig f/F-Pad to E-Pad.Remove Rear Boosters.Position Rig and spot over E-21.Skid Rig floor into drilling position.RU hard lines.take on 200 bbls of 8.5 source water to pits.RU Beaver Slide and conveyor.Sundry meeting with Rig Crew.RU and circ.out 3 bbls of diesel freeze protect.Pumped total of 9.5 bbls.2 bpm,120 psi.ND tree and set back in cellar.Wellhead Rep Install TWC,Function LDS.Inspect 2 7/8"EUE threads in top of hanger. 2/16/17 Thursday 'i Ii' ij l = X14 = NU BOPE.RU test equipment.PU 3 1/2"Test Joint.Test BOPE using 3 1/2"Test Joint per PTD and Doyon 14 procedure. NOTE:AOGCC Rep.Lou Grimaldi waived witness of test at 21:00 hrs on 2/15/17(Verbal).R/D BOPE test equipment,M/U dry rod,pull TWC,M/U landing joint to TBG hanger,Pull TBG hanger to rig floor(4lklbs),L/D TBG hanger,R/U GBR CSG services,L/D 2-3/8"kill string f/95'md to surface,M/U 4.75"milling BHA as per Co Rep,RIH and tag TOC @ 146'md.Circulate and shear mud system until milling properties are attained.Set down 5Klbs increments of weight on the TOC,after 20klbs obstruction began moving downhole to 149'md before stacking out.Set 25klbs on obstruction w/no movement seen.P/U milling BHA#1 and spud into obstruction in 5K increments up to 15klbs(No movement seen,hard tags each time),P/U off obstruction and gain milling parameters:60RPM=2.8k ft-lbs torque,3BPM=90psi,PUW=46klbs,SOW=45klbs.Set down 5K WOB and begin milling.Cement quickly seen on shakers,along w/metal shavings and rubber pieces.Initially milling quickly,with intermitten torque f/149'md to"166'md.Continue to mill ahead w/ Baker 4.75"milling BHA#1 f/166'md t/"180'md. Work parameters to find the optimum milling rates.Milling slowly f/174'md,copper,rubber,cement, and steel seen across the shakers. V14/17'-Fred o INl '"i(i �i 14�. i 0 P'l-= ( ' ji P l ( - ...i ..1 Continue milling on ESP cable,control line,etc.w/1-3 bpm,40-140 psi,60-100 rpm to±185'.Lost returns and gained pump pressure.Stop pumps&PU and work pipe.Lost±5'of hole.Stop pumps.Work&rotate pipe in attempt to shake loose cuttings(suspect packed off around mill/BHA).Bring pumps on at 1 bpm,140 psi.Minimal returns.Prep to POH.POH LD 4 joints of 3 1/2"DC's.Pull remainder to surface.Bumper sub cylinder packed off w/cuttings. Clean cuttings.Inspect mill(good).RIH to 185'md.Milling f/185'to 191'md w/5 blade junk mill.Work 10-14klbs WOB w/115GPM=90psi,80RPM=3.0k ft-lbs.MW=8.3ppg in and out w/52 funnel visc.POOH f/190'md to surface w/5 bladed junk mill.Mill showing visible wear.M/U BHA#3, 4.75"drag tooth shoe on 4-1/2"washpipe extension,RIH f/surface to 41'md,unable to RIH past 7"x5.5"casing crossover.Work weight onto obstruction w/no success,lightly rotate shoe on obstruction w/no success,pump on obstruction at 6 BPM w/no success.POOH and drain stack.Stack contained coating of metal shavings throughout.POOH,L/D drag tooth washpipe BHA#3 and M/U worn 5 bladed junk mill BHA#4,RIH to 41'md tagging up on obstruction.Set down weight in 5Klbs increments up to 20klbs,no movement seen.Lightly rotate on obstruction w/10RPM and no pumps,no movement seen.Turn pumps up to 6BPM w/30RPM and work down in 1KIbs increments,obstruction moving.Work obstruction down hole until only light resistance seen. POOH w/worn 5 bladed junk mill BHA#4.M/U drag tooth washpipe BHA#5 and RIH to 160'md.Set down on obstruction in lklbs increments w/no movement.P/U and gain milling parameters.PUW=46klbs,SOW=46klbs,Free TQ=3.4k ft-lbs,1BPM=40psi,MW=8.3ppg in and out w/52 funnel visc. Continue to wash over obstruction f/160'md to 165'md before drag tooth shoe stopped milling,w/2-3Klbs WOB, 30RPM=3.6k ft-lbs TQ,1BPM=40psi. POOH f/160'md w/slight drag noted.@ 51'md 4klbs overpull noted followed by a 2klbs drop in hookload.Pull BHA to surface,no metal in washpipe,drag tooth shoe heavily worn.L/D drag tooth washpipe BHA#5.M/U 6 bladed metal muncher junk mill BHA#6.RIH w/6 bladed metal muncher junk mill BHA #6 f/21'md to 163'md and tag obstruction.P/U and gain milling parameters.PUW=47klbs,SOW=47klbs,Free TQ=3.3k ft-lbs,7BPM=290psi.Work down hole w/1-2klbs WOB f/163'md to 190'md.Continue to mill w/6 bladed metal muncher junk mill BHA#6 f/190'md.Having to work milling parameters to make forward progress. • • Hilcorp Alaska, LLC Hilcorp Alaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-21 Doyon 14 50-029-22894-00-00 198-115 2/15/2017 Future /1g .i relay 4"5 Pump 20 bbls water followed by 20 bbls H.V.sweep while reaming and backreaming from 100'to±190'w/120-140 rpm,6-7 bpm attempting to break up compressed cuttings on bottom&move up hole.Continue to mill on ESP cable,control line,Cannon clamps,etc.Working pipe changing parameters.Very Little progress f/190'to±192'.POH f/190'to 80'.Rotate,reciprocate and pump through 7"x 5 1/2"XO at 38'attempting to dislodge accumulated cuttings.LD 6 bladed metal muncher mill BHA#6.Drain stack and function BOPE(Top,bottom&blind rams).PU burn shoe washover BHA#7,(4-3/4" burn shoe,1 joint of 4 1/2"washpipe, 1 WP extension).RIH w/burn shoe washover BHA#7.Stack weight at 165'in.Hit down several times w/no success.Rotate down±10'using tubing tongs and worked through.Screw in Top drive.PU and observe 5-10'over pull.Rotate back down w/50 rpm.No issues.Continue to RIH and tag fish at 186'.Milling on fish f/186'to 193.5'w/burn shoe washover BHA#7 w/80 rpm=3.9k ft-lbs TO,2-3k WOB,4 bpm, 230 psi,8.2ppg mud in and out w/52 funnel visc.Continue to mill w/burn shoe washover BHA#7 f/193.5'md to 196'md.WOB=5k,4bpm=300psi, (pump pressure began to rise before settling at 1120psi @ 4BPM).Reduce pump rate to 42GPM=300psi.Increase RPM to 120=3.6k ft-lbs TO.MW in and out=8.2ppg w/53 funnel visc.Decide to POOH when milling progress stopped.Blow down top drive,change out elevators in prep to POOH.POOH f/ 196'md to surface.BHA showing 4klbs drag when pulled up hole.See 10klbs over pull @ 165'md,work through obstruction in lklbs overpull increments up to 15klbs.Continue to see 3-4klbs drag while POOH.See 10klbs overpull @ 5.5"x 7"crossover(40'md).Pull into obstruction w/lklbs overpulls up to 18klbs(not able to pull through).M/U top drive and rotate BHA through obstruction w/15klbs overpull.L/D burn shoe washover BHA#7.Burn shoe and wash pipe packed solid w/3'of metal.Clean and clear rig floor.M/U burn shoe washover BHA#8 w/new burn shoe,and RIH f/surface to 165'md.Tag up on obstruction @ 165'md,M/U top drive and work thorugh obstruction several times.Continue to RIH to 194'md,tag up and begin milling w/burn shoe washover BHA#7. �I- Uay(i (iIi 0i (�4i� �) ' . �� i't ..��5 -I ) Continue milling/washover with 4 3/4"shoe and washover assembly f/194'to 201'w/80-140 rpm,2-12k WOB&1/2-5 bpm.POH f/201'w/no overpull,no issues.LD 4-3 1/2"DC's and pull remainder of BHA to surface.Break shoe and recovered±3'of compressed junk.Inspect shoe.Good condition.MU&RIH w/same shoe.Stacked weight at 165'but worked through area with little effort.Continue to RIH and tag up at 201'.Milling w/ washover assembly f/200'to 202'and w/80 rpm,2 1/2 bpm,160 psi.WOB 2-3k.Increase RPM to 120=3.8k ft-lbs TO,,8.2ppf MW in and out w/54 funnel visc.Pump pressure increase from 160psi tO 700psi indicating debris in washpipe.Burn shoe not responding to varying milling parameters,decide to POOH and check for debris.B/D top drive and POOH w/burn shoe washpipe BHA f/202'md to surface.3'of metal debris found inside washpipe.C/O burn shoe from BHA and replace w/new shoe.RIH w/burn shoe washpipe BHA f/surface to 165'md.Tag up on obstruction in hole.Work BHA down w/lklbs increments up to 10klbs,turn on pumps to 3BPM and attempt to pump through obstruciton w/no success.Attempt to rotate lightly through the obstruciton w/10RPM and 3BPM w/no luck.Gain milling parameters and mill down on obstruction f/165'md to 169'md.Not making milling progress. Pull up to 155'md and work down to 165'md without obstruction,carry on to 202'md.Tag bottom @ 202'md,P/U and gain milling parameters.28GPM, 120psi,80RPM,3.7kft-lbs TQ,PUW=46klbs,SOW=146klbs,MW=8.2ppg in and out w/53 funnel visc.Mill on bottom f/202'md to 203'md.Continue to mill on bottom w/burn show washpipe BHA.Pump pressure increase from 120psi to 500psi,indicating debris in washpipe.Work milling parameters to attempt to get mill to bite.No success.Decision made to POOH.POOH w/burn shoe washpipe BHA f/203'md to 40'md(No obstructions @ 165'md).5klbs overpull seen @ 40'md(5.5"x 7"crossover).Attempt to pull through in lklbs increments up to 15klbs w/no success.Work down out of x-over,rotate string @ 10RPM and attempt to pull through in lklbs increments(no success).Turn on pumps and try to rotate and wash through x-over.Work through after several attempts.M/U 4.75"string mill BHA and RIH to x-over @ 40'md.No sign of obstruction on way down.Stop at 55'md and POOH,2-3klbs overpull seen at x-over.Bring pumps up to 6bpm and rotate @ 20RPM through obstruciton.No TQ noted when pulling through.Turn off pumps and drift up and down through x-over with no overpulls.POOH and L/D string mill BHA.M/U 4-3/4"burn shoe washover BHA and RIH f/surface to 203'md w/no obstructions.Gain milling parameters and begin milling f/203'md. • • Hilcorp Alaska, LLC Hi'carp Alaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-21 Doyon 14 50-029-22894-00-00 198-115 2/15/2017 Future 2/20/i7-:' qday'4 _ e 4 Milling/washing over f/203'to 209'.80-120 rpm,2-3k WOB 1/2-3 bpm.At 207',Observed increase in pump pressure(1/2 bpm,1800 psi)indicating flow path blocked by junk in ID of shoe.ROP stalled.Increase weight in 1-2k increments to 12-13k WOB.Made approximately 1 1/2-2'and progress stalled. POH w/no issues.LD shoe(recovered±3'of compressed junk.PU new shoe&RIH.Tagged up at 165'but able to work through w/little effort.Continue RIH and tag up at 209'.Milling/washing over ESP junk f/209'w/60 rpm,1-2 bpm,2-4k WOB f/209'.After 2 hours of running light wt.&RPM,increase WOB to 7-10&RPM to 100.Broke through obstruction and milled /washed over for 5' to 214'with little effort.No signs of cement.Progress stopped at 214'.Continue milling/washing over w/4-5k WOB,90 rpm.Blow down top drive,POOH f/214'md to surface.No indication of obstructions on the way out of hole.4'of debris recovered from mill shoe barrel.M/U new 4-3/4"burn shoe on washover BHA assembly and RIH to 214'md.Slight tag seen at 165'md on the way in the hole,but able to shake through w/tubing tongs.Tag up at 214'md and gain milling parameters.PUW=47klbs,SOW=46klbs, 100 RPM=2.8k ft-lbs TO 208GPM=240psi,Mill/washover ESP debris f/214'md to 215'md w/burn shoe washover BHA. 67GPM=80psi,60-80RPM,=- 2.9k 2.9k ft-lbs,2-3klbs WOB.Continue to mill/washover ESP debris f/215'md to 220'md.5-10klbs WOB,35GPM=220psi,130RPM=3.2k ft-lbs TQ,MW= 8.2ppg in and out w/53 funnel visc.Decision to POOH.Blow down top drive and POOH w/burn shoe washover BHA. ?/214-0 i-Tuesda ° `i '11 p 7� F ` P RIH w/4 3/4"shoe,4 1/2"washpipe on 3 1/2"DC's to 220'.Pump HV sweep surface to surface.Milling/washing over f/220'to±222'w/3-4 bpm,3-4k WOB,80-100 rpm.While working pipe up at 207'(shoe depth),packed off and rotary stalled.Not able to move pipe up or down.While attempting to work free,Increased maximum torque to±6500 ft./lbs.While attempting to rotate free,twisted off 2 3/8"IF pin on#4 DC in hole.Left 2 DC's,jars, bumper sub and washover assembly in hole.Top of fish estimated at 88'below Rig Floor.Bottom at±207'.Monitor well and perform general housekeeping while waiting on fishing tools.Mobilize fishing BHA to the rig floor,perform per-jarring inspection on the derrick.M/U Baker fishing BHA w/ 3 joints of 3-1/2"DC's,oil jar,bumper sub,and overshot w/grapple.RIH and tag fish @ 85'md w/5klbs WOB.P/U and overpull w/25klbs,then slack off to 10klbs to ensure grapple is set.Work the pipe,picking up and slacking off.Grapple pulled free and unable to re-engage.POOH w/overshot spiral grapple BHA.Spiral grapple found to be parted.Baker fishing hand on location.Re-dress overshot w/new spiral grapple and RIH w/same BHA.Attempt to engage fish w/overshot spiral grapple with no luck.POOH and LID overshot spiral grapple BHA.Inspect overshot and note signs of wear on the internal bore of the barrel indicating we were able to get over fish w/overshot spiral grapple but unable to engage.M/U 4-3/4"Metal Muncher Mill BHA,RIH and tag top of fish to verify 85'md.M/U short catch overshot BHA w/basket grapple on 2 joints of 3-1/2"DC's,1 4-3/4'collar,oil jar,bumper sub,and overshot. Engage fish at 85'md and swallow w/short catch overshot 1'.Work pipe down setting 5klbs increments up to 25klbs followed by spudding down on the BHA w/the same increments.Attempt to release short catch overshot BHA f/fish by applying right hand torque.At 5k ft-lbs rotation able to rotate the string.POOH and L/D 4-3/4"drill collar,one 3-1/2"drill collar.String parted on the 2-3/8"IF pin on the top of the second 3-1/2"drill collar.New top of fish @ 35'md.Clean and clear rig floor,perform per-jarring top drive inspection.M/U overshot spiral grapple BHA on 4-3/4"drill collar,surface jars,4-3/4" drill collar and a joint of 4"DP.RIH and engage fish @ 35'md.Attempt to jar fish down. • • Hilcorp Alaska, LLC Hihorp Alaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-21 Doyon 14 50-029-22894-00-00 198-115 2/15/2017 2/26/2017 2/22/17-Wednesday - „ �� dais. �'� }, Y� �P-- j �' Go. —4 t 4 POOH w/overshot spiral grapple BHA laying down collars and surface jars.Perform post jarring derrick inspection,mobilize 6-1/4"tools to the rig floor, inspect drawworks brakes.M/U overshot spiral grapple fishing BHA w/6-1/4"bumper sub,oil jars,and accelerator.RIH and attempt to engage fish several times w/no success.POOH w/grapple and inspect,no major signs of wear.Change out spiral grapple for short catch basket grapple,RIH to top of fish.Unable to engage fish w/several attempts.POOH,inspect grapple.Debris found in grapple.RIH w/cleaned grapple and circulate on top of fish @ 8.5BPM w/70psi pressure.Lightly rotate overshot over fish,pressure increase noted.P/U on overshot w/25klbs overpull to verify engaged.Bleed jars, and overpull 40klbs.Fish came free.L/D short catch basket grapple BHA w/6-1/4"equipment.POOH w/fish,consisting of one 3-1/2"drill collar,oil jars, bumper sub,and basket grapple overshot,leaving original fish in the hole.Clean rig floor and equipment.Wait on fishing tools for next fishing run. Remove unnecessary tools from rig floor.Clean throughout rig.Fishing BHA on location.Load pipe shed w/drill collars and wash pipe.Strap collars and wash pipe.M/U burn shoe washover BHA 4-3/4"OD,3-7/8"ID w/3 joints of 4.5"wash pipe,drive sub,two 3-1/8"collars,one 4-3/4"collar and a joint of 4"DP.RIH w/washover assembly,Establish milling parameters and RIH over existing fishing assembly down to wash pipe drive sub located @ 164'md. PUW=40klbs,SOW=45klbs,ROT WT=42klbs,30RPM=1.3K ft-lbs TQ 1289GPM=110psi.Pressure and torque increase seen when swallowing fish.Tag fish @ 164'md(location of drive sub taper), mill 3"from tag location.Pump 20bbl high viscosity sweep @ 162GPM w/200psi,POOH,L/D burn shoe washover BHA and inspect rotatry shoe(minor signs of wear),M/U spiral grapple overshot BHA w/3-5/16"grapple.P/U two 3-1/8"OD PAC HT drill collars w/6-1/4"bumper sub,oil jars,accelerator,one 4-3/4"drill collar and a joint of 4"DP.RIH and locate fish @ 85'md w/5k WOB.Rotate over fish to try to engage further.Attempt to pull w/grapple but grapple quickly slipped off.Set down on fish w/5klbs increments and overpulls until fish is engaged @ 15klbs.Grapple continues to slip off w/slight overpull.POOH and inspect grapple.Spiral grapple control damaged,and only the lower most ring of spiral showed any wear.Decision made to change out overshot for short catch overshot and 3.5"basket grapple.RIH w/3.5"short catch basket grapple,and note tag at 86'md.Lightly rotate on fish to ensure fish is swallowed.Attempt to overpull on fish to ensure grapple is engaged.Not able to engage grapple. POOH w/BHA and inspect short catch overshot.No signs of wear on 3.5"basket grapple,and distinct wear on drive sub in overshot barrel indicating that fish was swallowed but 3.5"grapple too large.Decision made to test BOPE. L/D all BHA to pipe shed.Hilcorp Wellhead Rep Dean Norris on location to set TWC in TBG hanger.R/U for BOPE testing.NOTE:AOGCC was notified of upcoming BOP test via web site at 15:30 hrs.on 2-22-17.AOGCC Rep.Brian Bixby waived witness of test at 15:33 hrs.on 2-22-17. ry � ' iWi11, Ci� V SrS 9 � l) " s Prep for BOP test.Flush stack w/30 bbls of fresh water.Blow down Top Drive.Flush Flowline.Install hanger w/TWC.Pressure up&observe bottom rams leaking.Open rams&drain stack.Observe metal cuttings in stack.RU and flush stack with viscosified water.Function all rams and flush stack again. Attempt to shell test BOPE.Observed that the hanger was leaking.Wellhead Rep.delivered a test plug but observed that the top thread was HT-40 drillpipe connection.No XO's available for that connection.Rerun the hanger&energize seals by running in lock down screws.Testing BOPE per Sundry and Doyon 14 procedure.Test all equipment with 3 1/2"test joint to 250 psi low,3000 psi high for 5 charted minutes each test.Test annular to 250 low, 2500 high.NOTE:AOGCC Rep.Brian Bixby waived witness of test at 15:33 hours on 2-22-17.R/D BOP test equipment,blow down lines,drain stack.P/U 2- 7/8"landing joint,BOLDS,pull TBG hanger to the floor and L/D,M/U short catch overshot BHA w/3-3/8"ID basket grapple.RIH to 85'md,tag top of fish and attempt to engage.No success engaging fish.Attempt to wash off fish,pumping 4BPM=360psi.No success.POOH w/short catch BHA w/3-3/8"ID basket grapple,L/D short catch overshot.Note marks on the face of the grapple indicating the fish OD was slightly larger than the grapple ID,M/U 3.125" dress off shoe BHA and RIH to 85'md.Tag top of fish @ 85'md,P/U and gain milling parameters.PUW=45klbs,SOW=45klbs,ROT WT=45klbs,50RPM= lkft-lbs TQ 6BPM=160psi.Set down 1-2klbs on fish,dressing fish down to 85.5'md.POOH w/3.125"dress off BHA and L/D.B/D top drive,remove dress off shoe from BHA.Note signs of wear on inner cutrite of dress shoe.M/U short catch BHA w/3-3/8"ID basket grapple.RIH to 85'md circulate over fish @ 5.5GPM=110psi.Engage short catch BHA and overpull in 5klbs increments up to 35klbs over string weight.Fish slipped free at 35klbs.Attempt to re- engage fish w/no success.POOH w/short catch overshot BHA.Inspect short catch 3-3/8"grapple and note wear on the first 1/4 of the grapple.Metal debris found wedged in grapple.M/U burn shoe w/3-7/8"ID and RIH.Tag up at 85'md and lightly rotate over fish until 4'past fish neck.POOH and L/D 3- 7/8"burn shoe.M/U short catch overshot w/3-3/8"basket grapple and RIH to top of fish @ 85'md. Lightly pump through BHA to ensure short catch overshot barrel is clear.Set down on fish.Unable to engage grapple.Work pipe several times,attempting to rotate,pump and shake grapple.Not able to engage.POOH and inspect grapple.Metal debris from well found in grapple.M/U S-150 style overshot w/3.5"dress off guide lip,but no spiral grapple (we don't have an controls for the spiral grapples)and RIH to top of fish.Stop above fish,gain milling parameters.SOW=45klbs,PUW=45klbs,50RPM= 0.6k ft-lbs TQ 6BPM=150psi.Work 3.5"ID dress shoe across fish neck.POOH w/S-150 style overshot and L/D.RIH w/shot catch overshot w/3.5"ID basket grapple. Pump 1'above top of fish neck to ensure grapple is clear of debris.Set down on grapple the full swallow of the short catch.Engage fish and work pipe to ensure grapple is engaged fully.(Note:3.5"basket grapple easily swallowed fish yesterday but was too large of an ID for the grapple to get a bite as indicated by wear on the inner drive sub but not the grapple) J • S Hilcorp Alaska, LLC IliIcor')Alaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-21 Doyon 14 50-029-22894-00-00 198-115 2/15/2017 2/26/2017 ,-� � 'Iq �L Ji � ,'f �� ' � �s ,. 400- Engage 00 Engage fish w 3 1/2"grapple.Over pull to ensure engaged.PU to 60k over&bleed jars.Work several times to ensure good bite.Pull 35k over.Turn to the right in attempt to over torque 2 3/8"IF connection on fish and twist off.Grapple slipped&released.POH.PU Drive sub and 4 3/4"OD x 3 1/4"ID shoe. RIH and engage fish;.Burn over top DC and cut a 2 1/2'of new fishing neck.POH.LD shoe assembly.PU short catch O.S.w/3 1/4"grapple&RIH.Tag fish at 85'and swallow 1'to fully engage grapple.PU to ensure catch.PU to 60k over and bleed jars.Work pipe several times with 100k over allowing to jars to bleed.PU to 100k over.Rotate to the right while increasing maximum torque is stages to 7k ft/lbs.Unable to get 2 3/8"IF to twist off.Lower overpull in increments while holding 7k torque.Grapple slipped.POH.PU OS w/no grapple.RIH and set down on fish.Circulate in attempt to remove any debris from ID while waiting on Pollard Wireline to arrive location.LD Accelerator jars&1 joint of 4"DP to space out for wireline operations.Clean mud pits#1&2& suck out cuttings tank in preparation to stack rig.LD previous BHA.PU 4 3/4"x 3 1/4"wash over shoe,1 joint of 4 1/2"washpipe and 3 1/8"HT PAC DC's. RIH to top of fish at 85'.Tag top of fish @ 85'md,gain milling parameters.4BPM=110psi,50RPM=0.5k ft-lbs TQ PUW=43klbs,SOW=43klbs,ROT WT= 43klbs.Mill collar w/3-1/4"washover shoe f/85'md to 98'md.Pollard wireline service arrive on location.POOH w/washover mill shoe BHA and L/D,M/U S-70 short catch overshot w/3-1/4"basket grapple and RIH on two 3-1/8"DC's,6-1/4"bumper sub and oil jars.Engage fish w/grapple and verify hold w/ overpull.Mobilize Pollard Wireline equipment to rig floor.M/U 3/4"weight bar wireline drift w/CCL.RIH w/3/4"weight bar wireline drift w/CCL down to 196'md,P/U and make multiple passes w/CCL to verify string shot firing depth.POOH w/3/4"wireline drift BHA and L/D.Attempt to put left hand TQ into the workstring to ensure we can utilize the rig tongs to TQ the work string once on depth w/string shot.TQ was taken too high and a slight backoff was noted down hole.Release grapple, POOH and verify all connections in work string are made up to proper TQ.2-7/8"Reg connection found to be loose. M/U to proper TQ run back in hole w/short catch basket grapple BHA and engage fish.M/U and RIH w/Pollard Wireline string shot BHA w/160grains of primer cord and CCL.Tag up @ 135'md and attempt to work BHA past obstruction.(No success)POOH w/BHA and inspect.Rubbing noted on the tape used to hold primer cord onto rod.Re-tape primer cord,tightening the tape job to 13/16"and RIH. /25' lr Satorday� —I ." ��� 01 0 -00....0 11 (T tltl i_ �f ri i_ I - ' it �' f 46 i� i J 1=i0u � I1: l" y fiI 'ni ...... —. RIH w/attempt#2 with 2 strands,160 grain string shot.Tag up at 135'(same as last attempt).Work string w/no success.POH&inspect shot rod. Observed that the bull nose on bottom was bent over and obvious wear on the tape holding the primer cord.LD shot rod.MU 3/4"drift&RIH.Tag at 135'.Work pipe&made 9'but getting sticky.POH.Inspect drift.Obvious markings observed on nose of drift.Discuss options with town Engineer.Decision made to spot string shot across#1&2 DC connection.RIH w/2 strand,160 grain 4'long string shot and spot across connection at 113.5'.Work 4k left hand turn in pipe w/rig tongs&hold.Fire shot.Good indication of firing.RD W.L.&PU 1 it.of 4"DP.Screw in Top Drive.Attempt to back out DC. Connection not broke.Broke connection at 1st HT PAC DC below rotary.RIH&screw back in to string.Torque to 6k.Discuss options with town Engineer. Decision made to wash over fish to and mill 1'off of Washpipe Drive Sub. Release grapple&POH.MU washover BHA w/4 1/2"x 3 7/8"shoe,3 jts.of washpipe,DC's,B.S.&jars.RIH.Take weight at 142'(Just above 3 3/4").Break circulation w/6 bpm,300 psi.Begin milling on junk/fill at 142'w/3 bpm, 120 psi,60 rpm,3-5k WOB.Pressure increased and began pumping mud away.PU after making 1-2'each time and CBU 2-3x at 6 bpm.Continue to mill on junk to 150'(bottom of jars).Pressure continuing to increase(packing off)and losing mud(at 4 bpm,losing lbpm)..Call town Engineer.Decision made to suspend well.POH above fish.Monitor well for 15 minutes until static.LD BHA.Clear floor of Baker fishing equipment.L/D Pollard Eline equipment/Baker Fishing Tools/GBR power tong equipment and hydraulic hoses.M/U stack washer,flush BOP w/35bbls of fresh water,blow down top drive,L/D stack washer.Circulate down kill,through choke manifold w/30bbls of fresh water,drain stack and blow down choke/kill/hole fill lines.Cameron wellhead tech Tyler Strotz on location to remove TWC from TBG hanger and replace w/BPV,land hanger and RILDS.Open BOP stack bonnet doors,remove ram blocks and clean out all BOP cavities.Locate and inventory all third party equipment on the rig. •.., v ., f tom.', 16 i cT�i ' n- - N �'£W' - '114 ri N/U dry hole tree,Cameron wellhead hand Tyler Stortz on location to test void to 5000psi(good test).Bullhead 5bbls of Diesel down the TBG and IA, secure the tree.SIMOPS:gather all,Baker,API/Weatherford,and ASR,equipment from rig,begin cleaning mud pits from the shakers down.Release rig from well E-21 @ 06:00 on 02/26/17.Continue to remove third party equipment from rig,and clean pits.Remove all demco valves and grease mud manifold,while rigging down rig floor.Service top drive and ST-80 Iron Roughneck in prep for cold storage,prep brake linkage for shut down,grease choke manifold and fluid pack w/diesel.Prep mud pump#1 for cold storage,shut down rig floor glycol pumps,spray down tugger lines with wire rope lube,Totco rep on location removing monitors around the rig.Prep accumulator system for cold storage.Remove VBR and Blind/Shear rams from cellar, install intake covers on mud pumps,Cat Gensets,continue to prep accumulator for cold storage,blow down steam and water from rig floor,apply protectant to derrick sheaves,shut down boiler#1,remove shaker bed rubbers,flush mud gas seperator,continue to clean mud pits by circulating 120deg fresh water w/Baraklean through system. • II Hilcorp Alaska, LLC llilcurpAlaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-21 Doyon 14 50-029-22894-00-00 198-115 2/15/2017 2/26/2017 2/27/17 Monday `" " "I 11111 Al No Operations to report. 2/28/17 Tuesday ° ` (IL No Operations to report. • • • s THE STATE Alaska Oil and Gas y of Tye ti -.t✓� 0 fAT ASKA Conservation Commission 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage,GOVERNOR BILL WALKER Main: 907.279.1433 Agge" Fax: 907.276.7542 AL www.aogcc.alaska.gov Bo York SCA ,ED Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-21 Permit to Drill Number: 198-115 Sundry Number: 316-201 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, P996t4 Cathy . Foerster Chair DATED this I s day of April, 2016. RBDMS Lk, APR 0 4 2016 • 0 RECEIVED • STATE OF ALASKA MAR 2 4 2/016 ALASKA OIL AND GAS CONSERVATION COMMISSION 3c /</ l�jJ APPLICATION FOR SUNDRY APPROVALS ' 1iLL3 20 AAC 25.280 1.Type of Request: Abandon EI ' Plug Perforations❑ Fracture Stimulate El Repair Well ❑ Operations shutdown ❑ Suspend Li Perforate ❑ Other Stimulate ElPull Tubing ❑ Change Approved Program0 ❑ El El Pull Sundry#316-038 ❑ Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC - Exploratory ❑ Development E• 198-115 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-029-22894-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool'? N/A Will planned perforations require a spacing exception'? Yes ❑ No L + MILNE PT UNIT SB E-21 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0028231 • 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): 5,990 4,784 • 146 146 646 psi N/A 38' Casing Length Size MD ND Burst Collapse Structural Conductor 150' 13-3/8" 150' 150' 1.661 psi 5,380 psi Surface 38' 7" 38' 38' 7,240 psi 5.410 psi Intermediate Production 5,923' 5-1/2" 5,961' 4,765' 4.810 psi 4.040 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.7#/J-55/8RD EUE 5,421' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary Li Wellbore schematic I] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/30/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Li 17.I hereby certify that the foregoing is true and the procedure approved Tom/ "riltlt( tsi4401 44 4tc herein will not be deviated from without prior written approval. Contact Ted Kramer(907)777-8420 rap 14 am tt /J Email tkramer@hilcorp.com 6Lci. fIGIc.,t,C„ Printed Name Bo York /� a•vrc it,u `�i aAA4— Title Operations Manager Signature i/77'L Phone 907-777-8345 Date 3/Z 7/f(r.,,, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity LJ BOP Test I Mechanical Integrity Test ❑ Location Clearance j�❑/� Other: j�-- P12-06, dbe, .c �+ rC 4-5 i t�L.—W--1d ' �.fl jt FiiG�?� o —' , �� 3C�C'9c- /''''` Qc�r /mss Post Initial Injection MIT Req'd? Yes ❑ No El Spacing Exception Required'? Yes ❑ No Subsequent Form Required: / •--Li 07 RBDMS LL' APR 0 4 2016 APPROVED BY C� / // Approved by: . . COMMISSIONER THE COMMISSION Date: ( —/ - /Y 4-5/V,-%14 ORMLUAL.for Submn Form ane Form 10-403 Revised 11/2015 12 months from the date of approval. Attachments in Duplicate . 14 • • Well Prognosis Well: MPU E-21 IliI(orp Alaska,LL Date:3/23/2016 Well Name: MPU E-21 API Number: 50-029-22894-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: April 30, 2016 Rig: Doyon 14 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) MPSP: 646 psi (Based on offset E-32 on 11/16/14 and water cut of 50% (0.385psi/ft) with an added safety factor of 1,000' TVD of oil cap) Note: Current Surface pressure is 0 psi. Brief Well Summary: In January of 2016 an attempt was made to P&A this well by bull heading 50 bbls of mud push with LCM material and 235 bbls of class "G" cement down the well. There is an ESP stuck in the well and tubing was recovered down to 547 feet from surface. The ESP electrical cable and a control line stripped off of the tubing that was removed and was tagged prior to the cement job at 146'. The P&A was unsuccessful in that the cement exited the well bore shallow through a casing leak and migrated over and up the conductor by surface casing annulus on the MPU 17 injection well located six slots away on the same well pad. E-21 was cleaned out to 127' and pressure tested with a test packer. The well did not pass a pressure test down the tubing (100 psi bleed off in 5 minutes). The back side did pass a pressure test of 1,600 psi for 30 minutes. Objective: The purpose of this work is to rig up the Doyon # 14 rig and clean out the well down to 550 ft (top of the + r tubing) looking for a shallow casing leak. If a leak is found, a plan will be developed for fixing the leak and cementing the well to surface. Brief Procedure: WO Rig Procedure: 1. MIRU Doyon#14 Workover Rig. 2. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test in case they want to witness. 3. Bleed pressure to tank. . 11 • • Well Prognosis Well: MPU E-21 H'Icon)AIa..ka.LL Date: 3/23/2016 4. Fish/ Mill cement and ESP Cable, capillary line, and stainless steel bands from 130' to (+/-) 550 feet (top of 2-7/8" tubing). POOH with Mill. 5. PU test packer, RIH to (+/-) 545' and wt. Pressure test casing to 1,500 psi. on chart, both down the , ,f. (3 tubing and on the backside. If test passes, go to Step 9 otherwise go to step 6. —3? i r"P"S'J 3 �ssk 6 .Move test packer up the well hunting leak. POOH with test packer. (edc' 7. RU E-line. Run caliper log In 5-1/2" casing to find a good top and bottom for a possible patch. POOH with e-line. Ad e►-u- 8. Determine how to best correct casing leak(braiden head squeeze or straddle assembly)from Caliper and pressure test data. Discuss with AOGCC path forward for P&A plan for the well. If pumping cement,go to step#9. Otherwise, a program change will be required. -if . MIRU Cementers. Pressure Test lines to 4,500 psi. -I,l 10. RIH open ended with work string. 6-34 11. Spot balanced plug of AS1 Cement from 550' to surface. -17. /3 £a' 12. POOH. Allow cement to seek its own level. WOC. ,O 3 013/�� 13. RIH and Tag TOC. 14. RDMO Cementers. 15. RDMO Doyon# 14 Rig. 16. ND BOP, NU Dry Hole tree. Surface Procedure: ''/L.)IL c..7,�.;.:.....n,�,.." -- W a h C., .�.15.oeY'• 17. Excavate cellar, cut off wellhead and casing 3' below natural GL. 18. Set marker plate, collect GPS coordinates. - 'wt.._ z.o 4C-- Z-671Z 19. Backfill cellar, close out location. Attachments: 1. Current Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank MOC Form Milne Point Unit SCHEMATIC • Well: MPU E-21 H . As of 3/23/16 Last Completed: 9/13/1998 Hikorp Alaska,LLC PTD: 198-115 TREE&WELLHEAD Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Tree 2-1/16"5M l :'4\ Wellhead 7"5M Varco ADRS-7 Weld on style Tubing Hanger NSCT T&B 2"CIW H BPV Profile T'x5.5'X w ..-7 Wellhead HOLE/CEMENT DETAIL 13-3/8" O @38' L. 0.) 13-3/8" 250 sx Arcticset 19Approx)in a 16"Hole \ _ — Trace/ 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole HeatTop Job • ESP Cable NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III 0-135' Top@ 146' . 8/30/19981 641CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF • 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 0.148 o 2 7" Prod X-Over 26/L-80/BTC-MOD 6.276 , Surface 38' 0.0383 5.5" Production 15.5/J-55/BTC-MOD 6.151 38' 5,961' 0.0238 • TUBING DETAIL '9 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.995 547' 5,421' 0.00387f �� 6r Y WELL INCLINATION DETAIL „ KOP @ 550' '12 Max Hole Angle=58 deg. @ 4,081' t)1' Hole Angle thru perfs=50 deg. JEWELRY DETAIL , No Depth Item 1 547' Jet Cut 2-3/8"Tubing � Btm ©3,50CaceBh2 2,008' 5.5"Port Collar Cementer @ 3,500' Tubing Punch 3 5,322' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" ***No Valve Installed*** 4,823-4,828' 615/154 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 5 5,361' KUDU PCP,100TP1800-Intake ND @ 4,395' 6 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 • 5.5"BIC Marker 7 5,408' Centrilift FMH1-54hp/1,020V/35amp Joint: 8 5,419' Centrilift PHD-Bottom @ 5,421' 5,071'-5,111' , PERFORATION DETAIL I • Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ' 3 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 4 'OA' 5,548' 5,568' _ 4,496' 4,509' 20 _ 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open STIMULATION DETAIL 5 'OA'/'OB'121,840 lbs Proplok 16/30 Badger behind pipe on all three perforated intervals . GENERAL WELL INFO 6 API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 Initial Completion by Nabors 4E5 9/13/1998 �y3 g /343`/if- Fish:90ea.7/8"1.3 Schrader Sands ' 1' Ball Sealers. TCF @5,863 r_// Tc Calculated 41)3 5.5"A .. yd TD=5,990'(MD)/TD=4,784'(1VD) PBTD=Surface(MD)/PBTD=Surface(TVD) Revised By:JLL 03/23/16 Miln ini . PROPOSED • Well:e Point MPU Unit E-21 Last Completed: 9/13/1998 Hilcorp Alaska,LLC PTD: 198-115 TREE&WELLHEAD Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Tree 2-1/16"5M l it, Wellhead 7"SM Varco ADRS-7 Weld on style Tubing Hanger NSCTT&B 2"CIW H BPV Profile s= ', 7'x5.5 X w OPEN HOLE/CEMENT DETAIL 133/8 z"over@3813-3/8" 250 sx Arcticset I 9Approx)in a 16"Hole •. 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole Top Job I NOTE:Performed Top Job with AOGCC Approval—300sx Coldset III 0'-135' 8/30/1998 1 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 0.148 2 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' 0.0383 • 5.5" Production 15.5/J-55/BTC-MOD 6.151 38' 5,961' 0.0238 ' TUBING DETAIL 2-3/8" Tubing 4.7/1-55/EUE 8rd 1.995 547' 5,421' 0.00387 . WELL INCLINATION DETAIL ' KOP @ 550' Max Hole Angle=58 deg. @ 4,081' Hole Angle thru perfs=50 deg. JEWELRY DETAIL No Depth Item 1 547' Jet Cut 2-3/8"Tubing 3Btm @3,500,500' 2 2,008' 5.5"Port Collar Cementer @ ' Tubing Punch 3 5,322' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" ***No Valve Installed*** 4,82348M' ' 6/15/15 '''''').4.,‘,_ 4 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" = 5 5,361' KUDU PCP,100TP1800—Intake ND @ 4,395' 6 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 5.5'BTC Marker ,. 7 5,408' Centrilift FMH1—54hp/1,020V/35amp Joint: 8 5,419' Centrilift PHD—Bottom @ 5,421' 5,071'-5,111'y ' PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 3 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 4 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 1 1 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open STIMULATION DETAIL 5 'OA'/'OB'121,840 lbs Proplok 16/30 Badger ' behind pipe on all three perforated intervals ' itf:kli GENERAL WELL INFO t 6 API:50-029-22894-00-00 • Drilled and Cased by Nabors 27E -9/1/1998 Initial Completion by Nabors 4ES—9/13/1998 ' C .i Fish:90ea.7/8•'1.3 Schrader Sands SG Ball Sealers. TOF @ 5,866' Calculated • 5.5",a.,, , ..,I TD=5,990'(MD)/TD=4,784'(TVD) PBTD=Surface(MD)/PBTD=Surface(ND) Revised By:JLL 03/23/16 . • • CC U c j = J a) y Ep N O U x L N — ih U i 2 N M X x N MX M 05 MC f Qll en en M N M (, c / N 171 / inn„.... .:.. \ ) " �' nn y 2 = 0 4 c'—j F, 2. .‘"tillir"4‘igf ' ta N ° °° o �o e• T : & i e 00 ° B¢ � N �P CI 0 LJ �p 0 , '...� ( N N m x p N 2117 t. U. �uuuouui TO cobs Eco CO C > N =(AaUa ca ��. o m 0mwco E I=E `� o chrill 6 ch"\ _ � 0) o N c J Y • • f 0 6 / o § › +4 ■a § e E0) > Wc E • . o - ml % % O a § \ § < � 2 < a / � 2 ®> 7 = « ° mJ 2 2 0 _ k ¢ § \ ■ ■ � � 2 a a / / ƒ 0.Ca c C• o 0 0 "0 - > 0 is O kc w 2 a) �/ 10 — \ / / os § cn 00 = k � < C.) a) I... 2 E § E a) °o ° 0 ms / : 0 0 a / / a) t 4 O a) a) �7 § c § vs D � "' 0 c W > 2 $ ° c 2 § � 0 czt Q. « / \ 0 0. 2 xozi a) 0 2 » ■ i- d ...7■ 0 & o a) co 0 § o 4 0 0. � as 4- ® O .. / ■ % _ : U C E / o > m - 2 f O Q. 0- f :3 0 0 U) 2 CO< ¢ I U) w • 'Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, March 30, 2016 3:37 PM To: Schwartz, Guy L(DOA);Taylor Wellman Subject: RE: E-21 RWO to P &A (PTD 198-115 Guy, Step#5 is not clear. What it should say is if the tubing side passes but the casing side does not,then the leak is above us and we need to hunt it. If the back side passes and the tubing does not,then we need to discuss this with the AOGCC for a path forward. If for some reason,they both pass,then we also need to discuss that with the AOGCC. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, March 29, 2016 4:37 PM To: Taylor Wellman; Ted Kramer Subject: E-21 RWO to P &A (PTD 198-115 I am reviewing the sundry. Can you clarify what step 5 means as far as testing the casing. Both tests cannot pass ... ??? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 • • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, February 17, 2016 1:34 PM To: Schwartz, Guy L(DOA) Subject: MPU E-21 Sundry#316-038, PTD# 198-115 Attachments: P and A Cement Job Analysis.pptx Guy, i L Hilcorp would like to have a dialogue on how to proceed with the P&A of this well. t t { 'l. Hilcorp proposes that we attempt to clean out this well down to the tubing cut at 547'(+/-) looking for the shallow casing leak. We will take periodic pressure tests to see if we have casing integrity and a good pressure barrier below a packer. Once we have a good pressure test,we will consult the AOGCC on how to proceed with the P&A of the well. Rationale : The Cement Job on the above well did not go as expected but it is still probable that the objective of providing a barrier deep in the casing to the flow of hydrocarbons was met. The geometry of the well is as follows: Volume of the wellbore= (+/-) 131 Bbls. Volume between the tubing and the casing(from 547 ft to the ESP) = 101 bbls. With 25 bbls of mud push and 51 bbls of 15.6 ppg cement pumped we saw our highest surface pressure of 896 psi. I believe that is when the cement plugged off at the ESP pump. After that,something else opened up and the remaining 170 bbls of cement was pumped out that hole. Attached please find a pump log of the cement job supporting that claim. If we clean out to the hole,we should get a good pressure test below it. If you are available, I would like to discuss this plan with you on Monday following the 10:30 AM meeting to discuss using casing jacks on the K-30 well. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. SCANNED MAY 1 8 2016 0 907-777-8420 C 985-867-0665 1 . • . Pressure(psi) 0 g rg g g g § § o• 13:50:40 - -....N.... 13:56:13 0, 14:02:13 \\I't(' I 41.IIIIIIh fo vi 0.1 0 14:08:13 c . gr. 0_ co Ur li 14:14:13 -0 c " 0- .4 14:20:13 —......6,.. 14:23:55 401111111111111166.V1 _4.- 14:28:13 imm..mir.......••••00000.-- ;c: . ... 0, 14:30:13 ". tri 14:36:13 ' . 2._ . ,.. 14:39:48 . 14:44:13 irliMil Aill 17L ni—: N.K , 14:58:0 .1 15:00: -4111111411111"- NW MP1. 1 N 15:03:49 I.•a r) 15:08:13 ' . M 15:12:13 — 411,- ,.. 15:18:13 o ti1 a- 3 cr 15:26:13 17 re 15:32:13 7 w -c, 0 15:38:13 ao n cr 11 154813 15:54:13 1.4.--4 -.....o. 15:56:01 23 16:00:13 a' , r. 16:06:13 :A lb 16:10:13 ---rr 16:16:13 I. 4 16:22:13 ihr. 16:25:40r , , o ,-. N.,‘ ka A. to i i f 7:I r) 70 a c 7,1 r D 3 tn Ca < ID 0 , 1; ! -c•I''' —S\ v ' ..... a. tv -.,.. -o3 r 0 67 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg >��III-711G.' DATE: January 26, 2016 P.I. Supervisor SUBJECT: Well Bore Plug &Abandonment MPU E-21 FROM: Matt Herrera Hilcorp Alaska LLC Petroleum Inspector Milne Point Unit - PTD 1981150 - Sundry 316-038 Section: 25 Township: 13N Range: 10E Meridian: Umiat Drilling Rig: HAK ASR1 Rig Elevation: Total Depth: 5990 ft MD Lease No.: ADL 0028231 Operator Rep: Don Haberthur Casing/Tubing Data: Casing Removal: Conductor: 13 5/8" O.D. Shoe@ 150 - Feet Casing Cut@ n/a - Feet Surface: 5.5" " O.D. Shoe@ 5961 Feet Casing Cut@ n/a Feet Intermediate: O.D. Shoe@ Feet Casing Cut@ Feet Production: O.D. Shoe@ Feet Casing Cut@ Feet Liner: O.D. Shoe@ Feet Casing Cut@ Feet Tubing: 2-3/8" - O.D. Tail@ 5421 - Feet Tubing Cut@ 547 - Feet *5.5"cross over to 7"(L80, 26ppf) at 38 ft Plugging Data: Type Plug Founded on Bottom of T.O.C. Depth T.O.C. Mud Weight Pressure (bottom up) Cement Verified? above plug Test Tubing ID 3112 ft MD Tag; 11-11-15 • Wellbore 1 Bottom I 5961 ft MD est. 150 ft MD' No 1 13 ppg Fail Remarks: Attempt to RIH with tubing to tag anticipated cement top at 150ft was interrupted by a suspected cement bridge at surface just below the slips on the wellhead. Attempted pressure test(1500psi; 30min)would not hold. Equipment to be brought out to drill out obstruction at surface to determine true top of cement. Attachments: none SCANNED SEP 2 12016 rev. 2-25-14 2016-0126_Plug_MPU_E-21_mh.docx.xlsx 3/17/2016 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg t,11( DATE: January 27th 2016 P. I. Supervisor FROM: Brian Bixby SUBJECT: Inflatable Bridge Plug Test Petroleum Inspector MPU-E-21 Hilcorp Alaska LLC PTD 1981150 / Sundry# 316-038 January 27th 2016: I arrived on location [Hilcorp Rig ASR1 @ MPU E-21]at 15:30 and met up with the Company man Donny Haberthur. We talked about what was going on with well E-21 and the issues of the cement breakthrough to well the E-17 cellar. The rig crew and Baker hand just completed a scraper run down to 136' in prep to run the inflatable bridge plug (IBP). The IBP was set at 129' to enable pressure testing to determine if the leak is above the existing cement plug or below it. They pressured up to 1560 psi to test below the IBP and it had the same bled off as before — a little over 100 psi in 5 minutes. They next rigged up to test above the IBP by closing the rams and pumping in thru the kill line. The well was pressured up to 1600 - psi and it held solid for 30 minutes confirming the leak is below the top of the cement plug. I looked at the cement in the MPU E-17 cellar and also talked to Hilcorp engineer Ted Kramer. He confirmed they collected samples of the cement and sent them to Schlumberger for analysis; results not yet available. Hilcorp ASR1 is waiting on the path forward now from Ted Kramer and AOGCC Drilling Engineer Guy Schwartz. Attachments: none . St. E® JUL 2 e 2016 2016-0127 Plug Integrity_MPU_E-21_bb.docx Page 1 of 1 tiOF Thr, • THE STAT• Alaska Oil ���\I/�� as a and Gas . ��, of/` j AsKA Conservation Commission S tt"t l— 333 West Seventh Avenue ,ITh,, ow GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 43+ Main: 907.279.1433 Op ALAS'" T Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager NNED ; zis Hilcorp Alaska, LLC ` 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-21 Permit to Drill Number: 198-115 Sundry Number: 316-038 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, lo/ 4-f, Cathy :. Foerster Chair t DATED this day of January, 2016. RBDMS c`- JAN 2 5 2016 la+.stiVIL ' W ILA.) STATE OF ALASKA JAN 19 2 1 ALASKA OIL AND GAS CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVALS 0V PS' 20 AAC 25.280 1.Type of Request: Abandon Q Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ I Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program[ , Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑l . 198-115 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK,99503 50-029-22894-00-00- 7. If perforating: 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 AitC ive 0/` Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / MILNE PT UNIT SB E-21 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028231 , 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): 5,990 _ 4,784 ' 5,866. 4,702 .. 646 N/A 38' Casing Length Size MD TVD Burst Collapse Structural Conductor 150 13-3/8" 150' 150' 1,661 psi 5,380 psi Surface 5961 5-1/2" 5,961' 4,765' 4,810 psi 4,040 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic• See Attached Schematic 2-3/8" 4.7#/J-55/8RD EUE 5,421' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A 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: 1/27/2015 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ ) Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Et- 17. I hereby certify that the foregoing is true and the procedure approved yy herein will not be deviated from without prior written approval. Contact Ted Kramer G- 777-,Yi2i-cf Email tkramerafilcorp.com Printed Name Bo York Title Operations Manager "71/7)--- Signature Phone 907-777-8345 Date 1;19/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity i BOP Test [ Mechanical Integrity Test ElLocation Clearance ` Other: _ 3 Ooe) los, & P• -es- ---r f `� e p „do G«..�-►-...,.�as c u,s;in ,.. -c' c... c--- - 2 pCe', Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No UZ Subsequent Form Required: /0—Ho 7— APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:A �/� c 2` 16' GpFoGuiaNAILor � �� I't Submit Form and F rm 10-403 R ;sed 11/2015 12 months from thedateof approval. Attachments in Duplicate tt// RBDMS t,�- JAN 2 5 2016 • • Well Prognosis Well: MPU E-21 Rilcorp Alaska,LLQ Date: 1/19/2016 Well Name: MPU E-21 API Number: 50-029-22894-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: January 27th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) MPSP: 646 psi (Based on offset E-32 on 11/16/14 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: During a recent workover to convert the MPU E-21 to an injector, Hilcorp found that the ESP was stuck in the well. This is believed to be due to collapsed casing. 547' of 2-3/8" production tubing was cut and recovered but the bands/flatguard/cable/heat trace pulled free from the tubing and remains in the well with the ESP. Slick line made a tag of 157'(+/-) after the rig was moved off of the well with a 3.80" LIB. (Note: BOP Stack is still on the well.) Notes Regarding Wellbore Condition • 5.5" 15.5#casing cemented to surface; performed top job from 135'to surface on 8/30/1998. • Casing last tested to 3,500 psi for 30 min down to 5,876' on 8/30/1998. • Maximum hole angle is 58° @ 4,081' MD. • ip • Tubing pressure tested to 1,500 psi. on 11-9-15. (1A6: • Cement inside tubing tagged at 3,112' MD on 11-11-15. p _16 Objective: 1-70 The purpose of this work is to rig up the ASR#1 rig and pump a cement job to P&A the well . :- Brief Procedure: WO Rig Procedure: 1. MIRU ASR#1 Workover Rig. 2. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test in case they want to witness. 3. Bleed pressure to tank. 4. PU 4" LIB on WS. RIH and tag obstruction at 150' (+/-). POOH With LIB. 4 5. RIH with Work string to one joint above obstruction (determined by LIB in step 4). 6. MIRU Cementers. RU and pressure Test lines to 4,500 psi. 7. Line up to pump truck, bullhead 150 bbls of 8.5 ppg heated sea water and establish PIR. 8. Mix and pump ( bullhead )cement job according to attached cementing procedure. V} ! s I3[.'sc" C2 i .� 54/7- Lo I'- ( 3 3 ea a It:�o P--s e- i 70 i8t ct-tr • Well Prognosis Well: MPU E-21 Ililcora Alaska,Lb Date: 1/19/2016 a. Note: Objective is to fill well with cement from PBTD to above obstruction @ 150' (+/-). 9. Contingency—If unable to see a pressure increase, switch to seawater and over-displace well to perfs and notify AOGCC. 10. Open casing valve. 11. Displace tubing with fresh water and clean stack, taking flow to returns tank. 12. POOH. WOC 24 hrs. 13. RIH and Tag TOC. PU 10 feet. / �. 14. Close Rams and pressure test cement plug to 1,500 psi. ,• ir o , 15. Spot AS1 plug from TOC to surface. 1 % /V0 f e- ta 16. RDMO Cementers. A- 3 S 44.,. 1F01. w 17. RDMO ASR#1 Rig. - ��--- —�--�_ 18. ND BOP, NU Dry Hole t - `✓ G�c S i� C Surface Procedure: � //c4- 19. `f419. Excavate cellar, cut off wellhead and casing 3' below natural GL. 20. Set marker plate, collect GPS coordinates. 21. Backfill cellar, close out location. 4 L.,.)1.-6...A-5 a Attachments: 1. Current Schematic 2. BOP/Tree Schematic 3. Schlumberger Cementing Procedure 4. Proposed Schematic 5. Fluid Flow Diagram (Cementing) 6. Blank MOC Form • � Milne Point Unit Well: MPU E-21 , 14 SCHEMATIC Last Completed: 9/13/1998 PTD: 198-115 Hilcoru Alaska,LLC TREE&WELLHEAD Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Tree 2-1/16"5M Wellhead 7"5M Varco ADRS-7 Weld on style Tubing Hanger NSCTT&B 2"CIW H BPV Profile `° ''7'xssx OPEN HOLE/CEMENT DETAIL 133/8' Over@ 13-3/8" 250 sx Arcticset I 9Approx)in a 16"Hole Heat Trace/ 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole Top Job 1 ESP Cable NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III 0'-135 J' ,5) Top@ 150' 8/30/1998 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF i 0 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 0.148 1 14 2 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' 0.0383 • 0 .ia 5.5" Production 15.5/1-55/BTC-MOD 6.151 38' 5,961' 0.0238 TUBING DETAIL * 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.995 547 5,421' 0.00387 I, rtJ0 WELL INCLINATION DETAIL yl L KOP@550' J Max Hole Angle=58 deg. @ 4,081' Hole Angle thru perfs=50 deg. TOO JEWELRY DETAIL 3to) lz 3,112 h No Depth Item ' vj' Heat Trace Btrn 1 547' Jet Cut 2-3/8"Tubing , 11' @3,500 2 2,008' 5.5"Port Collar Cementer Tubing Punch y •,: f 3 5,322' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" ***No Valve Installed*** 4,823'4,828 6/15'15 " , 4 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 5 5,361' KUDU PCP,100TP3800-Intake TVD @ 4,395' !„ 6 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 5.5"BTC Marker .,^ 7 5,408' CentriliftFMH1-54hp/1,020V/35amp J'-t: 8765 5,419' Centrilift PHD-Bottom @ 5,421' 5,071'-5,111' t;� T Y PERFORATION DETAIL t 1 Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status !* 3 i` 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 4 r 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open 4 '-'1' STIMULATION DETAIL OA'/'OB'121,840 lbs Proplok 16/30 Badger i 00 behind pipe on all three perforated intervals IIII 6 GENERAL WELL INFO API:50-029-22894-00-00 x i Drilled and Cased by Nabors 27E -9/1/1998 Initial Completion by Nabors 4ES-9/13/1998 8 a, Fish:90ea.7/8 13 I, r=', Schrader Sands SG Ball Sealers. " t, TCF©5,866' Calculated 11 5514 to TD=5,990'(MD)/TD=4,784'(TVD) PBTD=5,876'(MD)/PBTD=47,708'(TVD) Created By:TDF 1/15/2016 . Milne Point Unit Well: MPU E-21 PROPOSED Last Completed: 9/13/1998 Ililcorp Alaska,LLCPTD: 198-115 TREE&WELLHEAD Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Tree 2-1/16"5M ! U k`Y Wellhead 7"5M Varco ADRS-7 Weld on style . r r,, �� TubingHanger NSCTT&B 2"CIW H BPV Profile :rt 3 acv g t " • OPEN HOLE/CEMENT DETAIL 13 3/8" e°38' 13-3/8" 250 sx Arcticset 19Approx)in a 16"Hole �, Hit Trace 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole Top Job ` ` / ESP Cable -7()....4-1NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III 0-135 Top@ 150' 8/30/1998i �id CASING DETAIL i :�"' 3S Size Type Wt/Grade/Conn Drift ID Top Btm BPF " '4 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 0.148 .; % 2 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' 0.0383 i 5.5" Production 15.5/J-55/BTC-MOD 6.151 38' 5,961' 0.0238 TUBING DETAIL 2-3/8" Tubing 4.7/1-55/EUE 8rd 1.995 547' 5,421' 0.00387 WELL INCLINATION DETAIL ,, KOP@550' Max Hole Angle=58 deg. @ 4,081' Hole Angle thru perfs=50 deg. TOO JEWELRY DETAIL t l'' 3,112 sl ' No Depth Item '° Heat Trace Btm 1 547' Jet Cut 2-3/8"Tubing °' @3,500 2 2,008' 5.5"Port Collar Cementer Tubing Punch , ,', , 3 5,322' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" ***No Valve Installed*** 4,823'-4,828' , _1 6/15/15 !7 6.,-.- 5i{ 4 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" .-j �r 5 5,361' KUDU PCP,100TP1800-Intake TVD @ 4,395' ' ", 4 6 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 "r�r 5.5'BTC Marker .F. I„;- -"" 7 5,408' Centrilift FMH1-54hp/1,020V/35amp Joint: e<� 8 5,419' Centrilift PHD-Bottom @ 5,421' 5,071'-5,111 `" 9 E PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open s 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 75 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open ff.III STIMULATION DETAIL 5 'OA'/'OB'121,840 lbs Proplok 16/30 Badger behind pipe on all three perforated intervals till t { 11` •s GENERAL WELL INFO I + API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 7 Initial Completion by Nabors 4ES-9/13/1998 5S ; , e a 3b' g'/1-- z3S Fish:90ea.7/8"1.3 = Schrader Sands SG Ball Sealers. TOF @ 5.866 Calculated , TD=5,990'(MD)/TD=4,784'(1VD) PBTD=5,876'(MD)/PBTD=47,708'(TVD) Created By:TDF 1/15/2016 II • • MPU E-21 TREE/WELLHEAD Wellhead/Tree <i;le.,.p Alaska,LLC Point Unit Original RKB IIIP I . ,. 15.05' r,,- 4 ` 1 'C, 0 . V •rF. • ASR Rig Floor 11 11 18.75' 10 O . --• _ / III 111 111 111111 MI 32.70' 33.80' [WIf1'11191.1 itl _� I _ 0 4r_: =— 1 F. E fir: 17.: ' 0,n nil frtatritt l ri . C i s 0D., OM 11 i1; Original Ground Level 1.10' • Top Tubing Head I A ♦ ♦ 1.00' -°� -""` Top of Cellar »..» III . II 1.58' i ; V' /mak 5.00' 5.33' - �'�� Z 2.61' • • Btm of Cellar ♦ . 1.14' Xo ♦ Fish at 24' (from ASR rig floor) 1.97' ,5-1/2" „,,,'lzAK-',' • • , ,,tfo,,, _,„, , - ,,„.., /.,,,, . , ,,___,,, ,.,,,,,,.....,-,-.....---„,z,,e: -- P1 ' (;"1 V pi\::: 1-KI44i.C-411,i r 1 re. , ,t- t- , e i r - , , .' 'fu }yam , a'S y rig r -a, *.f F a 3x fir` \-,4,..% ,..- .aY.i MPU E-21 Retainer Squeeze #4 (approximate) Version 3 1/19/2016 Field : Milne Point Prepared for: Prepared by : Ted Kramer Stephen Lauper Hilcorp Alaska 907 952 0445 SLAUPER@slb.com Prudhoe Bay,AKA zob- • F p JOB OBJECTIVES AND DESIGN CONSIDERATIONS Job Objectives Pump 143-bbls below Retainer prior to laying in AS1 plug on top of retainer Acceptance Criteria Pump Per Procedure Operational Statement To successfully set cement plugs the same methodology used to design and execute primary cement jobs is required(e.g.correct slurry design, mud-removal and placement design based on accurate well data).Often cement plugs are even more complex to design than primary jobs and this complexity should not be underestimated.This can include more laboratory tests as well as additional equipment requirements. Cement plugs are remedial cementing treatments.The first logical step is to determine the actual problem to solve,i.e.what is the purpose of setting a cement plug.The second step is to understand the criteria of evaluation(tag,no tag,positive pressure test,negative test,etc.).Both of these steps allow for the proper selection of the slurry specification and job placement technique. Key facts for successful plug cementing operation 1. Displacement and under-displacement volumes play a critical role for the success of the job and should be followed as per this program. 2. Time drilling is recommended when kick-off/sidetracking plugs are placed 3. Communication with the drilling company is important to understand the configuration of the BHA at the time of the operation(see recommendation in Kick-off Plug,Aberdeen,Side tracking Best Practices and Plug Design Checklist,InTouch ID#5895060) 4. Fluid contamination/mixing during plug setting can reduce job success;use of foamed balls ahead and behind is strongly recommended. Risk Statement As stated in the Operational Statement above,cement plugs are complex in design and execution,and should not underestimated.Cement plugs should never be considered as a'routine'job. With all the facts,best practices,and other recommendations as per Well Services standards,guidelines,etc,presented and covered by peer review in the job program,the risk of job failure should be reduced to a low level(cement plugs inherently have a higher risk level than primary cementing operations due to the increased number of unknowns that affect the entire job design). However if,for whatever reason,there is disagreement,debate,or refusal of implementation regarding one or more of the recommended practices or guidelines that mitigate risk,there must be an immediate Management of Change(MoC)submitted.By raising an MoC the appropriate level of escalation of approval to higher management can be made as necessary. 2 of 3 Schlumberger t i Squeeze Plan: BHST-75degF BHCT-80degF Pump Time: 562 min 235-bbls of Cement Requested Fresh Water 5 bbls 5 BPM 1 min Pressure Test Lines 4500-psi 11ppg MUDPUSH II + 25-bbls 5BPM 5 min 15lb/bbl CEMNET PLUS 15.6ppg Class G +41b/bbl 65-bbls 5 BPM 13 min CemNET PLUS 11ppg MUDPUSH II + 25-bbls 5BPM 5 min 151b/bbl CEMNET 13ppg Class G +4lb/bbl 170-bbls 5 BPM 34min CemNET PLUS(START AT 4 lb/bbl and SLOWLY RAMP UP as much as possible) Seawater 20 bbls 5 BPM 4 min TOTALS 3055 bbls 62min Required TT: 23:02 hr:mn Requested 3:30 to 4:30hr Thickening Time 1. RIH WI 2-3/8"Tbg to 100ft.Ted 2. Close annular. Establish pump in rate. 3. Pump 5-bbls of Fresh Water ahead of cement 4. Pressure Test Cement Unit to Max Pressure,4500-psi 5. Mix/Pump 25-bbls MUDPUSH II Spacer with 15-Ib/bbl CemNET PLUS 6. Pump 65-bbls of 15.6 ppg Class G Cement with 4-Ib/bbl CeJ ET PLUS(ALL OF ORIGINAL BLEND FORM 2015) 7. Mix/Pump 25-bbls MUDPUSH II Spacer with 15-Ib/bbl CemNET PLUS 8. Pump 170-bbls of 13 ppg Class G Cement with 4-Ib/bbl CemNET PLUS (START @ 4 lb/BBL CemNET PLUS and slowly ramp up until issues are seen. OK to shut down to decrease loading once cavitation is seen. Max expected to be 8-Ib/bbl) 9. Open backside valve to tank 10. Displace with 20 bbls of Seawater cleaning up cementing equipment and circulating to tank. Shut down, WOC. ,11. Open Annular, RIH with Tubing and tag top of cement. 12. Close Annular. 13. Set AS1 plug from TOC to surface. 15oz) 3 of 3 Schlumberger . • • as e o -r, cc x U 7d c a> > `0 `� F ...y o 'o > - H c re ' m 0 E. i w > W 5 rU m I „ 0 x 01) 91) n G > U ro - C Q 11' a > U ,.. Ln• J z 0.. 0 is >` a 2 Do11 0091,.. ... m a w > 7 m" ¢" a H LD z Z3 v 6) 1TD VI) m • 1p Y 17 x V$ V: u = lJ m a V V• m m O 0 m O Ln O a 83 Ln N• .y• V• N C N C C m m a 0 S V -4111 0i-' A1) W i i V m o o q _ > ii Yurgnj 110. 1Eff ' o a l M a ___ Lai' Y .. ® C Y B,.,• o H m • 1 V V h • Y %V, c an C. Z V a j V 2 Q a m K 1 a: 7 - O NQ .. Y Ot C a_,‹: H I • W J H E H ���` •_ 7 Y�J .. 0 m z 'Sal- 7 Q L.9 2 YS[ 9N}Z P 21 YLm Z Y W J w w l E V 1- ,.,) 1- F *E —{ — F a�� c �..1a o z— Y 3 23..< • • 13 _ , 0 0 Iii _› 0 / > a2 0 cci 6 U _ ca / >% o 0 2 ca $22 §m « � E a • c O 7 = C/) O 0 std 7 % I O.- \ \ < >' ,_ .- 7 L- D 2 / / a � J ci k / � � • eMI % .e ■ ■ \ C k k O ct Co / W ± / o CD 2 Q = k o C\ m e p � o ■ co L§ 0 O 0 2)— I- \ -00 -o - _f12 � S %f 2 0 E % & = 3 m O 2 / 'K o / / 'a;a. lc k / g CaaaB .r § ƒ 2 2 \ ^ ) 2 3 > ) > 0 2 co o § � k o CL a) � co . C0 k CC ƒ j k 0 0. Q R % t a E o cA c ca � � x � � ® co x u) ._ 0 § 2 x .§ / e 15 7 oc.e / 2ii: oo T k 2 g > a 2 f o a) 2 f 0 co Cl) 2 k 9 & STATE OF ALASKA ALL OIL AND GAS CONSERVATION COM SION r REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate Li Pull Tubing U Operations shutdown U Performed: Suspend 1 Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑✓ Plug for Redrill ❑ Brforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2. Name: 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 198-115 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22894-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028231 MILNE PT UNIT SB E-21 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL JAN 19 2016 11.Present Well Condition Summary: AOGCC Total Depth measured 5,990 feet Plugs measured N/A feet true vertical 4,784 feet Junk measured N/A feet Effective Depth measured 5,866 feet Packer measured N/A feet true vertical 4,702 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 150' 13-3/8" 150' 150' 1,661psi 5,380psi Surface 5,961' 5-1/2" 5,961' 4,765' 4,810psi 4,040psi Perforation depth Measured depth See Attached Schematic ����►►����� FEB2 True Vertical depth See Attached Schematic 11 ED FEB 2 2016 Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/J-55/8rd EUE 5,421' 4,417' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure • Prior to well operation: 0 0 0 40 0 Subsequent to operation: 0 0 0 40 0 14.Attachments(required per 20 MC 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 Q Gas [J WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑✓ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-512,315-651,315-690&315-702 r ICContact Ted Kramer / Email tkramer(a�hilcorp.com Printed Name Bo York Title Operations Engineer Signature OP, Phone 777-8345 Date 1/18/2016 )1;0 :%%/G4. RBDMS c._ JAN 2 1 2016 Form 10-404 Revised 5/2015 Submit Original Only H . • Milne Point Unit Well: MPU E-21 • r SCHEMATIC Last Completed: 9/13/1998 lhk, i,Alaska,LLC PTD: 198-115 TREE&WELLHEAD Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E)j , Tree 2-1/16"5M +� Wellhead 7"SM Varco ADRS-7 Weld on style ti, 71., ; Tubing Hanger NSCTT&B 2"CIW H BPV Profile tit 7)(55 OPEN HOLE/CEMENT DETAIL 13-3/8" 0 Ater @ 13 3/8" 250 sx Arcticset 19Approx)in a 16"Hole i Heat Trace/ 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole t/ $ 1 '' ESP Cable NOTE:Performed Top Job with AOGCC Approval—100sx Coldset III a�1 t Job , .. Topa 150' 8/30'1998 , s, CASING DETAIL i. ! Size Type Wt/Grade/Conn Drift ID Top Btm BPF F T 10'Y 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 0.148 '%y 2 e 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' 0.0383 ? ' 5.5" Production 15.5/J-55/BTC-MOD 6.151 38' 5,961' 0.0238 TUBING DETAIL * 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.995 547' 5,421' 0.00387 WELL INCLINATION DETAIL , KOP @ 550' Max Hole Angle=58 deg. @ 4,081' It; 1 Hole Angle thru perfs=50 deg. ' 0yy,, TOG JEWELRY DETAIL r k }� 3,112' I, 2 No Depth Item ,a. Heat Trace Btm 1 547' Jet Cut 2-3/8"Tubing ° ©141507 2 2,008' S.5"Port Collar Cementer Tubing Punch i' % 3 5,322' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" ***No Valve Installed*** 4,823'-4,828 6/15/15 4 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 5 5,361' KUDU PCP,100TP1800—Intake ND @ 4,395' 6 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 5.5"BTC Mater 7 5,408' CentriliftFMH1-54hp/1,020V/35amp Joint: 8 5,419' Centrilift PHD—Bottom @ 5,421' 5,071'—5,111' ' PERFORATION DETAIL "e "* Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 1. 3 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open I 4 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open STIMULATION DETAIL 5 'OA'/'OB'121,840 lbs Proplok 16/30 Badger �„ behind pipe on all three perforated intervals 6 GENERAL WELL INFO API:50-029-22894-00-00 +' Drilled and Cased by Nabors 27E -9/1/1998 r At tx 7 Initial Completion by Nabors 4ES—9/13/1998 0 8 t Fish:90e.7/8"1.3 ,- `-' Schrader Sands SG Ball Sealers. }F �` TGFy CalwIateded4 5.5"t' P314" TD=5,990'(MD)/TD=4,784'(TVD) PBTD=5,876'(MD)/PBTD=47,708'(TVD) Created By:TDF 1/15/2016 • • •r Hilcorp Alaska, LLC 4,04 Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-21 ASR#1 50-029-22894-00-00 198-115 6/21/15 11/12/16 Daily Operations: 11/4/2015 Wednesday Rig move from MPU-G-08A TO MPU-E-21 remove tree, install BOP and change pipe rams from 2-7/8 x 5 VBR to 2-3/8, pipe rams, install well house MIRU raise derrick, spot rig pipe handler rig tongs, rig up Koomy lines to BOP stack, rig up pumping &thawing boiler wrapping lines, winterize rig. Well head rep remove BPV install TWC in hanger.Test BOPs as per AOGCC requirements, test all rams and valves to 250psi low pressure and 3,000 psi high pressure. Witness to test was waived by AOGCC Matthew Herrera. 11/5/2015 -Thursday Continue to Test BOPS as per AOGCC requirements,test all rams and valves to 250psi low pressure and 3000 psi high _ pressure. Test H2S & methane gas alarms. Witness to test was waived by AOGCC Matthew Herrera. Pull TWC with well head rep. Circulate down tubing 1 tubing volume, taking returns to flow back tank. Make up 2-3/8" landing joint, attempt to pull tubing hanger, worked string at 58k at 80%of tensile of tubing, bullheaded 20 bbls down backside at 2 bpm at 65 psi, continue to work string at 72k at 100%tensile strength. Bullhead additional 30 bbls down backside at 4 bpm at 125psi continue to work string at 72k. Working pipe, worked pipe up hole 7 ft unable to land hanger, continue working 2-3/8" Tubing @ 72k. 11/6/2015- Friday Continue to work stuck tubing string, bullhead 30 bbls of sea water down backside @ 4 bpm 15 psi, continue to work string up & down, no movement, bullhead additional 50 bbls down backside 4 bpm @ 150 psi, continue to work string with no movement. Slack off weight, break out landing joint and install pups to space out to the rig floor for cement job and wire line work. Maintain rig, work on safety audit. r 11/7/2015 -Saturday R� Maintain rig &work on safety audit. Perform injection rate down tubing with sea water, 1 BPM @ 140psi, 2 BPM @ 400psi, t. 3 BPM @ 900psi. Rig up pumping services. PJSM with Hilcorp rep, rig crew& pumping services. Pump 5 bbls of fresh water, pressure test surface hard lines to 250psi low/3,500psi high pressure. Pump 30 Bbls of 15.8 PPG cement down 2-3/8"_ L' tubing @ 3 BPM @ 540psi, displace with 13 bbls of fresh water down tubing,final pressure at 858psi. Cement in place at (,0/3 11:30 AM 11-7-15. Rig down cementers. Wait on cement. Fill back side with sea water was unable to keep hole full, closed annular preceeded to perform injection rate test 4 bpm @ 215psi with 15 bbl pumped away R/U o bg pumped 1 bbl away. Pressured up to 500 bleed off. Maintain rig work on safety audits. (�,,� ��4,, 11/8/2015 -Sunday Rig up pumping services. PJSM with company rep, rig crew and cement pumping crew. Pump 3 bbl of fresh water, test hard lines to 3,500 psi, pump 30 bbl of 15.8 ppg cement down backside 5-1/2" x 2-3/8" @ 2 bpm @ 190 psi,displace with 15 bbl of fresh water followed by 70 bbl of seawater 3 bpm @ 170psi cement in place at 11:30 AM 11-8-15. Wait on cement, maintain rig. Service engines, work on safety audit. Fill BOPs stack with 1 bbl. Static level dropping in well bore, closed 1 annular conduct injection rate of 4 BPM @ 300psi with 15 BBL pumped away R/U on tbg.Test tbg to 1,500psi for 30 min bleed tbg off, blow down lines. cipelk CAP ?e F l • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-21 ASR#1 50-029-22894-00-00 198-115 6/21/15 11/12/16 Daily Operations: 11/9/2015- Monday Maintain rig. Wait on pumping services to arrive. R/U cementers, PJSM with Cement Crew.Truck drivers, rig crew, Hilcorp Co-Man, pumped 5 bbl fresh water 5 bpm ahead fill lines, pressure test lines 500/4,500psi 5 min each. Mix& pump 15 bbl mud push II withl0 lb/bbl CemNet Plus @ 10 ppg 3bpm @ 183psi. Mix &pum_p 50 bbl of 15.6 ppg Class G cement with 2 Ib/bbl CemNet Plus 5bpm @ 521psi displacement 60 bbl sea water 3bpm @ 250psi. Maintain rig, work on BOP drill procedures and safety audits. Fill back side up into the BOP stack closed annular, conduct casing test 2bpm @ 200psi with 10 bbl pumped away. Maintain rig, work on BOP drill procedures and safety audits. 11/10/2015 -Tuesday Rig up slick line with lubricator and test. Attempt to TIH with 1.75" bailer, had obstruction in tubing hanger, make up and run in the hole with 1.5" Bull nose to 3,112', top of cement in tubing. Attempt to swage out obstruction in tubing hanger pup. Run a 1.69" full body bull nose swage on wire line through tight spot in tbg at 18ft. WLM worked tight spot in tbg 30 times pulling up and down freely 2 ft behind first swage is a 1.75" flutted swage working it through tight spot at 18 ft.After working through tigh spot with many attempts up and down, continued running down hole to 600 ft with 1.75" flutted swage and 1.69" full body swage POOH. Rehead wire line for jet cutter run. RIH with jet cutter to 18 ft. WLM. Unable to get cutter through tight spot at 18 ft. POOH. Rig down wire line tools and equipment on pipe handler. P/U run in hole with a 1.87" mill and 1.85" xo sub on 1.25" CS Hydrill pipe willed up tight spot from 14 ft to17 ft. Worked through tight spot rotate freely, ran full joint down to 30 ft ASR RKB 100 lbs WOB 65 rpm torque limit set at min of 600 ft/lbs. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-21 ASR#1 50-029-22894-00-00 198-115 6/21/15 11/12/16 Daily Operations: 11/11/2015 -Wednesday Lay down mill & 1.6" pipe and prepare for wire line. Rig up slick line with lubricator. Make up & run in the hole to 600' with 1.87' drift, no problems, trip out. Make up and trip in the hole with 1.69" tubing_jet cutter, log in to place, make cut @ 547' trip out with cutter. Latch on to tubing, pull tubing free, pull tubing hanger to rig floor& lay down. Rig down wire line service.Trip out of the hole, laid down 3 joints, pipe became stuck on 4thjoint, work pipe free, continued to trip out, ESP cable and heat trace cable and guards were stripped out. Lay down cut joint. Make up 4.825" flat bottom mill & attempt to trip in hole, tagged up just below the wellhead. Conduct injection rate of 4 bbl @ 480 psi with 25 bbls pumped away, run joint pipe down into the well bore stacked out @ 24 ft. Pooh lay down, P/U tbg hanger RIH, unable to set hanger and RILDS do to obstruction in hole, POOH. Broke off 4 ft pup joint below hanger. Run back in the hole, land tbg hanger in well head RILDS. Wellhead rep P/U 4.5 LIB ran into the hole stacked out at 24 ft set 2,000 lbs. Maintain rig, work on top drive hydraulics. 11/12/2015-Thursday Maintain Rig. Rig up for BOP test, install test plug, make up test joints. Test BOPs as per AOGCC requirements, test all rams and valves to 250psi low/3,000 psi high pressure.Test H2s & methane gas alarms. Witness to test was waived by AOGCC Guy Cook. Pull test plug & rig down test equipment. Install 11" x 7" Otis tree cap on top of BOP. Close Blind rams and lock in. Prep rig for move, lower derrick move from MPE-21 to A-PAD clear& clean location. 11/13/2015 - Friday No activity to report. 11/14/2015 -Saturday No activity to report. 11/15/2015 -Sunday No activity to report. 11/16/2015 - Monday No activity to report. 11/17/2015 -Tuesday No activity to report. L of T�g ' • • 4,w„\ 1%% s\ THE STATE Alaska Oil and Gas .7 011W, of ASKA Conservation Commission 333 West Seventh Avenue 9 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1104Z, Main: 907.279.1433 of ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York ici#00 NOV 2 4 2. Operations Manager t Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-21 Sundry Number: 315-702 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 Pi Foerster Chair DATED this /7 day of November, 2015 Encl. 70� Sc 03 0 • • v URC STATE OF ALASKA NOV 1 3 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 071 odl ift(!S APPLICATION FOR SUNDRY APPROVALS A nn(`r` 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑✓ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska, LLC • Exploratory ❑ Development ❑✓ . 198-115 • McAJo,3aAli: 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK,99503 50-029-22894-00-00 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 SB E-21 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0028231 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): 5,990 - 4,784 - 5,866 ' 4,702 646 N/A 38' Casing Length Size MD TVD Burst Collapse Structural Conductor 150 13-3/8" 150' 150' 1,661 psi 5,380 psi Surface 5961 5-1/2" 5,961' 4,765' 4,810 psi 4,040 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic , See Attached Schematic 2-3/8" 4.7#/J-55/8RD EUE 5,421' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑� Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 171. Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 11/12/2015 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: 11/12/2015 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola Email Sporhola@hilcorp.com Printed Name Title Bo York Operations Manager Signature .2------ Phone Date / G 907-777-8435 )' i.--- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 --io2 Plug Integrity ❑ nBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ] ❑ ,n Other: CLn cxr y L...- �^tic /`e, c �^.z. ' k e-fir i^2._ ct,S,1..ti v_,` /'1. ) j ry e.i-c.i��e cn3'. ,J you 1 2415 Post Initial Injection MIT Req'd? Yes ❑ No ❑ . , Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: 10.-.ij/o -� 10°14S APPROVED BY Approved by: P9;2...e_t„,4_____ COMMISSIONER THE COMMISSION Date: !�— �— S /(15 0R4,64INA12c1 Submn Form ane Form 10-403 Re ed 11/2015 for 12 months fro the date Of�r04f---- Atta chments in Duplicate . • • Well Prognosis Well: MPU E-21 Hilrurp Alaska,LL Date:11/12/2015 Well Name: MPU E-21 API Number: 50-029-22894-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: November 12th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 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: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Max. Predicted Surf Pressure: 646 psi (Based on offset E-32 on 11/16/14 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU E-21 has had 547' of tubing pulled but the bands/flatguard/cable/heat trace are still in the well and the rig is tagging up at 38' RKB (at the bottom of the 7" x 5-1/2"XO). Will not be able to fish out the tubing, ESP cable, and heat trace cable and bands/flatguard with the ASR rig. Notes Regarding Wellbore Condition • 5.5" 15.5#casing cemented to surface; performed top job from 135'to surface on 8/30/1998. • Casing last tested to 3,500 psi for 30 min down to 5,876' on 8/30/1998. • Maximum hole angle is 58° @ 4,081' MD. • Cement inside tubing tagged at 3,112' MD and pressure tested to 1,500 psi. Obiective: The purpose of this work is to move off the ASR rig and leave the well in a condition to attempt to fish out the lost bands/flatguard/cable/heat trace to prep the well for abandonment. Brief Procedure: WO Rig Procedure: 1. Test BOPE to 250 psi Low/3,000 psi High,annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test(notice already sent). b. Test pipe rams on 2-3/8"test joint. 2. Close and lock blind rams. 3. Clean and clear rig floor. Flush all surface lines. 4. RD ASR 1. �� �� � f 5. NU 7"Valve and Tree Cap on top of BOPE. `��-""' 6. RU Wireline. PT lubricator to 1,500 psi. 7. Open blind rams. J--8 Fish ou .. ds/flat_uard cable heat - - depth of+/- 150' RKB. 9. Pending results of fishing, submit additional sundry procedure for abandonment. 111 • • Well Prognosis Well: MPU E-21 xac°")Alaska,LL Date: 11/12/2015 Attachments: 1. Current Schematic 2. Wellhead/BOPE Schematic H . • Milne Point Unit , 11 Well: MPU E-21 SCHEMATIC Last Completed: 9/13/1998 Hilcorp Alaska,LLC PTD: 198-115 CASING DETAIL Orig.DF Elev.:55.9/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm L'll'; 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 7" Prod X-Over 26/L-80/BTC MOD 6.276 Surface 38' t. 5.5" Production 15.5/J-55/BTC-MOD 6.151 38' 5,961' "' yyTx5.5"X 13-3/8' O�er@38 TUBING DETAIL 2-3/8" Tubing 4.7/1-55/EUE 8rd 1.995 547' 5,421' Top Job •' 1 i Fis•c 38' JEWELRY DETAIL y830/1 1 Flaty,d No Depth Item ESP Cable 1 547' Jet Cut 2-3/8"Tubing HeatTrace 2 2,008' 5.5"Port Collar Cementer 3 3,500' Centrilift Heat Trace Bottom L142 4 5,322' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" ***No Valve Installed*** R 5 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 6 5,361' KUDU PCP,100TP1800-Intake ND @ 4,395' k kz. ?' ?'' 7 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 Vij t. 8 5,408' Centrilift FMH1-54hp/1,020V/35amp 14 1 9 5,419' Centrilift PHD-Bottom @ 5,421' 3 PERFORATION DETAIL TOC Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 3,112 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open Tubing Rinch OPEN HOLE/CEMENT DETAIL 4,823-4,8285 11 # 13-3/8" 250 sx Arcticset I 9Approx)in a 16"Hole 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III 14 5.5 BTC Marker WELL INCLINATION DETAIL .Joint: 5,071'-5,111' i" KOP @ 550' Max Hole Angle=58 deg. @ 4,081' i Hole Angle thru perfs=50 deg. 4 u" # 5 TREE&WELLHEAD .1 Tree 2-1/16"5M Wellhead 7"SM Varco ADRS-7 Weld on style 6 Tubing Hanger NSCTT&B 2"CIW H BPV Profile STIMULATION DETAIL 'OA'/'OB'121,840 lbs Proplok 16/30 Badger 7 behind pipe on all three perforated intervals 8 GENERAL WELL INFO API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 ito Initial Completion by Nabors 4ES-9/13/1998 9 Fish:90ea 7/8"1.3 4}Schrader Sands SG Ball Sealers. TOF©5,865 Calculated 5.5" TD=5,990'(MD)/1D=4,784'(1VD) PBTD=5,876'(MD)/PBTD r47,708'(TVD) Created By:STP 11/12/2015 ‘ ut • • PROPOSED TREE/WELLHEADWel -21 lhead/T ee }blear')Alaska,LLCMilne Point Unit Tree Cap ..e It. r__ : . Tree Valve 7-1/16" 5M ------�I 0 \c, / DSA, 11 5MX71/165M f MI NMI p Shaffer N11" - 500Q iii liMii Ail iiMil III III III III III H (: W—U i H 2 3/8 Pipe 1 1"- 000 ' ' '� H Blind • \ 0 / 2 1/16 5M Kill Line III III III III III 2 1/16 5M Choke Line Valves Valves I. 111111111111111"111t i s o Ili:0 t - '}' i II V ' .11 i i III.IiLIILIILI/I'! ,i Manual Manual Manual HCR _e_:._ DSA, 11 5M X 7 1/16 5M --•sTi ._- 111 7-1/16" 5M Top x ■ill Vb'i' ' 7-1/16" 5M Btm A Casing Valve 2-1/16" 5M Conductor, 7" • tj Well Prognosis '/ Well: MPU E-21 Hilrorp Alaska,r.r, 471 e f t Date: 11/12/2015 Well Name: MPU E-21 API Number: 50-029-22894-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: November 12th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 First Call Engineer: Stan Porhola (907)777-8412 (0) 31-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,046 psi @ 4,000'TVD (Based on offset E-32 measured on 11/16/14) Max. Predicted Surf Pressure: 646 psi (Based on offset E-32 on 11/16/14 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000'ND of oil cap) Brief Well Summary: MPU E-21 has had 547' of tubing pulled but the bands/flatguard/cable/heat trace are still in the well and the rig is tagging up at 38' RKB(at the bottom of the 7"x 5-1/2"XO). Will not be able to fish out the tubing, ESP cable,and heat trace cable and bands/flatguard with the ASR rig. Notes Regarding Wellbore Condition S • 5.5" 15.5#casing cemented to surface; performed top job from 135'to surface on 8/30/1998. • Casing last tested to 3,500 psi for 30 min down to 5,876'on 8/30/1998. • Maximum hole angle is 58° @ 4,081' MD. • Cement inside tubing tagged at 3,112' MD and pressure tested to 1,500 psi. Objective: The purpose of this work is to move off the ASR rig and leave the well in a condition to attempt to fish out the lost bands/flatguard/cable/heat trace to prep the well for abandonment. Brief Procedure: SCANNED MAY 1 1. 2016 WO Rig Procedure: 1. Test BOPE to 250 psi Low/3,000 psi High,annular to 250 psi Low/2,500 psi High(hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test(notice already sent). b. Test pipe rams on 2-3/8"test joint. 2. Close and lock blind rams. 3. Clean and clear rig floor. Flush all surface lines. 4. RD ASR 1. 5. NU 7"Valve and Tree Cap on top of BOPE. 6. RU Wireline. PT lubricator to 1,500 psi. 7. Open blind rams. 8. Fish out bands/flatguard/cable/heat trace to depth of+/- 150' RKB. 9. Pending results of fishing, submit additional sundry procedure for abandonment. . 11 • • Well Prognosis Well: MPU E-21 11114In p kla-Lt I I Date: 11/12/2015 Attachments: 1. Current Schematic 2. Wellhead/BOPE Schematic Milne . . 40 WellPoint : MPU E-21Unit H . SCHEMATIC Last Completed: 9/13/1998 PTD: 198-115 Hileora Alaska,LLC CASING DETAIL Orig.DF Elev.:55.9/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm i ' ` 4 13 3/8" Conductor 72/L-80/N/A 12.191 Surface 150' 7" Prod X-Over 26/L-80/BTCMOD 6.276 Surface 38' .> 5.5" Production 15.5/J-55/BTC-MOD 6.151 38' 5,961' Tx5.5'X TUBING DETAIL 38 13-3/8" 4 .'Cver@ 2-3/8" Tubing 4.7/1-55/EUE 8rd 1.995 547' 5,421' Tap Jab 1 Fish @ JEWELRY DETAIL 0-135 Bards No Depth Item 8,3111996 Flatguad • ESP Cade 1 547' Jet Cut 2-3/8"Tubing ', ' Heat Trace .°a 2 2,008' 5.5"Port Collar Cementer 3 3,500' Centrilift Heat Trace Bottom i- •}2 C2 -3/8"co HES 2-3/8"XN-Nipple:x 1"SidepocketID=1.875KBM" M GLM:=1.ID=7911.945" " 4 5,322' ***No Valve Installed*** v 5 5,348' /No Go 6 5,361' KURU PCP,100TP1800-Intake TVD @ 4,395' 7 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 '' r' 8 5,408' Centrilift FMH1-54hp/1,020V/35amp .r i 9 5,419' Centrilift PHD-Bottom @ 5,421' 3 PERFORATION DETAIL '; Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status . TOC 3,112' 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 1 ro . * 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open Tubing Punch y OPEN HOLE/CEMENT DETAIL 4,8234828' 1 6/15/15 , 13 3/8" 250 sx Arcticset I 9Approx)in a 16"Hole { 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole `' NO IL:Performed Top Job with AOGCC Approval-100sx Coldset III 5s BIC Marker i,, 'Joirt WELL INCLINATION DETAIL 5,071'-5,111' KOP @ 550' 0 r' Max Hole Angle=58 deg. @ 4,081' Hole Angle thru perfs=50 deg. 4 TREE&WELLHEAD ' Tree 2-1/16"SM I ,, Wellhead 7"5M Varco ADRS-7 Weld on style .+ 6 Tubing Hanger NSCT T&B 2"CIW H BPV Profile a 1.0 .' STIMULATION DETAIL til t 'OA'/'OB'121,840 lbs Proplok 16/30 Badger ' ' behind pipe on all three perforated intervals GENERAL WELL INFO ` 8 API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 ,• ), Initial Completion by Nabors 4ES-9/13/1998 • 9 ,`a r : 1 {, Fish*90ea.7/6"1.3 Schrader Sands SG BaII Seaters. ' TCF @5,8E6' `. - Calculated __" - 5.5".a.'at '.,4 . u 1U=5,990'(M))/1D=4,784TIVD) PBTD=5,876'(ND)/PBTD=47,708'(TVD) Created By:STP 11/12/2015 . ‘ ‘ll • . PROPOSED TREE/WELLHEAD MPU E-21 Wellhead/Tree Milne Point Unit Hilcorp Alaska,LLC Tree Cap vi,171,1 L Tree Valve 7-1/16" 5M r p / DSA, 11 5M X 7 1/16 5M \ / '0 o s ti N ffll f�1flft / CU 1 L-J lima CIW-U H 2 3/8 Pipe H p N 11"- 000 'BJ H Blind �I Itt 2 1/16 5M Kill Line 2 1/16 5M Choke Line Valves Valves H Manual Manual Manual HCR I DSA, 11 5M X 7 1/16 5M iii K ■1 -- 1 I Casing Head ��ill`1 ;,o 7-1/16" 5M Top x a 1_�° 7-1/16" 5M Btm Casing Valve 2-1/16" 5M Conductor, 7" 9 OF rt. • • y9.*\ 1%% tv THE STATE Alaska Oil and Gas o �'►�--a� f L A S KA Conservation Commission Witt �= 333 West Seventh Avenue � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF *:h Q, Main: 907.279.1433 ,ALAS* Fax: 907.276.7542 SB ®�©i99���� N a i- �4° www.aogcc.alaska.gov Sems* Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-21 Sundry Number: 315-690 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter,or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this /2 day of November, 2015 Encl. !MOM S 1���' ° 131 015 • • RECEIVED STATE OF ALASKA ^Ie1vA0 9niF ALASKA OIL AND GAS CONSERVATION COMMISSION 1)c -- ,ti I -4-11 5 APPLICATION FOR SUNDRY APPROVALS A;O CG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Q Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska, LLC • Exploratory ❑ Development El, 198-115 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ElService L--] 6.API Number. Anchorage,AK,99503 50-029-22894-00-00• 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 SB E-21 9.Property Designation(Lease Number): 10.Field/Pool(s): r ADL0028231 - 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): • 5,990 - 4,784 5,866 • 4,702 260 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 150 13-3/8" 150' 150' 1,661 psi 5,380 psi Surface 5961 5-1/2" 5,961' 4,765' 4,810 psi 4,040 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic J See Attached Schematic 2-3/8" 4.7#/J-55/8RD EUE 5,421' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A 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: 11/6/2015 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended CI- 16.Verbal Approval: Date: 11/6/2015 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola Email Sporhola@hilcorp,com Printed Name Title Bo York Operations Manager Signature Phone Date .. 907-777-8435 `1 hip j r i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3] 6----_,to9D Plug Integrity IYI BOP Test &i.r Mechanical Integrity Test ❑ Location Clearance ❑ Other. 2 O d dl S. ao �--1- C A Y = 2-6 d ,US,' /o< docc.,,,,,,,,,,- r✓acs;_) Ce-,,F _7.1 w.4_14 I rd Post Initial Injection MIT Req'd? Yes ❑ No ❑ v13 �Q\'JSpacing Exception Required? Yes ❑ No Subsequent Form Required: /0-- D D�Oc RB / APPROVED BY Approved by: J COMMISSIONER THE COMMISSION Date:; _JJ��11 ,,// I If- I2-ls" 0 J T f /pp `k(' t L� Submit Form and Form 10-403 R/47 e11/2015R4091pNa , i valid for 12 months from the date of a rf // .gttac/ent Duplicate • • Well Prognosis Well: MPU E-21 Hilcorp Alaska,LL) Date: 11/06/2015 Well Name: MPU E-21 API Number: 50-029-22894-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: November 6th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 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: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Max. Allowable Surf Pressure: 260 psi (Based on offset E-32 on 11/16/14 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU E-21 has stuck tubing string (unknown cause). Will not be able to fish out the tubing, ESP cable, and heat trace cable and bands/flatguard. Notes Regarding Wellbore Condition • 5.5" 15.5#casing cemented to surface; performed top job from 135' to surface on 8/30/1998. • Casing last tested to 3,500 psi for 30 min down to 5,876' on 8/30/1998. • Maximum hole angle is 58° @ 4,081' MD. • Schrader Bluff interval to be open to injection is 5,359' MD to 5,644' MD (4,378'TVD to 4,557'TVD). • Unknown obstruction causing stuck pipe (fill/collapsed casing). Objective: The purpose of this work/sundry is to abandon the stuck ESP. Brief Procedure: WO Rig Procedure: 1. MIRU cementers. RU and PT Lines to 3,500 psi. 2. Mix and pump 30 bbl of 15.8 ppg cement down the tubing. a. Displace tubing with 8.5 ppg seawater(-13 bbl)to leave 5 bbl in the tubing and squeeze 25 bbl thru the punch holes to fill the wellbore down to PBTD (Capacity below punch holes= 25 bbl). 3. Wait on cement 6 hrs. `� yT (5-11v s f 4. RU Wireline. Tag cement inside tbing. Confirm cement top is above th tubing punch holes at 4,823'. 5. RIH w/jet cutter and make jet cut at+/- 200'. Make 2"d cut at+/-200' to cut ESP/Heat Trace cables. 6. PU to confirm tubing is free. If pipe is free, RD Wireline. Otherwise, make additional cuts. 7. MU bridge plug on tubing and RIH and set at+/- 150'. 8. Mix and pump 6 bbl of 15.6 ppg Permafrost Cement and circulate cement to surface (Capacity= 5.3 bbl). 9. POOH. Lay down tubing. • • • Well Prognosis Well: MPU E-21 ua „„:ti.v,ka,i,i; Date: 11/06/2015 10. Clean and clear rig floor. Flush all surface lines. 11. RD ASR 1. 12. ND BOPE. NU Dry Hole Tree. Surface Procedure: 13. Confirm cement to surface.Top off cement as needed. 14. Excavate cellar,cut off wellhead and casing 3' below natural GL. 15. Set marker plate, collect GPS coordinates. 16. Backfill cellar, close out location. to et, -�- Attachments: 1. Proposed Schematic H . • Milne Point Unit Well: MPU E-21 PROPOSED ABAN DON M ENT Last Completed: Proposed Hilcorp Alaska,LLC PTD: 198-115 CASING DETAIL Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm ;x 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' * r 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' Sk. * ,' 5.5" Production 15.5/1-55/BTC-MOD 6.151 38' 5,961' 7, 7'x5.5'X 3/8 * 1 rover@38' TUBING DETAIL 13- ” 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.995 Surface 5,421' Top Job '' `'. JEWELRY DETAIL + e I. '8r30a1sae No Depth Item- 1 150' CIBP r •" 2 2,008' 5.5"Port Collar Cementer a 3 0 3 3,500' Centrilift Heat Trace Bottom ( 2 Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" 4 5,322' ***Ni Valve Installed*** '. 5 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 6 5,361' KUDU PCP,100TP1800-Intake ND @ 4,395' i' v. 7 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 t 8 5,408' Centrilift FMH1-54hp/1,020V/35amp a1 9 5,419' Centrilift PHD-Bottom @ 5,421' 3 PERFORATION DETAIL Y to, Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status , 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open Tubing Punch OPEN HOLE/CEMENT DETAIL 4'8 -4' 13-3/8" 250 sx Arcticset I 9A 6/1515 �y pprox)in a 16"Hole 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole NOTE:Performed Top lob with AOGCC Approval-100sx Coldset III 5.5 BTC Marker .: WELL INCLINATION DETAIL Joint: 5,071'-5,111' KOP @ 550' Max Hole Angle=58 deg. @ 4,081' Hole Angle thru perfs=50 deg. 4 5 TREE&WELLHEAD 1' Tree 2-1/16"5M Wellhead 7"5M Varco ADRS-7 Weld on style 6 Tubing Hanger NSCTT&B 2"CIW H BPV Profile STIMULATION DETAIL 'OA'/'OB'121,840 lbs Proplok 16/30 Badger behind pipe on all three perforated intervals GENERAL WELL INFO .. 8 API:50-029-22894-00-00 ,, Drilled and Cased by Nabors 27E -9/1/1998 Initial Completion by Nabors 4ES-9/13/1998 9 • Fish:90ea 7/8"1.3 Sdrader Sands SG Ball Sealers. TDF @5,866 Calculated ,: 5.5"•• .,1.,,'..111° TD=5,990'(MD)/TD=4,784'(TVD) PBTD=5,876'(MD)/PBTD=47,7081TVD) Created By:STP 11/06/2015 i Stan Porhola From: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Sent: Monday, November 09, 2015 10:27 AM To: Stan Porhola Cc: Donald Haberthur - (C); Craig Smith - (C); Tom Fouts; Bo York Subject: RE: *URGENT* MPU E-21 (PTD 198-115, Sundry 315-651) Change of Plans to P&A - Verbal Approval Request Stan, Agree with your plan forward to attempt another cement sqz on the IA. You have verbal approval to proceed as proposed below. Still need the sundry to P&A(suspend) over at AOGCC as soon as possible. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola©hilcorp.com] Sent: Monday, November 09, 2015 9:08 AM To: Schwartz, Guy L (DOA) Cc: Donald Haberthur - (C); Craig Smith - (C); Tom Fouts; Bo York Subject: RE: *URGENT* MPU E-21 (PTD 198-115, Sundry 315-651) Change of Plans to P&A - Verbal Approval Request Guy, After performing our initial cement job on MPU E-21,we waited on cement and pressure tested the tubing x casing annulus and it pumped away. We did a brief test on the tubing to 500 psi and it held. We pumped a second 30 bbl of cement down the tubing x casing annulus and waited on cement.Attempted a test and it pumped away. We tested the tubing to 1,500 psi for 30 minutes and it held rock solid, so the tubing punch holes and tubing are isolated from the annulus and formation. At this point, we are proposing the following: 1.) Mix and pump 50 bbl of cement down the tubing x casing annulus(total annular capacity is 110 bbl to PBTD). This cement will have some CemNet (lost circulation material fibers)to help bridge off inside the formation. Displace with 60 bbl of seawater. Wait on cement 8 hours. 2.) If this cement does pressure test,continue with plan as previously submitted. 3.) If this cement does not pressure test,the plan would be to go in and cut the tubing at+1-500', pull the tubing, ESP, and heat trace cable. 4.) PU a cement retainer. Set at+1-450'.Test retainer and casing to surface to 1,500 psi for 15 min (confirm plug and casing integrity). 1 • 5.) Mix and pump 65 bbl of 15.6 ppg lead cement (Class G) and 35 bbl of 15.6 ppg tail cement(Permafrost Blend) below retainer(CAP = 100 bbl). 6.) PU above retainer, mix and pump 20 bbl of 15.6 cement(Permafrost Blend),circulating cement to surface (CAP = 11 bbl). a. If plug or casing above the retainer does not pass,this may alter the amount of cement for the surface plug. 7.) Follow remaining steps of previous procedure. Can we get verbal approval to proceed? Do you want to include this on the 10-403 hard copy we have prepared for the previous verbal? Stan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, November 06, 2015 2:43 PM To: Stan Porhola Cc: Donald Haberthur - (C); Craig Smith - (C); Tom Fouts; Bo York Subject: RE: *URGENT* MPU E-21 (PTD 198-115, Sundry 315-651) Change of Plans to P&A - Verbal Approval Request Stan, Have reviewed your proposed plan to P &A/suspend well E-21. At step 4 add a pressure test to 1500 psi for both tubing and the tubing x casing annulus after pumping the lower cement plug. With your sundry submittal the request will be for a suspension of the well (Vs Abandon)as the final wellhead cut off will be done at a later date. You have verbal approval to proceed with the your proposed plan with the above modifications . Submit a hardcopy sundry as soon as possible. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Friday, November 06, 2015 2:04 PM To: Schwartz, Guy L (DOA) Cc: Donald Haberthur - (C); Craig Smith - (C); Tom Fouts; Bo York Subject: *URGENT* MPU E-21 (PTD 198-115, Sundry 315-651) Change of Plans to P&A - Verbal Approval Request Guy, We are unable to pull the ESP on MPU E-21 (PTD 198-115, Sundry 315-651). It is unknown if it is fill or collapsed casing in this well. We are able to freely circulate down the well.The rig is currently continuing to pull the pipe with little to no movement at this time. 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, November 12, 2015 10:46 AM To: 'Stan Porhola' Cc: Bo York; Donald Haberthur- (C); Craig Smith - (C);Alaska NS - Milne - Field Foreman Subject: RE: MPU E-21 (PTD 198-115) change of plans Stan, You have approval to proceed as proposed by moving out ASR1 and moving in SL/CTU to fish junk on top of tubing stub at 500 ft. Based on fishing results a new sundry may be required to move forward with the P &A of E-21 or at least a MOC approval process to capture major changes. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@lhilcorD.com] Sent: Thursday, November 12, 2015 9:53 AM To: Schwartz, Guy L(DOA) Cc: Bo York; Donald Haberthur- (C); Craig Smith - (C); Alaska NS - Milne - Field Foreman Subject: MPU E-21 (PTD 198-115) change of plans Guy, Per our conversation, see attached for the proposed plan forward on MPU E-21 (PTD 198-115). Let me know if we can proceed.The ASR rig is due a weekly BOPE test today. Regards, Stan Porhola I Operations Engineer North Slope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 06, 2015 2:43 PM To: 'Stan Porhola' Cc: Donald Haberthur - (C); Craig Smith - (C);Tom Fouts; Bo York Subject: RE: *URGENT* MPU E-21 (PTD 198-115, Sundry 315-651) Change of Plans to P&A - Verbal Approval Request Stan, Have reviewed your proposed plan to P&A/suspend well E-21. At step 4 add a pressure test to 1500 psi for both tubing and the tubing x casing annulus after pumping the lower cement plug. With your sundry submittal the request will be for a suspension of the well (Vs Abandon)as the final wellhead cut off will be done at a later date. You have verbal approval to proceed with the your proposed plan with the above modifications . Submit a hardcopy sundry as soon as possible. Regards, Guy Schwartz Sr. Petroleum Engineer SCANNED JUN 0 3 2016 AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.cor Sent: Friday, November 06, 2015 2:04 PM To: Schwartz, Guy L(DOA) Cc: Donald Haberthur- (C); Craig Smith - (C); Tom Fouts; Bo York Subject: *URGENT* MPU E-21 (PTD 198-115, Sundry 315-651) Change of Plans to P&A -Verbal Approval Request Guy, We are unable to pull the ESP on MPU E-21 (PTD 198-115,Sundry 315-651). It is unknown if it is fill or collapsed casing in this well. We are able to freely circulate down the well. The rig is currently continuing to pull the pipe with little to no movement at this time. We will not attempt to cut and fish this ESP as there is a very high probability that cutting the tubing and ESP cable and heat trace will ball up in the well and not be fishable inside this 5-1/2" 15.5#casing, especially with the ASR rig. Attached is the proposed procedure and schematic. A hard copy sundry will submitted. Regards, 1 110 • Stan Porhola I Operations Engineer North Slope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 • • Well Prognosis Well: MPU E-21 Hilcorp Alaska,LL, Date: 11/06/2015 Well Name: MPU E-21 API Number: 50-029-22894-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: November 6th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 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: 1,046 psi @ 4,000'ND (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,046 psi @ 4,000' ND (Based on offset E-32 measured on 11/16/14) Max.Allowable Surf Pressure: 260 psi (Based on offset E-32 on 11/16/14 and water cut of 50%(0.385psi/ft)with an added safety factor of 1,000' ND of oil cap) Brief Well Summary: MPU E-21 has stuck tubing string (unknown cause). Will not be able to fish out the tubing, ESP cable, and heat trace cable and bands/flatguard. Notes Regarding Wellbore Condition • 5.5" 15.5#casing cemented to surface; performed top job from 135'to surface on 8/30/1998. • Casing last tested to 3,500 psi for 30 min down to 5,876'on 8/30/1998. • Maximum hole angle is 58° @ 4,081' MD. • Schrader Bluff interval to be open to injection is 5,359' MD to 5,644' MD (4,378'ND to 4,557'TVD). • Unknown obstruction causing stuck pipe (fill/collapsed casing). Objective: z-3 y °4`1/-f- •° 4`1/-F- The purpose of this work/sundry is to ab on the tuck ESP. 5u - Brief Procedure: WO Rig Procedure: 1. MIRU cementers. RU and PT Lines to 3,500 psi. 2. Mix and pump 30 bbl of 15.8 ppg cement down the tubing. a. Displace tubing with 8.5 ppg seawater(^'13 bbl)to leave 5 bbl in the tubing and squeeze 25 bbl thru the punch holes to fill the wellbore down to PBTD (Capacity below punch holes=25 bbl). 3. Wait on cement 6 hrs. c,43+' q C F = / 616Z- 4. RU Wireline.Tag cement inside tbing. Confirm cement top is above the tubing punch holes at 4,823'. {v clL��.:f 5. RIH w/jet cutter and make jet cut at+/-200'. Make 2"d cut at+/-200'to cut ESP/Heat Trace cables. 6. PU to confirm tubing is free. If pipe is free, RD Wireline. Otherwise,make additional cuts. 7. MU bridge plug on tubing and RIH and set at+/-150'. 8. Mix and pump 6 bbl of 15.6 ppg Permafrost Cement and circulate cement to surface (Capacity=5.3 bbl). 0231 Bagr - S""/,.` 9. POOH. Lay down tubing. S. 5 MO'x.043e z.bi 3S' .c .6354 : /•K>" 4.c4 68 • • Well Prognosis Well: MPU E-21 Hilcorp Alaska.LL Date: 11/06/2015 10. Clean and clear rig floor. Flush all surface lines. 11. RD ASR 1. 12. ND BOPE. NU Dry Hole Tree. Surface Procedure: 13. Confirm cement to surface.Top off cement as needed. 14. Excavate cellar, cut off wellhead and casing 3' below natural GL. 15. Set marker plate,collect GPS coordinates. 16. Backfill cellar, close out location. Attachments: 1. Proposed Schematic II • • Milne Well: MPU Point E-21Unit PROPOSED ABANDONMENT Last Completed: Proposed Mk-01T Alaska,J,1.0 PTD: 198-115 CASING DETAIL Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm r7,,...,,,‘`.� 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' .,;, '" 1: 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' 'lj . _ `T 5.5" Production 15.5/J-55/BTC-MOD 6.151 38' 5,961' _ -'cver/^X TUBING DETAIL 13-3/8° :t "Over(�36 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.995 Surface 5,421' Ta,Job JEWELRY DETAIL 0'-135 8/30119ye No Depth Item 1 150' CIBP 2 2,008' 5.5"Port Collar Cementer 3 3,500' Centrilift Heat Trace Bottom • 2 Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" 4 5,322' ""No Valve l+,staked' 5 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 6 5,361' KUDU PCP,100TP1800-Intake ND @ 4,395' 7 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 8 5,408' Centrilift FMH1-54hp/1,020V/35amp 9 5,419' Centrilift PHD-Bottom @ 5,421' - 3 PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' ✓ 4,545' 4,557' 20 9/3/1998 Open TtbirgFtrrh OPEN HOLE/CEMENT DETAIL 4823'4828' 13-3/8" 250 sx Arcticset 19Approx)in a 16"Hole 6/15/15 ~_ 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III 5.5"BTC.Jars: ' .Jars: WELL INCLINATION DETAIL l 5,071'-5,111', i KOP @ 550' Max Hole Angle=58 deg. @ 4,081' A1,4"Vt/t/ Hole Angle thru perfs=50 deg. >4 s TREE&WELLHEAD I Tree 2-1/16"5M Wellhead 7"5M Varco ADRS-7 Weld on style III 6 Tubing Hanger NSCTT&B 2"CIW H BPV Profile STIMULATION DETAIL fill: 'OA'/'OB'121,840 lbs Proplok 16/30 Badger i7 behind pipe on all three perforated intervals ' GENERAL WELL INFO 8 API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 Initial Completion by Nabors 4ES-9/13/1998 9 Fish:90ea.7/8"1.3rader Sands .7 0 tj' /t ,,,g�.Z( Sct SG Ball Seders. U TOE(g25,936 Calculated J 5.5":A .. TD=5,990'(MD)/TD=4,784'(TVD) PBTD=5,876'(MD)/PBTD=47,708'(TVD) Created By:STP 11/06/2015 • • • RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 C. 3 Q ���5 APPLICATION FOR SUNDRY APPROVALS AOGGC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations Q Fracture Stimulate ❑ Pull Tubing j Operations shutdown ❑ Suspend❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program 0 Plug for Redrill❑ Perforate New Pool ❑ Repair Well 2 Re-enter Susp Well ❑ Other: Convert to Injector RI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development 0 . 198-115 • 3.Address: Stratigraphic ❑ Service El6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22894-00-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ MILNE PT UNIT SB E-21 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028231 MILNE P T/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY', Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Dep s ' ): Plugs(measured): Junk(measured): 5,990 4,784 5,866 ,t N/A N/A Casing Length Size MD \ ' TVD Burst Collapse Structural Conductor 150' 13-3/8" 5N 150' 1,661psi 5,380psi Surface 5,961' 5-1/2" ��`t•' 4,765' 4,810psi 4,040psi Intermediate ,\ 1� t, Production r , Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): tit tt Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic V8" 4.7#/J-55/8rd EUE 5,421 Packers and SSSV Type: .; P.ckers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summ. of��;,j osal V, 13.Well Class after proposed work: Detailed Operations Program ❑ :c; .; etch ❑ Exploratory ❑ Strati ra hic Development g p ❑ p ❑ Service E 14. Estimated Date for15.Well Status after proposed work: Commencing Operations: N. 11/6/2015 OIL ❑ WINJ ❑✓ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOREl❑ SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing i rue and correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Stan Por •la Title Operations Engineer 1 Signature ' '1 1- ` Phone 777-8412 Date t v / 1 COMMISSION USE ONLY l Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ) 6 -(o,Plug Integrity ❑ BOP Test ElMechanical Integrity Test ❑ Location Clearance ❑ Other: V„' (IN 111015 RSDMS 1 SCANNED JA N 7 1 ,,,,- Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISS``IONEE DECOMMISSION Date: v Submit Form and Form 10-403 Revised 5/2015 Approved application ig'v li r tb`42 �o the from the date of approval. Attachments in Duplicate • • • 11 Choke Manifold ASR#1 09/29/2015 Hilnxp Woks,I i t Digital Reverse line back to Kill Line Pressure Readout C2 III.0 41 0 C3 Id Digital Pressure Transmitter '. / �0 '4 From Choke Line Manual Choke � IIIII � B "' Remote A I Choke C4 C5 C6 C7Choke I� 1 -1-K . - I . 11111y I h ♦ , 0 �� �, iil I i,s�, I II, III III III illi , 1. II I ui Jill 'r`n1 I.' lu las C9 _CIFII - All Valves 2" 5,000 psi "' ' a Piper Series PB Ball Valves ll a 11 C8�0 C11 �a0J/ C10_,0� 11 ' IIIC13 C15 waw 0 0114110111 0 0 li: :irJi OCI CI �� W' 0 0 I. III It. „ "I. C12 I.I— .. I ,74,_ .. poo -a 0 Ito C14 NM0 . 1 C16 �00- ,, .., To Panic Line liiii 1502 Union Outside NM'. End Capped To Gas Buster • EXISTING TREE/WELLHEAD MPU E-21 Wellhead/Tree Fliltrorp Alaska,LLCMilne Point Unit Tree Cap of '( �® Tree Valve 2-1/16"5M Q O uAwl a, -.._. Tree Cross 2-1/16"5M 11®60 ,� Tree Valve 2-1/16"5M -13 is SSV 2-1/16" 5M Si Tree Valve 2-1/16"5M Xioen, ,OpQ IiW111 ESP Cable Heat Trace Tubing Adapter J 11 _ p,„ all Casing Head b i/`� 7-1/16"5M Top x ■II �1 7-1/16" 5M Btm Casing Valve 2-1/16"5M Conductor, 7" 0 • H PROPOSED TREE/WELLHEAD MPU E-21 Wellhead/Tree Hilcoep Alaska,LLCMilne Point Unit Tree Cap „ r .,moi . A'©O Tree Valve 2-9/16"5M Q o`'' o• Tree Cross 2-9/16"5M Illilro*All Tree Valve 2-9/16"5M SSV 2-9/16"5M e Tree Valve 2-9/16"5M + -+(o`® ®m© Control Line Port (No ,. - ... Control Line in well) Tubing Adapter if slop Tubing Head (New) - --- 7-1/16"5M Top x esII 7-1/16" 5M Btm i1 MI ri" 111 'c' Casing Valve 2-1/16"5M In--- i. i l' Casing Valve 2-1/16"5M alt N E mu Casing Head ! si i . 7-1/16"5M Top x ■ll r C;`;v,iiir 7-1/16"5M Btm _ Casing Valve 2-1/16"5M Conductor, 7" • • a... .„4 0 7Z7 ? a' a q, ..,4 a OT3 9T3 E. E c., g ci 5 0 v ,..,.• E 1..> °,' > Q (.. c 6 u 41 :5 w z ar 4 2 al _. z Z3 v) 63 IT3 17.0 _. F. 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R C• - E 0. - CC 0 C 2 q g ® m ¢ � u S x t � ii cJ 0 .. « \ .. ti ° / & > e 2 \c a \ f V k Cl) Cl) k / < a 23 \ H . 0 Milne Point Unit Well: MPU E-21 SCHEMATIC Last Completed: 9/13/1998 Hileorp Alaska.LLC te..tet x(13115" PTD: 198-115 CASING DETAIL Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm • l 13-3/8" Conductor Over @ ' 72/L-80/N/A 12.191 Surface 150' 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' :'• / IC 5.5" Production 15.5/J-55/BTC MOD 6.151 38' 5,961' 4l 1 'XTUBING DETAIL 13-3/8" O @ 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.995 Surface 5,421' Top Job JEWELRY DETAIL 0-135' 8/30/1998 No Depth Item 1 115' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" 2 2,008' 5.5"Port Collar Cementer 3 3,500' Centrilift Heat Trace Bottom 0'2 Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" 4 5,322' ***No Valve Installed*** 5 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1 6 5,361' KUDU PCP,100TP1800—Intake TVD @ 4,395' 7 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 8 5,408' Centrilift FMH1—54hp/1,020V/35amp '' 9 5,419' Centrilift PHD— ` _ 3 ' PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open OPEN HOLE/CEMENT DETAIL 13-3/8" 250 sx Arcticset I 9Approx)in a 16"Hole 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole Tubing Punch Performed Top Job with AOGCC Approval—100sx Coldset III 4,8234828' 6/15115 . WELL INCLINATION DETAIL "'",...s„,_ KOP @ 550' Max Hole Angle=58 deg. @ 4,081' Hole Angle thru perfs=50 deg. IC a 4 TREE &WELLHEAD 5 Tree 2-1/16"5M I i Wellhead 7"5M Varco ADRS-7 Weld on style 6 Tubing Hanger NSCTT&B 2"CIW H BPV Profile r '' STIMULATION DETAIL t:Pl- 4 'OA'/'OB'121,840 lbs Proplok 16/30 Badger e' 7 behind pipe on all three perforated intervals \, GENERAL WELL INFO 8 API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 Initial Completion by Nabors 4ES—9/13/1998 s. 11 9 t_ Fish:93ea.7/8"1.3 Schrader Sands SG Ball Sealers. TOF©5,866 Calculated 5.5",a „6 TD=5,990'(MD)/TD=4,784'01/D) PBTD=5,876'(MD)/PBTD=47,708'(TVD) Created By:TDF 7/10/2015 IP III Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, November 09, 2015 4:04 PM To: 'Stan Porhola' Cc: samantha.carlisle@alaska.gov Subject: RE: MPU E-21 sundry withdraw - (PTD 198-115) Sundry 315-676 Stan, AOGCC will withdraw sundry 315-676 as requested. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:sporholaCa�hilcorp.com] Sent: Monday, November 09, 2015 4:01 PM To: Schwartz, Guy L(DOA) Subject: RE: MPU E-21 sundry withdraw - (PTD 198-115) Sundry 315-676 OK. Please disregard sundry 315-676 for MPU E-21. Stan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, November 09, 2015 4:00 PM To: Stan Porhola Subject: RE: MPU E-21 sundry withdraw - (PTD 198-115) Sundry 315-676 No that one is approved and you were working under that one. Withdraw 315-676... had mostly attachments and was submitted 10-30-15. 315-676 was never approved. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 1 • • recipient of this e-mail,please delete it,wifFout first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:1 Jrhola@hilcorp.com] Sent: Monday, November 09, 2015 3:56 PM To: Schwartz, Guy L (DOA) Subject: RE: MPU E-21 sundry withdraw - (PTD 198-115) Sundry 315-676 Is the extra sundry 315-651? Stan From: Schwartz, Guy L(DOA) [mailto:guv.schwartz@alaska.gov] Sent: Monday, November 09, 2015 3:50 PM To: Stan Porhola Subject: MPU E-21 sundry withdraw - (PTD 198-115) Sundry 315-676 Stan, There is an extra sundry for E-21 that was recently submitted. Since the situation has changed might be good to withdraw this one (315-676) as this one does not cover any of the P&A activity. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guv.schwartz@alaska.gov). 2 • • e //7,. s THE STATE \\I//� Alaska Oil and Gas W 9 ���r►•'i=���� of�T �� Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF � Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gay Stan Porhola cC104° ( S Operations Engineer $ 1 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-21 Sundry Number: 315-651 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this zo day of October, 2015 End. RBDMS ,OCj 2 "" 1 E STATE OF ALASKA 10 c T 1 ,5 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 071/ /o/zz/ iS APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑✓ Operations shutdown ❑ Suspend❑ Perforate 0 Other Stimulate ❑ Atter Casing 0 Change Approved Program 2 Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other. Convert to Irryector❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 2, 198-115 - 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22894-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 I Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / MILNE PT UNIT SB E-21 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028231 - MILNE POINT/SCHRADER BLUFF OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): * 5,990 . 4,784 . 5,866 , 4,702 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 150' 13-3/8" 150' 150' 1,661psi 5,380psi Surface 5,961' 5-1/2" 5,961' 4,765' 4,810psi 4,040psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic'/ See Attached Schematic 2-3/8" 4.7#/J-55/8rd EUE 5,421 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: _. Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 7 j Service L✓! 14.Estimated Date for 15.Well Status after proposed work: Operations: 11/1/2015 CommencingOIL ❑ WINJ 0- WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporholat hilcorp.com Printed Name Stan__Porrhola Title Operations Engineer Signature ._.z — Phone 777-8412 Date (t) IS IS COMMISSION USE ONLY ` Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑� Ji, BOP Test ❑ Mechanical Integrity Test [f Location Clearance ❑ Other: In e.Ao _ —r\ °Y� f be r . 0.GG trcrka,sq.Ge. w/1( '10 10Q . F 3000 (s 4'd ' r..R s -� Spacing Exception Required? Yes 0 No g7 Subsequent Form Required: 10— 4404 RBOMSIV 0 2 CI 1015 APPROVED BY Approved by: COMMISSIONER THECOMMISSIONDate:/0- 23 -7d [G'1/ l S j FinirGAtiAsialid � �1 %��4t,�Submn FormDupli ane Form 10-403 Re sed 5/2 15 for 12 molts frorrrfff�i�th data of approval. in Duplicate • • Well Prognosis Well: MPU E-21 Ilil"urp Alaska,LL: Date: 10/15/2015 Well Name: MPU E-21 API Number: 50-029-22894-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: November 1st, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 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: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,800 psi @ 4,000' TVD (Based on original reservoir pressures) Max. Allowable Surf Pressure: 260 psi (Based on offset E-32 on 11/16/14 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU E-21 was drilled in 1998 using Nabors 27E as a grassroots well in the Schrader Bluff sands.The ESP completion was ran by Nabors 4ES in 1998.The well has not produced since 1998. Q� f_ (6h vecfA,,i ((eV�'ew CgOae 4S ` - r a - Notes Regarding Wellbore Condition L 7, 3/f•. 1�L dRQ�i ��— • 5.5" 15.5#casing cemented to surface; performed top job from 135'to surface on 8/30/1998. • Casing last tested to 3,500 psi for 30 min down to 5,876'on 8/30/1998. • Maximum hole angle is 58° @ 4,081' MD. • Schrader Bluff interval to be open to injection is 5,359' MD to 5,644' MD (4,378'TVD to 4,557'ND). AOR(status of wells within 1/4 mile radius of injection zone): -,—, 31s-a- API Well No Permit Well ' Current Status Zonal isolation(method) S/I Producer 5-1/2" Production Casing cemented from casing 50-029-22894-00 198-115 E-21 shoe (5961'MD)to surface(Top job performed), (SI since 1998) casing shoe is—317' below OA sand. Active Producer- 9-5/8" Surface Casing cemented from casing shoe 50-029-22154-00 191-048 E-06 (5231'MD)to surface, casing shoe is"'187' below Kuparuk OA sand. 9-5/8" Production Casing cemented from casing 50-029-23261-00 205-065 E-32 Active Producer- shoe (5310' MD)to surface. Casing shoe is "192' Schrader below OA sand. Production lateral sections are uncemented. 7" Production Casing cemented from stage collar (6566'MD)to estimated TOC[No CBL ran] 50-029-22570-00 195-094 E-23 Active Injector- (5170'MD;4054'TVD), based on 63 bbl (310 sx) of Kuparuk 15.8 ppg Class G cement inside 8.5"openhole (est 100%openhole excess), casing shoe is set in the Kuparuk sands. Active Injector 9-5/8"Surface Casing cemented from casing shoe 50-029-22058-00 190-081 E-05 (5671'MD)to surface,casing shoe is—151' below Kuparuk OA sand. • • Well Prognosis Well: MPU E-21 Hilcorp Alaska,LL Date:10/15/2015 S/I Producer- 9-5/8"Surface Casing cemented from casing shoe 50-029-22156-00 191-050 E-08 Kuparuk to surface, casing shoe is^'184' below OA sand. Objective: The purpose of this work/sundry is to pull the failed ESP, cleanout to PBTD, abandon the OB sand perfs, add perfs in the NC, ND,and OA sands and convert the well to a water injector in the Schrader Bluff. / Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines.Clear and level area around well. 3. RU Little Red Services Pump.Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Reverse circulate at least one casing volume with 8.5 ppg sea water down casing,taking returns up tubing to 500 bbl returns tank. a. Tubing punch holes exist at 4,823'-4,828' MD. 6. Pump at least one tubing volume of 8.5 ppg seawater down tubing. 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 8. RD Little Red Services Pump and reverse out skid. 9. RU crane. Set BPV. ND Tree. NU 11" BOPE w/7-1/16"x 11"adapter. RD crane. 10. NU BOPE house.Spot mud boat. WO Rig Procedure: 11. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 12. Pull BPV. Bleed any pressure off tubing and casing. 13. Kill well w/8.5 ppg seawater as needed.Set TWC. 14. Test BOPE to 250 psi Low/3,000 psi High,annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-3/8"test joint. 15. Contingency: If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking 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.) , iti • • Well Prognosis Well: MPU E-21 Hilcorp Alaska,LL Date:10/15/2015 f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. (1 16. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. Pull TWC. Bleed any pressure off tubing and casing. Kill well w/8.5 ppg seawater as needed. 18. MU 2-3/8" landing joint(EUE) and BOLDS. 19. Pull over string weight(approx. 20k PU)on tubing hanger to confirm free. LD tubing hanger. 20. POOH. Lay 2-3/8"tubing on the pipe rack(plan to re-run tubing). Lay down ESP. 21. MU 4-5/8" bit and casing scraper and RIH w/2-3/8"tubing. 22. Scrape 5-1/2" 15.5#casing down to+/-5,876' MD(PBTD). a. Drift ID is 4.825". 23. POOH. Lay 2-3/8"tubing on the pipe rack. LD bit and casing scraper. 24. Remove old tubing from pipe rack, installing 2-3/8" EUE thread protectors(180 sets). 25. Place new tubing(2-3/8" EUE)on pipe rack and tally. 26. PU RTTS and RIH w/2-3/8"tubing(new tubing). 27. Set RTTS at+/-5,500' MD. Fill annulus w/8.5 ppg sea water. 28. Test casing to 3,000 psi for 30 min and chart. 29. Bleed off casing. Release RTTS. POOH. LD RTTS. Lay down 2-3/8"tubing. 30. RIH w/2-3/8"tubing down to 3,500'. 31. MU Storm Packer and set at 100'w/tubing hung off below. POOH w/landing string. 32. Test Storm Packer to 1,000 psi for 10 min to confirm isolation. 33. ND BOPE. NU New Tubing Head.Test tubing head to 250/5,000 psi for 30 min and chart. 34. NU BOPE and shell test flanged connection on new tubing head to 250/3,000 psi for 30 min. 35. MU landing string. Release Storm Packer. Monitor well. Kill well w/8.5 ppg seawater as needed. 36. POOH. LD Storm Packer. Lay down 2-3/8"tubing. 37. Remove new tubing from pipe rack. a. Do not pump cement thru new tubing. Utilized used tubing. 38. Place old tubing(2-3/8" EUE)on pipe rack and tally. 39. MU 5.5"cement retainer and RIH w/2-3/8"tubing(use old tubing). 40. Set cement retainer at+/-5,615' MD(above OB perfs). 0X-, V a. Va. ***VARIANCE REQUEST OF 20 AAC 25.112(c)(1)(D)*** b. Requesting to set retainer within 9'ofe �$ y. q g perfs instead of 50, (isolating sands within same pool, only 56'between intervals in the OA and OB.Abandon 08 sands, leave OA sands open). 41. Stab into retainer and perform injectivity test into formation. 42. Mix and pump 10 bbl of 15.8 ppg cement below retainer. 43. PU above cement retainer and circ well clean with 8.5 ppg seawater. 44. POOH. Lay 2-3/8"tubing on the pipe rack. LD retainer running tool. 45. Remove old tubing from pipe rack, installing 2-3/8" EUE thread protectors(180 sets). 4," 46. Place new tubing(2-3/8" EUE)on pipe rack and re-tally. .7� 47. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Install 11"x 7-1/16"adapter on top of annular for lubricator connection. 0' 48. RU 3-3/8" 6 spf HC wireline guns. 49. RIH and perforate OA sand interval from 5,518'-5,569' MD(51')at 6 spf. .r 50. RIH and perforate ND sand interval from 5,383'-5,396' MD(13')at 6 spf. r' /� 51. RIH and perforate ND sand interval from 5,359'-5,368' MD(9')at 6 spf. / • • Well Prognosis Well: MPU E-21 Hilcorp Alaska,LL Date:10/15/2015 a. Bleed tubing pressure to 0 psi before perforating. b. BHP= 1,800 psi (based on offset wells). c. Proposed perfs shown on the proposed schematic in red font. d. Correlate using Sperry MWD Log dated 8/29/98. e. Use Gamma/CCL/to correlate. f. Record casing pressures before and after each perforating run. g. Distance to nearest well open in same sands=750'to MPU E-32. h. Spacing allowance is based on CO 477.05, no spacing limitations in the Schrader Bluff. ,,. 52. RD E-line. 53. PU completion packer and jewelry with new 2-3/8"8RD EUE L-80 tubing. a. Run 2-3/8"X profile, production packer,and WLEG. b. Load X profile w/RHCP plug body. 54. RIH and set WLEG at+/-5,300' MD. Circulate packer fluid and freeze protect fluid. a. Use BARACOR 100 corrosion inhibitor w/8.5 ppg sea water for packer fluid. 55. Land tubing hanger. RILDS. a. Note PU (Pick Up)and SO(Slack Off)weights on tally. 56. Drop RHCP prong. Pressure up down tubing and set packer hydraulically. 57. Test tubing to 3,000 psi for 30 min and chart. Monitor IA pressure. 58. Bleed tubing to 1,000 psi. 59. Test packer/casing to 2,500 psi for 30 min and chart. Monitor tubing pressure. 60. Bleed off tubing and casing pressures. 61. Lay down landing joint. 62. Set BPV.Test tubing hanger to 250/5,000 psi. 63. RD Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 64. RD mud boat. RD BOPE house. Move to next well location. 65. RU crane. ND BOPE. NU new 2-9/16" 5,000#tree. Pull BPV. 66. Set TWC.Test tree to 250/5,000 psi. Pull TWC. RD crane. 67. Move 500 bbl returns tank and rig mats to next well location. 68. Replace IA&OA pressure gauge if removed (5-1/2" & 13-3/8"). 69. Turn well over to production. RU well house and flowlines. 70. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. 71. RIH and pull prong from RHCP plug. POOH. 72. RIH and pull RHCP plug body from X-profile. POOH. RD Slickline. Notify AOGCC and perform witnessed MILIA to 2,500 psi after stabilized injection. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Area of Review Map • . Milne Point Unit • 14Well: MPU E-21 SCHEMATIC Last Completed: 9/13/1998 Hilcorp Alaska,LLC PTD: 198-115 CASING DETAIL Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm d 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' .' ' « 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' I 1 w 5.5" Production 15.5/1-55/BTC-MOD 6.151 38' 5,961' �i O @3.3 4 TUBING DETAIL 13-3/8" 2-3/8" Tubing 4.7/1-55/EUE 8rd 1.995 Surface 5,421' a` Top Job `_ JEWELRY DETAIL 81 No Depth Item 1 115' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" 2 2,008' 5.5"Port Collar Cementer f i �a 2 3 3,500' Centrilift Heat Trace Bottom 4 5,322' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" " ***No Valve Installed*** 5 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 6 5,361' KUDU PCP,100TP1800-Intake ND @ 4,395' 7 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 k 8 5,408' Centrilift FMH 1-54hp/1,020V/35amp 9 5,419' Centrilift PHD-Bottom @ 5,421' 3 4. PERFORATION DETAIL 1 Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status '` 'OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open ii 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open OPEN HOLE/CEMENT DETAIL , 13-3/8" 250 sx Arcticset I 9Approx)in a 16"Hole i 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole Tubing Punch , j, NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III 4,823-4,828' &'15115WELL INCLINATION DETAIL KOP @ 550' Max Hole Angle=58 deg. @ 4,081' ' Hole Angle thru perfs=50 deg. 4 5 `r TREE&WELLHEAD A itTree 2-1/16"5M I Wellhead 7"5M Varco ADRS-7 Weld on style 6 Tubing Hanger NSCTT&B 2"CIW H BPV Profile STIMULATION DETAIL illi ,,, 'OA'/'OB'121,840 lbs Proplok 16/30 Badger I , 7 behind pipe on all three perforated intervals GENERAL WELL INFO ..8 API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 x Initial Completion by Nabors 4ES-9/13/1998 ,4 9 Fish:90ea.7/8 1.3 L.' .: Schrader Sands SG Ball Suers. + TOF@5,866 1,4 Calculated \.....Y. r 5.5"may ra ' ID=5,990'(MD)/TD=4,784'(TVD) PBTD=5,876'(MD)/PBTD=47,708'(TVD) Created By:TDF 7/10/2015 H . Milne Point Unit • P RO POS E D SCH E MATT C MPU E-21 Last Well:Completed: Proposed Uncurl)Alaska,LLC PTD: 198-115 CASING DETAIL Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm i / .*. j [4413 3/8" Conductor72/L-80/N/A12.191 Surface 150' \ 7" ProdX-Over 26/L-80/BTC-MOD 6.276 Surface 38' 5.5" Production 15.5/J-55/BTC-MOD 6.15138' 5,961' Tx5.5'X 13-3/8" over@ TUBING DETAIL 2-3/8" Tubing 4.7/L-80/EUE 8rd 1.995 Surface 5,300' Top Job psi JEWELRY DETAIL 0'-135' 8/30/1998 No Depth Item 1 2,008' 5.5"Port Collar Cementer 2 5,240' Hydraulic Production Packer 0 1 3 5,270' 2-3/8"X-Profile 4 5,300' WLEG 5 5,615' Cement Retainer(Sqz 8 bbl 15.8 ppg cement below) PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status .9 'NC' 5,359' 5,368' 4,378' 4,384' 9 Proposed Future 'ND' 5,383' 5,396' 4,393' 4,401' 13 Proposed Future 'OA' 5,518' 5,569' 4,477' 4,510' 51 Proposed Future 'ON 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open OPEN HOLE/CEMENT DETAIL 13-3/8" 250 sx Arcticset I 9Approx)in a 16"Hole 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III WELL INCLINATION DETAIL KOP @ 550' Max Hole Angle=58 deg. @ 4,081' Hole Angle thru perfs=50 deg. TREE&WELLHEAD Tree 2-1/16"5M Wellhead 7"5M Varco ADRS-7 Weld on style ' Tubing Hanger NSCTT&B 2"CIW H BPV Profile I igijr I J 2 STIMULATION DETAIL 'OA'/'OB'121,840 lbs Proplok 16/30 Badger 3 behind pipe on all three perforated intervals i. GENERAL WELL INFO 4 API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 • NC Sand Initial Completion by Nabors 4ES-9/13/1998 ND Sand - Qa,SAN Fish:90ea.7/8"1.3 SG Bel Sealers. 5 TOF @ 5,866' S.=' f'�'. OB Sand Calculated ,,'t 5.5 `.',i•14'Nr TD=5,990'(MD)/TD=4,784'(1VD) PBTD=5,876'(MD)/PBTD=47,708'(TVD) Created By:STP 8/11/2015 • • 111 Milne Point 2015 ASR Rig 1 it: o.p��ta>k..�.u. Knight Oil Tools BOP 11" BOPE IV tit Stripping Head 3.98' ° haffer 4 - 11" - 5000 fililals "Mills I!, EU1 Ili ELL - I • C I -U sisi 4.54' 0 - 2 7/8-5 variables MI*��� 11"-5000 hID - Blind di 1 ii iii I 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves J 2.00' . ' 111'111111"1!1- 1 i. i ) : ',S1 ,i 0 1 ,,ck - III Ill-alai 111`! Manual Manual A Manual HCR DSA,11 5M X 71/16 5M Updated 10/15/15 • • 1 i 2 , N ,15 .—f—)L • H!r _4 4 4O 88E`i7` Al K--- 0.4, S G W r lr ` ..------------- w -��1 __ , t ' / �, is , 9a t cu �°�'•_ 4 �_� cc r - _ _ _ _ -y' h. e. ca . :::til r�! �Fr WM ((r ZS I- , '--.,,.. / Q ��.-. �' I • y fI N N N j m1111111111. 411 fr.1,4 WI 1► -A.,„, ti _ i W ..,. �,T`.2 :int or; _Ar. ' 4,1 , W 1L ,41iimi ______________ _________ _ 4 i ,�1 44v N • N. 446 013 , /11. N ,—/ke 1 0 1140 � W op` I N I vOF Ty, • „w\� )7j�'s, THE STATE Alaska Oil and Gas �s�„-s '�, o Conservation Commission � fALASI�:A ti • __ __ 333 West Seventh Avenue 41^97:1:-----"7 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *% Main. 907 279 1 433 OF ALAS'" Fax: 907.276 7542 Satiwww.aogcc.alaska.gov G 5Stan Porhola ici --- ii Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-21 Sundry Number: 315-512 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ad-6 /°;14—.4Cle. Cathy P. Foerster 1 _79eli i iiia` Chair RBDMS DATED this 0:lay of September, 2015 Encl. RECEIVED • STATE OF ALASKA AV1 2 12915 ALASKA OIL AND GAS CONSERVATION COMMISSION b' 9I gp)s APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1 Type of Request: Abandon D Plug Perforations 0 • Fracture Stimulate ❑ Pull Tubing 0 - Operations shutdown ❑ Suspend ❑ Perforate Q. Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well E _ Re-enter Susp Well ❑ Other. Convert to Injector Q- 2.Operator Name: 4 Current Well Class: 5 Permit to Drill Number: Hilcorp Alaska,LLC . Exploratory ❑ Development Q - 198-115 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22894-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pools C.O.477.05 i Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT SB E-21 9.Property Designation(Lease Number). 10 Field/Pool(s): ADL0028231 ' MILNE POINT/SCHRADER BLUFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured). Junk(measured). 5,990 - 4,784 • 5,866 4,702 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 150' 13-3/8" 150' 150' 1,661psi 5,380psi Surface 5,961' 5-1/2" 5,961' 4,765' 4,810psi 4,040psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft)• Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.7#/J-55/8rd EUE 5,421 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal ❑, 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development❑ Service Q- 14.Estimated Date for 15.Well Status after proposed work: 9/25/2014' ❑ WINJ -❑ Commencing Operations OIL WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature .). 7) Phone 777-8412 Date g/14/(I-- COMMISSION USE ONLY 1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316- Gil Plug Integrity ❑ BOP Test 1: Mechanical Integrity Test ® Location Clearance ❑ I Othev lkt. Ptt 9,r1 ape e.o.„ 'vo be Q.0 coda.✓,c,2.. c,.)!IL yi1 O 1.0 a. 300-0/95-:- 1 P Ir-4-f- ( ,w4s = 26o r S. ) liC Spacing Exception Required? Yes ❑ No IJ•J Subsequent Form Required. /6 -Y O il / p APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 9-5,-/5 '121% vim/is L-0t✓ q2.#/hr •� �•Z•/S Submit Form and Form 10-40/Revised 5/2015 0 fttertIlloLid for .'1. i/.IV O1% Attachments in Duplicate yt(�u IV 1r� �� Well Prognosis Well: MPU E-21 Hilcorp Alaska,LL Date:8/20/2015 Well Name: MPU E-21 API Number: 50-029-22894-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: September 25th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-115 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: 1,046 psi @ 4,000' TVD (Based on offset E-32 measured on 11/16/14) Maximum Expected BHP: 1,800 psi @ 4,000' TVD (Based on original reservoir pressures) Max.Allowable Surf Pressure: 260 psi (Based on offset E-32 on 11/16/14 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU E-21 was drilled in 1998 using Nabors 27E as a grassroots well in the Schrader Bluff sands.The ESP completion was ran by Nabors 4ES in 1998.The well has not produced since 1998. Car cve . 74,3 elf �,'!/ �o c,/e /���"Pcf� d'! Notes Regarding Wellbore Condition �t ro j j • 2 ���'tea' ft?O�i�fr' '�, S�� row vhe d;,�cl'• vd'enr� /1 O,( / "r 1"ffi ). • 5.5,. 15.5#casing cemented to surface; performed top job from 135'to surface on 8/30/1998.""Le,"7.9 j , • Casing last tested to 3,500 psi for 30 min down to 5,876' on 8/30/1998. we// ,r a4 �� • Maximum hole angle is 58° @ 4,081' MD. In je cfroe .5-40 11/0, • Schrader Bluff interval to be open to injection is 5,359' MD to 5,644' MD(4,378'TVD to 4,557'TVD). ,,//oleo e cOvar� f/630f AOR(status of wells within 1/4 mile radius of injection zone): 7*s ,Qrr.br+ a Id rhe API Well No Permit Well Current Status Zonal Isolation(method)' ° (a3/ J5-1/2" Production Casing cemented from casing S/I Producer 50-029-22894-00 198-115 E-21 (SI since 1998) shoe(5961'MD)to surface(Top job performed), casing shoe is"'317' below OA sand. Active Producer 9-5/8" Surface Casing cemented from casing shoe 50-029-22154-00 191-048 E-06 Kuparuk (5231'MD)to surface,casing shoe is—187' below OA sand. 9-5/8" Production Casing cemented from casing Active Producer- shoe(5310' MD)to surface. Casing shoe is "192' 50-029-23261-00 205-065 E-32 Schrader below OA sand. Production lateral sections are uncemented. 7" Production Casing cemented from stage collar (6566'MD)to estimated TOC[No CBL ran] 50-029-22570-00 195 094 E 23 Active Injector- (5170'MD;4054'TVD), based on 63 bbl (310 sx)of 7 Kuparuk 15.8 ppg Class G cement inside 8.5" openhole (est 100%openhole excess), casing shoe is set in the Kuparuk sands. 9-5/8"Surface Casing cemented from casing shoe 50-029-22058-00 190-081 E-05 Active Injector (5671'MD)to surface, casing shoe is—151' below Kuparuk OA sand. • H Well Prognosis Well: MPU E-21 Hilcorp Alaska,LL' Date:8/20/2015 S/I Producer 9-5/8" Surface Casing cemented from casing shoe 50-029-22156-00 191-050 E-08 Kuparuk (5947'MD)to surface,casing shoe is^'184' below OA sand. Objective: P�=�S The purpose of this work/sundry is to pull the failed ESP, cleanout to PBTD, abandon the OB sand perfs, add perfs in the NC, ND, and OA sands and convert the well to a water injector in the Schrader Bluff. Brief Procedure: WO Rig Procedure: 1. Circulate well with 8.5 ppg seawater down tubing and fill casing. a. Tubing punch holes exist at 4,823'-4,828' MD. 2. RU crane. Set BPV. ND Tree. NU 7-1/16" BOPE. 3. MIRU Hilcorp ASR#1 WO Rig. L561'' 4. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/) i High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. s b. Test VBR rams on 2-3/8" test joint. , z 5. Bleed any pressure off tubing and casing. Pull BPV. 10/tr 6. MU 2-3/8" landing joint (8RD) and pull over string weight ("20k)on tubing hanger to confirm free. 7. POOH. Lay 2-3/8"tubing on the pipe rack(re-run good joints). Lay down ESP. 8. MU 4-5/8" bit and junk baskets and RIH w/2-3/8"tubing/workstring. 9. Clean out fill inside 5.5" 15.5#casing down to+/-5,876' MD (PBTD). a. Drift ID is 4.825". 10. Circulate well clean with 8.5 ppg seawater. 11. POOH. Lay 2-3/8" tubing on the pipe rack. LD bit and junk baskets. 12. PU RTTS and RIH w/2-3/8"tubing/workstring. 13. Set RTTS at+/-5,500' MD.Test casing to 3,000 psi for 30 min. 6-5,7 14. Release RTTS. POOH. LD RTTS Lay down 2-3/8" tubing/workstring. 15. RIH w/2-3/8"tubing/workstring down to 3,500'. 16. MU Storm Packer and set at 100'w/tubing hung off below. POOH w/landing string. 17. Test Storm Packer to 1,000 psi for 10 min to confirm isolation. 18. ND BOPE. NU New Tubing Head.Test tubing head to 250/5,000 psi for 30 min and chart. 19. NU BOPE and shell test flanged connection on new tubing head to 250/3,000 psi for 30 min.'I 20. MU landing string. Release Storm Packer. POOH. LD Storm Packer. Lay down 2-3/8" tubing/workstring. 21. MU 5.5" cement retainer and RIH w/2-3/8"tubing/workstring. 22. Set cement retainer at+/-5,615' MD. O Px�l�s a. ***VARIANCE REQUEST OF 20 AAC 25.112(c)(1)(D)*** w ` b. Requesting to set retainer within 9'of perfs instead of 50, (isolating sands within same pool, only 56'between intervals in the OA and OB.Abandon OB sands, leave OA sands open). 1)&11: 4-, ,,, y%L l -�� 23. Stab into retainer and perform injectivity test into formation. 24. Mix and pump 10 bbl of 15.8 ppg cement below retainer. 25. PU above cement retainer and circ well clean with 8.5 ppg seawater. 26. POOH. Lay 2-3/8"tubing on the pipe rack. LD retainer running tool. Well Prognosis Well: MPU E-21 Hilcorp Alaska,LI) Date:8/20/2015 27. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. BOPE connection is 7-1/16" studded top for lubricator on top of annular. 28. RU 3-3/8" 6 spf HC wireline guns. 29. RIH and perforate OA sand interval from 5,518'-5,569' MD(51')at 6 spf. 19,4 L 30. RIH and perforate ND sand interval from 5,383'-5,396' MD(13')at 6 spf. 31. RIH and perforate ND sand interval from 5,359'-5,368' MD(9') at 6 spf. a. Bleed tubing pressure to 0 psi before perforating. b. BHP= 1,800 psi (based on offset wells). c. Proposed perfs shown on the proposed schematic in red font. d. Correlate using Sperry MWD Log dated 8/29/98. e. Use Gamma/CCL/to correlate. f. Record casing pressures before and after each perforating run. g. Distance to nearest well open in same sands=750'to MPU E-32. h. Spacing allowance is based on CO 477.05, no spacing limitations in the Schrader Bluff. 32. RD E-line. 33. PU completion packer and jewelry with new 2-3/8" 8RD EUE L-80 tubing. a. Run 2-3/8"X profile, production packer. 34. RIH and set WLEG at+/-5,300' MD. Circulate packer fluid and freeze protect fluid. moo sL/ ,L 35. Land tubing hanger. Lay down landing joint. --A, 5e%E 1'4 �a z / 36. Set BPV. ND BOPE. NU new 2-9/16" 5,000#tree. Pull BPV. 37. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 38. RD Hilcorp ASR#1 WO Rig. 39. Replace IA x OA pressure gauge if removed (5-1/2"x 13-3/8"). 40. Turn well over to production. t� r 4 Attachments: L� �, �,.,�— MIT— I/x' 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Area of Review Map Milne Point Unit Well: MPU E-21 • SCHEMATIC Last Completed: 9/13/1998 Hileorp Alaska,LLC PTD: 198-115 CASING DETAIL Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm '' 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 150' toIII"' i° 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' 1 ' 5.5" Production 15.5/1-55/BTC-MOD 6.151 38' 5,961' 5 l' '' Tx5.5"X hi Cver @38' TUBING DETAIL 13-3/F '' ,,< 2-3/8" Tubing 4.7/J-55/EUE 8rd 1.995 Surface 5,421' Top Job '' JEWELRY DETAIL G-135' :. `. 8/30/1998 v .° No Depth Item 1 115' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" rt 2 2,008' 5.5"Port Collar Cementer ‘,.; 3 3,500' Centrilift Heat Trace Bottom 0'2 Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" .v 4 5,322' ***No Valve Installed*** o _1 5 5,348' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 6 5,361' KUDU PCP,100TP1800-Intake TVD @ 4,395' ar 7 5,395' Centrilift Seal Section:FSTBDBILPFSAFLASHN4 8 5,408' Centrilift FMH1-54hp/1,020V/35amp 9 5,419' Centrilift PHD-Bottom @ 5,421' s II 3 4,, PERFORATION DETAIL , r Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status is 'OA' 5,526' 5,536' 4,482 - 4,489' 10 9/3/1998 Open , 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open <. OPEN HOLE/CEMENT DETAIL io 1., , 13-3/8" 250 sx Arcticset 19Approx)in a 16"Hole ;� 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole Tubing Punch ; y NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III 4,823'-4,828' ' "1 6/15/15 WELL INCLINATION DETAIL KOP @ 550' Max Hole Angle=58 deg. @ 4,081' 4 Hole Angle thru perfs=50 deg. Pe 4 5 $ TREE&WELLHEAD Tree 2-1/16''5M%:1 :1'' :' Wellhead 7"5M Varco ADRS-7 Weld on style Tubing Hanger NSCTT&B 2"ow H BPV Profile fp& 6 s k STIMULATION DETAIL II 'OA'/'OB'121,840 lbs Proplok 16/30 Badger 7 behind pipe on all three perforated intervals ' GENERAL WELL INFO i 4 8 API:50-029-22894-00-00 Drilled and Cased by Nabors 27E -9/1/1998 r, Initial Completion by Nabors 4ES-9/13/1998 9 s i. y Fish:90ea.7/8"1 3 40, Schrader Sands SG Ball Sealers. r TCF @ 5,866' 3 Calculated MI 5.5"i "hs ": "w, TD=5,990'(MD)/TD=4,784'(TVD) PBTD=5,876'(MD)/PBTD=47,708'(TVD) Created By:TDF 7/10/2015 Milne Point Unit II Well: MPU E-21 • PROPOSED SCHEMATIC Last Completed: Proposed Hilcora Alaska.LLC PTD: 198-115 CASING DETAIL Orig.DF Elev.:55.9'/GL Elev.:23.2'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm '° i` [. 13-3/8" Conductor 72/L-80/N/A 12.191 Surface 1.50' T1 : 7" Prod X-Over 26/L-80/BTC-MOD 6.276 Surface 38' I l 9 5.5" Production 15.5/1-55/BTC-MOD 6.151 38' 5,961' 411 1 T xs5 x TUBING DETAIL 13-3/8 r ;Over @ 3g' 2-3/8" Tubing 4.7/L-80/EUE 8rd 1.995 Surface 5,300' Top Job i'* '; JEWELRY DETAIL 0-135 '. 8/30/1998 l' No Depth Item 1 2,008' 5.5"Port Collar Cementer ); 2 5,240' Hydraulic Production Packer li:- t ° 3 5,270' 2-3/8"X-Profile , 4 5,300' WLEG 4 fix 5 5,615' Cement Retainer(Sqz 8 bbl 15.8 ppg cement below) i. PERFORATION DETAIL ) $ Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status ' 'NC' 5,359' 5,368' 4,378' 4,384' 9 Proposed Future L `ND' 5,383' 5,396' 4,393' 4,401' 13 Proposed Future t: t 'OA' 5,518' 5,569' 4,477' 4,510' 51 Proposed Future ►° ,1 `OA' 5,526' 5,536' 4,482' 4,489' 10 9/3/1998 Open 'OA' 5,548' 5,568' 4,496' 4,509' 20 9/3/1998 Open 'OB' 5,624' 5,644' 4,545' 4,557' 20 9/3/1998 Open z AA' OPEN HOLE/CEMENT DETAIL rr 13-3/8" 250 sx Arcticset 19Approx)in a 16"Hole �ti g 5.5" 615 sx Coldset III,220 sx Foamed&175 sx Class"G"in a 6-3/4""Hole NOTE:Performed Top Job with AOGCC Approval-100sx Coldset III + WELL INCLINATION DETAIL s KOP @ 550' Max Hole Angle=58 deg. @ 4,081' l:y Hole Angle thru perfs=50 deg. TREE&WELLHEAD xA41rTree 2-1/16"SM V, r Wellhead 7"5M Varco ADRS-7 Weld on style i; Tubing Hanger NSCTT&B 2"CIW H BPV Profile .4 I ``I iI r 2 STIMULATION DETAIL ri 'OA'/'OB'121,840 lbs Proplok 16/30 Badger i,' behind pipe on all three perforated intervals '4. GENERAL WELL INFO t. ' API:50-029-22894-00-00 . " Drilled and Cased by Nabors 27E -9/1/1998 i' j It' _ NC Sand Initial Completion by Nabors 4ES-9/13/1998 L. ND Sand 1 7. it. ` " OA Sand Fish:93ea.7/8"1.3 V SG Ball Sealers. ' ,x d 5 TOF@5,866' ,i ' ".".- Calculated I, , OB Sand 5.51 i•or..# ' TD=5,990'(MD)/TD=4,784'(1VD) PBTD=5,876'(MD)/PBTD=47,708'(1VD) Created By:SIP 8/11/2015 Mime Point 2015 ASR Rig 1 F{o' 5rn ,i���� { Knight Oil Tools BOP n7-1/16" BOPE / Stripping Head 0 0 I-1 frl (frl IT ( l 11 2.57' / Shaffer 7 1/16 5000 [fe] iii[ll)rn-i ft-ii [[�j�[��))�l[(( �J(r� !r�[[[f[[ ]j�{)I< - i-.111111h2 3/8-3%variable - CAMERON 3.68' HI i..,-.7 ®�* H ,, , ink= 1 =4l Blind :� 7 1/16 50000 00 �mi_ tinfrj [f i (fel fft rill 111 2 1 16 5M Kill Line Valves 2 1/16 5M Choke Line Valves . Ill IIIlt1I I tI1 1.56' t : I4 ,,,,,t—is,' ° i° �� 1. C j --t is ! � 7 1/16 5000 tit UI 111 111 III - Manual Manual Manual HCR Updated 7/23/2015 = I a) - r.• E li -411•441 , ap, 138E17- r403 i C-- LU ,,,i rt. or fiNimilaissor. cu Ae0047/ • • (/ CD 44 Vs 96 / .,LA h4 a s ' \ CV ...:i.'‘. la i - -Nog- 1411/441F t• •••ai N " tit&/ le 2 III .4,7: lilt °I 1 II IIIIIII I I I I 1 I I I I I 1 1.- 'PA' - 31, .. .. v.. i t ----- lib-- I : ,,t, i';4 _ ___ _ -died / ' 1 •. Of ;1(N•,,,, , A* e Adik•pi I" c- I -In IN, 4 IA! 1 •. 0 ti 3 N !443) . ‘.A 1 I ‘it, r'"*"•., 'Ai • cli )111** wN Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Thursday, September 03, 2015 10:01 AM To: Schwartz, Guy L (DOA) Cc: Tom Fouts Subject: FW: MPU E-21 RWO convert to Inj. (PTD 198-115) Guy, Regarding the cement coverage in MPU E-23 (PTD 195-094), an offset Kuparuk injector to MPU E-21 (PTD 198-115). The estimated cement top (no CBL ran) in the 7" production casing for MPU E-23 is 5,170' MD/4,054'TVD based on 100% OH excess from the ES cementer in the 7" at 6,566' MD. The top of the Ugnu is at 5,259' MD/4,088'TVD. The base of the Ugnu is at 5,722' MD/4,279'TVD.This should be covered by the 2"d stage cement in the 7" casing. The top of the Schrader Bluff is 5,898' MD/4,353'TVD. The base of the Schrader Bluff is 6,481' MD/4,607'TVD.This should be covered by the 2nd stage cement in the 7" casing. The surface casing shoe is at 4,240' MD, roughly 1,000' MD above the Ugnu. Let me know if you have any additional questions or concerns. Stan Porhola Operations Engineer North Slope Asset Team Hilcorp Alaska, LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 From: Paul Chan Sent: Wednesday, September 02, 2015 4:48 PM To: 'Schwartz, Guy L (DOA)'; Stan Porhola Subject: RE: MPU E-21 RWO convert to Inj. (PTD 198-115) Guy Stan Porhola is working this well. Stan—can you get back to Guy on this? Thanks Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC 1 (907) 777—8333 (w) (907)444—2881 (c) From: Schwartz, Guy L(DOA) [ iailto:gwschwartz(aalaska.gov] Sent: Wednesday, September 02, 2015 4:38 PM To: Paul Chan Subject: MPU E-21 RWO convert to Inj. (PTD 198-115) Paul, Was looking at AOR for conversion of E-21 to injection. Can you elaborate a bit more on E-23 cementing status? It is a Kup injector in 1/4 mile area review but you don't mention the status of the cement in the SB/Ugnu sand in the write- up. ( mentions the 7" prod casing status only.)Assume the Schrader Bluff zone is behind the surface pipe and completely cemented but I need you to verify that. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz4alaska.gov). 2 Roby, David S (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Wednesday, September 02, 2015 11:55 AM To: Roby, David S (DOA) Subject: RE:Sundry application for MPU SB E-21 (PTD 198-115) conversion David, Answers to your questions regarding the conversion of E-21(PTD 198-115)to an waterflood injector: 1.) The E-21 injector will support E-32 producer. 2.) E-21 injector will only support E-32 producer. 3.) E-32 producer is also supported by E-12 injector in the same fault block. Stan From: Roby, David S (DOA) [mailto:dave.roby(aalaska.gov] Sent: Monday,August 24, 2015 3:28 PM To: Stan Porhola Subject: Sundry application for MPU SB E-21 (PTD 198-115)conversion ,tan. I'm reviewing your application to convert the subject well to an injector and have a couple of questions for you. 1) It appears that this well is being converted to provide injection support to the E-32 horizontal producer,is this correct? 2) If so, well E-21 provide injection support to any other wells? 3) Also,are there any other wells in the fault block that E-21 is completed in that are providing injection support to the E-32 well? Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 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 priviiegea 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 Dave Roby at(907)793-1232 or dave.roby a alaska.gov. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly Mildred Daretha I~Lowell Date: ~2/2/ Is/ ,~ TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Isl ' 'axT'Yl'�'TS cif' yy u'+ n^ n• u! c`^^ T! '•.m.:�°ac'4'",i°°Aw4T?'.W;ne4 +. -..N:; «.r vs. v'^g;'P.*wq',T" ^a'.mv h+9H,`Y'F_?M.a+w' , a m _ a .+. ..^!wm^<a .. .. r. m r. • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 11 S nit I "Fn � Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue V; , Anchorage, Alaska 99501 ' ' `' +" Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -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, fiC 2 ZU1 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) MPE -Pad 10/1012011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE-04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 ---.. MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE-32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE-33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 Well c° piim e Report File on Left side of folder 198-115-0 MILNE POINT UNIT SB E-21 50- 029-22894-00 BP EXPLORATION (AL^SK~) ~4C Roll #1: Start: Stop Roll #2: Start Stop MD 05990 TVD 04784 Completion Date: 9/3/98 Completed Status: 1-OIL Current: Name Interval D 8801 2 SPERRY GR/EWR4 OH L 4ARM CALIPER FINAL 150-5980 CH 5 L DGR/EWR4-MD FINAL 4141-5989 OH L DGR/EWR4-TVD FINAL 3683-4784 OH L INJP-SPIN/TEM/ FINAL PRES 9100-9515 CH 5 L INJP-SPIN/TEM/ FINAL PRES 9100-9515 CH 2 L PERF FINAL 5000-5874 CH 5 L RST-WTR FLOW FINAL 9100-9515 CH 5 L RST/WTRFLOW FINAL 9100-9515 CH 2 R SRVY RPT SPERRY 0-5990. OH T 8655 I SCHLUM BGT/PDC OH Daily WelIOps _ __--__ Was the well cored? yes no Comments: Sent Received T/C/D · 12/2/98 12/2/98 10/22/98 10/22/98 12/30/98 12/30/98 12/30/98 12/30/98 12/4/98 12/10/98 12/4/98 12/10/98 9/25/98 10/22/98 12/4/98 12/10/98 12/4/98 12/10/98 12/19/98 12/18/98 10/28/98 10/29/98 Are Dry Ditch Samples Required? yes~ And Received? yes no Analysis Description Received? yesC~ Sample Set # Wednesday, November 08, 2000 Page 1 of 1 r'l F! I I_1._1 ~ G S E FI~JI I-- I~ S To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Alaska 99501 Anchorage, MWD Formation Evaluation Logs - MPE-21, AK-MW-80343 December 30, 1998 MPE-21: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22894-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22894-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMFUrAL LETYER TO THE ATYENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 ,\/1::::. Date:DE C '.}.:,'".' ~998 ?,Ja~a C,'51 & ~ Cons. ~mm~it:m BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Si 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ....... STATE OF ALASKA .,_.., ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-115 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22894 4. Location of well at surface ~ .~ ~ ...... ~"--? i L.~~&..~ 9. Unit or Lease Name 3806' NSL, 1887' WEb, SEC. 25, T13N, R10E, UM ~i,':;i:..;i;i i~! il ~i;i '~ Milne Point Unit At top of productive interval ; -.~'~'~'~'~'~'~'~/~,,¢'~ !~!T~ 10. Well Number 3450' NSL, 637' WEb, SEC. 30, T13N, R11 E, UM .... !'t-, MPE-21 At total depth "~ ' i~: 11. Field and Pool 3381' NSL, 992' EWL, SEC. 30, T13N, R11 E, UM ' Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 57'I. ADb 028231 12. Date Spudded8/25/98 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re 16' N°' °f C°mpleti°ns8/28/98 9/3/98 N/A MSL One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD) I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 5990' 4784 FTI 5876' 4708 FTI [] Yes [] No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD/LWD 23. CASINGr LINER AND CEMENTING RECORD CASING S E~-I'ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BoTroM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 72# L-80 36' 150' 16" 250 sx Arcticset I (Approx.) 5-1/2" 15.5# J-55 34' 5961' 6-3/4" 615 sx Coldset Iii, 220 sx foamed, 175sx 'G' , *Performed top job with AOGCC approval with 100 sx coldset III 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter See attached sheet for SPF 2-3/8", 4.7#, J-55 5421' N/A MD TVD MD TVD 5526' - 5536' 4482' - 4489' 5548' - 5568' 4496' - 4509' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5624' - 5644' 4545' - 4557' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 45 bbls diesel 121840# Proplok 16/30 Badger behind pipe on all three perforated intervals 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) October 11, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb OIL GRAvITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA ..... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Schrader Bluff 'D' 5515' 4475' Top Schrader Bluff 'C' 5575' 4513' Schrader Bluff 'B' 5620' 4542' ~31. List of Attachments Summary of Daily Drilling Reports, Surveys ,32.1 hereby ce ~y hat t e for ~' is tr d correct to the best of my knowledge Signed :~.~a~~~.":~~-%,¢-"- c . /, ~¢,v-~ ..... f' ! Title Senior Drilling Engineer Date MPE-21 ,-~r--- ' ~ ~al ~h'~ 98_~ 5 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No./Approval No. J NSTRUCTIONS GENERAL.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM ,5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 08 Sep 98 09 Sep 98 10 Sep 98 11 Sep 98 12 Sep 98 13 Sep 98 Progress Report M Pt E Pad Well MPE-21 Page 1 Rig (~~ ¢~[~ Date 14December98 00:00-03:00 03:00-06:00 06:00-04:00 04:00-06:00 06:00-10:00 10:00-12:30 12:30-15:00 15:00-17:00 17:00-20:30 20:30-01:00 01:00-06:00 06:00-09:30 09:30-13:00 13:00-16:30 16:30-22:30 22:30-04:00 04:00-05:30 05:30-06:00 06:00-11:00 11:00-14:00 14:00-06:00 06:00-13:30 13:30-20:00 20:00-21:30 21:30-23:00 23:00-01:00 01:00-02:00 02:00-04:00 04:00-06:00 Duration 3hr 3 hr 22 hr 2 hr 4 hr 2-1/2 hr 2-1/2 hr 2 hr 3-1/2 hr 4-1/2 hr 5hr 3-1/2 hr 3-1/2 hr 3-1/2 hr 6 hr 5-1/2 hr 1-1/2 hr 1/2 hr 5hr 3 hr 16hr 7-1/2 hr 6-1/2 hr 1-1/2 hr 1-1/2 hr 2 hr 1 hr 2 hr 2 hr Activity Rig moved 100.00 % Rig waited: Orders Rig waited: Orders Rig moved 35.00 % Rig moved 100.00 % Fill pits with Seawater Rigged up BOP stack Tested BOP stack Made up BHA no. 1 Singled in drill pipe to 5372.0 ft Circulated at 5372.0 ft Drilled to 5828.0 ft Circulated at 5828.0 ft Circulated at 5828.0 ft Laid down 5828.0 ft of 2-7/8in OD drill pipe Conducted slickline operations on Slickline equipment - Tool run Worked on BOP - Pipe ram Rigged up Tubing handling equipment Ran Tubing to 3950.0 ft (2-3/8in OD) Serviced ESP Ran Tubing to 3500.0 ft (2-3/8in OD) Ran Tubing in stands to 5420.0 ft Rigged up Tubing hanger Removed BOP stack Rigged up Xmas tree Tested Xmas tree Functioned All tree valves Freeze protect well - 45.000 bbl of Diesel Installed Hanger plug Facility Date/Time 24 Aug 98 25 Aug 98 26 Aug 98 27 Aug 98 28 Aug 98 29 Aug 98 30 Aug 98 Progress Report M Pt E Pad Well MPE-21 Page 1 Date 14 December 98 12:00-15:00 15:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-08:00 08:00-11:30 11:30-12:30 12:30-13:00 13:00-16:00 16:00-00:00 00:00-04:00 04:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-21:00 21:00-23:00 23:00-06:00 06:00-06:30 06:30-14:00 14:00-15:00 15:00-16:00 16:00-16:30 16:30-18:00 18:00-21:00 21:00-22:30 22:30-00:30 00:30-02:30 02:30-06:00 06:00-06:30 06:30-21:00 21:00-22:30 22:30-02:30 02:30-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-11:30 11:30-16:00 16:00-17:00 17:00-17:30 17:30-01:00 01:00-04:00 04:00-04:30 04:30-06:00 06:00-07:30 07:30-11:00 11:00-13:00 13:00-14:00 14:00-16:00 Duration 3 hr 3hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 3-1/2 hr 1 hr 1/2 hr 3 hr 8 hr 4 hr 2 hr 1/2 hr 11-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr 2 hr 7 hr 1/2 hr 7-1/2 hr 1 hr 1 hr 1/2 hr 1-1/2 hr 3 hr 1-1/2 hr 2 hr 2 hr 3-1/2 hr 1/2 hr 14-1/2 hr 1-1/2 hr 4 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 3 hr 2 hr 4-1/2 hr 1 hr 1/2 hr 7-1/2 hr 3 hr 1/2 hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 2 hr 1 hr 2 hr Activity Rigged down BOP stack Rigged down High pressure lines Held safety meeting Rig moved 100.00 % Held safety meeting Rigged up High pressure lines Rigged up Divertor Rigged up Drillfloor / Derrick Tested Divertor Made up BHA no. 1 Drilled to 799.0 ft Rigged up sub-surface equipment - Survey instruments Drilled to 987.0 ft Held safety meeting Drilled to 2230.0 ft Held safety meeting Drilled to 2420.0 ft Circulated at 2420.0 ft Pumped out of hole to 1000.0 ft R.I.H. to 2420.0 ft Drilled to 3376.0 ft Held safety meeting Drilled to 4144.0 ft Circulated at 4144.0 ft Pumped out of hole to 3670.0 ft R.I.H. to 4144.0 ft Circulated at 4144.0 ft Pumped out of hole to 900.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 4144.0 ft Drilled to 4533.0 ft Held safety meeting Drilled to 5990.0 ft Circulated at 5990.0 ft Pumped out of hole to 1300.0 ft Circulated at 1300.0 ft R.I.H. to 5990.0 ft Circulated at 5990.0 ft Held safety meeting Pumped out of hole to 900.0 ft Pulled BHA Rigged up sub-surface equipment - Drilling tool / logs Rigged up Casing handling equipment Held safety meeting Ran Casing to 5962.0 ft (5-1/2in OD) Circulated at 5962.0 ft Held safety meeting Circulated at 5962.0 ft Mixed and pumped slurry - 329.000 bbl Rigged down Divertor Mixed and pumped slurry - 34.000 bbl Installed Casing head Ran Tubing in stands to 2000.0 ft Facility Date/Time 31 Aug 98 Progress Report M Pt E Pad Well MPE~21 Rig (j~[l) Page Date 16:00-17:00 17:00-18:00 18:00-18:30 18:30-20:30 20:30-05:00 05:00-06:00 Duration 1 hr 1 hr 1/2 hr 2 hr 8-1/2 hr 1 hr Activity Freeze protect well - 45.000 bbl of Diesel Pulled Tubing in stands to 0.0 ft Held safety meeting Installed Xmas tree primary components Laid down 6650.0 ft of 4in OD drill pipe Rigged down High pressure lines 2 14 December 98 Milne Point Unit, Alaska TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Bill Hill Herb Thackeray MP E-21 DRLG PERF 9-3-98 Date: 19-4-98 I II Objective: Run E-line GR/CCL correlation log and perforate the Schrader Bluff "OB" and "OA" sands. Sequence of Events: MIRU SWS. MU 20' perf gun and GR/CCL tool. RIH and tag PBTD. Log up to 5450' and correlate to MWD log 8/29/98. Drop back down to PBTD - corrected depth is 5871'. Log up to 5000' (above marker joints at 5071-5111 '). Drop back down and position gun #1. Perforate "OB" from 5624 - 5644' (20') with 2 spf (40 holes) 'Big Hole' charges at 0-180 phasing. POOH - all shots fired. MU and RIH with gun #2. Position in "OA" and perforate 5548 - 5568 (20') with total of 7 shots 'Big Hole' charges at 0-180 phasing. POOH - all shots fired. MU and RIH with gun #3. Position in "OA" and perforate 5526 - 5536 (10') with total of 5 shots 'Big Hole' charges at 0-180 phasing. POOH - all shots fired. RD MO SWS. Results: Ran GR/CCL from PBTD at 5871' to 5000'. Perforated Schrader Bluff "OB" and "OA" zones per program for limited entry frac completion. Tie in log/date Sperry_ MWD 8/29/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 5526 5536 3 3/8 ~ 0-180 5548 5568 3 3/8 .35 0-180 5624 5644 3 3/8 2 0-180 Page 1 ..... BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: John Hendrix FROM: Jim Fox DATE: RE: sept. 03, 1998 E-21 'OA / OB' DATAFRAC AND PROPLOK FRAC SERVICE CO'S.: Dowell, Halliburton, Peak, ProTechnics JOB SUMMARY This is the second radically descoped well to be fracced and utilized a limited entry frac design. Both the '©A' and 'OB' were fracced at one time rather than individually as in non-RDS wells. The first well, J-22, had indications of good response to it's frac design so the design for this well was modelled after the J-22 design. Unfortunately the results were not quite as favorable. The design plus excess was put away without problem however there did not appear to be any indication of tip screenout. The final design called for 112.5 M# of proppant. 125,600 lbs. of 16-30 Badger proppant was pumped, 121,800 made it behind pipe of which. 118,900 lbs. was coated with Halliburton PropLok resin at a concentration of 3/8 gal./100 lbs proppant. Crosslinked borate gel was used for the pad (injected at 5 bpm then increased to 20 bpm for the 0.5 ppg stage and finally to 40 bpm for the remainder of the slurry) and 0.5 ppg through 1 ppg stage, then switched to 75# HEC linear gel for the remainder of the slurry when the PropLok resin was pumped (due to incompatibility with the guar gel). The re-design called for the HEC to start in the 1 ppg stage and slightly larger middle stages but these were trimmed back due to limited vol. of HEC gel (redesign required significantly more than the original design). The slurry was displaced with 30 bbl. of HEC gel followed by 9.8 ppg brine (for freeze protection) to within 18.5 bbl. of the top perforation. As noted above there was very little or no net pressure build throughout the procedure. It was not realized until after the job that the PropLok resin was shut off a little prematurely. It was shut in when the order was given to cut proppant and not when the blender was almost empty, As it turns out the last of the treated proppant should have been just above the perforations when the pumps were shut down. To determine proppant placement and fracture extension a series of three Protechnics RA tracers were pumped (at a concentration of 0.4 mg/k) in the following stages of the slurry: Sb LZW tracer in the 0.5 ppg to 3 ppg stages, Sc ZW tracer in the Page 2 4 ppg through 5 ppg slurry, and Ir ZW tracer in the 6 ppg through 8 ppg slurry. 'The wellbore will be logged following the wellbore cleanout. Prior to the frac a ball out, injectivity test, and two data fracs (one gel, one water) were performed. The ball out was performed with 90 ea. 7/8" dia., 1.3 s.g. ball sealers pumped at intervals of 1 ball every two seconds in 45 bbl. of 2% KCl water, displaced to the perfs, and over displaced by 63 bbls. (30 bbls. past the bottom perforation) at a rate of 15 bpm. There was some pressure response (130 to 250 psi build ) starting as soon as the ball sealers reached the perfs. Immediately following the wellbore was surged three times to dislodge the ball sealers from the casing wall. Each surge consisted of rapidly bleeding the pressure back to the open top tank until the pressures fell from approx. 900 psi to nearly zero and stabilized (a period of 20 sec. each). The pressure falloff was monitored for an hour before going to the injectivity test. This consisted of 120 bbl. of 2% KCl water injected at 20 bpm. and monitor pressure falloff for 1 hr. This was then followed by two data fracs w/1 hr. pressure falloff surveys. The first consisted of 200 bbl. of 2% KCl at 40 bpm, The second consisted of 300 bbl. of 30 Cf crosslinked borate gel (YF130), overdisplaced into the formation by 5 bbl. BALL OUT Design Rate, Bbls Ball Number of Ball Final STP, psi Fluid Type BPM Pumped Type Balls Action? 15 200 7/8" 1.3 SG 90 yes 1700 2% KCl INJECTIVITY TEST Design Rate, Bbls Max Rate, Final treat. ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 20 120 20.1 1643 1007 na 0.66 DataFRAC (2% KCl) Design Rate, Bbls Max Rate, Final Treating ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 40 200 40.1 2362 1049 na 0.67 Page 3 DATA FRAC # 2 (XL borate) Design Rate, Bbls Max Rate, Final Treating ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 40 300 40.1 1922 1223 na 0.71 FRAC Sand Prop Prop Proppant Coated Tresaver pumped, # behind pipe, left in csg, size/type Prop, # rubber left in Job was # # hole? Flushed 125,560 121,840 3,720 16/30 Badger 118,850 No TIME OPERATIONS SUMMARY 09/03/98 2010 Safety meeting 2100 Set Treesaver - Pressure test treating lines to 5250 psig. 2118 Start ball out. 2218 Start injectivity test. 2325 Start datafrac #1 (water) 09/04/98 0041 Start datafrac #2 (gel) 0350 Start frac ri PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL BALL OUT DISPLACEMENT = 131.5 BBLS 2118 0 / 15 544 0 0 Start ball out -drop 1 ball every 2 sec. 2118.5 15 1702 5.2 5.2 At rate - start dropping ball sealers. 2119.5 15 1616 28 2121.3 14,9 1593 45 All ball sealers launched. 2124 15.1 1542 90 2125 15.1 1469 · 106 2126 14.9 1451 119 2127.3 14.4 1579 137 First ball sealer reaching perfs. 2130 15.1 1701 180 2131.5 15.0 1700 200 S/D 2132 back surge (approx. 20 sec.) 2132.5 back surge (approx. 20 sec.) 2133 back surge (approx. 20 sec.) 2135 0 892 2140 0 837 INJECTIVITY TEST 2219 0/20 549 0 200 I Start injectivity 2219.5 20 1670 6 206 @ rate 2221.5 20.1 1648 54 254 2223 20.0 1643 81 281 2224 20.1 1635 100 300 2225 20 / 0 1643 120.1 320.1 S/D pumps and monitor pressure falloff. ISIP = 1007 2228 0 965 2230 0 943 2235 0 906 2240 0 865 2250 0 787 2300 0 718 2310 0 668 DATA FRAC #1 Water onl, ., 2326 0 / 40 630 0 320.1 2327 40 2371 20 340 At rate 2328 40.1 2325 68 388 2330 40.1 2293 143 463 2331.5 40 / 0 2362 200.1 520.3 S/D pumps and monitor pressure falloff. ISIP -- 1049 2335 0 979 2340 0 943 2350 0 888 09/04/91) 0000 0 828 0010 0 773 0020 0 732 0030 0 691 0040 0 663 DATA FRAC (YF-130 g 0041.5 0 / 20 654 0 520.3 Prepare to start pumping 30 # borate XL. 0042.5 20 1670 9 529 At displacement rate. 0045 20.2 1579 50 570 0048 20.0 1533 110 640 0049 20 / 40 ' 1565 131 651 Gel at perfs. Ramp rate up to 40 bpm. 00~0 40 t 1918 150 670 At design rate. 0051.5 40.1 1899 220 740 0053.5 40.0 1977 300 820 Switch from gel to KCI flush 0054.5 39.9 2041 340 860 0056.8 40 / 0 1922 434.4 954.7 S/d pumps and monitor pressure falloff. ISIP = 1223 psig 0100 0 1190 0105 0 1162 0110 0 1135 0120 0 1112 0130 0 691 0140 0 663 FRAC 0350 0 833 0 955.0 Prepare to start frac 0351.5 0 / 5 833 0 955 Start displacing XL guar gel pad ad Iow rate 0352.5 5.0 1373 5.4 950 0354 5.0 1405 12.8 968 0356 5 / 20 1291 24 979 Start slurry and increase rate. 0358 20.0 1497 39 1017 0359.4 20 / 40 1812 90 1045 Increase rate to design rate and start 1 ppg. stage with HEC gel and PropLok 0400 40 1890 1086 Pad on perfs 0403 39.8 2046 1196 0404 40.0 2055 1235 I ppg on perfs 0406 39.9 2064 1316 3 ppg on perfs. 0408 40.0 2055 1400 Pod fluid temperature 77 deg. 0409 40.0 2055 1436 5 ppg on perfs. 0410.5 39.9 2057 1491 6 ppg on perfs. 0413 40.1 1941 1600 7,3 ppg on perfs. Pod temp. - 76 deg. F 0414.5 40.0 1931 1650 8 ppg on perfs. 0416 40.1 1876 1720 Cut sand at silo. 0416.5 40.4 1863 1735 Flush called. 0418 40.0 1808 1800 0419 40 / 0 1790 1848.6 S/D pumps with 18.5 bbls. of underdisplacement FLUIDS PUMPED DOWNHOLE Bailout 200 BBL Injectivity 120 BBL DataFRAC I 200 BBL DataFRAC II 434 BBL FRAC: 893 BBL TOTAL 1847 BBL Page 6 .~_,, .-_ f HEC QUALITY CONTROL CHECK HEC HEC I KCI HEC PIPEI XL XL pH TEMP TEMP VISCOSITY TIME TIME pH DF/FRAC 6.18&7.24 82&89 I101to102 137&100 n/a N/A N/A GEL QUALITY CONTROL CHECK WF30 WF30 XL TIME I Activator PIPE pH TEMPt Concentration TIME DF/FRAC 8.7 96 1:48 t 4.0#/1000 3:30 min ! FLUID ADDITIVES F-75N (surfactant) - 1 gal/1000 gal on the data frac fluid Halliburton surfactant was used for the entire frac job (.i.e. pad and slurry) J-218 (breaker) - 5 ppt gal on crosslinked fluids J-466 (breaker) - 2 ppt gal on crosslinked fluids J-475 (breaker) - 5 ppt gal on HEC stages J-465 (activator) - 5 gpt on crosslinked fluids L10 (crosslinker) - 2.2ppt gal on crosslinked fluids OOg~XAs :ja~ · S =~ 'n I A bi :=~ c; L--~ N 1-1 "-I I I:::1 0 ,O0'Z9 - ~.t~EOg/VilAI)lV #qo£ g6-~snf~nv-gz aTeo ~fa~ns 7se-/ OOP6gE~6ZOO~'ldV :Jabl Jno,~ 8661, '~aq~ueTdas l~lOd3EI /,3A~/n S ~~6~00 OCld VX'd8 ~I f ! d3S /,~-'~d/A/ Ped w____= 7U!Od aul!!AI f;, auoz aUeld aTe~S mlSelV 7!uti ~U!Od aUl!lAI Sperry-Sun Drilling Services Survey Report for MPE-2'I Your Ref: AP1.500292289400 Milne Point Unit Measured 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) (rt) (ft) (°/~ 00fi) (ft) Alaska State Plane Zone 4 Milne Point E Pad MPE.21 Top 0.00 0.000 0.000 -57.00 0.00 366.60 0.460 249.360 309.60 366.60 458.63 0.250 114.560 401.63 458.63 550.86 1,600 105.800 493.84 550.84 642,41 2.100 90.600 585.34 642,34 0.00 N 0.00 E 6016343.63 N 569257.52 E 0.00 0.52 S 1.38 W 6016343.10 N 569256.15 E 0.125 -1.29 0.73 S 1.54 W 6016342.88 N 569255.99 E 0.718 -1.42 1.17 S 0.12 W 6016342.46 N 569257.41 E 1,467 0.04 1.53 S 2.79 E 6016342.12 N 569260.32 E 0.761 2.97 MPE-21 Gyro 709.00 2.900 85.100 651.87 708.87 795.00 4.600 98.000 737.68 794.68 890,00 7.300 105.100 832.16 889.16 982.00 8.600 108.400 923.28 980.28 1078.00 8.590 109.730 1018.20 1075.20 1.40 S 5.69 E 6016342.28 N 569263.22 E 1.253 5.83 Fimt Gymdata Su~ey 1.70 S 11.27 E 6016342,04 N 569268.81E 2.195 11.40 3.80 S 20.87 E 6016340.03 N 569278.43 E 2.940 21.20 7.49 S 33.04 E 6016336.45 N 569290.63 E 1.497 33.76 12.18 S 46.60 E 6016331.89 N 569304.23 E 0,207 47.83 Last Gyrodata Suwey MPE-21 1114,61 8.350 110.610 1054.41 1111.41 1210.53 7.900 112.770 1149.37 1206.37 1306.77 9.550 110.11'0- 1244.49 1301.49 1399.19 9.400 109.960 1335.65 1392.65 1494.20 8.990 108.210 1429.44 1486.44 1590.15 11.590 105,520 1523.84 1580.84 1686,45 12.700 107.130 1617.98 1674.98 1782.11 13.530 105,410 1711.15 1768.15 1877.10 15.120 100.460 1803.18 1860.18 1974.58 16.710 100,900 1896.93 1953,93 14.04 S 51.66 E 6016330.07 N 569309.31 E 0.745 53,10 19.04S 64.26 E 6016325.19 N 569321.95 E 0.567 66.27 24.34S 77.86 E 6016320.01N 569335.60 E 1,765 80.47 29.56 S 92.15 E 6016314.93 N 569349.94 E 0,164 95.34 34.53 S 106.49 E 6016310.10 N 569364.33 E 0.522 110,23 39.45 S 122.91E 6016305.33 N 569380.79 E 2.755 127.16 45,15 S 142.34 E 6016299.80 N 569400.28 E 1.205 147.20 51.23 S 163.18 E 6016293.92 N 569421.17 E 0.959 168.68 56.43 S 186.08 E 6016288.93 N 569444.11 E 2.111 192.07 61.39 S 212.34 E 6016284,22 N 569470.42 E 1,636 218.77 Continued,.. 14 September, 1998 - 10:48 - 2 - DrillQuest Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPE-21 Your Ref: AP1-500292289400 Alaska State Plane Zone 4 Milne Point E Pad Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth Northings (ft) (ft) (fi) (ft) 2070.22 18.280 100.410 1988.14 2045.14 66.70 S 2164.95 19.480 99.440 2077.77 2134.77 71.97 S 2260.94 19.890 97.960 2168.15 2225.15 76.86 S 2355.11 21.180 96.110 2256.34 2313.34 80.89 S 2451.33 22.150 95.310 2345.76 2402.76 84.42 S 2546.81 23.310 93.550 2433.82 2490.82 87.25 S 2642.59 25.410 92.940 2521.07 2578.07 89.48 S 2737.96 27.230 92.710 2606.55 2663.55 91.56 S 2835.03 28.660 92.000 2692.30 2749.30 93.42 S 2930.17 30.790 93.060 2774.92 2831.92 95.52 S 3025.43 32.240 92.690 2856.12 2913.12 98.01 S 3121.36 33.940 92.350 2936.49 2993.49 100.31 S 3217.19 35.580 90.450 3015.22 3072.22 101.63 S 3313.15 38.130 91.320 3092.00 3149.00 102.53 S 3408.82 40.540 93.630 3165.99 3222.99 105.18 S 3504.34 43.310 98.170 3237.07 3294.07 111.80 S 3599.91 46.840 95.600 3304.56 3361.56 119.87 S 3694.65 49.600 96.160 3367.67 3424.67 127.11 S 3790.81 52.050 96.700 3428.41 3485.41 135.47 S 3885.95 54.620 96.770 3485.22 3542.22 144,42 S 3984.72 57.260 97.24D_ 3540.53 3597.53 154.40 S 4080,84 57.850 99.030 3592.10 3649.10 165.88 S 4090,68 57.700 98.300 3597.35 3654.35 167.13 S 4166.26 57,450 98.760 3648.60 3705.60 179.10 S 4281,44 56.900 99.060 3700.19 3757.19 191.49 S 4376,70 56.380 98.970 3752.58 3809.58 203.96 S 4471.40 55.380 99.890 3805.70 3862.70 216,80 S 4569.03 55.210 100.490 3861.28 3918.28 231.00 S 4664.82 56.430 98.530 3915,10 3972.10 244.08 S 4759.17 56.230 99.710 3967.41 4024.41 256.52 S Local Coordinates Global Coordinates Eastings Northings Eastings (ft) (fi) (fi) 240.60E 6016279.17N 569498.73E 270.79 E 6016274.18 N 569528.97 E 302.75 E 6016269.59 N 569560.97 E 335.53 E 6016265.86 N 569593.79 E 370.88 E 6016262.66 N 569629.17 E 407.66 E 6016260.17 N 569665.97 E 447.10 E 6016258.31N 569705.43 E 489.33 E 6016256.62 N 569747.68 E 534.78 E 6016255.18 N 569793.15 E 581.90 E 6016253.52 N 569840.29 E 631.63 E 6016251.49 N 569890.04 E 683.96 E 6016249.68 N 569942.38 E 738.57 E 6016248.87 N 569997.00 E 796.11E 6016248.50 N 570054.55 E 856.68 E 6016246.42 N 570115.14 E 920.12 E 6016240.38 N 570178,64 E 987.28 E 6016232.95 N 570245,87 E 1057.55 E 6016226.35 N 570316.20 E 1131.62 E 6016218.69 N 570390,35 E 1207.40 E 6016210.44 N 570466,21E 1288.61E 6016201.22 N 570547.51E 1368.90 E 6016190.48 N 570627.90 E 1377.13 E 6016189.30 N 570636.14 E 1456.92 E 6016178.08 N 570716.04 E 1535.93 E 6016166.43 N 570795.17 E 1614.51 E 6016154.69 N 570873.86 E 1691.85 E 6016142.57 N 570951.31 E 1770.85 E 6016129.11 N 571030.44 E 1849.00 E 6016116.75 N 571108.70 E 1926.52 E 6016105.03 N 571186.34 E Dogleg Vertical Rate Section (°/100fi) (fi) 1.649 247.49 1.309 278,12 0.672 310.45 1.533 343.47 1.054 378.97 1.408 415.79 2.208 455.16 1.911 497.28 1.512 542.55 2.306 589.51 1.536 639.11 1.783 691.25 2.051 745.53 2.712 802.65 2.947 863.00 4.299 926.75 4.155 994.38 2.946 1064.98 2.585 1139.49 2.702 1215.79 2.702 1297.59 1.687 1378.70 6.458 1387.03 0.483 1467.70 0.636 1547.67 0.552 1627.22 1.327 1705.59 0.534 1785.79 2.118 1864.99 1.062 1943.50 Comment Continue~.. 14 September, 1998 - 10:48 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for MPE-2'I Your Ref: API-500292289400 Milne Point Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth Nothings (~) (fi) (fi) (fi) 4856.26 55,760 100,410 4021.71 4078.71 270.58 S 4951.76 56.020 99.370 4075.26 4132.26 284.16 S 5046.99 53.070 98.160 4130.50 4187.50 295.99 $ 5143.44 52.280 98.200 4188.98 4245.98 306.91S 5238.47 52.260 99.130 , 4247.13 4304,13 318.23 S 5334.56 51.930 99.770 4306.17 4363.17 330.68 S 5430.14 51.610 100.150 4365.31 4422,31 343.66 S 5526.19 50.840 100.670 4425.47 4482.47 357.19 S 5620.95 50.210 100,740 4485.71 4542,71 370.78 S 5716.49 49.960 101.190 4547.01 4604.01 384.71S 5811.52 49.110 101.250 4608.68 4665.68 398.78 S 5908.28 48.160 101.200 4672.63 4729.63 412.92 S 5933.47 48.060 101.240 4689.45 4746.45 416.57 S 5990.00 48,060 101.240 4727.23 4784.23 424.76 S Local Coordinates Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (fi) (°/100fi) (fi) 2005.77 E 6016091.71N 571265.72 E 0,769 2023.92 2083.67 E 6016078.85 N 571343.74 E 0.942 2102.95 2160.32 E 6016067.73 N 571420.50 E 3.266 2180.50 2236.23 E 6016057.53 N 571496.51 E 0.820 2257.19 2310.54 E 6016046.89 N 571570.91E 0.774 2332.35 2385.32 E 6016035.14 N 571645.81E 0.628 2408.13 2459.27 E 6016022.84 N 571719.88 E 0.458 2483.17 2532.92 E 6016010.00 N 571793.65 E 0.906 2557.98 2604.79 E 6015997.08 N 571865.65 E 0,667 2631.04 2676.73 E 6015983.82 N 571937.71 E 0.446 2704.21 2747.65 E 6015970.41N 572008.76 E 0,896 2776.39 2818.88 E 6015956.93 N 572080.12 E 0.983 2848.88 2837.27 E 6015953.46 N 572098.54 E 0.414 2867.61 2878.52 E 6015945.64 N 572139.86 E 0,000 2909.58 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 97.910° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5990.00ft., The Bottom Hole Displacement is 2909.69ft., in the Direction of 98.394° (True). Comment Projected Survey Alaska State Plane Zone 4 Milne Point E Pad Con~nued... 14 September, '1998.10:48 - 4 - DrillQuest Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPE-21 Your Ref: API-500292289400 Alaska State Plane Zone 4 Milne Point E Pad Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 0.00 0.00 0.00 N 0.00 E 709.00 708.87 1.40 S 5.69 E 1078.00 1075.20 12.18 S 46.60 E 1078.00 1075.20 12.18 S 46.60 E 5990.00 4784.23 424.76 S 2878.52 E Comment Tie-on Survey First Gyrodata Survey Last Gyrodata Survey Tie-on to Gyrodata Survey Projected Survey 14 September, 1998 - 10:48 - 5 - DrillQuest GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12005 Company Alaska OII & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 10/29/98 Well Job # Log Description Date BL Sepia LIS Tape ~APE-21 '~t,,~'~ 98548 BGT (PDC) 980829 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: OCT 1998 Alasl~a Oii ~, ~a~ ~ofls. ~mmissio~ Anchora~o Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI-rN: Sherr~ Received ~;~"' ~.,4 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 11592 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 10/22/98 Well Job # Log Description Date BL Sepia LIS Tape MPB-03 PRODUCTION PROFILE 980823 1 1 MPB-03 iGAS LIFT SURVEY 980823 1 1 MPB-03 'DIGITAL FLUID IMAGER 980823 1 1 MPB-04 :PRODUCTION PROFILE 980823 1 1 MPB-04 'GAS LIFT SURVEY 980823 1 1 MPB-04 DIGITAL FLUID IMAGER 980823 1 1 MPB- 10 PRODUCTION PROFILE 980823 1 1 MPB-10 GAS LIFT SURVEY 980823 1 1 MPB-10 DIGITAL FLUID IMAGER 980823 1 1 MPB- 15 PRODUCTION PROFILE 980825 1 1 MPB-15 GAS LIFT SURVEY 980825 1 1 MPB-15 DIGITAL FLUID IMAGER 980825 1 1 MPE-21 FOUR ARM CALIPER 980829 1 i MPE-30 FOUR ARM CALIPER 980731 1 1 MPE-33 FOUR ARM CALIPER 980811 1 1 MPG-01 WATER FLOW LOG 980717 1 1 MPH- 10 GAMMA RAY/COLLAR LOG 980825 1 ! PLEASE ACKNOWLEDGE RECEIPT By SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 . Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A1ZN: Sherrie ~ ................. .//? GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 11515 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPB-03 JEWELRY LOG 9 8 0 8 2 3 I 1 MPB-04 JEWELRY LOG 9 8 0 8 2 3 1 1 MPB-10 JEWELRY LOG 9 8 0 8 2 3 1 1 M PB-15 ! JEWELRY LOG 9 8 0 8 2 5 I 1 M P B-20 JEWELRY LOG 9 8 0 91 1 I 1 M PC-22A TUBING PUNCHER RECORD 9 8 0 8 0 2 I 1 M P E-21 PERFORATING RECORD 9 8 0 9 0 3 I 1 M PE-30 i PERFORATING RECORD 9 8 0 9 0 7 I 1 M P H- 10 I PERFORATING RECORD 9 8 0 8 2 7 I 1 M PH-10 PERFORATING RECORD 9 8 0 8 2 9 I 1 M PH-10 PERFORATING RECORD 9 8 0 8 31 I 1 M P H-11 PERFORATION RECORD 9 8 0 8 0 8 I 1 M P H- 14 PERFORATING RECORD 9 8 0 7 2 8 I 1 M PH-14 PERFORATING RECORD 9 8 0 7 3 0 1 1 M PH-14 PACKER SETTING RECORD 9 8 0 8 01 I 1 M PJ-22 PERFORATION RECORD 9 8 0 7 3 0 I 1 M PJ-22 BRIDGE PLUG SET RECORD 9 8 0 813 I 1 M PJ-22 PERFORATION RECORD 9 8 0 817 I 1 MPK-21 /4 1 (-- JEWELRY LOG 980913 I 1 9/25/98 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK/,8'.~5~)3 D !:! I I-I- I IM I~ SEI:I~ICE S WELL LOG TRANSMITY~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPE-21, AK-MW-80343 December 2, 1998 1 LDWG formatted Disc with verification listing. APl#: 50-029-22894-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMI'ITAL LE'VFER TO ~ ATYENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company TONY KNOWLE$, GOVERNOR ~LASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 20. 1998 T. Brcnt Rccvcs Drilling Enginccring Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Rc: Milne Point Unit MPE-21 BP Exploration (Alaska) Inc. Permit No: 98-115 Sur Loc: 3806'NSL 1887'WEL. Sec. 25. T13N. R10E. UM Btmholc Loc: 3433'NSL. 4462'WEL. Sec. 30. T13N. R11E. UM Dcar Mr. Rccves: Enclosed is thc approvcd revised application for permit to drill the above rcferenced 'well. The provisions of thc original approved permit datcd Jul3' 10. 1998, arc in cffect for this revision. Si~~'~'x~'" ,,~ / Robcrt N. Christcnson. P.E. Commissioncr BY ORDER OF THE COMMISSION dlf/Enclosurcs CC: Dcpartmcnt of Fish & Game. Habitat Section W/o cncl Dcpartmcnt of Environmcntal Conservation v,'/o cncl ' STATE OF ALASKA ALASKA.-~,L AND GAS CONSERVATION COI~'r,,~tlSSION PERMIT TO DRILL 20 AAC 25.005 REVISED: 08/12/98 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [--I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 57' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028231 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3806' NSL, 1887' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3506' NSL, 4967' WEL, SEC. 30, T13N, R11E, UM MPE-21 At total depth 9. Approximate spud date Amount $200,000.00 3433' NSL, 4462' WEL, SEC. 30, T13N, R11 E, UM 08/20/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 779'I MPE-07, 21.7' at 900' 2555 5803' MD / 4752' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' MD Maximum Hole Angle 51.888° Maximum surface 1532 psig, At total depth (TVD) 4384' / 1960 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 16" 13-3/8" 72# L-80 BTC-Mod 120' 31' 31' 151' 151' 250 sxArcticsetl(Approx.) 6-3/4" 5-1/2" 15.5# J-55 BTC-Mod 5773' 30' 30' 5803' 4752' 395 sx CS III, 95 sx Foamed, 102 sx 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate . Production Liner ' '--~ ~ Perforation depth: measured ~8,S~¢~ 0il & Gas Cons, C0m~issM~ P i (? i i Anchorage ~'~ .~ - true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: R. George Scott, 564-586¢~ Torn Maunder, 564-4429 Prepared By Name/Number: Kathy Carnpoarnor, 564-5122 21. I hereby certify that the~g is tru~/d~rrect to the,best of my knowledge Signed ~ ' ' . ~ T. Brent~~-~/¢¢/?/ /~'~'~'~Uf'~~Title Drilling EngineeringSupervisor Date / { ' / Commission Use Only ' ~ Permit Number I APl Number I Approval Date See cover letter 98-115I 50-029-22894I 07/10/98 for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required []Yes [] No Hydrogen Sulfide Measures []Yes ,J~ No Directional Survey Required ~]Yes [] No Required Working Pressure for DOPE []2M; []3M; []5M; []10M; []15M Other: ORIGINAL SIGNED-BY by order of Approved By Robert N ~hristc, n~nq Commissioner the commission Date¢~'f_~ Form 10-401 Rev. 12-01-85 Submit In Triplicate ..r ~, STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 ,/LAC 25.005 REVISED: 08/12/98 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 57' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028231 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3806' NSL, 1887' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3506' NSL, 4967' WEL, SEC. 30, T13N, R11 E, UM MPE-21 At total depth 9. Approximate spud date Amount $200,000.00 3433' NSL, 4462' WEL, SEC. 30, T13N, R11E, UM 08/20/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 779'I MPE~07, 21.7' at 900' 2555 5803' MD / 4752' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' MD Maximum Hole Angle 5~-888° Maximum surface 1532 psig, At total depth 0WD) 4384' / 1960 psig :18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 16" 13-3/8" 72# L-80 BTC-Mod 120' 31' 31' 151' 151' 250 sx Arcticset I (Approx.) '6-3/4" 5-1/2" 15.5# J-55 BTC-Mod 5773' 30' 30' 5803' 4752' 395 sx cs Ill, 95 sx Foamed, 102 sx 'G' .. 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measuredDUPLII ATE true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: R. George Scott, 564-5862~...~ Tom Maunder, 564-4429 Prepared By Name/Number: Kathy Carnpoamor, 564-5122 2i. I hereby certify that the ~g is tru..~Z~rrect" / to the,best of my knowledge Signed~( ,/'/~. ~/'¢//~/¢/¢~_...~..j ' . - ¢¢:r///~/_~.,~-- -- T. Sren,~/ /2- ~r.~_¢;/ ,/'2/;/ // ~,--%.f ¢/f,,-,..~ ~tle Drilling Engineering Supervisor Date ' ~ Commission Use Only Permit Number APl Number Approval Date See cover letter 98-115 50-029-22894 07/10/98 for other requirements Conditions of Approval: Samples Required []Yes ~No Mud Log Required []Yes I~'No Hydrogen Sulfide Measures []Yes1~ No Directional Survey Required []Yes [] No Required Working Pressure for DOPE •2M; []3M; ~5M' [] 10M; [] 15M Other: ORIGINAL SIGNED'BY by order of Approved By Robert N. Christerl$o~ Commissioner the commission Date " ., Shared Services Drilling Contact: R. George Scott J Well Name: IMP E-21 IType of Well (producer or injector): Well Plan Summary ISchrader Bluff Producer 564-5862 Surface Location: 3806' FSL, 1887' FEL, S25 T13N R10E UM Target Location: 3506' FSL, 4967 FEL, S30 T13N R11 E UM Bottom Hole Location: 3535'FSL, 4456' FEL, S30 T13N R11E UM I AFE Number: 1337135 I Estimated Start Date: I 20 August 98 I I Rig: I Nabors27E I Operating! days to complete: I MD: I SS0 ' I I TVD: 147S=' I I Well Design: Formation Markers: 16.0 I KBE: 157 ft I Schrader Bluff Producer Formation Tops MD TVDSS KOP 400 400 Base of Permafrost 1807' 1735' Top of Ugnu 4320' 3762 Top M Sand 4732' 4016' Top NA (Target) 5135' 4266' Top of the N-A (EMW 8.6 ppg) Base Of Schrader 5503' 4502' TD 5803' 4695' TD at 300' MD past base of Schrader Bluff Casin~l/Tul: in~l Program: Hole ~ize ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tb~l O.D. MD/TVD MD/TVD (bkb) 16" 13-3/8" 72# L-80 BTC-MOD 120' 31'/31' 151'/151' 6-3/4" 5-1/2"** 15.5# J-55 BTC-MOD 5773' 30'/30' 5803'/4752' Internal yield pressure of the 5-1/2 .... 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/fi) to the reservoir at _+4384' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1960 psi (8.6 ppg EMW), is 1532 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). ** ** Note: The top joint in the 5-1/2" surface casing consists of a 7"x5-1/2" X-over from 26# BTC-MOD L-80 to, 5-1/2" 15.5# J-55 BTC-MOD, this is required to accommodate the penetrater offset. Properties of this top joint are Coupling O.D.-7.656", I.D. 6.276", Drift-6.151", Collapse-5410psi, Burst-7240psi, yield-604M lbs. Two 5-1/2" 15.5# 20' marker joints will be placed around 100' above the top of the NA. MP E-21 Well Plan PAGE 3 11 July 98 Logging Program: Open Hole Logs: MWD directional only from surface to 2200' MD. + 4-Arm Caliper Log From T.D. to. 151' M.D. (Base of 13-3/8" Conductor.*) MWD directional and LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr. ~. Cased Hole Logs: A Gamma Ray/CCL LOG WILL BE RUN FROM T.D TO THE BASE OF THE CONDUCTOR after drilling rig release. Mud loggers are NOT required for this well. *A conditioning trip will be made if required to assure running of the caliper. Mud Program: ISpecial design considerations lAn inhibitive polymer mud is planned from surface to TD. Solids control is critical to the success of the system. Surface Mud Properties:0-3000' I Density Marsh Yield LSRV 10 min pH Fluid (PPG) Viscosity Point gel Loss 8.6 150 40 50,000 8.5 NC to 9.0 Production Mud Properties:3000'-TD I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss 9.0 50 30 14 16 8.5 <6 to to to to 9.5 60 35 9.0 LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17 Well Control: Well control equipment consists of: Rig (Nabors 27E) ,13-5/8" 5000 psi W.P.Annular and 3000 psi Diver[er with 10" Diver[er Line. A Completion/Workover Rig with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diver[er, BOPE, and drilling fluid system schematics are attached. Directional: I KOP: 1400' MD Maximum Hole Angle: Close Approach Well: 51.888° at 4100'MD MPE-05,MPE-07,MPE-10 will need to be shut in and secured while drilling by the close approach. Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #4 facility. Fluids Handling: All drilling and completion fluids will be hauled to Drill Site #4 or CC-2A for injection. Annular Injection: Not planned for this well. MP E-21 Well Plan PAGE 4 1 1 July 98 MP E-21 Proposed Summary of Operations , 2. 3. 4. 5. , , , 10. Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 27E rig. NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program. Drill a 6-3/4" surface hole as per directional plan. Run Directional MWD from surface to 2500'+'MD, Note: If bit performance and hole conditions allow the first bit should be kept in the hole beyond this depth but pulled +/- 200'MD above the top of the Ugnu (4,120' MD). POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP. Drill 6-3/4" hole to TD as per directional plan. Stand back drill string and run 4-Armed Caliper from the base of T.D. to the bottom of the 13-3/8" conductor. ( A 2-7/8" work string will be set back for emergency operation of the port collar) Following this, the casing will be cemented. Run and Cement 5-1/2", 15.5#, J-55, Buttress-Modified casing. Refer to attached Detailed Cement Program and Back-up Port Collar operating Procedure. Displace casing with sea water and freeze protect from 2000' MD to Surface. Following the cementing of the well and the landing of the 7" x 5-1/2" landing joint the casing will be tested to 3500 psi.(74% of internal yield). The Diverter system will be rigged down and the frac head provided by the Well Services group installed, and tested to the same pressure. See attached bit program for recommended bits. In the upper hole a 6-3/4" MFI5L IADC 4-4-7X is recommended. This will be changed out to a 6-3/4" S-94PX bit at +2500' (or deeper as in step 5) which will be drilled to TD. POST DRILL AND CASE: Nabors Rig 4ES will run the completion on this well following rigless completion work. 1. The first part of the completion is planned to be done rigless. This includes perforating, frac'ing clean out. Rig 4ES is planned to be used for setting the screen and for the final running of the completion assembly. The well will be completed with 2-3/8" tubing. 2. A completion program will be issued for this. It is planned to run an ESPC completion with Centrilift Heat Trace to a depth of 5200' MD. Install Surface Lines and Wellhouse and turn well over to production. MP E-21 Well Plan PAGE 5 11 July 98 DRILLING HAZARDS AND RISKS: See the latest Milne Point E-Pad Data Sheet for offset information on E pad. The MPU PE group will be perforating, hydraulic fracturing and cleaning out this as per the completion program. 1. Hydrates: HYDRATES HAVE BEEN ENCOUNTERED ON WELLS DRILLED AT MILNE POINT 'E' PAD, in the interval of 2100-2400'MD just below the permafrost as summarized on the Pad data sheet. If encountered mud will be treated with 1-1.5 ppb Lechithin weight up to 9.8 ppg. (See Attached Mud Program). Minor hydrates have been encountered rec 2. Close Approach: The E-05, E-07 and E-10 wells are close approach and will need to be shut in and secured while drilling the close approach. E-05 35.86' @ 1495.26', E-0721.7'@ 900.02',E-10 51.83' @ 2114.27'. 3. Lost Circulation: There have not been any significant lost circulation incidents reported on any of the E Pad wells. HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. Recently over the period of 1994-96 no stuck pipe problems have occurred but tight hole problems have been experienced. 4. Stuck Pipe Potential: There have been several STUCK PIPE incidents on Milne Point 'E' Pad. The E-22 and E-3 wells experienced stuck pipe incidents. These wells were drilled in 1994 and 1990 respectively. Be especially aware of the need to maintain good hole cleaning properties and practices through the upper hole and the heavy clay sections REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE STUCK PIPE INCIDENTS. The frequency of wiper trips should be a minimum of once every 1000' as determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions using Hi/Low sweep combinations. If heavy gravel's are encountered while drilling the surface hole section, operations should be immediately stopped and the mud funnel viscosity is increased to help clean hole. 5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of 0.4476 psi/ft (8.6 ppg EMW) and a pressure of 1960 psi in the middle of the Schrader Bluff at 4384' TVDSS. 6. Directional Drillinq Concerns MP E-21 will be an ultra slim 6-3/4" hole drilled to a T.D. of 5803' md. KOP is 400' md and a variable build rate from that point will yield a sail angle of 51.888 deg. @ 3809' md. At 5070' md the well will begin to drop until a final angle of 50° is reached. The 50° angle will be held through the reservoir to TD. MP E-21 will have a horizontal displacement of 2694'. 7. Cement The surface hole will be cemented to surface in one stage with Cold Set III Cement, a foamed 10# intermediate slurry followed by Class G. The Class G is run from TD to 500' TVD above the top of the Schrader Bluff. A back up port collar will be run approximately 200' below base of the permafrost if gauge allows. The exact position determined from the caliper log. MP E-21 Well Plan PAGE 6 11 July 98 MP E-21 5-1/2"" SURFACE CASING CEMENT PROGRAM - B.J. Alaska CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS. Spacer 250bbls. Water 8.43 pp~l. STAGE1 LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Intermediate) WEIGHT: Cold Set III 12.2ppg YIELD: 1.92FT3/Sk. MIX WATER:10.53 GAL/sk. WEIGHT: Foamed 10.0ppg YIELD: 2.02 FT3/Sk. MIX WATER: 6.12 gal/sk APPROX #SACKS: 395 Cold Set III THICKENING TIME: Greater than 6 hrs at 50° F 95 Foamed Greater than 4:30 hrs." ANNULAR VOLUME TOP OF TAIL CEMENT TO Port Collar AT 2000' MD +50% EXCESS. (Confirm From Caliper) STAGE1 TAIL CEMENT TYPE: ADDITIVES: FLU ID LOSS: Approx. 102 SACKS PREMIUM 'G' FI-33-.4%, CD-32- .3%, R-1-.1% FP-6L lghs. WEIGHT: 15.8 ppg THICKENING TIME: Greater than 5' hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 500' FEET TVD ABOVE SCHRADER BLUFF + 80'md 5-1/2 .... ,15.5# capacity for float joints. EST TOC 4300' md (Confirm from Caliper) I STAGE2 Contingency: ADDITIVES: WEIGHT: APPROX #SACKS: Cold Set III PERMAFROST (If Single Stage Unsuccessful) Retarder 12.0ppg YIELD:2.02 ft3/sx MIX WATER: 11.63 gal/sk 247 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2000' MD TO SURFACE+ 200% EXCESS. (Confirmed by Caliper) Note Excess is estimate only caliper will be used for final determination. DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT TOP JOB CEMENT TYPE: Permafrost Cold Set Set III NOTE: ADDITIVES: Retarder TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.2 ppg YIELD: 1.92 ft3/sx MIX WATER: 10.53 gal/sk APPROX NO SACKS: 100 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: MP E-21 Well Plan PAGE 7 11 July 98 N IS00.00 22 I 11 · 18· 20 · 24 · 14m I15m 3 8 · · m2 · i I5 · 15 · 23 NO TES ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 2. GEODETIC COORDINATES ARE NAD 27. 3. MEAN PAD SCALE FACTOR 0.999905434. 4. HORIZONTAL AND VERTICAL CONTROL IS . BASED ON MONUMENTS CFP-3 ond E-1. 5. DATES OF SURVEY: 6/30/98 AND 8/8/98. 8. REFERENCE F[ELD BOOKS: MP98-06 (Pgs. 05-07, 64-66.) 7. ELEVATIONS ARE BASED ON BPX MILNE POINT DATUM (M.S.L.). + N 2600,00 i i . .. ~ A PAD I I I ~ 1.13N] ~ ~ I ~)T. 13,N. LEG[ND · EXISTING WELL CONDUCTOR · ~ AS-BUILT WELL CONDUCTOR + RENAMED WELL CONDUCTOR VICINITY MAP N.T.S. NAMED E-21, A NEW CONDUCTOR, E-21, HAS ~ BEEN AS-BUILT AND ADDED HEREON. BEEN AS-BUILT AND ADDED HEREON. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 8. 1998. e J7/1 IO,~ DATE LOCATED WITHIN PROTRACTED SEC. 25, T. 13 N., R. 10 E., UMIAT MERIDIAN ALASKA WELL -' A.S.P. -' PLANT' (JEODETIC " GEODETIC ". cELLAR SECTI6N NO. COORDINATES COORDINATES POSITION(DMS) POSlTION(D.DD) BOX ELEV. OFFSETS , _ y= 6,016,227.28 N. 1,950.56 70'27'16.877" 70.4546879' 23.4' 3,688' FSL E-29 X= 569,350.97 E. 1,450.11 149'26'02.626" 149,4340629' 1,794' FEL · - y= 6,016,390.55 N. 2,159.67 70'27'18.494" 70.4551373' 23.2' 3,853' FSL E-30 X= 569,220.32 .E. ..!,45~..40 149'26'06.420" 149.4351166' .... 1,923' FEL . 3,806' FSL y= 6,016,343.63 N. 2,099 78 70'27'18.029" 70'4550081° 22.9' E-21 ×= 569,25.7.52 E. 1,450.01 149'26'05.340" 149.4348167' ... 1,887' FEL R£NUI,,IE)ERED WELL £-21 TO £-'2g. ADDED NEW --. JACOBS c~[cKco: O'HANL~Y DATE: 7/1/98 DI~AW1NO: MP~-AB JO~ NO: L BP EXPLORATION MILNE POINT UNIT- E PAD AS-BUILT WELL CONDUCTORS WELLS E-21, E-29 &: E-30 EXPLORATION (ALASKA) INC. SURFACE LOCATION I PLOT DATE :__ 8/3/98 Horizontal Cogrdlhlt~l ;'"f~'l'lb~J4?l~.~)'~'~l; S~,O~-~"7,3d E~ ' Proposal Target Summa~"' g 177,25 MD 177.2s TVD : Start {)Ir @ 1000°/10Oft: 400.Q0fl MD, 40O.001t TVD 7OO Dir ~ 1.000"/100ft: 800.00fl MD, 799.68ft TVD FOP. PEPJ~ITTING ONLY 1400 DEr @ 1.000°/t 00ft: 1400.40ft MD, 1395.33rt 'rvD RatG Increase ~ 1.250V100tt: 1608,37fl MC), 1599,47fl TVD Jn-ASE PERMAFI~O~"J' 17.92.2.$ :I'VD Rate Increase ~ 2.000°/10Oft: 2615.04t'[ ME), 2555.4'~t TVD Rale Increase ~ 3.000°/100f~: 3519.09f[ MD, 3157.49tt TVD 4200 nd Dir, S~I @ 51.888°: 3808,93ft MD, 3503,55[t TVD ~.~ _S~ Dir ~ 3.000'I100ff: 5069.7~ MD, 4281.70fl ~D ' ~End Dir. Sail ~ 50.000": 5135.65f~ MD, 4323.25~ ~D ~s-Zt r~ ~~o~ top 5CH~D~R 4323.25 ~D ~/Total Depth: 5802.8~[ MD, 4752,09ft WD 6~ w~1/2" ~=JnnCa~ng ~ ~,80 MD / 4752.09 ~D I I I 700 1~0 2100 2aN Scale: linch m 700ft Section Azimuth: 97,917' (Truo North) Vertical Section 13R IL LllYE; _ S_E,F! V I ~.J~ ~_ BP EXPLORATION (ALASKA) INC, WELL: MPE-21 [PROPOSED MPE-29) WP1 I DrilIQuest' Proposal Data tot MPE-2I {PROPOSED ~PE.29) WP'[ Ve~cal C:flcjJ']; Vle~. I'c3r~.z~l~ 05gin: We[ N3~ Re~en.~: Tn~. Ve~ ~~: 97317' Ve~ ~ G~aln: 0.~ N,~ E U~sund In~ ~ VeStal No~gr ~sUngs Ve~l D~ 0.IX1 O. Ct, O ~)~] 0M 0 gO I~ D. OO E 40i~O OJX. O 053] 40~1~'1 O,~ I~ I).O~ E CO]C L~GIIO 4~CO IO~J[CO ?~l~ 3.14S I],~E 13.go tfill~37 I~C¢)1OLOG0 1.~99A7 32.71 g 122,49 £11537 1,60Q 2&15.O424 J'.~O 9S~'.0 2555.4'/ ~.10S 4TLD£ 4~50 3] 19.O9 3L~/J)92/.t~ 3]~A9 ](B.~4 g ]SS,IR E794 lc9 2,[K]O ~.~ 51~ 91L~ 35(B35 L'I&4I S ll31.1{; E I L39.44 3.1KNI 5~9,~1 SI388 91~69 42~1,~) Z)12~$ 2llL211E21]1.~9 513S.65-nt~CO98.1~ 439-] -~;,~91 S 21M,93 £21~Z30 51OZ.~ ~O 9~,1~ 47~2.~ 3~ g 2~7.8~ E~56 O ~ PLOT DATE- 8/3/98 Cmded B~: Tu~rl Kr,~: $IIT,-21 TA]LGET Proposal Target Summary 4Zf/i~0 4]Z[25 29K91 $,2 [I;I.~J ~. FOR PE~/~ITi'ING ONLY ' Scale: finch = 400fl Eastings -41)0 0 400 600 t200 Eastings 1600 2OO0 24OO 2800 Scale: t inch = 40Oft Reference Is True North ( ( ( ( · Uilne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth iff) Cfi) (fi) O.® O.O00 0.009 -57.25 0.00 ,177.25 O.ODO 0.000 12Q.00 177.25 400.00 O.O00 O.O00 342,75 400.00 500,00 1.01)0 103.009 442,74 499.99 600.00 2.009 103,000 542,71 599,96 700.00 3.000 103,000 642,61 699.86 800,00 4.000 103_000 742,43 799.66 900.60 4.999 103.665 842.12 899.37 1000.00 5.998 104.109 941.65 998.90 1100.00 6.91)7 104,426 1041,01 1098,25 1209.(~ 7,997 104.665 1140.15 1197.40 1309,~ 8.996 104,851 123~).06 1296.31 1409.~ 9.99~ 104.999 1337.68 I394.93 1400.40 10.0~ 105.000 1336.08 1395.33 15~.~ 10.954 1~,,,~2 1436.02 1493.27 1600.~ 11.919 107,699 1534,03 1591.28 1608.37 12.0~ 108,0[X) 1542,22 1599.47 1709.(X) 13.048 105.869 1631.67 1688.92 1800,09 14209 103.899 1726.85 1786.10 1806,34 14.263 103.785 1735.00 1792.25 19 ~,00 15,384 102223 1825.53 1882.78 2001).(N) 16.569 100.780 1921.67 1978.92 2109.00 17263 99.525 2017,21 2074,46 220,0.00 18.964 98.425 2112.12 2169.37 2300.00 20.171 g7.451 220B.34 2263.59 Sperry-Sun Drilling Services Proposal Report for MPE21 (1~IPE.29) MPE-21 (PROPOSED MPE-29) WP1 FOR PEP-J~I~ING ONLY Loca! Coordinates Northlngs Eastings Iff) (fl) 0,04) N 0.00 E 0,09 N O.O0 E 0.09 N O.O0 E 0.20 S 0.85 E 0.79 S 3.40 E 1.77 S 7.65 E 3.14 S 13.60 £ 4.95 S 2123 £ 7.26 S 30.53 E 10.05 S 41.50 E 13,33 S 54.13 E 17,09 S 6~.41 E 21,34 S 84.35 E 21.36 S 84.42 E 26,30 S 101,84 E 32.18 S 120.78 E 32.71 S 122.43 E 38.49 S 141.44 E 44,52 S 164.21 E 44.90 $ 165,73 E 5028 S 189.09 E 55.75 S 216.06 E 60.94 S 245.11 E 65,85 S 2762.3 E 70.47 S 309,40 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fl) (ft) (°llOOft} (ft) 6016343.80 N 569257.38 E 0,~ 6016343,80 N 569257.38 E 0.000 0,09 6016343.80 N 569257.38 E 0.000 0,00 6016343,61 N 569258,23 E 1.000 I),87 6016343,05 N 569260,79 E 1.000 3.48 6016342,10 N 569265.05 E 1.000 7,82 6016340.79 N 569271.01 E 1.000 13.90 6016339.04 N 569278,66 E 1.000 21.71 6016336.63 N 56.,q287,98 E 1.000 31.24 6016334.14 N 569298.97 E 1.000 42.49 6016330.98 N 569311,63 E 1,000 55.45 6016327.35 N 569325.95 E 1,000 70.11 6016323.24 N 569341-93 E 1,000 86.49 6016323.23 N 569342.00 E 1,000 86,66 6016318.45 N 569359.46 E 1,0~ 104.50 60'[6312.74 N 569378.45 E 1.000 124,06 60'[6312.23 N 569380.11 E 1,000 125,77 6056306.63 N 569399.17 E 1,250 145,39 6016300.81 N 569422.00 E 1.250 166,78 6016300.45 N 569423.52 E 1,250 170,33 6016295.28 N 569446.93 E 1.250 194,21 6016290.06 N 569473.95 E 1.250 221.68 6016285,14 N 569503.05 E 1.250 251.'[7 6016280,52 N 569534.21 E 1 250 282,67 6016276.21 N 569567.42 E 1.250 316.16 Alaska State Plane Zone 4 Miine Point E Pad Comment 13 318' Casing KOP: Stad Dir @ 100{)°/100tl' 400,0011 MD, 400.0011'R/D Continue Dir @ 1,000¥10011' 800.OOft MD, 799,68ft TVD Continue Dir ~ 1.000°/10~· 1400AOIt MD, 1395.33ftTVD DI r Rale increase @ 1,250°/10~: 1608.37ft MD, 1599,47fl 'T'VD BASEPERMAFROST Continued... 3 August, 19J8-17;01 .1 - DfiflGuest Milne point Unit Measured Sub-Sea Vertical Depth Incl, Azim. Depth Depth (fl) (fl) (ft) 2400.00 2L382 96,582 2299.84 2357.09 2500.00 22.598 95,803 2392,56 2449.81 2600.00 23,8'[6 95,109 2484.47 254-1.72 2615.04 24.000 85,009 2498,22 2555,47 2700.00 25.685 94.481 2575~32 2632.57 2800.00 27.671 93,946 2664.67 2721,92 2900.00 29.658 93.477 2752,41 2809.66 3000.00 31,647 93,062 2838,43 2895.68 3100.00 33.637 92,§91 2922,63 2979.88 3200.00 35.628 92,356 3004.91 3062,16 3300.00 37.620 92,055 3085,16 3142,41 3319.09 38.00{) 92,050 3100,24 3157,49 3400.00 40,2~ 93,393 3163,00 3220.25 3500.00 43.080 94,944 3237,69 3294-,94 3600,00 45.916 96,340 3309.02 33q6.27 3700.00 48.768 97.605 3376.77 3434,02 3800.00 51.832 98.770 3440,78 3498.03 3808.93 51.BBB 98,889 344~,30 3503,55 3900.00 51 ,BBB 96.86!) 3502,51 3559.76 4000.00 51 .BBB 98.869 3564,23 3621.48 4t00.00 51.888 98,869 3625,95 368320 4200.00 51.888 98.8b'9 3887.67 3744,92 4300,00 51,81~ 98.869 3749;3'9 3806.64 4320.43 51,BBB 98.86!) 3762,00 3819.25 4400.00 51.888 98.869 3811.11 3868.36 Sperry-Sun Drilling Services Proposal Report for !~1PE21 (MPE-29) J/IPE.21 (PROPOSED iI~PE.29) WP1 FOR PER/~ITTING ONLY Local Coord Mates Nmlhin9s Eastings (~t) (It) 74.79 S 344.60 E 78.82 S 381.83 E 82.56 S 421,06 E 83.10 S 427.13 E 86.04 S 4~2.70 E 89,33 S 507.4,7 E 92.43 S -555.3¢ F.. 95.33 S 606.24. E 98.04 S 660.10 E 100.54 S 716.88 E 102.83 S 776.48 E '[03.24 S 788,18 E 105.66 S 839,18 E i10.52 S 905,48 E t17.43 S 975,21 E 126.38 S 1048,20 E 137.33 S 1124,23 E 138.41 S 1131,16 E I49.46 S 1201.96 E 16159 S 1279,70 E 173.72 S 1357,44 E 185.85 S 1435,18 E 197.98 S 1512,92 E 200.46 S 1528,80 E 210.11 S 1590.66 E Global Coordinates Dogleg Verticat Northin~s Eastings Rate Section (fi) (ft) (°/lOOft) (fi) 6016272.21 N 561)602.66 E 1.250 351.62 6016268,53 N 569639.93 E 1250 389.05 6016265.16 N 569679.19 E 1.250 428,41 6016264,68 N 569685.26 E 1.250 434.50 6016262,06 N 569720.66 E 2.000 470,14 6016259.19 N 569765.66 E 2.000 514,94 6016256,53 N 569813.55 E 2.000 562.78 6016254,10 N 569864.4~ E 2.000 613.59 6016251,90 N 569918,37 E 2.000 667,31 6016249.93 N 569975.16 E 2,000 723,89 6016248.19 N 570034.79 E 2.000 78325 6016247.89 N 570046,46 E 2.000 794.69 6016245.95 N 570097.51 E 3.000 845.73 6016241.71 N 570163.84 E 3.090 912.07 6016235.44 N 570233,64 E 3.000 982.09 6016227.17 N 570308,71 E 3.O09 1055.6'[ 6016216.92 N 570382.84 E 3.000 113Z.43 60162.15,91 N 570389,78 E 3,000 1139.44 6016205.52 N 570460.68 E 0,000 1211.09 6016194.12 N 570538,52 E 0,000 1289.76 6016182.71 N 570616,37 E 0,000 1388,43 6018171.30 N 570694.22 E 0,0D0 1447,10 6016159.89 N 571)772,07 E 0,000 1525.77 6016157.56 N 570787,98 E 0,000 I541.84, 6016148,49 N 570849.92 E 0,0O0 1604.44 Alaska State Plane Zone 4 Uilne Point E Pad Comment D[r Rale Increase @ 2.000°/100fl: 2615.04fl MD, 2555.47fl 'TVD DIr Rate I r~cmase O 3,00D¥100ft: 3319.09fl MD, 3157.49lt TVD End Dir, Sail @ 51.888": 3808.93tl MD, 3503.55fl 'lAID TOPUGNU i o X Con~nuecl,.. 1998-17:0! - 2. Dr#/Quest Sperry-Sun Drilling Services Proposal Report for MPE21 (MPE-29) MPE-21 (PROPOSED MPE-29) WP1 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azlm. Deplh Depth ~,, (fi) {fi) (fi) .~' 4500,00 51.888 98.869 3872.83 3930.08 4600.00 51.888 98.869 3934.55 3991.80 4700.00 51.88B 98.869 3996.27 4053.52 4731.97 51,888 98.869 4016,00 , 407325 4800.00 51.888 98.869 4057,99 4115.24 4900.00 51.888 98.869 4119.71 4176:96 5000.00 51.888 96.869 4181.43 4238.68 5069.70 51.888 98.869 4224.45 4281.70 5100.00 51.020 98.524 4243.33 4300.58 5135.65 50.000 98.10B 4266,00 4323.25 FOR PEPJ~ITi'JNG ONLY Local Coordinates Northings Eastlngs (ft) (fi) 222,24 S 1668A0 E 234.37 S 1746.14 E 246,50 S 182~,8B E 250,38 S 184B.73 E 258.63 S 1901,62 E 270.76 S 1979.36 E 282,89 S 2057.10 E 291.35 S 2111.28 E 294,93 S 2134.71 E 298,91 S 2161.93 E Global Coordinates Dogleg Vertical Nodhings Eastings Rate Section (fi) (fl) (moofl) 6016137.08 N 570927.77 E 0,000 1683.11 6016125.67 N 571005.62 E 0,000 1761.7B 601611427 N 571083.47 E O,ODO 1840.45 6016110.62 N 571108.36 E O,O00 186559 6016102.86 iq 571161.32 E 0,000 1919.12 6016091.45 N 571239.17 E 0,000 1997.79 6016080.04 N 571317.02 E 0.000 2076.46 6016072.09 N 571371.28 F_ 0.000 2131.29 6016068.73 N 571394.74, E 3.000 2154.99 6016065.00 N 571422.00 E 3.000 2182.50 5200,00 50.000 98.108 4307.36 4364.61 305,86S 2210.73 E 5300.00 50.000 98.108 4371.64 4428.89 316,67 S 2286.57 E 5400.00 51).000 98.108 4435.92 4493.17 327,47 S 2362,41 E 5500.00 50.000 98.108 4500.20 4557.45 338,28S 2438,25 E 5502.80 50.000 98.108 4502,00 4559.25 338,58 S 2440.37 E 5600.00 50.000 98.108 4564,48 4621.73 349,08 S 2514.09 E 5700.00 50.000 98.I08 4628.76 4686.01 359,885 2589.93 £ 5800.00 50.000 98.'[08 4693.04 4750.29 370,69 S 2665.77 E 5802,80 50,000 9B,10B 4694.84 4752.09 370,99 S 2667.89 E 6016058.50 N 571470.86 E 0.000 2231.79 6916048.40 N 571546,80 E 0.000 2308,40 6016038.30 N 571622.73 E 0.000 2.385.00 6016028.20 N 571698,67 E 0.000 2461,60 6018027.92 N 571700,79 E 0.000 2463.75 6016018.11 N 571774,60 E 0,000 2538,21 6016008.01 N 571850.54 E 0.000 2614,,81 6015997.91 N 571926.48 E 0.000 2691,42 6015997.63 N 571928,60 E 0.000 2693.56 All dale Ts in feel unless otherwTse stated. Directions and coordinates are rel;~tive to True North. Vertical depths are relative to Well. North[rigs and Eastrngs are relative to Well The Dogleg Severity is in De[lTees per lOOft. Vertical SsclJon is from Well and calculated along an Azimulh of 97.917° ('rrLze}. Based upon Minimum Curvature type calculations, at a Measured Depth of 5802.80ft., The Botlorn Hole Displacement is 2693.5b'ff., in the Direction ot 97.917° (True). Alaska State Plane Zone 4 Milne Point E Pad Comment TOP M SAND SLed, DIr @ 3.000°/10011: 5069.70ft MD, 4281.70f{ TVD End Dir. Sail @ 50.000°' 5'[35 65fl MD, 4323~fl TVD TOP SCHRADER ' ' Target: MPE-21 TARGET, 200.00 R;~dlus,, Geological ..~ .~ ~ ~ ,.~ ~_ BASESCHRADER Tolal [)eplh: 5802,80ft MD, 4752.0911TV'D 51/2' C~lng i 3 Augus& f99~. 17:i~I - 3., DritiOues! Shared Services Drilling Contact: R. George Scott I Well Name: IMP E-21 IType of Well (producer or injector): Well Plan Summart/ ISchrader Bluff Producer 564-5862 Surface Location: 3806' FSL, 1887' FEL, S25 T13N R10E UM Target Location: 3506' FSL, 4967 FEL, S30 T13N R11E UM Bottom Hole Location: 3535'FSL, 4456' FEL, S30 T13N R11E UM J AFE Number: J 337135 I Estimated Start Date: I 20 August 98 I uD: 158°3' I ITVD: I Ri~l: I Nabors 27E Operating days to complete: 4752' I 16.0 I KBE: [57ft I Well Design: Schrader Bluff Producer I I 1 I Formation Markers: Formation Tops MD TVDSS KOP 4OO 40O Base of Permafrost 1807' 1735' Top of Ugnu 4320' 3762 Top M Sand 4732' 4016' Top NA (Target) 5135' 4266' Top of the N-A (EMW 8.6 ppg) Base Of Schrader 5503' 4502' TD 5803' 4695' TD at 300' MD past base of Schrader Bluff Casing/Tubing Pro~lram: Hole ,~ize ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tb~l O.D. MD/TVD MD/TVD (bkb) 16" 13-3/8" 72# L-80 BTC-MOD 120' 31'/31' 151'/151' 6-3/4" 5-1/2"** 15.5# J-55 BTC-MOD 5773' 30'/30' 5803'/4752' Internal yield pressure of the 5-1/2 .... 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/ft) to the reservoir at +4384' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1960 psi (8.6 ppg EMW), is 1532 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). ** ** Note: The top joint in the 5-1/2" surface casing consists of a 7"x5-1/2" X-over from 26# BTO-MOD L-80 to, 5-1/2" 15.5# J-55 BTC-MOD, this is required to accommodate the penetrater offset. Properties of this top joint are Coupling O.D.-7.656", I.D. 6.276", Drift-6.151", Collapse-5410psi, Burst-7240psi, yield-604M lbs. Two 5-1/2" 15.5# 20' marker joints will be placed around 100' above the top of the NA. MP E-21 Well Plan PAGE 3 11 July 98 Logging Pro~lram: Open Hole Logs: MWD directional only from surface to 2200' MD. + 4-Arm Caliper Log From T.D. to 151' M.D. (Base of 13-3/8" Conductor.*) MWD directional and LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 fi/hr. Cased Hole Logs: A Gamma Ray/CCL LOG WILL BE RUN FROM T.D TO THE BASE OF THE CONDUCTOR after drilling rig release. Mud loggers are NOT required for this well. *A conditioning trip will be made if required to assure running of the caliper. Mud Pro~lram: ISpecial design considerations An inhibitive polymer mud is planned from surface to TD. Solids control is critical to the success of the system. Surface Mud Properties:0-3000' I Density Marsh Yield LSRV 10 min pH Fluid (PPG) Viscosity Point gel Loss 8.6 150 40 50,000 8.5 NC to 9.0 Production Mud Properties:3000'-TD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~lel Loss 9.0 50 30 14 16 8.5 to to to to 9.5 60 35 9.0 LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17 Well Control: Well control equipment consists of: Rig (Nabors 27E) ,13-5/8" 5000 psi W.P.Annular and 3000 psi Diverter with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics are attached. Directional: I KOP: 1400' MD Maximum Hole Angle: Close Approach Well: 51.888° at 4100'MD MPE-05,MPE-07,MPE-10 will need to be shut in and secured while drilling by the close approach. Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #4 facility. Fluids Handling: All drilling and completion fluids will be hauled to Drill Site #4 or CC-2A for injection. Annular Injection: Not planned for this well. MP E-21 Well Plan PAGE 4 11 July 98 MP E-21 Proposed Summary of Operations . . . . , 10. Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 27E rig. NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program. Drill a 6-3/4" surface hole as per directional plan. Run Directional MWD from surface to 2500'+'MD, Note: If bit performance and hole conditions allow the first bit should be kept in the hole beyond this depth but pulled +/- 200'MD above the top of the Ugnu (4,120' MD). POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP. Drill 6-3/4" hole to TD as per directional plan. Stand back drill string and run 4-Armed Caliper from the base of T.D. to the bottom of the 13-3/8" conductor. ( A 2-7/8" work string will be set back for emergency operation of the port collar) Following this, the casing will be cemented. Run and Cement 5-1/2", 15.5#, J-55, Buttress-Modified casing. Refer to attached Detailed Cement Program and Back-up Port Collar operating Procedure. Displace casing with sea water and freeze protect from 2000' MD to Surface. Following the cementing of the well and the landing of the 7" x 5-1/2" landing joint the casing will be tested to 3500 psi.(74% of internal yield). The Diverter system will be rigged down and the frac head provided by the Well Services group installed, and tested to the same pressure. See attached bit program for recommended bits. In the upper hole a 6-3/4" MFI5L IADC 4-4-7X is recommended. This will be changed out to a 6-3/4" S-94PX bit at +2500' (or deeper as in step 5) which will be drilled to TD. POST DRILL AND CASE: Nabors Rig 4ES will run the completion on this well following rigless completion work. 1. The first part of the completion is planned to be done rigless. This includes perforating, frac'ing clean out. Rig 4ES is planned to be used for setting the screen and for the final running of the completion assembly. The well will be completed with 2-3/8" tubing. 2. A completion program will be issued for this. It is planned to run an ESPC completion with Centrilift Heat Trace to a depth of 5200' MD. Install Surface Lines and Wellhouse and turn well over to production. MP E-21 Well Plan PAGE 5 11 July 98 DRILLING HAZARDS AND RISKS: See the latest Milne Point E-Pad Data Sheet for offset information on E pad. The MPU PE group will be perforating, hydraulic fracturing and cleaning out this as per the completion program. 1. Hydrates: HYDRATES HAVE BEEN ENCOUNTERED ON WELLS DRILLED AT MILNE POINT 'E' PAD, in the interval of 2100-2400'MD just below the permafrost as summarized on the Pad data sheet. If encountered mud will be treated with 1-1.5 ppb Lechithin weight up to 9.8 ppg. (See Attached Mud Program). Minor hydrates have been encountered rec 2. Close Approach: The E-05, E-07 and E-10 wells are close approach and will need to be shut in and secured while drilling the close approach. E-05 35.86'@ 1495.26', E-0721.7'@900.02',E-10 51.83'@2114.27'. 3. Lost Circulation: There have not been any significant lost circulation incidents reported on any of the E Pad wells. HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. Recently over the period of 1994-96 no stuck pipe problems have occurred but tight hole problems have been experienced. 4. Stuck Pipe Potential: There have been several STUCK PIPE incidents on Milne Point 'E' Pad. The E-22 and E-3 wells experienced stuck pipe incidents. These wells were drilled in 1994 and 1990 respectively. Be especially aware of the need to maintain good hole cleaning properties and practices through the upper hole and the heavy clay sections REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE STUCK PIPE INCIDENTS. The frequency of wiper trips should be a minimum of once every 1000' as determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions using Hi/Low sweep combinations. If heavy gravel's are encountered while drilling the surface hole section, operations should be immediately stopped and the mud funnel viscosity is increased to help clean hole. 5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of 0.4476 psi/ft (8.6 ppg EMW) and a pressure of 1960 psi in the middle of the Schrader Bluff at 4384' TVDSS. 6. Directional Drillinq Concerns MP E-21 will be an ultra slim 6-3/4" hole drilled to a T.D. of 5803' md. KOP is 400' md and a variable build rate from that point will yield a sail angle of 51.888 deg. @ 3809' md. At 5070' md the well will begin to drop until a final angle of 50° is reached. The 50° angle will be held through the reservoir to TD. MP E-21 will have a horizontal displacement of 2694'. 7. Cement The surface hole will be cemented to surface in one stage with Cold Set III Cement, a foamed 10# intermediate slurry followed by Class G. The Class G is run from TD to 500' TVD above the top of the Schrader Bluff. A back up port collar will be run approximately 200' below base of the permafrost if gauge allows. The exact position determined from the caliper log. MP E-21 Well Plan PAGE 6 11 July 98 MP E-21 5-1/2 ....SURFACE CASING CEMENT PROGRAM - B.J. Alaska CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS. Spacer 250bbls. Water 8.43 pp~]. STAGE1 LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Intermediate) WEIGHT: Cold Set III 12.2ppg YIELD: 1.92FT3/Sk. MIX WATER:10.53 GAL/sk. WEIGHT: Foamed 10.0ppg YIELD: 2.02 FT3/Sk. MIX WATER: 6.12 gal/sk APPROX #SACKS: 395 Cold Set III THICKENING TIME: Greater than 6 hrs at 50° F 95 Foamed Greater than 4:30 hrs." ANNULAR VOLUME TOP OF TAIL CEMENT TO Port Collar AT 2000' MD +50% EXCESS. (Confirm From Caliper) STAGE1 TAIL CEMENT TYPE: ADDITIVES: FLUID LOSS: Approx. 102 SACKS PREMIUM 'G' FI-33-.4%, CD-32- .3%, R-1-.1% FP-6L lghs. WEIGHT: 15.8 ppg THICKENING TIME: Greater than 5 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 500' FEET TVD ABOVE SCHRADER BLUFF + 80'md 5-1/2 .... ,15.5# capacity for float joints. EST TOC 4300' md (Confirm from Caliper) STAGE2 Contingency: ADDITIVES: WEIGHT: APPROX #SACKS: Cold Set III PERMAFROST (If Single Stage Unsuccessful) Retarder 12.0ppg 247 SACKS YIELD:2.02 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2000' MD TO SURFACE+ 200% EXCESS. (Confirmed by Caliper) Note Excess is estimate only caliper will be used for final determination. DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT TOP JOB CEMENT TYPE: Permafrost Cold Set Set III NOTE: ADDITIVES: Retarder TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.2 ppg YIELD:1.92 ft3/sx MIX WATER: 10.53 gal/sk APPROX NO SACKS: 100 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: MP E-21 Well Plan PAGE 7 11 July 98 E-PAD ID' 3 8 I [] N i800.00 + lOm 22 [] 9 m 11 I 18 · 20 · 15I I2 · 1 + 30 · 23 NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC COORDINATES ARE NAD 27. MEAN PAD SCALE FACTOR 0.999905434. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MONUMENTS CFR-3 ond E-1. DATES OF SURVEY: 6/30/98 AND 8/8/98. REFERENCE FIELD BOOKS: MP98-06 (Pgs. 05-07, 64-66.) ELEVATIONS ARE BASEO ON BPX MILNE POINT DATUM (M.S.L.). . . RUG 11 ' 98 2600.00 LEGEND · EXISTING WELL CONDUCTOR AS-BUILT WELL CONDUCTOR RENAMED WELL CONDUCTOR 7:54 No.009 P.02 VICINITY MAP N.T.S. NAMED E-21. A NEW CONDUCTOR, E-21, HAS ~) BEEN AS-BUILT AND ADDED HEREON. .~ ~So STEPHEN STOLL ~.g ~'-. 6726-S o - ~"'~ SURVEYOR°S CERTIFICATE [ HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 8. 1998. LOCATED WITHIN PROTRACTED SEC. 25, T. 13 N. R. 10 E., UMIAT MERIDIAN ALASKA WELL A.S.P. PLANT GEODETIC GEODF:TIC CELLAR SECTION NO. COORDINATES COORDINATES POSIT{ON(DMS) POSITION(D.DD) BOX ELEV. OFFSETS E-29 Y= 6,O16,227.28 N. 1,950.56 70'27'16.877" 70.4546879' 2.3.4' .3,688' FSL X= 569,350.97 E. 1,450.11 149'26"02.626" 149.4340629' 1,794' FEL E-30 Y=6,016,390,55 N. 2,159.67 70'27'18.494" 70.4551373' 23.2' 3,853' FSL X= 569,220.32 E. !,450.40 149'26'06.420" 149.4351166' 1,923' FEL E-21 Y=6,016,543.63 N. 2,099.78 70'27'18.029" 70.4-550081' 22.9' 3,806' FSL X= 569,257.52 E. 1,450.01 149'26'05.340" 149.4348167' 1,88.7' FEL JACOBS C.[CKCD: O'HANLEY OAf£: ?/~/~ DRAWl NO: MP~- A8 ~ NO: 1'-200' IBP EXPLORATION MILNE POINT UNIT- E PAD AS-BUILT WELL CONDUCTORS WELLS E-21, E-29 & E-30 lorl aUG-03-98 NON 05:19 Pa SPEPoY-$UN aLaSKa FaX NO. 19075635754 P. 02 I],P EXPLORATION (ALASKA) INC. SURFACE LOCATION J PLOT DATE _- RKB I[~wizlon: :33;m3(t _l~g~rEal3 I C~ Ey t I - l Proposal Target Summa~" 8/_3/_9_8 o~~ ! ~lt 177.25 MD I '1' 177.2sTVo 700 [ [~ontinuo Clul~d cuo~ak~l: 601~$.o0 IT. $7143'J.00 F. FOP. PER/VUTTING ONLY 1400 Dir ~) 1.000°/100ft: 1400.40ft MD' 1395.331/TVD Rata Increase ~ 1.250"/100tt: 1608.37fc MC), 1599.47ft 3'VD '~100 2800 Rate Increase ~ 2.000°/lO0ft: 2615,04[[ MD, 255S.47fl TVD Rale Increase @ 3.000°/100t[: 3319.09f[ MD, 31-~7.491t TVD 3~00 :;~ 4200 ,-I I1 v~ 4900 i 0 700 Scale,: linch ,- 700~t: nd DiG Sail @ ~;1.888°: 3808.93ft MD, 3503.55~t TVD ooooo TOP [/G~U$~19.25 TVD -r.~.~ _$1~rt Dir @ 3.000~/100ff: 5069.70ft MO, 4281.7Oft TVD ~/-End Dir, Sail @ 50.000o: 5135.65ft MD. 43~3.25tt TVD ~... ~'Total Depth: 5802.80f~ MD, 4752.09ft '1'VD ~02:,80 MD ~ 4752.09 -rvD 1400 2100 2800 S~cl:lon Azimuth: 97,917' (Truo lqotl:h) Vertical Section BP EXPLORATION (ALASKA) INC, WELL: M?E-21 (PROPOSED l~PE-29) WP1 DrilIQ.est' 4CGO0 L~O.~ 4~C0 1n2£0} 't~/i! 3.11 S I],60 E 13~ t,~ 1~37 I~ 10~ 1~7 32.71 S 122,4~ E 1253~ I,~ 2615~ 3319.~ 31~ ~e~ 31~A9 1(O24 S ~8~.Ig E 7~9 2.~ 5135.65 ~CO SURFACE LOCATION Ho~,.~t~C~u~l~: 6~163A,1 ~e ~l, U8~ iPLOT DATE: 8/3/66 Cl~.r4~ By: MPF/Zt TA~.G'~ Proposal Target Summary 4265~ 4JZI, ZS 29L~I S,211;I.9~ ~ (Il I~ ILll N, 3'/142 Lffi ~. FOR PEP~ITTING ONLY ' -8( Scale: linch · 40Oft Eastings -400 0 400 800 1200 EastJngs 1600 2000 2400 2800 Scale: linch = 400fl Reference is Trae North cD x Milne Point Unit Measured Depth Incl. Azirrl. Sub-Sea Depth Vertical Depth (It) 0.00 O.D00 0,OD0 -57.25 0.00 177.25 O.0DO 0.0O0 120.00 177.25 400.00 O.ODO 0.0iX) 342,75 400.00 500.00 1.DO0 103.000 442,74 499,99 600.00 2.000 103,000 {N2,71 599.91~ 700.00 3.0{)0 103,0~ 642,61 699.86 800,(X) 4.000 103_000 742,43 799.~ 900.00 4.9FJ 1(33.665 842.12 899.37 1000.00 5.998 104.109 941,65 998,90 1100.00 6.997 104,426 1041,01 1098.25 1200.00 7,997 104.6~ 1140,15 1197.40 13~),00 8.996 104,851 1239,06 1296.31 140i),00 9.996 104399 1337.68 t394.93 1400,40 10.000 105.000 1338,08 1395,33 1509.00 10.954 106.572 1436,02 1493,27 1600.00 11.919 107,899 1534,03 1591.29 1608,37 12.000 108,0D0 1542,22. 1589,47 1700.(K) 13.048 105.669 1631,67 1688,92 1800,00 1420~ 103.899 1726.65 1786.10 1806,34 14283 103.785 1735,00 1792,25 1900,00 15,384 102223 1825,53 1882.78 ::)009.00 16.569 100.780 1921,b"7 1978.92 2100.00 17.763 99.525 2017,21 2074,46 2200,00 18,964 98.425 2112.t2 2169.37 2300.00 2.0.171 97.451 2206.34 2263.59 Sperry-Sun Drilling Services Proposal Report for MPE21 (MPE..29) MPE-21 (PROPOSED MPE-29) WP1 FOR PEP, MI~ING ONLY Locat Coordinates Nod, hings Eastings (ft) 0,00 N 0.00 E 0,~ N 0.00 E 0,~ N 0.00 E 0.20 S 0.85 E 0.79 S 3.40 E 1,77 S 7.65 E 3,14 S 13.60 E 4.95 S 21.23 £ 7.26 S 30.53 E 10,05 S 41.50 E 13,33 S 54.13 E 17,09S 6iL41 E 21,34 S 84,35 E 21,36 S 84.42 E 26.30 S 101.84 E 32.18 S 120.78 E 32.71 $ 122,43 E :38,49 S 141.44 E 44.52 S 164.21 E 44.9D S f65,73 E 5028 S 189.09 E 55.75 S 216,06 E 60.94 S 245,11 E 65,85 S 27623 E 7O.47 S 3(39A0 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/lOOft} (ft) 6016343.80 N 569257.38 E 6016343,80 N 569257.38 E 0.000 0,00 6016343,80 N 569257.38 E 0.000 0,00 6016343,61 N 56925823 E 1.000 0,87 6016343,05 N 569260,79 E 1.000 3.48 6016342,10 N 569265.05 E 1.000 7,82 6016340.79 N 569271.01 E 1.000 13.90 6016339.04 N 569278,66 E 1.000 21.71 6016336.63 N 569287,98 E 1.000 31.24 6016334,14 N 56929EL97 E 1.000 42.49 6018330.98 N 56~11,83 E 1,l)O0 55.45 6018327,35 N 569325.95 E 1,600 70.11 6016323.24 N 569341.93 E l,i)~O 86.49 6016323.23 N 569342.00 E 1.000 86,56 6016318.45 N 569359.46 E 1,000 104.50 60~6312.74 N 569378.45 E 1.000 124,O6 60~6312.23 N 569380.11 E 1,000 125,77 6016306.63 N 569399.17 E 1250 145.39 6016300.81 N 569422.00 E 12.50 168.78 6016300.45 N 569423.52 E 1,250 170,33 6016295,28 N 569446.93 E 1.250 194,21 6016290,06 N 569473.95 E 1.250 221.68 6016285.14 N 569503.05 E 1.250 251.I7 801628052 N 569534.21 E 1250 282.67 5016276,21 N 569567.42 E 1.250 316,16 Alaska State Plane Zone 4 Miine Point E Pad Comment 13 318' Casing KOP: Stad Dir ~ 100.0°/100fl: 4DO,O011 MD, 400.OOfl TVD Continue Oir @ 1,009"/10011: 800.OOfl M D, 799,68ft TVD Continue D1r @ 1.000°/10~: 1400AOIt MD, 1395,33ft TVD DI r Rale Increase @ 1.250°/100ft: 1608.37 ft M D, 1599,47ft TVD BASEPERMAFROST Conlinued... 3 August, 1998.17;01 Milne Point Unit Measured Depth Incl, Sub-Sea Depth ¢) Vertical Depth (ft) 2400.00 2L382 96.582. 2299.84 2357.09 2500.00 22.598 g5,803 2392.56 2449.81 2600.00 23.818 95,10D 2484..47 254.1.72 2815,04 24.000 95,000 2498,22 2555.47 2700.00 25,685 94,4 81 2576.32 2632 57 2800.00 27.671 93,946 2664.67 2721.92 2900.00 29.656 93,477 2752,41 2809,66 3000.00 31.647 93,082 2838,43 289.5.68 3100,00 33.637 92,691 2922.63 2979.88 3200,00 35.628 92,351~ 3004.91 3062,16 3300.00 37.6~ 92,055 3085,16 3142,4t 3319.09 38.000 92.009 3100.24 3157,49 3400.00 40.263 93,393 3163,00 3220.25 3500.00 43.080 94,94.4 3237,69 3294-.94 3600.00 45.916 96,340 3309.02 3366.27 ',,: 3700.00 48.768 97.605 3376,77 3434,02 .~ 3800.00 51.832 93,770 3440.78 3498.03 3808.93 51.888 98.869 34.46,30 3503,55 3900.00 51,868 98.86~) 3502,51 3559.76 4000.00 51,8~ 98,869 3564.23 3621,48 4100.00 51,8~ 98,869 3825,85 3683 20 4200.00 51.88~ 98.8b~ 31~87.67 3744,92 4300.00 51.888 98.869 3749,39 3806.64 4320.43 51,883 98.869 3'762,00 3819,25 4400,00 51,I~88 98.869 3811.11 3868.36 Sperry-Sun Drilling Services Proposal Report for MPE21 (MPE-29) ~fPE.21 (PROPOSED hIPE.29) WP1 FOR PEI~/tI'iTING ONLY Local Coordinates Northin9s Eastings (ft) (fi) 74.79 S 344.80 E 78.82 S 381,83 E 82.56 S 421.06 E 83.10 S 427,13 E 86.04. S 4§2,70 E 89.33 S 507.4.7 E 92.43 S .555.34. E 95.33 S 606.24- E 98.04 S 660,10 E 100.54 S 716.88 £ 102.83 S 776,48 E I03.24 S 788,16 E 105.66 S 639,18 E 110.52 S 905,48 E [17.43 S 975.21 E ~26.38 S 1048,20 E 137.33 S 112423 E 138.41 S 1131,16 E t49.46 S 1201.96 E 161.59 S 1279,70 E 173.72 S 1357,44 E 185.85 S 1435,18 E ~97.98 S 1512,92 E 200.46 S 1528,8{) E 210.11 S 1590.66 E Global Coordinales Dogleg Vertical Northings Eastings Rate Section (fi) ¢) (°/100fi) 6016272.21 N 589602.66 E 1.250 351,62 6016268,53 N 569639.93 E 12.50 389,05 6016265.1§ N 569679.19 E 12.50 428,41 8016264.68 N 569685.26 E 1.250 434,50 6016262,08 N 589720.86 E 2.000 470,14 8016259.19 N 569765,66 E 2.000 514,94 6016256,53 N 589813.55 E 2.000 562,78 6016254,10 N 569864.48 E 2.000 613,59 6016251,90 N 569918,37 E 2.000 667,31 8016249.93 N 589975,16 E 2,000 723,89 6016248.19 N 57003429 E 2.000 78325 6016247.89 N 570046,46 E 2.000 794.69 8016245.95 N 570097.51 E 3.000 845.73 8016241.71 N 570163,84 E 3.0~0 912.07 6016235.44 N 570233.64 E 3.000 982.09 6016227.17 N 570306,71 E 3,O00 1055.6~ 6016216.92 N 570382,84 E 3.000 1132,43 6016215.91 N 570369,78 E 3,000 1139.44 6016205.52 N 570460,68 E 0,000 1211.09 6016194.12 N 570538,52 E 0,000 1289.76 6016182.71 N 570616,37 E 0,000 1388,43 6016171.30 N 570694,22 E 0,000 1447,10 6016159.89 N 57D772, 07 E 0,000 1525.77 8018157.56 N 570787,98 E 0,000 1541.84. 6016148.49 N 5701~19.92 E 0.000 1604.44 Alaska State Plane Zone 4 Milne Point E Pad Commenl Dir Rale Increase @ 2.000°/100~1: 2615.04ft MD, 2555.47ft TVD Dlr Rate increase {~ 3,000V100ft: 3319.09ft MD, 3157.491t TVD End Dir, Sail @ 51.888": 3808.93It MD, 3503.55ft 'TVO TOP UGNU Con~nued.., 3 August, 1998-17:0! - 2. DriilOuest Sperry-Sun Drilling Serw'ces Proposal Report for MPE21 (MPE.29) BPE-21 (PROPOSED MPE.29) WP1 Uilne Point Unit FOE PEP,/~ITI'IN$ ONLY Measured Sub.Sea Vertical Local Coordinates Depth incl. Azim. Depth Depth Northings Fastings fit) (ft) (ft) (f~) fit) Global Coordlna{es Dogleg Vertical Nodhings Eastings Rate Section (ft) (fi) (°/lOOft) (it) 4500.00 51.888 98.869 3872.83 3930.08 222,24 S 1668,40 E 4600.00 51.888 98.869 393,~.55 3991.80 234,37 S 1746.14 E 4700.00 51.888 98.869 3996.27 4053.52 246,50 S 1823,88 E 4731.97 51.888 98.869 4016,00 4073.25 250,38 S 18.46.73 E 4800.00 51.888 98.869 4057,99 4115.24 258.63 S 191)1,$2 E 4900.00 51.888 98.869 4119,71 4176.96 270,76 S 1979,36 E 5000.00 51.888 98.869 4181.43 4238.68 282,89 S 2057.10 E 5069.70 51.888 98.869 4224.45 4281.70 291.35 S 2111.28 E 5100,00 51.020 98.524 4243.33 4300.58 294,93 S 2134.71 E 5135.85 50.000 98.108 4266,00 4323.25 298,91 S 2151,93 E 6016137,08 N 570927.77 E 0,000 1683.11 60161:25.67 N 571005.62 E 0,O0O 1761.'/B 6016114.27 N 571083.47 E 0,009 1840.45 6016110.62 N 571108.36 E 0,000 1865.59 6016102.86 N 571161.32 E 0,000 1919.12 6016091.45 N 571239.17 E 0,000 1997.79 6016080.04 N 571317,02 E 0.000 2076.46 6016072.09 N 57137L28 E 0.000 2131,29 6016068.73 N 571394.74. E 3.000 2154.99 60160 ,~5.00 N 571422.00 E 3.000 2182.50 5200,09 50.000 98.108 4307.36 4364.61 305,86 S 2210.73 E 5300.00 51).000 98.108 4371.64 4428.89 316,67 S 2286.57 E 5400.00 51).000 98.108 4435.92 4493.t7 327,47 S 2362,41 F.. 5500.00 51).000 98.108 4500.20 4557.45 338,28 S 2438.25 E 5502.80 51).000 98.I05 4502.00 4559.25 338,58 S 2440.37 E 5~00,00 51).000 98.I08 4564.,46 4621.73 349,08 S 2514.09 E 5700.00 50.000 98.I05 4628.76 4886.0f 359,88 S 2569.93 F_ 5800,00 50.000 98.105 4693.04 4750.29 370,69 S 2665.77 E 5802,80 50,000 98,I08 4694.84 4752.09 370.99 S 2667.89 E 6016058.50 N 571470,86 E 0.000 2231,79 6016048.40 N 571546.80 E 0.000 2308,40 6016038.30 N 571622,73 E 0.000 2385,00 6016028.20 N 571698,67 E 0.000 2461.60 6016027.92 N 571701),79 E 0.000 2463,75 6016018.11 N 571774,60 E 0,000 2538,21 6016008.01 N 571850,54 E 0.000 2614,81 6015997.91 N 571926,48 E 0.000 2691,42 6015997.63 N 571928,60 E 0.000 2693,56 Ali data is h feet unless otherwise slated. Directions and coordinates are relative to True North, Vertical depths are re]alive to Well. Northings and East[rigs are relative to Well The Dogleg Severity is in Degrees per 100fl, Vedical Seclion is from Well and calculated along an Azimuth of 97.917° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5802,80ft., The Bottom Hole Displacement is 2693.56tt., in the Direction ot 97.917" (True). Alaska State Plane Zone 4 Milne Point E Pad Comment TOP M SAND S[art DIr O 3.000°110011: 5069.70ft MD, 4281.70~t TVD End Dir. Sail 6 50.000°: 5135,65lt MD, 4323.25ft 'TOPSCHRADE R Target: MPE-21 TARGET, 200.00 R~dlus,. Geological · -' ... -., :., BASE,SCHRADER Tolal Deplb: 5802,60fl MD 4752.0911'1'VD 5 I/2' CAsing ' 3 August, ~g98.17:01 - 3" Dritlaues! TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ,ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: :907) 276-7542 July 7. 1998 T. Brcnt Reeves Drilling Engineering Supcn'isor BP Exploration (Alaska)Inc. POBox 196612 Anchorage. AK 99519-6612 Milne Point Unit MPE-21 BP Exploration (Alaska) Inc. Permit No. 98-115 Sur. Loc.: 3688'NSL. 1794'WEL. Sec. 25. T13N. RIOE. UM Btmhole Loc: 3535'NSL. 4456'WEL. Sec. 30. T13N. RI 1E. UM Dcar Mr. Recvcs: Enclosed is thc approved application for permit to drill thc above rcfcrenccd wcll. Thc permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Bloxvout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25.035. Sut'ficicnt notice (approxinmtcly 24 hours) of thc BOPE tcst pcrformcd bcforc drilling bclow the surface casing shoe must be given so that a representative of thc Commission may xx-imcss the test. Notice ma,,' bc given by contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. David ~,, Chairman BY ORDER OF THE COMMISSION .:: :' cncic, s utes cc: Department o1' Fish &(iame. tlabitat S¢ctioll w o encl. l)cpartment of l'hwiromnental C'onsc~'ation x~ o cncl. 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 June 12,1998 TO: Blair E. Wondzell, P.E. Senior Petroleum Engineer State Of Alaska, Oil & Gas Conservation Commission 3001 Porcupine Drive, Anchorage, Alaska 99501 RE: PERMIT TO DRILL REQUEST MILNE POINT E-21 WELL DEAR SIR: This correspondence confirms the conversation today between the undersigned and yourself concerning the referenced Permit To Drill Application. Mr. Scott pointed out that additional information has become available on the data in the application resulting in several changes in the permit information. These consist of the requirement to shut in MPE-23, a WAG injector with a proximity to MPE-21 of 73' at an MD of 3800'MD, while drilling the close approach portion of the well. The correction of the yield of the foamed intermediate stage of the surface cement job from 1.33 ft3/sk to 1.74 ft3/sk; and the use of 1 joint of 7" 26# BTC-MOD, L-80 as the top landing joint of the 5-1/2" 15.5# surface casing. It was agreed that it was not necessary to revise the June 9th, 1998 Permit To Drill, but that a note confirming the discussion and changes would surfice. The changes would be shown in the completion report. We thank you for your assistance with the above. Yours Truly, ~ ~ ~ge~co~t~ ~ Operations Drilling Engineer klc/rgs JUM lB ~98 DS:D4~M BP MILHE ~O1Hl GNOUH [ _~hared ~ _, _, _, _, _, _, _, _, _, _~e r v i c e s 'l rilling AlaSKa ~ 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 mT/.:) June 12, 1998 TO: Blair E. Wondzell, P.E. Senior Petroleum Engineer State Of Alaska, Oil & Gas Conservation Commission 3001 Porcupine Drive, Anchorage, Alaska 99501 RE: PERMIT TO DRILL REQUEST MIl,NE POINT E-21 WELL DEAR SIR: This correspondence confirms the conversation today between the undersigned and yourself concerning the referenced Permit To DriI1 Application. Mr. Scott pointed out that additional information has become ax, ailable on the data in the application resulting in several changes in the permit information. These consist of the requirement to shut in MPE-23, a WAG injector with a proximity to MPE-21 of 73' at an MD of 3800'MD, while drilling the close approach pmlion of the well. The correction of the yield of the foamed intermediate stage of the surface cement job from 1.33 ft3/sk to 1.74 ft3/sk; and the use of 1 joint of 7" 26# BTC-MOD, L-80 as the top landing joint of the 5-1/2" 15.5# surface casing. It was agreed that it was not necessary to revise the June 9'h, 1998 Permit To Drill, but that a note confirming the discussion and changes would surfice. The changes would be shown in the completion report. We thank you for your assistance with the above. .~tYours Truly, ~~ Operations Drilling Engineer klc/rgs JUN ] 5 1998 ~Og & Gas Cons. C~mi~ion STATE OF ALASKA ALASKA <,.~ . AND GAS CONSERVATION corv,..~_.SSlON PERMIT TO DRILL 20 AAC 25.005 !la. Type of work l~ Drill [-IRedrill Ilb. Typeofwell FI Exploratory I--IStratigraphicTest I~ Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 57' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028231/ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3688' NSL, 1794' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3506' NSL, 4967' WEL, SEC. 30, T13N, R11E, UM MPE-21 At total depth 9. Approximate spud date Amount $200,000.00 3535' NSL, 4456' WEL, SEC. 30, T13N, R11 E, UM 07/20/98 . 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 785'I No Close Approach 2555 5822' MD / 4752' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' MD Maximum Hole Angle 57.423° Maximum surface 1532 psig, At total depth ('l'VD) 4384' / 1960 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD . TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 16" 13-3/8" 72# L-80 BTC-Mod 120' 31' 31' 151' 151' 285 sx Arcticset I (Approx.) 6-3/4" 5-1/2" 15.5# J-55 BTC-Mod 5792' 30' 30' 5822' 4752' 362 sx Foamed CS III, 89 sx 'G', 272 sx CS III 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ProductionRECEIVED Liner ORIGINAL Perforation depth: measured ~8Sk~ 0it & Gas 00ns, Oom~issi0~ Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: R. George Scott, 564-5862 Prepared By Name/Number: Kathy Campoamor, 564-5122 21.1 hereby certif~going is tr/p~.and, d. d~r;ect td-th/best of my knowledge Signed T.B,r~tRele, yeVs....~/).,/~,~..,~,./~/t~ (¢~,~.~r~Title Drilling Engineering Supervisor Date Commission Use Only Permit Number I APl'Number Approval Date .. i See cover letter ~ ~-//,5-'[ 50- 0,3. ~ "- ~ c~ ~ C~ ~ "7 ---J ~ '"' ~",~[ for other requirements Conditions of Approval: Samples Required []Yes r~No Mud Log Required I-lYes ]~No Hydrogen Sulfide Measures []Yes ,J~ No Directional Survey Required J~Yes [] No Required Working Pressure for BOPE 1--12M; 1~3M; 1--15M; I-ll0M; FI15M Other: by order of Approved By Original Signed 6y Commissioner the commission Date 1~'/~ ~ , , ~_i~ !..I...~.~,~. Form 10-401 Rev. 12-01-85 -- , ! I~1 1.1...~ gavlo w, dUllil~ '~ Submit In Triplicate Shared Services Drilling Con~ct: I Well Name: IType of Well (producer or injector): R. George Scoff IMP E-21 Well Plan Summary ISchrader Bluff Producer 564-5862 Surface Location: 3688 FSL, 1794 FEL, S25 T13N R10E UM Target Location: 3506' FSL, 4967 FEL, S30 T13N R11E UM Bottom Hole Location: 3535'FSL, 4456' FEL, S30 T13N R11E UM I AFE Number: 1337135 I Estimated Start Date: 1 20 JULY 98 I I MD= I ss22' I I VD= Rig: I Nabors 27E I Operatin~l days to complete: 147s2' I 16.0 I KBE: 157ft I Well Design: Schrader Bluff Producer Formation Markers: Formation Tops MD TVDSS , KOP 400 400 Base of Permafrost 1882' 1800' Top of Ugnu 4242' 3762 Top M Sand 4721' 4016 Top NA (Target) 5154' 4266' Top of the N-A (EMW 8.6 ppg) Base Of Schrader 5522' 4502' TD 5822' 4695' TD at 300' MD past base of Schrader Bluff . Casing/Tub lng Program: Hole ~ize - Csg'/ WtJFt Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 16" 13-3/8" 72# L-80 BTC-MOD 120' 31'/31' 151'/151' 6-3/4" 5-1/2" 15.5# J-55 BTC-MOD 5792' 30'/30' 5822'/4752' Internal yield pressure of the 5-1/2 .... 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +4384' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1960 psi (8.6 ppg EMW), is 1532 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). MP E-21 Well Plan PAGE 3 jud ¥~' !9r¢~'' 1 Jun 98 ~as~ 0ii & 6~s Cons. Anchorage Logging Program: Open Hole Logs: MWD directional only from surface to 2200' MD. 4-Arm Caliper Log From T.D. to 151' M.D. (Base of 13-3/8" Conductor. MWD directional and LWD (GR/Resestivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr. Cased Hole Logs: A USIT LOG WILL BE RUN FROM T.D TO THE BASE OF THE CONDUCTOR. Mud loggers are NOT required for this well. Mud Program: ISpecial design considerations An inhibitive polymer mud is planned from surface to TD. Solids control is critical to the success of the system. Surface Mud PropertieS: I Density Marsh Yield LSRV 10 min pH Fluid (PPG) Viscosity Point gel Loss 8.6 150 40 50,000 8.5 NC to 9.0 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 30 14 16 8.5 <6 to to to to 9.5 60 35 9.0 LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17 Well Control: Well control equipment consists of: Rig (Nabors 27E) ,13-5/8", 5000 psi W.P.Annular and 3000 psi Diverter spool with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics are attached. Directional: I KOP: 1400' MD IMaximum Hole Angle: Close Approach Well: 57.423 NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #3 facility. Fluids Handling: All drilling and completion fluids will be hauled to Kuparuk, Drill site #3 or CC-2A for injection. Annular Injection: We are currently looking into this option, if Permitted a procedure and copy of permit will be issued. MP E-21 Well Plan PAGE 4 1 Jun 98 MP E-21 Proposed Summary of Operations . 2. 3. 4. 5. 6. 7. o Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 27E rig. NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program. Drill a 6-3/4" surface hole as per directional plan. Run Directional MWD from surface to +/- 2200'MD. POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP. : Drill 6-3/4" hole to TD as per directional plan. Lay down drill string and pick up 2-7/8" work strirtg for inner string cement job. (A 4-armed Caliper log will be run from TD to the base of the conductor to assist in planning the position of the port collar and volume of regular and foamed cement.) Prior to Cementing the casing will be displaced to sea water. Run and Cement 5-1/2"", 15.5#, J-55, Buttress-Modified casing. Refer to attached Detailed Cement Program and Back-up Port Collar operating Procedure. POOH freeze protect from 2000'MD to Surface. Following the cementing of the well and the landing of the 7" landing joint the casing will be tested to 3850 psi.(80% of internal yield). The Diverter system will be rigged down and the frac head provided by the Well Services group installed, and tested. POST DRILL AND CASE: Nabors Rig 4ES will run the completion on this well following rigless completion work. 1. The first part of the completion is planned to be done rigless. This includes perforating, frac'ing clean out. Rig 4ES is planned to be used for setting the screen and for the final running of the completion assembly. The well will be completed with 2-3/8" tubing. 2. A completion program will be issued for this. It is planned to run an ESPC completion with Centrilift Heat Trace to a depth of 5100"MD. Install Surface Lines and Wellhouse and turn well over to production. MP E-21 Well Plan PAGE 5 1 Jun 98 DRILLING HAZARDS AND RISKS: See the latest Milne Point E-Pad Data Sheet for offset information on E pad. The MPU PE group will be perforating, hydraulic fracturing and cleaning out this as per the completion program. 1. Hydrates: HYDRATES HAVE BEEN ENCOUNTERED ON WELLS DRILLED AT MILNE POINT 'E' PAD, in the interval of 2100-2400'MD just below the permafrost as summarized on the Pad data sheet, if encountered mud will be treated with 1-1.5 ppb Lechithin (See Attached Mud Program). If hydrates are encountered the cement program may be modified, to include a Cold Set III blend to ensure a high quality cement seal above the hydrate zones. 2. Close Approach: There are no close approach problems with MP E-21. 3. Lost Circulation: There have not been any significant lost circulation incidents reported on any of the E Pad wells. HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. Recently over the period of 1994-96 no stuck pipe problems have occurred but tight hole problems have been experienced. 4. Stuck Pipe Potential: There have been several STUCK PIPE incidents on Milne Point 'E' Pad. The E-22 and E-3 wells experienced stuck pipe incidents. These wells were drilled in 1994 and 1990 respectively. Be especi.ally aware of the need to maintain good hole cleaning properties and practices through the upper hole and the heavy clay sections REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE STUCK PIPE INCIDENTS. The frequency of wiper trips should be a minimum of once every 1000' as determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions using Hi/Low sweep combinations. If heavy gravel's are encountered while drilling the surface hole section, operations should be immediately stopped and the mud funnel viscosity is increased to help clean hole. 5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of 0.4476 psi/ft and a pressure of 1960 psi in the middle of the Schrader Bluff at 4384' TVDSS. 6. Directional Drillinq Concerns MP E-21 will be an ultra slim 6-3/4" hole drilled to a T.D. of 5822' md. KOP is 400' md and a variable build rate from that point will yield a sail angle of 57.423° at 3915' md. At 4779' md the well will begin to drop until a final angle of 50° is reached. The 50° angle will be held through the reservoir to TD. MP E- 21 will have a horizontal displacement of 2584.11' 7. Cement The surface hole will be cemented to surface with the following: Cold Set III Cement from base of permafrost to surface, a foamed 10# intermediate slurry from the base of the permafrost to 1000' TVD above the top of the Schrader Bluff, followed by Class G, run from TD to 1000' TVD above the top of the Schrader Bluff. The 6-3/4 .... hole will be cemented in a single stage to bring cement 1000' TVD above the top of the Schrader Bluff Sands, and assure cement returns to surface. A back up port collar will be run approximately 200'. below the permafrost the exact position determined from the caliper log. MP E-21 Well Plan PAGE 6 1 Jun 98 MP E-21 5-1/2"" SURFACE CASING CEMENT PROGRAM - B.J. Alaska CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS. Spacer 250bbls. Water 8.43 ppg. STAGE1 LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Intermediate) WEIGHT: Cold Set 12.2 ppg YIELD: 1.92ft3/sk. MIX WATER: 10.53 gal/sk WEIGHT: Foamed 10 ppg YIELD:1.33 ft3/sk MIX WATER: 6.12 gal/sk APPROX #SACKS: 187 Cold Set 111 THICKENING TIME: Greater than 6 hrs at 50° F. 175 Foamed ANNULAR VOLUME TOP OF TAIL CEMENT TO Port Collar AT 2200' MD +30% EXCESS. (Confirm From Caliper) STAGE1 TAIL CEMENT TYPE: PREMIUM 'G' ADDITIVES: APPROX #SACKS: FLUID LOSS: FI-33-.4%, CD-32- .3%, R-1-.1% FP-6Llghs. WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER 4.98 gal/sk 89 THICKENING TIME: Greater than 5 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 1000 FEET TVD ABOVE SCHRADER BLUFF + 30% EXCESS + 80'md 5-1/2 .... ,15.5# capacity for float joints. EST TOC 3310' md (Confirm from Caliper) STAGE2 Contingency: ADDITIVES: WEIGHT: APPROX #SACKS: Cold Set III PERMAFROST (If Single Stage Unsuccessful) Retarder 12.0ppg 272 SACKS YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2200' MD TO SURFACE+ 200% EXCESS. (Confirmed by Caliper) Note Excess is estimate only caliper will be used for final determination. DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT TOP JOB CEMENT TYPE: Permafrost Cold Set Set III NOTE: ADDITIVES: Retarder TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.2 ppg YI ELD: 1.92 ft3/sx MIX WATER: 10.53 gal/sk APPROX NO SACKS: 100 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL MP E-21 Well Plan PAGE 7 ' 1 Jun 98 CENTRALIZER PLA£.._JENT: .... 1. Spiral Glide 5-1/2' X 6-3/4" centralizers are planned for the 5-1/2" casing The number to be determined by the Caliper log, and also on the joint of casing above and below port collar. See attached Weatherford centralizer program in cementing section. 2. Place all centralizers in middle of joints using stop collars. Note: A revised centralizer program will be issued following receipt of the results of the 4-Arm Caliper Log. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace as per attached cement program. Mix slurry on the fly -- batch mixing is not necessary. Before Landing Casing following returns to surface the section of the diverter and wellhead system below the diverter line to the starting head may need to be will be displaced with inhibitive wash to prevent it from setting and thus easing the clean out of that section. : Refer to the Directional Drilling Program for recommended bottom hole assemblies. The amount of additional collars will depend on hole conditions and mud weight. Enough drill collars will be run between the directional assembly and the 4" drill pipe to assure the neutral point does not occur in the drillpipe. MP E-21 Well Plan PAGE 8 1 Jun 98 RDS DIVERTER AND BAG STYLE BOE for Surface Casings Bell Nipple & Flow Tee Hydril 13-5/8" 5000psi I ! BOP Controls & Actuator Diverter Spool 13-3/8" 3000 ps~ I Vetco Spool 13-3/8" 3000 psi 2 @ 3", Line Pipe Outlets for cmt rtns I Diverter Line, 10" Starting Head Diverter Knife Valve Hydralically Operated Automatic Open When Hydril is Closed. Normally Closed and auto. Hydril Open. S,I~:)~--I~I~'~'sLIn Shared Servic,$ Dfilll~g D rillQ ues t SURFACE LOCATION PLOT DATE: 5~7/98 Ho~on~l~hltel: · ~16~7.~ N,~51,~ E Creat~ By: RKB E~val~: ~.~ ~(ES~ C~r~le Sy~t~: NAD27 ~ S~e 13 3/8' Casing 177.~ MD 177.~ ~D o ] ~ ; Propo~l Da~ for MPE-21 (~2) WP5 KOP' Sta~ Dir ~ 0.500°/10~ ' 400.00ff MD, 400.00~ ~D~i~:~: ~w~' 400 00 ~ I ~ ~t~: T~ '~Stad Dir ~ 1.000°/100ff: 600.00fl MD, 599.99ff TVD , V~ ~ ~: W~I i V~~: 0.~ N,O.~ E /Stad DIr 0 1.500°/100~ ' 800.00ff MD, 799.86~ TVD .~.,~. ~. ~. v~ ,~,.~. ~.,.~. ~.v'"°" ~.~. 800 -- · o ~.~ o.~ o.s, o.~ ..,,, ~ ,,.~t~ ..~ . /Stad DIr ~ 2.000/lOOfl: 933.33H MD 932.86~ TVD ......... ,, ....................... 00( ,~ ~ ~.~ I.~ ~.~ ~.~ t.~2S L~ 1.4~ O.~ ~.~ ~.~ 1~.~ ~.~ 5.~1 s 6.6~ E 7.~ i.~ [ / 9)).)) 5.~ I~.~ ¢~.~ 11.595 I).81 E 14.47 I.~ 12ffi.~ IO. 333 I~.~ 1197.~ ~.45S 41.05 E 43.02 2.~ · O 14~.~ 15.333 I~.~ 1391.~ 62.~S 75.07 E Sta~ D r O 2.500/100fl: 1200.00fl MD, 1197.05fl TVD ~,~., ,,.,, ,o.~ 2~.~ o.~ ~ I 2411.61 25.~ 1~.~ 23~.~ 221.71 S 31U.~ E 322.62 5.~ ' 3111.61 Ig.~ 1~.~ ~11.~ 2~.23 S 562.~ E ~77.~ ' 391~.10 57.423 8~.413 ~35.~ 2~47S 1~07 E 105~,6~ 5.~ o.~ 1776.6~ ~nd nlr ~ ~ 15 333° ' 1400 00ff MD 1391 99ff TVD ; ,, ..... ,.,~ ~, '~ ~''1 v~ ~ · · · I ' 51~.32 ~.~ ~.7~ 4323.~ 181.50S 2~9.32E ~76.43 ~.~ ~ 400. ~ · 5521.41 ~.~ ~.782 4559.~ 165.71 S 23~.13 E 2355.82 O.~ ~ ~o~ - - ~ ....................... ~ P~ost ]8~7.~ ~ ~ /~ta~ DIr ~ 5.000°H00R: 2134.~4R MD, 2100.00fl ~D Q ~X ~DIr Rate Decrease ~ 1.000°/100ff: 2411.6 lff M D, 2360.81 ff TVD 0 - Dir Rate Increase ~ 5.000°/100ff: 3111.61ff MD, 3011.69ff TVD ~200 ; ~oo.~ o~ir, Sail ~ 57.423°: 3915.10ff MD, a635.87, . 390~ ' ~0.~ ~0. 000 ir Rate Decrease ~ 2.000°/100~:4779.10~ MD, 4101.07ff TVD · ~o.~ ~ ~End Dir, Sail ~ 50.000°: 5154.32ff MD, 4323.00ff TVD . ~ - ~7 ~-~ ..... Top N-A 4323.~ ~D ~ ~ -- ~~~~____~e Echrader Bluff4559.~ ~D ~ ~ Total Depth: 5821.~ff MD, 4751,84ff TVD 00 - 5 1/2' Casin ~21 .~ MD ffi 475; .~ '1 v o I I 0 800 ~ 600 2~0 Scale: ~inch = 800ffi Section ~imuth: 93.390' (True No~h) Vedical Section PROPOSAL TARGET SUMMARY Targel Nme: ~SS ~D~: Wel~ ~: G~ ~ffi~t~: MPE-21 T1 4~.~ 43~.~ 181.~ S, ~9.32 E ~1~.~ N,~14~.~ E ,. D illQ ESl~lel-q-~-SI-Jl-t Shared Services Drilling r uest ~.--..----...~=KsERv'~Es MPE-21 (98-2) WP5 I~~ Proposal Data for MPE-21 (98-2) WPS PROPOSAL TARGET SUMMARY w~ · ':' ~ wea Target Name: TVDSS TVDRKB: Weli'~ad Offsets: ,' Global ~tes: its: It I ,No~h Relerenc~: Tree North I MPE-21 T1 4266.00 4323.00 181 .SO S. 2069,32 E 6Ol1~.00 N,571422.00 E Dogleg s~vedly: D~ per 10Oit , Ve~cal Section Desctiplion:Well Valk:al Section Ofig~: 0.00 N,O.O0 E 0.00 0,000 0.533 0.00 0,00 N 0.00 E 0.00 I ~.oo o.o0o 0533 ~o.oo o.oo a o.oo E o.oo o.~ SURFACE LOCATION PLOT DATE: 5/27/98 laOO.oo ~5.333 mooo 13~.~) 6~.9~s ?5.o7E ~.~ ~.~ Horizontal ~tes: 6016227.23 N, ,5693,51.08 E Crealed By: 24! 1.61 25.0130 ]00.0(10 2360.80 22].?! S 310.05 E 322.62 5.000 RKBElevation: 33.00It Rig(EST)~:~ &"~,-~ ~]j 3111.61 IS.(XI0 100.000 3011.69 266,?,3S 562_54E 577.30 24,00 It Well (CBE) /~ t/,~ 3915.10 57,423 85.413 3635.87 260.47 S 1042.07 E 1055.65 5.000 57.00 ff RKB - AMSL Checked By: ~ 4779.10 57.4~3 85.413 4101.07 20224 S 1767.80£ 1776.67 0.000 · 5154.32 50.000 86.782 4323.00 181.50 S 2069.32 E 2076.43 2.000 Coon:linate System: NAD27 Alaska State pianos, 5521.48 50,000 86.782 4559.00 165.71 S 2350.13 E 2355.82 0.000 Zone 4. US Foot Approvod By: 5821.48 50.000 86.7112 4751.84 152.81 S 2579.58 E 2584.11 0.000 Scale: t inch = 40Oft Eastings ,, fro 5oo : fi~: S~ ~ S 0~/1~: ~,~ ~, ~.~ ~ ~~ ~,.~ ' 15.~' .... ~ MO, 1~1."~ ' / I 1800~01800.0~ ~ e s'~/l~: 2134'14R MD' 21~'~ ~~ ~~: , . I · -~o , --400 II ~ I I I I I I I I I ~ -~0 0 ~0 800 ~ 200 1600 2000 2~0 2800 $ Scale: t inch = ~ffi Easti~s Reference is True No~h .,, Sperry-Sun Drilling Services Proposal Report for MPE-21 (98-2) WP5 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -57.00 0.00 100.00 0.000 0.000 43.00 100.00 177.00 0.000 0.000 120.00 177.00 200.00 0.000 0.000 143.00 200.00 300.00 0.000 0.000 243.00 300.00 400.00 0.000 0.000 343.00 400.00 500.00 0.50,0 130.000 443.00 500.00 600.00 1.000 130.000 542.99 599.99 700.00 2.000 130.000 642.95 699.95 800.00 3.000 130.000 742.86 799.86 900.00 4.500 130.000 842.64 899.64 933.33 5.000 130.000 875.86 932.86' 1000.00 6.333 130.000 942.20 999.20 1100.00 8.333 130.000 1041.38 1098.38 1200.00 10.333 130.000 1140.05 1197.05 1300.00 12.833 130.000 1238.00 1295.00 1400.00 15.333 130.000 1334.99 1391.99 1500.00 15.333 130.000 1431.43 1488.43 1600.00 15.333 130.000 1527.87 1584.87 1700.00 15.333 130.000 1624.31 1681.31 1800.00 15.333 130.000 1720.75 1777.75 1882.17 15.333 130.000 1800.00 1857.00 1900.00 15.333 130.000 1817.19 1874.19 2000.00 15.333 130.000 1913.63 1970.63 2100.00 15.333 130.000 2010.07 2067.07 2134.14 15.333 130.000 2043.00 2100.00 2200.00 17.131 120.104 2106.24 2163.24 2300.00 20.562 108.782 2200.90 2257.90 2400.00 24.518 100.771 2293.26 2350.26 2411.61 25.000 100.000 2303.80 2360.80 Local Coordinates Northings · Eastings (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.28 S 0.33 E 1.12 S 1.34 E 2.80 S 3.34 E 5.61 S 6.68 E 9.81 S 11.69 E 11.59 S 13.81 E 15.82 S 18.85 E 24.02 S 28.63 E 34.45 S 41.05 E 47.35 S 56.43 E 62.99 S 75.07 E 79.99 S 95.33 E 96.99 S 115.58 E 113.98 S 135.84 E 130.98 S 156.10 E 144.95 S 172.74 E 147.98 S 176.35 E 164.98 S 196.61 E 181.97 S 216.87 E 187.78 S 223.78 E 198.24 S 238.85 E 211.29 S 268.24 E 220.83 S 305.27 E 221.71 S 310.05 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°r~OOft) 6016227.23 N 569351.08 E 6016227.23 N 569351.08 E 0.000 6016227.23 N 569351.08 E 0.000 6016227.23 N 569351.08 E 0.000 6016227.23 N 569351.08 E 0.000 6016227.23 N 569351.08 E 0.000 6016226.95 N 569351.42 E 0.500 6016226.12 N 569352.43 E 0.500 6016224.46 N 569354.45 E 1.000 6016221.68 N 569357.82 E 1.000 6016217.53 N 569362.86 E 1.500 6016215.77 N 569365.00 E 1.500 6016211.59 N 569370.08 E 2.000 6016203.48 N 569379.93 E 2.000 6016193.17 N 569392.45 E 2.000 6016180.41 N 569407.95 E 2.500 6016164.94 N 569426.73 E 2.500 6016148.13 N 569447.15 E 0.000 6016131.32 N 569467.56 E 0.000 6016114.52 N 569487.98 E 0.000 6016097.71 N 569508.39 E 0.000 6016083.90 N 569525.17 E 0.000 6016080.90 N 569528.80 E 0.000 6016064.09 N 569549.22 E 0.000 6016047.28 N 569569.63 E 0.000 6016041.54 N 569576.60 E 0.000 6016031.22 N 569591.76 E 5.000 6016018.44 N 569621.27 E 5.000 6016009.25 N 569658.39 E 5.000 6016008.42 N 569663.18 E 5.000 Vertical Section (ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.35 1.40 3.50 7.00 12.25 14.47 19.75 30.00 43.02 59.13 78.66 99.89 121.12 142.34 163.57 181.01 184.80 206.02 227.25 234.50 250.15 280.26 317.79 322.62 Comment Alaska State Plane Zone 4 Milne Point E Pad 13 3/8' Casing KOP: Stai~ Dir @ 0.500°/100ft: 400.00ft MD, 400.00ft 'I'VD Start Dir @ 1.000°/100ft: 600.00ft MD, 599.99ft TVD Start Dir @ 1.500°/100ft: 800.00ft MD, 799.86ft TVD Start Dir @ 2.000°/100ft: 933.33ft MD, 932,86ft 'I-VD Start Dir @ 2.500°/100ft: 1200.00ft MD, 1197.05ft TVD End Dir, Sail @ 15.333°: 1400.00ft MD, 1391.99ft TVD Base Permafrost Start Dir @ 5.000°/100ft: 2134.14ft MD, 2100.00ft TVD Dir Rate Decrease @ 1.000°/100ft: 2411.61ft MD, 2360.81ft TVD Continbed... 27 May, 1998 - 11:02 - 1 - DrillQuest Sperry-Sun Drilling Services Proposal Report for MPE-21 (98-2) WP5 Milne Point Unit Measured Depth (ft) Incl. 2500.00 2600.00 27O0.00 2800.00 2900.00 3000.00 3100.00" 3111.61 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 3915.10 4000.00 4100.00 4200.00 4300.00 4400.O0 4500.00 4600.00 4700.00 4779.10 4800.00 4900.00 5000.00 5100.00 24.116 23.116 22.116 21.116 20.116 19.116 18.116 18.000 22.220 27.067 31.959 36.877 41.812 46.759 51.713 56.674 57.423 57.423 57.423 57.423 57.423 57.423 57.423 57.423 57.423 57.423 57.009 55.030 53.051 51.074 Azim. lOO.OOO 1 oo.ooo 1 oo.ooo 1 oo.ooo lOO.OOO lOO.OOO lOO.OOO 1 oo.ooo 96.156 93.205 91 .o96 89.498 88.229 87.184 86.296 85.522 85.413 85.413 85.413 85.413 85.413 85.413 85.413 85.413 85.413 85.413 85.483 85.826 86.187 86.566 Sub-Sea Depth (ft) 2384.20 2475.82 2568.13 2661.10 2754.69 2848.89 2943.65 2954.69 3037.68 3128.55 3215.55 3298.02 3375.33 3446.9O 3512.17 3570.66 3578.87 3624.58 3678.43 3732.27 3786.11 3839.95 3893.80 3947.64 4001.48 4044.07 4055.39 4111.28 4170.00 4231.47 Vertical Depth (ft) 2441.20 2532.82 2625.13 2718.10 2811.69 2905.89 3000.65 3011.69 3094.68 3185.55 3272.55 3355.02 3432.33 3503.90 3569.17 3627.66 3635.87 3681.58 3735.43 3789.27 3843.11 3896.95 3950.80 4004.64 4058.48 4101.07 4112.39 4168.28 4227.00 4288.47 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/~OOft) Vertical Section (ft) 228.08 S 346.23 E 6016002.38 N 569699.42 E 1.000 359.11 235.04 S 385.68 E 6015995.79 N 569738.93 E 1.000 398.90 241.72 $ 423.55 E 6015989.46 N 569776.86 E 1.000 437.10 248.12 S 459.83 E 6015983.41 N 569813.20 E 1.000 473.70 254.23 S 494.50 E 6015977.61 N 569847.93 E 1.000 508.67 260.06 S 527.56 E 6015972.09 N 569881.04 E i.000 542.02 265.60 S 559.00 E 6015966.84 N 569912.53 E 1.000 573.73 266.23 S 562.54 E 6015966.25 N 569916.08 E 1.000 577.30 270.39 S 592.63 E 6015962.36 N 569946.20 E 5.000 607.58 273.69 S 634.17 E 6015959.45 N 569987.77 E 5.000 649.24 275.47 S 683.38 E 6015958.13 N 570036.99 E 5.000 698.47 275.72 S 739.88 E 6015958.41 N 570093.49 E 5.000 754.89 274.42 S 803.24 E 6015960.29 N 570156.84 E 5.000 818.06 271.60 S 872.98 E 6015963.77 N 570226.55 E 5.000 887.52 267.27 S 948.57 E 6015968.80 N 570302.10 E 5.000 962.72 261.47 S 1029.44 E 6015975.35 N 570382.91 E 5.000 1043.10 260.47 S 1042.07 E 6015976.47 N 570395.53 E 5.000 1055.65 254.75 S 1113.39 E 6015982.86 N 570466.79 E 0.000 1126.50 248.01 S 1197.38 E 6015990.38 N 570550.72 E 0.000 1209.95 241.27 ~S 1281.38 E 6015997.90 N 570634.65 E 0.000 1293.40 234.53 S 1365.38 E 6016005.42 N 570718.58 E 0.000 1376.86 227.79 S 1449.37 E 6016012.94 N 570802.51 E 0.000 1460.31 221.05 S 1533.37 E 6016020.46 N 570886.44 E 0.000 1543.76 214.31 S 1617.37 E 6016027.98 N 570970.37 E 0.000 1627.21 207.57'S 1701.37 E 6016035.50 N 571054.30 E 0.000 1710.66 202.24 S 1767.80 E 6016041.45 N 571120.69 E 0.000 1776.67 200.85 S 1785.32 E 6016043.01 N 571138.20 E 2.000 1794.08 194.56 S 1868.00 E 6016050.06 N 571220.81 E 2.000 1876.24 188.92 S 1948.75 E 6016056.46 N 571301.50 E 2.000 1956.51 183.93 S 2027.45 E 6016062.18 N 571380.16 E 2.000 2034.78 Alaska State Plane Zone 4 Milne Point E Pad Comment Dir Rate Increase @ 5.000°/100ft: 3111 ..61ft MD, 3011.69ft TVD End Dir, Sail @ 57.423°: 3915.10ft MD, 3635.87ft TVD Dir Rate Decrease @ 2.000°/100ft: 4779.10ft MD, 4101.07ft TVD Contin'ued... 27 May, 1998 - 11:02 - 2 - DrillQuest Sperry-Sun Drilling Services Proposal Report for MPE-21 (98-2) WP5 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 5154.32 50.000 86.782 4266.00 4323.00 181.50 S 2069.32 E 5200.00 50.000 86.782 4295.36 4352.36 179.54 S 2104.25 E 5300.00 50.000 86.782 4359.64 4416.64 175.23 S 2180.74 E 5400.00 50.000 86.782 4423.92 4480.92 170.93 S 2257.22 E 5500.00 50.000 86.782 4488.20 4545.20 166.63 $ 2333.71 E 5521.48 50.000 86.782 4502.00 4559.00 165.71 S 2350.13 E 5600.00 50.000 86.782 4552.47 4609.47 162.33 S 2410.19 E 5700.00 50.000 86.782 4616.75 4673.75 158.03 S 2486.67 E 5800.00 50.000 86.782 4681.03 4738.03 153.73 S 2563.16 E 5821.48 50.000 86.782 4694.84 4751.84 152.81 $ 2579.58 E Global Coordinates Dogleg Northings Eastings Rate (it) (ft) (°/'~OOft) 6016065.00 N 571422.00 E 2.000 6016067.29 N 571456.91 E 0.000 6016072.30 N 571533.35 E 0.000 6016077.31 N 571609.80 E 0.000 6016082.33 N 571686.24 E 0.000 6016083.40 N 571702.65 E 0.000 6016087.34 N 571762.68 E 0.000 6016092.35 N 571839.12 E 0.000 6016097.36 N 571915.56 E 0.000 6016098.44 N 571931.98 E 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 9.3.390° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5821.48ft., The Bottom Hole Displacement is 2584.11ft., in the Direction of 93.390° (True). Vertical Section (ft) 2076.43 2111.19 2187.28 2263.38 2339.48 2355.82 2415.57 2491.67 2567.76 2584.11 Alaska State Plane Zone 4 Milne Point E Pad Comment End Dir. Sail @ 50.000°: 5154.32ft MD, 4323.00ft TVD Top N-A Ta?get: MPE 21 T1,200.00 Radius., Geological Base Schrader Bluff Total Depth: 5821.48ft MD, 4751.84ft 'I'VD 5 1/2" Casing 27 May, 1998 - 11:02 - 3 - DrillQuest Shared Services Drilling Contact: I Well Name: R. George Scott IMP E-21 Well Plan Summary IType of Well (producer or injector): Schrader Bluff Producer 564-5862 Surface Location: 3688 FSL, 1794 FEL, S25 T13N R10E UM 3506' FSL, 4967 FEL, S30 T13N R11E UM Tar~let Location: Bottom Hole Location: 3535'FSL, 4456' FEL, S30 T13N R11E UM I AFE Number: 1337135 I · Estimated Start Date: 1 20 JULY 98 I I,Ri9: I Nabors 27E I Operatin~l days to complete: 1 6.0 MD: J5822' I I'rVD: ~ 4752' I Schrader Bluff Producer I Well Design: Formation Markers: IKBE: 157~ I Formation Tops MD TVDSS ~ KOP 4OO 400 Base of Permafrost 1882' 1800' Top of Ugnu 4242' 3762 Top M Sand 4721' 4016 Top NA (Target) 5154' 4266' Top of the N-A (EMW 8.6 ppg) Base Of Schrader 5522' 4502' TD 5822' 4695' TD at 300' MD past base of Schrader Bluff Casing/Tul: in9 Program: Hole ~ize ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 16" 13-3/8" 72# L-80 BTC-MOD 120' 31'/31' 151'/151' 6-3/4" 5-1/2" 15.5# J-55 BTC-MOD 5792' 30'/30' 5822'/4752' Internal yield pressure of the 5-1/2"" 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/fi) to the reservoir at ±4384' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1960 psi (8.6 ppg EMW), is 1532 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). MP E-21 Well Plan PAGE 3 1 Jun 98 Anchorage Logging P.rogram: Open Hole Logs: MWD directional only from surface to 2200' MD. 4-Arm Caliper Log From T.D. to 151' M.D. (Base of 13-3/8" Conductor. MWD directional and LWD (GR/Resestivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 fi/hr. Cased Hole Logs: A USIT LOG WILL BE RUN FROM T.D TO THE BASE OF THE CONDUCTOR. Mud loggers are NOT required for this well. Mud Program: ISpecial design considerations I An inhibitive polymer mud is planned from surface to TD. Solids I control is critical to the success of the system. .I Surface Mud Properties: I Density Marsh Yield LSRV 10 min pH Fluid {PPG) Viscosity Point gel Loss 8.6 150 40 50,000 8.5 NC to 9.0 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 30 14 16 8.5 <6 to to to to 9.5 60 35 9.0 LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17 Well Control: Well control equipment consists of: Rig (Nabors 27E) ,13-5/8", 5000 psi W.P.Annular and 3000 psi Diverter spool with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics are attached. Directional: I KOP: 1400' MD IMaximum Hole Angle: Close Approach Well: 57.423 NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #3 facility. Fluids Handling: All drilling and completion fluids will be hauled to Kuparuk, Drill site #3 or CC-2A for injection. Annular Injection: We are currently looking into this option, if Permitted a procedure and copy of permit will be issued. MP E-21 Well Plan PAGE 4 1 Jun 98 MP E-21 Proposed Summary of Operations . . 4. 5. 6. 7. . . Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 27E rig. ~.._ NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program. Drill a 6-3/4" surface hole as per directional plan. Run Directional MWD from surface to +/- 2200'MD. POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP. Drill 6-3/4" hole to TD as per directional plan. Lay down drill string and pick up 2-7/8" work strirtg for inner string cement job. (A 4-armed Caliper log will be run from TD to the base of the conductor to assist in planning the position of the port collar and volume of regular and foamed cement.) Prior to Cementing the casing will be displaced to sea water. Run and Cement 5-1/2"", 15.5#, J-55, Buttress-Modified casing. Refer to attached Detailed Cement Program and Back-up Port Collar operating Procedure. POOH freeze protect from 2000'MD to Surface. Following the cementing of the well and the landing of the 7' landing joint the casing will be tested to 3850 psi.(80% of internal yield). The Diverter system will be rigged down and the frac head provided by the Well Services group installed, and tested, POST DRILL AND CASE: Nabors Rig 4ES will run the completion on this well following rigless completion work. 1. The first part of the completion is planned to be done rigless. This includes perforating, frac'ing clean out. Rig 4ES is planned to be used for setting the screen and for the final running of the completion assembly. The well will be completed with 2-3/8" tubing. 2. A completion program will be issued for this. It is planned to run an ESPC completion with Centrilift H.eat Trace to a depth of 5100"MD. Install Surface Lines and Wellhouse and turn well over to production. MP E-21 Well Plan PAGE 5 1 Jun 98 DRILLING HAZARDS AND RISKS: See the latest Milne Point E-Pad Data Sheet for offset information on E pad. The MPU PE group will be perforating, hydraulic fracturing and cleaning out this as per the completion program. 1. Hydrates: HYDRATES HAVE BEEN ENCOUNTERED ON WELLS DRILLED AT MILNE POINT 'E' PAD, in the interval of 2100-2400'MD just below the permafrost as summarized on the Pad data sheet. If encountered mud will be treated with 1-1.5 ppb Lechithin (See Attached Mud Program)~-'--T- If hydrates are encountered the cement program may be modified, to include a Cold Set ill blend to ensure a high quality cement seal above the hydrate zones. 2. Close Approach: There are no close approach problems with MP E-21. 3. Lost Circulation: .. There have not been any significant lost circulation incidents reported on any of the E Pad wells. HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. Recently over the period of 1994-96 no stuck pipe problems have occurred but tight hole problems have been experienced. 4. Stuck Pipe Potential: There have been several STUCK PIPE incidents on Milne Point 'E' Pad. The E-22 and E-3 wells experienced stuck pipe incidents. These wells were drilled in 1994 and 1990 respectively. Be especi.ally aware of the need to maintain good hole cleaning properties and practices through the upper hole and the heavy clay sections REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE STUCK PIPE INCIDENTS. The frequency of wiper trips should be a minimum of once every 1000' as determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions using Hi/Low sweep combinations. If heavy gravel's are encountered while drilling the surface hole section, operations should be immediately stopped and the mud funnel viscosity is increased to help clean hole. 5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of 0.4476 psi/ft and a pressure of 1960 psi in the middle of the Schrader Bluff at 4384' TVDSS. 6. Directional Drillinq Concerns MP E-21 will be an ultra slim 6-3/4" hole drilled to a T.D. of 5822' md. KOP is 400' md and a variable build rate from that point will yield a sail angle of 57.423° at 3915' md. At 4779' md the well will begin to drop until a final angle of 50° is reached. The 50° angle will be held through the reservoir to TD. MP E- 21 will have a horizontal displacement of 2584.11' 7. Cement The surface hole will be cemented to surface with the following: Cold Set III Cement from base of permafrost to surface, a foamed 10# intermediate slurry from the base of the permafrost to 1000' TVD above the top of the Schrader Bluff, followed by Class G, run from TD to 1000' TVD above the top of the Schrader Bluff. The 6-3/4 .... hole will be cemented in a single stage to bring cement 1000' TVD above the top of the Schrader Bluff Sands, and assure cement returns to surface. A back up port collar will be run approximately 200'. below the permafrost the exact position determined from the caliper log. MP E-21 Well Plan PAGE 6 1 Jun 98 MP E-21 5-1/2 ....SURFACE CASING CEMENT PROGRAM - B.J. Alaska CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS. Spacer 250bbls. Water 8.43 PPg. STAGE1 LEAD: TYPE Cold Set I!1 PERMAFROST, Foamed (10ff Int?__rmediate) WEIGHT: Cold Set 12.2 ppg YIELD: 1.92ft3/sk. MIX WATER: 10.53 gal/sk WEIGHT: Foamed 10 ppg YIELD:1.33 ft3/sk MIX WATER: 6.12 gal/sk APPROX #SACKS: 187 Cold Set 111 THICKENING TIME: Greater than 6 hrs at 50° F. 175 Foamed ANNULAR VOLUME TOP OF TAIL CEMENT TO Port Collar AT 2200' MD +30% EXCESS. (Confirm From Caliper) STAGE1 TAIL CEMENT TYPE: PREMIUM 'G' ADDITIVES: APPROX #SACKS: FLUID LOSS: FI-33-.4%, CD-32- .3%, R-1-.1% FP-6L lghs. WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER 4.96 gal/sk 89 THICKENING TIME: Greater than 5 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 1000 FEET TVD ABOVE SCHRADER BLUFF + 30% EXCESS + 80'md 5-1/2 .... ,15.5# capacity for float joints. EST TOC 3310' md (Confirm from Caliper) STAGE2 Contingency: ADDITIVES: WEIGHT: APPROX #SACKS: Cold Set III PERMAFROST (If Single Stage Unsuccessful) Retarder 12.0ppg 272 SACKS YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2200' MD TO SURFACE+ 200% EXCESS. (Confirmed by Caliper) Note Excess is estimate only caliper will be used for final determination. . . - DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT' TOP JOB CEMENT TYPE: Permafrost Cold Set Set III NOTE: ADDITIVES: Retarder TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.2 ppg YI ELD: 1.92 ft3/sx MIX WATER: 10.53 gal/sk APPROX NO SACKS: 100 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL MP E-21 Well Plan PAGE 7 1 Jun 98 CENTRALIZER P LAcE~i~ENT: 1. Spiral Glide 5-1/2' X 6-3/4' centralizers are planned for the 5-1/2" casing The number to be determined by the Caliper log, and also on the joint of casing above and below port collar. See attached Weatherford centralizer program in cementing section. 2. Place all centralizers in middle of joints using stop collars. Note: A revised centralizer program will be issued following receipt of the results of the 4-Arm Caliper Log. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior-to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace as per attached cement program. Mix slurry on the fly -- batch mixing is not necessary. Before Landing Casing following returns to surface the section of the diverter and wellhead system below the diverter line to the starting head may need to be will be displaced with inhibitive wash to prevent it from setting and thus easing the clean out of that section. Refer to the Directional Drilling Program for recommended bottom hole assemblies. The amount of additional collars will depend on hole conditions and mud weight. Enough ddll collars will be run between the directional assembly and the 4" drill pipe to assure the neutral point does not occur in the drillpipe. MP E-21 Well Plan PAGE 8 1 Jun 98 RDS DIVERTER AND BAG STYLE BOE for Surface Casings Bell Nipple & Flow Tee Hydril 13-5/8" 5000psi ! BOP Controls & Actuator Diverter Spool 13-3/8" 3000 ps~ I VetcoSpoo' I 13-3/8" 3000 psi 2 @ 3", Line Pipe Outlets for cmt rtns I Diverter Line, 10" Starting Head Diverter Knife Valve Hydralicaily Operated Automatic Open When Hydril is Closed. Normally Closed and auto. Hydril Open. sl:l~-i~D~'sur'l Shared Services Drilling I DrillQ uext ~--~'L,~",...N-~=.,~S~,"r,,V,~.Ca~; MPE-21 (98-2) WP5 ~PLOT DATE: 5~7/98 SURFACE LOCATION ~ Ho~onlll ~galel: ~18~7,~ N, ~51.~ E Creal~ By: , RKB Eleval~: ~.~ ~ R~(ES~ 24.~ We~(CBE)~ ~7.~, ~s.~sL c,~ By: ~ ~~ i C~rd~le Sy~l~: NAD27 ~ S~te Z~e 4. US F~t ~ By: 13 3/8' Casing : 177.~ MD 177.00 ~D 0 ' " ~ [ Proposal Da~ for MPE-21 (~-2) WP5 ] ' ~ KOP · Stad DIr ~ 0.500°/100~· 400.00ff MD, 400.00ff ~D~i~;~: ~"w" 40000 ~.~StaH Dir ~ 1.000°/100ff ' 600.00fl MD, 599.99~ TVD v~~:~=~: ~, I V~ ~ ~: o.~ N.o.~ E ~oc.~ /Stad Dir ~ 2.000°/100fl: 933.33. MD, 932.86~ TVD ~:~ ~:~ ~ .~ 1:;~ :~ ~ . .13 . 5 .~ 1.125 134 E I L 933.33 5.~ I~.~ 932.~ I 1.5~ ~ 13 8l E J4 [ I 12~.~ 10.333 I~.~ i 19T.~ ~.45~ 41USE 43.0~ ' 0 . 4~.~ 15.333 I~.~ 391 ~ 62.~) ~ 7507 E l/Stad D~r ~ 2.500 dOOR. 1200.00~ MD, 1197.05~TVD ~,~.,, ,,.., ,,o.~ ~,~ ......... ~:~,, ~ 3111.61 I1.~ Iffi.~ 3011.~ 2~.23 s 562.M E 577.~ I.uD I O ~ 391t.10 ~7.423 11.411 ~1~.17 1~.4~ ~ Iml.o7 E ~ /End DIr Sail O 15.333 : 1400.00ff MD, 1391.99fl~D : ,,,.,o ..,~ ..,. ,,o,.~ ~o,~,~ ...... ~ ,o~.,~ 'vI ' 5521.41 ~.~ ~.782 4519.~ 165.71 s 23~.13 E 2355.12 0.~ ~ ~/~t~ DIr G 5.000°/~00~: 2184.~4~ MD, 2~00.00~ ~D ~ ..~..X/DIr Rate Decrease ~ 1.000°/100ff: 2411.61ff MD, 2360.81ff TVD 400 > ~ooo% Dir Rate Increase ~ 5.000°/100~: 3111.61fl MD, 3011.69~ TVD 3200 ~oo.~ 39o Dlr, Sail ~ 57.423 : 3915.10E MD, 3635.87fl TVD 00 t ~~Ir Rate Decrease ~ 2.000°/100~: 4779.10~ MD, 4101.07fl TVD · 4000.~ 4000. End Dir, Sail ~ 50.000°: 5154.32E MD, 4323.00~ TVD - '~7 ~ =~ ...... Top W-A 4323.~ ~D II ~ Total Depth: 5821.48ff MD, 4751.84fl TVD 00 - 5 1/2" Casin ~21.48 MD i I I 475;.84 ,i~'D 0 800 ~ 600 2~0 ~cale: ~inch = 800~ ~ection ~imuth: ~3.3~0' (True No~h) Ve~ical Section PROPOSAL TARGET SUMMARY MPE-21 T1 42~.~ 43~.~ 181.~ S, ~9.32 E ~1~.~ N,~14~.~ E ,. IShared Or#t . DrillQuest' o"'~'2Yd~"d2c~s MPE-21 08-2) WP5 Prowl Data for MPE-21 (9~2) WP5 PROPOSAL TARGET SUMMARY v~: wa ~ ~: W~ MPE-21 T1 4~.~ ~.~ 181.~ S. ~g.32 ~ ~1~.~ N.~I~ E ~ ~: ~ ~ 1~ V~ ~ ~:W~ V~ ~ ~: 0.~ N,O.~ E ~ ~ ~ V~ ~ E~t~ V~ o.~ o.~ o~ o.~ o.~ ~ o.~ ~ o.~ ~.~ o.~ o~ ~.~ o.~ ~ o.~ ~ o.~ o.~ 8~.~ 3.~ 1~.~ ~.~ 5.61 S 6.~ E ~.~ I 933.33 5.~ 1~.~ 932.~ 1159 S 13.81 E 14.47 1.~ 12~.ffi 10.333 1~.~ 1197.~ ~.45S 41.05 E 43.~ 2.~ SURFACE LOCAIION PLOI DAlE: 5~7~ ~.~ ~.~ m.~ m~.~ ~2.~s ~.o~ ~.~ ~.~ 21~.14 15,333 I~.~ 21~.~ 187.~ S 223.78 E 2~ 0.~ ~,~~~ 2411.61 25 .~ t~.~ 2~ ~l .TlS 310.0SE 3~ .~ 5.~ HO~ ~tes: ~16~.~ N. ~9~1.~ E C~ ~: 3111.61 18.~ l~.~ ~11.~ 2~23 S ~ E 577.~ ! ~: ~.ffi, ~ (ESB 24.~ ~ wea (CBE) 39~5.t0 57.4~ s5.4~3 ~35~ 2~.47 s ~2.07 E t055.~ 5.~ 4779.10 57.4~ 85.413 4lOl.~ 2~24S 1767.~ E I~6.67 0.~ S7.ffifl R~-~SL ~: , . 51~.32 ~.~ ~.~2 4323.m tS~.~S 2~9.32E 2m6.~3 2.~ 5521.~ ~.~ ~.782 4559.ffi 1~.71 S 23~.13 E 2355.82 0.~ Z~e 4. US ~ ~ ~: 5821 .~ ~.~ ~.~2 4751.g 152.81 S 2~.58 E 2584.11 O.~ Scale: linch = ~ffi Eastings ,, ... ,5oo o:oo ~ ~ o 1.~: ~.~MD, ~.~ ~ I ~~ ~ ' z~t,~: ,~.~ uo. ,,,.~ ~ ~ 5 1/2" Ca~ ng 0 0 ~~,~. ,s.~- ..... ~.1.,.~ / X 5821.48 MD : ' ~ E~ a ~ o ~' 4751.84 ~D -~o- I --4oo I I I I I I I I -~0 0 ~O 800 12OO 1600 2000 2~0 2800 Scale: linch = ~O~ Eastinfls Reference is True No~h Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Local Coordinates Depth Northings · Eastings (ft) (ft) (ft) 0.00 0.000 0.000 -57.00 0.00 100.00 0.000 0.000 43.00 100.00 177.00 0.000 0.000 120.00 177.00 200.00 0.000 0.000 143.00 200.00 300.00 0.000 0.000 243.00 300.00 400.00 0.000 0.000 343.00 400.00 500.00 0.5 .0~) 130.000 443.00 500.00 600.00 1.000 130.000 542.99 599.99 700.00 2.000 130.000 642.95 699.95 800.00 3.000 130.000 742.86 799.86 900.00 4.500 130.000 842.64 899.64 933.33 5.000 130.000 875.86 932.86' 1000.00 6.333 130.000 942.20 999.20 1100.00 8.333 130.000 1041.38 1098.38 1200.00 10.333 130.000 1140.05 1197.05 1300.00 12.833 130.000 1238.00 1295.00 1400.00 15.333 130.000 1334.99 1391.99 1500.00 15.333 130.000 1431.43 1488.43 1600.00 15.333 130.000 1527.87 1584.87 1700.00 15.333 130.000 1624.31 1681.31 1800.00 15.333 130.000 1720.75 1777.75 1882.17 15.333 130.000 1800.00 1857.00 1900.00 15.333 130.000 1817.19 1874.19 2000.00 15.333 130.000 1913.63 1970.63 2100.00 15.333 130.000 2010.07 2067.07 2134.14 15.393 130.000 2043.00 2100.00 2200.00 17.131 120.104 2106.24 2163.24 2300.00 20.562 108.782 2200.90 2257.90 2400.00 24.518 100.771 2293.26 2350.26 2411.61 25.000 100.000 2303.80 2360.80 Proposal Report for MPE-21 (98-2) WP5 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/~OOft) Vertical Section (ft) 0.00 N 0.00 E 6016227.23 N 569351.08 E 0.00 0.00 N 0.00 E 6016227.23 N 569351.08 E 0.000 0.00 0.00 N 0.00 E 6016227.23 N 569351.08 E 0.000 0.00 0.00 N 0.00 E 6016227.23 N 569351.08 E 0.000 0.00 0.00 N 0.00 E 6016227.23 N 569351.08 E 0.000 0.00 0.00 N 0.00 E 6016227.23 N 569351.08 E 0.000 0.00 0.28 S 0.33 E 6016226.95 N 569351.42 E 0.500 0.35 1.12 S 1.34 E 6016226.12 N 569352.43 E 0.500 1.40 2.80 S 3.34 E 6016224.46 N 569354.45 E 1.000 3.50 5.61 S 6.68 E 6016221.68 N 569357.82 E 1.000 7.00 9.81 S 11.69 E 6016217.53 N 569362.86 E 1.500 12.25 11.59 S 13.81 E 6016215.77 N 569365.00 E 1.500 14.47 15.82 S 18.85 E 6016211.59 N 569370.08 E 2.000 19.75 24.02 S 28.63 E 6016203.48 N 569379.93 E 2.000 30.00 34.45 S 41.05 E 6016193.17 N 569392.45 E 2.000 43.02 47.35 S 56.43 E 6016180.41 N 569407.95 E 2.500 59.13 62.99 S 75.07 E 6016164.94 N 569426.73 E 2.500 78.66 79.99 S 95.33 E 6016148.13 N 569447.15 E 0.000 99.89 96.99 S 115.58 E 6016131.32 N 569467.56 E 0.000 121.12 113.98 S 135.84 E 6016114.52 N 569487.98 E 0.000 142.34 130.98 S 156.10 E 6016097.71 N 569508.39 E 0.000 163.57 144.95 S 172.74 E 6016083.90 N 569525.17 E 0.000 181.01 147.98 S 176.35 E 6016080.90 N 569528.80 E 0.000 184.80 164.98 S 196.61 E 6016064.09 N 569549.22 E 0.000 206.02 181.97 S 216.87 E 6016047.28 N 569569.63 E 0.000 227.25 187.78 S 223.78 E 6016041.54 N 569576.60 E 0.000 234.50 198.24 S 238.85 E 6016031.22 N 569591.76 E 5.000 250.15 211.29 S 268.24 E 6016018.44 N 569621.27 E 5.000 280.26 220.83 S 305.27 E 6016009.25 N 569658.39 E 5.000 317.79 221.71 S 310.05 E 6016008.42 N 569663.18 E 5.000 322.62 - Comment Alaska State Plane Zone 4 Milne Point E Pad 13 3/8" Casing KOP: Staff Dir @ 0.500°/100ft: 400.00ft MD, 400.00ft 'i-VD Start Dir @ 1.000°/100ft: 600.00ft MD, 599.99ft TVD Start Dir @ 1.500°/100ft: 800.00ft MD, 799.86ft TVD Start Dir @ 2.000°/100ft: 933.33ft MD, 932.86ft TVD Start Dir @ 2.500°/100ft: 1200.00ft MD, 1197.05ft TVD End Dir, Sail @ 15.333°: 1400,00ft MD, 1391.99ft TVD Base Permafrost Start Dir @ 5.000°/100ft: 2134.14ft MD, 2100.00fl TVD Dir Rate Decrease @ 1.000°/100ft: 2411.61ft MD, 2360.81fl TVD Continbed... 27 May, 1998 - 11:02 - I - DrillQuest Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 2500.00 24.116 100.000 2384.20 2441.20 2600.00 23.116 100.000 2475.82 2532.82 2700.00 22.116 100.000 2568.13 2625.13 2800.00 21.116 100.000 2661.10 2718.10 2900.00 20.116 100.000 2754.69 2811.69 3000.00 19.116 100.000 2848.89 2905.89 3100.00 18.116 100.000 2943.65 3000.65 3111.61 18.000 100.000 2954.69 3011.69 3200.00 22.220 96.156 3037.68 3094.68 3300.00 27.067 .93.205 3128.55 3185.55 3400.00 31.959 91.096 3215.55 3272.55 3500.00 36.877 89.498 3298.02 3355.02 3600.00 41.812 88.229 3375.33 3432.33 3700.00 46.759 87.184 3446.90 3503.90 3800.00 51.713 86.296 3512.17 3569.17 3900.00 56.674 85.522 3570.66 3627.66 3915.10 57.423 85.413 3578.87 3635.87 4000.00 57.423 85.413 3624.58 3681.58 4100.00 57.423 85.413 3678.43 3735.43 4200.00 57.423 85.413 3732.27 3789.27 4300.00 57.423 85.413 3786.11 3843.11 4400.00 57.423 85.413 3839.95 3896.95 4500.00 57.423 85.413 3893.80 3950.80 4600.00 57.423 85.413 3947.64 4004.64 4700.00 57~-4~2.3 85.413 4001.48 4058.48 4779.10 57.423 85.413 4044.07 4101.07 4800.00 57.009 85.483 4055.39 4112.39 4900.00 55.030 85.826 4111.28 4168.28 5000.00 53.051 86.187 4170.00 4227.00 5100.00 51.074 86.566 4231.47 4288.47 Proposal Report for MPE-21 (98-2) WP5 .~ 228.08 S 346.23 E 235.04 S 385.68 E 241.72 S 423.55 E 248.12 S 459.83 E 254.23 S 494.50 E 260.06 S 527.56 E 265.60 S 559.00 E 266.23 S 562.54E 270.39 S 592.63 E 273.69 S 634.17 E 275.47S 683.38 E 275.72 S 739.88 E 274.42 S 803.24 E 271.60 S 872.98 E 267.27 S 948.57 E 261.47 S 1029.44 E 260.47 S 1042.07 E 254.75 S 1113.39 E 248.01 S 1197.38 E 241.27 S 1281.38 E 234.53 S 1365.38 E 227.79 S 1449.37 E 221.05 S 1533.37 E 214.31S 1617.37 E 207.57'S 1701.37 E 202.24 S 1767.80 E 200.85 S 1785.32 E 194.56 S 1868.00 E 188.92 S 1948.75 E 183.93 S 2027.45 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 6016002.38 N 569699.42 E 1.000 359.11 6015995.79 N 569738.93 E 1.000 398.90 6015989.46 N 569776.86 E 1.000 437.10 6015983.41 N 569813.20 E 1.000 473.70 6015977.61 N 569847.93 E 1.000 508.67 6015972.09 N 569881.04 E i.000 542.02 6015966.84 N 569912.53 E 1.000 573.73 6015966.25 N 569916.08 E 1.000 577.30 6015962.36 N 569946.20 E 5.000 607.58 6015959.45 N 569987.77E 5.000 649.24 6015958.13 N 570036.99 E 5.000 698.47 6015958.41 N 570093.49 E 5.000 754.89 6015960.29 N 570156.84 E 5.000 818.06 6015963.77 N 570226.55 E 5.000 887.52 6015968.80 N 570302.10 E 5.000 962.72 6015975.35 N 570382.91 E 5.000 1043.10 6015976.47 N 570395.53 E 5.000 1055.65 6015982.86 N 570466.79 E 0.000 1126.50 6015990.38 N 570550.72 E 0.000 1209.95 6015997.90 N 570634.65 E 0.000 1293.40 6016005.42 N 570718.58 E 0.000 1376.86 6016012.94 N 570802.51 E 0.000 1460.31 6016020.46 N 570886.44 E 0.000 1543~6 6016027.98 N 570970.37 E 0.000 1627.21 6016035.50 N 571054.30 E 0.000 1710.66 6016041.45 N 571120.69 E 0.000 1776.67 6016043.01 N 571138.20 E 2.000 1794.08 6016050.06 N 571220.81 E 2.000 1876.24 6016056.46 N 571301.50 E 2.000 1956.51 6016062.18 N 571380.16 E 2.000 2034.78 Alaska State Plane Zone 4 Milne Point E Pad Comment Dir Rate Increase @ 5.000°/100ft: 3111..61ft MD, 3011.69ft TVD End Dir, Sail @ 57.423°: 3915.10ft MD, 3635.87ft TVD Dir Rate Decrease @ 2.000°/100ft: 4779.10ft MD, 4101.07ft TVD Contin'ued... 27 May, 1998 - 11:02 - 2 - J~rillQuest Sperry-Sun Drilling Services Proposal Report for MPE-21 (98-2) WP5 Milne Point Unit Alaska State Plane Zone 4 Milne Point E Pad Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (.) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (ft) (°/100fi) (ft) Comment 5154.32 50.000 86.782 4266.00 4323.00 181.50 S 2069.32 E 5200.00 50.000 86.782 4295.36 4352.36 179.54 S 2104.25 E 5300.00 50.000 86.782 4359.64 4416.64 175.23 S 2180.74 E 5400.00 50.000 86.782 4423.92 4480.92 170.93 S 2257.22 E 5500.00 50.000 86.782 4488.20 4545.20 166.63 S 2333.71 E 5521.48 50.000 86.782 4502.00 4559.00 165.71 S 2350.13 E 5600.00 50.000 86.782 4552.47 4609.47 162.33 S 2410.19 E 5700.00 50.000 86.782 4616.75 4673.75 158.03 S 2486.67 E 5800.00 50.000 86.782 4681.03 4738.03 153.73 $ 2563.16 E 5821.48 50.000 86.782 4694.84 4751.84 152.81 S 2579.58 E 6016065.00 N 571422.00 E 2.000 2076.43 6016067.29 N 571456.91 E 0.000 2111.19 6016072.30 N 571533.35 E 0.000 2187.28 6016077.31 N 571609.80 E 0.000 2263.38 6016082.33 N 571686.24 E 0.000 2339.48 · 6016083.40 N 571702.65 E 0.000 2355.82 6016087.34 N 571762.68 E 0.000 2415.57 6016092.35 N 571839.12 E 0.000 2491.67 6016097.36 N 571915.56 E 0.000 2567.76 6016098.44 N 571931.98 E 0.000 2584.11 End Dir, Sail @ 50.000°: 5154.32ft MD, 4323.00ff TVD Top N-A Tai'get: MPE 21 T1,200.00 Radius., Geological Base Schrader Bluff Total Depth: 5821.48ft MD, 4751.84ft TVD 5 1/2" Casing All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 93.390° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5821.48ft., The Bottom Hole Displacement is 2584.1 1ft., in the Direction of 93.390° (True). 27 May, 1998 - 11:02 - 3 - DrillQuest · WELL PERMIT CHECKLIST FIELD & POOL ___~C .,~.~_/¢___(:¢ O INITOLASS /0~ .,,/ - ¢ ,, '// WELL NAME /~A~ "'2_ / GEOLAREA PROGRAM: exp [] dev'~'redrll [] serv [] wellbore seg II ann. disposal para req Il UNIT# ,/'Y32 ~' ON/OFF SHORE ~',,~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4 Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. cMr vol adequate to tie-in long string to surf csg ........ 18. CMr will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y~ N 22. Adequate wellbore separation proposed ............. N 23. If diveder required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to ~A*'cx~O psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y N GEOLOGY 30. 31. 32. 33. 34. Permit can be issued w/o hydrogen sulfide measures ..... Y N ,// Data presented on potential overpressure zones ....... ~__~,~ Seismic analysis of shallow gas zones. ' ~ Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports ....... / ¥ N [exploratory only] ~,N-'~JL~'F~'DI---~'P---~§~,[. ":~i With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; ........................ (D) will not damage producing formation or impair recovery from a pool; and ............................ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular' COMMISSION: RP~.~---/~ BEW ~:L P_j-/~.{~ WM DWJ ~ J D H(,........~-, RNC co Comments/Instructions' M:cheldist u;v 05129198 · WELL PERMIT CHECKLIST COMPANY ~:> )~-~. WELL NAME ~'V~ ~'~ ,~: _ ,,~ I PROGRAM: exp [] dev~ redrll [] serv [] wellbore seg [:] ann. disposal para req [I FIELD & POOL INIT CLASS ,~L,' I - 0,'1 GEOL AREA UNIT# 1 ! "~ 2.<;~ ON/OFF SHORE ADMINISTRATION R DATE -- 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ..~O"~ .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide ~.. 31. Data presented on potential overpre~,s..s~,-~nes ....... 32. Seismic analysis of sha~ones ............ 33. Seabed conditio~ 0'f off-shore) ............. 34. C~y progress reports ....... · ploratory only] ANNULA~ DISPOSAL APPR DATE Y N Y N Y N Y N Y N 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone;..~-¢ ..... Y N (B) will not contaminate freshwater; or cause.,drilling waste... Y N to surface; (C) will not impair mechanical integri. J.y,,~f the well used for disposal; Y N (D) will not damage producing fo~tion or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UIC/Ar~l~ar JDH /' ~ COMMISSION: DWJ CO (~ Comments/Instructions: M:chet~list rev 05~29~98 dlf:C:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUFiBERGER ....... ,Naska OJi & Ge~ C, ons. C, ommissior~ OCT 29 1998 A~ch~a~e COMPANY NAME : BP EXPLORATION WELL NAME : MPE-21 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292289400 REFERENCE NO : 98548 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/10/28 ORIGIN : FLIC REEL NAME : 98548 CONTINUATION # : PREVIOUS REEL : COM~ENT : BP EXPLORATION, MPE-21, MILNE POINT, API #50-029-22894-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/28 ORIGIN : FLIC TAPE NAME : 98548 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MPE-21, MILNE POINT, API #50-029-22894-00 TAPE HEADER MILNE POINT OPEN HOLE WIRELINELOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN1 98548 D KIRKBY PYRON SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPE-21 500292289400 BP EXPLORATION SCHLU~iBERGER WELL SERVICES 28-0CT-98 RUN 2 RUN 3 25 13N iOE 3806 1887 55.90 34.00 23.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7. 875 13. 375 150.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED OPEN HOLE FOUR ARM CALIPER BGT DATA AQUIRED ON BP EXPLORATION'S MPE-21 WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE BGT $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 5998.0 150.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: THIS FILE CONTAINS THE EDITED OPEN HOLE DATA. THE CURVES HAVE BEEN CLIPPED OF INVALID COUNTS AT FIRST READING ANDATLASTREADING. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... BGT RUN NO. PASS NO. MERGE TOP ~ERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: 3 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR BGT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 C13 BGT IN O0 000 O0 0 1 1 1 4 68 0000000000 C24 BGT IN O0 000 O0 0 1 1 1 4 68 0000000000 TENS BGT LB O0 000 O0 0 1 1 1 4 68 0000000000 TEND BGT LB O0 000 O0 0 1 1 1 4 68 0000000000 DEV BGT DEG O0 000 O0 0 1 1 1 4 68 0000000000 AZ BGT DEG O0 000 O0 0 1 1 1 4 68 0000000000 RB1 BGT DEG O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 5998.000 GR.BGT -999.250 Cl3.BGT -999.250 C24.BGT -999.250 TENS.BGT 2010.000 TEND.BGT 12.533 DEV. BGT 47.775 AZ.BGT 98.577 RB1.BGT 135.193 DEPT. 150.000 GR.BGT TENS.BGT 1038.000 TEND.BGT RB1.BGT 58.497 18.599 Cl3.BGT -999.250 C24.BGT -999.250 735.978 DEV. BGT 0.937 AZ.BGT 263.632 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NIIMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~zARY VENDOR TOOL CODE START DEPTH STOP DEPTH 6000.0 150.0 BGT $ LOG HEADER DATA DATE LOGGED: 29-AUG-98 SOFTWARE VERSION: 8Cl-205 TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: 1329 29-AUG-98 TD DRILLER (FT) : 5990.0 TD LOGGER (FT) : 5990.0 TOP LOG INTERVAL (FT) : 150.0 BOTTOM LOG INTERVAL (FT) : 5990.0 LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAi~4A RAY BGT FOUR ARM CALIPER TOOL NTJM~ER SGC- SA MEST- C LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED T~4PERATURE (DEGF) : RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 7.875 150.0 150.0 POL Yf4~R 9.30 64.0 8.9 7.1 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: PRIMARY DEPTH CONTROL USED MAGNETIC MARKS USED AND UP/DOWN LOG OVERLAY 10 FT OF STRETCH ADDED PAD PRESSURE RUN AT CAREFULLY ATTEMPTED TO LOG INTO CASING WITH CALIPER OPEN. CALIPER OPENED TO 21" JUST BELOW SHOE AND TENSION INCREASED CALIPER WAS CLOSED AND LOG STOPPPED IN ORDER TO SMOOTHLY GET THROUGH CASING. ELEVATIONS TAKEN FROM SPERRY-SUN'S MWD HEADER RIG: NABORS 27E THIS FILE CONATAINS THE RAW OPEN HOLE DATA AQUIRED AT O. 5 ' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NAME SERVUNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 TENS BGT LB O0 000 O0 0 2 1 1 4 68 0000000000 DEVI BGT DEG O0 000 O0 0 2 1 1 4 68 0000000000 RB BGT DEG O0 000 O0 0 2 1 1 4 68 0000000000 AZIM BGT DEG O0 000 O0 0 2 1 1 4 68 0000000000 HTENBGT LB O0 000 O0 0 2 1 1 4 68 0000000000 GR BGT GAPI O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 6009.000 TENS.BGT 1051.000 DEVI.BGT 47.778 AZIM. BGT 98.577 HTEN. BGT 12.533 GR.BGT 116.096 RB. BGT 135.163 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUO?4BER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN AFJMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1250 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 6000.0 150.0 BGT $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY BGT FOUR ARM CALIPER 29-AUG-98 8Cl -205 1329 29-AUG-98 5990.0 5990.0 150.0 5990.0 TOOL NI]M~ER SGC- SA MEST- C LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 7.875 150.0 150.0 POL Y~IER 9.30 64.0 8.9 7.1 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: PRIMARY DEPTH CONTROL USED MAGNETIC MARKS USED AND UP/DOWN LOG OVERLAY 10 FT OF STRETCH ADDED PAD PRESSURE RUN AT 25~ CAREFULLY ATTEMPTED TO LOG INTO CASING WITH CALIPER OPEN. CALIPER OPENED TO 21" JUST BELOW SHOE AND TENSION INCREASED CALIPER WAS CLOSED AND LOG STOPPPED IN ORDER TO SMOOTHLY GET THROUGH CASING. ELEVATIONS TAKEN FROM SPERRY-SUN'S MWD HEADER RIG: NABORS 27E THIS FILE CONATAINS THE RAW OPEN HOLE DATA AQUIRED AT O. 125 ' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.125 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT O0 000 O0 0 3 1 I 4 68 0000000000 Cl BGT IN O0 000 O0 0 3 1 1 4 68 0000000000 C2 BGT IN O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 6009.000 Cl.BGT 5.156 C2.BGT 5.034 DEPT. 150.125 Cl.BGT 21.750 C2.BGT 21.332 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-0CT-1998 11:36 PAGE: 10 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/10/28 ORIGIN : FLIC TAPE NAME : 98548 CONTINUATION # : 1 PREVIOUS TAPE : COMPIENT · BP EXPLORATION, MPE-21, MILNE POINT, API #50-029-22894-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/28 ORIGIN : FLIC REEL NAME : 98548 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MPE-21, MILNE POINT, API #50-029-22894-00 Sperry-Sun Drilling Services LIS Scan Utility Wed Nov 25 21:38:55 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/11/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 2 AK-MW-80343 J. FOLEY J. PYRON MPE-21 500292289400 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 25-NOV-98 25 13N 10E 3688 1794 DEC 1998 A!~a Oil & Ga~ Gon~, ~' FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 57.00 23.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.880 13.375 151.0 5.500 5803.0 5990.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD DEPTHS ARE CORRECTED TO THE GAMMA RAY FROM BOREHOLE GEOMETRY TOOL WHICH WAS RUN ON AUGUST 29, 1998. 3. MWD RUN 1 IS DIRECTIONAJ~ ONLY ~ NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 5. MWD RUNS 1 AND 2 REPRESENT MPE-21 WITH API#: 50-029-22894-00. THIS WELL REACHED A TOTAL DEPTH OF 5990'MD, 4784'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED P~LASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PH3~SE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME RESISTIVITY SENSOR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE N-UMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 4092 5 FET 4098 5 RPX 4098 5 RPD 4099 0 RPM 4099 0 RPS 4099 0 ROP 4136 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 4092.5 4111.0 4183.0 4231 0 4242 5 4347 0 4373 0 4375 0 4383 0 4460 0 4474 5 4485 5 4501 0 4509 5 4513 0 4520.5 4550.0 4554.5 4559.5 4648.5 4662.0 4674.0 4685 0 718 0 948 0 958 0 969 0 987 5 035 0 039 0 049 0 056 5 082 5 103 0 113 0 132 0 139 5 GR 4095.0 4113 5 4187 0 4234 0 4245 5 4349 0 4378 0 4379 5 4387 0 4463 0 4477 0 4488 0 4503 5 4513 0 4515 5 4523 5 4552.5 4558.0 4562.5 4651.0 4663.0 4675.5 4685.5 4718.5 4949.0 4959.5 4970.0 4988.0 5037.0 5040.0 5049.5 5055.0 5083.0 5105.0 5115.0 5133.0 5141.0 STOP DEPTH 5945.5 5952.5 5952.5 5952.5 5952.5 5952.5 5989.5 EQUIVALENT UNSHIFTED DEPTH 5164 5 5231 5249 5280 5313 5329 5330 5337 5341 5358 5363 5369 5398 5618 5634 5652 5663 5776 5779 5860 5869.5 5912.5 5989.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 5165 0 5232 5 5250 0 5282 0 5315 0 5331 5 5333 0 5340 0 5343.0 5361 0 5363 5 5370 5 5401 0 5620 0 5635 5 5654 0 5664 5 5777.5 5781.0 5861.0 5869.5 5913.0 5990.0 BIT RUN NO MERGE TOP MERGE BASE 2 4144.0 5990.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 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 Min Max Mean Nsam DEPT 4092.5 5989.5 5041 3795 ROP 12.5955 631.63 191.314 3708 GR 11.9332 139.136 69.9575 3707 RPX 1.145 33.0972 5.01946 3709 RPS 1.1586 49.7973 6.01768 3708 RPM 1.137 49.5495 5.97251 3708 RPD 1.1675 45.745 6.05038 3708 FET 0.0959 13.3998 0.66233 3709 First Reading 4092.5 4136 4092.5 4098.5 4099 4099 4099 4098.5 Last Reading 5989.5 5989.5 5945.5 5952.5 5952.5 5952.5 5952.5 5952.5 First Reading For Entire File .......... 4092.5 Last Reading For Entire File ........... 5989.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/25 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 ....... 98/11/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4095.0 FET 4101.0 RPX 4101.0 STOP DEPTH 5946.0 5953.0 5953.0 RPD 4101.5 RPM 4101.5 RPS 4101.5 ROP 4139.0 $ 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 AlqGLE: MAXIMUM ANGLE: 5953.0 5953.0 5953.0 5990.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AiYD 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) MLrD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERAT~E: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAATDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 28-AUG-98 ISC 5.07 DEPII(2.22A) , SP4 (5.04) MEMORY 5990.0 4144.0 5990.0 ~48.1 57.7 TOOL NUMBER P1043GR4 P1043GR4 7.880 7.9 POLYMER 9.40 68.0 8.5 12000 7.1 .660 .479 .420 .640 37.5 .6 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ............ Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 2 FT/H 4 1 GR MWD 2 API 4 1 RPX MWD 2 OHMM 4 1 RPS MWD 2 OHMM 4 1 RPM MWD 2 OHMM 4 1 RPD MWD 2 OHMM 4 1 FET MWD 2 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 4095 5990 5042.5 ROP 12.5955 631.63 191.363 GR 11.9332 139.136 69.8674 RPX 1.145 33.0972 5.01728 RPS 1.1586 49.7973 6.01658 RPM 1.137 49.5495 5.97067 RPD 1.1675 45.745 6.04975 FET 0.0959 13.3998 0.670332 First Last Nsam Reading Reading 3791 4095 5990 3703 4139 5990 3703 4095 5946 3705 4101 5953 3704 4101.5 5953 3704 4101.5 5953 3704 4101.5 5953 3705 4101 5953 First Reading For Entire File .......... 4095 Last Reading For Entire File ........... 5990 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/11/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
