The URL can be used to link to this page

Home My WebLink About195-1911a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 16.70' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" H-40 112' 7" L-80 7611' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 250 sx Class 'G'8-1/2" TUBING RECORD 12015' - 14135'3-1/2" 9.3# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 24" 250 sx Arctic Set I (Approx.) 4652' 12-1/4" 1396 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 12/9/1995 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 6041320 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 10/20/2020 3687' FSL, 5070' FEL, Sec. 08, T13N, R10E, UM, AK 2867' FSL, 1071' FEL, Sec. 32, T14N, R10E, UM, AK 195-191 / 320-366 Milne Point Unit, Kuparuk River Pool 47.9' 10175' / 5588' 12/22/1995 Gyro, MWD, LWD, GR / RES, GR / CDN / CDR, GR / CCL Surface HOLE SIZE AMOUNT PULLED 50-029-22629-00-00 MPU L-21 544806 6031876 2548' FSL, 1196' FEL, Sec. 32, T14N, R10E, UM, AK 548591 548713 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 6041640 BOTTOM TOP Surface DEPTH SET (MD) 13368' / 6995' PACKER SET (MD/TVD) 7249' CASING WT. PER FT.GRADE CEMENTING RECORD 91.1# 112' Gas-Oil Ratio:Choke Size: See Attached Per 20 AAC 25.283 (i)(2) attach electronic information 14135' Surface Water-Bbl: PRODUCTION TEST N/A Date of Test: Flow Tubing Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: ADL 025509 & 355017 88-002 1800' (Approx.) N/AN/A None 14155' / 7628' Surface26# 40#9-5/8" SurfaceL-80 Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 11:03 am, Nov 19, 2020 Abandonment Date 10/20/2020 HEW RBDMS HEW 11/25/2020 xGSFD 11/30/2020 DSR-11/25/2020MGR24FEB2021SFD 11/30/2020 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 13558' 7140' 13558' 7140' 13567' 7147' 13668' 7226' Kuparuk A 13668' 7226' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31:Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separ ately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Kuparuk A Summary of Pre-Rig Work, Drilling Report, Wellbore Schematic Signature w/Date: 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. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Kuparuk C Kuparuk B This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inc lination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered):FORMATION TESTS Permafrost - Top o N Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.11.18 11:53:04 -09'00' Monty M Myers _____________________________________________________________________________________ Revised By: JNL 11/10/2020 SCHEMATIC Milne Point Unit Well: MPU L-21 Last Completed: 10/20/2020 PTD: 195-191 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112’ 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,249’ 7" Intermediate 26 / L-80 / BTC 6.276 Surface 14,135’ TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / NSCT 2.99 12,015’ 13,404’ JEWELRY DETAIL No Depth Item 1 13,336’ XO 4.5” x 3.5” NSCT 2 13,368’ 7” Baker SAB-# Packer 3 13,372’ XO 4.5” x 3.5” NSCT 4 13,392’ 3.5” XN Nipple w/ RHC Plug – MIN ID = 2.750” 5 13,403’ WLEG – Bottom @ 13,404’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C1 13,558’ 13,567’ 7,139’ 7,146’ 9’ 11/23/2018 Squeezed Kuparuk B6 13,567’ 13,636’ 7,146’ 7,200’ 69’ 11/23/2018 Squeezed Kuparuk A3,2 &1 13,678 13,768’ 7,233’ 7,305’ 90’ 4/19/1996 Squeezed Perforation Summary: Ref Log – SBT/GR/ CCL – 4/18/1996 4.5 SPF 32 gm, Alpha Jet Charges (EHD=0.44” TTP=32.1” @ 72 deg. Phasing (Kuparuk A3/A2/A1) 6 SPF 11 gm, Geo Razors (EHD=0.31” TTP=32” @ 60 deg. Phasing (Kuparuk C1/B6) OPEN HOLE / CEMENT DETAIL 24" 250 sx of Arcticset I 12-1/4" 1,396 sx PF ‘E’, 250 sx Class ‘G’, 150 sx PF ‘E’ 8-1/2” 250 sx Class ‘G’ WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 70 to 72 deg. f/ ~4,650’ to ~11,800’ MD Hole Angle through perforations = 37 deg. TREE & WELLHEAD Tree 3-1/8” – 5M AlloyTree ‘FL’ Wellhead FMC 11” x 11” 5M, Gen 5 w/ 11” x 3.5” FMC Tubing Hanger, w/ NSCT Threads Top and bottom and 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22629-00-00 Drilled and Cased by Nabors 22E - 12/26/1995 Completed by Nabors 4ES – 5/16/1996 Abandoned: 10/20/2020 TD =14,155’ (MD) / TD = 7,628’(TVD) 20” Orig.DF Elev.: 46.2’/ GL Elev.: 16.7’ Nabors 22E 7” Top of Cement at 12,879’ (9/14/20) 4 5 Whipstock set at 10175’ 9-5/8” 1 2 Min ID= 2.75” @ 13,392’ Tubing Punc h PBTD =10,175’ (MD) /PBTD = 5,588’(TVD) 3 Cement Retainer 13341’ Howco ES Cementer @ 2,132’ 21’ and 20’ marker joints tag from 13,439’ to 13,479’ wlm. RA tag @ 13,439’ wlm. Tubing cut at 12,015’ KUP C1 KUP B6 KUP A3/A2/A1 STIMULATION DETAIL 8/8/1996 – High pressure breakdown – Four stages at 200bbls of 20ppt linear gel each. WELL NAME: MPU L-21 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 13341' Set Cement Retainer 13331' 20 Bbls Class 'G' 13325' - 13330' Tubing Punch 12879' 15 Bbls Class 'G' 12015' Cut & Pull Tubing 10175' Set Whipstock Well Name Rig API Number Well Permit Number Start Date End Date MP L-21 CTU 50-029-22629-00-00 195-191 9/10/2020 10/20/2020 9/11/2020 - Friday CTU #6 2.0" CT .156 wall - MU 2.80" DJN BHA for drift/tag and RIH. Tag XN and correct depth to 13,392', PUH 100', flag pipe for CICR run and POOH. MU Cast Iron Cment Retainer BHA and RIH to flag, correct depth to mid element and set at 13,341. Bleed off WHP to check float in retainer and float is holding, set down 3k with no movement, PU, PU is clean, POOH pumping 1.5 annular volumes to ensure clean any gas is swept from the well. Line up down the backside and trickle diesel freeze protect in the well. OOH, LD setting tools, MU CMT Stinger for morning run, install night cap and test to secure well. Continue OPS on 9/12/2020. Hilcorp Alaska, LLC Weekly Operations Summary 9/10/2020 - Thursday CTU #6 2.0" CT .156 wall - MIRU and Test BOPE. CTU #6 2.0" CT .156 wall - PU Injector with CMT Stinger and RIH. Tie in into EOP flag at 13,326', correct depth -36.15' and RIH. Online at 0.5 bpm down the backside, pressure increase at 13,340.3' shut down pump, we are on depth with the retainer. Line up to PT the CT backside to verify seals are holding. Pressure up to 2,000psi WHP, seals holding. Online down the coil to check injectivity. 1bpm = 2,050psi, 1.5 bpm = 2505psi. Discuss with OE and we are good to treat at 2,500psi and squeeze up to 3,000psi if needed. Pumped 20 bbls of 15.8 Class G CMT pumping 19.5 bbls below retainer, PU out of retaner and lay in 0.5 bbl on top. Clean out to top of retainer and POOH. MU TBG Punch, RIH, tag CICR (13,335) 6' high (float leaked), correct depth to bottom shot (-3.18' = 13,331.82), PU 2' (13,329.82'), fire punch, good indication that tubing punch fired, POOH. OOH, all shots fired, install night cap and PT to 250 low and 3,500 high to secure the well. Well secured, continue OPS on 9/13/2020. 9/12/2020 - Saturday MU Nozzle BHA for State Witnessed TOC Tag and PT on IA & OA. Tag TOC at 12,879' 27' or 0.23 bbls higher than plan. Perform CMIT-TBG & IA and passed. POOH for Jet cutter. Discuss Jet cut depth with OE, 12,015', confirmed depth. MU Jet Cutter BHA and RIH. RIH to flag, correct depth to centerline of cutter, PUH to 12,015'. Drop ball to fire cutter holding 500 psi to see pressure spike on IA when cutter fires. Good indication tubing is cut with pressure spike, POOH. At surface, LD BHA, ND BOPE and RDMO CTU 6 to Deadhorse. 9/13/2020 - Sunday CTU #6 2.0" CT .156 wall - PU Injector with CMT BHA w/ BDN and RIH. Swap IA to clean 2% KCl while RIH. Correct depth to EOP Flag. Tag TOC at 13,331'. PU clear nozzle, pump 93 bbls of diesel into the IA, (71 for FP, 12 for CMT and 10 to adjust choke). Mix and pump 15 bbls of 15.8 Class G Cement. Pump 11.2 bbls of CMT in to the IA and lay in 3.8 bbls in the tubing, CMT out at 12,909' TOC at 12,906'. At safety increase pump rate to 1.5 bpm to clear coil, get parameters to maintain while POOH. POOH at 0.5 bpm holding 275psi on WH and 548psi on the IA. Online with diesel down the backside at 6,565'. At surface WHP/IAP = 279/270 9 psi difference, trap pressures close swab and SSV. LD Nozzle BHA and stack down to change packoffs and check chains. Install Night Cap and PT to secure well. Continue OPS on 9/14/2020. 9/14/2020 - Monday Activity Date Ops Summary 10/15/2020 Notified AOGCC of upcoming BOP Test @ 05:54 on 10/15/2020, Move Rockwasher and finish prep rig for move. PJSM, Skid rig floor into moving position, move Rig off L-63 and park Rig at NW end of pad. Remove BOP Ram blocks for inspection & re-certification. Install new 2-7/8”x5” VBR, Blind rams & 2nd set of 2-7/8”x5” VBR’s. Remove two segment links from #1 drag chain. SimOps: HES slick line work on L-63. Move rig matts and clear area behind L-21 Well head. Start pad prep around Well. 10/16/2020 Wait on slickline and Tie-in work on L-63. Dress rig floor drillpipe handling equipment for 4" DP. Prep pad area around L-21 & set matting boards for Rig footprint. Spot tree behind L-21 Wellhead and perform general housekeeping around rig.,PJSM, Move Rig from staging area and spot over L-21. Level and shim rig then skid Rig floor into drilling position.,Work on rig acceptance checklist, spot rockwasher & fuel trailer. Spot flow back tank. Wells support crew rig up 2" hardline from Rig to tank. Rig accepted at 03:00. Finish hardline from Rig to flow back tank. Rig up in cellar to take returns from IA to tank. Check pressure on IA and Tree - 0 psi.,PJSM, Mobilize Cameron S10 lubricator to rig floor, install on Tree and test. Pull BPV and R/D lubricator. SimOps: Put steam on line from Cellar to flow back tank. 10/17/2020 Rig up lines to pump down tubing. Cover and secure cellar box with pit liner. Rig up tank farm to transfer fluid to Rig,PJSM to ciculate out freeze protect. Test high pressure lines 250 psi/3000 psi. Good. Pump 280 bbls 125° KCl brine with DeepClean added, 6 BPM – 2150 psi, 30 bbls Hi-Vis spacer 4 BPM – 810 psi and chase with 500 bbls 9.0 ppg brine 6 BPM – 2400 psi. Clean brine returns.,Monitor well – Static -. Blow down and rig down lines. Wellhead Rep set BPV.,N/D Tree. Test run crossover to tubing hanger. 7 turns to seat – Good. Stand Trees up out of way in cellar and secure,N/U BOPE stack. Weld additional 4’ section to trip nipple and install.,Flood stack and check for leaks. Run 3.5” test joint w/ donut spaced out at Annular. Flood choke and purge air from system. Attempt 4k shell test. Test hose appears to have blockage – replace hose. Purge air and shell test BOPE 250 psi/ 4000 psi, 5 min each.,Test BOP equipment as per AOGCC to 250 PSI low / 4000 PSI high. Tests held for 5 min each & charted. AOGCC inspector Robert Noble on-site to witness test. All tests performed with fresh water against a BPV test dart. Perform accumulator draw down. Test gas alarms and PVT. Monitor IA in Cellar.,1. Annular on 3.5" test joint, choke valves 1, 12, 13, 14, Kill Demco & 4” FOSV. 2. Upper 2.875"x5" VBR on 3.5” test joint, choke valves 9, 11, HCR kill & 4" dart valve. 3. Choke valves 5, 8, 10, Manual Kill & 3.5” FOSV. 4. Choke valve 4, 6, 7, & 3.5” dart valve. 5. Choke valve 2. 6. HCR choke. 7. Lower 2.875"x5" VBR on 3.5” test joint. 8. Upper 2.875"x5" VBR on 4.5” test joint, manual choke & lower IBOP,9. Lower 2.875"x5" VBR on 4.5” test joint & upper IBOP. 10. Blind Rams & choke valve 3 - Failed. 11. Manual choke A. 12. Manual choke B. Perform Accumulator test: 3080 psi sys pressure, 1675 PSI after closure, 200 PSI recovery in 38 sec, full recovery in 191 sec, 6 N2 bottle avg = 2142 PSI.,Trouble shoot and start repairs on choke valve 3.,H2O from L-Pad: 475 bbls Daily/ 475 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 180 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 680 bbls Daily / 680 bbls Total. 10/18/2020 Rebuild choke valve #3. Re test to 250/4000 psi. Good. R/D Testing equipment.,Suck out stack with rig vac. Pull TWC. Well static.,M/U 4'' Landing joint with NWCT XO. M/U to hanger. 7.5 Turns. M/U TD. BOLD, Pull hanger off seat at 92K up, 95K free wt. with tubing. Pull hanger to rig floor & L/D same. R/D landing joint.,R/U 3.5" Tongs and change handling equipment to 3.5". POOH f/ 11985' t/ surface. Total of 381 full joints and a 9' cut joint of 3-1/2" 9.3#, L-80, NSCT tubing pulled. Total of 12.013.76', 3-1/2" tubing pulled out of hole.,Rig down casing handling equipment, clear and clean rig floor. Set wear ring - 7 1/8" ID,Rig up test equipment. Purge air from system and test 7" casing against blind rams t/ 2500 psi for 30 minutes, charted. Good test. Rig down test equipment and blow down lines.,Mobilize 7" casing clean out assem bly components to Rig floor.,Hold PJSM on making up BHA. Make up 7" casing clean out assembly. 6-1/8" Hughes STX-1 Milltooth bit, WIS 7" casing scraper, 2x WIS 5" boot baskets, bit sub w/ ported float, WIS 4-3/4" oil jar, 9x 4-3/4" drill collars & 21x 4" HWDP t/ 959',RIH with 7" casing clean out assembly, picking up 4" drillpipe singles f/ 959' t/ 2695'. 4" drillpipe drifted to 2.35",H2O from L-Pad: 90 bbls Daily/ 565 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 0 bbls Daily / 680 bbls Total. 10/19/2020 Continue RIH with 7” scraper assembly, picking up 4” drillpipe singles f/ 2695’ t/ 10247’. Pipe drifted to 2.573”. 140k PU / 100k SO,Displace Wellbore f/ 9.0 ppg brine to 9.0 ppg LSND. 340 GPM – 1400 psi. Rotate and reciprocate string f/ 10247’ t/ 10148’ the duration of displacement. 20 RPM – 5k Tq,Pump dryjob, 1.5 ppg over, and blow down TopDrive.,POOH f/ 10247’ t/ 7773’ Racking drillpipe, HWDP and drill collars in Derrick. Swap to Drilling AFE @ 18:00,See MPU L-21A Drilling Report for details. H2O from L-Pad: 20 bbls Daily/ 585 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 214 bbls Daily / 894 bbls Total. 10/19/2020 POOH with 7” scraper assembly f/ 7773’ t/’ 31’ Racking drillpipe, HWDP and drill collars in Derrick. Break down scraper BHA. Empty and flush boot baskets – no debris captured in baskets. Clear and clean rig floor. SimOps: Test MPD lines 250/1300 psi. -Good. M/U Whipstock assembly. UBHO sub, float sub w/ ported float, TM collar, DM collar. Shallow pulse test MWD – good. Make up BHA, MCBPV, 1x Jt HWDP, running tool and tri-mill assembly. Scribe to MWD DM & UBHO. Mate up to WIS 7” casing hydraulic TrackMaster Whipstock. - 35k Shear bolt. RIH with 3 stds drill collars & 7 stds HWDP t/ 1024'. Continue in hole with stds 4" drillpipe t/ 3393'. 45'/min running speed. Fill pipe on the fly with fill hose and top off every 5 stands. H2O from L-Pad: 20 bbls Daily/ 585 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 214 bbls Daily / 894 bbls Total. Well Name: Field: County/State: MP L-21 Milne Point Hilcorp Energy Company Composite Report Alaska North Slope Burough, AK 50-029-22629-00-00API #: 10/20/2020 Continue trip in hole with Whipstock/Milling assembly on 4" drillpipe stands f/ 3393' t/ 10195'. 141k PU / 106k SO Establish circulation, work string 15’ while orient Whipstock to 172° right of HS. 250 GPM, 1380 psi. Cycle pumps 6x total, closing bypass valve. Pressure up to 3400 psi and set Whipstock anchor. Pressure drop down t/ 2600 psi. and falling. Engage pump @ 1 BPM – 3100 psi, getting returns. Maintain pressure with the 1 BPM & work Dn/Up 75k/160k several times. Shear Mill from slide 4th stroke dn. 33k to shear bolt. P/U & observe psi drop t/ 1700 psi- Anchor hyd line parting. Mill window f/ TOW =10175’ t/ BOW =10186’. 100 RPM, 6-7k Tq. 168 GPM, 1400 psi. 4-8k WOB. Continue drilling/milling t/ 10206', cutting 20' new hole past BOW. Dress window 3x, 60 RPM, 4k Tq. 168 GPM, 1300 psi., then work through with no rotary and again with no pumps/rotary - Clean. Total of 69.5# metal recovered at shakers and magnets. Circulate 30 bbl hi-vis sweep around and hole clean. 250 GPM, 2100 psi. 10 RPM, 3k Tq. Work string 90’. Minimal increase in cuttings with sweep to surface. Blow down TopDrive, Rig up testing equipment and lines. Close UPR &perform FIT t/ 11.7 ppg EMW with 9.0 ppg MW at 5594’ TVD. Pressure up to 786 psi, 1.1 bbls pumped, 1.1 bbls bled back. Blow down lines and rig down test equipment Lay down 2x singles of 4" drillpipe t/ 10124'. Cut & Slip 74' drilling line. Service Topdrive, draworks and iron roughneck. Re-calibrate block height. POOH with milling assembly f/ 10124' t/ 4750'. Rack stands in Derrick. Daily Loss = 0 bbls, Cumulative losses = 0 bbls. H2O from L-Pad: 90 bbls Daily/ 675 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 0 bbls Daily / 894 bbls Total. Wallace, Chris D (CED) From: Regg, James B (CED) Sent: Thursday, November 19, 2020 11:39 AM To: Jon Arend Cc: Brooks, Phoebe L (CED); Wallace, Chris D (CED) Subject: RE: re -submittal of SVS tests for MPU AIO 106.13 (MPU L-21; PTD 1951910) expired with the redrill of L -21A (PTD 2200620). Since L -21A is now online (based on the SVS tests), please provide the TIO pressures for L -21A. If the well continues to exhibit pressure communication or a leak, a new Admin Approval is required. Also, please provide the post initial injection MIT for L -21A as soon as it is completed. Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W. 71h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Sent: Thursday, November 19, 2020 11:22 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: FW: re -submittal of SVS tests for MPU Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.g_ov. From: Jon Arend <Jon.Arend@hilcorp.com> Sent: Wednesday, November 18, 2020 5:33 PM To: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Subject: re -submittal of SVS tests for MPU Hello Phoebe, Sorry for the "D" on my reports. I do have a couple questions now that I look further into this • 1 have the AA for L-21 and the A10 order no. is 106.013 (not 1013.014 which is what you had corrected B-13 to and has same communication issue) Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Friday, November 13, 2020 12:52 PM To: David Haakinson Subject: RE: MPU L-21 (PTD 195-191-), MPU L -21A (PTD 220-062) and AIO 106.013 David, Your request to bring MPU L -21A on water injection is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7tn Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: David Haakinson <dhaakinson@hilcorp.com> Sent: Friday, November 13, 2020 11:57 AM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Subject: MPU L-21 (PTD 195-191), MPU L -21A (PTD 220-062) and AIO 106.013 Chris, MPU L-21 has been sidetracked and completed as MPU L -21A in a separate fault block within the Kuparuk River Oil Pool. The L -21A wellbore was sidetracked out of the existing 7" casing and completed with a 4-1/2" liner. A new tubing and packer completion was installed and a MIT -IA to 2,500 psig passed. Hilcorp Alaska is seeking approval to bring MPU L -21A on injection and monitor the well for the next 30 days within AIO 106.013 to ensure that no anomalies exist. At that time, Hilcorp Alaska will plan to submit an approval request to rescind AIO 106.013 and return MPU L -21A to normal operating standards. Please let me know if you agree with this plan and approve to bring MPU L -021A on water injection. Regards, David Haakinson Operations Engineer I North Slope Asset Team Hilcorp Alaska, LLC Office: (907) 777-8343 1 Cell: (307) 660-4999 dhaakinsonLc hilcom.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '� p 9'2 j2�,,z, DATE: September 14, 2020 P.I. Supervisor SUBJECT: Plug Verification MPU L-21 FROM: Matt Herrera Hilcorp Alaska LLC Petroleum Inspector PTD 1951910; Sundry 320-366 Section: 8 Township: Drilling Rig: Schlbgr CTU Rig Elevation: Operator Rep: Mark Igtanloc Casing/Tubing Data: Conductor: 20" - 0. D. Shoe@ Surface: 9 5/8" 0. D. Shoe@ Intermediate: Feet 0. D. Shoe@ Production: 7" 0. D. Shoe@ Liner: 0. D. Shoe@ Tubing: 31/2" 0. D. Tail@ Plugging Data (depths are MD): 13N Range: 10E 28.7 ft Total Depth: 14,155 ft MD Suspend: 112 - Feet 7249 Feet Feet 14,135 Feet Feet 13.404 Feet Meridian: Umiat Lease No.: ADL 025509 P&A: X Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Balanced 13,341 ft MD 12,879 ft MD- 15.8 ppg - C.T. Tag OA 0 0 0 0 Test Data (CMIT TxIA): Pretest Initial 15 min 30 min Result Tubing 0 2223 2148 2114 IA 0 2222 2145 2111 - P OA 0 0 0 0 Pretest Initial 15 min 30 min Result Tubing IA OA Remarks: , Well MPU L-21 drilled by Nabors 22E in 1995 and completed by Nabors 4ES as injector for reservoir support. Lack of reservoir communication with this well has deemed it a candidate for sidetrack drill to move bottom hole location to an area where it can provide reservoir support for producers on pad. CTU set retainer and pumped 19.5 BBLs below and 3.8 BBLs cement above. Tubing punch at 13,330 ft MD; pumped 11.2 BBLs cement into IA. CTU tag cement top and CMIT performed to 2000 psi per Sundry 320-366. Attachments: NONE rev. 11-28-18 2020-0914_Plug_Verification_MPU_L-21 _mh 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,155'N/A Casing Collapse Conductor N/A Surface 3,090 Production 5,410 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: 9/1/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Ian Toomey itoomey@hilcorp.com 777-8520 7,628' 14,051' 7,539' 3,503 N/A Length Size COMMISSION USE ONLY Tubing Grade: Tubing MD (ft): 7,139 - 7,305 13,368' / 6,995' and N/A 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025509 & ADL0355017 195-191 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 C.O. 432D 50-029-22629-00-00 Hilcorp Alaska, LLC MILNE POINT, KUPARUK RIVER OIL MILNE PT UNIT L-21 PRESENT WELL CONDITION SUMMARY 9.3/ L-80 / NSCT TVD Burst 13,404 7,240 MD N/A 5,750 112' 4,652' 112' 7,249' 20" 9-5/8" 80' 7,249' 14,135' Perforation Depth MD (ft): 13558 - 13768 14,135' Perforation Depth TVD (ft): Tubing Size: 7,611'7" Authorized Signature: 9/12/2020 3-1/2" 7" Baker SAB-3 Packer and N/A Authorized Title: Operations Manager Authorized Name: Chad Helgeson ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.09.01 15:00:57 -08'00' By Samantha Carlisle at 3:07 pm, Sep 01, 2020 320-366 DSR-9/1/2020 Note: See Plug for Redrill form. X AOGCC to witness tag and pressure test (to 2000 psi) of abandonment plug. MGR02SEP20 DLB DLB 09/01/2020 10-407 Comm 9/2/2020 dts 9/2/2020 JLC 9/2/2020 RBDMS HEW 9/3/2020 Suspend for RD Well: MPU L-21 Date: 8/31/2020 Well Name:MPU L-21 API Number:50-029-22629-00-00 Current Status:SI –KUP Injector Pad:L-Pad Estimated Start Date:September 12 th, 2020 Rig:CTU Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:195-191 First Call Engineer:Ian Toomey (907) 777-8520 (O)(907) 903-3987 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O)(307) 660-4999 (M) AFE Number:Job Type:Suspend KUP Sands Most recent SBHP (7-30-19):4,232 psi @ 7,290’ TVD EMW = 11.2 ppg Maximum Expected BHP:4,232 psi @ 7,290’ TVD EMW = 11.2 ppg MPSP:3,503 psi Gas Column Gradient = 0.1 psi/ft Max Inclination 70° - 72° from 4,650’ to 11,800’ MD Max Dogleg:4.9°/100ft at 1,955’ MD Tree:Cameron 3-1/8” 5M BPV Profile:3” CIW Type H Minimum ID:2.750” at 13,392’ MD Brief Well Summary: Well L-21 was drilled by Nabors 22E in December of 1995 and completed by Nabors 4ES in May 1996 as a Kuparuk A, B & C sand injector. The well was brought on injection in June 1996 but was SI in October 1998 due to its lack of communication with producers in the area. The well remained SI until January 2019 when it was put on injection to support new drilled producer L-55 but was SI in May 2019 because it did not communicate to L-55. Producer F-116 was drilled in November 2019 and L-21 was again put on injection but did not communicate to F-116. Since this well does not seem to communicate to any of the producer in the area it has been chosen for a rotary sidetrack to move the bottom hole location to an area where is can support the producers in the area. Notes Regarding the Well & Design x 7” Casing MIT to 2,900 psi passed on 1/19/2019 x Recent water injection rates were 850 BWDP at 2,300 psi. x Last tag was at 13,799’ (31’ of rat hole) Objective: x Plug the Kuparuk sand with cement utilizing a 3-1/2” cement retainer. x Punch holes above the top packer. x Pump balanced cement plug. Tag TOC & PT the tubing & 7”casing to 2,000 psi. x Jet cut the tubing above TOC. CTU Procedure: 1. MIRU CTU with 2” coil and spot ancillary equipment. 2. Pressure test BOPE to 4,000/250 psi. a. Each subsequent test of the lubricator will be to 4,000/250 psi to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. If within the standard 7 day test BOPE test period for Milne Point, I concur. DSR 9/1/2020 Suspend for RD Well: MPU L-21 Date: 8/31/2020 3. MU cement retainer and cementing nozzle and RIH to 13,367’ MD. 4. Set the cement retainer mid joint at 13,341’ (Mid Element Set Depth). 5. Establish injection rate and pressure. 6. Mix and pump 20 bbls of 15.8 ppg class G cement with spacers. a. Volumes: top of fill to bottom of tubing = 15.2 bbls; bottom of tubing to cement retainer = 0.6 bbls; Total = 15.8 bbls 7. Pump a total 19.5 bbls of cement below the cement retainer (pump 15.8 bbls and squeeze 3.7 bbls), un-sting lay 0.5 bbls on top of the retainer, PU 20’ and circulate the coil clean. 8. POOH and lay down the cementing BHA. 9. PU, MU and RIH with tubing punch to the top of the cement retainer. 10. Punch holes in the tubing just above the cement retainer at 13,341’ MD. 11. POOH and lay down tubing punch BHA. Establish circulation down the tubing up the IA to confirm communication. 12. PU, MU and RIH with cement nozzle BHA to the top of the cement retainer. 13. Establish circulation taking returns out the IA. 14. Mix and pump 15 bbls of 15.8 ppg class G cement with spacers. 15. Lay in balanced cement plug (balance plug height ~425’). PU to safety depth ~12,500 MD, circulate the coil clean and POOH. 16. Notify the AOGCC 24 hours in advance to witness the tag and PT of the TOC. 17. WOC to reach 2,000 psi compressive strength. 18. RIH, tag the TOC (record tag depth in report) and POOH. 19. PT the tubing to 2,000 psi for 30 minutes (charted) and PT the IA to 2,000 psi for 30 minutes (charted). 20. PU, MU and RIH with a jet cutter. Cut the 3-1/2” tubing in the middle of the first full joint above the TOC. Establish circulation down the tubing up the IA to confirm the tubing is cut. POOH. 21. RDMO CTU. Post-CTU Procedure: 22. RU LRS pumping equipment and flow back tanks. 23. Freeze protect the well by pumping ~75 bbls of diesel down the tubing taking returns out the IA. Place the tubing and IA in communication allowing time for the diesel to u-tube and equalize. 24. RD LRS equipment. 25. Set 3” HP BPV. Attachments: 1. Current schematic 2. Proposed schematic 3. CTU BOP Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: WLR 4/3/2020 SCHEMATIC Milne Point Unit Well: MPU L-21 Last Completed: 5/16/1996 PTD: 195-191 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112’ 9-5/8"Surface 40 / L-80 / Btc. 8.835 Surface 7,249’ 7" Intermediate 26 / L-80 / BTC 6.276 Surface 14,135’ TUBING DETAIL 3-1/2"Tubing 9.3 / L-80 / NSCT 2.99 Surface 13,404’ JEWELRY DETAIL No Depth Item 1 13,366’ XO 4.5” x 3.5” NSCT 2 13,368’ 7” Baker SAB-# Packer 3 13,372’ XO 4.5” x 3.5” NSCT 4 13,392’ 3.5” XN Nipple w/ RHC Plug – MIN ID = 2.750” 5 13,403’WLEG –Bottom @ 13,404’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C1 13,558’ 13,567’ 7,139’ 7,146’ 9’ 11/23/2018 Open Kuparuk B6 13,567’ 13,636’ 7,146’ 7,200’ 69’ 11/23/2018 Open Kuparuk A3,2 &1 13,678 13,768’ 7,233’ 7,305’ 90’ 4/19/1996 Open Perforation Summary: Ref Log – SBT/GR/ CCL – 4/18/1996 4.5 SPF 32 gm, Alpha Jet Charges (EHD=0.44” TTP=32.1” @ 72 deg. Phasing (Kuparuk A3/A2/A1) 6 SPF 11 gm, Geo Razors (EHD=0.31” TTP=32” @ 60 deg. Phasing (Kuparuk C1/B6) OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I in 24” Hole 9-5/8" 1,396 sx PF “E”, 250 sx Class “G”, 150 sx PF ‘E in 12-1/4” Hole 7” 250 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 70 to 72 deg. f/ ~4,650’ to ~11,800’ MD Hole Angle through perforations = 37 deg. TREE & WELLHEAD Tree 3-1/8” – 5M AlloyTree ‘FL’ Wellhead FMC 11” x 11” 5M, Gen 5 w/ 11” x 3.5” FMC Tubing Hanger, w/ NSCT Threads Top and bottom and 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22629-00-00 Drilled and Cased by Nabors 22E - 12/26/1995 Completed by Nabors 4ES – 5/16/1996 TD = 14,155’ (MD) / TD = 7,628’(TVD) ”00 Orig.DF Elev.: 46.2’/ GL Elev.: 28.7’ Nabors 22E 7” 4 5 9-5/8”88 1 2 Min ID= 2.75” @ 13,392’ PBTD = 14,051’ (MD) / PBTD = 7,539’(TVD) Howco ES Cementer @ 2,132’ 21’ and 20’ marker joints tag from 13,439’ to 13,479’ wlm. RA tag @ 13,439’ wlm. KUP C1 KUP B6 KUP A3/A2/A1 STIMULATION DETAIL 8/8/1996 – High pressure breakdown – Four stages at 200bbls of 20ppt linear gel each. _____________________________________________________________________________________ Revised By: IAT 8/31/2020 PROPOSED Milne Point Unit Well: MPU L-21 Last Completed: 5/16/1996 PTD: 195-191 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 91.1 /H-40 / N/A N/A Surface 112’ 9-5/8"Surface 40 / L-80 /BTC 8.835 Surface 7,249’ 7"Intermediate 26 / L-80 / BTC 6.276 Surface 14,135’ TUBING DETAIL 3-1/2"Tubing 9.3 / L-80 / NSCT 2.99 Surface 13,404’ JEWELRY DETAIL No Depth Item 1 13,366’XO 4.5” x 3.5” NSCT 2 13,368’7” Baker SAB-# Packer 3 13,372’XO 4.5” x 3.5” NSCT 4 13,392’3.5”XN Nipple w/ RHC Plug –MIN ID = 2.750” 5 13,403’WLEG –Bottom @ 13,404’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C1 13,558’13,567’ 7,139’7,146’9’11/23/2018 Open Kuparuk B6 13,567’13,636’ 7,146’7,200’69’11/23/2018 Open Kuparuk A3,2 &1 13,678 13,768’7,233’7,305’90’4/19/1996 Open Perforation Summary: Ref Log –SBT/GR/ CCL –4/18/1996 4.5 SPF 32 gm, Alpha Jet Charges (EHD=0.44” TTP=32.1” @ 72 deg. Phasing (Kuparuk A3/A2/A1) 6 SPF 11 gm, Geo Razors (EHD=0.31” TTP=32” @ 60 deg. Phasing (Kuparuk C1/B6) OPEN HOLE / CEMENT DETAIL 24"250 sx of Arcticset I 12-1/4" 1,396 sx PF “E”, 250 sx Class “G”, 150 sx PF ‘E 8-1/2”250 sx Class “G” WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 70 to 72 deg. f/ ~4,650’ to ~11,800’ MD Hole Angle through perforations = 37 deg. TREE & WELLHEAD Tree 3-1/8”–5M AlloyTree ‘FL’ Wellhead FMC 11” x 11” 5M,Gen 5 w/ 11” x 3.5”FMC Tubing Hanger, w/ NSCT Threads Top and bottom and 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22629-00-00 Drilled and Cased by Nabors 22E -12/26/1995 Completed by Nabors 4ES –5/16/1996 TD =14,4 155’(MD) / TD = 7,628’(TVD) 20”00 Ori g.DF Elev.: 46.2’/ GL Elev.: 16.7’ Nabors 22E 7” 4 5 9-5/8”88 1 2 Min ID= 2.75” @ 13,392’ PBTD =BB 10,500’ (MD) / PBTD = 5,692’(TVD) 3 Howco ES Cementer @ 2,132’ 21’ and 20’ marker joints tag from 13,439’ to 13,479’ wlm. RA tag @ 13,439’ wlm. Tubing cut at ±12,900’ KUP C1 KUP B6 KUP A3/A2/A1 STIMULATION DETAIL 8/8/1996 – High pressure breakdown – Four stages at 200bbls of 20ppt linear gel each. MILNE POINT UNITCoil Tubing BOPE Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe 2.00" Single Stripper Crossover spool 4 1/16 10M X 4 1/16 5M 2” Single Stripper Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: August 31st, 2020Subject: Changes to Approved Sundry Procedure for Well MP L-21Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date Chris D From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, May 23, 2019 9:36 AM To: Wallace, Chris D (CED) Cr Schwartz, Guy L (CED); Regg, James B (CED); Alaska NS - Milne - Wellsite Supervisors; Darci Horner - (C); David Haakinson; Brooks, Phoebe L (CED) Subject: RE: [EXTERNAL] RE: MPL-21 (PTD # 1951910) Shut -In For IA Pressurization Attachments: MPL-21 TIO.XLSX; MIT -T MPU L-21 5-12-19.xlsx All, Milne Point WAG injector MPL-21 (PTD 1951910) had a passing diagnostic MIT -T to 3000 psi against a tubing tail plug on 5/12/19 (attached). Following the MIT -T, tubing pressure bled down to reservoir pressure (^'2350 PSI at surface) overnight indicating a slow leak by the TTP. In the 30 days following the MIT -T, the IA continued to pressurize at roughly 20 psi per day indicating a small tubing or packer leak. A TIO plot is attached for reference. The well will remain shut-in. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wriyard@hilcorl2.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Thursday, May 9, 2019 3:24 PM To:'Wallace, Chris D (DOA)' <chris.wa[lace@alaska.gov> Cc: 'Schwartz, Guy L (DOA)' <guy.schwartz@alaska.gov>; 'Regg, James B (DOA)' <jim.regg@alaska.gov>; Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-Milne-Wellsite5upervisors@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: [EXTERNAL] RE: MPL-21(PTO # 1951910) Shut -In For IA Pressurization All, Milne Point WAG injector MPL-21 (PTD # 1951910) was shut-in on 5/9/19 after returning to injection on 4/14/19 for a 28 day monitoring period. For two weeks, the well appeared to exhibit no annular pressurization but IA pressure now appears to be climbing at —150 psi/day. A TIO plot is attached for reference. The well had a passing diagnostic MIT -IA to 2900 psi on 4/6/19. Going forward a plug will be set in the tubing tail and an MIT -T will be performed to 3000 psi to rule out the possibility of a one-way leak to the IA. Path Forward — Operations 1) Set TTP in XN profile at 13,392' 2) Bleed IA to —300 psi 3) Perform MIT -T to 3000 psi 4) If passing MIT -T, leave tubing pressured up for minimum of 3 days before bleeding back. pressures for any indication of slow TxIA while shut-in. Thank You, Wyatt Rivard I Well Integrity Engineer lHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wLLyard@bilcorl2.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 Monitor daily T/1/0 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, May 9, 2019 3:24 PM To: Wallace, Chris D (DOA) Cc: Schwartz, Guy L (DOA); Regg, James B (DOA); Alaska NS - Milne - Wellsite Supervisors; Darci Horner - (C); David Haakinson Subject: [EXTERNAL] RE: MPL-21 (PTD # 1951910) Shut -In For IA Pressurization Attachments: L-21 TIO.XLSX All, Milne Point WAG injector MPL-21 (PTD It 1951910) was shut-in on 5/9/19 after returning to injection on 4/14/19 for a 28 day monitoring period. For two weeks, the well appeared to exhibit no annular pressurization but IA pressure now appears to be climbing at -150 psi/day. A TIO plot is attached for reference. The well had a passing diagnostic MIT -IA to 2900 psi on 4/6/19. Going forward a plug will be set in the tubing tail and an MIT -T will be performed to 3000 psi to rule out the possibility of a one-way leak to the IA. Path Forward -Operations 1) Set TTP in XN profile at 13,392' 2) Bleed IA to ^'300 psi 3) Perform MIT -T to 3000 psi 4) If passing MIT -T, leave tubing pressured up for minimum of 3 days before bleeding back. Monitor daily T/I/O pressures for any indication of slow TxIA while shut-in. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard(tbhilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday, April 11, 2019 8:25 AM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: [EXTERNAL) RE: MPL-21 (PTD # 1951910) Request to Return to Injection for 28 Day Monitoring Period Wyatt, Approved to resume injection and lets revisit in 28 days. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace(@alaska.eov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, April 11, 2019 8:25 AM To: Wyatt Rivard Subject: RE: MPL-21 (PTD # 1951910) Request to Retum to Injection for 28 Day Monitoring Period Wyatt, Approved to resume injection and lets revisit in 28 days. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7" Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.eov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, April 10, 2019 3:33 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: RE: MPL-21 (PTD # 1951910) Request to Return to Injection for 28 Day Monitoring Period Chris, Milne Point WAG injector MPL-21 (PTD # 1951910) was shut-in on 4/5/19 for signs of possible IA pressurization. Following shut-in, a passing diagnostic MIT -IA was performed on 4/6/19 to 2900 psi confirming tubing, packer and production casing integrity(attached). Additionally, a passing tubing hanger void test on 4/6/19 confirmed tubing neck and packoff seal integrity. MPL-21 had been shut in long-term for reservoir management prior to returning to injection early this year and receiving a passing AOGCC witnessed MIT -IA to 2900 psi on 1/19/19. Hilcorp believes pressurization may have resulted from thermal effects due to a recent large increase in injection pressure and not an integrity issue. Going forward, Hilcorp requests permission to return MPL-21 to injection for a 28 day monitoring period. Monitoring results will be provided at 28 days with the well shut-in at any indication of TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer lHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard0bilcoro.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wya_i'Rtva Sent: Friday, April 5, 2019 4:50 tom` To: 'Wallace, Chris D (DOA)' <chris.wallace a alas >• Alaska NS - Wells Foreman <AlaskaNS- WellsForeman(dhilcoro.com>; Alaska NS - Milne - Wellsite upe ' ors <AlaskaNS-M ilne- WellsiteSuoervisors hilcoro com> Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, April 5, 2019 4:50 PM To: Wallace, Chris D (DOA); Alaska NS - Wells Foreman; Alaska NS - Milne - Wellsite Supervisors Cc: Schwartz, Guy L (DOA); Regg, James B (DOA); Taylor Wellman; Almas Aitkulov, Darci Horner - (C); Chad Helgeson; Joseph VonBargen Subject: MPL-21 (PTD # 1951910) Shut -In for IA Pressurization Attachments: L-21 TIO.XLSX All, Milne point WAG injector MPL-21 (PTD # 1951910) has been shut-in for IA pressurization. The well's injection rate was increased from —450 bwpd to —1200 bwpd on 3/28/19 and the IA pressure increase was originally attributed to thermal effects. However, pressurization has been faster and continued beyond normal stabilization, indicating possible TAA communication. The well will remain shut in until diagnostics are complete and integrity can be confirmed. A TIO plot is attached for reference. Path Forward —Operation 1) Conduct diagnostic MIT -IA to 2500 psi 2) Perform a test of Tubing Hanger seals. Attempt to reenergize if failed. Please call with any questions. Thank You, WyattRivard I Well Integrity Engineer lHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard(ilhilcorp com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re ' DATE: Thursday, January 24, 2019 P.I.Supee"isor K9 i 11 1 SUBJECT: Mechanical Integrity Tests �� HILCORP ALASKA LLC L-21 FROM: Bob Noble MILNE PT UNIT L-21 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry JJ NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT L-21 API Well Number 50-029-22629-00-00 Inspector Name: Bob Noble Permit Number: 195-191-0 Inspection Date: 1/19/2019 IUSp Num: mi[RCN190120153854 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-21 "iType Inj I W ' TVD 6995 "Tubing 2220 2215 - 2212 2210 ' PTD 1951910 'Type Testi SPT Test psi 1749 IA 0 2926 - 1 2860 2837 BBL Pumped: 4.4 BBL Returned: 3.5 OA 213 boo 606 ',, 602 . Interval 4vRTSr Pj P i Notes: Thursday, January 24, 2019 Page I of I Pages NOT Scanned in this Well History File XHVZE 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 Nu mb er of Well H is to ry File PAGES TO DELETE Complete 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 COMMENTS: Scanned by: Beverly Dian~Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Be~,edy Dianna Vincent Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 A D FEB 4 20 2 Mr. Tom Maunder ( °to)._ Alaska OiI ah d Gas Conservation Commission l 333 West 7 Avenue Anchorage, Alaska 99501 0' I,, Subject: Corrosion Inhibitor Treatments of MPL -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPL -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator „ -..p ., a .. ��, ur.g, .:'�R'P?'. , tom °m , ,•;i ,, • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPL -Pad Date: 10/08/11 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 gal MPL -01A 2030640 50029210880100 Sealed conductor N/A N/A N/A N/A NA MPL -02A 2091470 50029219980100 Sealed conductor N/A N/A N/A N/A NA MPL -03 1900070 50029219990000 Tanko conductor N/A N/A N/A N/A NA MPL-04 1900380 50029220290000 Sealed conductor N/A N/A N/A WA NA MPL -05 1900390 50029220300000 Sealed conductor N/A N/A N/A N/A NA MPL -06 1900100 50029220030000 Sealed conductor N/A N/A N/A N/A NA MPL -07 1900370 50029220280000 Sealed conductor N/A N/A N/A N/A NA MPL -08 1901000 50029220740000 Sealed conductor N/A N/A N/A N/A NA MPL -09 1901010 50029220750000 Sealed conductor N/A N/A N/A N/A NA MPL -10 1901020 50029220760000 Sealed conductor N/A N/A N/A N/A NA MPL -11 1930130 50029223360000 Sealed conductor N/A N/A N/A N/A NA MPL -12 1930110 50029223340000 Sealed conductor N/A N/A N/A N/A NA MPL -13 1930120 50029223350000 Sealed conductor N/A N/A N/A N/A NA MPL -14 1940680 50029224790000 Sealed conductor N/A N/A N/A N/A NA MPL -15 1940620 50029224730000 3.3 N/A 3.3 N/A 15.3 8/9/2011 MPL -16A 1990900 50029225660100 23 Needs top job MPL -17 1941690 50029225390000 0.2 N/A 0.2 N/A 5.1 9/1/2011 MPL -20 1971360 50029227900000 0.4 N/A 0.4 N/A 3.4 8/10/2011 --- 7 MPL -21 1951910 50029226290000 1.7 N/A 1.7 N/A 8.5 8/10/2011 MPL -24 1950700 50029225600000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -25 1951800 50029226210000 1.7 N/A 1.7 N/A 15.3 8/10/2011 MPL -28A 1982470 50029228590100 0.3 N/A 0.3 N/A 8.5 10/8/2011 MPL -29 1950090 50029225430000 0.5 N/A 0.5 N/A 3.4 8/7/2011 MPL -32 1970650 50029227580000 0.5 N/A 0.5 N/A 5.1 8/10/2011 MPL -33 1971050 50029227740000 0.2 N/A 0.2 WA 8.5 10/8/2011 MPL -34 1970800 50029227660000 1.7 N/A 1.7 WA 8.5 8/9/2011 MPL -35A 2011090 50029227680100 0.2 N/A 0.2 WA 8.5 10/8/2011 MPL-36 1971480 50029227940000 0.1 N/A 0.1 N/A 7.6 9/1/2011 MPL-37A 1980560 50029228640100 6 N/A 6 WA 47.6 8/13/2011 MPL -39 1971280 50029227860000 1.7 N/A 1.7 N/A 6.8 8/8/2011 MPL -40 1980100 50029228550000 1 N/A 1 WA 6.8 8/8/2011 MPL -42 1980180 50029228620000 5.3 N/A 5.3 WA 30.6 8/14/2011 MPL-43 2032240 50029231900000 17.5 Needs top job MPL-45 1981690 50029229130000 10 N/A 10 WA 8.5 8/10/2011 "~'o1:!. J'V r::: u DEC 2. 2. 2005 '\ STATE OF ALASKA \ ALA~. A OIL AND GAS CONSERVATION COMrv~._SION REPORT OF SUNDRY WELL OPERATIONSAlasl\d VII v. ...'"~ D Stimulate D Other ~1\5~W~a~t to WAG D Waiver D Time Extension D 10/8/1997 D Re-enter Suspended Well D 5. Permit to Drill Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 47.9 KB 8. Property Designation: ADL-355017 11. Present Well Condition Summary: Total Depth measured 14156.7 true vertical 7629.21 Effective Depth measured 14051 true vertical 7539.27 Casing Conductor Surface Production Length 80 7218 14105 Size 20" 91.1# H-40 9-5/8" 40# L-80 7"26# L-80 Perforation depth: Measured depth: 13678 - 13768 True Vertical depth: 7233.36 - 7304.79 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze sUll1mary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 0: Stratigraphic C' feet feet feet feet MD 32 - 112 31 - 7249 30 - 14135 3-1/2" 9.3# 3-1/2" Baker SAB-3 Packer Of 195-1910 J;?! 6. API Number: 50-029-22629-00-00 9. Well Name and Number: Exploratory Service MPL-21 10. Field/Pool(s): Milne Point Field/ Kuparuk River Oil Pool Plugs (measured) Junk (measured) None None TVD 32 - 112 31 - 4651.86 30 -7610.75 Burst 1490 5750 7240 ~Ç^NNED DEC 2 g 2005 L-80 30 - 13403 13368 R8DMS 8Ft DEC 2 2 1005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 000 o 1565 0 15. Well Class after croposed work: Exploratory C Development r 16. Well Status after proposed work: Oil r Gas r WAG P' GINJ r 17. I hereby certify that the foregoing is tr-L:~ and correct to ltw best of my knowledge. Contact Sharmaine Vestal Printed Name Shann~ine Vest,, _, ) Signa~&érØjJ \ f Form 10-404 Revised 04/2004 \~". " ,.",.n ;¡:;::ì¡úri Collapse 470 3090 5410 Tubing pressure o 4446 Service P' WINJ r WDSPLr Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr I /' Phone 564-4424 Date 12/19/2005 Submit Original Only ''''--. r ' f " , / \ I ¡ '\¡ /-'\ L_ Milne Point 2001 Shut In Wells Date Reason for Future Utility Plans & Sw Name Shut-In Well Shut-In ~ Current Mechanical Condition of Well2 Possibilitiesa Comments MPB-07 Jul-97 A No known problems I High GoR well, Facilities can not handle gas. Possible production after gas expansion project. MPB-08 May-94 E No known problems 3 Futher use as an injector not required MPB-13 Jan-86 B GL well that was shut in due to high 3 Wellh~use and flowlines removed water cut. Possible channel into water zone. MPB-17 Jan-96 E No mechanical problems. Quick 3 Wellhouse and fiowiin~s removed' ' communication with producer MPB-19 Jul-91 B GL well. High water cut producer. 3 Weilh°use and flowlines removed Possible frac into water zone MPC-11 Feb-96 E No known problems 3 Further use as an Injector ~ot required while associated producer shut-in MPC-12 / Jan-O0 E Fish in hole, drilling problems 3 Suspended due to drilling problems. 12a ,, , MPC-16 Aug-93 A High GOR well, perfs and completion 3 Wellhouse and flowlines removed abandoned MPc-17 May-O0 D Leak in 9 5/8" casing to surface I Evaluating possible plans for solution to . problem. MPC-20 Apr-O0 B ~,High water cut well, no mechanical I Evaluating possible plans for solution to iproblems . problem. MPC-21 Feb-02 D Problems with Jet Pump Completion I Evaluating possible p~a'ns for solution to problem. MPD-01 Dec-90 C Dead ESP completion, no support to I Evaluating possible plans"~or solution to block problem. Possible alternative uses for wellbore , , , MPD-02/ Aug-99 B Dead ESP completion, very high water I Evaluating possible plans. 02a cut well MPE-02 Jun-05. C No known problems 2 Recomplete to upper Kup zo~'e . " MPE-19 Aug-99 C Failed ESP on tubing string 2 Well brought on line in 2002 MPL-01 Feb-O0 B High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole M~L-IO Feb.99 E No proof that is supports other wells I Evaluating side track possibilities ' MISL-17 Apr-O0 B No menchanical problems, dead ESP I Evaluating side track possibilities ~!?ii~:. '0ct,98 E " -High'p-ressureblock ~-~$O00-psi, no I Possible use for injection when pressure support needed for producers lowers Mi=L.37a Nov-99 C Dead ESP,-noother-mechanical I Evaluating possible side track plans or issuses recompletions MPL-39 Jan-99 E Could not inject gas into well, no use I Evaluating possible side track plans or .. for it. recompletions . , , *Note - Wells were shut in 100% during 2001 JUN Milne Pt Shut In Wells 2001.xis THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 M PL A T E T H IS E W IA L U N D ER M A R K E R C -J...OR_I~I'I .M.DO C P ~::~ R H Z T J} i!-'-, T A 'T' [) A T A P k. I.J 'S 95 - i 9 I C D N 9 5 .... I :~ i C D 9 c- '-- i 9 i r' I?., N 9 5 .... 1 9 i C [.:, i4: -- k1 D 95 ..... /9i 726,!+ ~?k( 8 ~{ P I A t" S E P l/:~, c~.<- 8 E P I A ¢~"'~'; E F' I A ,..t::x S E P I/?,. L. SEF'IA ~-t""' S E F' i A --n~%3 D R ./C D iq i'),.'iTc '~ J 2/' 'J R "q'? .... / '..1, L:,r,e dl'"y .... STATE OF ALASKA ALASI~, ,JIL AND GAS CONSERVATION ~COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 95-191 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 _ 50-029-22629 4. Location of well at surface .i i:i):'.? - ' . ~ ~it,~ 9. Unit or Lease Name 3687' NSL, 5070' WEL, SEC. 8, T13N, R10E,.:,'~ ~'~:~'/- '~i~~~/~,!! ~' Milne Point Unit At top of productive interval ~ 10. Well Number 2621' NSL, 1201' WEL, SEC. 32, T14N, R10E ,,, MPL-21i At total depth 11 Field and Pool 2871' NSL, 1103' WEL, SEC. 32, T14N, R10E ....... ......... ..~:. .... :-. Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 47.9', ADL 355017 12. Date Spudded12/09/95 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 16' N°' °f C°mpleti°nsl 2/22/95 05/16/96 N/A MSL One 17. Total Depth (MD+TVD)! 18. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrosl 14155 7640 F~ 14051 7552 FT~ []Yes I~No I N/A MD/ 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, GR/RES, GFFCDN/CDR, GR/CCL 23. CASING, LINER AND CEMENTING RECORD CASING I SE'FFING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 7249' 12-1/4" 1396 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 7" 26# L-80 29' 14135' 8-1/2" 250 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", L-80 13404' 13368' MD TVD MD TVD 13678'-13768' 7247'-7318' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/76 bbl diesel High Press~e ~re~(~w~ ~/~lDff ~S 20 ppt linear gel F,~L~..L I v L-t,- 27. PRODUCTION TEST i') L (' _, L_ -, U ~ Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 4, 1996 I Water Injection Alaska, 0ii & Gas Cons. commission Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S~nc~qqr~-O~L RATIO TEST PERIOD · / Flow Tubing Casing PressureCALCULATED o OIL-BBL GAS-MCF WATER-BBL 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 Geologic Marke: 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top Kuparuk 'A' 13668' 7193' Top Kuparuk A3 13678' 7200' Top Kuparuk A2 13695' 7214' Top Kuparuk A1 13730' 7242' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify' that the foregoing is trlae and cerrect~i to the best of my knowledge Signed ~./;~ ~--~:~~. '~ Tim Schofield --- , . Title Senior Drilling Engineer Date Prepared By Name/Number: Kathy Campoamor, 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27': Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPL-21I BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/08/95 10:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 22E WO/C RIG: 12/07/95 ( 1) TD: 0'( 0) 12/08/95 (2) TD: 112' ( 112) 12/09/95 (3) TD: 112'( 0) 12/10/95 ( 4) TD: 1860' ( 1748) 12/11/95 ( 5) TD: 3814' (1954) 12/12/95 (6) TD: 5476'(1662) 12/13/95 ( 7) TD: 7205' (1729) INSTALLING DIVERTER MW: 0.0 VIS: 0 MIRU. MOVE RIG FROM MPL-25 TO MPL-21. INSTALL SURFACE SPOOL & DIVERTER LINES. REPAIRING GOOSENECK MW: 0.0 VIS: 0 RU DIVERTER LINE, MOVE SUB. BROKE CYLINDER OFF GOOSENECK. MOVE GOOSENECK INTO SHOP FOR REPAIR. SPOT PITS & MOTORS. CIRC STEAM , WORK ON GOOSENECK. CHANGE VALVES & SEATS IN PUMPS, CHANGE #1 CHARGE PUMP, TORQUE CYLINDER BOLTS, CHANGE EQUALIZER VALVE IN PITS. RU FLOWLINE MW: 0.0 VIS: 0 CONT REPAIR GOOSENECK. FINISH MIRU. NU PITCHER NIPPLE, TIGHTEN HYDRIL, RU FLOWLINE. RIG ACCEPTED @ 2200 HRS., 12/08/95 TO COVER NU OF DIVERTER LINES. DRILLING MW: 0.0 VIS: 0 FINISH NU FLOWLINE. LOAD FLOOR WITH BHA & STEAM. FUNCTION TEST DIVERTER, TEST WAIVED BY LOU WITH AOGCC. PU HWDP WITH NEW HARDBAND, PU MOTOR & BIT. DRILL ICE F/30' T/l12', NEW HOLE T/l16'. SET BACK DRILL COLLARS, MU BHA. DRILL F/l16' T/174'. FINISH PU BHA. DRILL F/274' T/1860'. RIH MW: 0.0 VIS: 0 DRILL F/1860' T/2486' CBU, MONITOR WELL, PUMP PILL. SHORT TRIP TO JARS. OK. RIH. DRILLED F/2486' T/3814'. CIRC SWEEPS OUT, MONITOR WELL, PUMP PILL. POOH, CHANGE 2 STAB BLADES, LD MWD, 2 LC, CHANGE BITS. CLEAR FLOOR, PU CDR & DIFFERENT MWD, ALIGN & RIH WITH DRILL COLLARS. CUT & SLIP DRILLING LINE. RIH WITH BIT #2, LD BENT HWDP, PU NEW JT. DRILLING MW: 0.0 VIS: 0 MU BHA. LD BENT HWDP & PU NEW HWDP. RIH T/1847'. MWD SHOWED LOW OIL LEVEL. POOH, CHANGE MWD. RIH, TEST MWD. BLOWDOWN TOP DRIVE. RIH T/3717', WASH & REAM T/3814' DRILL F/3814' T/5133'. CIRC SWEEPS OUT, MONITOR WELL, PUMP PILL. POOH. RIH & WORK THRU 4890'-4925'. DRILL F/5130' T/5476'. DRILLING MW: 0.0 VIS: 0 DRILL F/5476' T/6354'. FINISH CIRC SWEEPS OUT OF HOLE, MONITOR WELL, PUMP PILL. SHORT TRIP, OK. CHANGE SAVER SUB ON TOP DRIVE. TIH, WASH & REAM LAST 90' OK. DRILL F/6354' T/7205' WELL : MPL-21I OPERATION: RIG : NABORS 22E PAGE: 2 12/14/95 (8) TD: 7268'( 63) 12/15/95 ( 9) TD: 7268' ( 0) 12/16/95 (10) TD: 8070' ( 802) 12/17/95 (11) TD:10390' (2320) 12/18/95 (12) TD:12315' (1925) 12/19/95 (13) TD:12315' ( 0) 12/20/95 (14) TD:12315' ( 0) 12/21/95 (15) TD:13542' (1227) RUNNING CASING MW: 0.0 VIS: 0 DRILL F/7205' T/7268'. CIRC HI-LO VIS SWEEPS AROUND. MONITOR WELL, PUMP PILL, POOH TO JARS. SERVICE TOP DRIVE & CROWN. RIH, WORK THRU TIGHT SPOTS 4567'-4662'. CIRC & COND MUD. MONITOR WELL, PUMP PILL, POOH. LD BHA, RU TO RUN 9-5/8" CASING. RIH WITH 9-5/8" CASING. TESTING BOPE MW: 0.0 VIS: 0 FINISH RUNNING 9-5/8" CASING. CIRC & COND MUD. TEST LINES. MIX & PUMP CEMENT. BUMP PLUG. FLOATS HELD. OK. CIP 1430 HRS. NO CEMENT TO SURFACE. RD CEMENT HEAD & LD LANDING JT. ND DIVERTER. RU TO PUMP TOP JOB. FLUSH ANNULUS WITH WATER & PUMP CEMENT. RD. INSTALL SPLIT HEAD & NU BOPE. TEST METAL TO METAL SEALS. OK. FINISH NU & CLEAR RIG FLOOR OF CASING EQUIP. RU ATLAS & RUN GYRO. PULL WR & INSTALL TEST PLUG. TEST BOPE. BOBBY FOSTER WITH AOGCC WAIVED WITNESSING TEST. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 FINISH TESTING BOPE. PULL TEST PLUG & INSTALL WR. MU BHA #3. ORIENT & TEST MWD. LOAD SOURCE. TIH T/2433'. SERVICE TOP DRIVE. TIH, PU 5" DP. TAG FLOAT COLLAR. TEST CASING. OK. DRILL FLOAT EQUIP & 10' NEW FORMATION T/7278' RUN LOT. DRILL 8-1/2" HOLE F/7278' T/8070' DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL 8-1/2" HOLE F/8070' T/9552' CIRC SWEEP AROUND. MONITOR WELL. PUMP PILL. POOH TO SHOE. WORK THRU TIGHT SPOTS. TIH, PU DP. DRILL 8-1/2" HOLE F/9552' T/10390' CBU MW: 0.0 VIS: 0 DRILL 8-1/2" HOLE F/10390' T/11846' FINISH CIRC SWEEP AROUND. MONITOR WELL. SHORT TRIP T/~500'. SERVICE TOP DRIVE & CROWN. TIH. OK. DRILL 8-1/2" HOLE F/11846' T/12315' CBU TO POOH TO SHOE & WAIT ON WEATHER. W O W MW: 0.0 VIS: 0 FINISH CIRC HOLE CLEAN. POOH TO CASING. OK. WAIT ON WEATHER. WAITING ON WEATHER MW: 0.0 VIS: 0 WAITING ON PHASE II WEATHER. DUMPED 3 GUZZLER LOADS INTO "A" RESERVE PIT & WILL CONTINUE USING "A" PIT UNTIL ROAD TO BALL MILL IS CLEARED. PRUDHOE BAY IS UNDER PHASE III WEATHER CONDITIONS. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 TIH T/9750'. CIRC & COND MUD. FINISH TIH T/12315'. NO FILL. CIRC & COND MUD. DRILL 8-1/2" HOLE F/12315' T/13260'. CBU. DRILL 8-1/2" HOLE F/13260' T/13542' WELL : MPL-21I OPERATION: RIG : NABORS 22E PAGE: 3 12/22/95 (16) TD:14135' ( 593) 12/23/95 (17) TD:14155' ( 20) 12/24/95 (18) TD:14155' ( 0) 12/25/95 (19) TD:14155' ( 0) 12/26/95 (20) TD:14155' ( 0) TIH MW: 0.0 VIS: 0 DRILL 8-1/2" HOLE F/13542' T/13731'. WELL FLOWING. CIRC MUD AROUND. MONITOR WELL. FLOWED BACK & STOPPED. DRILL 8-1/2" HOLE F/13731' T/13768'. WELL BLEW MUD OVER ROTARY TABLE. SHUT IN. CBU THRU CHOKE. NU MUD CUT OR GAS ON BOTTOMS UP. DRILL 8-1/2" HOLE F/13768' T/14135'. CIRC HI/LO SWEEPS AROUND. MONITOR WELL. POOH TO CASING SHOE. OK. MONITOR WELL. NO FLOW. SLIP & CUT DRLG LINE. TIH. RUNNING 7" CASING MW: 0.0 VIS: 0 FINISH TIH. NO FILL. DRILL F/14235' T/14155'. DRILL 20' RAT HOLE FOR CASING. CIRC & COND MUD TO RUN CASING. MU EMS & PUMP DOWN SAME. MONITOR WELL & PUMP PILL. POOH TO BHA. RECOVER EMS. LD BHA. DOWNLOAD SOURCE & LOGS. CHANGE TOP RAMS TO 7" & TEST SAME. LOGS WERE DOWNLOADED & FAXED TO GEOLOGIST WHO CONFIRMED TO RUN CASING. CLEAR RIG FLOOR & RU CASING TOOLS. RUNNING 7" CASING. WOC MW: 0.0 VIS: 0 FINISH RUNNING 7" CASING. SHOE @ 14135'. TIH. MU CIRC HEAD & BREAK CIRC SLOW. INCREASE RATE. TEST LINES. PUMP WATER & SPACER. MIX & PUMP 250 SX 'G' PUMP 10 BBLS WATER, 80 BBLS DIESEL & DISPLACE 447 BBLS SEAWATER WITH RIG PUMPS. BUMP PLUG 3500 PSI & FLOATS HELD. CIP @ 0330 HRS. WELL BREATHING MUD BACK. CLOSED ANNULUS & WOC. TEST CASING. OK. LD DP MW: 0.0 VIS: 0 WOC. OPEN ANNULAR. ONLY SLIGHT FLOWBACK. INSTALL 7" PACKOFF & 3-1/2" HANGER. TEST SAME. OK. CHANGE TOP RAMS TO 7" & ND BOPE. INSTALL ADAPTER FLANGE & NU TREE. TEST T/5000 PSI. ADAPTER FLANGE LEAKED. ND & CHANGE OUT O-RINGS. NU ADAPTER & TREE. RE-TEST T/5000 PSI. OK. LD DP FROM DERRICK IN MOUSE HOLE. RELEASED @ 1900 HRS,12/25 MW: 0.0 VIS: 0 FINISH LD DP FROM DERRICK IN MOUSE HOLE. WAIT ON PRODUCTION TO GIVE PERMISSION TO MOVE RIG. RIG RELEASED @ 1900 HRS., 12/25/95 FROM MPL-21I. SIGNATURE: (drilling superintendent) DATE: Milne Point Unit, Ak. TO: Steve Rossberg FROM: J. Fox Well Name: IMp L-21i Main Category: IWIRELINE Sub Category: ISBT / Perf Kup. I'A' Sand / SBHP Operation Date: 104 / 18-20 / 96 Date: 104 / 20 / 96 Purpose: In preparation for the completion of this well as a water injection well the wellbore needs to; have a cement bond evaluation Icg performed on it, Kup. 'A' Sand perforated, and a static bottomhole pressure measurement made. The bottomhole pressure will verify the utility of this well as an injector. Sequence of Events: 0900 -Ambient temp. = 14 deg. F, wind speed = 8 kts. MIRU Atlas Wireline (E-line) unit. Make up Segmented Bond tool, acoustic Icg tool, gamma ray tool, CCL centralizer, cablehead toolstring on magnetically marked 15/32" wireline and packoff assemblies. Tie in to surface elevation. 1145 - RIH w/logging assembly. Tag bottom at 13,997'. Log repeat section. RIH to bottom. Log main pass to 11,500' wlm. POOH. 1530 - MU 4.5" x 20' hollow carrier perforating gun assembly and lubricator system. 1700 - Pressure test lubricator to 1000 psi - OK. RIH. Tool setting down numerous times at various depths from 4700' to 6900'. POOH to install rollers. 2000 - Install one 4.5" roller on top (only) of gun assembly. RIH to 13,900'. Tool running speed was slow across the high hole angle (esp. around 7000'). Run correlation Icg. correct depth. Log into shooting depth (CCL @ 13,746'). WHP -- 0. Detonate gun to perforate casing from 13,748' to 13,768' w/5 JSPF 32 gm. AlphaJets. No increase in WHP. Log off, POOH. 2330 - Secure wellhead. Rig down for the night. 04/19 / 96 0730 - MIRU. Pwh = 0. Small amount of gas pressure that easily bled off. 0830 - RIH w/20'x 4.5" hollow carrier gun w/rollers top and bottom. Tool slowed down slightly at times but otherwise saw no problems. Make correlation run. Depth correct. Log into shooting position (CCL @ 13,726'). Detonate gun to perforate casing from 13,728' to 13,748' w/5 JSPF 32 gm. AlphaJets. No increase in WHP. Log off, POOH. All shots fired. 1130 - RIH w/20'x 4.5" hollow carrier gun w/rollers top and bottom. Tie into flagged depth. Make correlation run. Depth correct. Log into shooting position (CCL @ 13,706'). Detonate gun to perforate casing from 13,708' to 13,728' w! 5 JSPF 32 gm. Alpha Jets. No increase in WHP. Log off, POOH. All shots fired. 1430 - RIH w/20' x 4.5" hollow carrier gun w/rollers top and bottom. Tie into flagged depth. Make correlation run. Pulling weight occasionally through perforations. Depth correct. Log into shooting position (CCL @ 13,686'). Detonate gun to perforate casing from 13,688' to 13,708' w! 5 JSPF 32 gm. AlphaJets. No increase in WHP. Log off, POOH. All shots fired. 1730 - RIH w/10'x 4.5" hollow carrier gun-w/rollers top and bottom. RIH. Tie into flagged depth. Make correlation run. Pulled 1000 lb. over at 13,685'. Depth correct. Log into shooting position (CCL @ 13,676'). Detonate gun to perforate casing from 13,678' to 13,688' w/5 JSPF 32 gm. AlphaJets. No increase in WHP. Log off, POOH. All shots fired. 2030 - MU HP temp./press, tool. Take 10 min. pressure reading in lubricator- pressure = 9 psia at 36 deg. RIH. First noticed surface pressure increasing with the tool approx. 4000' in the hole and continued to pressure up as tool was run in the hole. Correlated depth and corrected. Position pressure sensor at the bottom of the perforated interval (13,768' = 7317' TVD). Monitor pressures and temperatures. elapsed time pressure (psia) Temp. (deg. F) Initial 3805 179 10 min. 3792 179 20 min. 37'79 179 30 min. 3770 179 40 min. 3765 179 50 min. 3759 179 60 to 90 min. data not recorded 90 min. 3739 100 min. 3599 First realized that grease supply for flow leaking through flow tube to bleed trailer. Surface Pressure (psig) 179 179 444 tube had run out and some fluid 110 min. 3473 179 340 120 min. 3474 179 341 130 min. 3469 179 338 140 min 3463 179 332 147 min. 3458 179 04/20/96 0035 - POOH 90' to place pressure probe across the top of the perforated interval (13,678' RKB = 7242' TVD) in an attempt to get a pressure gradient. 0039 initial 3414 178 314 10 3407 178 308 20 3401 178 302 30 3395 178 297 35 Bleed pressure (approx. 0.5 bbl.) off at surface in an attempt to stabilize pressure (i.e. bleed off volume displaced by wireline) 0237 - 40 3187 178 10 50 n/a 60 3122 178 24 7O 3128 178 3O 8O 3133 178 36 90 3137 178 40 100 3140 178 42 110 3142 178 44 120 3143 178 46 POOH. RDMO. ,~ Results: A cement bond Icg was performed, the entire Kup. interval was perforated, and a SBHP was measured. The wellbore is ready to be prepped for the completion rig. Cement Bond Quality: Top of the cement was noted at approx. 12,000' on the initial run in the hole. Cement bond quality appears very good throughout the logged interval. There was some indication of channeling intermittently throughout (notably throughout the production interval). This log was performed on marked line and will now be the primary correlation log. The wireline depths correlated closely to the MWD log depths. It was unnecessary to correct the proposed perforation interval to the wireline log depths as they were the same. If anything the wireline interval may show slightly less (2') formation thickness relative to the MWD log. The RA tag was located at 13,439' RKB. Perforating: The interval of 13,678' to 13,768' ( 90' ) was perforated with 32 gm. Alpha Jet charges (EHD = 0.44", TTP = 32.1") at 72 deg. phasing, random orientation. No pressure was seen at surface. No significant problems were encountered getting the SBT in the hole however the guns would not make it without the assistance of rollers. Static bottom hole pressure survey: A bottom hole pressure of approx. 3160 psig was measured at the top of the perforations (13,678' RKB = 7242' TVD) This equates to an EMW = 8.39 ppg. The pressure measurement took a long time to stabilize due to line displacement pressuring up the wellbore. The pressure was still climbing approx. 1 psi/5 min. at the end of the survey. It was determined that the reservoir pressure was well below virgin pressure indicating pressure communication with a producer and therefore confirmed it's utility as an injector. It's worth noting that on all of the gun runs little or no surface pressure was seen despite the displacement of the large line and tools and the fact that fluid was close to surface. On the final run in the hole w/the (smaller) press / temp. tool following the final perf run the well pressured up and pressure did not readily bleed off into the formation. Diesel Used [0 Methanol Used TD Wireline Depth_13.997' TD Measured Depth: SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPL-21i Rig Name: N-4ES AFE: 337001 Accept Date: 05/1 3/96 Spud Date: Release Date: 05/1 6/96 May 13 1996 MIRU. Rig accepted 05/13/96 @ 0300 hrs. May 14 1996 Set berms, install HD lines to tree. 200# on tree, bleed off, rig HD line to tiger tank. ND tree, frac hanger, install test plug. NU BOP, ND rams. Test BOP, bag t/5000#. Load tubing, SLM, Icad pipe shed. RIH with 3-1/2" tubing with packer retrieve tool. May 15 1996 Trip in hole with 3-1/2" tubing/packer retrieve tool, SLM, drift. Circ cond brine. Tag and release RBP @ 13519'. Monitor well, static. RIH to 13550'. CBU, crude and gas return on bottoms up. Circ influx out to tiger tank. Monitor well, static - TOH. Slip cut drill line. Cont TOH. May 16 1996 Lub rig service, pull WR. MU tail pipe assy & Baker S-3 packer & TIH with same on 3-1/2" tubing. MU hanger & land jt. Land same & RILDS, LD landing jt. ND BOP's. NU adapater flange & tree. Flange wouldn't test. ND tree & change out seal sleeve o-ring. NU tree & re-test. Sleeve seals failed again. ND & NU and re-test to 5000#, OK. Pull TWC. Rig lines to tree & test. Rev circ. Circ brine, follow with diesel + diesel down tubing. Drop ball & rod, allow to fall. Ball not on seat, wait & re-test. Ball not on seat. Rig Camco to RIH & put ball on seat. May 17 1996 Test lubricator & RIH with blind box & push rod & ball to seat & verify. POOH & RD Camco. Set & test packer. Bleed tubing & annulus. RU lubricator & set BPV. RD lines to tree & secure well & clean pits. Rig released 05/16/96 @ 1300 hrs. Page gyro/data' B,P, EXPLORATION ~-.~ ~ L-PAD, MPL-21 MILNE POINT, ALASKA Gyro Multishot Survey in 5" Drillpipe Survey date: 15 December, 1995 Job number: AK1295G313 ¢/ SR313.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 December 20, 1995 Directional Information B.P. Exploraton (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re: L-Pad, MPL-21, Milne Point, Alaska Enclosed please find one (1) original and six copies (6) and one (1) disk of the completed survey of Well #MPF-21 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely OPerations Manager RS/fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation OOQ'g I,~IS J.~lOd_:J~! -I¥OIDO"IONO~HO ClN¥ .LN~ll~ldlnO~ 'S 'IO~/NO0 ~_Ll'lYnO '1;, 9NIJ. SI-! xa^ans Nnazno '~ S-ll~f~lO xa^ans '~ Lq:IHS NOIlW)I-II/a:IO x:l^~lns ' NOlSSnosla '1, S.LN::I.I. NOO gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR313.DOC gyro/data DISCUSSION JOB NUMBER' AK1295G313 Tool 080 was run in L-pad well number MPL-21 inside of 5" drillpipe on Atlas 5/16 wireline. The survey was run without problems. SR313.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK1295G313 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR313.DOC gyro/data 2. SURVEY DETAILS · SR313.DOC gyro/data' SURVEY DETAILS JOB NUMBER: AK1295G313 CLIENT: B.P. EXPLORATION RIG: NABORS RIG 22E LOCATION: Milne Point WELL: MPL-21 LATITUDE: 70.485 LONGITUDE: W SURVEY DATE: 15-Dec.,1995 SURVEY TYPE : DEPTH REFERENCE: MAX. SURVEY DEPTH: MULTISHOT IN 5" drillpipe ROTARY TABLE ELEVATION 46.2 asl 7055.0 SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100'and 50' UTM CO-ORDINATES: TARGET DIRECTION: 20.68 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR313.DOC gyro/data 3. OUTRUN SURVEY LISTING SR313. DOC A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION Job Number: AK1295G313 WELL: L-PAD, MPL-21 Location: NABORS 22E, MILNE POINT, ALASKA Run Date: 15-Dec-95 00:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.485000 deg. N Sub-sea Correction from Vertical Reference: 46.2 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 20.680 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, Job Number: AK1295G313 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.0 0.0 -46.2 0.00 0.0' 0.0 0 - 7055 FT. GYRO SURVEY RUN IN 9 5/8" CASING. MEASURED DEPTHS ARE REFERENCED TO THE NABORS 22E R.K.B. AT 46.2 A FIVE FT. WIRELINE CORRECTION HAS BEEN ADDED TO THE SURVEY. FT. ABOVE M.S.L 0.00 N 0.00 E 105.0 .10 147.72 105.0 -.1 58.8 .10 205.0 .14 123.54 205.0 -.1 158.8 .06 305.0 .17 210.15 305.0 -.3 258.8 .21 405.0 .44 96.32 405.0 -.4 358.8 .53 505.0 .92 79.16 505.0 .2 458.8 .52 .1 147.7 .3 137.9 .5 151.4 .8 137~. 8 1.8 105.7 .08 .22 .42 .59 .48 .O5 E .20 E .23 E .53 E 1.70 E 605.0 1.59 80.22 605.0 1.3 558.8 .68 705.0 2.71 75.74 704.9 3.3 658.7 1.12 805.0 3.30 71.97 804.8 6.5 758.6 .63 905.0 5.58 76.44 904.5 11.0 858.3 2.30 1005.0 7.95 80.65 1003.7 17.2 957.5 2.42 3.9 91.4 7.5 84.5 12.7 80.1 20.4 78.1 32.2 78.4 .09 .73 2.20 4.23 6.49 S N N N N 3.85 E 7.51 E 12.54 E 20.00 E 31.56 E 1105.0 10.89 84.00 1102.4 24.9 1056.2 2.98 1205.0 11.83 84.74 1200.4 33.6 1154.2 .95 1305.0 13.14 77.53 1298.1 44.3 1251.9 2.03 1405.0 16.47 64.83 1394.8 60.7 1348.6 4.63 1505.0 17.21 58.85 1490.5 82.5 1444.3 1.88 48.5 79.8 68.2 81.1 89.8 81.1 114.8 78.7 142.7 75.4 8.61 10.53 13.93 22.42 36.10 N N N N N 47.78 67.38 E 88.68 E 112.62 E 138.11 E 1605.0 17.56 55.44 1585.9 106.6 1539.7 1.08 1705.0 19.11 50.41 1680.8 133.2 1634.6 2.22 1805.0 20.77 44.65 1774.9 163.6 1728.7 2.57 1905.0 22.54 40.40 1867.8 197.9 1821.6 2.36 1955.0 24.64 37.23 1913.6 216.9 1867.4 4.91 171.4 72.2 201.3 69.3 233.2 66.1 267.4 63.0 285.8 61.3 52.30 71.30 94.35 121.57 137.16 N N N N N 163.19 E 188.23 E 213.31 E 238.20 E 250.72 E A Gyr oda t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, Job Number: AK1295G313 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2005.0 26.50 35.10 1958.7 2105.0 28.78 32.71 2047.3 2205.0 31.95 29.99 2133.6 2305.0 33.77 29.59 2217.6 2405.0 33.72 28.86 2300.7 237.7 1912.5 4.15 305.4 59.6 282.8 2001.1 2.53 347.8 56.3 332.5 2087.4 3.46 394.2 53.2 386.1 2171.4 1.83 444.5 50.4 441.0 2254.5 .41 496.7 48.1 154:59 N 263.44 E 193.10 N 289.28 236.29 N 315.52 ~ 283.38 N 342.48 E 331.86 N 369.59 E 2505.0 33.36 28.19 2384.1 2605.0 32.88 28.78 2467.8 2705.0 33.97 27.38 2551.3 2805.0 33.91 27.51 2634.3 2905.0 33.45 27.96 2717.5 495.7 2337.9 .51 549.1 46.1 549.9 2421.6 .58 601.4 44.6 604.5 2505.1 1.33 654.4 43.2 659.9 2588.1 .09 708.3 42.0 715.0 2671.3 .52 762.1 40.9 380.40 N 395.97 E 428.43 N 422.03 E 477.02 N 447.95 E 526.57 N~ 473.68 E 575.65 N 499.49 E 3005.0 33.30 28.67 2801.0 3055.0 33.91 28.50 2842.6 3105.0 35.27 28.19 2883.8 3155.0 36.14 27.69 2924.4 3205.0 37.17 27.56 2964.5 3255.0 37.12 26.93 3004.4 3305.0 36.86 27.42 3044.3 3355.0 38.55 26.77 3083.8 3405.0 40.16 26.99 3122.5 3455.0 41.80 27.51 3160.3 769.5 2754.8 .42 815.9 40.1 796.9 2796.4 1.23 843.1 39.7 825.0 2837.6 2.73 870.9 39.4 854.0 2878.2 1.84 899.5 39.0 883.6 2918.3 2.06 928.8 38.6 913.6 2958.2 .76 958.4 38.3 943.5 2998.1 .78 988.0 37.9 973.9 3037.6 3.47 1018.0 37.6 1005.4 3076.3 3.23 1049.2 37.3 1038.0 3114.1 3.35 1081.5 37.0 624.08 N 525.59 E 648.39 N 538.83 E 673.37 N 552.31 E 699.15 N 565.98 E 725.59 N 579.82 E 752.43 N 593.64 779.19 N 607.38 E 806.42 N 621.30 E 834.70 N 635.64 E 863.85 N 650.65 E 3505.0 43.12 27.96 3197.1 3555.0 44.41 27.54 3233.2 3605.0 45.17 27.11 3268.7 3655.0 46.39 26.04 3303.6 3705.0 47.20 25.50 3337.8 1071.5 3150.9 2.71 1114.8 36.7 1105.8 3187.0 2.65 1149.0 36.4 1140.8 3222.5 1.64 1183.8 36.2 1176.4 3257.4 2.88 1219.1 35.9 1212.7 3291.6 1.79 1255.0 35.6 893.72 N 666.37 E 924.33 N 682.47 E 955.63 N 698.63 E 987.67 N 714.66 E 1020.50 N 730.51 E A Gyr oda t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, Job Number: AK1295G313 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3'755.0 48.91 24.46 3371.2 3805.0 50.74 24.00 3403.5 3855.0 52.09 24.22 3434.7 3905.0 52.96 23.79 3465.1 3955.0 53.52 24.40 3495.0 1249.8 3325.0 3.76 1291.6 35.3 1287.9 3357.3 3.71 1329.1 35.0 1326.9 3388.5 2.73 1367.5 34.7 1366.6 3418.9 1.88 1406.5 34.4 1406.5 3448.8 1.48 1445.9 34.1 1054.21 N 1089.04 N 1124.72 N 1160.96 N 1197.53 N 746.21'E 761.89 777.85 ~ 794.00 E 810.35 E 4005.0 54.26 24.76 3524.5 4055.0 55.10 25.27 3553.4 4105.0 56.48 24.73 3581.5 4155.0. 57.79 24.69 3608.6 4205.0 58.85 24.84 3634.9 1446.8 3478.3 1.58 1485.8 33.8 1487.5 3507.2 1.88 1526.1 33.6 1528.8 3535.3 2.91 1567.0 33.4 1570.7 3562.4 2.61 1608.6 33.1 1613.1 3588.7 2.13 1650.7 32.9 1234.27 N 1271.24 N 1308.71 N 1346.86 N 1385.50 N 827.15 E 844.40 E 861.87 E 879.43 E 897.25 E 4255.0 59.44 23.28 3660.5 4305.0 60.75 22.56 3685.5 4355.0 61.72 22.31 3709.5 4405.0 63.34 22.28 3732.6 4455.0 64.19 22.44 3754.7 1655.9 3614.3 2.93 1693.]. 32.7 1699.2 3639.3 2.90 1735.8 32.5 1743.1 3663.3 1.98 1779.0 32.2 1787.4 3686.4 3.23 1822.7 32.0 1832.2 3708.5 1.72 1866.9 31.7 1424.69 N 1464.61 N 1505.13 N 1546.17 N 1587.65 N 914.75 E 931.63 E 948.36 E 965.19 E 982.24 E 4505.0 65.42 21.63 3776.0 4555.0 66.21 21.28 3796.5 4605.0 68.03 20.96 3815.9 4705.0 71.03 19.56 3850.9 4805.0 70.21 19.89 3884.1 1877.5 3729.8 2.87 1911.5 31.5 1923.1 3750.3 1.69 1956.5 31.3 1969.1 3769.7 3.70 2001.8 31.0 2062.8 3804.7 3.28 2093.9 30.6 2157.1 3837.9 .88 2186.6 30.1 1629.59 N 1672.04 N 1715.01 N 1802.89 N 1891.69 N 999.21 1015.90 E 1032.49 E 1064.92 E 1096.75 E 4905.0 71.72 20.10 3916.7 5005.0 69.54 20.15 3949.8 5105.0 71.09 20.20 3983.5 5205.0 72.04 20.10 4015.1 5305.0 71.39 20.38 4046.5 2251.6 3870.5 1.52 2279.8 29.7 2346.0 3903.6 2.18 2372.8 29.3 2440.1 3937.3 1.55 2465.8 29.0 2535.0 3968.9 .95 2559.6 28.6 2629.9 4000.3 .71 2653.6 28.3 1980.52 N 2069.09 N 2157.47 N 2246.53 N 2335.62 N 1129.08 E 1161.54 E 1194.01 E 1226.69 E 1259.54 E A Gyrodat a Di re c t i ona i Survey B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, Job Number: AK1295G313 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5405.0 71.42 19.97 4078.4 5505.0 71.96 19.35 4109.8 5605.0 72.20 19.26 4140.6 5705.0 72.90 18.59 4170.6 5805.0 72.70 18.36 4200.2 2724.7 4032.2 .39 2747.4 28.1 2819.6 4063.6 .80 2841.4 27.8 2914.7 4094.4 .25 2935.5 27.5 3010.1 4124.4 .95 3029.9 27.2 3105.6 4154.0 .29 3124.3 27.0 2424.58 N 1292.23 E 2513.98 N 1324.18 2603.78 N 1355.64 ~ 2694.02 N 1386'.57 E 2784.62 N 1416.84 E 5905.0 71.70 18.41 4230.7 6005.0 71.69 18.25 4262.1 6105.0 71.95 18.56 4293.3 6205.0 71.29 18.21. 4324.8 6305.0 71.83 18.65 4356.5 3200.7 4184.5 1.00 3218.5 26.7 3295.6 4215.9 .15 3312.5 26.5 3390.5 4247.1 .39 3406.6 26.3 3485.3 4278.6 .74 3500.6 26.0 3580.1 4310.3 .68 3594.7 25.8 2874.98 N 1446.87 E 2965.10 N 1476.73 E 3055.25 N 1506.73 E 3145.30 N 1536.67 E 3235.30 N 1566.66 E 6405.0 71.03 18.87 4388.3 6505.0 72.29 19.37 4419.8 6605.0 71.23 18.64 4451.1 6705.0 72.92 17.79 4481.9 6805.0 71.85 18.11 4512.1 3674 · 8 4342 . 1 . 82 3688 . 7 25 . 7 3769.7 4373.6 1 · 34 3783.1 25.5 3864.7 4404.9 1.27 3877.4 25.3 3959.7 4435.7 1.87 3971.9 25.2 4054.9 4465.9 1.11 4066.4 25.0 3325.05 N 3414.74 N 3504.53 N 3594.91 N 3685.58 N 1597.15 E 1628.24 E 1659.17 E 1688.90 E 1718.28 E 6905.0 71.21 16.39 4543.8 7005.0 72.14 18.29 4575.3 7055.0 71.55 18.64 4590.8 4149.6 4497.6 1.76 4160.4 24.8 4244.3 4529.1 2.03 4254.6 24.7 4291.8 4544.6 1.35 4301.8 24.6 3776.16 N 3866.77 N 3911.83 N 1746.41 1774.69 1789.74 Final Station Closure: Distance: 4301.81 ft Az: 24.59 deg. A Gyroda t a D i r e c t i on a i Survey for B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, MILNE POINT, ALASKA Job Number: AK1295G313SS Run Date: 15-Dec-95 00:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.485000 deg. N Sub-sea Correction from Vertical Reference: 46.2 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 20.680 deg Vertical Section Calculated from Well Head Location C!csure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, MILNE POINT, Job Number: AK1295G313SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet -46.2 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0 - 7055 FT. GYRO SURVEY RUN IN 9 5/8" CASING. MEASURED DEPTHS ARE REFERENCED TO THE NABORS 22E R.K A FIVE FT. WIRELINE CORRECTION HAS BEEN ADDED TO THE .B. AT 46.2 FT. ABOVE M.S.L SURVEY. 0.00 N 0.00 E 100.0 .12 137.76 146.2 -.1 200.0 .15 159.22 246.2 -.2 300.0 .28 163.25 346.2 -.3 400.0 .63 89.25 446.2 -.2 500.0 1.20 79.60 546.2 .6 .08 .3 143.7 .13 .5 143.5 .34 .8 145.8 .52 1.8 124.6 .58 3.9 99.8 .14 S .11 E .30 S .21 E .49 S .35 E .54 S 1.01 E .32 S 2.59 E 600.0 2.05 78.37 646.2 2.1 700.0 2.95 74.18 746.2 4.6 800.0 4.25 73.83 846.2 8.4 900.0 6.58 78.21 946.2 13.6 1000.0 9.22 82.09 1046.2 20.5 .86 7.5 88.5 .92 12.7 82.6 1.32 20.4 79.2 2.35 32.2 78.2 2.67 48.5 79.0 .35 N 5.36 E 1.34 N 9.59 E 3.04 N 15.64 E 5.18 N 24.86 E 7.40 N 38.54 E 1100.0 11.31 84.33 1146.2 28.8 1200.0 12.44 81.36 1246.2 38.7 1300.0 14.79 71.21 1346.2 52.5 1400.0 16.87 61.62 1446.2 72.5 1500.0 17.41 56.86 1546.2 96.6 2.08 68.2 80.4 1.46 89.8 81.1 3.33 114.8 79.9 3.15 142.7 76.9 1.41 171.4 73.5 9.47 N 56.54 E 12.13 N 77.37 E 18.15 N 100.60 E 29.77 N 126.32 E 45.56 N 152.75 E 1600.0 18.55 52.24 1646.2 123.5 1700.0 20.27 46.40 1746.2 154.3 1800.0 22.13 41.38 1846.2 189.9 1900.0 25.98 35.69 1946.2 231.9 2000.0 28.75 32.74 2046.2 282.3 1.80 201.3 70.3 2.46 233.2 67.1 2.41 267.4 63.7 4.36 305.4 60.1 2.55 347.8 56.3 64.36 N 179.09 E 87.32 N 205.67 E 115.24 N 232.42 E 149.75 N 259.91 E 192.62 N 288.96 E A Gyr oda t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, MILNE POINT, Job Number: AK1295G313SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg. / 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 32.23 29.93 2146.2 340.5 2200.0 33.75 29.33 2246.2 405.0 2300.0 33.52 28.49 2346.2 470.9 2400.0 33.00 28.63 2446.2 535.9 2500.0 33.90 27.47 2546.2 601.1 .21 .34 .46 .56 .29 444.5 52.8 496.7 49.6 549.1 47.0 601.4 45.0 654.4 43.3 243.37 N 319.57 E 300.07 N 351.81 E 358.34 N 383.98' E 416.02 N 415.30 E 474.06 N 446.37 E 2600.0 33.84 27.58 2646.2 667.8 2700.0 33.40 28.21 2746.2 733.7 2800.0 34.03 28.47 2846.2 799.3 2900.0 36.70 27.62 2946.2 870.1 3000.0 36.95 27.39 3046.2 944.9 .15 .48 1.36 1.96 .91 762.1 41.8 815.9 40.7 870.9 39..7 928.8 38.8 1018.0 37.9 533.61 N 477.39 E 592.31 N 508.47 E' 650.56 N 540.00 E 713.53 N 573.50 E 780.51 N 608.05 E 3100.0 41.19 27.32 3146.2 1025.8 3200.0 44.69 27.38 3246.2 1118.6 3300.0 47.63 25.24 3346.2 1222.0 3400.0 52.42 24.06 3446.2 1341.9 3500.0 54.89 25.14 3546.2 1477.4 3.31 2.28 2.29 2.41 1.81 1081.5 37.1 1183.8 36.3 1291.6 35.5 1406.5 34.6 1526.1 33.7 852.99 N 645.06 E 935.75 N 688.37 E 1028.94 N 734.44 E 1138.43 .N 783.96 E 1262.02 N 840.10 E 3600.0 59.11 24.15 3646.2 1632.0 3700.0 63.86 22.38 3746.2 1815.0 3800.0 70.63 19.75 3846.2 2050.3 3900.0 69.78 20.15 3946.2 2335.6 4000.0 71.39 20.38 4046.2 2629.0 2.48 2.30 3 .33 2.10 .71 1693.1 32.8 1866.9 31.8 2093.9 30.6 2372.8 29.4 2653.6 28.3 1402.76 N 904.96 E 1571.70 N 975.68 E 1791.15 N 1060.59 E 2059.37 N 1157.97 E 2334.73 N 1259.21 E 4100.0 72.33 19.13 4146.2 2932.6 4200.0 71.70 18.33 4246.2 3247.5 4300.0 71.65 18.51 4346.2 3549.3 4400.0 71.40 18.75 4446.2 3849.8 4500.0 71.28 16.53 4546.2 4156.8 .38 .58 .70 1.28 1.78 3029.9 27.5 3312.5 26.6 3594.7 25.9 3877.4 25.4 4254.6 24.8 2620.65 N 2919.42 N 3206.04 N 3490.52 N 3783.06 N 1361.42 E 1461.60 E 1556.91 E 1654.34 E 1748.56 E A Gyro da t a D i r e c t i on a I Survey B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, MILNE POINT, ALASKA Job Number: AK1295G313SS Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4544.6 71.55 18.64 Final Station Closure: 4590.8 Distance: 4291.8 4301.81 ft 1.35 4301.8 24.6 Az: 24.59 deg. 391t.83 N 1789.74 E gyro/data' 4. QUALITY CONTROL SR313. DOC Quality Control Comparisons B.P. EXPLORATION WELL: L-PAD, MPL-21 Location: NABORS 22E, MILNE POINT, ALASKA Job Number : AK1295G313 / AK1295G313 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN OUTRUN Depth Inc Inc Delta Az Az Delta 1005.0 7.86 7.95 -.095 81.11 80.65 .467 2005.0 26.25 26.50 -.248 35.44 35.10 .342 3005.0 33.23 33.30 -.074 29.29 28.67 .611 3505.0 43.03 43.12 -.091 28.26 27.96 .300 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.1379 deg. Average Azimuth Difference = .41749 deg. gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK1295G313 TOOL NUMBER: 08O MAXIMUM GYRO TEMPERATURE: 72.98c MAXIMUM AMBIENT TEMPERATURE: 32.5 c MAXIMUM INCLINATION: 72.90 AVERAGE AZIMUTH: 24.59 WIRELINE REZERO VALUE: 5 feet REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: 11/18/95 CALIBRATION USED FOR FINAL SURVEY: 11/18/95 PRE JOB MASS BALANCE OFFSET CHECK: -.09 POST JOB MASS BALANCE OFFSET CHECK~: CONDITION OF SHOCK WATCHES -.16 USED -.16 UPON ARRIVAL AT RIG: uPON COMPLETION OF SURVEY: OK OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISONS: M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 7055 71.55 18.64 4590.8 3911.8N 1789.7E FINAL SURVEY 7055 71.55 18.64 4590.8 3911.83N 1789.74E SR313. DOC gyro/data SR313.DOC gyro/data FUNCTION TEST JOB NUMBER: AK1295G313 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ff 1 2 3 4 5 3500 43.03 43.03 43.03 43.03 43.03 AZIMUTH M.D. ft 1 2 3 4 5 3500 28.11 28.34 28.30 28.21 28.25 SR313.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR313.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK1295G313 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0098 DATA SECTION A0032 POWER SECTION A0027 COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0074 A0079 A0071 BACKUP TOOL No. 731 GYRO SECTION A0054 DATA SECTION A0025 POWER SECTION A0052 COMPUTER POWER SUPPLY PRINTER INTERFACE A0122 A0074 A0082 A0035 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 5/16 RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL: 17.5 feet MAXIMUM O.D.: 2.25 INCHES TOTAL WEIGHT OF TOOL: 190 Lbs SR313.DOC SURVEY F~OGRAM ****~***** COMP~4Y BF' WELL NAME NPL-21I LOCATION I HtLNE PT LOCATION 2 ALASKA MAGNETIC DECLINATION 27,6~ GRIg CONVERGENCE ANGLE 0,00 DATE: 08-DEC-95 WELL NUMBER 0 AF'I~ = ~ '~o~,- WE~k HEAD LOCATION: ~A~(~/-S) JOB NUMBER 3~4~1 AZIMUTH ~RQM ROTAE'~ TABLE ~0 TARGET IS .TIE IN POINT(TIP) : MEASURED DEFrH ~ 112,00 TRUE VERT DEPTH 112,00 INCLINATION 0,~ AZIMUTH 0,00 LATITUDE ,N/- S)0.00 DEPARTURE(E/-W) - 0,00 DEP(E/-W) 0,00 ************* Af,~DRILL ************** SURVEY CALCULATIONS ************* CIRCUL~ ~C METHOD******** MEA%~ED INTERVAL VERTICAL DEPTH i12,00 0,0 112,00 2,35,00 9~,0 205.00 u.,Ou 100,0 305.00 405,00 I~3.0 405.04 505,00 100,0 504.99 TARGET STATION AZIMUTH LATITUDE SECTION INCD4, N/-S ft deq Eeq ft 0,00 0.00 0,00 0,00 -0,03 0,14 123.54 -0.06 -O,~O 0.17 210,15 -0,26 -0,~5 0.44 96.32 -0.43 0,27 0,92 79,16 -0.32 DEPARTURE DISPLACEMENT at E/-W 0,00 0,04 0.09 0,11 0,12 0,29 0,43 0,61 1,60 1,63 AZIMUTH 0.04 123,54 154,74 135,00 101,33 DLS de9/ lOOft 0,00 0,15 0 0,53 0.52 605,00 705,00 805.00 905,00 100,0 704.90 IC~),O 604.76 100.0 904,45 104,0 1003,75 1,39 1.59 80.22 0,07 3,75 3,76 88.99 0,67 3,45 2.7i 75,74 0.88 7,41 7,47 83.20 1,13 6,60 3,30 71,97 2,36 12,44 12,66 79,~7 0,62 11,14 5,58 76,44 4,39 19,91 20,38 77,57 2,30 17,33 7,'W3 60,65 6,65 31,46 32,15 78,06 2,42 1105,00 1205,04 1305,00 1405,00 1505,00 100,0 1102,37 100,0 1200,43 100,0 1298,07 104,0 1394,76 100,0 1490~48 25,04 10.87 64,00 8.76 47.68 48~48 33,76 ll.&3 84,74 10.69 67,28 68,13 44,46 13,14 77,53 14.~ 88,59 89,70 60,86 16.47 ~.83 22.57 112,53 114,77 82.66 17.21 58,85 36,26 138.02 142,71 7?.59 80.97 60,97 78.66 75.28 2,99 0,95 ~,03 4,63 1,88 1605.00 * 1~05.00 1905,00 !$55.00 t~.0 1585,91 100.0 !680.84 104.0 i774.65 100,0 1867.79 50,0 1713,62 106,69 17,56 ~,44 52,47 133,30 19.tl 50,41 71,46 163.72 20,77 44,65 94,51 177+97 22,54 40,40 121.72 o~A~,.,,~o~24,64 37,23 137,32 163,11 171,34 72,17 1.08 188.15 201,26 69,20 2,21 213,23 233.23 66,10 2,57 238.11 267,42 62,92 2,36 250,63 285,79 61,~8 4,91 2005,00 2105,00 2305,00 2405,00 50,0 1756,72 1~,0 2047,30 i00,0 ~ ~- Zio~,5~ 100.0 2217.57 100,0 2300,73 =~7,78 n6.~u 35,i0 154,75 262,94 28,78 32,71 193,26 332,61 31~95 29,?9 236,45 386,18 33.77 29,59 283,53 441.11 33.72 28,86 332.01 263,35 305,45 59,56 4,15 289,20 347,83 56,25 2,53 315,44 394.22 53.15 3,45 342,39 444,55 50,37 1.83 369,51 496,76 46,06 0,41 ~05,gO ~705,00 £S05,00 2?05,00 t~.0 2384,08 100,0 2467,83 1~9.0 2551,29 i00.0 2634,25 1~,0 2717.47 ~-. ol 28.19 360.56 495,85 ~,~,., 549.78 32.88 28,78 426,58 604.60 33.97 ~.38 477.18 '660.05 33.91 ~7,51 526,73 71~.u~ 33,45 27.96 ~/J.o~ 395,?0 549.14 46,13 0,52 421,95 601,44 44.55 0,58 447,87 654,44 43.19 1,34 473,60 708.34 41.96 0.10 499,4i 762,22 40,94 ' ~,05,00 3055~00 3105,00 3i55,04 32G5,00 I00,0 2800.98 50,0 2842,62 50.0 2883.78 50.0 ~'~ ~¥~4,38 50.0 29~4.47 769,60 33,30 28,67 624,25 525.50 815,99 40,0? 0.42 797,01 33,91 28,50 6~,55 538,74 843,12 39,72 1,23 _ ~J,Z7 28.19 673,53 552,22- 870,97 39,35 2,74 654,09 36,14 27,69 699.31 565,89 899,59 38,96 1,84 883,7~ 37.17 27,56 725,75 579,73 928,87 38,62 3305,00 3355. 3405,00 o4JJ+VV 5~.0 3004.35 50,0 3044,29 50,0 3083,84 5 Q5,50 50,0 ~1~ .93,0 3160,~ '913,72 37.12 26.93 752.59 593,55 958,49 943.61 36,86 27,42 779,36 607.29 988,03 973.99 38.55 26.77 806,56 621,22 1018,08 1~5+51 40,16 26,9? 834,86 635.55 1047,25 1036,07 41.~ ~,51 844,01 650,57 1081,55 36,26 37.93 37,60 37,28 36,96 0.77 0,79 3,47 3,35 ft ft ft ft. deq. d.e.,: ft ft it deo lOOft 350580 SO& 3i'.:,'7,i4 i.''~.'~- ,Sa~ 43,i2 z.,",Y,5,~7..,.,.:""':: ap 866,,-'c. i~ ,,,:,:. . 3.555,00 _.. 50o0 , 2232,25. 1105,5'0_. 44,.41..~ ..... 27,54 ._ :. 924,4':/.. 662,26 ..... 1145',05 .... 3,43 .....2,64. · 3705.00 '50,0: 2,.~7o63 .. 1.21.2.84' .~ 47.20 25,50--. 1.020.65 730.42 ~' 12..55.05' 3755,00 50,0 3371,25 1249,5~ 46,91 24,46 1054,36 746,12 1291,66 35,26 3,75 3855,00 50,0 3434,69. 1327,06. 52,09 24,22 1124,60 777,76 13.5.7,57 34,6a 2,72 3~5,00 50,0 3465,11 1266,67 52,96-~ ~,79 1161,12 7~,90 1406,59 34,36 1,87 -,:-..,:c.:,... jj) :~jn^ c~.;s~,O 3495,03 i,~OA,A~,,,. .. 53,52 24,40 1197,69 6i0,7-5 1446,07_.: 34,08 ~.4'7.. ' (~!:: '415-5;O0~%iT;::'50;O-',?360&;-65!:?.1570;76~?'~::~:57,79~??:~:~-,.- -. ....33.14 2.62 4205,00 53,0' 3/:.,34,91 1613,20 58,85 24,84 1365,65 897,16 1650,74 32;92 2,14 4255,~0 .- 50,0 3660,55 1656,05 59.44 23,28 1424,65 914,66 1692,16 32,70 2,93 4305,00 ~,0 3~45,46 1699,36 60,75 22,56 1464,77 931,54 1735,89 32,45 2,90 · 4355,00 50,0 3709,54 1743,17 61,72 22,31 1505,26 948,26 1779,06 32,21 1,99 4405,03 5Q,O 3732,60 1767,51 63,34 22,26 15~$,32 '965,09 1622,78 31,97 3,24 ~55,00 50,0 3754,71 '1~2,34 64,19 22,44 1567,80 962,15 1867,01 31,74 1,72 4505,C~ 50,0 3775,9? 1877,57 4555,00 50,0 3796,46 1573,16 4605,00 ~,0 3815,92 196~,24 4705,00 100,0 3850,&9 2062,91 4605,00 100,0 3884,07 i157,23 65,42 21,62 1629,74 99~,13 1911,62 31,51 2,66 66,21 21,28 1672,19 i015.51 1956,55 31,26 1,71 68,03 20.96 1715.16 1032,41 2001,5'1 31,04 3,69 71,03 1~,56 1603,04 1064,63 ~094,00 30,57 3,27 70,21 19,69 1691,84 1096,67 2186,72 30,10 0,86 ::v...--~ ~005,00 iO0,O S947,65 5!05,00 lO0,n 3963,~ 2440 5305,00 100,0 ~wo,~ .- ....... · -a'a -; .'-. ,'" ~. '~ ..... ,c, F.' ~ ---.~. ' ' 07 +2,'q ~"j ~ 15 -'" ." 0 ",.~ 71,09 20,20 ~!57,62 1193,92 2465,92 28,96 72,04 'Z0,I0 '~'~ ~~.~.~,., ,..,,., '~ ii5-6 ,60 :_,_,. ,/1 _ ..AS,.._ , ~.....: ~'-Z,-Z'-> ~..' i .k.~....'.-' t. ,_: i.'-,-.'-' ..'.'.'i.' ;-'-'* :.' ..... 5505,00 5605,00 100.~0 4i40.A0 29i4,66 5705, O0 I00,0 ,~i ~:'. ........... 5605~00 !~,0 4200,i6 3i05,67 7i,?..?. t';;m :35 25i4:i'3 ~':'~'--'',__.__,:__. 7'2'20 19~26 '2e, OS .:i<3 i355,53 '.3'~'35,6:.'-! 27 .:5,;, 0,?_55 " .- ...... /.2,70 ~ o '~' 1~o6 ~, ,.-~,78 14!6,74 3i24,44 "-'" '" 5905,00 100,0 4230,73 4=6~,14 6C05,00 I~X),O ~ ~ 3295,66 6i05,00 100,0 4293,34 6205,~J 1¢~),0 43,24,87 3485,42 6305,00 100,0 4356,50 3560,2! 71,70 i8,41 2875,13 1446,77 3216,62 26,71 i,O0 71.69 18,25 2965,25 1476,62 3312,58 26,47 0,15 71,95 16,56 3055,40 1506,63 3406,67 26,25 0,39 71,29 18,21 3!45,45 1536.56 3500,70 26,04 0,74 71,83 18,65 3235.45 !566,55 3594,75 25,54 0,68 SUF~Ff CALCULflTIONS ~*~**~ CIRCUL~ ARC MEASURED INTEM~AL VERTICAL DEPTH DEPTH 6405,00 100,0 4388,34 6505,00 100,0 4419.61 .%05,00 100,0 4451,1i 6705,6~ i~3,0 4481,89 6805.00 100.0 4512.15 TARGET STATION AZIMUTH LASSITUDE SECTION INCLN, N/zS ft d. eq - 6eq ft 3674+95 71,03 18,87 3325.21 3769.~3 72,29 19.37 3414.89 38~4,76 71,23 18,64 3504,69 3959,62 72,~ 17.79 35?5.06 4055,02 71,85 16,11 3685,73 DEPARTURE DISPLACEMENT at AZIMUTH E/-W it ft deg 1597.04 3688.54 25.65 1628,13 3783.16 25.49 1659,06 ~577,54 25,33 1688.80 3971.96 25.16 171(3.17 406..4,54 24.99 ~S cte9/ lOOft 0.83 1 1,27 1.87 6905.6~ 7005,00 7055,00 7i33,84 7197,57 100.0 4543.83 !00,0 4575.Z7 50.0 4590,85 78,8 4~15.31 63.7 4.~4.8z 4149.69 71.21 !6.39 3776.31 4244.46 72,14 18,29 3866,92 429t.93 71.SS 18+64 3911,98 42.66.82 72.30 18,50 ~83.02 4427,46 72,06 19,03 4040,47 1746,30 4160.54 24,82 1,75 1774,59 4254+67 24,65 2,03 1769,64 -4301.91 24,58 1,35 1813,50 4376,45 24.48 0,96 1833,02 4436.62 24,40 0,87 7397+I5 /~.1.4~ 7~.03 7682.41 7774.59 199,6 4697,20 94.3 4727,63 96,6 4759,82 94.4 4790,47 92.2 4819,48 4616,67 71,52 15,47 4221,49 4705.69 70,~2 18,03 4306,93 4796,73 70,26 20,65 4392,87 4886,00 71,85 21.72 4476.11 4973.49 71,46 20,75 4557,66 1889,23 4624.95 24,11 1,71 1914,94 4713,46 23.97 2.67 1945.09 4804,24 23,88 2,62 1977.35 4893.41 23.83 2,00 2009,04 4960,82 23,79 1.08 7~6,~ 7963.66 8058.54 6153.03 8247.82 91.6 4646.68 97.4 4680;i6 94.9 4911.~$ 94.5 4942,71 94.8 4973.77 5060,34 71.37 19,83 4639,12 5152.45 70.91 16.73 4726,66 · 5241,95 70,72 19,06 4611,93 5331,07 70,53 20,31 4895,85 5420.62 71.21 19.57 49~D.04 2039,16 5067,51 23,73 0,96 20~,06 5159,29 23,63 3,04 2095,63 5248,46 23,53 2,34 2125.67 5337.40 23,47 1,24 ~4~/ ~ ~lJo,~v 5426,78 23,41 1.03 &343.65 6439.~ 8531.46 ~7~1,91 95.8 5004.39 '~.6 5034.93 92.2 5064.02 94.8 5093.67 95.7 5124,23 551!,42 v ~ .1.5~ 19,84 5065,J~ ~ 5601.97 71.21 20.38 5159.57 ~9,49 72.01 22.15 5232,13 5779.48 71.53 ~,03 5315,54 a70.OJ 71.22 24,27 5398,90 2186.82 5517.40 23.35 0.42 2217,95 5607.83 23,30 0,63 2249,70 5695,29 23.27 2,02 2283,56 5785,30 23.25 0,52 2319,20 5575,95 23.25 2.25 89C~,75 9¢94.61 9098.42 9!~3.72 92+0 5154,28 95,9 5185.49 94.9 5216,13 93.8 5245.99 ?5,3 5275.81 5956,79 70,63 24.39 5478,09 6C~7.25 71.38 24.46 5560,63 6136.88 70,92 ~,47 5642.67 6225,70 71,96 23,58 5724,21 6316,11 71.~ 22,47 5607,21 2355.01 5962,84 23.26 0,65 2392.49 6053,48 23.28 0.78 2428.95 6143,25 23,29 1,10 2464,45 6232.16 23.29 1.11 2500,58 6322,70 23,30 0,42 9~88..66 9383.60 9479.85 9595,29 9690,40 9785.~ 9~0,55 9974.74 10066.79 10163~22 94.9 5305.64 95.1 5~5.62 96.0 53~..04 ,1~.4 5402.11 95,1 5432,85 95,1 54&3.48 95,0 5493,75 94.2 5524,70 94,0 5555,61 94.4 5585.16 6406,20 71,81 20,73 5690,71 6496,42 71,18 20,29 5975,21 6567,59 72.15 20,83 6060,57 6697,25 71,44 20,76 6163,09 6787.~ 70.85 19,59 6247,57 4a77 ~q 71,60 ZO,¥~ 6332+08 6967.2~ 71,25 19,96 6416,46 7056,34 70,?, 20.71 6499,88 7145.i6 71.24 19,92 6583,17 .7Z~4,~4 72,30 20.20 6667,42 2534,48 6412,80 23,28 2,76 2566,09 6502.92 23.24 0,79 2598,11 6593.99 22,20 1,13 2637,04 6703,55 23,16 0.62 2&~8.07 6793.44 23.13 1,32 2699,26 6~83.41 23.09 1.55 2730,71 6973,36 23.05 1,03 2761,63 7062.22 23,02 1,18 2792,47 7150.95 22.99 1.20 2823,24 7240,52 22,95 1,16 M, .1I SURVEY CALCULATIONS ****~*******. CIRC~nAR ARC METHOD******** M~ASUR~I) INT~;AL V~RTICAL DEPTH DEPTH I0254,b~ 91,4 56!3,31 10445.22 94,9 5674,26 10539,35 94,i 5704.~0 i063~.73 -99.4 5736,94 TARGET STATION AZIMUTH LATITUDE SECTION INC~, N/-S ft deg deg. it 7321.76 71,82 19,23 6749.25 .o 4I~,5~ 71,12 18,79 6835,10 7502,31 71,34 20.30 6919.73 7591,2.5 70,60 21,02 7003,04 7665,39 71,47 21,02 7090,83 DEPARTUR~ DISPLACEM~N? at AZIMUTH E/-W ft it Oeg 2852.56 7327,31 22,91 2662,15 7417,90 2~.56 2912.20 7507,56 22,82 2943,61 7596.54 22,~0 2977,34 7690,54 22,76 lO0'ft 1.13 0,~5 1,52 0.92 0,68 1v, ol, 10625+65 1~'t9,26 I1011.71 11107,49 ,.,4 5766,49 94,5 5796.62 93,6 5826.60 92,5 ~v ~g 95,~ 5889,16 7772,92 71,22 19,51 7172.94 7662,51 71,61 21,99 7o~ 7~ 7951,i8 71,04 21,29 7339,15 8036,36 70,09 21,76 7420,25 8128,68 71,12 21,31 7504,29 3~)7,67 7777,99 22,75 1,57 3039.41 7867,53 22,73 2,51 3072,11 7956,20 22,71 0,94 3104,10 ~043,36 22,70 1,13 3137,26 8133,68 22,69 1,16 11201.02 !t297,!0 i1392.6~ 114~5,91 11581.67 ~,S 5919.'99 96,1 5951.56 95,5 5982.76 93,3 6013,10 96,0 6044,10 ~1..,96 70,39 ,49 75~,50 B307,72 71,21 20,77 7671,!4 8396,00 70,66 20,59 //~a,61 6466.22 71.37 20.75 7836.15 8577.03 70,93 21.11 7922,96 3169,46 6221,96 22,67 0,60 3202,19 8312.67 22,66 1,11 3234.07 6402,69 22,64 0,58 3265,21 8491.07 22,62 0.75 3297.66 8581.84 22,60 0,58 i1676.i5 11771.94 11666.20 11960,30 12052.35 94.3 6074.53 95.6 6105.51 94.3 6137.90 94.1 6173.29 92,0 6211.24 &~66,26 71,42 21,10 8006,21 6756,91 70,64 20,94 6090,83 6645.42. 66.96 20.13 6173.71 6932,59 66.65 19.19 6255,82 9016,38 64,45 17,80 8335,33 3329,60 8671,04 22,56 0,51 3362,31 6761,65 22,57 0.62 3393,35 6650,11 22,55 2,15 3422,69 6937,19 22.52 2,42 3449,29 9020.83 22,46 2,95 12147.46 122C~,41 12336,09 I243!.!1 95.1 6~4.02 92.0 6296,29 96,7 6~6,6.3 95,0 6396,02 92,6 6446.65 9101.24 62,09 18,72 64i6,00 9181,77 69,o5~ ~ 18,01 8492,49 9265.37 59.64 17.12 6572,31 9346.43 57,72 16,20 9424.09 56,11 18,66 6723,35 ~75,90 9105,54 22,44 3501,29 9185,93 22.41 3526,56 9269,37 22,36 3551.16 9350.26 22.32 3575.87 9427.81 22,29 '2,62 2,01 1,09 2,24 1,63 12617.74 I~11.63 12~07.29 12901,56 12997.60 93,9 6556.36 95,7 6615.93 94.3 6676,79 96,0 6740.76 9~K)I.12 54,24 19,67 6796,09 9576.40 52,37 20.36 ~66,B2 965i.24 50.59 20,44 8936,96 9723,22 49,00 21,49 9004,16 9794.64 47,45 21.19 9070,89 3601,29 9504.76 22,27 3627.07 9579.9B 22,25 3653.17 9654.76 22.23 3678,92 9726,75 22,22 3704,99 9796,37 22,22 2,12 2.06 1,69 13090,72 mi ~,t..ql 13279,70 1.~73,1B 13465,76 ,'q l y~,. 6604,66 94.1 68,,,11 94,9 6941,67 93,5 701i,62 9862,37 45,52 21.01 9123.90 972&,18 43,26 21,5& 9195,21 9992.50 42,i0 ~ ~o ~1,,, 9255,00 10~4,72 4i.38 20,13 ~13,12 10114,99 39.64 21.93 9369.36 3729.30 9865,69 22,21 2,08 3753.19 9931,67 22,20 2,44 3776,93 9996,Q1 22,20 1,22 3799,16 10058,22 22,19 1,37 3820.78 1011&.48 22,19 2.08 13561.39 13691,03 13679.74 95.6 7155.70 93.9 72~8.63 35.& 7256,69 94,6 7332.31 94,1 7409,04 10175.78 39,14 21,69 9425,&3 10234,64 38.52 19.95 94&4,B4 10256.62 ~,12 2t.31 9501,60 10313,90 36.13 20.92 9554.65 10556,40 34,64 21.21 9605.71 3643.37 10179.29 22,18 3864.30 10238.12 22.18 3872,11 10260.29 22.17 3892.66 10317.37 22,17 3912,27 10371.&6 22,16 0,75 1,34 2,61 2,12 1,5'? ~:P~ CALCULATI~qS MEASURED INTERVAL VERTICAL D~F'~H DEPTH ft ft ft 13974,87 95,1 7488.!4 14019,50 44.6 7525.87 14155.~ 135.5 7643,27 TA~ET STATION AZIMUTH LATITUDE DEPARTURE DISPLACEMENT at AZIMUTH DLS S~CTIOH INCLN, N/-S E/-W de9/ T~ deg deg ft Tt fz deg 10orr 10421.24 ~,85 21.10 ?654,99 3931.34 10424.70 22.16 1.88 10445,07 31.69 21.91 9677,16 3940,07 10448.52' 22,~5 2.77 ***** PROJECTION TO TD 10512.68 28,20 21,90 97~,91 3965.30 10516,15 22,15 2,58 SP~.~<RY-SUN DRILLING SERVICES ANCHORAGE ALJ~S ~ PAGE SH3~RED SERVICES DRILLING MILNE PT/MPL-21I 500292262900 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/27/95 DATE OF SURVEY:. 122295 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50128 KELLY BUSHING ELEV. = 46.20 FT. OPERATOR: BP EXPLOP~ATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7055 4590.85 4544.65 71 33 7339 4680.09 4633.89 71 53 7435 4710.27 4664.07 71 19 7530 4740.66 4694.46 71 27 7626 4771.74 4725.54 70 39 N 18.64 E .00 3911.98N 1789.64E N 19.11 E .20 4167.63N 1877.05E N 18.83 E .66 4253.48N 1906.55E N 18.99 E .21 4338.87N 1935.80E N 20.21 E 1.48 4424.19N 1966.18E 4291.93 4561.98 4652.71 4742.93 4833.48 7721 4802.31 4756.11 72 4 7817 4831.99 4785.79 71 42 7912 4862.12 4815.92 71 29 8008 4893.03 4846.83 70 44 8103 4924.17 4877.97 71 1 N 20.17 E 1.48 4509.23N 1997.46E N 19.95 E .43 4594.49N 2028.60E N 19.43 E .57 4679.76N 2059.12E N 18.58 E 1.15 4765.20N 2088.55E N 20.42 E 1.85 4849.90N 2118.55E 4924.09 5014.85 5105.41 5195.73 5285.57 8198 4955.66 4909.46 70 18 8293 4986.76 4940.56 71 19 8388 5016.98 4970.78 71 41 8484 5047.42 5001.22 71 10 8579 5077.60 5031.40 71 58 N 19.99 E .87 4934.13N 2149.55E N 20.16 E 1.09 5018.13N 2180.24E N 21.35 E 1.25 5102.61N 2212.25E N 21.25 E .54 5187.05N 2245.17E N 22.92 E 1.85 5271.01N 2279.24E 5375.32 5464.74 5555.09 5645.72 5736.29 8675 5107.51 5061.31. 71 34 8770 5137.97 5091.77 71 15 8866 5169.15 5122.95 70 39 8961 5200.05 5153.85 71 34 9057 5231.04 5184.84 70 41 N 23.01 E .42 5354.66N 2314.69E N 24.61 E 1.62 5437.56N 2351.27E N 24.06 E .83 5519.90N 2388.51E N 24.11 E .95 5602.38N 2425.38E N 23.64 E 1.03 5685.29N 2462.09E 5827.07 5917.56 6007.74 6097.92 6188.46 9152 5261.34 5215.14 72 9 9248 5291.32 5245.12 71 17 9343 5321.25 5275.05 71 51 9439 5351.74 5305.54 70 59 9534 5381.71 5335.51 72 13 N 24.00 E 1.59 5767.81N 2498.52E N 23.45 E 1.06 5850.95N 2535.06E N 21.58 E 1.97 5933.97N 2569.47E N 20.89 E 1.14 6018.54N 2602.33E N 21.30 E 1.37 6102.64N 2634.78E 6278.52 6369.21 6459.03 6549.76 6639.90 9629 5411.44 5365.24 71 25 9724 5442.24 5396.04 70 51 9819 5472.70 5426.50 71 51 9914 5503.12 5456.92 70 37 10009 5535.04 5488.84 70 22 N 20.66 E 1.06 6187.19N 2667.19E N 20.46 E .63 6271.64N 2698.86E N 20.90 E 1.14 6356.11N 2730.75E N 27.35 E 6.59 6437.75N 2767.29E N 20.04 E 7.22 6520.11N 2803.43E 6730.45 6820.64 6910.93 7000.21 7090.03 10105 5566.26 5520.06 71 23 10197 5594.93 5548.73 72 30 10290 5623.41 5577.21 71 48 10386 5653.78 5607.58 71 3 10481 5684.42 5638.22 71 30 N 20.29 E 1.09 6604.66N 2834.48E N 20.70 E 1.28 6687.05N 2865.28E N 20.60 E .77 6769.81N 2896.47E N 20.36 E .82 6854.48N 2928.09E N 21.47 E 1.20 6938.97N 2960.38E 7180.10 7268.06 7356.50 7446.88 7537.33 Date_ / SP~,{RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPL-21I 500292262900 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/27/95 DATE OF SURVEY: 122295 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50128 KELLY BUSHING ELEV. = 46.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10576 5715.10 5668.90 10638 5735.16 5688.96 10671 5745.52 5699.31 10766 5775.65 5729.45 10859 5805.20 5759.00 70 43 71 33 71 53 71 11 71 45 N 21.02 E .94 7022.60N 2992.89E N 21.58 E 1.57 7077.34N 3014.23E N 21.66 E 1.03 7106.47N 3025.78E N 21.30 E .82 7190.45N 3058.83E N 22.48 E 1.35 7272.24N 3091.70E 7627.05 7685.80 7717.13 7807.37 7895.50 10954 5835.59 5789.39 70 48 11049 5867.48 5821.28 69 56 11141 5898.13 5851.93 71 14 11236 5929.63 5883.43 70 12 11331 5960.77 5914.57 71 28 N 22.12 E 1.07 7355.22N 3125.73E N 21.96 E .92 7438.13N 3159.29E N 22.15 E 1.42 7518.77N 3191.96E N 21.93 E 1.10 7602.26N 3225.77E N 21.69 E 1.36 7685.48N 3259.07E 7985.15 8074.57 8161.56 8251.60 8341.22 11425 5991.28 5945.08 70 28 11520 6022.09 5975.89 71 41 11615 6052.51 6006.31 70 57 11676 6072.21 6026.01 71 30 11710 6083.01 6036.81 71 26 N 21.36 E 1.12 7767.82N 3291.55E N 21.62 E 1.29 7851.47N 3324.49E N 21.46 E .79 7935.14N 3357.52E N 21.32 E .93 7989.12N 3378.67E N 21.28 E .25 8019.15N 3390.38E 8429.73 8519.62 8609.56 8667.53 8699.77 11805 6113.74 6067.54 11899 6146.03 6099.83 11992 6181.43 6135.23 12087 6221.07 6174.87 12181 6263.70 6217.50 70 48 68 44 66 29 64 8 62 1 N 20.92 E .75 8103.00N 3422.74E N 20.51 E 2.25 8184.98N 3453.75E N 19.41 E 2.67 8265.77N 3483.10E N 18.81 E 2.54 8347.27N 3511.34E N 18.38 E 2.28 8426.86N 3538.12E 8789.63 8877.29 8963.24 9049.46 9133.38 12276 6309.88 6263.68 12376 6360.17 6313.97 12464 6406.19 6359.99 12558 6457.63 6411.43 12651 6511.19 6464.99 60 1 59 31 57 25 55 53 53 58 N 18.23 E 2.11 8506.03N 3564.32E N 17.70 E .68 8588.13N 3590.94E N 18.35 E 2.46 8659.48N 3614.15E N 19.46 E 1.91 8733.46N 3639.48E N 20.51 E 2.25 8805.19N 3665.56E 9216.70 9302.91 9377.86 9456.02 9532.33 12747 6568.66 6522.46 12841 6627.85 6581.65 12937 6690.15 6643.95 13031 6753.21 6707.01 13126 6819.16 6772.96 52 7 50 22 48 36 ~ 47 12 45 16 N 21.22 E 2.04 8876.58N 3692.77E N 21.15 E 1.84 8945.33N 3719.41E N 22.62 E 2.18 9013.02N 3746.58E N 21.04 E 1.94 9077.82N 3772.55E N 20.99 E 2.03 9142.12N 3797.25E 9608.73 9682.46 9755.38 9825.19 9894.06 13219 6885.91 6839.71 13312 6954.52 6908.32 13406 7024.42 6978.22 13502 7097.27 7051.07 13595 7169.87 7123.67 42 53 42 0 41 14 39 28 38 55 N 21.72 E 2.63 9202.33N N 21.47 E .96 9260.68N N 20.76 E .95 9318.62N N 22.27 E 2.11 9376.23N N 21.89 E .64 9431.11N 3820.78E 9958.70 3843.88E 10021.45 3866.25E 10083.56 3888.94E 10145.47 3911.20E 10204.67 SP~-,~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MILNE PT/MPL-21I 500292262900 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/27/95 DATE OF SURVEY: 122295 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50128 KELLY BUSHING ELEV. = 46.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 13691 7244.44 7198.24 38 7 N 21.31 E .93 13785 7319.85 7273.65 36 7 N 20.92 E 2.11 13879 7396.57 7350.37 34 38 N 21.21 E 1.60 13974 7475.67 7429.47 32 50 N 21.10 E 1.88 14019 7513.40 7467.20 31 41 N 21.91 E 2.78 9486.30N 3933.06E 10264.03 9539.55N 3953.62E 10321.11 9590.41N 3973.20E 10375.60 9639.68N 3992.27E 10428.43 9661.85N 4001.00E 10452.26 14155 7628.70 7582.50 31 41 N 21.91 E .00 9727.89N 4027.57E 10523.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 10528.68 FEET AT NORTH 22 DEG. 29 MIN. EAST AT MD = 14155 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 20.68 DEG. TIE IN POINT 7055' INTERPOLATED DEPTH 14155' - SPL ~XY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPL-21I 500292262900 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/27/95 DATE OF SURVEY: 122295 JOB NUMBER: AK-EI-50128 KELLY BUSHING ELEV. = 46.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION ~7055 4590.85 4544.65 3911.98 N 1789.64 E 2464.15 8055 4908.43 4862.23 4806.99 N 2102.60 E 3146.57 9055 5230.12 5183.92 5682.90 N 2461.04 E 3824.88 10055 5550.17 5503.97 6559.97 N 2817.97 E 4504.83 11055 5869.44 5823.24 7443.11 N 3161.30 E 5185.56 682.42 678.31 679.95 680.73 12055 6207.09 6160.89 8319.96 N 3502.04 E 5847.91 13055 6769.11 6722.91 9093.86 N 3778.72 E 6285.89 14055 7543.61 7497.41 9679.15 N 4007.96 E 6511.39 14155 7628.70 7582.50 9727.89 N 4027.57 E 6526.30 662.35 437.98 225.50 14.91 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ~ SS. .RY-SUN DRILLING SERVICES ANCHO/LAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPL-21I 500292262900 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/27/95 DATE OF SURVEY: 122295 JOB NUMBER: AK-EI-50128 KELLY BUSHING ELEV. = 46.20 FT. OPERATOR: BP EXPLOKATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 7055 4590.85 4544.65 3911.98 N 1789.64 E 2464.15 7230 4646.20 4600.00 4069.70 N 1843.11 E 2584.29 7547 4746.20 4700.00 4354.49 N 1941.18 E 2801.67 7862 4846.20 4800.00 4634.87 N 2043.22 E 3016.37 120.15 217.38 214.70 8170 4946.20 4900.00 4909.29 N 2140.51 E 3224.26 8480 5046.20 5000.00 5183.73 N 2243.88 E 3434.12 8796 5146.20 5100.00 5459.62 N 2361.38 E 3650.28 9103 5246.20 5200.00 5725.25 N 2479.60 E 3857.76 9422 5346.20 5300.00 6003.51 N 2596.60 E 4075.82 207.88 209.86 216.15 207.49 218.06 9736 5446.20 5400.00 6282.32 N 2702.85 E 4290.51 10043 5546.20 5500.00 6549.52 N 2814.15 E 4496.99 10362 5646.20 5600.00 6833.79 N 2920.41 E 4716.54 10673 5746.20 5700.00 7108.41 N 3026.55 E 4927.50 10986 5846.20 5800.00 7383.46 N 3137.21 E 5140.40 214.70 206.47 219.55 210.96 212.90 11286 5946.20 5900.00 7645.36 N 3243.09 E 5340.08 11596 6046.20 6000.00 7918.14 N 3350.84 E 5549.97 11899 6146.20 6100.00 8185.40 N 3453.91 E 5753.41 12143 6246.20 6200.00 8395.58 N 3527.73 E 5897.73 12348 6346.20 6300.00 8565.52 N 3583.72 E 6002.74 199.68 209.89 203.44 144.32 105.01 12537 6446.20 6400.00 8717.54 N 3633.86 E 6091.54 12710 6546.20 6500.00 8849.62 N 3682.31 E 6164.18 12870 6646.20 6600.00 8966.01 N 3727.41 E 6224.14 13021 6746.20 6700.00 9070.75 N 3769.83 E 6275.07 13165 6846.20 6800.00 9167.57 N 3807.02 E 6319.16 88.80 72.64 59.96 50.93 44.09 13301 6946.20 6900.00 9253.70 N 3841.13 E 6355.49 13435 7046.20 7000.00 9336.48 N 3873.02 E 6389.17 13565 7146.20 7100.00 9413.37 N 3904.07 E 6419.09 13693 7246.20 7200.00 9487.59 N 3933.56 E 6447.07 13818 7346.20 7300.00 9557.51 N 3960.49 E 6472.04 36.33 33.68 29.92 27.98 24.97 13939 7446.20 7400.00 9621.93 N 3985.42 E 6493.59 14058 7546.20 7500.00 9680.64 N 4008.56 E 6511.84 14155 7628.70 7582.50 9727.89 N 4027.57 E 6526.30 21.55 18.25 14.46 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518- 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) May 31, 1996 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD CDR/CDN,CDR/CDN TVD for well MPL-21, Job # 96009, was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 :~- 1 OH LIS Tape 3 Bluelines 1 Film State--~'~laska / -~l~ska Oil & Gas Conservation ttn: Howard Okland ,,..,3001 Porcupine Drive .~n..chorage, AK 99501 1 OH LIS Tape I Blueline 1 RFolded Sepia OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail Z 777 937 424 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson l~.kvd,~ Anchorage, Date Delivered: Alaska 0ii & g,~ uo;,~;. Commission ~-~chorage Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by: /~ / LARRY GRANT Attn. ALAS:~% OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE AN C..O. L%G~ AK, 99501. Date: 15 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION · ' ' ~/~ ~ Run MPL-21-- .',--dJ---/~/ ,-.~ -- ::~)2 J~ 1 LDWG TAPE+LiS ;~r/~/%' Run 1 ECC No. 6500.01 6661.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ) 563-7803 Received by: f 2 1 1996 Date: AlasKa 0it & Gas Cons. 6orrrm~mon LARRY GRANT Attn. ALASKA OIL + GAS CONSERVA?!C?i 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 26 ~D~ii 1596 RE: Transmittal of ~a Sent by: HAND DELIVERY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ n~qmmTmmTON i ?FC/PERF FINAL BL~AF i GR/CCL FINAL BL+RF _~SBT FINAL BL+RF ~-' o~ FINAL ~£ .~S BL+RF '~I~ PFC/PERF FINAL BL+RF MPL- 21 ~ GR/CCL FINAL BL+RF R~ri ~ i 6644.01 Run # 1 6658.01 Run # 1 Run " ~ Run # 1 Run # 1 6661.00 6661.01 Please sign and return to: Asmn. Rodney D. Paulson Western Atlas Logging Services ~0 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 ~ ..." / Date: Received by: · - ALASKA OIL AND GAS CONSERYATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 4, 1995 .: Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well Name Company Permit # Surf Loc Btmhole Loc Miine Point Unit MPL-21i BP Exploration (Alaska), Inc. 95-191 3687'NSL, 5070'WEL, Sec 08, T13N, R10E, UM 2922'NSL, 1040'WEL, Sec 32, T14N, R10E, UM Dear Mr Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission's petroleum field inspector on the NoAh Slope pager at 659-3607. David W Jol~nston Chairman ~, BY ORDER OF THE COMMISSION ijb/encl c: Dept of Fish & Game, Habitat Sect - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 .. Type of work Drill [] Redrill EIIlb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 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 RTE = 46 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. O, Box 196612, Anchorage, Alaska 99519-6612 ADL 355017 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 3687' NSL, 5070' WEL, SEC. 08, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2673' NSL, 1135' WEL, SEC. 32, T14N, RIOE MPL-21i 2S100302630-277 At total depth 9. Approximate spud date Amount 2922' NSL, 1040' WEL, SEC. 32, T14N, RIOE 12/05/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (uD and TV[:)) property line ADL025509 2922 feet No CloseApproach feet 4480 14168'MD/7571'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (.*ee 20 ^AC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole anglez~.o3 o Maximum sudace 3301 psig At tolal depth (TVD) 7000'/3998 psig 18. Casing program ' Setting Depth s~ze Specifications 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.) 12-1/4" 9-5/8" 40# L-80 BTRC 7219' 31' 31' 7250' 4647' 1396 sx PF 'E', 250 sx 'G', 150 PF 'E' 8-1/2" 7" 26# L-80 BTRC 14138' 30' 30' 14168' 7617' 231 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ...... ConductorRECblVED Surface Intermediate ~0V 2 9 Production ......... ..--. - -.~.~ Liner Perforation depth: measured ~ 041& Gas Cms. 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[] 21. I hereby certify_..t, hat the foregoing ibltrue and correct to the best of my knowledge Signed ~ ~~/~~/ .~/ il Title Senior Drillin~l Engineer Datel/ZT'/~ ,~ Commission Use Only / Permi, L, Number IAPI number IApproval,date¢ ISee cover letter ;¢:-/,?? - I If°r other requirements Conditions of approval Samples required [] Yes [] No Mud log rbqu~red []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BCtRl~irl~.lYike~i~M;,.,., ,.,. ,.,.~. ,, ~,. 1~SM; FIIOM; E]lSM; Other: by order of Approved by David W. Johnston Commissioner me commission Date,/ Form 10-401 Rev. 12-1-85 Submit ,'ate I Well Name: IMP L-21i I Well Plan Summary IType of Well (producer or injector). IKuparuk Injector ISurface Location: Target Location: Bottom Hole Location' 3687 NSL 5070 WEL Sec 08 T13N R10E UM., AK 2673 NSL 1135 WEL Sec 32 T14N R10E UM., AK 2922 NSL 1040 WEL Sec 32 T14N R10E UM., AK I AFE Number: 1337001 I Rig: I Nabors 22-E ' Formation Markers: · Formation Tops MD TVD (bkb) base permafrost 1,878 1,846 NA 6,32 4 4,34 6 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 7,094 4,596 Base of Schrader Bluff Sands (8.3 ppg) HRZ 1 3,1 98 6,8 76 High Resistivity Zone Top Kuparuk 13,489 7,096 Kuparuk Cap Rock Target Sand -Target 1 3,75 4 7,2 99 Target Sand (9.6 ppg) Total Depth 14,168 7,617 Casing/Tubing Pro ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 7,219 31/31 7,250,4,647 8 1/2" 7" 26# L-80 btrc 14,138 30/30 14168/7617 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3998 psi is 3301 psi, well below the internal yield pressure rating of the 7" casing. Logging Program, Open Hole Logs: Surface MWD Directional and LWD GR/RES Intermediate N/A Final Cased Hole Logs: MWD Directional and LWD (GR/CDR/CDN). Mudloggers are NOT required for this well. Nlud Program: Special design I None- SPUD MUD considerations I Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 1 00 1 5 8 1 0 9 8 to to to to to to to 9.0 50 35 I 5 30 1 0 1 5 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6 - 8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I oP: 150o' IMaximum Hole Angle: Close Approach Well: 171'°3° (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Request to AOGCC for Annular Pumping Approval for MP L-21i: 1. Approval is requested for Annular Pumping into the MP L-21i, 9-5/8" x 7" casing annulus. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 7,250 md (4,647 tvd) which is a minimum of 500' tvd below the Permafrost and into the Prince Creek formation which has a long established history of annular pumping at Milne Point. The burst rating (80%) for the 9-5/8" 40# LB0 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Prince Creek formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping regardless of fluid density is 2000 psi as per Shared Services Drilling "Recommended Cuttings Injection Procedure". A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. . . . ~INULAR INJECTION: /'HE FOLLOWING WELLS HAVE BEEN PERMITTED FOR ANNULAR INJECTION FOR 1995 AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Milne Point MPJ-13 4070 0 1JAN95-31DEC95 Milne Point MP L-14 0 35000 1JAN95-31DEC95 Milne Point MP L-15 0 35000 1JAN95-31DEC95 Milne Point MP L-16i 0 35000 1JAN95-31DEC95 Milne Point MP L-17 16026 35000 1JAN95-31DEC95 Milne Point MP L-24i 225 35000 1JAN95-31DEC95 Milne Point MP L-29i 0 35000 1JAN95-31DEC95 Milne Point MP L-25i 0 35000 1JAN95-31DEC95 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MAXIMUM EXPECTED FLUID DENSITY IS 17.0 PPG BURTST PRESSURE 9-5/8" 40# L-80 CASING: 5750 PSI COLLAPSE 7", 26#, L-80 CASING: 5410 PSI 9-5/8" SURFACE CASING SHOE DEPTH: 7,250' MD/4,647' TVD HYDROSTATIC PRESSURE @ 4,647 TVD WITH VARIOUS DENSITY FLUIDS: (0.052) X (4708) X (FLUID DENSITY) = HYDROSTATIC PRESSURE 80% OF 7' COLLAPSE PRESSURE = (5410 PSI) X (0.8) = 4328 PSI MAXIMUM ALLOWABLE INJECTION PRESSURE 2000 PSI AT ANY PPG MAXIMUM ALLOWABLE HYDROSTATIC 7" COLLAPSE ANNULAR INJECTION FLUID DENSITY PRESSURE AT 4708' TVD PRESSURE (80%) PRESSURE (PPG) (PSI) (PSI) (PSI) 8 1933.15 4328 2000 9 2174.80 4328 2000 1 0 2416.44 4328 1 912 1 1 2658.08 4328 1670 1 2 2899.73 4328 1428 1 3 31 41.37 4328 1 187 1 4 3383.02 4328 945 1 5 3624.66 4328 703 1 6 3866.30 4328 462 1 7 4107.95 4328 220 MAX ALLOWABLE INJECTION PRESSURE = 4328 PSI - HYDROSTATIC PRESSURE or 2000 psi (whichever is less). MP L-21i Proposed Summary of Operations , . , , . , , . . 10. 11. 12. 13. 14. Drill and Set 20" Conductor. Weld a starling head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan and run and cement 9-5/8" casing. Run only Dir MWD. ND 20" Diverter, NU and Test 13-5/8" BOPE. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 10' of new formation. Perform FIT to 12.5 ppg. Drill 8.5" hole to TD as per directional plan. Run and Cement 7" Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. Perforate and Stimulate in absence of rig. Displace well with 10.2 ppg brine and set a wireline retrievable bridge plug. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. Complete well with 3-1/2" tubing and packer hookup. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: 1. The Kuparuk reservoir sands are expected to be a maximum of 3500 psig or 9.6 ppg. 2. See the Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for a general recap of the original13 wells drilled by Conoco on L-Pad plus the L- 14 and L-15 wells recently drilled by BPX. Review the drilling of Milne Pt. Well# L-25i which the rig should just be coming off of. 3. There will be a close approach with Milne Pt. Well# L-29i requiring the plugging of L-29i. L-29i is currently plugged and is to remain plugged during the drilling of Miine Pt. Well# L-21i. 4. Surface casing will be deep set across the Scrader Bluff this well due to the high step out (+10,500' Departure). It is important that we drill the hole with minimum doglegs, concentrating on maintaining a low solids mud, and practicing good hole cleaning procedures. 5. Also construction offices are still located on Milne Pt. L-Pad. Construction is still onging between L pad and F pad. Ensure personnel and vehicles use caution while approaching and while on L-pad. 6. An in-hole reference gyro MAY be run in this well. L OS T CIRCULATION: Lost circulation while drilling the production interval has been a problem in on 4 different L-pad wells. The Kuparuk sands and a number of shallower intervals are highly fractured. Wells L-07, L-08, L-09 and L-11 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands. Be prepared to treat these losses with LCM treatments. Have the LCM materials outlined in the Drilling Fluid Program on location and recommended pills ready to address the Lost Circulation Problem when drilling into the Kuparuk Sand. Stuck Pipe Potential: Stuck pipe has occurred on 3 wells on this pad at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L- 07 @ 6859' ss, L-11 @ 6835' ss. While running 7" casing on MPL-29 the last two joints (TD was 14025'MD/7208'TVD) that were run acted sticky and repeatedly packed off for a period of time. Landing the casing hanger required working the casing string and circulating in order to get casing in place. Gas hydrates: Although hydrates were encountered on E, H, and Pads, no hydrates are expected on L pad. No hydrates were encountered during the recent drilling of MP L-29 and MP L-16i. 4. No other drilling hazzards or risks have been identified for this well. MP L-21i 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 50 deg F at 2500'.TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 1396 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% CaCl2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 YIELD'1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. 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 at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Top Job Cement Volume is 150 sacks. MP L-21i Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. SPACER: 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 231 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 19 joints of 7" Casing (38 total). This will cover 300' above the KUPARUK C1 Sand. Run two 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9- 5/8" casing shoe. 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 at 8-10 bpm. Batch mixing is not necessary, CEMENT VOLUME: , Stage 1 cement volume is calculated to cover 1000' md above the Kuparuk Target Sand with 30% excess. Nov-21-95 17:00 Anadrill DPC 907 344 2160 P.07 i mllll im ~ I ~o.~,u~.o u,oo ~oo o "' PLAN VIEW ,oo. .o E) CUnVE e.~/~O0 ~00 0 40 CLOSURE. ' ~0580 feet at Azimuth 22.19 F) END 2.5/~00 CUnVE 2281 285 303 DECLINATION.' +0.000 ~ CURVE ~,5/~00 30~ ~55 5e~ H) END 2.5/~00 CURVE ~6~ ~7~5 ~0t0 ~CALE ....... : ~ ~nch : ~600 feet I) CURVE 2.5/100 6182 3138 1526 J) END 2.5/100 CURVE 6270 3217 1554 DRAWN · ~/21/95 K) CURVE 2.5/~00 7~06 3969 1798 L) END 2.5/~00 CURVE 7207 4059 t830 m ~-5/a' C~s~N; ~om~ 7~50 4097 m44 ' ' ' 0~0~ a/~O0 llaO~ al~, 336, ~adr ~ ] ] Sch]usberger t) TO 14J~8 )797 3gg6 200 FT TARG[iT RADIUS ~B / ' -"-'~,,^_DPc } ........ -- . ...... ~ ............ . } ~ ........ ~ .... . . , I ~ - ....... ~ j . -! 800- 0 BO0 1600 2400 3200 4000 4800 5600 6400 7200 ilO00 flflO0 g600 10400 <- ~EST ' EAST -> ~ ~: , ,, (c)~ ~tP6 ~, .04 ~ ~P) -- ' ....... , , -- ,, __ '1 640( 800O ' PL-2 '(PC) VERTZOAL SEOTZON VZE~ Section at: 20.68 TVD Scale.' ~ inch : 1600 feet Dep Scale.' 1 inch : 1600 feet Drawn ' 11/21/95 00 00 20 20 05 05 05 05 05 05 05 00 00 00 u-- A ~ "- Marker Identification MO BKB SECTN INCt ANAl)RILL -- A) KB 0 0 0 0.( t B) KOP/BUILD 1/100 500 500 0 0.( AKA-D )C B ~'.-. ~-,,,-,~.,:u~~'~'" cl .~,o, ~/,oo ~oo ~oo ~ ~.~ ~ ~- FOR .~ERA/I//ING'"""~"- 0) BuIt. D 2/100 .~ 900 900 6 E ' - .: E] CURVE 2.5/t00 1100 1098 14 9. O-- . ~~.: 'I ' ~ '~~ i F) END 2.5/100 CURVEcuRvE 2281 2200 373 33.; ON I~ _,_ ~1 cu,v,~.~/~oo ~o~, ~,~ ~,~ ~A~ - .I E~O p_.5/mo 461~ 37~o 1989 .................... I ~ .,---- ..._____ -=---_. ~ ~ ~ I1 CURVE 2.5/100 6182 4300 3475 71.1 }. ---_. J) END 2.5/~00 CURVE 6270 4329 3559 71.1 ....... ,~ ........ K) CURVE 2.5/100 7106 4600 4348 71.t ' L) END 2.5/100 CURVE 7207 4633 4444 71.1 G -~ ,, M) 9-5/8' CASING POINT 7250 4647 4484 71 )--\ N) DROP 2/100 11801 6125 8789 ~, i 0) END 2/100 DROP ' 10053 40.~ 13354 6993 : P) TARGET 13754 7299 10310 40.( ) .... H'~"'i,,,,~',,,.._ 0) 7" CASING POINT 14168 7617 10577 40. R] TD 14168 7617 10577 40. , :~'~- ~:. ...... ..... ::---, _ -- -__.. = ==-__--- =_- = == =_-= =- ==-_=- =.- -- :,. , ..... ............,,.. .... ..... 0 BOO ~600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 12800 13600 Sect Jori Departure Z 0 < I I WELL PERMIT CHECKLIST COMPANY INIT CLASS GEOL AREA PROGRAM: exp [] der [] redrll [] serv~ ADMINISTRATION l. 2. 3. 4. 5. 6. ?. 8. 9. 10. 11. 12. 13. Permit fee.attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool .............. Well locaued proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ......... Operator only affected party ......... ' ..... Operator has appropriate bond in force ......... Permit can be issued without conservation order ..... Permit can be issued without administrative approval. 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 ...... !9. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndrunnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. ROPEs adequate ..................... 26. ROPE press rating adequate; test to ~~ 9sig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur withou~ operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/z/N 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... /. Y N / 34. Contact name/phone for weekly progress reports . . ./. . Y N [exploratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION: DWJ ~ ~.~_ Comments/Instructions: rev 11/95 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 * ....... SCHLUMBERGER ....... Oil & G~,,s Cor~s. Co~'~rnission ^ncho~age COMPANY NAME : BP EXPLORATION WELL NAME : MPL- 211 FIELD NAME '. MILNE POINT BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 500292262900 REFERENCE NO : 96009 LiS Tape ~erification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/05/21 ORIGIN : FLIC REEL NAME : 96009 CONTINUATION # : PREVIOUS REEL : COM~fEArT : BP EXPLORATION, MILNE POINT MPL-21I, API #50-029-22629-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/05/21 ORIGIN : FLIC TAPE NAME : 96009 CONTINUATION # : 1 PREVIOUS TAPE : COMPIENT : BP EXPLORATION, MILNE POINT MPL-21I, API #50-029-22629-00 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: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 ......... 96009 RUMINER PYRON WELL CASING RECORD 1ST STRING 2ND STRING MPL-21i 500292262900 BP EXPLORATION SCHLUMBERGER WELL SERVICES 21-MAY-96 BIT RUN 2 96009 RUMINER PYRON BIT RUN 3 8 13N 10E 3687 5070 46.20 28.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) O0 20.000 112.0 8.500 9.625 7248.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED LIBRARY TAPE DATA ON BP EXPLORATION MPL-21i. LOGGING WHILE DRILLING DATA ACQUIRED ARE CDR AND CDN. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SO?4MARY LDWG TOOL CODE CDR CDN $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 3764.0 14155.0 7172.0 14059.0 BASELINE DEPTH 88888.0 13963.5 13942.5 13934.5 13914.5 13881.0 13869.0 13830.0 13819.5 13805.0 13795.5 13791.5 13787.5 13772.0 13763.5 13757.5 13752.0 .......... EQUIVALENT UNSHIFTED DEPTH CDR/CDN 88883.0 13958.5 13941 0 13931 0 13911 0 13877 5 13865 0 13825 5 13815 0 13801 5 13793 5 13789.0 13785.5 13769.0 13761.0 13755.0 13750.0 Lib Tape ~erification Listing SchlurtffDerger Alaska Computing Center 13748.0 13745.5 13743.5 13739.5 13735.0 13726.5 13722.0 13719.5 13713.5 13708.5 13702.0 13679.0 13658.0 13654.0 13650.0 13643.0 13638.5 13625.5 13621.0 13611.5 13599.5 13596.5 13593.0 13579.0 13573.5 13564.0 13557.0 13544.0 13533.0 13518.0 13515.0 13505.0 13484.5 13481.0 13470.5 13460.0 13446.5 13436.0 13424.0 13416.0 13409.5 13403.5 13399.0 13390.0 13383.5 13377.5 13369.5 13364.0 13352.0 13342.5 13325.0 13320.5 13314.5 13313.0 13294.0 13746.0 13743.5 13741.5 13738.0 13733.0 13725.0 13722.0 13719 0 13714 5 13709 0 13702 0 13679 5 13659 0 13654 0 13651 0 13641.5 13638.5 13625.5 13621.5 13611.5 13600.0 13597.0 13593.0 13579.5 13574.0 13564.0 13557.5 13544 5 13533 5 13519 0 13515 0 13506 0 13484 0 13480 0 13470.0 13459.5 13446.0 13436.0 13425.0 13414.0 13407.5 13400.5 13397.0 13390.0 13383 5 13377 0 13368 5 13363 5 13349 0 13342 0 13323 5 13320.5 13313.0 13310.0 13293.0 21-MAY-1996 16:08 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: 13285 13260 13253 13240 13238 13235 13217 13205 13189 13187 13174. 13165. 13155. 13146. 13141. 13137. 13132. 13130.5 13125.5 13122.5 13115.5 13108.5 13091.0 13073.0 13063.0 13028.0 13007.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE .............. CDR CDR $ 13285.0 13259.5 13252.5 13238.5 13237.0 13235.0 13217.5 13205.5 13189 0 13187 0 13174 5 13165 0 13155 0 13146 5 13141 0 13137 5 13131.0 13128.0 13123.5 13120.5 13114.5 13107.5 13091.0 13072.5 13063.0 13027.5 13006.0 99.0 BIT RUN NO. MERGE TOP MERGE BASE 1 3764.0 7268.0 2 7268.0 14155.0 THIS FILE CONTAINS THE CLIPPED, DEPTH CORRECTED DATA OF THE MEASUREMENT WHILE DRILLING CDR AND CDN. BOTH CDR AND CDNHAVE BEEN DEPTH CORRECTED TO WESTERN ATLAS MARKED LINE GAlenA RAY DATED 18-APR-96. THE CDR DATA WAS ACQUIRED OVER 2 BIT RUNS AND THE CDN DATA WAS ONLY ACQUIRED OVER THE 2ND BIT RUN. THE QRO ENHANCED RESISTIVITIES PSVR AND ATVR WERE RECOMPUTEDAT SCHLUMBERGER GEOQUEST COMPUTING CENTER IN ANCHORAGE, AK. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 * * SET TYPE - CH_AN * * 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 56945 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H~456945 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0H~56945 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0H~456945 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD 0I~4~4 56945 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 0H~4~56945 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 56945 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 56945 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 56945 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 56945 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 56945 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 56945 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 56945 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 56945 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 56945 O0 000 O0 0 1 1 1 4 68 0000000000 GR ATLA GAPI 56945 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 14150.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 48.573 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD NPHI.MWD -999.250 CALN. MWD -999.250 DCAL.MWD -999.250 GR.ATLA -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: DEPT. 3763.000 RA.MWD VRP.MWD -999.250 DER.I~WD GR.MWD 73.395 RHOB.I4WD NPHI.MWD -999.250 CALN. MWD -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 DCAL.MWD -999.250 -999.250 -999.250 -999.250 VRA . MWD FET.MWD PEF. MWD GR. A TLA -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUI4~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: i DEPTH INCREMENT: 0.5000 FILE SU~2ARY VENDOR TOOL CODE START DEPTH CDR 3764.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNttOLE SOFTWARE VERSION: DATA TYPE (IvlEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): STOP DEPTH .......... 7268.5 22-DEC-95 FAST 2.5-005B V4. OC MEMORY 14155.0 3764.0 7268.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISITIVITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHI~iPI) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 42 48.9 72.1 TOOL NUMBER ........... CDR904 112.0 SPUD 10.00 REMARKS: ************ LWDRUN1 ************* DRILLED INTERVAL 3811 - 7268 UNCOMPENSATED RESISTIVITY FROM 5050-7230 RES TO BIT: 37.55'; GR TO BIT: 47.97' $ LIS FORMAT DATA 2. 270 66.0 2.030 66.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: 8 TYPE REPR CODE VALUE 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 ** NA~E 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 56945 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OH~ff456945 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LWl OH~4M56945 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 0P~4~56945 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 56945 O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR 56945 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 56945 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7268. 500 ATR. LW1 -999. 250 PSR. LW1 -999. 250 DER. LW1 -999. 250 ROPE. LW1 53 . 574 TAB. LW1 -999. 250 GR. LW1 -999. 250 DEPT. 3764. 000 ATR. LW1 -999. 250 PSR. LW1 ROPE. LW1 -999. 250 TAB. LWl -999. 250 GR. LW1 -999.250 DER.LW1 -999.250 73. 395 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE ~ER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~E4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH CDR 7216. $ 14155.0 CDN 7216.5 14155.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISITIVITY CDN DENSITY NEUTRON 22 -DEC- 95 FAST 2. $-005B V4. OC MEMORY 14155.0 7216.5 14155.0 8O 28.2 72.1 TOOL NUMBER CDR051 CDN022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: 10 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 112.0 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 270 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 030 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 1.0 REMARKS: ************ LWD RUN 2 TCB ************* DRILLED INTERVAL 7268 - 14155 RES TO BIT: 41.42; GR TO BIT: 51.84 DEN TO BIT: 96.17; NEUT TO BIT: 103.15 LAST 20 FT OF GR AND RES DATA LOST DUE TO MEMORY ERROR. $ LIS FORMAT DATA 66.0 66.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: 11 TYPE REPR CODE VALUE 11 66 18 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 56945 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OH~ff456945 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OH~4M56945 O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OHMM56945 O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR 56945 O0 000 O0 0 3 1 1 4 68 0000000000 TAB LW2 HR 56945 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 56945 O0 000 O0 0 3 1 1 4 68 0000000000 TABD LW2 HR 56945 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI LW2 PU 56945 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU 56945 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LW2 G/C3 56945 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LW2 G/C3 56945 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LW2 BN/E 56945 O0 000 O0 0 3 1 1 4 68 0000000000 DCAL LW2 IN 56945 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 14155.000 ATR.LW2 -999.250 PSR.LW2 -999.250 DER.LW2 ROPE.LW2 48.573 TAB.LW2 -999.250 GR.LW2 -999.250 TABD.LW2 DPHI. LW2 -999. 250 TNPH. LW2 -999. 250 RHOB. LW2 - 999.250 DRHO. LW2 PEF. LW2 -999. 250 DCAL. LW2 -999. 250 DEPT. 7166.000 ATR.LW2 -999.250 PSR.LW2 -999.250 DER.LW2 ROPE.LW2 -999.250 TAB.LW2 -999.250 GR.LW2 -999.250 TABD.LW2 DPHI. LW2 - 999. 250 TNPH. LW2 48. 500 RHOB. LW2 - 999. 250 DRHO. LW2 PEF.LW2 -999.250 DCAL.LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1996 16:08 PAGE: 12 **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~IE : EDIT DATE : 96/05/21 ORIGIN : FLIC TAPE NAME : 96009 CONTINUATION # : 1 PREVIOUS TAPE : COF~4F2VT : BP EXPLORATION, MILNE POINT MPL-21I, API #50-029-22629-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/05/21 ORIGIN : FLIC REEL NAME : 96009 CONTINUATION # : PREVIOUS REEL : COF~qENT : BP EXPLORATION, MILNE POINT MPL-21I, API #50-029-22629-00 MPL- 21 MILNE POINT Tape Subfile 2 is type. JIS TAPE HEADER MILNE POINT I/NIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPL-21 500292262900 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 13-MAY-96 6661.00 B. ESARY J. FOX 8 13N 10E 3687 5070 46.20 28.70 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 7249.0 40.00 PRODUCTION STRING 7.000 14135.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: SBT GRCH 1 1 18-APR-96 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH SBT/GR MARKED LINE. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** SHIFT PROCEDURE AS FOLLOWS: 1) SECOND PASS GAMMA RAY DEPTH MATCHED TO FIRST PASS GAMMA RAY. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 12988 . 0 13959.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPL - 21 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI API API API API Lo9 Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 16 Tape File Start Depth = 12990.000000 Tape File End Depth = 13960.000000 Tape File Level Spacin9 = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3883 datums Tape Subfile: 2 104 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 13770.0 13959 . 0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 13772.5 13772.0 13799.5 13799.0 13817.0 13818.5 13823 . 5 13823 . 5 13831.5 13832.0 13839 . 5 13839.5 13856 . 0 13856 . 0 13877.5 13877.5 13889.5 13889.0 13911.5 13911.5 13932 . 0 13931.5 13932.5 13932.0 13957 . 5 13958 . 0 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS). / ? ?MATCH2A. OUT $ CN : BP EXPLORATION WN : MPL - 21 FN : MILNE POINT COLIN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 * DATA RECORD (TYPE# 0) Total Data Records: 1022 BYTES * 30 995 99 Tape File Start Depth = 13770.000000 Tape File End Depth = 13960.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 763 datums Tape Subfile: 3 47 records... Minimum record length: Maximum record length: 62 bytes 1022 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE ~BER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12988.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 13986.0 18-APR-96 FSYS REV. J001 VER. 1.1 1423 18-APR-96 14051.0 13997.0 12988.0 13989.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330XA 1309XA 1633XA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : 0.000 14135.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG) : SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT R~_JE NORMALIZATION IN OIL ZON_ TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1 (MAIN PASS) . $ CN : BP EXPLORATION WN : MPL - 21 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/FIN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 80 Tape File Start Depth = 12990.000000 Tape File End Depth = 13985.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 23789 datums Tape Subfile: 4 156 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13769.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 13986.0 18-APR-96 FSYS REV. J001 VER. 1.1 1335 18-APR-96 14051.0 13997.0 12988.0 13989.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330XA 1309XA 1633XA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 14135.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 O.00O 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): 5~ATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RA_~ NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPL - 21 FN : MILNE POINT COLIN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 I 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0 ) 1006 BYTES * Total Data Records: 18 Tape File Start Depth = 13770.000000 Tape File End Depth = 13985.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5069 datums Tape Subfile: 5 94 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 6 is type: LIS 5/14 O1 **** REEL TRAILER **** 96/ '5/14 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 14 MAY 96 7:58a Elapsed execution time = 1.10 seconds. SYSTEM RETURN CODE = 0