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Home My WebLink About197-223David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 07/23/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well Name PTD Number API Number 18-13 187-100 50-029-21756-00-00 18-13PB1 187-100 50-029-21756-70-00 18-13PB2 187-100 50-029-21756-71-00 18-13A 197-223 50-029-21756-01-00 18-13B 207-157 50-029-21756-02-00 18-13BPB1 207-157 50-029-21756-72-00 18-13BPB2 207-157 50-029-21756-73-00 18-13BPB3 207-157 50-029-21756-74-00 18-13C 210-186 50-029-21756-03-00 Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/25/2023 Main Folder Contents: Please include current contact information if different from above. T39261 T39262 T39263 T39264 T39265 T39266 T39267 T39268 T39269 18-13A 197-223 50-029-21756-01-00 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.24 08:23:01 -08'00' 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. / ~ "~- 2~.~ File Number of Well History 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. [3 Other, No/Type OVERSIZED [] Logs of vadous kinds [3 Other COMMENTS: Scanned by: ~ve.y Mildred Damtha~o~ll TO RE-SCAN Notes: --~ STATE OF ALASKA ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~... ' ~~ DEC1~;: ,~ WELL COMPLETION OR RECOMPLETION REPORT A ~a~~i~ & Gas Cons E_-- :;.~,~:;;:finn AnChor~gli 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 2oAAC zs.,os 2oAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 11/08!2007 12. Permit to Drill Number 197-223 3~1•-~~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 02/13/1998 13. API Number 50-02921756-01-00 ~ t~ " 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 02/17/1998 14. Well Name and Number: PBU 18-13A 1045 FNL, 371 FWL, SEC. 19, T11N, R15E, UM Top of Productive Horizon: 3594' FNL, 3568' FWL, SEC. 19, T11 N, R15E, UM 8. KB (ft above MSL): 54.8' - Ground (ft MSL): 15. Field /Pool(s): - Prudhoe Bay Field / Prudhoe Bay Total Depth: 4795' FNL, 912' FWL, SEC. 20, T11 N, R15E, UM 9. Plug Back Depth (MD+TVp) 13000 8771 Pool 4b. location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 692133 y- 5960832 Zone- ASP4 10. Total Depth (MD+TVD) 13102 8772 - 16. Property Designation: ADL 028321 " TPI: x- 695394 y- 5958367 Zone- ASP4 Total Depth: x- 697737 y- 5957227 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, RES, ES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MO' SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP .BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 urface 110' Surface 110' 30" 1694# Poleset 13-3/8" 72# ! 68# K-55 ! L-80 Surface 4482' Surface 4429' 17-1 /2" 3500 sx CS III, 600 sx'G', Top Job: 100 sx CS II 9-5/8" 47# L-80 Surface 9103' Surface 8263' 12-1/4" 930 sx Class 'G' 7" 29# L-80 880 ' 9747' 8087' 532' -1/2" 5 0 sx Cla s'G' 4-1/2" 12.6# L-80 8698' 13097' 8025' 8772' 6" 523 sx Cla s'G' 23. Open to production or inject ion? ^ Yes ®No 24. TuewG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2", 12.6#, 8718' 8548' & 8662' MD TVD MD TVD ~ r ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ `~, ~~~ ~ ~~~~ a DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED l J `~ 9200' Set (2nd) Whipstock 26. PRODUCTION TEST Date First Production: ~ - Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC,~S~,QZ1,. j ~~iris L.~ IOid { F Y None _~ ~ ~~~~: ~ ~ 7001 ~ ~r i Form 10-407 Revised 02/2007 CONTINUED ON REVERSE .SIDE C~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS A KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit /Zone 1 10484' 8668' None Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work, Rig Workover and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si d ~Z~ t3/~ ~ gne Title Drilling Technologist Date Terrie Hubble PBU 18-13A 197-223 Prepared ey NameAVumber.• Terrie Hubble, 564-4628 W211 Number Drilling Engineer: Lamar Gantt, 564-5593 Permit No. / A royal No. INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: 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. Form 10-407 Revised 02/2007 Submit Original Only Digital Well File Well: 18-13 Well History Welt Date 18-13A 18-13A 1011 /2007 Page 1 of 1 Summary TIIAIOA= 0/210!0 Temp=Sl PPPOT-T (PASS} PPPOT-IC (PASS} (PRE RIG) PPPOT-T RU 2 HP bleed tools onto THA test void, 2000 psi bleed to 0 psi. Cycled LDS " ETstyle "all pins moved free no bent or damaged pins. Flush void until clean returns achieved, pressure to 5000 psi for 30 min test, 4800/ 15 mins, 4800! 30 mins. Bleed void to 0 psi, RD test equipment re-install Alemite caps. PPPOT-IC RU 2 HP bleed tools onto IC test void, 200 psi bleed to 0 psi. Cycled LDS " ET style "all moved free no bent or damage. Flush void until clean returns achieved, pressure to 3500 psi for 30 min test, 3400/ 15 mins, 3400/ 30 mins. Bleed void to 0 psi, RD test equipment re-installed Alemite caps. 10/6/2007 ****WELL S/I ON ARRIVAL**** PULLED P-PRONG Ca) 9215' SLM. PULLED PX PLUG BODY 9220' SLM, DRIFTE W/ 4.5" BRU H & 3.80' .RING TO 9300' SLM. ***LEFT WELL S/l**** 18-13A 10/7/2007 T/I/0=520/150/0 Assist E-line CMIT-TXIA Passed to 3500 osi (Pre-RWO) First-test CMIT Tx IA presured up to 3500/3200 psi with 22.6 bbls diesel. T/I lost 160/80 in first 15 minutes and 120/60 psi in second 15 minutes. For a total of 280/140 psi in 30 minutes. Second test - T/I presured up to 3500/3280 with .8 bbls diesel. T/I lost 80/20 psi in first 15 minutes and 20/0 psi in second 15 minutes. For a total of 100/20 psi in 30 minutes. Bled back - 15 bbls. Tagged wing and IA valves with info. Well S/I and departure with wing valve closed and all other casing valves open to gauges. FW HP's=500/320/0 18-13A 10!7/2007 ****WELL SI ON ARRIVAL**** (E-LINE SET PLUG AND CUT 4.5" TUBING) INITIAL T/UO: 650/15010. CORRELATED TO WELLSKETCH DATED 24-NOV-04. SETA 4.5" HES FASDRILL BRIDGE PLUG AT 9000'. LRS PT PLUG TO 3500 PSI AFTER POOH. SHOT A 3.65" JET CUTTER AT 8632' IN FIRST FULL JOINT ABOVE PACKER. DID NOT TAG TD. FINAL T/I/O: 600l300I0 -WELL LEFT SHUT-IN ***JOB COMPLETE*** 18-13A 10/7/2007 ****WELL SHUT-IN ON ARRIVAL**** (E-LINE SET PLUG AND CUT 4.5" TUBING) INITIAL T/I/O: 650/150/0. CORRELATED TO WELLSKETCH DATED 24-NOV-04. SETA 4.5" HES FASDRILL BRIDGE PLUG AT 9000'. LRS PT PLUG TO 3500 PSI AFTER POOH. SHOT A 3. FIRST FULL J FINAL T I T SHUT-IN**** 18-13A 10/8/2007 T/I/O = 550/360/0 Temp= S/I Circ-Out, (Pre RWO) Pumped 5 bbls. meth down flow line, Pumped 10 bbls. meth spear, Begin pumping 120* 1 %KCL down TBG taking returns up IA through jumper loop and casasco down flow line, ------Job In Progress----- ***WSR Continued to 10-09-07*** 18-13A 10/9/2007 *'`*WSR Continued from 10-08-07*** Circ-Out, MIT OA @ 2000 psi. FAILED 3 tests. (Pre RWO) Pumped a total 873 bbls 120* 1%KCL down TBG taking returns up IA through jumper loop and casasco down flow line, Pumped 160 bbls 80*F diesel down IA taking returns up Tbg down flow line for F/P, U-tube TxIA for 1 hr. to put F/P in place, Pumped 5 bbls meth spear followed by 35 bbls crude capped with 21 bbls 80*F diesel down flow line for F/P, MIT OA, Pumped 2.3 bbls crude down OA to reach test pressure of 2000 psi. OA lost 40 psi. in 1st 15 min. and 40 psi. in 2nd 15 min and 40 psi in the 3rd 15 min. for a total loss of 120 psi in the 45 min test (would not show stabilization). Bleed WHP's, Final WHP's 0/0/0 "Annulus casing valves tagged & left open" 18-13A 10!9/2007 Set 4" CIW ISA BPV, for pre rig Set at 102" eep 18-13A 10/10/2007 Pulled 4" CIW ISA BPV, for pre-rig Set at 92"deep Print Date: 12/13/2007 Page 1 of 1 http://di$italwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 12/13/2007 s • BP EXPLORATION Page 1 of 4 . Operations Summary Report Legal Well Name: 18-13A Common Well Name: 18-13A Spud Date: 11/3/1987 Event Name: WORKOVER Start: 10/9/2007 End: 10/14/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/14/2007 Rig Name: DOYON 16 Rig Number: Date I From - To I Hours } Task I Code I NPT 10/9/2007 12:00 - 12:30 0.50 MOB P 12:30 - 14:30 2.00 MOB P 14:30 - 15:30 1.00 MOB P 15:30 - 16:00 0.50 MOB P 16:00 - 17:00 1.00 MOB P 17:00 - 18:00 1.00 MOB P 18:00 - 00:00 6.00 MOB P 10!10/2007 100:00 - 01:00 I 1.001 MOB I P 01:00 - 03:00 2.00 MOB P 03:00 - 04:00 1.00 RIGU P 04:00 - 05:00 1.00 RIGU P 05:00 - 06:30 1.50 WHSUR P 06:30 - 07:30 I 1.001 WHSUR I P 07:30 - 09:30 I 2.001 KILL I P 09:30 - 11:00 I 1.501 WHSUR I P 11:00 - 12:00 I 1.001 WHSUR I P 12:00 - 12:30 I 0.501 WHSUR I P 12:30 - 14:30 I 2.001 WHSUR I P 14:30 - 16:00 I 1.501 BOPSU~P 16:00 - 16:30 0.50 BOPSU P 16:30 - 00:00 7.50 BOPSU P 110/11/2007 100:00 - 01:30 I 1.501 BOPSUR P Phase Description of Operations PRE Prepare for Rig Move and Held PJSM. PRE Move rig off of Well DS 18-17 to Center of Pad. PRE PJSM Lay Derrick Over. PRE Move Rig around Reserve Pit, stage in center of Pad. PRE Service Derrick Sheaves, Raise and Pin Derrick. PRE R/U Rig Floor, Unbridle Blocks. PRE Stand by for Well Preparation on DS 18-13, Perform Light Maintenance. PRE Continue to Stand By for Well Prep on DS 18-13, Light Maintenance. PRE Lay Herculite and Rig Mats, Stage Cellar Equipment. PRE Spot Rig over Well DS 18-13, and Level and Shim Rig. PRE Rig Up Double Annulus Valve, Circulating Lines, take on Sea Water in Pits 3 and 4. DECOMP Taking on 200 bbls of 120 deg Seawater, while waiting on DSM to pull BPV. DECOMP R/U DSM Lubricator and test to 200 psi low and 500 psi high test. Pull BPV, R/D DSM Lubricator. DECOMP Pressure Test Lines to 3,500 psi, Displace Wellbore to 120 deg Seawater. Pumped 600 bbls at 7 bpm and 800 psi. DECOMP Pressure Test #2 Mud Pump to 3,500 psi. Continue to Circulate at 7 bpm and 800 psi. While waiting on FMC. Redress/Rebuild ISA that was damaged while pulling out of the well. DECOMP Monitor Well for 15 minutes, B/D Circulating Lines, FMC Rep DECOMP TR/U and Test BPV to 1,000 psi for 10 charted minutes,. BID Lines. DECOMP N/D Production Tree and Adapter Flange, Bleed Control Lines, Prepare Wellhead, Install Blanking Plug. DECOMP N/U BOPE, Turn Buckles, Belf Nipple. DECOMP R/U to Test BOPE. DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High. Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Bob Noble. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- VBRs On 4" Test Jt. Test #2- Annular Preventer, Kill HCR, Choke Valves #12, 13, 14. Test #3- Choke Valves #9, 11, Manual Kill, Blinds, Upper IBOP Test #4- Choke Valves #5, 8, 10, Lower IBOP. Test #5- Choke Valves #4, 6, 7, TIW Valve Test #6- VBRs on 4.5" Test Jt, Dart Valve Test #7- HCR Choke Test #8- Manual Choke Test #9- Choke Valves # 1,3. DECOMP Continue to Test BOPE Test #10-Choke Valve # 2 Test #11-Blind Rams Accumulater Test- 3,100 psi Starting Pressure, 1,800 psi After Actuation, First 200 psi in 17 seconds, Full Pressure in 1 Minute 17 Seconds. Printed: 10/23/2007 2:59:19 PM a • BP EXPLORATION Page 2 of 4 Qperations Summary Report Legal Weil Name: 18-13A Common Well Name: 18-13A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To I Hours I Task I Code l NPT Start: 10/9/2007 Rig Release: 10/14/2007 Rig Number: Spud Date: 11/3/1987 End: 10/14/2007 10/11/2007 100:00 - 01:30 I 1.501 BOPSUFi P 01:30 - 02:00 I 0.501 BOPSUF{ P 02:00 - 02:30 I 0.501 BOPSU~ P 02:30 - 03:30 1.00 BOPSU P 03:30 - 05:00 I 1.501 FISH I P 05:00 - 05:30 I 0.501 FISH P 05:30 - 06:30 1.00 FISH P 06:30 - 09:30 1 3.001 FISH I P 09:30 - 10:30 1.00 FISH P 10:30 - 16:00 5.50 FISH P 16:00 - 17:00 1.00 FISH P 17:00 - 17:30 0.50 FISH P 17:30 - 19:30 2.00 FISH P 19:30 - 00:00 4.50 FISH P 10/12/2007 00:00 - 03:00 3.00 CLEAN P 03:00 - 03:30 I 0.501 CLEAN I P 03:30 - 04:30 I 1.001 CLEAN I P 04:30 - 05:30 I 1.00 I CLEAN I P 05:30 - 06:00 0.50 CLEAN P 06:00 - 07:00 I 1.00 f CLEAN I P 07:00 - 08:00 I 1.00 I CLEAN I P 08:00 - 08:30 I 0.501 CLEAN I P 08:30 - 10:00 1.50 CLEAN P 10:00 - 10:30 0.50 CLEAN P Phase I Description of Operations DECOMP 5 Nitrogen Bottles at 2,050 psi. The dart valve and full opening safety valve failed test. Both were replaced and tested again -passed test. DECOMP R/D BOP Test Equipment and B/D Choke Manifold and Surface Lines. DECOMP R/U FMC and Pull Blanking Plug. DECOMP PJSM, R/U DSM Lubricator, Test Lubricator to 200 psi low and 500 psi high test. Pull BPV. DECOMP PJSM, P/U jt Drill Pipe M/U Spear Assembly, Spear into Tubing Hanger. BOLDS, Pull Hanger to Rig Floor, Up Weight=140,000# Hanger Pulled Free. DECOMP L/D Spear, B/O Tubing Hanger and L/D same. R/U to CBU. DECOMP Circulating Bottoms Up at 8 bpm with 640 psi. R/U to L/D Tubing and R/U Control Line Spooler. DECOMP POOH and UD 4-1/2" 12.6#, L-80, IBT Tbg Completion. 55 jts plus SSSV. All of the 1/4" Dual Contol Line was recovered as well as 55 bands. DECOMP R/D Camco Control Line Spooler. DECOMP Continue to POOH and L/D 4.5" 12.6# L-80 IBT Tubing. Recovered a total of 205 jts, 4 GLM's, SSSV, 1/4" Control Line, Cut Jt, and 55 SS Bands. Cut Jt = 20.97' Flared to 4.75". Found one hole ' 1' below box end of Jt 119 out (-3393'). Pin ends had a good amount of corrosion on threads. Most of the outside of the tubing was in good shape, below last GLM the was a noticeable amount of scale on the outside of the tubing. DECOMP Clean and Clear Rig Floor. UD Tubing Handling Equipment. DECOMP Install Wear Ring 10" ID. DECOMP M/U Dress Off Assembly, BHA Consists of: Dress Off Shoe, Wash Pipe Ext, Triple Bushing Connection, XO, 9 5/8" Casing Scraper, 2 -Junk Baskets, XO, Bowen Bumper Jar, Bowen Oil Jar, XO, 9 - 6.25" Drill Collars, BHA Length =326.36' DECOMP RIH with 4" HT-38 DP from 328' to 5,325'. DECOMP Continue to P/U 4" Ht-38 Drill Pipe From Pipe Shed, from 5,325' to 8,620'. Up Weight=180,000# Down Weight=150,000#, Rotating Weight=165,000#, Pumping 5 bpm with 450 psi. DECOMP Tagged top of stump at 8,629' Milled to 8,630' with2-5 WOB, 5-10,000 ft-Ibs Torque. P/U and washed over stump. P/U and slid over stump 2X, Clean Stump. Milled off 1', new to of stum at 8 630'. DECOMP Pump 20 bbl Hi-Vis Sweep at 11 bpm with 1,950 psi. Monitor Well. DECOMP POOH and UD 30 jts Drill Pipe. DECOMP P/U and RIH with RTTS on 1 std of Drill Piae and set 102' below rig floor. DECOMP Pressure Test RTTS to 1500 psi for 15mins on chart. Good Test. Stand Back Stand. DECOMP PJSM on N/D BOP's and Change Out of Pack Off. WU to N!D BOP's. DECOMP Drain Down Slop Tank from Weir Side and M/U Pack Off Pulling Tool. DECOMP Flow Check 0A through 2" to Slop tank insure no pressure build and no flow. DECOMP N/D BOP's. Split wellhead at tubing spool. Printetl: 10/23/2007 2:59:19 PM • • BP EXPLORATION: Page 3 of 4 Operations Summary Report Legal Well Name: 18-13A Common Well Name: 18-13A Spud Date: 11/3/1987 Event Name: WORKOVER Start: 10/9/2007 End: 10/14/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/14/2007 Rig Name: DOYON 16 Rig Number: Date I .From - To 1 Hours i Task I Code l NPT 10/12/2007 10:30 - 11:00 0.50 CLEAN P 11:00 - 13:00 2.00 CLEAN P 13:00 - 13:30 0.50 CLEAN P 13:30 - 14:00 0.50 CLEAN P 14:00 - 14:30 I 0.501 CLEAN ~ P 10/13/2007 100.00 - 01.30 I 10.501 CLEAN I P 01:30 - 02:00. 0.501 CLEAN ~ P 02:00 - 04:00 2.00 RUNCO 04:00 - 14:00 14:00 - 15:30 15:30 - 16:00 16:00 - 16:30 16:30 - 17:00 17:00 - 22:00 22:00 - 22:30 22:30 - 00:00 10.00 1.50 0.50 RUN 0.50 RUN 0.50 RUN 5.00 RUN 0.50 RUN 1.50 RUN Phase I Description of Operations DECOMP Pull and Re lace FMC Mandrel Pack Off. DECOMP N/U BOP Stack, Turn Buckles and Flow Riser. DECOMP Test Hanger Void to 3,800 psi for 30 minutes. DECOMP Pressure Test BOP Tubing Spool Connection to 250 psi Low and 3 500 si Hi h. Test for 5 minutes each on Chart. DECOMP M/U Storm Packer Retrieving tool, RIH w/lstd drill pipe, Engage Storm Packer, POOH and UD Same. DECOMP POOH UD Drill Pipe f/7,600' to 328'. DECOMP L/D Drill Collars, L/D Dress off Assembly. DECOMP Continue to L/D Dress Off Assembly. Positive indication of Good Dress Off on Tubing Stub from Dress Off Mill, Approx 1/2 gal of Metal Shavings in Junk Basket. DECOMP Clean and Clear Rig Floor. RUNCMP Pull Wear Ring, R/U to Run 4.5",12.6#, 13CR-80, Vam Top Completion. RUNCMP Run 4.5",12.6#, 13CR-80, Vam Too Completion. 1-Unique Overshot, 1-X Nipple w/RHC, 1-X Nipple, 1-Baker S-3 Production Packer, 1-X Nipple, 1-4.5"x 1.5" GLM, and 30 jts of Tubing. Jt#120 did not make up correctly the joint was layed down as well as the collar it was made up to. Anew joint was picked up and run in its place. Average make up Torque 4,440 ft-Ibs, Using Jet Lube Sea{ Guard and Torque Turning all Connections. RUNCMP P/U Circulating Head on jt # 200, Up Weight=136,000#, Down Weight=124,000#, RIH Pressure increase of 130 psi as overshot swallowed Tubing Stub, Positive indication of Shear pins, Stacked Out at 8,636'. RUNCMP L/D Two Jts Tubing, Make up Space Out Pups P/U jt #199. RUNCMP M/U Tubing Hanger and Landing jt, Land Tubing Hanger and RILDS. RUNCMP R/U Circulating Lines to Landing jt, PJSM with rig crew and truck drivers, Pressure test lines to 3,500 psi. RUNCMP Reversed in 135 bbls of Clean Sea Water, followed by 470 bbls of Inhibited Sea Water at 120 degree at 2 bpm with 960 psi. RUNCMP Monitor well, drop ball and rod, L/D Landing jt. RUNCMP Pressure up on Tubing to 3,500 psi to set packer and test and Pressure up to 3,500 on the Annulus side for 30 chart_ ed . minutes 10/14/2007 00:00 - 00:30 0.50 RUNCO RUNCMP Bleed Off Tubing Pressure to Shear DCR, Pump in Both Directions at 2 bpm with 140 psi. 00:30 - 01:00 0.50 RUNCO RUNCMP ..Set TWC with C Rep. Pressure Tested and Chart TWC to 1,000 psi from below and 3,500 psi above. 01:00 - 02:30 1.50 RUNCO RUNCMP N/D BOPE. 02:30 - 03:30 1.00 RUNCO RUNCMP N/U Adapter Flange and Production Tree. 03:30 - 04:00 0.50 RUNCO RUNCMP Pressure Test Hanger Void to 5,000 psi for 30 mins. 04:00 - 05:00 1.00 RUNCO RUNCMP Pressure Test Production Tree to 5,000 psi for 30 mins on chart. 05:00 - 06:00 1.00 RUNCO RUNCMP R/U DSM Lubricator Pressure Test Same to 250 psi Low and 500 psi High. Pull TWC. L/D DSM Lubricator. 06:00 - 08:00 2.00 RUNCO RUNCMP PJSM w/ Little Red. R/U Lines and PT to 1500 psi. Freeze Protect Well with 140 bbls of Diesel. Pump at 1.5 bpm and 200 psi down IA taking returns up the Tbg. Printed: 10/23/2007 2:59:19 PM • BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: 18-13A Common Well Name: 1 8-13A Spud Date: 11/3/1987 Event Name: WORKOVER Start: 1019!2007 End: 10/14/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/14/2007 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/14/2007 08:00 - 09:00 1.00 RUNCO RUNCMP Line Up Tbg and IA, Allow Diesel to U-Tube for 1 hour. 09:00 - 10:00 1.00 RUNCO RUNCMP Check for equal pressures. Bleed Down and Rig Down circulating lines from tree cap. FMC Install BPV. Install Tree Cap with pressure Gauge. PT BPV from below to 1000 psi for 10 mins on chart. 10:00 - 11:00 1.00 RUNCO RUNCMP Suck Out Lines and R/D Little Red. R/D Secondary Annulus Valve and Install Gauges on Tree. 11:00 - 12:00 1.00 RUNCO RUNCMP Finish Cleaning Pits. Vac Out Slop Tank. Secure Well and Ready to Move Off. Rig Released. Printed: 10/23/2007 2:59:19 PM Digital Well File ~ ~ Page 1 of 1 Weli: 18-13 Welt History Well Date Summary 18-13A 10/22/2007 ***`WELL SHUT IN *'*` (POST RIG WORK) PULLED B & R @ 8590' SLM, ATTEMPT TO PULL 1.5" DCR VLV FROM STA# 3, UNSUCCESSFUL, LOC, LATCH, & PULL RKP-DCR FROM STA #3 @ 3001' SLM (VLV RECOVERED) ***CONTINUE WSR ON 10-23-07*** 18-13A 10/23/2007 ***CONTINUED FROM 10-22-07*"* (post rwo /pre sdtk) RETRIEVED 1.5" DCK FROM STA# 3 @ 3001' SLM, SET 1.5" DGLV (RK LATCH) IN STA# 3 @ 3001' SLM, PULLED RHC PLUG BODY @ 8597' SLM ATTEMPTED TOR DM M I HT FROM 8,592 TO FAST DRILL @ 8,984', RAN 3.80" GAUGE RING, & WORKED AREA TO CLEAN UP @ 8,717' TO 8,733' WLM, .RE-RAN DRIFT W/ 3.71" DUMMY WHIPSTOCK, S/D SOLID ~ 8977' SLM (POSSIBLE FILL MARKS ***WELL S/I ON DEPARTURE, SSV OPEN PER DSO*`* 18-13A 10/23/2007 T!I/O = 100/100/40 Temp = S/I MIT IA PASSED to 3000 psi (CTD prep) Pressured up IA w/5.5 bbls 40*F diesel. MIT IA lost 25 psi in s min an psi in n min or a o a oss of 25 psi in 30 min test. Bled back - 5 bbls. Tagged IA and Master valve with info. All other casing valves open to gauges at departure. FWP's = 100/0/40 18-13A 10!27/2007 T/I/O = 200/70/VAC. Temp = SI. Bleed WHP's to 0 psi (pre-RWO). TBG FL @ 110' (2 bbls). IA FL @ surface. Bled IAP to slop trailer from 70 psi to 0 psi in 5 min (all fluid). Bled TBGP to slop trailer from 200 psi to 0 psi in 30 min {all gas). SI & monitored for 30 min, FL's & pressures unchanged. Final WHP's = O/VAC/VAC. 18-13B 10/27/2007 Set 4" FMC ISA BPV. Set good. 18-13B 10/30/2007 Pulled 4" FMC ISA BPV Print Date: 12/13/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 12/13/2007 • • BP EXPLORATION ` Page 1 of 37 Operatiolns 'Summary Report Legal Well Name: 18-13A Common We11 Name: 18-13A Spud Date: 11/3/1987 Event Name: DRILL+COMPLETE Start: 10/27/2007 End: 11/7/2007 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number. Date.... From - To Hours Task Code NPT Phase 10/30/2007 00:00 - 02:30 2.50 MOB P PRE 02:30 - 03:40 1.17 MOB P PRE 03:40 - 06:00 2.33 MOB P PRE 06:00 - 08:30 2.50 MOB P PRE 08:30 - 10:30 2.00 MOB P PRE 10:30 - 10:45 I 0.25 ~ MOB I P I PRE 10:45 - 12:30 1.75 MOB P 12:30 - 18:00 I 5.501 BOPSUf~ P I PRE 18:00 - 23:00 5.00 BOPSU P PRE 23:00 - 23:45 0.75 BOPSU P PRE 23:45 - 00:00 0.25 BOPSU P PRE 10/31/2007 00:00 - 01:00 1.00 BOPSU P PRE 01:00 - 03:45 2.75 CLEAN P WEXIT 03:45 - 05:30 I 1.751 CLEAN I P I WEXIT 05:30 - 07:45 I 2.251 CLEAN I P I I WEXIT 07:45 - 07:50 I 0.08 {CLEAN { P I I W EXIT 07:50 - 09:00 I 1.171 CLEAN I P I I WEXIT 09:00 - 09:35 ~ 0.58 CLEAN I P I ~ WEXIT 09:35 - 10:10 0.58 CLEAN P WEXIT 10:10 - 10:30 I 0.331 CLEAN I P I I WEXIT 101:10 - 12:30 I 10.331 CLEAN I P I I WEXIT Description of Operations Move rig from X-pad to DS 18. Via the Spine, Oxbow & West dock road. Rig is on the Spine road. Rig is on the Oxbow road. Finish move to DS 18. Park in front of well and set down Find ceNar mats and herculite and set same MIRU main camp. Spot satellite camp Repair Baker choke Safety mtg re: move over tree Move rig over tree and set down (took a couple tries to get it right) Accept rig at 1230 hrs 10/30/07 ND tree cap. NU 7-1/16" BOPS. RU IA, OA gauges. Bring on rig water. Bring on 2% KCL water. RU hardline to TT & P.T. to 4000psi- good test, bled off. Spot cuttings box. Off load trailers. Get comms hooked up. Hook up comms to office shack. Get BOPE measurements. Lay out traction mats around rig/office/camp entrance's. SLB performing chain inspection, & replacing pins. Grease choke & kill line valves & all other associated valves. fnstalf night cap & hose to test pump. Fill stack with a clear nonalcoholic liquid aka H2O. Conduct BOP test as per PTD abd AOGCC Representative John Crisp Held PJSM on pulling BPV. Install lubricator and PT same to 2000 psi Pulled BPV pout and RD Valve Crew. WHP = 0 psi PU Injector and installed CTC and pull tested to 30k Pumped 6 bbl diesel to cutting box PT the CTC to 3500 psi. PU BHA Set counters and RIH to 200 ft, Open EDC, RIH displacing diesel to TT. Bring all well fluids up to 2 ppb biozan, Tag up at 8650' (overshot). Close EDC & pump through mil. Bobble past overshot. Continue to RIH. WT ck @ 8900' = 37k, RIW = 17K. Increase pump rate to 2.6bpm/2460psi. Slowly RIH & lightly tag Fas Drill Plug @ 901T. PUH slowly while .circulating bottom's up before milling on Fas Plug. Bottom's relieved various rig treats -silicone, electrical tape, bits of rubber, small bits of metal. Pump 5 bbls of Hi-Vis Bio. RIH to top of Fas Drill Plug. Bleed down IA from 900psi to 65psi to the TT, gas and diesel. Tag up @9016.3'. Stal13 times. 6k overpull. Ease on downhole, 0.1' every 1 min. Keep stalling at 9015.3', losing hole. PU, dragging something up hole 20k over. PU to 8960'. Pump 10bb1 Hi-Vis sweep. 9016.3' & stacking weight, not seeing any WOB, pill out of bit. PU to 8000' (40 degrees) & chase pill uphole WT=36k up. Dragging something up hole' 3k over. Small chunks of rubber coming across the shaker. Small chunks of composite Fas Drill plug coming across shaker. RIH to bottom. Didn't see anything while RIH past overshot @ 8650' B.O.B. 2.64bpm /2575psi. loosing returns. 2.78in/1.10out. Drop rate & POH & swap to flo-pro. Dragging something up hole. Increase pump rate. Printed: 12/512007 11:06:22 AM • • BP EXPLORATION Page 2 of 37 Operations Summary Report Legal Well Name: 18-13A Common Well Name: 18-13A Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA .,Rig Name: NORDIC 2 Spud Date: 11/3/1987 Start: 10/27/2007 End: 11/7/2007 Rig Release: Rig Number: Date (From- To ~ Hours I Task ~ Code ~ NPT ~ Phase ',10/31/2007 ! 12:30 - 13:25 I 0.921 CLEAN I P 1 1 WEXIT 15:05 - 15:40 I 0.581 CLEAN ~ P I I WEXIT 15:40 - 18:51 3.18 CLEAN P WEXIT 18:51 - 22:15 3.40 WHIP P WEXIT 22:15 - 00:00 1.75 WHIP P WEXIT 11/1/2007 00:00-00:30 0.50 WHIP P WEXIT 00:30 - 01:30 1.00 WHIP P WEXIT 03:15 - 03:40 I 0.421 WHIP (p I WEXIT WEXIT 05:30 - 06:00 ~ 0.501 WHIP N I DFAL I WEXIT 06:00 - 06:20 I 0.33 WHIP N DFAL WEXIT 06:20 - 07:00 0.67 WHIP N DFAL WEXIT 08:20 - 08:40 I 0.33 ~ WHIP ~ N I DFAL I WEXIT 08:40 - 09:00 0.33 WHIP N DFAL WEXIT 09:00 - 09:05 0.08 WHIP N DFAL WEXIT 09:05 - 09:45 0.67 WHIP N DFAL WEXIT 09:45 - 10:05 I 0.331 WHIP I N I DFAL I WEXIT 10:05 - 10:50 I 0.751 WHIP I N I DFAL I WEXIT 10:50 - 13:40 I 2.831 WHIP I N I DFAL I WEXIT Description of Operations Resume milling on Fas Plug. from 9014' @ 2.64bpm/3025psi. 2.4 bpm out. (30bbls away & losses recovered). Push plug to bottom @ 40'lmin. WT ck= 38k at 11300'. Stop pumping @ 11300' & push Fas dri{I plug past MLAS jt @ 11345'. Resume pumping at 11420' & continue to push plug to bottom. Tag bottom at 13017'. Open EDC & POH, WT=38k. LD BHA (3 bladed junk mill had severe scarring, multiple chipped teeth & motor had light scarring}. PU WS / KB Packer WS, setting tool and Coiltrac BHA RIH with WS BHA RIH with WS BHA Starting at 8600 ft, seen some set downs and lost returns while running in the hole.. Pushing something ahead of us. Worked down and at 8784 ft decided to POOH and clean this thing up. Unable to PUH, work CT Pulling between 50 k up and 1k down String wt at this depth = 36 k up and 20 k down Worst spot is the 8800 ft Not seeing WOB from sensor and orienter is turning freely. Had to pull up to 62k to get free No evidence of pulling on the tool, hung up somewhere above the CTC. POOH, ordered out 3-1/8" Venturi Basket with 3-5/8" "shoe. LD Coiltrack and discovered that the packer and WS are left in the hole Wait on fishing tools PU Fishing Hook BHA. Check out BHI tools on catwalk. Scribe WS hook. CO w/ day crew. PJSM regarding handing fishing tools. PU whipstock hook. PU BHI tools. PU injector & MU to tools. Stab onto well. Power up & check tools. RIH with whipstock pulling tool (slightly bent hook). WT ck @ 7500' = 30k, RIW = 13.5k. Pump 10bb1 sweep of 2ppb bio (left over from yesterday). 1.5bpm/2000psi. Orientate hook 57 degrees ROHS. Slow down RIH speed to 40'/min. WT ck @ 8000' = 31 k, RIW = 15.5k. Slowly RIH @ 40'/min. Circulating at 2.2bpm/2500psi. Out MM is intermittently plugging up with debris, purge/blow down w/ air. WT ck = 33k, RIW = 17k. Tag fish. CBU @ 2.2bpm/2660psi. Bottom's up revealed nothing of interest. Reduce to min rate. Try to latch @ 50 deg ROHS - no go, sat down at 8818'. Try 30 deg ROHS - no go, sat down at 8818'. Try 20 deg LOHS, saw top of WS at 8814', sat down at 8817'. PU to 38k & set brake, -5k DHWOB. 1k jar lick. PU, 69k & lost returns (element released). PU to 92k & slack off to 60k. Try 3 times increasing speed each time. Slack off to 40k & up to 92k. Lost DHWOB sensor. No movement. Tum pumps off w/ 92k up (59k at the bit). Make calls to the SLB for guidance on coil life. Pressure up coil to 1000 psi. Popped free! Slowly PUH & try to orientate. DHWOB sensors works & is showing drag. Can't orientate, torqued up. Coil wt=33k. Slowly PUH through profile @ 8696' & watch for overpull. POH Printed: 12/5/2007 11:06:22 AM • BP EXPLORATION Page 3 of 37 Operations Summary Report Legal Well Name: 18-13A Common Well Name: 18-13A Spud Date: 11/3/1987 Event Name: DRILL+COMPLETE Start: 10/27/2007 End: 11/7/2007 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase 11/1/2007 110:50 - 13:40 I 2.831 WHIP I N I DFAL I WEXIT 13:40 - 14:40 I 1.001 WHIP I N I DFAL I WEXIT 14:40 - 18:50 I 4.171 WHIP I N I DFAL I WEXIT 18:50 - 19:30 0.67 WHIP I N DFAL WEXIT 19:30 - 22:16 2.77 WHIP N DFAL WEXIT 11/2/2007 100:00 - 02:015 I 2.251 WHIP N ~ DFAL I WEXIT 02:15 - 05:00 I 2.751 WHIP I N I DFAL I WEXIT 05:00 - 05:20 I 0.331 WHIP I N I DFAL I WEXIT 05:40 - 07:45 I 2.081 WHIP I N I DFAL I WEXIT 07:45 - 09:35 I 1.831 WHIP I N I DFAL I WEXIT 09:35 - 10:30 I 0.921 WHIP I N I DFAL I WEXIT 10:40 - 12:20 I 01.67 WHIP ~ N I DFAL ~ WEXIT Description of Operations @ 50'/min. BHI tool shorted out @ - 8000' while POH. PJSM while POH regarding handling BHA. Flow check at 200'. Pop off well & slowly PUH. At surface. Pulled out of the coil connector, shallow grooves from set screws & small dings in the pipe. Make series of phone calls to numerous people. E-line pulled out of the anchor, recovered 225' of a-line cable (157' of a-line slack still inside reel). Cut off 10' of coil. Terminate a-line cable. Wait for BOT venturi BHA components. Bore out 2-3/8" BOT connector to 1.25" ID. Modify 3-7/8" Bowen overshot for SLB CTC. Load 6 jts of 2-3/8" PH6 into pipe shed. Installed modified CTC (1.25" ID) and BHA with Venturi Basket RIH Started circ at 2.2 bpm CTP at 3,700 psi at 5,000 ft Tagged at 8743 ft (Top of CTC) twice POOH OOH, RU to stand back PH6 tubing Recovered 1 small piece of rubber. LD Venturi Basket. PU OS (3.18" Grapple) BHA. TOF at 8,743 ft MD. PU Injector, set counters RIH Op = 0.44 bpm at 1564 psi. Set down at 8,518 ft, X nipple oriented 10 clicks, worked through. RIH, set down in the Packer at 8,559 ft, oriented and worked through. Tagged the "X" nipple below the packer at 8,593 ft took 16 clicks. RIH and tagged the next "X" Nipple at 8,623 ft Took 109 clicks to get past. RIH and set down in the packer area at 8663 ft CTMD. Orient and worked through. RIH to 8730 ft. Weight check up = 34.511bf at 1/2 bpm. 19k down, PU at 37.8 klbf wo /pump. RIH to look for fish and latch Latched fish at 8741 and set grapple. PUH and fish started to move at 67,324 Ibf. POH dragging through nipples Dragging 3000 Ib extra Pulled heavy through all nipples POOH. Weight bobble at 2942' (upper GLM @ 3009') while POH. Continue to POH. PJSM while POH regarding handling BHA. No drag or surge through profile at 2110'. Stop at 500'. Flow check. Pop off well. Set BHA in slips w/dog collar. Undo BOT slip CTC (reduce the chance of spinning off the fish from overshot). Slowly stand back 4 stds of 2-3/8" PH6 in derrick. Slowly hoist up BHA to overshot. LD fishing BHA. Recovered BHI fish. LD BHI coiltrac BHA. 3-7/8" Bowen .overshot heavily/deeply scarred w/ numerous dents. Whipstock still in the hole. Clean up RF. Fill hole -took 3bbls. Clean BOT fishing tools. Take pictures of overshot 8 send to 'town. Take Bowen overshot apart. All 12 set crews were sheared at the knurled end of the screw. Take BHI XO's (reg to pac) & float sub to tuboscope for inspection. Test BHI tools - tested ok. PJSM regarding Venturi BHA handling. PU venturi basket. Break apart basket 8 inspect upper filter (plugged). Clean filter - 1/41b of metal debris recovered (small brass pieces, small flat metal band pieces, possible slip material, coil shavings -cut from chrome tubing). Continue to MU venturi basket BHA. MU BOT CTC. Pull test to 40k & PT to 4000psi. Hydraulic weight indicator & hydraulic pressure supply Printed: 12/5/2007 11:06:22 AM • • BP EXPLORATION Page 4 of 37 Operations Summary Report Legal Well Name: 18-13A Common Well Name: 18-13A Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 11/3/1987 Start: 10/27/2007 End: 11 /7/2007 Rig Release: Rig Number: Date I From - To i Hours, Task I Code ~ NPT ~ Phase 11/2/2007 112:20 - 15:10 I 2.831 WHIP ~N DFAL WEXIT 15:10 - 16:40 ~ 1.501 WHIP ~ N I DFAL I WEXIT 16:40 - 18:00 1.33 WHIP N DFAL 1 WEXIT 18:00 - 20:30 I 2.501 WHIP I N I DFAL I WEXIT 20:30 - 23:00 I 2.50 WHIP ~ N (DFAL WEXIT 23:00 - 00:00 1.00 WHIP N DFAL WEXIT 111/3/2007 100:00 - 00:35 I 0.581 CLEAN 1 N I DFAL I WEXIT 00:35 - 01:30 I 0.921 CLEAN j N I DFAL I WEXIT 01:30 - 03:15 I 1.751 CLEAN j N j DFAL I WEXIT 03:15 - 04:30 1.25 CLEAN N DFAL WEXIT 04:30 - 05:30 1.00 FISH N DFAL WEXIT 05:30 - 06:30 1.00 FISH N DFAL WEXIT 06:30 - 08:00 1.50 FISH N DFAL WEXIT 08:30 - 09:00 I 0.50 ~ FISH I N I DFAL WEXIT 09:00 - 11:55 I 2.921 FISH i N I DFAL I WEXIT 11:55 - 12:10 I 0.251 FISH ! N I DFAL I WEXIT 12:10 - 13:05 I 0.921 FISH I N I DFAL I WEXIT Description of Operations gauge & CCAT read accurately +/- 10001b dill. RIH with venturi BHA. Lost 11 bbls white RIH to 8800'. Weight booble at 8150'. WT ck = 38k, RIW = 18.7k @ 8700'. Tag at 8810'. PU, 3k overpull. PU to 8750' &venturi down to B810' 2.3bpm/3900psi. PU to 8700' &venturi down to 8810'. POH @ 20'lmin up to 7700' while venturing. POH while pumping at 2.3bpm/3900psi. PJSM while POH regarding handling BHA. Flow check well. Pop off well. Stand back 4 stds of 2-3/8" PH6 tubing. Break apart venturi basket. Barrel was empty. Filter was plugged with metal shavings from coil, 1 piece of a metal bearing 1/4"x1/2", 4 ends of alien set screws from coil connector, large brass shear stock 1!4" to 3/4" OD in size, numerous slip pieces ranging in various sizes 3/4"x1/2", 2 large pieces of rubber from composite plug - 21b of steel/brass/rubber. Discuss with WSL & town. Ordered ou WL with extra wt bars, junk baskets and pump- bailer. Cut off 100 ft CT and installed new BOT CTC. Pull tested to 40k and PT to 3500 psi RU Wireline and PU JB / Gr RIH with 3.625" GR and junk basket Tagged at 8650 ft, Worked through tp 8716 ft. PUH and had to jar out od hole ,through all X nipples. POOH OOH with 1st JB run and recovered a few small piecies of metal The GR had a large groulge in it, dress up and RIH with GR #2 'RIH with JB/ GR tagged at 8,829 ft PBTD, POOH Clean PUH through nipples RIH with 3.5" Pump Bailer Pumped 15 min at 8829 ft. POOH and recovered 4 small pieces. RD Wireline RU to PU OS to fish WS and KB Packer PU HDC (5/8" ball) Wait for BOT to bring 5/8" ball disconnect. PJSM regarding handling BHA. MU fish BHA, inspecUredress overshot. PU 4 stds of 2-3/8" PH6. Forgot check valves. Stand back 4 stds of 2-3/8" PH6. Stab floor valve & wait. Inspect BHA. PJSM regarding handling BHA. MU BHA, PU 4 stds of 2-3/8" PH6. PU injector & MU to BHA. Set counters 8 RIH. WT ck = 38k up @ 8450'. Tag at 8518'-profile (bobble through it), 8548'-packer(bobble through it), 8583'-profile (3 attempts & bobble through it), 8670'-packer (bobble through it), 8710'-profile (bobble through). These depths are similar to previous set downs on prevoius runs (over torqued collars? rotten rubing? ballooned collars from setting numerous packers?. WT ck @ 8800', can't come up. On fish? Lost 11bbls while RIH. Start pumping at 1bpm to cock jars. 1 bpm/2220psi. Popped free, jars did not go off. WT ck = 33.5k up. Continue to RIH. RIW = 19k Set down @ 8810'. PU free-38k. Bleed of CTP, set down @ 8812', set 5k down. PU free-38k, Set down at 8816'. Push down to 8824', RWt=12k. PU 39k, stop at 8750'. RiH. Set down at 8825'-5k down. PU - 38k. RIH faster @ 60'/min & set down Printed: 12!5!2007 11:06:22 AM • • BP EXPLORATION Page 5 of 37 Operations Summary Report .Legal Well Name: 18-13A Common Well Name: 18-13A Spud Date: 11/3/1987 Event Name: DRILL+COMPLETE Start: 10/27/2007 End: 11/7!2007 Contractor Name: NORDIC CALISTA Rig Release: 'Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/3!2007 12:10 - 13:05 0.92 FISH N DFAL WEXIT at 8825'. PU - 41k stop at 8806'. Pump down backside & pressure up to 600psi (0.5bbls) &RIH. Set down at 8823', pressure fell to 200 psi. Pushing down hole. Set down at 8834', popped free. Stop RIH at 8838'. Bleed off pressure. PU-40k, no returns. RIH -- 25'/min, set down at 8853'. PU-38k. Set down at 8853'. Pump down coil. 1bpm/2245psi. PU - 35k. set down at 8853', slight booble and set down 5k to 8855' - no pressure increase. 500# jar lick down. Stop pumping & set down 5k, bleed off pressure. PU - 42k & lost 2k. RIH - 20k. Set down at 8853', 1 k jar lick down. 13:05 - 13:50 0.75 FISH N DFAL WEXIT PU & cock jars. 1 k jar lick down. PU -50k & popped free. RIH - 21 k, set down at 8855'. Push down hole to 8867' - 10k down. Jar down 10k jar lick. PU 45k, jar up 2k, PU to 50k. RIH to 8874'. PU to 8861' - 45k & sit. Pressure up backside to 750 psi (1bbl), jars went off. PU -lost 500psi of WHP, weight fell off- lost 7k. Keep PUH. Over pull at 8823'. Keep PUH. Over pull at 8779', 8772', continue to PUH. Pulling heavy at 8707', pressure up well to 750psi (1bbl). Popped free. Pulled heavy at 8622' 8592' 13:50 - 15:20 1.50 FISH N DFAL WEXIT Fill across top & POH. Pulled heavy & stop at 8525'. Pressure up backside to 750 psi. Move down hole. PU 43k & sit at 8527', jar lick. RIH & cock jars. PU to 50 at 8525'. RIH, WHP drops while RIH. PU & pressure well to 1000psi (1 bbl). Dump pressure. 3k jar lick. PU to 8524.6' @ 52k. RIH, cock jars. PU to 52k @ 8525'. 3k jar lick. RIH, cock jars. PU to 53k @ 8525'. Repeat. 12 jar licks up. Set down at 8534' w/ 10k, pressure up well (1 bbl). Jar lick down &RIH to 8597 & set down. PU 60'/min to 8525' (acts like swabbing). Jar up 8 times. Pressure up (1 bbl) & jar down twice. RIH & set down at 8596'. 15:20 - 15:40 0.33 FISH N DFAL WEXIT Wait at 8676' and let coil warm up & jars cool off. 15:40 - 15:45 0.08 FISH N DFAL WEXIT Put injector in high gear &PUH @ 90'/min. Saw a bunch of profiles, going to fast to write down. 15:45 - 16:50 1.08 FISH N DFAL WEXIT POH filling across top. 3k overpull at 2110' -profile. PJSM while POH regarding handling BHA. 16:50 - 17:50 1.00 FISH N DFAL WEXIT Stop at 300'. Flow check well. Pop off. PUH to CTC. Put BHA in slips & dog collar. Undo BOT CTC & unstab from CTC. Place injector over bung hole. Stand back 4 stds of 2-3/8" PH6 tubing. PU rest of BHA. 17:50 - 18:00 0.17 FISH N DFAL WEXIT No fish. Overshot was heavily scarred on low side of tool. Large split & hole on bottom (3/4"} of overshot. Approximately 4 collets left in hole, (1 "x4") from overshot. Take pictures, discuss with WSL & town engineer. Ordered out Wireline. 18:00 - 19:45 1.75 FISH N DFAL WEXIT Talked to town and planned way forward. Wait on Wireline 19:45 - 23:00 3.25 FISH N DFAL WEXIT RU Wireline Unit 23:00 - 00:00 1.00 FISH N DFAL WEXIT RIH with 3.625" JB with 3.625 TS RIH and tagged the top of the 4-1/2" stub at 8646 ft. Unable to get past the top. POOH No recovery in junk basket Removed top 3.625" TS and RIH 11/4/2007 00:00 - 01:45 1.75 FISH N DFAL WEXIT RIH with JB Set down at 8,652 ft. The top of the 4-1l2" stump Working to get past Set down at 8,822 ft, PU and pulled 200 Ib over. RIH and set down at 8,827 ft. Solid tag. DAYLIGHT SAVING TIME CHANGE 01:45 - 03:00 1.25 FISH N DFAL WEXIT POOH with junk basket. No recovery in junk basket. No extra marks on JB or stem. Printed: 12/5/2007 11:06:22 AM • • Legal Well Name: 18-13A Common Well Name: 18-13A Event Name: DRILL+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig (Number: Date From - To Hours Task Code NPT Phase I 11/4/2007 03:00 - 04:00 1.00 FISH N DFAL WEXIT 04:00 - 05:45 1.75 FISH N DFAL WEXIT 05:45 - 07:20 I 1.58 ~ FISH I N DFAL WEXIT 07:20 - 08:06 0.77 FISH N DFAL WEXIT 08:06 - 08:40 I 0.571 FISH I N I DFAL I WEXIT 08:40 - 08:55 I 0.251 FISH I N I DFAL I WEXIT 08:55 - 10:00 I 1.081 FISH I N I DFAL I WEXIT 10:00 - 11:00 1.001 FISH I N I DFAL WEXIT 11:00 - 11:35 I 0.581 FISH I N I DFAL I WEXIT 11:35 - 11:40 0.08 FISH N DFAL WEXIT 11:40 - 12:20 0.67 FISH N DFAL WEXIT 12:20 - 13:00 I 0.671 FISH I N I DFAL I WEXIT 13:00 - 13:30 I 0.501 FISH I N I DFAL I WEXIT 13:30 - 15:30 f 2,001 FISH I N I DFAL I WEXIT 15:30 - 16:30 I 1.001 FISH I N I DFAL I WEXIT Page 6 of 37 Spud Date: 11/3/1987 10!27/2007 End: 11/7/2007 Description of Operations RD wireline PU milling BHA 3.79" mill & 3.79" string reamer with 8 jts of 2-318" PH6 InstaN CTC, Pull test to 40k and PT to 3500 psi. RIH. Mix to-vis sweep in pill pit. Clean ditch magnets. WT ck = 33k @ 8400' pumps off. WT ck = 32k @ 8500' 2.3bpm/3300psi. Tag at 8500' mill/back ream section until clean @ 0.5'/min (300psi motor work)- profile at 8518'. RIH @ 15'lmin looking for next set down. Motor work at 8567'- profile at 8583', work area until clean. Motor work at 8628'- overshot at 8644', work area until clean. Pump 5 bbl of to-vis sweep. Stall! at 8630'- overshot, clean PU. Mill/back ream section until clean. Stall 8628'. Pump 5 bbls to-vis followed by 5 bbls hi-vis pill. RIH to 8820' & no tag. Back ream from 8820' @ 10'/min. Motor work at 8711'. Motor work at 8681'. Bottom's up from fo-vis pill revealed rubber pieces & milled up brass & metal pieces. RIH to bottom. @ 8820', let pill come out of mill & back ream. Motor work @ 8711', work area. Back ream up. Motor work @ 8681', work area -major problem area w/ lots of motor work. RIH from 8670' to 8685' - no motor work while RIH. PU @ 6'/min through area. Large pieces of rubber 2"x3", 3 in total from BU, samll milled up pieces of brass & metal. Back ream from 8685' to 8627'. Motor work at $627', work area. Pump 5bbl to-vis & 5 bbl hi-vis sweep. Motor work at 8529' & 8499', 8490' Mill down @ 10'/min. Bottom's up rerevealed large pieces of rubber 3"x3" 3 in total, pieces of composite plug, large milled up brass pieces & metal pieces, clean ditch magnets -large square pieces of metal. Slight motor work at 8494', 8502', 8532', 8597',8715'. Stop at 8820'. Turn pumps off. RIH & tag. Set down (3k) at 8830' but popped through. RIH. 8880' set down & keep pushing & set down at 8886' (5k). Start pumping 2.3bpm/3230psi. Pump 5 bbl of to-vis & 5 bbls of hi-vis. PU & look for motor work -clean. RIH to 8875'. Turn pumps off & tag fish @ 8888'. PU to 8875 & pressure up backside to 750 psi. RIH & tag fish. Push to 8892'. Bleed off pressure - WHP didn't change. Pump down coil while slow{y PUH to get pill out of coil. Pump pill from 8875' & chase it out of hole @ 17'/min. Slight motor work at 8711',8590', 8530'. PUH to 8500'. Turn pumps off &RIH to 8742'. Set down at 8742'. PU clean. RIH - no more set downs. Start pumping 2.4bpm13500psi. Rubber pieces & small chunks of metal (banding) coming across the shaker. -71bs of metal debris hitting the out MM all at once, big increase in density, inspect shaker -metal cuttings & metal hairbaits. POH to surface. PJSM while POH regarding handling BHA. Tag up. Flow check well. Pop off. Unstab from BHA. Place injector over bung hole. Stand back 4 stds of 2-3/8" PH6 tubing. PU rest of BHA. Milk motor. Mill is 3.73" No Go, string reamer is 3.75" No Go. BP EXPLORATION Operations Summary Report Printed: 12/5/2007 11:06:22 AM • • BP EXPLORATION. Page 7 of 37 Operations Summary Report. Legal Well Name: 18-13A Common Well Name: 18-13A Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date I From - To I Hours I Task I Code I NPT I Phase Spud Date: 11/3/1987 Start: 10/27/2007 End: 11/7/2007 Rig Release: Rig Number: 11/412007 116:30 - 17:50 I 1.331 FISH I N I DFAL I WEXIT 17:50 - 19:50 I 2.00 I FISH I N I DFAL I WEXIT 19:50 - 21:45 1.92 FISH N 11 /5/2007 ~ 00:00 - 01.00 10.00 ~ FISH I N I DFAL ~ W EXIT 01:00 - 02:15 I 1.251 FISH ~ N I DFAL I WEXIT 02:15 - 03:45 +I 1.50 FISH N +I DFAL +I WEXIT 03:45 - 06:00 2.25 FISH N DFAL WEXIT 06:00 - 07:10 I 1.171 FISH I N I DFAL I WEXIT 07:10 - 09:30 I 2.331 FISH I N I DFAL I WEXIT 09:30 - 10:30 I 1.001 FISH ~ N I DFAL I WEXIT 110:35 - 13:30 I 1.921 FISH N I DFAL I WEXIT Description of Operations PJSM regarding PU BHA. PU BOT box tap overshot BHA. Torque ail connections. PU injector. MU coil to BHA. Stab onto well. RIH to 8870 ft Wt check at 8870 ft = 33.7/34.5 wo pump. RIH and tagged at 8893 ft Inc pump to 1.5 bpm and Pp inc 3,500 psi. No stall. PUH 4k allow jars go off, NO, PUH to 6k and jars didn't go off. Cycled and PU to 8 k over and pop off. Worked Box tap and was unable to get rolled over lip. Tried PUH and RIH from 8,888 ft to 8,893 ft at 0.05 ft per stage. 3.625" Box fap is riding up on the tray of the WS. Motor constant = 0.26 gal/rev Tried several things and was unable to get the BT over the TOWS Worked slowly down and saw 500 psi Pp inc at 8893.08 ft No stall. Tried to latch without success. Tried more wt and higher Op still unable tp latch POOH to look at Box Tap Stood back 4 stds 2-3/8" PH6 LD box tap No evidence the whipstock was inside the box tap. The mule shoe part of the box tap is completly missing. Sent pictures to town. Clean floor and low WFT fishing motor and .3.80" Box Tap in the Pipe shed PU BHA, Changed out Box tap, motor and accelerator ~ RIH with 3.8" box tap Wt check at 8500 ft. 33.6 k. RIH and had to work the Box Tap through X nipple at 8518 ft and Packer at 8548 ft. RIH Worked through X nipple at 8583 ft RIH and tagged and stall at 8894.30 ft. Working the box tap over the WS Jar down 6 times. Jar up & pops off fish. Pressure up backside. Jar up, still have hold of fish. Pump down coil & jar down. 3 licks down, keep WHP at 1500psi &WHP dropped to 900psi. Fish moving down hole. Pressure WHP to 1500psi & jar lick down. WHP dropped to 900 psi. Bleed of pressure & pump down coil. 1.5bpm/2900psi, keep there for 2 min, pressure is coming down & weight is coming up -packer is spinning. Reduce rate to 0.75bpm/1950psi. Slowly close choke to maintain -500psi. Top of fish at 8899.8' with neutral weight. Stacking weight, pressure up WHP to 1000psi. Pump down backside at 0.25bpm/1700psi. Fish at 8935.8' (packer is catching collars). PU to 45k &RIH at 70'/min keeping WHP constant at 1800 psi. Repeat as necessary. Occasionally bleed off WHP & pump down coil to spin fish & also warm up coil 0.75bpm/2100psi. Beat down on fish at 9061'. Try to pressure up on the WHP & coil. Try to spin past tight spot -motor in stall position. Mix up lubricious pill in pill pit. Jar down 44 times - no movement. Jar up 2 times. Pulled free offish. Pump tube pill down coil. 0.75bpm/1780psi. 1.5bpm/2400psi. Pump 10 bbls of tube pill out coil. Close choke & pressure up backside. Injecting at 0.42bpm/1575psi, inject 5 bbls past fish. Bleeb off WHP, cir down coil & try to latch fish. Latched fish. Jar down 4 times. Slipped off while trying to cock jars. Attempt to latch fish again. Latched, beat down 45 times. Jar up twice, Pulled off. Printetl: 12/5/2007 11:06:22 AM • • Legal Well Name: 18-13A (Common Well Name: 18-13A Event Name: DRILL+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date I From - To } Hours ~ Task ~ Code I NPT ~ Phase 1115!2007 113:30 - 16:00 I 2.501 FISH I N I DFAL I WEXIT 16:00 - 17:20 I 1.331 FISH I N I DFAL I WEXIT 17:20 - 23:15 I 5.921 FISH I N I DFAL I WEXIT 1116/2007 100:00 - 02:105 I 2.251 FISH I N ~ DFAL WEXIT 02:15 - 04:35 I 2.331 FISH I N I DFAL I WEXIT 04:35 - 07:00 2.42 FISH N DFAL WEXIT 07:00 - 09:30 2.50 FISH N DFAL WEXIT 09:30 - 11:00 I 1.501 FISH I N I DFAL I WEXIT 11:00 - 17;30 I 6.501 FISH I N I DFAL I WEXIT 17:30 - 19:30 i 2.001 FISH I N I DFAL I WEXIT 19:30 - 21:00 I 1.501 FISH I N I DFAL I WEXIT 23:00 - 00:00 I 1.00 I CLEAN + N I DFAL +WEXIT Page 8 of 37 Spud Date: 11 /3/1987 10/27/2007 End: 11/7/2007 Description of Operations Pulling heavy. POH fisting across top. PJSM while POH regarding BHA handling. Pop off well, PUH inspecting the CT for ovality problems and physical damages. Stand back 4 stds of 2-3/8" PH6 tubing. Break off lower section of BHA. BOT pull disconnect has released from BHA. Discuss with town. Loaded 10 DC in pipe shed. prep and tally. RU and cut off 120 ft CT, Installed BOT's CTC and pull tested to 45k and PT to 3500 psi. PU BHA #11 Stab on well with injector RIH WT check at 8500 ft = 40.7k1b RIH and tagged the top of the fish at 9053 ft with hydraulic GS. PU and fish is latched. Set down and try and jarring up with low string wts Jarring down. Pressured up on the annulus to 500 to 1000 psi while jarring down on fish. SD after 15 jars and heat up CT and cool jars. RIH after 38 jar licks and removing the wellhead pressures. Set down again at 9,109 ft Jarring down through 4-1/2" collars. Spent a lot of times at 9234 ft ("X" Nipple ). With over 100 licks, 9,381 coil life is at 49 % fatigue. POOH to cut pipe. Need to cut 400 ft which will leave us 14,337ft and 500,000 running feet. PJSM while POH regarding handling BHA. Flow check. Pop off well. Place injector over bung hole & circulate. Stand back 4 stds of 2-3/8" PH6 & 5 stds of 3-1/8" drill collars in the derrick. Putl BHA to surface. Inspect GS for wear -minor wear to GS, dogs are rolled but very minor, small piece of brass in skirt -other wise in good condition. Fill hole 1bbl. Clean up RF of BOT tools. Discuss plan forward with town -cease fishing ops (plan to set whip, begin Mill/FCO ops. Call for 3.80" DS 331 mill. Swap out elevators to PU 2-3/8" PH6 tubing. PJSM regarding handling BHA. Function test BOPE, weekly test per AOGCC. PU mud motor & spin to verify. MU 3.80" DS 331 PBM w/ 3.80" string reamer, 2-718" MM,CS, Disco, Jars, DCV's & 4 stds 2-3/8" PH6 tubing (torque all connections to spec). PT CS & Disco on work bench to 4k -good. Inspect 80T CTC. Set counters &RIH. Wt check at 8500 ft 36.5k. Inc Op to 2.00 bpm and RIH cleaning out "X" Nipple area Mini stall and took wt at 9,000 ft ? Pumping 140kLSRV down hole and cleaned up, didn't see the 2nd time through it. RIH to 9210 ft, wt check = 36k, SD and dry tagged top of fish at 9233 ft. Circulated at 2.5 bpm CTP at 3600 psi sweep down and chase out of hole. PUH to 7000 ft and RIH at 90 fpm pumping i sweep # 3 to 9230 f. Pumped 4th sweep, RIH and chased up hole. Dropped 1/2 ball i Displace 1/2' ball to cir sub and open same with 4000 psi. POOH jetting mandels. Picked up some trash while jetting the GLM at 6225 ft. Pumped 20 bbl sweep, PUH chasing it to surface. Hold PJSM to discuss handling BHA. At surface. Stand back PH6 pipe. Lay down tools. Make up swirl nozzle BHA. Get on well. Run in hole. Wash across each GLM. Pump 20 bbl hi vis sweep once on BP EXPLORATION Operations Summary Report Printed: 12/5/2007 11:06:22 AM • • BP EXPLORATION Page 9 of 37 Operations Summary Report Legal Well Name: 18-13A Common Well Name: 18-13A Spud Date: 1 1 1311 9 8 7 Event Name: DRILL+COMPLETE Start: 10/27/2007 End: 11/7/2007 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11!6!2007 23:00 - 00:00 1.00 CLEAN N WEXIT bottom. 111712007 00:00 - 03:00 3.00 CLEAN N DFAL WEXIT Continue to wash GLMs with nozzle assembly. Circulate hi vis sweep and chase out of hole. 03:00 - 04:00 1.00 CLEAN N DFAL WEXIT Rmove nozzle. Make up venturi assembly. Get on well. 04:00 - 07:15 3.25 CLEAN N DFAL WEXIT Run in hole. Ran 2-10 bbl and 1-20 bbl sweep while working venturi basket from 8500 ft to 9223 ft POOH while pumping at 3.00 bpm 07:15 - 11:30 4.25 CLEAN N DFAL WEXIT Stand back PH6 and break down venturi basket. Broke down basket and recovered a couple of small pieces of metal. LD venturi basket PU Dummy WS and DC and PH6 tubing 11:30 - 14:48 3.30 CLEAN N DFAL WEXIT RIH with Dummy Whipstock. Tagged at 9,240 ft CTMD. POOH 14:48 - 17:00 2.20 CLEAN N DFAL WEXIT LD 2-318" PH6 tubing and 10-3" DC and dummy whipstock 17;00 - 17:30 0.50 WHIP N DFAL WEXIT Held PJSM on pumping slack 17:30 - 18:30 1.00 WHIP N DFAL WEXIT Rig up. Reverse circulate to pump a-line back in to reel. Heard lots of movement insdie pipe. 18:30 - 21:30 3.00 WHIP N DFAL WEXIT Cut 440' of coif and 36' of wire. Re-head coil connector. Pull and pressure test same. Continuity good. 21:30 - 22:30 1.00 WHIP N DFAL WEXIT Hold PJSM to discuss handling BHA. MU whip stock and setting tools. Scribe to Inteq orienter. Stab coil. Get on well. 22:30 - 00:00 1,50 WHIP N DFAL WEXIT Open EDC. Run in hole.l8k# do wt, 34k# up wt at 8700'. RIH to tie in depth. 1118!2007 00:00 - 00:30 0.50 WHIP N DFAL WEXIT Continue to RIH with whipstock. Losing 3 bbls mud per 1000' initially, then began to get proper hole fill. 00:30 - 00:45 0.25 WHIP N DFAL WEXIT Log gr tie in from 9,125'. Subtract 6' correction. 00:45 - 02:00 1.25 WHIP N DFAL WEXIT Log CCL tie in from 8500'. On depth with PDC log. Collars running about 13' deep compared to tubing detail. Tbg collar at 9190'. Set TOW 1 tray top at 9200'. 02:00 - 02:15 0.25 WHIP P WEXIT Close EDC. Orient for tray face to low side. Pressure coil to 3950 psi. Tool sheard, whipstock appears to be set. 34.5 k# up wk. 02:15 - 03:45 1.50 WHIP P WEXIT Circulate out of hole. 03:45 - 04:30 0.75 WHIP P WEXIT Lay down Baker whipstock setting toots and other Inteq mwd tools. C ,~ ~ " 04:30 - 05:15 0.75 STWHIP P WEXIT Pick up window milling BHA including string reamer and two jts ~3~ of PH6 pipe. ~~- ~3 ~ 05:15 - 08:00 2.75 STWHIP P WEXIT RIH with Milling BHA. Removed Injector cage on driller side for repairs Some wt bobbles at 8,315 ft and 8,515 ft and 8,719 ft 08:00 - 15:10 7.17 STWHIP P WEXIT Milling dual dual casing window as per RP from 9200 ft to 9400 ft Qp = 2.48 ! 2.49 bpm at 3400 psi on btm CTP = 3615 psi Time drill at 0.1 ftl 6 min. DHWOB = 3-4k 15:10 - 15:30 0.33 STWHIP P WEXIT PU to achieve updated off bottom pressures. 15:30 - 18:00 2.50 STWHIP P WEXIT Milling dual casing string window from 9200 ft Off bottom P = 3300 psi Op = 2.50 (2.50 psi CTP = 3560 psi on bottom DHWOB at 4k 18:00 - 22:30 4.50 STWHIP P WEXIT Continue to mill window from 9206'. Pick up to check WOB etc. RIH. Stack weight at 9205.6'. Resume time drilling from this depth. 3300 psi fs at 2.50 bpm in/out. 3500 psi on btm. 4.5 k# DHWOB, Printed: 121512007 11:06:22 AM I TREE = 41 /16" FMC WELLHEAD= _ _-_ - A CTUATOR = FMC BAKER C KB. ELEV = BF. ELEV = 54.8' KOP = 3450' Max Angle = 94 ~ 1 1073' Datum MD = . NIA Datum TVD= 8800' SS DRLG DRAFT 18-13B O 13-3/8" CSG, 68#, K-55 /72#, L-80, ID = 12.347" ~~ 4~ Minimum ID = 3.813" ~ 2208' 4-1 /2" CAMCO BAL-O SSSVN 41/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~--{ 871 T 9-5/8" X 41 /2" BKR S-3 PKR, ID = 3.875" 8696' --~ 41 /2" HES X PCP, ID = 3.813" TOP OF BKR TIEBACK SLV, C) = 7.500" 8698' 8703' 9-518" X 7" BKR ZXP PKR, D = 6.313" 9-5/8" X 7" BKR HMC HGR, D = 6.250" $711' $718' 41 /2" WLEG, ID = 3.958" 8720' 7" X 4112" LNR XO, ID = 3.958" TOP OFTM/TIEBACKSLV 8805 9-5/8" X 7" TIW LNR HGR 8815' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9103' T' LNR, 29#, L-80, ID = 6.184" 1027T 7" LNR tupl.LOUT WINDOW 974T - 9759' (OFF WHIPSTOCK) PERFORA TION SICUNM RY REF LOG: SPERRY MWD RESISTIVITY/GR 02/15/98 ANGLE AT TOP PERF: 88 ~ 11450' Note: Refer to Roduction DB for historical pert data SQE SPF INTERVAL Opn/Sgz DATE 2-3l4" 4 11450 - 11620 C 02/20/98 2-3/4" 4 11690 - 12005 C 02/20/98 2-3/4" 4 12055 - 12230 C 02/20/98 2-3/4" 4 12275 - 12385 C 04!17/04 2-3/4" 4 12405 - 12930 C 04/17/04 2-3/4" 4 12955 - 12995 C 04/17!04 2" 6 10160 - 10310 O 12/07107 2" 6 10580 - 11510 O 12/07/07 3.687" BKR N CIBP 13000' PBTD 13001' 4112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 13097' -~ SAFETY NOTES: W ELL ANGLE > 70° ~ 9825' 8 > 90° ~ 11298'. I 4112" CAMCO BAL-O SSSVN, ID = 3.813" ~ GA S LIFT MANDRELS ST MD ND DEV TYPE VLV LTCH PORT DATE 3 3009 3008 6 MMG DMY RK 0 10/23/07 2 6225 6009 25 MMG DMY RK 0 10/13/07 1 8479 7902 55 MMG DMY RK 0 10/13/07 8571' Top of KB Packer ID 2.56" 8594' -~TOL 3.7" OD 3.00" ~ 8604' Otis "X" Nipple L 9200' H Mechanical w hipstock 9225' 4112" HES X PCP, ID = 3.813" 11509 ft ft PSTD ®-® I I SSo ' 9233 ft Top of w hipstock fish )609' 4112" HES X NLP, ID = 3.813" 11345' ~-{ 41/2" MLA s .rT (zs.s'~ DATE REV BY COMMENTS DATE REV BY COMMENTS 12/07/87 ORIGINAL COMPLtT10N 02/25/98 RIG SIDETRACK 10/14/07 D16 RWO 72/09/07 Nordic2 CTD SIDETRACK PRUDHOE BAY UNfT WELL: 18-13A PERMIT No: 1972230 API No: 50-029-21756-Ot SEC 19, T11 N, R15E, 1045' SNL & 371' EWL BP Exploration (Alaska) • ALASKA OIL AI~TD GA5 COrT5ERQATIOIK COMl~IISSIOI~T Lamar Gantt CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612~~~~~~~ NC`s ~ ~ 2007 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-13A Sundry Number: 307-344 . ,:.--•~~-°~' °-` n 1~ r Dear Mr. Gantt: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30' PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. _ _ DATED this day of November, 2007 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM SION ~ NQV 0 ~ ~40~' APPLICATION FOR SUNDRY APPRO~a~~~g, ~~~ Cony. Commission 20 AAC 25.280 a....Mn.ana 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Pfug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-223 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-02921756-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-13A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field 1 Pool(s): ADL 028321 54.8' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT'WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13102 8772 13000 8771 None 9234 Casin Len th Size MD TVD Burst Colla se Structural Conduct r Surface 110' 20" 110' 110' 1490 470 Intermediate 4482' 13-3/8" 4482' 4429' 3700 2230 Production 9103' 9-5/8" 9103' 826 ' 6870 476 Liner 942' 7" 8805' - 9747' 8087' - 8532' 8160 7020 Liner 4399' 4-1l2" 8698' - 13097' 8025' - 8772' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11450' - 12995' 8766' - 8771' 4-1/2", 12.6# L-80 8718' Packers and SSSV Type: 9-5/8" x 4-112" Baker'S-3' packer; Packers and SSSV MD (ft): 8548'; 9-5/8" x 4-1/2" Baker'S-3' packer 8662' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: Immediately ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: 11/6/2007 ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: Art Saltmarsh 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Lamar Gantt, 564-5593 Printed Name ,Lamar Gantt Title CT Drilling Engineer Abby Higbie, 564-5480 .. Prepared ey Name/Number: ~ , ~';~~~~ ~ Phone 564-5593 Date I ~ ~r..,~~..° Terrie Hubble, 564-4628 Signature j ~'-~~~ ~. ~ , ~, ~~ Commission Use Onl Sundry Number: _ ~L 1y ~l~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 0~ S QF~. N(~V ~ 41007 Subsequent Form Required: APPROVED BY ~ "~ A roved B OMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 VI'/ ~ Submit In Duplicate `// IGINAL To: Tom Maunder Petroleum Engineer • Alaska Oil & Gas Conservation Commission From: Lamar Gantt CTD Engineer Date: October 7, 2007 Re: 18-13A Sundry Approval • by Sundry approval is requested for this proposal to isolate the existing perforations in the 18-13A wellbore as detailed for the 18-13B Coiled Tubing Sidetrack. Background The Doyon 16 Workover rig had just completed a workover on 10!14/2007 on the DS 18-13A wellbore to replace a corroded tubing string with a 4.5" Chrome tubing string. This operation was to be followed by a CTD sidetrack to drill a second lateral, DS 18-13 ALI. The Nordic 2 CTD rig rigged up on the 18-13 A well on 10/30/2007 to drill the proposed 18-13 ALl CTD sidetrack as detailed in Permit to Drill #207-134, approved on October 4, 2007. At that time no sundry was required as the parent wellbore was not to be abandoned and the well was to be completed as a multilateral producer. In the process of running the whipstock it became stuck at 8800', well above the proposed KOP of 11250'. All fishing operations at reMeving the whipstock were unsuccessful, however the fish was successfully pushed downhole to 9234'. Proposed Operations Because of the wellbore obstruction at 9234, verbal approval was received from the State on 10/06/2007(E-mail attached) to mill a window at a new KOP of 9200' and sidetrack to a new bottomhole location roughly halfway between the proposed 18-13 AL1 and the original 18-13A. The sidetrack will be completed as a cemented and perforated completion and will be named 18-13B. The existing perforations in the 18-13A wellbore will be isolated by the whipstock fish at 9234' and the liner cement job on the 18-13B proposed sidetrack. The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is also attached for reference. fin: s ~Qcovc~.~ Rig Work: (In progress -Nordic 2 was rigged up on DS 18-13A on 10/30/2007)) _ 1) Set 4-1/2" Baker Monobore WS at 9200' 2) Mi113.80" window at 9200' 3) Drill Build: 4.125" OH, 730' (15 deg/100 planned) 4) Drill Lateral: 4.125" OH, 2770' (12 degf 100 planned) 5) Run 3-3/16" X 2-7/8" solid liner targeting TOL at 8600' 6) Pump primary cement job to TOL, 39 bbl of 15.8 ppg cmt planned ~r6 '~, ~ ~3 7) Run Cleanout assembly 8) Run MCNL/GR/CCL log 9) Test liner lap to 2000 psi. 10) Perforate, planned 1500ft. 11) Freeze protect well with diesel, set BPV, and RDMO Post-Rig Work: 1) Pull BPV 2) Install well house, flow line, and gas lift valves „,~ ~.: ;;{,C~.~~ ~~'~ ~ "~ v ,~. Lamar Gantt CTD Drilling Engineer 564-5593 office 240-8045 cell CC: Well File Sondra Stewman/Terrie Hubble r~ L Gantt, Lamar L From: Saltmarsh, Arthur C (DOA) [art.saltmarsh@alaska.govJ Sent: Tuesday, November 06, 2007 2:47 PM To: Gantt, Lamar L Cc: Maunder, Thomas E (DOA) Subject: Change of plan, New PTD for the PBU 18-13B. Afternoon Lamar, ,~ Page 1 of 1 This a-mail will serve as approval from the AOGCC to change the drilling plan and BHL for the PBU 18-13AL1 well due to loss of the original borehole PBU 18-13A. The Commission will require a new PTD application with the new work plan and new BHL for the PBU 18-136 redrill that you have proposed. We will assign a new API and PTD number for the PBU 18-13B redrill and cancel the API # and PTD for the PBU 18-13AL1. Commissioner Seamount has signed your original a-mail request to Tom Maunder, giving approval for the proposed changes. Should you have any further questions, please feel free to contact me or Tom. Art Edmund Burke Art Saltmarsh Sr. Petroleum Geologist Ak. Oil & Gas Conservation Commission (907)793-1230 11!7!2047 '?he only thing necessary for -the triumph of evil is for load men to de no#hing'". `i V~1J L-li./1 YF1i1lYb VfJVyN,iVYV• i M~V 1 Vl 1 • Maunder, Thotttas E ~~A) From: C~rrtt, l..amar L [lamargarttt~bpt~rri] Sect: Tuesday, Navember O6, 20071:16 PM To: Maurer, Thomas E (ooAj Ctr: tiubb~, Term L SubJect: 1&13 AL1 drilling operations Tom G~~ r~ 1 ~ ~7 The Nord 2 rig is curr~ertttS- on tt-e 18-13A w~ and ~ experierxing diP that we rt us irvrri oo~etlng tl~e approved 1&13 AL1 sk~ope ofwork. The 18-13AL1 scope w~ ~ ex~ the exist~g at 1125ip MD, dose ~ twrizont~, tum ~d drib a hortzontd to #~ north. The cletion stratag3r was to with a sk>tGed witlt an openltQle jundiori at the vrindanr, and retrieve the whipstock to atlow fuUur+a ne-errtry ~a the pensnt v~etit~e In the process o€ nsutmg the n~ wodc, ti bet~me studk h tl~e vr+e~ore grid we have best tenable in putt it out of the hole. V1ie strocessf~ in pi~tdrtg ~ downhale b 923ti, but haiae decided the best oaurse of action from here wouM be m diartge the soaps of this sidetracc. V4~ are currently devebpitx~ a Platt do set a wttOdk at 9200 $ MD, rr~! a window and dired3ortally dr~l tQ the target Zone 1 horizon grid dr#!a a rtew trorizorital lateral to a MD of 12700' MD. The view BHl. wig be tocaf+ed roughly halfway between the !$-131 ate the prepared 18-13 AL1 per:r>! BHl(gr tt~i 5E~ fia;# auray)-~ Because of the ktge kt Kf~P, the cun+errt prrapased w~ bE a oem~ed and qs such, the parrot 18-13 A w+egbtxe w~ be by the c~ritent aril the new we~tae w~ be named 18-13B. VVe request vesbd Piaion to pursue this ttew p scope and w~! w~hh a revue pemtit tD drift for the 18-138 as soon as we resin eotriptefie ttie plans. Lamar L. Gantt CTD Engineer - ConocoPh~l~ Alaska, loc. ~, j Offoe: 9Q7 -564,5593 ~/~~' " Ceti: 907--240-$045 ~~ ~ ~ ~e~~ . raj ~~ iy~ ,~3~ ~---- rg,Y~B ~o ~isya 12/6/2007 ' Tr2EE = 4-1/16" FMC WELLHEAD= FMC ACTUATOR= BAKERC KB. ELEV = 54.8' BF. ELEV = KOP = 3450' Max Angle = 94 ~ 12441' Datum MD = N/A Datum TV D = 8800' SS 13-318" CSG, 68#, K-55 /72#, L-80, ID = 12.347" ~~ Minimum ID = 3.813" @ 2208' 4-1/2" CAMCO BAL-0 SSSVN 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 8717' TOP OF BKR TIEBACK SLV, ID = 7.500" 8698' 9-5/8" X 7" BKR HMC HGR, ID = 6.250" 8711' TOP OF TM/ TIEBACK SLV 8805' 9-5/8" X 7" TM/ LNR HGR 8815' ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ i Whipstock fish ~ 9234' 7" LNR, 29#, L-80, ID = 6.184" 1027, PERFORATION SUMMARY REF LOG: SPERRY MWD RESISTNfrY/GR 02/15/98 ANGLE AT TOP PERF: 88 C~ 11450' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 11450 - 11620 C 02/20/98 2-3/4" 4 11690 - 12005 C 02/20/98 2-3/4" 4 12055 - 12230 C 02/20/98 2-3/4" 4 12275 - 12385 C 04/17/04 2-3/4" 4 12405- 12930 C 04/17/04 2-3/4" 4 12955 - 12995 C 04/17/04 3.687" BKR N CIBP PBTD 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 18-13A Current Condition I O I SAFETY NOTES: W ELL ANC7.E > 70° ~ 9825' 8 > 90° Ca 11298'. GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 1 3059 3058 8 MMG-M DMY RK 0 04/27/05 2 5350 5218 25 W/u1G-M DMY RK 0 04/27/05 3 7263 6958 24 MMG-M DMY RK 0 04/27/05 4 8468 7895 54 MMG-M DMY RK 0 04/27/05 8518' 4-1 /2" HES X NIP, ID = 3.813" 8548' 60T S-3 Packer 8583' ~-1!2" HES X NIP. ID = 3.813" 8614' X NIP. ID = 3.813" 8635' ershot 8662' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8696' 4-1/2" HES X NIP, ID = 3.813" 8705' 9-5/8" X 7" BKR ZXP PKR, ID = 6.313" 8718' 4-1/2" WLEG, ID= 3.958" 8720' 7" X 4-1/2" LNR XO, ID = 3.958" 9225' ~ 4-1/2" HES X NIP, ID = 3.813" 7" LNR MLLOUT WNVDOW 9747' - 9759' (OFF WHIPSTOCK) 19' ~ 4-112" HES X NP,ID = 3.813" ~ 4-1/2" MLAS JT (28.5') ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 12/07187 ORIGINAL COMPLETION 09/24/05 MORlrLH PX TTP SET (05/13/05) 02/25198 RIG SIDETRACK 05/29/06 DFR/DTM CSG CORRECTIONS (11!24/04) 06/13/03 CMO/TLP KB ELEVATION CORRECTION 09/13/03 CMO/TLP DATUM MD/TVD CORRECTIONS 04/17/04 SRB/KAK MILL CIBP 05/03/05 RAGPJC GO GLV (4/27/05) PRUDHOE BAY UNR WELL: 18-13A PERMR No:'1972230 API No: 50-029-21756-01 SEC 19, T11 N, R15E, 1045' SNL 8 371' EWL BP 6cploratlon (Alaska) ° TREE = 4-1/t8" FMC WELLHEAD= FMC ACTUATOR= BAKERC KB. ELEV = 54.8' BF. ELEV = KOP = 3450' Max Angle = 94 ~ 12441' Datum MD = WA Datum ND = 8800' SS 13-3/8" CSG, 68#, K-55!72#, L-80, ID = 12.347" mmlmum lu = s.tf93-- L llUtf- 4-1/2" CAMCO BAL-0 SSSVN raP of r,Er~1EN 8600' 3- 1!2" XN NIP. Ill = 27~., 861 0' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, b = 3.958" $717' TOP OF BKR T~BACK SLV, ID = 7.500" 8698' 9-5/8" X 7" BKR HMC HGR, ID = 6.250" 8711 TOP OF TNV TIEBACK SLV 8805' 9-5/8" X 7" TNV LNR HGR 8815 = 8.681" v`Jhipstock f!sh ~ 9234' 7" LNR, 29#, L-80, ID = 6.184" PERFORATION SUMMARY REF LOG: SPERRY MIND REStSTNRY/GR 02/15/98 ANGLE AT TOP PERF: 88 C~ 11450' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 11450 - 11620 C 02/20/98 2-3/4" 4 11690 - 12005 C 02/20/98 2-3/4" 4 12055 - 12230 C 02/20/98 2-3/4" 4 12275- 12385 C 04/17/04 2-3/4" 4 12405- 12930 C 04/17/04 2-3/4" 4 12955 - 12995 C 04/17/04 3.687" BKR N CBP PBTD 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 18 -13 B sAl~Tir NOTES: wa.L,vrc~> 70° ~ 9825' 8~ > Proposed CTD Sidetrack 90° ~ 1129s'. 2110' 4-112" HES X NIP_ !D = 3.813" O GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LTCH PORT DATE 1 3059 3058 8 MMG-M DMY RK 0 04/27/05 2 5350 5218 25 MMG-M DMY RK 0 04/27/05 3 7263 6958 24 MMG-M DMY RK 0 04/27/05 4 8468 7895 54 MMG-M DMY RK 0 04/27/05 8518' 4-1/2" HES X NIP. ID = 3.813" 8548' BOT S-3 Packer 8583' 4-1/2" HES X NIP. ID = 3 813" 8600' Top of 3-1/2" Liner. TOC 8614' 4-112" HES X NIP ID = 3 ~' "',° Unique Overshot 8662' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" $696' 4-1 /2" HES X NIP, ID = 3.813" 8705' 9-518" X 7" BKR ZXP PKR, ID = 6.313" 8718 4-1/2" WLEG, ID= 3.958" 8720 7" X 4-1 /2" LNR XO, ID = 3.958" 9200' -itvlechanical Whipstock 101 3-3/16 x 2-7/8 X-over 3-3/16" X 2-7/8" anted & perfed H 1 9225' 4-1 /2" HES X NIP, ID = 3.813" 7" LNR MLLOUT WINDOW 9747' - 9759' (OFF WHIPSTOCK) 19' H 4-1/2" HES X NP, ID = 3.813" 4-1/2" M~AS JT (28.5') DATE REV BY COMMENTS DATE REV BY COMMENTS 12/07/87 ORIGINAL COMPLETION 09/24/05 MOR/TLH PX TTP SET (05/13/05) 02/25/98 RIG SIDETRACK 05/29/06 DFR/DTM CSG CORRECTIONS (11/24/04) 06/13/03 CMO/TLP KB ELEVATION CORRECTION 09/13/03 CMO/TLP DATUM MD/ND CORRECTIONS 04/17/04 SRB/KAK MILL CIBP 05/03/05 RAGPJC GO GLV (4/27/05) FRUDHOE BAY UNfT WELL: 18-13A PH2M1fT No: 1972230 API No: 50-029-21756-01 SEC 19, T11 N, R15E, 1045' SNL & 371' EWL BP Exploration (Alaska) 18-13A (PTD #1972230) Classified as Problem Well ) ) Subject: 18-13A (PTD #1972230) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellInteg;rityEngineer@BP.com> D~te: Sat, 23 Apr 200521:19:56 -0800. .. T~: "Schmoyer~ AI" <SchmoyAL@BP.cori1.>, "Golden, Johnny 0 (PhilliI-is)".· . . <JQOLDEN@ppco.com>, "GPB, FSl/SIP/STPAreaMgrU '¿GPBFSITL@BP ~éom>,· "RossbeI'g~ ,R Stbven'" <RossbeRS@BP.com>,·"NSU, ADW Well Operations S.upervisor"··· . <l\1SUAPWvv ellOperationsSuperyisor@BP . com>, "GPB,"W" ellSOptEI1g'~·,:·.. ,,::, ., . .'. ""." ."... <qPBWellsOptEng@BP.cOni>, "AOGCC Jiin Regg (E~mai1r'<.iimi.tegg@admill.state~~.us>ç "~OGCCWinton Aubert{E~mai1)" <winton_aub~rt@admin~state.8k.us>,1!NSU,·ADW·WL:& :. : C'qmpletion ,Supervisor" '<NSU.AÐWWL~CompletionSupervisor(@BP~com>/"GPB, ,FSI' DS9Ps: . .. , Le~dn <GPBFSIDSOpsLead@BP.com>, nGPB, EpC Specialists"; ·<GP~EÖCSpecialists@Bp:~COni> C¢:"NSU,ADW· Well Tntegrit~ E~ginèer", <NSUADWWenh1tegnÍ}'Engineer~BP.com>, '~'Mielke;,: ' Rqbert L." <robert.mie'lke@BP~com> :. , , . " ,. ,. . '. . .. . AIL, Well 18-13A (PTD #1972230) has been found to have sustained casing pressure on the IA. The TIO pressures on 04/21/05 were 2000/2310/0 when a TIFL was conducted and failed. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: DGL Vs, caliper tubing 3. DHD: Re-TIFL A wellbore schematic has been included for reference. « 18-13A. pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, }lnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNEJ':; ,flJ! O? 2005 1 of I 5/10/2005 8:47 AM ) TREE = WB..LHEA D= A CTUA TOR = KB. ELEV = BF.ELEV = KOP= 'rv;äx· Angie ~. Datum MD = Di:1fuñilVD·;;; 4-1/16" FMC FMC BA Kffi C 54.8' 3450' .. .......... ··94··@·"1·2441·;· N/A ääöëfss· 13-3/8" CSG, 72#, L-80, D = 12.347" 1-1 4486' rJ Minimum ID = 3.813" @ 2208' 4-1/2" CAMCO BAL'() SSSVN 4-1/2"TBG, 12.6#,L-80, .0152 bpf, D=3.958" H 871T I TOP OF BKRTIEBACK SLV, ID= 7.500" 1-1 9-5/8" x 7" BKR HMC HGR, ID = 6.250" l-i TOP OF TW TIEBACK SLV 1--1 1 9-5/8" X 7" TW LNR HGR I~ 8698' 8711' 8805' 8815' ) 18-13A SAFETY NOTES:W a.L ANGLE > 70° @ 9825' & > 900@ 11298'. fit 2208' 1-1 4-1/2" CAMCO BAL-OSSSVN, ID= 3.813" 1 ~ GAS LIFT MANDRELS ST I\iD 1VD DEV TYPE VLV LTCH PORT ()l\ TE L 1 3059 3058 8 MMG-M DOME RK 16 03/01/98 2 5350 5218 25 MMG-M DOME RK 16 03/01/98 3 7263 6958 24 MMG-M DOME RK 16 03/01/98 4 8468 7895 54 MMG-M SIO RK 24 03/01/98 :8: ~ 8662' 1-1 9-5/8" x 4-1/2" BKR S-3 PKR, ID = 3.875" 8696' 8705' 8718' 8720' 1-1 4-1/2" HES X NIP, ID= 3.813" 1 H 9-518" X7" BKRZXPPKR, ID=6.313" 1 H 4-1/2" WLEG, ID= 3.958" 1 H 7"X 4-112" LNRXO, ID= 3.958" 1 I I 1 I i H 1 l J ~ ~ .. IE I 9-5/8"CSG,47#,L-80,ID=8.681" I~ 9103' ~ [}6. 1E REV BY CO Mv1 ENTS DATE REV BY 12/07/87 ORIGINAL COM PLETION 02/25198 RIG SIDETRACK 10/21/01 CI-VKAK CORRECTIONS 06113/03 CIVOIlLP KB ELEVATION CORRECTION 09/13/03 CIVOIlLP DATUMMD'TVD CORRECTIONS 04117/04 SRB/KAK MILL aBP PffiFORA TION SUMI\N\ RY REF LOG: SPERRY MWD RESISllV IlY /GR 02/15/98 ANGLEA T TOP PffiF: 88 @ 11450' I\bte: Refer to A'oduction DB for historical perf data SIZE SPF INTERv' AL OpnlSqz ()l\ 1E 2-3/4" 4 11450 - 11620 0 02120/98 2-314" 4 11690 - 12005 0 02120/98 2-314" 4 12055 - 12230 0 02120/98 2-314" 4 12275 -12385 0 04/17/04 2-3/4" 4 12405 - 12930 0 04117/04 2-314" 4 12955 - 12995 0 04/17/04 7" LNR, 29#, L-80, ID = 6.184" H 10277' 1 ... I 9225' 1-1 4-1/2" HES X NIP, ID= 3.813" 1 7" LNR MLLOUT WINDOW 9747' - 9759' (OFF WHIPSTOCK) 10609' l-i 4-112"HESXNIP,ID=3.813" 1 11345' 1-1 4-1/2" M..ASJT(28.5') 1 . y.. - 1 3.687" BKR N aBP 1-1 13000' 4-112" LNR, 12.6#, L-80, .0152 bpf, ID =3.958" l-i 1309T 1 COMrvENTS PRLÐI-DE BAY lJ'.JrT \^ÆLL: 18-13A PffiMT~: 1972230 A R No: 50-029-21756-01 SEC 19, T11 N, R15E, 1045' SNL & 371' EWL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well rr§.aL 0.5. 07-03A JOJ -1'f.1K-10B ~qí~-C't' 0.5. 02-15A r-/¡U5'-- 0.5. 18-13A 2 ,1 ll.ll- G-12B 0.::>" "'\? (.....0.5. 05-26A ~-p- ; v'3_í~Lf-15-04A rq5-a3ð 18-02A 11)/_O~:.,.!18-04B 135-(Y5!i L 1-01 ('t''3-i-j1-L5-17 " '.' ,) ., I /'1H-18 ..'ö ". --f; 2-62/Q-17 18&-/t, 8. L5-15 \~ L5-15 _~q.; L5-15 \ L5-15 f~()-tl/fr E-17 QJ-/"lll- G-15A /-J J1 Job # 10715406 10715402 10715404 10715395 10715391 10715420 10715374 10621764 10708056 10913000 10900124 10703975 10900129 10708050 10563129 10672368 10913848 10703983 10679055 MCNL MCNL MCNL MCNL MCNL MCNL MCNL RST RST USIT US IT RST RST RST RST RST RST RST RST SCANNED JUN 1 ? 2005 Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: ·-1-ýt5 Date 06/03/04 05/16/04 05/18/04 04/16/04 03/21/04 08/19/04 01/14/04 02/23/64 03/05/04 12/25/04 11/30/04 02/17/04 12/24/04 02/07/04 11/15/03 04/16/04 09/26/04 04/09/04 02/02/04 Blueline /97-223 02/28/05 NO. 3354 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints -' CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 / '- 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 .IF Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 38 . / ATTN: Beth - // j Receive 1JQ..v-. Uð~...d~ Ó -" ~ r"\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Rf=CEIVED REPORT OF SUNDRY WELL OPERATIONS' 1. Operations Performed: MAY 1 0 200~ AbandonD SuspendD Operation ShutdownD Perforate D wai~erD c~tWmi~n Alter Casing 0 Repair Well 0 Plug PerforationsD Stimulate 0 Ti~~~'b~as Cons. nchoraae Change Approved ProgramD Pull TubingD Perforate New PoolD Re-enter Suspended Well Mill CIBP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 197-2230 BP Exploration (Alaska), Inc. 54.80 8. Property Designation: ADL-o028321 11. Present Well Condition Summary: Development ŒI StratigraphicD 9. Well Name and Number: 18-13A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory 0 ServiceD 6. API Number 50-029-21756-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 13102 feet true vertical 8771.8 feet Plugs (measured) None Effective Depth measured 13000 feet Junk (measured) 13000 true vertical 8771.3 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 34 114 34.0 - 114.0 1490 470 Liner 22 7" 26# L-80 8698 - 8720 8025.3 - 8037.8 7240 5410 Liner 4377 4-1/2" 12.6# L-80 8720 - 13097 8037.8 - 8771.8 8430 7500 Liner 935 7" 29# L-80 8812 - 9747 8091.2 - 8531.5 8160 7020 Production 9078 9-5/8" 47# L-80 32 - 9110 32.0 - 8266.7 6870 4760 Surface 4340 13-3/8" 72# L-80 33 - 4373 33.0 - 4327.6 4930 2670 Surface 116 13-3/8" 68# K-55 4373 - 4489 4327.6 - 4435.0 3450 1950 Perforation depth: Measured depth: 11450 -11620,11690 -12005,12055 -12230,12275 -12385,12405 -12930,12955 -12995 True vertical depth: 8765.86 - 8771.41,8773.04 - 8775.85,8774.48 - 8774.12,8773.14 - 8769.57,8768.82 - 8771.12,8771.16 - 8771.23 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 @ 30 8718 4-1/2" Baker S-3 Perm Packer @ 8662 4-1/2" Camco WRDP-2 SSV @ 2208 7" Baker ZXP Packer @ 8705 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl 736 Recresentative Daily Average Production or Iniection Data Gas-Me! Water-Bbl Casing Pressure 26.4 0 1180 13 810 26.3 0 760 Tubing Pressure 635 746 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒI ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilŒ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations - ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature .il ~ ('.¿( h-j,y. Form 10-404 Revised Q2/2003 Title Production Technical Assistant OK \ G \ N At" 56;;:;' BFL Date 5/7/04 MAY 1 0 10°' ~ .~ 18-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/05/04 PULLED 4112 WRDP-2 SSSV SER# HBS-756 DRIFT 3.50 CENT, SAMPLE BAILER TO 9866' SLM (HAW) 04/15/04 CTU #9: CNUMILL: MIRU CTU. 04/16/04 CTU #9: CNUMILL. CONTINUED FROM WSR 15-APR-04. CONTINUE RU OF CT UNIT. MU BAKER MHA WISLB MEM CNL AND RIH WHILE FLUID PACKING WELL WITH 375 BBLS FILTERED 1% KCL. LOGGED UPIDN PASSES FROM 9700' CTMD TO 11730' CTMD WHILE PUMPING 1 % KCL AT 1.7 BPM DOWN THE BACKSIDE. POOH WI LOGGING TOOLS. MU & RIH WITH BAKER 2 7/8" PDM WI 3.80" CONCAVE DIAMOND SPEED MILL. TAGGED clap AT 12269' CTMD. MILLED ON clap AT 12273' CTMD WIO SUCCESS. COULD NOT GENERATE MORE THAN 145 PSI MOTOR WORK, COULD NOT STALL OUT MOTOR. POOH TO INSPECT MOTOR AND MILL. MILL SHOWING BRASS AND SOME METAL IN TEETH. MU 3.75" OD 5 BLADED JUNK MILL WIMETAL MUNCHER BUTTONS. 04/17/04 RIH and tag clap @ 12,271' ctmd. Mill through clap and push to 13015' ctmd up depth (13,000' MDBKB). POOH. Had to turn motor and work pipe to get through all the perfs while POOH. Possibly dragging something along side of BHA through perfs. POOH. At surface. Displace well with 166 bbls diesel. FLUIDS PUMPED BBLS 226 548 1433 215 2422 60/40 Methonal 1 % KCL XS 1% KCL Diesel TOTAL Page 1 ~ TREE= W B.. LI-EA D = AClUATOR = KB. ELBI = BF. ELBI = KOP= Max Angle = Datum MO = DatUm TV 0 = 4-1/16" FMC FMC BAKER C 54.8' 3450' 94 @12441' N/A BaOO'SS 13-318" CSG, 72#, L-80, D = 12.347' H 4486' Minimum ID = 3.S13" @ 220S' 4-1/2" CAMCO BAL-O SSSVN I 4-1IZ' ìBG, 12.6#, L-80, .0152 bpf, D = 3.958" H 871T I TOP OF BKRTIEBACK SLV, ID= 7.500" H 8698' I 9-5/8" X 7' BKR HMC HGR, ID = 6.250" H I TOP OF TW llEBA CK SLV H I 9-518" X T' TW LNR HGR H 8711' 8805' 8815' 9-5/8"CSG,47#, L-80,ID=8.681" H 9103' PERFORATION SUMfvV:>.RY REF LOG. SPERRY MWD RESISllV rTY /GR 02/15/98 ANGLEATTOPPERF: 88@ 11450' I'bte: Refer to A"oduetion DB for historieal perf data SIZE SPF INfERv' AL OpnlSqz [)II. TE 2-314" 4 11450 -11620 0 02120/98 2-314" 4 11690 - 12005 0 02120/98 2-314" 4 12055 - 12230 0 02120/98 2-314" 4 12275 -12385 0 04117/04 2-314" 4 12405 -12930 0 04117/04 2-314" 4 12955 - 12995 0 04117/04 I 7" LNR, 29#, L-80, ID= 6.184" H 10277' I [)II. TE RBI BY COMMENTS 12/07/87 ORIGINAL COM PLErION 02/25/98 RIG SIDETRACK 10/21/0 1 CH'KAK CORRECllONS 06113/03 CMOIlLP KB ELBI A TION OORRECfION 09/13/03 CMO/TI..P DATUM MD'TVD OORRECTIONS 04117/04 SRB/KAK MILL aBP rJ ~ -l I 11 ~ 18-13A . ~ L :8: ~ ,-.., SAFETY NOTES: W B.L ANGLE > 70° @ 9825' & > 900@ 11298'. 2208' H 4-1/Z'CAMOOBAL-OSSSVN,ID=3.813" I ST 1\10 1 3059 2 5350 3 7263 4 8468 GAS LIFT MANffiELS lVO DBI TYPE VLV L TO; PORT [)II. TE 3058 8 MMG-M DOWE RK 16 03/01/98 5218 25 MMG-M DOWE RK 16 03/01/98 6958 24 MMG-M DaWE RK 16 03101/98 7895 54 MMG-M SIO RK 24 03101/98 I M I J ¡:¡ ~ . 8662' H 9-5/8"X4-1/2"BKRS-3PKR,ID=3.875" I 8696' H 4-1IZ' HEB X NIP, ID = 3.813" I 8705' H 9-518" X 7" BKR ZXPPKR, ID = 6.313" I 8718' H 4-1IZ' WLEG, 10= 3.958" I 8720' H 7"X4-1f2"LNRXO,ID=3.958" I 9225' H 4-1/Z'HEBXNIP,10=3.813" I 7" LNR MLLOUT WINDOW 9747' - 9759' (OFF WHIPSTOCK) 10609' H 4-1/2" I-ESX NIP, ID =3.813" I 11345' H 4-1/Z' MLASJT(28.5') I I 3.687' BKR N aBP H 13000' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID =3.958" H 13O9T I DATE REV BY COMWENfS PRLDI-OE BAY Lt-JIT WELL: 18-13A PERMT I'b: 1972230 AA No: 50-029-21756-01 SEC19, T11N,R15E, 1045' SNL& 371'EWL BP Exploration (Alaska) ~. L_~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X (CIBP) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_X RKB 54.8 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1043' FNL, 4582' FEL, Sec. 19, T11 N, R15E, UM (asp's 692133, 5960832) 18-13A At top of productive interval 9. Permit number / approval number 3594' FNL, 1396' FEL, Sec. 19, T11 N, R15E, UM (asp's 695394, 5958367) 197-223 At effective depth 10. APl number 50-029-21756-01 At total depth 11. Field / Pool 4794' FNL, 4367' FEL, Sec. 20, T11 N, R15E, UM (asp's 697737, 5957227) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13102 feet Plugs (measured) Set CIBP @ 12250' MD on 4/20/2001. true vertical 8772 feet Effective depth: measured 12250 feet Junk (measured) true vertical 8774 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 1694# Poleset 110' 110' Surface 4427' 13-3/8" 3500 sx cs III, 600 sx class G, 4482' 4428' & lOO sx cs II Intermediate 9048' 9-5/8" 930 sx Class G 9103' 8262' Production 942' 7" 5o0 Sx C~ass G 9747' 8532' Liner 4400' 4-1/2" 523 sx Class G 13097' 8772' Perforation depth: measured 11450'-11620'; 11690'- 12005'; 12055'- 12230'; RECE/~D~ (Isolated below CIBP 12275'- 12385'; 12405' - 12930'; 12955' - 12995'). true vertical 8766' - 8771" 8773' - 8776'; 8775' - 8774'; (Isolated below CIBP 8773'- 8770"; 8769'- 8771'; 8771'-8771').MAy 0 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 8718' MD. ~tc~a 0/7~ 200 ~ Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" BAKER S-3 PACKER @ 8662' MD; 9-5/8" X 7" BAKER ZXP LINER TOP PACKE-"R'~6~' M~.~n/S$ion 4-1/2" CAMCO BAL-O SSLN SSSV @ 2208' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mc1' Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 814 22167 0 - 1115 Subsequent to operation 609 9074 0 - 523 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the forego~q..~s true and correct to the best of my knowledge. Signed /'"'~J~" ,¢¢2 ~ Title: DS 18 Surveillance Engineer Date May4,2001 Al Schrnoyer ('~,,,,"'~'.'~ ~, /' ~' ~ Prepared by Paul Rauf 564-5799 ~, Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE bp April 5,2001 ONLY L~, UUI BP Exploration (Alaska) Inc. 900 Easl Benson Boulevard P,O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA_~ Pt. Mac, & Lisbume Well Work; , This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for April 2.- 9, 2001' ' WeU 02-19 Work Planned ADD PERFORATION 02-21 05-17B 06-21A 07-08A 11-22A 15-43 16-05Ai ADD PERFORATION ADD PERFORATION CTE PERFORATION CT REMOVE 2-3/8" GL COIL ADD PERFORATION SET CIBP W/CT CT REPERFORATION / ACID STIMULATION 18-04A CT REMOVE 2-3/8" GL COIL CT SET CIBP FOR GSO 18-18A SET CIBP W/CT Starting next week, I will be including WOA, Milne Pt, & Endicott wellwork. If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpcO~bp.eom. Sincerely, //~ ~ Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells ON OR BEFORE PL · M ATE IA L W UNDER TH IS M A R K ER ---- i97~223~0 MD 13102 PRUDHOE BAY UNIT 18-13A 50- 029-21756-01 ARCO TVD 08772 ~-tf//~pletion Date: 2/24/98 Completed Status: 1-OIL Current: T Name D 8402 OH 4/15/98 4/18/98 L DGR/EWR4-MD t~AL 9776-13102 OH 4/15/98 4/18/98 L DGR/EWR4-TVD ~AL 8541-8771 OH 4/15/98 4/18/98 Interval Sent Received T/C/D ~'~. SPERRY MPT/GR/EWR4 R MWD SRVY SPERRY 9724.81-13102. OH 3/18/98 3/25/98 Daily Well Ops ; · - ~ ' ' - Are Dry Ditch Samples Required? yes ~.~,,And Received~-~yes~n~~ Was the well coredZ yes (~r Analysis D~~~ no Sa~ Comments: Thursday, February 03, 2000 Page 1 of 1 ~ I:t I I_~1 N I~ WELL LOG TRANSMITTAL To: State of Alaska April 15, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 18-13& .AX-MM-80121 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ali Turker. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-21756-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries. Inc. WELL LOG TRANSMITTAL To: State of Alaska April 15, 1998 .Alaska Oil and Gas Conservation Comm. Attn.: Loft Tavlor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ ~ - ~ 2 ~ RE: MWD Formation Evaluation Logs D.S. 18-13& .AK-MM-80121 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' .Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 18-13A · 2" x 5" MD Resistivity, & Gamma Ray Logs: 50-029-21756-01 2" x 5" TVD Resistiviw & Gamma Ray Logs: 50-029-21756-01 1 BlUeline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil E~ Gas I~ Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-0223 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21756-01 4. Location of well at surface ~ ............... ~ ~:":;,.:~h.~;:~!~,;,i i i ~ 9. Unit or Lease Name 1045' SNL, 371' EWL, SEC. 19, T11N, R15E, UM i,...~.,.,~ . ;~! ~~i Prudhoe Bay Unit At top of productive interval ' ~-,/~_¢. i 10. Well Number At total depth _ll. Field and Pool 486' NSL, 928' EWL, SEC. 20, T11 N, R15E, UM ..... :? Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lease Designation and Serial No. Pool KBE = 54.80'I ADL 028321 12. Date Spudded2/13/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre I 16' NO' °f cOmpletiOns2/17/98 2/24/98 N/A MSLI One 17. Total Depth (MD+TVD) t18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 13102 8772 FTt 13001 8771 FT [~Yes I--INoI (Nipple) 2208' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, ES/AlT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 1694# Poleset 13-3/8" 72#/68# K-55/L-80 Surface 4482' 17-1/2" 3500 sx CS III, 600 sx 'G', Top Job100 sx CS II 9-5/8" 47# L-80 Surface 9103' 12-1/4" 930 sx Class 'G' 7" 29# L-80 8805' 9747' 8-1/2" 500 sx Class 'G' 4-1/2" 12.6# L-80 8698' 13097' 6" 523 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SizE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8718' 8662' MD TVD MD TVD 11450, _ 11620, 8766' _ 8771, .. 11690' - 12005' 8773' - 8776' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 12055' - 12230' 8775' - 8774' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12275' - 12385' 8773' - 8770' 12405' - 12930' 8769' - 8771' Freeze Protect with 150 Bbls of Diesel 12955' - 12995' 8771' - 8771' 27. PRODUCTION TEST ..... Date First Production I Method of Operation (Flowing, gas lift, etc.) March 3, 1998 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO iTEST PERIOD I Flow Tubing Casing Pressure CALCULATED 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. "' i 1998 [ : ,--.[ r- t ¢' "..;-.. Form 10-407 Rev. 07-01-80 Anchorage Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. ,,, Zone 1 10484' 8668' 2'i. List of Attachments Summary of Daily Drilling 7ports,/..Su~ 32. I hereby certify that tl?ecf~egoing/¢ ~e, and correct to the best of my knowledge ,,, Tim A. Burns V ~//t/'~ x,,'" ~ Title E.".S!.".o~r!n-~ ~_ups."'.':ccr Date 18-13A 97-0223 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: 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 Progress Report Facility PB DS 18 Well 18-13A Rig Doyon # 9 Page 1 Date 19 March 98 Date/Time 06 Feb 98 08:00-16:00 16:00-18:00 18:00-02:00 07 Feb 98 02:00-04:00 04:00-06:00 06:00-07:30 07:30-14:30 14:30-16:30 16:30-18:00 18:00-20:30 20:30-06:00 08 Feb 98 06:00-11:30 11:30-13:00 13:00-14:00 14:00-14:30 14:30-21:00 21:00-21:30 21:30-01:00 09 Feb 98 01:00-01:30 01:30-03:00 03:00-03:30 03:30-06:00 06:00-09:00 09:00-09:30 09:30-12:00 12:00-12:15 12:15-12:30 12:30-13:00 13:00-15:00 15:00-20:00 20:00-01:30 10Feb 98 01:30-03:30 03:30-04:00 04:00-06:00 06:00-07:30 07:30-08:00 08:00-11:30 11:30-13:00 13:00-14:00 14:00-16:30 16:30-17:30 17:30-20:00 20:00-22:30 22:30-02:00 11 Feb 98 02:00-02:30 02:30-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-07:00 07:00-13:30 13:30-14:30 14:30-04:00 12 Feb 98 04:00-06:00 Duration 8hr 2hr 8hr 2hr 2 hr 1-1/2 hr 7hr 2 hr 1-1/2 hr 2-1/2 hr 9-1/2 hr 5-1/2 hr 1-1/2 hr 1 hr 1/2 hr 6-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 3hr 1/2 hr 2-1/2 hr 1/4 hr 1/4 hr 1/2 hr 2hr 5 hr 5-1/2 hr 2hr 1/2 hr 2hr 1-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1 hr 2-1/2 hr lhr 2-1/2 hr 2-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr lhr 6-1/2 hr lhr 13-1/2 hr 2hr Activity Rig moved 100.00 % Fill pits with Seawater Circulated closed in well at 9990.0 ft Removed Xmas tree Installed BOP stack Installed BOP stack (cont...) Tested BOP stack Retrieved BOP test plug assembly Laid down 30.0 ft of Tubing Circulated at 9970.0 ft Laid down Tubing of 6000.0 ft Laid down 10174.0 ft of Tubing (cont...) Installed BOP stack Tested All rams Installed Wear bushing Conducted electric cable operations Tested Casing Ran Drillpipe in stands to 3852.0 ft Rigged up Drillstring handling equipment Ran Drillpipe to 4500.0 ft (5in OD) Repaired Spinner Ran Drillpipe to 5in (6500.0 ft OD) Ran Drillpipe to 8295.0 ft (5in OD) (cont...) Repaired Spinner Ran Drillpipe to 9764.0 ft (5in OD) Pumped Water spacers - volume 20.000 bbl Mixed and pumped slurry - 28.000 bbl Displaced slurry - 129.000 bbl Reverse circulated at 9764.0 ft Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 1 R.I.H. to 4074.0 ft Rigged up Drillstring handling equipment R.I.H. to 7000.0 ft R.I.H. to 8826.0 ft (cont...) Circulated at 8826.0 ft Pulled out of hole to 800.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 4678.0 ft Serviced Block line R.I.H. to 9764.0 ft Reverse circulated at 9764.0 ft Pulled out of hole to 4678.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 800.0 ft Pulled BHA Tested Casing - Via string Made up BHA no. 3 Made up BHA no. 3 Ran Drillpipe in stands to 5.0 ft Circulated at 9767.0 ft Milled Casing at 9747.0 ft Pulled out of hole to 8000.0 ft Facility Date/Time 13 Feb 98 14 Feb 98 15 Feb 98 16 Feb 98 17 Feb 98 18 Feb 98 19 Feb 98 PB DS 18 Progress Report Well 18-13A Page 2 Rig Doyon # 9 Date 19 March 98 06:00-09:30 09:30-10:30 10:30-11:30 11:30-15:30 15:30-16:30 16:30-17:30 17:30-22:00 22:00-00:00 00:00-01:00 01:00-05:00 05:00-06:00 06:00-12:00 12:00-06:00 06:00-06:00 06:00-06:30 06:30-08:00 08:00-14:00 14:00-15:00 15:00-15:30 15:30-19:00 19:00-19:30 19:30-00:00 00:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:00 06:00-20:00 20:00-21:00 21:00-05:00 05:00-06:00 06:00-06:05 06:05-07:30 07:30-08:30 08:30-11:00 11:00-12:00 12:00-12:30 12:30-16:30 16:30-17:00 17:00-19:30 19:30-21:00 21:00-21:45 21:45-22:00 22:00-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-05:00 05:00 06:00-06:05 06:05-10:30 10:30-11:30 11:30-12:00 12:00-12:15 Duration 3-1/2 hr 1 hr lhr 4hr lhr lhr 4-1/2 hr 2hr 1 hr 4 hr 1 hr 6hr 18hr 24 hr 1/2 hr 1-1/2 hr 6hr 1 hr 1/2 hr 3-1/2 hr 1/2 hr 4-1/2 hr 3hr 1 hr lhr 1 hr 24 hr 14 hr 1 hr 8hr lhr 0hr 1-1/4 hr 1 hr 2-1/2 hr lhr 1/2 hr 4hr 1/2 hr 2-1/2 hr 1-1/2 hr 3/4 hr 1/4 hr 2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 0hr 4-1/4 hr 1 hr 1/2 hr 1/4 hr Activity Pulled out of hole to 800.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 9772.0 ft Milled Casing at 9759.0 ft Circulated at 9779.0 ft Pulled out of hole to 800.0 ft Pulled BHA Circulated at 20.0 ft Made up BHA no. 5 R.I.H. to 1500.0 ft R.I.H. to 9779.0 ft Drilled to 10415.0 ft Drilled to 11162.0 ft Drilled to 11193.0 ft Circulated at 11193.0 ft Pulled out of hole to 200.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 6 R.I.H. to 9568.0 ft Serviced Block line R.I.H. to 11193.0 ft Took MWD survey at 11133.0 ft Drilled to 12435.0 ft Drilled to 13102.0 ft Circulated at 13102.0 ft Logged hole with LWD: DIR/DD from 13058.0 ft to 11250.0 ft Pulled out of hole to 9789.0 ft Pulled out of hole to 9759.0 ft Circulated at 9759.0 ft R.I.H. to 13102.0 ft Circulated at 13102.0 ft Pulled out of hole to 11000.0 ft Held safety meeting Pulled out of hole to 4600.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 200.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 1200.0 ft (4-1/2in OD) Held safety meeting Ran Liner to 1724.0 ft (4-1/2in OD) Installed Other sub-surface equipment Ran Liner to 4377.0 ft (4-1/2in OD) ~ Rigged up Tubing handling equipment ~ E C ~ ~ V ~ ~ Rigged up Tubing handling equipment (cont...) ~ --~ Ran Tubing to 4322.0 fl (2-7/8in OD) ~/!) ~ ,~ .] ~q~ Space out tubulars "~' '~' ~ ~ HeldInStalledsafetyLinermeetinghanger £4]8Sk8 Oil ~ ~as Cons. C0ra mJssJ0n Facility Date/Time 20 Feb 98 21 Feb 98 22 Feb 98 PB DS 18 12:15-13:00 13:00-17:00 17:00-18:00 18:00-19:30 19:30-20:00 20:00-23:15 23:15-23:30 23:30-23:45 23:45-00:15 00:15-00:20 00:20-01:15 01:15-01:30 01:30 06:00-06:05 06:05-12:00 12:00-12:15 12:15-12:30 12:30-13:00 13:00-14:00 14:00-16:00 16:00-16:30 16:30-18:30 18:30-20:00 20:00-20:30 20:30-23:00 23:00-05:00 05:00-05:30 05:30 06:00-06:30 06:30-10:30 10:30-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-14:30 14:30-17:00 17:00-19:30 19:30-20:30 20:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-02:15 02:15-02:30 02:30-02:45 02:45-03:00 03:00-03:15 03:15-04:00 04:00-05:30 05:30-06:00 06:00-12:00 12:00-12:30 12:30-13:00 13:00-14:00 Progress Report Well 18-13A Page 3 Rig Doyon # 9 Date 19 March 98 Duration 3/4 hr 4 hr lhr 1-1/2 hr 1/2 hr 3-1/4 hr 1/4 hr 1/4 hr 1/2 hr 0 hr 3/4 hr 1/4 hr 0hr 5-3/4 hr 1/4 hr 1/4 hr 1/2 hr lhr 2 hr 1/2 hr 2hr 1-1/2 hr 1/2 hr 2-1/2 hr 6 hr 1/2 hr 1/2 hr 4hr 1-1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr lhr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr 1-1/2 hr 1/2 hr 6hr 1/2 hr 1/2 hr 1 hr Activity Circulated at 4377.0 ft Ran Drillpipe in stands to 9680.0 ft Circulated at 9680.0 ft Ran Drillpipe in stands to 13080.0 ft Space out tubulars Circulated at 13097.0 ft Tested High pressure lines Pumped Synthetic based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 107.000 bbl Cleared Chicksan lines Displaced slurry - 172.600 bbl Functioned Liner hanger Circulated at 13000.0 ft Circulated at 13000.0 ft (cont...) Pulled Drillpipe in stands to 4412.0 ft Held safety meeting Rigged up Tubing handling equipment Rigged down Tubing handling equipment Serviced Block line Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - Setting tools Tested Liner Rig waited: Equipment Rigged up sub-surface equipment - Bridge plug Ran Tubing in stands to 4412.0 ft Ran Drillpipe in stands to 13006.0 ft Installed Bridge plug Tested Liner - Via annulus and string Tested Liner - Via annulus and string (cont...) Pulled Drillpipe in stands to 4365.0 ft Laid down 1475.0 ft of Tubing Held safety meeting Pulled Tubing in stands to 0.0 ft Rigged up Tubing handling equipment Held safety meeting Rigged up sub-surface equipment - TCP Ran Tubing in stands to 4443.0 ft Rigged up sub-surface equipment - Retrievable packer Ran Drillpipe in stands to 11200.0 ft Held safety meeting Ran Drillpipe in stands to 11647.0 ft Tested DST downhole equipment - Via annulus Ran Drillpipe in stands to 13001.0 ft Held safety meeting Tested Choke manifold Functioned Retrievable packer Perforated from 11450.0 ft to 12995.0 ft Reverse circulated at 8537.0 ft Circulated at 8537.0 ft Flow check Laid down 8000.0 ft of 5in OD drill pipe Held safety meeting Laid down 500.0 ft of 5in OD drill pipe Retrieved Retrievable packer Facility PB DS 18 Progress Report Well 18-13A Rig Doyon # 9 Page Date 4 19 March 98 Date/Time 23 Feb 98 24 Feb 98 14:00-14:30 14:30-16:30 16:30-16:45 16:45-20:30 20:30-21:30 21:30-22:00 22:00-22:30 22:30-22:45 22:45-00:00 00:00-00:30 00:30-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-12:00 12:00-12:30 12:30-14:00 14:00-14:30 14:30-15:00 15:00-15:30 15:30-16:30 16:30-18:00 18:00-18:15 18:15-18:30 18:30-20:00 20:00-22:30 22:30-23:00 23:00-02:00 02:00-04:00 06:00-06:05 06:05-06:45 06:45-07:30 07:30-07:45 07:45-10:30 10:30-11:00 11:00-12:00 Duration 1/2 hr 2hr 1/4 hr 3-3/4 hr 1 hr 1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 5hr 1/2 hr 1/2 hr 2-1/2 hr 3 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 2-1/2 hr 1/2 hr 3 hr 2hr 0 hr 1/2 hr 3/4 hr 1/4 hr 2-3/4 hr 1/2 hr lhr Activity Rigged up Tubing handling equipment Laid down 4443.0 ft of Tubing Held safety meeting Laid down 1545.0 ft of Tubing Rigged down Tubing handling equipment Removed Bore protector Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 400.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 6515.0 ft (4-1/2in OD) Installed SCSSSV nipple assembly Installed SCSSSV nipple assembly Ran Tubing to 2203.0 ft (4-1/2in OD) Space out tubulars Held safety meeting Circulated at 1817.0 ft Serviced Setting tools Serviced High pressure lines Held safety meeting Set packer at 8620.0 ft with 3500.0 psi Tested Tubing Laid down 40.0 ft of Tubing Installed Setting tools Rig waited: Equipment Removed Hanger plug Installed Hanger plug Rigged down All functions Installed Adapter spool Installed Xmas tree Removed Hanger plug Tested Xmas tree Held safety meeting Reverse circulated at 3050.0 ft Installed Accessories Installed Xmas tree integral components .~aska r ,, ,,, · 0, e, Gas Cons. Commission Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU / !8-!3A S00292175601 NORTH SLOPE BOROUGH COMPUTATiOIq DATE: 3/18/98 DATE OF SURVEY: 020898 MWD SURVEY JOB NUMBER: AKMM8012i PAGE I KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: ARCO ALASKA INC 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. 9724.81 8523.17 8468.37 67 54 S 47.40 E .00 2157.33S 2570.07E 3274.04 9759.01 8536.11 8481.31 67 38 S 47.39 E .76 2178.76S 2593.37E 3304.58 9801.08 8551.56 8496.76 69 15 S 49.09 E 5.38 2204.81S 2622.56E 3342.48 9832.89 8562.32 8507.52 71 10 S 49.77 E 6.36 2224.28S 2645.29E 3371.61 9864.41 8572.08 8517.28 72 45 S 50.45 E 5.42 2243.50S 2668.29E 3400.87 9896.09 8581.06 8526.26 74 18 S 51.11 E 5.26 2262.70S 2691.82E 3430.60 9927.97 8589.57 8534.77 74 45 S 54.77 E 11.15 2281.21S 2716.33E 3460.87 9959.79 8597.41 8542.61 76 43 S 53.87 E 6.77 2299.20S 2741.38E 3491.38 9991.40 8604.12 8549.32 78 45 S 57.92 E 14.07 2316.51S 2766.95E 3522.05 10023.11 8609.93 8555.13 80 9 S 59.85 E 7.45 2332.62S 2793.63E 3553.15 10054.85 8614.92 8560.12 81 44 S 60.38 E 5.24 2348.23S 2820.81E 3584.46 10086.46 8619.52 8564.72 81 30 S 60.09 E 1.16 2363.76S 2847.96E 3615.71 10118.26 8624.11 8569.31 81 54 S 59.32 E 2.71 2379.63S 2875.12E 3647.13 10150.05 8628.68 8573.88 81 33 S 59.85 E 1.98 2395.56S 2902.25E 3678.55 10181.89 8633.23 8578.43 82 0 S 58.09 E 5.64 2411.80S 2929.25E 3709.99 10213.68 8637.36 8582.56 83 3 S 60.03 E 6.91 2428.00S 2956.28E 3741.45 10245.42 8641.27 8586.47 82 47 S 61.26 E 3.94 2443.44S 2983.74E 3772.92 10277.18 8645.02 8590.22 83 40 S 62.84 E 5.66 2458.22S 3011.59E 3804.46 10308.45 8648.39 8593.59 83 56 S 63.02 E 1.04 2472.37S 3039.28E 3835.54 10340.32 8651.81 8597.01 83 43 S 62.93 E .72 2486.77S 3067.50E 3867.23 10371.98 8655.35 8600.55 83 25 S 63.59 E 2.28 2500.92S 3095.60E 3898.69 10403.86 8659.01 8604.21 83 24 S 65.13 E 4.80 2514.63S 3124.15E 3930.34 10435.35 8662.64 8607.84 83 19 S 65.27 E .51 2527.75S 3152.54E 3961.59 10467.04 8666.39 8611.59 83 5 S 65.57 E 1.19 2540.83S 3181.16E 3993.02 10498.82 8670.13 8615.33 83 22 S 65.77 E 1.05 2553.84S 3209.91E 4024.53 10530.41 8673.85 8619.05 83 7 S 65.73 E .80 2566.72S 3238.52E 4055.86 10562.24 8677.55 8622.75 83 30 S 66.00 E 1.46 2579.65S 3267.37E 4087.42 10593.90 868!.35 8626.55 82 43 S 66.34 E 2.68 2592.35S 3296.12E 4118.79 i0625.8i 8685.52 8630.72 82 16 S 65.96 E 1.82 2605.14S 3325.05E 4!50.37 10657.29 8689.82 8635.02 82 0 S 66.18 E 1.13 2617.79S 3353.55E 4181.50 10689.20 8694.29 8639.49 81 54 S 64.77 E 4.38 2630.90S 3382.30E 4213.05 10720.79 8698.66 8643.86 82 10 S 63.90 E 2.86 2644.45S 3410.50E 4244.32 10752.2? 8703.01 8648.21 81 56 S 62.97 E 3.02 2658.39S 3438.38E 4275.50 10784.42 870~.56 8652.76 81 47 S 62.93 E .48 2672.87S 3466.73E 4307.32 10815.99 8712.02 8657.22 81 56 S 62.46 E 1.56 2687.20S 3494.50E 4338.58 ORI$1NAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU / !8-!3A 500292175601 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/98 DATE OF SURVEY: 020898 MWD SURVEY JOB NUMBER: AKMM80i21 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 10847.72 8716.50 8661.70 10879.61 8721.23 8666.43 10911.57 8726.19 8671.39 10943.10 8731.05 8676.25 10974.98 8735.95 8681.15 COURS INCLN DG MN 81 49 81 7 81 2 81 12 81 6 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST S 62.16 E 1.02 2701.80S 3522.31E S 61.43 E 3.15 2716.71S 3550.10E S 61.79 E 1.14 2731.72S 3577.88E S 60.56 E 3.89 2746.74S 3605.17E S 59.97 E 1.86 2762.36S 3632.52E VERT. SECT. 4369.99 4401.52 4433.09 4464.23 4495.70 11006.66 8740.65 8685.85 11038.33 8745.08 8690.28 11070.08 8749.35 8694.55 11101.85 8753.39 8698.59 11133.80 8756.86 8702.06 81 49 82 5 82 26 82 58 84 33 S 60.15 E 2.34 2778.00S 3659.67E S 59.32 E 2.72 2793.80S 3686.76E S 58.62 E 2.45 2810.02S 3713.71E S 58.45 E 1.75 2826.47S 3740.59E S 59.13 E 5.38 2842.92S 3767.75E 4527.00 4558.32 4589.71 4621.14 4652.83 11169.56 8759.63 8704.83 11201.24 8761.24 8706.44 11232.92 8762.08 8707.28 11265.22 8762.32 8707.52 11297.89 8762.13 8707.33 86 34 87 35 89 20 89 49 90 49 S 57.04 E 8.12 2861.77S 3798.01E S 58.47 E 5.56 2878.65S 3824.77E S 63.37 E 16.42 2894.03S 3852.44E S 67.06 E 11.52 2907.57S 3881.76E S 70.18 E 10.04 2919.48S 3912.17E 4688.37 4719.89 4751.53 4783.79 4816.28 11329.65 8762.08 8707.28 11361.38 8762.55 8707.75 11393.15 8763.55 8708.75 11424.84 8764.89 8710.09 11456.41 8766.16 8711.36 89 20 88 56 87 26 87 42 87 41 S 70.56 E 4.81 2930.15S 3942.08E S 70.75 E 1.40 2940.66S 3972.02E S 70.05 E 5.21 2951.31S 4001.93E S 69.34 E 2.38 2962.30S 4031.62E S 68.69 E 2.06 2973.59S 4061.08E 4847.75 4879.16 4910.62 4942.04 4973.39 11488.18 8767.45 8712.65 11520.71 8768.56 8713.76 11552.40 8769.32 8714.52 11584.03 8770.15 8715.35 11615.69 8771.28 8716.48 87 39 88 24 88 51 88 7 87 48 S 68.67 E .12 2985.13S 4090.65E S 68.27 E 2.59 2997.07S 4120.89E S 67.41 E 3.08 3009.02S 4150.23E S 66.29 E 4.24 3021.45S 4179.30E S 65.30 E 3.28 3034.42S 4208.16E 5004.96 5037.30 5068.85 5100.38 5131.98 11647.34 8772.28 8717.48 11678.98 8772.90 8718.10 11710.65 8773.42 8718.62 11742.78 8?74.00 8719.21 11774.41 8774.25 8719.45 88 35 89 10 88 56 88 56 90 9 S 64.60 E 3.33 3047.81S 4236.81E S 64.82 E 1.96 3061.32S 4265.42E S 64.42 E 1.44 3074.90S 4294.03E S 64.25 E .53 3088.81S 4322.98E S 64.13 E 3.81 3102.58S 4351.45E 5163.58 5195.20 5226.84 5258.95 5290.57 11806.16 8774.11 8719.31 11837.76 8774.01 8719.21 11869.59 $774.54 8719.74 11900.77 8UU5.45 8720.65 11932.57 8~U5.96 8721.16 90 22 89 58 88 9 88 30 89 37 S 63.69 E 1.55 3116.54S 4379.97E S 64.19 E 2.03 3130.43S 4408.35E S 64.42 E 5.76 3144.22S 4437.03E S 64.42 E 1.15 3157.68S 4465.14E S 64.87 E 3.80 3i71.29S 4493.87E 5322.31 5353.90 5385.71 5416.86 5448.63 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU / !8-!3A 500292175601 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/98 DATE OF SURVEY: 020898 MWD SURVEY JOB NUMBER: AKMM80121 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: ARCO ALASKA iNC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11964.32 8776.11 8721.31 11995.96 8775.99 8721.19 12027.50 8775.27 8720.47 12059.11 8774.41 8719.61 12090.79 8774.15 8719.35 89 49 90 37 92 0 91 8 89 46 S 64.25 E 2.04 3184.93S 4522.54E S 63.37 E 3.76 3198.90S 4550.93E S 63.65 E 4.46 3212.96S 4579.15E S 63.67 E 2.72 3226.98S 4607.47E S 62.46 E 5.75 3241.33S 4635.71E 5480.37 5512.00 5543.52 5575.11 5606.79 12122.54 8774.09 8719.29 12154.30 8774.02 8719.22 12185.94 8774.29 8719.49 12217.66 8774.32 8719.52 12249.21 8773.77 8718.97 90 25 89 49 89 12 90 41 91 17 S 62.09 E 2.36 3256.10S 4663.81E S 62.31 E 2.04 3270.91S 4691.90E S 62.49 E 2.01 3285.57S 4719.94E S 61.79 E 5.19 3300.39S 4747.98E S 61.66 E 1.92 3315.33S 4775.76E 5638.54 5670.30 5701.93 5733.65 5765.19 12282.22 8772.98 8718.18 12314.03 8772.04 8717.24 12345.81 8770.94 8716.14 12377.39 8769.85 8715.05 12409.09 8768.68 8713.88 91 26 91 56 92 1 91 55 92 18 S 61.42 E .87 3331.06S 4804.78E S 61.10 E 1.84 3346.35S 4832.66E S 60.88 E .75 3361.75S 4860.43E S 61.08 E .71 3377.06S 4888.03E S 62.02 E 3.20 3392.15S 4915.88E 5798.18 5829.97 5861.72 5893.27 5924.94 12440.67 8767.06 8712.26 12472.42 8765.44 8710.64 12504.21 8764.66 8709.86 12535.61 8764.63 8709.83 12567.03 8765.41 8710.61 93 32 92 18 90 31 89 34 87 35 S 61.31 E 4.50 3407.12S 4943.64E S 61.26 E 3.88 3422.35S 4971.45E S 61.05 E 5.67 3437.68S 4999.28E S 60.90 E 3.06 3452.92S 5026.74E S 60.81 E 6.31 3468.21S 5054.17E 5956.47 5988.17 6019.93 6051.32 6082.71 12598.91 8766.59 8711.79 12630.51 8767.70 8712.90 12662.08 8769.09 8714.29 12693.84 8770.56 8715.76 12725.56 8771.84 8717.04 88 10 87 46 87 11 87 30 87 52 S 59.85 E 3.53 3483.98S 5081.85E S 59.97 E 1.32 3499.82S 5109.17E S 60.28 E 2.11 3515.53S 5136.52E S 59.68 E 2.12 3531.40S 5163.99E S 59.21 E 1.89 3547.51S 5191.28E 6114.54 6146.08 6177.59 6209.28 6240.93 127~7.05 8772.43 8717.63 127~8.65 8772.23 8717.43 12820.36 8771.82 8717.02 !2851.9S 8771.35 8716.55 12883.67 8771.12 8716.32 90 0 90 41 90 48 90 53 89 56 S 58.99 E 6.80 3563.68S 5218.29E S 58.80 E 2.30 3580.00S 5245.35E S 58.57 E .79 3596.48S 5272.44E S 58.50 E .36 36t2.97S 5299.38E S 57.77 E 3.78 3629.71S 5326.31E 6272.35 6303.88 6335.51 6367.02 6398.64 12916.27 8771.12 8716.32 12947.95 8771.14 8716.34 129~9.64 8771.20 8716.40 13011.39 8771.29 8716.49 13044.52 8771.45 8716.65 90 3 89 52 89 54 89 46 89 39 S 57.01 E 2.36 3647.28S 5353.77E S 57.62 E 2.02 3664.39S 5380.44E S 57.68 E .23 3681.34S 5407.21E S 57.55 E .57 3698.35S 5434.02E S 56.93 E 1.91 37t6.28S 5461.88E 6431.10 6462.64 6494.21 6525.84 6558.82 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU / 18-i3A 500292175601 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/98 DATE OF SURVEY: 020898 MWD SURVEY JOB NUMBER: AKMM80121 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: ARCO ALASKA INC 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. 13102.00 8771.79 8716.99 89 39 S 56.93 E .00 3747.64S 5510.05E 6616.01 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6663.74 FEET AT SOUTH 55 DEG. 46 MIN. EAST AT MD = 13102 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 117.36 DEG. TIE-IN SURVEY AT 9,724.81' MD WINDOW POINT AT 9,759.00' MD PROJECTED SURVEY AT 13,102.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING PBU / 18-i3A 500292175601 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/98 DATE OF SURVEY: 020898 JOB NUMBER: AKMM80121 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9724.81 8523.17 8468.37 10724.81 8699.21 8644.41 11724.81 8773.68 8718.88 12724.81 8771.81 8717.01 13102.00 8771.79 8716.99 2157.33 S 2570.07 E 2646.20 S 3414.07 E 3081.01 S 4306.79 E 3547.13 S 5190.64 E 3747.64 S 5510.05 E 1201.64 2025.60 823.96 2951.13 925.53 3953.00 1001.86 4330.21 377.21 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 SHARED SERVICES DRiLLiNG PBU / 18-13A 500292175601 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/98 DATE OF SURVEY: 020898 JOB NUMBER: AKMM8012! KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: ARCO ALASKA. INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9724.81 8523.17 8468.37 9810.43 8554.80 8500.00 10367.13 8654.80 8600.00 11114.12 8754.80 8700.00 2157.33 S 2570.07 E 2210.54 S 2629.20 E 2498.78 S 3091.28 E 2832.81 S 3751.00 E 1201.64 1255.63 53.99 1712.33 456.71 2359.32 646.99 11144.81 8757.85 8703.05 2848.60 S 3777.13 E 2386.96 27.65 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0 I=! I IL_ I I~1G S I:: Ft ~.~ I r- I~ S 18-Mar-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 18-13A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,724.81' MD 9,759.00' MD 13,102.00' MD (if applicable) Please call me at 563-3256 if you have any questions or co~ Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Ino. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 29. 1998 James Miller Engineering Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519 Re: Prudhoe Bav unit 18-13A ARCO Alaska. Inc. Permit No. 97-223 Sur Loc: 1045'SNL. 371'EWL, Sec. 19. T1 IN. R15E, UM Btmhole Loc: 716%ISL, 4698'WEL. Sec. 20. T11N. R15E. UM Dear Mr. Miller: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated December I, 1997. are in effect for this revision. Si Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game. Habitat Section W/o encl Department of Environmental Conservation xv/o encl " STATE OF ALASKA , AL~uKA L,i-L AND GAS CONSERVATIOi~-~;OiVr~ISSION PERMIT TO DRILL 20 AAC 25.005 Cks. ~ ~.~.~ t//2,.~.~/~ la. Type of work [] Drill [] Redrill I lb. Type of well [] Exploratory [] Stratigraphic ~st --- [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas •Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 67.90' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028321 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1045' SNL, 371' EWL, SEC. 19, T11N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 1297' NSL, 601' WEL, SEC. 19, T11N, R15E, UM 18-13A Attotal depth ~ 9. Approximate spud date Amount $200,000.00 716' NSL, 4698' WEL, SEC. 20, T11 N, R15E, UM 02/02/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028326, 716' .I No Close Approach 2560 12695' MD / 8755' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9760' Maximum Hole Angle 91° Maximum surface 2615 psig, At total depth 0WD) 8600' / 3475 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD I TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 BTC-Mod 4005' 8700'[ 7975' 12695' 8700' 496 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations.flg~ J~ \1/ ~l~,~u,~,~ Present well condition summary Total depth: measured 11077 feet Plugs (measured) ~j~'l ? ~II,~~ true vertical 8812 feet~,,~ -~F'~,,'~--~~ Effective depth: measured 11077 feet Junk (measured) true vertical 8812 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 1694# Poleset 110' 110' Surface 4445' 13-3/8" 3500 sx CS III, 600 sx 'G', 100 sx CS II 4482' 4427' Intermediate Production 9068' 9-5/8" 930 sx Class 'G' 9103' 8257' Liner 1472' 7" 500 sx Class 'G' 8805' - 10277' 7989' - 8700' Perforation depth: measured Slotted Liner: 10265'-10910' ORIGINAL true vertical Slotted Liner: 8701' - 8782' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Matt Scheuring, 564-4809 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certi~/that the foreg, pf~g is true and correct to the best of my knowledge Signed ~5 ~_~' ~,~ )/'/o~¢//~0 Jam Title Engineering Supervisor Date Commission Use Only Permit Number APl Number I Ap.p. rovalDate I See cover letter ¢-t'7--c) ~ 50-029-21756-01 ~re~d~/~~ for other requirements Conditions of Approval: Samples Required []Yes J~No Mud Log Req I'-IYes J~,No Hydrogen Sulfide Measures J~J'Yes [] No Directional Survey Required J~Yes J'-INo Required Working Pressure for ROPE []2M; []3M; J~5M; []10M; [] 15M Other: Or, lgl~al 5lgii~., --., by order of iApproved By ~- ~5'-~/¢J~Vid W, J0hrlstU~mmissioner the commission Date Form 10-401 Rev. 12-01-85 Submi' licate t STATE OF ALASKA · · · ALASKA OiL AND GAS CONSERVATION COMMISSION Revised: 01/26/98 APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: i~ Abandon [] Suspend ~ Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well i J Pull Tubing [] Variance ~ Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well E~ stimulate Plug Back for Sidetrack 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) ARCO Alaska Inc. [~ Development 48' RKB I--]. Exploratory 7. Unit or Property Name 3. Address ~]Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 .~.,Service 4. Location of well at surface 8. Well Number 18-13 1045' SNL, 371' EWL, SEC. 19, T11N, R15E, UM 9. Permit Number At top of productive interval M' '/~;;'"'~ '~i:~ ~'"'~¥ '~;'~-i~ "~ 2412'NSL, 2572'WEL, SEC. 19, T11N R15E, UM i~. ,~; ~*; ~i 2 l~.~P~~er At effective depth ~! ~'~ .~.' (~ 1208' NSL, 3932' EWE, SEC. 19, T11N, R15E, UM ~17~e~1~ool At total depth ~ / ¢ /;%~ Prudhoe Bay Field / Prudhoe Bay 1208' NSL, 3932' ~L, SEC. 19, T11 N, R15E, UM Dat~ .....~ ~ Pool 12. Present well condition summaw ~ Total depth: measured 11077 feet Plugs (measured) true ve~ical 8812 feet Effective depth: measured 11077 feet Junk (measured) true ve~ical 8812 feet .~ Casing Length Size Cemented ~ ~D Structural , ,, ~ / ¢ Conductor 80 20 ,, 1694¢ p~eset~ - ~ V110' 110' Sudace 4445' 13-3/8 3500 sx ~ II1,~00 sx 'G', 100 sx CS~l ~ ~2' 4427' Intermediate _ ~ ~ (, ~ ~ , Production 9068' 9-5~8" 930 sx~ss :¢', / ~ / ~ ~ 9103' 8~57 Liner 1472' 7 500~C1~'[ ~ ~ ]~ 8805'-10277' 7989-8700' Pedoration depth: measured Sl~d Liner: 10~65 - 10910' % ~~ .¢ '?~ ' true ve~ical Sl~tteGLiner:~70~- 8782' ~ ~%, Tubing (size, grade, and measured de,h)/ 3-~',.3~, L-80 PC Tubing at 10174' ~ ~.~;~ ,--" ired d p~ r~¢ '- ~,.~.,~" Packers and SSSV (type and measured de W packer at 10174, Otis TR SSSV at 22~ ~;¢~0~ ~*; .¢~ 0 Attachments 13. ~ Description summaq of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: Januaw 30, 1998 16. If proposal was verbally approved ~ Oil ~ Gas ~ Suspended Se~ice Name of approver Date approved Contact Engin~r Name/Number: Matt Scheuring, 564-4809 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby~e~ify that the f~going is true and correct to the best of my knowledgeU ¢~ Signed...~ ~/ ~~~ Title ~¢~ .~ ~¢ ¢-~ Date Commission Use Only Conditions of Approval: Noti~ Commission so representative may witness ~ Approval No. Plug integrity ~ BOP Test __ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate Well Name: I 1 8-1 3A Sidetrack Plan Summary Type of Redrill (producer or injector): Surface Location: X=692133.17 IPr°ducer I 1045' FNL, Target I Location: X=696200 Y-5958000 1297' FSL, 601' FEL, Sec. 19, T11N, R15E, UM Bottom Hole Location: X-697400 Y-5957450 716' FSL, 4698' FEL, Sec. 20, T11N, R15E, UM Y-5960832.37 371' FEL, Sec. 19, T11N, R15E, UM I AFE Number: I Pending I Estimated Start Date: 12/3/98 IRig: ID°y°n9 Operating days to complete: I MD: 112,695' I ITVD: 18755' I I Well Design (conventional, slimhole, etc.): 117 IRKB ~67.90' I Ultra-slimhole Horizontal Side-track I Objective: I Access Zone 1B reserves of 1.63 MSTBO Mud Program Production Mud Properties:I Solids Free Quikdriln Density Viscosity LSR LSRV Filtrate pH (PPG) YP 8.7-8.9 55-65 14-24 35000-55000 NC 8.5-9.0 Keep Sand content at less than 0.25% in the production interval Directional KOP: Maximum Hole Angle: Close Approach Well: 9,760' MD 91° N/A Formation Markers Formation Tops MD TVD (SS) Zone 2B - KOP 9760' 8480' Zone 2A 10296' 8586' Romeo 10596' 8620' CG OC 10840' 8650' Target Polygon Start 11374' 8705' TD 12695' 8700' BSAD N/A 8715' Casing/Tubinc. Pro.c ram Hole Size Csg Wt/Ft Grade Conn Length Top Btm MD/TVDss MD/TVDss Existing 9-5/8" 47#. L-80 BTRS 9,103' Surface 9,103'/8211' 6" 4.5" 12.6# L-80 BTC-MOD 4005' 8700'/7975' 12,695'/8700' Tubing 4.5" 12.6# L-80 BTC-MOD 8700' Surface 8700'/7975' Cement Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments P&A 120/15.8/1.15 Pre-rig Coil tubing spot cement down hole to place TOC ,-,10,180'. 4-1/2" 496/15.8/1.15 Soild Cemented Liner, Class "G", TOC to 200' above liner top Volume assumptions: Gauge hole + 50% excess; 80' shoe joints; TOC as listed. Logging Program ILogs: 6" Hole DPC Logs: MWD/GR from KOP to horizontal, MWD/GR/RES in horizontal section. Platform Express will be run through the build section after reaching horizontal. Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Bottom hole pressure is expected to be 3475 psi. Maximum expected surface pressure at 8600' tvdss is 2615 psi (assuming gas column of 0.1 psi/fi) Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards DS 18 is not an H2S drillsite. Stuck pipe/lost circulation has been reported. Shallow gas (Ugnu, W. Sak) and Put River (gas) will not be penetrated. Kingak will not be penetrated. (ST below) Disposal Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal. 18-06A Short Well Summary 18-13 History Well 18-13 was originally drilled in November 1987 as a high angle well cutting across Zone lB. The well produced in December 1987 at 1,200 BOPD and subsequently improved to over 2,000 BOPD. In 1990 18-13 began to be cycle produced. An August 1991 log showed that the GOC had moved down locally, leaving 15 feet of standoff left from the original 50 feet of standoff. In 1997 the well has been on-line 58% of the time, producing an average of 1,080 BOPD at 17,600 GOR. The well has a cumulative oil production of 2.86 MMBO. Well work options are not viable as there is a lack of shale breaks in the producing interval and the well has been completed with a slotted liner. The close proximity of the GOC will limit this wells production. The proposed side-track will not only improve standoff, but it will also replace a vertical well with a horizontal. Pre-Rig Operations: The objective of the pre-rig work is to ascertain the condition of the 9 5/8" casing presently in the hole; P&A all open perforations; and test the 9 5/8" pack offs. 1. Notify AOGCC of initiation prior to commencing any P&A operations. 2. NU on Well. 3. Make GR/JB run on 31/2'' tubing. 4. RIH with coil and spot 120 sks. (24 bbls.) of class G, 15.8 ppg cement to place TOC @ 10180' MD. TOC should be no higher than 10180' MD so as not to interfere with pulling the tubing later. 5. Tag and pressure test cement P&A. 6. Pressure test 9 5/8" annulus to 3000 psi for 30 min to check for casing leak against cement. If pressure test fails, notify ODE immediately. 7. Test packoffs on tubing and 9 5/8" annulus, and carefully cycle Iockdown screws. 8. Freeze protect tubing. 9. Set BPV. 10. Clear location, dig out cellar, remove electrical lines, remove well house. Rig 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Operations MIRU Pull BPV Circulate out freeze protection and circulate well with seawater. ND tree. NU BOP. Test BOP Change packoff if failed in Pre-rig Pull tbg. If there is evidence of debris, make GR/JB run. Set EZSV ,-, 9781' MD as per CCL. Set 7" whipstock assembly 25° left of highside. Displace to 4% KCI Quikdriln mud. Mill window MU BHA#1 for build w/MWD/GR & drill to horiz ,.-11373' MD. DPC Platform Express Build section. MU BHA#2 for horizontal section W/MWD/GR/RES and drill to TD @,--12,695' MD. POOH Run 4-1/2" L-80 liner with 2 MLAS subs. 2 X nipples, and set wi 9-5/8"x4-1/2" packer @ ,-,8700' MD. Cement via inner string to 8550' MD Perf as per asset direction. Complete with 4 GLMs, an X nipple and a SSSV on 4-1/2" tubing. Freeze protect well. RDMO Shared Services Drilling 5100 2700 3300 3900 4500 -2100 1",~~ . -2700 ~ ~740.54 -330 . ' 3515.g$ S. 5178.64 E -3900 . -I I I I I 2700 3300 · 3900 4500 51(30 Scale: linch = 600fl 5700 I Eastings 57OO Reference is True North DrillQuesf -21 O0 -2700 -3300 Proposal Data for 18-13A Wp1 Veflic~! Odgln: WeI~ Horizontal Ot'lgln: Well Measmement Units: It Nod. h Reference: Tru~ North Dogleg Severity: Degrees per lOOlt Venice! Section Azknoth: 117360' Vertlcsl Section DescdpUonWelt VertkT. al Section OHgln: 0.00 N,0.O0 E Moalured Incl. Azlr~ VerUcal Northlngs Eastlngs Vortical Dogleg 9760.(~ 67.640 132,605 ·8535.57 21./IL89 S 2594.1F/E 3305.9'/ 91{00.00 31.640 132.605 8549.48 2204.2'/S 2622.4'/E 3342.14-10.0~0 10111{.4182.931{116.780 8619.~6 2379.37 S 28TLI0 E 3648.37 6.000 I 1164.3082.938 116.380 8748.50 2~17.21 $ 3S04.08 E 46S'/.06 0.0~0 11373.1{090.532 113.26~ 8760.40 2935.42 S 3993.09 E 4895.4'/ 4.000 I 139 I.?0 ~0.611 112.555 8760.22 2942`3~, S 4009.5./E 4913.31 4.000 I I'n4../9 90.611 112.555 8'/56.14 30E9.3 ! s 4363.34 E 5295.03 11912.51 ~3.000 118.030 ' 8'/55.40 314E. 13 S 44~/.81 E 5432.61 4.000 .12695'1490.000 118.030 8755.40 3515.91 S 51'/8.64 E6215.18 0.0(X} t SURFAC~ LOCATION REFERENCE J4o~tm,~tbl ~ t 5060e32,37 N. 692133.17 E RKn E~'sU~: ~.oon t7.4o f~ ~5.40 t C4~a~lb~b Sys~m: Zone 4. US Fe<d PLOT DATE: 07..Ja'~ua~-91 : ' Cl~eked By: , Proposal Target Summary T~d Hm~: TVD~ TVD~b:Wdlh~J Off~t~: Gk~ ~d~: !~1~1 ~.ffi~.~ ~15.42 S. ~.~ E ILI~ 17~.~~55.~ 31~I3S,~AI E 1~1~ ~.~ ~55.~ ~15.91 ~5138~ E59~4~.~ N, 6~.ffi E ~. 8400 - 9000 9NXL(MI ............................................. , ........................................... , ...... , ............................................. Z2C 2222...;' . ................................. , ....................................................................................................... ........ ,~ · .~ ,~'~- .~-~.~ . ......... ,_. ........ ~ .... --.. ;..o.x...;...~' .... -..-..--"...;.-.~' .... -....;-..: ........... ~ ................... BSAD/OWC230 ......................................... ~.-~-h ~.~ ~r~ ~'~ ~7e0.40 TVO lS-12A'['2t 4 I~Z' gn~f 2935.42 S. 3~.09 E $7S5.40 TVD ~26~S.~4 [~D~755.40 ~ I I I I I I 3300 3900 4500 5100 5700 6300 Scale: 1 inch = 600tt Vertical ~ect[oFI Section Azimuth: 117.360° (True North) Sperry'Sun Drilling se rvi' es ProposaI Report for 18-13A- 18-13A Wp1 PRELIMINAI Y Shared Services Drilling Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 18 Measured Vertical Vertical Dogleg Depth Incl, Azim, Depth Northings Eastings Section ' Rate (ft) (ft) (ft) (ft) (ft) (°/100ft) 9760.00 67,640 132.605 8535.57 2178.89 S 2594.87 E 3305.97 9800.00 71,640 132.605 8549,48 2204.27 S 2622.47 E 3342.14 10,000 10118,41 82,938 116,780 8619,86 2379.37 S 2877.10 E 3648.77 6.000 11164.70 82,938 116.780 8748.50 2847.21 S 3804.08 E 4687.06 0.000 11373.80 90,532 113.266 8760,40 2935.42 S 3993.09 E 4895.47 4,000 11391.70 90,611 112.555 8760,22 2942,38 S 4009.57 E 4913.31 4.000 11774.79 90.611 112.555 8756.14 ' 3089,31 S 4363,34 E 5295.03 0,000 11912.51 90,000 118,030 8755.40 3148.13 S 4487.81 E 5432.61 4,000 12695.14 90,000 118.030 8755.40 3515,91 S 5178.64 E 6215.18 0.000 All data is in feet unless otherwise stated. Directions and coordinates are'relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100It. Vertical Section is from Well and calculated along an Azimuth of 117,360° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12695.14ft., The Bottom Hole Displacement is 6259.39ft., in the Direction of 124.174° (True). Formation Tops Measured Depth (ft) 10295,73 10495,17 10601.40 Vertical Sub-Sea Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) 8641.66 8586.26 2458.65 S 5034,20 E Z2A 8666.18 8610.78 2547,83 S 3210.89 E GOC 230 8679.24 8623.84 2595.33 S 3305.01 E Z1 Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) <Surface> <Surface> 12695.14 Targets associated with this wellpath Target Name 18-13A POLY 18-13A T1 18-13A T21 18-13A T3 Vertical Depth Casing Detail (ft) 8755.40 4 1/2' Liner Target Entry Coordinates TVD Northings Eastings Target Target (ft) (fi) (ft) Shape Type 8755.40 2832.89 S 3895.68 E Polygon Geologi,cal 8760.40 2935.42 S 3993.09 E Point Geological 8755.40 31 48.13 S 4487.81 E Point Geological 8755,40 3515.91 S 5178.64 E Point Geological PRELIM NARY .Sperry-Sun Drilling Services Proposal Report for 18-13A - 18-13A Wp1 Shared Services Drilling Prudhoe Bay Unit · Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9760.00 67.640 132,605 8480.17 8535.57 9780.00 69,640 132,605 8487.45 8542.85 9800.00 71,640 132.605 8494.08 8549,48 9820.00 72.317 131,564 8500.27 8555.67 9840.00 73.000 130,530 8506.23 8561.63 9860.00 73,689 129.504 8511.97 8567.37 9880.00 74.382 128,485 8517.47 8572,87 9900.00 75.080 127,473 8522.73 8578,13 9920,00 75.782 126.468 8527,76 8583,16 9940.00 ~- 76.488 125.469 8532.56 8587.96 9960.00 77.199 124.476 8537,11 8592.51 9980.00 77.913' 123.488 8541.42 8596.82 10000.00 78.631 122,506 8545.48 8600.88 10020.00 79.351 121.528 8549.30 8604.70 10040.00 80.075 120.555 8552.88 8608.28 10060.00 80.802 119.587 8556.20 8611.60 10080.00 81.531 118.622 8559.27 8614.67 10100.00 82.263 117.662 8562.09 8617.49 10118.41 82.938 116.780 8564.46 8619.86 10295.73 82,938 116.780 8586.26 8641.66 10495.17 82.938 116.780 8610.78 8666.18 10500.00 82.938 116.780 8611.37 8666.77 10601.40 82.938 116.780 8623.84 8679.24 11000.00 82.938 116.780 8672.85 8728.25 11164.70 82.938 116.780 8693.10 8748.50 11200.00 84.219 116.182 8697.04 8752.44 11300.00 87.850 114.501 8703.96 8759.36 11373.80 90.532 113.266 8705.00 8760.40 11391.70 90.611 112.555 8704.82 8760.22 11500.00 90.611 112,555 8703,67 8759.07 Local Coordinates Northings ' Eastings (ft) (ft) 2178.89 S 2594,87 E 2191,49 S 2608.58 E 2204,27 S 2622.47 E 2217.01S 2638,58 E 2229,55 S 2650.98 E 2241.87 S 2665,65 E 2253,97 S 2680,60 E 2265.84 S 2695,80 E 2277.48 S 2711,27 E 2288.89 S 2726,98 E 2300,05 S 2742,94 E 2310,96 S 2759.14 E 2321.63 S 2775.56 E, 2332.04 S 2792.21 E 2342.18 S 2809.07 E 2352.06 S 2826.13 E 2361.68 S 2843.40 E 2371.02 S 2860.86 E 2379,37 S 2877.10 E 2458.65 S '3034.20 E 2547.83 S 3210.89 E 2549,99 S 3215.17 E 2595.33 S 3305.01 E 2773.57 S 3658.16 E 2847.21S 3804.08 E 2862,85 S 3835.48 E 2905,54 S 3925.62 E 2935.42 S 3993.09 E 2942.38 S 4009.57 E 2983,92 S 4109,58 E Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°/100ft) 5958720.54 N 694782,90 E 5958708.28 N 694796,92 E 10.000 5958695,87 N 694811,13 E 10,000 5958683,49 N 694825,57 E 6,000 5958671,32 N 694840,28 E 6.000' 5958659,38 N 694855,27 E '6,000 5958647.67 N 694870,51 E 6,000 5958636,19 N 694886,02 E 6,000 5958624.95 N 694901,78 E 6,000 5958613,95 N 694917,78 E 6.000 5958603,20 N 694934,02 E 6.000 5958592,70 N 694950.49 E 6.000 5958582,46 N 694967,18 E 6.000 5958572.48 N 694984,08 E 6.000 5958562.77 N 695001.20 E 6.000 5958553,33 N 695018,51E 6.000 5958544,16 N 695036,02 E 6.000 5958535.27 N 695053,71 E 6,000 5958527,33 N 695070.16 E 6,000 5958452.09 N 695229,23 E 0,000 5958367.46 N 695408.15 E 0.000 5958365.41N 695412.48E 0,000 5958322,38 N 695503,45 E 0.000 5958153,23 N 695861.04 E 0.000 5958083.34 N 696008,80 E 0,000 5958068.51N 696040.58 E 4,000 5958028.14 N 696131,79 E 4,000 5958000,00 N 696200.00 E 4.000 5957993.46 N , 696216,65 E 4.000 595~954.49 N 696317,70 E 0.000 Vertical Section (ft) ', 3305.97 3323.94 3342.14 3360.54 3379.09 3397,78 3416.61 34,35.58 3454.66 3473.86 3~93.16 3512.56 3532.05 3551.62 3571.25 3590.95 3610.71 3630,51 3648.77 3824.73 4O22.64 4027.44 4128.06 4523.62 4687.06 4722.13 4821,81 4895.47 4913.31 5021.22 Comment Z2A GOC 230 Zl ' Target: 18-13A T1, Geological 7 ,January, 1998- 14:12 ,1- PRELIMINARY .Sperry-Sun Drilling Services Proposal Report for 18-13A - 18-13A Wp1 Shared Services Drilling Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Depth incl. Azim. Depth Depth Northings Eastings (tt) (ft) (ft) (ft) (ft) 11774.79 90.611 112.555 8700.74 8756.14 3089.31 S 4363.34 E 11800.00 90.500 113.557 8700.49 8755.89 3099.19 S 4386.54 E 11900.00 90.056 117.533 8700.01 8755.41 3142.30 S 4476.74 E 11912.51 90.000 118.030 8700.00 8755.40 3148.13 S 4487.81 E , 12000.00 90.000 118.030 8700.00 8755.40 3189.25 S 4565.04 E 12500.00 90.000 118.030 8700.00 8755.40 3424.21 S 5006.39 E 12695.14 90.000 118.030 8700.00 8755.40 3515.91 S 5178.64 E Global Coordinates Dogleg Northlngs Eastings Rate (ft) (f-t) (°/100ft) 5957855.62 N 696574.06 E 0.000 5957846.34 N 696597.50 E 4.000 5957805.55 N 696688.78 E 4.000 5957800.00 N 696700.00 E 4.000 5957760,88 N 696778.25 E 0.000 5957537.27 N 697225.46 E 0.000 5957450.00 N 697400.00 E 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 117.360" (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12695.14ft., The Bottom Hole Displacement is 6259.39ft., in the Direction of 124.174° (True). Vertical Section (ft) 5295.03 5320.17 5420.09 5432.61 5520.09 6020.05 6215.18 Comment Target: 18-13A T21, Geological 4 1/2" Liner Target: 18-13A T3, Geological 7 ~anuary, 1998 - 14:13 - 2 - TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 1, 1997 Erin Oba Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoe Bay Unit 18-13A ARCO Alaska, Inc. Permit No: 97-223 Sur. Loc.: 1045'FNL, 371'FWL, Sec. 19, TllN, R15E, UM Btmhole Loc: 4562'FNL, 4696'FEL, Sec. 20, TllN, R15E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) 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 test. Notice may be given by contacting the Commission petroleum field inspector on the North Sl. ope page~ David W. Johnston \ Chairman'%.......~ BY ORDER OF THE COMMISSION dlffenclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ...~. ALA~itA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill_ Redrill X lb. Type of Well Exploratory_ StratigraphicTest_ Development Oil Re-Entry__ Deepen _ Service_ Development Gas_ Single Zone X Multiple Zone_ 12 Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 48' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28321 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1045' FNL, 371' FWL, Sec 19, TllN, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2412' FSL, 2572' FWL, Sec 19, T11N, R15E, UM. 18-13A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 4562' FNL, 4696' FEL, Sec 20, T11N, R15E, UM. December, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 12800' MD / 8753' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10450 Maximum hole an~lle 91° Maximum surface 2800 psig At total depth (TVD) 8700' 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD 'I'VD (include stage data) 2-3/4" 2-3/8" 4.6 L-80 FL4S 2640' 10160' 8677' 12800' 8753' 9 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary REGEiV~D Total depth: measured 11077 feet Plugs(measured) true vertical 8812 feet ~0V Effective depth' measured 11077 feet Junk (measured) true vertical 8812 feet A~,$~I. 011 & Gas Cons. Comrnt~s~o~ Casing Length Size Cemented Measured depth True Conductor 110' 20" 1694# Poleset 110' 110' Surface 4445' 13-3/8" 3500 Sx CS III & 4482' 4427' 600 Sx Class G & 100 Sx CS II (top job) Production 9068' 9-5/8" 930 Sx Class G 9103' 8257' Liner 1472' 7" 500 Sx Class G 10277' 8700' Perforation depth: measured Slotted Liner: 10265 - 10910' true vertical Slotted Liner: 8645 - 8713'ORIGINAL 20. Attachments Filing fee x Property plat _ BOP Sketch x Diverter Sketch _ Drilling program x Ddlling fluid program Time vs depth plot _ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements_ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge (:~,.~ 2_%'~'~ O ~ '5 ~ ~"~ ',,/' ¢__. W o.. C'c:~. ~---~ -~ J~ S,~lned /4~'~ , %, ~ Title Engineering Supervisor Date //- //~-- ~' "'7 Commission Use Only Permit Number I AP, number I Approval date/-.~ ¢-. I See cover 'etter for p.~ - ~ 3 50- (:3 ~-- ~ --" ~ .,/ 7 ~ ~ '" 4:~ J ~ J '~ I other requirements Conditions of approval Samples required _Yes ,~'No Mud log required _Yes '~No Hydrogen sulfide measures ~ Yes _ No Directional survey required ,3~ Yes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 1OM; _ 15M X 3/,500 psi for CTU Other: t,,,/ Original Signed By David W. Johnston by order of /..-~L ¢~ Approved by Commissioner the commission Date . ~. Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll _ Redrai X lb. Type of Well Exploratory.._, Stratigmphic Test Development OII ~X Re-Entry__, Dee~ea _ , Service _ Development Gas _ Single Zone ~ Multiple Zone _ 2. Name of operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 48' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28321 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1045' FNL, 371' FWL, Sec 19, T11N, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2412' FSL, 2572' FWL, Sec 19, T11N, R15E, UM. 18-13A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 4562' FNL, 4696' FEL, Sec 20, T11N, R15E, UM. December, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 1-VD) property line No Close Approach 12800' MD / 8753' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Idckoff depth 10450 Maximum hole ancjle 91 o Maximum surface 2800 psi,~ At totaJ depth {TVD/ 8700' 18. Casing program Setting Depth Size ~tiorl Top Bottom Quantity of cement Hole Casin'q Wei,qht Grade i Couplin'q Len~h MD TVD MD TVD (include sta,c~e data) 2-3/4" 2-3/8" 4.6 L-80 j FL4S 2640' 10160' 8677' 12800' 8753' 9 bbls i 19. To be completed for Redrill, Re-entry, and Deepen Operations. Presentwellcondltionsumrnary RECEIVED Total depth: measured 11077 feet Plugs(measured) true vertical8812 fee, NoV 2 Effective depth: measured 11077 feet Junk (measured) true vertical 8812 feet Naska 011 & Gas Cons. cDmmi~¢on Casing Length Size Cemented Measured depth True Conductor 110' 20' 16944f Poleset 110' 110' Surface 4445' 13-..'.'.'.'.'.'.'.'~8' 3500 Sx CS III & 4482' 4427' 600 Sx Class G & 100 Sx CS II (top job) Production 9068' 9-5/8' 930 Sx Class G 9103' 8257' Uner 1472' 7" 500 Sx Class G 10277' 8700' Perforation dep{h: measured Slotted Liner: 10265 - 10910' true vertical Slotted Liner: 8645 - 8713'ii'iI?.i ~,, , ! ~_,'~'~' l i;.F~.//~ ~r- f--, 20. Attachments Filing fee ~ Property plat I BOP Sketch __x Diverter Sketch _ Driling program ~ Dfillin'q fluid pm,qram Time vs depth plot I Refraction analysis -- Seabed report _ 20 AAC 25.050 requirements - 21. I hereby certify that the foregoing is true ar~ correct to the best o! my knowledge (~ ~ ~%.~-; o t'-t '~ ~. ~ ~'~ V ~_ '~ o. t-& ~---~:~ ~'- ~-~ O.~. Signed ~'~_~ %, ~ Title Engineering Supervisor Date //- //~ -- ~' '7 Commission Use Only Permit Number I APl number Approval d~ate~ I See cover letter for ,,r other .- . requirements Conditions of approval Samples required _Yes ~ No Mud Icg required _ Yes Hydrogen sull'lde measures ,,~'Yes _ No Directional survey required ~'~'Yes _ No Required working pressur~ for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M X/3,500 psi for CTU Other: D~vid W, byorderof f ~ Approved by Commissioner the commission Date . '_ Form 10-401 Rev. 7-24-89 Submit in triplicate DS 18-13A CT Extension and Completion Intended Procedure Directionally drill --t900', 2-3/4" horizontal hole from the existing wellbore. Complete with 2-3/8" cemented liner. ~tended Procedure- -- Cement squeeze the current slotted liner and plugback the existing completion to -. 10200' md. Mill window in 4-1/2" liner at ~10450' md. Dr/Il 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to ~90~. Directionally drill 2-3/4" x 1900' horizontal well to access Lower Romeo Run and cement 2-3/8" liner to TD. Perforate selected intervals. Place well on production. November 18, 1997 3-1/2" Production Tubing 3-1/2" Offs FM-7 sSsv @ 2211' w/ WL Insert valve 3-1/2" X Nipple@ 8185' 3-1/2" X Nipple@ 10161' DS 18-13A PROPOSED CT ST AND COMPLETION TD @ ~ 12800' Initial perforations 2-3/8" Cmt'd liner 2.75" hole Window cut in 4.5" liner and cmt in 6" annulus @ 10450' II 10174' MD TIW Pkr. & OS Ass'y 10277' MD 7" Liner shoe !7 ppg ~ement pl~g in 4-1/2''~ liner and 4.5"x 6" annulus ' ~t~;1 ~, ~ '" 18-13A Well Plan 3 3/4" Hole Size Plane of Vertical Section = 114.225 o Relative to True North Magnetic Declination = 28.48° Grid Convergence = 1.465° RKB = 48ff. Surface Coordinates = 692133.2 X, 5960832.5 Y,Alaska State Plane Comments Coordinates referenced to True North MD Inc Dir SS Tvd Vsec Lat Dep Build Turn Dleg ft. deg. deg. ft. ft. ft. ft. °/100' °/100' °/100' 10287 79.00 130.50 8657.4 0.0 -2518.4 2961.3 0.0 0.0 0.0 1. Tie in point (Actual, not interpolated) 10290 79.09 130.50 8658.0 2.8 -2520.3 2963.6 3.1 0.0 3.2 10320 80.04 130.50 8663.4 31.1 -2539.5 2986.0 3.1 0.0 3.1 10350 80.98 130.50 8668.4 59.6 -2558.7 3008.5 3.1 0.0 3.1 10380 81.92 130.50 8672.8 88.0 -2577.9 3031.1 3.1 0.0 3.1 2. Kick offpoint. 10410 82.86 130.50 8676.8 116.6 -2597.3 3053.7 3.1 0.0 3.1 10440 83.80 130.50 8680.3 145.2 -2616.6 3076.3 3.1 0.0 3.1 10450 84.12 130.50 8681.3 154.7 -2623.1 3083.9 3.1 0.0 3.1 10470 84.31 129.31 8683.3 173.9 -2635.8 3099.2 0.9 -6.0 6.0 10500 84.60 127.52 8686.2 202.8 -2654.4 3122.6 1.0 -6.0 6.0 10530 84.89 125.74 8689.0 232.0 -2672.2 3146.5 1.0 -5.9 6.0 10560 85.19 123.96 8691.6 261.4 -2689.3 3171.1 1.0 -5.9 6.0 10590 85.49 122.18 8694.0 290.9 -2705.6 3196.1 1.0 -5.9 6.0 10620 85.80 120.40 8696.3 320.6 -2721.1 3221.7 'i.0 -5.9 6.0 10650 86.11 118.62 8698.4 350.4 -2735.9 3247.7 1.0 -5.9 6.0 10680 86.42 116.84 8700.4 380.3 -2749.8 3274.2 1.0 -5.9 6.0 10710 86.74 115.07 8702.2 410.2 -2762.9 3301.1 1.1 -5.9 6.0 10740 87.06 113.30 8703.8 440.2 -2775.2 3328.5 1.1 -5.9 6.0 10770 87.39 111.52 8705.2 470.1 -2786.6 3356.2 1.1 -5.9 6.0 10800 87.71 109.75 8706.5 500.0 -2797.2 3384.2 1.1 -5.9 6.0 3. Maintain -81 o toolface. 10830 88.04 107.98 8707.6 529.9 -2806.9 3412.6 1.1 -5.9 6.0 10860 88.37 106.21 8708.6 559.6 -2815.7 3441.2 1.1 -5.9 6.0 10890 88,71 104.44 8709.3 589.3 -2823,6 3470.2 1.1 -5.9 6.0 10920 89.04 102.67 8709.9 618.7 -2830.6 3499.3 1.1 -5.9 6.0 10927 89.12 102.25 8710.0 625.7 -2832.2 3506.2 1.1 -5.9 6.0 Alaska State Plane Grid Coordinates ASP ASP X Y 695157.9 5958390.5 695160.2 5958388.5 695183.1 5958370.0 695206.1 5958351.5 695229,1 5958333.0 695252.3 5958314.0 695275.4 5958295.5 695283.1 5958289.0 695298.7 5958276.5 695322.6 5958259.0 695347.0 5958241.5 695371.9 5958225.0 695397.4 5958209.5 695423.4 5958194.5 695449.8 5958180.5 695476.6 5958167.5 695503.9 5958155.0 695531.5 5958143.5 695559.5 5958132.5 695587.8 5958123.0 695616.4 5958114.0 695645.3 5958106.0 695674.4 5958098.5 695703.8 5958092.5 695710.7 5958091.0 11/18/97 18-13A.XLS 1 Commenl~ 4. Turn over to a +92.5° toolfacc. M D inc Dir SS Twl Vsec Lat ft. deg. d,e§. ft. ft. ft. 10950 89,33 100.90 8710.4 648.0 -2836.8 10980 89.62 99.12 8710.6 677.1 -2842.0 11010 89.90 97.34 8710.8 705.9 -2846.3 11040 90.18 95.56 8710.7 734.5 -2849.6 11070 90.46 93.79 8710.6 762.8 -2852.1 11077 90.53 93.36 8710.5 769.4 -2852.5 11100 90.47 94.73 8710.3 790.9 -2854.1 11130 90.39 96.52 8710.1 819.3 -2857.1 Dep Buihi Turn Dleg ft. °/10W °/100~ °/100' 3528.7 0.9 -5.9 6.0 3558.2 0.9 -5.9 6.0 3587.9 0.9 -5.9 6.0 3617.7 0.9 -5.9 6.0 3647.6 0.9 -5.9 6.0 3654.7 0.9 -5.9 6.0 3677.5 -0.3 6.0 6.0 3707.4 -0.3 6.0 6.0 ASP X 695733.3 695762.9 695792.7 695822.6 695852.6 695859.6 695882.5 695912.4 695942.3 695972.0 11160 90.31 98.31 8709.9 848.1 -2860.9 11190 90.23 100.10 8709.8 877.0 -2865.7 3737.1 -0.3 6.0 6.0 3766.8 -0.3 6.0 6.0 11220 90.15 101.89 11250 90.07 103.68 11280 89.99 105.47 11310 89.91 107.26 11340 89.83 109.04 8709.7 906.2 -2871.5 8709,6 935.6 -2878.1 8709.6 965.2 -2885.6 8709.6 994.9 -2894.1 8709.7 1024.8 -2903.4 3796.2 -0.3 6.0 6.0 3825.5 -0.3 6.0 6.0 3854.5 -0.3 6.0 6.0 3883.3 -0.3 6.0 6.0 3911.8 -0.3 6.0 6.0 5. Bump up to +87° toolface. 11370 89.76 110.83 11400 89.68 112.62 11427 89.60 114.26 8709.8 1054.7 -2913.7 8709.9 1084.6 -2924.8 8710.1 1112.0 -2935.7 3940.0 -0.3 6.0 6.0 3967.9 -0.3 6.0 6.0 3993.0 -0.3 6.0 6.0 11430 89.61 114.41 11460 89.71 116.21 8710.1 1114.6 -2936.7 8710.3 1144.6 -2949.6 3995.4 0.3 6.0 6.0 4022.5 0.3 6.0 6.0 11490 89.80 118.01 11520 89.90 119.81 11550 89.99 121.60 11580 90.09 123.40 11610 90.18 125.20 8710.4 1174.6 -2963.2 8710.5 1204.5 -2977.7 8710.5 1234.3 -2993.1 8710.5 1264.0 -3009.2 8710.4 1293.5 -3026.1 4049.2 0.3 6.0 6.0 4075.4 0.3 6.0 6.0 4101.2 0.3 6.0 6.0 4126.5 0.3 6.0 6.0 4151.3 0.3 6.0 6.0 11640 90.28 127.00 11670 90.37 128.79 11700 90.46 130.59 11730 90.56 132.39 11760 90.65 134.19 8710.3 1322.9 -3043.8 8710.2 1352.0 -3062.2 8709.9 1380.9 -3081.3 8709.7 1409.6 -3101.2 8709.3 1437.9 -3121.8 4175.6 0.3 6.0 6.0 4199.2 0.3 6.0 6.0 4222.3 0.3 6.0 6.0 4244.8 0.3 6.0 6.0 4266.6 0.3 6.0 6.0 6. Rc-oricnt to a -91 o toolfacc. 11790 90.74 !35.98 11820 90.84 137.78 11847 90.92 139.42 8709.0 1466.0 -3!4~3.0 8708.6 1493.6 -3164.9 8708.2 1518.6 -3185.5 4287.8 0.3 6.0 6.0 4308.3 0.3 6.0 6.0 4326.4 0.3 6.0 6.0 11850 90.91 139.27 11880 90.87 137.49 8708.1 1521.0 -3187.4 8707.6 1548.3 -3209.9 4328.1 -0.1 -5.9 5.9 4348.0 -0.1 -5.9 5.9 696001.6 696031.0 696060.2 696089.2 696117.9 696146.4 696174.6 696199.9 696202.4 696229.8 696256.8 696283.4 696309.6 696335.4 696360.6 696385.3 696409.4 696432.9 696455.9 696478.3 696500.0 696521.1 696539.7 696541.4 696561.9 ASP Y 5958087.0 5958082.5 5958079.0 5958076.5 5958074.5 5958074.5 5958073.5 5958071.0 5958068.0 5958064.0 5958059.0 5958053.5 5958046.5 5958038.5 5958030.0 5958020.5 5958010.5 5958000.0 5957999.0 5957987.0 5957974.0 5957960.0 5957945.5 5957930.0 5957913.5 5957896.5 5957879.0 5957860.5 5957841.0 5957821.0 5957800.5 5957779.0 5957759.0 5957757.0 5957735.0 11/18/97 18-13A.XLS :2 Comments MD ft. 11910 1194O 11970 12000 12O3O 12060 12090 12120 12150 12180 12210 12240 1227O 12300 12330 12360 12390 1242O 12450 12480 12510 12540 12570 12600 12630 12660 12690 12720 12750 12780 12799.4 7. TD is 2512 ft. fi.om TIP. Inc deg. 90.83 90,79 90,75 90.70 90.66 90.61 90.57 90.52 90.47 90.43 90.38 90.33 90.28 90.23 90.18 90.14 90.09 90.04 89.99 89.94 89.89 89.84 89.79 89.74 89.69 89.65 89.60 89.55 89.50 89.46 89.43 Dir deg. 135.72 133.94 132.17 130.39 128.62 126.84 125.06 123.29 121.51 119.74 117.96 116.19 114.41 112.64 110.86 109.09 107.31 105.54 103.76 101.99 100.21 98.43 96.66 94.88 93.11 91.33 89.56 87.78 86.01 84.23 83.08 SS Tvd 8707.2 8706.8 8708,4 8706.0 8705.6 8705.3 8705.0 8704.7 8704.4 8704.2 8704.0 8703.8 87O3.7 8703.5 87O3.4 87O3.3 87O3.3 8703.2 8703.2 87O3.2 8703.3 8703.4 8703.5 8703.6 8703.7 8703.9 8704.1 8704.3 8704.6 8704.8 8705.0 Vsec ft. 1576.1 1604.1 1632,5 1661.2 1690.1 1719.3 1748.7 1778.2 1807,9 1837,7 1867,6 1897,6 1927,6 1957,6 1987.5 2017.5 2047.3 2077.0 2106.6 2136.0 2165.2 2194.2 2223.0 2251.4 2279.6 2307.4 2334.8 2361.9 2388.5 2414.7 2431.4 Lat ft. -3231.7 -3252.8 -3273.3 -3293.1 -3312.2 -3330.5 -3348.1 -3365.0 -3381,1 -3396.3 -3410.8 -3424.5 -3437.3 -3449.3 -3460.4 -3470.6 -348O.O -3488.5 -3496.1 -3502.7 -3508.5 -3513.4 -3517.3 -3520.3 -3522.4 -3523.6 -3523.8 -3523.1 -3521.5 -3518.9 -3516.8 Dep ft. 4368.6 4389.9 4411.8 4434.4 4457.5 4481.2 4505.5 4530.3 4555.7 4581.5 Build °/100' -0.1 -0.1 -0.1 -0.1 -0.1 -0.2 -0.2 -0.2 -0.2 -0.2 Turn °/100' -5,9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 Dleg o/100, 5.9 5.9 5,9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 ASP X 696583.1 696604.9 696627,4 696650.4 696674.0 696698.2 696722.9 696748.2 696773.9 696800.1 4607.8 4634.5 4661.6 4689.1 4717.0 -0.2 -0.2 -0.2 -0.2 -0.2 -5.9 -5.9 -5.9 -5.9 -5.9 5.9 5.9 5.9 5.9 5.9 4745.2 4773.7 4802.4 4831.5 486O.7 -0.2 -0.2 -0.2 -0.2 -0.2 -5.9 -5.9 -5,9 -5.9 -5.9 5.9 5.9 5.9 5.9 5.9 4890.1 4919.7 4949.5 4979.3 5009.2 -0.2 -0.2 -0.2 -0.2 -0.2 -5.9 -5.9 -5.9 -5.9 -5.9 5.9 5.9 5.9 5.9 5039.2 5069.2 5099.2 5129.2 5159.1 5178.3 -0.2 -0,2 -0.2 -0.2 -0.2 -0.2 -5.9 -5,9 -5.9 -5.9 -5.9 -5.9 5.9 5.9 5.9i 5-9I 5.9 696826.8 696853.8 696881.3 696909.1 696937.2 696965,6 696994.4 697023.4 697052.6 697082.0 697111.6 697141.3 697171.1 697201.0 697231.0 697261.0 697291.0 697320.9 697350.8 697380.6 697399.9 II ASP Y 5957714.O 5957693.O 5957673.5 5957654.O 5957635.5 5957618.0 5957601.0 5957584.5 5957569.5 5957554.5 5957541.0 5957528.0 5957516.0 5957504.5 5957494.0 5957484.5 5957476.0 5957468.0 5957461.51 5957455.5 5957450.5 5957446.5 5957443.0 5957441.0 5957439.5 5957439.0 5957440.0 5957441.5 5957443.5 5957447.0 5957449.5 11/18/97 18-13A.XLS 3 ,,~&~, / ALASi<A INC AR-C laska I c. Wellplan for 18-13 EOA Prudhoe Bay, Alaska 8700-.-~ 8900 9100---~ 18-13AT 18130RTR o -2400 o ~ -2800 ~ -3200 -3600 Departure Scale 1 inch: 400 ft 4 5 Vertical Section Scale 1 inch: 200 ft Plm~e of vertical section = 114.225 degrees C T Drilling Wellhead Detail ~ CT Injector Head ~__~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection ~ I- 7'Riser I I Otis 7" WLA Quick Connect -----I I I I I I I ~~.~ Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange ~ I I 7'~5') ~ cutters or ' ~ Combination Cutter/Blinds 11 Fire Resistant Flanged Kelly Hoseto Dual HCR Man hal Vai, Choke Manifold ~]~ Slip / Pipe rams Manual Valves Ddlling spool 7-1/16", 5M by 7-1/16", 5M Ram T~,pe Dual Gate BOPE Manual over Hydraulic 7-1/16' ID with Pipe/Slip Rams Manual Master Valve 0.4SS' (S.5") 2' Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Mu~ Tanks ...... 60/40 I-ire Ext. Fuel Shop Boilers Water Pump Fire Ext. I-ire Ext. Pipe rack EDOWell Drilling J quipment Trailer Preferred Major Equipment Layout for CT Drilling DS 18.13A CT Extension and Completion Intended Proce~/ure Dh'ectional/y dr///-1900; 2-3/4" Complete with 2_3/8, cemented liner, from existing we//bore. horizontal hole the Cement squeeze the Current slotted //net C°mpletionto~ 10200'md. and plugback the existing MN W/ndow/n 4-1/2"/inet at ~10450' md. D~511 10' of formation and Perform Leak off test to 0.5 ppg above the highest anticipated mud Weight. Build angle to ~90°' Directionally drill reserves, x 1900' horizontal Well to access Lower Romeo Run and Cement 2-3/8" liner to TI). Perforate selected intervals. Place well on production. RECEIVED NOV 'igB November 18, 1997 3-1/2" Production Tubing 3-1/2" Otis FM-7 SSSV @ 2211' w/ WL insert valve 3-1/2" X Nipple@ 8185' 3-1/2" X Nipple@ 10161' II 10174' MD TIW Pkr. & OS Ass'y 10277' MD 7" Liner shoe DS 18-13A PROPOSED CT ST AND COMPLETION TD @ ~ 12800' Initial perforations 2-3/8" Cmt'd liner 2.75" hole Window cut in 4.5" liner and cmt in 6" annulus @ 10450' 17 ppg cement plug in 4-1/2" liner and 4.5"x 6" annulus 18-13A Well Plan 3 3/4" Hole Size Plane of Vertical Section =114.225 ° Relative to Tree North Magnetic Declination = 28.48° Grid Convergence = 1.465° RKB = 48ft. Surface Coordinates = 692133.2 X, 5960832.5 Y,Alaska State Plane Comments 1. Tie in point (Actual, not interpolated) 2. Kick offpoint. 3. Maintain -81 ° toolface. MD 10287 10290 10320 10350 10380 1O41O 1O44O 1O45O 10470 10500 10530 10560 10590 10620 10650 10680 1O71O 1O74O 10770 10800 10830 10860 10890 10920 10927 Coordinates referenced to True North Inc Dir SS Tvd Vsec Lat Dep Build Turn Dleg deg. deg. it. ft. it. it. °/100' °/100' °/100' 79.00 130.50 8657.4 0.0 -2518.4 2961.3 0.0 0.0 0.0 79.09 130.50 8658.0 2.8 -2520.3 2963.6 3.1 0.0 3.2 80,04 130.50 8663.4 31,1 -2539,5 2986.0 3.1 0,0 3.1 80.98 130,50 8668.4 59.6 -2558.7 3008.5 3,1 0.0 3.1 81,92 130.50 8672.8 88,0 -2577,9 3031.1 3.1 0.0 3.1 82.86 130.50 8676.8 116.6 -2597.3 3053.7 3.1 0.0 3.1 83.80 130.50 8680.3 145.2 -2616.6 3076.3 3.1 0.0 3.1 84.12 130.50 8681.3 154.7 -2623.1 3083.9 3.1 0.0 3.1 84.31 129.31 8683.3 173.9 -2635.8 3099.2 0.9 -6.0 6.0 84.60 127.52 8686.2 202.8 -2654.4 3122.6 1.0 -6.0 6.0 84.89 125.74 8689.0 232.0 -2672.2 3146.5 1.0 -5.9 6.0 85.19 123.96 8691.6 261.4 -2689.3 3171.1 1.0 -5.9 6.0 85.49 122.18 8694.0 290.9 -2705.6 3196.1 1.0 -5.9 6.0 85.80 120.40 8696.3 320.6 -2721.1 3221.7 1.0 -5.9 6.0 86.11 118.62 8698.4 350.4 -2735.9 3247.7 1.0 -5.9 6.0 86.42 116.84 8700.4 380.3 -2749.8 3274.2 1.0 -5.9 6.0 86.74 115.07 8702.2 410.2 -2762.9 3301.1 1.1 -5.9 6.0 87.06 113.30 8703.8 440.2 -2775.2 3328.5 1.1 -5.9 6.0 87.39 111.52 8705.2 470.1 -2786.6 3356.2 1.1 -5.9 6.0 87.71 109.75 8706.5 500.0 -2797.2 3384.2 1.1 -5.9 6.0 88.04 107.98 8707.6 529.9 -2806.9 3412.6 1.1 -5.9 6.0 88.37 106.21 8708.6 559.6 -2815.7 3441.2 1.1 -5.9 6.0 88.71 104.44 8709.3 589.3 -2823.6 3470.2 1.1 -5.9 6.0 89.04 102.67 8709.9 618.7 -2830.6 3499.3 1.1 -5.9 6.0 89.12 102.25 8710.0 625.7 -2832.2 3506.2 1.1 -5.9 6.0 Alaska State Plane Grid Coordinates ASP ASP X Y 695157.9 5958390.5 695160.2 5958388.5 695183.1 5958370.0 695206.1 5958351.5 695229.1 5958333.0 695252.3 5958314.0 695275.4 5958295.5 695283.1 5958289.0 695298.7 5958276.5 695322.6 5958259.0 695347.0 5958241.5 695371.9 5958225.0 695397.4 5958209.5 695423.4 5958194.5 695449.8 5958180.5 695476.6 5958167.5 695503.9 5958155.0 695531.5 5958143.5 695559.5 5958132.5 695587.8 5958123.0' 695616.4 5958114.0 695645.3 5958106.0 695674.4 5958098.5 695703.8 5958092.5 695710.7 5958091.0 11/18/97 18-13A.XLS 1 Comme~s MD Inc Dir SS Tvd Vsec Lat Dep Build Turn Dleg it. deg. deg. ft. ft. ft. ft. °/100' °/100' °/100' 0950 89.33 100.90 8710.4 648.0 -2836.8 3528.7 0.9 -5.9 6.0 0980 89.62 99,12 8710.6 677.1 -2842.0 3558.2 0.9 -5.9 6.0 1010 89.90 97,34 8710.8 705.9 -2846.3 3587.9 0.9 -5.9 6.0 1040 90.18 95.56 8710.7 734.5 -2849.6 3617.7 0.9 -5.9 6.0 1070 90.46 93.79 8710.6 762.8 -2852.1 3647.6 0.9 -5.9 6.0 4. Turn over to a +92.5° toolface. 11077 90.53 93.36 8710.5 769.4 -2852.5 3654.7 0.9 -5.9 6.0 100 90.47 94.73 8710.3 790.9 -2854.1 3677.5 -0.3 6.0 6.0 130 90.39 96.52 8710.1 819.3 -2857.1 3707.4 -0.3 6.0 6.0 160 90,31 98.31 8709.9 848.1 -2860.9 3737.1 -0.3 6.0 6,0 190 90.23 100.10 8709.8 877.0 -2865.7 3766.8 -0.3 6.0 6.0 11220 90.15 101.89 8709.7 906.2 -2871.5 3796.2 -0.3 6.0 6.0 11250 90,07 103.68 8709.6 935.6 -2878.1 3825.5 -0,3 6,0 6.0 11280 89.99 105.47 8709.6 965.2 -2885,6 3854.5 -0.3 6.0 6.0 11310 89.91 107.26 8709.6 994,9 -2894,1 3883.3 -0,3 6,0 6.0 11340 89.83 109.04 8709,7 1024.8 -2903.4 3911.8 -0.3 6.0 6.0 5. Bump up to +87° toolface. 11370 89.76 110.83 8709.8 1054.7 -2913.7 3940.0 -0.3 6.0 6.0 11400 89.68 112,62 8709.9 1084.6 -2924,8 3967.9 -0,3 6.0 6.0 11427 89.60 114.26 8710.1 1112,0 -2935.7 3993.0 -0.3 6.0 6.0 11430 89.61 114.41 8710.1 1114.6 -2936.7 3995.4 0.3 6.0 6.0 11460 89.71 116.21 8710.3 1144,6 -2949.6 4022.5 0.3 6.0 6.0 11490 89.80 118.01 8710.4 1174.6 -2963.2 4049.2 0.3 6.0 6.0 11520 89.90 119.81 8710.5 1204.5 -2977.7 4075.4 0.3 6.0 6,0 11550 89.99 121.60 8710.5 1234.3 -2993.1 4101.2 0.3 6.0 6.0 11580 90.09 123.40 8710.5 1264.0 -3009.2 4126.5 0.3 6.0 6.0 11610 90.18 125,20 8710.4 1293.5 -3026.1 4151.3 0.3 6.0 6.0 11640 90.28 127.00 8710.3 1322.9 -3043.8 4175.6 0.3 6.0 6.0 11670 90.37 128.79 8710.2 1352.0 -3062.2 4199.2 0.3 6.0 6.0 11700 90.46 130.59 8709.9 1380.9 -3081.3 4222.3 0.3 6.0 6.0 11730 90.56 132.39 8709.7 1409.6 -3101.2 4244,8 0.3 6.0 6.0 11760 90.65 134.19 8709.3 1437.9 -3121.8 4266.6 0.3 6.0 6.0 6. Re-orient to a -91 ° toolface. 11790 90.74 135.98 8709.0 1466.0 -3143.0 4287.8 0.3 6.0 6.0 11820 90.84 137.78 8708.6 1493.6 -3164.9 4308.3 0.3 6.0 6.0 11847 90.92 139.42 8708.2 1518.6 -3185.5 4326.4 0.3 6.0 6.0 11850 90.91 139.27 8708.1 1521.0 -3187.4 4328.1 -0.1 -5.9 5.9 11880 90.87 137.49 8707.6 1548.3 -3209.9 4348.0 -0.1 -5.9 5.9 ASP ASP X Y 695733.3 5958087.0 695762.9 5958082.5 695792.7 5958079.0 695822.6 5958076.5 695852.6 5958074.5 695859,6 5958074.5 695882.5 5958073.5 695912.4 5958071.0 695942.3 5958068.0 695972.0 5958064.0 696001.6 5958059.0 696031.0 5958053.5 696060.2 5958046.5 696089.2 5958038.5 696117.9 5958030.0 696146.4 5958020.5 696174.6 5958010.5 696199.9 5958000.0 696202.4 5957999.0 696229.8 5957987.0 696256.8 5957974.0 696283.4 5957960.0 696309.6 5957945.5 696335.4 5957930.0 696360.6 5957913,5 696385.3 5957896.5 696409.4 5957879.0 696432.9 5957860.5 696455.9 5957841.0 696478.3 5957821.0 696500.0 5957800.5 696521.1 5957779.0 696539.7 5957759.0 696541.4 5957757.0 696561.9 5957735.0 11/18/97 18-13A.XLS 2 Comments MD ft. 11910 11940 11970 12000 12030 12060 12090 12120 12150 12180 1221O 1224O 12270 12300 12330 12360 12390 12420 12450 12480 1251O 12540 12570 126OO 1263O 12660 12690 1272O 12750 12780 7. TD is 2512 ft. from TIP. 12799.4 Inc deg. 90.83 90.79 90.75 90.70 90.66 90.61 90.57 90.52 90.47 90.43 90.38 90.33 90.28 90.23 90.18 90.14 90.09 90.04 89.99 89.94 89.89 89.84 89.79 89.74 89.69 89.65 89.60 89.55 89.50 89.46 89.43 Dir deg. 135.72 133.94 132.17 130.39 128.62 126.84 125.06 123.29 121.51 119.74 117.96 116.19 114.41 112.64 110.86 109.09 107.31 105.54 103.76 101.99 100.21 98.43 96.66 94.88 93.11 91.33 89.56 87.78 86.01 84.23 83.08 SS Tvd fl. 8707.2 8706.8 8706.4 8706.0 8705.6 8705.3 8705.0 8704.7 8704.4 8704.2 8704.0 8703.8 8703.7 8703.5 8703.4 8703.3 8703.3 8703.2 8703.2 8703.2 8703.3 8703.4 8703.5 8703.6 8703.7 8703.9 8704.1 8704.3 8704.6 8704.8 87O5.O Vsec ft. 1576.1 1604.1 1632.5 1661.2 1690.1 1719.3 1748.7 1778.2 1807.9 1837.7 1867.6 1897.6 1927.6 1957.6 1987.5 2017.5 2047.3 2077.0 2106.6 2136.0 2165.2 2194.2 2223.0 2251.4 2279.6 2307.4 2334.8 2361.9 2388.5 2414.7 2431.4 Lat ft. -3231.7 -3252.8 -3273.3 -3293.1 -3312.2 -3330.5 -3348.1 -3365.0 -3381.1 -3396.3 -3410.8 -3424.5 -3437.3 -3449.3 -3460.4 -3470.6 -3480.0 -3488.5 -3496.1 -3502.7 -3508.5 -3513.4 -3517.3 -3520.3 -3522.4 Dep ft. 4368.6 4389.9 4411.8 4434.4 4457.5 4481.2 4505.5 4530.3 4555.7 4581.5 46O7.8 4634.5 4661.6 4689.1 4717.0 4745.2 4773.7 4802.4 4831.5 4860.7 4890.1 4919.7 4949.5 4979.3 5009.2 Build o/100, -0.1 -0.1 -0.1 -0.1 -0.1 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 Turn °/100' -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 Dleg °/100' 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 5.9 ASP X 696583.1 696604.9 696627.4 696650.4 696674.0 696698.2 696722.9 696748.2 696773.9 696800.1 696826.8 696853.8 696881.3 696909.1 696937.2 696965.6 696994.4 697023.4 697052.6 697082.0 697111.6 697141.3 697171.1 697201.0 697231.0 -3523.6 -3523.8 -3523.1 -3521.5 -3518.9 -3516.8 5039.2 5069.2 5099.2 5129.2 5159.1 5178.3 -0.2 -0.2 -0.2 -0.2 -0.2 -0.2 -5.9 -5.9 -5.9 -5.9 -5.9 -5.9 5.9 5.9 5.9 5.9 5.9 5.9 697261.0 697291.0 697320.9 697350.8 697380.6 697399.9 ASP Y 5957714.0 5957693.0 5957673.5 5957654.0 5957635.5 5957618.0 5957601.0 5957584.5 5957569.5 5957554.5 5957541.0 5957528.0 5957516.0 5957504.5 5957494.0 5957484.5 5957476.0 5957468.0 5957461.5 5957455.5 5957450.5 5957446.5 5957443.0 5957441.0 5957439.5 5957439.0 5957440.0 5957441.5 5957443.5 5957447.0 5957449.5 11/18/97 18-13A.XLS 3 Wellplan for 18-13 EOA Prudhoe Bay, Alaska True (+0) Mag (+28.47) 8300 -- -- -- -- -- -- -- 8500 - -- 8700 - - -- -- - 8900 - -- 9100 1 18-13AT 1813ORTR Departure Scale 1 inch '400 ft ~ o o o o o o o o o o o o o o _ ,Il IIllllIII [lJI II1[ IIIL~I,III IIL~_Illl IL_L. Ill]II ~ -2800 - '~"-.....~ CO - 4 - - -3600 7 3 4 I,, FITD - Vertical Section Scale 1 inch '200 ft ""~'~" '"'~'"'1""~'"' '"'~'"' '"'~"" '~"~""1'"'~'"'1'"'~'"'1'"'~'"' ""~'"'l'"'t'"'l''''~'''' '"'~'"' 0 0 0 0 0 bO -~ O~ CO 0 bO ~ C~ Plane of vertical section = 114.225 degrees C T Drilling Wellhead Detail ~ CT Injector Head ,~~ I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure -- 7" Riser Methanol Injection ConnectOtis 7" WLA Quick I '1 Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual ~ Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold \ Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M tm Type Dual Gate BOPE nua~ over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus Tanks 60/4OI I ,TrplxI I-ire Ext. Shop Fuel Boilers Water Pump Root Fire Ext. Fire Ext. Pipe ra~//¢ Dowell Drilling J Equipment TraiJe Preferred Major Equipment Layout for CT Drilling · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ ~'/ 0 '/~ 0 INIT CLASS WELL NAME PROGRAM: exp FI dev ,~ redrll J~ serv [] wellbore seg El ann. disposal para req [] ADMINISTRATION DATE ,., , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ....................... ~'~ Lease number appropriate ................... ~ Unique well name and number ................... t, ~ N Well located in a defined pool .................. .~- N Well located proper distance from drilling unit boundary .... i~) N Well located proper distance from other wells .......... (~) N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... N Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N REM,~RK, S ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Y N Surface casing protects all known USDWs ........... Y N CMT vol adequate to circulate on conductor & surf csg ..... Y N CMT vol adequate to tie-in long string to surf csg ........ Y... N CMT will cover all known productive horizons .......... (~ ~ N Casing designs adequate for C, T, B & permafrost ....... (, 'P N Adequate tankage or reserve pit ................. ~N _.~ Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequateBOPE press rating appropriate; ..... BOPEs, do they meet regulation .... test to ~'~~' ' ' Psigl Choke manifold complies w/APl RP-53 (May 84) ........ (_Y?.. N Work will occur without operation shutdown ........... ~ N Is presence of H2S gas probable ................. (,..Y,2 N GEOLOGY A~ DATE 30. Permit can be issued w/o hydroge~... Y N 31. Data presented on poten~essure zones ....... Y N 32. Seismic anal~L~allo_w_ g_a_szones ............. Y N 33. Seab ondition survey (if off-shore) ............. Y N 34."C'O'~act name/phone for we.ekly progress re~)o, rts ....... Y N lexploratory omyj B EV~.~__~'"z.~ D W J"~"'~ RPC ~.,)~ JDH ,,~d'~ RNC , co E.o'/zd 1 Comments/Instructions: HOW/Ijt- A:\FORMS\cheklist rev 09/97 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS WELL NAME /~.~_.~"~ /<:~-/'.~ GEOL AREA <~'~ ~ · PROGRAM: exp I-I dev/~ redrll/]~l',serv [] wellbore seg E: ann. disposal para req [] UNIT#"'/-- '//'~'?¢",~ ON/OFF SHORE 4:~"L~ -- ADMINISTRATION ,~R DATE / ENGINEERING APPR D~/,T _E/') GEOLOGY 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N REMARKS 14. Conductor string provided ................ Y N 15. Surface casing protects all I~n~n USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y NI 17. CMT vol adequate to tie-in long string to surf csg ........ Y 18. CMT will cover all known productive horizons .......... ~N/~j,.~ N" .~~ 19. Casing designs adequate for C, T, B & permafrost ....... _ 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diver[er required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~' N 25. BOPEs, do they meet regulation ...... .,'2...,('7¢7"~ .... (~ N 26. BOPE press rating appropriate; test to 2,,'~ ~'' - psigl N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... ~_,,~ 29. Is presence of H2S gas probable ................. 31. Data presented on potential overpressure zones ....... ,/~y NN,~ 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 lexploratory only] GEOLOGY: ENGINEERING: COMMISSION: BEW J~?'f,~,~'- DWJ~ JDH ~ RNC j~~ co I,,¢- Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 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. Sperry-Sun Drilling Services LIS Scan Utility Tue Apr 07 20:20:01 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK-MM- 80121 R. MCNEILL C DIXON 18-13A 500292175601 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 07-APR-98 MWD RUN 4 MWD RUN 4 AK-FIM-80121 AK-MM-80121 R. MCNEILL R. MCNEILL C DIXON C DIXON 19 liN 15E 1045 371 54.80 52.00 17.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 4.500 13103.0 PRODUCTION STRING 6.000 13103.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GIEGER MUELLER TUBES AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. A MEASURED AFTER DRILLING (MAD) PASS WAS PERFORMED AFTER MWD RUN 4. 5. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE CONVERSATION BETWEEN MIKE HARR AND ROB KALISH ON 02/23/98. THIS DATA IS PDC. 6. MWD RUNS 1, 2 (DIRECTIONAL ONLY), 3, AND 4 REPRESENT WELL 18-13A WITH API#: 50-029-21756-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13,102'MD, 8,771'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED DUAL GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD) $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SLrMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9732.0 13057.5 RPD 9739.0 13064.5 RPM 9739.0 13064.5 RPS 9739.0 13064.5 RPX 9739.0 13064.5 ROP 9776.0 13102.5 FET 9776.5 13064.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH .... BIT RUN NO MERGE TOP MERGE BASE 3 9776.0 11193.0 4 11193.0 13102.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 9732 13102.5 11417.2 6742 GR 12.8283 154.42 50.6457 6652 RPX 0.1751 2000 86.668 6652 RPS 0.3395 2000 101.06 6652 RPM 0.1464 2000 209.424 6652 RPD 0.4139 2000 265.177 6652 ROP 6.4432 8641.41 295.236 6654 FET 0.4286 24.9924 1.20408 6577 First Reading 9732 9732 9739 9739 9739 9739 9776 9776.5 Last Reading 13102.5 13057.5 13064.5 13064.5 13064.5 13064.5 13102.5 13064.5 First Reading For Entire File .......... 9732 Last Reading For Entire File ........... 13102.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPS RPX RAT $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: .500O all MAD runs merged using earliest Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 4 11209.0 13103.5 MERGED MAD PASS. $ START DEPTH STOP DEPTH 11209.0 13058.5 11216.0 13066.0 11216.0 13066.0 11216.0 13066.0 11216.0 13066.0 11216.0 13066.0 11235.0 13103.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD AAPI 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OH/~M 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 11209 13103.5 12156.2 3790 11209 RAT 49.6554 1626.82 272.86 3735 11235 GR 25.614 147.826 50.707 3700 11209 RPX 26.1469 2000 58.424 3701 11216 RPS 35.5948 155.99 69.4741 3701 11216 RPM 44.228 245.642 103.953 3701 11216 RPD 51.0918 232.895 116.456 3701 11216 FET 1.3653 46.4713 24.748 3701 11216 Last Reading 13103.5 13103.5 13058.5 13066 13066 13066 13066 13066 First Reading For Entire File .......... 11209 Last Reading For Entire File ........... 13103.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9732 0 RPD 9739 0 RPM 9739 0 RPS 9739 0 RPX 9739 0 ROP 9776 0 FET 9776 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11148 0 11155 0 11155 0 11155 0 11155 0 11155 0 11155 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 15-FEB-98 ISC 5.07 DEPII 2.17K / SP4 5.03 MEMORY 11193.0 9776.0 11193.0 67.6 84.6 TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 QUICKDRIL-N 8.60 65.0 8.5 19500 7.9 .200 .113 .180 .220 53.9 .0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHl~4 4 1 68 12 4 RPD MWD 3 OHMI~ 4 1 68 16 5 ROP MWD 3 FT/H 4 1 68 20 6 FET MWD 3 HOUR 4 1 68 24 7 RPM MWD 3 OHMM 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 9732 11155 10443.5 2847 9732 GR 12.8283 154.42 50.17 2833 9732 RPX 0.1751 2000 79.821 2833 9739 RPS 0.3395 2000 113.197 2833 9739 RPD 0.4139 2000 441.774 2833 9739 ROP 6.4432 2000 430.818 2759 9776 FET 0.4657 2.5007 1.17901 2758 9776.5 RPM 0.1464 2000 327.946 2833 9739 Last Reading 11155 11148 11155 11155 11155 11155 11155 11155 First Reading For Entire File .......... 9732 Last Reading For Entire File ........... 11155 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11111.0 13057.5 FET 11118.0 13064.5 RPD 11118.0 13064.5 RPM 11118.0 13064.5 RPS 11118.0 13064.5 RPX 11118.0 13064.5 ROP 11156.5 13102.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-FEB-98 ISC 5.07 DEPII 2.17K / SP4 5.03 MEMORY 13102.0 11193.0 13102.0 84.8 93.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0882SP4 P0882SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: QUIC~RIL-N 8.70 52.0 8.8 17600 6.2 .280 .151 .270 .340 62.8 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): .0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 4 AAPI 4 1 68 RPX MWD 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPD MWD 4 OHMM 4 1 68 ROP MWD 4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 RPM MWD 4 OHMM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 11111 13102.5 12106.8 3984 GR 31.5726 130.602 51.0054 3894 RPX 28.9141 263.716 90.9387 3894 RPS 39.2018 203.172 91.4432 3894 RPD 65.5722 267.033 133.568 3894 ROP 12.8104 8641.41 198.808 3893 FET 0.4286 24.9924 1.65362 3894 RPM 51.0328 285.964 120.821 3894 First 'Reading 11111 11111 11118 11118 11118 11156.5 11118 11118 Last Reading 13102.5 13057.5 13064.5 13064.5 13064.5 13102.5 13064.5 13064.5 First Reading For Entire File .......... 11111 Last Reading For Entire File ........... 13102.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: FILE S UMPLARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11209 . 0 13058 . 5 FET 11216 . 0 13066 . 0 RPD 11216 . 0 13066 . 0 RPM 11216 . 0 13066 . 0 RPS 11216 . 0 13066 . 0 RPX 11216 . 0 13066 . 0 RAT 11235.0 13103 . 5 $ LOG HEADER DATA DATE LOGGED: 17-FEB- 98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: DEPII 2.17K / SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 13102.0 TOP LOG INTERVAL (FT) : 11193.0 BOTTOM LOG INTERVAL (FT): 13102.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 93.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P 0882 S P 4 EWR4 ELECTROMAG. RESIS. 4 P0882SP4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.000 DRILLER'S CASING DEPTH (FT): 6.0 BOREHOLE CONDITIONS MUD TYPE: QUICKDRIL-N MUD DENSITY (LB/G) : 8.70 MUD VISCOSITY (S): 52.0 MUD PH: 8.8 MUD CHLORIDES (PPM) : 17600 FLUID LOSS (C3) : 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .280 MUD AT MAX CIRCULATING TERMPERATURE: .151 62.8 MUD FILTRATE AT MT: .270 MUD CAKE AT MT: .340 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units DEPT FT 4 1 68 RAT MAD 4 FT/H 4 1 68 GR MAD 4 AAPI 4 1 68 RPX MAD 4 OHFiM 4 1 68 RPS MAD 4 OHMM 4 1 68 RPM MAD 4 OHMM 4 1 68 RPD MAD 4 OPIMM 4 1 68 FET MAD 4 OHl~4 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 11209 13103.5 12156.2 3790 RAT 49.6554 1626.82 272.86 3735 GR 25.614 147.826 50.707 3700 RPX 26.1469 2000 58.424 3701 RPS 35.5948 155.99 69.4741 3701 RPM 44.228 245.642 103.953 3701 RPD 51.0918 232.895 116.456 3701 FET 1.3653 46.4713 24.748 3701 First Reading 11209 11235 11209 11216 11216 11216 11216 11216 Last Reading 13103.5 13103.5 13058.5 13066 13066 13066 13066 13066 First Reading For Entire File .......... 11209 Last Reading For Entire File ........... 13103.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 aI~ $I~ ~0 ~0~ I?oTsXMd 5uTqTx~ SIq S~S ................. squau~uoo NMONZNI1 ........... aur~x iaaH qxax IO ...... ~aqum~ uo~nu~uoo .N.~O~ ................ a~N Iaa~ S~S ................... UT~T~O L0/~0/86 ..................... a~eG 2~&SI~ ............. eureu asthmaS ~uT~T~ SIq S&S ................. s~uau~uoo NMONMNfl ........... e~N ad~ ~xeN T0 ...... ~equznN uoT~nuT~uoo N~ON3{N/] ................ sUreN sd~A S~S ................... uTDT~O £0/~0/86 ..................... s~G ~ASI~ ............. aureu ~OTA~aS ~0~ I~oTsXqd