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Home My WebLink About195-091David Douglas Hilcorp North Slope, 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: Hilcorp North Slope, LLC Date: 10/18/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Directional Survey Report (PDF) and Data File (XLSX) For each of the well bores listed in the table below: Well Name PTD # API # PBU 05-16 177-143 50029202620000 PBU 05-16A 194-129 50029202620100 PBU 05-16B 199-100 50029202620200 PBU 05-16C 213-056 50029202620400 PBU 18-30 195-091 50029225680000 PBU 18-30A 209-087 50029225680100 PBU 18-30APB1 209-087 50029225687000 SFTP Transfer - Data Folders: Please include current contact information if different from above. T38085 T38086 T38087 T38088 T38089 T38090 T38091 10/20/2023 PBU 18-30 195-091 50029225680000 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 16:29:04 -08'00' • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Ft~C~lVED I~E~3 0 ~ ~.~10 WELL COMPLETION OR RECOMPLETION REPORT G 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended 2oaaczs.~os 2oAACZS.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1 ®Developr~~lAl~xploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 01/12/2010 12. Permit to Drill Number: 195-091 309-283 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 7/1/1995 13. API Number: , 50-029-22568-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 07/20/1995 14. Well Name and Number: PBU 18-30 FEL, SEC. 24, T11 N, R14E, UM 3574 FSL, 26 Top of Productive Horizon: 769' FSL, 1176' FEL, SEC. 19, T11 N R15E, UM g. KB (ft above MSL): 53.45' GL (ft above MSL): 16' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4507' FSL, 4423' FEL, SEC. 29, T11 N, R15, UM 9. Plug Back Depth (MD+ND): 11430' 8776' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 691754 y_ 5960161 Zone- ASP4 10. Total Depth (MD+TVD): 12621 8731 16. Property Designation: ADL 028307, 028321, 028326 TPI: x- 695642 y- 5957457 Zone- ASP4 Total Depth: x- 697720 Y- 5955969 Zone- ASP4 11. SSSV Depth (MD+ND): N/A 17. Land Use Permit: ND f P f t k 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL erma ros ( ): ness o 20. Thic 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, NEU, CDL, CNL, Acoustic 22. Re-Drill/Lateral Top Window MD(fVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT. CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 0" 91.5# H-40 urf 110' urf 11 30" -260 sx Ar is Set - /4" - 111 F ' ' 7-5/8" 29.7# 8 7' S' 82 -7/ " 35 x Cla ' -1/2" 17# L-8 7 12 21' 171' 731' 6- /4" 24 sx I ' 24. Open to production or injection? ^ Yes ®No 25. TuewG RECORD If Yes, IISt each Interval Open n Size and Number): m P rf r ti MD+ND f T & B tt SIZE DEPTH SET MD PACKER SET MD / ND ; ( o op o o e o a o 4-1/2", 12.6#, 13Cr80 / L-80 9650' 9450' / 7967' MD TVD MD ND &9604' / 8090' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. e ~~ .~ rr,, ; DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED r , rC' ~_. ~ U .,_ .~ r,~.~,;,; ~ ~_'~ ~- 11430' Set Whipstock ~:~°~f 27. 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): 28. CORE DATA Conventi onal Core(s) Acqui red? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+ND 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 250.071. None RBDIVIS FEB 0 51010 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only 5•/U z~~a 29. GEOLbGIC MARKERS (List all formati ons and ma encountered): 30. RMATION 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. Sag River 9756' 8213' None Shublik 9814' 8260' Top of Sadlerochit 9885' 8316' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. O ~~~/ /-~ J / l l ~ . Title: Drilling Technologist Date: Signed: Terrie Hubble PBU 18-30 195-091 309-283 Prepan:d By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Ron Phillips, 564-5913 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 1 a: 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. Item 13: The API number reported to AOGCC must tie 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only CJ CJ 18-30, Well History (Pre Rig Sidetrack) Date Summary 8/1/2009 T/IA/OA= SSV/0/0 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP BT onto THA test void, 200 psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment, cycled LDS out 1.0" ran in torqued "ET style" all were in good working condition. PPPOT-IC RU 2 HP BT onto IC test void, 50 psi to 0 psi, flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment, cycled LDS out 1.0" ran in torqued "ET style" all were in good working condition. 8/4/2009 Rig up. RIH w/ 3.63" JDC. Unable to work past Unique Overshot C«? 9554' CTM. Sat down at 9559'. Attempt to work through. POH. Unable to operate swab. Valve crew on location to repair. 8/5/2009 Valve crew unable to repair Swab valve on location. ND BOPs and rig down P-Sub. Replace swab valve. MU and RIH with JDC Hydraulic Overshot w/ 1.75" grapple to fish IBP. Work past obstructions at 9556' & 9695'. Latched & pulled IBP from 10,756'. POOH. IBP missing 1 stiffener ring and 2 seals. 8/6/2009 M/U tool string w/3.5" OD Wire Catch to fish out IBP elements & RIH to 11,400'.,POOH. Recovered 1 stiffener ring and 2 rubber seals. All IBP components recovered. MU and RIH with 3.0" left hand motor and 3.79" OD HCC parabolic mill. Mill out XN nipple from 9622' to 9624' ctmd. Make multiple passes through profile after milling. No restrictions observed. Pump Geovis sweep and RIH to 11430' to drift with mill. Pump final Geovis sweep and POOH at 80%. MU and RIH with dummy whipstock drift and IGS Data coil tools. RIH to 14,430'. No restrictions observed. POOH freeze protecting well from 2500'. 8/7/2009 Finished POOH. Est inj rate of .7 bpm C~3 500 psi. Freeze protected well to 2,500'. LD drift tool assy. RDMO. Job complete. 8/16/2009 SVC TREE Pressure test tree Master / W ng / Ssv /Swab 5000 psi (pass) 8/30/2009 WELL S/I ON ARRIVAL. DRIFT W/3.84" NO-GO CENT TO X-NIP C~3 2,017' MD, (NO RESTRICTIONS). DRIFT W/3.88" CENT TO X-NIP C~ 2,017' MD / 2,000' SLM. (NO RESTRICTIONS). WELL LEFT S/I, DSO NOTIFIED. Nordic #2 Attempted to RU for Sidetracking Operations. The pad was too soft and eventually it was decided to move off location and wait until pad was more solid. (p9i03i09 - 09/07109) 10/12/2009 T/I/O = ?/290NAC. Temp = SI. Bleed IA & OA to 0 psi (pre CTD). Unable to get TP due to no scaffold on well. IA FL C~ 80'. Bled IAP from 290 psi to 0 psi in 1 hr. SI, Monitor for 30 min. IAP increased to 5 psi. Final WHPs ?/SNAG. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 10/13/2009 T/I/0=0/500/0 Set 4 1/16 CIW H TWC # 278 thru tree for tree pressure test.. Torqued tubing head adapter to tree flange to API specs, all nuts were to spec. Pressure tested tree to 5k passed. Pulled 4 1/16 CIW H TWC #278 thru tree. No problems. 12/10/2009 T/I/0=0/200/0 temp=S1 MIT IA Passed to 3000 psi/ MIT OA PASSED to 2000 psi (CTD Prep) MIT IA pressured up to 3000 psi with 6.7 bbls crude. IA lost 100 psi in first 15 minutes and 20 psi in second 15 minutes, for a total of 120 psi in 30 minutes. Bled back --5.5 bbls. MIT OA pressured up to 2000 psi with 3.2 bbls crude. OA lost 120 psi in first 15 minutes and 40 psi in second 15 minutes, for a total of 160 psi in 30 minutes. Bled back --2.5 bbls. FWHP's = 0/500/0. SV, WV -closed, SSV MV IA OA -open. 1/4/2010 T/I/0=vac/350/0 Temp=S/I Load TBG [CTD Prep] Pumped 5 bbl 60/40 meth spear, followed by 207 bbls 1 % KCL & 40 bbl crude FP. DSO & PE notified upon departure. FWP=0/100/0 SV = S/I, SSV & MV =Open, IA & OA = OTG. 1/5/2010 T/I/O =BPV/25Nac. Temp = SI. Bleed WHP's to 0 psi (pre CTD). No AL, flowline or wellhouse. IA FL near surface. Bled IAP to 0 psi in 10 min (gas). Monitored for 30 min. IAP increased to 0+ psi. FW HP's BPV/O+Nac. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. Page 1 of 1 • BP EXPLORATION Operations Summary Report Page 1 oi~9 Legal Well Name: 18-30 Common Well Name: 18-30 Spud Date: 6/22/1995 Event Name: REENTER+COMPLETE Start: 9/7/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/3/2009 00:00 - 01:00 1.00 MOB N WAIT PRE 01:00 - 01:45 0.75 MOB P PRE 01:45 - 03:00 1.25 MOB N RREP PRE 03:00 - 03:15 0.25 MOB P PRE 03:15 - 05:00 1.75 MOB P PRE 05:00 - 06:15 1.25 MOB P PRE 06:15 - 06:45 0.50 MOB P PRE 06:45 - 09:00 2.25 MOB P PRE 09:00 - 10:30 1.50 MOB P PRE 10:30 - 13:00 2.50 MOB P PRE 13:00 - 16:00 3.00 MOB P PRE 16:00 - 17:00 1.00 MOB P PRE 17:00 - 18:00 1.00 MOB P PRE 18:00 - 18:30 0.50 MOB P PRE 18:30 - 19:30 1.00 MOB P PRE 19:30 - 20:00 0.50 MOB P PRE 20:00 - 23:00 3.00 MOB N MISC PRE 23:00 - 00:00 1.00 MOB P PRE 9/4/2009 00:00 - 04:50 4.83 MOB P PRE 04:50 - 13:00 I 8.17 ~ BOPSUFj P ~ ~ PRE 13:00 - 15:15 2.251 BOPSUFj P PRE 15:15 - 16:45 1.50 RIGU P PRE 16:45 - 18:00 1.25 BOPSU P PRE 18:00 - 18:30 0.50 CONS P PRE 18:30 - 20:20 1.83 CONS P PRE Wait for security, they are currently moving the Klondike & 4ES. Coduct PJSM regarding moving the rig. Move rig from B-pad towards Spine rd. With the rig on the B pad access road & 150yrds from Spine road, lost power to move system. Wait for electrician. Establish power to move system. Move rig, again. Turn rig onto & travel down the Spine road. Turn rig onto & travel down the Oxbow road. Crew change at DS 7. Make rounds Continue move to DS 18. Stand by whille LRS completes loading well for MIRU. Stand by while DSM installs BPV in tree. MU tree adapter to btm of BOP stack. Pick up and secure reel in rig. Install hard line and coil grapple. Regrade location after work around well head. 120 yards of new gravel recently spotted in front of and around well. Spot full rig mats due to soft location and herculite. C/O w/day crew. PJSM regarding setting rig mats. Spot full rig mats due to soft location and herculite. PJSM regarding moving rig onto rig mats & over the well. Pad gave way resulting in tires sinking into the ground. Stop & conduct PJSM regarding getting rig unstuck. Crib up under tires using dunnage & composite rig mats. Back out of hole & place more rig mats down. Move rig onto rig mats & move over well. Continue to move over well. Set rig down. ND tree cap. NU BOP's. NU choke line. RU Handi berm. Accept rig at 01:30. Spot cuttings box. Spot cuttings box & attached a 2" 90 1502 connection for the cement returns. RU Handi berm. Spot office trailer. SWS working on P-14, again. MU packoffs to the injector. RU IA & OA gauges & crash frames. Spot support equipment. Fill stack w/ water. Shell test 250/3500 -pass. Begin testing BOPE per AOGCC regs, permit to drill, ADW DWOPS, and well plan to 250psU3500psi -PASS. Bob Noble waived witness to test. No failures. Record all data. E-mail completed AOGCC test form to Anchorage AOGCC office. SIMOPS: remove a-free reel and replace with a-coil reel. PJSM to pull BPV. Bring tools and lubricator up to floor. MU lubricator. Test same to 500 psi. Engage and pull BPV. WHP: 25 psi. Rig up to pull coil across. MU packoff assembly. MU lubricator below injector. Pressure test wing valves and flow back choke manifold to 250 and 3500 psi. C/O w/day crew. Perform walk arounds & spill champion. PJSM regarding daily activities. Fill coil w/ 2% KCL w/ safelube - 51 bbls. Pump out slack into rnnw¢ vcaic~iv ic.v°.u°nv, • • BP EXPLORATION Page 2 0#~ Operations Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Spud Date: 6/22/1995 Event Name: REENTER+COMPLETE Start: 9/7/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/4/2009 18:30 - 20:20 1.83 CONS P PRE bung hole, 315ft recovered. 20:20 - 20:30 0.17 CONS P PRE PJSM regarding the next activities, cutting -15ft of bad coil, securing wire, P.T. packoffs & inner reel. 20:30 - 21:15 0.75 CONS P PRE Cut off coil. Secure wire. Stab onto well. Fill out LOTO & enter reel to close the inner reel valve. 21:15 - 22:05 0.83 BOPSU P PRE Pressure test inner reel valve & pack offs per AOGCC regs 250psi/3500psi -PASS. 22:05 - 23:50 1.75 DRILL P PROD1 Pop off well. Install night cap. Open well, 30psi WHP. Bull head kill at 6bpm/1900psi, 360bb1s pumped. Bleed down IA from 330psi to tiger tank. Prep/dress end of coil for BOT CTC. 23:50 - 00:00 0.17 DRILL P PROD1 PJSM regarding MU No-Go BHA. 9/5/2009 00:00 - 01:00 1.00 RIGU P PRE Circ across the top to keep the hole full. Hoist BOT BHA to RF. MU BOT CTC, pull test to 35k & pressure test to 3500psi. MU No-Go BHA. 01:00 - 01:40 0.67 RIGU P PRE RIH w/ no-go BHA. PUW = 13k at 1900ft. Tag X nipple at 2035ft. PU & set down 5k, 8k & 12k. Clean PU. 01:40 - 02:05 0.42 RIGU P PRE POH pumping across the top. 02:05 - 02:20 0.25 RIGU P PRE PJSM regarding handling BHA. 02:20 - 05:40 3.33 RIGU P PRE LD No-Go BHA. MU safety jt. RU 2-7/8" elevators. RU Farr tongs. Loss rate - 20bbls/hr. MU SELRT test BHA using constant hole fill. LD 4 bad joints & PU 4 new joints. PU safety jt & stab onto liner. RU head pin & circulate 10bbls through '~ liner for verification. 05:40 - 08:30 2.83 RIGU P PRE MU SELRT tool to liner. PU 6 jts 2-3/8" PH6 DP. Stab coil. Get on well. 08:30 - 09:00 0.50 RIGU P PRE Run in hole. Circ at min rate. Hole taking 20-30 bph to fill. 09:00 - 12:00 3.00 RIGU P PRE Tag nipple at 3038'. Pressure coil to shear release liner. Unable to tell if released or not by up / do weight. Determine we are released from liner. PU to release dogs. Pressure coil and observe 400 psi. Hold this for 30 seconds to verify pee wee plug is on seat. PU to pressure bleed off. Circ 7 bbls to simulate side exhaust. Open Baker choke. Set back down to 2k# down wt. Close choke. Pressure coil to 3100 psi. Plug sheared. Pump Inner vol: 350 psi at 0.88 bpm. Plug landed at 12.1 bbls on landing collar. Hold pressure to verify floats holding. Unsting by picking up. Open choke and set back 2k# do wt. Close choke. Pressure coil to 1600 psi. Stage collar sheared. Circulate out of hole. 12:00 - 12:45 0.75 RIGU P PRE At surface. Get off well. LD PH6. LD SELRT tool. 12:45 - 13:45 1.00 RIGU P PRE MU GS spear on PH6 and tools. Stab coil and get on well. 13:45 - 14:45 1.00 RIGU P PRE Run in hole. Engage liner. 14:45 - 15:00 0.25 RIGU P PRE Pull out of hole. Circulate across the top to keep hole full. 15:00 - 18:00 3.00 RIGU P PRE Hold PJSM. Get off well. rnntea: ii~oizuiu iz:~o:~o rm • • BP EXPLORATION Page 3 . Operations Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code NPT Spud Date: 6/22/1995 Start: 9/7/2009 End: Rig Release: Rig Number: N1 Phase Description of Operations 9/5/2009 ~ 15:00 - 18:00 ~ 3.00 ~ RIGU ~ P PRE I LD BTT tools and PH6 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 20:00 1.50 RIGU N RREP PRE 20:00 - 23:00 3.00 RIGU N RREP PRE 23:00 - 00:00 1.00 RIGU N RREP PRE 9/6/2009 00:00 - 01:00 1.00 RIGU N RREP PRE 01:00 - 01:15 0.25 RIGU N RREP PRE 01:15 - 01:30 0.25 RIGU N RREP PRE 01:30 - 04:30 3.00 RIGU N RREP PRE 04:30 - 06:15 1.75 RIGU N RREP PRE 06:15 - 06:30 0.25 RIGU N RREP PRE 06:30 - 07:30 1.00 RIGU N RREP PRE 07:30 - 10:15 2.75 RIGU N RREP PRE 10:15 - 12:00 1.75 BOPSU~ N RREP PRE 12:00 - 12:30 0.50 BOPSU N RREP PRE 12:30 - 18:00 5.501 BOPSUFi N ~ RREP ~ PRE 18:00 - 19:30 ~ 1.50 ~ RIGD ~ N ~ RREP ~ PRE 19:30 - 20:30 1.00 BOPSU N RREP POST 20:30 - 21:00 0.50 BOPSU N RREP POST 21:00 - 21:45 0.75 RIGD N RREP POST 21:45 - 22:20 0.58 RIGD N RREP POST 22:20 - 00:00 1.67 RIGD N RREP POST ~ 9/7/2009 ~ 00:00 - 01:20 ~ 1.33 ~ RIGD ~ N ~ RREP ~ POST C/O w/ day crew. Perform spill champion & walk arounds. PJSM regarding, setting BPV, ND BOP's, cleaning & securing RF, RD cement flow back lines & choke, prepping to move rig. Blow down surface lines & BOP stack. T-bar in BPV, close tree & casing valves. Off load 110bb1s of rig water. Suck down pits. RD cement flow back lines from cellar & cuttings box. RD IA/OA gauges. Pull & LD 7" lubricator. Move dumpsters. Move liner. Move office camp. Nn B~PF. ND ~hnke line. Secure BOP stack w/ chain. FiU tree cap. RU test line. Test tree cap 250psi/3500psi. Continue to secure BOP stack. Continue to clean up misc equipment for moving off well. Suck down cuttings box. Move cuttings box. Skid cement choke out of way. Lay down rig mats in front of rig. PJSM regarding moving off well. Move rig straight off well & park onto rig mats. Move rig mats out of way from front side of well. Build up pad w/gravel & level pad. Clean rig while dirt work is going on. Spot double rig mats in front of well. Crew change. Make rig rounds. Discuss progress and plan. Continue to spot mats and wood sills as required. PJSM. Spot hands. Move rig over well. Center same. Install foot beam shims. Rig not completely leveled, but better. Will continue to monitor. Hold PJSM. Audited by TP and WSL. NU BOPS in cellar. Change over day crew change. Make rounds . Discuss operations. Continue to NU BOPs. Continue to spot equipment around rig. RU hard line, flow back choke, cuttings box. C/O with day crew. Perform walk arounds. Asses & discuss the sinking pad issues with the rig team management. Rig has settled _ 4" from this morning & continues to sink further & has been deemed as inappropriate working conditions. Determine next course of action & discuss with rig crew. Make appropriate notifications. Due to lack of rig mats for pending rig move, lack of pump trucks & temperature of water used to kill the well, it has been determined that the rig will need to FP the well. Continue to NU BOP's. RU tiger tank line. Shell test BOP stack, 250psi/3500psi. Conduct mini safety stand down w/crew. Discuss ADW expectations w/crews & conduct O&A session. Remove 3 RA PiP tags from whipstock. Wait for diesel for freeze protecting well & corrosion inhibitor for blowing down reel. Hook up diesel transport & vent same. Open master & swab. Install fuseable (problems opening SSV). Pump 45bbls of diesel at 3bpm, 20bbls to catch fluid. Final injection rate of 3bpm/1000psi. Stop pumping & close master, swab, remove rnniev: vzoizviv icvo:vorm C~ BP EXPLORATION Page 4 ~. Operations Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Spud Date: 6/22/1995 Event Name: REENTER+COMPLETE Start: 9/7/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From -To Hours Task Code NPT Phase Description of Operations 9/7/2009 00:00 - 01:20 1.33 RIGD N RREP POST fuseable cap & close SSV. RD SSV hose. 01:20 - 01:40 0.33 RIGD N RREP POST PJSM regarding pumping water+corrosion inhibitor cocktail followed by nitrogen. 01:40 - 03:40 2.00 RIGD N RREP POST Pull night cap. Pull bushings & install china cap, install bushings. PU injector. MU nozzle. Stab onto well. Pump 40bbls of fresh water followed by 15bbls of corrosion inhibitor cocktail followed by nitrogen. Take all returns to tiger tank. Let coil bleed off. PJSM while coil is bleeding off, regarding pulling coil across. 03:40 - 06:00 2.33 RIGD N RREP POST Pop off well. RD pull back winch. RU stabbing winch. Cut off BOT CTC. Dress end of coil. Cut off excess a-line & prep wire. Install grapple CTC. Pull coil across & secure w/ shipping bar. Lower down reel to trailer. Pull bushing. Pull 7" lubricator. Install bushings. RD elevators. MU BOP lifting slings. 06:00 - 06:30 0.50 BOPSU N RREP POST Crew change. Handover and make rig checks and spill champ rounds. ~dt7~ d 06:30 - 12:30 6.00 BOPSU N RREP POST Hold PJSM. Review procedure. n p . Remove and store SLB lubricator. / ND BOPS and other cellar equipment. ~~;Q RD wing valve flow back loop and choke skid. S o NU and test tree cap. 12:30 - 16:00 3.50 RIGD N RREP POST Grade pad. Spot rig mats. Continue to move and load out misc support equipment. Prep location to pull off well. 16:00 - 16:30 0.50 RIGD N RREP POST Pull off well & park down the pad on rig mats. Rig released at 16:30. SPIN DRIVE WHEELS AND WARM UP DRIVE SYSTEM. 19:30 - 20:00 0.50 MOB P PRE SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR MOVING THE RIG OFF THE WELL AND TO THE FRONT OF DRILLSITE 01. 20:00 - 21:00 1.00 MOB P PRE JACK RIG UP AND PULL OFF WELL. REAR TIRES ARE DRAGGING DUE TO COLD STIFF GREASE. 21:00 - 21:30 0.50 MOB P PRE PARK RIG IN CENTER OF DRILLSITE. SET DOWN AND WARM UP DRIVE SYSTEM. WARM UP REAL AXLES. 21:30 - 00:00 2.50 MOB N WAIT PRE WAIT TO HAVE PAD SANDED TO GIVE DRIVE WHEELS THE TRACTION TO PULL THE REAR WEALS. SANDED FRONT OF DRILLSITE AND ACCESS ROAD TO BACK OF DRILLSITE. 1/9/2010 00:00 - 01:00 1.00 MOB N WAIT PRE WAIT WHILE SANDING ACCESS ROAD AND FRONT OF DRILLSITE 01. 01:00 - 02:00 1.00 MOB P PRE MOVE RIG TO FRONT SIDE OF DRILLSITE 1. 02:00 - 02:15 0.25 MOB P PRE SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR MOVING THE RIG TO DRILLSITE 18. DISCUSS VERY COLD WEATHER OPERATIONS. -37F. 02:15 - 06:00 3.75 MOB P PRE MOVE RIG TO DRILLSITE 18. PARK RIG INFRONT OF 06:00 - 06:15 0.25 MOB P PRE SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR BACKING THE RIG OVER THE WELL. 06:15 - 07:00 0.75 MOB P PRE BACK RIG OVER THE WELL AND SET DOWN RIG. ACCEPT RIG ON DS 01-30A AT 0700 HRS, 01/09/2010 07:00 - 10:00 3.00 RIGU P PRE RIG UP CUTTINGS TANK, TIGER TANK AND HARDLINE. r. PnMetl: 1PL52U70 7L:Uti:Uti PM BP EXPLORATION Page 5'~t~ Operations Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Spud Date: 6/22/1995 Event Name: REENTER+COMPLETE Start: 9/7/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From- To Hours Task Code NPT Phase Description of Operations 1/9/2010 07:00 - 10:00 3.00 RIGU P PRE MOVE IN RIG SAT CAMP AND RIG IT UP. VERY COLD. -37F. -56 WIND CHILL. 10:00 - 13:00 3.00 RIGU P PRE EAT STACK WITH STEAM. 13:00 - 16:00 3.00 BOPSU~ P PRE 16:00 - 00:00 8.00 BOPSU N RREP PRE 1/10/2010 00:00 - 21:00 21.00 BOPSU N RREP PRE 21:00 - 23:00 2.00 BOPSU N RREP PRE 23:00 - 00:00 1.00 BOPSU P PRE 1/11/2010 00:00 - 07:00 7.00 BOPSU P PRE 07:00 - 07:15 0.25 RIGU P PRE 07:15 - 10:00 2.75 RIGU P PRE 10:00 - 11:30 1.50 WHIP P WEXIT 11:30 - 14:00 2.50 WHIP P WEXIT 14:00 - 17:30 3.50 WHIP P WEXIT 17:30 - 19:00 1.50 WHIP P WEXIT 19:00 - 20:15 1.25 WHIP P WEXIT 20:15 - 22:15 2.00 WHIP P WEXIT 22:15 - 22:30 0.25 WHIP N SFAL WEXIT 22:30 - 23:40 1.17 WHIP N SFAL WEXIT 23:40 - 00:00 0.33 WHIP N SFAL WEXIT 1/12/2010 00:00 - 01:30 1.50 WHIP N SFAL WEXIT 01:30 - 04:10 2.671 WHIP ~ N ~ SFAL ~ WEXIT HEAT CHOKE MANIFOLD AND LINES. THAW TEST PUMP LINE. FILL RIG PITS WITH 290 BBL 2% KCL WATER. PRESSURE /FUNCTION TEST BOPE AND ALARMS. TESTS WITNESSED BY AOGCC INSPECTOR, MR. NOBLE. STOP BOP TEST. CHOKE MANIFOLD FREEZING. NOT ABLE TO-KEEP RIG FLOOR AREA WARM ENOUGH TO TEST BOPE. DICK'S HEATER IS NOT WORKING, WAIT FOR REPAIR PARTS. RE-GREASE CHOKE, HCR VALVES & SWAB VALVES. CONTINUE WITH REPAIRS ON DICK'S AIR HEATER. REPAIRS COMPLETE. BUTTON UP DICKS HEATER. S/D & RE-FIRE HEATER - OK. RU BOPE TEST HOSE. TF$T BOPE PER AOGCC BEGS 250PSI/3500PSI. BOB NOBLE WAIVED WITNESS TO TEST. CONTINUE TO TEST BOPE PER AOGCC BEGS, 250PSI / 3500PSI -PASS. SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION TO PULL BPV. RIG UP LUBRICATOR, PRESS TEST, PULL BPV. WELL ON A VAC. RD LUBRICATOR. FILL COIL WITH KCL WATER. PRESS TEST INNER REEL VALVE AND PACKOFF. CUT OFF CTC AND REVERSE CIRC SLACK MANAGEMENT AT MAX RATE of 4.5 BPM, 3 TIMES. CUT OFF 150' OF COIL. TEST E-LINE. M/U CTC. PULL AND PRESS TEST. M/U BHI UOC. TEST E-LINE, OK. BULLHEAD KILL WELL WITH KCL WATER TO GET CRUDE _OUT OF TUBING~_ 4.0 BPM, 3170 PUMP PRESS. 1250 SIWHP. PUMP 320 BBLS. PJSM DURING KILL OPERATION REGARDING MU WS & COIL TRACK TOOLS. FLOW CHECK -VAC. POP OFF WELL. MU WS & COIL TRACK TOOLS PER PROGRAM. STAB ONTO WELL. POWER UP & TEST TOOLS. SET COUNTERS. RIH WITH BHA #1. PUMP THROUGH EDC, CIRC 0.75BPM WHILE RIH. STOP AT 6704', CAN'T COMMUNICATE WITH TOOLS. ELIMINATE SURFACE POSSIBILITIES. POH. PJSM WHILE POH REGARDING TROUBLE SHOOTING E-LINE. TAG UP. FLOW CHECK - NO FLOW. POP OFF. LD COIL TRACK TOOLS. CONTINUE TO LD TOOLS & WS/SETTING TOOLS. REMOVE UOC. E-LINE PULLED OUT OF THE ANCHOR. TEST WIRE - OK. CUT OFF CTC. CAP END OF E-LINE. STAB ONTO WELL. CONDUCT E-LINE SLACK MANAGEMENT. HEAR rented: vzoizutu tz:uti:ue rnn • BP EXPLORATION Page 6 Operations' Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Spud Date: 6/22/1995 Event Name: REENTER+COMPLETE Start: 9/7/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 1/12/2010 01:30 - 04:10 2.67 WHIP N SFAL WEXIT MOVEMENT. FILL HOLE. POP OFF WELL. RU COIL CUTTER. CUT 330' OF COIL TO FIND WIRE. RD COIL CUTTER. RU TREE CAP &CIRC ACROSS THE TOP TO KEEP HOLE FULL _ 0.456PM LOSS RATE. MU CTC. PULL TEST TO 35K. PRESSURE TEST TO 4000PSI. REREAD BHI UOC. PRESSURE TEST TO 4000 PSI. 04:10 - 04:20 0.17 WHIP N SFAL WEXIT PJSM REGARDING MU WS BHA. 04:20 - 05:00 0.67 WHIP N SFAL WEXIT PLACE INJECTOR OVER BUNG HOLE &CIRC FORWARD. MU WS & COIL TRACK TOOLS. STAB ONTO WELL. POWER UP & TEST TOOLS. SET COUNTERS. 05:00 - 06:15 1.25 WHIP N SFAL WEXIT RIH WITH WS BHA #2, DIMS BHA #3 TO 6000'. 06:15 - 07:00 0.75 WHIP P WEXIT CONTINUE TO RIH 9900'. 07:00 - 07:20 0.33 WHIP P WEXIT LOG GR TIE-IN AT 9900'. ADDED 1 FT CTD. 07:20 - 08:10 0.83 WHIP P WEXIT RIH, POSITION TOP OF WHIPSTOCK AT 11,430' WITH_185 ROHS TF FOR LOWSIDE WINDOW EXIT. CLOSE EDC. PRESS UP AND SET WHIPSTOCK WITH 3700 PSI SHEAR PRESS. PI(~K UP LEAN OFF OF WHIPSTOCK. , CIRC 2.7 BPM. 1450 PSI, 2.3 BPM RETURNS WITH KCL WATER. 0.4 BPM LOSSES WITH SLICK KCL WATER. 08:10 - 10:15 2.08 WHIP P WEXIT POH WHILE CIRC 2.7 BPM. 10:15 - 10:30 0.25 WHIP P WEXIT SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR SWAPPING BHA 10:30 - 11:30 1.00 WHIP P WEXIT L/O COILTRAK AND BAKER RUNNING TOOLS. M/U 3.80" WINDOW MILLING BHA WITH 3.80" HCC DIAMOND MILL, STRING REAMER, STRAIGHT MOTOR, CENTRALIZER, 2 JTS PH6 AND COILTRAK. BHA OAL = 121.70' 11:30 - 13:20 1.83 STWHIP P WEXIT RIH WITH WINDOW MILLING A #4• CIRC 0.3 BPM, 100 PSI. 13:20 - 14:40 1.33 STWHIP P WEXIT LOG TIE IN PASS. + 6' CORRECTION 14:40 - 16:00 1.33 STWHIP P WEXIT CIRCULATE SYSTEM TO NEW GEOVIS ~ 3.3 BPM WITH .4 TO .5 BPM LOSSES. LOSSES SLOWING TO .3 BPM WITH 80 BBLS OF GEOVIS ON BACKSIDE OF COIL. 16:00 - 18:00 2.00 STWHIP P WEXIT ESTABLISH FREE SPIN OF 2615 PSI AT 2.56 BPM IN AND 2.33 BPM OUT. RIH AND FIND PINCH POINT. PAINT COIL FLAG(WHITE) C~ 11431.4 18:00 - 00:00 6.00 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW, 1 FT/HR. 2.53 / 2.36 BPM ~ 2600-2650 PSI. PVT = 302 BBLS. 18:00 - 11433.31 FT 1.27K DWOB. 19:00 - 11434.30 FT 2.37K DWOB. 20:00 - 11435.20 FT 3.37K DWOB. PVT = 297 BBLS 21:00 - 11436.32 FT 3.73K DWOB 22:00 - 11437.10 FT 2.19K DWOB 23:00 - 11438.11 FT 2.57K DWOB PVT = 289 BBLS 00:00 - 11438.90 FT 2.81 K DWOB 1/13/2010 00:00 - 03:30 3.50 STWHIP P WEXIT CONTINUE MILLING WINDOW. 00:00 - 11438.90 FT 3.17K DWOB PVT = 286 BBLS 01:00 - 11439.90 FT 2.85K DWOB 02:00 - 11441.01 FT 1.95K DWOB 03:00 - 11442.10 FT 1.46K DWOB 03:30 - 04:20 0.83 STWHIP P WEXIT AFTER 11442.1 FT LET IT DRILL AT 6-10 FT/HR. APPEAR rnntea: vzaaviv icvovorm TREE= 4-1/16CMJ ~ 18-30 SA OTES: **4-1 /2" CHROME TBG** WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 53.5' BF. ELEV _ - KOP = 1876' Max Angle = 97 @ 11838' Datum MD = N/A Datum TV D = 8800' SS 110-3/4" CSC, 45.5#, NT-80 BTC, ID = 9.953" I 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3504 3316 35 KG62 DMY BK 0 06/09/09 2 6003 5252 40 KGB2 DMY BK 0 06/09/09 1 8001 6797 39 KG62 DNIY BK 0 10/23!07 Minimum ID = 3.80" @ 9629' 9420' 4-1/2" HES X NIP, ID = 3.813" 4-112" HES XN NIPPLE (MILLED OUT) 9450' 7-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9484' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 0152 bpf, ID = 3.958" 4-1/2" TBG STUB (10/23/07) I 9547' I ~ 9562' ~~7-5/8" X 4-1/2" UNIQUE OVERSHOT I 9604' 7-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9629' 4-1/2" HES XN NIP, ID = 3.80" (MILLED OUT 08/06/09) 9650' 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 9704' 7' TIEBACK SLV, ID = 5.75" 9711' 7-5/8" X 5-1/2" BKR HPLPO LTP w /HMC HGR, ID = 4.892" I 9556' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 9649' TOP OF 5-1/2" LNR I--I 9704' 7-5/8" CSC, 29.7#, USS S-95 9857' BUTT-M, ID = 6.875" PERFORATION SUMMARY REF LOG: BHCA ON 07/15!95 A NGLE AT TOP PERF: 83° @ 10620' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10620 - 11430 O 07/23/95 3-3/8" 4 11840 - 11900 C 08/23/96 3-3/8" 4 11940 - 12090 C 08/23/96 3-3/8" 4 12160 - 12250 C 08/23/96 PBTD 12494' 5-1/2" LNR, 17#, L-80 BTGM , 12621' .0232 bpf, ID = 4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/28/95 D-9 ORIGINAL COMPLETION 08/22/09 JKD/PJC PULL IBP, MILLOUTXN (08/06/09 10/25/07 D-16 RWO 11/01/07 AJW/PJC DRLGDRAFTCORRECTIONS 11/17/07 GS/PJC GLV C/O (10/31/07) 06/03/09 KSB/TLH IBP SET (05/14/09) 06/14/09 DAV/TLH GLV C/O (06/09/09) IBP (SET 08/23/96) PRUDHOE BAY UNff I WF1L: 18-30 PERMIT No: `1950910 API No: 50-029-22568-00 SEC 24, T11 N, R14E, 4421.86' FEL & 770.6' FNL BP Exploration (Alaska) • • ,~ a ~`~ ~ ~~ ~_k ~ C4 ~~F ~ , ~ ~ ~ , r $~\ ° ~ 6~ ~" " ~~ ~ ~ ~ ~ ~.,~ c fl. . N ~ k ~ ~ . ~~ ~° ~ r ~ ' f~x ~ ~@ ~k ~ S .P > ~ ~T d /a' sF ~ ~ .~-j'' r 5 t ~ ~ ~~ ~ ~ ~~~ ~~ ~ r ~ ~ `~,~`' ~ ~ ~~~ ~ ~ SEAN PARNELL, GOVERNOR ~ ~ , ~ ~F` r ' ~ ~-_• ~ ~~ q ~_ ~ ~ ~~ ~ ~ `~~x ~._~ ~ ~g ~~ ~ ~ ~ ~ ~~ ~~ ~~~ ~ ~~ ~: ~_ ~~ ~. ~r ~-7~~ QIL t'~lti1 Vrn47 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T COMAIISSIOi~T ~~ ANCHORAGE, ALASKA 99501-3539 C PHONE (907) 279-1433 g FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) P.O. Box 196612 Anchorage, AK 99515-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-30 Sundry Number: 309-283 Dear Mr. McMullen: , ~~a~~ ~~ + ~"~ ~a r' ~ "\j'- + ~ ; i ~ y' ~ . f )~.l~~i *^'~~¢.~: v '~,~ s a . ~ ._ _ • .. Enclosed is the approved Application for Sundrl~ 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. Sincerely, Daniel T. Seamount, Jr. ~/ Chair a,/~ DATED this l` day of August, 2009 Encl. ~ ~~ . ~ ~'~~ STATE OF ALASKA g,~41~~ ALAS~IL AND GAS CONSERVATION COMM~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~ed!f~ ~~ ~~~~'~ /~D3 ~U~ ~ 2 2(~~J 1. ~ Type of Request: ~ Abandon~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ T~~~~~i~i~,~.~ ~;t~~~. ~a~q~~-~;~~ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Susp~;~;;> ^ 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 195-091 ^ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22568-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes PBU 18-30 - Spacing Exception Required? ^ Yes ~ No 9. Property Designation: _ 10. KB Elevation (ft): 11. Field / Pool(s): _ ADL 028307; 028321, 028326 53.45' ' Prudhoe Bay Field / Prudhoe Bay Oil Pool 12~ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12621 - 8731 - 10762 8769 10762'& 11500' None in Len th Size MD ND Burst Colla s tructural C nd c or 110' 2" 110' 110' 14 470 Surface 3895' 10-3/4" 3930' 365 ' S210 2480 In ermediate 9822' 7-5/8" 9857' 8294' 8180 512 Prod i n Liner 2917' 5-1/2" 9704' - 12621' 8171' - 8731' 7740 6280 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10620' - 12250' 8763' - 8749' 4-1/2", 12.6# 13Cr80 & L-80 9650' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker'S-3' packer; Packers and SSSV MD (ft): 9450' 7-5/8" x 4-1/2" Baker'S-3' packer 9604' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory '~ Development ^ Senrice ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 4, 2009 ^ Oil ^ Gas ^ Plugged -~ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Na John cMullen Title Engineering Team Leader ~ Prepared By Name/Number: Signature - ~ s~~ hy,~~ Phone 564-4711 Date g- ~ Z- U~ Sondra Stewman, 564-4750 ~ ~'" Commission Use Onl Sundry Number: N/A Conditions of approval: Notify Commission so that a representative may witness ~~ s~~3 ~~U -/ ^ Plug Integrity Ll~BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~Soo Ps~: ~ P ~r,s'~" Other: 4nw../1~•~- -~S~ ~~• Se / r a $?Jt7 ~ Subsequent Form Required: ~ p SIO ~ ~4 9 ~~ N' ~ R ~ ~ ~ APPROVED BY ~ ~ ~ ~ ~ ^ roved Q: COMMISSIONER THE COMMISSION Date Form 10-403 Revis~J 06/2006 0RIGINAL :. ~~~~~+~~~:~~~~Q4 ~, . , ~ ~ Submit In Duplicate ~~%~~~-/T/ ~-~ ~'/8 9 / ~~~t • • To: Tom Maunder Petroleum Engineer b p Alaska Oil & Gas Conservation Commission From: Ron Phillips CTD Engineer Date: August 4, 2009 Re: 18-30 Sundry Approval Sundry approval is requested for well 18-30. Well 18-30 was drilled in July 1995 with 1110' of ZlA/1B perfs. The well initially came online with high gas rates. A Boru~ PNL run in 5/96 indicated no channel was present. The main gas entry was noted at 12,225' - 12,250'. An IBP was set at 12,140' for GSO in May 1996 and was apparently blown uphole by August of that same year. An IBP was set at 11,510' md to isolate the bottom three sets of perfs at the toe - these were ~ 20' TVD higher. The IBP job was a great success and allowed the well to stay fulltime for over 4 years. The well began experiencing AnnCOMM problems in May 2002. The TIFL failed on BUR. Subsequent pressure testing in July 2003 yielded 2 MITOA failures with a m~imum leak rate of 4 BPM at 1175 psi. On 8/25/03 an OA downsqueeze was pumped with 20 bbls of cement and the ensuing MITOA passed to 3000 psi. Following the OA squeeze, the well was allowed to produce via a TxIA waiver. 18-30 failed the NFT-IA in August 2005, resulting in the cancellation of the TxIA waiver. A caliper over the tubing was run on 9/1/OS and revealed significant tubing corrosion. The well was SI & secured with a TTP on 9/2/O5. The October 2007 RWO installed brand new 4-1/2" Cr tubing to resolve the TxIA. The post RWO production rates have been disappointing. The CTU PPROF performed on 5/13/09 showed the temp dropping by 2 deg F@~11,200' md (indication of possible gas entry) and two point source entries contributing ~25% each at ~ 10,840' md and ~ 10,670' md, without a corresponding drop in temperatures. We decided to have one of these point sources shut off by placing an IBP within the perfs C~ 11,760' md. Unfortunately, the post IBP test showed the well making 22 MMscfd with no oil. 18-30 is in good mechanical condition. The well has new 4-1/2" 13CR-80 TBG. The well passed the MITOA to 2000 and the MITIA to 3000 psi on 6/11/09. REASON FQR SIDETRACK: 18-30 has been producing at a high GOR with a low ontime of only 24% for the year. With no good wellwork options left to pursue, a CST is the most practicable alternative left to make this well become more competitive and add value to the GPB well stock. The proposed plan for 18-30 is to drill a Zn 1 A sidetrack with a Coiled Tubing Drilling rig on or around Sept 4, 2009. The existing perforations below 11,500' are isolated by an IBP set in 1996. The perforations above 11500' will be isolated by the primary cement job after drilling the well and running liner. The sidetrack, 18-30A, will exit the existing 5-1/2" liner and drill fairly straight to the Southeast around the parent well and further into the reservoir. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. r ~~~~~, Oq~os~ w2/l l1lor~c ~a~~~q6/~ ~ecq~~~'oA r,.,'~/ ~ tf ~~/~t ~ ~~ ~b ~rlo~t.- ~•y-c /~sr~ ~e~ q~ 9 ~~r~~ • Pre-Rig Work Summary: • l. F MIT-IA - to 3000psi 2. F MIT-OA - to 2000 psi 3. V PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi 4. W PPPOT-T, Function LDS 5. S Dummy off all gas lift valves 6. C Pull upper IBP @ 10,762'. (Inclination of we1190 deg at 10,762') 7. C Mill XN nipple in 4-1/2" tubing tail to 3.80" using a left hand mator. 8. C Drift well for Baker 4-1/2"x5-1/2" Whipstock to top of IBP @ 11,500'. (86 deg at 11,500') 9. C Injectivity test on well at 500 PSI WHP. 10. W Set BPV 11. O Bleed IA, gas lift and production flowlines down to zero and blind flange. 12. O Remove S-Riser, Remove wellhouse, level pad. Rig Work: (scheduled to begin on 5ept 4, 2009) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE. 3. Test BOPE to 250 psi low and 3500 psi high. 4. Pull BPV. 5. Set 4-1/2" x 5-1/2" Baker mechanical whipstock at 175 deg ROHS at 11,400' 6. Mill 3.8" window through 5-1/2" p1us10' of rathole. Swap the well to Geo-Vis. 7. Drill turn and lateral section to 13,840'. 8. Run a 3-3/16" x 2-7/8" L-801iner leaving TOL at 9,620'. 9. Pump primary cement leaving TOC at 10,300', 48.7 bbls of 15.8 ppg liner cmt planned. 10. Make a cleanout run with mill/motor and log MCNL/GR/CCL in one run. 11. Test liner lap to 2000 psi. 12. Perforate liner per asset instructions (~ 1200' ). 13. FP well to 2200' with diesel. 14. Set BPV. ND 7-1/16" stack. 15. FP tree and PT tree cap to 3500 psi. 16. RDMO Nordic l. Post-Rig Work: 1. W Pull BPV. 2. O Re-install well house and FLs 3. S Run gas lift design 4. T Test ~1,200' Perforations Ron Phillips CTD Engineer 564~1'~ CC: Well File Sondra Stewman/Terrie Hubble , £P 3o~,ag3 ~ 1'rn ao`~ _ os~ 2 _' ~_ 41t16 GW ~ IN~LF~640 = FAAC ACTUA7~OR = 8AK6t C KB. ELEV = 53.5' BF. ~B/ = ? KOP= 1879' Mau Arx~le = 97 ~ 11838' O9tum IuD = WA Detum ND = 8~0' SS ' CSG, 45.5ir, IYT-80 BTC, D= 9.953" H 393p' ; Minimam ID ~ 3.725" ~ 9628' ;4-1/2" HES XN NiPPLE 18-30 4-tf2"THG,12.6A~,13CR-SOVAMTOP, f-j 954T .0152 bpt, ID ~ 3.958" I ~ 9562' H7•S!8" X 4-1/2" tJNIQUE OV92SHOT 86lM' H7-5/8" X 41/2" BIQi S-3 PKR D= 3.875° 41l2" TBG, 12.61F, L-S0, .0152 bpf. D= 3.958" H 9649' ITOPOF r1/2" l.l~i l 7-5l8' CSC,, 29.7#, USS 5-95 BtlTT-M, D = 6.875" ~ow~,~no~, su~no,~rr li~ 10C3: BHCA ON 07/15P85 ANCaLEATTOPPHiF: 83' ~ 10B20' No4e: Refer to Rroduction DB for hiatoriCal p~f data S¢E SPF NTHtVAL OpMSqz OATE 3-318" 4 10620 -11430 O/ C 07/23/95 3318" 4 11840 -11900 C 08f23l96 3-3lS" 4 11940 -12090 C 08l23l96 3-3/8" 4 12180 - 12250 C 08/23l98 SAFETY NOTES: •'a-~n" CFNiOME TBG' 2" HE.S X NP, D= 3.813" GAS LFT NMNDRCiS ST ND 7VD DE1/ 7YPE VLV LATt;Ff PORT MTE 3 3504 3316 35 KG82 OONE BK 16 10/31l07 60Q3 5252 40 KG62 SO BK 20 10/31/07 1 8001 6797 39 KG62 DAAY BK 0 10/23I07 ~u~ I~~-i rc r~s ~ ~ar, u=-s.es~ a~• ~ 9450' 7-5/8° X 4-7f2" BKR 5-3 PKR D= 3.875" 9484' 4-1/2" FIES X t~YP, D m 3.813" E 9629' H41/2" F£S XN 1~, D= 3.725" ~ 9650' A-1i2" WLEG~ D= 3.958" ~-~6.AiD 1T N~T LOGG~ 9704' T 71~ACK SLV. D= 5.75" 9711' 7-5/8" X 5-1rz' eKR FRt~O LiP w lMAC HGR, D= 4.892" ~o~sr crM Ha-s-B• ~ac sP ~ PsTO H ~ 51/2" INR, 17*. L-80 BTGM' ~ .0232 bpf, D = 4.892" OATE REl/ BY COMNBYTS QqTE FtE1/ BY OOMJB~tfS o~ns+sa aa o~-~ c~atEr~ar 1QI25107 D~16 RWO 11/01/07 AJVWPJC DRI.GDWIFTC~CTI0r6 11/17/07 GSlPJC GLV GO (10/31/07) 08/aiD09 KS8lTLH BP SET (05/14J09) PRU~10E &4Y tNT V1taL: 1&30 PB~TT No: 1950910 API No: 50-029-22568-00 58C 24, T11 N, R14E, M21.88' FH. 8 770.8' FPL. 8P 6cptor~ion (Als~sk~) 3 ~ ~ ~ ~_ 4-'I H 6 CNU a ~$~3 oA SAFETY NOTES: "4-1/2" CHROME TBG' Proposed CTD Sidetrack WELLFfAD= FNIC ACTUATOR= BAK62C K8 ~EV = i 53.5' BF. ELEV = ? KOP = 1876' N~x Angle = - _ __ 97 (~ 11838' Datum AiD = WA Datum ND = 8800' SS 2" F~S X NP, D= 3.813" GAS LFT MANORELS ' CSG, 45.5t1~, IYT-80 BTC, D= 9.953" f-{ 393 Minimum ID = 3.725" ~ 9629' 41/Z" HES XN NIPPLE 7-5/8" X 4-1/2" BKR S-3 RCR, D= 3.875" 41/2" THG, 12.6#, 13CR-80 VF 0152 bpf, D = 3.958" 4-1/2" TBG STUB (ti TOP 3-1/2" X 3 3/16" X 2-7/8 BG, 12.6*, L-80. .0152 bpi, D= 7-5/8" X 5-1/2" BKR HPLPO L7P w ltiAAC FIGR, D= 4.892" ~ 7-5/8" CSG, 29.7#, S-95 BUTT-AA, D= 6.875" ~ TSGR 9756` TOC 10.300` ~ow-riori su~r~nnRr REF LOG: BHCA ON 07/15/95 ANGLE AT TOP P6iF: 83' ~ 10620' NoDe: F2efer to Ptotluctan DB for historical peA data S¢E SFf M6~VAL OpNSqz Q4TE 3-3l8" 4 10620 - 11430 O/ C 07/23~95 3-3/8" 4 11840 - t 1900 C 08/23/96 3-3/8" 4 11940 - 12090 C 08/23/96 3-3/8" 4 12160 - 12250 C 08/23/96 ~~ ST ND ND DEV 7YPE VLV LATCF PORT DINTE 3 3504 3318 35 KG82 DONE BK 16 10/31/07 6003 5252 40 KG82 SO BK 20 10l31/07 1 8001 6797 39 KG82 OMY BK 0 10l23/07 9484' H 4 7 2" F~S X 1~, D= 3.813" I 9562' 7-5/8" X 4-1/2" UNI~UE OVERSHOT 9604' 7-5/8" X 4-1l2" BKR S-3 PKR, D= 3.875" 9622' N61~ed out bushing ID = 2.30" ~629~ H41/2" FfS XN NP, D mlled to = 3.80" 9~ ~\\\ 3-3J16" x 2-7/8" crtt'd 8 perf'd 13840' ~ 11700' 3-3/16 x 2-7/8 X-over 5-1/2" LNR 17#, L-80 BTGM , 0232 bDf, D = 4.892" LIATE REV BY CONII~VTS DATE REV BY COMIu~MS 07/28195 Q9 ORIGINAL COMPLETION 10/25/07 D16 RWO 11/01/07 AJW/PJC DF~LG DRAFTOORRECTIONS 11/17/07 GS/PJC GLV GO(10/31/07) O6/03/09 KSB/TLN IBP SET (05/14/09) 08/24/09 MSE PROPOSm CTD SDETRACK PRUDFIOE BAY UNIT WELL: 18-30A P~Mff ~lo: API No: 50.029-2256&01 SEC 24, T11 N, R14~ 4421.86' F~ 8 770.6' FI~ BP 6cploration (Alaska) 4 06/08/09 • SCd~t#~~~I'I~~P Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK ~ 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE - 05/15!09 1 1 06-OSA AV1H-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 A-44 AWL8-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05/17/09 1 1 H-29A AYOO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK , 05/06/09 1 1 15-458 ANHY-00010 PRODUCTION PROFILE ~- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ ~ 05/08/09 1 1 M-196 AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A 61JJ-00018 MEM CNUSTP ~ 05/18/09 1 1 X-30A 62WY-00005 MEM PROD PROFILE C 05/10/09 1 1 12-23 AYKP-00021 USIT G - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 Z-146 AZCM-00022 PROD PROFILElJEWELRY LOG ~ ~- 05/20/09 1 1 L7-21 62NJ-00006 PRODUCTION PROFILE 05/24/09 1 1 A-31A AZCM-00023 USIT (~ - Q ~ G 05/22/09 1 1 H-19B' B2WY-00004 MEM PROD PROFILE `- 05/07/09 1 1 G-16 AYKP-00022 SCMT f / 05/09/09 1 1 M-19B AY3J-00024 SCMT 05/15/09 i 1 12-37 AWL9-00032 PRODUCTION PROFILE ~:/~/ / 04/21/09 1 1 11-04A AYOQ-00028 USIT J L/ _ 05/21/09 1 1 18-30 B1JJ-00015 MEM PROD PROFILE )G/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ v~ t 05/11/09 1 1 3-37lL-35 AWL9-00035 PRODflNJECTION PROFILE 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 1NJ PROFILEJRST WFL ~} -' /~d5 04/26/09 1 1 PLEASE ACKNVWLEDGE RECEIPT BY SIGNING AND RETURNING ONE CVPY EAGR TV: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 STATE OF ALASKA /D~~R{~~~~U~D ALASKA OIL AND GAS CONSERVATION COM SION ~0V 3 ~ 2QQ7 REPORT OF SUNDRY WELL OPERATIONS ,Alaska Oil & Gas Collet ~Ommillsian 1. Operations Performed: At1CIlOf~IgB ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-091 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22568-00-00 7. KB Elevation (ft): 53.45' 9. Well Name and Number: PBU 18-30 8. Property Designation: 10. Field /Pool(s): ADL 028326 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 12621 feet true vertical 8731 feet Plugs (measured) 11500 Effective depth: measured 12494 feet Junk (measured) None true vertical 8741 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3895' 10-3/4" 3930' 3658' 5210 2480 Intermediate 9822' 7-5/8" 9857' 8294' 8180 5120 Production Liner 2917' 5-1/2" 9704' - 12621' 8171' - 8731' 7740 6280 ~~~~I~~~~ DEC ~ ~ 2007 Perforation Depth MD (ft): 10620' - 12250' Perforation Depth TVD (ft): 8763' - 8749' 4-1/2", 12.6# 13Cr80 & L-80 9650' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x 4-1/2" Baker'S-3' packer; 9450' 7-5/8" x 4-112" Baker'S-3' packer 9604' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pulled tubing from 9556'. Run new Chrome Completion. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Gasin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 345 27,959 21 1,490 1,616 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name Terrie Hubble Title Drilling Technologist 1 Prepared By Name/Number: l Signature Phone 564-4628 Date ~~ Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~ Submit Original Only ~ ~~ ~~c ~ ~ 2oar ~~~~ ~ Digital Well File ~ • Page 1 ~ • Well: 18-30 Well History Well Date Summary 18-30 9/9/2007 T!I/0=500/400/0, Temp=SI. PPPOT-T (PASS), PPPOT-1C (PASS). Pre rig. PPPOT-T: Stung into test port to check pressure (0 psi), bled to 0 psi. Function LDS, all moved freely with no sign of bent or broken pins. Pumped through void until Dean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 0 psi in second 15 min (PASS). PPPOT-IC: Stung into test port to check pressure (500 psi), bled to 0 psi. Function LDS, all moved freely with no sign of bent or broken pins. Pumped through void until Gean fluid was achieved. Pressured void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). 18-30 9/14/2007 MIT OA- Load and travel to location 18-30 9/15/2007 T/I/0= 450/300/0 MIT OA PASSED to 2000 psi fPRE RWO] Pump 2.2 bbls crude down OA to achieve test pressure-MIT OA lost 40 psi in 15 min's, 40 psi in 2nd 15 min's, 20 psi in 3rd 15 min's for a total loss of 100 psi in 45 min's. FWHP's= 450/300/0 ***Annulus casing valves left open, OA tagged on departure*** 18-30 9/24/2007 *** WELL SHUT IN ON ARRIVAL *** (pre-rwo) RAN FLAPPER CHECKER TO TRSSSV @ 2180'SLM ,VALVE WORKING. LOCKED OUT 4 1/2" TRCF-4A TRSSSV @ 2180'SLM .PULLED P-PRONG FF~f~RIT~CQ ~ c ~Sb~fb~~C~000E6~~T~N PLUG BODY FROM 18-30 9/25/2007 *`* JOB CONTINUED FROM 09-24-07 WSR'*' (pre rvvo) BLED TBG AND IA PRESSURES DOWN AFTER CMIT DUMP BAILED 100# OF SLUGGETS ON 4 1/2" XXN PLUG @ 9632'SLM ***WELL LEFT S/I ON DEPARTURE*** 18-30 9/25/2007 *''* CONTINUED FROM WEATHER WSR "` (pre-rwo) DUMP BAILED 100# OF SLUGGITS ON 4.5 XXN PLUG @ 9632'SLM. ***WELL LEFT S/I ON DEPARTURE*** 18-30 10/6/2007 INITIAL T/I/O = 850/200/0 - (RWO PREP: STRING SHOT, TBG PUNCH, CHEMICAL CUT) CORRELATE TO TUBING TALLY 7/25/95. SHOT 12' OF 2 STRAND STRING SHOT FROM 9546'- 9558'. PUNCH TBG FROM 9538'-9540' (SMALL) 9 SHOTS. FULLBORE TO CIRC WELL PRIOR TO CHEM CUT. FINAL T/I/O = 750/150/0 ***JOB INCOMPLETE*** 18-30 10/7/2007 T/I/0=8001200/0 Circ-ouU Freeze Protect (RWO Prep) Pumped 5 bbls neat methanol spear, 582 bbls 1 kcl and 91 bbls diesel down IA taking returns up TBG to flow line. Let U-tube for 1 hr. Bled pressures down to 0 psi. Freeze Protected FL with 10 bbls diesel. FWHP's=0/0/0 18-30 10/7/2007 INITIAL WHP 0/0/0 RIG UP TO CHEMICAL BUT 4.5" TUBING AT 9556' IN FIRST FULL JOINT ABOVE PACKER ***** CONTINUE AWGRS ON 8-OCT-07 ***** 18-30 10/8/2007 Set 4" CIW BPV, for re ri ,set well et at eep 18-30 10/8/2007 "'WELL S/I ON ARRIVAL*** (fish) RAN 3.80" CENT & 3.70" LIB TO FISH @ 9615' SLM, SHOWED IMPRESSION OF CHEM CUTTER. RAN BAITED 1.5" BULL-DOG SPEAR TO 9615' SLM RECOVERED CHEM. CUTTER @ 9615' SLM ****LEFT WELL S/I..NOTIFIED DSO OF STATUS***** 18-30 10/8/2007 "'"*' CONTINUE AWGRS FROM 7-OCT-07 ""' INITIAL WHP 0/0/0 CHEMICAL CUT 4.5" TUBING AT 9556' IN FIRST FULL JOINT ABOVE PACKER. CORRELATED TO TUBING TALLY DATED 25-JUL-95. CUTTING HEAD SEVERED DURING OPERATION. LOWER CENTRALIZER AND BOTTOM HALF OF SEVERING HEAD (TOTAL OF 26" IN LENGTH, MAX OD 3.625") WERE LEFT IN THE WELL. WELL SHUT IN AND MASTER VALVE CLOSED UPON ARRIVAL. WELL LEFT SHUT IN. DID NOT TAG TD. FINAL WHP 0/0/0 ***JOB COMPLETE*** 18-30 10/13/2007 T/I/O = 0+/45NAC. Temp = SI. Bleed IAP 8 OAP to 0 psi (RWO prep). IA FL ~ Surface. Bled IAP from 45 psi to 0 psi in 1 minute. Monitored for 30 minutes. Final WHP's = 0+(0+/VAC. 18-30 10/14/2007 T/UO=0+/40/vac. Temp=SI. Monitor WHPs (post UIC bleed). IAP decreased 5 psi over night. No change in TBGP or OAP. http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 11 /30/2007 • BP EXPLORATi4N Page 1 of 7 Operations Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Spud Date: 6/22/1995 Event Name: WORKOVER Start: 10/15/2007 End: 10/24/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/24/2007 Rig Name: DOYON 16 Rig Number: Date. From - To Hours Task Code NPT Phase Description of Operations 10/14/2007 12:00 - 00:00 12.00 MOB N WAIT PRE Waiting on weather, high winds preventing rig prep on 18-30, rig stayed on 18-13 on mats and herculite, cleaned rig and performed maintenance. 10/15/2007 00:00 - 23:00 23.00 MOB N WAIT PRE Continued to wait on high winds to subside to move onto 18-30. Rig is on mats and herculite over 18-13, continuing cleaning and maintenance operations. Drill Site Maintenance beginning well work at 15:00. 23:00 - 00:00 1.00 MOB N PRE PJSM, Pull Rig Off of 18-13, Stage Rig in Center Of Pad and L/D Derrick. 10/16/2007 00:00 - 01:00 1.00 MOB P PRE Drive Rig Around Reserve and Stage Rig to Raise Derrick, 01:00 - 19:00 18.00 MOB P PRE Raise Derrick, R/U Rig Floor. Perform Light Maintenance while waiting on Pad Prep. 19:00 - 20:30 1.50 MOB P PRE Lay Herculite and set Rig Mats. 20:30 - 22:00 1.50 MOB P PRE Spot Rig up on Rig Mats 22:00 - 00:00 2.00 MOB P PRE R/U DSM Set VR Plug in IA and Take off Valve and Install Blind Flange to Spot Rig over Well Bore. 10/17/2007 00:00 - 00:30 0.50 MOB P PRE Spot and Shim Rig over Well 18-30, 0 psi on OA, 0 psi on IA, 0 psi on Tubing. Rig Acceptance at 24:00 10/16/2007 00:30 - 01:00 0.50 MOB P PRE Comply with Pre-Spud Check List. 01:00 - 02:00 1.00 MOB P PRE R/U DSM Lubricator and Pressure test to 250 psi low test and 500 psi high test. Pull BPV, R/D DSM 02:00 - 04:30 2.50 KILL P DECOMP PJSM Pressure test Circulating Lines to 3,500 psi, Pump 20 bbl Hi-Vis Sweep Followed by 500 bbl of 8.4 ppg 2% KCI at 7 bpm with 870 psi. Monitor well for 15 minutes. Well circulation was through the them cut at 9,556'. 04:30 - 05:30 1.00 WHSUR P DECOMP B/D Circulating Lines and Install TWC and Pressure Test to 1,000 psi from below and 3,500 psi from Above. TWC had slow above. Call DSM to bring out lubricator to remove and re-install another TWC. 05:30 - 07:30 2.00 WHSUR N WAIT DECOMP Wait on Drillsite Maintenance to bring lubricator. 07:30 - 09:00 1.50 WHSUR P DECOMP N/D Production Tree and Adapter Flange. R/U DSM lubricator to tree and PT to 500-psi for straight-line test on chart. RIH with retrieval tool and pull TWC. Saw no pressure on tree before or after pulling the TWC. There was no pressure in the IA. Break off lubricator and remove TWC. 09:00 - 10:00 1.00 WHSUR P DECOMP P/U another TWC, R/U lubricator to tree and install second TWC in Hanger. Break off and L/D lubricator. Pressure test from the bottom to 1,000-psi and from above to 3,500-psi, with r c rded a flat-line tests. There was no obvious damage to or junk found in the first TWC that would indicate why that TWC had failed. 10:00 - 11:00 1.00 WHSUR P DECOMP N/D tree and adaptor flange. AOGCC was contacted and given an update for the BOPE test start. AOGCC representative, Jeff Jones, waived State's right to witness the BOPE test. 11:00 - 12:00 1.00 WHSUR P DECOMP Terminate SSSV Control Lines and check hanger threads. A 4-1/2" NSCT crossover was screwed 7-1/2 turns into the hanger--a spear will not be utilized to pull the hanger. 12:00 - 13:00 1.00 BOPSU P DECOMP Nipple up BOP stack and connect control lines. 13:00 - 14:00 1.00 BOPSU P DECOMP pT BOPE to 250-psi low and 3,500-psi high. The Hydri{ annular preventer would not seal. It was reported by the Toolpusher that damage ("a chunk of rubber was missing") was seen on the bag during the course of the work on DS18-13, however the Printed: 11/12/2007 4:55:53 PM • BP EXPLORATION Page 2 of 7 Qperations Summary Report Legal Well Name: 18-30 Common We{I Name: 18-30 Spud Date: 6/22/1995 Event Name: WORKOVER Start: 10/15/2007 End: 10/24/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/24/2007 Rig Name: DOYON 16 Rig Number: Date ,From - To I Hours ~ Task I Code I NPT 4 Phase I Description of Operations 10/17/2007 13:00 - 14:00 14:00 - 17:00 7:00 - 19:00 19:00 - 20:00 20:00 - 00:00 1.00 3.00 .00 1.00 4.00 BOPSU BOPSU OPSU BOPSU BOPSU P P P P P DECOMP DECOMP ECOMP DECOMP DECOMP subsequent BOP tests were successful. The bag was last replaced in June. Hold PJSM to remove and replace the Hydril bag. Remove Air Boots and Riser. P/U Potato Masher and M/U to Hydril top. P/U Potato Masher run/pull tool and stab and pin into Potato Masher. Use rig tongs to backout the Hydril) top. Install new Hydril top seals (3-ea) and new Hydril bag. N/U Flow Riser. R/U and Test BOPE to 250 si Low Test and 3,500 si Hi h est all Tests held for 5 Charted minutes 10/18/2007 00:00 - 03:30 3.50 BOPSU P DECOMP Continue to Test BOPE. Valve #14 Failed Pressure Testing, Replaced Valve #14 and Retested Good. All Other Components tested OK, 250 low test and 3,500 high test for 5 charted minutes each. 03:30 - 04:00 0.50 BOPSU P DECOMP Blow Down R/D BOP Test Equipment. 04:00 - 05:00 1.00 BOPSU P DECOMP R/U DSM Lubricator, Pressure Test Lubricator to 250 psi Low Test and 500 psi High Test, Pull TWC, R/D DSM Lubricator. 05:00 - 06:00 1.00 PULL P DECOMP R/U Floor to Pull 4.5" Completion. The Top Drive main rotating motor would not remain energized. Troubleshooting has narrowed the source to the Variable Speed Drive supplying power to the Top Drive electrical components. We are awaiting a conference call between National Oilwell, Houston, and the Toolpusher and Rig Electrician. 06:00 - 08:45 2.75 PULL N RREP DECOMP Conference call with National Oilwell personnel focussed on troubleshooting the line connections into and out of the VSD. The subsequent troubleshooting narrowed the problem to the Dynamic Brake system, which led to another conference call. 08:45 - 14:30 5.75 PULL N RREP DECOMP Wait on National Oilwell in Houston to review T/D control system schematics and continue to troubleshoot equipment in the VSD building located on the Pipe Shed roof. A transformer in the Dynamic Braking system was found to be overheating, and this information has been relayed to National Oilwell in Canada. The Dynamic Brake Module was taken out of service in the VSD shack, RWO Superintendent was consulted and the decision made to go ahead with pulling the hanger to the floor since there is an air brake on the Top Drive and there would be no need to rotate the pipe string until after the tubing has been POOH and the cleanout run was made. 14:30 - 15:00 0.50 PULL N RREP DECOMP PJSM with entire crew, Toolpusher, and WSLs to pull the hanger and to discuss the plan forward for contingencies should we experience further problems while POH and L/D tubing. 15:00 - 16:30 1.50 PULL N RREP DECOMP Attempted to breakout the test sub from the Top Drive; the Grabber and Air Brake would not function. Consulted with RWO Superintendent and S/D current operations to await spare parts ordered from National Oilwell. Called Norway to discuss the problem and Norway focussed Electrician on the safety interlock for the Bails rotation lock pin. Consulted RWO Supt and will prepare to Pull and L/D Completion. 16:30 - 18:00 1.50 PULL P DECOMP Hold PJSM and prepare to pull Tubing Hanger to Rig Floor. M/U Landing Jt, BOLDS. 18:00 - 18:30 0.50 PULL N DECOMP Pull Hanger Free with 135,000# Work Pipe 4 time, Staging up to 205,000#. Pipe not Cut, RILDS Printed: 11/12/2007 4:55:53 PM • BP .EXPLORATION: Page 3 of 7 Operations Summary,Report Legal Well Name: 18-30 Common Well Name: 18-30 Spud Date: 6/22/1995 Event Name: WORKOVER Start: 10/15/2007 End: 10/24/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/24/2007 Rig Name: 4 DOYON 16 Rig Number: Date.. I From - To ~ Hours I Task ~ Code L NPT Phase Description of Operations 10/18/2007 18:30 - 19:30 1.00 N 19:30 - 21:00 1.50 PULL N 21:00 - 00:00 3.00 PULL N 10/19/2007 100:00 - 03:30 I 3.501 PULL I N 03:30 - 07:00 I 3.501 PULL I N 07:00 - 08:00 I 1.00 I PULL i N 08:00 - 09:30 1.50 PULL N 09:30 - 10:30 1.00 PULL N 10:30 - 12:00 1.50 PULL N 12:00 - 12:15 I 0.251 PULL I P 12:15 - 13:00 I 0.751 PULL I P 13:00 - 16:00 I 3.001 PULL I P 16:00 - 16:30 I 0.501 PULL I P 16:30 - 00:00 I 7.501 PULL I P 110/20/2007 100:00-01:30 01:30 - 02:00 1.501 PULL I P 0.501 CLEAN I P DECOMP Drain BOP Stack, Nipple Down Flow Riser Assembly, N/U Shooting Flange and Prepare for E-Line Crew. DECOMP Wait On SLB E-Line Crew to make second Cut on Tubing at approx 9,559' WLM. DECOMP PJSM Spot E-Line Trucks, P/U R/U SLB E-line Tools. Lubricator Extension, WL BOPs, Pump In Sub, Grease Tubes, Pack Off. STUC DECOMP Continue to N/U SWS E-Line Equipement. 7" XO, 10' Lubricator, Pump in Sub, Wireline BOPs, Quick Test Sub, 10' Lubricator, Flow Tubes w/Grease Control, Line Wiper, Pack Off. STUC DECOMP RIH with Jet Cutter to approximate 9,560' log into position to jet cut the 4-1/2" tubing. SLB had to RIH 500' at a time, then POOH in order to prevent kinking their new 1/4" E-line. STUC DECOMP POOH with Wire Line. Correlate Jet Cutter and set cutter at 9,560'. There was no indication of a chemical cut on the log. Fire cutter at 0740-hrs and see excellent surface response as well as 80-Ib weight loss on weight indicator. STUC DECOMP POOH with Schlumberger E-Line. STUC DECOMP R/D Schlumberger E-line equipment. STUC DECOMP N/D shooting flange and N/U flow riser and air boots. Pump out stack and install Landing Joint in Tubing Hanger, 8-turns. DECOMP M/U landing joint to Top Drive. Hold PJSM. Pull to -145K and entire string comes, and continues to pull easily. DECOMP Circulate Bottoms Up and R/U Camco spooler to spool the single 1/4" SS Control Line. R/U power tongs and inspect pipe skate for POOH and L/D 4-1/2" tubing. DECOMP POH and L/D 4-1/2" NSCT tubing, numbering all joints, spooling SS-Control line tubing. Recovered 52-joints of 4-1/2" NSCT tubing, possibly all of the 1/4" SS control line, and 19 of the 28 SS-bands that were shown in the original completion tally. The SS-bands were not installed properly which caused the SS control line to break while POOH. The bands appeared to have been installed in the middle of every-other joint, but should have been installed next to collars. Camco now has a Scintillation Counter which the spooler operator is trained to use; for removal of the SS control line from the wellsite. Control line and bands had NORM levels below background level. DECOMP R/D Camco spooler and remove through Beavalator. Unload SSSV from Pipe Shed and set aside for shipment to Baker Machine to buck off the handling pups. DECOMP Resume POOH and L/D 4-1/2" tubing through Pipe Shed. Layed down a total of 226 jts of Tubing. The tubes are in generally good condition, Boxes in good shape, Pin end had moderate erosion at the end of threads. 3-GLMs, 1-SSSV, and Cut jt. Cut jt was 16.28' and had a flare with a 5" OD Clean Cut. There was no external evidence of previous Chem Cut. Will have the Welder Cut a section out of pipe in AM. DECOMP Pull 7 5/8" Pack Off with 20,000# up weight, Pull and Install New 7 5/8" Pack Off. RILDS Test Neck Seal to 3,800 psi for 30 minutes. Retrieve 3 SS Control Line Bands with Pack Off and 6' Piece of Control Line. DECOMP Install 9" ID Wear Ring. Printed: 11/12/2007 4:55:53 PM • • BP EXPL©RATION : Page 4 of 7 Opera#ions Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Event Name: WORKOVER Start: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT I Phase 10/20/2007 02:00 - 03:00 1.00 CLEAN P 03:00 - 11:45 8.75 CLEAN P 11:45 - 12:15 0.50 CLEAN P 12:15 - 13:15 1.00 CLEAN P 13:15 - 14:00 0.75 CLEAN P 14:00 - 14:30 0.50 CLEAN P 17:00 - 18:00 1.00 I CLEAN ~ P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:30 1.00 CLEAN N 19:30 - 20:30 1.00 CLEAN P 20:30 - 23:30 3.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 10/21 /2007 100:00 - 00:30 00:30 - 01:30 01:30 - 02:30 02:30 - 07:00 07:00 - 07:30 0.50 CLEAN P 1.00 CLEAN P 1.00 CLEAN ~ P 4.50 CLEAN P 0.50 CLEAN P 07:30 - 12:30 12:30 - 12:45 12:45 - 14:00 14:00 - 17:00 17:00 - 17:30 5.00 CLEAN P 0.25 CLEAN P 1.25 CLEAN P 3.00 CLEAN P 0.501 CLEAN I P 10/15/2007 10/24/2007 Spud Date: 6/22/1995 End: 10!2412007 uescnptlon of vperatlons DECOMP P!U M/U BHA #1, BHA: 5 3/4" Dress Off Shoe, 5 3!4" Wash Pipe Extension, Tubing Dress Off Mill, 5 3/4" Junk Basket, XO, 7 5/8" CSG Scraper, 4 3/4" Junk Basket, XO, Bowen Bumper Jar, Bowen Jar, XO, 9-4 3/4" Drill Collars, BHA Length = 321.98' DECOMP Pick Up Drill Pipe 1x1 from Pipe Shed and RIH with Dress Off Assembly. Tag 4-1/2" stub at 9,554'. Get parameters: P/U wt 190K, S/O wt 140K. DECOMP Hold PJSM with crew to discuss the stub milling operation. DECOMP Get parameters: Free Torque 6K at 60-RPM, 4-BPM at 460-psi. Slowly lower and see washover pipe swallow stub at 9554' continue on in and swallow 8'. P/U joint #293 and continue RIH to polish off the stub to 9,555'. DECOMP Pump 20-Bbl hi-vis sweep to surface at 10-BPM, 2400-psi. DECOMP Conducted kick while drilling drill. Observed hands' reactions and held an after action review to discuss drill. DECOMP POOH with the Dress-off BHA. S/B DP and DCs in the Derrick. DECOMP Break out and L/D Dress-off BHA. Service Junk Baskets Recovered several Pieces of Control Line Clamps and Approx 1/2 gal of metal shavings. DECOMP Clear and Clean Rig Floor. DECOMP Repaired Top Drive; replaced Dynamic Brake Module for the rotary motor in the Top Drive. DECOMP M/U Reverse Circulating Junk Basket Assembly, BHA consists of: Jet Basket, XO, 3 jts of 2 7/8" Pac Drill Pipe, XO, XO, 4 3/4" Junk Basket, XO, Bumper Sub, Oil Jar, Pump Out Sub, XO, 9 - 4 3/4" Drill Collars. BHA Length=404.69'. DECOMP RIH to 4,100' Circulate Drill Pipe Volume, Continue to RIH to 9,526'. DECOMP Obtain Parameters: Up Weight=195,000#, Down Weight=135,000#. Tagged Top of Sluggets at 9,609', Pump Down Reversing Ball. DECOMP RIH and Tagged Sluggets on XXN plug at 9,606' and worked Reverse Circulating Basket to 9,614' at 4 bpm with 1,040 psi. Unable to wash past 9,614'. DECOMP Pump 20-Bbls Hi-Vis Sweep at 5.5-BPM @ 1930-psi. Monitor well, B/D lines. DECOMP PJSM, Slip and Cut 85' drilling line. DECOMP POOH with RCJB BHA. DECOMP The RCJB was packed off (about 1-quart) with debris from the Jet Cutter and small pieces of SS-bands. Empty the RCJB and prepare to re-run the RCJB BHA. DECOMP RIH RCJB BHA on DCs and DP from Derrick. DECOMP RIH and Tagged "XXN" plug at 9.623' and worked Reverse DECOMP Pump 20-Bbls Hi-Vis Sweep at 5-BPM @ 1260-psi. Monitor well, B/D {fines. DECOMP POOH and stand back 4" HT-38 Drill Pipe in Derrick. Stand back 3 Stands of 4-3/4" Drill Collars. POOH w/ RCJB. Junk Basket had only one small piece of banding. UD RCJB Assembly. DECOMP P/U Positive Latch GS Spear Assembly consisting of "XXN" Plug Retrieving Tool. 3 Jts 2-7/8" n ipe, - "Boot Basket, Printed: 11/12/2007 4:55:53 PM • C BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 10/21/2007 17:00 - 17:30 0.50 CLEAN P 17:30 - 20:00 2.50 CLEAN P 20:00 - 21:00 1.00 CLEAN P 21:00 - 22:30 1.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 10/22/2007 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:00 1.00 CLEAN P 02:00 - 02:30 0.50 CLEAN P 02:30 - 04:00 1.50 CLEAN P 04:00 - 05:00 1.00 CLEAN P 05:00 - 08:00 3.00 CLEAN P 08:00 - 09:00 1.00 CLEAN P 09:00 - 10:00 1.00 CLEAN P Spud Date: 6/22/1995 Start: 10/15/2007 End: 10/24/2007 Rig Release: 10/24/2007 Rig Number: Phase Description of Operations DECOMP (9) 4-3/4" Drill Collars, Bumper Sub, Jars, and Pump Out Sub. Total Length of BHA- 402.46' DECOMP RIH w/ Positive Latch GS Spear Assembly on 4" HT-38 Drill Pipe from Derrick to retrieve "XXN" Plug. DECOMP Tag "XXN" Plug at 9623'. Break circulation at 3 BPM w/ 280 psi. Wash down to "XXN" Plug and stack 5,000 Ibs on Plug 3 different times. Each time a 300 psi Pump Pressure increase was noticed. Each time picked up without over pull and the well's fluid level remained static with no losses. Last pull sat down 6" higher than previous attempts and a slight over pull was noticed, no fluid losses. DECOMP Open Pump Out Sub and CBU at 10 BPM with 1620 psi. Monitor well for gas or losses. No Gains or Losses. Pump 10 BBL Slug. DECOMP POOH w/ 4" HT-38 Drill Pipe. Stand Drill Pipe in Derrick. DECOMP Continue POOH w/ 4" HT-38 Drill Pipe. Stand Drill Pipe in Derrick. DECOMP POOH w/ Positive Latch GS Spear Assembly. Stand back 3 Stands of 4-3/4" Drill Collars. "XXN" Plu was not recovered. Examine GS Retrieving Tool. Shear Pins sheared and ogs in Retrieving Tool shifted into the release position. DECOMP Clear and Clean Rig Floor. Send for Standard GS Spear. DECOMP Wait on GS Spear. DECOMP M/U GS Spear Assembly consisting of Spear, (3) Joints 2-7/8" PAC Drill Pipe, Boot Basket, Bumper Sub, Jars, Pump Out Sub, (3) Stands of 4-3/4" Drill Collars from Derrick. Total Length of BHA- 402.98' DECOMP RIH w/ GS Spear Assembly on 4" HT-38 Drill Pipe from Derrick to retrieve "XXN" Plug to 9610'. DECOMP Establish Fishing Parameters and SPR. Up Wt- 195,000 Ibs and Down Wt- 135,000 Ibs; Pump Rate @ 2 BPM with 520 psi. Wash down to "XXN" Plug at 9623'. S/O 5000 Ibs on plug with 200 psi increased pump pressure. Unseat plug with 7000 Ibs over ull. Initial losses at 160 BPH. DECOMP Drop Ball and Rod. Open Circulating Sub. CBU at 6 BPM with 780 psi. Loss Rate ~ 50 BPH. 10:00 - 18:30 8.50 CLEAN P DECOMP Monitor Well Losses at 50 BPH. POOH with 4" HT-38 Drill Pipe. L/D Drill Pipe. 18:30 - 19:30 1.00 CLEAN P DECOMP POOH with GS Spear Assemby. L1D (9) 4-3/4" Drill Collars, (3) 2-7/8" PAC Drill Pipe, Jars, Bumper Sub, Pump Out Sub, and X/O Subs. L/D GS Spear and "XXN" Plug recovered from 19:30 - 20:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 20:00 - 22:00 2.00 RUNCO RUNCMP R/U Rig Floor to P/U and RIH with 4-1/2", 12.6#, 13Cr-80 Vam To Com letion. R/U Doyon Casing Equipment with Torque Turn and Compensator. All Tubing and Jewelry was drifted before RIH. Jet Lube Seal Guard used on Threads. 22:00 - 22:30 0.50 RUNCO RUNCMP P/U Completion BHA consisting of Unique Overshot, 1 Jt TBG, "X" Nipple, Baker S-3 Packer, and "X" Nipple. Baker Loc used on all connections below Baker S-3 Packer. Average make up Torque dumped at 4440 psi with Torque Turn Equipment. 22:30 - 00:00 1.50 RUNCO RUNCMP P/U and RIH with 4-1/2", 12.6#, 13Cr-80 Vam Top Completion. Jet Lube Seal Guard used on Threads. Average make up Printed: 11!12/2007 4:55:53 PM • • BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 10/22/2007 22:30 - 00:00 1.50 RUNCO 10/23/2007 00:00 - 09:00 9.00 RUNCO 09:00 - 09:30 0.50 RUNCO 09:30 - 10:30 1.00 RUNCO 10:30 - 11:30 1.00 RUNCO 11:30 - 13:00 1.50 RUNCO 13:00 - 13:30 0.50 RUNCO 13:30 - 16:00 2.50 RUNCO 16:00 - 17:30 1.50 WHSUR P Spud Date: 6/22/1995 Start: 10/15/2007 End: 10/24/2007 Rig Release: 10/24/2007 Rig Number: Phase Description of Operations RUNCMP Torque dumped at 4440 psi with Torque Tum Equipment. Average Running Speed- 25 Jointsl Hr. RUNCMP P/U and RIH with 4-1/2", 12.6#, 13Cr-80 Vam Top Comp{etion. Jet Lube Seal Guard used on Threads. Average make up Torque dumped at 4440 psi with Torque Turn Equipment. Average Running Speed- 25 Joints/ Hr. RIH with 223 joints of 4-1/2" Tubing. L/D one Joint damaged when Slip Segment broke from Slips and fell into Rotary Table Bowl and wedging agains Tubing Joint #118. Joint was replaced with new joint of the same length. RUNCMP Obtain Parameters: Down Weight= 115,000 Ibs; Up Weight= 148,000 Ibs; Pump Rate at 1 bpm and 30 psi. RUNCMP Tagged top of stub at 9,556'. Washed over at 1 bpm with 30 psi. Shear bottom pins at 9,560' with 11,000 Ibs to shear. Sheared top pins at 9,568' with 5,000 Ibs to shear, No Go out at 9,570'. Re-confirmed depths, L/D joint #222. No Space Out Pups Required. This was the first time we used the new design of the Unique Over Shot with the double shear pins it gives you positive indications of depths and Reduce Pipe handling in the space out process. This is a good design in terms of performance and safety. RUNCMP P/U M/U Landing joint and Tubing Hanger. R/U circulating equipment to pump packer fluid. RUNCMP Reverse Circulate 150 bbls of 140 deg Seawater at 3 bpm with 120 psi. Reverse Circulate 250 Bbls of Inhibited Seawater at 3 BPM and 120 psi. RUNCMP RIH and land Tubing Hanger. P/U = 118,000 Ibs (w/o block weight). S/O = 75,000 Ibs (w/o block weight). RILDS. RUNCMP Drop Ball and Rod. Wait 15 minutes. Pressure uo on Tubing to 3500 psi. Packer set at 1750 psi. Pressure Test Tubing to 3500 si. Hold test for 30 charted minutes, good test. Bleed Tubing pressure to 1500 psi and hold. Pressure test IA to 3500 si. Hold test for 30 charted minutes, good test. Bleed Tubing pressure to 0 psi and shear DGK valve. Circulate at 3 BPM and 900 psi and see returns. Reverse Circulate at 3 BPM and 60 psi and see returns. RUNCMP L/D Landing Joint. Dry Rod TWC in. Pressure Test TWC from above to 3500 psi for 10 minutes and chart. Attempt to P/T to 1000 psi from below. TWC is severely leaking. Call DSM for 17:30 - 19:00 I 1.501 WHSUR I P 19:00 - 20:00 I 1.001 WHSUR I P RUNCMP P/U and install DSM Lubricator Extension. DSM arrived on location @ 18:00 hrs. P/U DSM Lubricator and Tools. R/U Lubricator and test to 500 psi, good test. Pull TWC and examine for damage. No visible damage. Install new TWC. RUNCMP Test TWC to 3500 psi from above and hold for 10 charted 20:00 - 22:30 I 2.501 WHSUR I P 22:30 - 00:00 I 1.501 WHSUR I P 110(24/2007 100:00 - 01:00 I 1.001 WHSUR 4 P e minutes, good test. R/D DSM Lubricator and Tools. RUNCMP Blow down circuiting lines. Suck out BOP Stack, Riser, and Flow Lines. Break out Annular Preventer Cap. N/D BOPE, stand back and secure. RUNCMP Inspect Wellhead and Tubing Hanger. Prep Tubing Head for Adapter Flange and Tree. Install Adapter Flange and Tree. RUNCMP N/U Adapter Fange and Tree. Printed: 11/12/2007 4:55:53 PM • • BP EXPLORATION.' Page 7 of 7 Operations Summary Report Legal Well Name: 18-30 Common Well Name: 18-30 Spud Date: 6/22/1995 Event Name: WORKOVER Start: 10/15/2007 End: 10/24/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/24/2007 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/24/2007 01:00 - 05:30 4.50 WHSUR P RUNCMP R/U FMC Test Equipment. Test Adapter Flange Neck Seal to 5000 psi. Hold Test for 30 Minutes, good test. RID FMC Testing Equipment. WU and Test Tree to 5000 psi. Hold Test for 30 Charted Minutes, good test. Tests witnessed by BPX WSL. RiD Test Equipment. 05:30 - 06:00 0.50 WHSUR P RUNCMP P/U DSM Lubricator and Equipment. Pressure Test Lubricator to 500 psi. Putl TWC. 06:00 - 10:00 4.00 WHSUR P RUNCMP R/U LRHOS and pump 100 Bbls of Diesel down IA. U-Tube to Tubing for 1-hr. R/D LRS. Break Circulation Lines. 10:00 - 13:00 3.00 WHSUR P RUNCMP Set BPV and test to 1000 psi. Secure Tree and Cellar. Release Rig @ 1300- hrs. Printed: 11/12/2007 4:55:53 PM TREE= 4-1/16 CM! WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 53.5' BF. ELEV = _? KOP = 1876' Max Angle = 97 @ 11838' Datum MD = N1A Datum N D = 8800' SS 10-314" CSC, 45.5#, NT-80 BTC, ID = 9.953" I~ 3930' Minimum ID = 3.725" @ 9629' 4-1/2" HES XN NIPPLE 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 4-112" TBG STUB f 10(23!071 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" i TOP OF 5-1/2" LNR 7-5/8" CSC, 29.7#, USS S-95 BUTT-M, ID = 6.875" I 9547' I PERFORATION SUMMARY REF LOG: BHCA ON 07!15(95 ANGLEATTOPPERF: 83° @ 10620' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10620 - 11430 C 07/23/95 3-318" 4 11840 - 11900 O 08/23/96 3-3/8" 4 11940 - 12090 O 08/23/96 3-3/8" 4 12160 - 12250 O 08!23!96 5-1/2" LNR, 17#, L-80 BTGM, 12621' .0232 bpf, ID = 4.892" NOTES: **4-112" CHROME TBt~`* 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3504 3316 35 KG82 DOME BK 16 10!31/07 2 6003 5252 40 KG62 SO BK 20 10/31/07 1 8001 6797 39 KG62 DMY BK 0 10/23/07 4-112" HES X NIP, ID = 3.813" 7-5i8" X 4-112" BKR S-3 PKR, ID = 3.875" 4-112" HES X N1P, ID = 3.813" 7-5/8"X4-1/2"UNIQUEOVERSHOT 7-5/8" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES XN NIP, ID = 3.725" 9650' ~4-1/2" WLEG,ID=3.958"~ ELMD TT NOT LOGGED g7(~' 7' TIEBACK SLV, ID = 5.75" 9711' --~7-5/8" X 5-1/2" BKR HPLPO LTP w /HMC HGR, ID = 4.892" 11500' I-I IBP (SET 08!23!96) DATE REV BY COMMENTS DATE REV BY COMMENTS 07/28/95 D-9 ORIGINAL COMPLETION 10/25/07 D-16 RWO 11(01(07 AJW/PJG DRLG DRAFT CORRECTIONS 11/17/07 GS/PJC GLV GO (10/31/07) PRUDHOE BAY UNIT WELL 18-30 PERMfT No: 1950910 API No: 50-029-22568-00 SEC 24, T11 N, R14E 4421.86' FEL & 770.6' FNL BP F~cpioration (Alaska) 18-30 RECEiVED 3c,5O, \ r oq \ \C\j / SCANNED JUN 2 :3 2006 Schlumbel'gel' ,JLN 2 3 Z006 Alaska Data & Consulting Services . 2525 Gambell Street, Suite 400 ~ CH q, Gas C(.-flS. CcmmlSStCfl Anchorage, AK 99503-2838 A..nchCrage ATTN: Beth Well Job # Log Description Date 07-18 9153238 LDL 01/31/03 C-04A 10649975 SBHP SURVEY 06/26/03 N-11 C 10980595 PRODUCTION PROFILE 08/09/05 MPF-89 11084328 SCMT 11/24/05 D-10 10913021 MUL TI-FINGER CALIPER 06/02/05 NGI-09 11212860 USIT OS/23/06 MPH-09 11211412 US IT OS/28/06 MPH-15 11076486 CH EDIT PDC-GR OF USIT 12/15/05 MPS-90 11162721 CH EDIT PDC-GR OF US IT 11/27/05 AGI-07A 11212865 CH EDIT PDC-GR OF USIT OS/28/06 15-20C 11075906 MCNL 08/12/05 18-30 11209593 MCNL 03/25/06 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 clt-- \~ 06/20/06 NO. 3854 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 Color CD --- 1 1 1 1 Prints sent earlier Prints sent earlier 1 1 1 .o-- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Date: September 12, 2005 To: File From: Jane Williamson ~~%~'~ Subject: Prudhoe Well 18-30 Long Term SI ~~6~ ~ 1a Prudhoe well 18-30 has TxIA communication and the well no longer passes BP's internal waiver requirements. Attached are plots of production history and decline analysis for the subject well. DS 18- 30 produced between 250 to 750 BOPD at a GOR over 50,000 scf/STB. Backing out for the high GOR, the estimated production limit for the well is about 340 BOPD. Remaining reserves are less than 60 MSTB. At this GOR, nearly all the production is condensate. The well has little utilization with its current completion. No action is necessary. to-3o PRUDHOE BAY, PRUDHOE OIL a~ ai Rate Icol I Dtbbua 1 PBU DS18 ~~ watetRatalcol(mtbelm' pRUDHOEBAY ~~. G.a Rata icol(nn.crra 1 10~ ~ cem an araa (nlDeei 1 18-30 Gas /Oil Ratio (McllbDl 1 ' W~ate~r Cut 101 ! ~^ ~~f~~tW~G SE'F 2 12005 .r ~ o ~ 10 • 101 10' 10 104 1995 96 9l 96 99 2000 01 02 Ol 04 OS Date • 8 ._ •~ ~ E'3 J a a ~~ 0 =~ ~ a a~~~~~~~~~ ~ ~(~~~(p~p~p(~p~~j~MM~(My~ y~N~y ~~00~~~MMM~~3~LL ........ ..................... ~~ ~~ ~ ~~~~ . .._ ~, y~ 2!S ~ 8 18-30 (PTD #1950910) Internal Waiver Cancellation ) ) 'Ç,~q Q(tt(05' Subject: 18-30 (PTD #1950910) Internal Waiver Cancellation From: "Reeves, Donald F" <ReevesDf@bp.com> Date: Mon, 29 Aug 2005 14:54:54 -0800 To: "AOGCC Jim Regg (E~mail)" <jim~regg@admin.state.ak.us>, "AOGCC Winton Aubert (E~mail)" <winton _ aubert@admin.state.ak.us> CC: I'NSU, ADW Well IntegrityEngineer" <NSU.ApWWelllntegrityEngineer@bp.com?,,"Hughes, ! Andrea (VECQ)U <hugha4@bp.eom>, ItLuckett,Ely Z. (VECO)"<luckez@bp~com>, ItDube,Anna T", . ' <Anna.Dube@bp.com> Jim and Winton, The internal BP waiver for TxlA communication on well 18-30 (PTO #1950910) has been cancelled. The well no longer passes waiver requirements. The well will be secured and is classified as a trouble well. /' Although there are no plans for repair at this time due to being uneconomic, the well will be evaluated for future utility. Please let me know if you have any questions. «18-30.pdf» Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907 -659-51 02 907-659-5100 #1154 pgr (C(¡"" ¡I Ii ,~~ijlJ.::[1 \)~:..,J4~,p~o't\C: i <) ~i1 C) 0 r¡ í;:' {~1 .,~ (~J ¡JJ i Content-Description: 18-30.pdf 18-30.pdf Content-Type: application/octet-stream ¡j Content-Encoding: base64 .".." 1 of 1 9/9/2005 2:46 PM ) ) lREE= WELLHEA D = 'A'CTiJÄt'ÓR";;; KB. 8..EV = BF. REV = KOP= rv'Iax Angle = Datum IVID = Datum 1V 0 = 4-1/16 CMf CMf ....BÄk'ERC' 53.5' ? 1876' 97 @ 11838' N'A ......8800'SS 18-30 SAFETY NOTES: ***TxIACOMM. OPERATING LIMITS: MAX lAP = 2500 PSI, MAX OAP = 1000 PSI (03/30/03 WAlVER)*** - 2198' 1-i4-1/2"CAMCOlRCF-4ASSSVNIP,10=3.812" I 10-3/4" CSG, 45.5#, NT-80, D = 9.953" 1-1 3930' ~ ~ Minimum ID = 3.725" @ 9629' 4-1/2" HES XN NIPPLE L GAS LIFT MANDRELS ST 1\1[) TVO OBI TYPE VLV LATCH PORT Dð, 1E 1 3965 3686 37 CA.-KBMG BK 2 7224 6197 39 CA.-KBMG BK 3 9485 7995 38 CA.-KBMG BK :8: ~ 9604' 1-17-5/8" X 4-1/2" BAKER SABL-3 A<R, 10 = 3.875" I I 9629' 1-1 4-1/2" HES XN NIP, 10 = 3.725" I I TOP OF 5-1/2" LNR H 9704' I------. 7-5/8" CSG, 29.7#, 5-95,10= 6.875" H 9857' ~ 9649' Ii 4-1/2" TUBING TAIL WLEG, 10 = 3.958" l-i ELMO TT NOT LOGGEO I 14-1/2"TBG, 12.6#, L-80, .0152 bpf, 10 =3.958" H 9649' . .. PERFORATION SUIVMARY REF LOG: BHCA. ON 07/15/95 ANGLEATTOP ÆRF: 83 @ 10620' Note: Refer to Production OB for historcal perf data SIZE SPF INTERV AL Opn/Sqz OA 1E 3-3/8" 4 10620 - 11430 0 07/23/95 3-3/8" 4 11840 - 11900 C 08/23/96 3-3/8" 4 11940 - 12090 C 08/23/96 3-3/8" 4 12160 - 12250 C 08/23/96 ~ 11500' H IBP(SETOB/23/96) I I PBTO H 11881' I 5-1/2" LNR,17#, L-80, .0232 bpf. 10= 4.892" 1-1 12621' Oð.1E REV BY COMWENTS 07/27/95 ORIGINAL COMPlET'ION 05118/01 RN/KAK CORRECllONS 06115/03 CMOIllP KB ELEVATION CORRECTION 09/03103 KCIllH WArvER SAFETY NOTE 09/13103 CMOIllP OATLM tv[) CORRECTION OA TE REV BY COMWENTS PRUOHOEBAY UNIT WELL: 18-30 PERMT No: 1950910 API No: 50-029-22568-00 sæ 24, T11N, R14E, 4421.86' FEL & 770.6' FNL 8P Exploration (Alaska) (' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD SuspendD Operation ShutdownD Perforate D WaiverD OtherD Alter CasingD Repair WellŒJ Plug PerforationsD Stimulate D Time Extension 0 Change Approved ProgramD Pull TubingD Perforate New PoolD Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 195-0910 Development I]] ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-22568-00-00 7. KB Elevation (ft): 9. Well Name and Number: 53.45 18-30 8. Property Designation: 10. Field/Pool(s): ADL-028326 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 12621 feet true vertical 8731.3 feet Plugs (measured) 11531 Effective Depth measured 11531 feet Junk (measured) None true vertical 8778.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 37 - 117 37.0 - 117.0 1490 470 Liner 2917 5-1/2" 17# L-80 9704 - 12621 8171.0 - 8731.3 7740 6820 Production 9822 7-5/8" 29.7# S-95 35 - 9857 35.0 - 8294.2 8180 5120 Surface 3894 10-314" 45.5# NT-80 36 - 3930 36.0 - 3657.7 5210 2480 Perforation decth: Measured depth: 10620 -11430 True vertical depth: 8762.93 - 8775.5 R E C E 'VE D Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 31 - 9650 JAN 2 0 2004 Packers & SSSV (type & measured depth): 4-1/2" Baker SABL-3 Packer @ 9604 Alaska Oil & G Cr' .. 4-1/2" TRCF-4A SSV @ 2198 as DOS. uOmmlSSIOn 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubing Pressure Prior to well operation: 1127 39.2 0 1340 1067 Subsequent to operation: 1106 27.8 0 1350 1091 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ) ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D Oil I]] GasD WAG D GINJD WINJD WDSPLD Daily Report of Well Operations. ! Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Garry Catron NI A Printed Name Garry Catron Title Production Technical Assistant Signature" Date 1/15/04 ", " ,,', ' .' ç: 1 iUDtt tKìroW.~ J}~~ ~ ' Form 10-404 Revised 12/2~t;ANNE[} JAM 2 1 200/~ ( t 18-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/25/03 T/I/O = 2320/1340/650. OA Downsqueeze. (Waiver Eval). MIRU DS. PJSM. PT lines to 3500 psi. Started down OA with 2 bbls of DS CW 101 surfactant. Followed up with 200 bbls of freshwater 15 bbls of CW 5 bbls of freshwater and 20 bbls of 15.7 ppg Arctic Set 1 cement with 1/4# per sack of celloflake. Displaced cement to shoe with 100 bbls of crude at 6 bpm, slowed rate to 1 bpm for 15 bbls then to .5 bpm for 5 addional bbls. OAP increased from 750 psi to 800 psi. SD and monitored OAP for 10 min. OAP dropped off to 580 psi. SI well and RD. OAP dropped to 460 psi during RD. Final WHP's = 2320/1340/460. 08/25/03 T/I/O/=2300/ 1300 /350 Pump 104 bbls crude @ 3bbls min. 1200 p.s.i. for injectivity test. Final T/I/O/= 2300/1350 880 08/27/03 T/I/O= 2320/1320/0 ---MIT OA to 3000 psi--PASSED---Lost 200 psi first 15 minI Bumped up/ Lost 120 psi in 15 min and total loss of 170 psi in 30 min --- {Post OA Cement Sqz)---Final WHP's=2320/1320/0 FLUIDS PUMPED BBLS 215 Fresh Water 142 Crude 35 DS CW 101 20 15.7# pg Arctic Set 1 cement with 1/4# per sack celloflake 55 TOTAL Page 1 ~ ( ( 1REE= 4-1/16 OW SAFETY NOTES' ***TxIACOMM. OPERATING WELLHEAD = OW 18 30 . ACTUATOR = BAKERC - LIMITS: MAX lAP = 2500 PSI, MAX OAP= 1000 KB. ElEV = 53.5' PSI (03/30/03 WAlVER)*** BF. ElEV = ? KOP = 1876' Max Angle = 97@ 11838' 4-1/2" CAMOO1RCF-4A SSSV NIP, 10=3.812" Datum tv[) = N/A &i.I1\ Datum 1V 0 = 8800' SS ... 10-3/4" CSG. 45.5#. Nr-80, D = 9.953" GAS LIFT MANDRELS ST MD TVO DEV TYPE VLV LATCH PORT DA1E 1 3965 3686 37 CA.-KBM3 BK Minimum ID = 3.725" @ 9629' 2 7224 6197 39 CA.-KBM3 BK 4-1/2" HES XN NIPPLE 3 9485 7995 38 CA.-KBM3 BK 9604' 7-5/8" x 4-1/2" BAKER SABL-3 R<R, 10 = 3.875" 9629' -i 4-1/2" HES XN NIP, 10 = 3.725" I 4-1/2" TBG, 12.6#, L-80, .0152 bpf. 10 = 3.958" 4-1/2" TUBING TAIL WLEG, 10 = 3.958" I l-i ELMO TT NOT LOGGED I TOP OF 5-1/2" LNR 7 -5/8" CSG, 29.7#, S-95, 10 = 6.875" PERFORATION SUMMARY REF LOG: BHCA. ON 07/15/95 ANGLEATTOPÆRF: 83 @ 10620' Note: Refer to Produetion OB for historical perf data SIZE SPF INTERV AL Opn/Sqz, DA 1E 3-3/8" 4 10620 - 11430 0 07/23/95 3-3/8" 4 11840 - 11900 C 08123/96 3-3/8" 4 11940 - 12090 C 08123/96 3-3/8" 4 12160 - 12250 C 08123/96 11881' I 5-1/2" LNR, 17#, L-80, .0232 bpf. 10 = 4.892" I DA 1E REV BY COMMENTS DATE REV BY OOMMENTS PRUOHOEBAY UNIT 07/27/95 ORIGINAL COMPLETION WELL: 18-30 05/18/01 RN/KAK CORRECllONS PERMIT t\b: 1950910 06115/03 CMO/TLP KB ELEV A TION OORRECfION API t\b: 50-029-22568-00 09/03/03 KC/TLH WAIVER SAFETY NOTE SEe 24, T11N, R14E, 4421.86' FEL & 770.6' FNL 09/13/03 CMO/TLP DATUM MD OORRECfION BP Exploration (Alaska) TREE= 4-1/16 CIVV 18 30 I ACTUATOR=- BAKER C '= SAFETY NOTES KB. ELEV = 53' BF. ELEV = ? KOP= 1876' MaxAngle= 97@ 11838'~____~ 2198' H 4-1/2" CAMCO TRCF-4A SSSV NIP, ID=3.812" Datum IVD = 12799' i Datum TVD= 8800'SS , , I ~o-~,,,~,4~.~#,~,~o,~=o.o~,, H ~3o' GAS LIFT MANDRELS STA MD TVD DEV TYPE MAN 1 LATCH ~-.~-- r-~ ~ 3965 ~ 37 CA-KBMG BK 2 7224 39 CA-KBMG BK 3 9485 7995 38 CA-KBMG BK MinimumID= 3.725"@0529' :~ ~-----~ ~04' Id 7-S18"X4-1/2'BAKERSABL-3PKR, D=3.875" 4-112" HE$ XN NIPPI_£ ' I TC~OFS-1/2"LNR ~ ,?oa' I~ I 7.~/8,, CSG, ~.7#, s-95, ~D = 6.875" I--I ,857' I--~ · PI~FORATION SUMM~ RY i I:~F LOG: BHC~ on 07/15/95 [1 Note: Refer to R'odu¢~ion DB for historical perf data SIZE SPF INTERVAL Opn/SqzI DATE ' 3-3/8" 4 10620-11430 O I 07/23/95 3-3/8' 4 11840-11900 C 08/23/96 ~-~,~, ~ ~4o-~o~o o o~,~,~ ~4~ I .soo' H 3-3/8' 4 12160-12250 C 08/23/96 I I 5-1/2"LNR, 17#,L-80,0.0232bpf, ID=4.S92" H 12621' ~ DATE REV BY COMMENTS DATE REV BY COMIVIENTS PRUDHOEBAY UNIT 07/27/95 ORIGINAL COIVPLETION WELL: 18-30 01/10/01 SIS-Isl CONVERTED TO CANVAS PERMIT No: 95-091 02/22/01 SIS-LG REVISION .... APl No:., 5O-029-22568-00 05/18/01' ?I~I/K"~-K CORRECTION~ ' Sec. 24, Tll N, R14E, 4421.86 FEL 770.6 FNL BP Exploration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10620-11430 O 07/23/95 3-3/8' 4 11840-11900 C 08/23/96 3-3/8' 4 11940-12090 C 08/23/96 3-3/8' 4 12160-12250 C 08/23/96 DATE REV BY COMMENTS DATE REV BY COIVIV1ENTS 07/27/95 ORIGINAL COIVPLETION 01/10/01 SIS-Isl CONVERTED TO CANVAS 02/22/01 SIS-LC REVISION ~ 05/18/01' ?I~I/K"~-K CORRECTION~ ' ANNULAR INJECTION -. DATA ENTRY SCREEN Asset .E.O~ ........................................... Rig Name D.Q~g.[1..~. .................................... Inj Well Name .1..8.:.3.0 .......................................... Legal Desc .I..~.9.9.'.8.biI~.~.6.'.YV..EI~.8.{~.C..3.4.,.'['.I.I.bI.,.E:I.dE ....................................... Research Permit Start ........ .-'{~.~[.~.~ ........ Permit End .......].~/.:~.1/.~.~. ....... Sur Csg Dep 3.9.:~.0. ................ Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ctg Wash Fluids Fluids Freeze Freeze ........... .¢.~..' ......... Dai y Data Intmwaalz I FI'al Fom'alion Freeze Freeze Daly FUds F'mleclim ~ Tolal 216 720 130 90 Soulce Daleof Well Injeclion 8-30 07/11/95 8-30 07/12/95 8-30 07/16/95 8-30 07/18/95 216 720 RigWash 130 9O 18-30 ,07/27/95 .... 150 150 ....................................................... i ......................................................... i .......................................................... 1 .......... : .................................................. 1 .................................................. 1 ................................................. 1 ................ ................................... i .................................................. i , i Open 1995 Year End Summary ......................... ~-~-~--~..~...~.:~ ............................. ~ ........................ 5 bmp @ 900 psi Dry Crude ared rvices rilling Alaska December 14, 1998 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. AnchOrage, AK 99501-3192 Re: Annular Disposal Information Request RECEIVED DEC 14 1.998 Dear Ms. Mahan: Naska Oil & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through preSent time. We compared your list with our records and are able to provide yOu with the following data: · Individual Annular DiSposal Logs from the SSD database Which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are proVided to you in the same order as listed on your log. · There were some Wells on your list which were not injected into. These wells are identified as follows: Endicott wells 1-03/P-16, 1:65/N-25, 1-59/0-24 · EXploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1,. L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry ' Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: ,_Annular Disposal Letter 12/14/98 ! Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 EXploration well Sourdouch #3 - ~oo ~4 ,~ - - Mi~e Point wells F-06, H-05, H-06, J-13, L-24 - PBU wells'18~30, 18-31, 14~,~-43, E-34, E-36, G-~A, ~d S-33' ~dividu~ logs ~e provided to you for t~ese ~ogs ~ we~l. . · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be-of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED --- ;-.,- !4 AJaska Oil & ~as Co.s. Ar, ot~orage I ' · har(.:d SerVice Dlilling nndlar Injection Volumes ~ly 25, 199~ until December 1998 umulative Report surface casing InjWell ' . Depth .." Cum Mud I Legal Desc Cum Total & Ctgs dicott i/on 15 1-19/I-18 5000 Sec. 36, T12N, R16E 8,960 7,848 ~/on 15 1-23/O-15 4246 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 30,604 Cum Rig CumCompl Cum Form Cumlnterm Cum Final Disposal Period Annulus Wash Fluids Fluids Freeze Freeze Start . . End . S!atus , 992 120 12/5/95 12/5/96 Open 1,160 200 120 9/30/95 12/31/95 Open 150 8/31/95 12/31/95 Broached /on !5 1-33/M-23 5013 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9,729 /on 15 1-61/Q-20 4236 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 2,613 1,176 60 12/5/95 12/5/96 Open , 1,063 /on' 15 2-40/S-22 4531 2020'FNL, 2289'FEL, Sec 36,T12N, R16E 31,195 29,952 120 60 7/25/95 12/31/95 Open A ~on 14 15-47 3515 3648'NSL, 4956'WEL Sec 22 TllN, R14E 3,002 903 2 009 ' 90 11/7/95 12/31/95 . . Open ton 14 DS 15-45 3829 4749' NSL, 5180' WEL, Sec. 22, T11N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached ton 14 DS 15-48 3548 Sec 22, T11N, R14E 3,385 216 820 2 283 66 12/21/95 12/21/96 Open ,on 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 O )en ,on 9 18-30 3930 1499'SNL 26'WEL Sec 24 T11N R14E 2 266 936 380 800 150 7/25/95 12/31/95 O)en 'on 9 18-31 3680 3719'NSL 64'WEL Sec 24 T11N R14E 6 086 2 250 1 100 2 565 171 7/26/95 12/31/95 O ~en 'on 9 18-32 3830 3632'NSL 41'WEL Sec 24 T11N R14E 3 311 1 861 200 1 100 150 8/24/95 12/31/95 O~en 'on 9 18-33 4140 3690'NSL, 56'WEL, Sec 24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 O~en ,ors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 O3en ors 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1 871 120 10/13/95 12/31/95 O~en ors 18E 13-36 3431 1585'NSL 5187'WEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open ors 18E 14-44 3288 ' 2829'NSL 1617'WEL Sec 9T10N R14E 3 974 2,319 1,535 120 8/17/95 12/31/95. Open ,loration 14 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed le E MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR11E 19,608 18,538 285 685 100 4/18/96 4/18/97 Open ~)rs 22E MPC-23 4941 1038 NSL 2404 WEL Sec 10 T13N 2,060 1 800 130 130 1/25/96 1/25/97 Open ............................................................................................................................................................. .'. ..................... .'. .................... '_' .... '_L" ................. ~ ...................................................................................................................................................................................................... .3..r.s__2~.E" ............... _.M_P__C......2..5. ...................... 85_._9~_ ............... l_14_3'_FN_I:,_24.3_6'F_W_L:_,?_~c__~ 0_,.T- 13N, R10E .......1.,9~0.5.5_ ........ 2.,_465. 300 140 1/5/96 1/5/97 Open 3rs 22E MPC-26 4704 1086 NSL 2419 WEL Sec 10 T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open 3rs 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page 1 ,DEC 1 1998 ;na,,r~cl oervice Drilling ~,nn~i'ar InjeCtion Volumes luly 25, 199S until December 1998 ;umulative Report Sudace Casing ig Inj Well Depth abors 22E MPF-06 8766 · , abors 22E MPF-14 6690 abors 22E MPF-70 7919 , abors 22E MPH-05 5335 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze ..... I~reeze Start End status Sec 06,T13N, R 10E 1,927 1,731. 196 1/25/96 1/25/97 Open Sec'06,T13N, R10E UM 18,717 17,107 1,270 340' 6/3/96 6/3/97 Open ' 2189'NSL, 2591'WEL, SeC 6,T13N, R10E 19,775 18,794 735 190 56 6/17/96 6/17/97 Open 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 . 382 190 8/19/95 12/31/95 Open abors22E.' MI~H-06 . 7304 . 2824;NSL, 4044'WEL, Sec 34,T13N, R10E 8,515 . 8,335 180 8/5/95 ...... !2!?.!!.9.~ ............ O...p.~ ....... ~bors 22E MPI-07 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1 280 250 80 ' 70 9/21/95 12/31/95 Open ~bors 22E MPJ-13 2835 2319'NSL, 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10/17/95 12/31/95 O3en ~bors 22E MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 O3en ~bors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 . 1/25/96 1/25/97 O)en ~bors 27E MPF-22 8841 Sec 06,T13N, R10E UM 6,536 6,466 . 70 12/12/95 12/12/96 O)en . ~bors 27E MPF-25 3405 1857'NSL, 2696'WEL, Sec 6,T13N, R 10E ' 9 89'7 9 357 250 225 65 12/26/95 12/26/96 O )en ~bors 27E' MPF-37 6621 1931'NSL 2643'WEL Sec 6 T13N R10E 7 032 6 887 70 75 7/25/95 12/31/95 O)en ~borS 27E MPF-38 8561 1994'NSL 2731'WEL Sec 6,T13N R10E 9 232 9,157 75 i2/6/95 12/31/95 O ................................................ ! ............................................ ~ ................................................. .'. ............................................................. .....'. .................................................................................... : ......................................................................................................................... ...................................................................................................................................................................................................................... ~bors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 O )eh lbors 27E MPF~53 6750 2028'NSL 2572'WEL, Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 O )eh ibors 27E MPF-61 6585 2077'NSL, 526'WELl Sec 31,T14N, R10E 5,732 5,657 75 8/31/95 12/31/95 O ibors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 O ~bors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 91665 · 75 8/31/95 12/31/95 O )en ~bors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open E F-36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 ' 1,998 1,359 3,471 135 12/18/95 12/18/96 Open ,yon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1,035 140 i/31/96 1/31/97 Open ,yon 9 D-31 3215 SEC. 26, T11N, R13E 150 150 4/20/96 4/10/97 Open ,yon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open bors 18E S-43 3121' 421 l'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 · 5/7/98 OPEN Page 2 Shared sei~ice Dr. illing Ann'bi~'r ~njection Volumes July 25, 1995. until December 1998 Cumulative Report surface casing :ug Inj Well Depth ~labOrs 28E B-33 3504' ~labors 28E E-34 3664 , ~labors 28E E-36 3648 ., ' ' Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Legal Desc Cum 'TOte! & Ctgs Wash Fluids' Fluids Freeze Freeze Start End. status 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 857 195 80 5/1/96 12/31/96 Broached 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 858 40 110 8/23/95 12/31/95 Open 1706'SNL, 822'WEL, Sec 6,T11N, R14E 9,271 4,417 1,293 3,096 365 100 7/25/95 12/31/95 Open 4..a..b..o.?. 2..8..E' ............. ..E.~.?...7. ............... _3.81___0~ .................... .3. 3_9_1 '.__N__~_S L ,,881'w.__E L,....S_ .e_c.. _6.,. _T 11___ .N.L.R. 1._4 E_~._- 4,695 4,241 374 80 9/16/95 12/31/95 Open ~abors 28E E-39 3638 3358'NSL, 501'WEL, Sec 6,.T11N, R14E 2,250 928 220 1,022 .80 8/28/95 12/31/95 Open Jab'ors 28E G-O4A 3509 2917'NSL, 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1,824 2,315 10/20/95 12/31/95 Open !abO~S?~.E ............. ,.G,,:~,! ............................... .3.,? ....................... .2.(9.!..!..'.U.S,.~,..,2~,~,,8,.LW,,.E.~,...S.,e.?.J,.?,..!U~,.R,!.~,E. ......................... !_!,.,.~.3..0. ................................. ,3..,.(9.,5.~ .......................... ~,.o.?_2.. ......................... _,~,?.?_ ................................................................................. ~,o,, ....................................... ?, .............. ,9,!,!(9..~ ...................... ?!3,,?~ .......................... .,O,,,p,?? ................. labors ~.8..E, ...... S.'.2.4 ........................ .2.,7..57 ........... ! 6337...N.17.~..4..2..2..8; .W.E..t:.,... ~?C...3..5.,..T..!..~1~.'....~..!.~ .......................... .2..0...'...26...1. ............................ ! .! ,..'~.7...3. ............... .2..,..!...7.7 ......................... .575..! ~.~5. .......................... 285 .... !2/9!(95 ......... 12!9!(9.6.. ............................ O.p..~n. ............... labors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, .R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open labors 28E S-41 3331 4152' NSL, 4504' WEL, Sec 35,T12N, 8,062 4,159 2,034 1,754 115 2/8/96 2/8/97 Open ........................... ' .......................................................................... :,, ,..,: : ........................................... ~ ........................ i .................................................................................................................................................................... .......................................................................................................................................................................................................... : ........................ labors 28E S-42 3077 Sec 35 T12N, R12E 168 100 68 3/13/96 3/13/97 Open labors 2ES H-35 3157 4535'NSL, 1266'WEL Sec 21,T11N, R13E 4,860 3,725 555 480 20 80 10/26/95 ' 12/31/95 Open ~,a?,.,2,,,E..S., ............... ,H,:.3.~ .................................... ~.,5.,5,,.0, ............................... ,~,~?,,S,.,L,.,.,,,!.~?,,.E,,,L,,~,.,,~,e.~,.,~,!,,,,,T!?,~,,.,~,!,,,3,,,,E, ............................... !,:~5,2,, .......................................... ,8.,,,5,.7,, ........................................ !.0~ ...................................... ,?, ............................................................................................................................................... ,,8,,,5,. ............. !?/~!(97 ..................... !,,2!,3,75, ............................ ,,o?q ............... Page 3 Al h red riJlljng- TO: FROM: DATE: SUBJECT: APl # Blair Wondzell Chris West October 27, 1995 MPB-24 Well Suspension 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I maY be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 .... 95 .... 09 I 6 ? 7 S 9 .r.-..-i ...... 09 i B t..I C/' A C / ,S R 95 ...... 09i CNL/GR 9..5 ..... 091 Si;STVD 95"-~091 STAT F'RESS 95---09 i 7268 95~-091 '? 150 95 ...... 09 I U'R?' (30 BI P I... E T I 0 N P A T E ? / ,26 / ? O/' /~/'¢¢,/' D A Z 1. Y ~,,:,t E L.L.. 0 P E; '~'/F,: '7/Ca / ¢(5/ Ar'e dr"y d'~t;ch sarnples r'equ~r'ed? yes Was 'Ehe well cot"ed? yes Ar'.e well 'Ees!.:s r'equ~r'ed? j yes '¢1e'11 ~s 'in compliance .~~ I n '~ !: 'i a i TO ?/'A ~" CJ? ~A n d r" e c e 'i v e d ":' C 0 M H E N T S __________An a i y s '¥ s & d e s c r' '[ p 't: ')' o i", r" e c e "¢ v e d ? GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10405 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 9/18/96 Field: Prudhoe Bay Well Job # Log Description Date BL RF Sepia Anadrill Survey Calculation Anadrill Program Anadrill Performance Letter D.S. 15-26 ' ' TDTP BORAX 9 6 0 80 4 I 1 D.S. 15-43 TDTP BORAX 960806 1 1 ,., D.S. 15-42 TDTP BORAX 960512 I 1 !D.S. 15-48 TDTP BORAX 960805 I 1 ........... =D.S. 18-30 TDTP BORAX 960514 1 I ~>,-'-.r ...... il ....... .. ~I~ i.~.~ ~. ~' ~iiE'"" ..... i'~ Floppy Disk SIGNED: ~__~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10290 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 7/1 7/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk / Calculation Letter 'b?~lD.S. 11-16 ST1 ,/ 96184 CNTD 960605 ~)/ul? 1 qt D..S. 18-30 96148 DUAL BURST TDT-P (BORAX) 960514 ~/'~-O 1 '3~ D.S. 5-5A '~.~-,-~ ~/~',~'96166 DUAL BURST TDT-P (BORAX) 960520 7[~ 1 .11~D.S. 2-3A ~? 96174 DUAL BURST TDT-P (BORAX) 960601 ?./c/~ 1 ~,~ D.S. 1-04 ,,,× PERFORATING RECORD 960613 I 1 -,~ ~).S. 1-5 ST1 ~,/ PRODUCTION PROFILE W/DEFT 960620 I 1 i~;~D.S. 1-24A ~ / PRODUCTION PROFILE W/DEFT 960619 I I ..' / r~ D.S. 2-9 ~, PACKOFF GASLIFT MANDREL 96061 8 I 1 ,'}.?.~ D.S. 3-28 ~-' PRODUCTION PROFILE W/DEFT 960618 I 1 D.S. 4-19 ,-~ STATIC TEMP/PRESS LOG 960613 I 1 i-~,~ D.S. 4-19 ~, ~ PERFORATING'RECORD 960613 I 1 D.S. 4-19 ~ ~' DUAL BURST TDT-P BORAX 960613 I 1 L(}~D.S. 13-5 ~, ~ PRODUCTION PROFILE W/DEFT 960620 I 1 J~'?D.S. 13-15 = ~ LEAK DETECTION LOG 960618 I 1 .' -- .~l D.S. 14-16 ~ ~ LEAK DETECTION LOG 960615 I 1 -I1~D.S. 14-31 ,.,, j LEAK DETECTION LOG 96061 5 I 1 .1¢[7 D.S. 7-6A ~' 96167 DUAL BURST TDT-P (BORAX) 960515 -?/c//(',~ 1 '1 ............. R ,., .IVED Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. JUL 1 9 199G Alaska0il &GasC0ns. Anchorage ~ALASKAO ._~..-.hea red trices .rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: June 4, 1996 From: Terrie Hubble Technical Assistant Subject: Revised 10-407 for Permit #95-91, 18-30 Please find attached a revised Well Completion or Recompletion Report and Log for the above mentioned well. It was recently discovered that the wrong surface location was used on both the Permit to Drill and on the original 10-407. This caused the calculations for the below surface locations to be in error. In addition to the revised 10-407, I have also attached the approved As-Built which reflects the correct information. The directional surveys and summary of daily operations have previously been filed with you and there are no other changes. Again, I apologize for any inconvenience this may cause and appreciate your assistance and patience in this matter. /tlh RECEIVED JUN 11 1996 Alaska 0il & Gas Cons. Commission Anchorage .. ~'" STATE OF ALASKA r I Revised: 06/04/96 ALASK,-, OIL AND GAS CONSERVATION CfJ,;iMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '"1. Status of Well Classification of Service Well [] Oil [] Gas · [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 95-91 3. Address~ ............ ~ 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~i!,:~;~ 50-029-22568 4. Location of well at surface ........... ~, - , 9. Unit or Lease Name 3574 NSL, 26 WEL, SEC. 24, T11N, R14E At top of productive interval 771' NSL, 3794' EWL, SE C 19, T11N, R15#'-:--7/~-~-/~.,,,.,, it"~ R t ~/ 10. We II Nu18_30 mb er At total depth~,.~o '" 770' SNIT_~ ~=WL, SEC. 29, T11N, R15Ei ~-~ ¢ 11. Field and Pool ................ ~ Prudhoe Bay Field / Prudhoe Bay i'5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 53.45I ADL 028326 12. Date Spudded07/01/95 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 116' N°' °f C°mpleti°ns07/20/95 07/26/95 N/A MSLI One '~ 7. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrost 12621 8731 F~ 11881 8760 FT~ ~Yes ~No I 2198' MD! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, NEU, CDL, CNL, Acoustic 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" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# NT80 35' 3930' 13-1/2" 1113 sx PF 'E', 375 sx 'G', 150 sx 'G' 7-5/8" 29.7# S-95 35' 9857' 9-7/8" 350 sx Class 'G' 5-1/2" 17# L-80 9704' 12621' 6-3/4" 324 sx Class 'G' ~4. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 4 spf 4-1/2" 9650' 9604' MD TVD MD TVD 10620' - 11430' 8763' - 8775' 11840' - 11900' 8764' - 8758' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11940' - 12090' 8757' - 8752' 12160' - 12250' 8750' - 8748' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect w/92 Bbls Diesel 27. PRODUCTION TEST iDate First Production IMethod of Operation (Flowing, gas lift, etc.) October 4, 1995 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO l,, TEST PERIOD I iFIow Tubing Casing PressureCALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) iPress. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R£CEIVF..D JUN 1 1 1996 Ai~$k~ 01t & Gas Cens. commtssl0~ £ __1__,_~,.~ ~ G Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Marke, 30. { , Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 9756' 8213' Shublik 9814' 8260' Top of Sadlerochit 9885' 8316' 31. List of Attachments None 32. I hereby certify that ~egoing is~_~e,~/,~/d correct to the best of my knowledge DanStoltz ~ Title Senior Drilling Engineer Date /~" " o Prepared By Name/Number Terrie Hubble, 564-4628 ..... INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. RECEIVED Form 10-407 Rev. 07-01-80 JUN I I 1996 Alaska 0tl & Gas Cons. Commmsion Anchorage 10. 9 · 8 · 1J 18· 78 7 · 23· VICINITY MAP N.T.S. 6 · 16· 27 · 26 · 5 · 15· 25 · 24 · 3 · ,3· LEGEND 17· ~ AS-STAKED WELLS 2 · 12· · EXISTING WELLS I 19· 21 · 1 · 111 28 29_~ 20 · / ,,°°:~ ~" NOTES 1. DATE OF SURVEY MAY 10, 1995. ~ ~433Z~ 2. REFERENCE FIELD BOOKS L RR32~ / ~ W/~,,'/ PB95-OS(pgs.44-51). ~o~/ L $1~E 18 ~. A,ASXA S~A~ ,,A,~ ARE ZONE 4, NAD27. :':"~"' ..... :':"'::::: .... :. " : ' ' ' 4. PAD SCALE FACTOR EQUALS 0.9999415.': " .' ~ ~ ~. ~I~v~,z,CA, co, mo, ,s ~AS~ O, ~ / } ~ [~ ~~ "E 6' ELEVATIONS ARE ARCO DATUM M'L'L'W' ~~T~A AND EXISTING WELLS 27 AND 29. dUN 1 I 1996 Alaska Oil & Gas Cons, Commis Anchorage LOCATED WITHIN PROTRACTED SEC. 24, T. 11 N., R. 14 E., U.M., AK. WELL A.S.P. PLANT GEODETIC GEODETIC SECTION GROUND NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) OFFSETS ELEVATION Y=5,960,565.96 N. 1075.41 70'17'46.5.39" 70.2962608' 3778'FSL 28 X= 691,695.50 E. 424.95 148'26'51.454" 148.4476206' 79'FEL 16.2' !Y=5,960,555.05 N. 1045.28 70'17'46.255" 70.2961814' 5748'FSL QQ X= 691,703.94 E. 425.09 148'26'51.210" 148.4475583' 71'FEL 16.1' Y=5,960,305.65 N. 1014.89 70'17'45.962" 70.2961006' 3719'FSL 15.8' 51 X= 691,711.72 E. 424.47 148'26'51.005" 148.4475014' 64' FEL Y=5,960,276.78 N. 984.67 70'17'45.676" 70.2960211' 5690'FSL 15.8' 55 X= 691,720.66 E. 425.11 148'26'50.767" 148.4474.353' 56'FEL Y= 5.960,248.31 N. 955.09 70'17'45..394" 70.2959428' 3661' FSL 15.9' 54 X= 691,728.66 E. 424.95 148'26'50.554" 148.4475761' ' 48'FEL Y=5,960,219.05 N. 924.65 70'17'45.104" 70.2958622' 5652'FSL 16.2' 52 X= 691,7`37.06 E. 424.95 148'26'50.552" 148.447.3144' 41'FEL Y=5,960,190.84 N. 895.40 70'17'44.825" 70.2957847' 5605'FSL 16.5' RR X= 691,744.77 E. 424.59 148'26'50.128" 148.4472578' 34'FEL Y= 5,960,161.54 N. 864.65 70'17'44.555" 70.2957036' 5574'FSL 50 X= 691,755.54 E. 424.90 148'26'49.894" 148.4471928' 26'FEL 16.0' ~%°°o F. ROBERT BELL (~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 10, 1995. 0 5/14/95 ORIGINAL AS-BUILT ISSUE NO.I D^~ / RE.SION DRAWN: HITCH CHECKED: DENNY DATE: 5/~ 4/95 IRAW1NG: DS18AB SCAL[: 1 "=400' ARCO Alaska Inc. ,ak DRILL SITE 18 CONDUCTOR AS-BUILT WELLS 28,QQ,51,35,34,52,RR,30 JSItEETi OF ] BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 18-30 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 07/01/95 06:00 SPUD: 07/01/95 03:00 RELEASE: OPERATION: DRLG RIG: DOYON 9 WO/C RIG: DOYON 9 07/02/95 (1) TD: 1290' ( 0) 07/03/95 (2) TD: 3800' (2510) 07/04/95 (3) TD: 3800' ( 0) SPUD & DRILLED TO 1290' MW: 0.0 VIS: 0 MOVED RIG. RIG ACCEPTED AT 0600 HRS 07/01/95. RIGGED UP DIVERTER. R/U 20" DIVERTER, TAKE ON WATER & MIX SPUD MUD. WORK COMPLETED - WELL CONTROL IN POSITION. MADE UP BHA NO. 1. P/U BHA & MAKE UP KELLY. MAKE UP BIT #1 & ORIENT MOTOR AND MWD. MOTOR IS 9-5/8", 1-1/2" DEG BH DYNADRILL. DRILLED TO 1290'. SPUD IN AT 15:00 HRS TEST BIT #12 HRS/TRT=6HRS. DRLG W/BIT #1. DRILLED TO 3800' MW: 0.0 VIS: 0 DRILLED TO 2503'. STARTED SCHEDULED WIPER TRIP; DUE TO FOOTAGE DRILLED. CIRCULATED AT 2503'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). PULLED OUT OF HOLE TO 1067'. SHORT TRIP TO HWDP, NORMAL DRAG AND HOLE FILL. WASHED TO 2503'. RIH & WASH F/2460' TO 2503'. ON BOTTOM. DRILLED TO 3800'. DRLG W/BIT #1 AT REPORT TIME. TD OF 13-1/2" HOLE IS 3950'. NO REPORT RECEIVED ON 7/4 MW: 0.0 VIS: 0 07/05/95 ( 4) TD: 4863'(1063) DRILLING MW: 0.0 VIS: 0 RU BOP STACK. TEST T/5000. INSTALL BOWL PROTECTOR. MU BHA #2 & RIH T/3805. STOP T/PERFORM INTEGRITY TEST TAG CMT @ 3805. CASG T/3000 F/30 MIN. OBTAINED 25.4 PPG EMW. DRILL FLT EQUIP / HARD CMT & 10' OF NEW HOLE. PERFORM IT. OBTAINED LO @ 11.29 PPG EMW. DRILLED T/4132. REPAIR WASHOUT IN MUD LINE. DRILL T/4863. CBU. WELL : DS 18-30 OPERATION: RIG : DOYON 9 PAGE: 2 07/06/95 (5) TD: 5900' (1037) 07/07/95 (6) TD: 7755' (1855) 07/08/95 (7) TD: 8650' ( 895) DRILLED TO 5900' MW: 0.0 VIS: 0 BHA RUN NO. 2, PULLED OUT OF HOLE TO 4406'. ATTEMPT SHORT TRIP TO SHOE AT 3930' - WELL SWABBING. BEGAN PRECAUTIONARY MEASURES. RIH TO 4863'. ON BOTTOM. CIRCULATED AT 4863' · CIRCULATE HIGH VIS SWEEP AROUND. OBTAINED CLEAN RETURNS - 150% HOLE VOLUME. PULLED OUT OF HOLE TO 3930'. POOH TO 10-3/4" SHOE. CIRCULATED AT 3930'. BREAK CVIRCULATION - PERFORM 2ND LEAK-OFF TEST ON 10-3/4" CASING SHOE. LEAKED OFF AT 500 PSI WITH 9.6 PPG MUD AT 3657 TVD - 12.2 EMW. OBTAINED REQ'D FLUID PROPERTIES - 10% HOLE VOLUME. RIH TO 4863'. DRILLED TO 5817'. DRILL AHEAD - MAINTAIN MUD WT. 9.4 TO 9.6 PPG. ADT 5.0 HRS AST .5 HRS. MWD FAILED - END BHA RUN. CIRCULATED AT 5817'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). PULLED OUT OF HOLE TO 1080', SWABBING 5200' TO 4400'. PULLED BHA. ATTEND BACK BHA - L/D MWD - P/U MWD - CHANGE BIT AND ORIENT MWD. BHA STOOD BACK. TEST WELL CONTROL EQUIPMENT. INSTALLED BORE PROTECTOR. SERVICE WEAR BUSING. EQUIPMENT WORK COMPLETED, RUNNING TOOL RETRIEVED. MADE UP BHA NO. 3. TIH WITH BHA #3. RIH TO 5782' TIH WITH DRILL PIP - BENCH MARK SURVEY AT 4136'. BEGAN PRECAUTIONARY MEASURES. REAMED TO 5782'. PICK UP KELLY - REAM 5782' TO BOTTOM AT 5817'. DRILLED TO 5900'. DRILL AHEAD - ADT .5 HRS. POOH FOR PDC BIT MW: 0.0 VIS: 0 BHA RUN NO. 3. DRILLED & SURVEY 5900' TO 7755' - ART12.0 HRS AST 1.0 HRS - ADT 13.0 HRS. REACHED PLANNED END OF RUN - GEOLOGICAL. CIRCULATED AT 7755'. OBTAINED CLEAN RETURNS - 125% HOLE VOLUME. PULLED OUT OF HOLE TO 6000'. MONITOR WELL - PUMP SLUG - POOH FOR PDC BIT. DRILLING AT 8650' MW: 0.0 VIS: 0 PULLED OUT OF HOLE TO 3900'. CONTINUE POOH, SWABBING 5800 TO 5500'. P/U KELLY, BREAK CIRCULATION AND CIRCULATE 50 BBL. CONTINUE POOH TO 10-3/4" CASING SHOE. REST HOLE AT 3900', MONITOR WELL, MIX AND PUMP SLUG. RESUMED OPERATIONS. PULLED OUT OF HOLE TO 1000', CONTINUE POOH. PULLED BHA, LAY DOWN MOTOR AND BIT, SERVICE MWD, P/U 7-3/4" TAMDEN .78 DEG MOTOR WITH 9.75 BOTTOM STABLIZER AND 9.5 MIDDLE STABLIZER. BHA RUN NO. 4, RIH TO 3950'. MAKE UP HTC AG 526 PDC BIT, ORIENT MWD, TIH. SERVICED BLOCK LINE. SLIP AND CUT DRILL LINE, BREAK CIRCULATION. LINE SLIPPED AND CUT, RIH TO 7696'. CONTINUE TIH, FILL PIPE EVERY 25 STANDS. BEGAN PRECAUTIONARY MEASURES. REAMED TO 7755'. PRECAUTIONARY REAM 7696' TO BOTTOM AT 7755'. DRILLED TO 8650'. DRILL AND SURVEY 7755' TO 8650'. ART 5.75 HRS AST. 2.25 HRS - ADT 8.0 HRS, AVERAGE ROP 112 FT/HR. DRILLING AT 8650' AT 06:00 HRS. WELL : DS 18-30 OPERATION: RIG : DOYON 9 PAGE: 3 07/09/95 (8) TD: 9612'( 962) 07/10/95 ( 9) TD: 9866' ( 254) DRILLED TO 9612' MW: 0.0 VIS: 0 DRILLED AND SURVEY 8650' TO 9612' - ART 16.0 HRS AST. 7.75 HRS - ADT 23.75 HRS - DRILLING ASSEMBLY DROPPING 1 DEG PER 100' WHILE ROTATING AHEAD - SLIDE TO HOLD ANGLE. HAD DRILLING BREAK - MAX ROP 100'/HR. DRILLING BREAK AT 9612', CHECK FOR FLOW, OKAY. NO FLOW - EST TOP PUT RIVER AT 9650'MD. INSTALLED BOP TEST PLUG ASS. MW: 0.0 VIS: 0 CONTINUE DRILLING 9612' TO 9866' - RT 1 HR, ST 1.5 HRS. ADT 2.5 HRS - FORMATION TOPS: PUT RIVER 9650', SAG RIVER 9766', SHUBLIK 9818'. REACHED PLANNED END OF RUN - GEOLOGICAL. CIRCULATED AT 9866'. CIRCULATE BOTTOMS UP - GAS CUT MUD AT SURFACE AT 2000 STROKES. GAS FROM SAG RIVER FORMATION - MUD CUT 10.1 TO 7.2 PPG - INCREASE MUD WT. 10.1 TO 10.2 PPG. OBTAINED REQ'D FLUID PROPERTIES - 200% HOLE VOLUME. PULLED OUT OF HOLE TO 8500'. MONITOR WELL, OK, SHORT TRIP 15 STANDS TO 8500', HOLE FILL NORMAL. AT TOP OF CHECK TRIP INTERVAL. RIH TO 9866' TIH - TAG BRIDGE AT 9410' - WORK THROUGH BRIDGE. CIRCULATED AT 9866'. CIRCULATE BOTTOMS UP - GAS CUT MUD 10.2 TO 9.2 PPG - INCREASE MUD WT. 10.2 TO 10.4 PPG. OBTAINED REQ'D FLUID PROPERTIES - 300% HOLE VOLUME. PULLED OUT OF HOLE TO 3930'. SHORT TRIP TO 10-3/4" CASING SHOE. AT TOP OF CHECK TRIP INTERVAL. RIH TO 9866'. TIH - NO PROBLEMS. CIRCULATED AT 9866'. CIRCULATE HOLE CLEAN - MUD GAS CUT 10.4 TO 9.8 PPG. OBTAINED CLEAN RETURNS - 200% HOLE VOLUME. PULLED OUT OF HOLE TO 1080'. POOH FOR 7-5/8" INTERMEDIATE PROTECTIVE CASING DUE TO MUD WT. REQUIRED TO CONTROL SAG RIVER FORMATION. SLM - 4' LONG - NO CORRECTION - DRILL PIPE STOOD BACK. PULLED AND LAY DOWN BHA - DOWN LOAD MWD. TEST WELL CONTROL EQUIPMENT. INSTALLED BOP TEST PLUG ASSEMBLY. PULL WEAR BUSHING - CHANGE TOP RAMS TO 7-5/8". WELL : DS 18-30 OPERATION: RIG : DOYON 9 PAGE: 4 07/11/95 (10) TD: 9866' ( 0) 07/12/95 (11) TD: 9866' ( 0) LAID OUT DRILL PIPE F/DERRICK MW: 0.0 VIS: 0 TEST WELL CONTROL EQUIPMENT. TESTED TOP RAM. FINISH CHANGE TOP RAMS TO 7-5/8" - TEST RAM DOOR TO 2000 PSI. PRESSURE TEST COMPLETED SUCCESSFULLY - 2000 PSI. RUN CASING, 7-5/8" OD. RAN CASING TO 9857'. RIG UP CASING TOOLS, RAN 228 JTS 7-5/8", 29.7% S-95 BTC-MOD CASING. SHOE SET AT 9857'. HANGER LANDED. CASING LANDED ON FMC FLUTED MANDRELL HANGER. CEMENT: CASING CEMENT. CIRCULATED AT 9857'. CIRCULATE TWO CASING VOLUME 10 BBL/MIN 1100 PSI. OBTAINED CLEAN RETURNS - 200% HOLE VOLUME. MIXED AND PUMPED SLURRY - 72 BBL. TEST LINES 3500 PSI - PUMP 20 BBL FRESH WATER. PUMP 70 BBL NSCI SPACER MIXED AT 11.4 PPG, FOLLOWED BY 350 SX CLASS 'G' W/.2% CFR-3 + .45% HALAD 344 + .28% HR-5, MIX AT 15.8 PPG, 72 BBL OF CEMENT SLURRY, DISPLACED WITH RIG PUMP. BUMPED PLUG TO 3000. CEMENT PUMPED. FLOATS OK. RIG PUMP 94.8 EFFICIENT, -CIP AT 2100 HRS 07/10/95. RIGGED DOWN CASING HANDLING EQUIPMENT. LAY DOWN CEMENT HEAD, BACK OUT LANDING JT AND LAY DOWN, CLEAR FLOOR OF CASING EQUIPMENT. WELLHEAD WORK - INSTALLED SEAL ASSEMBLY, INSTALL 7-5/8" PACKOFF THROUGH BOP STACK ON TWO JTS OF HWT DRILL PIPE AND RUNNING TOOL. TIE DOWN BOLTS ENERGIZED. TESTED SEAL ASSEMBLY. TEST PACKOFF TO 5000 PSI FOR 15 MINUTES - OK. PRESSURE TEST COMPLETED SUCCESSFULLY - 5000 PSI. DERRICK MANAGEMENT. LAID OUT DRILL PIPE FROM DERRICK. DRILLED CEMENT TO 9840' MW: 0.0 VIS: 0 DERRICK MANAGEMENT. LAID OUT DRILL PIPE FROM DERRICK. FINISH LAY DOWN DRILL PIPE FROM DERRICK. 300 JOINTS LAID OUT. TEST WELL CONTROL EQUIPMENT. RIGGED UP ALL RAMS. CHANGE TOP AND BOTTOM SET OF RAM TO 3-1/2". CHANGE OUT KELLY TO 4-1/4" KELLY. WORK COMPLETED - ALL RAMS IN POSITION. TESTED BOP STACK. INSTALL TEST PLUG - TEST ALL RAMS, LINES AND VALVES TO 500 PSI LOW AND 5000 PSI HIGH-TEST HYDRILL 350 AND 3500 PSI, TEST KELLY, UPPER AND LOWER KELLY VALVE, TIW AND INSIDE BOP TO 500 / 5000 PSI. ALL OK. INSTALL WEAR BUSHING. PRESSURE TEST COMPLETED SUCCESSFULLY - 5000 PSI. MADE UP BHA NO. 5. SINGLED IN DRILL PIPE TO 9662'. TIH PICKING UP 3-1/2" 'E' AND X-95 DRILL PIPE. OBSERVED 10 KLB RESISTANCE. TAG CEMENT AT 9662' DRILL PIPE MEASUREMENTS. DRILLED CEMENT TO 9753'. DRILL SOFT CEMENT 9662' TO 9753', HARD CEMENT AT 9753'. STOPPED TO TEST CASING. CIRCULATED AT 9753'. CIRCULATE AND CONDITION MUD - CUT MUD WT. 10.5 TO 9.5 PPG. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). TESTED FLOAT COLLAR - VIA ANNULUS AND STRING. TEST 7-5/8" CASING TO 3500 PSI FOR 30 MINUTES - OK. PRESSURE TEST COMPLETED SUCCESSFULLY - 3500 PSI. DRILLED CEMENT TO 9840' TAG FLOAT COLLAR AT 9766' - DRILL CEMENT AT REPORT TIME ~840' WELL : DS 18-30 OPERATION: RIG : DOYON 9 PAGE: 5 07/13/95 (12) TD:10210'( 344) 07/14/95 (13) TD:10576'( 366) 07/15/95 (14) TD:10794' ( 218) 07/16/95 (15) TD:10794' ( 0) 07/17/95 (16) TD:l1470' ( 676) 07/18/95 (17) TD:ll600' ( 130) 07/19/95 (18) TD:11926' ( 326) SLIP & CUT DL MW: 0.0 VIS: 0 DRLG CMT T/9076. CBU. OBTAINED 125% HOLE VOL., PUMP 50 BBLS OF FW & 1 DRUM SAFECLEAN. PUMP 100 BBLS 9.2 PPG WATER W/FLO-PRO. DISPLACED T/9.0 PPG MUD. CBU & OBTAINED 100% HOLE VOL. DRILL T/10201. CBU. OBTAINED 100% ANNUL VOL. POOH T/985. PUMP SLUG. MU BHA #6. SHALLOW TEST MWD & MOTOR. TIH. FILL PIPE EVERY 30 STNDS. SLIP & CUT DL. POH TO 9800' MW: 0.0 VIS: 0 SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 10124' REAMED 10201' REAM 10124' TO BOTTOM AT 10201', BENCH MARK SURVEY @ 1018~'. MAD PASS F/ 10180 - 10201'. DRILLED TO 10576'. POH TO 9800' MONITOR WELL, SET BACK KELLY, POH TO 7 5/8" SHOE. MONITOR WELL, MIX SLUG. POOH T/5000 MW: 0.0 VIS: 0 POOH T/985. PULL BHA & CHANGE BITS. MU BHA #7 & TIH. STOP @10186 & TAKE SURVEY. DRILL T/10723. ELECTRIC MOTOR FAILURE. REPLACE & DRILL T/10794. POOH T/9860, HOLE OK. RIH T/10794. CBU. OBTAINED 150% HOLE VOL. POOH F/GR/NUETRON & SONIC LOGS. RIH T/7000 MW: 0.0 VIS: 0 PULLED BHA, RAN E-LOGS F/10756 T/9560. POOH LD TOOLS. SERVICE THE WEAR BUSHING. MU BHA #8. RIH T/7000. DRILL T/11470 MW: 0.0 VIS: 0 RIH T/10192. TAKE BENCHMARK SURVEY. RIH T/10756. WASH T/10794. CBU. DISPLACE T/9.0 PPG CLEAN FLO-PRO MUD. OBTAINED 100% HOLE VOL. DRILL T/11470. DRILL 11543' TO 11600' MW: 0.0 VIS: 0 DRILL & SURVEY 11470' TO 11543'. CBU. PULLED OUT OF HOLE TO 985' FOR BIT CHANGE. PU 4-3/4" F 2000M MEDIUM SPEED 1.15 DEG BH MOTOR. ORIENT MWD, SHALLOW TEST MOTOR AND MWD AT 385', OK. RIH TO 9800', FILL PIPE EVERY 20 STANDS. AT 7-5/8" CASING SHOE. SERVICED BLOCK LINE, LINE SLIPPED AND CUT. BEGAN PRECAUTIONARY MEASURES. REAMED TO 11543'. PRECAUTIONARY REAM 11474' TO BOTTOM AT 11543'. DRILLED 11543' TO 11600'. POH TO 7000' MW: 0.0 VIS: 0 DRILL AND SURVEY 11600 - 11926'. BUILD ANGLE LOOKING FOR SAND, FOUND SAND AT 11650', LOST SAND AT 11675', BUILD ANGLE DRILLING AHEAD, FOUND SAND @ 11800' DRILL SAND TO 11926'. CIRCULATED @ 11926' OBTAINED BOTTOMS UP. POH TO 7000'. MONITOR WELL, POH FOR BIT AND BOP TEST. WELL : DS 18-30 OPERATION: RIG : DOYON 9 PAGE: 6 07/20/95 (19) TD:12361' ( 435) 07/21/95 (20) TD:12621' ( 260) 07/22/95 (21) TD:12621 PB: 0 07/23/95 (22) TD:12621 PB: 0 07/24/95 (23) TD:12621 PB: 0 07/25/95 (24) TD:12621 PB: 0 DRILLING MW: 0.0 VIS: 0 POH TO 977' PULLED BHA. DOWN LOAD AND LOAD MWD PROBE, C/O BIT, SET BACK. TESTED BOP STACK. PULL WEAR RING, TEST ANNULAR, RAMS, VALVES AND LINES. INSTALLED WEAR RING. RIH W/ 4 3/4" 1.15 BH DD, MWD-GR, TEST MWD AND MOTOR. BHA #10 MADE UP. RIH TO 11926' DRILLED TO 12361' WASH & REAM MW: 0.0 VIS: 0 DRILL T/12621. CBU. POOH MU BHA #11. RIH T/10483. RUN CASING MW: 0.0 REAMED T/12621. CBU OBTAINED 100% ANNUL. VOL. POOH T/9857. RIH T/12621. CBU. OBTAINED 1.50% HOLE VOL. POOH T/1011. SLM W/NO CORRECTION. PULLED THE BHA. RUN 5.5" CASG T/1236. RAN DRILLPIPE MW: 0.0 RUN CASG, RUN CASG/T 2891. HANGER ASSEMBLY INSTALLED. CBU @2891. OBTAINED BOTTOMS UP 100% ANNULUS VOLUME. RAN CASG. ON LANDING STRING TO 9857. CBU @ 9857. OBTAINED BOTTOMS UP 100% ANNULUS VOLUME. RAN CASING ON LANDING STRING TO 12621. AT SETTING DEPTH 12621. CBU @ 12621. OBTAINED BOTTOMS UP 100% ANNULUS VOLUME. CEMENT: CASING CEMENT. PUMPED 90 VOLUME SPACERS, 10 BBL KCL H20, TEST LINES TO 4600PSI, 10 BBLS KCL H20, 70 BBLS KCL NSCI SPACER @ 1950-1625PSI. 324 SKS OF 15.70PPG PREMIUM CMT AT 5BPM 1535-1875PSI. RELEASED DART. DISPLACED SLURRY 129 BBL. BUMPED PLUG. REVERSE CIRCULATED AT 9693 FT., SET PKR W/3200PSI, SET LINER W/4500PSI, REVERSED OUT +/- 10 BBLS OF CMT, 70 BBLS OF SPACER, 20 BBLS OF WATER. OBTAINED CLEAN RETURNS - 200 % HOLE VOLUME. PULL DRILLPIPE, 3-1/2 IN O.D. RUN DRILLPIPE, 2-7/8 IN. O.D. RAN DRILLPIPE TO 2845 FT. RAN DRILLPIPE IN STANDS TO 10000 FT. R.I.H. TO 10821 MW: 0.0 RAN DRILLPIPE IN STANDS TO 10142 FT. AT TOP OF CEMENT: 10142 FT. CBU @ 10037 FT. ATTEMPT TO CIRC AT 10142', PLUG OFF, PULLED ONE STAND TO 10037', REVERSE CIRC BROKE FREE W/1500 PSI, REVERSED 2 DP VOLS, RECOVERED +- 5BBLS OF CMT CONTAMINATED MUD. OBTAINED CLEAN RETURNS 200 % HOLE VOLUME. RAN DRILLPIPE TO 12520 FT. CMT STRINGERS F/10130' - 10506', REST OF LINER OK, TAG AND DRESSED OFF LATCH DOWN COLLAR AT 12520, TEST LINER LAP & CSG TO 3500PSI 30 MIN, OK. CBU AT 12520 FT. HOLE DISPLACED W/SEAWATER - 100% DISPLACED. PULL DRILLPIPE. LAID DOWN DRILLPIPE TO 0 FT. COMPLETED OPERATIONS. BHA RUN NO. 12. DP CONVEYED PERF GUN ASSY. R.I.H. TO 10821 FT. MW: 0.0 WELL : DS 18-30 OPERATION: RIG : DOYON 9 PAGE: 7 07/26/95 (25) TD: 12621 PB: 0 07/26/95 (26) TD: 12621' ( 07/27/95 (27) TD:12621 PB: 8730 o) BHA LAID OUT MW: 0.0 BHA RUN NO. 12. R.I.H. TO 12520 FT. FIN CLOSING FAS-FILL VALVE, RIH, TAG LATCH DN COLLAR, PU AND POSITION BTM SHOT AT 12250' TOP SHOT AT 10620', R/U MANIFOLD AND LINES, FLUID LEVEL AT 1441' SET PKR @9338, TEST LINES TO 3000 · PSI. AT BOTTOM PERF. 12250 FT. REVERSE CIRC. AT 9338 FT. OBTAINED CLEAN RETURNS 200 % HOLE VOLUME. POOH TO 2924 FT. PULLED BHA. BHA LAID OUT. RIGGED DOWN BOP STACK MW: 0.0 VIS: 0 PLANNED MAINT. SERVICED ADDITIONAL SERV. RUN SINGLE COMP. RAN TUBING TO 9650 FT. CBU AT 9650 FT. SET PACKER AT 9604 FT. RIGGED DOWN HANDLING EQUIP. MIPPLE DOWN BOP STACK. WORK COMP. RIG RELEASED AT 1300 HRS.7/265 MW: 0.0 WELLHEAD WORK. INSTALLED XMAS TREE. REMOVED ACCESSORIES. FREEZE PROTECT WELL - 92.000 BBL. OF DIESEL. COMPLETE OPERATIONS. WELLHEAD WORK. RIG RELEASED AT 1300 HRS. 7/26/95 SIGNATURE: (drilling superintendent) DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 072095 MWD SURVEY JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -53.45 0 0 219 219.76 166.31 0 6 307 307.06 253.61 0 23 395 395.89 342.44 0 37 485 485.89 432.44 0 57 573 573.51 520.06 1 13 663 663.14 609.69 '1 15 752 752.90 699.45 0 55 842 842.91 789.46 1 10 931 931.43 877.98 0 3 1021 1021.77 968.32 0 55 1116 1115.86 1062.41 2 52 1211 1210.75 1157.30 3 24 1306 1306.06 1252.61 4 35 1399 1399.10 1345.65 5 10 N .00 E .00 .00N .00E N 85.00 W .05 .02N .19W S 86.82 W .33 .01N .56W S 83.69 W .27 .06S 1.35W N SO. 01 w .43 .01N 2.58W S 84 · 49 W . 45 ~'" '~' 05N 4 22W .~ ........ ~ · S 89.44 W .12 ~-"":~'"~ .05S 6.15W N 80.92 W .42 ............ 05N 7.84W N 86.58 W .30 ~' .22N 9.47W S 85.63 E 1.39 ......... .27N 10.33W '~.::'::~ ~ ..... 02S 9 60W S 67.12 E .97 ~ . · S 75.64 E 2.09 .90S 6.61W S 72.92 E .58 2.32S 1.59W S 72.08 E 1.25 4.34S 4.77E S 60.59 E 1.21 7.56S 12.00E .00 - .16 - .45 -1.04 -2.07 -3.40 -4.88 -6.29 -7.70 -8.41 -7.66 -4.74 .12 6.42 14.13 1493 1492.22 1438.77 5 14 1590 1588.73 1535.28 6 18 1685 1683.14 1629.69 6 32 1780 1777.70 1724.25 8 15 1876 1872.31 1818.86 9 50 S 58.49 E .22 11.86S 19.31E S 68.39 E 1.49 16.13S 28.03E S 66.80 E .31 20.18S 37.85E S 59.99 E 2.02 25.75S 48.77E S 59.68 E 1.65 33.328 61.80E 22.55 32.10 42.38 54.45 69.41 1970 1964.63 1911.18 12 55 2066 2057.56 2004.11 13 13 2162 2150.89 2097.44 14 25 2255 2240.61 2187.16 17 58 2353 2332.68 2279.23 19 55 S 56.68 E 3.34 43.18S 77;56E S 55.06 E .49 55.29S 95.42E S 51.82 E~ 1.49 68.98S 113.83E S 50.54 E 3.83 85.34S 134.12E S 49.37 E 2.03 105.69S 158.31E 87.93 109.48 132.43 158.48 190.05 2446 2419.71 2366.26 22 57 2541 2506.51 2453.06 23 42 2635 2592.15 2538.70 26 55 2732 2677.40 2623.95 29 58 2828 2758.56 2705.11 33 9 S 49.61 E 3.24 127.89S 184.29E S 49.55 E .79 152.15S 212.78E S 48.37 E 3.45 178.77S 243.32E S 50.38 E 3.29 208.81S 278.40E S 51.69 E 3.41 240.14S 317.18E 224.15 261.51 301.91 348.00 397.82 2923 2838.03 2784.58 33 39 3019 2917.59 2864.14 34 45 3114 2995.60 2942.15 34 53 3210 3074.46 3021.01 34 4 3306 3153.54 3100.09 34 39 S 50.79 E .74 272.94S 358.03E S 53.91 E 2.16 305.95S 400.85E S 54.50 E .38 337.69S 444.87E S 56.46 E 1.44 368.38S 489.47E S 57.20 E .75 397.96S 534.73E 450.20 504.26 558.51 612.61 666.56 · w ~ ,. · : _ SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE S~J~RED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/9 DATE OF SURVEY: 072095 MWD SURVEY JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL' DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS DIRECTION DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 3401 3232.03 3178.58 3494 3308.23 3254.78 3590 3385.90 3332.45 3686 3463.34 3409.89 3781 3539.25 3485.80 34 45 35 19 36 10 36 27 37 1 S 54.77 E 1.45 S 54.52 E .64 S 53.23 E 1.18 S 55.93 E 1.69 S 55.49 E .65 428.36S 579.77E 720.82 459.28S 623.35E 774.23 492.25S 668.51E 830.14 525.22S 714.89E 887.02 557.14S 761.70E 943.62 3894 3629.72 3576.27 4008 3719.86 3666.41 4073 3772.04 3718.59 4105 3797.45 3744.00 4199 3871.98 3818.53 37 27 S 55.61 E .39 37 5 S 54.64 E .61 37 4 S 54.21 E .40 37 2 S 54.81 E 1.14 38 44 S 54.62 E 1.79 596.05S 818.40E 1012.32 635.28S 874.70E 1080.89 658.22S 906.78E 1120.32 669.36S 922.40E 1139.51 702.88S 969.76E 1197.49 4295 3946.16 3892.71 4390 4020.00 3966.55 4486 4094.76 4041.31 4581 4167.78 4114.33 4676 4241.26 4187.81 39 1 39 12 39 29 39 35 39 24 S 54.35 E .35 S 53.85 E .38 S 53.30 E .46 S 54.47 E .80 S 54.11 E .32 737.63S 1018.45E 1257.29 772.84S 1067.09E 1317.33 809.24S 1116.42E 1378.63 844.77S 1165.12E 1438.91 880.13S 1214.30E 1499.47 4772 4315.21 4261.76 4866 4387.31 4333.86 4963 4461.06 4407.61 5057 4532.87 4479.42 5153 4606.27 4552.82 39 45 40 10 40 4 40 22 40 42 S 54.31 E .39 S 54.18 E. .46 S 53.90 E .21 S 54.63 E .60 S 54.26 E .41 915.87S 1263.88E 1560.58 951.17S 1312.91E 1620.98 987.67S 1363.21E 1683.11 1023.14S 1412.51E 1743.83 1059.64S 1463.59E 1806.60 5246 4676.14 4622.69 5342 4749.29 4695.84 5439 4822.56 4769.10 5534 4894.19 4840.74 5631 4967.08 4913.63 40 42 40 55 40 42 41 0 41 12 S 54.06 E .14 S 53.64 E .36 S 53.67 E .23 S 53.85 E .33 S 53.60 E .27 1094.84S 1132.11S 1169.62S 1206.24S 1243.86S 1512.32E 1563.34E 1614.31E 1664.28E 1715.54E 1866.69 1929.87 1993.15 2055.10 2118.68 5715 5031.10 4977.65 5819 5111.05 5057.60 5915 5185.46 5132.01 6011 5258.79 5205.34 6105 5331.17 5277.72 39 52 39 28 39 40 39 45 39 47 S 54.04 E 1.60 S 53.87 E .40 S 53.14 E .52 S 53.57 E .30 S 53.02 E .38 1276.19S 1315.22S 1351.80S 1388.15S 1424.17S 1759.74E 1813.37E 1862.81E 1911.68E 1959.99E 2173.43 2239.75 2301.25 2362.16 2422.42 6201 5405.30 5351.85 6297 5480.36 5426.91 6388 5552.08 5498.63 6482 5624.92 5571.47 6578 5699.69 5646.24 38 45 38 24 38 37 39 2 39 19 S 53.21 E 1.09 S 52.56 E .56 S 53.71 E .82 S 52.85 E .72 S 52.35 E .44 1460.56S 1496.69S 1530.93S 1565.99S 1603.01S 2008.49E 2056.23E 2101.90E 2148.90E 2197.32E 2483.05 2542.92 2600.00 2658.64 2719.58 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/9 DATE OF SURVEY: 072095 MIND SURVEY JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6676 5775.08 5721.63 6772 5849,28 5795.83 6867 5923,12 5869.67 6963 5996,50 5943.05 7057 6069.08 6015.63 39 15 S 51.41 E .62 1641.09S 2245.84E 39 27 S 50.01 E .95 1679.62S 2292.93E 39 39 S 49.53 E .38 1719.01S 2339.49E 39 43 S 50.23 E .47 1758.24S 2386.05E 39 34 S 52.99 E 1.87 1795.58S 2433.18E 2781.25 2842.05 2902.94 2963.73 3023.84 7150 6141.00 6087.55 7246 6214.60 6161.15 7342 6289,00 6235.55 7437 6361.84 6308.39 7533 6436.17 6382.72 39 40 S 52.65 E .26 1831.57S 2480.62E 3'9 27 S 54.75 E 1.42 1867.57S 2529.63E 39 34 S 54.60 E .15 1903.06S 2579.70E 39 31 S 54.46 E .10 1937.96S 2628.69E 39, 41 S 54.09 E .30 1973.88S 2678.63E 3083.39 3144.19 3205.54 3265.67 3327.17 7629 6509.81 6456.36 7691 6557.87 6504.42 7819 6655.92 6602.47 7914 6729.64 6676.19 8009 6803.66 6750.21 39 40 S 54.07 E .02 2009.72S 2728.11E 39 42 S 54.40 E .34 2033.03S 2760.47E 39 28 S 53.55 E .46 2080.72S 2826.05E 39 1 S 53.52 E .48 2116.52S 2874.49E 38 39 S 54.33 E .66 2151.62S 2922.66E 3388.26 3428.14 3509.21 3569.43 3629.03 8105 6879.04 6825.59 8200 6953.77 6900.32 8295 7029.86 6976.41 8391 7106.53 7053.08 8486 7183.82 7130.37 38 9 S 53.92 E .59 2186.63S 2971.08E 37 32 S 54.13 E .65 2220.74S 3018.07E 36 51 S 55.11 E .95 2254.19S 3065.17E 36 19 S 54.27 E .77 2287.09S 3111.62E 35 27 S 54.06 E .92 2319.83S 3156.95E 3688.77 3746.83 3804.57 3861.47 3917.38 8580 7260.31 7206.86 8677 7338.67 7285.22 8772 7416.14 7362.69 8867 7493.31 7439.86 8962 7570.71 7517.26 35 31 S 53.44 E .39 2352.08S 3200.93E 36 12 S 54.07 E .80 2385.57S 3246.63E 35 20 S 53.14 E 1.07 2418.69S 3291.57E 35 19 S 53.12 E .03 2451.51S 3335.33E 35 9 S 51.42 E 1.05 2484.96S 3378.57E 3971.91 4028.57 4084.38 4139.08 4193.75 9055 7647.23 7593.78 9087 7673.38 7619.93 9150 7724.81 7671.36 9182 7750.62 7697.17 9246 7802.86 7749.41 34 41 S 51.60 E .52 2518.22S 3420.39E 35 39 S 51.69 E 3.00 2529.66S 3434.84E 36 7 S 51.97 E .80 2552,65S 3464.10E 35 29 S 51.81 E 2.03 2564.14S 3478.75E 34 20 S 52.92 E 2.06 2586.41S 3507.62E 4247.16 4265.59 4302.79 4321.41 4357.87 9341 7880.72 7827.27 9437 7957.26 7903.81 9532 8032.56 7979.11 9627 8109.28 8055.83 9723 8186.58 8133.13 35 57 S 54.20 E 1.87 2618.97S 3551.73E 37 46 S 53.74 E 1.92 2652.74S 3598.15E 37 18 S 54.57 E .73 2686.63S 3645.06E 35 55 S 54.71 E 1.46 2719.62S 3691.55E 36 5 S 57.05 E 1.45 2751.12S 3738.05E 4412.69 4470.08 4527.95 4584.93 4641.02 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/9 DATE OF SURVEY: 072095 MWD SURVEY JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 9787 8238.18 8184.73 9959 8374.75 8321.30 10052 8446.99 8393.54 10138 8511.03 8457.58 10182 8542.88 8489.43 36 17 S 56.75 E .42 38 21 S 58.70 E 1.39 40 30 S 59.50 E 2.35 42 47 S 61.60 E 3.14 43 39 S 61.30 E 2.00 2771.74S 2827.30S 2857.79S 2885.77S 2900.08S 3769.67E 3857.72E 3908.70E 3958.30E 3984.60E 4678.69 4782.44 4841.51 4897.97 4927.58 10213 8565.71 8512.26 10245 8587.89 8534.44 10276 8609.04 8555.59 10308 8629.98 8576.53 10340 8650.49 8597.04 44 31 S 57.70 E 8.34 4'6 13 S 53.60 E 10.71 48 10 S 50.50 E 9.62 49 17 S 48.40 E 6.09 50 42 S 45.10 E 9.06 2911.30S 2923.98S 2938.03S 2953.55S 2970.30S 4003.64E 4022.17E 4040.17E 4058.30E 4076.09E 4949.54 4971.97 4994.80 5018.63 5042.91 10370 8669.06 8615.61 10398 8684.58 8631.13 10432 8701.30 8647.85 10464 8715.28 8661.83 10495 8727.79 8674.34 54 0 S 46.20 E 11.22 58 16 S 47.20 E 15.65 62 27 S 50.40 E 14.84 65 28 S 53.30 E 12.52 67 41 S 53.70 E 7.14 2987.12S 3002.98S 3022.32S 3039.99S 3057.18S 4093.31E 4110.14E 4132.26E 4154.77E 4178.01E 5066.79 5089.77 5119.07 5147.68 5176.59 10525 8738.72 8685.27 10558 8749.15 8695.70 10579 8755.04 8701.59 10591 8757.82 8704.37 10618 8762.67 8709.22 69 46 S 52.60 E 7.70 72 35 S 53.60 E 9.16 75 24 S 53.10 E 13.39 77 10 S 52.90 E 15.18 82 41 S 53.60 E 19.98 3074.02S 3092.41S 3104.66S 3111.52S 3127.88S 4200.47E 4224.97E 4241.44E 4250.54E 4272.45E 5204.66 5235.29 5255.82 5267.22 5294.57 10650 8765.85 8712.40 10682 8767.63 8714.17 10713 8768.46 8715.01 10746 8768.82 8715.37 10773 8768.77 8715.32 85 35 S 51.30 E 11.89 88 1 S 54.20 E 11.83 88 56 S 54.30 E 2.91 89 49 S 52.40 E 6.35 90 22 S 54.60 E 8.48 3146.76S 3166.07S 3184.65S 3204.28S 3220.19S 4297.01E 4322.41E 4348.21E 4374.60E 4396.10E 5325.54 5357.44 5389.23 5422.12 5448.87 10807 8768.81 8715.36 10838 8769.61 8716.16 10870 8771.03 8717.58 10902 8772.36 8718.91 10932 8773.40 8719.95 10964 8774.24 8720.79 10996 8774.89 8721.44 11026 8775.55 8722.10 11056 8776.28 8722.83 11088 8777.07 8723.62 89 30 S 54.70 E 2.57 87 35 S 54.70 E 6.02 87 17 S 54.30 E 1.58 87 52 S 54.40 E 1.87 88 9 S 54.10 E 1.37 88 49 S 54.10 E 2.13 88 51 S 53.70 E 1.25 88 37 S 53.80 E .87 88 35 S 53.60 E .67 88 34 S 52.90 E 2.19 3239.66S 3257.98S 3276.50S 3294.81S 3312.31S 3331.05S 3350.01S 3367.65S 3385.52S 3404.64S '4423.55E 4449.41E 4475.38E 4500.91E 4525.22E 4551.10E 4577.11E 4601.16E 4625.49E 4651.10E 5482.50 5514.19 5546.07 5577.48 5607.43 5639.37 5671.55 5701.38 5731.56 5763.52 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SFJkRED SERVICES DRILLING pBu/18-3o 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/9 DATE OF SURVEY: 072095 MWD SURVEY JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANG~ COORD DEGREES DG/100 NORTH/SOUTH EAST INATES VERT. /WEST SECT. 11119 8777.88 8724.43 11150 8778.69 8725.24 11182 8779.34 8725.89 11211 8779.71 8726.26 11243 8779.95 8726.50 88 27 S 52.30 E 1.94 3423.78S 4676 88 31 S 51.90 E 1.33 3442.43S 4700 89 8 S 51.60 E 2.16 3462.16S 4725 89 25 S 52.40 E 2.87 3480.31S 4748 89 43 S 52.00 E 1.55 3500.03S 4773 .13E 5795.03 .08E 5825.38 .liE 5857.25 .35E 5886.73 .77E 5918.90 11275 8779.57 8726.12 11305 8778.48 8725.03 11337 8777.30 8723.85 11368 8776.51 .8723.06 11401 8775.89 8722.44 91 39 S 52.80 E 6.62 3519.37S 4798 92 29 S 51.50 E 5.16 3537.70S 4822 91 46 S 51.40 E 2.26 3557.41S 4847 91 4 S 52.00 E 2.90 3577.14S 4872 91 8 S 52.60 E 1.88 3596.77S 4897 .88E 5950.60 .48E 5980.47 .21E 6012.09 .18E 6043.90 .58E 6076.00 11430 8775.35 8721.90 11462 8775.49 8722.04 11492 8776.53 8723.08 11523 8778.09 8724.64 11557 8779.75 8726.30 90 56 S 53.10 E 1.80 3614.68S 4921 88 31 S 54.40 E 8.69 3633.43S 4946 87 33 S 57.00 E 9.15 3650.48S 4971 86 39 S 56.80 E 3.02 3667.338 4997 87 46 S 55.00 E 6.23 3686.41S 5025 .23E 6105.66 .80E 6137.37 .79E 6167.59 .65E 6198.38 .81E 6232.35 11574 8780.14 8726.69 11585 8780.09 8726~64 11603 8779.62 8726.17 11616 8779.04 8725.59 11647 8777.43 8723.98 89 30 S 54.50 E 10.93 3695.91S. 5039.26E 90 58 S 54.80 E 13.02 3702.58S 5048.66E 92 7 S 57.40 E 16.29 3712.29S 5063.11E 92 44 S 55.70 E 13.36 3719.74S 5074.39E 93 10 S 56.40 E 2.63 3737.15S 5100.24E 6248.82 6260.33 6277.72 6291.21 6322.34 11683 8776.09 8722.64 11714 8775.14 8721.69 11744 8773.70 8720.25 11776 8771.41 8717.96 11807 8768.21 8714.76 91 10 S 54.20 E 8.40 3757.26S 5129.30E 92 22 S 53.70 E 4.21 3775.42S 5154.24E 93 4 S 56.00 E 7.95 3792.81S 5178.94E 95 12 S 55.10 E 7.28 3810.72S 5205.04E 96 30 S 54.40 E 4.70 3828.71S 5230.51E 6357.65 6388.49 6418.69 6450.31 6481.48 11837 8764.63 8711.18 11872 8760.70 8707.25 11902 8758.34 8704.89 11933 8757.17 8703.72 11963 8756.57 8703.12 97 2 S 52.40 E 6.78 3846.67S 5254.69E 95 56 S 55.00 E 8.08 3867.12S 5282.53E 93 1 S 53.50 E 10.86 3884.71S 5306.97E 91 17 S 53.40 E 5.58 3903.19S 5331.90E 90 58 S 53.20 E 1.22 3921.25S 5356.11E 6511.60 6546.13 6576.24 6607.27 6637.48 11994 8755.99 8702.54 12026 8754.94 8701.49 12055 8753.45 8700.00 12085 8751.94 8698.49 12116 8751.01 8697.56 91 13 S 53.20 E .82 3939.48S 5380.48E 92 31 S 51.30 E 7.20 3958.98S 5405.67E 93 15 S 51.30 E 2.50 3977.46S 5428.73E 92 33 S 50.70 E 3.12 3996.15S 5451.82E 90 51 S 50.80 E 5.41 4015.95S 5476.06E 6667.91 6699.77 6729.30 6759.00 6790.26 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/9 DATE OF SURVEY: 072095 MWD SURVEY JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANG~ COORDINATES VERT. DG Mi~ DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 12148 8750.51 8697.06 90 55 S 51.00 E .65 4036.12S 5500.87E 6822.22 12180 8749.91 8696.46 91 15 S 50.70 E 1.44 4056.02S 5525.31E 6853.71 12211 8749.25 8695.80 91 10 S 50.70 E .28 4075.91S 5549.61E 6885.09 12243 8748.55 8695.10 91 19 S 50.40 E 1.04 4096.30S 5574.40E 6917.16 12275 8747.97 8694.52 90 46 S 50.10 E 1.98 4116.56S 5598.76E 6948.81 12306 8747.62 8694.17 90 33 S 50.20 E .79 4136.24S 5622.33E 6979.48 12338 8747.18 8693.73 91 0 S 50.10 E 1.45 4157.058 5647.27E 7011.91 12370 8746.43 8692.98 91 41 S 49.90 E 2.24 4177.368 5671.48E 7043.47 12400 8745.49 8692.04 91 50 S 49.60 E 1.10 4197.088 5694.77E 7073.93 12432 8744.19 8690.74 92 53 S 49.20 E 3.57 4217.52S 5718.62E 7105.28 12464 8742.40 8688.95 93 35 S 48.00 E 4.38 4238.49S 5742.40E 7136.89 12495 8740.28 8686.83 94 7 S 48.00 E 1.65 4259.52S 5765.76E 7168.20 12527 8738.02 8684.57 94 7 S 47.60 E 1.27 4280.58S 5788.99E 7199.43 12558 8735.72 8682.27 94 9 S 47.50 E .32 4302.03S 5812.43E 7231.06 12566 8735.14 8681.69 94 16 S 47.20 E 4.11 4307.38S 5818.24E 7238.92 12621 8731.10 8677.65 94 16 S 47.20 E .00 4344.03S 5857.82E 7292.58 THE CALCIILATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7292.78 FEET AT SOUTH 53 DEG. 26 MIN. EAST AT MD = 12621 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 126.98 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 072095 JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANG~ COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -53.45 .00 N .00 E .00 1000 999.91 946.46 .12 N 9.93 W .09 2000 1993.03 1939.58 46.76 S 83.00 E 6.97 3000 2901.49 2848.04 299.37 S 391.82 E 98.51 4000 3713.40 3659.95 632.45 S 870.72 E 286.60 .09 6.88 91.54 188.09 5000 4489.12 4435.67 1001.57 S 1382.29 E 510.88 6000 5250.30 5196.85 1383.96 S 1906.00 E 749.70 7000 6024.85 5971.40 1773.31 S 2404.16 E 975.15 8000 6796.43 6742.98 2148.24 S 2917.96 E 1203.57 9000 7601.77 7548.32 2498.61 S 3395.67 E 1398.23 224.28 238.82 225.45 228.42 194.66 10000 8406.83 8353.38 2840.49 S 3879.42 E 1593.17 11000 8774.96 8721.51 3352.13 S 4580.00 E 2225.04 12000 8755.87 8702.42 3942.82 S 5384.95 E 3244.13 12621 8731.10 8677.65 4344.03 S 5857.82 E 3889.90 194.94 631.87 1019.10 645.76 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CIIRVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 072095 JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANG~ COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 53 53.45 153 153.45 253 253.45 353 353.45 -53.45 .00 N .00 E .00 .00 .00 N .00 E .00 100.00 .01 N .08 W .00 200.00 .02 N .25 W .00 300.00 .02 S .90 W .,00 .00 .00 .00 .00 453 453.45 553 553.45 653 653.45 753 753.45 853 853.45 400.00 .08 S 2.05 W .01 500.00 .09 N 3.80 W .03 600.00 .05 S 5.94 W .05 700.00 .05 N 7.85 W .07 800.00 .23 N 9.69 W .08 .01 .02 .02 .02 .02 953 953.45 1053 1053.45 1153 1153.45 1253 1253.45 1354 1353.45 1454 1453.45 1555 1553.45 1655 1653.45 1756 1753.45 1857 1853.45 1959 1953.45 2062 2053.45 2165 2153.45 2269 2253.45 2375 2353.45 2483 2453.45 2592 2553.45 2705 2653.45 2822 2753.45 2941 2853.45 3063 2953.45 3184 3053.45 3305 3153.45 3427 3253.45 3550 3353.45 900.00 .27 N 10.30 W .09 1000.00 .22 S 9.13 W .10 1100.00 1.37 S 4.78 W .21 1200.00 3.08 S .85 E .38 1300.00 5.60 S 8.41 E .70 .01 .01 .11 .17 .32 1400.00 10.00 S 16.27 E 1.11 .41 1500.00 14.69 S 24.42 E 1.55 .44 1600.00 18.84 S 34.72 E 2.17 .62 1700.00 23.99 S 45.72 E 2.91 .74 1800.00 31.67 S 58.98 E 4.09 1.17 1900.00 41.80 S 75.44 E 5.95 2000.00 54.74 S 94.63 E 8.60 2100.00 69.41 S 114.37 E 11.58 2200.00 87.99 S 137.34 E 15.88 2300.00 110.70 S 164.16 E 21.89 2400.00 137.15 S 195.18 E 29.89 2500.00 166.21 S 229.06 E 39.41 2600.00 200.12 S 268.01 E 51.98 2700.00 238.08 S 314.58 E 68.66 2800.00 279.43 S 365.99 E 88.47 2900.00 320.60 S 420.97 E 109.80 3000.00 360.53 S 477.63 E 131.48 3100.00 397.93 S 534.68 E 152.53 3200.00 436.93 S 591.91 E 174.18 3300.00 478.07 S 649.51 E 196.70 1.86 2.64 2.99 4.29 6.01 8.00 9.51 12.57 16.68 19.81 21.33 21.68 21.05 21.65 22.52 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 072095 JOB NUMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANG~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3674 3453.45 3400.00 3798 3553.45 3500.00 3924 3653.45 3600.00 4050 3753.45 3700.00 4176 3853.45 3800.00 521.13 S 708.83 E 563.21 S 770.52 E 606.32 S 833.41 E 650.01 S 895.39 E 694.27 S 957.63 E 220.70 23.99 245.51 24.81 271.26 25.75 296.76 25.50 322.60 25.84 4304 3953.45 3900.00 4433 4053.45 4000.00 4563 4153.45 4100.00 4692 4253.45 4200.00 4822 4353.45 4300.00 741.07 S 1023.25 E 788.95 S 1089.13 E 837.88 S 1155.47 E 886.00 S 1222.41 E 934.44 S 1289.73 E 351.04 28.44 380.00 28.97 409.60 29.60 439.21 29.60 469.13 29.92 4953 4453.45 4400.00 5084 4553.45 4500.00 5216 4653.45 4600.00 5348 4753.45 4700.00 5480 4853.45 4800.00 983.89 S 1358.04 E 1033.27 S 1426.79 E 1083.38 S 1496.51 E 1134.25 S 1566.24 E 1185.37 S 1635.73 E 499.94 30.81 530.95 31.01 562.75 31.80 594.85 32.10 626.92 32.06 5612 4953.45 4900.00 5744 5053.45 5000.00 5874 5153.45 5100.00 6004 5253.45 5200.00 6134 5353.45 5300.00 1236.78 S 1705.94 E 1287.15 S 1774.85 E 1335.89 S 1841.56 E 1385.51 S 1908.10 E 1435.33 S 1974.82 E 659.48 32.56 690.97 31.49 720.68 29.71 750.65 29.96 780.77 30.13 6262 5453.45 5400.00 6390 5553.45 5500.00 6518 5653.45 5600.00 6648 5753.45 5700.00 6777 5853.45 5800.00 1483.72 S 2039.30 E 1531.58 S 2102.78 E 1579.96 S 2167.34 E 1630.06 S 2232.03 E 1681.83 S 2295.56 E 809.23 28.45 836.98 27.75 865.47 28.49 894.68 29.21 923.97 29.29 6907 5953.45 5900.00 7037 6053.45 6000.00 7166 6153.45 6100.00 7296 6253.45 6200.00 7426 6353.45 6300.00 1735.32 S 2358.63 E 1787.81 S 2422.86 E 1837.84 S 2488.83 E 1886.04 S 2555.75 E 1933.93 S 2623.05 E 953.73 29.76 983.68 29.94 1013.50 29.83 1043.13 29.63 1072.83 29.70 7556 6453.45 6400.00 7686 6553.45 6500.00 7815 6653.45 6600.00 7944 6753.45 6700.00 8072 6853.45 6800.00 1982.29 S 2690.24 E 2030.90 S 2757.49 E 2079.51 S 2824.41 E 2127.99 S 2890.00 E 2174.79 S 2954.83 E 1102.65 29.82 1132.60 29.95 1162.38 29.78 1191.42 29.04 1219.46 28.04 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 10 SHARED SERVICES DRILLING PBU/18-30 500292256800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/30/95 DATE OF SURVEY: 072095 JOB NIJMBER: AK-MM-950732 KELLY BUSHING ELEV. = 53.45 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 8199 6953.45 6900.00 2220.60 S 3017.88 E 1246.24 8325 7053.45 7000.00 2264.31 S 3079.68 E 1271.66 8449 7153.45 7100.00 2307.13 S 3139.44 E 1295.78 8572 7253.45 7200.00 2349.16 S 3197.00 E 1318.58 8695 7353.45 7300.00 2391.92 S 3255.39 E 1342.03 26.78 25.42 24.12 22.79 23.45 8818 7453.45 7400.00 2434.56 S 3312.73 E 1364.94 8940 7553.45 7500.00 2477.38 S 3369.06 E 1387.44 9062 7653.45 7600.00 2520.91 S 3423.78 E 1409.46 9186 7753.45 7700.00 2565.39 S 3480.34 E 1432.66 9307 7853.45 7800.00 2607.39 S 3535.68 E 1454.44 22.91 22.51 22.02 23.20 21.78 9432 7953.45 7900.00 2650.99 S 3595.77 E 1478.99 9558 8053.45 8000.00 2695.86 S 3658.03 E 1505.05 9682 8153.45 8100.00 2737.98 S 3717.78 E 1528.93 9806 8253.45 8200.00 2777.88 S 3779.05 E 1552.81 9931 8353.45 8300.00 2818.54 S 3843.32 E 1578.47 24.56 26.06 23.88 23.88 25.66 10061 8453.45 8400.00 2860.60 S 3913.48 E 1607.69 10196 8553.45 8500.00 2905.13 S 3993.42 E 1643.26 10344 8653.45 8600.00 2972.94 S 4078.78 E 1691.52 10573 8753.45 8700.00 3101.35 S 4236.98 E 1820.24 10600 8759.64 8706.19 3116.70 S 4257.41 E 1840.36 29.22 35.57 48.25 128.73 20.12 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Ol:ll Ll--I N G S I::: Fi~/I C E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - DS 18-30 AK-MW-50063 May 31, 1996 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.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10047 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 3/1/96 Field: Prudhoe Bay FIo~ Well Job # Log Description Date BL RF Sepia Survey Performance Disl~ Calculation Letter '~_~' 'DIS. 3-33 ~cf.. {[(3 COMPENSATED NEUTRON LOG-CNT-D 960214 1 1 Z D.S. 4-19 o~)~-b;Z'l DUAL BURSTTDT-P 960209 I 1 D.S. 4-26 2~>-- )!'-I LEAK DETECTION LOG 960127 I 1 D.S. 5-4 '~H'0. Fq DUAL BURST TDT-P 960129 I 1 D.S. 5-25 o~(~--I~l DUAL BURSTTDT-P 9601 26 I 1 14-1~ , ~ -I'~ DIGITAL ENTRY 960215 1 1 & FLUID IMAGING D.S. 14-10 .. ~b ~ ~,~ PRODUCTION PROFILE 96021 5 I 1 D.S. 18-30 cl lC' -- (~ql STATIC PRESSURE SURVEY 960130 I 1 ~ ,, D.S. 18-33 q~-- lcf}~ STATIC PRESSURE SURVEY 960130 I 1 .= __ , Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. December 5, 1995 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Re: Survey Data 18-28, 18-30 Dear Mr. Grant, Enclosed are two hard copies of the above mentioned file(s) Well 18-28PB1 .Well 18-28 5q/Well 18-30 Please call me at 563-3256 if you have any questions or concerns. MWD survey, surface to 10596'. MWD survey, tied into 18-28PB1 at 10154.89', window point 10174', interpolated depth 11965' MWD Survey, surface to 12621' Regards, Sandra Lufkin / ... DEC O $199,5 Alask,q OJJ & Gas Cons. Commission /,,nchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino. Company WELL LOG TRANSMITTAL To: ARCO Alaska Inc. November 2, 1995 Atto: Larry Grant, AOGCC P.O. Box 100360 Anchorage, Alaska 99510-0360 MWD Formation Evaluation Logs - DS 18-30, AK-MM-950732, AK-MW-50063 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 18-30: 2" x 5" MD Gamma Ray Logs: 50-029-22568-00 2" X 5" TVD Gamma Ray Logs: 50-029-22568-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9¢7) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT Date: 19 July 1995 Attn. ALASKA OIL + GAS CONSERVATION RE: Transmittal of Data 3001 PORCUPINE DRIVE ECC #: 6459.00 ANCHORAGE Sent by: PRIORITY MAIL AK, 99501. \ Data: _ OH-LDWG % Dear Sir/Madam, Reference: ilili ~0 Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wir~vices // /~ Anchorage, AK 99518 /// Or tAX to (907) 563-7803 ~. Received by~~ ~ /~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 18 July 1995 Transmittal of Data ECC #: 6459.00 Sent by: PRIORITY MAIL Data: OH-LDWG Dear Sir/Madam, Reference: 18-30 ~ PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 BHC-AC FINAL BL+RF Run # 1 1 CN/GR FINAL BL+RF Run # 1 1 SSVD/MWD FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodn~on .... _~ At l~.~ire 1 ine S e r v i.~ 00 B Street horage, AK 99~16~_7803 FAX to (907) Received bye/ ~~~ ~,~,~ Date: ka Alaska Oil and Gas Conservation Commission TO' THRU: FROM: David Jo~ Chairman ~ Blair Wondzell, ~;¢~ P. I. Supervisor 7/¢,~?¢- Bobby Foster, ~~ Petroleum Inspector DATE: July 19, 1995 FILE NO: SUBJECT: AEFGISCD:doc BOPE Test - Doyon 9 ARCO - PBU - DS18-30 PTD # 95-0091 Prudhoe Bay Field Wednesday, July 19, 1995: I traveled this date to ARCO's PBU DS18-30 and witnessed the BOPE test on Doyon rig 9. As the attached AOGCC BOPE Test Report shows there was 1 failure. The / Methane Gas detector sensor in the rig subase would alarm on Iow alarm (20 PPM) / but would not alarm on high. The sensor was changed out and tested out OK. l The rig, which is being cleaned and painted, was very clean and all equipment seemed to be in good working order. The location was fairly clean since there is a lot of flowline construction on going around the rig. All equipment related to the rig was properly stored in various areas of the pad. Summary: I witnessed the BOPE test on Doyon rig 9 drilling ARCO's DS18-30 - test time 2 hours - 1 failure. Attachment:' AEFIGGSCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: DO¥ON Rig No. Operator: ARCO Well Name: DS 18-30 Casing Size: 7.625" Set @ g, 857' Test: Initial Weekly X Other PTD # Rep.: Rig Rep.: Location: Sec. 95-0091 DATE: 7/19/95 Rig Ph.# 659-4831/4832 CHARLIE DIXON MO R T HEA VILA ND 24 T. 11N R. 14E Meridian UM Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Standing orders posted OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Haz. Sec. OK Test Quan. Pressure P/F I 300/3,000 P I 500/5,000 P I 500/5,000 P I 500/5,000 P 3 500/5,000 P 2 500/5,000 P 3 500/5,000 P N/A FLOOR SAFETY VALVES: Upper Kelly /IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F NOTE NOTE I 500/5000 P I 500/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 14 Test Pressure P/F 50O/5,000 P 36 500/5,000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,150 P Pressure After Closure 1,650 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 30 TripTank YES OK System Pressure Attained 2 minutes 20 Pit Level Indicators YES OK Blind Switch Covers: Master: YES Remote: Flow Indicator YES OK Nitgn. Btrs: 5 ~ 2450Avg. Meth Gas Detector YES OK Psig. H2S Gas Detector YES OK sec. sec. YES Number of Failures: I ,Test Time: 2.5 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: METHANE GAS DETECTOR IN SUB BASE HAD TO BE CHANGED OUT. TESTED OK. NOTE: THE UUPPER AND LOWER KELLY VALVES WILL BE TESTED BEFORE GOING OUT CHASING SHOE. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 7/19) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: GSCD.XLS BOBBY D. FOSTER MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Johnsto~~ Chairma~ Blair Wondzell, P. I. Supervisor .: FROM: Bobby Foster,[~~'~ SUBJECT: Petroleum Inspector DATE: July 1, 1995 FILE NO: EEFIGACD:doc Diverter Inspection & Test ARCO - PBU - DS18-30 PTD # 95-91 Prudhoe Bay Field . . Satruday, July 1, 1995: I traveled to ARCO's DS 18-30 being drilled by Doyon rig 9 and inspected and tested the diverter. · As the attached AOGCC Diverter Inspection Report shows the diverter was installed properly and function tested OK. The rig was clean and the location was clean but there was a lot of construction on going. There was good access to all areas of the rig. Summary: ! inspected and function tested the diverter system on Doyon rig 9 drilling ARCO's DS18-30. Attachment:: EEFIGACD.XLS STATE OF ALASKA , ALASKA oIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Ddg Contractor: Doyon Ddiling Rig No. Operator: Arco Alaska Inc. Oper. Rep.: Well Name: DS18-30 Rig Rep.: Location: Sec. 24 T. 11N R. 15E Date: 7/1/95 Development Yes Exploratory: 9 PTD# 95-0091 Rig Ph. # 659-4831 JERRY HAUBTHER MORT HAVERSON Merdian Umiat MISC. INSPECTIONS: Location Gen.: OK Well Sign: OK Housekeeping: OK (Gen.) Drlg. Rig: OK Reserve Pit: N/A Flare Pit: N/A DIVERTER SYSTEM INSPECTION: Diverter Size: 20 in. Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes Vent Line(s) Size: 16 in. Vent Line(s) Length: 40 ft. Line(s) Bifurcated: No Line(s) Down Wind: Yes Line(s) Anchored: Yes Tums Targeted / Long Radius: N/A ACCUMULATOR SYSTEM: Systems Pressure: 3,000 psig Pressure After Closure: 1,500 1650 psig 200 psi Attained After Closure: ~ min. 36 sec. Systems Pressure Attained: 2 min. 16 sec. Nitrogen Bottles: 5 @ 2400 4 @ 3000 (Stand By Bottles) psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: OK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: OK OK NORTH 16" Hydraulically Operated Full Opening Knife Valve Motor, Pits, Pipe Shed ,~ Complex i i ////I 20" Annular Preventer -- gnition Sources are 00' from Wellbore Prevailing Wind Direction Northeast to Southwest I ~ VSM's Rig & Sub Base Non Compliance Items None Repair Items Within Remarks: Very good diverter system N/A Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - OpedRep c ~ Database c - Trip Rpt File c- Inspector AOGCCREP.: OPERATOR REP.: EEFIGACD.XLS BOBBY D. FOSTER JERRY HAUBTHER dvtdnsp.xlt (rev 1/94) ALASKA OIL ~D GAS CONSERVATION COMMISSION June 21, 1995 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Terry Jordan Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 18-30 ARCO Alaska, Inc. Permit No: 95-91 Sur. Loc. 1499'SNL, 26'WEL, Sec. 24, TllN, R14E, UM Btmhole Loc. 837'SNL, 4420'WEL, Sec. 29, TllN, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 ~cting the Commission petroleum field David W. Jo~fnston Chairman O~ BY ORDER ~ION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill I-lllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. 50. 75 feet Prudhoe Bay FielcYPrudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 28326 4. Location of well at surface R~ ,~¢/_., 7. Unit or property Name 11. Type Bond(see 20 ^AC 25.025) 1499' SNL, 26' WEL, SEC 24, T11N, Prudhoe Bay Unit At top of productive interval 8. Well number Number 5083' SNL, 533' WEL, SEC 19, T11N, R15E 18-30 (11-29-11-15) U-630610 At total depth 9. Approximate spud date Amount 837SNL, 4420' WEL, SEC29, T11N, R15E 06/22/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property'15. Proposed depth (MD and TVD) property line ADL28321 837 feet 18-28, 210'atSurface feet 2560 12653'/8784' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angle 9o o Maximum surface 3307 psig At total depth (TVD) 8072'/4114 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD TVD (include stage data) 30" 20" 91.5# H40 WELD 80' 30' 30' 110' 110' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NT80 NSCC 3919' 30' 30' 3949' 3665' 1113 sx PF 'E'/375 sx 'G' 9-7/8" 7-5/8" 29.7# L-80 NSCC 10738' 30' 30' 10768' 8784' 525 sx Class 'G' 6-3/4" 5-1/2" 17# L-80 NSCT 2035' 10618' 8750' 12653' 8784' 234 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production JUN ~.~ ]995 Liner Ai~s?,a U~i & Gas Cons. Commission Perforation depth: measured Anchorc , true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis l-I Seabed report[] 20 AAC 25.050 requirementsCI 21. I hereby certify that the. foreg.ojncl, is tr.u¢ and correct to the best of my knowledge . Signed ,.~/,,; - 4--,--_ Title Drilling Engineering Supervisor Date Commission Use Only Permit Number APl number Approyal date See cover letter 50-4:~.~-~'--~-. ,~..~z-~ ~, ,~¢--~/- ¢~ for other ?/,, requirements ConSitions of approval Samples required [] Yes .~No Mud log required []Yes ,]~ No Hydrogen sulfide measures ~;a Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; FI3M; ,I~.5M; I-I10M; F115M; Other: Original Signed By by order of_//" Approved by David W. Johnston Commissioner [ne comm,ssion Date . Form 10-401 Rev. 12-1-85 ¢ Submit ir i licate I Well Name: I 18-30 I Well Plan Summary I Type of Well (producer or injector): ] Producer Surface Location: 1499' FNL, 26' FEL, SEC 24, TI IN, R15E, UM Target Location: 5083' FNL, 533' FEL, SEC 19, T11N, R15E, UM Bottom Hole Location: 837' FNL, 4420' FEL, SEC 29, T1 IN, R15E, UM I AFENumber: 14J0291.0 I [Rig: [DOYON9 I Estimated Start Date: I June 22, 199S I Operating days to complete: 128 IMD: I 12653' I ITVD: I8784' I [KBE: I 50.75' Well Design (conventional, sHmhole, etc.): [ Slimhole Horizontal Formation Markers: Formation Tops MD TVD (BKB) Base of Permafrost 1969 1961 10-3/4" Casing 3949 3665 10' tvd above the TT4/T5/SV3 TT4/T5/SV3 3959 3679 UGNU Sands 6295 5494 Ugnu S marker WEST SAK 7316 6288 SEABEE (K-12) 7612 6518 K-10 8171 6952 PUT RIVER 9681 8126 LCU (KINGAK) 9713 8151 SAG RIVER 9804 8221 SHUBLIK 9861 8268 Sadlerochit (Z 4B) 9936 8324 Zone 3 10097 8449 Zone 2 10181 8514 Zone 2B 10237 8558 Zone 2A 10380 8658 Zone lB 10473 8710 CGOC 10406 8670 Beginning of SL 10768 8784 7-5/8" Casing Shoe End of SL 12653 8784 5-1/2" Liner Shoe Base S adlerochit 8795 Not planned to drill into Kavik Gas Cons. Commission Anchon '' Casing]Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H40 WELD 80' 30' 110'/110' 13-1/2" 10-3/4" 45.5# NT80 NSCC 3919 30' 3949/3665' 9-7/8" 7-5/8" 29.7# L-80 NSCC 10738' 30' 10768/8784' 6-3/4" 5 1/2" 17# L80 NSCT 2035' 10618'/8750' 12653'/8784' NA 4 1/2" 12.6# L80 NSCT 10420' surface 10450'/8690' Logging Program: Open Hole Logs: 13-1/2" MW]) Dh' 9-7/8" MWD Dir from surface shoe to 100' above the Sag River MW Dir/GR+CNL from 100' above Sag River to 100' MD below GOC. 6-3/4" MWD Dir/GR Cased Hole Logs: None Mud Program: Special design considerations I MI Flow Pro ® Polymer system in 6-3/4" horizontal hole I section. Surface Mud Properties: ] 13-1/2" hole section Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 8.5 15 to to to to to to to 9.2 300 60 60 80 10 25 Intermediate Mud Properties: 1 9-7/8" hole section Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.2 20 10 5 30 8.5 4 to to to to to to to 10.0 70 30 15 50 10 7 Production Mud Properties: I 6-3/4" hole section Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 10 15 5 30 8 <6 to to to to to to to 9.0 30 20 10 50 9 <6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and drilling fluid system schematics on file with AOGCC. Gas Cons. Cornrn~ss'~on AnchOrr ' Directional: IgoP.· I lO0O'~m I I Maximum Hole Angle: 1 90 degrees Close Approach Well: nearest is 18-28, 210' away at surface The above listed wells will be secured during the close approach. Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments 10-3/4" 1113/12.2/2.17 375/15.8/1.16 Perm & Class "G" 7-5/8" none 525/15.8/1.15 Class "G", to 1000' above Put River 5 1/2" none 234/15.8/1.2 Class "G" Gas Cons. Comrn'~ss'~on , . , . . . , 10. 11. 12. 13. 14. 15. 16. 17. PROPOSED DRILLING AND COMPLETION 18-30 Procedure MIRU drilling rig. N/U diverter and function test same. EC£1vED PROGRAM '~'"~V ~'_Gas Cons. Drill 13-1/2" hole to surface casing point (10' TVD above the SV3). Run and cement 10-3/4" surface casing. Nipple up BOPE and function test same to 5000 psi. PU 9-7/8" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' of new hole and perform leak off test. RIH and directional drill 9-7/8" hole to target (Zone 1). Log using MWD/LWD tools. MU and RIH with 7-5/8" casing string and cement as per well plan. MU 6-3/4" MWD BHA and PU 3-1/2" DP. Clean out to 7-5/8" landing collar and test casing to 3500 psi for 30 min. Drill 10' of new hole. Displace to 8.9 ppg FIo Pro mud system. Drill horizontal section as per directional plat. Run 6-3/4" hole opener to TD of 6-3/4" hole section. Circulate 6-3/4" hole clean. Run 5-1/2", L-80 solid liner assembly to bottom. Space the liner hanger and packer about 150' inside the 7-5/8" casing. Cement the liner in place with the total cement volume based on 30% excess across the reservoir, 150' liner lap, 200' above the liner with drillpipe in the hole, and 80' shoe volume. Set liner hanger and packer. Circulate excess cement from the wellbore. POOH. RIH with 4-3/4" Economill and 7-5/8" scraper spaced out to the top of the liner. Clean out to landing collar. Test liner and liner lap to 3500 psi. RIH with 3-3/8" drillpipe conveyed perforating guns and perforate the 5-1/2" liner. POOH and lay down guns. RIH with 4-1/2" L-80 completion with SSSV, GLMs, and 7-5/8" x 4-1/2" packer. Displace well to clean filtered inhibited seawater. Set packer, test casing and tubing. Set 2-way check valve. ND BOPs. 18. NU tubing head adaptor and tree. Test same. Pull 2-way check valve. Test 19. 20. inner annulus. Shear RP valve. Freeze protect well thru shear valve in top GLM station. Release rig. Notes: Maximum anticipated BHP: 4114 psi @ 8072' ss Maximum surface pressure 3307 psi @ 8072' ss Planned Completion Fluid: 8.6 ppg filtered sea water The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). The Cretaceous/Ugnu interval may be overpressured due to injection. This interval has produced salt-water flows on 18-29 and 18-28. Mud weights of up to 10.0 ppg may be required. No potential hazardous levels of H2S are anticipated in this well. Drilling Hazards: · Minor gas zones have been encountered around the K5 (4775' TVDss) to HRZ interval. · The Put River is a gas bearing sand at 8072' TVDss. It is not well developed in this area and is probably in pressure communication with the Sadelrochit. The required mud weight should be 9.8-10.2 PPg. · Gas zone from Top of Sag River to the current GOC. · Structurally, this well is Iow-risk. There are minor faults in the surrounding area, but they should not be a factor. The nearest major fault is 1200' from the BHS. a, b, c! d, e. K. Bardwell 18-30 Ops Summary June 14, 1995 HALl_ 6114195 5::34 om PR[jPF1SED BHL TVD 8783.99 ND 12652.69 VS 733i.46 N/S 4410.65 E/W 5856,32 J Da±e Ptotted : 6/14/95 N/ELLPLAN FE~IBILITY STUD Y This plan is for legibility purposes only it has not yet been certified! VERTICAL VIEW SCALE 1000 Ct, / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REP WELLHEAD 07 0.00 ~ 0 MD TIE IN I 8483 -- 3~00-- 3142 3679 40(20 4851 0.00 @ 1000 MD KEP / START ~ BUILD @ 1,0C)/100 Pt 2.00 ~ l~O0 ND jUN 1 5 !995 Oil & Gas Cons. Commission Anohor~ '~ tO00 &~]O0 3000 4000 5000 5,00(] ~ 1500(] ND START OF BUED 8 1.50/100 Pt 8.00 @ 1700 MD 11.00 e 19C0 MD END OF Bb1LD l l.OO ~ 8058 MD START OF BUILD ~ 2.00/103 Pt 15.00 @ 2858 HD 20,00 @ 8508 MD START OF BUILD @ 2.50/100 25,00 @ P708 MD 30,03 ~ 2908 MD 35.O0 ~ 3108 MD 39,00 a 3868 MD END UF BUILD 600 39.C0 ~ 3959 MD T-5 1035 39.00 a 4695 MD T-3 499 4771 5494 3148 6518 3334 7499 41L:>9 VERTICAL SECTION PLANE: 186,98 39.00 @ 5364 MD k_15 o~c~_ ~ ~TA ilOO0 4470 I I3000 5000 6OO0 MIl Inc Azi, TVD N/S E/W 1-El IN 0 0,00 IP_7,11 0 0 N 0 ~ / START 1C00 O.CO 1~_7.11 1C()O 0 N 0 1.C0/1 CO Pt START IF ~ 1~0 5,03 127.11 t4C)c) 13 S 17 ~ 1.5o/1co END I~- ~ lgO0 11,03 12_7.11 1895 47 S 6a START [}- BJILD 2058 11.00 187,11 2050 65 S 86 START ~- BUILD 2508 20.00 t27.11 ~483 137 S 18~ END EF BUILD 3E:~o8 30,03 1~7.11 314~ ~ § 479 T-5 3959 39.03 12_7.11 3679 685 S 8E5 T-3 4695 39.03 127,11 4~51 g04 S 1195 k_15 ~ 39.03 127,11 4771 1158 S 1531 ~Uc?s.~S ~ 39,03 127,11 5494 1511 S 1998 Sak 7316 39.03 127,11 6288 11~:)9S i5ll K-I~ 7618 39,03 127,11 6518 201~ S 8659 K-10 BI?I 39,03 127.11 6958 PPP4 S L:~)39 K-5 8874 39.03 127,11 7499 ~4gl S 3293 K-a 9418 J9,03 127,11 79~t E>697 S 3565 K-t c)663 J9.03 127.11 8IlP 2791 S ~ ~ 9675 39.03 127, tl 8iPt 2795 S :3694 Put 968i ~,03 127. tt 81a6 2797 S 3697 LCU / Top g?13 39,03 127.11 8151 2810 Sag ;~ve~ S~c~ k A 9861 39,00 127,11 .~:i:k B ~ ~,03 127,11. ~ ~75 S 3830 Sl,~ciik C 9901 39,03 127,11 BE'9? 8881 S ~ Zc~e 4 / Top c)9:]6 3c).03 127.11 8384 8894 S 38~ Zone 3 10097 39.03 127.11 8449 B:)55 S ~ Zc~e a 10181 39.03 127,11 8514 Tonnco 1C837 STRUT 'ZF' 1P_.~.46 ~c),03 127.1l 8565 301~ S 3981 10.(]0/103 Roreo 10380 58,3D 1L:~,48 8&58 :3070 S 40~ END IF' CURVE 10400 54,33 128,57 1~70 3080 S 4069 Cl]C 10406 54.33 128.57 1~74 3084 S 407~ START []:' t0410 54.33 128,57 8676 ~ S 4076, 10,00/100 Pt Zone ! 10473 END [Y CLRVE 10768 gO,O0 1L:>6.51 8784 3E'~c) S 4341 D-tS l lC)~8 90,03 186,51 8784 8979 S 5~.74 7~95 MD Ugnu S To~qet ~ TV]] NS E'~ C,',ict X C~;d Y ~ 8784 3378 S ~61 E 696..3C0 5956903 EHS 8784 3979 S ~4 E 697128 5956320 Polygon 87~ 33~ S 4351 E 6~190 ~;~6c)0c) ~x~39.00 ~ 7316 MD West S~ 39.00 ~ 761P ND K-12 e 8171 ND K-lO 39,00 ~ 8874 MD K-5 6606 7331 ~ 4000 ~ 6003 7000 8000 BPX-Shared Alaska PBU : 18-30 18-30 Services Drilling State Plane' Zone4 EOA' DS18As-built Wp4 Preliminary 6114/95 5,37 HALLIBURTON ~VELLPLAN FEASI BI LITY STUD Y This plan is for feasibility purposes only it has not yet been certified! 7600 -- 7921 -- 8100 8112 8121----- 8126_~ 8266-- 8285-- 8297-- 8324 -- 8449-- 8514 8558-- 8565 ~ 8600-- 8710 8784 9000 VERTICAL VIEW SCALE 500 ft. / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 39.00' @ 9418 MB K-2 - ~, ~39.00' @ 9663 MD K-1 \ /j39,00' @ 9675 MD BHRZ __ __462._5.~r~.~ ...... ~/39,00' @ 9681MD Put ---~-~ '~- .~F~3.2_---463~--~~_-~39.00' @ 9713 MD LCU / Top Kingok -- -- - 4657 ----- -- ~ /39.00' @ 9804 HD So9 River -- -- --4713-- -- -- -~/ j39.00' 8 9861 MD ShubLik A ~ ~ ~ ~39 00' ~ 9886 MD Shub[ik B -- 4750 ..... ~~39' 00' ~ 9901 MD Shubtik C ~ ~ 4765 4775 ~ ~ ~ ' · ..... 4797 -- _~39,00 ~ 9936 MD Zone 4 / Top S~d x ~ 39.00' ~ 10097 MD Zone 3 .... 4898 ..... ~ 39.00' e lO181 ~D Zone ~ ~ ~.39.00' ~ 10~37 ND T~n9o .... 4951 ..... ~ ~/39,00' ~ 10~46 MD START OF CURVE e iO,O0'/iO0 ~t 49~6 ~ A8.97' ~ 10346 MD ~ = = ~ 499~ .... -- ~ ~5~,30' e 10380 MD Romeo ~ ~.54,33' ~ 10400 MD END OF CURVE 508~ ~54'33' ~ 10406 MD GQC ~ ~ ~ ~--5~3 ~no~,,~ ; ;; ~554.33' 8 10410 MD START DF CURVE ~ 10.00'/100 gt =,~= ~u~ ~c ~60.58' ~ 10473 MD Zone 1 ~oJ ..... ~ /74.30' ~ 10610 MD --~ ~ 90.0~' ~ 10768 MD END OF CURVE 5447 6606 7331 o a 90.00' @ 11928 MD EHS 4000 4500 5000 5500 6000 6500 7000 VERTICAL SECTION PLANE: 126.98 90.00' @ 18653 MD o 7500 8000 Halliburton Travelling Cylinder Report Computed using WIN. CADDS REV2. I.B Page 1 Date: 6/14/95 Time: 5:29 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 PBU: EOA: DS18 18-30 As-built 18-30 Wp4 Preliminary N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 12652.69 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Well Safety Min. Clear Spread MD TVD 18-03A MWD 1896.8 1954.7 18-27 816.6 829.7 18-26ST 978.6 991.7 18-26 983.0 995.5 18-25 884.5 897.6 18-24 794.0 806.5 18-23A 929.2 943.0 18-23 931.4 945.1 18-22 534.0 563.1 18-21 -17.6 49.0 / 18-20 355.5 385.7 18-19 332.1 345.2 18-18 1298.5 1312.2 18-17 445.6 459.9 18-16A 1018.5 1033.5 18-16 1022.1 1036.5 18-15 931.3 945.7 18-14 831.4 846.4 18-13 180.6 241.0 18-12 674.2 683.0 18-11 491.6 537.2 18-10 1353.9 1367.6 18-09A 1241.0 1254.1 18-09 1244.1 1256.6 18-08 1107.8 1120.9 18-07 993.4 1006.6 18-06 871.2 884.9 18-05 707.0 724.5 18-04 632.7 646.4 18-03 508.5 522.3 18-02 391.1 404.8 18-01 271.6 285.4 WKUPST-01 107076.8107090.0 WETW 82475.5 82490.5 WENOMWRD 78679.5 78697.6 VEi~O~v~,,O~ 7§596.0 '"~':~' o TW-C 75838.2 75851.3 TW-A 28084.3 28106.1 SEEILEEN-2 70551.2 70572.4 SEEILEEN-1 71441.3 71454.4 SD311116 35913.3 35925.8 SD311016 54899.8 54912.3 SAGR-01 19759.2 19771.7 SAGD-05 32347.4 32403.9 SAGD-02A 49003.6 49016.1 SAGD-02 49002.3 49014.8 SAGD-01 45054.1 45066.6 PWDW-1-2A 11205.6 11264.1 PWDW-1-2 10889.3 10950.0 PW-3-1 21024.0 21040.9 Flowing Shut-in Enter Enter Exit Exit Safety Safety Shut-in Danger Danger Shut-in Dist Dist Zone Zone Zone Zone MD MD MD MD 9150 7713 80.7 22.9 1050 1050 15.8 2.6 1050 1050 15.8 2.6 1000 1000 15.0 2.5 1050 1050 15.8 2.6 1000 1000 15.0 2.5 1100 1100 16.5 2.7 1100 1100 16.5 2.7 2550 2523 35.5 6.4 12653 8784 98.3 31.6 2700 2661 37.0 6.7 1050 1050 15.8 2.6 1100 1100 16.5 2.7 1150 1150 17.3 2.9 1200 1200 18.0 3.0 1150 1150 17.3 2.9 1150 1150 17.3 2.9 1200 1200 18.0 3.0 10150 8490 85.7 25.4 700 700 10.5 1.8 4750 4294 57.5 11.9 1100 1100 16.5 2.7 1050 1050 15.8 2.6 1000 1000 15.0 2.5 1050 1050 15.8 2.6 1050 1050 15.8 2.6 1100 1100 16.5 2.7 1400 1400 21.0 3.5 1100 1100 16.5 2.7 1100 1100 16.5 2.7 1100 1100 16.5 2.7 1100 1100 16.5 2.7 1050 1050 15.8 2.6 1200 1200 18.0 3.0 1450 1450 21.8 3.6 '~ ~n 1350 '~0 ~ 1050 1050 15.8 2.6 1750 1748 26.3 4.4 1700 1698 25.5 4.2 1050 1050 15.8 2.6 1000 1000 15.0 2.5 1000 1000 15.0 1000 1000 15.0 2.5 8600 7286 78.0 21~5 1000 1000 15.0 2.5 1000 1000 15.0 2.5 1000 1000 15.0 2~ 9400 7907 82.0 23.5 10250 8568 86.2 25.6 1350 1350 20.3 3.4 12550 Close Approach Status OK OK OK OK OK OK OK OK oF s -iN 0. K.- OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK Halliburton Travelling Cylinder Report Computed using WIN. CADDS REV2.1.B Page 2 Date: 6/14/95 Time: 5:29 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 PBU: EOA: DS18 18-30 As-built 18-30 Wp4 Preliminary N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 12652.69 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Well Safety Min. Clear Spread MD TVD PW-2-1 16772.4 16784.9 PW-I-1 10545.8 10606.4 PRST01 35976.7 35991.7 PR331213 52956.5 52969.6 PR331113 50999.7 51013.5 PR271114 16053.7 16067.5 PR241014 34358.9 34371.4 PR191015 31014.0 31026.5 PR181015 30997.7 31010.2 PR141014 28412.1 28472.6 PR121014 19971.9 20024.3 PRlll014 19320.9 19381.6 PLAGHM-01 48855.7 48869.5 PBST01-OH 15583.8 15596.9 PBST01 15624.7 15637.8 NWEILEEN-2 115411.3115424.4 NWEILEEN-1 115361.2115374.3 Flowing Shut-in Enter Enter Exit Exit Close Safety Safety Shut-in Danger Danger Shut-in Approach Dist Dist Zone Zone Zone Zone Status MD MD MD MD NPBST02 27047.5 27066.3 NPBST01 31192.8 31205.9 NKUPST 76277.6 76290.8 MP43311113 57589.8 57602.9 MP32301113 59776.3 59798.8 MP22311113 60244.4 60256.9 MPl1331112 80560.1 80573.2 MP00151112 78714.1 78734.1 MP00031012 77351.1 77373.0 LAKEST-01 43354.6 43367.1 KUPST-01 82475.8 82489.0 KUPRST-01 58736.0 58749.1 K331112 80686.1 80699.2 K301113 60396.1 60409.8 K241112 64481.5 64502.8 K221112 72503.5 72517.3 K091112 81728.4 81741.6 K071112R ._ 92550.1 92568.8 K071ii2 92621.1 92639.9 JX-02ST 49812.4 49825.5 HURLST-01R 57703.1 57716.2 HURLST-01 57703.2 57716.3 HIGHLANDST 95198.4 95211.5 GULL-03 27622.0 27631.4 GULL-02 23149.8 23202.9 GULL-01 27527.8 27541.0 GETTY-01 44716.8 44730.5 EBAYST-01 13947.4 14011.3 DEADH31-25 35937.4 35949.9 CHEV181112 92376.6 92394.1 CC-02A 52948.1 52961.3~ ABEL-01 28226.4 28239.6 A/ETR3C 8005.9 8060.2 1000 1000 15.0 2.5 OK 10250 8568 86.2 25.6 OK 1200 1200 18.0 3.0 OK 1050 1050 15.8 2.6 OK 1100 1100 16.5 2.7 OK 1100 1100 16.5 2.7 OK 1000 1000 15.0 2.5 OK 1000 1000 15.0 2.5 OK 1000 1000 15.0 2.5 OK 10200 8529 86.0 25.5 OK 6950 6003 69.7 17.4 OK 10250 8568 86.2 25.6 OK 1100 1100 16.5 2.7 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1500 1499 22.5 3.7 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1800 1797 27.0 4.5 OK 1000 1000 15.0 2.5 OK 1050 1050 15.8 2.6 OK 1600 1599 24.0 4.0 OK 1750 1748 26.3 4.4 OK 1000 1000 15.0 2.5 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1100 1100 16.5 2.7 OK 1700 1698 25.5 4.2 OK 1100 1100 l&5 2.7 OK 1050 1050 15.8 2.6 OK 1500 1499 22.5 3.7 OK 1500 1499 .-~.~" ~ 3.'~. OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 750 750 113 1.9 OK 7250 6237 71.2 18.~ ! OK 1050 1050 15.8 2.6 ' OK 1100 1100 16.5 Zi7 OK 11550 8784 92.7 28.9 OK 1000 1000 15.0 2.5 OK 1400 1400 21.0 3.5 OK 1050 1050 15.8 2.6 OK 1050 1050 15.8 2.6 OK 7700 6586 73.5 19.3 OK Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2. I.B Page 3 Date: 6/14/95 Time: 5:29 am Normal Plane Method REFERENCE WELL: ~ BPX-Shared Services Drilling Alaska State Plane: Zone4 PBU: EOA: DS18 18-30 As-built 18-30 Wp4 Preliminary N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 12652.69 ft.(MD) All Directions using BP Highside Method in Dec. Deg. Ail Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Well Safety Min. Clear Spread MD TVD 33-29E 119915.6119933.1 1400 1400 NPBST03 23180.5 23193.6 1050 1050 LPC-01 1500.5 1555.1 7850 6703 LPC-02 717.6 767.0 5750 5071 L2-33 3889.0 3904.0 1200 1200 L2-32 3961.9 3969.4 600 600 L2-30 3891.8 3904.9 1050 1050 L2-29 3778.7 3793.1 1150 1150 L2-28 3842.2 3854.7 1000 1000 L2-26 3784.3 3798.7 1150 1150 L2-25 3676.6 3691.0 1150 1150 L2-24 3735.9 3750.9 1200 1200 L2-21 3570.4 3584.2 1100 1100 L2-20 3629.0 3645.8 1350 1350 L2-18 3588.1 3600.6 1000 1000 L2-16 3537.7 3552.0 1150 1150 L2-14 3480.9 3495.9 1200 1200 L2-13 3157.8 3195.6 3700 3478 L2-10 2608.0 2666.7 9450 7946 L2-08 3343.1 3356.3 1050 1050 L2-06 3282.6 3298.9 1300 1300 L2-03 1593.8 1645.7 6750 5848 18-29 219.1 232.2 1050 1050 18-29A 219.1 232.2 1050 1050 18-31 Wp3 126.4 139.6 1050 1050 18-32 Wp2 37.8 50.9 1050 1050 18-34 Wp5 71.1 82.4 900 900 18-28 Wp5 188.8 202.0 1050 1050 18-28RigMw 176.4 190.7 1150 1150 18-33 Wp3 98.5 111.0 1000 1000 Flowing Shut-in Enter Enter Exit Exit Safety Safety Shut-in Danger Danger Shut-in Dist Dist Zone Zone Zone Zone MD MD MD MD 21.0 3.5 15.8 2.6 74.2 19.6 63.7 14.4 18.0 3.0 9.0 1.5 15.8 2.6 17.3 2.9 15.0 2.5 17.3 2.9 17.3 2.9 18.0 3.0 16.5 2.7 20.3 3.4 15.0 2.5 17.3 2.9 18.0 3.0 47.0 9.3 82.2 23.6 15.8 2.6 19.5 3.2 68.7 16.9 15.8 2.6 15.8 2.6 15.8 2.6 15.8 2.6 13.5 2.2 15.8 2.6 17.3 2.9 15.0 2.5 Close Approach Status OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK WELL PERMIT CHECKLIST COMPANY INIT CLASS PROGRAM: exp [] dev~ redrll [] serv [] ~MINiSTRAT'ION' '' ENGINEERING 1. 3- 4. 5. 6. ~ 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary.. 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 APPR D~ ~ ~EOLOGY" 14. Conductor string provided ............... ~/ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.. ~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. Y~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..~f~,~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..~ N 25. BOPEs adequate ............. ~ ......... ~ N 26. BOPE press rating adequate; test to ~ ~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ ~'~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ .~ N 30. Permit can be issued w/o hydrogen sulfide measures .... N/Y N 31. Da~a presented on potential overpressure zones ..... ~/~../~} ~ 32. Seismic analysis gf shallow gas zones ........../z ~ / [./,/-/ , 33. Seabed condition survey (if off-shore) ....... ./Y N 34. Contact name/phone for weekly progress reports . . ./.. Y N [exploratory only] / -'"':'~S~cheklist my 03/94 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. .?ape Subfile 2 is t~pe: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPEP~ATOR WITNESS: MWD RUN 4 6686.00 M. GABEL C. DIXON D.S. 18-30 500292256800 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 23-MAY-96 MWD RUN 5 R. KRELL C. DIXON MWD RUN 6 R. KRELL C. DIXON JOB NUMBER:- LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 R. KRELL C. DIXON MWD RUN 8 de CHAMPLAIN C. DIXON MWD RUN 9 de CHAMPLAIN C. DIXON MWD RUN 10 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 de CHAMPLAIN C. DIXON 24 llN 14E 1499 26 53.45 50.65 16.00 JUN 0 4 199G ~' ...... Oil & ,~,~r~ . {.5~,:~ COrR, L COFF!rFii$SiOFi Anchorage OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 30.000 20.000 110.0 2ND STRING 13.500 10.750 3930.0 3RD STRING 9.875 7.625 9856.0 PRODUCTION STRING 6.750 12621.0 REMARKS: MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. DEPTHS ARE MEASURED FROM KELLY BUSHING. MWD RUNS 1 THROUGH 3 WERE WERE MUD PULSE TELEMETRY (MPT) DIRECTIONAL ONLY. MWD RUN 4 WAS MUD PULSE TELEMETRY (MPT) DIRECTIONAL WITH DUAL GAMMA RAY (DGR/SGRC). MWD RUNS 5 THROUGH 10 WERE DGWD DIRECTIONAL WITH GAMMA RAY (NGP/SGRD) . FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 7681.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 7681.0 7675.0 9561.0 9555.5 9585.5 9579.5 9604.0 9598.0 9633.5 9628.5 9648.0 9643.0 9664.5 9659.5 9681.0 9676.0 9756.0 9749.0 9766.0 9759.0 9817.0 9813.5 9833.5 9831.0 9847.5 9843.5 9856.0 9852.0 9863.0 9861.0 9877.0 9875.5 9885.5 9884.0 9890.0 9888.5 9898.0 9897.0 9931.5 9932.0 9954.5 9957.0 9963.0 9965.0 9972.5 9974.5 10006.0 10007.0 10010.0 10011.0 10026.0 10027.0 10064.5 10064.0 10163.0 10165.5 10217.0 10218.5 10239.5 10240.0 10251.0 10252.5 10260.5 10262.0 10288.0 10288.0 10298.5 10299.5 10317.5 10318.0 10325.5 10326.5 10329.0 10330.0 10344.5 10345.0 10348.0 10348.5 10367.0 10365.5 10388.5 10387.5 10392.0 10390.0 10418.0 10417.5 10428.0 10427.0 all bit runs merged. STOP DEPTH 12559.0 (open hole, WALS, 15-JUL-95) EQUIVALENT UNSHIFTED DEPTH 104 104 104 105 105 105 106 126 $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD $ REMARKS: 53.5 74.0 93.5 43.5 54.0 70.5 04.5 20.5 10453~5 10473.5 10494.5 10545.5 10556.0 10574.5 10605.0 12621.0 DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP MERGE BASE 4 7755.0 9866.0 5 9866.0 10201.0 6 10201.0 10579.0 7 10579.0 10794.0 8 10794.0 11543.0 9 11543.0 11926.0 10 11926.0 12621.0 MERGED PASS. ROP WAS SHIFTED WITH GR. /??SHIFT. OUT $ CN : ARCO ALASKA, WN : D.S. 18-30 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: INC. Name Tool 1 GR MWD 2 ROP MWD Code Samples Units Size 68 1 AAPI 4 68 1 FPHR 4 DATA RECORD (TYPE# Total Data Records: 0) 1014 BYTES * 118 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 12621.000000 Tape File End Depth = 7675.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29680 datums Tape Subfile: 2 268 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE StZVnVLARY VENDOR TOOL CODE START DEPTH GR 7675.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 4. 10-JUL-95 ISC 2.02 CIM 3.94 MEMORY 9866.0 7755.0 9866.0 0 34.3 39.7 TOOL NUMBER P0378CG6 9.875 3930.0 LSND 10.50 48.0 9.5 1400 3.6 .000 .000 .000 .000 .0 141.0 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length TIP Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 53 Tape File Start Depth = 9870.000000 Tape File End Depth = 7675.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13174 datums Tape Subfile: 3 116 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9634.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10129.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 5. 13-JUL-95 ISC 2.02 CIM 3.94 MEMORY 10201.0 9866.0 10201.0 0 38.3 42.8 TOOL NUMBER NGP 182 6.750 9856.0 FLO - PRO 9.00 62.0 9.3 41000 5.6 .000 .000 .000 .000 .0 124.9 .0 .0 .00 .000 .0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 14 Tape File Start Depth = 10205.000000 Tape File End Depth = 9630.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 33134 datums Tape Subfile: 4 77 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10078.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWlqHOLE 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) MINIM UMANGLE: MAXIMUM ANGLE: STOP DEPTH 10522.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 6. 14 -JUL- 95 ISC 2.02 CIM 3.94 MEMORY 10579.0 10201.0 10579.0 0 43.6 69.8 TOOL NUMBER NGP 182 6.750 9856.0 FLO-PRO 9.10 66.0 10.0 44000 .0 ,000 .000 .000 .000 .0 129.0 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 13 Tape File Start Depth = 10585.000000 Tape File End Depth = 10075.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16238 datums Tape Subfile: 5 76 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10523.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUMANGLE: STOP DEPTH 10737.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 7. 15-JUL-95 ISC 2.02 CIM 3.94 MEMORY 10794.0 10579.0 10794.0 0 72.6 89.8 TOOL NUMBER NGP 182 6.750 9856.0 FLO-PRO 9.10 46.0 10.0 44000 5.0 .000 .000 .000 .000 .0 129.0 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 18-30 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 10800.000000 Tape File End Depth = 10520.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34818 datums Tape Subfile: 6 70 records.'.. Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10734.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMIIMANGLE: STOP DEPTH 11480.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MI/D TYPE: MUD DENSITY (LB/G): MLTD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 8. 17-JUL- 95 ISC 2.02 CIM 3.94 MEMORY 11543.0 10794.0 11543.0 0 87.3 92.5 TOOL NUMBER NGP 42 6.750 9856.0 FLO- PRO 9.20 63.0 10.0 43000 5.0 .000 .000 .000 .000 .0 133.2 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 18-30 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 20 Tape File Start Depth = 11550.000000 Tape File End Depth = 10730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 21162 datums Tape Subfile: 7 83 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11480.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11864.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 9. 19-JUL-95 ISC 2.02 CIM 3.94 MEMORY 11926.0 11543.0 11926.0 0 86.3 97.0 TOOL NUMBER NGP 182 6.750 9856.0 FLO-PRO 9.20 60.0 10.0 42000 4.8 .000 .000 .000 .000 .0 145.9 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 Tape File Start Depth = 11930.000000 Tape File End Depth = 11475.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 37552 datums Tape Subfile: 8 74 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11864.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12559.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 10. 20-JUL-95 ISC 2.02 CIM 3.94 MEMORY 12621.0 11926.0 12621.0 0 90.5 94.3 TOOL NUMBER NGP 42 6.750 9856.0 FLO-PRO 9.20 63.0 10.0 41000 5.0 .000 .000 .000 .000 .0 150.1 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 19 Tape File Start Depth = 12621.000000 Tape File End Depth = 11860.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 25732 datums Tape Subfile: 9 82 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 10 is type: LIS 96/ 5/23 01 **** REEL TRAILER **** 96/ 5/25 01 Tape Subfile: 10 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sat 25 MAY 96 2:13a Elapsed execution time = 2.03 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE 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 RUN 1 6459.00 R. ECK B. GRABB D.S. 18 - 30 500292256800 ARCO ALASKA INC. WESTERN ATLAS LOGGING SERVICES 18-JUL-95 RUN 2 RUN 3 24 liN 14E 1499 26 53.40 50.60 16.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.625 PRODUCTION STRING 6.750 REMARKS: AC/CN/GR CIRCULATION STOPPED @ 03:30, 15-JUL-95. 9857.0 10794.0 LOGS WERE DRILLPIPE CONVEYED. DOWN LOG USED AS REPEAT PASS. SPIKES ON GR AND CNC ON DOWN LOG DUE TO PCL OPERATION. GR ABNORMALLY HIGH ON DOWN PASS DUE TO NEUTRON ACTIVATION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, *CASED HOLE BOREHOLE CORRECTION = 9.875", CHISM FILTERING IS ACTIVE, CASING CORRECTIONS ON CASING THICKNESS = 0.375" CEMENT THICKNESS = 1.125", SALINITY = 0.00 PPM. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX~ *OPEN HOLE BOREHOLE CORRECTION = 6.750", CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS 2435 $ depth shifted and clipped curves; .5O0O START DEPTH STOP DEPTH 9861.0 10749.0 9861.0 10784.0 9861.0 10755.0 BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH DT NPHI 9876.5 9876.5 9898.5 9898.0 9898.0 9902.0 9902.0 9902.0 9935.5 9935.5 9935.5 9953.5 9953.0 9964.0 9964.5 9963.5 9966.5 9966.5 9968.0 9966.5 9968.5 9969.0 9977.0 9976.0 10006.0 10006.5 10006.0 10008.0 10008.5 10008.0 10010.0 10010.5 10010.5 10010.0 10024.5 10024.0 10028.0 10027.5 10030.0 10028.5 10041.5 10041.0 10064.5 10064.0 10073.5 10073.0 10073.0 10094.5 10093.5 10125.5 10125.5 10163.0 10163.0 10162.5 10182.0 10182.0 10206.0 10205.5 10213.0 10213.5 10223.0 10227.0 10239.5 10249.5 10266.0 10281.0 10292.5 10295.5 10302.0 10314.0 10323.0 10329.0 10344.5 10349.5 10354.0 10239.0 10266.0 10314.5 10323.5 10329.0 all runs merged; 10223.0 10227.0 10239.0 10249.5 10266.0 10280.0 10292.0 10294.5 10302.0 10314.5 10323.5 10329.0 10345.0 10349.0 10354.0 no case 10363.5 10367.0 10367.5 10371.0 10380.5 10390.0 10394.0 10407.5 10413.5 10417.5 10419.5 10424.5 10428.0 10437.0 10454.0 10457.0 10470.0 10488.5 10490.5 10501.0 10506.0 10518.0 10520.5 10524.5 10529.0 10545.0 10546.5 10554.0 10602.5 10691.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS 2435 $ REMARKS: 10362.0 10365.5 10367.5 10370.0 10380.0 10387.5 10391.0 10407.5 10411.5 10417.0 10417.0 10419.5 10419.5 10425.0 10424.0 10428.0 10436.5 10436.5 10454.0 10454.0 10458.0 10458.0 10470.5 10488.5 10488.5 10490.5 10490.5 10501.5 10500.5 10506.0 10506.0 10518.5 10519.5 10525.0 10529.0 10545.0 10545.0 10547.0 10555.0 10554.0 10601.5 10601.5 10691.0 10691.0 RUN NO. PASS NO. MERGE TOP 1 3 9861.0 1 3 9861.0 1 3 9861.0 OPEN HOLE portion of MAIN PASS. MTEM, TEND, & TENS WERE SHIFTED WITH DT. FUCT & NUCT WERE SHIFTED WITH NPHI. MERGE BASE 10749.0 10784.0 10755.0 CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2. OUT $ : ARCO ALASKA INC. : DS 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 MTEM BCS 68 1 DEGF 4 4 TEND BCS 68 1 LB 4 5 TENS BCS 68 1 LB 4 6 NPHI 2435 68 1 PU-S 4 7 FUCT 2435 68 1 CPS 4 8 NUCT 2435 68 1 CPS 4 4 57 310 01 1 4 57 530 16 1 4 57 995 99 1 4 57 995 99 1 4 57 995 99 1 4 43 995 99 1 4 43 995 99 1 4 43 995 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 67 Tape File Start Depth = 10794.000000 Tape File End Depth = 9861.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16804 datums Tape Subfile: 2 240 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9553.0 2435 9559.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH NPHI 9601.5 9601.5 9611.0 9611.0 9634.5 9634.5 9664.0 9665.0 9676.5 9677.0 9688.0 9688.0 9735.0 9734.0 9751.0 9748.0 9762.0 9760.0 9765.0 9763.0 9768.5 9766.5 9845.5 9845.5 9856.0 9856.5 $ REMARKS: STOP DEPTH 9861.0 9861.0 EQUIVALENT UNSHIFTED DEPTH CASED HOLE portion of MAIN PASS. FUCT, NUCT, TEND, & TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH3. OUT $ : ARCO ALASKA INC. : DS 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TEND 2435 68 1 LB 4 6 TENS 2435 68 1 LB 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 20 4 43 310 01 4 43 995 99 4 43 995 99 4 43 995 99 4 43 995 99 4 43 995 99 24 Tape File Start Depth = 9861.000000 Tape File End Depth = 9506.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4978 datums Tape Subfile: 3 63 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9552.0 9848.0 9558.0 AC 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT TEMP GR CN KNJT PCM KNJT AC $ SWIVEL SUB CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT PULSE CODE MODULATOR KNUCKLE JOINT BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT)' LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 10749.0 10784.5 10756.0 15-JUL-95 FSYS REV. J001 VER. 1.1 330 15-JUL-95 1816 15-JUL-95 10794.0 10792.0 9560.0 10785.0 1500.0 TOOL NUMBER 3944XA 3974XA 2806XA 1309XA 2435XA 3921NA 3506XA 3921NA 1609EA/1603MA 6.750 9857.0 .0 FLO-PRO 9.10 65.0 9.8 5.2 171.0 .102 66.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. (THE CURVE CNCF WAS NOT RECORDED). $ CN WN FN COUN STAT : ARCO ALASKA INC. : DS 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA .039 .094 .000 . 110 .000 THERMAL SANDSTONE .00 6.750 .0 171.0 62.0 .0 67.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 TEMP AC 68 1 DEGF 4 4 CHT AC 68 1 LB 4 5 TTEN AC 68 1 LB 4 6 SPD AC 68 1 F/MN 4 7 CNC 2435 68 1 PU-S 4 8 CN 2435 68 1 PU-L 4 9 LSN 2435 68 1 CPS 4 10 SSN 2435 68 1 CPS 4 4 60 310 01 1 4 60 520 99 1 4 60 660 99 1 4 60 635 99 1 4 60 635 99 1 4 60 636 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 4O * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 225 Tape File Start Depth = 10794.000000 Tape File End Depth = 9506.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 73488 datums Tape Subfile: 4 304 records... Minimum record length: 50 bytes Maximum record length: 1018 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10121.0 AC 10156.0 2435 10127.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 10750.0 10785.0 10757.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT TEMP GR CN KNJT PCM KNJT AC $ SWIVEL SUB CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT PULSE CODE MODULATOR KNUCKLE JOINT BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: 15-JUL-95 FSYS REV. J001 VER. 1.1 330 15-JUL-95 1731 15-JUL-95 10794.0 10792.0 9560.0 10785.0 1500.0 TOOL NUMBER 3944XA 3974XA 2806XA 1309XA 2435XA 3921NA 3506XA 3921NA 1609EA/1603MA 6.750 9857.0 .0 FLO-PRO 9.10 65.0 9.8 5.2 171.0 .102 .039 .094 66.0 171.0 62.0 MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : DS 18-30 : PRUDHOE BAY : NORTH SLOPE : ALASKA .000 .110 .000 THERMAL SANDSTONE .00 6.750 .0 .0 67.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 TEMP AC 68 1 DEGF 4 4 CHT AC 68 1 LB 4 5 TTEN AC 68 1 LB 4 6 SPD AC 68 1 F/MN 4 7 CNC 2435 68 1 PU-S 4 8 CN 2435 68 1 PU-L 4 9 LSN 2435 68 1 CPS 4 10 SSN 2435 68 1 CPS 4 4 60 310 01 1 4 60 520 99 1 4 60 660 99 1 4 60 635 99 1 4 60 635 99 1 4 60 636 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 4O * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 126 Tape File Start Depth = 10792.000000 Tape File End Depth = 10072.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 5 Minimum record length: Maximum record length: 3667u datums 202 records... 62 bytes 1018 bytes Tape Subfile 6 is type: LIS 95/ 7/18 01 **** REEL TRAILER **** 95/ 7/18 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 18 JLY 95 2:30p Elapsed execution time = 6.98 seconds. SYSTEM RETURN CODE = 0 ~i~B}OD' ' * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : D . S . 18 - 30 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 500292256800 REFERENCE NO : 96148 RECEIVED JUL 1 9 199~ Alsska Oil & Gas Cons~ C.,orrirnission Anchorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 96/07/17 ORIGIN . FLIC REEL NA~E : 96 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, D.S. 18-30, PRUDHOE BAY, 50-029-22568-00 **** TAPE HEADER **** SERVICE NA~iE : EDIT DATE : 96/07/17 ORIGIN : FLIC TAPE NAME : 96 CONTINUATION # : 1 PREVIOUS TAPE : COMFfl~f : ARCO ALASKA INC, D.S. 18-30, PRUDHOE BAY, 50-029-22568-00 TAPE H~ER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D . S . 18 - 30 API NUMBER: 500292256800 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 11 -JUL- 96 JOB NUMBER: 96148 LOGGING ENGINEER: BAILEY OPERATOR WITArESS : MOXLOW/HARR SURFACE LOCATION SECTION: 24 TOWNSHIP: 1 iN RANGE: 14E FArL: 1499 FSL: FEL: 26 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 53.40 DERRICK FLOOR: 50.60 GROUND LEVEL: 16. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 10. 750 3930.0 45.50 2ND STRING 7. 625 9857. 0 29. 70 3RD STRING 5. 500 12621 . 0 17. O0 PRODUCTION STRING 4. 500 9649.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NI3MBER : DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH TDTP 88888.0 88899.0 10621 . 0 10632.0 10592.5 10602.5 10558.5 10567.0 10551 . 5 10558.5 10547.0 10554.0 10513.0 10521.0 10486.5 10494.0 10466.0 10473.5 10446.5 10454.0 10415.0 10424.5 10385.0 10391.5 10359.5 10367.0 10342.0 10349.5 10338.0 10344.0 10324.0 10331.5 10311.0 10317.5 10301.0 10308.5 10274.0 10279.5 10253 . 5 10261 . 0 10232.5 10239.5 100.0 107.0 $ REMARKS~ This diskette contains the ldwg formatted edit (TDTP-Borax) on ARCO Alaska Inc D.S. 18-30. The tape contains edited baseline pass #1, 2 edited borax passes, and the average pass. The TENS, CCL and LCO1 curves have been deleted from each pass. The depth adjustments shown above reflect cased hole SIGM to operator provided baseline GR baseline GR. All other TDTP curves were carried with the SIGM shifts. No GR was run. Baseline GR provided by ARCO. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NU14~ER .. 1 DEPTH INC~: O. 5000 FILE SUNR4ARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 12278.0 10224.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUbIBER : BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... TDTP REFiAPJ<S: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA No ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 80 1 0.5 FT 12 0 FT 68 1 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100388 SIGM TDTP CU 100388 TPHI TDTP PU-S 100388 SBHF TDTP CU 100388 SBH~ TDTP CU 100388 SIGC TDTP CU 100388 SIBH TDTP CU 100388 TRAT TDTP 100388 SDSI TDTP CU 100388 BACK TDTP CPS 100388 FBAC TDTP CPS 100388 TCAN TDTP CPS 100388 TCAF TDTP CPS 100388 TCND TDTP CPS 100388 TCFD TDTP CPS 100388 TSCN TDTP CPS 100388 TSCF TDTP CPS 100388 INND TDTP CPS 100388 INFD TDTP CPS 100388 GR BCS GAPI 100388 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12289. 000 SIGM. TDTP 22. 697 TPHI. TDTP O. 000 SBHF. TDTP SBHN. TDTP 110. 510 SIGC. TDTP O. 002 SIBH. TDTP 151. 090 TRAT. TDTP SDSI. TDTP 1 . 087 BACK. TDTP 60. 450 FBAC. TDTP 16. 522 TCAN. TDTP TCAF. TDTP O. 000 TCND. TDTP - 72 O. 973 TCFD. TDTP - 174 . 363TSCN. TDTP TSCF. TDTP O. 000 INND. TDTP -2. 055 INFD. TDTP -0. 562 GR.BCS DEPT. 9861 . 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP SBHT~. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP -999. 250 GR. BCS 71.297 0.000 0.000 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 348.567 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 5 DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 12280.0 10232.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: SIGM PASS NU~ER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH TDTP 88888.0 88907.5 12230.5 12250.0 12204.0 12222.0 12200.0 12218.5 12182.5 12198.0 12172.0 12189.5 12170.0 12188.0 12143.0 12155.0 12117.5 12135.5 12088.5 12108.0 12071.5 12090.0 12049.5 12070.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: 12015.0 11978.0 11945.5 11942.5 11907.0 11879.5 11853.0 11829.5 11819.5 11783.5 11681.0 11657.0 11623.0 11602.5 11592.0 11527.5 11501.0 11451.0 11412.5 11410.0 11336.0 11311.0 11294.0 11180.5 11154.0 11069 5 11050 0 11021 0 10995 5 10973 5 10864 0 10833.5 10774.5 10742.5 10686.5 10597.5 10538.5 10506.5 10492.0 10460.5 10450.0 10415.0 10403.5 10379.0 10353.5 10331.5 10305.0 10288.0 10268.0 10247.5 10245.5 100.0 $ 12034.5 11996.0 11961.5 11960.0 11920.5 11890.0 11866.5 11841.5 11832.5 11799.0 11695.5 11674.5 11643.0 11618.0 11604.0 11536.0 11515.5 11466.5 11428.0 11425.0 11351.5 11325.5 11309.0 11196.0 11169.0 11084.5 11065.5 11036.5 11013.5 10989.0 10881.5 10848.5 10791.0 10759.5 10703.0 10615.5 10550.5 10520.5 10505.0 10473.5 10463.0 10430.0 10419.0 10391.5 10367.0 10344.0 10318.0 10300.5 10280.0 10261.0 10258.5 113.0 ~S: This file contains Borax Pass #2 of the TDTP. The depth LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: adjustments shown above reflect Borax Pass #1 SIGM to Base Pass #2 SIGM. Ail other TDTP curves were carried with the SIGM shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100388 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 100388 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 100388 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 100388 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 100388 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 100388 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 100388 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 100388 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 100388 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TSCF TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 100388 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12299. 500 SIGM. TDTP 22.710 TPHI. TDTP O. 000 SBHF. TDTP SBHN. TDTP 300. 407 SIGC. TDTP O. 000 SIBH. TDTP 445. 820 TRAT. TDTP SDSI. TDTP O. 141 BACK. TDTP 400. 348 FBAC. TDTP 84 . 426 TCAN. TDTP TCAF. TDTP O. 000 TCND. TDTP -1540. 508 TCFD. TDTP -441. 534 TSCN. TDTP TSCF. TDTP O. 000 INND. TDTP -13. 609 INFD. TDTP -2. 870 DEPT. 10249.000 SIGM. TDTP 33.930 TPHI. TDTP 26.453 SBHF. TDTP SBHN. TDTP 89.090 SIGC. TDTP 0.027 SIBH. TDTP 185.617 TRAT. TDTP SDSI. TDTP 0.951 BACK. TDTP 193.689 FBAC. TDTP 38.328 TCAN. TDTP TCAF. TDTP 3691.594 TCND.TDTP 8352.039 TCFD.TDTP 2722.462 TSCN. TDTP TSCF. TDTP 467.248 INND. TDTP 1892.616 INFD.TDTP 300.032 249.311 0.000 0.000 0.000 72.747 1.213 8413.014 989.693 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SU~f4ARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 12290.0 10538.0 $ CURVE SHIFT DATA - PASS TO PASS (~IEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: SIGM PASS NO?4~ER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH TDTP 88888.0 88895.0 12275.0 12282.0 12247.5 12262.5 12227.5 12242.0 12209.5 12222.5 12204.5 12218.0 12176.5 12189.5 12174.0 12188.0 12127.0 12135.0 12100.0 12115.5 12091.5 12106.5 12077.0 12090.0 12030.5 12047.5 12021.0 12036.0 12011.0 12026.5 11950.0 11962.0 11945.5 11959.5 11910.0 11918.0 11885.5 11893.5 11833.0 11841.5 11788.5 11799.5 11739.5 11751.0 11684.5 11695.5 11630.5 11643.0 11592.5 11604.0 11534.5 11546.0 11504.5 11515.5 11494.0 11503.5 11027.0 11036.5 11021.0 11032.0 10978.5 10988.5 10853.0 10865.0 10804.0 10814.5 10748.0 10760.0 10692.0 10703.0 10638.5 10651.0 10603.0 10614.0 10546.0 10553.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: 10 100.0 $ 107.5 REMARKS: This file contains Borax Pass #3 of the TDTP. The depth adjustments shown above reflect Borax Pass #3 SIGM to Base Pass #1 SIGM. All other TDTP curves were carried with the SIGM shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100388 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 100388 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 100388 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 100388 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 100388 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 100388 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 100388 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 100388 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 100388 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE 11 NAM~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TCAF TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 100388 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12287.000 SIGM. TDTP 17.049 TPHI.TDTP 23.351 SBHF. TDTP 63.831 SBHN. TDTP 79.851 SIGC. TDTP 0.259 SIBH. TDTP 150.847 TRAT. TDTP 1.639 SDSI. TDTP 0.350 BACK. TDTP 130.717 FBAC. TDTP 29.125 TCAN. TDTP 20396.230 TCAF. TDTP 9426.664 TCND. TDTP 13186.902 TCFD.TDTP 4796.453 TSCN. TDTP 3974.486 TSCF. TDTP 1836.915 INND. TDTP 1944.744 INFD.TDTP 320.046 DEPT. 10545.500 SIGM. TDTP 16.465 TPHI.TDTP 28.956 SBHF. TDTP SBPiN. TDTP 76.982 SIGC. TDTP 0.290 SIBH. TDTP 152.843 TRAT. TDTP SDSI.TDTP 0.366 BACK. TDTP 189.964 FBAC. TDTP 34.984 TCAN. TDTP TCAF. TDTP 8452.434 TCND. TDTP 13059.965 TCFD.TDTP 4344.403 TSCN. TDTP TSCF. TDTP 1669.206 INND. TDTP 1734.440 INFD. TDTP 297.904 55.909 1.871 20938.023 4134.888 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 0 O1 CO1 DATE : 96/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: 12 FILE HEADER FILE NU~fBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP The arithmetic average of passes 1, 2 & 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100388 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 100388 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 100388 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 100388 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 100388 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1996 10:42 PAGE: 13 NAI~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIGC PNAV CU 100388 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 100388 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 100388 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 100388 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 100388 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12280.000 SIGM. PNAV 18.837 TPHI.PNAV 24.698 SBHF. PNAV 40.539 SBPiN. PNAV 46.113 SIGC. PNAV 0.962 SIBH.PNAV 61.846 TRAT. PNAV 1.690 SDSI. PNAV O. 550 BACK. TDTP 72. 379 FBAC. TDTP 14. 978 TCAN. PNAV 23865. 430 TCAF. PNAV 10227.426 TCND.PNAV 21470.086 TCFD. PNAV 6590.245 TSCN. PNAV 5200.267 TSCF. PNAV 2215. 916 INND. PNAV 1852. 666 INFD. PNAV 304 . 949 DEPT. 10243.500 SIGM. PNAV 37.212 TPHI.PNAV 42.614 SBHF. PNAV SBHN. PNAV 52.333 SIGC. PNAV 1. 753 SIBH. PNAV 87.066 TRAT. PNAV SDSI. PNAV O. 740 BACK. TDTP 196. 734 FBAC. TDTP 37. 401 TCAN. PNAV TCAF. PNAV 5125.654 TCND. PNAV 14476.197 TCFD.PNAV 3718.930 TSCN. PNAV TSCF. PNAV 474.885 INND.PNAV 1616.666 INFD.PNAV 280.097 48.821 1.560 17393.930 1418.106 ** END OF DATA ** **** FILE TRAILER **** FILE NAF~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-J~L-1996 10:42 PAGE: 14 **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 96/07/17 ORIGIN : FLIC TAPE NAME : 96 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~_~f : ARCO ALASKA INC, D.S. 18-30, PRUDHOE BAY, 50-029-22568-00 **** REEL TRAILER **** SERVICE NARiE : EDIT DATE · 96/07/17 ORIGIN · FLIC REEL NA~IE : 96 CONTINUATION # PREVIOUS REEL : COf~i~f : ARCO ALASKA INC, D.S. 18-30, PRUDHOE BAY, 50-029-22568-00