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Home My WebLink About189-046 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~--- ~ ~//,~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/TYpe OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Bren~than Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd ALASKA ~t AND ~~;gg~S~~J~ON COMMIJSION RECE IVE WELL COMPLETION OR RECOMPLETION REPORT AND LOG JAN 0 6 Z005 Alaska Oil & Gas Cons. Commission 1 b. Well clcAnchorage 0 Development 0 Exploratory 0 Stratigraphic a Service 12. Permit to Drill Number 189-046 304-342 13. API Number 50- 029-21942-00-00 14. Well Name and Number: ~,'P> No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged a Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: EWR , DGR , CNO , BGT , LDT , GR , GYRO CALIPER, TDT-P CASING, LINER AND CEMENTING RECORD SETTt~~'DËPtHMD . ~ËtTI~;~~f"fij fVo HQhE ,.TQp , BÒTTOM.,Top",,;tsÖTrOMSIZE . Surface 110' Surface 110' 30" Surface 2931' Surface 2510' 12-1/4" Surface 5891' Surface 4587' 8-1/2" 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: tlq/ 1754'~SL, 3361' WEL, SEC. 27, T13N, R10E, UM Top of ProAyctive Horizon: 2067' PWL~.i94' )/VEL, SEC. 27. T13N, R10E, UM Total Depjþ/ 1849' ~L, 592' WEL, SEC. 27, 13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 557244 y- 6014190 Zone- ASP4 TPI: x- 559797 y- 6015668 Zone- ASP4 Total Depth: x- 559997 y- 6015888 Zone- ASP4 18. Directional Survey 0 Yes a No 22. CÄSÎNG SiZE 13-3/8" 9-5/8" 7" W"t,PER FT, 48# 47# 29# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD SCANNED; JAN 11 20.05 26. Date First Production: Not on Prodution Date of Test Hours Tested Zero Other 5. Date Comp., Susp., or Aband. 9/18/2004 I 6. Date Spudded 08/29/1989 7. Date T.D. Reached 09/03/1989 8. KB. Elevation (ft): KBE = 59.27' 9. Plug Back Depth (MD+TVD) 5536' + 4520' 10. Total Depth (MD+TVD) 5910' + 4603' 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. SIZE None TVD MPG-03 15. Field / Pool(s): Milne Point Unit / Schrader Bluff Ft Ft 16. Property Designation: ADL 025906 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) I AMouNt PULLED CgMENTINßRECeJRP . Arctic Set to Surface(Approx.) 181 Bbls Perm 'E', 138 Bbls Class 'G' 87 Bbls 'G', 24 Bbls AS I, followed by 52 Bbls Dead Crude TU61NG RECORD DEPTH SET (MD) PACKER SET (MD) 25.. ACID,FRAc;TQ~E.;'CEMENTSQUEEZEj ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4899' Set EZSV with 48 Bbls 'G' cement placed 38 Bbls Below and 10 Bbls on top 3201' Set CIBP 1978' Set 9-5/8" EZSV Cement retainer with 53 Bbls ASI PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): PRODUCTION FOR OIL-BsL TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BsL Press. 24-HoUR RATE 27. GAs-McF W A TER-BsL CHOKE SIZE GAS-OIL RATIO GAs-McF W A TER-BsL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 OR\G\NAL CONTINUED ON REVERSE SIDE RBDMS BFL /l\N () 7 2005 t t"'.. ~ :\ ~ ", .,:.. 28. ) GEOLOGIC MARKERS NAME MD SBF2-NA 5336' SBF24-MF 5368' SBF1-NB 5371' TSBD-OA 5522' TSBB-OB 5598' SBA5 5619' 29. ) FORMATION TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted. state "None". 4112' None 4140' 41421 4270' 4336' 4354' 30. List of Attachments: Summary of Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondras~ "]:iUe Technical Assistant Date b( -OS-05 MPG-03 189-046 304-342 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No./ Approval No. Drilling Engineer: Walter Quay, 564-4178 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection. Water-Alternating-Gas Injection. Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Submit Original Only ") ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/17/2004 01 :00 - 07:00 6.00 MOB P PRE Move rig & rig components from MP H-07 to MP G-03. Raise and scope Derrick. Rig up lines. Accept rig at 07:00 hrs, 9/17/2004. 07:00 - 08:00 1.00 KILL P DECOMP PJSM. Rig up lines to wellhead & tiger tank. Take on 9.3 ppg 120 deg brine to pits. Pull BPV. Tubing & I/A = 0 psi. O/A = 0 psi. 08:00 - 08:30 0.50 KILL P DECOMP Pre kill safety meeting wI overview of well plan scope. Emphasis on fluid & pressure monitoring. 08:30 - 10:30 2.00 KILL P DECOMP Bring on pump @ 2 bpm I 200 psi, pumping 9.3 ppg heated brine down tubing, taking returns thru choke to tiger tank. Bring rate up to 4 bpm I 1100 psi. No gas. Pump 200 bbls & monitor well, well stable. 10:30 - 11 :30 1.00 WHSUR P DECOMP PJSM. Set 2 way check & test from below @ 1500 psi, OK. Rig down & blow down lines. 11 :30 - 13:00 1.50 WHSUR P DECOMP Bleed void & nipple down tree. Wire brush & inspect threads on tubing hanger. Threads not in real good shape. Opt to spear hanger & order out double spear assembly. 13:00 - 14:30 1.50 BOPSUR P DECOMP PJSM. N/U 13 5/8" x 5M BOPE. 14:30 - 16:00 1.50 BOPSUP P DECOMP PJSM. Commence wI full test on BOPE. AOGCC rep John Crisp witnessing test. Gland nuts on lock down screws leaking, call out wellhead man & continue testing choke valves. 16:00 - 17:30 1.50 BOPSUPP DECOMP Suck out stack. Change packings on Lock-Down Screws. 17:30 - 21 :00 3.50 BOPSUR P DECOMP Resume testing BOPE; R/U to test Kelly, set back down. All tests OK. 21 :00 - 21 :30 0.50 PULL P DECOMP PJSM. RID test lines. 21 :30 - 22:00 0.50 PULL P DECOMP P/U landing joint, XO and M/U to BOT 2-7/8" spear, RIH to hanger and set it. 22:00 - 22:30 0.50 PULL P DECOMP Pull slowly to 46K and hanger came free, wI 4-5 "bobbles" on weight indicator as the hanger came to the floor with 32 to 35K. 22:30 - 23:00 0.50 PULL P DECOMP Breakout and UD landing joint, BOT spear, and XOs. 23:00 - 00:00 1.00 PULL P DECOMP POH wI and UD 2-7/8" tubing. 9/18/2004 00:00 - 03:30 3.50 PULL P DECOMP POH and UD 2-7/8" tubing. Recovered hanger wI 2' pup; 155 joints of 2-7/8", EUE, 8rd tubing; 3-pups: 12.12', 10.11',2.13'; and the Locator Seal assy wI 6 seals intact. 03:30 - 05:00 1.50 CLEAN P DECOMP Clear and clean rig floor. R/U 3-1/2" DP handling equipment. 05:00 - 06:00 1.00 CLEAN P ABAN M/U BHA #2: 6-1/8" Bit, 7" Casing Scraper, 2ea Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, 9 ea 4-3/4" DCs. 06:00 - 06:30 0.50 CLEAN P ABAN Service rig. 06:30 - 07:00 0.50 CLEAN P ABAN Finish making up clean out BHA. 07:00 - 09:00 2.00 CLEAN P ABAN RIH wI clean out BHA on 31/2" DP, 1 x 1. 09:00 - 10:00 1.00 CLEAN P ABAN PJSM. Slip & Cut drilling line. 10:00 - 12:30 2.50 CLEAN P ABAN Continue to pick up 31/2" DP & RIH wI clean out BHA. Tag Baker SC-1 L Pkr @ 4939' DPM, l' in on jt #147. 82K up wt, 56K down. 12:30 - 14:00 1.50 CLEAN P ABAN PJSM. Line up & circulate 40 bbls Hi Vis sweep around @ 5 bpm I 900 psi. No significant amount of solids or sand recovered when sweep came back. Well stable. 14:00 - 16:00 2.00 CLEAN P ABAN PJSM. POOH wi clean out BHA. 16:00 - 16:30 0.50 CLEAN P ABAN UD clean out BHA. 16:30 - 17:00 0.50 CLEAN P ABAN PJSM. Fill hole & close blind rams. Establish injection rate of 1/2 bpm @ 130 psi. 17:00 - 18:00 1.00 PXA P ABAN PJSM. Pick up Halliburton 7" x 26-29# EZSV Cement Retainer. Printed: 9/27/2004 10:03:14 AM ') ) BP EXPLORATION' Qp~.~ätioI'1S ..S~mmaryRèRQrJ , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/18/2004 18:00 - 21 :30 3.50 PXA P ABAN RIH wI EZSV to set at -4900'. 21 :30 - 22:30 1.00 PXA P ABAN Set EZSV @ 4899'. Pump into formation 3 BPM @ 1000 psi. Unsting from EZSV and establish circulation up annulus--good. Sting back into EZSV. R/U Schlumberger equip, Vac and fresh water trucks. Pump Pit 1 to TT. 22:30 - 23:00 0.50 PXA P ABAN PJSM with Schlumberger, Peak, Halliburton, Nabors Crew, Tour Pusher and Co Man, to discuss safety performance and job procedures. 23:00 - 00:00 1.00 PXA P ABAN Pump 5 Bbls and pressure test line to 4000 psi. Check all connections. Pump 48 Bbls class G cement, displace wI 24 Bbls seawater to get 38 Bbls under EZSV. Unsting from EZSV, displace remaining cement on top of EZSV, (10 bbls). 9/19/2004 00:00 - 02:00 2.00 PXA P ABAN POH and UD DP to 4700', reverse circulate DP clean and swap 9.3 ppg brine with 9.8 ppg brine. 02:00 - 04:00 2.00 PXA P ABAN POH and UD 1500', SIB 34 stands. 04:00 - 04:30 0.50 PXA P ABAN PT cement plug to 1500 psi and record for 30 minutes. Bled 100 psi in 1 st 15 min, 50 psi in 2nd. Will retest prior to setting bridge plug. 04:30 - 05:00 0.50 PXA P ABAN M/U EZSV Bridge Plug on 3-1/2" DP. 05:00 - 07:30 2.50 PXA P ABAN RIH wi EZSV B/P. 101 jts total. P/U 10' pup & M/U head pin. 07:30 - 08:30 1.00 PXA P ABAN Close pipe rams & pressure test 7" from surface to estimated top of cement @ 4700' (+ -) @ 1500 psi 130 minutes, charted. Good test. Witnessing of setting cement plugs & subsequent pressure tests waived by AOGCC rep John Crisp. 08:30 - 09:30 1.00 PXA P ABAN PJSM. Up wt = 46K, Down wt = 41 K. Circulate 15 bbls @ 3 bpm I 275 psi. Shut down pump. Pick up to up wt. WI Bridge PLug @ 3201' DPM, rotate to the right (40) turns. Pick up to 65K, wait a few minutes, up to 80K, wait a few more & pull to 93K, sheared OK. Rotate to the right (30) turns. RBIH & tag bridge plug @ 3201'. 09:30 - 10:30 1.00 PXA P ABAN PJSM. Close pipe rams & test 7" from surface to top of bridge plug @ 3201' @ 1500 psi 130 minutes, charted. Good test. O/A monitored during test, no indication of flow or pressure. 10:30 - 12:00 1.50 PXA P ABAN PJSM. POOH wi 3 1/2" DP & Halliburton running tool. 12:00 - 13:00 1.00 PXA P ABAN PJSM. UD Halliburton Running Tool, pull wear bushing & M/U Baker Multi-String Cutter & (9) 4 3/4" DCs. 13:00 - 14:00 1.00 PXA P ABAN RIH wi cutter BHA on 31/2" DP. (90 jts DP). 52K up wt, 43K down wt, 50K rotating wt. P/U kelly. 14:00 - 15:00 1.00 PXA P ABAN PJSM. Bring on pump @ 3 bpm, 550 psi. Gradually slack off & locate casing collar approximately 26' in on kelly @ 3160'. Shut down pump & pick up to 3150'. Kick in rotary table @ 80 rpm I 2200 ft/lbs torque. Bring on pump @ 3 bpm I 525 psi & commence cutting 7" casing. Torque oscillating between 2000 ft/lbs & 3000 ft/lbs, gradually increase pump rate & pressure during cutting operation to final rate of 6.1 bpm I 1025 psi. Total cutting time = 50 minutes. Monitor O/A for pressure increase throughout operation, no increase. Shut down pump & rotary table & pick up 5'. Bring on pump @ 31/4 bpm I 675 psi & slack off to cutting depth. See 200 psi decrease in pump pressure @ 3150', indicating cutting blades extending. Repeat. Good indication of successful cut. 15:00 - 16:30 1.50 PXA P ABAN Stand back kelly & POOH wi cutter assembly. Noted fluid loss rate increase when POOH. When OOH loss rate increased to Printed: 9/27/2004 10:03:14 AM ) ) 8PEXPLORATION Qp~r~Ji()Ï1$$u. mrharyR~Þørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/19/2004 15:00 - 16:30 1.50 PXA P ABAN the point unable to keep hole full. Ordered out (2) loads seawater. 16:30 - 18:00 1.50 PXA P ABAN Break out and UD BHA #3. Clear and clean rig floor. R/U lines to circulate annulus and R/U lines to Tiger Tank. 18:00 - 19:00 1.00 PXA P ABAN Hook up HB&R to annulus to pump heated diesel. Try 3 times pressuring to 2000 psi, for total of 2.2 Bbls; stop pump, hold pressure, but no leak off. 19:00 - 21 :30 2.50 BOPSUP P ABAN Change out 3-1/2" x 5" rams to 7" rams and test. 21 :30 - 23:00 1.50 PXA P ABAN Fill 7" with 19 Bbls seawater. M/U 7" casing spear BHA #4: Spear Packoff Bullnose, Spear Packoff Packer Cup, 2 ea 5-3/4" Itco Spears wi 6.095" grapple, Extension Sub, Spear Stop Sub, Lubricated Bumper Sub. 23:00 - 00:00 1.00 PXA P ABAN RIH and engage 7" casing, Pull slowly to 170K, relax and pull to 180K. Repeat cycles up to 225K with no gains. observed stretch ... (21")... when overpulling to 225K. 9/20/2004 00:00 - 00:30 0.50 PXA P ABAN Set hanger back down, RILDS. Hook up HB&R and attempt to pump into annulus. No Joy. 00:30 - 02:00 1.50 PXA P ABAN Release, POH wi spear, add jars and accelerator. RBIH and engage spear in 7". 02:00 - 02:30 0.50 PXA N DPRB ABAN Work pipe and set off jars @ 175K several times with no positive results. Call engineer and discuss option to install retrievable B/P in order to circulate hot seawater to free pipe. 02:30 - 03:30 1.00 PXA N DPRB ABAN Break out and UD BHA #5. Order packer and running tool from Halliburton. 03:30 - 04:30 1.00 PXA N DPRB ABAN Clear and clean rig floor, wait on tools from Halliburton. H/U HB&R to heat seawater in pits for downhole circulation. 04:30 - 06:00 1.50 BOPSUP N DPRB ABAN PJSM. CIO P/Rams to 2 7/8" X 5" variables. Test same, OK. Pull test plug. 06:00 - 07:00 1.00 PXA N DPRB ABAN PJSM. P/U Halliburton 7" RTTS & M/U above (9) 4 3/4" DCs. 07:00 - 08:30 1.50 PXA N DPRB ABAN PJSM. Change of plan, opt to recut casing above 9 5/8" shoe. 08:30 - 09:30 1.00 PXA N DPRB ABAN PJSM. POOH wi 31/2" DP & RTTS. 09:30 - 11 :00 1.50 PXA N DPRB ABAN PJSM. UD Halliburton RTTS. Pick up Baker Multi-String Cutter Assembly. 11 :00 - 12:00 1.00 PXA N DPRB ABAN RIH wi Baker Cutting Assembly, 77 jts 31/2" DP. Kelly Up. Establish parameters: 51 K Up wt, 42K down wt, 48K rotating wt. Rotating torque = 90 amps in 2nd gear or 1900 ft/ Ibs. Search for collar in vicinity of projected cutting area by picking up to 2740' & bringing on pump @ 3 bpm I 600 psi & gently slacking off, looking for blades to catch a connection & take weight. Slack off to 2755', no connection located. 12:00 - 13:00 1.00 PXA N DPRB ABAN PJSM. Pick up to 2750'. Engage rotary table & rotate @ 80 rpm. Bring on pump & gradually work rate up to 4112 bpm @ 1000 psi. See pressure drop off to 700 psi in just a few minutes, indicating cut made. Continue with cutting ops, bringing pump rate up to 6112 bpm @ 1000 psi to ensure a good cut. Total cutting time 45 minutes. Shut down pump & rotary table. Pick up a few feet & bring on pump @ 3112 bpm I 600 psi. Slowly slack off & observe pressure decrease of 250 psi @ 2750' DPM. Continue to slack off & observe 2-3K weight drop on indicator. Good indication of cut. 13:00 - 14:00 1.00 PXA N DPRB ABAN POOH wi 31/2" DP & cutting assembly. 14:00 - 15:30 1.50 PXA P ABAN PJSM. Line up to pump & pump hot seawater down 7", taking returns to tiger tank. Pumping 4 bpm, seeing good returns Printed: 9/27/2004 10:03:14 AM ) ) ~ BP:EXPUORATION Qp.~..~..~tigtì.~..."...~..y.rílf'l1a.ry .'.Re.port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/20/2004 14:00 - 15:30 1.50 PXA P ABAN initially, but returns gradually trail off to less than 1 bpm. Line up & pump hot seawater down 95/8" x 7", taking returns up 7" to tiger tank @ 4 bpm I 1100 psi. Note arctic pack coming back. Circulate 200 bbls total. 15:30 - 17:30 2.00 BOPSUP P ABAN PJSM. Set test plug, RILDs. Change out pipe rams to 7" & test same, OK. Pull test plug. 17:30 - 18:00 0.50 BOPSUR P ABAN P/U running tool and pull test plug. 18:00 - 19:30 1.50 BOPSUF P ABAN M/U casing spear and engage casing, pull to 150K, then 175K. Make decision to POH and replace 4-3/4" DC wi 3-1/2" DP to be able to circulate and pull at the same time. 19:30 - 20:00 0.50 BOPSUP P ABAN POH, UD 1 jt 4-3/4" DC, P/U 1 jt 3-1/2" DP. Engage 7" wi spear, P/U to 175K, begin circ 150 F seawater, 3 M @ 500 psi and set brake. Wt dropped to 150K, pres dropped to 100 psi. P/U to 175K, circ and hold, for three times. Each time the wt fell off to 150K while pumping. Made no gain. Calculate free point wi 9" stretch and 84K overpull = -2050'. 20:00 - 23:30 3.50 BOPSUP. N DPRB ABAN Re-align for rev circ for 2 ann vols of 70 Bbls ea. Discuss options with engineer. Conntinue rev circ for 4 additional volumes. Start at 5 BPM, but losses are 1 BPM, reduce to 3 BPM and losses average 2.8 Bbls/10 mins. 23:30 - 00:00 0.50 BOPSUP. N DPRB ABAN Bleed down lines. Pull and work pipe to 175K and hold, 3 times, then to 225K and hold, 2 times. No gains. Stretch is 11.25" w/1 07K overpull, free pipe - 2220'. 9/21/2004 00:00 - 01 :00 1.00 BOPSUP N DPRB ABAN Make decision to cut pipe - 2000'. Breakout and UD Spear. Wait on new Multi-string cutter from Baker. 01 :00 - 02:00 1.00 BOPSUF. N DPRB ABAN Change out rams to 2-7/8" x 5". Take on 150 F C/wtr thru HB&R hot oiler. 02:00 - 02:30 0.50 BOPSUR N DPRB ABAN M/U new 7" BOT Multi-String casing cutter. 02:30 - 03:30 1.00 FISH N DPRB ABAN RIH wi new csg cutter BHA #8. 03:30 - 04:30 1.00 FISH N DPRB ABAN Locate lower collar and P/U to start cut. Start cut @ 90 RPM, bring pump up 90 SPM @ 600 psi to 103 SPM @ 1000 psi. See good pressure drop in 10 minutes and torque increase steadily to constant rate. Continue rotating for 20 minutes. SID pump, P/U slowly, then lower slowly to relocate cut twice. Cut made @ 1686'. 04:30 - 06:00 1.50 FISH N DPRB ABAN POH and SIB DP and DCs. 06:00 - 06:30 0.50 FISH N DPRB ABAN Lubricate & service rig. 06:30 - 08:30 2.00 BOPSUP N DPRB ABAN PJSM. Set test plug. C/O rams from 2 7/8" x 5" to 7". Pt same @ 250 I 3500 psi, OK. Pull test plug. 08:30 - 09:30 1.00 FISH N DPRB ABAN PJSM. M/U double spear assembly, complete w/ jars. M/U circulating head. 09:30 - 10:00 0.50 FISH N DPRB ABAN PJSM. RIH & latch fish. Verify able to pull free wi 50K up wt. 10:00 - 11 :00 1.00 FISH N DPRB ABAN PJSM. Line up & circulate @ 5 bpm I 350 psi once around to clear hole of residual oil I arctic pack. 100 bbls pumped. Rig up floor to pull 7" casing. 11 :00 - 12:00 1.00 FISH N DPRB ABAN PJSM. Pull 7" & packoff, mandrel hanger to floor. UD fishing assembly, pack off & mandrel hanger. 12:00 - 15:00 3.00 FISH N DPRB ABAN PJSM. POOH & UD (42) full jts & (1) 36.80" cut off jt. 15:00 - 18:00 3.00 BOPSUR N DPRB ABAN PJSM. Set test plug. C/O P/Rams from 7" to 2 7/8" x 5". Test same @ 250/3500 psi, OK. Drain stack. UD test plug. RID test equip. 18:00 - 19:30 1.50 FISH N DPRB ABAN M/U BHA to spear 7" csg as follows: Spear Bullnose, Spear Pack Off, XO, Spear wi 6.095" Grapple, Spear wi 6.095" Printed: 9/27/2004 10:03:14 AM ) ) Legal Well Name: MPG-03 Common Well Name: MPG-03 Spud Date: 8/29/1989 Event Name: PLUG+ABANDON Start: 9/17/2004 End: 9/26/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2004 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/21/2004 18:00 - 19:30 1.50 FISH N DPRB ABAN Grapple, Extensiobn, Stop Sub, XO, Bumper Sub, Oil Jar, XO, 6 - 6 1/4" DCs, XO, Jar intensifier, XO. TL = 238.58' 19:30 - 20:30 1.00 FISH N DPRB ABAN RIH wI Spear Assy on 31/2" DP to 1886'. P/U kelly. Engauge fish wI spear. Top of stub @ 1687'. 20:30 - 22:00 1.50 FISH N DPRB ABAN P/U wt = 41 K, SIO wt = 41 K. Attempt to fish 7" casing. Jar on fish from 125k to 200 K. Attempt to circulate 3 BPM 600 to 1000 psi. No returns. 22:00 - 22:30 0.50 FISH N DPRB ABAN P/U to wI 125K & reverse circulate & heat wellbore fluids to 95 deg. Pumped 115 bbls.. 3.4 BPM @ 300 psi. 22:30 - 00:00 1.50 FISH N DPRB ABAN Con't to to jar on fish.wl 200K. Pump 1/2 BPM @ 120 psi. 9/22/2004 00:00 - 02:00 2.00 FISH N DPRB ABAN Con't to jar & work pipe. Fish not coming free. P/U wt = 41 K, SIO Wt = 41 K. Jarred wI 200K. no movement. 02:00 - 03:00 1.00 FISH N DPRB ABAN POOH w/3 1/2" DP & Spearing Assy. Inspect derrick. Release spear. Circulate oil out of BOP stack. Set back kelly. 03:00 - 03:30 0.50 FISH N DPRB ABAN POOH w/3 1/2" DP & spearring assy. 03:30 - 05:00 1.50 FISH N DPRB ABAN UD spear assy & 61/4" Des. 05:00 - 06:00 1.00 EVAL N DPRB ABAN P/U RTTS & drill collars. 06:00 - 06:30 0.50 EVAL N DPRB ABAN Lubricate & service rig. 06:30 - 07:30 1.00 EVAL N DPRB ABAN PJSM. RIH wI RTTS on 31/2" DP. 18 stands & (1) single. 41K down wt, 43K up wt. 07:30 - 08:00 0.50 EVAL N DPRB ABAN PJSM. Set RTTS in 7" casing @ 1732'. Verify by pass valve is closed. 08:00 - 08:30 0.50 EV AL N DPRB ABAN PJSM. Close annular preventor. Pump down 9 5/8" attempting to break circulation around 7" to cut @ 2750' & back up DP. Pressure up gradually to 3200 psi. Very little bleed off in 15 minutes, approximaterly 50 psi. Call Schlumberger to run USIT log. Bleed all pressure, open annular preventor, well stable. 08:30 - 09:30 1.00 EVAL N DPRB ABAN POOH w/3 1/2" DP. 09:30 - 10:30 1.00 EVAL N DPRB ABAN UD Halliburton RTTS & 4 3/4" DCs. 10:30 - 13:30 3.00 EVAL N DPRB ABAN Wait on Schlumberger & change out liners in mud pump to 5 1/2" in preparation for milling 7" casing. 13:30 - 15:00 1.50 EVAL N DPRB ABAN PJSM. Rig up Schlumberger E-Line. 15:00 - 18:00 3.00 EVAL N DPRB ABAN Run USIT log on E-Line. Log from 3150' to top of 7" @ 1687'. Log indicates top of cement @ 2294'. pipe appears to be free from 2200' up. plan to cut 3' below collar @ 2186'. (ELM) Logged from 3165' to 1687'. 18:00 - 19:00 1.00 EVAL N DPRB ABAN RID loggers & equip. 19:00 - 20:30 1.50 EVAL N DPRB ABAN Change out cutters & redress cutting tools. M/U BHA to cut 7" csg as follows: Multi-string Cutter, XO, String Stabilizer & 9 - 4 3/4" DCs. TL = 288.28'. 20:30 - 21 :30 1.00 EVAL N DPRB ABAN RIH wI cutting assy on 20 stds. of 31/2" DP. 21 :30 - 23:00 1.50 FISH N DPRB ABAN P/U kelly. Break circulation & locate collar @ 2191' (DPM). Space out cutler 3' below collar @ 2194' (DPM) Cut 7" casing. P/U Wt = 45K, SIO Wt = 41 K, Rot Wt = 45K. 90 RPMs, 3 1/2 BPM @ 1000 psi. Torq. 2K. lost 250 psi after 4 min. Con't to rotate & insure complete cut for 30 min. SID P/U 2'. Break circ & RIH 2' & verify cut. Positive indication. Set back kelly & blow down lines. 23:00 - 23:30 0.50 FISH N DPRB ABAN POOH wI drill string. 23:30 - 00:00 0.50 FISH N DPRB ABAN UD BHA & 4 3/4" DCs. 9/23/2004 00:00 - 00:30 0.50 FISH N DPRB ABAN Finish UD BHA & 4 3/4" DCs. 00:30 - 01 :30 1.00 FISH N DPRB ABAN Clear & clean rig floor. Printed: 9/27/2004 10:03:14 AM ) ) .BPEXPUORATION . OpØrätig~~i,$Qmrra~rY~éP9rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours Task Code NPT Phase 9/23/2004 01 :30 - 02:30 1.00 FISH N DPRB ABAN 02:30 - 03:00 0.50 FISH N DPRB ABAN 03:00 - 06:00 3.00 FISH N DPRB ABAN 06:00 - 17:00 11.00 FISH DPRB ABAN N 17:00 - 18:30 1.50 FISH N DPRB ABAN 18:30 - 19:30 1.00 FISH N DPRB ABAN 19:30 - 20:30 1.00 FISH N DPRB ABAN 20:30 - 22:00 1.50 FISH N DPRB ABAN 22:00 - 22:30 0.50 FISH N DPRB ABAN 22:30 - 23:30 1.00 FISH N DPRB ABAN 23:30 - 00:00 0.50 FISH N DPRB ABAN 9/24/2004 00:00 - 00:30 0.50 FISH N DPRB ABAN 00:30 - 01 :30 1.00 FISH N DPRB ABAN 01 :30 - 02:00 0.50 FISH N DPRB ABAN 02:00 - 02:30 0.50 FISH N DPRB ABAN 02:30 - 03:00 0.50 FISH N DPRB ABAN 03:00 - 05:00 2.00 FISH N DPRB ABAN 05:00 - 07:00 2.00 FISH N DPRB ABAN 07:00 - 09:00 2.00 FISH N DPRB ABAN 09:00 - 13:00 4.00 BOPSUR N DPRB ABAN 13:00 - 14:00 1.00 FISH N DPRB ABAN 14:00 - 16:00 2.00 FISH N DPRB ABAN 16:00 - 17:00 17:00 - 18:00 18:00 - 19:30 19:30 - 20:00 1.00 FISH 1.00 FISH 1.50 FISH 0.50 FISH DPRB ABAN DPRB ABAN DPRB ABAN DPRB ABAN N N N N Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 Description of Operations M/U spear assy & P/U 6 - 6 1/4" DCs. RIH wI spear assy on 3 1/2" DP 1687'. P/U 44K SIO 40K. P/U kelly & engage spear into csg stub. Attempt to circ & pull csg. Having to jar. After 3rd lick casing started to move. Pump @ 2 BPM, 750 psi. No returns. SID pump & con't to jar. Casing moving 3-4" per lick. Jarring @ 200K. Pulled fish up hole approximately 15' - 16'. Continue jarring. 300 -400 jar licks @ 200K total. Tried bullheading I circulating past around outside of 7", no indication of much success. Pulled fish up hole total of 24' - 25' since latching up. believe turbulator(s) are giving us grief. Opt to recut @ 2005' (+ -). Release spear from 7" casing. Inspect derrick. POOH wI Spear Assy. UD Spear Assy & DCs. Clear & clean rig floor. Adjust brakes. M/U BHA to cut 7" casing. RIH wI Cutting Assy. Top of 7" stub now @ 1665'. (22' high from jarring) P/U kelly. Locate collar @ 1974'. Space out cutter to 1987'. P/U Wt = 40K, SIO Wt = 40K. Rot Wt = 40K. Cut 7" casing as follows: 90 RPMs, 3 1/2 BPM @ 1000 psi, Torq = 2K. Cut thru casing & pressure dropped 250 psi. Con't to rotate for additional 30 min. P/U & SID pump. lower back down wI pump on & verify casing cut. Ok. Set back kelly & POOH wI cutting assy. Con't to POOH wI BHA & DP. UD 4 3/4" DCs & cutting BHA. M/U BHA & P/U 6 1/4" DCs to Fish cut casing. RIH wI BHA to Spear casing. Engage spear into casing & P/U wI 15K over pull. Casing free. P/U 46K, SIO 44K. Set back kelly & blow down lines. POOH wI fish. Have up to 30K overpull in spots. PJSM. UD fishing assembly. Rig up to UD 7" casing. PJSM. UD 7" casing & turbulators. Recovered total of 325.11' of 7" casing. Total recovered since onset of fishing ops = 2012'. PJSM. Conduct weekly BOPE test. Witnessing of test waived by AOGCC rep John Spalding. PJSM. P/U 7" Multi-String Cutter Assembly & RIH on (20) stands DP. PJSM. P/U kelly. 40K down wt, 43K up wt. Bring on pump @ 3 bpm 1600 psi & slack off slowly. Locate collar @ 2093'. Shut down pump & P/U 5'. Slack off to cutting depth of 2110', (25') in on kelly. Kick in rotary table @ 90 RPM & bring on pump @ 5 bpm 11000 psi. See indication of cut 3 112 minutes into operation. Continue to rotate for an extra 20 minutes @ 6 bpm / 650 psi to ensure good cut. PJSM. POOH wI cutter assembly. Clear & clean rig floor. Adjust brakes. P/U 6 1/4" DCs & Spear Assy. RIH wI fishing assy. Printed: 9/27/2004 10:03:14 AM ) ) BPEXPI..l0BA7F10N' Q pe.t~t.io.n$...'.$..lI..tp'OO~..~y.....'R;~.p():rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/24/2004 20:00 - 21 :00 1.00 FISH N DPRB ABAN P/U kelly. Attempt to engauge spear & work pipe. Spear bottoming out 12' high. Appears not to be entering 7" stub. Did see pressure increase. 21 :00 - 22:00 1.00 FISH N DPRB ABAN POOH wI Spear Assy. 22:00 - 23:30 1.50 FISH N DPRB ABAN No recovery. Cup above bull nose on spear is mushroomed out. Wire re-enforcement prevented spear from entering 7" stub. Remove cup & re-dress spear. Clean threads on DCs. 23:30 - 00:00 0.50 FISH N DPRB ABAN RIH wI re-dressed Spear Assy. 9/25/2004 00:00 - 01 :00 1.00 FISH N DPRB ABAN Finish RIH wI Spear Assy. P/U kelly. 01 :00 - 01 :30 0.50 FISH N DPRB ABAN Engauge casing stub @ 1978'. P/U & attempt to pull casing. Casing stuck. Jar on fish wI 200k. Fish moved up approx. 1'. Each jar lick moved less. Would not pull free. 01 :30 - 02:00 0.50 FISH N DPRB ABAN POOH wI spear Assy. 02:00 - 04:00 2.00 FISH N DPRB ABAN B/O & UD spear Assy. 04:00 - 05:00 1.00 PXA P ABAN M/U Scraper Assy. 05:00 - 06:00 1.00 PXA P ABAN RIH & scraper casing to top of casing stub. Tag top of 7" casing @ 1985'. 06:00 - 07:00 1.00 PXA P ABAN Reverse circulate bottoms up, returns clean. Service rig. 07:00 - 08:30 1.50 PXA P ABAN PJSM. POOH wI clean out assembly. 08:30 - 09:00 0.50 PXA P ABAN PJSM. M/U Halliburton 9 5/8" EZSV cemaent retainer & inspect same. 09:00 - 10:30 1 .50 PXA P ABAN RIH wI EZSV on 3 1/2" DP. 62 jts total. 37K up wt, 35K down. 10:30 - 11 :30 1.00 PXA P ABAN PJSM. M/U 24' pup wI headpin & lightly tag 7" casing stub @ 1985'. P/U 3' & circulate @ 3 bpm 1250 psi, 15 bbls. WI top of retainer @ 1978' DPM, rotate to the right 35 turns. Pick up 20K over up wt to 57K, wait a minute, pick up another 15K to 72K, wait a minute & shear @ 92K. Rotate to the right 40 turns. Pressure test 9 5/8" casing to top of retainer, 2500 psi 110 minutes, OK. Stab into retainer & establish injection rate of 3 bpm 11100 psi. 11 :30 - 12:00 0.50 PXA P ABAN Held safety meeting wI cementers & truck drivers. 12:00 - 13:00 1.00 PXA P ABAN Rig up cement lines & test @ 3500 psi, OK. Pump 5 bbls water followed by 53 bbls 15.7 ppg Arctic Set 1 @ 2.5 bpm 1400- 500 psi average pressure. Displace wI seawater, (10 bbls). WI 2-3 bbls cement left in DP, unsting from retainer. 13:00 - 14:00 1.00 PXA P ABAN PJSM. Line up & reverse circulate @ 4 bpm 1400 psi, (2) DP volumes. 14:00 - 15:00 1.00 PXA P ABAN Clean pits, take on 9.8 ppg brine & reverse circulate hole to 9.8 ppg brine to 9.8 ppg returns, 160 bbls. 15:00 - 16:30 1.50 PXA P ABAN PJSM. Close pipe rams & rig up on lower annulus valve. Pressure test 9 5/8" from surface to top of retainer @ 1978' DPM @ 2000 psi I 30 minutes, charted. Good test. 16:30 - 20:00 3.50 PXA P ABAN POOH & LDDP. UD EZSV stinger. RIH wI remaining 9 stands & UD same. 20:00 - 21 :00 1.00 WHSUR P ABAN Install Pack off. RILDS. UD running tool. 21 :00 - 21 :30 0.50 PXA P ABAN RID DP tools & RlU tbg tools. Clear floor. 21 :30 - 23:00 1.50 WHSUR P ABAN P/U & RIH w/5 jts of 2 7/8" tbg. TL = 155'. M/U tbg hanger. Land hanger. RILDS. J/D landing jt. RID tbg tools. Install TWC. 23:00 - 00:00 1.00 BOPSUR P ABAN N/D BOPE. 9/26/2004 00:00 - 01 :00 1.00 BOPSURP ABAN Finish N/D BOPE. 01 :00 - 02:30 1.50 WHSUR P ABAN N/U tree. Test to 5000 psi, OK. 02:30 - 03:00 0.50 WHSUR P ABAN Pull TWC. Install BPV. 03:00 - 03:30 0.50 WHSUR P ABAN RlU hot oilers. Test lines & pump 10 Bbls for diesel cap. 3/4 Printed: 9/27/2004 10:03:14 AM ) ) BP EXPLORATION Operations .$umÔ1~tyaøgQtt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-03 MPG-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 8/29/1989 End: 9/26/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/26/2004 03:00 - 03:30 03:30 - 04:00 0.50 WHSUR P 0.50 WHSUR P ABAN ABAN BPM @ 100 psi. Secure well. Clean cellar. RELEASE RIG @ 0400 hrs. 9/26/2004 Printed: 9/27/2004 10:03:14 AM ~ ~ ~~~~Œ (ID~ ~[L~~~~ / j / / AI,ASIiA OIL AND GAS / CONSERVATION COMMISSION í / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 3, 2004 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPG-03 Sundry: 304-342 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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 ifthe 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enclosure /"""' ~ k Çf;>y'if"> ? /J> / jZ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Plug Back for Sidetrack . Abandon 0 Repair Well . Plug Perforations 0 Stimulate . Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 0 Development 0 Exploratory 189-046 3. Address: 0 Stratigraphic II Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21942-00 7. KB Elevation (ft): KBE = 59.27' 9. Well Name and Number: MPG-O3 8. Property Designation: 10. Field 1 Pool(s): ADL 025906 Milne Point Unit 1 Schrader Bluff 11. .' PRESENT WEll CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5910' 4603' 5536' 4520' NIA NIA Cð$ina .. Lenatb'.. 'SD:/....... ..,..,.. . .....>. M( "T\lD. / '.."". 'Rò,rct CoUaøse 110' 13-3/8" 110' 110' 1670 670 ~ r. 2931' 9-5/8" 2931' 2510' 6870 4760 Drnnlll'tinn 5891' 7" 5891' 4587' 8160 7020 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 5334'-5568' 4111'-4310' 2-7/8", 6.5# L-80 5493' Packers and SSSV Type: Sand Screen Assembly - 7" Baker SC-1 L Packer and a 7" Packers and SSSV MD (ft): 4946' and 5464' Baker Model 'D' Packer 12. Attachments: 13. Well Class after proposed work: II Description Summary of Proposal 0 BOP Sketch 0 Exploratory 0 Development II Service 0 Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 10, 2004 0 Oil 0 Gas II Plugged 0 Abandoned 16. Verbal Approval: Date: 0 WAG DGINJ DWINJ 0 WDSPL Commission Recresentative: 17. I hereby certjW. that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Na1~ Davis! R8W1 ~ /I Title Drilling Engineer Date 9/01 JO4 Prepared By Name/Numbe~ Signature lJ~ C j{.o 11 A'A Phone 564-5743 Sandra Stewman, 564-4750 ~ ) ", .'.'~ ... > ... .. .". I Sundry Number: ..30t/- 3/.?- Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance RECEIVED 0Ihe. ~ 5 00 ~., -. fl "" W::¡f? ,«-., '\. 'i) ~ \t= "- é) \>'<: \(>. .\¡"", '>, S E P - 3 '2004 . ~ ~~~' ~ ~<l:\>o-\O.\€- ~<"~~~a Oil & Gas Cons. Commission 50"""00' F°'7a i-A h ~ nc oraga APPROVED BY Approved By: 7 COMMISSIONER THE COMMISSION Date ~~ /ð~ V' Form 10-403 RI~d 15/2004 - ~ub~it In Duplicate ORIG\NAL RBDMS BF l SEP 0 8 1004 /"""' ~ MPG-O3 Plug and Abandonment Objective To plug and abandon the MPG-03 Schrader Bluff completion and prepare the well for a sidetrack immediately beneath the 9.625-in surface casing. The sidetrack will be for a Schrader Bluff injector to be drilled in Oct 2004 (separate permit application to follow). Scope of Work 1. MORU N4ES. 2. Kill well. 3. Pull 2.875-in tubing. V 4. Set EZ-SV at 4,900-ft and squeeze off perforations with 30-bbl cement (15.8-lb/gal class G). 5. Set CIBP in 7.0-in casing at 3,200-ft. 6. Cut and ~I 7.0-in casing from 3, 150-ft to surface. 7. Place a 'áO-bbl cement plug (15.8-lb/gal class G) from CIBP up to 2,800-ft. 8. Leave well filled with brine. 9. RD N4ES. ~ Tree: 2 9/16" - 5M WKM Wellhead: 11" 5M FMC w/ 27/8" WKM Tubing Hanger, EUE lift threads, 2.5"" CIW H BPV profile 13 3/8" 48 ppf, H-40 ~ 95/8",47 ppf, L-80 BTC I 2931' I 27/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift 10 = 2.347", cap. = 0.0058 bpf ) 7" 29#, L-80, BTC production casing (drift 10 = 6.059, Annular cap. = .0371 bpf RA r" 5219' ~ Stmulatlon Sunmary: Frac '0' Sands (5522-5536') w/ 30250 Ibs of 16/20 mesh Carbo-Lite GI'IIY8I Pack Sunrmq. 'N' Sands Frac Pack - 20-40 Mesh Gravel behind screens Perforation Summary Ref log: 8I25J9O & 7/23/92 GAl CCL Size SPF Interval (TVD) 'N' Sand 4.5" 24 5334' - 5356' (4111'-4130') 4.5" 24 5372' - 5382' (4143'-4152') 4.5" 24 5404' - 5408' (4170'-4174') 4.5' 24 5433' - 5438' (4195'-4199') '0' Sand 4.5" 4 5522' - 5536' (4270'-4282') 111/16' 6 5538' - 5568' (4284'-4310') ~ DATE REV. BY COMMENTS 9/5/89 Drilled and cased by Parker 141 7/29/92 CFP Workover 3/04/04 Lee Hulme Set Up Canvas Drawing --------. Orig. RKB. elev. = 30' (Parker 141) Orig. KDB-GL = 29.8' (Parker 141) Orig. KDB-SL = 59.3' (Parker 141) KOP @ 800' Max hole angle = 55 deg at 4000' Hole angle thru perfs = 31 deg Baker S-22 Locator Seal Assy wi 5 molded seals (2.35 ID) 7" Baker SC-1L Pkr I 4946' 3792' TVD 27/8" Bakerweld .012 ga. screen 5324' - 55449' Baker polished bore receptacle (2.062 10) I 5449' 27/8" Bakerweld .012 9a. screen 5450' - 5462' 7" Baker Model '0' Pkr. I 5464' (3.2510) HES 'X' Nipple (1.875" id) I 5486' WLEG (2.00" id) I 5493' WLEG ELMO I 5493' 7" float collar (PBTD) I 5814' MILNE POINT UNIT WELL MPG-O3 API NO: 50-029-21927 BP EXPLORATION (AK) ~ Tree: 2 9/16" - 5M WKM Wellhead: 11" 5M FMC w/ 2 7/8" WKM Tubing Hanger, EUE lift threads, 2.5"" CIW H BPV profile 13 318" 48 ppf, H-40 ~ 7" 29#, L-80, BTC production casing (drift 10 = 6.059, Annular cap. = .0371 bpf RA T', 5219' ~ Stlmt8llon Sunrmuy: Frac '0' Sands (5522-5536') w/ 30250 Ibs of 16/20 mesh Carbo-Lite GI'IMII Pack SUnI1l8lY- 'N' Sands Frac Pack - 20-40 Mesh Gravel behind screens perforation Sunmary Ref log: &n5I9O & 7/23/92 GAl CCL Size SPF Interval (TVD) 'N' Sand 4.5" 24 5334' - 5356' (4111'-4130') 4.5" 24 5372' - 5382' (4143'-4152') 4.5" 24 5404' - 5408' (4170'-4174') 4.5" 24 5433' - 5438' (4195'-4199') '0' Sand 4.5" 4 5522' - 5536' (4270'-4282') 111/16" 6 5538' - 5568' (4284'-4310') ~ DATE REV. BY COMMENTS 9/5/89 Drilled and cased by Parker 141 7/29/92 CFP Workover 3/04/04 Lee Hulme Set Up Canvas Drawing 16Aug04 MDG P&A /'"""0, Orig. RKB. elev. = 30' (Parker 141) Orig. KDB-GL = 29.8' (Parker 141) Orig. KDB-SL = 59.3' (Parker 141) Top CEMENT I 2,800-ft I CEMENT Top Casing I 3,150-ft I '" I 3,200-ft I CIBP KOP @ 800' Max hole angle = 55 deg at 4000' Hole angle thru perfs '" 31 deg EZ-SV I 4,900-ft I I 4946' 7" Baker SC-1L Pkr 3792' TVD 27/8" Bakerweld .012 ga. screen 5324' - 55449' Baker polished bore receptacle (2.062 10) I 5449' 27/8" Bakerweld .012 ga. screen 5450' - 5462' 7" Baker Model '0' Pkr. (3.2510) HES 'X' Nipple (1.875" id) I 5464' I 5486' I 5493' WLEG (2.00" id) WLEG ELMO I 5493' CEMENT 7" float collar (PBTD) I 5814' MILNE POINT UNIT WELL MPG-O3 API NO: 50-029-21927 BP EXPLORATION (AK) MEMORANDUM TO: Dan Seamount Commissioner 'THRU: Blair Wondzell P.I. Supervisor FROM: John Cris~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 1, 2000 SUBJECT: Mechanical Integrity Tests BPX F & G Pads F-83i, G,01i,03i,05i,07i Milne Point Unit Milne Point Field NON- CONFIDENTIAL . Packer Depth ..' Pretest Initial 15 Min..30 Min. We'llI F-83i I Typelnj:! .' S. I T.V.D. 16425 I Tubing i 2200"1 2200I~ooI~00 I,nt~rv,,I , P.T.D.I 5001030 ITyPete;tI .P I.Testpsil 1606 I Casi~gl 1900. 126801.266'0. I 2650 I P/F I P' Notes: . ' ' 'w;i,t ~-o~, ].Type'"i.! "s "l.~.v.o.'l's~o .IT'u~,,g] '~200 I' ~3~0 I ~3,0I ~,o li.,.~;,.i 4 P.T:D.] 1890290 ]Typetest] P ]Test psi] 923 .] Casing ] '0 I 1725 'J '1725 I 1725 I' P/F I ' P - Notes: 'We,I ~-0~, I Type'~ni.l' s'i.~.v.o.'l379~ ]Tu~,ngl~720 l~720 'i ~720 I~o'1';'.,.~,1, . P.T.D.] 1890280 ITypetestl 'P. ITestpsi] 948 ]CaSingI 950 ! ;~190 ] 2180 I '2;175 ]' P/F I P- NOtes:. Weli~ i"'-'i-~'l-Type~lnj' I S I T.V:D. '1 '3929 I Tubing'! 900 I 900 i 900 I 900 I lntervall 4 , P.T.D.'~~'~lT~etestl .'P 'lTeStpsil 982 I.Casing'l. 0 t 1778'1.1.75° I 173°"1 P/FIE Notes: w.,,I ~-o,, i~,. Inj~l-S '! T.V.D. }. 3983I ~u~,n, I ~ooo' ! ~ooo'1 ~ooo' I =ooo i,.,.~.,r ~ · .P.T..D,I 18.90450 ITypetestl '. P .ITestpsil. 991 /Casingl 62o' I 25oo I 2480 I 2480 }' P/F I ~P' Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= 'Annulus Monit0dng P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test I-witnessed 5 successful Es @ BP's MPU. Test's Details Interval I= Initial Test 4= Four .Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) .I.T.'s performed: 5_ Attachments: Number of Failures: Total Time during tests: 2 hrs. cc.' MIT report form 5/12/00 L.G. MIT MPU F & G Pads 10-01-00jc.xls 10/3/00 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 P M C:LORIXMFILM.DOC E E L E W A T E R IA L U N D E THIS MARKER R LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/~adam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run ~ 1 6427.00 Run # 1 6428.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and me~u~l ~o~ petrotechnic~l Da'~s, Cen%e~ BP Exploration (Alaska) In~ 900 E~s% Benson Bouleva~ RECEIVED ~ MA.Y-,2 4 1995 Alaska 011 & 6as Cons. Anchorage l1ECHANICAL INTEGRITY REPORT -_.."._.._:~ t ß 9 -- I{-6 J04-;)\c; . SPUD DATE: 0/2918,- . OPER & FIELD (O"oQ') /::.ç.t.paruf:-(4'W IJef£ 9 /~fCJo RIG RELEASE: ' 91Í~f9o \arELL NUMBER MPCl r;. -~? WELL DATA TD: S~{OMD 4bO~ TVD; PBTD:~8(3' MD lIS-r9 TVD Cas ing: 7 '2.<1 L Shoe:.s-B c¡ ( MD TVD J DV: MD.TVD Liner: Tu bin g : '1-7¡g Hole Size Shoe: ~qq, Packer !)'f6Lí MD MD TVD; TOP: MD TVD TVD; Set at 4. 90(") and sÝ... J Perfs ~-11 'f- to SS"'"2. "2.. MECHANICAL INTEGRITY - PART 11 Annulus Press Test: IP . 15 min J 30 min Comments: ".- .' MECHANICAL INTEGRITY - PART #2 . 67 Ik"J..o[. - IÞ-bl. Cement Volumes: Amt. Liner ; Cs. 'iHH r¡J,(c; J DV ." e.. - .C7o'Z 1'44=1,3 z~,' (2..~ r" ~ ðkz.. ~ .0 ~~ Cmt vol to cover perf~ 9'1-.0' "'2) -if!l1./3 ).077. -f~B"-4f7.~lf ).02"26 =- ".ß ~ ,.,.. 'L .03 YI e7-(~,,8 , Theoretical Toe r-a ~ Lf - L(J( ( .fir ) ~ ,01r:r ~ .?lflf ~ Cement Bond Log (Yes or No) f~ CBL Evaluation, zone above perfs J ~n ADGCC File' ~ d ( f't! fu.,.. I\. ç. Production Log: Type ; Evaluation CONC~USIONS: Part #1: . ~art #2: jV\/ I:; {Ì1r1('crt-~cl SCANNED NOV 0 3 2004 a..~"'-\-~ \.~K,,>.þ~Ç)(rG-\=\~t---~ -ð3~ CD/~~'(r'æ~~ IÒ!>-~-öL-f 1f~/~z.. rev. OS/20/87 C.028 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 August 26, 1992 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Wondzell, Attached are Reports of Sundry Well Operations, Form 10-404, for the recent perforating of Milne Point Unit Wells G-3 and G-5. Please direct any questions or concerns regarding these forms to me at 564-7660. Sincerely, -- Tom Yeager SHEAR Specialist Att: cc: CVL, BGA GDF/FWG, WCD/HDS Chevron Occidental G-3 Well File G-5 Well File R EIV D AUG 2 ? 1992 Alaska Oil & Gas Cons. Commission Anchorage ^,o REPORT OF .SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate :X Other __ 2. Name of Operator CONOCO :INC. 3. Address "OW' STREET SUITE 200. AK 99503 4. Location of well at surface 3525'FNL, 3362'FEL, SEC.27; T13N, RIOE, UM, NSB At top of productive interval 2875'FNL, 2181'FEL, SEC. 27, T13N, RIOE, tM, NSB At effective depth Attotal depth 12. Present well condition summary Total depth: measured true vertical 5910 feet 4601 feet 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB 59.3' (NSL) feet 7. Unit or Property name NILNE POINT UNIT 8. Well number 9. Permit number/approval number 89-46 ,,, 10. APl number 50--029-21942 11. Field/Pool KUPRRUK RIVER/SCHRADER BLUFF Plugs (measured) Effective depth: measured true vertical 5813 4519 feet feet Junk (measured) Casing Length Structural Conductor 75' Surface 2896' Intermediate Production 5856' Liner Perforation depth: measured Size 13-3/8" 9-5/8" 7" Cemented Measured depth True vertical depth SURFACE 110' 110' SURFACE 2931 ' 2510' 5891 5334'-5356', 5372'-5382', 5404'-5408', 5433''5438', 5522''5536', 5538'-5568' truevertical 4111'-4130', 4143'-4152', 4170'-417~", 4195'-4199", 4270"-4282', 4284'-4309' 4585" Tubing (size, grade, and measured depth) 2-7/8", 6.5~, L-80, 8rd EuE, Packers and SSSV (type and measured depth) NONE 13. Stimulation or cement squeeze summary Intervals treated (measured) NONE Treatment description including volumes used and final pressure AU 6 2 7 1992 Alaska Oil & Gas Cons. Commission Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-MCf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 700 BPO 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations _~x Oil __ Gas __ Suspended 17. I here~~_ ~ t the~true and correct to the best of my knowledge. Sic. ned ~"~ L~dl~ ~r- Title~'~"~ ~'~c',.~ \f ~ R~v'06/15/88 Form 10-404 0 700 Service WATER INJECTOR SUBMIT IN DUPLICATE CONOCO INC. 14:14 DAILY WELL ACTIVITY REPORT PRGE.OOE ALASKA FROM TO i HOURS ~ ' ' ' A~VI~ - ~.~,tr. J" ~ ~ ~~'~~~.' ~-~~/ ' ' . , ( ~ ~ ~ ~ /~ ... ~ ~~ ...... ~ ~ ~. ?~vt.~ . M~ ~~~ ........... .... ~_ ~//~ ~,_ ~~l ~~ ~ ~,,/mo ........ ~ ~ .,.. . . ....... Al~a Gii ~, 8as Cons. C"em~sc~,: , . ~ ,.., , .. .,~ ~ ~nC~orage ,, , ~~~~ ', ............... RIG SAF~ PERFORMANCE ALL DAILY COSTS PI~ ~&.,'"'~ ~~~~, /_~o~. ~ ~,v '. .... ~+ .~ ,,.,~ ~,~ w~,.ou,! .......... ~ ....... ~u* ~s.. _.... Y~R TO DATE I $ COST SUMMA~ DAILY CUMU~TNE ., . ~ = .. ,_,~ ,,,,= , .. . EN~RONMENTALINCIDENTS $ PRE~S T~AL $ ,, $ , ., .,., . .~ ~ ~ ,,, .. , ..,- · , m~ DOPE TE~ DUE $ A~ COST " ' ,., .,,-, . ~, i , ,~ ~ ,. i . , j,U-L,¢2g 'g~ lES:S-7 CONOCO FROhl COl'.,lOCO NI".IC EI"IG,,"'EXPL INC. REQUEST FOR FACSIMILE DATE: FROH: CZTY/STATE: July 29, 1993 Stephen F. Davies Anchorage, Alaska TO: Latey Grant COMPANY: Alaska 0tl & Gas Conservation Commission CITY/STATE: Anchorage, Alaska FAX #: 276-7542 NO. OF PAGES: COVER + 8 SPEC]AL INSTRUCTIONS: FAX REPLY NUMBER: (:907) 564-7655 Please notify mY secretary, Dorothy Bourbeau, at (907) 664-7611 if transmission is incomplete or illegible. SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7'7251-2175 Jill I ? 1gQ2 Conoco, Inc 3201 "C" Street, Suite 200 Anchorase, AK 99503 Attention:. Llnda Start ~EASE RElY TO ~HLUMBERGER WELLSERVICES Pouch 340069 ?rudhoe Bay, AK 9973~-0069 ATTN: Bernie/Shelley (~entlemen: Enclosed are 3 BLprintsof the. Company Conoco ~ Inc Well G-3 Field Mllne Point/Schrader Bluff Additional prints ore being sent to: . I BI. prints Cgnoco,Inc 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 PER , .. Perf Rec, Run 1, 7/23/92 County .on: North Slope State Alaska 1BL prints, I RF Sepia Chevron U.S,A. 11!11 South Wllcrest Houston, TX 77099 ATTN: Michael Qut.nn *(713/561-367.3) 1BL prints Conoco, Inc 1000 South Pine Ponco City. OK 7460__~_ Attn: Glenn Welch, 7360 RDW Commj ssion O1 PorcuoJne Drive chora~e.- AK 99501 // ~rints, I RF Sepia OXY U,S.A. Inc 6 De.~t.a Drive= Rut te Midland.. TX 79705 *(ql prints prints The film is returned to Conoco, Linda Start Alaska 0ii & Bas ~;on~. ~- ............. Date: Anchma§6 We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES SW$-- 1327-F OH/CH (IlBL/3RF) Raymond N. Dtckes DISTRICT MANAGER , :.' STATE OF ALASKA ~.~ ALA,("~OIL AND GAS CONSERVATION COMMi,/'~, N 0 It I G ! 1. Type of Request: Abandon Suspend __ Alter casing Repair well Change approved program __ Operation shutdown __ Re-enter suspended well Plugging __ Time extention ~ Stimulate .. Pull tubing Variance ~ Perforate X Other Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development __ Exploratory __ Stratigraphic ~ Service X Location of well at surface 3525' FNL, 3362' FEL, Sec. 27, T13N, R10E, U.M. At top of productive interval 2875' FNL, 2181' FEL, Sec. 27, T13N, R10E, U.M. At effective depth NSB AK NSB AK At total depth 1850' FNL, 594' FEL, Sec. 27, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 59.3' (USE) 7. Unit or Property name Milne Point Unit feet 8. Well number G-3 9. Permit number 89-46 10. APl number 50-029-21942 11. Reid/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured true vertical 5910' feet Plugs (measured) 4601' feet None Effective depth: measured 5814' feet Junk (measured) true vertical 4519' feet None Casing Length Size Structural Conductor 75' 13-3/8" Surface 2896' 9-5/8" Intermediate Production 5856' 7" Uner Perforation Depth: Cemented Measured depth True vertical depth Surface 110' 110' Surface 2931' 2510' TOC @ +3560' 5891' measured 5334'-5356', 5372'-5382', 5404'-5408', 5433'-5438', 5522'-5536' 4585' true vertical 4111 '-4130', 4143'-4152', 4170'-4174', 4195'-4199', 4270'-4282' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 4946' MD RECEIVEI) Packers and SSSV (type and measured depth) Baker Model SC-11 Packe~ at 4946' 13. Attachments Description summary of proposal __ Detailed operations program X JUN - 1 1992 Alaska 0ii & Gas Cons. Coma BOP sketch Ancl~0rage 14. Estimated date for commencing operation June 8, 1992 16. If proposal was verbally approved Oil __ Gas Name of approver Date approved Service Water I niection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~4~,~ ~,~~B. G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY 15. StatUs of well classification as: Suspended __ Date 5/28/92 Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance _.~.~)Z~pproved Copy Mechanical Integrity Test Subsequent form required 10- -,, -- Returned ORIGINAL SIGNED BY ~' '~ ~ ~''~ I..ONN1E C. SMITH Approved by order of the Commission Commissioner Date JApproval NO. .~ ssiO~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE .ILNE POINT UNIT G-3 'OB' ~'SAND PERFORATING PROCEDU~R~' NOTES: a) A safety/planning meeting shall be held at the beginning of this job to ensure good communication between all parties on location. b) Depths referenced to Schlumberger Litho- Density/Gamma Ray log run on 9/3/89. c) d) e) f) Area Engineer should be on-site for perforating. Ensure that all permits required for work have been approved. This work should be charged to AFE No. 10-61-1458 "G-3: Convert to Injection." A wellbore schematic is attached. le e Shut down injection into well. MIRU Schlumberger perforating unit with mast truck. RU lubricator and pressure test to 1500 psi. RIH with a 1.75" gauge ring to 5500' to ensure tubing and gravel pack assembly are clear. POOH. NOTES: a) Ensure that all radios, telephones (rig and cellular) and any other radio wave sources within a 500' radius of the wellsite are turned off. Broadcast a warning over the field radio before starting the process of arming the guns. Place warning signs on the roads leading to and from the location. b) Strap and record the lengths and OD for all tools that are RIH. c) Record length from CCL measurement point to the top shot on all gun assemblies. d) The gun should incorporate a GR/CCL sub to tie into the openhole. GR. e) Resistive blasting caps should be used for all wirel ine perforating (standard Schlumberger pol icy). RECEIVED J U N - 1 199~ Alaska Oil & Gas Cons. Commission Annhnrnnn Page 3 MILNE POINT UNIT G-3 e RIH with 1-11/16" Enerjet gun loaded with 6 SPF in 0° phasing. Perforate the following interval- Depth Feet Sand Shot Density 5538'-5568' 30 OB 6 POOH with perforating gun and RD Schlumberger. 5. Return well to injection.. . Notify AOGCC of the following- a) ComPletion of project (AOGCC Form 10-404). RECEIVED J UN - 1 1992 Alaska Oil & Gas Cons. Commission Anchorage April 3, 1992 Conoco Inc. 3201 C Street, Suite 200 Anchorage, Al( 9~ (9O7) 564-76OO oRIGINAL Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: WELL COMPLETION REPORT Dear Mr. Johnston: Attached please find a Well Completion Report for Well G-3. This well is located on the Milne Point Unit. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, Bob Soptei Environmental Coordinator- RJS/bgs Attachments CC G-3 Well File Chevron Occidental Hal Stevens/Van Heare, MPOC (w/o attachments) \RJS\AOGCC33 RECEIVED APR - 9 1992 Alaska Oil & Gas Cons. C0mrnissi0'n Anchorage i II . '/-"!', sTATE OFALASKA ~'i n 161N A [ ALASKA 0i'E AND GAS CONSERVATION COtv,,V, iSS~)l~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,. 1. Status of Well Classification of Service Well OIL C GAS [] SUSPENDED [] ABANDONED [] SERVICE ~. Name of Operator 7. Permit Number Conoco Inc. 89-46 3. Address 8. APl Number uPouch 340045, Prudhoe Bay, Alaska 99734 so- 029-21942 4. Location of well at surface 9. Unit or Lease Name 3525' FNL, 3362' FEL, SECTION 27, T13N, R10E, UM Milne Point Unit At Top Producing Interval 10. Well Number 2875' FNL, 2181' FEL, SECTION 27 G-3 At Total Depth 11. Field and Pool 1850' FNL, 59.4' FEL, SECTION 27 Kuparuk River/ 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Schrader ;Bluff 59.3' KB (MSt)J ADL 25906 i2. Date Spudded 13. Date T.D. Reached 14. Date Com_p., Susp. or Aband. 1 15. Water Depth, if offshore 16. No. of Completions 8/29/89 9/03/89 9/13/~ld/ ~,~ ]~/,~ feet MSL 1 17. Total Depth (MO+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set [ 21. Thickness of Permafrost 5910'/4603' 5813'/4519', YES ~] NO [] N/A feet MDJ +-- 1800 22. Type Electric or Other Logs Run ~R, DGR, CNO, rBGT, LDT, GR, GYRO CALIPER, TDT-P 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1'13-3/8" 48 H-40 SURFACE Il0' RKB 30" ARC SET TO SURF. NONE · 9-5/8' 47 L-80 , SURFACE 2931' RKB12-1/'4" 181 Perm E/138G NONE 7" 29 L-80 SURFACE 5891' RKB 8-11'2" 87 BBL G NONE I i ] 24 BBLS ARC SET I~ ?OLLOWED BY 52 BBLS DEAD CRUDE , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE - DEPTH SET (MD) PACKER SET (MD) lq SANDS 5334' (4111) - 5356' (4129) 2-7/8" 4946' 4946' 24 SPF 5372' (4142) - 5382' (4151) 5404' (4169) - 5408' (4173) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5433' (4194) - 5438' (4198) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5522 - 5536 517 BBLS Gelled Water OA SAh'D 5522 (4270) - 5536' (4282) 30. 250 lbs Carbolite , .5334 - 5438 Gravel Pack :27. PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A (Surface Hodification)[ N/A "bate of -i-est Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ] GAS-OIL RATIO TEST PERIOD * I Flow Tubing Casing Pressure .CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 28. CORE DATA B'ri 'el' description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A RECEIVED APR - 9 1992 </'~'~~ *~ ~/~' ~' '~ ~ Alaska 0ii & Gas Cons. G0mmiSs't0n Form 10-407 ; Amm,hora§~ Submit in duplicate Rev. ?-l~0 CONTINUED ON REVERSE SIDE 29. , ,:i" [?~' :' G~:O[O~C';'~rVI~R. ,. .,RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. IDEPTH GOR, and time of each phase. RKB RKB N/A Not Tested Top Upper Ugnu 4716 3623 Top Lower Ugnu 5050 3874 Top West Sak 5522 4270 3~. UST OF ATrACUMENTS Da'~ly Well Activit-ies Reports, Well sketch, and G~rr.o Survey 32. I hereby certify that the fore§oing is true and correct to the best of my knowledge INSTRUCTIONS General: This form, is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28' If no cores taken, indicate "none". Form 10-407 Sq(~qL C:4~8' 4 Fie'- 41'i4' ~:~%~- 5448' 4 55zzS 55~' 4z-~o'- qz.9 z RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 CONOCO INC. G-3 MILNE POINT ALASKA COMPUTATION DATE: 9/20/89 TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DATE OF SURVEY: 9-19-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90100 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER DLS TOTAL RECTANGULAR COORDINATES VERT. DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. ,, 0 .00 -59.27 100 100.00 40.73 200 200.00 140.73 300 300.00 240.73 400 399.99 340.72 0 0 N .00 E .00 0 16 S 79.30 W .27 0 24 N 76.30 W .20 0 19 N 84.60 W .11 0 20 N 54.10 W .17 .00 .00 .00 .04S .23W -.22 .00S .81W -.70 .liN 1.44W -1.18 .31N 1.95W -1.52 500 499.99 440.72 600 599.92 540.65 700 699.68 640.41 800 799.11 739.84 900 897.99 838.72 0 35 N 50.20 E .75 2 52 N 67.30 E 2.32 4 49 N 68.10 E 1.94 7 13 N 70.90 E 2.43 9 43 N 67.10 E 2.55 .81N 1.80W -1.13 2.11N .91E 1.87 4.65N 7.13E 8.50 8.27N 16.97E 18.81 13.62N 30.70E 33.33 1000 996.04 936.77 12 53 N 64.40 E 3.22 1100 1092.60 1033.33 17 10 N 61.30 E 4.34 1200 1187.64 1128.37 19 1 N 61.80 E 1.86 1300 1281.44 1222.17 21 27 N 61.80 E 2.44 1400 1373.16 1313.89 25 27 N 61.10 E 4.01 21.73N 48.54E 52.81 33.64N 71.57E 78.69 48.43N 98.88E 109.71 64.78N 129.36E 144.26 83.82N 164.31E 184.03 1500 1462.36 1403.09 28 16 N 61.40 E 2.81 1600 1550.24 1490.97 28 43 N 61.70 E .47 1700 1637.26 1577.99 30 17 N 62.10 E 1.59 1800 1722.58 1663.31 32 32 N 61.60 E 2.27 1850 1763.74 1704.47 36 35 N 61.20 E 8.11 105.55N 203.93E 229.18 128.27N 245.88E 276.85 151.47N 289.32E 326.04 176.07N 335.28E 378.11 189.65N 360.19E 406.46 1900 1803.17 1743.90 39 15 N 61.10 E 5.32 2000 1880.04 1820.77 40 15 N 61.10 E 1.00 2100 1956.01 1896.74 40 51 N 61.20 E .60 2200 2030.19 1970.92 43 20 N 60.60 E 2.52 2300 2101.04 2041.77 46 24 N 60.50 E 3.06 204.48N 387.10E 437.17 235.39N 443.09E 501.08 266.76N 500.05E 566.07 299.37N 558.61E 633.06 334.06N 620.05E 703.60 2400 2168.05 2108.78 49 25 N 60.10 E 3.02 2500 2232.42 2173.15 50 26 N 59.60 E 1.09 2600 2296.13 2236.86 50 25 N 60.20 E .46 2700 2360.08 2300.81 50 4 N 60.30 E .36 2800 2424.63 2365.36 49 31 N 60.60 E .60 370.83N 409.27N 447.93N 486.08N 523.74N 684.51E 777.79 750.67E 854.30 817.36E 931.38 884.11E 1008.24 950.55E 1084.59 2900 2489.37 2430.10 49 46 N 60.10 E .46 3000 2554.46 2495.19 49 0 N 60.90 E .99 3100 2620.97 2561.70 47 36 N 62.50 E 1.83 3200 2688.47 2629.20 47 28 N 63.90 E 1.04 3300 2753.88 2694.61 50 48 N 64.80 E 3.40 561.44N 1016.78E 1160.78 598.83N 1082.85E 1236.67 634.23N 1148.58E 1311.25 667.50N 1214.43E 1384.84 700.22N 1282.60E 1460.14 ANCHORAGE ALASKA PAGE 2 CONOCO INC. G-3 MILNE POINT ALASKA COMPUTATION DATE: 9/20/89 DATE OF SURVEY: 9-19-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90100 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3400 2817.26 2757.99 50 31 N 64.60 E .32 3500 2881.59 2822.32 49 23 N 65.80 E 1.46 3600 2945.93 2886.66 50 30 N 65.70 E 1.12 3700 3007.57 2948.30 53 22 N 64.80 E 2.95 3800 3066.45 3007.18 54 29 N 63.50 E 1.54 733.27N 1352.54E 1537 · 13 765 . 39N 1422 . 02E 1613 . 24 796 . 83N 1491.81E 1689 · 27 829 . 80N 1563 . 30E 1767 . 55 865.04N 1636.04E 1848.05 3900 3124.40 3065.13 54 40 N 62.80 E .60 4000 3181.73 3122.46 55 20 N 62.70 E .68 4100 3239.82 3180.55 53 37 N 59.90 E 2.86 4200 3298.85 3239.58 54 1 N 60.40 E .56 4300 3357.65 3298.38 53 57 N 60.60 E .18 901.85N 1708.75E 1929.35 939.37N 1781.58E 2011.11 978.43N 1852.98E 2092.43 1018.61N 1922.99E 2173.14 1058.44N 1993.39E 2254.00 4400 3418.66 3359.39 50 51 N 56.80 E 4.31 4500 3481.69 3422.42 51 0 N 56.50 E .27 4600 3545.39 3486.12 49 51 N 57.00 E 1.20 4700 3612.01 3552.74 46 34 N 55.30 E 3.52 4800 3682.58 3623.31 43 37 N 55.00 E 2.96 1099.54N 2061.09E 2333.20 1142.22N 2125.94E 2410.77 1184.48N 2190.40E 2487 · 78 1225.99N 2252.34E 2562.24 1266.46N 2310.47E 2632.90 4900 3756.44 3697.17 41 7 N 54.60 E 2.52 5000 3833.44 3774.17 38 9 N 53.70 E 3.02 5100 3913.85 3854.58 34 45 N 53.20 E 3.41 5200 3996.98 3937.71 32 45 N 54.10 E 2.07 5300 4081.36 4022.09 32 13 N 48.30 E 3.16 1305.30N 2365.53E 2700.10 1342.64N 2417.24E 2763.65 1378.02N 2464.98E 2822.78 1410.95N 2509.72E 2878.08 1444.56N 2551.55E 2931.23 5400 4166.10 4106.83 31 57 N 42.90 E 2.88 5500 4251.15 4191.88 31 30 N 42.90 E .46 5600 4336.67 4277.40 30 56 N 42.70 E .57 5700 4422.45 4363.18 30 54 N 42.70 E .03 5800 4508.32 4449.05 30 45 N 41.70 E .54 1481.69N 2589.47E 2982.84 1520.21N 2625.27E 3033.34 1558 . 24N 2660.49E 3083 . 09 1596.01N 2695.34E 3132 · 40 1633.97N 2729.77E 3181.43 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSIONRADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3181.43 FEET AT NORTH 59 DEG. 5 MIN. EAST AT MD = 5800 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 59.10 DEG. / £CEI VED '~laaEa,Oil,& Oas Cons. Commission Anchorage RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE CONOCO INC. G-3 MILNE POINT ALASKA COMPUTATION DATE: 9/20/89 DATE OF SURVEY: 9-19-89 JOB NUMBER: AK-BO-90100 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASDVERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -59.27 .00 .00 .00 1000 996.04 936.77 21.73 N 48.54 E 3.96 3.96 2000 1880.04 1820.77 235.39 N 443.09 E 119.96 116.00 3000 2554.46 2495.19 598.83 N 1082.85 E 445.54 325.58 4000 3181.73 3122.46 939.37 N 1781.58 E 818.27 372.73 5000 3833.44 3774.17 5800 4508.32 4449.05 1342.64 N 2417.24 E 1166.56 348.29 1633.97 N 2729.77 E 1291.68 125.12 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. t~'ZY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 CONOCO INC. G-3 MILNE POINT ALASKA COMPUTATION DATE: 9/20/89 DATE OF SURVEY: 9-19-89 JOB NUMBER: AK-BO-90100 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -59.27 59 59.27 .00 159 159.27 100.00 259 259.27 200.00 359 359.27 300.00 .00 .00 .00 .01 S .04 W .00 .00 .07 S .53 W .00 .00 .09 N 1.21 W .00 .00 .17 N 1.76 W .01 .00 459 459.27 400.00 559 559.27 500.00 659 659.27 600.00 759 759.27 700.00 860 859.27 800.00 .54 N 2.12 W .01 .00 1.33 N . .96 W .02 .02 3.3.8 N 3.98 E .17 .15 6.62 N 12.20 E .57 .40 11.04 N 24.59 E 1.44 .87 962 959.27 900.00 1065 1059.27 1000.00 1169 1159.27 1100.00 1276 1259.27 1200.00 1384 1359.27 1300.00 18.32 N 41.30 E 3.10 1.66 29.01 N 62.94 E 5.99 2.89 43.81 N 90.26 E 10.72 4.73 60.66 N 121.68 E 16.91 6.18 80.68 N 158.62 E 25.40 8.49 1496 1459.27 1400.00 1610 1559.27 1500.00 1725 1659.27 1600.00 1844 1759.27 1700.00 1972 1859.27 1800.00 104.76 N 202.49 E 37.24 11.84 130.62 N 250.23 E 51.02 13.79 157.49 N 300.69 E 66.22 15.20 188.09 N 357.35 E 85.21 18.99 226.89 N 427.69 E 113.51 28.30 2104 1959.27 1900.00 2240 2059.27 2000.00 2386 2159.27 2100.00 2542 2259.27 2200.00 2698 2359.27 2300.00 268.12 N 502.52 E 145.04 31.53 313.15 N 583.05 E 181.14 36.10 365.78 N 675.71 E 227.31 46.17 425.71 N 778.71 E 282.88 55.57 485.60 N 883.27 E 339.47 56.59 2853 2459.27 2400.00 3007 2559.27 2500.00 3156 2659.27 2600.00 3308 2759.27 2700.00 3465 2859.27 2800.00 543.73 N 985.93 E 601.52 N 1087.68 E 653.46 N 1185.83 E 703.03 N 1288.58 E 754.72 N 1398.28 E 394.13 54.65 448.06 53.93 497.51 49.46 549.26 51.74 606.44 57.18 3621 2959.27 2900.00 3787 3059.27 3000.00 3960 3159.27 3100.00 4132 3259.27 3200.00 4302 3359.27 3300.00 803.59 N 860.56 N 924.46 N 991.67 N 1059.53 N 1506.72 E 661.85 55.40 1627.03 E 728.37 66.53 1752.70 E 801.22 72.85 1875.82 E 873.52 72.30 1995.30 E 943.47 69.94 .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 CONOCO INC. G-3 MILNE POINT ALASKA COMPUTATION DATE: 9/20/89 DATE OF SURVEY: 9-19-89 JOB NUMBER: AK-BO-90100 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAEVERTICAL DEPTH DEPTH DEPTH 4464 3459.27 3400.00 4621 3559.27 3500.00 4767 3659.27 3600.00 4903 3759.27 3700.00 5032 3859.27 3800.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 1126.94 N 2102.86 E 1005.11 61.64 1193.37 N 2204.00 E 1062.10 56.99 1253.50 N 2291.92 E 1108.24 46.14 1306.72 N 2367.52 E 1144.47 36.23 1354.42 N 2433.24 E 1173.32 28.84 5155 3959.27 3900.00 5273 4059.27 4000.00 5391 4159.27 4100.00 5509 4259.27 4200.00 5626 4359.27 4300.00 1396.65 N 2490.00 E 1195.83 22.52 1435.43 N 2540.99 E 1214.60 18.77 1478.59 N 2586.54 E 1232.68 18.08 1523.86 N 2628.66 E 1250.25 17.57 1568.20 N 2669.68 E 1267.08 16.83 5742 4459.27 4400.00 5800 4508.32 4449.05 1612.22 N 2710.28 E 1283.64 16.56 1633.97 N 2729.77 E 1291.68 8.04 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS 9..~ 9-'f59 RECEIVED APR - 9 1992 Alaska Oil & Gas Cons, Commission Anchorage SPERRY--SUN DRLG. °VCS. ' G-3 ~4ILNE POTNT ALASKA 9-19-89 VERTICAL PROJECTZON START TVD = 0 FINISH TVD = 4508,32 SCALE IS 1000 FEET/IN _.J ! 1000 2000 ~000 4o00 SO00 eO0O 7000 5800 ~o~o so5o VERTTCAL SECTTON DIRECTION = 0.00 5o5o so5o Nilne.Poin~ G No. 3 - CONVERSION . AP!_ .No..; 50-.029.-21942 ~_ L(~ation: Milne point Field ~ SCHRADER BIA3FF POOL ~E ~er: 10-61-1458 ]tpp~'oV~: 12/27/91 AFE /~~tl $ 501,000 gross Cost to Date~ $ 148,391 gross o~erator: Conoco Chevron OXY 0.5942340 0.3764866 0.0292794 Objeotives~ schrader Bluff Pool Spud Date: aig: s#4 Drilling Days Completion Dayst Workover Days Actual ~ ~' Depth: N/A N/A 6 Teat .... _Typ_e ,. Intgrval ~rrent operations~ Sh°ws RECEIVED APR - 9 1992 Oil & Gas Cons. Commission Anchorage 2-3-92 Pull BPV. R/U Trans Tech and pull AVA sleeve at 4748' ~1/~ a~d move off Trans Tech. Install BPV. Moving rig onto~e 2-4-92: Continue to rig up on G-3. R/U HB&R and heat 200 BBLS of 8.6 ppg Nacl with 12% methanol brine to 150 degrees and off load through rig filters to shaker pit for changing over hole. Also, off load 300 BBLS of 8.6 ppg N&cl with 12% methanol brine for completion work. Pull BPV. R/U & Circ. 8.6 ppg Nacl with 12% methanol brine at 150 degrees down CSG at 2 B~LS/M at 220 PSI and taking returns to slop tank. Hole taking some fluid. Total BBLS pumped 225. Set BPV and NU tree. Check press, on tubing; 75 PSI. Felt Putting in two way check would beun-safe due to gas breakout. N/tree back up and pump 40 BBLSbrine at 1-1/2 BBLS/M at 200 PSI down tubing. No returns. Shut tubing and CSG in for 30 min to check for pressure build up. Tubing went on vacuum. Set BPV N/D tree and N/U BOP'S. Note: lost 95 bbls of 8 6 brine to formation. Note: Held pre-job safety meeting with all hands. 2-5-92: Completed N/U BOP'S. Pull BPV. Set two way check and test BOP'S. S/D and attend annual environmental kick-off meeting. Start rigging up ~pooling unit, sheave,etc., in order to POOH with ESP. Pull 2-way check in hanger. Sting into hanger with 2-7/8" EUE. Lost main engine on draworks, engine knocking. S/D and check out. Dropped two rods. Wait on mechanic from Deadhorse to trouble shoot problem. Initial indications show the valves to be frozen in the heads. Will call NC Machinery in the morning to send out parts required to repair out of Fairbanks. S/D wait on parts. Routine rig maintenance and clean-up. 2-7-~2: 2-8-92 Reverse circulate 8.6 PPG NACL. Pumped 25 BBLS and never got returns. Well on vacuum. Standby waiting on parts from Seattle, while working on main engine of drawwork~. Continue to work on engine. Able to start and run :in order to check o,ut, everything looks good. Held pre-job safety meeting. Back out lug bolts and alignment pin on tubing hanger. Continue to POOH with 2-7/8" EUE and ESP cable. Checked cable at surface; looks good. ~Checked rotation of pump and motor; both will turn freely. Motor looks like it got hot at one time. Resistance looks good through-out cable and penetrator. Top of pump indicates some sand, but not packed. Found coupling between gas sep. and pump washed out with pieces of metal on lower flange. Pump shaft had lots of play on lower end of pump, indicating impeller's, diffusers, etc., washed out. Some formation sand on outside of ESP assembly. Lay DN ESP assembly in pipe van and load in shipping boxes. Start loading pipe van with 1" CS Hydril and handling tools. Change oil in main engine on drawworks. Rig DN ESP sheave and associated equipment. Set up to RIH with 1" CS Hydril, 2.25#/Ft. PU a total of 30 JNT.'s of 1" and follow up with 2-7/8" x 1" XO. One hour from top of Baker gravel pack packer at 4946'. Continue to RIH with 1" CS Hydril on 2-7/8" EUE tbg. Tag fill at 5728', 85' above PBTD at 5813'. "OB" Sand perf's will beat 5538' - 5568', which will be 160' above fill mark. POOH with 1" CS Hydril and 2-7/8" EUE tbg. Lay dow%~ 1# CS in pipe van and rig down associated handling tools. RIH with Baker model S-22 locator seal assembly on 2-7/8" EUE 6.5#/FT tbg. Sting into Baker gravel pack packer at 4946' and press, up on annulus to 1500 PSI and hold for 15 mins. Sting out of packer assembly. Pump 100 BBLS of 8.6 NACL w/NALCO 3900 down annulus, displace with 30 B~LS of meth., w/10 BBLS of diesel on top. Space out 2-7/8" EUE tubing at 4946' with 155 JNT'S of 2-7/8" EUE 6.5#/ft. tubing and three separate pup JNT'S of 12.10', 10.10', and 2.10' with hanger assembly length of 2.35'. Total tally was 4946.59'. Set S-22 seal assembly in neutral weight on Baker packer. Tested 7" annulus to 1500 PSI for 15 min's, after locking down hanger. Set BPV, freeze protect tubing with 30 BBLS of methanol. Pull BPV and set 2-way check in tubing hanger. Screwed in alignment pin on hanger. ND BOP'S and NU wellhead, test to 5000 PSI. Tested ok. Pump off brine tanks. Stored clean brine at Baroid, and vac. out slop tank, etc. Rig down move to J-Pad for sub structure modifications. Total 8.6 PPG NACL left was 225 BBLS and 25 BBLS of diesel. Start moving 1" CS Hydril out of pipe van to tubing racks, will keep on location for possible clean-out on J-2 well. RD and move to J-pad for sub-structure modifications. Lay out rig matting. Level pad, etc. Clean-up G-Pad locations around the G-1 and the G-3 wells. Left BPV in wellhead. Rig Up sub- structure for modification work. Remove BOP'S and associated lines, etc. ** TOTRL PRGE.13T~-** STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLTCAT!ON FOR SUNDRY APPROVALS ORIGInaL 1, Type of Request: Abandon ,,. Suspend ,,, Alter casing Repair well Change approved program __ Name of Operator Conoco Inc. Operation shutdown Re-enter suspended well Plugging __ Time extention Stimulate Pull tubing X Variance Perforate X . Other..X Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development X Exploratory Stratigraphic NSB AK NSB AK Location of well at surface 3525' FNL, 3362' FEL, Sec. 27, T13N, RIOE, U.M. At top of productive interval 2875' FNL, 2181' FEL, Sec. 27, T13N, RIOE, U.M. At effective depth At total depth 1850' FNL, 594' FEL, Sec. 27, T13N, RIOE, U.M. NSB AK 8. Datum elevation (DF or KB) KB 59.3' (MSL) unit or Property name Milne Point Unit feet 8. Well number G-3 9. Permit number 89-46 10. APl number 50-029-21942 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition surnrnary Total depth: measured 5910' feet Plugs (measured) tree vertical 4601' feet None Effective depth: measured 5813' feet Junk (measured) tree vertical 4519' feet None Casing Length Size Cemented Measured depth Structural Conductor 75' 13-3/8" ' Surface 110' surface 2896' 9-5/8" Surface 2931' Intermediate Production 5856' 7" See Attached 5891' Liner Perforation Depth: measured 5334'-5356', 5372'-5382', 5404'-5408', 5433'-5438', 5522'-5536' True vertical depth 110' 2510' 4585' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 4897' MD tree vertical 4111'-4130', 4143'-4152', 4170'-4174', 4195'-4199', 4270'-4282' R£¢ IV -D Packers and SSSV (type and measured depth) None 13. Attachments NOV A,..~o ni~ & Gas Cons. Description summary of proposal X. Detailed operations program ....n"~"'"B-OP s .1~1~(~I~ 14. Estimated date for commencing operation January 15, 1992 16. If proposal was verbally approved Name of appmver Date approved 15. Status of well classification as: Oil X Gas Suspended Date th fore}going is true to rny 17. I hereby certify the and correct the best of knowledge. Signed "~~.~B. G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: NOtify CommiSsion so representative may witness IApprovai NO. Plug integrity BOP~/~ Test Location clearance~.~, ~ Mechanical Integrity Test ;~ Subsequent form required 10- .~z,'-t-- -~'"'~' .,.-..,~" ,~.i,'::;{ Approved by order of the Commission._.. LONNIE C. CommiSsioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE INl~l-~tt~iiROD: OIL ' BPD. WATgER" ' ....... : BPOe. GAS '' '~.' ,"' ' ~iON DATE . -' " .' fMUD .TYPE' ~;': - ...... MUD WT~~ ' WELL DATA MCFD MCFO BILl. gED ON NEW WgEIGHT SlZI FROM TO MAXIMUM PS1 USgED AL'IOWAB/Ir LINGER TU BINO ~)PgE, HOI..gE _ . 5 ~Idl~ I ~4~ ( O FIr RFORATION$ · PgERFORATIONS PgERFORATIONS .- ..... -.~-. _'. PRIrSSURgE :';."' ' ' ' .... .-:' ~ -,' "i ?'-:i .'.'i:.-L;-. ' .*-:.:?~:. .. JOB DATA .~',: --.:::.~ I+-: ,."~ ~;~ I'"%'-m;~, I-,-. '~:s~ ~,.., ~:~8 1, ~:., ~ ...~, ',:r;~ ~,; ~-' .:.":.~;~..:t'-. ~.; d' ~ . .' ._ "r~ PERSONNEL AND ~ERVI~E UNIT~ MATERIALS . ':- ' DBN$1T, Y' '-' ~BIGAL,.O-.API ... 0 · ' ' ' ' DgEN$1T.Y i' ~' '" 'LB/GAL,-API · ' $1Z~ : ' .LB, ,,, SIZi ''' '* .... LgE, NAME UNIT NO. ~ TYPIr I 3 '4 ~ 7c} ! ,.0= AT,ON ~oSs -7~oz. J4/ '?" La,,.) q I ' I -'," "-~'~-'" :-;'. ,~!: ~,- ~. CEMENT DATA · - " -. :""':'~ gEeL ~AL DmePL: mml..-(~M.. -CIMINTILURRYI tIL ~AL 37 C ¢LI To,,,Lvo,,,.. ,.L.---L. ' :' ~-;-4 i:~'~ I CASING AND Ground Elevation: ( RKB - Grd. E3.ev.: (ft) Top of Hanger-RKB:_~p,~ (ft) Maximum Recorded Temperature from Logging Runs , .Casin~ Tally .,. ' ............. Makeup Setting No., Pieces .... Size, - Weight % Gra..d_e - Thread - Etc. ..Le.n§t..h Depth · / ~-,, - -~ - / , ' Cement (Stage II) BBLS of PPG Time Started Time Completed Rate (BPM) PSI (max.) Pre-Flush Stage I Stage II Displacement ('~'-~_5-- ~_/~~ ~- ~. _: 7'~)0 _ _ Recip, Pipe c~=9 .z~,~" .._ j'~_~o~OCZ) ~ (Why Stopped)zZ~,~ ~q,~zz~/ Bottom Plug: ~ No) Top Plug: (Y~es', No)Bumped Top P]ug:,~, No) Total Pumped Disp.~k~ .... (bbls) ~/ Floats Held: (~s~ No) Full Returns: ~, No> Cement Returns to Surface: (Yes, ~ Initial String Weight:.. /~ ~ (lbs) f,aFtnal tana~ns Weight : Y~ ~ Service Co.: ~/~ Perfo~ance:~ Fair, Poor) Date: _ ?:._~-~?-' ' Supervisor: ~~j~ 16-0 BBLS (lbs) MIRU EWS #4 rig. HILNE POINT UNIT ~-3 CONVERT TO INJECTION SUMMARY PROCEDURE 2. Kill well with 8.5 ppg NaCl. ND production tree. NU BOPE and test. 3. POOH with tubing, ESP, and ESP cable. LD ESP and cable. 4. RU slickline unit and RIH with wireline tools. Tag fill. 5. POOH with wireline and RD unit. 6. RIH with seal assembly on 2-7/8" tubing and sting into gravel pack packer at 4946'. Pressure test annulus to 500 psi. 7. RU coiled tubing unit. PBTD. RIH with coiled tubing and circulate out fill to 8. POOH with coiled tubing and RD coiled tubing unit. · Pull out of gravel pack packer. Space out tubing. Circulate in packer fluid. Sting back into gravel pack packer and land tubing hanger. Pressure test annulus to 500 psi. Pressure test hanger to 500 psi. 10. ND BOPE and NU production tree. RDMO rig. 11. MIRU perforating company with mast unit. Rig up lubricator. RIH with perforating gun and perforate 5538'-5568'. POOH with perforating gun. RDMO perforating company. ~~. Prepare well for injection. BGA- 11/21/91 .,." . ;~, ~ STATEOF ALASKA 0 J~ I ,~ ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ]~ GAS ~ SUSPENDED [m ABANDONED I--~ SERVICE ~--I_.._ 2. Name of Operator ~ ['~'~'¥i-~t~i 1 7. Permit Number CONOCO INC. i VErIFiED ! I 89-46 3. Address ~__02 ~-- 340045 PRUDHOE B~Y~ AK 99734 21942 4. Location of well at surface ~~.~,~...~ 9. Unit or Lease Name 3525' ~NL, 3362~ FEL~ SECTION 27~ T1 ~ UM MILNE POINT UNIT At Top Pre~.~ucing Interval I~l 10. Well Number 2875~ FNL, 2181~ FEL, SECTION 27 I VEflfFIED I G-3 At TOtal Depth J.~_/Z~- J 1 1. Field and Pool 1850~ FNL, 594~ FEL, SECTION 27 ~ KUP/~RUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. SCH~UtDER BLUFF POOL :K.B 59 · 3 ' MSL J 2~,D125906 12. Date Spudded08/29/89 13. Date T.D. Reached09/03/90 J '4' Date c°mp" sum' °r Aband' J ~5' Water Demh' if °ffsh°re I '6' N°' °f C°m~'eti°ns09/13/90 N/A feet MS[. I 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set .21. Thickness of Permafrost 5910 ~/4603' 5813 ~/4519 YES~ X NO~] N/]~ feet MD +___1800! 22. Type Electric or Other Logs Run EWR, DGR, CNO, BGT, LDT, GR, GYRO, C]~LIPER, TDT-P 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP /BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8' 48 H-40 SUP. FACE 110~ RKB 30!'~ ~C. SET TO S'3RF, NONE __9-S/8" 47 L-SO SURF/~C]~ 2931' RKB12 ,/4"181 PERM E/138G NONE 7" 29 L-80 SURF/~C] 5891~ RKB 8 ./2' 87 BBL G I NONE 24 BBLS ARC SET ~, FOLLOWED BY .~2 BBLS DEAD caupE 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N SANDS 5334~ (4111) - 5356~ (4129) 2 7/8 4900t 4946~ 24SPF 5372" (4142) - 5382" (4151) 5464~ 5404" (4169) - 5408~ (4173) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC, 5433t (4194) -- 5438t (4198-) DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 5522 - 553.6J 517 bbls Gelled Water 01% SAND 5522(4270) - 5536~ (4282) [ 30t 250 lbs Carbolite PrODDan~ , 4SPF 5334 - 5438J G-r-&vel Pack 27. PRODUCT!ON TEST D~*- =:-~t Production J Method of Operation (Flowing, gas lift, etc.) "~/'2.~,~,.clt. J Electrical Submersible Pumg Date of Test Hours Tested IPRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO % · I o,.,,,.., Flow Tubing Casing Pressure JCALCULATED . JOIL-88L GAS-MCF WATER-88L OIL GRAVITY-APl (corr) Press. ZT,,O --- J24-HOUR RATE J~J jot~ "Z.~,~ ~'~... 28. CORE DATA Brief description of lithoiogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chios. · ~ ..... '.,-0/j .& Ga,,.; Cons. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplica~~/ 29. NAME GEOLOGIC MARKERS Top Upper Ugn't Top Lower Ugn~ Top West Sak I MEAS, DEPTN RKB 4716 5O5O 5522 TRUE VERT. DEPTH RKB 3623 3874 4270 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, ancl t~me of each phase. N/A Not Tested 31. LIST OF ATTACHMENTS Daily Activity Reports and Gyro Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signe~. ~:---'"'-~'~ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lanes 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 welt 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 DRILLING HISTORY KuParuk River - SBP - North Slope Borough, Alaska W. I. 1.000000% Milne Point G No. 3 (SB REW) CONFIDENTIAL AFE 10-61-1310 Location: 3420' FEL, 3940' FNL, Sec. 27, T13N, R10E, Umiat Meridian Location: Bottom hole, 660' FEL, 1800' FNL, Sec. 27, T13N, R10E Objective: 6,115' MD- Schrader Bluff 09-02-89: Drilling f/4275' to 5180', circulate and condition hole, POOH Change BHA, move RLL tool to top of Navidrill TIH to 5180' · · f logging with RLL f/4976' to 5180'. Drilling f/5180' to 5240'. MWD Surveys MD Angle Direction 4518' 50.9 N54.1E 4884' 41.2 N51.5E 5110' 34.4 N47.9E Mud wt. 9.1 Parker 141 (0-5-0) Viscosity 38 Cum. Mud Cost: $17,550 Drilling Foreman: Brady 09-03-89: Drill and Navidrill f/5240' to 5910', circulate and short trip, 15 stands. Circulate and POOH, L/D BHA. R/U Schlumberger, RIH w/LDT and GR log f/5570' to 4900' and f/5907' to 2900', POOH R/U Borehole vol. (BGT) and GR. MWD Survey Depth Angle Direction 5016' 37.7 N50.9E 5110' 34.4 N47.9E 5232' 32.5 5668' 30.7 5806' 30.6 Viscosity 40 Mud wt. 9.3 Parker (0-6-0) N50.1E N40.7E N38.SE Cum. Mud Cost: $20,733 Drilling Foreman: Brady 09-04-89: POOH w/GR and LDT, run BGT w/GR f/5907' to 2930'. P/U BHA and TIH, cir. and condition hole. POOH L/D Drill pipe and BHA. RIH w/151 joints 7" 291b/ft L-80 BTRC csg. Float shoe at 5891'. Pump 10 ppg 40 BBL Sepiolite spacer. Mud wt. 9.3 Viscosity 42 Cum. Mud Cost: $23,926 Parker 141 (0-7-0) Drilling Foreman: Brady 09-05-89: Mix and pump 87 Bbls. of Class "G" with .3% Halad 24, .1% LWL, .2% CFR-3. Drop plug and displace with 190 Bbls. of 9.6 ppg NaCl and 20 Bbls of diesel. Bumped plug to 2500 psig. Rig down csg. crew. ND BOP, NU blind flange. Released rig @ 0600 hrs. 9/5/89· Mud wt. 9.3 Viscosity 42 Cum. Mud Cost: $23,926 Parker 141 (0-8-0) Drilling Foreman: Brady DR~LL~N~ H~STORY Kuparuk River - SBP - North Slope Borough, Alaska W. I. 1.000000% Milne Point G No. 3 (SB REW) CONFIDENTIAL AFE 10-61-1310 Location: 3420' FEL, 3940' FNL, Sec. 27, T13N, R10E, Umiat Meridian Location: Bottom hole, 660' FEL, 1800' FNL, Sec. 27, T13N, R10E Objective: 6,115' MD- SChrader Bluff 08-29-89: Skid rig, N/U diverter and flowlines and test. P/U BHA. Drlg. ice from 40' to 110'. Orient MWD, drlg. and Navidrill f/ll0' to 931'. Mud wt. 9.5 Parker (0-1-0) SURVEY DATA MD Angle Dir. 381' 0.70 N62.7E 563' 1.80 N73.4E 745' 6.20 N69.6E 837' 8.20 N66.0E ViscOsity 93 Cum. Mud Cost: $405 Drilling Foreman: Brady 08-30-89: Drill and navidrill f/931' to 1113' short trip to 280' Drill and navidrill f/ll13' to 1883'. Short trip to 1113'. Drill and navidrill f/1883' to 2761' Mud wt. 9.5 Viscosity 67 Cum. Mud Cost: $5159 Parker 141 (0-2-0) Drilling Foreman: Brady 08-31-89: Drilling f/2761' to 2981' short trip f/2981' to 500' circulate and condition hole. POOH, L/D BHA. R/U and run 74 jts. 9 5/8", 47#/ft L-80 BTRC casing. Pump 40BBLs of 10ppg Sepiolite, 181 BBLs of 12.3 ppg Type E cement, 138 BBLs of 15.8 ppg Class G cement, displace with drilling mud, bump plug w/2000 psi. Float shoe set at 2931'. N/D diverter, N/U BOP. Mud wt. 9.5 Viscosity 67 Cum. Mud Cost: $9,159 Parker 141 (0-3-0) Drilling Foreman: Brady 09-01-89: Continue N/U of BOPE, Test BOPE to 5000 PSI, Annular to 3000 PSI. p/U and orient BHA, TIH to 2850' , Drill out float collar and float shoe and 10' of new hole, 2981' to 2991'. Perform EMW test to 10 ppg Drill f/2991' to 4022' short trip to float shoe . f · Drill f/4022' to 4275'. MWD SURVEY Depth Angle 2852' 49.3 3227' 48.8 4109' 53.4 Mud wt. 9.0 Viscosity 30 Parker 141 (0-4-0) Direction N57.6E N62.7E N58.1E Cum. Mud Cost: $10,701 Drilling Foreman: Brady Milne Point G No. 3 COMPLETION HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W.I. 1.000000% Milne Point G No. 3 (SB REW) CONFIDENTIAL AFE 10-61-1310 Location: 3420' FEL, 3940' FNL, Sec. 27, T13N, R10E, Umiat Meridian Location: Bottom hole, 660' FEL, 1800' FNL, Sec. 27, T13N, R10E Objective: 6,115' MD- Schrader Bluff 08-23-90: MIRU. Replace annular preventer sealing element. ND blind flange on csg spool, NU tbg spool, NU BOP. Cum Cost: $ 787,222 Mud wt. 9.6 Viscosity 42 Cum. Mud Cost: $23,926 EWS 4 (0-8-1) Drillinq Foreman: Fox 08-24-90: NU BOP, test BOP - OK. MU bit and scrapper, TIH 14 jts, set down on ice plug, circulate using diesel to remove ice plug. TIH to 5810' and tag fill. Short trip 20 stands. Cum Cost: $ 792,922 Mud wt. 9.6 Viscosity 42 Cum. Mud Cost: $23,926 EWS 4 (0-8-2) Drillinq Foreman: Fox 08-25-90: Tag PBTD, circ out 9.6 ppg NaCl to 9.2 ppg. Mix 43 BBL pill w/3 ppg caustic soda and 20 BBL pill of DM-40 Dirt magnet and brine. Reverse circ 90 BBL brine, pressure test csg. Pump 43 BBL pill @ 2 1/4 BPM followed by 40 BBL brine @ 4 BPM, followed by 22 BBL Dirt Magnet @ 2 1/4 BPM. Reverse circ an additional 140 BBL brine. POOH LD 26 jts., POOH standing back. MU perforating assembly. Cum Cost: $ 825,842 Mud wt. 9.2 Viscosity NA Cum. Mud Cost: $31,722 EWS 4 (0-8-3) Drilling Foreman: Fox 08-26-90: RIH w/ perforating-packer assembly. RU E-line, RIH w/ GR/CCL and correlate depth, POOH, add 2 pup joints to space out, set packer. RU E-line, RIH w/GR/CCL to verify guns on depth. POOH, RU surface equipment, pressure test flow lines. Drop bar to perforate. Csg perforated f/5522' to 5536' at 4 SPF. Cum Cost: $ 849,088 Mud wt. 9.2 Viscosity NA Cum. Mud Cost: $31,722 EWS 4 (0-8-4) Drilling Foreman: Fox 08-27-90: POOH w/ perforating assembly, RIH w/ RTTS packer and set @ 5320'. RU Dowell frac equipment, test surface lines. Pump 95 BBL prepad @ 20 BPM. Max pressure 4800 psi, final pressure 3680 psi, ISIP 1117 psi. Pump 274 BBL gelled water followed by 148 BB1 slurry w/ sand concentrations ramped from 2 ppg to 8 ppg. treating pressure 3900 psi at 20 BPM. FSIP 1240 psi. RD Dowell, RU E-line and tag fill @ 5733' RKB. POOH. Cum Cost: $ 960,263 Mud wt. 9.2 viscosity NA Cum. Mud Cost: $31,722 EWS 4 (0-8-5) Drilling Foreman: Fox Milne Point G No. 3 COMPLETION HISTORY Page 2 08-28-90: Finish R/D slickline unit, PU to RTTS PKR. revers circulate 20 BBLS of brine. POOH W/frac string L/D PKR. RIH W/ baker model (D) packer. Space out and set packer at (top) at 5462'RKB. POOH. M/U packer blanking plug and setting tool on bottom of 2-7/8 TBG.RIH 86 stands, set plug in sump packer and POOH. R/U slick line unit RIH with dump bailer w/ 100 lbs. of gravel pack sand. Set down at 5418' WLM. Shear disc POOH. Prepair to P/U perforating assembly. Cum Cost: $ 1,013,644 Mud wt. 9.2 Viscosity NA Cum. Mud Cost: $36,372 EWS 4 (0-8-6) Drilling Foreman: Fox 08-29-90: P/U perforating assembly, pkr, 2-DC's, RAM, 4-DC's, and OMNI valve. Test tools & RIH. RU E-line & RIH w/ GR-CCL. Correlate and space out guns. POOH & RD E-line. Set pkr & test surface lines. Cycle OMNI valve and pump 16.8 bbls brine down tbg. followed by 13 bbls diesel. Cycle OMNI valve and drop detonating bar. Cycle OMNI valve 0 psi w/ no initial flow. Cycle OMNI valve and reverse out w/ 190 bbls 9.2# brine followed w/ 45 bbls diesel. Cycle OMNI valve & release pkr. POOH w/ tbg. Cum Cost: $ 263,368 (corrected) Mud wt. 9.2 Viscosity NA Cum. Mud Cost: $36,372 EWS 4 (0-8-7) Drilling Foreman: Stevens Cum Cost: $ 329,829 Mud wt. 9.2 EWS 4 (0-8-8) 08-30-90: Continue POOH w/ tbg. L/D tools and spent perf. assembly. P/U 2nd perforating assembly, pkr, safety jt., jars, 6- DC's, RAM, and OMNI valve. Test tools & RIH. RU E-line & RIH w/ GR-CCL. Correlate and space out guns. POOH & RD E-line. Set pkr & test surface lines. Cycle OMNI valve and pump 27 bbls diesel down tbg to obtain 300 psi underbalance. Cycle OMNI valve to test position and drop detonating bar. Flow well 1 hr on 64/64 choke. Flowed 16.7 bbls. Cycle OMNI valve to circ. position & reverse circ w/ 36 bbls 9.2# brine and 34 bbls diesel down annulus and 7 bbls down tbg. Cycle OMNI valve to test position & release pkr. POOH w/ tbg. INTERVALS PERFORATED: 5334'-5356' md 5372'-5382' md 5404'-5408' md 5433'-5438' md Viscosity NA Cum. Mud Co ~ , 372 Drilling Foreman: Stevens 08-31-90: Continue POOH w/ tbg. L/D tools and spent perf. assembly. P/U bit & csg scraper. RIH w/ 2 7/8" tbg. TFF @ 5450' RKB MD. Indicates 7' fill. Work csg scraper through perfs 3 times & POOH. RU wireline. RIH w/ 5" pump bailer. Bailing to CO fill. Cum Cost: $ 358,549 Mud wt. 9.2 Viscosity NA Cum. Mud Cost: $39,222 EWS 4 (0-8-9) Drilling Foreman: Stevens Milne Point G No. 3 COMPLETION HISTORY Page 3 09-01-90: Bailer sticking. Worked free. Recovering sand & perf. gun debris. Stuck bailer on 8th trip. Drop blind box and cut wire at rope socket. RIH and fish blind box. RIH w/ 3" JDC and fish bailer. Jarred bailer free & POOH. (Still have 7' fill) M/U Baker blanking plug over shot and P/U Bulldog bailer & RIH on 2 7/8" tbg. Cum Cost: $ 384,319 Mud wt. 9.2 Viscosity NA Cum. Mud Cost: $39,222 EWS 4 (0-8-10) Drilling Foreman: Stevens 09-02-90: Continue in hole w/ tbg. TFF and CO to 5463' MD RKB. Top of pkr. Bailer pump started sticking. POOH and CO sand from bailer and pump. RIH w/ Bailer & over shot and 2 7/8" tbg. TFF at 5463' and work bailer. Could not engage fish. POOH w/bailer. RIH w/ over shot and 2 7/8" tbg to 5463'. Circ. 62 bbls down tbg. and engaged fish. Could not unseat plug. Sheared the shear out stud and POOH w/ tbg, over shot, and connecting rod. Order out fishing tools, PU DC's. Cum Cost: $ 404,869 Mud wt. 9.2 Viscosity NA Cum. Mud Cost: $39,222 EWS 4 (0-8-11) Drilling Foreman: Stevens 09-03-90: Wait on tools. M/U 4 11/16" od overshot, jars, bumper sub, 6 DC's & RIH w/ 2 7/8" tbg. Wash down over fish. Engage fish & PU set off jars. Set back down & PU fish free. POOH. Plug parted at pkr. Order short catch overshot. PU new overshot and RIH. Wash down over fish but could not engage. POOH & LD jars, BS, & overshot. Cutting brine from 9.2# to 8.6#. Cum Cost: $ 480,579 Mud wt. 9.2 Viscosity NA Cum. Mud Cost: $39,222 EWS 4 (0-8-12) Drillinq Foreman: Stevens 09-04-90: MU BakerCC milling tool, 2 junk baskets, 2 DC and RIH. Circ 9.2 brine out. Begin milling, unable to make hole or stall motor. POOH to change milling tool and modify shoe. PU larger milling tool w/modified millshoe. RIH. Cum Cost: $ 501,129 Mud wt. 8.6 Viscosity NA Cum. Mud Cost: $39,222 EWS 4 (0-8-13) Drilling Foreman: Stevens 09-05-90: RIH w/ mill, began milling, not making hole. Motor stalls out at 15K WOB and 4.5 BPM. POOH, small amount of sand and metal filings in junk basket. RU slick line, RIH w/ LIB, POOH. Impression shows sand or fine filings. RIH w/mill and 2 junk baskets. Reverse circulate brine, little or no solids returned. Prepare to POOH. Cum Cost: $ 511,619 Mud wt. 8.6 Viscosity NA Cum. Mud Cost: $39,222 EWS 4 (0-8-14) Drilling Foreman: Fox Milne Point G No. 3 COMPLETION HISTORY Page 4 09-06-90: POOH w/mill, packer plug no-go and collet were weged inside the burn shoe. RU slickline, RIH w/LIB to sump packer. POOH. Impression indicates no plug body, is suspected to have fallen through into millout extension. RD slickline. MU BHA and RIH. Tag sump packer and mill on packer. Cum Cost: $ 539,423 Mud wt. 8.6 Viscosity NA Cum. Mud Cost: $39,222 EWS 4 (0-8-15) Drilling Foreman: Fox 09-07-90: Continue to mill on packer, packer released, pushed packer to bottom. POOH, LD BHA. MU Haliburton bridge plug and RIH and set. Pump 10 BBL HEC pill w/250#'s sand on top of plug. RIH to check for sand fill, none tagged. Mix 500# sand and 15 BBLS brine and pump down tubing and displace to end of tubing, POOH 1 stand. Cum Cost: $ 572,021 Mud wt. 8.6 Viscosity NA Cum. Brine Cost: $ 7,745 EWS 4 (0-8-16) Drilling Foreman: Fox 09-08-90: RIH, tag sand 15' above bridge plug. POOH. RIH w/down hole tools to isolate and flow N series sands 300 psi underbalanced. Open to flow for 40 min., no flow to surface. Release pkr, tag bridge plug, sand no longer in place. Reverse curc 56 BBL brine, no sand or oil in returns. Release bridge plug, POOH. MU bit and scrapper, RIH to 5722' RKB, POOH. PU bridge plug, setting tool Champ III pkr and 6 DC's. Cum Cost: $ 609,658 Mud wt. 8.6 Viscosity NA Cum. Brine Cost: $26,545 EWS 4 (0-8-17) Drilling Foreman: Fox 09-09-90: RIH w/ isolation pkr and bridge plug. Unsuccessfully attempt to set BP. POOH, recovered pkr only. PU new Champ III pkr, RIH, J into BP, POOH 7 stands, set BP at 5277'. pressure test annulus to 500 psi - OK, pressure test annulus to 1500 psi - OK, retrieve BP. Attempt to set BP at 5517',5521', 5325', 5295' and 5625' with no success; pressure test indicated leak off. POOH w/pkr and BP and lay down. Cum Cost: $ 640,415 Mud wt. 8.6 Viscosity NA Cum. Brine Cost: $26,545 EWS 4 (0-8-18) Drilling Foreman: Fox 09-10-90: RIH w/ Baker isolation packer to 5565' and test - OK, retest at the top of th OA sands - OK. POOH, LD pkr. RU HLS, RIH w/ Model D sump pkr assembly. Set w/top @ 5464'. POOH, RD HLS wireline unit. PU gravel pack assembly, RIH w/gravel pack assembly. Cum Cost: $ 678,307 Mud wt. 8.6 Viscosity NA Cum. Brine Cost: $26,545 EWS 4 (0-8-19) Drilling Foreman: Fox Milne Point G No. 3 COMPLETION HISTORY Page 5 09-11-90: Continue RIH w/gravel pack assembly & 2 7/8" tbg. RU surface equip. & hold safety meeting. PT lines to 4000 psi. Set pkr and PT annulus to 500 psi. Release setting tool and L/D 1 jt tbg. Pickle tbg w/ 15% HCL and reverse out. Pump 3 bbl pre-pad, 12 bbl slurry (2 ppg. sand), and 3 bbl post pad for pre pack. Displace w/ final of 1750 psi. Mix main slurry and pump 20 bbl pre-pad, 28.5 bbl slurry (8 ppg sand), 10 bbl post pad, and displace w/ 8.1 bbls of brine and pressured out at 1800 psi. Reverse out. Allow 4 hours for gel to break and PT pack to 1500 psi OK. POOH w/x-over tool closing sliding sleeve. Continue POOH and L/D x-over, and wash pipe. RU Schlumberger and RIH w/ TDT tool & log f/5460' to 4870' RKB. POOH and RD Schlum. R/U Transtech and RIH and shear isolation disk. POOH & RD Transtech. Cum Cost: $ 764,773 Mud wt. 8.6 Viscosity NA Cum. Brine Cost: $26,545 EWS 4 (0-8-20) Drillinq Foreman: Fox 09-12-90: Continue RIH w/ 1 3/4" blind box & TFF @ 5705' RKB. POOH & RD Transtech. L/D 22 jts 2 7/8" tbg. P/U ESP equipment and service. RIH w/ ESP and 10 jts, 2 7/8" tbg., AVA 2 7/8" isolation sleeve, continue in hole w/ tbg. M/U tbg. hangar & splice cable. Land tbg. hangar. Pump 55 bbls diesel down csg. Cum Cost: $ 780,723 Brine wt. 8.6 Viscosity NA Cum. Brine Cost: $26,545 EWS 4 (0-8-21) Drilling Foreman: Stevens 09-13-90: Continue to equalize tbg. & csg. w/diesel. ND BOPE. NU wellhead and tree. Test tree and set BPV. RDRR. Drop from daily drilling report pending production tie in. Cum Cost: $ 792,560 Brine wt. 8.6 Viscosity NA Cum. Brine Cost: $26,545 EWS 4 (0-8-22) Drillinq Foreman: Stevens Mr. Steve Rossberg ~0~o0o, Ino. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 September 21, 1989 Re: Our Boss Gyroscopic Survey Jo~ No. AK-BO-PUiOO Well: G-3 ~ilne ~., Alaska Survey Date: 09/19/89 Operator: D. Harger ar. RossDerg: Please find enclosed two copies of our Boss Gyroscopio Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard Diptrict Manager Directional Services RECEIVED JUL 9 199 Gas Cons. ,,M~chorag~ 8537 Corbin Drive (99507) * P.O. Box 231649 · Anchorage, Naska 99529 (907) 267-0200 · Fax (907) 522.3432 A Baroid ,Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PA~E.000 PAGE i CONOCO INC. MILNE POINT ALASKA COMPUTATION DATE: 9/20/89 TRUE SUB-SEA COURS COURSE MEA~D VE1RTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DATE OF SURVEY: 9-19--8D BOSS GYROSCOPIC STJRFEY JOB NUMAR: AK-BO-90100 KELLY BUSHING ELEV. = 59,27 FT. OPERATOR: D. HARGER DLS TOTAL P, ECTANGULAK COOI~DINAT~$ V~RT. DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. ,' 0 .00 -59,27 0 0 N .00 E ,00 100 100,00 40.73 0 16 S 79.30.W .27 200 200,00 140.73 0 24 N 76.30 W .20 300 300,00 240.73 0 19 N 84,60 W ,11 .00 ,00 ,00 .04S .23W -,22 .00S ,81W -.70 .11N 1,44W -1.18 ,31N 1.95W -1.52 $00 499.99 440,7Z 600 599.92 540,65 7o0 699.6R 640.41 800 799.11 739.84 900 897,99 838.72 O 35 N 50.~0 E .75 2 52 N 67.30 E 2.32 7 13 N 70.90 E 2.43 9 43 N 67,10 ~ 2,55 .81N 1,00w -1,1~ 2,11N .91E 1.87 4.~5N 7.1~E 8.50 8.27N 16,97E 18.81 13.62N 30,70E 33.33 1000 996,04 936,77 12 53 N 64,40 E 3.22 1100 1092,60 1033.33 17 10 N 61.30 E 4.34 1200 1187.64 1128.37 19 i N 61,80 E 1.86 1300 1291,44 1222.17 ~1 27 N 61.80 E ~,44 1400 1373,16 1313.89 25 27 N 61.10 E 4.01 1500 1462.36 1403.09 28 16 N 61.40 E 2,81 1600 1550.24 1490,97 28 43 N 61.70 E .47 17oo 1637-~G 1577.99 30 17 N 62.10 E 1.b9 1800 1722.58 1663.31 32 32 N 61,60 E 2.27 1850 1763,74 1704.47 ~6 35 N 61.20 ~ 8.11 21.73N 48.54E 52.81 33.~4N 71,57~ 78.69 48.43N 98.88E 109.71 64.78N 129,36~ 144,26 83.82N 164.31E ' 184.03 105,55N 203,93E 229.18 128.27N 245.88E 276.85 lbl.47R 289,32E 32b. U4 176,07N 335.28~ 378,11 109,65N 3G0,19E 40~.46 1go0 ~803,17 1743.90 39 15 N 61,10 E 5.32 2000 1880,04 1820,77 40 15 N 61.10 E 1,00 2100 1956.01 1896.74 40 51 N 61,20 E .60 2200 2030.19 1970.92 43 20 N 60,60 E 2.52 2300 2101.04 2041.77 46 24 N 60.50 E 3.06 204.48N ~87.10E 437.17 235.39N 443o09E 501,08 266,76N 500.05E 566,07 299,37N 555.61E 633.06 334.06N 620.05~ 703,60 2400 2168,05 2108.78 49 25 N 60,10 ~ 3.02 2500 2232.42 2173,15 50 26 N 59.60 ~ 1.09 2600 2296.13 2236,86 50 25 N 60,20 E .46 2700 2360.08 2300.81 ~0 4 N 60.30 2800 2424,63 2365,36 49 31 N 60.60 ~ ,60 2900 2489.37 2430.10 49 46 N 60.10 E .46 3000 2554,46 2495.19 49 0 N 60.90 E ,99 3100 2620,97 2561.70 47 36 N 62.50 E 1.53 3200 2688.47 2629.20 47 28 N 63,90 E 1.04 3300 2753.88 2694.61 50 48 N 64.80 ~ 3,40 370.83N 409.27N 447.93N 4R~,ORN 523.74N 684.51E 777.79 750.67S 854.30 817.36E 931,38 RR4.1~ 1008.24 950.55E 1084.59 561,44N 1016.78E 1160,78 598,83N 1082,85E 1236.67 634.23N 1148.~8~ 1311.25 667,50N 1214,43E 1384.84 ~00.2~N 1282.G0~ 1460,14 JUL RO ~ 1~:~8 PN~,004 SPERRY-SUN DRIr.T.?NG SERVTCER ANCHO~GE ALASKA PAGE CONOCO INC. MILNE POINT COMPUTATION DATE DATE OF SURVEY: 9-19-89 BOSS GYROSCOPIC JO~ND~z KELLY BUSHING ELEV. ~ 59.27 FT. OPERATOR~ D. TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD V~i('rlcALVERTICAL INCLN DI~ION ~~GU~ ~0~INA~S VERT. DE~H D~ DE~H ~ ~ DEGAS ~/100 NOR~/SO~ ~T/WEST 3400 2817.26 2757.99 50 31 N 64.60 E .~2 733.27N 1352.54E 1537.13 ~5oo ~R91.~9 2022.32 49 23 N 65.00 E 1.46 76~.39N 14~2.02E 1~13.24 3600 2945.93 2886.66 50 30 N 65.70 E 1.12 796.83N 1491.81E 1689.27 3700 3007.57 2948.30 53 22 N 64.80 E 2.95 82~.80N 1~63.~0E 1767.55 3800 3066.45 3007.18 54 29 N 63.50 E 1.54 865.04N 1636.04E 1848.05 3900 3124.40 ~U~b.13 54 40 N 62.80 E .60 4000 3181.73 3122.46 55 20 N 62.70 E .68 41OO ~39.$2 3180.55 53 37 N $9.90 E 4200 3298.85 3239.58 54 I N 60.40 4300 3357.65 3298.39 ~ 57 N 60.60 E .1~ 901.85N 1708.75E 1929.35 939.37N 1781.58E 2011.11 978.43N 18~2.9~E 2092.43 1018.61N 1922.99E 2173.14 1058.44N 1993,39E 22~4.00 4400 3418.66 3359.39 50 51 N 56.80 E 4.31 4500 3481.69 3422.42 51 0 N 56.50 E .27 4600 3545.39 3486.12 49 51 N 57.00 E 1.20 4700 3612.01 35~2.74 46 ~4 N 55.30 E 3.52 4800 3682.58 3623.31 43 37 N 55.00 E 2.96 4900 3756.44 3697.17 41 7 N 54.60 E 2.52 5000 3833.44 3774.17 3s 9 N 53.70 E 3.02 5100 3913.85 3854.58 34 45 N 53.20 ~ 3.41 5200 3996.98 3937.71 32 45 N 54.10 E 2.07 530U 4U81.36 4022,09 32 13 N 48.30 E 3.16 !099.5aN 2061.09E 2333.20 1142.22N 2125,94E 2410.77 1184.48N 2190.40E 2487.78 1225.99N 2252.34E 2562.24 1266.46N 2310o47E 2632.90 1305.30N 2365.53E 2700.10 1342.64N 2417.24E ~.7G;3.65 1378.02N 2464,98E 2822.78 1410,95N 2E09 . ?2E 2878.08 1444.56N 2551.55E 2931,23 5400 416(;,lo 4106,83 31 57 N 42.90 J~ 2,88 1481,69N 25B9.47~. 2982.84 5500 4251,15 4191.88 31 30 N 42,90 ~ .46 1520.21N 26~5.27E 3033.34 5600 ~.3.~6.~;? 4~77.40 30 56 N 42.70 E .57 1~,8.24N 261~0.49E 3083.09 5700 4422.45 4363.18 30 54 N 42.70 E .03 1596.01N 2695.34E 3132.40 5800 4508.32 4449.05 30 45 N 41.70 ]; -54 1633.97N 2729.77E 3181.43 CALCULATION PROCEDURES ARE BASED ON THE USE OF THR~--DINENSION RADIUS OF CURVATURE METHOD. IIORZ~-ONTAL DZSP~d%C]U~ERT =, 3181.4~ k*ki~"l' AT NORTH 59 DEG. 5 XIN, FAST AT ~D -- 5800 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 59.10 DEG. '! JUL 29 ~9~ 1S~00 · FROM COl".tOCO n~..~C EI,.IG,.."EXPL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 DATE OF SUKVEY; 9-19-89 JOB NUMBER: .%,K-BO-90100 KELLY BUSHING ELEV, - 59.27 FT. OPERATOR, D, HARGER INTERPOLATED VALUES FOR EVeN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEA~D VERTICAL VERTICAL I%~CTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST ND-TVD VERTICAL DIFFERENCE COP3~ECTION 0 ,00 -59,27 1000 996,04 936.77 2000 1880.04 1820,77 3000 2554.46 2495.19 4000 ~1~1.73 3122.46 .00 .00 21.73 N 48.54 235.39 N 443.09 595,83 N 1082,85 939,37 N 1781,58 00 3,96 3,96 119.96 116.00 445.54 325,58 818 .z7 37Z. 73 5000 3833.44 3774,17 5800 4508.3~ 4449.05 1342,64 N 2417.24 1633.97 N 2729.77 1".66.56 340.29 1291.68 125.12 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF T~{REE-DIMENSiON RADIUS OF CURVATURE METHOD, ,! JUL ,°9 'gG 1S:G9 FROM COHOCO nHC PAGE.00~ SPeRRY-SUN DRILLING SERVICES ANCIi0RAGE ALASKA PAGE 4 CONOCO iNC. G-3 MI~ F-OINT ALASKA COF~PUTATION DAT~: DATE OF SURVEY: 9-19-89 JOB NUM~ER; AK-BO-90100 KELLY BUSHING ~L~V, m 59,27 FT, OPERATOR: D. liA~ER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA D~PTH TRUE SUB-SEA I~EASD VERTICAL ¥~RTXCAr. DEPTH DEPTH D]~ 0 ,00 -59,27 59 59,27 .00 159 159,27 100.00 259 259,27 200.00 359 359.27 300.00 459 459.27 400.00 559 559.27 500.00 659 659.27 600.00 759 759.27 700.00 860 859.27 800.00 TOTAL RECTANGUha/{ COORDINAI'~S ~U;-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE C0RRR~ION ,00 ,00 ,00 .Ol R .04 w .oo .oo .07 S ,53 W ,00 ,00 .09 N 1,21 W ,00 ,00 ,17 N 1,76 W ,01 ,00 .~ ~ 2,12 W ,O1 1,33 N ,96 W ,02 .02 3.38 N 3,98 E ,17 ,15 6,62 N 12,20 E ,57 .40 11,04 N 24,59 E 1,44 .~7 962 959,27 900,00 1065 1059,27 IUUU,UU 1169 1159,27 1100,00 1276 1259.27 1200.00 1384 1359,27 1300.O0 1496 1459,27 1400.00 1610 1559,27 1500.00 1725 1659,27 1600,00 1844 1759,27 1700,00 1972 18~9,~7 1800,00 18,32 N 41.30 E 3.10 1.66 29,01 N 62.94 E 5,99 2,89 43.81 lq 90, 26 ~- 10,72 4,73 60.66 N 121, 6~ E 15,91 6 · 18 80,68 N 158,62 E 25,40 104,76 N 202,49 E 37,24 11,84 130.62 N 250,23 E 51,02 13.79 157,49 N 300,69 E 66,22 15,20 188.09 N 357.35 E 85.21 18.99 22~.~ N 42'i.69 E 113,51 28,30 2104 1959.27 1900.00 2240 2059,27 2000,00 2386 2159.27 2100.00 2542 2259.27 2200.00 2698 2359,27 2300.00 2853 2459.27 2400.00 3007 2559.27 ~500.00 3156 2659.27 2600.00 330~ ~759.27 2700,00 3465 2859.27 2800.00 268.12 N $02.52 E 145.04 31.5:3 313.15 N 583,05 g 181,14 36,10 365.78 N 675.71 E 227.31 46.17 425.71 N 778.71 E 282.88 55.57 485,60 N 883.27 E 339.47 56,59 543,73 N 985.93 E 394,13 54,65 60[,52 N IU87,~8 = 44~,06 53,93 653.46 N 1185.83 E 497.51 49.46 703.03 N 1280.58 E 549.26 51,74 754.72 N 1398,28 E 606,44 57,18 3621 2959,27 2900,00 3787 3059,27 3000,00 3960 3159,27 3100,00 4132 3259.27 3200.00 4~02 33~9.27 3300.00 803.59 N 1506,72 E 661,85 55,40 860.56 N 1627.03 E ?28,37 66,53 924,46 N 1752,70 E 801,22 72,85 991,67 N 1875,82 E 873,52 72,30 105~,53 N 1995.30 E 943.47 .~,94 JUL 29 '9S 15~40 FROM COHOCO nl'.lC EI',IG,'"EXPL PnGE.007 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE CONOCO INC. DATE OF 8T, J'R'V"EY; 9-19-69 MZL~[ POZNT JOB NUF/~ERt AI~--BO-90L00 ALASKA KELLY BUSHING ELEV, ,- 59.2'7 FT. COM1WJTAT IO~ DATE: g/20/sg INT~.RPOLAT~D VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-$F.2% DEPTH D~FTt{ D~PTH 4464 3459.27 3400.00 A~A1 3559.27 35O0.00 4767 3659.27 3600.00 4903 3759.27 3700.00 5032 3859,27 3800.00 TOTAL ~'&~UL~%R COORDINATE~ MD-T~D VF./~TZC~AL NORTH/SOUTH EAST/WE~T DIFFERENCE CORRECTION 1126.94 N 2102.86 E 1005.11 61.64 1193.37 N 2204,00 E 1062.10 56.99 1253.50 ~ 2291.92 E 1108.24 46,14 1306.72 ~ 2367,52 E 1144,47 36,23 1354.42 N 2433,24 E 1173,32 25,84 5155 39D~.27 3900.00 5273 4059.27 4000.00 5391 4159.27 4100.00 5509 4259.27 4200.00 ~626 4359.27 4300,00 1396.65 N ~490,00 E 1199,83 22,52 1435.43 N 2540.99 E 1214,60 18.77 147~,$9 N 2~6.54 E 1232.68 1~.08 1523.86 N 2628,66 E 12~0,25 17.57 1568.20 N 2669,68 E 1267,08 16.83 5742 4459,27 4400.00 5800 4508.32 4449.05 1612.22 N 2710.28 E 1283.64 16.56 1633.97 N 2729.77 ~ 129&.6~ 8.04 TH~ CALCULATION PROCEDURES USE A LINF, AR INT~RPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS JUL .°9 '9~3 15-'40 FROM COHOCO r')HC EI,.IG,.."EXPL 1'"' ~SPERRY~SUN-DRLG. '~/CS. 0--~ MILNE POINT ALAi)KA 9-19-69 HORIZONTAL PROJECTION START TVD .,, 0 FI'N:I;SH TVD ,,. +,508.3:8 SCALE :IS :500 FEET/TN I ! I i I Ii SO00 lggO lOOO 16oo DEPARTURE aooo omo 8ooo JUt_ '9~1 IS: 41 FRO,,~COHOCO ~I'IC I:'I'IG,/I:'XPL ~'$PERR'~-~$UN DRL G. VC$. PA~E.009 i! 0-.,3 HTLNE PO.]:NT ALASKA 9~19-69 O- 1000 2000 ! Togo ltl VERTICAL PROJECTION START TVD- F:ZNZSH TYD '- 4,506. SCALE ,TS 1000 FEET/ZN , ,i VERTICAL SECTION D~RgCTiD~ - O. O0 AOGCC GEOLOGICAL MATERIALS iNYENTORY LiST COMPLETION DATE ~ t /3 I ~° CO. CONTACT ~e~ e c check off °r"i'i'~ data as it is receiYed.*list received date for 40?. if ~iO? ! * ~//z//?/, drillin.Q history.' ~l , su~eY!/' ! well iests cq[ed iniewa!s core analysis ~ d~ ditch intcwals ,, not re~juired list as NR ~"~! core descr,!ptio~ ~ d!,~,,ital data i LOG -~r,=, ,~--- i RUN INTERYALS SCALE NO. . (to t. hc nearest foot). (inchtlO0'] ~. ~;~o ... ~ , ,~r9 , i i i i iiiii 7) ' 10~ 1 "i~] ..... 17] ~11 iii i i ii i i i TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C(I%I,%~ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following material which was transmitted via "~ is hereby acknowledged. QUANTITy ' pssc~ ~ pr ~ REC'EIVED OCT ~ ~ ]ggO Alaska.Oil & G~s Cons. Cammlssion RECE I VED: ~ DATED: z'~--- ..~!_~ .--- ~-~ __ Copy sent YES to sender NO SCHLUMBERGER WELL SERVICES A DIVISION OF ~CHLUMBIrRGER TECHNOLOGY CORPORATION HOUSTON, TEXAS 97251-2175 SEPt 2 lggO CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Marc Shannon ~ RElY TO BCHLUMBERGER WELL ~ICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore.2_BL_printsofthe Company CONOCO, Inc. Well Milne Point Unit G-3 Field MJ ln~ Poin~ Additional prints ore being sent to: 1 BL prints CONOCO, Inc.. 600 North Dairy. Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER Gravel Pack Log/TDT-P, Run 1. 9/11/90 . On' County Nnrt~ Slope State Alaska _/_ILL_prints, 1RF Sepia .1000 South Pine Ponca CitY, OK 74603 Attn: Log Library I BL prints, 1 I~F Sepia OXY U.S.A., Inc. ..Midland, TX '79710 ...At tn: John Carrol *(915/685-5600) _l_JlL_prints, I RF Sepia _Chevron U.S.A. 6001Boll~nger Canyon Road San Ramon, CA 94583-0943 ...Attn: ?rJscJlla MacLeroy *(415/842-1000) ~/'3~001 Porcupine Drive :~:~?.'. AnC hot a'ge, AK' .. 99501 L?ttn: ] John Boy~i.~ m~, .... The film is returned to Conoco.. Log Library. We appreciate the privilege of serving you. ~.orints prints prints Date: SFP 1 7 1QOn Alaska 0il & Gas Cons. Commission Very truly yours, ,qncJl0rag8 SCHLUMBERGER WELL SERVICES David M, Saalwaechter D~TR ~CT MANAGER SWS-- t 3274r STATE OF ALASKA L r~ ALASKA OIL AN D GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend __ Alter casing __ Repair well Change approved program __ 2. Name of Operator CONOCO INC. Operation shutdown t Re-enter suspended well m Plugging __ Time extension m Stimulate ~X Pull tubing __ Variance __ Pedorate -X-- Other 3. Address BOX 340045 PRUDHOE BAY~ ALAKSA 99734 4. Location of well at surface 3525' FNL, 3362' FEL, SECTION 27, T13N, RIOE, UM At top of productive interval 2875' FNL, 2181' FEL, SECTION 27, T13N, RIOE, UM At effective depth 1886' FNL, 628' FEL, SECTION 27, TI3N, RIOE, UN At total depth 1850' FNL, 594' FEL, SECTION 27, T13N, RIOE, UN 12, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 59:10' :feet 4603' feet '5813' feet 4 519' feet Size 13-3/8"48#/FT 9-5/8"47#/Ft Length _+80' 2899' 5862' 7" 29#/FT 87 24 52 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth)N/A · 13. Attachments Description summary of proposal 5. Type of Well: Development X Exploratory ~ Stratigraphic __ Service ~ .. Plugs (measured) N/A Junk (measured) N/A 14. Estimated date for commencing operation 115. Status of well classification as: AUGUST 24t 1990 16. If proposal was verbally approved LONNIE SMITH _08/24/90 Name of approver Date approved J Service 17. I herebycertify th ~t th'~-rO~going is true and correct to the best of my knowledge. Signed (17_,~ ~ /~"~~~ Title SENIOR PRODUCTION FOREMAN FOR COMMISSION USE ONLY Approved COpy ~ Aet~(~) Form 10-403 Rev 06/15/88 Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Cemented Measured depth True vertical depth 7. Unit or Property name NILNE P0]NT UNIT 8. Well number G-3 9. Permit number 89-46 10. APl number 50- 029-21942 11. Field/Pool KUPARUK RIVER FIELD Approved by order of the Commission Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~'c;'~ ARC SET TO SURF 110' 110' 181BBLS PERM E 2931' 2450' 138 BBLS CLASS G BBLS CLASS G 5891' .4587' BBLS ARCTIC SET I BBLS DEAD CRUDE RECEIVED AU G 2 9 1990 0Il & Gas n0h0rag, Detailed operations program X__ BOP sketch Oil X Gas ~ Suspended SUBMIT IN TRIPLICATE 6. Datum elevation(DF or KB) RKB = 59,3' MSL feet P~GE, 003 COMPLETION PROCEDUR~ MILNE POINT WEbL August ~0, 1990 Well, Znfornt _t.:l. on .. Perforattonm; Burst Bur~t p~e~ure = 10570 DSl (no Sa]:t~y Zao~or) Capacity - 0,0057~ bbl/f~ ~nular Capaoity (Tbg x Csg) - 0.0302 bbl/~t 5334 - 5356 (N Sand) 5372 - 5382 (N Sand.) 5404 - 5408 (N Sand) 5433 - ~438 (N Sand) · · ss22 ' ~5'3~ (oa sand) RECEIVED G 2 9 1990 Gas Cons. uommiSStotl ~chor~e j~ HUla-~--"-' ~tl 11: ~O I U: HI',ICHUb,'RL~I- OFF I CE -3 01~G zt 'so 1~=33 /~-~M conoco P £ R TEL NO:SG4?G05 ~S439 P22 ? Wellbo~e OleanA~ stage 1. G~H with bit/scrape~ on wo~ks~rin~ and two additional soraper~ ~paced out to position one scraper on bo~om~ one s~raper 1~50 ~ o~f bo~tom~ and one scraper 3700 f~ 0~£ bottom. ~his will allow a sho~t trip (a~roxima~ely 1850 ~o completely scrape and clean ~he casing wall. Scrapers mus~ be checked to insure blade OD is correc~ ~o~ the 7" 26# c~sing. ' Hold on-~ite safeuy meeting to co~unicate hazards of completion fluids and chemical washe~ to appropriate rig personnel... 2. Once at TD circulate the following at 6 BPM (minimu~)~ · a. Bottoms up with brine. b. 20 bbl chemical, wash (composition to be ~eoided, C. 40 bbl b~i~e scavenger (~o'b% d~sposed of afterward). d. 20 bbl ch~m~oal wash (see e. Bottoms up wtth brine. Only clean, filtere~ brine should be'pumped into the well at any time during the completion operation. DE uniC (MI Drilling Fluids) shoulQbe hooked ~ on r~g, completely tested and operational before starting the procedure. s~parate tank for d~sposal. None o~ these stages should return to the active pit system. Un~il on site measurements ~ndioa~e a n~ed for a change in a~d 50 NTU as aooeptable from the well. This £igure will be calibrated to actual solids content by taking fluid samples to the lab at the central facility =nd performing tests. This mea~uromont of solids content and turbidity will reg~la~% the acceptance range of turbidity readings (~ZU) On location. ¢ont~nu~ circulat~ng at ~ ~PM wh~le sbor~ =ripping out Of the ~ole. Rotate while POOH· POOH un~il the ~ppe= scraper ~S at GIH tO TD and circulate bottoms up. Perform repeat step 2.a. through step Page 2 _AUG 2 9 1990 Alaska 0il & Gas Go~s. Ancl~orag~ m "'" 'R '"'"" ' qO 11: 42 ......... ~u~---'-.'-- - ! D: RNCHORt--]GE OFF I CE ., ¢-.t~.16 ~1 ',.90 1 ~: 34 ~/'"~OM CONOCO .11 · TEL NO: 5~605 1:t439 P04 PAGE. 885 brine in t~e wellborm. Filter maximum volume of brine in the pit system before continuing the ope~ation. RECEI /I!H) AU 6 ~ 9 1990 ..Alaska Oil & Gas Cons. Anchorao8 z~a;~e 3 AUG-~=- 90 11: 4~ - A~G ~! '90 , NCHORRGE OFF ! CE CONOCO P E TEL NO: 5~'~5 / ~439 P05 REEEIVEI leerforatioa ~t&ge - Fracture T~e&~ment AU G 9 1990 AMs .OII .& Gas Cons. 6ommi¢lon choragel 3~ m · 0 . :LO. Rig up perforating equipment and prepare to perforate "0" Sand at 5522 to 5S35 ft MD. Measure XD, OD, and length of all tools to be run in the hole. Tnsure that all special~2 tools have been rabbited or visually lnspec=ed to be free of obstructions. Mca;ute and record the distance from the to~ shut o£ the gun assembly to the radioactive marker. . Hold on-site safety meeting with rig personnel and perforating crew to communicate hazards of the perforatim~ operation. I~TR wt~h thc 4" 4 SPF aa~emblV as shown l.n attachment #1. Rabbit the workstring as RXH. The ~i tOO1 ia ~un In the ~irculating position .(ball valve close, ciroula2i~g valve o~en) to automa~i~lly fill the workst=ing while ~rt;pping in. Wi~ the ~i valve ].~'~Jhe cir~la~ ;Q~~n, di;pla~e thm t~ng wi~ diesel to obtain ~e re, re4 ~n4erbalance. ~cle the ~i valve to the bl~ ~osit~on. R~g up and ~ ~e ~/CCL to log the ~A marker. Correlate wi~ ~e ~sod hole GR log. Place ~s on dep~ by s~aQe out at surface, Set the packer w£~h ;0,000 lbm. lnstall surface equipment and pressure test ail lines. Line up through the choke manifold to the appropria~e tank on location to flow the well after perforating. cycle Omni valve to well test position (ball valve open, circulating valve closed in preparation to fire guns. Ri~ up shot detection equipment to confirm fire. Drop detonating bar to fire guns. After fire, flow less than one tubing volume, shut in before formation fluids reach surface. Cycle the Omni valve to the circulating position (ball valve clo~ed, circulating valve open) and reverse OU~ all for~ation Zluids to the disposal tank. Minimize contamination of the comple~i~n fluids in tho active pit system. Release the packer. Insure =he well is under uu~,trol and POOH. Fill the hole with diesel only. Rig down perforating equipment. Page 4 AUG-~2-' 90 11: 4~ I D: ANCHORAGE OFF ! CE A~uG 21 '90 I~':3~ i" ~ CONOCO ;~ E R ~439 POG PAGE. 00? Fr&ctur6 ~re&tme~% AUG ~ 9 ]990 Alas~.Oii & Gas Cons. Commission Anchorage Spot two 500 bbl £='ao tanks on location approximately 100 Et from the wellhead. ~levate the rear of ~he tanks approximately $". Visually inspect the interior of the tanks for cleanliness. DO NOT ~NTER TH~ TANKS. Fill each tank with 350 bbls o~an injection water filtered to 10 microns absolute. The water should be heated and maintained at 75 to 80 degrees F ~o insure p~oper hydration of the gelling agent. one joint above the packer. RIH wi~h the packer on tubing and set it at 5322 ft ND. RIB with slickline and set a plug in the nipple. Pressure teat the tubing to 6000 psi. Retrieve the plug from th~ well. 4~ Rig up Dowell Schlumberger to perform the frao treatment. Use of threaded connections, crossovers, swedges, e~c. in the treatinq line is not acceptable. Use two in-line densitometers. Use ~wo shut-off valves on the wellhead. Set backup pumps for o~ossiinXer and diesel. .. Batch mix 700 bbl gelling agen~ at 40 lb/1000 gal and addittve~ as prescribed in the material de,ail. The pre-pad consist of non-orosslinked gel. Pa.~ciculate fluid loss additive should be added in the pre-pad and pad fluids on1¥. Diesel aild crossltnker activator are %he only additives tha~ ~houid be ~ixed on the fly. Sand (¢arbo-Lite) will be added in the prescribed stages through the blender. . Yill out the fluid reportforms and ~heok all eddltlve~ agalnct tho ,ttschod materi~l detail, continuously roll tanks until the viscosity is within the recommenae~ limits (30 tO 35 cps at 300 RPM on Farm 3~ vis~ometer). Check sampl~ from the top and bottom of the frac tanks. Values ~ to communicate hazards of ~he opera, ion, 8~ Pressure test surface lines and frac head ~o 7000 psi and insure there ars Ilo leaks. Set the automatio pressure sh~t- dowll on each pump at 6200 psi. standby pumps (50%) are required. TheSe pumps must be manned and primed to come on line immediately if needed. A standby blender 6hould be hoo~d up and ready to come on line in case of primary ble~der failure. Pa~e $ ... R.~G ~1 '90 I~;$5 F...,M ¢0N0¢0 P E R TEL NO:5E/--~5 ~39 PO? PAGE.008 Tank bottoms arm included in the volume listed in step #5. Plan for 50 bbl tank bottom~. Use the in-line densitometer during the treataent. Record ra~e, pressure, and density on & chart. 10. Place the~o sample~ in a bath a: 80 F, Note ~he actual break time. · Note the pre-pad ~s crosslinked and ~oes not c~nta~n d~e~el. DO NOTOV~RDISPLAC~ THE TRF~TMENT UNDER. ANY CIRCUMSTANCES. Pump the fr~c ~ob as follows: Stage Fluid ~rop ~t~p 8tags Cum P-Pad WF140 0 35 '4000 4000 .Pad YF140D '0 2~ 11500 15500 Slurry Y~140D ;- 25 ~lurry YF140D 4 2S ., 1500 17000 2?00 19700 Slurry YF140D 8 25 2000 21700 11, Flush WF140 0 25 1730 23400 Shut down. Allow the pressure to bleed off into the formation. Record the IsIP, ~, 10~ and 15 minute pressures. Close all surface valve~ and leave the well shut in. ~onttor the break time o~ the last pumping e~pment. 12. After adequa2e break release packer and allow fluid level to ~tabilize. Fill hole onl~ with diesel. 13. After the frac treatment there is a possibility of proppant in the wellbore. RIH with a sinker bar to immure the perforation~ are clear. Tag bottom to identify the amouDt of proppant in the casing. covering the perzoratio~ tn =ne event of a san~out. bar tags proppant in the perforation tnte~al then p~foFatton i~te~al. iD Page 6 AUG 2 9 1990 011 & sas cons, t;om 'msio Anchorage · .,~ .l::l,,I,,tO 81 '~10 IP-;~; I:'~ CONOCO P E R -~'~, PAGl:',009 · DUring the trip out fill the hole with diesel only minimize fluid lost to the formation. i RECEIVED AU G 2 9 1990 ~ J)ii & Gas Cons. uomm'~s$~on ,, ~horagei AUG-22-' 90 11: 54 ! D: RNCHORRGE OFF ! CE ~ .R,U~i ~1 '90 1~.'37 F/~ CONOCO P £ R TEL NO:56a/~5~ Perforation Stage -Oravel Pack ?=eatment 2~ % 5, . 1 · 0 RIH with Baker Nodal "D" size 84-32 st~mp packer on wire line and set at 5462 ft MD. Run packer wi~h extension and Otis X nipple. Have e~ipment available to =et on work string as backup. OIH with blanking plug and set in sump packer a~ 5462 £t HD. Circulate 200 lbs sand (3 St3 - 9 ft fill) to bottom and allow it to settle out on top of the'plug. This will make it easier to retrieV~ after perforation operations. Rig up perfora~ing equipment and prepare to perforate ,,~, Sand as follows: 5334 - 5356 ~i372 - 5382 5404 - 5408 5433 - 5438 REi EIVED 2 9 1990 Alaska Oil & Gas Cons. Co. mmissi_Qa ~choragOI Hold on-site ~afety meeting with rig'personnel and perforating crew to communicate hazards o£ the perforating operation. Measure ID, OD, and length of all tools to be run in the hole. Insure tha~ all special2y tools have been rabbited or visuall~ in~ected to be free of obstructions. Measure and record ~he distance from the top shot of the gun assembly to the radioactive marker. RIH with the 4 5/8" 12 SPF TCP as~embly'as shown in attachment #2. Rabbit the workstring a, RIH. The Omni to~l is ~A~ An ~l ai~oulating pooition (ball valve closed, circulating valve open) to au~oma=ica~ly ~ill the workstrin9 while tripping in. Spot guns on depth bypipe tally measurements. Circulate 1.5 hole volumes with brine to insure correct hydrostatic in the well. Circulate diesel to obtain 100 psi underbalance. With the omni valve in the circulate position, displace tubing with diesel to obtain the required underbalance. Cyole the Omni valve to the blank position (b~th valve~ closed). Rig up and run the GR/COL to log the R/A marker. Correlate with the cased hole OR log. Place guns on depth by space ou~ at s~rface. D6~ aha packer ~ith 30,o00 lb¢. 8 AUG-=~- 90 11: ~5 I D: ANCHORAGE OFF ! CE ~. t:~JJ6 ~1 '$0 1£;137 F,/-~ CONOCO t~ E R TEL N0:56~5 ! ~439 P09 10. Install ~urfaoe equipment and pressure test all lines. Line up through ~he-~heko manifold to the~appropriate tank on m~/64. 11. C~ole Omni valve to well test position (bali valve open, circulating valve closed in preparation to fare guns. 12, Test with annular pressure to $00 psi. Recheck underbalance calculations and fluid fill. Rig up shot detection equipment to confirm fire. Drop detonating bar to fire guns. 13. After fire, flow less than one tubing volume. Shut in before formation fluids reach surface, cycle the O~/~i Valve tO the circulating position (ball valve closed, circulating valve open) and reverse out ell formation fluids to the disposal tank. Minimize cootam~ation of the completion fluids in the active pit system. 14. Release the packer. Insure the well is under control and POOH. Pill ~he hole wit~ diesel only. 15. Repeat from step ~4 to shoot =he second set of perforations. Perforate u~der balanced with a drop bar/isolatio~ disc mechanism r~n with the Omni Valve above ~he tool to allow for und=rbalanoe t~ · previously perforat~ well ~ circulation a~te~ar~. Set packer. Test wi~h annular pressure to 500 psi. Recheck underbalanoe calculations and fluid fill.. Rig up high pressure lines at surface through choke ~anifold for fluid flow after perforating. Bet choke at 12/64. Line up to ChOke and prepare to fire guns. Drop bar to fire guns. After fire, flow less than one t~bing volume. Shut in before formation fluids reach surface. cycle ~he omni valve to the circulating po~ttion (ball valve closed, circulating valve open) and reverse out all forma~ion fluids to the disposal tan~. ~nxmxze contamination or ~ne completion fluids in the active pit system. 17. ~el~a~ eha pa~)~e~. Z~su~o tho ~;oll lo undor oontrol ~nd POOH. FAll the h~le with diesel only. AUG ?- 9 1990 ,Oil & Gas Cons. ,A chomge ' Page 9 w_~-=~- :~J 11:45 ID:ANCHORAGE OFFICE · A~J6 ~1 'gO 1~:38 pr ~ CONOCO P E TEL NO:56r4~5 ~439 PlO RECEIV'ED GF~vel Pa~,k S~&go l& 2 9 1990 ~las~.Oll & Gas Cons. Commission GIH with b£~/ecraper as~ombl~ (~or 7" 26~ o~tng). W~HOU~ CZ~CU~TX~G, ro~a~e bi~/scraper ~om 5300 to sump pacAer a~ 5462 ft. ~f ~tll im the hole preven~ reachin9 5462 ~hen ~OH and ~e~ove ~t11 wi~ hailac. Re-run scraper if it did not reach 5462 ft OB the first a~temp~. POOH slowly (prevent swab 'e. ffect). Do no~ diesel only aB ~. . ¢IH and retrieve the blanking plug from the sump packer. Ca~e mus~ be taken since both zones will be in communication during this s~age of the aompletion, circulation to retrieve the plug must be minimal. FAll ~he hole with diesel ertl2 as POOH. RIH with plug for X nipple. GIH with the gravel pack assembly as folloWBl . . 'a. Baker ~o~el "8-22" Snap Latch Seal Assembly, size 80-32, wi~h 2 additional seal unit~. 11 ft of 2 7/9" baker-weld wire wrappod 1~- gauge gtainles= steel lower ~ell tale sateen. , c. "O" ring seal sub, 1 ft length. d. 119 ft of 2 ?/$" Baker-weld wire wrapped 12 gauge s~ainless steel screen, weld on centralizers every 15 ft. e. 342 ft of f. Run a 6 f~ polished stinger and l.g" tubing (length as reguired) in~ide screen as washpipe. g. 19 ft length Baker Model "$" Gravel Pack .Extension with a G.P. sliding sleeve, and upper extension size h. Baker Model "SC-l" gravel pack packer, si~e 7002-40. i. Baker Model "sc" crossover tool with "SC" ,erring tool, size 80-40. Note, Items (g) through (i) ara picked up am.one unit. Use screen table over rotary when running screen. screen An the screen table oB collar shoulder. No slips or clamps allowed on the screen. Hang of~ blank pipe in rotary table with 2 7/8" slips. Page 10 AUG-=~- 90 11: 4A I D: ANCHORAGE OFF I CE , t~tdG ,'-'! '90 1~:38 F(~ CONOCO P E R · TEL NO: 564~ · [¢EIVEO ~439 Pll PAGE ,013 AU G 2 9 1990 Alas~ .Oil & Gas Cons, Co. mat~t~ NO. EXCESS PIPE ~P~ ON ~Y CO~E~IO~0.~E PIN ~NDS ONLY. Leave Re pup Joint off ~he packer assembly to make it easier to lift to the rig floor. ~ . 7. · Run the gravel pack assembly into the well SlOWly, space the obtain a safe workin~ height at ~he To~a~ t~le. Do ~Ot e~ace out any Co~ect~ons a~ or near ~he wellhea~ asse~ly. When on bottom, snap ~nto and out of s~p 'packer to ver~ pos~t~on. Record pick-up and slack off weights. Set ~000 lb~ weight do~ to snaD th~ ~n~p l~nh S~p packer to verify slip ancho~agm. Rig ~p treating lines on rig floor. High pressure lines on all bu~ ~e ret~n l~ne. The line fro~ ~e man~fold to the pit can be a high pressure hose (5000 psi to be oo~ected to the hose. Rig up I~lt~e man~fold a~propriatel~. A flow meter must be ins~alled in the ~turn line from the a~ulus to the ~anifold (to ~e~sure ~luid flow A ball catcher should be used on ~e rig floor to prevent compl~cations ~rom ~e setting ball retu~nq to surface any t~me u~ing ~e operation. Make the h~k-up as simple as possible on the rig floor. Hold a pre-job safety meeting for all peMso~el o~ location that could be e~osed ~o hazards of ~e tritest. The ~wo main points of conoe~ to be stressed are material hazards and pumping presm.tra~. Discuss g~eral salety precautions and first aid procedures (l~ation of eye wash, personnel, etc. } · Test line~ to 500'0 psi. Includes all treating l~es, gauges, manifold, etc. of filtered clean brine at 2 BPM. This .is to insure that the Drop the I 7/16" Kirksite setting ball and allow 30 minuees for the ball to gravitate down. increase to 2500 p~i (by 500 increments, proper t~ming). Test Page AUG-22-' 9~ 11: 4? I D: ANCHORAGE OFF I CE · .6.~6 Z! 'gO 1~:38 ~ CONOCO P £ R 1990 ¢~439 P12 Dil, & 6as Cons. c°mmis [on Anchorao l by pulling 15000 lbs Over ~trinq weight and pressure testing annulus to ?o0 psi. This in turn will actuate the hydraulic release feature in the setting tool. 10. Releas~ from the SC-1 packer by picking straight up and then Position the crossover tool in reverse position and circulate the fOllowinq: a. 10 bbl gel fluid (brine with 60 lb HEC/1000 gal). b. 500 gal 15% Hcl with inhibitor, itoh sequestering agent,. surfactmnt. - C. Brine. ' At~ ~c$d appro×ima~el¥ 1 bbl from crossover~ shut down and rever~e circulate acid back to surface. Pump acid down and back out at 4 to $ BPM. Have tank at surface ready to accept acid flowback before pumping acid into well. Have ~aterial in ~ank to neutralize acid. It is acceptable to mix soda ash in ~he pump truck (mix tank) and pump it throu, gh the 1.ins to the disposal tank to neutralize the pickle acid. 11. Release from the SC-1 packer by ptcki)~q straight up, a~ ~hen position and mark crossover tool in ~he squeeze, lower circulating, upper circulating and reverse positions. Establish ra~e and pressure a~ each position. Take measurements a~ 0.5, 1, 2, snd ~ BPM. Pump only enough fluid to establish a stable pressure at each ~ate. · Establish in~ection with minimal volume of brine. Do not exceed fracture gradien~ of 0.7 psi/ft. 12. Wellbore ready for gravel pack. Circulate to packer, shift to squeeze and inject prepack slurry as follows: a. 9 bbl slUrry at 2 ppg 20-40 mesh gravel (2% Kcl with 30 lb/ ooo '. Mix 12 bbl slurry' (il bbl 2% Kcl with 921 lb 20-40 mesh gravel). carrier fluid to contain appropriate breaker concentration, added JUSt prior tO pumping. Carrier fluid preparation includes shear/filter to l0 micron absolute. Perform {~C test on gravel and carrier fluid. Gravel test ~onsi~t of ~pot check of sieve analysis. Test on carrier fluid include~ break test at BHST and filterability. Injection Page 12 AU .... 90 11: 4? ! D: ANCHORAGE OFF'! CE ~. L.]--.-',~- . ,, ,P~UG Z! '9¢ 1Z:40 ~ CONOCO P E ~ TEL NO: 56~j~5 I ¢EIVED ~t439 PAGE .015 A US 2 9 1990 rate to be dete~i~Id based o~ inJ~ction t~~~ lhould bl at least 2 BPM. Over displace the slurry from the annulus. w4 th ~l.r~y t n ~he annulus, Do not ~hut down 13, 14, If no pre~sure re~pon~e ie observed during the prepack op~a~io~ then a ~oond volume of p~opa~k gravel ~ay b~ p~ped. ~e decision will be made on location during ~e opera,ion. · ~ tO =everse c~roulate position and reverse (m~nimum of 1.5 t~ vol~.s) wh~le prep~ng ~ravel paok fluid. ~e t~l to the =t~erse pos~t~on ~d circula~e the ~ravel pack do~ as follows~ a. 20 bbl pre-pad b. 25 bbl slu~f, 8 ppg gravel c. 10 bbld~s~t-pad .d. brine placement.'' · . Base fluid is 2% ~01 at 60 # HEC/iO00,~ gal, sheared and filtered through 10 micron absolute filter. .. For the pad fluids mix a total of 35 bbl and pump total of 30 bbl. For the slurry mix a total of 28 bbl slur~ and pump only 25 bbi. Exces~ must be dumped ~f~ ~* ~=e~t~en2. Slurry consist of 2O.S bbl fluid with 688S lb 20-40 mesh ~ravel. Fluid, bo~h slurry and pad, to contain.appropriate breaker concentration,, added ~ust pride' tu ~umping, after' e~tabl~shing c~rculation through lower tell tale. 15. Pump down at 6 B~M. When pre-pad is 3 bbl above the cro~over slow r~te and shift tool to lower circulation position (~ell tale screen). Monitor return ra~e at all time~. Data recorder to include turbine flow mete~ in the treating line between the squeeze manifold and annulus, ~et up to m~as~e retur~ rate. Screen out tell tale to 1000 psi if possible (actual may be only 500 psi). A~ screen-out occurs shaft tool to upper circulation position. If returns drop off but pressure does not increase, shift ~ool. ~ '/%t~G 21 '$0 l~:dO '~m CONOCO . PaGE screen out the main screen with a 1000 psi increase. Attempt to maintain a 4 BPM rate through the placement process. If no screen out is seen overdisplace the slurry and repeat from ~tPD 27 with 10 hhl of Dad, 1~1 hhl ~luY~, and ~ bbl ~nst. pad. £hift to tho rovoroo pocition and ravarza out until ~11 exce~s ~lurry has returned. ~{masure sand volume. C~ntinue ~everme oi~culating while waiting on b~eak ~e (assum, 4 hours ~less testing indicates o~e~ise). After appropriate break time place tool in mai~ screen circulation position and pressure up. If rate/pressure Indicates exposed screen then pump another batch of gravsl screen ~s stall Oove~ed then prmpare ~o ~H. 18. Before I~OH circulate sufficient volume of diesel to balance well after pulling running tool out of packer and "U ~ube" subsides. Be prepared to handle diesel at surface during "U tube". 19. 20, 21. 22. 23. 24. 25. POOH with running tool. Fill hole with diesel only, · th l:~rf~rat~on pregsur~ drop ~o~oss the gra%'el p~c~complet~on. , The rate should"be~mainta~ned at ~ lowest rate, pos~ble 9n the Esp./until~productton/is all o~. Each ~ime/'~, hoke bumped/up thw rat'b and Proocuro~ouould(bO ~loWod ~ ~ stabilize (f6r ~" hour minimu) ~efore increasi, n~ the choke size again./ ~s also holds true for inCreasin9 %he p~p Page 14 AUG 2 9 1990 011 & Gas Cons. GommiSSiOn Anchora s AUG-22-' 90 11: 49 fi~D~ANCHORAGE OFFICE TEL NO: 5~"~05 ~439 P15 ~UG ~1 go 1~:41 '/ OM CONOCO ~ E R :. ....',, ~ ..(~ ~ "': ......, , , .. .~ .. , .:',', ,/,, */I,~"~; . . ,'i..' ..,:..:; . :.,:~,:,~ ~ .c ,. ~..'. ,.,, .,., ..... ': " '.:.~'...}:.,': ::':,... 5..;., ' : ~. ' ,',(' '~'.,~, ;'~:" rj :;' · .. ' .r.:,.'.'. .... ,, ,: · el q ,.'' .. . , ., .: . , · , . de ~* , '*, 'I. '* · · ~ ~ M ~~~ : AU~ ~ 1~: ...~::~:.,~,/,[.,~...~ .,~?:.,.,. . '~~ , ' ~st,, ,,'~ ~ ':,,,,,... ~ · · ' ~ t . . .. ,,', AI~A DII & G~s Cons..~m~~,~ ~ .,,. ~ ,:.~ :.... ,.. ', '~ ~. ' ~ '~ ~n~n~n~ _~'. ;5 e... ~'":,, , '~.'," ............ ., .-"~ . .. ~, ,, ',~ .,, "*l~ ~ ~ Iv~~['., ': '~. ' '. :-':~.",~*":':.;.'.'~,','dJ" · .' ~ 11I II ~ I i I .; ,,~ , , ,. .el , -" 'l ...... ','.-.;',,,Y'~.". · .,' ' ', · ..- '~ ' " - , ~ ,'2~S',,.',~':~' .J' ' ' , ? }" ~ e t ~ q' '-', ' ~'r, , t tI'" e' , ' t'.,, e . .. ... , ,. , ~ ~,. , .. · : ~ .... .. .", . .',, e~ ~.,. ~; t , ..' ' -o - --~ ~ ....... ' ' ' ',' ," , ~.~/,~' ,~.~':,,' ~ '~'~'.;, - · - ~ 4~ .~ ~Z ~- ~ ~, i~o ',~,~:~q '.:.'.:: '.~ '" · . ' ~" ~ ' · ~ ' "~ ' I ' "' -'- ' 'v'~ ' · r · .~, · i,, I,., · i i'' ~, , ' , '' ' '~' ":' "~, ' ,'Z ) . , "iI~:.~:~:~',Y~." · .'t.; ~ ', , · ~ ...-~ . -;.. · ,,~ . · t.t ~ ,'.,j ~w },, ,/ , ,.,~ ,.' · ' ' ' ~ ::"~' ~ .... d ~. %~':, ~ '4,, ,",, ~ ,'~, , " · ' ...... ~,. '~ fi~, .' '~ ': .' ' , ',', '.=. ~.~r.,~A:~,~),,'~:[ .." . , .... , ,~ ~ ,~,' ~ ... . . .'., 7~.~ '~ 4 ~.~ ~ , ~ ,,: . " . : ~'.-..' '.",. : '.% "- . %.. ~'~,'; ,%.~:;~",V ..... '.:. ~ ,r . ' ,.,,',':~ ~' ~' .. ,'., ; .' '. '':." ~.~"'~?;;,'~,, '.' ~. ',' . '~;,~ .:..;'./.~ , .:.......~' , "...'.~.:,~.,~A,~'.~:~<.;,y, .:'.' ,~, ,.. , .: -,.~. ,.., ~.. , . · ,~,... ,4:%~'. ~..y,~, ~-~: ,, ~ . ~.. ·, ~., .., i , ..... %,.t. · ..... ~, ~ · .~ .... 4.,e . , · . · v,-~ ,, ~., ....... ; ,-* _:,,~;~, . · , ~*"~: -. .', ~, ~ ,.,. · I i . '~ ' ~'.'. , ~l~,~' ~-~ i * ' · i', . ·... , o · _ ' ~ ~ ...... ~v',,/,.~. ~<- . ~?~ =~,,, ,'~f.~ .... ' ~.',' ~,; "'- ~'. , e '.'.. '.. ..',:.., ,. ~ ,.. ,~ · t,. ..... a "':'''""" ' '* ' ' ~ "l" '; ' ' ,t~ .~.. , ."' f "' I . ,.., s.. , .' ,,,0 ~ ': ' ' ...... " ?,,,,''%.,) :."..~ · ,.... · .,.f~..;;,~.,;....:::.~,.....~ , ..~:..; , ..~ ~=....~., , .:,,~ . · ,. ~ , , ,* . ... ~ .2'. , , , V~ ~ ~~ w,w :.. :. ,,,.. ~,., .,. . · ~'; ~.,%.. , ,?'~ .. ~,' , . *.. ,.. . . ,. : .,' ,',, ,,;.~:, , .., . . ,,,, , . ~.'. · ~.,.:.,,~.~,. ,, . , . '..,.' , ,,, . . ..' ~ .... m ' ' ~.."~'.. . ''~ ~: · r' · . ' ' ' · , ,',:'.' .. :... -- ~~~w~ , ' ', ~ .~ , · ' ~'~ , ' '" ,f · .., - , ,~~~ ,~,,,.~...... :.. ,. .. , '.~ . " " '"' , ' ,'· · ' I ' ·' ' ' · .. . s · -.~ ~ ~' ~" ..,.. , . ' '"' "" "',"": .... ' '":'~ ' , .... ''"m i~ · ..~, .,..:,.,. , ;::=~. [~~on~.~, ~ .... ..' . ~ ~ .~' .-. .L.v;,~'-~ ~-'T~-' ~ ,,L';?~' ':~_%',', · ;r": · · .~. , . [,~., , ... -~..... ~ ..:"t~,, l.l~,~,fl ,~, .'. .. .- :' ..-' ....... · '..,; ........ ,~ ,'~~" ..... ~4..',. · I '/'?"',';~. ~.,'. ';,'~", ?' ~~~~~v.~e~,~.- ,__, ,,~.,... .... , . , · , ~ ~ ~- ~~ ~... · . . , ,, , ~ , , . ~ I~ .... ..., ~ ..... C~~ ~~ ~~~. l.,, ....., ,, , ~ __~ ~~ - ~ ... , , j, ~ .., '.. .. ,~ · .. ·. .:-~ ..... . , ' .~v'~4 " ..... "V":':' ' ;'" ' ' ~ I ' ' · ' , ' ,~' . · ' ' ' ' · ' .'~ ' ' e':'. '-" , " ~ ,~: ' .... ,, ,0 , "'1' ' . , ..I' ~".:'~'" ' 4 ' ' -:~".9 -'.. ' .... " "' ~' "" ~'"' ' ~ , , % ,,~ " ~ .~.: -. · ...,:,; ~ ~, ~,//' . .' , .,. .' ..... ., ~,.,'.~ ; · . . .... .,' ....,., . .V~ · . ~ ' . · ~ -'v ~ · ,, . ;... . -. ,.~,~.;,;?,.~ .?...... , ..... · : .. ..~,: . . ,. , · .. : . .,. . ,, · ~ , AUG-~-~ 90 11: 49 I~NCHORAGE OFF ! CE TEL NO: 56~,~5, 6 AU6 21 '90 1:::':41 F, ,~ CONOCO e E R ~ . F. rmlnL,~~ ~, # Conq)loUorm 6Y6TEM CONOCO ~39 P~qGE. 0 1 B \ RECEIVE'D i G ~ 9 1990 Gas Gons. · -o 4 e/0- o.~, %m eJ(~ pan. J'ooT (~ ~l:pO ~ t~1~ OM' ILtsOH ! · i '7 TEL NO: 564~ .439 PI? PRGE, 0 1 9 AI'I'ACHMENT #3 Reoommended ESP Running Procedure appropriate portior~ of ~tandard pm~dure that W in~uded, · RECEIVED AUG 2 9 1990 .Oil & Gas Cons. uumm'~ssion ', ~An~horalle . AUG-~2-~ 90 11: 50 ,~'~NCHORAGE OFF I CE · TEL NO: 5~--~5 M439 P18 PARF Interoffiee Communication RECEIVED TO: FROH: DAT£~ SUB,.1ECT: ,1, D. Cope land C. Van Ltneberger Oune !4, !9gO AU G ~- 9 1990 Alaska .Oil & Gas Cons. Go. mmis~n HPU KUP Recommended Esr Running Procedure - Addendum TI,. r,.ll.,.I,,~ o1.,,~,~ o,~ Lu !.~ l.=,.~ I,~d I. Lite =,ubJuu~, prucedur, as approvea on 4/3/90. Shou,ld you have any auesttons, please ¢a11. 4) Pick up tubing and shea~ out of the PBR assembly. Circulate b~tno to maintain the hole full. PO011 w~eh tuHn~. b) PU and GIH'wJth packel- ~etrtever. Reverse ctrcullte debris from top of packer at maximum pump rates prior to PetMevtng. Latch packer and zonal isol~tton .~embly. ~ 3nd L/D pook0P assembly. ' ' NOTE= If well exhibits high fluid loss tendency, spot a 5 bbl HE(; pl1~ (3.5 ~'s HE¢/bbl o~ brine) above packe~ and allow pill to fall across peris, c) HU bit w/o jets and tandem full gauge casing scrapers on production tubing. $IH and tag sump packet'. While reciprocating J:mxlmllm strnklno ranahllitx nf rio) and tntttt~ plpm. munrro circulate the following cleansing ptll at maximum pump rates. l) ~) 3) 4) Lead pad - 2S bbls of 3,5 #'s HEC/bbl of brtne Chemical pad - BO bbls of brine + ] drum of, su~faetant/d~spersant($afe-Kleen, Dirt Nagnet, eL~,,) Tat1 pad - 25 bbls of' 3,5 #'s HEC/bbl of' brtne Post flush - 2 complete circulations with filtered brine (2 microns) at maxlmum rates NOTE; a) Safety and environmental precautions must be taken when handling brines and chemicals. Revtew MSDS sheets prior to hand3tng. b) Chemicals must be mixed and maintained above 70 degt'ee~ F. c) I~onttoe brine clarity every 50 bbls during post f~ush with a Turbidity Mete~. Submit d) POOH and L/O bit and scrapers. Start ESP and set frequency of controller to establish an initial rate equal to 75% of the prev(ous rate. Allow well to unload and stabilize for 3 days at this rate, I AUG-22-'90 11:52 ixDr~NCHORAGE OFFICE TEL N0:5647605 ~439 PAGE. 02 ! TEL NO: 56~5 :EEEIVED ~1439 P20 PAGE AUG 2 9 19'90 mmm Alaska 0il & Gas Cons. Gom~sSton ;Anchorage .NDED E.S.P RUNNING PROCEDURE .~nd production and report to engineering ~ameters described in Step Zg. are open to production prior to starting lz i,,~,'eaaed, Lu, l.l,~e Lumu, lLur well n. Do ri. et ~ncrease rate ~f sand cut (uS1, water and gas). RIH w~th pressure lowing well pressure w~th gauge set at the well at the sqrf t re ard a l g hnur :termtne reservoir pressure. Report the s~gned based on the measured pressures to All k111 fluid should be ftltered tO two ~nks. ;. Move tn and rig up workover r~g, ftlter Bullhead brine down tubing to ktll the well .~). Nipple down wellhead and nipple up BOPs. stg. r thR PRR a~,~mhl~ (See~the attached wollbo~o o maintain the hole eu11' POOH ~ith tubing. lustrated on 'the attached completion gutde. each component. Run a standard Centrtltft '~rtP~ mntnr~ and 7", ~& lb/fi ca,trig on the to the attached table containing pertinent lugtattons). than 30' per minute. Maintain sufficient )trol 1 ine while running to maintain the valves ch 2 cable bands per Joint. Attach additional ~.able splice. Set the bottom of the motor at ached E.S.P. data table. , Original to File: ~alves at SO0'. Packer~ should be pinned to ;ely ],JO0 p$tg -el ine and set in the "X" nipple located below dp to 1,O00 pPsStigg. Set packer btyn grlduilly ?rom l,O00 to 2,500 pslg $00 psig lug and POOH. ; pressure to close the annular vent valve and annulus to 5o0 psig foe lO minutes to test the alve. If pressure holds, proceed to Step 10, retrieve the packer/S¢SSV system and repair or up tree, rig r~nwn and move to the next well. ml connections at the vont box, transformers '.L'Allut' art aL CO k,,. Il' ,,~ussd,'y, ~hu ~requency .ad the kill f'luid, ghen the well Is unloaded, Cting to 60 hz. AUG-Z2-'90 11:52 ~'~NCHORAGE OFFICE TEL NO:5~OS, ~439 P21 ?1 ',~l~ !?~44 "~ .~OM CONOCO P F R PAGP.PIP~ ~/tth the choki fully open, a11o~ peeductIon ~e -~t~bili~u ru[. ~ppruximetely 3 days at the 60 hz setting. Honito~ production (otl, Nate~ & gas), FBHP, current and frequency. Report this data to engineering on a daily basis. Do not adjust controller frequency, unless the well pumps off, until these parameters stabtl t. ze. ]3) ]4) I~hen the well stabilizes, controller frequency' should be ad.lusted to maintain a FSHP of SOO p$1g. Report stabilized well telts (oil, watet~ !tel, rOllP, fl'eque,~ ,,Ll ~;urrant,) tO engt.neering. Shut-in the E.S-.P. and the TR$C$$$V. Observe for leakage of the SCSSSV. If liquid leakage ~n excess of 200 cc per minute or gas leakage greater than S $CF per minute Is_observed, the valve must he repRtred or replace [As peri,IS, AP! ]4A Section ~0.~4 aI-9~ Production Safety System ?esttng and Rec°rds). Note: A representative of the AOGCC must be present duelng steps 9 and ]4 to ,~tness testing of the sub-surface safet~ system. Apply' sufficient control 1 Ina pressure to open the safet~ valves and return the ~ell to production. · . .,... Prepared by': Superv~st , ng Production Engine~ Approved by: ion Superintendent RECEIVED AU G 2 9 1990 ~i~ Oil & Gas Cons. Gomm'tss'ton ,, Rnchorage /"% STATE OF ALASKA r/"~ 0 ~ AI_~KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .~X Stimulate __ Plugging __ Perforate Pull tubing __ Alter casing 2. Name of Operator CONOCO INC. 3. Address 3201 C ST #200, ]~NCHOR~GE, AK Repair well __ Other 5. Type of Well: Development __X Exploratory __ Stratigraphic ~ 99~503 Service ' 4. Location of well at surface 3525' FNL, 3362' FEL, Section 27, At top of productive interval 2875' FNL, 2181' FEL, Section 27, · At effective depth 1850' FNL, 594' FEL, Section 27, At total depth T13N, R10E, UM T13N, R10E, OM T13N, R10E, UM 6. Datumelevaion(DForKB) KB-59.3' MSL ZUnitorPropertyn~me Milne Point Unit 8. Well number G-3 9. Permit number/approval number 89-46 10. APl number 50-- 029-21942 11. Field/Pool 12. Present well condition summary feet Upper cretac. ~- w s Total depth: measured 5910 · feet true vertical 4603 · feet Plugs (measured) N/A Effective depth: measured 5 813 · feet true vertical 4 519 ' feet Junk (measured) Casing Length Size Structural N/A Conductor 80' 13-3/8", 48#/Ft Surface 2900' 9-5/8",47#/Ft Intermediate N/A Production 5863' 7" 29#/Ft Liner Perforation depth: measured N/A Cemented Measured depth True vertical depth 60 bbls Arc Set 110'RKB 110'RKB 181 bbls Permf G2931' RKB 2509'RKB 138 bbls Class G 87 bbls Class G 5891' RKB 4534' RKB 24 ~lSs Arc Set I 62 Dead Crude true vertical N/A Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary RECEIVED DEC !i_ 7,1989 Alasl a 0il & Gas Cons. C0m Intervals treated (measured) ~/~ Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __~ 16. Status of well classifiCation as: Oil __x Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Signed .'~,~4'~ '~-----"~ Title Senior Form 10-40~'1~V 06~.15/~8 Production Foreman Date 12 SUBMIT IN DUPLICATE Kuparuk River-(SOS) North Slope Borough, Alaska W.I. 1.0000000% Milne Point G No. 3 CONFIDENTIAL (6115'-Shallow Oil Sands) AFE 10- 61-1205 API No. Ak. Permit No. Elevation Location: 3420' FEL, 3940' FNL, Sec 27, T13N, R10E Umiat Meridian Auqust 29, 1989 Skid rig, NU diverter & flowlines, test. PU motor, NMDC, Stb & XO. Drlg ice @ 40' to 110'. Orient MWD. Drlg & Navidrill f/ll0' to 931'. RIG ACCEPTED 07:00 8/29/89. MD ANGLE DIRECTION 0 0 0 381' 0.70° N62.7°E 563' 1.80° N73.4°E 745' 6.20° N69.6°E 837' 8.20° N66 °E Daily Mud Cost: $ 404 Cumulative Mud Cost: $ 405 Daily Cost: $ 75,562 Cumulative Cost: $ 75,562 Auqust 30, 1989 Drlg & Navidrill f/931' to 1113' Short trip f/ll13' to 280' clean trip. Drlg & Navidrill f/ll13' to 1883'. Short trip f/1883' to 1113' clean trip Drlg & Navidrill f/1883' to 2761' f · · MD ANGLE DIRECTION 927 10.60 1017 13.80 1170 18.40 1261 20.80 1352 23.70 1538 28.80 1725 30.60 1817 34.00 1943 39.50 2130 41.60 2223 45.00 2318 47.00 2444 50.40 2570 49.90 2695 49.80 N65.70E N60.80E N60.10E N60.40E N58.70E N59.10E N59.40E N60.40E RECeIVeD N57.60E N57.80E DEC 1 1989 N57.60E N56.7 (~j~ska OJJ & Gas Cons· Comm!o~ N57.80 E Anch0mge N56.90E Daily Mud Cost: Daily Cost: $ 4,754 $ 39,160 Cumulative Mud Cost: Cumulative Cost: $ 5,159 $ 145,497 August 31, 1989 Drlg f/2761'-2981' Circ & pump pill. Short trip f/2981' to 500' & RIH. Circ & cond. POOH, LD BHA. RU to run csg & conduct safety meeting. Run 74 jnts of 47 lb/ft 9 5/8" csg w/BTRC threads, full returns while running pipe, 44 total centralizers used 1/jnt 3000'- 2000', 1/2 jnts 2000'-500'. MU Howco cmt head. Circ 250 bbls of mud & reciprocate pipe. Full returns @ 6 bpm, SD test lines to 3500 psig. Pump 40 bbls of 10 ppg. Sepiolite followed by. 181 bbls of 12.3 ppg type E w/5 lb/sk Gilsonite. Full returns, mix & pump 138 bbls of Class G w/l% --- , 0.2% CFR-3, 3% salt (BWOW) @ 6 bpm. Full returns. Drop top plug, displace w/5 bbl HzO & 208 bbls of 9.5 ppg mud. Began .... Sepiolite pill @ surface. Lost returns w/--- bbls of disp pumped. Bumped plug w/2000 psi, bled off, floats held. ND diverter, found good cmt @ hanger. Hanger was about 2" above landing shoulder. NU BOP. Witness test by AOGCC waived per verbal order of Doug Amos. Daily Mud Cost: Daily Cost: $ 4,000 Cumulative Mud Cost: $ 9,159 $ 178,760 Cumulative Cost: $ 324,257 September 1, 1989 NU BOP. RIH w/test plug. Tet rams, HCR valve, outer choke line valve, both kill valves, choke manifold, upper & lower kelly cock, inside BOP to 5000 psig. Test annular to 3000 psi. LD test tools, set wear bushing, out kelly spinner sub. PU & orient BHA. RIH to 2850'. Tag float collar @ 2850 & test csg to 1500 psi. Drlg plugs, cmt & shoe & 10' .... to 2991'. Perform EMW test to psig. Drlg f/2991' to 4022'. Pump pill & short trip f/4022' to shoe. Drlg f/4022' to 4275'. Daily Mud Cost: $ Daily Cost: $ 1,542 Cumulative Mud Cost: $ 10,701 39,488 Cumulative Cost: $ 363,745 September 2, 1989 Drlg f/4275' to 5180', oil & gas cut mud @ 4780'. Circ & cond to POOH. POOH f/5180'. -- BHA so that RLL tool is on top of Navidrill. RIH to 5180'. Logging w/RLL f/4976'-5180'. Drlg 5180'-5240'. Daily Mud Cost: $ Daily Cost: $ 6,849 Cumulative Mud Cost: $ 17,550 49,527 Cumulative Cost: $ 413,272 RECEIVED DEC ! 1 89 ' ncliorage September 3, 1989 Drlg & Navidrill f/5240'-5910'. Circ for short trip. Circ. POOH & SLM f/5910'. LD BHA. RU Schlumberger & RIH 5570'. log up w/LDT & GR f/5570' to 4900'. RIH. Log up w/LDT & GR f/5907' to 2900', POOH. RU borehole vol. (BGT) & GR. MD ANGLE DIRECTION 5668 30.60 N40.70E 5806 30.60 N38.80E Daily Mud Cost: $ Daily Cost: $ 3,183 Cumulative Mud Cost: $ 20,733 68,276 Cumulative Cost: $ 481,548 September 4, 1989 POOH w/GR & LDT. RIH w/BFT (borehole geometry) to 5907'. POOH for 4 arm caliper, run w/GR. PU BHA, RIH to csg shoe. Slip & cut drlg line. RIH to 5910'. Cir¢ bottoms up. POOH, LD DP & BHA. Pull wear bushing, RU csg crew. RIH w/151 jts of L-80, 29 lb/ft BTRC csg. Short joint @ 4485' w/GR marker in box (note pup jnt is 26 lb/ft 7"). Float collar @ 5813'. Float shoe @ 5891'. Full returns while running pipe. Circ & cond mud. Pump 10 ppg, 40 bbls of Sepiolite spacer. Daily Mud Cost: Daily Cost: $ 3,193 Cumulative Mud Cost: $ 23,926 $ 225,875 Cumulative Cost: $ 707,423 September 5, 1989 Test lines to 3500 psig, Mix & pump 87 bbls of Class G w/0.3% Halad 24, oil % LWL & 0.2% CFR-3. Full returns while pumping @ 4 bpm. Reciprocating pipe. Drop top plug. Displace plug w/190 bbls of 9.6 ppg NaCl Brine and 5 bbls H20 + 20 bbls of diesel. Bumped plug w/1500 psi. Heats hold. Full returns. Land csg. R/D csg crew, LD landing joint, drain BOP. ND BOP. NU blind flanges. RIG RELEASED Daily Mud Cost: $ Daily Cost: $ Cumulative Mud Cost: $ 1,274 Cumulative Cost: $ 706,149 CONOCO MILNE POIN,T~8... 141. 881 ION RECEIVED 8£P 0 ! Ig89 Aikl 011 & ~ai Con~. Comll~ls~lo Pimtt f IIr#l If~ir Pu~P tn0f ilol Puli ohirII Cenk~llt Ind InlpIetor/CmItliion offlOI ,,2931 ....... _ ,t zOO Piti __,___mln ~~oo Piti_ FAX //,,/,' RECEIVED S£P o 11989 Oil & ;es Cons. Commlselon Anchorage , & Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 6, 1989 John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Please find enclosed the gyroscopic surveys on the Milne Point G-l, G-2, G- 3 and G-4 wells. No LIS tape or floppy disk format directional data is available for these wells. Sincerely, Michael R. Zotzky Senior Reservoir Engineer cc' well files (4) TO: Mr. John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DATE: TRANS.#: September 15, 1989 89-0817AK REFERENCE: CONOCO Milne Point G-3 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad. ENCLOSED INFORMATION SUMMARY Well G-3 MD: 1 Each Blueline; Total 3 1 Each Sepia; Total 3 1 Each Blueline; Total 1 1 Each Sepia; Total 1 Digital: 1 LIS Tape 1 LIS Tape Verification Listing A.O.G.C.C. / Date Received By: -oo --- (o ooo 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 ° Fax (907) 522-3432 A Baroid Company COMPANY · LOCATION · ATTENTION · aK aiL c~, ~:~S SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 Cui~SERVATION COMM. 300t PUi<~UPiNE DRIVE ~OHii 60YLE COMPUTING CENTER PRINT CENTER WELL NAME · SERVICES · i¥1iLNE-.POINT UNIT G-3 'I OH~' iS TAPE L)NE 73N. 61 '*:SEE ABOVE WELL NAME · SERVICES · NO. OF BOXES: JOB NO. ' ADD'L TAPES · NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME · WELL NAME · SERVICES SERVICES · NO. OF BOXES: JOB NO. · NO. OF BOXES' JOB NO. · ADD'L TAPES · z/2_3 - S- o- WELL NAME · SERVICES ' NO. OF BOXES: JOB NO. · ADD'L TAPES · ADD'L TAPES · DATE DELIVERED: WELL NAME · SERVICES · NO. OF BOXE~~ JOB NO .... ADD'L TAPES · Anchorage I / ~ ,,~' C/ .~L. RECEIVED BY: Conoco, $CHLUMBERGER WELL SERVICES A DIVISION OF~::HLUMBERG~R T£CHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 SEP I 1~9 SCHLUMBERGER WELLiERVICE$ Pouch 340069 Prudhoe Bay, Al( 99734-0069 Attn: Bernie/Shelley 3201 'C' Street,, Suite 200 Anchorage,, Ali .99..503 Attention:, ,ILt, c,,k k'heeler , Gentl&men: ' Enclosed are 3 BLprintsofthe BGT/Raw Data/Porosity, Run 1, 9/3/89 Company Conoco. Znc. Well H/lne Point Unit G-3 ,on: ] Field Ydlne Point Additional prints are being sent to: I BL prints Conoco, Inc. 3201 'C' Street. Suite 200 Anchorage, AK 99503 At,n: l~arc Shannon I BL prints, I [~ Sepia Conoco, Inc. lOOO South Piue PonCa CitY, OIC 74603 At,n: Log Library, I BL nrints ConocO, Inc. 600. North. Dairy Ashford Houston, TX 77079 At,n: George Lamb, OF 2018 PER County_North Slave State Alasks ... _t_BL._prints, I RF Sepia Chevron: U. S. A. P. O. Box l~O&3 San Ramon, CA g4583-O963. .. ~s, I RF Septa~'~ // Alaska 011 & Gas Conservation\ ~ ,3001 Porcupine ,Drive *---' --/ , k ~chora~e, ~ 99501 , ,, I BL nrints, I RF Sepia OXY, L1T. S.A. P. O. Box 12011 Bakersfield, CA 93389-2011 At,n: Jim Conners · prints PLEASE SIGN AND RETURN ONR COPY The film is..returned to Conoco, Anchorage. We appreciate the privilege of serving you. Received b:~: ~ ~,~, ~ l't I ~9 Date: SEP 11 Very truly yours/~la$~a ~i~ & GaG C0~15. ~O~21la~,': SCHLUMBERGER WELL David H. Saalwaechter DISTRICT MANAGER SWS-- ! 32 ?-F . SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON, TEXAS 77251-2175 Pt. EAIE REPLY TO S[~P t 19(~9 SCHLUMBERGER WELL 8EFIVIOES Pouch 340069 Prudhoe Bay, Ali 99734-0069 Attn: Bernie/Shelley Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage~ A!l, 99503 Attention: Rick Iiheeler Gentl&men: Enclosed are...3 BLprintsof the BGT/Raw Data/Porosity, Run 1, 9/3/89 Company Conoco. lac. Well Hilne Point Unit Field Iii 1ne Point .... County North S19pe State_ Alaska Additional prints are being sent to: I BL nrints ' '0noc , Inc. 3201 "C" Street, Suite 200 Anchora&e, AK 99503 Atto: Harc Shannon I BL prints, I RF Sepia Conoco, Inc. I000 South Pi~.e ............... Ponca CitY, OK 7a603 Atto: Log Library A__EL__prints, I RF Sepia Chevron, U,S.A ..... P. O. Box 5063 San Ramon, CA 96583-0963 Atto: Prisr4 lla ,, ~.3001 Porcupine Drive ~~;a;;;;rvatlO'~tt ' choraae,.AK 99501 .. / I BL ~rints Conoco, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 PER .nrints I BL nrints, I RF Sepia OXY, I~. S.A. P. O. Box 12011 Bakersfield~ CA 93389-2011 Attn: Jim Conners prints PLEASE SIGN AND RETURN ONR COPY 0]~. ?ItlR TRANRMTTTAT._ THANK yOl_~: . The film is....returned to Conoco, Anchorage. We appreciate the privilege of serving you. Received by: Date: SEP 11 Very truly you/'~a~ Oil & Gas Cons. SCHLUMBERGER WELLing8 David H. Saalwaechter DISTRICT MANAGER SWS-- 1327-F _ May 5, ]989 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay~ AK 99734 (907) 659-6300 Mr. D. Johnston Alaska Oil an Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE' Milne Point Unit; Wells G-l, G-2, G-3, and G-4 Dear Mr. Johnston' With reference to Bob Soptei's conversation with Mr. Bob Crandell on May 5, 1989 and the AOGCC mud logging and sampling requirements returned with the approved subject permits dated March 21 and April 21, please be advised that Conoco agrees to mud log Well G-1 and take mud samples on Wells G-]/2/3/4. No mud' logs are planned on Wells G-2/3/4. Conoco regrets any confusion that may have occurred when we informed you we were planning to mud log all the subject wells. If you should have any questions please call Bob Soptei or Hal Stevens at (907} 659-6327. Yours very truly, D. F. Rainwater/E. L. Robinson Senior Production Foreman RJS cc Field Superintendent, Anchorage Safety & Compliance Coordinator Senior Production Specialist RECEIVED April 21, 1989 Telecopy, (907)276-7542 T. R. Painter Division Manager Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Mtlne Point Unit No, G-3 Conoco Inc. Permit No' 89-46 Sur. Loc. 3525'F~, 3362'FEL, Sec. 27, T13N, R10E, UM. Btmhole Loc. 1825'FNL, 642'FEL, Sec. 27, T13N, R10E, UM. Dear ~. Painter Enclosed is the approved application for permit to drill the above referenced well. The pemt~ to drill does not exempt you from obtaining additional Pdermits required by law from other governmental agencies, and ocs not authorize conducting drilling operations until all other required pe~tting determinations are made. To aid us in schedulin§ field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness, testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. trulr ?urs, " ' I / ur.' Chai~n of Aias~ Oil and Gas Conservation Comission BY O~ER OF THE COMMISSION d!f ~closure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 April 12, 1989 Mr. C. V. Chatterton Chairman of the Commission Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: RE: PERMITS;. MILN. E POINT UNIT; WELLS G-.I, G-2, G-3 AND G-4 Enclosed you will find ApplicatiOns for Sundry Approvals for Milne Point Unit Wells G-] and G-2 (original drilling permits approved by your office on March 6, ]989) and Permit to Drill Applications for Wells G-3 and G-4. A check for $200 is included for the Drilling Applications. If you should have any questions, please contact Bob Soptei or Hal Stevens at 659-6327. ' T/(. R. Painter Division Manager RJS/jah File 500.2].04 RECEIVED [~JaS,k~ 0JJ .& Gas Cons, Commissi0~ STATE OF ALASKA ~ ALASKA _ AND GAS CONSERVATION C~ ~'IlSSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill .~. Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen . Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator Conoco Inc. 3. Address 3201C Street, Ste 200, Anchorage, AK 99503 4. Location of wellatsurface 3525' FNL, 3362' FEL Sec. 27, TI3N,R10E,UM Attop ofproductiveinterval 1984' FNL, 897' FEL Sec. 27, T13N,RiOE,UM Atto~aldeptn 1825' FNL, 642' FEL Sec. 27, T13N,R10E,UM 12. Distance to nearest property line @ Target 897 feet 13. Distance to nearest well 60 feet 16. To be completed for deviated wells Kickoff depth 600 feet Maximum hole angle 500 5. Datum Elevation (DF or KB) KB 28 feet 6. Property Designation ADL 25906 7. Unit or property Name Milne Point Unit 8. Well nurpber G-3 9. Approximate spud date August 1989 14. Number of acres in propert' 2560 10. Field and Pool Kuparuk River Field 11. Type Bond (see 20 AAC 25,025) Blanket Number 8086-15-54 Amount $200,000 15. Proposed depth (MD and TVD) 5888MD*/4610TVD* feet 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Maximum surface 2200 psig At total depth ('rVD) 2300 psig 18. Casing program size Hole Casing 30" 13-3/8" 12-1/4" 9-5/8" 8-1/2" 7" Specifications Weight J Grade Coupling 48~/ IH-40 Weld 36f~ IK-55 BTRS 26~! IL-80 BTRS ILength 80' 2916' 5860' MD 28' 28' 28' Setting Depth Top Bott( 28' I 108' 28' 12944' I 28' 15888' )m Quantity of cement TVD (include stage data) 108' 2500' 4610' 19. To be completed for Redrill, Re-entry, and Deepen O~erations. Prbsent well condition summary Total depth: measured feet Plugs (measured) true vertical feet ~485 SKS PermaFrost C +486 SKS PermaFrost E ~640 SKS PermaFrost G +129 SKS PermaFrost E +355 SKS PermaFrost G ~409 SKS PermaFrost C ~60 Bbls. Arctic Pak Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented measured true vertical Measured depth True Vertical depth RECEIVED ~.. ~,~,,,~ 0il & Gas Cons. C0mmjssi0B ': ~,nch0rage ~' 20. Attachments Filing fee ~ Property plat ~ BOP Sketch [] Diverter Sketch ~ Drilling program ~ Drilling fluid program ~_ Time vs d,..~th plot ~., Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify ~f.(~going)is true and correct to the best of my knowledge Commission Use Only APl number ! Approval date 50-OZ,~-.~_._/~":.2.J 04/21!89 PermitI I Conditions of approval Samples requ. ired Yes ,~ No Mud log required Li Yes~No Hydrogen sulfide measures [] Yes ~'No D. irectional survey required ~'Yes [] No'' ' Required working j;;~e~sure~or BO, I;~-~ E~JVI; ~ 3M; [] 5M; [] 10M' [] 15M Other: //~7/~ ' ' by order of Approvedby {~ ~.. ~,", k_..,'ff~x~,~~l, Commissioner ,he commission Form 10-401 Rev. 12-1-85 See cover letter for other requirements SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT G-3 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 I · Casing and Cementing Program ae The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ~485 sacks of Permafrost Type "C". BI The 9-5/8" surface casing will be cemented with ±486 sacks of Permafrost "E" cement followed by ±640 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. el The 7" production casing will be cemented in two stages. The first stage will consist of ±129 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±355 sacks of Class "G" cement. The secondary cement job will consist of ±409 sacks of Permafrost "C" cement followed by ± 60 barrels of Arctic Pack pumped down the 7" x 9- 5/8"annulus. II. Drilling Fluid Program Al Bi 0-3610' 9.0 ppg freshwater spud mud. 3610'-3830' 9.2 ppg low solids non-dispersed. RECEIVED Ce 3830' - TD 9.4 low solids non-dispersed. III. Drilling Program Alaska ,Oil & Gas Cons. CommisslOl~ '.-~ ~chorage Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly will be tested to 500 psig and 5,000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1,500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is G-2 with a'closure of 60 feet at the surface. The well will not be completed or tested at this time. A® Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to +2500' TVD (2944' MD) and set 9-5/8" casing. Ce Drill a 8-1/2" production hole to 5888' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV VIS FL 0' 0' Gravel 1-1-4 9.0 32 20 90 15 2500' 2944' Sand/Clay 1-1-4 9.0 25 20 65 15 3610' 4886' "K" Sand 1-1-4 9.2 25 15 35 10 3830' 5195' "M" Sand 1-1-4 9.4 25 15 35 10 4090' 5512' "N" Sand 1-1-4 9.4 25 12 35 5 4260' 5708' "0" Sand 1-1-4 9.4 25 12 35 5 4610' 5880' TD 1-1-4 9.4 25 12 35 5 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. CONOCO. Ino. i Ped O, ~ell No, ~ Rev~eed P~opoieel HIIne Poln~ Unl~, Nor~ Slope, ~laeke 1000 2000 :3000 4000 5000 0 RKB ELEV AT ! ON ~ KOP TVD=600 TtlD=61 9 15 21 3g )0 DEP"O BUILD 3 DEG ! PER 1oo FT i EOB TVD"2059 THD"2261 DEP-6?~, 9 5/8" CSG PT TVD-2500 TI DROP 3 DEg- PER IOOFT 42 HAX l HUH ANGLE 49 DEG 49 ~HIN ID=2944 DEP-1200 ANGLE DROP TVD=3586 TPID=4627 DEP-2485 TARGET ANGLE 30 DE(; 1000 2000 , VERTICAL SECTION I( SNDS TVD.361 O, TtlD-46.64 DEP-2513 , itl SNDS !VD-3830 THD 4971 DEP-2r2r. ! , 3000 TARGET"~-N-'SNDU .... TVD=4090 TPID=5287 DEP-2907 0 SND~ TVD.4260 THO-5484 DEP-3005 'TD /i?" CSG PT TVD-4610,TtlD-5888 DEP-320Z PERH!TTED DEPTH TVD-49!O TtlD-6234 DEP-3380 4000 -) PERH[TTED DEPTH LOCATION 17'33' FIJL. 496' FEL ~3EC. 27*, T13N. RIOE 9URFN~ LOCAT [ ON ~ 3525' FNL, 3362' FEI. 9EC. 27. 1'1314, RIOE HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET CONOCO. I. ~ · Pmd 0 Well No, 3 Revlmed Propo.el HIIne Poln~ Uni~. No~h Slope, iAImmke i . , WEST~EAST I000 0 i000 3000 2000 _ 1000 _ 1000 2000 SUm'ACE / N! 57 'DEO 2907' (T 59 MI NT~ TARGE 3000 I TD LOCAT !ON, 1825' FILL. 642' FEL ~J:EC. 27, TI3N, RIOE TARGET / Ii SND$ TVD-4OgO TIID-$287 DEP-~GO? NORTH 154,1 EAST 2465 TARGET LOOAT !0# m 1g~4' F14L. ~gT' FEL 9EC. 27, TI3N. RIOE DEVELOPMENT WELL WELL NAME: WELL G-3 02-Feb-89 CONDUCTOR SETTING' DEPTH: SURFACE CASING SETTING DEPTH: INTERMEDIATE CASING~SETTING DEPTH: PRODUCTION CASING SETTING DEPTH: 8O 3,010 0 6,115 DEPTH 0 O. (3,010) (3,010) (3,010) (3,010) (3,010) (3,0]0) (3,110) (6,115) (6,115) (6,115) (6,115) (6,115) (6,115) (6,115) (6,115) (6,115) OPERATION: RIG MOVE: RIG-UP;SET CONDUCTOR: DRL/SURVEY SURFACE HOLE: SURFACE HOLE LOGGING: CONDITIONING TRIP: RU/RUN SURFACE CASING: RU/CEMENT SURFACE CASING: CHNG BOPs; PU BHA; RIH: DRL OUT; TEST; TOOH; RIH: DRILL PRODUCTION HQLE: CORING OPERATIONS: LOGGING OPERATIONS: CONDITIONING TRIP: RU/RUN PRODUCTION CASING:' RU/CEMENT PRODUCTION CASING: ND BOPs; NU TREE: ADDITIONAL RIG-TIME: RIG-DOWN; MOVE RIG: CUM HOUR DAYS DAYS 0 0.00 0.00 12 0.50 O.50 53 2.22 2.72 0 0.00 2.72 3~ 0.13 2.85 10 0.41 3.25 6 0.25 3.50 9 0.38 3.88 10 0.40 4.27 6g 2.88 7.15 0 0.00 7.15 18 0.75 7.90 10 0.42 8.32 16 0.65 8.g7~ 6 ',-~ 0.25 9.23 12" 0.50 9.73 0 0.00 9.73 0 0.00 9.73 3350 3400 3450 3500 3550 3600 3650 3700 3750 3500 I 3500 3450 3400 3350 I I { 1:>00 ! ~' ! 000 I 900 ! 8oo 600 ,,. /iooo' ~"900 'o oOO / 1 200 '"'i 100 3250 I /, 1 ;300 I 3400 600 800 900 ! 000 1100 I ! 1 200 3~$0 '*' 1-200 i 3200 I I I II 3300 3250 ;3200 _ 33' .34C _ 345 .350 _ 355' .360~. _ 370( _ 375C TRACT 14 D EVELOPMENT fl_ W r~ · · i i i ! i ii I i i I i i lIlIlIIIlliI IlI~ II IlliIiIi iIIIiiI iiii~IIliiiiIiIIIiiiIIiiI ~iiiiIIIilIIIIIIIIitIi~IIIiIIIIIIi IIiiIiIilI i i i i i i i i I i I I I i I ii . i I i I i i i i i I ~' i i i I I i i i I iii ! Ii~lJlIIiIIiiIIIIIJIIiJi~iiIliJIIIiiIIlIlIiiI;IiIiIJi IiIllIiiIliIII;lI IJII i I iIII iii iiiIi i i i i I i i ~ i i I i / i i I I~II II~ I i i I i I i i i i I i i I i I i i I i ii i · I i .................................. : .................... ; ..................... ; ...................... II·iX ~F FC ~l! ' ' '"' '"' I I . I I .......................... _~ ................. ~ ..................... ; ....... , .............. i ~ i i ill i iI~I~ I . i i i I I I i I I i I i i i i I t ! i i e i i i I i i I i I i !111 !! ii III !i !~ i i!1111 II!! !!!111111 I~lllllllllll iiIIll !~ i Iti1111 II !!II!1 !!!! ~11 i! !1 II!!1 !!! !t !! !11, i I i I i i i i , I i I · '~ i · i · i I i I i ~ , : \: . .... 1~ ........... ?'A:'~. ...................................... 'I, ...................... ~ I -- ~ ,--,-,. : : %, . . ~.~ I I I ~I~ I ' -' ..... ' tiaa ~'~' I i I I ~F,-~ .... ~ .... I. l.L,. .................... ~.----~ .......... ~ ......... .~ ...................... 0 L'~ ~. ~..,.m o . m . · . ~ 0 ~ i i i i S~ ~ _..-~, , , , 10 DEPTH NOTES: ~.~ PO~ U~T 1. STATE PLANE COORDINATES ARE ZONE 4 . 2. ALL GEODETIC POSITION8 ARE BASED ON ^ccc~ N.A.D. 1927 I-- 3. O~8"8 TO SECTION L.E8 ARE CO~~ BAS~ ON PROTRACTED VALUE8 OF ~E SECTION COR~ POST.N8 . MILNE PT, VICINITY,,MAP ~o'~., ~ o I j 110' _~O~ _ 120' = I m ' ~ ~, ~ ' LOCATION IN 1' ~ 'b SEC. 27, T13N, R1OE, UMIAT MERIDIAN ~) ~ ~ WELL ~OM NOR~ L~ FROM ~ST L~ 30, -~ ~.~ I~ ~ " ~ ~ ~ , G-4 , ~,~ G-1 3644' 3346' - < [ ~ G-2 3585' 3354' ~ ' ~ , ~-3 b~ G-3 3525' 3362' ~ ' G-2 : bi~ G-4 3466' 3370' ~' STATE PLANE COORDINATES-ZO~ 4 ~ , , ! ' , G-1 ~,014,071.302 557,2~0.513 '' m ' I' ~r G-2 6,O14,130.704 557,252.065 G-3 6,O14,190.106 557,2~.616 '. ~'_ G-4 6,O14,249.509 557,235.167 ~_60'__ so' _~_ mo' _~ ~, GEODETIC POSITIONS NAD 1927 t -~ -{J . ~' ~ G-1 70' 26'56.6828' 149'31'58.2867 ~~ ~:~/~?.~:~:~/~:~.::~::~:/~'~:~.~?/~?'?:/:.~:~ ~ G-2 70' 20'~7.2077 ~9'er~e.a2~4 G-4 70' 2o'se.4e74 ~49' 3rae.990e TYPiCaL SECTION NO SC~E II I I III ~.~ ~L D~ ~ O~ ~8 ~ ¢~. ~~'..:~'..:...~ o,~w. J~ L~A~ ~~i'~~ ~~~ ~ ~ ~ ~ F~D BOOK ~ ~ ~ SCALE ~' JOB ~, 8900~ I I I I "~, ss't4 -- 1,OL-2S5~5 2544 AC 29 2~,35 AC ~ IIII I I III · ,o T 13/t R 10E 1 T 13 N R 11 E MILNE POINT UNIT -- ! ii ~ Il I IIIlll ! Il , ,,, i lU i, ..... -- - · .....:' - II ] ' ~~// ~ ~ ~~.'AD~-31071 1265 AC/ ~x~L ~~ . i i i i i " ....... ~ ~ ' · ' '~ II IL I[ I iiii C~VAO~ c~oco E~ A~t CO.OCO ~T *L . 23 24 19 2~ 2 t 22 AOL-4742O ~ £ i,,tC'Y. ~£C0 AOL-25518 2S~)0 ii il i - 30 20 --+-- 31 32 ADL-28231 2SS5 AC £ EXHI]~ t']' A MILNE :POINT UNiT AREA Itl, los 0 I 2 S c It i ii i ! I~ILLoU P LIRE MILNE POINT uNiT BOP STACK FOR 9-5/8" SURFACE CASING m PLOw LINE ARNULAR PREVENTER I$l/i # APl SO004 RAM BOP I&S/~# APl 8000t~ RAM BOP I}~l" APl SO00~ SPOOL (1) (2) ~" - AP, acco S,0E OUTLE?, (3) I~S/I" APl 5000~1 APl 5000~__~~JI TBG OUTLETS U/ ~SPOOL · r_/ ' 3" APl 50004. CSG SlOE OUTLETS SPOOL Threaded Connection 9--~/8"CASINO RAM BOP ISS/i" APl 5OOO~ · '11' APl SO00 (4) II" APl 5000 ' ' ' '~i~a Oil ~ Gas Cons . o ~ · · · ~ B.O.P. stack size rating meets AP1 RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote vith 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. Ram type BOP to include a minimum of one set of blind rams and two sets of apptoprlate pipe rams. Choke and kill manifolds sho~rn separately to meet AP1RP 53 class 5M requirements. 0o o ~o Well Histo.ry 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. (NOTE: ** REEL HEADER ** **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) REEL SEQUENCE # 1 SERVICE NAME: SPERRY DATE: 89/09/21 ORIGIN OF DATA: MWD REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 89/09/21 ORIGIN OF DATA: G-3 TAPE NAME: MILNE PT CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE ********** ** FILE HEADER ** FILE SEQUENCE # 1 F I LE NAME: G- 3. DAT SERVICE NAME: RLL VERSION #: REV 2.3D DATE: 89/09/21 MAX. RECORD LENGTH: FILE TYPE: EO PREVIOUS FILE NAME: 1024 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT TVD GYRO NDIS GYRO EDIS GYRO DEVI GYRO NPS MWD DRHO MWD RHOB MWD GRC MWD EWR MWD CAL MWD ROP MWD FXE MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD ORDER# L0G TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 DEG 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 oHMM 0 0 0 0 1 4 0 1 68 IN 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HRS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT TVD GYRO NDIS GYRO EDIS GYRO DEVI GYRO NPS MWD DRHO M~D RHOB MWD GRC MWD EWR MWD CAL MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 DEG 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 3. 4 0 3. 68 G/C3 0 0 0 0 1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 IN 0 0 0 0 1 4 0 1 68 ROP , Fk'E ,~' NFO NFl NN0 NN1 MWD FT/H MWD HRS MWD CTS MWD CTS MWD CTS MWD CTS 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 ** 472 DATA RECORDS ** FROM 2700.00 TO ** FILE TRAILER** FILE NAME: G-3.DAT SERVICE NAME: RLL VERSION #: REV 2.3D DATE: 89/09/21 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ** TAPE TRAILER** SERVICE NAME: RLL DATE: 89/09/21 ORIGIN OF DATA: G-3 TAPE NAME: MILNE PT CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT 6000.00 FT ** REEL TRAILER ** SERVICE NAME: SPERRY DATE: 89/09/21 ORIGIN OF DATA: MWD REEL NAME: CONOCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT COMPANY NA:~E : CONOCO INC. WELL NAM!~ : MILNE POINT UNIT G-3 -~:IELD NAM~ : MILNE POINT ~O~:~UGH : NCRTH SLOPE STATE : ALASKA API NUDqBER : 50-02'9-21942 REFERENCE NO : IS TAPE VERIFICATZON LISTING .CHLUN~_,E~GER ALASKA COMPUTING CENTER 15-SEP-19~9 OB:Z4 PAGE: ~'~'~' REEL HEA'D~_=R "-~ '" SERVICE NAM5 : EDIT DATE ' 89/09/i4 ORIGIN : ~=LIC REEL NAME : 73~61 CONTINU~TiON m : PREVIOUS REEL : COMMENT : CONOCO I~C. ~ILNE P3INT ~LNE POINT UNIT G-3,50-029-21942 ~' ~"~ ~' TAPE HE~DER ~ ..... SERVICE NAME : EDIT DATE : ORIGIN : FLIC TAPE NAME : 73~;61 CONTINUATION PREVIOUS T~PE : CDMMENT : C~.NOCO ZNC. ,MILNE P~INT ~M~LNE PDINT UNIT G-3~50-O2g-21942 ~:¢~ FILE HE,O'ER ;~ ~.~ FILE NAME : EOIT oOOl SERVICE : =LIC VERSION : O01AO2 DATE M.~X REC SIZE :: 1092 FILE TYPE : LO LAST ~ILE : COMPANY NAME: CONOCO INC. WELL: ~ILN~ ~OIN'T UNIT G-3 FIELD: ~!LN5 POINT BORDUGH: NOqTH SLOPE STATE: ,~L~SKA API NUMBER: 50-029-2 17~,2 LOCATiION: ~5,2=,' FNL ~ ':~'~62" ~EI. SECTION: 27 TOWNSHIP: I~N R A N G E: ! 0 E PERMANENT D4TUM': MSL ~LEVATZON: 0 LOG ME.ASUREO '.~ROM RKS, 59. Z7 A~.OVE P~R=~ANENT D~TUM .IS TA'PE VERIFZC.~TZON LISTING ;CHLUMBERGER ~L~SKA SOMPUTIN~ CENTER '..5-SEP-lg89 08:24 PAGE: ELEVATIONS K~' O=: 59.27 GL: 29.5 DATE LOGGED: 3-S EP-S9 RUN NUMBER: ONE TD DRILLER: 5910 TO LOGGER: 5907 CASING 2: g 5/8 LB @ DRILLER DEmTH OF 0 TO 2930 ~ND LOGGER DEPTH OF 0 TO -- BIT SiZE 2: 12 /14" TYPE FLUID IN HOLE: LSND POLYMER DENSITY: 9o29c~999 VISCOSITY: 40 PH: 8.5 :LUID LOSS: 5.5 MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 4.02 @ 64 3.44 @ 64 3,79 -~ 64 TIME CIRCULATION EN'gED: ~,-SEP,-89 15:00 MAXIMUM 'TEMP LOGGING OIST~ICT: LOGGING ENGINEER: WITNESS: 4~t5 HUS~AND/TTNKH~M S.BR~DY TOOL NUMBERS: AMM-AA 712 SGC-SA 50 DqS-C 4 908 TCC-B 281 NSC-E TCM,-A~ 10'7 FIELD REMARKS: TOOL STRING (!BOT-TOP) IS LDT--GR-TCC-AMS. DENSITY MAT-RIX = 2.65 G/CC, FLUID DENSI'TY : 1.0 G/CC DAT~.E JOB STARTED: 14-SEP-B9 JOB REFERENCE NO: ?3461 LDP/ANA: R. SINES FILE - EDIT.O01 CONOCO liNC. MILNE POINT MILNE POINT UNIT 50-029-21942 MAIN PASS LOG g~TA IS TAPE V~_RIEIC,~TZON LISTINS CHLUM~ERG~R AL~SK~ COMPUTING CENTER 15-SEP-1989 0,8:24 PAGE: .,- DATA SA,.u,P~ ED :EVERY - ~000 -,- DATA ZNrLUCED- "'-.,- T OCL 5XT E NS I ~,.. N 'rOOL -,,. TYPE US EO N~E -,'k. LOT .LOT LZTHg DENSITY ~- BST .BGT 80RFHOLE GE3METRY # GR .CSG TABLE TYPE : TUNI CONS VALU DEFI CN FN WN APIN FL SECT TOWN RANG CDUN STAT NAT I LATI LONG ENGI W ITN SON PDAT EPD FT L MF APD FT EKB FT EOF EGL FT TDD ~T BLI FT TLI TCS STEM DEGF CONOCO INC. MILNE POINT MILNE POINT 50-029-21942 3 525~ mNL & IOE NORTH SLDP~ A. LASK,~ U S ~m UNIT 3362 m FEL HUSgANO/TINKHAM S.BRADY 73461 M SL O. R K B 59.27 59.27 5,9.27 2 '.9.5 5910. 5910. 2830. 3 -SEP-Sg 15:00 COMPANY N~ME FIELD NAME WELL NAME APl SERIAL NUMSER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION LATIT:UgE LONGITUDE ENGINEER'S NAME WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT D~TUM LOG MEASURED FROM BOTTOM LOG INTERVAL 'TOP LOG INTERVAL 'TIME CIRCULATION STOPPED IS TAPE VERIFICATION LTSTZNG CHLUM~:RGER. ~LA:SKA -~'~OMPUTING C~NTER_ 15-SEP-1989 O~B: 24 PAGE: TABLE TYP5 : CURV ,-. DEPT DPHI RHOB DRHO PEF QLS QSS LS LU LL L ITH SS! SS2 LSHV SSHV S1RH LSRH LURH CALI GR TENS MTEM MRES H TEN G R C1 C2 'TiE N S GR TENS MRES MTEM HTEN DEPTH CHANNEL NAME DENSITY POROSITY BULK DENSITY DELTA PHDTg-ELECTR!C FACTOR qU4LITY CONTROL DF LONG SP&CING ,=OR LOT ~UALITY CONT.~OL ON SHORT SPACING FOR LOT LONG SPACING COMPUTED COUNT RATE (LL+LU/2) LONG UPPER 1-2 WINDOW COUNT ~ATE (LU!+LU2) LONG LOWER WINGOW COUNT RATE LITHOLDG WINDOW COUNT RATE SHORT SPACING t WINDOW COUNT R~TE SHORT SP~CING 2 W!N~W COUNT RA'TE LONG SPACING HIGH VOLT&GE OUTPUT SHORT SP~CIN~ HIGH VOLT~.GE LOOP OUTPU'T SHORT SPACING 1 DENSITY LONG SPACING RHOB CUNCORR~CTED) LONG UPPER RHO~ CALI~ER GAMMA R~Y TENSION MUg TEMPERATURE MUD ~ESISTIVITY HEAD TENSION GAMMA R~Y CALIPE~ CALI PER 2 - 'TENSION GAMM~ R~Y TENSION MUD REST.,.S'TZVITY MUD TEMPERATURE HEAD TENSION DATA FORMAT SPECIFICATION RECORD '~-~ :~ SE~T 'TYPE- 6.~E~ -'--" TYPE REPR ~ D · ~ 0 ~., E V ~ L U E 1 66 2, ~56 0 3 T 3 ! '32 4 66 5 55 IS TAPE V.ER;ZFZC&TZON LIS?INS CHLUMBERGER ALASKa, COMPUTING CENTER 15-SEP-1989 08:24 PAGE: TYPE RSPR CODE VALU~ 9 65 FT 11 66 1Z 68 13 66 0 15 66 16 66 1 0 66 0 ,"' ~:T TYP~ CHAN ** NAME SERV UNIT SEqVICF API AP1 AP1 .AP1 ~ILE NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 5~0763 OD DPHI LDT PU 530763 45 RHOB LDT G/C3 530763 45 DRHO LDT G/C3 530753 45 P E F L D 'T 51307,63 45 QLS LOT :530'763 45 (~SS LDT 530?63 45 LS LOT CPS' 530763 4.5 'LU LDT CPS 530763 45 LL LOT CPS 530763 45 LITH LDT CP~" 530763 45 $.S1 LDT CPS 530763 45 SS2 LOT CPS 5307,53 45 LSHV LDT V 530763 45 S;SHV LOT V 530763 45 SIRH LDT G/C3 530763 45 LSRH LOT G/C3 530763 45 LURH LD'T G/C3 530763 45 CA,L! LDT IN 530763 45 GR LD'T GAPI 530763 45 TENS LOT LB 530763 45 MTEM LDT DEGF 530763 45 MRES LDT OHMH 530763 45 HTEN LD'T L'B 530763 45 GR BGT GAPI 530763 76 C1 BGT IN 530763 76 C2 ~GT IN 530763 76 TENS ~GT L8 530763 76 GR CSG GAPI 5~0763 45 TEN:S C'SG L~ 530763 45 MRES CSG OHHM 530763 45 M'TEM CSG D~GF 53076~ 45 HTEN CSG LB 530'763 45 000 O0 0 1 1 1 4 68 890 O1 O I 1 1 4 6B 350 OZ 0 1 I ' 1 ¢ 68 356 O1 0 I 1 1 4 68 1358 O 1 0 1 1 I 4 68 354 0'I 0 I 1 1 4 68 35~ 01 0 1 1 1 4 68 354 Ol 0 1 1 1 4 68 354 01 0 I 1 ! 4 68 35,4 O1 0 I 1 1 4 68 354 01 0 1 1 1 4 .6 8 354 02 0 1 1 1 4 68 354 02 0 1 1 1 4 68 3~4 O0 0 ! 1 I 4 68 354 OO 0 1 1 1 ,4 68 350 02 0 '! 1 1 4 68 35 O 02 0 1 1 1 4 .6 8 350 07- 0 1 1 I 4 68 280 Ol 0 I 1 1 .4 68 310 0 t 0 1 I 1, 4 68 635 21 0 1 1 1 4 68 900 Og 0 I I 1 4 68 000 00 0 1 1 1 4 68 000 O0 0 1 1 I 4 68 310 01 0 1 1 1 4 68 280 13. 0 t 1 1 4 68 2~0 24 0 1 t 1 4 68 635 21 0 1 I I 4 68 310 O1 O 1 1 1 ,4 68 · ~35 21 0 1 1 '1 4 68 000 00 0 1 1 1 4 68 O00 O0 0 1 I 1 4 68 OOO O0 O: 1 1 1 4 68 0000000000 0000000000 0000000~000 0000000000 0000000000 00000000~00 0000000000 0000000000 0000000000 0000000000 00'000:00000 000000000'0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000'000 ~0000000000 0000000000 000000000:0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000:0000000 0000000000 0,000000000 0000000,000 .IS TAPE. VERT.FZCATION LiSTZNG ;CHLUMBERGER ALASK~ CO~PUTZNG CENTER 15-SEm-1959 08:24 PAGE: DEPT. 5928.500 gPHI.LDT PEF.LDT -9 '99.2 50 QLS.L OT LU.LDT -999.2 50 LL.LOT SS2.LDT -999. 250 LSHV.LDT LSRH.LDT -999. 250 LURH.LDT TENS.LDT -999.250 MT=_M.LDT GR.BGT 110.688 CI.6GT GR.CSG -999.250 TENS.CSG HTEN.CSG -999.250 DEPT. 5900.000 DPHI.LDT PEF.LDT 2.930 TLS.LOT LU.LDT 353.750 LL.LDT SS2.LDT 335.250 LSHV.LDT LSRH.LDT 2.238 LU~H.LDT TENS.LDT 3550.000 MTEM.LDT GR.BGT 108.625 C1.BGT GRoCSG -999.250 TENS.CSG HTEN.CSG -999.250 DEPT. 5800.000 DPHI.LDT PEF.LDT 2.580 QLS.LDT LU.LDT 351.'750 LL.LDT SS2.LD'T 3t3.750 ;LSHV.LOT LSRH.LD'T 2.240 LURH.LOT TENS.LDT 3260.000 M'TEM.LOT GR.BGT 79.813 C!.BGT GR.CSG -999.250 TENS.CSG H'TEN.CSG -999.250 DEPT. 5700.000 DPHI.LDT PEF.;LDT 2. 875 GLS.LDT LU.LDT 3~0.000 LL.LDT SS2.LDT 309.250 LSHV.LDT LSRH..LDT Z.,Z~5 LURH.LgT TENS.LOT 3304.000 MTEM.LOT GR. BGT 85.063 C1. B GT GR.CSG -999. 250 TENS,.CSG HTEN.CSG -999. 250 DEPT. 5600,000 DPHI.LOT PEF,LDT 3.0,20 CLS.LOT LU.LDT 295.500 LL. LDT SS2.LDT 305.000 LSHV.LOT LSRH.LDT 2.334 LURH.LDT TENS.LDT 3170. OOO MTEM.LDT GR. BGT 104. 438 C1. BGT GR.CSG -999.250 TENS.CSG HTEN. CSG -999.250 -999.250 RHOB.LDT -999.250 -999.250 QSS.LDT -999.250 -999.250 LITH.LDT -999. Z50 -999.250 SSHV.tDT -999.250 -999.~__50 CALI.LDT -999.250 - 999. 250 MESS.LOT -999. 250 7.255 C2.BGT 2.127 -999.250 MRES.CSG -999.250 19.757 RH.3B.LDT -0.015 QSS.LOT 203.250 LITH.LDT 1408.000 SSHV.LDT 2.242 CALI.LOT 90.438 MR'ES.LDT 8.758 CZ. BGT -999.250 MRES.CSG 23. 921 RHOB.LDT -0.005 QSS.LDT 20&..625 LITH.LDT 1~09. 000 SSHV.LgT Z. 2.46 CALI.LDT 90 . 625 MR!ES.LOT 9.680 C2.BGT -999. 250 MRF~S.CSG 20. 376 RHOB.LDT - 0.006 Q S S. t D'T 183.625 LITH.LDT 1:~09. DO0 SSHV.LDT .2. 303 CALI.~LDT 90. 375 MRES.LDT 9. 391 C2.BGT -999.250 MRES..CSG 18,239 RHOB.LDT 0.025 QSS.'LDT !74.375 LITH. LOT 1409.000 SSHV.LDT 2.352 CALI.~LDT 89.688 MRES.LDT $.992 C2.BGT -999.250 MR~S.CSG 2.324 0.~41 112.563 1321.000 8.?11 2.602 ~.617 -999.250 2.257 0.036 121.813 1321.000 8.883 2.635 9.203 -999.250 2.314 0.029 101.625 1321.000 9.172 2.656 9.500 -999.25'0 2.349 0.923 96.563 1321 ,. 000 9.156 2.688 g, 656 - 999.250 DRHO.LDT LS.LDT SS1.LDT S1RH.LDT GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DRHO.LDT LS.LDT SS1 .LDT S1RH.LDT GR.LDT HTEN.LDT TENS oBGT MTEM.CSG DRHD.LDT LS.LDT SS1.LDT S1RH.LDT GR.LDT HTEN.LDT 'TENS,.~GT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT SIRH.LDT GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DRHD.LDT LS.LDT SS1 .LDT S1RH.LDT G R. L O T H'TEN.LDT T F. N S. B G T MTEM.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1485.000 -999.250 0.084 380.000 238.875 2.059 100.875 559.500 2844.000 -999.250 0.015 380.500 220.000 2.180 81.688 517.:000 2710.000 -999.250 0.017 343.500 217.125 2.232 83.500 48,8.250 2890.000 -999.250 0.015 322. 000 214.125 2.275 97.625 491.500 2730.000 -999.250 IS 'TA~E VER. IFIC.~TION LISTZNS CHLUM&ERGER ALASK~ COMPUTING CENTER DEPT. 5500. 000 DPHT.LOT PEF.LDT 2.99(+ TLS.LOT LU.LDT 282.250 LL.LDT SS2.LDT 298.750 LSHV.LDT LSRHoLDT 2.375 LURH.LDT TENS.LDT 3224.000 MTEM.LDT GR. BGT 90. 813 C1. BGT GR.CSG -999o250 TENS.CSG HTEN. CSS -9 )9.250 DEPT. 5400.000 gPHZ.LDT PEF.LDT 2.715 QLS.LDT LU.LDT 31~.750 LL. LD'r SS2.LDT 307.000 LSHV.LDT LSRH.LDT 2.30i LURH.LDT TENS.LDT 3020.000 MTEM.LgT GR.~GT 78.625 CZ.BGT GR.CSG -999.250 TENS.CSG H'TEN.CSG -9'99. ,250 DEPT. 5300.000 CPH[.LDT PEF.LDT 2.770 C~LS.LDT LU.LDT 236.500 LL.LDT SS2.LDT 299.750 LSHV.LDT LSRH.LDT 2. 363 LURH.LgT TENS.LDT 3024.000 ~,T~M.LDT GR.. BGT 76. 313 C1. BGT GR.CSG -999. 250 TENS.CSG HTEN.CSG -9~,99o 250 DEPT. 5200.000 DPH~.LDT PEF. LDT 2. !580 ~ LS.LDT LU.LOT 306.750 LL.LDT SS2.LDT 301. 500 LSHV.LDT LSRH.LDT 2.324 LURH.LOT T~NS.LDT 2800.000 MTEM.LOT GR.BGT ,55.688 :Cl. BGT GR.CSG -~99. 250 TENS.CSG HTEN.CSG .-999.2 50 DEP'T. 5100.000 9PHI-LDT PEF.LDT 2.377 CLS.LDT LU.LOT 3 ~6. 750 LL.LDT SS2.LDT 315.500 LSHV.LDT LSRH, LDT 2.186 LURH.LOT T ENS.LD'T 27,50. ODD MT EM. LDT GR,.~GT ,51. 688 C1 GR.CSG -999.250 TENS.CSG HTEN. CSG .-999.250 DEPT, 5090.000 DPHI.LOT PEFoLDT 2.68'9 GLS.!LOT LU. LDT 340. 000 LL. LOT SS2.LDT 311.7,50 LSHV.LOT L SR.H~. LDT 2. 256 L'U~H.LDT 15-SEP-1989 0~:24. 16.125 RHOB.LOT -0.007 QSS.LOT 158.375 LITH.LDT 1409.000 SSHV.LgT 2.379 CALI.LOT 88.93~ MRES.LDT 9.266 C2.BGT -999.250 MRES.CSG 21.150 RHOB.LQT -0.010 QSS.LOT 181.625 LITH.LDT 1¢09.000 SSHV.LDT 2.305 CALI.LOT 88.313 MRES.LDT 9.422 C2.BGT -999.250 MRES.CSG 16.208 RHDB.LDT -0.005 QS, S.LDT t61. 500 LITH.LDT 1409.000 SSHV.LDT 2.371 CALI.LOT 8'7.563 MRES.LD'T 8.922. C2,BGT --999.~50 MRE.S.CSG 19.667 RHOB.LDT -0.010 QSS.LDT 173.'750 LITH.LDT 1409.000 SSMV.:LDT 2.3128 CALI.LDT 86.688 MRES.LDT ~.$44 C2.BGT -999.250 MRES.CSG 2.38(+ 0.010 89.188 1322.000 8.945 2.736 9.391 -999.250 2.301 0.001 102.688 1321.000 8.367 2.754 9.578 -999.250 2.383 0.030 84.185 1321.000 8.9,45 2.797 9.234 .-999.250 2.325 0.006 99.750 1321.000 8.906 2.818 $.766 -999.250 28.1,47 RHOB.LDT. 2.186 -O.O:OZ QSS.:LDT 0.018 228.625 LITH.LDT 149.250 1¢07.000 SSHV.LDT 1321.000 2. 191 CALI.LDT 9.41~ 86- 1563 M R f S. t D T 2.824 8. g 14 C 2. B G T g. 656 -999.250 MRES.CSG -999.150 23. 286 RHO~,. LOT 0.005 QSS.LDT 199. 500 LITH.LOT 1,(+08. 000 SSHV.LDT 2.266 CALI,LDT Z. 266 0.024 112.625 1321.000 9.1.02 DRHO.LDT LS.LDT SS1.LDT SIRH.LDT GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT SIRH.LDT GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT SIRH.LDT GR.LDT HTEN.LDT TENS.SGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT SIRH.LDT GR.LDT HTEN.LDT TENS.~GT MTEM.CSG DRHO.LDT LS.LD'T SS1.LO~T SIRH.LDT GR.LDT HTEN.LD'T TENS.BGT MTEM. CSG DRHO.LDT t S. L DT SS1.LDT $1RH.LD'T GR.LDT PAGE: 0.007 299.500 207.375 2.348 94.000 491.000 2544.000 -999.250 -0.001 341.000 207.375 2.303 75.875 481.000 2514.000 -999.250 0.019 304.750 213.500 2.297 75.063 525.500 2550.000 -999.250 -0.001 327.250 206.000 2.328 82.313 460-250 2390.000 ,-999.250 -0.002 422.000 213'125 2.193 61'656 496.500 2310. 000 -999. 250 0.009' 369.500 215.75.0 2.219 68.188 ,IS 'TAPE VSRIFIC.~T'igN LISTING ,CHLUM~ERGER -AL~SK~ CO~!PUTIN5 CENTER 15-SEP-1989 08:24 PAGE: TENS.LOT 2'794.000 MT:-=N.LOT GR. SGT 57.438 C1 .BGT GR.CSG -999. 250 TENS.CSG HTEN.CSG -999.250 DEPT. 4900.000 DPHI.LgT PEF.LDT 2.105 QLS.LDT LU.LDT 4 97. 000 LL.LOT SS2.LDT 334.250 LSHV.LgT LSRH.LDT 2.047 LURH.LDT TENS.LOT 2810.000 MTEM.LDT GR.BGT 31.453 C!.BGT GR.CSG -999.250 TENS.CSG HTEN.CSG -999.250 DEPT. 4800.000 9PHI.LDT PEF.LDT 1.910 ~LS.LDT LU. LDT 472.000 LL.LDT SSZ.LDT 329.000 LSHV.LDT LSRH.LOT 2.0'70 LUSH.LOT TENS.LOT 26~4.000 ~TEM.L~T GR.BGT 29.531 CI.~GT GR.CSG -999.250 TENS.CSG H'TEN.CSG -999.250 DEP'T. 4700.000 DPHI.LDT PEF.LDT 2.865 CLS.LOT LU.LDT 34.3.250 LL.LDT SSZ.LDT 312.750 LSHV.LDT LSRH.LDT 2.242 LURH.LDT TENS.LOT 2564.000 MTEM.L~T GR.BGT 73.688 C1.BGT GR.CSG -999.250 TENS.:CSG HTEN.CSG -999.250 DEPT. 4600.000 DPH!.LDT PEF.LDT 2.260 QLS.LDT LU.LDT 409.250 LL.LOT SS2.LDT 315.000 LSHV.LgT LSRH.LDT 2.145 LURH.L~T TEN~S.LD'T 2514.000 MTEM.LDT GR.BGT 54.938 C1.BGT GR.CSG ,-999.250 TENS.CSG HTEN.CSG '-999.250 DEPT. '450'0.000 DPHI.LgT PEF.LDT 2.6'72 QLS. LOT LU.LDT 3~0. 250 LL ;LOT SS2.LDT 317.750 LSHV.LgT LSRH.LO'T 2.1'99 :LURH.LOT T~NS.LDT 252~. OOO ~4TEM.LDT GR. BGT 87.6:~ 8 CI.'BGT GR,.CSG -'999.250 TENS.CSG HTEN.CSG -9'99.250 85.688 MRES.LDT 9.445 C2.BGT -999.250 MRES.CSG 35.59! RHOB.LDT 0.006 QSS.LDT 300.500 LITH.LDT 1406.000 SSHV.LDT 2.049 CALI.LDT 84.~75 MRES.LDT 9.484 C2.BGT -999.250 MRES.CSG 35. 362 RHOB.LDT 0.012 ~SS.LDT 287.750 LITH.LDT 1406.000 SSHV.LgT Z.O7~ CALI.LOT 84.563 MRES.LDT 9.~06 C2..BGT -'999.259 MRES.CSG 24. 5213 RHOB.LOT O. 022 QSS.LDT 206. 375 LITH.LDT 1fi06.000 SSHV.LOT 2.,260 CA.LI.;LDT 83.7.50 MRES.LDT ~. 617 C2. BGT -999.250 M~ES.CSG 31.032 ~HOB,.LDT 0.011 QSS.LOT 24'7.750 LITH.LDT 1406.000 SSHV.LDT ~.158 CALI.LDT 83.250 MRES.LDT 9.180 C2.BGT -999.250 MR~$.CSG 26.742 RHOB.LgT -0.014 QSS.LDT 220.500 LITH.'LDT 1~05.000 SSHV.LDT 2. ZO1 CALI,.LDT ~2.750 MRES.LOT ~.938 CZ.BGT -999.~50 MRES.CSG 2.848 9.844 -999.250 2.046 0.018 221.500 1321.000 11.633 2.879 10.094 -999.250 2.067 0.015 201.000 1321.000 9.477 2.908 9.672 -999.250 2 · 244 0.010 113.813 1321.000 9.148 2.. 939 9.3'98 -999. 250 2.138: 0.010 165.500 1321.000 8.766 2.951 9.430 -:999.250 2.209 0.029 132.875 1321.000 8.211 3.045 9. 023 -999. 250 HTEN.LDT TENS.BGT MTEM.CSG DRHD.LDT LS.LDT SS1.LDT S1RH.LDT GR.LD'T HTEN.LDT TENS.BGT MTEM. CSG DRHO.LDT LS.LDT SS1.LDT S1RH..LDT GR.LDT HTEN.LOT TENS.BGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT S1RH.LDT GR.LDT HTEN.LOT TENS.BG'T MTE~.CSG DRHO.LOT LS.LDT SSI.LOT S1RH.LDT GR.LDT HTEN.LD'T TENS.BGT MTEM.CSG D~HO.LOT tS.LOT SS1.LDT S!RH.LDT GR.L~T HTEN'LDT TENS.BGT MTEM.CSG 527.000 !274.000 -999.250 -0.002 549.000 220.250 2.055 33.188 557.500 2260.000 -999.250 -0.006 523.500 216.875 2.094 27.328 539.500 2234.000 -999.250 0.000 378.000 211.37'5 2.240 68.750 524,500 2104.000 -999.250 -0.012 452.250 209.125 2.197 54.188 560.500 211&.000 -999.250 0.009 410.750 219.000 2.160 101'563 519.500 1995.000 -999.250 ,IS TAP.E VER. IFIC,&TION LISTING CHLUMBERGER ,~LASK4 COMPUTING CENTER D~PT. 4400.000 DPH!.LOT PE F. LO'T 2.78 ! QLS. LOT LU.LDT 414.500 LL.LDT SS2.LDT 316.500 LSHV.LOT LSRH.LDT 2.150 LURW.LDT T=-NS.LOT 2490.000 MT.EM.LOT GR. 5GT 73.6 88 C1 . BGT GR.CSG -999.250 TENS.CSG HTEN.CSG -999.250 DEPT. 4300.000 DFHI.LDT PEr-. LDT 2.863 CLS.LOT LU.LDT 395.500 LL.LOT SSZ.LDT 320.250 LSHV.LDT LSRH.LDT 2.178 LURH.LOT TENS.LDT 2544.000 MTEN.LDT GR. 9G'T 69. 625 Ct. GR.CSG -999.2:50 TENS.CSG HTEN. CSG -999.250 DEPT. .4200.000 DPHI..LDT PEF.LD'T 2.260 QLS.LDT LU..LDT 4.83.250 LL.LDT SS2.LDT 331.750 LSHV.LOT LSRH.LDT 2.068 LURH.LDT TENS.LD'T 2384.000 ~TE~.LDT GR.BGT 44.594 CI.~GT GR.CSG -999.250 TENS.CSG HTEN.CSG -999.250 DEP'T. 4100.000 DPHI.LDT PEF.LDT 2.4'55 QLS.LOT LU. LDT 3 ~9. 000 LL.. LDT SS2.LDT 318.000 LSHV.LgT LSRH.LDT 2.176 LURH.LDT TENS.LD.T .25 ! O. 000 MT~.LDT GR. BGT 82.0 63 Cl. BGT GR.CSG -999.250 'TENS.C.SG HTEN,.CSG -999.250 DEPT. ~000.000 gPH!.LOT PEF.LDT 2.615 ~LS,.LgT LU.LDT 415.250 LL,LDT SS2.LDT 324.7S0 LSHV.LgT LSRH..LDT 2.146 LURH.LOT T~NS.LDT 2~20.000 MTEM.LOT GR. BG'T 5'?.09,4 CI.BGT GR.CSG -999.250 'TENS.CSG HTEN.,CSG -999.250 DEPT. 3900.000 gPH!.LOT PEF.LDT 2.3~4 ~LS.LDT LU.LgT 469.500 LL.LDT SS2.LD'T 332.750 LSHV.LOT 15-SEP-1989 08:24 30. 267 RHOB.LDT -0.022 QSS.LDT 240. OOO LITH.LDT 1405.000 SSHV.LDT 2.1~0 C,&LI.LDT 82.125 MRES.LDT 8. 945 C2.BGT -999.250 MRES.CSG 28.53'5 RHDB.LDT -0.022 QSS.LDT 227. 750 LITH.LOT 1405.000 SSHV.LDT 2.178 CALI.LOT 81.563 MRES.LDT 8.352 C2.BGT -999.250 MRES.CSG 35.654 RHDB.LDT -0.011 QSS.LDT 285. 500 LITH.LDT 1405.000 SSHV.LDT 2.06'4 CALI. LOT B0.563 MRES.LDT '~.977 C2.BGT -999.250 MRES.CSG 28.560 RHOB.LDT 0.010 QSS.LDT 234.000 LITH.LOT 1405.000 SSHV.LDT 2. 188 CALI.LDT 79.93~ MRES.LDT 8. 594 C2.BGT -99'9.250 MRES.CSG 30.399 ~HOB.LDT -0.016 QSS.LDT 242.750 LITH..LDT 1404.000 SSHV.LDT 2.!50 C~LI.LDT 79:.563 MRES.~LOT 8.656 C2.BGT -999.2~0 MRES.CSG 34.65T RHOB.LDT -0.011 QSS'LDT 278.000 LITH.LDT I~04.000 SSH'V.LOT 2.15! 0.028 140.875 1321.000 8.625 3.051 9.000 -999.250 2.179 0.014 131.750 1321.000 9.305 3.092 9.484 -999.250 '2.062 0.008 202.000 1321.000 8.6¢1 3.111 9.578 -999.250 2.179 0.020 146.125 1320.000 8.906 3.250 9. 266 -999. 250 2.148 O. 014 142.000 1320.000 9. ¢92 3.225 9.617 -999.250 2.078 0.013 176.625 t320.000 DRHO.LOT LS.LOT SS1.LDT SIRH.LDT GR .LDT HTEN.LDT TENS. BGT MTE~4.CSG DRHO.LDT LS.LDT SS1.LDT SIRH.LOT GR.LDT HTEN.LDT TENS. BGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT S1RH.LDT GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT SIRH.LDT GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT StRH.LDT GR.LDT HTEN.LDT TENS.SGT MTEM. CSG DRHO.LDT LS,.LDT SS1.LDT SIRH.LDT PAGE: -0.001 447.250 215.750 2.152 82.875 532.000 1960.000 -999.250 0.001 425.500 215.250 2.17¢ 85.063 5.65.500 1920.000 -999.250 -0.007 527.000 216.375 2.096 49.906 529.000 1880.000 -999.250 0.001 428. 500 215.375 2.172 '73.188 649.000 1905.000 -999.25:0 0.001 45O.5OO 2!6.875 2.14~ 60.563 590.000 1845.000 -99'9.250 -0.002 512.500 218.875 2.086 .IS TAPE V~RIF,iC~TION LISTING ;CHLUMEERGER ~LASK~ COMPUTINS C~NTER PAGE: 10 LSRH.LDT Z.079 LURH.LOT TENS.LOT 22B4.000 MTEM.LOT GP.BGT 56.750 C1.~GT GR.CSG -999.250 TENS.£SG HTEN.CSG -999.250 DEPT. 3200.0C0 3PHI.LOT PEF.LO'T 2.604 QLS.LDT LU.LDT 425.250 LL.LDT SSZ.LDT 317.~00 LSHV.LDT LSRH.LOT 2.125 LU~H,LD~ TENS.LOT 2230.000 MTEM.LDT GR.BGT 63.156 GR.CSG -999.250 TENS,CSG HTEN,CSG DEPT. 3700.090 DPHI.LDT PEF.LDT 2.232 CLS.LDT LU,LOT 499.000 LL,LOT SS2.LDT 339.000 LSHV. L:D'T LSRH,LDT 2.043 LURH.LDT TENS,.LD'T 2194.000 MTEM.LgT GR. BG'T 52.31 GiR.CSS -~99.250 TENS,CSG HTEN.CSG -999.2 50 DEPT. .36 00. 000 DPHI. L'DT PEF.LDT 2.371L CLS.LgT LU, LOT 415,250 LL.LOT S S 2, L D T 3, 13,7:50 L S H V. L g T LSRH, LOT 2. 141 LU~H.LUT TENS,LOT Z170,000 '~T'EM, L ,DT G~. 8GT 57,0 63 CI.BGT GR.CSG -999,230 'TENS.CSG H'TEN.CSG -999,2.50 DEPT. 3500.000 OPH~.LgT PEF.LDT 2.490 CLS.LgT LU.LDT 3~0.500 LL.LgT SS2,LDT 299.000 LSHV,LDT LSRH.LDT Z.260 LU~H.LDT T~NS,LDT Zt74,000 MT~,LDT GR.B, GT )8,781 C1.BGT GR.CSG -999.250 TENS.CSG HTEN.CSG '-999.250 DEP'T. 3400,000 DPH'!,LgT PEF.LDT 2,357 QLS,L. OT LU.LD'T ~'79.~00 LL.LD'T SSZ.LDT 331.250 LSHV,LDT LSRH.LDT 2,063 'LURH.LOT TENS.LDT ZO~O.O00 MT~M.LOT G~,~GT 44.188 CI,~GT GR.CSG --999.250 TENS.CSG HTEN, CSG -999~,250 2.092 CALI.LDT 75.875 MRES.LDT $.75~ C2.BGT .-999.250 MRES.CSG 32.778 RHOB.LDT 0.003 QSS.LDT 255. B75 LITH.LDT 1404.000 SSHV.LDT 2.137 C~LI.LDT 75.125 MRES.LDT 9.414 CZ.BGT -999.250 MRES.CSG 36.471 RHOB.LDT 0.006 QSS.LOT 301.750 LITH.LDT 1403.000 SSHV.LDT .2,047 CALI.LDT 77,063 MR!ES.LOT 10,242 C2.BGT -999.250 MRES.£SG 31.419 ~HOB.LDT O.OOB QSS.LDT 251,000 LITH.LDT 1403,000 SSHVoLDT 2.150 CALI..LDT 76.063 MRES.LDT 9.602 C2,BGT -999,250 MRES.CSG 24.490 ~HOB.LDT 0.003 QSS.LDT 199.625 LITH.LDT 1404,000 SSHV.LDT 2.266 CALl. LOT 76.4)8 MRES.iLDT 10. lOZ C2.~GT -999.250 MR~$.CSG 35.562 RHOB.LDT 0.006 QSS.LOT 290.000 LITH.LDT 1,~03.000 SSHV.'LDT Z.070 C~LI.LDT 75.938 MRE:S.~LOT !0.461 C2.SGT -9'99,250 MRES.CSG 8.797 GR.LDT 51.531 3.203 HTEN.LDT 536.000 9.320 TENS.BGT 1745.000 -999.250 MTEM.CSG -999.250 2.109 DRHO.LDT -0.018 O.O01 LS.LDT 468.500 151.875 SS1.LDT 207.125 1320.000 S1RH.LDT Z.19T 8.622 GR,LDT 56.031 3.201 HTEN.LDT 538.500 8.953 TENS.SGT 1665.000 -999.250 MTEM.CSG -999.250 2.048 DRHO.LDT 0.004 0.021 LS.LDT 551.000 209.875 SS1.LDT 224.375 1320.000 S1RH.LD'T 2.025 10.211 GR.LD'T 53,281 3.244 HTEN,LDT 563.500 B.755 TENS.BGT 1670.000 -999.250 MTEM. CSG -999.250 .2.132 DRHO.LDT -0.010 0.020 LS.LDT 458.500 163.250 SS1.LDT 210,750 1320.000 SIRH.LD'T 2.182 8.633 GR,LD~T 50.844 3.301 HTEN.LDT 569.000 8.734 TENS,BGT I635.000 -999.250 MTEM.CSG -999.250 2.246 ORHO.LDT -0.015 0.007 LS.LOT 370.000 128.625 SS1.LDT 201.875 1321.000 S1RH.LDT 2.318 9.758 GR,LDT 36'563 3.303 HTEN.LDT 544.000 8,578 TENS,~GT 1655,000 -999.250 MTEM.CSG -999.250 2.063 DRHO.LOT '-0.001 0.022 LS.LDT 530.000 191.875 SSI..LDT 220,250 1320.000 S1RH.LDT 2.066 9,688 GR,LDT 44.438 3.266 HTEN,LDT 589.000 9.516 TENS.OGT 1560.000 -999.250 MTEM.CSG -999.250 .IS TAPE VER, iF!C~T'ION LISTINS ;CHLUM~ERG~R AL~ ~A CO~PUTZNG CENTER DEPT. 3300.000 3PHI.LgT PEF.LDT 2.2.19 ~LS.LDT LU.LOT 488.000 LL.LgT SSZ.LOT 332°000 LSHV.LDT LSRH.LDT 2.057 LURH.LgT TENS.LOT ZO00.O00 MTEM.LDT GR.BGT 46.813 C1.EGT GRoCSG -999.250 TENS.CSG HTEN. CSG -999.250 DEPT. 3200.000 DPHI.LgT PEF.LDT 2.1 84 QLS.LOT LU.LOT 507.250 LL.LgT SS2.LDT 356.250 LSHVoLOT LSRH.LDT Z.OZ7 LURH.LgT TENS.LDT 1935.000 MTEM.LgT GR. BGT 43. 875 C1. BGT GR.CSG -999.250 TENS.CSG HTEN.CSG -999. 250 DEPT. 3100.000 DPHI.LOT PEF.LDT 2.203 CLS.LgT LU. LDT 560.000 LL.LOT SSZ.LDT 352,Z50 LSHV,LDT LSRH,LDT 1.98.4 LURH.LDT TENSoLDT 1830.000 MTE~.LDT GR 5GT 36.813 CloBGT GR.CSG -999.250 TENS.CSG HTEN.CSG -999.250 DEPT. 3000.000 DPHZ.LDT PEF.LDT 2-232 Q:LS.LDT LU.LDT 475..500 LL.LOT SS2.LDT 3~8.750 LSHV.LDT LSRHoLDT 2-0'53 LU~.H..LDT TENS.LDT 1895.000 MTEM.LDT GR.SGT 36.656 CI.iEGT GRoCSG -999.250 TE'NS.CSG HTEN.CSG -999.250 DEPT. 2900.000 OPHI.LDT PEF.LDT 26.641 ~LS.LDT LU.LDT 203.500 LL.LDT SS2. LDT 130.875 LSHV.LDT LSRH.LDT 2.537 LURH.LD? TENS.LDT 1905.000 M~E~.LDT GR.BGT ~4,.406 CI.BG'T G2.CSG 40.625 TENS.CSG H'TEN.CSG 481.500 DEPT. 2800.000 OPHZ.LDT PEF.LDT -99~.250 QLS.LDT LU.LDT -'999.250 LL.LOT SS2.LDT -999.250 LSHV.LDT !5-SEP-1989 08:24 36. 595 RHOB.LDT 0.001 QSS.LOT 292.000 LITH.LDT 1402.000 SSHV.LDT 2.061 CALI.LDT 75.313 MRES.LDT 9.680 C2.BGT -999.250 MRES.CSG 35. 873 RHOB.LDT 0.009 QSS.LOT 309.250 LITH.LDT l~OZ.DO0 SSHV.LDT 2.039 CALI.LDT 74.375 MRES.LDT 11.572 C2.BGT -999.250 MRESoCSG 38.569 RHOB.LDT -0.010 QSS.LDT 331. OOO LITH.LDT t~01.000 SSHV.LDT 1.985 CALI.LDT 74.313 MRES.LDT 10.008 C2.~GT -999.250 MRES.CSG 35. 983 RHOB.LDT O. 020 QSS.LDT 292.250 LI'TH.LDT 1601.000 SSHV.LDT 2.074 CALI.LDT .'7, 3..25 O M R E S. :L O'T 9.555 C2.BGT -999.250 MRES.CSG 49.679 RHOB.LDT 0.111 QSS.LDT 1!5.063 LITH.L.'OT !404. OOO SSHV.LOT 2.596 :CALI.LDT T3.063 MRES.LDT 9.22'7 C2.BGT 18'35.000 MRES.CSG 2.046 0.003 192.625 1320.000 9.445 3.270 8.398 -999.~50 2.058 0.021 200.750 1320.000 11.570 3.428 9.898 -999.250 2.014 0.042 240.000 1320.000 11.539 3.357 1.2.344 -999.250 2. 056 0.017 186.000 1320.000 10.719 3. 422 11.406 -999.250 1.8:30 -0.133 24.672 13. 2 1.000 8.594 3. 396 9.305 3.43 6 -999.250 R:HO~.:LDT -999.250 -999.250 QSS.LDT -999.Z50 -999.250 LI'TH.LDT -999.250 -999.250 SSHV.LDT -999.250 DRHO.LDT LS.LDT SSI.LDT S1RH.LDT GR.LDT HTEN .LDT TENS. BGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT S1RH.LDT GR.LDT H'TEN.LDT TENS.SGT MTEM.CSG DRHO.LDT LS.LDT SSI.LDT S1RH.LDT GR.LDT HTEN.LDT TENS. BGT M'T E M. C $ G DRHO.LDT LS.LDT SS1.LDT S1RH.LDT GR.LD'T H'TEN.LDT TENS.BGT M'TEM. C:SG DRHO.LDT LS..LDT SS1.LDT SiRH.LDT GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT S1RH.LO'T PAGE: 11 -0.011 536.000 214.375 2.102 44.781 538.000 1460.000 -999.250 0.029 563.000 235.625 1.945 39.625 543.000 1425.000 -999.250 0.029 611.000 237.750 1.901 34.219 495.500 1450.000 -999.250 -0.006 53O.0O0 217.000 2.086 38.063 486.250 1385.000 -999.250 -0.707 216.875 72.938 4 · 078 39.281 514:500 1485.000 72.563 -999.250 -999.250 -999.250 -999.250 .IS TAP.E VER. IFZC~TiON LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER LSRH.LDT -999.2 50 LURH. LOT TEN S, LOT -9 99.2 50 MT EM.LOT GR,SGT -999.250 C1.BGT GR,CSG 45,094 TENS,CSG HTEN.CSG 464.250 DEPT, 2700,000 DPHI,LDT PEF,LDT -999,2 50 CLS,LDT LU.LDT -999.250 LL.LDT SS2.LDT -999. 250 LSHV.L3T LSRH. LDT -999,,250 LU~H.LgT TENS.LOT -999.250 MTEM.LOT GR, BGT -999,250 C1, BGT GR,CSG ¢0,656 TENS,CSG HTEN,CSS 442,250 DEPT. 2600. 000 OPM!.LDT PEF.LDT -999.250 CLS. LOT LU~, LDT -~99.2 50 LL. LDT SS2,LDT -999,250 LSHV,LDT LSRH,LDT -999,250 LURH.LDT TENS.LDT -999.250 MTEM.LgT GR,BGT -999,250 C1, BGT GR,CSG 36.000 TENS,CSG HTEN. CSG 457.750 DEPT., 2500,000 3PHZ,LDT P E: ~, L D'T '- 999 - 250 Q L 'S, L D T LU.LDT -999- 250 LL,.LgT SSZ.LD'T -999,250 LSHV.LOT LSRH.LDT -999. 250 LURH.LDT TENS.LDT -999.250 MTEM.LOT GR. ~GT -9 99.2 50 Cl. BG'T GR,CSG 16,969 'TENS.CSG HTEN. CSG 472.5 O0 DEPT. 2400,000 OPHI.LgT P EF, LD'T -999.2 50 QLS.LOT LU.LDT -999. 250 LL.LDT SS2oLD'T -999.250 LSHV.LDT LSRH, L~D'T -999,250 LURW.LDT TENS.LDT -999.250 MTEM.LDT GR. ~GT -999.2 ~0 Ct. BGT GR.C, SG 3,5,. 2,B1 TENS.CSG HTEN. CSG 4,6'9.250 DEPT. 2300. OOO DPHI.LOT PEF.LDT -999.250 QLS. LOT LU. LD'T '-999. Z '50 LL. LOT SS2.LD'T -995,.250 LSHV.LOT LSRH.LDT -999.2150 LURH.LOT TENS,LOT -999.250 MTEM.LDT GR. 5G'T -999.2, 5 O C1. ~G'T GR.CSG 21,031 'TENS.CSG HTEN,CSG 471,000 !5-5EP-1989 0:8:24 -999.250 CaLI.LDT -999.250 MRES.LDT -999.250 C2.BGT 1550.000 MRES.CSG -999.250 RHOB.LDT -999. 250 QSS.LDT -999. 250 LITH.LDT -999.250 SSHV,LDT -999.250 CALI,LDT -'999. 250 MRES.LOT -999.250 C2.BGT 1605,000 MRES,CSG -999.250 RHOB.LDT -999.250 QSS.LDT -999.250 LITH.LDT -999.250 SSHV.LDT -999. 250 CALI.LDT -999.250 MRES.LDT -999.250 C2.BGT 1:595,000 MRES,CSG -999.250 -999,250 -999.250 3,422 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.46T -'999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 3,512 -999,250 RHOB,LDT --999.250 -9'99,250 QSS.LDT -999,250 -999. 250 LITH.LOT -999.250 -999.;250 SSHV.LDT -999.250 -99'9.Z 50 .CALI,LgT -999,250 -999.250 M~ES.LDT -999.250 - 999.250 C2, ~BGT -999. 250 1560.000 MRES,CSG 3.561 -999,250 RHOB.LDT -999.250 -999.250 QSS.~LOT -999.250 -999.. 250 LiTH.LOT -999.250 -999°250 SSHV.LDT -999.250 -99,9. 250 CALI.LDT -999,250 -'~99. 250 MRES.LDT -999.250 -999. 250 C2. BGT -99'9.25'0 1550,000 MRES,CSG 3.590 -999.250 RMOB.LDT -999.250 QSS.LgT -999.250 ti'TH.LOT -999.250 SSHV.LDT -999,250 CALI,LDT - 999 . .250 M R E S. L g T - 999 . 250 CZ , BGT ! 590. OOO MRES,CSG -999.250' -999,250 -999.250 -999.250 -999,250 -999.250 -999.250 3.58.~ GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DRHO.LDT LS.LDT SS1,LDT S1RH,LDT GR.LDT HTEN.LDT TENS.'BGT MTEM.CSG DRHO.LD'T LS.LDT SS1.LDT S1RH.LDT GR.LDT HTEN.LDT T:ENS.~GT MTEM.CSG DRHO.LDT LS.LDT SS1.LDT S1RH.LDT GR.LDT HTEN.LDT TENS.BGT MTEM.CSG ORHO..LDT LS.LDT SS1.LDT S1RH.LDT GR.LDT HTEN.LDT 'TENS.BGT MTEM.CSG DRHO.LDT :LS-LOT SS1.LD'T S1RH,LDT GR.LDT HTEN.LDT TENS.~GT MTEM.CSG PAGE: 12 -999.250 -999.250 -999.250 72.125 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 71.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 71'063 -999.250 -999.250 -999. 250 -999.250 -999.250 -9'99.250 - 999. :250 70. 438 -999.250 -999°250 -999,250 -999,250 · -999,250 -999'250 -999.~50 69. 688 -999,250 -999. 250 -999.250 -999,250 -999,250 -999. 250 -9'99,250 68'625 .IS TAPE 'VERIFICATION LISTING ;CNLUMSERGER ALASKA CO~4PUTiNG CTNT~ 15-SEP-1959 0~:24 PAGE: 13 DEPT, 2200.000 DPHi. LOT -999,250 PEF,LDT -999,250 CLS,LDT -999,250 LU.LDT -999,290 LL.LOT -999,250 SS2.LDT -999.250 LSHV.LDT -999.Z50 LSRH.LDT -990.250 LURH.LOT -gqg.zso TENS.LDT -999,250 MTSM.LgT -999.250 GR,BGT -999,250 CI.BGT -999,250 GR,CSG 24,594 TENS.CSG 1550,000 HTEN,CSG 495,000 RHOB.LOT QSS.LDT LITH.LDT SSHV.LDT CAL!.LDT MRES.LDT C2.BGT MRES.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2-50 3.664 DRHO,LDT tS,LOT SS1,LDT S1RH,LDT GR,LDT HTEN,LDT TENS,3GT MTEM,CSG DEPT, 2100.000 DPHI,LDT -999.250 RHDB,LDT -999,250 DRHO,LDT PEF.LDT -999.250 CLS.LDT -999. ZSO (~SS.LDT -999.Z50 LS.LDT LU.LOT -9~9.250 LL,L~T -999.Z50 LITH.LDT -999.Z50 SS1.LDT SS2,LDT -999.250 LSHV,LDT -999,250 SSHV,LDT -999,250 S1RH,LDT LSRH,LDT --999,250 LURH,LDT -'999,250 C~LI,LDT -999,250 GR,LDT TENS,LOT -999.250 MTEM,LDT -999,Z50 MRES,LDT -999.250 HTEN,LDT GR,iBGT -999,250 CI,~GT -399,25D C2,8GT -999.2.50 TENS,BGT GR,CSG 1'7.203 TENS.CSG 1500,000 MRES,CSG 3.791 MTEM,CSG HTEN,CSG 511 DEPT, ZO00,OOO 9PHI.LOT -999,250 PEF.LDT -999,250 QLS,LDT -999,250 LU,LD'T -999.250 LL.LOT -999.250 SSZ,LDT -999,250 LSHV,LgT -999,250 LSRH.LDT -999,250 LURH:.LgT -999,250 TENS,LOT -999.250 MTEM,LgT -999,250 GR,,BGT -999,250 CI,BG~ -999,250 GRoCSG ~0.750 'TEN:S,CSG HTEN,CSG 513.500 -999.250 -999.250 -999.2-50 -999.250 -999.250 -999.250 -999.~50 3.783 RHDB.LOT QSS.LDT LITH.LDT SSHV.LDT CALI.LDT MRE;S.LDT C2.BGT MRES.CSG DRHO,LDT tS,LOT SSI,LOT S1RH,LDT GR,LDT HTEN.LDT TENS.BGT MTEM.CSG DEPT, !900,000 DPHI,LOT -999,250 RHOB.LDT -999,250 DRHOoLOT PEF.LDT -999,250 ~LS,LDT -999,250 QSS,'LDT --999.250 tS,LOT LU.LDT -999.250 LL.LDT -999.250 LITH.LOT -999.Z50 S~S1.L~DT SS2,LDT -999,250 LSHV,LOT -999.250 SSHV.LOT -999,250 SiRH.LDT LSRH,LDT -999,250 LURH,LgT -999,250 CALl.LOT -999.250 GR,LDT TENS.,LDT -999,250 M?EM.LDT -99'9,250 MRES,LDT -999.250 HTEN,LOT GR.BGT '-999.250 C!.BGT -999.250 C2.BGT -999.250 TENS.BG'T GR,CSG 22,125 TENS,CSG 1530,000 MRES,CSG: 3,838 MTEM.,CSG HTEN, CSG 5!3,500 - 999. Z 50 -999.250 · -999.250 -999.250 -999.250 -999.,250 -99 9.250 4,020 DEPT. 1800.000 DPHI.LD'T -999.250 PEF.LDT -9 99.2 50 QLS.LDT -999. 250 · LU,LOT -999,250 Lt, LOT -999, 250 SS2.LDT ,-999.250 LSHV,LD'T -999,250 LSRH,LDT -999,250 LURH,LDT -999. :250 T~NS.LDT -999.,250 ~4T EM. LO'T -999. 250 GR, BG'T -'~ 99,250 CI, ~-GT -999,250 GR. CSG 35.719 TENS.CSG 1495.000 HTEN. CSG 514,. 0§0 RHOB,LDT QSS.LDT LITH,LDT SSHV,LgT CALI.LDT ~RES.,LDT C2.BGT MRES,CSG DRHO.LOT tS.LOT SS1.LDT S1RH.LDT GR.LOT HTEN.LDT TENS.BGT MT~M.CSG DEPT. 1700.000 DPH!.LDT -999,250 RHOB.LOT -999,250 DRHO.LDT PEF.LOT -999,250 ~LS.LDT -999,250 QSS,;LDT -999,250 LS.LDT LU,LDT -999.250 LL,LDT -999,250 LI'TH,'LDT -999,250 SSI,LOT SSZ,LDT -999.250 LSHV,LDT -999.250 SSHV,LOT -999.250 S1RH,LDT -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 68.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 67.375 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999.250 67.000 -999.250 -999-250 -999.250 -999. 250 -999.250 -999. 250 -999.250 66.313 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999-250 65.313 -999.250 -999. Z 50 - 999.250 -999 ' 250 .IS TAPE VER. IFIC,~TZ~N LiST'ItJG ;CHLUMBERGER ~LASK,~ COMPUTINr~ CSNT:~ 15-$EP-1989 08:24 LSRH,LDT -999.250 LURH.LgT -999.250 CALI,LOT TENS.LDT -999.250 MTEM.LDT -999.250 MRES.LgT GR.BGT -999.250 C1.BGT -999.250 C2.BGT GR,CSG 23,891 TENS,CSG 1450,000 MRES,CSG HTEN,CSG 518,000 --999.250 -999.250 -999.750 3.977 GR.LDT HTEN.LDT TENS.BGT MTEM.CSG DEPT, 1500,000 DPHI.LgT -999,250 RHOB,LgT -999,250 DRHO,LDT PEF.LDT -999.250 QLS.LOT -999.250 QSS.LgT -999.250 LS.LDT LU.LDT -999.250 LL.LOT -999.250 LITH.LDT -999.250 SSI.[D'T SS2.LDT -999.250 LSHV.LOT -999.!50 SSHV.LDT -999.250 S1RH.LOT LSRH,LDT -999.250 LURH,LDT -999,250 C~LI,LDT -999.250 GR,LDT TENS.LDT -999.250 MTEM.LgT -999.250 MRES.LDT -999.250 HTEN.LDT GR.SGT -999.250 CI.BST -999.250 C2.BGT -999.250 TENS.BGT GR.CSG 32.969 TENS.CSG 1465.000 MRES.CSG ~.023 MTEM.CSG HTEN.CSG 535.000 DEPT, 1500,000 DPHI,LDT .-999,250 RHDB,LDT -999,250 DRHO,LDT PEF.LDT -999.250 ~LS.LDT -999..~50 Q$S.LDT -999.250 L$.LDT LU.LOT -999.25g L~L.LDT -999.159 LITH.LDT -999.250 SSi.LDT SS2,LDT -999,250 LSHV,L~T -999,250 SSHV,LDT -999,250 S1RH,LDT LSRH,LDT -999,250 LURH,LDT -999,250 C~LI.LOT '-999,250 GR,LDT TENS.LDT -999.250 ~TEM.LOT -999.250 ~RES.LDT -999.250 HTEN.LDT GR.~GT -999.250 Clo~GT -'999.250 C2.BGT -999.250 TENS.~GT GR.C.SS 51.344 TENS.CSG 1415.000 MRES.CSG 4.012 MTEM.CSG HTEN.CSG 541.500 DEPT- 1400.000 DPHi.LDT -999.250 RHOB.LDT ,-999.250 DRHO.LDT PEF.LDT -999.250 QLS.LDT -999.250 QSS.LDT -999.250 LS'LDT LU,LDT -999.250 LL.:LDT -999.250 LITH.LD.T -999,250 SS1,LDT SSZ,LDT -9'9~, 2 50 LSHV.L~T -999.250 SSHV,:LDT -999,250 S1RH,LDT LSRH.LDT -999,250 LURH.LOT .-999. 250 C~LI.LOT -99'9,250 GR.LDT TENS.LDT -999.250 MTiEM.LDT -999.250 MRES.LDT -99'9.250 HTEN.LD'T GR.~GT -9'99.250 C1.BGT -999.250 C2.BGT -999.~50 TENS..BGT GR.CSG 41.594 TENS,.CSG 1'3.30. :000 MRES.:CSG 4.063 M'TEM.CSG HTEN.CSG 54!. 000 DEPT, 1300,000 DPHI,LOT -999.250 ~HOB.LDT -999,250 PEF,LDT -9'99,.250 QLS.LgT -999,250 QSS.LDT -999,250 LU,LDT -999.250 iLL.LDT -999,250 LI'TH, LD.T -!)99,250 SS2,LDT -999,250 LSHV,LDT -999.250 SSHV,LDT -999,250 LSRH, LDT -999, 25 O LURH.LgT -999,250 CAL I,LDT -999,250 lENS,LOT -999,250 MTEM.LDT -999,250 MR5S,LDT -999,250 G~, ~BGT -999,2 50 C1, ~GT -999,250 C2,~GT -999,250 GR,CSG 31.969 TENS,CSG 1290,000 MRES,CSG 4,145 HTEN.CSG 535. OOO DRHO.LDT L S. LDT SS SIRH.LDT GR.LDT HTEN.LDT TEN S. BGT MTEM.CSG DEPT, 1200,000 3PHI,LgT -999,250 RHDB,LDT -999,250 DRHD,LDT PEF.LD'T -999.250 QLS.LQT -999.250 ~SS.LDT -999.250 LS.LDT LU,LDT .-999, Z 50 LL, LOT -999,250 LITH,LDT -999,250 SS1,LDT SSZ,:LDT -999,2150 LS'HV,LDT -999,250 SSHV.LDT -999,250 S1RH,LDT LSRH, LD'T -999,250 LURH,LDT -999,250 CALI,LDT -999,250 GR,LDT TENS.LDT -999.250 MT~M.L;DT -999.250 MRES.iLDT -999.250 HTEN.LDT GR,~GT -999,250 C1,BGT -999.250 C2,SGT -999°250 TENS,~GT GR,CSG 38,5131 TENS,CSG ! 2.40, OOO MR:ES,C SG 4,211 MTEM, CSG HTEN.CSG 523..500 P~GE: 14 -999.250 -999.250 -999.250 63.563 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 62.844 -?,99.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6 !. 969 '-999. 250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 62.250 -999,250 -999,250 -999'250 -999,250 -999,250 -999,250 -999,250 61.469 -999,250 -999,250 -999-250 -999,250 -'999,250 -999.250 -999.250 60.719 ,IS TAPE V--_R'IFZCAT!ON LISTZNG ;CHLUMBERGER ALASKA Cg~4PUTZNG CENTER 15-SEP-1989 08:24 PAGE: 15 DEPT. I100.000 SPHI.LDT -999,250 RHOB.LDT FEE.LOT -999,250 CLS.LOT -999.250 OSS.LDT LU.LDT -999.250 LL.LOT -999.250 LITH.LDT SS2.LDT -$99,2'50 LSHV.LDT -999.250 SSHV.LDT LSRH.LDT -9'99. 250 LURH.LgT -999. !50 CALI.LDT TENS.LDT -999.250 MTEM.LDT -999.250 MRES.LDT GR. BGT -999.250 CI . BGT - 999. 250 C2. BGT GR.CSG .27.8/+4 TENS.CSG 1240.000 MRES.CSG HTEN.CSG 551. ODD DEFT, lOOO. OOO DPHI.LDT -999-. 250 RHOB.LDT PE.~.LDT -999.250 CLS.LDT -999.250 QSS.LDT LU.LDT -999.250 LL.LOT -999.250 LITH.LDT SS2.LDT -9a, 9,250 LSHV.LgT -999,250 SSHV.LDT LSRH.LDT -999.250 LURH.LDT -999.Z50 C~LI.LOT TENS.LDT -999.250 HTSM.LDT -99'9.250 MRES.LDT GR. BGIT -999,2 50 CI . BGT -999. 250 C2,BGT GR.CSG Z3,063 TENS,CSG 1050.000 MRES.CSG HTEN,CSG 5/+1,000 DEPT. 997.000 DPHI.LDT PEF. LDT -999.2 50 ~LS.LOT LU.LDT -9:99. 250 LL,LOT SS2.LDT -999.250 LSHV.LOT L:SRH.LDT -999.2:50 LURH.LgT TENS.LDT -999.2:50 MT~M.LDT GR, 5GT -:999.2:50 C1,'BGT GR.CSG 39.750 TENS,CSG HTEN, CSG 547.5 O0 -999.250 - 99 9..250 -999,250 -999.25'0 -'999,, 250 -999.Z50 -'~99.250 1170.000 RHOB.LDT QSS.LOT LITH.LOT SSHV.LDT C~LI.LDT MRES.LDT C2.BGT MRES.CSG -999,250 DRHOoLDT -999.250 LS.LDT -999.250 SS1,LDT -999.250 SIRH.LDT -999.250 GR.LDT -999.250 HTEN.LOT -999.250 TENS.~GT /+.Z3O MTEM.CSG -999.250 DRHOoLDT -999.Z50 LS.LDT -999.250 SSI.LDT -999.250 SIRH.LDT -999.250 GR.LDT -999.250 HTEN.LDT -999.250 TENS.BGT 4.266 MTEM.CSG -999.250 DRHO.LDT -999. 250 LS.LDT -999.250 SS1,LDT -999.250 $1.RH.LDT -999. 250 GR.LDT -9'99. 250 HTEN.LDT -999.250 TENS.BGT 4.27:3 MTEM.CSG -999.250 -999.250 -999.250 -999.'250 -999.250 -999.Z50 -999.250 60.59/+ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 60.500 -999.250 -999.250 .-999..250 .-999.250 -999.250 -999.250 -999.250 60.469 END OF DATA ;~'~ · , ~-- ~ ~- FILiE TRAILER ;~'~ ~ ~-. FILE NAME : EDIT SERVICE : FLIC VERSION : O01AOZ DATE : 89/09/14 MAX REC SIZE : 1092 FIL'E TYPE : iLO L~S'T FILE SERVICE NAM:E : EC, IT DA'TE : 89/09/14 ORIGIN : FLIC TAPE N~ME : 7~461 CONTINUATION ~ : 1 P~EVIOUS 'TAPE : COMMENT : CONOCO INC, ,MILNE POI NT ,MILNE POINT UNIT G'-3,50-029- 2194Z IS TAPE V~R'IFIC~T.ICN LISTING CHLUMBERGER .~LASK~ COMPUTING CENTE~ 15-SEP-19~.9 08:24 ~. ~.-e.. ~ REEL TRAILER ~-~ SERVICE N&M] : =OIT DATE : 8970g/14 ORIGIN : FL!C REEL NAME : T3~61 CONTINUATION ~ PREVIOUS REEL COMMENT : CONOCO INC. ~MILNE POINT ,MILNE POINT UNI'~ G-3,50-O2g-219~2 PAGE: 16